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180-117
Ima ect Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other. No/Type ~ Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of vadous kinds NOTES: [] Other BY: BEVERLY ROBIN VINCENT SHERYL~WINDY DATE:¢,/~ ,¢,¢~' /SI ~'~p Project Proofing BY: ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation x 30 = + , = TOTALPAGES /,-~/ BY: ROBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage f PAGE COUNT FROM SCANNED FILE: '/~/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ,,.,: (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALI'rY. GRAY$CALE OR COLOR IMAGES ) ReScanned (individuat page [special et~e¢~tiett] .~ca,ning ct~mple~ed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 12/10102Rev3NOTScanned.wpd STATE OF ALASKA ALASKA AND GAS CONSERVATION COMII~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~s 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoa-c zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. 8~ ~te~~, ~Oi~tl'C3l~; Develo me E~lorato ^ Service ~~ ~ICrati raphic 2. Operator Name: BP Exploration (Alaska Inc. 5. Date Comp., Susp., or A~ 1/9/2008 12. Permit to Drill Number 180-117 307-296 ~ 3. Address: P.O. Box 196612., Anchors e, Alaska 99519-6612 6. Date Spudded 10/14/1980 13. API Number 50-029-20515-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/30/1980 14. Well Name and Number: PBU A-12 1116 FNL, 920 FEL, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 153' FNL, 1366' FEL, SEC. 35, T11 N, R13E, UM 8. KB (ft above MSL): 77.4' Ground (ft MSL): 47.27' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 102' FSL, 1401' FEL, SEC. 26, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 9757 9511 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 654447 y- 5949331 Zone- ASP4 10. Total Depth (MD+TVD) 9801 - 9553 - 16. Property Designation: ADL 028286 TPI: x- 653981 y_ 5950285 Zone- ASP4 Total Depth: x- 653940 y- 5950540 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No i 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (11/D): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / SFL / SP / GR, DIL / BHCS, FDC / CNL, GYROSCOPIC Surve 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD I'~pLE AMOUNT WT. PER FT. GRADE ` TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED ~~ ~~ ~~ , ~~ 4' _/~~ ~~ 23. Open to production or inject ion? Yes No 24. T usING_RECOrtD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SRE DEPTH SET MD PACKER SET MD None 4-112", 12.6#, 13Cr80 8399' 8144' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. {~(}Q FEB ~ ~ 2008 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8926' Set Whipstock 8930' P8A with 20 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? Yes No Sidewal l Core s A wired? Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical result ~~~50.~0y~• None s ~~. I _ ~l ~~~e ~ ~ 1~~~ ~' Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ ~\5 ll)I~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals a ormations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River SST 8898' 8701' None Shublik 8925' 8726' lvishak 9007' 8802' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports and Well Schematic Diagram. 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Sondr Stewman Title Drilling Technologist Date ~ "(~~- PBU A-12 180-117 307-296 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submk Original Onry TREE= 4" Cfvi1 WELL HEA G= FMC ACTUATOR OTISI KEG ELEV = 77.43` BF ELEV = 43.56' Max Anale .. r ; ~,. Datum nJID =~' ._ 9~T ~~ Datur~lTVC~ 8800 SS _, 13-318" CSG, 72#, L-8t3, ID =12.347" ~-~ 2677' ,, 4 ,~ of . 2p$~' --j 4-112" X-NIP ID=3.813" 2593• s-518" DV PK GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3151 3151 1 MMG DMY RK 0 12/25/07 4 4725 4725 1 MMG DMY RK 0 12/06/07 3 6009 6003 14 MMG DMY RK 0 12/06(07 2 7083 7015 19 MMG DMY RK 0 12/06/07 1 7991 7876 22 1~1(~1G DMY RK 0 12(06/07 8113' --~ 4-1/2"X-NIPID=3.813" 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 4.75" $`I7' ~--~4-1/2" OTIS X NIP, ID = 3.813" I TOP OF 7" LNR [ 4-112" TBG, 12.6#, 13Cr8Q, VamTop, ~ 839 .0152 bpf, ID = 3.958°' 9-518" CSG, 47#, l-8U, ID = 8.6£31" ;~i804' Ix;4F"r?i~ATIQN SUMIVIAEiY Note Re~e t Production QB for historica' serf siata SIZE SPF INlif:vAL .,_.._.... OpnfSgz DA'iL 2„ C? 2` ~ ~. : 6 I $ j' 2,. 6 ~} t 2 ` 6 O (3 ~ .;, ~3 2„ 0 - O .~1 ~. ~w PBTD ', 9757' 7" LNR. 29#, L-8€1, i3.Q371 bp1„ ID = 6.184" 9800' ~ --~ TOP OF 3-3116" LNR; ID = ??? .,..,....~~".........•.....• $272° 3-112" XN X NIP, ID = 2.75„ _~ $3$$' 4-112" TBG TAiL; ID = 3,958" ~- ~ ~ w r' S.5" OD (Fluted) !r'VLEG I ~ $~(}{}' TOP OF CEMENT I ~ ~ ~ r,. ,. i f FiSw _ (2) 3-112° SPINNER BLADES E1L (1i31171b2} DATE REV E3Y COMMENTS DATE. REV BY COMRAFNTS 011041$0 CNi[GINAL COMPLETICIN (19126tfl8 ITLH CCtRRECTK3N5 $6£01(90 21IUt3 Q51181fli RNIKAK CORRECTIONS 10104,'0? BM-'KAK V+lAllll=R SAFETY NC'~E ' ~ I! PRUl:1HGE BAY UN[T WELL; PERMIT N~: , , API Na: I i SEC 35, T71 N, R13E Expiuraton (Alaska) • • BP EXPLORATION Operations Summary Report Page 1 of 9 ~ Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date. From - To I Hours Task Code I, NPT Phase it Description of Operations 1/4/2008 21:30 - 23:00 1.50 MOB P PRE Jack up rig and prepare to move off of DS 15-04B well. 23:00 - 23:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving rig. 23:15 - 23:45 0.50 MOB P PRE Move rig off of well and down back side of DS 15 and onto access road to front of DS 15 23:45 - 00:00 0.25 MOB N RREP PRE 1/5/2008 00:00 - 04:00 4.00 MOB N RREP PRE 04:00 - 04:30 0.50 MOB P PRE 04:30 - 12:00 7.50 MOB N RREP PRE 12:00 - 12:50 0.83 MOB N RREP PRE 12:50 - 13:30 0.67 MOB P PRE 13:30 - 17:30 4.00 MOB N WAIT PRE 17:30 - 00:00 6.50 MOB P PRE 1/6/2008 00:00 - 01:45 1.75 MOB P PRE 01:45 - 02:00 0.25 MOB P PRE 02:00 - 02:30 I 0.501 MOB I P I I PRE 02:30 - 08:00 I 5.501 BOPSUR P I I PRE 08:00 - 14:00 6.00 BOPSUF~ P PRE 14:00 - 17:30 3.50 RIGU P PRE 17:30 - 18:15 0.75 BOPSU P PRE 18:15 - 19:15 1.00 RIGU P PRE 19:15 - 20:15 1.00 RIGU P PRE 20:15 - 20:30 0.25 BOPSU P PRE While moving the rig on the access road between the back drillsite and front drillsite of DS 15, at 23:45 hrs, on 01/04/2008, the front hydraulic drive gasket failed on the drillers side of the rig. A fine spray of hydraulic oil left a thin spray film on the road for about 100 yds, about 2 ft. wide. Driller shut down rig drive system as soon as the spill was seen. The rig crew put dykes under the dripping drive motor and cleaned up area around drive motor. The tourpusher called 5700 spill response and notified them of hydraulic oil spill on road. We estimated the spill volume at 30 gals. Access to back of drillsite is blocked by rig. Work on drive motor to move rig to front of DS 15 and clear access. Refer to remarks section of this report. Work on rig drive motor to allow movement of rig and clear DS 15 access road. Repair hydraulic drive motor on rig to move rig forward and clear DS 15 access road. Move rig to front part of DS 15, so access road is clear. Clean rig tire and rim. Remove hydraulic drive motor. Build and install temporary cover on gear box Plug hydraulic lines and PT. OK Warm up moving system to 100F. Restab drive bushing into reel. Move held up by 27E move. Wait on security. Move rig to A pad. -30F, 5 mph wind. Move rig to A pad. Position rig in front of well. -30F. SAFETY MEETING. Review procedure, hazards and mitigation for backing over well. Back rig over well and set rig down with no incidents. ACCEPT RIG AT 02:30 HRS, 01/06/08. N/U BOPE. Move in cuttings tank and continue with general rig up. Spot trailers and M/U hardline. Test BOP. Witnessing BOP test waived by AOGCC representative John Crisp. Install packoff on lubricator. PU injector and stab onto packoff. PU injector and stripper. Thread tugger cable thru the packoff and reconnect to air tugger. RU & pull coil across. MU CTC. Fill CT. PT inner reel valve and bulkhead. Reverse circ at max rate for E-Line slack management. 5.0 bpm, 2000 psi. Cut off coil to find E-Line. Cut 20' coil. M/U CTC and pull test. SAFETY MEETING. Review procedure, hazards and Printed: 7/14/2008 8:59:31 AM • • BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations i -- -- - __ 1/6/2008 20:15 - 20:30 0.25 BOPSU P PRE mitigation for pulling BPV with lubricator. 20:30 - 00:00 3.50 BOPSU P PRE Riq up lubricator, press test with 1500 psi, try to pull BPV. No recovery, grease and ice on top of BPV. Jet top of BPV. Attempt to pull, no recovery. Bullhead 30 bbls water at 75F at 3 bpm. Attempt to pull BPV. No recovery. bottom 1/2" of threads on recovery tool come back damaged. 1/7/2008 100:00 - 04:00 I 4.00 N I DPRB I WEXIT Replace BPV recovery threaded spear and try again 04:00 - 10:00 I 6.00 N DPRB WEXIT 10:00 - 11:30 I 1.501 BOPSURN I DPRB I WEXIT 11:30 - 12:55 1.42 CLEAN P WEXIT 12:55 - 13:15 0.33 CLEAN P WEXIT 13:15 - 13:40 0.42 CLEAN N DFAL WEXIT 13:40 - 16:10 2.50 CLEAN N DFAL WEXIT 16:10 - 19:00 I 2.831 CLEAN I P I I W EXIT 19:00 - 20:30 1.50 CLEAN P WEXIT 20:30 - 22:00 1.50 CLEAN P WEXIT 22:00 - 00:00 I 2.001 CLEAN I P I I WEXIT 1/8/2008 00:00 - 00:30 0.50 CLEAN P WEXIT 00:30 - 00:45 0.25 EVAL P WEXIT 00:45 - 02:00 I 1.251 EVAL I P I I W EXIT 02:00 - 03:00 I 1.001 EVAL I P I I W EXIT 03:00 - 03:40 I 0.671 EVAL I P I I WEXIT 03:40 - 04:10 I 0.501 EVAL I P I I WEXIT Made 3 attempts with no success, each time the bottom 1/2" of threads are worn off. The threads are not getting started. Bullhead 40 bbls thru BPV at 4 bpm to clear thread area. Well is dead. Try again to M/U threads and pull BPV. No luck. Change threaded spear and try again. Made up to BPV threads OK, but was not able to pull BPV. Check recovery tool. Put Tioga heater on tree. Bullhead 30 bbl thru BPV. Wait on day BPV crew. PU nozzel and wash BPV little returns injecting thru BPV. PJSM./ Check threads with plug on "T" bar. OK. PU lubricator RIH and retrieve PBV, Valve had significant dehydrated gel packed around it, About one quart. Some of ge not u ly hydrated. LD lubricator. MU BHI BHA#1 cleanout and logging run. RIH to 1200. Circulating at min rate. Short reported by MWD. POH Pop off well. Set back injector and test MWD. Wire pulled from anchor, were not pumping at high enough rate to move wire forward. Cut coil, install new CTC and rehead. PT to 4000 psi. RIH. Circulate at 3 bpm C~3 900 psi returns at 118 bbp. Continue to RIH at .6 bpm, no returns. Log down with GR for depth tie-in from 8880-9050 at 150 fph. Correct -4' CTD. Pump 0.4 bpm, no returns. Log down with CCL from 8100' to PBTD. Tag PBTD at 9273'. Pump 0.4 bpm, no returns. POH. pump 1.6 bpm while POH. No returns. Pump across the top to fill tubing with slick fluid for chrome tubing. Lay out BHI MWD logging BHA #1. SAFETY MEETING. Review procedure, hazards and mitigation for M/U BHA #2, BTT ball catcher BHA. M/U SWS E-Line Anchor and BTT ball cathcers BHA #2. Drifted SWS E-Line Anchor with 7/8" ball. BHA OAL = 5.85'. RIH with SWS anchor / BTT ball catchers BHA to 4015'. Circ 0.8 bpm with no returns. Insert 5/8" Phenolic ball and displace with 2% KCL water, double slick. Circ. at 2.5 bpm at 900 psi. Slow down to 1.5 bpm at 50 bbls. Ball on seat at 54.1 bbls. Coil volume was 58.4 bbls. Sheared at 1300 psi. Pins set for 2040 psi. Losing returns, so do not have a full column of fluid on backside of coil. Insert 3/4" Phenolic ball and displace with 2% KCL water, Printed: 1/14/2008 8:59:31 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code ~ NPT Phase - J __! - -- _-~ - 1 /6/2008 Page3of9~ Spud Date: 10/14/1980 End: Description of Operations 1/8/2008 03:40 - 04:10 0.50 EVAL P WEXIT double slick. Circ at 2.5 bpm at 900 psi. Slow down to 1.5 bpm at 45 bbls. Ball on seat at 54.0 bbls. Sheared at 2300 psi. Pins set for 2040 psi. Well almost full of fluid after pumping 110 bbls for 2 balls 04:10 - 04:50 0.67 EVAL P WEXIT POH. Circ across the top at 1.5 bpm. 04:50 - 05:00 0.17 EVAL P WEXIT Lay out BHA. Found the 5/8" Phenolic ball had broken in half. This could cause a problem during a liner job. Recommend that we use Aluminium balls to prevent this problem. 05:00 - 05:10 0.17 EVAL P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for running liner and BTT SELRT 05:10 - 06:00 0.83 EVAL P WEXIT M/U 2-7/8" bull nose guide shoe with no holes, pup jt, pre-drilled pup jt, 2 float shoes, pup jt, Landing cllr, 5 jts, 2-7/8" STL Liner, XO and 4 jts, 3-3/16" TCII Liner, XO and X Nipple 06:00 - 06:30 0.50 EVAL P WEXIT Crew change. SAFETY MEETING. Review procedure, hazards and mitigation for running liner and BTT SELRT. 06:30 - 08:05 1.58 EVAL P WEXIT MU 3-1/2" STL, 10' pup Jt, BTT Deployment Sleeve and BTT SELRT. Liner total length of liner = 313.82'. M/U XO, Hyd Disc, Locking swivel , SW S E-Line Anchor and CTC. Liner and runnin tools BHA = 325.1'. 08:05 - 10:00 1.92 EVAL P WEXIT RIH with liner. Up wt 43K. Dwn wt 23K. Tag at 9276'. To of liner = 8959.2' corrected de th. 10:00 - 10:30 0.50 EVAL P WEXIT PJSM for liner release and cementing. Walked thru the sequence of events for the entire job with this new SELTR tool. Discussed job hazards in particulare, the extreme weather. -35F with slight breese. 10:30 - 11:45 1.25 EVAL P WEXIT Position reel in ball drop position. Launch 5/8" AI ball with 500 psi. Circulate ball 2.6 bpm, @ 44 bbl slow to 0.75 bpm. Bump total 68 bbls. Rock rate. Shut in and wait 10 min. Recommend pumping 1.0-1.5 bpm to move ball better. 11:45 - 12:15 0.50 EVAL P WEXIT Pump 5 bbl 2# bio. AL Ball on seat at 88 bbls. sheared at 2100 psi. Correct press. 41 K. Liner looks free. Stack 10K wt back down on liner. 12:15 - 13:00 0.75 EVAL P WEXIT Batch mix 20 bbl cement. Press test cement line w/4000 psi. 13:00 - 14:00 1.00 EVAL P WEXIT Stage 15.8 PPG, G Cement, 2.0 bpm, 800 psi, Pumped 17.4 bbls. Pump Biozan to cementers. Zero in/out totalizers on end of cement. Coil capacity = 58.5 bbls. Liner capacity = 1.84 bbls to landing collar. Total = 60.34 bbl. Displace Cement with 30 bbl, 2# Biozan, 2.7 bpm, 1600 psi. No returns. Stage KCL water. 2.7 bpm, 1600 psi, no returns. 40 bbl displ, 2.7 bpm, 1600 psi, no returns 42.9 bbl displ, cement at shoe. pump press is increasing as expected. 45 bbl displ, 2.7 bpm, 1920 psi. no returns. 50 bbl displ, 2.7 bpm, 2050 psi, starting to get returns. 55 bbl displ, 2.7 bpm, 2100 psi, 1.0 bpm returns. Printed: 1/14/2008 8:59:31 AM • • BP EXPLORATION Operations Summary Report Page 4 of 9 ~ Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: REENTER+COMPLETE Start: 1/6/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date ,From - To ' Hours I Task 'Code' NPT ~' Phase Description of Operations EVAL P WEXIT 56.5 bbls. Stop displacement. This leaves 2 bbls cement in 1/8/2008 13:00 - 14:00 1.00 - - - 14:00 - 14:15 I 0.25 I EVAL I P I I W EXIT 14:15 - 14:50 ~ 0.58 ~ EVAL ~ P ~ ~ W EXIT 14:50 - 16:45 1.92 EVAL P WEXIT 16:45 - 18:00 1.25 EVAL P WEXIT 18:00 - 20:30 2.50 EVAL P WEXIT 20:30 - 21:00 0.50 EVAL P WEXIT 21:00 - 23:30 2.50 WHIP P WEXIT 23:30 - 00:00 0.50 WHIP P WEXIT 1 /9/2008 00:00 - 00:30 0.50 WHIP P WEXIT 00:30 - 02:30 2.00 WHIP P WEXIT 02:30 - 03:00 I 0.501 WHIP I P I I WEXIT 03:00-03:15 ~ 0.25~WHIP ~P ~ WEXIT coil. Pick up 11 ft to 9261'. Up wt with no pump was 39.5K. Stinger out of LW P and seals above deployment sleeve. Pump 7 bbls displacement, to displ 2 bbl cement and 5 bbl Biozan to backside of coil. 2.2 bpm, 1350 psi. No returns. Stop pump. RIH again. 28K dwn wt. Set down 10K at same depth so seals are in. Pump 1.6 bpm to bump plug. Pump 4.5 bbls. Did not bump plug. Liner came up hole with us when we pulled up. Very light liner. 2000 lbs. Pick up 20' and RIH to same depth and stack wt. Pump 4 bbls at 1.5 bpm. No bump plub. Pick up full speed while pumping. Pick up 30 ft. RIH with pumps on. Partial returns. RIH to PBTD, stack 10K. No increase in pump press. Work pipe up and down to try and release from liner. Work pipe with and without pump. RIH to PBTD with BHA. Bullhead KCL water down backside of coil to clear any cement from 7" liner and 4-1/2" tubing. Bullhead 5.0 bpm at 1400 psi. Backside volume = 97 bbls. Bullhead 150 bbls. POH while pumping 1.0-2.0 bpm down backside with slick KCL water. L/O BHA. R/U to pump slack management. Circ. across top of stack thru kill line to shaker to clean stack. Fill coil w/ rig water. Reverse circ thru coil at 4.50 bpm, 4500 psi. 3 times. Heard e-line move for a total of 2 min. Reverse circ 3 bbls air thru coil. Cut coil to find E-Line. Cut 39' of coil. M/U SLB Dipple CTC, Re-head eline. meg test eline -okay. PT to 4000 psi. M/U BOT 4-1/2" x 7" whipstock setting BHA #4. WS, #10 J-Hydraulic setting tool, BHI CoilTrak. Overall BHA length 81.33' Continue M/U whipstock setting BHA #4. Stab injector. Open EDC. RIH w/ whipstock BHA #4. RIH at 80 fpm, 0.4 bpm, no returns. At 6500', started getting nearly full returns. Returns were mostly diesel. Log GR tie-in to PDC log from 8920'-8955'. -5.5' correction. Up wt 41 k. Dn wt 30K. PUH to 8.926' too of whipstock. Orient TF to 0 deg highside. Top of Whipstock at 8,926'. Close EDC. Began pumping at 0.5 bpm. Bring up pump to 3000 psi, pressure dropped to 300 psi. Clear indication of release. Shut off pumps, RIH slow, set down 3K. P/U clean. Printed: 1/14/2008 8:59:31 AM ," • • BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To ' Hours Task ~ Code NPT Phase 1/6/2008 Page 5 of 9 Spud Date: 10/14/1980 End: Description of Operations 1/9/2008 03:15 - 05:10 1.92 WHIP P WEXIT POOH to surface, 100 fpm, 1.5 / 0.6 bpm 05:10 - 06:00 0.83 WHIP P WEXIT S/B injector. L/D whipstock setting BHA #4. 06:00 - 06:20 0.33 WHIP P WEXIT M/U Cementing nozzle BHA #5. OAL = 14.55'. 06:20 - 08:00 1.67 WHIP P WEXIT RIH with cementin BHA. circ at 0.7 bpm. 50% returns. 08:00 - 08:15 I 0.251 WHIP I P 08:15 - 09:05 I 0.831 WHIP I P 09:05 - 10:00 I 0.921 WHIP I P 10:00-11:30 1.50~WHIP P 11:30 - 11:50 I 0.331 WHIP I P 11:50 - 14:00 2.17 WHIP P 14:00 - 15:00 1.00 STWHIP P 15:00 - 17:00 I 2.001 STWHIP~ P 17:00 - 20:00 I 3.001 STWHIPI P Tag pinch point on whipstock at 8940' and correct depth to 8930'. -10' correction. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement job. WEXIT Batch mix 20 bbl, 15.8 ppg, G Cement. circ at 1.8 bpm, 1.3 bpm returns, 620 psi. WEXIT Stg 4 bbl water. Press test cement line to 4000 psi. Stg 20.3 bbl, 15.8 ppb, G Cement, 2.1 bpm, 1000-2200 psi. Stop pump. Pump Biozan to cementers to clean line. Blowdown Stage 30 bbl 2# Biozan to displace cement. 20 bbl displ, 2.0 bpm, 700 psi, 1.7 bpm returns. Stage 2% KCL water. 30 bbl displ, 2.0 bpm, 470 psi, Close choke 35 bbl displ, 2.0 bpm, 420 psi, 310 psi SIWHP, CMT at nozzle. 40 bbl displ, 2.0 bpm, 360 psi, 385 psi WIWHP, 5 bbl cmt out 45 bbl displ, 2.0 bpm, 1300 psi, 850 psi SIWHP, 10 bbl cmt out. Open choke and LaY in 10 bbl CMT,1.5 bpm, pull at 40 fpm, hold 300 psi WHP 50 bbl displ, 1.5 bpm, 930 psi, 420 psi choke press, 1 bpm returns. 58 bbl displ, 1.5 bpm, 1300 psi, 400 psi choke press, Bio to nozzle at 8650' Stop pump, Close choke and pull to safety at 8300'. WEXIT Wait 15 min. S z 1 bbl 50 si WHP. wait 10 min. S z 1 bbl, 50 psi WHP, Wait 10 min. Sqz 1 bbl, 100 psi, Wait 10 min. S z 1 bbl, 100 si, Wait 10 min. Sqz 1/2 bbl, 100 psi, Wait 10 min. Not ettin a s z WHP bleeds off slow to zero May be leaking into Sag River perfs above whipstock. Sqz 1/2 bbl, 100 psi, Sqz 1/2 bbl, 100 psi. Cement is Sqz away to top of Sag River perfs and still bleeding off. Open choke and circ at 0.5 bpm. WEXIT RIH while circ at 0.5 bpm. Full returns. RIH to 89 0'. No cement. Circ at 1.5 bpm. 1.45 bpm returns.. WEXIT POH. Circ. bottoms up. No cement to surface. WEXIT M/U 3.80" Window millin BHA with 3.80" HCC Diamond Window mill, used string reamer, 2 Jts 2-3/8" PH6 and BHI Coiltrak tools. OAL = 112.67'. WEXIT RIH with Window milling BHA #6. Dry tag at 8928". Full returns with KCL water. Swap well to 2# Biozan. WEXIT Mill cement down from 8927-8930' i win ow ru - finer. tart i ing at Printed: 1/14/2008 8:59:31 AM 12/28/07 ~cfumberrer NO. 4542 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~r,,~~ FED ~ ~ 2008 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 L. GID7 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Orion. Well _Inh $ Inn rlncr ..f:.... n_a_ o~ Z-15 11968824 PROD PROFILE 12/17/07 1 L1-02 11982424 PROD PROFILE - 12/12/07 1 GNI-04 NIA DIGITAL SHEAR SONIC TOOL ()~-- 11/08/07 1 N-27 11962771 SCMT '~- - ~ 11128/07 1 A-12 11975740 USIT Q - ~ t 12/03/07 1 03-36A 40015115 OH MWD/LWD EDIT ~ ~-= (~ (~ ~j' 04/30/07 2 1 V-210 11963075 MEMORY INJECTION PROFILE 12118/07 1 ~v....v.~~~vva-.~a.v~n , YI V1V1\II~V MI\V RCINnI\119V V19C liVr"1 CN~.n iV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~ :{ -,~. ~~ ~~ Anchorage, Alaska 99508 Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • i~ STATE OF ALASKA _ - ~+ • ALAS~DIL AND GAS CONSERVATION COMM ~~ ~~~-+E'~~~ REPORT OF SUNDRY WELL OPE NS JAN 1 6 2008 `lay 1. Operations Performed: Alaska ~1~ $ Gas C011S, G011'UTIISSIOt) ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Qn1~{~~~ended 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 180-117 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20515-00-00 7. KB Elevation (ft): 77 4' , 9. Well Name and Number. y PBU A-12 8. Property Designation: 10. Field /Pool(s): ADL 028286 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9801 ~ feet ~,r~~r~~~~, ~7'~ ., ~I~ SAN ~ ~~(~ true vertical 9553 ~ feet Plugs (measured) None Effective depth: measured 9757 feet Junk (measured) 9757 (Approx.) true vertical 9511 feet Casing Length Size MD TVD Burst Collapse Structural ~ '~ . _ __ . ,_. ,_- Conductor 113' 20" x 30" 113' 113' Surface 2677' 13-3/8" 2677' 2677' 5380 .2670 Intermediate 8804' 9-5/8" 8804' 8614' 6870 4760 Production Liner 1489' 7" 8311' - 9800' 8166' - 9552' 8160 7020 Perforation Depth MD (ft): .9012' - 9107' Perforation Depth TVD (ft): 8807' - 8896' 4-1/2", 12.6# 13Cr80 8399' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker's-3' packer 8144' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pulled tubing patch and plug. Cut and pulled tubing. Run USIT on 9-5/8". Set Bridge Plug at 2740'. Cut and .pull 9-5/8" casing from -2140'. Run new 9-5/8" (47#, L-80) casing to 2145', cement with 150 Bbls Class 'G' (842 cu ft / 720 sx). Pull RBP. Ran new Chrome completion. Prep for S/T. 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 N/A if C.O. Exempt: Contact Howard West, 564-5471 307-324 Printed Name Terfie Hubble Title Drilling Technologist O / Prepared By Name/Number: ' ~` Si nature Phone 564-4628 Date JD Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 Submit Original Only ~"~ tt~rv ~ w~ tooi Digit~a7 Well File ~ ~ Page 1 of 2 •Well: A-12 Well History Well Date Summary A-12 10/18/2007 T/I/O = 500/460/70. Temp = SI. Monitor WHP (pre rig). AL SI @ casing valve. ALP = 1700 psi. S-Riser = 10 psi & SI @ lateral valve. TP increased 190 psi, IAP increased 90 psi, OAP increased 30 psi since last bleed on 9/28/07. A-12 10/19/2007 TIO = 480/460/70. Temp = SI. Bleed WHPs to 0 psi (pre LDS). Flowline = 50 psi. AL blinded. T FL @ 240', IA FL @ 80'. Bled T & IA simultaneously to gas buster tank. After 15 mins T & IA both began slugging fluid, both @ 300 psi. Bled T & IA for 5 hrs, fluid and gas (put 20" of liquid in gas buster tank). TP increased 140 psi, IAP decreased 200 psi (from initial WHPs), OAP unchanged. Monitored 30 mins. TP increased 30 psi, IAP increased 40 psi. FWHPs = 650/300/70. A-12 10/20/2007 ***WELL SHUT IN ON ARRIVAL*** (pre wh repair) RIG UPS/L UNIT W/ EXTRA RISER CURRENTLY DRIFTING TO HLS TBG PATCH W/ 3.80 G-RING @ 7205'MD *** CONT WSR ON 10-21-07*** A-12 10/21/2007 *** CONT WSR FROM 10-20-07*** (pull patch) MADE SEVERAL ATTEMPTS TO PULL HLS TBG PATCH AT 7203' MD (UNSUCCESSFUL) *** LEFT WELL S/I NOTIFY OP OF STATUS*** A-12 10/23/2007 ***WELL S/I ON ARRIVAL*** (pre rwo) RIGGING UPBRAIDED LINE IN PROGRESS ***JOB CONTINUED ON 10-24-07 WSR*** A-12 10/24/2007 ***WSR CONTINUED FROM 10/23/2007*** (pre rwo) PULLED HLS TBG PATCH @ 7181' SLM. RECOVERED ALL SLIPS, BUT MISSING UPPER & LOWER ELEMENTS. RIGGED UP SLICKLINE, FISHING ELEMENTS IN PROGRESS. ***CONT JOB ON 10/25/07 WSR*** A-12 10/25/2007 ***WSR CONTINUED FROM 10/24/2007*** PURGED 12 GAL OF HYD FLUID DOWN CHEM INJECTION LINE. RAN 3-PRONG GRAB & CENTER SPEAR TO TOP OF PLUG @ 8318' SLM, NO ELEMENTS RECOVERED. MADE MULTIPLE BAILER RUNS TO PLUG @ 8317' SLM... RECOVERED APPROX. 1/2 GAL OF PARAFFIN & PIECES OF PATCH ELEMENTS. -- CURRENTLY IN PROCESS OF PULLING TT PLUG. ***CONT JOB ON 10/26/07 WSR*** A-12 10/26/2007 ***CONT. JOB FROM 10/25/07 WSR*** [pre nvo] PULLED 2-7/8" XX PLUG FROM NIPPLE REDUCER @ 8317' SLM. PULLED 4-1/2" NIPPLE REDUCER FROM XN NIPPLE @ 8317' SLM. RAN 3.75" CENTRALIZER & S-BAILER TO 8300' SLM... DRIFT CLEAR. ***LEFT WELL S/I*** A-12 10/31/2007 Load TBG Assist S-line(RWO prep)Road to location Job in progress Continued on 11/01/07 A-12 11/1/2007 T/I/0=1150/500/0+ Temp=S/I Load TBG (RWO prep) Pumped 5 bbls AMBNT Neat meth spear followed by 150 bbls 100* crude to load TBG FWHPs=20/700/0+ Annulus casing valves left open to gauges A-12 11/1/2007 INITIAL WHP 200/500/0 ET HALLIBURTON 4-1/2" FASDRILL PLUG @ 8300' MID ELEMENT. COOH FOR LRS TO TEST PLUG (OMIT TXIA TO 3500 P OMIT TXIA TO 3500. PASSED. START TO BLEED PRESSURES DOWN WAIT ON BLEED BEFORE RIH WITH POWER JET CUTTER. ****JOB IN PROGRESS AND CONTINUED ON 11-02-07 WSR**** A-12 11/1/2007 T/I/O = 100/530/20 Temp = SI CMIT TxIA to 3500 psi PASSED. Pumped 45.7 bbls of diesel into the tubing to reach test pressure. CMIT TxIA lost 110/90 psi in the 1st 15 min and 40/20 psi in the 2nd 15 min for a total loss of 150/110 psi in the 30 min test. Bled TxIAP back down. Final WHP's = 380/520/20 "Annulus casing valves tagged & left open" ---- SLB still on well on departure----- A-12 11/2/2007 ***CONTINUED FROM 1 NOV 2007*** WHP 200/500/0 RIH W/ POWER JET CUTTER, 3.65" OD, CUT DEPTH 8231'. POOH, CONFIRMED CUTTER FIRING, RDMO. DID NOT TAG TD. PAD OP NOTIFIED UPON DEPARTURE. WHP 500/500/0 ***JOB COMPLETE*** A-12 11/4/2007 T/I/0=500/500/0 Temp=S/I Circ out Freeze protect well & F-line(RWO prep)Pumpedl0 bbl AMBNTneat meth spear,879 bbls 110* 1 % KCL down TBG taking returns up IA through Jumper loop and casasco into F-line F-protect IA jumper w/2 bbls meth Pumped 160 bbls 80* diesel into IA U-tube for TBGxIA freeze protect F-protect F-line w/7 bbls meth 52 bbls crude 30 bbls diesel Final Whp's=vac/vac/o *** Swab shut wing shut pit valve open SSV shut master open casing valves open *** http://digitalwellfile.bpweb.bp.coin/WIInfo/Reports/ReportViewer.aspx 1/14/2008 Digital Well File ~ ~ Page 2 of 2 ~A-12 11/4/2007 T/I/O = 0/0/0 Temp = SI MIT OA to 2400 psi PASSED. Pumped 3.8 bbls of crude into the OA to reach test pressure. MIT OA lost 90 psi in the 1st 15 min and 10 psi in the 2nd 15 min for a total loss of 100 psi in the 30 min test. Bled OAP back to 0 psi. Final WHP's = 0/0/0 "Annulus casing valves tagged & left open" A-12 11/5/2007 T/I/O=SSVNAC/0, Temp=Sl. Free 2 stuck LDS (Pre rig). 2 stuck LDS on casing head upper flange. Stung into IC test void to verify 0 psi in void. Functioned LDS, and discovered 3 stuck. Freed up 3 stuck LDS on casing head, left backed out. A-12 11/6/2007 Freeze protect flowline. (RWO prep) Pump 2 bbls meth, 39 bbls crude, 3 bbls meth, 51 bbls crude, 2 bbls meth down flowline. Well left s/i, casing valves open to gauges. A-12 11/11/2007 Set 4" H plug BPV Print Date: 1/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 1/14/2008 • Start: 11 /21 /2007 Rig Release: Rig Number: BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Contractor Name: Rig Name: -'gyp ~~ ~ ~,v Date From - To Hours Task Code NPT __ _ l _ _ -- 11/29/2007 100:00 - 06:00 I 6.001 MOB P 06:00 - 09:00 3.00 MOB P 09:00 - 11:00 2.00 MOB P 11:00 - 13:00 2.00 MOB P 13:00 - 15:00 2.00 MOB P 15:00 - 18:00 3.001 RIGU P 18:00 - 19:00 1.00 WHSUR 19:00 - 21:00 2.00 WHSUR P 21:00 - 22:00 1.00 KILL P 22:00 - 00:00 2.00 KILL P 11 /30/2007 00:00 - 00:30 00:30 - 01:00 01:00 - 01:30 01:30 - 03:30 0.50 KILL P 0.50 KILL P 0.50 WHSUR P 2.00 WHSUR P 03:30 - 06:00 06:00 - 09:00 09:00 - 14:00 14:00 - 14:30 14:30 - 22:30 2.50 BOPSU P 3.00 BOPSU P 5.00 BOPSU P 0.50 BOPSU P 8.00 BOPSU P Phase • Page 1 of 18 Spud Date: 10/14/1980 End: Description of Operations PRE Move Doyon 16 from Pad 10 to A-12. Rig on D-Pad Access Road @ 06:00 hrs. PRE Continue rig move from D-Pad Access Road to DS-A. PRE Spot Rig. PJSM and prep Location, lay Herculite and Rig Mats. Remove Rear Booster Wheels. Set BOPE in Cellar and secure. PRE Position Rig to raise Derrick. Raise Derrick and Secure. PRE PJSM. Jack up Rig and move over Well Slot A-12. Shim and level Rig. PRE Spot Pump Module, Slop Tank, and Mud Lab. Bring Tools and Equipment to Rig Floor and Cellar. Prep Pits to load Fluid. R/U Circulating Lines on Tubing and IA through Pump Manifold in Cellar. R/U 2" Line for OA to Slop Tank. Double Valve IA. Accept Rig @ 18:00 hrs. DECOMP Load Pits w/ 120 deg F Seawater and Mix 20 bbl High Visc Sweep. DECOMP Bring DSM Lubricator, Tools and Equipment to Rig Floor. Check for 0 Pressure on Tubing, IA, and OA. R/U DSM Lubricator to 1000 psi. Good Test. Pull BPV as per CH2MHill Wellhead Tech. Tubing Pressure 0 psi. UD DSM Lubricator and Equipment. DECOMP PJSM with Rig Team, Vac Truck Drivers and Mud Engineer for testing and upcoming well kill operation. Fill Circuating Lines and test Lines to 250 psi low pressure and 3500 psi high pressure. DECOMP Start Well Killing Operations. R/U and reverse circuate 50 bbls at 7 BPM with 860 psi. Line up to pump down the tubing and take returns up the IA to the Slop Tank. Pump 20 bbl High Viscosity Spacer followed by 650 bbls of 8.5 ppg 120 deg F Seawater at 8 BPM with 1070 psi. DECOMP Continue pumping 650 bbls of 8.5 ppg 120 deg F Seawater at 8 BPM with 1070 psi. DECOMP Monitor to confirm Well Dead. Tubing Pressure- 0 psi, IA Pressure- 0 psi. OA Pressure- 0 psi. DECOMP R/U and Set TWC as Per FMC Re . DECOMP R/U and test TWC to 3500 si from above. Hold test for 10 charted minutes. Good Test. Line up and test TWC from below to 1500 si. Hold test for 15 charted minutes. Good Test. DECOMP R/D Circulating Lines and Equipment. N/D Production Tree and Adapter Flange. DECOMP Check Tubing Hanger Threads with TDS X/O Sub with 9-1/2 turns. Bleed off and terminate Control Lines. Four 1/4" SS Lines were found, 2 were known to be control lines for SSSV, 1 was for the Chemical Injection Line, the last was unknown. DECOMP P/U BOPE Stack and set on Wellhead. N/U BOPE. Check Pipe Rams for 3-1/2" x 6" Variables. R/U Tools and tighten Annular Cap. Install Bell Nipple on BOP Stack. R/U Circulating Lines. DECOMP R/U Tools and Equipment to Test BOPE. DECOMP Test BOPE to 250 osi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. Test was witnessed by AOGCC Inspector Chuck Sheve, BPX WSL, and Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Page 2 of 18 Legal Well Name: A-12 Operations Summary Report Common W ell Name: A -12 Spud Date: 10/14/1980 Event Nam e: WORKO VER Start : 11/21/2007 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours Task ' Code I NPT I'~ Phase Description of Operations 11/30/2007 14:30 - 22:30 8.00 BOPSU P DECOMP Doyon Toolpusher. Test 1-Pipe Rams w/ 4" Test Joint, Upper IBOP Test 2- Choke Valves 1, 12, 13, 14, Annular Preventer w/ 4" Test Joint, and HCR Kill Test 3- Choke Valves 9, 11, Blind Rams, Lower IBOP, and Manual Kill Test 4- Choke Valve 5, 8, and 10 Test 5- Choke Valve 4, 6, 7, and Dart Valve Test 6- Choke Valve 3, and TIW Valve Test 7- HCR Choke Test 8- Manual Choke Test 9- Choke Valve 2 Test 10- Choke Valve 2 Flange Breaks Test 11- Pipe Rams w/ 4-1/2" Test Joint Accumulater Test- Starting Pressure- 3,100 psi. After Actuation- 1,800 psi. First 200 psi Recovery in 16 Seconds. Full Recovery in 77 Seconds. 