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Alaska Oil and Gas Conservation Commission
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10/6/2005 Well History File Cover Page.doc
•
4.w��\ I%%i s THE STATE Alaska Oil and Gas
f Ll SKI 1
Canservati4n Commission
*h„ GOVERNOR SEAN PARNELL 333 West Seventh Avenue
OF Q. Anchorage, Alaska 99501-3572
ALAS Main: 907.279.1433
SCANNED NOV z 2 2013 Fax: 907.276.7542
John McMullen
Engineering Team Leader
BP Exploration (Alaska), Inc. 4 o 7-- I 17q
P.O. Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-45B
Sundry Number: 313-491
Dear Mr. Wood:
Enclosed is the approved Application for Sundry Approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the
AOGCC an application for reconsideration. A request for reconsideration is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend.
Sincerely,
Cathy P. oerster
f�,, Chair, Commissioner
DATED thisg day of September, 2013.
Encl.
0,..,\la'
• • STATE OF ALASKA ce"
ALASKA OIL AND GAS CONSERVATION COMMIMON REC IVED/
APPLICATION FOR SUNDRY APPROVAL -S 1 2 3
20 AAC 25.280
1. Type of Request: AOGCC
❑Abandon ®Plug for Redrill • ❑Perforate New Pool ❑Repair Well ❑Change Approved Program �,/{'�
❑Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension
❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ❑Other
2. Operator Name 4. Current Well Class 5. Permit To Drill Number
BP Exploration(Alaska) Inc. 207-179
3. Address: o Exploratory 0 Stratigraphic
e,Alaska 99519-6612 ®Development ❑Service
P.O. Box 196612,Anchorage, 6. API Numbe
9 50.029-22671-02-00 •
7. If perforating: 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
PBU 15-45B
Will planned perforations require a Spacing Exception? ❑Yes No
9. Property Designatior 10.Field I Pool(s):
ADL 028306 , Prudhoe Bay Field/Prudhoe Bay Oil Pool •
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured):
12094'• 8824' • 12034' 8822' 10650' None
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 110' 20" 110' 110' 1490 470
Surface 3829' 9-5/8" 3829' 3554' 5750 3090
Intermediate 9258' 7" _ 9258' 8287' 7240 5410
Production
Liner 318' 4-1/2" 9080'-9398' 8119'-8419' 8430 7500
Liner 3085' 3-1/2"x 3/16"x 2-7/8" 9002'- 12087' 8046'-8823'
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
10038'- 12020' 8785'-8822' 4-1/2", 12.6# 13Cr80, L-80 9032',9023'-9091'
Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Packer; Packers and SSSV 8936'/7983'
7"x 4-1/2"Baker S-3 Packer MD(ft)and TVD(ft): 9056'/8096'
12. Attachments: 13.Well Class after proposed work:
®Description Summary of Proposal _1 BOP Sketch
❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ® Development ❑Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operation. October 1,2013 • ❑Oil ❑WINJ ❑WDSPL ❑Plugged
16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned
Commission Representative: ❑WAG ❑SPLUG ®Suspended .
17. I hereby certify that the for-goin• true an. orrect to the best of my knowledge. Contact: Nathan Sperry,564-4258
Printed Name: Joh3 rli�Y�� Title: Engineering Team Leader mil: Nathan.Sperry@bp.com
Signature: 4111' / Phone: 564-4711 Date: 7 e2-l43
Commission Use Only
Conditions of approval: Notify Commission so that a representative may witness J col J�
�// Sundry Number:
❑Plug Integrity Ly BOP Test ❑Mechanical Integrity Test ❑Location Clearance
Other: A /t c_if rn�r r l v c 1.2. l cf<< t, a pp�y-c I�c'cf �'� 714-C, Z a�./12 l
,�
oc p tf s7` 351 v p s
--,{ R .t: OCT 1 0 200'
Spacing Exception Required? ❑Yes No Subsequent Form Required: /z) 4 0 _
f / / APPROVED BY p 4)
Approved By: _sI, ` _, COMMISSIONER THE COMMISSION Date: / 39-13 \
Form 10-403 Revised 4/2012 Submit In Duplicate 1� ti
Approved application is valid for 12 months from the date of approval p �`
J q-177--1i3 ORIGINAL
• •
To: Alaska Oil & Gas Conservation Commission
From: Nathan Sperry by
CTD Engineer
Date: September 9th, 2013
Re: 15-45B Sundry Approval
Sundry approval is requested to plug the 15-45B perforations as part of the drilling and completion of
proposed 15-45C coiled tubing sidetrack.
History and current status: Well 15-45B was CTD sidetracked to its current bottom hole location in
zone 1A 2008. The well came on strong but gassed out after only 6 months of production. The initial
—870' of perfs were plugged off in July of 2009. 70' of zone 1 perforations were added and the well
produced over the next 2-1/2 years before gassing out. The well started cycling in late 2011 without
much success. Zone 1B perforations were added in September 2012 but only produced gas. There
are no further wellwork options for this well and the well is no longer a competitive producer.
Proposed plan: Sidetrack 15-45B to the 15-45C location using Nordic 1 Coiled Tubing Drilling rig on
or around October 31st, 2013. The 15-45C sidetrack will exit the existing 4-1/2" liner and kick off in the
Shublik and land in Zone 1A. This sidetrack will be completed with a 3-1/4" L-80 liner and cemented in
place. This Sundry covers plugging the existing 15-45B perforations via the 15-45C primary liner
cement lob and a liner top packer if the liner lap pressure test fails (alternate plug placement per 20
AAC 25.112(i)).
The following describes work planned and is submitted as an attachment to Form 10-403. A
schematic diagram of the proposed sidetrack is attached for reference.
6n(vt. i h we 11 (t��r(eh s ��U� �` t ll w�
C
10v G°A . /'CJ �c% �1� G
//, 7////
5/2 y PTA 2l3- 1
• •
Required
Permit?
Pre-Rig Work(scheduled to begin October 1St, 2013) 10-403 PTD
1. C Release LTP No No
2. C Injectivity test No No
3. V PT MV, SV, WV. Set BPV. No No
4. 0 Remove wellhouse and level pad No No
Required Per
Rig Work(scheduled to begin October 31St, 2013) 10-403 , b,
1. MI RU and test BOPE 250 psi low and 3,500 psi high Yes 7TJ
2. Pull BPV Yes Svvt Gtr y
3. Kill well Yes
4. Pull liner top packer assembly/r // 2/p( Gj;! 4 ,,,6111 J Yes
5. Set whipstock / / i Yes
6. Mill 3.80"window at 9,280' and 10' of rathole 1) 6 Yes
7. Drill build: 4.25" OH, 795' (12 deg DLS planned). No Yes
8. Drill lateral: 4.25" OH, 2205' (12 deg DLS planned). No Yes
9. Run 3-1/4" liner leaving TOL at 9,000' MD. No Yes 121-17
10. Pump primary cement job: 30 bbls, 15.8 ppg, TOC at 9,000' MD. Yes* No 21 -/4-O
11. Perform liner cleanout and MCNL/GR/CCL log No Yes
12. Test liner lap to 2400 psi. No Yes
13. Perforate liner based on log interpretation (-800'). No Yes
14. Freeze protect well to 2500' MD. No Yes
15. Set BPV; RDMO. No Yes
*Approved alternate plug placement per 20 AAC 25.112(i)
Post-Rig Work:
1. Re-install wellhouse, flowline and pull BPV.
2. Set GLV's
3. Set liner top packer with slickline as needed if failed liner lap pressure test in Rig Work step 12 above.
4. ASRC flowback/well test
Nathan Sperry
CTD Engineer
564-4258
CC: Well File
Joe Lastufka
Itdt=- CM/ •
,WaLFEAD= FMC TES: WELL ANGLE >70°fa 9712'.
BAKER . 1 5-4 5 B '"'4112 CFROME TB& ORIGINAL 8<15-45A
ACTl1ATOR= BAKE C
URAL KB.gF 68.06' WELLBORES NOT SHOWN BELOW WHIPSTOCK*"
BF.ELEV= _? ill,
KOP= 931' 2118' H4-1/2'HESX NP,D=3.813'
Max Angle= 95'(4 11933'
Datum 6D= I VA GAS LFT MANDRELS
Datum TV D= 8800'SS ST MD TV D DEV TY PE V LV •LATCH FORT DATE
IV 4 3355 3157 32 KBG-2 DMY BK 0 06/19/10
3 5561 5012 35 KBG-2 DMY BK 0 06/19/10
9-5/8"CSG,40#,L-80,D=8.835' I— 3829' I— 2 7436 6596 26 KBG-2 DMY BK 0 05/14/05
1 8846 7 19 KBG-2' EMY BK 0 05/14/05
Minimum ID =2.37" @ 9002' 8915' )—4-12•HIESxrP,D=3.813' I
3-3/16" LINER TOP PACKER I 8936' 7"x 4-12'BKR S-3 PKF? D=3.875•
■ 8959' H4-1/2'1-E5 X NP,D=3.813" 1
9002' --{BKR LW SEAL BOF .D=2.37" 1
4-1/2"TBG,12.6#,13CR80 VAM TOP, — 9022'
.0152 bpf,ID=3.958" 9032' Hr x 4-1/2"UNIQUE OV B25 HOT I
4-1/2'TBG STUB(DIMS 05/13/05) — 9023' 7:11 ICA 9056' H7'x 4-1/2'BKR S-3 PKFL D=3.875'
ITOP OF 4-1/2"LNR —I 9080' El 6079• I--I4-12'HE5 X NP,D=1812' I
4-12"TBG, 12.6#,L-80 BTC-M, — 9091' I AN 9091' r-1412'WLEG,D=3.958" I
.0152 bpf,D=1958'
H ELK)TT NOT LOGO
17"CSG,26#,L-80,13=6.276' H 9258' I •
PERFORATION SIJIMRRY
REF LOG:BKR MWEVGR ON 02/12/08 0 1 , 9299' —3.70"UT DEPLOY LENT SLV w/4'GS
ANGLE AT TOP PERE 61°@ 10038' / 1 PROFL D=3.00"
Note:Refer to Production DB for historical pert data •4 PI
SIZE SPF MERVAL Opn/Sqz SHOT SQZ / V
2" 6 ' 10038-10048 0 09/23/12 • • 9340' HI 3-1/2"Hey x NP,D=2.873'
2' 6 10250-10270 0 07/25/09 1/ !,
2" 6 10420-10445 0 07/25/09 !/ •!
2" 6 10445-10470 0 07/25/09 • MLLOUT VITDOW(15-458) 9 -9404'
•
2' 6 10810-11680 C 02/15/08 .1
2' 6 11930-12020 C 02/15/08 �1
/1 1
,' l 9373' H3-1/2"X 3-3116'X0,D=2.786• I
3-1/2'L1*,9.2#,L-80 STL,.0087 bpf,D=Z992' I— 9373' 1
••,
VuhPSTOCK 9398' 4 44•0
'4,14, 9999' I--33/16'X 2-7/8" XO,D=2.387' I
.i, s.,..
412"Lf42,126#,L-80 NSCi..0152 bpf,D=3.958' —1 9398' P,IM.M4
IRA TAG(02/07/08) I-L 9408'
10650' I—2.2"WFD CBP
3-3/16'L ,62#,L-80 TC31,.0076 bpf,D=2.80' —I 9999' I (07/24/09)
Ar
•FSTD 12034' '*4*•
12-7/8'LNR,6.16#,L-80 STL, 0058 bpf,D=2441" H 1208T
DATE REV BY CONSENTS DATE REV BY CX)MANTS R D-IOE BAY UHT
05/04/96 ORIGINAL COMPLETION 06/25/10 RCT/PJC GLV 00(06/19/10) VVR i. 15-45B
09/09/00 JOM CTD SIDETRACK(15-45A) 12/13/10 CSR/PJC FERF CORRECTIONS(02/15/10) REMIT:' 071790
05/15/05 D16 IMO 09/24/12 RWM/JMD ADR3IFS(09/23/12) AR Na: 50-029-22671-02-00
02/18/08 NORDIC 1 CTD SIDETRACK(15-458) 07/16/13 LEC/JMD NTH)X NP SIZE SEC 22,T11 N,R14E,530'FWL 8 100'PAL
03/08/08 DAV/PJC GLV 00(02/22/08)
11/11/09 AMINE) DRLG DRAFT CORRECTIONS BP Exploration(Alaska)
TREE=' CIW
WELLHEAD= FMC 5 B S TES: WELL ANGLE >70°@ 9712'.
15-4
ACTUATOR= BAKER C ***4-1/2"CHROME TBG***ORIGINAL&15-45A
INITIAL KB.ELE 68.06' WELLBORES NOT SHOWN BELOW WHIPSTOCK***
BF.ELEV= ? I II
KOP= 931' I 2118' H4-1/2"HESX NP,D=3.813"
Max Angle= 95°@ 11933'
Datum MD= N/A
GAS LIFT MANDRELS
Datum TV D= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE
11 4 3355 3157 32 KBG-2 DMY BK 0 06/19/10
' 3 5561 5012 35 KBG-2 DMY BK 0 06/19/10
9-5/8"CSG,40#,L-80,D=8.835" H 3829' 2 7436 6596 26 KBG-2 DMY BK 0 05/14/05
1 8846 7899 19 KBG-2 DMY BK 0 05/14/05
Proposed CTD Pre-Rig
Minimum ID =2.37" @9002' 1 I 8915' H4-1/2"FES X NP,13=3.813"
3-3/16" LINER TOP PACKER ( 8936' H7"x 4-1/2"BKR S-3 RtR D=3.875"
I I 8959' H4-1/2"HES X NP,D=3.813"
.1 ® I J002' H BKR LW SEAL BORE,13=2.37" I
4-1/2"TBG,12.6#,13CR80 VAM TOP, H 9022' I X 4 112"U
`
032' -i 7"
.0152 bpf,D=3.958" f UNIQUE OVERSHOT
[4-1/2"TBG STUB(DIVE 05/13/05) H 9023' I �� 9O56' 7"X 4-1/2"BKR S-3 FKR,D=3.875" I
I TOP OF 4-1/2"LNR H 9080' 1................_I 9079' H4-1/2"HES X NP,D=3.812"
4-1/2"TBG,12.6#,L-80 BTC-M, 9091' 9091• —14-1/2'WLEG,ID=3.958"
.0152 bpf,D=3.958"
L Haw TT NOT LOGGED
7"CSG,26#,L-80,D=6.276" —I 9258' ,
PERFORATION SUMMARY
Fib LOG:BKR MMVD/GR ON 02/12/08 1 ■
ANGLE AT TOP PERF:61°@ 10038' •4
Note:Refer to Roduction DB for historical perf data •4 •t 9299' I—3.70"BTT DEPLOYMENT SLV w/4"GS
SIZE SPF INTERVAL Opn/Sgz SHOT SQZ /. 11 PROF LE,D=3.00"
2" 6 10038-10048 0 09/23/12 1 •1
2" 6 10250 10270 0 07/25/09 0 4 11 9340' H3-1/2"MS X NP,D=2.813'
2" 6 10420-10445 0 07/25/09
/4 • MLLOUT WNDOW(15-45B) 9398'-9404'
2" 6 10445-10470 0 07/25/09 0/ •1
2" 6 10810-11680 C 02/15/08 1 1 ,I
2" 6 11930-12020 C 02/15/08 �4 •
.4 1
1• ;11 9373' H 3-1/2"X 3-3/16"XO,D=2.786"
13-1/2"LNR,9.2#,L-80 STL,.0087 bpf,D=2.992" H 9373' 14 4'
WHPSTOCK -I 9398' ''�4�4i*�.1
1,
1 4-1/2"LNR,12.6#,L-80 NSCT,.0152 bpf,D=3.958" H 9398• MggITA
RA TAG(02/07/08) 9408'
9999' H3-3/16"X 2-7/8" XO,U=2.387"
■
44
3-3/16"LNR,6.2#,L-80 TCII,.0076 bpf,D=2.80" H 9999' i `� 10650' —2.2"WFD CUP
PBTD —1 12034' ,/..'
(07/24/09)
4..4..
I2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" H 12087'
DATE REV BY COM ENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
05/04/96 ORIGINAL COMPLETION 06/25/10 RCT/PJC GLV C/O(06/19/10) WELL: 15-45B
09/09/00 JOM CTD SIDETRACK(15-45A) 12/13/10 CSR/PJC PERF CORRECTIONS(02/15/10) PERMIT:'2071790
05/15/05 D16 RWO 09/24/12 RWM/JMD ADPERFS(09/23/12) AR No: 50-029-22671-02-00
02/16/08 NORDIC 1 CTD SIDETRACK(15-45B) 07/16/13 LEC/JMD CORRECTED X NP SIZE SEC 22,T11 N,R14E,530'F WL&100'FWL
03/08/08 DAV/PJC GLV GO(02/22/08) 08/07/13 NWS PROPOSED GI U PRE-RIG
11/11/09 AW/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska)
RECEIVED
STATE OF ALASKA
ALA KA OIL AND GAS CONSERVATION COMMI•N ULI I 12 L012
REPORT OF SUNDRY WELL OPERATIONS AOGCC
1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U
Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑
Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wele
2. Operator 4. Well Class Before Work: 5. Permit to Drill Number:
Name: BP Exploration (Alaska), Inc
Development IS Exploratory ❑ - 207 -179 -0
3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number:
Anchorage, AK 99519 -6612 50- 029 - 22671 -02 -00
7. Property Designation (Lease Number): 8. Well Name and Number:
ADL0028306 PBU 15-45B
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): _.
To Be Submitted PRUDHOE BAY, PRUDHOE OIL
11. Present Well Condition Summary:
Total Depth measured 12094 feet Plugs measured 10650 feet
true vertical 8823.65 feet Junk measured None feet
Effective Depth measured 10650 feet Packer measured See Attachment feet
true vertical 8836.49 feet true vertical See Attachment feet
Casing Length Size MD TVD Burst Collapse
Structural None None None None None None
Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470
Surface 3800 9 -5/8" 40# L -80 29 - 3829 29 - 3554.28 5750 3090
Intermediate None None None None None None
Production 9230 7" 26# L -80 28 - 9258 28 - 8287.07 7240 5410
Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Perforation depth Measured depth 10038 - 10048 feet 10250 - 10270 feet 10420 - 10445 feet 10445 - 10470 feet 10810 - 11680 feet
11930 - 12020 feet
True Vertical depth 8784.79 - 8789.47 feet 8823.55 - 8824.14 feet 8833.16 - 8834.09 feet 8834.09 - 8835.13 feet 8834.71 - 8839.53 feet
8826.96 - 8821.81 feet
Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment
Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer
None None None SSSV
12. Stimulation or cement squeeze summary: SCANNED JAN 2 8 2013
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: 114 21419 0 0 321
Subsequent to operation: 193 30615 0 0 566
14. Attachments: 15. Well Class after work:
Copies of Logs and Surveys Run Exploratort❑ Development 6 Service ❑ Stratigraphic ❑
Daily Report of Well Operations X 16. Well Status after work: Oil - p Gas ❑ WDSPLU
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Nita Summerhays Email Nita.Summer bra. com
Printed Name Nita S ilffr um �me - Title Petrotechnical Data Technician
. i• nat - / 1 - / / i v I - Phone 564 -4035 Date 10/11/2012
/4(
OCT 1 prif)---N 1 2
Form 10-404 Revised 10/2012 Submit Original Only
•
•
Daily Report of Well Operations
ADL0028306
ACTIVITYDATE ( SUMMARY
TV - . • 1 • - " • pe ora ing
DRIFT W/ 2.0" x 10' DUMMY GUN & S- BAILER TO DEVIATION @ 9,735' SLM - NO
SAMPLE
9/15/2012 ** *WELL LEFT S/I ON DEPARTURE * ** DSO NOTIFIED
T /I /O =2380 /80/50 Assist EL ( Obj. Add perfs) Spear in l bg with 5 bbls of 60/40 ( from
CH2 tanker #39013) followed by 155 bbls of crude to kill well. Continue WSR on next
9/22/2012 day
* ** JOB CONTINUED FROM 22 -SEPT -2012 * ** (ELINE ADPERI -)
RIH W/ WELLTEC TRACTOR W/ 10' x 2" PJ HMX GUNS & PERFORATED INTERVAL
FROM 10038' - 10048'
FINAL T /I /O = 10/150/0
9/23/2012 * ** JOB COMPLETE * **
Continue WSR from previous day
TWO = 1000/90/50 Assist EL (Obj. Add perfs) Pumped 65 bbls ( 220 job total) of
crude ( 155 bbls prior to Midnight) down Tbg to kill well for EL. RDMO. IA. OA = open
9/23/2012 DSO notified @ time of departure. EL in control of WH. FWHP = 450/90/50
FLUIDS PUMPED
BBLS
1 DIESEL
220 CRUDE
5 60/40 METH
226 TOTAL
i S
Packers and SSV's Attachment
ADL0028306
SW Name Type MD ND Depscription
15-45B PACKER 8936 7915.33 4 -1/2" Baker S -3 Perm Packer
15-458 PACKER 9002 7977.46 Baker Liner Top Packer
15-45B PACKER 9056 8028.26 4 -1/2" Baker S -3 Perm Packer
Casing / Tubing Attachment
ADL0028306
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470
LINER 371 3 -1/2" 9.2# L -80 9002 - 9373 8045.52 - 8395.41 10160 10530
LINER 324 4 -1/2" 12.6# L -80 9080 - 9404 8118.92 - 8424.67 8430 7500
LINER 2088 2 -7/8" 6.16# L -80 9999 - 12087 8764.37 - 8823.44 13450 13890
PRODUCTION 9230 7" 26# L -80 28 - 9258 28 - 8287.07 7240 5410
SURFACE 3800 9 -5/8" 40# L -80 29 - 3829 29 - 3554.28 5750 3090
TUBING 9005 4 -1/2" 12.6# 13Cr80 27 - 9032 27 - 8073.74 8430 7500 •
TUBING 68 4 -1/2" 12.6# L -80 9023 - 9091 8065.27 - 8129.29 8430 7500
•
'TREE= ChIV SA . WELL ANGLE > 70° @ 9712' .
ACTUATOR= BAKER C 15-45B ***4 -1/2" CHROME TBG7'**ORKBNAL & 15-45A
ACTlY1
KB. B.V = . 68.1' W8IBORES NOT SHOWN BELOW WHIPSTOCK'**
BF.B.EV= ? I I"
KOP= 931' I 2118' 1H4- 1 /2I-1ESX1 D= 3.813"
Max Angle = 95° @ 11933'
Datum MD = WA GAS LFT MAPORE S
�._..._.. ST MD TVD DE TYPE VLV LA POF7T DATE
Datum TVO = 8800' SS
4 3355 3157 OMY BK 0 06/19/10
3 5561 5012 32 35 KBG KBG-2 2 DMY BK 0 06/19/10
19 -5/8' CSG, 40 #, L-80, D = 8.835" 1-1 3828' ( 2 7436 6597 26 KBG-2 DMY BK 0 05/14/05
1 8846 7899 19 KBG-2 DMY BK 0 05/14/05
Minimum ID =2.37" @ 9002' ( 8915' — I4- 1/2 3.613 I
3 -3/16" LINER TOP PACKER ICS• ►_� 8936• r X 4 -1/2" BKR S-3 PKR, D = 3.875" I
I 8969' H4 -1/2' FES X NP, D = 3.813" I
4-1/2' TBG, 12.6#, 13CR80 VAN TOP, 9022• "' '= 9002' (� LIP SEAL a D =2.37" I
.0152 bpf, D = 3. 958' 9032' —17" X 4-1/2 UNIQUE OVERSHOT I
4-1/2" TBG STUB (DIMS 05 /13/05) I—I 9023' I 9066' 7" X 4 -112" BKR S-3 PKF2, D = 3.875"
1 El (TOP OF 4-1/2 LNR I 9080' ' I I 9078' HH 4 a / D 2" HIE
TT S NOT X N 'LOGGH , D = 3.81 2" I
4-1/2" 1BG, 12.6#, L -80 BTC-M —I 9091' 9091' — I4 -1/2' WLEG, 0 = 3.958" I
.0152 bpf, D = 3.958"
17" CSG, 26#, L-80, D = 6.276" H 9288'
PERFORATION SUMMARY
FRFF LOG: BKR MIMYGR ON 02/12/08 , ; 9299' 1E'
3.70" BIT DLOY MBJT SLV w /4" GS
ANGLE AT TOP PEW: 61° @ 10038' 0 4 PROFILE, D = 3.00"
Pbte: Refer to Production DB for historical pert data � 1 ∎4
SIZE SW INTERVAL Opn/Sqz DATE ,- • 4 ■
•
r 6 10038 - 10048 0 09/23/12 V , 4 1 1 9340' H4-1/2' I-ES X FOP D= 3.812" I
r 6 1 0250 - 10270 0 07/25/09 �, ∎
r 6 10420 -10445 0 07/25/09 1 • I
T 6 10445 - 10470 0 07/25/09 14 • MLLOUT WI'COW (15 -458) 9398' - 9404'
2" 6 10810 - 11680 C 02/15/08 • 1 • �,
2" 6 11930 - 12020 C 02/15/08 , 1
t � f• 9373' H 3-1/2" X 3 -3/16" XO, 0= 2.786' I
13-1/2" LNF� 9.2#, L-80 STL, .0067 bpf, D = 2.992 I-I 8373' 1 ,
IWFI'STOCK I-I 9398' • • ,4•4•.
