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206-085
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 15 2020 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑AOGUC Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Acid Stimulation 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to DNI Number 206-085 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service❑ 6API Number: 50-029-21700-61-00 7 Property Designation (Lease Number): ADL 028320 B. Well Name and Number: PBU L5-16AL2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, LISBURNE OIL 11. Present Well Condition Summary: Total Depth: measured 11500 feet Plugs measured None feet true vertical 8646 feet Junk measured None feet Effective Depth: measured 11500 feet Packer measured 8715 feet true vertical 8846 feet Packer true vertical 8521 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 42-122 42-122 1490 470 Surface 3967 10-3/4" 41-4006 41-4000 5210 2480 Intermediate Production 9059 7-5/8" 38-8936 38-8725 7900 6560 Liner 133 4-1/2" 8803-8936 8602-8725 8430 7500 Perforation Depth: Measured depth: 8910- 11500 feet True vertical depth: 8701-8846 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 36-8802 36 - B601 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 8715 8521 true vertical depth) 4-1/2" HES WellStar TRSSSV 2177 2177 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8910'- 11 500'(L5-16AL2) Treatment descriptions including volumes used and final pressure: RIH with Stimulation Packer BHA. Sting in to ML KB Packer and set. Pump ETCHNDA acid stage into motherbore (1-5-16A). Open circ -sub and then pump ETCHNDA acid stage into 1-5-16AL1. Pump Stimulation #3 down the backside into L5-16AL2. Well was on a vac during the entire stimulation. Acid Volumes Pumped: 111 bbls VDA and 259 bbls ETCH. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Lateral 0 632 Subsequent to operation: Lateral 2435 779 14.Attachments(reguired per 20 MG 25.0/0.25.071, s 25.263) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Sauve, Mark A Contact Name: Sauve, Mark A Authorized Title: GPMA/Lisburne Lead PE Contact Email: Mark.Sauve@bp.com Authorized Signature: Date. 1-15-2,C) Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 •-+rf[. . J+ .Ci ROMS n' JAN 16 2020 Submit Original Only 'of 0/ 40 w - ------ ---- ***WELL S/I ON ARRIVAL*** (Acid) TAGGED TRSV AT 2,177' MD WITH 3.84" NO-GO CENT RAN FLAPPER CHECKER TO TRSV AT 2,177' MD RAN 3.50" LIB TO TOP OF KB PKR AT 8,969' MD TAG BOTTOM AT 9,106' SLM WITH 1.90" CENT & 1.50" S. BAILER 12/8/2019 ***CONT WSR ON 12/9/19*** ***CONT WSR FROM 12/8/19*** (acid) SWCP 4521 RIG DOWN 12/9/2019 ***WELL S/I ON DEPARTURE*** CTU#8 1.75" CT. Job Scope: Acid Stimulation MIRU CTU. MU & RIH w/ Baker PISS ( Pressure Indicating Seal Sub) BHA. Bullhead well w/ 1 % KCL & diesel. Well was still dead after pumping 248 bbls of diesel. Attempt to sting into the ML KB Pkr at 8940' ctm. Did not see any circ pressure changes while attempting to sting in. Pooh pumping diesel down backside. Redress seal sub and reconfigure BHA. Re -run Baker PISS (pressure indicating seal sub). RIH and stab into ML KB Packer at 8958' ctm. Able to sting in and ensure seal integrity, seat shifted at 2400 psi. Pump diesel down the backside while stung in and unable to maintain fluid level at surface at rates below 3.0 bpm. Unsting and POOH. Make up Stimulation Packer BHA and RIH. 12/22/2019 ...Continued on WSR 12-23-19... CTU #8 - 1.75" Coil, 0.156" wt ***Cont. from WSR 12-22-19*** Job Objective: Acid Stimulation RIH with Stimulation Packer BHA. Sting in to ML KB Packer and set. Pump ETCHNDA acid stage into motherbore. Open circ -sub and then pump ETCHNDA acid stage into L1. Pump Stimulation #3 down the backside into L2. Well was on a vac during the entire stimulation. Was unable to underbalance the well with diesel, the well remained on a Vac. Release Baker Pkr. Pooh. Recovered ball. Lost 1 element. Freeze Protect Tbg w/ 42.5 bbls diesel. 12/23/2019 ***Job Com lete*** I TREE= 4-1/6'CNV WELLHEAD = CNV ACTUATOR= CIWSH3000 KB. ELEV = fi0' WE—E == NA KOP= 3800' Max Angle = 99' @ 9326' Datum MD= 9082' Datum TVD= 89001SS 110-3/4" CSG, 45.5#, K-55 BUTT XO TO L-80 VAM CONDUCTOR 91.5#, H-40, D = 19.124' 80' 1 3/4" CSG, 45.5#, L-80 VAM, D = 9.953• 4008' Minimum ID = 2.010" @ 8973' 2-7/8" XN NIPPLE (KB PKR ASSY) 1-1/2' TBG, 12.6#, L-80 IBT-M, I—j 8792' .0152 bpf, D = 3.958" TOP OF 4-1/2•LNR 8803' PEJORATION SUMMARY RE= LOG: ANGLE AT TOP PER 23' @ 8876' Note: Refer to P7oducbm DB for historical pert data SIZE SPF PTTHiVAL Opn/Sgz I SHOT I SOZ 2-1/2" 6 8876 -8900 O 07/17/18 4708 PKR TOP, D= 12-7/8"PKRTAL,D=2.441" I 5 SAFETY NOTES: WELL ANGLE> 70° @ 9206'. 6 ..=CAT I SSSV 1-12S (PPM) 250 L 1 AL2 ' BKR WHIPSTOCK (06/14/06) 11 9097 ELM RA PP TAGS (TVND) (06/14/06) 9109' . 14-12" SCAB LNR 12.6#, L-80 IBT-M, ID= 3.958" I 33. D = 6.765" I 9119' I D = 3.813" C P' R I F MANn RFI R STI MD I ND I DEVI TYPE I VLV I LATCH I PORT DATE 5 2781 2780 2 KB G2 DOME BK 16 1229/19 4 4708 4694 4 KBG2 SO BK 20 1229/19 3 6387 6371 9 KBG2 DMY BK 0 05/17/09 2 7603 7509 26 KBG2 DMY BK 0 05/17/09 1 8616 8430 24 KBG2 DMY BK 0 05/17!09 HES X NP, ID= 3.813- X 4-12 BKR S-3 PKR HES X NP, ID = 3.813" 879—J4-1/2" WLEG, D = 3.958" 8803' 7-518"X5-12"ZXP LTPw/11.5'PBR D=4.90• 8820' S" BOT HMO LNR HGR D = 4.810" 8827' 5-1/2" X 4-12• XO, D = 3.958" L2 (OPEN HOLE COMPLETION) FTDTE 11501 3.80" MILLOUT WINDOW (LS16A-L2) 8936' - 8947' L1 (OPEN HOLE COMPLE 3.80" MILLOUT WINDOW (L6 -1610-L7) 8961' -8974- L5 -16A 961' -8974' L5 -16A (OPEN HOLE COMP 3.80" MILLOUT WINDOW (LS -16A) 9097'-9109' LSBURE UNIT WELL: L5 -16A PERMIT No: 2060830,(40),(50) APINo:50-029-21700-01,(60),(61) SEC 1, T11 N, R1 5E 1788' FSL 8 19' FAL DATE REV BY COMMENTS DATE REV BY COMMENTS 03117187 RWN 41 ORIGSUSPENDED 09/19/17 JMG1JMD PULLED STRADDLE PKR 9/16117) 06/03187 NORDIC ORIGINAL COMPLETION 05107118 KP/JMD TREE CIO (05/02118) 06101106 NORDD2 RWO 07/17/18 MS/JMD PERFS(07117/18) 09101106 NORDIC 2 MULTI- LAT (1-5-16A, /LL7 8 AL2) 0110220 JPK/JMD GLV C/O (1229/19) 12MMS RRD/PJC SETSTRADDLEPKR 1123/0B BP Exploration (Alaska) 06/01/09 SEW/TU-I GLV C/O (05M 7109) STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI T 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Remove Patch II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-085 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21700-61-00 7. Property Designation(Lease Number): ADL 028320 8. Well Name and Number: PBU L5-16AL2 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 11500 feet Plugs measured None feet RECEIVED true vertical 8846 feet Junkmeasured None feet Effective Depth: measured_ 11500 feet Packer measured 8715 feet o C T 1 72017 true vertical 8846 feet Packer true vertical 8521 feet ACC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 42-122 42-122 1490 470 Surface 3967 10-3/4" 41 -4008 41 -4000 5210 2480 Intermediate Production 9059 7-5/8" 38-8936 38-8725 7900 6560 Liner 133 4-1/2" 8803-8936 8602-8725 8430 7500 Perforation Depth: Measured depth: 8910-11500 feet SCANNED DEC 2 62017, True vertical depth: 8701-8846 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36-8802 36-8601 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8715 8521 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory ❑ Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 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 Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: GPMA/Lisburne L d PE Contact Email: Mark.SauveCD_bp.com Authorized Signature: /lA �-. Date: D—/,--79 Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 1/71- j 7/ 7/) RBD IVIS j _- OCT 2 5 2 617 . Submit Original Only 100 • • Daily Report of Well Operations L5-16A / AL2 ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL***(Profile Mod) DRIFT W/3.805" G. RING &TAG Straddle packer @ 8902' SLM JAR ON 45 KB STRADDLE PATCH FOR 2 HOURS W/0.125"WIRE TO 1800 LB 9/15/2017 ***CONT. ON 09/16/17 WSR*** ***CONT. FROM 09/15/17 WSR***(Profile Mod) PULL 45 KB STRADDLE PATCH FROM 8902' SLM (one rubber element not recovered). RUN 4-1/2" BRUSH & 3 PRONG 3.50" WIRE GRAB, STOP @ 8912' SLM (nothing recovered) 9/16/2017 ***WELL TURNED OVER TO DSO*** TREE= 4-1t6"FMC 1+Nt3LHEAD= ow 0 1_5-1 6A, SiY SST H2S LL NOTES: WELL A) 0*70°@ 9206'. ACTS„LATOR=- AXELSON KB.ELEV= 60' AL1 & AL2 BF.ELEV= NA KOP= 3800' Max Angle= 99°@ 9326' I Datum MD= 9082' Datum NO= 8900'SS 2177' —14-1/2"FES WELLSTARTRSSSV,D=3.813" 10-3/4"CSG,45.5#,K-55 BUTT --I 65' XO TO L-80 VAM GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 20 CONDUCTOR 91.5#,FF40,D=19.124" — 80` 1 115 2781'2780 2 KBG-2 DBK 0 05/17/09 10-3/4"CSG,45.5#,L-80 VAM,D=9.953" J 4((t06' DW4 4708 4694 4 KBG-2 ow BK 0 05/17/09 I 3 6387 6371 9 KBG-2 OM1' BK 0 05/17/09 2 7603 7509 26 KBG-2 OMY BK 0 05/17/09 Minimum ID =2.010" 8973' 1 8616 8430 24 KBG-2 DW BK 0 05/17/09 2-7/8" XN NIPPLE (KB PKR ASSY) I I 8684' —j4-1/2"FES XNr;D=3.813" ZI . . 8704' H7-5/8"X 4-1/2 BKR S-3 PKR,ID=3.870" ' ' 8728` H 4-1/2"FES X NP,D=3.813" 4-1/2"TBG,12.6#,L-80 BT-M, H 8792' _0152 bpf,D=3.958" TOP OF 4-1/2"LN2 — 8803' 8792' �4 1/2"WLEG,D=3.958' ��8803' —17-5/8"X 5-1/2"ZXP LTPw/11.5'EBR,D=4.90" *41 �� 8820' H 5"BOT FNAC LNR HGR,ID=4.810" i♦. --8827' 5-1/2"X 4-1/2"XO,D=3.958" • ♦♦i ♦♦i ♦♦i i♦• ' \ ♦�i L2(OPEN HOLE COMPLETION) 1 ♦♦i, /\ i♦i i♦i TD -1 11500' ♦♦i •i♦♦' ♦♦i •1,4,4 ♦•i %♦4 ML 3.80" LOUTIN WDOW(L5-16A-L2) 8936'-8947' ♦♦• ♦♦i ♦♦i •�• Li (OPEN HOLE COMPLETION) ♦. LOWER KB PKR TOP,D=3.00" H 8969' ♦♦• ►♦♦♦� A w ►'4'♦♦i' 9757' 2-7/8"XN NP,ID •=2.010" — 8973' ♦�� i♦�♦i ♦4• ►♦♦• 2-7/8"PKR TAIL,13=2.441" — 8978' '♦� ►♦♦4 3.80"MLLOUT VNNDOW(L5-16A-L1) 8961'-8974' ♦♦ ♦4 •• ••• ♦�♦ � 4-1/2"BKR WHPSTOCK(06/14/06) H 9097' ELM �� •. RA PF TAGS(TWO)(06/14/06) -[ 9106' •% L5-16A(OPEN HOLE COMPLETION) ...>... . ..•.4 4.4 TD — 10875' PBTD ---[. 9119` %•, l• 4-1/2"SCAB LNR 12.6#,L-80 BT--M,D=3.958" — 9206' •♦♦.�����.w.!.i*Q4 3.80"MLLOUT WMJDOW(15-18A) 909T-9109' ♦♦♦♦♦♦♦♦♦♦♦♦♦♦♦4 ♦♦♦♦♦♦♦♦♦♦♦♦♦♦♦♦• 7-5/8"CSG,33.7#,L-80 NSCCBUTT,13=6.765" --1 9559` ��i�i.i.i�i�i.i.i.4I DATE REV BY COMMENTS DATE REV BY (X)? E TS LISBURE INT 03/17/87 RWN41 ORIG SUSP 09/20/08 SWC/SV RILL FISH @ 2177(09/06/08) WELL: L5-16A 06103/87 NORDIC 1 ORIGINAL COMPLETION 12/04/08 RRO/PJC SET STRADDLE PKR(11/23/08) FERAL Na: 2060830,(40),(50) 06/01/06 NORDIC 2 RWO 06/01/09 SEW/TLH GLV C/O(05/17/09) AR No:50-029-21700-01,(60),(61) 09/01/06 NORDIC 2 MULTI-LAT(L5-16A,AL1&AL2) 09/19/17 JMG/JMD RULED STRADDLE PKR(9/16/17) SEC 1,T11N,1215E 1788'FSL&19'FWL 05/08/08 KSB/PJC DRLG DRAFT CORRECTIONS 06/26/08 BSE/PJC RILL KB GLIDE SHOE/FISH(06/22) BP Exploration(Alaska) bo Date 20-MAY-2015 Transmittal Number: 93426 BPXA WELL DATA TRANSMITTAL RECEIVED Enclosed are the materials listed below. MAY 2 0 2015 (BPXA LOG DATA) AOGCC If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 04-21, 04-22, 04-33, C-01, C-31, L1-09, L2-03, L3-15, L3-31, L4-30, L5-01, L5-15, L5-16A, L5-16AL1, L5-16AL2, L5-31, L5-33, L5-36 04-21 185-212 261yy• 04-22 185-233 02545' 04-33 186-035 ,2 5-441(9- Please Sign and Return ne copy of this transmittal to; C-01 172-030 .25447- C-31 25447C-31 188-006 254q gancpdc@bp.con L1-09 185-001 254149• L2-03 185-247 25760- Doug 5}SODoug Dortch L3-15 185-266 )751-51 Petrotechnical Data Center SCANNED MAY 2 7 2015 L3-31 186-034 ,251.152 L4-30 188-101 25753. L5-01 189-009 2515`( Attn: State of Alaska - AOGCC L5-15 188-109 025155 Attn: Makana Bender L5-16A 206-083 25/5G,• 333 W. 7th Ave, Suite 100 L5-16A L1 206-084 25 Anchorage, Alaska 99501 5�- 5-16A L2 206-085 ZS-158' L5-31 190-130 25-tsci L5-33 189-047 2,e4(00.• L5-36 189-036 ;,5-7(P Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~d ~ - ~ ~~ Well History File Identifier Organizing (done> ^ Two-sided II I II'III II III II III ^ Rescan Needed III IIIIII II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ Q /s/ Project Proofing I II I III II III II I I II I BY: Maria Date: ! 0 l ~.,,,IO v lsl Scanning Preparation _~ x 30 = _~ + _~, =TOTAL PAGES l Q (Count does not include cover sheet) BY: _ Maria Date: `~~~, ~Og /s/ 11111111111111 II111 Production Scanning Stage 1 Page Count from Scanned File: ~~-~- (Count does include cover sheet) Page Count Matches Number in Scanni/n'g Preparation: l~ YES NO BY: Maria Date: `~1 ~ O~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: a~„~,~~~~ iiiumuuiuuii P P 10/6/2005 Well History File Cover Page.doc i ~ ~~ ~. ~~- y ~~ ~. r t ~; ,.; ~ ~Att ~~ ~ : ~ .. ~~ ;_ 4~ .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • Maunder, Thomas E (DOA) From; Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Thursday, January 29, 2009 10:13 AM To: Maunder, Thomas E (DOA) - Subject: Emailing: L5-16AL2.PDF Attachments: L5-16AL2.PDF ~..'r.l@... ~..C.A' L5-16AL2.PDF (37 KB) «L5 -16AL2 . PDF» The message is ready to be sent with the following file or link attachments: L5-16AL2.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. Page 1 of 1 Sc~MV~w.~ Q~b.~c~ `r. ~~ y Maunder, Thomas E (DOA) ,~-~'~ From: Maunder, Thomas E (DOA) '~~ ~Zsp`q~S ~" 1 ~ H~a Sent: Thursday, January 29, 2009 8:58 AM ~ ~ ~~~ To: 'Preble, Gary B (SAIC)' ~~ ~~~ ~~°'~ ~-'~ ~©~~~~~`^C Subject: L5-16A (206-083) and L5-16AL2 (206-085) ~'' pco ~c~ ~. Gary, You have submitted dua1404s for the work done to isolate LS-16AL2 in the LS-16A wellbore, however you included the procedure not the operations summary. Could you please send the ops summary? Email is fine. Tom Maunder, PE AOGCC Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 4:59 PM To: 'Preble, Gary 13 (SAIC)' Subject: L5-16A (206-083) Gary, Last one for today!! I briefly looked at the 404 submitted for placing the patch to isolate L5-16AL2 (206-085). Has a 404 for L5-16AL2 been submitted? It may be in the stack and 1 haven't gotten to it yet. Thanks in advance. Tom Maunder, PE AOGCC .\Y" STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMON ~r REPORT OF SUNDRY WELL OPERATIONS ~C~~~-~ JAS! ~ 4 ZOQ9 1. Operations Abandon ~ Repair Well ~ Plug Perforations Q , Stimulate ~ A~aSIcS~~il• ~8S Cony. C®mmissi Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~Inchorage Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 206-0850 3. Address: P.O. Box 196612 StratigraphlC ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21700-61-00~ 7. KB Elevation (ft): 9. Well Name and Number: 60 KB - L5-16AL2 - 8. Property Designation: 10. Field/Pool(s): , ADLO-028320 ~ PRUDHOE BAY Field/ LISBURNE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11500 ' feet Plugs (measured) None true vertical 8845.77 - feet Junk (measured) None Effective Depth measured 11500 - feet true vertical 8846 - feet Casing Length Size MD TVD Burst Collapse Conductor 120 20" 91.5# H-40 SURFACE - 120 SURFACE - 120 1490 470 Surface 4006 10-3/4" 45.5# L-80 SURFACE - 4006 SURFACE - 3998 5210 2480 Production 9559 7-5/8" 29.7# L-80 SURFACE - 9559 SURFACE - 8918 6890 4790 Liner 2072 4-1/2" SCAB L 12.6# L- 8803 - 9098 8602 - 8873 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 8792' 0 0 - Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" BKR S-3 8704' LOWER KB PKR 8969' 45 "KB" UPPER STRADDLE PKR 8905' 45 "KB" LOWER STRADDLE PKR 8925' 12. Stimulation or cement squeeze summary: ` 1`~_ "T1C~h I t l ~C"-00 t t d d h-~ `~ ~ "'E~ erva (measure n rea e ): ~ ~ s ~ f~ \ c~v~ ~o Po..iiTC..~ ~ w` ti~~c o~ 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: Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development C~i'- Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r ~ Gas ~ WAG ~ GINJ ~ WINJ '~ 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 ~ ~~ ,jQ,l~l i-~ Q LQQ~ Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 1/14/2009 E Form 10-404 Revis d 04/2006 ~ ~ ( ~ ~~ ~~~ Submit Original Only L5-16AL2 206-085 PERF ATTArHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L5-16AL2 9/1/06 OH 8,910. 11,500. 8,701.01 8,845.77 L5-16AL2 11/23/08 STC 8,904. 8,932. 8,695.46 8,721.38 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 L5-1bAL2 / ~.S- \ (o ~ ,T ~~yy~ DESCRIPTION OF WORK COMPLETED k~ ~a~ NRWO OPERATIONS EVENT SUMMARY 11/20/2008;*'*WELL SHUT-IN ON ARRIVAL**` INITIAL T/lAlOA: 2200/2200/0 PSI ;STANDBY FOR SWS CRANE TO RIG UP ELINE FOR JEWELRY LOG/PATCH ***CONTINUED 21-NOV-2408**` 11/21/2008?***CONTINUED FROM 20-NOV-2008*** INiTlAL T/IA/OA: 2200/2200/0 PS1 :RIG UP ELINE FOR JEWELRY LOG / PL LOG WITH X/Y CALIPER 8380-9050 FT, ;VERIFY L2 LATERAL DEPTH FROM 8910-8920FT. "JOB CONTINUES ON 22-NOV-2008"* 11/22/2008:***CONTINUED FROM 21-NOV-2008**` T/IA/OA: 2200/2200/0 PSI sMISRUN ON PATCH SETTING PASS DUE TO BAD fGNITER. REATTEMPT 'PATCH SET. ***JOB CONTINUES 23-NOV-2008*"` _ _._ _ _ .: 11/23/2008;`**CONTINUED FROM 22-NOV-2008*** ENITIAL T/IA/OA: 2200/2200/50 PSI `20' 3 70" BAKER PATCH SET ArRnc~ ~ ~ i n'r~oni ~A~i~-$g20.5 FT} FROM :8905-8925 FT. PATCH TOP 8905 FT, PATCH WLEG 8931.5 FT, MIN ID 2.313". :FINAL TI/I/O = 2100/2200/50 ***JOB COMPLETE"` _. _ - ___ FLUIDS PUMPED BBLS 1 diesel .5 MEOH WHILE POOH 1.5 Total • by To: C. Olsen / J. Bixby, GPB Wells Operations Supervisor October 17, 2008 From: Shane Wills, Wells Group Scheduler Justin Nash, Lisburne PE Subject: L5-16AL2: GSO AL2 Lateral Isolation IOR: 200 BOPD LSL05W L16-N Attached is a procedure to install a ~20' 4'/z" Baker Single Set Patch with a Sliding Sleeve across the upper lateral of the L5-16A. This job includes the following major step: Step Type Procedure 1 S Drift with Baker Dummy Patch to 8969' DD 2 E Run Gamma Ray CCL Correlation Log Set Baker 4-1/2" Baker Single Set Patch w/Sliding Sleeve • Current Status: • Last test: • Max Deviation: • BHP: • BHT: • Min. ID: • Last TD tag: • Last DH Ops: • Latest H2S Value Obiective• P -Cycle (no gas lift). 582 BOPD, 14 BWPD, 25,910 MCFD, GOR=44,480 (09/17/08) 99° at 9,326' MD 3,177 psi @ 8900'SS taken on 04/18/06 173 F @ 8900'SS taken on 04/18/06 3" open hole sections, XN profile @ 8,973' MD, ID= 2.010" 9095' SLM (09/06/2008). SL D&T, PDS Caliper (09/06/2008). 60 ppm on 1/7/07. Isolate the upper-most lateral by installing a retrievable Baker ~20' 4-1/2" Single Set Patch with a Sliding Sleeve and Tail Pipe Assembly with Elements at 8905' (upper) and 8925' (lower). The top of the lateral window is C~ 8910' and the bottom of the window is (~ 8920.5'. L5-16AL2 Lateral Isolation Pitch With Sliding Sleeve • Background Information: The L5-16 well was drilled and completed in July 1987 with 3-1/2" TBG in zones 6, 5, 4 and 1. After 19 years of production (1.53 mmbbls), various acid jobs and three cement squeezes, the well was sidetracked in June, 2006. The original 3-1/2" completion was pulled and a 4-1/2" tubing completion was run to 9,475' MD. A whipstock was then set at 9097' MD and the first of three multilaterals were drilled under-balanced with UBCTD. The well initially produced at high rates, although after one year the GOR started to increase. In August 2007 the well reached MGOR and had to be cycled. Since that time the well has been a sporadic cycle producer, but has struggled to produce with a GOR below 40,000, and be a full time producer. Real time inflow data obtained during the UBCTD drilling of the upper lateral showed that this lateral was responsible for the majority of the gas (see attached presentation for additional information). The intent is to shut-off the high gas producing lateral, making the well a competitive full time producer. A sliding sleeve will be incorporated into the. patch to allow the lateral to be produced without pulling the straddle. A tubing tail assembly with nipple reducer will allow the well to be secured with a TTP. A tubing Caliper is included which clearly snows the lateral window to be straddled. **NOTE** - PDS caliper is 2' shorter than the tubing tally. - PDS GR/CCL run on 5/31/2006 was revised on 9/19/2008 putting it on depth with the tubing tally. Electronic revised GR/CCL copies were emailed to the Wells Group Project Aide on 10/3/2008. - On 6/11/2008 SL pulled KB tray and packer for previous patch procedure and hung up in the TRSSSV. On 9/6/2008 KB tray and packer were fished out with no issues. Packer still retained all elements. (See Attached WSR's) Any questions concerning this program please contact: Justin Nash at 564-4752 (work), 522-0726 (home), 440-6782 (cell), or Jennifer Julian at (work) 564-5663, (cell) 240-8037, (home) 274-0929. CC: Well Files Sam French Amy Frankenburg Ross Warner Justin Nash G ANC Wellwork GPB, LPC DS Ops Page 2 of 16 L5-16AL2 Lateral Isolation~ch With Slidin Sleeve 9 PROCEDURE: • Ensure Baker hand on location while setting patch. (Contact Carl Diller 907-317-7755, or Bob Harris 907-240-0427 with any questions regarding Straddle Packer assembly and location). • Drift & Tag with SL for straddle assembly. • Tag Lower KB Packer C«38969' DD with E-Line and log up to GLM #1 C~ 8616', Tie-in with memory jewelry log 5/31/2006, revised on 9/19/2008. • Note: Top of Li C~3 8937', this correlates with the L1 open-hole completion on the WBS @ 8961' DD. • All equipment has been ordered and is available from Baker. Pre-Patch Slickline: 1. MIRU S-line unit. 2. MU and RIH, with 20' x 3.7" OD Baker dummy patch D&T to Lower K8 Packer Q 8969' DD. • Locate X Nipple Cc~ 8728' DD (Use Jewelry Log 5/31/2006, Revised on 9/19/2008). Jewelry log 5/31 /2006 was revised on 9/19/2008 to get it on depth with tubing tally. Copies have been sent to the slope. Ensure correct tie-in is used, depth control is very important because of tight window. 3. RDMO E-Line Set Straddle 1. MIRU E-line unit. 2. MU and RIH with Gamma Ray and CCL (Jewelry Log) • Log up from Lower KB Packer ~ 8969' DD • Tie-In to X Nipple @ 8928' DD • Log up past GLM Station 1 («~ 8616' DD 3. POOH 4. MU and RIH with Baker Single Set 4-1/2" KB straddle assembly (upper packer, sliding sleeve in closed position, lower packer, XN nipple, and tail pipe), ~20' element to element. (See attached schematic) 5. Tie-in to Lower KB Packer C«~ 8969' DD (Use Jewelry Log performed in step 2 above), make necessary correction. Ensure correct tie-in is used, depth control is very important because of tight window. • NOTE: Bottom section of patch assembly (XN Nipple & Tail Pipe) could possibly slide into lower KB Packer. Be careful to ensure patch assembly does not get stuck. 6. PUH and set upper element C~3 8905' ELM. • Top of Window C«3 8910' • Bottom of Window C«3 8920.5' • Set Upper element C«~ 8905' ELM • Set Lower Element @ 8925 ELM 7. POOH 8. RDMO Page 3 of 16 L5-16AL2 Lateral Isolation ~h With Slidin Sleeve • 9 WBS TRFE= 4-116" Fnac Y11aLFfAD= ACTUATpR= AXELS KB. ELEV = 80' ~.aE~ KOP= 3800' .. Ma>< A is = 9328' 99° Ooaoum IWD= 8087 Da1umTVD= 8800'$$ 314` CSG, 46.+Jt. K-8C TO L-80 VAM N2. 