5 Nitrogen Bottles C~ 2025 psi. Note: On initial testing, Choke Valve #2 Failed Pressure Test. Replaced Choke Valve #2 and retested good. 22:30 - 23:30 1.00 BOPSU P DECOMP R/U DSM Tools and Equipment. R/U DSM Lubricator and test to 500 psi. Good Test. Pull TWC. Tubing Pressure- 0 psi, IA Pressure- 0 psi, OA Pressure- 0 psi. R/D DSM. 23:30 - 00:00 0.50 PULL P DECOMP P/U Doyon Tubular Handling Equipment. 12/1/2007 00:00 - 00:30 0.50 PULL P DECOMP P/U Landing Joint and M/U X/Os to 4-1/2" TDS Tubing Hanger. RIH and engage Tubing Hanger with 9-1/2 right hand turns. BOLDS. 00:30 - 01:00 0.50 PULL P DECOMP Pull Han er Free at 110 000 Ibs~ P II Ibs; Up Wt of Tubing String- 134,000 lbs. Pull Tubing Hanger to Rig Floor. Bleed pressure off 4th Control Line. 01:00 - 02:00 1.00 PULL P DECOMP R/U and CBU at 11.5 BPM with 800 psi. Returns were clean with no gas. 02:00 - 02:30 0.50 PULL P DECOMP Monitor Well and confirm well dead. Continue to bleed pressure off 4th Control Line. Attempt to purge Control Line w/o success. Camco confirmed Control Line Dead. 02:30 - 03:30 1.00 PULL P DECOMP R/D Landing Joint and X/O Subs. UD FMC Tubing Hanger. Secure Control Lines and Chemical Injection Line, R/U to Camco Spooling Unit on Floor. R/U Handling Tools to pull and UD 4-1/2" Tubing. 03:30 - 16:00 12.50 PULL P DECOMP POOH and UD 4-1/2" 12.6# L-80 TD Tubin Recovered 215 LeSalle Clamps, 203 Jts of Tbg, 4 Otis 1-1/2" GLM's, 1 Chemical Injection Mandrel, 1 Camco Bal-O SSSV, Dual incapsulated 1/4" SS Control Lines to SSSV 1990', Dual incapsulated 1/4" SS Chemical Injection Lines to Chemical Injection Mandrel -8200'. Tbg was in decent shape on outside small amount of soft black scale material present. Found 1 hole and numerous places of significant external corrosion on Jt #1 (as per tbg tally dated 6/1/90 ). There was a heavy build up of scale and material on the outside of the tbg at this point but only in about a 10' section. Depth of hole and corrosion -8170' md. Jet Cut was at 8221.4' Length of cut joint = 3.51'; OD of Flare = 5" Printed: 1/14/2008 8:46:27 AM i • BP EXPLORATION Page 3 of 18 ~ Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours Task Code NPT 12/1/2007 16:00 - 17:30 I 1.5~PULL ~ P 17:30 - 18:00 0.501 FISH P 18:00 - 18:30 I 0.501 FISH I P 18:30 - 20:30 2.00 FISH P 20:30 - 00:00 I 3.501 FISH I P 12/2/2007 00:00 - 03:30 3.501 FISH 03:30 - 04:30 I 1.001 FISH 04:30 - 06:00 1.501 FISH 06:00 - 10:00 I 4.001 FISH I P Spud Date: 10/14/1980 Start: 11 /21 /2007 End: Rig Release: Rig Number: Phase. Description of Operations DECOMP Clean and Clear Rig Floor of Tbg Handling Equipment, Control Line Spooler, and LeSalle Clamps. DECOMP M/U Landing Joint and set Wear Ring with 8.75 ID. UD Landing Joint. DECOMP Gather up Baker Tools and Equipment for BHA #1 (Dress Off and Grapple Assembly). Dress Guide Shoe and Overshot with 4.5" Grapple. DECOMP M/U BHA #1 (Dress Off and Grapple Assembly) consisting of Fluted Guide Shoe, Overshot w/ 4.5" Grapple, Top Sub, Bumper Sub, Jars, Pump Out Sub, X/O, (9) 6-1/8" Drill Collars, X/O, Accelertor Jars, and X/O to 4" HT-38 Drill Pipe. Total Length of BHA #1- 324.97' DECOMP RIH with BHA #1 on 4" HT-38 Drill Pipe picked up from Pipe Shed to 3200'. DECOMP Continue RIH with BHA #1 on 4" HT-38 Drill Pipe picked up from Pipe Shed. Picked up 250 total Joints to 8202'. DECOMP Establish Fishing Parameters of Up Wt- 175,000 Ibs; Down Wt- 170,000Ibs; Rot Wt- 175,000 Ibs at 50 RPM and 3,000 ft-Ibs Torque; Pump Pressure- 290 psi at 4 BPM. RIH and to To of Tubin Stub at 8223'. Dress off Tubing Stub at 55 RPM and 3500 ft-Ibs Torque and 12,000 Ibs WOB to 8224' where Pump Pressure increased from 180 to 890 psi at 3.5 BPM. Shut down Pump and slide 5' over Tubing Stub to 8229'. Stack 20,000 Ibs of Tubing Stub. Make 13 jar Licks from 40,000 Ibs to 150,000 Ibs overpull. At 150,000 Ibs overpull, Tubing Stub jarred free. POOH to 8202' and R/U to circulate. DECOMP Pump 20 bbl high viscosity Sweep. Circulated Sweep out of Hole at 11.5 BPM with 1930 psi. Sweep did not bring a noticeable increase in solids to Surface. DECOMP POOH with Overshot Grapple BHA. Stand Back DP and DC's. 10:00 - 11:00 I 1.001 FISH I P 11:00 - 13:00 2.00 FISH P 13:00 - 13:30 I 0.501 FISH I P 13:30 - 16:00 2.50 FISH P 16:00 - 16:45 0.75 FISH P DECOMP B/O BHA. UD Jars and Bumper Sub. B/O Overshot and Grapple. Did not recover the whole fish, the Seal Assembly and remaining tbg and jewelry to recover was 33.5 ft. Only recovered apiece -3.05' long, piece of the tbg body that grapple latched into to recover the remaining fish. The tube body parted to what looks like bad pipe. The part was jagged with sharp edges and not indicative of tensile strength. DECOMP Clean and Clear Rig Floor. Contact Town and Discuss Options. W III Attempt to fish again with bigger OD grapple sized to 5.25" to grab the tbg collar, worried about more bad pipe. Wait on parts from Baker Fishing to arrive. DECOMP M/U BHA #2, same Overshot /Grapple Assembly but with grapple sized to 5.25" to grab the 4-1/2" Btrs Tbg Collar. DECOMP RIH w/ BHA#2 on 4" HT-38 Drill Pipe from Derrick to 8202'. DECOMP Initial Parameters; Up Wt = 175,000 Ibs; Dw Wt = 170,000 ibs; Rot Wt = 175,000 Ibs. 2,500 Ibs free torque at 35 RPM's. Pump Rate = 4.0 bpm at 270 psi. S/O to top of Tbg Stub at 8226' continue to S/O and Stack 20,000 Ibs on Fish to 8229'. P/U and Find over Pull, latched into fish. Make 13 Jar Licks from 35,000 Ibs to 100,000 Ibs over with straight pulls up to 150,000 Ibs over. Jar Something loose. F'rlnt8tl: 7/l4/ZUUS 8:4ti:2/ HM ~ ~ BP EXPLORATION Page 4 of 18 Operations Summary Report Legal Well Name: A -12 Common W ell Name: A -12 Spud Date: 10/14/1980 Event Nam e: WORKO VER Start : 11/21/2007 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: Date '~~ From - To Hours j Task Code , NPT ' Phase ', Description of Operations _ - --- 12/2/2007 ---- 16:45 - 18:00 1.25 FISH P DECOMP __ _ Circulate Bottoms Up at 10.0 BPM and 1620 psi. 18:00 - 21:00 3.00 FISH P DECOMP POOH standing back 4" HT-38 Drill Pipe in Derrick. 21:00 - 22:30 1.50 FISH P DECOMP POOH with BHA #2 with full recovery of Production Jewelry. ~, Stand back 3 stands of Drill Collars in Derrick UD Overshot Extensions, Grapple, and Guide Shoe. Recovered Parted TBG Pup, 2 X/O Pups, 1 X/O Collar, 1 SWS Nipple, 1 full BTRS TBG Pup, SBR Barrel with Top Sub and Guide Shoe. Total Length of Recovery- 31.14'. Pitting was prevalent thoughout the fish and the SBR Barrel had significant external damage in multiple areas beyond reuse. 22:30 - 23:00 0.50 FISH P DECOMP Clear and clean Rig Floor. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U BHA #3 (Cleanout Assembly) consisting of Washpipe and Shoe, Drive Sub, X/O, (2) 5-1/2" Boot Subs, CSG Scraper, Bit Sub, Bumper Sub, Oil Jars, (3) Stands of 6-1/8" Drill Collars, and X/O Subs. Total Length of BHA #3- 342.63' 12/3/2007 00:00 - 04:00 4.00 CLEAN P DECOMP RIH with 4" HT-38 Drill Pipe from Derrick to 8220'. Reciprocate casing scraper 5 times across projected packer setting depth from 8100' to 8200'. 04:00 - 04:30 0.50 CLEAN P DECOMP Establish Parameters of Up Wt- 175,000 Ibs; Dw Wt- 170,000 Ibs; Rot Wt- 175,000 Ibs at 50 RPM with 3,000 ft-Ibs free torque; Pump Pressure- 420 psi at 5.5 BPM. Continue RIH washing over slick stick. T.~a ton of 9-5/8" Baker "SAB" packer at 8260'. S/O 5,000 Ibs of packer. R/U to circulate. 04:30 - 06:00 1.50 CLEAN P DECOMP Pump 20 bbl high viscosity sweep. Pump sweep out of hole at 11.5 BPM with 1800 psi. A good amount of sand and scale seen with sweep. 06:00 - 09:30 3.50 CLEAN P DECOMP POOH with Wash Over /Scraper BHA, Stand Back DP. 09:30 - 10:00 0.50 CLEAN P DECOMP Stand Back Drill Collars. B/O and UD Wash Over Assembly. Found a very small amount of sand and scale in boot baskets. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM with E-Line Crew and Rig Crew. Spot Unit and Rig Up E-Line Sheaves and Tools. 12:00 - 13:30 1.50 CLEAN P DECOMP Run USIT Log on E-Line from 3000' to surface. Log in Cement and Corrosion mode. No Corrosion problems seen. ' Top of Cement in 9-5/8" x 13-3/8" annulus identified at 2194'. Consult with town and decide to make cut in 9-5/8" Casing at 2140' and set RBP at 2740'. 13:30 - 14:30 1.00 CLEAN P DECOMP Rig Down E-Line Equipment. Wait on HES RBP to arrive. 14:30 - 15:00 0.50 CLEAN P DECOMP Load and M/U HES 9-5/8" RBP set up for 47# Casing and setting tool to 4" HT38 DP. 15:00 - 16:30 1.50 CLEAN P DECOMP RIH with RBP on 4" DP from Derrick to 2740'. 16:30 - 17:00 0.50 CLEAN P DECOMP Establish parameters of Up Wt- 80,000 Ibs; Dw Wt- 82,000 Ibs. Set HES RBP at 2740' with 1 Left hand turn and set 15,000 Ib on tool. Pick up with 5,000 Ibs overpull. S/O 15,000 Ibs and release from RBP with 1/4 turn left. Perform confidence check and POOH to 2673'. 17:00 - 18:00 1.00 CLEAN P DECOMP R/U and ressure test HES RBP to 1500 si. Held pressure for 30 minutes. Good test, charted results. 18:00 - 19:30 1.50 CLEAN P DECOMP R/U and dump 2200 Ibs of 20/40 Sand. Chase sand with mud pump at 1/2 BPM and 50 psi to clear Drill Pipe. 19:30 - 22:30 3.00 CLEAN P DECOMP Shut down mud pump and allow sand to settle. Tagged sand at 2726' C~3 20:50 hrs, Tagged again at 2702' C~ 22:30 hrs. 22:30 - 00:00 1.50 CLEAN N WAIT DECOMP Clean pits for new brine. Wait or vac truck with 9.0 ppg brine. Printed: 1/14/2008 8:46:27 AM BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: WORKOVER Start: 11/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To ' Hours I Task Code NPT Phase ~ Description of Operations 12/3/2007 22:30 - 00:00 1.50 GLEAN N WAIT DECOMP M-I Mud Plant did not have brine ready when needed. 12/4/2007 00:00 - 03:00 3.00 CLEAN N WAIT DECOMP Clean pits for new brine. Wait or vac truck with 9.0 ppg brine. M-I Mud Plant did not have brine ready when needed. Phase II driving conditions C~ 01:30 hrs. CH2MHill waiting for convoy. Wind up to 70 MPH on Location. 03:00 - 04:00 1.00 GLEAN P DECOMP PJSM with rig team and CH2MHill Vac Drivers on displacement procedures. All precausions taken for working in high winds. All personnel will use the buddy system while going outdoors. Load pits with 140 deg F 9.0 ppg NaCI brine. 04:00 - 05:00 1.00 CLEAN P DECOMP Pump 20 bbl high viscosity spacer and chased with 230 bbls of 9.0 ppg brine at 7.5 BPM with 650 psi. 9.0 ppg Brine in and Out. Monitor well. 05:00 - 06:00 1.00 CLEAN P DECOMP POOH and stand back 4" HT-38 drill pipe in derrick. 06:00 - 06:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 06:30 - 07:00 0.50 CLEAN P DECOMP Pull Wear Ring. 07:00 - 07:30 0.50 FISH P DECOMP PJSM M/U 9 518" Gsg Cutter assembly, BHA Consist of Multi String Cutter, XO, Stabilizer, XO, BHA Lenght=11.36' 07:30 - 08:30 1.00 FISH P DECOMP RIH to 2,100', Obtain Parameters Up Weight=75,000#, Down Weight=70,000#, Rotating Weight=72,000#, 2,000 ft-Ibs Torque, at 50 rpm, 570 psi at 60 strokes/ min 08:30 - 09:00 0.50 FISH P DEGOMP Locate collars at 2,127' and 2,166'. 09:00 - 09:30 0.50 FISH P DECOMP B/D Top Drive, Install Head Pin. 09:30 - 11:00 1.50 FISH P DECOMP Waiting on Wind. 11:00 - 15:30 4.50 FISH N DECOMP Call out Little Reds, Pressure Test Hard Line to Tank to 500 psi. Circulate Well bore at 2 bpm 1,190 psi with 115 deg 9.0 ppg brine, While waiting on LRS. 15:30 - 16:00 0.50 FISH P DECOMP Position Cutter to 40' in on stand #23, ake Cut at 2,140' . Pump rate 8 bpm, 1450 psi, 60 rpm w/ 2,500 ft-Ibs Torque, Indication of cut w/ 5,000# Weight increase, 650 psi pressure loss, 10,000 ft-Ibs Torque reduction. 16:00 - 16:30 0.50 FISH P DECOMP Shut down Pumps and Rotation, Close Annular Preventer, Establish Circulation Rates Initial Rate 1.2 bpm 1,780 psi. 1.4 bpm 1,400 psi, First 25 bbls pumped with rig 9.0 ppg brine. Returns to slop tank, Crude diesel followed by Thick Arctic Pack. 16:30 - 17:30 1.00 FISH P DEGOMP Attempt to Pump EUR-710 for a pill, Unable to pump out of drums to thick, R/U Little Red to pump Diesel into Annulus. 17:30 - 00:00 6.50 FISH P DECOMP PJSM with LRS and Rig Crews on Displacement of Arctic pack from Well Bore. Pressure Test Little Reds Lines to 2,500 psi. Pumped 75 bbls of120 deg Diesel into 13 3/8"x 9 5/8" Annulus at 2 bpm with800 psi. Channeling after 60 bbls, Shut down Pumping after 75 bbls. Let Diesel Soak in 13 3/8 x 9 5/8" Annulus for 45 minutes. Pumped 20 bbls Hi-Vis Sweep followed by 125 bbls of 120 deg 9.0 ppg Brine at 6 bpm with 1,070 psi. Sweep returns observed at tiger tank at 57 bbls away indicating Channeling. Allowed 9.0 brine to soak for 45 minutes. Pumped 20 bbl Hi-Vis Sweep followed by 65 bbls of 120 deg Diesel, Allowing Diesel to Soak for 45 minutes. Pumped 180 bbls of 120 deg 9.0 ppg Brine at a rate of 7.5 bpm with 1,490 psi Clean returns observed at tiger tank on final circulation. 12/5/2007 00:00 - 00:30 0.50 FISH P DECOMP Allowed Brine to soak for 30 minutes, Continue to Circulate with 9.0 ppg, 120 deg brine at 7 bpm w/1,500 psi. Confirming Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To 'Hours ~~ Task Code NPT Spud Date: 10/14/1980 Start: 11 /21 /2007 End: Rig Release: Rig Number: Phase Description of Operations 12/5/2007 00:00 - 00:30 0.50 FISH P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:00 0.50 FISH P 02:00 - 02:30 0.50 FISH P 02:30 - 04:00 1.50 WHSUR P DECOMP Clean returns at Tiger Tank DECOMP Opened Annular Preventer, CBU at 10 bpm with 2,100 psi. Blow Down Surface Equipment. DECOMP POOH f/2,140', L/D Cutter Assembly. DECOMP Clear and Clean Rig Floor. DECOMP M/U 9 5/8" Casing Spear Assembly, and Spear 9 5/8" Casing. DECOMP BOLDS, Had difficulty backing out one of the lock down screws, Had three turns out when it locked up. Steamed and continue to back out LDS as per FMC Rep. LDS sheared off at the Well Head. Called out Cameron to Drill out LDS. 04:00 - 07:30 3.50 WHSUR N SFAL DECOMP 07:30 - 09:00 1.50 WHSUR N SFAL DECOMP 09:00 - 16:00 7.00 WHSUR N SFAL DECOMP 16:00 - 16:30 0.50 CASE P DECOMP Well work report dated 11/5/07 states that all LDS were worked free. The LDS that were initially stuck (3) were backed out and left out. The LDS that stuck was in all the way. Wait on Cameron to arrive on location with Wach's Drill for Lock Down Screws. R/U Wach's Drill in cellar on twisted off lock down screw for casing spool. Drill Out FMC "Standard "LDS as ner ameron with Wach'c _ Drill Assembly. Re-Tap Hole and Install new LDS. Pull 9-5/8" casing and mandrel packoff / hanger to the floor through BOP's. P/U and work f/ 50,000 Ibs - 200,000 lbs. Casing started moving on 4th attempt at 190,000 Ibs. Pulled Casina and Mandrel to floor with 135,000 Ibs. Found aouae in Discuss findings with town and LDS will be worked on once all casing is out of hole. 16:30 - 17:00 0.50 CASE P DECOMP Circ down 9-5/8" casing and up 13-3/8" annulus at 10 bpm and 800 psi for 135 bbls, take returns to flow back tank. Returns had - 50-60bbls of Arctic Pack followed by another 40 bbls of dirty brine /Arctic Pack mix, last 30 bbls returns cleaned up to mostly brine. Monitor well for flow. 17:00 - 17:30 0.50 CASE P DECOMP B/O and L/D Csg Spear. Blow Down Top Drive. R/U False Bowl, Power Tongs, and Elevators. 17:30 - 18:00 0.50 CASE P DECOMP Rigging up the rig floor with 9 5/8" casing tools. 18:00 - 19:30 1.50 CASE P DECOMP B/D T/D and R/U test equipment, test wellhead and well bore to 750 si for 15 charted minutes. 19:30 - 00:00 4.50 CASE P DECOMP POOH and L/D 9 5/8" CSG. iron 2,140 to 615'. Break out 40,000 to 50,000 ft-Ibs. 12/6/2007 00:00 - 01:00 1.00 CASE P DECOMP Continue to L/D 9 5/8" CSG f/615' to Cut Jt. Recovered 54 jts Casing and Cut jt. Casing In Generally good condition, Cut jt flare 10.25" and 12.26' in length. Note: No centrilizers. Old reports state that there were centrilizers placed every 3rd joint. No centrilizers found when , VD casing. No signs that centrilizers were ever installed. 01:00 - 02:00 1.00 CASE P DECOMP Clear the Rig Floor on false bowl and casing tongs, Clean rig floor. 02:00 - 02:30 0.50 CASE P DECOMP P/U Spear Assembly and break down same. 02:30 - 03:30 1.00 CASE P DECOMP N/D BOPs and Flow line, In preparation for LDS Replacement and Repair 03:30 - 06:00 2.50 WHSUR P DECOMP Replaced and Redressed 5 LDS. Ground Nose off Stuck LDS. There is two LDS that are Stuck, both flagged and in OUT Printed: 1/14/2008 8:46:27 AM s • BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Start: i 1/21/2007 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task I' Code NPT Phase Page 7 of 18 Spud Date: 10/14/1980 End: Description of Operations 12/6/2007 03:30 - 06:00 2.50 WHSUR P DECOMP position. 06:00 - 07:00 1.00 WHSUR P DECOMP N/U BOP's and Flow Riser. 07:00 - 08:00 1.00 WHSUR P DECOMP Install Test Plug in lower profile. Test Breaks to 250 psi low and 3500 psi high for 5 mins each. Pull Test Plug. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM and M/U Dress Off BHA for 9-5/8" Casing w/ 13-3/8" Casing Scraper. Dress Off Shoe, Wash Pipe Extension, Wash Over Boot Basket, XO, 13-3/8" Csg Scraper, Bit Sub, Bumper SUb, Oil Jar, XO, 9 DC's, XO, XO. Total Length = 320.74' 09:00 - 10:00 1.00 CLEAN P DECOMP RIH w/ Dress Off BHA on DP. 10:00 - 10:30 0.50 CLEAN P DECOMP Line up and Pump 70 bbls out OA to Flow Back Tank at 8 bpm 550 psi. Approx 50 bbls of Arctic Pack seen at tank. 10:30 - 11:30 1.00 CLEAN P DECOMP Take Initial Parameters. Up Wt = 87,000 Ibs; Dw Wt = 80,000 Ibs; Rot Wt = 90,000 Ibs. 2500 ft -Ibs torque at 60 RPM's, 8 bpm at 550 psi. S/O and Find Top of Stub at 2140'. Mill on Top of 9-5/8" Casing Stub at 60 RPM and 5000 - 10000 ft-Ibs torque with 4 bpm and 135 psi. Dress Off the Top 6 inches of Casing Stub. P/U and Slide over Casing easily with rotation. P/U and Slide over Casing again w/o rotation. Went over easily. 11:30 - 13:00 1.50 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Chase with 9.0 ppg Brine at 7.5 bpm and 275 psi. Returns going to Slop Tank Initially but turned over to System after about 35 bbls. Arctic Pack Showing Up in Chunks every so often with One Big Slug as Sweep was back at surface. Shut-Down Pumps and Monitor for Flow. 13:00 - 14:00 1.00 CLEAN P DECOMP B/O and Blow Down Top Drive. POOH and Stand Back DP. 14:00 - 15:30 1.50 CLEAN P DECOMP Stand Back DC's. B/O and UD Dress Off BHA. Mill face showed good signs of wear and boot basket contained -1 gallon of curly metal shavings. 15:30 - 16:30 1.00 CASE P TIEB1 R/U Torque Turn, False Bowl, & Side Door Elevators. Load Centrilizers and Cement Head on Rig Floor. 16:30 - 00:00 7.50 CASE P TIEB1 PJSM with Rig Crew on Running 9-5/8" Casing. Run 9-5/8" 47#, L-80 Casing, Bowen Overshot Patch, HES Baffle Collar, ES Cementer w/ XO to TC-II, 15 Joints of 9-5/8" TC-I I UD 't # 6 and #7 due to galled threads and poor make up on Chart, Had to Clean up several TC-II pin ends due to rough surface on nose seal. TC-II x Hyd 563 XO and 38 Joints of 9-5/8" Hyd 563. TC-II Torqued to 17,800 ft-Ibs, Hyd 563 Torqued to 15,800 ft-Ibs. 12/7/2007 00:00 - 01:00 1.00 CASE P TIEB1 Continue to RIH with 9 5/8", 47#, HYD 563 Casing. From 1760' to 2,140', Up Weight=130,000#, Down Weight=132,000#, Ta ed To of Stum at 2,142', Rotated down to 2,144'. Pull tested Casing Patch to 100,000# over string weight. 01:00 - 01:30 0.50 CASE P TIEB1 M/U Cement Head and Circulating Lines. 01:30 - 03:00 1.50 CASE P TIEB1 Attempt to Pressure Test casing to 2,000 psi, At 1,150 psi Casing move at rig floor, continued to pressure up and at 1,500 psi we had returns from casing. E-S Cementer had partially, o ened. Circulated at 6 bpm with a pressure of 1,750 psi, increased pumps to 7 bpm with a pressure of 2,700 psi in an attempt to fully open cementer. Halliburtons recomendation was to Drop the opening bomb to fully open cementer. Called and Informed Anchorage Engineer of halliburtons recomendation. R/D Cement Head and Circulating Lines, Printed: 1/14/2008 8:46:27 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Page 8 of 18 ~ Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: WORKOVER Start: 11/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ,, Date From - To Hours I Task Code NPT Phase Description of Operations CASE P TIE61 Dropped the opening bomb down the 9 5/8" csg. R/U the 12/7/2007 01:30 - 03:00 1.50 Cement head and Circulating Lines, Allowed the bomb to drop and Circulated at a rate of 6 bpm with 400psi indicating cementer was now fully open. 03:00 - 03:30 0.50 CASE P TIEB1 PJSM with SLB cementers, Halliburton Hand, Truck Drivers, Mud Engineer, and Rig Crews about the cementing program and displacement. 03:30 - 05:00 1.50 CEMT P TIE61 Pumped 5 bbls water with SLB cementers, Tested Lines to 4,500 psi. Pumped 150 bbls of Class G Cement at 5 bpm. Displaced with rig pumps, pumping 9.0 ppg Brine at 6 bpm Cement to surface with 130 bbls of displacement pumped. 20 bbls of cement back to surface. Bumped the plug and pressure up to 2,100 psi and held for 5 minutes, Checked Floats, floats holding. Flush Lines with Cement retarder, Cement in Place at 05:00. 05:00 - 06:00 1.00 CEMT P TIEB1 N/D BOPE and Rig Down Cement Head. Clear Rig Floor. 06:00 - 08:30 2.50 CASE P TIEB1 Set Emergency Slips, in Tension with 100,000# over stirng weight, Cut 9 5/8" Casing with Wachs Casing Cutter. Install Pack off. 08:30 - 11:00 2.50 CASE P TIEB1 N/U BOP's. Test Casing Pack Off to 3800 psi (80%) for 30 mins 11:00 - 11:30 0.50 CASE P TIEB1 RU to Test BOP's and Set Test Plug. 11:30 - 20:00 8.50 CASE P TIEB1 Test BOPE 250 psi Low and 3500 psi High. Test witness waived by Lou Grimaldi w/ AOGCC. 20:00 - 20:30 0.50 CASE P TIEB1 B/D Choke Manifold and Kill Line, Pull Test Plug, Set Wear ring. 20:30 - 22:30 2.00 DRILL P TIEB1 P/U M/U Drill out Assembly, 22:30 - 23:00 0.50 DRILL P TIE61 RIH w/ Drill out assembly, to 2,100', Obtain Parameters: Up Weight=95,000#, Down Weight=90,000#, Rotating Weight=90,000#, 60 rpm, 2,000 ft-Ibs Torque, 8 bpm w/ 370 psi, Tagged Cement at 2,115'. Drilled down to E-S Cementer a' 2131. 23:00 - 00:00 1.00 DRILL P TIEBi Drill out Shoe track with 15,000 wob, torque 2-3,000 ft-Ibs, Tagged Baffle Plate at 2,139'. ..12/8/2007 00:00 - 00:30 0.50 DRILL P TIEB1 Drill through Baffle Plate w/5-10,000 wob, 80 rpm, 2-5,000 ft-Ibs of torque, 8 bpm with 370 psi, Pump 20 bbl Hi-Vis Sweep at 9 bpm and 450 psi, Rotate, Reciprocate and Slide through Shoe Track Several times while pumping. 00:30 - 01:30 1.00 DRILL P TIE81 RIH to top of sand, Upweight-100,000#, Down weight=100,000#, Tagged top of sand at 2,690'. Dry Drilled on top of sand with no weight at 50 rpm. Stand back one stand of Drill Pipe. 01:30 - 02:30 1.00 DRILL P TIE61 PJSM with Truck Drivers and Rig Crew to discuss Displacement Operations. Pumped 20 bbl Hi-Vis Sweep followed by 8.4 ppg Sea Water at 8.5 bpm with 450 psi. B/D T/D. 02:30 - 04:00 1.50 DRILL P TIE61 Slip and Cut 88' of Drilling Line, Adust Brake, Grease Draworks, Inspect and Lube. 04:00 - 04:30 0.50 DRILL P TIEBi POOH to 113'. 04:30 - 05:30 1.00 DRILL P TIEB1 Stand Back Drill Collars, B/O and UD Drill Out Assembly, Clean out Junk Baskets approx 2.5 gal of alum w/cement recovered. 05:30 - 07:30 2.00 CASE P TIEB1 Pressure test casin to 3 500 si. Close Blinds and pressure Printetl: 1/14/2008 8:46:27 Am • • BP EXPLORATION Page 9 of 18 Operations Summary Report Legal We11 Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ' Hours I Task Code NPT 12/8/2007 05:30 - 07:30 1 2.00 CASE P 07:30 - 09:00 1.50 CASE P 09:00 - 10:00 1.00 CASE P 10:00 - 11:30 1.50 CASE P 11:30 - 12:00 0.50 ~ CASE ~ P 12:00 - 13:00 1.001 CASE P 13:00 - 15:30 ~ 2.50 ~ CASE ~ P 15:30 - 16:30 I 1.001 CASE I P 16:30 - 17:00 0.50 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 19:30 1.50 CASE P 19:30 - 21:30 2.001 CASE I P Spud Date: 10/14/1980 Start: 11121!2007 End: Rig Release: Rig Number: Phase ' Description of Operations TIEB1 up on casing to 3500 psi for 30 mins -charted. Lost a little over 200 psi in 30 mins. Repeat test to confirm. Lost a little under 200 psi in 30 mins on repeat test. Consult with town on pressure test findings. TIE61 M/U Reverse Circ Junk Basket BHA. TIEB1 RIH w/ Reverse Circ Junk Basket BHA on 4" DP to 2600'. TIEB1 Pressure Test Casing again to 3500 psi for 30 mins. Lost 150 psi in 30 mins on chart. Consult with town on pressure test findings. TIEB1 RIH with one more stand. P/U single joint of DP. Tag Up at 2644'. Initial Parameters Up Wt = 90,000 Ibs, Dw Wt = 95,000 lbs. TIE61 Attempt to circ, unable to. Pressure up to 3000 psi in less than 1/2 bbl. Rack Back on stand and attempt through head pin. Still unable to circulate. Check surface hoses and lines, blow down all. Able to move fluids through surface hoses and lines. Plug down hole. TIEB1 POOH w/drill pipe and stand back in derrick. Fill Hole every 5 stands. TIEB1 Stand Back DC's and B/O BHA. Found Reverse Circ Junk Basket and Boot Baskets packed full of what looks like green cement w/ Arctic Pack. Clean Out BHA. Consult Town with findings. TIEB1 Clean Rlg Floor. TIE61 M/U Clean Out BHA with 8-1/2" Bit. TIEB1 M/U Top Drive C~ 2,498' and wash down to 2,644' ,Pump 20 bbls Hi-Vis Sweep. Up weight=92,000#, Down weight=95,000#, Rotating Weight=95,000#, 40 rpm with 1-2,000 ft-Ibs of torque, Pump rate at 8.5 bpm and 370 psi, Shakers blinded off when sweep back to surface. Large quanity of Arctic pack back to surface TIE61 Continue to wash down to 2,687', Pump 20 bbl Hi-Vis Sweep surface to surface. Again Shakers blinded off, Large quanity of Arctic Pack back at surface, Circulated hole Clean. 21:30 - 22:00 0.50 CASE P TIEB1 POOH from 2,687' to 315'. 22:00 - 22:30 0.50 CASE P TIEB1 Stand Back Drill Collars and UD Clean Out Assembly. 22:30 - 00:00 1.50 CASE P TIEB1 Clean out junk baskets, Approx 2.5 gals of alumnium and metal cutting recovered. M/U RCJB Assembly, BHA consists of: 7 7/8" RCJB, 2-Junk Baskets, Bit Sub, Pump out sub, Lubricated Bumper Sub, Oil Jar, XO, 9-Drill Collars, XO, BHA Lenght=324.48 12/9/2007 00:00 - 00:30 0.50 GLEAN P CLEAN RIH w/RCJB to 2,702' Dropped Reverse circulation ball, Obtain Parameters, Up weight=95,000#, Down Weight=95,000#, Rotating Weight=100,000#, 20 rpm, 2,000 ft-Ibs torque, 4.3 bpm with 2,800 psi. 00:30 - 01:30 1.00 CLEAN P CLEAN Wash down to 2,728' with reverse circulating junk basket. 01:30 - 02:00 0.50 CASE P TIEB1 Drop Opening Dart, pump 20 bbl Hi-Vis Sweep, at 15 bpm with 1,020 psi. Good volume of sand seen with sweep. 02:00 - 02:30 0.50 CASE P TIEBi B/D T/D and POOH to 324'. 02:30 - 03:30 1.00 CASE P TIE61 Stand Back Drill Collars, B/O RCJB, Clean 2 Junk Baskets, Recovered closing plug cone, Landing ring in 5 pieces, and 2.5 gals of alum and metal pieces. Rebuild Pump Out Sub. 03:30 - 04:30 1.00 CASE P TIEB1 M/U RCJB Assembly, BHA consists of: 7 7/8" RCJB, 2-Junk Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Legal Well Name: A-12 Operations Summary Report Page 10 of 18 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: WORKOVER Start: 11/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours j Task Code I NPT Phase 'I Description of Operations 12/9/2007 03:30 - 04:30 1.00 CASE P TIEB1 Baskets, Bit Sub, Pump out sub, Lubricated Bumper Sub, Oil Jar, XO, 9-Drill Collars, XO, BHA Lenght=324.48. 04:30 - 05:30 1.00 CASE P TlEB1 RIH to 2,728' 05:30 - 06:30 1.00 CASE P TIEB1 Take Initial Parameters; Up Wt = 95,000 Ibs, Dw Wt = 98,000 Ibs, Rot Wt = 100,000 Ibs. 2,000 ft-Ibs free Torque at 20 rpms. 7 BPM C~ 1640 psi. Rotate and Wash Down to 2730'. Stop Rotation and Wash Down on top of RBP, Tag at 2740'. Pump 20 bbl High Visc Sweep and Chase Out of Hole at 9.5 bpm at 2700 psi. Small Amount of Sand seen wit cwPPn over the shaker . 06:30 - 07:30 1.00 CASE P TIE61 POOH w/ RCJB BHA. Stand Back DP. 07:30 - 08:30 1.00 CASE P TIEB1 Stand Back DC's. UD RCJB, Boot Baskets, Jars, Bumper Sub, and DC's. RCJB was empty and Boot Baskets contain ~1.5 gallon of sand with a few pieces of aluminim and other metal. 08:30 - 09:00 0.50 CASE P TIEB1 Clean Up Floor and M/U HES Retrieval Tool. 09:00 - 10:00 1.00 CASE P TIE61 Inspect and Service Brake Linkage. 10:00 - 11:00 1.00 CASE P TIE61 RIH to the top of the RBP. Tao Toa at 2740'. 11:00 - 11:30 0.50 CASE P TIE61 Circ off top of RBP 10 bpm and 420 psi, prior to attempting to latch RBP. Small amount of sand seen with bottoms up. 11:30 - 12:30 1.00 CASE P TIE61 Lat h into RBP as er HES. PU to 15,000 Ibs over to release. Wait 5 mins and then S/O past setting depth to confirm latch up. Circ Bottoms Up at 9 bpm and 310 psi. 12:30 - 13:30 1.00 CASE P TIE61 Blow Down Top Drive and POOH with RBP. UD RBP. Rubber had two small cuts but still in place on Plug. Some small metal shaving found on top of plug as well. 13:30 - 17:30 4.00 CASE P TIEB1 M/U Mule Shoe and XO on to bottom of Drill Pipe; 5.2' BHA. RIH with all DP in Derrick to 7873'. P1U 12 Joints from Pipe Shed and Continue to RIH. Tag Top of Slick Stick at 8241'. 17:30 - 19:00 1.50 CASE P TIEB1 Pump 20 bbl High Visc Sweep and Chase out of Hole at 8.5 bpm with 840 psi. Nothing brought back with sweep. 19:00 - 00:00 5.00 CASE P TIE61 POOH UD Drill Pipe from 8,237' to 2,501'. 12/10/2007 00:00 - 02:00 2.00 CASE P TIEB1 Continue to UD Drill Pipe to Pipe Shed. From 2,501' to Surface. 