• / 9999' H 3 -3/16" X 2 -7/8" X0, D= 2.387"
1 4-1/2" LNR, 12.6#, L -80 NSCT, .0152 bpf, D = 3.958" I—I 9398'
IRA TAG (02/07/08) H 9408'
` 10650' 2.7" WFD CEP
13 -3/16" LNR, 6.2#, L-80 TO, .0076 bpf, D = 2.80" I—I 9999' I ` 4 I (07/24109)
P BTD �� ■ •
I H 17034' I e•�∎ •
12-7/8" LM, 6.16#, L -80 STL, .0058 bpf, D = 2.441' H 1208T ,
ATE REV BY COMFITS DATE REV BY CONSENTS PRUDHOE BAY UNIT
05/04/96 ORIGINAL COMPLETION 06/25/10 RCT/PJC GLV CIO (06/19/10) WELL 15-45B
06/09/00 JOM CTD SIDETRACK (15 -45A) 12/13/10 CSR/PJC PERF CORRECTIONS (02/15/10) PERT IT: "2071790
06/15/05 016 F8NO 09/24/12 RVMNJM) ADF'E2FS (09/23/12) API Pb: 50- 029 - 22671 -02-00
02/16108 NORDIC 1 CTD SIDETRACK (15-45B) SEC 22, T11 N, R14E 531' F P& & 99' PAL
03/08/08 DAV /PJC GLV C/O (02/22/08)
11/11/09 AMID DRLG DRAFT CORRECTIONS_ BP Exploration (Alaska)
OPERABLE: Producer 15-45B (PTD~071790) Tubing integrty restored • Page 1 of 2
Regg, James B (DOA)
From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~}~~~~ ~J/5t1 ~o
Sent: Sunday, June 20, 2010 10:00 PM ' l ~
To: AK, D&C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L
(DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS
Operators; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization
Engineer; AK, OPS EOC Specialists; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services
Operations Team Lead; Cismoski, Doug A; Engel, Harry R
Cc: Clingingsmith, Mike J (CH2M Hill); Lee, Timothy
Subject: OPERABLE: Producer 15-45B (PTD #2071790) Tubing integrty restored
All,
Producer 15-45B (PTD# 2071790) passed an MITIA after the as lift valves were dummied off. The
passing test verifies that tubin in e ~ d. The well has been reclassified as Operable
and may be placed on production when convenient for operations. Please be careful for thermal ~
expansion when placing the well on production as the IA is fluid packed.
Thank you,
Toxin Roschinger (alt. Jerry Murphy)
Well Integrity Coordinator
Office (907) 659-5102
Harmony Radio x2376
Cell (406) 570-9630
Pager (907) 659-5100 Ext. 1154
From: AK, D&C Well Integrity Coordinator
Sent: Sunday, June 13, 2010 10:25 PM
To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS
FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production
Optimization Engineer; AK, OPS EOC Specialists; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;
Cismoski, Doug A; Engel, Harry R; AK, D&C Well Integrity Coordinator
Cc: Prowant, Josh L (CH2M Hill); Quy, Tiffany; Holt, Ryan P (ASRC)
Subject: UNDER EVALUATION: Producer 15-45 (PTD #2071790) for TxIA Communication
All,
Producer 15-4~(PTD #2071790) has confirmed sustained casing pressure following a failed TIFL after
the pro-ration shut down. The well head pressures on 5/29/2010 broke MOASP with tubing/IA/OA equal
to 349/2100/20 and were reported to the state in the 05/30/2010 e-mail attached below. The well may
remain online while work is conducted to attempt to restore integrity. The well has been reclassified as
Under Evaluation.
Plan forward:
1. Slickline: Install dummy gas lift valves
2. Fullbore: MIT-IA to 2500 psi
A copy of the schematic and T/I/O plot are included for reference. ~
« File: 15-456 (PTD #2071790) schematic.pdf » « File: Producer 15-45 06-13-2010 TIO Plot.doc »
7/15/2010
OPERABLE: Producer 15-45B (PTD~071790) Tubing integrty restored • Page 2 of 2
Please call if you have questions or concerns.
Thank you,
Gerald Murphy (alt. Torin Roschinger)
Well Integrity Coordinator
Office (907) 659-5102
Cell (907) 752-0755
Pager (907) 659-5100 Ext. 1154
From: AK, D&C Well Integrity Coordinator
Sent: Sunday, May 30, 2010 11:20 AM
To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'
Cc: AK, D&C Well Integrity Coordinator
Subject: Producers with sustained casing pressure on IA and OA due to proration
Jim/Tom/Guy,
The following wells were found to have sustained casin pressure on the IA durin the roration Ma 28-29. The
immediate action is to perform a TIFL on each of the wells an evaluate or IA repressurization. If any of the wells fail the
TIFL, a follow up email will be sent to the AOGCC for each individual well.
07-15A (PTD #1981120)
07-21 (PTD #1830190)
15-458 (PTD #2071790)
W-30 (PTD #1881360)
W-38A (PTD #2021910)
Z-26A (PTD #2060790)
The following well was found to have sustained casing pressure on the OA during the proration May 29. The immediate
action is to perform an DART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication
is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan.
M-23 (PTD #1830550)
Please call with any questions or concerns.
Thank you,
Torin Roschinger (alt. Jerry Murphy)
Well Integrity Coordinator
Office (907) 659-5102
Harmony Radio x2376
Cell (406) 570-9630
Pager (907) 659-5100 Ext. 1154
7/15/2010
PBU 15-45B
PTD #2071790
6/13/2010
TIO Pressures Plot
r"
f 4,000
3,000
c,000
i
1,000
We11:15-45
03f13f10 03f20f10 03f27f10 04f03f10 04~1Of10 04f1?f10 04f24f10 05fO1f10 05fOSf10 05115f10 05f22f10 05f29f10 O~6f05f10
--~- Tbg
---~- IA
~- 0,~
OOA
~U OOOA
On
•
•
TREE = CIW
WELLHEAD =
..a
ACTUATOR =
KB. ELEV = FMG
BAKER C
68.1'
BF. ELEV = ~
KOP = .........931'
Max Angle = 95° @ 11933'
Datum MD =
Datum TVD = N/A
8800' SS
9-518" CSG, 40#, L-80, ID = 8.835"
SAFETY S: W ELL ANGLE > 70° @ 9712' .
1 /~ ~ ***4-1l2" OME TBG"**ORIGINAL & 15-45A
® WELLBORES NOTSHOWN BELOW WHIPSTOCK"*"
4-1/2" HE5 X NIP, ID = 3.813"
GAS LIFT MANDRELS
Minimum ID = 2.37" @ 9002'
3-3/16'" LINER TOP PACKER
4-1/2" TBG, 12.6#, 13CR80 VAM TOP, I-~ 9022,
.0152 bpf, ID = 3.958"
4-1/2" TBG STUB (DIMS 05113/05) 9023'
TOP OF 4-112" LNR 9080'
4-1/2"-TBG, 12.6#, L-80 BTGM, 9091'
.0152 bpf. ID = 3.958"
7" CSG, 26#, L-80, ID = 6.276 9258'
PERFORATION SUMMARY
REF LOG: BKR MWDlGR ON 02/12!08
ANGLE AT TOPPERF: 88° @ 10250'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2" 6 10250 - 10270 O 07/25/09
2" 6 10420 - 10445 O 07/25109
2" 6 10445 - 10470 O 07/25/09
~3-1/2" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" (-j g373,
WHIPSTOCK 9398'
4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" 9398'
RA TAG (02/07/08) 9408'
3-3(16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" (-j 9999'
PBTD 12034"
2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441"
DATE REV BY COMMENTS DATE REV BY COMMENTS
05/04/96 ORIGINAL COMPLETION
09/09/00 JOM CTD SIDETRACK {15-45A}
05/15!05 D16 RWO
02/16!08 NORDIC 1 CTD SIDETRACK {15-456)
03/08/08 DAV(PJC GLV GO {02/22/08)
11/11/09 AWIJMD DRLG DRAFT CORRECTIONS
(a7/24/09>
PRUDHOE BAY UNfT
WELL: 15-45B
PERMIT: 2071790
API No: 50-029-22671-02-00
SEC 22, T11 N, R14E, 531' FNL & 99' FWL
BP Exploration {Alaska)
ST MD TVD DEV TYPE VLV LATCH PORT DATE
4 3355 3157 32 KBG-2 DOME BK 16 02/22!08
3 5561 5012 35 KBG-2 SO BK 20 02!22/08
2 7436 6597 26 KBG-2 DMY BK 0 05!14105
1 8846 7899 19 KBG-2 DMY BK 0 05/14/05
$j y15. ~-j 4-112" HES X NIP, ID = 3.813""
8936' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875"
8959' 4-112" HE5 X NIP, ID = 3.813"
9002' BKR. LTP SEAL BORE, ID = 2.37"
9032' 7"X4-1/2"UNIQUEOVERSHOT
9056' 7" X 4-112" BKR S-3 PKR, ID = 3.875"
9079' 4-112" HES X NIP, ID = 3.812"
9091' 4-112" WLEG, ID = 3.958"
C____~- ELMD TT NOT LOGGED
9299' ~ 3.70" BTT DEPLOYMENT SLV w (4" GS
PROFILE, ID = 3.00"
9340° 4-112" HES X NIP, ID = 3.812"
MILLOUT WINDOW (15-456) 9398' - 9404'
3-1/2" X 3-3/16" XO, ID = 2.786"
~ 3-3/16" X 2-7/8" XO, ID = 2.387" ~
`4.. r. ..
~ .~
aL I
_ ,y~a.y.
MICROFILMED
6/30/2010
DO .NOT PLACE
ANY NEW MATERIAL
UNDER THiS PAGE
C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc
C~
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
January 1, 2010
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7t" Avenue
Anchorage, Alaska 99501
•
~~
`~ ~ 20t,
aa~y x`79
~ s ~ ~ 5 ~3
Subject: Corrosion Inhibitor Treatments of GPB DS 15
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS
15 that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Anna Dube.
Sincerely,
Torin Roschinger
BPXA, Well Integrity Coordinator
• •
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
DS-15
r)atP~ 01/n5/10
r
Well Name
PTD #
API #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft na al
15-01 B 2042570 50029206960200 NA Sealed NA
15-026 2060720 50029206970200 NA Sealed NA
15-03 1820300 50029207220000 NA Sealed NA
15-046 2071380 50029207260200 NA Sealed NA
15-05A 1950340 50029207310100 NA Sealed NA
15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009
15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009
15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009
15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009
15-10A 1880850 50029205010100 NA Sealed NA
15-11 B 2041460 50029206530200 NA Sealed NA
15-126 2060870 50029206650200 NA Sealed NA
15-13A 1991240 50029206450100 NA Sealed NA
15-14A 2042220 50029206820100 NA Sealed NA
15-15C 2081820 50029206910300 NA Sealed NA
15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009
15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009
15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009
15-19A 1990990 50029218290100 NA surface NA
15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009
15-21A 1990290 50029205030100 NA Sealed NA
15-22 1800970 50029205090000 NA Sealed NA
15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009
15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009
15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009
15-268 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009
15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009
15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009
15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009
15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009
15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009
15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009
15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009
15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009
15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009
15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009
15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009
15-38A 2030160 50029224960100 NA Sealed NA
15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009
15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009
15-418 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009
15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009
15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009
15-458 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009
15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009
15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009
15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009
15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009
STATE OF ALASKA ~
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
%I~~G!
~~~~~~~~
1. Operations Abandon ~ Repair Well Plug Perforations ~ Stimulate ~ Other ~~: : Q~
Performed: Alter Casing ~ Pull Tubing ~ PerForate New Pool ~ Waiver~ Time E
x
te
ns
i
on
t
~
~~
~
~
Change Approved Program ~ Operat. Shutdown~ Perforate Q- Re-enter Suspe~tR~W~~ fJ3'3 ~ii~h~, (~~t~tfnjwSj
2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Num ,~tc~t,~r~~g
rvame: De~lopment ~ - Exploratory ~ 207-1790 ,
3. Address: P.O. Box 196612 Stratigraphic I~ Service ~ 6. API Number:
Anchorage, AK 99519-6612 50-029-22671-02-00 -
7. KB Elevation (ft): 9. Well Name and Number:
68.06 KB- PBU 15-45B '
8. Property Designation: 10. Field/Pooi(s):
ADLO-028306 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool
11. Present Well Condition Summary:
V
Total Depth measured 12094 ~ feet Plugs (measured) 10650' 7/24/09
true vertical 8823.65 - feet Junk (measured) None
Effective Depth measured 12034 - feet
true vertical 8821.91 ~ feet
Casing Length Size MD TVD Burst Collapse
Conductor 110 20" 91.5# H-40 Surface - 110 Surface - 110 1490 470
Production 3829 9-5/8" 40# L-80 Surface - 3829 Surface - 3554 5750 3090
Liner 9258 7" 26# L-80 Surface - 9258 Surface - 8287 7240 5410
Liner 318 4-1/2" 12.6# L-80 9080 - 9389 8119 - 8419 8430 7500
Liner 3289 3-1/2'X3-3/16"X2-7/8" 9002 - 12087 8046 - 8823
9.2# 6.2# 6.5# L-80
Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _
True Vertical depth: _ _ _ _ _
Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 9022'
0 0 -
Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 8936'
7"X4-1/2" BKR S-3 PKR 9056'
BAKER LINER TOP PKR 9002'
0 0
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
~~~~~-%7 !'~~ ~ « i~ ~~~~
~~:
~,
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbi Gas-Mcf Water-Bbl Casing Pressure Tubing pressure
Prior to weli operation: 677 41295 17 1024
Subsequent to operation:
14. Attachments: 15. Well Class after aroposed work:
Copies of Logs and Surveys Run Exploratory ~ Dev~elopment ~~ Service ~
Daily Report of Well Operations X 16. Well Status after proposed work:
Oil ~~ Gas ~ WAG ~ GINJ ~ WINJ I~ WDSPL ~
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Gary Preble
Printed Name Gary Prebl Title Data Management Engineer
r~
.
Signature~ Phone 564-4944 Date 7/27/2009
Form 10-404 Revised 04/2006 ~„ ~~~ ~'-~~ ~~~a~~ Submit Origir~a
~-i~' ~.--~/o~
15-45B
207-179
PERF ~4TTACHMENT
•
Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base
15-45B 2/15/08 PER ' 10,810. 11,680. 8,834.71 8,839.53
15-45B 2/15/08 PER ~ 11,930. 12,020. 8,826.96 8,821.81
15-45B 7/24/09 BPS 10,650. 10,655. 8,836.49 8,836.25
15-45B 7/25/09 APF 10,250. 10,270. 8,823.55 8,824.14
15-45B 7/25/09 APF 10,420. 10,445. 8,833.16 8,834.09
15-456 7/25/09 APF 10,445. 10,470. 8,834.09 8,835.13
AB ABANDONED PER PERF
APF ADD PERF RPF REPERF
BPP BRIDGE PLUG P ULLED SL SLOTTED LINER
BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED
FCO FILL CLEAN OUT SPS SAND PLUG SET
FIL FILL SQF SQUEEZE FAILED
MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE
MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED
MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN
OH OPEN HOLE
•
~ ~
15-45B
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
BBLS
1 diesel
1 Total
osios/os
•
~~
Sch~~erg~r
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
Log Description
NO.5271
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Date BL Color CD
H-35 AYTO-00018
_
CROSS FLOW CHECK ~ 05/09/09 1 1
14-35 ANHY-00087 INJECTION PROFILE
~ 05/15/09 1 1
06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESSIT P 05/11/09 1 1
A-44 AWLS-00017 SCMT 05/25/09 1 1
12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1
09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1
H-29A AYOO-00027 PPROF/RST 05/19/09 1 1
09-09 AYTU-00032 CROSS FLOW CHECK - `a- , 05/06/09 1 1
15-45B ANHY-00010 PRODUCTION PROFILE '~- 05/09/09 1 1
13-13A AYTU-00033 USIT - `~~ / ~ 05/08/09 1 1
M-196 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1
Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1
E-36A B1JJ-00018 MEM CNUSTP j` 05/18/09 1 1
X-30A 62WY-00005 MEM PROD PROFILE a 05/10/09 1 1
12-23 AYKP-00021 USIT G - 05/08/09 1 1
W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1
Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • ~- 05/20/09 1 1
L1-21 B2NJ-00006 PRODUCTION PROFILE 05/24/09 1 1
A-31A AZCM-00023 USIT ~ - Q ~ G 05/22/09 1 1
H-19B' B2WY-00004 MEM PROD PROFILE L 05/07/09 1 1
G-16 AYKP-00022 SCMT / J - 05/09/09 1 1
M-19B AY3J-00024 SCMT - 05/15/09 1 1
f2-37 AWLS-00032 PRODUCTION PROFILE _ ~,f~ r 04/21/09 1 1
11-04A AYOO-00028 USIT J L~ _ 05/21/09 1 1
18-30 B1JJ-00015 MEM PROD PROFILE jG/ 05/13/09 1 1
4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - - ! 05/11/09 1 1
3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1
3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1
V-217 AYOO-00024 INJ PROFILE/RST WFL ~ l~dl5 04/26/09 1 1
PLEASE AGKNUWLEUGE NEGEIPI I3Y SIGNINGi ANU HEI UriNIN(a UNG I:UPY EAGtt I U:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
- a~~j,~ ~~ lac
DATA SUBMITTAL COMPLIANCE REPORT
1 /7/2009
Permit to Drill 2071790 Well Name/No. PRUDHOE BAY UNIT 15-45B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22671-02-00
MD 12094 TVD 8824 Completion Date 2/16/2008 Complet ion Status 1-OIL Current Status 1-OIL UIC N
REQUIRED INFORMATION
Mud Log No Samples No Direction al Survey Yes
DATA INFORMAT ION
Types Electric or Other Logs Run: MWD / DIR / GR, 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 /
Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments
,(ftD D Asc Directional Survey 10019 12094 Open 3/10/2008 ~'
~ Directional Survey 10019 12094 Open 3/10/2008
D Asc Directional Surve
Y 9381 10265 O en
P 3/10/2008 PB 1
~2pt Directional Survey 9381 10265 Open 3/10/2008 PB 1
~
` I
uLog 16106
eutron 2 Btu 8920 11946 4/10/2008 MCNL, GR, CCL, w/Carrier !, y
14-Feb-2008 w/PDS
graphics
'~ LIS Verification 9243 12096 Open 4/28/2008 LIS Veri, GR, ROP, RAD, ~~
~
// //
~ RAS, RPD, RPS
'
/ED C Lis 16169
nduction/Resistivity 9243 12096 Open 4/28/2008 LIS Veri, GR, ROP, RAD, i ~
RAS, RPD, RPS
~tpt LIS Verification 9243 10270 Open 4/28/2008 PB1 LIS Veri, GR, ROP,
RAD, RAS, RPD, RPS
~D C Lis 16170 ~nduction/Resistivity 9243 10270 Open 4/28/2008 PB1 LIS Veri, GR, ROP, t
RAD, RAS, RPD, RPS
Log Induction/Resistivity 25 Col 9398 12096 Open 4/29/2008 MD MPR, GR 12-Feb-2008
og Induction/Resistivity 25 Col 9398 12096 Open 4/29/2008 TVD MPR, GR 12-Feb-
2008
„Log Gamma Ray 25 Col 9398 12096 Open 4/29/2008 MD GR 12-Feb-2008
~
g See Notes 2 Col 9250 12050 Open 4/29/2008 Depth Shift Monitor Plot I'
//
/Log Induction/Resistivity 25 Col 9398 10265 Open 4/29/2008 PB1 MD MPR, GR 12-Feb-
-~.r'
I
,2~-
-~a+- 2008
-
/Log
Gamma Ray
25
Col
9398
10265
Open
4/29!2008 FelYtObS
P61 MD GR 12-Feb-2008 'i
i
i
r:
DATA SUBMITTAL COMPLIANCE REPORT
1 /7/2009
Permit to Drill 2071790 Well Name/No. PRUDNOE BAY UNIT 15-458 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22671-02-00
MD 12094 TVD 8824 Completion Date 2/16/2008 Completion Status 1-OIL Current Status 1-OIL UIC N
___
_ _ _
og See Notes 2 Col 9250 10225 Open 4/29/2008 P61 Depth Shift Monitor
Plot
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? Y~
Chips Received? Y-F#--
Analysis 1"~"I~
Received?
Comments:
Compliance Reviewed By: __ ___
Daily History Received? ~/ N
Formation Tops QN
Date ~ _ ._ v.~. ~~~
r:
i
Page 1 of 1
Maunder, Thomas E (DOA)
From: Schnorr, DeWayne R (PRA) [DeWayne.Schnorr@bp.com]
Sent: Tuesday, April 29, 2008 5:03 PM
To: Maunder, Thomas E (DOA); Hubble, Terrie L; Stewman, Sondra D
Subject: RE: PBU 15-458 (207-179)1
Hi Tom. Yes, part of the 13 is missing along with day 14 and 15.'
We will correct this and send new copies. _ GS ~~
Thanks DeWayne ~M~~rS~~ °~~'P ~~
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] I~~ ~/ P~
Sent: Tuesday, April 29, 2008 4:25 PM i% V ~ /rC--C~~S
To: Hubble, Terrie L; Stewman, Sondra D; Schnorr, DeWayne R (PRA)
Subject: PBU 15-45B (207-179)1
Ladies and DeWayne,
I am reviewing the recently submitted 407 for this well.
The operational summary ends on 2/13/08 at 11:45
making up the liner.
It appears that the summary is not complete.
Could you send the remaining summary?
Email is fine.
Call or message with any questions.
