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Home My WebLink About185-001 • 26C413 ■am gxie.23Zdl. BAKER PRINT DISTRIBUTION LIST HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED t /216/2014 WELL NAME L1-09 900 E.Benson Blvd. M. K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE October 19,2015 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhucihes.com TODAYS DATE December 21,2015 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #tit-VilIN I a #OF COPIES #OF COPIES #OF COPIES V 1 BP North Slope. 0 I 1 0 I 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 I 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 SCANNED IL'; 2 2016: 3 ExxonMobil,Alaska 0 I 1 I 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 41State of Alaska -AOGCC 0 1 I 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 I 1 0 I 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 I 1 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Behrooz Raessi TOTALS FOR THIS PAGE: 0 6 5 0 0 TOTALS FOR ALL PAGES: 0 6 5 0 0 bp Date 20-MAY-2015 Transmittal Number: 93426 BPXA WELL DATA TRANSMITTAL RECEIVED Enclosed are the materials listed below. MAY 20 2015 (BPXA LOG DATA) AOGCC If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 04-21, 04-22, 04-33, C-01, C-31, L1-09, L2-03, L3-15, L3-31, L4-30, L5-01, L5-15, L5-16A, L5-16AL1, L5-16AL2, L5-31, L5-33, L5-36 04-21 185-212 251 A c) ---Csky,--Or 04-22 185-233 a 53 45' 04-33 186-035 .2544.(0° Please Sign and Return ne copy of this transmittal to; C-01 172-030 .2544I C-31 188-006 25-7q5 gancpdc@bp.conL1-09 185-001 ,254y9 �L2-03 185-247 25750• Doug j750- Doug Dortch L3-15 185-266 0251.51 Petrotechnical Data Center L3-31 186-034 ,253'1/5L L4-30 188-101 25753. L5-01 189-009 251-51-1• Attn: State of Alaska - AOGCC L5-15 188-109 .25155 Attn: Makana Bender ��A NNED MAY 2 1 20 5 L5-16A 206-083 25-4.5‘„• 333 W. 7th Ave, Suite 100 SCA L5-16A L1 206-084 25167- Anchorage, Alaska 99501 L5-16A L2 206-085 2615(6, L5-31 190-130 2515/ L5-33 189-047 2.S%o L5-36 189-036 25 x(01 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 C--4 i) m - l 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 es 000000000000000000000 a 1/4.• 71 v H ✓ r, • a U > .L:. Z_ r r r r O ✓ m O d - 0 Y z E--, a l'.: ti n vi v �1 i i a m 0Z r r .- 3 c O KA V V .\ E (1 CJ L. N N N N N N N N N N N N N " N " N N O N N '�; 0 (� N m L O �� W 3 3 3 C 3 3 3 � C j 3 j 3 j 3 3 co 3 3 v Li-) p t co: Q� to N O p) N M O M M OaO) CO 0 O) at 41 U C Cr: N ,. N NaaN NN a- ft' i� X a O Q F-i Zi j J U N Z F- H H Z cc • p O O O OO O - o O c7 W 0 0 LL10 0 W 1-..- z n- w - p w cx: U u. 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Q W( • N d 110 3 l0 —Ic N ..Lo Q V€ o M N ii I— w Z Q X X X X X x X X X X X X x X X X x X X X X a cQc o In E cd GD J i, to CO O O ap W CO CO 'f) N Caa ' N N M a- (D CO tO N 6) W W O) M Tr d' O cc H ,z W 0 0 0 0 •- 0 0 0 1- 0 c) ' O O O T '� 1:1 "'i'I O, O O O 0 O O O O O O O Q O C O O O O r O 0 7 0 0 0 0 0 ' 0 ,- U d U fn fn 0 7- -) 7 u N n D O O O X X X = 7 co co a: CO m m r: • p m m CO ttoo 0 CO 0 0 0 0 m 0 m m m m m Q Q a] CO CO c o a' cl- a; o O o i N Lii N '� > 01 Q v) 1� U co El al to is N O „Ma g • C e-1 C a CD m Q �' W m U m U N Q Q Q m m rn N m Q CD Q ' N 0 v W > A 4i 6t N O O N p O M Cs/ 0 0 0 N O O N �- N N N r v CC C to N a cc 'a = _Z m E w Z U' W O Y > N r o = a- d C 0- J J ® opo U N a u m p .0 -� O Q L.- �^ d L a y cu n= N V J d 4 O C Q y ▪ N Q Ca 5 Ln c el I X d m Q1 Q V) t_ - 1 10/26/10 Schiumherger NO. 5628 Alaska Data & Consulting Services Company State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 11 -04A BCZ2 -00022 RST 09/06/10 1 1 F -478 BCUE -00038 MCNL 08104/10 1 1 F -048 AZ2R00061 MCNL 08/20/10 1 1 15-308 SAUJ -00026 MCNL 05/30/10 1 1 L1 -09 BBSK -00027 RST 08/24110 1 1 D5-33A BCRD -00037 CH EDIT P -GR SIT 07/27/10 1 13 -21A BD88 -00038 CH EDIT PDC -GR GR -CCL 08/31/10 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • °ti t1t1 !,O Schtumberger Alaska Data 8 Consulting Services 2525 Gambell Sireet, Suile 400 Mchofage,AK 99503-2B3B RTTN: Beth Well Job M ~~a~1 ~g l,a~ ~ Log Description Date BL NO. 5353 Compa~y: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD osii vos V-02 W-26A H•32 B2WY-00018 81 JJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ' - MEM PRODUCTION PROFILE ~ - PRODUCTION PROFILE ~ L- 07127/09 07/26/09 07/25/09 1 1 1 1 1 1 P2-29 L2-11 L2-06 AYTU-00052 ANHY-00106 B69K-00007 INJECTION PROPILE ~ ~'7 _~ LDL CROSS FL W CHECK ~ - 08/02I09 08/02/09 07/31/09 1 1 1 1 1 1 P2-28 L-273 V-221 AYTlh00051 82WY-00019 AX80.00037 INJECTION PROFILE C, -~ MEMINJECTIONPROFI E' - MEM INJECTION PRpFILE' - 08/01/09 07/29/09 07/28/09 1 1 1 1 7 ~ L-220 07-22 04-02A B7 JJ-00035 AZCM-00036 AYS4-00091 MEM INJECTION PROFILE ~ - PRODUCTION PROPILE - - ~ USIT - 07/30/09 08/09/09 OB/11/09 1 1 / 7 1 1 J•11A 17-09 X-28 AWLB-00029 AVS4-00089 AXBP00026 USIT - PRODU TION PROFILE '~ (p MEM INJECTION PROFILE U - OB/OS/09 08/08/09 05/17/09 1 1 1 1 1 1 L2-06 3-29/J-32 06-04A B3S0-00020 AP3Q-00055 85JN-00009 PRODUCTION PROPILE - IBP SET RECOflO W/CROSSGLOW , - RST 08/14/09 OB/08/09 08/23l09 1 1 1~ ~ ~ 7 15-49B B2NJ-00013 MCNL - 07l15/09 1 7 03-328 08AKA0030 OHMWD/LWDEDIT 02/28/09 2 7 G-148 AWJI-00043 MCNL 07/24/09 1 1 12-13A AWJI-00036 MCNL OW77/09 ~ 18-028 AWJI-00045 MCNL q- ' ~ pg/~~~Qg ~ ~ P1-05 AWLB-00032 RST OB/09/09 1 ~ 8-16A 82WY-00020 MCNL ' - ' 08/03/09 1 ~ J-208 AJ(80.00020 MCNI (REVISED) ~ ;"L OM12/09 ~ PLEASE ACKNOWI. Fn[:F acr c~ar wv cir_uiu r eun ocri ~or.uur_ .,.~~ .....,.. ~.......... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~,.;; ~ x6 <rr t, ,., ~,~.. ~ .- ~ ~ Alaska Data & Consulting Services 2525 Gambell Slreet, Suhe 400 Anchora9e, AK 99503-2838 • • J~ n.~ ;~,~ ,:, `~~ n u r~ ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv nnPCtinnc nleaca rnntart Tna T actnf~ro o* !~!1'7lGti~t illlllt Date t2-16-2008 Transmittal Number:93026 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion PRODUCTION PROFILE L3-23 09-08-2008 HALLIBURTON 1 10964 11476 WITH MAPS CD-ROM -PRODUCTION L3-23 09-08-2008 HALLIBURTON PROFILE W ITH MAPS PRODUCTION PROFILE L1-09 10-20-2008 HALLIBURTON 1 11016 11869 WITH MAPS CD-ROM -PRODUCTION 1-09 10-20-2008 HALLIBURTON PROFILE WITH MAPS PRODUCTION PROFILE L5-36 09-12-2008 HALLIBURTON 1 11748 12120 WITH MAPS CD-ROM -PRODUCTION L5-36 09-12-2008 HALLIBURTON PROFILE WITH MAPS PRODUCTION PROFILE L5-32 09-09-2008 HALLIBURTON 1 0 9615 WITH MAPS CD-ROM -PRODUCTION L5-32 09-09-2008 HALLIBURTON PROFILE WITH MAPS PRODUCTION PROFILE L5-24 12-05-2008 HALLIBURTON 1 10110 10640 WITH MAPS CD-ROM -PRODUCTION L5-24 12-05-2008 HALLIBURTON PROFILE WITH MAPS ~, ~ ~ J ,t i'/~__ Please Sign and Return one copy of this transmittal Thank You, Joe Lastufka Petrotechnical Data Center BPXA Exxon DNR AOGCC 1~~~r.~~ 1-~~~~~ Analisa Clo ton P File Room Kristin Dirks Christine Mahnken Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 ~~ Anchorage, AK 99519-6612 . . _ rj ~`M1 STATE OF ALASKA M.~,„ ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS ~ ~ ~ 2008 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 185-001 , 3. Address: ^ Service ^ Stratigraphic 6. API Number: P,O. Box 196612, Anchorage, Alaska 99519-6612 51T-029-21265-00-00~ 7. KB Elevation (ft): 44, , 9. Well Name and Number: PBU L1-09 - 8. Property Designation: 10. Field /Pool(s): ADL 028302 ~ Prudhoe Bay Field / Lisburne Pool 11. Present well condition summary Total depth: measured 14136' - feet true vertical 10414' - feet Plugs (measured) None Effective depth: measured 11900' feet Junk (measured) None true vertical 9158' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4002' 13-3/8" 4002' 3997' 4930 2670 Intermediate 11095' 9-5/8" 11095' 8741' 6870 4760 Production Liner 3009' 7" 9591' - 12600' 7810' - 9467' 8160 7020 Liner 1706' 5" 12430' - 14136' 9399' - 10414' Liner Tieback 2971' 9-5/8" 2971' 2971' 6870 4760 AAyy Perforation Depth MD (ft): 11258' - 11848'- '`~~ Perforation Depth TVD (ft): 8828' - 9131' ` 3-1/2", 9.2# 13Cr-80 11209' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer 11067' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pull tubing. Cut and pu119-5/8" casing from 2968'. Run 9-5/8" (47#, L-80, Hydril 563) tieback to surface. Cement w/ 194 bbls Class 'G' 1089 cu ft / 939 sx . Clean out and run new Chrome tubin . 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: 0 0 0 20 0 Subsequent to operation: 2165 1753 1618 1820 975 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 Hank Baca, 564-5444 308-198 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si nature Phone 564-5743 Date~l~'" ~ ~"~ d Sondra Stewman, 564-4750 Form 10-404 Revised 0412006 e~ ~~LL ski' ! n ZUUtI Submit Original Only ~~~~ TREE = 4-1/16" CNV WELLHEAD= FMC ACTUATOR= BAKER KB. ELEV = 44' BF. ELEV = KOP = 4000' Max Angle = 67 @ 12600' Datum MD = 11,289' Datum TV D = 8900' SS DRAG DRAFT Csg Patch wt new 9-5/8", 47#, L-80 Csg 2,$71 13-3/8" CSG, 72#, K-55, BTC, ID = 12.415" 4002' (JOINTS #1 & #1 = 88#, BTC, ID =12.347") TOP OF 7" LNR 9591' 7" LNR, 29#, L-80, BTC, .0371 bpf, ID = 6.184" ~-i 10788' 9-5/8" CSG, 47#, L-80, BTC, ID = 8.681" ~--~ 11095' 3-1J2" VamTop TBG, 9.2#, 13Cr-80, ID = 2.992" I-i 11.208' TOP OF 5" LNR ~-~ 12430' 7" LNR, 29#, L-80, BTC, .0371 bpf, ID = 6.184" 11 12600, PBTD 14019' 5" LNR, 17.9#, SS95, FL4S, .0178 bpf, ID = 4.276" 14136' L ~ -O ~ AFETY NOTES : ***3-1 (2" CHROME TBG*** XXO SVLN IS A SINGLE CONTROL LINE NIPPLE 2206' 3-112" XXO SVLN; 2.$13" ID ', G ~ _. GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4331 4314 21 MMG DOME RK 16 07!17/08 2 6809 5995 54 MMG SO RK 20 07117/08 3 8466 6997 48 MMG DMY RK 0 47/09f08 4 9496 7739 42 MMG DMY RK 0 07/09108 5 10965 8670 58 MMG DMY RK 0 07/09148 9591' ~-~ 7" x 5" LNR TOP PKR, ID = 7.50" 10788' ~-~ 7" TIEBACK SLV w! HYDRO HGR, ID = 7.50" 11,034 ~-13-112" "X" Nipple, 2.813" ID. 11,067 -Baker 4-1/2" x 7", S-3 PKR 11,103 3-1/2" "X" Nipple, 2.813" ID. 11,196 3-112" "XN" Nipple, 2.75" ID. 11,207 ~3-,1-12" WLEG 11285' ~~ ivwRKERJOiNr Of Sand{Fill DATE REV BY COMMENTS DATE REV BY COMMENTS 04/18/85 ORIGINAL COMPLETION 07/09/08 DOYON 16 RWO 01/03/94 N2ES RWO 07/13/08 /TLH CORRECTIONS 04/11/07 DRS/PJC TBG, CSG, TD CORRECTIONS 07/19/08 BSE/SV GLV GO (07/17/08) & CORR 05/05/07 SWGPA GLV GO (05/03/07) 07/22!07 DMS/PJC 20/40 SAND DUMP (07/07/07) 11/17/07 JN/PJC 7" LNR/SAND DEPTH CORRECTIONS 15" BKR MC HYDRAULIC HGR, ID = 4.25" LISBURNE WELL: L1-09 PERMIT No:1850010 API No: 50-029-21265-00 SEC 1, T11N, R14E, 2448' FWL & 2183' FSL BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: LDT/CNL ON 03/10/85 ANGLEATTOPPERF: 64 @ 11258' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA r: PERFORATION SUMMARY REF LOG: LDT/CNL ON 03/10/85 ANGLE AT TOP PERF: 64 @ 11258' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 11258 - 11278 O 01/15/86 4" 4 11292 - 11328 O 01/15/86 4" 4 11334 - 11378 O 01/15/86 4" 4 11393 - 11401 O 01/15/86 4" 4 11407 - 11415 O 01/15/86 4" 4 11442 - 11462 O 01/15/86 4" 4 11471 - 11478 O 01/15/86 4" 4 11506- 11514 O 01/15/86 4" 4 11521 - 11542 O 01/15/86 4" 4 11548 - 11563 O 01/15/86 4" 4 11568 - 11572 O 01/15/86 4" 4 11576- 11612 O 01/15/86 4" 4 11621 - 11628 O 01/15/86 4" 4 11633- 11646 O 01/15/86 4" 4 11681 - 11696 O 01/15/86 4" 4 11706- 11712 O 01/15/86 4" 4 11730- 11760 O 01/15/86 4" 4 11770 - 11780 O 01/15/86 4" 4 11818 - 11830 S 02/27/89 4" 4 11838 - 11848 O 01/15/86 4" 8 12966 - 12972 C 01/15/86 4" 8 12998 - 13008 C 01/15/86 4" 8 13066 - 13126 C 01/15/86 4" 8 13246 - 13254 C 01/15/86 4" 8 13270 - 13280 C 01/15/86 4" 8 13395 - 13425 C 01/15/86 2-1/8" 4 13484 - 13530 S 05/14/85 4" 8 13507 - 13530 C 01/15/86 • DATE REV BY COMMENTS DATE REV BY COMMENTS 04/18!85 ORIGINAL COMPLETION 07/09/08 DOYON 18 RWO 01/03/94 N2ES RWO 07/13/08 /TLH CORRECTIONS 04/11/07 DRS/PJC TBG, CSG, TD CORRECTIONS 07/19/08 BSE/SV GLV GO (07/17/08) & CORR 05/05/07 SWGPA GLV GO (05/03/07) 07!22/07 DMS/PJC 20/40 SAND DUMP (07/07/07) 11/17/07 JI~I/PJC 7" LNR/SAND DEPTH CORRECTIONS LISBURNE WELL: L1-09 PERMfT No: 1850010 API No: 50-029-21265-00 SEC 1, T11 N, R14E, 2448' FWL & 2183' FSL BP F~cploration (Alaska) L1-09 ~ i PBU L1-09 Well History Date Summary 5/27/2008 T/1/0=150/980/400 Temp=S/I MIT OA PASSED to 2000 PSI (RWO prep)Pumped 10.7 bbls 30* diesel to test. 1st 15 min loss of 120 PSI & 2nd 15 min loss of 40 PSI for a total loss of 160 PSI in 30 min Bled OAP to 300 PS (3bbls)FWHP's=150/980/300 Annulus casing valves tagged & open 6/13/2008 T/I/O=NA/1000/550, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (500 psi), bled to 0 psi. Function LDS (ET style), all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Function LDS (standard), all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. CTU #9 Swap Pipe from 1.75" to 1.50" CT. 6/14/2008 CTU # 9 w 1.50" CT, (job scope; cleanout sand plug) Rig up/ safety meeting.. Perform BOP test. MU & RIH BHA with 1.50" OD BDN. Had a spill from kelly hose from the tank manifold to the tanks, all was contained in the spill containment. notified all parties. 6/15/2008 CTU # 9 w/ 1.50" CT 9 (cleanout sand plug), Job continued from 06/14/08: POOH after not being able to pass by the GLM at 5252', CTM 5238'. Bend pipe and RBIH. tapped Top of Sand at 11272' CTM. No cleanout necessary. POOH. Freeze protect well to 2500 ft. 6/16/2008 RAN CAMCO LOCK OUT TOOL, LOCK OUT TRSSSV ~ 2039' SLM,RAN 2.72" CENT, S-BAILER TO 10822' SLM, (sample of plastic coating) BAILING IN PROGRESS RECOVERED 4 CUPS PLASTIC COATING 6/17/2008 RU ELINE TO SET HES FASDRILL AT 10,976 FTMID-ELEMENT. RAN 2.35 G-RING TO TOP OF PATCH C~3 10926'SLM GUAGE RING HAD METAL MARKS INDICATING WE WERE AT THE PATCH 6/18/2008 Set HES FasDrill at 10976' MD. Waited for IA to bleed down. LRS PT HES FasDrill to 3500 PSI pt failed. T/I/0=850/1180/340 Assist E-line w/CMIT-TxIA to 3500 psi ****FAIL****/LLR (Pre RWO) Bled gas off IA. Pumped 3 bbl neat meth spear & 275 bbls DSL down TBG for CMIT. Ran out of fluid before reaching pressure. Bleed gas off IA. Pumped 77 bbls crude down TBG to reach 3500 psi for CMIT-TxIA. On 3rd test, T/IA lost 800/740 psi in 1st 15 min. Fail. (Pumped 22 bbls crude down TBG to establish LLR = .45 bpm ~ (T/I/O) 3200/3460/730 psi for 25 min) 6/19/2008 SHUT IN ON ARRIVAL. INITIAL T/ t/ O = 900/1200/350. SET HES FASDRILL AT 10976' MD LRS PT HES FASDRILL TO 3500 PSI PT FAILED RIGGING UP FOR LDL. CONFIRM LEAK AT GLM 2 8506 FT. PROCEED WITH 2.5 IN JET CUT AT 10,928 FT. JET CUT FIRED. FINAL T/I/O = 700/1240/450 PSI. T/I/0=0/0/360. Temp=Sl. Assist LRS w/Circ out. (Pre-RWO). LRS pumping Circ-out_and fluid started comminq out of conductor. Vac truck on location to vac fluids from conductor during pump job. Fluid sample taken from conductor. Fluid in the conductor rose 36" in 1 hour with the OAP ~ 65 psi. Bled OAP from 370 psi to 13 psi in 8 hours 30 minutes. Fluid in the conductor still rising. Change out with day crew. Final WHP's=0/0/13. 6/20/2008 Circ. Out (Pre RWO) Pumped 180 bbls DSL down IA for FP. U-tube from IA to TBG. Pumped 23 bbls DSL down FL for FP. Hardline crew still on well. DHD still bleeding OAP & monitoring conductor fluid. Contacted DSO on valve position & well condition. T/I/0=0/0/6. Temp=Sl. Bleed OA to 0 psi (possible SC leak to conductor). ** Continued from night shift. ** Bled OAP from 6 psi to 0 psi in 5 hrs, 30 mins (all gas). WIE called for MITOA to 2000 psi. Pumped 15 bbls diesel to pressure OA to 500 psi in 100 psi increments. ** Note: Conductor fluid continued to inflow w/OAP ~ 0 psi and during subsequent testing. MITOA to 500 psi passed on 3rd attempt. OAP decreased 10 psi in 1st 15 mins, 10 psi in 2nd 15 mins. MITOA PASSED to 2000 psi. IAP decreased 30 psi in 1st 15 mins, 10 psi in 2nd 15 mins for a total of 40 psi in 30 mins. Bled OAP back to 0+ psi (140 gals returns). Final T/I/0=0/0/0+. • • PBU L1-09 Well History Date Summary 6/21/2008 T/I/0=0/0/0; Set 4-1/16" FMC ISA BPV #511 for Doyon 16 pre-rig; 1-2' ext, used, tagged C~3 102". 6/22/2008 T/I/O=Vac/Vac/0. Rolled 2-1/16" I/A and 3-1/8" O/A to back side of well, pre-rig. 6/23/2008 T/I/O=Vac/Vac/0. Pull 5-1/16 ISA BPV #511 thru tree, rig move over well. 1-2' ext used, tagged C~ 102". No problems. 6/24/2008 T/I/0=0/0/0; Pull 4-1/16" FMC ISA BPV Thru Stack For Doyon 16; 2-5' & 1-2' Ext & 5' Cenralizer Used, Tagged C~ 72" 7/5/2008 T/I/0= 0/0/0. Temp= SI. IA FL (RWO). IA FL ~ 42' (7:30 am). IA FL ~ 1450' (10:00 am). 7/7/2008 TIO= NA/0/0. SI. IA FL's for Dovon 16. IA FL ~ 426' ~ 11:50 om, Rig to circulate more fluid, stand by for IA FL. 2nd IA FL inconclusive, 3rd IA FL ~ 990' ~ 0130 hrs. 4th IA FL C~3 930' C~ 0200 hrs. 5th IA FL ~ 1152' ~ . 0500 hrs. 7/8/2008 T/I/0=200/0/0. Pulled 4" CIW BPV thru tree with 1 - 2' ext. at 102". No problems. 7/9/2008 T/I/0=0/0/0. Set 4" CIW BPV thru tree with 1 - 2' ext. at 102". No problems.For Rig, Doyan 16. 7/12/2008 Install 2 1/16" FMC 120 I/A on front of wellhead. roll 3 1/8 Mcevoy O/A to front of wellhead 7/14/2008 T/I/0=0/0/0. Pull 4-1/8" CIW "H" BPV #144 thru tree, post rig. 1-2' ext used, tagged ~ 100". No problems. 7/15/2008 PULL DSSSV FROM 2187' SLM PULL BALL & ROD FROM 11170' SLM PART WIRE PULLING DGLV FROM STA# 2 7/16/2008 FISH TOOLSTRING FROM 11098' SLM RECOVER DROPPED GLV FROM 3 1/2" RHC-M C~ 11180' SLM PULL RK-DCR VLV FROM STA#1 C~ 4331' MD 7/17/2008 SET RK-DOME VLV IN STA#1 C~3 4331' MD SET RK-OGLV IN ST# 2 ~ 6809' MD RAN VARIOUS WIRE GRABS. **RECOVER 12' OF WIRE** 7/18/2008 RAN VARIOUS WIRE GRABS. RECOVERED 2' OF WIRE PULL 3 1/2" RHC-M P-BODY FROM 11,196' MD DRIFT TUB W/ 2.65" CENT & S-BAILER TAG SOFT BTM ~ 11,935' MD. -87' OF RATHOLE TUBING CLEAR, NO RESTRICTIONS. RECOVER SAMPLE OF SAND RAN SBHPS 8/5/2008 RAN 3-1/2" BRUSH, 2.8" GUAGE RING TO XXO SVLN ~ 2188' SLM W/ NO RESTRICTIONS. SET 3-1/2" FXE WRSSSV (s/n= FX4-02, 74" open, 1.5" id) IN XXO SVLN C~ 2188' SLM. • BP EXPLORATION Operations Summary Report Page 1 of 18 Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/22/2008 00:00 - 05:00 5.00 RIGD P PRE Secure Production Tree, R/D rig floor,pull off well 6-15, UD Derrick, Install Boosters front and rear. Clean up Well Site. 05:00 - 07:00 2.00 MOB P PRE Wait on Security. 07:00 - 09:00 2.00 MOB P PRE Move rig from DS 6-15 to the OX Bow road. 09:00 - 12:00 3.00 MOB P PRE Waitin on Toolservice to la I wood over flow lines on OX bow rd. 12:00 - 17:00 5.00 MOB P PRE Continue to move rig down OX Bow rd to Li pad. 17:00 - 18:30 1.50 RIGU P PRE Remove Booster Wheels, and Install BOPS into cellar. 18:30 - 20:00 1.50 RIGU P PRE PJSM Raise and Pin Derrick. 20:00 - 00:00 4.00 RIGU P PRE Wait for Pad preparation. R/U rig floor, bridle down, R/U Top Drive and doing general maintenance around the rig. 6/23/2008 00:00 - 12:30 12.50 RIGU N PRE Waiting On Pad Preparation. Had to bring location up 2' with gravel. Change out Iron Roughneck spinner, Change out bell guide on top drive, Repaired suction line in #1 pill pit, Perform light maintenance, and general housekeeping. 12:30 - 14:00 1.50 RIGU P PRE Lay Herculite and Mats on Well L1-09. 14:00 - 16:00 2.00 RIGU P PRE PJSM with Rig crew. Spot Rig over well and shim in place. 16:00 - 17:00 1.00 RIGU P PRE Set Slop tank. RU manifold and lines to circulate out Freeze Protection. Install double annulus valves and 2" Full opening valve on OA. RU CH2MHILL slop tank and choke manifold with hard line back to IA. 17:00 - 18:00 1.00 RIGU P DECOMP Continue to RU CH2MHILL tank and lines and in cellar. Bring on 110 degree 8.4ppg Seawater to pits. Pressure test CH2MHILL hard line to 1,000 psi. Good Test. RIG ACCEPTED ~ 17:00 18:00 - 18:30 0.50 WHSUR P DECOMP Test. Continue to fill pits with 110 degree 8.4ppg Seawater. Spot Mud Pump #2 module and 3516 generator module. 18:30 - 19:00 0.50 WHSUR P DECOMP Pull BPV with DSM lubricator. Well on vac. 19:00 - 20:00 1.00 WHSUR P DECOMP Hold Pre-spud and PJSM with Rig Crew, BP WSLs, and CH2MHILL truck drivers. Discuss goals and associated tasks for RWO. Outlined plan for circulating out Freeze Protection. Assigned spill champ and positions of people to monitor CH2MHILL tank and annuli. RU to vac out conductor flutes if needed. 20:00 - 22:00 2.00 KILL P DECOMP Pump 20-bbl HI Vis sweep and clrculate out 180-bbls of Diesel Freeze Protection at 8 bpm / 810 psi. Displace well with 110 degree 8.4ppg Seawater. Pumped 58-bbls before seeing returns. Took first 160 bbls of diesel from IA out to CH2MHILL flow back tank. When seeing diesel-free returns, swap over to rig slop tank and take rest of displacement to the slop tank. Work pump rate up to 8.5 bpm / 1,270 psi. Pumped full circulation with no sweep returned. Flutes monitored Burin circulation w/ no fluid see . OA mionitored, during circ out. OA was noted to flow small quantities of gas laden fluid. 22:00 - 22:30 0.50 KILL P DECOMP Monitor well. Well dead. Flow from OA with small amount of gas continued after shutting down pumps. 22:30 - 23:00 0.50 WHSUR P DECOMP Blow down all lines. Drain tree. FMC tech T-bar in ISA-BPV. 23:00 - 00:00 1.00 WHSUR P DECOMP Test ISA-BPV from below to 1,000 gsi for 10 charted minutes. 6/24/2008 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM on upcoming tasks with Rig Crew and FMC hand. Blow down circulating manifold. Bleed pressure off of control lines. ND Production tree and adapter flange and remove from cellar. Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 2 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 6/24/2008 01:30 - 02:00 0.50 WHSUR P DECOMP Install ISA-BPV blanking olua with 12 and 1/2 turns to the left (12-1/2 turns to left to release). Inspect Tbg Hgr threads. Hanger retrieving tool makes up with 5 left hand turns. 02:00 - 03:30 1.50 BOPSU P DECOMP NU 13-5/8" x 11"spacer spool and BOP stack. 03:30 - 04:30 1.00 BOPSU P DECOMP R/U to test BOP equipment. 04:30 - 06:30 2.00 BOPSU P DECOMP Begin BOP test.Begin BOP test. Test BOPs to 250 low / 3500 high. Hold each test for 5 charted minutes. All tests done per AOGCC and BP policies. Test witnessed by BP WSL and Doyon Toolpusher. BOP test right to witness waived by AOGCC, Jeff Jones. Test as follows: 1: Pipe Rams w/ 3-1/2" Test jt. 2: Annular, Kill HCR, Choke Manifold valves #12,13, & 14. Noticed that blanking plug or hanger seals are failing. 06:30 - 07:00 0.50 BOPSU P DECOMP Drained BOP stack, called out FMC tech, M/U blanking plug retrieval tool. 07:00 - 07:30 0.50 BOPSU P DECOMP Wait for FMC tech to arrive. 07:30 - 08:00 0.00 BOPSU P DECOMP Re-torqued LDS. Hanger seals were leaking. 08:00 - 11:00 3.00 BOPSU P DECOMP Continued to test BOP equipment 3: Blind/Shear Rams, Manual Kill, Choke Manifold valves #9 & 11, Upper IBOP. 4: Choke Manifold valves #5, 8 & 10, Lower IBOP. 5: Choke Manifold valves # 4, 6 & 7, Dart valve. 6: Choke Manifold valve #2 (4& 6 shut), TIW valve. 7: Choke Manifold valves #1 & 3 (4 & 6 shut). 8: Choke line HCR valve. 9: Manual Choke line valve. 10: Pipe Rams w/ 4" test jt. 11: Accumulator Test. 11:00 - 11:30 0.50 BOPSU P DECOMP R/D and B/D BOP testing equipment, B/D Choke and Kill lines. 11:30 - 12:00 0.50 BOPSU P DECOMP RIH with Blanking plug retrieval tool and pull Blanking plug. 12:00 - 13:00 1.00 BOPSU P DECOMP P/U DSM lubricator and test lubricator to 500 psi and pull BPV. 13:00 - 13:30 0.50 PULL P DECOMP M/U Hanger pulling tools and BOLDS, Verify no pressure on IA. Pull hanger to rig floor. Hanger and tubing pulled free at 120,000#. 13:30 - 14:00 0.50 PULL P DECOMP Cut control line and B/O and UD tubing hanger and hanger pulling tool. 14:00 - 15:30 1.50 PULL P DECOMP Circulate Bottoms up at 9 bpm with 1,720 psi. R/U Control line spooler unilt. 15:30 - 16:00 0.50 PULL P DECOMP Monitor well, Blow down Cement line. 16:00 - 17:30 1.50 PULL P DECOMP POOH laying down 3.5" completion string.from 10,970' to 8,870'. 68 SS Control line bands were recovered. 17:30 - 18:00 0.50 PULL P DECOMP R/D and UD SLB control line spooler unit. 18:00 - 00:00 6.00 PULL P DECOMP Continue to UD tubing from 8,870' to 2,060'. 6/25/2008 00:00 - 01:00 1.00 PULL P DECOMP Continue to UD Tubing from 2,060' to surface, 1 SSSV, 2 GLMs, 344 jts of 3.5" tubing, 1 cut jt, Length of cut jt=10.41'. Flare on cut joint was 4-3/16". Corrosion holes were found on the pup joints above and below the #2 GLM 01:00 - 01:30 0.50 PULL P DECOMP Clear and Clean Rig Floor, UD tubing handling equipment. 01:30 - 02:00 0.50 PULL P DECOMP Install Wear Ring, ID= 9-1/16" 02:00 - 02:30 0.50 PULL P DECOMP P/U BHA components. 02:30 - 03:30 1.00 PULL P DECOMP PJSM. P/U M/U Dress-off BHA: Cut lip guide, hollow mill, overshot bowl, Overshot ext, top sub, Lubricated Bumper Sub, Printed: 7/23/2008 2:29:28 PM • • BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase i Description of Operations 6/25/2008 02:30 - 03:30 1.00 PULL P DECOMP oil jar, pump out sub, XO, accel jar, XO. BHA length = 415.84'. 03:30 - 12:30 9.00 PULL P DECOMP RIH with dress-off BHA picking up HT-38 drill pipe from Pipe Shed. Get parameters at 10,224' in the hole: 190K Up, 140K Down. Manifold Building alarm sounds and Driller calls for Rig Evacuation, see Comments for further info. 12:30 - 13:30 1.00 PULL P DECOMP P/U joint #332 and M/U to Top Drive, get parameters: P/U wt 195K, S/O wt 145K, Rot wt 170K at 50-RPM with 6K-Ib-ft free torque, 3-1/2-BPM at 310-psi. RIH to 10,887' and tag hard. P/U with 30K overpull, but jars go off and BHA releases from tag. P/U another 5' and start rotating 50-RPM at 6K-Ib-ft, 3-1/2-BPM, 310-psi. Slowly RIH and tag at 10,887' and washover with 1-3K-Ibs WOB while torque runs to 6-7K-Ib-ft. Make 3' to 10,890'. Do not see any increase in pump pressure. Stop rotating anf P/U to 20-K overpull, and let jars go off. Continue POH -5' and see 1-3K-Ibs extra weight. Start rotating and set back down to 145K-Ibs. Make another 1.5' to -10,891.5'. Stop rotating and POH to 220-K-Ibs and jars go off. Continue to P/U 5' and see 1-3K-Ibs additional weight. Stop POH and RIH to set down to -120K-Ibs. P/U and jars go off at 220K-Ibs, and continue POH another 5' with the same 1-3K-Ibs additional weight. Set back down to 120-K-Ibs, P/U but jars do not go off. Continue P/U another 5' and decide to Circulate Bottoms Up while making a recount of the 3-1/2" tubin th had been POOH and L/D Did not see any D/P pressure changes during the forgoing operations. 13:30 - 15:30 2.00 PULL P DECOMP CBU 9-BPM at 1,900-psi and find that 343 full ioints of 3-1/2" tubing had been pulled instead of the earlier reported 344-ioints. Recount the joints twice while loading them on the truck to verify the 343-joint count. Discuss findings with ADW Engineer and Baker Fishing Rep and decide to POOH to look at the BHA and possible fish. Circulate a total of 540-Bbls and do not see any particulate matter across the shakers. 15:30 - 20:00 4.50 PULL P DECOMP POH and S/B DP in Derrick. S/B 110-stands and L/D two joints of DP to verify that the Drillers DP tally was correct. S/B 4-stands of DCs in the Derrick. B/O and L/D BHA with no fish. The cutlip guide on the overshot was torn up with no indication that the grapples had ever engaged the stub. Decide to RIH with an overshot dressed with carbide to dress-off the stub. 20:00 - 20:30 0.50 PULL P DECOMP Hold Safety and Performance talk with Superintendent James Willingham and HSE rep Jeff Kilfoyle. Highlight ADW safety record and acknowledge work by rig crews to achieve this record. 20:30 - 21:00 0.50 PULL P DECOMP Clear and clean rig floor and service equipment. 21:00 - 22:00 1.00 PULL P DECOMP MU BHA #2 -Dress off Shoe, Overshot w/ 2-extensions, Bumper sub, Jar, 4-stds of 4-3/4" DCs, and Accelerator to dress off tubing stub and attempt to fish remaining completion. 22:00 - 00:00 2.00 PULL P DECOMP RIH with BHA #2 from 419' to 6,587' md. 6/26/2008 00:00 - 01:00 1.00 PULL P DECOMP Continue to RIH with BHA #2 from 6,587' to 10,862' md. 01:00 - 03:00 2.00 PULL P DECOMP Establish parameters: PU wt = 207K, SO wt = 140K, Rot wt = 165K. Rotate at 50-rpm with 7K Ibs-ft of free torque. Pumping at 5-BPM / 450-psi. Take Slow Pump Rates: MP #1 - 30-spm= 90-psi, 40-spm = 230-psi. MP #2 - 30-spm = 190-psi, 40-spm = 360-psi. Continue to RIH and tag top of fish at 10,887' md. Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 4 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 6/26/2008 01:00 - 03:00 2.00 PULL P DECOMP 03:00 - 04:00 1.00 PULL P DECOMP 04:00 - 05:30 1.50 PULL P DECOMP 05:30 - 06:30 1.00 PULL P DECOMP 06:30 - 10:30 4.00 PULL P DECOMP 10:30 - 13:30 3.00 PULL P DECOMP Dress off stump, slide over stump and engage fish with overshot grapple. PU to 250K three times. Begin pattern of jarring with 100K over PU wt then PU to 350K max (150K overpull) then slack off with 20K-Ibs set down. Jarred -40 times to achieve 60' of movement. Fish came free. CBU at 10-BPM / 2,600-psi. Saw crude and small amount of gas at bottoms up. POH from 10,887' to 7" liner top at 9,591' md. Carrying -5K over PU wt coming up. CBU from above the Liner Top; 10-BPM at 2600-psi and get an oil sheen in the Pits. Continue to POH with fish, S/B DP and DCs in Derrick. Fish to the rig floor at 1030-hours. Break out and L/D fish using die punch in Iron Roughneck to bleed pressure from all joints in the fish. The first punches at the cutoff joint released trapped pressure in the form of gas, saltwater and some gummy material, but no sand or scale. Subsequent punches were free of any pressure. The top running sub (-2-1/2" OD and 4' long) for the Eclipse patch was loose and inside the top of the top pup joint of the GLM. The pup joint above the bottom anchor for the patch was separated from the patch and was protruding from the top of the full joint immediately below the GLM bottom pup joint. Recovered assembly: cutoff (20.53'), 3 full joints (31.51', 31.68', and 31.35'), GLM (30.26'), 1 full joint (31.39'), X-nipple assembly (25.32'), top of the Seal Stem assembly that No-Goes on top of the PBR (7.16') and the Seal Stem assembly (11.84'). This puts the top of the PBR at -11,101'. FasDrill plug was found in 13:30 - 14:30 1.00 PULL P DECOMP Contact ADW Engineer and decide to RIH with Itco spear dressed with 3.25" grapple. Clear and clean Rig Floor. Bring new spear and BHA to Rig Floor. 14:30 - 15:30 1.00 PULL P DECOMP P/U and M/U 3.25" Itco Spear BHA and M/U to 4-stands of 15:30 - 18:30 3.00 PULL P DECOMP RIH Spear BHA on DP from Derrick. Filled drill pipe at 4,700' and to ensure drill string was clear due to .5"jet in spear. 18:30 - 19:30 1.00 PULL P DECOMP Slip and Cut drilling line, 12 wraps for 81' cut. 19:30 - 20:00 0.50 PULL P DECOMP Continue to RIH from 10,761' to 10,950' md. Obtain parameters: upweight=212,000#, Down weight=145,000#. 20:00 - 20:30 0.50 PULL P DECOMP Continue to RIH, washing down to TOF. Tagged up on fish at 11,101' and no-go out at 11,109' with the pump rate o 1. pm with 260 psi.Verified stinging into fish by increase of pump pressure to 460 psi. 20:30 - 21:00 0.50 PULL P DECOMP Picked up on drill string 28,000# over string weight for a total of 240,000# and fired jar, then pulled up to 300,000# to free the packer. Let packer relax and RIH past packer setting depth to veri latch of fish. P/U weight increased from 212,000 # to 225,000#. 21:00 - 00:00 3.00 PULL P DECOMP POOH while pumping at 3 bpm with 360 psi, from 11,109'to 10,091', working pipe and jarring to obtain upward movement of packer. 6/27/2008 00:00 - 01:00 1.00 PULL P DECOMP Continue to Pull Packer from 10,094' to 9,523' md. Pumping Printed: 7/23/2008 2:29:28 PM ~J BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release; 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ___ 6/27/2008 00:00 - 01:00 1.00 PULL P 01:00 - 02:00 1.00 PULL P 02:00 - 05:30 I 3.501 PULL I P 05:30 - 06:30 I 1.001 PULL I P 06:30 - 07:30 1.00 PULL P 07:30 - 08:30 1.00 CLEAN P 08:30 - 11:30 3.00 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 16:30 4.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 22:30 4.50 DHB P 22:30 - 23:00 0.50 DHB P 23:00 - 00:00 1.00 DHB P 6/28/2008 00:00 - 03:30 3.50 DHB P 03:30 - 04:00 0.50 DHB P 04:00 - 05:00 1.00 EVAL P 05:00 - 09:00 4.00 EVAL P 09:00 - 10:00 1.00 EVAL P 10:00 - 12:00 2.00 EVAL P DECOMP out at 2 bpm with 620 psi. DECOMP Dropped opening dart and CBU at 10 bpm with 2,000 psi. Saw some fine, oily sand back throughout circulation. Flow check well -Static. DECOMP Pump 15-bbl dry job. Blow down Top Drive. POOH from 9,523' To BHA. DECOMP Stand back Drill Collars. Break out FH packer and UD with S ear inside the PBR. Break out and UD 2-joints of 2-7/8" EUE 8-rd tubing that was severely corroded. The Cameron D-nipple was left on the bottom of the first joint of 2-7/8" below the FH packer. There was a 2-7/8" Baker Shear Sub on the bottom of the 2nd-joint of 2-7/8" that appeared, at first, to be a WLEG. completion tallies for 1/18/1986 and 12/29/1993. DECOMP Clear and Clean Rig Floor. Hold PJSM. Bring Baker 7" and 9-5/8" Casing Scrapers and BHA to Rig Floor. DECOMP M/U Casino Scraper BHA with 7" Scraper under 4-stands of 4-3/4" DCs and 13-stands of DP to space-out the 9-5/8" Scraper. DECOMP RIH with double scraper BHA to 11,170' for the 7" Scraper max depth and 9,550' for the 9-5/8" Scraper max depth. DECOMP CBU. Ease 9-5/8" Scraper down onto the 7" Liner Top and find it at 9,577', Doyon 16 DP MD. DECOMP Monitor well -Static. Pump dry job and blow down Top Drive. POH from 11,170' to 1,632'md. Standback all 4" DP in Derrick. Saw 10K-Ib drag coming up thru 7" liner. DECOMP UD Scraper BHA. Stand back 4-3/4" DCs and remaining 13-stds of 4" DP. UD remainder of Scraper BHA. DECOMP Clean and Clear Rig Floor. DECOMP PU and MU 7" HES RBP. RIH on 4" DP to 11,102' md. Halliburton rep supervised running speed and setting procedure. DECOMP Slack off and set 15K-Ibs on RBP. Turn to left 3 times and release from RBP. Stand back 1-std of 4" DP. RU to pressure test Cs above RBP. Top of RBP at 11,102' md. Center of Elements on RBP at 11 106' md. DECOMP Pressure test all Cs above RBP 11 102' and to 3 500- si. Hold test for 30 charted minutes. Rock solid, straight line Test. RD test equipment. DECOMP Blow Down Choke and Kill lines. Flow check -Static. Pump 15-bbl dry job. POH from 11,006' to 391' md. DECOMP Stand back 4-stds of 4-3/4" DCs and LD HES 7" RBP running tool. DECOMP Break down 9-5/8" RTTS. MU 9-5/8" RBP running tool. Clean Rig Floor. DECOMP RU Dutch Riser System. Spot Schlumberger E-Line unit. Hold PJSm for R/U SWS equipment on rig floor. R/U SWS equipment. PT Line Wiper to 500-psi. R/U USIT logging Tool and lower into Dutch Riser. DECOMP RIH with USIT logging tool to 4500' using Rig Floor as zero DECOMP Log up from 4500' to 500' in Cement/Corrosion mode. Make repeat pass from 3300' to 2600'. Find top of cement at 2980', Printetl: 7/23/2008 2:29:28 PM • • BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Hours Task Code NPT Phase ~ Description of Operations - Date From.- To - `- - 6/28/2008 10:00 - 12:00 - 2.00 EVAL P DECOMP exactly on depth with a casing collar. 12:00 - 13:00 1.00 EVAL P DECOMP R/D SWS equipment and pull Dutch Riser. Blowdown Kill Line. 13:00 - 14:30 1.50 DHB P DECOMP P/ M Halliburton RBP and I 14:30 - 15:00 0.50 DHB P DECOMP R/U and test RBP to 1,500 psi for 15 charted minutes. 15:00 - 16:30 1.50 DHB P DECOMP P/U one stand and install sand dump hopper on top of DP to dump 44-sacks of 20-40 River Sand on top of the RBP. Pump DP volume to chase sand out of DP. 16:30 - 17:00 0.50 DHB P DECOMP P/U one stand and tag top of sant to verify depth, TOS at 17:00 - 18:00 1.00 CLEAN P DECOMP POOH with RBP running tool from 3,124' to surface. 18:00 - 18:30 0.50 CLEAN P DECOMP B/D choke and kill lines, drain BOP stack, B/D hole fill, pull wear ring. 18:30 - 19:30 1.00 BOPSU P DECOMP Ni le down BOP stack to Chan a out Tb s ool from 11 "x 13-5/8" to 13-5/8" x 13-5/8" spool. 19:30 - 20:00 0,50 WHSUR P DECOMP Nipple down 11" x 13-5/8" Tbg Spool. 20:00 - 20:30 0.50 WHSUR P DECOMP Nipple up new 13-5/8" x 13-5/8" Tbg spool. 20:30 - 22:00 1.50 BOPSU P DECOMP Change out BOP stack spacer spool to fit new Tbg spool and NU BOP stack. 22:00 - 22:30 0.50 BOPSU P DECOMP Bod test BOP to 250- si low and 3 500- si hi h. Chart and hold each test for 5 minutes. Good Test. 22:30 - 23:00 0.50 BOPSU P DECOMP Pull Test plug and Install wear Ring. Blow down Kill line. 23:00 - 23:30 0.50 CLEAN P DECOMP PU & MU 9-5/8" Csg Cutter BHA. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH with 9-5/8" Csg Cutter on 4" DP. 6/29/2008 00:00 - 00:15 0.25 CLEAN P DECOMP Continue to RIH with 9-5/8" Csg Cutter on 4" DP. 00:15 - 01:30 1.25 CLEAN P DECOMP H2S Ri Evacuation Drill with full res onse b crew. Driller and lead floorhand donned SCBAs, secured the well and swept the rig prior to exit. All crew and 3rd party hands on location were accounted for in the safe briefing area. Stand by until Rig cleared for reentry. Determined to be false alarm from cellar H2S sensor that was covered b condensin moisture from a wet fo that was blowin throw h the cellar due too en cellar windwalls. 01:30 - 02:00 0.50 CLEAN P DECOMP Review H2S Rig Evacuation Drill with Rig crew and 3rd party hands. Hold PJSM for cutting 9-5/8" csg and circulating out Arctic Pack. Assigned hands positions and discussed in depth procedures. Ensured all necessary personnel had the ability to communicate with the driller via handheld radios. 02:00 - 03:30 1.50 CLEAN P DECOMP Continue to RIH with 9-5/8" Csg Cutter on 4" DP to 2,957' md. 03:30 - 04:00 0.50 CLEAN P DECOMP Establish cutting parameters. PU wt = 90K, SO wt = 82K. Rotate at 50-rpm with 2K Ibs-ff free torque. Mud Pump #2 online at 5-bpm / 450-psi. Open knives on cutter and locate collar at 2,940' md. Pumps off and slack off cut depth of 2,957' md. Pumps on at 7-bpm / 1000-psi. Rotate at 50-rpm and cut casing. Pressured up to 1,200-psi while cutting. Pressure dropped off to 750-psi when cut was made. Also felt jolt on the rig floor indicating that the csg was in tension prior to cutting Pumps off and PU -10'. Pump back to 5-bpm / 500-psi. Attempt to run in to cut depth, unable to reach 2,957' md. Monitor well for flow. 04:00 - 04:30 0.50 CLEAN P DECOMP CBU at 11-bpm / 2500-psi to get gas to break out and ensure well not flowing. Got crude back across shakers. Well static when finished circulating. 04:30 - 05:00 0.50 CLEAN P DECOMP Pressure test Lil Red Hot Oil lines to 2,500-psi. Good Test. Lil Printed: 7/23/2008 2:29:28 PM n • BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 6/29/2008 04:30 - 05:00 0.50 CLEAN P DECOMP Red pump 32-Bbls of 90-degree F diesel at 2-BPM / 500-psi. 05:00 - 06:30 1.50 CLEAN P DECOMP Close annular preventer and open OA to flowback tank. Lil Red pump 70-Bbls of 90 degree F diesel. Break circulation with .5-bpm / 200-psi and work up to 2-bpm / 700 psi. 06:30 - 08:30 2.00 CLEAN P DECOMP Let Diesel and Safe-Surf-O soak in annulus. 