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Home My WebLink About185-306 • . bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 StAMED AUG 02 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 66-5-306 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Lisbume 3 L' Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659- 5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) GPMA Lisbume 3 Date: 03/08/2012 Corrosion I Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date L3-01 1890750 50029219590000 0.0 WA 0.0 N/A 10.20 11/29/2011 L3-02 1661540 50029216440000 0.0 N/A 0.0 WA 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-08 1831430 50029210190000 3.0 WA 3.0 N/A 27.20 11/29/2011 L3-11 1852310 50029214520000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-12 1861610 50029216510000 Dust Cover N/A 0.0 N/A N/A 3/8/2012 L3-15 1852660 50029214760000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-18 1861670 50029216570000 0.0 N/A 0.0 WA 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-22 1861750 50029216630000 0.0 N/A 0.0 N/A 10.20 11/20/2011 - L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-24 1861820 50029216700000 0.0 WA 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 P&A 12/93 NA NA NA NA NA L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-31 1860340 50029215440000 0.0 N/A 0.0 N/A 8.50 11/29/2011 • U ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv nnectinnc nlPace rnntart Tna T aet„flr~ ~r !~(l'71G~n nnni Date 12-16-2008 Transmittal Number:93026 _ ~_ .,.. Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion 3-23 09-08-2008 HALLIBURTON 1 10964 11476 PRODUCTION PROFILE WITH MAPS L3-23 09-08-2008 HALL~BURTON CD-ROM -PRODUCTION PROFILE WITH MAPS L1-09 10-20-2008 HALLIBURTON 1 11016 11869 PRODUCTION PROFILE WITH MAPS L1-09 10-20-2008 HALLIBURTON CD-ROM -PRODUCTION PROFILE WITH MAPS L5-36 09-12-2008 HALLIBURTON 1 11748 12120 PRODUCTION PROFILE WITH MAPS L5-36 09-12-2008 HALLIBURTON CD-ROM -PRODUCTION PROFILE WITH MAPS L5-32 09-09-2008 HALLIBURTON 1 0 9615 PRODUCTION PROFILE WITH MAPS L5-32 09-09-2008 HALLIBURTON CD-ROM -PRODUCTION PROFILE WITH MAPS LS-24 12-05-2008 HALLIBURTON 1 10110 10640 PRODUCTION PROFILE WITH MAPS L5-24 12-05-2008 HALLIBURTON CD-ROM -PRODUCTION PROFILE WITH MAPS ~~ ~ J ;i ~ ; ~__ Please Sign and Return one copy of this transmittal Thank You, Joe Lastufka Petrotechnical Data Center 1 ~~ - ~c<~ ~~~~~~ ~ BPXA ,. ~, r Exxon ~~ ~ ~ ~ ` ~ DNR AOGCC Analisa Clopton File Room Kristin Dirks Christine Mahnken Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA iP~ A~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS t'.'.! ~ ~. ~ 2008 _~;~; ~.~ns. Commission -~~-n 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 185-308 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21513-00-00 7. KB Elevation (ft): 51.0 9. Well Name and Number: L3-23 8. Property Designation: 10. Field /Pool(s): ADL 028322 Prudhoe Bay Field / Lisburne Pool 11. Present well condition summary Total depth: measured 11900 feet true vertical 9571 feet Plugs (measured) 11509' Effective depth: measured 11852 feet Junk (measured) None true vertical 9533 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4021' 13-3/8" 4021' 3847' 3450 1950 Intermediate Production 10993' 9-5/8" 10993' 8893' 6870 4760 Liner 1142' 7" 10756' - 11898' 8735' - 9569' 8160 7020 ~'~lN~ S ~ 1' ~ '~ 2008 Perforation Depth MD (ft): 11050' - 11460' Perforation Depth TVD (ft): 8932' - 9229' 3-112", 9.2#, 13Cr-80 10995' Tubing Size (size, grade, and measured depth): 2-718", 6.5# L-80 11493' - 11522' Packers and SSSV (type and measured depth): 7" x 4- 1/2" Baker S-3 Packer, 10885' 7" x 2-7/8" Baker DB Packer 11493' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 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 NIA if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed Nam Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si ature Phone 564-4750 Date `~f° ondra Stewman, 564-4750 Form 10-404 Revised 0412006 ~e Q I Submit Original Only ~~ ~ ~~! ~! 1M.~ ~~~13 TREE= McEVOY WELLHEAD = McEVOY ACTUATOR = - AXELSON KB. ELEV - BF. ELEV = 51.4' KOP = 2700' Max Angte = 49° @ 10900' Datum MD = 11078' Datum TV D = 8900' SS DRLG DRAFT L3 ~~ ~ • SAFETY NOTES: H2S PPM 35 2181, 3 1/2"XXO Npl w/ dmy packoff(1.75} I. 2.813" GAS LIFT MANDRELS 13-3/8" CSG, 68#, L-80, ID = 12.415" ~-~ Minimum ID =1.812" @ 11509' 2-7/8" AVA NO GO NIPPLE 9-5/8" X 7" BOT LNR HGR ~-~ 10742' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3422 3008 21 MMG DCR RKP 1.5" 07!27/08 3 5500 5002 43 MMG DMY RK 1.5" 07127108 2 8512 7087 45 MMG DMY RK 1.5" 07127/08 1 10582 8613 45 MMG DMY RK 1.5" 07127108 10$62' -~ 3-112" HES X NIP, ID 2.813" 10$$3` 3-1t2" x 4-112"CROSSOVER, ID 2.992" 10$85' 7" X 4-1l2" BAKER S-3 PKR, ID = 3.98" 1 pggg' 3-1/2" x 4-1/2"CROSSOVER, ID 2.992" I3-112" TBG, 9.2#, 13Gr-8{t, .0087 bpf, ID = 2.992" ~ 10995' 9-518" CSG, 47#, L-80, ID = 8.681^ 10993' 10910' 3-1/2" HES X NIP, ID 2.813" 10972' 3-1/2" HES XN NIP, ID = 2.75" 10995' 3-112" BAKER WLEG, ID = 2.905" PERFORATION SUMMARY REF LOG: LDT/CNL ON 02/06/86 ANGLE AT TOP PERF: 47° @ 11050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz Date 4" 4 11050-11156 O 02/25/86 4" 4 11190-11322 O 02/25/86 11493' 7" X 2-7/8" BAKER DB PKR, ID = 3.25" 2-118" 4 11360-11460 O 04/03/86 4" 4 11528-11684 C 03/30/86 8 11509' 2-718" AVA NO GO NIP, ID = 1.812" W/PLUG 03/30/86 2-7/8" TTP-IPC, 6.5#, L-80,.0058 bpf 11522' 11523' 2-7/8" BAKER WLEG, ID = 2.41" PBTD 11852' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 11900' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 02/28/86 ORIGINAL COMPLETION 03/04/07 RL DATUM MD WELL: L3-23 12/19/00 SIS-QAA CONVERTED TO CANVAS 07127108 Haberthur Recompie#ion ! RWO PERMff No: 1853060 03/13/01 SIS-MD FINAL API No: 50-029-21513-00 11/25/01 CH/TP CORRECTIONS SEC 22, T11 N, R15E, 934' FNL & 679' FWL 10/06/02 DMB/KK GL MANDREL CORRECTION 10/08/02 DMB/KK SET CIBP BP Exploration (Alaska} Start: 7/7/2008 Rig Release: 7/27/2008 Rig Number: BP AMERICA Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task --- . Code NPT Page 1 of 14 Spud Date: 7/7/2008 End: 7/27/2008 Phase Description of Operations • 7/7/2008 10:00 - 12:00 2.00 RIGD P I PRE 12:00 - 00:00 12.00 RIGD P PRE 7/8/2008 00:00 - 16:00 16.00 RIGD P PRE 16:00 - 00:00 8.00 RIGD P PRE 7/9/2008 00:00 - 12:00 12.00 RIGD P PRE 12:00 - 00:00 12.00 RIGD P PRE 7/10/2008 00:00 - 12:00 12.00 RIGD P PRE 12:00 - 14:30 2.50 RIGD P PRE 14:30 - 15:30 1.00 RIGD P PRE 15:30 - 17:00 1.50 RIGD P PRE 17:00 - 00:00 7.00 MOB P PRE 7/11/2008 00:00 - 02:30 2.50 MOB P PRE 02:30 - 10:30 8.00 MOB P PRE 10:30 - 23:30 13.00 MOB P PRE 23:30 - 00:00 0.50 MOB P PRE 7/12/2008 00:00 - 02:30 2.50 MOB P PRE 02:30 - 06:00 3.50 MOB P PRE 06:00 - 08:30 2.50 MOB P PRE 08:30 - 12:00 3.50 RIGU P PRE 12:00 - 14:30 2.50 RIGU P PRE 14:30 - 16:00 1.50 RIGU P PRE 16:00 - 18:00 2.00 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 22:00 3.00 WHSUR P DECOMP 22:00 - 00:00 I 2.001 WHSUR I P 3/2008 100:00 - 01:30 I 1.50 ~ WHSUR ~ P 01:30 - 03:30 I 2.001 WHSUR I P -PJSM on skidding rig floor -Started to skid rig floor to moving position. Had incident with drip pan flow line cover falling from drip pan into cellar. -Stop skidding operations for incident investigation Safety stand down pending incident investigation Safety stand down pending incident investigation Wait on rig Doyon-16 move. Cont. waiting on rig Doyon 16 move Cont. waiting on rig Doyon 16 move Cont. waiting on rig Doyon 16 move -Skid rig floor to moving position Install front booster rack and boosters Move rig off well 12-31 and position on pad -Remove BOP stack from cellar -Install back boosters Wait on rig mats to be set on road for rig move Wait on rig mats to be set on road for rig move Move rig f/ DS 12 to PBOC Park rig by PBOC. Wait to move rig mats out in front of rig Cont. moving rig Cont. moving rig to DS 4. Cont. moving rig to L3 pad. Spot rig on pad. -RD front and rear boosters -Bring BOP stack in cellar. PU mouse hole -Hang cellar doors -Extend conveyor -Hook up hydraulic hoses to BOP stack Wait on site preparation around tree LD herculite around well and set rig mats -Position rig on well L3-23 -Shim rig -Skid rig floor to drilling position -Spot and berm rock washer -Pull BPV. Tubing on vac. -RD lubricator SIM OPS: Spot and berm tiger tank. RU hard line and choke manifold DECOMP -Spot Schlumberger slick line unit -Mobilize equipment to rig floor -Start RU slick line DECOMP -RU lines and valves to tubing and IA for bullhead. Install secondary valve on IA -Check hard line w/air. OK. Test w/ water to 3500 psi. Good test. Blow down lines -Bleed off IA to tiger tank f/ 30 psi to 0 psi. Monitor IA. No more pressure build up. NOTE: Schlumberger looking for additional lubricator extension to finish RU slickline DECOMP -RU slickline equipment: lubricator extensions, pump in sub, BOPs and lubricator. Printed: 8/21/2008 1:55:17 PM • Operations Summary Report Page 2 of 14 Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To j Hours Task !Code ~, NPT `, Phase Description of Operations 7/13/2008 01:30 - 03:30 03:30 - 04:00 04:00 - 05:00 2.00 0.50 1.00 WHSUR WHSUR WHSUR P P P DECOMP DECOMP DECOMP -Test to 500 psi x 5 min on chart. Good test Run 2.53" drift on slickline to 2210' SLM. Locate SSSV. R SSV ~ 2210' SLM and set same. 05:00 - 06:00 1.00 WHSUR P DECOMP RD Schlumberger slickline 06:00 - 06:30 0.50 WHSUR P DECOMP -Spot trucks w/ additional seawater. -Prime pumps and prepare to bullhead. -Open IA to tiger tank. No pressure. 06:30 - 09:00 2.50 WHSUR P DECOMP Bullhead 1140 bbls seawater down tubing and IA ~ 9 bpm. Observe no pressure at wellhead level while bullheading 09:00 - 10:30 1.50 WHSUR P DECOMP -Cameron Reo. drv rod TWC -Test f/ above to 3500 psi x 10 min on chart. Good test -Pump down IA ~ 8.5 bpm x 10 min without pressure build up at wellhead level. Verify no leaks by TWC while pumping down 10:30 - 11:00 0.50 WHSUR P DECOMP -Bleed off and blow down lines. -RD hoses and valves -Suck out tree 11:00 - 12:00 1.00 WHSUR P DECOMP ND tree and adapter flange. Remove f/ cellar 12:00 - 19:00 7.00 BOPSU P DECOMP -NU 13 5/8" 5M BOP, riser and flow line. Install fill up line -Remove extension f/ choke line. Install choke line -C/O bottom rams to 2-7/8" x 5" VBR -BOP configuration (f/ top to bottom): 1. 13 3/8" annular preventer 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. Mud cross w/ choke line and kill line 5. 2-7/8" x 5" VBR (lower rams) 19:00 - 20:30 1.50 BOPSU P DECOMP RU to test BOP 20:30 - 00:00 3.50 BOPSU P DECOMP T in BOP and related a ui ment er BP / AOG procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Testing top rams and rest of pressure control related equipment w/ 4" test jt. Test witnessed by WSL and Tourpusher. Jeff Jones, AOGCC Rep, waived witness of test. 7/14/2008 00:00 - 03:00 3.00 BOPSU P DECOMP Cont. testing BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test top rams w/ 4" test jt. Test bottom rams w/ 4" and 2-7/8" test jts. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 2-7/8" test jt. Test witnessed by WSL and Tourpusher. Jeff Jones, AOGCC Rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1725 psi 3. 200 psi attained at 31 sec 4. Full pressure attained at 2 min 45 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1. 13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams "-~' ~- 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) BP AMERICA Printed: 8/21/2008 1:55:17 PM • • BP AMERICA Page 3 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ~, Description of Operations 7/14/2008 ~ 00:00 - 03:00 ~ 3.00 ~ BOPSUp P 03:00 - 03:30 0.50 BOPSUFj P 03:30 - 05:30 2.00 WHSUR P 05:30 - 06:30 I 1.001 PULL I P 06:30 - 07:30 I 1.001 PULL I P 07:30 - 11:00 3.501 PULL ~ P 11:00 - 12:00 I 1.001 PULL I P 12:00 - 22:30 I 10.50 I PULL I P 22:30 - 00:00 I 1.501 PULL I P 7/15/2008 00:00 - 00:30 0.50 PULL P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 WHSUR P 01:30 - 03:00 1.50 FISH P 03:00 - 04:30 I 1.501 FISH I P 04:30 - 06:00 1.50 FISH P 06:00 - 09:30 3.50 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 13:30 3.00 FISH P 13:30 - 14:30 1.00 FISH P 14:30 - 15:00 0.50 FISH P DECOMP 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) DECOMP RD testing equipment. Blow down choke and kill lines DECOMP -RU lubricator extension and lubricator -Test to 500 osi x 5 min on chart -Pull C -RD lubricator and lubricator extension DECOMP -Mobilize control line spooling unit and tubing tongs to rig floor -RU to pull and LD completion DECOMP -MU 1 jt 4" DP and XOs. -RIH and screw in tubing hanger. MU top drive. BOLDS -Pull hanger to rig floor. Hanger pull free w/ 115k total pull (blocks weight 50k) -Cut control lines. -LD tubing hanger, 4" DP jt and XOs DECOMP POO n # L- E t i -Recover 1-1/4" SSSV control line and 1-3/8" chemical injection line. Recover 76 SS bands. -Pump 45 bbls seawater every 15 min in IA DECOMP -LD SSSV and chemical injection mandrel -RD control line spooling unit. Mobilize same off rig floor DECOMP Cont. LD 2-7/8" 6.5# L-80 EUE 8Rd tubing and completion equipment -Total LD: 340 tubing joints +SSSV + chemical injection mandrel + 5 GLMs + 4 pup jts 2-7/8" 6.5# L-80 EUE Rd + 14.15' cutoff 2-7/8" jt. -Jet cut uniform, flare to 3-3/8" OD DECOMP -Clean tubing handling equipment and rig floor -Clear rig floor of tools not needed for coming operation DECOMP Finish cleaning rig floor DECOMP Mobilize Baker tools to rig floor DECOMP Install wear ring DECOMP MU fishing BHA,per Baker Rep: 7-3/4" Oversize Cut Lip Guide + Hollow Mill Container (dressed w/ 4-1/4" x 2-7/8" insert) + Overshot Bowl w/ 2-7/8" Basket Grapple + Top Extension + Bumber sub + Jars + 6-1/4" DCs (9) DECOMP -Change elevators -RIH w/fishing BHA on 4" DP 1x1 to +/- 2200' -Cont. pumping 45 bbls seawater in IA every 15 min. DECOMP Cut and slip drilling line DECOMP Cont. RIH w/ 4" DP 1x1 F /2200' to 7041' DECOMP DHD on location shot fluid level. Fluid level ~ 3150' DECOMP -Cont. RIH 2/ 4" DP 1x1 F/ 7041' to 10640' -Increased oumoina from 45 bbls to 60 bbls seawater in IA DECOMP DHD on location shot fluid level. Fluid level tapes_ indicated 3150' and 3200' DECOMP Spot 50 bbl pill of safe tube in annulus Printed: 8/21/2008 1:55:17 PM • c BP AMERICA Page 4 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING .INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/15/2008 15:00 - 16:00 1.00 FISH P DECOMP -Established dressing off parameters: P/U: 290K, S/O 150k, Rotating 195k, 30 rpm ~ 12-15k torque -Ta to of fish ~ 10706'. Dress off to of cut 'oint, en a ed: -Pulled up to 325k, S/O to neutral, pulled to 350k and set off jars. Fish pulled free. -Spot 50 bbl pill of safe tube in annulus -Increased pumping from 60 bbls to 75 bbls seawater in IA eve 15 min. -Currently pumping 300 bbls per hour down the wellbore 16:00 - 20:00 4.00 FISH P DECOMP POH with fish, standing back 4' DP Continued pumping 75 bbls seawater in the IA every 15 min. 20:00 - 20:30 0.50 FISH P DECOMP -Stand back drill collars -LD 16.47' cut joint and 20.63' seal assembly 20:30 - 22:00 1.50 FISH P DECOMP -Closed blind rams for fluid shot -Shut down pumps -DHD shot fluid level. Fluid level indicated at 1800' -After blind rams shut for 45 minutes to an hour noticed 100# ressure on the annulus. Contacted Dave Reem and Jim Willingham for way forward. Determined to bullhead 1.5 wellbore volumes of seawater down well to knock pressure off. -Called and notified AOGCC Jeff Jones of ressure seen on annulus while blind rams closed. 22:00 - 23:30 1.50 FISH P DECOMP -Initiated bullhead of seawater. -Bullheaded 1140 bbls of seawater ~ 10-12 bpm ~ 240 psi -After bullhead complete monitored IA pressure and flat lined 0 psi -Opened blind rams and resumed pumping 75 bbls sewater in IA every 15 min. -While bullheading BHA #2 was made up on rig floor 23:30 - 00:00 0.50 FISH P DECOMP RIH on 4" DP with BHA #2 as per Baker rep: 3-1/8" bullnose mill + 8-1/2" Packer Mill +Triple Conn + Boot Basket (3) + Bit Sub + Bumper Sub + Oil Jar + Crossover Sub + 6-1/4" Drill Collars (9) + Crossover sub =Total length 323.17' 7/16/2008 00:00 - 03:00 3.00 FISH P DECOMP RIH w/ BHA (packer mill) to 8500' - Continue to pump 75 bbls of seawater down the IA every 15 minutes 03:00 - 03:30 0.50 FISH P DECOMP Spot EP tube pill (1 drum per 50 bbl seawater) 03:30 - 04:00 0.50 FISH P DECOMP RIH to 10706' -Establish parameters: S/O 170k, P/U 225k, Rot 200k, Torque 4k ~ 85 rpm -Pumping 5 bpm (~ 160 psi. 04:00 - 07:30 3.50 FISH P DECOMP Milling on Packer from 10720' to 10723' WOB=8 to 15k 07:30 - 08:00 0.50 FISH P DECOMP Pumpe in 300 bbls seawater ~ 10 bpm and 120 psi down the annulus 08:00 - 11:30 3.50 FISH P DECOMP POOH, standing back 4" DP from 10723' to 323' -Pumping 75 bbls seawater down the annulus every 15 minutes 11:30 - 12:00 0.50 FISH P DECOMP Standing back 3 stands of drill collars. VD mill, XO, boot baskets. -Boot baskets were empty. 12:00 - 13:00 1.00 FISH P DECOMP UD BHA, Clear Rig floor and pull next BHA onto Rig floor Printed: 8/21/2008 1:55:17 PM c: BP AMERICA Operations Summary Report Page 5 of 14 Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To j Hours Task Code ~ NPT ~ Phase ; Description of Operations 7/16/2008 12:00 - 13:00 1.00 FISH P DECOMP -Pumping 75 bbls seawater down the annulus every 15 minutes 13:00 - 13:30 0.50 FISH P DECOMP ~(jU fishina BHA #3 per Baker Rep: Itco Tvoe Soear dressed with 3.198 Grapple + XO sub + Bumber sub + Jars + 6-1/4" DCs (9) 13:30 - 18:30 5.00 FISH P DECOMP RIH with 4" drill pipe F/ 315' to 10650' -During trip started see air and water coming out of drill pipe. Pumped DP volume, -Notified town and decided while tripping in hole to pump DP volume down DP every 10 stands starting ~ 8000' -After DP volume pumped saw no returns and continued to RIH. 18:30 - 20:00 1.50 FISH P DECOMP Slip and cut drilling line. Service top drive. 20:00 - 21:00 1.00 FISH P DECOMP Ta fish ~ 10725'. -P/U 210-215k, S/O 170k. -Attempt to fish packer and tubing tail. Sat down 20k on fish. -Pumping 2 bpm down DP ~ 0 psi. Pressure increased to 1200 psi when stacking weight on spear before turning the pump off. 21:00 - 00:00 3.00 FISH P DECOMP POOH, F/ 10,725' to 5500', standing back DP. -Continuing to pump 75 bbls seawater every 15 minute down annulus -Pumping DP volume every 20 stands coming out of hole. 7/17/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue to POOH F/5500' to 315'. -Continue to pump 75 bbls every 15 minutes into the IA. -Continue to pump DP volume every 20 stands POOH. 02:30 - 03:00 0.50 FISH P DECOMP Stand back Drill collars. Pull spear to floor. No fish. -Grapple still in catch position. -No indication of entering the fish w/ spear. -Very slight wear on bullnose. 