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HomeMy WebLinkAbout208-156•
Ima a Pro'ect Well Histo File Cove~age
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~~~ - L~~/j Well History File Identifier
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NOTES: ^ Other::
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Production Scanning
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Stage 1 If NO in stage 1, page(s) discrepancies w re found: YES NO
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Comments about this file: y
10/6/2005 Well History File Cover Page doc
f�3LC 0-334
Regg, James B (DOA) P ) 2061€7 )
From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] epe 7('l(i3
Sent: Tuesday, June 11, 2013 3:14 PM f7
To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops
Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK,
D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;
Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC
Specialists; Daniel, Ryan
Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Grey, Leighton (CH2M Hill); Weiss, Troy
D
Subject: 09-33A(PTD#2081560) Outer Annulus Casing Pressure Above MOASP
Attachments: 09-33A(PTD#2081560) TIO Plot.docx; 09-33A(PTD#2081560)Wellbore Schematic Plot.pdf
All,
Producer 09-33A(PTD#2081560)was reported to have outer annulus pressure above MOASP on 06/10/2013. The
tubing/inner annulus/outer annulus pressures were reported to be 263/1980/1120 psi. The well was evaluated with an
outer annulus repressurization test on 05/04/2013 and found to have a buildup rate of 100 psi per day. The outer
annulus pressure is considered manageable by bleeds, however, it was allowed to exceed MOASP. The pressure was
bled off the same day.
Plan forward:
1. DHD: Monitor outer annulus pressure to ensure the buildup rate has not increase to an unmanageable level.
A TIO plot and a wellbore schematic is attached for reference.
Thank you,
Jack Disbrow
BP Alaska -Well Integrity Coordinator
GWgrcni2aiGr
SCANNED f
Office: 907.659.5102
WIC Email:AKDCWellIntegrityCoordinator Pbp.com
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TREE= 4,1/16"CIW
WELLHEAD= McEVOY 09-33A WELL ANGLE TES:70° jgRO ETBG&LNR"""
ACTUATOR= BAKER
KB.ELEV = 55' 1
BF El-EV 2081' H3-1/2"OTIS TRSV SSSV NIP,ID=2.813"
KOP= 3300' Q
L,Max Angle= 98°@ 10334"
Datum MD= 12726'
Datum'DID= 8800'SS
GAS LIFT MANDRELS
13-3/8"CSG,72#,L-80,ID=12.347" 2522' ST MD ND DEV TYPE VLV LATCH PORT DATE
1 3021 3020 5 MMG DOME RK 16 06/02/09
2 4745 4556 36 MMG DOME RK 16 06/02/09
3 5821 5410 37 MMG DOME RK 16 06/02/09
4 6380 5855 37 MMG SO RK 24 06/02/09
Minimum ID = 1.875" @ 9465' 5 6904 6273 38 MMG DMY RK 0 09/29/91
BTT Plug Holder Bushing 6 7397 6662 37 MMG DMY RK 0 09/30/95
7 8015 7156 36 MMG DMY RK 0 09/29/91
8 8693 7711 37 MMG DMY RK 0 05/31/92
9 9310 8207 33 MMG DMY RK 0 10/10/94
9397' _J—I3-112"BKR LOC SEAL ASSY,ID=4.75" I
I►MI *4 9398' H 9-5/8"X 3-1/2"BKR MODEL D PKR, ID=4.75" I
9417' J—17'BKR MILLOUT EXTENSION,ID=6.00 I
9423' J—17"X 3-1/2"XO, ID=2.992" I
1� ���, 9455' H2-3/8"BTT DEPLOYMENT SLV, ID=2.250"
TOP OF 7"LNR H 9472' 11 I
� kll 9456' H PLUG BUSHING,ID=1.875" I
1�='; 9511' H3-1/2"OTIS XN NIP, ID=2.75" I
X11 r
1111 0111
3-1/2"TBG,9.3 4,13CR-80, .0087 bpf,ID=2.992" H 9526' X11 4 - 9526' —13-1/2"BKR MULESHOE,ID=2.992"
1111 '111
1N 4
1111 •114 9522' —I ELMD TT LOGGED 10/09/91 I
111 11
9-5/8"CSG,47#,L-80, ID=8.681" —I 9781' 1 11 1 ■11 4
11• /111 9909' J—(CEMENT RAMP WINDOW
111+1 111114
111• 111'
114 .4 4, MILLOUT WINDOW 9910'-9914'
PERFORATION SUMMARY I114
REF LOG: SWS MCNL/GR/CCL OF 04/01/09 I 111111• 't _
111111
ANGLE AT TOP PERF:89°@ 11650' N 4/1111111t Oft
Note:Refer to Production DB for historical perf data 11111114
11NN11
SIZE SPF INTERVAL Opn/Sqz DATE 1111111111111111;', S
1.56 6 11650- 12100 0 04/03/09 11111114
1.56 6 12600- 12625 0 04/03/09 N 1
11111111114a 1�1���1�
1111111
1.56 6 12670- 12685 0 04/03/09 11111111
1.56 6 12770- 12815 0 04/03/09 11111114'. PBTD H 13125'
1111111+
1.56 6 12920- 12960 0 04/03/09 �
1.56 6 13015- 13090 0 04/03/09 �4> 2-3/8"LNR,4.7#,13C STL, .0039 bpf,ID=1.995" —I 13163' I
11111114•
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111j111j1j114
1111111111111i1!
111111111111114
I
111,' ,• 10184' I--{FISH-CA-RD-RK(LOST 10/10/94) I
PBTD —I 10277' ,1.1.1....I.1:♦:
x'1'1'1'1'1.1.1'
I 111111114
7"LNR,29 4,L-80,.0371 bpf,ID=6.184" H 10316'
A1A1A 1A 1A 1AA 4
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
07/05/85 ORIGINAL COMPLETION 11/14/09 JC/PJC TREE C/O(10/26/09) WELL: 09-33A
09/29/91 LAST WORKOVER PERMIT No:"208156
04/04/09 NORDIC 1 CTD SIDETRACK(09-33A) API No: 50-029-21365-01-00
06/01/09 JLJ/TLH GLV C/O(04/27/09) SEC 2 T10N,R15E, 1705'FSL&1023'FEL
06/13/09 KDC/TLH GLV C/O(06/02/09) I
09/17/09 SM/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska)
• el3lt O t -334
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com]
Sent: Sunday, November 04, 2012 7:34 PM
To: Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2
Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline
Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A;
Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere
Cc: AK, D &C DHD Well Integrity Engineer
Subject: OPERABLE: Producer 09 -33A (PTD #2081560) IAxOA Manageable By Bleeds
All,
Producer 09 -33A (PTD #2081560) has been found to have an OA build up rate of 125 psi /day when the well is
online. This build up rate confirms that the well can be managed with no more than two bleeds per week to
keep the OA pressure below MOASP, making the well manageable by bleeds. Wellhead testing was also
performed and confirmed that the primary wellhead seal is holding, indicating that the IAxOA communication
is not occurring through the wellhead. At this time the well is reclassified as Operable. Please notify Well
Integrity if the OA build up rate becomes unmanageable.
Thank you, a°13
Mehreen Vazir %W ED
BPXA Well Integrity Coordinator
From: AK, D &C Well Integrity Coordinator
Sent: Thursday, October 11, 2012 6:28 AM
To: 'jim.regg @alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK,, PS FS2 Facility OTL; AK, OPS FS2 DS
Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; D &C Well Services Operations Team
Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; I2 •okwe, Chidiebere
Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLU ONS LLC)
Subject: UNDER EVALUATION: Producer 09 -33A (PTD #2081560) Sus'•ined Casing Pressure Above MOASP on OA
All,
Producer 09 -33A (PTD # 2081560) has confirmed sustain d casing pressure on the OA above MOASP. The
tubing /IA /OA pressure were equal to 232/1840/1020 • i on 10/09/2012. The well is reclassified as Under
Evaluation and may remain online while further dia: ' ostics are performed.
The plan forward:
1. Wellhead: PPPOT -IC
2. Downhole Diagnostics: OA Repres:urization Test to determine if OA build up rate is manageable
TIO plot and wellbore schematic ar attached for reference:
« File: 09 - 33 TIO Plot 10 -11- / .docx » « File: 09- 33A.pdf »
1
• P 01 33
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 10/1111 -
Sent: Thursday, October 11, 2012 1:21 PM
To: Regg, James B (DOA)
Subject: RE: UNDER EVALUATION: Producer 09 -33A (PTD #2081560) Sustained Casing Pressure
Above MOASP on OA
HI Jim,
I believe you are correct in your assessment that the OA pressure has been bled on a regular basis to maintain below
MOASP.
While the well is Under Evaluation we will be performing a Pack Off Test on the inner casing hanger to test the wellhead
seals (PPPOT -IC) and possibly re- energize the seals in an attempt to lower the OA build up rate. Further to that, our
internal well integrity practice is to allow 2 bleeds per week to keep a well Operable under the "manageable by bleeds"
policy. When the well integrity team is notified of a well with an OA that is regularly being bled or if the pressure
exceeds MOASP, we verify that the well is still Operable under this criteria. Our Downhole Diagnostics technicians
perform a OA Repressurization Test, during which calibrated test gauges are used and test tags are placed on the well to
ensure the well operator does not perform any bleeds or make any changes to the well while the test is ongoing so an
accurate build up rate can be captured under the documented conditions.
The AOGCC was included on this notification to meet the requirements of CO 492. If 1 have misunderstood the
requirements of the policy, I would appreciate any clarification you could provide so appropriate notifications and
actions can be taken in the future.
Thank you,
Mehreen Vazir
BPXA Well Integrity Coordinator SCANNED APR 0 9 2013
907 - 659 -5102
From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov]
Sent: Thursday, October 11, 2012 12:51 PM
To: AK, D &C Well Integrity Coordinator
Subject: RE: UNDER EVALUATION: Producer 09 -33A (PTD #2081560) Sustained Casing Pressure Above MOASP on OA
I have to ask — why now? TIO plot shows approximately one bleed per week with same repressure signature for at least
past 90 days. Appears from chart the only reason it is now being reported as SCP is because someone decided not to
bleed pressure when OA approached 1000psi. Looks to me like you have 90 days of OA Repressurizaton Tests with same
signature. I'd appreciate your assessment.
Jim Regg
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907 - 793 -1236
1
•
From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWellIntegrityCoordinator@ bp.com]
Sent: Thursday, October 11, 2012 6:28 AM
To: Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS
Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team
Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere
Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC)
Subject: UNDER EVALUATION: Producer 09 -33A (PTD #2081560) Sustained Casing Pressure Above MOASP on OA
All
Producer 09 -33A (PTD # 2081560) has confirmed sustained casing pressure on the OA above MOASP. The
tubing /IA /OA pressure were equal to 232/1840/1020 psi on 10/09/2012. The well is reclassified as Under
Evaluation and may remain online while further diagnostics are performed.
The plan forward:
1. Wellhead: PPPOT -IC
2. Downhole Diagnostics: OA Repressurization Test to determine if OA build up rate is manageable
TIO plot and wellbore schematic are attached for reference:
«09 - 33 TIO Plot 10 11 12.docx» «09 33A.pdf»
Thank you,
Mehreen Vazir
BP Alaska - Well Integrity Coordinator
« OLE Object: Picture (Device Independent Bitmap) »
WIC Office: 907.659.5102
WIC Email: AKDCWeIIIntegritvCoordinator PBP.com
Direct Cell: 832.651.5253
Direct Email: Mehreen.VazirPBP.com
2
PBU 09 -33A
PTD #2081560
10/11/2012
TIO Pressures Plot
Well: 09-33
4.00D •
3.000 -
—6— IA Tic
—II— IA
-0A
2.000 ' - 00A
--A- 000A
on
t, 000 '
r
•
cn%u 072 12 072a 030 75 1 ,. 001072 0 87512 09'0in2 09,08.12 0915,12 09+2212 09,29112 1005112
-� bteeS43 tj t ptSsope rear eS IODops;
04-e1 qpixvv-vd- w1 (&%1- r Preiswe-
ctAJ noi kee / (Ake& r " t4 loOops;
ti0+ sixe •NA6 '3 C AS c S co( 1 .. -'C9S
SC Ru ( Co 4 i' L)
JRefgr0Iwtlz
TREE= 4- 1/16" CIW
• SAF OTES: * * *CHROMETBG LNR ***
WELLHEAD = McEVOY 09-33 & WELL ANGLE> 70° @ 13089'
ACTUATOR= BAKER
KB. ELEV = 55' 4 [
BF. ELEV = m 1 2081' 1 -1/2" OTIS TRSV SSSV NIP, ID = 2.813" 1
K_OP = 3300'
Max Angle = 98° @ 10334"
Datum MD = 12726'
Datum ND = 8800' SS GAS LIFT MANDRELS
13 -3/8" CSG, 72 #, L -80, ID = 12.347" 1 2522' ST MD ND DEV TYPE VLV LATCH PORT DATE
1 3021 3020 5 MMG DOME RK 16 06/02/09
2 4745 4556 36 MMG DOME RK 16 06/02/09
3 5821 5410 37 MMG DOME RK 16 06/02/09
4 6380 5855 37 MMG SO RK 24 06/02/09
Minimum ID = 1.875" @ 9465' 5 6904 6273 38 MMG DMY RK 0 09/29/91
BTT Plug Holder Bushing 6 7397 6662 37 MMG DMY RK 0 09/30/95
7 8015 7156 36 MMG DMY RK 0 09/29/91
8 8693 7711 37 MMG DMY RK 0 05/31/92
9 9310 8207 33 MMG DMY RK 0 10/10/94
L 9397' — 13 -1/2" BKR LOC SEAL ASSY, ID = 4.75" I
fg
, 9398' _19 -5/8" X 3 -1/2" BKR MODEL D PKR, ID = 4.75" 1
OM 941 —17' BKR MILLOUT EXTENSION, ID = 6.00
” '�� 9423' —I 7" X 3-1/2" XO, ID = 2.992" 1
TOP OF 7" LNR H 947T i i i ► � i� 9455' — 12-3/8" BTT DEPLOYMENT SLV, ID = 2.250" 1
1 1 11 9456' —1 PLUG BUSHING, ID = 1.875" 1
1 1
�� I 9511' 1--1 -1 /2" OTIS XN NIP, ID = 2.75" 1
lit1 •
1 11
X 1 1 1 1 • •
3 -1/2" TBG, 9.3 #, 13CR -80, .0087 bpf, ID = 2.992" I 9526' ,1 /11 9526' 1-1 -1/2" BKR MULESHOE, ID = 2.992" 1
I I 111 / N 4 1 952T H ELMD TT LOGGED 10/09/91 1
111
11
9 -5/8" CSG, 47 #, L-80, ID = 8.681" 1 9781' ► 1 X11
1 1 1 11 11!11 9909' H CEMENT RAMP WINDOW 1
I 1 1 1 4
1111 11*:
I 11 � -4•.4 MILLOUT WINDOW 9910' - 9914'
PERFORATION SUMMARY I1A
1111..
REF LOG: SWS MCNL /GR/CCL OF 04/01/09 ►1l1111��t _ _
ANGLE AT TOP PERF:89 °@ 11650' 1111!1114 aligo
1 1111111
1111!11♦
Note: Refer to Production DB for historical perf data 1 1 1 1 1 1 1 1 1 1 1 1 1 4 _
S IZE SPF INTERVAL Opn /Sqz DATE 1 1 1 1 1 1 1 1 1 1l1 1 1�'
1.56 6 11650 - 12100 0 04/03/09 1111 ! 114
►11!1111 }!
1.56 6 12600 - 12625 O 04/03/09 I 1111111 ♦1�
1.56 6 12670 - 12685 0 04/03/09 / 111i i1 PBTD H 13125'
1.56 6 12770- 12815 O 04/03/09 ►1!!11!1
111 Nf '
1.56 6 12920 - 12960 0 04/03/09 ►1111
11 11 1 1 114 '' I2 -3/8" LNR, 4.7 #, 13CR STL, .0039 bpf, ID = 1.995" 1 13163'
1.56 6 13015 - 13090 0 04/03/09 *1111/11:
1 1111!11 4
►1!1111111 -
►111111
►11 ..k 1
! !•` 10184' —I FISH - CA -RD-RK (LOST 10 /10/94) 1
PBTD 1 10277' OA,e.101:
1 1 1 111111 �
► 1 1 1 1 1 1 1 1 1 !1
1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" N 10316'
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
07/05/85 ORIGINAL COMPLETION 11/14/09 JC /PJC TREE C/O (10 /26/09) WELL: 09 -33A
09/29/91 LAST WORKOVER PERMIT No: "208156
04/04/09 NORDIC 1 CTD SIDETRACK (09 -33A) API No: 50 -029- 21365 -01 -00
06/01/09 JLJ/TLH GLV C/O (04/27/09) SEC 2 T10N, R15E, 1705' FSL & 1023' FEL
06/13/09 KDC/TLH GLV C/O (06/02/09)
09/17/09 SM/JMD DRLG DRAFT CORRECTIONS . BP Exploration (Alaska)
• •
bp
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB -20 ,.
Post Office Box 196612
Anchorage, Alaska 99519 -6612
December 30, 2011
66 : n
Mr. Tom Maunder
a r I
Alaska Oil and Gas Conservation Commission q - 3�
333 West 7 Avenue `
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of DS -09
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09
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, Gerald
Murphy, at 659 -5102.
Sincerely,
Mehreen Vazir
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-09
10/20/11
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # cement pumped cement date inhibitor sealant date
ft bbls ft gal
09 -01 1750760 50029201880000 Sealed conductor NA NA NA NA NA
09 -02 1760160 50029201980000 Sealed conductor NA NA NA NA NA
09 -03 1760350 50029202090000 Sealed conductor NA NA NA NA NA
09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA
09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA
09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA
09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA
09 -08 1760700 50029202300000 Sealed conductor NA NA NA NA NA
09 -09 1760760 50029202320000 Sealed conductor NA NA NA NA NA
09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA
09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010
09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA
09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA
09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA
09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA
09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA
09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA
09 -18 1770390 50029202590000 Tanko conductor NA NA NA NA NA
09 -19 1770400 50029202600000 Sealed conductor_ NA NA NA NA NA
09-20 1770410 50029202610000 Sealed conductor NA NA NA NA NA
09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010
09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010
09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010
09 -24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011
09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010
09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010
09 -27 1850280 50029212910000 Dust Cover NA NA NA 6.8 1020/2011
09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA
09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011
09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 1020/2011
09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010
09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA
-3. 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/182010
09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA
09 -35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010
09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10202011
09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10202011
09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011
09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010
09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010
09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA
09-42A 1990070 500292205901 SC Leak
09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011
09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010
09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011
09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010
09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010
09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/182010
09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011
09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011
09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011
DATA SUBMITTAL COMPLIANCE REPORT
2/25/2010
Permit to Drill 2081560 Well Name/No. PRUDHOE BAY UNIT 09-33A Operator BP EXPLORATION (ALASKA INC API No. 50-029-21365-01-00
MD 13163 TVD 8971 Completion Date 4/2/2009 Completion Status 1-OIL Current Status 1-OIL UIC N
REQUIRED INFORMATION
Mud Log No Samples No Directional Survey es
DATAINFORMATDN
Types Electric or Other Logs Run: MWD DIR / GR / RES, GR /CCL /CNL (data taken from Logs Portion of Master Well Data Maint
Well Log Information:
Log/ Electr
Data Digital Dataset Log Log Run Interval OH /
ry mearrrmt rvumoer ame acme rvieaia rvo start atop ~.n rcecervea ~.ommenrs
ED~ C Lis 17969 eutron 9309 13115 Case 5/4/2009 LIS Veri, GR, CNT
~Cog Neutron 5 Blu 9303 13112 Case 5/4/2009 MCNL, Lee, GR, CCL,
~ CNL 1-Apr-2009
D D Asc Directional Survey 35 13163 Open 5/18/2009 i
pt
~ Directional Survey 9900 13163 Open 5/18/2009
pt LIS Verification 9789 13158 7/6/2009 LIS Veri, GR, ROP, RAD,
RAS, RPD, RPS
D C Lis //
18224~Induction/Resistivity 9789 13158 Open 7/6/2009 LIS Veri, GR, ROP, RAD,
RAS, RPD, RPS
og Induction/Resistivity 25 Col 9909 13159 Open 7/6/2009 MD MRP, GR
Log Induction/Resistivity 25 Col 9909 13159 Open 7/6/2009 TVD MRP, GR ',
Log Gamma Ray 25 Col 9909 13159 Open 7/6/2009 MD GR
og See Notes 2 Col 9780 13158 Open 7/6/2009 Depth Shift Monitor Plot
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
•
DATA SUBMITTAL COMPLIANCE REPORT
2/25/2010
Permit to Drill 2081560 Well Name/No. PRUDHOE BAY UNIT 09-33A
MD 13163 TVD 8971
ADDITIONAL INFORMATION
Well Cored? Y /~
Chips Received? ~-/-Ids
Analysis .Y~.Ah
Received?
Completion Date 4/2/2009
Comments:
API No. 50-029-21365-01-00
UIC N
Compliance Reviewed By: _ Date: ,
~~z~~~~
n
~J
Operator BP EXPLORATION (ALASFC~ INC
Completion Status 1-OIL ~C'u,1rrent Status 1-OIL
Daily History Received? ~'"
Formation Tops ~ N
T~: Mate ~~ Alaska -A,~~~~~~
333 Wo 7t" Agee
Suite 100
Anch®rage9 Alaska 99501
Attention: Christine 1~ahnken
Reference: 09-33A
Contains the following:
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
!E 1 color print - GR Directional Measured Depth Log (to follow)
1 color print - MPR/Directional TVD Log (to follow)
`° 1 color print - MPR/Directional Measured Depth Log (to follow)
9
C
~b
LAC Job#: 2493101
Sent by: Catrina G idry Date: 06f25f09 ; '
Received by: Date:
PLEASE ACI~N®VVLEDGE RECEIPT BY SIGNING ~ RETURNING
®R FAXING Y®UR C®PY
EA~m X307) ~5', -523
faker Hughes i1~1'rEQ
~` ~ 7260 Homer Drive
Anchorage, Alaska 99518
Direct: (907) 267-6612
Ol~d'i'~~ FAX: (907) 267-6623
~ ~c~ `~'
COMPANY
WELL NAME
FIELD
~ '>'~t
BAKER
!#VGtiESi
~alc~~- Alas
~R~~T ~~STRIB~~I® ~IS~
BP EXYLUKA1lUN (ALASKA) 1NC CUUNIY NUK1H SLOPE BUKUUCiH
09-33A STATE ALASKA
PRUDHOE BAY UNIT DATE 6/25/2009
THIS DISTRIBUTION L[ST AUTHORIZED BY CATRINA GUIDRY
SO #: 2493101
Copies of Copies Digital Copies of Copies Digital
Each Log of Film Data Each Log oC Eilm Data
2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS
Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS
Address LR2-l Address 550 WEST 7TH AVE
900 E BENSON BLVD. SUITE 800
ANCHORAGE AK 99508 ANCHORAGE AK 99501
I Company EXXON MOBIL PRODUCTION CO Company
Person F[LE ROOM Person
Address 800 BELL STREET Address
EMB GSC 3082A
HOUSTON, TX 77002
I Company STATE OF ALASKA - AOGCC Company
Person CHRISTINE MAHNKEN Person
Address 333 W. 7TH AVE Address
SUITE 100
ANCHORAGE, AK 99501
Company Company
Person Person
Address Address
Company Company
Person Person
Address Address
Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield Houston Texas 77073
This Distribution List Completed By
~~ ~ ~- / ~~
Page I of t
- ~ STATE OF ALASKA • f~-~~~~ iP ll.~ ~d~~
ALASKA OIL AND GAS CONSERVATION COMMISSION 3-~ ~
WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~ ~ '~ ~~~~
1 a. Well Status: ®Oit ^ Gas ^ Plugged ^ Abandoned ^ Suspended
zoAACZS.~os zoAACZS.~~o el las
•® D
lo~f~'~ E
l
t
eve
xp
ora
ory
^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic
2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number
BP Exploration (Alaska) Inc. 4/ 2009 208-156
3. Address: 6. Date Spudded 13. API Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 3/19/2009 50-029-21365-01-00
4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number:
Surface:
1704' FSL
1023' FEL
SEC
0 3/27/2009 PBU 09-33A
,
,
.
2, T10N, R15E, UM
Top of Productive Horizon: 8. KB (ft above MSL): 55' 15. Field /Pool(s):
161' FSL, 439' FEL, SEC. 35, T11 N, R15E, UM Ground (ft MSL): 20.5' Prudhoe Bay Field / Prudhoe Bay
Total Depth: 9. Plug Back Depth (MD+TVD) Oil Pool
250' FSL, 2278' FWL, SEC. 36, T11N, R15E, UM 13125' 8956'
4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation:
Surface: x- 717348 y- 5943143 Zone- ASP4 13163' 8971' ADL 028327 & 028324
TPI: x- 717821 y_ 5946894 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit:
Total Depth: x- 720534 y- 5947063 Zone- ASP4 None
18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD):
S mi electronic an rin ed inf rm lion r 20 AA 2 . N/A ft MSL 1900' (Approx.)
21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071):
MWD DIR / GR / RES, GR / CCL / CNL !~/~yQoy~~ ~90~'MG ~~a?-!~S ~Tyl~
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
20" 91.5# H-40 Surface 113' rface 113' 3 " 2000 # Pol t
7# 6 K- rf rf Ids I I x 1
9- / " 47# L-80 Surfa 781' urf 14' 12-1/4" 00 sx Cla s'G' 300 sx S I
7" 29# L-80 72' 727' -1/2" 50 sx Cla s'G'
- 4. # 13 r 1 1 x I /
23. Open to production or inject ion? ®Yes ^ No 24. TUBING RI=_coRD
If Yes, list each interval open
(MD+TVD of Top 8~ Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD
1.56" Gun Diameter, 6 spf 3-1/2", 9.3#, 13Cr80 9525' 9398'
MD TVD MD TVD
11650' - 1210U' 8736' - 8748' r 25. ACID, FRACTURE
CEMENT SQUEEZE
ETC
12600' - 12625' 8815' - 8823' ,
,
.
12670' - 12685' 8837' - 8842' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED
12770' - 12815' 8867' - 8877' 2500' Freeze Protected with Diesel
12920' - 12960' 8899' - 8909'
13015' - 13090' 8922' - 8943'
26. PRODUCTION TEST
Date First Production: Method of Operation (Flowing, Gas Lift, etc.):
May 1, 2009 Flowing
Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO:
5/2/2009 16 TEST PERIOD 425 296 2,837 84 697
Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK):
Press. 266 1,600 24-HouR RATE• 637 444 4,256 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.
/!slF710P1
+
~ ~s~
None ~ .~ ~ ~~Y k~ 2~~4 ~ -d•~~9
_. ~ ~~;Y ~`~ ~ 2QD9 ;
Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE,, ~ 17 ,,,/~ pct ~~~~~,
~~
28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS
NAME TVD Well Teste ^ 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.
27P 9963' 8766' None
26P 12477' 8784'
25N 12550' 8800'
24N / 23S6 12589' 8812'
23P / 22TS 12776' 8868'
22N 12870' 8887'
22P / 21TS 12934' 8903'
21 N 13012' 8921'
21 P 13072' 8937'
Zone 1 13140' 8962'
Formation at Total Depth (Name):
Zone 1 13140' 8962'
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the fore ing is true and correct to the best of my knowledge.
~
/~~ /~
Signed Terrie Hubble ~ Title Drilling Technologist Date
PBU 09-33A 208-156 Prepared ey Name/Number. Terrie Hubble, 564-4628
Welt Number Permit No. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387
INSTRUCTIONS
GeNeRA~: 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.
IreM 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).
IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28.
IreM 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).
IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain).
IreM 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
s
BP EXPLORATION
Operations Summary Report
Page 1 of 20 ~
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date From - To 'Hours ' Task Code NPT Phase Description of Operations
3/11/2009 09:00 - 00:00 15.00 RIGU N WAIT PRE Perform rig maintenance and wait on wind. Rig is still at
3/12/2009 100:00 - 00:00 24.001 RIGU N WAIT PRE
3/13/2009 00:00 - 13:00 13.00 RIGU N WAIT PRE
13:00 - 13:15 0.25 MOB P PRE
13:15 - 13:30 0.25 MOB P PRE
13:30 - 13:45 0.25 MOB P PRE
13:45 - 16:45 3.00 MOB P PRE
16:45 - 17:00 0.25 MOB P PRE
17:00 - 18:00 1.00 MOB P PRE
18:00 - 18:30 0.50 MOB P PRE
18:30 - 00:00 5.50 MOB P PRE
3/14/2009 00:00 - 03:00 3.00 MOB P PRE
03:00 - 03:15 0.25 MOB P PRE
03:15 - 07:00 3.75 MOB P PRE
07:00 - 07:15 0.25 MOB P PRE
07:15 - 10:00 2.75 MOB P PRE
10:00 - 10:15 0.25 MOB P PRE
10:15 - 11:00 0.75 MOB P PRE
11:00 - 14:30 3.501 BOPSUFj P PRE
DS-05. Perform rig maintenance and housekeeping while
waiting.
Rig was released from well 05-27B at 0900.
19:30 18-29 MPH wind speed.
21:00 20-26 MPH
00:00 20-26 MPH
Continue waiting on wind gust to decrease below 20 MPH.
Perform rig maintenance and housekeeping while waiting.
Rig is still on DS-05.
03:00 20-30 MPH
00:00 22-37 MPH
Continue waiting on DS-05 for wind to slack off < 20 MPH to
lower derrick.
SAFETY MEETING. Review procedure, hazards and
mitigation for moving rig off of well.
Move rig forward off of well and set down again.
SAFETY MEETING. Review procedure, hazards and
mitigation for laying down wind walls.