08:30 - 10:30 2.00 CLEAN P DECOMP Circulate the 9-5/8" x 13-3/8" annulus with Hi Vis sweep chased by 367-Bbls of hot seawater. S/I 30-minutes. Take on more seawater and start pumping at 11-BPM and 2620-psi, see clean returns to Slop Tank after 70-Bbls pumped. S/I pumps. 10:30 - 11:00 0.50 CLEAN P DECOMP CBU through the DP x 9-5/8" annulus for 170-Bbls at 9.5-BPM, 1690-psi. Blow down lines, UD single and monitor well. 11:00 - 12:30 1.50 CLEAN P DECOMP POH and S/B DP in Derrick. At 1039' of DP and DCs (7-stands DP and 4-stds DCs) remaining in the well, stop to take on seawater to the Pits. Open OA and U-tubing starts unloading the 9-5/8" x 13-3/8" annulus. Fluids from OA are clean seawater, so S/I OA and open IA and get diesel back to the Pits. Build a Hi-Vis sweep and CBU in the DP x 9-5/8" annulus. 12:30 - 13:30 1.00 CLEAN P DECOMP Circulate Hi-Vis sweep to clean up IA, 10-BPM at 1440-psi. S/I OA. 13:30 - 14:30 1.00 CLEAN P DECOMP POH and S/B DP and DCs in Derrick. Clear and clean Rig Floor. Pull Wear Ring. 14:30 - 15:00 0.50 CLEAN P DECOMP PJSM. P/U and M/U 9-5/8" Spear. Check all pre-torqued connections before RIH. Open the OA to check for further U-tubing and flow quits almost immediately. 15:00 - 16:00 1.00 PULL P DECOMP RIH and enaaae 9-5/8" Soear in 9-5/8" casina. BOLDS. M/U landing joint to Top Drive. P/U on landing joint to 175K and hanger comes free. Pull hanger to floor with 170K-Ibs. 9-5/8" String weight in seawater -121 K-Ibs. Blocks weight -40K-Ibs. 16:00 - 17:00 1.00 PULL P DECOMP UD Spear and Hanger. R/U Doyon Casing power tongs and rig tongs for 9-5/8" casing. R/U to circulate full wellbore volume as there is diesel and crude oil standing in the top of the 9-5/8" casing from the earlier circulations. 17:00 - 18:00 1.00 PULL P DECOMP Circulate full wellbore volume, 10-BPM at 740-psi. 18:00 - 18:30 0.50 PULL P DECOMP Blow down all lines. RD circulating equipment. 18:30 - 00:00 5.50 PULL P DECOMP UD 9-5/8" 47# L-80 BTC from 2,957' to 997' md. Pressure washin Cs exterior of excess crude while ullin out of the hole. Average break out torque needed was 35K-Ibs-ft. Some joints needed as much as 45K-Ibs-ft of torque to break out. Recovered half of a broken centralizer and noticed where 3 centralizers were missing from joints. 6/30/2008 00:00 - 03:30 3.50 PULL P DECOMP Continue to pull and UD 9-5/8" casing, washing crude from all joints. 72 full joints recovered, cut it was clean cut length=17.15', 16 Centralizers recovered out of a possible 18 centralizers. 03:30 - 04:00 0.50 PULL P DECOMP Clear and clean rig floor. 04:00 - 05:00 1.00 CLEAN P DECOMP O en VBR ram door and remove two feces of broke centralizers from ram bod .Close ram door. 05:00 - 06:00 1.00 CLEAN P DECOMP Pressure test BOP full bod test, 250 psi low test and 3,500 high test. 06:00 - 08:00 2.00 CLEAN P DECOMP M/U 9-5/8" dress off assembl with 13-3/8" CSG scraper. BHA consists of: Dress off shoe, Wash pipe ext, Dress off mill, Printed: 7/23/2008 2:29:28 PM • • BP EXPLORATION Page 8 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours-~ Task Code NPT Phase os:oo - 08:00 2.001- _- - 6/30/2008 CLEAN P DECOMP 08:00 - 09:30 1.50 CLEAN P DECOMP 09:30 - 10:30 1.00 CLEAN P DECOMP 10:30 - 11:00 0.50 CLEAN P DECOMP 11:00 - 12:00 I 1.001 CLEAN I P I I DECOMP 12:00 - 15:00 I 3.001 CLEAN I P I I DECOMP ii 15:00 - 16:00 ~ 1.00 ~ CLEAN ~ P ~ ~ DECOMP Description of Operations Wash over junk basket, Double Pin sub, 13-38" Casing scraper, Bit Sub, XO, Float sub, XO, XO, LBS, Oil Jar, XO, 12- 4-3/4" Drill Collars. BHA length=416.76'. RIH with BHA to 2790' and stop to slip and cut drilling line. Slip and cut Drilling Line. Inspect Top Drive. RIH to 2885' and get parameters, P/U wt 90K, S/O wt 92K, free torque 3K-Ib-ft at 60-RPM, 4-BPM at 140-psi. Stop rotating and pumping and slowly RIH to taa stub at 2957'. P/U to circulate. Circulate out some gas and Arctic Pack. Pump Safe-Surf-O sweep, 4-BPM at 160-psi. Returns appear clean, but opaque with a tan color. Start rotating 60-RPM and pump 3.5-BPM at 150-psi slowly RIH and slip over stub with 5-10K-Ib-ft of torque. Dress-off -6" of stub, work the string up -2' and back down 3-times to polish. P/U above stub and stop rotating, then slowly RIH, but stack out on top of stub. P/U and start rotating to slowly RIH, but stack out on top of stub. Put 5-10K-Ibs on bit and work down a few inches, but cannot get further. P/U and stop rotating and slowly RIH and repeat stack out. Work again with increasing WOB up to 18K-Ibs, but no go. P/U and try rotating down over stab and make it all the way to the polish mill. P/U -2' and slowly RIH to polish, repeat this two more times. P/U and stop rotating to try to slide down over stub; No Go. P/U and start rotating and slowly RIH, but stack out at 2957.5'. Increase WOB and make some progress to abouUse alternating WOB and make no more progress. Call town and decide to POH to look at dress-off BHA as well as to prepare for weekly BOP Test. Gave AOGCC a 24-hr notice of this test at 1730-hours 29 June 2008. Call AOGCC with an update. Chuck Sheve asked for a further update in case we were not ready for him. POH and S/B DP in Derrick. Have to R/U double strippers and DCs. Use wash wand to clean off the BHA. 16:00 - 18:00 2.00 CLEAN P DECOMP B/O and UD BHA. Find pieces of metal and -1-gal of debris in the Boot Basket. The shoe was damaged with a pair of parallel 6" gouges and a pair of parallel 18" gouges that were caused by the shoe rotating eccentrically around the stub, with the stub cutting into the shoe. Call ADW engineer and decide to make a second run with the Baker Multi-Strina cutter to cut off an 18:00 - 18:30 0.50 ~ BOPSUp P ~ ~ DECOMP 18:30 - 19:30 1.00 BOPSUF~ P DECOMP 19:30 - 23:30 4.00 BOPSU P DECOMP additional 8-10' of 9-5/8" Casing. Pull wear ring and use Johnny Whacker to clean out BOP stack. Set Test Plug and R/U for BOPE Test. Set test plug and R/U for BOP testing. Test BOPE to 250 osi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test by Chuck Scheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1-VBR Pipe Rams on 4" Test joint. Test #2- VBR Pipe Rams on 3.5" Test joint and Upper IBOP Test #3- Choke Valves 1, 12, 13, 14, Lower IBOP, Kill HCR, Annular Preventor on 3.5" Test joint Test #4- Manual Kill Valve, Choke Valves #9, 11 Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 9 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To ;Hours Task Code NPT Phase Description of Operations -- 6/30/2008 19:30 - 23:30 4.00 BOPSU P DECOMP -- Test #5-Choke Valves 5, 8, 10 Test #6- Choke Valves 4, 6, 7 Test #7- Choke Valves #2 Test #8- Manual Choke, Dart Valve Test #9- Choke HCR, TIW Test #10- Blinds and Choke Valve #3 Accumulater Test- 2,900 psi Starting Pressure, 1,800 psi After Actuation, First 200 psi in 20 seconds, Full Pressure in 1 Minute 26 Seconds. 5 Nitrogen Bottles at 2,150 psi. 23:30 - 00:00 0.50 BOPSU P DECOMP R/D Test Equipment and Blow Down Choke and Kill lines and the Top Drive. 7/1/2008 00:00 - 00:30 0.50 BOPSU P DECOMP Pull Test Plug and set Wear Ring. 00:30 - 01:30 1.00 FISH P DECOMP M/U Baker Multi-String Cutter Assembl to RIH to make a second cut in the 9-5/8" Casing to ensure that the possibly damaged stub is removed. 01:30 - 02:30 1.00 FISH P DECOMP RIH to 2,957' Obtain Parameters: up weight=92,000#, down weight=90,000#, 60 rpm, 2.5-5,000 Ibs-ft torque, set cutter knives at 2,967' and pumped at 7-BPM with 1,170-psi. Saw a slight bobble on the weight indicator when the bullnose below the Baker Multi-string Cutter passed through the stub at 2957' 02:30 - 03:00 0.50 FISH P DECOMP Made cut in 9-5/8" cs at 2 967. With 60 rpm, 2.5-5,000 Ibs-ft of torque, 7 bpm with1,170 psi, verify cut by slacking off 5,000# and pressure dropped to 1,000 psi. 03:00 - 04:00 1.00 FISH P DECOMP CBU at 12 bpm with 2,000 psi, blow down top drive and monitor well 04:00 - 05:30 1.50 FISH P DECOMP POOH from 2,967' to 375' stand back drill collars and UD BHA. 05:30 - 06:00 0.50 FISH P DECOMP Clean and Clear rig floor. 06:00 - 06:30 0.50 FISH P DECOMP - 06:30 - 08:00 1.50 FISH P DECOMP RIH with 9-5/8" Spear to 2934', get parameters: 4-BPM, 120-psi, P/U wt 89K-Ibs, S/O wt 90K-Ibs. 08:00 - 08:30 0.50 FISH P DECOMP Ta fish at 2957' and work down inside to a bullnose depth of 2975'. P/U and slowly lower to put 10K-Ibs on spear, make two left-hand turns. P/U 5', then RIH slowly to confirm tag. 08:30 - 10:30 2.00 FISH P DECOMP Break-off Dp from Top Drive, bleed down Top Drive. POH and S/B DP and DCs in Derrick. VD BHA and release cut-off from Spear. Cut-off length is 8.76'. Both ends were clean, with very little damage from the previous dress-off operation seen on the top of the cut-off. 10:30 - 11:00 0.50 FISH P DECOMP Clear and clean rig floor. 11:00 - 12:00 1.00 FISH P DECOMP M/U Dress-off BHA: Dress-off Shoe, Washpipe Extension, Dress-off Mill inside Washpipe, Washover Boot Basket, Float Sub, Bumper Sub, Oil Jars, and 12-ea 4-3/4" drill collars. 12:00 - 12:30 0.50 FISH P DECOMP RIH with Dress-off BHA and stop at 2941' to get parameters: P/U wt 90K-Ibs, S/O wt 90K-Ibs, Rot Wt at 20-RPMs with 1 K-Ib-ft free torque 90K. 12:30 - 14:00 1.50 FISH P DECOMP Continue to RIH and li htl to stub at 2967'. P/U and start rotating at 10-RPM, 4-BPM, 110-psi, WOB 10K-Ibs, torque 1 to 5K-Ib-ft. Increase RPM to 60-RPM. Continue to polish down and tag up with internal polish mill. P/U and polish stub twice. Went over stub once with no rotation. Took 2K-Ibs to lightly rotate over stub second time. Stub is laying beside 13-3/8" Printed: 7/23/2008 2:29:28 PM • ~ BP EXPLORATION Page 10 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: i Date ~ From - To Hours i Task Code NPT Phase Description of Operations 7/1/2008 12:30 - 14:00 1.50 FISH P DECOMP casing. 14:00 - 15:30 1.50 FISH P DECOMP Circulate 20-Bbl Safe-Surf-O sweep followed by HiVis sweep and chase out of hole at 10-BPM and 800-psi. Pump dry job, monitor well, and blow down Top Drive. 15:30 - 16:30 1.00 FISH P DECOMP POOH, S/B DP and DCs in Derrick. B/O and L/D Dress-off BHA. 16:30 - 18:30 2.00 CASE P TIEB1 fl r IH with 9-5/8" casin . M/U XO from 9-5/8" Hydril 563 to 4-1/2" IF for Floor Safety Valve. Change bails to longer bails. R/U Doyon Casing Torque Turn equipment. 18:30 - 20:00 1.50 CASE P TIE61 PJSM. P/U and M/U Bowen Casing Patch, BakerLok to BTC-M pup joint, BakerLok to ES Cementer, BakerLok to XO Pup Joint (Hydril 563 box xBTC-M pin). RIH on 9-5/8", 47#, L-80, Hydril 563 from Pipe Shed. Torque Turn each connection to 15,800-Ib-ft (per Doyon Casing Crew recommendation), using Jet Lube Seal Guard pipe dope. 20:00 - 00:00 4.00 CASE P TIEB1 Continue P/U and RIH with 9-5/8". 47#, L80, Hydril 563 tie back casin 7/2/2008 00:00 - 01:00 1.00 CASE P TIEB1 Continue P/U and RIH 77 total joints of 9-5/8", 47#, L80, Hydril 563 tie back casing patch. 01:00 - 01:30 0.50 CASE P TIEBi Establish parameters of P/U Wt- 164,000 Ibs; S/O Wt- 170,000 lbs. Continue RIH and tag top of casing stub at 2968'. Ease casing patch over casing stub to set the total depth of the overshot at 2971'. S/O 28,000 Ibs on casing stub. P/U 30,000 Ibs overpull to set grapple. S/O 35,000 Ibs on casing stub. Pull test casin atch to 290 000 Ibs 125 000 Ibs over ull/ 01:30 - 02:30 1.00 CASE P TIEB1 M/U cementing head with circulating lines. 02:30 - 03:30 1.00 CASE P TIEB1 Pressure test casino Hatch to 1500 psi for 15 charted minutes. I rease ressure to 2000 si and hold for 30 charted minutes. Hold PJSM with rig crew, HES, Baker, Mud Engineer, and CH2MHill Support crew. Discuss upcoming cement operation plan and procedures. Assign job assignments and last minute action items. Discuss job safety and stop the job as needed. 03:30 - 04:00 0.50 CASE P TIE61 Shear o en ES cementer with 2950 si. Circulate through cementer at 6 bpm with 310 psi. 04:00 - 06:00 2.00 CEMT P TIE61 Ensure all lines are R/U properly. Pressure test lines to 4500 psi. Start cement job by pumping 5-Bbls water, mix and pump 194 bbls of 15.8 Class G cement with .4 gal/sx D047 Antifoam, .35%BWOC D065 Dispersant, 2.0 gal/sx D600G GASBLOK, and .5% BWOC S002 Accelerator at 6 BPM with 300 to 360 psi wellhead pressure. Shut down pumps and dropped dart. Schlumberger flushed lines to rig floor. Switch over to rig pump and displace cement with seawater at 6.2 to 7.4 BPM and 300 to 450 psi to catch cement after pumping 93-Bbls of seawater. Pump pressure increased to 650 psi at 6.4 BPM after catching cement. Pressure increased to 1650 psi at 5.9 BPM when cement returns came to su ace. er good cement returned to surface, divert returns through choke. and maintain 400 si back ressure. Decreased pump rate to 2 BPM after displacing 200-Bbls, wellhead pressure at 1770 psi. Bumped plug at 209 bbls with 1770 psi. Slowly increase pressure to close ES Cementer at 2300 psi. Hold 2350 psi on plug. Bleed pressure and check for flow back. ES Cementer Printed: 7/23/2008 2:29:28 PM • BP EXPLORATION Page 11 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task '~ Code NPT j Phase Description of Operations 7/2/2008 04:00 - 06:00 2.00 CEMT P TIEBi holdin .Bleed pressure. CIP at 05:15 hrs. Flush ROPE. 06:00 - 06:30 0.50 CASE P TIEB1 Pump citric acid pill to Wells support Slop Tank and through BOP Stack. R/D Halliburton Cementing Head and crossover. 06:30 - 13:00 6.50 WHSUR P TIEB1 N/D Tubing Spool with Sweeney Wrench. P/U BOP Stack with beam crane winches. Install FMC 9-5/8" Casino Slias. The B-Condition 9-5/8" casing calipered almost 9-3/4", which increased the resistance of the slips to being driven down the 9-5/8" casing and into the Casing Bowl. P/U the casing to 150K-Ibs and move slips down 3-4-inches. Set back down and leave 145-150K-Ibs on slips. R/U Wachs casing cutter and make cut on 9-5/8" casing. Set BOP stack and Tubing Spool back on Casing Spool and N/U. M/U 9-5/8" packoff pulling tool to landing joint, RIH and pull packoff. M/U new (old style) packoff and attempt to install in Tubing Spool, but will not go even with 18,000-Ibs set down by M/U the landing joint to the Top Drive. POH and remove the old style, install new style packoff, which was brought along with the old style, on tool and RIH, easily installing the packoff in the Spool. RILDS. 13:00 - 13:30 0.50 WHSUR P TIE61 FMC pressure test 9-5/8" packoff and Spool break to 3800-psi 13:30 - 18:00 4.50 CEMT P TIEB1 Wait on cement. Perform rig workorders. Load, rabbit, and strap 3-1/2", 9.2-Ib, L-80, VamTop tubing (-360-jts required for completion) in Pipe Shed. Set 9" Wear Ring. Install rebuilt Weight Indicator in Driller's Console. Slowdown Choke and Kill lines. Changeout long Bails on Top Drive for short Bails to run DP and tubing. R/U elevators for DP. Perform rig maintenance. Schlumberger forgot to call with the UCA compressive strength results until 1700-hours: 500-psi at 1400-hours, 1000-psi at 1700-hours. 18:00 - 19:00 1.00 DRILL P TIEB1 P/U and M/U Cement Track BHA#10 consisting of 8-1/2" used bit, (2) 7" boot baskets, bit sub, jars, x/o sub, and (12) 4-3/4" drill collars. Total length of BHA #10- 393.52' 19:00 - 19:30 0.50 DRILL P TIEB1 RIH with BHA #10 on 4" HT-38 drill pipe from derrick to 2862'. 19:30 - 22:30 3.00 DRILL P TIEB1 Establish drilling parameters of P/U Wt- 86,000 Ibs; S/O Wt- 90,000Ibs; Rotating Wt- 92,000 Ibs at 60 rpm with 2000 ft-Ibs free torque; Pump Pressure- 100 psi at 4 bpm. Continue to RIH and to wi er lu at 2939'. No cement noted on top of wiper plug. Control drill through wiper plug and ES Cementer with 5000 Ibs WOB, 4.3 bpm with 140 psi, 80 rpm and 2500 ft-Ibs torque. Drilled through wiper plug and ES Cementer at 21:30 hrs. Continue control drilling though cement with same parameters. Found end of cement at 2978'. Continue to wash to top of sand at 3074'. 22:30 - 23:30 1.00 DRILL P TIEBi P/U 5' and pump high visc sweep at 12 bpm with 1100 psi. High pump rate and sweep unloaded well of cement, rubber, and aluminum. 23:30 - 00:00 0.50 DRILL P TIE61 Dry drill on top of sand at 40 rpm. Torque 2500 ft-Ibs with 2000 to 5000 Ibs WOB 7/3/2008 00:00 - 00:30 0.50 DRILL P TIEB1 Continue to dry drill at 40 rpm. Torque at 2500 ft-Ibs with 2000 to 5000 Ibs WOB. 00:30 - 01:00 0.50 DRILL P TIEBi Pump high visc sweep at 12 bpm with 1030 psi. Sweep bought back an increase in sand to surface. Retag top of sand at 3091'. Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 12 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 7/3/2008 01:00 - 01:30 0.50 DRILL P TIEB1 Monitor well and blow down top drive. 01:30 - 02:00 0.50 DRILL P TIE61 POOH standing back 4" HT-38 drill pipe in derrick. Bit hung while pulling through ES Cementer. S/O and work through with 5000 Ibs overpull. Ran back through cementer and worked through two more times without overpull. 02:00 - 02:30 0.50 DRILL P TIEB1 POOH and UD drill out assembly. Stand back 4 stands of 4-3/4" drill collars in derrick. 02:30 - 03:00 0.50 DRILL P TIEB1 R/U to test 9-5/8" casing patch. 03:00 - 04:00 1.00 CASE P TIEB1 Pressure test 9-5/8" casin atch to 3500 si. Hold test for 30 charted minutes ood test. Bleed pressure and R/D testing equipment 04:00 - 04:30 0.50 CASE P TIE61 P/U BHA #11 RCJB consisting of RCJB, (2) 7" boot baskets, bit sub, jars, x/o sub, 4 stands of 4-3/4" drill collars from derrick. Total length of BHA = 399.66'. 04:30 - 06:00 1.50 CASE P TIEB1 RIH with BHA on 4" HT-38 drill pipe from derrick. 06:00 - 07:30 1.50 CASE P TIEB1 Circulate sweep 8-BPM at 2100-psi, didn't detect hard materials while working down to 3102', 23' above the RBP. Saw lots of sand and some blackish- ra debris over the Monitor well, blow down Top Drive, and prepare to POOH. Saw a slight bobble while RIH through the ES Cementer, but did not see it when POOH. 07:30 - 09:30 2.00 CASE P TIEB1 P Hand S/B DP and DCs in Derrick. Clean out Boot Baskets and get 5-gallons of sand and blackish-gray debris as well as pieces of aluminum from the ES Cementer and plug. Find the remains of the 1/2 centralizer, which had been lost downhole, inside the JRCJB. Clear and clean Rig Floor. 09:30 - 10:00 0.50 CASE P TIEB1 M/U 2nd RCJB BHA, to include a 9-5/8" Casing Scraper to run through the ES Cementer. 10:00 - 12:00 2.00 CASE P TIEB1 RIH 2nd RCJB on DP and DCs from Derrick. Do not see anything in the ES Cementer area. 12:00 - 12:30 0.50 CASE P TIEB1 Wash down to 3114' with 5.5-BPM at 1020-psi at 10-RPMs. See sand in returns coming across the Shakers. 12:30 - 13:30 1.00 CASE P TIEB1 Circulate HiVis sweep all the way around at 7.5-BPM and 2040-psi; get sand across shakers. 13:30 - 14:30 1.00 CASE P TIEB1 POH S/B DP and DCs, cleanout boot baskets and get 1/2-gal of sand and cement. The JRCJB had small chunks of cement inside. 14:30 - 15:30 1.00 CASE P TIEB1 M/U 9-5/8" Halliburton RBP retrievin tool and RIH to 3,052'; get P/U wt 85K, S/O wt 90K, Continue to slowly RIH and tag to of RBP at 3124'. Set down 5000-Ibs to verify RBP. 15:30 - 16:30 1.00 CASE P TIEB1 Circulate 20-Bbls HiVis sweep, 9-BPM at 600-psi. 16:30 - 17:00 0.50 CASE P TIE61 P/U on RBP and overpull 5000-Ibs to ensure latch-up. Slackoff and set down 15,000-Ibs, then P/U and take overpull to 15-20-K-Ibs. Do this 3-times while working one full turn to the right into the RBP. RBP pulls free. RIH past setting depth to ensure RBP is free. 17:00 - 18:30 1.50 CASE P TIEB1 POH with HES RBP standing back 4" HT-38 drill pipe in derrick. UD RBP. 18:30 - 22:30 4.00 CASE P TIE61 RIH Haliburton RBP retrievin tool and to 11 102' 22:30 - 23:00 0.50 DHB P TIEB1 Establish parameters of P/U Wt- 215,000 Ibs; S/O Wt- 140,000Ibs. Tag HES RBP and set 5000 Ibs on RBP. P/U without RBP. S/O 10,000 Ibs on RBP. Circulate 5-Bbls. P/U with 5000 Ibs overpull. S/O and set 20,000 Ibs on RBP. Put 2 Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: ~ ~ ~ ~ Date Description of Operations From - To Hours Task ~ Code ~ NPT ~ Phase 7/3/2008 22:30 - 23:00 0.50 DHB P TIE61 right hand turns on RBP and pulled 15,000 Ibs overpull. Work sequence 3 more time to work torque down to tool. S/O 20,000 lbs. Put 1/4 right hand turn and pulled 20,000 Ibs to unset RBP. Relax elements and P/U 5'. Put 1 right hand turn into tool. P/U and release for ue. S/O 10' below set de th. 23:00 - 00:00 1.00 CASE P TIE61 CBU at 12.6 bpm with 3100 psi. No gas at bottoms up. Monitor well, no gain or losses, well stable. 7/4/2008 00:00 - 04:30 4.50 DHB P TIEB1 .POOH and stand back 4" HT-38 drill pipe in derrick. 04:30 - 05:00 0.50 DHB P TIE61 POOH and stand back 4 stands of 4-3/4" drill collars. L/D HES RBP and retrievin tool. 05:00 - 05:30 0.50 DHB P TIEBi Clear and clean rig floor. 05:30 - 06:00 0.50 CLEAN P DECOMP P/U clean out BHA consisting of 6" used bit, bit sub, 4 stands of 4-3/4" drill collars. Total length of BHA- 371.56'. 06:00 - 09:30 3.50 CLEAN P DECOMP RIH cleanout BHA on DCs and DP from Derrick to 11194'. Had to rotate to et throw h the 7" liner to at 9577'.. 09:30 - 11:00 1.50 CLEAN P DECOMP Slip and Cut drilling line. Service Top Drive, inspect Derrick. 11:00 - 14:00 3.00 CLEAN P DECOMP PJSM. Get parameters: P/U wt 225K, S/O wt 137K, Rot wt 170K, 50-RPM with 10K-Ib-ft free torque. Tag sand at 11,191' and wash down to 11 329', with 4 singles; get 2-Bbls loss during this time. Pump HiVis sweep to move sand uphole, 8-BPM at 1480-psi, 50-RPM and repeatedly reciprocating for one joint. See no sand across shakers during 600-Bbls of circulatio . P/U 'oints 5 and 6 and wash down to 11,384' and lose circulation while pumping 5-1/2-BPM at 680-osi. Calculated loss started at 240-Bbls at a pumping rate of 8-BPM. Back off to 6-BPM, 793-psi and reduce oss to calculated rate of 100-BPH 14:00 - 20:00 6.00 CLEAN P DECOMP Call ADW Engineer to discuss options. Program called for viscosifying the fluid system with FloPro and some calcium carbonate if the losses become severe. Decide to get MI to build three truckloads of FloPro viscosified fluid with calcium carbonate. First two truckloads to arrive -1800-hours. Reduce um in rate to 4-BPM, 390- si and et calculated loss ram tee 60-BPH. 20:00 - 21:30 1.50 CLEAN P DECOMP Losses at 50-BPH pumping at 4.7-BPM with 390 psi. While waiting for Flo Pro to arrive, P/U singles and continue washing and reamin throw h sand at 62 r m with 12,000 ft-Ibs for ue and 1000 to 2000 Ibs WOB; Pump rate at 4.7 bpm with 590 psi. Pumped high visc sweep. Washed and reamed to 11,542' where returns were lost. 21:30 - 23:30 2.00 CLEAN P DECOMP Stop drilling and fill hole by circulating long at 6.1 bpm and with the hole fill. Established returns with a loss rate of 96 bph.. Continue to circulate and monitor well. Loss rate continued to decrease to 45 bph while pumping 6.1-BPM with 100 psi. Continue to pump the high visc sweep out of the hole. Sweep brought back a slight increase of sand to the shakers. 23:30 - 00:00 0.50 CLEAN P DECOMP Isolate pit 3 for FloPro mud. Fill the rest of the mud system with seawater. Empty pit 3 of seawater. 7/5/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Load new FloPro mud into pit 3. 00:30 - 06:00 5.50 CLEAN P DECOMP Start pumping FloPro mud to bit at 5.2 bpm with 550 psi. Continue washing and reaming through fill at 60 rpm with 12,000 to 12,500 ft-Ibs torque and 1000 to 2000 WOB; Pump rate at 5.8 bpm with 500 psi. Dynamic losses averaging 5-6 Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 14 of 18 ~ Operations Summary Report Legal Well Name: Li -09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase j Description of Operations 17/5/2008 100:30 - 06:00 I 5.501 CLEAN I P ~ DECOMP ~ bpm. Losses increased as new washino and 06:00 - 07:00 1.00 ~ CLEAN P 07:00 - 09:30 2.50 ~ CLEAN ~ P 09:30 - 11:30 I 2.00 I CLEAN I P 11:30 - 12:00 0.50 CLEAN P 12:00 - 20:30 I 8.50 I CLEAN I P 20:30 - 21:30 I 1.00 I CLEAN I P 21:30 - 22:00 0.50 CLEAN P 22:00 - 22:30 0.50 EVAL P 22:30 - 00:00 1.50 EVAL P 7/6/2008 100:00 - 01:00 I 1.00 I EVAL I P 01:00 - 02:00 1.00 EVAL P 02:00 - 10:00 8.00 EVAL P 10:00 - 12:00 ~ 2.00 ~ EVAL ~ P 12:00 - 13:00 I 1.001 EVAL I P 13:00 - 13:30 I 0.501 WHSUR I P 13:30 - 15:30 2.00 reamin to 11 900' with same aarameters. -. _ DECOMP Fluid loss to formation increased. Tried to get a calculated fluid loss with charge pump but 4-BPM wouldn't keep up. Call ADW Engineer and decide to POH to a position above the Top of 7" Liner at 9577' to prevent being trapped by falling sand. Keep hole fill at 100-BPH and POH with 26-stands of DP, DECOMP v I hot from Wells Su ort. Did not find fluid level. Decide to pump last truckload of ProFlo to establish circulation, but did not see fluid at the surface after pumping 280-Bbls at 12-BPM and 50-psi. Talk with ADW Engineer and RWO Superintendent and decide to RIH to check for fill, using , 100-BPH hole fill. Call for another fluid level shot. DECOMP RIH with DP from Derrick, using constant hole fill of 100-BPH. Stop with Bit near top of Liner to allow the Wells Support Tech to shoot FL. Find FL at 1500'. Continue RIH to soft tag at TOL. P/U an start ro a ing at - PM and slip down through TOL. Stop rotating and continue RIH, do not tag any fill all the way to 11 900'. DECOMP Circulate 100-Bbls at 4.5 BPM 20-30- si. Get no returns. Inform ADW Engineer and RWO Superintendent that we will POH and UD DP. Cleanout mission accomplished. DECOMP PJSM. POH and UD DP through Pipe Shed. Joint # 30 UD at 1300-hours. Maintain constant hole fill at 100-BPH. DECOMP POH and UD cleanout BHA. UD (12) 4-3/4" drill collars in pipe shed. DECOMP Clear and clean rig floor. OTHCMP Install rig Dutch System riser for SWS Lubricator. OTHCMP Spot SWS a-line unit. Bring SWS tools and equipment to rig floor. R/U SWS. Continue hole fill at 100 BPH. OTHCMP Continue to R/U SWS a-line unit. R/U SWS BOPE with line wiper and pump in sub. Pressure test SWS BOPE equipment to 500 psi, hold test for 5 minutes, good test. OTHCMP R/U SWS logging tool BHA consisting of CCL, Gamma Ray, Sonic Scanner, and G Pit with PPC. OTHCMP RIH with sonic scanner logging tool. SWS reported logging tool having difficult travel through 10,500' to 10,800'. Make 3-passes at 500'/hr. Did not have any difficulty POH through 10,800' to 10,500'. OTHCMP POH with Sonic Scanner Lo in Tool. Hold PJSM with Evening Tour crew, Schlumberger, and WSL to discuss R/D and loading out the SWS equipment from the Rig Floor. OTHCMP PJSM with Schlumberger crew, rig crew, Toolpusher, and WSL. R/D SWS equipment. RUNCMP P/U test joint with wear ring run/pull tool and RIH to pull wear ring. RUNCMP PJSM for RIH with tubing with rig crew, Doyon Casing Tech, Baker Completions tech, Toolpusher, and WSL. R/U Doyon Casing torque turn equipment for RIH with 3-1/2" Vam Top Completion. At 1400-hours, Supersucker leaked seawater from snorkle into secondary containment that overflowed onto rig mat then onto ground. See "Remarks" for further information. Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations T 7/6/2008 15:30 - 21:30 - - 6.00 BUNCO - -- RUNCMP RIH with 118 joints of 3-1/2", 9.2#, 13Cr-80, VamTop com letion. Use Jet Lube eal Guard thread compound on all connections, torqued to 2900-Ib-ft. All connections below the Baker S-3 packer were Bakerlocked. 21:30 - 00:00 2.50 BUNCO RUNCMP RIH with 118 joints of 3-1/2" tubing to 3909' where gas and fluid started comin from the tubin strip .Rig crew stabbed the TIW valve and closed in the tubin strip . No flow was comin u the annulus. Annulus remained open. Called for fluid level shot to find out where the fluid was in the annulus. SITP was 90 psi at 21:30 and steadily increased to 280 psi at 23:50 hrs with no signs of fluid on the annulus side. Still maintaining 100 bph hole fill on the backside. Fluid shot showed the annulus level to, be at 426'. Indications were that gas was come to surface. Notified AOGCC, Bob Noble of situation at 23:00 hrs. 7/7/2008 00:00 - 01:30 1.50 BUNCO DPRB RUNCMP Shut in annular preventer and open choke position to full open. Break circulation by pumping down the tubing string at 3 bpm with 350 psi ICP. Continue pumping 35-Bbls to fill tubing string with 8.4 ppg seawater, FCP at 80 psi, gas and seawater coming from backside. Shut down circulation after filling the tubing string and monitor well, SITP- 0 psi, SICP- 450 psi. Break circulation and maintain constant casing pressure at 450 psi while bringing pump rate to SPR of 3 bpm with 80 psi for ICP. Maintain ICP while circulating out gas from the annulus side. After gas was circulated out of annulus, increase pump rate to 5 bpm while keeping casing pressure constant. Continue circulating at 5 bpm with 200 psi. Maintain 200 psi pump pressure at 5 bpm, finish circulating after pumping 1 wellbore volume at 3909'. FCP- 200 psi at 5 bpm, CSG pressure- 0 psi with choke wide open with no returns at surface. 01:30 - 02:00 0.50 BUNCO DPRB RUNCMP Shut down um and monitor well well on a vacuum. Take 2 fluid shots First shot at 990'. Second shot at 930'. R/D circulating equipment and prepare to RIH. Hold PJSM with rig crew on the probability of taking another kick and that each rig hand needs to know his job assignment before it comes. It was also brought up that we maybe able to get a warning of an upcoming kick by watching for any gas coming from the tubing string while RIH. uster 02:00 - 06:00 4.00 BUNCO RUNCMP Continue to RIH with 3-1/2" completion from 3909' to around 5800' where a small amount of gas was noticed on the tubing string. R/U an too a ui sot, morn or we w i e s noting fluid level, well appeared stable, fluid level at 1152'. R/U and position TIW valve in position to stab if needed. Continue RIH to 6042' where fluid started to spit from the tubing. Rig crew stabbed the TIW valve and closed in the tubing string. No flow was coming up the annulus. Shut in annular preventer and monitor well. SITP 40 psi, SICP- 0 psi. Contact and report well control situation to Bob Noble with AOGCC at 05:45 hrs. 06:00 - 08:30 2.50 BUNCO RUNCMP Circulate bottoms up through choke and gas buster: Time Rate DP Pres Csg Pres Volume 0600-hrs 3-BPM 70-psi 0-psi 33-Bbls 0624-hrs 3-BPM 70-psi 0-psi 77-BBIs 0641 3 70 90 113 Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours Task Code NPT ~ Phase li Description of Operations ~ - - - --- 7/7/2008 06:00 - 08:30 2.50 BUNCO RUNCMP 0651 3 80 400 148 0701 3 70 300 183 0706 3 70 200 217 0711 3 70 120 250 0715 3 70 50 282 0720 5 190 0 311 Fully open the choke and pump additional 300-Bbls. S/I to monitor and well is dead. Break off circulating line, floor valve and well is on a vacuum. Discuss the results with ADW-Anchorage and decide to perform a 1.5 Wellbore volume Bullhead down tubin and annulus into the erf . 08:30 - 12:00 3.50 BUNCO DPRB RUNCMP Wait on 4-truckloads, 290-Bbls each, of seawater to perform bullhead operations. 12:00 - 15:00 3.00 BUNCO DPRB RUNCMP PJSM with 6-CH2MHill drivers, Truck Pusher, Rig Crew, and WSL. R/U to pump 4-truckloads of seawater. Bring pumps up to 11-BPM, 340-350-psi, pumping down tubing and IA for 1160-Bbls. S/D pumps and open Hydril and hear IA on vacuum. Break off circulating line and floor valve. Tubing on vacuum. 15:00 - 16:00 1.00 BUNCO RUNCMP Resume RIH with new 3-1/2" VamTop completion. 16:00 - 16:30 0.50 BUNCO RUNCMP Sto at 7515' to um a tubin volume: 65-Bbls at 6-BPM and 240-psi. Baker confirmed that we needed to stay below 300-psi while pumping through the tubing. The tubing was on a good vacuum when the circulating line and floor valve were removed. 16:30 - 19:00 2.50 BUNCO RUNCMP Resume RIH with new 3-1/2" VamTop completion with a total of 278 joints to 9002'. 19:00 - 20:00 1.00 BUNCO RUNCMP Sto at 9002' to um a tubin volume:80-Bbls at 6-BPM and 240-psi. Baker confirmed that we needed to stay below 300-psi while pumping through the tubing. The tubing was on a good , va uum when the circulating line and floor valve were removed. Hold PJSM with rig crew, HES, and Baker completions. Discuss R/U and installation of HES SSSV. Install SSSV, make control line connections, and pressure test control line to 5000 psi, hold for 10 minutes, good test. R/D circulating lines. 20:00 - 21:30 1.50 BUNCO RUNCMP Resume RIH with new 3-1/2" VamTop completion and tag top of 7" liner at 9587'. Rotate 3/4" right hand turn to work through liner top. Continue to RIH with a total of 306 joints to 9895'. 21:30 - 22:30 1.00 BUNCO RUNCMP Sto at 9895' to um a tubin volume:80-Bbls at 3.7-BPM and 100-psi. Baker confirmed that we needed to stay below 300-psi while pumping through the tubing. The tubing was on a good vacuum when the circulating line and floor valve were removed. R/D circulating lines. 22:30 - 00:00 1.50 BUNCO RUNCMP Resume RIH with new 3-1/2" VamTop completion with a total of 336' joints to 10,786'. 7/8/2008 00:00 - 00:30 0.50 BUNCO RUNCMP Resume RIH with new 3-1/2" VamTop completion with a total of 346' joints to 11,150'. 00:30 - 01:30 1.00 BUNCO RUNCMP Stop at 11,150' to pump a tubing volume:96-Bbls at 3-BPM and 80-psi. Baker confirmed that we needed to stay below 300-psi while pumping through the tubing. The tubing was on a good vacuum when the circulating line and floor valve were removed. R/D circulating lines. 01:30 - 03:00 1.50 RNTBH P TUBHGR P/U joint 347 and RIH. P/U and M/U tubing hanger and test control lines to 5000 Ibs for 10 minutes, good test. Final Tally: Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i Date From - To Hours Task ;Code 17/8/2008 101:30 - 03:00 03:00 - 04:00 04:00 - 09:00 1.50 I RNTBHG P 1.00 RNTBH~ P 5.00 CONDH P 09:00 - 10:00 1.00 CONDH P 10:00 - 12:30 2.50 RUNCO 12:30 - 13:00 13:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 20:00 20:00 - 22:30 22:30 - 00:00 0.50 2.001 WHSUR I P Start: 6/15/2008 Rig Release: 7/9/2008 Rig Number: Page 17 of 18 Spud Date: 6/15/2008 End: 7/9/2008 NPT ' Phase Description of Operations TUBHGR I Ran 347 Bands to hold sin le 1/4" control line to SSSV 1 SSSV Assembly, 5 GLM Assemblies, 3 "X" Nipple Assemblies, 1 Baker S-3 Packer Assembly, WLEG, and FMC 13-5/8' x 4-1/2" TC-II Tubing Hanger with 4-1/2" x 3-1/2" X/O Pup Joint. TUBHGR RIH and land tubing hanger and completion. RILDS OTHCMP PJSM with rig crew, Baker completion tech, and CH2MHill. Discuss spotting packer fluid, assign job assignments to rig personnel. Reverse circulate 120 deg 8.5 ppg seawater treated with EC-1124A corrosion inhibitor at 3 bpm with 30 psi. Gas be an to mi rate u tubin stab floor valve on tubin and M/U flowline to the Choke manifold. Pinch back on choke and pressure climbs to 350-psi. Take surging gas and liquid returns throw h the choke and as buster. Returns reduce to liquid and 0-psi with choke fully opened after 2nd truck is hooked up and pumping down the IA. Still seeing some liquid coming through the choke after third truck is hooked up and pumping corrosion-inhibited fluid down the IA. Stop pumping with 800-Bbls pumped in IA. No pressure on tubing, but prepare to bullhead 100-Bbls hot seawater down tubing. OTHCMP R/U to bullhead 100-Bbls down tubing at 3-BPM, 30-psi. Tubing" is on vacuum. RUNCMP Dro ball and rod to set acker and chase with 1.1-BPM seawater from Pits since the tubing is on a vacuum. Ball/Rod on seat in 13-minutes. Pressure up to 3500-psi and hold for 30-minutes recorded on chart. Rock Solid test. Bleed off pressure on tubing to 1500 psi. R/U to pressure u on the IA, have to take on seawater to fill backside. Pressure up and test IA and Baker S-3 acker to 3500 si and hold for 30-charted minutes, good tes;. Bleed off pressure on the tubing to shrear DCR valve. DCR valve sheared with 900 psi on tubing. RUNCMP Line up and reverse circulate through the DCR valve at 3 bpm with 360 psi to confirme communication. Line up and pump down the tubing taking returns out the IA at 3 bpm with 320 psi to confirm communication through the DCR valve. RUNCMP Monitor well for flow. Pull landing joint. Install TWC. R/U and test TWC from below to 1000 psi for 10 charted minutes, good 1.00 WHSUR P RUNCMP Pull and L/D landing joint. Suck BOP stack dry, B/D and R/D circulating line. 1.00 WHSUR P RUNCMP N/D BOPE and secure to landing stump. 2.00 WHSUR P RUNCMP Clean and prep wellhead for tree and bonnet installation. Pressure test control line to 5000 psi for 10 minutes, good test. N/U adapter flange and test to 5000 psi for 30 minutes, good test. 1.00 WHSUR P RUNCMP P/U and N/U production tree as per FMC Tech. 2.50 WHSUR P RUNCMP R/U and test tree to 5000 psi for 30 charted minutes, good test. R/D test equipment. 1.50 WHSUR P RUNCMP P/U and R/U DSM lubricator tools and equipment to production tree. Test lubricator to 500 psi, good test. Pull TWC with 165 7/9/2008 ~ 00:00 - 00:30 ~ 0.50 ~ W HSUR ~ P ~ ~ RUNCMP ~ PJSM with rig crew, LRHOS, and DSM. Discuss the situation Printed: 7/23/2008 2:29:28 PM BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: L1-09 Common Well Name: L1-09 Spud Date: 6/15/2008 Event Name: WORKOVER Start: 6/15/2008 End: 7/9/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/9/2008 Rig Name: DOYON 16 Rig Number: Date i From - To Hours Task Code NPT Phase Description of Operations 7/9/2008 00:00 - 00:30 0.50 WHSUR P RUNCMP with this well having gas under the TWC. Discuss plan forward of R/D DSM and R/U LRHOS with a live well, then continue as planned to pump freeze protection. Discuss all risks and precautions associated with this operations. Make sure each team member understands and is comfortable with his job and assignments. 00:30 - 01:00 0.50 WHSUR P RUNCMP Pull TWC into tree above master valve. Shut in master valve. Bleed pressure off DSM lubricator. UD TWC. UD DSM lubricator and tools. Tubing and IA pressure at 170 psi. 01:00 - 01:30 0,50 WHSUR P RUNCMP R/U circulating lines to pump freeze protection with LRHOS down IA and to take returns up the tubing and through the choke. Pressure test circulating lines to 3500 psi, good test. 01:30 - 02:30 1,00 WHSUR P RUNCMP SICP at 200 psi, SITP 200 psi. Break circulation at 3 bpm with 600 psi ICP. Maintain 250 to 300 psi casing pressure. Pump 155 bbls diesel freeze protection. FCP at 900 psi. Shut down pumping operations and observe well for irregularities with 0 psi on tubing. 