03:00 - 04:00 1.00 FISH P DECOMP Redress Spear BHA. 04:00 - 10:30 6.50 FISH P DECOMP RIH with on 4" DP, to 10680'. -Continue to pump 75 bbls every 15 minutes into the IA. -Pump DP volume every 10 stands RIH. 10:30 - 12:30 2.00 FISH P DECOMP Establish fishing parameters: P/U: 225k, S/O: 175k, ROT: 195k, Torque: 4k (~ 30 rpm, 840 psi ~ 3.5 bpm. - Tag fish ~ 10725'. Work spear into packer. -Attempted to Rotate spear into packer. - DP pressure would increase when spear sat down on obstruction. - No luck. Decide to POOH. 12:30 - 17:30 5.00 FISH P DECOMP POOH F/ 10725' to 315'. -Continue to pump 75 bbls every 15 minutes into the IA. -Pump DP volume every 20 stands POOH. 17:30 - 19:30 2.00 FISH P DECOMP LD Spear BHA & stand back 6-1/4" DCs. -Grapple still in catch position. -M/U aaker mill assembly: BHA #4 as per Baker rep: 3-1/8" bullnose mill + 6' extension + 8-1/2" Packer Mill + Triple Conn + Boot Basket + Bit Sub + Bumper Sub + Oil Jar + Crossover Sub + 6-1/4" Drill Collars (9) + Crossover sub =Total length 318.77'. 19:30 - 00:00 4.50 FISH P DECOMP RIH with Packer Mill BHA on 4" DP to 8600'. Printed: 8/21/2008 1:55:17 PM • • BP AMERICA Operations Summary Report Page 6 of 14 ~ Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2008 119:30 - 00:00 4.501 FISH P 7/18/2008 100:00 - 01:00 I 1.001 FISH I P 01:00 - 03:30 ~ 2.50 ~ FISH ~ P 03:30 - 04:30 I 1.001 FISH I P 04:30 - 05:30 1.00 FISH P 05:30 - 09:00 3.50 FISH P 09:00 - 09:30 0.50 FISH P 09:30 - 10:00 0.50 FISH P 10:00 - 10:30 0.50 FISH P 10:30 - 16:30 6.00 FISH P 16:30 - 17:00 0.50 FISH P 17;00 - 23:00 6.00 FISH P 23:00 - 00:00 1.00 FISH P 7/19/2008 00:00 - 01:00 1.00 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:00 0.50 FISH P DECOMP -Continue to pump 75 bbls every 15 minutes into the IA. -Pump DP volume every 10 stands RIH. DECOMP RIH with Packer Mill BHA on 4" DP f/ 8600' to 10,720'. -Continue to pump 75 bbls every 15 minutes into the IA. -Pump DP volume every 10 stands RIH. DECOMP Establish milling parameters: P/U: 225k, S/O: 160k, Rot: 190k, Torque: 70 spm ~ 6k, WOB 5-10k 245 gpm ~ 530 psi -Tagged Packer ~ 10,723'_ -Started milling packer. -1 hour in to milling ~ 15k WOB lost weight. -Pumping 6 bpm down DP and 5 bpm down Annulus. -Saw returns, shut down pumps, and fluid level started to fall. -Continued to pump down annulus ~ 3 bpm. -Chased packer body to 10735', -Tagged fish 3' deeper while rotating than with no rotation DECOMP POOH with acker A on 4" DP F/10735' to 8850' -Returned to pump down annulus at 75 bbs every 15 minutes -Pump DP volume every 20 stands POOH. DECOMP Slip and cut drilling line. Grease blocks and crown DECOMP POOH with packer Mill BHA on 4" DP F/ 8850' to 320' -Standing back 4" DP - Continue to pump 75 bbls every 15 minutes into the IA. - Pump DP volume every 20 stands. DECOMP Stand back Drill Collars. DECOMP LD Mill BHA DECOMP BHA #5 per Baker Rep: Itco Type Spear dressed with 3.198 Grapple + XO sub + Bumber sub + Jars + 6-1/4" DCs (9) DECOMP RIH w/ BHA on 4" DP F/315' to 10647' - Continue to pump 75 bbls every 15 minutes into the IA. - Pump DP volume every 10 stands RIH DECOMP Establish spear parameters: P/U: 228k, S/O: 155k, 35 spm =1330 psi -PU 1 joint and 1 stand NO-Go ~ 10730' -P II F e ~ 250k 22k over ull DECOMP POOH with Spear BHA and fish F/ 10730' to 315' - Continue to pump 75 bbls every 15 minutes into the IA. - Pump DP volume every 20 stand POH. DECOMP Stand back 6-1/4" Drill Collars - LD Oil Jars, Bumper sub, - R/U to punch tubing DECOMP Puncture 2-7/8" tubing below the packer. - L/D Spear, Jars and Bumpers - Packer milled up to just a stub. - Spear fully engaged into seal assembly - Punch expelled air from tubing DECOMP R/U double stack tongs DECOMP UD 2-7/8" tubing - Layed down tubing below packer. - Total length of packer and seal bore extensions: 21.67 ft - Total length of 2-7/8" fish: 218.67 ft - Tot I len th of fish was 244.34 ft - Cut joint was 4.0 ft long. Printed: 8/21/2008 1:55:17 PM • • BP AMERICA Page 7 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To i Hours Task ~ Code NPT Phase Description of Operations 7/19/2008 01:30 - 02:00 0.50 FISH P DECOMP -Cut joint was flared to 3.125 inches. - Cut joint left in hole 27.57 ft 02:00 - 03:30 1.50 FISH P DECOMP UD 9 6-1/4" Drill collars 03:30 - 05:00 1.50 FISH P DECOMP P/U overshot assembly BHA #6: Cut Lip Guide + Hollow Mill Container + Overshot Bowl + Top Extension + Subs + Jars + Subs + 9 4-3/4" Drill Collars + Sub + Jar + Sub = 321.06' 05:00 - 11:00 6.00 FISH P DECOMP RIH with BHA #6 on 4" DP f/320' to 10750' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 10 stands 11:00 - 11:30 0.50 FISH P DECOMP Establish parameters: P/U: 227k, S/O: 160k, ROT: 185k. - Pumping 7 bpm down the DP ~ 1390 psi - Pumping 3 bpm down the annulus ~ 100 psi - Ta tubin stub ~ 10969'., - Dress off stub and engage with overshot - Fish pulled free ~ 75k overpull - POOH with fish 11:30 - 13:30 2.00 FISH P DECOMP POOH with fish from 10969' to 8818' 13:30 - 15:00 1.50 FISH P DECOMP Slip and cut drilling line. Inspect Brass. 15:00 - 19:30 4.50 FISH P DECOMP POOH with fish F/ 8818' to 321' - Continue pumping 75 bbls every 15 minutes down the annulus - Pump DP volume every 20 stands 19:30 - 20:00 0.50 FISH P DECOMP Lay down hollow mill spear assembly. 20:00 - 21:00 1.00 FISH P DECOMP PJSM on punching holes in tubing - Punch 2 holes in 2-7/8" below the the CIBP. - Minimal trapped pressure. Not gas. 21:00 - 00:00 3.00 FISH P DECOMP PJSM on laying down tubing - RU double stack tongs. - UD 2-7/8" tubing - UD 3-3/4" AVA blast joints 7/20/2008 00:00 - 01:00 1.00 FISH P DECOMP Finish breakin and la in down fish and overshot BHA 01:00 - 02:00 1.00 FISH P DECOMP M/U Packer Millin BHA #7 =Packer Mill w 2-1/4" stinger + Boot Basket (3) + Subs + Jars + Subs + 4-3/4" Drill Collars (9) + 4" HWDP (12) = 685.42' 02:00 - 08:00 6.00 FISH P DECOMP RIH with BHA #7 on 4" DP f/686' to 11305' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 10 stands 08:00 - 11:30 3.50 FISH P DECOMP Establish Milling Parameter: P/U: 250k, S/O: 150k, ROT: 186k w/ torque of i Ok ~ 70 rpm, Pumping 7 bmp ~ 1250 psi -Tagged fish ~ 1135 ' - Milling packer ~ 7 - 12k WOB. Milled Packer 11:30 - 12:00 0.50 FISH P DECOMP P/U Drill Pipe and pushed packer down to 11502 12:00 - 19:00 7.00 FISH P DECOMP POH with BHA #7 on 4" DP f/ 11509' to 686' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 20 stands 19:00 - 20:30 1.50 FISH P DECOMP Rack back HWDP, Drill Collars, UD junk baskets, Mill. -P/U Spear BHA #8 = 2-13/16" Itco type spear + XO + Bumper Sub + Oil Jar + Pumpout Sub + XO + Drill Collars (9) +HWDP (12) = 669.53' 20:30 - 00:00 3.50 FISH P DECOMP RIH with BHA #8 on 4" DP f/686' to 6355' Printed: 8/21/2008 1:55:17 PM • BP AMERICA Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours I Task Code Start: 7/7/2008 Rig Release: 7/27/2008 Rig Number: NPT I Phase Page 8 of 14 Spud Date: 7/7/2008 End: 7/27/2008 Description of Operations 7/20/2008 20:30 - 00:00 3.50 FISH P DECOMP -Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 10 stands 7/21/2008 00:00 - 04:30 4.50 FISH P DECOMP Continue to RIH with BHA #8 on 4" DP f/ 6355' to 11505' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 10 stands 04:30 - 05:30 1.00 FISH P DECOMP Establish parameters: P/U: 230k, S/O: 158k Engage fish 05:30 - 07:00 1.50 FISH P DECOMP POOH w/fish f/ 11505' to 8200' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 20 stands 07:00 - 07:30 0.50 FISH P DECOMP Started pulling wet. Opened pump out sub.Check for flow. Monitor well. Pump ball and rod, no flow. 07:30 - 11:00 3.50 FISH P DECOMP Continue POOH f/8200' to 625' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 20 stands 11:00 - 12:00 1.00 FISH P DECOMP Stand back HWDP, Stand back DC's, Pull Spear to floor no fish 12:00 - 13:00 1.00 FISH P DECOMP LD BHA #8. 13:00 - 18:00 5.00 BOPSU P DECOMP Testing BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test rams w/ 4" and 3-1/2" test jts. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 3-1/2" test jt. Test witnessed by WSL, Tourpusher and AOGCC rep Chuck Sheve -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1800 psi 3. 200 psi attained at 37 sec 4. Full pressure attained at 2 min 43 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1. 13-5/8" annular 2. 3-1l2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 18:00 - 18:30 0.50 FISH P DECOMP Rig Down Testing equipment, Install wear ring, blow down choke 18:30 - 19:30 1.00 FISH P DECOMP MU BHA #9 and RIH to 679' -P/U S ear BHA #9 = 1348 Bowen tubing spear (Grapple 2.430") + Spear Extension + Spear top sub + Bumper Sub + Oil Jar + Pumpout Sub + XO + Drill Collars (9) +HWDP (12) _ 679.43' Printed: 8/21/2008 1:55:17 PM w • BP AMERICA Page 9 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 7/21/2008 19:30 - 20:30 1.00 FISH P DECOMP RIH w/ 4" DP f/ 679' to 1627' 20:30 - 21:30 1.00 FISH P DECOMP Slip and cut Drilling line. Service TD and Blocks. Fire Drill, time 1:00 21:30 - 00:00 2.50 FISH P DECOMP Continue to RIH f/1627' to 5417' - Continue to fill hole 75 bbls every 15 minutes down the annulus - Pump DP volume every 10 stands. - Seeing returns when running in hole, turn off pumps and fluid falls immediately. - Flow check every 10 stands after pumping DP volume. 7/22/2008 00:00 - 06:30 6.50 FISH P DECOMP Continue to RIH t/ 5,417' to 10,729' and w/ 4" D.P. -Continue to fill hole 75 bbls every 15 minutes down the annulus. Pump DP volume every 10 stands. -Seeing returns when running in hole. -Turn off pumps and fluid falls immediately. -Flow check every 10 stands after pumping DP volume. 06:30 - 07:30 1.00 FISH P DECOMP Top drive up & wash down f/ 10 729' to 11,012' md. -No Fish to ed. 07:30 - 08:00 0.50 FISH P DECOMP Continue in hole f/ 11,012' to 11,509' md. -En a e Fish. 08:00 - 08:30 0.50 FISH P DECOMP Work Fish. 126 gpm / 1600 psi. PUW 210k, SOW 165k. -Observed pressure increase to 1900 psi. -Set 25k down on Fish. Noted PUW incrgase of 8k. 08:30 - 12:00 3.50 FISH P DECOMP POH w/ 4" D.P. f/ 11,509' to 5,417' md. -Continue to fitl hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 20 stands. Fluid loss for tour 3,338 bbls of Seawater. -Total losses to date = 60 0 12:00 - 14:30 2.50 FISH P DECOMP Continue to POH f/ 5,417' to BHA f~ 679' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 20 stands. 14:30 - 16:00 1.50 FISH P DECOMP Rack back 4" HWDP & D.C's. -LD Spear assembly. 16:00 - 17:30 1.50 FISH P DECOMP Grease blocks & Service Rig while waiting on Taper Tap. -Continue to monitor losses ~ 333 bbls / hr. 17:30 - 18:00 0.50 FISH P DECOMP PU & MU Taper tap assembly. -MU D.C's & 4" HWDP to 671' md. 18:00 - 00:00 6.00 FISH P DECOMP RIH w/ Ta er to assembler on 4" D.P. f/ 671' to 11,480' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 10 stands. Fluid loss for tour 4,863 bbls of Seawater. -Total losses to date = 64,876 bbls. ,7/23/2008 00:00 - 01:00 1.00 FISH P DECOMP Establish parameters ~ 11,480' md: -PUW 240k, SOW 155k, ROT wt 190k, Tq 4k ~ 10 RPM. -126 gpm / 860 psi. -Wash down & rotate to to Fish ~ 11 505' md. -Rotary stalled ~ 8k Tq. Set down 20k twice on Fish, Printed: 8/21/2008 1:55:17 PM • • BP AMERICA Page 10 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/23/2008 00:00 - 01:00 1.00 FISH P DECOMP -Noted pump pressure increase of 800 psi to 1660 psi. 01:00 - 07:00 6.00 FISH P DECOMP Fill & Monitor well. -POH f/ 11,505' and to 671' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. ~ -Pump 1 D.P. volume every 20 stands. ~, 07:00 - 07:30 0.50 FISH P DECOMP Stand back 4" HWDP & 6 3/4" D.C's. 07:30 - 08:00 0.50 FISH P DECOMP LD Fish. 08:00 - 08:30 0.50 FISH P DECOMP Clear Rig floor of vendor tools & Fish. 08:30 - 09:30 1.00 CLEAN P DECOMP (Hughes tri-cone), Junk baskets & 7" Csg scraper. -RIH w/ 4" HWDP & 6 3/4" D.C's. to 686' md. 09:30 - 10:30 1.00 CLEAN P DECOMP Slip & cut 59.5' of 1.25" drilling line. -Service Rig: Top drive, Crown & Blocks. 10:30 - 12:00 1.50 CLEAN P DECOMP RIH w/ scraper assembly on 4" D.P. to 4,598' md, -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 10 stands. 12:00 - 16:00 6:00 - 16:30 4.00 .50 CLEAN LEAN P P DECOMP ECOMP Fluid loss for tour 2,714 bbls of Seawater. -Total losses to date = 67,590 bbls. Continue to RIH w/ Csg scraper f/ 4,598' to 10,830' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 10 stands. Circulate Rotate & work pipe over Pkr setting area ~ 10.89( md. -Work pipe with a 90 ft stroke. -PUW 225k, SOW 154k, Rot wt 180k ~ 40 RPM / 5k tq. -210 gpm / 610 psi. 16:30 - 17:00 0.50 CLEAN P DECOMP RIH w/ 7" Scraper assembly on 4" D.P. f/ 10,924' to 11,494 md. -No trouble noted in 7" Csg. 17:00 - 21:30 4.50 CLEAN P DECOMP POH f/ 11,494' to 686' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 20 stands. 21:30 - 22:30 1.00 CLEAN P DECOMP Rack back 4" HWDP & 6 3/4" D.C's. -Break and LD Scraper assembly. -Boot baskets recovered: -Approximately 0.5 gal of Paraffin /Tar /Sand, Scale & metal shavings. 22:30 - 00:00 1.50 CLEAN P DECOMP PU & MU HES RBP. -MU 6 3/4" D.C's. to 366' md. Fluid loss for tour 3,580 bbls of Seawater. -Total losses to date = 71,170 bbls. 7/24/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Lubricate Rig. 00:30 - 01:00 0.50 CLEAN P DECOMP Run D.C's. &HWDP in hole w/ RBP to 660' md. 01:00 - 07:30 6.50 CLEAN P DECOMP RIH w/ RBP on 4" D. P. f/ 660' to 7" liner top at 10,756' md. -Enter L.T. and taking weight at 10,773' md. -PU and turn pipe 3 turns right -Continue RIH to 10,990' md. Printed: 8/21/2008 1:55:17 PM • ~ BP AMERICA Page 11 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date j From - To j Hours Task Code NPT Phase Description of Operations 7/24/2008 101:00 - 07:30 I 6.50 I CLEAN I P 07:30 - 08:00 0.501 CLEAN P 08:00 - 09:30 1.50 CLEAN P 09:30 - 10:30 1.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 12:00 0.50 CLEAN P 12:00 - 22:30 I 10.501 CLEAN I P 22:30 - 00:00 I 1.501 CLEAN I P DECOMP -Continue to fill hole 75 bbls every 15 minutes down the annulus. -Pump 1 D.P. volume every 10 stands. DECOMP Screw in T.D. -Obtain parameters: -PUW 260k -SOW 145k. -PU and spot tog of RBP at 10,966' md. -Set RBP per HES Rep w/ 3 L.H. turns -Release from RBP -Top at 10,966' -C.O.E. at 10,969' md. DECOMP Break circulation: -Circulate bottoms up w/ 504 gpm / 3200 psi. DECOMP LD single - RU to test 9 5/8" casing and liner lap. -Test to 3500 si f/ 30 min on chart -Pass. DECOMP RD test equipment. -Blow down Kill line. DECOMP P HE 9 5/8" Storm acker. DECOMP RU to test Storm packer. -Test Storm packer from above. -Test to 1000 si / 10 minutes -Pass. -Blow down Kill & Choke line. Pull Wear ring. Fluid loss for tour 2,823 bbls of Seawater. -Total losses to date = 73,993 bbls. DECOMP ND BOP stack. -Remove: Mouse hole, Flow line, Riser, Turn buckles, -Bleed off, Choke line, Double annulus valve. - Tb S ool. C/O Packoff. Instal spool. -Put on Stack. Test Pack off to 5000 psi / 30 minutes -Pass. -Pump plastic into Y-Seal. -Install 12" extension to Choke line & Mouse hole. -NU Flow line, Riser, Double annulus valve. DECOMP RU to test Choke line & BOP stack breaks - 250 low / 3500 high psi. -Test Choke line & BOP stack breaks,- Pass. -Install Wear ring. Fluid loss for tour 0 bbls of Seawater. -Total losses to date = 73,993 bbls. 7/25/2008 00:00 - 00:30 0.50 CLEAN P DECOMP MU running tool f/ Storm packer. -RIH to 100' md. 00:30 - 01:30 1.00 CLEAN P DECOMP En a e 9 5/8" acke ,turn 3 turns to left. -Pull Packer to floor. LD same. -PU 2 stands & engage RBP ~ 10,966' md. -Turn 2.5 turns Rt & set down 20k. -PU 225k & ull free w/ RBP. -Circulate & monitor well. 01:30 - 02:00 0.50 CLEAN P DECOMP POH, stand back 2 stands f/ 10,966' to 10,710' and above Liner top. 02:00 - 09:30 7.50 CLEAN P DECOMP Continue to POH w/ RBP. LD D.P. 1 X 1 f/ 10,710 to 660' md. -Continue to fill hole 75 bbls every 15 minutes down the Printed: 8/21/2008 1:55:17 PM • BP AMERICA Page 12 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task ~ Code ~ NPT ~, Phase Description of Operations ~ ~ --- - 7/25/2008 02:00 - 09:30 7.50 CLEAN P DECOMP annulus. -Pump 1 D.P. volume every 20 stands. 09:30 - 10:00 0.50 CLEAN P DECOMP RIH w/ 4" D.P. from derrick to 1,500' md. 10:00 - 11:00 1.00 CLEAN P DECOMP Continue to LD D.P. 1 X 1 f/ 1,500 to 660' md. -Continue to fill hole 75 bbls every 15 minutes down the annulus. 11:00 - 12:00 1.00 CLEAN P DECOMP LD RBP retrieval BHA: -LD HWDP, 4 3/4" D.C's, HES running tool &RBP. Fluid loss for tour 3,707 bbls of Seawater. -Total losses to date = 77,700 bbls. 12:00 - 13:00 1.00 BUNCO RUNCMP Pull Wear ring. -Clear Floor of vendor Tools. 13:00 - 14:30 1.50 BUNCO RUNCMP PJSM...RU to run 3 1/2". 9.2#. 13Cr-80 Tba. -RU Torque Turn ,Compensator, Tongs & Elevators. 14:30 - 00:00 9.50 BUNCO RUNCMP Run 3 1/2", 9.2#, 13 Cr-80 Vam Top Tbg & jewelry to 4,850' md. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum Tq = 2900 ft/Ibs -Max Tq = 3190 fUlbs. -All connections under packer are Baker Loked. -Continue to fill hole w/ 5 bpm down backside. -Pump 1 Tbg volume every 30 Jts. Fluid loss for tour 3,710 bbls of Seawater. -Total losses to date = 81,410 bbls. 7/26/2008 00:00 - 08:00 8.00 BUNCO RUNCMP Continue to run Tbg f/ 4,850' to 8,850' md. -Running 3 1/2", 9.2#, 13 Cr-80 Vam Top Tbg & jewelry. -Using Torque turn & Compensator. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum Tq = 2900 Wlbs -Max Tq = 3190 ft/Ibs. -All connections under packer are Baker Loked. -Continue to fill hole w/ 5 bpm down backside. -Pump 1 Tbg volume every 30 Jts. 08:00 - 12:00 4.00 BUNCO WAIT RUNCMP Wait on SLB control line &representitive. -Clean Rig floor. Perform maintenance. -Prep for Rig move. Fluid loss for tour 3,795 bbls of Seawater. -Total losses to date = 85,205 bbls. 12:00 - 15:30 3.50 BUNCO WAIT RUNCMP Continue to wait on SLB control line &representitive. -Prep for Rig move. 15:30 - 16:30 1.00 BUNCO RUNCMP RU Control line. Test to 5000 psi / 5 minutes -Pass. 16:30 - 21:30 5.00 BUNCO RUNCMP Continue to run Tb f/ 8 850' to 10 995' md. WLEG~. t ~ 10 884' md. -Running 3 1/2", 9.2#, 13 Cr-80 Vam Top Tbg & jewelry. -Using Torque turn & Compensator. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum Tq = 2900 ft/Ibs -Max Tq = 3190 ft/Ibs. -All connections under packer are Baker Loked. -Continue to fill hole w/ 5 bpm down backside. -Pump 1 Tbg volume every 30 Jts. Printed: 8/21/2008 1:55:17 PM • BP AMERICA Page 13 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: i Date From - To Hours Task Code ~ NPT ~ Phase Description of Operations ~ 7/26/2008 ----- 16:30 - 21:30 5.00 BUNCO RUNCMP - -Utilized 72 SS bands on Control line. 21:30 - 23:00 1.50 BUNCO RUNCMP PU Tbg Hanger & Landing Jt. C/O Seal on Hanger. -PUW 165k, SOW 105k. -Installed control line into Hanger. -Test line to 5000 psi / 5 minutes -Pass. 23:00 - 00:00 1.00 BUNCO RUNCMP Land Tbg Hanger. RILDS. -RU to reverse circulate. Clear Rig Floor of Tools. Fluid loss for tour 3,840 bbls of Seawater. -Total losses to date = 89,045 bbls. 7/27/2008 00:00 - 03:00 3.00 BUNCO RUNCMP Reverse circulate in 752 bbls of 9.4 ppg NaCI. -Start adding Corrosion Inhibitor after 100 bbls away. -Pump 210 gpm / 420 psi. 03:00 - 04:00 1.00 BUNCO RUNCMP Drop Ball & rod. Pump down same. -RU Chart to record tests. -Pressure u to 3500 si / 30 minutes - 100 si loss. -Small surface leak observed - Re-test for 10 min -Good test. -Bleed down Tbg to 1500 psi. ~~~ -Chart all tests. 04:00 - 05:30 1.50 BUNCO RUNCMP Fill void on back side with 152 bbls 9.4 NaCI. 05:30 - 07:00 1.50 BUNCO RUNCMP Pressure annulus to 3500 psi / 30 min - 100 psi loss. -Bleed it from s stem - Re-test for 15 min -Good test. -Bleed tubing pressure and shear DCR valve w/ 2600 psi differential. -Break circ. through DCR w/ 84 gpm / 170 psi - 126 gpm / 270 psi. 07:00 - 08:00 1.00 WHSUR P WHDTRE RD lines - LD landing joint, elevators, bales & compensator. -Blow down T.D. 08:00 - 08:30 0.50 WHSUR P WHDTRE Cameron Re . MU TWC to d rod and install same. 08:30 - 09:00 0.50 WHSUR P WHDTR m bove and below to 1000 si f/ 10 min each. __ -- -On chart -Pass. 09:00 - 09:30 0.50 WHSUR P WHDTRE RD test equipment. -Blow down Choke, Kill, Hole fill and Bleed off lines. 09:30 - 10:30 1.00 WHSUR P WHDTRE PJSM - ND BOPE. -LD mouse holes. -RD flow line, riser, flow line. -Set BOP stack on pedestal and secure. 10:30 - 12:00 1.50 WHSUR P WHDTRE Clean hanger -Prep control line. -MU Adapter flange & Tree. -Test Tree & Adaptor to 5000 psi. -Chart test. Tighten Adaptor flange -leaking visably. Fluid loss for tour 925 bbls of Seawater. -Total losses to Well = 89 970 bbls. 12:00 - 14:30 2.50 WHSUR P WHDTRE Continue to tighten Adaptor flange. -RU to circulate freeze protection. -Clear Floor. Remove Kelly hose. -Test Tree & Adaptor flange to 5000 psi / 30 minutes -Pass. -Chart test. 14:30 - 15:30 1.00 WHSUR P WHDTRE RU Lubricator. Test Lubricator to 500 psi -Pass. -Remove TWC. 15:30 - 16:30 1.00 WHSUR P WHDTRE Continue to RU to pump Freeze protection. Printed: 8/21/2008 1:55:17 PM BP AMERICA Page 14 of 14 Operations Summary Report Legal Well Name: L3-23 Common Well Name: L3-23 Spud Date: 7/7/2008 Event Name: WORKOVER Start: 7/7/2008 End: 7/27/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 7/27/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/27/2008 15:30 - 16:30 1.00 WHSUR P WHDTRE -PJSM w/ LRS Hot Oii. -Pump 13 bbls of diesel freeze protection. -Pump 84 gpm / 400 psi. 16:30 - 17:30 1.00 WHSUR P WHDTRE Allow diesel to U-Tube 1 hour. -Clear Rig floor of: -Subs, Bales, Riser, Mouse hole. -De- Mob #2 conveyor. 17:30 - 18:30 1.00 WHSUR P WHDTRE RU & Set BPV. Test BPV w/ LRS Hot Oil. -Test to 1000 psi / 10 minutes -Pass. 18:30 - 21:00 2.50 WHSUR P WHDTRE RD LRS. Secure well. Remove pump in flanges. -Install flanges & gauges. -Check gauges for pressure. IA had 950 psi. -Bleed IA to zero psi. 21:00 - 22:00 1.00 WHSUR P WHDTRE Slip on more drilling line. -Add: for a total of 40 wraps of 1.25" line on drum. 22:00 - 00:00 2.00 RIGD P WHDTRE RD Top Drive. Install front boosters. -RD & prepare to skid Rig floor. -Tree pressures: T/I/O = O/O/O psi. Rid released at 23:59:59 07/27/2008 -Prepare for move to well H-11 Printed: 8/21/2008 1:55:17 PM Page 1 of 3 Well: L3-23 Well History Well Date Summary • • L3-23 7/8/2008 CMIT TxIA to 3500 psi ** Job postponed due to rig job ** L3-23 7/8/2008 ***WELL S/I ON ARRIVAL*** (pre jet) RAN 2.34" SWEDGE TO TRSSSV W/ NO RESTRICTIONS. RAN 2.34" SWEDGE, FLAPPER CHECKER TO TRSSSV C~ 2210' SLM. PERFORMED GOOD FUNCTION TEST ON TRSSSV. ***CONT. JOB ON 07/09/08 WSR*** L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 L3-23 7/9/2008 *** CONT JOB FROM 07/08/08 WSR *** (pre jet cut) RAN 2.25" CENT. S-BAILER TO TOP OF CIBP AT 10967' SLM WITH NO RESTRICTIONS. S-BAILER EMPTY. *** LEFT WELL S/I. TURNED WELL OVER TO DSO *** 7/9/2008 WELL SHUT IN ON ARRIVAL, NO WELL HOUSE OR SCAFFOLDING PRESENT, STANDBY FOR SCAFFOLDING TO RU. ***JOB IN PROGRESS AND CONTINUED ON 10-JUL-2008 WSR*** 7/9/2008 T/I/O = 400/420/120 CMIT TxIA to 3500 osi PASSED on 2nd attempt (Pre RWO) Pumped 28.1 bbls of crude into the tubing to test. CMIT TxIA lost 70/70 psi in the 1st 15 min and 30/30 psi in the 2nd 15 min for a total loss of 100/100 psi in the 30 min test. Bled TxIAP back down. Final WHP's = 260/440/120 Valve Positions: Swab closed /Wing closed /Companion closed /SSV closed /Master open (tagged) / IA open (tagged) / OA open ** Master closed and flagged upon arrival ** 7/10/2008 ***CONTINUED FROM 9-JUL-2008***WELL SHUT IN ON ARRIVAL, NO WELL HOUSE OR SCAFFOLDING PRESENT. T/I/0= 0/460/120 7/10/2008 T/I/O = 0/170/120 -Circ out, MIT OA to 2000 psi (RWO Prep) *** Job continued on 07/11/08 WSR *** 7/11/2008 T/I/0= 45/50/300. Temp= SI. IA & OA FL (prep-RWO). IA FL C~ 3567' (below sta # 1) (235 bbls). OA FL near surface. 7/11/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Open bleeder screw to verify 0 psi in test void. Removed internal check and installed Alemite external check. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Open bleeder screw to verify 0 psi in test void. Removed internal check and installed Alemite external check. Functioned LDS, 1 pin was previously backed out, the rest moved freely. Pumped through void, clean returns. Re energized secondart Y seal with plastic. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 7/11/2008 *** Job continued from 07/10/08 WSR *** T/1/O = 0/170/120 -Circ-out, MIT OA FAILED to 2000 psi (RWO prep) -Pumped 5 bbls neat meth followed by 277 bbls 95* 9.3# brine down TBG taking returns up IA to L3-31 flowline. TP and IAP dropped off w/250 bbls pumped. Pumped 378 bbls 95* 9.3# brine down TBG w/hardline loop shut in. Pumped 465 bbls 95* 9.3# brine down IA. Freeze protect IA w/7 bbls diesel. Freeze protect TBG w/1 bbl diesel. Flush hardline loop w/2 bbls diesel. Pumped 5 bbls of meth down TBG followed by 100 bbls of 120* 2%KCI, capped w/2 bbls of diesel. Pumped 930 bbls of 120* 2% KCI down IA. 30 psi on IA when shut down pump. Pumped 23 bbls of 60* diesel down OA to reach 1400 psi. OA psi falling. Pumped additional 6 bbls of diesel ~ 1 bpm. OA pressured up to 1400 and then fell to 1250 psi. OA lost 650 psi in 30 min. F-protect L3-31 flowline w/12 neat meth. FWP's =vac/30/35 *** Tags hung, notified DSO of all valve positions: Swab closed, master open, SSV open, IA open, OA open. L3-31 -Swab closed, master open, SSV closed, wing closed, IA open, OA open *** 7/12/2008 T/I/O=VAC/0/50. Set 2-9/16" CIW BPV at 102". 7/12/2008 *** RIG JOB - DOYON 14 *** CURRENTLY RIGGING UP SLICKLINE UNIT. *** CONT ON 7/13/08 WSR *** 7/13/2008 T/I/0=0/0/0. Pulled 2-1/2" CIW BPV for Doyon 14 with thin collars thru tree C~ 102" 7/13/2008 ***CONT WSR FROM 7/12/080***(DOYON 14 RIG JOB) GLM #5. FINAL T/I/O 0/120/100. WELL LEFT SHUT IN. ***JOB COMPLETE*** Page 2 of 3 DRIFTED W/ 2.NT. TO TRSSSV AT 2230'MD SET 2-7/8"CS LO /HOLD OPEN SLEEVE(1.75" FN 114" OAL) IN TRSSSV AT 2230'MD. *** JOB COMPLETE. TURN WELL OVER TO RIG *** L3-23 7/14/2008 T/I/0=0/0/0. Pull 2-1/2" CIW TWC for Doyon 14 through stack with 5 - 5' ext C~ 78". L3-23 7/15/2008 T/I/O = NANAC/0. Temp = SI. IA FL for Rig. IA FL C~3 3150'. 1st FL shot ~ 1000 hrs. 2nd FL shot C~3 1300 hrs. No Tree, Rig currently on well. IA = SI. OA =Open bleed. *Valves in position per Rig* L3-23 7/15/2008 T/I/O = NA/0+/0. Temp = SI. IA FL for Rig. IA FL C~3 3150'. No Tree, Rig currently on well. IA = SI. OA =Open bleed. *Valves in position per Rig* L3-23 7/16/2008 TIO= NA/vac/0. SI. IA FL for Rig. IA FL C~3 1788'. FL shot C 2000 hrs. L3-23 7/28/2008 T-i-O O-O-O pulled 4 1/16 ciw twc for rig de completion used 1-2" extension tag at 105" no problems L3-23 7/29/2008 Assist wireline pump as directed- **Continued on 7-30-08 WSR** L3-23 7/29/2008 ***WELL SI ON ARRIVAL***(post rwo) PULL 3 1/2" DMY SSSV FROM 2159' SLM S TO -SUB AT5595'SLM SET 3 1/2" SS C-SUB C~3 5595' SLM, PULL 1.5" RK-DGLV FROM STA# 3 C 5487' SLM & RKP- DCR FROM STA# 4 ~ 3002' SLM SET RK-LGLV (1500#TRO) IN STA# 4 C~ 3002' SLM, SET RK-S/O (5/16") IN STA# 3 ~ 5487' SLM PULL 3 1/2" C-SUB FROM 5595'SLM PULLED BALL AND ROD. RHC FROM 10972'MD LOC TT ~ 10984'SLM = 10995'MD (+11'corr) TD AT 11516'MDcorr 56' RAT HOLE ***CONT WSR ON 7-30-08*** L3-23 7/29/2008 T/I/O = 10/0/0 Pulled 4 1/16" CIW H BPV post RWO L3-23 7/30/2008 ***CONT WSR FROM 7-29-08*** RAN 2.60"SWAGE, TEL, S-BAILER, METAL MARK RING AROUND 2.60" SWAGE, SAMPLE OF BLACK CLAY LOOKING SUBSTANCE OBTAIN +11' CORRECTION ON PREVIOUS WSR RUN MEM/PRESS/TEMP, CCL GAUGES, MAKE STATIC, DYNAMIC, & WARM BACK PASSES FROM 11476' MD TO 10911' MD x tea RUN SBHPS AS PER PROGRAM *GOOD DATA* ***WELL S/I ON DEPARTURE*** L3-23 7/30/2008 T/I/O=VACNAC/0. SI. TBG & IA FL (for W/L). TBG & IA FL near surface. L3-23 7/30/2008 **Job continued from 7-29-OS WSR** T/I/0=0/0/0 Assist wireline pump as directed- Memory log. Pumped 180 bbls 1 % KCL while SLB ran memory log followed by 12 bbls meth & 3 bbls of diesel.. Final WHP's= 0/0/0 ***Annulus casing valves left open to gauges*** Swab, Wing, SSV= shut. Master, IA, OA, open. L3-23 8/13/2008 T/I/0= 1800/1810/15. Temp= SI. TBG & IA FL (OPER). T FL C~ 5038'(above sta# 3, SO). IA FL 5335'(above sta# 3, SO). L3-23 8/17/2008 *** WELL S/I ON ARRIVAL *** (post rwo) ATTEMPTED TO SET 3 1/2" C-SUB, SD ON ICE PLUG ~ 1761' SLM DRIFTED W/ 2.50" CENT & S-BAILER, SD ~ 1761' SLM PUMPED 5 BBLS METH & CLEARED RESTRICTION DRIFTED TO XN NIP C~ 10,955' SLM W/ 2.80" CENT & S-BAILER ATTEMPTED TO SET 3 1/2" C-SUB, SD C~ 6210' SLM, UNABLE TO PASS ***CONT ON 8/18/08*** L3-23 8/18/2008 T/I/O = 1800/1550/0 Temp = S/I -Assist Slickline, load TBG -Pumped 5 bbls neat meth follwed by 85 bbls 100* crude down TBG while slickline RIH w/valve. Pressured up TBG to 800 psi w/10 bbls 100* crude. FWP's = 800/1550/0 *** Slickline on well at departure. Casing valves open to guages *** L3-23 8/18/2008 *** CONT FROM 8/17/08 *** (post rwo) RAN 3 1/2" BRUSH & 2.805" G. RING TO XN NIP ~ 10955' SLM RAN 2.75" BLIND BOX, FOUND FLUID Ci? 10400' SLM TBG WAS VERY UNDERBALANCED. LRS PUMPED 95 BBLS CRUDE SET 2.81" CAT STANDING VLV IN XN NIP C~ 10,955' SLM PULLED ST#1 RK-DGLV FROM 10582' MD. PULLED ST#2 RK-DGLV FROM 8512' MD PULLED ST#3 RK-OGLV FROM 5500' MD. PULLED ST#4 RK-LGLV FROM 3022' MD SET ST#4 RK-DGLV ~ 3022' MD. SET ST#3 RK-LGLV @ 5500' MD SET ST#2 RK-LGLV C~3 8512' MD. SET ST#1 RK-OGLV ~ 10582' MD *** CONT ON 8/19/08 *** Pale 3 of 3 L3-23 8/19/2008 *** CONT FROM 8/18/08 *** (post rwo) PULLED CAT STANDING VLV FROM XN NIP ~ 10955' SLM. RDMO *** TURNED WELL TO DSO S/I*** Print Date: 8/21/2008 Page 1 of 1 , . ~ r"'\ . . '(~;' :':;;",:;, r"\ :::;-¡::l if::" f \..1 - i. i !" I ¡ .! , "" !, ¡. \ \ \ ¡ i ~.-:' ') Ill~-'\ IJ lL QL.. L Iì.J L -.:í lID lr; íT\ 1 Jí:\ (f1:.J --1/7 fì~\ 11\\ I I¡\,\\,,'-,- tí ff\\ íA~ -6 U\~ cQ) J ~ Lf\1 ! í FRANK H. MURKOWSKI, GOVERNOR / , AI4A.SIiA ORAND GAS CONSERVATION COmnSSION ! ! 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 I ~ 6' '<?Þfo 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 PBU L1 PBU L2 PBU L3 Date of SVS Test April 23, 2004 April 26, 2004 Apri127,2004 Failure Rate 30.0% 16.7% 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 L1, 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 w't th SVS test. Sincerely, J . Norman, Chair C~missioner 2J~ Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) ~, r--... 'r t 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: 04/27/2004 Unit/Field/Pad: Greater Pt McIntyre/Lisburne/L3 Separator psi: LPS 450 HPS 450 "1mJ.~ _ll~- - ..II IBlIJîImlAIIB -.,.. 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 13-01 1890750 12/4/1993 SI 13-02 1861540 450 350 350 P 6 P OIL 13-05 1851950 1/14/2003 SI 13-08 1831430 7/2/1994 SI 13-11 1852310 9/9/2003 81 13-12 1861610 4/19/1997 81 13-15 1852660 12/22/1996 SI 13-18 1861670 2/16/1997 SI 13-19 1852860 11/17/2001 81 13-22 1861750 6/4/2003 SI L3-23 1853060 6/26/1995 SI L3-24 1861820 5/12/1997 81 L3-28 1890660 9/7/1993 SI 13-30 1861850 11/25/1996 SI L3-31 1860340 7/28/2003 SI Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service SSV Page 1 of 1 SVS PBU LIS L3 04-27 -04,xls ARCO ALASKA INC. LISBURNE ENGINEERING DATE: 10-24-89 FROM: TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: L3-23 ~lll~ L4-30 ~ L4-31 L5-1 ~ L4-14 ~i, L4.14 ~ L4-14 ~ L4-14 %,,,,,,t L4-14 .Ii,,~,j L4-14 ~ L4-14 L4-14 L4-14 L4-14 L1-1 TAPES: L4-14 OPEN HOLE LOGS L4-14 RFT COMPLETION RECORD PRODUCTION PROFILE SE'I-rING SERVICE (EZSV) TEMPERATURE LOG PHYSICAL FORMATION CNL IN CASING DUAL LATERLOG NATURAL GAMMA RAY SPECTRA LOG REPEAT FORMATION TESTER COMPENSATED NEUTRON LITHO DENSITY- RAW DATA COMPENSATED NEUTRON LITHO DENSITY, - POROSITY CEMENT EVALUATION CEMENT BOND LOG GCT GYRO DIRECTIONAL SURVEY PRODUCTIQN PROFILE SIGN AND RETURN TO: TINAKINCAID RECEIVED BY: EXXON BP TRANSMITTAL # 624 RUN I 10-13-89 RUN 1 8-27-89 RUN I 9-12-89 RUN 1 7-6-89 RUN 1 9-21-89 RUN 1 9-30-89 RUN 1 9-30-89 RUN 1 9-30-89 RUN 1 9-3089 RUN 1 9-30-89 RUN I 9-30-89 RUN I 9-30-89 RUN 1 9-30-89 RUN 1 10-14-89 RUN1 10-14-89 RUN 1' 9-29-89 RUN 1 9-30-89 ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA STATE ©._ SCHLUMBERGER CAMCO ATLAS HALLIBURTION ANADRILL SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER CAMCO SCHLUMBERGER SCHLUMBERGER 99510 Anchorage ARCO Alaska, Inc. ~'"- Posl Office J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAHP LE TRANSHITTAL Handcarry SHIPPED TO' State of Alaska Oil & Gas C.C. 3001 PorcuDine Dr. Anchorage, Alaska 99501 DATE' February 8, 1988 OPERATOR' ARCO West Beach St. iA NAME.L3-23, Trading Bay K-25 SAi'IP LE TYPE' SAMPLES SENT' ChiDs ! L3-23 i ~9~11434-11439 ,, 11514-11533/// West Beach State lA O~ 9670.0-9698.0 " 9719 0-9736 0 9737 0-9753 0 9782 0-9806 0 9807 0-9824 0 10009.0-10038. 10039.0-10053 Trading Bay Unit e~13698.0-i3731.0 13732.0-13756.0 K-25' 13757.0-13775.0 13777.0-13791.0 13797.0-13822.0 13823.0-13826.0 NUMBER OF BOXES' 14 *On these samples, if VOU need further information, contact Rick Levinson, at 265-1652 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND btAIL A SIGNED COPY OF THIS FOP, bi TO' ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/iO0 57 ' z_3 / ..... '. bAY§: $ ,s ARCO Alaska, Inc I'~ a .qub'~d,ary of AtlanhcHichfteldCompan¥ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE TP~NSMITTAL · Handcarry SHIPPED TO: State of Alaska Oil & Gas C.C. 3001 Porcupine Dr. Anchorage, Alaska 99501 DATE: February 8, 1988 OPERATOR: ARCO West Beach St. lA N;3iE.L3~23,,. Tradinq Bay K-25 S:%',IPLE TYPE: Chips NUMBER OF BOXES: 14 S~PLES SENT: L3-23 Trading Bay Unit K-25' 11434-1143~ 13698.0-13731.0 11514 1153 13732.0-13756.0 13757'0-13775[0~~ West Beach State iA 13777 0 13791 9670.0-9698.I ~ 13797.0-13822.0 9719 0-9736 13823.0-13826.0 9737 0-9753 10039.0-1005 *On these samples, if you need further information, contact Rick Levinson, at 265-1652 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND bi~IL A SIGNED COPY OF THIS FOIh%I TO: RECEIVED BY: ARCO ALASKa, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/100 ARCO Alaska, Inc. i Po~! Ollme Bo,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ( Handcarr¥ SHIPPED TO' OPERATOR' ARCO S:~IP LE TYPE' S~IPLES SENT: L3-23 ~11434-11439 11514-11533 West Beach State 9670.0-9698.0 9719.0-9736.0 9737.0-9753.0 9782.0-9806.0 9807.0-9824.0 10009.0-10038.0 10039.0-10053.0 SAblP LE TRANSHITTAL State of Alaska Oil & Gas C.C. 3001 Porcupine Dr. Anchorage, Alaska 99501 Chips Trading Bay Unit K-25' e~13698.0-13731.0 13732.0-13756.0 13757.0-13775.0 IA 13777.0-13791.0 13797.0-13822.0 13823.0-13826.0 *On these samples, if information, contact 265-1652 DATE' February 8r 1988 West Beach St. lA N~iE:L3v23, Trading Bay K-25 NUbtBER OF BOXES' ]4 /0 you need further Rick Levinson, at UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND btklL A SIGNED COPY OF THIS FORbl TO: ARCO ALAStCR, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/iO0 RECEIVED (~~' ~~,,,. ARCO Al.i~,ka, Iilc is a $[Jbsldlary ol AllanllcJilchtleldColnp.fly ARCO Alaska, Inc. x:~.~,,."-~ Post Office B~)360~'-~-- Anchorage, Alaska 99510 Telephone 907 276 1215 SA.MPLE TRANSHITTAL SHIPPED TO' · State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak 99501 DATE' Jan 18, 1987 OPERATOR' ARCO Core chips and dry ditch. S:%xlP LE TYPE' NAblE' L3-23, ?--' ...... -' NUblBER OF BOXES' 3 S~IPLES SENT: ~ Chips Dri l~it~~ 11213 Dry 11216.9 11217.5 11220.0 UPON RECEIPT OF THESE SJuMPLES, PLEASE NOTE ANY DISCREPANCIES AND brA, IL A SIGNED COPY OF THIS FORbl TO' ARCO ALAS}C~, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 /~ ATTN: Paleo Lab RECEIVED' / ~ ,-~"' ABV/iO0_-J. DATE: ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany SHIPPED TO' ARCO Alaska Post Or.v_.=~-~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 TRANSMITTAL State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchoraqe, AK 99501 ~and Carry DATE- Dec. 30, 1987 OPERATOR- S:%IPLE TYPE: . S~IP LES SE~T: PBU-LGI-12 10290-10296.5 10301-10314 10314-10335 10335-10358 10358-10385 10386-10420 10420-10428 10430-10449 10449-10466 10466-10501 10501-10517 10523-10549 ARCO Core Chips L3-23 11076-11103 11105-11121 11121-11151 11152-11181 11181-11201 11201-11212 11262-11315 11315-11335 11335-11370 11372-11407 11560-11590 11590-I1632 N;~\IE- PBU LGI-12, NU~IBER OF BOXES: 5 , L3-23 SHIPPED BY:~ P&leo Lab Tech UPON RECEIPT OF THESE S~qPLES, PLEASE NOTE .%NY DISCREP.%~CIES .(ND ~£~IL A SIGNED COPY OF THIS FO~q TO' RECEIVED BY' ARCO ALAS~R, INC. P.0. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/100 DATE. -- ARCO Alaska, Inc. Is a Sul=s~dlary of AllantlcRIchfleldCompany STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM.,_/SION REPORT OF SUN DRY WELL OPERATIONS shutdown ~ Stimulate,-~i~ Plugging E] Perforate/~ Pull tubing [] 1. Operations performed: Operation Alter Casing F20ther]~ 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 4. Location of well at surface 934 ' FNL ~ 6?9 ' FWL, Sec . 