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Home My WebLink About205-112By James Brooks at 8:09 am, Dec 29, 2022 Abandoned 12/9/2022 JSB RBDMS JSB 122922 xGMGR28JULY2023DSR-1/3/23 12.28.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.12.28 16:19:27 -09'00' Monty M Myers ACTIVITYDATE SUMMARY 11/17/2022 ***WELL S/I ON ARRIVAL*** DRIFTED 20' x 2.70" DUMMY WHIPSTOCK FREELY TO 3,000' SLM, (no issues) ***JOB COMPLETE, WELL LEFT S/I*** 11/28/2022 ***WELL S/I ON ARRIVAL*** HES UNIT 759 R/U ***CONT, ON 11/29/2022*** 11/29/2022 ***CONT, FROM 11/28/2022*** DRIFT TO TD @ 8687' SLM, TAG HARD BTM, PUH BRUSH TARGET NIPPLE @ 8312' SLM. DRIFT W/ 20' OF 2.74" DUMMY WHIPSTOCK W/ 1-3/4" SAMPLE BAILER, DRIFT FREELY TO 8687' SLM SET 3-1/2" PX-PLUG IN NIP @ 8311' MD SET PX PRONG IN PX-PLUG @ 8312' SLM, LEFT 3-1/2" BAIT SUB W/ 2-1/2" JDC ATTACHED TO ACT AS CATCHER. PULL STA# 1,2,3,4 & 6 BTM INT GLVs DUMMY OF STA# 2,3,4, & 6 W/ BTM INT DMY GLVs. STANDBY FROM PUMP TRUCK. ***CONT, ON 11/30/2022*** 11/30/2022 ***CONT, FROM 11/29/2022*** LRS CIRC'D WELL W/ 173 BBLS OF 2% KCL & 60 BBLS OF CRUDE. SET INT-DLGV IN ST#1 @ 8136' MD. LRS PERFORMED PASSING MIT-T TO 4514psi. LRS PERFORMED PASSING MIT-IA TO 4585psi. PULLED 3 1/2" PX-PLUG FROM 8,311' MD ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 11/30/2022 T/I/O = 1162/1443/377. Temp - SI. Unit 72 Assist SL (Circ Out). Pumped 4 bbls 60/40, 173 bbls 2% KCL and 60 bbls Crude into TBG taking IA returns to L-121 FL. U- Tubed TxIA. MIT-T to 4500 psi PASSED at 4514 psi (4706 psi max applied pressure). TBG lost 146 psi during thefirst 15 minutes and 46 psi during the second 15 minutes. TBG lost 192 psi during the 30 minute test. Pumped 1.5 bbls of 56*F crude to achieve test pressure. Bled back 0.7 bbls to 2024/288/388. MIT-IA to 4500 psi PASSED at 4584 psi (4700 psi max applied pressure) IA lost 90 psi during thefirst 15 minutes and 26 psi during the second 15 minutes. IA lost 116 psi during the30 minute test. Pumped 2.2 bbls of 56*F crude to achieve test pressure. Bled back 2.2 bbls to Final T/I/O= 510/15/386. 12/1/2022 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3000#HP RUN 1 TS: 1 7/16" CHD (1" FN), 2" WEIGHT, 2 x 1 11/16" WEIGHT, GR/CCL RUN 2 TS: 1 7/16" CHD (1" FN, 1 11/16" SWIVEL, 2 x 4 ARM CENTRALIZERS, 1 3/4" DC MOT, BKR #10 SETTING TOOL, SET NORTHERN SOLUTIONS 350-272 MONO-PACK RETRIEVABLE WEDGE (11.2' OAL, 2.72" MAX OD) TOWS @ 8561' TRAY LENGTH = 5' CCL OFFSET=13.6', TOW=8,561', CCL STOP DEPTH=8,547.4', WEDGE ORIENTED @20 DEG ROHS ***WELL LEFT SHUT IN*** Daily Report of Well Operations PBU L-114A Daily Report of Well Operations PBU L-114A 12/6/2022 T/I/O=0/1250/350. Pre CDR2. Removed Wellhouses 114, 50, 51. Installed 3" spec blind between S-riser and WV, Torqued to ANSI specs, RD AL line to TPV, RD tree cap Installed 5K blind with jewelry at 90 degrees, Torqued to API specs, PT'd on top of SV 5000 PSI (17 psi loss over 5 min) (Pass), Installed Target 90 to FC, torqued to API specs, PT'd tree against SSV to 5000 PSI (Pass). ***Job Complete*** Finual WHP's 0/1250/350. Activity Date Ops Summary 12/6/2022 Move rig from S-pad to L-pad. 12/7/2022 Complete move from S-Pad to L-Pad. Spot Main sub and Mud module. Rig accepted 12:30. PJSM, Perform RU checklists. Shore up cellar walking surfaces. LTT swab and master to 3500# Good test. Test gas alarms LEL and H2S. All visual and audible passed. Install MPD line. Remove tree cap, set BOP stack down. Continue grease and function valves. Continue grease valves. M/U test jt. M/U nozzle, get on well. Change packoffs. Flush and fluid pack lines. Test BOPs as per AOGCC and Hilcorp regs. All tests 250 / 3500 psi. Test witness waived by AOGCC Inspector Austin McLeod. Test 1: IRV, Stripper, C7, C9, C10, C11. Pass. Test 2: Blind / Shears, R2, BL2, C15. Pass. Test 3: Annular (2"), TIW1, B1, B4. Fail annular. Test 4: Upper 2" Pipe / Slips, TIW1, B1, B4. 12/8/2022 Annular Failed in Test 3. Close Upper 2" Pipe /Slips. Continue remainder of Test 3. Test 3: Upper 2" Pipe / Slips, TIW1, B1, B4. Pass. Test 4: Upper 2" Pipe / Slips, TIW1, B2, B3. Pass. Test 5: Lower 2" Pipe / Slips, C5, C6, C8, TV2. Pass. Test 6: Choke A, Choke C. Pass. Test 7: C1, C4, TV1,. TV1 Fail/ Grease / Pass. Swap test joint. Test 8: 2-3/8" Pipe / Slip, C2, C3. Pass. Perform accumulator drawdown test. PJSM. Replace annular element. Test Annular (2"). Pass. Replace sequencing valve on 2-3/8" Auto Loc block. Pressure test both PDLs to 3500 psi, good. Install floats in UQC and pressure test, good. M/u BHA #1, nozzle w/ CCL. Circ remaining fresh water out to tiger tank followed by 10 bbls MeOH, followed by hot KCl. With MeOH at nozzle pressure up to 1200 psi and open well. WHP = 1000 psi. RIH pump 0.4 bpm hold 1100 psi WHP initially returns to tiger tank. Crack choke to keep returns < 1:1 while RIH. Stop at 3700' and adjust gooseneck, reel clamps. Continue RIH. Log CCL from 8150' to get preliminary correction. Continue logging CCL down to 8500'. Light tag whipstock 8562' uncorrected, pickup 34k clean. Circ well to KCl. With KCl at surface purge riser. Bleed small increments of fluid to find BHP = 10.88 ppg. Vac out tiger tank. Pump remaining KCl then mud to surface. POOH keep 11.0# ECD at window. 12/9/2022 Pooh. Mud Weight: 8.68 ppg in, 8.71 ppg out. Rate: 1.54 bpm in, 1.14 bpm out Window ECD:11.0 ppg. Tag up. Trap 750 psi on well. Close master valve. Flush MPD of freshwater. Close swab. Put well on MPD at 750 psi. Make up BHA#2 Window milling BHA. Stab PDL. Perform PD checklist. Deploy BHA. RIH with 2.80" Window Milling BHA #2. Rate: 0.53 bpm in, 0.43 bpm out. Circ pressure: 1789 psi. Mud Weight: 8.69 ppg in, 8.69 ppg out. Log down for tie-in from 8240' to 8327' MD (formation) with -4' correction. PUW 32K, RIW 14K. Dry tag at 8561' MD. Mill 2.80 window in 3.5 liner per NSAK from 8560' md to 8564.63' md Full exit. Free spin: 3713 psi, 1.70 bpm. Rate: 1.70 bpm in, 1.55 bpm out. Circ pressure: 3713. 3870 psi. Mud weight: 8.68 ppg in, 8.69 ppg out, Window ECD: 11.04 ppg Pump on choke: 174 psi. Milling rathole 8565'. 8575'. Free spin: 3713 psi, 1.70 bpm. Rate: 1.68 bpm in, 1.52 bpm out. Circ pressure: 3713. 3990 psi. Mud weight: 8.68 ppg in, 8.69 ppg out, Window ECD: 11.09 ppg Pump on choke: 155 psi. WOB: 0.7K to 2.9K. Perform reaming passes. Slight motor work increase on passes. Conduct 5 reaming passes until clean. Dry drift is clean, tag 8575' end of rathole. Open EDC POOH keep 11.0# ECD at window. Tag stripper and space out. Undeploy BHA #2 window mill. Mill and reamer are 2.81" Go 2.80" NoGo. M/U nozzle and stinger, jet stack. Deploy BHA #3, build BHA w/ 2.35 deg AKO. Difficulty getting through stack. Lift PDL off and turn bit. Work BHA down to landing ring. Finish deployment. RIH, keep 11.0# ECD at window. Tie-in depth from 8290', no correction. RIH to 8500' close EDC. Pass window 0 pump, 20R clean. Tag bottom 8571' get up wt then bring pump to 1.8 bpm. Drill from 8570'. 1.81 / 1.52 bpm In / Out. 8.68 / 8.70 ppg. Window ECD 11.06 ppg. 50-029-23032-02-00API #: Well Name: Field: County/State: PBW L-114B Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 12/9/2022Spud Date: 1 Regg, James B (OGC) From:Alaska NS - CTD DSM <AlaskaNS-CTD-DSM@hilcorp.com> Sent:Saturday, December 10, 2022 3:07 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Robert Coyne; Nathan Wheeler; Henson, Thomas; Williams, Wade; Henson, James Subject:Nabors CDR2AC PBU L-114A Initial BOPE test Attachments:Nabors CDR2AC 12-08-22.xlsx Initial BOPE test. John Perl Sr. Drilling Foreman Nabors CDR2 Rig (907) 670 3097 Personal Cell (907) 355 5815 H# 4169 Positional Email AlaskaNS CTD DSM@hilcorp.com Alternate: Mark Igtanloc Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CDR2AC DATE: 12/8/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2051120 Sundry #322-597 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250 /3500 Annular:250 /3500 Valves:250 /3500 MASP:2944 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2.0"P Trip Tank P P Annular Preventer 1 7-1/16" GK FP Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 2.0" Pipe / Slip P Meth Gas Detector P P #3 Rams 1 2-3/8" Pipe / Slip P H2S Gas Detector P P #4 Rams 1 2.0" Pipe / Slip P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)2980 P Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2300 P Check Valve 0 NA 200 psi Attained (sec)20 P BOP Misc 2 see remarks FP Full Pressure Attained (sec)52 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 1960 P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 5 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 1 P #3 Rams 5 P #4 Rams 4 P Test Results #5 Rams NA #6 Rams NA Number of Failures:3 Test Time:12.0 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/06/22 10:00 Waived By Test Start Date/Time:12/8/2022 3:00 (date) (time)Witness Test Finish Date/Time:12/8/2022 15:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Annular Fail / Replace element / Pass, TV1 Fail / Grease / Pass. Hydraulic drip coming from sequencing valve on 2-3/8" P/S Auto Lock block. Replace valve. Verify function, and test to full accumulator pressure. R. Coyne / T. Henson Hilcorp J. Perl / T. Kavanagh PBU L-114A Test Pressure (psi): Robert.Coyne@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022) 2022-1208_BOP_Nabors_CDR2AC_PBU_L-114A FPsee remarks FP Annular Fail TV1 Fail Hydraulic drip coming from sequencing valve on 2-3/8" P/S 10.11.2022 By Anne Prysunka at 4:15 pm, Oct 11, 2022 'LJLWDOO\VLJQHGE\0RQW\00\HUV '1FQ 0RQW\00\HUVF 86 R +LOFRUS$ODVND//&RX 7HFKQLFDO 6HUYLFHV$.'ULOOLQJ HPDLO PP\HUV#KLOFRUSFRP 5HDVRQ,DPDSSURYLQJWKLVGRFXPHQW 'DWH 0RQW\0 0\HUV '/% %23(WHVWWRSVL ; '65 ; '/% 0*52&7 9DULDQFHWR$$&L$OWHUQDWHSOXJSODFHPHQWDSSURYHGIRUDEDQGRQPHQW 1R/% ZLOO EH RLO *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.26 16:55:54 -08'00' RBDMS JSB 102722 7R $ODVND2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ )URP 7UHYRU+\DWW 'ULOOLQJ(QJLQHHU 'DWH 2FWREHU 5H 3%8/$6XQGU\5HTXHVW 6XQGU\DSSURYDOLVUHTXHVWHGWRVHWDZKLSVWRFNDQGPLOOWKHZLQGRZLQ/$SUHULJDV SDUWRIWKHGULOOLQJDQGFRPSOHWLRQRIWKHSURSRVHG/%&7'ODWHUDO 3URSRVHGSODQIRU/%3URGXFHU 3ULRUWRGULOOLQJDFWLYLWLHVVFUHHQLQJZLOOEHFRQGXFWHGWRGULIWIRUZKLSVWRFNDQG0,7(OLQHZLOOVHWDSDFNHU ZKLSVWRFN6HUYLFHFRLOZLOOPLOODZLQGRZ¶RIIRUPDWLRQRXWRIWKH´OLQHUULJZLOOPLOOZLQGRZLI QHHGHG 6HH/%37'UHTXHVWIRUFRPSOHWHGULOOLQJGHWDLOV$FRLOWXELQJGULOOLQJVLGHWUDFNZLOOEHGULOOHGZLWKWKH 1DERUV&'5ULJ7KHULJZLOOPRYHLQWHVW%23(DQGNLOOWKHZHOO$ZLQGRZ¶RIIRUPDWLRQRXWRIWKH ´OLQHULIQRWDOUHDG\GRQHSUHULJ7KHZHOOZLOONLFNRIIGULOOLQJDQGODQGLQWKH.XSDUXN7KHODWHUDOZLOO FRQWLQXHLQWKH.XSDUXNWR7'7KHSURSRVHGVLGHWUDFNZLOOEHFRPSOHWHGZLWKD´/VROLGOLQHUDQG FHPHQWHGLQSODFH7KHZHOOZLOOEHVHOHFWLYHO\SHUIRUDWHGSRVWULJDQGIUDFNHGVHHIXWXUHSHUIIUDFVXQGU\7KLV FRPSOHWLRQZLOOFRPSOHWHO\LVRODWHDQGDEDQGRQWKHSDUHQW.XSDUXNSHUIV 7KLV6XQGU\FRYHUVSOXJJLQJWKHH[LVWLQJSHUIRUDWLRQVYLDWKHSDFNHUZKLSVWRFNOLQHUFHPHQWMRERUOLQHUWRS SDFNHULIWKHOLQHUODSSUHVVXUHWHVWIDLOVDOWHUQDWHSOXJSODFHPHQWSHU$$&L 3UH5LJ:RUN(VWLPDWHGWRVWDUWLQ1RYHPEHU 6OLFNOLQH'XPP\:6GULIW D 'ULIWSDVWZKLSVWRFNVHWWLQJORFDWLRQ )XOOERUH0,7,$DQG0,77WRSVL (OLQH6HW´SDFNHUZKLSVWRFN D 7RSRIZKLSVWRFNVHWDW¶0'WRSRIZLQGRZ±SLQFKSRLQW E 2ULHQWHG52+6 6HUYLFH&RLO0LOO:LQGRZULJZLOOPLOOZLQGRZLIQHHGHG D 0LOO:LQGRZ , 0,586HUYLFH&RLO:LQGRZ0LOOLQJ6XUIDFH.LW ,, *LYH$2*&&KUQRWLFHSULRUWR%23(WHVW ,,, 7HVW%23(WRSVL0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL ,9 0LOO´ZLQGRZSOXV¶RIUDWKROH 9 6LQJOHVWULQJZLQGRZH[LWRXWRI´OLQHU 9DOYH6KRS3UH&7'7UHH:RUNDVQHFHVVDU\ 5LJ:RUN x 5HIHUHQFH3%8/%37'VXEPLWWHGLQFRQFHUWZLWKWKLVUHTXHVWIRUIXOOGHWDLOV x *HQHUDOZRUNVFRSHRI5LJZRUN 0,58DQG7HVW%23(0$63ZLWKJDVSVLIWWRVXUIDFHLVSVL 0LOO:LQGRZRQO\LIQRWGRQHSUHULJ 'ULOO%XLOGDQG/DWHUDO 5XQDQG&HPHQW/LQHU )UHH]H3URWHFWDQG5'02 6HW/73 LIQHHGHG530ORJDQGSHUIRUDWHIUDFSRVWULJ $SSURYHGDOWHUQDWHSOXJSODFHPHQWSHU$$&L 6XQGU\ 37' 7KLVS\SSJ FRPSOHWLRQZLOOFRPSOHWHO\LVRODWHDQGDEDQGRQWKHSDUHQW.XSDUXNSHUIV'/% 7KHVXQGU\DQGSHUPLWWRGULOOZLOOEHSRVWHGLQWKH2SHUDWLRQV&DELQRIWKHXQLWGXULQJWKHZLQGRZPLOOLQJ RSHUDWLRQ :LQGRZ0LOOLQJ)OXLGV3URJUDP x $PLQ(0:RISSJ.&/.&OZLOOEHXVHGDVWKHSULPDU\ZRUNLQJIOXLGDQGYLVFRXVJHOVZHHSVZLOOEH XVHGDVQHFHVVDU\WRNHHSWKHKROHFOHDQ x 7KHZHOOZLOOEHIUHH]HSURWHFWHGZLWKDQRQIUHH]DEOHIOXLGW\SLFDOO\DPHWKDQROZDWHUPL[WXUHSULRU WRVHUYLFHFRLO¶VGHSDUWXUH x $GGLWLRQDOO\DOO%+$¶VZLOOEHOXEULFDWHGDQGWKHUHLVQRSODQWR³RSHQKROH´D%+$ 'LVSRVDO x $OO&ODVVO ,,QRQKD]DUGRXVDQG5&5$H[HPSWGULOOLQJDQGFR PSOHWLRQIOXLGVZLOOJRWR*1,DW'6 x )OXLGV!K\GURFDUERQVRUIODPPDEOHVPXVWJRWR*1, x )OXLGV!VROLGVE\YROXPHPXVWJRWR*1, +ROH6L]H x 7KHZLQGRZDQG¶RIIRUPDWLRQZLOOEHPLOOHGGULOOHGZLWKD´2'PLOO :HOO&RQWURO x %23GLDJUDPLVDWWDFKHG x $2*&&ZLOOEHJLYHQDWOHDVWKRXUQRWLFHSULRUWRSHUIRUPLQJD%23(IXQFWLRQSUHVVXUHWHVWVRWKDWD UHSUHVHQWDWLYHRIWKHFRPPLVVLRQFDQZLWQHVVWKHWHVW x 3LSHUDPVEOLQGUDPV&7SDFNRIIDQGFKRNHPDQLIROGZLOOEHSUHVVXUHWHVWHGWRSVLDQGDWOHDVW SVL x %23(WHVWUHVXOWVZLOOEHUHFRUGHGLQRXUGDLO\UHSRUWLQJV\VWHP$ODVND:HOOV*URXS5HSRUWLQJ6\VWHP DQGZLOOSURYLGHWKHUHVXOWVWRWKHFRPPLVVLRQLQDQDSSURYHGIRUPDWZLWKLQILYHGD\VRIWHVWFRPSOHWLRQ x %23(WHVWVZLOOEHSHUIRUPHGXSRQDUULYDOSULRUWRILUVWHQWU\LQWRWKHZHOODQGDWGD\VLQWHUYDOV WKHUHDIWHU x$$&F&UHTXLUHVWKDWD%23(DVVHPEO\PXVWLQFOXGH³a firewall to shield accumulators and primary controls´$YDULDQFHLVUHTXHVWHGEDVHGRQWKHUHVXOWRIWKHMRLQWKD]RSZLWKWKH$2*&&)RURXU RSHUDWLRQWKHSULPDU\FRQWUROVIRUWKH%23(DUHORFDWHGLQWKH2SHUDWLRQV&DELQRIWKH&RLOHG7XELQJ8QLW DQGWKHDFFXPXODWRUVDUHORFDWHGRQWKHEDFNVLGHRIWKH2SHUDWLRQV&DELQRSSRVLWHVLGHIURPWKHZHOO 7KHVHDUHDSSUR[LPDWHO\ IURPWKHZHOO +D]DUGV x 3%8/SDGLVDQ+6SDG o 7KHKLJKHVWUHFRUGHG+6ZHOORQWKHSDGZDVIURP/SSPLQ o /DVWUHFRUGHG+6RQ/ZDVSSPLQ 5HVHUYRLU3UHVVXUH x 7KHHVWLPDWHGUHVHUYRLUSUHVVXUHLVH[SHFWHGWREHSVLDW¶79'SSJHTXLYDOHQW x 0D[LPXPH[SHFWHGVXUIDFHSUHVVXUHZLWKJDVSVLIWWRVXUIDFHLVSVLIURPHVWLPDWHG UHVHUYRLUSUHVVXUH x 5HVHUYRLUSUHVVXUHZLOOEHFRQWUROOHGZLWKDFORVHGFLUFXODWLQJV\VWHPDQGFKRNHIRUEDFNSUHVVXUHWR PDLQWDLQRYHUEDODQFHWRWKHIRUPDWLRQ 7UHYRU+\DWW && :HOO)LOH 'ULOOLQJ(QJLQHHU -RVHSK/DVWXIND &RLOHG7XELQJ%23V /6ROLG+/LQHU :HOO 'DWH 4XLFN7HVW6XEWR2WLV IW 7RSRI2WLV IW 'LVWDQFHVIURPWRSRIULVHU ([FOXGLQJTXLFNWHVWVXE 7RSRI$QQXODU IW C L Annular IW %RWWRP$QQXODU IW &/%OLQG6KHDUV IW &/3LSH6OLSV IW % % % % Kill Line Choke Line &/3LSH6OLS IW &/3LSH6OLSV IW 79 79 7 7 )ORZ7HH 0DVWHU 0DVWHU /'6 ,$ 2$ /'6 *URXQG/HYHO /3KRVHRSHQHQGHGWR)ORZOLQH CDR2-AC BOP Schematic &'55LJ V'ULS3DQ )LOO/LQHIURP+) 1RUPDOO\'LVFRQQHFWHG +3KRVHWR0LFURPRWLRQ +\GULO $QQXODU %OLQG6KHDU 3LSH6OLSV 3LSH6OLSV 3LSH6OLSV N0XG &URVV 3LSH6OLSV 3LSH 6OLS +) QQHFHHHHHHHHHHHHHHHHHHHHHHHHHHHHHHH • 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. ~ a s- 1 L ~- Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria - Project Proofing SY: aria ,_ Scanning Prep~ara~tion BY: /Maria > ~..o.=cea iuuiiiiiiiiiuii DIGITAL DATA Diskettes, No. I ^ Other, No/Type: Date: Date: x 30 ~ 3 Date: ~~ ae,~a~~ee~a uiimiuuiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ Illlffllllllll 11111 ~ /s/ ~~ _ + ~ ~ =TOTAL PAGES ~ ~ ///---~~~ (Count does not include cover sheet) ~,I J Production Scanning III II~IIIIIIII IIIII Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ ~l ~ ~ ~ ~ /s/ !~ Stage 1 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. !) I II ~I II I II II I I III ReScanned II I II iI II I I III I I III BY: Maria Date: /s/ Comments about this file: o , ~,~kea ouiiimiinmu 10/6/2005 Well History Fiie Cover Page.doc ~ l._J BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~,'~~~~~'~~~~~y~ -r,,~ i ~ ~~Ja August 14, 2009 C~ bp , ~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, o c T o~ zao9 ~~as~C~ ~il ~c Gas Cons. Commi~~ion Anchorage ~~"~f~ ,, ( ~ ~-~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10at04) I~A~P_ L pad an annos Well Name PTD # API # Inftial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Ci~n~$~~ inhibitod sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 P1A 15.3 6/25/20~9 ~-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? MA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011570 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6129l2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 ~-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121 A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L•204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 1-205 2080530 50029233880000 NA t NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-2t1 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA 1-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 STATE OF ALASKA AI,KA OIL AND GAS CONSERVATION C~SSION REPORT OF SUNDRY WELL OPERATIONS. li?~d'v Y 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing . ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 205-112 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23032-01-00 " 7. KB Elevation (ft): 76 3' ~ 9. Well Name and Number: PBU L-114A- 8. Property Designation: 10. Field /Pool(s): ADL 028239 ~ Prudhoe Bay Field /Borealis Pool 11. Present well condition summary Total depth: measured 8826' - feet true vertical 6876' _ feet Plugs (measured) None Effective depth: measured 8725' ~ feet Junk (measured) None true vertical 6777 ` feet Casing Length Size MD TVD Burst Collapse Structural Conductor 106' 20" 106' 106' 1490 470 Surface 2610' 7-5/8" 2637' 2598' 6890 4790 Intermediate Production 7414' 5-1/2" 7438' 5554' 7000 4990 Liner 815' 3-1/2" 7438' - 8253' 5554' - 6319' 10160 10530 Perforation Depth MD (ft): 8528 - 8548 Perforation Depth ND (ft): 6586' - 6606' 3-1/2", 9.2# 13Cr80 8266' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 243 86 2,452 1,480 400 14. Attachments: [] Copies of Logs and Surveys run 15. Well Class after work: _ ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ 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: Contact David Bjork, 564-5683 (J/q Printed Name Terrie Hubble Title Drilling Technolo ist / l Prepared ey Name/Number: ~ Signature Phone 564-4628 Date ! Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 Submit Original Only ,~ .,; i`t • • L-114A, Well History (Pre Rig Workover) Date Summary 10/12/2008 T/I/O=SSV/1000/400, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void (600 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (2"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 20 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void (500 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (2"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 10/13/2008 T/I/O = SSV/880/470. Temp = SI. OA FL (RWO). OA FL C~ 500' (9 bbls). WV, SSV & SV =Closed. MV = Open. IAV & OAV = OTG. NOVP. 10/14/2008 WELL SHUT IN ON ARRIVAL. T/I/0=1000/1000/600. LOGS CORRELATED TO TUBING TALLY DATED 21- AUG-2005. SET WEATHERFORD BRIDGE PLUG AT 8290' IN THE LOWER 1/3 OF A FULL JOINT. BLED PRESSURE ON SURFACE TO MONITOR BUILD UP TO YIELD INDICATION OF PLUG SETTING. RIG UP AND RIH WITH TECWELL TOOLS. PERFORM BASELINE PASS DOWN TO 8270'. ~SSIBI F I FAK SEEN AT GLM AT 6300'. 10/14/2008 T/I/0= 1260/1020/460. Temp= SI. TBG & IA FL for E-Line. AL shut-in C~3 casing valve, ALP = 950 psi. TBG & IA FL @ surface. E-Line on site, responsible for valve positions. 10/15/2008 LOGS CORRELATED TO TUBING TALLY DATED 21-AUG-2005. BLED PRESSURE ON SURFACE TO MONITOR BUILD UP TO YIELD INDICATION OF PLUG SETTING. RIG UP AND RIH WITH TECWELL TOOLS. PERFORM BASELINE PASS DOWN TO 8270'. PRESSURE UP TUBING, RETURNS DOWN IA HARDLINED TO ADJACENT WELL. LEAK SEEN AT GLM #3 AT 6296'._ LOG COMPLETE PASS FROM 6400' TO 1780' WHILE POOH. NO FURTHER ANOMALIES. WELL LEFT SHUT IN ON DEPARTURE: T/I/0=200/275/600. JOB COMPLETED. 10/15/2008 T/I/0=500/75/600 Temp=S/I Assist E-line w/LDL. Pumped 134bb1s crude down tubing, taking returns up IA, down L-51's flowline. Freeze protected L-51's flowline w/ 7bbls meth, 13bbls crude, per WOA recipie. FWHP's = 500/250/550. E-line has control of well upon departure. 10/16/2008 WELL S/I ON ARRIVAL. SET 3 1/2" WHIDDON C-SUB ON WRP Q 8284' SLM. 10/17/2008 T/I/0= 650/380/500 Temp= SI CMIT Tx IA PASSED to 3500 psi (RWO prep) Pressured T/IA to 3500~si_ with 3.1 bbls of inhibited 60/40 meth. T/IA lost 160/160 psi 1st 15 mins and 60/60 psi 2nd 15 mins for a total loss of 220/220 psi in 30 mins. Bled whp's to 300/300 psi down flow line of L-51 to prepare for circ out. 10/17/2008 PULL STA#1 INT-DGLV FROM 8160' MD. POCKET LEFT OPEN. PULL empty WHIDDON C-SUB FROM 8184' SLM. DUMP 5 GALLONS OF SLUGGITS ONTO WRP ~ 8284' SLM. SET 3 1/2" JUNK CATCHER (118" oal) ONTO SLUGGITS Q 8264' SLM. WELL LEFT S/I, DSO NOTIFIED. 