Wind at 12-18 mph, -19F, -42 WC.
Lay down wind walls. Scope down derrick.
SAFETY MEETING. Review procedure, hazards and
mitigation for raising pipeshed roof and lowering derrick. Wind
at 11-15 mph, -18F, -39 WC.
Raise pipeshed roof. Keep all cables clear.
Lower Derrick using hydraulic rams.
Close pipeshed roof.
SAFETY MEETING. PJSM with Security and CPS for moving
rig off location and under power lines.
Final walk arounds and prep rig for travel.
Jack up rig and move off location.
Move rig off DS-5 to West Dock Road, past East gaurd shack,
past Veco yard onto ice road, across Sag River to DS-09.
Move rig to DS 09-33A
SAFETY MEETING. Review procedure, hazards and
mitigation for opening pipeshed roof and raising derrick.
Raise pipeshed roof. Raise derrick. Close pipeshed roof.
Scope up derrick.
SAFETY MEETING. Review procedure, hazards and
mitigation for raising wind walls.
Raise wind walls. Close derrick jacks and secure them.
SAFETY MEETING. Review procedure, hazards and
mitigation for backing over well.
Position rig in front of well and back over well.
Rig centered over well.
ACCEPT RIG AT 1100 HRS, 03/14/09.
Nlpple UD BC)PF
Printed: 4/13/2009 2:52:22 PM
BP EXPLORATION Page 2 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date ,From - To Hours Task Code I NPT ' Phase Description of Operations
__ _ _ _ - __
3/14/2009 11:00 - 14:30 3.50 BOPSU P PRE M/U hardline to tiger tank. Position cuttings tank.
14:30 - 22:30 8.00 BOPSU P PRE Pressure to t BOP e t witn
Test Annular, Blind /Shears, 2" Combi, 2-3/8" Combi, and
lower 2" Combi Pipe /Slip rams. Also test tree valves and
choke manifold valves.
Pressure test both stabbing valves.
22:30 - 23:00 0.50 RIGU P PRE Perform High level H2S alarm exercise with rig evacuation drill.
Good response from crews, some lessons learned.
23:00 - 23:20 0.33 RIGU P PRE SAFETY MEETING. PJSM for putting pipe straightener and
gooseneck on injector. Hand and finger injuries were
discussed.
23:20 - 00:00 0.67 RIGU P PRE Pick up and install pipe straightener on injector.
3/15/2009 00:00 - 02:00 2.00 RIGU P PRE Lift injector out of stabbing box.
Secure hose bundle in derrick.
02:00 - 03:00 1.00 RIGU P PRE Hook up to gooseneck, lift it into position.
Attach gooseneck support arms.
03:00 - 03:45 0.75 RIGU P PRE Set up to pull CT across pipe shed into injector.
Install beams in pipe shed.
03:45 - 04:00 0.25 RIGU P PRE SAFETY MEETING. PJSM for pulling CT across pipe shed
roof into injector.
04:00 - 05:30 1.50 RIGU P PRE Pull out CT into injector.
Cut off internal grapple, prep end of CT for connector.
05:30 - 08:30 3.00 RIGU P PRE Weld on CT connector. Pull test to 35K, good.
Fill coil with Biozan.
PT inner reel valve, good.
08:30 - 08:45 0.25 CLEAN P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for M/U LH milling BHA.
08:45 - 09:30 0.75 CLEAN P WEXIT M/U Baker 2.80" milling BHA #1 with 2.80" HCC D331 diamond
mill, motor, MHA, 1 jt and CTC.
All tools left hand thread. BHA OAL = 47.77'.
09:30 - 11:35 2.08 CLEAN P WEXIT RIH with 2.80" LH milling BHA #1. Circ at 0.30 bpm, 730 psi.
RIH clean to 9475'. Up wt = 34K.
RIH and tagged XN nipple at 9514.9'. Correct depth to 9507'.
11:35 - 13:00 1.42 CLEAN P WEXIT Mill out XN nipple to 2.80". 1.6 bpm, 2850 psi. Milled easy
with very light WOB and 50 psi motor work. 3 stalls to get
started. RIH 5' and backreamed XN. Ream down thru XN
clean.
13:00 - 13:10 0.17 CLEAN P WEXIT RIH clean thru tailpipe. RIH found cement at 9576'.
13:10 - 15:00 1.83 CLEAN P WEXIT POH with left hand milling BHA. Circ at 1.0 bpm, 1900 psi.
15:00 - 15:15 0.25 CLEAN P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for L/O BHA and pump slack.
15:15 - 15:45 0.50 CLEAN P WEXIT L/O milling BHA. Mill gauged at 2.80" No-Go.
Send all left hand milling tools back to Baker for storage.
15:45 - 16:30 0.75 STWHIP P WEXIT Reverse circ at 3.3 bpm, 3800-4000 psi. E-line moved for 1.5
min. Stop pump.
We pumped for 3 min. at 4200 psi, last time and cut 302' of
coil.
Cut off 375' of coil to expose E-Line. We pumped 1/2 as long
with less pressure and cut more coil.
16:30 - 19:00 2.50 STWHIP P WEXIT M/U Kendal connecter. Pull test 35K, good.
19:00 - 19:45 0.75 STWHIP P WEXIT Install nozzle, RIH to thaw out CT.
19:45 - 20:20 0.58 STWHIP P WEXIT Set Farr tongs down into stabbing box to eliminate a trip hazard
Printed: 4/13/2009 2:52:22 PM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33
Event Name: REENTER+COMPLETE Start: 2/24/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Page 3 of 20 ~
Spud Date: 6/11/1985
End: 4/4/2009
Date From - To I Hours Task Code NPT Phase Description of Operations ~
3/15/2009 19:45 - 20:20 0.58 STWHIP P
20:20 - 21:00 0.67 STWHIP P
21:00 - 22:00 1.00 STWHIP P
22:00 - 00:00 2.00 STWHIP P
3/16/2009 00:00 - 01:30 1.50 STWHIP P
01:30 - 02:30 1.00 STWHIP P
02:30 - 03:30 1.00 STWHIP P
03:30 - 04:00 0.50 STWHIP P
04:00 - 06:00 2.00 STWHIP P
06:00 - 07:30 1.50 STWHIP P
07:30 - 09:30 2.00 STWHIP P
09:30 - 11:00 1.50 STWHIP P
11:00 - 12:30 1.50 STWHIP P
12:30 - 13:20 0.83 STWHIP P
13:20 - 14:15 0.92 STWHIP P
14:15 - 15:00 0.75 STWHIP P
15:00-16:30 ~ 1.50~STWHIP~N ~DFAL WEXIT
on rig floor.
Check accumulators on injector.
PT connector to 4,000 psi, good.
M/U nozzle and get back on well, pump slack forward.
PJSM for P/U BHA while pumping slack forward.
M/U BHA #2 - 2.80" Diamond Speed Mill, 1.75 deg AKO motor,
2-3/8" CoilTrack.
BHA OAL = 58.24 ft.
Test BHA at surface.
RIH BHA #2.
Log GR down from 9450 ft.
Continue logging GR down for tie-in.
No matching GR features seen after 100 ft.
Pick up to 9190 ft and log GR down from here.
Correct -7.5 ft.
RIH, tag cement top at 9,587 ft.
Stall at 9,590 ft.
Drill cement at 180E TF at 20-30 fUhr, with 0.3-0.6 Klbs DWOB.
Gradually push ROP to 50-60 ft/hr with around 2.5 Klbs
DWOB, try to gauge cement hardness.
Past 9600 ft drill at 80-90 fUhr, 1.9 Klbs DWOB with 250-300
psi motor work. Motor stalls out right away at this ROP.
Drill 1.63 / 1.62 bpm Q 200-300 psi motor work.
ROP is 50-60 ft/hr with 1.5-3 Klbs DWOB.
Stall at 9644 ft.
Past 9650 ft drill at 100 fUhr.
Drill to 9,660 ft, cement is soft at this depth, around 100 fUhr
ROP with 1-2 Klbs DWOB.
Wiper trip back to tubing tail, pump 1 bottoms up.
Drill cement from 9660 ft.
ROP is 20-30 ft/hr with 1.2 Klbs DWOB, 200 - 300 psi motor
work.
Drill cement, 1.6 bpm, 3500 psi, 30 fph, 1-2.5K wob.
Drilled to 9780'.
Drill cement, 1.6 bpm, 3500 psi, 30 fph, 1-2.5K wob.
Soft to firm cement. ROP 20-110 fph. soft spot at 9810'.
Drilled to 9825'.
Drill cement, 1.6 bpm, 3420 psi, 1 K wob, 40 fph. Drill to 9860'
Drill hard cement starting 9860'. 10-15 fph, 1.5k WOB
drilled to 9875'.
Drill hard cement to 9877'. ROP went from 15 fph to 50 fph.
Drilling 40-50 fph, 1.6 bpm, 3200-3500 psi, 1.5K wob,
Drilled to 9894'.
Wiper trip to top of cement.
Ream up and down, high side 9550-9600' to open up entry of
pilot hole.
RIH to bottom again.
Drill firm cement, 45-40 fph, 1.5K WOB, 1.6 bpm, 3350-3600
psi,
Stalled motor at 9897'. Circ press increased, not able to clear
mill.
POH for plugged mill. Open EDC and Circ 1.6 bpm, 2700 psi
while POH.
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
Printetl: 4/13/2009 '2:52:'L'L F'M
BP EXPLORATION Page 4 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
3/16/2009 16:30 - 16:45 0.25 STWHIP N DFAL WEXIT SAFETY MEETING. Review procedure, hazards and
16:45-17:45 1.OO~STWHIP~N DFAL WEXIT
17:45-19:45 ~ 2.OO~STWHIP~N DFAL WEXIT
19:45 - 20:05 ~ 0.331 STWHIP N ~ DFAL ~ WEXIT
20:05 - 21:25 1.331 STWHIP( N DFAL WEXIT
21:25-22:15 0.83STWHIPP (WEXIT
22:15 - 23:00 I 0.751 STWHIP( P I I WEXIT
23:00 - 00:00 I 1.001 STWHIP( P I I WEXIT
3/17/2009 00:00 - 00:45 0.75 STWHIP P WEXIT
00:45 - 01:00 0.25 STWHIP P WEXIT
01:00 - 02:00 1.001 STWHIP(P WEXIT
02:00 - 04:20 ~ 2.33 STWHIP P ~ ~ WEXIT
04:20-05:15 0.92~STWHIP~P ~ WEXIT
05:15 - 05:30 I 0.251 STWHIP( P I I WEXIT
05:30 - 09:30 I 4.001 STWHIP( P I I WEXIT
mitigation for changing BHA.
Lay out CoilTrak BHA. Mill was not plugged.
Change out motor, re-run mill, still in gauge.
M/U CoilTrak. BHA #3 OAL = 58.24'.
RIH with cement milling BHA #3.
Test circ OK at surface, 1.6 bpm, 3300 psi. Motor was
plugged.
RIH while circ at 0.2 bpm, 950 psi.
Log GR down from 9190 ft.
No correction.
RIH, bring pump up at 9750 ft, pressure is >4000 psi at 1.5
bpm. Circ bottoms up to clear hole.
RIH, tag bottom at 9,900 ft (Last run TD was 9,897.8 ft.)
Ease back down and start drilling cement.
Drill from 9900 ft at 1.40 / 1.35 bpm C~3 3560 psi FS.
Try to drill at 30 fUhr with about 2 Klbs DWOB results in a stall.
Drill from 9900 ft at 10-20 ft/hr. DWOB = 0.86K, Dp is 200 -
300 psi. Stall at 9901 ft.
Increase rate to 1.6 bpm / 4,080 psi FS.
Drill at 15 ft/hr with 0.6-0.9 Klbs DWOB with 200 psi motor
work.
Turn TF highside and start ramp from 9,903 ft.
Drill ramp at 1.49 / 1.42 bpm C~ 3900-4300 psi. ROP is 60 ft/hr
with 2-3 Klbs DWOB. Stall at 9908 ft.
Stall at 9909.3 ft 2 times, likely casing contact.
Clean TOC 9550-9600 ft at HS and LS orientation.
ROP across the ramp was faster than what is considered ideal,
however both Town and Rig team consider starting the window
on the current ramp is the best way forward.
Continue POOH.
SAFETY MEETING. Discuss hazards and mitigations for
change out BHA.
Lay down BHA #3. Parabolic diamond speed mill is worn on
the side, comes out 2.76" no-go, 2.77" go.
Pick up BHA #4 - 2.80" Diamond speed mill, 2-3/8" WFT motor
with 2.5 deg fixed AKO, 2-3/8" CoilTrak.
Test tool at surface.
RIH with no pump, keep HS toolface.
Set down in SSSV nipple, have to spin through it at min rate.
Continue RIH.
Log GR down from 9190 ft.
Correct -2 ft.
Continue RIH HS toolface with no pump.
Dry tag at 9908.8 ft.
Pick up 10 ft and start pump, 1.43 bpm C~ 3900 psi FS.
Pumping tag is at 9909.5 ft.
Pick up 1 ft to take out stack in coil.
Circ well to new Biozan to reduce press and get better slide.
Start time drilling sequence at 9908.5 ft
05:30 9908.5 ft
Printed: 4/13/2009 2:52:22 PM
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
Date
3/17/2009
Page 5 of 20 ~
09-33
09-33 Spud Date: 6/11 /1985
REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
NORDIC CALISTA Rig Release: 4/4/2009
NORDIC 1 Rig Number:
From - To ~I Hours , Task
05:30 - 09:30
09:30 - 12:00
4.001 STWH
2.50
Code !~ NPT Phase Description of Operations
P WEXIT 06:00 9908.6 ft
P
12:00 - 18:00 6.00 STWHIP P
18:00 - 18:30 0.50 STWHIP P
18:30 - 19:30 1.00 STWHIP P
19:30 - 22:30 3.00 STWHIP P
22:30 - 23:05 I 0.581 STWHIPI P
06:24 9908.7'
06:44 9908.8'
07:02 9908.9' 0# wob
07:19 9909.0' 100# wob
07:35 9909.1 300# wob, mill is taking wt, good sign
07:50 9909.2 400# wob
08:04 9909.3 600# wob
08:17 9909.4 600# wob
08:29 9909.5 600# wob
08:51 9909.6 700# wob
09:09 9909.7' 800# wob. milling liner.
09:24 9909.8' 900# wob
WEXIT Mill 2.80" highside window off of cement ramp thru 29#, L-80
liner.
1.4 bpm, 3420 psi.
Follow time milling schedule
09:37 9909.9' 1200# wob, milling on liner, WOB mills off
09:49 9910.0' 1300# wob, looking good.
10:00 9910.1' 1500# wob
10:10 9910.2 1600# wob
10:29 9910.4' 1700# wob
10:46 9910.6' 1900# wob
11:01 9910.8' 2100# wob metal on shaker.
11:30 9911.2 2500# wob.
WOB at 2700#, mill rest of window at 2.5-3K WOB.
Depart from milling schedule to limit WOB.
11:45 9911.4' 2700# WOB.
WEXIT Mill 2.80" highside window off of cement ramp thru 29#, L-80
liner.
1.4 bpm, 3430 psi.
WEXIT 18:00 9914.11 ft 2.78 Klbs DWOB
18:25 9914.22 ft 2.42 Klbs DWOB
WEXIT DWOB is falling off < 3 Klbs. Release brake and drill 5 ft/hr.
Likely BOW depth is 9914.3 ft.
Sample at 9914.2 ft is 40% sand.
19:00 9915.3 ft 3.74 Klbs DWOB stacking wt now
WEXIT Stall at 9916.8 ft with 5.3 Klbs DWOB.
Pick up, new FS is 3570 psi at 1.53 / 1.44 bpm.
Ease back down, start taking wt ar 9914.5 ft. Set brake at
9915.3 ft with 300 psi motor work at 3 Klbs DWOB.
20:00 9915.4 ft 1.80 Klbs DWOB 300 - 400 psi motor work
20:30 9916.3 ft 3.26 Klbs DWOB 200 - 300 psi motor work
Sample from around 9915 ft is 60% sand.
21:30 9917.2 ft 3.38 Klbs DWOB 200 - 300 psi motor work.
22:00 9917.3 ft 3.45 Klbs DWOB 200 - 300 psi motor work.
WEXIT 22:30 9917.5 ft 3.75 Klbs DWOB 180 psi motor work.
Stacking wt without much progress. Pick up and ease back
down.
Start taking wt around 9916.5 ft, with BOW 9914.3 ft, about 2.2 '
ft of rathole.
23:00 9917.4 ft 3.39 Klbs DWOB 150 psi motor work.
F'rlfltBtl: 4/13/GUUB "L:~2:2Z F'M
BP EXPLORATION
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33
Event Name: REENTER+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 1
Date '~ From - To Hours Task Code' NPT
3/17/2009 22:30 - 23:05 0.58 STWHIP P
23:05 - 00:00 0.92 STWHIP P
3/18/2009 00:00 - 00:55 0.92 STWHIP P
00:55 - 01:10 0.25 STWHIP P
Start: 2/24/2009
Rig Release: 4/4/2009
Rig Number:
Page 6 of 20 ~
Spud Date: 6/11/1985
End: 4/4/2009
Phase Description of Operations
WEXIT
WEXIT
WEXIT
WEXIT
01:10 - 01:40 0.50 STWHIP P WEXIT
01:40 - 03:40 2.00 STWHIP N WAIT WEXIT
03:40-04:00 ~ 0.33~STWHIP~P ~ WEXIT
04:00 - 06:15 ~ 2.25 ~ STWHIPI P ~ ~ WEXIT
06:15 - 06:45 0.50 STWHIP P WEXIT
06:45 - 07:15 0.50 STWHIP P WEXIT
07:15 - 09:00 1.75 STWHIP P WEXIT
09:00 - 11:00 2.00 STWHIP P WEXIT
11:00 - 13:00 2.00 STWHIP P WEXIT
13:00 - 15:15 2.25 STWHIP P WEXIT
15:15 - 17:15 2.00 STWHIP P WEXIT
17:15 - 17:40 0.42 STWHIP P WEXIT
17:40 - 18:20 0.67 STWHIP P WEXIT
18:20 - 19:00 0.671 STWHIPI P WEXIT
19:00-20:45 I 1.751STWHIPIP I (WEXIT
20:45 - 21:00 0.251 STWHIPI P WEXIT
21:00 - 21:50 0.83 STWHIP P WEXIT
21:50 - 23:00 1.17 STWHIP N WAIT WEXIT
Milling parameters not changing, little to no progress. POOH to
change mill and motor.
Open EDC when inside tubing tail.
POOH.
Continue POOH.
SAFETY MEETING. PJSM for change out BHA. Crew
positions and hand injuries were discussed.
Tag stripper, L/D BHA #4. Mill was 2.79 no-go, showed normal
wear pattern with worn center buttons.
WFT motor arrives, Bent housing angle measures 2.9 deg
instead of desired 2.5 deg. Send it back to Deadhorse for new
housing. BHI DD also goes to WFT shop to verify motor angle.
SLB repair cotter pins on injector chains while waiting.
Motor arrives, lift it to floor.
M/U BHA #5 - 2.80 one-step mill, 2-3/8" WFT motor with 2.5
deg bent housing, 2-3/8" CoilTrack.
Test BHA at surface.
RIH BHA #5. Set down in SSSV again, spin through at min
rate.
Tie -in at 9190' correction -3'.
RIH.
Drill rat hole 1.45/1.28 bpm ~ 3700 psi FS 3600 psi. WOB 3K,
ECD 10.38. to 9921'.
Back ream C~ high side orientation to 9900'.
POH
BHA. LD one step mill and motor and PU diamond crayola.
2.79 crayola pin would not shoulder-up. Discussed option with
engineering. decided to use 2.73 diamond crayola.
RIH
Log tie-in. Correction - 2'
Tag window at 9915 ft at HS orientation, several attempts, can't
pass.
Crew change and discuss options.
Try to pass at 20R with no pump and 20L with no pump, can't
pass. Stacking at 9913 ft.
RIH to 9912 ft and roll pump at 0.2 bpm with HS orientation,
can't pass.
RIH to tag, pick up 1.3 ft go to 1.4 bpm / 4000 psi FS.
Tag at 9912 ft with HS orientation, no motor work.
Ease down to 9913.5 ft, no motor work gradually stacking wt.
Stack about 2K and try to work past, can't pass.
Try again 10 ft/min 1.46 bpm can't pass, tag with motor work.
Set down and stall again twice, with very light WOB.
POOH for new assembly. Discuss with Drlg Engineer, decide
to run a 1-step mill with 1.75 deg motor to clean out a
suspected lip at the bottom of the window.
SAFETY MEETING. Discuss hazards and mitigations for
change out BHA.
Tag stripper and L/D BHA #6. crayola mill had traces of soft
cement on it, confirmed by Geo.
Wait on new 1-step mill from Deadhorse, previously run mills
are worn.
Printed: 4/13/2009 2:52:22 PM
BP EXPLORATION Page 7 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
i
Date From - To li Hours Task Code NPT Phase Description of Operations
3/18/2009 21:50 - 23:00 1.17 STWHIP N WAIT WEXIT SLB conduct PJSM then replace 4 tie-rods on injector.
23:00 - 00:00 1.00 STWHIP N SFAL WEXIT SLB continue to replace tie-rods. Injector chain was scraping
3/19/2009 100:00 - 00:30 I 0.501 STWHIPI P I I WEXIT
00:30 - 01:00 0.50 STWHIP P WEXIT
01:00 - 02:30 1.50 STWHIP P WEXIT
02:30 - 03:25 0.92 STWHIP N SFAL WEXIT
03:25 - 06:00 2.58 STWHIP P WEXIT
06:00 - 06:20 0.331 STWHIP P
06:20 - 07:35 I 1.251 STWHIPI P
07:35 - 09:45 2.17 STWHIP P
09:45 - 10:00 0.25 STWHIP P
10:00 - 11:20 1.33 STWHIP P
11:20 - 13:30 2.17 DRILL P
13:30 - 14:45 1.25 DRILL P
14:45 - 18:00 3.25 DRILL P
18:00 - 23:15 I 5.251 DRILL I P
23:15 - 00:00 0.75 DRILL P
3/20/2009 00:00 - 01:00 1.00 DRILL P
01:00 - 01:15 0.25 DRILL P
01:15 - 03:00 1.75 DRILL P
03:00 - 05:45 2.751 DRILL P
05:45 - 06:10 I 0.421 DRILL I P
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
against the tie-rods on the drillers side resulting in substantial
wear on them.
Cut 50 ft of CT off for chrome management. Wadded and
kinked cable found about 30 ft behind the connector.
Install CT connector and pull test to 35K, good.
Install BHI cable head. Electric test and PT to 3,500 psi is
good.
M/I I RHA #7 - 7 Rn 1-ctan mill with 1 J5 rtea AKO motor
SLB change out 21 cotter pins on injector chains, drillers side.
RIH.
Tie-in depth from 9190 ft.
Correct -2 ft.
Continue RIH.
Tag bottom of window at 9913 ft.
Pick up 7 ft and turn on pump, run back to 9912.1 ft and start
time milling 0.6 ft/hr. 1.6 bpm (~3 3000 psi. 50 psi MW pop thru.
RIH to 9921.
Back ream 1.6 bpm C~ 2909 psi. to 9909 (pipe strech 3'.) PU
to 9900. RIH to 9920 no problem. tag and drill to 9922.
POH
PJSM to LD window dressing BHA and PU build assembly.
LD window mill 2.80 No Go. Cement in water coarses of mill.
PU 2.8 motor building assy.
RIH.to 9820.
Log tie-in -5' correction
Tag TD 9922. Drill 1.55 / 1.27 bpm ~ 3070 psi. FS 2900 psi.
ECD 9.89 ppg, WOB .6K,
Drill down through Z3 with slow ROP. Continue building angle
for landing around 8740 ft TVD on this run.
1.6 / 1.5 bpm @ 2800-3000 psi. ROP is 15-30 ft/hr with 1-2K
DWOB. Stalls if pushed harder.
Drill to 10,035 ft, land build section at 78 deg inc, 8739 ft TVD
at the bit. Plan to make up the rest of the build with the next
assembly.
POOH. Shut off pump, allow motor Dp to bleed down before
pulling across ramp.
Continue POOH.
SAFETY MEETING. Discuss hazards and mitigations for
change out BHA.
Open CT riser and look at last 100 ft of pipe, tag stripper.
UD BHA #8. Bit is 1-3. Turn motor to 1.1 deg.
M/U BHA #9 - 2.73" SRX HYC bit + 1.1 deg AKO Xtreme +
2-3/8" CoilTrak with Res.
Test tool at surface.
RIH.
Log GR down from 9190 ft, correct -1.5 ft.
Continue RIH.
Pass through window clean.
RIH to bottom, tag at 10039 ft.
MAD pass up from TD at 300 ft/hr to just below window.
Printed: 4/13/2009 2:52:22 PM
~ r
BP EXPLORATION Page 8 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
i
Date From - To Hours Task Code NPT Phase ~I Description of Operations
3/20/2009 06:10 - 06:30 0.33 DRILL P PROD1 RIH
06:30 - 12:15 5.75 DRILL P PROD1 Directionally drill 1.69 / 1.58 bpm 3350 psi, FS = 3100 psi.
WOB 1.67K,ECD 9.89, Qrill to 10.200'.
12:15 - 12:35 0.33 DRILL P PROD1 Wiper to window.
12:35 - 18:00 5.42 DRILL P PROD1 Directionally drill 1.69 / 1.58 bpm 3325 psi, FS = 3070 psi.
WOB .98K, ECD 10.0, Drill to 10,290'.
18:00 - 19:15 1.25 DRILL P PROD1 Drill from 10,290 ft. Drilling break after 10,280 ft.
ROP is 50-60 ft/hr with 1-2 Klbs DWOB.
1.7 / 1.6 bpm @ 3000-3600 psi.
Drill to 10,328 ft, difficult sliding.
19:15 - 19:40 0.42 DRILL P PROD1 Wiper to window. Clean pass up and down.
19:40 - 20:00 0.33 DRILL P PROD1 Drill from 10,328 ft. Continue holding 95-96 deg inc.
ROP is 40-60 ft/hr with 1-2 Klbs DWOB. Motor stalls getting
weak.
1.69 / 1.52 bpm C~ 3000 - 3600 psi.
Drill another foot, Weak stalls now with low WOB, POOH for bit
/motor change.
20:00 - 22:15 2.25 DRILL P PROD1 POOH. MAD pass back through window.
Open EDC when inside tubing tail.
22:15 - 22:30 0.25 DRILL P PROD1 SAFETY MEETING. Discuss hazards and mitigations for
change out BHA.
22:30 - 23:10 0.67 DRILL P PROD1 Tag stripper, UD BHA #9. Bit is 1-1.
23:10 - 23:45 0.58 DRILL P PROD1 M/U swizzle stick.
Close swab and jet stack out.
SLB inspect tie-rods and center up injector chains (again).
23:45 - 00:00 0.25 BOPSU P PROD1 Function test BOPS.
3/21/2009 00:00 - 00:30 0.50 BOPSU P PROD1 Continue function test BOPs.
00:30 - 01:00 0.50 DRILL P PROD1 P/U BHA #10 -New SRX bit, 1.0 deg AKO Xtreme, 2-3/8"
CoilTrak with Res.
BHA OAL = 67.95 ft
01:00 - 03:30 2.50 DRILL P PROD1 RIH BHA #10.
Log GR down from 9850 ft. Correct -4 ft.
Continue RIH. Pass through window clean.
RIH to bottom, tag at 10327 ft.
03:30 - 12:15 8.75 DRILL P PROD1 Drill from 10326 ft. Maintain 95-96 deg inc for now.
1.71 / 1.50 bpm ~ 3060 - 3400 psi.
Initial ROP is 30 fUhr with 1-2 Klbs DWOB. Continued Poor
ROP. Add 1 % additional Iub.Continued poor ROP in clean
sand. Frequent stalling (soft stalls) increase pump rates to 1.9
bpm max slight improvement. Strll frequent stalls. decide to
POH to inspect bit and BHA for wash outs.
12:15 - 14:40 2.42 DRILL P PROD1 POH
14:40 - 14:55 0.25 DRILL P PROD1 PJSM fror BHA swap, PT of CTC and PT of MWD for
washouts.
14:55 - 15:30 0.58 DRILL P PROD1 CTC PT OK, PT of MWD tools OK, Pull motor, Weak motor.
BIT 1-1.
15:30 - 16:25 0.92 DRILL N SFAL PROD1 Replace chain traction cylinder and realign chains.
16:25 - 17:00 0.58 DRILL P PROD1 MU BHA
17:00 - 19:30 2.50 DRILL P PRODi RIH.
Log GR down from 9850 ft to tie-in. Correct -10 ft.
RIH, pass through window with a 2K wt bobble, HS no pump.
RIH to bottom, tag at 10,444 ft.
19:30 - 21:10 1.67 DRILL P PROD1 Drill from 10,444 ft, continue holding 95-96 deg inc for now.
PtlntBtl: 4/13/200y 2:SL:LL PM
i ~
BP EXPLORATION Page 9 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date From - To Hours Task Code' NPT ~ Phase Description of Operations
3/21/2009 19:30 - 21:10 1.67 DRILL P PROD1 1.55 / 1.45 bpm @ 3000-3200 psi.
Initial ROP is 100-120 fUhr with 1-2 Klbs DWOB.
PVT = 326 bbls, ECD = 10.08 ppg.
Drill to 10,600 ft.
21:10 - 21:50 0.67 DRILL P PROD1 Wiper trip to window. Clean pass up and down.
21:50 - 23:20 1.50 DRILL P PROD1 Drill from 10,600 ft. Continue holding 96 deg inc.