Tom Maunder, PE
AOGCC
4/29/2008
COMYAN Y
WELL NAME
FIELD
~~:~,
BAKER
Ni/6NE5
Baker Atlas
PRINT DISTRIBUTION LIST
BP EXYLURAI'IUN (ALASKA) INC CUUNCY NUK'1'H SLUYE BUKUUUH
I S-45BPB 1 STATE ALASKA
PRUDHOE BAY UNIT
DATE 4/25/2008
THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY
SO #: 1809593
Copies of Copies Digital Copies of Copies Digital
Each Log of Film Data Each Log of Film Data
2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OII, & GAS
Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS
Address LR2-I Address 550 WEST 7TH AVE
900 E BENSON BLVD. SUITE 802
ANCHORAGE AK 99508 ANCH RAGE AK 99501
1 Company EXXON MOBIL PRODUCTION CO Company
Person FILE 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
ao~-l~~
Page 1 of 1
•
COMPANY
WELL NAME
FIELD
r, n . ~ ,
BAKER
F~t~6F~E5
Baker Atlas
PRINT DISTRIBUTION LIST
BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH
IS-45B STATE ALASKA
PRUDHOE BAY UNIT DATE 4/25/2008
THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY
SO #: 1809593
Copies of Copies Digital Copies of Copies Digital
Each Log of Film Data Each Log of Film Data
2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL Bc GAS
Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS
Address LR2-I Address 550 WEST 7TH AVE
900 E BENSON BLVD. SUITE 802
ANCHORAGE, AK 99508 ANCHORAGE. AK 99501
1 Company EXXON MOBIL. PRODUCTION CO Company
Person FILE ROOM Person
Address 800 BELL STREET Address
EMB GSC 3082A
HOUSTON, TX 77002
1 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 Bv:
~6`~-!~
Page 1 of 1
INTEQ Log & Data Transmittal Form
To: State of Alaska -AOGCC
333 W. 7th Ave.
Suite 100
Anchorage, Alaska 99501
Attention: Christine Mahnken
Reference: 15-458 & 15-45BPB1
Contains the following:
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
1 color prints - GR Directional Measured Depth Log (to follow)
1 color prints - MPR/Directional TVD Log (to follow)
1 color prints - MPR/Directional Measured Depth Log (to follow)
LAC Job#: 1809593
av~-/~~'
/~~9
~~i~d
Sent by: Catrina Guidry Date: 04/25!08
~~
Received by: ~
Date: L~,l ~~~ C(~
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COPY
FAX: (907) 267-6623
~6NE5
Il~(TEQ
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska 99518
Direct: (907) 267-6612
FAX: (907) 267-6623
04/09/08
~~~
a
NO. 4657
Alaska Data & Consulting Services Company: State of Alaska
2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: P.Bay, Endicott, Orion
Well Job # Loa Description Date BL Color CD
03-10 12045070 USIT -~ 03/24/08 1 1
1-21/K-25 11998996 USIT 03/25/08 1 1
V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1
V-214 11978449 MI INJECTOR U - ~ (p t Q 04/01/08 1 1
18-13B 12061689 PRODUCTION PROFILE ~ _"~~ '~ 03/27/08 1 1
E-10A 11998994 USIT (~ '~ 03/28/08 1 1
02-12B 11628789 MCNL a / ! U "-' 08/21/07 1 1
15-45B 11963079 MCNL Q 02/14/08 1 1
V-220 12031459 CH EDIT PDC GR (USIT)~CS~ ((o d 03/07/08 1
V-214 40016214 OHMWD/LWD 04/01/08 2 1
_~ .1,
-\
P-- -• -
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EACH TO:
BP Exploration (Alaska) Ina + ~ -
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
°~,1~.?
Date Delivered:
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-28
ATTN: Beth \
Received b Y
~s~>_ ~~. Y~`~
BAKER
FIt~GNES
INTEQ 7260 Homer Drive
.Anchorage, Alaska 99518
Te1907-267-6600
Fax 907-267-6623
To Whom It May Concern: March 7, 2008
Please find enclosed directional survey data for the following wells:
A-12A
OS-13B
15-45BPB 1 ~
15-45B /
18-32B
C-35B
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: U ,State of Alaska AOGCC
DATE: ~ 6 ~ S
Cc: State of Alaska, AOGCC
ads-i~~
' ' STATE OF ALASKA ~ ~~
ALASKA'61L AND GAS CONSERVATION COMI~SION
FtE~E1VED
MAR o s zoos
WELL COMPLETION OR RECOMPLETION EPOR A G
~~~ ,~~,,,)°~a~ca Oit ~ Gas Cons. Commission
A ~~--_
1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended
zoAAC zs.,os zoAAC zs.,,o
^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class:
®Development ^ Exploratory
^ Service ^ Stratigraphic
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban
2/16/2008 12. Permit to Drill Number
207-179
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded
2/7/2008 ~ 13. API Number
50-029-22671-02-00 `
4a. Location of Well (Governmental Section):
Surface:
'
' 7. Date T.D. Reached
2/12/2008 ~ 14. Well Name and Number:
PBU 15-45B
4749
FSL, 5180
FEL, SEC. 22, T11 N, R14E, UM
Top of Productive Horizon:
2802' FSL, 821' FEL, SEC. 16, T11 N, R14E, UM
8. KB (ft above MSL): 68.06'
Ground (ft MSL):
15. Field /Pool(s): ,
Prudhoe Bay Field / Prudhoe Bay
Total Depth:
2453' FSL, 4196' FEL, SEC. 15, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD)
12034 _ 8822 Pool
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 676014 y- 5960952 Zone- ASP4 10. Total Depth (MD+TVD)
12094 - 8824 16. Property Designation:
ADL 028306'
TPI: x- 675009 y- 5964262 Zone- ASP4
Total Depth: x- 676922 y- 5963958 Zone- ASP4 11. SSSV Depth (MD+TVD)
None 17. Land Use Permit:
18. Directional Survey ®Yes ^ No
Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore
N/A ft MSL 20. Thickness of Permafrost (TVD):
1900' (Approx.)
21. Logs Obtained (List all logs here and submit electronic and printed inform ion per 20 AAC 5.071):
MWD DIR / GR, GR / CCL / CNL L~/j^/ /~~ 3 ~Md ~~ q rya
22. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT
WT. PER FT. GRADE TOP BOTTOM ' TOP BOTTOM SIZE CEMENTING RECORD PULLED
20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set A rox.
9-5/8" 40# L-80 Surface 3829' Surface 3554' 12-1/4" 305 sx'G', 1085 sx CS III, 200 sx CS I
7" 26# L-80 Surface 9258' Surface 8287' 8-1/2" 230 sx Class 'G'
4-1/2" 12.6# L-80 9080' 8119' 8419' 6" 220 sx Class 'G'
3-1/2"x3-31,6"x2-t/8" ,2#/6,2#/6,5# L-80 9002' 12087' 8046' 8823' 4-1/8" 169sxClass'G'
23. Open to production or injec tion? ®Yes ^ No 24. TuewG RECORD
If Yes, list each i
(MD+TVD of Top & Bottom; Pe nterval open
rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD
2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 / L-80 9091' 8936' & 9056'
MD TVD MD TVD
10810' - 11680' 8835' - 8840'
11930' - 12020' 8827' - 8822' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED
6000' Freeze Protect w/ 90 Bbls of Diesel
26. PRODUCTION TEST
Date First Production:
March 1, 2008 Method of Operation (Flowing, Gas Lift, etc.):
Flowing
Date Of Test:
2/28/2008 HOUfS Tested:
6 PRODUCTION FOR
TEST PERIOD OIL-BBL:
ggg GAS-MCF:
5,155 WATER-BBL:
.25 CHOKE SIZE:
128 GAS-OIL RATIO:
5,737
Flow Tubing
Press. 176 CBSIng PfeSS:
1,320 CALCULATED
24-HOUR RATE OIL-BBL:
3,594 GAS-MCF:
20,620 WATER-BBL:
1 OIL GRAVITY-API (CORK):
27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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.
OOIv;Pi.ri;CiPJ '-
None a ~ED
f
Form 10-407 Revised 02/2007 ~ ~ CONTINUED ON REVERSE SIDE ~~k `~ '~ f
1 (~
28. GEOLOGIC MARKERS LIST ALL FORMATIONS AND RS 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.
Sadlerochit 9295' 8322' None
Top CGL /Zone 3 9449' 8468'
Base CGL I Zone 2C 9510' 8527'
23SB /Zone 26 9560' 8572'
22TS 9623' 8622'
21TS /Zone 2A 9837' 8696'
Zone 1 B 10032' 8782'
TDF /Zone 1 A 10055' 8793'
Formation at Total Depth (Name):
TDF /Zone 1 A 10055' 8793'
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ fa/ _~
~
Signed Terrie Hubble Title Drilling Technologist Date / ~v
PBU 15-45B 207-179 Prepared By NameMumber. Terrie Hubble, 564-4628
Well Number Drilling Engineer: Abby Higbie, 564-5480
Permit No. / A royal No.
INSTRUCTIONS
GeNew-~: 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 downhofe well design is changed.
IreM 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.
frets 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.
IreM 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-fn, 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
i +~
BP EXPLORATION
Operations Summary Report
Page 1 of 7
Legal Well Name: 15-45
Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
,Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
i
Date ~ From - To Hours , Task Code' NPT ~ Phase Description of Operations
12/3/2008 07:00 - 10:00 3.00 RIGD P PRE Prep rig for movinng off well.
10:00 - 10:15 0.25 RIGD P PRE PJSM for Pulling off well.
10:15 - 11:00 0.75 RIGD P PRE Move rig off well and spot for BOP stack teardown.
11:00 - 00:00 13.00 RIGD P PRE Continue with stack teardown. Replace Hydril and double gate.
2/4/2008 00:00 - 01:00 1.00 RIGD P PRE Continue with BOP stack rebuild
01:00 - 06:00 5.00 RIGD P PRE Secure BOP stack in cellar. Lay down wind walls. Scope
down derrick. Lay down derrick.
06:00 - 08:00 2.00 RIGD P PRE Prep for move
08:00 - 09:00 1.00 MOB P PRE Move rig from DS 5 to pad 10
09:00 - 14:00 5.00 RIGU P PRE Raise derrick and wind walls
14:00 - 18:30 4.50 MOB P PRE Move from Pad 10 to DS 15
18:30 - 21:30 3.00 RIGU P PRE Waiting on drill site maintenance crew to install work platform
and ladder on tree. Install tubing straightener on injector, spot
', equipment on pad, meet with DSO for unit work permit. PJSM
for backing over well
21:30 - 22:30 1.00 RIGU P PRE Back over well. Set cuttings box. RU tiger tank and hardline
22:30 - 00:00 1.50 RIGU P PRE RIG ACCEPT AT 22:30.
NU BOP stack
2/5/2008 00:00 - 09:30 9.50 RIGU P PRE NU BOP, install drip pan. Ru hydraulic lines to PU new coiled
tubing reel and MU hard line. Spot tiger tank and RU hardline.
Spot satellite camp. Open doors on BOP rams and found hard
cement around rams, chip away same. ND Stack and clean off
debree from top of swab valve and from stack (2-3 gallons).
NU BOP
09:30 - 12:00 2.50 RIGU P PRE Remove injector from stabbing box. M/U guide arch.
12:00 - 19:00 7.00 BOPSU P PRE Pressure /Function test
19:00 - 22:00 3.00 BOPSU N SFAL PRE During drawdown test discovered opening hoses from hydril
and pipe rams were crossed. Hoses were not properly labeled
when removed from stack for component repairs. Traced lines
and confirmed that all hoses were installed correctly. Attaching
proper labels to all hoses to stack.
22:00 - 23:00 1.00 BOPSU P PRE Re test hydril and upper pipe rams. Drawdown test.
23:00 - 00:00 1.00 BOPSU P PRE PJSM, pull BPV. PT lubricator and pull BPV. 700 psi on well.
Attempt to bleed off to TT failed dueapparently to an ice plug
2/6/2008 00:00 - 01:00 1.00 BOPSU P PRE Attempt to thaw ice plug in hard line to tiger tank. Prep to pull
coil from reel to injector.
01:00 - 02:30 1.50 RIGU P PRE Pull coil into injector. Dress end of coil.
02:30 - 04:30 2.00 RIGU P PRE Slack management. Cut 123' of coil
04:30 - 05:00 0.50 STWHIP P WEXIT Install SLB CTC, pull test.
05:00 - 08:30 3.50 STWHIP P WEXIT MU Coiltrak UQC, -35F requires circulating through coil every
25 min.
Track down a-line leak in connection at UQC. Tested OK.
Press test UOC and CTC with 4000 psi. OK.
08:30 - 10:45 2.25 STWHIP P WEXIT Bleed off WHP from 1000 psi to 250 psi to Tiger tank. WHP
not bleeding to zero.
Bullhead 72 bbls Biozan, 4 bpm at 1500 psi, IAP and OAP = 0
psi.
Bleed WHP to 50 psi, still have slight gas flow at surface.
Not able to bullhead gas away due to whipstock packer.
10:45 - 11:30 0.75 STWHIP P WEXIT PJSM. M/U nozzle BHA #1 to bottom kill well.
11:30 - 13:30 2.00 STWHIP P WEXIT RIH with nozzle BHA. Circ at 0.7 bpm with returns thru choke
to Tiger tank.
RIH to 9370'.
Printed: 2/13/2008 2:42:58 PM
BP EXPLORATION Page 2 of 7
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours ', Task Code NPT ! Phase. Description of Operations
'~
2/6/2008 13:30 - 15:00 1.50 --
STWHIP -- _
P WEXIT Circ bottoms up thru choke to tiger tank, 2.5 bpm, 2500 psi.
Circ until returns are steady, gas free and 8.3 ppg.
15:00 - 17:30 2.50 STWHIP P WEXIT POH while Circ at 2.6 bpm, clean returns, full returns.
17:30 - 17:45 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for M/U window milling BHA.
17:45 - 18:15 0.50 STWHIP P WEXIT M/U 3.80" window milling BHA #2 with 3.80" HCC window mill
and reamer and Xtreme motor, 2 jts PH6 and BHI CoilTrak
tools. BHA OAL = 112.59'.
1 :1 - 2 :1 2.00 STWHIP P WEXIT RIH with millin BHA
s~~'C' 20:15 - 22:00 1.75 STWHIP P WEXIT Dry tag at 9395' CTMD. PUH to 9380', pump on line at 2.57
~C, u $ 4
J BPM ~ 2250 CTP. Tag at 9393.4'. Start time milling from
9393.0'. Motor work at 9393.4', set depth to 9398.0'. Gas in
returns, divert to tiger tank. Coiltrak: 300 differential presure,
zero WOB
22:00 - 00:00 2.00 STWHIP P WEXIT 9399.1', 2.55 BPM ~ 2560 CTP. Coiltrak: 460 DP, 1800 WOB
2/7/2008 00:00 - 02:30 2.50 STWHIP P WEXIT Milling 3.80" window at 9400.6' off Baker whipstock in 4-1/2" ,
liner. TOWS = 9398'.2.49 BPM ~ 2590 CTP. Coiltrak data:
588 Differential pressure, 3800 WOB
02:30 - 04:05 1.58 STWHIP P WEXIT 9402.6', 2.53 BPM ~ 2520 CTP. Coiltrak: 420 DP, 2000 WOB
04:05 - 05:15 1.17 STWHIP P WEXIT 9404.5', appears to be through liner. Continue at 10 FPH with
400 DP, WOB increasing to 4000. 9404.9', 600 DP, 5000
WOB
05:15 - 06:00 0.75 STWHIP P WEXIT 9406.5', start disposing BIO to make room for Flo-pro.
06:00 - 07:00 1.00 STWHIP P WEXIT 9414'. Ream window with up down passes at 1 FPM. Ream
window up and down 3 times.
Dry tag PBTD, OK. Clean window.
07:00 - 08:30 1.50 STWHIP P WEXIT POH with window milling BHA.
08:30 - 08:45 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for L/O milling BHA and M/U drilling BHA.
08:45 - 09:00 0.25 STWHIP P WEXIT Lay out milling BHA. Window mill and reamer gauged at 3.80"
Go and 3.79" No-Go.
09:00 - 10:15 1.25 DRILL P PROD1 M/U BHI CoilTrak Build BHA #3 with HYC BC Bit, 2.7 deg
Xtreme motor and CoilTrak tools.
BHA OAL = 66.04'.
10:15 - 12:10 1.92 DRILL P PROD1 RIH with BHA #3. Circ. at min rate.
12:10 - 13:00 0.83 DRILL P PROD1 Log down with GR for tie-in. Added 6' to CTD.
13:00 - 13:10 0.17 DRILL P PROD1 RIH clean thru window. 22.5K down wt.
Tag bottom at 9412'.__
13:10 - 15:20 2.17 DRILL P PROD1 Drill build /turn section in Z4 and Z3. 2.6 bpm, 3000-3600 psi,
2 K wob, 120R, 12 deg incl, 30 fph,
Drilled to 9485'.
15:20 - 17:00 1.67 DRILL P PROD1 Drill build /turn section in Z3 and Z2. 2.6 bpm, 3000-3600. psi,
2 K wob, 70R, 20 deg incl, 40-60 fph,
Drilled to 9550'.
17:00 - 17:15 0.25 DRILL P PROD1 Wiper trip to window. Clean hole.
17:15 - 19:55 2.67 DRILL P PROD1 Drill build /turn section in Z2. 2.6 bpm, 3000-3600 psi, 2 K
wob, 30R, 30 deg incl, 60-80 fph,
Drilled to 9700'.
19:55 - 20:20 0.42 DRILL P PROD1 9700', wiper trip to window. Clean hole
20:20 - 21:55 1.58 DRILL P PROD1 Drill build /turn section in Z2. 2.6 bpm, 3000-3600 psi, 4 K
wob, 60R, 54 deg incl, 80-120 fph,
21:55 - 22:25 0.50 DRILL P PROD1 9850', wiper trip to window.
22:25 - 22:35 0.17 DRILL P PROD1 9420', log down for tie-in. +1.5' correction.
Printed: 2/13/2008 2:42:58 PM
BP EXPLORATION Page 3 of 7
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours Task ', Code NPT Phase Description of Operations
2!7/2008 22:35 - 23:00 0.42 DRILL P PROD1 Wiper back to bottom
23:00 - 00:00 1.00 DRILL P PRODi Drill build /turn section in Z2. 2.6 bpm, 3000-3600 psi, 2 K
wob, 110R, 79 deg incl, 100-120 fph, at 9875' turned tool to
140L. Drilled to 9950'.
2/8/2008 00:00 - 02:45 2.75 DRILL P PROD1 POH with Build BHA.
02:45 - 03:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and
mitigation for C/O Drilling BHA.
03:00 - 04:15 1.25 DRILL P PROD1 M/U Lateral /RES CoilTrak BHA #4 with HCC BC Bit #2, 1.4
deg Xtreme motor, RES and CoilTrak tools.
BHA OAL = 78.96'.
04:15 - 04:45 0.50 DRILL N SFAL PROD1 Perform maintenance on SWS injector head, replaced upper
traction accumulator bottle.
04:45 - 07:00 2.25 DRILL P PROD1 RIH with Lateral /RES BHA. Circ at min rate.
07:00 - 07:30 0.50 DRILL P PROD1 Log GR tie-in at RA tag at 9407.5'. Added 6' to CTD.
07:30 - 08:15 0.75 DRILL P PROD1 Log down with RES tool to bottom at 900 fph.
08:15 - 10:00 1.75 DRILL P PROD1 Drill Z1B lateral with RES tool, 2.6 bpm, 3100-3600 psi, 1-2K
wob, 58 deg incl, 110E TF, 9.9 ECD, 50 fph,
Drilled to 10,050'.
10:00 - 11:00 1.00 DRILL P PROD1 Drill Z1B lateral with RES tool, 2.6 bpm, 3100-3600 psi, 1-2K
wob, 59 deg incl, 80R TF, 9.9 ECD, 50 fph,
Drilled to 10,100'.
11:00 - 11:45 0.75 DRILL P PRODi Wiper trip to window. Clean hole. RIH clean to bottom.
11:45 - 13:00 1.25 DRILL P PROD1 Drill Z1B lateral with RES tool, 2.6 bpm, 3100-3600 psi, 1-2K
wob, 65 deg incl, 5R TF, 10.0 ECD, 40 fph,
Drilled to 10,162'.
13:00 - 15:00 2.00 DRILL P PROD1 Drill Z1A lateral with RES tool, 2.6 bpm, 3100-3600 psi, 1-2K
wob, 75 deg incl, 40L TF, 10.0 ECD, 20 fph,
Drilled to 10,200'.
15:00 - 16:15 1.25 DRILL P PROD1 Drill Z1A lateral in 15N shale, 2.6 bpm, 3100-3600 psi, 1-2K
wob, 75 deg incl, 20L TF, 10.0 ECD, 20 fph,
Drilled to 10,212'.
16:15 - 17:00 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom.
17:00 - 18:20 1.33 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3100-3600 psi, 1-2K wob, 80 deg
incl, 30L TF, 10.0 ECD, 30 fph,
Drilled to 10 235'.
18:20 - 21:00 2.67 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3100-3600 psi, 1-2K wob, 80 deg
incl, 30L TF, 10.0 ECD, 10 fph.
Drilling has gotten progessivly worse. Geologist discussing
possible side track.
Drilled to 10265'
21:00 - 21:30 0.50 DRILL P PRODi Wiper trip to window while waiting on town geologists to
discuss
21:30 - 00:00 2.50 DRILL C PRODi POOH for open hole sidetrack
2/9/2008 00:00 - 01:30 1.50 STKOH X WAIT PROD1 Waiting on BTT and open hole side track aluminum billet and
anchor
01:30 - 03:30 2.00 STKOH C PROD1 MU aluminum billet, open hole anchor, BHI tool string with
orienter.
03:30 - 05:45 2.25 STKOH C PROD1 RIH with aluminum billet
05:45 - 06:00 0.25 STKOH C PROD1 Tie in from 9310'. Correction +6'.
06:00 - 06:35 0.58 STKOH C PRODi Close EDC, continue RIH to set depth of 10031', top of billet at
10020'
06:35 - 06:45 0.17 STKOH C PROD1 Set AL Billet with top at 10,020'. 20R TF on top edge of Billet.
Setting tool sheared at 3600 psi.
Printed: 2/13/2008 2:42:58 PM
~ ~
i
BP EXPLORATION Page 4 of 7
Operations Summary Report
Legal Well
Common W
Event Nam
Contractor
Rig Name:
Date
__ Name: 1
ell Name: 1
e:
Name:
From - To 5-45
5-45A
REENTE
NORDIC
NORDIC
Hours
R+COM
CALIS
1
Task
PLET
TA
Code
E
NPT
Start
Rig
Rig
Phase
__ I
Spud Date: 4/8/1996
: 2/4/2008 End:
Release:
Number: N1
~, Description of Operations
-- -__ __
2/9/2008 06:35 - 06:45 0.17 STKOH C PROD1
06:45 - 09:00 2.25 STKOH C PROD1 Pick up clean off top of Billet. POH clean thru open hole and
window.
POH while circ at 1.5 bpm.
09:00 - 09:30 0.50 STKOH C PROD1 L/O BHA. BTT running tools looked OK.
09:30 - 09:45 0.25 STKOH C PROD1 SAFETY MEETING. Review procedure, hazards and
mitigation for cutting coil for pipe management and M/U
sidetrack BHA.
09:45 - 10:15 0.50 STKOH C PROD1 Cut 100' of coil with hyd cutter.
M/U CTC and pull test.
M/U BHI UOC and test E-Line.
10:15 - 11:45 1.50 STKOH C PROD1 ,lN/U BHI Billet Sidetrack BHA #6 with 3.75" HCC STR335 Bit
#3 with 1.7 deg Xtreme motor and Coiltrak.
BHA OAL = 65.80'.
11:45 - 13:45 2.00 STKOH C PROD1 RIH, circ at min rate.
13:45 - 14:00 0.25 STKOH C PRODi Log GR tie-in at RA tag. Added 4' CTD.
14:00 - 14:30 0.50 STKOH C PROD1 RIH clean. Tagged AL Billet at 10,020.2'. Pick up and circ at
2.5 bpm, 3000 psi.
Orient TF to 20R.
14:30 - 16:30 2.00 STKOH C PROD1 Tme drill at 1 fph off top of AL Billet at 20R TF, 2.5 bpm, 2850
psi,
One stall at 10021.1'.
Held kick while drilling drill.