2~;TM, T 11N, R15E, UM At top of productive interval 1067' FSL, 1585' FWL· Sec. 21, T11N, R15E,UM At effective depth 752' FSL, 1158' FWL, Sec. 21, TllN, R15E,UM At total depth 733' FSL~ 1133' FWL~ Sec. 21~ TllN~ R15E,UM 11. Present well condition summary Total depth: measured i 19OO feet Plugs (measured) true vertical 9568 feet 5. Datum elevation (DF or KB) RKB 5 1 ' Feet 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number L3-P3 8. Approval numberN/A 9. APl number 029-21513 50-- 10. Pool LISBURNE OIL POOl NONE NONE Effective depth: measured 11852 feet Junk (measured) true vertical 9530 feet Casing Length Size Cemented Measured depth Structural 80' 20" 1950 s× POLESET 110' Conductor 3991' 13-3/8" 2600 sx PF "E" & A021' Surface 600 sx class G Intermediate 9159' 9-5/8" 1050 sx class G & i0993' Production 300 s× PF "C" 1142' ?" 245 sx CLASS C 10956-11898' Liner ~ueVerticaldepth 110' 3861' Perforationdepth: measured 11050-11156', truevertical 8946-9024', 9048-9144', 9172-9245', 9294-9408' ~bing(size, gradeand measureddepth) 2-7/8", L80, 11522' Packers: 9-5/8 BAKER DB @ 10692'47" Packers and SS~ (t~el~3moe~Sur~t? CAMCO 2.3 ! 2" I D @ 2197' 8905' 8731-956E 11190-11322', 11360-11460', 11528-11684' BAKER 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation 14. Attachments Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A 3800 4256 0 1050 ?00 i_ Daily Report of Well Operations [] Copies of Logs and Surveys 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed LISBURNE OP. COORD. 12/1/86 Title Date Form 10-404 Rev. 12-1-85 Submit in Duplicate General Purpose Workst;--~t AR3B-1473-D General Purpose Works iSublect ia)' · I ILI~ To TA L_ 2_.~ " ID 000 ' /- i0 ~SPH. AR3B-1473-D L3-23 Acid Treatment Summary Wahoo 5 - Transition Zone Test Perforated Interval: 11,360 - Il,&60' ND Da~~ Time Description Acid Breakdown Treatment ** Attachment 1 4-5-86 1230-1349 hrs. Pump acid breakdown treatment thru-tubing into Wahoo 5 perfs. Treatment included 10 bbls diesel w/101 U-66 (Musol) as pre-flush, 104 bbls 15% HCL (MSR) and 81 bbls 100% diesel as final flush. Maximum rate of 4 BPM w/2400 psig WHP. Total load of 195 bbls. See Attachment 1 for detail log of events. ** Flowback Summary ** Attachment 2 4-5-86 1605-2400 hrs. Open well to tank for flow test. 4-6-86 0000-0410 hrs. Continuing to flow well to tanks. Well produced back without Na assist_~211 bbls before dying. Last samples indicated oil cuts of 30%. See Attachment 2 for detail log of events for period. 4-7-86 1215-1440 hrs. 1st Na lift-started pumping Na @ 300 SCFM, increased to 800 SCFM. shutdown N= w/ 37 MSCF in hole. Total volume gain during lift - 75 bbls. 4-7-86 1530-1640 hrs. 1713-1850 hrs. 2nd Na lift. Total volume gain of 31.6 bbls for a gross total during lifting of 106.5 bbls. Flowed well for 1/2 hr., tank strap indicates 111.4 bbls. 3{d Ni lift. Total volume gain of 29.9 bbls for a gross total during lifting of 141.6 bbls in tank. " 22O0 Shut-in well and freeze protect w/18 bbls methanol and I bbl to tanks Treatment Stmmary * Volume % Water Stage Recovered (Average) _ Natural Flow 211 1st Lift 75 2nd Lift 31.6 3rd Lift 29.9 75 61 Chlorides (ppm) Max./Min. ! 92,400/33,100 Hydrocarbons Max./Min. 35.2 (Average of 6 Samples) 26,870/25,380 61/31 23,160/16,035 36/25 Total Recovered Treatment Load 367.5 bbls 195.0 bbls CTU Diesel 26.0 bbls Recovery Over Load 126.0 bbls * Sample Tabulation Attached ~oo Zoo IOO L3-~5 ~A, H O0 ~ i I ~ I F~ow LIFT LIlT L]: n' L3-23 Wahoo 5 Treatment Flovba~k Sample Tabulation Date Chlorides APl Gravity Time I Water (ppm) (API°) 4-5-86 4-6-86 4-7-86 4-7-86 1605 hrs. 74 92,600 1735 75 58,100 1910 74 44,000 2010 72 37,500 2110 64 34,600 2210 68 35,200 2310 61 34,500 0010 65 32,800 0110 63 31,900 0245 63 30,600 0310 66 30,000 0410 59 33,100 35 35 33 37 1410 89 27,080 * 1415 89 27,940 * 1440 78 27,120 41 1550 41 25,750 41.1 1555 18 24,550 39.6 1600 60 25,900 33.0 1613 79 25,790 39 1615 79 26,870 41 1620 64 25,380 * 1627 76 25,620 31 1755 57 22,870 25 1800 68 16,035 * 1805 51 23,140 29 1815 68 19,950 36 * Insufficient sample volume for accurate determination L3-23 Summary Wahoo 6/7 Date Time Pre-Stimulation Flow Test Log of Events No pre-stimulation flow test Acid Breakdown 8-31-86 Post-Stimulation Flow Test 8-31-86 9-03-86 9-04-86 09-06-86 09-10-86 Pumped 10 bbls pre-flush of diesel + 10% mutual solvent, followed up with 238 bbls 15% HCL+ additives and flushed with 72 bbls diesel. Average pump-in rate with full column of acid of 6.4 BPM at 2350 psig injection pressure. Average pump-in rate with full column of diesel of 6.3 BPM @ 2800 psig. ISIP ' 1350 psig SIP (5 minutes) = 1225 psig SIP (15 minutes) = 1175 psig Flow well back to PTF to recover load. SI for static BHP survey. Static bottom-hole pressure survey Well brought on to PTF. Average oil rate of 3700 FTP 810 psig and 47 bean choke position. Lower Zone W5 opened up for commingled flow test. Rates did not change. Water did not increase. Continuing to flow well, 3650 BOPD @ 0% BS&W @ FTP = 820 pstg 2 9/11 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions' Prepare and submit the "Initial Rel~Ort" on the first Wednesday after a well is spudded or workover operations are started Daily wort( prior to spudding should be summarized on the form g;wng Inclusive dates only Dlstr~ct F~eld Alaska JCounty parish or borough North Slope Borough Lease ADL 28322 or Umt IT,t,e Drill Prudhoe Bay State Alaska Well nO 1',3-23 Auth or W O no AFE AL0141 Parker #176 API 50-029-21513 Operator ARCO W I ARCO Alaska, Inc. Spudded or W O begun ]Date IHour Pnor status ,f a W O Spudded I 12/27/85 I 1900 Hrs. Date and depth as of 8 00 a m 12/28/85 thru 12/30/85 12/31/85 1/01/86 thru 1/o2/86 1/03/86 1/04/86 thru 1/06/86 Complete record tot each day reported 5O% 20" @ 110' 3275', (3165'), Drlg Wt. 9.4, PV 12, YP 48, PH 10, WL 15.8, Sol 9.0 Accept rig @ 1600 hrs, 12/27/85. NU diverter sys. Spud well @ 1900 hrs, 12/27/85. Drl 17½" hole to 2340', DD & surv to 3275'. 2426', 3.6°, S40.9W, 2425.91TVD, 3.80 VS, 2.99S, 2.59W 3091', 22°, S34W, 3073.22 TVD, 135.97 VS, 110.60S, 90.19W 20" @ 110' 3905', (630'), Rm'g Wt. 9.4, PV 8, YP 29, PH 9, WL 16.0, Sol 5.0 Drl, DD & surv to 3905', TOH. TIH w/angle bld'g assy, rm DD r~. 3481', 29.9°, S45W, 3423.02 TVD, 298.74 VS, 240.17S, 200.01W 3756', 34.8°, S58.7W, 3656.38 TVD, 444.54 VS, 329.58S, 315.75W 13-3/8" @ 4021' 4040', (135'), Prep f/EMW tst Wt. 8.8, PV 4, YP 2, PH 9.5, WL NC, Sol 3 Drl f/3905'-4030'. RU & rn 100 its, 13-3/8", L-80, 72# BTC csg & 2 jts, 13-3/8", K-55 BTC csg w/FS @ 4021', FC @ 3938'. Cmt w/2600 sx PF "E" & 600 sx C1 "G" w/l% CFR-2 & 1% CaClA. CIP @ 2215 hrs, 12/31/85. ND diverter, NU & tst BOPE. TIHZw/i~'' BHA, tst csg to 2500 psi, DO cmt & FS. 13-3/8" @ 4021' 4980', (940'), POOH Wt. 9.2, PV 5, YP 3, PH 10.5, WL 16.6, Sol 6.5 Perform formation tst to 12.3 ppg EMW. Drl 12¼" hole f/4040'-4980'. 4337', 41.5°, S61W, 4098 TVD, 821VS, 523S, 638W 4708', 38.1°, S61.5W, 4383 TVD, 1057 VS, 638S, 847W 13-3/8" @ 4021' 7809', (2829'), Drlg Wt. 9.4, PV 10, YP 5, PH 12.4, WL 9.2, Sol 8 DD, drl & surv 12¼" hole to 7809'. 5120', 34°, S56W, 4717 TVD, 1299 VS, 762S, 1054W 5630', 46°, S50.6W, 5110 TVD, 1619 VS, 969S, 1301W 6058', 46.8°, S51.7W, 5405 TVD, 1928 VS, 1164S, 1543W 6580', 46.7°, S53W, 5763 TVD, 2307 VS, 1396S, 1844W 7070', 45.3°, S55W, 6103 TVD, 2659 VS, 1602S, 2130W 7658', 48°, S55.2W, 6508.9 TVD, 3084.73 VS, 1840.9S, 2482.2W The above is correct For torm prepara.on and d~stnbuhon, see Procedures Manuat, Section 10, Drllhng, Pages 86 and 87 I Date C ~ 2/21/86 1TM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim InstructJolll' Th~s form is used during drllhng or workover operations If testing, conng or perforating show formation name in descmb~ng work performed Number all drdl slem tests seclL~enllaily Allach description of all cores Work performed by Producing Section will be rec, orted on ' Interim' sheets untd final completion Report official or representative test on "Final" form Subm t "llltert.l" sheets when hlled out but not less frequently than every 30 days, or [2) on Wednesday of the week in which olJ string is set SubmH weekly for workovers and following setting of oH s ring un ~1 completion I State District County or Parish Alaska North Slope Borough Alaska F~eld ~Lease or Umt Well no Prudhoe Bay I ADL 28322 L3-23 Date and dept. as of 800 am 1/07/86 1/08/86 1/09/86 1/10/86 1/11/86 thru 1/13/86 1/14/86 Complete record for each day while drdhng or workover in progress 13-3/8" @ 4021' 8458', (715'), Rm to btm Wt. 9.5, PV 14, YP 7, PH 12.1, WL 6.2, Sol 8.7 Drl & surv 12¼" hole to 8458'. 8122', 46.7°, S55.2W, 6822.9 TVD, 3426.17 VS, 2035.84S, 2762.65W 8369', 45.3°, S54.2W, 6994.5 TVD, 3603.7 VS, 2138.49S, 2907.66W 13-3/8" @ 4021' 9610', (1152'), Drlg Wt. 9.6, PV 13, YP 11, PH 12.3, WL 6, Sol 4 Drl & surv 12¼" hole to 9610'. 8806', 44.7°, S53.8W, 7303.5 TVD, 3912.3 VS, 2320.1S, 3156.6W 9360', 43.6°, S52.7W, 7701TVD, 4297.4 VS, 2550.9S, 3466.8W 13-3/8" @ 4021' 10,126', (516'), TIH Wt. 9.6, PV 14, YP 9, PH 11.2, WL 8, Sol 5 Drl & surv 12¼" hole to 10,126', TOH f/bit chg, TIH. 9917', 40.3°, S55W, 8115.27 TVD, 4669.12 V$, 2770.73S, 3767.29W 13-3/8" @ 4021' 10,611', (485'), Drlg Wt. 9.6, PV 9, YP 12, PH 11.9, WL 7.2, Sol 5.5 Fin TIH, rm to btm. Drl & surv 12¼" hole to 10,611'. 10,288', 40°, S57.3W, 8390.86, 4908.29 VS, 2903.97S, 3965.92W 13-3/8" @ 4021' 10,930', (319'), Rm'g Wt. 9.8+, PV 10, YP 5, PH 12, WL 6.8, Sol 8.5 Drl to 10,628', TOH. RU Schl, rn BGT/GR f/9285'-6500', RD Schl. RIH, rm 9255'-9482'. TIH, rm f/9700'-10,628', drl to 10,930', att 25 std short trip; hit tight spots @ 10,522', 10,398' & 10,337'. C&C mud, POH to 9035'. RIH, hit bridge @ 10,160', rm 10,151'-10,306'. 10,568', 43°, S59W, 8608.56 TVD, 5093.74 VS, 3001.79S, 4123.56W 13-3/8" @ 4021' 11,003', (73'), C&C mud Wt. 10.0+, PV 15, YP 5, PH 12, WL 7.8, Sol 10 Rm f/10,306'-10,930', drl 12¼" hole to 11,003' TD, 20 std short trip, C&C hole f/csg. The above ~s correct For form preparation and distribution see Procedures Manual Section tO Drdhng, Pages 86 and 87 2/21/861TM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instl'uctlons: This form is used during drdhng or workover operations If testing, coring, or perforating show formation name m describing work performed Number ail drill stem tests sequentially Attaci~ descrlpt,on of alt cores Work performed by Producing Section wdl be reported on "Interim' sheets until hnat comple.on Report official or representative Iest on 'Final" form II Submd "l./er.11' sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week m which od string is set Submit weekly for workovers and followmg setbng of oH str~nG until completion Oistrlct F~etd Oate and deptl3 asof800 am Alaska Cou,ty or P .... h North Slope Borough Prudhoe Bay Lease orUn,t ADL 28322 Complete record for each day while drilling or workover in progress 1/15/86 1/16/86 1/17/86 1/18/86 thru 1/20/86 1/21/86 1/22/86 State Alaska Well no I,3-23 9-5/8" @ 10,993' 11,003' TD, (0'), BO lnd'g jt Wt. 10.1, PV 15, YP 9, PH 11.8, WL 6.6, Sol 11 RU & rn 273 its, 9-5/8", 47#, L-80 BTC w/FS @ i0,993', FC @ 10,907'. Cmt w/250 sx Cl "G" w/3% KCl, 1% D-60, .1% D-133 & .2% D-46, followed by 800 sx C1 "G" w/.05 gal/sx M-451, .3% D-65 & .2% D-13. ClP @ 0530 hrs, 1/15/86. 10,906', 48°, S54W, 8846 TVD, 5334.43 VS, 3134.93S, 4323.90W 9-5/8" @ 10,993' 11,072', (69'), POOH f/core assy Wt. 9.2, PV 17, YP 10, PH 9.5, WL 6.2, Sol 7.0 RIH w/8~" BHA, tst csg to 3500 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl f/11,013'-11,072', C&C, POH. 9-5/8" @ 10,993' 11,086', (18'), Coring Wt. 9.2, PV 12, YP 6, PH 8.0, WL 5.4, Sol 7 Core #1 f/11,068'-11,086', rec'd 18'. TIH w/core #2. 9-5/8" @ 10,993' 11,207', (87'), Coring Wt. 9.3, PV 13, YP 8, PH 7.5, WL 5.8, Sol 6.6 Core #2, 11,086'-11,105', rec'd 19'. Core #3, 11,105'-11,120' rec'd 15'. Core #4, 11,120'-11,151', rec'd 31' Core #5, [1,151'-11,181', rec'd 30'. Core #6, 11,181'-i{,202', rec'd 20' Core #7, 11,202'-tl,207', incompl. 9-5/8" @ 10,993' 11,220', (13'), Coring Wt. 9.3, PV 12, YP 8, PH 8.0, WL 6.2, Sol 6.6 Fin core #7 to 11,213', lost mud, pmp'd 12 sx nut plug & 30 bbls LCM pill, POH, rec'd 12'. Lost total 50 bbls on round trip. TIH, core #8, 11,213'-11,220', rec'd 5'. 9-5/8" @ 10,993' 11,261', (41'), C&C Wt. 9.2, PV 15, YP 7, PH 8.0, WL 5.4, Sol 6.0 TIH, core #9 f/11,220'-11,221', rec .5'. TIH w/bit, rm 11,066'-11,221', C&C gas cut mud. The above is correct For form preparation and distribution see Procedures Manual Section 10 Drtlhng, Pages 86 and 87 2/21/86 T,tle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructlona' Th~s form ,s used durmq drHhng or workover ooeratlons If testrng, coring, or perforating, show formation name ~n descrrbmg work performed Number all drill stem tests sequen.alty Attach descrlphon of all cores Work performed by Producing Section will be reported on "Interim" sheets untd f,nat complehon Report official or representative lest on "F~.al" form ~) Submd: 'llllerlm" sheets when filled pul but not less frequently than every 30 days, or (2) on Wednesday of the week ~n which oll string ts set Submit weekly for workoverS and following setting of oll strln(j until completion D,str~ct F~eld Date and depth as of 800 am l County or Pamsh Alaska North Slope Borough Lease or Unit Prudhoe Bay ADL 28322 Complete record for each day whde drdhng or workover in progress 1/23/86 1/24/86 1/25/86 thru 1/27/86 1/28/86 1/29/86 1/30/86 1/31/86 State Alaska Well no 1,3-23 9-5/8" @ 10,993' 11,279', (22'), TIH w/core bbl Wt. 9.3, PV 14, YP 8, PH 8.7, WL 5.4, Sol 4.0 Circ gas cut mud thru choke, TOH. MU core bbl, TIH, CBU, core #11, 11,257'-11,279', rec'd 19.5'. TIH w/core #11. 9-5/8" @ 10,993' 11,295', (16'), Coring Wt. 9.3, PV 15, YP 7, PH 8.5, WL 5.4, Sol 5 Core #11 f/11,279'-11,289', rec'd 6.5'. Core #12, 11,289'-11,295', incompl. 9-5/8" @ 10,993' 11,393', (98'), Coring Wt. 9.3, PV 14, YP 5, PH 7.5, WL 5.6, Sol 4 Fin core #12 to 11,315', rec'd 26.5'. Core #13, 11,315'-11,341', rec'd 25.5'. Core #14, 11,341'-11,372' 29'. Core #15, 11,372'-11,383', rec'd 11'. Core #16, 11,383'-11,393', incomp. , rec'd 9-5/8" @ 10,993' 11,396', (3'), Coring Wt. 9.3, PV 15, YP 8, PH 7.5, WL 5.2, Sol 4 Fin core #16 to 11,395', rec'd 12'. Core #17, 11,395'-11,396' rec'd 1'. TIH w/core #18. 9-5/8" @ i0,993' 11,434', (38'), LD sponge core Wt. 9.3, PV 13, YP 6, PH 7.5, WL 5.0, Sol 4 Core #18, tl,396'-11,406', rec'd 11'. PU sponge core, TIH, core #19, 11,406'-11,434', TOH & LD core. 9-5/8" @ 10,993' 11,461', (27'), POOH w/core #21 Wt. 9.3, PV 14, YP 7, PH 7.5, WL 4.8, Sol 4 No rec'y rept'd f/core #19. Core #20, 11,434'-11,439' Core #21, 11,439'-11,461', POOH. , rec' 5'. 9-5/8" @ 10,993' 11,522', (61'), Core #22 Wt. 9.3, PV 13, YP 6, PH 7.5, WL 4.8, Sol 4 No rec'y rept'd for Core #21. PU drlg assy, RIH, drl 11,461'-11,514', POH. PU core bbl, RIH, core #22, 11,514'-11,522', incompl. The above ~s correct S~gna.ture . I Date I For form preparation and dlstrlbuUon J see Procedures Manual Section 10, Drdhng, Pages 86 and 87 2/21/86 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inetructione: This form is used during drilling or workover operations If testing, comng or perforahng show formation name =n describing work performed Number all drill stem tests secluentlally Attach descrlphOn of all cores Work performed by Producing Section will be reported on "interim" sheets untd fmal completion Re,port ottlcla~ or re0resentahve lest on "Final" form 1) Submit "lnlertm" sheets when hlled out but not less frequently than every 30 days. or (2) on Wednesday of the week ~n which od str~ng ~s set Submit weet<ly for workovers and following settmg of od string; untd complet{on District Freld Date and depth as of 8 00 a.m Alaska County or Parish North Slope Borough Prudhoe Bay Lease or On,t ADL 28322 Complete record for each day while drllhng or workover ~r~ progress 2/01/86 thru 2/03/86 2/04/86 2/05/86 2/06/86 2/07/86 State Alaska Well no L3-23 9-5/8" @ 11,612', Wt. 9.3, Fin core rec'd 26 11,590'- 10,993' (90'), POOH w/core #26 PV 13, YP 7, PH 7.5, WL 5, Sol 4 #22 to 11,533', rec'd 19'. Core #23, 11,533'-11,560', '. Core #24, 11,560'-11,590', rec'd 30'. Core #25, 11,595', rec'd 5'. Core #26, 11,595'-11,612', POOH. 9-5/8" @ 11,632', Wt. 9.3, Rec'd 16 10,993' (20'), Coring PV 12, YP 8, PH 7.5, WL 5, Sol 4 ' f/core #26. Core #27, 11,612'-11,632', POH. 9-5/8" @ 11,838', Wt. 9.3, Rec'd 18 drl f/ll 10,993' (206'), Drlg PV 14, YP 5, PH 7.5, WL 5, Sol 4 ' f/core #27. LD coring equip. RIH w/8½" drlg assy, ,632'-11,838'. 