91.83. F440. D .1 Min~tum ~ = 2.090" ~ 8973' 2 718" XN NIPPLE (KB PKR ASSIn t•1n" TBG, 12.83, L-80 6T-tA .0152 Dpf, ID = 3.958" BKR NMfPSTOCK L 5 -16A -'CAT (8881/ H28 (PPS 260... AL 1 & ALZ 21TT FI511R9~IOV~(08f06/08) M C 1 Fr W Nfg7A C ST MD TVD ~/ TYPE VLV L.A1Y;fi PORT DATE 5 2781 2780 2 K~2 DOME 81C 18 06H1108 4 4708 4894 4 KBf3-2 D BK t6 08/11108 3 8387 837i 9 K73Q-2 ODME BK 18 08/11/08 2 7'803 7508 28 KBCr2 DOME BK 18 08I1i108 1 8818 8430 24 KBG-2 SO BK 24 06/11/08 b ~ 3.813' x a1n BK7~ 5-9 PKR. FfS X NP, ID = 8.819" YYLEG, D = 3.888" X 5-1n• 2:XP LTPw I 1 L2 (OPB+I HOLE CONIPLE7iON) 0 118d 9.87 Mk.7.0Uf WNDOYV (L6-16A-12) 8898' - 8847 Lt (OPEN HOSE COMPLETION) TD 9TS7 3.87 biLLOtlT WPDOW (L8-/8A"L1) 8861' •8874' L5~16A (aPB~ HOLE ODN~LE'f{ON~ To 1087 3.60"MtiOLA'VVINDdWi~LB-18A) 8087'-8108' DATE REV BY OOMM6NT DATE REV BY MkEMS OSl17/8T RYMN 41 OItlG BUBPEND® 08f09108 JMD REWIDV9? F13F1(09i08108) 06103187 NfNiDIC 1 OTBGG~PIAL COYFI.&TION 06FD1106 NDR771C 2 NIAIO 08101 NDRpC 2 MULT6 LAT (L8-16A, AL1 i AL2) 05/08108 KSB~JC ORL{i DRAF70DR~CTgN5 06n8A8 JC Ftkl KB DUDE L3H (08/22) LISBURE U-+U!' WQL- t5-i8A PBtb1R No: 2080830. (40), (~) AP9 ND: 50-029.21700.Ot, (80), (81) 5EC 7, T11N, R15E 1788' F5l d~ 19' PVI ~ 1]tpbratbn (Alaska) Page 4 of 16 L5-1tiAL2 Laterallsolation Witch With Slidin Sleeve 9 Baker Straddle Assembly by Baker Thru-Tubin Straddle Completion Well: L5-16 Date: 2~ 45 "KB^ Upper Straddle Packer 4" GS Fishing Neck Up 2 7/8" STL Pin Down 30K Shea Release 9 Ch 2 718" STL Pup Jam X-02718"STLBx2718"CSHP Baker Sliding Sleeve 2.312" "BX" profile 2718"CSHBxP X-0 2 718" CSH B x 2 7i8" STL P 2 718" STL Pup Jant X-02718"STLBx3112"STEP 45 "KB" Lower Straddle Packer 3'l:" STL Bcx Up 2 718" STL Pin Down 30K Shear Reb~e 9Ch 9 Baker Oil Tools Co. Man: OD ID Length 3,70" 2.3T' 5.76' 2.875" 2.38" TBD 2.875" 2.38" TBD 3.17" 2.312" 3.64' 2.875" 2.38" TBD 2.875" 2.38" TBD 3.500" 2.38" TBD 3.70" 2.37" 5.49' Haliiburton z 718" "XN^ TBD 2.205" TBD w! 2.205" No-Go TAI Pipe wl WLEG 2.875" 2.3T' TBD Page 5 of 16 L5-16AL2 Lateral Isolation ~Ch With Sliding Sleeve L5 16A gAfET1,NOTES:wELLANGLE,iO-X92!%'. ~ "'CAT 1$3$V H23 (PPM) 2S0 ••• AL1 &AL2 Proposed Straddle Assembly Tfi~= 4•tl8" FMC WELLHEAD= CNY ACTLI4TOR= AXELSON K8, aEV = 6J BF. f3EV = NA KOP~ 3800' Max Angle = 9 9' ~ 9326' Carton IV "~ -- - L-80 VAM Minimum ID = 2.010" (c3~ 8973' 2-718" XN NIPPLE KB PKR ASSY) 4-1/2" T80. 12.81. L-80 BT-A( .0752 bp(. D = 3.958' ~ CeMer Upper Element ~ 8905' ~ ~ Sliding Sleeve ~ I Center Lower Element ~ 8925' I • GAS LFT MANDRFIS ST MD ND OEV 7Y PE VLV LATCH PORT QATE 5 2787 2780 2 KBG2 DOME BK t6 06/11106 1 4708 4894 a KBG•T OOME t3K t 6 06/11!06 3 6387 6371 9 KBG-2 DOME BK t6 O6l11~06 2 760'1 '519 26 K9C-2 '?O!a-_ Gz _ ;;t7:9~: EO-5 2a ;? 24 K7G 2 I Top of Window ~ 8910' 3 80" h4LLOUT VvfJUOW (L8.18A-L2) 8938' - 894T L1 (OPEN FIOLE COMPLETION) 3.80' MLLDl1T WBJOOW (LS-18A"Lt) 8981' •8974' L5.16A (OPEN HOLE COMPLETION) 3.80' MILOUT NANDOW (LS•16A) 9097' - 9709' DATE REV BV COMMENTS DATE REV BV COA9u1ENfS 03177187 RVVN st OPo6 SUSPENDED 09/09!08 SWI,I~D REA40VED FISH (09IOS/08) 06!03/87 NORDIC 1 OPoGINAL CONPLETtON 06!01/08 NORDIC 2 ItYYO 09l01I06 NORDIC 2 MULTI• LAT ~L6.16A, AL1 i AL2) 05/08!08 KSB/PJC ORLG DRAFT CORF2ECTgNS 08/28/08 BSFIPIC FULL KBGIADESHOFIFLSM(08/22) LISBLFE UNfF WELL: LS-itSA PEAAIIT No: 2080830. (40-. (50) AR No: 50.029-21 700-Ot, (80}, {87} 3C 1.it1N.Rt5£ t788'FSL61ffFN BP Fxpbratbn (Alaska) Page 6 of 16 L5-16AL2 Lateral Isolation ~Ch With Sliding Sleeve Revised Jewelry Log from 5/31/2006 on Depth with Tubing Tally Page 7 of 16 L5-16AL2 Lateral Isolation Witch With Sliding Sleeve • '"wEus~ JEWELRY LOG c'' a~ I" N MPL-GR-CCL ISM IVW ~,;~, „K ~,,,,;~, 31-May-O6 = cry BP EXPLORATION (ALASKA), INC. ~ weu L5 -16A a Field LISBURNE County NORTH SLOPE State ALASKA o ~ Surface Locatbn timer SeMws ~ u'S ~ a ~ m 1,788' FSl & 19' FWL NO^e m ~ ~~ a SEC: 1 T1NP: 11N RGE: 15E Ebva6on ~~ -- Pama~M Daeun MSL Elewtlon O l] ' ~ ~ F . Log Metawed From RKB ~ ~ Above Perrn Datum K.B. 60.0 F 6g o V a ,g~ ~ . . . . . U S LL U H API 6sriW,Lmbar 50-022770!}01 G.L. 21.0 ~~---- ,3:,g FINAL ( PRINT ~~~4r i7f1f1 Page 8 of 16 L5-16AL2 Lateral Isolation ~ch With Sliding Sleeve • Page 9 of 16 L5-16AL2 Lateral Isolation Witch With Sliding Sleeve • Caliper 9/6/2008 **NOTE*"PDS Caliper is 2' shallower than tubing tally. Patch depths shown are referenced to tubing tally. representation of what the patch will look like. L5-16AL2 --- 3D View of L2 Lateral and Patch with Sliding Sleeve & XN Nipple Collar ~ 8893' Patch with Sliding Sleer-e and XN Nipple 8905' 8910' L 2 P a t c h a I 8920.5' 8925' Page 10 of 16 L5-16AL2 Lateral Isolation P~'fch With Sliding Sleeve • NOTE: Caliper is 2' shallower than tubing tally. PDS REPORT JOINT TABULATION SHEET Pipe: 45 in 12.6 ppf L-80 IBT-MOD 1b'ell: 15-16A Bodv Nall: 0.271 in Field: Lisburne Upset Nall: 0271 in Company: BP Exploration i•Alaska}, Inc. Nominal I.D.: 3.958 in CounW: USA Survey Date: September 6. 2008 Joint No. Jt Depth ;Ft) Pen. Upset Ins.I Pen. Body ilns.) Pen. °o ~tiletal Loss Min. LD. ilns.l Comment; Damage Profile t°'o walll 0 50 100 I 7- I 183 7691 0 0.01 5 I 3.91 1 1 7 0 I - 7771 I 186 7816 0 0.01 3 I 3. 187 7858 0 0.01 , I 3.92 188 7900 0 0.01 ? 3.91 1 7 41 0 - I 79 0 191 8024 0 0.01 ~ I 3.92 192 8066 0 0.0 3 I 3 193 8107 0 0.01 3 2 3.92 1 4 14 0 ~ - 0 4 9 I 7 71 0 198 8313 0 0.01 1 3.92 199 8355 0 0.01 ' 3.90 200 839b 0 0.01 3 3.92 201 1 8 0 D - 203 8521 0 0.01 3 ! 3.89 204 8562 0 0.01 1 ~ 3.90 201.1 8601 0 0.00 0 I 3.89 PU'P 01. 14 C 0 N A ~ h 7: 01 8 1 0 1 I - 'P 205 8631 0 0.01 3 3.87 0 .1 867 0 I ' 0 .~ 8682 0 0 0 0 1."" -Ni I d 0 0 0 ~P 205.1 8693 0 0.00 0 0 9 PUP 205.5 8703 0 0 0 ~) N%A 15" x 7.625" Baker Packer 870 0 0 0 'P 717 0 I I ~P 205.8 8727 0 0 0 ~ N;`~i 15" X-Vi le 205.9 8729 0 0.01 0 0 .85 PL'P 206 8738 0 0.01 5 ? 3.81 7 0 0 0 0 4 ' 7 1 0 0 0 N.` 4 -" 206.3 8807 0 0.01 1 I 3.92 PU'P ~ 7 ll 0 0 T f i r 208 8852 0 0.01 3 I 3.90 ~~ ' i r 210 8934 0 0.01 1 I 2.9-1 L5-16AL1 Lateral 210.1 89-1 0 ' - ' '' 9-4 0 0 ~ - P 210.3 8956 0 0.00 0 J 2.31 PU'P Shallow ittin . 210.4 8961 0 0.0 3. 0 Remainder or oint 210 211 8974 G 0.01 ~ ~ 3.91 Penetration Body ,yletal Loss Body Page 5 Page 11 of 16 L5-16AL2 Lateral Isolation Witch With Sliding Sleeve p te: All tutu camectiesna are IBTM threads SCAB LINER ~& COMPLETION SUMMARY VYELL # L5-16 TUBING SIZEIGRADE/THREAD 4.50 in Tt1B84G YVT/FT 72.601fi11t BOTTOM OF TUBING AT 9,206.00 ft TOP OF TUB~1G AT (RKB) 8,802.99 ft Connections DATE L-80 5282006 IBTM nput Depth NO ITEM lop Bottwn OD ID LENGTH TOP ,1t BOTTOM HES Float 5hae 4!112" I@T Box 5.250 3.500 1.75 9,20425 9,106.00 1 4-112" 12.631ft L-80 IBTM R -3 Casir~, Baker Loc 4112' IBT Box 411!2" 03T Pke 5.500 3.958 41.58 9,162.67 9,204.25 HES Float Collar 4!112" IBT Box 4/1P2" ~T Pin 4.500 3.500 1.45 9,161.22 9,162.67 1 4-112" 12631ft L-80 ATM Rge -3 Casing Centralizer 4112' IBT Box 411/2" 83T P~ 5.500 3.956 41.59 9,119.83 9,169.22 BOT Landing Collar 41112" IBT Box 4112" IBT Pin 5.250 3200 0.65 9,198.78 9,119.63 1 4-112" 12.fi#IR L-80 ATM Rge -3 Cas~g Centralizer 411/2" IBT Box 41112" IBT P~ 5.260 3.958 41.59 9,077.19 9,118.7$ 1 4-112" 12.6318 L-60 ATM Rge -3 Casing Centralzer 4112" IBT Bax 4112" 18T Pke 5.260 3.958 40.70 9,038.49 9,077.19 1 4-112" 12.631ft L~lO ATM Rge -3 Casing Centralzer 41112" !BT Box 41112" IBT Pi- 5.260 3.958 41.47 8,995.02 9,036.49 1 4-112" 12.6311! L-80 ATM Rge -3 Casing Centralizer 41112' IBT Box 4/12" 18T Pin 5.260 3.958 40.59 8,954.43 8,995.02 1 4-112" 12.631ft L-80 ATM Rge -3 Casing Centralzer 4/1/2" IBT Box 41112" IBT Pin 5.280 3.958 40.58 8,913.85 8,954.43 t 4-12" 12.6318 L-80 ATM Rge -3 Casing Centralizer 41112" IBT Box 41112" IBT Pm 5.260 3.958 40.58 $,87327 8,913.85 1 4-12" 12.63/ft L-80 ATM Rge -3 Casing Centralizer 4112' IBT Box 4112" IBT Pin 5.260 3.958 40.58 8,832.69 8,873.27 4-12" 12.631!! Liner Pup Jt 4112" IBT Bvx 4112" IBT Pin 5.260 3.958 3.83 8,828.66 8,832.69 4-112" X 5-112" Cro$s Over 5112" IBT Box 41112" IBT P~ 6.030 3.958 1.82 8,827.04 $,828.86 BOT HMC Liner Hanger 5112" IBT Box 5112" 83T Pin 6.390 4.810 6.65 8,820.39 6,827.04 BOT 7-518" X4-12" ZXP Ling Top Packer. 111.5 ft PBR) 11.5 tt PBR 51112" IBT Pir 6.560 4.900 17.40 8,802.99 6,820.39 8,802.99 ~ Whrpstack sptfing depth 9100-90911 8950-897{! 8923-8933 Page 12 of 16 L5-16AL2 Lateral Isolation~ch With Sliding Sleeve Cfl14~LETION SUMMARY DATE V~L # L5-15 TUB$#G 4.50 in L4~ #BTN TU81NG tKnt=T 1260 IWFt BOTTOM 4f TUB$!G AT $,781.75 ff TOP OF TUBN4G AT Iii 25.5#( it . Alf to ~ eon,eedons are BTN Caamets MO i1T:M T BotEora 00 ID LE1lGTH TOP BOITON BOT 4112" TCfI Box 5.(90 3.958 1.32 8`790.44 $,791.75 4.5° 12.9N1R LSD Pup XO.k 412' HBT Box 412" TC#IPin 5.~0 3.958 9.91 8,7#D.53 8.790.44 1 4.5" 12.8dk L-8088TH 18 T ~ 4t2" tBT Bat 4112" -BT Pia 4.50D 3.958 41.48 8,7'39.05 8,78Q_53 4.5" 12.BA41t L-8D XO 1t 4112" TC#i Bcx 4112" ~T Pia 4.50D 3.958 fl:95 8,729.1U 8.731#.D5 HES 'X' ar! 3.813° Padter Bore aad Ii11C PI 412' TC11 Box 412' TC11 Pin 5.030 3.8(3 113 ##,7Z7.$$ 8.729.1D 4.5° 12.6Ahit L-8D XO Jt 412" tBT Bat 4112' TClI Firr 4.950 3.9'58 9.711 8,71$.18 8,727.8$ 4.5" 129#18 L~0 XO ~ 4t2" IBT Bat 412" IBT Pia 4.93D 3.920 9.82 8.708.58 8.718.18 Baker 7-51$" X 418' X 9-518" S3 Padoer 412" IBT Bat 4112" IB Pia 8.550 3.958 4.10 $, 8.7058 4.5" 12.61141t L-8D XO 3 4(12'° IBT Bat 412" IBT Pia 4.990 3.930 9.78 8,894.7(1 8,704.45 4.5" 12:81kIt L-811 XO 3 412' TCtI Box 4112" IBT Pia 4.960 3.9~ 9.95 8°884.75 S,p94_TO NES 7C ad 3.$13° Bart 412' TClI Bat 4112' TCII Pin 8.750 3.813 1.22 $,583.53 8,684.75 4.5" 12.8#(14 L XO Jt 4112° IBT Bat 411? TCIt Pin 5.000 3.958 9.89 8,873.84 8.683.53 1 4.5" 128Abit L Et# Rge ill Ttt~ap 4117' IBT Bac 412" IB Pn 4.5D0 3.958 41 # 8.832.40 8,673.84 4.5" i2.6i141t L-80 XO Jt 4(12' TCIt Box 4112" IBT Pin 5.190 3.958 9.~ 8,822.51 8.63240 $LB 4.5" x 1° 12.6~Rt MIMG DGW # 1 492" TCII Bast 4(12' TCt1 Dirt 5.999 3.938 8.97 $,515.54 8.67251 4.5" 12.8#At L-8D XO JI 4t2' IBT Box 4(12" TCt1 Pica 4.940 3.558 9,75 8,8D5.79 8.615.54 24 45" 12.8ii1#t L,80 II1 T 4112" IBT Bat 4112" IBT Pin 4.50D 3.958 985.97 7,819.82 8,645.79 4.5" 12.4iMiR L-8D XO Jt 4912" TCII Box 411x' IBT Pia 5.(90 3.958 9.911 7,809.92 7.619.82 ;9LB 4.5" x 1" 12.5#4( t3lVMG GllYt # 2 412' TCtI Bat 4112' TCtI P'ira 5.999 3.938 6.97 7,50293 7.80992 4.5" 12.6t~4R L-80 XO Jt 4112" IBT Bat 412' TCtI Pin 4.94D 3.958 9.75 7.54#'320 7.80295 29 4.6" 124#NYft L~ tll T 4-117" IBT Banc 4-112° IBT Pin 4.50D 3.958 t189.4K1 6,404.17 7,593.20 4.5" 12.8#fk L-80 XO ,lt 4t2' TCII Bax 412" IBT Pia 5. t90 3.958 9.91 6,394.28 6.404.17 St9 4.5" x 1" 125~P# DIIMAG GLM # 3 4t2' TCti Sax 4112' TCp Pirt 5.999 3.938 6.97 5,3$739 6„384.28 4.5" 12.Bi!!R L-80 XO Ptap Jt 4t2" IBT Bat 412' TCft Pin 4.940 3.958 9,89 6,377.80 6,38739 40 4.6" 126M1#t L-80 #II T 4(17' IBT Box 4-112 IBT Pia 4.500 3.958 t852.25 4,72.5.35 677,80 4.5" 12:8x141( L-8D XO Jt 4117' TCFl Bat 412" ~T Pia 5.(90 3.958 9.93 4,715.42 4.72x.35 SlE 4.5" x 1" 12.BNt DMNG GLM # 1 4112' TC41 Bat 4112°' TCII Pin 5.989 3.938 6.97 4,70$.45 4,715.42 4.5' 12:8xMiR L-80 XO J4 4-12" IBT Sax 4112°' TCI4 Pin 4.948 3.958 9.87 4,89878 4,708.45 4.6" 126dgft 1~ III T 4-(12' IBT Bat 4-112" IBT Pia 4.500 3.958 (:900.91 2.7978 48.78 4.5" 12:61fi#t L-80 XO Jt 412' TCII Bat 412" IBT Pia 5. t90 3.958 9.92 278795 2,797.87 SLB 4.5" x 1"125Nt D61NG GLM# 5>td OC#(aralve 412' TC41 Box 412' TCtt Pin 5.999 3.938 6.97 2,7'$0. 2,787.95 4.5" 12.6;M>ft L-80 XO Jt 4-117' IBT Box 4117' TCtt P"ir- 4.940 3.958 9,74 .2,771.24 2,78Q98 id 4.6" 126xY14t L-80 III T 4-1/2° IBT Bat 4112" BT Pia 4.500 3.958 576.417 2,196.17 2,77(24 4.5" 12.8xMfft L-~ XO Jt 412' TCtI Bax 4-112" IBT Pia 5.19D 3.958 9. 2,18~3.27 2.195.17 4-iii2" #~S We#ISdx TRSSSV 3.$ir ifl 4i2' TC[l Box 4t2' TGIi Pirt 8.620 3.813 7.86 2.177.39 2.18537 4.5" 12.OaYAt L-8D XO Jt 4t t8 Bat 412" tl F~ira 4. 3. 9. 2,167. 2,177.39 59 4.5" 126(l/ttL-Stt 111 4-(12^ I 4112" Pn 4. 3.9x8 2084.E 103.43 2,187.77 4.5' t28#!R L-80 .R 4t2" Box 4112° 18 Pia .SDD 3. 9.85 58 1 .43 4S t2.8BVR LSD .$ 4-117' IBT Bat 4-'12" IBT Pia 4.500 3.958 9.83 ~i.75 94:58 4.5" t2tl;ilft L-80 J4 4t2" iBT Bac 4-112" ~T Pin 4.50D 3.958 7.88 76.09 83.?5 4.5' 128171ft L~f#' J4 4t2" IBT Bat 4117' IBT Pin 4.60D 3.958 5.8t 7018 78.119 1 4.6" t28Npit L~ F#ge 111 Tuhiap 412" IBT Bat 4117' IBT Pia 4.500 3.968 41.53 28.75 7018 4.5" 1284aft L-$11 CrossoaRr J! 4112" TCI1 Box 4-112" tBT Pia 4.540 3.958 238 26,37 28.75 t 1" X 4.6 LB F1#IG T 412' TCtI Bat 412' TC#i Bax 10.840 3.928 0.77 25.5D 26.37 25.80 25.811 2x.80 25.80 205 Mork 2 RM® 5.6(1 26.80 BHA Ta#a# 8391.76 GLM i-4 Have „DGLVwi'8K Larehes GLM #3 has 1`tICK Sheared Yaive w'RfCPlatCh The '~4~LEG ;vas landed 8 fr inside liner hanger PBR. Used 53 SS bands on CL Tire lower 7if' of this eom letion has an RHC u with a half and rod on seat Page 13 of 16 1 ©~; ~~o~ DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2060850 Well Name/No. PRUDHOE BAY UN LIS L5-15AL2 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21700-61-00 MD 11500 TVD 8846 Completion Date 9/1/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments %EU D Asc Directional Survey 8921 11500 Open 9/7/2006 Disk also has L5-16A, L5- ! 16 L1, L5-16A L1 PB 1 I:,R~t Directional Survey 8921 11500 Open 9/7/2006 ~~ FFpt ~ ~ ,p 15224 Ll&'d2rlfhation w ~\ 8918 11500 Open 6/14/2007 LIS Veri, GR, ROP w/Graphics TIF g 15224 Gamma Ray 25 Blu 8935 11500 Open 6!14/2007 MD GR 24-Aug-2006 f,L~og 15224 Gamma Ray 25 Blu 8935 11500 Open 6/14/2007 TVD GR 24-Aug-2006 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION r ` Well Cored? Y ~ Daily History Received? ~/ N /~ t ~~ ~ ~ h ~ ~ ~p - Q Chips Received? "4'TF~- Formation Tops ® N Analysis ~ffd" Received? Comments: ~`, ,' J. `_. _~•.. ?:_~~ ~~ 3 "Tr°ansmittal F®rm INTEQ To AOGCC 333 West 7"'Ave, Suite 100 Anchorage, Alaska 99501 Anchorage GEOScience Center %~. Attention: Christine Niahnken Reference: LS-16AL2 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Measured Depth Log 1 blueline - GR TVD Log LAC Job#: 1194703 Sent By: Deepa Joglekar Date: May 24, 2007 Received By: Date: ~ °~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska ~b~ `d~~ 99518 ~ 1 ~j ~ ~ L1 Direct: (907) 267-6612 FA<~C (907) 267-6623 '!_ _ __ ~- - _ - - -_ --_ _. ~ f - - - .' r ~E~EIVED STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COM~SION SEP ~ 9 20Ub WELL COMPLETION OR RECOMPLETION REPORT AND LO A aska Oil & Gas Cans. Commission A ....L.w nna 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAa,czs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/1/2006 12. Permit to Drill Number 206-085 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/21/2006 13. API Number 50-029-21700-61-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/29/2006 14. Well Name and Number: PBU L5-16AL2 1788 FSL, 19 FWL, SEC. 01, T11N, R15E, UM Top of Productive Horizon: 1223' FSL, 1051' FWL, SEC. 01, T11 N, R15E, UM 8. KB Elevation (ft): 60 15. Field /Pool(s): Prudhoe Bay Field / Lisburne Pool Total Depth: 3154' FSL, 2243' FWL, SEC. 01, T11N, R15E, UM 9. Plug Back Depth (MD+TVD) 11500 + 8846 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 717447 y- 5974920 Zone- ASP4 10. Total Depth (MD+TVD) 11500 + 8846 Ft 16. Property Designation: ADL 028320 TPI: x- 718495 y_ 5974386 Zone- ASP4 Total Depth: x- 719630 y- 5976352 Zone- ASP4 11. Depth where SSSV set 2177' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING. RECORD PULLED See L5-16A 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD Open Hole Completion 4-1/2", 12.6#, L-80 8792' 8704' MD TVD MD TVD 8936' - 11500' 8725' - 8846' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 8936' Set Whipstock (Top of Window at 8936') 26. PRODUCTION TEST Date First Production: Reported on L5-16A Method of Operation (Flowing, Gas Lift, etc.): See L5-16A 10-407 (Dated 09/29/06, PTD # 206-083) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core c~il~~;+# Ito state "none". ~~~ N~~ $ `~3~ ~ ~~ ~~~ f None ~ ~ O " t, =~ ~~ ~.., ~ ~r~~ aCi ~ ~ 20D6 Form 10-407 Revised 12/20 ,~ CyONTINUED ON REVERSE SIDE ~ ~ ;°" ~ a ~~ ~ a ~ ~ ~. ~ 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and brie ummarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Wahoo 6.1.1 9008' 8785' None Wahoo 5.3 9013' 8788' Wahoo 5.2 9052' 8810' PU3 / 3c 9058' 8813' Wahoo 5.2 10584' 8848' Wahoo 5.1.2 11282' 8854' Wahoo 5.1.2 11470' 8849' 30. List of Attachments: Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Q ~ ~ [ Z %~~ `~ Signed Terrie Hubble Title Technical Assistant Date PBU L5-16AL2 206-085 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Drilling Engineer: Greg Sarber, 564-4330 Well Number 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. IreM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irenn 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. 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-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only f BP Alaska ~ s,~ ar by Baker Hughes INTEQ Survey Report INTE~G~~ Q Company: BP Amoco Date: 8/30/2006 Time: 14:37:18 Page: I Field: Lisbume Co-ordinate(NE) Reference: WeIL L5-16, True North Site: Lis DS 05 Vertical (TVD) Reference: 9:16 3/2/1987 00:00 60.0 We0: L5-16 Section (VS) Reference: Well (O.OON,O.OOE,35.OOAzi) Wellpath: L5-16AL2 Snrvey Calculation Method: Minimum Curvature Db: Orade Field: Lisburne 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 : bggm2005 Site: Lis DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Easting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: L5-16 Slot Name: 16 L5-16 Well Position: +N/-S 4778.96 ft Northing: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Easting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Wellpath: L5-16AL2 Drilled From: L5-16 Tie-on Depth: 8921.35 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum; Mean Sea Level Magnetic Data: 8/15/2006 Declination: 24.65 deg Field Strength: 57627 nT Mag Dip Angle: 80.96 deg Vertical SeMion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 35.00 Survey Program for Definitive Wellpath Date: 8/20/2006 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 60.00 8921.35 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 8935.80 11500.00 MWD (8935.80-11500.00) MWD MWD -Standard Annotation MIS TVp - ft ft 8921.35 8711.52 TIP 8935.80 8724.90 KOP 11500.00 8845.74 TD Survey: MWD Start Date: 8/23/2006 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD ft Ind deg Azim deg TVD ft Sys TVD ft N/S ft E/W ft MapN ft MagE ft VS ft; DLS Tool deg/100ft 8921.35 22.20 125.65 8711.52 8651.52 -546.46 992.19 5974402.91 718454.08 121.47 0.00 MWD 8935.80 22.18 125.85 8724.90 8664.90 -549.65 996.62 5974399.85 718458.60 121.40 0.54 MWD 8960.87 2724 115.16 8747.68 8687.68 -554.86 1005.66 5974394.89 718467.79 122.31 26.86 MWD 8990.37 39.76 107.96 877224 871224 -560.67 1020.81 5974389.53 718483.10 12624 44.46 MWD 902027 51.90 10326 8793.04 8733.04 -566.34 1041.44 5974384.46 718503.88 133.43 42.12 MWD 9050.45 63.09 99.77 880924 874924 -571.36 1066.35 5974380.16 718528.92 143.60 38.33 MWD 908120 73.57 89.90 8820.60 8760.60 -573.67 1094.74 5974378.68 718557.37 157.99 4525 MWD 911124 87.50 83.34 8825.53 8765.53 -571.90 112423 5974381.31 718586.79 176.36 51.11 MWD 9141.80 9023 68.40 8826.14 8766.14 -564.46 1153.77 5974389.60 718616.11 199.40 49.68 MWD 9176.99 92.32 62.91 8825.36 8765.36 -549.96 1185.81 5974405.02 718647.71 229.65 16.69 MWD 9207.39 94.50 59.53 8823.55 8763.55 -535.36 1212.41 5974420.39 718673.87 256.87 1321 MWD ~~t--o$~ BP Alaska ~ s~R ~ by Baker Hughes INTEQ Survey Report ~~~ 1NTEQ Company: BP-Amoco Date: 8/30/2006 Tim e: 14:37:18 Page: 2 Field: Lisburne Co-ordinate(NE) Reference: WeIC L5-16, True North Site: Lis DS 05 Vertical. (TVD) Itefereuce: 9:163/211987 00:00.60.0 Well: L5-16 Section (VS) Reference: Well{O.OON,O.OOE,35.OOAzi) Wellpath: L5-16AL2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD ft deg deg ft 9240.22 92.75 54.95 8821.47 9272.27 91.92 50.87 8820.16 9301.44 91.83 47.38 8819.21 9331.06 91.64 43.87 8818.31 9366.05 91.52 40.57 8817.35 9395.71 90.94 37.00 8816.71 9425.60 91.22 33.43 8816.15 9462.23 94.78 31.07 8814.23 9491.67 94.20 34.58 8811.93 9520.61 92.01 37.67 8810.36 9550.80 91.40 39.91 8809.46 9580.49 93.15 44.34 8808.28 9612.83 93.68 48.74 8806.35 9642.69 93.70 53.17 8804.43 9672.44 92.50 56.36 8802.82 9704.27 89.22 58.28 8802.34 9736.90 89.95 61.72 8802.58 9768.88 91.71 61.26 8802.12 9799.16 93.58 57.29 8800.72 9829.64 92.26 53.13 8799.16 9867.28 91.12 48.60 8798.05 9897.91 90.57 44.59 8797.60 9930.02 89.31 40.89 8797.64 9961.29 87.93 38.07 8798.39 9991.58 84.54 34.58 8800.38 10021.98 82.81 27.76 8803.73 10051.12 84.83 28.43 8806.87 10080.41 88.88 24.93 8808.48 10110.47 88.79 20.74 8809.09 10140.49 87.40 16.26 8810.09 10170.59 87.06 7.86 8811.54 10200.24 86.18 9.55 8813.29 10230.78 89.68 13.83 8814.39 10260.31 91.71 19.17 8814.04 10299.16 88.44 23.20 8813.98 10329.86 87.71 28.92 8815.02 10361.86 81.75 27.12 8817.95 10395.49 78.17 29.63 8823.82 10438.30 80.80 21.52 8831.64 10472.42 83.11 18.13 8836.42 10499.85 83.68 12.68 8839.58 10535.55 83.92 7.84 8843.43 10571.79 84.30 1.69 8847.16 10602.86 85.99 359.07 8849.79 10644.30 85.87 353.64 8852.73 10674.50 85.65 346.94 8854.96 10702.27 89.34 346.82 8856.18 10730.54 92.72 341.40 8855.67 10761.04 92.66 345.08 8854.24 10790.26 93.27 351.11 8852.73 10831.26 94.88 358.25 8849.81 10861.01 93.03 1.37 8847.76 10892.05 91.65 4.99 8846.49 Sys TVD N/S ft ft 8761.47 -517.63 8760.16 -498.32 8759.21 -479.25 8758.31 -458.54 8757.35 -432.65 8756.71 -409.53 8756.15 -385.12 8754.23 -354.19 8751.93 -329.54 8750.36 -306.20 8749.46 -282.68 874828 -260.68 8746.35 -238.48 8744.43 -219.72 8742.82 -202.58 8742.34 -185.40 8742.58 -169.09 8742.12 -153.82 8740.72 -138.37 8739.16 -121.01 8738.05 -97.27 8737.60 -76.23 8737.64 -52.65 8738.39 -28.53 8740.38 -4.18 8743.73 21.65 8746.87 47.21 8748.48 73.33 8749.09 101.02 8750.09 129.47 8751.54 158.84 8753.29 188.10 8754.39 217.97 8754.04 246.27 8753.98 282.49 8755.02 310.04 8757.95 338.15 8763.82 367.28 8771.64 405.22 8776.42 436.99 8779.58 463.25 8783.43 498.17 8787.16 534.07 8789.79 565.03 8792.73 606.26 8794.96 635.93 8796.18 662.95 8795.67 690.12 879424 719.29 8792.73 747.83 8789.81 788.52 8787.76 818.19 8786.49 849.15 E/W MapN MapE ft ft ft 1239.95 5974438.90. 