02:00 - 02:30 0.50 BUNCO P RUNCMP Pull Wear Ring. 02:30 - 03:30 1.00 BUNCO P RUNCMP R/U to Run Completion, Change out to Long Bails, Change Elevators, Slips, R/U Torque Turn Equipment. Arrange Completion Equipment in Pipe Shed. 03:30 - 14:00 10.50 BUNCO P RUNCMP PJSM with Packer Hand, Casing Tech, Rig Crew, on Running Completion. P/U and Ran Unique Overshot, 190-Jts of 4.5", 12.6#, 13CR-80 Vam To Tubin 3-X Nipples, Baker S-3 Packer, 5 - GLM - 4.5" x 1.5" 410 SS MMG, GLMs Placed as per Program. All connections torque turned to 4,440 ft-Ibs using Jet Lube Seal Guard pipe dope. All Joints Made Up i Correctly -None UD. 14:00 - 16:00 2.00 RUNCO~P RUNCMP P/U and Space Out Tubing. Final Up Wt = 132,000 Ibs Down Wt = 132,000 lbs. Did not see first set of shear pins, second set of shear pins went at 5,000 Ibs. No-Go on top of Slick Printed: 1/14/2008 8:46:27 AM • • BP EXPLORATION Page 11 of 18 Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To 'I II NPT 1 Hours I Task __~II----Code 12!1012007 ~ 14:00 - 16:00 I 2.00 ~ RUNCOt~Y 16:00 - 16:30 0.50 BUNCO 16:30 - 17:30 1.00 BUNCO 17:30 - 19:00 1.50 BUNCO 19:00 - 21:00 21:00 - 21:30 21:30 - 00:00 12/11/2007 100:00 - 00:30 00:30 - 03:30 03:30 - 05:00 05:00 - 06:30 06:30 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 11:00 11:00 - 12:00 12:00 - 20:00 20:00 - 21:00 21:00 - 22:30 22:30 - 00:00 12/12/2007 00:00 - 01:00 01:00 - 01:30 01:30 - 05:30 05:30 - 07:30 07:30 - 10:30 10:30 - 12:00 2.001 BUNCO Spud Date: 10/14/1980 Start: 11 /21 /2007 End: Rig Release: Rig Number: Phase I Description of Operations RUNCMP Stick w/ -17,000 Ibs down. PiU and repeat twice and No-Go at same Spot. Total Depth reached = 8262'. POH and UD with Jt #191 and #190, M(U 2.07 ft Space Out Pup and M(U Jt 190. Bottom of Unique Over at 8259'. RUNCMP Clear Rig Floor of Tubing Equipment. RUNCMP PJSM R/U SLB Slick Line Equipment. RUNCMP RIH with 4.5" GS Retrieval Tool to Pull RHC Located at 8,172' SLM, Unable to Latch RHC. POOH w/GS Retrieval tool. RUNCMP RIH w /4.5" GR Retrieval Tool to Retrieve RHC. RHC 0.50 BUNCO RUNCMP UD RHC Retrieve! Tool and M/U Dummy Whip Stock. 2.50 BUNCO RUNCMP RIH with 3.70" x 20' Dummy Whipstock to 8278'SLM, POOH. Needed to get to 8300' for Fas Drill. P/U Run CCL. 1.75" OD x 13.9' w/ 2.25" Cent on top. to tie into wellbore equipment to confirm depth. 0.50 BUNCO RUNCMP B/O and UD Dummy Whipstock. M/U Memory CCL. 1.75" OD x 13.9' w/ 2.25" Cent on top. CCL to correlate and give hard proof that drift made it down to Fas Drill Plug. 3.00 BUNCO RUNCMP RIH w/CCL Memory tools to 8,255', First Reading at 8,245' WLM. POOH B/O and UD Logging Tools 1.50 BUNCO RUNCMP Down Loading Memory Logs and Reviewing Same. 1.50 BUNCO RUNCMP M!U 3.25" LIB w13' stem, 3.61" centrilizer, 3' stem, and second 3.61" centrilizer. LIB made it to 8255'. POOH. LIB showed impression of half moon. 2.00 BUNCO RUNCMP Discuss options with ADW Enaineerino and decide to PON with 0.50 BUNCO RUNCMP RID Schlumberger. 1.00 PULL X DPRB DECOMP R/U 4-1/2" tubing handling equipment with compensator. 1.00 PULL X DPRB DECOMP Hold PJSM. Drain Stack and M/U landing joint and R!H to engage hanger. BOLDS. 1.00 PULL X DPRB DECOMP Pull hanger to floor with 132K-Ibs. B/O and UD landing joint and tubing hanger. 8.00 PULL X DPRB DECOMP POH and UD 4-1/2" tubing in Pipe Shed. Examine threads and install thread protectors on each pin end. Upon inspection of the Unique Overshot the lower set of shear pins had two Shear Pins that did not shear, the upper set of shear pins had 3 Shear Pins that did not shear. Packer looked to be in good shape. 1.00 PULL X DPRB DECOMP Clear the Rig Floor of Tubing Handling equipment, Clean Rig Floor. 1.50 CLEAN X DPRB CLEAN Install Wear Ring, Change Bails on Top Drive, Load and Strap Drill Pipe in Pipe Shed. 1.50 CLEAN X DPRB CLEAN M/U Wash Over Assembly, BHA Consists of: Over Shot Guide, 5-Overshot Extensions, Top Sub, Bowen LBS, Bowen Jar, XO, Bowen ACC, XO. BHA Length=335.07'. 1.00 CLEAN X CLEAN Continue to M/U Wash Over Assembly, BHA Consists of: Over Shot Guide, 5-Overshot Extensions, Top Sub, Bowen LBS, Bowen Jar, xo, Bowen ACC, XO. BHA Length=335.07' 0.50 CLEAN X CLEAN Continue to Load and Strap 125 jts of Ht-38 Drill Pipe in Pipe Shed. 4.00 CLEAN X CLEAN RIH with Drill Pipe P/U 1x1 from Pipe Shed. 2.00 CLEAN X CLEAN Load and Strap 126 Joints of HT-38 Drill Pipe in Pipe Shed. 3.00 CLEAN X CLEAN RIH with Drill Pipe P/U 1x1 from Pipe Shed. 1.50 CLEAN X CLEAN P/U stand #83 and S/B in Derrick, RIH with 2-singles, P/U Printed: 1/14/2008 8:46:27 AM BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Start: 11/21/2007 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours ~ Task Code NPT Phase l - - -.._- 12/12/2007 10:30 - 12:00 I 1.50 CLEAN X CLEAN 12:00 - 15:00 ~ 3.00 ~ CLEAN X ~ ~ CLEAN 15:00 - 18:00 3.001 CLEAN X CLEAN 18:00 - 20:30 2.50 CLEAN X CLEAN 20:30 - 22:00 I 1.50 I CLEAN I X I I CLEAN 22:00 - 00:00 { 2.00 {CLEAN { X ~ ~ CLEAN 12/13/2007 00:00 - 01:00 1.00 CLEAN X CLEAN 01:00 - 02:00 1.00 CLEAN X CLEAN 02:00 - 04:30 2.50 CLEAN X CLEAN 04:30 - 08:00 3.50 CLEAN X CLEAN 08:00 - 09:00 1.00 CLEAN X CLEAN Page 12 of 18 Spud Date: 10/14/1980 End: Description of Operations stand #83 and RBIH to get parameters: P/U wt 173K, S/O wt 172K. See top of Slick Stick at 70' in on #R~ (@ R~ F~';,^ swallow to 81' (8,263') and stack out. P/U to 225 and set off jars, S/O to reset jars, P/U to 225K and set off jars. S/O to 185K and start rotating slowly to the right. Torque builds slightly then weight and torque drop at 13-turns. Decide to POH. See 1-2K increase in weight at start of POH. POH and S/B DP in Derrick, L/D DCs. B/O and VD BHA. Nr o Fish in Overshot, but find Arctic Pak residue inside Grapples. Consult with Baker Fishing and ADW Engineering. Baker is verifying the ID of the SBR pulled from the original completion to ensure correct grapples will be utilized. Will RIH with a double grapple BHA and reverse circulate a 40-Bbl Hi-Vis sweep when on bottom. Wait on two new grapples from Baker. The SBR bore was verified by Baker Fishing Shop to be 4.875" and all the seals inside the SBR appeared to be intact. M/U Double Grapple BHA, Unable to M/U BHA on Rig Floor, Sent tools back to Baker to Be Redressed and M/U. Attempt to M/U Tools for Approx 1 hr before sending them back to shop. Continue to M/U Overshot Assembly, P/U 9, 6.125" Drill Collars, from Pipe Shed. RIH with Double Grapple assembly, BHA Consists of :Guide Shoe, Bowl, Double Pin Bushing, Bowl, 5-Extendsions, Top Sub, Bowen LBS, Oil Jar, Rotary Sub, Bowen ACCEL, Pump Out Sub, XO. BHA Total Lenght=339.71' Continue to RIH f/5218' t/8,217' Slip and Cut 88' of drilling line. Obtain Parameters: Up Weight=175,000#, Down Weight=172,000#, 10 rpm w/ 2,000 ft-Ibs torque, P/U 1 jt DP, Spot a 20 bbl Hi-Vis Sweep at Grapples at 7 bpm w/710 psi. Continue to Wash Down noticed a slight bobble on the wei_ ht _ indicator at approx 8,252' top of slick stick, continue down to NO-GO at 8,259', Did not see any increase of pump pressure, Circulated first sweep out of well bore, slight amount of sand on returns. Pull Tested up on Grapples pulled up to 230,000# and held for the jars to hit 3 times, Rotate down and No-go at 8,259'. Jar down to ensure solid hit on the packer, Pumped 2nd 20 bbls Hi-vis at 7 bpm and 710 psi and Chased both sweep out from well bore at 11 bpm w/2,060 psi, Jar up on slick stick 4 times, Max over pull 65,000# over string weight, Jar down 2 times, Jar up at 65,000# over, Slacked off to 180,000# Rotated Pipe 25 turns to the right, Weight dropped 5,000# Picked up on Pipe 1 ft increased up weight to 190,000# Rotated to the right 20 turns to the right, weight indicator fell to 175,000# Pick up on Drill String and lost 60 psi of pump pressure. Increased Pump pressure to previous rate of 7 bpm which has 710 psi, after pulling up on string and bringing up the pumps to 7 bpm pressure was 560 psi. Increased pumps to confirm recovery of slick stick. POOH from 8,259'. B/O and L/D DCs. B/O and L/D BHA, find no fish. Check grapples and see that both were engaged over the Slick Stick, but the ridges were still in good shape. Pdnted: 1/14/2008 8:46:27 AM A-12 BP EXPLORATION Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/13/2007 09:00 - 10:00 10:00 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 18:30 18:30 - 19:30 19:30 - 21:00 21:00 - 00:00 12/14/2007 00:00 - 00:30 00:30 - 09:00 09:00 - 11:30 11:30 - 13:00 13:00 - 16:30 16:30 - 21:00 Operations Summary Report Page 13 of 18 A-12 Spud Date: 10/14/1980 WORKOVER Start: 11/21/2007 End: NORDIC CALISTA Rig Release: NORDIC 1 Rig Number: Hours i Task Code ! NPT ! Phase j Description of Operations 1.00 CLEAN X CLEAN Call ADW engineering and discuss options. Next trip will be to mill up the Slick Stick and Packer, but will go ahead with the weekly BOPE test since need to wait on tools from Baker. 1.50 CLEAN X CLEAN Breakout and UD the grapples and extensions from the BHA. 0.50 CLEAN P CLEAN Clear and clean rig floor and R/U to perform weekly BOPE test. Load 4" and 4-1/2" test joints in Pipe Shed. Pull Wear Ring, install Test Plug, fill stack to prepare for ROPE test. LDS won't seat on Test Plug. Called FMC and they advised that we need to M/U the Test Plug to a stand of DP and RIH, and leave LDS in backed out position. Drain stack. 1.00 CLEAN P CLEAN P/U Stack Washer and RIH to wash out BOP stack due to presence of Arctic Pak and junk found on top of the first test plug. 1.00 CLEAN P CLEAN Turn around three single joints of DP in Pipe Shed and make them up one by one. P/U and M/U test plug to DP and RIH with Landing Joint. 4.50 CLEAN P CLEAN Pressure test BOPE to 250- AOGCC test witness waived by John Chrisp. 1.00 CLEAN P CLEAN Pull Test Plug and 3 jts underneath Test Plug, B/D Blow Down Choke and Kill Lines, Set 8.75" Wear Ring. 1.50 CLEAN P CLEAN M/U Packer Milling Assembly, BHA consists of: Packer Shoe, 1-jt of TSWP, Junk Basket Top Sub, Pin x Pin sub, 2-Junk Baskets, Bit Sub, Bowen Jar, Pump Out Sub, XO, 9-6.25" Drill Collars, XO. BHA Lenght=347.28' 3.00 CLEAN P CLEAN RIH w/ Packer shoe and wash pipe to 8,259' 0.50 CLEAN X DPRB CLEAN Continue to RIH from 5,566' to 8,256'. Drilling parameters: Up Weight=175,000#, Down Weight=170,000#, 60-RPM, 3,000 ft-Ibs of torque, 6-BPM, 560-psi. Continue to wash down and to Packer at 2 ' 8.50 CLEAN X DPRB CLEAN Millin Packer from 8,259' to 8,262' with 60 to 100-RPM, 5-7,000 ft-Ibs torque, 6-BPM, 560-psi. Pumped one Hi-Vis sweep, produced curlicue metal shaving, previously the returns were fine metal cuttings. Spinning in place from 0530-hours to 0730-hours. Tried various changes in technique to make headway. Torqued up to max at -0730-hrs. P/U and hung up, so worked pipe for a few minutes until free. Set back down and resumed milling at 8,262', 80 to 100-RPM, 4 to 7,000 ft-Ibs, 3 to 6-BPM, 560 to 650-psi. Hung up again, worked pipe free and resumed drilling. Made 3-4" then progress quit at 0800-hrs and string began spinning with no change in torque while varying weight on bit and changing the rotating RPM. Decide to POH and S/B DP and DCs in Derrick to changeout the shoe. Checked Ditch Magnets and collected 33-Ibs of cuttings. 2.50 CLEAN X CLEAN POH and S/B DP. 40-stands out at 1000-hrs. 80-stands C~? 1100-hrs. 1.50 CLEAN X CLEAN Empty Boot Baskets and get back 73-Ibs of cuttings. Inspect washover shoe and see that the leading edges of the cutters on the shoe were worn down. Decide to run a re-dressed shoe. 3.50 CLEAN X CLEAN RIH new washover shoe BHA on DP and DCs from Derrick. 70-stands RIH at 1550-hours. 4.50 CLEAN X CLEAN M/U to Top Drive and get parameters: Up Wt 175K, Dn Wt 170K,Rot Wt 175K, 70-RPM, Free Torque 2-3K. Slowly lower down over Slick Stick and taa at 8,263'; start milling at Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Legal Well Name: A-12 Operations Summary Report Page 14 of 18 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: WORKOVER Start: 11/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To I Hours Task 'f Code '~ NPT it Phase Description of Operations I 12/14/2007 16:30 - 21:00 4.50 CLEAN X CLEAN 100-RPM, 6-BPM, 4-5K ft-Ibs Torque, 3K-Ibs WOB. Milled on Packer to 8,266' Packer Fell to 8,273'. Fluid I~ os_ s rate established at 144-BPH. Packer broke free and chased it to 8,287'. Monitor well, fluid loss estimated at 88-BPH. P/U single Drill Pipe, made a connection and continued to chase Packer to 8,300'. Unable to push it any further. Fluid Loss Rate established after pushing packer to bottom at 8-BPH. 21:00 - 21:30 0.50 CLEAN X GLEAN Circulate Bottoms Up at i 4-BPM with 2,300-psi. Losses to the formation 171-Bbls total. 21:30 - 00:00 2.50 CLEAN X CLEAN POOH from 8,300' to 2,723'. 12/15/2007 00:00 - 00:30 0.50 CLEAN X DPRB CLEAN Continue to POOH from 2,723' to BHA. 00:30 - 02:00 1.50 CLEAN X DPRB CLEAN Stand Back Drill Collars, UD junk Baskets, extensions and Mill, 61-Ibs of metal recovered from junk baskets, for a total of 167 Ibs of metal recovered from milling operations. Mill shoe was totally used up. 02:00 - 03:30 1.50 CLEAN X DPRB CLEAN M/U Overshot Grapple Assembly, BHA Consisted of:Overshot Guide, Bowl with 4-7/8" Grapple, Double Pin Sub,Bowl with 4-3/4" Grapple, 5-Extensions, Top Sub, Bowen LBS, Bowen Jar, Pump Out Sub, XO Sub, 9-ea 6.25" Drill Collars, XO. BHA Length=324.27. 03:30 - 07:00 3.50 CLEAN X DPRB CLEAN RIH BHA on DCs and DP from Derrick. 07:00 - 07:30 0.50 CLEAN X CLEAN Get parameters: P/U wt 175K, S/O wt 170K, 5-BPM, 310-psi, Free Torque 2K ft-Ibs. Stop rotating and swallow fish C~ -8,281', see slight pressure increase to 340-psi, continue on in to 8,291' and stack out 10,000-Ibs, but do not see any further increase in tubing pressure. P/U 30' and see 20-30-psi decrease in pump pressure, do not see any increase in weight or any drag. S/O and stack out 20,000-Ibs and see no tubing pressure change. P/U and see no change in pressure. S/O and stack out 30,000-Ibs with no change in tubing pressure. S/D pump and P/U, but see no increase in weight nor any drag. Start pump, slowly rotate while S/O over fish. Set Down 10,000-Ibs and stop rotating. P/U 30', but see no change in weight or tubing pressure. S/O and stack out 30,000-Ibs and P/U 30'. Repeat this last operation; again, no changes in tubing pressure, no evidence of drag. Discuss with Baker Fishing and inform ADW engineer that we are POH and S/B DP to see if we have Slick Stick fish. 07:30 - 08:45 1.25 CLEAN X CLEAN Circulate bottoms up, 14-BPM at 1,950-psi. Do not see gas nor much debris over the Shakers. 08:45 - 12:00 3.25 CLEAN X CLEAN POH and S/B DP and DCs in Derrick. 75-stands out at 1100-hours. Very slight drop in fluid can be seen in the stack when POH is stopped. 12:00 - 14:00 2.00 CLEAN X CLEAN B/O and UD the Slick Stick which was caught with the 4-3/4" grapple. The length of the Slick Stick is 10.57' versus a reported 19.82', which is why we were only seeing about 10' between tag up and stack out each time we washed over the Slick Stick. The OD of the bottom of the Slick Stick was 6.75"; the mouth of it had a smile to match the remains of the OD of the packer stacked out on top of the 7" Llner Top. Call ADW engineer and discuss next step: RIH with 4" Spear, engage packer remains, and POH. 14:00 - 16:45 2.75 CLEAN X CLEAN RIH Packer Plucking BHA: 4" Spear, Bowen Bumper Sub, Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 12/15/2007 114:00 - 16:45 16:45 - 17:30 i 7:30 - 19:30 19:30 - 00:00 12/16/2007 00:00 - 01:00 01:00 - 02:00 02:00 - 03:00 03:00 - 04:00 A-12 Page 15 of 18 A-12 Spud Date: 10/14/1980 WORKOVER Start: 11/21/2007 End: NORDIC CALISTA Rig Release: NORDIC 1 Rig Number: j Hours Task Code NPT Phase Description of Operations 2.751 CLEAN X CLEAN 0.75 ~ CLEAN ~ X 2.00 CLEAN X 4.50 CLEAN X CLEAN CLEAN CLEAN 1.00 CLEAN X i .00 CLEAN X 1.00 CLEAN X 1.00 I CLEAN I X 04:00 - 18:00 I 14.00 I CLEAN I X CLEAN CLEAN CLEAN CLEAN CLEAN 18:00 - 18:30 0.50 CLEAN X CLEAN 18:30 - 19:30 1.00 CLEAN X CLEAN 19:30 - 00:00 4.50 I CLEAN I X I I CLEAN 12/17/2007 ~ 00:00 - 03:00 ~ 3.00 ~ CLEAN ~ X ~ ~ CLEAN Bowen Oil Jars, Pump Out Sub and XOs on DCs and DP from Derrick. 32-stands at 1530-hours. 55-stands C~ 1600-hrs. Stop RIH one joint above Packer remains at 8,300'. Get parameters: Up wt 175K-Ibs, S/O wt 170K-Ibs. Start pump at 2.5-BPM and slowly RIH, see packer at _8,300' and stack out on NoGo. P/U to 225K-Ibs to set off jars. Packer pulls free but pulls with 20 to 30K-Ibs over. Stop at one joint of DP out of hole. Lost 51-Bbls on initial packer release. Drop Pump-Out sub Dart and wait 12-minutes for it to get on seat. Pressure up to 2,000-psi to shear pins and open port. Establish initial loss rate of 3-BPM. Circulate Bottoms Up 10-BPM at 1350-psi .Loss rate 230 bph Static, POOH w/Spear Assembly and Packer f/8,300' Tight pulling First 11 stands, pulling 70,000# over and having to work the packer at every Casing Tool jt, Had to work the jar on several to work past tool jts. Double Displacing Drill Pipe Displacement + 20 bph to fill the hole on trip out. POOH f/2,112' to 324', w/Tubing Spear and Fish. UD 6.25" Collars, LBS and Jar. dulled the Packer Joint, Packer and Spear above the rotary table, Set Slips and Broke Connection under Packer joint that swedged down from 7" to 4.5", the remainder of the tail Pipe was 4.5". The Floor Hands were using Chain Tongs to Back out the the 7" packer joint. As they completed backing out the joint it released trapped pressure from the 4.5"Tubing Tail. A Tar and or Paraffin was discharged onto the rig floor. Gathered the Floor hands in the dog house and cleaned up the paraffin that was on them. There were no injuries to report, I examined them there and instructed them to go to the rig camp and clean themselves up. After Showering one of the floor hands reported that while showering he believed he washed something into his right eye. Both Floorhands that had come over to shower- up were sent to BOC Medic for examination. Held meeting with rig crew about the incident. Reviewed tubing punch procedure and continued to pull and lay down 4.5" tubing using Iron rough neck tubing punch. Pulled and UD remainder of tubing tail pipe. Clear and Clean Rig Floor, Wind Walls, A-legs, Draw-Works. Using charge pump at 50-BPH to keep fluid column in well. Arrange pipe in Pipe-shed, P/U BHA components to Rig Floor. M!U Clean Out assembly, BHA consist of: 6" Bit, 2-Junk Baskets, Bit Sub, 12 - 4 3/4" Drill Collars, 18 jts Drill Pipe, XO, Pin x Pin XO, 9.625" CSG Scraper, Bit Sub, XO. BHA Length=962.71'. RIH from 962' to 9,140', M/U T/D and establish Parameters: Up Weight=180,000-Ibs, Down Weight=175,000-Ibs, 10 BPM, 2,000-psi, Bit depth 9,149', 9.625" CSG Scraper at 8,200'. Establish Circulation and Loss Rate: Wellbore taking fluid 150 BPH at 2 BPM wl150 psi, Static Losses at 140 BPH. Pumped 40 BBL Hi-Vis Sweep Surface to Surface. Pumped Sweep to the Bit at 6 BPM wf810 psi with loss rate of 150 BPH, Staged up pumps to 12 BPM w/2,200 psi and 160 BPH Losses. Printed: 1/14/2008 8:46:27 AM • BP EXPLORATION Operations Summary Report Legal Well Name: A-12 Common Well Name: A-12 Event Name: WORKOVER Start: 11/21/2007 Contractor Name: NORDIC GALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To Hours ii Task Code NPT Phase 12!1712007 00:00 - 03:00 3.00 CLEAN I X I CLEAN 03:00 - 10:30 I 7.50 I CLEAN I X I I CLEAN 10:30 - 12:00 I 1.501 CLEAN I X I I CLEAN 12:00 - 14:00 2.001 RUNCO~DC ~ ~ RUNCMP 14:00 - 00:00 10.00 RUNCOfyDC RUNCMP 12/18/2007 100:00 - 08:30 I 8.501 RUNCOMX I I RUNCMP 08:30 - 10:00 1.501 RUNCOi~iDC 1 RUNCMP 10:00 - 12:30 2.50 BUNCO RUNCMP 12:30 - 13:30 1.00 BUNCO RUNCMP 13:30 - 15:00 I 1.501 RUNCOItIDC I I RUNCMP 15:00 - 18:30 3.501 RUNCOI~1P ~ ~ RUNCMP 18:30 - 20:30 I 2.001 RUNCON1P l I RUNCMP Page 16 of 18 Spud Date: 10/14/1980 End: Description of Operations Small amout of gas noticed at the Flow Line at B/U, no noticeable amount of metal or cutting came back with sweep. Flow Check Wellbore, loss rate at 140- BPH Static, B/D Top Drive, POOH L/D Drill Pipe from 9149', Fillling the hole with double pipe displacement + 30 BPH. POH and L/D DCs and 6" bit. Clear handling tools from Rig Floor and clear and clean in Preparation to RIH with new Vam Top completion. Pull Wear Ring and R/U Doyon Casing's power tongs, compensator, and Torque-turn computer. Verify joint count, jewelry, and running order with Baker Completions expert. Hold PJSM with rig crew, Doyon Casing hand, Baker Completions hand, Tool Pusher, and WSL. At 1430-hours, P/U full joint with 5-1/2" OD WLEG on bottom and RIH. Torque-Turn all connections to 4,640-Ib-ft using Jet Lube Seal Guard pipe dope and Baker Lok all connections below the Baker S-3 packer. The first connection above the packer required thorough cleaning due to drag seen on the Torque-Turn computer. Decide to thoroughly clean all connections because this completion had already been downhole, but none of the pins showed any obvious thread galling or damage when the joints were L/D in the Plpe Shed. One Joint had to have a box replaced, no joints L/D. Filling the Wellbore at 50 BPH. Continue to Run 4.5", 12.6#, 13CR80, Vam Top Completion, using Jet Lube Seal Guard Pipe Compound, and Torque Turning all connections, Avg make up Torque 4,640 ft-Ibs. Filling the hole at 50 BPH. Replaced joints #138 and #143 as well as the collars on #137 and #141. Stop RIH with completion and clean box and pin ends of the last row of 4-1/2" remaining in the Pipe Shed. Continue RIH with new completion. Filling hole at 50-BPH. P/U landing joint and M/U to Hanger. P/U wt 135K-Ibs, S/O wt 132K-lbs. Land hanger and RILDS. 4-joints were replaced with new Vam-Top tubing during the completion using the original string. R/D Doyon Casing Torque Turn equipment. Clear and clean rig floor. Use charge pump to continuosly fill at 50-BPH. Wait on vac truck with Corrosion Inhibited Fluid. Hold PJSM with truck drivers, rig crew, Baker Completions expert and WSL. Reverse circulate 450-Bbls 130-F seawater with corrosion inhibitor, 3-BPM at 10-psi, but do not get returns. Finish pumping at 1815-hrs and break off tubing circulating line, drop ball and rod. M/U circulating line to tubing and wait for ball and rod to get seat. Start pumping down tubing, takes 3-Bbls to fill~ressure o on gibing and hold at 3,700-psi, chart-recorded rock solid for_ 30-minutes. Bleed off tubing to 1,600-psi. Fill annulus with 46-Bbls seawater from Pits, pressure up on annulus to 3,000-psi and won't climb, but pump discharge pressure continues climbing to 4,000-psi. Stop pumping, bleed off annulus and change out pressure sensor on annulus. Start pump and bring pressure up to 3,600-psi and hold it rock solid Printed: 1114!2008 8:46:27 AM • • BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: e{I Name: e: Name: From - To A-12 A-12 WORKO NORDIC NORDIC Hours VER CALIST 1 Task ~- - - A Code I PT _ _ 12/18/2007 18:30 - 20:30 2.00 RUNCO P 20:30 - 21:30 1.00 BOPSU P 2130 - 22:00 0.50 BOPSU P 22:00 - 23:00 1.00 BOPSU P 23:00 - 23:30 0.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 12/19/2007 00:00 - 02:00 2.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 04:00 1.00 WHSUR P 04:00 - 05:00 1.00 WHSUR P 05:00 - 08:00 3.00 WHSUR X 08:00 - 09:00 1.00 WHSUR X 09:00 - 11:30 2.50 WHSUR X 11:30 - 14:30 3.00 WHSUR P 14:30 - 15:30 1.00 WHSUR P 15:30 - 17:30 2.00 WHSUR P 17:30 - 18:30 1.00 WHSUR P 18:30 - 20:30 2.00 WHSUR P 20:30 - 22:00 1.50 WHSUR P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 RIGD P 12/20/2007 00:00 - 02:00 2.00 RIGD 02:00 - 03:30 1.50 RIGD Spud Date: 10/i 4/1980 Start: 11 /21 /2007 End: Rig Release: Rig Number: Phase Description of Operations ~_ - _ _ - RUNCMP for 30 chart-recorded minutes. Bleed off tubing and DCR valve shears at 500-psi on tubing. Annulus and tubing bleed off to 0-psi. Pump both ways through DCR. RUNCMP FMC tech install TWC and attempt to test from above to 3,500-psi. Unable to test. Fluid observed leaking past closed blinds. Bleed off pressure and open blinds. Test TWC from Below to 1,000- si for 10 charted minutes. Good test RUNCMP P/U landing joint and MU to Hanger. Fill landing joint with fluid and screw on test cap. Pressure test TWC from above through andin 'oint to 3 500- si for 10 charted minutes. Good test. RUNCMP UD landing joint. Clear and clean rig floor. Drain stack. N/D BOPE. RUNCMP PJSM on NIU adapter flange and tree. RUNCMP NU adapter flange and tree. RUNCMP Finish N/U Adapter flange. R/U FMC to test adapter flange. RUNCMP Pressure test adapter flange to 5,000-psi for 30 minutes. Good test. RUNCMP N/U Production tree. Fill tree with diesel from rig. R/U to pressure test tree. RUNCMP Test tree to 5 000- si. Unable to achieve stable pressure test. Leaking clean diesel through SPMS seal and out test valve in adapter flange. RUNCMP Drain tree and N/D tree and adapter flange. FMC rep to change out SPMS seal. Bring out new Adapter Flange. Steam flange before installing seals and before placing it on top of Tubing Spool. RUNCMP N/U new Adapter Flange and the existing Tree. Fill Tree with diesel to prepare for Tree test. RUNCMP R/U to test Tree to 5 000- si. Pressure test Tree to 5 000- si and chart for good test. Pressure test Adapter Flange SPSM seal to 5,000-psi for 15-minutes and chart for good test. RUNCMP P/U DSM lubricator and RIH and M/U to Tree. Pull TWC and prepare to reverse circulate diesel freeze protection fluid. ~WS',,.. 's difficult to ull out of rofile. D DSM lubricator and R/U lines in Cellar to pump diesel freeze protection fluid. RUNCMP R/U Lil Red Hot Oilers to pump 175-Bbls of diesel freeze protection fluid. Pressure test fines and find a leaking Demco valve in the line on the rig floor; replace it with new and that one leaks, so replace it with another. R/U and test Lil Red hoses. RUNCMP Reverse Circulate 175-Bbls of 60-F Diesel, 2-BPM at 150-psi. RUNCMP R/U to U-tube diesel from IA to tubing. RUNCMP Slip and cut 1,800' of drilling line. RUNCMP P/U DSM lubricator and M/U to tree. et BPV in han er and test from below to 1 000- si for 10 minutes. Good test. RUNCMP Bleed off pressure and suck out lines to hot oiler. UD DSM lubricator. POST RID cellar and clear rig floor. Secure wellhead and tree. Prepare to pull rig off of the well. RIG RELEASED C~ 24:00. POST Move rig off of A-12. inspect well and make sure the wellhead valves and tree are left to Pad operator's satisfaction. POST Move rig down pad and along well row to allow rig camp to be turned around for move to DS-14. Printed: 1/14/2008 8:46:27 AM • • BP EXPLORATION Page 18 of 18 Operations Summary Report Legal We11 Name: A-12 Common Well Name: A-12 Spud Date: 10/14/1980 Event Name: WORKOVER Start: 11/21/2007 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To I, Hours Task jl Code I NPT I Phase Description of Operations - --- - _ __- L ' _ - __ __ 12/20(2007 03:30 - 04:30 1.00 RIGD POST Load BOP stack onto cradle for transport. 04:30 - 06:00 1.50 RIGD POST Clean rig and perform light maintenance while waiting for auxiliary booster wheels from Doyon 14. Printed: 1/74/2008 8:46:27 AM i r~ TR~= 4' CIW wELLijEAO= P#~ ACTUATOR= OTIS KB. t3EV = 77.43' BF. ELEV = 49.56" KOP = 5800' Max Angle = 27 ~ 8200' Datum MD = 908T DatumTVD= 8800' SS ~ 9-518' CSG, 4{»,1-lydri 563,E-80 ~ Completion A-12 2145' 1 13-318" CSG, 72#, L-80, D=12.347" H 267T Mininum ID = 3.725" ~ 8342' XN NIPPLE SAFETY MOTES: W ARNIN6: RADIO TRANS1117TER iN iNEATNER 1/ OMITORING SNACK Y UST BE TURNED OFF BEFORE ANY WEIi. WORNINYOLYINO EXPLOSIVES CAN BE61N. CONTACT PAD OPERATOR. 2089' ~ 4-112"X-NPD=3.813' 2593' 9-518" DV PIQ2~ GAS LF'f MANDRBS ST MD 1VD DEV TYPE VLV 5 3151 4 4725 3 6009 2 7083 1 7ss1 8113' H 4-112' X t>~D=3.813" 8144' ]-19-518" x 4-112" BKR S-3 H(R, fl = 4.75" 8179' 4-1/2° OTlS X NP, D= 3.813" TOP OF 7° LtVt 8310' 4-112" TBG, 12.6#, 13Cr80, VamTop, .0152 8398' ~pf, ID = 3.958" 9-~8" CSG, 4791!, L-80, D = $.681 • $$(j4' PB~ORATtON SII~RY REF LOG: SWS IiHCS ON 10130!80 ANGLEATTOPPERF: 21 ~ 889T Nole: Refer in Production ~ for fi~torical perf Rata SQE SPF tNTHti/AL OpNSgz DATE 3-318" 4 8897 -8924 S 08!18/9.1 3-318' 4 9012 -9020 C 09H4190 3-318" 4 9027 - 9107 C 09/14l'9t1 3-118" 4 91 ~ - 9132 S 08/30/90 3-118' 4 9137 - 9144 S 08/300 3-118" 4 9149 - 9182 S 0$130/90 _PBTG 975T 7" LHR. 298, L-80, .0371 t~#, D = 6.184" 9$00' 4-112" TBG TAIL, ID = 3.958" w ! 5.5" QD (Fluted) WLEG 9067' MARK92 JOi+il• i F1SH- {2j 3-112° SP'IR+Eft$IADES E1L (m17102j DATE REV BY t:0#IMBJTS DATE REV BY CX3MI~1T'S PR9lOHOE 8AY lJl~T 01!04180 01L CaAPLETt~I Nil:LL: A-12 06/01Nl0 taIMO PHiMT No: ~180i 170 10/17102 QAV/KK FISH API No: 50-029-20515-00 , 9/24105 EZLITLH WANER SPTY NOTE DEL SEC 35, Ti 1N, 813E 061196 RCTIPJC SET XXP as l SAND EXT. 3131!07 KSB/PJC RESSEf XX i"I'P ~ 8342' 8P Explorapon (Aiaskaj • ~, ~ ~ ~ ~~' ~~ ~ °~~, ° ~Y~ SARAH PALIN, GOVERNOR ALASFiA OIL ~D Gr~-S C01~5ERQA~`I011T COMl-IISSIOIQ David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~,,f~N~L~ NO~~ ~ ~ 2007 Anchorage, AK 99519-6612 ~ ,, ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBLJ_,l~-12 _~,, , Sundry Number: 307-324 Dear Mr. Reem: ~ ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this'~3day of October, 2007 Encl. Sincerely, /~~ STA E OF ALASKA ~rV~Q ~t'' ALASKA OIL AND GAS CONSERVATION COM~ION ~-rJ~~.Z QC APPLICATION FOR SUNDRY APPROVAL r 2 2 2~D7 Alaska Oil & Gas r,,.._ „ 20 AAC 25.280 1. Type Of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension RfIC~lOrB~@ ^ After Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 180-117 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20515-00-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU A-12 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Poot(s): - ADL 028286 ~ 77.4' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9801 9553 - 9757 9511 None 9757 (Approx.) a in L n h ize M TVD Burst Coll se . Structural on u for 113' 0" x 3 " 113' 113' Surface 2677' 13-318" 2677' 2677' 5380 2670 Intermediate 8804' 9-5l8" 8804' 8614' 6870 4760 Pro u i n Liner 1489' 7" 8311' - 9800' 8166' - 9552' 8160 7020 Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9012' - 9107' 8807' - 8896' 4-1/2", 12.6# L-80 8373' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 8248' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 20, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Name.' avid Reem Title Engineering Team Leader Prepared By NamelNumber: Signature ~ Phone 564-5743 Date w~{;~~b`7 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 3~OO~7S~ ~~` ~S'~ `` G ~ ~ ~ ~ I -' . ~ r ~ Subsequent Form Required: („~~ !~ APPROVED BY /~~ ~j ~~ 7 A roved B MMISSIONER THE COMMISSION Date ,~, 410tT Form 10-403 Revised 06/2006 V `~~ ~"" Submit In Duplicate ~ t-~ t n t r ~ w r , . ~~._ Q (' ~ `~ ~ 2DQ7 • by cr, A-12 Rig Workover Scope of Work: Pull 4 1/2" L-80 completion, cut and pull 9-5/8" casing above the surface casing shoe, run premium threaded 9-5/8" tieback and cement 9-5/8" x 13-3/8" annulus to surface, changeout 9 5/8" packoffs, run 4-%2" Chrome completion. MASP: 2375 psi Well Type: Producer Estimated Start Date: November 20, 2007 Pre-rig prep work: O 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured at this time with 2 7/8" XX TTP in the 4 %2" X-Nip w / 2 7/8" reduced ni ple at 8342'. PPPOT-T & IC. S 2 Pull patch at 7203'. Pull XX plug & nipple reducer at 9225'. Drift thru 4-1/2" tubing to 8300 and for 4 1/2" fas-drill & power jet cutter. Pull DGLV from Chem Inj Mandrel, purge line w/ diesel, reset DGLV and PT line to 2000 si. E 3 .Set 4-%" HES Fasdrill composite bridge-plug at -8300' md. CMIT TxIA to 3500 psi to confirm mechanical barrier and casing integrity. Power Jet cut tubing @ 8220', leaving a 7' stub in the 2nd 10ft u below the chemical in~ection mandrel. Ref: 06/01/1990 tubin summa F 4 MIT-OA to 2400 psi. Circulate well with seawater thru the cut. Bleed WHP's to 0 si. O 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4 1/2" tubing string. 