9-5/8" @ 10,993' 11,900', (62'), Logging Wt. 9.3, PV 14, YP 5, PH 7.5, WL 5, Sol 4 Drl 8½" hole to 11,900', 10 std short trip, CBU, POOH. DLL/MSFL/NGT/CAL & LDT/CNL/GR/CAL. Log 9-5/8" @ 10,993' 11,900', (0'), POOH w/CET Wt. 9.3, PV 14, YP 5, PH 7.5, WL 5, Sol 4 Rn LSS/GR. Rn RFT. Rn 4-arm CAL. Rn CET f/10,993'-7500', POOH. The above is correct S~grk3ture ~ ~' Date For'form I~reparatlon and dlstmbutlon see Procedures Manual Sec.on t0, Drllhng, Pages 86 and 87 2/21/86 T,t,e Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Dr$tr~ct Alaska F~eld Prudhoe Bay County or Parish Lease or Umt IT~t e Accounting cost center code State Alaska JWoII no L3-23 North Slope Borough ADL 28322 Drill Auth or W O no AFE ALO 141 Parker #176 Operator ARCO Alaska, Inc. Spudded or W O begun Spudded Date and depth as of 8 00 a m API 50-029-21513 Old TD 2/08/86 thru 2/10/86 ARCo ~10% Date 12/27/85 Released r~g Complete record for each day reported I otal number of wells (achve or machve) on this Pst center pmor to plugging and bandonment of this well our I Prior status ~f a W O, I 1900 Ers. 7" @ 11,898' 11,852' PBTD, RR 9.3 ppg filtered brine Fin rn'g CET log, RD Schl. TIH, C&C f/7" lnr, POOH. RU & rn 26 its + 1 marker jr, 7", 29#, L-80 BTC w/FC @ 11,857', FS @ 11,898', TOL @ 10,756' (7" lnr f/10,756'-11,898'). Cmt w/300 sx Cl "G" w/4% gel, 5#/sx Gilsonite, .5% FDP-C344 & .3% LW2. Bump plug. CIP @ 1015 hrs, 2/9/86. TIH w/bit & scrpr, CO to TOL. TIH w/6" bit/7" scrpr, CO cmt to 11,852' PBTD. Tst csg to 3000 psi; OK. Chg well over to 9.3 ppg NaC1 brine, POOH, LD DP. ND BOPE, NU & tst tree. RR @ 1500 hrs, 2/10/86. I New Kind of r~g TD 11,900' P~Oeoth 11,852' Date 2/10/86 Rotary 1500 Hrs. Classifications toll, gas, etc ) Oil Producing method Flowing Type completion tslngle, dual etc J Single Official reservoir namers) Ltsburne Well no Date Reservoir Producl'~g Interval Oii or gas Test time Production Oii on test Gas per day Pump size, SPM X length Choke s~ze T P C P Water % GOR Grawty Allowable Effective date corrected The above ~s correct For form preparation and d~str~butlo., see Procedures Manual, Section 10, Drilling, Pages 86 and 87 2/21/86 Title Drilling Superintendent 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~ fotu~d 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 6/10/85 85-47 KRU 3B-14 5/22/85 85-24 Teresa Gorup October 9, 1986 Page 2 (.3) LITHOLOGIC DESCRIPTION Well Name Completion Date PBU DS 3-32 PBU DS 16-21 PBU L1-9 PBU LGI- 12 Hemi Springs Unit f3 4/12/86 9/2/86 1/19/86 5/2/86 4/6/85 We appreciate your attention to this matter. ~iS'fhcere~l~ ' , ~- John F. Boyle ~ Petroleum Engineer Assistant jo/A.JFB.4 Permit Number 84-]07 85-312 85-1 86-54 85-22 ARCO Alaska Inc. ~ --~ Lisburne Engineering To: ~ate of Ak From: Pam Lambert John Boyle Date: 9-18-86 Transmitted herewith are the following: Magnetic Tape for L3-23 OH LIS Shifted Run 2 Sch 2-6-86 Tape Number 71486 Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: ~}~-~Z Lisburne Engineering To: State of Ak From: Pam Lambert John Boyle Date: 8-28-86 Transmitted herewith are =he following: Stratigraphic High-ResolUtion Dipmeter for L3-23 2-6-86 Sch Receipt Acknowled$~ent: Return Receipt PO 360 Anchora 99510 ,ge, Alas~ Transmittal No: To: State of Ak John Boyle Lisburne Engineering From: Pam Lambert Date: 7-25-86 Traasmitted herewith are the following: CH Final Prints for Lisburne Wells L2-13 Collar Log 4-6-86 Run 1 5" DA L3-23 Collar Log 4-2-86 Run 1 5" DA L3-23 Gamma Ray Log 4-2-86 Run 1 5" DA Receipt Acknowl~ Return Receipt t~~~Alask~a Inc.,,. JUL Para Lambert ATO~I~ Oil & 6~ P0 Box 100360 Anc~ Anchorage, Alas~ 99510 Transmittal No:~ ADDENDUM WELL: 2/20/86 6/02/86 L3-23 Rn CBT/VDL/GR/CCL f/11,808'-10,746'. Rn GCT gyro f/ll,800'-surf. Rn CET/GR/CCL f/11,821'-10,700'. Att to inj dn 9-5/8" x 13-3/8"; well Arctic Pak'd. Suspend operations. Drilling Superintendent ~ L£sburne £ng~neering To: State of Alaska John Boyle ~'rom: Pam Lambert Date: 6-2-86 Traasmi~ted herevith are the following: CH Final for Lisburne Wells ~L2-21 CET 1-8-86 Run 2 5" Sch ~L2-25 CET 2-6-86 Run 1 5" Sch ~L2-29 CET 1-21-86 Run 2 5" Sch "--L3-23 CET 2-18-86 Run 1 5" Sch Receipt Acknowledgement: Re~urn Receip~ to: ARCO Alaska Inc. Pa= Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmit:al Nc: To; State of Alaska Lisburne Engineering rom: Jobn Boyle Date: Pam Lambert~ April 24, 1986 Transmitted herewith are =he following: CH FinalPrint for Lisburne Well L3-23 Collar log for setting packers 2-25-86 Run 1-3 5" GO Gamma Ray 2-24-86 Run 1 5" GO PO Box 100360 Anchorage Anchorage, Alaska 99510 Transmittal No: 70~ STATE OF ALASKA ALASKA 01~E AND GAS CONSERVATION CO',~M ISSION WELL COMPLETION OR RECOMPLETION REPORT 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. 85-306 3 Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21513 4. Location of well at surface 9. Unit or Lease Name ~--~ Prudhoe Bay Unit/Lisburne 934' FNL, 679' FWL, Sec.22, T11N, R15E, UM i LOCATIOI'q2 At Top Producing Interval . VERIFIED I 10. Well Number 'J'-~' ! L3-23 1067' FSL, 1585' FWL, Sec.21, T11N, R15E, UM Surf.~,~- ! AtTotal Depth B.H.-~ 11 F~eldand Pool 733' FSL, 1133' FWL, Sec.21, T11N, R15E, UM Prudhoe Bay Field Lisburne Oil Pool 5 Elevation ~n feet (~nd~cate KB, DF, etc.) I 6. Lease Designation and Serial No. 51' RKBI ADL 28322 ALK 2320 12. Date Spudded 13. Date T.D Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, ~f offshore 116. No of Completions 1 2/27/85 02/05/86 02/1 0/86*I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18. Plug Back Depth (MD+-FVD) 19. Direct~onaISurvey 20. Depth where SSSV set 21. Th~ckness of Permafrost l1900'MD,9568'TVD 11852'MD,9530'TVD YES ~X NO [] 2230 feetMD 1900' (approx) 22 Type Electric or Other Logs Run BGT/GR, DLL/HSFL/NGT/Cal, LDT/CNL/GR/Cal, LSS/GR, RFT/GR, Col, CET/GR/AMS, CBT/VDL/GR/CCL, GCT, CET/GR/CCL, GRt 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE!WT PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 1750# Poleset 13-3/8" 68.0#/72.3# K-55/L-;10 Surf 4021' 17-1/2" 2600 sx PF "E" & 600 sx Class G 9-5/8" 47.0# L-'~0 Surf 10993' 12-1/4" 1050 sx Class G & 300 sx PF "C" 7" 29.0# L-80 10,756' 11898' 8-1/2" 300 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11,050' - 11,156' 2-7/8" !1 ,522' 10,692', 11,330' and 11,190' - 11,322' w/4 spf, 90° phasing 11,497' 11,528' - 11,684' 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.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of llthology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips See attached core description. Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 2/28/86. DAM2/WC20 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 31 LIST OF ATTACHMENTS GEOLOGIC MARKERS TRUE VERT. DEPTH 8925' 9011' 9133' 9234' 9432' 9492' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and tIme of each phase. MEAS DEPTH 11,045' 11,166' 11,334' 11,470' 11,727' 11,804' DEPTH HYDRO. PRESS. SHUT-IN PRESS. 11,053' 4373 psi 4320 psi 11,125' 4397 psi 4367 psi 11,406' 4496 psi 4268 psi Well History (completion details), Core Description, Gyroscopic Survey (2 copies) 32 I hereby certify that the foregoing is true and correct to the best of my knowledge _ ~)x~ j~ Associate Engineer S,gne~ _ -i 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 (GL) 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 10-407 Well History- Initial Report- Dally after a wall it spudded or wo~r o~ratlonl are fo~ giving inclullve datH only. North Slope Borough ~L ~28322 Unit TItta Completion APl 50-029-21~I~3 State Alaska Well no. L3-23 ~ - ' ,, I ~ _,, I u, I .~ ~"~,ll ,,,, i i i il ....i i i ii LI s~~ ~ Iom Ol~ M M' ~mpl~e ~ord for eKh day M of I~ 2/22/86 thru I A.CO w, 50:1 l,,, · I,.o. 8tldUl ifaW.O. 2/23/86 0230 7" @ 11,898' 11,852' PBTD, RIH v/parr guns Wt. 9.5 ppg NaC1 Accept rig @ 0230 hfs, 2/23/86. ND vellhead, NU BO~E, pull 7" 2/25/86 ~/26/86 2/27/86 x 10" 5M tbg hgr. TsC BOPE. RIH v/15 its, displ out fzeeze~ protection, POOH. TIH w/4", 4 SPF, 90° phasin~ chi conveyed guns & R-3 pkr assy. RIH w/parr guns on 2-7/8" vrk string. 7" @ 11,898' 11,852' PBTD, RIH v/gage ring/JB Wt. 9.4 ppg Nat1 RU WL, RIH w/GR/CCL, log 11,100'-10,700' to correlate perf guns, RD WL. POOH 68', set pkr. RU WL, parr 11,050'-11,156' 11~190'-11,322' & 11,528'-11,684'. Bullhead 28 bbls dn tbg, rev 2 tbg vol, well stable. POOH, LD perf guns. RUWL, RIH w/gage ring/JB. 7" @ 11,898' 11,852' PBTD, TsC upper pkr Wt. 9.4 ppg NaC1 RIH w/gage ring/JB/CCL to 11,813'. Rn lower & middle pkr per well plan, RD. Rn upper pkr & tail assy on wrk string. Sting into middle pkx, set upper pkr &tst. 7" @ 11,898' 11,852' PBTD, P,n'g compl string Wt. 9.4 ppg NaC1 brine POOH, LD 2-7/8" wrk string. RU & begin rn'g compl string. For for~l~perltlon 4(l~PdlstrflDutlofl, ¢{~ Ul. PrMMdUml Manual. Section 10, Drilling, Plgal 8~ and 87. 3/13/86 [Title Drilling Superintendent AtlanticRichfieldCompany Daily Well History-Final Report Inltn~llefta: Prepare end submit the "Penal R~poll" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Re~e~' ihould be submitted also when operations ara suspended for an mdefimte or appreciable length of time On workovers when an official test Is not required upon completion, report completion and representative test data in blocks prowded. The "PInal Repo~" form may be used for reporting the entire operation it Space il available. Accounting cost center code District Icounty or Parish I Alaska Field ILeaae or Unit I Prudhoe Bay Auth, or W,O. no. [Title I AffE AL0184 Roll'n 4 North Slope Borough State Alaska I Well no ADL #28322 I L3-23 Completion AP1 50-029-21513 Ol~retor I A.R.Co. W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun IDate Complete I 2/23/86 2/28/86 Date and depth aa of 8:00 I.m. 2/28/86 Complete record for each day reported Iotal number of wells (active or inactive) on this, pst center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0230 Hrs. 7" @ 11,898' 11,852' PBTD, Instl BPV in tree Diesel Rn 2-7/8", 6.5~, L-80 EUE 8RD IPC prod string w/7" DB perm pkr @ 11,497', TT @ 11,347', SSSV @ 2230', 9-5/8" DB pkr @ 10,692' & 11,330'. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. Close SSSV. Instl BPV. RR to standby @ 1300 hfs, 2/28/86. Wait on weather to move rig. Old TD Released rig Claaalflcstlona (o11, gas, etc.) 0il Producing method Flowing Potential test data New 11,852 TD PB Depth Date I K nd of rig 1300 Hrs.[ Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Ltsburne Well no. Date Reservoir Producing Interval OII 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 .~e Is correct [Title I Date Drilling Superintendent For form Ld'"~r;tlon and ~rlbution, III Procl~]"-rea Mlnull, Section 10, Drilling, Pagaa ~ and g7 Well Core L3-23 #1 L isburne Core Description CONFIDENII L 11,068-11,086 Cut 18' Recovered 18' 1/17/86 4.0' Dolomite; mudstone. 5.0' Interbedded dolomite and dolomite limestone; skeletal grainstone. 6.7' Limestone and dolomite limestone; interbedded skeletal and non-skeletal grainstone. 2.3' Limestone; cherty wackestone. Co re #2 1.5 1.2 7.3 2.0 5.0 2.0 Il,086-11,105 Cut 19' Recovered 19' Limestone; skeletal wackestone. Dark gray silty shale. Limestone; skeletal grainstone. Dolomite; skeletal grainstone. Dolomite limestone; skeletal grainstone. Dolomite; skeletal grainstone. 1/17/86 Core #3 2.2I 0.2' 2.6' 10.0' ll ,105-11,120 Cut 15' Recovered 15' Limestone; non-skeletal grainstone. Silty shale; dark gray. Limestone; skeletal grainstone. Limestone; non-skeletal grainstone. 1/18/86 Core #4 11,120-11,151 Cut 31' Recovered 31' 1/18/86 2.0' Limestone; cherty, skeletal grainstone. 13.0' Limestone; interbedded skeletal and non-skeletal grainstone. 11.4' Limestone; skeletal grainstone. Well Site Description by L. J. Casarta ~ CONFIDENTIAL Core #4 Continued 0.2' 2.4' 2.0' Il,120-11,151 Cut 31' Recovered 31' Silty shale; dark green. Dolomite; silty wackestone. Shaly siltstone. 1/18/86 Core #5 10.O' 4.3' 5.2' 3.5' 2.5' 1 .81 Il,151-11,181 Cut 30' Recovered 30' 1/19/86 Silty dolomite; cherty. Dolomitic limestone; skeletal grainstone. Limestone; skeletal grainstone. Interbedded dolomitic siltstone and silty dolomite. Limestone; skeletal wackestone. Interbedded siltstone, skeletal lime-grainstone and silty dolomite. Interbedded lime grainstone and chert. Core #6 16.5' 3.5' 11,181-11,202 Cut 21' Recovered 20' 1/19/86 Limestone; non-skeletal grainstone in part cherty. Limestone; silty, cherty mudstone/wackestone. Core #7 5.0I 7.0' 11,201-11,213 Cut ll' Recovered 12' 1/20/86 Cherty limestone; interbedded mudstone and skeletal wackestone and grainstone. Cherty limestone; skeletal grainstone. Core #8 5.0' 2. O' No Recovery. Well Site Description by L. J. Casarta 11,213-11,220 Cut 7' Recovered 5' Limestone; skeletal grainstone. 1/21/86 Core #9 Core #1 0 0.5' 10.0' 6.4' 2.9' 2.5' CONFIDENTIAL 11,220-11,220.5 Cut 0.5' Rec. 0.5' 1/21/86 Chert and silty shale. Drilled up the interval 11,220.5-11,257 11,257-11,279 Cut 22' Rec. 19.5 1/23/86 Limestone interbedded skeletal and non-skeletal packstone. Silty limestone; skeletal grainstone. Cherty lime mud/packstone. No Recovery. Core #11 0.3' 6.2' 3.5' 11,279-11,289 Cut 10' Rec. 6.5' Silty shale. Cherty, dolomitic mudstone. No Recovery. 1/23/86 Core #12 5.41 18.0' 3.5' 11,289-11,315 Cut 26' Rec. 26' 1/24/86 Interbedded chert, shale, siltstone and lime mudstone. Limestone; skeletal grainstone. Silty cherty, lime mudstone. Core #1 3 1.8I 18.2' 3.9' 2.6' 0.5' Well Site Description by L. J. 11,315-11,341 Cut 26' Rec. 25.5 Cherty, lime mudstone. Limestone; skeletal grainstone. Dolomite; skeletal grainstone. Shale; medium gray. No Recovery. Casarta 1/25/86 Core #14 6.8' 4.9' 17.3' 2.0' 11,341-11,372 Cut 31' Rec. 29' Shale; silty, medium gray. Silty, cherty, lime mudstone. Limestone; skeletal grainstone. No Recovery 1/26/86 Core #1 5 5.3I 3.4' 1.3' 1.0' 11,372-11,383 Cut ll' Rec. ll' Limestone; skeletal grainstone. Cherty limestone; skeletal packstone. Limestone; grainstone. Limestone and chert. 1/26/86 Core #16 4.4' 11,383-11,395 Cut 12' Rec. 12' 1/27/86 Limestone; skeletal grainstone. Interbedded dolomite and dolomitic limestone; skeletal wackestone to grainstone. Core #17 1 .0' 11,395-11,396 Cut 1' Rec. 1' 1/28/86 Interbedded chert and skeletal lime grainstone. Core #18 2.4' 8.6' 11,396-11,406 Cut 10' Rec. Il' 1/29/86 Interbedded chert, shale and skeletal lime grainstone. Limestone; skeletal grainstone. Core #19 Core #20 11,434-11,439 Cut 5' Core #21 11,439-11,461 Cut 22' Well Site Description by L. J. Casarta Sponge Cores no Litholog~, Description ll ,406-11,434 Cut 28' Recovered 28' Recovered 5' Recovered 22' Core #22 Core #23 Core #24 2.6 3.2 0.8 2.4 9.0 0.8 4.2 5.1 1.9 From ll ,461-11,514 Drilled up. ll ,514-11,533 11,533-11,560 11,560-11,590 Cut 19' Cut 27' Cut 30' Recovered 19' Recovered 27' Recovered 30' 2/2/86 Limestone; skeletal grainstone. Dolomite; mudstone. Limestone; skeletal grainstone. Limestone; skeletal wacke/mudstone. Limestone; skeletal grainstone. Siltstone; greenish-gray. Dolomite; mud stone. Limestone; skeletal grainstone. Dolomite; skeletal wackestone. Core #25 0,3' 1.1' 1.7' 2.0' 11,590-11,595 Cut 5' Rec. 5' Dolomite, skeletal mud/wackestone. Siltstone; greenish-gray. Dolomite; skeletal mud/wackestone. Skeletal, lime grainstone interbedded with chert. 2/2/86 Core #26 Well 8.1' 2.1' 0.9' 5.4' 0.5' Site Description by L. 11,595-11,612 Cut 17' Rec. 16.5 Limestone; skeletal grainstone. Dolomite; mudstone. Limestone; skeletal grainstone. Limestone; skeletal wackestone. No Recovery. J. Casarta 2/3/86 Core #27 10.O' 5.4' 3.1' 1.5' 11,612-11,632 Cut 20' Rec. 18.4 2/4/86 Interbedded dark gray shale, siltstone and lime wackestone. Silty, dolomitic limestone; skeletal grainstone. Limestone; non-skeletal grainstone. No Recovery. Well Si te Description by L. J. Casarta - STATE OF ALASKA ~ ALASKA OTL AND GAS CONSERVATION COi~MISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG , 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] -~ 7. Permit Number 2. Name of Operator ARCO Alaska, Inc. 85-306 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21513 4. Location of well at surface 9 Unit or Lease Name 934' FNL, 679' FWL, Sec.22, T11N, R15E, UN Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number To be submitted when gyro is received. L3-23 At Total Depth 11. Fmld and Pool To be submitted when gyro is received. Prudhoe Bay Field 5. Elevation m feet (~nd~cate KB, DF, etc.) 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 51' RKB ADL 28322 ALK 2320 12. Date Spudded 13. Date T.D. Reached 14. Date Comp, Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1 2/27/85 02/05/86 02/10/86I N/A feet MSL N/A 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. D~rect~onal Survey 20. Depth where SSSV set I 21. Th~ckness of Permafrost 11900'MD 11852'MD YES ~ NO [] N/A feet MDI 1900' (approx) 22. Type Electric or Other Logs Run BGT/GR, DLL/MSFL/NGT/Cal, LDT/CNL/GR/Cal, LSS/GR, RFT/GR, Cal, CET/GR/AMS, CBT/VDL/GR/CCL, GCT, CET/GR/CCL 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# H-40 ' Surf 110' 30" 1750# Poleset 13-3/8" 68.0#/72.~)# K-55/L-II0 Surf 4021' 17-1/2" 2600 sx PF "E" & 600 sx Class G 9-5/8" 47.0# L-80 Surf 10993' 12-1/4" 1050 sx Class G 7" 29.0# L-80 10,756' 11898' 8-1/2" 300 sx 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 N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of I~thology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description to be submitted when received. RE¢£1VED APR 1 6 1986 Nuka 011 & 6u Con;, Commission Anchor~le Form 10-407 DAM/WC89 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .~. 30. . ," ~ ' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted when gyro is received. RFT data to be submitted when received. 31 LIST OF ATTACHMENTS Well History, Addendum (dated 2/27/86) 32 I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned__ (~ ~ ~ T,tle Associate Engineer Date ~'~4-"~ 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 sup~plemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Mbthod of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, S,,h, ut-~in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 ADDENDUM WELL: 2/20/86 L3-23 Rn CBT/VDL/GR/CCL f/11,808'-10,746'. Rn GCT gyro f/ll,8OO'-surf. Rn CET/GR/CCL f/11,821'-10,700'. Dril~i~ Superintendent MDate SUB. SURFACE DIRECTIONAL ~URVEY [~]UIDANCE ~]ONTINUOUS ~"~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL L3-23 (934'FNL, 679'F~, S22, TllN, R15E) LISBURNE POOL/PRUDI-IOE BAY, NORTH SLOPE, ALASKA _ I Jol~ Reference No_. 7[337 SARBER/WEST Oat.....~e 14-MARCH- 1986 Computed 8~. OGDE~ GCT DIRECTI2NAL SURVEY CUSTOMER LISTIN3 FO~ LISBURNE L3-23 PRUOHDE BAY/LISBURtE POOL NOR[H SLOPE~AL~SKA SURVEY DATE: ~8-FEB-86 ENGINEER: WEST/S~RBER METHODS 3m COM~T~TION TOOL LgCATIgN: TANSENTIAL- AVERAGE~ DEVIATION AND ~ZIMUTH INTERP2LATION: LINEAR VERTICAL SECTI2N: dDRIZ. DIST. PRgJECTEO O~TO A TRRGET AZIMUTH OF SOUT~ 56 DE~ 53 MIN ~EST ARCO ALASKA, INC. LISBURNE 13-23 PRJDHOE B&Y/LISBURNE POOL ND~TH SLOPE,ALaSKA COMPUTATION DATE: 14-M~R-86 PAGE DATE 3F SJRVEY: 1B-F_=B-86 KELLY BUSHING ELEVATION: ENGINEER: WEST/SARBER 51.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SdB-SEA COJRSE tEASURED VERTICAL VERTICAL 3EVIATI3t AZIMUT~ 3EPTM DEPTt DEPTH 3EG qIN 3E3 O.OO 0.00 -51.00 0 0 N O ) E 100.00 100.00 49.00 0 10 S 29 28 E 200.00 200.00 149.00 0 14 S D 25 E 300.00 300.00 249.00 0 27 S 24 47 W ¢00.00 399.99 348.99 0 36 S 9 2 W 500.00 499.99 ¢48.99 0 65 S 11 28 W 500.00 599.97 548.97 0 54 S 16 25 W ?00.00 699.96 548.95 0 65 S 37 57 H 800.00 799.96 748.96 0 38 S 38 ~1 W 900.00 899.95 849.95 0 34 S 41 7 W 1030.00 999.95 948.95 1130.33 1099.94 1068.9~ 1230.00 1199.94 1148.94 1300.00 1299.93 1248.93 1600.00 1399.93 13~8.93 1500.33 1499.93 1448.93 16~0.0~ 1599.93 1548.93 1700.00 1699.93 1645.93 1830.00 1799.93 1748.93 1900.00 1899.32 1~43.92 2030.00 1999.~2 1948.92 2100.00 2099.92 2048.92 2200.00 2199.91 2148.91 2330.00 ~299.90 2248.90 2~D0.03 2399.~8 2348.88 2500.00 2&99.57 2448.57 0 33 S 43 23 W 033 S 31 3 W 0 27 S 26 12 W 0 23 S 2 29 W 0 25 S 15 55 E 0 23 S 25 39 E 0 21 S 33 19 E 0 14 S 31 49 E 0 8 S 26 $ W 0 19 N 82 39 E 0 .~0 0 52 0 38 2 35 5 %0 2500.00 2598.B0 2547.80 8 12 2700.00 2597.65 2665.45 10 39 2800.00 2795.29 2900.00 2892.25 28~1.05 16 15 30~0.33 2987.01 2935.01 20 16 3100.00 3079.65 3028.45 24 54 3200.00 3168.~3 3117.03 29 55 3300.00 3253.33 3202.03 32 38 3430.~0 3337.59 3285.59 31 14 3500.00 3423.~9 3372.89 29 56 3500.00 3510.18 3659.18 31 10 3700.00 359~.53 35~3.53 33 55 3800.00 3676.