10/18/2008 Circ out/ MIT OA PASSED to 2000 psi- 2nd attempt (RWO prep). Circulated well bore pumping down tbg thru cut up IA to flow line of L-51. Pumped 49.5 bbls of inh 60/40, 243 bbls of 9.8 ppg NaCI brine and 8 bbls diesel. U-tubed to freeze protect well to 400'. Freeze protected surface lines and flowline w/ 49 bbls of inh 60/40 chased by 2 bbls of diesel. MIT OA- Pressured up to 2000 psi with 9 bbls crude. Second test: OA lost 140 psi 1st 15 mins and 40 psi 2nd 15 mins for a total loss of 180 psi in 30 miins. Bled pressures FWHP's=0/0/0 AT DEPARTURE VALVES in following positions -and operator notified of positions and result of job. Wing closed, Swab closed, SSV open, Master open, IA open, OA open -Well SI. 10/20/2008 T/I/O 500/500/0 Set 3' CIW H plug for pre riq used 1-2' ext set at 84'., 10/24/2008 T/I/O=BPV/370/190. Temp=S1. Monitor pre IA & OA bleed. AL is SI at casing valve & locked out. ALP=O psi. IA FL is near surface. OA FL is @ surface. SV, WV =closed. SSV, MV =open. IA, OA = OTG. NOVP. 10/30/2008 T/I/O = 0/0/0. Pulled 3-1/8" CIW "H" TWC# 319 thru tree. Would not test from topside,.. Set 3-1/8" CIW "H" TWC # 306. Tested plug from both ways, no pressure loss. 11/2/2008 T/I/O=Vac/0/0. Pull 3-1/8" CIW H BPV #306 thru tree, rig move over well. 1-2' ext used, tagged @ 84". No problems. Page 1 of 1 • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: WORKOVER Start: 11/1/2008 End: 11/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/5/2008 Rig Name: DOYON 14 Rig Number: Date ~ From - To I~ Hours ~ Task ;Code NPT Phase I Description of Operations ____ 11/2/2008 02:00 - 03:00 1.00 RIGD P PRE Skid rig floor to moving position. 03:00 - 04:30 1.50 MOB P PRE -Move rig off well L-116 and spot over rig L-114. -Shim rig in place. 04:30 - 05:30 1.00 RIGU P PRE -Skid rig floor to drilling position. -Spot and berm rock washer. 05:30 - 06:00 0.50 RIGU P PRE Hook up lines under rig floor. 06:00 - 09:00 3.00 WHSUR P DECOMP -Remove IA and wing blank flanges on tree. -Install secondary valve in IA and pump in flanges on tree. -RU lines to tree. -Extend hard line f/ tiger tank. -Test hard line w/ 100 psi air. Steam and fill w/ water. Test to 3500 psi. 09:00 - 10:30 1.50 WHSUR P DECOMP -RU DSM lubricator on tree and test same to 500 osi x 5 min- -Pull BPV. -RD lubricator 10:30 - 11:30 1.00 WHSUR P DECOMP Displace freeze protect out (well was freeze protected w/ 8 bbls diesel per handover form): -Pump 10 bbls 9.8 ppg brine down IA, taking returns out tubing to tiger tank. 2.5 BPM / 910 psi. -Swap lines in tree. -Pump 25 bbls 9.8 ppg brine down tubing, taking returns out IA to tiger tank. 3 BPM / 1050 psi. 11:30 - 12:00 0.50 WHSUR P DECOMP Allow any diesel remains to migrate x 30 min. 12:00 - 13:30 1.50 WHSUR P DECOMP -Pump 5 more bbls 9.8 ppg brine down tubing, taking returns out IA to tiger tank and clear any diesel remains. -Swap return line to rig pits. -Circulate well w/ 170 bbls 9.8 ppg brine. 3 BPM / 1180 psi. -Verifv well static. 13:30 - 15:00 1.50 WHSUR P DECOMP -FMC Rep d rod TWC. -Test TWC f/ below to 1000 osi x 10 min on chart. Test f/_ 15:00 - 16:00 ~ 1.00 ~ WHSUR ~ P ~ ~ DECOMP ~ ND tree and adapter flange. Barriers in place: -Tested WRP ~ 8290' -Tested TWC in tubing hanger. 16:00 - 19:00 3.00 BOPSU P DECOMP -NU BOP -Install choke line, riser and flow line. 13-5/8" 5M BOP stack configuration: - Annular preventer - 3-1/2" x 6" VBR (top rams) - Blind Rams - Mud cross - 2-7/8" x 5" VBR (bottom rams) 19:00 - 20:00 1.00 BOPSU P DECOMP RU to test BOP. 20:00 - 00:00 4.00 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 4000 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart. Perform all tests w/ 3-1/2" test jt. Printed: 11/25/2008 11:01:52 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To 'Hours Task Code 11 11/2/2008 ~ 20:00 - 00:00 ~ 4.00 ~ BOPSUFj P 11/3/2008 00:00 - 00:30 00:30 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 20:30 0.50 BOPSUF~P 2.00 WHSUR P Start: 11 /1 /2008 Rig Release: 11/5/2008 Rig Number: Page 2 of 4' Spud Date: 8/4/2001 End: 11 /5/2008 NPT I Phase Description of Operations DECOMP Test witnessed by WSL and Tourpusher. Chuck Scheve, AOGCC Rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1700 psi 3. 200 psi attained at 30 sec 4. Full pressure attained at 2 min 50 sec 5. Nitrogen bottles: 4 x 2150 psi avg. -Tested 29 components: 1.13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) DECOMP RD testing equipment. LD 3-1/2" testjt. DECOMP -MU 6" lubricator extension and install in BOP stack. Close top rams. -RU DSM lubricator on extension. Test assy. to 500 psi x 5, -RD lubricator and 6" lubricator extension. 0.50 PULL P DECOMP -RU to pull tubing hanger: install bales and elevators. -MU XOs to 1 jt 4" DP. 0.50 PULL P DECOMP -Screw 4" DP jt in tubing hanger. MU top drive. BOLDS. -Pull tubin han er. Observe tubing hanger free. Seals pull free f/ sealbore w/ PUW 117k-120k. Pull tubing hanger to rig floor. String weight 115k when tubing hanger ~ rig floor. All weights indicated include 50k blocks weight. 1.00 PULL P DECOMP -Circulate well S/S w/ 9.8 ppg brine. 5 BPM / 2280 psi. -Install power tongs to LD tubing. -Flow check well f/ 10 min. 0.50 PULL P DECOMP RU to LD 3-1/2" tubing and completion. LD tubing hanger. 7.00 PULL P DECOMP POOH and LD 3-1/2" 9.3# L-80 IBT tubing and completion equipment. -Recover: 264 jts tubing , 7 GLM assy, 2 X-nipple assy, 1 seal assy. 1.00 WHSUR P DECOMP -Vac out stack. -Install wear bushing. 2.00 EVAL P DECOMP -Mobilize and RU Schlumberger a-line equipment. Install air line wiper (tested W RP ~ 8290' as barrier) -MU and test USIT tool. 5.50 EVAL P DECOMP -RIH w/ USIT on a-line to 8200'. -Take USIT loa in cement evaluation mode f/ 8200' to surface 20:30 - 21:30 1.00 EVAL P DECOMP RD Schlumberger a-line equipment. 21:30 - 22:00 0.50 WHSUR P DECOMP Pull wear bushing. 22:00 - 23:30 1.50 WHSUR P DECOMP -BOLDS. C/O mandrel packoff through BOP stack. RILDS. Printed: 11/25/2008 11:01:52 AM • BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ', Hours Task ~ Code NPT 11/3/2008 22:00 - 23:30 1.50 WHSUR P 23:30 - 00:00 0.50 BUNCO 11 /4/2008 100:00 - 00:30 I 0.50 00:30 - 01:00 I 0.50 01:00 - 16:00 I 15.00 16:00 - 17:30 I 1.50 17:30 - 19:30 2.00 19:30 - 21:00 I 1.50 Spud Date: 8/4/2001 Start: 11 /1 /2008 End: 11 /5/2008 Rig Release: 11/5/2008 Rig Number: Phase Description of Operations DECOMP -Test new mandrel packoff to 5000 psi x 30 min per FMC Rep. RUNCMP RU to run 3-1/2" 13Cr80 Vam Top tubing and completion: C/O bales and elevators, install compensator. RUNCMP RU to run 3-1/2" 13Cr80 Vam Top tubing and completion equipment: -Install power tongs and torque turn equipment. RUNCMP Lubricate rig. -Inspect top drive. RUNCMP -MU 3-1/2" seal assy w/ locator and X-nipple assy. -Run 3-1/2" 9.2# 13Cr80 Vam Top tubing and completion equipment. -Torque turn all connections to 2900 ft-Ib. -Run tubing to -8,220' md. RUNCMP Locate Seal Ass oin into To of PBR f~ 8 250' md: -PU 115K, SO 92K -Circulate singles down C~ 126 gpm with 290 psi. -Seen PSI increase @ 8,250' md. -Turn off pumps and cont. in. Bottom out (~ 8,268' md. -Pressure up to 500 psi and hold for 5 min. Good test. RUNCMP Space out. -LD 3 jts 3-1/2" 9.2# 13Cr80 tubing. (Jts. # 254, 255, 256) -PU 2 pups (3.87' and 9.85') -PU Jt # 254 (31.46'). PU Hanger (9.96') -Leave Hanger above rig floor to Circulate. RUNCMP Reverse circulate C~ 126 gpm with 700 psi: -Close Bag on Tbg. -Reverse circulate 20bb1 9.8 ppg Brine Hi-Vis Sweep. -Followed by 82 bbls 9.8 ppg clean Brine. -Followed by 39 bbls 9.8 ppg Brine w/ Inhibitor. -Followed by 59 bbls 9.8 ppg clean Brine. -Followed by 10 bbls 9.8 ppg Hi-Vis Brine. -Followed by 10 bbls 9.8 ppg Clean brine to flush Lines. 21:00 - 21:30 I 0.50 Corrosion Inhibitor spotted between 4,975' and t/ 8,257' md. RUNCMP Land Hanger. -Land Hanger so that Btm of Seal Assv. is @ $,2Sfi:.md.. -RILDS. 21:30 - 23:30 2.00 BUNCO RUNCMP RU to Test 3-1/2" 13Cr80 Vam Top tubing: -Test Tba to 3,500 psi for 30 min. Good test. -Bleed off Tbg to 1,500 psi. -Test IA to 3,500 psi for 30 min. Good test. 23:30 - 00:00 I 0.50 11/5/2008 100:00 - 00:30 I 0.501 RU 00:30 - 01:00 I 0.501 RU 01:00 - 02:00 1.00 RU 02:00 - 03:00 1.00 RU -Confirm Sheared DCK Valve. -Pumped down IA taking returns out Tubing l~ 106 gpm. -Pumped down Tubing taking returns out IA ~ 106 gpm. RUNCMP LD Landing joint. -Install TWC. RUNCMP Test TWC from bottom to 1,000 psi for 10 min. Good tes -Test TWC from to to 3,500 si for 5 min. Good Test. RUNCMP RD test equipment. -Clear Rig Floor of Vender Tools. RUNCMP Remove & LD long Bales. RUNCMP Cut & slip 1 1/4" drilling line (59.5'). Printed: 11/25/2008 11:01:52 AM • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: WORKOVER Start: 11/1/2008 End: 11/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/5/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 11/5/2008 03:00 - 04:30 1.50 WHSUR P RUNCMP Suck out Stack. LD mouse hole. -Remove Flow line, Riser & Choke hose. -ND BOP's. 04:30 - 06:00 1.50 WHSUR P RUNCMP NU Adaptor flange & Tree. -FMC test Adaptor Flange to 5,000 psi / 30 Min. Good Test. -Test Tree -SPMS Seal Failed. 06:00 - 07:30 1.50 WHSUR P RUNCMP ND Tree. -ND Adaptor Flange. 07:30 - 11:00 3.50 WHSUR P RUNCMP Install new Ada for Flan a &SPMS Seal. -NU Tree. -FMC test Adaptor Flange to 5,000 psi / 30 Min. Good Test. -FMC test Tree to 5,000 psi / 10 Min. Good Test. 11:00 - 12:00 1.00 WHSUR P RUNCMP RU DSM Lubricator and test to 500 psi / 5 Min. Good Test. -Pull TWC. -RD DSM Lubricator. 12:00 - 14:00 2.00 WHSUR P RUNCMP RU to Freeze Protect TBG to 4,970' md. -Little Red pumped Diesel down IA, Up Tbg ~ 84 gpm - 2,100 psi. -Diesel pumped = 103 bbls. 14:00 - 14:30 0.50 WHSUR P RUNCMP RU DSM Lubricator and test to 500 psi / 5 Min. Good Test.; -Install BPV.. -RD DSM Lubricator. 14:30 - 15:00 0.50 WHSUR P RUNCMP Test BPV from bottom to 1,000 psi / 10 Min. Good Test. -Blow Down Lines. -RD Little Red. 15:00 - 16:00 1.00 WHSUR P RUNCMP Secure Tree. -T/I/O = 0 / 0 / 0 psi. -Riq Released ~ 16:00 Hrs. Printed: 11/25/2008 11:01:52 AM ~' L-114A, Well History (Post Rig Workover) Date Summary 11/8/2008 T/I/0= 0/0/0. Pulled 3-1/8" CIW "H" BPV #318 thru tree post rig. 1-2' ext. used, tagged C~ 84". Complete. 11/16/2008 T/I/0=0/0/240. Temp=Sl. Bleed IAP to 0 psi (pre-RWO). AL SI C~ casing valve, ALP=O psi. Replaced IA gauge. SV, WV =Closed. MV, SSV =Open. IA & OA = OTG. NOVP. 11/20/2008 WELL S/I ON ARRIVAL. SET X C-SUB IN X-NIP ~ 8224' MD. PULL INT-DGLV FROM STA #3 C~3 6296' SLM. PULL INT-DCK3 FROM STA #4 ~ 4981' SLM. PULL INT-DGLV FROM STA #5 C~ 3780' SLM. 11/21/2008 SET INT-LGLV (16/64", 1500#) IN STA #5 Q 3780' SLM. SET INT-DGLV IN STA #4 C~ 4981' SLM. SET INT-DGLV (20/64") IN STA #3 C«~ 6296' SLM. PULLED -EMPTY - 3 1/2" X C-SUB FROM X-NIP C~ 8224' MD. PULLED 3 1/2" JUNK CATCHER @ 8274' SLM. MADE FOUR RUNS W/ 10' x 2.25" P. BAILER, MULE SHOE FLAPPER BTM. WORKED FROM 8284' SLM TO 8301' SLM. RECOVERED -3 GAL TOTAL SLUGGITS. MADE 1 UNSUCCESSFUL ATTEMPT TO PULL 3 1/2" WRP W/WFD WRP PULLING TOOL. 11/22/2008 MADE TWO RUNS W/ 10' x 2.25" P. BAILER, FLAPPER BTM TO 3 1/2" WRP C«~ 8301' SLM - 1/2 GALLON OF SLUGGITS RECOVERED. MADE FAILED ATTEMP TO PULL 3 1/2" WRP C«~ 8301' SLM, W/ 3 1/2" WFD WRP PULLING TOOL. RAN W/ 10' x 1 3/4" P. BAILER TO 3 1/2" WRP C~ 8301' SLM ~2 CUPS OF SLUGGITS RECOVERED. CURRENTLY IN HOLE W/ 3 1/2" WFD WRP PULLING TOOL. 11/23/2008 MADE RUN W/ 10' x 2.25" P. BAILER, FLAT FLAPPER BTM TO WRP ®8301' SLM, bailer came back empty. MADE TWO FAILED ATTEMPS TO PULL 3 1/2" WRP C~ 8301' SLM W/ 3 1/2" WEATHERFORD WRP PULLING TOOL, unable to latch. MADE FAILED ATTEMP TO PULL 3 1/2" WDF WRP W/ 2.60" OVERSHOT (1.66" GRAPPLE). LEFT WELL S/I, PAD OP NOTIFIED UPON DEPARTURE. 11/25/2008 WELLS/I ON ARRIVAL. PULLED 3-1/2" WRP FROM 8,284' SLM (missing 3 rubber elements). FISHED 1-1/2 RUBBER ELEMENTS FROM 8,519' SLM. 11/26/2008 FISH APPROX -2 CUPS OF SMALL PIECES OF RUBBER ELEMENT FROM 8,519' SLM. RIH W/ 5' x 2.25" D-DOWN BAILER, TAG 8,519' SLM (SAMPLE OF CARBOLITE). WELL LEFT S/I, TURN OVER TO DSO. Page 1 of 1 JELLHEAD = 11" FMC CTUATOR~ Y BAKER B. ELE?/ = ~ 76.3' ~ F. ELEV = 49.4' OP= 1591' tax Angle = 59° @ 5205' Datum MD = 8621' Datum TVD = 6600' SS DRLG DRAFT L -114A SAFFfYNOTES: 981' 7-5/8" TAM PORT COLLAR 2203' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2693 2652 18 KBG-2 DMY INT 0 11/03/0. 5 3790 3468 53 KBG-2 DOME INT 16 11/21/0 4 4980 4106 59 KBG-2 DMY INT 0 11/2110 3 6292 4801 58 KBG-2 DP INT 20 11121/0 2 7575 5677 24 KBG-2 DMY INT 0 11/0310 1 8135 6205 15 KBG-2 DMY INT 0 11/03/0 MILLOUT WINDOW (L-114A) 2657' - 2677' 7-5/8" CSG, 29.7#, L-80 BTGM, ID = 6.875" ~ 2637' Minimum ID = 2.813 " @ 2203' 3-1 /2" HES X NIPPLE I TOP OF CEMENT 5-112" STUB (TAGGED 08/11/05) I 2715' 5-1/2" EZSV (TAGGED 08/0/05) 2775' 5-1/2" CSG, 17#, L-80 TCII, .0232 bpf, ID = 4.95" 3-112" TBG, 9.2#, IBT-M, .0087 bpf, ID = 2.992" ~~ I 8241' I g2c~c~ 8224' -~ 3-1/2" HES X NIP, ID = 2.813" 8240' 5-1/2" X 4-3/4" XO, ID = 4.0~ $247' 3-1/2" BKR SEAL ASSY, ID = 2.980" 8260' 4-3/4" X 3-1 /2" XO, ID = 2.950" 8264'SLM JUNK CATCHER (10/17/08) PERFORATION SUMMARY REF LOG GRJCCL ON 09/10/05 ANGLE AT TOP PERF: 14° @ 8528' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8528 - 8548 O 09/10/05 1' -i 3-1 /2" X NIP, ID = 2.813" 3' ~-1/2" X NIP, ID = 2.813" 4-1/2" RA TAG BPTD I 8525' I 3/1/2" CSG, 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" I 8821' DATE REV BY , COMMEMS DATE REV BY COMMENTS 08/17/01 CH/KAK ORIGINAL COMPLETION 08/23/05 N9ES SIDETRACK"A" 11/05/08 D14 RWO 11/21/08 DTR/PJC GLV C/O 1 I BOREALIS UNff WELL; L-114A PERMff No: 2051120 API No; 50-029-23032-01 SEC 34, T12N R11 E, 2346' FSL & 3845' FEL RP Fxnlnra4inn f0laekal 12/08/08 Alaska Data & Consulting Services 2525 Gambe:ll Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Bethi wou r,.ti ~ r~1%~~ ~ n,..... NO. 4995 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-026 4994 MEM PROD PROFILE - 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG Q ~ 11/04/08 1 1 P2-41 4994 PRODUCTION LOG - 11/07/08 1 1 1••29/M-25 4994 PRODUCTION LOG 11/04/08 1 1 NIPC-OSA 4994 MEM LDL ~ 11/15/08 1 1 L-114A 4994 USIT ~ ,- ( $ 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ - ( ~ 11/27/08 f f 07-18 4994 INJECTION PROFILE ~- 12/02/08 1 1 15-12B 4994 MEM PROD PROFILE ~p ~- ~ 11/27/08 1 1 4-40/P-43 4994 MEM LDL i~j - '~' lx 11/26/08 1 1 N-14B 4994 MCNL-O`(Si~ ( ' 09/20/08 1 1 01-21A 4994 MCNL -- 09/29/08 1 1 E-29A 4994 MCNL - 09/01/08 1 1 PI FeRF eCKNAWI Fr1RC oc r•eioT av err_~ u~~r_ n~~n o~ru~~u~~~ .. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I ' ! ~ ~. ,' D Date Delivered: Alaska Data & Consulting Services 2525 Gambell Sireet, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: • • ~~ s V 1~~~~ __ ~. TI~.4/~~IAL R ProActive Diagnostic Services, Inc. r1 To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 c d~~ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 a6~ t ~~- r ~ 63~ ProActive Diagnostic Services, Inc. '~03'-! a 3 ~ ~ d 3 ~r 1) Leak Detection -WLD 14-0ct-08 L-114A 1 Color Log / EDE 50029-23032-01 2) Leak Detection -WLD 14-0ctr08 MPS•08 Signed Print Name: ~~1V_~J~'b ~ _~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-IwAIL: o€isar~~3~oragel~r~esea~r~~~ag.sars~ WEBSITE:4nnn~Lv,e~a~r~e~•~ors~ ~_ C:\Documents and Settings\Oamer\Desktop\Transztut_BP.doc ,~ Schlam~erger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2638 ATTN: Beth Well Job # Log Description NO.4250 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suke 100 Anchorage, AK 99501 Field: Borealis Orion Date BL Color CD L-114A L-218 40012309 40012334 OH EDIT MWD/LWD OH EDIT MWDILWD 08120/05 08130/05 2 2 1 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Cenfer LR2-1 ,~ ; ~ V,~,.,.9 ,~ 900 E Benson Blvd .' ~ kAjFl Anchorage AK 99508-4254 ~~ ~ ~ ,I~ ~^*~, ; p ~ yT„!~' Date Delivered: "8 J ~ '`'~o-'~?`D A ~l ls~ ~s a 7°tP ~$j~~,~. ~4~$~3~~i pr`i.,4n,,f „d1~, ('~e~'R?;~ R~'~t Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~Q>~~ osio4im • • 01/18/08 ~~i[I~~m~~s~~~~ NO. 4560 Alaska Data & Consulting Services °~{'t(~~ Company: State of Alaska Anchorage,eAKt99503--2838 00 ~~~ ~ ~ tU V Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Wall .InF, ik Inn fln~r.l n~Inn ~- n~~e a1 r.,~.,. nn L-219 11966240 MDT ~-- iC 12/22107 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL ~ '" f 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE ~C.( ~- as (~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL ~ ~, 01/02108 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~} - 01/04/08 1 15-046 12005202 MEM CEMENT BOND LOG 12/28/07 1 G-31A 11962778 SCMT f - C 01/01/08 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL '~- ~ 08/28/07 1 1 G-04B 11628765 MCNL - ~ ~ 04/06/07 1 1 K-02D 11209613 MCNL ~ - ~ c, 07/21106 1 1 17-07B 11649940 MCNL - 7i / 02/17/07 1 1 L2-28 11975742 RST = 12/05107 1 1 Z-06 11968821 RST ~ 12/13/07 1 1 YLCHJt HGrINVWLtUtit Ktla1P I IiY SICiNINIi ANU KE 1 UKNINIi UNE DOPY EAGIi TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 . a .„>"" i, ~+~' ~ ~) ~~'~ 900 E. Benson Blvd. ~`- ~ ~' ,.~ tl ~,~ ti~.. ~., Anchorage, Alaska 99508 Date Delivered: o~,~+,~`s, ~ !~O~"~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: t ~~ L-114 (PTD#2051120} Sustained~ing pressure ~ Page 1 of 1 Regg, James B (DOA) From; Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~ I(~7 f Sent: Tuesday, November 06, 2007 10:19 AM 1` To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA}; Fleckenstein, Robert J (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Oakley, Ray (PRA); Robertson, Daniel B (Alaska) Cc: Lau, John, Jack; Holt, Ryan P (ASRC); Norene, Tyler M Subject: L-114 (PTD#2051120) Sustained casing pressure Attachments: L-114 TIO 90days.BMP; L-114A.pdf All, L-114 has been found to have sustained casing pressure on the IA. The wellhead pressures were 2100!2000/420 on 11105/07. DHD performed a subsequent TIFL which failed by flow to surface on 11!05/07. L-114 is a gas lifted producer ,~ that has been shut in since 09/06/07. Based on the TIFL results we suspect a faulty check in the orifice GLV in Sta#1. This well has been reclassified to Under Evaluation due to TxIA communication. The Well Integrity plan forward is as follows: Obj: Mitigate TxiA Communication 1. D: TIFL -FAILED 2. S: c/o OGLV in Sta#1 @ 8160' MD '~ 3. D: Re-TIFL T/I/0 Plot for last 90 days «L-114 TIO 90days.BMP» WBS «L-114A. pdf» Please let me know if you have any questions or concerns. Thanks, Ja~.h l:.,au {fc~r ~n.drea l lugl~es} t~~el4lgltegrity ~'.ngin~;e~- c~ff~ce (1107) {;~£)_j~?; l~artn~an~- Y~>7f§ pa~„~~;r (~)d)7) ~~~i~)-5100x 1 ~)2. Sc~' °z~~c~~; ti~~ ~~~~ '77gd1~,~' ~~5~ ~`~ c~ ~v 11 /7/2007 3,000 IA MP.A ~P Pfs(~ L.- 114 A p'~ Zo ~- i i Z + Tbg t IA -~- OA 0 ~ OOOA 8!6!2006 1021(2006 1 P52007 3/1272007 6~G2007 8212007 11 X62007 TREE= 3-1i8" CNV U1IELLHEAb = 11" FMC ACTUATdR = BAKER KB ELEV = 76.3' BF ELEV = ~. ~ . KOP = 49.4' 1591' . -.~.m Max Angle = Datum MD - ~,. .~,. 59° ~ 5205' bo21' Datum TV D = 6600' SS ~ 7-5l8" CSG, 29.7#; L-80 BTC-M, ID = 6.875" ~ 1t71t71tl1'41 ~ = °~~ " '~7~~' °~f~" HES X iPPLE _~ TOP aF CEft9ENT ~--24.06' 5-1r2" STUB (TAGGED 08111105} +-~ 2775 5-1l2" EZSV TAGGED 08/0105) 2775` MILLaUT }NINDOUV (L-114A} 2657` - 267?' 3-112" HES X NIP. ID = 2.813" 9$1 ` ~- ~ 7-518" TAPJi FORT COLLAR 1793° - ~ 3-1 t2" HES X NIP, ID = 2.813" GAS UFO MANDRELS ST MD TVD DEV TYPE VLV LATCH PART DATE 7 2025 2011 15 KGB2-9 DMY INTG 0 08/22/05 6 2848 2809 16 KGB2-9 baME INTG 16 11103106 5 3667 3394 53 KGB2-9 DMY INTG 0 09/02105 4 4663 3939 58 KGB2-9 DOME INTG 16 11/03!06 3 6296 4804 58 KGB2-9 DOME INTG 1 fi 11 /03106 2 7386 5509 31 KGB2-9 DOME INTG 16 11103!06 1 8160 6229 15 KGB2-9 Sa INTG 22 11(03/06 5-112" CSG; 17#, L-80 TCII, .0232 bpf, ID = 4,95" $2~7' -- 3-1 i2" TBG, 9.2#: L-80 IBT-441, .0087 bpf, ID = 2.992" $257' ~ PERFORATION SEJMMARY REF LOG: GR;`CCL aN 09i10r`'05 ANGLE AT TOP PERF: 14° C 8528` Note: Refer to Producfio~s DB for historical perf data SIZE SPF INTERVAL OprtiSgz DATE 2-112" 6 8528 - 8548 O 09/10!05 4-1f2" RA TAG ~ $525' BPTD $725' 311 /2" CSG, 9.2#, L-80 IBT-M, .0087 bpf, I©= 2.992" ~-{ $$2 DATE REV BY COt1fiIL1ENTS 08117(Q1 CFlIKAtC CJFTIGINAL COfV1PLETli?N 08(23105 N9ES SCDETP.Ia,CK"A" _.