3. Run a cement evaluation log to determine top of cement in 9-5/8" x 13-3/8" annulus. 4. Cut and pull 9-5/8" casing above TOC. 5. Tie back 9-5/8" casing with ES cementer. 6. Cement 9-5/8" x 13-3/8" annulus to surface. 7. Run new 4-1/2" Chrome tubing completion with packer at 8420'. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = 4" CIW LHEAD= FMC ACTUATOR= OTIS KB. ELEV = 77.43' BF. ELEV = 49.56' KOP = 5800' Max Angle = 27 (a3 8200' Datum MD = 9087' Datum TV D= 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.313" ~ 8342' 2-7/8" REDUCED NIPPLE TOP OF 7" LNR ~-{ 8310' ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9-5i8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS BRCS ON 10/30/80 ANGLEATTOPPERF:21 (i~ 8897' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8897 - 8924 S 08/18/91 3-3/8" 4 9012 - 9020 C 09/14/90 3-3/8" 4 9027 - 9107 C 09/14/90 3-1/8" 4 9108 - 9132 S 08/30/90 3-118" 4 9137 - 9144 S 08/30/90 3-1/8" 4 9149 - 9182 S 08/30/90 I PBTD I ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ A-1 ~ SAFEITNOTE3: WARWNG: RADIO TRANSMITTER IN WEATHER MONITORING SHACIf MUST BE TURNID OFF BEFOREANY WELL WORKINVOLYING EXPLOSNES CAN BEGIN. CONTACT PAD OPERATOR ® 1988' --~4-112" CAMCO SSSV NP, D = 3.81 ~~ .... 2593` 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3088 3004 1 OTIS RA 3 5754 5670 6 OTIS RA 2 7438 7268 18 OTIS RA 1 8136 7926 24 OTIS RA 71 203' {-- { HLS TBG PATCH 7203'-7217', ID = 2.35" I (ELEMENTS (d~ 7205'-7215' 8204' CHEMICAL INJ. MANDREL 8235' 4-1 /2" PARKER X NIP, ~ = 3.813" 8244' TBG SEAL ASSY 8248' 9-518" x 4-112" BKR S-3 PKR, 1D = 4.75" 8311' 4-112" OTIS X NIP, ID = 3.813" 8342' 4-1 /2" XN NIP w / 2-7/8" RED NIP, ID = 2.313" $342' 2-7/8" XX TTP (03/31/07) NO SAND EXT 8373' 4-1/2" TBG TAIL, ID = 3.958" 8368' - -~MD•TT LOGGED 02/17/95 MA RKER JOINT FISH - (2) 3-1/2" 1 DATE REV BY COMMENTS DATE REV BY COMMEMS 01/04/80 ORIGINAL COMPLETION 06/01/90 RWO 10/17/02 DAV/KK FISH 9/24105 EZL/TLH WANER SFTY NOTE DEL 06/19/06 RCT/PJC SEf XXP w /SAND EXT. 3/31/07 KSB/PJC RESET XX TTP @ 8342' PRUDHOE BAY UNIT W®.L: A-12 PERMIT No: 1801170 API No: 50-029-20515-00 SEC 35, T11 N, R13E BP Exploration (Alaska) TREE = 4" CMJ WELLHEAD= FMC ACTUATOR= OTIS KB. ELEV = 77.43' BF. ELEV = 49.56' KOP = 5800' Max Angle = 27 (a3 8200' Datum MD = 9087' Datum ND= 8800'SS Proposed RWO A-1 9-5l8" CSG, 40#, Hydrd 563,E-80 -~_~ 13-3l8" CSG, 72#, L-80, m ~ 12.347" H 2677' Minimum ID = 3.725" @ 8342' XN NIPPLE 2593' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV 5 3150 4 4750 3 6006 2 7087 1 8017 l~ 4-1/2" X-NIP X3.813" 9 5/8" X 4-1/2" BAKER S-3 PKR 4-1/2" X-NIP ID=3.813„ TOP OF 7" LNR $310' $244' TBG SEAL ASSY 8248' 9-5/8" x 4-1/2" BKR S-3 PKR, ~ = 4.75" $311' 4-1/2" OTIS X NIP, ID = 3.813" 8342' 4-1/2" XN NIP w / 2-7/8" RED NP, ID = 2.313" 4-112" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" $373' 9-5l8" CSG, 47#, L-80, ID = 8.681" $$04' PERFORATION SUMMARY REF LOG: SWS BRCS ON 10/30/80 A NGLE AT TOP PERF: 21 ~ 8897' Note: Refer to Productbn DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8897 - 8924 S 08!18/91 3-3l8" 4 9012 - 9020 C 09/14/90 3-3/8" 4 9027 - 9107 C 09/14/90 3-1/8" 4 9108 - 9132 S 08/30/90 3-1/8" 4 9137 - 9144 S 08/30/90 3-1/8" 4 9149 - 9182 S 08/30/90 PBTD s~sr 7" LNR, 29#, L-80, .0371 bpf, m = 6.184" 9800' Com ple~n 2 SAFETY NOTES: W ARNING: RAD10 TRANSM ITTER IN W FATHER M ONITORINp SNACK M UST BE TURNED OFF BEFOREANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR. 4-112" X-NIP ID=3.813" $373' 4-1/2" TBG TAIL, ID= 3.958"1 $~$' ELMD-TT LOGGED 02/17/95 9Q$7' MARKER JOWT FISH - (2) 3-112" SPMVNER BLADES E/L (10/17/02) DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/80 ORICdNAL COMPLETION 06/01/90 RWO 10/17/02 DAV/KK FISH 9/24/05 QL/TLH WANERSFTY NOTE DEL 06/19/08 RCT/PJC SET XXP w !SAND EXT. 3/31/07 KSB/PJC RESET XX TTP (~ 8342' PRl~HOE BAY UNIT WELL: A-12 PERMfT No: 1801170 API No: 50-029-20515-00 SEC 35, T11 N, R13E l3P 6cploratlon (Alaska- \ r- p. - I .,---r STATE OF ALASKA ~ I)~ 5/711-- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 /"*". 1. Type of Request: 181 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 0 Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Perforate 181 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: 1m Development D Exploratory D Stratigraphic Test D Service 0 Waiver 0 Time Extension 0 Annular Disposal 5. Permit To Drill Number 180-117 /' 6. API Number: / 50-029-20515-00-00 0 Other 99519-6612 77.4' 9. Well Name and Number: PBU A-12 '" 1f " Total Depth MD (ft): 9801 ::ßøsìiiQ Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): ADL 028286 Prudhoe Bay Field / Prudhoe Bay Pool " " ,', ' ,1~$Et+];W$tLE¡ø.~t1'!Ð~~$\ài}MJ:iflf':::~:(c¡:', " "" ' '::. Total Drs~3TVD (ft): 1 Effective ~~~;hMD(ft):IEffective ~~~~TVD (ft): " PIU9S~0~~SUred): ~c::~;:[. -:":1~1~~ ::?i::@~f' '._~~~:'r.1t ìli:':'11;(~ø"'~~Q'i:'i:~',"f~~'E!àW:it.;,\:~~: ' Junk (measured): 9757 ~,Aeprox.} , ,: ~õllà¡)~:.,.' 8. Property Designation: 113' 20" x 30" 113' 2677' 13-3/8" 2677' 8804' 9-5/8" 8804' 1489' 7" 8311' - 9800' 113' 2677' 8614' 5380 6870 2670 4760 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 9012' - 9107' 8807' - 8896' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'S-3' packer; 4-1/2" Cameo SSSV Nipple 816R~Cf::'IVð) MAY) 1 ?nIl Tubing ~Q 'rtlb~4v,D (ft): L-80 'Gas Cons, {'.m3~., Packers and SSSV MD (~-.. """.JQQr, . 19~" 13. Well Class after proposed work: / D Exploratory 1m Development D Service 8166' - 9552' Tubing Size: 4-1/2", 12.6# 12. Attachments: 1m Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and eorrect to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer , ~Q~~~t#/~¡~~~!y,:~::~~;[J.'r ~~~;::::;;:. , I Sundry Number: ~ C/ /rl./ V Conditions of approval: Notify Commission so that a representative may witness . May 14, 2004 / Date: 15. Well Status after proposed work: Don DGas DWAG DGINJ D Plugged DWINJ / 1m Abandoned D WDSPL D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: Approve-d ¡:o y",^- '0 - +0 ( Yebuiv~J tý sitklrtt-u~ tJ,<..ll( A-I,-A. ORIGINAl RBDMS BFL ~œ ~éi~. MAY 1 1 ?OO~ COMMISSIONER BY ORDER OF THE COMMISSION !. ~ .~ bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: May 6, 2004 Re: Well A-12 prep for a CTD sidetrack Well A-12 is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, A-12A, will exit .Q8t'ef1he existing 7" liner from a thru tubing whipstock and target Zone 4 reserves. / The existing perfs will be isolated with cement pumped past the whipstock. Prior to setting the whipstock a tubing patch must be removed, the tubing patch will be replaced after the sidetrack. ,/' The following describes work planned for the P&A and sidetrack and is submitted as an attachment to Form 10- 403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) No flow test on lA, MIT-IA / 2) MIT-OA wI fluid levels 3) Pull 14' long RCP tubing patch (leak in tubing at 7210', set in 1995,2.35" id) /' 4) Retrieve reducing nipple at 8342' (2.313" id) 5) Run LDL to confirm no additional leaks in tubing (confirmed leak at 7210') /' 6) Drift / Run PDS Caliper to assess liner near KOP at 8896' 7) Set mechanical whipstock at approx 8896' (22d~ inc) 8) Pump cement past whipstock for P&A . 'lo/. . ~- 40 bblç WGA- CTD Sidetrack Summary 1) MIRV CTD rig. 2) Mill 3.8" window at approx. 8896' md. 3) Drill to 10925' planned TD with MWD/gamma raylResistivity. 4) Run 3-3/16" x 2-7/8" liner completion. Top ofliner will be at approx 8325' md (8101 'TVDss) in 4 W' tubing tail. 5) Cement liner, Run MCNL, Perforate. 6) RDMO. <II. Tlt~ 10 ~ 4-°3 ¥ P Y'\)" (:A., ( . The pre CTD work is scheduled to begin May 14,2004. Thomas McCarty CTD Drilling Engineer 564-4378,748-2598 CC: Well File Terrie Hubble ! TREE = W8..LHEAD= ACftJð. TOR= KB. ELEV = BE ELEV = KOP= Max Ange = DatumMD= DatumTVO= r'\ 4"CIW FMC OTIS 77:43' 49,56' 580Ô' 27 @ 8200' 9087' 8800' SS 113-318" CSG, 72#, L-80, ID = 12.347" 1-1 2677' Minimum ID = 2.313" @ 8342' 27/8" REDUCED NIPPLE 1 TOP OF 7" LNR H 14-112" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H DATE 01/04/80 06101/90 01/30/01 02127/01 05118/01 10/04/02 19-518" CSG, 47#, L-80, 0 = 8.681" H ÆRFORA 1l0N SLMMARY RB= LOG: SWS BI-CS ON 10ßO/80 ANGLEATTOPPffiF:21 @ 8897' Note: Refer to Production œ for historical perf data SIZE SPF INTERV AL OpnlSqz DATE 3-3/8" 4 8897-8924 S 08/18/91 3-3/8" 4 9012-9020 0 09114/90 3-3/8" 4 9027-9107 0 09/14/90 3-1/8" 4 9108-9132 S 08/30/90 3-1/8" 4 9137-9144 S 08/30/90 3-1/8" 4 9149-9182 S 08/30/90 ~ 17" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" H 8310' 8373' 8804' 9757 9800' A-12 / ~ . - L - .f.-b i ì ~ - I :8: r--I - r--1 --..4 'r .-- RBI BY DA TE REV BY 10/17/02 DAV/KK FISH COMtÆNìS co f\IM 8',¡r S ORIGINAL COMPLE1l0N RWO SIS-fIIH CONVERTED TO CANVAS SIS-rvD FINAL Rf\VKAK CORREC1l0NS BIINKAK WAIVffi SAFETY NOTE I z-i r . 1988' 2593' 'ST MO 4 3088 3 5754 2 7438 1 8136 7203' 8204' 8235' 8244' 8248' 8311' 8342' 8373' 8368' 9067' ,;-..., SAr~ NOTES: W ARNNG: RADIO TRA NSMITTffi IN WEA Tf-ER MONITORNG SHACK MUST BE TURNBJ OFF BEFORE ANY W8..L WORK INVOLV ING EXPLOSIV ES CAN BEGIN. CONTACT PADOPERATOR.***TX lAX OA COM M. OPERATING PRESSURE OF THE 13- 3/8" ANNULUS MUST NOT EXCEED 2000 PSI (10/04102 WAIVER)*** H4-112" CAI'vCOSSSV NIP, ID= 3.813" I H9-518" rN R<R I GAS LIFT MANDRELS TVD OEV TYPE VLV LATa-! 3004 1 OTIS RA 5670 6 OTIS RA 7268 18 OTIS RA 7926 24 OTIS RA PORT OATE HHLSTBG PATCH 7203'-7217',10= 2.35" I IELB'v1ENTS @ 7205'- 7215' HCHB'v1ICAL INJ. MANCREL I H4-112" PA RKER X NIP, ID = 3.813" I HTBG SEALASSY I H9-518" x 4-1/2" BKR 3-3 R<R, ID = 4.75" I H4-112" OTIS X NIP, ID = 3.813" I H4-112" XN NlPW/2-718" I I REruONG NIP, ID = 2.313" H4-112"lBGTAIL, 0=3.958" I HEUvV.TT LOGGED 02117/95 I HMARKffi JOINT I RSH- (2) 3-1/2" SANNER BLADES 5'L (10/17/02) I ffiUCHOE BA Y UNIT W8..L: A-12 PERMIT No: 1801170 API No: 50-029-20515-00 SEC 35, T11N, R13E BP Exploration (Alaska) TREE = 4" CNV .. WaltfiAD= FMC ------ --'---"'-'--- AClUA TOR= OTIS ------ '----- KB. aEV = 77.43' --,--,_.._---,-- BF. aEV = 49.56' -----..--- KOP = 5800' -,----- ,-- ~x Angle = 27 @ 8200' Datum MO = 9087' --- DatumTVD= 8800' SS ~ A-12 A Proposed CTD Sidetrack SAFETY NOTES: WARNING: RADIO TRANSMITTER IN ~ THER MONITORING SHACK MUST BE TURNED OFF a=OREANY Wal WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PADOPæATOR***TX lAX OA COMM, OPERATING PRESSURE OF THE 13- 318" ANNULUS MUST NOT EXCEED 2000 PSI (10/04/02 WAlVER)*** / ~ ~STMO 4 3088 3 5754 2 7438 1 8136 . /13-3/8" CSG, 72#, L-80, Ð = 12.347" H 2677 ~ Minimum ID = 2.313" @ 8342' 27/8" REDUCED NIPPLE (retrieved) TOPOF 7" LNR /-I /TOPOF 3-3/16" LN~-I /3.5" XN Nip 2.75" q-l 14-112" TBG, 12.6#, L-80, 0.0152 bpf, Ð = 3.958" H ToPofCement H I 9.5/8" CSG, 47#, L-80, D = 8.681" /-I ÆRFORA TION SUMMARY REF LOG: SWS BHes ON 10/30/80 ANGLE AT TOP ÆRF: 21 @ 8897' Note: Refer to Production DB for historical perf data SIZE SPF MERV Al Opn/Sqz DATE 3-3/8" 4 8897-8924 isolated proposed 3-3/8" 4 9012-9020 isolated proposed 3-3/8" 4 9027-9107 isolated proposed 3-1/8" 4 9108-9132 isolated proposed 3-1/8" 4 9137-9144 isolated proposed 3-1/8" 4 9149-9182 isolated proposed I PBmH 17" LNR. 29#, L-80, 0.0371 bpf, D = 6.184" H DATE REV BY COMMENTS 01/04/80 ORIGINAL COMPlETION 06101190 FmO 01/30/01 SIS-M-I CONVERTED TO CANVAS 02127/01 SIS-t.'D FINAL 05118/01 RWKAK CORRECTK:>NS 10/04/02 BM'KAK WAIVER SAFETY NOTE L .£.....J. í 8: 8310' r-"I ì ~ - .. 8325' / 8335' I 8373' t----J 8600' I 8804' ~ 9757' 9800' 1 'd .. 1988' /-I4-1/2"CAMCOSSSVNP,D=3.813" / 2593' /-19-5/8" DV PKR 1 GAS LA" MANDRB.S TVO DEV TYPE VLV LATCH PORT DATE 3004 1 OTIS RA 5670 6 OTIS RA 7268 18 OTIS RA 7926 24 OTIS RA 7203' - HlS TBG PATCH 7203'.7217', D = 2.35" I pull & rerun I I I I I 8204' /-I CHEMICAL NJ. MANDRB. I 8235' H4.1/2" PARKER X NIP, D= 3.813" I 8244' /-ITBG SEAL ASSY 1 8248' /-19-5/8" x 4-1/2" BKR S.3 PKR. D = 4.75" / 8311' /-I4-1/2"OTlSXNIP,O=3.813" 1 8342' 114-1/2"XNNlPretrieve I REDUCING NIP, 10 = 2.313" 8373' H4-1/2" TBG TAL, D = 3.958"1 8368' /-I aM(). TT LOGGED 02117195 / 8896' /-1 Mechanical Whipstock I} 10925' 1 1/ 1 3-3/16" X 2-7/8" cmt'ed and perfed/-l DATE REV BY 10/17102 DAVIKK FISH COMMENTS FISH - (2) 3-1/2" SPINNER BLADES ElL (10/17/02) I PRUDHOE BAY UNIT WaL: A-12 PERMIT No: 1801170 API No: 50.029-20515-00 see 35, T11N, R13E BP Exploration (Alaska) ,' ~- STATE OF ALASKA AL ....,A OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Sewice 4. Location of well at surface 1116' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 7'SNL, 1387' WEL, SEC. 26, T11N, R13E, UPM At total depth 101'NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 9801 feet BKB 9553 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE= 77.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number/approval number 80-117 / 95-032 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9294 feet BKB 9070 feet Junk (measured) fill at 9294' (11/92) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 113 20x30 8 c.y. 140 2650 13 3/8 3720 c.f. 2677 8 777 9 5/8 1340 c.f. 8804 measured True vertical depth BKB 140 2677 8612 .. 1489 7 396 c.f. 8897'-8924' (Sag R) 9012'-9020', 9027'-9107' (Ivishak) true vertical subsea 8622'-8647' (Sag R.) 8729'-8737',8743'-8819' Tubing (size, grade, and measured depth) 8311-9800 8166-9552 Sqzd: 9107'-32', 9137'-44',9149'-82' Sqz'd:8819'-8842, 8847'-8853', 8858'-8889' 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 1988' AUG 1 4 1995 ~ 9ii .& Gas Cons. C0maissl0n Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 17. I here~y c_~ that the f/~egoing is true and correct to the best of my knowledge. Signed ~v/~ ~.,,/~.~.~ Title SupervisorWaterflood/MiscibleFIood Form 10-404 Rev 06/~-5/8-8/' SUBMIT IN ~UPEICATE WELL A-12(31-35-11-13) Kinley/Tubing Wash & Patch Operation Approval #95-032 3/19/95 Ran Kinley Caliper 5/9/95 5118195 A tubing wash was performed using the following fluids: JOB SUMMARY Treated Flowline with 4 Bbls HCL/xylene Fluid packed IA with sea water Fluid packed and washed tubing with sea water with surfactant. Treated flow line with 6 Bbls HCL/Xylene Pumped 28 Bbls 15% HCL / 10% Xylene down tubing with 94 Bbls sea water to displace it down the tubing Treated flow line with 10 Bbls HCL/Xylene Step No 5 in program request that a injection rate be established between the tubing and IA but this will not result in a usable rate since the tubing does not have a plug and is open to the perforations as well as being on vaccum. This would allow a large volume of fluids to be pumped downhole but not through the leak. The IA cannot be used to establish a rate either since the S/O GL valve will allow fluids to pass though. Instead, we pumped the acid until, it was above the hole at 7210' MD and then started pumping fluids into the IA at one Bbl/ rain until we finished pumping acid and the acid was below the leak. FLUID SUMMARY 48 Bbls of 15 % HCL/10% Xylene 119 Bbls of Sea water with 0.2%FE-41 surfactant. 558 Bbls of sea water 14 Bbls of methanol Perfomed a tubing patch well passed tubing integrity test after patch set. Gas Cons. Commission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 23 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: .B E_LL ~ (~/~ 17 (43-25-11-13) ¢/~% N-13 (42-07-11-13) DESCRIPTION -1 PDK/GR FINAL BL+RF - 1 PLS FINAL BL+RF 1 CCL FINAL BL+RF 1 PDK/GR FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 992.11 Run # 1 2189.'03 . Run # 1 5757.03 Run # I 6245.04 Run # 1 6431.02 Please sign and return to: Attn.~Rodney D. Pau~n ~ Atlas ~reline Services '~ Received by:/ /~~ ~~ -Date: '~'~ ' · LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL A-18A DESCRIPTION PLS FINAL BL + RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL' BL+RF ECC No. Run # 1 3704.01 Run ~ 1 5757.02 Run # 1 5820.05 Run # 1 5820.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ Or FAX t J~ (907) 563-7803 Received b Date: RECEIVED FEB Anchorage STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMIS~~ APPLICA..ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Alter casing __ Change approved program 2. Name of Operator BP Exploration (Alaska) Inc. Suspend__ Operation Shutdown __ Repair well __ Plugging __ Pull tubing__ Variance X 5. Type of Well: Development X Exploratory __ Stratigraphic Sewice __ 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1116' SNL, 920° WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193'SNL, 1363'WEL, SEC. 35, T11N, R13E, UPM RECEIVED At effective depth 7'SNL, 1387'WEL, SEC. 26, T11N, R13E, UPM FEB 2 2 ]995 At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, uP~laska Oa & Gas Cons. ~.~,~lmi~.eia_n- 12. Present well condition summary /tnch0ra~e Total depth: measured 9801 feet Plugs (measured) true vertical BKB 9553 feet Re-enter suspended well Time extension __ Stimulate' Perforate __ Other __ 6. Datum elevation (DF or KB) KBE= 77.43 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number 80-117 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool feet Effective depth: measured 9294 feet true vertical BKB 9070 feet Junk (measured) fill at 9294' (11/92) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size .. 113 20x30 2650 13 3/8 8777 9 5/8 Cemented 8 c.y. 3720 c.f. 1340 c.f. Measured depth True vertical de~h BKB 140 140 2677 2677 8804 8612 .. 1489 7 measured 8897-8924' (Sag R) 9012'-9020', 9027'-9107' (Ivishak) true vertical subsea 8622'-8647' (Sag R.) 8729'-8737',8743'-8819' 396 c.f. 8311-9800 8166-9552 Sqzd: 9107-32', 9137'-44',9149'-82' Sqz'd:881958842,884758853~885858889' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tai~ipe to 8373' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 1988' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch __ 14. Estimated date for commencing operation I 15. Status of well classification as: 16. If proposal was verbally approved I Oil X Gas Suspended Name of approver Date approved Service 17. I hereby ce~j that the f/~going is true and correct to the best of my knowledge. Sic~ned ~/"~/~x' ~-'~~ ~/'~ TitleSupervisorWaterflood/MiscibleFIood ' ~' FOR COMMISSION USE ONLY Conditions of approval: Not, Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ SubA~f'tt~r~(D~i~uired 10- /,fo ~ 0rigir~l~m[! By Approved by order of the Commission David W. Jnhrmtnn_ Approved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Welt A-12 .AnnUlus communication 'l'ubin!~ tubing-to-annulus communication during a r 17, 1995. The source o~ determined to have --..~.-~,~d FebrUa Y . _ ,,4n, ~,~D (7,058' Welt A-12 was . rye co"~"~'", ted at/,~' "' both · ' ' e surveillance su Y in the tubing Ioca.. in normally ~rom e w~ret~n ent hole well ts h~t g PD at rout~n . . . naPpar ~2. The · 750BO , comm~mc~t'on ? a I 228' ab?e GLM's currently Pr°~u~mte witnessed N0 a fox, mate Y Welt A-12 ~ asseu ~ ~'- ace over patch over the leak. ' work is completed and the hole can be until such time as the surveillance well patched, proposed schedule is as follows; rom the State. ad[scent to the hole. ' e variance f . ndition o~ tubing Rece~v ..... ~o determine co 1. Run Kiniey ca~p~, · . RECEIVED FEB 2 2 3995 Alask~ OJl & Gas Cons. Commission Anchora/:~ ALASKA OIL AND GAS CONSERVATION COMMISSION ...WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 20,. 1994 Steve Farris/Jerry Bixby Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PBU A Pad Wells Nos.i~'A-1.2, -13, -26, -30, -34A, & -37 Dear Mr. Farris/Bixby: On July 18, 1994, our Inspector Lou Grimaldi witnessed no-flow tests on BPX's PBU A Pad wells 12(PTD 80-117), 13(PTD 81-159), 26(PTD 82-117), 30(PTD 85-119), 34A(PTD 85-105), and 37(PTD 93-007). The wells had been shut in on the previous day. All wells were bled down to atmospheric tanks on-site. Five of the wells were essentially dead; the sixth well (A-30) made a small amount of gas; a gas meter showed that the flow rate was approximately 360 SCF per hour versus 900 SCF per hour acceptable. Since these rates are well below the limits for "no-flows", the Inspector concluded that subject wells were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from BPX's PBU wells A-12(PTD 80-117), A-13(PTD'81-159), A-26(PTD 82-117), A-30 (PTD 85-119), A-34A(PTD 85-105), and A-37(PTD 93-007) on the condition that the low-pressure sensors and surface safety valves must be maintained in good Condition and, if for any reason, the wells again.become capable of unassisted flow of hydrocarbons, the subsurface safety.valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. W PI Supervisor c: Lou Grimaldi bew/n 1 pba 5 MEMORANDD,Vl · TO: . David Joh~ Chairmad ~ THRU: Blair Wondzell, P. I. Supervisor /w .__ __...._._. _ Lou Grimaldi,,~'~'~ ~.,~.~, FROM: Petroleum Inspector State Alaska Alaska Oil and Gas Conservation Commission DATE: July 18, 1994 FILE NO: SUBJECT: 9A9JGRBD.DOC No Flow verification BPX wells A-12,13,26~4,&37 Prudhoe Bay Field Sunday, July 17,1994; I verified the NO-FLOW status of 4 BPX wells, A-12,26,34 &37, in the Prudhoe Bay field. The subject wells had been flowed down to separator pressure the night before and then bled to zero in a bleed trailer. All four wells were dead either no gas flow or just a whisper when opened to atmosphere. I recommend the approval of the NO-FLOW status for these wells. Monday, July 18, 1994; ! retUrned to A pad today and verified NO FLOW status on well # A-13.. This well like the others produced no fluid or had significant gas flow. There was a additional well tested, this being A-30. Although no fluid was produced a small amount of gas was steadily coming from the tubing. A residential type gas meter was installed on a hose routed from the tree cap to. The pressure was stabilized at approximately .5 psi with the meter registering on the two foot scale thirty subdivisions (or three revolutions) in thirty seconds. As there were no instructions with this meter and we were not sure of its operation I did not approve the test at this time, if the instructions prove out that two standard cubic feet is measured per revolution instead of a subdivision this well would pass the NO FLOW test. SUMMARy: I witnessed NO-FLOW tests on six BPX A pad wells. t"/' 9 .3 .- BP EXPLORATION RECEIVED BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/16/92 T# 84059 BP LOGS Endlosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-12 ~,-I[~ pRoDuCTiON LOG 11/07/92 8750.00- 9250.00 ATLAS 5 " A-18~-/o8 CCL (c"J~e~,r.~ ¢~,~1/10/92 ~1~ 8100.00- 9270.00 ATLAS 5 " B-21~-I~ PFC/~(~) 11/_Q9/92 ~1~ 9400.00- 9824.00 ATLAS 5 " M-15~I-~CC5 (~-,~/~,~/~8/92 ~1~ 8500.00- 9330.00 ATLAS 5 " R-29~-~; PFC/~ (~) 11/10/92 ~1~ 10140.00-10320.00 ATLAS 5 " R-30 ~-'/ff PRODUCTION LOG .. 11/08/92 ~1 ~ 11100.00-11550.00 ATLAS 5 " S-07~ ~ 11/11/92 $1~' 9620.00- ~720.00 ~T~S 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/19/92 T4 83612 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below If you have any questions, please contact BP Well Records at (907) 564-4004. A-25~Z'~¢ PROD-F 05/24/92 41 A-12~'--I/~ STATIC 05/21/92 41 A-21~-'g GAS LIFT SURVEY 05/24/92 41 S-14 ~-I~ INJ 05/14/92 41 D-17 ~_l~f GAS LIFT SURVEY 06/01/92 41 S-09~"f°~ INJ 05/26/92 ~1 M-21~~-~$ ~ PROD-F 06/01/92 %1 P-15~--/~ GAS LIFT SURVEY 05/28/92 %1 X-12~-~ GAS LIFT SURVEY 06/02/92 %1 ~-o5~-~ ~ o~/o~/9~ ~ R-27 ~'S/ CCL/PE~ 06/13/92 91 Y-34~'~, GAS LIFT SURVEY 05/13/92 %1 A-27~)~ MISC GAS INJ 05/20/92 ~1 s-0 9.~Z-,"g INJ 05/14/92 %1 ~ ~.~ GAS ENTRY SURVEY 5 " D-21~Z-~ZGAS ENTRY SURVEY 5 " Z-01 ~-~ GAS ENTRY SURVEY 5 " C-01 ~2.~. GAS ENTRY SURVEY 5 " 12350.00-12525.00 CAMCO 5 " 8790.00- 9290.00 CAMCO 5 " 3000.00-12700.00 CAMCO 2/5" 10250.00-10800.00 CAMCO 5 " 100.00-10376.00 CAMCO 2 " 9840.00-10253.00 CAMCO 5 " 100.00- 9110.00 CAMCO 2/5" 0.00-12300.00 CAMCO 2/5" 2400.00- 8500.00 CAMCO 2 " 8890.00- 9165.00 SCH 5 " 8650.00- 9553.00 ATLAS 5 " 100.00- 9678.00 CAMCO 2 " 8300.00- 9116.00 CAMCO 5 " 9850.00-10200.00 CAMCO 5 " 05/28/92 41 10750.00-11080.00 CAMCO 05/26/92 41 9900.00-11220.00 CAMCO 05/13/92 41 10400.00-10782.00 CAMCO. 05/15/92 41 7200.00- 9070.00 CAMCO Information Control Well Records Adrian J. Martin ECEIVED JUN 2 6 1992 Alaska 0il & 8as Cons. Commission Anchorage ~'",, STATE OF ALASKA /,, ,KA OIL AND GAS CONSERVATION COMMI, ~N REPORTOF SUNDRY WELL OPERATIONS Gl 1. Operations performed: Operation shutdoWn _ - Pulltubing__. AItercasing Stimulate X Plugging .... 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Repair well. 5. Type of Well: Development ~X Exploratory · Stratigraphic Service .... Perforate Other 6. Datum elevation (DF or KB) KBE = 77.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1116' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35,- T11N, R13E, UPM At effective depth 7' SNL, 1387' WEL, SEC. 26, T11N, R13E, UPM At total depth - 101' NSL, 1403' WEL, SEC. 26,- T11N, R13E, upM A-12, (31-35-11-13) PBU 9. I~ermit number/approval' num'ber 80-117/ 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured- true vertical 9801feet BKB 9553feet 9449feet BKB 9218feet Plugs (measured) Junk (measured) fiil at 9449' (09/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 113 2650 8777 .. 1489 measured true vertical Tubing (size, grade, and measured depth) Size Cemented 20x30 8 c.y. 13 3/8 3720 c. fo 9 5/8 1340 c.f. Measured depth True vertical depth' BKB 140 140 2677 2677 8804 8612 7 396 c.f. 8897'-8924' (Sag R) 9012'-9020', 9027'-9107' (Ivishak) subsea 8622'-8647' (Sag R.) 8729'-8819' (two Ivishak intervals) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' 8311-9800 8166-9552 Sqzd: 9107'-32', 9137'-44',9149'-82' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 1988' 13. stimulation or cement squeeze Summary See Attachment ~ 14. Intervals treated (measured) JUN 1 5 1992 Treatment deSCription including volumes used and final pressure Alaska 0ii & Gas Cons. uu~i~missio~" Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 550 .965 907 1215 266 2980 4663 2798 1569 300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ,,. Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby c-ertify that the foregoing is true and' correct to the best of my knowledge. . Signed Title Supervisor Waterflood/Misciblo Flood Form 10-404 Rev 06/15/68 SUBMIT IN DUPLICATE WELL A-12 (31-35-11-13) PBU SetIBP/NRWO/Frac/PulllBP 08/06/91 08/18/91 09/11/91 Set Baker Inflatable Bridge Plug at 9200' CTMD corrected. Sanded back to 9052' CTMD corrected with 20/40 LWP carbolite. A NRWO was performed using the following fluids listed below. 179 5 14 22 14 16 167 73 174 13 BBLS PW to load well BBLS EW (PREFLUSH) BBLS CEMENT BBLS EW (SPACER) BBLS DUO POLYMER (CONTAMINANT) BBLS PW (DISPLACEMENT) BBLS PW (REVERSE OUT) BBLS PW (JET PASS) BBLS PW (FINAL REVERSE OUT) WELL CLEANED OUT TO 8950' BBLS LOAD .FLUID BEHIND PIPE (APPROX TOTAL BEHIND PIPE IS 21 BBLS) BBLS CEMENT RECOVERED(DOES NOT INCLUDE CEMENT NOT PIJMPED) Begin initial sqz press, of 1000 psi. incr. sqz press to 3000 psi over 50 ._ min. A hydraulic fracture treatment was performed by pumping data frac as designed. ISIP after injectivity test was 1600 psig, with a frac grad. of .62 psi/ft. Perf friction after the injection test was 1180 psig. As a results, 3,000 gal's of 15% HCL was called out. Pressures declined 690 psi when acid hit the perfs. ISIP after the data frac was 1700 psi. Frae gradient was estimated at .64 psi/ft. Closure time and pressure was estimated a 4 min. and 1400 psi. 680 bbl's. SW left on location. 491 gals. of ESL was pumped. Pumped revised program as designed. Pressure started climbing steadily when 6 ppg hit the perfs. Well screened out when 8 ppg hit the formation. A total of 68,200# of 16/20 Carbolite was pumped down the tubing. 25,500# was pumped behind pipe, with 42,700# remaining in the tubing. A total of 1,031 gals of ESL was pumped for the data frac and final frac .treatment. Intervals treated (9010-9120'). 10/12/91 fjh 5/25/92 Pulled .Inflatable Bridge Plug washed sand from 9107 to 9193' CTMD. REiEEIVED JUN 1 5 1992 Alaska Oil & Gas Cons. commission' Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 1966t2 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/03/92 T# 83153 BP CASED HOLE FINALS Enclosed is your copy of. the materials listed below. If you have any questions, .please contact BP Well Records at (907) 564-4004. ,/-~-26 ~-5~ LEAK DET 11/07/91 #1 ~0--;17 GAS LIFT SURVEY 11/16/91 #1 /-01 ?Z'3~. LEAK DET ~5 ~--~1 INJ /-G-11 ~-~o LEAK DET ~ ~ I~ A~ ~OD-~ ~08 ~-~ PROD-F ~13 ~-Iel LEAK DET ~33 ~1-~ TEMP ~3 ~ LE~ DET ~~ q~-9~ TEMP ~~~ LEAK DET ~-13 J JEWELRY LOG 5 " 5 " 11/17/91 #1 11/14/91 #1 11/07/91 #1 11/20/91 #1 11/20/91 #1 11/23/91 #1 11/21/91 #1 11/16/91 #1 11/13/91 #1 11/17/91 #1 12/10/91 #1 12/14/91 #1 12/10/91 #1 12/15/91 #1 12/12/91 #1 11/17/91 #1 216.00-11697.00 CAMCO 2 " 150.00- 9311.00 CAMCO 2/5" 10200.00-10378.00 CAMCO 5 " 8700.00-10119.00 CAMCO 5 " 2000.00- 7600.00 CAMCO 5 " 9400.00- 9940.00 CAMCO 5 " 11200.00-11430.00 CAMCO 5 " 9350.00- 9816.00 CAMCO 5 " 2900.00-10210.00 CAMCO 5 " 150.00-12776.00 CAMCO 2 " 9050.00- 9430.00 CAMCO 5 " 10150.00-11400.00 CAMCO 5 " 10500.00-11345.00 CAMCO 5 " 400.00-10446.00 CAMCO 2 " 8900.00- 9708.00 CAMCO 5 " 200.00-10800.00 CAMCO 2/5" 9400.00- 9780.00 CAMCO 5 " 10150.00-11400.00 CAMCO 12/11/91 #1 13575.00-14590.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED JAN 2 2 1992. Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) inc. 900 East Benson BouJevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 56%5111 TO: DISTRIBUTION Date: 08/13/91 T#:82703 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. 'If you have any questions, please contact BP Well Records at (907) 564-4445. -A-12 STEP RATE TESTS 08/09/91 #1 8750-9080 'SCH 'M-19 TDT-P BORAX 08/06/91 #1 9895-10456 SCH -~1-1 lA COLLAR 08/08/91 #1 9420-10223 ATLAS '" R-08 STEP RATE TESTS 08/06/91 #1 10800-11075 SCH · 'R-18 PERF O8/07/91 #1 9050-10001 SCH '-S-07 PRODUCTION LOG 07/31/91 #1 0.0-6500 ATLAS '-U-10 INJ 08/06/91 #1 9690-10082 SCH ~X-12 PRODUCTION LOG 08/05/91 #1 8900-9300 $CH 5~ 5" 5" 5" 5" 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED AUG 2 2 1991 Naska 011 & Gas Cons, Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard FO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Date:06/06/91 T#:82487 RECEIVED JUN ? 7 1991 Alaska Oil & Gas Cons. C°mm---n~ssio Anchorage .. Enclosed is your copy of the material listed below. If you have any questions, please contact BP -:-:ii:-.i'i, ',:~iii'il,i~::::.",',~: Well Records at (907) 564-4445. ' ~:.':"::-ii~:'?