~6 3625.46 36 4 3~00.00 3755.71 370~.71 39 16 N 56 6? E N 67 55 E N 55 ~+2 E S 53 19 W S 53 51W S 5% 32 W S 69 4~ W S 39 2% W S 32 49 ~ S 31 2~) W S 29 53 W S 30 21 W S 36 25 W S 68 2O W S 58 3 W S 59 58 W S 55 3 W V!RTICAL DOGLEG RECTANGULAR CDORDItATES HSRIZ. DEPARTURE SECTION SEVERITY N3RTH/SOUTt EAST/WEST OI;I. AZIIUTH FEET DEG/IO~ FEET FEET FEET DEG MIN 0.00 D.O0 0.00 N O.O0 E -0.02 0.05 0.11 S 0.10 E 0.03 0.53 0.43 S 0.24 E 0.61 0.17 1.02 S 0.06 W 1.29 0.13 1.91 S 0.30 W 2.07 0.3~ 3.06 $ 0.48 W 3.19 O.lO 4..52 S 0.86 W 4.42 0,11 5.81 S 1.49 W 5.57 0.05 6.75 S 2.25 W 6.61 0.11 7.59 S 2.93 W 0.00 ~4 i) 0 E 0.15 S 40 59 E 0.49 S 29 7 E 1.03 S 3 24 1.94 S 8 51 W 3.10 ~.60 S 10 48 W 6.00 S 14 20 7.12 S 18 23 W 8.14 7.53 O.11 8.30 S 3.58 W 8.47 0.55 9.03 S 6.22 W 9.23 0.12 9.79 S 4.54 W 9.76 0.1~ 10.69 S 4.81 W 10.07 0.14 11.21 S 4.72 W 10.23 3.07 11.B8 S 6.4~ W 10.27 0.27 12.~6 S 4.14 W 10.26 0.15 12.89 S 3.85 W 10.36 3.13 13.16 S 3.79 W 10.39 3.72 13.34 S 3.70 W 9.04 S 23 19 W 9.97 S 25 3 ,I 10.84 S 25 19 ~ 11.54 S 24 38 W 12.16 S 22 49 a 12.69 S ZO 34 W 13,13 S 18 21 W 13.45 S 15 36 ~ 13.69 5 1~ 3 W 13.84 S 15 30 W 9.75 O.OB 12.99 S 3.17 W 8.87 0.30 12.41 S 2.~9 W 7.52 0.26 11.82 S 1.27 W 5.98 1.27 11.10 S 0.10 E 5.97 5.27 11.55 S 0.72 W 16.71 2.91 16.03 S 7.11 W 26.96 2.38 23.17 S 17.07 W q. 3.20 3.19 33.15 S 29.96 W 63.40 3.83 47.73 S 44.56 W 86.69 3.78 68.%0 S 58.88 W 13.37 S 13 44 12.66 11.89 S 11,10 S 0 31 E 11.67 17.54 S 23 54 28.78 S 35 22 44.68 S 42 6 65.30 90.25 S 40 43 W 115.02 %.15 149.13 5.12 190.28 ~.33 237.12 1.65 285.63 5.79 334.37 ~.03 384.75 4.32 438.34 2.79 495.61 3.71 556.49 ~.75 94.90 S 75.4.2 W 121.22 S 38 28 d 127.70 S 94.74 W 159.01 S 35 34 ~ 167.99 S 117.60 W 205.06 S 34 59 ,~ 213.69 S 143.72 W 257.52 S 33 55 W 258.80 S 172.20 W 310.85 S 33 38 ,t 296.11 S 205.05 W 360.74 S 3~ 49 ,1 325.85 S 266.80 W %08.76 S 37 8 d 352.58 S 293.35 W 658.56 S 39 45 W 383.54 S 341.53 W 513.56 S 41 41 W 419.05 S 391.05 W 573.17 S 43 1 W ARSO ~,LAS(Am IYC. LISBURNE 13-23 PRJDHDE B~Y/LISBURNE POOL N32TH SL3PE,AL~SK~ CDMPdT~TI]V DATE: 14-MAR-8$ PAGE' 2' DATE DF SURVEY: 18-FEB-86 KELLY BUSHING ELE~T£DN: 51,00 FT ENGINEER: WEST/SARBER [NTE~POL&TED VALJES FOR EVE~ 100 FEET, OF MEASURED DEPTH TRUE SdB-SEA COJRSE ME~SURE3 VERTICAL VERTI'AL 3EVI~Ti3Y AZIMUTH DEPTH DEPT~ DEPTH 3EG qIN DES 40DO.OD 3830.99 3779.99 42 31 4100.30 3904.50 3853.60 42 13 4200.00 3978.88 3927.88 41 58 4300.00 ¢053.37 %002.37 41 32 4%00.03 ~128.95 %071.95 40 3 4500.00 ~206.13 %155.13 39 6 ~5DO.DO ~28~.12 %233.12 38 25 4790.0~ ¢362.83 %311.83 38 3 6800.00 ~441.54 439~.54 37 54 49~0.~ %520.51 %469.61 37 ~7 5000.93 %600.%3 ~549.43 36 26 5100.3~ ¢681.78 %530.98 33 54 5200.03 %765.54 ~71¢.54 33 ~9 5300.~0 4847.23 %795.23 36 %9 5~00.00 4925.54 ~876.~4 39 %9 5500.00 5000.71 %949.71 42 %4 5500.00 5072,39 5021,39 45 !3 5700,00 51%2.%3 5091.43 45 27 5830.DD 5212,50 5151,50 45 32 59~0,00 5282,57 5231,57 45 33 6030.00 5351.)7 5303.97 46 33 6130.00 54~0.56 5367.56 46 6200.00 5488.73 5437.73 47 12 6300.00 5556.78 5505.78 46 6~30.30 5625.50 557%.60 46 6500.00 5694.31 5643.31 46 33 6630.3~ 5763.34 5712.0~ 46 32 6700.00 5832.07 5781.07 46 13 6830.30 5901.3% 5850.3~ 46 1 6)00.00 59TI.35 5920.05 45 7000.DD 5040.81 5989.81 45 32 7100.00 5111.24 5060.24 44 52 7200.30 5182.%6 5131.46 44 7300.00 $254.35 5203.05 44 33 7~O0.OO 5324.59 5273.59 45 56 75D0.00 5393.31 $3~2.31 47 9 7600.00 5460.85 5~09.85 47 7730.33 5527.37 5476,37 48 36 7800.00 5593.74 5542.74 48 8 7930.33 5650.71 5609.71 47 32 VERTICAL D02LEG RECTANSULAR COORDINATES H3RIZ. DEPARTURE SECTION SEVERITY N3RTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEEr, FEET FEET DEG MIN S 58 3q, W 622.26 S 59 32 W 589.91 S 59 43 W 756.76 S 60 ,9 W 823.41 S 61 25 W 888.73 S 62 1% W 952.07 S 62 48 W 1014,34 S 62 19 W' 1075.72 S 63 5 W 1137.11 S $~ 11 W 1197.87 S 61 18 W 1257.73 S 55 I W 1315.51 S %8 23 W 1370.12 S ~7 23 W 1426.99 S %8 21 W 1~88.25 S %) 18 W 1553.65 S ~9 46 W 1622.79 S 50 22 W 1693.66 S 50 lO W 176%.54 S 50 ~ W 1835,38 S 50 ~8 W 1905.90 S 51 29 W 1979.31 S 52 5 W 2052.19 S 52 23 W 2125.23 S 53 15 W 2197.60 S 53 19 W 2270,11 S 53 13 W ~3~2.61 S 53 16 W 2414.81 S 53 35 W 2485.81 S 5~ 13 W 2558.41 S 5% 47 d Z629.99 S 54 53 W 2700.94 S 55 18 W 2771.09 S 55 27 W ~8%3.89 S 55 3% ~ 2911.75 S 55 4~ W 2984.38 S 55 %% W 3058.11 S 55 33 W 3132.76 S 55 21 W 3207.53 S 55 1% W 3281.77 1.63 0.1B 1,18 1.87 0,96 0.73 0.62 1.45 %54.19 S 446.67 W 537.02 S'4% 31 W %89.02 S 504.71 W 702.76 S 45 54 522.72 S 562.55 W 767.92 S 47 6 556.39 S 620.15 W 833.17 S 48 6 588.%1 S 677.26 W 897.17 S 49 0 W 518.34 S 733.36 W 959.25 S 49 51 W 547.14 S 788.93 W 1320.39 S 50 38 575.51 S 843.70 W 1380.81 S 51 19 704.11 S 898.35 W 1141.~0 S 51 54 W 730.99 S 953.36 W 1201.35 S 52 31 3.21 5.33 3.08 3.48 2.81 2.88 1.1% 0.23 3.29 3.48 758.20 S 1007.08 W 1260.58 S 53 1 ~' 788.26 S 1056.46 W 1318.12 S 53 16 W 822.64 S 1099,22 W 1372.96 S 53 11 ~ 861.56 S 1141.67 W 1%30.34 S 52 57 W 903.31 S 1187.65 W 1~92.14 S 52 44 W 946.78 S 1237.37 W 1558.0~ S 52 34 d 991.96 S 1290.45 W 1527.$5 S 52 27 W 1337.7~ S 13~5.20 W 1598.96 S 52 21 W 1383.29 S 1~00,12 W 1770.27 S 52 16 W 1129.09 S 1~5%.83 W 1841.56 S 52 11 W 1.09 3.20 0.86 0.63 0.09 3.42 0.22 0.42 0.57 1175.05 S 1510,23 W 1913.51 S 52 6 d 1220.73 S 1566,89 W 1985.28 S 52 4 ~ 1265.94 S 1624.47 W 2059.~3 S 52 4 W 1310.74 S 1682.39 W 2132.71 S 52 4 d 1354.59 S 1743.19 W 2205.26 S 52 6 W 1397.94 S 1798.49 W 2277.89 S 52 8 W 14,41.36 S 1856.72 W 2350.52 S 52 10 ~ 1%84.69 S 1914.66 W 2~,22.86 S 52 12 k } 1527,55 S 1972.60 W 2~9~.97 S 52 14 W 1569.91 S 2030.51 W 2566.6% S 52 17 W :3.56 3.7) 0.41 1.05 1.82 1.35 1.09 0.35 0.41 9.75 1611.%9 S 2088.87 W 2538.23 S 52 21 d 1552.35 S 21~$.91 W 2709,15 S 52 25 W 1692.51 S 2206.48 W 2779.26 S 52 29 W 1732.18 S 2261,9~ W 2349.00 S 52 33 d 1772.34 S 2320.35 W 2919.79 S 52 37 W 1813.25 S 2380.38 W 2992.34 S 52 42 W 1854.72 S 2441.35 W 3:365.98 S 52 46 d 1896.81 S 2503.03 W 3140.55 S 52 50 W 1939.24 $ 256%.62 W 3215.27 S 52 54 W 1981.49 S 2625.7D W 3289.~,6 S 52 57 W A:~Cg ~L. AS(A~ LISBUR~iE '- 3-23 PRdDH3E B,Y/LISBJR~IE ~301 NDRTH SLO~E~ALAS,(A CDqPdT6TID~ DATE: 14-M~R-85 D~TE DF SJRVE¥: 18-FEB-86 KELLY BUSdIN5 ELEVATI3N: ENGINEER: WEST/SARBER INTERPOLATED VALDES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SJB-SEA CDJRSE 4E~SURE] VERTIC&L VERTI"AL DEVI&TID~ AZIM~JTH DEPTH DEPTq DE~TH )EG MIN DEG MI~ 8030.33 5728,53 5677.63 46 58 8100,30 6797,10 5745,10 46 38 8200,00 5865,99 581¢,99 46 12 8390.00 5935.56 5886.56 45 35 8400.00 ?005.34 5954.94 44 58 8500.00 7075.96 ?025.96 ~4 8500.00 7147.87 ?095.87 45 3 8700,00 7218.40 7167.40 44 50 8~00.00 7289.44 7238,44 44 32 8930.33 7360.88 7309.88 44 18 9330.3~ 7~32.55 7381.65 43 59 9100.90 7504.58 7~53.68 43 51 9200,99 7576.81 7525.81 43 ¢5 9300,00 7549,22 759~.22 43 34 9¢90.33 7721.78 7679.78 43 13 9590.00 7795.17 77¢6.17 42 25 9530.00 7869.24 7818.24 41 44 9730,00 7944.32 ?893.02 41 ~6 9830.03 8019.21 7968.21 40 50 9900.30 )095.29 8046.29 40 8 L0390.00 8172.33 8121.03 39 36 L0190,33 9249.53 8198.53 38 52 i02DO,DD )327,36 8275.06 39 33 .0300,00 8403,5¢ 8352.54 40 ~? .0600.00 8¢78.58 B¢27,68 41 ~5 L0530.93 8552.31 ~501.31 43 34 .0530,30 8623.93 8572.93 44 50 :0700.00 8693.99 86~2.99 46 15 .0830.03 8762.23 8711.23 47 33 ,0900.00 8828,~7 8777.97 48 38 51,00 FT S 55 ? W 3355.13 S 54 53 W 3427.98 S 54 32 W 3500.41 S 5~ 10 W 3572.17 S 53 45 W 3643,11 S 53 35 ~ 3713.40 S 53 33 W 3783.80 S 53 28 W 3854.56 $ 5325 W 3924,82 S 5317 W 399~.66 0.25 0.35 3.59 0.83 3.5:1 3.52 9.90 0.40 0.37 0.37 2:)23.40 S 2685.95 W 3362.81 S 53 0 ~' 2065.16 S 2745.68 W 3435.64 S 53 3 W ?107.03 S 2804.84 W 3508.10 S 53 5 d 2148,87 S 2863,24 W 3579,91 S 53 6 W 2190,58 S 2920,66 W 3550,93 S 53 7 ~ 2232.~1 S 2977.37 W 3721.34 S 53 8 d 2274.25 S 303t..12 W 3791.85 S 53 8 / Z316.41 S 3091.11 W 3862,73 S 53 9 2358,30 S 314,7.66 W 3933,11 S 53 9 ~1 2400.03 S 3203,83 W 4,303.08 S 53 9 'd S 53 1 W 4064.15 S 52 51 W 4133.35 S 52 43 W ~202.43 S 52 39 W 4271.23 S 52 25 W 4333.82 S 52 27 W 4407.56 S 52 35 W ~74.5~ S 53 5 W ~5¢0.76 S 53 ~9 W 4505.56 S 5~ 25 W ~671,38 0,19 9,28 0,40 3,12 0,60 3,25 0.gB 0,72 0,8¢ 0,81 26¢1.80 S 3259,55 W 4072.72 S 53 9 W 2483.59 S 3314.91 W 414,2.09 S 53 9 ~ 2525.47 S 3370.07 W 4,211.34 S 53 9 W 2567.38 S 34,24.87 W 4,280.32 S 53 8 W 2509.31 S 3479.41 W ~349,12 S 53 7 d 2550.72 S 3533.27 W 4417.05 S 53 7 d 2591,50 S 3585.59 W 4484.23 S 53 6 W 2731.58 S 3639.50 W 4550,51 S 53 6 d 2770.99 S 3692.42 W 4516.53 S 53 6 W 2809,02 S 374,5.01 W 4581.42 S 53 7 W S 54 55 W 4735.45 S 55 38 W ~798.50 S 55 52 W 4~61.77 S 55 t W 4926,18 S 54 I W ~992,10 S 53 2 W 5059,64 S 52 2 W 5123.22 S 51 23 W 5200,27 S 50 ~2 ~ 5273,00 S 51 4 W 5347,03 1.07 0.89 1.63 1.35 2.07 1.50 1.7~ 1,25 1,lO 2846.09 S 3797.33 W 4745.51 S 53 8 d 2882.02 S 3849.16 W 4~08.54 S 53 10 W Z317.55 S 3901.53 W 4871.76 S 53 12 d 2953,99 S 3954.66 W 4~36.13 S 53 14 d 2992.29 S 4008.38 W 5002.09 S 53 15 ~ 3032,56 S ~062,75 W 5069,75 S 53 15 W 3075,95 S 4118,11 W 5[39.53 S 53 15 ~ 3119.23 S 4,174.12 W 5210.84 S 53 13 W ) 3165.22 S 4230.95 W 5283.89 S 53 11 W 3212,30 S 4288.63 W 5358.29 S 53 9 a S 51 55 W 542;?.06 S 52 50 W 5494.12 S 52 55 id 556~.4,8 S 53 39 W 5632.97 S 53 43 ~ 5700.14, S 53 4,5 W 5765.01 S 53 53 W 5839.13 S 53 54 W 5893.57 S 53 57 W 5955.36 S 53 5? W 5015.28 t.,03 1,31 1,4,.% 0,58 0,83 1,38 1,4,4 16,05 0,00 3259,25 S /+34?,58 W 5433,61 S 53 8 W 3303.18 S 4~04,96 W 5505,88 S 53 8 W 3345.82 $ 44,61,15 W 5576.~,1 S 53 7 d 3386.80 S 4516.20 W 5545.0¢ S 53 7 d 3425.54 S 4570.4,1 W 5712.31 S 53 8 d 3465.65 S 4623.61 W 5778,28 S 53 8 d 3503.54, S 4675.~4 W 5842.¢8 S 53 9 W 354,0.36 S 4,726.78 W 5906,0.0 S 53 9 d 3577.38 S 4776.79 W 5967.86 S 53 10 d 3613.27 S 4826,12 W 6328.86 S 53 10 d 1000.00 8894.71 8843.71 48 7 1100.00 8963.79 8912.79 44 56 IZOO,O0 9034,57 8983.67 44 37 1300,00 9107.40 9055.40 ¢2 28 1490.00 ~181,37 913~,37 4,2 1 1530,170 9256.51 9205,51 40 26 1500.00 9333.19 ~7282.19 39 ~4 1700.00 9410.41 9359.41 38 50 1800.00 3488.98 3437.98 37 34 1930.33 9568. ,~2 ~517.22 37 35 VERTICAL DOGLEG RECTANSULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NDRTH/SDUTH EAST/WEST DIST, AZIMUTH FEET DE$/IOO FEET FEET FE~T: DE~ MIN CO4PUTATI34 DARE: 14-MAR-85 PAGE ALAS(A, IqC. DATE DF SURVEY: 18-F~B-85 LISBURNE L3-23 PRUDH3E BAY/LISBJR4E POOL N3RTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WEST/S*RBER 51.00 FT INTERPOLATED VAL3ES FOR EVE~ 100) FEET 3: MEASURED DEPT TRUE SUB-SEA COURSE 4E&SUR:] VERTI'~L VERTISAL 3EVICTION AZIMJTH DEPTH DEPT9 DEPTH 3EG 4IN DEG MI4 0.03 0.00 -51.00 0 0 1DD0.33 999.95 948.95 0 ~3 2030.30 1999.92 1948.92 0 22 3000.00 2987.31 2935.01 ZO 16 4330.~3 3830.99 3779.99 42 31 5030.3~ ~500.~3 ~54~.43 36 26 6000.00 5351.97 5300.97 46 33 7000.00 5040,31 5989,81 45 32 8330.33 5728,53 5577.63 46 ~B gO00.OO ?432.55 7381.65 43 59 VERTICAL DOGLEG RECTAN3ULAR CDORDIiATES H]RIZ. DEPARTURE SECTION SEVERITY NORTH/SDUT~ EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET: FEET FEEl DEG MIN L0030.3:) B172.D3 812.1,03 39 35 LIO00,O3 !3894.71 8843.71 48 7 N 0 } E 0.00 S ~3 23 W 7,53 N 45 3 E 9,75 S 31 23 W 115,02 S 58 36 W 622.26 S 51 lB W t257.73 S 53 48 W t905.90 S 5~ ~7 W Z629.99 S 55 7 W 3355.13 S 53 t W ~064,15 S 5~ 55 d ~735.45 S 51 55 W 5422.06 O.O0 0.11 3.03 ~.15 1.63 3.21 1.Og 2.55 0.25 0,30 N 0.00 E 0,00 N 3 0 E 8,30 S 3,58 W 9,04 S 23 19 W 12.99 S 3,17 W 13,37 S 13 44 W 94.90 S 75.62 W 121,22 S 38 28 d 654.19 S 446,67 W 537.02 S ~6 31 W 75B.ZO S 1007.08 W 1260,58 S 53 1 W 1175,D5 S 1510,23 W 1~13.51 S 52 6 F 1511.49 S 2088,87 W 2538,23 S 52 21 2223.~0 S 2685,95 W 3362,81 S 53 0 ~ ~41oB0 S 3259,55 W 4372,72 S 53 9 W 0.89 4.03 28¢6.0g S 3797.33 W 4745.51 S 53 8 W 3259.25 S 4347.58 W 57+33.61 S 53 8 W AR=O ~LAS~A, I~C. LISBURqE L3-23 PRJDHO= B~¥/LISBURqE NS]TH SLOPE,ALaSKA C2qPUTATI]~ DALE: 14-M~R-$$ PAGE DATE OF SURVEY: 18-FEB-86 KELLY BUSHING ELEVATION: ENGINEER: WEST/SARBER INTERPOLATED VALJES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SJB-SEA COJRSE ~E~SURED VERTICAL VERTICAL 9EVICTION AZIMUT4 3EPT4 9EPT4 DE~rH ~EG ~IN DES MI~ 0.0~ 0.00 -51.00 0 0 N 0 ~ E 51.00 51.00 O.O0 0 11 S 61 32 E 151.00 151.90 103.00 0 12 S 27 4~ E 251.00 251,00 200.00 0 25 S 30 22 W 351.03 351.00 30~.00 0 31 S 1~ 38 W ~51.01 451.00 400.00 0 39 S 8 lg W 551.02 551.~0 500.00 0 53 S 15 9 W 551.03 651.00 600.00 0 ~9 S 25 51 W 751.D~ 751.00 700.00 0 ~0 S 3) 1~ W 851.05 851.80 803.00 0 38 S 38 ~5 W 951.05 951.00 )OO.O0 1~51.~5 1051.00 100~.00 1151.35 1151.00 1109.00 1251.05 1251.00 1200.00 1351.D? 1351.00 1300.00 1651.07 1651.00 1400.00 15~1.07 1551.00 1500.00 1551.07 1651.00 150~.00 1751.07 1751.00 l?OO.O0 1~51.~8 1851.00 1800.00 0 33 S 4Z 33 W 0 33 S ?+3 5 W 0 30 S 29 3~ W 0 ~_4 S 13 3) W 025 S 8 I E 0 2~, S ZO 53 E 0 22 S 29 8 E 0 18 S 3~ 33 E 0 9 S 10 21 E 0 8 S 1 2 ~ 1951.0~ 1951.00 1900.00 2051.08 2051.20 2000.00 2151.09 2151.00 2100.00 2251.10 2251.00 2200.00 2351.10 2351.00 2300.00 27+51.2~ Z451.~0 2400.00 2551.75 2551.00 2500.00 0 21 N 54 3~ E 0 30 N 49 18 E 0 ~7 N 65 9 E 0 56 N 51 ?+5 E 0 26 S 85 23 W 437 S 57 7 9 S 52 13 W S ?+5 3 W S 3?+ 2? W 2552.82 2651.00 2600.00 9 24 2754.53 2751.20 2703.00 12 2 2857.40 2851.D0 2800.00 1~ ~6 2961.77 2951.00 2900.00 18 3068.90 3051.00 3009.00 23 3180.?+0 3151.00 3100.00 29 2 32~7.58 3251.00 3200.00 32 37 37+15.67+ 3351.00 3303.00 30 55 3531,27 3451.00 340~.00 30 6 35~7.9~ 3551.00 350~.00 32 26 3768.59 3651.00 3600.00 35 3~93.92 3751.00 3703.00 39 Z 4327.27 3851.~0 3800.00 42 ~0 S 31 51 W S 30 1~, W S 29 29 ,~ S 30 1~ W S 38 9 W S 51 53 W S 6~ 10,~ S 55 5 W S 55 .~7 W S 58 4) W 51.00 FT V~RTIC~L DOGLEG RECTANSULAR CD2RDIN~TES HSRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIiUTH FEET DE~?IO0 FEET FEET FE~T DES ~.00 O.O0 0.00 N 0.00 E 0,00 9.58 0.00 S 0.00 E -0.01 0.21 0.25 5 0.18 E 0.28 0.12 0.69 S 0,12 E 0,95 0.26 1.~3 S 0.20 W 1.67 ~.13 2.?+7 S 0.38 W 2.61 0.1~ 3.77 S 0.65 W 3.81 0.86 5.27 S 1.11 W 5.03 0.17 6.31 S 1.89 W 5.11 0.07 7.20 S 2,60 W 0.00 4 0 0 E 0.00 S 58 23 E 0.)1 S 35 27 E 0,70 S 9 57 ; 1.~ S 7 59 W 2.50 S 3 44 ~ 3,83 S 9 50 ~ 5.38 S 11 55 6.59 S 16 40 W 7.85 S 1~ 52 ~ 7.09 2.15 7.96 S 3.26 W 8.02 0.05 8.56 S 3.92 W 8.88 0.21 9.43 S ~.45 W g.54 0.27+ 10,16 S 4.77 W 9.94 0.15 10.85 S ~.79 W 10.17 0.18 11.57 S 4.59 W 10.26 3.05 12.19 S ?+.30 W 10.27 O.11 12.70 S 3.98 W 10.29 :).23 13.05 S 3.77 W 10.47 0.5?+ 13.27 S 3.85 W 8.51 S 22 17 W 9.51 S 2~ 21 d 10.43 S 25 15 ,~ 11.22 S 25 9 ~ 11.86 S 23 50 W 12.?+5 S 21 38 ~ 12.92 S 19 27 W 13.31 S' 17 23 kl 13.58 S 16 6 ~ 13.82 S 16 9 ~ 10.07 0.28 13.20 S 3.41 W 9.38 0.41 12.73 S 2.90 W 8.21 0.22 12.08 S 1.92 W 5.70 0.2?+ 11.~7 S 0,52 W 5.79 3.11 10.96 S 0.23 E 10.37 2.17+ 13.59 S 3.51 W 20.52 2.25 19.?+6 S 11.80 W 35.04 ~.59 27.38 S 23.58 W 53.87 3.25 40.41 S 37.96 W 76.28 3.59 58.91 S 52.55 W 13.54 S 14 28 W 13.05 12.24 S 9 2 W ll.?+B S 2 36 W 10.96 S 1 12 E 14.04 S 1G 29 W 22.76 S 31 14 36.59 s 40 6 55.44 S 43 1Z 79.01 S ?+1 47 W 103.45 4.17 137.93 181.67 4.72 235.95 1.6~ 293.22 $.09 349.84 5.3D 409.92 3.50 477.40 552.66 4.65 640.78 1.37 84.01 S 68.71 W 108.53 S 39 16 W 116.83 S 88.47 W 146.54 S 37 8 W 159.54 S llZ.B3 W 195.41 S 35 16 W 212.55 S 143.06 W 256.21 S 33 56 ~ 265.16 S 177.12 W 318.87 S 33 44 W 306.11 S 218.00 W 375.80 S 35 27 W 338.56 S 268.56 W ~32.15 S 38 25 W 373.11 S 325.50 W ~95.86 S 41 11 W ~t6.91 S 387.88 W 569.44 S 42 56 W ~53.81 S 462.59 W 555.00 S 44 55 ~ A~'..2 6. LAS~A~ IYC. LISBURNE L3-23 PRJDHDE B*Y!LISBJRNE POOL N]RTH SLgPE,AL~SK~ CD~PUT~TI]N DATE: 14-M~R-85 P~GE, 6, D~TE DF SURVEY: 1B-FES-B$ KELLY BUS4ING ELE~ATI3N: ENGINEER: WEST/S~RBER INTErPOLaTED VALJES FOR EVE~ 100 FEET OF SgB-SEA DEPTH TRUE SJB-SEA CDJRSE ME*SURE3 VERTISAL VERTISAL DEVI~TI2N AZIMdT4 DEPTH DEPT~ DEPTH 3EG MIN DEG MI~ ~152.50 3951.00 3~00.00 41 59 4~96,83 ~051,00 ¢00).00 41 33 4~28.68 ~151.00 ~10).00 39 ~0 ~557.$~ ~251.00 ~200.00 38 ~0 4584.97 ~351.00 ~300.00 38 0 4~11.97 ~451,~0 ~400,00 37 50 4938.19 ~551,00 ~50D.00 37 10 5062,46 ~651,00 ~500,00 35 1 5182,5~ ~751,00 6700,00 33 31 5304,70 ~851,00 ~800,00 36 59 5~33,29 ~951,00 ~903,00 40 ~7 5569.51 5051,00 5000,00 44 ~6 5712.~2 5151.00 5103.00 45 lB 5~54.9a 5251.00 5209.00 45 31 5998,58 5351,00 5309,00 46 33 5144.48 5451.00 5400.00 46 59 6~91.55 5551.00 550~.00 46 51 6~36,93 5651.00 5603,00 46 36 6582,~8 5751,00 5703,00 46 34 6727,35 5851,00 5803,00 46 Il 6871,2~. 5951,00 5903,00 45 ~4 7014.53 5051,00 500~,00 45 27 7155,92 5151.00 5100,00 44 31 7295.72 5251.00 6200.00 4~ 30 7~38,23 $351,00 $30~,00 46 24 7585,~3 5451.00 6400,00 47 40 7735.77 5551.30 5500.00 48 31 7385,$3 6651.30 5600.00 47 39 8032.79 5751.00 $703.00 46 50 8178,32 6851,80 6803,00 46 19 51.00 FT 8322.03 6951,00 5gOD,O0 45 27 8~53,51 7051,00 7000.00 44 ~1 8504.~3 7151.00 710~.00 45 5 8745.93 7251.30 7200.00 44 i6 83B6.1~ 7351.00 7303.00 44 ~0 90~5.~9 7~51.00 7400.00 43 57 9154.Z1 7551.00 7500.00 43 50 9302.65 7651.~0 7603.00 43 35 9~60.02 7751.00 7707.00 42 53 9575.56 7851.00 7800.00 42 0 VERTICAL OO3~ES RECTANSULAR CODRDIY~TES H]RIZ, DEPARTURE SECTION SEVERITY NDRTH/SOUTq EAST/WEST DIST. AZ[IUTH FEET DEGIIOO FEET FEET FEET; DES MIN S 59 46 W 731.72 S 59 5g W 821.31 S 61 46 W 907.01 S 52 41 W 988,07 S $2 23 W I066.49 S 53 ZO W 1144,41 S 63 3~ W 1220,82 S 57 51 d 1294,33 S 49 8 W 1360,55 S ~7 25 W 1429,76 S 18 38 W 1509,60 S 49 43 W 1601,22 S 50 22 W 1702,31 S 50 3 W 1803,53 S 50 47 W 1905.87 S 51 55 W 2011,61 S 52 21 W 2119,09 S 53 22 W 222~.43 $ 53 15 W 2329.90 S 53 21 W 2434.52 S 5~ 2 W 2537,80 S 5~ 49 W 2540.34 S 55 8 W 27~0.23 S 55 27 W 2837.89 S 55 41 W 2939,38 S 55 4~ W 3047,34 S 55 28 W 3159.61 S 55 15 W 3271,18 S 55 5 W 3379.09 S 54 36 W 3484.75 S 5~ ~ ~ 3587,86 S 53 37 W 3687.80 S 53 33 W 3786,93 S 53 28 W 3886.87 S 53 1~ W 3985.03 S 52 59 W ~081.80 S 52 46 W ~177.72 S 52 30 W ~272.92 S 52 27 W ~357,09 S 52 32 ~..~458,32 1.16 1.05 0.65 0.81 1.51 1.55 5.15 3.35 3.48 510,09 S 560,88 W 743,47 S 46 40 W 555,33 S 618,36 W 831,11 S 4~ 4 W 597.11 S 693,42 W 915.08 S 49 16 ~ 535.08 S 765,43 W 99~,59 S 50 19 W 671,20 S 835,49 W 1071,71 S 51 13 W 707,46 S 906,88 W 1148,61 S 5! 58 W 741,11 $ 974,15 W 1224,02 S 52 44 " 776,57 S 1038,80 W 1296,98 S 53 13 ~16,26 S 1091,97 W 1363,33 S 53 13 w 863.57 S 1143.74 W 1~33.14 S 52 56 ~ 3,05 3,42 0,27 0,35 1,12 0,95 0,92 0,0~) 0,35 3,31 917.50 S 1203,81 W 1513.65 S 52 41 977.91 S 1273.87 W 1505.74 $ 52 29 W 1~43,28 S 1351.92 W 1707.57 S 52 20 1108,46 S 1430,24 W 1809,50 S 52 13 1174.40 S 1509,43 W 1912,48 $ 52 6 l~.4O,B1 S 1592,35 W 2018,?1 S 52 4 1306,97 S 1677.51 W 2126.55 S 52 4 1370.62 S 1761.77 W 2232.13 S 52 7 W 1433,74 S 1846,53 W 2337.79 S 52 10 1496.49 S 1930,50 W 2~42,61 S 52 13 W 3.87 0,60 0,65 1,01 0,71 0.8~ 0,91 1.08 0,6~ 0.5~ 1557,84 S 2013,79 W 2545,02 S 52 16 W 1517,65 S 2097,33 W 26~+8,57 S 52 21 W 1574.93 S 2179.10 W 2748,43 S 52 27 W 1730.