- 09I10?05 RWI_?PJC PERFORATIaNS 01%17.06 RCCIPAG GLV C`O {01!11;D6} 02i22r'Ofr~ KSBiTHL GLV caa (02(13x06) 11i03r'06 DRFiPJG GL\! c;ra DATE ~ REV BY ~ CrJP7itv1ENTS O130i07 ?I P,IC DRLG DRAFT CORRE( 820' 1-~ s-~ f2„ x a-s!4'° xa, ID = 4.045° I $257' 3-112" BKR SEAL ASSY, ID = 2.980" $2Sp' 4-314" X 3-112" Xa, ID = 2.950" $37 7' 3-112" X NIP. Ib = 2.813" $363' 3-112" X NIP, ID = 2.813° BOREALIS UNIT ~rVELL: L-114A PEF2Mf1" No: °°2051120 API No: 50-1729-23032-01 SEC 34, T12N R11 E, 234n' FSL & 3845° FI1 BP Exploration {Alaska) 1~ ~~a~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2051120 Well Name/No. PRUDHOE BAY UN BORE L-114A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23032-01-00 MD 8826 TVD 6876 Completion Date 9/10/2005 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 / RES / NEU /DEN / PWD (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tyke Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 8826 Open 9/8/2005 !,fit Directional Survey 0 8826 Open 9/8/2005 :~D C Lis 15123v!~Induction/Resistivity 2637 8826 Open 5/16/2007 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics TXT and PDS ~I~ 15123 Induction/Resistivity 2 Blu 2637 8826 Open 5/16/2007 MD Vision Service 20-Apr- I 2005 'og 15123 Induction/Resistivity 2 Blu 2637 8826 Open 5/16/2007 TVD Vision Service 20-Apr- - ----_ --- - 2005 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y Chips Received? --'Y'TN- Analysis ~fT 1F~ Received? Comments: Compliance Reviewed By: Date: ,~. Daily History Received? ~.~ Formation Tops ~.L-N '! '~ STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS .. -~ .. ~~~ AI8Sk8 nif ~n,~rd ~ 7` i ~~~Ur`S 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 S ~~ 8 Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~/~,,~r "':'u~ ,a ~~ ~ S 't~~~@ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ r1G 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ! Exploratory ~ 205-1120 3. Address: P.O. Box 196612 Stratigraphic '~ Service l" 6. API Number: Anchorage, AK 99519-6612 50-029-23032-01-00 7. KB Elevation (ft): 9. Well Name and Number: 76.3 KB L-114A 8. Property Designation: 10. Field/Pool(s): ADL-028239 PRUDHOE BAY Field/ BOREALIS OIL Pool 11. Present Well Condition Summary: Total Depth measured 8826 feet Plugs (measured) None true vertical 6876.1 feet Junk (measured) None Effective Depth measured 8725 feet true vertical 6777.42 feet Casing Length Size MD TVD Burst Collapse Conductor 78 20" 91.5# H-40 28 - 106 28 - 106 1490 470 Surface 2610 7-5/8" 29.7# L-80 27 - 2637 27 - 2598.06 6890 4790 Intermediate 8217 5-1/2" 15.5# L-80 24 - 8241 24 - 6306.97 7000 4990 Production 581 3-1/2" 9.2# L-80 8241 - 8822 6306.97 - 6872.19 10160 10530 Perforation depth: Measured depth: 8528 - 8548 True Vertical depth: 6586.15 - 6605.55 Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 22 - 8257 Packers and SSSV (type and measured 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: 972 424 380 420 340 Subsequent to operation: 1829 627 1473 540 440 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~: Service "' Daily Report of Well Operations X 16. Well Status after proposed work: 0it ~' Gas ~' WAG ~! GINJ WINJ 1""-'° 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 Sharmaine Vestal Printed Name Sharmaine Vestal ~ Title Data Mgmt Engr 3/13/2006 ~ ' ~C Yl ~ >~~~2 Signatu ~-3 ~ ,r#;ati~J Phone 564-4424 Date r~~. ~y/ -n Form 10-404 Revised 04/2004 ~ ~ ~ ~„ ~ ~ ~ ~'; ~ -/ I,i>~`L ~~ ~ '~ L`JGh Submit Original Only V ~Y...s^.`~. ! ! L-114A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/31/2006 Frac Kuparuk C sand perfs 8528' - 8548' w/128K# of 16/20 carbolite, YF125LG gel system. 23.7K# to recover in wellbore (76 bbls). Well is not freeze protected. Max treating pressure 7960 psi. Average treating pressure 3860 psi. Tree saver pulled, all cups .retrieved. '`* SHUT IN JOB COMPLETE** FLUIDS PUMPED BBLS 1360 GW 3 Diesel 1363 TOTAL t. ! STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMf~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/10/2005 12. Permit to Drill Number 205-112 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/15/2005 13. API Number 50-029-23032-01-00 4a. Location of Well (Governmental Section): Surface: 2346' FSL 3845' FEL SEC 7. Date T.D. Reached 8/20/2005 14. Well Name and Number: PBU L-114A , , . 34, T12N, R11 E, UM Top of Productive Horizon: 2910' FSL, 2849' FEL, SEC. 33, T12N, R11 E, UM g• KB Elevation (ft): 76.3' 15. Field /Pool(s): Prudhoe Bay Field /Borealis Pool Total Depth: 2932' FSL, 2914' FEL, SEC. 33, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 8725 + 6777 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583072 y- 5978067 Zone- ASP4 10. Total Depth (MD+TVD) 8826 + 6876 Ft 16. Property Designation: ADL 028239 TPI: x- 578782 y- 5978584 Zone- ASP4 Total Depth: x- 578716 Y- 5978606 Zone- ASP4 11. Depth where SSSV set (Nipple) 1793' 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/RES/NEU/DEN/PWD 22. CASING, LINER AND EMENTING RECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 106' Surface 106' 30" 260 sx Arctic Set A rox. 7-5/8" 29.7# L-80 27' 2637' 27' 2598' 9-7/8" 352 sx Arcticset Lite, 173 sx Class 'G' 5-1 /2" x 3-1 /2" , ~n ~ 15.5# ~ s.2a L-80 24' 8821' 24' 6871 6-3/4" 232 sx Class 'G', 158 sx Class 'G' 23. Perforations open to Produc tion (MD +TV D of Top and " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 8257' None MD TVD MD TVD 8528' - 8548' 6586' - 6606' 2rj. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 4638' Freeze Protect w/ 93 Bbls of Diesel 26. PRODUCTION TEST Date First Production: September 13, 2005 Method of Operation (Flowing, Gas Lift, etc.) Gas Lift : Date Of Test 9/13/2005 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 201 GAS-MCF 77 WATER-BBL -0- CHOKE SIZE 176 GAS-OIL RATIO 382 Flow Tubing Press. 30 Casing Pressure 1,320 CALCULATED 24-HOUR RATE OIL-BBL 1,206 GAS-MCF 461 WATER-BBL -0- 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). Suk]rr~wit ccu;e chips; if none, state "none". .~- ~ , LG, 7¢ M~~ ~ ~~~ ~~ ( ~~ ~, ~)~i ({ 2[)U5 Z6 tS '" ° its None ~ `~ ( _ e V ~iF(EU '~~~~~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE $IDE ~' I ` I ~ I I ~+ ~ L_ r~ 28. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 2921' 2770' None Ugnu M Sands 4577' 3894' Schrader Bluff N Sands 5084' 4160' Schrader Bluff O Sands 5231' 4236' Base Schrader Bluff /Top Colville 5944' 4615' HRZ 8101' 6172' Kalubik 8328' 6392' Kuparuk D 8492' 6551' Kuparuk C 8524' 6582' Kuparuk B 8690' 6743' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date. ~' 'O~~b PBU L-114A 205-112 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Matt Martyn, 564-4101 INSTRUCTIONS GeNeruL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 8/26/2005 11:38:47 AM BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: - Date j From - To 8/9/2005 00:00 - 06:00 06:00 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00- 11:00 11:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 23:30 23:30 - 00:00 8/10/2005 00:00 - 01:00 01:00 - 02:00 02:00 - 03:00 03:00 - 03:30 L-114 L-114 Spud Date: 8/4/2001 REENTER+COMPLETE Start: 8/4/2005 End: 8/16/2005 NABOBS ALASKA DRILLING I Rig Release: 8/23!2005 NABOBS 9ES Rig Number: Hours Task Code I NPT i :Phase Description of Operations 6.00 MOB P 2.50 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 1.00 WHSUR P 2.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P 1.50 WHSUR P 2.00 BOPSU P 1.00 BOPSU P 4.50 BOPSU P 0.50 BOPSU P 1.00 PULL P 1.00 BOPSU P 1.00 PULL P 0.50 PULL P 03:30 - 15:00 I 11.501 PULL I P 15:00 - 15:30 0.50 PULL I P 15:30 - 16:00 0.50 BOPSU P 16:00 - 17:00 1.00 EVAL P 17:00 - 18:30 I 1.501 DHB I P 18:30 - 19:00 I 0.501 DHB I P 19:00 - 21:00 I 2.00 I STCTPL I P 21:00 - 00:00 I 3.001 STCTPL I P PRE Move rig and spot over L-114A. Accepted Rig C 0600 hrs. DECOMP Check Annulus Pressures, IA 0 psi. OA 250 psi. Install Secondary Annulus Valves on IA and OA. R/U Circulating Lines to Tree for Displacement of Freeze Protection from Wellbore taking Returns Through Choke Manifold to Cuttings Tank DECOMP P/U and R/U DSM Lubricator and Pull BPV. R/D and L/D Luburicator. Tubing 0 psi. DECOMP Held Pre-Spud Safety Meeting w/ Toolpusher, WSL and Mudman DECOMP R/U Rig Floor to Reverse Out Freeze Protection. Test Lines U 3,500 psi DECOMP Reverse Circulated Diesel f/ 2,428' at 3 bpm at 500 psi. Switch Directions and Circulate Down Tubing taking Returns Up Annulus at 3 bpm at 230 psi. Total Diesel Recovered - 50 bbls. Monitor Well-Static. Circulate 8.8 ppg 40 bbl Brine Soap Sweep I followed by 150 bbls Clean 8.8 ppg Brine at 4 bpm at 625 psi. ~ Monitor Well-Static DECOMP Blow Down Choke Manifold and Lines. R/D Same. I DECOMP Install TWC and Test from Below U 1,000 psi ' DECOMP N/D Production Tree. Inspect NSCT Threads on Tubing Hanger DECOMP N/U BOPE, Install Drilling Riser. DECOMP R/U Test Joint and Test Manifold. DECOMP PJSM-Test BOPE's; Blind/Shear and Pipe Rams, Annular, Choke Manifold, Choke and Kill Line Valves, Floor Safety Valves, Upper and Lower IBOP Valves t/ 250 psi low / 3,500 psi high. All Tests held 5 min with No Visual Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor, Nabors Tourpusher and AOGCC Rep. Jeff Jones DECOMP R/D Test Joint and Manifold. Blow Down Top Drive. DECOMP Change Out Bails DECOMP P/U and R/U DSM Lubricator and Pull TWC. R/D Lubricator. Monitor Well-Static DECOMP P/U XO/ Landing Joint and M/U to Tubing Hanger. R/U Tubing Handling Equipment and Camco Contol Line Spooler DECOMP Pull Tubing Off Seat with 98,000# Up Weight, Continue to Pull Tubing Hanger to Rig Floor, Circulate Surface to Surface w/ 8.8 ppg Brine at 10 bpm at 3,000 psi. Monitor Well-Static DECOMP B/O and L/D Landing Joint and Hanger. Continue to POH with 3-1/2" 9.2# L-80 IBT-mod Tubing. Recovered 229 Full Jts-2 GLM's-1 HES SSSV-3 Pup Jts-20.12' Cutoff Jt. and 75 SS I Contol Line Bands ', DECOMP Clean and Clear Rig Floor DECOMP Install Wear Ring, 9" ID DECOMP PJSM-R/U SWS E-Line, RIH with 4.72" Gauge Ring/Junk Basket t/ 2,870'. POH w/ Same. Junk Basket Clean DECOMP M1U EZSV on E-Line. RIH and Set at 2,770'. POH w/ E-line and R/D SWS DECOMP Test EZSV x 5-1/2" Casing U 3,500 psi. Held 10 min. Bled Down Pressure and Blew Down Lines. DECOMP PJSM-R/U Handling Tools for 3-1/8" DC's and 2-7/8" PAC DP. Load Pipeshed with DC's and Strap Same. DECOMP P/U and M/U 5-1/2" Casing Cutter BHA: 3-3/4" Multi-String Printed: 8/26/2005 11:38:53 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-114 L-114 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABORS9ES Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Date I From - To Hours Task ~' Code NPT Phase 8/10/2005 21:00 - 00:00 3.00 STCTPL P DECOMP 8/11/2005 00:00 - 03:30 3.50 STCTPL P DECOMP 03:30 - 04:00 04:00 - 05:00 0.50 STCTPL P 1.00 STCTPL P DECOMP DECOMP 05:00 - 06:00 1.001 STCTPL I P 06:00 - 08:00 I 2.001 STCTPL ( P 08:00 - 10:30 2.50 STCTPL P 10:30 - 11:30 1.00 STCTPL P 11:30 - 12:00 0.50 STCTPL P 12:00 - 14:30 2.50 STCTPL P 14:30 - 15:00 0.50 STCTPL P 15:00 - 16:00 1.00 STCTPL P 16:00 - 16:30 0.50 STCTPL P 16:30 - 17:00 I 0.501 STCTPL I P 17:00 - 17:30 0.50 STCTPL P 17:30 - 21:00 3.50 STCTPL P 21:00 - 21:30 0.50 STCTPL P 21:30 - 00:00 2.50 STCTPL P 8/12/2005 00:00 - 02:00 2.00 STKOH P 02:00 - 02:30 0.50 STCTPL P 02:30 - 03:00 0.50 STCTPL P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 2 of 9 Spud Date: 8/4!2001 End: 8/16/2005 Description of Operations Cutter w/ 3" Knives-XO-XO-Stabilizer-3 x 3-1/8" DC's. Total BHA Length = 96.99'. NOTE: While Picking up DC's Heavy Internal Scaling was Encountered During the Rabbeting Process. Decision was Made to Flush DC's w/ Rig Pumps Prior to RIH w/ BHA RIH w/ 2-7/8° PAC DP. Picking Up from Pipeshed 1 x 1. Tag EZSV at 2,775' P/U and M/U XO's from Top Drive to 2-7/8" PAC DP Break Circulation at 2 bpm, 385 psi. Up Wt. 65K, Dn Wt. 60K. Shut Down Pumps. Position Cutter Blades at 2,720'. Bring Rotary Up to 100 rpm, 1,000 ft/Ibs Torque. Bring Pumps up to 725 psi at 2.5 bpm. Rotated Steady for 20 min. Observed Pressure Loss of 65 psi. No Increase or Decrease in Annulus Pressure of 200 psi. Increase Pump Rate to 3.5 bpm at 935 psi. Pump 25 bbl Hi-Vis Sweep Surface /Surface at 3.5 bpm at 1,015 psi. Continously Rotating at Cut with 100 rpm through out Circulatio PJSM-Close Annular and Pump Down DP. Lined Up to take Returns up OA Through the Choke to Cuttings Tank. Pressured up to 700 psi. OA Pressure Steady at 180 psi. Bled Down OA to 0 psi. Bring DP Pressure up to 1,240 psi. No Returns, Pressure Held Steady. Bled Down all Pressure. Open Annular. Close OA. POH w/ 2-7/8" PAC DP UD Cutter-No Wear on Cutter Blades, P/U New Cutter Test 5-1/2" Casing to 3,500 psi. Good Test RIH w/ 5-1/2" Casing Cutter. Tag EZSV at 2,775' P/U to 2,580'. Pump at 2.5 bpm, 555 psi. Slack Off and Located 5-1/2" Collar at 2,709' Position Cutter at 2,715'. Cut Casing with 100 Rotary RPM, 705 ff/Ibs Torque, 3.25 bpm at 780 psi. Increase Pump to 4-1/2 bpm, 1,500 psi, 680 ft/Ibs Torque. Shut Down Pump and P/U above Cut, Slack Off with Pumps at 3.5 bpm at 530 psi. to Verify Cut. Blades Engaged Cut at 2,715' and Took Weight Closed Annular. Pump Down DP Attempting to Take Returns up OA through Choke to Cuttings Tank. Pressured up to 980 psi. Started Pumping Fluid Away with No Returns from OA. Shut Down Pumps and Bled Down Pressure. Pump Down OA and Pressured up to 2,500 psi. No Bleed Off Held 2,500 psi on OA. No Bleed Off Bled Down OA Pressure and Leave Open to Cuttings Tank. Pump Down DP with 102 deg 8.8 ppg Brine, Taking Returns up IA. Circulating at 3.5 bpm, 1500 psi. Shut Down Pumps and Switch to OA. Pressure up on OA in 500 psi Increments to 2,500 psi. No Pressure Loss at Each Stage. Circulate Heated 8.8 ppg Brine Down DP Taking Returns UP IA at 3.5 bpm, 1,500 psi POH w/ 2-7/8" PAC DP B/O and UD 3-1/8" DC's, UD 5-1/2" Casing Cutter C/O Elevators, P/U Joint 4" DP, Pull Wear Ring Printed: 8/26/2005 17:38:53 AM • BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task Code NPT 8/12/2005 03:00 - 03:30 0.50 STCTPL P 03:30 - 05:30 2.00 STCTPL P 05:30 - 06:00 0.50 STCTPL P 06:00 - 08:00 2.00 STCTPL P 08:00 - 10:30 I 2.50 I STCTPL I P 10:30 - 11:00 I 0.50 I STCTPL I P 11:00 - 12:30 I 1.501 STCTPL I P 12:30 - 16:00. 3.501 STCTPL I P 16:00 - 16:30 0.501 STCTPL P 16:30 - 17:30 1.00 ~ STCTPL P 17:30 - 19:00 1.50 STCTPL P 19:00 - 19:30 0.50 STCTPL P 19:30 - 20:30 I 1.001 STCTPL I P 20:30 - 21:00 0.50 ~ STCTPL ~ P 21:00 - 22:30 1.50 STKOH P 22:30 - 23:00 0.50 STCTPL P 23:00 - 00:00 ~ 1.00 ~ STCTPL P 8/13/2005 100:00 - 01:30 I 1.501 STCTPL I P 01:30 - 02:30 1.00 ~ STCTPL' P 02:30 - 03:30 1.00 STKOH P 03:30 - 05:00 1.50 STKOH P Start: 8/4/2005 Rig Release: 8/23/2005 Rig Number: Spud Date: 8/4/2001 End: 8/16/2005 Phase Description of Operations __ _ _ __ DECOMP P/U and M/U 5-1/2" Casing Spear w/ 4.961 Grapple on 4" DP DECOMP RIH w/ Spear Assy. Spear Stopped at 25'. Try to Work Spear through Hanger, w/o success. Released Spear and POH. Suspect Pack-off. Pull Pack-off and Rerun Spear. Stopped at 25'. Worked Spear Free. POH w/ Same DECOMP Clear and Clean Rig Floor DECOMP C/O Bails, P/U 200 Ton Elevators, M!U 5-112" BTC x HT40 XO, Floor Safety Valve and Circulating Head DECOMP P/U Landing Joint and M/U to 5-1/2" Hanger. Pull 210K, (23" stretch). Work Pipe f/ 50k - V 210K with 500 psi on 5-1/2" Casing, w/o success. Work Pipe V 235K w/o success. Bled Down Pressure to 0 psi. DECOMP Pump Down OA and Pressure Up V 2,350 psi in Attempt to Circulate OA and IA. No Communication. Bled Down All Pressure. DECOMP R/D Landing Joint, XO, Safety Valve and Circulating Head. C/O Elevators and Bails, R/U 4" Elevators DECOMP P/U and M/U Jarring Assy. w/ Spear (4.961 Grapple). M/U Landing Joint to Hanger. Spear Landing Joint w/ Jarring Assy. Jarring on 5-1/2" Casing with 235 Up Wt. Grapple Failed. B/O and UD Spear Assy. B/O and UD Landing Joint. DECOMP Inspect Derrick and Top Drive DECOMP P/U and M/U Multi-Bring Cutter (w/ 3" Knives), 3 x 31/8" DC's. Total BHA Length = 96.73' DECOMP RIH w/ 2-7/8" PAC DP V 2,615'. DECOMP M/U Top Drive and Established Parameters; Up Wt. 62K, Dn Wt. 60K, Break Circulation w/ 2.5 bpm, 500 psi. S/O and Found 5-1/2" Collar at 2,625'. Shut Down Pumps and S/O to Position Knives at 2,627' DECOMP Cut 5-1/2" Casing at 2,627' w/ 100 Rotary rpm {680 fV{bs Torque w/o Pump . ump Rate 3.5 bpm, 1,100 psi, 730 fUlbs Torque. Observed Pressure Loss of 60 psi. Increased Pump Rate to 4.5 bpm, 1,640 psi. DECOMP Circ Hi-Vis Sweep S/S. Continuing to Rotate at 100 rpm at 2,627' While Circulating Sweep Around. Shut Down Rotary and Pumps. P/U V 2,635' Bring Pumps Up to 600 psi. S/O and Engaged Cut w/ Knives at 2,627'. Repeat Process to Verify Cut. DECOMP POH w/ 2-7l8" PAC DP DECOMP UD 3-1/8" DC's & 5-1/2" Casing Cutter. Lost 1 Knife from Cutter, 3" x 1-1l4" x 5/8" DECOMP C/O Elevators, P/U 5-1/2" Landing Joint and M/U to Casing Hanger. M/U Top Drive to Landing Joint DECOMP Work 5-1/2" Casing f/ 2,627' - V 2,600'. String Came Free at 325K. Intermittent Drag to 325K.Attempting to Circulate w/o success DECOMP B/O and L/D Landing Joint and Casing Hanger DECOMP POH w/ 5-1/2" Casing w/O Circulating V 2,425' DECOMP Close Annular and Circulate 45 bbls 8.8 ppg Brine Down Casing Taking Returns up OA to the Cutttings Tank. Open Annular and Circulate 8.8 ppg Brine S/S. Pump 50 bbls Safe-Surf Pill followed by 40 bbls 120 deg Brine. Pump Additional S/S at 10 bpm to Clean Casing. I I I I I I i Printed: 8/26/2005 71:38:53 AM • BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: REENTER+COMPLETE Start: 8/4/2005 End: 8/16/2005 Contractor Name: NABOBS ALASKA DRILLING t Rig Release: 8/23/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To ' Hours i Task Code ,j NPT Phase ! Description of Operations 8/13/2005 05:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 20:00 20:00 - 00:00 3.50 STKOH P 1.00 STKOH P 2.50 STKOH P 2.50 STKOH P 0.50 STKOH P 1.00 STKOH P 0.50 STKOH P 0.50 STKOH P 1.00 STKOH P 1.50 STKOH P 0.50 STKOH P 4.00 STMILL P 8/14/2005 100:00 - 12:00 I 12.001 STMILL I P 12:00 - 14:00 I 2.001 STMILL I P 14:00 - 15:30 1.50 STMILL P 15:30 - 16:30 1.00 STMILL P 16:30 - 17:30 I 1.001 STMILL I P 17:30 - 18:30 1.00 ~ STKOH P 18:30 - 21:00 2.50 STKOH P 21:00 - 21:30 0.50 STKOH P 21:30 - 22:30 I 1.00 ~ STKOH P 22:30 - 23:00 0.50 STKOH P 23:00 - 00:00 1.00 STKOH P 8/15/2005 00:00 - 01:30 1.50 STKOH P 01:30 - 02:00 0.50 STKOH P 02:00 - 06:30 4.50 STKOH P 06:30 - 07:00 0.50 STKOH P 07:00 - 08:00 1.00 STKOH P 08:00 - 08:30 ~ 0.50 ~ STCTPL P DECOMP POH w/ 5-1/2" Casing DECOMP Clean and Clear Rig Floor, UD Baker Tools, R/D and UD Casing Equipment DECOMP RIH w/ 2-7/8" PAC DP From Derrick DECOMP POHLDDP DECOMP R/D and UD 2-7/8" Handling Tools DECOMP Slip and Cut Drilling Line. Inspect Drawworks DECOMP Install Wear Ring DECOMP P/U 15 Joints 4" DP and Stand Back in Derrick DECOMP P/U Milling BHA; Pilot Mill-3 x Junk Baskets-Bit Sub-Jars-9 x 4-3/4" DC's- XO. BHA Total Length = 306.33' DECOMP RIH w 4" DP. Picking Up From Pipeshed 1 x 1 DECOMP M/U Top Drive. Established Parameters; Up Wt. 85K, Dn Wt. 80K, Rt Wt. 82K, Pump 8 bpm, 350 psi, Rotary 65 rpm, 900 ftllbs Torque. Wash Dn f/ 2,544'. Mi11 Started Taking 2/3K Wt. at 2,550' - U 2,627'. Mill 5-1/2" Casing f/ 2,627', WOM 3/4K. 80 rpm, 1,100 ft/Ibs Torque. DECOMP Mill 5-1/2" Casing fl 2,627' - U 2,633'. WOM 3/4K. 80 rpm, 1,250 fUlbs Torque. 