~'i-i~i~ii~iiii~i~i/'i~' A-13 -: --Temp · ' -- .......A-23 ........ :- PITS A-34A Temp B-02 Prod-F B-14 Jewelry B-23 Prod-F B-24 Gas Lift · A-01 '" CL 05/08/91 A-02 Temp 05/12/91 A-04 Temp 05/12/91 A-09 Static Temp 05/12/91 - ~ A-12 ~'~ ~'!:-'~ Temp 05/12/91 '-05/12/91 .... :: 05/15/9.1 05/12/91 ' 05/17/91 05/17/91 05/18/91 05/26/91 #1 #1 #1 #1 #1 #1 .#1 #1 #1 #1 #1 #1 7733-8200 Camco 11100-11394 Camco 10700-11115 Camco 9340-9931 Camco ~ ~:.. 8700-9300 ,, Camco ~" 9150-9529 ~::, Camco ll 200-11651 ..... Camco 8800-9102 Camco -- 10300-10536 Camco 10490-11900 Camco 9600-9920 " Camco 9423-9900 Camco Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:04/22/91 T#:82355 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 5.64-4445. A-12 E-21 E-21 qo', 3 z-30 Production Log 04/16/91 #1 8794-9388 Sch 5" Tubing Cutter 04/17/91 #1 9200-10440 Sch 5" Perf 04/15/91 #1 10180-10590 Sch 5" Perf 04/17/91 #1 9000-9500 Sch 5" Completion 04/17/91 #1 13828-14738 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES STATE OF ALASKA A~, .,A OIL AND GAS CONSERVATION COMMIS~._,d REPORT OF SUNDRY WELL OPERATIONS Alter casing 9801feet BKB 9553feet 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1116' SNL, 920' WEL, SEC. 35, .T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 7' SNL, 1387' WEL, SEC. 26, T11N, R13E, UPM At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Stimulate Plugging Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) AL Perforate Other x 6. Datum elevation (DF or KB) KBE= 77.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number/approval number 80-117/90-647 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9449feet BKB 9218feet Junk (measured) fill at 9449' (09/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 113 20x30 8 c.y. 140 2650 13 3/8 3720 c.f. 2677 8777 9 5/8 1340 c.f. 8804 .. 1489 7 396 c.f. measured 8897'-8924' (Sag R) 9012'-9020', 9027'-9107' (Ivishak) true vertical subsea 8622'-8647' (Sag R.) 8729'-8819' (two ivishak intervals) Tubing (size, grade, and measured depth) True vertical depth BKB 140 2677 8612 8311-9800 8166-9552 Sqzd: 9107'32', 9137'-44',9149'-82' 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. 9 5/8" Baker SAB packer at 8248? 4 1/2" SSSV at 1988' Inten/al$ treated (measured) Treatment de~oription inoluding volumes used ~nd final pressure ~. nil & G~s Cons. Gom~'~-O~ Representative Daily Average Production or Iniection D~{~- ...... ~aCh0~g~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 260 877 3992 1680 1923 1002 16. St~us of wellclassEic~ion as: Oil X Gas Suspended 0 266 1221 248 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ ~~ TitleSupervisorWatedlood/MiscibleFIood Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL A-12 (31-35-11-13~ PBU CTI. I CEMENT SOUEEZE/REPERF OPERATIONS 8~30~90 9/1-3/90 9/8/90 9/14/90 Rigged up coiled tubing and pressure tested BOP equipment to 4000 psi. Performed perforation acid wash and sump cleanout. Pumped cement and squeezed off all perforations. Pressure tested squeeze, okay. Rigged up Schlumberger and reperforated the following intervals using 3 3/8" carrier guns at 4 spf. 8897' - 8924' MD BKB 9012' - 9020' MD BKB 9027' - 9107' MD BKB Returned well to production and tested. jam 1/11/90 R EIVED JAN 1 8 ~99t OJl & 6as Cons. Commission Anchorage OR!61 STATE OF ALASKA ~ ~ '~LA~KA OIL AND GAS CONSERVATION COM~v,$S~,N 1. Operations performed: Operation shutdown Pull tubing X 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging Perforate Alter casing Repair well. Other 5. Type of Well: Development X Exploratory Stratigraphic 4. Location of well at surface 1116°SNL, 920' WEL, SEC. 35, T11N, R13E At top of productive interval 193'SNL, 1363'WEL, SEC. 35, T11N, R13E Ateffective depth 87'NSL, 1401' WEL, SEC. 26, T11N, R13E Attotal depth 101'NSL, 1403'WEL, SEC. 26, T11N, R13E 12. Present well condition summary Total depth: measured true vertical 9801 feet Plugs (measured) 9553 feet BKB NA[ 6. Datum elevation (DF or KB) KBE = 77.43 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) 9. Permit number/approval number 80-117/9-1102 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured true vertical 9754 feet Junk (measured) 9508 feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth 140 2677 8804 113 20 x 30" 8 cu yds 2650 13.3/8" 3720 cu ft 8777 9-5/8" 1340 cu fl 1489 7" 396 cu ft 8311-9800 8897'-8924' (Sag R); 9012'-9020', 9027'-9107 '(open); 9107'-9132', 9137'-9144', 9149'-9182' (Squeezed) True vertical depth BKB 140 2677 8612 8166- 8552 true vertical subsea ~ 8622'-8819' (three open intervals) Tubing (size, grade, and measured depth) 4-1/2" L-80 to 8263' w/4-1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9-5/8" Baker SAB Packer at 8248; 4-1/2" SSSV at 1994' Intervals treated (measured) Treatment description including volumes used and final pressure NOV 2 8 1990 Naska 011 & Gas Cons. commtss~oa 'anehnmnA 14. F{eoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 4 hr test 560 1269 5989 ~Ubsequent to operation 4 hr test 1820 1995 1450 4500 1950 Tubing Pressure 305 256 15. Attachments ~ 16. Status of well classification as: CoPies of Logs and Surveys run Daily Report of Well Operations x Oil X Gas Suspended . Service .17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~. ~./~~----z~.~''/ Title Completion Engineering Supervisor Form 10,404 Rev 06/15A~' SUBMIT IN DUPLIOATE ACcepted Fig at 0~00 hfs on ~/~/90 I%lle . 30_00 Ps_i and tubi, 5/8 casing. I~a d .4;1/.2 tubi, ._ . hfs ong by casin n 4-1/2 ~UDin g- Recoverec/ 5/31/90. 6.2 Daw g annulus to 250 n.,, ~g'. Tested tubinn ,,, ._ 0 ,o,. ~e~eased dg at RECEIVED NOV 2 8 1990 Nasla Oil & Gas Cons. Com~Ot~ ~mchoraoe BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, May 25, 1990 WELL: A-12 (31-35-11-13) Day: 0 PRUDHOE BAY UNIT RIG: DOYEN #16 ..,.. Expense AFE Number: Expense AFE Amount = 160532 Current Field Costs = Current Operation. Accept rig at 300 hrs on 5/25/90. Summary of Last 24 Hours: Move rig to A-12. Accept rig at 300 hrs on 5/25/90. Take on 8.5 ppg filtered brine. RECEIVE'D NOV 2 8 1990 Naska 0il & Gas Cons. tommiss'~o~ Anchorage Reviewed By' .~L/ BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, May 29, 1990 WELL: A-12 (31-35-11-13) Day: 4 Expense AFE Number: 160532 Expense AFE Amount -- Current Field Costs = PRUDHOE BAY UNIT RIG: DOYON #16 Current Operation: RIH with 9-5/8" scraper. Summary of Last 96 Hours: Circulate freeze protection from well. Change 4-1/2" rams. Pull XXN plug. Pull 4-1/2" tubing. PU fishing tools. Recover fish. Run vertilog through 9-5/8" casing. RIH with retrievable bridge plug. Test to 2500 psi, ok. Set storm packer. Pull and replace 9-5/8" packoff. LD storm packer. Pull bridge plug. Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 30, 1990 WELL: A-12 (31-35-11-13) RIG: DOYON #16 Day: 6 Expense AFE Number: Expense AFE Amount = 160532 Current Field Costs = Current Operation: RIH with 4-112" tubing. Summary of Last 24 Hours: RIH with wash pipe. RIH with SBR. LD 3-1/2" drillpipe. R/U to run 4-1/2" tubing. Reviewed By: BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, May 31, 1990 WELL: A-12 (31-35-11-13) PRUDHOE BAY UNIT RIG: DOYON #16 Day: 7 Expense AFE Number: Expense AFE Amount = 160532 Current Field Costs = Current Operation' Secure wellhead and move rig to well A-10. Summary of Last 24 Hours: RIH with 4-1/2" tubing. Space out tubing. Hook up control lines and tested to 5000 psi. Set two-way check valve. ND BOP's and.NU adapter flange and tree; Pulled two-way check. RIH and set plug in taiipipe. Tested tubing to 3000 psi, ok. Tested 4-1/2" x 9-5/8" annulus to 2500 psi, ok. Displace 135 bbls of diesel and u-tube. Reviewed By: ¢.'~,-~, ' BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Friday, June 1, 1990 WELL: A-12 (31-35-11-13) PRUDHOE BAY UNIT' RIG: DOYON #16 Day: 8 Expense AFE Number: Expense AFE Amount = 160532 Current Field Costs = Current Operation: Released rig at 0700 hrs on 5/31/90. Summary of Last 24 Houm: U-tube diesel. Set BPV. Release rig. Reviewed By: ~=,',.-k. BP EXPLORATION BP ExoIoratton (Alasi~al Inc. 900 East 8enson Bouieva~ I:~. Box 196612 Anct~ora{]e. Alasl~a 99519-~612 (907) 561-5111 TO: DISTRIBUTION Date:09/20/90 T#:81671 FROM: SUBJECT: Information Control Well Records LR2-1 RECEIVED c 2 1990 ~,..~ L ~ - · BP. CASED HOLE FINALS Alaska 0ii & Gas Cons. Commissio~ Anchorage Enclosed is your copy of the mat~fi=i li~ed below, if you have any questions, please ~nta~ BP Well Records at (907) 5~-~d~5.. A-12 Perf 09114/90 A-13 Perf 09/16/90 G-06 Tubing Puncher/ Cutter 09/15/90 W-40 Perf 09/17/90 X-08 Perf 09/13/90 X-16 S pinner/Temp- Pres 09/16/90 #1 8900-9419 Sch 5" #1 8600-9465 Sch #1 7908-8188 Sch 5" #1 10100-10485 Sch 5" #1 9400-10027 Sch 5" #1 10350-10750 -Sch . 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS STATE OF ALASKA A[ A OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing Repair well., Plugging ...... Time extension .. . Stimulate Change approved program .... " Pull tubing Variance 1Serf"rate X Other X 5. TyPe of Well~ Development Exploratory Stratigraphic Service , Plugs (measured) 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1116'SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1383' WEL, SEC. 35, T11N, R13E, UPM At effective depth 5269' NSL, 1390' WEL, SEC. 26, T11N, R13E, UMI At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 9801 feet true vertical BKB 9553 feet 6. Datum elevation (DF or KB) KBE,, 77.43 AMSL feet , 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number 80-117 ,, 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9507 feet true vertical BKB 9274 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 113 20x30 8 c.y. 140 140 Surface 2650 13 3/8 3720 c.f. 2677 2677 Intermediate 8777 9 5/8 1340 c.f. 8804 8612 Production Liner 1489 7 396~f 8311-9800 8166-9552 Perforation depth: measured 8897'-8924' (Sag R) Sqzd: 9149'-9182' 9012'-9020', 9027'-9132', 9137'-9144 (ivishak) ~ E CE i FED true vertical subsea 8754'- 8853' (three intelvais) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' /:i]~ Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 1988' RflChora~o, 13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation August 1990 16. If proposal was verbally approved Oil X Gas . Name of approver Date approved Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~~ Title Supervisor Watedlood/Miscible Flood / FOR COMMISSION USE ONLY Cor~ditions of apProval: Notify Commission so representative may witness Plug integrity BOP Test . Location clearance. Mechanical Integrity Test~ 'Subsequent form required 10- ' 15. Status of well classification as: Suspended Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY ' ',' C;;;;;;~. 0. 'gM!TH Commissioner i Approved Copy Returned SUBMIT IN TRIPLICATE WELL A-12 NRWSO STATE SUNDRY A coiled tubing cement squeeze of existing perforations is proposed as follows: 1.) 2.) 3.) Rig up CTU and support equipment and pressure test BOP's to 4000 psi. Perform a perforation Clean up job and sump cleanout. Pump cement and squeeze existing channel from 9182' - 9208' MDBKB to reduce water production from the lowest leaking interval, and resqueeze the lowest interval, 9149'-9182' MD. 4.) Reverse out cement after squeeze is obtained. Wait 12 hours, then test squeeze by performing inflow test. If squeeze fails, immediately resqueeze. 5.) If squeeze is successful, perforate the following intervalS: 8897'-8924' MDBKB 9012'-9020' MDBKB 9027'-9132' MDBKB 6.) Return well to production CLL 8/8/90 RECEIVED AUG 1 6 ]990 Alaska Oil & Gas Cons. Commiss[o~ Anchorage BOP INJECTOR HEAD PAC:'( OFF Q UiC:~ UNION BLIND SHEARS ElL/ND SHEARS KILL LINE CONNECTION FLANGED CONNECT'ION 8WAEt VALVE TYPICAL CTU STACK BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard Re. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :08/03/90 T#:81468 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below, if you have any questions, please contact BP Well Records at (907) 564-4445. A-12 Prod-F 07/30/90 #1 8150-9506 Sch 5" A-13 Pmd-F 07/31/90 #1 9140-9680 Sch 5" S-27 CBT 07/30/90 #2 10380-11177 Sch 5" S-27 CET 07/30/90 #2 10380-11197 Sch 5" S-27 Packer 07/31/90 #1 10700-11150 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES'-'------'- Anchorage BP EXPLORATION ,/UN 0 ] ]990 Alaska Oil & Gas Cons. Commission BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :05/29/90 T#:81189 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED. HOLE FINALS Enclosed is your copy of the matedal listed beloW. If you have any questions, please contact BP Well Records at (907) 564-4445. A-12 Vertilog 05/28/90 #1 16-8238 Atlas 5" A-14 Vertilog 05/23/90 # 1 50-8815 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ~ ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 21, 1989 Alaska Oil & Gas Conservation commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton Gentlemen' Well A-12 (31-35-11-13) PBU Enclosed, in triplicate, is form 10-403, Application for Sundry Approvals, for the above-named well. This outlines our proposal to pull tubing in the well. Yours very truly, R. V. Schock Workover/Completions Supervisor RVS/KTH Enclosures cc' J. Martin (MB 9-4) F. Hernandez Well File STATE OF ALASKA ALA~,. ,,~ OIL AND GAS CONSERVATION COMMISS~,.,,,~ FOR SUNDRY APPLICATION 1. Type of Request: 2. Name of Operator BP Exploration Abandon ~ Suspend ~ Operation Shutdown__ Alter casing ~ Repair well ~ Plugging ~ Change approved program .__ Pull tubing X Vadance 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory ~ Stratigraphic ~ Service Re-enter suspended well Time extension ~ Stimulate ~ Perforate Other 6. Datum elevation (DF or KB) KBE = 77.43 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1116'SNL, 920'WEL, SEC. 35, T11N, R13E At top of productive interval 9. 8. Well number A-12 (31-35-11-13) Permit number 80-117 10. APl number 50- 029-20515 193' SNL, 1363' WEL, SEC. 35, T11N, R13E At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E At total depth 101 'NSL, 1403'WEL, SEC. 26, T11N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9801 feet Plugs (measured) 9553 feet BKB 9754 feet Junk (measured) 9508 feet BKB 11. Field/Pool Prudhoe Bay Field~Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB 140 140 2677 2677 8804 8612 113 20 x 30" 8 cu yds 2650 13-3/8" 3720 cu ft 8777 9-5/8" 1340 cu ft 1489 7" 396 cu ft 8311-9800 measured 8897'-8924' (Sag R); 9012'-9020', 9027'-9132', 9137'-9144' (Ivishak); 9149'-9182' (Squeezed) 8166-8552 RECEIVED true vertical subsea 8622'-8647' (Sag R); 8729'-8737, 8743'-8842, 8846'-8853'(Ivishak); DEC .. e 6 tQIIL 8858'-8889' (Squeezed) Tubing (size, grade, and measured depth) 4-1/2" L-80 to 8248' w/4-1/2" tailpipe to 8373' .~ OU & 6a~.~j~ ~ Packers and SSSV (type and measured depth) 9-5/8" Baker SAB Packer at 8248'; 4-1/2" SSSV at 2162' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation April 15, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_'~ ~.~ ~ ~[/._.~'~ TitleCompletionEngineeringSupervisor ' ~' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date/~ -2~'"~ IApproval No. Plug integrity ~ BOP Test Mechanical Integrity Test__ Approved by order of the Commission Location clearance Subsequent form required 10- /-~ Z~ ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 Commissioner Date /.~ ~-~-~o~7 SUBMIT IN TRIPLICAI~E A=12 AFE Workover Procedure Outline Outline 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15, 16. 17. 18. 19. 20. 21. 22. 23. Procedure: Pull SSSV. Kill well with sea water. Set plug in tailpipe. Pull valve from, the GLM. Circulate well & freeze protect to 2000' with diesel. Set BPV. MIRU workover rig. Pull BPV. Circulate diesel from well. Install two-way check valve. ND tree. NU & test BOP's to 5000 psi. Pull 4-1/2" tubing. Replace the 9-5/8" packoff. Mill and recover packer and tailpipe assy RIH with test packer Test 9-5/8" casing to 3000 psi Run 9-5/8" casing scraper Run 7" casing scraper reverse circuulate. Change over to clean brine. RIH with 4-1/2" 13 % CR tubing and GLM's. Set two-way check valve. ND BOP's. NU & test tree to 5000 psi. Shear valve in the GLM. Displace annulus to filtered and treated brine + 140 bbls diesel. Set BPV. Release rig. RECEIYED DEC261 )D9 Ala,q~ Oit & 6as Cons. Ancllora~)9 BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRIPLE RAM STACK WORKO VER RISER ANNULAR PREVENTER I I P l PE RAMS I I I I 2" KILL LINE MANUAL HYDRAULIC GATE GATE I I PI PE RAMS I I DRILLING SPOOL I I BLIND RAMS I I RE EI ED DEC261~ _AImlm' Oll & Gas Cops. ~mchorage 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 NoVember 15, 1989 Alaska Oil & Gas ConServation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very trul~ /~ ~ Waterflood & Miscible Flood BJP: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File RECEIVED. ,Nov O# & 8as Cons, Commission AnchoraE3 STATE OF ALASKA /'"'~ AL .,A OIL AND GAS CONSERVATION COMMIS,. REPORT OF SUNDRY WELL OPERATION Stimulate__ Plugging Perforate X Repair well. 5. Type of Well: Development _X Exploratory Stratigraphio Service Plugs (measured) 1. Operations performed: Operation shutdown Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519.6612 4. Location of well at surface 1116' SNL, 920'WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Pre~ent well condition summary Total depth: measured true vertical 9801 feet BKB 9553feet Other 6. Datum elevation (DF or KB) KBE = 77.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number/approval number 80-117/9-903 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9754feet true vertical BKB 9508feet Junk (measured) Casing Length Size Structural -- Conductor 113 20x30 Surface 2650 13 3/8 Intermediate 8777 9 5/8 Production -- Liner 1489 7 Perforation depth: Cemented 8 c.y. 3720 c.f. 1340 c.f. 396c. f. measured 8897'-8924' (Sag R) , 9012'.9020', 9027,-9132, 9137'-9144 (Ivishak) true vertical subsea 8754'. 8853' (three intervals) Tubing (size, grade, and measured depth) Measured depth 140 2677 8804 63 11-9800 4 1/2" L-80 to 8248' with 4 1/2" tallpipe to 8373' True vertical depth BKB 140 2677 8612 8166-9552 Sqzd: 9149'-9182' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 2162' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Re~3resentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure RECEIVED Nov t ]98g 0il & Gas Cons. C0mmi~.~in~ Anchora~3 Tubing Pressure Prior to well operation 520 525 2066 Subsequent to operation 1030 1050 2010 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run . ,. Daily Report of Well Operations ~ Oil X Gas Suspended '"i 7. I he'reby ~rt~y that th~~g~ue and correct to the best of my knowledge. Signed ~~'~'~~ Title FOrm 10'404 Rev 06~15/88 ' 1432 .J 480 16 74~ ~r~ 731 Service Supervisor Waterfiood/Miscible Flood SUBMIT IN DUPLICATE WELL A.12 (31.3~.11.13~ PBU ADD~L. PERFORATION OPERATIONS The following additional intervals were perforated October 4, 1989 using Schlumberger 3 3/8" carrier guns at 4 spf: 8897' - 8924' MD BKB Sag R. 9012' - 9020' MD BKB Zone 4 9027' - 9038' MD BKB Zone 4 9046' - 9053' MD BKB Zone 4 All depths are referenced to GR/CCL of 2/8/89. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jm 11/7/89 BP EXPLORATION October 23, 1989 ORIgINAl. BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to continue production from the well until a rig workover to repair a tubing leak can be completed during December, 1989. The leak currently presents no operating difficulties. If you have any questions, please contact me at 564-5564. Yours very truly, J. A. Bragg Manager Production Engineering JAM: JAM Enclosures (9) CC: R. B. Laule (MB12-1) Well File RECEIVED Alaska.Oil.& ~as Co,s, Co~r~s$iot~ '" '.Anchorage ( STATE OF ALASKA . A~.,-,$KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation Shutdown Alter casing Repair well PluggiDg Time extension ~ Variance X Change approved program Pull tubing ~ Perforate 9801 feet BKB 9553 feet 5. Type of Well: Development X Exploratory Stratigraphic Service Re-enter suspended well , Stimulate Other 6. Datum elevation (DF or KB) KBE ,, 77.43 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number 80-117 10. APl number 50- 029.20515 11. Field/Pool Prudhoe Oil Pool Plugs (measured) 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1116'SNL, 920'WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1383' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101'NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 9754 feet true vertical BKB 9508 feet Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 113 20x30 8 c.y. 140 140 Surface 2650 13 3/8 3720 c.f. 2677 2677 Intermediate 8777 9 5/8 1340 c.f. 8804 8612 Production -- Liner 1489 7 396 c.f. 8311-9800 8166-9552 Perforation depth: measured 9038'-9046', 9053'-9132', 9137'-9144 Sqzd: 9149'-9182' true vertical subsea R E C E ~ V E D 8754'. 8853' (three intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' OCT 2 4 1989 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSS Vat 216~a$~(a 0JJ & Gas Cons. C0mmis Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch ~ 14. Estimated date for commencing operation N/A 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended Service 17. I hereby ~rtify that the foregoing is true and correct to the best of my knowledge. Signed.~~~~~ Title Manac~lerProductionEr~lineerinc~l Date/~'~/~? I Conditions of approval: Notify Commission so representative may witness .,~ I~,..~rpval No. ~'_ ~ ~ -~ Plug integrity BOP Test Location clearance ...... ,~,!~:~:*~ ~.. -- Approved by order of the Commission 0Ri~:li:i; ~'C~I,~THBY Co Date /0 '-~,~"~-~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WI~LL A.12 (31.3~-11.13~ PBU Reauest for Variance to Produce with Tubin_~ Leak A tubing leak has been detected in Well A-12 at approximately 6992' MD. We propose to continue production from the well with the tubing leak until December, 1989, at which time a rig workover will be performed to replace the tubing as outlined below. If bleeding of inner annulus pressure precipitates annular flow at the surface, the well will be shut in immediately and prepared for the rig workover le . . Se Rig Workover Procedure PunCh tubing, circulate produced water into tubing/9-5/8" annulus, and set BPV in tubing hanger. Pull 4 1/2" tubing; remove packer. Make bit/scraper runs in the 9 5/8" casing and the 7" liner. Check PBTD to ensure perforations are not covered and sufficient rathole exists. If 13-chrome tubing is to be installed, run casing inspection logs/ Kinley caliper on 9 5/8" casing. Run 4 1/2" tubing, packer, and 4 1/2" tailpipe. Utilize one 4 1/2" "X" nipple, one 4 1/2" "XN" 'nipple, and WL entry guide in the tailpipe. Install gas lift mandrels. NOTE: A previously issued Application for Sundry Approval to add a perforated interval should be cancelled (Approval No. 9-040). JAM 10/9/89 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 10/11/89 Transmittal: 80475 From: Subject: Information Control Well Records LR2-1 BP CASED HOLE FINAL LOGS ' Enclosed is your coPy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-12 Completion 10/04/89 ~'-...'#1 8787-9571) Sch 5" A-20 PROD-F 10/07/89 #1 11800-12284 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS R~~3 ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 27, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, B. ~. ~oli¢k¥ Supervisor Waterflood/Mis¢ible Flood Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED _ Alaska 0ii & Gas Cons. C0mmiss[0. Anchorage f~"%~i STATE OF ALASKA .~'N .ASKA OIL AND GAS CONSERVATION COMk. ,~ION APPLICATION FOR SUNDRY APPR /[ Si N A t 1. Type of Request: Abandon Suspend operation Shutdown, Re-enter suspended well Alter casing ~ Repair well. Plugging Time extension Stimulate ~ Change approved program Pull tubing ~ Variance Perforate x Other 2. Name of Operator I 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. I Development X Exploratory ~ 3. Address Stratigraphic P. O. Box 196612, Anchorage, Alaska 99519-6612 service .... 4. 'Location of well at surface 1116'SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. PreSent well condition summary Total depth: measured true vertical 9801 feet BKB 9553 feet KBE= 77.43 AMSL feet Plugs (measured) 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number 80-117 10. APl number 50- 029.20515 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9754 feet true vertical BKB 9508 feet Junk (measured) Casing Length Size Cemented Structural -- Conductor 113 20x30 8 c.y. SurfaCe 2650 13 3/8 3720 c.f. Intermediate 8777 9 5/8 1340 c.f. Production -- Liner 1489 7 396 c.f. Perforation depth: measured 9038'-9046', 9053'-9132', 9137'-9144 Measured depth 140 2677 8804 8311-9800 true vertical subsea 8754'. 8853' (three intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 2162' 13. Attachments DescriptiOn summary of proposal x Detailed operations program ~ True vertical depth BKB 140 2677 8612 8166-9552 Sqzd: 9149'-9182' RECEIVED Alaska 0il & Gas Cons. C0mm Anchorage BOP sketch ..X_ 14. Estimated date for commencing operation October 1989 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17, I here~ ~fy that th~~,~ tru~nd correct to the best of my knowledge. Si~lned ,,~=~~~,~~" Title Supervisor Waterflood/Miscible Flood Approved by order of the Commission Form 10-403 Rev 06/15/88 15. Status of well classification as: Suspended~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance ... Mechanical Integrity Test ~ Subsequent form required i'0- ~e ~k ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner SUBMIT IN TRIPLICATE Approved Copy Returned_ WELL A-12 (31-35-11-13~ PBU ADD'L. PERFORATION PROPOSAL We propose to perforate the following additional intervals during October 1989: 8897' - 8924' MD BKB Sag R. 9012' - 9020' MD BKB Zone 4 9027' - 9038' MD BKB Zone 4 9046' - 9053' MD BKB Zone 4 (previously approved - Approval # 9-040) All depths are referenced to GR/CCL of 2/8/89. A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. NOT~ Discrepancy existed among logs run for depth control. It has been determined that the original perforations were 26' 'off depth. Correct depths are shown on Form 10- 403. All future logging work will reference the GR/CCL of 2/8/89 for depth control. jm 9/27/89 RECEIVED Alaska Oil & Gas Cons, Commission Anchorage BOWEN PA~;KOFF FLOW TUBES & PACKOFF FLOWLINE FLOWLINE VALVE HAND PUMP GREASE SEAL FLOWTUBE GREASE LINE RISER GREASE --MANIFOLD GREASE PUMP . , ..-'GREASE RESERVOIR BOP BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 08/31/89 Transmittal: 80313 From: Subject: Information Control Well Records LR2-1 BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-12 TEMP 08/19/89 #1 2800-8500 Camco 5" A-15 PROD-F 08/25/89 #1 10600-11074 Sch C-28 Completion 08/28/89 #1 10772-11106 Sch 5" D-07 Leak Detection 08/19/89 #1 11000-12100 Camco 5" G-11 Tubing Puncher 08/27/89 #1 9.800-10078 Sch 5' N-20 Completion 08/26/89 #1 8734-10126 Sch R-12 PROD-F 08/21/89 #1 3050-10940 Camco S-08 Leak Detection 08/16/89 #1 1850-8600 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS ARCHIVES Anchorage BP EXPLORATION HOUSTON ARCO CHEVRON E~LION TEXAuO TO: MOBIL REFERENCE: PHILLIPS STATE OF AI~SKA GEOSC IENCES RESERVOIR ARCHIVES B~ CASED HOLE FINAL LOGS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 9951~6612 (907~ 561-5111 INDEXED D ate: 02/14/89 79812 The follow!ng material is being submitted herewith. Pleese acknowledge receipt by signing a copy of this letter and returning It to this office: A-12 Prod 02/08/89 #I 7941-9628 Sch 5" F-11 Prod 02/09/89 #I 8900-9480 Sch 5" H-14 Prod 02/06/89 #I 10350-10878 Sch 5" W-38 Prod 02/10/89 #I 14200-14680 Atlas 5" W-42" HP-Press Fall-Off 02/09/89 #I 9600-9600 Sch Rece i ved Date Jennifer Dietz INFORMATION CONTROL Wet I Records ER2-1 Standard Alaska ~ Production Company 900 East Benson Boulevc~,~. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 16, 1989 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, B J. Polzcky~upervzsor Waterflood & Miscible Flood BJP:JAM Enclosures (9) cc: L. Burke (MB12-1) A-12 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. RECEI,VED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Alter casing Repair well Change approved program. 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage' Alaska 99519-6612 4. Location of well at surface 1116'SNL, 920'WEL, SEC. 35, T11N, RI3E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101'NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 12. Present Well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 113 Surface 2650 Intermediate 8777 Production -- Liner Perforation depth: measured 9801 feet BKB 9553 feet Operation Shutdown ~ Re-enter suspended well~ Plugging ~ Time extension Stimulate ~ Pull tubing ~ Variance Perforate X Other 6. Datum elevation (DF or KB) KBE, 77.43 AMSL feet 5. Type of Well: Development X Exploratory ~ Stratigraphic ..... Service Plugs (measured) 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-12 (31-35-11-13) PBU 9. Permit number 80-117 10. APl number 50- 029-20515 11. Field/Pool Prudhoe Oil Pool 9754 feet Junk (measured) BKB 9508 feet Size Cemented 20x30 8 c.y. 13 3/8 3720 c.f. 9 5/8 1340 c.f. Measured de~h True vertical de~h BKB 140 140 2677 2677 8804 8612 1489 7 396~ 6311-9800 8166-9552 9012~9020~902~-9106~ 9111~9118' Sqzd: 9123~9156' true vertical subsea 8729'- 8829' (three intervals) RECEIVED Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' JAN 1 8 19 9 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 21~i~a8.~![ OJJ & ~a$ Cotl& CoDI!I~jsSi 13. Attachments Description summary of proposal x Detailed operations program ~ BOP ske~1~""Y~g~ ' 14. Estimated date for commencing Operation ] 15. Status of well classification as: January/February 1989 16. If proposal was verbally approved Oil X Gas~ Suspended Name of approver Date approved Service 17. I hereby certify that the foreg~ng~ is true and correct to the b est of my knowledge. _ ..,~~ Title Waterflood/Miscible Flood Si~lned . FOR COMMISSIoNSUperviS°rusE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance .... MechaniCal Integrity Test . Subsequent form required 10- ~"c~/-P-' I Approval No. (~._ ~7~ ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGInAl. SIGNED BY Commissioner A, pproved Copy Returned~_ SUBMIT IN TRIPLICATE WELL A-12 (31-3~;-11-131 PBU ADD'L. PERFORATION PROPOSAL We propose to perforate the following additional interval during January/February 1989: 8897' - 8924' MD BKB (Ref. BHCS, 10/30/80) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 1/12/89 RECEIVED FLOW TUBES & PACKOFF BOWEN PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE GREASE LINE FLOWLINE VALVE GREASE 'MANIFOLD GREASE PUMP RISER ~- GREASE RESERVOIR BOP $1andard Alaska Production Compc, 900 East 8enson Boulevard P.O. Bo~ 196612 Anchorage. Alaska 995 (907) 564.51 I I HOUSTON ARCO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS STATE OF! ~SKA ~ · GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION O~te: 08/22/88 TI: 79232 The following materiel is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning It to this office: A-12 A-17 R-05 S-07 S-09 Collar 07/18/88 #1 7980-9600 GO 5" Collar 07/30/88 #1 10100-10300 GO 5" Collar/Per~ 07/25/88 #1 8950-9150 GO 5" Collar/Perf 07/22/88 #1 10450-10630 GO 5" Collar 07/17/88 #1 9250-9840 GO 5" Race I ved Da te A u,~,l of ~he Or,g;noI Stondo,d O~1 Company fou,~ded ,n C|evelond. Ofl;o. ,n 1870 Jennifer Dietz NFORMAT I ON CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION August 17, 1988 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-12 Well File Manager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. 