718700.89 1265.49 5974458.94 718725.85 1287.53 5974478.65 718747.33 1308.69 5974499.95 718767.88 1332.19 5974526.52 718790.62 1350.76 5974550.16 718808.51 1367.99 5974575.06 718825.03 1387.51 5974606.54 718843.64 1403.41 5974631.65 718858.82 1420.45 5974655.47 718875.17 1439.35 5974679.52 718893.38 1459.24 5974702.09 718912.63 1482.67 5974724.96 718935.40 1505.81 5974744.39 718957.98 1530.07 5974762.22 718981.73 1556.85 5974780.17 719008.01 1585.11 5974797.29 719035.77 1613.20 5974813.36 719063.42 1639.20 5974829.56 719088.95 1664.19 5974847.64 719113.43 1693.37 5974872.21 719141.90 1715.61 5974893.89 719163.53 1737.40 5974918.09 719184.62 1757.27 5974942.78 719203.79 1775.17 5974967.63 719220.97 1790.81 5974993.90 719235.85 1804.45 5975019.84 719248.74 1817.57 5975046.33 719261.11 1829.23 5975074.35 719271.96 1838.75 5975103.06 719280.65 1845.03 5975132.60 719286.07 1849.51 5975161.97 719289.70 1855.69 5975192.01 719295.01 1864.07 5975220.54 719302.57 1878.11 5975257.15 719315.55 1891.58 5975285.08 719328.22 1906.55 5975313.61 719342.36 1922.28 5975343.18 719357.24 1940.42 5975381.63 719374.27 1951.87 5975413.72 719384.80 1959.10 5975440.18 719391.27 1965.42 5975475.26 719396.57 1968.42 5975511.23 719398.52 1968.62 5975542.18 719397.83 1965.99 5975583.32 719394.01 1960.92 5975612.83 719388.07 1954.62 5975639.65 719381.00 1946.89 5975666.58 719372.48 1938.10 5975695.48 719362.85 1932.08 5975723.83 719356.01 1928.29 5975764.40 719351.04 1928.20 5975794.05 719350.08 1929.92 5975825.05 719350.90 VS DLS Tool ft degl100ft 287.19 14.91 MWD 317.65 12.98 MWD 345.92 11.96 MWD 375.02 11.86 MWD 409.71 9.43 MWD 439.29 12.19 MWD 469.17 11.98 MWD 505.70 11.65 MWD 535.03 12.05 MWD 563.91 13.07 MWD 594.02 7.69 MWD 623.45 16.03 MWD 655.07 13.68 MWD 683.72 14.81 MWD 711.67 11.44 MWD 741.10 11.94 MWD 770.67 10.78 MWD 799.29 5.69 MWD 826.86 14.48 MWO 855.42 14.30 MWD 891.60 12.41 MWD 921.59 13.21 MWD 953.40 12.17 MWD 984.56 10.04 MWD 1014.77 16.04 MWD 1044.90 23.01 MWD 1073.66 7.30 MWD 1102.59 18.26 MWD 1131.96 13.94 MWD 1160.72 15.62 MWD 1188.38 27.90 MWD 1214.92 6.42 MWD 1242.93 18.09 MWD 1270.92 19.34 MWD 1308.64 13.36 MWD 1338.93 18.77 MWD 1370.55 19.45 MWD 1403.43 12.93 MWD 1444.91 19.61 MWD 1477.51 11.94 MWD 1503.17 19.85 MWD 1535.39 13.49 MWD 1566.52 16.91 MWD 1592.00 10.01 MWD 1624.27 13.07 MWD 1645.66 22.14 MWD 1664.18 13.29 MWD 1682.00 22.59 MWD 1700.85 12.05 MWD 1720.78 20.71 MWD 1751.94 17.81 MWD 1776.19 12.17 MWD 1802.54 12.47 MWD BP Alaska ~ s~R ~ by Baker Hughes INTEQ Survey Report 1NTE~G~a Q Company: BP Amoco Date: 8/30/2006 Tim e: 14:37:18 page: 3 Field: Lisburne Co-ordinate(NE) Reference: WeIL• L5-16, True North Site: Lis DS 05 Vertic al (TVI)) Reference: 9:16 3/2/1.987.00:00 60.0 Well: L5-16 Section (VS) Reference: Well (O.OON,O.OOE,35.OOAzi) WeOpath: L5-16AL2 Survey Cakolation Method: Minimum Curvature Db: OraGe Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10921.15 93.80 9.50 8845.10 8785.10 877.98 1933.58 5975853.97 719353.73 1828.25 17.15 MWD 10951.37 92.88 13.26 8843.34 8783.34 907.55 1939.53 5975883.70 719358.82 1855.89 12.79 MWD 10982.01 94.45 18.15 8841.38 8781.38 936.97 1947.80 5975913.35 719366.24 1884.74 16.73 MWD 11013.06 90.20 20.81 8840.12 8780.12 966.21 1958.15 5975942.87 719375.73 1914.62 16.14 MWD 11043.72 93.62 24.67 8839.10 8779.10 994.46 1969.99 5975971.46 719386.75 1944.56 16.81 MWD 11077.64 94.97 29.15 8836.56 8776.56 1024.62 1985.29 5976002.04 719401.17 1978.04 13.76 MWD 11106.42 91.52 31.97 8834.93 8774.93 1049.35 1999.90 5976027.19 719415.05 2006.68 15.47 MWD 11143.21 90.17 36.97 8834.39 8774.39 1079.67 2020.71 5976058.09 719434.97 2043.45 14.08 MWD 11177.62 86.33 38.45 8835.44 8775.44 1106.88 2041.74 5976085.89 719455.21 2077.80 11.96 MWD 11209.05 81.75 39.44 8838.70 8778.70 1131.18 2061.39 5976110.76 719474.14 2108.97 14.90 MWD 11246.67 75.58 41.79 8846.09 8786.09 1159.17 2085.38 5976139.43 719497.31 2145.66 17.51 MWD 11280.90 79.99 36.31 8853.34 8793.34 1185.14 2106.43 5976166.00 719517.60 2179.01 20.26 MWD 11312.13 83.73 37.07 8857.76 8797.76 1209.93 2124.90 5976191.31 719535.34 2209.91 12.22 MWD 11341.10 87.26 35.48 8860.03 8800.03 1233.21 2141.98 5976215.07 719551.74 2238.78 13.36 MWD 11373.43 91.50 34.82 8860.38 8800.38 1259.64 2160.59 5976242.03 719569.57 2271.10 13.27 MWD 11401.47 95.05 33.92 8858.78 8798.78 1282.74 2176.39 5976265.58 719584.70 2299.09 13.06 MWD 11432.04 99.68 31.02 8854.86 8794.86 1308.30 2192.67 5976291.61 719600.22 2329.36 17.83 MWD 11463.01 97.13 26.79 8850.34 8790.34 1335.12 2207.47 5976318.84 719614.24 2359.82 15.82 MWD 11500.00 97.13 26.79 8845.74 8785.74 1367.88 2224.01 5976352.06 719629.82 2396.14 0.00 MWD • • a ^;. FRANK H. MURKOWSKI GOVERNOR jai ~~,~~ ;~ ~1. ~ :i j ~ ~~ ~~, ~ % .4 ~~'"~~ ,~~ 3 ~~ ~ ,~ ~ J ~ _. , L>•sI[J•a7~ O~ ~ Vr0-7 '', 333 W. 7"' AVENUE, SUITE 100 CO1~T5ERQA`rIOAT CO1rII-'IISSIOI~T 1 r p ONES 907) 279-1433501-3539 Greg Sarber FAx c9a~ 276-75x2 CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-16AL2 BP Exploration (Alaska) Inc. Permit No: 206-085 Surface Location: 1788' FSL, 19' FWL, SEC. O1, T11N, R15E, UM Bottomhole Location: 3466' FSL, 2004' FWL, SEC. O1, T11N, R15E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. Due to your requested bottom hole location change, the August 23, 2006 approved permit to drill for PBU L5-16AL2 is cancelled .and superseded by this permit. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness required test, contact the Commission's petroleum field inspector at (907~~5 -3607 (pager). DATED this~~day of August, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. --- RECEIVED v~G~ ~° ZDO~ STATE OF ALASKA ~~ ~ ~p AU ~ ~ /~~~IL AND GAS CONSERVATION COMM~N ~~ ~'ERMIT TO DRILL Alaska Oil & Gas Cons. Cpmrrtissio 20 AAC 25.005 08/28/06: Revised, Change BHL 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. 71FE'll Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L5-16AL2 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11752 TVD 8800ss 12. Field /Pool(s): Prudhoe Bay Field / Lisburne 4a. Location of Well (Governmental Section): Surface: 19' FWL 1788' FSL 01 T11N R15E UM SEC 7. Property Designation: ADL 028320 Pool , , , , , . Top of Productive Horizon: 1245' FSL, 1005' FWL, SEC. 01, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 21, 2006 Total Depth: 3466' FSL, 2004' FWL, SEC. 01, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6320' 4b. Location of Well (State Base Plane Coordinates): Surface: x-717447 y-5974920 Zone-ASP4 10. KB Elevation (Height above GL): 60 feet 15. Distance to Nearest We11 Within Pool: 2850' 16. Deviated Wells: Kickoff Depth: gg37 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3184 Surface: 2294 18. Casin Pr ram: S fi tio ns Ta '- Settin De th - Bo uan ~ of Cement c.f. ors s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10875 Total Depth TVD (ft): gg75 Plugs (measured): None Effective Depth MD (ft): 10875 Effective Depth TVD (ft): 8975 Junk (measured): None 'Casing Length ize Cement Volume MD N Conductor /Structural 120' 2 1800# Poleset 120' 120' Surface 4006' 10-3/4" 1300 sx AS III 325 sx Class'G' 4006' 3998' Intermediate Production 9559' 7- /8" 425 sx Class'G' S 9' 92 ' Liner Scab Liner 403' 4-1/2" 97 sx Class'G' 8803' - 9206 8603' - 8974' Perforation Depth MD (ft): Open Hole Completion for L5-16A & L5-16AL1 Perforation Depth TVD (ft): Open Hole Completion 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 foregoing i true and correct. Contact Greg Sarber, 56a-4330 Printed Name Gr~ artier Title CT Drilling Engineer e' ^~ Prepared By Name/Number: Si nature Phone 564-4330 Date C~ " 2 Terrie Hubble, 56a-4628 Commission Use Onl Permit To Drill Number: 206-085 API Number: 50-029-21700-61-00 Permit p val See cover letter for Dat : other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, ydrates, or gas contained shales: ;~ _ Samples Req'd: ^ Yes ~ o Mud Log Req'd: ^ Yes ~No ~ 'C'~~ 3~ ~ ~ t~ 3 S ~ v ~ LLr . HZS Measures: Yes Directional Survey Req'd: Yes ^ No °~'wvsu.au-~ f o 2oh-~c zs, 033 C?', u~,~.d~ ~la~.~ "vr~,~ ~~~~5 ~tr~e ap~o~ved. Ifs 0~ APPROVED BY THE COMMISSION Date .,~/ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~/~ ~~~ Submit In Duplicate GR1G1 • • BP L5-16A, AL1, AL2 UBCTD Sidetrack Revision Extending Bottom Hole Location of L5-16AL2 Discussion of Operations: Well L5-16 is the 2"d of two planned underbalanced CTD, thru tubing sidetrack wells planned for the summer of 2006. L5-16 was originally drilled in March of 1987, and completed in zones 4,5, and 6. It has produced at total of 1.53 MMBO since it was originally brought on line in 1987. Currently the well is cycling between 400-500 BOPD. The well is typically on line for approximately 5 days until it reaches MGOR of 30,000 SCF/STB. The well is shut in for approximately 20 days. The cycle has been repeating for the last several years. No outstanding integrity issues exist with the parent wellbore. Extensive stimulation work has been performed on this well and there is little opportunity for further well work. Nordic 2 rigged up on L5-16 on May 12, 2006, and successfully completed a workover in preparation for the CTD UBD sidetrack. That work was completed under Sundry Approval 306-120. The sidetracks, L5-16A, L5-16A L1, and L5-16A L2 will kick off from separate windows milled from mechanical whipstocks set in Lisburne Zone 4. Targets for the 3 laterals are in zone 4, 5, and 6. If real time well testing does not indicate that the wells have encountered fracturing or high productivity rock, an open hole sidetrack in a different azimuthal direction will be considered, but will not be permitted at this time due to uncertainty over the alternate well path. If an open hole sidetrack of L5-16A proves to be needed, then a Permit application for an additional lateral will be submitted at that time. This is the 2"d of 2 CTD underbalanced wells planned for the Lisburne field this summer. Extensive planning for success has been made, and is ongoing. Blade Energy Partners, which is a consulting firm specializing in UBD has been engaged to assist in project planning, personnel training, and on side assistance during the drilling phase of the project. Well control equipment has been designed specifically for the planned operation and procedures have been written to cover each aspect of the operation. There has been HSE and operational training conducted for the town and field staff using a UBD simulator. All relevant contractors, crew and engineering staff have completed this training. HAZid and HAZop procedures have been completed and overall planning has been Peer reviewed by operating partners and outside experts with specialization in coil tubing and underbalanced drilling operations. This underbalanced coil tubing drilling operation will use diesel as the power fluid and gas lift to achieve an underbalance of 200-400 psi while drilling. Return fluids will flow to an on site separator supplied by ASRC. The fluids will be separated and measured, then flowed to the Lisburne Production Center (LPC) at about 600 psi line pressure. There will be no flaring or compression involved in the project. The BOP stack drawing is significantly different than a standard CTD rig up, and is attached. This stack incorporates 6 BOP rams, an annular preventor, 2 flow spools, 2 swab valves, and a master valve. The UBD flow spool is located below double swab valves such that produced fluids do not flow through the upper four rams. An ESD valve on the outlet of the UBD flow spool along with double rams (Shear/seal and 2" pipe/slip • • combination) located below the UBD flow spool provide emergency shut in capability in the event of a flow line leak. Equipment and procedures for pressure deploying/undeploying the drilling BHA have been used successfully on the managed pressure drilling campaigns in the Kuparuk field in the past few years, and have been refined for the UBD process at Lisburne. A tubing retrievable SSSV has been installed. during the workover specifically to provide additional pressure control capability. The attached drawings describe the BOP stack, the P & ID of the full process spread and a flow diagram that includes all surface equipment. Summary of Underbalanced Drilling and Completion Operations: 1. Move rig over well from L5-28. 2. Rig up 2" CTE, UBCTD Stack and BOPE. PT BOPE. 3. Mill L5-16A window with 2% KCL and biozan sweeps. (Top of window at 9100' MD, 8817' SS) 4. Drill L5-16A lateral using diesel/lift gas to achieve underbalance. 5. TD lateral and flow test well for 6 hours. 6. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A. (Top of window at 9040' MD, 8761' SS) 7. Mill L5-16A L1 window with 2% KCL, and biozan sweeps. 8. Drill L5-16A L1 lateral using diesel/lift gas to achieve underbalance. 9. TD L1 lateral and flow test well for 6 hours. 10. Recover whipstock tray, and PXX plug. Set guidestock in L5-16A L1 lateral packer. 11. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A L1. (Top of window at 8923' MD, 8653' SS) 12. Mill L5-16A L2 window with 2% KCL, and biozan sweeps. 13. Drill L5-16A L2 lateral using diesel/lift gas to achieve underbalance. 14. TD L2 lateral and flow test well for 6 hours. 15. Recover whipstock tray and PXX plug from L2 whipstock. Install hollow guidestock into L2 packer. 16. Set BPV. RD and move off well. Post RWO Status: • L5-16 has been worked over. The original perforations have been successful squeezed off. A 4-1/2" scab liner has been run and cemented. The production tubing has been replaced with new 4-1/2" L-80 tubing. A gas lift design has been run and the well is ready for the drilling phase of operations. Drilling Status • The rig has moved onto L5-16 and successfully completed the L5-16A lateral drilling in an underbalanced mode using a diesel as the power fluid as shown in the original permit to drill application. • The rig has milled the window and completed the L5-16AL1 lateral drilling in an underbalanced mode using 2% KCL water as the power fluid. • The rig has milled the window and drilled the L5-16AL2 lateral to its permited TD of 10538' using 2% KCL as the power fluid and drilling in an underbalanced mode. During the drilling of this lateral we have had better than expected • • results. We have reached the permitted TD, and are continuing to drill with good weight transfer and in a good porosity fairway. We have crossed a fault zone at 10200', and are currently drilling in a region that exhibits higher formation pressure. It is our objective to maximize the length of the lateral in the higher pressure zone. For this reason it will be necessary to drill past our permitted TD by more than 500'. We would like to extend the bottom hole (ocation on this well. Anew directional plan showing that there are no collision risks with other wells is attached to this application. Mud Program: • The window will be milled with 2% KCL with'/z ppb Biozan. Sweeps will be 2 ppb Biozan. The 3 lateral sections will be drilled with diesel as the power fluid with gas lift used to underbalance the well. Viscosified mineral oil sweeps will be used for hole cleaning during drilling. Due to lack of diesel availability currently on the North Slope, the drilling fluid for the L5-16AL2 lateral will be 2% KCL water with viscosified mineral oil as sweeps. Kill Weight Fluid. 2% KCL will be in the rig pits on location. BHP with 2% KCL will be 3864 psi. Measured BHP is 3184 psi. 2% KCL will overbalance the formation pressure by 680 psi. OH/Tubing volume = 153 bbls. Disposal: • During the drilling phase all fluid and gas returns from the well will be pumped down the L5 pad production line and sent to the Lisburne Production Center for recycling. • All drilling and completion waste fluids and any other Class II wastes will go to Grind and Inject, or Pad 3. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • None. All laterals will be completed open hole. Well Control: • The BOP schematic, P & ID drawing, and fluid flow diagrams are attached. • Pipe rams, blind rams and the CT pack-ff will be pressure tested to 400 psi and 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional: • See attached directional plans. Maximum planned hole angle is approximately ~97 deg. • Magnetic and inclination surveys will be taken every 30'. No Gyro survey will be run. Logging: • An MWD Gamma Ray log will be run of the entire open hole section. Hazards mitigated through training, procedures, and UBD equipment: • Hydrogen Sulfide -Maximum H2S measured on L5 pad is 600 ppm (3-27-92) on L5- 12. L5-16 has recorded H2S at 50 ppm on 1-9-2006, and the lift gas has an H2S concentration of 60 ppm. • Maximum BHP is expected to be 3184 psi @ 8900' SS (6.9 ppg). Maximum anticipated surface pressure with a full column of gas to surface is 2294 psi. • • • A combustible power fluid will be used. (Diesel) Flash Point 100 deg F o Fire, Environmental, Health (exposure), impact on other equipment (elastomers) • A combustible artificial lift fluid will be used. (Natural Gas) o Fire, HZS, Health (exposure) • Produced Fluids will be present in returned fluids. (Oil and Natural Gas) o Fire, Environmental, HZS, Health (exposure), impact on other equipment (elastomers) • Pressure - 650 to 1000 psi on surface. o Leaks, loss of containment, pipe whip • SIMOPS -Drilling/Production. • New Procedures for most people involved -Human Error. • Additional Equipment -Escape areas, slips and trips. • Poor Hole Cleaning -Stuck Pipe • Hole Instability - Mudstones Reservoir Pressure: • Bottom Hole Pressure was measured at 3184 psi at 8900' TVDSS (6.9 ppg) • Maximum surface pressure with gas (0.1 psi/ft) to surface is 2294 psi. BP Drilling Contacts: • Greg Sarber 564-4330, 242-8000 cell • Mark Johnson 564-5666, 240-8034 cell Attachment List Updated schematic L5-16A L2 directional plan (Showing Extended BHL) L5-16R' AL1, AL1-PB1, AL2 _, stiFET~r NoT~:CJ~TI~U res (PPI~~iC UBD Sidetrack Uadate 8-28-2006 10 ~ 3.91' 10-3f~' C~,15.5N, LSO, ~ - 9953' I 4 1/2" 12.6#, L-80, IBT-Mod. Tbg. 5 GLM's Deepest GLV 8380 MD (8155ss) 4 1/2" x 7 5/8" Baker Packer 8460 MD 4 1/2" X Nipple Liner Hanger/Packer 8800 MD, 8540ss - L5-16AL2: 8937 MD, 8666ss L5-16AL1: 9060 MD, 8761 ss L5-16A: 9100 MD, 8817ss Revised TD=11752' MD, 8800' TVDss L5-16AL2 (In Progress) OH Sidetrack @ 9260' L5-16AL1 (Complete) • AL1-PB1 (Complete) L5-16A Zone 4 (Complete) ~ 4 1/2" 12.6#, L-80, IBT-Mod 9475` MD P 8 TO '~ 4 ~ 'i' 1~8'~,8.7N, LSO, ~-6875' I by BP Alaska ~~$ Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Date: 8/28/2006 Time: 09:47:08 Page: I Field: Lisbume Co-ordinate(NE) Referenee: Wetl: L5-16, True North Site: Lis OS 05 Vertical (TVD) Reference: 9:16 3/2/1987`00:00 60.0 Well: L5-16 Section (VS) Reference: Well (O.OON,O.OOE,1 O.OOAzi) Wellpat6: Plan 3, L5-16AL2 Survey Calculation: Methods Minimum Curvature ` Db: OraGe Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1 927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Lis DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Fasting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: L5-16 Slot Name: 16 L5-16 Well Position: +N!-S 4778.96 ft Northin g: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Fasting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, L5-16AL2 Drilled From: L5-i6AL2 Tie-on Depth: 11077.64 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/28/2006 Declination: 24.64 deg Field Strength: 57627 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 10.00 Plan: Plan #3 Date Composed: 8/28/2006 Extend TD to Tgt recd frm Greg S. on OS-28-2006 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude ----> <--- Longitude .-- Name Description TVD +N/-S +E/-W Northing: Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft R L5-16AL2 Extended TD Tgt 8860.00 1678.89 1985.10 5976656.00 719382.01 70 20 19.263 N 148 13 10.846 W Annotation MD TVD ft ft 11077.64 8836.56 TIP 11508.00 8838.16 2 11752.00 8860.01 TD Plan Section Information MD Iocl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg: ft ft tt deg/100ft deg/100ft deg/100tt deg 11077.64 94.97 29.15 8836.56 1024.62 1985.29 0.00 0.00 0.00 0.00 11508.00 84.63 338.48 8838.16 1439.63 2013.04 12.00 -2.40 - 11.77 259.13 11752.00 85.32 7.87 8860.01 1678.29 1984.51 12.00 0.28 12.04 90.00 • by BP Alaska ~ Baker Hughes INTEQ Planning Report LNTE Q Company: BP Amoco Date: 8/28/2006 Time: 09::47:08 Page: 2 Field: Lisburne Co-ordinate(NE) Reference: Well: L5-16, True North Site: ' Lis bS 05 Vertical (TUD)Reference: 9:16 3/2/1987 00:00 60.0. Well: L5-16 Section (VS) Reference: Well (O.OON,O.OOE,IO.OOAz i) Wellpat6: Plan 3, L5-1 liAL2 Snrvey Calculation Metbod: 'Minimum Curvature Db: Orade Survey MD Incl Azim Sys TVD N/S E/W 114apN MapE DLS VS TFO Tool ft deg deg ft R ft tT ft deg/100ft ft deg. 11077.64 94.97 29.15 8776.56 1024.62 1985.29 5976002.D4 719401.17 D.00 1353.79 0.00 MWD 11100.00 94.46 26.51 8774.72 1044.32 1995.69 5976022.04 719410.99 12.00 1375.01 259.13 MWD 11125.00 93.88 23.56 8772.90 1066.91 2006.24 5976044.92 719420.88 12.00 1399.09 258.91 MWD 11150.00 93.28 20.61 8771.34 1090.03 2015.62 5976068.30 719429.59 12.00 1423.48 258.70 MWD 11175.00 92.68 17.67 8770.04 1113.62 2023.81 5976092.11 719437.08 12.00 1448.13 258.51 MWD 11200.00 92.07 14.73 8769.00 1137.60 2030.77 5976116.29 719443.35 12.00 1472.96 258.36 MWD 11225.00 91.46 11.79 8768.23 1161.92 2036.50 5976140.76 719448.37 12.00 1497.90 258.24 MWD 11250.00 90.84 8.85 8767.73 1186.51 2040.98 5976165.47 719452.13 12.00 1522.89 258.15 MWD 11275.00 90.22 5.92 8767.50 1211.30 2044.19 5976190.34 719454.63 12.00 1547.86 258.09 MWD 11300.00 89.60 2.98 8767.54 1236.22 2046.13 5976215.30 719455.84 12.00 1572.74 258.06 MWD 11325.00 88.98 0.05 8767.85 1261.20 2046.79 5976240.30 719455.78 12.00 1597.47 258.07 MWD 11350.00 88.36 357.11 8768.43 1286.19 2046.17 5976265.25 719454.43 12.00 1621.96 258.10 MWD 11375.00 87.75 354.17 8769.27 1311.10 2044.27 5976290.09 719451.81 12.00 1646.16 258.17 MWD 11400.00 87.15 351.23 8770.39 1335.87 2041.10 5976314.76 719447.92 12.00 1670.01 258.27 MWD 11425.00 86.55 348.29 8771.76 1360.43 2036.66 5976339.18 719442.78 12.00 1693.42 258.40 MWD 11450.00 85.96 345.34 8773.40 1384.71 2030.97 5976363.29 719436.38 12.00 1716.35 258.56 MWD 11475.00 85.38 342.39 8775.29 1408.66 2024.04 5976387.02 719428.77 12.00 1738.73 258.76 MWD 11500.00 84.81 339.43 8777.42 1432.19 2015.90 5976410.31 719419.94 12.00 1760.49 258.98 MWD 11508.00 84.63 338.48 8778.16 1439.63 2013.04 5976417.66 719416.87 12.00 1767.32 259.23 MWD 11525.00 84.63 340.53 8779.75 1455.48 2007.11 5976433.33 719410.48 12.00 1781.90 90.00 MWD 11550.00 84.65 343.54 8782.08 1479.16 1999.44 5976456.78 719402.13 12.00 1803.88 89.81 MWD 11575.00 84.68 346.56 8784.41 1503.20 1993.01 5976480.62 719395.01 12.00 1826.45 89.53 MWD 11600.00 84.73 349.57 8786.71 1527.56 1987.87 5976504.82 719389.16 12.00 1849.54 89.25 MWD 11625.00 84.79 352.58 8789.00 1552.15 1984.01 5976529.28 719384.59 12.00 1873.09 88.97 MWD 11650.00 84.87 355.59 8791.25 1576.91 1981.44 5976553.96 719381.31 12.00 1897.03 88.69 MWD 11675.00 84.96 358.60 8793.47 1601.78 1980.18 5976578.78 719379.33 12.00 1921.30 88.42 MWD 11700.00 85.06 1.61 8795.64 1626.68 1980.23 5976603.67 719378.65 12.00 1945.83 88,16 MWD 11725.00 85.18 4.62 8797.77 1651.55 1981.58 5976628.57 719379.28 12.00 1970.56 87,89 MWD 11752.00 85.32 7.87 8800.01 1678.29 1984.51 5976655.39 719381.43 12.00 1997.40 87.64 Casing • • Q ~ t ~t~ ~ § ~'~' ~ u .t ~ ~~' r !fill ti~ I { : (( l_ 1 ~ l~ a 's3E - II tt~ r ~l t gS 1 k~~ ~ s~ ~ ~, p2 w :s ~ ~~~lll ~~- r ~ , ttli trtt t r T ~ f ~ 1. ~1 '~l ttf tt ~}~`1 rt *{r ft$ j ~ [ fit ~ i , ` I.' trr l ~ ( 1~' I~~ Its' i`{F, t 'i [r~ tt f1 r'~r ~~f11 1f ~ '.1 { ~i_l ~ ~4 ~ f ~~ 'tl 1 I 1~ ~ tr f I 111 ,~I1 ,~, ~~ r rill t1~ ~11 } t1I~ 1 f ~?