8 bpm, 500 psi. Pumping Hi-Vis Fibre Sweep Every 5'. Weighted Fibre Sweep Every 20' DECOMP Mill f/ 2,633' - U 2,691'. Up Wt. 83K, Dn Wt. 80K, Rt Wt 80K, Pump 8 bpm, 585 psi, Rotary 100 rpm, 1450 fUlbs Torque. Pumping Hi-Vis Sweep Every 5' U 2,640', Every 10' t/ 2,690' DECOMP Circulate and Condition Mud; Pump 27 bbls Weighted Fibre Sweep followed by 23 bbls Hi-Vis Sweep,. Back Ream to 7-5/8" shoe at 2,636'. Circulate Bottoms Up DECOMP POH w/ 4" DP DECOMP UD Milling BHA; Recovered 1/2 gal. Metal Cuttings from Junk Baskets DECOMP Pull Wear Ring, P/U BOPE Flushing Tool, Function All Rams and Annular, Flush Choke Line. Flush ROPE of Metal Cuttings. Install Wear Ring, 9.937 ID, UD Flushing Tool DECOMP R/U 2-7/8" Handling Tools. RIH w/ 2-7/8" Mule Shoe- 4 Stands 2-7/8" PAC DP- 2 x XO. Total Stinger Length = 380.36' DECOMP RIH w/ 4" DP. P/U from Pipeshed 1 x 1 to 2,775' DECOMP Circulate and Condition Mud. Held PJSM w/ WSL, Rig Crew, SCH Cementers, MI and Veco while Circulating. DECOMP R/U Cement Head, Pump 5 bbls Water, Shut In Cement Head, Test Lines to 3,500 psi. Pump 5 bbls water, 14 bbls 17 ppg Class "G" Cement, 3.28 bbls water. Switched to Rig Pump and Displace Cement w/ 19.5 bbls 8.8 ppg Brine at 3 bpm, 235 psi. R/D Cement Head and POH with 5 stand 4" DP t/ 2,346'. CIP AT 2215 HRS. DECOMP Circulate Bottoms Up at 450 gpm at 680 psi. No Cement at BU DECOMP POH w/ 4" DP WEXIT POH w/ 4" DP and Stand Back In Derrick. POH w/ 2-7/8" PAC Dp and UD Same WEXIT R/D 2-7/8" Handling Tools WEXIT P/U 111 Joints (3,470') 4" DP and Stand Back In Derrick WEXIT Pull Wear Ring WEXIT P/U BOPE Flushing Tool, Function Test Rams and Annular, Flush Stack, UD Flushing Tool WEXIT Test Cement Plug U' 1,500 psi. Good Printed: 8/26/2005 11:38:53 AM BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: REENTER+COMPLETE Start: 8/4/2005 End: 8/16/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/23/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To ' Hours Task '~ Code ~ NPT ~ Phase 8/15/2005 108:30 - 10:00 1.50 BOPSU I I P I I WEXIT 10:00 - 10:30 0.50 BOPSUFi P 10:30 - 12:00 1.50 BOPSU P 12:00 - 13:00 1.00 BOPSU P 13:00 - 15:30 2.50 STKOH P 15:30 - 16:00 0.50 STKOH P 16:00 - 17:30 1.50 STKOH P 17:30 - 18:00 ' 0.50 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 20:00 I 1.001 DRILL I P 20:00 - 22:00 2.00 DRILL P 22:00 - 00:00 2.00 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INTi INT1 I~ I NT1 INT1 Description of Operations Install Test Plug, Remove Mouse Hole and Drilling Riser. N/D BOPE FMC Rep. Inspected Csg Bowl. One area of minor scratching. Dress with flapper wheel and sand paper to remove any sharpe edges. OK N/U BOPE, Install Drilling Riser and Mouse Hole Test Csg. Spool x Tbg. Spool Flange to 250 psi low/ 3,500 psi high. Test Held- for 5 min Each w/o Pressure Loss. R/D Test Equipment and Remove Test Plug. P/U and M/U Directional BHA; Bit, Motor (1.15 ABH), By Pass Sub, NM Lead DC, NM Stabilizer, MWDlLWD, VPWD, ADN, 2 NM Flex DC, XO, 1 HWDP, Jars, 20 HWDP, Ghost Reamer. Total BHA Length = 860.06' Test MWD Tools at 860', 260 gpm, 740 psi, Good Test. RIH w/ 4" Dp. Tag Cement at 2,406' Drill Cement f/ 2,406' - U 2,657' Drill f/ 2,657' - U 2,677', KOP Circulate, Pump~~T~bl Spacer and Displace 8.8 ppg Brine with 8.8 ppg LSND Mud Perform LOT with following results: EMW = 13.8 ppg; Test mud= 8.8; TVD=2598 Surface pressure=675 Drill f/ 2,677' - U 2,822'. Observed Increased Flow, Shut Well In Let Pressures Stabilize, Initial SICP 270 psi, Initial SIDPP 60 psi 2210 hrs. S1CP 370 psi. SIDPP 80 psi 2217 hrs. SICP 450 psi. SIDPP 110 psi 2220 hrs. SICP 490 psi SIDPP 150 psi 2245 hrs. SICP 590 psi SIDPP 270 psi 8/16/2005 100:00 - 01:00 01:00 - 02:00 02:00 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 06:30 1.001 DRILL I P 1.00 DRILL P 1.50 DRILL P 1.50 DRILL P 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start Drillers KIII Method. Circulate 8.8 ppg Mud. STB Stks = 497, BTS Stks = 1,475, Total Stks = 1.972 Stks. ICP 480 psi, At 300 Stks. Away Lost Returns. Shut Down Pumps, Shut Well In. SICDP 270 psi, SIDPP 150 psi. Resume Pumping w/ New Valve, ICP 380 psi. Continue Pumping at 34 spm Until 8.8 ppg Mud at Surface Shut Down Pumps, Shut Well In, Let Pressures Stabilize, SICP 150 psi, SIDPP 150 psi. Bled Down 50 psi, Pressure Stabilized at 100 psi, Bled Down 50 psi to 50 psi, Pressure Stabilized at 50 psi, Bled All Pressure Down to 0 psi. Opened Annular and Monitor Well. Well Started to Flow Gradually Increasing in Volume, Shut Well In. Monitor Pressures; Final Shut In Pressure SICP 150 psi, SIDPP 150 psi. Weight Mud in Pits to 9.2 ppg. Start Pumping 9.2 ppg LSND Mud. ICP = 400 psi, FCP = 348 psi. Circulated Around Until 9.1+ppg Back to Surface. Shut Down Pumps, Shut In Well, SICP = 90 psi, SIDPP = 90 psi. Bled Down 5 bbls Mud. CBU w/ 9.2 ppg Using Drillers Method. Shut Down Pump, Shut In Well. SICP 0 psi, SIDPP 0 psi. Open Up Well. Observed Small Amount of Flow. Shut In Well After 20 min SICP 20 psi, SIDPP 0 psi. Circulate Around 9.2 ppg Mud at 52 spm 300 psi (SPR) Through Choke. Shut down pumps, monitor pressure, zero Printed: 8/26/2005 11:38:53 AM • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours Task I Code ~I NPT -- _ ~- 8/16/2005 05:30 - 06:30 1.00 DRILL P 06:30 - 07:00 0.50 DRILL P 07:00 - 12:00 I 5.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 8/17/2005 100:00 - 02:15 I 2.251 DRILL I P 02:15 - 02:30 I 0.251 DRILL I P 02:30 - 03:00 I 0.501 DRILL I P 03:00 - 12:00 I 9.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 8/18/2005 (00:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 8/19/2005 100:00 - 12:00 ~ 12.00 DRILL P 12:00 - 00:00 I 12.001 DRILL I P Spud Date: 8/4/2001 Start: 8/4/2005 End: 8/16/2005 Rig Release: 8/23/2005 Rig Number: Phase Description of Operations pressure on casing and DP, open well Circulate bottoms up at drilling rate 290 gpm, 1620 psi, 100 rpm torque 2k. No signs of gas with bottoms up. well stable. Directional drill from 2,822' to 3,399', 5-10k wob, 290 gpm, 1820 psi on bottom, 1620 psi off bottom, 100 rpm, torque 2.5k on bottom, 1.9k off bottom, up wt = 97k, do wt = 79k, rt wt = 89k, Calculated ECD 10.39, actual ECD 10.67. AST = 1.10 hrs, ART = 1.20 hrs. Directional drill from 3,399' to 4,790', 5-10k wob, 290 gpm, 1850 psi on bottom, 1730 psi off bottom, 100 rpm, torque 3.5k on bottom, 2.5k off bottom, up wt = 108k, do wt = 83k, rt wt = 90k, pumped 20 bbl hi vis sweep at 4,722' with no increase in cuttings. Calculated ECD 10.50, actual ECD 10.90. AST = 2.45 hrs, ART = 5.42 hrs. Directional drill from 4,790' at 5,074' driller noticed 5 increase in flow, picked up to monitor well. Monitor well, gained 1 bbl in 10 min., fluid level then began to drop slightly, with small amount of gas breaking out at surface. Circulate bottoms up at 290 gpm, 1750 psi, the first 70 bbls pumped showed small amount of gas breacking out at surface then cleaned up, no sign of gas at bottoms up. Shut down pumps, monitor well, well static. Continue drilling from 5,074' to 5,758' 10-15k wob, 290 gpm, 2100 psi on bottom, 1950 psi off bottom, 100 rpm, torque 4-5k on bottom, 3.5k off bottom, up wt = 120k, do wt = 90k, rt wt = 102k, Cal ECD 10.68, actual ECD 10.90, AST = 1.4 hrs, ART = 6.29 hrs. Directional drill from 5,758' to 6,640' 10-15k wob, 288 gpm, 2290 psi on bottom, 2135 psi off bottom, 100 rpm, torque 4-5k on bottom, 3.5k off bottom, up wt = 130k, do wt = 94k, rt wt = 105k, Cal ECD 10.49, actual ECD 11.58, AST = 2.25 hrs, ART = 6.63 hrs. Directional drill from 6,640' to 7,129' 10-20k wob, 290 gpm, 2260 psi on bottom, 2075 psi off bottom, 100 rpm, torque 5k on bottom, 4k off bottom, up wt = 139k, do wt = 96k, rt wt = 112k, Cal ECD 10.54, actual ECD 10.86, AST= 3.93 hrs, ART = 6.23 hrs. Directional drill from 7,129' to 7,688' 10-20k wob, 285 gpm, 2450 psi on bottom, 2230 psi off bottom, 100 rpm, torque 5.5k on bottom, 4k off bottom, up wt = 145k, do wt = 100k, rt wt = 115k, At 7,450' began weighting up mud system to 10 ppg by adding 290 bbls of 11 ppg spike fluid treated with Resinex and Asphasol. Cal ECD 11.15, actual ECD 11.65, AST= 2.27 hrs, ART = 7.31 hrs. Directional drill from 7,688' to 8,155' 10-20k wob, 289 gpm, 2460 psi on bottom, 2220 psi off bottom, 100 rpm, torque 6k on bottom, 5k off bottom, up wt = 168k, do wt = 108k, rt wt = 135k, Cal ECD 11.14, actual ECD 11.60, AST = 1.85 hrs, ART = 8.64 hrs. Directional drill from 8,155' to 8,656' 10-20k wob, 290 gpm, 2520 psi on bottom, 2270 psi off bottom, 100 rpm, torque 9k on bottom, 7k off bottom, up wt = 183k, do wt = 108k, rt wt = 137k, Cal ECD 10.94, actual ECD 11.31, AST = 1.44 hrs, ART = 7.51 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi Printed: 8/26/2005 11:38:53 AM • BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: REENTER+COMPLETE Start: 8/4/2005 End: 8/16/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/23/2005 Rig Name: NABOBS 9ES Rig Number: Date ~ From = To ', Hours Task ~ Code NPT ~ Phase ~, Description of_Operations - - , _ 8/19/2005 12:00 - 00:00 12.00 DRILL ~ P PROD1 hrs. 8/20/2005 00:00 - 02:00 2.00 DRILL P PROD1 Directional drill from 8,656' to TD at 8,826' 10-20k wob, 290 gpm, 2520 psi on bottom, 2270 psi off bottom, 100 rpm, torque 9k on bottom, 7k off bottom, up wt = 183k, do wt = 108k, rf wt = 137k, Cal ECD 10.94, actual ECD 11.18, ART = 2.29 hrs. 02:00 - 03:30 1.50 DRILL P PROD1 Pump 20 bbl hi vis weighted (11.4 ppg) sweep with 1 Ib Super-Sweep, around, pumping 290 gpm 2,370 psi, 110 rpm, torque 9-9.5k. No increase in cuttings with sweep. Cal ECD 10.91 actual ECD = 11.08. Monitor well. 03:30 - 04:30 i.00 DRILL P PRODi POH from 8,826' to 7,595' no hole problems. 04:30 - 06:30 2.00 DRILL P PROD1 At a bit depth of 7595' upper ghost reamer positioned @ 3,400' 500' below UGN4 begin back reaming through UGNU to 7 5/8" shoe (~ 2,637', pumping at 290 gpm, 2370 psi, 100 rpm, torque. No excess drag torque or packing off when back reaming. Pumped out an additional 2 stands to achieve bottoms up from once the upper reamer entered into the 7 5!8 shoe at 2637. 06:30 - 09:00 2.50 DRILL P ~ PROD1 POH from 6,663' to 2,632', no problem hole in good shape. Monitor well. 09:00 - 10:30 1.50 DRILL P PROD1 Cut and slip drilling line, change out topdrive blower hose. 10:30 - 11:00 0.50 DRILL P I PRODi Service rig and topdrive. 11:00 - 14:00 3.00 DRILL P PROD1 RIH from 2,632' to 8,715, no problem, make up topdrive and i wash last stand to bottom as a precaution. No adverse hole conditions or fill. 14:00 - 16:00 2.00 DRILL P ! PROD1 Stage pumps up slowly while watching for ECD spikes, from 220 gpm to 290 gpm Q 290 GPM/2555 psi, 100 rpm, torque 9.2k. After getting one good bottoms up, pump 20 bbl hi vis sweep around Q 290 gpm 2550 psi, rotating 100 rpm, torque 9k , no significant increase in cuttings with sweep. Calculated ECD 11.07, Actual ECD 11.29 16:00 - 22:30 6.50 DRILL P PROD1 POH standing back 2 stands, from 8826 to 8635, to confirm ability to pull with no adverse hole conditions. Pump dry job POH laying down 1 x 1. 22:30 - 23:00 0.50 DRILL P PROD1 PJSM, recover sources and lay down BHA. 23:00 - 00:00 1.00 DRILL P PRODi Lay down jars, flex collars 8/21/2005 00:00 - 01:30 1.50 DRILL P PROD1 Lay down BHA. PJSM to remove source from MWD tool. Break and grade bit: 2 6 RO G X I BT TD. 01:30 - 02:00 0.50 DRILL P PROD1 Clear floor of all excess vendors equipment and ready rig for next operation. 02:00 - 03:30 1.50 CASE P RUNPRD Pull wear ring and make dummy run with hanger on landing joint. Mark landing joint and lay out same. 03:30 - 05:00 1.50 CASE P RUNPRD Swap out short bales for long. Rig up 3 1/2 equipment to run 16 joints of IBT L-80 3 1/2. 05:00 - 05:30 0.50 CASE P RUNPRD PJSM with all those to be involved with casing running operations. 05:30 - 07:00 1.50 CASE P RUNPRD RIH with 3 1/2 shoe track and Weatherford, "Latch In By-Pass Receptacle". Fill Pipe and confirm floats are operational. pickup remaining 13 joints of 3.5" 9.2# L-80 IBT-M casing, one pup joint with RA tag and 2 "X" nipple assemblys. Makeup torque 2,300 ft/Ibs, using Best-O-Life 2000 pipe dope. 07:00 - 08:00 1.00 CASE P RUNPRD Rig down 3.5" handling tools, rig up 200 ton elevators and makeup Franks tool. 08:00 - 13:00 5.00 CASE P RUNPRD Make up 5.5" seal bore receptacale and run 5.5" 17# L-80 TC-II Printed: 8/26/2005 11:38:53 AM • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: L-114 Common Well Name: L-114 Spud Date: 8/4/2001 Event Name: REENTER+COMPLETE Start: 8/4/2005 End: 8/16/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/23/2005 Rig Name: NABOBS 9ES Rig Number: Date ,From - To I Hours Task .!.Code ~ NPT I Phase 8/21/2005 08:00 - 13:00 5.00 CASE f ~ P ~ ~ RUNPRD 13:00 - 13:30 0.50 CASE P RUNPRD 13:30 - 00:00 10.50 CASE P RUNPRD 8/22!2005 100:00 - 01:30 I 1.501 CASE I P I I RUNPRD 01:30 - 02:00 0.50 CASE P RUNPRD 02:00 -04:00 2.00 CEMT P RUNPRD 04:00 - 06:30 2.50 ~ CEMT ~ P I RUNPRD 06:30 - 08:00 I 1.501 CEMT I P I I RUNPRD 08:00 - 09:00 1.00 WHSUR P RUNPRD 09:00 - 09:30 0.50 EVAL P SURE 09:30 - 10:30 1.00 10:30 - 21:00 10.50 RUNCMP RUNCMP Description of Operations production casing to 2,603', using jet-tube pipe dope, torque turn all connections to 4,350 fUlbs, fiNing pipe every 5 joints. Circulate 1.5X casing volume with Franks tool, stage pumps up to 5 bpm, 535 psi. no losses. Up wt = 71 k, do wt = 68k. Continue running 3.5" X 5.5" production string per running detail from 2,603' to 7,767', filling every 5 joints, makeup torque 4,350 fUlbs, hole taking proper displacement, no hole problems. Continue running 5.5" X 3.5" production casing per running detail. Makeup casing hanger and landing joint, Land casing. Up wt = 210k, do wt 90k. Ran a Total of 16 joints 3.5" 9.2# L-80 IBT-M tubing, 200 joints 5.5" 17# L-80 TC-II casing, Seal bore recepticale, 2 X Nipple assemblies, 1 20' 3.5" pup joint with RA tag. 16 3.5" X 6.5" centralizers. 101 5.5" X 6.375" centralizers. Rig down Franks tool and rig up cement head. Break circulation @ 1 bpm, 440 psi, reciprocating pipe 20', up wt = 200k, do wt = 90k, increased rate to 2 bpm, 550 psi, losing 60 bph while pumping 2 bpm. maintain 2 bpm, 550 psi for first bottoms up, increased pump rate to 3 bpm, 630 psi for second bottoms up returns slowly increasing during second bottoms up. lost a total of 109 bbls while circulating. Held PJSM with cementers and all rig personnel while circulating. Pump 5 bbls water and test lines to 3,500 psi. Pump 15 bbls Mud-Push weighted to 10.7 ppg C~ 4 bpm, 800 psi, pump 72 bbls (231sx) 13.5 ppg class G cement @ 4 bpm, final pressure 410 psi, pump 33 bbls (157 sx) 15.8 ppg class G cement @ 4 bpm, final pressure 140 psi. Shut down pumps, close annular to prevent cement from falling away. Wash up with 5 bbls water thru tee. break cap on cement head and load plugs. Switch over to rig pumps, open HCR choke valve, no pressure, open annular. Displace cement with rig pumps @ 4 bpm caught up with cement after 18 bbls pumped, 250 psi, reciprocate pipe 20' strokes. slowed rate to 2 bpm, 1290 psi 172 bbls into displace ment, landed casing @ 175 bbls into displacement. 100 psi pressure increase when wiper plugs entered 3.5" final rate 2 bpm, 1700 psi, bump plug at calculated strokes, pressured up to 2300 psi, bled pressure to zero, check floats. Well flowed back 2 bbls. CIP @ 06:00 hrs. Blow down surface line, rig down cement head, flush stack, back out and lay down landing joint. Install and test packoff to 5,000 psi for 15 min ok. Rig up and perform LOT and infectivity test on 7 5/8" X 5.5" annulus, pressure achieved 450 psi, mud wt 10.0 13.4 ppg EMW, inject 5 bbls mud to confirm no cement in annulus. Rig up completion running equipment Make up Baker seal assembly, X nipple assembly and run 3.5" 9.2# L-80 BT-M completion per running detail to 8,221', makeup torque 24,00 fUlbs, dope with BOL-2000. Freeze protect 7 5/8" X 5.5" annulus with 35 bbls dead crude at 2 bpm, 900 psi. 21:00 - 21:30 0.50 BUNCO RUNCMP Make up circulating head, rig up and test 5.5" X 3.5" production casing to 3,500 psi for 30 min record on chart. Printed: 8/26/2005 11:38:53 AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ', Name: L ell Name: L e: Name: From - To ' -114 -114 REENTE NABOB NABOB Hours R+COM S ALASK S 9ES Task PLET A DRI ~ Code ~ E LLING NPT , Start I Rig Rig Phase Spud Date: 8/4/2001 : 8/4/2005 End: 8/16/2005 Release: 8/23/2005 Number: j Description of Operations 8/22/2005 21:30 - 23:00 1.50 BUNCO RUNCMP Wash down ~ 1 bpm, 120 psi to locate top of seal bore receptacle, 300 psi pressure increase as seals entered seal bore, shut down pumps slack off slowly, set down on no-go, POH lay down 3 joints of tubing, Make up 9.78' space out pup , joint # 264, make up tubing hanger and landing joint with circulating head. 23:00 - 00:00 1.00 BUNCO RUNCMP Reverse in 93 bbls clean seawater @ 4.5 bpm, 2,600 psi, followed by 72 bbls clean seawater treated with corrosion inhibitor. 8/23/2005 00:00 - 01:00 1.00 BUNCO RUNCMP Change out tubing hanger seal, land tubing in well head Up wt = 108k do wt = 72k. 01:00 - 01:30 0.50 BUNCO ; RUNCMP RILDS. 01:30 - 03:30 2.00 BUNCO ' RUNCMP Rig up to pump down tubing, pressure up on tubing to 4,000 psi, bled off 400 psi in 10 min. (suspect air trapped in line) rig down circulating head, back out and lay down landing joint. Close blind rams, Pressure up on tubing to 4,000 psi for 30 min, record on chart, bleed tubing pressure to 2500 psi. Pressure up on back side to 4,000 psi hold for 30 min record on chart. bled annulus pressure to zero, bled tubing pressure to zero. Pressure up on annulus to shear DCK shear valve in lower GLM @ 8,160' sheared at 3,600 psi. pumped both ways thru DCK shear valve 3 bpm 2,000 psi 03:30 - 04:30 1.00 ZONISO P OTHCMP Blow down circulating lines, drain stack, install TWC, test from below to 1,000 psi. ok 04:30 - 07:00 2.50 BOPSU P WHDTRE Nipple down BOP and driling nipple. 07:00 - 09:00 2.00 WHSUR P WHDTRE Nipple up adapter flange and tree. 09:00 - 11:30 2.50 WHSUR P WHDTRE Test tree and adapter flange to 5,000 psi, Rig up and pull TWC with lubricator. 11:30 - 13:00 1.50 WHSUR P WHDTRE PJSM with Little Red, Rig up circulating lines and test to 2500 psi. Reverse 93 bbls diesel down 7 5/8" X 5.5" annulus to freeze protect tubing and annulus to 4, 638' pumping at 2 bpm 2,150 psi. 13:00 - 14:00 1.00 WHSUR P WHDTRE Allow diesel to U-tube, Inatall BPV with lubricator, and test from below to 1,000 psi, ok. 14:00 - 15:00 1.00 WHSUR P WHDTRE Clean cellar area, secure well. Prepare for Move to L-218. Release Rig @ 15:00 hrs from L-114i, 8/23/2005 Printed: 8/26/2005 11.38:53 AM • Well: L-114A Accept: 08/09/05 Field: Prudhoe Bay Unit Spud: 08115/05 API: 50-029-23032-01-00 Release: 08/23/05 Permit: 205-112 Ria: Nabors 9ES POST RIG WORK 09/02/05 SET 2.81" X-LOCK CATCHER SUB AT 8296' SLM. PULLED 1" SV FROM STA #1 AT 8152' SLM. PULLED 1" DGLV FROM STA#3 AT 6290' SLM &STA#5 AT 3654' SLM. SET 1" DOME GLV IN STA#5 AT 3654' SLM. SET 1" S/0 GLV IN STA #3 AT 6290' SLM. SET DGLV IN STA#1 AT 8152' SLM. (ALL INTG LATCHES) PULLED C- SUB AT 8269' SLM. 09/10/05 RUN JEWELRY LOG (GR-CCL-TEMP-PRESS) FROM 8725' - 8000'. PERFORATED WITH 2.5" HSD GUN, 6 SPF, FROM 8528' - 8548'. 09/16/05 RAN 2.50" CENT AND DUAL PETRADAT GAUGES. MADE 20 MIN STOPS AT 8620' MD AND 8518' MD. RDMO. LEFT WELL SHUT IN, TURNED WELL OVER TO PAD OPER. 0. L-114A Survey Report schlumhe er Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / L-114 Well: L-114 Borehole: L-114A UWVAPI1f: 500292303201 Survey Name /Date: L-114A /August 20, 2005 Tort /AHD / DDI I ERD ratio: 182.464° / 4449.78 ft / 6.018 ! 