16:30 - 17:15 0.75 STKOH N SFAL PROD1 Lost power on rig. Start up generators. Ease back down to
start time drilling again.
17:15 - 10:00 16.75 STKOH C PROD1 Time drill off of AL Billet. 1 fph, 2.5 bpm, 2940 psi, 20R TF.
Increased ROP after 3' to 5 FPH. Increasedd ROP to 10 FPH
after 5'
10:00 - 11:15 1.25 STKOH C PROD1 10045', Backream across billet at 20R TF, no motor work.
11:15 - 00:00 12.75 STKOH C PROD1 Continue drilling ahead at 2.57 bpm, 2950 freespin. Start mud
swap. Drilled to 10070' at midnight
2/i 0/2008 00:00 - 02:15 2.25 STKOH C PROD1 Continue drilling sidetrack off aluminum billet. 2.5 bpm, 2950
psi, -50 fph. Drill to 10170'.
02:15 - 05:00 2.75 STKOH C PROD1 POOH for motor angle adjust and bit
05:00 - 07:00 2.00 STKOH C PROD1 Change motor bend to 1.2 deg, PU HCC bi-center bit and
resistivity. Installed CT inspect.
07:00 - 09:00 2.00 STKOH C PROD1 RIH with Lateral / RES BHA #7. circ at min. rate.
SWS running their CT inspect while RIH, to check for chrome
tubing wear on the coil.
09:00 - 09:10 0.17 STKOH C PROD1 Logged GR tie-in at RA tag. Added 4' to CTD.
09:10 - 09:30 0.33 STKOH C PRODi RIH. Orient TF to 20R for Billet exit at 10,020'. RIH clean thru
sidetrack and to bottom.
09:30 - 11:30 2.00 STKOH C PROD1 Drill Z1A lateral, 2.6 bpm, 3000-3600 psi, 100E TF, 1-2K
wob, 60 fph, 10.0 ecd.
Drilled to 10,265. now drilling past old lateral depth.
11:30 - 12:30 1.00 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3000-3600 psi, 100E TF, 1-2K
wob, 60 fph, 10.0 ecd.
Drilled to 10,346'.
12:30 - 13:30 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean past billet and to
bottom.
13:30 - 15:45 2.25 DRILL P PROD1 Drill ZiA lateral, 2.6 bpm, 3200-3900 psi, 90L TF, 1-2K wob,
80 fph, 10.0 ecd.
Drilling clean sand. Drilled to 10,500'.
Printed: 2/13/2008 2:42:58 PM
BP EXPLORATION Page 5 of 7
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
Date From - To ~ Hours ' Task Code NPT Phase Description of Operations
2/10/2008 15:45 - 16:45 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. R(H clean past billet and to
bottom.
16:45 - 18:15 1.50 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3230-3900 psi, 30R TF, 1-2K wob,
80 fph, 10.2 ecd.
Drilled to 10600'.
18:15 - 19:50 1.58 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3230-3900 psi, 10R TF, 1-2K wob,
80 fph, 10.2 ecd.
Drilled to 10,650'.
19:50 - 20:45 0.92 DRILL P PROD1 Wiper trip to window
20:45 - 20:55 0.17 DRILL P PROD1 Tie in at RA, correct + 3.5'.
20:55 - 22:00 1.08 DRILL P PROD1 Wiper back down
22:00 - 00:00 2.00 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3250 psi free spin, 165R TF, 1500
wob, 20-40 fph, 10.14 ecd
10750' at midnight
2/11/2008 00:00 - 01:00 1.00 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3250 psi free spin, 165R TF, 1500
wob, 45-60 fph, 10.14 ecd
Drilled to 10796'
01:00 - 02:30 1.50 DRILL P PROD1 Wiper trip to window
02:30 - 04:45 2.25 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3250 psi free spin, 165R TF, 1500
wob, 45-60 fph, 10.25 ecd
Drilled to 10900
04:45 - 06:30 1.75 DRILL P PROD1 Wiper trip to window
06:30 - 08:45 2.25 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3280 psi free spin, 90L TF, 1-2K
wob, 80 fph, 10.4 ecd
Swapped to new FloPro.
Drilled to 11,000'.
08:45 - 10:00 1.25 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3000 psi free spin, 100E TF, 1-2K
wob, 80 fph, 9.9 ecd
Drilled to 11,100'.
10:00 - 11:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole.
11:00 - 11:15 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Aded 4' to CTD.
11:15 - 12:00 0.75 DRILL P PROD1 RIH clean past billet and to bottom.
12:00 - 13:15 1.25 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3150 psi free spin, 120E TF, 1-2K
wob, 100 fph, 10.0 ecd
Good sand GR and RES.
Drilled to 11,250'.
13:15 - 14:30 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean past billet and to
bottom.
14:30 - 16:15 1.75 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3150 psi free spin, 90R TF, 1-2K
wob, 100 fph, 10.1 ecd
Good sand and RES.
Drilled to 11,400'.
16:15 - 18:15 2.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean past billet and to
bottom.
18:15 - 20:00 1.75 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3150 psi free spin, 90L TF, 1-2K
wob, 100 fph, 10.1 ecd
Drilled to 11,550'
20:00 - 21:30 1.50 DRILL P PROD1 Wiper trip to window
21:30 - 21:45 0.25 DRILL P PROD1 Tie-in, + 8.5'
21:45 - 23:15 1.50 DRILL P PROD1 Wiper trip to bottom
23:15 - 00:00 0.75 DRILL P PROD1 Drill Z1A lateral, 2.55 bpm, 3100 psi free spin, 90L TF, 1-2K
wob, 100 fph, 10.1 ecd
Drilled to 11590' at midnight
Printed: 2/13/2008 2:42:58 PM
BP EXPLORATION Page 6 of 7
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours Task ~ Code NPT Phase Description of Operations
2/12/2008 00:00 - 02:20 2.33 DRILL P PROD1 Drill Z1A lateral, 2.55 bpm, 3100 psi free spin, 90L TF, 1-2K
wob, 100 fph, 10.1 ecd
Drilled to 11700'
02:20 - 03:40 1.33 DRILL P PROD1 Wiper trip to window
03:40 - 04:40 1.00 DRILL N SFAL PROD1 Repair broken bearings on injector
04:40 - 05:45 1.08 DRILL P PROD1 Continue with wiper trip back in hole
05:45 - 08:30 2.75 DRILL P PROD1 Drill Z1A lateral, 2.55 bpm, 3150 psi free spin, 90R TF, 1-2K
wob, 100 fph, 10.25 ecd
Drilled to 11900'.
08:30 - 10:45 2.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean past billet and to
bottom.
10:45 - 12:00 1.25 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3100 psi free spin, 90R TF, 1-2K
wob, 100 fph, 10.2 ecd,
Swapped to new flopro at 11,920'i
Drilled into clean sand at 11,935'..
12:00 - 13:25 1.42 DRILL P PROD1 Drill Z1A lateral, 2.6 bpm, 3000 psi free spin, 130R TF, 1-2K
wob, 100 fph, 9.9 ecd,
Drilled to ed a of of on at 12 090'.
13:25 - 14:45 1.33 DRILL P PROD1 Wiper trip to window. Clean hole.
14:45 - 15:45 1.00 DRILL P PROD1 Install SWS CT Inspect tool on horses head to inspect OD and
wall thickness of coil from TD to surface.
15:45 - 16:00 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Added 9.5' CTD.
16:00 - 16:50 0.83 DRILL P PROD1 RIH clean past billet and to TD.
Ta~~ed final TD at 12,094'.
16:50 - 20:00 3.17 DRILL P PROD1 Log RES tool while POH at 820 fph.
41 K up wt off bottom.
Reduce pump to zero when passing aluminum billet.
20:00 - 22:00 2.00 DRILL P PROD1 Pull through window and POOH.
22:00 - 22:10 0.17 DRILL P PROD1 Tag stripper and flow check well. Conduct PJSM for laying
down BHA.
22:10 - 22:50 0.67 DRILL P PROD1 Break off CT riser and stand back injector.
Beak out BHA and lay down.
Close swab valve.
22:50 - 23:20 0.50 BOPSU P PROD1 Conduct PJSM for BOP function test.
Lower 2-3/8" test joint into BOP stack.
Function test 2-3/8" pipe /slip rams, both sets, and VBR rams.
Remove test joint and function test blind /shear rams.
23:20 - 23:40 0.33 CASE P RUNPRD Break off BHI cable head.
Install cable boot and prep to displace mud from reel.
23:30 -Fill well with 4 bbls.
23:40 - 00:00 0.33 CASE P RUNPRD Start 50 bbls fresh water down CT, followed by 10 bbls
inhibited water and 10 bbls McOH.
2/13/2008 00:00 - 00:40 0.67 CASE P RUNPRD Continue displacing mud from reel.
00:40 - 01:00 0.33 CASE P RUNPRD Purge reel with N2 at 1,800 scfm.
01:00 - 01:50 0.83 CASE P RUNPRD Shut down N2, bleed off pressure.
PJSM for pulling CT across to reel.
01:50 - 03:30 1.67 CASE P RUNPRD Remove CT connector.
Install internal dimple connector for pulling CT across.
Pull CT across and secure to reel.
02:30 -Fill well with 7 bbls.
Lower a-line string onto truck bed.
03:30 - 06:00 2.50 CASE P RUNPRD Fill well with 3 bbls.
Prep work string to lift into reel house.
Printed: 2/13/2008 2:42:58 PM
~ ~
BP EXPLORATION
Operations Summary Report
Page 7 of 7
Legal Well Name: 15-45
..Common Well Name: 15-45A Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End:
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 1 Rig Number: N1
Date I From - To ~ Hours I Task ~ Code I NPT I Phase Description of Operations
03:30 - 06:00 2.50 CASE P RUN Lift up work string and secure in reel stand.
ook up hardline, attach internal grapple for pulling across.
• 0 - 11:00 5.00 CASE P RUNPRD Pu it to injector. Cut off grapple. M/U BTT CTC and pull
test.
Pump 5 bb OH. Pump 10 bbl FloPro. Press test inner reel
valve and hardli OK.
Fill coil with FloPro. sert dart and displace with FloPro. Dart
landed at 60.0 bbl. Cal 60.9 bbl.
11:00 - 11:30 0.50 CASE RUNPRD Stand back injector, circ coi .
11:30 - 11:45 0.25 CASE P " RUNPRD SAFETY MEETING. Review pro dure, hazards and
.•,, mitigation for running liner.
11:45 - 0.00 CASE P '`'`~ UNPRD Run indexing guide shoe, Flt Cllr, 1 jt 2- " STL, Flt Cllr,
Landing Cllr and 63 jts of 2-7/8", 6.16#, L-80, L Liner.
• CHILL rig water vac truck had 20 gal spill tog nd of
clean la ter, due to leaky valve. Called 5700 and we were
told clean lak ter is anon-event. Not a recordable spill.
~ ~ ~v ~- ~ ~ S G~
•
~~ L
Printed: 2/13/2008 2:42:58 PM
~ ~
BP EXPLORATION
Operations Summary Report
Legal Well Name: 15-45
Page 7 of 11
Common Well Name: 15-45 Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End: 2/16/2008
Contractor Name: NORDIC CALISTA Rig Release: 2/16/2008
Rig Name: NORDIC 1 Rig Number: N1
Date From - To ~I Hours Task ~I Code I NPT Phase ', Description of Operations
2/13/2008 103:30 - 06:00 2.501 CASE ~ P
06:00 - 11:00 5.001 CASE P
11:00 - 11:30 0.50 CASE P
11:30 - 11:45 0.25 CASE P
11:45 - 15:30 ~ 3.75 ~ CASE P
RUNPRD Lift up work string and secure in reel stand.
Hook up hardline, attach internal grapple for pulling across.
RUNPRD Pull coil to injector. Cut off grapple. M/U BTT CTC and pull
test.
Pump 5 bbl MEOH. Pump 10 bbl FloPro. Press test inner reel
valve and hardline. OK.
Fill coil with FloPro. Insert dart and displace with FloPro. Dart
landed at 60.0 bbl. Calc at 60.9 bbl.
RUNPRD Stand back injector, circ coil.
RUNPRD SAFETY MEETING. Review procedure, hazards and
mitigation for running liner.
RUNPRD Run indexing guide shoe, Flt Cllr, 1 jt 2-7/8" STL, Flt Cllr,
Landing Cllr and 63 jts of 2-7/8", 6.16#, L-80, STL Liner.
NOTE: CHILL rig water vac truck had 20 gal spill to ground of
clean lake water, due to leaky valve. Called 5700 and we were
told clean lake water is anon-event. Not a recordable spill.
15:30 - 16:00 0.50 CASE P RUNPRD Fill liner with water at 50 jts in hole. Calibrate little jerk
make-up tongs.
16:00 - 18:15 2.25 CASE P RUNPRD Run total of 64 Its of 2-7/8" Liner XO 22 jts 3-3/16", 6.2#. L-80
TCII Liner, XO, 1 jt 3-1/2" STL liner, X Nipple,
1 jt 3-1/2" STL Liner, 3-1/2" pup jt, BTT Deployment sleeve and
CTLRT.
18:15 - 21:15 3.00 CASE P
21:15 - 22:20 ~ 1.08 ~ CASE ~ P
22:20 - 23:20 I 1.001 CASE I P
23:20 - 00:00 0.67 ~ CEMT ~ P
12/14/2008 00:00 - 01:20 1.33 CEMT P
01:20 - 01:40 0.33 CEMT P
01:40 - 02:30 0.83 CEMT P
02:30 - 02:40 0.17 CEMT P
Liner total length = 2787.97".
Liner with CTLRT = 2797.3'.
RUNPRD RIH with liner on CT. Fill liner at surface until steady returns.
RIH while circ at 0.5 bpm.
Up weight at 9,300 ft is 37 Klbs.
RUNPRD Pass through window, continue RIH at 30 - 40 fpm.
Clean pass to bottom, bottom is found at 12,088 ft.
Pick up weight is 60 Klbs.
Tag bottom a second time at 12,088 ft, up weight again is 60
Klbs.
RUNPRD Pick up to position reel for ball drop.
Launch 5/8" aluminum ball with 1,200 psi and chase with
flo-pro mud.
RIH back to bottom and stack 10 Klbs on it, continue to chase
with flo-pro at 2.1 bpm / 2,500 psi.
After 10 bbls reduce to 2.0 bpm / 2,400 psi.
At 35 bbls slow to 1.5 bpm / 2,000 psi.
At 40 bbls pump 0.5 bpm / 1,340 psi.
At 42 bbls pump 0.3 bpm / 1,200 psi.
RUNPRD At 48.4 bbls pumped circ pressure starts to climb, goes to
4,200 psi then shears.
Up weight is now 35 Klbs, run back in and put 10 Klbs down.
Swap to 2% double slick KCI water and swap well over at 2.8
bpm.
RUNPRD Continue circulating the hole to 2% KCI double slick water.
RUNPRD SAFETY MEETING. Review procedure, hazards and
mitigations for liner cement job.
RUNPRD Batch mix 34 bbls pumpable of 15.8 ppg cement.
RUNPRD Cement is up to weight, pump 3 bbls fresh water ahead for PT
of cement lines.
Nnnteo: 5nrzuua tu:~u:u,vm
~ ~
BP EXPLORATfON
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
15-45
15-45
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Start: 2/4/2008
Rig Release: 2/16/2008
Rig Number: N1
Page 8 of 11
Spud Date: 4/8/1996
End: 2/16/2008
Date From - To .Hours Task Code
2/14/2008 02:30 - 02:40 0.17 CEMT P
02:40 - 03:05 0.42 CEMT P
03:05 - 03:10
03:10 - 03:30
03:30 - 03:50
0.08 CEMT ~ P
0.33 CEMT P
0.33 CEMT P
NPT ~ Phase Description of Operations
RUNPRD Pressure test cement line to 4,000 psi, good.
RUNPRD Start pumping cement down CT.
02:43 -Zero MM at 12 ppg density.
Stage 35 bbls of cement at 1.8 bpm.
RUNPRD Shut down cement pump and close inner reel valve. Line up to
clean up pump line going out to cement unit. Pump biozan out
to cement unit with rig pump.
RUNPRD Isolate Nordic pump and vac out line to cement unit.
RUNPRD Insert dart into reel. Zero both in/out MM. Displace cement
with 2# biozan at initial rate of 3.3_bpm•
20 bbls displaced - 2.65 bpm / 1,600 psi m withL.57 bpm
returns.
34.4 bbls displaced -switch to 2% KCI. 2.7 bpm / 1,300 psi in
with 2.6 bpm returns.
42.2 bbls displaced -cement at shoe, zero out MM. 2.7 bpm I
1,490 psi with 2.6 bpm returns.
56 bbls displaced, slow to 1.5 bpm and watch for dart to land.
03:50 - 04:00
0.171 CEMT I P
04:00 - 04:20 I 0.331 CEMT I P
04:20 - 06:10 1.83 CEMT P
06:10 - 07:00 0.83 CEMT P
07:00 - 07:30 0.50 CEMT P
07:30 - 08:00 0.50 EVAL P
08:00 - 08:15 0.25 EVAL P
08:15 - 12:15 I 4.00 I EVAL I P
12:15 - 13:45 1.50 EVAL P
13:45 - 15:45 2.00 EVAL P
15:45 - 16:30 0.75 EVAL P
RUNPRD I Dart lands at 59.4 bbls, shear out at 3,400 psi and resume
um in at 2.55 bpm / 2,100 psi with 2.4 bpm returns.
At 74 bbls displaced slow pump to 1 bpm / 1,300 psi to see
plug bump.
Plug lands at 76.6 bbl displacement and 33.3 bbls out.
Pressure up to 1,000 psi over circ pressure, hold for 5 minutes
then bleed off.
RUNPRD Bleed off circ pressure and check floats, no flow.
Pressure up to 500 psi then pull out of liner hanger, up weight
is 30 Klbs.
Stay at 12,072 ft and pump 5 bbls at 0.38 bpm.
Cement 'ob went ve well. Lost 1.7 bbls to formati n
dis lacin cement.
Very close to full returns at end of cement job.
RUNPRD POOH, replacing coil voidage.
RUNPRD Tag stripper. Break off CT riser and break out liner running
tools.
RUNPRD Jet stack with swizzle stick.
LOWERI M/U 2.30" mill, motor, XO, 2 jts 1-1/4" CSH and XO.
LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for running SWS MCNUGR logging tools.
LOWERI M/U SWS carrier and insert MCNUGR/CCL logging tools.
M/U BTT circ sub and Hyd disc.
Pick up 90 jts of 1-1/4" CSH workstring in singles from pipe
shed.
M/U BTT MHA. BHA OAL = 2,885.6'.
LOWERI RIH with Mill, motor, MCNUGR/CCL BHA #8. circ at 1.0 bpm,
900 psi.
LOWERI Log down with MCNUGR at 30 fpm from 9000'. No wt loss
entering top of liner at 9306'.
Had contaminated cement returns at 9.3 PPG to surface
indicating contaminated cement above the liner top.
Circ. 25 bbl new high vis FloPro pill to mill while logging in hole.
Ta PBTD at 12047'. Dwn depth and 12043' up depth.
circ. High vis pill to mill.
LOWERI Log up off bottom at 60 fpm, while laying in new FloPro pert
Printetl: 5/1/2UU8 1 U::iU:1/ AM
s r
BP EXPLORATION Page 9 of 11
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 1 5-45 Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start : 2/4/2008 End: 2/16/2008
Contractor Name: NORDIC CALISTA Rig Release: 2/16/2008
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours Task Code NPT Phase Description of Operations
2/14/2008 15:45 - 16:30 0.75 EVAL P LOWERI pill. 1.5 bpm, 2530 psi.
16:30 - 18:40 2.17 EVAL P LOW ER1 POH. Tag stripper and break off CT riser, stand back injector.
18:40 - 19:00 0.33 EVAL P LOWERI SAFETY MEETING. Crew change and discuss procedures,
hazards and mitigation for pulling and standing back CSH.
19:00 - 19:20 0.33 EVAL P LOWERI Drop a 5/8" ball to open Circ sub so CSH will pull dry.
19:20 - 21:00 1.67 EVAL P LOWERI Stand back CSH, leave one stand remaining on top of neutron
source.
21:00 - 21:15 0.25 EVAL P LOWERI SAFETY MEETING. Discuss procedure and personnel
positions, hazards and mitigations for pulling neutron source
tool.
21:15 - 22:00 0.75 EVAL P LOW ER1 Pull source tool and remaining BHA.
22:00 - 22:25 0.42 PERFO P LOWERI Perform liner lap test to 2 000 psi Pressure falls to 1 000 osi
22:25 - 23:30 I 1.081 PERFOBI P
23:30 - 23:50 I 0.331 PERFOBI P
23:50 - 00:00 0.17 PERFO P
2/15/2008 00:00 - 01:30 1.50 PERFO P
01:30 - 02:45 1.25 PERFO P
02:45 - 03:10 0.42 PERFO P
03:10 - 05:00 1.83 PERFO P
05:00 - 08:15 I 3.251 PERFOBI P
08:15 - 10:30 2.25 ~ PERFOB~ P
10:30 - 11:25 0.92 ~ PERFOB, P
Pump up a ain to 1,900 si, ressure falls to 1,200 si after 2
minutes, failed test.
LOW ER1 Prep to jet the stack. Close master valve.
MU swizzle stick BHA.
Make 3 passes through BOP stack at 2.9 bpm.
LOW ER1 Prep to open BOP doors to check for cement.
RIH 200 ft to displace water so the BOP stack is dry. Hang up
base flange when pulling up, open CT riser and work past this
point.
LOWERI Open lower BOP doors to check for cement.
Some cement found, cleanout BOPs.
LOWERI Remove rams from lower BOPs and continue cleaning cement
from them.
LOWERI Put rams back in and button up doors on BOPs.
Perform body test of BOPs. 200 / 3.500 osi. good test.
Pick u test 'oint to function test ram
LOWERI SAFETY MEETING. Discuss procedures, hazards and
mitigations for running TCP guns. Discussed crew awareness
of kick procedures.
LOWERI Run TCP uns as er ro ram. 960 ft of erfs at 6 s f.
255.18' of blanks.
M/U SWS firing head, BTT hyd disc and XO
LOWERI RIH with 27 stds of CSH.
M/U BTT Hyd Disc, swivel, BPV, XO and CTC. BHA Total
length = 2891.51'.
LOWERI RIH with 2" SWS perforating BHA #9.. Circ at 0.3 bpm at 100
psi.
Up wt at 9300' = 38K.
RIH and tag PBTD at 12,034.5'. Correct depth to 12,034' to
match MCNL/GR PBTD up depth.
Up wt at bottom = 42K.
LOWERI Circ. in 10 bbl high vis FloPro pert pill. Insert 1/2" AL Ball and
displace with 10 bbl FloPro.
Displace with KCL water. Slow pump to 1 bpm, 720 psi at 40
bbls.
Ball on seat at 54.2 bbls. Firing head fired at 3200 psi. Good
shot detection.
Fired guns on depth on the fly. Up wt = 43K.
PERFORATED INTERVALS: 10,810 - 11,680' AND 11 930 -
Printed: 5/1/2008 10:30:27 AM
~ ~
BP EXPLORATION Page 10 of 11
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45 Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End: 2/16/2008
Contractor Name: NORDIC CALISTA Rig Release: 2/16/2008
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours Task Code NPT Phase Description of Operations
2/15/2008 10:30 - 11:25 0.92 PERFO P LOW ER1 12 020'.
TOTAL PERFORATIONS = 960'.
11:25 - 14:30 3.08 PERFO P LOWERI POH with pert guns. Circ at 1.4 bpm, 900 psi.
Flow check at 9200'. No Flow.
POH.
Flow Check at surface. No flow.
14:30 - 14:45 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for standing back CSH workstring.
14:45 - 16:30 1.75 PERFO P LOWERI Stand back 27 stds of CSH workstring.