1. Operation performed: Operation shutdown [] Stimulate [] Plugging [] ....... ,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Perforate [] Pull tubing [] Alter casing I-! Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 ¢. Location of well at surface 1116' SNL, 920'WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM measured true vertical 1. Present well condition summary Total depth: measured true vertical Effective depth: 9801 feet BKB 9553 feet 9754 feet BKB 9508 feet Size Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) KBE = 77.43 AMSL feet 20x30 133/8 9 5/8 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-12 (31-35-11-13) PBU 8. Approval number 7.901 Casing Length Structural -- Co nd ucto r 113 S u rface 2650 Intermed late 8777 Production -- Liner 1489 Perforation depth: measured 9. APl number 5 0 - 029-20515 0. Pool Prudhoe Oil Pool Cemented Measured depth True Vertical depth BKB 8 c.y. 140 140 3720 c.f. 2677 2677 1340 c.f. 8804 8612 7 396 c.f. 9012'-9020', 9027'-9106', 9111'-9118' true vertical subsea 8729'- 8829' (three intervals) Tubing (size, grade and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' 8311-9800 8166-9552 Sqzd: 9123'-9156' Packers and SSSV (type .and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSVat 2162' 2. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure , Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 460 276 423 1757 570 284 1946 1921 Tubing Pressure 276 281 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Manager Production Engineering Subrfiit in Duplicate WKLL A-12 f31-35-!1-13~ PBU ADD*L. PERFORATION/STIMULATION OPERATIONS The following previously squeezed interval was rcperforatcd July 18, 1988 using Gearhart 3 118" HSC guns at 4 spf: 9012' - 9020' MD BKB (8729' - 8737' TVDss) Ref. BHCS 10f30/80 On July 25, 1988 a 15% HCI acid wash was pumped as follows via coiled tubing: 24 bbls. acid · 7 bbls. divcrtcr stage 24 bbls. acid 7 bbls. divcrtcr stage 24 bbls. acid 9 bbls. divcrtcr stage 24 bbls. acid 10 bbls. divcrtcr stage 52 bbls. acid 26 bbls. diesel wi10% mutual solvent Following the HCI wash, the well was put back on production and tested. The following scale inhibition treatment was performed August 4, 1988 via coiled tubing' 11 bbls. diesel preflush 26 bbls. EDTA 127 bblS. scale inhibitor 405 bbls. seawater Thc treatment fluids were displaced to the perforations with diesel. The wcll was left shut in for 24 hours, then returned to production and tested. jm 8/12/88 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION July 13, 1988 Alaska Oil & Gas Conservation i~ommission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our propoSal to add perforations and stimulate the well. Yours very truly, JAB: JAM Enclosures (9) cc: J. L. Haas, MB12-1 A-12 Well File ager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing r'l Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1116' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101' NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 5. Datum elevation (DF or KB) KBE = 77.43 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-12 (31-35.11-13) PBU 8. Permit number 80-117 9. APl number 5 0 - 029-20515 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 113 S u rface 2650 I nte rmed i ate 8777 Production -- Liner 1489 Perforation depth: measured 9801 feet BKB 9553 feet 9754 feet BKB 9508 feet Size Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth BKB 8 c.y. 140 140 3720 c.f. 2677 2677 1340 c.f. 8804 8612 20x30 13 3/8 9 5/8 7 396 c.f. 9027'- 9106', 9111'- 9118' true vertical subsea 8743'- 8829' (two intervals) Tubing (size, grade and measured depth) 8311-9800 8166-9552 Sqzd: 9012'-9020', 9123'-9156' 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 9 5/8" Baker SABpacker at 8248'; 4 1/2" SSSV at 2162' 2. Attachments Description summary of proposal [] Detailed operations program~F'l BOP sketch [] 13. Estimated date for commencing operation July~August 1988 4. If proposal was verbally approved Name of approver Subsequen~ Work,Re. ported on Form No. ,/d; ~'?2~'~ated.~_./~~ '~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~lne~/~,~-j/~.~'~ T itlecommissionManagerusePrOductiOnonly En~lineerin~l Conditions of approval Notify commission so representative may witness IApproval No. [] Plug integrity [] BOP Test [] Location clearance I ' :~,PPr0ved Copy ~~~_ ~.~85~, .~~ ~~/~~/ _ Returned bY order of Approved by the commission Form 10-403 ~ ,~ubmit/ in triplicate ..~ELL A-12 (31-35-11-13~ PBU ADD'L. PERFORATION/STIMULATION PROPOSAL We propose to perforate the following additional interval at 4 spf, followed by a HCI acid wash and contingent scale inhibition treatment. 9012' - 9020' MD BKB (8729' - 8737' TVDss) Ref. BHCS 10/30/80 The 15% HCI acid wash will be pumped as follows via coiled tubing: 1000 gal. acid 1/4 of diverter stage 1000 gal. acid 1/4 of diverter stage 1000 gal. acid 1/4 diverter stage 1000 gal. acid 1/4 diverter stage 2000 gal. acid 500 gal. diesel w/10% mutual solvent Following the HCI wash, the well put back on production and tested. Depending on the results of the HCI wash, the following bullheaded scale inhibition treatment will be performed: 10 bbls. diesel prcflush 25 bbls. EDTA 121-145 bbls. scale inhibitor 50 bbls. seawater The treatment fluids will be displaced to the perforations with diesel. The well will be left shut in for 24 hours, then returned to production and tested. jm 7/08/88 FLOW TUBES & PACKOFF BOWEN PACKOFF J-*-- HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE VALVE -- GREASE LINE RISER GREASE / ~' MANIFOLD GREASE PUMP BOP -..-GREASE RESERVOIR Standard Alaska Production Compa~'~'~ 900 East Benson Bo~ rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION May 3, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a cement squeeze and reperforation of the well. Yours very truly, JAB: JAM ~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-12 Well File Manager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland Ohio in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · Operation performed: Operation shutdown [] Stimulate [] Plugging [] Alter casing [] Other r~ 2. Name of Operator Standard At~ska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4, Location of well at surface 1116'SNL, 920'WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, SEC. 35, T11N, R13E, UPM At effective depth 87' NSL, 1401' WEL, SEC. 26, T11N, R13E, UPM At total depth 101'NSL, 1403' WEL, SEC. 26, T11N, R13E, UPM 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 113 Surface 2650 I nte rm ed late 8777 Production -- Liner 1489 Perforation depth: measured 9801 feet BKB 9553 fee t 9754 feet BKB 9508 feet Size Plugs (measured) Junk (measured) Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) 20x30 13 3/8 9 5/8 KBE = 77.43 AMSL feet S. Unit or Property name Prudhoe Bay Unit 7, Well number A-12 (31-35-11-13) PBU 8. Approval number 7-901 9. APl number 5 0 - 029-20515 0. Pool Prudhoe Oil Pool Cemented Measured depth True Vertical depth BKB 8 c.y. 140 140 3720 c.f. 2677 2677 1340 c.f. 8804 8612 7 396 c.f. 9027'- 9106', 9111'- 9118' true vertical subsea 8743'- 8829' (two intervals) Tubing (size, grade and measured depth) 8311-9800 8166-9552 Sqzd: 9012'-9020', 9123'-9156' 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 2162' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1 Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 770 416 5644 1662 880 533 629 1831 Tubing Pressure 262 252 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge I Sig~ed ~j~~j~ Title Manager ProductionEngineering FOrm 10-4J~4 R§v. 12-1-~ //' Date Submit in Duplicate Well A-12 (31-35-11-13) PBU CTU CEMENT SOUEEZE OPERATIONS A coiled tubing cement squeeze of existing perforations and a confirmed channel was performed as detailed below. l® Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. 2. Performed perforation mud acid wash; flowed well. 0 Cement squeezed perforations. Contaminated cement in the wellbore, then reversed out after 24 hours. Pressure tested squeeze. e Reperforated the following intervals using Gearhart 3 1/8" HSC guns at 4 spf: 9027' - 9106' MD BKB (8743' - 8818' TVDss) 9111' - 9118' MD BKB (8822' - 8829' TVDss) Returned well to injection and tested. The above work was completed December 23, 1987. 0834Z/jm 04/08/88 Stonclo~d Alaska Production Comport 900 Eo*~ Benson PO Bo:, 196612 An(horoge. Aloe, ko 99519 ~907~ 564.511 I INDEXED DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA STANDARD AL ASKA PRODUCTION Date: 01/26/88 TO: T//: 78486 GEOSCIENCES REFERENCE: SAPC cASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to thls office: A-13 B-3B D-3 D-18 D-18 F-8 F-19 H-9i J-28 K-12 K-13 K-14 Y-24 CCL/Perf. 12/23/87 Caliper Tool(Multifinger) O1/10/88 Spinner/Hydro/Temp. on coil tubing Production Profile O1/08/88 f/1 Cont. Flow Survey 12/27/87 f/1 Temp. 12/27/87 f/1 Production Profile 01/16/88 f/2 CCL/Perf. 12/25/87 f/1 Injection Profile 01/10/88 f/1 Production Profile 01/12/88 f/1 Production Profile 01/08/88 f/1 Production Profile 01/18/88 f/1 CCL/Perf. 12/22/87 ~/1-4 PIT/Flowmeter 01/09/88 f/1 8100-9230 GO 5" f/2 100-8650 Sch 5" 12/17-18/87 f/1 9500-11055 10400-10660 Camco 10900-11200 GO 5" 10800-11200 GO 5" 10950-11250 Camco 12200-12830 GO 5" 9500-10000 Camco 10790-1~030 Camco 9150-9370 Camco 11800-12100 Camco 10950-11730 GO 12828-13450 Camco 51! 1! 11 5" 5" 5" 5~' 5" GO 5"/2" Received z~ -x/ Y~ ~'~ '~ ; ~''' Victo i Aldridge Date (~, ]~..,...~ ~ , ~.~eh0~ We I I Records LR2- I A unit ol the or;g;nol S~ondord ~1 Co--pony Founded ~n Cle~elond. ~,o. ,- 1870 Standard Alaska /,.-.~ Production Compa; 900 East Benson Boo,. ,~rd P.O. Box 196612 Anchorage, ALaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION November 16, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, JAB:JAM~ Enclosures (9) cc: J. L. Haas (MB12-1) A-12 Well File ragg er Production Engineering R CEI IEg NOV I e, ]~7 Oil 8, Gas Cons. Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CCtv, MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 77.43 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, Sec. 35, TllN, R13E, UPM At effective depth 87' NSL, 1401' WEL, Sec. 26, TllN, R13E, UPM At total depth 101' NSL, 1403' WEL, Sec. 26, TtlN, R13E, UPM 7. Well number A-12 (31-35-11-13) PBU 8. Permit number 80-117 9. APl number 50--029-20515 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9801 feet Plugs (measured) 9553 feetBKB Effective depth: measured 9754 feet Junk (measured) true vertical 9508 feetBKB Casing Length Size Cemented Measured depth True Vertical depth Structural -- BKB Conductor 113' 20"x30" 8 cu. yds. 140' 140' Surface 2650' 13 3/8" 3720 c.f. 2677' 2677' Intermediate 8777' 9 5/8" 1340 c.f. 8804' 8612' Production -- Liner 1489' 7" 396 c.f. 8311'-9800' 8166'-9552' Perforation depth: measured 9012' - 9156' true vertical (ss) 8729' - 8865' (four intervals ) ~)~ Tubing (size, grade and measured depth) ~ 4 [/2" ~-80 to 8248' with 4 [/2" tailpipe to .8373' NOV Z 8 19 7 12.Attachments Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. C0mmissi0r~ 9 5/8" Baker SAB packer at 8248'; 4 1/2" SSSV at 2162' ~hn~,~ Description summary of proposal K] Detailed operations program [] BOl~'~'~'~u~ 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Subsequent Work Reported on · Form No./-~' ~/0¢ Dated~_~./.~ Date approved ~/~. A. Bragg ~/~ Date 15. I hereby certify that the foregoing is true and correct t° the best of my knowledge Title Manaqer Production Enqineerinq Commission Use Only i Conditions of approval Notify commission so representative may witness I [] Plug integrity ~ BOP Test [] Location clearan_ce| ~'~ Approval No. Approved Copy Returnee ,,/,,I Approved by ~/W,ub'. /' ~,w ,-- -'- ~ Commissioner . by order of the comm,ssio, Date Form 10-403 Rev 12-1-85 Submit in triplicate Well A-12 (31-35-11-13) PBU CTU CEMENT SQUEEZE PROPOSAL A coiled tubing unit cement squeeze of existing perforations is proposed. The existing perforated intervals are as follows (ref. BHCS/GR 10-30-80): 9,012' - 9,020' MD BKB 9,027' - 9,106' MD BKB 9,111' - 9,118' MD BKB~ 9,123' - 9,156' MD BKB This work is outlined below: 1. Perform preworkover .surveillance. 2. Rig up CTU and support equipment. 3. Perform perforation and channel mud acid wash, flow well. 4. Clean out sump with well flowing. 5. Remove gas lift system. 6. Cement squeeze all perforations. 7. Contaminate cement. WOC. 8. Clean out contaminated cement and pressure test squeeze. 9. Reperforate as.follows: 9,027' - 9,106' (79') MD BKB 9,111' - 9,118' (7') MD BKB (Depths ref. BHCS/GR 10-30-80) 10. Return the well to production and obtain production tests. 11. Following post-workover production evaluation, following interval at limited shot density: 9,123' - 9,128' (5,) 12. Based on post-workover GOR response, possibly reperforate the uppermost perforation interval: 9,012' - 9,020' ( 8') MD BKB 13. Return the well to production and obtain periodic production tests. RECEiYEI) NOV i 8 !95] Alas~ Oil & Gas Cons. comm'issio[~ Anchorage reperforate the Coiled Tubing Blow-Out-Preventers Coiled Tubing PaCk-Off · Blind Rams · Cutter Rams - ! 2' Chicksan (Kill Line) I I Slips ~ Pipe Pump-In Sub Rams (C ircula te/R e turns ) Well Head Swab Valve Standard Alaska Production Company /~ 900 East Benson Boulev,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 May 27, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU. Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our sub- sequent report of perforating the well. Yours very truly, PFB:JAM~ P. F. Barth Supervisor, Reservoir/Production Surveillance Unit I EnclosUres (4) cc: Drilling Well Files (MB12-1) Well Records (LR2-1) A-12 Well File MAY 2 A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASK,~/'-h'L AND GAS CONSERVATION COMMI,~""'"ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing F! Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 77.43 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1116' SNL, 920' WEL, Sec. 35, TIlN, R13E, UPM At top of productive interval 193' SNL, 1363' WEL, Sec. 35, TllN, R13E, UPM At effective depth 87' NSL, 1401' WEL, Sec. 26, TllN, R13E, UPM At total depth 101' NSL, 1403' WEL, Sec. 26, TllN, R13E¢ UPM 11. Present well condition summary Total depth: measured 9801 feet Plugs (measured) true vertical 9553 feet 7. Well number A-12 (31-35-11-13) PBU 8. Approval number N/A 9. APl number 50-- 029-20515 10. Pool Prudhoe Oil Pool Effective depth: measured 9754 feet Junk (measured) true vertical 9508 feet B~ Casing Length Size Cemented Structural -- Measured depth True Vertical depth BKB Conductor 63 ' 20"x30" 8 cu.yds. Surface 2627' 13 3/8" 3720 c..f. Intermediate 8754' 9 5/8" 1340 c.f. Production -- 113' 113' 2677' 2677' 8804' 8612' Liner 1489' 7" 396 c.f. Perforation depth: measured 9012' - 9156' (four intervals) true vertical (subsea) 8729' - 8865' Tubing (size. grade and measured depth) 4 1/2" L-80 to 8248' with 4 1/2" tailpipe to 8373' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8248'; 4 1/2" Otis $$$V at 2162' 12. Stimulation or cement squeeze summary 8311'-9800' 8166'-9552' R C IV D Alaska 0it & Gas C,)~m, CommJss~0n Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation RepresentatiVe Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing'Pressure 1850 1775 4351 1585 Tubing Pressure 267 Subsequent to operation 2840 4301 6706 1909 296 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~, ~'--/4¢'"' o~, Signed eL; 8~~, Title Supvr.. Res./PrOd. Surveillance I Date Form 10,404 R . -1- Submit in 'Dupiicate PERFORATING DATA - Well A-12 (31-35-11-13) PBU 4/12/86 Pulled SSSV from ball valve nipple at 2162'. 4/13/86 Installed and tested lubricator to 3500 psi for all Well work. Rigged up Dresser'Atlas and perforated the following additional intervals using 3 1/8" Jumbo Jet guns at 4 spf: 9012' - 9020' MD BKB (8729' - 8737' TVDss) 9027' - 9087' MD BKB (8743' - 8800' TVDss) 9111' - 9118' MD BKB (8822' - 8829' TVDss) All depths are referenced to BHCS/GR, 10/30/80. Put well on production. 5/22/86 Reset and tested SSSV in ball valve nipple at 2162'. Well on production. jm 5/23/86 SOHIO ALASKA PETROLEUM COMPANY · 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 995024)612 March 11,1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 kttn: Mr. C. V. Chatterton Well A-12 (31-35-11-13) PBU Gentlemen: Enclosed in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to perforate the well. Very truly yours, Enclosures (3) cc: Drilling Well Files (MB 12-1) Well Records (LR 2-1) A-12 Well File 4052m P. F. Barth Supervisor, Reservoir/ Production Surveillance Unit I RECEIVED MAR 1 1986 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name°fOperator 7. PermitNo. STANDARD ALASKA PRODUCTION COMPANY 80-117 3. Address 8. APINumber P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50- 029-20515 4. Location of Well At surface: 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM · 5o Elevation in feet (indicate KB, DF, etC.) ~CRW. = 77.43' AM.qT, 12. 6. Lease Designation and Serial No. ADL 28286 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number A-12 (31-35-11-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [-] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). The following additional intervals will be perforated during March/April, 1986 at 4 spf: 9012' - 9020' BKB (Ref. BHCS/GR, 10/30/80) 9027' - 9087' BKB ( " ) 9111' - 9118' BKB ( " ) A lubricator will be installed and tested to 3500 psi for all well work· An SSSV will be reset and tested in the ball valve nipple at 2162'. RECEIVED MAR 1 3 1986 Alaska 0ii & Gas Cons, C0mmissi0~ Anchorage 14. I hereby certify that the foregoing is true ar)t~correct to the best of my knOwledge. Signed ' TitleSUpvr. ReserVoir/Production The space below for Commission use P. F. Barth Surveillance Unit I Conditions of Approval, if any: Ap~ro¥~d Copy Date ....... By Order of Approved by. COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate INDEXED TO: SFO/UNIT/STATE: SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO (-Marathon) MOBIL PHILLIPS STATE:, BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 8-01-85 76349 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-12 7-13-85 FlOwing Gradient Camco REC~,V~D ............................... ~-Oiy-&-GaS--GeI~S' c°mmiSS~a~thy Perkins DATE Anchorage LR 2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON 31 1 1 "C" $1F{EEl ANCHORAGE. ALASKA 1ELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 EXXON ~o: SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS . . STATE OF AK BPAE (Transmittal Only) . _ CENTRAL FILES(CC#'s-Transmittal Only) Date: Trans. #: CC#: 12/6/82 2904 55904 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receip! by signing copy of this letter and returning it to this office:-- E-21 Q_3~- - G_.i 7.~ R-17 ~ R-18 ~ A-12 Spinner 11/17/82 Spinner 11/6/82 #1 Perf. Depth il/4/82 #1 Perf. Record 10/30/82 #1 CCL/Perf. 11/9/82' #1 Temp. 11/10/82 8910-9310 9850-11320 9680-11119 Camco 5" Otis 5" Sch 5" Sch 5" Sch 5" Otis 5" 4182) RIrc[IVED .................... Va. ctoria Aldridge ' pment Geology ~ ] o.. {,[~ TP 1-5 ................ ,, 8Z wo]. Alaska Oil & Gas Cons. Commission Anch.,age SOHIO ALASKA PETROLEUM COMPANY S¥0 ARCO CHEVRON EXXON GETTY ~o: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only_.) _ CENTRAL FILES(CC#' s-Transmit tal Only)_ 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6.612 ANCHORAGE, ALASKA 9[~502 Date: 11/1/82 Tr ans. #: 2802 CC#: 55802 REFERENCE: / 0 CASED HOLE FINAL LOGS . · 'The following material is being submitted herewith. Please acknowledge receipt by signing a copy of' this letter and returning it to this office:- E-17 Spinner 9/27/82 #1 10.650-1 t160 Otis 5" _ . M-15 Spinner 9/1/82 #1 9'050-9300 GO 5". G-18 Spinner 9/25/82 #1 10000-1.0350 GO 5" G-3 Spinner 9/23/82 #1 8850-92'30 GO 5" Y-13 Spinner 9/19/82 #1 103.50-10700. GO 5" A-12 Temp. Survey 10/19/82 #1 880(~-9600 Camco 5" (4/82):,'~ R[C[IV£O DATE Victoria Aldridge Alaska 0il & Gas Cons. C0m:nis$i0~evelopmen t Geology ............................ AnGh~?ag~---- ~ell Records TP1-5 SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~'o: SFO/UNIT/STATE: (-Mara tho n) EXXON GETTY MOBIL PHILLIPS STATE OF ~ BPAE (Transmittal Only) CENTRAL FILES(CC#' s-Transmittal Only) Date: 10/6/82 Trans.#: 2703 55703 CC#: REFERENCE: ~~__OHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-14--~ A-15" A-18-~ G-12J G-13-~ M-15 -~ N-12-" N-12 N-14 N-14 N-15 --' R-7 -~ R-8--~ DDNLL 7/27/82 #1 Dres 8800-9714 5" DDNLL 8/10/82 #1 Dres 9300-10135 5" Spinner 8/27/82 #1 GO 10600-11000 5" Spinner 8/29/82 #1 GO 9900-10250 5" DDNLL 7/20/82 #1 Dres 9750-10686 5" DDNLL 7/23/82 #1 DRes 8600-9418 5" TDT-M 8/15/82 ~1 Sch 8750-9596 5" DDNT,T, 7/30/82 ~1 Dres 9200-9997 5" Spinner 8/18/82 #1 GO 9550-9800 5" Spinner 8/16/82 . #1 GO 9459-9800 5" DDNLL 8/3/82 ..: ~1 Dres 9250-10146 5" TDT-M 8/14/82 "~ #1 Sch 9300-10329 5" TDT-M 8/12/82 #1 Sch 9450-10426 5" TDT-M 8/13/82 #1- Sch 10850-11455 5" ~(4/82) RECEIVED DATE ................ 19 Victoria Aldridge Development Geology Well Records TP1-5 SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON GETTY To: SFO/UNIT/STATE: (-Mar a tho n) MOBIL PHILLIPS STATE 0 BPAE (Tr, ans..'mitt, al Only.),, CENTRAL FILES(CC#'s-Transmittal Only) REFERENCE: 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 9/2/82 Trans.#: 2593 CC#: 55593 SOHIO CASED HOLE FINAL LOGS . ~-t~ollowing material is being, submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- , . A-14 A-9 A-23 G-i3 Spinner Spinner CCL/OR Spinner Spinner RECEIVED (4/82) DATE 8/03/82 #1 9250-9612 Otis 5" 8/13/82 #1 9250-9650 6tis 5" 7/11/82 #1 10400-11993 Dres 5" 7/24/82 #1 8850-9220 Dres 5" 7/21/82 #1 8950-9350 Dres 5" .Victoria Aldridge Development Geology Well Records TP 1-5 SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON 31 1 1 "C" S'~REET ANCHORAGE, ALASKA TELEPHONE (907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~o: SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CC#'s - Transmittal Only) REFERENCE: ' ~SO~IO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-12f Pressure Survey & BHPD 7/25/82 Dres. A-10' " " 7/31/82 GO A-11 " " 7/24/82 GO A-16 " " 7/24/82 GO A-17 " " 7/28/82 GO B-16 " " 7/27/82 GO H-8 " " 8/4/82 GO J-10 " " 8/13/82 GO Y-6 " " 8/11/82 GO N-15 Pressure Survey 8/10/82 GO R-3 " 8/6/82 Sch E-7 Pressure Survey & BHPD 7/23/82 Sch M-15~ Pressure Survey & BHPD 8/13/82 Camco A-18 - " " 8/14/82 Camco M-16- " " 8/15/82 Camco R-7 " " 8/7/82 Camco R-8 " " 8/11/82 Camco Y-11 " " 7/27/82 Camco /82) RECEIVED DATE h~O~(~ · --~,~D'~ Development Geology ~s Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON '~o: SFO/UNIT/STATE: GETTY (-Marathon) MOB IL PHILLIPS STATE ~ Bp~-~(Transmittal Only) _ CENTRAL FILES (CC#' 3111 "C" SIREET ANCHORAGE. ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 7/20/82 Trans.#: 1738 CC#: 49738 s - Transmittal Only) REFERENCE: //~.$~O FINAL DATA' 9RESSURE SURVEY DATA The following material 'is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-12 A-17 A-10 A-ii- A-16 A-9 G-13 E-8 M-12 M-9-~ M-10 ~- J-6 H-16 A-14 Pressure' .Analysis CAML~ 6/28/82 pressure Analysis CAMCO 6/28/82 Pressure Analysis CAMCO 6/30/82 Pressure Analysis CAMCO 7/2/82 Pressure Analysis CAMCO 6/27/82 Pressure Analysis ~ 6/26/82 Pressure Analysis CAMCO 6/27/82 Pressure Analysis CAMCO 7/3/82 Pressure .Survey & BHPD Sch 6/30/82 Pressure Analysis & BHPD CAMCO 7/4-6/82 Pressure Survey & BHPD Sch 6/26/82 Pressure Survey & BHPD GO 7/1/82 Pressure Survey & BHPD Sch 7/2/82 Pressure Survey GO 7/6/82 /82) RECEIVED DATE Victoria , Aldridge Development~.~~f Well Records SOHIO ALASKA PETROLEUM COMPANY July 13, 1982 3tll "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive ,- Anchorage, Alaska· 99501 Attention: Mr. C. V. Chatterton Gentlmen: Wells ~:12::and A-17 PBU Enclosed, in duplicate, are the following forms for the above-named wells. 1. Form 10-407, CompletiOn Report; 2.. Form 10-403, Sundry Notice and Reports on Wells; 3. Form.10-404, Monthly Report of Drilling and Workovers. GJP:JLH:ybr Enclosures cc: J. D. Hartz Geology Well File #17 Yo~~s ·very truly, Dlstrlct Field Englneer STATE Of ALASKA -'~, ALASKA~,,,_ AND.GAS CONSERVATION CC.._.,~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well - · · · . . OIL:~] GAS [] SUSPENDED [] ABANDQNED [] SERVICE I-]..: : , 2. Name of Operator 7. pe r~i~N ,ufJi:)e~ Sohio Alaska Petroleum Company - 3. Address 8. APl Number _ Pouch 6-612, Anchorage, Alaska 99502 50_029-20515 4. Location of well at surface 9. Unit or Lease Name 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 193' SNL, 1363' WEL, Sec. 35, TllN, RI3E, UPM A-12 (31-35-11-13) · At Total Depth 11. Field and Pool 101' NSL, 1403' WEL, Sec. 26, TllN! R13E, OPM Prudhoe Bay .5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 77.43' AMSL ADL 28286 · 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/14/80 10/30/80 11/4/80I feet MSLI One .17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost ~801 'MD9553 ' TVD 9754'MD9508 ' TV ~ES~ NO[] 2162 feet MD 2125' 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, DIL/BHCS, FDC/CNL, Gyroscopic survey · 23. CASING, LINER AND CEMENTING RECORD SETTING DEP'TH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , ?~"~n,,T~.m~]ate].Cond. Surface` '113, 36,, 8 cu.yds, concrete , 11 2/R" 72~ L-80 Surface 2677' 17 1/2'3720 cu.ft. Articset -~' '.~.8,, 47~ L'80 Surface . 8804' 12 ~l-/4'1210cu,~.t.-'.:class~z~.uc~ft.a~c.; ?# 29# L-80 8311' 9800' 8 1/2' 39~'cu'.~t. Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ' SIZE DEPTH SET (MDi' PACKER SET (MD) ' interval' size and number) MD ...... TVDs's. 4 1/2- 8373' 8248 ['rudhoe .Oil. Pool Top , 9087, 8.799'~,,~ ~.~... ,~. Bottom 9156 ' 8864 ! __26' ACID, FRACTURE, CEMENT SQUEEZE, ETC. / DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED - ' i ~ ~' .' '. '~" ' --" ' .. .,:?';"- '- ' 9087'-9106' BKB (8799-8817' TVDss) ".: -. -. 9123 '-9156' BKB (8833'8'8164' TVDss) : , : . .. - · .: .. ~ " . t% 3;- , ,, . ~" .~ :~ ~ -'? ', ' '~' . · 27. PRODUCTION TEST Date: First Production jUn~ 14, 1982 ','- :--I'Meth,°d °f Operati'°nF'~'Owing' (Fl°wing" gas lift"etc') ,, :,i.....~ '"- :. , .. , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE SIZE IGAS-OILRATIO .. : . · . TEST PERIOD .~. I Flow..Tubing Casing Pressure ' : "" ~' ; ' '" " '~ " ' CALC'ULATED I~'OIL'BBL . GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ~Press. "~'.4_,oURR~.E.~''~ -- .~ ,,. . ,, ~ . . 28. COP E DATA ' , . ' .; .. i': .~ - , , .-~_ : . , , . '.. : · : None .. , .- .. .:., ..,. .::. ~......:.,.... ~..,, .. jUL 1 51982 '.. "' ' ' ^t~sk~ 0il & 6as Cons. Commission '" Anch0rag"~ · . ~.et t Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "": : 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. ,, , BKB Subsea ,,, Sag River SST 8897' 8622' Shublik 8924 ' 8647' Ivishak 9008 ' 8725' 31. LIST OF ATTACHMENTS · B2. I hereby hat s true and correct to the best of my knowledge Signed ,/'/'~-~,~""'"~.J ~&~O(~, Tit,~District Field Date 7//3/Y~ ~G. J. ~P~isga Engineer~' , . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log On all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, Observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in .item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". STATE OF ALASKA ALASKA ~.,L AND GAS CONSERVATION CO',aMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL E] COMPLETED WELL~3 OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, Alaska 99502 4. Location of Well At Surface: 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 77.43' AMSL 6. Lease Designation and Serial No. ADL 28286 7. Permit No. 80-117 8. APl Number 50- 029-20515 9. Unit or Lease Name Prudhoe Bay .U~it 10. Well Number A-12 (31-35-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair~Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). The following intervals were performed June 14, 1-982, using Gearhart 3 1/8" carrier guns at 4 spf. A lUbricatOr was installed and tested to 3500 psi on all well work. 9087'-9106' BKB (Ref. BHCS/GR, 10/30/80) 9123'-9156' BKB '( . " ) An SSSV was set and tested in the BVN at 2162' RECEIVED J U L 1 5 i,9o82 Alaska 0il & Gas Cons. C0mrnissiun Anchorag9 14. I her ng is true and cOrrect to the best of my knowledge. Signed r.,/"/~.~J ~,~~ Title District Field Engineer The spac~el~w f~ ~mmission use %- conditions of Appro~l, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PERFORATING DATA - Well A-12 (31-35-11-1.3) June 12, 1982 June 14, 1982 June 26, 1982 June 28, 1982 June 29, 1982 Pressure tested tubing and inner annulus. Rigged up Gearhart and perforated the following intervals using'3 1/8" Carrier guns at 4 spf: 9087'-9106' BKB (Ref. BHCS/GR, 10/30/80) 9123'-9156' BKB~ ( " ) Put well on production. Shut well in to prepare for. static pressure survey. Ran static pressure/temperature survey at 8800' TVDss. set and tested SSSV in ball valve nipple at 2162~ Well oh production. ,,..% STATE OF ALASKA .-.., ALASKA~ ~ AND GAS CONSERVATION CC, }VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER 1 Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum ComDanv 80-117 3. Address ' ' 8. APl Number Pouch' 6-612. An~_h~r~_ A]~,~ qq~n9 5°-02q-2~K1K 4. Location of Well ' ' "- ' 9. Unit or Lease I~a-m~ at surface Prudhoe Bay Unit 10. Well No~ 11t6' SNL, 920' WEL, Sec. 35, TllN, R13E, UP, A-12 (31-35-11-13) 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation-and Serial No. Prudhoe Oil Pool KBE = 77.43' AMSL ADL 28286' For the Month of. June ,19 82 . ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling Problems, spud date, remarks : 13. Casing or liner run and quantities of cement, results of pressure tests . 