02:30 - 04:30 2.00 WHSUR P RUNCMP Shut in well. R/D circulating lines and R/U to U-tube freeze protection. Allow well to U-Tube. R/D rig floor for rig move to DS 05. Final tubing pressure- 200 psi. Final IA pressure- 200 psi. 04:30 - 06:30 2.00 WHSUR P RUNCMP R/U DSM lubricator and tools. Install lubricator to production tree. Pressure Test Lubricator to 500 si ood test. Set BPV. Pressure Test Under BPV to 1000 si for 10 mins with LRH S. Good Test - No Pressure seen on tree cap,. Suck Back and Blow Down Lines. 06:30 - 07:30 1.00 WHSUR P RUNCMP Rig Down LRHOS. Rig Down Secondary Annulus Valve. Secure All Tree Valves, Install Gauges and Jewerly on Tree. Suck Out Slop Tank and Rig Down Circ Manifold in Cellar. Release Rig at 07:30 Hrs on 07/09/2008. 07:30 - 0.00 WHSUR P RUNCMP Printed: 7/23/2008 2:29:28 PM L 1-09 Well Control Report • . Maunder, Thomas E (DOA) Page 1 of 2 From: Regg, James B {DOA) Sent: Thursday, July 10, 200$ 5;25 PM To: Maunder, Thomas E {DOA) Subject: FW: t.1-09 Well Control Report Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ~b~ \~~ From: Mabeus, Rodney E (M-I) [mailto:mabere@BP.comJ Sent: Monday, July 07, 2008 9:46 AM To: DOA AOGCC Prudhoe Bay Cc: Willingham, James M; Rossberg, R Steven; Rooney, Michael 5 (ORBIS ENGINEERING); Reem, David C; NSU, ADW Drlg Rig 16 Subject: L1-09 Well Control Report Gentlemen, As requested by AOGCC inspector Bob Noble, here is a description of the well control events for Doyon 16, July 6, 2008. Regards, Rodney Mabeus Doyon 16 WSL RIH with 118 joints of 3-1/2" tubing to 3909' where gas and fluid started coming from the tubing string. Rig crew stabbed the TIW valve and closed in the tubing string. No flow was coming up the annulus. Annulus remained open. Called for fluid level shot to find out where the fluid was in the annulus. SITP was 90 psi at 21:30 and steadily increased to 280 psi at 23:50 hrs with no signs of fluid on the annulus side. Still maintaining 100 bph hole fill on the backside. Fluid shot showed the annulus level to be at 426'. indications were that gas was come to surface. Notified AOGCC, Bob Noble of situation at 23:00 hrs. Shut in annular preventer and open choke position to full open. Break circulation by pumping down the tubing string at 3 bpm with 350 psi ICP. Continue pumping 35-Bbls to fill tubing string with 8.4 ppg seawater, FCP at 80 psi, gas and seawater coming from backside. Shut down circulation after filling the tubing string and monitor well, SITP- 0 psi, SICP- 450 psi. Break circulation and maintain constant casing pressure at 450 psi while bringing pump rate to SPR of 3 bpm with 80 psi for ICP. Maintain ICF while circulating out gas from the annulus side. After gas was circulated out of annulus, increase pump rate to 5 bpm while keeping casing pressure constant. Continue circulating at S bpm with 200 psi. Maintain 200 psi pump pressure at 5 bpm, finish circulating after pumping 1 wellbore volume at 3909'. FCP- 200 psi at 5 bpm, CSG pressure- 0 psi with choke wide open with no returns at surface. 9/17/2008 L 1-09 Well Control Report Page 2 of 2 Shut down pump and monitor well, well on a vacuum. Take 2 fluid shots First shot at 990'. Second shot at 930'. R/D circulating equipment and prepare to RIH. Hold PJSM with rig crew on the probability of taking another kick and that each rig hand needs to know his job assignment before it comes. It was also brought up that we may be able to get a warning of an upcoming kick by watching for any gas coming from the tubing string while RIH. Continue to RIH with 3-1/2" completion from 3909' to around 5800' where a small amount of gas was noticed on the tubing string. R/U and took a fluid shot, monitor well while shooting fluid level, well appeared stable, fluid level at 1152'. R/U and position TIW valve in position to stab if needed. Continue RIH to 6042' where fluid started to spit from the tubing. Rig crew stabbed the TIW valve and closed in the tubing string. No flow was coming up the annulus. Shut in annular preventer and monitor well. SITP 40 psi, SICP- 0 psi. Contact and report well control situation to Bob Noble with AOGCC at 05:45 hrs. 9/17/2008 L 1-09 info • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Baca, Hank [hank.baca@bp.com] Sent: Tuesday, Jufy O8, 2008 1:58 PM To: Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; Willingham, James M Subject: L1-09 info ~'~ Attachments: FW: L1-09---Request for Weekly BOP Test Deferral for Doyon 16---7/7/2008 ~ Q Q.,~ Gents, here's a brief summary of the well control event on Doyon 16 while on L1-09. ~ v While RIH w/ the completion gas was seen at surface. The well was shut-in and the kick circulated out. AOGCC (Bob Noble) notified. Approximately 1.5 x hole volume was then bullheaded down casing and tubing. The well went on vacuum. We staged into the hole with tubing, breaking circulation and pumping 1 tubing volume approximately every 1000'. The tubing was on vacuum after each circulation. The packer was set and casing and tubing both tested today. The emails between Mike Rooney and John Crisp regarding delaying the weekly BOP test are attached. «FW: L1-09---Request for Weekly BOP lest Deferral for Dayon 16---7/7/2008» Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 9J17J2008 L 1-09---Request for Weekly BQP Test Deferral for Doyon 16---7/7/2008 Page 1 of 1 • Maunder, Thamas E (DfJA) • From: Willingham, James M [James.Willingham@bp.comj Sent: Tuesday, July 08, 2008 12:46 PM O` To: Baca, Hank ~~ Subject: FW: L1-09---Request for Weekly BOP Test Deferral for Doyon 16---7/7/2008 \C~ From: Crisp, John H (DOA) [mailto:john.crisp@alaska.gov] Sent: Monday, July 07, 2008 8: i i PM To: Rooney, Michael S (ORRIS ENGINEERING); DOA AOGCC Prudhoe Bay; Regg, James B (DOA); aogcc_prudhoe_bay@admin.state.ak.us Cc: Willingham, James M; Rossberg, R Steven; Reem, David C; NSU, ADW Drlg Rig 16; Engel, Harry R Subject; RE: L1-09---Request for Weekly BOP Test Deferral for Doyon 16---7J7/2008 Thank you for the note & good luck with your Operation. From: Rooney, Michael S {ORBI5 ENGINEERING) [mailto:Michael.Rooney@bp.com] Sent: Monday, July 07, 2008 4:39 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); AOGCC prudhoe_bay@adminstate.ak.us Cc: Willingham, James M; Rossberg, R Steven; Reem, David C; NSU, ADW Drlg Rig 16; Engel, Harry R Subject: Li-09---Request for Weekly BOP Test Deferral for Doyon 16---7J7J2008 Gentlemen---I had a telephone conversation with John Crisp at about 1500-hours today regarding the weekly BOP test scheduled for Doyon 16 today, 7-July, in which I asked for and was granted a release from conducting the scheduled weekly BOP test for Doyon 16. When the packer is set on L1-09's completion, late tonight or early tomorrow morning, the only other operation to be conducted in the wellbore will be the circulation of freeze-protect fluid after the new wellhead has been installed. Doyon 16 is currently running the production completion tubing string and we hope to have it down near midnight tonight. Earlier today, Doyon 16 experienced a well control event when formation gas migrated to the surface, causing the completion operation to be shut-in to allow controlled circulation of the gas out of the wellbore. AOGCC was notified of this via an Email from Mr. Rodney Mabeus, Doyon 16 Wellsite Leader. Subsequently, it was decided that bullheading operations be conducted to prevent incursion of gas, which has further postponed the packer setting time. Since Doyon 16 is using constant IA hole-fill of 150-BPH while running the completion, we do not wish to P/U a Storm Packer to run in and set below the wellhead due to the likelihood of gas freely migrating up-hole, therefore it is our desire to defer the weekly test to the initial test after rigging up on our next rig workover scheduled for DS5-08. Please let me know if you require additional information. Sincerely, Mike Rooney, Wellsite Leader, Doyon 16 9n~/zoos oa/2s/os .~^~ i S~hlUmde~ge~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh ik N0.4843 Company: State of Alaska Alaska Oil & Gas Cons Comm c3~ ~ ~ ~j~~~ S ~ h ~ ~ ~~~~ Attn: Christine Mahnken J~0'ii r 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... no ..a:.... n... H-31 11999035 USIT ~ L - ~L - 08/16/08 _- _ 1v. 1 14-22A 11999036 PPROF W/FSI - 08/17/08 1 1 13-34 11676963 USIT a - 08/18/08 1 1 H-35 11970840 RST .. , 3 08/12/08 1 1 G-16 11982438 RST _ ~ C( 06/21/08 1 1 Li-09 12017501 CH EDIT (SONIC SCANNER) ~ '" 06/06/08 1 1 --~.+~.-...........~~.+.w.- ..w..~r ~ u. v~~arnn~a nnv nil Vnl~n~aa vl~c l.vr'i CN~.II ItJ: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~'' Date Delivered: ~{ ~{~ sg ~/~~~ --1.~ ~, v .... , %1~iiS~{ci tl'Ir cx (.a«~;'; I:CaY15. 1-.(~iTli(11"i3101j ,~I1~:~1t)Pc~C~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 Anchorage, AK 99503-2838 ATTN: Beth Received by: • i 07/14/08 S~h[umberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu .Ini. ~ NO.4779 Company: State of Alaska ~q q~y9~y Alaska Oil & Gas Cons Comm ur~"i.)@t1i~~ ~~L ~ ~~~~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I ,,,. r,es.. ...:,... .,_._ Li-09 11968948 LDL /~ZS. 06/19/08 1 -- _ 1 G-266 11978455 MEM PROD PROFILE 04/24/08 1 1 15-25B 12005210 MEM CBL ~j- 04/13/08 1 1 C-19B 12031482 USIT (~ 06/08/08 1 1 J-05B 12083400 MEM SBHP J 07/05/08 1 1 04-28 11968951 LDL ~ `- ~ ~ 06/29/08 1 1 Z-06 11975781 GLS 07/08/08 1 1 L1-09 11962605 USIT ' - ~ ~ 06/28/08 1 1 L1-09 12017501 SONIC SCANNER 07/06/08 1 1 04-43, 12031490 INJECTION PROFILE ( ~ _ ~ 07/08/08 1 1 r~ce~.~c r~a.nwvvr6CVVC nGliGll-1 of A1671VIIVl7 NIVU 11C 11J 17IVIIVl71 VIVO ~.VYT' CNGrI 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99505 ~ ~':i Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503- 38 ATTN: Beth Received by: • • ~~ L1-09 Well Control Report • Regg, James B (DOA) Page 1 of 1 ~`~ ~ `~ 5~ -moo I From: Mabeus, Rodney E (M-I) [mabere@BP.com] Sent: Monday, July 07, 2008 9:46 AM To: DOA AOGCC Prudhoe Bay Cc: Willingham, James M; Rossberg, R Steven; Rooney, Michael S (ORBIS ENGINEERING); Reem, David C; NSU, ADW Drlg Rig 16 Subject: L1-09 Well Control Report Gentlemen, As requested by AOGCC inspector Bob Noble, here is a description of the well control events for Doyon 16, July 6, 2008. Regards, Rodney Mabeus ~~ ~UL ~, s 2Da~i Doyon 16 WSL RIH with 118 joints of 3-1/2" tubing to 3909' where gas and fluid started coming from the tubing string. Rig crew stabbed the TIW valve and closed in the tubing string. No flow was coming up the annulus. Annulus remained open. Called for fluid level shot to find out where the fluid was in the annulus. SITP was 90 psi at 21:30 and steadily increased to 280 psi at 23:50 hrs with no signs of fluid on the annulus side. Still maintaining 100 bph hole fill on the backside. Fluid shot showed the annulus level to be at 426'. Indications were that gas was come to surface. Notified AOGCC, Bob Noble of situation at 23:00 hrs. Shut in annular preventer and open choke position to full open. Break circulation by pumping down the tubing string at 3 bpm with 350 psi ICP. Continue pumping 35-Bbls to fill tubing string with 8.4 ppg seawater, FCP at 80 psi, gas and seawater coming from backside. Shut down circulation after filling the tubing string and monitor well, SITP- 0 psi, SICP- 450 psi. Break circulation and maintain constant casing pressure at 450 psi while bringing pump rate to SPR of 3 bpm with 80 psi for ICP. Maintain ICP while circulating out gas from the annulus side. After gas was circulated out of annulus, increase pump rate to 5 bpm while keeping casing pressure constant. Continue circulating at 5 bpm with 200 psi. Maintain 200 psi pump pressure at 5 bpm, finish circulating after pumping 1 wellbore volume at 3909'. FCP- 200 psi at 5 bpm, CSG pressure- 0 psi with choke wide open with no returns at surface. Shut down pump and monitor well, well on a vacuum. Take 2 fluid shots First shot at 990'. Second shot at 930'. R/D circulating equipment and prepare to RIH. Hold PJSM with rig crew on the probability of taking another kick and that each rig hand needs to know his job assignment before it comes. It was also brought up that we maybe able to get a warning of an upcoming kick by watching for any gas coming from the tubing string while RIH. Continue to RIH with 3-1/2" completion from 3909' to around 5800' where a small amount of gas was noticed on the tubing string. R/CJ and took a fluid shot, monitor well while shooting fluid level, well appeared stable, fluid Level at 1152'. R/U and position TIW valve in position to stab if needed. Continue RIH to 6042' where fluid started to spit from the tubing. Rig crew stabbed the TIW valve and closed in the tubing string. No flow was coming up the annulus. Shut in annular preventer and monitor well. SITP 40 psi, SICP- 0 psi. Contact and report well control situation to Bob Noble with AOGCC at 05:45 hrs. 7/10/2008 • C®1~T~EIt~A 1~T C BSI1dT David Reem Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 • S,4R.4H P,4LIN, GOVERNOR Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-09 Sundry Number: 308-198 ~~~,tVNEf~ JUN ~ ~. 2D0~ Dear Mr. Reem: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 lg~-©o I Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~'d ~~~~ :% Cathy P. Foerster Commissioner DATED this~?'~-day of June, 2008 Encl. f~ STATE OF ALASKA ~^~~^C3~ ALA~OIL AND GAS CONSERVATION COM~ION ~~~ d1UN ® r~ !~ APPLICATION FOR SUNDRY APPROVAL ' 20 AAC 25.2so Alaska Oil & Gas Cons. mission 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing ®Repair Welly ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 185-001 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21265-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU L1-09 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028302' 44' ~ Prudhoe Bay Field / Lisburne Pool 12_ PRESENT WELL CQNDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14136' 10414' 11001' 8690' 11001 None Casin Len h iz MD TVD Burst Colla se S ru ral nd r 11 20" 11 110' 14 47 rfa 4002' 13-3/8" 4002' 3997' 4930 2670 Int rmediate 11095' 9-5/8" 11095' 8741' 6870 4760 Pr i n Liner 3009' 7" 9591' - 12600' 7810' - 9467' 8160 7020 Liner 1706' S" 12430' - 14136' 9399' - 10414' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11258' - 13530' 8828' - 9965' 3-1l2", 9.2# x 2-7/8", 6.5# L-80 11207' Packers and SSSV Type: 3-1/2" Camco'TRDP-4A' SSSV; Packers and SSSV MD (ft): 2089 ; 7" x 2-7/8" Baker'FH' packer 11137' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 15, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name D 'd Reem Title Engineering Team Leader -- Prepared By Name/Number: Signature Phone 564-5743 DateS2~ D Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: (~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity i~BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~~ ~~ \ ~~~~~~ Subsequent Form Required: ~,~^~~ \~J APPROVED BY C ~ "~ G ~ A roved B : COMMISSIONER THE COMMISSION Date / Form 10-403 Revised 02006 Submit In Duplicate / I GIN Al. ~~ s~~.. ~la~ ®~ ~oo~ OR by GP,~r~ L1-09 Rig Workover (Restore OA/IA integrity) • Scope of Work: Pull 3.5" L-80 completion, cut and pull 9-5/8" casing, tie-back w/ new 9-5/8" casing (cemented to surface), replace 9 5/8" hanger and primary pack-off, and run 3.5" 13 Cr-80 completion. Engineer: Hank Baca MASP: 2441 psi Well Type: Producer Estimated Start Date: June 15th, 2008 O 1 MIT OA PASSED DONE 05/27/08 C 2 Clean out sand lu to 11,207' MD min ID 1.74" . 2-7/8" tubin tail C«~ 11,207 E 3 Drift to 10,980' MD for 3-1/2" Power Jet cutter and 3.5" Fasdrill. Set 3-1/2" Fasdril C~ 10,975' MD. Eclipse packer set at 10,982' could not be pulled with coil. Power Jet cut tubing ~ 10,970 (Ref: 12/29/93 tubing summary). Jet cut desired to be 10' down on deepest full joint above the Ecli se acker. F 4 CMIT TxIA to 3500 psi for 30 minutes. Circulate well with seawater and FP w/ diesel thru the cut. Bleed WHP's to 0 si. O 5 PPPOT-T, -IC, check all LDS. O 6 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE with 3-~/z" x 6" VBR's and blind rams to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9 5/8" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Stack -50 ft of sand on RBP. 5. Mechanically cut 9 s/a" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/8" stub in preparation of casing overshot. Note: VBR's will not be changed to 9 5/8" pipe rams as (.~~ ~ ~5 the well has two tested barriers (Fasdrill @ -10,975 MD and RBP) to the reservoir. /~- 6. Run back in with new 9-5/$", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-5/g' pack-off to 3500 psi. Cer~nt new 9-5/8' casing to surface 7. Cleanout above 9-5/8" RBP. Pull 9-5/" RBP. ~KCSSv~cc. ~ ~S~t CAS 9. Fish or mill up remaining tubing and retrievable packer Ciz 11,137' 10. Run 3-~h" 13Cr-80 completion with Baker S-3 packer. ~ 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 13. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. ~= 4-1/16" CM/ WELLHEADS FMC ACTUATOR = BAKER KB.1-1.EV = '44' BF. ELEV = KOP = 4000' Max Angle = 67 @ 12600' Datum MD = 11,289' Datum TV D = 8900' SS 13-3/8" CSG, 72#, K-55, BTC, ID = 12.415" I-{ 4002• (JOINTS #1 8~ #1 = 88#, BTC, ID = 12.347") TOP OF 7" LNR 9591' 7" LNR, 29#, L-80, BTC, .0371 bpf, ID = 6.184" ~ 10788' Minimum ID =1.74" @ 11069' STRADDLE ASSY ANCHOR 9-5/8" CSG, 47#, L-80, BTC, ID = 8.681" 11095' TOP OF 20/40 SAND (07/02/07) 11001' ; 3-1/2" TBG, 9.2#, L-80, TDS/ NSCT, .0087 bpf, ID = 2.992" 2-7/8" TBG, 6.5#, L-80, EU~8RD, IPC, I~ ~ 0058 bpf, ID = 2.441" -- PERFORATK)N SUMMARY REF LOG: LDT/CNL ON 03/10/85 ANGLE AT TOP PERF: 64 @ 11258' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATK)N DATA • L 1-O ~ SAFETY NOTES 2089' 3-1/2" CAMCO TRDP 4A SSSV, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5252 5040 51 MERLA DMY RM 0 04/25/07 2 8506 7024 48 MERLA DMY RM 0 05/03/07 3 11041 8711 57 MERLA DMY RA 0 08/30/96 9591' (~ 7" x 5" LNR TOP PKR, ID = 7.50" 10788' H 7" TIEBACK SLV w / HYDRO HGR ID = 7.50" 10982' ECLIPSE SERIES III PKR LSTRADDLE ASSY, ID = 1.75" 11069' STRADDLEASSY ANCHOR ID = 1.74" 11105' 3-1/2" OTIS X NIP, ID = 2.813" 11123' 3-1/2" BKR SEAL ASSY (12.52' SEALS), ID = 2.327" 11124' 2-7/8" BKR PBR, ID = 2.441" 11137' 7" X 2-7/8" BKR FH PKR, ID = 2.441" 11174' 2-7/8" CAMCO D NIP, ID = 2.25" 11207' 2-7/8" TBG TAIL W/BKR SHEAR SUB, ID = 2.44" 11173' ELMD TT LOGGED 02/07/89 11285' 7" MARKER JOINT TD (TAGGED 10/03/06) 11973 ELM TOP OF 5" LNR ~-{ 12430' 7" LNR 29#, L-80, BTC, .0371 bpf, ID = 6.184" C 5" LNR, 17.9#, SS95, FL4S, .0178 bpf, ID = 4.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/18/85 ORIGINAL COMPLETION 04/25/07 DAV/TLH GLV GO 01/03/94 N2ES ItWO 05/05/07 SWGPAG GLV GO (OS/03!07) 05/31/06 DTM WELLHEAD CORRECTION 07/22!07 DMS/PJC 20/40 SAND DUMP(07/07/07) 10/03/06 BSE/PAG ECLIPSE PATCH CORRECTON 11/17/07 JN/PJC 7" LNR/SAND DEPTH CORRECTK 02/28/07 RL DATUM MD 04!11/07 DRS/PJC TBG, CSG, TD CORRECTK)NS ~ TOP OF CMT /SAND PLUG (02/27/89) ~ ~ 5" BKR MC HYDRAULK: HGR, ID = 4.25" ~ LISBURNE WELL: L1-09 PERMff No: 1850010 API No: 50-029-21265-00 SEC 1, T11 N, R14E, 2448' FWL ii< 2183' FSL BP Exploration (Alaska) E= 4-1/16" CNV WELLHEAD'= FMC ACTUAACTUA BAKER KB.'E1EV = ''4 , BF. ELEV = KOP = 4000' Max Angle = __ 67 @ 12600' Datum MD = 11,289' Datum TV D = 8900' SS L1-09 PROPOSED 13-3/8" CSG, 72#, K-55, BTC, ID = 12.415" ~-~ 4002, (JOINTS #1 8~ #1 = 88#, BTC, ID = 12.347") TOP OF 7" LNR 9591' 7" LNR, 29#, L-80, BTC, .0371 bpf, ID = 6.184" 10788' 9-5/8" CSG, 47#, L-80, BTC, 1D = 8.681" ~ 11095' 3-1/2" 9.3#/ft, 13Cr-80, Vam Top - -11,207` PERFORATKN SUMMARY REF LOG: LDT/CNL ON 03/10/85 ANGLE AT TOP PERF: 64 @ 11258' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA TD (TAGGED 10/03/06) 11973 ELM TOP OF 5" LNR ~ 12430' 7" LNR, 29#, L-80, BTC, .0371 bpf, ID = 6.184" 12600' PBTD 14019' 5" LNR, 17.9#, SS95, FL4S, .0178 bpf, ID = 4.276" 14136' SAFETY NOTES GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4325 2 6817 3 8466 4 9510 5 10939 NEW 9-5/8" CSG, 47#, L-80 from TOC to surface 9591' 7" x 5" LNR TOP PKR, ID = 7.50" 10788' 7" TIEBACK SLV w / HYDRO HGR, ID = 7.50" - 3.5" X NIPPLE 3.5" X NIPPLE 3.5" XN NIPPLE 11173' ELMD TT LOGGED 02/07/89 11285' 7" MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 04/18185 ORIGINAL COMPLETION 04/25/07 DAV/TLH GLV GO 01/03/94 N2ES RWO 05/05/07 SWGPAG GLV GO (05/03/07) 05/31/06 DTM WELLHEAD CORRECTK)N 07/22/07 DMS/PJC 20/40 SAND DUMP(07/07!07) 10/03/06 BSEJPAG ECLIPSE PATCH CORRECTK)N 11/17/07 JWPJC 7" LNR/SAND DEPTH CORRECTK 02/28/07 RL DATUM MD 04/11/07 DRS/PJC TBG, CSG, TD CORRECTIONS ~ 5" BKR MC HYDRAULK; HGR, ID = 4.25" ~ LISBURNE WELL: L1-09 PERMfT No: 1850010 API No: 50-029-21265-00 SEC 1, T11N, R14E, 2448' FWL & 2183' FSL BP Exploration (Alaska) Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 09, 2008 9:53 AM To: 'Baca, Hank' Cc: Worthington, Aras J; Reem, David C Subject: RE: L1-09 (185-001) Workover Hank, Thanks for the information. No need to send a revised copy. I will place a copy of this message in the file. Since you won't be running 2-718" pipe, you are correct there shouldn't be any need for the pipe rams. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Monday, )une 09, 2008 9:49 AM To: Maunder, Thomas E (DOA) Cc: Worthington, Aras J; Reem, David C Subject: RE: L1-09 (185-001) Workover Sorry Tom, was out Friday. Basically step 8 shouldn't have been in there. We're planning to pull the 2-7/8"x 7" retrievable packer and remaining tubing with the plug still in the tubing. We want to leave the sand below the tubing tail to slow losses while working and then clean it out with coil after the rig moves off. There shouldn't be any need for 2-7/8" pipe or rams in this case. Sorry for the mistake and thanks for catching that. Do I need to get a revised copy to you? Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 09, 2008 9:40 AM To: Baca, Hank Cc: Worthington, Aras J; Reem, David C Subject: RE: L1-09 (185-001) Workover Hank, et al, I am waiting on your response regarding this proposed workover, Look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, June 05, 2008 4:01 PM To: Worthington, Aras J Subject: FW: Li-09 (185-001) Workover I guess you drew Dave's short straw. 6/9/2008 ~_ Page 2 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, June 05, 2008 3:59 PM To: 'Baca, Hank' Cc: Reem, David C Subject: Li-09 (185-001) Workover Hank and Dave, I am reviewing the 403 for this workover and have a couple of questions ... 1. When the F~sdrill plug is milled (step 8), will the mill be sized to pass through the eclipse packer @ 10980? 2. Although not stated, is the intent also to wash out the sand? 3. Will the BOP be equipped with 2-7/8" rams during this operation? Thanks in advance. Tom Maunder, PE AOGCC 6/9/2008 Sehlumbargep ..... E·ïVE·~ ,.-~) R,EC ....1 ~_I-· /15~ -CO! 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambel/ Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL 3 0 Z007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r-\)b ~ 1 lf0f)l I\laska Oil & Gas COi.-l$. commL5~~\\,\eJ -\ ,~nchor¿¡ge 5~" Well Job# Log DescrIPtion Date L o or 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07 A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 Field: Prudhoe Bay Endicott B C I CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: dVJ . STATE OF ALASKA I ALA Oil AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Plug Perforations Performed: Alter Casing D Pull Tubing D Perforate New Pool Change Approved Program D Ope rat. Shutdown c:r- Perforate 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: Name: Development w 3. Address: P.O. Box 196612 Stratigraphic Anchorage, AK 99519-6612 7. KB Elevation (ft): 44 KB 8. Property Designation: ADLO-028302 / 11 . Present Well Condition Summary: Total Depth measured 14136 ' true vertical 10416 / feet feet Effective Depth measured 11806 true vertical 9114 feet feet Casing Conductor Surface Intermediate Liner Liner Length 80' 3972' 11095' 2996' 1695' Size MD Surface - 110' Surface - 4002' Surface 11095' 9604' - 12600' 12441' 14136' 20" 13-3/8" 72# K-55 9-5/8" 47# L-80 7" 29# L -80 5" 17.9# SS95 FL4S Perforation depth: Measured depth: 11258' - 12972 True Vertical depth: 8852' - 9638' - - Tubing: (size, grade, and measured depth) 2-7/8" 6.5# 3-1/2" 9.2# 7"X2-7/8" BKR FH PKR o o o Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ Stimulate D Oth0 Waiver D Time ExtensiD Re-enter Suspended wD 5. Permit to Drill Number: Exploratory Service 185-0010 /' 6. API Number: 50-029-21265-00-00 / 9. Well Name and Number: L 1-09 / 10. Field/Pool(s): PRUDHOE BAY Field/ LISBURNE OIL Pool - Plugs (measured) CTU/Sand plug 11840 Junk (measured) None TVD Surface - 110' Surface - 3995' Surface - 8775' 7816' - 9468' 9400' - 10111' Burst 3700 6870 8160 5~ JUL 1 '1 2007 - - L-80 L-80 11123' - 11207' Surface - 11123' 11137' o o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 383 SHUT-IN Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 4857 1376 0 000 15. Well Class after proposed work: Exploratory Development W 13. x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Service WINJ Title Data Management Engineer Date 7/3/2007 Signature Phone 564-4944 Form 10-404 Revised 04/2001 'OR I GIN At R8DMS BFL JUl ¡ 61Di-... II.,. ~ 7~;~h71 Only SET SAND PLUG I2P ::) Ø} ¡..o< C'> "" :::r ('j t:\.'I (t"'.J {~..:.' -J ;> '3 ª. tn Ifi g" Collapse 2230 4760 7020 Tubing pressure 745 o W DS P L . . LI-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 81 Diesel 76 Dirty sand slurry 10 Clean HEC Gel 160 Fresh Water 327 Total . . 6/29/2007 MIRU CTU #5. ***Publishing to InterAct*** MU BHA w/ 1.9 fluted CTC and 1.75" BDN. RIH. Load IA with 15 bbls of 50/50 meth and 580 bbls of 9.8 ppg NaCI brine. Load tubing with 32 bbls of 50/50 meth and 141 bbls of 9.8 ppg NaCI brine. Land nozzle at 10,.925' CTM. Pump 17,300 Ibs of 20/40 sand in 30# HEC gel at 6 ppg. PUH to 5240' to wait for gel to break. RIH to 10900' to varafiy tubing is clear. Park and get fluid levels shot 15 min apart 1 st level shot @ 1020' 2nd shot @ 1090' LLR of .3 bbl/min. Start circing gas out of IA ***Continue job on 6/30/2007*** 6/30/2007 *** ASSIST CTU#5 , WELL S/I ON ARRIVAL *** (tag sand top) DRIFTED W/1.5" SAMPLE BAILER, TAGGED TD @ 11 ,948'SLM , NO SAMPLE ***WELL OVER TO CTU#5 ON DEPARTURE*** 6/30/2007 000/500. TBG & IA FL (for CTU). FL unreadable. IA FL @ 1020'. Shot a second FL 20 minutes later at 1098'. 6/ 260/1940/400 Assist CTU # 5 pump as directed--- Pumped 8 bbls neat 693 bbls 80*f crude down the IA. Final WHPs 552/500/550 6/30/2007 CTU #5 ***Continue job from 6/29/2007*** InterACT publishing during job. Pump 80 bbls down IA to make sure clear of sand. Swap down CT caught fluid at 24 bbls pumping @ 2.4 bpm continued pumping to hold 800 psi circulating pressure. Pump down backside of CT at 3 bpm zero WHP. Rig up Slickline and drift through Eclipse Series III Packer to find sand top. Tagged hard bottom @ 11948' SLM. POOH & RD Slickline. MU BHA w/ 1.75 BDN. RIH. Load IA with 675 bbls of crude. Load backside with 80 bbls of diesel. Pump 17,300 Ibs of 20/40 sand in 30# HEC gel at 8 ppg. Wait for gel to brake and drift back down to top of Eclipse packer. Pumped down IA and backside of CT in an attempt to find out if sand dump covered perfs. POOH for Slickline. in ***Continue job after safety stand down*** RIH w. 1.75" sand dump nozzle w/ 1" hole CTU #5 ***Continue job from 6/30/2007*** publishing during job. Set down CT injector & RU Slickline. RIH with 1 1/4" tool string w/ 1.725" centralizer. Sat down on lower anchor assembly at 11,069' slm. RIH w/ 1.5" centralizer and tag sand top at 11,781' slm. Filled rat hole to bottom of perf interval. RIH w/ 1.71" centralizer to 11,200'. Passed through lower patch anchor assembly. POOH and secure well for safety stand down. ***Continue job after stand down*** WELL IN ON ARRIVAL *** (tag sand top) DRIFTED W/1.725 CENT & SAMPLE BAILER TO 11 ,048'SLM(BTTM ANCHOR) , UNABLE TO WORK PAST. DRIFTED W/1.5 CENT & S.B. TO 11 ,784'SLM , REC. 1/2 CUP OF SAND. DRIFTED W/1.71 CENT TO 11 ,200'SLM WINO PROBLEMS. ***WELL TURNED CTU #5 ***Continue job from 7/1/2007*** RIH w. 1.75" sand dump nozzle w. 1" hole. Park CT @ 10900' Pumped 17,300 Ibs of 20/40 mesh sand. Saw climbing @ 63.3 bbls of slurry out nozzle, lay in last 13.7 bbls of slurry @ 1:1 Park CT. After 1 hr sand out nozzle bring pump on at min rate pumped .8 bbls WHP/IAP came up 60 psi and held. Stopped pump and RIH looking for sand top. RIH WHP/IAP increased let build up to 700 psi and took returns holding 500 psi. Drifted to 10,900' no problems. POOH pumping @ CT displacement. Rig up slickline unit with 1.5" centralizer and sample bailer. Tag 11,001' SLM. Sat down several times and unable to make further progress. POOH and sample bailer full of sand. Pump 73 bbls of 9.8# NaCI brine down while taking returns from IA. Allow tubing and IA to U-tube to freeze protect. RDMO. *** Job complete*** uPDATE: Ll-09 (pTD #185.0) UNDER EVALUATION for Sustai¡ casing pressur... Page 1 of2 Maunder, Thomas E (DOA) From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Monday, June 25, 2007 3:57 PM Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; James Regg; tom_maunder@admin.state.ak.us; bob_fleckenstein@admin.state.ak.us; Nash, Justin; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer Subject: UPDATE: L 1-O&(PTD #1850010\ UNDER EVALUATION for sustained casing pressure - TxlA Communication Sent: To: All, Coiled tubing was unsuccessful at pulling the Eclipse patch and killing L 1-09, despite the 2100 bbls of water pumped. The following is the updated plan forward for the well: 1. E: Temp log 2. F: Pump designed load & kill Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, June 06, 2007 2:46 PM To: GPB, LPC DS Ops Lead¡ GPB, GPMA OTL¡ GPB, Area Mgr North (Gas Plants/GPMA)¡ Rossberg, R Steven¡ Engel, Harry R¡ NSU, ADW Well Operations Supervisor¡ GPB, Wells Opt Eng¡ GPB, Optimization Engr¡ 'James Regg'¡ Tom_Maunder@admin.state.ak.us¡ Bob_Fleckenstein@admin.state.ak.us¡ Nash, Justin¡ NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer¡ Winslow, JaCk l. Subject: L1-09 (PTÐ #1850010) UNDER EVALUATION for sustained casing pressure - TxIA Communication Hi everyone, Welll1-09 (PTD #1850010) has sustained casing pressure on the IA. The well has a know tubing leak at gas lift mandrel #3 that was previously patched. The wellhead pressures were 2540/2560/590 on 06/03/07. The well has been classified as Under Evaluation under a 28-day clock and should remain shut-in. Plans are progressing to pull the failed patch and set a new patch. The plan for ward is: 1. D: TIFL - FAilED 2. F: load & kill - DONE 3. S: Pull Eclipse Patch 4. E: Set Patch A wellbore schematic has been included for reference. 7/16/2007 Ll-09 (PTD #1850010) UNDER EVALUATION for sustained casing... e e Subject: LI-OCJ(PfÐ #1 850010) UNDER EVALUATION for sustained casing pressure - TxIA Communication From: "NSU, ADW Well Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com> Date: Wed, 06 Joo 200714:46:25 -0800 To: "GPB, LPC DS Ops Lead" <GPBLPCDSOpsLead@BP.com>, "GPB, GPMA OTL" <GPBGPMAOTL@BP.com>, "GPB, Area Mgr North (Gas Plants/GPMA)" . <GPB _ AreaMgrNorth@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "Engel, Harry R" <Harry.Engel@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, James Regg <jim _regg@admin.state.ak.us>, tom_ maooder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us, ''Nash, Justin" <Justin.Nash@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com> cc: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com> Hi everyone, Well L 1-09 (PTD #1850010) has sustained casing pressure on the IA. The well has a know tubing leak at gas lift mandrel #3 that was previously patched. The wellhead pressures were 2540/2560/590 on 06/03/07. The well has been classified as Under Evaluation under a 28-day clock and should remain shut-in. Plans are progressing to pull the failed patch and set a new patch. The plan for ward is: 1. D: TIFL - FAILED 2. F: Load & kill - DONE 3. S: Pull Eclipse Patch 4. E: Set Patch SCANNED JUN 1 4 2007 A wellbore schematic has been included for reference. «L 1-09.pdf» Please call with any questions. Thank you, }lnna (j)u6e, œ. Œ. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 T 1 An .,,... 4-1/16" CIW FMC ~"''''''~".,'-'-''=''','''''','''''''''''=== BAKER 44' 4000' ax Angle - ~@L~2600' Datum MD = 11,289' Datum 1VD - 8900' SS 1-09 .FETY NOTES: 2089' -13-1/2" CAMCO TRDP-4A SSSV, ID = 2.813" GAS LIFT MANDRELS ST MD 1VD VLV LA TCH PORT DATE 1 5252 5040 51 MERLA DMY RM 0 04/25/07 2 8506 7024 48 MERLA DMY RM 05/03/07 3 11041 8711 57 MY 08/30/96 13-3/8" CSG, 72#, K-55, BTC, ID = 12,415" (JOINTS #1 & #1 <= 68#, BTC, ID <= 12.347") I TOP OF 7" LNR I 9604' 17" LNR, 29#, L-80, BTC, .0371 bpf, 10 - 6.184" I 10788' Minimum ID = 1.75" @ 11032' ECLIPSE SERIES III PKR 19-5/8" CSG, 47#, L-80, BTC, ID = 8.681" I 3-1/2" TBG, 9.2#, L-80, TOSI NSCT, .0087 bpf, 10 = 2.992" 2-7/8" T8G, 6.5#, L-80, ElJE-8RD, IPC, .0058 bpf, 10 = 2.441" PERFORA TION SUMMARY REF LOG: LOT/CNL ON 03/10/85 ANGLE AT TOP PERF: 64 @ 11258' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORA TION DATA ITD (TAGGED 10103/06) I !TOPOF 5" LNR I I 7" LNR, 29#, L-80, BTC, .0371 bpI, 10 = 6.184" I I FBTO I 15" LNR, 17.9#, SS95, FL4S, .0178 bpf, 10 = 4.276" DA TE REV BY COMMENTS 04/18/85 ORIGINAL COM PLETION 01/03/94 N2ES RWO 11/20/01 DDVV/KA PKR STRADDLE ASSY 03/07/04 OAV/TLP GLV C/O 05/31/06 DTM WELLHEAD CO 10/03/06 BSEiPA G ECLIPSE PA TCH CORRECTION DATE 02/28/07 04/11/07 04/25/07 05/05/07 -17" x 5" LNR TOP PKR, ID = 7.50" I -17" TIEBA CK SL V wi HY ORO HGR, ID - 7.50" 3-1/2" BKRSEALASSY (12.52' SEALS), ID = 2.327" 11124' -12-7/8" BKR PBR,ID = 2.441" 11137' -17" X 2-7/8" BKR FH PKR, ID = 2,441" 11174' -12-7/8" CAMCO D NIP, ID = 2.25" I 11207' -12-7/8" TBG TAil W/BKR SHEAR SUB, ID = 2.44" H ELMD TT LOGGED 02/07/89 I -17" MARKER JOINT I ??? H TOP OF C~.AT / SAND PLUG (02/27/89) I 12430' 12430' -15" BKR Me HYDRAULIC HGR, 10 = 4.25" I REV BY COMMENTS RL DA TUM MD DRS/PJC TBG, CSG, TO CORRECTIONS DAVITLH GlV ClO SWC/PAG GlV ClO (05/03/07) LISBURNE WELL: L 1-09 PERMrr No: '1850010 API No: 50-029-21265-00 SEC 1, T11N, R14E, 2448' FWL & 2183' FSL BP Exploration (Alas ka) . SIZE INTERV A Op DATE 4" 11258 - 11278 0 01/15/86 4" 11292 - 11328 0 01/15/86 4" 11334 - 11378 0 01/15/86 4" 11393 - 11401 0 01/15/86 4" 11407-11415 0 01/15/86 4" 11442 - 11462 0 01/15/86 4" 11471 - 11478 0 01/15/86 4" 11506-11514 0 01/15/86 4" 11521 - 11542 0 01/15/86 4" 11548 - 11563 0 01/15/86 4" 11568 -11572 0 01/15/86 4" 11576 - 11612 0 01/15/86 4" 4 11621 - 11628 0 01/15/86 4" 4 11633 - 11646 0 01/15/86 4" 4 11681 - 11696 0 01/15/86 4" 4 11706 - 11712 0 01/15/86 4" 4 11730 - 11760 0 01/15/86 4" 4 11770 - 11780 0 01/15/86 4" 4 11818 - 11830 S 02/27/89 4" 4 11838 - 11848 C 01/15/86 4" 8 12966 - 12972 C 01/15/86 4" 8 12998 - 13008 C 01/15/86 4" 8 13066 - 13126 C 01/15/86 4" 8 13246 - 13254 C 01/15/86 4" 8 13270 - 13280 C 01/15/86 4" 8 13395 - 13425 C 01/15/86 2-118" 4 13484 - 13530 S 05/14/85 4" 8 13507 - 13530 C 01/15/86 DA TE REV BY COMMENTS 04/18/85 ORIGINAL COMPLETION 01/03/94 N2ES RWO 11/20/01 DDW/KA PKR STRADDLE ASSY 03/07/04 OAVITLP GLV C/O 05/31/06 DTM WELLHEAD CORRECTION 10/03/06 BSEiPAG ECLIPSE PA TCH CORRECTION DATE 02/28/07 04/11/07 04/25/07 05/05/07 L 1-09 REV BY COMMENTS RL DA TUM MD DRS/PJC TBG, CSG, TO CORRECTIONS DA V /TLH GL V C/O SWClPAG GLV ClO (05/03/07) . LISBURNE WELL: L 1-09 PERMrr No: "1850010 API No: 50-029-21265-00 SEC 1, T11 N, R14E, 2448' FWL & 2183' FSL BP Exploration (Alaska) -'" .',,_., r".' -'.-"::.1 ,"'-, ({,¡ì"'jr~!t\"'I¡ If' \:-'::'!ii¡\\ ,¡~:j ,,) II[<'-J\li lL æf 1- J"\J ) _i ('r:1'\ I' 'f':) ! ¡! L.~ llliLf r¡~\ i ¡ (¡t:; (.-fLJ r~// (¡ \ I '\ \ " . \' ". " " I ¡ j' \ I f i . '. ".', ! \ :' , \ LA~ L6l(-1:J @ U~ if\,} ! i FRANK H. MURKOW5KI, GOVERNOR ! Î / AI.ASKA OIL AND GAS CONSERVATION COMMISSION ! 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501'3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr, Bruce J, Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc, P. O. Box 196612 Anchorage, AK 99519-6612 Ig~--,ôo I . Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location Date of SVS Test Failure Rate PBU Ll April 23, 2004 30,0% PBU L2 April 26, 2004 16.7% PBU L3 April 27, 2004 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25,265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS, Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \\I't th SVS test. Sincerely, ÇJ~ Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/2312004 Unit/Field/Pad: Greater Pt McIntyre/Lisburne/Ll Separator psi: LPS 450 HPS 450 Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI LI-0l 1850550 7/19/2003 SI LI-02 1851720 450 350 320 P 5 P 4/27/2004 OIL L1-09 1850010 450 700 690 P P P OIL LI-10 1850830 4/30/1990 SI Ll-14 1851400 3/10/1996 SI Ll-15A 2031200 450 350 350 P P P OIL Ll-21 1780300 450 600 550 P 5 P 4/27/2004 OIL Ll-27 1891220 5/1 0/1994 SI LI-28 1880250 12/17/1992 SI LI-30 1900180 3/28/1995 SI LI-31 1980150 450 350 350 P 5 P 4/27/2004 OIL Wells: 5 Components: 10 Failures: 3 Failure Rate: Remarks: L1-02 4/23/2004: Called grease crew and heater LI-21 4/23/2004: Called grease crew Ll-31 4/23/2004: Called grease crew Page 1 of 1 SVS PBU LIS L 1 04-23-04,xls Date: Subject: From: To: G(eaterr ARCO Alaska Inc. Point Mclntyre Engineeri',tg March 7, 1994 Transmittal Number 704 ARCO Alaska, Inc. Bob Crandall AOGCC 3001 Prokupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated: L1-09 LOG: Leak Detection Log SPIN/TEMP/PRESS 1~ 10/23/93 Schlumberger L3-28 L4-02-' L4-02 L4-02, LPC-2 Collar Log (Jet Tubing Cutter) (~ 12/11/93 ~-~- -Ct ~ q Ultrasonic Imager (USIT) Casing Inspection Log ~) 12/23/93 loo - t t ~ :ZC~ ~51 f Ultrasonic Imager (USIT) Cement Evaluation v- (~ 12/23/93 Log %\bO - ~ y'4- 3.o ~'~ Collar Log (Bridge Plug Record) ~ 12/25/93 Boo--- 11-2(-00 ~ Tape: Dual Prop Resistivity, GR, also Depth- shift Data w/LIS Verification and blackline 5/13/93 Atlas Schlumberger Schlumberger atlas BakerHughes Please sign Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 i STATE OF ALASKA ..... ALASKA OIL AND GAS CONSERVATION COMMISSI({,,.. REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2422' NSL, 2468' EWL, SEC. 1, T11N, R14E At top of productive interval 1466' SNL, 1147' WEL, SEC. 11, T11N, R14E At effective depth 1771'SNL, 1478'WEL, SEC. 11, T11N, R14E At total depth 2413' NSL, 2264' EWL, SEC. 11, T11N, R14E 12. Present well condition summary Total depth: measured true vertical 14136 feet Plugs (measured) 10416 feet 6. Datum elevation (DF or KB) 44 7. Unit or Property name Lisburne 8. Well number L1-9 9. Permit number/approval number 85-1/93-330 10. APl number 50- 029-21265 11. Field/Pool Lisburne Oil Pool CTU/Sand plug to 11840', cement to 11806' Effective depth: measured true vertical 11806 feet Junk (measured) 9114 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 1800 # Polyurethane 3972' 13-3/8" 3200 sx "E'Y400 sx "G" 11095' 9-5/8" ~ooo sx "G"/3oo sx CS I 2996' 7,, ~o4o sx "G"/280 sx "G" 1695' 5" 100 SX Class "G" measured 11258'- 11780' (Nineteen open intervals) Measured depth True vertical depth 110' 110' 4O02' 3995' 11095' 8775' 9604'-12600' 7816'9468' 12441' 14136' 9400J-10111' RECEI. VED true vertical 8852,9101'(Nineteen open intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 tubing, to 11123'MD JAN 19 t994 0[1 & (~as Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker "FH"packer @ 11102'MD; 3-1/2" Camco TRDP-4A SSS V @ 2083' MD feet 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Avera(]e Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned ~f'~~ TitleDrillincjEncjineerSupervisor Form 10-404 Rev 06/15/88 Date I' SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: L1-09 BOROUGH: NORTH SLOPE UNIT: LISBURNE FIELD: LISBURNE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/26/93 09:00 SPUD: RELEASE: 12/29/93 10:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 2ES 12/27/93 (1) TD:14136 PB:l1806 12/28/93 (2) TD:14136 PB:l1806 LD TBG MW: 9.4 FSW MOVE RIG. ACCEPTED RIG 12-26-93 @ 09:00 HRS. TAKE ON SW, CIRC OUT DIESEL CAP. TEST CSG. SET BPV. ND TREE, NU BOPE. MU LDG JTS, PULL PIPE FREE. TEST BOPE, LD TBG. PU TBG MW: 8.5 Seawater LD TBG. CHG RAMS, TEST BOPE. CLEAN & STRAP TBG, PU TBG & TRIP IN HOLE. 12/29/93 (3) TD:14136 PB:l1806 SPACE OUT TBG MW: 8.5 Seawater CONT PU TBG & TEST. CIRC. POH. RUN COMPLETION. SPACING OUT TBG. 12/30/93 (4) TD:14136 PB:l1806 RELEASE RIG MW: 8.5 Seawater SPACE OUT TBG, TEST LINES & TBG. FREEZE PROT WELL, SET BPV. ND, NU. SET TREE TEST PLUG & TEST. SECURE TREE. RELEASE RIG 12-29-93 @ 22:00 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED JAN 1 9 t994 0]] & {?,as Cons. Commission Anchorage .,, '" STATE OF ALASKA ~', AL,.,~, OIL AND GAS CONSERVATION COMMI .