16:30 - 16:45 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and
mitigation for laying out Perf guns.
16:45 - 18:45 2.00 PERFO P LOWERI La out SWS 2" fired erf uns. All shots fired.
57 uns and blanks.
18:45 - 19:00 0.25 PERFO P LOWERI SAFETY MEETING. Tour change, discuss procedures,
hazards and mitigations for laying down fired guns with night
tour.
19:00 - 21:00 2.00 PERFO P LOWERI Ensure hole is full then lay out remaining guns.
21:00 - 22:00 1.00 PERFO P LOWERi Clear rig floor and pipe shed of perforation equipment and
spent guns.
Attach tugger to end of CT to straighten it.
22:00 - 22:20 0.33 CASE P RUNPRD RIH and back again to ensure CT connector will not hang up in
tree, passes twice without incident.
22:20 - 22:35 0.25 CASE P RUNPRD SAFETY MEETING. Discuss procedures, hazards and
miti ations for runnin 11 'ts of 3-3/16" liner.
22:35 - 00:00 1.42 CASE P RUNPRD Run BHA #10 -Locator seal unit + 11 jts 3-3/16" liner + liner
top packer + running tool + hydraulic disconnect.
2/16/2008 00:00 - 02:00 2.00 CASE P RUNPRD MU CT riser to wellhead and RIH with BHA #10.
02:00 - 02:10 0.17 CASE P RUNPRD Tag deployment sleeve at 9,295 ft while pumping minimum
rate. Pressure increase seen, shut down pump.
Continue to stack weight to 9,300 ft.
Bleed off circ pressure.
Pick up 3 ft to get string weight back, 42 Klbs.
02:10 - 02:20 0.17 CASE P RUNPRD dine up for injectivit test down CT x tubing annulus while stunt
into de to ment sleeve.
Pump 0.6 bpm down annulus, injection pressure levels off at
1,550 psi.
Pump 0.8 bpm down annulus, pressure levels off around 1,700
psi.
02:20 - 02:50 0.50 CASE P RUNPRD Shut down pump and bleed off pressure.
~ Line up valves to pump down the CT.
Pick up out of deployment sleeve to 9,290 ft to find a ball drop
position and enable circulation.
Drop 5/8" steel ball and chase it at 2.3 bpm.
Slow down pump at 45 bbls away.
02:50 - 03:00 0.17 CASE P RUNPRD Ball on seat at 49.9 bbls.
Shut down pump and bleed off pump pressure.
Run back in to sting into deployment sleeve at 9,295 ft then
RIH further to no-go at 9,300 ft.
Pick up until weight comes back at 9,297 ft and pick up one
more foot to correct space-out.
Pressure up to 2,000 psi and slack back to 12 Klbs to inflate
element.
Bleed off pump pressure slowly to zero.
Printed: 5/1/2008 10:30:27 AM
~ ~
BP EXPLORATION Page 11 of 11
Operations Summary Report
Legal Well Name: 15-45
Common Well Name: 15-45 Spud Date: 4/8/1996
Event Name: REENTER+COMPLETE Start: 2/4/2008 End: 2/16/2008
Contractor Name: NORDIC CALISTA Rig Release: 2/16/2008
Rig Name: NORDIC 1 Rig Number: N1
Date From - To Hours ~ Task Code NPT Phase'' Description of Operations
2/16/2008 03:00 - 03:15 0.25 CASE P RUNPRD Pick back up to string weight of 38 Klbs.
Line up valves for pressure test down CT annulus.
um CT x tubin annulus u to 2 000 si
Press test Liner To Packer, after 5 min / 1 890 si 10 min /
1,868 si ood test.
03:15 - 04:00 0.75 CASE P RUNPRD Bleed off pressure and line up to pump down the CT.
Slack back to 15 Klbs.
Pump down the CT to shear off the packer, shears at 3,500
psi.
Pick up off packer and start pumping diesel down CT.
04:00 - 04:40 0.67 CASE P RUNPRD Diesel out nozzle, start POOH.
At 89 bbls out shut down diesel and switch to KCI water,
continue POOH.
04:40 - 04:50 0.17 CASE P RUNPRD Stop at 6,000 ft until diesel returns at surface.
04:50 - 05:40 0.83 CASE P RUNPRD Diesel at surface, close choke and POOH with no pump.
05:40 - 06:45 1.08 CASE P RUNPRD Tag stripper. Shut in master and swab valves and remove
fusible cap.
Remove packer setting tools and lay down.
06:45 - 07:00 0.25 DHB P POST SAFETY MEETING. Review procedure, hazards and
mitigation for setting BPV with lubricator.
07:00 - 09:00 2.00 BOPSU P POST Set BPV with valve crew and lubricator. Press test lubricator.
Set BPV OK.
09:00 - 09:15 0.25 DEMOB P POST SAFETY MEETING. Review procedure, hazards and
mitigation for blowing down coil with N2.
09:15 - 11:00 1.75 DEMOB P POST Pump N2 and blowdown to Tiger tank thru choke. Bleed down
press to zero.
11:00 - 13:00 2.00 DEMOB P POST Empty and clean rig pits.
13:00 - 16:00 3.00 BOPSU P POST N/D BOPE. N/U Tree cap and Pressure test. OK.
RELEASED RIG AT 1600 HRS, 02/16/2008.
A TOTAL OF 11 DAYS, 17-1/2 HOURS FROM RIG ACCEPT
TO RELEASE.
MOVE RIG TO DS 18-32B.
ALL FURTHER RIG INFORMATION WILL BE UNDER D1MS
18-326.
Printed: S/1/1UOk3 1():3U:G/ AM
•
by BP Alaska sr
Baker Hughes INTEQ Survey Report >1vTE
Q
Company: BP Amoco Date: 2!13/2008 Titne: 09:50:14 Page: t
Field: Prr~hoe Bay Go-ardirataNE) Reference: Wets: 15-45, True North
.Site: PB DS 15 Vertical (TVD) Reference: 63:45 9/24!1996 16:29 68.1
Well: 15-45 Section (VS) Rekrenta: Wel! (O.OON,O.OOE,18.16Azi)
Wellpatb: 15-458 Sarvey Caknbtioe Method: Minimum Curvature Qb: Orade
Field: Prudhoe Bay
North Slope
UNITED STATES
Map System:US State Plane Coordinate System 1927 Map Zoae: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordbate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Site: PB DS 15
TR-11-14
UNITED STATES :North Slope
Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N
From: Map Easting: 676296.98 ft Loagitnde: 148 34 21.213 W
Position Uneertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 1.34 deg
Well: 15-45 Sbt Name: 45
15-45
WeN Position: +N/-S 2121.31 ft Northing: 5960952.49 ft Latitude: 70 17 56.099 N
+E/-W -232.87 ft Eastiog : 676014.44 ft Loegitude: 148 34 28.002 W
Position Uncertainty: 0.00 ft
Welipath: 15-456 Drilled From: 15-45BPB1
500292267102 Tie-oo Depth: 10019.36 ft
Current Datum: 63:45 9!24/1996 16:29 Heigh[ 68.06 ft Above System Datum: Mean Sea Level
Magnetic Data: 12/4/2007 Declination: 23.54 deg
FPM 5treegth: 57667 nT Mag Dip Angle: 80.93 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
37.06 0.00 0.00 18.16
Survey Program for Definitive Wellpath
Date: 2/12/2008 Validated: Yes Version: 8
Actual From To Survey Tookode Tool Name
ft ft
117.90 9381.15 MWD (117.90-10643.90) (0) MWD MWD -Standard
9398.00 10019.36 MWD (9398.00-10265.00) (6) MWD MWD -Standard
10020.00 12094.00 MWD (10020.00-12094.00) MWD MWD -Standard
Annotation
MD TVD
ft ft
10019.36 8775.27 TIP
10020.00 8775.62 KOP
12094.00 8823.65 TD
Survey: MWD Start Date: 2/12/2008
Company: Baker Hughes INTEt1 Eegioeer:
Tool: MWD;MWD -Standard Tied-to: From: Definitive Path
by BP Alaska '~
Baker Hughes INTEQ Survey Report INTE
Q
Company: BP Amoco DAte: 2/13/2008 Time: 09:50:14 Page: 2
'Fktd: Prudhoe Bay Go~rd~tc(NE)Reference: Well: 15-45, True North
.Site: PB DS 15 Vertical (TVD) Rekreaee: 63:45 9f24l1996 16:29 68.1
Well: 15-45 Se etiAu (YS) Rekrrece We!! (Oa?ON,O. OOE,18.16Azi)
Well~ai6 15-458 Survey GAkalatioo Metf~od: Minimum Curvature Db: OraGe
Sarvey
MD Iael Azim TVD Sys TVD N!S F./W MapN MapE VS DIS Tool
1t deg deg ft ft ft ft ft ft ft deg/100ft
10019.36 57.57 122.64 8775.27 8707.21 3350.53 -952.99 5964279.56 674983.30 2886.56 0.00 MWD
10020.00 57.58 122.55 8775.62 8707.56 3350.24 -952.53 5964279.28 674983.76 2886.43 11.97 MWD
10050.17 63.51 126.00 8790.45 8722.39 3335.44 -930.85 5964264.99 675005.78 2879.12 22.03 MWD
10080.55 69.83 127.78 8802.47 8734.41 3318.69 -908.56 5964248.78 675028.46 2870.16 21.49 MWD
10111.51 76.15 129.79 8811.53 8743.47 3300.15 -885.50 5964230.78 675051.95 2859.73 21.34 MWD
10140.17 83.12 130.76 8816.68 8748.62 3281.93 -864.00 5964213.08 675073.86 2849.12 24.55 MWD
10170.60 86.28 134.73 8819.49 8751.43 3261.37 -841.76 5964193.04 675096.58 2836.52 16.63 MWD
10206.93 87.02 139.30 8821.62 8753.56 3234.85 -817.04 5964167.11 675121.91 2819.02 12.72 MWD
10236.47 87.51 135.81 8823.03 8754.97 3213.08 -797.13 5964145.81 675142.32 2804.54 11.92 MWD
10264.99 88.56 131.60 8824.00 8755.94 3193.39 -776.53 5964126.61 675163.38 2792.25 15.21 MWD
10296.51 87.05 127.44 8825.21 8757.15 3173.35 -752.24 5964107.15 675188.13 2780.78 14.03 MWD
10335.31 85.76 122.53 8827.65 8759.59 3151.16 -720.52 5964085.70 675220.35 2769.58 13.06 MWD
10365.27 85.30 118.26 8829.98 8761.92 3136.05 X94.77 5964071.20 675246.46 2763.25 14.29 MWD
10396.65 87.02 114.66 8832.08 8764.02 3122.10 -666.74 5964057.91 675274.80 2758.73 12.69 MWD
10426.41 87.91 111.60 8833.40 8765.34 3110.42 -639.41 5964046.88 675302.40 2756.16 10.70 MWD
10456.31 87.76 108.03 8834.53 8766.47 3100.30 -611.30 5964037.42 675330.73 2755.30 11.94 MWD
10485.27 86.65 104.30 8835.94 8767.88 3092.24 -583.52 5964030.02 675358.69 2756.30 13.42 MWD
10515.51 88.22 103.29 8837.30 8769.24 3085.04 -554.19 5964023.50 675388.18 2758.60 6.17 MWD
10545.13 88.59 101.90 8838.12 8770.06 3078.58 -525.29 5964017.73 675417.22 2761.48 4.85 MWD
10575.91 88.93 104.58 8838.79 8770.73 3071.54 -495.34 5964011.38 675447.33 2764.12 8.77 MWD
10605.43 91.29 107.16 8838.73 8770.67 3063.47 -466.95 5964003.98 675475.90 2765.30 11.84 MWD
10635.06 93.91 109.75 8837.39 8769.33 3054.10 -438.88 5963995.27 675504.18 2765.15 12.43 MWD
10668.46 91.78 112.22 8835.73 8767.67 3042.15 -407.73 5963984.06 675535.59 2763.50 9.76 MWD
10698.08 91.13 117.02 8834.98 8766.92 3029.82 -380.82 5963972.36 675562.78 2760.17 16.35 MWD
10728.32 90.25 120.44 8834.61 8766.55 3015.29 -354.31 5963958.46 675589.62 2754.63 11.68 MWD
10759.62 88.86 116.65 8834.86 8766.80 3000.33 -326.82 5963944.15 675617.45 2748.99 12.90 MWD
10790.22 90.44 115.65 8835.04 8766.98 2986.85 -299.36 5963931.32 675645.23 2744.74 6.11 MWD
10820.86 92.04 111.05 8834.38 8766.32 2974.71 -271.24 5963919.84 675673.62 2741.97 15.89 MWD
10850.52 92.55 107.33 8833.19 8785.13 2964.97 -243.26 5963910.76 675701.82 2741.43 12.65 MWD
10880.36 91.93 103.88 8832.02 8763.96 2956.95 -214.54 5963903.41 675730.71 2742.76 11.74 MWD
10911.24 92.45 100.59 8830.84 8762.78 2850.41 -184.39 5963897.58 675761.01 2745.95 10.78 MWD
10941.44 92.27 96.79 8829.60 8761.54 2945.86 -154.57 5963893.73 675790.93 2750.91 12.59 MWD
10990.58 91.47 91.09 8827.99 8759.93 2942.48 -105.59 5963891.50 675839.97 2762.98 11.71 MWD
11020.18 90.64 88.59 8827.45 8759.39 2942.57 -76.00 5963892.28 675869.55 2772.28 8.90 MWD
11048.34 90.40 85.13 8827.19 8759.13 2944.11 -47.89 5963894.48 675897.61 2782.51 12.32 MWD
11080.58 88.62 81.54 8827.47 8759.41 2947.85 -15.87 5963898.97 675929.53 2796.04 12.43 MWD
11111.32 87.39 77.07 8828.54 8760.48 2953.55 14.31 5963905.37 675959.56 2810.86 15.07 MWD
11140.58 86.38 75.84 8830.13 8762.07 2960.39 42.71 5963912.88 675987.80 2826.22 5.43 MWD
11170.86 85.54 73.98 8832.26 8784.20 2968.25 71.87 5963921.42 676016.77 2842.78 6.73 MWD
11199.67 85.78 78.42 8834.45 8766.39 2975.10 99.76 5963928.92 676044.49 2857.98 15.39 MWD
11240.97 86.22 84.86 8837.33 8769.27 2981.09 140.50 5963935.86 676085.07 2876.37 15.59 MWD
11271.99 88.86 88.85 8838.66 8770.60 2982.79 171.44 5863938.28 676115.96 2887.62 15.41 MWD
11299.67 90.89 92.02 8838.72 8770.66 2982.58 199.11 5963938.72 676143.63 2896.05 13.60 MWD
11332.42 90.40 96.81 8838.35 8770.29 2980.06 231.75 5963936.97 676176.32 2903.83 14.70 MWD
11362.11 90.15 101.58 8838.21 8770.15 2975.32 261.05 5963932.91 676205.72 2908.46 16.09 MWD
11393.38 80.28 106.42 8838.09 8770.03 2967.75 291.38 5963926.06 676236.22 2910.73 15.48 MWD
11424.11 90.71 104.67 8837.83 8768.77 2959.52 320.99 5963918.52 676266.00 2912.13 5.86 MWD
11457.47 91.47 100.79 8837.19 8769.13 2952.17 353.52 5963911.94 676298.69 2915.28 11.85 MWD
11487.74 90.67 98.01 8836.63 8768.57 2947.23 383.37 5963907.70 676328.65 2919.89 9.56 MWD
11517.01 90.46 94.94 8836.34 8768.28 2943.93 412.45 5963905.08 676357.80 2925.82 10.51 MWD
11552.25 88.99 91.90 8836.51 8768.45 2941.83 447.62 5963903.80 676393.01 2934.79 9.58 MWD
11584.53 87.85 88.41 8837.40 8769.34 2941.74 479.88 5963904.47 676425.26 2944.78 11.37 MWD
11618.83 87.57 84.20 8838.77 8770.71 2943.95 514.08 5963907.48 676459.39 2957.52 12.29 MWD
•
by BP Alaska S
Baker Hughes INTEQ Survey Report INTEQ
Comps®y: BP Amoco Date: Z/t3l2008 Time: 09:50:14 Pale: 3
Fief: Prudhoe Bay Co-ardioate(NE) Retereuces Well: 15-45, True North
Site: PB DS 15 Vertical (TW) Reterence: 63 : 45 9/24/1 996 16:29 68.1
Well: 15-45. Seetioa (VS) Rekrence: Well (O.OON,O .OOE,18.16Azi)
Wellpath: 15-458 S®rvey Cskalution Method: Minimum Curvature Db: OraGe
Survey
MD Itacl Azim TVD SysTVD N!S E/W MApN MapE VS DLS Tool
ft deg deg ft ft ft ft- ft; ft ft deg/100ft
11650.07 89.26 81.45 8839.63 8771.57 2947.85 545.06 5963912.10 676490.27 2970.88 10.33 MWD
11681.13 91.20 79.28 8839.51 8771.45 2953.04 575.67 5963918.02 676520.75 2985.36 9.37 MWD
11711.87 91.93 76.33 8838.67 8770.61 2959.53 605.71 5963925.21 676550.62 3000.89 9.88 MWD
11742.67 91.78 74.14 8837.67 8769.61 2967.38 635.47 5863933.75 676580.20 3017.62 7.12 MWD
11778.35 94.15 71.20 8835.83 8767.77 2977.99 669.48 5963945.15 676613.94 3038.30 10.57 MWD
11805.93 93.69 71.61 8833.94 8765.88 2986.76 695.56 5963954.53 676639.81 3054.77 2.23 MWD
11837.87 92.71 75.87 8832.16 8764.10 2995.69 726.17 5963964.17 676670.20 3072.79 13.67 MWD
11864.59 92.64 80.25 8830.91 8762.85 3001.21 752.27 5963970.30 676696.17 3086.18 16.38 MWD
11898.23 93.26 85.63 8829.18 8761.12 3005.34 785.60 5963975.21 676729.39 3100.49 16.08 MWD
11932.87 94.89 89.10 8826.71 8758.65 3006.93 820.11 5963977.61 676763.85 3112.75 11.04 MWD
11967.25 94.58 94.00 8823.87 8755.81 3006.00 854.35 5963977.48 676798.10 3122.55 14.23 MWD
11994.03 92.12 96.93 8822.31 8754.25 3003.45 880.96 5963975.56 676824.75 3128.42 14.27 MWD
12021.97 89.94 99.54 8821.81 8753.75 2999.45 908.60 5963972.21 676852.48 3133.23 12.17 MWD
12046.15 88.25 102.66 8822.19 8754.13 2994.80 932.32 5963968.11 676876.30 3136.21 14.67 MWD
12094.00 88.25 102.66 8823.65 8755.59 2984.32 978.99 5963958.73 676923.20 3140.79 0.00 MWD
•
by BP Alaska r
Baker Hughes INTEQ Survey Report INTE
Q
Company: BP Amoco Date: 2/13/2008 Time: 09:49a7 Page: 1
Fkhl: Prudhoe Bay Co-ardhate(NE) Retereace: Well: 15-45, True North
Site:: ' PB DS 15 Vertkal (TVD) Reference: 63:45 9124/1 996 16:29 68.1
Well: 15-45' Section(VS);Rekreece: Well (O.OON,O.O OE,346.66Azi)
Wellpath 15-458P81 Survey Cakalatioa,Method: Minimum Curvature Db: Oracle
Field: Prudhoe Bay
North Slope
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 15
TR-11-14
UNITED STATES :North Slope
Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N
From: Map Eastiog: 676296.98 ft Longitude: 148 34 21.213 W
Position Uncertainty: 0.00 ft North Rekreoce: True
Gronnd Level: 0.00 ft Grid Convergence: 1.34 deg
Well: 15-45 Sbt Name: 45
15-45
Well Position: +N/-S 2121.31 ft Northing: 5960952.49 ft Latitude: 70 17 56.099 N
+E/-W -232.87 ft Fasting : 676014.44 ft Longitude: 148 34 28.002 W
Position Uncertainty: 0.00 ft
Welipath: 15-456P61 Drilled From: 15-45P61
500292267173 Tie-on Depth: 9381.15 ft
Current Datum: 63:45 9!2411996 16:29 Height 68.06 ft Above System Datum: Mean Sea Level
Magnetic Data: 2/9/2008 Declination: 23.44 deg
Field Strength: 57671 nT Mag Dip Angle: 80.93 deg
Vertical Section: Depth From (TVD) +N/S +E/-W Direction
ft ft ft deg
37.06 0.00 0.00 346.66
Survey Program for Definitive Wellpath
Date: 2/9/2008 Validated: Yes Version: 3
Actual From To Survey Tookode Tool Name
ft ft
117.90 9381.15 MWD (117.90-10643.90) (0) MWD MWD -Standard
9398.00 10265.00 MWD (9398.00-10265.00) MWD MWD -Standard
Annotation
MD TVD
ft ft
9381.15 8403.09 TIP
9398.00 8418.99 KOP
10265.00 8859.85 TD
Snrvey: MWD Start Date: 2/9/2008
Company: Baker Hughes INTEQ Engineer:
Tool: MWD;MWD -Standard Tied-to: From: Definitive Path
Snrvey
MD Inch Azim TVD Sys TVD N/5 E/W MapN MapE VS DLS Tool
ft deg deg ft ft tt ft ft ft ft degl100ft
9381.15 19.47 348.20 8403.09 8335.03 3547.21 -1291.15 5964468.25 674640.64 3749.37 0.00 MWD
9398.00 19.29 347.89 8418.99 8350.93 3552.68 -1292.31 5964473.70 674639.36 3754.96 1.23 MWD
9437.59 13.03 17.53 8457.05 8388.99 3563.36 -1292.34 5964484.37 674639.08 3765.36 25.69 MWD
9470.31 16.61 50.43 8488.74 8420.68 3569.87 -1287.61 5964490.99 674643.65 3770.60 27.48 MWD
9501.73 17.53 75.80 8518.81 8450.75 3573.89 -1279.55 5964495.20 674651.62 3772.66 23.70 MWD
9532.11 22.51 91.43 8547.37 8479.31 3574.87 -1269.29 5964496.42 674661.85 3771.25 23.93 MWD
9562.41 30.29 94.07 8574.49 8506.43 3574.18 -1255.85 5964496.05 674675.31 3767.48 25.96 MWD
9592.41 38.45 96.85 8599.23 8531.17 3572.53 -1239.01 5964494.79 674692.18 3761.99 27.69 MWD
9620.41 46.02 100.33 8619.95 8551.89 3569.68 -1220.43 5964492.38 674710.82 3754.93 28.29 MWD
9652.07 54.51 101.91 8640.17 8572.11 3564.97 -1196.56 5964488.23 674734.78 3744.84 27.09 MWD
9679.77 62.35 105.35 8654.66 8586.60 3559.39 -1173.66 5964483.18 674757.81 3734.12 30.21 MWD
by BP Alaska ~
Baker Hughes INTEQ Survey Report INTE
Q
°Co®paay: BP Amoco Date: 2/1312008 Timc: 09:49:17 Page: 2
I'Seld: Prudhoe Bay Co-erdinate(NE) Refereaeee Well: 15-45, True North
Site: PB DS 15 Vertienl (TVD) Refere®ce: 63:45 9/24/1 996 16:29 68.1
We0: 15-45 Sceti0e (VS) Refer+enee: Well{O.OON,O .OOE,346.66Azi)
Wellpath: 15-45BPB1 S®rvey C9lculatien Method; Minimum Curvature Db: Orade
Sarvey
MD Inel Azim 1'vD Sys TVD N/S E/W MapN MapE VS DLS Tool
ft deg deg ft ft ft ft ft ft ft deg/100ft
9711.93 71.43 110.43 8667.28 8599.22 3550.27 -1145.56 5964474.73 674786.11 3718.77 31.74 MWD
9740.52 75.64 118.33 8675.39 8607.33 3538.95 -1120.63 5964463.99 674811.30 3702.00 30.31 MWD
9770.65 76.29 127.73 8682.72 8614.66 3523.03 -1096.16 5964448.65 674836.14 3680.87 30.34 MWD
9800.40 78.47 136.48 8689.23 8621.17 3503.58 -1074.65 5964429.71 674858.10 3656.98 29.62 MWD
9834.37 79.16 147.71 8695.84 8627.78 3477.33 -1054.21 5964403.95 674879.14 3626.73 32.49 MWD
9863.63 75.64 156.16 8702.23 8634.17 3452.17 -1040.78 5964379.11 674893.16 3599.14 30.64 MWD
9891.15 67.73 152.53 8710.87 8642.81 3428.63 -1029.50 5964355.85 674904.99 3573.64 31.35 MWD
9919.39 62.41 143.45 8722.79 8654.73 3406.93 -1015.98 5964334.47 674919.00 3549.41 34.69 MWD
9956.70 57.09 133.72 8741.62 8673.56 3382.77 -994.77 5964310.81 674940.78 3521.00 26.64 MWD
9989.46 57.75 126.89 8759.27 8691.21 3364.93 -973.73 5964293.47 674962.23 3498.79 17.68 MWD
10019.36 57.57 122.64 8775.27 8707.21 3350.53 -952.99 5964279.56 674983.30 3480.00 12.02 MWD
10049.54 57.97 118.31 8791.37 8723.31 3337.59 -930.99 5964267.14 675005.59 3462.33 12.21 MWD
10079.90 59.61 123.34 8807.11 8739.05 3324.28 -908.71 5964254.36 675028.18 3444.24 15.16 MWD
10110.12 64.62 126.02 8821.24 8753.18 3309.08 -886.76 5964239.68 675050.48 3424.39 18.34 MWD
10140.08 69.60 126.73 8832.89 8764.83 3292.71 -864.55 5964223.84 675073.07 3403.34 16.76 MWD
10170.86 74.85 126.17 8842.29 8774.23 3275.31 -840.98 5964206.99 675097.03 3380.97 17.14 MWD
10199.92 77.31 126.41 8849.28 8781.22 3258.61 -818.24 5964190.83 675120.15 3359.48 8.50 MWD
10265.00 84.00 119.00 8859.85 8791.79 3223.99 -764.26 5964157.49 675174.93 3313.34 15.22 MWD
FREE = CMI
WELLHEAD = FMC
ACTUATOR= BAKER
KB. ELEV = 68.1'
BF. ELEV = _?