~~l ,~ ~~ ~{, ~tE1 ~r~ i~, tl{{~ t~+ ~ ~ I~Ir i`I ~tl~~ 11 I, f't(1 I t I f I~~ E4l ~Gk( rr.~ lt{t it ~ I ~~ ~~ Ij ~, f (' I ,l t{, }~`~ ~ ~} 1I ~rl-( rt ~t11 la+r I;it I It~ l ' ' ; { f r r ~lEi~ u+[ i~+} i~ta ~L1 #~t-i + ~~J-- ' ,~ r F~~~ F {-F ~ ~.rl-( ~~-kt , , t rtlt ~+ ~ r t r r J ~'r ~Jr [t[ r n ~itr f ~C ~~ ,I f ~ ~. , i E1 4~ 1 ~ ~ 1r~ lfrt ~ Ii. 1 ~ ~ t {l rj *trr , r t#t-r ,1 , ~ ~ (t1.I1 {a ItII(l~r~ ".fl-1 ilt lli~ll~t +r~ .r[ . r ,a,-- rI{-r tnt ~,-r , r ij-~ ~ ~1, f •t rr +tit t«tf [i~ 111t 4 F I r (,I 1 r~-~- 1 + ~ ~~ + 4 Y G~ 'Itl -rt ~l ,~;;-t `~ I f ' , allt t l,rl r F~FI , f1, lt_'' ! ~ I tl±r Yt , ~r,kF „ ~~ ! l, F , I(~ E ;i~ Gf~ 11 (i t( i '- i ~{1-!~ i-t 1l I ' t ' tl t11 1 i1 ~~ f~ rlr 1} ~t 1 1 tt I ! ( ~l~ ~ r, ~~ t titt [ail-t l}r_t t 1 } ~t,' i t;! It~l~ ~I!tP,~l>~ t ~{fti~ i ti t I' !tt i~?Z~lril r~r r(Ir~ ~l irt ilf~ ~ ~jfii ltltt ~ 1 lltf lull , T f lll~ Ill G liil ('r',,I ~ ~~ ~l- fl ~ _ 11 f i~ 1 lrl ~~~ ~ I 1 i' ~~ ~ ~ I 1~~ ~~ja ~ k ~f I ~i il ~f C~;~~ {1 [~~, ~ f,l rt[I Tl~t t t ,t tf, li l i ,t ~ . 1 ~ ~ r~ f 11 ~ ~( I ~~ ~ ' (, ~l IEt~ E,~r , ,r, ~~~ r ;; 1 t 1 ~~l ~~ ~ _~;, a .~ ~`-- ~ , ..1 ~ 1~~ '~ tilt . a. . 9. ~. A ~. _ ~ ~, tea,. A. a 1 • i [111 (~14ww('I4v+o5 M ~ ~~ It ~ ~ 's h's F ( ~E~~ t~r~ Irf$ e ~ J{ T} 9 ~ Y 8Sa ~ z ~ -~. ~t I ~}-t ~t.f[ tQ ~ a ~' 8 ; ssa o } 1 r 1 r~ Fl i 8 ~~ 8 Q '"~ ~° ~~ ~ ~.t ~ -~ (~ ,~ .141 11 ~1~ y ei8a ~ ~ :a: ~ " ~, - 7 s~ a; $ S ~e'DrE ° ?a? a ~'ri~ '1(;:.1111 ~ , r, f {. j Q ~ ~m ~ c ~ 3~i'A a~ ~ 3: 3 J 1 S ~ ~Ee ~ '~~ m a~ °'~ 4~ 9 ~grg~ ~ _ 'E{1 ~ f$ ~ 5~~8- ~ I ~~ s a,~ _ ~ . _ _ [1 y xsa -°_ (~~ §8 ~g 0 8 a r~= ` 8 by BP Alaska Anticollision Report ~.r INTEQ Company: BP Amoco Date: 8/28/2006 Time: 09:42:02 Page:: 1 Field: Lisburne Reference$ite: Lis DS 05 Co-ordinate(NE) Reference: WeIL•L5-16, True North Reference We14 L5-16 Vertical (TVD) Reference: 9 : 163!2!1987 00:00 60.0 Reference Wellpathc Plan 3, LS-16AL2 Db: Orate GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Inte rval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 11077.64 to 11752.00 ft Scan Method: Trav Cylinder North Maximam Radius: 5000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/28/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 60.00 8921.35 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 8921.35 11077.64 MWD (8935.80-1 1077.64) (6) MWD MWD -Standard 11077.64 11752.00 Planned: Plan #3 V1 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 11752.00 8860.01 3.500 4.125 Casing Summary <------- -Offset Wellpath - Reference Offset ' Ctr-Ctr No-Go Allowable Site Weil Wellpath MD MD .Distance Area Deviation Warning: ft ft ft ft' ft L5-16,PIan 3, L5-16AL2 11752.00 11752.00 0.00 129.03 -129.03 FAIL: Major Risk Lis DS 05 L5-16 L5-16AL2 V3 11077.64 11077.64 0.00 131.03 -131.03 FAIL: Major Risk Lis DS 05 L5-24 L5-24 V1 11475.00 8450.00 1803.09 116.39 1686.70 Pass: Major Risk Lis DS 05 L5-26 L5-26PB1 V1 11742.59 7850.00 1993.37 96.74 1896.62 Pass: Major Risk Lis DS 05 L5-26 L5-26PB2 V1 11742.59 7850.00 1993.37 96.74 1896.62 Pass: Major Risk Lis DS 05 L5-26 L5-26PB3 V1 11742.59 7850.00 1993.37 96.74 1896.62 Pass: Major Risk Lis DS 05 L5-32 L5-32 V1 11752.00 7750.00 1887.18 214.97 1672.21 Pass: Major Risk Site: Well: Rule Assigned: Major Risk Wellpath: L5-16,PIan 3, L5-16AL2,PIan #3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MI) TVD Ref Offset- TFO+AZI TFO-HS Casing/HSUistance Area Deviatjou Warning ft $ ft ft ft ft deg deg in ft ft ft 11077.64 8836.56 11077.64 8836.56 24.40 0.00 29.15 0.00 4.125 0.00 106.34 -106.34 FAIL 11100.00 8834.72 11100.00 8834.72 24.54 0.18 26.51 0.00 4.125 0.00 106.90 -106.90 FAIL 11150.00 8831.34 11150.00 8831.34 24.70 0.98 20.61 0.00 4.125 0.00 107.96 -107.96 FAIL 11200.00 8829.00 11200.00 8829.00 24.67 1.77 14.73 0.00 4.125 0.00 108.44 -108.44 FAIL 11250.00 8827.73 11250.00 8827.73 24.45 2.54 8.85 0.00 4.125 0.00 108.35 -108.35 FAIL 11300.00 8827.54 11300.00 8827.54 24.04 3.29 2.98 0.00 4.125 0.00 107.70 -107.70 FAIL 11350.00 8828.43 11350.00 8828.43 23.46 4.00 357.11 0.00 4.125 0.00 106.52 -106.52 FAIL 11400.00 8830.39 11400.00 8830.39 22.71 4.68 351.23 0.00 4.125 0.00 104.84 -104.84 FAIL 11450.00 8833.40 11450.00 8833.40 21.82 5.31 345.34 0.00 4.125 0.00 102.73 -102.73 FAIL 11500.00 8837.42 11500.00 8837.42 20.81 5.90 339.43 0.00 4.125 0.00 100.26 -100.26 FAIL 11550.00 8842.08 11550.00 8842.08 22.46 6.57 343.54 0.00 4.125 0.00 105.68 -105.68 FAIL 11600.00 8846.71 11600.00 8846.71 24.51 7.18 349.57 0.00 4.125 0.00 112.29 -112.29 FAIL 11650.00 8851.25 11650.00 8851.25 26.40 7.75 355.59 0.00 4.125 0.00 118.44 -118.44 FAIL 11700.00 8855.64 11700.00 8855.64 28.09 8.26 1.61 0.00 4.125 0.00 124.00 -124.00 FAIL 11750.00 8859.84 11750.00 8859.84 29.54 8.69 7.63 0.00 4.125 0.00 128.85 -128.85 FAIL 11752.00 8860.01 11752.00 8860.01 29.59 8.70 7.87 0.00 4.125 0.00 129.03 -129.03 FAIL Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16AL2 V3 inter-Site Error: 0.00 ft Reference Otfset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref .Offset TFO+AZI TFO-HS CasinglHSflistance Area Deviatiou :Warning • i by BP Alaska Anticollision Report ~.r sus 1NTEQ Company: BP Amoco Date: 8/2812006. Time: 09:42:02 Page:: 2 Field• L isburne Reference Site: Lis DS 05 Co-ordinate(NE) Reference. WeIL• L5-16, True North Reference Well: i5-16 Vertical (1'VD) Reference: 9:16 3/2f1987 00:00 60.0. Reference Wellpath: Plan 3, L5-1 6AL2 Db: Oraole Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16AL2 V3 Inter-Site Error: 0.00 ft ltetereuce Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD- TVD MD TVD Ref Offset TFO+AZI TFO-HS` Casing/H3listance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11077.64 8836.56 11077.64 8836. 56 24.40 24.40 29.15 0.00 0.00 131.03 -131.03 FAIL Site: Lis DS 05 Well: L5-24 Rule Assigned: Major Ris k Wellpath: L5-24 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go - Allowable MD TVD NID TV D Ref Offset TFO+AZI TFO-HS Casing/IISUistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11093.94 8835.20 6050.00 5511. 27 24.50 16.09 19.26 352.04 3358.28 72.30 3285.97 Pass 11112.67 8833.77 6100.00 5547. 15 24.60 16.28 17.13 352.11 3317.98 72.87 3245.11 Pass 11130.82 8832.52 6150.00 5582. 88 24.66 16.47 15.10 352.23 3277.92 73.44 3204.48 Pass 11148.38 8831.44 6200.00 5618. 41 24.70 16.65 13.20 352.40 3238.17 74.03 3164.14 Pass 11165.31 8830.52 6250.00 5653. 80 24.71 16.84 11.42 352.61 3198.70 74.64 3124.06 Pass 11181.53 8829.75 6300.00 5689. 11 24.70 17.01 9.76 352.86 3159.46 75.27 3084.19 Pass 11196.92 8829.12 6350.00 5724. 51 24.68 17.05 8.24 353.16 3120.32 75.70 3044.62 Pass 11211.39 8828.62 6400.00 5760. 17 24.63 17.09 6.87 353.49 3081.13 76.15 3004.98 Pass 11225.16 8828.23 6450.00 5795. 93 24.59 17.09 5.64 353.85 3042.07 76.58 2965.49 Pass 11238.40 8827.93 6500.00 5831. 60 24.51 17.08 4.46 354.25 3003.33 77.04 2926.29 Pass 11251.08 8827.72 6550.00 5867. 26 24.44 17.07 3.40 354.68 2964.85 77.51 2887.33 Pass 11263.14 8827.58 6600.00 5902. 99 24.36 17.06 2.45 355.14 2926.55 78.01 2848.54 Pass 11274.61 8827.50 6650.00 5938. 81 24.27 16.94 1.59 355.62 2888.44 78.34 2810.10 Pass 11285.54 8827.48 6700.00 5974. 73 24.18 16.82 0.82 356.14 2850.53 78.69 2771.84 Pass 11295.93 8827.51 6750.00 6010. 75 24.08 16.71 0.14 356.68 2812.83 79.08 2733.75 Pass 11305.80 8827.59 6800.00 6046. 88 23.98 16.61 -0.46 357.24 2775.34 79.49 2695.86 Pass 11315.16 8827.69 6850.00 6083. 05 23.88 16.60 359.04 357.84 2738.14 80.04 2658.11 Pass 11325.00 8827.85 6900.00 6119. 20 23.77 16.60 358.51 358.46 2701.30 80.62 2620.68 Pass 11332.39 8827.99 6950.00 6155. 35 23.68 16.65 358.29 359.11 2664.84 81.29 2583.55 Pass 11340.40 8828.17 7000.00 6191. 51 23.58 16.70 358.03 -0.21 2628.76 82.00 2546.77 Pass 11350.00 8828.43 7050.00 6227. 74 23.46 16.65 357.61 0.50 2593.02 82.64 2510.38 Pass 11355.30 8828.58 7100.00 6264. 12 23.39 16.63 357.70 1.22 2557.55 83.29 2474.27 Pass 11362.23 8828.81 7150.00 6300. 63 23.29 16.56 357.64 1.97 2522.40 83.93 2438.46 Pass 11368.85 8829.04 7200.00 6337. 27 23.19 16.49 357.63 2.74 2487.57 84.61 2402.97 Pass 11375.00 8829.27 7250.00 6374. 04 23.11 16.42 357.70 3.53 2453.10 85.33 2367.77 Pass 11381.24 8829.53 7300.00 6410. 93 23.01 16.36 357.79 4.35 2418.99 86.08 2332.91 Pass 11387.04 8829.78 7350.00 6447. 86 22.92 16.43 357.95 5.20 2385.37 87.10 2298.27 Pass 11392.62 8830.03 7400.00 6484 .75 22.83 16.51 358.17 6.07 2352.34 88.16 2264.18 Pass 11400.00 8830.39 7450.00 6521 .68 22.71 16.58 358.22 6.99 2319.83 89.28 2230.55 Pass 11400.00 8830.39 7500.00 6558 .76 22.71 16.70 359.11 7.88 2287.77 90.43 2197.34 Pass 11408.02 8830.80 7550.00 6595 .91 22.58 16.64 359.14 8.85 2256.23 91.45 2164.78 Pass 11412.76 8831.05 7600.00 6633 .08 22.49 16.61 -0.44 9.84 2225.32 92.49 2132.83 Pass 11417.32 8831.31 7650.00 6670 .27 22.42 16.61 0.04 10.85 2195.07 93.64 2101.43 Pass 11425.00 8831.76 7700.00 6707 .50 22.28 16.59 0.19 11.91 2165.48 94.82 2070.66 Pass 11425.00 8831.76 7750.00 6744 .75 22.28 16.63 1.24 12.95 2136.58 96.08 2040.50 Pass 11429.99 8832.07 7800.00 6782 .03 22.19 16.64 1.75 14.05 2108.43 97.36 2011.06 Pass 11433.89 8832.31 7850.00 6819 .42 22.12 16.64 2.42 15.18 2080.93 98.67 1982.26 Pass 11437.60 8832.55 7900.00 6857 .01 22.05 16.64 3.14 16.34 2054.01 100.02 1953.99 Pass 11441.18 8832.79 7950.00 6894 .82 21.99 16.64 3.90 17.52 2027.66 101.40 1926.26 Pass 11444.67 8833.03 8000.00 6932 .86 21.92 16.64 4.69 18.73 2001.89 102.81 1899.08 Pass 11450.00 8833.40 8050.00 6971 .08 21.82 16.63 5.32 19.98 1976.78 104.21 1872.57 Pass 11450.00 8833.40 8100.00 7009 .43 21.82 16.64 6.55 21.21 1952.41 105.72 1846.70 Pass 11450.00 8833.40 8150.00 7047 .98 21.82 16.67 7.81 22.47 1928.77 107.27 1821.50 Pass 11457.87 8833.96 8200.00 7086 .77 21.67 16.64 8.24 23.83 1905.74 108.68 1797.07 Pass • by BP Alaska Anticollision Report • ~.r s ~c ins INTEQ Company: BP Amoco Date: 8!28/2006 Time: 09:42: 02 Page; 3 Field: Lisburne Reference Site:- 1_is DS 05 Co-ordinate(NE) Reference: Wetl:15- 16, True North Reference Well: L5-16 Vertical (TVD) Reference: 9:16 3/2/1987 00:00 60.0 Reference Wellpath: Pl an 3, L5-16AL2 Db: Orate Site: Lis DS 05 Well: L5-24 Rule Assigned: Major Risk Wellpath: L5-24 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istaece Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11460.99 8834.20 8250.00 7125.73 21.61 16.65 9.22 25.18 1883.52 110.21 1773.32 Pass 11464.02 8834.42 8300.00 7164.78 21.55 16.66 10.24 26.55 1862.23 111.75 1750.48 Pass 11466.97 8834.65 8350.00 7204.00 21.49 16.68 11.29 27.96 1841.77 113.32 1728.46 Pass 11475.00 8835.29 8400.00 7243.48 21.33 16.67 11.82 29.43 1822.07 114.73 1707.35 Pass 11475.00 8835.29 8450.00 7283.23 21.33 16.72 13.25 30.86 1803.09 116.39 1686.70 Pass Site: Lis DS 05 Well: L5-26 Rule Assigned: Major Risk Wellpath: L5-26P61 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ret Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11525.00 8839.75 6950.00 6443.64 21.39 15.50 317.73 337.20 30.000 2606.27 88.56 2517.71 Pass 11535.98 8840.78 7000.00 6470.28 21.86 15.72 319.48 337.62 30.000 2569.39 89.38 2480.01 Pass 11543.87 8841.51 7050.00 6496.56 22.19 15.93 320.90 338.10 30.000 2533.08 89.94 2443.14 Pass 11550.00 8842.08 7100.00 6522.64 22.46 16.10 322.15 338.61 30.000 2497.20 90.50 2406.70 Pass 11560.54 8843.07 7150.00 6548.81 22.90 16.29 323.89 339.08 30.000 2461.53 91.36 2370.17 Pass 11569.32 8843.88 7200.00 6575.05 23.26 16.48 325.45 339.58 30.000 2426.08 92.05 2334.03 Pass 11575.00 8844.41 7250.00 6601.38 23.50 16.64 326.69 340.13 30.000 2390.88 92.45 2298.43 Pass 11588.03 8845.61 7300.00 6627.99 24.03 16.74 328.73 340.60 30.000 2355.85 93.04 2262.81 Pass 11600.00 8846.71 7350.00 6654.99 24.51 16.85 330.65 341.08 30.000 2320.98 93.51 2227.48 Pass 11608.96 8847.54 7400.00 6682.39 24.86 16.94 332.24 341.59 30.000 2286.27 93.74 2192.53 Pass 11620.37 8848.58 7450.00 6710.14 25.30 17.07 334.09 342.06 30.000 2251.76 94.03 2157.73 Pass 11632.55 8849.68 7500.00 6737.97 25.76 17.23 336.02 342.53 30.000 2217.70 94.24 2123.45 Pass 11645.56 8850.85 7550.00 6765.83 26.24 17.40 338.03 342.98 30.000 2184.15 94.46 2089.69 Pass 11659.46 8852.09 7600.00 6793.70 26.73 17.59 340.14 343.41 30.000 2151.13 94.68 2056.44 Pass 11675.00 8853.47 7650.00 6821.59 27.27 17.88 342.42 343.81 30.000 2118.62 95.05 2023.57 Pass 11689.94 8854.77 7700.00 6849.48 27.76 18.19 344.62 344.21 30.000 2086.59 95.38 1991.21 Pass 11706.55 8856.21 7750.00 6877.36 28.29 18.53 346.99 344.58 30.000 2055.04 95.76 1959.28 Pass 11724.12 8857.70 7800.00 6905.25 28.82 18.89 349.45 344.93 30.000 2023.97 96.17 1927.80 Pass 11742.59 8859.24 7850.00 6933.06 29.33 19.29 352.00 345.26 30.000 1993.37 96.74 1896.62 Pass Site: Lis OS 05 Well: L5-26 Rule Assigned: Major Risk Wellpath: L5-26P62 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Azis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casiog/HSilistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11525.00 8839.75 6950.00 6443.64 21.39 15.50 317.73 337.20 30.000 2606.27 88.56 2517.71 Pass 11535.98 8840.78 7000.00 6470.28 21.86 15.72 319.48 337.62 30.000 2569.39 89.38 2480.01 Pass 11543.87 8841.51 7050.00 6496.56 22.19 15.93 320.90 338.10 30.000 2533.08 89.94 2443.14 Pass 11550.00 8842.08 7100.00 6522.64 22.46 16.10 322.15 338.61 30.000 2497.20 90.50 2406.70 Pass 11560.54 8843.07 7150.00 6548.81 22.90 16.29 323.89 339.08 30.000 2461.53 91.36 2370.17 Pass 11569.32 8843.88 7200.00 6575.05 23.26 16.48 325.45 339.58 30.000 2426.08 92.05 2334.03 Pass 11575.00 8844.41 7250.00 6601.38 23.50 16.64 326.69 340.13 30.000 2390.88 92.45 2298.43 Pass 11588.03 8845.61 7300.00 6627.99 24.03 16.74 328.73 340.60 30.000 2355.85 93.04 2262.81 Pass 11600.00 8846.71 7350.00 6654.99 24.51 16.85 330.65 341.08 30.000 2320.98 93.51 2227.48 Pass 11608.96 8847.54 7400.00 6682.39 24.86 16.94 332.24 341.59 30.000 2286.27 93.74 2192.53 Pass 11620.37 8848.58 7450.00 6710.14 25.30 17.07 334.09 342.06 30.000 2251.76 94.03 2157.73 Pass 11632.55 8849.68 7500.00 6737.97 25.76 17.23 336.02 342.53 30.000 2217.70 94.24 2123.45 Pass 11645.56 8850.85 7550.00 6765.83 26.24 17.40 338.03 342.98 30.000 2184.15 94.46 2089.69 Pass 11659.46 8852.09 7600.00 6793.70 26.73 17.59 340.14 343.41 30.000 2151.13 94.68 2056.44 Pass 11675.00 8853.47 7650.00 6821.59 27.27 17.88 342.42 343.81 30.000 2118.62 95.05 2023.57 Pass by BP Alaska Anticollision Report L~ ~.r s ~~s 1NTEQ Company: BP Amoco Date: 8/28/2006 Time: 09:42:02 Page:. 4 Field: Lisburne Reference Site: Lis DS 05 Co-ordiuate(NE) Reference: WeIL' L5-16, True North Reference Well: L5-16 Vertical (TVD) Reference: 9:16 3/2/1987 00:00 60.0 Reference Wellpath: Plen 3, L5-16AL2 Dbe Orate Site: Lis DS 05 Well: L5-26 Rule Assigned: Major Risk Wellpath: L5-26P62 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Cfr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistaoce .Area Deviation Warning ft ft ft' ft ft ft deg deg in ft ft ft 11689.94 8854.77 7700.00 6849.48 27.76 18.19 344.62 344.21 30.000 2086.59 95.38 1991.21 Pass 11706.55 8856.21 7750.00 6877.36 28.29 18.53 346.99 344.58 30.000 2055.04 95.76 1959.28 Pass 11724.12 8857.70 7800.00 6905.25 28.82 18.89 349.45 344.93 30.000 2023.97 96.17 1927.80 Pass 11742.59 8859.24 7850.00 6933.06 29.33 19.29 352.00 345.26 30.000 1993.37 96.74 1896.62 Pass Site: Lis DS 05 Well: L5-26 Rule Assigned: Major Risk Wellpath: L5-26P63 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation 'Warning. ft ft ft ft ft ft deg deg in 8' ft ft 11525.00 8839.75 6950.00 6443.64 21.39 15.50 317.73 337.20 30.000 2606.27 88.56 2517.71 Pass 11535.98 8840.78 7000.00 6470.28 21.86 15.72 319.48 337.62 30.000 2569.39 89.38 2480.01 Pass 11543.87 8841.51 7050.00 6496.56 22.19 15.93 320.90 338.10 30.000 2533.08 89.94 2443.14 Pass 11550.00 8842.08 7100.00 6522.64 22.46 16.10 322.15 338.61 30.000 2497.20 90.50 2406.70 Pass 11560.54 8843.07 7150.00 6548.81 22.90 16.29 323.89 339.08 30.000 2461.53 91.36 2370.17 Pass 11569.32 8843.88 7200.00 6575.05 23.26 16.48 325.45 339.58 30.000 2426.08 92.05 2334.03 Pass 11575.00 8844.41 7250.00 6601.38 23.50 16.64 326.69 340.13 30.000 2390.88 92.45 2298.43 Pass 11588.03 8845.61 7300.00 6627.99 24.03 16.74 328.73 340.60 30.000 2355.85 93.04 2262.81 Pass 11600.00 8846.71 7350.00 6654.99 24.51 16.85 330.65 341.08 30.000 2320.98 93.51 2227.48 Pass 11608.96 8847.54 7400.00 6682.39 24.86 16.94 332.24 341.59 30.000 2286.27 93.74 2192.53 Pass 11620.37 8848.58 7450.00 6710.14 25.30 17.07 334.09 342.06 30.000 2251.76 94.03 2157.73 Pass 11632.55 8849.68 7500.00 6737.97 25.76 17.23 336.02 342.53 30.000 2217.70 94.24 2123.45 Pass 11645.56 8850.85 7550.00 6765.83 26.24 17.40 338.03 342.98 30.000 2184.15 94.46 2089.69 Pass 11659.46 8852.09 7600.00 6793.70 26.73 17.59 340.14 343.41 30.000 2151.13 94.68 2056.44 Pass 11675.00 8853.47 7650.00 6821.59 27.27 17.88 342.42 343.81 30.000 2118.62 95.05 2023.57 Pass 11689.94 8854.77 7700.00 6849.48 27.76 18.19 344.62 344.21 30.000 2086.59 95.38 1991.21 Pass 11706.55 8856.21 7750.00 6877.36 28.29 18.53 346.99 344.58 30.000 2055.04 95.76 1959.28 Pass 11724.12 8857.70 7800.00 6905.25 28.82 18.89 349.45 344.93 30.000 2023.97 96.17 1927.80 Pass 11742.59 8859.24 7850.00 6933.06 29.33 19.29 352.00 345.26 30.000 1993.37 96.74 1896.62 Pass Site: Lis DS 05 Well: L5-32 Rule Assigned: Major Risk Wellpath: L5-32 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aaic Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H3)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11557.72 8842.80 6350.00 6118.37 22.78 28.99 316.64 332.17 3089.68 121.40 2968.28 Pass 11562.71 8843.27 6400.00 6162.10 22.99 29.96 317.13 332.05 3043.84 123.36 2920.48 Pass 11567.81 8843.74 6450.00 6205.84 23.20 30.96 317.61 331.92 2998.14 125.40 2872.75 Pass 11575.00 8844.41 6500.00 6249.62 23.50 32.10 318.32 331.77 2952.55 127.77 2824.78 Pass 11575.00 8844.41 6550.00 6293.35 23.50 32.85 318.24 331.68 2907.09 129.20 2777.89 Pass 11583.79 8845.22 6600.00 6336.96 23.85 34.15 319.12 331.50 2861.81 131.91 2729.89 Pass 11589.43 8845.74 6650.00 6380.43 24.08 35.34 319.64 331.35 2816.75 134.28 2682.47 Pass 11600.00 8846.71 6700.00 6423.77 24.51 36.85 320.71 331.14 2771.97 137.41 2634.55 Pass 11600.00 8846.71 6750.00 6466.99 24.51 37.72 320.60 331.03 2727.44 139.11 2588.33 Pass 11607.49 8847.40 6800.00 6510.14 24.80 39.10 321.31 330.84 2683.23 141.95 2541.29 Pass 11613.84 8847.98 6850.00 6553.32 25.04 40.40 321.88 330.64 2639.24 144.69 2494.55 Pass 11625.00 8849.00 6900.00 6596.63 25.48 42.04 322.96 330.38 2595.35 148.23 2447.12 Pass 11625.00 8849.00 6950.00 6640.00 25.48 42.94 322.80 330.22 2551.63 150.17 2401.46 Pass 11633.46 8849.76 7000.00 6683.40 25.79 44.42 323.56 329.96 2508.22 153.45 2354.77 Pass 11640.27 8850.38 7050.00 6726.84 26.04 45.82 324.11 329.69 2465.06 156.59 2308.47 Pass r1 ~~ by BP Alaska Anticollision Report ~~ ~.r ~'~wciiEs INTEQ Company: BP Amoco Date:. 8/28/2006 Time: 09:42:02 'Page: 5 Fields Lisburne Reference Site: Li s DS 05 Co-ordinate(NE) Reference: Well'. L5-16, True Nordt Reference Well: L5-16 Vertical (TVI)) Reference: 9 t 163/2/1987 00:00 60.U Reference Wellpath: Plan 3, L5-1 6AL2 Db: Oracle Site: Lis DS 05 Well: L5-32 Rule Assigned: Major Risk Wellpath: L5-32 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVI) MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area.. . .Deviation Warniag ft ft ft ft ft ft deg deg in ft ft ft 11650.00 8851.25 7100.00 6770.33 26.40 47.42 324. 97 329.38 2422.11 160.27 2261.84 Pass 11650.00 8851.25 7150.00 6813.85 26.40 48.37 324. 75 329.16 2379.37 162.55 2216.82 Pass 11661.31 8852.26 7200.00 6857.38 26.79 50.10 325. 75 328.80 2336.82 166.65 2170.17 Pass 11668.54 8852.90 7250.00 6900.88 27.05 51.59 326. 29 328.46 2294.51 170.25 2124.26 Pass 11675.00 8853.47 7300.00 6944.33 27.27 53.03 326. 73 328.13 2252.46 173.83 2078.63 Pass 11683.36 8854.20 7350.00 6987.78 27.54 54.61 327. 36 327.75 2210.64 177.81 2032.83 Pass 11690.89 8854.86 7400.00 7031.30 27.79 56.14 327. 87 327.36 2169.04 181.78 1987.26 Pass 11700.00 8855.64 7450.00 7074.82 28.09 57.78 328. 54 326.93 2127.72 186.13 1941.59 Pass 11706.28 8856.18 7500.00 7118.33 28.28 59.24 328. 88 326.51 2086.72 190.16 1896.56 Pass 11714.14 8856.85 7550.00 7161.82 28.52 60.84 329. 36 326.05 2046.06 194.61 1851.45 Pass 11725.00 8857.77 7600.00 7205.29 28.85 62.62 330. 15 325.53 2005.75 199.66 1806.09 Pass 11725.00 8857.77 7650.00 7248.73 28.85 63.74 329. 72 325.10 1965.82 203.24 1762.57 Pass 11738.38 8858.89 7700.00 7292.14 29.21 65.70 330. 73 324.50 1926.25 209.00 1717.26 Pass 11752.00 8860.01 7750.00 7335.48 29.59 67.67 331. 74 323.87 1887.18 214.97 1672.21 Pass ~ • Q +Ki t~~~ f1 o G-~-tG r t~ t~ (' o e ~ ~ -~ ~ N t }111 I} a ~~~ ..FCi 1 ~ ~ r i l l j, r a ~ o '~ ~rl~_~ A o 1 ,~ i o s ~ O I Q N 9 .-.. ~ ,O J ~ N 1~1{tY o ~ C t0 m ~ O Q :.A.{{-~--.. 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PERMIT TQ DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of thi lic tio'nn with the application for a Permit to Drill for that branch. For each subsequent well branch, the app for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITTAL LETTER CI-IECKLIST WELL NAME ~ ~ ~--~ ~~~~ PTD# ~' ~~ Development Service Exploratory Stratigraphic Vest Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES i TEXT FOR APPROVAL LETTER :MULTI LATERAL ~ The permit is for a new wel(bore segment of existing ~ ~ well ~ (If last two digits in ~ permit No. ,API No. 50- i API numb - - er a between 60-69) re ; j Production should continue to be reported as a function of the ~ i original API number stated above. PILOT HOLE ~ In accordance with 20 AAC 25.005(f), all records, data and togs ', acquired for the pilot hole must be clearly differentiated in both j I well name ( PH) and API number ~ (~0- - -_) from records, data and logs acquired for well i SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~' 25.05. Approval to perforate and produce . inject is contingent upon issuance of a conservation order approving a spacing exception . assumes the i liability of any protest to the spacing exception that may occur. i DRY DITCH j All dry ditch sample sets submitted to the Commission must 6e in ;` SAMPLE no greater than 30' sample intervals from below the permafrost or j from where samples are first caught and 10' sample intervals j through target zones. 'Please note the following special condition of this permit: Non-Conventional I production or production testing of coal bed methane is not allowed Well ~ for name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data j ; on water quality and quantity. SCompany Name) must contact the i Commission to obtain advance approval of such water well testing j program. I Rev: 1 !25/06 C:`jodyltransmittal checklist • -7 N O ° ~~ N Q T '~,, a~ O ° N ?