~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well__ Alter casing ~ Repair well Plugging ~ Time extension ~ Stimulate Change approved program __ Pull tubing x Vadance Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic__ Service 4. Location of well at surface 2422' NSL, 2468' EWL, SEC. 1, T11N, R14E At top of productive interval 1466' SNL, 1147' WEL, SEC. 11, T11N, R14E At effective depth 1771'SNL, 1478'WEL, SEC. 11, T11N, R14E At total depth 2413' NSL, 2264' EWL, SEC. 11, T11N, R14E 12. Present well condition summary Total depth: measured true vertical 14136 feet 10416 feet Plugs (measured) 6. Datum elevation (DF or KB) 44 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number L1-9 9. Permit number 85-1 10. APl number 50- 029-21265 11. Field/Pool Prudhoe Bay Field/Oil Pool CTU/Sand plug to 11840', cement to 11806' Effective depth: measured true vertical 11806 feet Junk (measured) 9114 feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 1800 # Polyurethane 3972' 13-3/8" 3200 sx "E"/400 sx "G" 11095' 9-5/8" 1000 sx "G"/300 sx CS I 2996' 7" l o4o sx "G"/280 sx "G" 1695' 5" 100 SX Class "G" measured 11258'-11780' (Nineteen open intervals) true vertical 8852'-9101' (Nineteen open intervals) Tubing (size, grade, and measured depth) 2-7/8", L-80 to 11173' MD Measured depth True vertical depth 110' 4002' 11095' 9604'- 12600' 12441 '- 14136' 110' 3995' 8775' 7816'-9468' 9400'-10111' ECE1VEE Packers and SSSV (type and measured depth) Baker "FH"packer @ 11102' MD; 2-7/8" Camco SSSV, TRDP-1A @ 2155' MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 12/15/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~V,~ I~ Title Drilling Engineer Supervisor ' FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance__ Mechanical Integrity Test Subsequent form required Original Signed By Approved by order of the Commission ~n2V!d W. ,,10.h,.n.$t0rl Form 10-403 Rev 06/15/88 Approval ~,,~ ,_ ,~ ~ (:~ No. Approved Copy Returned CommP~slcncr, D'-~e .! f /.~_ ~/'~, '-~ SUBMIT IN TRIPLICATE i' L1-09 RIG WORKOVER Ob!ective: The workover on L1-09 is required to repair tubing leaks from 3000'-3500' in the current 2-7/8" production tubing. The scope of the work will be to pull the 2-7/8" L-80 tubing without pulling the existing packer, run a vertilog, and recomplete with new 3-1/2" tubing. Background; L1-09 is a 2-7/8" single packer completion with current perforations in Zones 6-4. The well was initially completed in April 1985 and was drilled to the Alapah formation. When the Alapah proved wet, the well was plugged back in January 1986 to the Wahoo formation. In February 1989, the well was plugged back to 11806, mid W-4, to shut off high water cut production. Present Statl)S: Leaks in the 2-7/8" tubing were first suspected in June 1993 during a field shutdown. Initial work included rerunning dummy GL valves., A leak detection log was run in October 1993, confirming multiple leaks between 3,000'-3,500'. Most of the leaks appear to be at the collars. Subsequently, wireline pulled the dummy in GLM #5 and ran a Camco CA-2 blanking plug in the D nipple at 11,140'. The tubing and annulus were pressure tested to 2,200 psi, losing 15 psi in 35 minutes. Timing: December 15, 1993. Estimate 7 Days and a pad to pad move with Nabors 2ES. Procedure Outline Pre 1. 2. 3. 4. Rig Work: Lock open SSSV. Bleed tubing and annuli pressures to zero. Install BPV in FMC Gen IV, 5-1/2" tubing hanger. Remove wellhouse and flowlines, level pad, dig out cellar. Rig 1. 2. 3. 4. 5. . Sa. 9. 10. 11. 12. Work: Pull BPV. Circulate well to filtered seawater. Install TWC. ND tree. NU BOPE. Test to 5000 psi Pull BPV. Puli 2-7/8" Baker seal assembly from packer. CBU, pull and lay down completion. RIH w/7" csg scraper to top of Baker "FH" packer. Reverse circ bottoms up if csg pressure can be limited to 1100 psi. R/U Atlas. Run Vertilog: If leak detected, RIH with 7" test packer. Set just above the Baker "FH" packer. Test 7" and 9-5/8" casing to 3000 psi. If leak detected, run a 9-5/8" test packer to isolate the leak. Run 3-1/2" completion stdng. Space out, land tubing. Test annulus to 3500 psi. ND BOP's. NU and test tree to 5000 psi. Freeze protect well. Set BPV. Release rig. RECE[VED 11/19/93 Page 1 DRN ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: July 12, 1991 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: Well Type (1 blueline, 1 sepia) L1-02 Production Profile Run Run Date Company L1-09 ,'0~ L5-01 L5-17 Production Profile Production Profile Production Profile 1 6/17/91 Camco 1 5/30/91 Camco 1 5/30/91 Camco 1 5/30/91 Camco SIGN AND RETURN TO: LAURA S. LAHRSON, ATO 409 ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: Exxon BPX AOGCC D&M TRANSMITTAL # 645 STATE OF ALASKA '(',, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging w Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other 2. Name of Operator ARCO Alaska 'mc. 3. Address P.O.Box 100360 Anch AK 4. Location of well at surface 2422' FSL, 2468' FEL, Sec.1 At top of product,vd interval ' 1466' FNL, 1147' FEL, Sec.ll, At effective depth 2222' FNL, 1905' FEL, Sec.ll, At total depth 2413' FSL~ 2264' FWL~ Sec.ll~ 12. Present well condition summary Total depth: measured 1413 6 ' true vertical 10416 ' Effec!ive depth: measured 12200 ' true vertical 9298 ' TllN, TllN, TllN TllN 5. Type of Well: Development Exploratory Stratigraphic Service R14E, UM R14E, UM , R14E, UM feet Plugs (measured) feet feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3972' 11095' 2996' 1695' measured 11278'-11989' trueve~ical 8839' 9200' ~bing(size, gmde, andmeasumddepth) 2-7/8", L-80 @ 11207 PackersandSSSV(typeandmeasureddepth) PKR: Baker FH 7" @ 11137' SSSV: Size 20" 13-3/8" 9-5/8" 7" 5~ None 6. Datum elevation (DF or KB) RKB 44 7. Unit or Property name Pr~dho¢_ Bay. lln'i 8. Well number 11. Field/Pool Lisburne 0il Pool L1-9 9. Permit number/approval number 85-1/9-043 10. APl number 50-- 029-21265 Camco TRDP-1A @ 2155' Cemented Measureddepth 1800 Polyurethane 110' 3200 sx PF "E" & 4002' 400 sx Class G 1000 sx Class G & 11987' 300 sx CS I 1040 sx Class G 9604'-12600' 100 sx Class G 12441'-14136' None ~ueverticaldepth 110' 3995' 9150' 7816'-9468' 9600'-10111' R'ECEI:V.ED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average P~du~ion or Injection D~a OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1380 1320 590 1500 1250 15 Tubing Pressure 410 510 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _z; Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed.~ /~ Title Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE feet WELL WORK SUMMARY L1-09 2/6 2/7 2/8 2/15 2/24 2/27 SI well. Replace orifice at 11,034 with gas lift dummy. Rig up service company. Pumped sand placement down 2-7/8" tubing in 5 stages. Displaced each stage with diesel. Rigged up wireline to tag top of sand. Found top at 11,707'. Performed post sand placement cleanout with a CTU nozzle wash. Pumped a cement plug on top of sand with CTU. Wireline tagged top of cement at 11,806'. RECEIVED MAR 2 "~ t989 ? & Gas Cons..Com~b~lon ~"gncfiorage ' i'/' STATE OF ALASKA i' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging _.,x,. Time extension ~ Stimulate __ Change approved program ~ Pull tubing __ Variance __ Perforate ~ Other 2. NameofOperator ARCO Alaska Inc. 3. Addre~ P.O. Box 100360 Anch AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 2422' FSL, 2468' FEL, Sec. 1, TllN, At top of productive interval 1466' FNL, 1147' FEL, Sec. 11, TllN, At effective depth 2222' FNL, 1905' FEL, Sec. 11, TllN, At total depth 2413' FSL, 2264' FWL, Sec. 11, TllN, R14E, UM R14E, UM R14E, UM R14E, UM 6. Datum elevation (DF or KB) RKB 44 feet 7. Unit or Property name Prudhoe Bav! Jn~ -- 8. Well number L1-9 9. Permit number 10. APl number 50-- 029-21265 11. Field/Pool gisburne Oil Pool 12. Present well condition summary Total depth: measured true vertical 'KR: Effective depth: measured true vertical 14136' 10416' 12200' 9298' Casing Length Structural 80 ' Conductor 3972' Surface Intermediate 11095 ' Production 2996' Liner 1695' Perforation depth: measured 11278'-11989' true vertical 8839' -9200' ~bing(size, grade, and measureddepth) 2-7/8", L-80 @ 11207 Pac~rsandSSSVcypeandmeasureddepth) Baker FH 7" @ 11137' SSSV: feet feet feet feet Size 20" 13-3/8" 9-5/8" 7" 5" Plugs (measured) None Junk (measured) None Cemented Measured depth 1800 Polyurethane 110' 3200 sx PF "E" & 4002' 400 sx Class G 1000 sx Class G & 11987' 300 sx CS I 1040 sx Class G 9604'-12600' 100 sx Class G 12441'-14136' ~ueverticaldepth 110' 3995' 9150' 7816'-9468' 9600'-10111' RECEIVED ,Alas~ Oil .& Gas Cons. Commission 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation .','..' January 24, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢0~'~ F('3~~)~)~,..,~ Title Technical Aide FOR COMMISSION USE ONLY Date 1-17-89 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ORIGIN/~I SIGNED BY LONNIE C. SMITH JApproval No. ¢ _, ~.)~-~ Approved Copy Returned ,~,,. /'-.~F~ Oommissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE AI-I'ACHMENT 1 L 1-09 ARCO ALASKA INC. PROPOSES TO SHUT IN L1-09, REPLACE ORIFICE WITH DUMMY GAS LIFT VALVE, ALLOW PRESSURE TO STABILIZE, PUMP SAND, AND PUT A CEMENT PLUG OVER SAND. THIS PLUG WILL AFFECT LOWER WAHOO 4. THE PERFORATIONS IN THAT ZONE WILL BE SHUT OFF. STATIC PRESSURE 4288 PSI ON 8-7-86 DATE: ].0-2'1-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Pressure Reports L1-9 9-5-88 Flowing Gradient Camco LGI-2 9-28-88 Flowing GRadient Camco PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D & M STANDARD EXXON STATE OF ALASKA TRANSMITTIAL # .578 ARCO AILA$1I(A ~INC. ~' DATE: 9-26-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Final forL1-9 Production Profile Log 9-4-88 Run2 5" Camco RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 TRANSMITTIAL # 56'7 ARCO ILII:S UIRNIE N 31INIEIEIRIIN{3 DATE: 9-14-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals L1-9 composite Production, Profile 8-8-.88 Run 1 GO L1-28 Leak Detection Log 8-21-88 Run 1 5" Camco L1-28 Collar/Perf Log 8-1-88 Run i 5" GO L3-30 Production Profile Log 8.14-88. Run I 5" Camco. L5-8 Composite Production Profile 8-7-88 run I 5" GO PL~SE SI~N AND RETURN TO: PAM ~MBERT ARCO A~SKA INC. 700 ~ STREET' ATO 477 ANCHORAGE, AK. 995~0 CENTRAL FIL~S- PLANO D & M STANDARD EXXON TRANSMITTIAL # 558 STATE Of ALASKA " STATE OF ALASKA .,' ALA~ , OIL AND GAS CONSERVATION COM. $SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other E~ Restimulation 2. Name of Operator Arco Ala$ka Inc, 3. Address P.O. Box 100360 Anchorage, Alaska 4. Location of well at surface 99510 2422' FSL, 2468' FEL, Sec. 1, TllN, R14E, UM Attop of productiveinterval 1466' FNL, 1147' FEL, Sec. 11, TllN, R14E, UM Ateffective depth 2222' FNL, 1905' FEL, Sec. 11, TllN, R14E, UM Attotaldepth 2413' FSL, 2264' FWL, Sec. 11, TllN, R14E, UM 11. Present well condition summary Total depth: 5. Datum elevation (DF or KB) RKB 44 6. Unit or Property name Prudhoe Ba¥/Lisburne 7. Well number , L1-9 8. Approval number 8085 9. APl number 5O-- 02o2_2126,5 10. Pool Lisburne Oil Pool measured 14136 'feet true vertical 10416 'feet Feet Effective depth: measured 12200,feet true vertical 9298 ,feet Plugs (measured) Junk (measured) 12972'-13270', Cmt retainer @ 12364', 40 sx Class G Plug on top of retainer NONE Casing Length Size Structural Conductor 80' 20" Surface 3972 ' 13-3/8" Intermediate 11095' 9-5/8" Production Liner 2996 ' 7" Perforation depth: mea&t89§' 5" Cemented Measured depth True Vertical depth 1800 Polyurethane 110' 3200 sx PF "E" & 4002' 400 sx Class G 1000 sx Class G & 11897' 300 sx CS I 1040 sx Class G 9604'-12600' 100 sx Class G 12441'-14136' 110' 3995' 9150' 7816'-9468' 9400'-10111' 11278'-11989' true vertical 8839'-9200' ~bing(size, grade and measured depth) 2-7/8", L-80 @ 11207' Packers and SSSV(type and measured depth) PKR: Baker FH 7" @ 11137' SSSV: Camco TRDP-1A 2-7/8" @ 2155' 12. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo Zones 4-7 Treatment description including volumes used and final pressure E E E I E,,: p ~*~..,,,;,,~.,,~,~"~'~ 0il & Gas Cons. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 682 504 367 Casing Pressure 5O 5O 749 587 460 Tubing Pressure 417 416 14. Attachments Daily Report of Well Operations~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Technical Aide Date 3-24-88 Submitin Duplicate¢ ATTACHMENT 1 L1-9 WAHOO 4-7 RESTIMULATION 3 - 8- 8 8 SHUT-IN WELL IN PREPARATION FOR RESTIMULATION. 3-9-88 RIGGED UP FRACMASTER (CTU) AND HALLIBURTON (ACID) TO STIMULATE WAHOO ZONES 4-7. PRESSURE TESTED TO 4000 PSI. LOADED HOLE WITH DIESEL (21 BBLS) WHILE RUNNING IN HOLE. ACIDIZED PERFORATIONS FROM 11,258' TO 11,898'MD WHILE RECIPROCATING TUBES ACROSS INTERVAL. TREAT- MENT INCLUDED: 10 BBLS DIESEL WITH 10% MUTUAL SOLVENT 150 BBLS 15% HCL WITH ADDITIVES 40 BBLS DIESEL FLUSH POOH. RD. OPEN WELL TO COMMON LINE. Gas Cons. Com~iss~or~ Anchorage ARCO ALASIKA ONC, DATE: 2-18-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals "-"L2-32 CBL (CBT) Run i 5" Sch 2-14-88 "L2-32 GCT Directional Survey Run I 5" Sch 2-14-88 --L2-32 CET Run i 5" Sch 2-14-88 ~.,~.?..,' Production Log Run i 5" Sch 12-16-87 RECEIVED BY: ~ Alast',a 0il & Gas Cans. Commission PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D & M STANDARD EXXON STATE OF ALASKA TRANSMITTIAL # 301 ,,~ STATE OF ALASKA '"'J' ALA , OIL AND GAS CONSERVATION CO ~,.,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension r~ Change approved program [] Plugging [] Stimulate X-! Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 3. Address P.O. Box 100360 Anchorage, Alaska 99510 4. Location of well at surface 2422' FSL, 2468' FEL, Sec. 1, T11N, R14E, UM At top of productive interval 1466' FNL, 1147' FEL, Sec. 11, T11N, R14E, UM At effective depth 2222' FNL, 1905' FEL, Sec 11, T11N, R14E, UM 5. Datum elevation (DF or KB) JqKB 44 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number Ll-9 8. Permit number 9. APl number 50--029-2126.5 At total depth 2413' FSL~ 2264' FWL~ Sec, 11. Present well condition summary Total depth: measured 14136' true vertical 10416' Effective depth: measured 12200' true vertical 9298' Casing Length Size Structural 80' 20" Conductor 3972' 13-3/8" surface Intermediate 11095' 9-5/8" Production Liner 2996' .... Perforation depth: measure~1695' 11278'-11989' true vertical 11, TllN~ R14E, UM feet feet 8839' -9200' Tubing (size, grade and measured depth) 2-7/8" L-80 11207' Packers and SSSV (type and measured depth)Py, R: SSSV: 10. Pool Lisburne 0il Pool feet feet feet Plugs (measured) 12972'-13270', Cmt retainer @ 12364', 40 sx Class G Plug on top of retainer Junk (measured) NONE 12.Attachments Cemented Measured depth True Vertical depth 1800 Polyurethane 110' 3200 sx PF "E" & 4002' 400 sx Class G 1000 Sx Class G & 11897' 300 sx CS I 1040 sx Class G 9604'-12600' 100 sx Class G 12441'-14136' 110' 3995' 9150' 7816'-9468' 9400'-10111' BOP sketch [] Baker FH 7" @ 11137' £amnn TRllP-1A 2-7/R" 21~.~' Description summary of proposal I~ Detailed operations program [] 13. Estimated date for commencing operation February 18, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I her~ertify t.hat the foregoing is tru~ and Sig ned %~/~ '¥',~ ~ b~~ correct to the best of my knowledge Title Technical Aide Commission Use Only Date 2-12-88 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 124-85 I Approval [] BOP Test [] Location clearancel Approved Copy Returned....-, Commissioner the commission Dat Submit in triplicate¢ ATTACHMENT 1 WELL L1-9 ARCO ALASKA INC. PROPOSES TO CONDUCT THE FOLLOWING ON LISBURNE WELL L1-9. 1. ACID WASH WAHOO 4-7 PERFORATIONS WITH 150 BBLS OF 15% HCL. ACID WILL BE PUMPED THROUGH COILED TUBING. ALL PRE/POST STIMULATION FLOW TESTING WILL BE DONE USING THE L1 DRILLSITE FACILITIES. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hand-carried S~,~IP LE TRANSMITTAL SHIPPED TO: State of Alaska · Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: John Boyle DATE-5/26/87 OPERATOR: ARCO S~{PLE TYPE' SAMPLES SENT: core chips 11292 - .11299 11305 - 11358. 11373 - 1.1406 11414 - 11435 11438 .- 11447 11451 - 11525 11528 - 11548 11552 - 11569 11571 - 11599 11603 - 11614 11630 - 11710 11712- 11846 11854 - 1193' N~.IE- Lisb. Llk9 NUMBER OF BOXES' 50 boxes UPON RECEIPT OF THESE SAaXlPLES, PLEASE NOTE ANY DISCREPANCIES AND ~IL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ~.. DATE' ARCO Alaska, Inc. is a Subsidiary of AllanhcRichheldCompany ARCO ALASKA INC. LISBURNB ENGINEERING Date: 2-2-87 From: Para Lamber t Enclosed are the following: CH Finals for L1-9 CCL/Perf Log 4-21-85 Run 1 5" Sch ~p<~o Perforating Record 5-18-85 Run 1 5" Sch v~ Received by: ~ Please sign and retur0 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 159 ARCO ALASKA INC. LISBURNE ENGINEERING Date: 12-19-86 From: Pam Lambert Enclosed are the following: CH Final for L1-9 Gamma Ray 1-15-86 Run 1 5" DA CH Final for LGI #10 '-~ Collar Log 10-16-86 Run 1 5" DA CH Final for Li-1 Collar Log 1-21-86 Run 1 5" DA Received by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 126 STATE OF ALASKA ALA~' OIL AND GAS CONSERVATION CO~¢,'' ,;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate Alter Casing [] Other~ 2. Name of Operator ARCO ALASKA, INC. Plugging [] Perforate [] Pull tubing 3. Address P.O.B. 100360~ ANCHORAGE, AK. 99510 4. ~cationofwellatsurface 2422' FSL, 2468' FEL~ Attopofproductiveinterval 1466' FNL, 1147' FEL. Ateffectivedepth 2222' FNL, Attotaldepth 2413' FSL, 1905' FEL, 2264' FWL~ 11. Present well condition summary Total depth: measured Sec. 1~ TllN, R14E~ UM Sec. 11~ TllN, R14E,UM Sec. 11, TllN~ R14E~ UM(APF Sec. 11~ TllN~ R14E~UM 14136' feet Plugs(measured) Effective depth: true vertical 10416 ' feet measured 12200 ' feet true vertical 9;:)98, feet 5. Datum elevation (DF or KB) RKB 44 Feet 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number L1-9 8. Approval numberN/A 9. APl number 029-21265 50-- 10. Pool L ISBURNE O I L POOL 12972'-13270', Cmt RETAINER @ 12364' ~ 40 SX CLASS G PLUG ON TOP OF RETAINER Junk(measured) NONE Casing [l~(~gt h S,i~(~ ,, Structural 3972 ' 13-3/8" Conductor Surface 11095' 9-5/8" Intermediate Production 2996 ' 7" Liner 1695 ' 5" Perforation depth: measured 11278 ' -11989' true vertical 8839 ' -9200' Tubing (size, grade and measured depth) 2-7/8", L80, 11207' Packers: Packers and SSSV (type and measured depth) SSSV: Measureddepth 1E~nt~lyurethane 110' 3200 sx PF "E" & 4002' 400 sx class G 1000 sx class G & 11897' 300 sx CS I 1040 sx class G 9604-12600' & 280 sx class G 100 sx class G 12441-14136' BAKER FH, "7" @ 11137' CAMCO TRDP-1A, 2-?/8" @ 2155' 12. Stimulation or cement squeeze summary ~ueVerticaldepth 110' 3995' 9150' 7816-9468' 9400-10111 13. Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure RePresentative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure NOT AVAILABLE 1900 1600 300 20 700 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,~'~ ) ? Form 10'40"~1~e~.-12--1-85- - LISBURNE OP. COORD. 12/2/86 Title Date Submit in Duplicate Sequence of Events L1-9 (Wahoo 4, 5, 6, & 7) 01/29/86 Rig up Halliburton. Press. test lines to 5000 psi - ok. Pump 10 bbls diesel w/5% Musol "A." Pump 357 bbls 15% HCL. Displace acid with 73 bbl diesel. Average rate = 8 BPM @ 3200 psi. Total Load = 440 bbls. Two week production test-open well to obtain flow rates. Oil rate stabilized at 1899 BOPD, 1600 MCFD, WHP 550 psi. Water rate increased to 292 BWPD. 01/30/86 Rig up Camco to run spinner/CCL/Temp. Tool stopped working. POOH. Rerun. RIH, tie-in, no stop counts. Tag bottom at 11,754'. POOH. Rig down. 01/31/86 RIH w/spinner/CCL/Temp. Made dynamic passes @ 1500 BPD rate and at 2160 BPD. Made passes with well SI. 02/09/86 Due to increased water cut, rig up Gearhart to run production log. RIH w/CCL/spinner/capacitance tool. Run dynamic passes @ 40, 80, 120, & 160 FPM from 11,200 - 11,750'. Tool setting down at 11,750 (BTM 61' of perfs are covered up). Run capacitance log. Water column indicated from 11,340'-11,350'. 03/30/86 Rig up Camco. Run static temperature survey. Obtain following temp stops: Depth Temp. Depth Temp. MD ° F MD ° F 1000' 17° 6,000' 100.9° 2000' 28.6° 7,000' 112.9° 3000' 47° 8,000' 123° 4000' 66.9° 9,000' 143° 5000' 87° 10,000' 167° 10,300' 170.7° Obtain down pass temperature survey from 10,300' to 11,555'. 08/07/86 Rig up Camco for static BHP. Pressures are as'follows: MD SS P (PSIG) 11,700' 9010' 4327.9 11,486 8900' 4285.4 11,100 8697' 4223.9 10,500 8373' 4136.8 Temp. ° F 187.9° 185.5° 179.9° 170.6° Telecopy No. (907) 276-7542 October 10, 1986 Teresa Gorup - ABV 100. ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Ms. Gorup: In an effort to make our data current, it has been found that the following materials have not been submitted to the Commission as required by 20 AAC 25.071(b) of our regulations. Please submit the following materials: (. 2 ) SAMPLES Well Name Completion Date Permit Number Hemi Springs Unit ~3 Winter Trails #1 4/6/85 85-22 3/7/86 86-8 ( . 3) CORE CHIPS PBU DS 3-32 4/12/86 84-107 PBU DS 16-21 9/2/86 85-312 PBU L1-9 11/19/86 85-1 PBU L2-29 4/12/86 85-297 PBU L3-23 2/28/86 85-306 PBU LGI-12 5/2/86 86-54 KRU lQ-16 6/10/~5 85-47 KF~U 3B-14 5/22/85 85-24 Teresa Gorup October 9, 1986 Page 2 (.3) LITHOLOGIC DESCRIPTION Well Name PBU DS 3-32 PBU DS 16-21 PBU L1-9 PBU LGI-12 Hemi Springs Unit ~3 Co.mp!et ion Date 4/12/86 9/2/86 1/19/86 5/2/86 4/6/85 We appreciate your attention to this matter. F~ncerel~, John F. Boyle ~-~'J o" Petroleum Engineer Assistant jo/A.JFB.4 Permit Number 84-]07 85-312 85-1. 86-54 85-22 ARCO Oil and Gas Company Well History- Initial Report- Daily leltlll~llOltl: Prepere and submit the "lalllll Rl~el't' on the first Wednesday after a well is spudded or workover operations are started. Dilly wor~ prior to s~uddlng should be summarized on the form giving inclusive dltel only. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 504211 Parker #176 lCounty, pams~ or borough [State North Slope Borough I Laa~ ADL ~28302 ITItl, Drill, Core, Complete & Perforate Alaska IWell no. L1-9 AP1 50-029-21265 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m, 1/o8/85 thru 1113185 1/14/85 1/15/85 1/16/85 1/17/85 1/18/85 IO,,t, 1/13/85 1"our Complete record for each day reported ARCO W.,. 50% Prior status if · W.O. 0100 Hrs. Move rig & RU. 20" @ 110' 2995', (2895'), RIH w/Jetting assy Wt. 9.6+, PV 7, YP 27, PH 8.5, WL NC, Sol 9.5 Accept rig @ 1600 hfs, 1/12/85. Spud well @ 0100 hfs, 1/13/85. Drl to 2995'. 20" @ 110' 3601', (606'), Navi-Drlg ahead Wt. 9.5, PV 6, YP 24, PH 8.5, WL NC, Sol 8.5 ~ Drld & jetted 2995'-3284'. Navi-Drl 3284'-3601'. 3011', Assumed vertical 3128', 2.2°, N19W, 3128 TVD, 0.76 VS, 2.13N, 0.73W 3395', 6.8°, N54W, 3394 TVD, 4.50 VS, 22.33N, 15.63W 20" @ 110' 4032', (431'), Rn'g 13-3/8" csg Wt. 9.6, PV 7, YP 40, PH 8.5, WL NC, Sol 8.5 Navi-Drl 3601'-4032', short trip, TOH f/csg. Rn 61 of 98 its total 13-3/8" csg. 3517', 5.6°, N73W, 3515 TVD, 0 rS, 28.21N, 27.42 3793', 6.2e, S61W, 3790 TVD, +22 VS, 25.29N, 52.89 3886', 7.8°, SS1W, 3882 TVD, +33 VS, 18.95N, 62.26 13-3/8" @ 4002' 4032', (0'), NU BOPE Cln pits Rn 98 its, 13-3/8" csg. FS @ 4002', FC @ 3913'. Cmt w/3200 sx PF "E" & 400 sx C1 "G". NU wellhead. NU BOPE. 13-3/8" @4002' 4481', (449'), Drlg Cln pits Tst BOPE per AOGCC. DO cmt. leak-off. Drl to 4481'. Tst formation to 12.6 ppg The al3ove is correct Signature For form preparation and q~tributlon, see Procedures Manual, Se'btlon 10, IDate 10/25/85 [Title Drilling Superintendent ARCO 011 and Gas Company Daily Well History--Interim Inltructiene: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or repreeentative test on "Final" form. 1) Submit "lnlerlal" sheets when filled out but not less Irequent[y than every 30 days, or (2) on wednesday of the week in which oil string is set. Submit weekly for workovers and following setting Of O~1 string until completion. District ICount,or Parish I State Alaska North Slope Borough ~,e,d ILe.. or Unit #283O2 I Complete record for each day while drilling or workover in progress Prudhoe Bay Date and depth as of 8:00 a.m. 1/19/85 thru 1/21/85 1/22/85 1/23/85 1/24/85 1/25/85 Tho above is correct Signature For form preparation and d~tribution see Procedures Manual Sec~on 10, Drilling, Pages 86 and 87 13-3/8" @ 4002' 7760', (3279'), TIH Wt. 9.6, PV 8, YP 14, Drl & surv 4481'-7760 4138', 13.3°, S32W, 4474', 26.5°, S36W, 4996', 43-1/4°, S34W, 5150', 48-1/2°, S34W, 5669', 51.8°~ S36W, 6465', 53°, S4OW, 6958', 54-1/2°, S4OW, PH 8.0, WL 16, Sol 8.5 · 4129.81, 77.07 VS, 15.60S, 92.84W 4445.66, 188.80 VS, 107.72S, 158.77W 4871.34, 483.79 VS, 353.08S, 331.25W 4978.56, 592.15 VS, 444.73S, 393.06W 5311.13, 984.06 VS, 771.12S, 621.60W 5797.33, 1610.10 VS, 1261.91S, 1016.85W 6088.85, 2005.81VS, 1566.43S, 1272.44W 13-3/8" @ 4002' 8760', (1000'), Drlg Wt. 9.7, PV 7, YP 10, PH 8.0, WL 12, Sol 9.4 Drl 12¼" hole f/7760'-8760'. 7330', 54.8°, S40W, 6304 TVD, 2308 VS, 1799S, 1467.44W 7797', 53.8°, S41W, 6576 TVD, 2686 VS, 2087S, 1713.74W 8261', 50.3°, S42W, 6862 TVD, 3051VS, 2361S, 1956.18W 13-3/8" @ 4002' 9375', (615'), Drlg Wt. 9.8, PV 5, YP 8, PH 8.3, WL 14.2, Sol 11 Drl & surv 12¼" hole to 9375'. 8728', 46.0°, S43W, 7176 TVD, 3398 VS, 2617S, 2191W 8913', 43.2°, S44W, 7305 TVD, 3528 VS, 2712S, 2281W 9290', 42.4°, S44W, 7582 TVD, 3784 VS, 2896S, 2459W Alaska 13-3/8" @ 4002' 10,072', (697'), Control drl'g ahead Wt. 10, PV 7, YP 7, PH 8.0, WL 9.8, Sol 12.5 Drl 9375'-10,072'. Top of Put River Sand @ 9954' KB MD - Sag River @ 10,014' MD. 9598', 41.4°, S46W, 7811.09 TVD, 3989.89 VS, 3041.71S, 2603.99W 9915', 43.2°, S51W, 8044.08 TVD, 4201.57 VS, 3182.19S, 2762.78W IWell no. L1-9 Date ITitle 10/25/85 13-3/8" @ 4002' 10,496', (424'), POOH Wt. 10.1+, PV 7, YP 8, PH 8, WL 12.2, Sol 13 Drl & surv 12¼" to 10,496'. 10,224', 51.2°, S50W, 8255.39 TVD, 4428.86 VS, 3327.34S, 2938.86W 10,377', 55.5°, S47W, 8346.72 TVD, 4551.43 VS, 3408.67S, 3030.79W ARCO 011 and Gas Company Daily Well History--Interim Inltll~CtlOIll: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1~ Submit "lnlerlm" sheets when filled out but not less frequently than every 30 (~ays, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District ICountyor Parish Istata Alaska [Lease or UnitADLNOrth#28302Slope Borough Complete record for each day while drilling or workover in progress Field Prudhoe Bay 1/26/85 thru 1128/85 1/29/85 1/30/85 1/31/85 Date and del3tn as of 8:00 a.m. 2/Ol/85 · 13-3/8" @ 4002' 10,837', (341'), Drlg Wt. 10.2, PV 7, YP 8, PH 8.3, WL 10.4, Sol 14 Drl 12¼" hole to 10,496', stuck DP, wrk ~ree. Drl to 10,837' Alaska 13-3/8" @ 4002' 11,120', (283'), POH f/tag Wt. 10.2, PV 7, YP 4, PH 8.0, WL 12.4, Sol 14 Drl to 11,120', 14 etd short trip, CBU, POH. TIH, pmp light LCM pill, POH f/csg. 10,795', 57.3°, S46W, 8578 TVD, 4899 VS, 36485, 3283W 10,946', 57.8°, S45W, 8659 TVD, 5027 VS, 37385, 3374W 13-3/8" @ 4002' 11,120', (0'), Fin RIH Wt. 10.2+, PV 8, YP 4, PH 8.0, WL 16, Sol 14 POH, chg BHA. RIH, wsh & rm to 11,120', C&C w/LCM. 13-3/8" @ 4002' 11,120', (0'), CBU & mx LCM Wt. 10.2, PV 11, YP 8, PH 8, WL 8, Sol 14 TIH, wsh thru bridge, spot LCM pill. Short trip while mx'g LCM pill. Fin TIH, rm & wsh thru bridges & ratty hole 9934'-11,120'. Lost 120 bbls mud on trip. Circ to cln hole & spot LCM pill. Short trip. Spot LCM pill on btm. TOH 30 stds to monitor hole. Hit bridge @ 10,700'. 13-3/8" @ 4002' 11,120', (0'), Monitor hole Wt. 10.2, PV 9, YP 4, PH 9, WL 6, Sol 14 Wrk sloughing hole f/10,182'-10,647', spot LCM pills & monitor hole. Spot LCM pill & circ. TOH 30 stds, monitor fluid level. Circ while dispersing mud. TIH, wrk bridge @ 10,182', spot LCM pill. TOH 30 stds, monitor hole. TIH, wrk thru bridges 10,182'-10,647', TOH 10 stds. Spot LCM pill, TOH 10 stds, monitor hole. no. 1-9 The above is correct Signature For form preparation and~distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date 85 ]Title 10/25/ Drilling Superintendent ARCO Oil and Gas Company Daily Well History--interim Inetr~¢tlone: This form is used during drilling or workover operations, If testing, conng, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or repre.entative test on °'Finer' form. 1) Submit "lnlerlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the weak in which oil string is set. Submit weekly for workovers and following setting Of oil string untd complehon. District 1Countyor Parish IState Alaska ILeaae or unit North Slope Borough I APL #283O2 Complete record for each day while drilling or workover in progress Field Prudhoe Bay Date and depth as of 8:00 a.m. 2/02/85 thru 2/04/85 2/05/85 2/06/85 2/07/85 2/08/85 Alaska IWell no. L1-9 9-5/8" @ 11,095' 11,120', (0'), TSt BOPE Wtr Spot 75 bbls LCM pill @ 10 152' TOH 20 stds, observe hole · , . TIH, hit bridge @ 10,275' . Pmp , rm to 10,330', wsh to 10,380' 50 bbl gel pill, POH 30 stds, observe hole. TIH, no bridges or fill. Pmp 75 bbls gel pill, CBU, TOH f/9-5/8" csg. RU & rn 273 its, 9-5/8", 47#, L-80 BTC csg to 11,095' w/FC @ 11,011'. M&P 1000 sx C1 "G" w/l% CFR-2, .3% Halad-24 & 5% KC1 @ 15.8 ppg. Displ w/786 bbls mud using rig pmps, bump plug to 3500 psi. CIP @ 0039 hfs, 2/3/85. LD BHA. PU & rn scrpr & CO assy, TOH & LD bit & scrpr. RU & rn Caliper f/10,926' - surf. Cln pits, fill w/wtr. Tst BOPE to 5000 psi. 9-5/8" @ 11,095' ].1,130', (10'), Mx'g bland mud Wt. 9.6, PV 18, YP 11, PH 9, WL 5.8, Sol 13 PU 8½" BHA, TIH, CO cmt to FS. Drl 10' new hole. Conduct leak-off tst to 12.5 ppg EMW. Cln mud pits & mx bland mud. 9-5/8" @ 11,095' 11,250', (120'), RIH Wt. 9.6, PV 12, YP 9, PH 9.3, WL 7.6, Sol 6 Mx bland mud & displ hole w/same. Rm swelling shales 11,092'-11,130'. Drl 8½" hole to 11,208', pull into 9-5/8" shoe. Inc salt concentration in mud. RIH & drl 11,208'-11,250', CBU, start TOH. TIH to drl as per geologist orders, lost pmp press, TOH f/wshout in bit nozzle. Chg bit, TIH. 9-5/8" @ 11,292', Wt. 9.6, TIH, drl TIH, drl TOH. PU 11,037', 11,236', 11,095' (42'), RIH w/core bbl PV 9, YP 7, PH 9.1, WL 7.8, Sol 6 to 11,262', CBU. Drl to 11,271', TOH, lk'g f/wshout. 11,292' (top of Lisburne @ 11,281'). CBU, pmp pill, core bbl, & prep to TIH. 57.8°, S45W, 8708 TVD, 5104 VS, 3792S, 3429W 52°, S50W, 8822 TVD, 5267 VS, 3902S, 3549W 9-5/8" @ 11,095' 11,300', (8'), Fsh'g Wt. 9.6, PV 9, YP 5, PH 8.8, WL 8.2, Sol 6.5 Core #1, 11,292'-11,297', Jammed, rec'd 4.5'. Core #2, 11,297'-11,303', rec'd 3'. M&P pill, POOH, core bbl twisted off below top stabilizer on core bbl (30.6' left in hole). WO Tri-State fsh'g tls. The above is correct Signature Date ITitle lo/25/85 For form p~e~ration an'~ distr/~)ution see Procedures Manual Sectidt~ 10, Drilling, Pages 86 and 87 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instn~ctiona: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem teats sequentially. Attach description of all cores. Work 13erformed by Producing Section will be reported on "Interim" sheets until final completion. Rel3ort official or repreSentative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less trequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string unttl completion. District I County or Parish I Stale Alaska North Slope Borough Alaska Field ILeaae or Unit IWell no. Prudhoe Bay ADL #28302 I L1-9 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 2/09/85 thru 2/11/85 2/12/85 2/13/85 2/14/85 2/15/85 2/16/85 thru 2/19/85 9-5/8" @ 11,095' 11,356', (56'), RIH w/DST tls Wt. 9.6, PV 7, YP 5, PH 8.5, WL 8.4, Sol 6.5 RIH w/fsh'g assy, wsh over fsh, POH, TOH; left core carrier sub in hole. RIH w/mill & JB, mill 11,300'-11,301', TOH; no rec'y in JB. TIH w/bit & JB, cln hole to 11,301', CBU, TOH; no rec'y in JB. RIH, core #3, 11,301'-11,330', rec'd 29'. Core #4, 11,330'-11,356', rec'd 26'. PU DST tls. 9-5/8" @ 11,095' 11,356', (0'), POH w/DST tls Wt. 9.6, PV 6, YP 5, PH 8.3, WL 7, Sol 6.5 . TIH w/DST tls. RU &tst surf equip. Load DP to 2000 psi BHP w/No. Open DST f/5 min flow; showed 400' rise in fluid level. SI 2/3 Hrs. Open f/flow @ 15:39 hfs - gas to surf @ 1620 hfs Bled off NA cushion. Tst terminated @ 1900 hfs w/fluid to 1800'. Shear sampler & rev out oil, catching samples f/DP. Rel RTTS &circ out contaminated mud & oil. TOH w/DST tls. 9-5/8" @ 11,095' 11,356', (0'), Rm'g Kavik shales Wt. 9.6, PV 6, YP 4, PH 8.0, WL 8.2, Sol 7.0 LD DST tls, RIH, rm 11,085'-11,157', POH 2 stds, hole swabbing, CBU, fin POH. Chg bits, RIH, rm 11,095'-11,150'. 9-5/8" @ 11,095' 11,373', (17'), TOH f/core bbl Wt. 9.8, PV 6, YP 4, PH 8.0, WL 10.5, Sol 8 Rm 11,150'-11,158'. Drl f/11,158'-11,373', POH f/co~e bbl. 9-5/8" @ 11,095' 11,394', (21'), TIH w/core bbl Wt. 9.7, PV 6, YP 4, PH 8.0, WL 11, Sol 7 Core #5, 11,373'-11,394', rec'd 21.5'. TIH. 9-5/8" @ 11,095' 11,479', (85'), TOH w/core #10 Wt. 9.7, PV 8, YP 6, PH 7.0, WL 12, Sol 7 Core #6, 11,394'-11,415' 'd . , rec 13.5' Core #7, 11,415'-11,432', rec'd ~8'. Core #8, ll,432'-ll,~3.~L,~C~ec'd.~=..~,, 'i' ~.~;, '.~ 4'. Core #9, 11,438'-11,451 , rec'd 9.5'. ~;~ 11,451'-11,479', TOH. ' , ~ ' .., ~ '~,,, Alaska 0it The above is correct Signature For form i:)reparation and dyribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate JTitle 10125185 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instruction,,: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative teat on "Final" form. 1) Submit "leterlm" sheets when filled out Put not less frequently than every 30 days, or (2) on wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. mstr~ct ICo-nty or Parish ]State Alaska North Slope Borough Fie~d I|.eaae o,' Unit #28302 I Complete record for each day while drilling or workover in progress Prudhoe Bay Date and depth as of 8:00 a.m. 2/20/85 2/21/85 2/22/85 2/23/85 thru 2/25/85 2/26/85 2/27/85 2/28/85 Alaska IWell no. L1-9 9-5/8" @ 11,095' 11,504', (25'), LD core #11 Wt. 9.7, PV 6, YP 5, PH 7.6, WL 11.6, Sol 7 LD core #10, rec'd 27'. Core #11, 11,479'-11,504' , TOH & LD. 9-5/8" @ 11,095' 11,528', (24'), RIH w/core bbl Wt. 9.7, PV 5, YP 5, PH 7.5, WL 13.8, Sol 7 LD core #11, rec'd 25'. Core #12, 11,504'-11,528', rec'd 24' TIH w/core #13. 9-5/8" @ 11,095' 11,565', (37'), Coring Wt. 9.7, PV 5, YP 5, PH 7.6, WL 13.6, Sol 7 TIH, wsh & rm thru bridge @ 11,189', rm to btm. Core #13, 11,528'-11,552, rec'd 21.5'. Core #14, 11,552'-11,565', incompl. 9-5/8" @ 11,095' 11,659', (94'), POH w/core #19 Wt. 9.7, PV 5, YP 5, PH 7.7, WL 16, Sol 7 Core #14, 11,565'-11,571' ' ' , recd 19. Core #15, 11,571'-11,584', rec'd 13'. Core #16, 11,584'-11,603', rec'd 15.5'. Core #17, 11,603'-11,630', rec'd 12'. Core #18, 11,630'-11,640', rec'd 11.3'. Core #19, 11,640'-11,659', jammed, POH. 9-5/8" @ 11,095' 11,683', (24'), Core #21 Wt. 9.7, PV 6, YP 4, PH 7.6, WL 14.4, Sol 7 POH w/core #19, rec'd 19'. Core #20, 11,659'-11,672' 10.6'. Cutting core #21 f/11,672'. · rec'd 9-5/8" @ 11,712', Wt. 9.7, Fin core 11,702'- 9-5/8" @ 11,759', Wt. 9.7, Core #23 11,735'- 11,095' (31'), RIH f/core #23 PV 6, YP 5, PH 7, WL 14, Sol 3 #21, 11,672'-11,702', rec'd 30'. Core #22, 11,712', rec'd 9'. RIH f/core #23. 11,095' (47'), TOH w/core #24 ~/~='~.. PV 8, YP 8, PH 8, WL 14.0, Sol 8 , 11,712'-11,735', rec'd 23'. Core #24, 11,759', TOH. The above is correct Signature /,~ For form preparation and distrib~lon see Procedures Manual Section 10, Date ITi{le 10125/85 Drilling Superintendent Drilling, Pages 86 and 87 ARCO Oil and Gas Company ~, Daily Well History--Interim InstlllCtione: This form is used during drilling or workover operations. If testing, coring, or peHorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when filled OUt hut not less frequently than every 30 days, Or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oi{ string until completion. District JCounty or Parish jState Alaska North Slope Borough Field ILease or Unit Prudhoe Bay I ADL #28302 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 3/Ol/85 3/02/85 thru 3/04/85 3/05/85 3/06/85 3/07/85 3/o8/85 Alaska Jwe~ no. 1-9 9-5/8" @ 11,095' 11,790', (31'), Core #26 Wt. 9.8, PV 7, YP 6, PH 7.8, WL 15, Sol 8 LD core #24, rec'd 24'. Core #25, 11,759'-11,785', TOH, wrk pipe thru swelling shales; rec'd 26'. TIH, rm thru shales. Core #26 f/11,785'-11,790', incompl. 