KOP = 931'
Max Angle = 93 @ 10635'
Datum MD = WA
Datum TV D = 8800' SS
DRLG DRAFT
9-5/8" CSG, 40#, L-80, ID = 8.835" I~ 3829'
Minimum ID = 2.37" @ 9002'
3-3/16" LINER TOP PACKER
9002' ~ BAKER Liner top packer seal bore ID = :' 3"
4-112" TBG, 12.6#, 13CR80 VAM TOP, 9022'
.0152 bpf, ID = 3.958"
TOP OF 4-1 /2" LNR ~ 9080'
4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9091'
7" CSG, 26#, L-80, ID = 6.276" 9258'
4 112" MONOBORE PKR WHIPSTOCK 9398'
2-7/8" LNR TOP 9584'
PERFORATION SUMMARY
REF LOG: BAKER MWD/GR ON 02/12/08
ANGLE AT TOP PERF: 91 @ 9880'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2" 6 10810 - 11680 O 02I15i08
2" 6 11930 - 12020 O 02/15/08
~ 4-1/2" TNV WHIPSTOCK ~
PBTD 10973'
4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11060'
-I SAFETY NOTES: 70° @ 9852'
15 -4 5 B **•4-1 /2" CHROME TBG**
2118' I~ 4-1/2" HES X NIP, ID = 3.813"
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
4 3355 3157 32 KBG-2 DMY BK 0 03/05/06
3 5561 5012 35 KBG-2 DMY BK 0 03/05/06
2 7436 6597 26 KBG-2 DMY BK 0 05/14/05
1 8846 7899 19 KBG-2 DMY BK 0 05/14/05
8915' ~ 4-1/2" HES X NIP, ID = 3.813"
8936' 7" X 4-112" BKR S-3 PKR ID = 3.875"
8959' 4-1/2" HES X NIP, ID = 3.813"
9023' TBG STUB (DIMS 05/13/05)
9032' 7" X 4-112" UNIQUE OVERSHOT
9056' 7" X 4-1/2" BAKER 5-3 PKR
9079' 4-1/2" HES X NIP, ID = 3.812"
9091' 4-1/2" TUBING TAIL WLEG
ELMD TT NOT LOGGED
9299' BAKER DEPLOYMENT SUB. ID = 3.00"
XO 3-3/16" x 2-718" 1
9999' I
~~L// PBTD 12034'
3 112" x 3 3x16" x 2-7/82 LNRr16" x 12087'
pQ4441 PBTD ~ 12846' r
® 22-7/8'~ LNR, 6.16#, L-80, .0056 bpf, ID = 2.441"
DATE REV BY COMMENTS DATE REV BY COMMENTS
05/04196 ORIGINAL COMPLETION
09109100 JOM CTD SIDETRACK (15-45A)
05/15/05 D18 RWO
08!27/06 TWC(fLH DRLG DRAFT CORRECTIONS
02116!08 NORDICI CTD SIDETRACK (15-45B)
i,
PRUDHOE BAY UNfT
WELL: 15-45A
PERMIT: 2000680
API No: 50-029-22671-01
SEC 22, T11 N, R14E, 590' FNL & 5177' FEL
BP Exploration (Alaska)
{
E
s ~~ ~,°"`~ ~ i ~,~ ~ ~ ~ SARAH PALIN, GOVERNOR
ALA17~ OIL olsi7 t7[t;y7 333 W. 7th AVENUE, SUITE 100
COI~TSF.RQATIOl~T COrII~IISSIOI~T ANCHORAGE, ALASKA 99501-3539
PHONE (907)279-1433
Jacki Randall FAX (907) 276-7542
E Pad Engineer
BP Exploration Alaska Inc.
PO Box 196612
Anchorage, Alaska 99519-6612
Re: Prudhoe Bay Field, Prudhoe Bay OiI Pool, PBU E-18B
Sundry Number: 307-370
Dear Ms. Randall:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
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).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
DATED this ~ day of January, 2008
Encl.
STATE OF ALASKA /~,z
ALASt~IL AND GAS CONSERVATION COMMI~N
PERMIT TO DRILL ~~~
~°~
~-~~~. ~ ~QQ~
20 AAC 25.005 a~188k~ ~' ~~' ~ `:~;sa~. ~~~,z`~~
1 a. Type of work
^ Drill ®Redrill
^ Re-Entry 1 b. Current Well Class ^ Exploratory O Development Gas
^ Service ^ Multiple Zone
^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify. if we b 'mod for:
^ Coalbed Methane ^ Gas Hydrates
^ Shale Gas
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Singte Well
Bond No. 6194193 11. Well Name and Number:
PBU 15-458
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth:
MD 12011 TVD 8771 ss 12. Field /Pool(s):
Prudhoe Bay Field / Prudhoe Bay
4a. Location of Well (Governmental Section):
Surface:
4749' FSL
5180' FEL
SEC
22
R14E
UM
T11N 7. Property Designation:
ADL 028306 Pool
,
,
,
.
,
,
Top of Productive Horizon:
3295' FSL, 1253' FEL, SEC. 16, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date:
February 15, 2008
Total Depth:
2494' FSL, 4268' FEL, SEC. 15, T11N, R14E, UM 9. Acres in Property:
2560 14. Distance to Nearest Property:
24,000'
4b. Location of Well (State Base Plane Coordinates):
Surface: x-676014 y-5960952 Zone-ASP4 10. KB Elevation
(Height aboveGL): 68.06 feet 15. Distance to Nearest Well Within Pool:
1,100'
16. Deviated Wells: Kickoff Depth: 8400 feet
Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole: 3263 Surface: 2383
18. Ca in Pr ram: S 'catio ns To - Se 'n th - B m uanti of C ment .f. or sacks
Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data
4-1 /8" 3-3116" x z-~~e•~ 6.2# / 6.5# L-80 TCI I / STL 2701' 9310' 8268' 12011' 8771' 145 sx lass 'G'
1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations)
Total Depth MD (ft):
12906 Total Depth TVD (ft):
8840 Plugs (measured):
None Effective Depth MD (ft):
12841 Effective Depth TVD (ft):
8842 Junk (measured):
12830
asing Length ize ement Volume M TVD
Conductor /Structural 110' 20" 2 0 sx Ar ticset A rox. 11 11 '
Surface 3829' 9-5/8" 1085 sx CS III 305 sx'G' 200 x CS 11 382 ' 3554'
Intermediate 9258' 7" 230 sx Clas 'G' 9258' 8287'
Pro ion
Liner 1745' 4-1 /2" 220 sx CI ss 'G' 9080' - 10825' 8119' - 776'
Liner 322' 2-7/8" 14 x LARC 584' - 129 8595' - 8
Perforation Depth MD (ft): 11815' - 12820' Perforation Depth TVD (ft): 8820' - 8843'
20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis
^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct. Contact Abby Higbie, 564-5480
Printed Name Abby Higbie Title CT Drilling Engineer
~ Prepared ey Name/Number:
Si nature ~`--~"-' Phone 564-5480 Date Terrie Hubble, 564-4628
Commission UseAni
Permit To Drill API Number:
Number ~ ~9~ 50-029-22671-02-00 Permit Approval See cover letter for
D te: other re uir men
Conditions of Approval
If box is checked, well may not be used to explore for, test, or produce coalbed met1hane, gas by s, or gas contained shales:
Samples Req'd: ~es L~J No Mud Log Req'd: ^,Yes ~No
HZS Measures: Y N i al Survey Req'd: ~ Yes ^ No
Other: ~®®~St ~~~ '~~~
Date ~ ~(~ AP VED BY THE COMMISSION
,COMMISSIONER
Form 10-401 Revised 12/2005 `~ Submit In Duplicate
~~~~.~ ~.
•
by
To: Tom Maunder, Petroleum Engineer
Alaska Oil & Gas Conservation Commission
From: Abby Higbie, CTD Engineer
Date: December 20, 2007
Re: Prudhoe Bay 15-45B Permit to Drill Request
The sidetrack, 15-45B, is scheduled to be drilled by Nordic 1 around February 15th
Pre-Rig Work: The pre CTD work is slated to begin on January 15th, 2008.
1. S Caliper inspection to 9500' Done 12/17/07
2. S Run dummy whipstock drift to 9500'
3. E Set Baker 4-1/2" Monobore packer whipstock lowside at 9400'.
4. W Set BPV
5. O Pass MIT-IA, -OA
6. O PPPOT-IC, -T; LDS
7. o PT MV, sv, wv ~~`~_~~~
8. O Blind and bleed lines, remove well house, level pad
Rig Work:
1. MIRU and test BOPE to 250 psi low and 3500 psi high
2. Mi113.80" window at 9,400' and 10' of openhole. Swap the well to Flo-Pro.
3. Drill Build: 4.125" OH, 900' (30 deg/100 planned)
4. Drill Lateral: 4.125" OH, 1950' horizontal (15 deg/100 planned)
5. Run 3-3/16" x 2-7/8" solid liner leaving TOL at 9310'
6. Pump primary cement job
7. Run MCNL/GR/CCL log
8. Test liner lap to 2000 psi.
9. Perforate, 800' minimum
10. Freeze protect well with diesel down to 2500', Set BPV, RDMO
Post-Rig Work
1. Pull BPV
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: 4.125"
Casing Program:
• 3-3/16", 6.2# , L-80, TCII or STL connection Solid liner - 9,310' to 10,400' MD
• 2-7/8", 6.5 #, L-80, STL connection Solid liner-10,400'-12,011'
• A minimum of 30 bbls 15.8 ppg cement will be used for liner cementing.
• TOC planned at 9310 ft (TOL). .''
•
Weli 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 92 deg.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property - 24000'
• Distance to nearest well within pool - 1100' north of 15-08C TD
Anticollision Summary
• 15-27 - 47' ctr-ctr, Status: Currently plugged, fasdrill Plug set at 10,200'
• 15-41B - 99' ctr-ctr, Status: Currently plugged; one IBP at 10,212' and one at 10,515'
Logging
• MWD directional and Gamma Ray 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 15 is 40 ppm on 15-20C
• Lost circulation risk is moderate.
Reservoir Pressure
• Res. press. is estimated to be 3,263 psi at 8,800'ss (7.1 ppg EMW).
Maximum surface pressure with gas (0.10 psi/ft) to surface is 2383 psi.
Abby Higbie
CTD Drilling Engineer
564-5480
CC: Well File
Sondra Stewman/Terrie Hubble
u~u = rnnc
CTUATOR = _ _
BAKER
KB. ELEV = 68.1'
BF. B.EV = _?
KOP = 931'
Max Angle = 97 ~ 10909'
Datum MD = WA
Datum ND = 8800' SS
9-5/8" CSG, 40#, L-80, ID = 8.835" H 3829'
Minimum ID = 2.37" ~ 9584'
TOP OF 2-7/8" LINER
15-4 5 A "'" ~~: 70" ~ 9852'
4-112" CJ~RANIF TR[~!'""
2118' H 41/2" HES X NIP, ID = 3.813"
GAS LIFT MANDRELS
S MD TVD DEV TYPE VLV LATCH PORT DATE
3355 3157 32 KBG-2 DRAY BK 0 03/05/08
3 5561 5012 35 K8G-2 DMY BK 0 03105/06
2 7438 6597 26 KBG-2 DMY BK 0 05/14/05
1 8848 7899 19 KBG-2 DMY BK 0 05/14/05
8915' 4-1 /2" HES X NIP, ID = 3.813"
8936' 7" X 4112" BKR S-3 PKR, ID = 3.875"
8959' 41/7' HES X NIP, ID = 3.813"
4117' TBG, 12.6#, 13CR80 VAM TOP, X22' 9023' TBG STUB (DNNS 05/13/05)
.0152 bpf, ID = 3.958" 8032' T' X 4112" UNIQUE OVERSHOT
9058' 7" X 41/2" BAKER S-3 PKR
9079' 41 /2" HES X N~, ID = 3.817'
TOP OF 41/2" LNR H 9080'
41/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" 9091'
T' CSG, 28#, L-80, ID = 6.278" 925$'
PERFORATION SUVMARY
REF LOG: SPERRY MWDIGR ON 09/06/00
A NGLE AT TOP PERF: 79 ~ 9880'
Note: Refer to Production DB for histor~al perf data
SIZE SPF INTERVAL Opn/Sgz DATE
2-3/4" 4 X880 - 10080 S 09109/00
2-3/4" 4 10110 - 10510 S 09V09/00
2-3/4" 4 10560 - 10770 S 09!09100
2-3/4" 4 10820 - 10890 S 09V091D0
2" 4 11815 - 12250 O 09108/00
7' 4 12360 - 12420 O 09/08N0
2" 4 12480 - 12820 O 09/08/00
9091' -~ 41/2" TUBING TAIL WLEG
ELMD TT NOT LOGGED
9684' BAKER DEPLOYMENT SUB, ID = 3.00"
WINDOW MILLED TO 10837.
3.75" HOLE WAS DRILLED TO
TD OF 12906' MD.
12830' FISH: RIG 8 FASDR~L
DEBRIS (05/2510,5)
41!2" TiW wHA~STOCK H 10825'
PBTD 10973'
12.6p, L-80, .0152 bpf, ID = 3.958" 11080'
2-7/8" LNR, 6.1 ~, L-80, .0058 bpf, A7 = 2.441" H 12906' ~
DATE REV BY COMMENTS DATE REV BY COMMENTS
05/04198 ORIgNAL COMPLETKNN 08127106 TWCtTLH ORLG DRAFT CORRECTIONS
09/09/00 JOM CTD81DEfi81CK 15-45A 11108A6 RLMITI.H PERF SQZ (2000 CORRECTIONS
05/15105 D18 RaMO
05/21105 RVVI./PJC GLV GO
05/25AQ5 MDCIPJC PUSH FASDF2N.L TO BTM
03/05/06 CIAV/PJC GLV GO
PRUDI-IOE BAY UN(T
W~L: 15-45A
FERMTf: 2000680
AR No: 50.029-22671-01
SEC 22, T71 N, R7 4E, 590' FNL 8 517T FEL
~ Bcpbratbn (Afaskai
._
~IfAD= ~ ~ 8S2'
45B s
15
E
JATOR = BAKER ••• *•
-
.,~
,
iEV = 68.1'
Proposed CTD sidetrack
iEy= ,
= 931'
Angle = 97 ®10909'
m ND = WA 2118' 4-1/2" HES X NP, D = 3
m TVD = 8800' SS
~ 9-5/8" CSG, 40i, L-80, D = 8.835" ~
GAS LET MANDRELS
S MD TVD DEV TYPE VLV LATCH PDRT DATE
4 3355 3157 32 KBG-2 DMY BK 0 03/05/06
3 5561 5012 35 KBG-2 DMY BK 0 03/05/06
2 7436 8597 26 KBG-2 DMY BK 0 05/14/05
1 8848 7899 19 KBG-2 DMY BK 0 05/14/05
Minimum ID = 2.37" ac 9300'
TOP OF 3-112" LINER
8915' H 4-1/2" HES X NP, D = 3.813"
8936' 7" X 4-1/2" BKR S-3 PKR, D = 3.875"
4-1/2" TBG, 12.8, 13CR80 VAM TOP, 9022'
.0152 bpf, D = 3.958"
TOP OF 4-1 /2" LNR
12.6*, L-80, .0152 bpf, D = 3.958"
7" CSG, 26~, L-80, D = 6.276"
4 112" MONOBORE PKR WHIPS?OC
PS~FORATION SUMMARY
REF LOG: SPERRY MIM]/GR ON 09/06/00
ANGLE AT TOP PERF: 79 (~ 9880'
Note: Refer to Roduction DB for historical pert data
S¢E SPF INT6T/AL OpNSgz DATE
2-3/4" 4 09880 - 10080 S 09/09/00
2-3/4" 4 10110 - 10510 S 09/09/00
2-3/4" 4 10560 - 10770 S 09/09/00
2-3/4" 4 10820 - 10890 S 09/09!00
2" 4 11815 - 12250 O 09/08/00
2" 4 12360 - 12420 O 09/08/00
2" 4 12460 - 12820 O 09/08/00
7" X 4-1/2" UNIQUE OVERSHOT
7" X 4-1/2" BAKER S-3 PKR
4-112" HES X N~ D = 3 812"
9091' a-112" TUBING TAIL WLEG
H.MD TT NOT LOGG®
9300' F3AKEIt t ~~e~~~ _~ - ~~ sea~~ bore ID = 2 375"
XO 3-3/16" x 2-7/8" f-{ 10400'
~~~~;~ ?D 12011'
3 1/2" x 3 3/16" x 2-7/8" LNR 12011'
L-80, .0152 bpf, D = 3.958" H 1
2-718" LNR, 6.18, L-80, .0056 bpi, D = 2.441" H 12906'
COMMi~fTS PRUDHOE BAY UNIT
DRAFT CORRECTDNS 1NELL: 15-45A
iAZ (2000) OORRI~TIONS PERMR: 2000680
API No: 50-029-22871-01
SEC 22, T11 N, R14E, 590' FNL fl 517T FEL
8P 6cploratbn PAlaska)
~p BP Alaska
Baker Hughes INTEQ Planning Report
~i%~
~~
INTEQ
Compat+y: BP AMOCO Datr. 12/512()d7 Time: 14:48:57 Page: i
Field: Pnxihoe $aY Go-erdinate(PtE) Reference: Well: 15-45. True North
Site: PB DS 15 Vertltai (TVD) Reterencr. 63:45 9/24/199816:29 68.1
Welk 15.45 Satiou (VS) te~reece; _ Well (O.OON,O.OOE,120.OOAzi)
Wellpsi6: Plan 2,15-458 Suevey CakOn Method; Minimum Curvature Db: Orade
Field: Prudhoe Bay
North Slope
UNITED STATES
Map System:US State Plarm Coordinate System 1927 Map Zone; Alaska, Zone 4
Gen Datum: NAD27 (Clarke 1866) Ordinate System: Wei Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Site: PB DS 15
TR-11-14
UNITED STATES :North Sbpe
Sih Petitioa: Northing: 5958837.36 ft L.atltadt: 70 17 35.236 N
From: Map Eetting: 676296.98 ft Longitude: 148 34 21.213 W
Petition Uncertainty: 0.00 ft Nertb Rekrence: True
Ground Level: 0.00 ft Grid Convergence: 1.34 deg
WeY: 15-45 Slat Name: 45
15-45
WeN Position: +N/-S 2121.31 ft Nort6iag: 5960952.49 ft I.atitnde: 70 17 56.099 N
+E/-W -232.87 ft Eastiug : 676014.44 ft Longitude: 148 34 28.002 W
Position Uncerta®ty: 0.00 ft
WeYpatb: Plan 2, 15~5B Drilled From: 15-45A
Tie-on Depot: 9381.15 ft
Current Datnm: 63:45 9/24/1996 16:29 Height 68.06 ft Above System Datnm: Mean Sea Level
Magnetie Data: 12!4!2007 Dcelinatioa: 23.54 deg
Field Strength: 57667 nT Mag Dip Angle: 80.93 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
37.06 0.00 0.00 120.00
Plan: Plan #2 Date Composed: 12/4/2007
copy Mary's plan 2 Version: 8
Prioeipal: Yes Tied-to: From: Definitive Path
Targets
.Map.. Map <-- Latitude .-a' 4- Longitude -^~
Name Description TVD +N/-S +FJ-W Nortbi~ Eastiag ' Deg Mia See Deg Min Sce
.:1Aµ Die ' R ft ft ft ft
15-458 Target 1 8713.06 3402.55 -1020.10 5964330.00 674915.00 70 18 29.563 N 148 34 57.753 W
15-458 Target 5 8838.06 3027.30 906.77 5964000.00 676850.00 70 18 25.872 N 148 34 1.558 W
15-456 Target 4 8863.06 3019.01 -233.81 5963965.00 875710.00 70 18 25.791 N 148 34 34.821 W
15-456 Target 2 8868.06 3200.92 -739.72 5964135.00 675200.00 70 18 27.580 N 148 34 49.575 W
15-456 Target 3 8868.06 3132.42 -591.28 5964070.00 675350.00 70 18 26.906 N 148 34 45.246 W
An~~tbn
MD TVD
f1' ft
9381.15 8403.09 TIP
94t~.00 8420.87 KOP
9420.00 8439.85 End of 9 Deg/100' DLS
9450.00 8468.96 4
9714.40 8665.56 5
9764.40 8678.35 6
9884.40 8702.22 7
9944.40 8735.16 End of 30 Deg/100' DLS
10054.40 8799.70 9
10286.25 8867.92 10
10461.25 8867.92 11
10561.25 8867.47 12
10811.25 8863.99 13
by BP Alaska
Baker Hughes INTEQ Planning Report
~.r
~~
1NTEQ
Company: BP AmoCQ Date: 12/5/2007 Time: 14:48:57 Pagr. 2
Field: Prudhoe Bay Co-orditiatetNE) Refereacr. Well: 15-45, True North
SNet ' PB DS 15 Vertical (TVD) Rekreace: 63:45 9!2411 996 1 6:29 68 .1
Welt 1 5-45 Sertiea (VS) Referesee: Well (O.OON,O. OOE,120.OOAzi)
'WeI1pAt<, Phan 2;15-458 ' Sawey CakrakNian Method: Minimum Curvature Db: Orade
Araotstier
MD TVD
ft ft
1116L25 8855.99 14
11411.25 8850.26 15
11711.25 8844.97 16
11881.25 8842.44 17
12011.25 0.00 TD
Pisa Section Information
NID Iael Aziet TVD +NFS +E/-W DLS ' Build Tara TFO Target
ft deg deg ft ft ft deg/1 OOft degN OOft deg1100ft deg
9381.15 19.47 348.20 8403.09 3547.21 -1291.15 0.00 0.00 0.00 0.00
9400.00 19.27 347.86 8420.87 3553.32 -1292.45 1.22 -1.06 -1.80 209.26
9420.00 17.47 347.86 8439.85 3559.49 -1293.77 9.00 -9.00 0.00 180.00
9450.00 10.64 12.92 8468.96 3566.80 -1294.10 30.00 -22.76 83.53 150.00
9714.40 75.00 125.70 8665.56 3505.87 -1163.36 30.00 24.34 42.65 115.00
9764.40 75.52 141.20 8678.35 3472.72 -1128.38 30.00 1.04 31.01 90.00
9864.40 77.50 110.39 8702.22 3416.70 -1050.50 30.00 1.97 -30.81 270.00
9944.40 53.50 110.39 8735.16 3391.52 -982.77 30.00 -30.00 0.00 180.00
10054.40 55.22 130.62 8799.70 3346.39 -906.51 15.00 1.57 18.39 90.00
10286.25 90.00 130.62 8867.92 3204.54 -741.14 15.00 15.00 0.00 0.00
10461.25 90.00 104.37 8867.92 3124.45 -587.26 15.00 0.00 -15.00 270.00
10561.25 90.52 89.38 8867.47 3112.51 X88.27 15.00 0.52 -14.99 272.00
10811.25 91.02 126.88 8863.99 3036.11 -254.92 15.00 0.20 15.00 89.00
11161.25 91.41 74.37 8855.99 2973.81 77.08 15.00 0.11 -15.00 271.00
11411.25 91.12 111.88 8850.26• 2960.43 322.21 15.00 -0.12 15.00 90.00
11711.25 90.79 66.87 8844.97 2963.63 614.49 15.00 -0.11 -15.00 270.00
11861.25 91.12 89.37 8842.44 2994.30 760.31 15.00 0.21 15.00 89.00
12011.25 91.80 66.88 8838.58 3024.95 906.12 15.00 0.45 -15.00 272.00
Sarvey
MD Inc! Azim SS TVD N~ ENVY MapN MapE DLS . VS TFO Too!'