1.48 / 1.4 bpm @ 2900-3100 psi.
ROP is 100-120 ft/hr with DWOB = 1-2 Klbs.
PVT = 325 bbls, ECD = 10.16 ppg.
Drill to 10,750 ft.
23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip to window.
3/22/2009 00:00 - 02:00 2.00 DRILL P PROD1 Drill from 10,750 ft. Start to gradually reduce inc to level out at
8675 ft TVD.
1.68 / 1.58 bpm C~3 3000-3500 psi.
ROP slows after 10850 ft with uneven drilling.
PVT = 313 bbl, ECD = 10.24 ppg.
New mud scheduled for 0600.
Past 10870 ft hold 93 deg inc until further notice, as per Anc
Geo.
Drill to 10,900 ft.
02:00 - 03:25 1.42 DRILL P PROD1 Wiper back to window and tie-in.
Pull through window, and clean short section of 7" csg back to
9500 ft.
Run back down to tie-in depth from 9850 ft. Correct -0.5 ft.
RIH back to bottom.
03:25 - 07:00 3.58 DRILL P PROD1 Drill from 10.900 ft. Hold 91 dep inc now.
1.59 / 1.49 bpm @ 3000-3500 psi.
ROP is 80-100 ft/hr with 2 Klbs DWOB.
ROP slows to around 30-50 fUhr after 10,970 ft.
07:00 - 08:30 1.50 DRILL P PROD1 Directionally drill 1.58/1.46 2950 psi .ROP 6-7, FS 2900
psi.WOB 2.83. Good weight transfer little motor work. Couple
of stalls. Swap to new mud. 1.66 / 1.45 bpm, 3100 psi FS
3050psi. Unable to drill. 10995
08:30 - 11:00 2.50 DRILL P PROD1 POH
11:00 - 11:15 0.25 DRILL P PROD1 PJSM to BD BHA and cut - CT for chrome management
11:15 - 11:45 0.50 DRILL P PROD1 LD BHA bit 6-2
11:45 - 14:15 2.50 DRILL P PROD1 Cut 50' CT and rehead. HOT not testing properly. Change out
HOT.
14:15 - 14:45 0.50 DRILL P PROD1 MU BHA
14:45 - 17:30 2.75 DRILL P PROD1 RIH Stop at 9550. Investigate High amps. on HOT.
17:30 - 17:52 0.37 DRILL P PROD1 Continue to RIH to 9850'.
17:52 - 18:20 0.47 DRILL P PROD1 Log tie-in. Correction -5'.
18:20 - 18:40 0.33 DRILL P PROD1 RIH. Tag at 10,992 ft.
18:40 - 21:00 2.33 DRILL P PROD1 Drill from 10,992 ft. Continue holding 91 deg inc.
1.66 / 1.44 bpm @ 2950 FS - 3500 psi.
ROP is 100-130 fUhr with 3 Klbs DWOB.
Past 11,100 ft level off to 90 deg to anticipate a fault.
Drill to 11,150 ft.
21:00 - 22:00 1.00 DRILL P PROD1 Wiper trip from 11,150 ft back to window. Clean pass up and
down.
22:00 - 00:00 2.00 DRILL P PROD1 Drill from 11,150 ft. Continue holding 90 deg inc.
1.67 / 1.45 bpm ~ 3000-3400 psi.
ROP is 60-90 fUhr with >3 Klbs DWOB.
rnmea: anmzuua Z:JG:ZZ YM
a •
BP EXPLORATION Page 10 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date ~~, From - To it Hours Task Code NPT Phase Description of Operations
3/22/2009 22:00 - 00:00 2.00 DRILL P PROD1 PVT = 321 bbls, ECD = 10.15 ppg.
Drill to 11,300 ft.
3/23/2009 00:00 - 01:10 1.17 DRILL P PROD1 Wiper trip from 11,300 ft to window. Clean pass up and down.
01:10 - 03:40 2.50 DRILL P PROD1 Drill from 11,300 ft. Continue to hold 90 deg inc.
1.71 / 1.46 bpm C~ 3000-3700 psi.
ROP is 80-90 fUhr with 3-4 Klbs DWOB.
PVT = 309 bbls, ECD = 10.31 ppg.
Drill to 11,450 ft.
03:40 - 05:20 1.67 DRILL P PROD1 Wiper trip to 9,500 ft and tie-in. Correct +1 ft.
05:20 - 09:45 4.42 DRILL P PROD1 Drill from 11,450 ft. Drilling with 1.66 / 1.42 bpm 3700 psi,
WOB 2.28, ECD 10.4, ROP Drill to 11600. ROP decreasing.
Chert consistently in samples.
09:45 - 12:30 2.75 DRILL P PROD1 POH
12:30 - 13:45 1.25 DRILL P PROD1
13:45 - 15:50 2.08 DRILL P PROD1
15:50 - 16:15 0.42 DRILL P PROD1
16:15 - 17:10 0.92 DRILL P PROD1
17:10 - 19:30 2.33 DRILL P PROD1
19:30 - 21:00 1.50 DRILL P PROD1
21:00 - 22:40 1.67 DRILL P PROD1
22:40 - 00:00 1.331 DRILL P ~ PROD1
3/24/2009 ~ 00:00 - 01:45 ~ 1.75 ~ DRILL ~ P PROD1
01:45 - 02:00 I 0.251 DRILL I P I I PROD1
02:00 - 03:20 ~ 1.33 ~ DRILL ~ P ~ ~ PROD1
03:20 - 05:20 2.00 DRILL P PROD1
05:20 - 05:40 0.33 DRILL P PROD1
05:40 - 06:30 0.83 DRILL P PROD1
06:30 - 10:15 3.75 DRILL P PROD1
10:15 - 12:30 2.25 DRILL P PROD1
12:30 - 15:25 2.92 DRILL P PROD1
15:25 - 18:15 I 2.831 DRILL I P I I PROD1
BHA
RIH to 9850.
Log tie -in. Correction = -4'.
RIH. tag 11598.5'.
Drill 1.48 / 1.27 bpm @ FS = 3440 psi.
PVT = 252 bbls, ECD = 10.63 ppg. New mud scheduled for
24:00.
Drill to 11,742 ft.
Wiper trip from 11,742 ft to window. Clean pass up and down.
Drill from 11,742 ft. Hold 89 deg inc for now.
1.61 / 1.43 bpm C~ 3600-4100 psi.
ROP is 30-60 ft/hr with 3-4 Klbs DWOB.
PVT = 240 bbls, ECD = 10.74 ppg.
ROP 10-20 fUhr after 11760 ft, then < 10 ft/hr.
Sample at 11,750 ft is 25% chert.
POOH to check bit and motor.
Two 10K overpulls through 11560-11580 ft.
Open EDC when inside tubing tail.
Continue POOH BHA #13.
Test agitator at 300 ft, not working.
SAFETY MEETING. Discuss hazards and mitigations for
change out BHA. Excess personnel and communications were
discussed.
Tag stripper and UD BHA #13. Nose of bit has been worn to a
concave shape, all cutters in the center worn off.
M/U BHA #14 - SRX bit + 1.0 deg Xtreme + 2-3/8" CoilTrak
with Res and Agitator.
BHA OAL = 75.56
RIH BHA #14. Shallow hole test of agitator is good.
Log GR down from 9850 ft. Correct -4.5 ft.
Continue to RIH. tag at 11762'.
Drill @ 1.42/1.22bpm ~ 3860 psi 3740 psi FS, 2k WOB, ECD
11.23. ROP 30-80. Drill ti 11900'.
Wiper to window
Drill 1.59 / 1.40 bpm C«3 4300 psi., FS = 3680 psi, 1.7K WOB,
ECD 10.77, ROP 80.
Wiper to window over 30K off bottom. Madd pass
11800-11300. C~ 10 fVmin
Printed: 4/13/zoos 2:52:22 NM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33
Event Name: REENTER+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 1
~'
23:00 - 00:00 1.00 DRILL P
00:00 - 01:50 1.83 DRILL P
Date ,From - To Hours ! Task Code NPT j Phase i
3/24/2009 118:15 - 23:00 I 4.751 DRILL I P
3/25/2009
3/26/2009
01:50 - 04:40 I 2.831 DRILL I P
04:40 - 07:15 2.58 DRILL P
07:15 - 09:30 2.25 DRILL P
Start: 2/24/2009
Rig Release: 4/4/2009
Rig Number:
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
09:30 - 12:50 3.33 DRILL N DFAL PROD1
12:50 - 13:15 0.42 DRILL N DFAL PROD1
13:15 - 13:45 0.50 DRILL P PROD1
13:45 - 15:30 1.75 DRILL N DFAL PROD1
15:30 - 16:45 1.25 DRILL N DFAL PROD1
16:45 - 17:30 0.75 DRILL N DFAL PROD1
17:30 - 20:50 3.33 DRILL N DFAL PROD1
20:50 - 23:15 2.42 DRILL P PROD1
23:15 - 00:00 0.75 DRILL P PROD1
00:00 - 01:40 1.67 DRILL P PROD1
01:40 - 04:00 2.33 DRILL P PROD1
04:00 - 08:45 4.75 DRILL P PROD1
Page 1 1 of 20
Spud Date: 6/11 /1985
End: 4/4/2009
Description of Operations
Drill from 12,058 ft. Hold 85 inc for now, to drill down through
24N shale later on.
1.61 / 1.40 bpm @ 3800 FS - 4300 psi.
ROP is 70-80 ft/hr with 1.9 Klbs DWOB.
PVT = 304 bbls, ECD = 10.85 ppg.
ROP slows to 30-40 ft/hr after 12,080 ft. Samples have been
40 - 50% chert.
Drill to 12,200 ft. 12,200 ft sample is 70% chert.
Wiper back through 7" casing, and tie-in log.
Continue wiper trip + tie-in log. Correct +3.5 ft.
Pass through window clean, RIH to bottom.
Drill from 12,200 ft, continue holding 85 deg inc.
1.42 / 1.20 bpm C~? 3700-4200 psi.
ROP is 50-60 fUhr with 1.9 Klbs DWOB.
PVT = 265 bbls, ECD = 11.08 ppg.
Starting to see differential sticking, 50 Klbs off bottom at
12,345 ft.
Drill to 12,350 ft.
Wiper trip from 12,350 ft to window. Clean pickup off bottom.
Drill 1.5 / 1.24 bpm C~ 4300 psi,3950 psi = FS, 1.4K WOB,
ECD 11.4ppg. Drill to 12424 seeing over pulls when PU off
bottom 50K. Surface wt -1 K .Drill to 12438. Stall PU over pull
72K. Agitator not operating. Decided to POH for new agitator.
POH.
LD BHA bit 1-3
3rd party SLB inspection of slings on injecfor.
Check In MM Callibration. at .5 bpm to known surface vo1.2.03
min. stab onto well. Compare IN /OUT rate and densities at
1,1.5&2bpm
In Rate Out Rate In density Out density
1.02 .80 8.53 8.61
1.52 1.33 8.57 8.63
2.09 1.92 8.57 8.62
CTC leaking. Rehead CT.
MU BHA.
RIH.
Tie-in from 9850 ft, correct -4.0 ft.
Continue RIH, tag bottom at 12,437 ft and MAD pass back to
11,400 ft.
MAD pass from TD to 11,400 ft.
Drill from 12438 ft. From this point forward drop inc to 73 deg
to cut through 24N shale.
1.53 / 1.32 bpm @ 3600 - 4200 psi.
ROP is 60-100 ft hr with 1-2 Klbs DWOB.
Drill to 12489 ft.
Start new mud downhole.
Continue drilling to 12,600 ft.
Wiper trip from 12,600 ft to window.
Drill from 12,600 ft. Continue holding 73 deg until through 24N
shale.
Mud swap complete.
1.51 / 1.32 bpm ~ 3650-4100 psi.
ROP is 60 ft/hr with 2.8 Klbs DWOB.
Nrintea: an'sizuua z:5rzz rnn
BP EXPLORATION Page 12 of 20
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
09-33
09-33
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Spud Date: 6/11/1985
Start: 2/24/2009 End: 4/4/2009
Rig Release: 4/4/2009
Rig Number:
Date I From - To I Hours I Task I Code I NPT
3/26/2009 ~ 04:00 - 08:45 ~ 4.75 ~ DRILL ~ P
08:45 - 12:00 3.25 DRILL N DFAL
12:00 - 13:30 1.50 DRILL N DFAL
13:30 - 17:15 3.75 DRILL N DFAL
17:15 - 21:50 4.58 DRILL P
21:50 - 00:00 2.17 ~ DRILL P
3/27/2009 00:00 - 00:15 0.25 DRILL P
00:15 - 04:45 4.50 DRILL P
04:45 - 06:20 1.58 DRILL P
06:20 - 08:00 1.67 DRILL P
08:00 - 14:30 6.50 DRILL P
14:30 - 16:30 2.00 DRILL P
16:30 - 16:40 0.17 DRILL P
16:40 - 17:45 1.08 DRILL P
17:45 - 22:30 4.75 DRILL P
22:30 - 22:45 0.25 DRILL P
22:45 - 00:00 1.25 DRILL P
3/28/2009 00:00 - 01:20 1.33 DRILL P
01:20 - 01:50 0.50 DRILL P
01:50 - 02:05 0.25 BOPSU P
02:05 - 11:00 8.92 BOPSU P
11:00 - 11:30 0.50 CASE P
11:30 - 11:45 0.25 CASE P
11:45 - 12:00 0.25 CASE P
12:00 - 18:00 6.00 CASE P
18:00 - 18:15 0.25 CASE P
18:15 - 19:50 1.58 CASE P
19:50 - 00:00 ~ 4.17 ~ CASE ~ P
Phase Description of Operations
PRODi Top 24N at 12,589 ft based on GR.
PVT = 326 bbls, ECD = 10.87 ppg.
Drill to 12724. Agitator not working unable to slide. POH for
agitator.
PROD1 POH
PROD1 M/U new BHA
PROD1 RIH with new BHA, Hole tight from 12,600'- 12,712'
PROD1 Drill from 12,724 ft.
Mud swap complete.
1.47 / 1.43 bpm ~ 3650-4100 psi.
ROP is 50 ft/hr with 2 Klbs DWOB.
ECD = 11.12 ppg.
FS = 3,650
ROP slows to 10-20 ft/hr after 12,730 ft.
18:50 PVT = 280 bbls.
Drill to 12,870 ft.
PROD1 Wiper trip to window. Minor overpulls through shales
12,700-12,820 ft.
PROD1 Continue wiper trip from 12,870 ft to window.
PROD1 Drill from 12,870 ft. Continue holding 78 deg inc.
1.42 / 1.35 bpm (~ 3900 - 4350 psi.
ROP 10-60 ft/hr with 3-4 Klbs DWOB.
Drilling break 12,930 - 12,950 ft ROP goes to 100-120 fUhr.
Drill to 13.000 ft.
PROD1 Wiper trip from 13,000 ft to window.9927
PROD1 RIH Set down at 12630,RIh tag 13000'.
PROD1 Drill 1.36 1.29 BPM 4550 psi, FS 3850 psi, 1.37K WOB, ECD
11.32, ROP 10-30 . Drill to 13160 . Geo called TD. .(
PROD1 Wiper to window. ` r
PROD1 Log tie-in. Correction +8'.
PROD1 RIH to TD
PROD1 Lay in liner running pill while POOH, PJSM for L/D of Drilling
Assy & Slack Management
PROD1 L/D drilling Assy.
PROD1 Pump Slack & cut 50' of coil, 330' of cable
PROD1 Line out equipment for BOP test
PROD1 Weld on new CTC
Pull test & Pressure test CTC
PROD1 PJSM for Pressure testing BOP
PROD1 Pressure test BOP
RUNPRD Clear floor and prep for liner job.
RUNPRD PJSM for running liner.
RUNPRD Open well well on Vac. Took 11 bbl to fill well.
RUNPRD PU 121 jts 2-3/8 13CR liner drifting each connection.
RUNPRD SAFETY MEETING, re: PU remaining Liner BHA
RUNPRD PU liner de to ment sleeve & 'nts of 2-1 1 "
Cut 10' of coil, leave 5' eline tail, install slip on CTC, pull test &
pressure test CTC.
Stab injector onto well.
RUNPRD RIH Liner BHA w/ Baker quick connect, 6 jnts 2-1/16" CSH,
3/4" ball hydraulic disconnect, SELBRT, 39 jnts 2-3/8" 4.7#
13CR Liner w/ turbos, 10' 2-3/8" 4.7# 13CR Pup Jnt (no turbo),
81 jnts 2-3/8" 4.7# 13CR Liner w/ turbos, Landing collar, 4' Pup
rrincea: an srzuuy Z:bY:ZZ YM
BP EXPLORATION Page 13 of 20
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
09-33
09-33
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Spud Date: 6/11/1985
Date From - To Hours Task Code
3/28/2009 19:50 - 00:00 4.17 CASE P
3/29/2009 100:00 - 01:00 I 1.001 CASE I P
01:00 - 05:00 ~ 4.00 ~ CASE ~ N
05:00 - 06:00 ~ 1.00 CASE ~ N
06:00 - 11:00 5.00 CASE N
11:00 - 15:00 4.00 CASE N
15:00 - 16:15 1.25 CONDH N
16:15 - 18:20 2.08 CONDH N
18:20 - 19:45 1.42 CONDH N
19:45 - 20:00 0.25 CONDH N
20:00 - 23:30 I 3.501 CONDHLI N
23:30 - 00:00 0.50 CONDH N
3/30/2009 00:00 - 02:30 2.50 CONDH N
02:30 - 02:45 0.25 CONDH N
02:45 - 06:00 3.25 CONDH N
06:00 - 07:55 I 1.921 CONDHLI N
Start: 2/24/2009 End: 4/4/2009
Rig Release: 4/4/2009
Rig Number:
NPT Phase Description of Operations
RUNPRD jnt, Float collar, 1 jnt 2-3/8" 4.7# 13CR Liner, Float collar, Bias
edge indexing guide shoe.
PU Wt at 9990' is 32k#.
Run liner to 11,430' with steady decrease in CT Wt, pumping
0.2 bpm.
Work liner from 11,430' picking up frequently and pumping to
clean the hole, then RIH w/ no pumps.
Work liner to 12,150'.
RUNPRD Run liner from 12,150' by RIH w/ no pumps & PU frequently
pumping ~ 0.5 bpm.
Temporarily stuck at 12,160' and pulled free at 65k#.
Work liner to 12,213' then started pulling heavy 40k-55k# (34k#
normal up wt). Work pipe free then PU circulating.
RREP RUNPRD Generator #2 failed.
PUH pumping /pulling minimum rate into cased hole.
Plan forward is to make a cleanout run.
POOH to surface while troubleshooting generator.
DPRB RUNPRD Generator #2 is operating.
Continue POOH to surface.
DPRB RUNPRD a k liner
DPRB RUNPRD Pump slack Cut. Head up E coil. Investigate low restivity in E
coil conductor. Cut additional CT and wire. Rehead a second
time. RIH thaw CT.
DPRB RUNPRD MU cleanout BHA with MWD.
DPRB RUNPRD RIH
DFAL RUNPRD BHI tool failure. Eline shorted out. POH to surface.
DFAL RUNPRD SAFETY MEETING, re: troubleshooting tool failure & handling
BHA.
DFAL RUNPRD Pop off injector, check UOC, eline pulled out of the anchor.
UD BHI tools.
Coil slack management--pumped eline back, cut 165' coil and
145' of eline, eline was bent in an accordion fashion.
Install Kendal connector, rehead eline, and pressure test .
DFAL RUNPRD PU cleanout BHA. Stab injector onto well.
DPRB RUNPRD RIH w/cleanout BHA #19
DPRB RUNPRD Log tie-in. Correction -4'.
DPRB RUNPRD cleanout from 9500', 1.5 bpm C~J 3250 psi
Shutdown pumps across cement ramp
Ream from 9915', 1.5 bpm ~ 3330 psi, 20 deg RHS, 10 fpm
Ream from 10,200', 1.5 bpm C~3 3440 psi, 20 deg RHS, 11 fpm
Ream from 10,500', 1.5 bpm ~ 3520 psi, 35 deg RHS, 11 fpm
Ream from 10,900', 1.5 bpm C~ 3560 psi, 20 deg RHS, 11 fpm
Ream from 11,100', 1.5 bpm ~ 3580 psi, 25 deg RHS, 11 fpm
Ream from 11,380', 1.5 bpm ~ 3650 psi, 20 deg RHS, 11 fpm
DPRB RUNPRD Ream from 11630, 1.5 bpm C~3 3660 psi, 20 deg RHS 11 fpm
CT wt 11.5K
Ream from 11950, 1.5 bpm ~ 3660 psi, 20 deg RHS 11 fpm
CT wt 10.2K
Ream from. 12050 , 1.5 bpm ~ 3770 psi, 20 deg RHS 11 fpm
CT wt 10.OK
Ream from 12200 , 1.5 bpm ~ 3870 psi, 20 deg RHS 11 fpm
CT wt 9.3 K
YfIf1SEO: 4/1J/ZVU`J Z:OL:ZL YM
BP EXPLORATION Page 14 of 20
Operations Summary Report
Legal Well Name: 0 9-33
Common W ell Name: 0 9-33 Spud Date: 6/11/1985
Event Name : R EENTE R+COM PLET E Start : 2/24/2009 End: 4/4/2009
Contractor Name: N ORDIC CALIST A Rig Release: 4/4/2009
Rig Name: N ORDIC 1 Rig N umber:
Date From - To I Hours Task ' Code ~ NPT Phase Description of Operations
3/30/2009 06:00 - 07:55 1.92 CONDH N DPRB RUNPRD Ream from 12500, 1.5 bpm C~ 3900 psi, 20 deg RHS 11 fpm
CT wt 8.8 K
Increasing pressure ECD related. RIH to 12571'.
Gen #2 failed.
07:55 - 10:15 2.33 CONDH N RREP RUNPRD Repair Gen #2 while POH to window.
Back ream to window with
10:15 - 11:30 1.25 CONDH N RREP RUNPRD RIH with 20R TF clean to 12600'
11:30 - 13:30 2.00 CONDH N DPRB RUNPRD Back to last operational depth. RIH clean to shale at 12,590'.
Ream shales from 12,590-12784'.
Stack full wt and overpull several times up to 68K up wt.
Shales do not look good.
13:30 - 15:30 2.00 CONDH N DPRB RUNPRD Shales are cleaned up down to 12,690'.
Ream down and stack full wt at 12,780 and 12794'.
Back ream with 40-60K up wt. up to 12680'.
Ream down, stack full wt at 12760'. Ream down to 12785'.
Back ream 9 fpm, 1.5 bpm, 4100 psi, 31-38K up wt.
Over pull to 55K at 12690 and 12670'.
Back ream to 12550'. RIH. Stack wt at 12640'.
Ream down to next shale at 12870'.
Back ream up to 12,650' again.
Ream down thru second shale to 12,944'.
Back ream up to 12550'. 20K overpulls at 12690 and 12670'.
15:30 - 16:00 0.50 CONDH N DPRB RUNPRD RIH from 12550'. Stack full wt at 12630', 12690', 12705',
12875'.
RIH with -5K wt to 13050'. Below the shales.
Back ream up to 12950'. RIH with -5K wt, 0.5 bpm to 13084'.
RIH to TD of 13,163' with 0.2 bpm, and negative weight.
16:00 - 16:50 0.83 CONDH N DPRB RUNPRD Back ream up to 12,550'. Overpull at 12680' and 12650'.
Good back ream.
Ream back to bottom. Stack full wt at 12640', RIH with full
j pump at 1.5 bpm, 4100 psi,
Tag TD at 13163'.
16:50 - 17:40 0.83 CONDH N DPRB RUNPRD Back ream with 180 deg out TF. 1.5 bpm, 4100 psi, 20 fpm.
Backream up to 12,550' clean.
RIH to TD clean. Shales look good now.
17:40 - 20:00 2.33 CONDH N DPRB RUNPRD Backream up to window, 1.4 bpm, 3800 psi, 20 fpm, 33-38K up
wt.
20:00 - 00:00 4.00 CONDH N DPRB RUNPRD Ream 20 fpm, 1.4 bpm @ 3730 psi, HS from window to
12,500'.
Ream 10 fpm, 1.4 bpm C~? 3730 psi, HS to 12,670'.
Set-down 12,705'. 34k# PU wt. Back ream to 12,650'.
Ream 12 fpm, 1.4 bpm ~ 3800 psi, HS to TD.
Backream 12 fpm, 1.4 bpm ~ 3750 psi, LS to 12,500'.
Ream 13 fpm, 1.3 bpm @ 3500 psi, HS to TD.
3/31/2009 00:00 - 02:00 2.00 CONDH N DPRB RUNPRD POOH la in in liner runnin ill w/ al ine beads.
02:00 - 02:30 0.50 CONDH N DPRB RUNPRD Replace 5 cotter pins on injector.
02:30 - 04:00 1.50 CONDH N DPRB RUNPRD POOH to surface.
04:00 - 04:15 0.25 CONDH N DPRB RUNPRD SAFETY MEETING, re: UD Cleanout BHA
04:15 - 06:00 1.75 CONDH N DPRB RUNPRD UD Cleanout BHA, RD UOC
Pump 95' slack
Cut off Kendal connector, Install Baker slip on connector, pull
test & pressure test.
06:00 - 06:30 0.50 CASE N DPRB RUNPRD RU to PU liner.
rnmea: an sizuua fbZZZ YM
~ r
BP EXPLORATION
Page 15 of 20,1
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33
Event Name: REENTER+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 1
Date From - To Hours Task Code
Start: 2/24/2009
Rig Release: 4/4/2009
Rig Number:
Spud Date: 6/11 /1985
End: 4/4/2009
3/31/2009 06:30 - 06:45 0.251 CASE N
06:45 - 11:00 I 4.251 CASE I N
11:00 - 12:15 I 1.251 CASE I N
12:15 - 13:30 ~ 1.25 ~ CASE N
13:30 - 14:00 I 0.501 CASE I P
14:00 - 16:10 I 2.171 CASE I P
NPT ~ Phase Description. of Operations
DPRB RUNPRD SAFETY MEETING. Review procedure, hazards and
mitigation for running 2-3/8" Liner and running tools.
DPRB RUNPRD Run 2-3/8" STL, 13CR Liner with Baker float a ui ment.
Stop and fill liner at 60 jts.
Run total of 121 jts of 2-3/8" liner with two 10 pup jts, and P110
Deployment Sleeve.
M/U BTT SELBRT, Hyd Disc, 6 jts 2-1/16" CSH, BTT Quick
connect and CTC.
2-3/8" Liner OAL = 3,708.07'.
Liner with running tools, BHA OAL = 3,895.47'.
Circ liner volume at surface. 0.15 bpm, 1300 psi.
DPRB RUNPRD RIH with 2-3/8" 13CR Liner on coil.
Circ 0.1 bpm, 1200 psi.
RIH to 9800', Up wt = 33K, Dwn wt = 15K.
RIH thru window clean.
DPRB RUNPRD RIH with liner at 80 fpm, 0.1 bpm, 1600 psi, 14K dwn wt at
10500'.
10.5K down wt at 11000'.
2K dwn wt at 11500', RIH at 65 fpm
-6K dwn wt at 11700', RIH at 50 fpm, No pump.
-7K dwn wt at 11800', RIH at 40 fpm, no pump.
-8K dwn wt at 12000', Stack -12K at 12000'.
Pick up 100', Up wt = 54K.
-9K dwn wt at 12050', RIH at 10 fpm, no pump.
Set down at 12,086'.
Pick up 100', Up wt = 52K.
RIH to 12,136'. Stack full wt. Pick up 50'.
RIH to 12,143'. Stack full wt. Pick up 100'.
RUNPRD Not able to get below 12143' due to drag.
Pump down backside to have fluid moving in same direction as
liner.
Pump 0.2 bpm down backside (1600 psi), RIH with liner to
12550'.
Stack -12K, Stop pump, pick up wt = 61 K. Pick up 50'.
RIH, pump down backside at 0.2 bpm, RIH to 12630'.
Stack -12K. Pick up 50'.
RIH, pump down backside at 0.2 bpm, RIH to 12800'
Stack -12K, Pick up 50', 62K up wt.
RIH, pump down backside at 0.2 bpm,
RIH at 50 fpm, -1 K dwn wt,
RIH, -3K dwn wt at 13100'.
Landed liner at 13,175'. Corrected TD = 13 163'.
Liner is landed at TD.
RUNPRD Circ 0.8 bpm, 3000 psi with 0.12 bpm returns.
Circ 1.8 bpm, 4600 psi with 0.2 bpm returns.
Pick up to 42K, still have liner.
Position reel for ball drop.
Launch 5/8" steel ball, Displace with GeoVis. 1.8 bpm, 4400
psi, 0.2 bpm returns.
Heard ball go over guide arch at 28 bbls.
Slow pump to 0.30 bpm at 32 bbls, 2100 psi, 0.2 bpm returns.
Ball not on seat at 52 bbls. Surge rate from 0-.9 bpm.
Ball on seat at 53.7 bbl. Sheared at 3800 psi.
Printed: 4/13/2009 2:52:22 PM
~ r
BP EXPLORATION Page 16 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33
Event Name: REENTER+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 1
Date I From - To {j Hours Task Code NPT
3/31/2009 14:00 - 16:10 I 2.17 CASE P
16:10 - 18:45 I 2.581 CEMT I P
18:45 - 20:00 ~ 1.25 ~ CEMT ~ P
20:00 - 20:15 ~ 0.25 ~ CEMT ~ P
20:15 - 21:00 I 0.751 CEMT I P
21:00 - 22:45 ~ 1.75 ~ CEMT ~ P
Spud Date: 6/11 /1985
Start: 2/24/2009 End: 4/4/2009
Rig Release: 4/4/2009
Rig Number:
Phase i Description of Operations
RUNPRD Stop pump, Pick up free from liner at 27K up wt.