~ °~ I~ o ~ m m. ~ c ~ ~ ~ 3 a~ c ~ m' f6' ~ w N N Z' N m O O C O' i m ~ z c.~ m Z li .3 .Q m ~ i m E ~ E .. - U. o Q m. Q E 3~ ; I I s' n. n 3' ~ ~° .5, J o, ° N, c =' o, ~ m w, m ~ m; ; I ~ r -0 3' J, m. ~ ~ ' ~ o m' ¢ ~' c U' C' (O' •y' ~' O .~.., o ° 2 c ~3 9 c >, ~ m m. a a> a ,~ a~, a0. (0 J, J. ~ (6 ~. to ~, Q v. c. '~ o. m C7 ° ~ ~ c ° ? o. ~ o °, o M N J, C. N' -~. LL.. Z. O' L N. ~ ~ N' C ~, O. 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MURKOWSKI, GOVERNOR nilL'1•-7~ OII/ ~lsa1 ~va7 333 W. T" AVENUE, SUITE 100 CO~SERQAilOl` CO~TISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Field, Lisburne Pool, L5-16AL2 BP Exploration (Alaska), Inc. Permit No: 206-085 (Revised) Surface Location: 1788' FSL, 19' FWL, Sec. O 1, T i 1 N, R 15E, UM Bottomhole Location: 2271' FSL, 1966' FWL, Sec. U 1, T11 N, R 15E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well PBU LS-16A, Permit No 206- 083, API 50-029-21700-01. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable pro~~ision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspr at (907) 659-3607 (pager). DATED this~day of August, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. l~t~IVt~Q ~.cbh- ~I-~.3~zo0(o STATE OF ALASKA AUG ~ ~A~~OIL AND GAS CONSERVATION COM~ON Alaska Oil & Gas Cans. Commission PERMIT TO DRILL 20 AAC 25.005 08/21/06: Revised, Change BHL -__L~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. urrent ell Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L5-16AL2 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth:, MD 10538 ~ TVD 8801ss 12. Field /Pool(s): Prudhoe Bay Field / Lisburne 4a. Location of Well (Governmental Section): Surface: 17 8' FSL 19' FWL SEC 01 T11N R15E M 7. Property Designation: ADL 028320 Pool , , . , , 8 , U Top of Productive Horizon: 1245' FSL, 1005' FWL, SEC. 01, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 21, 2006 -' Total Depth: 2271' FSL, 1966' FWL, SEC. 01, T11N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6320' 4b. Location of Well (State Base Plane Coordinates): Surface: x-717447 y-5974920 Zone-ASP4 10. KB Elevation (Height above GL): 60 feet 15. Distance to Nearest Well Within Pool: 2850' 16. Deviated Wells: Kickoff Depth: gg37 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 .035) Downhole: 3184 Surface: 294' 18: Casin Pr ram: S ecificatio ns To - Settin D e th -Bo ttom antit of Dement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 19. PRESE NT WELL CONDITION SUMMARY (To be completed: for'Redrill and Re-entry Operations) Total Depth MD (ft): 10875 Total Depth TVD (ft): 8975 Plugs (measured): None Effective Depth MD (ft): 10875 Effective Depth TVD (ft): 8975 Junk (measured): None Casing . Length Size Cement Volume MD TVD Conductor /Structural 12 ' 20" 1800# Poleset 120' 120' Surface 4006' 10-3/4" 1300 sx AS III 325 sx Class 'G' 4006' 3998' Intermediate Prod ction 9 5 ' 7-5/8" 425 sx Class' 9559' 9298' Liner Scab Liner 403' 4-1/2" 97 sx Class'G' 8803' - 9206 8603' - 8974' Perforation Depth MD (ft): Open Hole Completion for L5-16A & L5-16AL1 Perforation Depth TVD (ft): Open Hole Completion 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 ' true and correct. Contact Greg Sarber, 564-4330 Printed Name Gr Sarber Title CT Drilling Engineer / Prepared By Name/Number: Si nature ~ Phone 564-4330 Date ~ 2(" ~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: 206-085 API Number: 50-029-21700-61-00 Permit pp See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ,L,. ;~ ti Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No ~'2 S l I J ~ ~~ (_, "f "-O ~ S O t~ `/1 L-~ HZS Measures: Yes ^ No it tional Survey Req'd: Yes ^ No Ott. er: r~,t,~, (~ 7A l~'/~ 25 . n 3 3 ~ 7 ~~ ~-~ ~ cc,~~-cLC d ~ ~ i ~tS l.~+t-Q c+~~ W clPc~ . ~ ~v~u APPROVED BY THE COMMISSION Date Z~ ,COMMISSIONER Form 10-401 Revised 12/2005 ^ ~ ~ ~ ~ A 1 ~ Submit (n Duplicate • • BP L5-16A, AL1, AL2 UBCTD Sidetrack Revision Changing Bottom Hole Location of L5-16AL2 Discussion of Operations: Well L5-16 is the 2"d of two planned underbalanced CTD, thru tubing sidetrack wells planned for the summer of 2006. L5-16 was originally drilled in March of 1987, and completed in zones 4,5, and 6. It has produced at total of 1.53 MMBO since it was originally brought on line in 1987. Currently the well is cycling between 400-500 BOPD. The well is typically on line for approximately 5 days until it reaches MGOR of 30,000 SCF/STB. The well is shut in for approximately 20 days. The cycle has been repeating for the last several years. No outstanding integrity issues exist with the parent wellbore. Extensive stimulation work has been performed on this well and there is little opportunity for further well work. Nordic 2 rigged up on L5-16 on May 12, 2006, and successfully completed a workover in preparation for the CTD UBD sidetrack. That work was completed under Sundry Approval 306-120. The sidetracks, L5-16A, L5-16A L1, and L5-16A L2 will kick off from separate windows milled from mechanical whipstocks set in Lisburne Zone 4. Targets for the 3 laterals are in zone 4, 5, and 6. If real time well testing does not indicate that the wells have encountered fracturing or high productivity rock, an open hole sidetrack in a different azimuthal direction will be considered, but will not be permitted at this time due to uncertainty over the alternate well path. If an open hole sidetrack of L5-16A proves to be needed, then a Permit application for an additional lateral will be submitted at that time. This is the 2"d of 2 CTD underbalanced wells planned for the Lisburne field this summer. Extensive planning for success has been made, and is ongoing. Blade Energy Partners, which is a consulting firm specializing in UBD has been engaged to assist in project planning, personnel training, and on side assistance during the drilling phase of the project. Well control equipment has been designed specifically for the planned operation and procedures have been written to cover each aspect of the operation. There has been HSE and operational training conducted for the town and field staff using a UBD simulator. All relevant contractors, crew and engineering staff have completed this training. HAZid and HAZop procedures have been completed and overall planning has been Peer reviewed by operating partners and outside experts with specialization in coil tubing and underbalanced drilling operations. This underbalanced coil tubing drilling operation will use diesel as the power fluid and gas lift to achieve an underbalance of 200-400 psi while drilling. Return fluids will flow to an on site separator supplied by ASRC. The fluids will be separated and measured, then flowed to the Lisburne Production Center (LPC) at about 600 psi line pressure. There will be no flaring or compression involved in the project. The BOP stack drawing is significantly different than a standard CTD rig up, and is attached. This stack incorporates 6 BOP rams, an annular preventor, 2 flow spools, 2 swab valves, and a master valve. The UBD flow spool is located below double swab valves such that produced fluids do not flow through the upper four rams. An ESD valve on the outlet of the UBD flow spool along with double rams (Shear/seal and 2" pipe/slip • • combination) located below the UBD flow spool provide emergency shut in capability in the event of a flow line leak. Equipment and procedures for pressure deploying/undeploying the drilling BHA have been used successfully on the managed pressure drilling campaigns in the Kuparuk field in the past few years, and have been refined for the UBD process at Lisburne. A tubing retrievable SSSV has been installed during the workover specifically to provide additional pressure control capability. The attached drawings describe the BOP stack, the P & ID of the full process spread and a flow diagram that includes all surface equipment. Summary of Underbalanced Drilling and Completion Operations: 1. Move rig over well from L5-28. 2. Rig up 2" CTE, UBCTD Stack and BOPE. PT BOPE. 3. Mill L5-16A window with 2% KCL and biozan sweeps. (Top of window at 9100' MD, 8817' SS) 4. Drill L5-16A lateral using diesel/lift gas to achieve underbalance. 5. TD lateral and flow test well for 6 hours. 6. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A. (Top of window at 9040' MD, 8761' SS) 7. Mill L5-16A L1 window with 2% KCL, and biozan sweeps. 8. Drill L5-16A L1 lateral using diesel/lift gas to achieve underbalance. 9. TD L1 lateral and flow test well for 6 hours. 10. Recover whipstock tray, and PXX plug. Set guidestock in L5-16A L1 lateral packer. 11. Set Baker whipstock packer with tailpipe and PXX plug to isolate L5-16A L1. (Top of window at 8923' MD, 8653' SS) 12. Mill L5-16A L2 window with 2% KCL, and biozan sweeps. 13. Drill L5-16A L2 lateral using diesel/lift gas to achieve underbalance. 14. TD L2 lateral and flow test well for 6 hours. 15. Recover whipstock tray and PXX plug from L2 whipstock. Install hollow guidestock into L2 packer. 16. Set BPV. RD and move off well. Post RWO Status: • L5-16 has been worked over. The original perforations have been successful squeezed off. A 4-1/2" scab liner has been run and cemented. The production tubing has been replaced with new 4-1/2" L-80 tubing. A gas lift design has been run and the well is ready for the drilling phase of operations. Drilling Status • The rig has moved onto L5-16 and successfully completed the L5-16A lateral drilling in an underbalanced mode using diesel as the power fluid as shown in the original permit to drill application. • The rig successfully set the whipstock and milled the window for the L1 lateral. The build section was completed and the lateral drilled to 9759'. Unfortunately, hole stability problems caused us to lose this lateral. A sidetrack was attempted at 9260' MD. A short section of sidetrack hole was drilled to 9370' MD before again losing the hole. To successfully drill to the bottom hole location targeted by the L1 lateral it is necessary to avoid the unstable mudstone/dolomite that was found in the L1 lateral. • Anew whipstock was set in the parent wellbore at 8937'. A sidetrack will be made from this lateral that targets the bottom hole location that the L1 lateral was trying to reach. This is a different bottom hole location than originally targeted in the original L2 lateral permit to drill application. Because the new bottom hole location is more than 500' away from the old one, a new permit to drill application is being made for L5-16AL2. / Mud Program: • The window will be milled with 2% KCL with'/2 ppb Biozan. Sweeps will be 2 ppb Biozan. The 3 lateral sections will be drilled with diesel as the power fluid with gas lift used to underbalance the well. Viscosified mineral oil sweeps will be used for hole cleaning during drilling. Due to lack of diesel availability currently on the North Slope, the drilling fluid for the L5-16AL2 lateral will be 2% KCL water with viscosified brine as sweeps. Kill Weight Fluid. 2% KCL will be in the rig pits on location. BHP with 2% KCL will be 3864 psi. Measured BHP is 3184 psi. 2% KCL will overbalance the formation pressure by 680 psi. OH/Tubing volume = 153 bbls. Disposal: • During the drilling phase all fluid and gas returns from the well will be pumped down the L5 pad production line and sent to the Lisburne Production Center for recycling. • All drilling and completion waste fluids and any other Class II wastes will go to Grind and Inject, or Pad 3. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • None. All laterals will be completed open hole. Well Control: • The BOP schematic, P & ID drawing, and fluid flow diagrams are attached. • Pipe rams, blind rams and the CT pack-ff will be pressure tested to 400 psi and 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional: • See attached directional plans. Maximum planned hole angle is approximately ~97 deg. • Magnetic and inclination surveys will be taken every 30'. No Gyro survey will be run. Logging: • An MWD Gamma Ray log will be run of the entire open hole section. Hazards mitigated through training, procedures, and UBD equipment: • Hydrogen Sulfide -Maximum H2S measured on L5 pad is 600 ppm (3-27-92) on L5- ~ 12. L5-16 has recorded H2S at 50 ppm on 1-9-2006, and the lift gas has an H2S concentration of 60 ppm. • • • Maximum BHP is expected to be 3184 psi @ 8900' SS (6.9 ppg). Maximum anticipated surface pressure with a full column of gas to surface is 2294 psi. • A combustible power fluid will be used. (Diesel) Flash Point 100 deg F o Fire, Environmental, Health (exposure), impact on other equipment (elastomers) • A combustible artificial lift fluid will be used. (Natural Gas) o Fire, HzS, Health (exposure) • Produced Fluids will be present in returned fluids. (Oil and Natural Gas) o Fire, Environmental, H2S, Health (exposure), impact on other equipment (elastomers) • Pressure - 650 to 1000 psi on surface. o Leaks, loss of containment, pipe whip • SIMOPS -Drilling/Production. • New Procedures for most people involved -Human Error. • Additional Equipment -Escape areas, slips and trips. • Poor Hole Cleaning -Stuck Pipe • Hole Instability - Mudstones Reservoir Pressure: • Bottom Hole Pressure was measured at 3184 psi at 8900' TVDSS (6.9 ppg) • Maximum surface pressure with gas (0.1 psi/ft) to surface is 2294 psi. ~. BP Drilling Contacts: • Greg Sarber 564-4330, 242-8000 cell • Mark Johnson 564-5666, 240-8034 cell Attachment List Updated schematic L5-16A L2 directional plan L5-"I bH, HL"I , HL"I I-'ti"I , HL gBFET'Y NDT~: ~T I~{f F~ (PPiq~io UBD Sidetrack Update 8- 6 1C,~1' Cam, 15.511, L-B0, ~ - 9953' ~~ 4406' 4 1/2" 12.6#, L-80, IBT-Mod. Tbg. ner Hanger/Packer 8800 MD, 8540ss - L5-16AL2: 8937 MD, 8666' ss L5-16AL1: 8960 MD, 8688' ss L5-16A: 9097' MD, 8814' 1/2" 12.6#, L-80, IBT-Mod 9475` MD PBTO 9479' . I at~i Tw~eu, io - 3.a~~• 5 GLM's Deepest GLV 8380 MD (8155ss) 4 1 /2" x 7 5/8" Baker Packer 8460 MD 4 1/2" X Nipple Planned TD=10538' MD, 8800.78' TVD L5-16AL2 To Be Permitted i ~ ~ OH Sidetrack @ 9260' MD L5-16AL1 TD=9759' MD L5-16AL1 PB1 _ _ i TD=9370' MD __ L5-16A TD=10,875' MD j 158' ~, X3.111, LSO, ~ -6815' I by BP Alaska s ~~ Baker Hughes INTEQ Planning Report 1(1VTE Q Company: BP Amoco Date: 8/20/2006 Time: 11:48:46 Page: L Field: Lisburne Co-ordmate(NE) Reference: = We1L' L5-16, True North Site: Lis OS 05 Vertical (1'VD) Reference: 9:16 312/1 987 00:00 60.0 Wells 15-16 Section (VS) Reference: 1Nell (O.OON,O.OOE,35.OOAzi) Wellpaths Plan 2, L5-1fiAL2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Lisburne 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: bggm2005 Site: Lis DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Easting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: L5-16 Slot Name: 16 L5-16 Well Position: +N/-S 4778.96 ft Northing: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Easting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, L5-16AL2 Drilled From: L5-16 Drill to L1 Targets, cpy Greg's 08-19-06 path file Tie-on Depth: 8921.35 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/15/2006 Declination: 24.65 deg Field Strength: 57627 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 35.00 Plan: Plan #2 Date Composed: 8/1 712 0 06 Copy Greg's Path file of 08-19-2006 Version: 18 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude' ---> c-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting beg Miu Sec Deg Mine Sec Dip. -Dir. ft ft ft ft ft L5-16AL1-01 Target1 60.00 -580.01 1255.27 5974377.00 718718.00 70 19 57.048 N 148 13 32.174 W L5-16AL1-01 Target2 60.00 -300.87 1634.54 5974667.00 719089.00 70 19 59.793 N 148 13 21.098 W L5-16AL1-01 Target3 60.00 332.22 2021.07 5975311.00 719457.01 70 20 6.018 N 148 13 9.806 W Annotation MD TVD ft ft 8921.35 8711.52 TIP 8937.00 8726.01 KOP 8954.00 8741.67 End of 9 Deg/100' DLS 9041.00 8806.46 4 9128.00 8828.09 5 9148.00 8827,31 End of 45 Deg/100' DLS 9349.00 8816.79 End of 16 Deg/100' DLS 9477.00 8807,96 8 9669.00 8799.76 9 9852.00 8795.63 10 10035.00 8795.21 11 10218.00 8798.31 12 10278.00 8800.25 13 10382.00 8812.72 14 10538.00 8860.78 TD u.r by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 8/20/2006 Time: 11:48;46 Pager ' 2 Field: Lisburne Go-ordinate(NE) Reference: Well; L5'16, Ttue North Site:: Lis DS 05 Vertical (TVD) Reference: 9:16 3/2/1987 00:00 60.0 Weli: L5-16 Section (VS) Referenees Well (O.OON,O.OOE,35.OOAzi) Welipatb: Plan 2, L5-16AL2 Survey Calculation Metbodr Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S' +E/-W DLS Bnild Turn TFO Target ft deg deg ft ft ft deg/1OOft deg/100ft deg/100ft deg 8921.35 22.20 125.65 8711.52 -546.46 992.19 0.00 0.00 0.00 0.00 8937.00 22.18 125.87 8726.01 -549.91 996.99 0.55 -0.13 1.41 103.64 8954.00 23.71 125.87 8741.67 -553.79 1002.36 9.00 9.00 0.00 0.00 9041.00 58.97 97.60 8806.46 -569.59 1055.57 45.00 40.52 -32.49 320.00 9128.00 92.17 75.80 8828.09 -563.63 1137.88 45.00 38.17 -25.06 324.00 9148.00 92.30 66.79 8827.31 -557.22 1156.79 45.00 0.65 -45.03 271.00 9349.00 93.54 34.61 8816.79 -431.79 1310.11 16.00 0.62 -16.01. 273.00 9477.00 94.34 47.42 8807.96 -335.64 1393.74 10.00 0.62 10.00 86.00 9669.00 90.51 66.26 8799.76 -231.24 1553.59 10.00 -1.99 9.81 101.00 9852.00 92.05 48.02 8795.63 -132.39 1706.62 10.00 0.84 -9.97 275.00 10035.00 88.21 30.12 8795.21 9.09 1821.46 10.00 -2.10 -9.78 258.00 10218.00 89.87 11.89 8798.31 179.18 1886.76 10.00 0.91 -9.96 275.00 10278.00 86.43 16.81 8800.25 237.25 1901.62 10.00 -5.73 8.20 125.00 10382.00 79.80 8.74 8812.72 337.79 1924.47 10.00 -6.37 -7.77 230.00 10538.00 64.20 8.74 8860.78 483.99 1946.93 10.00 -10.00 0.00 180.00 Survey MI)' Iucl Azim Sys TVD N/S E/W MapN MapE DL.S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 8921. 35 22.20 125.65 8651.52 -546.46 992.19 5974402.91 718454.08 0.00 121.47 0.00 MWD 8937. 00 22.18 125.87 8666.01 -549.91 996.99 5974399.59 718458.97 0.55 121.39 103.64 MWD 8954. 00 23.71 125.87 8681.67 -553.79 1002.36 5974395.87 718464.45 9.00 121.29 0.00 MWD 8960. 00 25.83 121.89 8687.11 -555.19 1004.45 5974394.53 718466.58 45.00 121.34 320.00 MWD 8970. 00 29.57 116.47 8695.97 -557.44 1008.51 5974392.40 718470.71 45.00 121.83 323.62 MWD 8980. 00 33.48 112.20 8704.49 -559.59 1013.27 5974390.39 718475.53 45.00 122.80 328.41 MWD 8990. 00 37.51 108.74 8712.63 -561.61 1018.71 5974388.53 718481.03 45.00 124.27 332.06 MWD 9000. 00 41.62 105.86 8720.34 -563.50 1024.79 5974386.82 718487.16 45.00 126.21 334.88 MWD 9010. 00 45.79 103.42 8727.57 -565.24 1031.48 5974385.27 718493.89 45.00 128.62 337.10 MWD 9020. 00 50.01 101.31 8734.27 -566.82 1038.72 5974383.90 718501.18 45.00 131.47 338.86 MWD 9030. 00 54.26 99.44 8740.41 -568.24 1046.49 5974382.71 718508.98 45.00 134.77 340.28 MWD 9040. 00 58.54 97.76 8745.94 -569.48 1054.72 5974381.71 718517.24 45.00 138.47 341.43 MWD 9041. 00 58.97 97.60 8746.46 -569.59 1055.57 5974381.62 718518.09 45.00 138.86 342.36 MWD 9050. 00 62.27 94.91 8750.88 -570.44 1063.36 5974380.99 718525.91 45.00 142.64 324.00 MWD 9060. 00 66.00 92.11 8755.24 -570.99 1072.34 5974380.71 718534.90 45.00 147.34 325.32 MWD 9070. 00 69.77 89.47 8759.00 -571.12 1081.60 5974380.85 718544.16 45.00 152.55 326.54 MWD 9080. 00 73.59 86.95 8762.15 -570.82 1091.09 5974381.42 718553.63 45.00 158.23 327.54 MWD 9090. 00 77.43 84.53 8764.65 -570.10 1100.74 5974382.42 718563.26 45.00 164.36 328.33 MWD 9100. 00 81.30 82.19 8766.49 -568.96 1110.50 5974383.84 718572.98 45.00 170.89 328.93 MWD 9110. 00 85.17 79.89 8767.67 -567.41 1120.30 5974385.67 718582.74 45.00 177.78 329.37 MWD 9120. 00 89.06 77.61 8768.18 -565.46 1130.10 5974387.90 718592.47 45.00 185.00 329.64 MWD 9128. 00 92.17 75.80 8768.09 -563.63 1137.88 5974389.97 718600.20 45.00 190.97 329.75 MWD 9130. 00 92.18 74.90 8768.01 -563.12 1139.81 5974390.53 718602.12 45.00 192.49 271.00 MWD 9140. 00 92.25 70.40 8767.63 -560.14 1149.35 5974393.78 718611.56 45.00 200.40 270.97 MWD 9148. 00 92.30 66.79 8767.31 -557.22 1156.79 5974396.92 718618.91 45.00 207.06 270.79 MWD 9150. 00 92.32 66.47 8767.23 -556.43 1158.63 5974397.76 718620.72 16.00 208.76 273.00 MWD 9175. 00 92.52 62.48 8766.17 -545.67 1181.16 5974409.17 718642.94 16.00 230.50 272.99 MWD 9200. 00 92.71 58.48 8765.03 -533.37 1202.89 5974422.10 718664.30 16.00 253.04 272.82 MWD 9225. 00 92.89 54.48 8763.81 -519.58 1223.70 5974436.48 718684.70 16.00 276.27 272.64 MWD 9250. 00 93.05 50.47 8762.52 -504.37 1243.50 5974452.25 718704.05 16.00 300.08 272.44 MWD 9275. 00 93.20 46.47 8761.16 -487.83 1262.18 5974469.33 718722.24 16.00 324.35 272.23 MWD 9300. 00 93.33 42.47 8759.73 -470.02 1279.66 5974487.64 718739.20 16.00 348.97 272.02 MWD 9325. 00 93.45 38.46 8758.25 -451.04 1295.85 5974507.09 718754.83 16.00 373.80 271.79 MWD 9349. 00 93.54 34.61 8756.79 -431.79 1310.11 5974526.73 718768.53 16.00 397.75 271.55 MWD 9400. 00 93.88 39.71 8753.49 -391.25 1340.85 5974568.15 718798.07 10.00 448.59 86.00 MWD 9450. 00 94.19 44.72 8749.96 -354.32 1374.35 5974606.03 718830.49 10.00 498.05 86.33 MWD r: b BP Alaska ~r p Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 8/20/2006 Time: 11:48:46 Page::. 3 Field: Lisburne Co-ordinate(NE) Reference: Well: L5=16, True North - Sites Lis DS 05 Vertical (TVD) Reference: 9 ; 16 3/2/1987.00:00 60.0. Well: L5- 16 Seetiou (VS) Reference: Well (O.OON,O.OOE,35.OOAzi) Wellpath: Plan 2, L5-1 6AL2 8arvey Calculatiou Metbod: Minimum Curvature Db: Oracle Survey 114D Iacl Azim Sys TVJJ N/S E/1'V MapN MapE DLS VS TFO Tool: ft deg deg ft ft ft ft ft' deg/100ft ft deg. 9477. 00 94.34 47.42 8747.96 -335.64 1393.74 5974625.26 718849.33 10.00 524.47 86.68 MWD 9500. 00 93.90 49.68 8746.30 -320.46 1410.93 5974640.94 718866.07 10.00 546.77 101.00 MWD 9550. 00 92.92 54.60 8743.33 -289.84 1450.33 5974672.69 718904.56 10.00 594.45 101.16 MWD 9600. 00 91.91 59.50 8741.22 -262.67 1492.23 5974701.05 718945.66 10.00 640.74 101.45 MWD 9650. 00 90.90 64.40 8739.99 -239.17 1536.33 5974725.82 718989.05 10.00 685.28 101.66 MWD 9669. 00 90.51 66.26 8739.76 -231.24 1553.59 5974734.25 719006.08 10.00 701.68 101.78 MWD 9700. 00 90.78 63.17 8739.41 -218.00 1581.62 5974748.30 719033.71 10.00 728.60 275.00 MWD 9750. 00 91.21 58.18 8738.54 -193.53 1625.19 5974774.02 719076.55 10.00 773.64 274.97 MWD 9800. 00 91.63 53.20 8737.31 -165.36 1666.46 5974803.37 719116.99 10.00 820.39 274.88 MWD 9852. 00 92.05 48.02 8735.63 -132.39 1706.62 5974837.49 719156.17 10.00 870.43 274.76 MWD 9900. 00 91.05 43.32 8734.34 -98.87 1740.93 5974871.99 719189.49 10.00 917.57 258.00 MWD 9950. 00 90.00 38.43 8733.88 -61.07 1773.64 5974910.72 719221.09 10.00 967.29 257.87 MWD 10000. 00 88.94 33.54 8734.34 -20.63 1803.01 5974951.99 719249.27 10.00 1017.26 257.83 MWD 10035. 00 88.21 30.12 8735.21 9.09 1821.46 5974982.24 719266.85 10.00 1052.19 257.87 MWD 10050. 