ft deg deg. _ft ft ft ft ft deg/100ft ft _,deg
9381.15 19.47 348.20 8335.03 3547.21 -1291.15 5964468.25 674640.64 0.00 -2891.77 0.00 MWD
9400.00 19.27 347.86 8352.81 3553.32 -1292.45 5964474.34 674639.21 1.22 -2895.96 209.26 MWD
9420.00 17.47 347.86 8371.79 3559.49 -1293.77 5964480.47 674637.74 9.00 -2900.18 180.00 MWD
9450.00 10.64 12.92 8400.90 3566.60 -1294.10 5964487.57 674637.24 30.00 -2904.03 150.00 MWD
9500.00 14.18 86.11 8449.99 3571.55 -1286.92 5964492.68 674644.31 30.00 -2900.28 115.00 MWD
9600.00 41.40 117.20 8537.99 3556.93 -1244.31 5964479.07 674687.25 30.00 -2856.07 43.08 MWD
9700.00 70.75 124.90 8593.26 3513.82 -1174.59 5964437.60 674757.95 30.00 -2774.13 14.66 MWD
9714.40 75.00 125.70 8597.50 3505.87 -1163.36 5964429.92 674769.36 30.00 -2760.43 10.21 MWD
9764.40 75.52 141.20 8610.29 3472.72 -1128.38 5964397.60 674805.11 30.00 -2713.56 90.00 MWD
9800.00 75.78 130.18 8819.14 3448.09 -1104.33 5964373.54 674829.73 30.00 -2680.42 270.00 MWD
9864.40 77.50 t 10.39 8834.16 3416.70 -1050.50 5964343.42 674884.27 30.00 -2618.11 272.74 MWD
9899.86 66.86 110.39 8845.00 3404.95 -1018.90 5964332.42 674916.13 30.00 -2584.87 180.00 15-458
9900.00 66.82 110.39 8645.06 3404.91 -1018.78 5864332.38 674916.25 30.00 -2584.75 180.00 MWD
9944.40 53.50 110.39 8667.10 3391.52 -982.77 5964319.84 674952.57 30.00 -2546.86 180.00 MWD
10000.00 53.94 120.73 8700.06 3372.21 -942.43 5964301.49 674993.35 15.00 -2502.28 90.00 MWD
10054.40 55.22 130.62 8731.64 3346.39 -908.51 5964276.51 675029.86 15.00 -2458.25 83.87 MWD
10100.00 62.06 130.62 8755.35 3321.05 -878.97 5964251.87 875059.98 15.00 -2420.00 0.00 MWD
10134.20 67.19 130.62 8770.00 3300.94 -853.53 5984232.32 675083.89 15.00 -2389.64 0.00 15-458
10200.00 77.06 130.82 8790.17 3260.22 -806.05 5964192.72 675132.30 15.00 -2328.17 360.00 MWD
10286.25 90.00 130.62 8799.86 3204.54 -741.14 5964138.59 675198.50 15.00 -2244.12 0.00 MWD
10300.00 90.00 128.56 8799.86 3195.78 -730.54 5964130.07 675209.30 15.00 -2230.56 270.00 MWD
10400.00 90.00 113.56 8799.86 3144.33 -645.12 5964080.65 675295.89 15.00 -2130.86 270.00 MWD
1048t.25 90.00 104.37 8799.86 3924.45 -587.28 5964062.12 675354.20 15.00 -2070.81 270.00 MVW
10500.00 90.20 98.56 8799.80 3116.75 -549.30 5964055.32 675392.33 15.00 -2034.08 272.00 MVW
10561.25 90.52 89.38 8799.41 3112.51 -488.27 5964052.51 675453.44 15.00 -t979.11 271.99 MVVD
10600.00 90.62 95.19 8799.03 3110.98 -449.56 5964051.87 675492.17 15.00 -1944.82 89.00 AAWD
by BP Alaska
Baker Hughes INTEQ Planning Report
~%r
S
1NTEQ
Coe~paey: BP AmoCO Date: 12!5/2007 Tiex: 14:48:57 Pale: 3
Reid: Pnuihoe Bay Co~ordlwte(NEJ1Refereoce: Well: f5-45, True North
She: PB DS 15 ' Vertkal(TV1D) Retereece: 63:45 9/24/1998 16:29 68.1
Wet1; 15-45 Sectie~ (VS) Rtiereace: WeN (O.OON,O.OOE,120.OOAzi)
We®pat6s .'Plan 2, 15-456` S®rvey CelrnlaAoe Method: Minimum Curvature Db: Oracle
Servey
MD !eel Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool
ft deg deg R ft' ft ft R deg/100ft ft deg
10700.00 90.84 110.19 8797.75 3089.06 -352.29 5964032.25 875589.92 15.00 -1849.62 89.06 MWD
10800.00 91.00 125.19 8796.13 3042.72 -264.01 5983988.00 675679.25 15.00 -1T50.Q0 89.25 M{M1IO
10811.25 91.02 126.88 8795.93 3036.11 -254.92 5963981.60 675688.50 15.00 -1738.82 88.49 MWD
10900.00 91.22 113.57 8794.19 2991.54 -178.42 5963938.84 675786.02 15.00 -1650.28 271.00 MWD
11000.00 91.37 98.56 8791.81 2963.95 -82.62 5963913.50 675862.43 15.00 -1553.53 270.74 MWD
11100.00 91.43 83.56 8789.46 2962.11 17.04 5963913.99 675962.10 15.00 -1466.29 270.40 MWD
11161.25 91.41 74.37 8787.93 2973.81 77.08 5963927.10 676021.84 15.00 -1420.16 270.03 MWD
11200.00 91.41 80.18 8786.98 2982.34 114.85 5983936.51 676059.40 15.00 -1391.71 90.00 MWD
11300.00 91.32 95.19 8784.59 2986.37 214.45 5963942.87 676158.88 15.00 -1307.46 90.14 MWD
11400.00 91.15 110.19 8782.42 2964.47 311.71 5963923.25 676256.61 15.00 -1212.28 90.50 MWD
11411.25 91.12 111.88 8782.20 2960.43 322.21 5963919.47 676267.20 15.00 -1201.18 90.83 MWD
11500.00 91.09 98.56 8780.47 2937.19 407.64 5963898.23 676353.15 15.00 -1115.57 270.00 MWD
11600.00 90.99 83.56 8778.65 2935.34 507.32 5963898.72 676452.84 15.00 -1028.32 269.74 MWD
11700.00 90.82 68.56 8777.07 2959.36 604.08 5963925.00 676549.01 15.00 -956.53 269.47 MWD
11711.25 90.79 66.87 8776.91 2963.63 614.49 5963929.50 676559.31 15.00 -949.65 269.23 MWD
11800.00 91.00 80.19 8775.51 2988.73 699.40 5963956.59 676643.60 15.00 -888.67 89.00 MWD
11861.25 91.12 89.37 8774.38 2994.30 760.31 5863863.58 676704.37 15.00 -838.70 89.21 MWD
11900.00 91.31 83.56 8773.56 2996.68 798.97 5963966.87 676742.95 15.00 -806.41 272.00 MWD
12000.00 91.75 68.56 8770.87 3020.69 895.71 5963993.14 676839.10 15.00 -734.64 271.88 MWD
12011.25 91.80 66.88 8770.52 3024.95 906.12 5963987.64 676849.40 15.00 -727.76 271.47 3.5"
WF.1.1. Dlsfna.s
. N..g •E•W Nwdkp Fi+Onp f.salude I.masu.le Slw
113131 -2i2.e7 i91d19i149 b7lAli 44 70'1Tifi.1199N 14E .i4'18 fn1W 4i
g5g9
o`7~S
~-
~~~~
ANTI-COLLISION SETTINGS
Intttpolauon Method MD Wen al: Sfl.tq
Depth Range From: `}faILIN) To: 12a1 L25
Maximum Range: 25(Nl.gl Rcfercncc: Plan: Plan k2
,,.,~.~.,DEr.~rs
av.am.,.
`~~ ~~. ski s um ~.w.a~.
~s
9<-a.N<~nt r ~. Wn::uW
tT.e rung. ! ~.wl ~ <'wry
tl unary ~h.1 RW.~tl~uN
\\
~\ ~
~..~ ~
~~ ~ ~
,~ \~\ ~ ~ ;
„~,~„e,K:kut
umw r. D.r<n i,, .v, ,
9vi a un i ~. vw..~ w~,., ~.
,~
,1 ~ ~
' ~
~
~
~
~~
r ~
~ „
~
~
,_
. , ~ ,
~ +
~ ~
:,
~ ~ ,
\ ,
,
-
~,:~ ,,
__
,.:
__
\~~ __ - Igr2g
____ _
;~~~~~ ~_~ _ t~
.,r
_
~~~` ~
_
~~ ~ ~~~ l ~ ~ ~ I ~ , ~
~ ~ ,;
i' ~~
,'
,.
=. ,; , ,,,
;; ~, ,,
j. -~~%~~
_,
_,
_f,,,,,
n..dw gLnk, o-oo,wx,rvo. vel+al ~~, wr<kiw ry wllsnu,~
ran er: isasa
N~1
N~f Duw F.. vx41YM IbA n+ma
v SN¢k {~ ~4'D
LEGEND
- 15-08 (13-08B), Major Risk
13-08 (IS-08BPB1),Major Risk
- IS-08115-08C), Major Rlsk
15-17 (IS-l7), Major Risk
- IS-19115-19A), Major Ris-
IS-26(13-26B),MalorRisk
15-27 (I 5-27), Major Risk
IS-01 (IS-41), Mayor Rlsk
15-01 (13-41A), Major Risk
IS-41 (15-41B), MalorRisk
13.41 (15-418PB1), rlajor Risk
- 15-41 (PIanH3 13-41A), Major Risk
- 15-44 (154), Mayor Risk
15-45 (IS-43), Mayor Risk
- 15-45 (IS-43A), Major Risk
IS-45 (IS-13APB1), ~lajor Risk
- - IS-0S (I S-0SAP82), Major Risk
15-45 (1 S-43PB I ), Major Risk
Plan 2, IS-438
Plan N2
by
r~.~~
INTEQ
sv<iiu. SOl.I•w
s« +m u. ~ a-u ni.<+ nr< s~s« r +
nn
_
ivii ur+'vs writ
~'xu it is+rx
min
wrw
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on. n r =i w iine a. iw~+
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ii: s'
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s
ucm inoso
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rl si rz iwi~
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e
ts
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u iu
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iwi9 :;mm~
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maxs r - iui -imsii
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18-13B
. - . - BAG
Dowell
bag
Blind/Shears
2 3/8" combi ram/slips
TOTs
Mud Cross I I Mud Cross
cross
variable bore pine 3 1/2"-2 7/8"
2 3/8" combi ram/slips
TOTs
Flow Tee
Alaska Department of Natural Resources Land Administration System Page 1 of 2
•
.,-. , , ~ , y.,~~~~ :r~~~ '~ ~_~.;~. ,~ .. ;t; c~;rc#~r's Se~~ch State Cabins ~ ~tu~ 41l'CkES
Alaska DIVR Case !5ummar~/
File Type: ADI_ File Number _„ 28306 ~1 printable Case Fite_Summary
See Township, Range, Section and Acreage?
New Search
~' Yes C"' No _~_ ~ W
LAS Menu I Case Abstract 1 Case Detail ~ Land Abstract
'~,
I~rlc: AUL 28306 ~~~ ~ Search for Status Plat Updates
1; ~>I I ~''?Si~0C17
Ca~stomer: 000107377 8P EXPLOR4"h[ON (ALASKA) INC
PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER-
ALASKA
ANCHORAGE AK 995 1 966 1 2
Case The: ~~. OIL & GAS LEASE COMP DNR Unit: 780 OiL AND GAS
File Location: DOG DIV OIL AND GAS
Case S`tatars: 35 LSSUED Status Date: 09/14/1965
Total ~~icres: 2560.000 Date Initiated' 05/28/1965
Office of Pf~inurrv Responsibility: DOG D[V O IL AND GAS
Last Transaction Date: 12/04/2006 Case Sz~bhhe : ~ ~ NORTH SLOPE
Last Transaction: AA-NRB ASSIGNMENT APP ROVED
TI217Chai2_ ~~ I(~It~211?ZIJ: OLIN Ra]lof;: OI~E ~S(?Ct1012: I ~ ~C'C/IClnr~CrC'S:O'-~~) 5~8rCfl
~i~~S
11~~ri~ fian: U 7'uu~jc~l~i/~: O J 1 N Range: 014E St>.clir,~r ~ f t~ ti'~~~~/ion Acres: (,~0
1/eria'ian: U Irnrn~hi1~.~ Ol I\ IZcrn~~~.~ 014E Section_ 21 ~<<~liu~r.lc~rc~~~: (CIO
ll~~ridian: U li~ii.>nsl~r/~: ill/V'' Range: 014E Sectior2: 22 ~'~~c~ivir.lcr~~s: 6IO
Legal :Description
0~-?b'-196~ *'`~SALENOTIC'ELEC:AI,DESCRIPTION*~`^`
C'1-1-1?711V 1-lE L;~1I1~,16. ?1,?~ 2~hU.00 U- 3- 7
I
Last updated on 12/28/2007.
http:/lwww. dnr. state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=283 06... 12/28/2007
~ ~
TRANSMITTAL LETTER CHECKLIST
WELL NAME P/~u /S- ~~~
PTD# ~~~/~90
Development Service Exploratory Stratigraphic Teat
Non-Conventional Well
Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS TEXT FOR APPROVAL LETTER
WHAT {OPTIONS)
APPLIES
MULTI LATERAL The permit is for a new welibore segment of existing
well
(If last two digits in permit No. , API No. SO- -
API number are
Production should continue to be reported as a function of the
between 60-69) original API number stated above.
PILOT HOLE In accordance with 20 AAC 2S.OOS(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in .both
well name ( PH) and API number
(SO- _) from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to perforate and produce /inject is contingent
upon issuance of a conservation order approving a spacing
exception. , assumes the
liability of any protest to the spacing exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the Commission must be in
SAMPLE no greater than 30' sample intervals from below the permafrost or
from where samples are first caught and 10' sample intervals
through target zones.
Please note the following special condition of this permit:
Non-Conventional production or production testing of coal bed methane is not allowed
Well for dame of well) until after ~Companv Name) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. ~,Comoany Namel must contact the
Commission to obtain advance approval of such water well testing
ro ram.
Rev: 7113!2007
^^
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1
Well History File
APPENDIX
s
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 calegory of information.
**** REEL HEADER ****
MWD
08/04/24
BHI
O1
LIS Customer Format Tape
**** TAPE HEADER ****
MWD
08/02/08
1809593
O1
3.0" CTK
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
Version Information
VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20
WRAP. NO: One line per frame
Well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 9243.0000: Starting Depth
STOP.FT 10270.0000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent Value
COMP. COMPANY: BP (Alaska)Exploration, Inc.
WELL. WELL: 15-45BPB1
FLD FIELD: Prudhoe Bay Unit
LOC LOCATION: 70 deg 17' 56.099"N 148 deg 34' 28.002"W
CNTY. COUNTY: North Slope
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 3.0" CTK
DATE. LOG DATE: 08-Feb-2008
API API NUMBER: 500292267173
Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
SECT. 22 .
TOWN.N T11N .
RANG. R14E .
PDAT. MSL
EPD .F 0
LMF DF .
FAPD.F 68.6
DMF DF .
EKB .F 0
EDF .F 68.6
EGL .F 0
CASE.F N/A .
OS1 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.
~, ate--~ ~--q ~ !~! ~
(2) All depths are Bit Depths unless otherwise noted.
(3) All True Vertical Depths (TVD) are Subsea corrected.
(4) All Formation Evaluation data is realtime data.
(5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the
Advantage
surface system to log 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 and
Ultra Slim Resistivity Sub.
(7) Data presented here is final and has been depth adjusted to 15-45B
above the Kick Off Point
of 10018 feet MD per Roger Furley with BP.
(8) The sidetrack was drilled from 15-45 through a milled window in 4
1/2 inch liner.
Top of window 9398 ft.MD (8351 ft.TVDSS)
Bottom of window 9404 ft.MD (8357 ft.TVDSS)
(9) Tied to 15-45 at 9381 ft.MD (8335 ft. TVDSS)
(10) The interval from 10225 feet to 10265 feet MD (8786 feet to 8792
feet TVDSS) was not logged due to sensor to
but offset.
MNEMONICS:
GRAX -> Gamma Ray [MWD] (MWD-API units)
ROPA -> Rate of Penetration 3.0 Avg (ft/hour)
RACLX -> Compensated Resistivity Borehole Corrected(LS)(AT)
(400kHz),Ohm-m
RACHX -> Compensated Resistivity Borehole Corrected (LS)(AT)
(2MHz),Ohm-m
RPCLX -> Compensated Resistivity Borehole Corrected (LS)(PD)
(400kHz),Ohm-m
RPCHX -> Compensated Resistivity Borehole Corrected (LS)(PD)
(2MHz),Ohm-m
TVD -> Subsea True Vertical Depth
CURVE SHIFT DATA
BASELINE, MEASURED, DISPLACEMENT
9246.23, 9244.98, ! -1.24414
9247.05, 9246.02, ! -1.03613
9248.09, 9247.88, ! -0.207031
9249.75, 9250.99, ! 1.24316
9251.82, 9252.86, ! 1.03711
9254.1, 9255.14, ! 1.03711
9256.8, 9257.83, ! 1.03613
9260.74, 9260.74, ! 0
9261.77, 9262.81, ! 1.03711
9264.05, 9265.3, ! 1.24414
9268.82, 9270.06, ! 1.24316
9270.89, 9271.1, ! 0.208008
9273.17, 9272.34, ! -0.829102
9274.62, 9274.62, ! 0
9280.43, 9280.84, ! 0.414062
9282.5, 9283.75, ! 1.24414
9284.78, 9285.4, ! 0.62207
9287.06, 9287.89, ! 0.830078
9289.14, 9290.17, ! 1.03613
9291.21, 9292.04, ! 0.829102
9292.66, 9294.11, ! 1.45117
9294.94, 9295.56, ! 0.62207
9297.63, 9299.09, ! 1.45117
9301.99, 9303.65, ! 1.6582
9304.06, 9306.13, ! 2.07227
9308.83, 9309.87, ! 1.03613
9388.92, 9390.37, ! 1.4502
9394.31, 9396.59, ! 2.28027
9399.49, 9400.94, ! 1.45117
9406.54, 9408.2, ! 1.6582
9408.61, 9410.48,
9410.27, 9411.93,
9415.87, 9417.73,
9418.56, 9420.01,
9420.22, 9421.67,
9421.88, 9423.75,
9424.78, 9426.65,
9427.89, 9429.55,
9430.17, 9432.25,
9434.21., 9436.49,
9437.94, 9439.81,
9441.26, 9442.71,
9442.5, 9443.95,
9444.37, 9445.82,
9448.1, 9449.14,
9449.55, 9450.79,
9462.97, 9464.21,
9505.35, 9507,
9512.19, 9513.64,
9556.96, 9559.03,
9561.31, 9562.97,
9562.55, 9564,
9566.49, 9567.73,
9568.15, 9569.19,
9572.71, 9572.71,
9580.69, 9582.97,
9582.97, 9585.25,
9586.91, 9588.98,
9589.19, 9591.05,
9593.12, 9595.4,
9597.68, 9599.34,
9647.73, 9649.81,
9654.58, 9657.06,
9671.37, 9673.85,
9673.65, 9676.13,
9679.29, 9681.73,
9682.35, 9685.05,
9687.16, 9690.89,
9698.77, 9702.71,
9704.99, 9706.23,
9707.68, 9708.72,
9709.96, 9710.38,
9712.25, 9712.87,
9716.18, 9717.84,
9723.44, 9725.3,
9728.62, 9729.45,
9736.7, 9737.11,
9746.23, 9746.86,
9756.39, 9757.01,
9762.4, 9762.61,
9773.39, 9774.43,
9828.15, 9828.36,
9832.92, 9833.33,
9837.89, 9838.31,
9854.83, 9855.45,
9874.32, 9874.73,
9878.26, 9878.88,
9904.99, 9906.03,
9908.31, 9909.55,
9918.61, 9920.48,
9928.56, 9929.81,
9935.4, 9936.23,
9941.21, 9942.87,
9951.1, 9952.76,
9957.73, 9959.19,
9960.84, 9962.29,
9966.44, 9968.31,
1.86621
1.65918
1.86523
1.45117
1.45117
1.86523
1.86621
1.6582
2.07324
2.28027
1.86621
1.45117
1.45117
1.45117
1.03613
1.24316
1.24414
1.6582
1.45117
2.07324
1.6582
1.45117
1.24316
1.03613
0
2.28027
2.28027
2.07324
1.86621
2.28027
1.6582
2.07324
2.4873
2.4873
2.4873
2.48828
2.69434
3.73145
3.93848
1.24316
1.03711
0.415039
0.62207
1.65918
1.86523
0.829102
0.414062
0.62207
0.621094
0.208008
1.03613
0.207031
0.415039
0.414062
0.62207
0.414062
0.62207
1.03613
1.24414
1.86621
1.24414
0.829102
1.6582
1.6582
1.45117
1.45117
1.86523
M
9969.14, 9970.59, ! 1.45117
9971.83, 9973.49, ! 1.6582
9974.1, 9975.97, ! 1.86621
9994.21, 9995.66, ! 1.45117
9998.98, 10000.4, ! 1.45117
10005.4, 10006.2, ! 0.829102
10006.9, 10008.1, ! 1.24414
10008.3, 10010.2, ! 1.86523
10012.2, 10013.9, ! 1.6582
10015.6, 10017.2, ! 1.6582
EOZ
END
! BASE CUR VE: GROH, OFFSET CURVE: GRAX
Tape Subfile: 1 181 records...