0.647 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 70 21 0.180, W 14919 31.991 Location Grid WE Y/X: N 5978066.520 ttUS, E 583072.240 ftUS Grid Convergence Angle: +0.63517370° Survey /DLS Computation Method: Minimum Curvature / Li Vertical Section Azimuth: 290.780° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 76.30 ft relative to MSL Sea Bed /Ground Level Elevation: 47.80 ft relative to MSL Magnetic Declination: 24.355° Total Field Strength: 57620.918 nT Magnetic Dip: 80.813° Declination Date: August 1 t, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.355° • Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea TVD 7yp Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft h ft de 100 h ftUS RUS H I t U.UO 0.00 VAU -/6.30 OAU U.UU O.VV V.UO V.00 U.OU V.00 59/SU66.52 583072.24 N /U Z1 U.180 W 149 19 31.991 First MWD+IFR+MS 101.61 0.54 338.39 25.31 101.61 0.32 0.48 0.48 0.45 -0.18 0.53 5978066.96 583072.06 N 70 21 0.185 W 149 19 31.996 187.00 0.72 338.39 110.69 186.99 0.96 1.42 1.42 1.32 -0.52 0.21 5978067.83 583071.70 N 70 21 0.193 W 149 19 32.006 288.50 0.49 342.89 212.19 288.49 1.65 2.49 2.49 2.33 -0.88 0.23 5978068.84 583071.33 N 70 21 0.203 W 149 19 32.017 379.85 0.53 336.22 303.53 379.83 2.19 3.30 3.30 3.09 -1.17 0.08 5978069.59 583071.04 N 70 21 0.211 W 149 19 32.025 473.31 0.70 1.02 396.99 473.29 2.68 4.29 4.27 4.05 -1.33 0.33 5978070.56 583070.86 N 70 21 0.220 W 149 19 32.030 566.23 0.82 15.09 489.90 566.20 2.94 5.52 5.39 5.26 -1.15 0.24 5978071.77 583071.03 N 70 21 0.232 W 149 19 32.024 658.74 1.00 25.58 582.40 658.70 2.94 6.98 6.66 6.63 -0.63 0.26 5978073.14 583071.54 N 70 21 0.245 W 149 19 32.009 750.79 1.70 350.72 674.42 750.72 3.56 9.09 8.72 8.70 -0.50 1.14 5978075.21 583071.64 N 70 21 0.266 W 149 19 32.005 842.32 2.43 342.76 765.89 842.19 5.43 12.38 11.96 11.89 -1.30 0.86 5978078.40 583070.81 N 70 21 0.297 W 149 19 32.029 936.56 3.67 338.27 860.00 936.30 8.70 17.39 16.87 16.60 -3.01 1.34 5978083.09 583069.05 N 70 21 0.343 W 149 19 79 1030.18 5.23 338.98 953.33 1029.63 13.57 24.65 24.04 23.37 -5.65 1.67 5978089.82 583066.34 N 70 21 0.410 W 149 196 1123.45 6.46 341.49 1046.12 1122.42 19.73 34.15 33.50 32.31 -8.84 1.35 5978098.73 583063.05 N 70 21 0.498 W 149 19 49 1217.69 7.36 336.55 i 139.67 1215.97 27.29 45.48 44.78 42.88 -12.92 1.14 5978109.25 583058.84 N 70 21 0.602 W 149 19 32.368 1311.30 6.86 334.54 1232.56 1308.86 35.51 57.07 56.29 53.43 ' -17.71 0.60 5978119.74 583053.94 N 70 21 0.706 W 149 19 32.508 1404.38 6.96 315.31 1324.98 1401.28 44.66 68.16 66.93 62.46 -24.07 2.48 5978128.70 583047.48 N 70 21 0.794 W 149 19 32.694 1497.27 8.16 300.44 1417.07 1493.37 56.28 80.32 77.51 69.80 -33.71 2.46 5978135.94 583037.76 N 70 21 0.867 W 149 19 32.976 1591.02 10.18 294.57 1509.62 1585.92 71.11 95.24 89.88 76.62 -46.98 2.37 5978142.60 583024.41 N 70 21 0.934 W 149 19 33.364 1684.85 9.40 292.09 1602.08 1678.38 87.04 111.20 103.33 82.95 -61.62 0.94 5978148.77 583009.71 N 70 21 0.996 W 149 19 33.792 1778.61 10.40 288.00 1694.45 1770.75 103.15 127.31 117.11 88.44 -76.77 1.30 5978154.10 582994.50 N 70 21 1.050 W 149 19 34.234 1871.21 11.96 284.86 1785.29 1861.59 121.04 145.26 132.57 93.48 -93.99 1.81 5978158.95 582977.23 N 70 21 1.100 W 149 19 34.738 1963.32 14.78 281.99 1874.89 1951.19 142. i 5 166.55 151.12 98.37 -114.71 3. i 4 5978163.61 582956.45 N 70 21 1.148 W 149 19 35.343 2057.75 15.57 284.13 1966.03 2042.33 166.65 191.27 173.41 103.97 -138.79 1.03 5978168.94 582932.32 N 70 21 1.203 W 149 19 36.047 2150.89 16.75 284.36 2055.49 2131.79 192.40 217.19 197.60 110.35 -163.91 1.27 5978175.04 582907.13 N 70 21 1.265 W 14919 36.781 2245.70 16.54 284.71 2146.32 2222.62 219.40 244.35 223.39 117.17 -190.20 0.25 5978181.56 582880.77 N 70 21 1.332 W 149 19 37.549 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-114\L-114\L-114A\L-114A Generated 9/20/2005 3:20 PM Page 1 of 3 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ft de 100 ft ftUS ftUS 2338.78 16.67 284.83 2235.52 2311.82 245.85 270.95 248.97 123.95 -215.92 0.14 5978188 .05 582854.98 N 70 21 1.399 W 149 19 38.301 2431.83 16.43 285.10 2324.72 2401.02 272.22 297.45 274.67 130.79 -241.53 0.27 5978194 .61 582829.30 N 70 21 1.466 W 149 19 39.049 2524.54 16.26 285.02 2413.68 2489.98 298.18 323.54 300.11 137.57 -266.72 0.18 5978201 .11 582804.03 N 70 21 1.533 W 149 19 39.786 Tie-In Survey 2596.17 16.04 284.37 2482.48 2558.78 317.99 343.47 319.58 142.63 -285.99 0.40 5978205 .95 582784.71 N 70 21 1.583 W 149 19 40.349 Blind (Inc + Trent) 2670.98 16.67 274.09 2554.28 2630.58 338.54 364.48 339.67 145.96 -306.71 3.95 5978209 .05 582763.96 N 70 21 1.616 W 149 19 40.954 Blind (Inc + Trent) 2764.52 23.27 275.16 2642.15 2718.45 369.22 396.41 369.70 148.58 -338.53 7.07 5978211 .32 582732.11 N 70 21 1.641 W 149 19 41.884 First MWD+IFR+MS 2857.66 28.05 259.00 2726.18 2802.48 405.62 436.51 405.63 146.05 -378.43 9.06 5978208 .35 582692.25 N 70 21 1.616 W 149 19 43.050 2951.53 32.56 264.62 2807.22 2883.52 447.09 483.84 447.56 139.46 -425.27 5.67 5978201 .25 582645.49 N 70 21 1.552 W 149 19 44.419 3045.38 34.99 271.30 2885.25 2961.55 495.15 535.97 496.81 137.71 -477.34 4.73 5978198 .91 582593.45 N 70 21 1.534 W 149 19 45.941 3139.44 38.68 275.18 2960.53 3036.83 548.91 592.34 551.91 140.97 -533.60 4.64 5978201 .56 582537.16 N 70 21 1.566 W 149 19 47.585 3232.89 42.58 276.35 3031.44 3107.74 607.67 653.18 612.07 147.11 -594.13 4.25 5978207 .02 582476.57 N 70 21 1.627 W 149 19 3327.27 46.58 279.24 3098.66 3174.96 672.21 719.40 677.96 156.15 -659.73 4.75 5978215 .33 582410.88 N 70 21 1.716 W 149 19 5 3419.81 49.57 281.43 3160.49 3236.79 739.91 788.24 746.71 168.53 -727.44 3.68 5978226 .96 582343.04 N 70 21 1.837 W 149 19 53.250 3512.42 49.80 281.17 3220.41 3296.71 809.56 858.86 817.30 182.37 -796.69 0.33 5978240 .03 582273.65 N 70 21 1.973 W 149 19 55.274 3606.08 50.95 279.55 3280.14 3356.44 880.51 930.99 889.36 195.33 -867.65 1.81 5978252 .20 582202.56 N 70 21 2.101 W 149 19 57.348 3700.47 53.42 275.11 3338.02 3414.32 952.98 1005.54 963.59 204.79 -941.58 4.54 5978260 .84 582128.54 N 70 21 2.194 W 149 19 59.508 3793.71 53.29 276.29 3393.68 3469.98 1025.21 1080.35 1037.94 212.22 -1016.01 1.02 5978267 .44 582054.03 N 70 21 2.267 W 149 20 1.684 3886.61 56.23 275.10 3447.28 3523.58 1098.46 1156.22 1113.40 219.73 -1091.51 3.33 5978274 .12 581978.47 N 70 21 2.340 W 149 20 3.890 3980.64 55.98 275.87 3499.71 3576.01 1173.75 1234.27 1191.07 227.19 -1169.20 0.73 5978280 .72 581900.70 N 70 21 2.414 W 149 20 6.161 4073.77 57.48 273.71 3550.81 3627.11 1248.59 1312.13 1268.49 233.68 -1246.78 2.52 5978286 .35 581823.06 N 70 21 2.477 W 149 20 8.428 4167.09 57.76 275.33 3600.78 3677.08 i 324.24 1390.94 1346.88 239.89 -1325.34 1.50 5978291 .69 581744.44 N 70 21 2.538 W 149 20 10.724 4266.33 57.16 275.81 3654.16 3730.46 1404.97 1474.60 1430.28 248.01 -1408.61 0.73 5978298 .88 581661.10 N 70 21 2.618 W 149 20 13.158 4360.47 58.87 273.59 3704.03 3780.33 1481.68 1554.44 1509.79 254.54 -1488.18 2.70 5978304 .52 581581.47 N 70 21 2.682 W 149 20 15.483 4453.99 58.48 276.23 3752,66 3828.96 1558.51 1634.32 1589.40 261.37 -1567.76 2.45 5978310 .47 581501.82 N 70 21 2.749 W 149 20 17.809 4547.45 58.19 276.26 3801.72 3878.02 1635.51 1713.87 1668.83 270.03 -1646.84 0.31 5978318 .25 581422.66 N 70 21 2.834 W 149 20 20.120 4640.17 57.97 277.81 3850.75 3927.05 1711.95 1792.57 1747.47 279.66 -1724.94 1.44 5978327 .02 581344.47 N 70 21 2.929 W 149 20 22.403 4733.61 57.23 276.12 3900.82 3977.12 1788.56 1871.46 1826.30 289.23 -1803.25 1.72 5978335 .72 581266.07 N 70 21 3.023 W 149 20 24.691 4826.10 58.91 271.48 3949.75 4026.05 1863.59 1949.94 1904.43 294.41 -1881.54 4:63 5978340 .02 581187.73 N 70 21 3.073 W 149 20 26.979 4917.57 59.07 273.01 3996.88 4073.18 1937.92 2028.34 1982.32 297.48 -1959.87 1.44 5978342 .23 581109.38 N 70 21 3.103 W 149 2~9 5011.51 58.74 274.01 4045.39 4121.69 2014.73 2108.78 2062.45 302.40 -2040.16 0.98 5978346 .26 581029.05 N 70 21 3.152 W 149 2 5 5111.04 58.18 275.97 4097.46 4173.76 2096.35 2193.60 2147.12 309.77 -2124.66 1.77 5978352 .69 580944.48 N 70 21 3.224 W 149 20 34.085 5204.79 59.11 274.15 4146.25 4222.55 2173.41 2273.66 2227.05 316.83 -2204.40 1.93 5978358 .86 580864.67 N 70 21 3.293 W 149 20 36.415 5298.13 58.96 274.94 4194.27 4270.57 2250.25 2353.69 2306.93 323.17 -2284.18 0.74 5978364 .32 580784.83 N 70 21 3.355 W 149 20 38.747 5391.15 58.34 275.18 4242.67 4318.97 2326.72 2433.13 2386.27 330.18 -2363.31 0.70 5978370 .45 580705.63 N 70 21 3.424 W 149 20 41.060 5484.06 57.65 270.60 4291.93 4368.23 2401.67 2511.91 2464.73 334.16 -2441.97 4.25 5978373 .56 580626.95 N 70 21 3.463 W 149 20 43.358 5577.33 57.07 270.70 4342.23 4418.53 2475.41 2590.45 2542.67 335.05 •2520.50 0.63 5978373 .58 580548.41 N 70 21 3.471 W 149 20 45.654 5671.24 57.60 271.82 4392.92 4469.22 2549.92 2669.51 2621.27 336.79 -2599.54 1.15 5978374 .44 580469.37 N 70 21 3.488 W 149 20 47.964 5765.60 58.34 275.57 4442.98 4519.28 2626.37 2749.49 2701.08 341.95 -2679.35 3.46 5978378 .72 580389.52 N 70 21 3.539 W 149 20 50.296 5858.94 57.71 275.12 4492.40 4568.70 2702.69 2828.67 2780.21 349.33 -2758.18 0.79 5978385 .22 580310.62 N 70 21 3.611 W 149 20 52.600 5952.58 56.54 274.40 4543.23 4619.53 2778.28 2907.31 2858.78 355.86 -2836.55 1.41 5978390 .88 580232.19 N 70 21 3.675 W 149 20 54.890 6045.72 58.43 274.80 4593.30 4669.60 2853.71 2985.85 2937.25 362.16 -2914.83 2.06 5978396.32 580153.85 N 70 21 3.736 W 149 20 57.178 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-114\L-114\L-114A\L-114A Generated 9/20/2005 3:20 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS Ei138.8L 5(i.b1 L/b.U4 4fi4:i.3Ei 4(ly.fiEi "Ly~y."Ll 3Uti4.S4 3Ulb.fitt ;ifiti.tiy -"Lyy3.U3 "L.U/ 5y/t54U'G.liS 5auu(5.oa N !U "Ll J.tSU'L W 14y "LU 5y.4(i4 6232.48 58.48 275.00 4693.68 4769.98 3005.22 3143.32 3094.62 375.80 -3071.71 2.10 5978408.22 579996.84 N 70 21 3.870 W 149 21 1.764 6325.70 58.21 275.62 4742.61 4818.91 3081.70 3222.67 3173.93 383.15 -3150.72 0.64 5978414.68 579917.76 N 70 21 3.942 W 149 21 4.073 6418.39 57.46 275.56 4791.95 4868.25 3157.42 3301.14 3252.38 390.79 -3228.81 0.81 5978421.46 579839.60 N 70 21 4.017 W 149 21 6.355 6512.66 56.69 276.28 4843.19 4919.49 3233.90 3380.26 3331.49 398.95 -3307.52 1.04 5978428.74 579760.81 N 70 21 4.097 W 149 21 8.655 6606.21 55.66 271.58 4895.29 4971.59 3308.25 3457.97 3409.07 404.29 -3385.01 4.32 5978433.23 579683.27 N 70 21 4.149 W 149 21 10.920 6699.34 54.91 271.61 4948.32 5024.62 3380.55 3534.52 3485.31 406.42 -3461.54 0.81 5978434.51 579606.74 N 70 21 4.169 W 149 21 13.157 6792.61 53.92 272.84 5002.60 5078.90 3452.46 3610.37 3560.94 409.36 -3537.33 1.51 5978436.61 579530.92 N 70 21 4.198 W 149 21 15.372 6885.73 50.83 273.31 5059.44 5135.74 3522.71 3684.11 3634.54 413.31 -3610.97 3.34 5978439.74 579457.25 N 70 21 4.236 W 149 21 17.524 6978.79 46.98 275.75 5120.60 5196.90 3590.00 3754.23 3704.61 418.80 -3680.86 4.58 5978444.46 579387.31 N 70 21 4.290 W 149 21 19.567 7073.03 42.85 277.13 5187.33 5263.63 3654.44 3820.75 3771.13 426.24 -3746.96 4.50 5978451.16 579321.13 N 70 21 4.363 W 149 21 2 7165.80 41.52 277.37 5256.07 5332.37 3715.01 3883.05 3833.42 434.10 -3808.76 1.44 5978458.33 579259.26 N 70 21 4.440 W 149 21 7259.36 37.80 279.22 5328.08 5404.38 3773.29 3942.74 3893.09 442.67 -3867.84 4.17 5978466.25 579200.09 N 70 21 4.524 W 149 21 2'J~ 7353.27 32.47 280.92 5404.86 5481.16 3826.36 3996.77 3947.01 452.07 -3921.04 5.77 5978475.05 579146.80 N 70 21 4.616 W 149 21 26.587 7446.30 27.68 280.35 5485.34 5561.64 3872.24 4043.37 3993.50 460.68 -3966.84 5.16 5978483.16 579100.91 N 70 21 4.701 W 149 21 27.926 7538.89 25.42 280.02 5568.16 5644.46 3912.92 4084.76 4034.81 468.01 -4007.57 2.45 5978490.03 579060.10 N 70 21 4.772 W 149 21 29.116 7631.85 22.30 281.24 5653.16 5729.46 3949.92 4122.35 4072.31 474.92 -4044.53 3.40 5978496.53 579023.08 N 70 21 4.840 W 149 21 30.196 7724.62 19.54 283.38 5739.81 5816.11 3982.67 4155.47 4105.28 481.94 -4076.89 3.09 5978503.19 578990.64 N 70 21 4.909 W 149 21 31.142 7818.95 20.79 287.01 5828.36 5904.66 4015.02 4187.98 4137.42 490.49 -4108.25 1.87 5978511.39 578959.19 N 70 21 4.993 W 149 21 32.059 7912.35 19.73 290.86 5915.99 5992.29 4047.33 4220.31 4169.04 500.95 -4138.83 1.82 5978521.52 578928.50 N 70 21 5.096 W 149 21 32.953 8005.05 18.77 292.88 6003.50 6079.80 4077.88 4250.87 4198.57 512.32 -4167.20 1.26 5978532.57 578900.01 N 70 21 5.207 W 149 21 33.782 8098.53 15.74 294.65 6092.77 6169.07 4105.57 4278.59 4225.13 523.46 -4192.58 3.29 5978543.43 578874.51 N 70 21 5.317 W 149 21 34.524 8191.26 14.24 293.94 6182.34 6258.64 4129.50 4302.58 4248.05 533.33 -4214.44 1.63 5978553.06 578852.54 N 70 21 5.414 W 149 21 35.163 8285.55 13.16 296.94 6273.94 6350.24 4151.76 4324.90 4269.27 542.90 -4234.61 1.37 5978562.40 578832.27 N 70 21 5.508 W 149 21 35.753 8379.09 13.68 290.97 6364.93 6441.23 4173.41 4346.59 4290.05 551.69 -4254.43 1.58 5978570.96 578812.36 N 70 21 5.594 W 149 2f 36.332 8470.83 13.05 290.98 6454.19 6530.49 4194.61 4367.80 4310.67 559.28 -4274.23 0.69 5978578.33 578792.47 N 70 21 5.669 W 149 21 36.911 8564.58 14.45 290.91 6545.25 6621.55 4216.89 4390.08 4332.34 567.24 -4295.04 1.49 5978586.07 578771.58 N 70 21 5.747 W 149 21 37.519 8658.13 13.76 288.65 6635.98 6712.28 4239.68 4412.88 4354.61 574.97 -4316.49 0.94 5978593.55 578750.05 N 70 21 5.823 W 149 21 38.146 8750.47 12.48 288.98 6725.91 6802.21 4260.63 4433.84 4375.17 581.72 -4336.33 1.39 5978600.09 578730.14 N 70 21 5.889 W 149 21 38.726 Last MWD+IFR+MS 8768.88 12.14 286.76 6743.90 6820.20 4264.55 4437.76 4379.03 582.93 -4340.06 3.17 5978601.25 578726.39 N 70 21 5.901 W 149 2 ~5 TD (Projected) 8826.00 12.14 286.76 6799.74 6876.04 4276.53 4449.78 4390.90 586.39 -4351.56 0.00 5978604.59 578714.85 N 70 21 5.935 W 149 21 39.172 Survey Type: Definitive Survey NOTES: MWD +IFR + MS - (In-field referenced MWD w ith mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2346 FSL 3845 FEL S34 T12N Ri 1 E UM 5978066.52 583072.24 BHL : 2931 FSL 2915 FEL S33 T12N R11 E UM 5978604.59 578714.85 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-114\L-114\L-114A\L-114A Generated 9/20/2005 3:20 PM Page 3 of 3 TREE = 3-118" CM/ • L-114A S NOTES: WELLhSEAD= FMC ACTUATOR = WA KB. ELEV = 76.3' BF. ELEV....- _ 49.4' KOP = 200 Max Angle = 59 @ 5205' Datum MD = xxxxx' -Datum TV D = xxxx' SS 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~~ 2637' Minimum ID = 2.813" @ 1793' 3-112" HES X N{PPLE I3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" ~ 8237' 5-1/2" CSG, 15.5#, L-80, ID = 4.95" $240' 1793' ~-{ 3-1 /2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 7 2025 2011 15 KBG-2-9 DMY INTG 08/22/05 6 2648 2609 16 KBG-2-9 DMY INTG 08/22/05 5 3667 3394 52 KBG-2-9 DMY INTG 08/22/05 4 4663 3940 58 KBG-2-9 DMY INTG 08/22/05 3 6296 4803 58 KBG-2-9 DMY INTG 08/22/05 2 7386 5509 31 KBG-2-9 DMY INTG 08/22/05 1 8160 6229 15 KBG-2-9 DCK-3 INTG 08/22/05 8186' -13-1/2" HES X NIP, ID = 2.813" BAKER 5-1/2" CSG RECPT, ID = 4.0" 8241' 8257' BAKER3-1/2"SEALASSY TOP OF 5-112" CUT-OFF 2720' \ 5-1/2" HES EZSV 2770' 3-1/2" CSG, 9.2#, L-80 8253' REF LOG: ANGLE AT TOP PERF: xx° @xxxx' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE # DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 10/30/04 LV ORIGINAL COMPLETION WELL: L-114A 08/22/05 TA / BB SIDETRACK COMPLETION PERMIT No: 205-112 API No: 50-029-23032-01-00 SEC 34, T12N, R11 E, 2346' NSL & 3845' WEL BP Exploration (Alaska) 8311' ~ 3-1/2" HES X NIP, ID = 2.813" 8363' 3-1/2" HES X NIP, ID = 2.813" 8525' PUPJT W/ RA TAG PBTD 8725' ~ 3-1/2" CSG, 9.2#, L-80 IBT-M, .0087 bpf, ID =2.992" 8822' r SCHLUMBERGER Survey report 20-Aug-2005 06:30:49 Page 1 of 5 Client .................... BP Exploration (Alaska) Inc. Field ..................... Borealis Well ...................... L-114A Spud date................. 04-Aug-2005 API number ...............: 50-029-23032-01 Last survey date.........: 20-Aug-05 Engineer .................: St. Amour Total accepted surveys...: 97 MD of first survey.......: 0.00 ft Rig :...................... Nabors 9ES MD of last survey......... 8826.00 ft STATE :.................... Alaska ----- Survey calculation methods------------- ----- Geomagnetic data ---- ------------------ Method for positions.....: Minimum curvature Magnetic model...........: BGGM version 2004 Method for DLS............ Mason & Taylor Magnetic date ............. 11-Aug-2005 Magnetic field strength..: 1152.45 HCNT ----- Depth reference ---- ------------------- Magnetic dec (+E/W-).....: 24.36 degrees Permanent datum..........: Mean Sea Level Magnetic dip .............: 80.81 degrees Depth reference..........: Driller's Pipe Tally GL above permanent.......: 47.80 ft ----- MWD survey Reference Criteria --------- KB above permanent.......: N/A (Topdrive) Reference G ..............: 1002.68 meal DF above permanent.......: 76.30 ft Reference H ..............: 1152.45 HCNT Reference Dip ............. 80.81 degrees ----- Vertical section origin---------------- Tolerance of G...........: (+/-) 2.50 meal Latitude (+N/S-).........: 0.00 ft Tolerance of H...........: (+/-) 6.00 HCNT Departure (+E/W-)........: 0.00 ft Tolerance of Dip.........: (+/-) 0.45 degrees ----- Platform reference point--------------- ----- Corrections --------------------------- Latitude (+N/S-).........: -999.25 ft Magnetic dec (+E/W-).....: 24.36 degrees ', Departure (+E/W-)........: -999.25 ft Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)..... 24.36 degrees Azimuth from Vsect Origin to target: 290.78 degrees (Total az corr = magnetic dec - grid cony) ~~ Survey Correction Type ...: I=Sag Corrected Inclination ~,";~. M=Schlumberger Magnetic Correction 5 ~ S=Shell Magnetic Correction F=Failed Axis Correction -._, '~- R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report 20-Aug-2005 06:30:49 Page 2 of 5 Seq Measured Incl` Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 101.61 0.54 338.39 101.61 101.61 0.32 0.45 -0.18 0.48 338.39 0.53 BP_ MWD+IFR+MS 3 187.00 0.72 338.39 85.39 186.99 0.96 1.32 -0.52 1.42 338.39 0.21 BP_ MWD+IFR+MS 4 288.50 0.49 342.89 101.50 288.49 1.65 2.33 -0.88 2.49 339.17 0.23 BP_ MWD+IFR+MS 5 379.85 0.53 336.22 91.35 379.83 2.19 3.09 -1.17 3.30 339.24 0.08 BP_ MWD+IFR+MS 6 473.31 0.70 1.02. 93.46 473.29 2.68 4.05 -1.33 4.27 341.78 0.33 BP_ MWD+IFR+MS 7 566.23 0.82 15.09 92.92 566.20 2.94 5.26 -1.15 5.39 347.66 0.24 BP_ MWD+IFR+MS • 8 658.74 1.00 25.58 92.51 658.70 2.94 6.63 -0.63 6.66 354.57 0.26 BP_ MWD+IFR+MS 9 750.79 1.70 350.72 92.05 750.72 3.56 8.70 -0.50 8.72 356.69 1.14 BP_ MWD+IFR+MS 10 842.32 2.43 342.76 91.53 842.19 5.43 11.89 -1.30 11.96 353.77 0.86 BP_MWD+IFR+MS 11 936.56 3.67 338.27 94.24 936.30 8.70 16.60 -3.01 16.87 349.74 1.34 BP_ MWD+IFR+MS 12 1030.18 5.23 338.98 93.62 1029.63 13.57 23.37 -5.65 24.04 346.42 1.67 BP_ MWD+IFR+MS 13 1123.45 6.46 341.49 93.27 1122.42 19.73 32.31 -8.84 33.50 344.71 1.35 BP_ MWD+IFR+MS 14 1217.69 7.36 336.55 94.24 1215.97 27.29 42.88 -12.92 44.78 343.23 1.14 BP_ MWD+IFR+MS 15 1311.30 6.86 334.54 93.61 1308.86 35.51 53.43 -17.71 56.29 341.66 0.60 BP_ MWD+IFR+MS 16 1404.38 6.96 315.31 93.08 1401.28 44.66 62.46 -24.07 66.93 338.93 2.48 BP_ MWD+IFR+MS 17 1497.27 8.16 300.44 92.89 1493.37 56.28 69.80 -33.71 77.51 334.22 2.46 BP_ MWD+IFR+MS 18 1591.02 10.18 294.57 93.75 1585.92 71.11 76.62 -46.98 89.88 328.48 2.37 BP_ MWD+IFR+MS 19 1684.85 9.40 292.09 93.83 1678.38 87.04 82.95 -61.62 103.33 323.39 0.94 BP_ MWD+IFR+MS 20 1778.61 10.40 288.00 93.76 1770.74 103.15 88.44 -76.77 117.11 319.04 1.30 BP_ MWD+IFR+MS 21 1871.21 11.96 284.86 92.60 1861.59 121.04 93.48 -93.99 132.57 314.84 1.81 BP_ MWD+IFR+MS • 22 1963.32 14.78 281.99 92.11 1951.19 142.15 98.37 -114.71 151.12 310.61 3.14 BP_ MWD+IFR+MS 23 2057.75 15.57 284.13 94.43 2042.33 166.65 103.97 -138.79 173.41 306.84 1.03 BP_ MWD+IFR+MS 24 2150.89 16.75 284.36 93.14 2131.79 192.40 110.35 -163.91 197.60 303.95 1.27 BP_ MWD+IFR+MS 25 2245.70 16.54 284.71 94.81 2222.62 219.40 117.17 -190.20 223.39 301.63 0.25 BP_ MWD+IFR+MS 26 2338.78 16.67 284.83 93.08 2311.82 245.85 123.95 -215.92 248.97 299.86 0.14 BP_ MWD+IFR+MS 27 2431.83 16.43 285.10 93.05 2401.02 272.22 130.79 -241.53 274.67 298.44 0.27 BP_ MWD+IFR+MS 28 2524.54 16.26 285.02 92.71 2489.98 298.18 137.57 -266.72 300.11 297.28 0.18 BP_ MWD+IFR+MS 29 2596.17 16.04 284.37 71.63 2558.78 317.99 142.63 -285.99 319.58 296.51 0.40 BP_ MWD+IFR+MS 30 2670.98 16.67 274.09 74.81 2630.58 338.54 145.96 -306.71 339.67 295.45 3.95 BP_ INC+TREND SCHLUMBERGER Survey Report 20 -Aug-2005 06:30:49 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2764.52 23.27 275.16 93.54 2718.45 369.22 148.58 -338.53 369.70 293.70 7.07 BP _INC+TREND 32 2857.66 28.05 259.00 93.14 2802.48 405.62 146.05 -378.42 405.63 291.10 9.06 BP _MWD+IFR+MS 33 2951.53 32.56 264.62 93.87 2883.52 447.09 139.46 -425.27 447.56 288.16 5.67 BP _MWD+IFR+MS 34 3045.38 34.99 271.30 93.85 2961.55 495.15 137.71 -477.34 496.81 286.09 4.73 BP _MWD+IFR+MS 35 3139.44 38.68 275.18 94.06 3036.83 548.91 140.97 -533.60 551.91 284.80 4.64 BP _MWD+IFR+MS 36 3232.89 42.58 276.35 93.45 3107.74 607.67 147.11 -594.13 612.07 283.91 4.25 BP _MWD+IFR+MS 37 3327.27 46.58 279.24 94.38 3174.96 672.21 156.15 -659.73 677.96 283.32 4.75 BP _MWD+IFR+MS • 38 3419.81 49.57 281.43 92.54 3236.79 739.91 168.53 -727.44 746.71 283.04 3.68 BP _MWD+IFR+MS 39 3512.42 49.80 281.17 92.61 3296.70 809.56 182.37 -796.69 817.29 282.89 0.33 BP _MWD+IFR+MS 40 3606.08 50.95 279.55 93.66 3356.44 880.51 195.33 -867.65 889.36 282.69 1.81 BP _MWD+IFR+MS 41 3700.47 53.42 275.11 94.39 3414.32 952.98 204.79 -941.58 963.59 282.27 4.54 BP _MWD+IFR+MS 42 3793.71 53.29 276.29 93.24 3469.98 1025.21 212.22 -1016.01 1037.94 281.80 1.02 BP _MWD+IFR+MS 43 3886.61 56.23 275.10 92.90 3523.58 1098.46 219.73 -1091.51 1113.40 281.38 3.33 BP _MWD+IFR+MS 44 3980.64 55.98 275.87 94.03 3576.01 1173.75 227.19 -1169.20 1191.07 281.00 0.73 BP _MWD+IFR+MS 45 4073.77 57.48 273.71 93.13 3627.11 1248.59 233.68 -1246.78 1268.49 280.62 2.52 BP _MWD+IFR+MS 46 4167.09 57.76 275.33 93.32 3677.08 1324.24 239.89 -1325.34 1346.88 280.26 1.50 BP _MWD+IFR+MS 47 4266.33 57.16 275.81 99.24 3730.46 1404.97 248.01 -1408.61 1430.28 279.99 0.73 BP _MWD+IFR+MS 48 4360.47 58.87 273.59 94.14 3780.33 1481.68 254.54 -1488.18 1509.79 279.71 2.70 BP _MWD+IFR+MS 49 4453.99 58.48 