00 88.34 28.62 8735.66 22.16 1828.81 5974995.51 719273.82 10.00 1067.11 275.00 MWD 10100. 00 88.79 23.64 8736.92 67.02 1850.82 5975040.99 719294.52 10.00 1116.48 275.04 MWD 10150. 00 89.24 18.66 8737.78 113.63 1868.86 5975088.10 719311.20 10.00 1165.01 275.17 MWD 10200. 00 89.70 13.68 8738.24 161.63 1882.78 5975136.48 719323.72 10.00 1212.32 275.26 MWD 10218. 00 89.87 11.89 8738.31 179.18 1886.76 5975154.14 719327.19 10.00 1228.98 275.30 MWD 10250. 00 88.03 14.51 8738.89 210.33 1894.07 5975185.48 719333.59 10.00 1258.68 125.00 MWD 10278. 00 86.43 16.81 8740.25 237.25 1901.62 5975212.62 719340.36 10.00 1285.07 124.95 MWD 10300. 00 85.02 15.12 8741.89 258.34 1907.65 5975233.87 719345.78 10.00 1305.81 230.00 MWD 10350. 00 81.83 11.25 8747.62 306.69 1918.98 5975282.52 719355.70 10.00 1351.91 230.13 MWD 10382. 00 79.80 8.74 8752.72 337.79 1924.47 5975313.77 719360.28 10.00 1380.53 230.57 MWD 10400. 00 78.00 8.74 8756.19 355.25 1927.15 5975331.30 719362.46 10.00 1396.37 180.00 MWD 10450. 00 73.00 8.74 8768.70 403.08 1934.50 5975379.32 719368.42 10.00 1439.77 180.00 MWD 10500. 00 68.00 8.74 8785.38 449.65 1941.66 5975426.08 719374.22 10.00 1482.02 180.00 MWD 10538. 00 64.20 8.74 8$00.78 483.99 1946.93 5975460.55 719378.50 10.00 1513.17 180.00 3.50" a ~~ .~ ~ .. ~ ! t E' ~ ~ i- ~~~ ~ I~' ~ ~ '~I n ~ ;~{i' r il, ~E :~ I•~ i Q E ~ ~~~ kk ~1 f f, : Aso ~ 1, r? SSR i siJ. ~ = 9~~ ' ~ I ~ $ a 838888588888888 8 ~ eee i ~ f ' g ~~ 8 ; 8 8888888aF8888 8~i~i ~"-' Y 8 6 4 4 ~~ -~ .i S ese '. ~i I ~~I f 8 . SS S i ;~~~ ~ • ~ ~ ~ v~ % a ~ ~§ ~; i = n!a s in3s i € i3a s~ ~~ ~a $ ,~ y~ ~ 3 a s s . s t i& s' ~ i~8ic i w T ~ ~I ~J4`. ~~I~ ~ Y • ~~ o S~ °~~ ~~ a r4-~~ ~ :s ~ ~ ss C ' ~I J1 i SS S S'S eaB8a828E888 i i ~~ I~i 9 asaaaaasaasas& ~"ea~~ea ~i LCE~':::S:.SesoE r ,qz;..:8-...,,.,.a ~ii,. n 8 $2 S ~ ~ 8 n O N R ~ 8 j a a by BP Alaska Anticollision Report • -~.r ins 1NTEQ Company: BP Amoco Date: 8120!2006 Time: 11:44:25 Page: 1 Field: Lisburne Refereuce Site: Lis DS 05 Co-ordiuate(NEj Reference: V11e1L' L5-16, True North Reference Well: L5-16 Vertical(TVD) Refereuce: - 9:16.3/2/1987 00:00$0.0 Reference. Wellpath: . Plan 2, L5-16AL2 Db: Oracle NO GLOBAL SCAN: Using aser defined seleMion & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50 .00 ft Error Model: ISCWSA Ellipse Depth Range: 8937.00 to 10538.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/20/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 60.00 8921.35 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 8921.35 10538.00 Planned: Plan #2 V18 MWD MWD -Standard Casing Points MD TVD Diameter Hole' Size Name ft ft in in 10538.00 8860.78 3.500 4.125 3.50" Summary <-----=-------- Offset Wellpath ---- ---------a Reference Oft'set Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning. ' ft ft ft ft ft L5-16,PIan 2, L5-16AL2 1 0538.00 10538.00 0.00 106.92 -106.92 FAIL: Major Risk Lis DS 05 L5-16 L5-16 V1 8950.00 8950.00 0.14 82.71 -82.57 FAIL: Major Risk Lis DS 05 L5-16 L5-16A V2 8950.00 8950.00 0.14 82.71 -82.57 FAIL: Major Risk Lis DS 05 L5-16 L5-16AL1 V4 8950.00 8950.00 0.14 82.71 -82.57 FAIL: Major Risk Site: Well: Rule Assigned: Major Risk Wellpath: L5-16,PIan 2, L5-16AL2,PIan #2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area. Deviation Warni g ft ft ft ft ft ft deg deg in ft ft ft 8950.00 8738.00 8950.00 8738.00 10.67 0.13 125.87 0.00 4.125 0.00 65.33 -65.33 FAIL 9000.00 8780.34 9000.00 8780.34 10.72 0.87 105.86 0.00 4.125 0.00 67.63 -67.63 FAIL 9050.00 8810.88 9050.00 8810.88 10.53 1.64 94.91 0.00 4.125 0.00 69.17 -69.17 FAIL 9100.00 8826.49 9100.00 8826.49 10.16 2.23 82.19 0.00 4.125 0.00 69.45 -69.45 FAIL 9150.00 8827.23 9150.00 8827.23 9.65 2.61 66.47 0.00 4.125 0.00 68.37 -68.37 FAIL 9200.00 8825.03 9200.00 8825.03 9.48 3.05 58.48 0.00 4.125 0.00 68.01 -68.01 FAIL 9250.00 8822.52 9250.00 8822.52 9.36 3.49 50.47 0.00 4.125 0.00 67.86 -67.86 FAIL 9300.00 8819.73 9300.00 8819.73 9.31 3.89 42.47 0.00 4.125 0.00 67.93 -67.93 FAIL 9350.00 8816.73 9350.00 8816.73 9.33 4.23 34.71 0.00 4.125 0.00 68.25 -68.25 FAIL 9400.00 8813.49 9400.00 8813.49 9,78 5.01 39.71 0.00 4.125 0.00 69.87 -69.87 FAIL 9450.00 8809.96 9450.00 8809.96 10.25 5.70 44.72 0.00 4.125 0.00 71.57 -71.57 FAIL 9500.00 8806.30 9500.00 8806.30 10.78 6.43 49.68 0.00 4.125 0.00 73.50 -73.50 FAIL 9550.00 8803.33 9550.00 8803.33 11.37 7.17 54.60 0.00 4.125 0.00 75.59 -75.59 FAIL 9600.00 8801.22 9600.00 8801.22 11.98 7.90 59.50 0.00 4.125 0.00 77.79 -77.79 FAIL 9650.00 8799.99 9650.00 8799.99 12.61 8.61 64.40 0.00 4.125 0.00 80.04 -80.04 FAIL 9700.00 8799.41 9700.00 8799.41 13.08 9.34 63.17 0.00 4.125 0.00 81.85 -81.85 FAIL 9750.00 8798.54 9750.00 8798.54 13.43 10.01 58.18 0.00 4.125 0.00 83.32 -83.32 FAIL 9800.00 8797.31 9800.00 8797.31 13.75 10.61 53.20 0.00 4.125 0.00 84.71 -84.71 FAIL 9850.00 8795.71 9850.00 8795.71 14.04 11.12 48.21 0.00 4.125 0.00 86.01 -86.01 FAIL 9900.00 8794.34 9900.00 8794.34 14.28 11.54 43.32 0.00 4.125 0.00 87.18 -87.18 FAIL 9950.00 8793.88 9950.00 8793.88 14.48 11.86 38.43 0.00 4.125 0.00 88.21 -88.21 FAIL 10000.00 8794.34 10000.00 8794.34 14.62 12.10 33.54 0.00 4.125 0.00 89.11 -89.11 FAIL 10050.00 8795.66 10050.00 8795.66 14.72 12.25 28.62 0.00 4.125 0.00 89.87 -89.87 FAIL 10100.00 8796.92 10100.00 8796.92 14.76 12.29 23.64 0.00 4.125 0.00 90.47 -90.47 FAIL 10150.00 8797.78 10150.00 8797.78 14.75 12.25 18.66 0.00 4.125 0.00 90.92 -90.92 FAIL 10200.00 8798.24 10200.00 8798.24 14.69 12.11 13.68 0.00 4.125 0.00 91.24 -91.24 FAIL 10250.00 8798.89 10250.00 8798.89 15.26 12.82 14.51 0.00 4.125 0.00 93.44 -93.44 FAIL • by BP Alaska Anticollision Report -i.r ~~t3lii~s 1LNTEQ Company: BP Amoco Date:. 8/20/2006 Time: 11:44:25 Page: 2 ..Field: Lisburne ReferenceSite: 1is DS D5 Co-ordinate(NE) Reference: WeA: L5-16, True North .Reference Well: i5-16 Vertical (TVD) Reference: 9:163/2/1987 00:00 60:.0 Reference Wellpath: Plan 2, L5-1 6AL2 Db: Oracle Site: Well: Rule Assigned: Major Risk Wellpath: L5-16,PIan 2, L5-16AL2,PIan #2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr- No-Go - Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft' ft ft 10300.00 8801.89 10300.00 8801.89 15.74 13.45 15.12 0.00 4.125 0.00 95.50 -95.50 FAIL 10350.00 8807.62 10350.00 8807.62 15.78 13.50 11.25 0.00 4.125 0.00 96.41 -96.41 FAIL 10400.00 8816.19 10400.00 8816.19 15.99 13.79 8:74 0.00 4.125 0.00 98.13 -98.13 FAIL 10450.00 8828.70 10450.00 8828.70 16.52 14.51 8.74 0.00 4.125 0.00 101.12 -101.12 FAIL 10500.00 8845.38 10500.00 8845.38 17.10 15.26 8.74 0.00 4.125 0.00 104.35 -104.35 FAIL 10538.00 8860.78 10538.00 8860.78 17.56 15.83 8.74 0.00 4.125 0.00 106.92 -106.92 FAIL Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major AaLc Ctr-Ctr No-Go Allowable MD TVI) MD TVD Ref Offset TFO+AZI TFO-HS Castng/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft' 8950.00 8738.00 8950.00 8738.05 10.67 10.72 302.76 176.89 0.14 82.71 -82.57 FAIL 8997.74 8778.64 9000.00 8784.33 10.72 10.90 267.90 161.43 9.21 87.43 -78.22 FAIL 9035.14 8803.33 9050.00 8830.53 10.61 10.92 262.32 163.76 33.99 85.40 -51.41 FAIL 9061.38 8815.80 9100.00 8876.60 10.44 10.87 257.02 165.28 68.54 82.45 -13.91 FAIL 9079.45 8821.99 9150.00 8922.57 10.31 10.85 252.33 165.25 108.54 80.02 28.52 Pass 9092.15 8825.10 9200.00 8968.47 10.21 10.89 248.84 164.81 151.73 78.18 73.55 Pass 9101.40 8826.70 9250.00 9014.30 10.15 10.98 246.19 164.33 196.84 76.81 120.03 Pass 9108.35 8827.53 9300.00 9060.12 10.11 11.05 244.15 163.88 243.21 75.77 167.44 Pass 9113.71 8827.94 9350.00 9105.97 10.07 11.08 242.55 163.51 290.47 74.97 215.50 Pass 9117.94 8828.13 9400.00 9151.86 10.05 11.13 241.28 163.20 338.32 74.30 264.01 Pass 9121.40 8828.19 9450.00 9197.72 10.03 11.28 240.23 162.94 386.56 73.86 312.70 Pass 9124.26 8828.18 9500.00 9243.59 10.01 11.44 239.35 162.70 435.11 73.52 361.59 Pass 9126.67 8828.13 9550.00 9289.45 10.00 11.60 238.61 162.50 483.89 73.25 410.64 Pass 9129.55 8828.03 9600.00 9335.31 9.96 11.74 237.41 162.31 532.85 73.08 459.78 Pass Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area. Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8950.00 8738.00 8950.00 8738.05 10.67 10.72 302.76 176.89 3.500 0.14 82.71 -82.57 FAIL 8997.74 8778.64 9000.00 8784.33 10.72 10.90 267.90 161.43 3.500 9.21 87.43 -78.22 FAIL 9035.14 8803.33 9050.00 8830.53 10.61 10.92 262.32 163.76 3.500 33.99 85.40 -51.41 FAIL 9061.39 8815.80 9100.00 8876.59 10.44 10.83 257.01 165.27 3.500 68.53 73.84 -5.30 FAIL 9081.29 8822.51 9150.00 8919.71 10.29 10.64 249.80 163.16 3.500 105.60 70.52 35.09 Pass 9100.14 8826.52 9200.00 8948.97 10.16 10.48 238.51 156.32 3.500 135.24 69.62 65.63 Pass 9117.87 8828.13 9250.00 8957.32 10.05 10.38 224.73 146.63 3.500 154.78 71.59 83.19 Pass 9131.66 8827.95 9300.00 8951.80 9.93 10.28 208.96 134.80 3.500 175.87 76.85 99.03 Pass 9141.41 8827.57 9350.00 8944.02 9.77 10.13 194.21 124.45 3.500 206.04 81.60 124.44 .Pass 9146.57 8827.37 9400.00 8937.10 9.68 10.04 184.19 116.75 3.500 244.02 84.73 159.28 Pass 9148.48 8827.29 9450.00 8930.67 9.65 10.02 177.88 111.16 3.500 286.61 86.87 199:74 Pass 9148.20 8827.30 9500.00 8924.32 9.65 10.03 173.83 107.04 3.500 331.40 88.36 243.04 Pass 9149.48 8827.25 9550.00 8918.48 9.65 10.02 170.55 103.99 3.500 377.66 89.25 288.42 Pass 9150.00 8827.23 9600.00 8916.12 9.65 10.02 168.55 102.08 3.500 425.69 89.79 335.90 Pass 9152.94 8827.11 9650.00 8917.31 9.63 10.01 166.97 100.96 3.500 474.78 89.97 384.81 Pass 9156.29 8826.97 9700.00 8918.10 9.62 9.99 165.50 100.03 3.500 523.49 90.08 433.40 Pass 9158.50 8826.88 9750.00 8917.15 9.61 9.99 164.20 99.08 3.500 572.33 90.24 482.10 Pass 9159.04 8826.86 9800.00 8916.42 9.61 9.99 163.32 98.29 3.500 621.63 90.40 531.23 Pass 9160.02 8826.82 9850.00 8916.64 9.61 9.99 162.57 97.70 3.500 671.11 90.50 580.61 Pass • by BP Alaska Anticollision Report • -i.r il~s INTEQ Company: BP Amoco Dater 8!20/2006 Time: 11:44:25 Page:.. 3 Field:: Lisburne Reference Site: Lis DS 05 Co-ordiuate(NE) Refereuce: WeIL' L5-16, True North Reference Well: L5-16 Vertical ('I'VD) Reference:. 9 ;' 16 3/2/198700:00 60.0 Reference Wellpath: Plan 2, L5-1 6AL2 Db: .Oracle Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Gtr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IISDLstance Area Deviation Warning. ft ft ft ft ft ft 'deg deg in ft ft ft 9162.19 8826.73 9900.00 8917.00 9.60 9.98 161.73 97.21 3.500 720.34 90.53 629.81 Pass 9164.66 8826.62 9950.00 8915.68 9.59 9.98 160.78 96.65 3.500 769.25 90.57 678.69 Pass 9165.02 8826.61 10000.00 8912.37 9.59 9.98 160.09 96.02 3.500 818.44 90.68 727.76 Pass 9163.70 8826.66 10050.00 8909.91 9.60 9.99 159.79 95.51 3.500 867.64 90.82 776.82 Pass 9161.79 8826.74 10100.00 8909.80 9.60 10.00 159.79 95.20 3.500 916.89 90.93 825.96 Pass 9158.90 8826.86 10150.00 8912.29 9.61 10.01 160.13 95.08 3.500 965.70 91.04 874.66 Pass 9150.00 8827.23 10200.00 8914.26 9.65 10.12 161.45 94.98 3.500 1013.56 91.52 922.05 Pass 9150.00 8827.23 10250.00 8916.01 9.65 10.07 161.29 94.81 3.500 1059.52 91.39 968.13 Pass 9148.00 8827.31 10300.00 8918.20 9.65 10.05 161.49 94.70 3.500 1103.71 91.39 1012.31 Pass 9143.81 8827.48 10350.00 8919.35 9.72 10.19 163.28 94.60 3.500 1146.25 92.10 1054.14 Pass 9140.00 8827.63 10400.00 8922.94 9.79 10.32 165.02 94.63 3.500 1188.41 92.73 1095.67 Pass 9140.00 8827.63 10450.00 8927.16 9.79 10.27 165.01 94.61 3.500 1232.55 92.58 1139.97 Pass 9140.00 8827.63 10500.00 8935.62 9.79 10.23 165.19 94.80 3.500 1278.49 92.44 1186.06 Pass 9135.69 8827.80 10550.00 8942.82 9.86 10.40 167.32 94.98 3.500 1325.65 93.19 1232.46 Pass 9133.98 8827.86 10600.00 8949.42 9.89 10.45 168.20 95.09 3.500 1371.51 93.41 1278.10 Pass 9130.00 8828.01 10650.00 8952.73 9.96 10.61 170.00 95.10 3.500 1413.54 94.14 1319.39 Pass 9128.93 8828.05 10700.00 8955.06 9.97 10.62 170.41 95.03 3.500 1449.89 94.26 1355.63 Pass 9125.26 8828.17 10750.00 8961.82 10.01 10.70 171.58 95.16 3.500 1487.54 94.68 1392.86 Pass Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Vb'ellpath: L5-16AL1 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr Nato Allowable MD TVD MD TVD Ref Offset TFO+AZf TFO-HS tasingBSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8950.00 8738.00 8950.00 8738.05 10.67 10.72 302.76 176.89 3.500 0.14 82.71 -82.57 FAIL 8998.65 8779.33 9000.00 8783.10 10.72 10.78 263.90 157.68 3.500 6.20 84.25 -78.04 FAIL 9044.40 8808.18 9050.00 8817.41 10.56 10.61 237.94 141.38 3.500 13.60 85.77 -72.16 FAIL 9087.85 8824.17 9100.00 8837.33 10.24 10.28 214.81 129.76 3.500 21.16 85.42 -64.26 FAIL 9130.54 8827.99 9150.00 8843.62 9.95 9.97 205.21 130.55 3.500 24.05 78.99 -54.94 FAIL 9176.00 8826.13 9200.00 8845.29 9.55 9.57 193.45 131.13 3.500 29.16 75.59 -46.44 FAIL 9221.35 8824.00 9250.00 8846.90 9.42 9.46 180.75 125.69 3.500 39.32 77.30 -37.98 FAIL 9262.39 8821.85 9300.00 8844.82 9.35 9.42 162.42 113.93 3.500 56.70 82.14 -25.44 FAIL 9298.05 8819.85 9350.00 8842.02 9.31 9.42 148.53 105.75 3.500 81.82 84.90 -3.07 FAIL 9330.74 8817.91 9400.00 8840.87 9.31 9.45 .139.66 102.11 3.500 109.60 85.96 23.63 Pass 9371.20 8815.39 9450.00 8839.58 9.52 9.70 137.00 100.17 3.500 137.27 87.90 49.36 Pass 9431.67 8811.29 9500.00 8836.94 10.07 10.40 142.24 99.36 3.500 158.23 92.09 66.14 Pass 9499.14 8806.36 9550.00 8832.68 10.77 11.25 148.51 98.91 3.500 170.35 97.15 73.20 Pass 9570.21 8802.37 9600.00 8827.11 11.61 12.13 154.92 98.34 3.500 170.65 102.79 67.86 Pass 9639.75 8800.17 9650.00 8824.65 12.48 12.96 162.05 98.66 3.500 162.63 108.05 54.59 Pass 9689.78 8799.54 9700.00 8825.02 13.00 13.46 164.16 99.98 3.500 147.09 110.83 36.26 Pass 9727.79 8798.98 9750.00 8824.21 13.27 13.71 161.52 101.13 3.500 130.79 111.97 18.82 Pass 9733.24 8798.88 9757.00 8824.09 13.31 13.75 161.15 101.30 3.500 128.74 112.13 16.62 Pass L5-1 ~, AL1, AL1-0 , AL2 S~LFEI'Y NDT~: r~T 1~t1 r~ (PPi~~iC U Sidetrack Update 8-18-0 I ~^ 7!3' THJ~~, 14 ~ 3.973' iG-3r1' C~~ L5.5N. L-8G. ~ - 9953' ~-~ A006' 4 1/2" 12.6#, L-80, IBT-Mod. Tbg. 5 GLM's Deepest GLV 8380 MD (8155ss) 4 1/2" x 7 5/8" Baker Packer 8460 MD 4 1/2" X Nipple i~e• ~. ~.~*. Leo. o -sei5• ~ Status of LS-16AL1-01 • • Subject: Status of L5-16AL1-01 From: "Barber, Greg J" <SarberJG@BP.com> Date: Fri, 18 Aug 2006 10:51:59 -0800 To: winton_aubert@admin.state.ak.us CC: "Hubble.., Terrie-L" <Terrie.Hubble@BP.com~ Winton, Just to summarize our telephone conversation of earlier today. Nordic 2 is drilling a coil tubing underbalanced program on the L5-16 parent well. We have drilled and completed the "A" lateral. We are currently drilling the L5-16AL1 lateral. We drilled to a measured depth of 9759' and encountered significant hole problems. I contacted you yesterday for the verbal permission to begin an openhole sidetrack lateral from L5-16AL1. We did this in the L5-16AL1 lateral at a measured depth of 9260'. We drilled ahead to 9370', for 110' of new hole. Unfortunately, we again encountered hole problems. Due to the nature of the problems we are experiancing, we intend to cancel further attempts to deepen this lateral. As it exists now we have the L5-16AL1 lateral with TD at 9759' MD, with a shorter section of hole from 9260'-9370'. It is my understanding from our conversation that you do not wish to have any additional permit to drill for this small section of hole. Going forward we plan to still attempt to achieve the 2 laterals to the 2 Lisburne zone 5 TD's as documented in the original permit to drill. This will requre 2 more laterals from where we are now. The first window will be to achieve the original TD targeted by the L5-16AL1 lateral that we failed to reach. The second window will be to achieve the target that has been permitted as L5-16AL2. ~ What I propose to do is to submit a new permit to drill for L5-16AL2. It will have a revised TD that will take it to what was originally targeted by the L5-16AL1 lateral. Should we still have time to drill the last lateral I will submit a permit to drill and we will name that lateral L5-16AL3. Please write me back if this summary is different that what you understood from our conversation. Thank you, Greg Barber - PE Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberjg@bp.com «L5-16A, L1, L1-01, L2 Update 8-18B.pdf» Yom, ~~ °~ ~q iFa ao ~~ ~~-~ _ _ _ _ _ Content-Description: $ 18B.pdf1, L1-01, L2 Update I '~L5-16A, L1, L1-01, L2 Update 8-18B.pd~ Content-Type: application/octet-stream Content-Encoding: base64 'ail, 1 of 1 8/18/2006 11:04 AM • ` Terri Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF First. Nation'al`Bank Alaska AnchorQagMe,~ AK 99501 MEMO ~V/~ . ~I~L LS'~(of}tr2- "Mastercard Check" C~ • as-sn zsz 296 DATE ~Zt'~ $ ~ va ~:i25200060~:99L46227i556~~' 0296 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ ~~~ ~ ~ PTD# 20~ - ~ 6~ X Development Service Exploratory Stratigraphic Test Non-Conventional W ell Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK j ADD-ON'S ! TEXT FOR APPROVAL LETTER V6'HAT i (OPTIONS) APPLIES i I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ we l l P ~r- ,,~-- /~~j~ (If fast two digits ~ i API number - in ~ Permit No,,,~p, .~~ -dQ API No. ~0-O2~-z r 7~,Gy o are ; -~_~ between 60-69) Production should continue to be reported as a function of the original API number stated above. i PILOT HOLE In accordance with 20 AAC 25.005(f}, all records, data and logs acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number (~0- - -`) from records, data and logs f acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.05~. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH i AI[ 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. j i Non-Conventional ~ Please note the following special condition of this permit: ~ production or production testing of coal bed methane is not allowed Well for (name of well) until after ~Com~anv Name) has designed and j tmplemented a water well testing program to provide baseline data j on water quality and quantity. _(Company Name) must contact the Commission to obtain advance approval of such water well testing ~ Rev: I i2~106 C:~jody\transmittal checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, LI56URNE OIL - 640144_ _ _ Well Name: PRUDHO_ E BAY_U_N_LIS L5-_i_6AL2 ___ Program DEV Well bare seg ` ' PTD#:2060850 Company 8P EXPLORATI_ON ~ALASKA)_INC ___ _ __ _ _ __-_ ________ .Initial Classlfype _ DEV l 1-OIL GeoArea 890___ _ _ Unit 1.1650_ _ __ On/Off Shore On Annular Disposal ',_ Administration 1 Permit fee attached- Yes - drilling operations are underway. '2 Lease number appropriate Yes ~~3 Unique well name and number Yes - - '4 Well located in a-defined pool.. - _ Yes - 5 Well located proper distance-from drilling unit boundary- - - - Yes - - ~6 Well located proper distance from other wells- Yes - 8122 While drilling the L5-16AL1 BP encountered mechanical-problems requiring the latteral to be prematurely. ',7 Sufficient acreage available in-drilling unit Yes Tq'd. The L5-16AL2 has subsequently been redirected to a new BHL. The original BHL for L5-16AL2 was. - - 8 Itdeyiated, is-wellbore plat. included Yes - 1 T FNL, 541' FWL Sec 12, T11 N, R15E, UM- The new reissued permit has aBHL of-2271' F$L, 1966' FWL, Sec !9 Operator only affected party Yes - - T11 N, R15E,11M.-RPC ~I10 Operator has appropriate bond in force _ - Yes - I,11 Permit can be issued without conservation order- _ _ _ Yes - - - 12 Permitcan be issued without administrative-approval _ Yes - - _ Apps Date 13 Can permit be approved before 15-daywait Yes - - RPC 812212006 !14 Well located within area and strata authorized by Injection Order # (put 10# in-comments). (For- NA_ - - - 15 All wells-within 114 mile area-of review identified (For service well only) - - - - NA. ~16 Pre-produced injector; duration ofpre-production less-than 3 months (For_service well-only) NA- . Nonconven. gas conforms io AS31 05 030Q.1.A) ~.2.A-D) NA 8 - - - - - -- Conductor st[ing_provided A_ - - --- - -- - - - ---- Engineering 19 Surface casing protects all known USDWs - NA- - - 20 CMT vol adequatelo circulate on conductor-& surf csg - NA , - - 21 CMT vol adequate to tie-in long string to surf csg NA- '22 CMT-will cover-all kno_wnproductiye horizons- No- - - - - Open hole completions. 23 .Casing designs adequate for C, T, B & permafrost - NA- _ - - None planned. X24 Adequate tankage or reserve pit - Yes - - ; - CTDU. I25 If a re-drill, has a 10-403 for abandonment been approved - - _ _ _ - - - - .Yes . - - 313012006.. x,26 Adequate wellbore separation proposed - - - Yes 'i27 If diverter required, does it meet. regulations- NA - - Sidetrack. - - ~,28 Drilling fluid-program schematic & equip-list adequate_ - Yes IJBI) operations approved, Appr Date ',29 BOPEs,-do they meet regulation Yes WGA 8/2312006 30 q pp p (p p 9 ) BOPE-press satin a ro state; test to ut si in comments - . - Yes - - - Test to 3500-psl. -MSP 2294 psi, X31 Choke-manifold complies wlAPLRP-53 (May 84) - _ _ Yes _ _ - !,32 Work will occur without operation shutdown- Yes - - - - 1133 Is presence of H2S gas_probable - Yes - _ 60 ppm expected, !34 Mechanical condition of wells within AOR verified (For-service well only) - . - - - NA - I35 Permit, can be issued w/o hydrogen sulfide measures . - - No_ __ -- __ -_ Geology j36 Data presented on-potential overpressure zones _ - - _ _ NA _ - - I,37 Seismic analys_is_ of shallow gas zones_ - _ NA_ _ - - _ _ ----- ---------- Appr Date X38 Seabed condition survey-(ifoff-shore) . - - NA - - - - - RPC 812212006 ';39 Contact namelphone for weekly-progress reports [exploratory only] NA_ - Geologic Engineering lic Commissioner: te: Co issioner: Date Co mis ' n Date ~~~~~ ~ ~"91~~4 DTS '~A96+ 6/2012006 ~~ • q ~{ ~, 1~ ~4 ~ 7 1 1 h p{+~ ~S / 3 ' 3r '1j{ ALASSA Olli A1QD (sAaS C011TSERQATIOI~T COrII~IISSIOI~T Greg Sarber CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 f FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 700 ANCHORAGE, ALASKA 99501-3539 J PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L5-16AL2 BP Exploration (Alaska) Inc. Permit No: 206-085 Surface Location: 1788' FSL, 19' FWL, SEC. 01, T 11 N, R 15E, UM Bottomhole Location: 17' FNL, 541' FWL, SEC. 12, T11N, R15E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well PBU L5-16A, Permit No. 206- 083, API 50-029-21700-01. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of June, 2006 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Rio V ~~ft.