Minimum record length: 10 bytes
Maximum record length: 132 bytes
**** FILE HEADER ****
MWD .001
1024
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------------
WDFN 15-45BPB1 5.xtf
LCC 150
CN BP (Alaska) Exploration Inc.
WN 15-45BPB1
APIN
FN Prudhoe Bay Unit
COUN North Slope
STAT Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
Data presented here is final and has been depth adjusted to 15-45B
per Roger Furley with BP Alaska. Resistivity data has also been clipped
at 2000
*** INFORMATION TABLE: CIFO
MNEM
----- CHAN DIMT
---------
- CNAM ODEP
GR --
------
GR ------------
GRAX -----------------
0.0
ROP ROP ROPA 0.0
RAD RAD RACLX 0.0
RAS RAS RACHX 0.0
RPD RPD RPCLX 0.0
RPS RPS RPCHX 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logging direction is down (value= 255)
Optical Log 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:
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units
1 GR MWD 68 1 AAPI
2 ROP MWD 68 1 F/HR
3 RAD MWD 68 1 OHMM
4 RAS MWD 68 1 OHMM
5 RPD MWD 68 1 OHMM
6 RPS MWD 68 1 OHMM
Total Data Records: 58
1
Size Length
4 4
4 4
4 4
4 4
4 4
4 4
24
Tape File Start Depth = 9243.000000
Tape File End Depth = 10270.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2 71 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** FILE HEADER ****
MWD .002
1024
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN 15-45BPB1.xtf
LCC 150
CN BP (Alaska) Exploration
WN 15-45BPB1
APIN
FN Prudhoe Bay Unit
COUN North Slope
STAT Alaska
CJ
•
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
This file contains the raw-unedited field data.
*** INFORMATION TABLE: LIFO
MNEM CHAN DIMT CNAM ODEP
GR GR GRAX 0.0
ROP ROP ROPA 0.0
RAD RAD RACLX 0.0
RAS RAS RACHX 0.0
RPD RPD RPCLX 0.0
RPS RPS RPCHX 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logging direction is down (value= 255)
Optical Log 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; 115
Tape File Start Depth = 9243.000000
Tape File End Depth = 10270.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3 128 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
C~
**** TAPE TRAILER ****
MWD
08/02/08
1809593
01
**** REEL TRAILER ****
MWD
08/04/24
BHI
O1
Tape Subfile: 4 2 records...
•
Minimum record length: 132 bytes
Maximum record length: 132 bytes
•
•
Tape Subfile 1 is type: LIS
Tape Subfile 2 is type: LIS
DEPTH GR ROP
RPD RPS
9243.0000 -999.2500 -999.250C
-999.2500 -999.2500
9243.5000 69.4398 -999.250C
-999.2500 -999.2500
9300.0000 34.4995 -999.250C
-999.2500 -999.2500
9400.0000 28.9148 0.7333
-999.2500 -999.2500
9500.0000 23.0335 30.8827
-999.2500 -999.2500
9600.0000 39.5397 81.8607
-999.2500 -999.2500
9700.0000 33.4114 67.8410
-999.2500 -999.2500
9800.0000 39.2899 133.1192
-999.2500 -999.2500
9900.0000 28.1768 105.3190
-999.2500 -999.2500
10000.0000 39.2140 45.6775
102.3721 83.8090
10100.0000 51.9107 54.6816
123.3447 95.0447
10200.0000 147.1213 56.1574
15.4150 13.1907
10270.0000 -999.2500 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 9243.000000
Tape File End Depth = 10270.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
•
RAD
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
2000.0000
2000.0000
37.6139
-999.2500
RAS
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
2000.0000
2000.0000
21.3289
-999.2500
•
Tape Subfile 3 is type: LIS
DEPTH GR ROP
RPD RPS
9243.0000 -999.2500 -999.2500
-999.2500 -999.2500
9243.2500 -999.2500 -999.2500
-999.2500 -999.2500
9300.0000 27.5000 -999.2500
-999.2500 -999.2500
9400.0000 34.5000 0.8000
-999.2500 -999.2500
9500.0000 19.6000 29.0000
-999.2500 -999.2500
9600.0000 25.6000 84.9000
-999.2500 -999.2500
9700.0000 28.5000 33.1000
-999.2500 -999.2500
9800.0000 37.4000 133.2000
-999.2500 -999.2500
9900.0000 31.3000 102.5000
-999.2500 -999.2500
10000.0000 33.8000 46.7000
100.1090 83.2810
10100.0000 52.6000 52.6000
125.4940 99.3280
10200.0000 98.0000 37.6000
15.7160 13.4970
10270.0000 -999.2500 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 9243.000000
Tape File End Depth = 10270.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
•
RAD
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
2179.3999
2179.3999
36.9500
-999.2500
RAS
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
6064.5400
6064.5400
21.7470
-999.2500
Tape Subfile 4 is type: LIS
l
**** REEL HEADER ****
MWD
08/04/22
BHI
O1
LIS Customer Format Tape
**** TAPE HEADER ****
MWD
08/02/12
1809593
O1
3.0" CTK
*** LIS COMMENT RECORD ***
!!!!!~!!!!!!!!!!!!! Remark File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
Version Information
VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20
WRAP. N0: One line per frame
Well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 9243.0000: Starting Depth
STOP.FT 12096.0000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent Value
COMP. COMPANY: BP (Alaska)Exploration, Inc.
WELL. WELL: 15-45B
FLD FIELD: Prudhoe Bay Unit
LOC LOCATION: 70 deg 17' 56.099"N 148 deg 34' 28.002"W
CNTY. COUNTY: North Slope
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 3.0" CTK
DATE. LOG DATE: 12-Feb-2008
API API NUMBER: 500292267102
Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
SECT. 22
TOWN.N T11N
RANG. R14E
PDAT. MSL
EPD .F 0
LMF DF
FAPD.F 68.6
DMF DF
EKB .F 0
EDF .F 68.6
EGL .F 0
CASE.F N/A .
OS1 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.
~0'~-- Iii ~ ~~ ~O~
C~
(2) All depths are Bit Depths unless otherwise noted.
(3) All True Vertical Depths (TVD) are Subsea corrected.
(4) All Formation Evaluation data is realtime data.
(5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the
Advantage
surface system to log 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 and
Ultra Slim Resistivity Sub.
(7) Data presented here is final and has been depth adjusted to PDCL
(Primary
Depth Control Log provided by Schlumberger GR CNL dated 28 Feb 2008
per Roger Furley with BP Alaska.
(8) The sidetrack was drilled from 15-45 through a milled window in 4
1/2 inch liner.
Top of window 9398 ft.MD (8351 ft.TVDSS)
Bottom of window 9404 ft.MD (8357 ft.TVDSS)
(9) Tied to 15-45 at 9381 ft.MD (8335 ft. TVDSS)
(10) Resistivity data is MAD Pass data acquired up to 80 hours after
drilling. Drilled resistivity data was disgarded and
replaced with the MAD Pass data per the wellsite geologist.
(11) The interval from 12054 feet to 12096 feet MD (8754 feet to 8756
feet TVDSS) was not logged due to sensor to
but offset.
MNEMONICS:
GRAX -> Gamma Ray [MWD] (MWD-API units)
ROPA -> Rate of Penetration 3.0 Avg (ft/hour)
RACLX -> Compensated Resistivity Borehole Corrected(LS)(AT)
(400kHz),Ohm-m
RACHX -> Compensated Resistivity Borehole Corrected (LS)(AT)
(2MHz),Ohm-m
RPCLX -> Compensated Resistivity Borehole Corrected (LS)(PD)
(400kHz),Ohm-m
RPCHX -> Compensated Resistivity Borehole Corrected (LS)(PD)
(2MHz),Ohm-m
TVD -> Subsea True Vertical Depth
CURVE SHIFT DATA
BASELINE, MEASURED, DISPLACEMENT
9247.19, 9246.15, ! -1.03711
9249.78, 9251.03, ! 1.24414
9252.06, 9253.1, ! 1.03711
9254.76, 9255.8, ! 1.03613
9256.83, 9257.87, ! 1.03711
9260.56, 9260.36, ! -0.207031
9262.64, 9263.88, ! 1.24414
9263.88, 9265.12, ! 1.24316
9268.86, 9270.1, ! 1.24414
9273.21, 9271.96, ! -1.24414
9274.66, 9274.87, ! 0.207031
9280.05, 9280.67, ! 0.62207
9282.54, 9283.57, ! 1.03613
9289.17, 9290.21, ! 1.03613
9291.04, 9292.28, ! 1.24414
9292.69, 9293.94, ! 1.24414
9294.77, 9295.6, ! 0.829102
9297.56, 9299.01, ! 1.4502
9304.4, 9306.48, ! 2.07324
9308.96, 9310, ! 1.03711
9406.1, 9407.76, ! 1.6582
9407.34, 9409.21, ! 1.86621
9408.59, 9410.45, ! 1.86523
9410.25, 9411.91, ! 1.6582
9416.05, 9417.92, ! 1.86523
9418.33, 9419.99, ! 1.6582
C~
9420.2, 9421.65,
9422.06, 9423.93,
9423.51, 9425.38,
9430.77, 9432.63,
9435.74, 9437.82,
9442.58, 9444.04,
9447.97, 9499.01,
9463.15, 9464.39,
9557.19, 9559.05,
9561.75, 9563.41,
9568.38, 9569.42,
9572.94, 9572.94,
9579.16, 9580.4,
9580.4, 9583.1,
9583.31, 9585.38,
9586.83, 9588.9,
9589.32, 9591.18,
9593.05, 9595.12,
9598.02, 9599.68,
9654.6, 9657.09,
9682.58, 9685.-07,
9688.33, 9692.48,
9695.59, 9700.15,
9702.94, 9704.19,
9704.6, 9705.64,
9712.06, 9712.48,
9716.21, 9718.28,
9724.09, 9725.74,
9728.44, 9729.06,
9746.05, 9746.88,
9762.43, 9762.43,
9773.21, 9774.45,
9832.89, 9833.1,
9951.03, 9952.68,
9960.56, 9962.22,
9969.48, 9971.34,
10006.5, 10007.8,
10012.5, 10014.2,
10050.5, 10051,3,
10054.4, 10053,8,
10058.3, 10058,3,
10065.6, 10066,
10077, 10076.6,
10095, 10095.2,
10103.3, 10103.3,
10107.8, 10107,6,
10112, 10111.5,
10117.1, 10117,4,
10122.1, 10122.1,
10129.8, 10130.4,
10138.7, 10138.9,
10143.5, 10144.7,
10145.5, 10146.6,
10150.5, 10151.5,
10184.2, 10183.8,
10201.6, 10201,
10281.6, 10281.2,
10289.1, 10283.9,
10288.4, 10288.4,
10292.8, 10292,
10299.8, 10299.4,
10303.2, 10303,
10309.8, 10311,
10314, 10315.6,
10321.9, 10323.7,
10326, 10327.2,
10334.3, 10336,
1.45117
1.86621
1.86621
1.86523
2.07324
1.45117
1.03711
1.24316
1.86523
1.6582
1.03613
0
1.24316
2.69531
2.07324
2.07227
1.86523
2.07324
1.6582
2.4873
2.48828
4.14551
4.56055
1.24914
1.03613
0.415039
2.07324
1.6582
0.62207
0.829102
0
1.24414
0.207031
1.6582
1.6582
1.86621
1.24414
1.6582
0.829102
-0.621094
0
0.415039
-0.415039
0.207031
0
-0.207031
-0.414062
0.208008
0
0.62207
0.207031
1.24414
1.03613
1.03613
-0.414062
-0.62207
-0.415039
-0.207031
0
-0.830078
-0.415039
-0.207031
1.24316
1.6582
1.86621
1.24316
1.65918
•
•
10341.1, 10340.5,
10343.6, 10345.1,
10368.9, 10370.6,
10373.3, 10374.1,
10377.2, 10378.4,
10380.3, 10380.9,
10385.1, 10386.5,
10390.9, 10390.9,
10396.7, 10396.1,
10399.2, 10400,
10482.5, 10483.9,
10487.9, 10490.4,
10499.9, 10503,
10513.8, 10513,
10618.6, 10621.3,
10622.9, 10625,
10626.3, 10628.3,
10628.5, 10630.6,
10631.4, 10632.7,
10633.1, 10635.2,
10635.4, 10637.2,
10653, 10654.2,
10655.7, 10657.4,
10660.3, 10662.1,
10675.8, 10676.3,
10680.6, 10680.2,
10682.9, 10683.1,
10688.3, 10689.9,
10706.1, 10706.1,
10756.2, 10759.9,
10810.6, 10808.7,
10832.9, 10834.8,
10843.3, 10846,
10847.2, 10850.3,
10859, 10863.1,
10872.6, 10873.5,
10876.2, 10879.1,
10879.7, 10884,
10884.7, 10888.2,
10898.5, 10902.1,
10911.4, 10914.9,
10917.7, 10921.2,
10921.4, 10925.3,
10927.8, 10932.2,
10932.8, 10935.5,
10942.3, 10945.2,
10952.9, 10954.6,
10960.4, 10962.6,
10969.9, 10974.2,
10978.2, 10981.3,
10979.8, 10983.4,
10986.7, 10992.3,
10990.6, 10997.5,
10996.6, 11001.2,
10999.7, 11003,
11003, 11006.4,
11077.2, 11079.7,
11081.1, 11083,
11121, 11121.9,
11164.3, 11164.1,
11169.1, 11168.3,
11221.7, 11222.4,
11225.1, 11228.6,
11230, 11232.5,
11234.6, 11236.5,
11243.5, 11244.5,
11273.3, 11274.8,
-0.621094
1.45117
1.65918
0.829102
1.24414
0.62207
1.4502
0
-0.621094
0.829102
1.45117
2.4873
3.10938
-0.829102
2.69434
2.07324
2.07324
2.07324
1.24316
2.07227
1.86523
1.24316
1.65918
1.86621
0.415039
-0.415039
0.207031
1.6582
0
3.73145
-1.86621
1.86523
2.69531
3.10938
4.14648
0.829102
2.90234
4.35352
3.52441
3.52344
3.52344
3.52441
3.93848
4.35254
2.69531
2.90137
1.6582
2.28027
4.35254
3.10938
3.52344
5.59766
6.83984
4.56055
3.31738
3.31641
2.4873
1.86621
0.829102
-0.208008
-0.829102
0.62207
3.52344
2.4873
1.86523
1.03711
1.45117
~ ~
11305.8, 11307.3, ! 1.45117
11416.9, 11417.5, ! 0.62207
11422.5, 11423.6, ! 1.03613
11431.6, 11434.7, ! 3.10938
11449.2, 11451.7, ! .2.4873
11457.9, 11460.8, ! 2.90234
11461.8, 11464.3, ! 2.48828
11463.3, 11466, ! 2.69531
11529.1, 11527.5, ! -1.6582
11536, 11535.6, ! -0.415039
11539.5, 11537.9, ! -1.6582
11543.2, 11541.4, ! -1.86523
11547, 11547.2, ! 0.207031
11554.9, 11553.8, ! -1.03613
11578.5, 11579.1, ! 0.62207
11589.1, 11587.6, ! -1.45117
11595.9, 11593.9, ! -2.07324
11611.5, 11609.8, ! -1.6582
11614.8, 11613.1, ! -1.6582
11806.1, 11805.3, ! -0.829102
11823.1, 11821.6, ! -1.45117
11876.5, 11878.5, ! 2.07324
11903.3, 11903.7, ! 0.415039
11911, 11912.6, ! 1.6582
11916.6, 11921.5, ! 4.97461
11919.3, 11924.2, ! 4.97559
11931.9, 11933.8, ! 1.86523
EOZ
END
! BASE CURVE: GROH, OFFSET CURVE: GRAX
Tape Subfile: 1 263 records...
Minimum record length: 10 bytes
Maximum record length: 132 bytes
**** FILE HEADER ****
MWD .001
1024
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------------
WDFN 15-45B 5.xtf
LCC 150
CN BP (Alaska) Exploration Inc.
WN 15-45B
APIN
FN Prudhoe Bay Unit
COUN North Slope
STAT Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
Data presented here is final and has been depth adjusted to a Primary
Depth Cont
Schlumberger GR CNL dated 28 Feb 2008 per Roger Furley with BP Alaska.
Resistivi
data acquired up to 80 hours after drilling. Drilled resistivity data was
disgar
with the MAD Pass data per the wellsite geologist. Resistivity data has
also bee
*** INFORMATION TABLE: LIFO
MNEM
----- CHAN DIMT
------------------ CNAM
---------- ODEP
GR
GR --
GRAX -----------------
0.0
ROP ROP ROPA 0.0
RAD RAD RACLX 0.0
RAS RAS RACHX 0.0
RPD RPD RPCLX 0.0
RPS RPS RPCHX 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logging direction is down (value= 255)
Optical Log 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:
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units
1 GR MWD 68 1 AAPI
2 ROP MWD 68 1 F/HR
3 RAD MWD 68 1 OHMM
4 RAS MWD 68 1 OHMM
5 RPD MWD 68 1 OHMM
6 RPS MWD 68 1 OHMM
1
Size Length
4 4
4 4
4 4
4 4
4 4
4 4
24
Total Data Records: 159
Tape File Start Depth = 9243.000000
Tape File End Depth = 12096.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2 172 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** FILE HEADER ****
• ~
MWD .002
1024
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN 15-45B.xtf
LCC 150
CN BP (Alaska) Exploration
WN 15-45B
APIN
FN Prudhoe Bay Unit
COUN North Slope
STAT Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!~~!!!!!!!! Remark File Version 1.000
This file contains the raw-unedited field data.
*** INFORMATION TABLE: CIFO
MNEM
----- CHAN DIMT
------------------ CNAM
---------- ODEP
GR
GR --
GRAX -----------------
0.0
ROP ROP ROPA 0.0
RAD RAD RACLX 0.0
RAS RAS RACHX 0.0
RPD RPD RPCLX 0.0
RPS RPS RPCHX 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logging direction is down (value= 255)
Optical Log 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
Total Data Records: 317
Tape File Start Depth = 9244.000000
Tape File End Depth = 12093.750000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3 330 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** TAPE TRAILER ****
MWD
08/02/12
1809593
01
**** REEL TRAILER ****
MWD
08/04/22
BHI
01
Tape Subfile: 4 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
29
• •
Tape Subfile 1 is type: LIS
t A
Tape Subfile 2 is type: LIS
DEPTH GR ROP RAD RAS
RPD RPS
9243.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9243.5000 69.2241 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9300.0000 34.9851 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9400.0000 29.0569 0.6997 -999.2500 -999.2500
1.9610 -999.2500
9500.0000 23.2231 29.3737 -999.2500 -999.2500
146.2752 217.8976
9600.0000 39.5174 81.8558 -999.2500 -999.2500
108.1041 89.8582
9700.0000 40.7580 69.0955 156.3116 39.2117
23.4102 21.4514
9800.0000 38.8840 132.7423 -999.2500 -999.2500
103.9201 84.2410
9900.0000 27.9611 105.5489 -999.2500 -999.2500
79.7854 63.1699
10000.0000 39.2068 45.6805 -999.2500 -999.2500
74.5094 62.0940
10100.0000 78.0014 57.5163 -999.2500 -999.2500
86.3046 66.4668
10200.0000 58.4620 90.1584 -999.2500 -999.2500
108.9211 92.3174
10300.0000 76.5785 69.9061 -999.2500 -999.2500
108.3683 80.2373
10400.0000 88.8180 78.8797 -999.2500 -999.2500
82.9959 57.0630
10500.0000 100.7274 68.1863 -999.2500 98.2441
47.3143 47.0798
10600.0000 82.3544 80.4172 47.9420 74.4015
40.3137 39.0384
10700.0000 55.7313 60.2179 -999.2500 -999.2500
88.7354 71.8776
10800.0000 80.1517 38.0396 -999.2500 -999.2500
82.1347 63.8686
10900.0000 33.6338 44.3780 -999.2500 -999.2500
122.5061 91.5565
11000.0000 142.7131 83.7032 -999.2500 -999.2500
159.9851 161.1809
11100.0000 72.9003 141.9975 -999.2500 -999.2500
212.7329 169.1213
11200.0000 35.6158 159.8481
174.1794 148.3505
11300.0000 47.5000 153.9000
182.8840 136.1220
11400.0000 59.6278 105.3722
213.9295 147.5071
11500.0000 53.0415 82.0185
106.2106 85.3036
11600.0000 63.6329 48.5770
70.2808 59.0703
11700.0000 91.5689 72.9727
78.6514 68.5679
11800.0000 95.6388 129.9194
70.7867 67.6268
11900.0000 70.0836 117.8043
61.4570 54.1513
12000.0000 90.0580 128.4420
99.9110 86.9011
12096.0000 -999.2500 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 9243.000000
Tape File End Depth = 12096.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
•
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
-999.2500
469.4963
133.3086
265.0947
-999.2500
-999.2500
• •
Tape Subfile 3 is type: LIS
DEPTH GR ROP RAD RAS
RPD RPS
9244.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9244.2500 64.1000 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9300.0000 27.5000 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
9400.0000 34.5000 0.8000 2179.3999 858.6630
2.3040 47151.5234
9500.0000 19.6000 29.0000 2179.3999 6064.5400
129.5170 321.2750
9600.0000 25.6000 84.9000 2179.3999 6064.5400
125.0450 104.4670
9700.0000 28.5000 33.1000 1027.2458 26.5070
17.7080 12.7760
9800.0000 37.4000 133.2000 2179.3999 6064.5400
102.9980 84.2410
9900.0000 31.3000 102.5000 2179.3999 5514.8281
81.8040 64.5960
10000.0000 33.8000 46.7000 2179.3999 6064.5400
69.3320 57.1190
10100.0000 79.6000 57.5000 2179.3999 6064.5400
86.1260 66.3050
10200.0000 43.5000 109.4000 2179.3999 6064.5400
114.9380 97.7580
10300.0000 80.9000 63.9000 2179.3999 6064.5400
107.5040 79.9560
10400.0000 80.5000 78.1000 2179.3999 6064.5400
82.8240 56.9920
10500.0000 83.3000 84.6000 2179.3999 97.5170
49.7510 49.5710
10600.0000 87.7000 81.8000 57.7910 71.4780
39.4400 38.4660
10700.0000 53.5000 62.1000 2179.3999 6064.5400
86.6480 68.9560
10800.0000 82.6000 37.9000 2179.3999 6064.5400
83.3790 64.8990
10900.0000 45.6000 42.5000 2179.3999 6064.5400
102.0520 82.0720
11000.0000 120.6000 120.5000 .2179.3999 6064.5400
142.4290 101.6160
11100.0000 80.5000 140.6000 2179.3999 6064.5400
216.8010 173.2730
11200.0000 35.6000 159.5000
173.7810 148.1730
11300.0000 55.6000 153.0000
182.1670 138.6140
11400.0000 57.3000 107.7000
211.1330 150.5380
11500.0000 53.3000 82.6000
106.5130 85.4050
11600.0000 59.0000 43.1000
65.6950 56.3110
11700.0000 91.8000 98.4000
78.8800 69.0810
11800.0000 97.1000 130.5000
70.6680 67.8550
11900.0000 64.3000 98.1000
61.4570 54.8790
12000.0000 88.0000 124.6000
96.9560 84.4720
12093.7500 -999.2500 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 9244.000000
Tape File End Depth = 12093.750000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
2179.3999
2179.3999
2179.3999
2179.3999
2179.3999
2179.3999
2179.3999
2179.3999
2179.3999
-999.2500
6064.5400
6064.5400
6064.5400
6064.5400
6064.5400
492.0020
134.5400
281.4350
4577.6748
-999.2500
Tape Subfile 4 is type: LIS