Stack 10K down on liner.
RUNPRD Circ well to double slick KCL water with 0.6% SafeLube for
cement job.
Circ 1.6 bpm, 2500 psi, 0.4 bpm returns at start.
Circ 1.6 bpm, 2300 psi, 1.2 bpm returns after 130 bbls
pumped, 30 bbls up ann.
Circ 2.0 bpm, 2700 psi, 1.5 bpm returns after 160 bbls
pumped,
Circ 2.1 bpm, 2750 psi, 1.8 bpm returns with KCL water to
surface.
12% fluid loss with KCL around.
Cement job = 16 bbl, plus 2 bbl for fluid loss, plus 2 bbl for
side exhaust
Cement job will be 20 bbl total.
RUNPRD Circ double slick 2% KCL while rigging up cementers.
circ 1.7 bpm, 1.60 bpm returns, 300 bbl circ so far.
RUNPRD SAFETY MEETING. Review procedure, hazards and
mitigation for pressure testing and pumping 20 bbl liner cement
job.
RUNPRD Batch mix 20 bbl, 15.8 PPG, G Cement. Circ. KCL water while
batch mixing.
circ. 400 bbl total before cement job.
Cement at weight at 2045 hrs.
RUNPRD Circ. 5 bbl KCL water to warm cement line.
Pressure test cement line with 6500 psi.
5 bbl Cmt, 1.5 bpm, 2900 psi, 1.4 bpm returns
10 bbl Cmt, 1.2 bpm, 2500 psi, 1.1 bpm returns
15 bbl Cmt, 1.2 bpm, 3200 psi, 1.1 bpm returns
18 bbl Cmt, 1.2 bpm, 3200 psi, 1.1 bpm returns.
Stop pump.
Isolate coil from cementers. Pump 3 bbl Biozan to cementers.
Blow down line. Vac cement line.
Zero In total on start of displacement.
Leave cementers on standby incase we need them to pump.
Stage 2# Biozan displacement.
10 bbl displ, 1.4 bpm, 3000 psi, 1.3 bpm returns
20 bbl displ, 1.5 bpm, 3200 psi, 1.4 bpm returns
30 bbl displ, 1.5 bpm, 3650 psi, 1.4 bpm returns
33.4 bbl displ, cement at shoe, zero out totalizer
35.0 bbl displ, stop pump, leaving 2 bbl cement inside coil for
side exhaust.
Coil capacity = 37.0 bbl.
Pick up 13 ft from break over depth, Pick up to 13,151 ft.
Pump 5 bbl to backside, 2 bbl cement and 3 bbl Biozan
2.5 bpm, 2.5 bpm returns, 3900 psi.
Open Baker choke, RIH and stack 10K dwn wt at same depth.
13,173.5'
Close Baker choke, press up and shear LW P at 3200 psi, 40.8
bbl displ
Pflflt2tl: 4/73/ZUU9 L:S"L:LZ PM
~ ~
BP EXPLORATION Page 17 of 20
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
09-33
09-33
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Spud Date: 6/11/1985
Start: 2/24/2009 End: 4/4/2009
Rig Release: 4/4/2009
Rig Number:
Date '.From - To Hours ' Task Code NPT
3/31/2009 ~ 21:00 - 22:45 ~ 1.75 ~ CEMT ~ P
22:45 - 00:00 I 1.251 CEMT I P
4/1/2009 00:00 - 00:30 0.50 CEMT P
00:30 - 00:45 0.25 CEMT P
00:45 - 01:15 0.50 CEMT P
01:15 - 01:25 0.17 CEMT P
01:25 - 06:00 4.58 CEMT P
06:00 - 06:25 0.42 CEMT P
06:25 - 07:30 I 1.081 CEMT ( P
07:30 - 09:00 I 1.501 CEMT I P
09:00 - 09:50 ~ 0.83 ~ CEMT ~ P
09:50 - 10:45 ~ 0.92 ~ CEMT ~ P
10:45 - 13:15 2.50 CEMT P
13:15 - 13:30 0.25 CEMT P
13:30 - 15:45 I 2.251 CEMT I P
15:45 - 16:45 I 1.001 CEMT I P
16:45 - 17:00 I 0.25 I EVAL I P
17:00 - 18:00 1.00 EVAL P
18:00 - 18:15 0.25 EVAL P
18:15 - 20:25 2.17 EVAL P
Phase ~ Description of Operations
RUNPRD Displ LWP, Calc 14.2 bbl to bump plug.
43 bbl displ, 1.4 bpm, 3900 psi, 1.2 bpm returns
46 bbl displ, 1.1 bpm, 3500 psi, 0.9 bpm returns
48 bbl displ, 0.9 bpm, 3250 psi, 0.8 bpm returns
50 bbl displ, 0.7 bpm, 3050 psi, 0.7 bpm returns
52 bbl displ, 0.6 bpm, 2980 psi, 0.5 bpm returns
54 bbl displ, 0.5 bpm, 2950 psi, 0.4 bpm returns
Bumped LWP at 54.8 bbl, 0.2 bbl early, 0.5 bpm, 3000 psi,
Press up to 3860 psi on LWP. Hold pressure, 5 min. Good test.
Out totalizer indicated that we got 14.2 bbl CMT up backside of
liner.
Blead off press. Check floats, Good test, No Flow.
Press up 900 psi on coil, pick up to 13,152', seals out.
circ, 0.8 bpm, 0.8 bpm returns, circ 2 bbl at top of liner.
Full returns. Cement job went very well.
RUNPRD POH with SELBRT. Replace coil voidage.
Circ 0.5 bpm, 0.2 bpm returns.
RUNPRD POOH to surface.
RUNPRD SAFETY MEETING, re: UD liner running tools.
RUNPRD UD 6 jnts 2-1/16" CSH & liner running tool.
RUNPRD SAFETY MEETING, re: PU Cleanout BHA
RUNPRD PU Cleanout BHA with 104 jnts of 1" CSH.
RUNPRD Crew Changeout
SAFETY MEETING, re: PU 20 jnts of 1" CSH
RUNPRD PU 20 jts of 1"CSH, MHA, 2 jts 2-1/16" CSH, Quick Con and
CTC.
BHA OAL = 3,884.25'.
RUNPRD RIH with 1.875" mill and motor ceanout BHA #21.
Circ at 0.9 bpm, 2100 psi.
Tag Deployment sleeve profile at 9451.5'.
Correct depth to 9465'. Added 13.5'.
RUNPRD Mill out profile to 1.875".
0.9 bpm, 3300-3900 psi.
Milled thru profile with total of 3 stalls.
Ream up/down across profile. No motor work.
RUNPRD 81H to cleano~t 2-3/8" 13GR liner
Circ 0.9 bpm, 3600 psi, 1.2 bpm returns, RIH at 60 fpm.
RIH with 8K injector weight just off bottom. No weight transfer
problems.
Tag PBTD at 13,123', on depth with liner tally for PBTD.
RUNPRD POH while circ at 0.9 bpm, 3500 psi.
RUNPRD SAFETY MEETING. Review procedure, hazards and
mitigation for standing back 1"CSH workstring.
RUNPRD Standback 1" CSH workstring, 62 stds.
Lay out 1.875" mill and motor.
RUNPRD Jet stack with swizzle stick to clear any cement from BOP
rams.
LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for M/U SWS memory logging tools and running 1"
CSH workstring.
LOWERI PU Logging tools & 14 stands of 1"CSH.
LOWERI SAFETY MEETING, re: PU Logging BHA
LOWERI PU 48 stands of 1"CSH & remaining logging BHA.
F'flfltBtl: 4/13/'LUUy L:S"L:"LZ YM
~ ~
BP EXPLORATION Page 18 of 20
Operations Summary Report
Legal Well Name: 0 9-33
Common W ell Name: 0 9-33 Spud Date: 6/11/1985
Event Name : R EENTE R+COM PLET E Start : 2/24/2009 End: 4/4/2009
Contractor Name: N ORDIC CALIST A Rig R elease: 4/4/2009
Rig Name: N ORDIC 1 Rig N umber:
Date I From - To ~~ Hours Task Code NPT Phase Description of Operations
4/1/2009 20:25 - 21:45 1.33 EVAL P LOWERI RIH with Logging BHA to 9300'.
21:45 - 00:00 2.25 EVAL P LOWERI Log down at 30 fpm to PBTD. Tag at 13,116'.
4/2/2009 00:00 - 01:10 1.17 EVAL P LOWERI Log up 60 fpm from PBTD to 9300'. Lay in pert pill.
01:10 - 02:30 1.33 EVAL P LOWERI POOH to surface.
02:30 - 02:40 0.17 EVAL P LOWERI SAFETY MEETING, re: UD Logging BHA
02:40 - 05:00 2.33 EVAL P LOWERI UD Logging BHA, S/B 62 stands of 1"CSH, UD logging tool.
05:00 - 06:45 1.75 EVAL P LOWERI Pressure Test Liner Lap to 2000 psi for 20 min.
0 min, 2000 psi
10 min, 1830 psi
20 min, 1750 psi
Pressure back up to 2000 psi
0 min, 1937 psi @ 05:48
10 min, 1912 psi C~ 05:58
20 min, 1901 psi @ 06:08
30 min, 1897 psi @ 06:19
Line Lap Test Passed. Very good test. lost 40 psi in 30 min.
06:45 - 07:15 0.50 PERFO P LOWERI Load SWS 1.56" erf uns into ri i e shed. Lay out guns.
M/U Safety jt and XO.
07:15 - 07:30 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for running SWS 1.56" pert guns and 1" CSH
workstring.
07:30 - 11:00 3.50 PERFO P LOWERI M/U 24 SWS 1.56", PJ perf guns /blanks, guns loaded at 6
SPF. M/U 1/2" firing head.
M/U Hyd Disc and RIH with 54 stds of 1"CSH. M/U Hyd Disc,
Checks, 2 Jts 2-1/16" CSH, Quick Conn and CTC.
BHA OAL = 3,899..2'.
11:00 - 13:00 2.00 PERFO P LOWERI Circ at surface, OK.
RIH with SWS 1.56" perforating BHA #23. Circ. 0.1 bpm, 150
psi.
Tag PBTD at 13,105, correct +20' to put on depth with tied-in
PBTD of 13,125'.
Pick up to good ball drop spot.
13:00 - 14:40 1.67 PERFO P LOWERI Pump 2 bbl new FloPro, Launch 1/2" AL ball with 1000 psi,
Displ with 5 bbl new FloPro.
Circ 0.9 bpm, 2600 psi to launch ball. Pull up to 13,093' to circ
ball on seat.
Circ at 0.9 bpm, 2900 psi, Slow pump at 30 bbl to 0.6 bpm,
1200 psi, Pump 54 bbl, no ball on seat.
' Surge pump rate, Circ 1.0
bpm, Ball on seat at 70 bbls. Firing head sheared at 4200 psi,
Good shot detection.
°? ~~
PERFORATION INTERVALS
12,600 - 12,625
12,670 - 12,685
12,770 - 12,815 J
12,920 - 12,960
13,015 - 13,090, Total perfs for Perf run #1 = 200'.
14:40 - 18:00 3.33 PERFO P LOWERI POH with perf BHA. Flag coil at 8000' EOP, 11,899' CTD with
BHA #23.
Flow check at top of liner, no flow. POH. Circ 0.7 bpm, 1000
psi.
rrirnea: anmzuua z:oz:zzrm
BP EXPLORATION Page 19 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
~ ~ ~ i ~
Date 'From - To Hours Task 'Code NPT Phase Description of Operations
4/2/2009 14:40 - 18:00 3.33 PERFO P LOWERI Flow check at surface, no flow.
18:00 - 18:15 0.25 PERFO P LOWERI SAFETY MEETING, re: UD Perf BHA.
18:15 - 21:00 2.75 PERFO P LOW ER1 UD 2 jnts 2-16" CSH
S/B 54 stands of 1 "CSH
21:00 - 21:10 0.17 PERFO P LOWERI SAFETY MEETING, re: UD Perf guns.
21:10 - 22:30 1.33 PERFO P LOWERI UD 24 pert guns
22:30 - 22:40 0.17 PERFO P LOWERI SAFETY MEETING, re: PU Perf guns for second run.
22:40 - 23:50 1.17 PERFO P LOWERI M/U 22 SWS 1.56", PJ perf guns, loaded at 6 SPF. M/U 1/2"
firing head.
23:50 - 00:00 0.17 PERFO P LOWERI SAFETY MEETING, re: PU 54 stands of 1 CSH.
4/3/2009 00:00 - 02:30 2.50 PERFO P LOWERI PU 54 stands of 1"CSH.
02:30 - 04:00 1.50 PERFO P LOWERI RIH with SWS 1.56" perforating BHA #24. Circ. 0.3 bpm, 330
psi.
RIH to 8000' EOP flag at 11,838' uncorrected. Correct to
11,856' (+18' correction).
RIH to perforating depth.
04:00 - 05:45 1.75 PERFO P LOWERI Pump 5 bbl new FloPro, Launch 1/2" AL ball with 1200 psi,
Displace with 4 bbl new FloPro.
Circulate ball to firing head at 1.0 bpm, 2900 psi. Pull up to
12,102.5'.
At 30 bbl slow pump to 0.6 bpm, 1450 psi.
Ball on seat at 38.5 bbl, Firing head sheared at 4000 psi, Good
shot detection.
Bottom shot at 12,100'.
PERFORATION INTERVAL
11,650' - 12,100', Total perfs for run #2 = 450' ~
05:45 - 07:30 1.75 PERFO P LOWERI POOH.
Flow check above liner. POH.
Flow check at surface.
07:30 - 07:45 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for standing back 1" CSH.
07:45 - 09:30 1.75 PERFO P LOWERI Stand back 54 stds of 1" CSH.
09:30 - 09:45 0.25 PERFO P LOWERi SAFETY MEETING. Review procedure, hazards and
mitigation for laying out the fired perf guns
09:45 - 11:45 2.00 PERFO P LOWERi Lay out SWS 1.56" PJ Perf guns. All shots fired. 450' at 6
SPF.
Load out perf guns from pipe shed.
11:45 - 15:00 3.25 WHSUR P POST RIH with nozzle BHA to circ Diesel from 2500' to surface.
Little Red hauled diesel to rig.
RIH to 2500'. Heat and circ diesel out nozzle.
Chase diesel to surface. POH.
15:00 - 15:15 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and
mitigation for setting BPV with T bar.
15:15 - 16:00 0.75 WHSUR P POST Set BPV. Close Swab valve. SIWHP = 0 psi.
16:00 - 16:30 0.50 RIGD P POST Circ 30 bbl rig water, 10 bbl corrosion inhibitor, 6 bbl MEOH to
pickle coil.
16:30 - 16:40 0.17 RIGD P POST SAFETY MEETING. Review procedure, hazards and
mitigation for pumping N2.
16:40 - 17:30 0.83 RIGD P POST Displace coil to N2. Bleed down coil press to tiger tank.
17:30 - 19:45 2.25 RIGD P POST Cut off CTC. Install internal grapple. Pull coil to reel.
19:45 - 23:45 4.00 RIGD P POST R/D injector head for injector head swap
rnnceo: vi i aicwa c.occc nvi
BP EXPLORATION Page 20 of 20
Operations Summary Report
Legal Well Name: 09-33
Common Well Name: 09-33 Spud Date: 6/11/1985
Event Name: REENTER+COMPLETE Start: 2/24/2009 End: 4/4/2009
Contractor Name: NORDIC CALISTA Rig Release: 4/4/2009
Rig Name: NORDIC 1 Rig Number:
Date From - To Hours ! Task Code NPT Phase Description of Operations
4/3/2009 23:45 - 00:00 0.25 RIGD P POST PJSM for positioning injector head on catwalk
4/4/2009 00:00 - 01:30 1.50 RIGD P POST Move Injector head off rig floor to catwalk
01:30 - 02:30 1.00 RIGD P POST R/D in preperation for rig move
02:30 - 02:45 0.25 RIGD P POST PJSM for blind pick to swap injector
02:45 - 04:00 1.25 RIGD P POST Swap injector and place new Injector on floor
04:00 - 06:00 2.00 RIGD P POST Rig up new injector head.
06:00 - 09:00 3.00 RIGD P POST Nipple down BOP's. N/U tree cap and press test.
RELEASED RIG AT 0900 HRS, TOTAL OF 20 DAYS AND 22
HOURS FROM RIG ACCEPT TO RELEASE.
The well was planned for 22.46 days.
Prepare to move rig 21 miles to DS 18-26B.
All further DIMS information will be under well 18-26B.
F'llf1t00: 4/1;1/LUUy L:JC:LL YM
.~~~
BAIC~R
1~5
INTEL
North America -ALASKA - BP
Prudhoe Bay
PB DS 09
09-33 -Slot 33
09-33A 500292136501
Design: 09-33A
Survey Report -Geographic
30 March, 2009
by
• Survey Report -Geographic
hVTEQ
Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 09-33 -Slot 33
Project: Prudhoe Bay TVD Reference: 48:33 6/11/1985 00:00 @ 55.OOft (generic drillinc
Site: PB DS 09 MD Reference: 48:33 6/11!1985 00:00 @ 55.OOft (generic drillinc
Well: 09-33 North Reference: True
Wellbore: 09-33A 500292136501 Survey Calculation Method: Minimum Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
Project Prudhoe Bay, North Slope,, UNITED STATES
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site PB DS 09, TR-10-15
Site Position: Northing: 5,940,909.88ft Latitude: 70° 14' 28.451 N
From: Map Easting: 717,218.90ft Longitude: 148° 14' 44.098 W
Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 1.65 °
Well 09-33 -Slot 33, 09-33
Well Position +N/-S 0.00 ft Northing: 5,943,143.45ft Latitude: 70° 14' 50.374 N
+E/-W 0.00 ft Easting: 717,347.81 ft Longitude: 148° 14' 38.479 W
Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft
Wellbore 09-33A 500292136501
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
bggm2007 9/26/2008 23.22 80.94 57,695
Design
Audit Notes:
Version:
Vertical Section:
--- -
09-33A
.0 Phase: ACTUAL Tie On Depth:
Depth From (TVD) +N/-S +E/-W
35.00 0.00 0.00
9,900.00
Direction
(°)
40.78
Survey Program Date 3/30!2009
From To
(ft) (ft) Survey (Wellbore) Tool Name
100.00 9,900.00 1 : Sperry-Sun BOSS gyro multi (09-33) BOSS-GYRO
9,903.00 13,163.00 MWD (09-33A 500292136501) MWD
Description
Sperry-Sun BOSS gyro multishot
MWD -Standard
3/30/2009 2:29:02PM Page 2 COMPASS 2003.16 Build 70
BAJnR ^
~
~
Mtei1~ Survey Report - Geographic bP
)ENTEQ
Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 09-33 -Slot 33
Project: Prudhoe Bay TVD Reference: 48:33 6/11/1985 00:00 @ 55.OOft (generic drillinc>
Site: PB DS 09 AAD Reference: 48:33 6/11!1985 00:00 @ 55.OOft (generic drilling
Well: 09-33 North Refe rence: True
Wellbore: 09-33A 500292136501 Survey Calculation Method: Minimum Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
.Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting
(ft) (°) (°) (ft) (ft) (ft) (ft} (ft) Latitude Longitude
9,900.00 27.03 9.39 8,719.38 3,698.10 564.82 5,946,856.13 717,805.72 70° 15' 26.744 N 148° 14' 22.047 W'I
TIP
9,903.00 27.30 9.49 8,722.05 3,699.45 565.05 5,946,857.48 717,805.90 70° 15' 26.757 N 148° 14' 22.040 W
KOP II
9,925.31 41.12 20.68 8,740.47 3,711.43 568.50 5,946,869.56 717,809.01 70° 15' 26.875 N 148° 14' 21.940 W
9,955.67 51.83 29.84 8,761.37 3,731.20 578.00 5,946,889.59 717,817.94 70° 15' 27.070 N 148° 14' 21.663 W ~'
9,981.27 60.61 35.07 8,775.60 3,749.10 589.45 5,946,907.81 717,828.86 70° 15' 27.246 N 148° 14' 21.330 W
10,009.29 69.31 48.99 8,787.49 3,767.80 606.45 5,946,927.00 717,845.32 70° 15' 27.430 N 148° 14' 20.835 W
10,030.07 74.49 55.78 8,793.95 3,779.83 622.09 5,946,939.47 717,860.60 70° 15' 27.548 N 148° 14' 20.380 W
10,059.99 77.72 54.13 8,801.14 3,796.51 645.86 5,946,956.83 717,883.88 70° 15' 27.712 N 148° 14' 19.689 W
10,090.75 81.59 52.19 8,806.66 3,814.65 670.07 5,946,975.66 717,907.56 70° 15' 27.890 N 148° 14' 18.984 W
~
10,120.37 85.24 50.52 8,810.06 3,833.02 693.05 5,946,994.69 717,930.00 70° 15' 28.071 N 148° 14' 18.316 W
~
10,150.43 89.57 49.25 8,811.42 3,852.37 716.01 5,947,014.68 717,952.39 70° 15' 28.261 N 148° 14' 17.648 W
10,180.53 93.01 47.70 8,810.74 3,872.31 738.53 5,947,035.27 717,974.32 70° 15' 28.457 N 148° 14' 16.992 W
10,210.89 95.44 45.00 8,808.50 3,893.21 760.44 5,947,056.79 717,995.62 70° 15' 28.663 N 148° 14' 16.355 W
10,240.09 95.13 41.98 8,805.81 3,914.30 780.45 5,947,078.45 718,015.01 70° 15' 28.870 N 148° 14' 15.773 W
10,272.25 94.86 38.11 8,803.01 3,938.82 801.05 5,947,103.55 718,034.90 70° 15' 29.111 N 148° 14' 15.173 W
10,304.23 96.49 37.21 8,799.85 3,964.01 820.50 5,947,129.29 718,053.61 70° 15' 29.359 N 148° 14' 14.608 W
10,334.40 97.82 41.33 8,796.09 3,987.18 839.44 5,947,153.00 718,071.87 70° 15' 29.587 N 148° 14' 14.056 W
10,365.42 96.49 45.75 8,792.22 4,009.49 860.64 5,947,175.90 718,092.42 70° 15' 29.806 N 148° 14' 13.440 W i
10,395.52 96.77 50.52 8,788.75 4,029.44 882.90 5,947,196.48 718,114.09 70° 15' 30.003 N 148° 14' 12.792 W
10,425.21 96.24 53.12 8,785.38 4,047.67 906.08 5,947,215.38 718,136.74 70° 15' 30.182 N 148° 14' 12.117 W',
10,457.07 96.21 57.85 8,781.93 4,065.61 932.17 5,947,234.06 718,162.30 70° 15' 30.358 N 148° 14' 11.358 W ~I,
10,485.19 97.01 62.45 8,778.69 4,079.51 956.39 5,947,248.65 718,186.11 70° 15' 30.495 N 148° 14' 10.653 W
10,517.41 96.76 67.59 8,774.82 4,093.01 985.38 5,947,262.99 718,214.69 70° 15' 30.628 N 148° 14' 9.810 W'~
10,545.63 96.48 71.99 8,771.57 4,102.69 1,011.68 5,947,273.42 718,240.70 70° 15' 30.723 N 148° 14' 9.045 W
10,574.75 96.27 77.43 8,768.33 4,110.32 1,039.58 5,947,281.85 718,268.37 70° 15' 30.798 N 148° 14' 8.233 W
~ 10,604.07 96.08 82.23 8,765.18 4,115.47 1,068.27 5,947,287.82 718,296.89 70° 15' 30.848 N 148° 14' 7.398 W
~ 10,635.35 95.81 87.59 8,761.93 4,118.23 1,099.24 5,947,291.47 718,327.78 70° 15' 30.875 N 148° 14' 6.497 W ~~
10,665.49 95.96 87.10 8,758.84 4,119.61 1,129.19 5,947,293.72 718,357.67 70° 15' 30.889 N 148° 14' 5.626 W
j 10,694.19 96.30 83.12 8,755.78 4,122.05 1,157.62 5,947,296.97 718,386.01 70° 15' 30.913 N 148° 14' 4.799 W ~I
10,724.73 96.65 78.83 8,752.33 4,126.81 1,187.58 5,947,302.59 718,415.82 70° 15' 30.960 N 148° 14' 3.927 W
i
10,766.43 96.09 73.32 8,747.70 4,136.78 1,227.79 5,947,313.72 718,455.73 70° 15' 31.058 N 148° 14' 2.757 W
t
10,797.47 96.06 69.75 8,744.42 4,146.55 1,257.06 5,947,324.33 718,484.70 70° 15' 31.154 N 148° 14' 1.905 W
10,830.21 93.50 66.11 8,741.69 4,158.81 1,287.29 5,947,337.46 718,514.56 70° 15' 31.274 N 148° 14' 1.026 W
10,863.67 91.66 63.09 8,740.18 4,173.14 1,317.48 5,947,352.66 718,544.33 70° 15' 31.415 N 148° 14' 0.147 W',;
10,895.37 92.05 61.43 8,739.16 4,187.89 1,345.52 5,947,368.21 718,571.93 70° 15' 31.560 N 148° 13' 59.332 W
10,925.75 89.85 55.45 8,738.65 4,203.78 1,371.39 5,947,384.84 718,597.33 70° 15' 31.716 N 148° 13' 58.579 W%
10,952.71 91.54 50.95 8,738.32 4,219.92 1,392.97 5,947,401.59 718,618.43 70° 15' 31.875 N 148° 13' 57.951 W'
10,988.59 92.19 45.75 8,737.16 4,243.75 1,419.75 5,947,426.18 718,644.52 70° 15' 32.109 N 148° 13' 57.171 W
11,021.67 90.25 40.97 8,736.45 4,267.79 1,442.45 5,947,450.86 718,666.51 70° 15' 32.346 N 148° 13' 56.511 W
11,052.41 89.60 35.29 8,736.49 4,291.96 1,461.43 5,947,475.57 718,684.78 70° 15' 32.583 N 148° 13' 55.959 W'~,
11,080.53 87.51 37.08 8,737.20 4,314.64 1,478.02 5,947,498.72 718,700.71 70° 15' 32.807 N 148° 13' 55.476 W
~ 11,107.13 88.80 40.86 8,738.06 4,335.31 1,494.74 5,947,519.86 718,716.83 70° 15' 33.010 N 148° 13' 54.989 W
11,138.57 89.02 46.05 8,738.66 4,358.12 1,516.35 5,947,543.28 718,737.77 70° 15' 33.234 N 148° 13' 54.360 W ~!