9-5/8" @ 11,095' 11,937', (147'), TOH w/core #29 Wt. 9.7, PV 7, Y? 7, PH 7.6, WL 15, Sol 7 Core #26, 11,790'-11,811'; rec'd 26' Core #27, 11,811'-11,854'; rec'd 35.5'. Core ~28, 11,854'-11,887' 33'. Core #29, 11,887'-11,937', TOH. ; rec'd 9-5/8" @ 11,095' 12,090, (153'), Drlg Wt. 9.7, PV 8, YP 9, PH 7.8, WL 15.6, Sol 7 Rec'd 50' f/core #29. RIH w/BHA & 8½" bit, drl f/11,937'-12,090'. 9-5/8" @ 11,095' 12,335, (245'), Drlg Wt. 9.7, PV 8, YP 10, PH 7.6, WL 15.2, Sol 6.5 Drl 8½" hole to 12,226', high flow in vol, C&C; well not flowing. Drl to .12,335'. 9-5/8" @ 11,095' 12,398', (63'), Spot LCM pill @ 9-5/8" shoe Wt. 9.7, PV 16, YP 9, PH 7.7, WL 6.2, Sol 6 Drl 8%" hole to 12,398', lost rtns. Spot 130 bbls LCM pill, build mud vol. POH to 9-5/8" shoe, top stab hung on shoe. Wrk top stab thru 9-5/8" shoe, spot 50 bbls LCM pill. (Lost total ~i000 bbls fluid~) 9-5/8" @ 11,095' 12,498', (100'), Drlg ahead Wt. 9.7, PV 8, YP 9, PH 7.7, WL 12.8, Sol 6.5 Spot LCM pill, POH, chg BHA. RIH to 9-5/8" shoe, break circ, rm & wrk thru 9-5/8" shoe, wsh 12,225'-12,398', drl 8½" hole to · ~.,~ ~,,=,? li'.~~ ~ The above is correct Signature For form preparation an~J distribution see Procedures Manual Section 10, Drilling, Pages 86 and87 JDate JTitle 10/25/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inetl~.lctlona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinG until completion. District ICounty or Parish IState Alaska ILease Or Unit North Slope Borough I ADL #28302 Complete record for each day while drilling or workover in progress Field Prudhoe Bay 3/09/85 thru 3/11/85 3/12/85 3/13/85 3/14/85 3/15/85 Date and depth ss of 8:00 a.m. The above is correct For form preparation and distrit~tion see Procedures Manual Section'10, Drilling, Pages 86 and 87 Alaska IWell no. L1-9 9-5/8" @ 11,095' 12,600', (102'), Logging Wt. 9.7, PV 5, YP 8, PH 7.0, WL 19.6, Sol 6.5 Drl 8½" hole to 12,600', cond hole f/logs, POH. RU WL, log rn #1, DLL/SP/MSFL/NGT/CAL f/12,327'-11,085'. Log rn #2, LDT/CNL/GR/CAL/MS/EPT f/12,419'-11,085' & 12,419'-11,085'; cont w/CNL/GR to 9800', cont w/GR to 4000'. Log rn #3, FDC/GR/CAL f/12,362'-11,085'. Log rn #4, BHCS/GR/CAL f/12,400'-11,085', BHCS/GR/WF f/11,500'-11,300' & 12,335'-11,085'. RIH w/LSS/GR. 9-5/8" @ 11,095' 12,600', (0'), Logging Wt. 9.7, PV 5, YP 6, PH 7.1, WL 26.8, Sol 6.5 Rn #5, 1st pass, log LSS/GR f/12,300'-11,218'. Rn #5, 2nd pass, rn LSS/GR; in shorted out. RIH, cond hole, CBU, POH. Rn #6, 1st pass, rn DLL/MSFL/GR f/12,429'-11,234'. Rn #6, 2nd pass, rn DLL/MSFL/GR f/12,429'-11,234'. Rn #5, 3rd pass, rn LSS/GR. 9-5/8" @ 11,095' 12,600', (0'), RIH to cond f/lnr Wt. 9.7, PV 6, YP 6, PH 7.0, WL 26, Sol 6.5 Rn #5, pass #3, LSS/GR f/12,436'-11,085', pass #4, LSS/GR f/11,500'-11,085'. Rn #7, pass #1, SHDT/AMS/GR f/12,320'-11,085', Rn DiaLog csg caliper f/ll,000'-surf. cond f/lnr. RIH to 7" @ 12,600' 12,600', (0'), Cmt'g 7" lnr Wt. 9.7, PV 5, YP 6, PH 7, WL 25, Sol 6.5 TIH to cond hole f/lnr, CBU, 3 std short trip, TOH. RU & rn 43 its, 29#, L-80 BTC csg w/TOL @ 10,788', FS @ 12,600'. Cmt w/850 sx C1 "G" w/l% CFR-2, 2% gel, 10#/sx Gilsonite, .1% HR-7. Prep to displ cmt. 7" @ 12,600' 12,600', (0'), CO cmt in 9-5/8" Wt. 9.7, PV 6, YP 6, PH 10.5, WL 27, Sol 6.5 Displ cmt w/rig pmps, bump plug. CIP @ 0700 hfs,. 3/14/85. w/csg scrprs, tag cmt stringers @ 8500'-8950', break circ@ 8850' wsh & rm cmt stringers f/8945'-9575'. ~.. :,~...., TIH IOate ITit3e . 10125/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History---Interim Instll~cttone: This form is use(~ during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem testa Sequentially. Attach description of ell cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative teat on "Final" form. 1) Submit "Interim" sheets when filled out but not less frecluently than every 30 days. or (2) on Wedlleeday of the week in which oil string is set. Submit weekly for workovera and following setting of oil string until completion. District Field County or Parish [State Alaska ILease o, Unit North Slope Borough Prudhoe Bay I ADL #28302 Alaska IWell no. LI-9 Date and depth aa of 8:00 a.m. 3/16/85 thru 3/18/85 3/19/85 3/20/85 3/21/85 3/22/85 3/23/85 thru 3/25/85 3/26/85 Complete record for each day while drilling or workover in progress 7" @ 12,600' 12,985', (385'), Turbine drlg Wt. 9.7, PV 8, YP 5, PH 12.0, WL 25, Sol 6.5 Drl cmt to 10,788', TOH. Chg lower rams to 3½" & tst; OK. TIH w/6" BHA, drl cmt f/12,443'-12,558', tst lnr lap & csg to 1500 psi, DO cmt & flt equip + 10' new hole to 12,612'. Conduct leak-off tst to 10.35 ppg EMW. Drl & surv to 12,985'. 7" @ 12,600' 13,023', (38'), Drlg Wt. 9.7, PV 9, YP 7, PH 11.5, WL 24, Sol 8.5 Turbine drl to 13,023'. 7" @ 12,600' 13,371', (348'), Drlg Wt. 9.4, PV 6, YP 5, PH 12.1, WL 28, Sol 8.5 Drl f/13,023' to 13,371'. 7" @ 12,600' 13,432', (61'), Wsh & rm to btm Wt. 9.7, PV 8, YP 12, PH 11.8, WL 19.2, Sol 7.5 Drl to 13,432', stuck pipe on btm. Wrk & Jar free, pmp LCM pill, POOH. TIH, wsh & rm 13,385'-13,432'. 7" @ 12,600' 13,807', (375'), Drlg ahead Wt. 9.7, PV 6, YP 7, PH 11.6, WL 24/32, Sol 7.5 Drl 6" hole to 13,807'. 7" @ 12,600' 14,136', (329'), POH f/logs Wt. 9.7, PV 5, YP 14, PH 11.3, WL 44, Sol 7.5 Drl to 13,690', pipe stuck. Spot SFT pill, jar pipe free. Drl & surv 6" hole to 14,136', C&C, short trip, CBU, POH f/logs. 7" @ 12,600' 14,136', (0'), POH f/logs Wt. 9.7, PV 4, YP 12, PH 11.3, WL 46.4, Sol 7.5 RU Schl, att to rn logs, tl stopped @ 12,630', POH. to 12,556', rm to 12,758', CBU, TOH f/logs. TIH w/BHA The above is correct For form preparation and dis~'ibution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ]Date 10/25/85 ]Title Drilling' Superintendent ARCO Oil and Gas Company ~, Daily Well History--Interim Inet~¢tlona: Thi· form i· u·ed during drilling or workover operation·. If re·ting, coring, or perforating, show formation name in de·cribing work performed. Number all drill ·tern te·t· sequentially. Attach de·cription of all cores. Work performed by Producing Section will be reporled on "Interim" sheet· until final completion. Reporl official or repre·entative te·t on "Final" form. 1} Submit "Interim" sheet· when filled out but not la·· frequently than every 30 day·. or (2) on Wednesday of the week in which oil ·tring i· set. Submit weekly for workovers and following setting of oil strinG until completion. Di·trict ICounty or Parish IState Alaska North Slope Borough Alaska Field ILease or Unit Iwe, no. Prudhoe Bay ADL #28302 I LI-9 Date and deptl~ Complete record for each day while drilling or workover in progre·s as of 8:00 a.m. 3/27/85 3/28~85 3129/85 3/30/85 thru 4101185 · 4/02/85 4/03/85 The above is correct 7" @ 12,600' 14,136', (0'), Displ w/new mud Wt. 9.7, PV 25, YP 30, PH 9.0, WL 6.0, Sol 5 CBU, TOH. RU Schl, att to rn logs; tl stopped @ 12,658' RD Schl. TIH w/7" scrpr to TD & prep to displ mud sys. · POtt, 7" @ 12,600' 14,136', (0'), Wrk stuck logs Wt. 9.7, PV 16, YP 14, PH 8.8, WL 7.2, Sol 5 Displ hole w/9.7 mud, circ, TOH. RU SOS, att to log LDT/CNL/GR/CAL, stuck @ 12,915'. Wrk logging tls. 7" @ 12,600' 14,136', (0'), POH to chg log tls Wt. 9.7, PV 15, YP 11, PH 8.8, WL 7, Sol 5 Wrk stuck logging tls free, POH to 7" csg, log to 12,050', POH. RIH, rm 12,751'-13,138', TIH to TD, CBU, POH. RIH w/BHCS to 12,750', stuck, wrk free, POH. 5" @ 14,136' 14,136', (0'), Displ cmt Wt. 9.7, PV 12, YP 10, PH 8, WL 6.8, Sol 5 Wrk stuck pipe free. Rn CBL/CCL/VDL/Signature f/12,585'-9700' & cased hole sonic f/2530'-12,100'. Rn CET f/10,788'-8950'. Rn Caliper f/10,712'-surf. Make cond'g trip, CBU. RU & rn 43 its, 5", 17.93# SS95 FL4S lnr w/TOL @ 12,441', FS @ 14,136'. Cmt w/100 sx C1 "G" w/l% CFR-2, 2% Gel, 10#/sx Gilsonite & .1% HR-7. Displ cmt to bump plug. CIP @ 0603 hfs, 4/1/85. 5" @ 14,136' 10,069' PBTD, POH Wt. 9.7, PV 10, YP 8, PH 7.8, WL 10, Sol 4.5 TOH aft cmt'g 5" lnr. TIH & polish 7" lnr tieback slv, TOH. 31 its, 7", 29#, L-80 BTC tieback lnr f/9604'-10,792' & cmt w/190 sx C1 "G" cmt w/5% KC1, 1% CFR-2, .3% Halad-24. CIP @ 0621 hfs, 4/2/85. 5" @ 14,136' 14,069' PBTD, POH Wt. 9.4+, PV 5, YP 23, PH 12.4, WL --, Sol 5 Fin displ'g cmt, POH. TIH to 9458', wsh cmt to 9591', CBU. PU BHA, TIH to 10,480', DO cmt to 10,788', wsh to 10,848', TIH to 12,400', CBU, POH. Signature For form preparation and distribution see Procedure· Manual Section 10, Drilling, Pages 86 and 87 Date ]Title 10/25/85 Drilling Su.p.er.in~ea&9~t y" ',.~ it,, ! ~ "ii' ,I ',.!.f~ -~ ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is uSed during drilling or workover operations. If testing, coring, or i~edorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative lest on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until comloletion. O~stHct ICounty or Parish [State Alaska North Slope Borough Field IUease or Unit ADL ¢/28302 I Complete record for each day white drilling or workover irt progress Prudhoe Bay Date and deptl~ as of 8:00 a.m. 4/04/85 4/o5/85 thru 4/08/85 4/09/85 4/10/85 , 4/11/85 Alaska no. LI-9 5" @ 14,136' 14,069' PBTD, POH to rn logs Wt. 9.7, PV 6, YP 12, PH 12.5, WL 22.4, Sol 5 Fin POOH. RIH w/4-1/8" bit & 5" csg scrpr, wsh & rm thru 5" tie back, cont in hole to 13,901', wsh & rm to 13,988'. Tst csg to 2100 psi, press fell to 540 psi. DO LC, soft cmt & FC @ 14,065', POH. POH to rn CNL/CBL/CET/GCT. 5" @ 14,136' 14,065' PBTD, Drlg cmt Wt. 9.6 Att to rn CBL logs w/o success. TIH w/5" RTTS, set @ 12,468', tst below in 5" lnr, tst backside, rel RTTS & POOH. RIH w/7" RTTS, set @ 12,034', tst above. M&P 100 sx C1 "G" w/5% KC1, 1.% CFR-2 & .3% Halad-24 & sqz lnr lap. CIP @ 1300 hfs, 4/5/85. RIH w/6" bit & 7" csg scrpr, tag cmt stringers @ 12,173', rm to 12,199', drl green cmt to 12,400', POH. RIH w/4-1/8" bit & 5" csg scrpr, circ@ FC & att to tst to 2500 psi, bled to 450 psi, POH. RIH w/7" RTTS, set @ 11,942', M&P 120 sx C1 "G" w/5% KCL, 1.0% CFR-2 & .3% Halad-24, hesitate sqz, POH & LD RTTS. CIP @ 1500 hfs, 4/7/85. RIH w/6" bit & 7" scrpr to 11,270', tag cmt @ 11,944', drl hard cmt f/12,092' on. 5" @ 14,136' 14,069' PBTD, RU to log 9.7 ppg NaC1 Fin drlg cmt to 12,400', POOH. RIH w/4-1/8" bit & scrprs, drl cmt thru 5" lap f/12,400'-12,495', fin RIH, tst csg to 2500 psi. Displ well to 9.7 NaC1, POOH. 5" @ 14,136' 14,069' PBTD, Logging 9.7 ppg NaC1 Rn GR/CCL f/14,074'-9500'. Att to rn CBL/GR/CCL (log #2, rn #4), tls stopped @ ±12,400'. RD Gearhart, RU Schl & prep to log. 5" @ 14,136' 14,069' PBTD, LD DP 9.7 ppg NaC1 Rn CNL/GR/CCL f/14,075'-10,300'. Rn CET/GR/CCL, tl stopped @ 12,400'. Rn GCT gyro f/surf - 12,325', RD Schl. TIH w/5" csg scrpr to 13,600', CBU, POH, LD DP. The above is correct Signature ~ ~)=,,~ ~l~..l,~.~__,l~__r___~_.,J For form preparation and distribution see Procedures Manual Section' 10, Orilling, Pages 86 and 87 IDate ITitle 10125185 Dr211irig Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inatl~ctlons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerila' sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlarlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesclay of the week in which oil string is set. Submit weekly for workovers and following setting of oil strmC5 until completion. District ICounty or Parish ]State Alaska North Slope Borough Field lc.seor Unit ADL #28302 I Complete record for each day while drilling or workover in progress Prudhoe Bay Date and depth as of 8:00 a.m. 4/12/85 4/13/85 thru 4115185 4/16/85 · 4/17/85 4/18/85 The above is correct 5" @ 14,136' 14,069' PBTD, Rn'g 3½" Cbg 9.7 ppg NaC1 LD DP & 5" csg scrpr. Rn 404 its, 3½", 9.2#, N-80 BTC PC=0 tbg w/special drift tailpipe. Alaska 5" @ 14,136' 14,069' PBTD, TOH 9.7 ppg NaC1 Fin rn'g 404 its, 3½", 9.2#, N-80 BTC tbg w/btm of mule shoe @ 12,516' & Ind. Tat pack-off to 5000 psi. ND BOPE, NU tree & tst tree to 5000 psi. Pmp 140 bbls diesel dn 3½" x 9-5/8" f/freeze protection. RIH w/std'g vlv, press up on tbg to 2500 psi, pkr set @ 1500 psi, POH w/std'g vlv. Pressure up on tbg to 2500 psi, press bled to 1200 psi/15 min. Press ann to 2500 psi; OK, no communication. ND tree, NU & tat BOPE. Open SSSV, circ out diesel cap. RU & pull 3½" tbg, pull pkr. TIH w/RTTS, set @ 12,384'. Press up to 2500 psi, bled to 1100 psi/30 min. Att to est IR, bleeding f/3500 psi to 2500 psi/2 min, TOH & LD RTTS. TIH w/10 its, 2-3/8" DP to 12,436'. RU & pmp 60 sx C1 "G" w/5% KC1, 1.0% CFR-2 & .3% Halad 24. Displ cma w/rig. Sqz cma w/final press of 3500 psi, .7 bbls. Total sqz 4.8 bbls. Bled press, TOH. , drl cma to 12,400', circ, 5" @ 14,136' 14,069' PBTD, TIH w/5" csg scrpr 9.7 ppg NaC1 TIH w/7" csg scrpr, tag TOC@ 12,059' TOH. PU 5" csg scrpr, TIH. 5" @ 14,136' 14,069' PBTD, Displ'g hole w/cln brine 9.7 ppg NaC1 Drl cmt to 12,432', rm stringers to 12,494', TIH to 14,069' circ, tst csg to 2500 psi; OK. Displ hole to cln brine. 5" @ 14,136' 14,069' PBTD, ND BOPE 9.7 ppg Nat1 Fin CO brine, tst csg to 2500 psi, POH, LD DP. Rn 404 Jts, 3½", 9.2#, N-80 PC=0 tbg & lnd w/btm mule shoe @ 12,515.56', SSSV @ 2169', FHL Pkr @ 12,093'. ND BOPE. IWell no. [.1-9 Signature For form preparation a~d distribution see Procedures Manual'Section 10, Drilling, Pages 86 and 87 IDate ]Title 10/25/85 ARCO Oil and Gas Company Daily Well History-Final Report Instructione: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Ptugged, Abandoned. or Sold. "Final Re~o~'t" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish I State Alaska I North Slope Borough I Alaska Field ILease or Unit lWell no. Prudhoe Bay I ADL ~28302 I L1-9 Auth. or W.O. no. ]Title AFE 504211 I Drill, Core, Complete & Perforate Parker #176 Operator [A.R.Co. W.I, ARCO Alaska, Inc. 50% Spudded or W.O. begun ]Date Spudded I l / 13/85 -Date and depth as of 8:00 a.m, Complete record for each day reported Old TO AP1 50-029-21265 I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prlor status if a W.O. 0100 Hrs. 4/19/85 5" @ 14,136' 14,069' PBTD, RR ND BOPE. Nil & tst tree to 5000 psi. Dislp 9-5/8" x 3½" ann w/140 bbls diesel. RIH w/std'g vlv to 12,472', set pkr, POH w/std'g vlv. Tst SSSV. RR @ 1800 hfs, 4/18/85. RECEIVED APR 0 9 1,986 Alaska t.~,~ " New TD 14,136' (3/24/85) Released rig Date 1800 Hrs. 4/18/85 PBDepth 14~069' I Ki~d of rig Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Sin$1e Official reservoir name(s) Lisburne Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature _ For form preparation ~l[d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 10/25/85 [Title Drillin~ Superintendent ARCO Alaska Inc. Lisburne Engineering To: State of Alaska John Boyle From: Pam Lambert Date: March 12, 1986 Traasmitted herewith are :he following: CH Finals for Lisburne Well L1-9 Hydro Log 2-9-86 Run 1 5" GO Spinner 2-9-86 Run 1 5" GO Receipt Acknowledgement: 7 Return Receipt to: ARCO Alaska Ic~. '-'~Alaska 0il& Gas Cons. G0mmissi0, . Pam Lambert ~TO 47%-'/ Anch01'age PO Box i00360k---/ Anchorage, Alaska 99510 Transmittal No: ~5 "~0 STATE OF ALASKA O~ ALASKA IL AND GAS CONSERVATION C v~MISSION WELL COMI LETION OR RECOMI LETION RERORT AND LOG Classification of Service Well 1. Status of Well .~/ OIL I~xX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21265 4. Location of well at surface 9. Unit or Lease Name 2422' FSL, 2468' FWL, Sec.1, T11N, R14E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1466' FNL, 1147' FEL, Sec.11, T11N, R14E, UN L1-9 At Total Depth 11. Field and Pool 2413' FSL, 2264' FWL, Sec.11, T11N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 44' RKBI ADL 28302 ALK 2313 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 01/13/85 03/25/85 04/18/85* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set 21. Thickness of Permafrost 14136'MD,10416'TVD 12200'MD, 9298'TVD YES [~X NO [] 2155 'feet MD 1900' (Approx) 22. Type Electric or Other Logs Run SHDT/AMS/GR, Casing Cal, DI L/SP/MSFL/NGT/Cal ,LDT/CNL/GR/Cal/ML/EPT,FDC/GR/Cal, (See attached sheet) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEI WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# U-40 Surf 110' 30" 1800# Polyurethane 13-3/8" 72.0# L-80 Surf 4002' 17-1/2" 3200 sx PF"E" & 400 sz Class G 9-5/8" 47.0# L-80 Surf 11,095' 12-1/4" 1000 sx Class G & 300 sx CS I 7" 29.0# L-80 9604' 12,600' 8-1/2" 1040 sx Class G & 280 sx Class G 5" 17.93# FL4S 12441' 14,136' 6" 100sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11,278' - 11,898' w/4 spf, 90° phasing 2-7/8" 11,207' 11,137' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 12,972'-13,270' Alapah perfs have been abandoned. Cmt retainer e 1~:,364' 40 sx Class G plug on top of retainer 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested IPRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GASIOIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None E i V E D ['% ~ APR 0 1986; Alaska O}i & C-:3s C.:,,ns. Commi~]o,~ m NOTE: Well was recompieted and perforated i/i9/86. DAM/WC67 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Lisburne MEAS. DEPTH 11,281 ' TRUEVERT. DEPTH 8837' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GQR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Workover Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Associate Engineer Signed ~ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 Well Completion or Recompletion Report and Log L1-9 (cont'd) ITEM #22: DIL/MSFL/GR, BHCS/GR/Cal, BHCS/GR/WF, LSS/GR, DLL/MSFL/NGT, LDT/CNL/GR/Cal, CBL/CCL/VDL/Signature, CET, Dialog casing caliper, GR/CCL, CNL/GR/CCL, CET, GR/CCL, GCT, DST ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is Spudded or worKover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only, District ICounty, parish or borough Alaska I North Slope Borough i Field ILease or Unit Prudhoe Bay I ADL 28302 Auth, or W,O. no. ITitle AFE 703851 Alapah/504211 WahooI Recompletion Istate Alaska - w/o Pool 102 API 50-029-21265 Operator ARCO Alaska, Inc. Workover 1/07/86 Date and depth as of 8:00 a.m. 1/08/86 1/o9/86 1/10/86 1/11/86 thru 1/13/86 1/14/86 1715/86 Complete record for each day reported 1100 Hrs. lARGO W.I. 50% Prior status if a W,O. 5" @ 14,136' 13,308' PBTD, Set BPV 9.6+ ppg NaCl/NaBr Accept ri~ @ 1100 hrs, 1/7/86. Pull BPV. Kill tbg by bullheading 123 bbls, 9.6+ ppg brine dn tbg. Monitor well. RIH, pull dummy @ 10,744'. Displ ann to brine. Monitor well. 5" @ 14,136' ' 13,308' PBTD, LD 3½" tbg 9.6+ ppg NaCl/NaBr Set BPV. ND tree, NU & tst BOPE. Shear out PBR, POH, LD 3½" tbg. Wrk tbg, mx mud lub in sys. 5" @ 14,136' 13,308' PBTD, PU 2-7/8" DP 9.6+ ppg NaC1 Fin POH & LD 3½" prod tbg & equip. & 2-7/8" DP. MU PBR retrv'g tl. PU DC's 5" @ 14,136' 12,142' PBTD, RIH w/bit & scrprs 9.6 ppg NaCl PU DP, latch into PBR, pull pkr loose, POH & LD pkr & tbg tail. RIH w/6" bit/7" scrpr to 12,350', POH. MU 7" Bkr CR, RIH, set CR @ 12,364'. Equalize 40 sx C1 "G" cmt plug on retnr, POH, LD 2-7/8" DP. MU bit & scrpr, RIH. 5" @ 14,136' 12,200' PBTD, ND Gen III tbg head 9.6 ppg NaC1 DO cmt to new PBTD of 12,200', rev circ, cln & filter brine wtr, POH. RIH, set retrv BP @ 2004'. ND BOPE to chg tbg head. 5" @ 14,136' 12,200' PBTD, RIH w/perf guns 9.6+ ppg NaC1 Chg out tbg head. Instl Gen IV 13-5/8" 5M x 11" 5M. flange & pack-off. PU DA tbg conveyed guns & RIH. Tst The above is correct Signature _~2~ ~j~l~~ For form preparation and distrib~lon, see Procedures Manual, Section I0, Drilling. Pages 86 and 87. IDate Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. DistrictAlaska county or Parish Field ]Lease or Unit 1 Prudhoe Bay Auth. or W.O. no. AFE 703851 Alapah/504211 Waho~TM Pool 102 Accounting cost center code State North Slope Borough Alaska ADL 28302 Recompletion Well no. L1-9 W/O API 50-029-21265 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 50% Spudded or W.O. begun ~Date Workover I 1/07/86 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prtor status if a W.O. I 1100 Hrs. Date and depth as of 8:00 a,m. Old TD Complete record for each day reported 1/16/86 1/17/86 1/18/86 thru 1/20/86 5" @ 14,136' 12,200' PBTD, POOH w/3½" DP 9.6+ ppg NaC1/NaBr RIH w/guns on DP, fire guns & monitor. POOH w/3½" DP. 5" @ 14,136' 12,200' PBTD, POOH, LD DP 9.6+ ppg NaC1 POOH w/DP & tbg conveyed guns. Shear PBR, POOH, LD DP. Kill well w/9.6+ brine, RIH w/FH pkr, set @ 11,120'~£~. 5" @ 14,136' 12,200' PBTD, RR Diesel Chg rams & tst. RU & rn 257 its, 2-7/8", 6.5#, L-80 EUE 8RD tbg w/SSSV @ 2155', PBR @ 11,124', FH Pkr @ 11,137', "D" Nipple @ 11,174', TT @ 11,207'. Tst csg & tbg. Tst SSSV. Set BPV. ND BOPE, NU & tst tree. Displ well w/diesel. RR @ 0900 hrs, 1/19/86. New TD Released rig Date 0900 Hrs. Classifications (oil, gas, etc,) O±l Producing method Flowing PB Depth 1/19/86 [K nd of rig Type completion (single, dual, etc,) Single Official reservoir name(s) Lisburne 12,200" ': Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribgtion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling Superintendent ARCO Alaska, Inc. ,~ Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Subsequent Sundry Reports - L1-9 & L3-5 Dear Mr. Chatterton' Enclosed are Subsequent Sundry Reports for the following Wells. L1-9 L3-5 If you have any questions, please call me at 263-4944. SincerelY, J~.' Gruber Associate Engineer JG/tw GRU13/L117 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~r~M ALASKA OIL AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P. 0. Box 1002,60, Anchorage, AK 99510 50- 029-21265 2422' FSL, 2468' FWL, Sec.1, T11N, R14E, UN 4. Location of Well Surface: 5. Elevation in feet (indicate KB, DF, etc.) _ 44 ' RKB 12. 6. Lease Designation and Serial No. ADL 282,02 ALK 22,12, 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well Number L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations '~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing ]~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1100 hfs, 1/7/86. Killed well. ND tree. NU BOPE & tstd to 5000 psi - ok. Pulled 3-1/2" tubing. Recovered pkr. Set cement retainer ~ 12,2,64'. Mixed & pumped 40 sx Class G plug on top of the retainer. Tstd csg to 2,000 psi - ok. Perf'd 11,278' - 11,898' w/4 spf, 90° phasing. Ran 2-7/8" completion assy w/SSSV ~ 2155', pkr ~ 11,12,7', & tail ~ 11,207' ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel. Set BPV. Secured well & released rig ~ 0900 hfs, 1/20/86. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ ~~1_, Tit,e Associ ate Engineer The space belov~for Commission use Date Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU12,/SN33 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B~[~ ~30360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton' Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the January Monthly Reports for the following wells: 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 ~Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc, is a Subsidiary of AtlanllcRIchfleldCompany RECEIVED r EB 1 1986 AlasKa 0il & bus Ccns. Gu~n[nission Anchorage STATE OF ALASKA ALASKA'~.- _ AND GAS CONSERVATION CO('# .,'IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operationX~] 2. Name of operator 7. Permit No. ARCO A1 aska, I nc, 85-1 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21265 4. Location of Well atsurface 2422' FSL, 2468' FWL, Sec.1, T11N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 44' REB ADL 28302 ALK 231~ 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of January ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1100 hfs, 1/7/86. Killed well. ND tree. NU BOPE & tstd. Pulled 3-1/2" tbg. Jarred on and pulled pkr. Set cmt. retainer ~ 12,364'. Mixed & pumped 40 sx Class G cmt. Set bridge plug ~ 2004'. Set FH pkr. Perf'd well. Ran 2-7/8" completion assy. ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured wel 1 & RR ~ 0900 hfs, 1/19/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 2-7/8" tbg. SSSV @ 2155', FH pkr ~ 11,137', & tailpipe @ 11,207' 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data 11,278' - 11,898' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED & ~0(j .~/,A~L.2 TITLE Associate Engineer DATE '~'/~'~ ~- , NOTE--Repori~/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR45 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. {" Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation ConTnission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: L1-9 Permit No. 85-1 Enclosed is the "Intention" Sundry Notices detailing work proposed on the above-mentioned well. You may contact me at 265-6254 for ConTnents and/or questions. Very truly yours, B. T. Kawakami BT:A/STATE:cjb Attachment cc: Fi le ARCO Alaska, ~nc, is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL/~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 85-1 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21265 4. Location of Well Surface' 2422' FSL, 2468' FWL, Sec. 1, TllN, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit/Lisburn~ 1320' FNL, 1320' FEL, Sec.11, T11E, R14E, UM @ Target 2372; FNL, 2385; FEL, Sec.11, T11N, R14E, UM (Approx) 6. L~eLDe~i§r~a~)i,~n a/~ld~erial No. 2313 10. Well Number L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ,~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to conduct the following operations on Lisburne well L1-9' (1) Stimulation with 15,000 gallons of 15% HCL. The acid will be pumped through the production string to the perf, orated intervals between 11,258' and 11,898' (359' of perforated interval). (2) 14 day production test. A portable test facility will be used for the product ion test. (3) If poo~ product ion is shown after 2 days of production testing, the testing will be shut down and a major fracture stimulation performed. This fracture stimulation will be~gelled water fracture with 2800 barrels of water and 70,000 pounds of 20/40 ISP propant. It will be pumped down the casing at 50 barrels per minute. After the fracture stimulation the production test will be completed. Estimated Start' January 20, 1986 RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knov~ 0il & Gas Cons, 001~'lilliSSi0[I The space below for Commission use ~) ,A~chorage Title Z~'~/,/'~L/~;' ~ )~'t~' ~, Conditions of Approval, if any: Approved by. ,:_,~,j~pr o v ed C. oi.~. Y ~turned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc..~.c Post Office Bo'x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 9950]. SUBJEC'T- L1-9 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Chatterton. Enclosed is a copy of the L1-9 Core Description to include with the t~ell Completion Report dated 10/22/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L154 Eric1 osure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .~RCO Alaska Inc. Lisburne Engineering TO ~ Addream: State of Alaska 3001 Porcupine Dr. Thousand Oaks, CA 91360 Para Lambert From: , December 24, i985 Date: . C.V. Chatterton Attn: Transmitted herewith are the following: CH Final Logs for Lisburne Wells L1-9 Gamma Ray Run 1 5" Sch 5-1-85 ~'~Li-10 CET Run 1 5" Sch 5-31-85 Receipt Acknowledsemant: ........... Return Receipt to: ARCO Alaska Inc. Lisburne Engineering Attn: Pam Lamber~ ATO 477 P.O. Box 10036Q Anchorage, Alaska 99510 Transmittal No.: ~~~ AIt¢O AIiI#i. Inc. I~ · $ul~sKIlar¥ o! Alllnllclqlcl~flelcIComl)sny ( STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION C0~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLxE~ OTHER 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage~ AK 99510 4. Location of Well Surface: 2422' FSL, 2468' FWL, Sec.1, T11N, R14E, UN 1320' FNL, 1320' FEL, Sec.11, T11E, R14E, UM ~ Target 2372' FNL, 2385' FEL, Sec.11, T11N, R14E; UM (A.nprn×) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I 7. Permit No. 85-1 8. APl Number 50- 9. Unit or Lease Name Pru ...................... 10. Well Number L1-9 11. Field and Pool Prudhoe Bay Fi eld Lisburne 0il Pool RKB 44'., PAD 14' ADL 28302 ALK 23!3 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate h~ Alter Casino,_~,___.~x-- [] Perforations [] Altering Casing Stimulate [] ~:::gd~: Ia n~sJ~-'/~) ~;] Stimulation [] Abandonment Repair Well [] [] Repairs Made [] Other Pull Tubing ~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to abandon Lisburne Alapah perforations 12,966' - 13,280' (overall) by pulling the 3-1/2" completion, setting a cast iron bridge plug in 7" casing at approximately 12,400' and dumping 50' of cement fill on top. The 7" liner will be perforated for Wahoo production selectively from 11,258' - 11,478' and 11,506' - 11,898 (overall) and a 2-7/8" completion run with provisions for subsurface safety and with a packer set above the Wahoo. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below~or Commission use Alaska OJ! ~,~ u~ ~,u.,~. Cu~unlSSlOn Anchorage 'Date 1Z-4-,95 Conditions of Approval, if any: Approved by. Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 (JJG) SN/107 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: L1-9 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for L1-9. I have not yet received the Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L37 Enclosures RECEIVED NOV 0 ]985 Alaska Oil & Gas Cons. 8oiiimission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfieldCompany ,,,,- STATE OF ALASKA ALASKA ~ .. AND GAS CONSERVATION Cq~ .41SSION WELL COMPLETION OR RECOMPLETION R'EPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. /~/'~1, I1-11~1"~ I'I'11~ I 85-1 3. Address L;UNI-IU~j~IRL 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 . ~- 50- 029-21265 LOCATIONS 4. Location of well at surface VERiFieD 9. Unit or Lease Name 2422' FSL, 2468' FWL, See.l, T11N, R14E, UN'~ Prudhoe Bay Unit/Lisburne Surf. At Top Producing Interval ~ 10. Well Number 1466' FNL, 1147' FEL, Sec.ll, TllN, R14E, UM ~B'H'~__ L1-9 At Total Depth 11. Field and Pool 2413' FSL, 2264' FWL, See.ll, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lisburne 0il Pool 44' RKB ADL 28302 ALK 2313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01/13/85 03/25/85 04/18/85J N/Afeet MSLI 17, Total Depth (MD+TVD) 18, Plug Back Depth (MD+TVD)19, Directional Survey I 20. Depth where SSSV set 121.Thickness of Permafrost 14136'MD,10416'TVD 14069'MD,10362'TVD YES [~X NO [] 2169 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run SHDT/AMS/GR, Casing Cal, D I L/SP/MSFL/NGT/Cal, LDT/CNL/GR/Cal/ML/EPT, FDC/GR/Cal, (See attached sheet) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5/t H-40 Surf 110' 30" 1800# Pol3/urethane 13-3/8" 72.0# L-80 Surf 4002' 17-1/2" 3200 sx PF"E" & 400 sx Class G 9-5/8" 47.0# L-80 Surf 11~095' 12-1/4" 1000 sx Class G & 300 x CS I 7" 29.0# L-80 9604' 12,600' 8-1/2" 1040 sx Class G & 280 x Class G 5" 17.,93# FL4S 12441' 14,136' 6" 100sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET ('MD) None 3-1/2"' 12,516' 12 ~ 093' 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A , 27. N/A PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc. I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCI~ WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ , , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .RECEIVED Alaska Oi~ & Gas Cons, Commissio~ Anchorage Form 10-407 TEMP2/WC40 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~. . ,, -. .. , , '. . , ;, - , ~,~ ,: ; ,,, . · ~: " .... '~; "' :'' """:' ' '"':: ..... i"-' 'M~,T~ION!':T T~ '". · , .'~ .... G,EOiZ.'OGiO'MARKERS; ' ""':'" .... ~ 4,': ': '. FOiR E'S '~.. . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Lisburne 11,281' 8832517 ,~J'~ ° ~"~i~,{m'! DST Data to be submitted, when received. 31. LIST OF ATTA'CHMENTS · -~ ..... r ..... ~ - J · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,, ~~,~~ Title ASSOc$ ate E,g~ neeF Date ]0' ZZ-~ .... ~J - .~~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in AlaSka. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached suPplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-40'7 Core #1 0.8' 3.3' 1 .5' L1-9 Well-Site Core Description CONFIDENTIAL ll ,292-11,298 Cut 6' Recovered 4.5' 2/7/85 Interbedded dark gray si ltstone and shale. Interbedded argillaceous skeletal packstone/grainstone, sandy in part with sandy dolomite limestone near base. Not recovered. Core #2 0.8' 2.2' 3.0' 11,298-11304 Cut 6' Recovered 3' 2/8/85 Argillaceous, skeletal, lime packstone Skeletal, lime grainstone; chert nodules near base. Not Recovered. Core #3 3.8' 6.8' 1.1' 9.31 11,304-11,334 Cut 30' Recovered 30' 2/10/85 Silty, argillaceous, line packstone to grainstone. Limestone, superficial oolitic grainstone with scattered crinoidal debris. Quartz sandstone, fine grained, moderately sorted. Limestone, mixed skeletal/peloidal packstone to grainstone. Oolitic, lime grainst°ne. Core #4 11.0' 2.6' 9.41 11,334-11,359 Cut 25' Recovered 25' 2/10/85 Oolitic lime grainstone Cherty, dolomitic, lime wacke/packstone interbedded with thin dolomite stringers. Skeletal, lime grainstone. Blue-gray, spiculitic chert. Core #5 9.7~ 1 ~0' 2.9' 0.4' 11,373-11,394 Cut 21' Recovered 21' 2/15/85 Core #5 is a repeat of same stratigraphic interval cut in Core 4. Core #5 was cut after a sidetrack was made uphole. Top of Core #$ and Core #5 are at TVD 8890. Oolitic, lime grainstone. Mixed skeletal and peloidal grainstone. Becomes dolomitic at base. Siliceous dolomite; spiculitic packstone. Skeletal, lime grainstone. Rubble; highly fractured, siliceous, peloidal, lime grainstone. JA~t 0 2 ~'~'" Alaska .Oil :& Gas Cons. .-,~,i ~chorage Core #6 1.3' 4.1' 6.6' 1 .0' 11,394-11,415 Cut 21' Recovered 13' 2/16/85 Cherty, peloidal, lime grainstone. Limestone; cherty, skeletal grainstone. Calcareous chert and cherty peloidal and skeletal pack/grainstone. Calcareous dolomite. Not Recovered. Core #7 0.5' 4.5' 7.8' 4.2' 11,415-11,432 Cut 17' Recovered 17' 2/17/85 Calcareous dolomite. Limestone; skeletal grainstone slightly dolomitic. Calcareous dolomite; mudstone. Interbedded chert and siliceous limestone; limestone dominantly mudstone except near base where it is a skeletal wackestone. Core #8 4.0' 2.0' ll ,432-11,438 Cut 6' Recovered 4' Cherty, siliceous, lime mudstone. Not Recovered. 2/17/95 Core #9 8.0' 1.2' 0.3' 11,438-11,451 Cut 13' Recovered 9.5' Siliceous, skeletal, lime wackestone. Dark gray to black, calcareous chert. Dolomitic, skeletal, lime packstone. 2/18/85 Core #10 14.8' 3.4' 3.8' 5.0' 11,451-11,479 Cut 28' Recovered 27' 2/19/85 Interbedded skeletal and oolitic lime grainstone; few stringers and nodules of chert. Lime grainstone. Skeletal, lime packstone. Interbedded skeletal and peloidal lime grainstone. Core #11 0.2' 7.8' 3.0' 6.0' 3.7' 1.8' 11,479-11,504 Cut 25' Recovered 25' 2/20/85 Rubble; silty claystone. Interbedded skeletal and non-skeletal lime grainstone. Skeletal, lime-packstone. Skeletal, lime-grainstone. Silty claystone; sub-fissile to fissile, slightly calcareous, medium gray. Limestone; grainstone. Clayey siltstone; medium gray. RECEIVED ,Oil .& Gas Cons. ~,um,",sston --,~.i ;Anchorage Core #12 7.5' 0.5' 2.8' ll,2' 2.0' 11,504-11,528 Cut 24' Recovered 22' 2/21/85 Clayey siltstone; pyritic, slightly calcareous. Interbedded clayey siltstone and skeletal, 1 ime-grainstone. Siliceous limestone; skeletal grainstone. Limestone; skeletal grainstone. Not Recovered. Core #13 13.7' 2.3' 5.5' Core #14 6.0' 13.0' 11,528-11,552 Cut 24' Recovered 21.5' 2/21/85 Interbedded skeletal and non-skeletal l ime-grainstone. Dolomitic, lime-mudstone. Limestone; skeletal and non-skeletal grainstone. 11,552-11,571 Cut 19' Recovered 19' 2/22/85 Limestone; skeletal and peloidal grainstone interbedded with chert. Limestone; skeletal and peloidal grainstone. Core #15 6.1' 6.9' 11,571-11584 Cut 13' Recovered 13' Limestone, skeletal wacke/packstone. Limestone; cherty, skeletal grainstone. 2/23/85 Core #16 15.5' 3.5' ll ,584-11,603 Cut 19' Recovered 15.5' Limestone; skeletal and non-skeletal grainstone. Not Recovered. 2/23/85 Core #17 12.0' 15.0' 11,603-11,630 Cut 27' Recovered 12' 2/24/85 Skeletal and non-skeletal l ime-grainstone; cherty at base. Not Recovered. Core #18 ll .3' 0.7' ll ,630-11642 Cut 12' Recovered 13' 2/24/85 Interbedded dolomitic l ime-packstone and grainstone. Not recovered. Core #19 5.0' 5.0' 2.0' 7.0' ll ,642-11,661 Cut 19' Recovered 19' 2/25/85 Limestone; skeletal packstone. Dolomitic limestone; skeletal and non-skeletal grainstone. Brecciated skeletal and non-skeletal lime-grainstone and spiculitic dolomite. Limestone. RECEIVED CONFIr3ETi"i ,L Core #20 2.0' 2.3' 1 ,2' 1 .Bt 11,661-11,672 Cut 13' Recovered 10.5' 2/25/85 Dolomitic limestone; skeletal and non-skeletal grainstone. Cherty, dolomitic limestone; skeletal and non-skeletal grainstone. Interbedded argilleceous siltstone and silty dolomite. Skeletal and non-skeletal grainstone; with irregular patches of l ime-mudstone. Breccia; clay, siltstone and skeletal lime-grainstone. Not Recovered. Core #21 2.0' 4.2' 23.3' 0.5' 11,672-11,702 Cut 30' Recovered 30' 2/26/85 Skeletal lime-grainstone, brecciated. Dolomitic limestone; skeletal and non-skeletal grainstone and packstone. Dolomitic, silty shale and shaly siltstone. Limestone with shale clasts. Core #22 '3.5' 4.0' 1.5' Il,702-11,712 Cut 10' Recovered 9' Limestone, skeletal and non-skeletal grainstone. Dolomitic, silty shale. Skeletal, lime-grainstone. 2/27/85 Core #23 13.0' 7.0' 2.8' 0.2' 11,712-11,735 Cut 23' Recovered 23' 2/27/85 Limestone; skeletal grainstone in part dolomitic; a few thin shale and siltstone layers. Cherty, dolomitic limestone; skeletal and non-skeletal grainstone. Skeletal and non-skeletal lime-grainstone. Pyritic, shaly siltstone. Core #24 2.8' 1.4' 4.8' 15.0' 11,735-11759 Cut 24' Recovered 24' Shaly siltstone, slightly pyritic. Interbedded calcareous shale and l ime-mudstone. Limestone; mudstone. Limestone; skeletal and non-skeletal. 2/28/85 Core #25 ll .0' 2.0' 3.5' 1.5' 8.0' 11,759-11,785 Cut 26' Recovered 26' 2/28/85 Dolomitic limestone; skeletal grainstone. Dolomite; skeletal pack/grainstone. Dolomitic limestone; skeletal grainstone. Siltstone and chert; medium to dark gray. Interbedded skeletal and non-skeletal lime-grainstone; cherty towards top of interval. I ECEIVED .~ 1 ~. JAN 0 2 .~:~ · Oil & Bas Cons. Anchorage Core #26 4.0' 10.0' 12.0' ll ,785-11,811 Cut 26 Recovered 26' Skeletal, lime-grainstone. Silty dolomitic, skeletal grainstone. Limestone; skeletal and non-skeletal packstone. 3/1/85 Core #27 4.6' 3.4' 2.0' lC.O' 1.0' 12.0' 3.5' 7.5' 11,811-11,854 Cut 43' Recovered 35.5' Skeletal 1 ime-grainstone. Silty, dolomitic shale. Limestone; skeletal and non-skeletal grainstone. Dolomitic and limy siltstone and shale. Interbedded dolomitic, lime-grainstone and chert. Limestone; non-skeletal (oolitic) grainstone. Limestone; skeletal and non-skeletal grainstone. Not Recovered. 