~8 S 2259.46 W 2846,00 S 52 33 1787.03 S 2343.17 W 2~347.39 S 52 39 d 1848,56 S 2432.45 W 3355.22 S 52 45 W 1912.~1 S 2525.17 W 3167.38 S 52 52 1975.~ S 2617.00 W 3278.88 S 52 57 2337.10 S 2705.61 W 3786.7~ S 2~97.95 S 2792.07 W 3692.63 S 53 0.81 0.33 0.97 0.38 0.22 3.17 0.13 0.13 l .03 1.49 2158,08 S 2875,95 W 3595,62 S 53 6 ~ 2217.19 S 2956.73 W 3595,70 S 53 8 W 2276.11 S 3036.6~ W 3794.98 S 53 8 ~ 2335.67 S 3117.12 W 3895.09 S 53 9 W 2394,25 S 3196,09 W 3393.~3 S 53 9 a 2452,~4 S 3273.68 W ~90.~1 S 53 9 d 2510.~8 S 3350,35 W 4185,57 S 53 9 W 2568.~1 S 3425,22 W 4282,~2 S 53 8 W 2525.97 S 3501.10 W 4376.46 S 53 7 W 2681,71 S 3573,67 W 4~67.96 S 53 6 W CDMPUT~TIDN DATE: 14-M~R-8$ PRGE .' 7 , ARCO ALAS(A, IqC. LISBURNE L3-23 PRJDHDE B*YtLISB'JRNE POOL NORTH SLOPE,ALaSKA 9ATE DF SJRVET: 18-FE~-85 KELLY BUSHING ELECAT[ON: ENGINEER: WEST/SARBER INTERPOLATED VAL~ES FOR ~VEN 100 FEET O= SUB-SEA DEPTH TRUE SJB-SEA COJRSE IEASURE2 VERTICAL VERTIOAL ~EVI~TIDN AZIMgT4 DEPTH DEPTfl DEPTH ~EG ~IN DE~ 51.00 FT 9709.35 7951.00 7900.~0 41 33 9)G1.91 8051.00 BO00.O0 40 30 9972.55 B151.~O 8100.00 39 ~6 .01~1.T5 8251.00 8200.00 38 52 .0231.11 8351.00 ~300.00 39 51 ,0353.01 8451.00 8400.00 41 23 · 0498.19 8551.00 8500.00 43 3~ ,0538.35 8651.00 8500.00 45 ~2 .0783.~1 8751.00 BTOD.O0 47 22 · 0~33.~ ~851.00 8800.00 48 58 · 1081.89 8951.00 ~900.00 45 17 · 1222.85 9051.00 9OOD.O0 44 3 · 1359.03 9151.00 9109.00 42 15 .1~92.75 9251.00 920~.00 40 32 .1523.16 9351.00 ~30~.00 39 60 !1751.85 9451.~0 9403.00 38 .1~78.27 9551.00 950~.00 37 35 .1900.00 9568.22 9517.22 37 35 S 53 ? W %546.97 S 54 3 W 4633.84 S 56 %7 W 6717.98 S 55 39 W ~799.59 S 55 43 W ~881.62 S 54 21 W ~967.58 S 53 3 W 505~.40 S 51 48 W 5156.29 S 50 48 W 5260.85 S 51 2~ W 5372.07 S 52 49 W 5481.33 S 53 5 W 5580.44 5 53 ~0 W 5672.68 S 53 ~5 W 5751.33 S 53 5~ W 58~.91 S 53 55 W 5925.80 S 53 5? ~ 5003.04 S 53 57 W 5015.28 1.OD :).91 3.57 l.O? 1.34 1.00 2.10 1.47 1.15 1.19 2.27 0.45 1.45 9.45 1.11 0.00 2735.62 S 3644.47 W 4556.83 S 53 6 2787.08 S 3714.50 W 4543.8'5 S 53 7 2836.02 S 3783.03 W 4728.04 S 53 8 Z882.$3 S 3850.05 W 4809.63 S 53 10 2~28.59 S 3917.95 W 4891.59 2977.96 S 3988.~4 W 4977.55 S 53 15 W 3931.B1 S 4061.76 W 5968.51 S 53 15 3091.81 S 4139.50 W 5166.70 S 53 14 3157.50 S 4221.49 W 5271.69 S 53 12 3228.06 S 4308.25 W 5383.43 S 53 9 3295.43 S 4394.7~ W 5693.05 S 53 8 ~ 3355.65 S 4473.93 W 5592.61 S 53 7 d 3~10.36 S 4548.24 W 5584.80 S 53 8 ~ 3~6Z.88 S 461~.83 W 5773.59 S 53 8 d 3512.26 S 4687.41 W 5857.28 S 53 9 W 3559.98 S 4752.85 W 5938.17 S 53 9 W 3505.~7 S 4815.40 d 6015.$1 S 53 10 W 3513.27 S 4826.12 W 6028.86 S 53 10 d VERTICAL DOSLEG RECTANSULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG~IOO FEET FEET FEE~' DEG MIN LISBURNE 13-23 PR~DMDE BAY/LISBURNE NORTH SLOPE~AL~SKA M~KER TOP ~AH30 ~OP ~AHDO TOP ~H~O TOP WAH30 TOP dAMOD PBTD TO ZONE ZONE ZONE ZOqE ZONE ZO NE CDMPUTATI3~ D~TE: 14-M~R-85 P30L , INTERPOLATED VALJES FOR 4EASJRED DEPTH BELOW KB 11065.00 11t55.00 11334,00 11670.00 11727.00 11B0~.00 IIBSZ.DO 11~00.~0 SHOSEN HORIZONS ORIGIN= TVD PROM KB ~925.25 9010.58 9132.50 9233.76 9530.18 9568.22 P&SE" 8 D~TE 3F SURVEY: 1B-FEB-B6 KELLY BUS9ING ELECATIDN: 51.00 ENGINEER: WEST/SARBER 934' SJB-SEA B87~.25 ~B59.58 9381.50 93B0.50 9~79.18 ~517.2Z 679 ' SJRFASE LO(iA ~T FWL~ SEC 22, r~lN RECTANGULAR COD NDRTH/SDUTt E 3279.45 S 4 3331.33 S 3400.38 S 3454.09 S 3550.B~ S 3578.81 S 35~6.0~ S 3~13.27 S rION ~ R15E~ RDINATES AST/WEST 3?3.72 W ~2.03 W 53~. 57 W SO7.85 W 740.3~ W 778.7'5 W BO2,4¢ W B2~.12 W FT CD4PUT~TI3~ DARE: I~-M~R-8$ P~$E 9 ~RSD &LAS~A~ I~C. DATE DF SURVEY: 18-F~B-85 LISBUR~E ~.3-23 PRU3HDE B~Y/LISBUR~E N3,~TH ~LDPE~&L~S(A P30L KELLY BUSHIN~ ELEVATION:- ENGINEER: WEST/S~RBER 51.00 D~IGIN: 934' FNL~ IEASJRED DEPTH TVD BELOW KB FROM KB SJB-SEA 679' SJRFACE LDCA FWL~ SEC 22, TI1N RECTANGULAR CO0 NDR~H/S3UT~' E TIDN ~ R15E~ UM RDIN&TES ~ST/WEST TOP 4AHOO ZD,~E 7 TOP 4~H3D ~31E 5 ~OP 4AHgO ZOnE 5 TOP TOP 4~H30 ZOtE 2 TO 11045.00 8925.25 8874.25 11166.~0 9010.58 B959.58 1133¢.00 9132.50 9081.50 11~70.00 ~233.76 ~182.76 11727.00 9431.50 9380.50 llBO~.O0 9~92.15 9~1.15 11852.00 9530.18 9~79.18 11900.00 9568.Z2 ~517.22 3;?7 333 3~0 3¢5 355 357 35g 35[ . 1. O. 4. O. B. 6. 3. ~$ S 33 S 38 S 09 S B9 S 81 S O~ S 27~' S FINAL WELL LDC~TI]N *T TO: TRJE SUB-SEA HEASJRE3 VERTICAL VERTI:AL DEPTH DEPTH DEPTH 9DRIZONF*L ~EP&RTURE DISTANCE AZIMUT9 FEET 3EG 11903.03 ~568.22 ~517.22 6028.86 S 53 10 W FT SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL L I SBURNE L3-23 FIELD PRUOHOE BAY/L I SB. POOL COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00007]3~7 WELL L3-23 (934'FNL, 679'FWL, TllN, RI5E) VERTICAL PROJECTION ?'--r---- ~-~ ~- ~-- -~ ............ ~ .............. ; ~ -, ~.-~. ~ .... ~.~:~ :~ ~: E $: 7'. [ ~:.LL... L~. E 7 ~ '].:~' ~ L :' $ 7'.L ~ ~'.I. ] .: ~' L~. ~ ~' L I ' ' ' -~ ~-T .................. T ~ ........... ~ ~ * ~ ..... ' ........... ~ ........ ~ ............... ' ' ' ::~ :":: :~-- ~o~o--~. ........ ...... ~-.~ ............... ~ ................... + ......:.-: :-.:. :. ~.~.:. ~'...~ ,, E.--~ ~..L'~'.~ "' :"": 77: ~ ....... ': .... ~nnnl ....... .... ' ~.':.:.;..~..:i"~;.: '::;: :.;:;.~.:'":~:'::: :-~-::: :-:.-;';:4-: ;..:-:'-:~':"~ ::: :'.::: :.:.:::::.:.:.:: L..~ :':' _;:.:.:.;. :: ! ::;:..:.~. :. ::: ::: :-r::: :. :::: t-: :~ ::::::::::::::::::::::: :':~': ~'~:~: s~s~': f: :.: :' ';':-: ~':: :': :: ....., ...... ..... : ....... , .............. ............................................ ,,. 'T ;[T ..... ~T'T T"'T't T'T'I T"T'T T'~;; ;'; T ! T'T'T'T T't T T t", ..... :-~ ....... ~"'T"t "'T'~: f "TT T T"-T'T'T:~ :~' :" ' ': ' '; ~ '" l, ~;- ~ . _' ' . . ; t . ~ }' ' ' ~ ' ' ' ' ~ · ; ' ' ~ ....... ; · · ' ' · ' ' : : i : : ';'.;.~':s'::..s.:".s'::;;s-: :.: :":;":~"';'~':.':: ~.:--: :.:. ~. :;":.. : 'z .~;': :: ':'-: .: ; :":'.::-t;;.~';"t';:. :':::'~:-:':s': :' :": ..... ~.'".; ~ ..... :.': .... : "77'7' .... T'TTT'"'TT'TT!'TTT' '~'~"''T' ~ ..... : ........ ~-?'~'~ ....... ;; ......... ; ........ T ..... ;'' T T",-," F",'~'T-T ............... '~ T"T"T- 'T~h~'? T' *.' ."T-T"T'T"~' . ...... 235. PROJECTION ON VERTICAL PLANE 236. - S6. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT WELL L3-Z3 (934'FNL, 679'FWL, S22, TllN, R15E) HORIZONTAL PROJECTION NORTH 2000 ! ooo - 1 ooo -2000 -=~ooo -4ooo SOU'TH -SO00 -SO00 WEST REF 000071337 $CP, L£ = 1/1000 IN/FT '-~ .... ~""; ........ ~ ....... ~-~--~ ....... ~.---;. ~. ~ ....... ~--; ..... :-,-N-,--* .... ~-;. ;....--;-.g ......... ;~ ............ ~ ........... g. ;. '. ~ ;-.2.~ ............. ~ ~ ...... ~ . . . : . . : . : , , . : . . ~,,, ,, , , , , . ~ , ~ , . : : : : : , , ~ ~ . ~ : : :::: :::~ ~ , . ; ' I ' ' m ..~ .~ ~.~ ~+x i-;--.-: i_;.~ :;4 ;-~ .... ~-.~: I--:. ~ :-4 .-:-~; ~.--:-;-4 :--.--;~-:-~. :-&;.;--~--~-~.--;-;-:-;~4 ;.i.. -~ .;--; ..... ~--:~: ..... :m''~ ~ ~': ' :' ~ +':' '? '+'' '~': '; '": ~ ': ~ :':';' ~:-"-~'~";: '*"+~, ......... ;"~ ~'~"~':'"~'~ "~F ,'~ ........... ~ +"*~ .... ~ -F ~ ~ ~' -+'* .... : ;'~' ~ ~: ~ ~ : ~ ': :'~ ~'~'F:--~':4~""~ ~'~ ~ :'4' ~- "";' ~:~'"~"~"~'""~ ~"~": '" ~"; ~ :" ~-.~4 ~ ........ ~ ~.; ' ' * ~ ' ' ' T' ~ T T .... T ' --r,~* ........ + * ....... · · ~ r ................. r-g- ~--~ - -- ;-- g-* ...... v 4 -, .... ;. g.~, g. ~ + .+ .4 ..... ;.-;.;~- y; ~r' ~ T T ~ ' T ' T*'~ ~* * ........... ~ ....... T ..... *-+*T' + * + ....... T ............ T'* ........... 1''* ...... T'~ ? .... t + I ' ' ' ' ......... ~ ............ ~ .................. :-,_i'z'~ .*. :** :. ~:~ ;.~ '-:~: ~'r: :.L: '~. :::: :. :'~ '.i :: :'~ ::..~..: :.:: :::'~:..:.:: 2.:::f:: :.:.:: ~ :_L: L::_:":: -SO00 -4000 -3000 -2000 -1000 0 1000 2000 EXACT RADIUS OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH O. 0 FT TRUE VERTICAL DEPTH 0.0 FT DISTANCE NORTH 0.0 FT DISTANCE EAST 0.0 FT BOTTOM HOLE LOCATION COURSE LENOTH S0~9.! FT COURSE AZIMUTH 299.2 OEO MEASURED DEPTH ll90O.O FT TRUE VERTICAL DEPTH 9S68.? FT DISTANCE SOUTH 38]3.2 FT DISTANCE WEST 482S.4 FT REF 00007)337 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. PERATOR, HELL N~K AND NUMBER- Required Date Received Remarks Completion Report Well History Samples re Chips Registered Survey Plat ~~ /~ ~/Z~~ ~ ...... Inclination Survey ~ ....... , ~ ~l~ Directional Survey ~rill Stem Test Reports ~~~ ~ ~. ,,. Production Test Reports 'Log Run Digitized Data To: ARCO Ai~$ka Inc. Lisburne Engineering Sohio Don Fisher Date: Pam Lambert March 18, 1986 Transmitted herewith are ~he following: ,,~Magnetic Tapes for Lisburne Well L2-33 ~OH LIS Unshifted 3-2-86 Run 2 Tape Number 71325 Sch Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Anchorage, Alaska 99510 Transmittal No: ALASKA C._ AND GAS CONSERVATION CO, AISSION STATE OF ALASKA 4ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wel~(Yl~ Workover operation [] 2 Name of operator ARCO Alaska, Inc. 3. Address ~.~. Permit No. ~-~' ~ ~ i i i-''~' . APl Number P. O. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 93b~' FNL, 679' FWL, Sec.22, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 51 ' RKB I 6. Lease Designation and Serial No. ADL 28322 ALK 2320 50- 029-21513 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L3-23 11. F~eld and Pool Prudhoe Bay Field Lisburne 0ii Pool For the Month of February , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] L~ 1900 hfs, 12/27/85. Dr]d 17-1/2" hole to #030'. Ran, cmtd, & tstd 13-3/8" csg. Dr]d 12-1/4" hole to 11,003'. Ran, cmtd, & tstd 9-5/8" csg. Dr]d 8-1/2" hole to 11,068'. Cored f/11,068' - 11,221'. Cont'd dr]g 8-1/2" hole to 11,257'. Cored f/11,257' - 11,461'. Cont'd dr]g 8-1/2" hole to 11,514' Cored f/11,514' - 11,632'. Cont'd dr]g 8-1/2" hole to 11,900'TD (2/5/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 11,852'. Secured we]] & RR L~ 1500 hfs, 2/10/86. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91 °5¢, H-40, weld conductor set ~ 110'. Installed w/1750¢ Po]eset. 13-3/8", 68.0¢/72.0#/ft, K-55/L-80, BTC csg w/shoe 4021'. Cmtd w/2600 sx PF "E" & 600 sx Class G. 9-5/8", 47.0¢/ft, L-80, BTC csg w/shoe @ 10,993'. Cmtd w/1050 sx Class G. 7", 29.0¢/ft, L-80, BTC csg f/10,756' - 11,898'. Cmtd w/300 sx Class 6. 14. Coring resume and brief description Core ¢1 f/11,068' - 11,086'; cut 18' Core #2 f/11,086' - 11,105'; cut 19' Core #3 f/11,105' - 11,120'; cut 15' Core ¢4 f/11,120' - 11,151'; cut 31' Core #5 f/11,151' - 11,181'; cut 30' Core #6 f/11,181' - 11,202'; cut 21' recovered 18 recovered 19 recovered 15 recovered 31 recovered 30 recovered 20 (see attached sheet) 15 Logs run and depth where run BGT/GR f/9285' - 6500 CET/GR/AMS f/10,993' - 7500' DLL/MSFL/NGT/Cal3 LDT/CNL/CR/Cal ~ LSS/GR ~ RFT/GR / Cal ~/ depths not available 16 DST data, perforating data, shows of H2S, m~scellaneous data None 17 I hereby certify that the foregoing ~s true and correct to the best of my knowledge. SIGNED ~/~~ ~"~2~.~,,' TITLE Associate Engineer DATE NOTE--Repo'/on this form is required for each calendar month, regardless of the status of operations, and must be filed m duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAH/HR22 Submit in duplicate Monthly Report of Drilling and Workover Operations L3-23 February, 1986 (cont'd) ITEM #14: Core #7 f/11,202' - 11,213'; cut 11, recovered 12' Core #8 f/11,213' - 11,220'; cut 7', recovered 5' Core #9 f/ll ,220' - 11 ,221 '; cut 1 ', recovered 0.5' Core #10 f/11 ,257 Core #11 f/11 ,279 Core #12 f/11 ,289 Core #13 f/11 ,315 Core #14 f/ll ,341 Core #15 f/ll ,372 Core #16 f/ll ,383 Core #17 f/ll ,395 Core #18 f/11 ,396 Core #19 f/ll ,406 - 11 ,279 - 11 ,289 - 11 ,315 - 11 ,341 - 1 I ,372 - 11 ,383 - I 1 ,395 - 11 ,396 - 11 ,406 - 11 ,434 Core #20 f/11 ,434 - 11 ,439 Core #21 f/11 ,439' - 11 ,461 Core #22 f/11 ,514 - 11 ,533 Core #23 f/ll ,533 - 11 ,560 Core #24 f/11 ,560 - 11,590 Core #25 f/11 ,590 - 11 ,595 Core #26 f/ll ,595 - 11 ,612 cut 22', recovered 19.5' cut 10 , recovered 6.5' cut 26 , recovered 26.5' cut 26 , recovered 25.5' cut 31 , recovered 29' cut 11 , recovered 11' cut 12 , recovered 12' cut 1', recovered 1' cut 10', recovered 11' cut 28', recovery not available cut 5', recovered 5' cut 22', recovery not available cut 19', recovered 19' cut 27', recovered 26' cut 30', recovered 30' cut 5', recovered 5' cut 17', recovered 16' Core #27 f/11 ,612 - 11 ,632 ; cut 20' , recovered 18' To: State of Alaska John Boyle Lisburne Engineering From: Pam Lambert Date: March 7, 1986 Traasmitted herewith are the following: OH Final Prints for Lisburne Well L3-23 -'~ LSS/GR 2-6-86 Run 2 2"&5" Sch ~ X~RFT 2-6-86 2 5" Sch ~'~ ~ DLL/MSFL 2-6-86 Run 2 2"&5" Sch x~ ~"LSS Waveforms 2-6-86 Run 2 '5" Sch x~ ~ Natural GR Spectroscopy 2-6-86 Run 2 2"&5" Sch '~WLDT/CNL (raw) 2-6-86 Run 2 2"&5" Sch -~LDT/CNL (poro) 2-6-86 Run 2 2"&5" Sch ~ ~Dual Dipmeter 2-6-86 Run 2 5" Sch ~"° Four arm caliper 1-10-86 Run 1 5" Sch 'x~ "~CNL in 9 5/8 cag 2-6-86 Run 2 2"&5" Sch CET 2-7-86 Run 2 5" Sch Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 .~nc~ora~ Anchorage, Alaska 99510 Transmittal No:~ To: Tohn Ba','l e ARCO Al=ska inc. Lisburne Engineering Date: ~rom: Para Lambert {~ [~,1 3c~ February 27, 1986 Transmitted herewith are the following: .Magnetic Tapes for Lisburne Wells L2-29 OH LIS Shifted Run 1 Tape Number 71151 Sch 1-6-86 L3-23 OH LIS Unshifted Run 2 2-6-86 Tape Number 71255 Sch · __ /_ s - ~.f ~ ~ ?77- .~ - ~?e~._ Receipt Ac~owledg~ent: ~ ~~. ~-~ $,, ~ ~ ~ns. ~mmi~ Return Receipt to: NC Alas Anch0mge P~ ~ ATO 477 PO Box 100360 ~chorage, Alas~ 99510 Transmittal No:~O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COmlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 934' FNL, 679' FWL, Sec. 22, TllN, R15E, UM 1005' FSL, 837' FWL, Sec. 21, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 51', Pad 21 12. NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~]~ Alter Casing Stimulate -~ Abandon Repair Well [] Change Plans Pull Tubing [] Other 6. Lease Designation and Serial No. 7. Permit No. 85-306 8. APl Number 50- 029-21513 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well Number L3-23 11. F~eld and Pool Prudhoe Bay Field ADL 28322 ALK 2320 Lisburne Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Perforations [] Altering Casing [] [] Stimulation [] Abandonment [] [] Repairs Made [] 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., proposed to conduct the following on Lisburne Well L3-23' 1. Stimulate Wahoo Zone 4 with 6500 gallons of 15% HC1. The acid will be pumped through tubing and flowed back for recovery. 2. Production test of Wahoo Zone 4. 2 days if no oil production, 40 days if oil is produced. 3. Isolate Wahoo Zone 4 with tubing plug. 4. Perforate~lahoo Zone 5 (100') with 2 1/8" through tubing gun at 4 SPF. 5. Stimulate Wahoo Zone 5 with 4200 gallons of 15% HC1. Acid will be pul;l~e~ql through tubing and flowed back for recovery. J~J~(~ 6. 3 day production test of Wahoo Zone 5. 7. Isolate Wahoo Zone 5. Continued on next page. 14. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. S,gned fi~l' 7'"' Title L'Si. The space below for Commission use Conditions of Approval, if any. Approved by By Order of Date COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duphcate SUNDRY NOTICES AND REPORTS ON WELLS Well Number' L3-23 February 24, 1986 8. Stimulate Wahoo Zones 6 and 7 with 10,000 gallons of 15% HC1. Acid will be pumped through tubing and flowed back for recovery. 9. Production test Wahoo Zone 6 and 7 with the balance of 60 days of total production testing on L3-23. 10. If production testing indicates a potential for significant production improvement by fracturing, production testing on any zone may be stopped, a gelled fluid fracture performed, and production testing resumed. Production testing will be done through the Lisburne Portable Test Facility. Estimated Start Date' February 28, 1986. ARCO Alaska, Inc. ~'~- Post Office B 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Cha Enclosed are tterton: 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 AtlanticRichfieldCompany RECEIVED F E B 1 1986 Alaska 0~l & ~us Cons. Om.mission Anchorage STATE OF ALASKA - ALASKA C.~_ AND GAS CONSERVATION CO,,..AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~O~] Workover operation [] 2 Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 934' FNL, 679' FWL, 5ec.22, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 51 ' RKB 6. Lease Designation and Serial No. ADL 28322 ALK 2320 7. Permit No 85-306 8. APl Number 50-- 029-21 513 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L3-23 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool For the Month of. January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drdling problems, spud date, remarks Spudded well @ 1900 hfs, 12/27/85. Drld 17-1/2" hole to 4030'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 11,003'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,068'. Cored f/11,068' - 11,221' Cont'd drlg 8-1/2" hole to 11,257'. Cored f/11,257' - 11,461'. Cont'd drlg 8-1/2" hole to 11,514'. Cored f/11,514' - 11,533' as of 1/31/86. 13. Casing or I~ner ru.n and quantities of cement, results of pressure tests 20" 91.5#, H-40, weld conductor set @ 110' Installed w/1750# Poleset , · · 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe 4021'. Cmtd w/2600 sx PF "E" & 600 sx Class G. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe @ 10,993'. Cmtd w/1050 sx Class G. 14. Coring resume and brief description Core #1 f/11,068' - 11,086'; cut 18', recovered 18 Core #2 f/11,086' - 11,105'; cut 19', recovered 19 Core #3 f/11,105' - 11,120'; cut 15', recovered 15 Core #4 f/11,120' - 11,151'; cut 31', recovered 31 Core #5 f/11,151' - 11,181'; cut 30', recovered 30 Core #6 f/11,181' - 11,202'; cut 21', recovered 20 (see attached sheet) 15. Logs run and depth where run None 6 DST data, perforating data, shows of H2S, miscellaneous data None 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ,~~ Associate Engineer ~'/~'~ SIGNED TITLE DATE NOTE--Report/gj~ th~s form is required for each calendar month, regardless of the status of operations, and must be filed m duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected. ~m ~ ri.aha DAM/MR1 0 Submit in duplicate Monthly Report of Drilling and Workover Operations L3 -23 January, 1986 (cont'd) ITEM #14: Core #7 f/11,202' - 11,213'; cut 11, recovered 12' Core #8 f/11~213' - 11,220'; cut 7', recovered 5' Core #9 f/11,220' - 11,221'; cut 1', recovered 0.5' Core #10 f/11,257' - 11,279 Core #11 f/11 ,279' - 11 ,289 Core #12 f/ll ,289' - 11 ,315 Core #13 f/ll ,315' - 11 ,341 Core #14 f/ll ,341 ' - 11 ,372 Core #15 f/ll ,372' - 11 ,383 Core #16 f/ll ,383' - 11 ,395 Core #17 f/ll ,395' - 11 ,396 ; cut 22 ; cut 10 ; cut 26 ; cut 26 ; cut 31 ; cut 11 , recovered 19.5' , recovered 6.5' , recovered 26.5' , recovered 25.5' , recovered 29' , recovered 11' ; cut 12 , recovered 12' ; cut 1', recovered 1' Core #18 f/11 ,396' - 11 ,406 ; cut 10', recovered 11 ' Core #19 f/11,406' - 11,434'; cut 28', recovery not available Core #20 f/11 ,434' - 11 ,439'; cut 5', recovered 5' Core #21 f/11 ,439' - 11 ,461 '; cut 22' , recovery not avail able Core #22 f/11 ,514' - 11 ,533'; cut 19' , recovered 19' MEMORANnUM TO: THRU: FROM' State of Alaska ChairMa~ FI LE NO.: · Lonnie C. Smith TELEPHONE NO.: Commissioner SUBJECT: Edgar W. Sipple, J~__~~ Petroleum Inspector January 7, 1985 D.EWS. 68 BOPE Test ARCO's PBU L3-23 Permit No. 85-306 Lisburn~ Oil Pool Mond____~aM, :.De_cember 30, 1985: On duty at Sohio's H-24, Nabor's Rig 22E. ~ues~ay~_ December 31, 1985:~ On duty at ARCO's 3I-1 Parker Rig 141. Wednesday, January !, 1986~ I traveled from ARCO's 3I-1 to ARCO's ~3~23 to"w'itness BOPE on P~rker Rig 176. The BOPE test commenced at 3:15 PM and was concluded at 5:40 PM. There was one failure. The API ring between bottom pipe rams and mud cross leaked, the above was repaired and tested to 5,000 pounds. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's L3-23, Parker Rig 176. Attachment STATE 'OF ALASKA ALASKA OIL & GAS CONSERVATION CO~fl~ISSION B.O.P.E. Inspection Report Location: Sec ~ .T.//flf R/S[~,,,M Date Representative Permit # .f.5"-- ~ ~_ ~Casing Set ~ ~~? ft. ?0~'~' Drilling Contractor Pz~r _,_,~__~'"~. - Ri~ 'f/ /f~, Representative t~' /~{~',~.~,,~.~.,~.. ,.o~,,t~o., O~n~r,,~ ~'y W~ S~_g. ~ AC~t~rO=ATO~ S~$~ General Housekeeping~Rig , _~ A Ful~ Charge Pressure 3~ psig 3' 2.~O Reserve Pit ~._ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack ~n~a~ r..~Frevent er Pipe Rams Blind Ram~ l~~ Choke Lin~alves H. ~~Valv~ e Test Results Test Pressure Pressure After Closure/.~Z~ U Pump incr. clos. pres. 200 psig. psig /~.2 ,0 ~ rain ~ 7sec. ~ rain S.5'sec. Full Charme Pressure Attained: __ Controls: Master Remote Kelly and Floor Safety Valves Upper Kelly,S( ..~-Test Pressure Lower Kelly ~/Test Pressure Ball Type ~ ~est Pressure Inside BOP O~~est Pressure c~o~ ~i~o~C ~~ ~r~ssur~ No, flanges~ l~Adjustable Chokes Hydrauically operated choke Test T~e ~- hrs. Repair or Replacement of failed equipment to~ be made within ~/~_days and Inspector/ Commission office notified. ' .,~ ~, ,,, ~-,r~ P,>, Distribution orig. - AO&GCC cc - Operf~l cc - Supurv Inspecto December 23, 1985 Mr. Don E. Breeden Sr. Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit L3-23 ARCO Alaska, Inc. Permit No. 85-306 Sur. Loc. 934'F~L, 679'FWL, Sec. 22, TllN, R15E, Btrmhole Loc. 1005'FSL, 837'FWL, Sec. 21, TllN, R15E, UM. Dear Mr. Breeden: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this o~fice 24 hours prior to commencing 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, t.~ere a diverter system ~.s required, please also notify this office 24 hours prior to commencin~ equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~y) tr~l% .y. ours, C. V. c~-a~te~ton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COP~{ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower~ ARCO Alaska, Inc. ~- Post Office B 400360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Lisburne L3-23 Permit to Drill Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Lisburne L3-23, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Diagrams showing the proximity to other wells in the area. Only well L3-19 is within 200' of L3-23, as discussed in the application. A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment o A copy of the certified "As-Built" conductor survey We estimate spudding this well on December 26, 1985. If you have any questions, please call me 263-4963. Sincerely, D. E. Breeden Senior Drilling Engineer DEB/tw PD2/L15 Enclosures RECEIVED Alaska 0~t & Gus Cons. CommissJor~ Anchorage ARCO Alaska, Inc. ~s a Subsidiary of AtlanhcRichheldCompany STATE OF ALASKA ALASKA ,~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE E3(X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address ,~ P. 0. Box 100360, Anchorage, Alaska 99510 4. Locat on of well at surface 934' FNL, 679' FWL, Sec.22, T11N, R15E, UN At top of proposed producing interval & Target (8956 TVD) 1320'ESL, 1320' FWL, Sec.21, T11N, R15E, UM At total de t'~" ' ~//~"/1~. ~.1", ~,l~t)~. 1005' FJlt_, 837' FWL, Seco21~ T11N, R15E, UM 5. Elevation in feet (~ndicate KB, DF etc.) 6. Lease designation and serial RKB 51', PAD 21' ADL 28322 ALK 2320 12 Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Umt or lease name Prudhoe Bay Unit/Lisburne 10. Well number L3-23 11. Field and pool Prudhoe Bay Fi eld Lisburne 0il Pool Amount $500,000 13. D~stance and d~rection from nearest town 14. D~stance to nearest property or lease I~ne 7-1/2 m~. NE of Deadhorse m~les 837' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres ~n lease 11951 'FID, 9542' TVD feet 2560 19. If dewated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2390 feet. MAXIMUM HOLE ANGLE/+4 oI (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed L3-19wel1120' @ surface feet 18. Approximate spud date 1 2/26/85 3420 psig@__40°F . Surface 4490 ps,g@ 8951 ft. TD (TVD) SIZE Proposed Casing, Liner and Cementing Program Hole Casing Weight 30" 20" 91.5# 17-1/2"I 13-3/8" 68.0# 17-1/2"1 13-3/8" 72.0# 12-1/4" 9-5/8" 47.0# 8-1/2" 7" 29.0# 22. Describe proposed program CASING AND LINER Grade Coupling/ Length H-40 Wel~ 80' K-55 BTC! 70' L-80 I BTC/ 407 ' L-80 I BTC! 106/+' SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD (include stage data) 30' I 30' 30' I 30' 100' I 100' I 28' I 28' 10887' I 8783' 1 MD BOTTOM TVD 110' 110' 100' I 100' 4175' I /+000' 11087' I 8926' 11951' I 9542' ARCO Alaska, Inc., proposes to drill this Lisburne development well to approximate1 planned as a Wahoo production well. Approximately 750' of the Wahoo will be cored. 2000# Pol eset 3000 sx PF "E" Lead & 400 sx Class G Tail 750 "G"/300 PFC&ArcticPk 400 sx Class G y 11,951'MD(9542'TVD). It is 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. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. 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 the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) 23 I hereby certify that the foregoing ~s true and correct to the best of my knowledge SIGNED ~(,~~~,~ TITLE Sr. Dril ling Engineer The space below for Commission use CONDITIONS OF APPROVAL DATE Samples required Mud tog required []YES ~NO []YES Permit number ~ (,~ Approval date D~rectlonal Survey required APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE December 23, 1 985 by order of the Commission Submit in triplicate PERMIT TO DRILL L3-23 (cont'd) 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 (approx 130 bbls Arctic Pack on top of 300 sx Permafrost C cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig ~ 40°F was calculated from the Wahoo datum pressure of 4490 psig @ 8951'TVD and 183°F. It assumes a 300' oil column to 8651'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and present reservoir pressure in the Sadlerochit @ 8316'TVD, yields a maximum surface pressure of 2850 psig @ 40°F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set @ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history, for surface pipe set at similar depth, shows a 11.5 to 13.7 ppg EMW pump-in gradient just below the casing shoe. Only well L3-19 is within 200' of L3-23. of L3-23. Well L3-23 is 120' from L3-19 from surface to 2390', the kickoff point /~,~'"' . ' L3-23 1000 2O0O 3000 4000 -r- SO00 > 6000 w 7000 8000 9000 10000 i1000 1000 2000 3000 4000 SO00 8000 7000 8000 2 ' ARC 3 AL ,SKA, INC. ,~CALE I IN = 1~0 FT. SHL: 934'FNL, 679'FWL, 2.5 KOP TVD =23~0 SEC.22,"11N, R15E, Ul~ 7.5 THL:1320' =SL, 1320'F~ L, 12.5 17.5 ~E~ 91: 3'11N: R1RF_ IJl~ -~~ ,5 2.5 27.5 ~2,5 FO~ TVO~~ MD~4179 O~P 13-3 '8' SURFACE TVD ~ 4000 MD = 4175 [)EP -- 661 K-15 "VD ~ 4920 ~D = 5466 Df[P ~ 1566 S 60 DEG 63 k IN W 5539 FT(TO T kRGET) K-13 TVD=7151 MD-8596 )EP=3762 TVD= 7651 MD= 1298 DEP=~.254 L(:U TVD ~ 83( 1 MD = 10211) DEP = 489z SHUB~LIK TVD = 83(~1 MD = 10213 DEP = 489~ SADLEROCI'IIT TVD = 83 16 MD = 102~I1 DEP = 490~ KAVIK TV~ =8751 MD==10841 DEP =5337 9-5/1 ' CASING TV 3 = 8926 ME = 11087 DEF = 5509 TD-7'LINERTVD=g542 MD=11951 DEP=6115 - , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 0 1000 2000 3000 4000 5000 VERTICRL SECTION 1000 2000 3000 4000 5000 6000 7000 8000 8000 10000 9000 E - N COOROINFtTES o -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 tO00 i i I I I I I I I , t 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 t i i i i ii i i I , , , i , .~HI ' ~.~ L'FNI RTR'F NI _ SEC.22, 1'11N, R15E, JM THL:132t 'FSL, 1320'F INL, SEC.21, F'11N,R15E, 1.IM ~8E3 TARGET TVD = 8 )58' T~ D ---- ! 1!29' i DEP = 5! i39' W 463~c ............... , , , i , ,,1, , i , , , , ~ , , ~ ,,, , , , , , , , , , , ~ , ~ , i i , , , , , , , ........ i , i , , , , , ~ ' ' ' ' ' ' ~' ~ .~, _ r", E - 14 OOORDINnTES -5000 -4000 -3000 -2000 - 1000 0 i 000 -~UUU -/UUU ouuu ~uuu IIIIIIII IIIIIIIII IiiIIIIII IIIIIIIII iiit111I IIIIIIIII L3-19 ........................... -8000 -7ooo -eooo -5ooo -4000 -3ooo - 900 -300 i i i I ~ i I i i t ; , i , , , i i , , 0 I I t -300 -700 -100 0 100 /' ?00 I0 400 SURFACE HOLE D IVERTER SYSTEM ARCO ALASKA INC. SCHE~TIC IO" HYD. OPR. BALL VALVE If~LL BORE (SEE DETAIL) ~--- IO" HYD, OPR. BALL VALVE ALL 90' TURNS ARE "TEE" I cus.]o.I I I I I I I I I I I I I I I I I I I ,, RESERVE PIT AREA NOTE' FLOI~ INE DR ILL RISER 20# 2000 PS] ~P ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular oreventer is closed. ILL ING 20" ;ONDUCTOR PIPE I O" HYDRAULIC OPERATED BALL VALVES "DETAIL" 2026010203 P~P~ SPOOL Acc~mlator ~ac~:7 Test ~eve~ ~th ~~c ~. ~s~e ~t at--acer p~s~e is 3000 psi with 1500 psi ~t~m of t~ re~latoT. ~se~e t~, cmn close all ~cs s~:~ly ~ r~ord c~ t~ ~ pressure r~~g all ~ts a~ clos~ wi~ ~rg~ ~ ~o~ on ~ re~. ~ acceptable lo~r is a5 sec~ clos~g t~ ~ 1200 psi press~. 1~-5/8" ~P St~ Test 1. Fill ~P sca~ ~ ~fold ~:h a li~d. ~ck :~t all ~ld ~ s~s a~ ~ly rec~c:ed. ~rk ~g jo~ ~th p~te~ plug seat~g ~h. ~ test plug on drill pi~ ~ seat ~1~. ~ ~ 1~ ~ sc~s. ~. Close ~~ p~encec ~ ~scTe~ valves. ~. ~io~lly test c~s. -5. -In e~ of tM ~ll~g tesM, first ~ld a gS0 psi 1~ p~s~e test ~r a ~ of ~ ~es, test at tM ~ ~~ 6. I~ue p~ss~ t~p...ps~ ~ld for a 7. ~n ~ar ~cer ~ c!o~_~ sec of pi~ leM: ~ ~es. al~ ~s~e co 8. ~ose valves ~ly ~sc~ of ~s ~ o~n ~s.. I~eue ~s~e to 5000 psi ~ ~ld a: leu: ~ ~es. Bi~ press~e co :e~. 9. ~n top sec of pi~ ~ cmn close ~t:~ set pi~ r~. I~ue p~s~e :o 5000 psi ~1~ ~t:~ set o~ pi~ r~ ~ ~ld f~ at utes. 10. Test re~ ~:es:ed ~fold valves with 5000 psi ~s:~em of valve ~ :e~ press~e ~l~d ~es~e :o zero. ~n ~t:~ ~t of pi~ r~. 12. h~ off ~g jo~t ~~1 o~ of ~le. Close bl~ r~ ~ :es: :o 5000 psi for at le~: ~tes. 1~. Bled press~ off all ~~nt. ~n bl~ r~. ~e s~e ~old ~ li~s ~ ~1 o~ n~* ~z~g li~d ~ all ~ves a~e set ~ ~ill~g 14. Test s:~i~ valves :o 5000 psi. 15. Test ~lly c~ ~ ~i~ ~P :o 5000 ps~ wi~ ~y ~. 16. ~k ~rati~ of ~gMse~. 17. bco:d :es: i~o~tion ~ bl~ p~ven:et 18. Per~o~ c~lete ~5 Ces: ~e a ~k ~ ~c- tio~lly o~tate ~ ~ily. Revised 2121/8~ i i .el .,.~.'~' nF A :,~ ,~",, '~"b e· ,, - ~.~ .' ~,Ah~ '.?-_?. ;_;:: ~' '***.* · .....**_o,o,,,,,,%...~ %,%>..........:[,7 w~.~- WEST UNE OFFSET NLO ' No~ra U~ OFFSET ~ CONDUC,~:~S ~S.eUmT . THIS SURVEY. ~ .._. PLANT NORTH 4. 8rid North i'~ I45° East Cond ASP ZONE 4 2 ¥=5 962 076.16 X: 70?' 961.01 5 Y=5 961 949.12 X= 707' 810.65 I0 Y ::5 961 842.30 X= 708 014.97 Y=5 961 783.86 X: 7'08 15 Y=5 961 598.54 x= 707 891.78 18 Y =5 961 608.42 X= 708 068.98 f9 Y =5 961 481.43 X= 707 918.71 2.2 Y:5 961 491.6~ X= 708 096.03 23 X :5 961 364.5~ X= 707 945.70 24 Y:5 9Gl 433.15 X= 708 109.41 25 Y =5 961 X '- 707 959.10 28 Y~5 961 316.20 X= 708 136.4B 30 Y=5 961 X= 708 14991 SITE L'$ VICINITY TII# /..AT =70e_ 17: 59.1199',', LONG =148018 56.1066 I LAT = 70°17,57, 9I 18 ,, LONG = 148=19 00.5908 , LAT LC'NG = 148~18 54.7?.27 LONG :148°18 54.3746 ~T: ?0°, ?',54. 4,~1o",, LONG = 148018 58.5095 LAT: 70° 17'54.4919", LC~VG = 14a° lS r55.5376' LAT= 70°17',5.3. LONG = 148° 18 5~ 8189 /..AT: 7~~ 17' ~2. !~' ~NG = 148°18 52.50~ LONG: 1~°18 56.78~ ~T: ~ 17, 51.6~,, 14~g 140.~ LA~ 7~J~9.86~, 176.93 ~ =1~lg~56~ ~CO ~ ARCO CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPEI~.Y REGISTERED LICENSED '0 PRACTI~ LAND SU~EYI~T~E ~KA AND T~T THIS PLAT REP~ES S SURV~ MADE BY ME OR UNDER MY DIRECT ~E~IS~.N~. ~D ALL DIMENSIONS ~D OTHER DETAILS DATE SUR~EY~ MAP SECTION 22 OFFSET WLO M..O 715 223 561 346 762 459 774 518 632 699 810 694 656 817 812. 9~4 E'/'e 993 I047 117'0 116,,~ 833 679 $45 691 868 880 726 904 I Alaska, Inc. DRILL SITE L-$ CONDUCTORS LOCATED IN PROTRACTED SECTION ~2, TI I N, R 15 E U.M. PREPARED BY LOUNSBURY & ASSOCIATES~ INC. 725 W6th AVF., ANCHORAGE,ALASKA DATE :;O/~9,/8~ SCAL[:I · :~OO CHKD. 8¥' GEL IFLO. BK.: LHD ARCO Alaska, Inc. Post Office .100360 ._ _ Anchorage, Alaska 99510-0360 -" Telephone 907 276 1215 November 6, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - L3 Pad (Wells 2, 3, 10, 12, 15, 18, 19, 22 - 25, 28, 30, 31, 34) Dear Mr. Chatterton' 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 GRU12/L74 Enclosure RECEIVED 0 8 !9 5 A!aska OiJ & G2s Cons. Commissio: Anchora9~ ARCO Alaska, Inc. is a Subsidiary of AtlanhcR;chf;eldCompany *, e Cond ,ASP ZONE 4 ~ ii 2 Y=5 962 076.16 ~ * X= 707 961.01 ,~ 15 ~6 * 5 Y=5 961 949.12 CEE:> ~ x= 707 810.65 '° ~? I0 Y-'5 961 842..30 zo° X= 708 014.97 ~ ~ 12 Y=5 961 785.86 ,o zl ~ X-' 708 028.53, (:~ 15 Y=5 981 598.34 z~ * X= 707 891.78 ~ 18 Y=5 961 608.42 , z? X= 708 068.98 o z~ 19 Y=5 961 481.43 ~ o x= 707 918.71 ~ 22 Y=5 961 491.63 o 33 X= 708 096.05 32. .o 35 23 Y=5 961 364.52 ×= 707 945.70 .. ~x.........,q,;,, . "~-' ' ~ -.~e ~eeeeeeeeeee-- ...... · ~ PLA~ NORTH 4 · ~rid North is 15° East LEGEND W~.C.~- WEST LINE OFFSET NLO -NORTH LINE OFFSET ~ CONDUCTORS AS-BUILT ...... THIS SURVEY. 24 Y=5 9Gl 45=...15 X= 708 109.41 25 Y =5 961 306.08 X= 707 959.10 28 Y=5 961 316.20 X= 708 136.48 30 Y=5 961 257. 72 X= 708 14g~91 ;51 Y=5 961 130.62 X= 707 999.7Z Y=5 961 140.73 X= 708 176.95 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATIO..N AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT~- DATE VICINITY MAP SECT/ON ~2 0~'FSET WLO NLO LAT =70° 17, 59. !199,, 715 225 LONG =148018 56.1066 LAT = 70°/7',5Z9;18",, 561 346 LONG = 148°19 00.5908 LAT = 70° 17 ~_ 6.8060_;, 762 459 LCNG = 148°18 54.7P_.27 I_AT= 70°/7',5__6. Z2. 7.7,:' 774 5/8 LONG =148°18 54.5746 LONG =148 18 58.5095 LAT=70°17 ~54.4919 ,, 810 694 LONG = 148°18 '53.5376 0 ~ 4 LONG = 148= 18 5'7. 8139 LAT= 70 17 53.33-3_3,, 833 812 LONG = 148°18'52.6455 LAT= 70o17' 52.1275'' 679 934 LONG = 148°18'57. 1267" I..AT = LONG = 148018 I_AT= 70°17 ~.1.549_ ,, 691 993 LONG = 148°18 56.7835 ~AT= 7o°;7',5;.~oc~:/ eee LONG =148°18 51.6065 I.AT= 70°17' ~1.0218' 880 1047 LONG = 148°18 51.,262_~. L~T= 70°17'~9.81~2', 726 1170 LONG = 148° 18 55.7415 0 LAT=70 17"49.864~ , 904 /165 LONG = 14~° 1~.56b~f ARCO No. D '" .... & Gas SURVEYOR A,,,,: · ARCO Alaska , Inc. AS- BUILT DRILL SITE L-$ CONDUCTORS LOCATED IN PROTRACTED SECTiON 2?- ~ TIIN~ RI5E U.M. PREPARED BY LOUNSBURY 1~ ASSOClATES~ INC. 723 W6th AVF.~ ANCHORAGE,ALASKA CHKD. BY: GEL SCALE: I"= 300' FLI:IBK.: LHD 85-101 ,~PPROVE ~ ~ thru 8) ,//xH (3) Admin /./."J,'J,',) '~f. 9. (~ thru 12) 10. ('10 and 1~) / 12. (4) Casg ~.~ )'~- (13 thru 21) (22 thru 26) 2. Is well to be located in a . 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. Lease & Well No. YES NO eeeeeee~ ~ ~eeeeeee( ~ REMARKS Does operator have a bond in force .................................. Is conductor string provided ; ...... Is enough cement used to circulate ;;';;~;;; ;~";~;~;;;']~i~i~ 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 a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~OOO psig ...~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: 6eolo~ Eng~jleerin~: Hw~ / LCS V~ ~ WVA~JAL MTM ~ HJH,//~-// rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , NELL .SIT: D&T~ AqD TADLES ~E NJT ZNC.UD~D IN THIS LISTZ~S tV~ Oil.HOP VERI;I'3~T!~q LIETiN3 P~E ~ R :C3'23 TYPE 137 · ,o.~. =TL: HcADr-R~, ,:I~M NAM5 :EDIT VE~SI'3~ ~ : ]ATE : ~AXiMUM LE~STH : =ILE TYPE : oR~VI~J5 FILE : .001 1024 .,..,. , .,.., .... ,,..,. ~?. ;~, ~,,: ¢.',: ...... ., ..... .,..,..,. ,,,. ::: ..... ., .......... .,. .,- -,- :,-' .,- ,,..,- .,- ::: ::: ....... :',: ;'.-' ~: ¢ "'"'"' .... " ...... ~' ::: "' :~ "' "' "' ::::;'- :;-' '~' :;: :,'-' ;l-' .,- ¢ -,- ;',: :;: ~;: ::: ALASKA 3]MPJTI~G CE~TE~ WELL = _iSD]RN~ LD-Z3 :!ELD : ~RUD~OE ::3~Y/.!S~JRNr' mO3L 'DJ',ITY : ~3RT-t S.3mE ST~T: = 'ALAS <,A JOB ~J~~ ~T ~C: ~1255 ' D~'. C. ~!' KI~ Ty~ FLJiD D=~SIT¥ =LJID L3SS 47.0,3' Si'=~_ : 5.5" T3 11933' 57.3 DF 57.0 DF 57.0 DF 180. DP ~ATqIX LIM:STON: APl SERIAL NO. 5002921513 ~V= 010.902 VE~i=iEITl]g ~ISTIN3 ~35 ~ :)jAL L. ATS~L3] COL_) i..]N$ SDA':'D SDNIC LD2- (LSS) _IT-ti 3:NSITf COM>ENS~TE3 Lg] (L3T) '3MP=NISAT:D NI=UTR3N LJg ('NL) '~L I~ '~SiN3 (C,~~) :,- ..... -,- ::-' :k ~1.'.,."' %' :'; <: ;;:.,."' :l: .,. ....... .,. ,.' .. ::~ ;~,-' %' -.- :',: :*~:.,-~" ::-' .,- ¢~ D~T~ FD~MAT =NTtY 5LOC~S 9~TJM ~N~ LLS SP C~LS OV9 910 SIO TE'~S S,~ECIFIC~TIDN S5~VISE SErViCE ID OR DER ~ DLL )LL D.L 3LL 3LL 3LL DLL DLL DLL DLL JqlT ]iMM J~ J~ ~P LO 0 0 0 0 0 O 0 0 0 SIZE ! ! 4 I ! 55 56 73 65 60 .tin apl AP1 ~Pt FiLE SiZE S~L TYPE CLASS 313 $1 0 0 ~ I 223 lO O 0 ~ 1 ZZO 3~ ] 0 4 1 01~ O1 0 0 ~ I 000 OO 3 0 ~ 1 300 O0 3 0 4 t OOO 30 O 0 300 O0 OOO 03 D 0 ~ ! 635 21 PqOSSSS (OCTAL) OOOOOOOO00OOOO 03300030000000 OOO00000030000 00000030000000 33303330000000 00300030000000 03000000000000 33300330030000 33000000000000 00000000003000 00000000003000 tV~ 013.~0~ ~f~i~lg~rlO~ LISTiN3 m~gf 5 SR 'NL ~PI 03 313 01 3 ~Sq' -~L ~S O0 333 31 3 :S~' C~L '~S O0 33~ 30 3 ~N~ S~L 03 003 O0 ] TENS Z~L _~ O0 635 2i 3 DPql LDT ~J O0 990 30 O RflO3 ~ DT 3/C3 O0 350 J2 3 3R~3 LDT 3~C3 O0 355 31 3 ~E= LDT OD 3~ O1 3 ~LS LD~ O0 000 O0 O ~SS LDT 30 000 30 J tS ~DT -~S O0 354 O1 ~ ' t LDT Z~S O0 35~ O1 O LO LDT 'DS O0 35~ 31 O ~ITq LDT ODS O0 354 Ol O 551 ~DT CPS O0 00~ DS 0 SS! 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