~ 11,166.07 90.06 50.69 8,738.88 4,376.38 1,536.90 5,947,562.13 718,757.78 70° 15' 33.414 N 148° 13' 53.762 W'
11,195.97 91.11 55.46 8,738.57 4,394.34 1,560.79 5,947,580.77 718,781.15 70° 15' 33.590 N 148° 13' 53.067 W ~
11,225.17
91.90
61.67
8,737.80
4,409.56
1,585.69
5,947,596.70
718,805.59
70° 15' 33.740 N I
148° 13' 52.343 W
11,255.11 92.08 66.87 8,736.76 4,422.54 1,612.63 5,947,610.45 718,832.15 70° 15' 33.867 N 148° 13' 51.559 W
11,285.65 91.10 72.10 8,735.92 4,433.24 1,641.21 5,947,621.97 718,860.41 70° 15' 33.973 N 148° 13' 50.727 W
11,318.83 90.40 78.91 8,735.48 4,441.53 1,673.32 5,947,631.19 718,892.26 70° 15' 34.054 N 148° 13' 49.793 W ~I
11,345.29 89.88 85.33 8,735.42 4,445.16 1,699.51 5,947,635.57 718,918.34 70° 15' 34.090 N 148° 13' 49.031 W ~,
11,374.35 90.52 90.22 8,735.31 4,446.29 1,728.54 5,947,637.53 718,947.32 70° 15' 34.101 N 148° 13' 48.186 W
11,406.93 91.32 96.53 8,734.79 4,444.37 1,761.04 5,947,636.55 718,979.86 70° 15' 34.082 N 148° 13' 47.240 W
11,435.69 93.16 102.01 8,733.67 4,439.74 1,789.40 5,947,632.75 719,008.34 70° 15' 34.036 N 148° 13' 46.415 W j
3130/2009 2:29:02PM Page 3 COMPASS 2003.16 Build 70
Survey Report -Geographic
IIVTEQ
Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 09-33 -Slot 33
Project: Prudhoe Bay ND Reference: 48:33 6/11/1985 00:00 @ 55. OOft (generic drillinc
Site: PB DS 09 MD :Reference: 48:33 6/11/198500:00 @ 55. OOft (generic drillinc
Well: 09-33 North Refe rence: True
Wellbore: 09-33A 500292136501 Survey Cal culation Method: Minimum . Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
!Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth +Nl-S +E/-W Northing Easting
(ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude
11,465.23 91.23 102.15 8,732.53 4,433.57 1,818.26 5,947,627.40 719,037.36 70° 15' 33.975 N 148° 13' 45.576 W'i
11,495.01 88.71 96.61 8,732.55 4,428.72 1,847.63 5,947,623.40 719,066.86 70° 15' 33.928 N 148° 13' 44.721 W ~I
11,526.81 87.42 90.78 8,733.62 4,426.67 1,879.33 5,947,622.27 719,098.60 70° 15' 33.907 N 148° 13' 43.799 W
11,555.05 86.99 86.25 8,735.00 4,427.40 1,907.52 5,947,623.81 719,126.76 70° 15' 33.915 N 148° 13' 42.979 W
11,596.39 90.06 90.97 8,736.07 4,428.40 1,948.81 5,947,626.00 719,168.01 70° 15' 33.924 N 148° 13' 41.777 W
11,624.63 90.43 93.94 8,735.95 4,427.19 1,977.03 5,947,625.61 719,196.24 70° 15' 33.912 N 148° 13' 40.956 W ~
11,654.69 88.62 98.68 8,736.20 4,423.89 2,006.89 5,947,623.17 719,226.19 70° 15' 33.880 N 148° 13' 40.087 W
11,682.79 88.59 103.69 8,736.88 4,418.44 2,034.44 5,947,618.52 719,253.88 70° 15' 33.826 N 148° 13' 39.286 W
11,712.05 89.02 108.82 8,737.49 4,410.25 2,062.52 5,947,611.15 719,282.18 70° 15' 33.746 N 148° 13' 38.469 W
11,743.99 89.05 120.22 8,738.03 4,397.02 2,091.52 5,947,598.76 719,311.56 70° 15' 33.615 N 148° 13' 37.625 W ii
11,773.13 89.51 124.53 8,738.40 4,381.42 2,116.13 5,947,583.88 719,336.60 70° 15' 33.462 N 148° 13' 36.909 W ~~,
11,803.41 89.66 128.54 8,738.62 4,363.40 2,140.45 5,947,566.56 719,361.43 70° 15' 33.285 N 148° 13' 36.202 W ~
11,832.65 88.93 131.96 8,738.98 4,344.51 2,162.76 5,947,548.33 719,384.28 70° 15' 33.099 N 148° 13' 35.553 W ~
11,863.57 87.21 136.81 8,740.02 4,322.91 2,184.84 5,947,527.37 719,406.97 70° 15' 32.886 N 148° 13' 34.911 W
11,892.75 87.88 139.66 8,741.27 4,301.16 2,204.26 5,947,506.19 719,427.00 70° 15' 32.672 N 148° 13' 34.346 W
11,922.87 89.11 137.26 8,742.06 4,278.63 2,224.22 5,947,484.25 719,447.61 70° 15' 32.451 N 148° 13' 33.765 W ~
11,953.23 89.79 134.99 8,742.35 4,256.75 2,245.26 5,947,462.98 719,469.27 70° 15' 32.235 N 148° 13' 33.153 W
11,982.45 89.51 132.90 8,742.53 4,236.47 2,266.30 5,947,443.32 719,490.88 70° 15' 32.036 N 148° 13' 32.541 W ii
12,011.43 87.27 130.61 8,743.34 4,217.18 2,287.91 5,947,424.66 719,513.04 70° 15' 31.846 N 148° 13' 31.913 W I,
12,044.91 86.81 126.00 8,745.07 4,196.46 2,314.14 5,947,404.71 719,539.85 70° 15' 31.642 N 148° 13' 31.150 W
12,073.53 86.66 125.85 8,746.70 4,179.70 2,337.27 5,947,388.62 719,563.46 70° 15' 31.477 N 148° 13' 30.477 W
12,104.59 85.39 121.44 8,748.86 4,162.53 2,363.06 5,947,372.21 719,589.73 70° 15' 31.308 N 148° 13' 29.727 W ~
12,135.97 84.64 119.49 8,751.58 4,146.68 2,390.01 5,947,357.14 719,617.12 70° 15' 31.152 N 148° 13' 28.943 W
12,164.27 84.13 118.62 8,754.35 4,133.01 2,414.62 5,947,344.18 719,642.12 70° 15' 31.018 N 148° 13' 28.227 W
12,193.51 83.94 116.80 8,757.39 4,119.48 2,440.37 5,947,331.41 719,668.25 70° 15' 30.885 N 148° 13' 27.478 W
12,231.01 83.72 113.86 8,761.42 4,103.54 2,474.06 5,947,316.44 719,702.39 70° 15' 30.728 N 148° 13' 26.498 W
12,260.13 84.27 110.68 8,764.47 4,092.56 2,500.86 5,947,306.24 719,729.49 70° 15' 30.620 N 148° 13' 25.718 W
12,289.17 85.16 107.81 8,767.15 4,083.03 2,528.16 5,947,297.51 719,757.05 70° 15' 30.526 N 148° 13' 24.924 W i,
~ 12,322.67 86.06 104.77 8,769.71 4,073.67 2,560.22 5,947,289.07 719,789.36 70° 15' 30.434 N 148° 13' 23.992 W li
12,355.47 86.55 100.97 8,771.83 4,066.38 2,592.12 5,947,282.70 719,821.46 70° 15' 30.362 N 148° 13' 23.064 W',
12,386.69 85.76 99.08 8,773.92 4,060.95 2,622.79 5,947,278.17 719,852.27 70° 15' 30.308 N 148° 13' 22.171 W'~,
12,416.69 83.60 98.05 8,776.70 4,056.50 2,652.33 5,947,274.57 719,881.92 70° 15' 30.265 N 148° 13' 21.312 W
12,434.51 83.60 97.73 8,778.69 4,054.07 2,669.87 5,947,272.65 719,899.53 70° 15' 30.241 N 148° 13' 20.802 W
12,469.35 81.33 98.98 8,783.26 4,049.06 2,704.04 5,947,268.62 719,933.82 70° 15' 30.191 N 148° 13' 19.808 W
~ 12,497.33 78.75 99.76 8,788.09 4,044.57 2,731.23 5,947,264.92 719,961.13 70° 15' 30.147 N 148° 13' 19.017 W
12,530.53 75.92 101.05 8,795.37 4,038.72 2,763.08 5,947,259.99 719,993.14 70° 15' 30.089 N 148° 13' 18.090 W j
12,557.21 73.36 101.95 8,802.44 4,033.60 2,788.29 5,947,255.59 720,018.48 70° 15' 30.039 N 148° 13' 17.356 W''i
j 12,594.43 72.19 98.06 8,813.47 4,027.42 2,823.29 5,947,250.43 720,053.65 70° 15' 29.978 N 148° 13' 16.338 W ~~
12,622.67 71.54 96.15 8,822.26 4,024.10 2,849.92 5,947,247.88 720,080.36 70° 15' 29.945 N 148° 13' 15.563 W ~
12,657.83 71.04 92.41 8,833.54 4,021.61 2,883.12 5,947,246.35 720,113.62 70° 15' 29.921 N 148° 13' 14.598 W
12,688.53 71.47 88.47 8,843.41 4,021.39 2,912.19 5,947,246.97 720,142.67 70° 15' 29.918 N 148° 13' 13.752 W i
12,716.81 72.09 88.12 8,852.25 4,022.19 2,939.04 5,947,248.54 720,169.49 70° 15' 29.926 N 148° 13' 12.971 W
12,745.39 74.71 90.87 8,860.42 4,022.43 2,966.42 5,947,249.57 720,196.85 70° 15' 29.928 N 148° 13' 12.174 W
12,776.43 76.51 95.29 8,868.13 4,020.81 2,996.43 5,947,248.81 720,226.90 70° 15' 29.912 N 148° 13' 11.301 W I~
12,805.89 77.91 100.62 8,874.66 4,016.83 3,024.87 5,947,245.66 720,255.44 70° 15' 29.873 N 148° 13' 10.474 W
12,833.31 79.01 105.41 8,880.15 4,010.78 3,051.04 5,947,240.36 720,281.77 70° 15' 29.813 N 148° 13' 9.712 W'
~' 12,863.53 78.89 110.56 8,885.94 4,001.62 3,079.24 5,947,232.03 720,310.22 70° 15' 29.723 N 148° 13' 8.892 W
12,896.09 76.07 113.01 8,893.00 3,989.83 3,108.75 5,947,221.09 720,340.06 70° 15' 29.607 N 148° 13' 8.034 W
12,927.97 74.84 118.05 8,901.01 3,976.54 3,136.59 5,947,208.61 720,368.26 70° 15' 29.476 N 148° 13' 7.224 W
12,964.61 77.18 122.90 8,909.87 3,958.51 3,167.21 5,947,191.47 720,399.39 70° 15' 29.299 N 148° 13' 6.333 W
12,993.67 76.00 127.31 8,916.62 3,942.26 3,190.33 5,947,175.90 720,422.97 70° 15' 29.139 N 148° 13' 5.661 W
13,022.47 75.31 133.29 8,923.76 3,924.23 3,211.60 5,947,158.48 720,444.75 70° 15' 28.962 N 148° 13' 5.042 W
13,054.29 74.41 136.97 8,932.07 3,902.46 3,233.27 5,947,137.36 720,467.04 70° 15' 28.747 N 148° 13' 4.412 W
13,088.57 70.95 138.65 8,942.28 3,878.22 3,255.25 5,947,113.76 720,489.70 70° 15' 28.509 N 148° 13' 3.773 W
13,116.05 66.90 140.27 8,952.16 3,858.75 3,271.91 5,947,094.77 720,506.93 70° 15' 28.317 N 148° 13' 3.288 W
3/30/2009 2:29:02PM Page 4 COMPASS 2003.16 Build 70
swiaR ~
~
Its Survey Report -Geographic bR
tNTEQ
Company: North America -ALASKA - BP L.ocaf Co-ordinate Reference: Well 09-33 -Slot 33
Project: Prudhoe Bay TVD Reference: 48:33 6/11/1985 00:00 @ 55.OOft (generic drillinc
Site: PB DS 09 MD Reference: 48:33 6/11/1985 00:00 @ 55.OOft (generic drillinc
Well: 09-33 North Reference: True
Weltbore: 09-33A 500292136501 Survey Calculation Method: Minimum Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
;.Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting
(ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude
13,163.00 66.90 140.27 8,970.58 3,825.53 3,299.52 5,947,062.37 720,535.47 70° 15' 27.990 N 148° 13' 2.486 W
TD - 2.875 _~
3/30/2009 2:29:02PM Page 5 COMPASS 2003.16 Build 70
swsa
Survey Report -Geographic
~
bP
1~ITEQ
Company: North America -ALASKA - BP Locaf Co-ordinate Reference: Well 09-33 -Slot 33
Project: Prudhoe Bay TVD Reference: 48:33 6111!1985.00:00 @ 55.OOft (generic drillinc
Site: PB DS 09 MD Reference: 48:33 611 111 985 00:00 @ 55.OOft (generiadrillinc
Well: 09-33 North Reference: True
Wellbore: 09-33A 500292136501 Survey Calculation Method: Minimum Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
Targets
Target Name
- hit/miss target Dip Angle Dip Dir. TVD +N/S +E!-W. Northing Easting
-Shape (°) (°) (ft) (ft) (ft) :' (ft) lft) Latitude Longitude
09-33A Polygon 0.00 0.00 55.00 3,897.92 569.87 5,947,056.00 717,805.00
- actual wellpath mi sses target center by 8666.68ft at 9900.OOft MD (8719.38 TVD, 3698.10 N, 564.82 E)
- Polygon
Point 1 55.00 3,897.92 569.87 5,947,056.00 717,805.00
Point 2 55.00 4,037.74 612.92 5,947,197.00 717,844.00
Point 3 55.00 4,567.94 1,446.60 5,947,751.00 718,662.00
Point 4 55.00 4,686.11 2,032.28 5,947,886.00 719,244.00
Point 5 55.00 4,278.59 2,875.91 5,947,503.00 720,099.00
Point 6 55.00 4,195.10 3,099.61 5,947,426.00 720,325.00
Point 7 55.00 4,085.12 3,374.56 5,947,324.00 720,603.00
Point 8 55.00 3,879.62 3,561.72 5,947,124.00 720,796.00
Point 9 55.00 3,685.47 3,356.03 5,946,924.00 720,596.00
Point 10 55.00 3,795.25 3,088.07 5,947,026.00 720,325.00
Point 11 55.00 3,878.74 2,864.38 5,947,103.00 720,099.00
Point 12 55.00 4,286.26 2,020.74 5,947,486.00 719,244.00
Point 13 55.00 4,168.09 1,435.06 5,947,351.00 718,662.00
Point 14 55.00 3,637.89 601.38 5,946,797.00 717,844.00
Point 15 55.00 3,498.07 558.33 5,946,656.00 717,805.00
09-33A Fault 2 0.00 0.00 55.00 3,765.54 1,690.57 5,946,956.00 718,929.00
- actual wellpath mi sses target center by 8699.37ft at 11011.89ft MD (8736.54 TVD, 4260.48 N, 1435.95 E)
- Polygon
Point 1 55.00 3,765.54 1,690.57 5,946,956.00 718,929.00
Point 2 55.00 4,378.64 1,558.19 5,947,565.00 718,779.00
Point 3 55.00 4,976.31 1,440.37 5,948,159.00 718,644.00
Point4 55.00 5,860.01 1,568.92 5,949,046.00 718,747.00
Point 5 55.00 4,976.31 1,440.37 5,948,159.00 718,644.00
Point 6 55.00 4,378.64 1,558.19 5,947,565.00 718,779.00
09-33A Fault 1 0.00 0.00 55.00 3,076.57 1,123.44 5,946,251.00 718,382.00
- actual wellpath misses target center by 8704.58ft at 9900.OOft MD (8719.38 TVD, 3698.10 N, 564.82 E)
- Polygon
Point 1 55.00 3,076.57 1,123.44 5,946,251.00 718,382.00
Point 2 55.00 3,894.54 790.87 5,947,059.00 718,026.00
Point 3 55.00 3,960.26 697.73 5,947,122.00 717,931.00
Point 4 55.00 4,020.95 501.39 5,947,177.00 717,733.00
Point 5 55.00 4,517.94 301.63 5,947,668.00 717,519.00
Point 6 55.00 4,020.95 501.39 5,947,177.00 717,733.00
Point 7 55.00 3,960.26 697.73 5,947,122.00 717,931.00
Point 8 55.00 3,894.54 790.87 5,947,059.00 718,026.00
70° 15' 28.709 N 148° 14' 21.899 W
70° 15' 27.406 N 148° 13' 49.295 W
70° 15' 20.631 N 148° 14' 5.798 W
09-33A Target 1 0.00 0.00 8,719.00 3,697.99 564.10 5,946,856.00 717,805.00 70° 15' 26.743 N 148° 14' 22.068 W
- actual wellpath hits target center
- Point
09-33A Target 3 0.00 0.00 8,755.00 4,368.02 1,440.83 5,947,551.00 718,662.00 70° 15' 33.332 N 148° 13' 56.558 W
- actual wellpath misses target center by 64.62ft at 11099.20ft MD (8737.86 TVD, 4329.27 N, 1489.61 E)
- Point
09-33A Target 6 0.00 0.00 8,802.00 3,995.17 3,093.84 5,947,226.00 720,325.00 70° 15' 29.660 N 148° 13' 8.467 W
- actual wellpath misses target center by 85.45ft at 12863.01ft MD (8885.84 TVD, 4001.80 N, 3078.76 E)
- Point
09-33A Target 4 0.00 0.00 8,740.00 4,486.18 2,026.51 5,947,686.00 719,244.00 70° 15' 34.492 N 148° 13' 39.516 W
- actual wellpath misses target center by 64.78ft at 11661.94ft MD (8736.37 TVD, 4422.71 N, 2014.05 E)
- Point
09-33A Target 2 0.00 0.00 8,813.00 3,837.82 607.15 5,946,997.00 717,844.00 70° 15' 28.118 N 148° 14' 20.815 W
- actual wellpath misses target center by 57.66ft at 10055.10ft MD (8800.08 TVD, 3793.72 N, 641.99 E)
- Paint
09-33A Target 7 0.00 0.00 8,923.00 3,885.39 3,361.80 5,947,124.00 720,596.00 70° 15' 28.579 N 148° 13' 0.673 W
- actual wellpath misses target center b~9_8,18ft at 13116.05ft MD (8952,16 TVD, 3858.75 N, 3271.91 E)
3/30/2009 2:29:02PM Page 6 COMPASS 2003.16 Build 70
Survey Report -Geographic
flVTEQ
Company: North America -ALASKA - BP Local Go-ordinate Reference: Well 09-33 -Slot 33
Project: . Prudhoe Bay TVD Reference: 48:33 6/11 /1985 00:00 @ 55. OOft (generic drillinc
Site: PB DS 09 MD Reference: 48:33 6/11/1985 00:00 @ 55. OOft {generic drillinc
Well: 09-33 North Reference: True
Wellbore: 09-33A 500292136501 Survey Calculation Method: Minimum Curvature
Design: 09-33A Database: EDM .16 - Anc Prod - WH24P
-Point
09-33A Fault 3 0.00 0.00 55.00 2,679.04 2,799.75 5,945,902.00 720,069.00 70° 15' 16.717 N 148° 13' 17.038 W
- actual wellpath misses target center by 8828.12ft at 12193.52ft MD (8757.39 TVD, 4119.48 N, 2440.38 E)
- Polygon
Point 1 55.00 2,679.04 2,799.75 5,945,902.00 720,069.00
Point 2 55.00 3,790.60 2,451.64 5,947,003.00 719,689.00
Point 3 55.00 4,299.00 2,411.29 5,947,510.00 719,634.00
Point 4 55.00 6,362.05 2,026.61 5,949,561.00 719,190.00
Point 5 55.00 4,299.00 2,411.29 5,947,510.00 719,634.00
Point 6 55.00 3,790.60 2,451.64 5,947,003.00 719,689.00
09-33A Target 5 0.00 0.00 8,765.00 4,078.66 2,870.15 5,947,303.00 720,099.00 70° 15' 30.482 N 148° 13' 14.974 W
- actual wellpath misses target center by 81.50ft at 12617.50ft MD (8820.62 TVD, 4024.64 N, 2845.05 E)
- Point
-
Casing Points __-- --
--
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(n) (ft) Name ("> (")
13,163.00 8,970.58 2.875 2-7/8 4-1/8
Design Annotations
Measured Vertical Local Coo rdinates
Depth Depth +N/-S +E/-W
(n) Ift) (ft) (ft} comment
9,900.00 8,719.38 3,698.10 564.82 TIP
9,903.00 8,722.05 3,699.45 565.05 KOP
13,163.00 8,970.58 3,825.53 3,299.52 TD
Checked By: Approved By: Date:
3/30/2009 2:29:02PM Page 7 COMPASS 2003.16 Build 70
TREE = 3.1 CR McV
WELLHEAD = McEVOY
AC, UATOR = OTIS
KB. ELEV = 55'
BF. ELEV =
KOP = 3300'
Max Angle = 98° @ 10334'
Datum MD = 12726'
Datum ND = 8800' SS
DRLG DRAFT
13-3/8" CSG, 72#, L-80, ID = 12.347" ~-j 2522'
Minimum ID =1.875" @ 9465'
BTT Plug Holder Bushing
TOP OF 7" LNR )~ 9472'
~ 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" ~~ 9525'
9-5/8" CSG, 47#, L-80, ID = 8.681"
PERFORATION SUMMARY
REF LOG: SWS MCNL/GR/CCL OF 04/01/09
ANGLE AT TOP PERF: 89° @ 11650'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
1.56 6 11650 - 12100 O 04/03/09
1.56 6 12600 - 12625 O 04/03/09
1.56 6 12670 - 12685 O 04/03/09
1.56 6 12770 - 12815 O 04/03/09
1.56 6 12920 - 12960 O 04!03109
1.56 6 13015 - 13090 O 04/03/09
PBTD 10277'
7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10316'
09-33A
I I
lp~ ~ Z
/ ` ~''t
~~^^-
SA NOTES: ***CHROMETUBING & 2-3/8" CHROME
LINEN ** WELL ANGLE> 70° @ 12658' 8 >90° @
11286'
2081' ~ 3-1/2" OTIS TRSV SSSV NIP, ID = 2.813"
GAS LIFT' MANDRELS
ST MD ND DEV NPE VLV LATCH PORT DATE
1 3021 3020 5 MMG DMY RK 0 10/14/08
2 4745 4556 36 MMG DMY RK 0 10/14/08
3 5821 5410 37 MMG DMY RK 0 10/14/08
4 6380 5855 37 MMG DMY RK 0 09/30/95
5 6904 6273 38 MMG DMY RK 0 09/29/91
6 7397 6662 37 MMG DMY RK 0 09/30/95
7 8015 7156 36 MMG DMY RK 0 09/29/91
8 8693 7711 37 MMG DMY RK 0 05/31/92
7 i 1,11~1G DMY RK 0 10/10/94
9I 39T I-~ 3-1/2" BAKER LOC SEAL ASSY
9398' 7" X 3-1/2" BAKER MODEL D PKR
9455' Top of 2-3/8" Liner
9465 Plug bushing, 1.875" ID
9510' 3-1 /2" OTIS XN NIP, ID = 2.75"
9525' 3-1/2"BAKERMULESHOE
9522' ELMD l7 LOGGED 10/09/91
9909' Cement Ramp Window
13.125' PBTD
2-3/8". 4.7#, 13 CR. STL Liner, TD 13163'
10184' )~ FISH - CA-RD-RK (LOST 10/10/94)
DATE REV BY COMMENTS DATE REV BY COMMENTS
07!05/85 ORIGINAL COMPLETION
09129/91 LAST WORKOVER
04/04/09 NORDIC1 CTD SIDETRACK (09-33A)
E
PRUDHOE BAY UNIT
WELL: 09-33A
PERMfT No: 208-156
API No: 50-029-21365-01
SEC 2 T10N, R15E, 425.07' FEL & 4971.1' FNL
BP Exploration (Alaska)
~%~
BAKER
11Y~iNES
~i~l ~~
7260 Homer Drive
Anchorage, AK 99518
•
To Whom It May Concern: May 15, 2009
Please find enclosed directional survey data for the following wells:
09-33A
18-26B
03-14B 03-14BL1
G31BPB1 G31B
Enclosed for each well is:
tea copies of directional survey reports
1 ea 3.5" floppy diskette containing electronic survey files
Please sign and return one copy of this transmittal form to:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
to acknowledge receipt of this data.
RECEIVED BY: (/ ,State of Alaska AOGCC
DATE: ~ ,~ ~ ~ ~
Cc: State of Alaska, AOGCC
04/27/09
~[r~l'~~~6~~~
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Woll _Inh ft
NO.
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnkelt
333 West 7th Ave, Suite 100
Anchorage, AK 99501
~ n.
F-45A AP3O-00033 RST GRAVEL PACK LOG 04/17/09 1
P2-07 AVYO-00023 PRODUCTION PROFILE
^ 04/05/09 1 1
11-12 AYOO-00019 USIT L -
~ 04/19/09 1 1
X-05 AYTO-00010 USIT Qj~ 04/03/09 1 1
X-01 AZ4D-00012 PRODUCTION PROFILE - (' 03/18/09 1 1
Z-21A AP3O-00022 RST 02/24/09 1 1
E-34L1 AYTU-00010 OH LDWG EDIT (IFLEX) 02/08/09 1 1
L-106 22026 OH LDWG EDIT (REDO) 01/10/02 1
MPF-96 09AKA0039 OH MWD/LWD EDIT ~ 02/23/09 2 1
F-19A 40018664 OH MWD/LWD EDIT - 02/14/09 2 1
F-18A 09AKA0034 OH MWD/LWD EDIT 03/16/09 2 1
06-23C 12066550 MCNL ~ 09/14/08 1 1
03-14B BIJJ-00005 MCNL 03/30/09 1 1
11-18 BOCV-00006 RST 1 03/02/09 1 1
07-206 AWJB-00028 MCNL ~ 02/27/09 1 1
MPB-22A AXBD-00005 CH EDIT PDC-GR (CBL) 12/23/08 1
07-29D AXBD-00016 MCNL ~ (~ 03/17/09 1 1
09-33A AWJI-00019 MCNL - 04/01/09 1 1
• ~~.~~.-.~.-.........-.-.+..~ .,w...r ~ u ~ .a~.ann.v ea~ai l1G1 Vf11Y11YV VIYG l.Vr7 ~r~a.n ~ V:
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 99503-2838
ATTN: Beth
Received by:
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AI.ASSA OIL AZITD GA$
CO1~T5ER~ATIOI~T CO1rIIrII55I0IK
John McMullen
Engineering Team Leader
BP Exploration Alaska Inc.
PO Box 196612
Anchorage, AK 99519-6612
SARAH PALlN, 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 Oil Pool, PBU 09-33A
BP Exploration Alaska Inc.
Permit No: 208-156
Surface Location: 1704' FSL, 1023' FEL, SEC. 02, T10N, R15E, UM
Bottomhole Location: 310' FSL, 2342' FWL, SEC. 36, T11N, R15E, UM
Dear Mr. McMullen:
Enclosed is the approved application for permit to drill the above referenced
development well.
This permit to drill does not exempt you from obtaining additional permits or
an approval required by law from other governmental agencies and does not
authorize conducting drilling operations until all other required permits and
approvals have been issued. In addition, the Commission reserves the right to
withdraw the permit iri 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 g day of October, 2008
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
~~ STATE OF ALASKA
- ; ~°'~'~ ~ ALASK~ AND GAS CONSERVATION COMMISSI C
~n~ PERMIT TO DRILL
20 AAC 25.005
/~Y
1 a. Type of work
Drill ®Redrill
Re-Entry 1 b. Current Well Class ExQloratorv ~
~ Service
^ Stratigraphic Test ®Development Oil Development Gas
MuRiple Zone
Single Zone 1 c. S eCify if well is proposed for:
~Coalbed Methane ^ Gas Hydrates
^ Shale Gas
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Bond: Blanket ^ Single Well
Bond No. 6194193 11. Well Name and Number:
PBU 09.33A
3. Address:
P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth:
MD 13220' TVD 8869'ss 12. Field /Pool(s):
Prudhoe Bay Field / Prudhoe Bay
4a. Location of Well (Governmental Section):
Surface:
'
' 7. Property Designation:
028324 Pool
FEL, SEC. 02, T10N, R15E, UM
1704
FSL, 1023
Top of Productive Horizon:
R15E
UM
457' FEL
SEC. 35
T11 N
117' FSL
8. Land Use Permit:
13. Approximate Spud Date:
February 15, 2009
,
,
,
,
,
Total Depth:
310' FSL, 2342' FWL, SEC. 36, T11 N, R15E, UM 9. Acres in Property:
2560 14. Distance to Nearest Property:
16,560'
4b. Location of Well (State Base Plane Coordinates):
Surface: x-717348 -5943143 Zone-ASP4 10. KB Elevation
(Hei ht above GL): 55' feet 15. Distance to Nearest Well Within Pool:.
513'
16. Deviated Wells: Kickoff Depth: 9900 feet
Maximum Hole A ~: 95 d Tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole: 3300 Surface: 2420
Hole Casin Wei ht Grade Cou lin Len MD TVD MD TVD includin sta a data
,
1 g, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrilt and Re-entry Operations)
Total Depth MD (ft):
10320' Total Depth TVD (ft): Plugs (measured):
None Effective Depth MD (ft):
10277' Effective Depth TVD (ft):
9057' Junk (measured):
10184'
asi Len h Size Cement Volume MD TVD
Conductor /Structural "
Surface
Intermediate
Liner -
Perforation Depth MD (ft): 9888' -10224' Perforation Depth TVD (ft): 8709' - 9009'
20. Attachments ^ Filing Fee, $100 ®BOP Sketch
^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis
^ Seabed Report ®Drilling Fluid Program ~ 20 AAC 25.050 Requirements
21. Verbal A oval: Commission Representative: Date:
22. I hereby certify that the fo ~ going i .rue and correct.
Printed Name n i' n/
Si nat Contact Sean McLauphGn, 564-4387
Title En ineerin Team Leader
vreParea ay Man,dNumber:
Phone 564-4711 Date ~~ / d Terrie Hubble, 564-4628
C
Perini o Drill
~ -15,6 API Number:
iS0-029-2131ii5-01-00 Permit royal See cover letter for
Conditior~ of Approval: ry
If box is checked, well may not be used to explore for, test, or produce coalbed methane,. gas hydrates, or gas contained shales: lJ
~~~ Samples Req'd: ^ Yes C~lo Mud Log Req'd: ^ Yes Cl~lo
~~~~ ~ ~(~ '~S~ Cs-~ ~ `~ HrS Measures: O~Yes ^ No Directional Survey Req'd: Ce~'Sfes ^ No
Other.
Q ~ ~ APPROVED BY THE COMMISSION
Date COMMISSIONER
Form 10-401 Revised 12/2005
.~ _
7 } ~~
6 L.
auoma m uupucaie
• •
by
To: Tom Maunder, Petroleum Engineer
Alaska Oil & Gas Conservation Commission
From: Sean McLaughlin, CTD Engineer
Date: September 29, 2008
Re: Prudhoe Bay 09-33A Permit to Drill Request
The sidetrack, 09-33A, is scheduled to be drilled by Nordic 1 around February 15, 2009. The plan calls for a
slimhole lateral with a solid liner and 500 ft of perforations.
1.
2.
3.
4.
5.
6.
7.
8.
9.
Pre-Rig Work: The pre CTD work is slated to begin on November 15, 2008.
S Dummy GLV's
S Drift to 10000' with 2.70" x 10' Dummy WS
S Caliper Tubing
W MIT-IA to 3000 psi
C Lay in 17# kick off plug from PBTD, wash down to the tubing tail (35 bbl of cement)
W AC-LDS; AC-PPPOT-T
W PT tree (MV,SV,WV) ~ `~~~
O Bleed gas lift and production flowlines down to zero and blind flange
O Remove S-Riser, Remove wellhouse, level pad ,~
Rig Work:
1. MIRU and test BOPE to 250 psi low and 3500 psi high
2. Mill 2.74" cement ramp win ow a an
3. Drill Build: 3" OH, 185' (40 deg/100 planned)
4. Drill Lateral: 3" OH, 3135' horizontal (12 deg/100 planned)
5. Run 2 3/8" solid chrome liner leaving TOL at 9,450'
6. Pump primary cement job to TOL (15 bbls of cement)
7. Run CO assembly
8. Run MCNUGR/CCL log
9. Test liner lap to 2000 psi.
10. Perforate, planned 500ft.
11. Freeze protect well, Set BPV, RDMO
Post-Rig Work
1. Install GLV
2. Install well house. Hook up flow line.
~ ~~~ ~~ ~
Mud Program:
• Well kill: 8.6 ppg brine
• Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling.