3/3/85 Core #28 16.0' 5.0' 9.0' 2.0' 1.0' 11,854-11,887 Cut 33' Recovered 33' 3/3/85 Interbedded limestone, dolomite and shale; limestone and dolomite are silty skeletal and non-skeletal and non-skeletal grainstone. Limestone, non-skeletal (peloidal) grainstone, lower 1.0' is interbedded limestone, shale and chert. Limestone, skeletal grainstone. Rubble; dolomitic, silty shale. Silty, dolomitic limestone, non-skeletal grainstone. Core #29 18.0' 5.0' 3.0' 12.0' 2.0' 11,887-11,939 Cut 52' Recovered 50' Limestone; interbedded skeletal and non-skeletal (peloidal) grainstone. Limestone; non-skeletal (peloidal) grainstone. Dolomitic limestone; skeletal grainstone. Limestone; oolitic grainstone. DolOmitic shale. Not Recovered. 3/4/85 RECEIVED JAN 0 2 · ~aska Oil & Gas Cons. Commission ..... ~ Anchora§e, Well Completion or Recompletion Report & Log (Cont'd) L1 -9 Item 22: CONFIDENTIAL DIL/MSFL/GR,BHCS/GR/Cal,BHCS/GR/WF,LSS/GR,DLL/MSFL/NGT,LDT/CNL/GR/Cal,CBL/CCL/ VDL/Signature,CET, Dialog casing caliper,GR/CCL,CNL/GR/CCL,CET,GR/CCL,GCT,DST. ,~rFiVED ~"~!cv o 4 1985 Anchorage CONFII]ENTI L SUB-SURFACE DIRECTIONAL SURVEY !"~ UIDANCE I~ONTINUOUS I-~OOL Company Well Name Field/Location Job Reference No,, 70512 HALFACRE/LESNIE ATLANTIC RICHFIELD COMPANY L1-9 (2422' FSL., Z46~' FELL. S1...TllN. R14E- 1~) LISBURNE UNIT, NORTH SLOPE~ ALASKA ! ! * This Survey is tied into Sperry Sun dated: 21-APR-85 k£C£iv£b 24-JUNE- 1985 NOV O' ' ~:9~ Computed By: 4iaska .Oil & Gas "~ A/~chora!ge (;°'"~'.'~:;~'on STEVENS GCT ~I~ECTIONAL SUR'V~¥ CUSTOMER LISTTNG ARCO ALASKA, INC. [, 1-9 NOR?H SbQPE,Ab. ASKA , SU.PVF~¥ DATE~ lO-APR-B5 ENGINEER: HAI, F;~CRE/LEBMIE ~ET!,~DS OF CO~Pl;TATION TOOb [._r~C~'l'TOg: TAr.)GENTI~.L- averaged deviation and azimuth It~T~RPObAT I[)N: 'r!k IN: This listinq is tied into Sperry Sun S,rvey dated 21-APR-85 Der custo,'~er req~]est. VWRTICAL S~C'J'TO~: riqRIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 45 DEG 21 MIN WEST ARCF} A L,,a 5KA. b T SP I.~ R f,: k~ NORTH S[,OPD:.ALASKA CO~{PLITATION DATE; 21-dUN-85 PAGE DATE OF SURVEY: lO-APR-85 KELGY RUSHIN~ EDEVATION: ENGINEER~ HAbFACRE/LESNIE IDJTERPL)I,ATEI:) VAI;UE$ FOi~ EVEN lO0 FEET OF MEASURED DEPTH MEASli~Fp VrRTI~AI, VERtICAl, DEYTATIOm AMIMUTH DEP'[ri D~P~ I)£PTH D~G MTN D~G ~{1~ n.o0 O.OO -44,00 0 0 lo0,o0 09,9q 20o,oo 199,9o 155,99 0 300,Ou 209,90 25~ q9 0 4 $ ~8 l? W 400.nU 3o9,99 355:99 0 14 500.00 ,tO~.~g 455 99 0 11 . 600,00 509,99 555,99 0 17 700.¢~0 oq~,~q 655,09 0 26 RO0.O0 7q~.~n 755,99 0 16 $ 4 3 E O00.O0 ~99.9g ~55,99 0 lq S 15 36 W tO00.O0 999.9~ IIUO nu 10g9 9~ 1055.q~ 1200:00 1!09!9~ 1!55,q~ ~ · . . . _ _ _ ¢3 ~ l~O0 0~ 12q9 ~R 1255,. 1600,0(> 1599,98 1555,08 1700,0o ~699 97 i655,g7 1800.OU ~799~97 1755,07 lgo0.o0 1899,97 lg55,07 2700 OO 2800:0u 2755,q6 290n,00 2809.96 2855,96 2000,00 19~9.97 1055,97 2100,00 2099 97 2055.o7 2~00,00 7299,97 2?bM,07 24oo.o0 93q9.96 23SM.q6 2500,00 2499,96 2455,q~ 2600,~0 Psg9.96 2555,ob 75g~,96 2655,~6 2799.96 0 17 ~ 4~ I E 5 3~ r 26 56 W 6 37 ~ 35 47 W 6 4o N 51 17 w 5 b~ w 64 10 w 4 55 ~ 79 58 W 5 0 $ 79 10 w 6 8 S 59 lP w 7 b~ S ~8 5H w O0 2909 96 2~5~ 96 3000, , , 310n,00 30~9,95 3055,95 3200.00 3109.72 3155,72 3400.00 33g~.4o 3354.40 3500.~0 ]407,77 3453.77 3600.00 3597,37 355~.32 3700,00 36qb,95 3652.g5 3800 (}O 3706 4P 3757.4~ 3OO0:OU 3895:73 385~.73 VERTICAL DO~bF.G RECTA~IGUbAR COOROINATE8 HORIZ, SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, FEET DEG/IO0 FEET FEE'f FEET o.OU 0,00 0,00 N 0,00 -0,30 0,03 0,13 g 0,30 -0.46 0,12 0,22 N 0,42 -0.47 0,24 0 28 M O,3R -0.~8 0,19 0:00 S 0,39 -0.12 O.1R 0 39 $ 0,55 0.11 0.27 0:75 S 0,58 0,65 0,08 1,44 S 0,51 l 10 0.20 2,12 S 0,54 I~52 0.1~ 2,64 S 0.47 2.11 2,50 2.57 ?.71 2,97 3,19 3.27 ~.32 3,49 3.80 0.17 0 39 0 07 0 08 013 0 10 0 02 0 15 0,26 0,55 3,29 S 0,29 ~ 3,82 S 0,26 E 4,02 S 0,35 E 4,26 S 0,39 E 4,69 S 0 46 ~ 5,23 $ 0:69 E 5,78 S 1,1i E 6,30 S 1,56 F 6,78 S 1,79 E 7,35 S ~,92 E 3.93 3,73 3.22 7,45 t.62 0,98 R,52 ,~6 0.04 '0,41 0,23 0.22 0.12 0 05 0 13 0 20 0 O? 0 09 0 10 O,ll 7,56 S 1,94 7,55 S 2,22 7,24 S 2,64 6,68 S 3,15 6,02 S 3,67 5,58 S 4.14 5,32 S 4,52 5,11 S 4,82 4,98 S 4,98 4,72 $ 5,24 '1,76 '4,14 '6,q5 '7.11 '4.66 -0.49 5,68 14.53 26,53 0,16 3,78 3,66 1,94 1,38 1,55 1,75 I 7! 2:16 2~16 4 44 S 3 36 S 2 61 N 12 45 N 20 69 N 26 78 N 29 79 N 29 65 N 26 i7 N 19~08 N 5 62 E 5 79 E 3 24 E 2 53 W lO 45 W 19 90 W 28 74 W 37 27 W 46 27 W 56:13 W 44,00_FT DEPARTURE AZIMUTH DEG ~iN 0,00 N 0 0 E 0,33 N 66 34 E 0,48 N 61 57 E 0,47 N 52 58 g 0,39 S 89 49 E 0,68 0,95 1,53 $ 19 2~ E 2,18 8 14 18 E 2,68 S 10 4 E 3,30 S 4 59 E 3,83 $ 3 57 E 4,03 $ 5 0 E 4,28 $ 5 17 E 4,71 S 5 33 E 5,28 S 7 29 E 5,89 S 10 54 E 6,49 $ 13 55 E 7.01 S I4 49 E 7,60 S 14 37 E 7,80 S 14 22 E 7,87 $ 16 21 E 7,71 S lO 59 E 7,3q $ 25 14 E 7,05 S 3i 20 E 6,95 S 36 39~-.~ 6,98 $ 40 2 ' 7.02 S 43 2u ~ 7,04 8 44 58 E 7,05 S 47 59 E 7,16 S 51 40 E 6,69 S 59 53 E 4,16 N 51 9 E 12,71 N 11 30 W 23,18 N 26 47 h 33,36 N 36 37 W 41.40 a 43 58 ~ 47,62 N 51 29 ~ 53.16 N 60 30 W 59,29 N 71 13 W ARCO blSBUPNE NORTH SI. OPE,ALASKA TRU~ SUB-SEA CD{iPS~ PACE COMPUTATION DATE: 21-JUN-R5 DATE DF SURVF¥: lO-APR-U5 KELLY BUSHING EbEV~TION: ENGINEERS HAbFACRE/bESNIE INTFRPULATED VALUES ~OR EVEN 100 Ff~T OF MEASURED D~PTH VERTYC~L DOGLEG RECTANGUbAR COORDINATES HORIg, DEPARTURE 6ECTI~N SEVERZT¥ NORTH/SOUTH EAST/WEST DIST, Ag~MUTH FEgT DEG/~O0 FEET FEET FEE~ DEG ~IN 4000,o0 ]904.59 3o50.59 9 25 4t0o oO 4o02,80 4~4~,~0 12 27 420o~00 4199.60 4145,~0 15 39 4100.00 42~4.07 4240,07 19 45 4400 oO 4377.92 4333,q2 ~3 18 4~On[O0 446~,03 4424.03 ~7 48 460n.00 4554.96 4510.96 ~! 22 4700 DO 4638,?g 4K94,75 ~4 42 4800:00 47~9.1~ 4675.~4 38 4goo. Do 4704.27 4'750,27 40 54 S 36 37 w ~ 33 59 w S 33 39 w $ 34 30 w $ 34 39 w S 34 23 W G 34 11 w S 34 2 W 41,50 59,08 8t.71 1!),66 !9~,35 240,R5 ~94,40 352,73 413,73 551.39 625,06 701,61 77g,03 856,60 5000 O0 48~9.9fl 4S25.q8 43 56 5100:o0 4939,93 4.~95,g3 47 20 5?O0.no 5005,85 4961,~5 49 59 53U0,00 5068.~0 5024.40 51 46 5400.0() 5130,12 50~6,12 52 I 3,58 3,47 3 82 3 71 3 45 3 4i 3 41 3 1~ 2 67 3,49 3,79 3,17 0,~? 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51 810o.o0 675~.6P 6714.68 51 4 ~200.nO 68?2.20 0'77~,20 50 21 830n.00 6886.50 6~42,50 49 8400,00 6951,84 bgO7,R4 48 46 8500.00 70~8.39 697~,38 47 48 8&00,00 70~6.15 704~,~5 46 56 8700,00 7~55.05 7~1~,05 45 47 8800.00 7225,3~ 8900.00 7297,55 7~53.55 ~2 59 9AOO 0(3 737~' 26 7327.~6 42 2~ 9~0~A0 744=~97 7400,97 42 45 92U0'o0 75~ 2~ 7~7~,74 42 40 9]00'o0 7591:96 7947,96 42 24 9400:~0 7~66·3~ 7627.]! ~! 59 9500'00 7740'44 7696.44 42 9600:00 7815:15 -1771,15 40 56 9900,00 7Fg0.25 7846.25 9~00.00 7965.20 7~21.20 9000.00 ~038.97 7094,97 ~OOOO.O0 ~110,~7 8n66,47 45 17 lOlOn O0 R179.17 813K.17 47 10200'00.._ . -8244. .17 8206,17 50 49 ~0300,00 g304 96 8~0,96 54 10 ~040o.00 ~302:0i 831,.01 l.o~oo.oo ~.t17.4o 837~ 40 ~o 5~ 106o0.00 8471;?~ ~427:75 57 7 10800:00 ~579.9~ 8~35,99 57 !09~0,00 ~633,33 8~89,33 57 51 ~100o O0 ~86,57 86-i~.57 5't ~1~00~00 q740,92 8696,92 56 0 !12oo.o0 g795.54 8~51,54 58 34 11300,00 884o,93 8802,93 58 41 1140n..00 ~9d,63 8954.~3 58 36 tlg00.00 o9~0.95 8~o6'95 58 47 11600 oo 9002 44 805R 44 59 tt7On:Ou ~o~a~5~ 11800,o0 0104.33 90~o.33 59 45 lI~gO,nO 9&54,~0 9110,50 59 bO g 41 54 at 2R45.51 $ 42 5 .'; 2023.76 $ 42 i9 w 3000.90 e 42 34 w 3077 37 5 42 53 ~ 3152;96 g 43 12 w 3227.58 S 43 37 w 3301,08 S 44 0 W 3373,52 S ~4 26 W 3444.65 S 44 56 W 35!3,80 S 45 20 W 3581,36 S 45 21W 3648,94 $ 45 23 W 3716.88 S 45 35 W 3784,57 $ 46 19 W 385~,44 S 40 57 W 3918,55 $ 47 34 W 3984,98 S 48 33 '{ 4050,92 S 49 36 W 4116.99 S 50 57 W 4~84,25 $ 51 33 W 425~.86 g 51 12 W 4326,13 S 50 12 W 4401,77 S 48 42 W 4480,94 $ 47 4~ W 4562.~6 S 47 26 W 4646,16 $ 47 3 ~ 47]0.04 $ 46 39 W 4813,93 S 46 I0 W 4898,18 $ 45 30 w 498~,76 $ 45 21 w 5067.41 $ 40 16 W 5151'33 S 47 0 N 5235,07 S 47 38 W 5320,79 s 47 35 W 5406,20 $ 47 30 W 549~.47 S ~7 40 W 5577,13 $ ~7 37 w 566~,99 $ 47 40 W 5749.09 S 48 13 W 5835,50 0,42 1,76 0,47 0,72 1,16 1,32 0,66 0,20 1,63 1,10 0,4.7 0,72 0,9~ 0,83 1,10 1,63 6,20 1.24 1,17 2,29 3,09 3,70 3,45 ,10 .05 0,61 0,45 0,84 0,20 0,46 0 27 2 02 ] 64 ! 57 0 64 0 72 0 43 0 64 0 64 0 ,52 ; 218'1 36 S 1~39 O0 W 2857 71 S 40 3 W 2245 60 S 1891 47 W 2936 04 S 40 6 ~ 2302 7q S 1943 2359 35 S 1995 2414 97 5 2046 2469 57 S 2097 2522 94 $ 2147 2575,21 S 2198 2626,22 $ 2247 2675,43 $.2296 2723 2770 2818 2865 2912 2958 3003, 3048, 3091, 3134, 40 W 3013 02 W 3089 33 W 3165 27 W 3239 87 w 3313 66 W 34 23 W 3525 24 5 40 9 ~ 76 $ 40 13 W 37 $ 40 16 W 96 S 40 )9 S 40 2 74 S 4O 2b ~ 73 S 40 33 W 7t $ 40 38 W 05 S 2344,17 w 3593 07 8 40 43 W 52 S 2392,27 W 3660 43 8 40 48 W 7 S 2440,60 ~9 S 248 80 47 S 253ii68 81S 25n 25 07 S 268 14 45 ~ 2733,16 59 S 2785,07 3178,34 S 2839 3223,59 S 2896 327i,68 $ 2955 3323 28 S 3015 3378 02 $ 3076 3434 16 S 3138 3491 1~ S 3200 3548 48 S 3261 3606 56 S 3322 3665 48 5 3383 W 3728 W 3795 W 3862 W 3929 W 3995 W 4060 W 4126 W 4193 15 S 4.0 53 W 64 S 40 58 W 29 S 41 3 W 13 $ 41 8 W 23 S 41 1.4 W 78 fi 41 21W 4O $ 41 28 W 13 S 41 37 W 71 W 4262,14 $ 41 46 W 60 W 4333,80 S 41 56 W 41W 4408,89 $ 42 5 k 73 W 448'1,63 $ 42 13 W 94 W 4569,3] S 42 19 W 43 W 4652,22 $ 42 2~--~. 09 W 4735,86 $ 42 3 ~ 32 W 4819,54 $ 42 3b W 37 W 4903,62 $ 42 39 W 06 W 4988,07 $ 42 42 W 3724 95 $ 3443 3t W 5072 63 $ 42 45 W 3783 47 S 3503 46 W 5156 44 S 42 47 W 3841 3809 3956 4014 4072 4130 4-188 4245 04 S 3564 29 W 5240 18 S 3627 35 W 5325 71S 3690 58 W 5410 32 S 3753 54 W 5495 13 $ 3816 83 w 5581 04 S 3B80,31 W 566b O0 S 3944,0R W 5752 88 S 4008,36 W 5839 02 $ 42 51W 53 $ 42 55 W 72 $ 43 0 W 80 S 43 4 W 26 $ 43 8 W 93 $ 43 12 W 84 S 43 16 W 05 $ 43 21 w ARCO ALASKA, L1--~ i'R U F, SUB,,SEA COURSE -M. EA611RFD VFRTICA[, VERTICAL DEVIATION AZ/~UTH DEPT'!.-~ DEPTH DEPTH DRG MTN DRG MTN COMPUTATION DATE: 21-dUN-85 PAGE 4 DAT~ 0~ ~URV~¥~ ~O-AP~-85 KELLY BUSHING EbEVATION~ ENGINEER: HAbFACRF/LESNIE I~T~RPOLATED YALUE5 f'~ EVE~ 100 FEET OF MEASURED D~PTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DI$X, AZIMUTH FEET D~G/1.00 FEET FEET FEE~ DEG MIN 44.00. FT 12000.00 q204.57 9160,57 60 26 12100,00 q252.60 9~08,60 62 129U0,0U 9298.2~ 9254,~8 63 33 12~00.00 0341.79 g797,79 64 5~ ~2400,00 o397.~ 934],15 65 25 ~2500 O0 04~8.10 9~8~ ~0 66 10 ~2600:00 0467,70 9d23:70 67 7 ~2700.~0 OL~8.Oa 94~4.04 65 14 ~2800.n0 OLM2.U8 95Og,0~ 62 29 12go0.O0 0600.83 9556,~3 59 7 13000.00 q~52.75 960R.75 58 17 1~100.00 9706.15 966~,~5 57 7 13700,00 0761.9K 9717.g5 54 59 ~330o,0o ~820.37 9776.37 53 2~ 13~00.0U o8~1,47 9~37,~7 51 10 1350~.00 q945.~ 990~.44 49 14 13600.00 10012.10 9908.10 a7 5 13700 o0 ]0Og2.~O ]0038.20 43 50 13800:00 10155.80 ~O~l~,Bcj 41 in 13900,0O 10229.70 10!85,70 ~3 20 140on. O0 }0307.47 t0203.4'1 37 17 14100.C. 0 103a7 0~. !0~43,02 3'1 i7 14~36.00 10415~t.6 !0371,6t, 37 17 $ 48 47 W 5921,q3 S 49 17 W 600q,46 S 49 33 W o098,20 S 49 44 W 6187.97 $ 54 16 W 6~74,65 S 53 4! W 5364,91 S 53 42 W 645K,~3 $ 54 6 W 6546,~9 $ 50 29 W 6634,7! S 59 59 W 5719,~0 $ 59 11 W 6~02,67 S 55 59 W S 57 29 W 6966,62 $ 56 54 W 7046.03 $ 61 !1 N 7122.96 $ 60 6 W 7~97 ~0 $ 53 29 W 7339,58 S 51 30 W 7406,76 $ 52 53 w 7473,62 S 50 47 W 7535.95 S 5~ 47 w 7596,~8 $ KO 47 W 7619,00 !,74 1.69 1.39 4418 ! 96 4476 1:53 45~0 1,34 4574 1,!2 4629 1 93 4602 3~49 4734 4,53 4780 1,18 1,57 3,9~ 2,07 2,52 4,8~ 2,99 2,48 0o00 0,00 0,00 4303 26 S 4073,10 W 5925 27 $ 43 25 W 4360 89 S 4139 29 W 6012 58 $ 43 30 W 85 W 6101 07 S 43 35 W 77 S 4206 9 S 4275 51 W 619~ gO $ 4354 57 W 6276 33 S 4428 07 W 6366 09 S 4501 78 W 6457 98 S 4575 70 W 6547 Og $ 4649 50 W 6635 07 S 47~3 69 W 6720 60 $ 43 40 W 57 S 43 55 W 50 $ 44 S 44 1 $ 44 2u W 47 $ 44 29 W 29 S 44 39 W 4873 43 S 4797 34 W 6802 94 $ 44 50 ~ 4868 82 S 486~ 64 W 6805 42 S 44 59 W 4914 32 5 49~80l W 6966 4958 25 5 5006 24 W 7046 4999 OR 5 5074 04 W 7122 5036 83 $ 5140 96 W 71~7 5074,93 S 5204 95 W 7269 5115,06 S 5263 95 W 7339 5156,45 S 5317,50 W 7407 5197,70 $ 5370,73 W 7474 67 S 45 8 W 04 S 45 1.6 W 97 $ 45 25 W 16 $ 45 35 W 56 $ 45 43 W 82 S 45 49 W 08 8 45 52 W 01 S 45 56 ~ 5236,82 5275,12 S 5288,91 $ 5419,71 W 7536,41 S 45 58 W 5466,67 W 7596,80 $ 46 1 W 5403,57 W 761~,54 $ 46 2 W COMPU~ATInN DATE: 21-JUN-85 PAGE 5 ARcn ~-bASKA~ L1-9 NOR'tN SLOPE~ALASKA DATE OF SURVEY{ 10-APR-85 KELb¥ RUSHING EGEVATION: ENGINEER: HAhFACRE/LESNIE 44,00.FI INTERPOI, ATED VALUES FOR gVBN 1000 FEET OF MEASURED DEPT %R{JF SUR-SEA MEASIIRFI} VFR~IC~L VERTTCAb DEVIATION AZIMUTH DEPT~ D~pTH OEPTH DEG MTN bEG MTN VERTICAL DOGbEG RECTANGUbAR COORDINATES HOR~Z, DEPARTURE SECTION SEVERITY NOR?H/SOUTH EAST/WEST DIST, AZIMUTH FEET DEC/lO0 FEET FEET FEE~ OEO PIN ¢),nO 0,00 -44,00 0 0 lnO0,Oo 999,q~ 955 98 0 23 2000,00 1909,97 1055~97 0 3000,00 ~909,96 2055'96, 0 17 ,59 9 25 4000 O0 ]904 59 3050 ShOO,nO 4869~94 4~25,98 43 56 60{)0,00 5504,15 5460,15 51 7000 ou ~107,51 6063,51 54 17 8000~0U 6006.58 665~,5~ 51 51 9000~00 7371,26 7327,26 42 23 1000o O0 8110.47 8066,47 45 17 llOOn'no g096.57 8642,57 57 42 1200o~no 92n4,57 91.60,57 60 26 13000 oO ob52,75 9608.75 58 17 14oO0~nu i0307.47 10263.47 37 17 14136~oo 10415.66 10371.66 37 17 N 0 0 E 0,00 $ 10 53 W 2,11 S 40 44 ~ 3,93 ~ 4U 1 E '0,88 S ]6 37 W 41,50 $ 33 51 W 481,38 $ 39 3~ W $ ~,1 ? W 2043,23 S 41 54 W 2845,51 $ 45 20 W 3581,36 $ 51 33 W 4253 86 $ 45 2] W 5067 41 S 48 42 W 5921 93 $ 59 11 W b802 67 ~ 50 47 W 7535 95 S 50 47 W 761~,00 0,00 0 17 0~23 0 16 3 58 3 49 1 21 0 35 0 42 0 47 3 09 0 27 1 74 1 18 0 O0 0 O0 0 3:29 S 0,29 E 3 7g 56 S I 94 E 7 4 44 $ 5 62 ~ 7 8 l]N 66 36 W 66 362 65 S 318 4~ W 482 984 65 S 775 67 W 1253 1585 94 S 1304 40 W 2187 36 S 1839 O0 W 2857 27~3 05 S 2344 17 W 3593 0 00 N 0 0 E 30 $ 4 59 E 80 S 14 22 g 6 $ 51 40 E ~6 N 83 0 W 60 $ 41 1-""~W- 48 $ 38 1 23 S 34 25 W 71 S 40 3 W 07 $ 40 43 W ]178 3724 4303 4823 5288 34 S 2839 71 W 4262,14 $ 41 46 W 95 S 3443 31W 5072,63 $ 42 45 W 26 $ 4073 18 W 5925,27 $ 43 25 N 43 $ 4797 34 W 6802,94 S 44 50 W ~2 S 5419 71W 7536,41 S 45 58 W 91S 5483 57 W 7618,54 $ 46 2 W ARCn ~GAS~A~ TNC. bi -g hT6~UPh~ NORTH ST.URE~ALA~A DEPTH DEPTH cn~PUTATION DATE: 21-JUN-B5 PAGE 6 DATE OF SURVEY: lO-APR-U5 KELLY BUSHING KbEVATION: ENGINEER: HAbFACRE/LESNIE iNTERPO[.ATED VAI..U~6 ~'OR EVEN ~00 FEFT OF SUR-$E~ DEPTH VE~;~ICA5 DO,bEG RECTANGIJL~R COORDINATES HORIZ, DEPARTURE 6~CTION SEVERITY hORTH/SOUTH EAST/WEST DIST, AZIMUTff DEG ~?N F~ET DEL/lO0 FEET FE~T FEET DEL ~IN 0.00 0.00 -44.00 0 0 N 0 0 E 0,00 44 O! 44,00 0 O0 0 144~n9 144,00 !00:00 0 ~44 ¢)1 ~44.~)0 ~00,00 0 4 ~.] 27 37 W -0.49 .344:Ol 344.0~ ~00,00 0 g $ 0 35 g -0,39 444.01 404,00 400,00 0 15 544,01 544,00 500.00 0 10 $ 8 55 ~ -0.06 64~.01 64q,00 50~,00 0 23 S 8 11 W 0,33 74~,01 704.00 700,00 0 ~3 S 2 54 ~ 0,88 844,01 ~44.00 800.00 0 18 S 5 17 w 1,97 q~,Ot 944.00 qO0.O0 104~.02 1U~4.00 loO0,O0 1344o02 ]144,00 1100.00 1240,o2 ]244.00 1700;00 1344.02 !344 144~.02 ~44q!o0 1400,00 1644:02 1644,U0 1600]00 1744,03 !7~4.00 1700,00 1~44,o3 1~04.~n 1800.00 10q4.03 1944.~0 lnon,o0 2044,0] ~044.00 2000.00 2144.n 7144,00 2~00,00 2244.03 ?244.00 2900.00 2344.03 ?344 O0 2300,00 244~ ~4 7444[00 2400.00 254~04 9544 O0 2qon,O0 2644.04 ?044~ 0n 2600.00 2740,04 ?744.00 270~,00 284~,04 ~44.00 28U0'00 0 2~ 0 7 0 7 0 14 0 20 0 23 0 23 0 16 0 21 0 6 o 0 !7 0 24 0 2.2. o 15 0 16 0 25 3 35 6 45 b 31 5 21 O 53 2944~04 ?944 On 2qOn nO 3o~.o~ ~044:uo 3fion:6o 3144 10 3144.00 3t00.00 3244.:K5 3244,00. 3~0~,00 74 3344.60 3300.00 334~"nl 3444 OO 3400,0Q ]445, . . . · On 350~ nO ~546 47 ~544, . 3646.R5 ~644.00 3600.00 3747.75 ~744.00 3700.00 3847,83 3844,00 3~0n,Ob S 2 56 w .~ 54 3~ E ~-' 42 2 F~ ~.; 37 12 E u 52 ~. r ~'; 54 7 t.77 ?.33 ?.53 2,62 ~ 82 3~09 3,74 3,29 3,36 3.62 3,89 3,90 3.54 2,92 1,31 0.79 0,31 0,O7 -O,18 -0,61 -t.13 -2,64 -7,41 -6,26 -¢,91 2,10 g 49 19~84 0.00 1,33 0,.13 0,13 0,1~ 0.18 O,IB 0,10 0,07 0,04 ,17 ,27 0,12 0,16 0,10 0,13 0,12 0,02 0,30 0,00 0.08 0 24 014 02! 0 27 0 1! 0 10 0 3! 0 07 0,17 0,74- 4 25 1 94 1 97 1 52 0,00 ~ 0.09 N O, 16 N O, 28 N O, 19 N 0 In S 0 53 S 1025 1 77 S 2 34 S 2.90 3,57 3,92 4,10 4,43 4,93 5,47 6,02 6,51 7,04 7 47 S 7 59 S 7 45 S 7035 6 37 S 5 79 S 5 ~7 S 5,19 S 5,06 S ~, 88 S ~.60 S 4,2.3 S 1,4] $ b 86 N 16 44 N 23 84 '~ 28 57 N 30 10 N 28 49 N 23 20 N 0,00 0,2! 0 37 0 41 0 36 0 46 0 60 0 54 0 51 0,53 0,39 0,25 0,31 0,37 0,41 0,53 0,85 1,32 1,70 1,86 1,92 2,02 2,39 2,85 3,39 3,88 4,30 4,69 4,89 5,07 5,40 5,76 5,12 0,95 5,82 14.74 24.14 32,69 41,49 50,81 5 6 17 37 44 50 55 44,00. FT 40 N 65 59 E 50 N 55 13 E 41 N bt 45 E 49 S 68 80 $ 48 3 15 $ 28 '/ E 84 S 16 6 E 40 S 12 43 E .93 $ 7 33 E ,58 $ 3 58 E 3,93 $ 4 33 E 4,12 S 5 12 E 4,44 S 5 17 E 4.96 $ 6 9 E 5,54 5 8 47 E 0,17 S 12 23 E ,73 S 14 40 E. ,28 $ 14 46 E 7 10 $ 49 34 E 7 15 S 53 43 E 32 S 74 24 E 93 N 7 53 E 44 N 19 29 W 03 N 31 44 W 40 N 40 11 W 43 n 47 21 W 33 n 55 31 w U6 N 65 27 w 0,00 N 0 0 E 0 23 N 65 55 E ARCO AI_,~bKA~ INC-, NOk~H SLOPlf ~ ALASKa, DATE OF SURVEY: tO-APR-85 KELLY BUSHING EbEVAT[ON: ENGTNEER= HAbFACRE/LESNIE INTERPOLATED VA[,UE$ FOR EVEN 100 FEET UF SUB-SEA DEPTH TRUE SUB-SEA COUESM ~gASI!RbTD VERTICAL VERTICAL .DEVIATION AZIMUTH DEPTW OFpTH DEPTH DEG MTN DEG SIN 44,00 FT 394~.78 3944,00 3900,00 8 39 4050.18 4044.00 4000,00 10 36 4152,63 4144.00 4!00.00~ 14 9 4~56.~7 ~24~ QO 4~00,00 18 6 4~b3.75 4349~U0 4]00,00 ~2 7 4477,Ol 4444.0n 44u0,00 ~6 48 45%{7,19 ~b44.00 4500,00 ]0 55 4706.38 4644°00 4600,00 34 55 483~,~5 ~7~4.0o 4700.00 ~9 9 4964,?9 ~44,00 4800,00 42 47 VE~TTCAL DOGLEG R~CTANGULAR CnURDINATE$ HORIZ, DEPARTURE SECTION SE~£RIT¥ N~RTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 5106 O0 4944,Q0 4900,00 a7 34 5~b0:5~ 50~4.U0 5000,00 5~ 35 5427.K4 5144.00 5100.00 52 9 S 43 26 W 3~.54 $ 35 8 W 50,17 S 32 bg W 71,89 $ 34 7 W 135.93 S 3~ 40 W 180,06 $ 34 17 W 234.34 S ]4 23 w ~97,q5 $ 34 O W 372,30 S 33 55 w 457,3~ S 33 4~ W 555 71 S 34 17 W 67l:15 $ 35 24 W 796,52 S 36 57 W g21,16 s w o45 17 $ 39 3 W $ 40 ~ W ,294.09 622",~I 504~,00 5600.00 52 47 S al ~ W 1423.65 639~o69 ~'14~ 00 57()~,n0 g2 4] S 41 32 W 155~,05 6559,0q ~84~[0~ 5fl00,00 52 4~ S 41 44 ~ 1686'53 5583,61 5244.00 5~00,00 51 25 5743 96 5344 On 530n,00 51 28 5~03~6~ 5444:00 5~00.¢)0 50 58 6064.32 5544.00 5500,00 gl 4~ 673o.9~ 5944.00 bqO0,O0 53 21 5 41 3-~ w 1830.85 6R94.64 6044 Oo 6000,00 54 ~ S 4[ 15 W lo55,35 6144: 60 2094. O0 706K.o0 6100.00 54 20 7237 43 624g O0 5~OO.O0 56 26 7408:71 6344:bO h~OO.no 54 24 7~7P,oj 6q44.00 b400,OO 54 4~ 7748,'~6 654~.00 bKO0.O0 53 26 7q14.~9 6644,00 6600,00 52 23 8076,53 674~.0~ 6700,00 51 24 8734.12 6844,00 bRO0.O0 50 4 $ ~t 11 W S 41 2l '~ 2233,03 $ 41 40 w 2~71,77 $ ~1 47 W 250g.~2 S 4[ 56 W 2645,54 S 41 53 W 2778.2~ S 42 ~ W 2g08,10 S 42 !7 W ]027,~! 8380.n9 ~944.00 6900,00 48 53 8537.40 7044.00 7000,00 47 24 8664.16 7144.00 7100.00 45 57 8a26,09 7244,00 7~'00,00 44 5 8gb~,!3 7344.00 7~00,00 42 19 909g,68 7444,00 7400,00 42 44 9~34,~1 7544.00 7500,00 a2 3~ 937n.o5 7644,00 7600.~0 al 49 9504.Pl 7'744.00 7700,00 A2 0 9638,31 7~4~,Q0 7RO0.O0 41 15 $ 42 50 W 3~.44.00 g 43 28 W 3255,63 $ 43 58 W 3~b2.17 $ 44 2~ W 346~,86 S 45 2! W 3648:04 S 45 17 W 3740,54 S ~5 4~ W 393],45 S 46 57 W 3921,78 ~ 47 53 W 4~9,!5 2,46 3,21 2,98 4 O5 2:90 4,11 55 3,01 3 7~ ! 7~ ! 11 0 76 0 88 ! 40 0°64 0,44 0,24 0 52 0 46 0 47 0 72 ! 27 0,97 0,26 0,84 !,28 1,16 1,20 0 62 0 75 0 l? 0 86 14,23 H o.9g g 71 50 W 71 17,41S 83 86 W 85 41,25 S 99 70 W 107 71,82 S 120 12 W 139 108,77 S 145 65 W 181 154,33 S 176 95 W 234 207.82 S 213,52 W 2~7 270,45 S 256,15 W 3 72 342,3! $ 304,75 W 458 61 21 W 62 84 N 76 54 W 51 N 89 12 W 64 $.78 16 W 90 $ 67 31 ~ 95 $ 59 7 ~ 79 $ 48 5 96 S 45 4b 50 S 43 26 32 S 41 40 425 04 S 360 66 W 557,90 $ 40 16 523 33 S 426 43 W 675.07 S 39 10 ,. 627 75 S 499 50 W 802 23 5 38 30 w 729 829 926 1023 1121 1220 1318 73 S 573 97 w 928,4! $ 38 11W 21S 650 Ol W 1053,61 S 38 5 W 39 S 7~8 06 W ~,78.25 S 38 9 W 35 S 808,12 W 1303,95 $ 3~ 17 W 70 S 893,08 W 1433.80 5.38 31W 55 S 980,12 W 1565,37 S 38 45 W 96 S 1067,73 W 1696,97 $ 3fl 59 W 1420 99 S 1163 8R W 1841,44 S 39 12 W 1520 56 S ~246 45 W 1966,15 S $9 20 W ]625 31 $ 1337 86 W 2105.11 $ 39 27 W ~7~9 99 S 1429 89 W ~244 42 S 39 34 W ]833 99 S 1522 16 W 9383 38 S 39 41W 1936 71 S ~613 89 W 2521 01 S 39 4~-~ 2038 26 $ ~705 20 W 2657 48 $ 39 5 , 9137 14 S 1794,01W 2790 3! $ 40 b W 9231 98 $ ~882,91 W 9920 12 S 40 9 W ~392 ~9 S 1961,07 W 3039 47 S 40 10 W 2408,41S 2040 22 W 3156,41 S 40 16 W 2489,97 S 2116 54 W 3267,99 S 40 21W 2567,04 S ~lgo 1~ W 3374,40 S 40 28 W 2639,21S 2260 42 W 3474,90 S 40 34 W 2705 61S ~326 50 W 3568,32 S 40 41W 2769 89 S 2391 63 W 3659,53 S 40 48 W ~834 91S 2457 42 W 375%,75 $ 40 55 W 2898 53 S 2522 ]6 W 3842,37 $ 41 I W 2961 O1S 2587,b0 W 3932,34 S 41 8 W 3020 90 S 2652,67 w 4020,26 S 41 17 W A_P. CO aLAGKA~ TI',iC, GTSnUPN~ NC)NTH ~T.~[]['E:vAlr,ASKA DEPT!~ DEPTH DEPTH DEG ~IN DES MIN COHPUTA'rInN DATE; 21-JUN-B5 PAGE DATE OF SURV£Yt )O-APR-85 KEbbY ~USHIN~ ENGTNEER~ HAbFACRE/LESNIE INTERPOLATED VAGUF~ f'OR ~VEN 100 FEET OF SUB-SEA DEPTH VERTiCAl, DOGbEG RECTANGUb~R COORDINATEM HORIg. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST. ~Z~MUTH ' f'EET DE~/!O0 FEET FEET FEET DEG 977~.~3 7944.00 7000.00 41 34 S 49 20 W 4098.19 9~06.n5 R044 O0 8000,00 43 39 $ 51 ~ w 4180.02 ~004~.78 R144:00 ~00,00 46 3~ S 51 3~ w 4~88,43 ~0199 74 ~244 O0 8200,00 50 4° S 50 12 W 4401.56 ~036~107 ~344:00 8~00,00 55 2~ $ 48 1 w 4536.62 1054~P4 ~4d4.0o 8400.00 57 4 S 47 15 W 4687,~0 10733.04 R54~ O0 8500,00 57 18 ~ 46 31 W 4841,72 10920 07 ~644~()0 8600 O0 57 5~ S 45 25 W 4999.76 ' 8700:00 55 53 S 46 1~ W 515~,84 tllO5.m6 P744.00 t1~94,39 8844,00 8ROO,O0 58 43 ~1486 56 P94~.00 8qO0,O0 58 41 11681~]7 o04~.00 9000,00 ~9 ]5 11879.08 9144.00 9tO0.O0 59 52 12081.7i 9244.00 9700,00 61 ~6 ~2305.~8 0344.00 9300 O0 64 50 12540,~5 q44g OO 9400:00 66 33 t2781.65 n54~OO 9500.00 63 ~ ~2983.15 ~044,00 9~00.00 58 26 13~67.~3 Q744.00 9700 00 55 4~ 13~38.67 ~844.00 9~UO:O0 52 36 13497.75 n944.00 9900.00 49 17 13645.5! ino44,uo lO000.O0 45 4l 13783 97 10144,00 10]00,00 41 37 13glO'P2 10244.00 lOPO0,O0 41 q 14o45.q2 1034,!,00 10300.00 37 17 $ ~7 3~ W 5316,01 S 47 31 W 5479,98 $ 47 35 W 5646.8I S 48 6 W 5817.43 S 49 6 W 5993.]7 S 49 42 ~ 619~.64 S ~3 4~ W 0401.4~ S 56 3 W 6618,49 $ 59 lO W 678~,71 ~ 57 0 W 5940,46 S 58 33 W 7075,79 $ 60 7 W 7195 43 S 51 50 W 7395.99 $ 52 5 W 7485,73 $ 50 47 W 756~.65 $ 50 47 W 7618,00 0,81 2.23 2,06 3,44 0:40 0,45 0,36 1,]4 1,8i 10~ 0i73 0 44 1,41 ~,25 3,20 1,74 2.6~ 2,50 2,11 3,59 3,29 6.32 0,00 0,00 3079,19 S 2718 3137,5l S ~788 3199.95 S ~866 3271,55 S 2955 3360,34 S 3057 3461 90 S 3168 3567 58 S 3281 3677 41S 3395 3786 58 S 3506 '3895 ~6 $ 3623 44.00 FT 4006,55 S 3745 06 W 5484 33 8 43 4 W 4119,12 S t868 35 W 5650 78 8 43 12 W 4233 82 S 3994 4350 36 S 4127 4480 O1 $ 4279 4596 32 S 4457 4724 71 $ 4635 48~6 12 S 4784 4899 68 S 4915 4974 04 S 5032 88 W 58~1 07 W 5996 10 W 6145 67 W 6402 96 W 66119 93 W 6789 69 W 6940 46 W 7075 02 S 43 ~0 W 26 S 43 41 W 88 $ 44 7 W 29 $ 44 27 W O0 S 44 48 W 53 $ 45 5 W 79 S 45 20 W 5035 98 $ 5139 45 W 7195,49 S 45 34 W 5093 19 S 5231 80 W 7301.53 & 45 46 W 5149 81 $ 5308 9~ W 7396,29 $ 45 52 W 5205 22 S 5380 33 W 74R6,13 $ 45 56 W 5254 4) S 5441 27 W 7564,14 $ 46 0 W 5288 91 $ 5483 57 W 7618.54 S 46 ~-W 83 W 4107,73 $ 41 26 W 80 W 4197,86 $ 41 37 W 95 W 4296,40 S 41 51 W 25 W 4408,69 S 42 5 W 37 W 4543,06 S 42 17 W 57 W 4693,04 S 42 ?~-~W 5~ W 4847,27 $ 4? W 17 W 5005,05 $ 42 ~z W 7~ w 5160,94 $ 42 48 W 82 W 53~0,76 $ 42 55 W ARCR AbASKA~ ThC, bTSBU~N~ NORth 8LUDE,AI-,A~KA ~A~KER TO'I',~ b DF:PTH DATE: 21-dUN-05 PAGE DATE O~ SURV~¥~ lO-APR-85 KELLY BUSHING ELEVATZON~ ENGINEER: HAbFACRE/b~SNIE . 44,00 FT INTENPOLATED VAI,U~5 FOR N~ASUREh D~PTH 140~9,00 14Z36,00 CHOSEN ORIGIN= 2422' TVD FROM K[½ SUB-SEA FSS, 2468' BR37,00 8793,00 10367,36 1031B,36 !0415,66 10371,66 SURFACE LOCATION AT FWl, SEC 1~ TI1N R14E, RKCT~NGUbAR COORD{NATES NORTH/SOUTH EAST/WEST 5288, 5483,57 W tim A_~CF1 ALA~jKA, TNC, NORTH 51,UPE, A)',ASKA PP TD TOTAL DEPTH COMPUTATION DATE: ************ 5TRATTGRAPHIC 112E1,00 14069,00 14136,00 2! -JUI')-R5 SUMMARY PAGE 10 DATE OF SURVEY: IO-APR-~5 KELLY RUSHING ELEVATION: ENGINEER; HAbFACRE/LEMN~E ORIGIN= 2422' TVD FB SUB-SEA 44,00 FT 8793,00 10318,36 10571,b6 8837.00 1036~,3o 10415.60 2~68' SURFACE LOCATION AT FWI, SEC 1~, TllN. R14E~ RECT~NGIIbAR COORDINATES NORTH/SOUTN ~AST/WEST tim 3888,28 $ 3615,37 W 5261,~5 $ 545~,11 W 5288,91 $ 548],57 W F'I~A[, WE~,L bf]ChTI{3M ~T TO: T~UM SUB-SEA VERTICAL VEWTICAL DEPTti DEPTH 1413b,0~ 10415,6b 10371,b6 HDRTZONTAL QMPAR?URE DISTANCE AZIMUT}! FEET DEG 7618,54 846 2 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL L ISBURNE L1-9 F I ELD L I SBURNE UN I T COUNTRY USA RUN TWO DATE LOOOEO lO-APR-85 REFERENCE 000070S ] 2 NE WELL NAME: L 1- 9 SURFACE LOCATION~"' ~.422' FSL, 2468' FWL, S1, TllN{ 4E, UM VERTICAL PROJECTION -4000 -ZOO0 0 0 2000 4000 6000 8000 lO000 12000 PROJECTION ON VERTICAL PLANE SW - NE SCALED IN VERTICAL BEPTH$ HORIZ SCRLE = ]/2000 IN/FT WELL NAME: LISBURNE L1-9 SURFACE LOCATION~~" R422' FSL, 2468' FWL, S1, TllN.~' '4E, UM HORIZONTAL PROJECTION NOI~TH ~000 REF O000?OSI~ 1ooo -1ooo -2000 -9000 -4000 -S000 SOUTH -6000 -$000 NEST SCALE = 1/1000 IN/FT -7._~.~_L~ ~ ,;~ ~I ~ t ~ y~..m :-T~ i ~ i i I i i .:'-~-~ ~ i ~ i ~ ~W-; .",',',",""",,-',-,"',",'",'",-','-,'",-,"',-,'",',","','",'-"",'",'",'",'",'",'",,, ~'~-?~++'~ .... ~ ........... ~ ~'~"' ~.?-H..++++.~..~.~..?+...?..+..+.....+`.+...+..?..?..~..~...~...?..~..+..+..~...~..*...+ ...... ~-. 3..L~.i... 4...~...~.i..,.-L.LL.L[.L~.x..L,..x...~~..LL ...~_U...~.......L. 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SURFACE DIRECTIONAL SURVEY ~]UIDANCE r~ONTINUOUS r'~OOL Company RECEIVED A/aska Oil & Sas Cons'. Commis Anchora&)e ATLANTIC RICHFIELD CO~A~ _ Well Name LISBURNE, L1-9 (242.2' FSL~..2468' FWL~ Sl~ TllN, R14E, UM) Field/Location LI, SBUR,NE UNIT, NORT.H SLOPE, ALA$~ .,lob Reference NO; 3'0512 }LALFACRE/LESNIE Date 10-JUNE-85 Computed By: STEVENS b~_rlR NORTH SURVEY DATE) lO-APR-85 ENGINEER) HA[,FACRE/bE~NI£ ARCF~ AbAbKA, INC, bIS~URhE NOH?H 6I, uPE,AIoASKA COhPUTATION L)ATR: 10-.JUN..85 DATE OF SURVK¥{ KELbY BUSHING EbEVATION{ 44,00 ENGINEER; HAbFACRE/DESN]~ INTERPOLATED VALUE5 FOR EVEN 100 FEET UF MEASURED DEPTH 7:RU~ SUB-$~A C[!URb~ MEASilt{FD VEATICAI, ¥~RTTCAb DEVIATLON AZLMUTH DEPTH D~PTH DEPTH PEG NIN i)EG MfN 0,00 0.0O 100.00 09.90 ~00.00 300.00 209,g~ 400,00 5q9,99 500,00 499,~q 600,00 599,90 700 OO 009 90 900~0o 0 0 N u 0 6 0 4 0 4- 0 11 $ 23 26 F 017 $ 8 7 W 0 26 S i 4] W 016 0 1q $ 15 36 W -44,00 55 99 155 99 ?55 09 355 99 455 99 555 99 655 99 755 09 R55 09 0 23 S 10 53 w O 10 S 1.5 0 E 0 6 S 17 45 E 0 11 $ 5 5g E 0 18 ~ 13 I F o 20 $ 32 10 ~ u 24 S 4.1 16 E O 20 S 37 53 E O IR S lO 6 E 0 14 S o 27 E 1000 O0 909.98 055.98 1100~'oo lu99'9H J055, 1200.00 1109 98 1155,q8 1300,00 12q9 98 1~55,06 1400.00 1599 98 1355,05 1500 O0 i499 98 14hq,g8 1600 O0 !5g9 9R 1555,98 1700 0U lbg9 97 1655.97 1800 O0 1709 97 1755,97 lEO000 1099 ~7 1855,o7 o % S 40 44 E 0 14 N 67 56 r u 21 ~' 47 g E 0 30 N 39 2 E 0 26 N 40 41 E 0 16 N 55 12 E o 16 N 54 34 E 0 6 tJ 61 26 E 0 R N 40 27 g 0 14 ~ 51 9 F 2000,00 1999,97 lObS,q7 2100,00 2009.97 2055,07 2200,00 2199 97 2155,07 2300,oo 2299:97 2255,0'1 2400.00 23q9,96 2355,g6 2500,00 7499,96 24b~.g6 2600 O0 7599,96 2555.96 2700:00 ~bg9 96 2655.06 2800,00 2799!96 2755.qb 2900,00 2~g9 96 2R55,96 3000,00 2909 96 2055,06 3100.00 3099:95 3055,~5 ~00 OU 31q9,72 3155,72 00:00 32o9.06 3255.06 3400,O0 3308.40 3354,40 3500.00 3407,77 3453,77 5600.00 3597,J? 5553,]2 3700,00 3096.95 565? 05 5800,00 3796,~8 3752~48 5900,00 3895.73 J851.75 0 17 N 4~ 1 E 1 41 ~ 11 9 W b 57 N 35 47 W b 40 N 51 17 W 5 59 g 64 10 W ~ 55 N 79 58 W 5 0 S 79 lo W b 8 S 59 lB W 7 54 S 48 58 W VER'I'ICAD DOGbEU RECTANGObAR COURDINAtE~ HOgig, DEPARTURE 8ECTION SEVERITy NORTH/SOUTH EA~T/WE$~ DI$~, AZIMUIH FEET PEG/100 FEET FEE~ FEET DEG NIN 0.00 0.00 '0.30 0.03 :O,4b 0,12 0.47 0,24 -0,28 0,19 'O,12 O.1R 0,11 0,27 0,65 0,Off 1.10 0,20 1,52 0,12 0,00 FI 0 13 N 0 22 N 0 28 N 0 O0 S 0 39 S O, 75 1,44 $ 2,12 $ 2,04 S 2,11 2,50 9,57 2,71 2,97 3 ~9 3 27 3 32 3 49 3 O0 0.17 0.59 0,07 0 O8 0 13 0 02 0 15 0 26 0,55 3,29 3,d2 4,02 4,26 4,69 5,2] 5,78 · 50 6,78 0,29 0,26 0 35 E 0 59 E 0 46 E 0 69 E I 11 E 1 56 E 1 79 E t 92 E 3,93 3.73 3,72 2.45 1.62 0,98 0,52 O.lb 0.04 '0,41 0,23 0,22 0,12 0,05 0 1~ 0,28 0,07 0,09 0,10 0,11 7,56 7,b5 7,24 b 68 6 02 5 58 5 32 5 11 4 98 4 72 I 94 E 222E 2 64 E 3 15 F, 3 67 E 4 14 E 4 52 E 4 82 E 4 98 E 5 24 E 87 S 16 E 39 05 95 $ 98 S 40 02 $ 4') 04 $ 44~ '0,88 '1,76 '4,14 '6,95 -7,11 -4 66 --0' ,49 5,68 14,53 26,53 0,16 3,78 3,66 ~,94 1,38 1,55 1'75 1,Ti 2,~6 2,~6 4 44 S 5565 2 6t N 12 45 N 20 69 N ;.6 78 N 29 79 N 29 65 N 2b 17 N 19 08 N 5,62 E 5 79 E 3 24 E 2 53 W l0 45 W 19 90 W 28 74 W 37 27 W 4O 27 W 56 13 W 7,16 $ 51 40 E 12 23 33 41 47 53 59 78 N W t6 N 36 37 w 4O N 43 58 W 16 e 30 W 29 N ?t 13 W ARCO Ab~KA~ TNC, h! ,-9 NOETIi ~SI,OP-,E ~ AI,ASi~A CNMPbTA'rlnN OATE; IO-JUN-~5 PATE OF SURVEY1 lO-APR-85 KELLY BUSHING EGEVATZON; ENGTN£gR; INTERPOLATED VA[,UE5 KNN EVgN 100 FEET UF MEASUNED DEPTH TRUF; SIlR-$EA COUR~ DEPTH DEPTii DEPTH DEG MIN PEG MIN 44,00 4000.00 399q.5~ ~950 59 4100.00 4092.U0 40~8 4200 NO 41Hg.~N 4145 430~0U 4284.0? 4240 4400.00 4377.~2 43~3 4500,00 446~,03 4424 4600.00 4554.96 4510 4700.00 4a3~,75 4594 4800 00 4719,14 4675 4900:00 4794.27 4750 · 9 25 $ ~6 37 W 80 ~2 27 $ 33 52 W 80 15 34 S 33 37 W 92 23 18 $ 34 30 W 03 27 48 S 34 39 W 96 31 22 S 34 18 W 75 34 47 S 34 2) W 14 38 9 S 34 11 W 27 40 54 :; 34 2 W VERTICAL DOGLEG RECTANGUbA~ COORDINATE& HOM1Z, DEPARXURE ~ECTION SEVERfT¥ NORTH/SOUTH EA&T/WEST D~$T, AZIMUTH FEET DEG/!O0 FEET FEEX FEET DEG M~N 41.50 59.g8 83.71 113.65 192 ]5 240 95 294 40 352 73 413 73 3,58 3,47 3,82 ~,71 3,76 3,45 3,41 3,41 3,18 2,67 3 49 3 79 3 17 0 82 0 80 1 08 0,80 0,92 0,66 1,37 B 13 N 7 2'1 52 26 S 77,~4 W 48 S 90,52 W 94 93 S 107,47 W 119 ~ i 128,11 15 279 87 ~ , 414 421 97 S 358 21 W 553 51 a 40 19 . 484 40 $ 400 10 W 62827 $ 39 33 W 5000.00 4~&9.98 4825.qG 43 56 5100,00 49~9 93 4895,g3 47 20 5200 Ou 5005[85 4gO1.~5 49 59 54 0O 0O 51~0,1~ 5086,12 52 1 5500 OO 51gleb~ 5147.82 51 3] 5600 O0 525~.1g 5210,~9 5~ 24 S 33 50 W 551,39 S 33 56 W 625,05 S 34 40 W 701,61 $ 35 17 W 779.03 S 35 5 W 856 60 S 30 55 W 933 85 5700.00 5516,55 5800,00 537~.95 53~4.95 51 24 5900,00 5441.08 5397,6~ 50 57 bO00,OU 5504.15 5460,15 51 3~ 6100.00 5566,UR 5527.08 51 59 ~00. O0 5525.~6 558~ ~6 52 47 6300 NO 5687,30 5643:30 52 4R b40d O0 5747,U~ 5703.R2 52 43 5500 O0 58n8,28 5754.78 52 52 6600 NO 586u.70 bR24.7(; 52 56 5700.O0 5923,85 5RT'.R5 53 11 bSO0.0O 59R8,33 5944.13 53 42 5900.00 6047.14 6003,14 54 q 7000,00 6107,91 o0~3,51 54 17 7100,00 &163,Sg 5119,f19 54 20 7200,00 6222.16 617R,16 54 15 7300.00 62RO.3R 0236.38 54 7 7400.00 6338,96 6994.96 54 25 7500.00 6397.48 5353,48 53 5! 7600.00 645b,)4 6412.'14 54 7700,00 &515,37 647~,37 53 7800,00 6574,88 6530.R~ 53 17 7900,00 6~35.~7 S 37 41 W lOll S 38 39 W 1088 S 39 3 W lib6 17 S 39 38 W 1243,81 S 40 41W 1322,02 S 40 55 W 1401.18 S 41 22 W ~480.64 S 41 3t W 15bO,Ob S 4i 39 w 1639.5 5 S 41 46 W 171g,07 S 41 34 W 1798,87 S 41 24 w 1879,00 S 41 14 W 1959,68 41 2 W 2043,23 ,. 41 18 W 2121,62 S 4i lq W 2202,69 $ 41 30 w 2283,80 $ al 40 W 2364'68 $ 41 30 W 2445.61 S 41 52 W 2526,29 S 41 57 W 2606,88 S 42 t) W 2687.10 S 41 54 W 2756,73 1,21 1~46 0 57 0,38 0,52 0,51 O,bl 0,33 0,72 0,44 0,35 0,44 0,55 1,32 0 62 2 0 0 36 802,17 S 28 93 01 _~ , 77 ,J4 09 924,19 S 726,27 w 1175 41 S 8 9 w 984,55 S 775 67 W 1253 48 $ ~8 !3 g 1044,65 S 82b 33 W 1331 96 $38 20 W 1104, 29 W 1411 _29 8 38 ~ W ,63 S 930 78 W 1490U7 ~ 38'~; W 69 $ 878 1164 122~ ~2 S 983 1283 81S 1030 1343 27 S lOR9 140302 S 1142 1463 13 $ 1195 1523 83 S 1249 45 W 1570 42 W 1649 46 W 1729 61W 1809 85 W 1889 31 W 1970 39 S 38 46 W 95 $ 38 54 W 43 S 39 ~ 66 $ 39 15 g 49 $ 39 20 W 1580 94 S 1304 40 W 2054 23 $ 39 25 W 1640 12 S 1350 14 W 2132 80 $ 39 28 W 1707 2009 2069 2128 15 $ 1409 63 45 S 1679 19 S 1733 58 S 1786 80 W 2214 56 ~ 2295 44 2376 43 ~ 2457 31 2538 32 W 2618 06 W 2699 33 W 277U 02 $ 39 33 ~ 41 78 S O8 S 39 56 ~ 82 $ 4O 0 W ARCO ALASKA. TidC, b1-9 ~.ISRUR~E NORTH SLUPE.AI,ASKA 'A'RbF SU~-$~A COURSe: M~ASUREb V~RTICAL VKRTICAD DEVIATION AZZMUTh DEPTH DPP?H DEPTH PEG MIN DFG MIN PAG{~ CO~4PUTATION DATE: IO-JUN-Bb DATE OF $URVE¥~ 10-AP~-85 K~bY BUSHING EbEVA~ZONI ~N~]NEER~ HAbFACRE/~$NXE IN'YFRPOLAT~D VAT,UP;6 FOR EVeN 100 FEET UF MEA6URED DEPTH VERTTCAG DOGLEG RECTANGULAR CO~RDiNA~E~ MORI~, DEPARTUR~ ~ECTIDN SEVERITY NORTh/SOUTH EAST/WES~ DXST, ~ZXMUTH FEET DEG/IO0 FEET FEET FEE~ D~G MIN 8000,08 6bgb.bH 065~.58 51 51 8100.00 6758.bB 6714 68 51 4 8200,n0 6822,20 b778 20 50 21. 8300,00 6881,,50 0842 50 49 30 8400,08 695~o84 ug07 84 48 46 8500,00 7UI~,JR b074 38 47 48 8600,ou 7u~,15 'yO~ 15 46 56 8?00,00 7156,05 7111 05 45 47 8~O0,nU 72~5.31 7161 31 44 28 8800,00 72q7,55 7253,55 42 59 S 41 54 W 2845,51 S 42 5 W 2923.76 S 42 lq w 3000,gO $ 42 34 ~ 3077,]7 S 42 53 W 3152,90 $ 43 12 W 3227,58 S a3 37 w 3]01,08 S 44 o w 3373,52 S 44 26 w 3444,65- S 44 56 W 3513,80 9000 nu 7j71,26 7327 26 42 23 S 45 20 W 35~1 36 ' 7444.97 7400 q7 42 45 S 46 21 w 3648 96 9100.00 9200,00 751~,24 7474 24 42 40 9]00,00 75gl,96 7547 90 42 24 9400.00 7~60,~1 7622 ]1 41 5~ 9500,00 7740~44 7696,44 42 1 9600,00 7~15,A5 7771,15 40 56 9700,o0 7890.25 1846,25 41 23 9800.00 79~5,20 7q21,20 41 4~ 9900,0Q R038.97 7994,q7 43 31 $ 45 2] w 3716 88 S 45 35 w 37-84 57 S 46 19 w 3851 44 $ 48 57 w 3918 55 S 47 34 W 3984 98 S 48 33 W 4050 q2 $ 49 36 W 4{]6,99 K 50 57 W 4184,25 $ 51 33 w 4753.86 S 51 12 W 4326 13 S 50 1~ w 4401 77 S 48 42 w 4480 94 S 47 48 w 45~ 96 $ 47 26 w 4646 1~ S 47 3 w 4730 04 S 40 39 W %813 93 S 4~ 10 W 489fl,18 S 45 30 W 498~,76 S 45 2t W 9067.41 S 46 16 W 5i51 33 S 47 0 W 5235 07 S 47 38 W 5]20 79 S 47 35 W 5406 20 S 47 30 w 5491 47 S 47 40 W 5577 13 S 47 37 W 5662 99 S 47 49 W 5749 09 $ 48 13 .W 5835,50 0,42 1,76 0 47 0,72 1,16 1,32 0,66 ,29 1,10 0,47 0,83 10 1'63 1,24 1,17 2,29 3,0q 3,70 3,45 3,10 1,05 45 84 29 0,46 0 27 '2 02 3 64 1 57 0 b4 0,72 0,43 0,64 0,64 0,52 2187 36 S !839 2245 60 S 1891 2097 94 $ 2147 21S 2198 22 S 2247 43 $ 2296 2 2522 2575 2626 2675 O0 w 2857 47 W 2936 40 W 30t3 02 ~ 3089 3165 87 W 3313 07 ~ 3385 66 N 3456 23 N 3525 44,00 F~ 2723.05 ,5 2344 17 W 3593 07 $ 40 43 ~ 52 2392 27 W 3660 43 & 40 48 W ,5 4053 Vd 3 3271 3323 3378 3434 3491 3548 3606 3665 3724 95 S 3443 3783 3841 3899 395b 4014 4072 4130 4188 47 $ 3503 04 S 3564 18 S 3627 71S 3690 S 3816 04 S 3880 O0 S 3944 4245,88 S 4008 60 ~ 3726 ~0 3795 68 ~ 3862 25 3929 02 ~ 3995 14 4060 16 4126 07 ~ 4193 34 S 2839 71 W 4262 59 ,5 2896 bO W 433 3 68 S 2955 28 S 3015 02 S 3076 16 S 3138 I S 3200 8 S 3261 56 S 3322 48 S 3383 41 W 4408 73 W 4487 94 w 4569 43 W 4652 09 W 4735 32 W 4819 i~ 4O 5 41 ~ $ 41 W 14 $ 41 46 W 80 S 41 56 89 $ 42 5 W 63 S 42 13 W 31 $ 42 19 w 22 $ 42 25 W 86 S 42 54 S 42 3 37 W 4903 62 06 W 4988,07 S 42 42 w tW 5072 W 5 35 W 5325 58 W 5410 54 W 5495 83 W 5581 ~ 5666 36 W 58{9 63 $ 4_2 45 w 44 $ 42 47 W 02 S 42 51 ~/ 53 $ 42 55 w 72 3 43 0 w 80 $ 43 4 W 26 $ 43 8 W 93 $ 43 {. 2 W 84 S 43 16 OS $ 43 21 W llOUO,Ou 8080.57 ~642,5'1 57 42 11100,00 8740,92 8696,92 50 o 11200,00 8795,54 8751.54 5~ 34 ~1]00,00 8846,93 BRO~ 93 58 41 11400,00 8898,8] 8854~83 58 36 i1500,00 ~950,~5 8006,96 58 47 11600,O0 9002.44 895~,44 59 ~ 11700,08 0053,59 9009,59 59 18 llSO0,O0 0104,3] 9080,]] 59 45 11900,00 0154,b0 9110.50 59 bO 10000,00 RllO 47 8006,47 45 17 10100,00 R179 17 8135.17 4'/ 59 10200 O0 8244 17 ~00,17 50 49 10300:00 R304 96 87o0,q6 54 10 lO400,O0 8362 01 ~318,01 ~5 47 10500,00 8417,40 8373,d0 5~, 5~ .10600,00 g,17l.'Y5 8427.75 57 7 10700,00 R576.14 ~482,14 57 q ~O 8535 09 57 30 10800,nO ~579. 10900,00 8633,33 8589,]3 57 51 ARCO AbA,SKA~ I:NC~ I,T iS~ U P I'd E TRUE SUB-SEA COURSE ~EA61JHFD VFHT1CAL V~RTTCAb DEVIATION AZIMUTH DEPTtl DEPTH D~PTH DEG HTN i)EG CO~PU?AT£ON ~ATE; lO-JUN-g5 ' PAGE 4 DATE OF SURVE]': JO-APR-85 KELh¥ BUSHING EbEVAT2UN{ ENGINEER{ HAuFACRE/LESNIE INTERPOLATED VALUES FOR ~V~N 100 FEET OF MEASURED DEPTH VERTTCAb DUGbEG RECTANGULAR COORDINATES MOR]~, DEPARTURE SECTION SEVERITY NORTH/$O~TM EAST/WEST D{$~, RZ2MUTH FEET DEG/IO0 FEET FEET F~E~ DEG M~N 44,00 12000,o0 920q.57 9100 57 60 26 12100,no o252,0o 9208 60 62 2 12~00,0u q29~,2R 9254 28 63 3] 12~00,00 q341 79' 9~97 79 64 53 12400,o0 93H3~O 9330 80 65 14 q4~5,o8 93'81 68 65 14 125U0,0~ 12600,00 gq6~,57 ~423,57 65 14 12?UO O0 0509,45 94u5,45 65 i4 1280n~00 0551,33 95u7,33 65 14 12g00.00 gbg3,2~ 9549,22 65 14 13000cOO 0u35,10 9591 10 65 14 i3100.00 9b?b,~q 9632~99 65 i4 13200,00 q718,87 96'14,R7 65 14 13300,00 q760,75 9716 75 65 14 13400.O0 q802,~4 ~75R~64 65 14 {35uO,Oo 0844.52 9800.52 65 14 {J600.00 9886.41 9R4~.4! 6~ ~4 1~700.00 q928,2g 98~4 29 65 14 {]800,00 q9'10,~7 9026:~7 65 14 13900.00 10012.06 99~8.06 65 [4 14000.00 10053.94 looug 94 65 14 14100,0u JOOg5 ~] !0051~83 65 ~4 14136~00 1011~0 100o6,90 65 14 $ 48 42 W 5921.q3 S 49 12 W OOO9,4b $ 49 33 W 609~,20 S 49 ~4 W 6187,97 S 49 57 w 627R.43 S 49 57 W 6308.94 $ 49 57 W 6459 45 S 49 57 W 654q:97 $ 49 57 W ~640.48 $ 49 57 W 0730.99 S 49 57 W 0821,5~ S 49 57 W 6912.02 $ 49 57 W 7002.53 S 49 57 W 7093,04 S 49 57 W 7183,55 S 49 57 W 7~74,07 S 49 57 W 7]54,58 $ 49 57 W 7455.10 S 49 57 W 7545.61 S 49 57 W 7636,~2 S 4~ 57 w '1726.63 S 49 57 W 7817,15 $ 49 57 w 7849,73 1,74 1.69 1,3g 4418 1,96 4476 0,00 4535 O,OO 4593 U,O0 4552 0,00 4710 0.00 4769 0,00 4827 0,00 0,00 4944 0,00 5002 0.00 506! 0.00 5119 0,00 511~ O,VO 52 0,00 5294 0,00 5353 0,00 5411 0,00 4303 26 S 4U73 18 W 5925 4360 89 S 4139 29 W 60:12 77 S 4205 99 S 4275 40 S 4344 82 S 4414 24 S 4484 56 $ 4553 09 S 4523 51S 469~ 85 W 610 5t W 61'9~' 97 W 6280 49 W 6371 01 W 6461 52 W 6551 04 w 6642 56 W 6732 43 25 W ~ ~ 43 30 ~ 07 S 43 35 w 60 $ 43 40 w 81 S 43 46 N ~0 $ 43 51_w 40 S 43 5 ~ ~ $ 44 ~ $ 44 ~ w ~8 S 44 11 W 4885 93 S 4762 07 W 6822 73 $ 44 15 W $ 44 20 W 35 S 4831 78 S 4~0! 20 S 4970 62 S 5040 O4 $ 5109 47 S 5179 89 $ 5248 Jl $ 5318 73 S 5387 59 W 6913 11 ~ 7003 62 W 9093 14 W 7184 66 w 7274 17 ~ 7365 69 W 7455 21 W 7545 72 W 7636 lO 47 $ 44 24 W ~ ~ 44 28 44 33 : 66 $ 44 37 w 08 $ 44 41 W 51 $ 44 44 W 94 $ 44 48 ~ & 44 52 W 5470,15 S 5457,24 W 7725,84 $ 44 55 W 5528,58 $ 5525,76 W 7817,30 S 44 59 W 5549,61 $ 5551,78 W 7849,87 $ 45 0 W L,I 5F~U Rr~ ~: NORTh $I,UPE·ALASKA CONPUTAT/DN DA~E: 10-JUN-85 DATE UR SURVEY: 10-APR-U5 iNTERPOLATED VAhUE$ FOR ~VEN 1000 FEET OF MEASURED DEPT TRUF SUB-SEA COtIRSE ~EASIlRVU VVAT.LCAL VgRTICAD DEVIATION AZIMUTH DEPTH DEPTh DEPTH DEG MIN DEG i4IN -44.00 0 955 98 0 2] 97 0 5 96 0 17 59 9 25 98 43 56 15 51 ~8 51 54 17 58 ~1 51 25 42 2] 0.00 0,00 1000,00 999°98 2000 OU 1909,97 1955 30ON:a0 2999.96 2955 4000,00 _~994.59 3950 5000,00 4869'9~ 4825 60OO,OU 5504:15 5450 7000,00 6107.51 b0~3 8000,00 6596.5H 6652 9000,~0 7371,26 7]27 lOOUO,O0 ~110,47 8066,47 45 17 11000.00 ~580,57 8642,57 57 42 12000,00 ~204,57 91~0.57 60 26 l~OUO O0 9635,10 9591,10 65 14 14000:00 10053'94 10009,94 65 14 14~36,00 10110,90 10066,90 65 14 N 0 0 E $ 10 53 W ,_q 4u 44 F PAGE 5 44,00'FT VERTICAL DOGLEG RECTANGULAR COORDINATE~ HORI~, DEPARTURE SECTION SEVERIT¥ NORTH/SOUTH EAST/WEST DXS~. FE~T DEG/IO0 F~ET FEET FEE~ DEG 0,00 2,11 N 45 I ~ -0,88 S 3u 37 W 41,50 S 33 51 W 481,]8 S 39 38 W 1243,81 S 41 2 W 204],23 S 41 54 W 2845,51 S 49 20 W 3581.]b 0.00 0.23 0.16 3,58 3,49 1,21 0,35 0,42 0,47 0,00 N 3,29 S 7,56 ~ 44 $ 5 8 13 N 66 362 05 2187 36 $ 1839 2723 05 S 2344 U.O0 E 0,29 E .