276.23 93.52 3828.96 1558.51 261.37 -1567.76 1589.40 279.47 2.45 BP _MWD+IFR+MS 50 4547.45 58.19 276.26 93.46 3878.02 1635.51 270.03 -1646.84 1668.83 279.31 0.31 BP _MWD+IFR+MS 51 4640.17 57.97 277.81 92.72 3927.05 1711.95 279.66 -1724.94 1747.47 279.21 1.44 BP _MWD+IFR+MS • 52 4733.61 57.23 276.12 93.44 3977.12 1788.56 289.23 -1803.25 1826.30 279.11 1.72 BP _MWD+IFR+MS 53 4826.10 58.91 271.48 92.49 4026.05 1863.59 294.41 -1881.54 1904.43 278.89 4.63 BP _MWD+IFR+MS 54 4917.57 59.07 273.01 91.47 4073.18 1937.92 297.48 -1959.87 1982.32 278.63 1.44 BP _MWD+IFR+MS 55 5011.51 58.74 274.01 93.94 4121.69 2014.73 302.40 -2040.16 2062.45 278.43 0.98 BP _MWD+IFR+MS 56 5111.04 58.18 275.97 99.53 4173.76 2096.35 309.77 -2124.66 2147.12 278.30 1.77 BP _MWD+IFR+MS 57 5204.79 59.11 274.15 93.75 4222.55 2173.41 316.83 -2204.40 2227.05 278.18 1.93 BP _MWD+IFR+MS 58 5298.13 58.96 274.94 93.34 4270.57 2250.25 323.17 -2284.19 2306.93 278.05 0.74 BP _MWD+IFR+MS 59 5391.15 58.34 275.18 93.02 4318.97 2326.72 330.18 -2363.31 2386.27 277.95 0.70 BP _MWD+IFR+MS 60 5484.06 57.65 270.60 92.91 4368.23 2401.67 334.16 -2441.97 2464.73 277.79 4.25 BP _MWD+IFR+MS a SCHLUMBERGER Survey Report 20- Aug-2005 06:30:49 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5577.33 57.07 270.70 93.27 4418.53 2475.41 335.05 -2520.50 2542.68 277.57 0.63 BP _MWD+IFR+MS 62 5671.24 57.60 271.82 93.91 4469.22 2549.93 336.79 -2599.54 2621.27 277.38 1.15 BP _MWD+IFR+MS 63 5765.60 58.34 275.57 94.36 4519.28 2626.37 341.95, -2679.35 2701.08 277.27 3.46 BP _MWD+IFR+MS 64 5858.94 57.71 275.12 93.34 4568.70 2702.69 349.33 -2758.18 2780.21 277.22 0.79 BP _MWD+IFR+MS 65 5952.58 56.54 274.40 93.64 4619.53 2778.28 355.86 -2836.55 2858.78 277.15 1.41 BP _MWD+IFR+MS 66 6045.72 58.43 274.80 93.14 4669.59 2853.71 362.16 -2914.83 2937.25 277.08 2.06 BP _MWD+IFR+MS 67 6138.82 56.51 275.04 93.10 4719.66 2929.21 368.89 -2993.03 3015.68 277.03 2.07 BP _MWD+IFR+MS • 68 6232.48 58.48 275.00 93.66 4769.98 3005.23 375.80 -3071.71 3094.62 276.98 2.10 BP _MWD+IFR+MS 69 6325.70 58.21 275.62 93.22 4818.91 3081.70 383.15 -3150.72 3173.93 276.93 0.64 BP _MWD+IFR+MS 70 6418.39 57.46 275.56 92.69 4868.25 3157.42 390.79 -3228.81 3252.38 276.90 0.81 BP _MWD+IFR+MS 71 6512.66 56.69 276.28 94.27 4919.49 3233.90 398.95 -3307.52 3331.49 276.88 1.04 BP _MWD+IFR+MS 72 6606.21 55.66 271.58 93.55 4971.58 3308.25 404.29 -3385.01 3409.07 276.81 4.32 BP _MWD+IFR+MS 73 6699.34 54.91 271.61 93.13 5024.62 3380.55 406.42 -3461.54 3485.31 276.70 0.81 BP _MWD+IFR+MS 74 6792.61 53.92 272.84 93.27 5078.90 3452.46 409.36 -3537.33 3560.94 276.60 1.51 BP _MWD+IFR+MS 75 6885.73 50.83 273.31 93.12 5135.74 3522.71 413.31 -3610.97 3634.54 276.53 3.34 BP _MWD+IFR+MS 76 6978.79 46.98 275.75 93.06 5196.90 3590.00 418.80 -3680.86 3704.61 276.49 4.58 BP _MWD+IFR+MS 77 7073.03 42.85 277.13 94.24 5263.63 3654.44 426.24 -3746.96 3771.13 276.49 4.50 BP _MWD+IFR+MS 78 7165.80 41.52 277.37 92.77 5332.36 3715.01 434.10 -3808.76 3833.42 276.50- 1.44 BP _MWD+IFR+MS 79 7259.36 37.80 279.22 93.56 5404.38 3773.29 442.67 -3867.84 3893.09 276.53 4.17 BP _MWD+IFR+MS 80 7353.27 32.47 280.92 93.91 5481.16 3826.36 452.07 -3921.04 3947.01 276.58 5.77 BP _MWD+IFR+MS 81 7446.30 27.68 280.35 93.03 5561.64 3872.24 460.68 -3966.84 3993.50 276.62 5.16 BP _MWD+IFR+MS • 82 7538.89 25.42 280.02 92.59 5644.46 3912.92 468.01 -4007.57 4034.81 276.66 2.45 BP _MWD+IFR+MS 83 7631.85 22.30 281.24 92.96 5729.46 3949.92 474.92 -4044.53 4072.31 276.70 3.40 BP _MWD+IFR+MS 84 7724.62 19.54 283.38 92.77 5816.11 3982.67 481.94 -4076.89 4105.28 276.74 3.09 BP _MWD+IFR+MS 85 7818.95 20.79 287.01 94.33 5904.66 4015.02 490.49 -4108.25 4137.42 276.81 1.87 BP _MWD+IFR+MS 86 7912.35 19.73 290.86 93.40 5992.28 4047.33 500.95 -4138.83 4169.04 276.90 1.82 BP _MWD+IFR+MS 87 .8005.05 18.77 292.88 92.70 6079.80 4077.88 512.32 -4167.20 4198.57 277.01 1.26 BP _MWD+IFR+MS 88 8098.53 15.74 294.65 93.48 6169.06 4105.57 523.46 -4192.58 4225.13 277.12 3.29 BP _MWD+IFR+MS 89 8191.26 14.24 293.94 92.73 6258.64 4129.51 533.33 -4214.44 4248.05 277.21 1.63 BP _MWD+IFR+MS 90 8285.55 13.16 296.94 94.29 6350.24 4151.76 542.90 -4234.61 4269.27 277.31 1.37 BP _MWD+IFR+MS SCHLUMBERGER Survey Report 20-Aug-2005 06:30:49 Page 5 of 5 Seq Measured Incl Azimuth Course - TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8379 09 13.68 290.97 93.54 6441.23 4173.41 551.69 -4254.43 4290.05 2.77.39 1.58 BP_MWD+IFR+MS 92 8470.83 13.05 290.98 91.74 6530.49 4194.61 559.28 -4274.23 4310.67 277.45 0.69 BP_MWD+IFR+MS 93 8564.58 14.45 290.91 93.75 6621.55 4216.90 567.24 -4295.04 4332.34 277.52 1.49 BP_MWD+IFR+MS 94 8658.13 13.76 288.65 93.55 6712.28 4239.69 574.97 -4316.49 4354.61 277.59 0.94 BP_MWD+IFR+MS 95 8750.47 12.48 288.98 92.34 6802.21 4260.63 581.72 -4336.33 4375.17 277.64 1.39 BP_MWD+IFR+MS 96 8768.88 12.14 286.76 18.41 6820.19 4264.55 582.93 -4340.06 4379.04 277.65 3.17 BP_MWD+IFR+MS 97 8826.00 12.14 286.76 57.12 6876.04 4276.54 586.39 -4351.56 4390.90 277.67 0.00 • Projected to TD [(c)2005 IDEAL ID10_OC_04] • • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian Well No L-114A Date Dispatched: 1-Sep-05 Installation/Rig Nabors 9ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys ~ 2 1 ~ , ~ Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nrosett~lslb.com Fax:907-561-8317 ~ Ug -I( ~.. ~. ~-i_. ' ~ . ~ ~ ~ ~ ~, ~ ~ , ;~,, ~ ~ ~ '~ ~ FRANK H. MURKOWSK/ COVER u ~ ~# a] ~~'. ~ aa,,., ~..~. ._a NOR ~~ ~~r ~~ ~~+r ~ ~arr~ ~ ~ ~+ t ~-7~ OIL nusL vaa+7 '~ 333 W. 7'" AVENUE, SUITE 100 COI~TSFiR~A~l`IO1Q CO1rIl~iISSIOIQ ~ ANGHORAGE,ALASKA99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-114A BP Exploration (Alaska) Inc. Permit No: 205-112 Surface Location: 2346' FSL, 3845' FEL, SEC. 34, T12N, R1 lE, UM Bottomhole Location: 2931' FSL, 2914' FEL, SEC. 33, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of th Commission to witness any required test. Contact the Commission's petrol field inspector at (907) 659- 3607 (pager). _ ' „ `Chairman DATED this ~da of Jul 2005 y y, cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~~~ ~ ~ ~ ~ j zoos STATE OF ALASKA ° ALAS OIL AND GAS CONSERVATION~UMMISSIO~~~~~~ PERMIT TO DRILL ~u~ ~ ~ 200 ~n Qat^ ~ti nn~ .,_ , 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Developmen~ Oil Multip a one ^ Stratigraphic Test ^ Service ^ DevelopmerfAtl~Ot~Bingle Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU L-114A 1~)3~ns 3. Address: P,O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8803 TVD 6805 12. Field /Pool(s): Prudhoe Bay Field /Borealis Pool 4a. Location of Well (Governmental Section): Surface: 2346' FSL 3845' FEL SEC T12N 34 R11E UM 7. Property Designation: ADL 028239 , , . , , , Top of Productive Horizon: 2926' FSL, 2865' FEL, SEC. 33, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Sp te: Aug t 9, 05 Total Depth: 2931' FSL, 2914' FEL, SEC. 33, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to est Property: 3800' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583072 y- 5978067 Zone- ASP4 10. KB Elevation (Height above GL):Plan 77.9 feet 15. Distance to Nearest Well Within Pool 1950' to L-112 16. Deviated Wells: Kickoff Depth: 2700 feet Maximum Hole Angle: 58.1 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3377 Surface: 2714 1 Casing rogram: Size Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 6-3/4" 5-1 /2" 17# L-80 BTC-M 8306' Surface Surface 8335' 6344' lsv2" x 3-112" Cement Listed Below) 6-3l4" 3-1 /2" 9.2# L-80 IBT-M 468' 8335' 6344' 8803' 6805' 185 sx LiteCrete 19." PRESENT_WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 8270 Total Depth TVD (ft): 7155 Plugs (measured): N/A Effective Depth MD (ft): 8158 Effective Depth TVD (ft): 7045 Junk (measured): N/A Casing Length Size Dement Volume MD TVD tr I C n uctor 106' 20" 260 sx Arcticset A rox. 106' 106' 2610' 7-5/8" 352 sx Arcticset Lite, 173 sx Class 'G' 2637' 2598' P u i 7414' 5-1 /2" (st /r x s-v2^ Cement Listed Below) 7438' 6349' 815' 3-1/2" 239 sx LiteCrete 7438' - 8253' 6349' - 7139' Perforation Depth MD (ft): 7704' - 7750' Perforation Depth TVD (ft): 6603' - 6647' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25:050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Martyrs, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer (t'1:1C"'1'+~ p: 5l. - 77 Prepared By Name/Number: Si nature ~~ Phone 564-4166 Date ~~ai ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: 2'© .. API Number: 50- 029-23032-01-00 Permit Approv I Date: ~~~~ DS See cover letter for other requirements Conditions of Approval: Samples q 'red ^ Yes No Mud Log Required ^ Yes ~ No Hydr n Sul de Measures Yes ^ No Directional Survey Required Yes ^ No Other: ~~~~~ ~~ ~ a ~t:7L'% pSi . APPROVED BY A roved THE COMMISSION Date Form 10-401`Re4sed 0~ ~ °° `°' " " "' ` `~ Sybmit Irt/Duplicate • :~ Well Name: L-114A Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Producer Surface Location: X = 583,072.24' Y = 5,978,066.52' As-Built 2346' FSL (2933' FNL), 3845' FEL (1434' FWL), Sec. 34, T12N, '` R11 E Target Location: X = 578,765.00' Y = 5,978,600.00' Top Kuparuk 2926' FSL (2353' FNL), 2865' FEL (2415' FWL), Sec. 33, T12N, R11 E Bottom Hole Location: X = 578,716.08' Y = 5,978,604.14' 2931' FSL (2348' FNL), 2914' FEL (2366' FWL), Sec. 33, T12N, / R11E AFE Number: BRD5M4190 Ri Nabors 9ES -' Estimated Start Date: 8/09/2005 MD: 8803' TVD: 6805' O eratin da s to com lete: 12.0 BF/MS: 47.8' RKB: 76.3' Well Desi n conventional, slimhole, etc.: Microbore (longstring) Ob"ective: Kuparuk Formation Mud Program: 6 3/a" Intermediate /Production Hole (2637' - 8803'): Fresh Water LSND Interval Density PV YP API HTHP pH Drill MBT (ppg) Filtrate Filtrate Solids LGS% Drill-out - 9.2 12-18 20-28 4-7 N/C 9.0-9.5 < 6 <10 2,650 2,650- 9.2-9.4 12-18 20-26 3-5 N/C 9.0-9.5 < 6 <15 8,165 TH RZ 8,165 - 8,803 .4' 14-22 20-26 3-5 8-10 9.0-9.5 < 6 <20 KUPB --.. Hydraulics: Intermediate/Production Hole: 6 3/a" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2637' - 300 4" 15.7# 249 2562 11.1 8 5x10 .432 8803' L-114A Drilling Program Page 2 i • Directional: Ver. Anadrill P3 KOP: 2700' Maximum Hole Angle; 58.1 ° at 3719' MD Close Approach Wells: WKUPST-01 fails the major risk (conventional rule) at 3,600'md in the planned well. Since this well is a vertical exploration well, plugged and abandon, the risk is minimal in drilling to TD of L-114A. A risk based 1:200 rule has been run and asses. Distance to Nearest 3800' from PBU boundry Pro ert Distance to Nearest Well 1950' to L-112; 2500' to L-122; 2600' to L-100; 1400' to Within Pool: L-114 Parent Well Lo in Pro ram: Intermediate/Production Drilling: MWD / GR / Res /NEU /DEN/ PWD Hole Open Hole: Cuttings samples Cased Hole: None Formation Markers: Formation To s MDbkb TVDss SV5 1546' SV4 1678' Base Permafrost 1691' SV3 1925' SV2 2087' SV1 2404' KOP 2582' UG4 2810' 2685' UG4A 2842' 2715' UG3 3247 3060' UG1 3954' 3495' Ma 4597' 3835' Na 5032' 4065' H drocarbon Bearin 8.4 OA 5249' 4180' H drocarbon Bearin 8.4 Obf base 6071' 4615' Fault 1 6204' 4685' CM2 Colville Shales K-10 6610' 4900' CM1 Colville Shales 7560' 5530' THRZ 8165' 6100' Fault 2 8221' 6155' Kalubik 8358' 6290' K-1 8414' 6345' To Ku aruk TKD 8520' 6450' TKC4 8548' 6475' H drocarbon Bearin , 3227 si, 9.6 TKC1 8693' 6620' H drocarbon Bearin , 3300 si, 9.6 LCU Ku aruk B 8271' 6630' H drocarbon Bearin , 3377 si, 9.7 ~ TD 8803' 6728' q~4 z 9 l~,n L-114A Drilling Program Page 3 • • Casing/Tubing Program: Hole Size Csg/ Tb O.D. Wt/Ft Grade Conn Length Top MDlTVD Btm MD/TVD bkb 6-3/4" 5-1/2" 17# L-80 BTC-mod 8306' GL 8335'/6344' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 468' 8335'/6344' 8803'/6805' Tubin 3-1/2" 9.2# L-80 IBT-mod 8306' GL 8335'/6344' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT / 13.7 ppg surface shoe Cement Calculations: Casing Size 5-1/2"x3-1/2" Production Lon strin Basis: Lead: Based C 500' MD above top of Ma sand & 30% excess + 80' shoe. Lead TOC: 10 ' MD, 3648' TVDbkb Total Cement Vol e: Lead 102 bbls / 571 / 5. ks of Dowell LiteCrete at 11.0 oaa an O f/s . Well Control: The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi. Due to anticipated maximum surface pressures not exceeding 3,000 psi it will not be necessary to have two sets of pipe rams installed at all times. BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- s Maximum anticipated BHP: 3377 psi C~ 6630' TVDss - Kuparuk B Sands • Maximum surface pressure: 2714 psi @ surface (based on BHP and full gas column C 0.1 psi/ft C«~ 6630 TVDss) • Planned BOP test pressure: 3,500 psi/250 psi Rams ; 2,500 psi/250 psi Annular -d • 5'h" x 31h" Casing Test: 3,500 psi • Integrity Test - 6-3/4" hole: 13:7 ppg minimum EMW LOT 20' from 7-5l8" shoe • Kick Tolerance: ~2 ~bls • Planned completion fluid: ~.6 ppg filtered seawater / 6.8 ppg Diesel A majority of L-Pad wells have "kick tolerances" in the 25 bbl range. A heightened awareness of kick detection will be essential while drilling/tripping the intermediate/ production intervals. Disposal: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. i i L-114A Drilling Program Page 4 • • DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Riq Work: 1. Test the casing and tubing pack-offs to 5000 psi. Test the OA. Function all lockdown Screws. 2. Fluid pack the tubing and IA. 3. Drift 3-1/2" tubing as deep as possible. 4. P&A production interval with 6.5 bbls cement to 7,420' MD & obtain squeeze. 5. Pressure test 3-1/2" tubing and P&A plug to 3000 psi. 6. Tag TOC. 7. Chemical cut the 3-1/2" tubing at 7210' MD (1St full joint above GLM 2). 8. Circulate to seawater and freeze protect with diesel. 9. Set BPV. Secure we11. Remove the wellhouse. If necessary, level the pad. Riq Operations: 1. MIRU Nabors 9ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. 3. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 3-1/2" tubing from pre-rig cut. 5. RIH (picking up 2-7/8" DP) w/ 5.5", 15.5# bridge plug and set at 2770' MD (50' below cut point). 6. Pressure test casing to 3500 psi for 10 minutes. 7. Swap over to 9.2 ppg LSND cutting/drilling fluid. Spot an 18 ppg pill on the bridge plug to ~50' above the cut point. 8. RIH with 5.5, 15.5# mechanical casing cutting assembly to top of bridge plug 9. Cut 5.5" casin at 2720' MD (80' below surface shoe & circulate out IA to 9.2# mud. I g ) 10. Attempt to pull on casing to verify good cut. POOH (laying down 2-7/8" DP) w/ casing cutter. 11. Pull 5.5" casing from cut. 12. RIH w/ 4" drillpipe and a 2-7/8" cement stinger. Tag bridge plug in lower casing stub. Circulate bottoms up. 13. Spot a balanced 17 ppg cement kick-off plug from EZSV to 2500'. WOC. 6-3 4~drilling assembly with Dir/GR/Res/Dens/Neu/PWD and RIH. Drill excess cement in 7-5/8" casing to surface casing shoe'. 15. Kick off and drill 6-3/4" hole ~20' past cement kick-off plug. Perform LOT. (If a 13.7 ppg EMW is not ~i}` obtained, notify ODE) j l~ S i0 ~~'i6. Drill the 6-3/4" hole, turning at 4°/100' to a 58° hold angle. ~ Yv~wl 17. Verify that the mud weight is at least 10.0 ppg prior to cutting HRZ. (9.8 ppg pore pressure in KupB). °~ ~ 18. Drill ahead to TD at 8803' (150' MD below LCU). l 19. Condition hole for running 5.5" 17# x 3.5" 9.2# casing. 20. Run and cement the production casing in a single stage (expected TOC=3,600' MD) Displace the ~ cement with 8.5 ppg filtered seawater. 21. Freeze protect the 5-1/2" x 7-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 22. Test casing to 3500 psi for 30 minutes. r 23. Run the 3-1/2", 9.2#, L-80 IBT-Mod completion assembly. Test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. i 24. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 25. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 26. Rig down and move off. Post-Rice Work: 1. Install wellhouse, flowlines and instrumentation. 2. MIRU slickline. 3. Drift & Tag PBTD & Install gas lift valves. 4. MIRU E-Line. Record Jewelry Log & Perforate well (Approximately 40' of perforations). / 5. POP well and evaluate production for ~2 months prior to frac job to ensure frac will be effective. L-114A Drilling Program Page 5 s • Job 1: MIRU Hazards and Contingencies - L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-111 i 0 ppm L-116 10 ppm L-121 10 ppm L-100 10 ppm - The closest surface location is L-111 i at 30'. No surface shut-in will be required - Post Drilling Permit & Sundry with Summary of Drilling Hazards in doghouse prior to spud. - Notify AOGCC 24 .hours advance for BOP function test witness. Reference RPs :• "Drilling/ Wark over Close Proximity Surface and Subsurface Wells Procedure" Job 2: De-Complete Well Hazards and Contingencies - NORM test all retrieved well head and completion equipment. - The perforations in L-114A have been isolated with a cement plug set during pre-rig operations. Monitor well for any signs of pressure or flows. - Verify the hanger type and connection. Be prepared with necessary equipment to remove. - Note and record required PU weight to pull tubing at cut point. Reference RP • "De-completions" RP Job 4: Casing Cut and Pull Hazards and Contingencies - Once casing cutting is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. - Maintain kill weight fluid in the hole at all times. - After performing 5-1/2" casing cut pump a viscosified hot water "sweep" to remove as much dead crude from annulus as possible prior to laying dawn casing. RU secondary valve and choke on wellhead spool in preparation for circulating dead crude from annulus after 5-1/2" cut. Reference RP • "Setting aKick-off or Abandonment Plug in Open Hole" RP • "Casing and Cutting Pull with Baker Back-Off Tool" RP Job 7: Drilling Production Hole Hazards and Contingencies - KICK TOLERANCE: A Recent SBHP survey from L-114 indicates a 9.6 ppg EMW in the Kuparuk C. Assuming a 9.8 ppg pore pressure at the Kuparuk B target depth as per the SOR, gauge hole, a fracture gradient of 13.7 ppg at the surface casing shoe and 10.0 ppg mud in the L-114A Drilling Program Page 6 i • hole, the kick tolerance is 25. ,kSbls. An accurate LOT will be required as well as heightened awareness for kick dete 'on. If LOT is less than 13.7 ppg contact Drilling Superintendent. (The original L-114 LOT was recorded at 15.9 EMW in the SV1 & L-116 reported a lot of 15.4 EMW) - A majority of the L-Pad development will have "kick tolerances" in the 25 bbl range or less. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. - Faults: The well trajectory is expected to intersect the same fault twice. The first intersection is at approximately 6204' MD (4685' TVDss (Colville Formation)) with an estimated throw of 85'.The second intersection is at approximately 8221' MD (8205' TVDss (HRZ)) with an estimated throw of 75'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. - There are no "close approach" issues with the production hole interval of L-114A. WKUPST-01 fails the major risk (conventional rule) at 3,600'md in the planned well. Since this well is a vertical exploration well, plugged and abandon, the risk is minimal in drilling to TD of L-114A. A risk based 1:200 rule has been run and passes. Reference RPs • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torpue and Drag Management. • "Shale Drilling- Kingak & HrZ" Job 9: Case & Cement Production Hole Hazards and Contingencies - The 5-1/2" casing will be cemented to at least 500' above the Schrader Ma sand; the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. - Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting the 5'/i" x 7-5/8" casing annulus with dead crude. The hydrostatic pressure will be 10.5 ppg or .7 ppg more than the maximum anticipated pore pressure if the cement has not reached compressive strength. It is essential that freeze protection of the annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. - The well will be under-balanced after displacing the cement with Sea Water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. - Ensure a minimum hydrostatic equivalent of 10.0 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes Reference RPs • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting Outer Annulus" Job 12: Run Completion Hazards and Contingencies - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RPs • "Completion Design and Running" L-114A Drilling Program Page 7 i • • "Tubing connections" RP Job 13: ND/NU/Release Rip Hazards and Contingencies - No hazards specific to this well have been identified for this phase of the well construction. - Diesel wilt be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RPs • Freeze Protection of Inner Annulus L-114A Drilling Program Page 8 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control /Reservoir Pressures: Interval TD Psi TVDss Comments Schrader 2,122 8.7 4,615 Assumed to be vir in ressure Ku aruk 3,227 9.6 6,475 Based on L-114 static ressures II. Hydrates and Shallow gas: A. Gas Hydrates are expected at L-pad near the base of the permafrost. Existing surface casing through the SVi should keep hydrate exposure from extending past the surface shoe. Occasionally hydrates are encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed if hydrates are encountered while drilling. III. Lost Circulation /Breathing: A. Lost circulation is considered low risk throughout the uphole intervals. IV. Kick Tolerance /Integrity Testing: A. The 5-~/2" x 3-'/z" casing will be cemented to 500' MD above the Ma sand. B. Integrity Testing: NOTE: If the LOT is less then the minimum notify the ODE immediately Kick Tolerance / Inte rit Testin Summar Table Casin /Interval Acre table Influx Volume Mud Wei ht Ex Pore Press Min LOT Production / 6-3/a" 25.2 bbls 10.0 9.6 13.7 NOTE: The LOT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the casing string L-Pad development wells may have "kick tolerances" in the 25 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drillin tripping the intermediate/production intervals. V. Stuck Pipe A. There could be slight differential sticking across the reservoir while running 5-1l2"x3-112" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide A. L Pad is no designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. HZS Summa Table Well Name. H2S Level Date of Readin #1 Closest SHL Well H2S Level L-111 i 0 m Feb-05 #2 Closest SHL Well H2S Level L-121 10 m Feb-05 #1 Closest BHL Well H2S Level L-116 10 m Jul-03 #2 Closest BHL Well H2S Level L-100 10 m Feb-05 VII. Faults Fac~tf ~.O~C~~#F3t7~ r `` ' ` ,r, -~ ; ' MD..