Disposal:
• All drilling and completion fluids and all other Class II wastes will go to Grind & Inject.
• All Class I wastes will go to Pad 3 for disposal.
Hole size: 3"
Casing Program:
• 2 3/8", 4.7# ,Chrome, STL connection Solid liner - 9,450' to TD
• A minimum of 15 bbls 15.8 ppg cement will be used for liner cementing.
• TOC planned at 9,450 ft (TOL).
Well Control:
• BOP diagram is attached.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi.
• The annular preventer will be tested to 250 psi and 2500 psi.
Directional
• See attached directional plan. Max. planned hole angle is 95 deg.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property - 16560 ft
• Distance to nearest well within pool - 513' ft to 09-42
Anticollision Summary
• 04-04: 55' ctr-ctr, Status: P&A'd
• 04-04A: 70' ctr-ctr, Status: P&A'd
• 09-07A: 641' ctr-ctr, Status: Active well, fails AC at window, 09-33A will be drilled away from this
wellbore.
• 09-34A: 529' ctr-ctr, Status: Plug in tubing tail while evaluating pert options.
Logging
• MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section.
• A cased hole GR/CCL/CNL log will be run.
Hazards
• The maximum recorded H2S level on DS 09 is 1200 ppm on 09-29 (7/31/08)
• Lost circulation risk is high.
Reservoir Pressure
• Res. press. is estimated to be 3,300 psi at 8,800'ss (7.2 ppg EMW).
Maximum surface pressure with gas (0.10 psi/ft) to surface is 2420 psi.
Sean McLaughlin
CTD Drilling Engineer
564-4387
CC: Well File
Sondra Stewman/Terrie Hubble
TREE = Mc EV OY
WELLHEAD = McEVOY
ACTUATOR = OTIS
KB. ~EI.EV = 55'
BF. ELEV =
KOP = 3300'
Max Angle = 38 @ 8800'
Datum MD = 10052'
Datum TVD = 8800' SS
13-3/8" CSG, 72#, L-80, ID = 12.347"
Minimum ID = 2.75" @ 9510'
3-1 /2" OTIS XN NIPPLE
O ~ -3 3 SAFEI~TE3: """ 3-1/2 " CHROM E TBG'*"
2081' 3-1/2" OTIS TRSV SSSV NIP, ID = 2.813"
GAS LIFT MANDRELS
ST MD TV D DEV TYPE V LV LATCH PORT DATE
1 3021 3020 5 MMG RK
2 4745 4556 36 MMG RK
3 5821 5410 37 MMG RK
4 6380 5855 37 MMG RK
5 6904 6273 38 MMG RK
6 7397 6662 37 MMG RK
7 8015 7156 36 MMG RK
8 8693 7711 37 MMG RK
9 9310 8207 33 MMG RK
9397' I-j3-1/2"BAKERLOC SEALASSY
9398' 7" X 3-1/2" BAKER MODEL D PKR
TOP OF 7" LNR H 9472'
II 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" I-j 9525'
9510' I-I3-1/2" OTIS XN NIP, ID = 2.75"
9525' -~3-1/2" BAKER MULESHOE
9522' ELMD TT LOGGED 10/09/91
9-5i8" CSG, 47#, L-80, ID = 8.681" ~ 9781'
PERFORATION SUMMARY
REF LOG: BRCS ON 07/01/85
ANGLE AT TOP PERF: 27 @ 10080'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
2" 6 10080 - 10092 O 05/23/05
3-1/8" 4 10151 - 10159 S 10/11/91
3-1/8" 4 10166 - 10192 S 10/11/91
2-5/8" 4 10203 - 10224 O 11/10/91
2-1/8" 6 9888 - 9893 O 04/18/95
2-1/8" 6 9898 - 9908 O 04/18/95
2-1/8" 6 9920 - 9940 O 04/11/94
PBTD
7" LNR, 29#, L-80, .0371 bpf, ID = 6.184"
10184' H FISH - CA-RD-RK (LOST 10/10/94)
1o27r
10316'
DATE REV BY COMMENTS DATE REV BY COMMENTS
07/05/85 ORIGINAL COMPLETION 05/15/07 RDW/PAG WANER SFTY NOTE DELETED
09/29191 LAST WORKOVER
10/07/01 RN/TP CORRECTIONS
02/07/03 JMP/KK WANB2 SAFETY NOTE
05/23/05 WJH/PJC PERF
12/21/05 COM/PA WANERSAFETY NOTE
PRUDHOE BAY UNff
WELL: ~9-33
PERMfT No: 1851110
API No: 50-029-21365-00
SEC 2 T10N, R15E, 425.07' F~ & 4971.1' FNL
BP Exploration (Alaska)
TREE = Mc EV OY
WELLHEAD = McEVOY
ACTUATOR= OTIS
KB.•ELEV = 55'
BF. ELEV =
KOP = 3300'
Max Angle = 38 @ 8800'
Datum MD = 10052'
Datum TV D = 8800' SS
09-33a
Proposed CTD sidetrack SAFE~TES: **" 3-112 " CHROM ETBG ***
I
13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2522'
Minimum ID = 2.75" @ 9510'
OF 7" LNR I-i 9472'
II 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" I-I 9525'
9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 9781'
PERFORATION SUMMARY
REF LOG: BHCS ON 07/01 /85
ANGLE AT TOP PERF: 27 @ 10080'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
2" 6 10080 - 10092 O 05/23/05
3-1/8" 4 10151 - 10159 S 10/11/91
3-118" 4 10166 - 10192 S 10/11/91
2-5/8" 4 10203 - 10224 O 11/10/91
2-1/8" 6 9888 - 9893 O 04/18/95
2-1/8" 6 9898 - 9908 O 04/18/95
2-1/8" 6 9920 - 9940 O 04/11/94
PBTD
7" LNR, 29#, L-80, .0371 bpf, ID = 6.184"
10277'
10316'
3-1/2" OTIS TRSV SSSV NIP, ID = 2.813"
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
1 3021 3020 5 MMG RK
2 4745 4556 36 MMG RK
3 5821 5410 37 MMG RK
4 6380 5855 37 MMG RK
5 6904 6273 38 MMG RK
6 7397 6662 37 MMG RK
7 8015 7156 36 MMG RK
8 8693 7711 37 MMG RK
9 9310 8207 33 MMG RK
9397' -j 3-1 /2" BAKER LOC SEAL ASSY
9398' 7" X 3-1/2" BAKER MODEL D PKR
9450' Top of 2-3l8" Liner
9510' 3-1/2" OTIS XN NIP, ID = 2.75"
9525' -t3-1/2"BAKERMULESHOE I
9522' E1MD TT LOGGED 10/09/91
9900' I-{Cerr,ent Ramp Window
I 2-3/8" 13 CR liner
DATE REV BY COMMENTS DATE REV BY COMMENTS
07/05/85 ORIGINAL COMPLETION 05/15/07 RDW/PAG WANERSFTY NOTE DELETED
09/29/91 LAST WORKOVER
10/07/01 RN/TP CORRECTIONS
02/07/03 JMP/KK WANER SAFETY NOTE
05/23/05 WJH/PJC PERF
12/21/05 COM/PA WANERSAFETY NOTE
I 13220' I
FISH - CA-RD-RK (LOST 10/10/94)
PRUDHOE BAY UNfr
WELL: X09-33
PERMIT No: 1851110
API No: 50-029-21365-00
SEC 2 T10N, R15E, 425.07' FEL & 4971.1' FNL
BP Exploration (Alaska)
by « BP Alaska
Baker Hughes INTEQ Planning Report
INTEQ
Company: BP Amoco Date: 9/26!2008 Time: 14:53:33 Page: 1
Field: Prudhoe Bay Co-ordinate(NE)Reference: W ell: 09-33, True North ~
Site: PB DS 09 Vertical(TVD) Reference: 48 :33 6/1 1/1985 00:00 55.0
Well: 09-33 Section (VS}Reference: W ell (O.OON,O.OOE,85.OOAzi)
Weilpath: Ptan 4, 09-33A
- Survey,Calculation Method: Minimum Curvature
. --- Db: Sybase
-
!, Field: Prudhoe Bay - i
~,
I North Slope 'i
UNITED STATES
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
-Site: PB DS 09 - --- ,
-_-- _ -___~
! TR-10-15
UNITED STATES :North Slope
Site Position: Northing: 5940909. 88 ft Latitude: 70 14 28.451 N ~
~
', From: Map Easting: 717218. 90 ft Longitude: 148 14 44.098 W ~
'Position Uncertainty: 0.00 ft
I North Reference: True !~
I Ground Level: 0.00 ft Grid Convergence: 1.65 deg
Well: 09-33 Slot Name: 33
09-33
Well Position: +N/-S 2229.03 ft Northing: 5943143. 45 ft Latitude: 70 14 50.374 N ~i
I, +E/-W 193.23 ft Easting : 717347. 81 ft Longitude: 148 14 38.479 W
Position Uncertainty: 0.00 ft
! Wellpath: Plan 4, 09-33A Drilled From: 09-33
~i 500292136501 Tie-on Depth: 9900.00 ft
Current Datum: 48:33 6/11 /1985 00 :00 Height 55. 00 ft Above System Datum: Mean Sea Level
Magnetic Data: 9/26/2008 Declination: 23.22 deg
Field Strength: 57695 nT Mag Dip Angle: 80.94 deg !
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
35.00 0.00 0.00 85.00
Plan: Plan #4 Date Composed: 9/26/2008 !
copy Sean M's plan 4 Version: 4 !
', Principal: Yes Tied-to: From: Definitive Path ~~
Targets
-- - _ - ___
Map: Map
<---- Latitude ---->
<--- Longitude --->
Name Description TVD +N/-S +E!-W Northieg Easting Deg Min Sec Deg Min Sec ~
Dip. Dir. ft ft ft ft ft
09-33A Polygon 55.00 3897.92 569.86 5947056.00 717805.00 70 15 28.709 N 148 14 21.900 W ~~
-Polygon 1 55.00 3897.92 569.86 5947056.00 717805.00 70 15 28.709 N 148 14 21.900 W !,
-Polygon 2 55.00 4037.74 612.92 5947197.00 717844.00 70 15 30.084 N 148 14 20.647 W
-Polygon 3 55.00 4567.94 1446.59 5947751.00 718662.00 70 15 35.298 N 148 13 56.389 W
j -Polygon 4 55.00 4686.11 2032.27 5947886.00 719244.00 70 15 36.459 N 148 13 39.347 W
~
!, -Polygon 5 55.00 4278.59 2875.91 5947503.00 720099.00 70 15 32.448 N 148 13 14.805 W
I
-Polygon 6 55.00 4195.10 3099.61 5947426.00 720325.00 70 15 31.626 N 148 13 8.297 W i
-Polygon 7
55.00
4085.12
3374.56 5947324.00 720603.00
70 15 30.543 N t
148 13 0.299 W
-Polygon 8 55.00 3879.63 3561.72 5947124.00 720796.00 70 15 28.521 N 148 12 54.856 W
-Polygon 9 55.00 3685.47 3356.03 5946924.00 720596.00 70 15 26.613 N 148 13 0.843 W
-Polygon 10 55.00 3795.25 3088.07 5947026.00 720325.00 70 15 27.694 N 148 13 8.638 W
i -Polygon 11 55.00 3878.74 2864.37 5947103.00 720099.00 70 15 28.516 N 148 13 15.145 W
-Polygon 12 55.00 4286.26 2020.74 5947486.00 719244.00 70 15 32.526 N 148 13 39.686 W
-Polygon l3 55.00 4168.09 1435.06 5947351.00 718662.00 70 15 31.365 N 148 13 56.727 W
-Polygon 14 55.00 3637.89 601.38 5946797.00 717844.00 70 15 26.152 N 148 14 20.983 W
-Polygon 15
~ 55.00 3498.07 558.33 5946656.00 717805.00 70 15 24.777 N 148 14 22.236 W !
'I 09-33A Faults 55.00 3076.58 1123.43 5946251.00 718382.00 70 15 20.631 N 148 14 5.798 W !,
-Polygon 1 55.00 3076.58 1123.43 5946251.00 718382.00 70 15 20.631 N 148 14 5.798 W i
'
-Polygon 2 55.00 3894.55 790.87 5947059.00 718026.00 70 15 28.676 N 148 14 15.470 W
,
-Polygon 3 55.00 3960.26 697.72 5947122.00 717931.00 70 15 29.322 N 148 14 18.180 W I~
I -Polygon 4 55.00 4020.95 501.38 5947177.00 717733.00 70 15 29.919 N 148 14 23.892 W
-Polygon 5 55.00 4517.94 301.62 5947668.00 717519.00 70 15 34.807 N 148 14 29.703 W
-Polygon 6 55.00 4020.95 501.38 5947177.00 717733.00 70 15 29.919 N 148 14 23.892 W
-Polygon 7 55.00 3960.26 697.72 5947122.00 717931.00 70 15 29.322 N 148 14 18.180 W
i -Polygon 8 55.00 3894.55 790.87 5947059.00 718026.00 70 15 28.676 N 148 14 15.470 W
09-33A Fault2 55.00 3765.54 1690.57 5946956.00 718929.00 70 15 27.406 N 148 13 49.295 W ~
bP ~ BP Alaska
Baker Hughes INTEQ Planning Report
INTEQ
[ Company: BP Amoco
~ Field: Prudhoe Bay
Site: PB DS 09
Well: 09-33
Wellpath: Plan 4, 09-33A
Targets
Name Description TVD
.Dip. Dir. ft
-Polygon 1
-Polygon 2
-Polygon 3
-Polygon 4
-Polygon 5
-Polygon 6
09-33A Fault 3
-Polygon 1
-Polygon 2
-Polygon 3
-Polygon 4
-Polygon 5
-Polygon 6
09-33A Target 1
09-33A Target 4
09-33A Target 3
09-33A Target 5
09-33A Target 6
09-33A Target 2
09-33A Target 7
Date: 9!26!2068 Time: 14:53:33 Page: 2
Co-ordinate(NE) Reference: Well: 09-33, True North
Vertical (TVD} Reference: 48:33 6/11 /1985 00:00 55.0
Section (VS} Reference: Well (O.OON,O.OOE,85.OOAzi) ~
Survey Calculation Method: Minimum Curvature Db: Sybase
----
Map Map <---- Latitude ----> <--- Longitude --->
+N/-S +EFW Northing Easting Deg Min Sec Deg Min Sec ~
ft ft ft ft
- - - - -
3765.54 1690.57 5946956.00 718929.00 70 15 27.406 N 148 13 49.295 W
4378.64 1558.19 5947565.00 718779.00 70 15 33.436 N 148 13 53.143 W
4976.31 1440.37 5948159.00 718644.00 70 15 39.314 N 148 13 56.568 W
5860.02 1568.91 5949046.00 718747.00 70 15 48.005 N 148 13 52.822 W j
4976.31 1440.37 5948159.00 718644.00 70 15 39.314 N 148 13 56.568 W ''
4378.64 1558.19 5947565.00 718779.00 70 15 33.436 N 148 13 53.143 W 'i
2679.05 2799.74 5945902.00 720069.00 70 15 16.717 N 148 13 17.038 W
2679.05 2799.74 5945902.00 720069.00 70 15 16.717 N 148 13 17.038 W i~
3790.60 2451.64 5947003.00 719689.00 70 15 27.650 N 148 13 27.153 W 'I
4299.00 2411.29 5947510.00 719634.00 70 15 32.650 N 148 13 28.323 W
6362.05 2026.61 5949561.00 719190.00 70 15 52.942 N 148 13 39.498 W 'I
4299.00 2411.29 5947510.00 719634.00 70 15 32.650 N 148 13 28.323 W
3790.60 2451.64 5947003.00 719689.00 70 15 27.650 N 148 13 27.153 W
55.00
55.00
55.00
55.00
55.00
55.00
3697.99 564.10 5946856.00 717805.00 70 15 26.743 N 148 14 22.068 W
4486.18 2026.50 5947686.00 719244.00 70 15 34.492 N 148 13 39.516 W
4368.02 1440.83 5947551.00 718662.00 70 15 33.332 N 148 13 56.558 W
4078.66 2870.14 5947303.00 720099.00 70 15 30.482 N 148 13 14.975 W
3995.17 3093.84 5947226.00 720325.00 70 15 29.660 N 148 13 8.467 W
3837.82 607.15 5946997.00 717844.00 70 15 28.118 N 148 14 20.815 W
3885.40 3361.79 5947124.00 720596.00 70 15 28.579 N 148 13 0.673 W
55.00
55.00
55.00
55.00
55.00
55.00
55.00
8719.00
8740.00
8755.00
8765.00
8802.00
8813.00
8923.00
Annotation
MD TVD
ft ft
t 9900.00 8719.38 TIP / KOP
I
9920.00 8737.05 End of 9 Deg/100ft DLS
110050.00 8809.83 3
'~ 10085.00 8812.60 End of 40 Deg/100ft DLS
!~ 10500.00 8799.34 5
10790.00 8780.75 6
r 11140.00 8751.23 7
i 11350.00 8741.05 8
11700.00 8739.57 9
', ~ 11910.00 8739.68 10
~ i 12160
00 8740
82 11
.
112460.00 .
8750.58 12
12720.00 8770.80 13
12900.00 8801.63 14
13060.00 8850.73 15
13220.00 8923.88 TD
Plan Section Information
MD Inc! - Azim TVD +N/-S +El-W DLS Build Turn TFO Target
ft deg deg ft ft ff degl100ft deg(100ft deg/100ft deg
9900.00
27.03
9.39 --
8719.38
3698.10
564.82 --
0.00
0.00 --
0.00 - -
0.00
9920.00 28.80 10.04 8737.05 3707.33 566.40 9.00 8.87 3.24 10.00
110050.00 80.47 18.01 8809.83 3805.99 593.58 40.00 39.74 6.14 10.00
110085.00 90.46 27.86 8812.60 3838.04 607.16 40.00 28.55 28.14 45.00
10500.00 92.97 77.63 8799.34 4081.39 926.94 12.00 0.60 11.99 86.50
10790.00 94.15 42.78 8780.75 4222.94 1174.25 12.00 0.41 -12.02 273.00
111140.00 95.09 84.91 8751.23 4373.30 1480.25 12.00 0.27 12.04 87.00
11350.00 90.38 60.12 8741.05 4435.89 1678.67 12.00 -2.24 -11.81 260.00
by ~ BP Alaska
Baker Hughes INTEQ Planning Report uvTE
Q
Company: BP Amoco Date: 9/26!2008 Time: 14:53:33 Page: 3
Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 09-33, True North
Site: PB DS 09 Vertical (TVD) Reference: 48:33 6/1 1/1985 00:00 55.0
Well: 09-33 Section tvS) Reference: Well (O.OON,O.OOE,85.OOAzi)
Wellpath: Plan 4, 09-33A Survey Calculation Method: Minimum Curvature Db: Sybase
Plan Section Information
MD Intl T Azim TVD +N!-S +E(-W DLS :Build Turn TFO Target
ft deg deg ft ft ft deg/1AOft de94t00ft deg/100ft deg
11700.00 90.08 102.12 8739.57 4488.71 2016.78 12.00 -0.09 12.00 90.30
';11910.00 89.86 127.32 8739.68 4401.60 2206.00 12.00 -0.11 12.00 90.50 ',
12160.00 89.63 97.32 8740.82 4307.74 2434.64 12.00 -0.09 -12.00 269.50
!12460.00 86.76 133.23 8750.58 4181.89 2701.37 12.00 -0.96 11.97 95.00
I
12720.00 84.54 102.01 8770.80 4063.12 2928.15 12.00 -0.86 I
-12.01 264.80
'.12900.00 75.92 122.13 8801.63 3997.26 3091.64 12.00 -4.79 11.18 115.00
'.13060.00 68.62 103.46 8850.73 3938.09 3231.10 12.00 -4.56 -11.67 245.00 ~I
' 13220.00 57.24 120.90 8923.88 3885.71 3362.51 12.00 -7.11 10.90 130.00
Survey
MD Inc! Aaim SS TVD N/S F1W "MapN MapE DLS VS TFO Tool
ft deg deg. ft ft ft ft ft deg/100ft ft deg
--
9900.00
27.03
9.39
8664.38
3698.10
564.82
5946856
.13
717805.72
0.00
884.98
0.00
MW D
9920.00 28.80 10.04 8682.05 3707.33 566.40 5946865 .40 717807.03 9.00 887.36 10.00 MWD
it 9923.39 30.14 10.51 8685.00 3708.97 566.70 5946867 .05 717807.28 40.00 887.80 10.00 09-33~
9925.00 30.78 10.72 8686.39 3709.77 566.85 5946867 .85 717807.41 40.00 888.02 9.59 MWD
9941.43
i 37.27 12.49 8700.00 3718.77 568.71 5946876 .90 717809.01 40.00 890.66 9.41 09-334
t
9950.00
40.67
13.21
8706.66
3724.02
569.91
5946882
.19
717810.06
40.00
892.31
7.94
MWD
9954.46 42.44 13.55 8710.00 3726.90 570.60 5946885 .08 717810.66 40.00 893.25 7.38 09-33~
9975.00
~ 50.60 14.87 8724.12 3741.33 574.26 5946899 .61 717813.91 40.00 898.16 7.12 MWD
10000.00 60.55 16.10 8738.23 3761.18 579.77 5946919 .61 717818.84 40.00 905.38 6.22 MWD
10020.47 68.70 16.95 8747.00 3778.90 585.04 5946937 .47 717823.59 40.00 912.16 5.51 09-33~
10025.00 70.51 17.12 8748.58 3782.95 586.28 5946941 .56 717824.72 40.00 913.75 5.15 MWD
10050.00 80.47 18.01 8754.83 3805.99 593.58 5946964 .80 717831.35 40.00 923.03 5.09 MWD'
10075.00 87.59 25.07 8757.44 3829.09 602.71 5946988 .15 717839.81 40.00 934.14 45.00 MW D
10085.00 90.46 27.86 8757.60 3838.04 607.16 5946997 .22 717844.00 40.00 939.36 44.26 MWD
10100.00 90.57 29.66 8757.47 3851.19 614.38 5947010 .57 717850.84 12.00 947.69 86.50 MWD
10125
00 75
90 32
66 8757
18 3872
58 627
31 5947032 32 717863
15 12.00 962.44 86.52 MWD
.
10150.00 .
90.93 .
35.65 .
8756.81 .
3893.26 .
641.34 5947053 .
.40 .
717876.58 12.00 978.22 86.55 MWD
10175.00 91.11 38.65 8756.37 3913.18 656.44 5947073 .75 717891.09 12.00 994.99 86.59 MWD
10200.00 91.28 41.64 8755.85 3932.29 672.55 5947093 .31 717906.64 12.00 1012.71 86.65 MWD
10225.00 91.45 44.64 8755.25 3950.52 689.64 5947112 .03 717923.19 12.00 1031.32 86.71 MWDII
10250.00 91.62 47.63 8754.58 3967.84 707.65 5947129 .86 717940.70 12.00 1050.78 86.78 MWD
I~, 10275.00 91.78 50.63 8753.84 3984.18 726.55 5947146 .74 717959.12 12.00 1071.03 86.86 MWD,
'I 10300.00 91.94 53.63 8753.03 3999.52 746.27 5947162 .64 717978.39 12.00 1092.01 86.95 MWD
10325
00 92
09 56
63 15
8752 4013
80 766
77 5947177 51 717998.46 12.00 1113.67 87.05 MWD
.
10350.00 .
92.24 .
59.63 .
8751.21 .
4027.00 .
787.98
5947191 .
.31
718019.29
12.00
1135.96
87.15 I
MWD
10375.00 92.38 62.62 8750.20 4039.06 809.85 5947203 .99 718040.80 12.00 1158.79 87.27 MW D
10400.00 92.51 65.62 8749.13 4049.96 832.32 5947215 .54 718062.94 12.00 1182.13 87.39 MW D ~,
10425.00 92.64 68.62 8748.01 4059.66 855.33 5947225 .90 718085.66 12.00 1205.90 87.52 MWD
~' 10450.00 92.75 71.63 8746.84 4068.15 878.81 5947235 .06 718108.89 12.00 1230.03 87.65 MWD
i 10475.00 92.87 74.63 8745.61 4075.40 902.70 5947243 .00 718132.56 12.00 1254.46 87.79 MWD'
10500.00 92.97 77.63 8744.34 4081.39 926.94 5947249 .68 718156.61 12.00 1279.13 87.94 MWD
I~ 10525.00 93.12 74.63 8743.01 4087.37 951.17 5947256 .36 718180.66 12. 00 1303.79 273.00 MWD
10550.00 93.27 71.63 8741.61 4094.61 975.06 5947264 .29 718204.33 12. 00 1328.22 272.84 MWD
i 10575.00 93.40 68.63 8740.16 4103.10 998.53 5947273 .45 718227.54 12. 00 1352.33 272.67 MWD
10600.00 93.53 65.62 8738.65 4112.80 1021.51 5947283 .80 718250.24 12. 00 1376.08 272.50 MWD
I~, 10625.00 93.65 62.62 8737.08 4123.69 1043.96 5947295 .33 718272.36 12. 00 1399.39 272.32 MWDI,
10650.00 93.75 59.61 8735.47 4135.73 1065.80 5947308 .01 718293.85 12. 00 1422.20 272.13 MWD
10675.00 93.85 56.61 8733.81 4148.91 1086.98 5947321 .79 718314.63 12. 00 1444.45 271.94 MWD
10700.00 93.93 53.60 8732.12 4163.18 1107.44 5947336 .64 718334.67 12. 00 1466.07 271.74 MW D
10725.00
94.01
50.60
8730.38
4178.50
1127.11
5947352
.52
718353.90
12.
00
1487.00
271.53 ~
MWD
10750.00 94.07 47.59 8728.62 4194.82 1145.96 5947369 .38 718372.26 12. 00 1507.20 271.32 MW D
~ 10775.00 94.12 44.58 8726.84 4212.12 1163.92 5947387 .18 718389.72 12. 00 1526.60 271.11 MWD
by ~ BP Alaska i
Baker Hughes INTEQ Planning Report
~. _..,,~
company: esr Hmoco
Field: Prudhoe Bay
Site: PB DS 09
j Well: 09 -33
Wellpath: Plan 4, 09-33A
Survey
NID Incl Azim SS TVD
it ft deg deg ft
10790.00 94.15 42.78 8725.75
10800.00 94.21 43.98 8725.02
10825.00 94.36 46.99 8723.15
10850.00 94.49 49.99 8721.22
10875.00 94.62 53.00 8719.24
10900.00 94.73 56.01 8717.20
10925.00 94.82 59.02 8715.12
10950.00 94.91 62.02 8713.00
~ 10975.00 94.98 65.04 8710.85
11000.00 95.03 68.05 8708.67
11025.00 95.07 71.06 8706.46
11050.00 95.10 74.07 8704.25
11075.00 95.12 77.08 8702.02
11100.00
11125.00
11140.00
11150.00
11175.00
11200.00
11225.00
11250.00
11275.00
11300.00
11325.00
11350.00
11375.00
11400.00
11425.00
11450.00
11475.00
11500.00
11525.00
11550.00
11575.00
11600.00
11625.00
11650.00
11675.00
11700.00
11725.00
11750.00
11775.00
11800.00
11825.00
11850.00
11875.00
11900.00
11910.00
11925.00
11950.00
11975.00
12000.00
12025.00
.Date: 9/26/2008 Time: 14:53:33 Page: 4
Co-otdipaite(NE) Reference: Well: 09-33, True North
Vertical (TVD) Reference: 48:33 6/1 1/1985 00:00 55.0
Section (VS} Reference: Well (O.OON,O.OOE,85.OOAzi)
Survey Calculation Method: Minimum Curvature Db: Sybase
------
N/S E/W MapN MapE DLS VS TFO Too.
ft ft ft ft deg/100ft ft deg
4222.94 1174.25 5947398.30 718399.73 12.00 1537.84 270.90 MWDI:
4230.18 1181.10 5947405.74 718406.37 12.00 1545.29 87.00 MWD
4247.66 1198.88 5947423.72 718423.63 12.00 1564.52 87.09 MW D
4264.18 1217.54 5947440.77 718441.81 12.00 1584.55 87.31 MWD j
4279.69 1237.04 5947456.84 718460.85 12.00 1605.33 87.54 MWD i
4294.16 1257.32 5947471.88 718480.71 12.00 1626.80 87.78 MW D I
4307.54
1278.33
5947485.86
718501.32
12.00
1648.90
88.03 I
MWD
I
4319.80 1300.02 5947498.74 718522.64 12.00 1671.56 88.28 MWD
,
4330.90 1322.31 5947510.48 718544.61 12.00 1694.74 88.53 MWD
4340.81 1345.15 5947521.05 718567.15 12.00 1718.36 88.79 MWD
4349.51 1368.48 5947530.41 718590.22 12.00 1742.36 89.06 MWD
4356.97 1392.24 5947538.56 718613.75 12.00 1766.68 89.32 MWD
4363.17 1416.35 5947545.45 718637.67 12.00 1791.24 89.59 MWD
4368.10 1440.76 5947551.08 718661:92 12.00 1815.98 89.86 MWD
4371.74 1465.39 5947555.43 718686.44 12.00 1840.83 90.13 MWD
4373.30 1480.25 5947557.41 718701.25 12.00 1855.77 90.39 MWD
4374.28 1490.16 5947558.69 718711.13 12.00 1865.73 260.00 MWD
4377.65 1514.85 5947562.76 718735.71 12.00 1890.62 259.90 MWD
4382.28 1539.35 5947568.10 718760.06 12.00 1915.43 259.66 MW D
4388.18 1563.59 5947574.69 718784.12 12.00 1940.09 259.45 MWD'~~
4395.32 1587.51 5947582.52 718807.82 12.00 1964.55 259.27 MWD',
4403.69 1611.04 5947591.56 718831.10 12.00 1988.72 259.11 MWD',
4413.26 1634.12 5947601.79 718853.90 12.00 2012.54 258.99 MWD'
4424.00 1656.68 5947613.18 718876.14 12.00 2035.96 258.90 MW D ~
4435.89 1678.67 5947625.70 718897.77 12.00 2058.90 258.83 MWD;
4447.77 1700.66 5947638.21 718919.41 12.00 2081.84 90.30 MWD j
4458.49 1723.25 5947649.57 718941.68 12.00 2105.27 90.32 MW D i.