~li,~ Ofv STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMII~ION SUN 1 ~ 2006 PERMIT TO DRILL ssion 20 AAC 25.005 ~:luske Gt1 ~ Gas Cons. CtN~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class O Exploratory p Development Gas O Service O Multiple Zone O Stratigraphic Test ®Development Oil O Single Zone 1 c. Specify if well is pro ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L5-16AL2 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed D h' MD 1 70 TVD 8731 12. Field /Pool(s): Prudhoe Bay Field / Lisburne 4a. Location of Well (Governmental Section): Surface: 19' FWL T11N R15E 1788' FSL SEC 01 UM 7. Property _ ignation: ADL 028320 Pool , , , , . , Top of Productive Horizon: 1245' FSL, 1005' FWL, SEC. 01, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 12, 2006 Total Depth: 17' FNL, 541' FWL, SEC. 12, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6320' 4b. Location of Well (State Base Plane Coordinates): Surface: x-717447 y-5974920 Zone-ASP4 10. KB Elevation (Height above GL): 60 feet 15. Distance to Nearest Well Within Pool: 2850' 16. Deviated Wells: Kickoff Depth: 8923 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3184 Surface: 2294 18. Casin Pro .ram: Specificafrons Top -,Settin ? De th -Bottom Quanti of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 19. PRESENT WELGCONDITION SUMMARY (To be completed for Redrill and Re-entry Operations} Total Depth MD (ft): 10822 Total Depth TVD (ft): 8893 Plugs (measured): None Effective Depth MD (ft): 10822 Effective Depth TVD (ft)' 8893 Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 120' 20" 1800# Poleset 120' 120' Surface 4006' 10-3/4" 1300 sx AS III, 325 sx Class 'G' 4006' 3998' Intermediate Production 9559' 7-5/8" 425 sx Class 'G' 9559' 9298' Liner Scab Liner 403' 4-1/2" 97 sx Class 'G' 8803' - 9206 8603' - 8974' Perforation Depth MD (ft): Open Hole Completion for L5-16A & L5-16AL 1 Perforation Depth TVD (ft): Open Hole Completion 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. 1 hereby certify that the foregoing is true and correct. Printed Name Greg S rber Title CT Drilling Engineer Si nature Phone 564-4330 Date Contact Greg Sarber, 564-4330 ed tagg, 5 4-4 Prepared By Name/Number: ` - %S~-Q~0 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: 2 .-[~ API Number: Permit Approval 50-029-21700-61-00 Date: ~ See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales l Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No ~ >e 5 ~ ~j O P ~` l D Tj SD O ~ u~ HZS Measures: Yes ^ No Directior~ Survey Req:d: Yes ^ No P~,cr s uau~- {-~ 2fl /~C 25, 0 33 ~ z ~ ~ ttac,d e.• ti~•.~~r-C.d d ~ l l 1 . `'`~,~ ~ Gam. ~~t~(!e oI . ~~ ~ ~ O /' 1~PROVED BY THE COMMISSIO ~"j ,COMMISSIONER Form 10-401 Revised 12/2005 ®{ ~ ~ ~' ~ ~ ~ "r `~ Submit In iDupliCate ~ • BP L5-16A, AL1, AL2 UBCTD Sidetrack Discussion of Operations: Well L5-16 is the 2~d of two planned underbalanced CTD, thru tubing sidetrack wells planned for the summer of 2006. L5-16 was originally drilled in March of 1987, and completed in zones 4,5, and 6. It has produced at total of 1.53 MMBO since it was originally brought on line in 1987. Currently the well is cycling between 400-500 BOPD. The well is typically on line for approximately 5 days until it reaches MGOR of 30,000 SCF/STB. The well is shut in for approximately 20 days. The cycle has been repeating for the last several years. No outstanding integrity issues exist with the parent wellbore. Extensive stimulation work has been performed on this well and there is little opportunity for further well work. Nordic 2 rigged up on L5-16 on May 12, 2006, and successfully completed a workover in preparation for the CTD UBD sidetrack. That work was completed under Sundry Approval 306-120. The sidetracks, L5-16A, L5-16A Li ,and L5-16A L2 will kick off from separate windows milled from mechanical whipstocks set in Lisburne Zone 4. Targets for the 3 laterals are in zone 4, 5, and 6. If real time well testing does not indicate that the wells have encountered fracturing or high productivity rock, an open hole sidetrack in a different azimuthal direction will be considered, but will not be permitted at this time due to uncertainty over the alternate well path. If an open hole sidetrack of L5-16A proves to be needed, then a Permit application for an additional lateral will be submitted at that time. This is the 2"d of 2 CTD underbalanced wells planned for the Lisburne field this summer. Extensive planning for success has been made, and is ongoing. Blade Energy Partners, which is a consulting, firm specializing in UBD has been engaged to assist in project planning, personnel training, and on side assistance during the drilling phase of the project. Well control equipment has been designed specifically for the planned operation and procedures have been written to cover each aspect of the operation. There has been HSE and operational training conducted for the town and field staff using a UBD simulator. All relevant contractors, crew and engineering staff have completed this training. HAZid and HAZop procedures have been completed and overall planning has been Peer reviewed by operating partners and outside experts with specialization in coil tubing and underbalanced drilling operations. This underbalanced coil tubing drilling operation will use diesel as the power fluid and gas lift to achieve an underbalance of 200-400 psi while drilling. Return fluids will flow to an on site separator supplied by ASRC. The fluids will be separated and measured, then flowed to the Lisburne Production Center (LPC) at about 600 psi line pressure. There will be no flaring or compression involved in the project. The BOP stack drawing is significantly different than a standard CTD rig up, and is attached. This stack incorporates 6 BOP rams, an annular preventor, 2 flow spools, 2 swab valves, and a master valve. The UBD flow spool is located below double swab valves such that produced fluids do not flow through the upper four rams. An ESD valve on the outlet of the UBD flow spool along with double rams (Shear/seal and 2" pipe/slip • ~ combination) located below the UBD flow spool provide emergency shut in capability in the event of a flow line leak. Equipment and procedures for pressure deploying/undeploying the drilling BHA have been used successfully on the managed pressure drilling campaigns in the Kuparuk field in the past few years, and have been refined for the UBD process at Lisburne. A tubing retrievable SSSV has been installed during the workover specifically to provide additional pressure control capability. The attached drawings describe the BOP stack, the P & ID of the full process spread and a flow diagram that includes all surface equipment. Summary of Underbalanced Drilling and Completion Operations: 1. Move rig over well from L5-28. 2. Rig up 2" CTE, UBCTD Stack and BOPE. PT BOPE. 3. Mill L5-16A window with 2% KCL and biozan sweeps. (Top of window at 9100' MD, 8817' SS) 4. Drill L5-16A lateral using diesel/lift gas to achieve underbalance. 5. TD lateral and flow test well for 6 hours. 6. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A. (Top of window at 9040' MD, 8761' SS) 7. Mill L5-16A L1 window with 2% KCL, and biozan sweeps. 8. Drill L5-16A Li lateral using diesel/lift gas to achieve underbalance. 9. TD L1 lateral and flow test well for 6 hours. 10. Recover whipstock tray, and PXX plug. Set guidestock in L5-16A L1 lateral packer. 11. Set Baker whipstock/packer with tailpipe and PXX plug to isolate L5-16A L1. (Top of window at 8923' MD, 8653' SS) 12. Mill L5-16A L2 window with 2% KCL, and biozan sweeps. 13. Drill L5-16A L2 lateral using diesel/lift gas to achieve underbalance. 14. TD L2 lateral and flow test well for 6 hours. 15. Recover whipstock tray and PXX plug from L2 whipstock. Install hollow guidestock into L2 packer. 16. Set BPV. RD and move off well. Post RWO Status: • L5-16 has been worked over. The original perforations have been successful squeezed off. A 4-1/2" scab liner has been run and cemented. The production tubing has been replaced with new 4-1/2" L-80 tubing. A gas lift design has been run and the well is ready for the drilling phase of operations. Mud Program: The window will be milled with 2% KCL with ~/z ppb Biozan. Sweeps will be 2 ppb Biozan. • The 3 lateral sections will be drilled with diesel as the power fluid with gas lift used to underbalance the well. Viscosified mineral oil sweeps will be used for hole cleaning during drilling. • • • Kill Weight Fluid. 2% KCL will be in the rig pits on location. BHP with 2% KCL will be 3864 psi. Measured BHP is 3184 psi. 2% KCL will overbalance the formation pressure by 680 psi. OH/Tubing volume = 153 bbls. Disposal: • During the drilling phase all fluid and gas returns from the well will be pumped down the L5 pad production line and sent to the Lisburne Production Center for recycling. • All drilling and completion waste fluids and any other Class II wastes will go to Grind and Inject, or Pad 3. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • None. All laterals will be completed open hole. Well Control: • The BOP schematic, P & ID drawing, and fluid flow diagrams are attached. • Pipe rams, blind rams and the CT pack-ff will be pressure tested to 400 psi and 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional: See attached directional plans. Maximum planned hole angle is approximately ~97 deg. Magnetic and inclination surveys will be taken every 30'. No Gyro survey will be run. Logging: • An MW D Gamma Ray log will be run of the entire open hole section. Hazards mitigated through training, procedures, and UBD equipment: • Hydrogen Sulfide -Maximum H2S measured on L5 pad is 600 ppm (3-27-92) on L5- 12. L5-16 has recorded H2S at 50 ppm on 1-9-2006, and the lift gas has an H2S concentration of 60 ppm. • Maximum BHP is expected to be 3184 psi @ 8900' SS (6.9 ppg). Maximum anticipated surface pressure with a full column of gas to surface is 2294 psi. • A combustible power fluid will be used. (Diesel) Flash Point 100 deg F o Fire, Environmental, Health (exposure), impact on other equipment (elastomers) • A combustible artificial lift fluid will be used. (Natural Gas) o Fire, H2S, Health (exposure) • Produced Fluids will be present in returned fluids. (Oil and Natural Gas) o Fire, Environmental, H2S, Health (exposure), impact on other equipment (elastomers) • Pressure - 650 to 1000 psi on surface. o Leaks, loss of containment, pipe whip • SIMOPS -Drilling/Production. • New Procedures for most people involved -Human Error. • Additional Equipment -Escape areas, slips and trips. • Poor Hole Cleaning -Stuck Pipe • Hole Instability - Mudstones Reservoir Pressure: • Bottom Hole Pressure was measured at 3184 psi at 8900' TVDSS (6.9 ppg) Maximum surface pressure with gas (0.1 psi/ft) to surface is 2294 psi. BP Drilling Contacts: • Greg Sarber 564-4330, 242-8000 cell • Ted Stagg 564-4694, 240-8074 cell • Mark Johnson 564-5666, 240-8034 cell Attachment List Proposed schematic Existing schematic L5-16A directional plan L5-16A L1 directional plan L5-16A L2 directional plan Lisburne UBD block flow diagram Lisburne UBD BOP stack-up Lisburne UBD P&ID Lisburne UBD site layout SIti F ETY IYOT~: CJLT 1 X11 F~ (PP I~ZSG L5-16 Post Workover 0.3B1~' 5 GLM's #1 - 8,615 #2 - 7,602' #3 - 6, 387' #4 - 4,708' #5 - 2,781' 0-999• AU06` ~ ~ ~~ 8683' - 4 1/2" X Nipple 8704' - 1/2" x 7 5/8" Baker SB3-A Packer 11'1Q' 790, 1~9;M, L-8D, BT-Yr I 4 1/2" Scab Liner Cemented inside 7 5/8" liner 4 1/2" 12.6#, L-80, IBT-Mod Scab Liner @ 9,206' M P Bl'0 81178' 8727' - 4 1 /2" X Nipple 1/2" x 7 5/8" HMC hanger and ZXP packer Packer @ 8,802', Hanger @ 8,820' 8964 M D - Top of fill ~ 9280 9378 MD L5-16A, AL 1, AL2 Prop. UBCTD Sdrtks. • 10-3C1' Cam, ~5.5M, L-90, O - 9953' ~ 4 1/2" 12.6#, L-80, IBT-Mod. Tbg. 5 GLM's 1 - 8615' 2 - 7602' 3 - 6387' 4 - 4708' 5 - 2781' SIL F ETY NDTI~: ~JLT I ~U FQS (PP 1~~50 Ik+Q•Tit~r, a -38~~• 8704' - 4 1/2" x 7 5/8" Baker Packer 8727' - 4 1/2" X Nipple Liner Hanger/Packer 8802' MD L5-16AL2: 8923 MD, 8653ss L5-16AL1: 8960' MD, 8687'ss L5-16A: 9100 MD, 8817ss L5-16AL2 Zones 5 & 6 ~ L5-16AL1 Zones 4 and 5 I L5-16A Zone 4 I 4 1/2" 12.6#, L-80, IBT-Mod 9,206` MD~ PBT17 9473' BP Alaska by Baker Hughes INTEQ Planning Report BAIQR ^ ~cili~s INTEQ Company: BP Amoco Date: 6/11/2006 Time: 12:29:41 Page: 1 Fiehic Lisburne Co~ordinate(NE) Refereoce: Well: L5-16; True North Site: Lis DS 05 Vertical(TYD)Reference: 9:16 3/2/1987 00:00 60.0 WeIL L5-16 Seetion(VS)Reference: Well (O.OON;O.OOE,190.OOAzi) Welipath: Plan 1, L5-16AL2 Snrvey CakulaNon Method: Minimum Curvature Db: OraGe Field: Lisburne 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: bggm2005 Site: Lis DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5969995.70 ft Latitude: 70 19 15.771 N From: Map Easting: 712359.13 ft Longitude: 148 16 41.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.62 deg Well: LS-16 Slot Name: 16 LS-16 Well Positron: +N/-S 4778.96 ft Northing: 5974920.34 ft Latitude: 70 20 2.754 N +E/-W 5224.93 ft Easting : 717446.51 ft Longitude: 148 14 8.827 W Position Uncertainty: 0.00 ft Welipath: Plan 1, L5-16AL2 Drilled From: L5-16 Tie-on Depth: 8921.35 ft Current Datum: 9:16 3/2/1987 00:00 Height 60.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6!9/2006 Declination: 24.72 deg Field Strength: 57626 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft dog 40.00 0.00 0.00 190.00 Plan: Plan #1 Date Composed: 6/9/2006 match Ted's case 201 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets Map Map c~ Latitude .--> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing:.: .Easting Deg: Min Sec :Deg Min Sec Dip. Din Annotation MD TVD ft ft 8921.35 8711.52 TIP 8923.00 8713.05 KOP 8943.00 8731.44 End of 9 Deg/100' DLS 9024.00 8791.03 4 9105.00 8811.24 End of 45 Deg/100' DLS 9259.00 8803.51 6 9490.00 8791.87 7 9570.00 8787.81 8 9690.00 8781.11 9 8950.00 8737.76 10 9990.00 8764.43 11 10182.00 8762.28 12 10310.00 8770.36 13 10470.00 8791.41 TD Plan Section Information MD Intl Azim TVD +N/-S +E/=W DLS Build ...Turn TFO .:.Target ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg 8921.35 22.20 125.65 8711.52 -546.46 992.19 0.00 0.00 0.00 0.00 8923.00 22.20 125.67 8713.05 -546.82 992.70 0.46 0.00 1.21 90.01 8943.00 24.00 125.67 8731.44 -551.40 999.07 9.00 9.00 0.00 0.00 9024.00 59.49 139.31 8791.03 -588.73 1036.47 45.00 43.81 16.84 20.00 9105.00 91.47 157.67 8811.24 -654.88 1075.94 45.00 39.49 22.66 32.00 9259.00 94.24 175.97 8803.51 -803.98 1110.89 12.00 1.80 11.88 81.00 9490.00 91.43 203.58 8791.87 -1029.11 1072.04 12.00 -1.21 11.95 95.00 9570.00 94.37 212.73 8787.81 -1099.47 1034.39 12.00 3.67 11.44 72.00 9690.00 92.00 226.96 8781.11 -1191.20 957.81 12.00 -1.97 11.86 99.00 BP Alaska by Baker Hughes INTEQ Planning Report BAI~R ^ Nua~s INTEQ Company: BP Amoco Date: 6/11/2006 Time: 12:29:41 Page: 2 Fie1d:S Usbume Co-ordinste(NE) Reference: WeIC L5-16, True North :Sites Lis DS 05 Vertical (TVD) Reference: 9 :16 3/2/1987 00:00 60. 0 Well; 15-16 Sectio n(V5)Reference: Well (O.OON,O.OOE,190.OOAzi) Wellpath: "Plan 1, L5-16AL2 Survey CaMalation Method: Minimum Curvature Db: Orade Plan Section Information M71 Intl Azim TVD r+N/S +E/-W DI.S Bnitd Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9850.00 94.19 207.86 8772.39 -1317.49 861.19 12.00 1 .37 -11.94 277.00 9990.00 92.28 191.14 8764.43 -1448.78 814.72 12.00 -1 .36 -11.94 264.00 10182.00 88.98 213.95 8762.28 -1624.91 741.60 12.00 -1 .72 11.88 98.00 10310.00 83.82 228.44 8770.36 -1720.77 657.76 12.00 -4 .04 11.33 110.00 10470.00 81.21 247.63 8791.41 -1804.40 523.87 12.00 -1 .63 11.99 99.00 Survey MD Inch Azim Sys.TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg. deg ft ft ft ft ft deg/100ft ft deg 8921.35 22.20 125.65 8651.52 -546.46 992.19 5974402.91 718454.08 0.00 365.86 0.00 MWD 8923.00 22.20 125.67 8653.05 -546.82 992.70 5974402.56 718454.60 0.46 366.13 90.01 MWD 8943.00 24.00 125.67 8671.44 -551.40 999.07 5974398.17 718461.10 9.00 369.53 0.00 MWD 8950.00 26.98 128.04 8677.76 -553.21 1001.48 5974396.43 718463.56 45.00 370.90 20.00 MWD 8960.00 31.29 130.70 8686.49 -556.30 1005.24 5974393.45 718467.40 45.00 373.29 17.86 MWD 8970.00 35.65 132.77 8694.83 -559.97 1009.35 5974389.89 718471.62 45.00 376.19 15.54 MWD 8980.00 40.03 134.43 8702.73 -564.20 1013.79 5974385.79 718476.18 45.00 379.59 13.81 MWD 8990.00 44.43 135.82 8710.13 -568.97 1018.52 5974381.17 718481.05 45.00 383.46 12.49 MWD 9000.00 48.85 137.01 8717.00 -574.24 1023.53 5974376.05 718486.21 45.00 387.78 11.46 MWD 9010.00 53.27 138.05 8723.28 -579.97 1028.78 5974370.47 718491.62 45.00 392.51 10.65 MWD 9020.00 57.71 138.97 8728.95 -586.14 1034.24 5974364.46 718497.26 45.00 397.65 10.00 MWD 9024.00 59.49 139.31 8731.03 -588.73 1036.47 5974361.94 718499.56 45.00 399.80 9.47 MWD 9030.00 61.79 140.94 8733.97 -592.74 1039.82 5974358.03 718503.03 45.00 403.17 32.00 MWD 9040.00 65.66 143.49 8738.40 -599.83 1045.31 5974351.10 718508.72 45.00 409.20 31.20 MWD 9050.00 69.57 145.90 8742.21 -607.37 1050.65 5974343.72 718514.28 45.00 415.70 30.07 MWD 9060.00 73.51 148.18 8745.37 -615.33 1055.81 5974335.91 718519.66 45.00 422.64 29.15 MWD 9070.00 77.48 150.38 8747.88 -623.65 1060.75 5974327.74 718524.85 45.00 429.98 28.43 MWD 9080.00 81.47 152.50 8749.70 -632.28 1065.45 5974319.24 718529.79 45.00 437.66 27.88 MWD 9090.00 85.46 154.58 8750.84 -641.18 1069.88 5974310.48 718534.47 45.00 445.65 27.49 MWD 9100.00 89.47 156.64 8751.28 -650.27 1074.00 5974301.51 718538.86 45.00 453.90 27.26 MWD 9105.00 91.47 157.67 8751.24 -654.88 1075.94 5974296.96 718540.93 45.00 458.10 27.16 MWD 9125.00 91.84 160.04 8750.66 -673.52 1083.15 5974278.53 718548.68 12.00 475.20 81.00 MWD 9150.00 92.31 163.01 8749.76 -697.22 1091.07 5974255.08 718557.28 12.00 497.16 81.07 MWD 9175.00 92.76 165.98 8748.65 -721.28 1097.75 5974231.22 718564.65 12.00 519.70 81.18 MWD 9200.00 93.21 168.95 8747.35 -745.65 1103.17 5974207.02 718570.78 12.00 542.76 81.31 MWD 9225.00 93.65 171.92 8745.85 -770.25 1107.31 5974182.55 718575.63 12.00 566.27 81.46 MWD 9250.00 94.08 174.89 8744.16 -795.03 1110.18 5974157.87 718579.22 12.00 590.17 81.64 MWD 9259.00 94.24 175.97 8743.51 -803.98 1110.89 5974148.95 718580.19 12.00 598.86 81.84 MWD 9275.00 94.07 177.88 8742.35 -819.91 1111.75 5974133.05 718581.51 12.00 614.40 95.00 MWD 9300.00 93.79 180.88 8740.64 -844.85 1112.02 5974108.13 718582.50 12.00 638.91 95.14 MWD 9325.00 93.51 183.87 8739.05 -869.77 1110.98 5974083.18 718582.19 12.00 663.64 95.34 MWD 9350.00 93.21 186.86 8737.58 -894.62 1108.65 5974058.28 718580.58 12.00 688.51 95.53 MWD 9375.00 92.91 189.85 8736.24 -919.31 1105.02 5974033.49 718577.67 12.00 713.46 95.71 MWD 9400.00 92.60 192.84 8735.04 -943.79 1100.11 5974008.88 718573.47 12.00 738.42 95.87 MWD 9425.00 92.28 195.82 8733.98 -967.99 1093.93 5973984.52 718567.99 12.00 763.33 96.01 MWD 9450.00 91.96 198.81 8733.05 -991.84 1086.49 5973960.47 718561.25 12.00 788.10 96.14 MWD 9475.00 91.63 201.79 8732.27 -1015.27 1077.83 5973936.79 718553.27 12.00 812.69 96.25 MWD 9490.00 91.43 203.58 8731.87 -1029.11 1072.04 5973922.80 718547.89 12.00 827.31 96.34 MWD 9500.00 91.80 204.72 8731.58 -1038.23 1067.95 5973913.56 718544.06 12.00 837.01 72.00 MWD 9525.00 92.72 207.58 8730.60 -1060.65 1056.95 5973890.83 718533.71 12.00 861.00 72.03 MWD 9550.00 93.64 210.44 8729.21 -1082.48 1044.84 5973868.66 718522.24 12.00 884.60 72.15 MWD 9570.00 94.37 212.73 8727.81 -1099.47 1034.39 5973851.37 718512.29 12.00 903.15 72.30 MWD 9575.00 94.27 213.33 8727.44 -1103.65 1031.67 5973847.12 718509.70 12.00 907.73 99.00 MWD 9600.00 93.80 216.30 8725.68 -1124.12 1017.44 5973826.24 718496.06 12.00 930.37 99.04 MWD 9625.00 93.31 219.26 8724.13 -1143.84 1002.15 5973806.09 718481.35 12.00 952.44 99.25 MWD 9650.00 92.81 222.23 8722.79 -1162.75 985.86 5973786.72 718465.62 12.00 973.89 99.44 MWD 9675.00 92.31 225.19 8721.67 -1180.80 968.61 5973768.17 718448.90 12.00 994.67 99.60 MWD 9690.00 92.00 226.96 8721.11 -1191.20 957.81 5973757.46 718438.41 12.00 1006.78 99.73 MWD 9700.00 92.15 225.77 8720.75 -1198.10 950.58 5973750.36 718431.38 12.00 1014.83 277.00 MWD 9725.00 92.51 222.79 8719.73 -1215.98 933.14 5973731.98 718414.47 12.00 1035.47 276.96 MWD BP Alaska by Baker Hughes INTEQ Planning Report s~R ~ s INTEQ Coropaay: BP Amoco - Date: 6/11/2006 Tiroe: 12:29:41 Page: 3 Feld: l.isbume Co-ordinate(NE) Reference: Well: L5-16, True North Site: Lis. DS 05 ' .Vertical (TVD) Reference: 9 :16 3/2/1987 00:00 60.0 We1L• L5- 16 Section(VS)Reference: Well (O.OON, O.OOE,190: OOAzi) Wellpath: Plan 1, L5 1 6AL2 Survey CalcnlationMethod: Minimum Curvature Db: Oracle Survey MD Intl Aziro SysTVD `N/S EIVY MspN MapE DIS VS TFO Tool ft deg deg ft ft ft ft' ff deg/100ft ft deg 9750.00 92.86 219.81 8718.56 -1234.74 916.66 5973712.76 718398.54 12.00 1056.80 276.84 MWD 9775.00 93.21 216.82 8717.24 -1254.32 901.19 5973692.73 718383.64 12.00 1078.78 276.70 MWD 9800.00 93.55 213.84 8715.76 -1274.68 886.76 5973671.96 718369.80 12.00 1101.33 276.54 MWD 9825.00 93.87 210.85 8714,14 -1295.76 873.41 5973650.51 718357.08 12.00 1124.41 276.36 MWD 9850.00 94.19 207.86 8712.39 -1317.49 861.19 5973628.43 718345.49 12.00 1147.93 276.17 MWD 9875.00 93.87 204.87 8710.63 -1339.83 850.12 5973605.78 718335.07 12.00 1171.86 264.00 MWD 9900.00 93.54 201.88 8709.01 -1362.73 840.22 5973582.61 718325.84 12.00 1196.13 263.79 MWD 9925.00 93.20 198.89 8707.54 -1386.12 831.53 5973558.97 718317.83 12.00 1220.67 263.60 MWD 9950.00 92.85 195.91 8706.22 -1409.94 824.06 5973534.95 718311.06 12.00 1245.43 263.42 MWD 9975.00 92.50 192.93 8705.05 -1434.13 817.84 5973510.60 718305.55 12.00 1270.32 263.26 MWD 9990.00 92.28 191.14 8704.43 -1448.78 814.72 5973495.86 718302.85 12.00 1285.30 263.12 MWD 10000.00 92.11 192.33 8704.04 -1458.57 812.69 5973486.02 718301.10 12.00 1295.29 98.00 MWD 10025.00 91.69 195.30 8703.21 -1482.83 806.72 5973461.60 718295.84 12.00 1320.21 98.05 MWD 10050.00 91.26 198.27 8702.57 -1506.75 799.51 5973437.47 718289.32 12.00 1345.03 98.14 MWD 10075.00 90.83 201.24 8702.11 -1530.27 791.06 5973413.72 718281.56 12.00 1369.66 98.22 MWD 10100.00 90.40 204.21 8701.84 -1553.33 781.40 5973390.39 718272.58 12.00 1394.04 98.28 MWD 10125.00 89.97 207.18 8701.76 -1575.86 770.57 5973367.56 718262.40 12.00 1418.11 98.31 MWD 10150.00 89.53 210.15 8701.87 -1597.79 758.58 5973345.29 718251.05 12.00 1441.79 98.32 MWD 10175.00 89.10 213.11 8702.17 -1619.07 745.47 5973323.64 718238.57 12.00 1465.02 98.30 MWD 10182.00 88.98 213.95 8702.28 -1624.91 741.60 5973317.70 718234.87 12.00 1471.44 98.27 MIND 10200.00 88.24 215.98 8702.72 -1639.65 731.29 5973302.66 718225.00 12.00 1487.75 110.00 MWD 10225.00 87.22 218.80 8703.71 -1659.50 716.13 5973282.38 718210.41 12.00 1509.93 109.95 MWD 10250.00 86.21 221.63 8705.14 -1678.56 700.02 5973262.86 718194.86 12.00 1531.50 109.84 MWD 10275.00 85.20 224.46 8707.01 -1696.77 683.00 5973244.16 718178.38 12.00 1552.39 109.68 MWD 10300.00 84.21 227.30 8709.32 -1714.10 665.13 5973226.32 718161.02 12.00 1572.56 109.46 MWD 10310.00 83.82 228.44 8710.36 -1720.77 657.76 5973219.44 718153.84 12.00 1580.41 109.20 MWD 10325.00 83.54 230.23 8712.02 -1730.49 646.45 5973209.41 718142.82 12.00 1591.94 99.00 MWD 10350.00 83.09 233.22 8714.93 -1745.86 626.96 5973193.47 718123.79 12.00 1610.47 98.80 MWD 10375.00 82.66 236.21 8718.03 -1760.19 606.71 5973178.56 718103.96 12.00 1628.10 98.46 MWD 10400.00 82.24 239.21 8721.32 -1773.43 585.76 5973164.72 718083.41 12.00 1644.77 98.08 MWD 10425.00 81.85 242.21 8724.78 -1785.54 564.17 5973151.99 718062.18 12.00 1660.45 97.69 MWD 10450.00 81.48 245.22 8728.40 -1796.49 541.99 5973140.40 718040.33 12.00 1675.08 97.27 MWD 10470.00 81.21 247.63 8731.41 -1804.40 523.87 5973131.97 718022.45 12.00 1686.02 96.84 3.50" • a ~~ ~j,~ ~ ~€ ~ ~~ } e sRC ig~ ~8~ I~~ .