~ t~ ;~~ ~ - ",.~ ~'Vf~ss ~~ ~~ <Throw, Direction UncertaEnty Fault #1 -Colville below Obf, Fault A 6,117 -4685 85' West +/-150' MD Fault #2 - HRZ, Re-Penetrate Fault A 8,205 -6155 75' West +/-100' MD CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION LOCATED WITHIN PROTRACTED SECTION 34. T. 32 N.. R. 11 E.. UM[AT MFRit}IAI~f. AI ASKA i V``i l /.. ~,b~ WELL/SLOT A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NUMBER COORDINATES COORDINATES POSITION(DMS) POSITION{D.DD) BOX ELEV. OFFSETS WELL L-114 5,978,066.52 9,819.92 70'21'00.180" ' " 70.3500500' 47 8' 2 346' F5L ' 583,072.24 5,029.83 --149'19 31.991 -149.3255531' ' 3,845 FEL SLOT S-D 5,978,070.34 9,819.83 70'21'00.216" ` " 70.3500600' 47 8" 2,350' FSL ` 583,086.84 5,044.92 -149'19 31.563 -149.3254342' ' 3,830 FEL WELL L- 'S+ 5, 978, 078.1 S 9, 819.86 70"21'00.290" ' " 70.3500806' 47 9, 2, 357' FSL ' 583,115.$9 5,@75.00 -149'19 30.711 -149.3251975' . 3,801 FEL WELL L-110 5,978,086.04 9,820.01 70'21'00.364" ' " 70.3501011' 48 2' 2,365' FSL ' 583,144.73 5,104.90 149'19 29.866 -149.3249628' ' 3,772 FEL SLOT S-E 5,97$,089.96 9,820.01 70'21'00.401" ' " 70.3501114' 48 1 2,369' FSL ' 583,159.38 5,120.07 149'19 29.436 -149.3248433' ' 3,757 FEL WELL L-116 5,978,093.86 9,820.06 70'21'00.438" ' " 70.3501217' 48 2' 2,372' FSL ' 583,173.75 5,1354.96 -149'19 29.015 -149.3247264' ' 3,743 FEL WELL L-1091 5,978,097.98 9,820.28 70'21'00.477" ' " 70.3501325' 47 9• 2,376' FSL ' 583,188.27 5,i5PJ.06 149'19 28.589 -149.3246081' . 3,728 FEL S- 5,978,101.53 9,819.9$ 70'21'@0.510" 70.3501417' 48 0' 2,380' FSL WELL L- 583,202.66 5,164.87 -149'19'28.168" -149.3244911' ' 3,714' FEL WELL L-0t 5,978;116.04.. 9,820.20 70'21'00.647" ' " 70.3501797' 48 7' 2,394' FSL 583,255.98 5,220.14 149'19 26.605 -149.3240569. ' 3,660' FEL SLOT S-N 5,978,119.56 9,819.$2 70'21'00.680 ' ' 70.3501889' 48 8' 2,397' FSL ' 583,270.56. 5,235.13 -149'19 26.178 -149.3239383' . 3,646 FEL r. rcaaer~ _.."..... lac CNECHED:,J (., R D Y® T r,,,~ A.1p ~ ~0~~ ~®~ i ` 6 0 oA~E: 4 28/01 SJf .I~^ ^ 'S`~ ~' ~ ONAkIxC' Flaeei wOL e3-ea .ae ~~o: WOA L-PAD CONDUCTOR AS-GUILTS ~~~' Ei1~IJ~o ,tea„:.o,..~n.,,,a, scA~: FOR SLOTS S-D, S-1, S-N AND 2 aF 2 ..~K,,,,...~,,.K Yd.O„¢ MNU Nffl N.T.S YVELLS L-01,109i,119,1i1i,114,115i & lib ~ .. ~p L-114A (P3) Proposal Schlumberger CIieM: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / L-114 ~ O?' Well: L-114 Ov~ Borehole: Plan L-114A Apps I1WI/API#: 50029 Survey Name /Date: L-114A (P3) /May 5, 2005 Tort IAND / DDI I ERD rntio: 116.596° / 4433.46 ft (5.825 / 0.652 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70.35005005, W 149.32555296 Location Grid NIE YDC: N 5978066.520 ftUS, E 583072.240 ftUS GddConvergenceAngle: +0.63517370° Vertical Section Azimuth: 290.780° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVO Reference Dawm: Rotary Table ND Reference Elevation: 76.30 ft relative to MSL Sea Bed I Ground Level Elevation: 44.70 ft relative to MSL Magnetic Declinatlon: 24.508° Total Field Strength: 57575.81 nT Magnetic Dip: 80.845° Declination Date: August 21, 2005 Magnetic Declinatlon Model: BGGM 2004 North Reference: True North Total Corr MagNorth -> True North: +24.508° • Measured Vertical Along Hole Comments Depth Inclination Azimuth Sub-Sea TVD ryp SecOon Departure NS EW DLS Tool Face Bu(Id Rate Walk Rate Northing Easting Latitude Longitude R d de ft R ft R ft ft de 1100 ft de de N00 ft d 1100 R RUS ftUS tie-rn survey 2'J91i.1/ 11i.U4 2134.3/ 24132.421 2b08. /t3 31/.99 :543.4/ 142.(53 -2255.99 U.4U 1t1.;54Ci -U.31 -U.91 59/2f2Ub.95 5152 /134./1 N /U.3bU4;f9ti/ W 149.:12/87465 7-5/8" Csg Pf 2637.00 16.68 285.10 2521.66 2597.96 329.43 354.97 145.55 -297.11 1.64 17.64G 1.56 1.79 5978208.76 582773.56 N 70.35044766 W 149.32796493 KOP Crv 4!100 2700.00 17.66 286.14 2581.85 2658.15 347.95 373.56 150.56 -315.02 1.64 -13.53G 1.57 1.64 5978213.57 582755.60 N 70.35046135 W 149.32811032 2800.00 21.57 283.59 2676.03 2752.33 381.32 407.13 159.10 -347.48 4.00 -11.13G 3.91 -2.54 5978221.75 582723.05 N 70.35048468 W 149.32837379 UG4 2809.66 21.95 283.39 2685.00 2761.30 384.87 410.71 159.94 -350.96 4.00 -10.95G 3.93 -2.07 5978222.54 582719.56 N 70.35048696 W 149.32840205 UG4A 2842.15 23.23 282.77 2715.00 2791.30 397.24 423.19 162.76 -363.12 4.00 -10.37G 3.93 -1.93 5978225.23 582707.38 N 70.35049467 W 149.32850075 2900.00 25.51 281.80 2767.69 2843.99 420.84 447.05 167.83 -386.44 4.00 -9.49G 3.94 -1.67 5978230.04 582684.00 N 70.35050851 W 149.32869008 3000.00 29.46 280.46 2856.39 2932.69 466.32 493.19 176.70 -431.72 4.00 -8.30G 3.95 -1.34 5978238.41 582638.63 N 70.35053274 W 149.32905764 3100.00 33.42 279.41 2941.69 3017.99 517.54 545.34 185.67 -483.09 4.00 -7.40G 3.96 -1.05 5978246.81 582587.17 N 70.35055724 W 149.32947469 3200.00 37.39 278.56 3023.18 3099.48 574.23 603.27 194.70 -540.31 4.00 -6.71G 3.97 -0.85 5978255.20 582529.86 N 70.35058190 W 149.32993919 UG3 3246.93 39.26 278.22 3060.00 3136.30 602.66 632.37 198.95 -569.10 4.00 -6.44G 3.97 -0.74 5978259.13 582501.03 N 70.35059349 W 149.33017292 3300.00 41.37 277.86 3100.46 3176.76 636.14 666.70 203.74 -603.09 4.00 -6.17G 3.98 -0.68 5978263.55 582466.99 N 70.35060659 W 149.33044887 3400.00 45.35 277.25 3173.16 3249.46 702.96 735.34 212.75 -671.13 4.00 -5.73G 3.98 -0.60 5978271.80 582398.85 N 70.35063119 W 149.33100127 3500.00 49.33 276.73 3240.91 3317.21 774.36 808.86 221.69 -744.11 4.00 -5.37G 3.98 -0.53 5978279.93 582325.79 N 70.35065559 W 149.33159368 3600.00 53.31 276.26 3303.40 3379.70 849.99 886.91 230.51 -821.66 4.00 -5.08G 3.98 -0.47 5978287.89 582248.16 N 70.35067966 W 149.33222323 3700.00 57.30 275.84 3360.31 3436.61 929.48 969.11 239.17 -903.40 4.00 -4.84G 3.99 -0.42 5978295.64 582166.33 N 70.35070329 W 149.33288683 End Crv 3719.17 58.06 275.76 3370.57 3446.87 945.14 985.31 240.81 -919.52 4.00 O.OOG 3.99 -0.40 5978297.10 582150.20 N 70.35070775 W 149.33301769 UG1 3954.38 58.06 275.76 3495.00 3571.30 1137.92 1184.91 260.86 -1118.11 0.00 O.OOG 0.00 0.00 5978314.94 581951.42 N 70.35076245 W 149.33462987 Ma 4597.06 58.06 275.76 3835.00 3911.30 1664.67 1730.28 315.64 -1660.72 0.00 O.OOG 0.00 0.00 5978363.70 581408.28 N 70.35091183 W 149.33903498 Na 5031.81 58.06 275.76 4065.00 4141.30 2021.00 2099.21 352.69 -2027.78 D.00 O.OOG 0.00 0.00 5978396.68 581040.86 N 70.35101282 W 149.34201494 OA 5249.18 58.06 275.76 4180.00 4256.30 2199.17 2283.67 371.22 -2211.32 0.00 O.OOG 0.00 0.00 5978413.17 580857.15 N 70.35106330 W 149.34350494 OBf Base 6071.43 58.06 275.76 4615.00 4691.30 2873.10 2981.43 441.31 -2905.54 0.00 O.OOG 0.00 0.00 5978475.55 580162.26 N 70.35125412 W 149.34914106 Fault 1 Crossing 6203.75 58.06 275.76 4685.00 4761.30 2981.55 3093.71 452.59 -3017.26 0.00 O.OOG 0.00 0.00 5978485.59 580050.43 N 70.35128481 W 149.35004803 CM2 6610.14 58.06 275.76 4900.00 4976.30 3314.65 3438.58 487.23 -3360.38 0.00 O.OOG 0.00 0.00 5978516.42 579706.98 N 70.35137905 W 149.35283375 Drp 4/100 6861.82 58.06 275.76 5033.14 5109.44 3520.92 3652.15 508.68 -3572.87 0.00 -180.OOG 0.00 0.00 5978535.52 579494.29 N 70.35143738 W 149.35455890 6900.00 56.53 275.76 5053.77 5130.07 3551.96 3684.28 511.91 -3604.84 4.00 -180.OOG -4.00 -0.01 5978538.39 579462.29 N 70.35144616 W 149.35481843 7000.00 52.53 275.76 5111.79 5188.09 3630.60 3765.71 520.08 -3685.85 4.00 -180.OOG -4.00 -0.01 5978545.66 579381.19 N 70.35146837 W 149.35547618 7100.00 48.53 275.75 5175.34 5251.64 3705.14 3842.89 527.81 -3762.65 4.00 -180.OOG -4.00 -0.01 5978552.54 579304.33 N 70.35148940 W 149.35609966 7200.00 44.53 275.74 5244.12 5320.42 3775.22 3915.45 535.08 -3834.85 4.00 -180.OOG -4.00 -0.01 5978559.01 579232.06 N 70.35150915 W 149.35668581 WeIlDesign Ver Bld(doc40x_37) L-114\L-114\Plan L-114A1L-114A (P3) Generated 711912005 9:38 AM Page 1 of 2 Measured Vertical Along Hole Comments Inclination Azimuth SutrSea TYD ryp NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft de 1100ft d de 1100ft de 1100ft ftUS ftUS /300.00 40.53 2/5./3 531/./9 5394.09 3840.49 3983A4 541.84 -3902.09 4.00 -180AU(i -4.W -0.01 5978565.02 5/9164./5 N 70.35152/51 W 149 .35723179 7400.00 36.53 275.72 5396.00 5472.30 3900.64 4045.32 548.05 -3964.07 4.00 -180.OOG -4.00 -0.01 5978570.55 579102.72 N 70.35154441 W 149 .35773493 7500.00 32.53 275.71 5478.37 5554.67 3955.37 4102.00 553.70 -4020.46 4.00 -180.OOG -4.00 -0.01 5978575.56 579046.27 N 70.35155975 W 149 .35819278 CMl 7560.45 30.11 275.70 5530.00 5606.30 3985.71 4133.42 558.82 -4051.73 4.00 -180.OOG -4.00 -0.02 5978578.34 579014.97 N 70.35156823 W 149. 35844662 7600.00 28.53 275.69 5564.48 5640.78 4004.41 4152.79 558.74 -4071.00 4.00 -180.OOG -4.00 -0.02 5978580.05 578995.68 N 70.35157346 W 149 .35860311 7700.00 24.53 275.67 5653.93 5730.23 4047.53 4197.45 563.17 -4115.44 4.00 -180.OOG -4.00 -0.02 5978583.98 578951.20 N 70.35158548 W 149 .35896393 7800.00 20.53 275.65 5746.28 5822.58 4084.52 4235.76 566.95 -4153.57 4.00 -180.OOG -4.00 -0.03 5978587.34 578913.04 N 70.35159574 W 149 .35927347 7900.00 16.53 275.60 5841.08 5917.38 4115.19 4267.54 570.06 -4185.19 4.00 -180.OOG -4.00 -0.04 5978590.10 578881.38 N 70.35160421 W 149 .35953022 8000,00 12.53 275.54 5937.86 6014.16 4139.40 4292.63 572.50 -4210.16 4.00 -180.OOG -4.00 -0.07 5978592.26 578856.39 N 70.35161083 W 149 .35973294 End Drp 8063.31 10.00 275.47 5999.94 6076.24 4151.33 4304.99 573.69 -4222.47 4.00 O.OOG -4.00 -0.11 5978593.31 578844.07 N 70.35161405 W 149 .35983289 Top HRZ 8164.91 10.00 275.47 6100.00 6176.30 4168.35 4322.64 575.37 -4240.03 0.00 O.OOG 0.00 0.00 5978594.80 578826.49 N 70.35161862 W 149. 35997547 Fault 2 Crossing 8220.76 10.00 275.47 6155.00 6231.30 4177.70 4332.34 576.29 -4249.69 0.00 O.OOG 0.00 0.00 5978595.62 578816.83 N 70.35162113 W 149. 36005385 Kalubik 8357.84 10.00 275.47 6290.00 6366.30 4200.66 4356.14 578.56 -4273.38 0.00 O.OOG 0.00 0.00 5978597.62 578793.11 N 70.35162729 W 149. 36024624 K1 8413.69 10.00 275.47 6345.00 6421.30 4210.01 4365.84 579.49 -4283.04 0.00 O.OOG 0.00 0.00 5978598.44 578783.45 N 70.35162980 W 149. 36032462 Top Kuparuk 8520.30 10.00 275.47 6449.99 6526.29 4227.87 4384.35 581.25 -4301.46 0.00 O.OOG 0.00 0.00 5978600.00 578765.00 N 70.35163460 W 149. 36047423 L-114A Tgt1 8520.31 10.00 275.47 6450.00 6526.30 4227.87 4384.35 581.25 -4301.47 0.00 O.OOG 0.00 0.00 5978600.00 578765.00 N 70.35163460 W 149 .36047425 TKC4 8545.70 10.00 275.47 6475.00 6551.30 4232.12 4388.76 581.67 -4305.85 0.00 O.OOG 0.00 0.00 5978600.37 578760.61 N 70.35163574 W 149. 36050987 TKC1 8692.93 10.00 275.47 6620.00 6696.30 4256.78 4414.33 584.11 -4331.31 0.00 O.OOG 0.00 0.00 5978602.53 578735.13 N 70.35164236 W 149. 36071651 LCU / Kup 8 8703.08 10.00 275.47 6629.99 6706.29 4258.48 4416.09 584.28 -4333.06 0.00 O.OOG 0.00 0.00 5978602.67 578733.38 N 70.35164281 W 149. 36073074 8703.09 10.00 275.47 6630.00 6706.30 4258.48 4416.09 584.28 -4333.06 0.00 O.OOG 0.00 0.00 5978602.67 578733.38 N 70.35164281 W 149 .36073076 OWC 8728.47 10.00 275.47 6655.00 6731.30 4262.73 4420.50 584.70 -4337.45 0.00 O.OOG 0.00 0.00 5978603.05 578728.99 N 70.35164395 W 149. 36076638 FWL 8753.86 10.00 275.47 6680.00 6756.30 4266.99 4424.91 585.12 -4341.84 0.00 O.OOG 0.00 0.00 5978603.42 578724.59 N 70.35164509 W 149. 36080201 TD 8803.09 10.00 275.47 6728.48 6804.78 4275.23 4433.46 585.93 -4350.35 0.00 O.OOG 0.00 0.00 5978604.14 578716.08 N 70.35164731 W 149 .36087110 Legal Description: Northing (YI tftUSl Easting IXl fftUSl Surface : 2346 FSL 3845 FEL S34 T12N R11E UM 5978066.52 583072.24 BHL : 2931 FSL 2914 FEL S33 T12N R11 E UM 5978604.14 578716.08 WeIlDesign Ver Bld( doc40x_37) L-114\L-1141PIan L-114A1L-114A (P3) Generated 7/19/2005 9:38 AM Page 2 of 2 UiJ Schlumberger µEL` L-114A (P3) FIELD Prudhoe Bay Unit - WOA STRUCTURE L-PAD Afagne~e Pxxnelers Su~.xo Lorueon Nn-2] AMSka Sine PHres. Zaw W. US Feel t.FSCelaneats Motlel BGGM 2005 qp. BO 846' DMe: A,pus121. 2005 Lal N]02tOt80 m6ing S9]BOfi662 flU5 Gntl Canv.0.6361]]]0' Sld L-11d TVD ReT Rotary Tade 116.30 Rabove MSLI Mag Dee. X26508' FS'. ]5]5.81 nT Lan: Wtd9 t9 )1.991 Easll~g. 6B]o]2.24 PUS Scala Fah'.°99990]839) Plan'. L~114A (P31 Srvy Date. 800 1600 2400 3200 4000 2400 3200 4000 0 0 C 4800 H 5600 6400 7200 -11a .......... .........Ae-in.surx6Y................................... i....................................o.............. 7-518" Cig Pt ...................... i.................................... o................................. KOP Civ M100 ._.._.._. _..: ~ i......_..:.._.. _..:.._.._. _ -.._..~......... ~. ~..~ ..-..-..- ..-..-. ~. ~..- - -. -..-. -. ~. -. ~.._.._ _.._..:..:.._.._.. _.._ End Crv .._.._.._.. _.._.. _.. _.._..~.._ _.._. .._.._.._..-..~..-.._.._.._.._..-..-..-..-.d-.....-..- 1 .....-.._.....-..a..-..-..-..-.._..-..-.._.. _:._.._.._.._.._.._.._.._.. .._.._.._.. _.. _.._.._.. _..i-..-..-..-..-..-..-. ..-..<.. .-.._..-.._.._.._.._.._.i-.._..-.._ ................................... i............................... ... i........ .......................... i.............. ..-..-..-..-..-..i..-..-..-..-..-..-..-.._.. _i. _.._.. _.. _.. _.. _.._.._.. ...................... i.................................... ~ ................................. Fault 7 Crossing i i .-.._..-.._.._.._.. _.. -..-..-..-..-..-..-..-. ..-..-..-..-.. -.. .-..-..- ..-. J:. _.._.._.._.. _.._.._.. _.. .._.._.._.._.._.._.._ ase Drp a~oo End Drp~ .._.._.._.._.._.._.._.._.....-..-..-..-..-..-..-..-..~..-..-..-..-..-..-..-..-..-.i-..-. ..-. _.._.._..~..-..-..-..-. -. - - - - - ._.._ _ ~ Top i1FiZ Fault 2 Crossing; -.i- L-114A Tgt 4, .._..-..-..-..-..-..-..-..r..-..-..-..-..-..-..-..-..y.-..-..-..-..-..-..-..~..-.~-..-..-..- ..-..-..-..-..-..j: ..-..-..-..~~~~.THC4._.. . _.. _.._.._.._ ~~~~~~~~~~~~~~~~~-~e~ra-~~-~aga~~e-~~~~~~de~a~~~e~d~~~a~al~~a~da-d~~ ~a-da~d~-~~~a~~~a~~d la-aa-a.- _ TD ...................................:.....................................:....................................a.............. ......................i.........L.t7A.....................;................................. 2400 3200 4000 4800 5600 6400 7200 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 290.78°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W by Schlumberger WELL L-114A (P3) FIELp Prudhoe Bay Unit - WOA STRUCTURE L-PAD Magrelic Parameters Surtaw Lewlbn N/~p2I HlasMa Slata PMws. Line 01. US Fuut n AIWeI'. SGGM 2004 Dip. BO eI]' Dale: Auyus131, ]005 lal: NIO 2t0 tb0 I~Wrthmg. h5/tlOfifi S2 RUS Grv3 Gxiv •O.filSt/]/0" Sbl~b LIIJ TVp Rnf RW.vy Ta01a 12fi.30 Rabwe MSLf May Uec. •2a 1J 3" FS. 5]6330 nT lnn- WtJ9 t51t 991 Embry: 58]0/32J IttI S' Sub Faa: 0o99y0 ]b353 Plan L~t fJA IP3f Srry pale MaY OS. 2005 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 1800 1200 n n n Z 0 0 s 600 a~ `~ v v v 0 -600 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 «< W Scale = 1(in):600(ft) E »> •i 1800 1200 600 • 0 -600 L-114/Plan L-114A • ` -~ ~ ,-_ ~- • • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Tuesday, July 19, 2005 Matthew Marlyn BP Exploration Alaska Sd~h~g Prudhoe Bay L-114A (P3) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survev Program: Instrument Type Start Depth End Depth MWD +IFR + MS 101.61'md 2,596.71'md MWD 2,596.71'md 4,100.00'md MWD +IFR + MS 2,596.71'md 8,803.09'md) Close Approach Analysis results: Under method (2): Note 1: WKUPST-01 fails the major risk (conventional rule) at 3,600'md in the planned well. Since this well is a vertical exploration well, plugged and abandon, the risk is minimal in drilling to TD of L-114A. A risk based 1:200 rule has been run and passes. A Tolerable Risk Worksheet should be filled out for documentation. If the tolerable risk number is less than 200, then it is safe to proceed. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Checked by: Scott DeLapp 07/19/05 Schlumber er g Anticollision Report Company: BP Amoco Date: 7/19/2005 Time: 10`.03:40 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE}Reference: We1C L-114, True North Reference. Well: L-1.14 ' Vertical (TVD) Reference: L-114A Pian 76:3 Reference Wellpath: Plan L-114A Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method : MD + Stations Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 2700.00 to 8803.09 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/6/2005 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 101.61 2596.17 Survey #1 ( 101.61-8213.60) (0) MWD+IFR+MS MWD +IFR + Multi Station 2596.17 4100.00 Planned: Plan #3 V1 MWD MWD - Standard 2596.17 8803.09 Planned: Plan #3 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in irr 2637.00 2597.96 7.625 8.750 7-5/8" 2800.00 2752.33 5.500 6.750 51/2" Summary <------------- Offset Wellpath -------------_--> Site Well Wellpath Reference MD Offset MD Ctr-Ctr Distance No-Go Area' Allowable Deviation Warning / ft ft ft ft ft_ EX WKUPST-01 WKUPST-01 WKUPST-01 V1 3600.00 8700.00 8388.3912348.80 -3960.41 FAIL: Major Risk PB L Pad L-01 L-01 V14 2700.00 3350.00 1507.50 36.92 1470.58 Pass: Major Risk PB L Pad L-02 L-02 V1 2738.11 2750.00 225.67 37.89 187.78 Pass: Major Risk PB L Pad L-02 L-02A V5 2741.56 2750.00 241.15 42.02 199.13 Pass: Major Risk PB L Pad L-02 L-02APB1 V2 2741.56 2750.00 241:15 42.02 199.13 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 2738.11 2750.00 225.67 37.89 187.78 Pass: Major Risk PB L Pad L-101 L-101 V4 2718.92 3050.00 1070.95 42.95 1028.00 Pass: Major Risk PB L Pad L-102 L-102 V2 2700.00 6150.00 4904.95 38.79 4866.16 Pass: Major Risk PB L Pad L-102 L-102P61 V10 Out of range PB L Pad L-102 L-102PB2 V2 Out of range PB L Pad L-103 L-103 V23 2700.00 4200.00 2672.04 40.31 2631.73 Pass: Major Risk PB L Pad L-104 L-104 V7 2700.00 5400.00 3887.69 37.54 3850.15 Pass: Major Risk PB L Pad L-105 L-105 V4 2700.00 3700.00 2050.31 37.44 2012.87 Pass: Major Risk PB L Pad L-106 L-106 V14 2700.00 3150.00 1221.57 36.06 1185.51 Pass: Major Risk PB L Pad L-107 L-107 V14 2700.00 4400.00 2837.78 40.08 2797.70 Pass: Major Risk PB L Pad L-108 L-108 V18 2700.00 3250.00 1266.65 38.48 1228.17 Pass: Major Risk PB L Pad L-109 L-109 V12 2710.52 3100.00 1134.17 40.55 1093.63 Pass: Major Risk PB L Pad L-110 L-110 V11 2724.93 3200.00 1277.78 43.03 1234.74 Pass: Major Risk PB L Pad L-111 L-111 V24 3875.46 3850.00 663.51 91.98 571.53 Pass: Major Risk PB L Pad L-112 L-112 V8 2760.07 2800.00 672.75 39.29 633.46 Pass: Major Risk PB L Pad L-114 L-114 V15 2749.99 2750.00 0.59 5.50 -4.91 FAIL: Minor 1/200 PB L Pad L-115 L-115 V7 2709.32 2800.00 605.49 42.03 563.46 Pass: Major Risk PB L Pad L-116 L-116 V10 2739.08 2800.00 382.69 42.63 340.06 Pass: Major Risk PB L Pad L-117 L-117 V11 2706.70 3200.00 1483.17 43.32 1439.85 Pass: Major Risk PB L Pad L-118 L-118 V9 2700.00 3650.00 2108.71 41.66 2067.04 Pass: Major Risk PB L Pad L-119 L-119 V9 2700.00 3650.00 2083.68 41.90 2041.79 Pass: Major Risk PB L Pad L-120 L-120 V8 2700.00 4250.00 2835.42 40.36 2795.05 Pass: Major Risk PB L Pad L-121 L-121 V14 2702.84 3750.00 2209.53 45.41 2164.12 Pass: Major Risk PB L Pad L-121 L-121A V1 2702.84 3750.00 2209.53 45.29 2164.24 Pass: Major Risk PB L Pad L-122 L-122 V5 2821.47 2950.00 1197.14 40.36 1156.78 Pass: Major Risk PB L Pad L-124 L-124 V11 11699.53 3150.00 1553.33 127.08 1426.25 Pass: Major Risk PB L Pad L-124 L-124P61 V5 11699.53 3150.00 1553.33 127.08 1426.25 Pass: Major Risk PB L Pad L-200 L-200 V7 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-200 L-200L1 V3 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-200 L-200L2 V6 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-201 L-201 V6 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201L1 V9 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201L1P61 V10 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201 L2 V5 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201 L3P61 V6 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201PB1 V12 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk Schlumber er • g Anticollision Report Company: BP Amoco Date: 7/19/2005 Time: 10:03;40 _ _~ Page: 2 .:Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: L- 114, True No rth Reference Well: L-1-14 Vertical (TVD) Reference: L-114A Plan 76.3 Reference Wellpath Plan L-114A Db: Sybase Summary <~_______-_ ~_ .Offset Wellpath_ ------------>" l3efecence . Offset.. . Ctr-Ctr No-Go Allowable. - Site Weii Wellpath MD MD Distance Area Deviation- Warning ft ft ft ft ft PB L Pad L-201 L-201 P62 V3 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PS L Pad L-202 L-202 V5 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk PB L Pad L-202 L-202L1 V7 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk PB L Pad L-202 L-202L2 V6 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk PB L Pad L-202 L-202L3 V6 2713.02 3550.00 1916.83 43.36 1873.47 Pass: Major Risk PB L Pad L-210 L-210 V6 Out of range PB L Pad L-210 L-210PB1 V8 2700.00 10000.00 8833.19 41.16 8792.03 Pass: Major Risk PB L Pad L-211 L-211 V6 2741.59 3500.00 1946.11 43.03 1903.08 Pass: Major Risk PB L Pad L-211 L-211 PB1 V6 2741.59 3500.00 1946.11 43.03 1903.08 Pass: Major Risk PB L Pad L-212 L-212 V11 2712.68 3850.00 2442.09 44.32 2397.77 Pass: Major Risk PB L Pad L-212 L-212P61 V9 Out of range PB L Pad L-212 L-212PB2 V2 2713.45 3850.00 2445.60 44.38 2401.22 Pass: Major Risk PB L Pad L-214 L-214 V9 2700.00 7300.00 6221.53 39.91 6181.62 Pass: Major Risk PB L Pad L-216 L-216 V6 2700.00 4800.00 3595.94 41.86 3554.08 Pass: Major Risk PB L Pad NWE1-01 L-100 V2 2745.92 2850.00 992.38 48.49 943.89 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 2745.92 2850.00 992.38 48.49 943.89 Pass: Major Risk PB L Pad Plan L-03 (S-O) Plan L-03 V4 Plan: Pla 2700.00 4250.00 2489.56 38.42 2451.14 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123 V4 Plan: PI 2700.00 4800.00 3453.83 41.36 3412.47 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123PB1 V2 Plan: 2700.00 4800.00 3453.83 41.29 3412.55 Pass: Major Risk PB L Pad Plan L-203 (N-O) Plan L-203 V6 Plan: PI 2700.00 3400.00 1566.01 42.43 1523.58 Pass: Major Risk PB L Pad Plan L-213 (S-B) Plan L-213 V5 Plan: PI 2700.00 5900.00 4552.46 39.15 4513.31 Pass: Major Risk PB L Pad Plan L-215 Plan L-215 V2 Plan: PI 2700.00 8800.00 7729.23 43.02 7686.21 Pass: Major Risk PB L Pad Plan L-215 Plan L-215P61 V2 Plan: Out of range PB L Pad Plan L-218 (N-B) Plan L-218 V2 Plan: PI 2722.57 3300.00 1541.11 41.87 1499.24 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250 V1 Plan: PI 2700.00 3450.00 1922.37 44.75 1877.62 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250L1 V5 Plan: 2700.00 3450.00 1922.37 44.77 1877.61 Pass: Major Risk PB L Pad Plan L-50 Plan L-50 V1 Plan: Pla 2722.54 2900.00 692.38 38.34 654.05 Pass: Major Risk Schlumber er g Anticollision Report Company: BP Amoco Date: 7/19/2005 Time: 09:56;30 Fage: 1 Field: Prudhoe Bay. leference Site: PB L Pad Co-ordinate(NE) Reference: Well: L-114, True No rth Reference Well: L-114 Vertical (TVD) Reference: L-114A Plan 76:3 Reference Wellpath: Plan L=114A Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD + Stations Interval: 50.00 ft Error Model: 1SCWSA Ellipse Depth Range: 2700.00 to 8803.09 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/6/2005 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 101.61 2596.1 7 Survey #1 ( 101.61-8213.60) (0) MWD+IFR+MS MWD +IFR + Multi Station 2596.17 4100.00 Planned: Pl an #3 V1 MWD MWD -Standard 2596.17 8803.09 Planned: Pl an #3 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 2637.00 2597.96 7.625 8.750 7-5/8" 2800.00 2752.33 5.500 6.750 51/2" Summary <----------- Offset Wellpath '--- ------------> Reference Offset Ctr-Ctr No-Go Allowable Site WeII Wellpath MD MD Distance Area' Deviation Warning ft ft ft ft ft EX WKUPST-01 WKUPST-01 WKUPST-01 V1 2700.00 4000.00 6322.93 0.00 6322.93 Pass: Minor 1/200 PB L Pad L-01 L-01 V14 2700.00 3350.00 1507.50 36.92 1470.58 Pass: Major Risk PB L Pad L-02 L-02 V1 2738.11 2750.00 225.67 37.89 187.78 Pass: Major Risk PB L Pad L-02 L-02A V5 2741.56 2750.00 241.15 42.02 199.13 Pass: Major Risk PB L Pad L-02 L-02APB1 V2 2741.56 2750.00 241.15 42.02 199.13 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 2738.11 2750.00 225.67 37.89 187.78 Pass: Major Risk PB L Pad L-101 L-101 V4 2718.92 3050.00 1070.95 42.95 1028.00 Pass: Major Risk PB L Pad L-102 L-102 V2 2700.00 6150.00 4904.95 38.79 4866.16 Pass: Major Risk PB L Pad L-102 L-102P61 V10 Out of range PB L Pad L-102 L-102P62 V2 Out of range PB L Pad L-103 L-103 V23 2700.00 4200.00 2672.04 40.31 2631.73 Pass: Major Risk PB L Pad L-104 L-104 V7 2700.00 5400.00 3887.69 37.54 3850.15 Pass: Major Risk PB L Pad L-105 L-105 V4 2700.00 3700.00 2050.31 37.44 2012.87 Pass: Major Risk PB L Pad L-106 L-106 V14 2700.00 3150.00 1221.57 36.06 1185.51 Pass: Major Risk PB L Pad L-107 L-107 V14 2700.00 4400.00 2837.78 40.08 2797.70 Pass: Major Risk PB L Pad L-108 L-108 V18 2700.00 3250.00 1266.65 38.48 1228.17 Pass: Major Risk PB L Pad L-109 L-109 V12 2710.52 3100.00 1134.17 40.55 1093.63 Pass: Major Risk PB L Pad L-110 L-110 V11 2724.93 3200.00 1277.78 43.03 1234.74 Pass: Major Risk PB L Pad L-111 L-111 V24 3875.46 3850.00 663.51 91.98 571.53 Pass: Major Risk PB L Pad L-112 L-112 V8 2760.07 2800.00 672.75 39.29 633.46 Pass: Major Risk PB L Pad L-114 L-114 V15 2749.99 2750.00 0.59 5.50 -4.91 FAIL: Minor 1/200 PB L Pad L-115 L-115 V7 2709.32 2800.00 605.49 42.03. 563.46 Pass: Major Risk PB L Pad L-116 L-116 V10 2739.08 2800.00 382.69 42.63 340.06 Pass: Major Risk PB L Pad L-117 L-117 V11 2706.70 3200.00 1483.17 43.32 1439.85 Pass: Major Risk PB L Pad L-118 L-118 V9 2700.00 3650.00 2108.71 41.66 2067.04 Pass: Major Risk PB L Pad L-119 L-119 V9 2700.00 3650.00 2083.68 41.90 2041.79 Pass: Major Risk PB L Pad L-120 L-120 V8 2700.00 4250.00 2835.42 40.36 2795.05 Pass: Major Risk PB L Pad L-121 L-121 V14 2702.84 3750.00 2209.53 45.41 2164.12 Pass: Major Risk PB L Pad L-121 L-121A V1 2702.84 3750.00 2209.53 45.29 2164.24 Pass: Major Risk PB L Pad L-122 L-122 V5 2821.47 2950.00 1197.14 40.36 1156.78 Pass: Major Risk PB L Pad L-124 L-124 V11 11699.53 3150.00 1553.33 127.08 1426.25 Pass: Major Risk PB L Pad L-124 L-124PB1 V5 11699.53 3150.00 1553.33 127.08 1426.25 Pass: Major Risk PB L Pad L-200 L-200 V7 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-200 L-200L1 V3 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-200 L-200L2 V6 2700.00 4350.00 3069.25 42.72 3026.52 Pass: Major Risk PB L Pad L-201 L-201 V6 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201L1 V9 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201 L1 P61 V10 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201 L2 V5 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major. Risk PB L Pad L-201 L-201 L3 V2 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201L3PB1 V6 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-201 L-201PB1 V12 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk • Schlumber er g Anticollision Report Companyc BP Amoco Date: 7/T9/2005 Time: 09:56:30 Page:' 2 Fields Prudhoe Bay -Reference Site: PB L Pad' Co-ordinate(NE) Reference: Well: L-114, True North Reference Vl'ell: L-114 Vertical (TVD) Reference: L-114A Plan 76.3 Reference WeDpath: Plan L-114A Db: -Sybase Summary <------- Offset Wellpath --------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area' Deviation "Warning" ~ ft ft ft ft ft PB L Pad L-201 L-201 P62 V3 2700.00 3550.00 2165.19 42.64 2122.56 Pass: Major Risk PB L Pad L-202 L-202 V5 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk PS L Pad L-202 L-202L1 V7 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk. PB L Pad L-202 L-202L2 V6 2713.02 3550.00 1916.83 43.35 1873.48 Pass: Major Risk PB L Pad L-202 L-202L3 V6 2713.02 3550.00 1916.83 43.36 1873.47 Pass: Major Risk PB L Pad L-210 L-210 V6 Out of range PB L Pad L-210 L-210PB1 V8 2700.00 10000.00 8833.19 41.16 8792.03 Pass: Major Risk PB L Pad L-211 L-211 V6 2741.59 3500.00 1946.11 43.03 1903.08 Pass: Major Risk PB L Pad L-211 L-211 P61 V6 2741.59 3500.00 1946.11 43.03 1903.08 Pass: Major Risk PB L Pad L-212 L-212 V11 2712.68 3850.00 2442.09 44.32 2397.77 Pass: Major Risk PB L Pad L-212 L-212P61 V9 Out of range PB L Pad L-212 L-212P62 V2 2713.45 3850.00 2445.60 44.38 2401.22 Pass: Major Risk PB L Pad L-214 L-214 V9 2700.00 7300.00 6221.53 39.91 6181.62 Pass: Major Risk PB L Pad L-216 L-216 V6 2700.00 4800.00 3595.94 41.86 3554.08 Pass: Major Risk PB L Pad NWE1-01 L-100 V2 2745.92 2850.00 992.38 48.49 943.89 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 2745.92 2850.00 992.38 48.49 943.89 Pass: Major Risk PB L Pad Plan L-03 (S-O) Plan L-03 V4 Plan: Pla 2700.00 4250.00 2489.56 38.42 2451.14 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123 V4 Plan: PI 2700.00 4800.00 3453.83 41.36 3412.47 Pass: Major Risk PB L Pad Plan L-123 (S-U) Plan L-123PB1 V2 Plan: 2700.00 4800.00 3453.83 41.29 3412.55 Pass: Major Risk PB L Pad Plan L-203 (N-O) Plan L-203 V6 Plan: PI 2700.00 3400.00 1566.01 42.43 1523.58 Pass: Major Risk PB L Pad Plan L-213 (S-B) Plan L-213 V5 Plan: PI 2700.00 5900.00 4552.46 39.15 4513.31 Pass: Major Risk PB L Pad Plan L-215 Plan L-215 V2 Plan: PI 2700.00 8800.00 7729.23 43.02 7686.21 Pass: Major Risk PB L Pad Plan L-215 Plan L-215P61 V2 Plan: Out of range PB L Pad Plan L-218 (N-B) Plan L-218 V2 Plan: PI 2722.57 3300.00 1541.11 41.87 1499.24 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250 V1 Plan: PI 2700.00 3450.00 1922.37 44.75 1877.62 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250L1 V5 Plan: 2700.00 3450.00 1922.37 44.77 1877.61 Pass: Major Risk PB L Pad Plan L-50 Plan L-50 V1 Plan: Pla 2722.54 2900.00 692.38 38.34 654.05 Pass: Major Risk Field: Prudhoe Bay Site: PB L Pad Well: L-114 Wellpath: Plan L-114A Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre [o Cenre Separation [SOR/in] • Site: PB L Pad Drilling Target Conf.: 95% Description: Map Northing: 5978600.00 ft Map Easting :578765.00 ft Latitude: 70°21'05.885N Shape: Circle Target: L-114A Tgt 1 • Well: L-I l4 Based on: Planned Program Vertical Depth: 6540.00 ft below Mean Sea Level Local +N/-S: 581.25 ft Local +E/-W: -4301.46 ft Longitude: 149°21'3 7.707 W Radius: 150 ft 800 800 X00 600 500 4-00 r~ 0 0 0 0 ~ o D D ~ ~ ~ o ,~ ,~ ~ ~ ~ 0 ~ 0 0 0 0 0 0 - o ~ ~ ~ goo 0 m TREE= 3-1/8" 5MCIW WELLHE4D= 11" FMC ACTUATOR = KB. ~El/ = 76.3' BF. B_EV = 49.4' KOP= 1591' Max An le = 55 4052' Datum MD = 7780' Datum N D = 6600' SS -5/8" CSG, 29.7#, L-80, ID = 6.875" ~-{ 2637' Minimum ID = 2.75" @ 2193' 3-1 /2" HES SSSVN PERFORATION SUMM4RY REF LOG: ANGLEATTOPPERF: 15 @ 7704' Note: Refer to PI'oduction OB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2-1 /2" 6 7704 - 7750 0 09/13/01 5-1/2" CSG, 15.5#, L-80, BTC, ID= 4.950" ~ -- ~ 7425' 3-112" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 7431' 5-1/2" X 3-1/2" CSG XO, ID = 2.968" 7438' L -114 / SAFETY NOTES: 981' H7-5/s° I 2193' H3-1/2" HES xD6 BVN, ID =2.75" GA S LIFT MA NDRELS ST MD N D DEV N PE V LV LATCH PORE DATE 4 3695 3423 49 KBG-2 DOME BL 16 05/28/03 3 6246 5226 37 KBG-2 SO BL 20 05/14/03 2 7234 6084 24 KBG-2 DMY BL - 08/17/01 1 7353 6194 21 KBG-2 DMY BL - 10111!01 7379' ~--~ 3-1 /2" HES X NP, ID = 2.75" 7425' TOP OF BKR PBR, ID = 4.00" 7442' ~--~3-1/2"BKR SEAL ASSY,D=3.00" 7489' 3-1/2" HES X NP, ID=2.75" 7509' 3-1/2" HES X NP, ID=2.75" 7551' 20' Ft1P JT W / RA TAG 8146' H 10' FUP JT W / RA TAG PBTD 3-1 (2" CSG, 9.2#, L-80, NSCT, ID = 2.992" 8158' 8253' ~ DATE REV BY COMMENTS DATE REV BY COMMBVTS 08/17/01 CH/KAK ORIGINAL COMPLETION 09!13/01 CWS/KK FERFS 12/30/02 DAGKK GLV CORRECTIONS 04/08/03 DRS~TP ND'MDCORRECTIONS 05/15/03 JCMTLH GLV C/O 05/28/03 MWTLP GLV C/O BORE4LIS UNff WELL• L-114 PERMIT No: 2011360 API No: 50-029-23032 S~ 34, T12N R11 E 2346' NSL & 3844' WEL BP Exploration (Alaska) Borealis L-114A: Proposed Completion TREE 31/B" - 5M CIW L-80 WELLHEAD: 11"- SM FMC G5 1808' Top of Kick-Off Cement 2537` 7-5/8", 29.7 #/ft, L-80, BTC ~ 5-1/2", 15.5 # - EZSV 2770` 5-1 /2", 15.5 #!ft, L-80, BTC-Mad 3-1/2"'X' Landing Nipple 7379' Top of P8A Cement 7420` 5-1/2"x3-112" XO above Kuparuk 7437' L-114 Perfs @ 7704`-7750' MD 3-1/2"'X' Landing Nipple 74$g` 3-112"'X' Landing Nipple 7509' Plug Back Depth 81 ~~ 8253`I 3-1/2", 9.2 #/ft, L~O,IBT Mod y` IO U / kl4F~- Proposed Top of Cement ~ Date Rev By Comments 14-Jun-05 MJM Proposed Seal Bore Completion - WP3 Cellar Elevation = 47.80' RKB - MSL = 76.30' -1/2"'X' Landing Nipple with 2.813" seal bore. 3-12° x 1.5" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS # MD/TVD Size Vale Type 7 2014' / 2000' 3.5" x 1" DK-1/Bottom Latch 6 2639' / 2600' 3.5" x 1" DK-1/Bottom Latch 5 3635' / 3400' 3.5" x 1" DK-1/Bottom Latch 4 4954' / 4100' 3.5" x 1" DK-11Bottom Latch 3 6277' / 4800' 3.5" x 1" DK-1/Bottom Latch 2 7434' / 5500' 3.5" x 1" DK-1/Bottom Latch 1 ? / ?' 3.5" x 1" DCK-3/Bottom Latch 5-1 /2", 17 #/ft, L-80, BTC-M 3-12' 92# IBT Mod L-80, Tubing 3-12" 'X' Landing Nipple with 2.813" seal bore, l jt above PBR 3-1/2" Seal Asembly PBR 17' w! 4 Seal Sections (4.0" OD, 3.0" ID) S-1l2"x3-12" XO placed above Kuparuk 3-12"X' Landing Nipple with 2.813" seal bore ID 3-12"X'Landing Nipple w/ 2.813" sealbore ID.+/- 150• above Kupanik RA Tag (only 1 pip) in 10' x 3.5" pup at TKC4 3-1/2", 9.2 #/ft, L-80,IBT Mod Borealis WELL: L-114A API NO: 50-029-23032-01 BP Alaska Drilling ~ Wells TERt~IE L RUBBLE ss-si,zsz 213 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 j ANCHORAGE, AK 99519'-6612 DATE ''/ PAY TO THE ~~ ~ '/'y1. W ORDER OF ~/[~~~''''~~ V(J ~W DOLLARS First National Bank Alaska .Anchorage, AK 99501 MEMO ~--~ I i ~(~ ~ ~:L25200060~:99L4~~~6227~~~L556~~' 0213 .w ~ ~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~"~J~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to 6e reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) .assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, BOREALIS OIL-640130 Well Name: PRUDHOE BAY UN BORE L-114A Program DEV Well bore seg ^ PTD#:2051120 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV / 1-OIL GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal ^ Administration 1 Permitfeeattached________-_______________________ ___--___ Yes-__-__ ____--____--_____.--___-_-___ --------------------------------------- 2 Lease number appropriate - - - - Yes - - - - - - 3 Uniquewelfnameandnumber_____________________________ _________ Yes_____._ - 4 Well located in a-defnedpool______________----____- -___ -.-_-__-. Yes--_____ -.--._ - - - 5 Well located proper distancef[o-m drilling unitboundary--------------- --------- Yes---:-_ -..--__----___-.----..-__-----__-_--_.-___-.---_-.___.__.--_-. 6 Well located p[operdistance_fromotherwells____________________ ________ Yes-___- --___-______-_-___--_____--_----_-__--_ ---------------------------- 7 Sufficient acreageayail_ablein_drillinqun~__------------------ --._ ---- Yes------- -------------------------------------------------------------__---- 8 If_deviated, is-wellbore plat included - - - - - - - YeS - - - - - - - - - - - . 9 Operator ogly affected party- - - - - - - - - - - Yes - - - - - - - - - - - 10 Operatorhas.appropr#atebondinforce------ ------- ------- ----..-- Yes.---- - -- -- ---------- ---------...-- --~---------------- ------- -- ~- 11 Permit can be issued without conservation order-________________ __---____ Yes_____-_ __---___-______--______--___-__---______--__-----_-,__--__--_---- Appr Date 12 Permitcan be #ssued without administrativ_e_appr_oyal - - . - _ - _ . - - - - - Yes - - _ - - - . - - - _ - RPC 7128/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_s#rataauthprizedf~y_IpjectionO[de[#(putlp#in_co mments)_(For- NA-____--- _-_______________________________________--__--_--__--_--_- __-- 15 All wells-within114_milearea_ofreyiew)dentifled(Fprsen!icewellonly)______ _________ NA-____-_- _._..-___._____..______-______- ----------------------------------- 16 Pre-produced injector: duration of pre production less than_ 3 months_(For service well only) NA_ - - - - - - - 17 AC_M_P-Finding of Consistency_h_asbee_nissued-forthisproject--- ------- --------- NA__---___ _---__ __--__--_-_-__----__-__-__-----_---_--__--_---_-__--__---_-. Engineering 18 Condu_ctorstring_provided___________________--_____--__ __---___- NA___--___ _-_--____--_____-___-.___ 19 Surface-casing-protect&ail_knownUSDWs - - - NA - - - -- 2D CMT_vol-adequate-tocircul_ate-oncgnductor_&surf-csg--.___.___ -__..- NA________ _______________________________________--___. - - 21 CMT_vol_adequate_totie-in long string to surfcsg_-____--______-___ ______-- No_______ __________________ _________-.-___-- -- 22 _C_MT_will coverall known-productive horizons- _ _ - . _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ _ - _ _ _ 23 CasingdesynsadequateforG,TB&_permafr_ost-.______________ ____.-._ Yes-_____- .____-____-_- __-.-____.____ 24 Adequate tankage_or reserve pit - - - - - Yes - Nabors_9_ES, - - - - - - - 25 Ifa-re-drill,has_a.10-403 for abandonment beenapprcved__.-________ _________ Yes____.-_ 7113!2005.____---___-_ ___-,_____---_-__--___--__-_---__ __-____---- -- 26 Adequatewellboreseparation_proposed____________________--_ __-__,___ Yes--_.--- -.._._ ------------------------------------------------------------- 27 Ifdive[terrequiretl,doesitmeetregulations______________________ _________ NA--______ Sidetrack.---___----__-.-___-_--__--_--__-_--__---_-----__-__--------_ Appr Date 28 Drillingfluid_programschematic&equiplistadequate_--_ __-._____ -____,--_ Yes.-____- Max MW-10,Qppg.__-__..__.__ ..-___-------------- _.-___..__.- WGA 7128/2005 29 BOPEs,_tlotheymeetregulation____________________________ ________ Yes__--_ __-_-___________- 30 BOPE_pressratingapp[op[rate;testto_(putpsigincomments)___________ ____._-- Yes-____- Test to3500-psi._MSP2714psi..--__-___-----__--__-__---__---__-__-_--_- 31 Choke-manifold compliesw/APfRP-53 (May84)________ __________ _________ Yes-____-_ -____--____-.- - - 32 Work willoccurwithoutoperationshutdown---------------------- -------- Yes--_____ -____--_____--___-_- 33 Is presence-ofH2Sgas-probable--------------------------- ----.--- N°--- NotanH2$pad._--___--___--___---__----------------------- 34 Mecha_nical_condition of wells within AOR yedfied (For service well Doty) - _ _ - . - . NA_ _ _ - - _ - - - - - Geology 35 Permit_can be issued wlo, hyd[ogen_sulfide measu[es _ - - _ _ - _ - . No_ _ _ _ - _ 36 Data_presentedon_poten#ialoverpressur_ezones__________________ -____,--- NA-_-___- _-_-___-____-_---__-.-_ - - - - Appr Date 37 SeismicanaNsis_ofshallowgas_zones_---___-_- ~ - NA - _---------------____--_--__-_--__--__---_ RPC 7128!2005 38 Seabed conditionsurvey,(ifoff-shore)_______________----_____ -___--_- _N_A_--___-_ _-___-__-__-_____-- - - - 39 _ Contact name/phone_forweeklyprDgress-reports [exploratory only]_ _ - - _ - NA_ - _ Geologic Engineering P blic Commissioner: s Date: Commissioner: Date er ~ ~ ~~S ~ Date ~ -~ g - ~ ~~ ~ ~ ~~ I o s •