4468.00 1746.36 5947659.75 718964.51 12.00 2129.13 90.34 MWD;
4476.30 1769.94 5947668.72 718987.84 12.00 2153.34 90.36 MW D II
4483.35 1793.92 5947676.46 719011.60 12.00 2177.85 90.37 MWD
4489.13 1818.24 5947682.94 719035.74 12.00 2202.58 90.39 MWD j
4493.63 1842.83 5947688.15 719060.19 12.00 2227.46 90.40 MWDI
4496.85 1867.62 5947692.08 719084.88 12.00 2252.44 90.42 MWD
4498.75 1892.54 5947694.70 719109.73 12.00 2277.43 90.43 MWD I
4499.36 1917.53 5947696.03 719134.70 12.00 2302.38 90.44 MWD
4498.65 1942.52 5947696.04 719159.69 12.00 2327.21 90.45 MWD
4496.64 1967.44 5947694.75 719184.65 12.00 2351.86 90.46 MWD
4493.32 1992.21 5947692.15 719209.51 12.00 2376.25 90.47 MWD
4488.71 2016.78 5947688.25 719234.20 12.00 2400.32 90.47 MWD
4482.83 2041.08 5947683.07 719258.66 12.00 2424.01 90.50 MWD
4475.68 2065.03 5947676.61 719282.81 12.00 2447.25 90.50 MW D li
4467.29 2088.57 5947668.90 719306.58 12.00 2469.98 90.51 MWD
4457.67 2111.65 5947659.96 719329.92 12.00 2492.12 90.51 MWD
4446.86 2134.19 5947649.80 719352.76 12.00 2513.64 90.51 MW D'I
4434.89 2156.13 5947638.47 719375.04 12.00 2534.45 90.50 MWD',
4421.78 2177.42 5947625.98 719396.70 12.00 2554.52 90.50 MWD
4407.58 2197.99 5947612.38 719417.67 12.00 2573.77 90.50 MWD
4401.60 2206.00 5947606.64 719425.85 12.00 2581.23 90.49 MWD I
~
4392.70 2218.07 5947598.09 719438.17 12.00 2592.48 269.50 I
MW D
4378.71 2238.79 5947584.70 719459.29 12.00 2611.90 269.50 MWD
4365.83 2260.22 5947572.45 719481.07 12.00 2632.12 269.51 MWDI
4354.09
2282.28
5947561.35
719503.47
12.00
2653.08
269.52 i
MWDI, ~,
4343.52 2304.93 5947551.43 719526.41 12.00 2674.73 269.53 MW D ~,
95.12
95.10
95.09
94.88
94.35
93.80
93.25
92.69
92.12
91.54
90.96
90.38
90.36
90.35
90.33
90.31
90.29
90.27
90.25
90.22
90.20
90.18
90.16
90.13
90.11
90.08
90.06
90.03
90.00
89.98
89.95
89.92
89.90
89.87
89.86
89.85
89.82
89.79
89.77
89.75
80.09
83.11
84.91
83.73
80.76
77.81
74.85
71.90
68.95
66.01
63.06
60.12
63.12
66.12
69.12
72.12
75.12
78.12
81.12
84.12
87.12
90.12
93.12
96.12
99.12
102.12
105.12
108.12
111.12
114.12
117.12
120.12
123.12
126.12
127.32
125.52
122.52
119.52
116.52
113.52
8699.79
8697.56
8696.23
8695.36
8693.35
8691.57
8690.03
8688.74
8687.69
8686.89
8686.34
8686.05
8685.89
8685.73
8685.59
8685.45
8685.32
8685.19
8685.08
8684.98
8684.89
8684.80
8684.73
8684.67
8684.62
8684.57
8684.55
8684.53
8684.52
8684.52
8684.54
8684.57
8684.61
8684.66
8684.68
8684.72
8684.79
8684.88
8684.97
8685.08
bP ~ BP Alaska
Baker Hughes INTEQ Planning Report
INTEQ
~ Company: BP Amoco Date: 9/26/2008 Time: 14:53:33 Page: 5
Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 09-33, True North
Site: PB DS 09 Vertical (TVD) Reference: 48:33 6/11 /1985 00:00 55. 0
Well: 09- 33 Section '{VS) Reference: WeII (O. OON,O.OOE,85.OOAz i)
Wellpath: Pla n 4, 09-33A Survey Calculation Method: Minimu m Curvature Db: Sybase
Survey
-
--
-
MD -
Intl Azim -
SS TVD N/S E/W MapN MapE DLS VS TFO Tool
ft deg deg ft fl ft tt ft deg/100ft ft deg
12050. 00 89.72 110.52 8685 .20 4334. 15 2328.11 5947542.73 719549.84 12.00 2696.99 269.55 MWD
!i 12075. 00 89.70 107.52 8685 .32 4326. 00 2351.74 5947535.27 719573.70 12.00 2719.83 269.56 MWD
12100. 00 89.68 104.52 8685 .46 4319. 10 2375.77 5947529.07 719597.91 12.00 2743.16 269.58 MWD'
12125. 00 89.66 101.52 8685 .60 4313. 47 2400.12 5947524.14 719622.42 12.00 2766.93 269.59 MWD'
I~ 12150. 00 89.64 98.52 8685 .76 4309. 12 2424.74 5947520.51 719647.15 12.00 2791.07 269.61 MWD,
I
12160.
00
89.63
97.32
8685
.82
4307.
74
2434.64
5947519.42
719657.09
12.00
2800.82
269.63
MWD
12175. 00 89.47 99.11 8685 .94 4305. 60 2449.48 5947517.70 719671.99 12.00 2815.42 95.00 MWD
12200. 00 89.21 102.10 8686 .22 4301. 00 2474.05 5947513.81 719696.68 12.00 2839.49 94.99 MWD
12225. 00 88.96 105.09 8686 .62 4295 .12 2498.35 5947508.64 719721.13 12.00 2863.18 94.95 MWD'
12250. 00 88.70 108.08 8687 .14 4287 .99 2522.30 5947502.20 719745.28 12.00 2886.42 94.90 MW D ~~
~~ 12275. 00 88.45 111.07 8687 .76 4279. 62 2545.84 5947494.51 719769.05 12.00 2909.15 94.84 MW D ~I
12300. 00 88.20 114.06 8688 .49 4270 .03 2568.92 5947485.59 719792.39 12.00 2931.30 94.77 MWD
12325. 00 87.96 117.05 8689 .33 4259 .25 2591.46 5947475.47 719815.23 12.00 2952.81 94.68 MW D I,
12350. 00 87.72 120.05 8690 .27 4247 .31 2613.40 5947464.17 719837.51 12.00 2973.63 94.58 MWD
12375. 00 87.49 123.04 8691 .31 4234 .24 2634.68 5947451.72 719859.16 12.00 2993.69 94.47 MWD',
12400. 00 87.27 126.04 8692 .45 4220. 09 2655.25 5947438.16 719880.13 12.00 3012.95 94.34 M W D
12425. 00 87.05 129.03 8693 .69 4204 .88 2675.05 5947423.53 719900.36 12.00 3031.35 94.21 MWD',
12450. 00 86.84 132.03 8695 .02 4188 .66 2694.02 5947407.86 719919.79 12.00 3048.84 94.06 MWD
12460. 00 86.76 133.23 8695 .58 4181 .89 2701.37 5947401.32 719927.32 12.00 3055.57 93.90 MWD
12475. 00 86.60 131.43 8696 .45 4171 .81 2712.44 5947391.56 719938.68 12.00 3065.71 264.80 MWD
12500. 00 86.34 128.44 8697 .99 4155 .80 2731.57 5947376.10 719958.26 12.00 3083.38 264.90 MWD
12525. 00 86.09 125.44 8699 .64 4140 .81 2751.51 5947361.69 719978.62 12.00 3101.93 265.09 MWD'
12550. 00 85.85 122.44 8701 .40 4126 .88 2772.19 5947348.37 719999.70 12.00 3121.32 265.29 MWD
~ 12575. 00 85.62 119.44 8703 .26 4114 .06 2793.57 5947336.18 720021.44 12.00 3141.51 265.50 MWD
12600. 00 85.40 116.44 8705 .22 4102 .39 2815.59 5947325.14 720043.78 12.00 3162.42 265.72 MWD i
I
12625. 00 85.19 113.44 8707 .27 4091 .88 2838.18 5947315.29 720066.66 12.00 3184.01 265.96 MW D
CI
12650. 00 85.00 110.44 8709 .40 4082 .58 2861.28 5947306.66 720090.02 12.00 3206.21 266.20 MW D II
12675. 00 84.82 107.43 8711 .62 4074 .50 2884.83 5947299.26 720113.80 12.00 3228.97 266.46 MWD
12700. 00 84.66 104.42 8713 .91 4067 .67 2908.77 5947293.13 720137.92 12.00 3252.22 266.73 MWD
I
12720. 00 84.54 102.01 8715 .80 4063 .12 2928.15 5947289.13 720157.43 12.00 3271.13 267.00 MW D
CI
ii 12725. 00 84.29 102.56 8716 .28 4062 .06 2933.01 5947288.22 720162.32 12.00 3275.88 115.00 MWD
~I 12750. 00 83.03 105.30 8719 .05 4056 .08 2957.12 5947282.93 720186.59 12.00 3299.38 114.95 MWD
12775. 00 81.78 108.05 8722 .35 4048 .97 2980.86 5947276.51 720210.52 12.00 3322.41 114.64 MWD
12800. 00 80.56 110.83 8726 .19 4040 .75 3004.15 5947268.97 720234.04 12.00 3344.90 114.28 MW D ~,
12825. 00 79.36 113.62 8730 .55 4031 .44 3026.94 5947260.32 720257.08 12.00 3366.78 113.85 MW D I,
12850. 00 78.18 116.43 8735 .41 4021 .07 3049.16 5947250.60 720279.59 12.00 3388.01 113.37 MWD!
i 12875. 00 77.03 119.27 8740 .78 4009 .67 3070.74 5947239.82 720301.50 12.00 3408.52 112.82 MWD
12900. 00 75.92 122.13 8746 .63 3997 .26 3091.64 5947228.02 720322.74 12.00 3428.26 112.21 MWD
12925. 00 74.66 119.31 8752 .98 3984 .91 3112.43 5947216.27 720343.87 12.00 3447.89 245.00 MWD',
~~ 12943. 46 73.76 117.21 8758 .00 3976 .50 3128.07 5947208.32 720359.75 12.00 3462.74 245.72 09-33A
,
12950. 00 73.45 116.46 8759 .85 3973 .66 3133.67 5947205.65 720365.43 12.00 3468.07 246.29 MWD
i
12975. 00 72.27 113.57 8767 .21 3963 .56 3155.31 5947196.18 720387.36 12.00 3488.75 246.50 MWD!
13000. 00 71.14 110.65 8775 .06 3954 .63 3177.30 5947187.88 720409.59 12.00 3509.88 247.35 MWD'.
13025. 00 70.05 107.68 8783 .37 3946 .88 3199.57 5947180.78 720432.07 12.00 3531.39 248.27 MWD!:
13050. 00 69.02 104.68 8792 .11 3940 .36 3222.06 5947174.91 720454.74 12.00 3553.22 249.25 MWD':
j 13060. 00 68.62 103.46 8795 .73 3938 .09 3231.10 5947172.90 720463.85 12.00 3562.04 250.31 MWD!
13075. 00 67.47 104.96 8801 .34 3934 .68 3244.59 5947169.88 720477.42 12.00 3575.17 130.00 MWD!-
13100. 00 65.58 107.50 8811 .30 3928 .27 3266.60 5947164.11 720499.61 12.00 3596.55 129.44 MWD ",
~I 13125. 00 63.74 110.12 8822 .00 3920 .99 3287.99 5947157.45 720521.20 12.00 3617.21 128.43 MWD
13150. 00 61.94 112.82 8833 .41 3912 .85 3308.69 5947149.92 720542.12 12.00 3637.12 127.31 MWD',
13175. 00 60.21 115.62 8845 .50 3903 .88 3328.64 5947141.53 720562.32 12.00 3656.22 126.07 MWD
13200. 00 58.53 118.51 8858 .24 3894 .10 3347.80 5947132.30 720581.75 12.00 3674.45 124.72 MW D ~i
by ~ BP Alaska
Baker Hughes INTEQ Planning Report ATE
Q
~ Company: BP Amoco Date. 9/26/2008 Time: 14:53:33 Page: 6
Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 09-33, True North
', Site: PB DS 09 Vertical (TVD) Reference: 48:33 6!11/1985 00:00 55.0
Well: 09-33 Section (VS) Reference: Well (O.OON,O.OOE,85.OOAzi)
~ Welipath: Plan 4, 09-33A Survey Calculation Method: Minimum Curvature Dh: Sybase
Survey
- -
MD - -
L~cl Azim
SS TVD
N/S
E!W Ms1pN ___
NIapE DLS VS TFO
Taoi
ft deg deg ft ft ft ft dey/100ft ft deg
ft ,
I
13218.3 8 57.34 120.70 8868.00 3886.41 3361.33 5947125.00 _
720595.51 12.00 3687.27 123.25 09- A
I
13220.00 57.24 120.90 8868.88 3885.71 3362.51 5947124.34 720596.70 12.00 3688.37 122.08 2 3/8"
BP Alaska
wog
flM60l
0a W-00
TIS en M0. 9800.00
~:
RN.OSW:S: 99: 886N1i199500:00 SSAOII
C
C
E
^
A .
7
b ~
Y
2
LEGEND
--- 09-33(09-33)
-- Plan 4, 09-33A
Plan il4
by
•
LEGEND
BP Alaska ~-
~
A
a
o
4
(04-0
A,
043 (04-43)
wELVBTN 09mu 09-07 (09-07)
09-07A (09-07A)
B~azo osaaa
f]]c3N 09-08 (09-08)
--~~- 09-15 (09-15)
F.r.n w.uB.m: ~.v
1 09-15 (09-i5A)
TN en w0: .oo --- 09-33 (09-33)
ti
° 09-34(09-34)
. N:]]snu1BU 00.00 as.aoN
B.l. Oal
O 09-34A (09-34A)
V.N^NO^ ~
:~T"fro
B
:rfii ~~w 9F
~ 09-41 (09-01)
np.
r
e 09-02 (09-02)
s3.N• 0.00 O.oo ]3.N -- Plan 4, 09-33A
Pl
#4
REFERENCEINFORMATION an
Courtlinale (N/E) Reference: Well Centre: 09-33, True Norlh
Verlicel (TVD~ Reference: 48:33 fi/11/1985 OO:DO 55.00
Section (VS Reference: Slot - 33 (O.OON,O.OOE)
Measured Depth Reference'.48'.336/11/198500:00 55.00
'
. Minimum Curvawre
Calculation Methotl
BEOTNIN OETBILt
Nc NO Inc Ati TVO ~Nl4t •Ef~w OLSe TFec. VNC TerB.l
8900.00 T].O] B.]9 ]BW.]O N4A2 0.00 0.00 BN.W
8910.00 28-00 ).]] 68fi.40 BAD 10.00 BBT.b
] 10030.00 80.4) 18.0 40.OD 10.00 823.0]
10083.N • IT.N 812:60 ]8]B:N N]:1B 40.00 43.00
]
10000.00 Bz.BT 928A4 12.00 N.SO 12
8:1]
41.]8 4T22.N
e
ii
9o 2ii
9O
ii2
n
:
:a
:o
O
s
i i
w:ii 98ioi:2a'a
zoie]
]
_
i lnau na9sT
e
o D
i
i ii
o
°
i
3
°
i
iiiao°
°
°
'
ii
i
i
zn+
O
:
e
:
a
0
o
B
o
a
o
4
:
S
:
z
s
i
9sisose 4+w.BB 2]01.]1
1±
11
9
i ii
w
a3
i
1
:
4
:
:
a
o
2
ii iii2o:oo is:i
3413800.00 T8.B3 1221] 801.3] 98)26 ]921.84 1 13.00 Nb28
080.00 !).93~ !p]N eY]]88 2]t.t0 1.00 '43.00 ]382.N
181]2zo.N 1 • ]883.11 ]MT.33 11.00 ]0.00 ]BN.]T
T Plan: Plan !{4 (09-33/Plan 4, 09-33A)
M Atimutlis la True None Created By: BP Dale: 92fi/2008
Magnele NOM:23.TZ° ChBCked: Dale:
Ma9ear Fall
SOenOth. S]695nT
DAP DON: 80.90° Coned in/amuuon.
Dale: wzruzaoe a0 Mim,Neon
Model: bg9m200]
Ce3 190]130135]0
E-mmr. dn.mcha0NO0~~m09
•
BP Alaska
=`~'~ by
'`~+~`~ Anticollision Report
~t~
BAKER
Nua~s
1NTEQ
Company: BP Amoco Date. 9/26/2008 Time: 15:31:59 Page: l
Field: Prudhoe Bay
I Reference Site: PB DS 09 Co-ordinate(NE) Reference: Well: 09-33, True No rth
ieference Well: 09-33 Vertical ('fVD) Reference: 48:33 6( 11!1985 00: 00 55.0
Reference Wellpath: Plan 4;A9-33A Db: Oracle
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Ri~idiilaeells in this~IehBipal Plan & PLANNED PROGRAM ~~
Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse
Depth Range: 9900.00 to 13220.00 ft Scan Method: Trav Cylinder North
aximum Radius: 1518.50 ft Error Surface: Ellipse + Casing
Survey Program for Definitive Wellpath ~~
Date: 9/26/2008 Validated: No Version: 0
Planned From To Survey Toolcode Tool Name
ft ft
100.00 9900.00 1 : Sperry-Sun B OSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot
~, 9900.00 13220.00 Planned: Plan #4 V4 MWD MWD -Standard 1
Casing Points
MD TVD Diameter Hole Size Name
ft ft
in
in II
J
13220.00 8923.88 2.375 3.000 2 3/8"
---
-- - ~
Summary
_
~ <-------- Offset Wellpath ---- ------> Reference Offset Ctr-Ctr No-Go Allowabie
Site Welt Wellpath MD MD Distance Area Deviation Warning
ft ft ft ft ft -J
PB DS 04 04-04 04-04 V1 11706.35 12700.00 54.72 1867.69 -1812.97 FAIL: Major Risk ~,
PB DS 04 04-04A 04-04A V1 11682.90 12675.00 69.92 279.54 -209.62 FAIL: Major Risk ',
PB DS 04 04-43 04-43 V1 10630.98 11725.00 1103.73 426.47 677.26 Pass: Major Risk ',
PB DS 09 09-07A 09-07A V5 9966.12 10935.00 641.46 705.16 -63.70 FAIL: Major Risk ',
PB DS 09 09-08 09-08 V1 13220.00 10175.00 1298.35 772.02 526.33 Pass: Major Risk
PB DS 09 09-15 09-15A V4 Out of range '
PB DS 09 09-33 09-33 V1 9900.00 9900.00 0.00 631.81 -631.81 FAIL: Major Risk
PB DS 09 09-34 09-34 V1 10975.00 10625.00 1276.81 858.09 418.72 Pass: Major Risk
~~ PB DS 09 09-34A 09-34A V1 10930.22 10800.00 529.36 891.95 -362.59 FAIL: Major Risk
~ PB DS 09
I 09-41 09-41 V1 12250.00 10050.00 1477.11 244.42 1232.69 Pass: Major Risk
i PB DS 09 09-42 09-42 V1 13212.87 9850.00 701.22 290.58 410.63 Pass: Major Risk
PB DS 09 09-42A 09-42A V2 13212.87 9850.00 701.22 290.58 410.63 Pass: Major Risk
PB DS 09 09-42AP61 09-42AP61 V2 13212.87 9850.00 701.22 290.58 410.63 Pass: Major Risk
Site: PB DS 04
Well: 04-04 Rule Assigned: Major Risk
Wellpath: 04-04 V1 Inter-Site Error: 0.00
-- ft
--
Reference
Offset '
Semi-Major Axis
Ctr-Ctr
No-Go -
Aliowable
MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning
i
ft ft ft ft ft ft deg deg. in ft ft ft
.10964.76 8766.73 10900.00 7824.29 105.17 275.08 12.43 308.63 1515.39 889.29 626.10 Pass ',
'.10968.02 8766.45 10925.00 7836.79 104.19 278.67 12.88 308.68 1493.01 894.73 598.28 Pass ~,
10975.00 8765.85 10950.00 7849.29 102.10 284.94 13.82 308.78 1470.63 903.73 566.90 Pass !,
10975.00 8765.85 10975.00 7861.79 102.10 286.20 13.84 308.81 1448.20 906.04 542.16 Pass
', 10975.00 8765.85 11000.00 7874.29 102.10 287.45 13.87 308.84 1425.78 908.25 517.53 Pass
i~ 10981.33 8765.30 11025.00 7886.79 100.15 293.26 14.73 308.93 1403.36 916.51 486.85 Pass I,
10984.77 8765.00
1 11050.00 7899.29 99.09 296.99 15.21 309.00 1380.97 921.98 458.99 Pass
I
10988.26 8764.69 11075.00 7911.79 98.01 300.77 15.70 309.06 1358.61 927.51 431.10 Pass
I
~ 10991.81 8764.38
11100.00 7924.29
96.91 304.60
16.19 309.13
1336.27
933.10
403.17 I
Pass
11000.00 8763.67 11125.00 7936.79 94.38 311.76 17.29 309.25 1314.05 943.01 371.04 Pass
11000.00 8763.67 11150.00 7949.29 94.38 313.08 17.32 309.27 1291.88 945.43 346.44 Pass
~, 11000.00 8763.67 11175.00 7961.79 94.38 314.40 17.34 309.29 1269.85 947.87 321.98 Pass
'i 11007.06 8763.05 11200.00 7974.29 92.15 320.81 18.28 309.38 1247.91 956.98 290.93 Pass
i 11011.19 8762.68 11225.00 7986.80 90.85 325.15 18.83 309.44 1226.14 963.51 262.63 Pass
11015.47 8762.31 11250.00 7999.30 89.50 329.60 19.40 309.49 1204.54 970.28 234.26 Pass
' 11019.90 8761.91 11275.00 8011.80 88.09 334.16 19.97 309.53 1183.12 977.30 205.82 Pass !,
' 11025.00 8761.46 11300.00 8024.30 86.48 339.21 20.63 309.57 1161.88 985.03 176.85 Pass '
11025.00 8761.46 11325.00 8036.80 86.48 340.69 20.62 309.56 1140.74 988.36 152.37 Pass
111033.94 8760.67 11350.00 8049.30 83.61 348.45 21.77 309.63 1119.61 999.64 119.97 Pass '
11038.80 8760.24 11375.00 8061.80 82.05 353.34 22.39 309.66 1098.561007.31 91.25 Pass '
•
are
i
~_
~ 09-33A
of bag
BAG
of bag
blind/shear
Blind/Shears
TOTs
of pipes/slip
of flow cross
of pipe/slip
2" combi ram/slips
Mud Cross I I Mud Cross
2 3/8" pipe/slip
TOTs
2" pipe/slips
b Va
Flow Tee
Alaska Department of Natural Resources Land Administration System Page 1 ofTl`
~ i
-~!_, _ . ~:t> F ~••^~r;~er's Search State Gabins ~tU1~ 4.IC~S
Alaska DNR Case 5ummary~
SAS ~llc~nt_a ~ Case Abstract ~ Case Detail I !_anc! Abstract
x?~,,
bile: ADL 283'.-1 Search for Status Plat relates
Cz+stonaer: 000107377 BP EXPLORATION (ALASKA)1NC
PO BOX 196612/900 E. BENSON BL ATT`N: LANDMANAGER-
ALASKA
ANCHORAGE AK 995196612
Case Type: ,~a=~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS
File Location: DOG DIV OIL AND GAS
Case States: 35 ISSUED Status Date: 09/]4/1965
Total9c~°es: 2560.000 Date Initiated ' 05/28/1965
Office of Pf~ifna~~~ Responsibiltti~~ DOG DIV OIL AND GAS
LastI'ransactroj~ Date: 12/0/2006 Case SuUxi'he : ;°~t~ NORTH SLOPE
Last Transaction: AA-NRB ASSIGNMENT APPROVED
l~~_~ridian: U Totivrzs{ir/~: (lI1N Range: 015E .~~c°~~u<,tr: ?~ Sectiofr~cres: (i~(> earc0t
~~s
l/rri~li~~tr.~ I ' ~~nrf~~~lri/>: U 1 I ~~ Range: 015E :S'c~cli~,~t.~ ~'(, 1'~~c~~iurt . l~~r~c~~: 6 ((1
t/r~-r~/i~nt.~ l' Toivnslt~~~: Q I I ~~ l~cin;~~.~ (11 ~I: 5'r~c~rrur.~ 35 ~'rctiurl .I~~r~~~~: Ei-((1
JI~~r~hliui~- i' Totiti~nslri/~ 01 I V' R~inge: 015E ~ ,~rrlir~n: i(~ .5~~c~/i~,fr :9crr~. h-1(I
Legal Description
0~-28-196 * ~` ~ ~S;1LE [VOTTCE LEGAL DESCRIPTION"
Cl-/-1 ~~ TIIN-RISE-UM2~,26,35,36 260.00 U- 3- 7
fit ~ sUt~"1t11"
Last updated on 10107/2008.
http://www. der. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=2 8324&... 10/7/2008
•
TRANSMITTAL LETTER CIiECKLIST
WELL NAME _ /~ L~ Oy! ~,~l~
PTD# c,?Oe~ !S6
Developments _____ Service _____ Exploratory S
_____ Noa-Conventional WeU ~~~Ptil~ Test
FIELD: _ ~.~UOf/DE' ,4y POOL: _ ~.e</Dh~oE / yy.
Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS -
~yyAT (OPTIONS) ~~. FOR APPROVAL LETTER
APPLIES
MULTI LATERAL The permit is for a new wellbore segment of existing
well
(If Iast two digits in Permit No.
API number are . AP[ No. 50-
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 ( PI-~ and API number
(SO--= ~) from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with ZO AAC
EXCEPTION 25.055. Approve! to perforate and ~oduce / infect 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.
"'" "" `'" 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 fast caugfit and 10' sample intervals
throu tar et zones.