~ 94 E 62 ~ '7 36 W 66 41W 482 67 ~ 1253 40 2054 O0 W 2857 17 W 3593 0 O0 N 0 30 ~ 4 59 g 80 ~ 14 22 E 6 S .51 40 g ~6, N 83 0 W 60 ~ 4i i7 w 71 5 40 3 W 07 $ 40 43 ~ S ~1 33 W 4253 80 S 45 21 W 5007 41 S 48 42 W 5921 93 S 49 57 W 6821 51 S 49 57 W 7726 63 S 49 57 w 7849 73 ~.09 0,27 1.74 0,00 0,00 0.00 3178,$4 $ 2839 71W 4262 14 $ 41 46 W 3724,95 S 3443 31 W 5072 63 $ 42 45 ~ 4303,26 S 4073 18 W 5925 27 S 43 25 W 4885,93 S 4762 07 W 6822 73 & 44 iS W 5470,15 S 5457 24 W 7726 84 $ 44 55 W 5549,61S 5551 78 W 7849 87 ~ 45 0 W bl-9 ~ONPu~ATZO~ D~TE~ 10-JUN-~5 DATE UF SURVEY1 lO-APR-85 KELb¥ BUSHING £bEVATZON{ 44,0o 1q44 03 1944o00 lO00,00 2044 03 7044.00 20oo,o0 2i44 03 ~144,00 2100,00 2244 03 2244.00 220o,00 2344 03 2344 oO 2300,00 7444:on 2444,04 2400 2544,n4 2544,0o 2500,00 2644,0~ 2644,0o 2744,04 2744,00 27uO,OO 2844,o4 2844,00 2800.00 0 6 S 2 56 w O 9 S Rb 4] E 0 17 I.., 54 3FI E 0 24 t.J 42 2 E 0 2.°. t~l 37 12 E O 22 N 45 22 E 015 .r~ 52 4 F 0 5 - N % 4 7 E 0 t2 N 44 14 E 2944 04 2944,00 2000,00 3044 04 3044,00 3000.00 3144 10 3144,00 J1uO,00 3244 55 3244,00 3~00 O0 3345 24 3344,00 33uO:.O0 3445 91 3444,0o 340noO0 3546 a'l 3544,00 3~On,O0 3646 Rb 3644 O0 3600.00 3747 25 3744:00 3700.00 3847:83 3~4,I,00 3800,00 0 16 ,.1 54 47 F '0,61 0 25 N ?1 5 E :1,13 3 35 a ?1 10 W 2,64 b 45 N 29 44 W -5,50 b 33 N 55 41 W 6, 6 b 21 N 70 46 W 2, ~ 50 S 89 31 W 2,10 5 2q R 69 57 W 9,49 b 53 S 55 9 W 19,84 944,01 944,00 1044.~2 1044 O0 lOOO,O0 1144,02 ~144 O0 llO0,O0 1244 02 1244 O0 1200.00 I344~02 1~44 O0 1~00,00 1444 02 1444 O0 1400,00 1544,02 1544 OO i500,00 1644,02 ~044 O0 1600,00 1744,03 1744,00 1700,00 1844,03 1044,00 1RO0.O0 O,Ou 0,00 -44,00 0 0 N U 0 44.01 44,00 0.00 0 13 N 60 52 144.09 144,0¢) 100,00 0 5 N 53 1 ~44,0! 244,00 200,00 0 4 N 77 37 344.01 344,00 300,00 0 9 S 0 .35 444.01 444.00 400,00 0 15 $ 23 45 544,01 544.00 500.00 0 10 S 8 55 644o01 644.00 600,00 O 23 S 8 11 744 O1 744 O0 700 O0 0 23 S 2 54 844:01 ~4~:00 800:00 0 18 S 5 17 iNTEHPOI, ATLD VAhUF8 FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-S~A C(')U Rt~E NEA,,SIJ~Et) VERTICAL VERTICAh DEVIATION AZI~OTIi DEPTH DEPTH DEPTH DEG i-'l.Tl~ DEG bin V~RTICgb DOGbEG RECTANGIJL~R CnOROINATE6 HORZge DEPARTURE SECTION SEVERITY NORTH/GOUTH EA&T/NES~ DISTe AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 0.00 '0,21 :0.37 0,49 :§1 o '0.06 0,33 O,fl8 1,27 1,77 2,33 2,62 ~,02 3,09 3,24 3,29 3,36 ],62 3,89 3,90 3,54 2 92 ~ O6 0 79 0 ]! 0.07 0,00 1,33 0.13 ,13 .18 0.1~ 0,18 O.lO 0,07 0,04 0 17 0 27 0 12 0 16 0 10 0,13 0.12 0,02 O.&O 0,0~ 0 08 0 24 0 0 27 0 1! 0 10 0,19 0 17 0 74 4 25 ! 94 ! 97 1,83 I'72 ,5~ 2,32 2,03 0,00 N 0,09 N O, 16 N 0,28 U 0 19 N 0 18 S 0538 I 02 s 1 77 S 2348 2.90 ~,57 3,92 4,10 4,43 4,9] 5,47 6,02 6,51 7,04 7475 7595 7 45 S 7035 6378 5798 5475 5 19 S 5065 4885 4,b0 S 4 23 S I 43 $ b 86 N 16 44 N 23 84 N 28 57 N 30 lO N 28 49 N 23 20 N 0,00 E 0,21 E 0,37 E .0 0,41 E 0 0,36 E 0,46 F O,bO E 0 0,54 F 0,51 E 0,53 E 2 0,39 0,25 0,31 0,37 0,41 0,53 0,85 1,32 1,70 1,86 1 92 E; 2 02 E 2 39 E 2 85 E 3 39 E 3 t~8 E 4 30 E 4 69 E 4 89 E 5 07 E 5,40 5,76 5,12 14,74 24,14 32,69 41,49 50.81 0 00. N 0 0 E '0 23 N 65 55 g 40 N 65 59 E 50 N 55 13 g 0 $ 48 3. 15 S 28 ', . 2 93 S 7 33 E 496 5 6 ~ E 5 54 $ 8 4 E 617 S 12 I~ g 0,73 ~ 14 E- 7,28 & 34 4~ E 7 72 $ 14 24 g 7 85 $ 14 54 g t ~3 S ~I 47 E 59 $ I E b 96 $ 381c--'~ 6,99 $ 42 ,, . 7,04 $ 44 3 E 7,04 $ 46 5 E 7 10 $ 49 34 E 6 17 28 37 44 50 55 93 N 7 53 g 44 N 19 29 ~i 03 N 31 44 W 40 N 40 11 W 43 N .47 21 N 33 N 55 31 # a6 a 65 27 ENGINEER{ HAbFACRE/LESNIE ARCO RL, A~SKA, fmC. bI$BURi~V. NONTH ,.'SLUPE,Af,ASKA DATE; IO..JUN-.R5 PAG~ DATE'OF SURVEY1 tO-APR-85 KEbbY BUSHING EbEYATIONI 6NGINEERI HAbFACRE/bESNIE INTERPOLATED VAI, UE~ ~'D~ ~V~N 100 FEE~ UF SUB-S~A D~PTH TRUK SUR-$~A COURS~ M~ASI~NPD V~NTICA[, VER'I'ICAb DKVIATIDi~ A~IMU~H DEPTH DEPTH DEPTH DEG MII~ D~G MIN S 43 26 W S 35 H W S 32 59 W S 34 7 W S 34 4q W S 34 ~7 W ~ 34 23 W S 34 9 W S 33 55 W 3q4R.7b 3944.00 3900 O0 .8 39 4050.18 4044.00 4000 O0 10 36 4152.63 4144,00 410o O0 14 9 4256 67 4244.u0 4~00 O0 18 6 4353 75 4344 O0 4300 O0 22 7 4472 91 4444~00 4400 O0 26 48 4587 ~9 4544~00 4~OneO0 30 55 4706 38 4o44,0~ 4600,00 34 55 4831 85 4744,00 4700~00 39 9 4954 29 4~44,u0 4800,00 42 47 · ° 44, O0 FT 638R 09 6944 uO OqO0,Oo 40 53 8537 40 7044 O0 7000,00 47 24 060410 7144 O0 710o,00 45 57 8826 o9 7244 od 7200,00 44 ~9~3 13 7344 uO 7300,00 42 19 9098 6~ 7444 O0 7400.00 42 44 9734,9! 7544~V0 7500.00 42 39 9370.05 7~44,00 7600,00 41 40 9504.01 7744,00 7700,00 42 0 9638,31 704~.00 7800,O0 41 15 S 42 50 W 3144.00 S 43 28 W 3255 63 S 43 58 W 3362 17 $ 44 28 W 34~2 86 S 45 14 W 355653 $ 45 21 W 3648 04 S 45 17 W 3740,54 $ 45 ~? W 3831.45 S 46 57 W 3921.78 S 47 5~ W 4010,15 6739 qu 5944 O0 5900,00 ~3 21 6894:64 6044:00 OOuO.00 54 R 7005.~q0 6144.0o olO00U 54 20 7237,43 6244,00 0200:00 54 26 7408 71 6544,00 6300.00 54 24 7578~1 644.i.00 ~400.00 54 47 '1749.]b 654~.00 0%00 O0 53 26 7q14,49 6644,00 ~600:00 52 23 8076 51 674q,OO 6700,00 51 24 8234:]2 6844,00 bROO.00 50 4 5106.00 4944.00 4qu0.O0 47 34 5260.54 5044 UO 5000,00 51 35 5427.54 5144:00 5100,00 52 2 5583 61 5244,00 5200,00 51 25 5743~86 5344.00 5300,o0 51 28 5903.6~ 5444 UO 5400.00 50 5fl 6064.32 5544:00 55u0.00 51 42 622R,31 5644.00 b6uO.O0 52 47 6393,69 5744.00 5700,00 52 43 6559.09 5~44.00 5800,00 52 49 $ 41 33 W 1830.85 S 41 15 W 1955,35 S 41 11W 2094.00 S 41 21 W 2233,03 S 4i 40 W 2371.77 S 41 ~7 W 250g,22 S 41 56 W 2645,54 S 41 53 W 2778.21 S 42 I W 2908,10 $ 42 17 W 3027,ll 2.46 3 21 298 4 O5 2 9O 4 11 3 55 3 55 3 01 2 87 3,73 1,72 1,11 0,76 1 .40 ,23 0.44 0,24 0,52 0.,46 0,47 0.72 1.22 0,97 0,26 0,88 0,84 1,28 1,16 0,82 1,20 1,17 0,62 0,73 O, 2,13 1,18 , 71,50 71, N 89 12 W 41 , 31 W , 99 70 107,90 67 ,77 ~ 120, 145,65 181,79 53 14 W 48 2'3,52 297, 45 -'-- ' , 43 ~'.~I ~304256.75~5 ~ 458,32 372, "~5 41 4020'W, 425 64 S 360,06 W 523 33 S 420.43 W 627 75 S 499 50 W 802 729 829 920 1023 1121 1220 1~18 73 $ 573 21S 650 39 $ 728 35 S 8O8 70 S 893 65 S 980 96 S 1067 97 W 928 Ot W 1053 06 W 1178 12 W 1303 08 w 1433 12 W 1565 73 W 1696 557,90 ~ 40 16 b 675 07 6 39 10 ~ 23 ~ 38 30 W 41 ~ 38 11 w 61 $ 38 5 W 25 $ 38 9 W 95 S 38 17 ~ 80 $ 38 31 ~ 37 ~ 38 45 ~ 97 & 3859 w 1426 99 S 1163 1520 56 S 1 246 1625 1729 1833 1936 2038 2137 2231 2322 $1 S 1337 99 S 1429 99 $ 1522 71 $ 1613 26 S 1705 14 S 1794 98 S 1882 19 $ 1961 88 W 1841 44 S 39 12 W 45 W 1960 15 6 39 20 W 86 W 2105 89 W 2244 W 2521 20 W 2657 01W 2790 91W 2920 07 W 3039 11 S 39 27 ~ 42 S 39. 34 W 38 ~ 3941 W Ol S39 48 ~ 48 S 39 31 ~ 40 12 $ 40 ~ ~ 47 S 40 10 W 2408 41 $ 2040 22 W 315b 41 ,5 40 16 W 2489 97 S 2116 54 W 3267 99 S 40 21 .S 4028 W 2567 2639 2705 2769 2834 2898 2961 3020 04 S ~190 21S 2260 61 S 2326 89 S 2391 9t S 2457 53 S ?522 01S 2587 90 S 2652 18 W 3374 42 W 3474 50 W 3568 63 w 3659 42 W 3751 36 W 384 bO W 393~ 67 W 4020 W 40 90 & 4034 W 32 S 40 41 W 53 & 40 48 W 75 S 40 55 W 34 S W 26 ~ 41 17 . S 33 49 W 555.71 S 34 17 W 671.15 S 35 24 W 796,52 S 36 52 W 921 16 S 38 11 W 1045 !7 S 39 3 W llb8 99 S 40 19 W 1294 09 S 41 5 W 1423 65 S 41 32 W 1555,o5 S 41 44 W 16u6,53 33.54 50.17 71.89 99,92 135.93 180 06 23434 297 95 372 30 45738 VERTTCAb DUGbEG RECTANGUbAR COORDTNATES HORIg, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET. DEG MIN ARCO. AL, ASKAw INC, L, 1 -,9 NORTH SI,OPEwALASKA COt, IPUTATION DATE: lO-dUN-85 PAGE DATE OF SURVEY: lO-APR-U5 KgbbY BUSHING EbEVATION$ ENGINE~RI MAbFACRE/DESNIB /NTERPUI, A?I=D VALuF:,5 [,'IDA I:';VEN 100 F~ET OF' $UB-$EA DEPTH ]'RU~ SUB-SEA COURSE M~A611MEU V~iRTIPAI, VERTICAb D£VIATIDN AZIMUTH D~PTH DMPTu D~PTH DEG MTN DEG MTN 9771.63 7944,o0 7900,00 41 34 9906,05 8044,0o ~OOO,O0 43' 39 10048,Y8 8144,00 UlO0 O0 46 38 10~99,74 R24~.00 8~00 O0 50 49 1030~.07 8344,00 8]00 O0 55 20 10548,~4 8~44,00 H400 O0 57 4 10733,04 R544,00 8500 O0 57 1R 10920.07 R044,00 ~600 O0 57 52 11105 46 R744,00 ~700,00 55 53 11294:39 R84~,00 8800.00 58 43 11486.50 8944 O0 8qO0,Oo 58 4l 11601 17 9044~00 9000,00 59 15 11879:0~ 014~,00 910o O0 59 52 12081,71 0244 UO 9700~00 61 46 12305.1~ 9344,U0 930o,00 f4 50 12543,73 9444,00 9400,00 65 14 12702,49 9549,00 9500,00 65 14 13021,34 0o44 O0 9600,00 65 14 13~60,00 9744:00 9700.00 60 14 13498,75 gu4~,O0 9800,00 65 1~ 44,00 FT VERTICAb DUGDEG RECTANGUbAR COORDINATE8 HORIZ, DEPARTURE SECTION SEVERITY NORTIt/SOUTH EAST/WEST DIS~. AZIMUTH FEET D£G/IO0 FEET FEET F~E~. DEG M~N S 49 20 W 4098,!9 S 51 I W 4189,02 S 51 31 W 4288,43 S 50 12 W 440~,56 $ 4~ 1. W 4536,62 S 4'1 15 W 4607,10 S 40 31 W 4841,72 $ 45 25 W 499g,76 S 40 18 W 5155.84. $ 47 36 W 5316,01 0,~1 2,23 3137 ,06 3199 ~,44 3271 1,25 3360 0.40 3461 0,45 3567 0,36 3077 1,34 378~ !,81 3895 1,02 0,73 0,44 1,41 0,00 O,UO 0,00 0,00 0,00 0,00 0,00 0,00 3079 lg$ 2718 61S 2788 95 S 2860 55 S 2955 34 S 3057 90 $ 3168 58 S 3281 41 $ 3395 58 S ]506 96 S 3623 83 W 4107 73 4296 25 W 4408 37 W 4543 57 W 4693 52 W 4849 17 W 5005 72 W 5160 ~2 W 532O 86 41 37 $ 42 06 $ 42 17 ~ 04 S 42 28 ~ 27 $ 42 3~'-'~, $ 42 4. 94 S 42 48 ~ 76 & 42 55 N 4000 55 $ 3745 06 W 5484 33 S 43 4 W 4119 3868 ~ 43 12 W 4233 4350 4480 4019 4758 4898 5037 5177 2 S 2 S 3994 36 S 4127 O1 $ 4279 37 S 4444 86 S 4010 34 $ 4770 83 S 4942 32 S 5108 W 5050 W 5821 07 W 5996 10 W 6195 89 W 6410 87 W 6626 84 W 6841 82 W 7057 79 W 7273 78 02 $ 43 20 W 52 S 43 29 W 26 S 43 41W 59 S 43 53 W 22 & 44 5 W 93 $ 44 16 ~ 70 S 44 27 W 54 & 44 .37 W 5310,80 $ 5274,~7 W 7489,43 ~ 44 46 ~ 5450,29 S 5440,,4 W 7705,~7 S 44 55 W 5549,0t S 5551,78 W 7849,87 ~ 45 0 W 13737,51 9944,V0 9000,00 65 14 13976,27 10U44,o0 lOnuO,O0 65 14 14136.00 10110.90 10006.90 65 14 S 47 ~1 W 5479,98 S 47 35 W 5646,81 S 48 6 W 5R17~43 S 49 6 W 5993,37 S 49 42 W ~192,64 S 49 57 W 6409.53 S 49 57 W 6624,63 S 49 57 W 0840,74 S 49 57 W .'/05~,~4 S 49 57 W 7272,94 S 49 57 w 7489,05 S 49 57 W 7705,15 S 49 57 W 7849,73 NORTH TOP GIS~URNE PBTD TAT~b DEPTH C{3~,1PUTATiON L)AI'E; IO-JUN,,B~ .LN']'E~PU[,ATE['~ VAI,UE,$ Flll~ CHUSEN HORIZUN$ r~EAS~.J R~;D DEPTH BELUW 14069,0~ 1413b,00 DATE UF SURVE¥~ lO-APR-,85 Kg[,L,¥ BUSHING EL, EYA'I':::[UN~ 44,00 ENG~NE~R~ ItAbFAC~E/b~$NIE SURFACE EOCATZON AT OAIGTN= 2422' r&bv 2468' FWb, SEC ! TlJN~ R14E~ U~ TVD RECTANGUbAR ~OORD!NATES e'aU, Ku SU~-$EA NORTH/SOUTH EA&T/NEST , 10082:84 10038,84 5510,47 $ 55.-,21N 1.0110,9o 10065,90 5549~61 ~ 5551,18 W ARCO ALA;SKA, lr~C, bl -q blSBURr~F. NORTH 5I, OPi~,AI, A,q. KA MARKEH TOP bT5RURNE T[I'£A l, DEPTH FI_HAI, WE[,6 bOCAI'TON COi~PUTATION DALE: I'Ru~ SUR=SEA D~["I't! U~PTH DEPTH ~R]ASUR~D DEPTH BE, LUW K~ 112Bl,O0 14U69,00 14130,00 1413o,00 10110,90 10066,90 lO-JUN-85 SUMMARY FROM PAGE DATE OF SURVEY! t0-APN-85 KELLY BUSHING EbEVATION~ ~NGINEER~ HALFACRE/bESNZE ORIGIN= 2~22' F8L, TVD Kb SUB-SEA 8R37,00 10082,B4 10110,90 8793,00 10038,84 10066,90 ~ORIZONTAb DEPARTURE DISTANCE AZIMUTH 78't9,87 44,00 F~ SURFACE hOCAT[ON RECTANGULAR COORDINATE,,5 NORTH/SOU'[H ~A~T/NEST 36gSS,37 N $55t, w 5510,47 S 5549,61 S U~ ,545 OW SCHLUMBERGER O'[ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL L I SBURNE L 1-9 F I ELD LISBURNE UNIT COUNTRY USA RUN ONE DATE LOOOED 1-APR-8S REFERENCE O000?OS 12 WELL NAME: LISBURNE L1-9 StmFACE LOCAT~O~ ~-42~-' ~m., ~-468' m~rL., S~, ~ ~4~, ~ ~ ~ ~ERTIC~ PROJECTION -4000 -ZOO0 0 0 ~000 4000 ~000 8000 ~0000 · { ~ ! ! ! t ~ i ~. ~ :: ~ ~ -'+-+-/--+-: "?-?-? ~ : ~ ~ ~ ~ ~ ~-?'~-~--?~?--~-~w~ ~ ~ ~- , . . ~ . ~ ...... , ...... ~, . , ~. ~__~.~ ~ , ~ ~J-~- ~ , ,.~J._~ ..... ~ ........ ~_ ---~"'+-~-~-'~-'-¢4-e"+ ..... 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L..i...:....L.L..~....~....~....~... '"T"???"*'"?'?"?~ ...... w"T"T'"T'"T-T-W'T"T'"'"T"T"T'T ...... T"'r"T'"T ...... T'"r"T"? ...... I T T T : T T i I ~ ~ ~ t ~ ~ ! ~ ! ~ ! : i ~ :'"T"T'"T'"T'"T"T'T"T'"T ....... T"'T'"T"T"?"T'"T'"T'"r'""TT~'~T'"?'T .......... T'T'"T'"T'",,'"?~":: .... T~ ~ T'":"T"T ......... 7"t"7",F'T'"T'"7"T ............. r"F"F't"i'"'?["'[ ............. ?'"F"['"~"'['"F";'"'?":'" PROJECTION ON VERTICAL PLANE Sld - NE SCALED IN V~'R'r]CAL BEPTHS HORIZ SCI~LE = 1/2000 IN/FT WELL NAME: LISBURNE L1-9 SURFACE LOCATIO~ 2422' FSL, 2468' FWL, S1, Tll~ l14E, UM .' HORI,-oNTAL PROJECTION NORTH ~'OOQ REF O0007OS ] 2 SCRLE = ] / ] 000 ! N/FT 1000 -1000-- -2000 -HO00 -4000 -5000 SOUTH -6000 -6000 -5000 -4000 -9000 -2000 -1000 0 I000 2000 Suggested fo'.-.~ to be inserted in each "Active" well folder to check for' timely compliance with our regulations. Reports and Materials to be received by: Date Required Date Received Remarks Completion Report ...... ~'.,,...~.., ,,.~'" ~,,.., , ,.. """.,,..,,~, .' k,. ........ Samples' Mud Log .~ p~ ..... ?.~m~,~ ..... ~2'~.~'-~''' Registered Survey Plat ~. Directional Survey '?~,,.~,,,u,,~?" .,,,,%.:~,~,,,,,,,,,~,¢y,iI*~''' ,,,. i" ' , " Production Test Reports ~,, ~ ,' Digitized Data ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 17, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: RE: Well L1-9 Monthly Report of Drilling and Workover Operations Attached is the Monthly Report of Drilling and Workover Operations (Form 10-404) for Lisburne Well L1-9 for completion activities during August. Any questions you may have on this information should be directed to me at 265-6538. Very truly yours, Area Operations Engineer JLH:RML/kh 06-1 attachment cc: J. S. Dayton J. J. Guerrero .S. Hasund R. G. M. Oba E. G. Przybyszewski J. P. Schumacher RECEIVED 1 !985 AJaska Oil & Gas Cons. Commission Anchora::t~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation I~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P.O. Bo× 100360 A_nchorage, AY, 99510-0360 5o- 029-21265 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec. 1, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 4~' RKB 6. Lease Designation and Serial No. ADL 28302 ALK 2313 9. Unit or Lease Name Prudhoe Bay Unit-Lisburne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of August ,19 R5 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Pumped 20 bbls diesel and 9 bbls water with 20 ft.3 of sand. at 13175' MD. Top of sand 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run D None ~laska Oil ~ 'd,:¢s COns 16. DST data, perforating data, shows of H2S, miscellaneous data Performed fracture stimulation on 8-24-85 with 1181 bbls fluid containing 35500 lbs. sand. Well opened to flow with no response. Nitrogen jetted and produced 955 bbls fluid with a hydrocarbon cut of 50%. Produced hydrocarbons consisted of mostly load diesel. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED Z~~~~¢//~~ TITLE Area Engineer DATE ~/7/~'--- NOTE--ReI~t ~r~his fbrm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 ARCO Alaska, Inc. Post Office B~:'~ ~)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 13, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: RE: Well L2-28 and Well L1-9 Monthly Report of Drilling and Workover Operations Attached are the Monthly Report of Drilling and Workover Operations (Form 10-404) for Lisburne Wells L2-28 and L1-9 for completion activities during July. Any questions you may have on this infor- mation should be directed to Dave McNaughton at 263-4399 or me at 265-6330. , Very truly yours, Sr. Area Operations Engineer CC/lch 14-1 attachment cc: J. S. Dayton R. K. Doughty T. L. Fithian D. A. McNaughton R. G. M. Oba RECEIVED AUG 1 6 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchfieldCompany '" " STATE OF ALASKA ,, ALASKA q,,~' AND GAS CONSERVATION CO~..'*41SSION · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska Inc. 85-1 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of Well at surface 2422' FSL, 2468 FWL, 5. Elevation in feet (indicate KB, DF, etc.) 44' ~ Sec. 1, T-11N, R-14E UM 6. Lease Designation and Serial No. ADL 28302 ALK 2313 For the Month of July ,19 85 8. APl Number 5o- 029-21265 9. Unit or Lease Name Prudhoe Bay Onit-Lisburne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Ran a downhole sample on 7/9/85 to recover a bottomhole fluid sample. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None Alaska 0il & 6as Cons., Commission Anchorage 16. DST data, perforating data, shows of H2S, miscellaneous data N±trogen jetted-produced a mlnlmal volume of fluld wlth an oll cut of 5-20%, Acldl~ed on 7/3/85. Produced 311 bbls of fluid w/85% water cut. The well would not flow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .......... ~ --_ DATE 7 -'~ NOTE-.Report on this form ~quired for each calendar month, regardless of the status o.f operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1.80 New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive From: Kelly Prockish Date: Anchorage, AK 99501 Attn: Transmitted herewith are the following: August 12, 1985 C. V. Chatterton Revised Final Tapes for Lisburne Well L1-9: (Corrected NGT Field Data) Tape 1 . Open Hole Shifted LIS, Run 1 & 2, 3-27-85 Start Dept'h ~4-149.0~, Stop Depth 11055.0' Tape 2 Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: /7~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Aiaska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive From: Ke±ly Prockish Date: August 6, 1985 Anchorage, AK 99501 Attn: C. V. Chatterton Transmitted herewith are the following: Final copies for the following Lisburne Wells: L2-6: Pressure Data Flowing Survey, 7-5-85 (Gearhart) L1-9: Pressure Data Flow & Static for Tie-In, 7-24-85 (Gearhart) Receipt Acknowledgement: Return Receipt to: Alaska Inc. ' New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage,' Alaska 99510-0360 "'~ OOns C°rnrnissiot~ '~' /~nOhurage · Transmittal No.: /'~/~ ARCO Alaska, Inc.~'{' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 12, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Well L1-9 Monthly Report of Drilling Operations and Workover Operations Attached is the Monthly Report of Drilling and Workover Operations (Form 10-404) for Lisburne Well L1-9 for testing activities during June. Any questions you may have on this information should be directed to Keith Paige at 265-6234 or me at 265-6330. Very truly yours, D. K. Chancey DKC: KTP / kh 05-1 ~-~%= cc: J. S. Dayton R. K. Doughty T. L. Fithian R. G. M. Oba J. S. Shockley RECEIVED J U L ! 8 ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ~' ALASKA ,.~!' AND GAS CONSERVATI,,O.N CO~.~'~41SSION Drilling well ~ Workover operation 2. Name of operator ARCO Alaska, Znc. 3. Address P.O. Bo× 100360 Anchorage, AK 99510 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec. 1, T-liN, R-14E UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 44' RKB ADL 28302 ALK 2313 . ?. Permit No. 85-1 8. APl Number 5o- 029-21265 9. Unit or Lease Name Prudhoe Bay Unit-Lisburne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of June , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks The thru-t.ubing bridge plug and cement set @ 13,392' MD on 5/29/85 failed pressure test- ing, Two additional cement placements, 0.7 bbls of Class G on 6/9/85 and 5 bbls of Class G on 6/13/85, were necessary to isolate the 13,395' - 425' perfs. Lost fish (tubing tail locator) in'hole (12,391') while running in hole to verify bottom. Retrieve/push fish to bottom (13,303' ELM) on 6/25/85. 13. casing or liner run and quantities of cement, results of pressure tests Pressure test following cmt. placement on bridge plug 6/2/85 - failed. Pressure test following cmt. placement on bridge plug 6/11/85 - failed.. Post squeeze pressure test 6/26/85- acceptable. 14. Coring resume and brief description NONE 15. Logs run and depth where rOn CCL/Temp f/13,383' -12,450' CCL f/13,303' - 12,450~ 611o185 6/27/85 J U L t 8 1985 Alaska 0il & Gas Cons. C0mmiSsi0~ Anchorags 16. DST data, perforating data, shows of H2S, miscellaneous data N2 jetted top 2,000' of fluid from wellbore to achieve a 1500 psi drawdo~rt, Perforate~ 13,270' - 280' 13,246' - 254' 13 066~ - I26' 12,998"- i3,008~ and 12 966' - 972' ~ ~ , ', , , on 6/27/85. Well did not flow to surface. Acidized w/95 bbls 18.i% HC1 through coiled tubing on 6/29/85 Produced i0 bbls fluid/day @ 10 psi FTP with an 80% water cut. Total volume produced is 200 bbls. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE---Report on this form is required for eac'N calendar month, regardless ~f the status'~' ~-l:7~r~;tions, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-t .80 i .J ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive Anchorase~ AK 99501-3192 From: Kelly Prockish Date: July /~ 1985 Attn: C.V. Chatterton Transmitted herewith are the following: Final GCT LIS Tape for Lisburne Well L1-9: 'Start Depth - 10' Stop Depth - 12320' Run Two, 4-10-85 (Tape Computed on 6-24-85) Receipt Acknowledgement: 0 Return Receipt to: . AR~Co Alaska Inc. //Z~e~ Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: ",.. Processed by: ~ ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission Address: 300i Porcupine Drive From: Kelly Prockish Date: July 5, 1985 Anchorage, AK 99501-3192 Attn: Transmitted herewith are the following: C. V. Chatterton Final Copies for Lisburne Well L1-9: CCi..'L'.g, 6-9-85 (1 each Blueline, 1 each folded sepia) (Ref: Otis) Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Date: Transmittal No.: Processed by: ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska. Inc. New Projects - Lisburne TRANSMITTAL To: S~ate of Alaska Alaska Oil & Gas Conservation Committee Address: 3001 Porcupine Drive From: Kelly Prockish Date: June 28, 1985 Anchorage, AK 99501-3192 Attn: C.V. Chatterton Transmitted herewith are the following: (1 Set Bluelines, 1 Set Folded ~epias) Final Well Logs for Lisburne Well Li-9: Computer .Processed Log, Run 1,~ 3-9-85 Micro-Log/GR, Run 1, 3-10-85 2" & 5" BHC Sonic .in 7" Casing, Run 2, 3-30-85 ~Cased Hole CNL/GR, Run 1, 3-10-85 1", 2" & 5" TVD-Borehole Conpensated Sonic, Run 1, 3-11-85 2" & 5" Natural Gamma Ray Spectrometry Log, Run 1, 3-9-85 Dual Dipmeter, Run 1, 3-12-85 2" & 5" Long Spacing Sonic/GR, Run 1, 3-12-85 2" & 5" Raw Data ComPensated Neutron Litho Density, Run 1, 3-10-85 Fracture Identification Log, Run i, 3-12-85 EPT/GR, Run 1, 3-10-85 ---2" & '5" Por. osity Compensated Neutron Litho Density, Run 1, 3-10-85 .---2" & 5" Compensated Neutron Log (In Casing), Run 2,3-28-85 Long Spacing Sonic Waveforms, Run. l, 3-12-85 1", 2" & 5'~ DLL/MSFL/GR TVD, Run 1,. 3-12-85 ... BHC Sonic Waveforms, Run 1, 3-11-85 2" & 5" Borehoie Compensated Sonic / GR, Run 1, 3-11-85'~'~=~',~ 2" & 5" Simultaneous Duai Laterolog, Run 1, 3-12-85 2" & 5" Formation Density - GR (Porosity) Run 1, 3-1Dv85 1", 2" & 5" LDT/CNL/GR TVD, Run 1, 3-10-85 2" & 5"'Formation Density - GR (Raw Data), Run 1, 3-10-85 Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 ~Dat~e: R~E~C ~!V F I~ Gas Cons. Oo~]mission Anchorage Transmittal No.: ~~ ? Processed by: ~~ ~~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCornpany ARCO Alaska, Inc. New Projects - Lisburne TRANSMITTAL To: Slate of Alaska Alaska Oil & Gas Conservation Committee Address: 3001 Porcupine Drive From: Date: Anchorage, AK 99501-3192 Attn: Transmitted herewith are the following: Kelly Prockish June 26, 1985 C. V. Chatterton Final copies for Lisburne WelI L1-9: Basket Flow Meter, Run two, 6-12-85 (1 each Blueline, 1 each Folded Sepia) Receipt Acknowledgement: Return Receipt to: /~AR~6 Alaska Inc. ~ New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: Processed by: ARCO Alaska. Inc. is a Subsidiary ot AtlanticRichfieldCompany ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Committee Address: 3001 Porcupine Drive From: Kelly Prockish Date: June 18, 1985 Anchorage, AK 99501-3192 Attn: Transmitted herewith are the following: C. V. Chatterton Final Copy GCT Sub-Surface Directional Survey for Lisburne Well L1-9. Receipt Acknowledgement: Return Receipt to: ARco Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 ;'!"~"~'~ ~ ~ ~ Cons,, Commission P. O. Box 100360 ~chorage, ~aska 99510-0360 Transmittal No.: ~Sf Processed by: ~~ ~ ARCO Alaska, Inc. is a Subsidiary of Atlant cRichfieldCompany ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: RE: Well L1-9 Monthly Report of Drilling and Workover Operations File: L1-9 W1-2 :~-~OMM ~-~ao'~-i~ I S. TAT ~-_ ~ ST,Al' T"C -~ ................... CONFER: Attached is the Monthly Report of Drilling and Workover Operations (Form 10-404) for Lisburne Well L1-9 for testing activities during May. Any questions you may have on this information should be di- rected to Dave McNaughton at 263-4399 or me at 265-6330. Very truly yours, D. K. Chance~ Sr. Area Operations Engineer DKC: DAM/kh o5 ~~ cc: J. S. Dayton R. K. Doughty T. L. Fithian R. G. M. Oba J. S. Shockley RECEIVED JUN 1_ 7 1 85 Alaska Oil & Gas Cons. Commission] Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany " STATE OF ALASKA ' ALASKA (~.. AND GAS CONSERVATION CO~ .,llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec. 1, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 44' RKB ADL 28302 ALK 2313 7. Permit No. 85-1 8. APl Number 50- 029-21265 9. Unit or Lease Name Pr,,Hh_nm gay Un~t/Li~burne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of. May ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Continued cement squeeze operations on perforations 13,456' - 13,502'. Pumped 463 bbl LCM pill to seal natural fractures. Parted coiled tubing during cleanout operations; top of fish @ 13,440'. Resqueezed 05/14/85 w/30 sx (5 bbl) Class "G" cement; left PBTD @ 13,430'. Set thru tubing bridge plug @ 13,392' MD w/56 sx (11.4 bbl) Class "G" cement on plUg May 29, 1985; left PBTD @ 13,365v. Waiting on cement as of May 31. 13. Casing or liner rgn and quantities of cement, results of pressure tests Post squeeze pressure test 05/01/85 - squeeze failed. Post squeeze pressure test 05/16/85 - acceptable squeeze. 14. Coring resume and brief description 15. Logs run and depth where run GR/CCL/Temp f/13,482' - 12,450' 2 May 85 .Alaska 0ii & Gas Cons. ComrnJssi0 Anchorage 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated. f/13,395' - 13,425' w/2000 psi drawdown 05/18/85. Prod'Uced 11 bbls total fluid; well died. Acidized w/35 bbls 14.4% HCl through coiled tubing 05/25/85. Produced 240 bbl water/day @ 20 psig'FTP with trace hydroCarbon initially. Produced total volume of 516 bbls water; 12,000 ppm Chlorides. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge.. NOTE--Report on this form is required calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alaska ~ ~ ~ Cas Conservation Commission 3001 Porcupine Drive Receipt of the following material which was transmitted via /~i'/ is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent to sender YES NO ARCO Alaska ina. New Projects - Lisburne TRANSMITTAL To: state of Alaska Alaska Oil & Gas Conservation Committee Address: 3001 Porcupine Drive From: Kelly Prockish Date: May 29~ 1985 Anchorage~ AK 99501-3192 Attn: C. V. Chatterton Transmitted herewith are the following' Final copies for the following Lisburne Wells: 1 each OH-LIS Depth Shifted Tape, Run 1, 2-28-85 Start Depth of 11541', Stop Dep-h of 10510.5' L1-9: ,Cement Bond Log, Variable Densi[y, Run 1, 3-8-85 (1 each Blueline, folded Sepia) Gamma Ray Collar Log, Run 1, 4-9-85 (1 each Blueline, rolled Sepia) COI FIBEt TIAL CET Log, Run 1, 3-30-85 .Cement Bond Log, Variable Density, Run 1, 3-29-85 Differential Temperature Log, Run 1, 4-24-85 Gamma Ray Log, Run 1, ~-25-85 (1 each Blueline, folded Sepia)- Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisbur-_.e Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: Processed by.'~ ~RCO Alaska, Inc, is a $obs,,aiary o! Al!anhcR,cht,elaCom: ARCO Alaska, Inc.'~{' Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 20, 1985 File: L1-9 W1-2 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: RE: Addendum to Well L1-9 Monthly Report of Drilling and Workover Operations Attached you will find an addendum to the Monthly Report of Drilling Operations (Form 10-404) for Well L1-9 filed by J. Gruber May 13, 1985. This addendum covers testing operations that have occurred since the drilling rig was released April 18, 1985. If you have any questions about the information, in this addendum or about any of the forthcoming L1-9 Monthly Reports, please contact Dave McNaughton at 263-4399. Very truly yours, D. K. Chancey Sr. Area Operations Engineer DKC: DAM/kh 05 cc: J. S. Dayton R. K. Doughty T. L. Fithian R. G. M. Oba J. S. Shockley RECEIVED Alaska Oil & Gas Cons. ComrnJssio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA ~ AND GAS CONSERVATION COl( IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~ Addendum Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P.O. Box 100360 Anchorage, AK 99510 50-029-21265 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec. 1, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 44' ~ 6. Lease Designation and Serial No. ADL 28302 ALK 2313 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L1-9 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of April ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks (See also monthly report subm±tted.b¥ 3. Gruber, 5/13/85) Plugged 5" llner from 13,505' - 14,036', w/46 s×.'of Class G Cement. Squeeze cemented perforations from 13,456' - 13,502' w/488 s× Class 6. Squeeze falled. Aesqueeze in progress as of 04/30/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 14. Coring resume and brief description None 15. Logs run and depth where run Directional Survey (gyro) f/13,950' - 12,016' GR/CCL 14,033' - 12,000' Differential Temperature 14,000~ - 13,400' GR/CCL 12,481' - 10,685' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated f/13,456' - 13,502'. Acidized w/4300 gallons 15% HC1 on 04/22/85. Flowed 2500 BWPD, 40/64" choke, 315 psig FTP, no oil cut. R[C.E VED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ataska 0JJ & (]as C0fls, C0millliSSJ0r, SIGNED ['~ ' TITLE ~T'. Ol~T',~f'i~la~ ~,~gi~l~ DATE /~"--~ I~ y ..Z~ NOTE--Report on this form is-reqt~ed f;r each calendar month, regardle;s of the status of operations, and must be file4;J..~ duplicate with tl~e Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ARCO Alaska, Inc Post Office ,_,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports . Dear Mr. Chatterton. Enclosed are the April monthly reports for the following wells' 1Q-1 2u-10 1Q-2 2U-11 1Q-16 2U-12 1R-5 2V-10 2U-9 2V-11 2V-12 3B-16 9-28 2V-13 3-16 (workover) 17-14 3B-1 4-32 L1-1 3B-2 9-16 (workover) 'L~-9 3B-3 9-27 L2-28 If you have any questions, please caT1 me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures ,.. MAY ! 19 5 CJI & Gas Cons. Con;mission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 'i STATE OF ALASKA ALASKA d _ AND GAS CONSERVATION CO~( ,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well I-~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21265 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec.1, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 44' RKB ADL 28302 ALK 2313 9. Unit or Lease Name Prudhoe Bay Unit/Lisburn 10. Well No. L1 -9 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool For the Month of Apri 1 ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 0100 hfs, 01/1~3J-8-5~. ..... Drld 17-1/2" to 4032'. Ran, cmt~l & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,496'; stuck pipe. Stuck wireline tool @ 8920' and recovered. Work pipe free; drilled ahead to 11,120'. Fluid loss occurring ~ 10 BPH. Ran & cmtd 9-5/8" csg. Ran log. Drld 8-1/2" hole to 11,292'. Cored f/11,292' - 11,356' (core barrel twisted off while cutting Core #2. It was fished & recovered). Performed DST. Continued drlg 8-1/2" hole to 11,373'. Cored f/11,373' - 11,937'. (see attached sheets) 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40, weld conductor set ~ 110' Instld w/1800# Polyurethane 13-3/8'", ?2.0#/ft, L-80, BTC csg w/FS @ 4002'. Cmtd w/3200 sx Perm "E" 4- 400 sx Class 9-5/8", 4?.O#/ft, L-80, BTC csg w/FS @ 11,095'. Cmtd w/lO00 sx Class 7", 29.0#/ft, L-80, BTC csg. f/10,788' - 12,600'. Cmtd w/850 sx Class {see attached sheets) 14. Coring resume and brief description Core #1 f/11,292' - 11,297' - cut 5'; no recovery. Core #2 f/11,297' - 11,303' - cut 6'; no recovery. Core #3 f/11,301' - 11~330' - cut 29'; recovered 29'. Core #4 f/11,330' - 11,356' - cut 26'; r~covered 26'. Core #5 f/11,373' - 11,394' - cut 21'; recovered 21-1/2'. (see attached sheets) 15. Logs run and depth where run SHDT/AMS/GR f/12,374' - 11,085' Casing Caliper f/10,926' - surface DIL/SP/MSFL/NGT/Cal f/12,327' - 11,085' LDT/CNL/GR/Cal/ML/EPT f/12,419' - 11,085' (CNL/GR to 9800'; GR to 4000') FDC/GR/Cal f/12,362' - 11,085' (see attached sheets) 6. DST data, perforating data, shows of H2S, miscellaneous data DST data will be submitted with Completion Report 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED // TITLE Associate Engineer DATE NOTE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by tl~ i=1 ~tl~/l~:~ Cucceeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate Monthly Report of Drilling and Workover Operations (cont'd) For April, 1985 L1 -9 Item 12: Drilled f/11,937' - 12,600'. Ran OHL. Ran, cmtd, & tstd 7" liner. Drilled 6" hole to 14,136'TD as of 03/25/85. Ran OHL. Ran 5" liner f/12,427' - 14,136'. Ran, cmtd, & tstd 7" liner tie back. Performed cmt squeezes. Ran 3-1/2" completion assembly. Pulled 3-1/2" tubing. Performed cmt squeeze. Re-ran 3-1/2" completion assembly w/SSSV ~ 2169', packer set ~ 12,093, tail ~ 12,516'. PBTD = 14,069'. Secured well & RR ~ 1800 hfs, 4/18/85. Item 13: 7" liner tie back, 29.0#/ft, k-80, BTC csg f/9591' - 10,792'. Cmtd w/190 sx C] ass "G". Performed cmt squeeze w/lO0 sx Class "G". Performed 2nd cmt squeeze w/120 sx Class "G". Performed 3rd cmt squeeze w/60 sx Class "G". Item 14: Core #G f/11,394' - 11,415' - cut 21'; recovered 13-1/2' Core #7 f/11,415' - 11,432' - cut 17'; recovered 18' (includes part of Core #6) Core #8 f/11,432' - 11,438' - cut 6'; recovered 4' Core #9 f/11,438' - 11,451' - cut 13'; recovered 9-1/2' Core #10 f/11,451' - 11,479' - cut 28'; recovered 27' Core #11 f/11,479' - 11,504' - cut 25'; recovered 25' Core #12 f/11,504' - 11,528' - cut 24'; recovered 24' Core #13 f/11,528' - 11,552' - cut 24'; recovered 21-1/2' Core #14 f/11,552' - 11,571' - cut 19'; recovered 19' Core #15 f/11,571' - 11,584' - cut 13'; recovered 13' Core #16 f/11,584' - 11,603' - cut 19'; recovered 15-1/2' Core #17 f/11,603' - 11,630' - cut 27'; recovered 12' Core #18 f/11,630' - 11,640' - cut 10'; recovered 11.3' Monthly Report of Drilling and Workover Operations (eont'd) For April, 1985 L1 -9 Item 14 (cont'd) Core #19 f/11,640' - 11,659' - cut 19'; recovered 19' Core #20 f/11,659' - 11,672' - cut 13'; recovered 10.6' Core #21 f/11,672' - 11,702' - cut 30'; recovered 30' Core #22 f/11,702' - 11,712' - cut 10'; recovered 9' Core #23 f/11,712' - 11,735' - cut 23'; recovered 23' Core #24 f/11,735' - 11,759' - cut 24'; recovered 24' Core #25 f/11,759' - 11,785' - cut 26'; recovered 26' Core #26 f/11,785' - 11,811' - cut 26'; recovered 26' Core #27 f/11,811' - 11,854' - cut 43'; recovered 35.5' Core #28 f/11,854' - 11,887' - cut 33'; recovered 33' Core #29 f/11,887' - 11,937' - cut 50'; recovered 50' Item 15: DIL/MSFL/GR f/12,429' - 11,234' BHCS/GR/Cal f/12,400' - 11,085' BHCS/GR/WF f/12,335' - 11,085' LSS/GR f/12,300' - 11,218' DLL/MSFL/NGT f/14,096' - 12,600' LDT/CNL/GR/Cal f/14,098' - 12,915' CBL/CCL/VDL/Signature f/12,585' - 9700' CET f/12,600' - 8950' Dialog casing caliper f/10,712' - surface GR/CCL f/9500' - 14,074' CNL/GR/CCL f/14,075' - 10,300' CET/GR/CCL f/surface - 12,400' GCT f/surface - 12,325' ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 25, 1985 Mr. 3ack Courts Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99707 Dear Mr. Courts: "I-'~, COMM RES i'' .. SL~.T TFC - ST~,T ,. , ,~ CONF~: ........ ?.E' Well Testing at Lisburne, Well This letter confirms our April 22 phone conversation concerning the planned Lisburne well test. During my call I explained that a test separator will be used to separate the produced gas and liquids (hydrocarbons and water). The liquid will not be burned and therefore the chance for generating black smoke is minimaL The maximum expected gas rate during testing is 250~000 SCFD. Several zones will be tested during the next 30 to #0 days. The nature of the test will result in several short flow periods (several hours up to three days) and at other times the well will be shut in. The maximum Btu's that may be generated during the gas flaring is estimated at 10,000~000. During our conversation we agreed that the testing activity must be performed in compliance with existing black smoke considerations and that no additional permits are needed in order to conduct the planned test for the L-l-9 well. It is planned to forward the results of the testing to AOGCC via the "Completion Report" form 10#07. If black smoke is generated we will make a verbal report to ADEC as soon as possible and also provide a written follow-up report. For your information, well testing began on the afternoon of April 22. Should you have a question or disagree with the contents of this letter give me a call at 265-6176. Sincerely, Peter lq. Hellstrom Sr. Environmental Coordinator PNH:jms cc: Blair Wondzell, AOGCC RECEIVED AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompan¥ ARCO Alaska, Inc. ~' ' Post Office Bo~x ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the March monthly reports for the following wells' 1Q-3 2u-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 1 6 Alaska Oil & Gas Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany STATE OF ALASKA CO( ALASKA ~ _ AND GAS CONSERVATION ...vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS .1. Drilling well [] X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 2422' FSL, 2468' FWL, Sec.1, TllN, R14E, UM Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 44' RKBI ADL 28302 ALK 2313 For the Month of. Hatch ,19 85 7. Permit No. 85-1 8. APl Number 50-- 029-21265 9. Unit or Lease Name Prudhoe Bay Unit/Lisbur 10. Well No. L1 -9 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0100 hfs, 01/13/85. Drld 17-1/2" to 4032'. Ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,496'; stuck pipe. Stuck wireline tool ~ 8920' and recovered. Work pipe free; drilled ahead to 11,120'. Fluid loss occurring (~ 10 BPH. Ran & cmtd 9-5/8" csg. Ran log. Drld 8-1/2" hole to 11,292'. Cored f/11,292' - 11,356' (core barrel twisted off while cutting Core #2. It was fished & recovered). Performed DST. Continued drlg 8-1/2" hole to 11,373'. Cored f/11,373' - 11,937'. (see attached sheets) 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40, weld conductor set ~ 110' Instld w/1800# Polyurethane. , · · 13-3/8" 72 O#/ft, L-80, BTC csg w/FS ~ 4002' Cmtd w/3200 sx Perm "E" + 400 sx Class G. , · · 9-5/8" 47 O#/ft, L-80, BTC csg w/FS @ 11,095' Cmtd w/lO00 sx Class "G" , · · · 7" 29 O#/ft, L-80, BTC csg. f/10,788' - 12,600' Cmtd w/8'50 sx Class "G" , · · · 14. Coring resume and brief description Core #1 f/11,292' - 11,297' - cut 5'; no recovery. Core #2 f/11,297' - 11,303' - cut 6'; no recovery. Core #3 f/11,301' - 11,330' - cut 29'; recovered 29'. Core #4 f/11,330' - 11,356' - cut 26'; recovered 26'. Core #5 f/11,373' - 11,394' - cut 21'; recovered 21-1/2'. (see attached sheets) 15. Logs run and depth where run SHDT/AMS/GR f/12,374' - 11,085' Casing Caliper f/10,926' - surface DIL/SP/MSFL/NGT/Cal f/12,327' - 11,085' LDT/CNL/GR/Cal/ML/EPT f/12,419' - 11,085' (CNL/GR to 9800'; GR to 4000') FDC/GR/Cal f/12,362' - 11,085' (see attached sheets) 16. DST data, perforating data, shows of H2S, miscellaneous data RECeiVED DST data will be submitted with Completion Report· APR ! 6 ' 985 · Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~(~ ~[,U.~J-~,_Ji.j TITLE _As_s__oc.i ate_ E_ngi_near' DATE NOTE--ReporlUon/I this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM/MR77 Rev. 7-1-80 Submit in duplicate Monthly Report of Drilling and Workover Operations (cont'd) For March, 1985 L1 -9 Item 12: Drilled f/11,937' - 12,600'. Ran OHL. Ran, cmtd, & tstd 7" liner. Drilled 6" hole to 14,136'TD as of 03/25/85. Ran OHL. Ran 5" liner f/12,427' - 12,136' as of 03/31/85. Item 14: Core #6 f/11,394' - 11,415' - cut 21'; recovered 13-1/2' Core #7 f/11,415' - 11,432' - cut 17'; recovered 18' (includes part of Core #6) Core #8 f/11,432' - 11,438' - cut 6'; recovered 4' Core #9 f/11,438' - 11,451' - cut 13'; recovered 9-1/2' Core #10 f/11,451' - 11 ,479 - cut 28 ; recovered 27' Core #11 f/11,479' - 11,504 - cut 25 ; recovered 25' ~ Core #12 f/11,504' - 11,528 - cut 24 ; recovered 24' Core #13 f/11,$28' - 11,552 - cut 24 ; recovered 21-1/2' Core #14 f/11,552' - 11,571 - cut 19 ; recovered 19' Core #15 f/11,571' - 11,584 - cut 13 ; recovered 13' Core #16 f/11,584' - 11,603 - cut 19 ; recovered 15-1/2' Core #17 f/11,603' - 11,630 - cut 27 ; recovered 12' Core #18 f/11,630' - 11,640' - cut 10 ; recovered 11.3' Core #19 f/11,640' - 11,659 - cut 19 ; recovered 19' Core #20 f/11,659' - 11,672 - cut 13 ; recovered 10.6' Core #21 f/11,672' - 11,702 - cut 30 ; recovered 30' Core #22 f/11,702' - 11,712 - cut 10 ; recovered 9' Core #23 f/11,712' - 11,735 - cut 23 ; recovered 23' Core #24 f/11,735' - 11,759 - cut 24 ; recovered 24' Core #25 f/11,759' - 11,785 - cut 26 ; recovered 26' RECEIVED APR 1 6 Alaska Oil & Gas Cons. Commissiou Anchorage Monthly Report of Drilling and Workover Operations (cont'd) For March, 1985 L1 -9 Item 14 (cont'd) Core #26 f/11,785' Core #27 f/11,811' Core #28 f/11,854' Core #29 f/11 ,887' - 11,811' - cut 26'; - 11,854' - cut 43'; - 11,887' - cut 33'; - 11,937' - cut 50'; recovered 26' recovered 35.5' recovered 33' recovered 50' Item 15: DIL/MSFL/GR f/12, BHCS/GR/Cal f/12, BHCS/GR/WF f/12,3 LSS/GR f/12,300' DLL/MSFL/NGT f/14 LDT/CNL/GR/Cal f/ CBL/CCL/VDL/$igna CET f/12,600' - 8 Dialog casing cal 429' - 11,234' 400' - 11,085' 35' - 11,085' - 11,218' ,096' - 12,600' 14,098' - 12,915' ture f/12,585' - 9700' 950' iper f/10,712' - surface RECEIVED APR 1 6 1985 AlasKa Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc.{ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 13, 1985 Mr. C. V. Chatterton Commissioner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the February monthly reports for the following wells' 17-11 2C-11 2U-1 17-12 2C-12 2U-2 L2-30 1Q-6 2U-3 L1-9 1Q-7 2U-4 2C-10 1Q-8 2w-1 2w-2 2w-3 2w-4 If you have any questions, please call me at 263-4944. Sincerely, ' Gruber Associate Engineer JG/tw GRU5/L18 Enclosures RECEIVED MAR 1 1985 Alask~ Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany - STATE OF ALASKA ALASKA ~.._ AND GAS CONSERVATION CO~[' ~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21265 4. Location of Well atsurface 2422' FSL, 2468' FWL, Sec.1 , T11N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 44' RKB ADL 28302 ALK 231~ 9. Unit or Lease Name Prudhoe Bay Unit/Lisbur 10. Well No. L1 -9 11. Field and Pool Prudhoe Bay Fi eld Lisburne 0il Pool For the Month of February , 19 85 12. Depth at Spudde Drld Work 9-5/8 twi st drlg end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks d well @ 0100 hfs, 01/13/85. Drld 17-1/2" to 4032'. Ran, cmtd & tstd 13-3/8" csg. 12-1/4" hole to 10,496'; stuck pipe. Stuck wireline tool ~ 8920' and recovered. pipe free; drilled ahead to 11,120'. Fluid loss occurring ~ 10 BPH. Ran & cmtd " csg. Ran log. Drld 8-1/2" hole to 11,292'. Cored f/11,292' - 11,356' (core barrel ed off while cutting Core #2. It was fished & recovered). Performed DST. Continued 8-1/2" hole to 11,373'. Cored f/11,373' - 11,785' as of 2/28/85. · Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 110'. 13-3/8", 72.0#/ft, L-80, BTC csg w/FS @ 4002'. 9-5/8", 47.0#/ft, L-80, BTC osg w/FS ~ 11,095'. Instld w/1800# Polyurethane. Cmtd w/3200 sx Perm "E" + 400 sx Class G. Cmtd w/lO00 sx Class "G". 14. Coring resume and brief description Core #1 f/11,292' - 11,297' Core #2 f/11,297' - 11,303' Core #3 f/11,301' - 11,330' Core #4 f/11,330' - 11,356' Core #5 f/11,373' - 11,394' - cut 5'; no recovery. - cut 6'; no recovery. - cut 29'; recovered 29'. - cut 26'; recovered 26'. - cut 21'; recovered 21-1/2'. (see attached sheet) 15. Logs run and depth where run Casing Caliper f/10,926' - surface 6. DST data, perforating data, shows of H2S, miscellaneous data RECEiVE'i,) DST data will be submitted with Completion Report. ~laska Oil & Gas Cona. £;ou'~missk Anchorages 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Rep4t on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR11 Rev. 7-1 Submit in duplicate Monthly Report of Drilling and Workover Operations (cont'd) For February, 1985 L1 -9 Item 14: Core #6 f/11,394' - 11,415' - cut 21'; recovered 13-1/2' Core #7 f/11,415' - 11,432' - cut 17'; recovered 18' (includes part of Core #6) Core #8 f/11,432' - 11,438' - cut 6'; recovered 4' Core #9 f/11,438' - 11,451' - cut 13'; recovered 9-1/2' Core #10 f/11,451 - 11,479 - cut 28 ; recovered 27' Core #11 f/11,479 - 11,504 - cut 25 ; recovered 25' Core #12 f/11,504 - 11,528 - cut 24 ; recovered 24' Core #13 f/11,528 - 11,552 - cut 24 ; recovered 21-1/2' Core #14 f/11,552 - 11,571 - cut 19 ; recovered 19' Core #15 f/11,571 - 11,584 - cut 13 ; recovered 13' Core #16 f/11,584 - 11,603 .- cut 19 ; recovered 15-1/2' Core #17 f/11,603 - 11,630 - cut 27 ; recovered 12' Core #18 f/11,630 - 11,640 - cut 10 ; recovered 11.3' Core #19 f/11,640 - 11,659 - cut 19 ; recovered 19' Core #20 f/11,659 - 11,672 - cut 13 ; recovered 10.6' Core #21 f/11,672 - 11,702 - cut 30 ; recovered 30' Core #22 f/11,702 - 11,712 - cut 10 ; recovered 9' Core #23 f/11,712 - 11,735 - cut 23 ; recovered 23' Core #24 f/11,735 - 11,759 - cut 24 ; recovered 24' Alaska Oil & Gas Anchor'a.(? ARCO Alaska, Inc.{~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are the January monthly reports for the following wells- 6-5 2C-13 2U-13 11-15 2C-14 2U-14 17-12 2E-9 2U-15 17-13 1Q-9 2U-16 L1-9 1Q-10 2w-13 L2-30 1Q-11 2W-14 If you have any Sincerely, Gruber Associate Engineer JG/tw GRU4/L143 Enclosures questions, please call me at 263-4944. 2W-15 2W-16 WSP-4 WSP-8I RECEIVED Alaska Oil & Gas 'Cons. Commlsslor~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllanticRIchfieldCompany STATE OF ALASKA ' ALASKA ~ _ AND GAS CONSERVATION cO!',..¢IISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ['X]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-1 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21265 2422' 4. Location of Well atsurface FSL, 2468' FWL, Sec.1, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 44' RKB 6. Lease Designation and Serial No. ADL 28302 ALK 2313 For the Month of. January , 19 85 9. Unit or Lease Name Prudhoe Bay Unit/Lisbur 10. Well No. L1 -9 11. Field and Pool Prudhoe Bay Fi eld Lisburne 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0100 hrs, 01/13/85. Drld 17-1/2" to 4032'. Ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,496'; stuck pipe. Stuck wireline tool @ 8920' and recovered. Work pipe free; drilled ahead to 11,120'. Fluid loss occurring ~ 10 BPH. Pump LCM slugs and monitor hole as of 01/31/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20" 91 5#/ft, U-40, weld conductor set (~ 110' 13-3/8", 72,0#/ft, L-80, BTC csg w/FS (~ 4002', Instld w/1800# P'olyurethane. Cmtd w/3200 sx Perm "E" + 400 sx Class G. 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE RECE VED 16. DST data, perforating data, shows of H2S, miscellaneous data NONE Alaska Oi~ & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , SIGNED (¢/1~~ TITLE .............. Associate Engineer DATE NoTE-~ReportCn this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM/MR57 Rev. 7-1-80 Submit in duplicate MEMORANOUM State of Alaska TO: THRU: Lonnie C. Smith Commis s ioner ;'/ TELEPHONE NO: Ben LeNorman ~ ~../ SUBJECT: FROM: Petroleum Inspector ALASKA OIL AI~D GAS CONSERVATION CO}R4ISSION 12. V erton DATE: January 23, 1985 F~LE NO: D. BHL. 2 Witness BOPE Tests on ARCO's L1-9, Sec. !, TllN,R14E,IR.I, Prudhoe Bay Unit. Tuesday.p. January 15, 1985: I departed my home at 3:25 pm for a -~55 pm 's'h~wup and 4":55'~m departure via Alaska Airlines, Fit. #59 for Deadhorse, arriving at 7:30 pm. Weather: -30*F, blowing snow. Wednesday, January 16, 1985: Standing by on ARCO's L1-9. Thursdajy, January 17, 1985: BOP'E tests on ARCO's L1-9 began at 9-:20 ~an-d were' C6~Pl~-d at 11:20 am. BOPE inspection report is attached. BOPE tests on ARCO's Kuparuk 2C-13 were completed, the subject of a separate report. BOPE tests on ARCO's Kuparuk lQ-9 were completed, the subject of a separate report.. Friday, January 18, 1985: BOPE tests on ARCO's Kuparuk 2W-15 were comPleted,. the Subje'~'~~ Of separate report. Saturday,~anuary 19, 1985: Standing by on Sohio's Niakuk ~4. Sunday, January 20, 1985: Inspected surface lo~ation of H.G. & G''s abandoned :#'l'~ sag River, the subject of a separate report. Monday, January 21, 1985: BOPE tests ~"n Sohio's Niakuk ~4 were ~bmple'~d],-~e~Subjed~f a separate report. I departed Deadhorse via Alaska Airlines, Fit. #54 at !0:00 am, arriving in Anchorage at 11:40 am and at my home at 12:10 pm. In summary, I witnessed successful BOPE tests on ARCO's DS L1-9. Attachment 02-00IA(Rev. 10/79) " 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Date 1-/7-~ Representative .J~ Well /,~ 7-~ Permit # Location: Sec / Tf;~/ R/+Z~ M g/,~7 .'/,~ >~Casing Set @ zw'oo ~' ft. Drillin~ Contractor ~zz~F_~W~ Rig #/~ Representative ~-~ Location, General ~ ~ Well Sign__~ General Housekeeping (;~ Rig Visual Audio Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N'2~oo,~O~/,~.o~r ~o~ psig Controls: Master psig .~ eOao~ psig rain/~ sac. Remote ~2_Blinds switch cover Kelly and Floor Safety Valves BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R~. Valve Kill Line Valves Test Pressure Upper KellM ~~ Lower KellM ~5-o~ Ball Type ~--Z~o Inside BOP 0--oo,o Choke Manifold ,~~ No. Valves ~~.~ No. flanges Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Check Valve .~/o';'" ~-.,/~-~ Adjustable Chokes Hydrauically operated choke Test Results: Failures ~,~ Test Time ~, hrs. Repair or Replacement of failed equipment to be made within day~ and Inspector/ Commission office notified. Remarks:~ 7-~'--~' ~ ,~7-~f.~ ,~ ,~~ ~--~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor MEM'ORANOUM State of Alaska ALASKA OIL A/~D GAS CONSERVATION COPR{ISSION TO: · THRU: Lonnie C. Smith Commissioner FROM: Bobby Fos t e;'-'~"-~- ~; Petroleum Inspector DATE: January 18, 1985 F,LE NO: D. BDF. 2 TELEPHONE NO: SUBJECT: Inspect Diverter System on ARCO's L1-9, Sec. 1, TllN,R14E,b%i, Permit No. 85-1. .Saturda~vLJ.anuary 12, 1985: I traveled this date to Prudhoe Bay and inspected the ~i%eft'er system on ARCO's L1-9. The system met or exceeded all AP1 RP 53 and AOGCC AAC 25.035(b) regulations. After the inspection, i informed Henry Peterson, ARCO drilling foreman that he could spud-in. He then invited me to attend the pre-spud meetings to be held with the drill crews on site, which I accepted. I was very pleased with the crews, Mr. Peterson and Mir. Ed Bierhower; Parker toolpusher, attitudes as the meetings topics of shallow gas sands, H S gas, rig and personal safety were discussed in a professional li~e mannerism. 02-00IA(Rev. 10/79) ARCO Alaska, Inc. Post Office B~'_. 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 15, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Conductor As-Built Location Plat - DS L1 Wells I & 9 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me.at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L57 Enclosure ARCO Alaska, Inc, is a Subsidiary of AflantlcRIchfleldCompany ~,~ SEC. I~TWP. II N.~ R . 32O 031 30O O29 o2? 26O O25 24O O23 22O 2OO 019 180 017 160 Ot 5 140 '013 120 011 I00 ®9 O7 60 O5 4O O3 2O II ;. LEGEND / NOTES 0 CONDUCTOR AS-BUILT EXIST. WELL FUTURE WELL ALL COORDINATES SHOWN ARE A.S.P. ZONE 4. BASIS OF LOCATION IS MON'S. L-I N. TEMR L-I $. TEMP. PER. FR. BELL B ASSOC. CHK. W.S. DATE I-9-8 § JOB N0.-7163 WGI II CCPt PBUDHOE BAY VICINITY MAP T. IIN NO SCALE ]_1-1 11-9 , CONOUCTO. LOC^T~O..S.~ I .¥=5,974,534.?4 LAT.= 70°20'06.648'' 2448' F.W,L X= 688.579.25 LONG=I48°28'II.857'' 2.183' F.S.L. Y=5,974,774.15 3(= 688,593.84 LAT.= 70° 20'08.998" LONG=148°28' 11.255" 2468' EW.L, 2422' ES.L. ~ RECEIVED JAN 2 1 1985 ~"~.;~,"~ (:'~ ~ ~:~s Cons. C0m~Is~lgrl I D.S.L.I COND.~S. la9 AS-BUILT SHIE' RCO A ska. Inc. ~. o~, J Subsidiory of Atlontic Richfield Compon¥ J NORTH SLOPE DRILLINO-PRUOHOE BA,Y,, ,, January 10, 1985 ~.{r. T. L. Fithian Area. Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit L1-9. ARCO Alaska, Inc. Permit No. 85-1 Sur. Loc. 2422'FSL, 2468'FWL, Sec. 1, TllN, R14E, UM. Btmhole Loc. 2372'FNL, P385'FEL, Sec. 11, TllN, R14E, I1M. Dear Mr. Fithian: Enclosed is the approved application for permit to drilI the above referenced well. If coring is conducted, a brief description of'each core and a one cubic inch size chip from each foot of recover~ed core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). .If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their .drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the'State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereUnder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you.may be contacted by a representative of the Department of Environmental Conservation. Mr. T. L. Fi thia~ Prudhoe Bay Unit L1-9 January 10, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to cor~nencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours2~ C. V. ChR~-~t~rt~n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Lisburne L1-9 Permit to Drill Dear Mr. Chatterton: Attached is our application for a permit to drill Lisburne development well L1-9. Supporting documents and the $100 filing application fee are also included. We plan to set 13-3/8" surface casing at 4000'TVD. This provides an added margin of safety for well control while drilling through the Sadlerochit before setting 9-5/8" casing. I have included a copy of a "Review of Shallow Hydrocarbon Potential in the Lisburne Development Area" in support of setting the surface casing at 4000'TVD. We will use a diverter system while drilling the 17-1/2" surface hole. An "as staked" survey plat showing this well and several other conductor locations on L1-Pad is also attached. A certified survey plat will be sent to you as soon as we receive it. Since we plan to spud this well about January 10, 1985, your earliest approval will be appreciated. This is a "tight hole", therefore please keep all information on this well confidential. If you have any questions, please call Don Breeden at 263-4963 or 263-4961. T. L. Fithian Area Drilling Engineer TLF/DEB/tw PD/L18 Attachments RECEIVED JAN 0 7 1 85 Alaska 0il & .Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ,,,';' ' STATE OF ALASKA ..... ALASKAi~,L AND GAS CONSERVATION C ,,,-MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I--I REDRILL [] DEVELOPMENT OIL I-~X SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 . . 4. Location of well at surface '~ ~'~ (0 7 9. Unit or lease name 2422' FSL, 2468' FWL, Sec.1, T11N, R14E, UM ' Prudhoe Bay Unit/J,~.~.~e At top of proposed producing interval number 1320' FNL, 1320' FEL, Sec.11 T11N, R14E, UM (~ Ta~,l~l~ 0i~ & GaS CONS. , L1-9 At total depth Ai~oho[a~e 11. Field and pool 2372' FNL, 2385' FEL, Sec.ll, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Li sburne Oi 1 Pool RKB 44', PAD 14' ADL 28302 ALK 2313 12. Bond information (s~e-2© AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line '5. Distance to nearest drilling or completed 9-1/2 mi. N of Deadhorse miles 2812' ~ surface feet NGI-14 well 184' (~ 5247'TVD feet 16. Proposed depth {MD & TVD) 17. Number of acres in lease 18. Approximate spud date 13209' MD, 10344' IYD feet 2560 01/10/85 19. If deviated {see 20 AAC 25.050) 120. Anticipated pressures 3450 psig@__80°F Surface KICK OFF POINT 3000 feet. MAXIMUM HOLE ANGLE 47 oI (see 20 AAC 25.035 (c) (2) __5000 psig@ 10300 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' I 30' 110' II 110' 2000# Poleset 17-1/2" 13-3/8" 72.0# L-80 BTC 4005' 30' I 30' 4035'I 4000' 3400sx PF"E" & 400sx "G" I 12-1/4" 9-5/8" 47.0# L-80 BTC 10829' 29' I 29' 10858' ] 8744' 500sx"G" & 300sx PF "C"' 8-1/2" 7" 29.0# L-80 BTC 1351' 10558' II 8540, 11909' I 9459' 300 sx Class "G" 6-1/8" 5" 18.0# L-80 LTC 1500' 11709' I 9323' 13209' ! 10344' 20O sx Class I1(~11 ____ I T 22. Describe proposed program: Alaska, Inc., proposes to drill this Lisburne development well to 13,209'MD (10,3441TVD). A 7" liner will be set across the Wahoo. The well will be deepened to 13,20911vid to test the Alapah. Alternative plans are to test the A]apah by open-hole DSTs or by cased-hole tests after setting a 5" liner. If productive, a long term Alapah test will be conducted through tubing. Approximately 350' of the top of the Wahoo will be cored. An open-hole DST is planned for the top 50' of the Wahoo. Test intervals will be acidized as necessary. A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. The maximum anticipated surface pressure (see attached sheet) .23. I hereby certify that t~e foregoing is true and correct to the best of my knowledge SIGNED '7~_. L./~.~~ .... TITLE Area Dri 1ling Engineer DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number []YES [~'NO []YES C~NO [~YES ~NO 50_0 Z. ~ - 7.,/'Z.~J~-"- -- Permit number Approval date ...- , -~f'-/ ,/'"-h _ 01J/10//85 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY~_/~ ~ ,COMMISSIONER DATE January 10, ~985 Form 10-401 (DEB) PD/PD18 Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL L1-9 of 3450 psig was calculated assuming a full gas column from the top of the Wahoo (4340 psig ~ 8769'TVD) considering temperature and compressibility effects. Selected intervals will be logged. A string of 2-7/8", 6.5#, L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with packer set above the Wahoo. Selected intervals in the Lisburne will be perforated and reported on subsequent reports. Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations. That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. DSL1-9 1000 2000 3000 4000 5000 6000 7000 0 1000 2000 3000 4000 5000 6000 7000 8000 0 20' CONDUCT(: R TVD = 110I ARCO AL~,SKA, IN ~,. I SCALE 1 iI~i. 1 1000 FT. SHL' 2422' FSL, 2468' FWL F SEC.1, TllN, R14E, UM ~op TVD =~OIbA THL ' 1320 ' FNL, 1320' FEL, 2.b SEC.11, TllN, R14E,UM 7.5 17.5 11 37.5 42.5 ~7.1 EOC__TVD- 4679 MD- 4885 DEe- 732 + 8 4s OEG Illll. W 8 6326 FT(TO T ,R ~VERA~E AN( LE ~7 BEG7 MIN ~ K-lO TV~--8~94 MDIR~II8 ~EPI K-6 TVD I 7544 MD I 909'~ DEP I 3817 PUT RIVI~R TVD-8114 ~D--9932 DEl I4431 LCI TVD = 8124 ~ D - 9947 DEP - 4442 SAG RIVI~R TVD-8159 MD-9998 DE =4479 IVISHAK TVD i 825~ MD I 10138 [ EP -- 4582 ~ TVl)-8144 MD = 1085a DEP AHOO T~D--8769 MD .10895 DEP-- 5136 7' CASING TVD = 9469 MD = 11~ 38 DEP -- 6879 ALAPAH TVD I9684 MD- ~092 DEP-8014 TD - 6' CASING TVDIlOi344 MDI132C9 DEP m6832 RECEIVED .. Alaska Oi~ & Gss (;OHS. Oommiss Ancho; age ~ ' , , , , i , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ," 8000 9000 10000 11000 12000 1000 2000 3000 4000 5000 ~ 6000 ~-~ 7000 8000 9000 10000 llO00 0 1000 2000 3000 {000 SO00 8000 7000 V£RT!CFIL SECTION 12000 8000 -7000 CD I -6000 -5000 E - N COOROINR?ES -4000 -3000 -2000 -1000 0 1000 SHL' 2422' FSL, 2468' FWL SEC.1, TllN, R14E, UM "~ 73 THL' 1320' FNL, 1320'FEL, SEC.11, T11N, R14E,UM i z~4 TARGET ~ /~ TVD= 8944' TMD= 11152' DEP= 5325' , i , i i i i i i ii i i i i i i i i, i , i ! i i i ii i ~ i i i , ~ ii i i T i i i i ii i i i i i i : ii , i , i i i i ii i , i i ii i i i -~ooo -~ooo -~ooo -~ooo -~ooo -~.ooo F~'~C E iV EiD ~o El - N COORDINF~?FiS ~.,]aska 0i~ & Gas Cons. Commission AnchoraQe 0 {' ,( L1-9 F~ - W COOROINF~T£5 -7ooo -6ooo -sooo -,~o o o -3ooo -2ooo - i ooo o i ooo J i ~ J i I ~ i ~ ~ ~ i ~ i i i i ~ ~ ~ i I I I I i I i i ~ ~ i i ) ~ i ~ ~ ~ i ~ i i ~ I I I [ [ I I I I J I I ! I I I i I I I I I I I I I I ~3 NgI-E '"%,8 2~ ~760~ ~~99 , ~ ~ .... RI CEIVE[} ,,, ,, , , Alaska, Oil i Gas Cons. Cot mission Anchorage -7000 -6000 -5000 -~000 -3000 -2000 - 1000 O 1000 E - N COORDINflT~S Q -- 0 :? '-1 5 I E - 1,4 COOBOT. NRTES -6000 -5000 -dO00 -:30,20 -2000 -i 000 0 _ ,1.0,130 i i i i I I I I II I . ~ , , ,. ,. i , ~ , ~ , i i i i I I I I I I I I I.~ I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ I , . ' I I I NGI-9 767 NGI-1 56 N61-10, 689!7 NGI- ,1~81 o "'-7351 ° ' Y22 $z151 , 0 ' RECEtVED CD ~ AlasKa Oil $ Gas (;on ;. 6omrnlsulun ^nchorao -7000 -6000 -5000 -d:O00 -3000 -2000 -1000 0 1000 E - H COORBIN~TE$ z -7000 z o -7000 -6000 -5000 -4000 -3~300 -2000 - 1000 0 1000 0 ,, ,,, · , , , ..... , --, , , I I I I t i i , , , ,, , , o~ ' ................................... ~ ......... I ~75z] 1 ' ;zt61 6 73 ' 722 ~451 8854 I CD - I ! [ I ! ] [ [ I I [ [ I I I ] [ I [ I I ] I I I I I [ I , i , I I [ I [ ] ! , [ ] i i , i ~ i i i i i [ i I ] I , [ I [ I I ] I I I I I I ] -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 £ - N COORDIN~T£S ~'~ ,, .- , Anchorage, ,. E - IA COOROINFITE:~,,, o -1600 -1500 ( -14~00 -1300 -1200 -1100 -tO -900 C~ I I I I I I I I I I I I I I I ~ I I I I I I I I' I 252~3g[i9 / NGI 14~~~ 5205 ")~ o Li-~ 291 ~ ' ~900 4~85 / t27 /~ / 56~ d5 ~ 563;~ 5700 . '961 ~' i I i i i i i i ii i i i i i i i i i i , I i i 1 ' i -1600 -1500 -1~00 -1300 -1200 -1100 -tO00 -900 E - N COORDINRTES R[C[~VED ..... ,..,,, o '7 1985 Alaska. Oil & Gas Cons. Cornmissior~ Anchorage .: MAP -,~':~., 2~0 019 017 160 015 011 05 4O 2e el ;, I LEGEND / NOTES CONDLICTOR AS' STAKEO £XIST. WELL. O FUTURE WELt. ALL COORDINATES $1'IDWN ARE A.$,P. ZONE: 4. BASIS OF LDCATION IS MON'S. L'I I:1 5. TEMP. F~:R. F.R. 8£L1,. A ASSOC. * L I"t Y=§,974,554.60 - LAT.=70°20'06.6464'' 2448' F.W.L. X= 688,579.07 1..0N~.=14802..8'11,~165" 2185' ES.L,. LI'2 Y--5,974,5 55.86 L AT.=70020'06.7921" ~' 624' F. W,I- X~ 688~755.57 L. ONG.=I48'e28'06.696' 2 198' F.. $.L. LI'8 Y=5,974,733.51 LAT.-' l'Oe ~-'0' 08.5558'' 3640' EW.L. X= 688, 766,55 LONG;I48421~O~,245" ~.$77' ES,L. LI-9 Y=5,974,?74.14 688,595.72 LAT.= 70020'01~9980" 2468' k";W. L. I.-DNG .= 148028' I 1 · 2-'.'."~" 242~' LI'IO Y, ~'~74,795,40 L AT., 7'0 0~0'09..14~,?' 2645' F.W.L. X = 688,770.22 L.~NG= 148e28°06.092' 2457' ES, L. L.I-14 Y-5,974,915, 16 LAT=70%~'IO.$194' 2656' F.W.I.. X= 688tT77.54 I.DNG.=i4.Se28'05.790" 2555' F.$.L. RECEIVED JAN 0 7 lg85 Alaska Oil & 6as Cons. Anchorao~ or=a. j. 8, CHK. J.s. O~tll I-2-85 NO. ?16~ D.$ L-I COND. NO S. 1,2,8,9,10,14 AS STAKED I NORTH SLOPE DRILLtNG-PRUOHOE BAY · . [ ',-I 80: [ [ '-iS...'",.~O.,." l,:} [40 ~1.4 SURFACE HOLE DTVERTER SYSTEM SCHEMATTC ARCO ALASKA ~NC'. I0" HYD. OPR. BALL VALVE V~ELL 80RE (SEE DETAIL) / /~-'-' I0" HYD. OPR. BALL VALVE / // ~ ALL 90° TURNS ARE "TEE" ~ I CUSHZO~ _1 ~LL RESERVE PIT AREA NOTE · FLOWL INE DR ILL lNG RISER F 20" 2000 PSI V~P ANNULAR PREVENTOR ~'~DIVERTERLINE~/~'~ , SPOOLi L'V~ E J Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE / IO" HYDRAULIC OPERATED BALL VALVES "DETAIL" 2026O10203 RNNULJqtq m PREVENTOR 13-5/8" BOP STACK DIAGRAM PIPE R~MS BLIND RAMS DRILLING SPOOL PIPE RRMS .11. 12. Accumulator Capacit7 Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the ti~ and pressure remaining after all units are closed with charging pump off. 4. R~cord on IADC reporz. (The acceptable lower limit is 15 seconds closing time and 1200 psi renmining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing 1 iquid. 2. Check that all hold down screws are fully retracted. Hark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. · $. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of 5 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimim~m of 3 minutes. Bleed pressure to zero. 7. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes, Bleed pressure to zero, 8, Close valves directly upstream of chokes and open chokes., Increase pressure to 5000 psi and hold for at least 3 minutes, Bleed pressure to zero, 9, Open top set of pipe rams then close bottom set of pipe rams, Increase pressure to $000 psi below the bottom set of pipe rams and hold for at least 3 min- utes, 10. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe ral~s. Back off .running joint and pull out of hole. Close blind rams and test to S000 psi for at least 3 mir~tes. 13. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling pos it ion. 14. Test standpipe valves to S000 psi. 15. Test Kelly cocks and inside BOP to S000 psi with Koomey pump. 16. Check operation of Degasser. 17. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. 18. Perform complete BOP£ test once a week and func- tionally operate BOPE daily. JAN 0 ? i1985' A,!aska O~t & Gas~, Cons. Anc. orage Revised 2/21/8¢ ARCO Alaska, Inc. Subject: In(~rrml Con'~ponc~ ~ October 22, 1984 Review of Shal low Hydrocarbon Potential in the Lisburne Development Area From/Location: To/Location: M. R. Werner ATO-IO00 D. T. Owens AT0-1048 I N'FRODUCTI ON At the request of Don Breeden (Drilling), the potential for shallow hydrocarbons in the Lisburne development area has been reviewed. Drilling proposes to set surface casing in the Lisburne development wells at approximately 4000 feet TVD. This is significantly deeper than that permitted by the existing Prudhoe'Bay Unit field rules (2700 feet TVD). Shallow hydrocarbons would impact this proposal with possible adverse effects on Lisburne drilling costs. The question of shallow hydrocarbons probably will have to be reviewed with the AOGCC in order to establish Lisburne field rules favorable to surface casing depths of 4000 to 5000 feet TVD. DISCUSSION The available data from the Shallow Sands (West Sak and Ugnu sands) in the Lisburne development area indicate there are no significant hydrocarbons present. However, this corresponds to depths between -5600 and -7500 feet subsea. It was necessary to review in more detail the available surface logs and mudlogs in the area to evaluate the shallower sands and gravels which comprise the Sagavanirktok Formation (Figure 1). The wells and area of review are shown in Figure 2. The method of review consisted of examination of the resistivity log and mudlog if available. The resistivity log is a reasonably accurate indicator of oil in this area since the sands contain relatively saline connate water (estimated at greater than 30,000 ppm NaC1 equivalent). This results in deep resistivity readings in the water sands of one to four ohm-meters. Readings greater than this, which would indicate significant oil saturation, were not observed in any sands between the base of permafrost and 5000 feet MD. The mudlogs were checked for indications of gas or oil in the mud and cuttings. From surface to the K-15 marker (Figure 1) in the wells reviewed, there are no significant indications of oil. Small concentrations of methane gas were noted to occur in some water sands, but this is common in shallow water sands in both the Kuparuk River and Prudhoe Bay Units and is believed to be biogenic in origin. ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldComplny AR3B-6001 RECEIVE Alaska Oil & Gas The intensity of methane shows increase at the K-15 marker. The K-15 marker is defined as the top of the first significant coal bed. The subsea depth of the top of this marker is shown in Figure 2. Although it is not necessarily the same bed from well to well, this marker occurs consistently within a distinctive package of sands from Kuparuk east across the entire Prudhoe Bay Unit. The presence of coal is demonstrated by the response of the resistivity and sonic logs and confirmed by the description of cuttings from the wells. Coal beds 5 to 10 feet thick are common between the K-15 marker and the top of the upper Ugnu and are clearly the principle source of methane in this part of the section. Indications of oil in the mud such as bitumen (tar), oil stained cuttings and sample fluorescence also are more common below K-15. These shows still are not indicative of substantial amounts of oil, but the section below K-15 is more oil prone based on our knowledge of the equivalent sands in the Kuparuk area. CONCLUS I ON The top of the K-15 coal (Figure 2) is a convenient marker, and is below -4500 feet subsea in the area reviewed. It is recommended that the top of the marker be considered a maximum depth for setting the surface casing shoe in planning the Lisburne development wells. Above this there are no obvious or significant hydrocarbons based on the data reviewed. Below K-15 no significant amount of oil is believed to occur, but methane is more abundant. If you have any questions, please contact me at 6191. M. R. Werner Senior Geologist MRW1/vgm CC: D. E. Breeden AT0-1458 L. E. Okland AT0-1052 File IKRIOD Z 0 0 0 K 12 GENERALIZED STRATIGRAPHIC SECTION DESCRIPTION PERMAFROST: Interbedded gravels, sands and shales. K-15' First coal marker underlain with sands, silts and shales. Localized coals occur within this interval. UPPER UGNU' Interbedded coarse to fine sands and shales. LOWER UGNU' Interbedded coarse to fine sands and shales. WEST SAK SANDS' Interbedded fine-sandstones, siltstones, and clays. K-12' Interlaminated silty mudstones and shales with minor ~ .F_CEtV?.~ty sandstones. Based on data from: ARCO J/'.,!~,~ 0 '? 1~5 West Sak River State #1 FIGURE I ABEL 5T · -4860 -494§ W BEACH Z · -4864 · ~ · B~¥ SI I · ~89 ?RUDHOE BAY } · -4685 . PRUDHOE AY H POINT SO BAY '0 -4884 IT STRUCTURE TOP K-15 MARKER FIGURE 2 0 ,.I AK UK I A 6 x-Jr- -1L-PINGUT 5T I · -5048 , · ii 4-_~4Bi, 4 · ! -551 I-I§ 155 · f CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS (8) (3) Admin 9. (9 thru 12) j 10. (10 and 12) 12. (13 thru :21:) (22 thrM' 2'6) Aaa: 1. Is the permit fee attached .......................................... ,/ 2. Is well to be located in a defined pool ............................ ' 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... ' 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ..........................__ 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Does operator have a bond in force ................................. Is a conservation order needed ........... Is administrative approval needed .................................. Is the lease number appropriate ..................................... ~,,.,'" / Is conductor string proVided ........................................ Is enough cement used to circulate on conductor and surface ...... '. Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons .................. ~'~/ Will surface casing protect fresh water zones ............. .. Will all casing give adequate safety in collapse, tension and burst.. Is this'well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is diverter system required ' Are necessary diagrams of diverter and BOP equipment attached ...... f~_~.~ Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ~// Additional requirements , , ,, Additional Remarks: : ,( Geology: X LCS WVAz~ JKT JAL ' .~.. ~ __ rev: 10/29/84 6. CKLT Engineering: ' BEW ~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. 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H A 'i" 'r ...,n, ~ -~'- "'" Fi M i:' I::' N .C:; A T .':: TI :"'""" ...... '"::"'l..,.,f'.i ," l:.:'Tti-,..' ) .:-'..':. ...................... !".:' c.L..-' I I'.'.. IJ I:~Fi '" .'. ....... .~. ~ ,'i .... D ~b i .)~ j...',";"t i'"~ '"TV F: Fi i'".; l::' F:' !'-'" ~i!i; /.-i 'i" ji:_' )~) i ...""~':' F~ ¥',c,'., ..':(. ~:' - .,: L, Pi~~.[.Ji!i:: ~.'. .):..'. ..'K. -"': "'I :::~ '": F' :'.~1 -"": · :"." .'..,L,r,l" c.F...:::.-~...'.: I::.:.., .............. NFl i 'i" .r;: ri i"--.! I...PFi, ... .... CA~;I.Z¥''....., .................. i..i,""I! I::' ( i::'i"i,"".' ) .:,.'.: · )e ')(- l::. :... ;.! · JOB NUi'fiBEF;..' A'" ACC: 70'.567 F;..' i t i"-! :i~: 2 .., .... ~'~'~ 'i" E --~.I: ):'i F:, ', L.. ;'.'-'----~H ~r-', x, ;::' v f....-; ,..: ·: :: ~ -.~ : :!.:2:5(.:,,.'.':."- ~.) J..'-- .:::-' .L ..:'.. 1-'-'. "~' i.-~ , LJ .I. '*~' .L -.7.~ i:): : I ~ ~ ,~., ! ~ .... ., ,1, .,..- '-' ~! t-'i i~ i ..,,I !.., I"! I "~ ....,i :0 F.i: N ::.~i; :I: 1" Y :::: 9 ,, 7' L.. B / G R M '.:':: ,, 56:3 67 ,, 0 'V '~' SC OS .'i,': T ].,. ...... - ,-~- ~'.:::, _.. ,"'~.., S i.';-..'M F '.'.", ':::', ...":~;_ ~ ... ~___ 67~~.~ '67,0 FL.:U]::O LC)SS - ,~. ,.-.-,.-..*.-.:. : ~ : :~:.,~.,~ ~.r '~,~..~:~r: :: .... ;.~,'~ J. 82.,, 3 !:t t i::: :: :: : :: :( ::::: i c: i :t:t; f:::::: :::::: :' :?C: :,::: Cl.::.:: ::ii :::::::: : ;:. t].:.' ....... F:; F; .... -.:.."' '"''....-- ;'"....- ~-" !:q ~ :::~ (~ i;:'" .._ ?, ?~ c>... '.'::" F:; .,"'~ ";' '"-' .._ ,.';: c', c:, ? ~:.~ i[ ,::> c:, ,::, ..................... bc, r.. · ,. , ,, 0CAL. '"', , , ,, 250 F:' 0 'i" A_ c.:,, ,::,, .-:::,,., ,,.."'~ ':::,.: :"',, F:' 0 .... { ~..,~ .... c:,, c.'., ,"',v, 2 5. 0 'i" {"l 0 R_. c:,, c,..:.. .-" ,.:... ......... :::' 5 '"'" LJ F..' A N_.. c:,, c,',, ,:::,,. 2 .~:; ..... ':") (i.~ R ..- ? 9 <? ') !::; ('.': l-.' .;'bi J T .... -'::.-~ (.;' q.:, ? !:-': ..."~ j'{, LI ."~ }{.~ .... g '";" '":) q"' ~::i {~ ¥'1 I;' M .,"'i .... 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OSn() . o 9 a. ? fin 0 :,i 5 f'-~ G -99g.7500 POTA -q9q.25oO CA!~I -~99. 2500 CR -OgO. 2500 CR 53.~4]0 ~JPHi -99o.250o ¢,2NG -Ogq. 25n0 -o90.25n0 [.i[.P -090. 250o SGP, -090.9.500 -999. ~500 -n9q,~50O SGR -q99, ~500 P()TA -999. 9500 CALI -~9q,9500 GR 5~.]867 -990.~500 -099.2500 LIjD -090.7500 CR -090.7500 NC~L -099.250o SGR -a9g,250U P[J~A -09q.~500 -9g~.7500 53.76~7 -~9q,950~ W2~G -o90.2500 Lbf~ -g9n.25n0 -09o.2500 UR -qgg,?5'~0 ~fRAT -n9~,25o0 ~'CNL -q9o.g500 SGP -990.~500 -qgn.95D0 CArpi -o9q.2500 -o9o.~500 mR -qgq.~bO0 CR 250;) -099,2500 -99q.2500 -999.2500 -099.2500 -999.2500 -qgg.~500 -999o~500 -qgo,~5o0 -o90.7500 -990,2500 -999.9500 -990,7500 -999.~500 -qgg.2500 -099.2500 -999.2500 -999.7500 -999,~500 -990.250O -099.2500 -099.~500 -999.25O0 -999.2500 -g99,2500 1090.2500 -099,~500 -o90.2500 -099.~5o0 -99~.~50o -a99,25o0 -~gq.~5oo -999.25no -990.25oo -q99.2500 -o9g.2500 -990.~500 -q99.2500 -o9o.2500 -099.2500 -99q.~50U -q9q.2500 -ggg.?50O -g9g.~Sf)O =990.2500 CGR TNOR RHOB CALI ~ATT LbS CALl CA[,I CGR THOR RHOB CALI ~ATT NCNb W3~G LbS CALl CALl FCNL CG~ THOR RHOB CALi ~ATT NCNb W3NG l{99,2500 -~99.2500 -999.2500 99,2500 -999o2500 -099°~500 -990°~500 -990.2500 -9gg~ 5,0 -~99 ~500 - o2 5oo 099 2500 -ggg'2500 -999~2500 -Q99.~500 -999,~500 -999°~500 -999.2500 -999,250o -999 ~500 -999 2500 -999 2500 -999 2500 -999 ~500 -999,~500 -999.2500 -999.~500 -999,~500 1999,~500 -999,~5~0 '99g,~500 -O90 2500 -O99.2500 -ggg 2500 -099' .2500 -999°~500 -99q,2500 -qgq,2500 -999.~500 -999,~5o0 -999.2500 -099.7500 -999.95o0 ~ P CAT, ~ '~' _t 'q V 9 T T: i;'. 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LVP OI~.HOZ VERIFIgATION LISTING PAG~ i ~-~ REEL HEADER SERVICE NAME DATE :85,/'06,/25- ORIGIN REEL NAM~ CONTIN~AT I:,2N PReViOUS REEL CDMMENTS : ~* TAPE HEADER SERVICE NAME :GCT DATE ORiGIN TAPE NAME :05:12 CONTIN~ATIgN ~ PREVIOUS TAPE COMMENTS: **,FILE HEADER FILE NAME :GCT SERVICE NAME VERSION ~ : DATE:: MAXIMUM LENGTH FiLE TYPE PREVIDU$ FILE 102~ ~, iNF3RMATION RECOROS~ MNEM CONTENTS ~NIT TYPE .CATE SIZE CODE C:N : ARCO ALASKA INC 000 WN~ : LISBURNE :L1-9 000 FN : LISBURNE UNIT 000 RANG: tAE 000 TOWN: 11,~ 000 SECT,: 1 000 COUN: N. SLOPE 000 STAT: ALASKA 000 CTRY: US~A OOO MNEM CONTENTS ~NIT TYP~ 000 015 Ob3 000 013 065 CO0 013 0~5 000 0~3 055 000 003 055 000 OOl 065 000: 00~ 065 000 006 065 000 003 Ob5 CATE SIZE CO~E PRES: E 000 000 001 K~ 'COMMENTS ~, 005 LVP 010oHOZ VERIFICATION LISTING~ PA-~E Z SCHLUMSERG~R ALASKA COMPtJI'IN~CENTER COMPANY = ARCO ALASKA, INC. WELL = Ll-9 FIELD = LISBURNE ~ COUNTY = NORTH SLOPE ALASK~ = ALASKA JO8 N?-JMSER AT .ACC: 70512. RUN #ONE~ DATE LOGGED: lO-APR-SS LOP: STEP~AN F. STEVENS AZIMU1.H OF PLANNED VERTICAL:PLANE: S ~5 gfG Zl* W: SURFACE LOCATION: Z&22' FSL~ 2~68' F~L, SEC [, T.[IN, R14E,-UM TIE IN: THIS LISTING IS TIED ~TO SPERRY SUN SURVEY DATED gl-APR-85 GYRO -CONTINUOUS TOOL CGCT) ~ I LVP OlOoMO2 VERIFICATION LISTING PAGE 3 ~ DEFINITIONS: ~ ; HLAZ: AZIMUTH ~ DEVI: DEVIATION ~ GDEP= GYRO DEPTH ~ VDEP= TRUE VERTICAL DEPTH ~ NSOR: NORTH OR SGUTH DEPARTUR~ ~ E:W~R= ~AST OR wEST DEPARTURE ~ OGL = DOG LEG (CURVATURE:OF TH~ WELL) ~: DATA FORMAT REC.-DRD ~NTRY TYPE SIZE 4 8 t6- 0 DATUM SPE:CIFICATION BLOCKS REPR CgDE 66 ENTRY 255 60 .lin MNEM SERVICE SERVICE ~NtT API A~I APl APl FILE SIZE SPL REPR ORDER ~ OEPT FT GDEP LOS FT VDEP LOS FT HLAZ LOS DEG OEVI LOS DEG NSDR LOS FT ~W~R LOS FT. OGL LOS FT PROCESS LOG TYP~ CLASS MOD NO. 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