~ ~8f II a s ca ~ Y s~ ~ -~ ~; ~;m me ~J w2 Q ~ ; m ~~ ~~ ~ ~s a 3 ;9 ~ ; r 0 8. 0 v • C a ~,,, ~ III ~~ F~~1I is4 i 4 '3 'f~_. ^~ff VIII a S u~ wig $ ° =v a ~ Q ' f ~~ a ~~ s~ a~ m ~~ '~ ~f 0 8 a • • ~ ~ ~ II. 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Lisburne Reference Site: Lis-0S 05 Co-ordinate(NE) Reference: Well: L5-1 6, True North Reference Welle L5-16 Vertical (TVD) Reference: 9`: 16 3/2! 1987 00:00 60.0 Refere~rce Wellpathc Plan 1, L5-16AL2 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Refereuce: Prinapal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8921.35 to 10470.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/9/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 60.00 8921.35 1 : Schlumberger GCT multishot GCT-MS SGtlumberger GCT multishot 8921.35 10470.00 Planned: Plan #1 V5 MWD MWD - Standard Casing Points MD TVD Diameter 13ok Size Name ft tt in in 10470.00 8791.41 3.500 4.500 3.50" Summary Offset Wegpath ----- ----.--~ Refereace Offset Ctr-Ctr Nato Allowable Site Well Wegpath MD MD Distance Area- Deviation Warning ft ft ft` ft ft Lis DS 05 L5-16 L5-16 V1 8995.88 9000.00 13.91 82.18 -68.27 FAIL: Major Risk Lis DS 05 L5-16 Plan 1, L5-16AL1 Conti 8996.66 9000.00 11.76 77.45 -65.69 FAIL: Major Risk Lis DS 05 L5-16 Plan 1, L5-16AL2 Conti 8995.88 9000.00 13.91 82.18 -68.27 FAIL: Major Risk Lis DS 05 LS-16 Plan 2, L5-16A V1 Plan 8995.88 9000.00 13.91 82.18 -68.27 FAIL: Major Risk Lis DS 05 L5-16 PIan3, L5-16AL1 V1 Pla 8996.66 9000.00 11.76 77.45 -65.69 FAIL: Major Risk Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: L5-16 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warniug- ft ft ft ft ft ft deg deg in ft tt ft 8995.88 8774.23 9000.00 8784.33 10.46 10.64 323.48 186.94 13.91 82.18 -68.27 FAIL 9055.51 8804.03 9100.00 8876.60 10.20 10.65 332.62 185.45 76.76 73.99 2.77 Pass 9085.34 8810.40 9200.00 8968.47 10.06 10.82 340.56 186.94 160.24 69.51 90.73 Pass 9101.60 8811.29 9300.00 9060.12 10.01 11.10 345.26 188.29 251.46 67.73 183.72 Pass 9123.88 8810.70 9400.00 9151.86 9.97 11.19 349.15 189.24 345.82 67.63 278.19 Pass 9148.20 8809.83 9500.00 9243.59 9.93 11.47 352.85 190.06 440.87 67.56 373.31 Pass 9169.89 8808.89 9600.00 9335.31 9.91 11.76 356.14 190.77 536.44 67.53 468.91 Pass Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: Plan 1, L5-16AL1 Contingency VO Plan: Plan #1 V4 Inter-Site Error: 0.00 ft Refereae Offset Semi-Major Axis Ctr-Ctr No-Go Allowabk MD TVD MD TVD Ref Offset _ TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in _ ft ft ft, 8996.66 8774.77 9000.00 8783.28 10.46 10.48 327.11 190.48 11.76 77.45 -65.69 FAIL 9076.12 8809.08 9100.00 8838.55 10.10 10.11 11.03 219.35 38.71 73.75 -35.04 FAIL 9136.09 8810.29 9200.00 8836.51 9.95 10.03 54.76 253.40 91.85 87.97 3.89 Pass 9141.14 8810.10 9300.00 8829.82 9.94 10.05 65.89 263.93 186.61 91.25 95.36 Pass 9121.96 8810.76 9400.00 8823.46 9.97 10.09 67.09 267.41 281.22 92.25 188.97 Pass 9098.22 8811.25 9500.00 8816.91 10.02 10.17 65.40 269.13 370.47 93.11 277.36 Pass 9076.47 8809.14 9600.00 8810.42 10.10 10.29 61.59 269.84 454.17 94.13 360.04 Pass 9062.56 8806.08 9700.00 8804.06 10.17 10.37 58.97 270.22 545.85 94.70 451.16 Pass 9057.37 8804.60 9800.00 8798.03 10.19 10.41 58.21 270.61 644.29 94.91 549.37 Pass 9058.57 8804.96 9900.00 8792.59 10.19 10.41 58.86 271.00 743.86 94.89 648.97 Pass 9061.58 8805.81 10000.00 8787.07 10.17 10.39 59.86 271.33 842.32 94.79 747.53 Pass 9050.00 8802.21 10100.00 8777.88 10.23 10.53 57.52 271.62 926.98 95.29 831.69 Pass 9030.00 8793.97 10200.00 8771.20 10.36 10.94 52.71 271.78 968.94 96.61 872.32 Pass 9005.84 8780.74 10300.00 8775.19 10.43 11.66 48.04 270.41 1002.19 98.34 903.85 Pass 8983.15 8765.12 10400.00 8786.33 10.50 12.91 43.13 268.23 1036.41 100.09 936.32 Pass 8971.73 8756.23 10500.00 8804.49 10.55 13.80 38.81 265.74 1093.78 101.47 992.30 Pass 8966.69 8752.12 10600.00 8827.71 10.57 14.57 35.53 263.40 1169.98 102.28 1067.70 Pass 8964.80 8750.55 10700.00 8850.68 10.58 15.37 33.44 261.69 1259.69 102.56 1157.13 Pass • o~ BP Alaska Anticollision Report • ~~~ ~e ins LNTEQ Company:.. BP Amoco Date: 6N 1!2006 Time: 12:27: 09 Page: 2 Fieldi Lisburne Reference Sitee Lis DS 05 Co-ordinate(NE) Reference:. WeIL' L5- 16, True North Reference Well: L516 Vertical (T'VD) Reference: 9:16 3/2/1987 00:00 60.0 Referenee Wellpath: :Plan 1, L5-16AL2 Db: Orade Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: Plan 1, L5-16AL1 Contingency VO Plan: Plan #1 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD 111D TVD Ref.' .Offset TFO+AZI TFO•HS CasiaglHSfltstance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft- ft 8964.66 8750.43 10737.00 8858.81 10.58 15.68 32.96 261.24 1295.08 102.57 1192.50 Pass Site: Lis DS OS Well; L5-16 Rule Assigned: Major Risk Wellpath: Plan 1, L5-16AL2 contingency V0 Plan: Plan #1 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD- MD TW Ref Offset' TFO+AZI TFO-HS Casing/HSi>istsnce Area. Deviation R'arning ft ft ft Iq ft g ~g deg in ft ft ft; 8995.88 8774.23 9000.00 8784.33 10.46 10.64 323.48 186.94 13.91 82.18 -68.27 FAIL 9055.51 8804.03 9100.00 8876.60 10.20 10.48 332.62 185.45 76.76 64.89 11.87 Pass 9093.97 8811.10 9200.00 8952.57 10.03 10.28 346.94 191.54 144.59 57.36 87.23 Pass 9155.82 8809.52 9300.00 8965.13 9.92 10.19 10.60 206.90 174.65 60.66 113.99 Pass 9223.47 8805.95 9400.00 8951.82 9.89 10.14 33.61 221.87 196.29 69.36 126.93 Pass 9290.21 8801.30 9500.00 8939.18 9.91 10.18 51.83 232.12 225.08 76.01 149.07 Pass 9345.74 8797.82 9600.00 8926.77 9.95 10.29 68.10 241.74 272.83 82.27 190.56 Pass 9386.49 8795.67 9700.00 8914.55 10.01 10.40 80.69 249.46 339.26 86.84 252.42 Pass 9427.93 8793.86 9800.00 8902.70 10.09. 10.52 90.49 254.32 403.00 89.73 313.27 Pass 9472.32 8792.34 9900.00 8889.07 10.20 10.45 99.15 257.68 453.46 91.31 362.15 Pass 9521.59 8790.75 10000.00 8862.63 10.36 10.42 107.92 260.73 446.56 92.58 353.98 Pass 9568.43 8787.93 10100.00 8834.46 10.52 10.51 115.89 263.34 402.19 94.06 308.13 Pass 9620.33 8784.40 10200.00 8814.36 10.69 10.55 123.99 265.29 365.23 95.41 269.82 Pass 9677.70 8781.57 10300.00 8806.70 10.88 10.77 131.45 265.94 355.42 97.06 258.37 Pass 9987.63 8764.52 10400.00 8803.63 14.33 14.60 95.00 263.58 349.81 118.54 231.27 Pass 10047.24 8762.63 10500.00 8805.49 14.80 14.87 100.41 262.46 326.89 120.37 206.52 Pass 10105.84 8761.80 10600.00 8818.51 15.18 15.15 104.15 259.25 304.08 121.47 182.61 Pass 10166.95 8762.05 10700.00 8840.44 15.46 15.41 107.04 254.88 300.63 121.62 179.01 Pass 10228.57 8763.89 10800.00 8867.68 15.65 15.33 110.65 251.44 326.57 122.78 203.79 Pass 10241.89 8764.63 10822.00 8873.78 15.67 15.26 111.60 250.89 334.03 123.80 210.23 Pass Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: Plan Z, L5-16A V1 Plan: Plan #2 VS Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Cssin);/HSDistanee Area' Ikwiation Warning ft ft ft ft ft' ft deg deg in ft tt ft 8995.88 8774.23 9000.00 8784.33 10.46 10.64 323.48 186.94 3.500 13.91 82.18 -68.27 FAIL 9055.51 8804.03 9100.00 8876.60 10.20 10.48 332.62 185.45 3.500 76.76 64.89 11.87 Pass 9093.97 8811.10 9200.00 8952.57 10.03 10.28 346.94 191.54 3.500 144.59 57.36 87.23 Pass 9155.82 8809.52 9300.00 8965.13 9.92 10.19 10.60 206.90 3.500 174.65 60.66 113.99 Pass 9223.47 8805.95 9400.00 8951.82 9.89 10.14 33.61 221.87 3.500 196.29 69.36 126.93 Pass 9290.21 8801.30 9500.00 8939.18 9.91 10.18 51.83 232.12 3.500 225.08 76.01 149.07 Pass 9345.74 8797.82 9600.00 8926.77 9.95 10.29 68.10 241.74 3.500 272.83 82.27 190.56 Pass 9386.49 8795.67 9700.00 8914.55 10.01 10.40 80.69 249.46 3.500 339.26 86.84 252.42 Pass 9427.93 8793.86 9800.00 8902.70 10.09 10.52 90.49 254.32 3.500 403.00 89.73 313.27 Pass 9470.59 8792.39 9900.00 8891.74 10.20 10.64 98.79 257.52 3.500 459.94 91.84 368.11 Pass 9510.99 8791.20 10000.00 8881.66 10.32 10.77 105.87 259.90 3.500 516.06 93.39 422.66 Pass 9543.62 8789.60 10100.00 8872.71 10.43 10.94 111.54 261.83 3.500 585.57 94.74 490.83 Pass 9577.79 8787.23 10200.00 8869.10 10.55 11.11 116.38 262.72 3.500 648.29 95.77 552.52 Pass 9613.54 8784.81 10300.00 8871.34 10.67 11.17 120.81 262.91 3.500 701.98 96.47 605.50 Pass 9644.34 8783.08 10400.00 8881.96 10.77 11.14 124.13 262.58 3.500 766.19 96.77 669.42 Pass 10050.00 8762.57 10500.00 8900.83 14.82 16.46 98.58 260.31 3.500 821.96 126.08 695.88 Pass 10084.55 8761.98 10600.00 8920.49 15.05 16.64 101.71 259.34 3.500 856.95 126.97 729.98 Pass 10119.67 8761.76 10700.00 8938.41 15.25 16.65 105.01 258.46 3.500 883.23 127.32 755.91 Pass 10150.00 8761.87 10800.00 8950.86 15.39 16.67 .108.40 258.25 3.500 928.19 127.79 800.40 Pass 10157.99 8761.94 10822.00 8952.73 15.42 16.62 109.39 258.30 3.500 940.92 127.80 813.12 Pass • BP Alaska ~ s~R ~ by I-~t~s Anticollision Report LNTEQ Company: BP Amoco Date: 6/11/2006 Time: 12:27: 09 Page: 3 .Field: Lisbtxne Reference Site: Lis DS 05 Co-ordinate(NE) Reference: WeIL L5- 16, True North Reference Wellt t5-16 Vertical(1'VD) Reference: 9:16 3/2/1987 00:00 60.0 Retereaee Wellpathe Plan 1, L5-16AL2 Db: Orade Site: Lis DS 05 Well: L5-16 Rule Assigned: Major Risk Wellpath: PIan3, L5-16AL1 V1 Plan: Plan #3 V14 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aaic Ctr-Ctr No-Go Allowable MD 1'VD MD TVD Ref: Offset TFO+AZI TFO-HS Casiog/H9)istance Area Deviation Warning ft ft ft ft ft ft deg deg: in ft ft ft 8996.66 8774.77 9000.00 8783.28 10.46 10.48 327.11 190.48 3.500 11.76 77.45 -65.69 FAIL 9076.12 8809.08 9100.00 8838.55 10.10 10.11 11.03 219.35 3.500 38.71 73.75 -35.04 FAIL 9136.09 8810.29 9200.00 8836.51 9.95 10.03 54.76 253.40 3.500 91.85 87.97 3.89 Pass 9141.14 8810.10 9300.00 8829.82 9.94 10.05 65.89 263.93 3.500 186.61 91.25 95.36 Pass 9121.96 8810.76 9400.00 8823.46 9.97 10.09 67.09 267.41 3.500 281.22 92.25 188.97 Pass 9098.22 8811.25 9500.00 8816.91 10.02 10.17 65.40 269.13 3.500 370.47 93.11 277.36 Pass 9076.47 8809.14 9600.00 8810.42 10.10 10.29 61.59 269.84 3.500 454.17 94.13 360.04 Pass 9062.56 8806.08 9700.00 8804.06 10.17 10.37 58.97 270.22 3.500 545.85 94.70 451.16 Pass 9057.37 8804.60 9800.00 8798.03 10.19 10.41 58.21 270.61 3.500 644.29 94.91 549.37 Pass 9058.57 8804.96 9900.00 8792.59 10.19 10.41 58.86 271.00 3.500 743.86 94.89 648.97 Pass 9064.58 8806.60 10000.00 8787.97 10.15 10.39 60.51 271.31 3.500 840.51 94.73 745.78 Pass 9071.54 8808.20 10100.00 8784.74 10.12 10.37 62.17 271.47 3.500 935.87 94.57 841.30 Pass 9073.50 8808.59 10200.00 8783.78 10.11 10.37 62.53 271.40 3.500 1035.31 94.53 940.78 Pass 9070.00 8807.88 10300.00 8785.14 10.13 10.41 61.62 271.24 3.500 1134.34 94.69 1039.65 Pass 9065.66 8806.87 10400.00 8788.77 10.15 10.45 60.30 270.87 3.500 1229.13 94.84 1134.30 Pass 9060.00 8805.37 10500.00 8794.51 10.18 10.54 58.52 270.33 3.500 1316.72 95.11 1221.60 Pass 9050.00 8802.21 10600.00 8802.11 10.23 10.90 55.78 269.88 3.500 1394.71 95.90 1298.82 Pass 9040.00 8798.40 10700.00 8814.91 10.29 11.76 52.84 269.34 3.500 1469.50 96.68 1372.82 Pass Lisburne UB-CTD Heater C l 5000 psi njection 1376 psi@186 F Block Flow Diagram 2.5 MM BTU 2X 5gal 36 MMscfd 30 gpd 11000 bpd liquids 27-Apr-06 + Heat 140 F Trace Solids Oil 2850 bopd Gas 16.5 mmscf/d Water/KCI 2304 bpd Pressun: Ship to L5-32 (28) to L5-24 (16) Production Header + 40uppm Demulsi8er + Defoamer P-500psi T -140 F L-5 Header Wells L5-28 ~ In Line 2 Phase rrocess upset Vent toFbwback L5-16 16.5 mmsd/d gas Heater T-f4oF ASRCSeparator T_t4oF Tan 2850 bpd effluent P-550psi g P-550psi T-55F P - 650 prig T -140 F P-14.7psi Solids Pressure ship 10 Slop Tank Reservoir Ls-fs T 165 F Static Gas 11.5 mmscf/d T xxx Flowing Oii 650 bopd L5-2a Water 135 bopd T 174 F Static T xxx Flowing Fluid Injected Via CT - 2304 bpd Gas LiR Potan~el Injection ~ T - 60 F 0 to 5 MA~cP/d P- as req'd I Lisburne Process-Block Flow rev p Contingency For KCI Mud System. Would be req'd for L5-16 Flowback Tank ASRC P - 5000 psi P - xxx T - 4o F Mud Pump 1 Mud Pump 2 Gas Metering Feed Gas Gas Lift I Skid 2500psi Header L-5 Header to LPC Test Separator DSO Clean Out KCL DRA Mixing +0.6 % Safelube + f,71b!bbl Concor404 Diesel +0.751b/bbl Sodium ~soo bbl Metabysulfide +400 PPm + 0.068% pRp J313 Diesel KCI ASRC Nordic Tank Rig Farm Tanks Methanol 4/29/2006 • ~ ~ L5-16 Stack rev4 4/29/2006 • • - - _ -- ~- ~ __ - - W- nn ~ c v o ~ m E . -. ' m s e ~ e a b --- --m a ~~ pp3i qua; I ~ Cm ~ I - A - A5 <z ~ ~ ;~ ma c :sec ICI ~~ ,, ~ ~ O' r. _;~ ;;~ ~ i ! i~~ ~ ~ O € ~ j' -off x i !j n 0 ~~~ 'fi °~ ~ _ F / ,' ~ I O ~ ~ o`. o _ ~~ ~J 0 ~ o 'I ~ s n \~ ~ ~ z i ' ;_~'~~ { ; m a t <a , e 1~ a o- s m ~ a + _-~ n r ...... - -__.~.......: A e 'r ~ ~~ c J e5 ~_ '1 ~((( ~~ F F M1 ..~- Y' " %~ ~ ~ N ~ r I ~ c m ~ s ~ ~ i` ~ '-~9 a, #~ iI i; r _ ~~ ~- . s gl. ~~ ~ ~~eF 2 3 ~j9. _~£ `~ y "s a F F - F[& ~~~~-~ ~I / l ~~~ ~~ y~~. rv t a i S ~ e C \~~ •~~ ~~, h U ;~ f F 8 J' ~ _~ ~ __II L III N 1 h Z 1 M I ~ ~ c I \ \!~ m (4) C N a ~~ 447' ~-}---~I ~ ~/ WIND ' -' r ~ ~` I ~ ;;",; 150 ft radius ~ '~ .i= -' ,~ ' ~~ __ >~ _ -___ ,' ~ _ ~ '. :' -' '~ ` 50 ft radius :~ . ;~ ~ , ~- r ti '--' -, ~ ` f Nordic 2 0 ~~~ ~J o. / CQ _ ~ . 18 4925 ~, Nord 2 ~j i __ ~ ,'2 ~l ~ ~ F ~ "~ ~ \, ~ . 8. N _~. T -' ~ I ~ 4-• I ~ C7 ~ I i m C .~ -_- ~ - g Cam I I I ~ ~4917~- 'h I II 4911 ~~ ~ N II M :_, ,Y .~~ Enter/Exit '~ ~~' "~ iQ i ~ WELL PRODUCER • DATE :03/28/2006 SCALE : 1" = 250' MAP DATE :2004 PBU - DSL5 WELL INJECTOR ~ bs14495.dgn • • TRANSMITTAL LETTER CHECKLIST WELL NAME P~)~ ~ ~-- ~~~2 PTD# ~ -~-~~_ ~ ,~, Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER i WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing wel I -~.. S ~ ~~ ~ , (If last two digits in API number permit No. ~_ ,Z l7~ _~. -~~`~~~ API No. 50- - o are between 60-69) Production should continue to be reported as a function of the i original API number stated above. ' PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent ~ upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in , SAMPLE no greater than 30' sample intervals from below the permafrost or ~ from where samples are first caught and 10' sample intervals 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 (name of well) until after (Com~any NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. _~Company Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist _m ~~_wm-s.n: WELL PERMIT CHECKLIST Field & Pool- PRUDHOE BAY, LISBURNE OIL - 640144 _ _ Well Name: PRUDHOE BAY UN_I,IS L5-16AL2 __ Program DEV Well bore seg PTD#~ 2060850 Company BP EXPLORATION (ALASfCA) INC _ Initial ClasslType DEV! 1-OIL / GeoArea 890. _ Unit 11650 OnlOff Shore On Annular Disposal .,._ Administration 1 Permitfee attached. - No - PERMIT FEE NOT REQUIRED FOR LATTERAL `2 .Lease number appropriate- - - - - - Yes Fee attached tc motherbore application- B Unique well-name and number Yes 4 Well located in a defined pool - Yes I ',5 Well located proper distance from-drilling unit boundary Yes - - - - - - 16 Well located proper distance fto_m other wells. Yes ~',7 Su_fficientacreageayailablem_drillingunit- Yes - - - - ~~8 If deviated, is-wellbore plat included _ _ _ .._ _ Yes _ . _ _ 19 Operato[ only affected party - - - - - - - - - - - - Yes . - X110 Operator has-appropriate. bond in force - Yes - 11 Permit-can be issued without conservation order- - Yes i12 Permit can be issued without administrative approval - - - - - - - - - - - - - _ _ Yes _ _ - - - Appr Date 113 Can permit be approved before l5-day wait- - - - - - - _ _ _ _ Yes - - _ - RPC 6!16!2006 x!,14 Well located within area and-strata authorized by-Injection Order # (put IQ# in comments)_(FOr_ lJA_ - I15 All wells-within 114 mile area of review dentfied (For service well only) - - NA- - - - - - ~I16 Pre-produced inlectcr; duration of pre production Less than_3 months-(For service wetl_ only) - - _NA- - - . _ - - - ~,17 NOnconuen, gas conforms to AS31.0$,030(j.1.A),(j.2.A-D) - _ NA. 18 Conductor stung provided _ - - - - - - NA - -- Engineering 19 I Surface casing.protects all known USDWS - NA_ ~I20 CMT-voI_ adequate_to circulate on conductor_& surf_csg _ - - - _ NA_ - - _ - - . 1,21 CMT voI_ adequatetotie-in long string to surf csg_ - - ----- --------- NA_ 122 1 CMT-will. cover all known productive horizons- No Open hole completions. !23 .Casing designs adequate for C,_T, B & permafrost- - - ----- --------- NA - . None planned. ~'24 Adequate tankage.or reserve pit - Yes . CTDU 125 If a-re-drill, has-a-10-403 for abandonment been approved - Yes - - 3!30!2006.... j26 Adequate wellbore separation proposed. _ _ Yes _ _ _ - - - _ 27 1f diverter required., does it meet regulations. NA_ - - - - -Sidetrack.. ',28 l)rillingfluid-program schematic & equip list adequate- . - - . - ... - .. Yes - - - - - UBDoperations-approved, Appr Date '129 BOPEs, do they meet regulation Yes - WGA 611912006 ~i30 BOPE-press rating appropriate; test to (put prig in comments) - - - Yes Test to 3500. psi. MSP 2294 psi.- 131 Choke-manjfold complies-w/API-RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - Yes - .. _ - - - _ _ !32 Work will occuC without operation shutdown- - - - - - - - - - - - - Yes - . ~~i33 Is presenceof H2S gasprobable Yes 60_ppm expected, i~34 Mechanical condition of wells within AQR verified ~Fo[se[vice well only) . - - - NA _._ _- '35 Permit-can be issued wlo hydrogen sulfide measures - - - - - - No- - -- - Geology ',36 Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ NA - ... ... . ',37 Seismic analysis of shallow gas.zones- .. - _ _ _ _ tyA_ _ .. _ _ - Appr Date !,38 Seabed condition survey_(if off shore) - NA-- -- RPC 6116/2006 1,39 Contact namelphone for Weekly.progress reports_[exploratory onlyj - - NA- Geologic Engineering Pu ' Date: Date Date Commissioner: C missioner: Co issi r • • Well History File APPENDIX Information of detailed nature that is not • particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of ilie 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 io chronologically organize this category of information. • **** REEL HEADER **** MWD 07/05/24 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 06/08/29 1194703 O1 2.375 CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: WRAP. NO: Well Informa tion Block #MNEM.UNIT Data Type STRT.FT 8918.0000: STOP.FT 11500.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD FIELD: LOC LOCATION: • CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska) Inc. L5-16AL2 Lisburne 70 deg 20' 2.754" N 148 deg 14' 8.827" W 1788' FSL, 19'FWL CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375 CTK DATE. LOG DATE: 29-Aug-06 API API NUMBER: 50029217006100 Parameter Information Block #MNEM.UNIT Value ----------------- ------------ - SECT. - 01 TOWN.N 11N RANG. 15E PDAT. MSL EPD .F 0 LMF DF FAPD.F 60.0 DMF KB EKB .F N/A EDF .F 60.0 EGL .F 0 CASE.F N/A 051 DIRECTIONAL 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 ~-oC~_a~s ~ t5aa~f • i Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. {4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, and Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Directional, Outer Downhole Pressure, and Downhole Weight on Bit), a and Gamma Sub, and a Hydraulic Orienting Sub with a near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control) log as there is no common interval with L5-16 well and this well below casing. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) This well was drilled from L5-16 through a milled window in 4.5" liner: Top of Window 8936.0 ft.MD (8665.0 ft.SSTVD) Bottom of Window 8947.0 ft.MD (8675.0 ft.SSTVD) (8) The interval from 11470.0 ft.MD to 11500.0 ft.MD (8789.0 ft.to 8785.0 ft.SSTVD) was not logged due to bit to sensor offset at TD. (9) Tied to L5-16 at 8902.0 ft.MD (8633.6 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN L5-16AL2 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN L5-16AL2 FN Lisburne COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 • • The data presented here is final has not been depth shifted. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 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 8 Total Data Records: 62 Tape File Start Depth = 8918.000000 Tape File End Depth = 11500.000000 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 L5-16AL2.xtf LCC 150 CN BP Exploration (Alaska) WN L5-16AL2 FN Lisburne COUN North Slope Boro 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 ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MVJD 68 1 F/HR 4 4 8 Total Data Records: 123 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 132 Minimum record length: 54 Maximum record length: 4124 8918.000000 11500.000000 0.250000 feet records... bytes bytes **** TAPE TRAILER **** MWD • 06/08/29 1194703 O1 **** REEL TRAILER **** MWD 07/05/24 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS s Tape Subfile 3 is type: LIS DEPTH GR ROP 8918.0000 -999.2500 -999.2500 8918.2500 -999.2500 -999.2500 9000.0000 17.6000 32.0000 9100.0000 13.3000 25.0000 9200.0000 15.7000 63.9000 9300.0000 13.2000 80.0000 9400.0000 30.1000 50.2000 9500.0000 14.4000 67.1000 9600.0000 51.0000 80.4000 9700.0000 41.5000 102.8000 9800.0000 15.0000 76.6000 9900.0000 15.9000 72.8000 10000.0000 16.9000 12.6000 10100.0000 40.7000 39.7000 10200.0000 59.1000 65.2000 10300.0000 36.3000 51.1000 10400.0000 16.2000 46.0000 10500.0000 29.5000 51.0000 10600.0000 27.4000 38.4000 10700.0000 17.5000 56.3000 10800.0000 20.2000 53.7000 10900.0000 17.7000 91.4000 11000.0000 15.1000 64.2000 11100.0000 25.1000 62.7000 11200.0000 26.1000 33.0000 11300.0000 20.4000 43.1000 11400.0000 25.6000 37.0000 11500.0000 -999.2500 58.6000 Tape File Start Depth = 8918.000000 Tape File End Depth = 11500.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~J U Tape Subfile 2 is type: LIS DEPTH GR ROP 8918.0000 -999.2500 -999.2500 8918.5000 -999.2500 -999.2500 9000.0000 17.6000 32.0000 9100.0000 13.3000 25.0000 9200.0000 15.7000 63.9000 9300.0000 13.2000 80.0000 9400.0000 30.1000 50.2000 9500.0000 14.4000 67.1000 9600.0000 51.0000 80.4000 9700.0000 41.5000 102.8000 9800.0000 15.0000 76.6000 9900.0000 15.9000 72.8000 10000.0000 16.9000 12.6000 10100.0000 40.7000 39.7000 10200.0000 59.1000 65.2000 10300.0000 36.3000 51.1000 10400.0000 16.2000 46.0000 10500.0000 29.5000 51.0000 10600.0000 27.4000 38.4000 10700.0000 17.5000 56.3000 10800.0000 20.2000 53.7000 10900.0000 17.7000 91.4000 11000.0000 15.1000 64.2000 11100.0000 25.1000 62.7000 11200.0000 26.1000 33.0000 11300.0000 20.4000 43.1000 11400.0000 25.6000 37.0000 11500.0000 -999.2500 58.6000 Tape File Start Depth = 8918.000000 Tape File End Depth = 11500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