Non-Conventional please note the following special condition of this permit:
Well production or production testing of coat bed mejhaae is not allowed
for name f we! anti( after (Comoanv Narae) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity.lComnanv Name) must contact the
Commission to obtain advance approval of such water weft testing
-_ ffMOe am
Rte: v~ ~rzoos
WELL PERMIT CHECKLIST: Field & Pool PRUDHOE BAY, PRUDHOE OIL •640150 Well Name: PRUDHOE BAY UNIT 09-33A Program DEV Well bore seg ^
PTD#:2081560 Company BP EXPLORATION~ALASKA~ INC Initial Classltype DEV i P END GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^
Administration t Pe(mitfeeaitached-- ----- -- --- -- ----- ----- NA- --- -- - --- -- --- ---- --- - -- -- ----- -
2 Lease numberappropnate. --- ---- - -- -- --- Yes -- -- -- - --- - - - - ---- --- -- -- - ---
3 UniquBwell_nameandnumber- --- -- - - -- - - --- -- Yes --- -- - - - - -- ---- ---- -- -- --- - - - --
4 Well located ina_defnedpool----------------------------------__-- Yes------ -P[udhoeBayOii Pool._-_._-_____--._.-__---__---__-_------------ -,-
5 Well locatedproperdistancefromdrill(ngunit_boundary--_-------------__--- Yes----- --------------------------------- ---- -- --- - ----- --
6 Welilocatedproperdistancefromotherweds_----..---..__--.----_---__ Yes------ ----------------------------------- -- --- -- -- - -
7 Sufficianta4reageayail_ablein_dritlingunit_----------------------_----- Yes-_--- 2560 acres•---------------------------------------- -- ------
8 ffdeviated,is-wellboreplatincluded-- ---- - -- --- --- ------- Yes - - -- - - - ----- --- - - -- -- ------
9 Operator only affectedparfY-- ----- --- - - ---- --- Yes - ---- -- - -- --- -- --- -- -- -- ----
10 Operator bas-app[opriatebond in-force----------------------------_-- Yes------ -BlanketBond#6194193..---------------------------------- ----- ---- ---
11 Permitcanbeissuedwithoutconservatienorder---------------------------- Yes------ -------------.---------------------- -- - - -- --------- ----.~
Appr Date 12 Permitc_anbeissuadwithoutadministrative_approval--------------------.--- Yes----- --------------------------------- - - --- - - - -- - - -
13 Can permit be approved before t5-day wak. - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
ACS 101712008 14 _~Nelllocated~ithinsreaandsSrataauth4rizedby_InjectionOrder#(putlp#in-commeMs)_(Fpr _NA------- ---------------------------_--_.__---_----__.-------___----__----
15 AJiweils_urithin1(4-milearaeofrevigv~identified(Forservicewellonh±)------------- NA------ -------------------------------------------------~-- - -----
16 Pre-produced injector. duration of preproduatioo less than 3 months (For service well oNy) - - -NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - -
17 .Nonconven,gas-conforms to AS31,05 030(1.1.A),U.2.A-D) - - - - - - - - - - - - NA - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - -
Engineertng 18 Conductor string-provided------------------------------------,--- NA_.--__ ConductorsetinDS09-33(185.111).-------------------------------------------
19 Sutface_casingprotectsallknouvnU$DWS------------------------------- NA----.-- -NOaquifers,_AIQ4B,_Conclusion_5..----------------------.----------------------
20 CMT_voladequatetoarculakeonconductor$surf-csg------------------------ -P1A_---___ -SurfaceGasi-ngst<tin DS 09-33.______--__---_---_--__---_._.---__---_--_---_-_
21 CMT.voladequatetotie-iniQngstringtosurfcsg_-__--_--_----_---.__---._ -NA_--_:-- -ProductiQn_casingsei in-D$09x33,-__--.-_--_-_--------------------------------
22 CMT will coyer all knownproduCtivehorizons------------------------------ Yes------ ------------------------------------- -- -- -- - -- -----
23 Casing designs adequate forG,Tl3&_permafrost-------------------------- Yes_----- -----------------. --------------- -- -- - -- -- ------
24 Adequate tankage-or teservQ pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ . _ - -Rig equipped with steel pits, No reserve pit planned._ All waste_to approved disposal wed(s), _ _ _ . - - - - - _ . _ -
25 ICa_re.drill,bas_a10.403for abandonment been approved--------------------_ Yes--.-- -308-355---.------------------------------------------- --- ---
26 Adequate welibore separailon-proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - . _ - -Proximity analysis performed, Close approaches identified._ All approaches within [eservoir, - - - _ _ - - _ - - - - _
27 Ifdiverterre4uired,doesitmeetre9ulations..-_-._---._----_----_--_--- NA------ -BQPsiack_will al[early-beinptace.--------------------------------------------
Appr Date 28 Driliingfluid_program sehematic_BEequiplist adequate_ _ - - - - - - - - --- - - - - - - - - Yes _ - - - _ _ Maximum expected forrrlaticn pressure 7,2_EMW. MW planned 8.6ppg. - _ _ - . _ . - - - _ - - - _ - - . - - - _ - _
TEM 10!812008 29 BO.PI=s,-do they meet regulation - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
30 BOPE_ptess rating appropriate; lest to_(put prig in comments)- - - - - - - - - - - - - - - - - Yes - - _ _ _ _ _ _ _ _ .. _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
BOP testplanned, _ _ _ _ _
- MASP caieulated_at 2420 psi, 3500_psi
31 Choke-manifoldeQmplieswlAPI_RP•53(May84)__----------------------_- Yes_._--- _
=
__---_-_
32 Y+torkwilloGCUrwithoutoperationsbutdown------------------------------- Yes------ ------------------------------------ ---- - - ---- -
33 Is presence of H2$ gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . - _ - - - H2& is reporled_on t)S-09, Mud should_preclude H2S en rig. -Rig has seosors_and ala[ms, - - - _ - - - _ -
34 Mechanical.~oditionofwelisw'tthinAQRyerifiedLFCrservicewellonrya-----------. -NA------ ------------------------------- --- - - - -- --- - ----
Geology 35 Permit can be issued wlo hyd[ogensulfidameaeures - - - - - - - - - - - - - - - - - - - - - No- _ _ _ . _ - -Max level H2S on_ pad DS-09 is t200ppm-for well 09.29 (7!31!08). - - - - . - - - _ - - - - - _ - - _ - - _ _ - -
36 Data-preseotedon potential overpressurezones-----__--------------__-_ -NA_----- ------------------ --- - - --- ---- --- - ---- -
Appr Date
37
Se(smrc analysis of shailcw gas.zones- - - - - - - - - - - - - - -
KA - - -
- - - - - - - - - - - - - - - - - - - - - - - - -
ACS tOR12008 36 Seabed_condjtionsurvey_(ifeffshore)__---_-_------------------------- -KA----
39 Contact namelphone for weeky_progress reports (exploratory only] _ - _ - _ - - - - _ - - _ -Yes . - - _ - Sean Mclaughlin_-_554-4367, - - - - _ - - - - - - - - - - - - - - - - - - - .. - - - _ - - - _ - - - _ - - _ _ - _ _
Geologic
Commissioner: Engineering Public
Date: Commissioner; Date o ner Date
/D- B-d~
Welt History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
tapescan.txt
**** REEL HEADER ****
MWD
09/06/23
BHI
O1
LIS Customer Format Tape
**** TAPE HEADER ****
MWD
09/03/28
2493101
O1
2.375" CTK
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
version Information
VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20
WRAP. N0: One line per frame
well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 9789.0000: Starting Depth
STOP.FT 13158.5000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent value
COMP. COMPANY: BP Exploration (Alaska), Inc.
WELL. WELL: 09-33A
FLD FIELD: Prudhoe Bay Unit
LoC LOCATION.: 70 deg 14' 50.374"N 148 deg 14' 38.479"w
CNTY. COUNTY: North Slope Borough
STAT. STATE: Aldskd
SRVC. SERVICE COMPANY: Bilker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 2.375" CTK
DATE. LOG DATE: 28 Mar 2009
API API NUMBER: 500292136501
Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
SECT. 02 .
TOWN.N T10N .
RANG. R15E .
PDAT. MSL
EPD .F 0
LMF DF
FAPD.F 55 .
DMF DF .
EKB .F 0 .
EDF .F 55
EGL .F 0
CASE.F N/A .
051 DIRECTIONAL
Remarks
Description
Section
Township
Range
Permanent Datum
Elevation Of Perm. Datum
Log Measured from
Feet Above Perm. Datum
Drilling Measured From
Elevation of Kelly Bushing
Elevation of Derrick Floor
Elevation of Ground Level
Casing Depth
Other Services Line 1
(1) All depths are Measured Depths (MD) unless otherwise noted.
<2) All depths are Bit Depths unless otherwise noted.
(3) All True vertical Depths (TVDSS) are Subsea corrected.
(4) All Formation Evaluation data is realtime data.
Page 1
~~~~~~ ~~G~G~
tapescan.txt
(5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage
surface system to lob this well..
(6) Tools ran in the string included Casing Collar Locator, an'
Electrical Disconnect and circulating sub, a Drilling
Performance Sub (Inner and outer Downhole Pressure, vibration and
Downhole weight on Bit), a Directional and Gamma Sub, and
a Hydraulic orienting sub with a Near Bit Inclination sensor.
(7) Data presented here is final and has been depth adjusted to a PDC
(Primary Depth control) log provided by schlumberger GR CNL dated
O1 Apr 2009 per Daniel Schafer with BP Exploration (Alaska), Inc.
(8) The sidetrack was drilled from 09-33 through a milled window in a
7 inch liner.
Top of window 9909 ft.MD (8672.3 ft.TVD55)
Bottom of window 9914 ft.MD (8676.8 ft.TVDSS)
(9) Tied to 09-33 at 9900 feet MD (8664.4 feet TvDSS).
(10) The interval from 13119 feet to 13159 feet MD (8899.9 feet to 8915.6 feet TvDSS)
was not logged
due to sensor to bit offset at well TD.
MNEMONICS:
GRAX ->
ROP~4VG ->
RACLX ->
RACHX ->
RPCLX ->
RPCHX ->
TVDSS ->
CURVE SHIFT
Gamma Ray [MWD] (MWD-API units)
Rate of Penetration, feet/hour
Resistivity (AT)(LS)400kHZ-Compensated Borehole corrected (OHMM)
Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (OHMM)
Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM)
Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (oHMM)
True vertical Depth (Subsea)
DATA
BASELINE, MEASURED,
9798.3, 9798.12,
9803.23, 9803.23,
9809.23, 9808.53,
9810.99, 9809.76,
9814.17, 9813.64,
9816.29, 9815.23,
9818.05, 9816.64,
9819.11, 9818.93,
9822.46, 9822.63,
9825.1, 9824.75,
9826.16, 9825.81,
9827.04, 9827.04,
9831.45, 9830.92,
9833.04, 9832.33,
9835.69, 9835.33,
9837.98, 9837.45,
9842.04, 9841.51,
9846.97, 9847.33,
9850.32, 9851.38,
9851.03, 9852.79,
9855.44, 9854.91,
9857.03, 9856.85,
9858.08, 9858.44,
9861.08, 9860.73,
9868.67, 9866.9,
9870.17, 9868.93,
9874.93, 9875.1,
9877.4, 9877.22,
9878.98, 9878.98,
9885.16, 9884.27,
9887.45, 9886.57,
9888.16, 9888.16,
9891.68, 9891.68,
9896.09, 9895.92,
9900.15, 9900.5,
9907.38, 9908.08,
9908.79, 9909.85,
9920.22, 9919.69,
9927.63, 9927.63,
9932.81, 9932.28,
9939.69, 9938.63,
9940.39, 9939.69,
DISPLACEMENT
-0.175781
! 0
! -0.705078
! -1.23438
! -0.529297
! -1.05762
! -1.41016
! -0.176758
! 0.176758
-0.352539
-0.352539
! -0.529297
! -0.705078
! -0.352539
! -0.529297
! -0.529297
! 0.352539
! 1.05859
1.76367
! -0.52832
! -0.176758
! 0.352539
! -0.352539
! -1.76367
! -1.23535
! 0.175781
! -0.176758
! 0
-0.881836
! -0.881836
! 0
i n
-0.176758
0.353516
0.705078
1.05762
-0.52832
0
-0.529297
-1.05859
-0.705078
Page 2
~ ~
9943.85, 9942.62,
9946.85, 9946.15,
9955.18, 9953.59,
9959.23, 9957.12,
9963.11, 9961.35,
9964.88, 9964.17,
9969.81, 9968.05,
9973.87, 9973.34,
9980.22, 9977.75,
9987.63, 9983.75,
9992.74, 9989.92,
9998.03, 9993.98,
10003.9, 9999.97,
10006.7, 10002.1,
10014.3, 10009.7,
10017.6, 10012.5,
10026.1, 10022.7,
10029.1, 10025.9,
10031.7, 10028.5,
10035.4, 10032.9,
10040, 10036.6,
10060.4, 10058,
10066.8, 10064,
10081.6, 10079.9,
10088, 10085.9,
10090.3, 10087.8,
10101.4, 10098.9,
10103.7, 10101.4,
10186.7, 10184.2,
10209.2, 10206.8,
10225.7, 10223.9,
10232.2, 10229.7,
10242.8, 10240.5,
10249.3, 10247,
10251.1, 10249.3,
10254.4, 10252.1,
10262.2, 10259.5,
10263.7, 10261.3,
10265.5, 10263,
10266.9, 10264.8,
10271.2, 10268.5,
10274.9, 10273,
10276.8, 10274.9,
10365.1, 10367,
10366.8, 10368.6,
10368.9, 10370.5,
10371, 10372.5,
10373, 10374,
10374.4, 10375.3,
10381.3, 10382.5,
10397.7, 10398.9,
10403, 10405.3,
10410.7, 10413.2,
10439.3, 10439.5,
10446.7, 10446.9,
10461.4, 10462.3,
10468.6, 10468.1,
10470.7, 10470.7,
10489.9, 10490.4,
10497.3, 10497.3,
10500.8, 10501,
10504.2, 10503.4,
10510.7, 10510.9,
10520.6, 10522.9,
10524.2, 10525.2,
10525.8, 10527.5,
10532.6, 10534,
10545.7, 10546.2,
10547.8, 10548.3,
10555.2, 10554.9,
tapescan.txt
-1.23438
-0.705078
-1.58691
-2.11621
-1.76367
-0.705078
-1.76367
-0.529297
-2.46875
-3.88086
-2.82227
-4.05664
-3.87988
-4.58496
-4.58496
-5.11426
-3.35059
-3.1748
-3.1748
-2.46875
-3.35156
-2.46875
-2.82227
-1.76367
-2.11621
-2.46973
-2.46875
-2.29297
-2.46875
-2.46875
-1.76367
-2.46875
-2.29297
-2.29199
-1.76367
-2.29297
-2.64551
-2.46875
-2.46875
-2.11621
-2.64551
-1.94043
-1.94043
1.94043
1.76367
1.58789
1.41113
05859
0.881836
1.23438
1.23438
2.29297
2.46875
0.176758
0.175781
0.881836
-0.529297
0
0.529297
0
0.176758
-0.706055
0.176758
2.29297
1.05859
1.76367
1.41113
0.529297
0.529297
-0.352539
Page 3
s
tapescan.txt
10563, 10562.6, ! -0.352539
10571.8, 10571.8, ! 0
10581.6, 10580.9, ! -0.705078
10597.8, 10598, ! 0.176758
10610.7, 10611.6, ! 0.881836
10618, 10617.8, ! -0.176758
10622.2, 10622, ! -0.175781
10635.6, 10635.3, ! -0.352539
10663.8, 10663.8, ! 0
10676.7, 10676.7, ! 0
10678.3, 10678.4, ! 0.175781
10681.1, 10681.4, ! 0.353516
10683, 10683.2, ! 0.176758
10686.2, 10686, ! -0.176758
10689.6, 10688.9, ! -0.705078
10708.4, 10708, ! -0.352539
10710.5, 10711.2, ! 0.706055
10713.2, 10714.2, ! 1.05859
10741.6, 10741.2, ! -0.352539
10749.5, 10749.5, ! 0
10781, 10781.2, ! 0.176758
10789.1, 10788.9, ! -0.176758
10793.5, 10793.3, ! -0.176758
10826.7, 10827, ! 0.353516
10829.3, 10829.5, ! 0.176758
10834.3, 10832.9, ! -1.41113
10844.5, 10843.8, ! -0.705078
10881.4, 10882, ! 0.52832
10893.3, 10894.3, ! 1.05762
10901.6, 10901.2, ! -0.352539
10922, 10922, ! 0
10934.7, 10935.6, ! 0.881836
10939.8, 10941, ! 1.23438
10943, 10944.9, ! 1.93945
10955, 10956.6, ! 1.58691
10960.6, 10961.9, ! 1.23438
10970.1, 10970.3, ! 0.176758
10977, 10975.7, ! -1.23438
10984, 10981.2, ! -2.82129
10987.9, 10985.6, ! -2.29297
10995.6, 10991.4, ! -4.23242
11027.6, 11024.2, ! -3.35059
11056.2, 11051.9, ! -4.2334
11058.8, 11054.2, ! -4.58594
11063.7, 11060.9, ! -2.82129
11067.1, 11063.2, ! -3.87988
11068.3, 11064.4, ! -3.87988
11074, 11068.3, ! -5.64355
11077.3, 11071.7, ! -5.64355
11184.9, 11180.8, ! -4.05566
11189.5, 11186.3, ! -3.1748
11202.3, 11197.9, ! -4.40918
11211.9, 11207.4, ! -4.40918
11221.2, 11218.4, ! -2.82227
11238.1, 11236.2, ! -1.93945
11256.3, 11254.1, ! -2.11621
11264, 11261, ! -2.99805
11269.1, 11264.2, ! -4.93848
11275, 1 1270.6, ! -4.40918
11288.4, 11283.6, ! -4.76172
11346.4, 11344.1, ! -2.29297
11360, 1 1357.9, ! -2.11719
11367.9, 11364.6, ! -3.35156
11399.8, 11396.8, ! -2.99805
11406.1, 11404.3, ! -1.76367
11460.6, 11459.6, ! -1.05859
11500.9, 11504.1, ! 3.17383
11502.5, 11506.2, ! 3.7041
11655.9, 11649.9, ! -5.99707
11661.7, 11654.7, ! -7.05371
Page 4
C,
11694.6, 11687.7,
11783, 11782.7,
11786, 11786, !
11791.3, 11790.8,
11795.9, 11796.1,
11822.5, 11820.7,
12004.4, 12004.7,
12008.8, 12007.6,
12103, 12100.4,
12120, 12118.9,
12155.5, 12151.8,
12163.1, 12158.5,
12184.2, 12182.1,
12210.3, 12206.8,
12212.3, 12208.9,
12233.8, 12234.8,
12300.1, 12295,
12309.4, 12304.9,
12339.9, 12336.5,
12360.5, 12356.1,
12368.6, 12363,
12376.2, 12371.1,
12430.4, 12428.2,
12434.9, 12432.9,
12437.9, 12434.9,
12460.4, 12457.4,
12468, 12465.2,
12471.9, 12468.6,
12475.4, 12471.9,
12504.9, 12501.7,
12530.7, 12530.7,
12536, 12535.8,
12547.2, 12546,
12557.1, 12553.6,
12574, 12571, !
12576, 12573.5,
12584.5, 12582.2,
12597, 12594, !
12602.6, 12598,
12606.8, 12604.7,
12612.7, 12609.5,
12618.7, 12615.8,
12622, 12619.5,
12625.2, 12622.9,
12635.3, 12633.5,
12639.5, 12638.5,
12644.6, 12643.9,
12652, 12649.6,
12654.2, 12650.8,
12659.1, 12656.3,
12660.7, 12657.3,
12667.2, 12663.9,
12670, 12666.3,
12673.7, 12670.4,
12678, 12674.5,
12688.3, 12683.3,
12693.9, 12688.6,
12699, 12695.3,
12713.1, 12709.4,
12719.8, 12714.7,
12725.1, 12719.1,
12728.1, 12722.5,
12735.4, 12729.9,
12738, 12732.5,
12744.1, 12739,
12752.2, 12747.3,
12753.8, 12749.4,
12768.1, 12762.4,
12771.8, 12766.3,
12773.6, 12769,
J
tapescan.txt
-6.87793
-0.352539
0
i
i
i
i
i
i
-2
-2
. i
i
i
i
-0.529297
0.175781
-1.76367
0.352539
-1.23438
-2.64551
-1.05859
-3.7041
-4.58496
-2.11621
-3.52734
-3.35156
1.05762
-5.11426
-4.58594
-3.35059
-4.40918
-5.64355
-5.11523
-2.29199
-1.94043
-2.99805
-2.99805
-2.82129
-3.35059
-3.52734
-3.1748
0
-0.175781
-1.23535
-3.52734
.99805
-2.46875
-2.29297
.99902
-4.58594
-2.11621
-3.1748
-2.82129
-2.46973
-2.29199
-1.76367
-1.05762
-0.706055
-2.46973
-3.35059
-2.82227
-3..35059
-3.35059
-3.7041
-3.35059
-3.52734
-4.93848
-5.29102
-3.7041
-3.7041
-5.11426
-5.99609
-5.64355
-5.46777
-5.46777
-5.11523
-4.9375
-4.40918
-5.64355
-5.46777
-4.58594
r
Page
12775.3, 12771.1,
12779.4, 12775.3,
12783.4, 12779.5,
12799.9, 12795.7,
12802.6, 12798.2,
12805.4, 12799.9,
12810.5, 12804.9,
12813.1, 12808.4,
12817, 12813,
12822.6, 12818,
12838.7, 12835,
12841.9, 12837.4,
12852.1, 12847.5,
12853.9, 12849.3,
12857.6, 12852.6,
12865.7, 12861.3,
12882.5, 12877.4,
12891.2, 12885.7,
12897.7, 12893.6,
12901.9, 12896.6,
12915.2, 12908.5,
12921.6, 12917,
12929.1, 12923.3,
12935, 12930,
12948.2, 12942.3,
12955, 12950.6,
12967.7, 12965.8,
12978.5, 12974.6,
12985.9, 12981.6,
13012.5, 13007.7,
13014.6, 13010.3,
13016.3, 13012.6,
13018.5, 13015.6,
13024.3, 13019.7,
13030.6, 13026.2,
13032.6, 13028.3,
13038.4, 13032.4,
13046, 13042.6,
13051.3, 13048.8,
13054.4, 13052.1,
13058.3, 13055,
13062.7, 13059.5,
13066.1, 13063.4,
13069.8, 13066.8,
13071.9, 13068.5,
13074.3, 13071.2,
13078.6, 13075.6,
13081.4, 13078.4,
13085.5, 13081.4,
13088.3, 13083.9,
13098.9, 13094.3,
13104.9, 13101.2,
13107.7, 13103.1,
tapescan.txt
! -4.2334
! -4.05664
! -3.87988
! -4.2334
! -4.40918
! -5.4668
! -5.64453
! -4.7627
-4.05664
! -4.58594
! -3.70312
! -4.40918
! -4.58594
! -4.58594
! -4.93848
! -4.40918
! -5.11426
! -5.46777
! -4.05664
! -5.29102
! -6.70215
! -4.58496
! -5.82031
-4.93848
! -5.82031
! -4.40918
! -1.93945
! -3.88086
! -4.2334
! -4.76172
-4.23242
! -3.70312
! -2.82227
! -4.58496
! -4.40918
! -4.2334
! -5.99609
! -3.35059
! -2.46875
! -2.29297
! -3.35059
! -3.1748
! -2.64551
! -2.99805
! -3.35059
! -3.1748
! -2.99805
! -2.99805
! -4.05566
! -4.40918
! -4.58594
! -3.70312
! -4.58594
EOZ
END
! BASE CURVE: GROH, OFFSET CURVE: GRAX
Tape Subfile: 1
Minimum record length:
Maximum record length:
**** FILE HEADER ****
MWD .001
1024
380 records...
10 bytes
132 bytes
C
Page 6
~ ~
tapescan.txt
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Vers ion 1.000
The data presented here is final and has been depth shifted to a PDCL
from Schlumberger GR CNL dated O1 Apr 2009 per Daniel Schafer with
BP Exploration (Alaska), Inc.
* FORMAT RECORD (TYPE# 64)
Data record type. is: 0
Datum Frame Size is: 28 bytes
Logging direction is down (value= 255)
opticall Lod Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 36
one depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples units Size Length
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAS MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
- --- 24
Total Data Records: 188
Tape File Start Depth = 9789.000000
Tape File End Depth = 13158.500000
Tape File Level Spacing = 0.500000
Tape File Depth units = feet
**** FILE TRAILER ****
Tape subfile: 2 201 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** FILE HEADER ****
MWD .001
1024
*** LI5 COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File version 1.000
Page 7
tapescan.txt
This file contains the raw-unedited field MWD data.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logyin direction is down (value= 255)
Optical Loy Depth Scale units: Feet
Frame spacing: 0.250000
Frame spacing units: [F
Number of frames per record is: 36
one depth per frame (value= 0)
Datum Specification Block sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAS MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
24
Total Data Records: 375
Tape File Start Depth = 9789.000000
Tape File End Depth = 13162.750000
Tape File Level spacing = 0.250000
Tape File Depth units = feet
**** FILE TRAILER ****
Tape Subfile: 3 388 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** TAPE TRAILER ****
MWD
09/03/28
2493101
O1
**** REEL TRAILER ****
MWD
09/06/23
BHI
Ol
Page 8
•
tapescan.txt
Tape Subfile: 4 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
0
Tape Subfile 1 is type: LIS
D
Tape Subfile 2 is type: ~zs
DEPTH GR ROP RAD RAS
RPD RPS
9789.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9789.5000 113.9296 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9800.0000 106.4044 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9900.0000 33.6201 -999.2500 1495.5850 1.1933
2000.0000 2000.0000
10000.0000 65.2804 12.3479 4.6847 4.8882
4.7793 4.8996
10100.0000 41.3145 62.4176 3.6886 3.6302
3.4291 3.2941
10200.0000 27.3290 28.7418 2.8940 2.7526
2.6082 2.5804
10300.0000 35.6985 47.5545 3.5326 3.6597
3.8829 4.4617
10400.0000 35.1679 24.6109 3.2983 3.0167
2.7550 2.5051
10500.0000 46.6955 106.9942 3.6661 3.8215
3.9709 4.5740
10600.0000 30.9273 105.5822 3.7516 3.3621
3.1420 2.9559
10700.0000 31.5176 104.2949 4.6803 4.7825
4.6559 4.9153
10800.0000 27.2395 105.8628 8.4451 7.7099
6.9249 6.3117
10900.0000 36.8263 83.1767 13.8201 11.2226
10.1342 8.8618
11000.0000 45.7000 145.8356 17.2830 16.8788
14.6398 13.6118
11100.0000 27.3157 63.3363 9.5484 8.0661
7.6237 7.4156
11200.0000 38.0008 82.5000 8.8184 7.5996
7.2896 7.3360
11300.0000 25.9385 86.4785 14.8663 12.7320
10.5176 9.1931
Page 9
tapescan.txt
11400.0000 25.2976 56.3419 30.9554
28.7530 30.4045
11500.0000 29.2631 58.9958 55.3549
36.1739 35.4737
11600.0000 26.5000 77.0895 46.3419
38.9769 39.7888
11700.0000 27.6763 57.8682 55.9797
50.7583 53.2660
11800.0000 26.4233 49.5529 40.8729
53.8736 57.6290
11900.0000 28.0072 99.3802 47.2172
52.4008 54.8456
12000.0000 30.8168 76.2061 46.2783
54.8302 57.7830
12100.0000 32.6047 36.4813 38.4289
47.3234 49.1529
12200.0000 25.5984 54.0393 7.9998
7.4395 7.2311
12300.0000 37.8187 65.9348 2.8848
2.9669 3.2464
12400.0000 32.7778 62.8000 2.9159
2.9458 3.1419
12500.0000 33.6612 97.5654 3.0834
3.3517 3.7791
12600.0000 107.5469 34.9159 10.0686
23.1749 32.8353
12700.0000 153.6595 47.0086 5.3544
5.3252 5.8826
12800.0000 70.2067 54.9476 9.9828
12.1265 14.1454
12900.0000 166.2382 13.9230 7.4607
6.3800 6.1330
13000.0000 27.1169 97.5253 4.1293
2.2895 1.8353
13100.0000 69.5477 65.8117 6.6152
5.3192 5.3686
13158.5000 0.0000 0.0000 0.0000
0.0000 0.0000
Tape File Start Depth = 9789.000000
Tape File End Depth = 13158.500000
Tape File revel Spacing = 0.500000
Tape File Depth units = feet
0
Tape subfile 3 is type: LIS
DEPTH GR ROP RAD
RPD RP5
9789.0000 -999.2500 -999.2500 -999.2500
Page 10
•
25.6044
41.5933
36.7808
48.0819
44.7580
47.1226
45.6556
43.5299
6.6782
2.7829
2.7346
3.0303
14.2399
4.8411
9.1678
5.9932
2.3361
4.5326
0.0000
RAS
-999.2500
•
-999.2500 -999.2500
9789.2500 115.5000
-999.2500 -999.2500
9800.0000 106.2000
-999.2500 -999.2500
9900.0000 32.8000
9522.7754 53821.6953
10000.0000 58.0000
4.1550 3.8480
10100.0000 44.7000
3.5840 3.3750
10200.0000 23.8000
2.7100 2.7250
10300.0000 36.1000
3.8390 4.4370
10400.0000 34.1000
2.7930 2.4730
10500.0000 46.9000
3.9680 4.5740
10600.0000 30.2000
3.1420 2.9680
10700.0000 31.9000
4.6780 4.9280
10800.0000 27.3000
6.9140 6.3010
10900.0000 37.7000
10.0690 8.7710
11000.0000 45.9000
13.4730 12.4630
11100.0000 25.2000
7.0460 6.6620
11200.0000 28.6000
6.7040 6.6870
11300.0000 26.0000
10.5360 9.7750
11400.0000 33.3000
27.5980 28.7620
11500.0000 32.9000
39.0670 37.0470
11600.0000 40.7000
39.1020 39.9090
11700.0000 25.5000
49.3030 50.5910
11800.0000 26.8000
53.6160 57.3710
11900.0000 23.0000
52.1520 55.6260
tapescan.txt
-999.2500 -999.2500
-999.2500 -999.2500
-999.2500 528.5270
13.2000 4.5410
59.4000
46.6000
48.0000
24.8000
107.9000
127.4000
103.2000
105.5000
84.3000
165.1000
67.6000
80.5000
77.6000
45.1000
46.1000
88.6000
84.1000
49.6000
51.2000
Page 11
3.8610
2.9450
3.4940
3.4070
3.6670
3.7540
4.6930
8.4340
13.7970
16.4240
9.2340
8.2560
13.6580
28.9670
54.8710
43.5300
51.3720
40.4310
49.4970
-999.2500
-999.2500
2.3350
4.4790
3.8100
2.8290
3.6130
3.1130
3.8230
3.3700
4.8110
7.6950
11.1970
15.3730
7.6820
7.2630
11.7780
24.1760
42.6380
35.2010
44.0840
44.2450
50.5040
•
tapescan.txt
12000.0000 31.9000 76.6000 46.8750
54.0370 57.3950
12100.0000 29.4000 34.2000 39.4420
46.9440 49.1890
12200.0000 25.5000 55.4000 8.6940
8.1470 8.0750
12300.0000 35.7000 39.1000 2.9300
3.1310 3.5720
12400.0000 33.9000 66.5000 2.8570
2.9000 3.0120
12500.0000 38.0000 95.4000 3.0900
2.8330 2.9490
12600.0000 184.9000 30.0000 8.7390
12.7960 14.1730
12700.0000 129.3000 78.5000 5.2810
5.0390 5.6070
12800.0000 48.6000 78.1000 12.3280
10.6680 9.6730
12900.0000 166.3000 15.9000 6.6670
6.5070 6.3790
13000.0000 32.6000 53.3000 4.0320
3.3200 3.8220
13100.0000 41.4000 223.6000 7.7110
6.3800 6.0850
13162.7500 -999.2500 76.5000 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 9789.000000
Tape File End Depth = 13162.750000
Tape File revel Spacing = 0.250000
Tape File Depth Units = feet
0
Tape Subfile 4 is type: LIS
44.8600
43.0750
7.2820
2.8210
2.7220
2.7370
11.0730
4.4890
11.1270
6.4310
2.9310
6.4720
-999.2500
Page 12