14. Coring resume and brief description · 15. Logs run and depth where run , JUL ;i 5 11 6. DST data, perforating data, shows of H2S, miscellaneous data ~Jaska Oil & Gas Cons. C0mrnissR,n · See Attachment z!.nch0ra~? 17. I hereb~ c rtify that t oing is true and correct to the best of my knowledge. ~SIGNED NO TE--Re~p~rt on t~l form is required fo' each calendar month, regardless of the status of operations, and must be file4in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY August 3, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Co~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Wells A-I2, H-12, M-14, N-10, X-14, X-15 Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate the wells. ' sga ~ ~-~is~i~3t ~ld Engineer GJP:JLH:ja Enclosures CC: Well File ~17 S. R. Bundy J. D. Hartz Geology [ ECEIVED Al.~ska Oil & ~a~ Cons. Commission Anchorage STATE OF ALASKA ALASKA L.- AND GAS CONSERVATION CC,~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Sohio Alaska Petroleum Company 3. Address PouCh 6-612, Anchorage, Alaska 4. Location of Well At surface: 99502 920' WEL, 1116' SNL, Sec. 35, TllN, R13E, UPM 6. Lease Designation and Serial No. ADL 28286 5. Elevation in feet (indicate KB, DF, etc.) KBE = 77.43' AMSL 7. Permit No. 80-117 8. APl Number 50- 029-20515 9. Unit or Lease Name Prudhoe. Bay Unit 10. Well Number .A-12 (31v35-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during August/September, 1981 using Schlumberger 2 7/8" Hyperdc~e guns at 4 spf: 9087' -9106' BKB (Ref. BHCS/GR, 10/30/80) 9123' - 9156' BKB ( " ) * 9166' - 9198' BKB ( " ) * t© be shot only if initial perforations will not flow, A SSSVwill be set and tested in the ball valve nipple ca. 2000'. AUG --~ l~,i,.~ hereby~i Subsequent Worl~ Reportecl _ ABska Oil & Gas Cons. Commission on Fora No. ~ Dated ~/~/~ Anch0rag~ 14. i ng is true and correct to the best of my knowledge. - s~,.e~~~ J ~a~ T~t~District ~ield Engineer D.te Co.~iti;.; o* A,~. i~ Approved Copy Returned By Order of Approved by . DY [0~![ ~. S~]T~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ('-~'AN D GAS CONSERVATION C~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum ~ny 80-117 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well At surface: 99502' 920' WEL, 1116' SNL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 77.43' AMSL 12. I 6 . Lease Designation and Serial No. AD~, 28286 8. APl Number 50- 029-20515 9. Unit or Lease Name Prudhoe Bay,, Unit 10. Well Number A-12 . (31-35-11,13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate NatUre of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment !-'] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during August/September, 1981 using Schlumberger 2 7/8" Hyperdome guns at 4 spf: . 9087' - 9106' BKB (Ref. BHCS/GR, 10/30/80) 9123' - 9156' BKB ( " ) * 9166' - 9198' BKB ( " ) * to be shot only if initial perforations will not fl~, A SSSVwill be set and tested in the ball valve nipple ca. 2000'. :: le~:ha~~i~rueandc°rrectt°thebest°fmY kn°wledge' n Tit~e.District Field Engineer ' Co'~dit~S of 'Ap~ov~l, if any: i Approved Copy i Returned ' Approved by COMMISSIONER the Commission i Date ~/2/~/ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate January 29, 1981 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Reiley: We have received your letter of January 21, 1981 requesting the waiver of Rule 4(b) of Conservation Order No. 145 for the drilling of future wells on Pad "A". In this letter it was noted that during the drilling of the 17%" hole on the~.~~ Bay:-~Unit~_ _%A-~!2_ well there was no encounter of gas. This letter will advise you that the C~mmission has examined the evidence available and hereby waives the requirements of Rule 4(b) of Conservation Order 145 for the drilling of future wells from Pad "A" in the Prudhoe Bay Field. Yours very truly, Harry W. Kugler Commissioner HWK:be SOHIO ALASKA PETROLEUM COMPANY -- R~,:.7, I · ~.r '- ANCHORAGE, ALASKA 3 ~.';"~ :.~ '~' 4'~:~-~PH~NE (907)265-0000 .~-"~ ~OR~GE, ALASKA 99502 ~,: ~.~ ' ~ T .... ~e~ [5, [98 --1 ?ATTEC.J Alaska Oil & Gas Conservation Conm~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well A-12 (31-35-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of November, 1980. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer RECEIVEI) DEC ! 6 ]gSO Alaska 011 & Gas Oons. - STATE OF ALASKA " ALASK L AND GAS CONSERVATION C MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska PetroleUm Company 80-117 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well at surface 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 77.43' AMSL ADL 28286 8. APl Number 50_029-20515 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. A-12 (31-35-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool November For the Month of ,19,80 . 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at .month-end: 9801 ' Footage drilled: -0- 13. Casing or liner run and quantities of cement, results of pressure tests Ran 37 jts. 7" 29~ L-80 Buttress liner to 9800', cemented with 396 cu.ft. Class G cement. Tested liner to 3000. psi, okay. Ran 195 jts. 4 1/2" 12.6~ L-80 Buttress tubing to 8373'. Tested tubing to 3500 psi, okay. 14. Coring resume and brief description 15. Logs run and depth where run CBL/VDL/CCL/GR at 9754'. Gyroscopic survey at 9622'. .1 6. DST data, perforating data, shows of H2S, miscellaneous data Released rig at 1200 hours, November 4, 1980 RECEIVED DEC 1 6 1980 --: ....,o. uomrl]i&lioe Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TIT EDistrict Drilling EngineerD E ~- % ~ ~ . L ~ ~~ ~ _ ATE * NOTE--~---~eport on this form is required for eac-'~alendar month, regardless of-~~ ~ ~n~- must be filed in ~t~-~i~at~ w----~ the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed, Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY December !10, 1980 3111 'C" STREE ANCHORAGE, ALA TELEPHONE (907) 26! MAIL: POUCH 6-6 ANCHORAGE, ALASK.~ CONFIDENTIAl Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well A-12 (31-35-11-13) in duplicate, is Form 10-407, Completion Report, for Enclosed, the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. RHR: ja Enclosures cc: Well File ~17 Geology Yours very truly, RECEIVED DEC 1 0 1980 Alaska 011 & Gas Cons. Commission Anchorage / ~ STATE OF ALASKA m 0 I I G t R ~ t ALASKAUtL AND GAS CONSERVATION CO~:~_,MISSION WELL COMPLETION, OR'RECOMPLETION REPORT AND LOG - i. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator' 7'i Permit Number Sohio Alaska Petroleum Company 80-117 3. Address 8. APl Number Pouch ....... 6-612, Anchorage, Alaska 99502 50-029-20515. 4. Location of well at surface ~. Unit or Lease Name 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval lO__umber" ' 193' SNL, 1363' WEL, Sec. 35, Ti1N, R13E, UPM ~-12¢.331-35-11-13) At Total Depth T'I~PI'eld and Pool 101' NSL, 1403' WEL, Sec. 26, TllN, R13E, UPM Prudhoe Bay 5."Elevation in feet (indicate KI~, DF, etc.) I 6. Lease Designation an'd Serial No. Prudhoe Oil Pool KBE = 77.43' AMSL I ADL 28286 , 12. Date SPudded 13. Date T.D. Reached 14. Date Comp., SNap. or Aband. I 15. Wat'e~'Depth, if offshore 116. No. of Completions :10/14/80 10/30/80 11/4/80 I -;:,! feetMSL I O~e 17. T~tal Depth'(MD+TVD) 18. PlugBacNDepth(MD+TVD) 19. DirectionalSurvey I 20"Depthwh'eresssVset I 21. Thickness of Permafro~t 9801'MD 9553.' TVD 9754'MD. 9508' TVD YES~ NO[]I 2162 feetMD I 21.25' 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, DIL/BHCS, FDC/CNL, Gyroscopic survey , 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD cASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED · , 20"x30" insu!a(e~[ Conduct~)rsurfac( 113"" .36" 8 c~.¥~s, concrete. 3/ ,, . 13 . 8... 72~ L-80 Surface 2677' 17½" 3720 cu. ft Arcticse~- 9 5/8" 47~ L-80 Surface. 8804'. 12¼" 1210 cu~ ft. Class G. 130cu. ft.Arctics~ 7'.' 295 L-80 8311' 9800' 8½" 396 cu. ft. 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) PACK:ER S'ET (~D) None .4½" 8373' 8248' 26'.' ACID, FRACTURE, CEMENT SaUEEZE, ETC. ' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USEd . ,, ,, · , . 27. PRODUCTION TEST ..... Date'First Production . '~" I Method of Operation (FIowing,.gas lift, etc.) · , Date of Test Hours Tested PRODUCTION FOR gl L~BBL GAS-M~;F wATER-BBL CHOKE SIZE GAs-OIL RATIO . TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL G~AS-MCF' W~ATER-BBL OIL GRAVITY-APl (co~'r) · Press. -, - 24-HOUR.,RATE ~'' ' · ' ' · . , 28. CORE DA-FA , , Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. " "" RECEIVED None DEC 1 0 1980 " :: ' ' Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ _ 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, NAME MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST 8897" 8622 '- Shublik 8924 ' 8647 Ivishak 90.08" 8725 ' 31. LIST OF ATTACHMENTS Well History r Well Togs, · Direction~,] S]n-veyS 32. I hereby certify that the foregoing is true and correct to the best (~f my knowledge S g,~ R9' 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. Irem 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 · IndiCatewhether 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:' Me~h°d of.Operation: Flowing, Gas Lift, Rod pump, Hydraulic Pump, Submersible, Water In- jection, Gas: Injection, Shut-in, Other-explain. Item 28: If no cores takenl indicate ,'none". Form 10-407 WEI.T. A-12 (31-35-11'13) WELL HISTORY Spudded well at 1100 hours October 4, 1980. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2677'. Cemented with 3720 cu. ft. Arctic Set Cement. Tested casing to 3000 psi, ok. Drilled out to 2677', ran leak-off test to 0.76 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8804'. Ran 226 jts. 9 5/8" 47# L-80 Buttress casing to 8802'. C~ted in tw~ stages: First stage with 1210 cu. ft. Class G cement; second stage through D. V. packer with 130 cu. ft. Arctic Set I cement preceded by Arctic Pack. Tested casing to 3000 psi, ok. Drilled to 8845', performed formation competency test to 0.7 psi/ft, gradient. ~Directionally drilled 8 1/2" hole to 9801'. Ran open hole logs. Ran 37 jts. 7" 29# L-80 Buttress liner to 9800', c~ted with 396 cu. ft. Class G cement. Cleaned out to the top of the liner at 8311', tested lap to 3000 psi. Cleaned .out liner to'79757', _ Tested liner to.3000 psi, ok. Ran CBL. Ran 195 jts. 4 1/2" 12.6# L-80 Buttress tubing to 8373'. Landed tubing with ball valve at 2162'. Installed and tested tree. Displaced tubing to diesel, set packer at 8248'.. Tested tubing to 3500 psi, ok. Released rig at 1200 hours November 4, 1980. d. A. Fouch~ President November-12, 1980 Mr. Gary Plisga Sohio Alaska Petroleum Company 3111.C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16700 Well---A-t2-(SEC35 TllN R13E) Prudhoe Bay Field North Slope, Alaska Date of Survey: November 7, 1980 Operator: John Samec Dear Mr. Plisga: Please find enclosed the "Original!' and seventeen (17) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. ' Thank you for giving us this opportunity to be of service. Yours very truly, r~S/kc SPERRY-SUN, INC. Ken BroUssard District Manager Enclosures COI, iI:ID£NTIAL EC iV D DEc ! 0 I980 gtaska Oil & Gas Cons. Commission Anchora~o SPERRY-SUN WELL SU-~VEYING COMPANY AN CHORAGE~ ALASKA N OV'EMBE~.R__G · 198 0 A-12 SEC35·Tll. N,~R13E COMPUTATION DATE BOSS GYROSCOPIC SURVEY PRUDHOE BAY /~ i' % ',~;'* NOVEMBER 7· 19R0 ,JOB NUMBER BOSS-16700 /"' '-,~ ~/-j 6: .... .'.":.': .' OPER A TO R'S AME C .... :.~:: ~.' ' . ' ' ' - . '~..:'::. ';:':-.":, ../ :<.: .'.: / :.,," · ~'::.':..~:~ ~::': :.:'.' :'.::" .' . :".'.":h:':T': ': :.":: ............... "" oU sE ~p~-~ G ' MEASURED VERTICAL VERTICAL INCLINATIQN DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 1'00 100,00 .'22'i.57:. -' :' i0' <22 "'"'!$ 62,'59 E '200 199.99 ' '. ::i22"56 .... ,0....4~9:.... "$:.23'.39' E 300 299.99 222.56 0 31 S 40.60 E ~00 399.98 322,55 0 51 S 25. 0 ~00 ..... ~'99. ~ 700 699.96: 622.53 0 39 S 47.10 E ,22 .- ;,39 .' S:' 3.86 ..E .ql 3,82 S ~.,74 E '5030 I 2q 00':' 2399.'83.-. 23220q0 0 25.00'. - '2~99.-82". ...2~22039 O ~7 'S:.76;,'9 E 2600:."' 25-99,80.':' ~ .2522,3'7 I ~ .:~S _21,30 E , 1900 1899,88 1822045 2100 2099.86 2022.~ 2200 21~9.85 2122.~2 2300 2299.8~ 2222.~1 54 $ 27.69 E .79 -' 1'3..~3:7 S::. 11,05.'E ',:": ~.~=..:-;-,----:.s_.:.-5~;5_/o.5, .................... .,..~. ~"'~:',"'~ ._ .. L~:-'~__6'~s::~ , Q3 S 48,19 E -17 15.06 S 12,66 E -18.67 ~8 S 52.19 E .10 15.91 S 13.69 E -19.8~ 51 S q9o50 E .136 16.83 S lq.81 E -21.10 5.7 -.:'$'.~-~=2-~'- E ..<1'2 - ~~;-§'9:-S : 15'..98::'E?.:;... :..:..~. -22.,.52 2700 2800 290~ 3000:. 2699079 2622-36 0 53 S 23030 E 2799078 2722035 0 42 S 25,10 E 2899,77 2822..o~ ~ ............ .0. ..... .3.5_ .......... S_.~_O..,...5..p.. E 2999.77 2922-3~ 0 28 -S. ':..16 ,.69 E : · 18 21.26 S .19 22.53 S · 20 23.~7 S :..-25 24,26 S . : ,. -'.'. ':::.'.. 17'25" £;:!::-,.: .... -23,69 ... - . :- !.~::':.~.5...:..E..:.- - -25.02 18.90 E -26.73 19.~,7 E -28.12 20.06 £ -29.21 900 R99.95 822.52 0 43 S qOolO E .3~ 5.08 S 6.5~ E -7.13 1000 999.9~ 922,51 0 22 N 720q0 E .67 5.~6 S 7.25 E -7o75 .1_1_0_0_.____1.Qi.,9._..,~_ ...... 1..0.22.,.5.1 ................... 0 ._ 1.6 ............ S....!.7....,.. 0._£ ................ -15 ......... '5.38 S 7.8{) E -?.88 1200 11-99.9~+. 1.122-51 0 34 S 26-,50 E .50 5-84 S 8'.27 E -8.47 1301) 1299.92. 1222.~9 I 9 S 0,'30. E .7§ 7.29.S 8.50 E -9.91 __~q..o:L'~)::~?-9-:I_:.:, ...... L)2~?-..):) .................. q ) .3. ............ S.,.':~5..,*:Q~:._E. .................. ..70~ ......... _~ .: .8:~:.7,:_5-s~ ......... 1500 1~99o91 11220~8 0 3q S 5060 E 020 9,69 S 8.97 E -12.32 1600 1599.90 1522.~7 0 50 S ~1.80 E .26 1.0.92 S 9.09 E _._.,LT_Q_O _.t..6..9__9__,_8_9 .... 1_6.22,,..~.6 .............. O ..~_8 ..... .S_3!.,,,~.O E ........ .3_9.. ......... .!.2..,_1..~ S 9o~4 E ~.14~.'_,../~._. . . A-12 SEC35,~ TllN,,R13E Pt~UDHOE BAY COMPUTATION DATE BOSS NOVEHBER 7~ 1980 ,JOB GYROSCOPIC SURVEY NUMBER BOSS-16700 MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IOO NORTH/SOUTH EAST/WEST SECTION ~200 31~'76 3122.33 '."" 0 ~0 S' 2.29 W .28". ' '26'3~ S 3~00 3399.75 3322.32 0 16 S 51.30 E .1~ 27.12 S 21.63 E 3500 3~99.75 3~22.32 ~ 2~ S ~9.80 E .~3 27.50 S 22.08 E -33.70 3700 3699.'7~.: 0 30 $ 2'*~0 E .0~ '29.0~ S. -35.29 3800 379'9.7~ :':-.~ 722.. ~ 1 O [~ S. ~.8, e.~O.' Z est . 29e~8 4000 3999.73 3922.30 0 37 S 9.10 E .70 4100 ~099.73 4022.30 0 2~ S 9.39 E' .22 ........... ~2,..0_0 ...... ~,1~.~.7.L___~]22,.._3.0. ............. 0 ..... 28 .............. ~.23_,._...I:L..E: ....................... ,.1 _3- 4300 4299.72 .' ""'::'4222':' 2:9 0 3~ $ 'q::,lO":.W 4400 4399.72 432'2,29 0 ~7 S ~,~9.' W. .22 4600 ~599.70 4.522,27 0 18 S 11,19 E · ,700 4699,70 4622°27 0 49 S 21~79 W ,59 30.'40 S 23.65 E -36.97 31.28 S 23.80 E "37o8~ '32...89; ':S 3'4.0 7 S 24 36.26 S 23.85 E 37.18 S 23.64 E 'SOOO:. 4999,68 "4922*"25 ' .' 0 10 .S 6:9,80. E ,50 '-.-.".".".:'1:3'9,91 S ..; 22."'95"::.'E"i':;::'' 5~00 5~.~ 5~2~.~5 0 ~0 s ~.50 E .~ ~0.62 s 2~..~0 5300 529~.67 5222.2~ 0 12 S 11.19 E .15 ~.09 S 23.~ E 5~00 5399.67 5322.2~ 0 27 S 5.~_~_..[ ...................... .26 ~1.66 S 23.51 E 5500 5~99.66 5'~22,23 - .: 1- ~6- N ~7'39 ~ 1.65 5800 5798.2~ 5720.81 9 8 N 21.89 W 2.7~. 17.59 S 11.39 E 5900 5896.6~ 5819.21 11 15 N 27.79 ~ 2.36 1.58 S ~.88 E ~000 __59~ 59~~ 1~ 38 N 36.79 ~ 3.06 ~6.50 N 7.7~ ' ':' '39 -40.53 ......... =..El-'- _6 9 ..... -~3.27 '~5.'56 -45'88 . .. -46.38 -~'6.84 -47.39 1Ro19 -46.77 -42.70 .-_34.07 -20.55 -2.90 ANCHORAGE~ ALASKA A-12 SEC359T11N~R13E COMPUTATION DATE PRUDHOE BAY NOVEMBER 79 1980 MEASURED VERTICAL VERTICAL INCLINATION DI RECTZeN DEPTH DEPTH DEPTH DEG MIN DEGREES 6i:86 BOSS GYROSCOPIC SURVEY ,.JOB NUMBER BOSS-16700 KELLY BUSHZNG ELEV. = SEVERITY RECTANGULAR DEG/IO0 NORTH/SOUTH 6500 6~68.77 6391.3~ 21 q5 N 37.29 i,t .73 138..01 N 6600 6§61,75 6~8~,32 21 27 N 37,20 Id ,30 167,31 N 77 .~3 FT. 7700 7600.79 7523,36 7800 7695.91 7618.~8 8600:";:. "7883.98 7806-55 810'0' ~i: ~ 7975.82 7898',39 VERTICAL SECTION L COORDINATES EA ST/kIEST 105.62 R 127.90 Id Id 6900.- 68:42.,58 ;':;':./'6765.~;1:5-' . 19 4.0 N 37.10' 7100 7031.21 6953.78 19 ~9 N ]5.79 W .33 30~.93 N 230.95 7200 7125.61 70~8.18 19 I2 N 3~.~0 W. .~2 331.89 N 2~9.97 7~00":.. '7315'0'7'- '.:.:.~7237,-6~ 18 I N 30,50 ~ '~9 .. ~85'85 N 7500-:::.' 7~1'0,2~ '7332,78 17 ~8 N 28'70 ~ ,60 ~12,60 N 299,69 17 ~7 N 25,89 ~ ,~ ~66,57 N 327.37 18 7 N 23,39 ~ ,8~ ~94,60 N 3~0.22 ~2 10 N 18,89 W 2,77 557,89 N 3G~.'.79 69 -'20 9'i R300 8155.70 8078.27 26 7 N 12.50 84.00 824.5.~7 8168.2q 25 3R N 11.8':) . . _ RS~_Q ..... 8_3 3,~. .,&.9_5 ........ ~8,~.5_8,_._.5_~. 25 17 N 10.89 167,22 202,67 368 q00.65 4'32.4.6 463,54t 8900 8702'06 8624..63 21 4.1 N 8-70 t,I 1.3A, 924.,,11. N ~4.,0.70 I,i 1021o{{8 9000 8795.32 8717.89 20 :56 N 9. 0 Id 1.09. 959,76 N qq6.25 t/ 1056,67 .91_.~0 .~- 8889,09 . 8811,._.6..6 ............ 2.0. ............ 3._ ........ ..N. .... .9..._,.2.0..!!{ ........... ,55 994.,07 N ~51,74t Id 1090,59 .. 9200 ..' 8983° 13.. 8905- 7:0 ' 19 1123,78 - .. :... · . · , . , : . , .. .. .... , .. .:" . . 2q 2q N !6, O. I,I 2,52 595,60 N 76 ":: 692,4.7 637'1 .7 .71 680.:35 N 397.71 g 779,03 · 55 723.01 N 4.06.9~ ~/ 822-09 · 55 '3'65,16 N 4.15.~4. g 86~.~1 2 84. ,~.9 g:.. 5~.16 554'.38 585.17 617,4.' A-12 SEC35,mTllNgR13E PRUDHOE BAY TRUE "~£'a S URED VERTICAL VERTICAL DEPTH DEPTH DEPTH .~P-"~'RRY'SU-~ idELL AGE 4 ' ' ANCHORAGE9 A'LASK'A :": '- ''''¥: ';"::: CONPUTAT[O~ DATE BOSS GYROSCOPIC SURVEY NOVERBER 7e 1980 dOB NUHBER BOSS'16700 -- ....... ~.-.~.~.~ ........................................................... ~ELL.~BU~.~_ ELEV_.. ':" '""' "~' ' :'?' ':'":':': :: :'":'":::' ' 0 ": :OPER AT.O R'~ .:,: .,::..; ..- : - .~ :,::::......-.. ::..:.?: .: ?.::/:.: . .. .. ~.;.-....;.{:' >::. :?: · ...... D G LEG .. :..:....:.~j.:.~;.?:~::..~.T~TAE~::.:~.`J:.:/~::~:~::::...~:;~.`~.~.:~:~:~.:~:·. ' ]NCL]NATZON DZRECTZON SEVERZTY RECTANGULAR COORDINATES VERTZCAL DEG HZN DEGREES DEG/IO0 NORTH/SOUTH EAST/UEST SECTZON ]9. '0: N 7'79 14 .15 1 092"89"N 9.lq 9400 : ; 9171-95 9094-52 96013 9361./+9 9284.06 18 11 N 7,60 Id .46. 1156,19 N 474o69 Id 1249.75'~ 96513 9409.04 9331,61 17 52 N 3'.39 Id °65 11.71.53 N 476,71 Id 1264.76 ,.-- 9,OJ~.L .... . ~ 5_5. . 2. _, .7_ .5_ . ~.~5.~ 3. 2._ 17 5 2 N L OH R.I:ZONTAL D :I SP LA CE PIE NT. . =': 1:309.67 FEET' __~ .......... ~...;~. :Q::-:.: .'. ,......~: ::.?.;.,~:... ' . .- . THE. CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DINEN$IONAL RADIUS OF CURVATURE METHOD. ..-. - : ...... WELL ING "' . ANCHORAGE, ALASKA ~-12 SEC35~TllN,~R13E COMPUTATION DATE :'I~UDHOE BAY NOVEMBER 7~ 1980 ,JOB NUHBER BOSS-16700 KELLY BU~HIN$ ELEV ~ FT. TRUE SUB-SEA TOTAL DEPTH DEPTH? -: DEPTH NORTH/SOUTH 'EAST/~EST DIFFERENCE CORRECTION :.. 1000 999.9~ 922.51 5.4,6 $ 7.25 E .06 .06 ' 2000 1999.87 1922.~,4, 1~.36 S 11.80 E .13 .07 ~ooo .: ~7',~ ~:::0'~':~'~ .... 2~*eS:',.",E ..... '" . .0 :"'"':~:: 5000 ,- ~9'9.9'68 ::~:;~.'.'~ ~922,25:" 22'95 E . .~6 r~.:"~:~ ..' ',:'~ .... 7000 6956.85 6859.4,2 278.27 N 211.37 M 6.3.15 57.~ Bl}O0 7883.98 7806.55 557.89 N 36q. 79 U 116.02 52.86 A. NCHORAGEe ALASKA A-12 SEC:55,~T 11N 9 R 13E PR UDHOE BAY COMPUTATION DATE NOVEMBER 7,~ 1980 dOB NUMBER BOSS-1G700 OF TRUE SUB-SEA TOTAL M_£.~ SU..B;.E_D__ _ V~_RT_I~AL '_Y_g_g,!!.C..A.L_ ........ ~R_E_C_.T~A,.N._ERkAE .... C.O.O..gD.!N A TBS DEPTH . DEP.TH''' · ?T DEPTH :'EAST/WEST - 77 77.43 0.00 .08 S .16 E 177 177.~+3 100.00 .G6 S .'73 E 37.7 3 7'7.' ~3 300'00 S 1.92 E 477 ~77o~+3 4'00'00 ....... :'3.,.59 S 2. GG E 677 677.43 600.00 3.6/+ $ A, o55 E 777 777.43 700.00 A..52 S 5.~+3 E 87_7 877. ~3 ~Q..~.~O..O_ ~ .86 S 6.36 E 977 977.~3 900.00 ,~,:.,-5~51 S 7.11 E ...-:.:~ MD-TVD D,I' .00 .00 *~03 .0~ · 05 6, °06 .00 .00 1.077 1077.43 1000.00 5.57 S 7'69 E _' .... . :_'1_~ 7_7..:.~.?.:.' ':.'_.. 'Ji:.7:,71,.A~_:,. .... '._!.~ 0..0 ,.0. 0..:_:.~. ..: ...... :.: '__..57.6.~..~.. S ' .... $. :~z.7. :.'.E 1277 1277.~+3 1200.00 6.84S 8.,~9 E .07 .01 1377 1377.~3 1300.00 8.55 S 8.62 E .09 °02 ' 1 ~ 77 ._~...~_~. ...... 1_/+_ 0.0.,..0.0. ........... 9 · ~ 6 S .8 · 95 E .......... · _6_9_ ......... ~.0_.0_ ~-- 1577:,: .1577-~+'3 1500.00 10.60 S 9.06 E L 1677''I- 1677.~3 160{2.00 '11.92 S 9°31 E oll °.01 ANCHORAGE 9 ALASKA ~"~.'~.:.~ ': I CO~PUT~T[O~ NOVEMBER 7~ 1~80 dOB NUMBER BOSS-16700 -12 SEC359TllN,~R13E RUDHOE BAY K__[ L L, ~RU_S_I:IJL~NA_E_kEY, OP ERATOR,'SA. HE TRUE SUB-SEA TOTAL [./t,~____.Y. Eg.T..L,CAJ.,. _V..5,B.T. IJ;.~.L ..... _R...E,~T_..AN.~P..L~A ...... .~.Q..O. BQ.IN..A !,ES.. EPTH ' D E P. Ti~!':;~...' - ..... :':.:"~." DE~'T H N 0 RT.H/SO.U'T:'H EAsT/WEST 1977 1977.A3 1900.00 1%o2:5 S 11.~2 E o15 o01 2077 2077.a~3 2000.00 1~o87 S 12.~.§ E .1a, .01 21_7 7 ....... ~1_?. 7~_~ .......... 21 I).0.,.0.0 ..kS..,,..?. LB ............... 1. :5. ,. ~ ~ _.. · -2277 '" 22 77';' ~ 3:, ".i' . ::::' 2200. lie ~ 1'6',61 S 14.56 E 2377 2577o~3 2300.00 17°63 S 15.7 2577 2577.zt3 2500°00 19.29 S 18.10 E .I9 .01 2.677 2677.~3 2600.00 20.9A S 18o7G E .21 '.02 28'77 2l:I77'~.3 2800'-00 ' 3177 3177.~.3 31O0.00 26.08 S 21.05 E .2~. 3277 3277.~3 3200.00 26o9~ S 21.13 E .25 ___... ~ ~ 7.7. ....... ~.7..7..,~.~ .... ~_~.Q~,.O._O ................. ~7_.,.~6._~ ......... ~A-..5~__g .......... · 2 ~ 3q77~;::'::''3~77..~3 3~00.00 '¥:27'~3.9 S ' 21. gG"E . . .25 3577.-:.~-' 35'.77' ~3 3500.00 27.., S 2.2:' 39 E .25 .01 .00 ALASKA COMPUTA1 NOVEMBER 1980 ,JOB NUMBER BOSS'16700 KELLY BUSHING ELEV. = 77,q3 FT. DEPTH TRUE DE SUB-SEA 5778 5777.q3 5700.00 5880 5877.'3 5800.00 ~085 6077~qi3-'''' &O00'O0 1' 6177 6100,00 6q01 6377.q3 6300,00 6509 6q77.~3 6q. O0,O0 ~ ...........E5. Z,7_,.~3 ........... 65.00.0,.0 .... TOTAL CTANGU AR COORDINATES MD- C 20.59 S 12.60 E 1,51 .80 4,9'7 S 5.66 E 2,99 1.47 :'33.26 N 2'1,08 W .{..8-~A . 3.20 55,59 N 39.89 W., , -,,:I2'63 lq0.75 N 107.72 W 31,89 1..~,2- 22.,,N, .................. 1,3..,!,~,.6A_..W ' 39 · ~ 2 7.5 3 672-q 6677oq3 6600,00 ' ' '-..203,03 N 15~,,73 W ~6,58 7,16 6830 6777.43 67'00,00 232.8q N 177'13 id 53.51 6-73 . . 71~8 7077.~ 7000.00 318.09 N 2~0~0' W 71.5Q 5.97 7360"::. 7277.~3 7200.00 375.30 N 2.78,2.7 W 82,99 5.57 :',':-... 7~65~:" 7377,q3 7300.00 q03..36 N 29q.63 W 86.1~' 5-1q ::~'.' .': - AN CHORA GE,~'. A L ASK A .:.. ~-12 SEC3~,T[1N,RI3E CONPUTATION DATE ~RUDHOE BAY NOVEMBER 7, 1980 dOB NUHBER BOSS-16700 OPER ATOR-S,AHEC ._,:I;~.T,g. gBO. L~A IgP.,.~A.L.UE s .F.C~. EVE N 1 O0 ..... FE.E?.~.,~.F......S:UB.~.SEA..DgP ~.H ..................... .., :..:..:.... .......... . ...... TRUE SUB-SEA TOTAL ~_S_U.R_EL_.._V..EB.~CJL__VERJ. !.C ~.L .... B.E C I A N G UL ~ R.. ...... C 0 0 R D IN. A.TE S........ ~D..r..).Y~.,_ DEPTH D£PT'H ' DEPTH.'.'.' '": NORTH/SOUTH EAST/WEST 'DIFFERENCE XE.E.T_I_C AL CORRECT TON 3877 3877.43 3800.00 29.88 S 23.05 E .26 .00 :3977 3977.~3 :3900°00 30.16 S 23.62 E .27 .00 _ A ~ .......... ~~~ ....... ~.O.~..O_,..RO ...................... 5.~.1.2_.~ .............. 2.3,.17_E _,.2_Z ........ ~.277 ~277-.~3..'.'"'.'::'.".:~:'.~ 32.G7 S..:.~.:.'2"~.'16.E ... ....~.~2:~ '.':~.,7,.',L:.~,.- qq77 q~+77.~3 ~OO.O0 35.10 S 23.92 E ~577 ~577.q3 ~500.00 36.1~ S 23.83 E _ q~7_ _E6..~7_,.~ ....... ~_6_.0~..,..~ Q ............... ~. 6., .8.8.....S ............. ~,~ 5_.. E q877 .... q877~q'3 ~800'00".' 39,17 S -22',75 E ....... ~.~-~'..-:~.:;:':__.-~:~.7]..,.~.[._,. '_~.~.o.~ ;,A~ '~ :':,.....:. ~.., ..... ..... ~..~ ,.' ~.? ...s .............. __.."~ '.~:~. ~.:,' .~ ~.....g .... 5077 5077.q3 5000,00 ~0,06 S 23,17 E 5~77 5177.~3 5[00.00 ~O.q9 S 23,39 E ...... 52.7~ 5~77 5577.~ 5377,q3 5~77"-'. 5q77,~3 ._ 5577~.":.~ "- 5577,~3 '5300.00 Al.qR S 2.3. q9 E .33 '0'0 5ebO.O0 ~1.64 S 23.09 E. .3q '*01 s5o. O..,AO. ....... : ................. ~.?.._O.,S.....S ........... ?.:O-..~S.._.E. .................... .-.3.~ ............... '. .,..0.7 AN CHORAGE,e ALASKA -12 SEC35~TllN~R13E COMPUTATION DATE RUDHO£ BAY NOVEMBER 7,~ 1980 :LA_ $~A__ . : .. ............................................ _[.NT.~.R_p_~ ..L..~:T_E..~ :./V'...A...L..~..E..$ ......F...O.R- ....If: V.~.~.....!.:..0. 0 ...... F..E'..E.?,...._O...~.,..~. dOB NUMBER BOSS-16700 !EASURED )EPTH 7675 7780 7886 TRUE SUB-SEA TOTAL VERTICAL VERTICAL, RECTANGULAR COORDINATES MD-TVL !'6f:i~:--- ....... 6'~i~'~i:i' ......... ~:if :~ ::fi~'TSci.'~ f i~~ .......... f~'~: f Fi~' ~:'f ........ 7677.43 7600.00 q89.05 N 337.82 W 103.12 7777.43 7700.00 520.12 N 350.83 W 108.65 VERTICAL CORRECT 5.08 5.53 810'1 '8212 '.' 8077.43 8545 8655 8765 8873 R980 9087 9193 9299 9405 9511 8277.43 8200.00 737.92 N ~10.08 W 157.79 8377.43 830'0.00 78~.38 N qi9.I1 W 8477.43 ..... ~.0..0.~.0~ 829,~7 N ~26,63 W I 8 :8577'.q3 8500"'0.0' :"?' ]:: ":: 87:2,99 N 8677.~3- 8600,0.0' 9'I. 4.~3 N ~39',22..W 8977,~3 8900,00 1025,62 N ~56,8~ ~ 216,51 9177.~S 9i00.00 109~,76 ~ ~66.67 W 228.36 9277.q3 9200.00 1128.49 N ~71,08 W 233.99 11.03 10,.63 9.95 6,.70 6.35 6.0.9_ ...... . 5'81 5'63 __5p36 1980 77.q3 FT. AN CHORAGE,~ ALASKA · DATE, OF' Su'R'VEY. NOvE'MBER: £O~,PUTATION DATE NOVEHBER 7, 1980 ,JOB NUMBER BOSS-16700 KELLY BUSHING ELEV. = TRUE SUB-SEA TOTAL )'EPTH 981)1 9552.75 94,75°32 1217.q8 N ~82.68 W 2A8o25 3.82 THE NEAREST 20: FOOT ~,D ('FRO.~-.:.RADiUS:i~'-:OF C.URYATURE) GREAT LAND DIRE;CTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY pan nan Al AC:gA LOCATION AL- 10-80 D31 Single Shot 11-5-80 JOB NUMBER TYPE SURVEY -"DATE NAR'~ ............ " ............................. : TI I'~L-E=''= ...................... S'I GNATURE" ' 2700 980! -DEPTH INTERNAL ................ FRO~I* ......................... TO .................... 10-15-80 DATES' SURVEY~ WAS- ~TAKEN''' ~'''~ FROM ............... 10-30-80 ...... Li ~TO~ THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are-held-im~ strietest confidence. Additional copies of your survey report can bemade from theOriginal by any blueprint company. RECEIVED DEC! 0 ]980 ~laska Oil & Gas Cons. Commission Anchorage MAGNETIC' .SINGLE' :SHOT; SURVEY'.~' ~.:'.:': RADIUS OF CURVATURE HETHO,D OF CONPUTATION COI~TEO-FOR¥ . ALL CALCULATIOHS PERFORMED BY :[; $ M ELEcTRON~'C COMPUTER DEPTH ANGLE O Pt: DEPTH SEA DIREC ' DEG e: STANCE.: :' :. ANGLE': -RSSU~'ED-VERT'IC'~L--TO-2?O'O, 2700 0 0 2700,00 2622.57 N O.OOE -~32'0'6 ...... 0'15 3-Z05';99 ..... -3-I:28;56 .... 'S3Z'~OOE 373~ 0 15 3733,99 3656,56 S14,.OOE i ~451 I 0 4450,9~ 4373,51 S38-00E '5500-0 1~ .... 5~99~87 ....... 565~ · 30 5657,70 5580,27 N28,00~ 599~ 13 ~0 5988,23 5910,80 0,00 S 0,00 W 0,00 $ 0 0 O. ~ 0,000 7,71 $ 17,72 E 19,32 S 66 28 11 E 2,72} 38,06 N 7,6~ ~ 38e83 N 11 22 gZ ~ 2,687 6195 16 0 6183.~9 6106.06 N39.00~ 79.7~ N 38.11 ~ 88,38 N 25 6319 18 ~5 6301,82 622~,39 N39.00W 108,~1 N: 61',~2 W. 12~,6g N 29 30 6~'2 2Z- 30 ..... ~'~T~---6~'g'~ST ...... ~'~ ...... I~'~-~"~-~-~'*--~---~- ~6'6'~6Z--~-~-'-'~-~'~*"~ 66~ 22 0 6604.92 6527.~9 N35,00W 201e79 N 132,28 · 241~29 .N 33 1~ 43 ~ 0,32~ 237, 6862 20 0 6808~3 6731.00 N35.00~ 265.79 N 177.08 ~ 319,38 N &92 ~-'ZO ....-0 ....... 686T~'6~ ......6~'~ ..... ~0~;' -. 28~ 33-*'R~ ......I89'~-~~'~0'~9:~~~-q:~'--~'--':-0'~'~ 7073 19 30 7006 93 ~929.50 N3S.O0~ 32~,0~ N 218.6~ ~'-. ~'-' 390,91 ~ :.: .:: ..." L' _ 4' *: ...... DEPTH Ol .,%TANC ANGi D£G/iOOFT 8339 26 8§91 25' 0 "8&2 .. ~ ~80I 18 15 954~*':18 9467,75 TRUE DEPTH e77 ................... 9'77' 1077 11: .............. 12: t377 177' 277. ?!: 200 777. ,' 0 877. 177 7 ...................... ].:'877 .................. , ..... I'8 1977 1977. 1900 0 2077 2077. 2000 0 2277 2277. ~... 22 2377 2377''' '~' 2300:" '.'" 0 2~77 ....................... 2'A.775- ..... 2zi*O0*' ........ 0 ...................... : .............. 0 2.577 2577- 2.500 0 0 2677 2677,, 2600 0 0 2777 ....... i ............... 277'7 ~' ...... 2700 .... ~-'0: ........................ O' 2877 2877. 2800 0 0 2977 2977. 2900 '0 0 3077 .................... 3077g- --30'00 3177 3177. :~100 0 0 3277 3277. 3200 0 0 ..................... 3377 ............... 3-3'77 ~ 3~+77 3477. 3~00 0 0 3.577 3577, ', 3500 0 0 0 0 ~0o 0.00 $ 0.00 it- TRUE ~ : 3677 3.777 . . 3677. 3600 3777~ 3700 0 0 0 0 1,64 $ 4277 4377 a277. 4200 4377' 450'0 7',82 ~87~ ~978 5278 5378 5~7~ 5578 5~7~ 5778 5880 4877. 4800 4977, 4900 5477. 5400 5577. 5500 5777. 5700 5877. 5800 0 0 0 0 0 0 0 0 5982 ....................... 5977~~ ........ 6085 6077~ 6189 6177. 0 O 2 2 6000 7 3 6100 11 4 629'3 ....................... 6277'~ ......... 6200 ......... X'5 .............................. ~- 6:399 637.7. 630,0 21 6 6507 6477e 6400 29 8 12.85 S isl. 13.24 $ 16,87 E .............. 661 &' ............... 65-77~ ......... 6500 ........... 36 ............................. '7 .............................. -~g2"~-637-1~[ ....... 6722 6677° 6600 44 8 225,36 N 148.78' ~t 6P. 29 6777. 6700 51 7 256.~7 N I70,~b ~ " 6q35 .............. 6'877, ........... 6800 .............. 57 ............................... 6 ...... ~'86;09:-'N ................ 1'9~;6~7~ 71~8. 7077. 7000 70 6 344,~ N 232,85' ~ ........ . ................................................................................. - · DEPTH . . · 799'1 7]L?7'e 7100 7277. 7200 777? ' 7700 107' 7877, 11.:3: 8542' 8377. 83,00- 164: 8652 84,77.~ 175 401,64 : 898 ! 87'7:,7. 9089 ...................... 9197 8977. 8900 219 9304 9077. 9000 226 9~18 9277e 9200 8 7' 1092 9624 9377e 9300 9730 ............. 9477i ...... 91+00" ~ HORIZONTAL.: VIEW' WELL, RADIUS OF CURVATURE Check Form for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: ..... / ~ -- ~ Date Completion Report Wel 1 History Samples Mud Log Core Chips R, equired Yes Yes Date Received Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes Remarks SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO--BP ALASKA PRODUCTION DIVISION MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: SFO/UNIT/STATE: SFO/UNIT/STATE: OH Final Logs STATE ONLY: ARCO ___ C~_ ~ 11/7/80 (/462 M~u~ (11/~/80: State OH Finals) Mobil REFERENCE: SFO i ~ ~The following material ~s e~n u m~ h r ~ h P kn d signing wle ge receipt by a copy of this letter and returning it to this office:-- _ .. .. A-12 DIL/SFL 10/26/80 & 10/30/80 ~l&2 2" &5" A-12 BHCS 10/30/80 ~1 2" & 5" A-12 FDC 10/31/80 ~1 2" & 5" A-12 FDC/CNL 10/31/80 ~1 2" & 5" A-12 Magnetic Single Shot Surve~ ..................... )~--//~/80 '~ ................ A-12 Gyroscopic Survey %1~/%/80 1 Kriet~r ~ ~/.~.~//...~~ ~,~ Well Records SOHIO ALASKA PETROLEUM COMPANY Alaska Oil & Gas Conservation Cc~rmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well A-12 (31-35-11-13) Enclosed, in dUplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of October, 1980. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer RECEIVEI) NOV 1 7 1980 Al~ka 011 & Gas Co~. Commlasb. STATE OF ALASKA /% ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, Drilling well ~:] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Ccx~any 80-117 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 504329-20515 4. Location of Well at surface 1116' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM* *Corrected 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 77.43' AMSL I ADL 28286 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. A-1 2. (ql -~qS-11-1 3) 1 1. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of October ,1980 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month: 9801' Footage Drilled: 9801 ' Spudded well at 1100 hrs., 10/14/80 13. Casing or liner run and quantities of cement, results of pressure tests Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2677'. Cemented with 3720 cu. ft. Arcticset. Tested casing to 3000 psi, okay. Drilled out to 2677', ran leak-off test to 0.76 psi/ft, gradient. Ran 226 jts. 9 5/8" 47# L-80 Buttress casing to 8804'. Cemented in 2 stages: 1st stage with 1210 cu. ft. Class G; 2nd with 130 cu. ft. Arcticset preceded by Arctic Pack. Tested casing to 3000 psi, okay. Drilled to 8845', performed formation competency test to 0.7 psi/ft, gradient. 14. Coring resume and brief description None 5. Logs run and depth where run DIL/SFL/SP/GR at 8767' DIL/BHCS, FDC/CNL at 9792' DST data, perforating data, shows of H2S, miscellaneous data NOV 1 7 ]980 Alaska 011 & Gas eons. Commission Anchorage !7. I hereby certify that the foregoing is true and correct to the best of mv knowledge. SIGNED U ~t ~ TITLE Dri.l!inq. Engineer DATE , _ NOTE--RepOrt on this form isrequired foreca hcal~n~ month, regardless of the status of o'oerations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed, Form 10-404 Submit in duplicate SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: .~CO ............ . EXXON ............ . . . PHILLIPS .......... 3111 "C" STR4'ET'I'''CO/VUV~' ANCHORAGE. A IL~-'~-~A~' TE LEPHON E (907) t'-~0~>~t '~,~ '"i ANCHORAGE, A LAS~~ 11/lo/8o SOHI.0 MAGNETIC LIS TAPE '~~Th2 following material is being submitted herewith. Please acknowledge receipt by signing a .' copy of this letter and retu'rming it to this office:-- A-12 Magnetic LIS Tape 10/30/80 #1&2 #61130 Well Records- (SF0 - sent directly from'Ventura) 19 ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton Chairman/Comm. i s $ i o ~e~r~/ Thru: Lonnie C. Smith Commissioner Doug AmOs ~ Petroleum Inspector October 24, 1980 Witness BOPE test on Sohio's A-12 well, Sec. 35, T11N, R13E, UM. Permit # 80-117 on Nabors Rig 18E. Thursday October 16, 1980: I travled from Parker Rig 176 to N~0r~""~ig-18E::'@ 3=00 pm this date. The BOPE test commenced at 6:00 pm and was concluded at 10..00 pm. I filled out an AOGCC BOPE Test Report which is attached. In summary I witnessed the BOPE test on Sohio's A-12 well. I filled out an AOGCC BOPE Test Report which is attached. O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspec%ion Report Inspector Date OCT /~'? Ig,~O Well -,L~- IZ Operator Well Location: Sec Drilling Contracto.r . 'Representative Permit # /~ Casing Set Rig # /~ Representativ~ Location, General ~/~' Well Sign General Housekeeping Reserve pit 'Rig "',{...~' BOPE Stack'- Test Pres sure I ~o~o 2 ACCUbIULATOR SYSTEM Full Charge Pressure ~O00 psig Pressure After Closure ~%p psig 2~00 psig Above Precharge Attained: Full Charge Pressure Attained: ~ N2 ~2J"~5.~/2.0~). ~9_D0,~!'75 t- / --- y Controls: Master .... min.~,~..' sec min /~.. sec ps ig r)Y Remote Blinds switch cover Kelly and Floor Safety Valves .Annular Preventer Pipe Rams '-,- Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ,. Upper Kelly / Test Pressure ~dP~Ddo Lower Kelly I Test Pressure ~cDo Ball Type / Test Pressure --~~ Inside BOP / Test Pressure ~D ~/Choke Manifold / Test Pressure No. Valves /~ No. flanges Ad/ustable Chokes 'Z. Hydrauically operated 'choke-.. / Test Results: Failures /~o~c~ Test Time.. Repair or '.~eplacement of failed equipment to be made within Inspector/Commission office notified. Remarks: hrs. days and .Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector October 10, 1980 Hr'. R. H. Retley District Drillin$ RnSinear Sohio Alaska Petroleum Company Poueh 6-612 Anchorage, Alaska 99502 Res Frudhoe Bay unit A-12 Sohio Alaska Petroleua Company Permit No. 80-117 Sur. Loc.~ II16tSNL, 922'WEL, Sec. 35, TIlN, R13E, UPH. Bottomhole Loc.: iIO~SNL, 150S'WEL, Sec. 35, TIlN, al3E, UPM. Dear ~r. Reiley: Enclosed is the approved application for permit to drill the above refereneed well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized lot iniormation shall be submitted on all loss tor copyinl except experimental loss, velocity surveys and dipmeter surveys. ~any rivers in 'Alaska and their drainage systems have been classified as important for the spavning or migration of anadromous ~ish'. Operations in these areas are sub~ect to AS 16.~0.870 and the regulations promulgated thereunder (Title ~, Alaska Administrative Code). Prior ~o commencin~ operations you may be contacted by ~he ~abitat ~oordinator's office, Depar~men~ o£ Fish and Came. Pollulion of any raters o~ the S~ate is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska ld~tnis~rative Code, Chapter 70) and by the Federal Waler Pollution Control Ac~, as amended. Prior to Hr. R. H. Reiley Prudhoe Bay Unit A-12 -2- October 10, 1980 commencing Operations you may be Contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.!0, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field york, we would appreciate your notifying this office within 18 hours after the veil is spudded. We vould also like to be notified so that a repre- sentative of the commission may be present to witness testing of blOwout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate, advance notification so that we may have a witness pres-ent. Very truly yours, Ho.ylg'H. Hamilton Alaska Oil & Cas Conservation Co~mission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY CONFIDENTIAL 3111 °'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 October 9, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Re: Well A-12 (31-35-11-13) Gentlemen: Enclosed are the following documents, in triplicate, along with our check for $100 to cover the permit filing fee. 1. Application for Permit to Drill; 2. Proposed Drilling Program Outline; 3. Surveyor's Plat showing well location; 4. Blowout Prevention Equipment Diagram. Very truly yours, SOHIO ALASKA PETROLEUM COMPANY District Drilling Engineer RHR:mlh Enclosures Form 10-401 REV. 9-1-78 SUBMIT IN TRIt (Other instruction,. reverse side) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~ b. TYPE OF WELL ~LL~[[] GAS SINGLE MULTIPLE WELL [--] OTHER ZONE [] ZONE 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, AK 99502 DEEPEN [--] 4. LOCATION OF WELL At surface 1116' SNL, 922' WEL, Sec. 35, TllN, R13E At proposed prod. zone 110' SNL, 1505' WEL, Sec. 35, TllN, R13E 1'3. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 8 Miles NW of Deadhorse API ~50-029-20515 6. LEASE DESIGNATION AND SERIAL NO. ADL 28286 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. A-12 (31-35-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Oil Pool lI. SEC., T., R., M., (BOTTOM HOLE OB3ECTIVE) Sec. 35, TllN, R13E, UPM 12. 14. BOND INFORMATION: TY~EBlanket Surety and/or No. American Ins. Co: 3348616 15. DISTANCE FROM PROPOSED.,*., [ 16. No. OF ACRES IN LEASE LOCATION TO NEAREST .~ / 75 ' E O f ADL 28287 PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) } 2 4 91 18. DISTANCE FROM PROPOSED LOCATION 119.PROPOSED DEPTH ' TO NEAREST WELL DRILLING, COMPLETED, ! R%APPLIED FO,. FT_ 2370 · fYom -A~--I_. D750'MD, 9530'TVD mount $500,000 17. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START Est. KBE = 75' AMSL 10/25/80 23. PROPOSED CASING AND CEMENTING PROGRAM , , SIZE OF HOLE SIZE OF CASING ~IGHT PER FOOT GRADE ~D SETTING DEPT~VD ~antity of cement , , 36" 20"x30" Insulated Coilductor lI0* 110' 8 cu.yds, cement . 17 1/2" 13 3/8" 729 L-80 2680' 2680' 3220 cu.ft. Arcticset II 12 1/4" 9 5/8" 47# L-80 8830' 8610' 1205 cu.ft. Class G 8 1/2" 7" 299 L-80 9750' 9530' 270 cu.ft. Class G cement ~/18% : OCT. 9 IN ~O~ SPACE DESC~BE PRO~SED PROG~M: If pTopo~l i8 to due~e~ ~ve dSta o~ p~ese~t pTod~ctive go~e a~d proposod ~ew pIod~c~ve gone. If pIo~l is to d~ oI deepe~ dkec~on~y, ~ve peTtinent data on sub~face locations ~d ~eas~Ied ~d tI~e veTtj~ depths. Giw blowout ~Te~e~teT pTo~a~. SIGNED (This space for State office use) DATE. SAMPLES AND CORE CHIPS REQUIRED [] YES ~o DIRECTIONAL SURVEY REQUIRED CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES DISTRICT ~TLEDRILLING ENGINEER OTHER REQUIREMENTS: ~YES [] NO PERMIT NO., ~ 0 -' A PPROVEDBY ~.~t~~ TITLE 1~¥ O~OF~ OF/a= E0~SSlo~ee InstrUCtion OnReverse ........ Side an GK: mlh A.P.I. NUMERICAL CODE APPROVAL DATE 0trebor I 0; 1 980 DATE PROPOSED DRILLING AND COMPLETION PROGRAM WELL A-12 Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Install 20" diverter system. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72% L-80 Buttress casing to surface using 3220 cu.ft. Arcticset II cement. Blowout preventer program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8610' TVD. Run 9 5/8" 47% L-80 Buttress casing to 8610' TVD and cement first stage with 1205 cu.ft, cement. Cement second stage through D.V. packer 'collar at 2600'~ with 130 cu.ft. Arcticset I cement. 9 5/8" casing will be hung at surface, the 9 5/8' x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9530' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 270 cu.ft. Class G cement with 18% salt. Run 4 1/2" 12.6% tubing with 5 gas lift mandrels and a production packer assembly at 8050'~ TVD. A subsurface safety valve with dual control lines will be placed at 2000'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. GK: mlh 10/7/80 4O ~ 04 ~ Ol o2 03 04 TIIN ~,, TION ~ 01 -..d O3 04 lO i ...-- 95' A-16 (.P r~ po{ed~ ) zo 26 ~o ,,o ,o eo 2,5 ~o I I hi 40 n' I A-t2 - ( Pro, posed = ELL A- 1~ I LAT. ?0e~6'06.48" I LONG.148°4§' 05,65" y I I I i I I ' I . ,, -- ,. '~ ~~ , . PORTION OF T. I0 ~ II N.,R. 13E., U.M SCALE I"= I/2 MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents o location survey of the wellpad shownand the wells thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by °thers. Date Surveyor SUMP (4/-05-/o- Ii) (/z-al-lO-/$) ,,.-__265L--~ '(3 PAD DETAIL SCALE I" 400' .... .. ~' ,~ · , ~; ,,~ , ~ 'F'- .... : :,. ..... PAD "A" EXTENSION Located in e I/Z PROTRACTEDSEC.$5 Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F.M. LINDSEY 8[ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-08i Anchorage Alaska B.O.P. S-I::ACK. CONFIG.URA~,~N 1:5 5/8" TRIPLE RAM STACk_ =ooo P,S~ ,,,wP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2:" KILL LINE CHECK GATE GATE ORILLING SPOOL CHOKE LINE GATE HYDR. ASST. GATE PIPE RAMS FLOWLINE , , 10-3/4" GROUlhrD LEVEL _ I I II I I DRILLING RISER DIVERTER SYSTEM DETAIL DRILL. DEPT. MARC}{ 1980 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL 20" CONDUCTOR PIPE NOTE: DIVERTER LINE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. B.O.P.~_S.~AC K CONFIGURATION TRIPLE RAM STA(,n i i i _5_0,00 PS,I ,WP DRILLING ANNULAR PREVENTER PIPE RAMS 2" KILLLINE CHECK GATE GATE BLIND RAMS DRILLING SPOOL CHOKE LINE GATE HYDR. ASST. GATE PIPE RAMS CHECK LIST FOR NEW WELL PERMITS Item Date (1) Fee '~L°ve / 1. Is the permit fee attached ................................ 2 Is well to be located in a defined pool ....... 3 Is a registered survey plat attached ....... · · Yes No (2) ,Loc..?~"~-.. (3) /~lnlin. ~ 4. Is well located proper distance frcm property line .................. _~/~L ..... 5. Is well located proper distance frcm other wells ................... 6. Is sufficient undedicated acreage available in this pool ............ 7. Is mll to be deviated ............................................... ,,, 8 Is operatOr the only affected party ............. ' .. 9. Can permit be approved before ten-day wait .......................... ~-~-fu 10. Does operator have a bond in force ............... ' ....... . ........... ~ '~ 11. Is a conservation order needed ...................................... (4) Casg. /69~_~/~~~ 12. Is administrative approval needed ................................... ( 5 ) BOPE 13. Is conductor string provided ........ ' .............................. ~~ 14. Is enough corr~nt used to circula~ on conductor and surface ..... '...~_ 15. Will cement tie in surface and intermediate or production strings ...~ 16. Will cement cover all known productive horizons ................... i.'~.~~ 17 Will surface casing protect fresh water zones ... , 18. Will all casing give adequate safety in collapse, tension and burst..~~ 19. Does BOPE have sufficient pressure rating - Test to ~C)(D~ psig~//--L _%~ Approval Reccmmended: Lease & Well No. .//~ /'~ Remarks Additional Requirements: Geology: Engine~.r '.zng: , ," rev: 03/05/80 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. 11 000000 I1 000000 1111 00 O0 1111 00 O0 11 00 0000 11 O0 0000 11 00 O0 O0 11 00 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 00 O0 111111 000000 111111 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 OO0000 7777'777777 00OOO0 7777777777 O0 OO 77 O0 OO 77 O0 0000 77 O0 0000 77 00 O0 OO 77 00 Ot) OO 77 OOO0 O0 77 O000 OO 77 00 OO 77 00 OO 77 000000 '77 OOO000 77 666666 11 666666 11 66 1111 66 111.1 66 I1 66 11 6~0~6666 11 66660666 11 b6 66 11 66 66 11 66 66 11 66 b6 11 666660 llllil 666666 11111i 11 11 1111 1111 11 11 11 11 11 11 11 11 111111 II1111 333333 000000 333333 000000 33 :3,3 O0 O0 33 3.3 00 OO 33 O0 0000 33 O0 0000 3.3 O0 O0 O0 33 O0 O0 O0 33 0000 O0 33 O000 O0 33 33 O0 O0 33 33 O0 O0 33]333 000000 333333 000000 U U U O U U U U U U U U UUUUU [)DOD R h OOO EEEEE D D H H 0 O E D D H H U 0 E D D HHHHH O 0 EEEE D O H H O O E DDDD H H OO0 EEEEE ,START* USEE PCAL [10707,b11~01 dUB MONItO~ S~S KL1.0EiO SLP-80. ,STABT* ,START* USEB PCAL [1070'7,~11301 ,][iB MONITOR Sins .FLIOE40 ShP-!dO. ,fi'tAR[['* SHIP SEQ. 2677 DATE 04-~0V-80 20:29:27 2677 I)A'I'~ 04-NOV-80 20:29:27 SUMMARY ~I~ DATA ~i~CuHDS NI]MB~[~ 0I~ REC,[]FiD6: 953 I,ENGTi-~ O~ I~A.S"I RECUI-~D: 70 FILE T1RAILE,R L£NGTH: 1024 LENG'I~N: 62 BYTES FiLE NAME: EDIT .001 MAXIMUM PHISICAL RECURD NEXT ~ILE NAME: Ef3F TAP~ It~.A I [Et~ DATE: NUMBER LENGIH: 132 B~TES TAPE NAME: 61130 SERVICE Ng~E: EDIT TAPE Ct]NTINUATiON NUMBER: 01 NEXT TAPE, NAME: COMMEN'~S: UNIQUE WkLb £DENTIFICATION 80/11/ 4 i8 50-029-20515 -) II 1I 1i II II I1 II II II II II ii II I1 1I 11 II II Il ti .I I ii PPPPPPPP PPPPPPPP PP Pp PP PP PP PP DP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTT TTTT TTTTTT TT 0~ TT 0~ OO T T 0 ~ TT 0~ 00 TT 0(] TT UC UO TT O~ OO TT 0~ 00 TT O.bO000 TT OOOOOO *START* USkP, PCAL [10707,611301 jOB SHIP MONITOR S~S KL1OE40 SEP-80. *START* VILE: DSK~ISHIP T.U<255>t10707 611J01 CREATED: P~lbi~k~: 04-.NOV-80 26:29:42 ~UEUE S~ITCHES: /PILE:PO~T /COPIES:I /8PACIN6:i /LIMII':129 /~'ORNS:NO~MAL SE~. 2677 OATh 04-NOV-80 04-NOV-80 15:12:32 20:29:27 VV ~ EEEEEEEEEE 9RRBRRR~ VV VV EEEEEEEEEE BRRRRRR9 VV VV EE ~R ~R VV ~V EE H~ ~ VV VV ~E ~ N~ VV VV ~E~E~ ~N~ VV VV EEEEEEEE RRRRRRR~ VV VV EE ~R RR VV VV EE ~ ~R VV VV EE RR ~R VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR ~R IillII 1IIIii II II il Ii II I1 Ii II II Ii 11iiii 1Iiili YY YY Y¥ YY YY 000000 000000 66666t 000000 000000 666666 O0 09 ()0 O0 66 O0 OO O0 O0 66 00. 0000 O0 0000 ~ O0 0000 O0 0000 bb O0 O0 O0 O0 O0 O0 66666666 O0 O0 O0 O0 O0 O0 66666666 0000 O0 O000 O0 66 0000 O0 0000 O0 bO O0 O0 O0 O0 ~6 00 O0 O0 O0 66 000000 000000 066666 000000 000000 66666~ 66 66 66 66 ,SIART* USE[{ PCAL [10707,b1130J dOB SHIP QUEUE 8~il~CfiES: /~lb~:~tJa; tCOPIES:I 26'77 DATE O4-NOV-80 04-NOV-80 20:27:03 20:29:27 SCHLUMBEP, GER CO,~PUTING CENTEI~ 10707,6! ! 30 REEL ~EADER LENG~IH: 112 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBE~: O1 PREVI[]US HEEL NAME: COMMENTS: LIS FO~AT CUSTOME~ TAPE DATE:: 801111 TAPE; ttEADEB LENGTH: 132' BYTES TAPE NA~4E: 61130 DATE: 80/11/ 4 SERVICE NA~E: EDIT TAPE CONTINUAl[ION NUSBER: O1 PREVii][JS TAPE NAME: COMMENT6: UNIQUE WELL ~DENTIFICATiON NUMBEB iS 50-0~9'205~5 TAPE CUM~ENTS RUN (]NE/~OGG~D 20-OCT-80/CASlN6 SIZE 1].37 7~ 0 2075/81I' 61ZE 12.25 ~ 8767/DENS 9.B/PB 9.0/VISC 35'O/~LUiD LOSS 6 6/T~PE FLUID GEL XC PL P[]L~MER/DM 3'52 ~ 75 D~'/BM~ ].6 ~ 75 DF/RMC]~0 75 RUN 'IWU/LfJGGED 30-OC~-80/CASING 13.37 72# ~. 2675/BIT 61ZE 8.5/ TYPE fLUID GEL XC P(JLY,MEB/DENS 9.7/ViSC 34.0/PH 9.O/FLUID LOSS t~.O/ RM 2.85 0 56 DF/RME ,5.05 ~ 56 EFtRMC 3.11 ~ 56 DF/ EOF FILE HtADEtq LENGI]H: 62 BYTES ~ILE NANE: EDIT .001 MAXIMUM PHYSICAL ~EC{J~D LENGTH: PREVI~[)S ~ILE NAME: ~'ILE COM~.NTS 1024 BITES ~ELL 8I~E IN~MAIION RECG~D LENGI'~ Ct]MPA~ WELL: E iELD: RANGE: TOW N; SECII 194 SOHIO ~LASKA PEIROLEUM CO. A-12 (31-35-11-13) 13E lin ) 3300.000 ,3200.000 3100.000 3000.000 2900.000 2800.000 2700.000 2670.000 MNEM[JMIC SP NPH1 SP NPH1 NPHi ~CNL SP NPH1 ~C.aL FCNL SP GR NPHI SP NPH1 ~CNL 8P GR NPHI FCNL VALUE -86.625 65.313 -999.250-999.250 -60.500 81.188 -999.250-999.250 -75.875 68,500 :999 . so 99.250 -49,250 67.813 -999.250-999.250 -55.250 77.875 -999.250-999.250 -96,81~ 55,938 -999.250-999.250 -99.313 37.031 -999.250-999.250 -22.281 31.Olb -999.250 =999.250 ILD GR 1LD GR RH.t]O G~ ILD G~ GR GR 1LD .~H(]B GR ILO RHQO GR 1LD GR GR ILD GR RH[JB VALUE . 7 082 999:250 -999.250 -999.250 6.105 -999 250 -9 2 5o -999. 250 6.141 -999.250 -999.250 -999.250 4.281 :99 -999.250 1.059 -999.250 -999.250 -999.250 2,408 -999 250 -999.250 1 922 - 99'. so -999.250 -999.250 2000.000 -999.250 -999.250 -999.250 VALUE MNLMONiC VALUL ILM 7 578 SFLU 9.555 CALl -999:250 DRHO -999.250 DTNRAI' -.999 9992250250 NCNb -999.250 ILN 5.508 SFhO 4.938 CALl -999.250 DRHO -999.250 NRA~ -999,250 NCNb -999.250 DT -999.250 ILM 6 512 SFLU 7.766 CALl ' -999~250 DRHO -999.250 NRAI -999,250 NCNb -999.250 OI: '999.250 iLM 4.0]9 SFLU 4.176 CALl -,999.250 DRtdCi ,-999.250 NRAT ' 999,250 NCNb .999.250 DT -999.250 IbM 3,94~ SFGO , 4,527 CALl -999,250 DRHO 999.250 NRA~ -999.250 NCNb -999.250 DT -999,250 ILM 2,580 SFLO 4,805 CALl -999,250 DRHU -999.250 NRA~ '999.250 NCNb -999.250 DT -999.250 iLM 2.035 SFLU 2.551 CALl -999.250 DRHO -999,250 NRA~' -999.250 NCNb -999.250 D~ -999.250 iLM 2000,000 S~'LO 2000.000 CALl '999.250 ORHO -999.250 N~AT -999.250 NCNb -999.250 DT -999.250 DkFTiq 44{30. 000 4]00.000 4200. 000 4100.000 4000.000 :1900.000 ]800.000 ]700.000 9600. 000 3500.000 :1400. o00 MNLNON iC GR NPHI bCNL 8P GR FCNL 6P NPHI fCNL SP GR FCNL SP GR NPH1 fCNL SP GR NPHi ~ChL SP GR NPH1 FCNL SP NPE1 ~CNL 8P GR NPH i FCNL 8P GR NPHI FCNL 8P NPh I ~'CNL V A L U E; -52.375 70.000 -999.250-999.250 -104.438 4,].094 -999.250-999.250 -49.531 67.375 -999.250-999.250 -55.813 75.000 -999.250-999.250 -5~.031 66.000 -999.250-999.250 -94.063 45.375 -999.250-999.250 -60.250 70.750 -999.250-999.250 -97.875 50.875 -999.250-999.250 -53.750 78.875 -999.250-999.250 -80.375 64.I88 -999.250-999.250 -77.250 59.625 -999.250-999.250 I GR H It 0 B ILD GR Gg 1LD GR GR ILD GR RHOB GR ILD RHOB GA ILD GE ~HUB GR GR thg GR RHOB GR GH AHOB GR GR GH VALUE :t.262 -999.250 -99 : .50 2.645 -999 250 -999~250 -999.250 4.906 -999.250 -999. 5. ]75 :999 250 999:250 -999.250 6 621 -999:250 -999.250 -999.250 5.2'73 -999 250 -999:250 -999.250 7.930 -999.250 -999.250 -999.250 4.688 -999.250 -999.250 -999.250 6.680 -999.250 -999.250 -999.250 6.555 -999.250 -999.250 -999.250 6.082 -999.250 -999.250 -999.250 MN ENONIC CALl NRA'I DT iLM CALl NRAI iL~ CALl NRA't DT CALl NRA'I DT CAb 1 NRA1' ILM CALl NRAI DT ILM CALl DT IL~ CALI NBA'I CALl N~A'I DT CALl NRA/ DT iL~ CALl VALUE 3 461 -999:250 -999.250 '999'250 3.076 -999.250 -999.250 -999.250 5.156 -999.250 -999.250 -999.250 5.~13 -999.250 '999-250 -999.250 b.727 -999.250 -999.250 -999.250 5.949 -999.250 -999.250 -999.250 7.810 -999.250 -999.250 -999.250 4.969 -999.250 -999.250 -999.250 5.8:16 -999.250 -999.250 -999.250 6.785 -999.250 -999.250 -999.250 6.012 -999.250 -999.250 -999.250 NNEMONIC S~'LU DRHO NCNb SFhU DRHO NCNb SFLU DRHO ~C~L SFLU DRHU NCNL SFbU DRHU NCNL SI;lbO DRHO NCNb 8FLU DRHO NCNb SFLO DRHO NCNb 8FbO DRHO ~CNB SFbO DHHO NCNL SFLO D R H 0 NCNb VALUL . 3.250 999,250 -999.250 6.084 -999.250 -999.250 b.b91 -999'250 -999.250 ~.590 -999.250 -999.250 7.496 -999.250 -999.250 8.938 -999.250 -999.250 7.863 -999.250 -999.250 0.414 -999.250 -999.250 6.012 -999.250 -999.250 8.531 -999.250 -999.250 7.852 -999.250 -999.250 5500.000 5400.000 5300,000 5200.000 5100.000 5000.000 4900.000 4~00,000 ~700.000 4600.000 4500.000 NPH1 FCN6 8P NPH 1 F CNL SP GP NPHi FCNL NPHi FCNL SP GR NPHI fCNL SP G~ NPHI ~CNb SP NPHI ~CNL SP NPH I ~CNL, 6P NPH i fCNL SP NPHI f'CNI~ SP GR NPH 1 ~-r.C NL VALUE -134.500 ~3.918 -999.250-999.250 -155.125 47.844 -999.250-999.250 -'71.750 63.750 -999.250-999.250 -41.469 67.750 -999.250 -999.250 -108.750 45.969 -999.250 -999.250 -81.250 59.000 -999.250 -999.250 -59.844 60.125 -999.25O -999.250 -47.000 59.031 -999.250 -999.250 -76.250 57.094 -999.250 -999.250 -88.6~5 61.06,3 -999.250 -999.250 -37.281 79.~25 -999.250 -999.250 MNEF~ONIC 1 I., D GR RHOB RHLJB GR iL, D lED R. HO~ GR RHOB GR ILD GR GB GR GR 1 i,D GR ILl) GR RHI3B GB 2.46~ -999.250 -999.250 -999.250 1.495 -999.250 -999.250 -999.~50 3.164 -999.250 -999.250 -999.250 3.840 -999.250 -999.250 -999.250 1.225 -999.250 -999.250 -999.250 1.656 -999 ~50 so -999.250 250 -999.250 -999.250 2,738 -999.250 -999.250 -999.250 2.963 -999.250 -999.~50 -999.250 2.150 -999.250 -999.250 -999.250 5.426 -999.250 -999.250 -999.250 MNkM{]N iC CALl DT IL~ CALl NRA"[ CALl CALl CALl NR~T DT CALl ,NR CALl D~ ILM CA~I NRA~ CA~I NRAi I. LN CALl CaLl 'VALUE 3.262 -999.250 -999.250 -999.250 1.8~4 -999.250 -999.250 -999.250 ].277 -999.250 -999.250 -999.250 3.676 -999.250 -999.250 -999.250 1.509 -999.250 -99~ 250 -99 ~250 1.836 -999.250 .250 2.102 -999.250 999. 50 2.912 -999.250 ~999.250 -999.250 3.482 -999.250 -999.250 -999.250 2.398 -999,250 -999.250 -999"250 5.355 -999.250 '999.250 -999.250 NNEMtJNIC VALUE 8FLU 4.938 DRMO -999.250 i~CNL -999.250 SFbU 7.863 DRHO -999.250 NCNb -999. 250 SFLU 4.340 DRHO -999.250 NCNb -999.250 SFLU 3.410 ORHO -999.250 NCNL -999.250 ,.SFLU 3.328 DRHO -999.250 NCNL -999.250 SFi~U 2.541 DRHO -999.250 NCNL -999.250 . a./21 DRHO 999.250 NCNI. -999.250 SFbU 3.893 DRHO -999.250 NCNb -999.2'50 8FLU b.227 DRHU -999.250 NCNb -999.250 SFBU 5.59B DRHO -999.250 NCNb -999.250 SFLU 5.566 DRHO -999.250 NCNb -999.250 DEPIH 6600.000 650O .000 6400. 000 6300.000 62O0.O00 6100.000 6O00.00O 5900.000 5800.000 5700.000 5600.000 NNENi, JNIC GR FCN G SP GR NPH, I [, CNL SP GR F'CNb SP NPH1 i' CNL SP GR [CNL G~ NPH I ~ CNL SP GR NPH1 ~CNL SP GR NPHI FCN[, GR [~PH1 ~CNL 8P GR ~CNL Gt~ lq P H I FCNL V AL UE -68.750 85.065 -999.250-999.250 -72.500 99.~88 -999,250-999.250 -73.75O 94.938 -999.250-999.250 -75.250 88.125 -999.250-999.250 -79.750 85.063 -999.250-999.250 -73.250 97 063 -999;250-999.250 -100.500 70.000 -999.250-999.250 -120.750 63.875 -999.250-999.250 -123.250 76,063 -999.250-999.25o -97.250 64.875 -999.250-999.250 -103.250 71.188 -999.250-999.250 GE lbD RHOB G~ GR GR 1LO ~HOB GR 1LO GR GR ILO GR ILD GR GR 1LD RHOB G~ 1LD GR BHOB GR 1LD G~. iLO G~ VAbL)E 2.299 -999.250 -999.250 -999.250 2.549 -999.250 -999.250 -999.250 2.908 -999.250 1999.250 999.250 3,146 -999.250 -999,250 -999,250 3,785 -999,250 -999.250 -999.250 1.998 -999.250 -999.250 -999.250 2.906 -999.250 -999.250 -999.25O 3.713 -999.250 -999.250 -999.250 2.867 -999.250 -999.250 -999.250 2,709 -999,250 -999,250 -999,250 3.93~ -999,250 -999.250 -999.250 CALl NRA1' D~ CALl DT CALl NRA~I DT IbM CALl DT I .L CALl NRAI DT IbM CALl NRAT DT CALl NRA]~ DT ILM CALl NRAI~ D'I' CALl DT CALl NRA1 D%~ CALl NRAT DT VALUE . 2.3'1] 999,250 -999,250 -999.250 2.b04 -999.250 -999.250 -999.250 2.914 -999.250 99. 250 3.156 -999.250 -999.250 -999.250 3.764 -999.250 -999.250 -999.250 1.930 :999.250 999.250 -999.250 3.096 -999.250 -999.250 -999.250 4.055 -999.250 -999.250 -999.250 3.098 -999.250 -999.250 -999.250 2.705 -999.250 -999.250 -999.250 3.842 -999.250 -999.250 -999.250 MNEMONIC SFbU DRHO NCNb SFLU DRH0 NCNb ,.Btm'bO DRHO NCNb SFLU DRHO NCNb SFLO DRHO NCNb SFLU oRHO NCNb SFbU DRHO NCNb SFLU DRHU NCNb S[*'LU DRHU NCNb 8FLU DRHO NCNb SFLU DRHO NC NL VALUE . 2.7b4 999.250 -999.250 2.850 -999.250 -999.250 . 2.814 999.250 -999.250 3.156 -999.250 -999.250 3.764 -999.250 -999.250 2.277 -999.250 -999.250 2.907 -999.250 -999.250 9.250 -999.250 -999.250 4.250 -999.250 -999.250 2.523 -999.250 -999.250 3.793 -999.250 -999.250 7700 . 0 () 0 7600.000 7500.000 7400,000 7300.000 7200.000 7100.000 7000.000 6900.000 6800.000 6700.000 8P GR NPH1 I'CNL 8P GR NP}t I 8P NPH I SP (;Ia NPHI 6P GR NP}tl [~ CNb 8P G~ PCi~L ,SP GR NPH I ~ CNL SP NPH1 ~'CHb SP GR NPHI ~CNL 8P G~ ~Ci~b SP GR ~CNL VALUE -55.969 217.875 -999.250 -999.250 -55.9~9 125.125 -999.250 -999.250 -71.250 119.813 -999.250 -999.250 -58.719 214.]75 -999.250 -999.250 -64.750 245,125 -999.250 -999.250 -~0.969 98.375 -999.250-999.250 -el.469 38.344 -999.250-999.250 -62.469 87.688 -999,250-999.250 -64,750 92,875 -999.250-999,250 -o5.250 98.688 -999.250-999.250 87.750 -999.250 -999.250 MNEi~LiN lC l L D iLD G~ GR iLL GR ILD ILL GR PHOB 1LO GR RHUB GA ILL GR ILD GH }{HUB 1 LD HHUB iLL GH VALUE 2.029 -999.250 -999.250 -999.250 2.033 -999.250 -999.250 -999.250 2.447 -999.250 -999.250 -999.250 1.900 -999.250 -999.250 -999.250 2.~36 -999.250 -999.250 -999.250 1.751 -999.250 -999.250 -999.250 1,b84 -999.250 -999.250 -999.250 1,847 -999,250 -999,250 -999,250 2.563 -999.250 -999.250 -999.250 2.574 -999.250 -999.250 -999.250 2.699 -999.250 -99g.250 -999.250 NNEMONiC 1LM CALl UT CALl NRAI DT ILM CALl BT ILM CALl DT ILM CALl DT ILM CALl DT ILM CALl NRA~ DT IL~ CALl ILM CALl NRA7. bi IbM CALl NRA'I DT CALl NRA'].' DT VAbUE 2.197 -999.250 -999.250 -999.250 2.229 -999.250 -999.250 -999.250 2,484 -999.250 99.250 2.068 -999.250 -999,250 -999.250 2.414 -999,250 -999,250 -999,250 1.825 -999.250 -999,250 -999.250 1.976 -999,250 -999.250 -999.250 1,961 -999,250 -999,250 -999.250 2.750 -999,250 -999,250 -999.250 2.609 -999.250 -999.250 -999.250 2.79/ -999,250 -999,250 -999,250 MNkMON lC SFbU DRHO NCNb SFLU D H HO ORHO NC!Nb SFbO DRHO NCNb SF6U DRHO NCNb SFLU DRHO NCNb S~LU DRHO SFLU DRHO NCNb SFLU ORHO SFLU DRHO NCNb SFUU DRHO NCNb VAbUE 3,314 -999.250 -999.250 3.77'7 -999.250 -999.250 2.785 -999.250 -999.250 3.328 -999.250 -999.250 3.3J0 -999.250 -999.250 2.129 -999.250 -999.250 4.914 -999.250 -999.250 2.311 -999.250 -999.250 3.480 -999.250 -999,250 2.752 -999.250 -999.250 3.0~2 -999.250 -999.250 8700.000 8000.O00 8500.000 8400.000 8300.000 8200.0OO 8100.000 8000.000 7900.000 7800.000 t. MON1C SP GR NPHI ~'CNL SP G~ NPHi ~'CNb SP NPHI ~CNL NPH1 ~CNL SP GR NPHi FCNL SP GR NPHI ~'CNL SP GR ~CNL SP NPHI ~CNL SF NPHi FCNL SP GR NPHI FCNL G~ NPN1 FCNL V A L tJ ~j -25.234 88.563 45.1bb 335.750 -34.781 117.125 -99,9.250 -999.250 -]2.719 I17.438 -999.250 -999.250 -36.281 85.375 -999.250-999.250 -36.719 107.188 -999.250 -999.250 -38.219 119.125 -999.250 -999.250 -43.719 112.375 -999.250 -999.250 -49.719 83.125 -999.250-999.250 -45.719 92.438 -999.250-999.250 -49.719 95.875 -999.250-999.25O -54.219 162.250 -999.250 -999.250 EMON 1C 1 LD GR ILD GR GR ]bD GR GR iLD GR RHOB GR RHOB GR ILD GR ILO GR GR 1LD 6R RHOB ILO GR G~ G~ GR 1LD V A L U E ,t2g 8 .125 2.019 88.563 1.502 :999,250 999.250 -999.250 I 129 -999 250 -999~250 1 ,919 -99q:250 -999.250 -999.250 1.527 -999.250 -999.250 999.250 1.249 -999.250 -999.250 -999.250 1.292 -999.250 -999.250 -999.250 2.621 -999.250 -999.250 -999.250 1.00~ -999.250 -999.250 -999.250 1.014 -999.250 -999.250 -999.250 1.411 -999.250 -999.250 -999.250 M N kMON lC iLM CALl NRA~I DT IbM CALl NRAI iLN CALl NRA'I DT 1LM CALl NRA~I DT VALUE MNEM. OmIC VALUE 1.20~ SFbU 1.772 15.867 ORHO 0.098 4,324 NCNb 1343.000 125.188 1.562 SFLU -999.250 'DRHO -999.250 NCNb -999.250 . 1.209 SFLU 999.250 DRHO -999.250 NCNb -999.250 2.012 SFLU -999.250 DRHO -999.250 NCNb -999.250 ILM 1.625 SFLU CALl -999,250 DRHO NRAI -999.250 NCNb DT -999.250 IL~ CALl NRAI DT CALl NRA'I DT ILM CALl NRAt C AL 1 IL~, CALl NRA'i OT ILM CALl 1.336 SFLU -999.250 DRHO -§99.250 NCNb -999.250 1.371 SFbU -999.250 DRHU -999.250 NCNb -999.250 2.705 8~bU -999.250 DRHO -999.250 NCNb -999.250 1.082 SFLU -999.250 DRHO -999.250 NCNb -999.250 1.087 SFLU -999.250 ORHO -999.250 NCNb -999.250 1.488 SFUU -999.250 DRHO -999.250 NCNb -999.250 2.084 :999.250 999.250 1.642 '99.250 -999.250 2.555 -999.250 -999.250 2.092 -999.250 -999.250 9 ~ ~ ' 99-250 1.O98 -999.250 -999.250 2.949 -999.250 -999.250 1.339 -999.250 -999.250 1.262 -999.250 -999.250 1.745 -999.250 -999.250 98 10. 000 9800.000 q 7 O0. O00 9600.000 9500.0()0 9400,000 9900.000 9200.000 9100.000 9000.000 8900.000 E M U N 1 C S P GR .N P B I 8P GE NPH1 B'CNL GR NPH1 ~CNL SP NPHI fCNL 5P GR NPHI fCNb 8P NPHI fCNL NPHI FCNL GR NPHI f'C NL SP GR NPHI ~CNL SP GR NPHi FCNL SP GR NFhi ~CNL 'VA L 81 19 1391 -35 81 15 1391 -50 78 17 1481 -104 21 25 981 -11l 21. 2O 1252 UL .875 .250 .873 .000 .469 .250 .088 .000 .000 .313 .285 .OO0 .000 .5O0 .684 .500 .500 .688 .801 .000 -90.750 30.813 24.512 llb3.000 -1 22 -1 13 -1 11 19 1 lb 11.250 18.438 11.768 10.000 08.500 20.563 21.387 2~.000 07.250 25.891 23.047 05.000 40.719 93.31,~ 13.]35 20.000 44.719 17.9)8 20.752 65.000 MN k M 0 N I C 1LD GR MHOB GR ILD GR i LD GR ,RHUB GR GH RHOB GR GR GR ILD GR GR 1LD GR GR 1LD GR RHOB GB ILD GR G~ ILD GR GR ILD GR RH[JB GR VALUk ~.057 120.563 2.697 81.250 3.053 120.563 2.510 81.250 5.805 88,563 2.596 78. 313 4.113 28.016 2.350 21.500 2.129 24.766 2 271 211688 1.832 28.000 2-186 30.813 8.828 19.844 2. ~52 18.438 42.594 23.453 2.318 20.563 J8.125 27.828 2.428 25.891 25.609 88.563 2.605 93.]13 7.590 129,500 2.492 117.9~8 CALl 1L~, CAb 1 NRA~I OT ILM CALl NRA'I DT iLM CALl NRA? DT IbM CALl NR A'I DT ILM CALl DT l LM CALl DT IL~ CALl NRA'I DT CALl CALl NMAI DT CALl 0I; VALUE 3,202 1.435 1.90J 80.375 3.270 b.770 1.903 80.375 6.297 8.680 2 184 74:000 4.496 8.477 2.730 91.188 2.324 8.531 2.406 88.188 2.064 8.445 2.650 92.188 9.23~ 8.414 1.790 74.563 32.688 8.563 2.451 85.750 30.047 8.414 2.551 86.188 35,156 8.734 1.909 73.375 8.336 9.484 2.480 75.750 MNEMONIC SFbU DRHO NCNb SFLU DR HO NCNL ,SFLU DRHO NC NL SFLU ORHO NCNb St'bO DRHO NCNL SFhU DRHO NCNb SI;LO DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFBU DRHO NCNL VALUE .2.973 0.087 2582.000 2.961 0.09i 2582.000 0.015 3312.000 13.109 -0.012 2628.000 6,035 0,01.6 2914.000 4.320 0.006 2952.000 23.188 0.019 3802.000 39.063 0.026 3130.000 35.531 0.059 2638.000 b0.219 0.034 3604.000 13.O70 0,039 3566.000 DATUM SPEC .IFICfiTI(JN BL(3Ct'tS: ENTRY IC TOOL I DEP'[ ILD Bi h 4 I ,L M D I L 5 SFLU DIL 6 G~ DIL ? G~ C~b 8 C~L1 C~L DB~G CNb 10 ~FHI It ~HO~ C~L NC~L CNL i4 ~CNL CI~L 15 G~ BHC D~ B~C UNI%8 API AP1 AP1 APl FILE FT 0 0 0 0 MV ? 1 0 0 OHM~ ? 12 46 0 Ot~M~ ? 12 44 0 OHMN 7 22 1 0 GAPI 7 31 ]2 0 GAPI 42 31 32 0 IN 42 28 1 0 G/C] 42 44 0 0 PU 42 68 2 0 G/C] 42 35 1 0 C/C 42 42 1 0 CPS 42 34 92 0 CPS 42 ~4 93 0 GAPI 60 31 ]2 0 US/[" e-O 52 32 0 SIZk EXF PROC SAM 0 4 0 0 0 4 0 0 0 4 O 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 REP DEPT SHIi~T I b8 0 0 I 68 0 0 I 68 0 0 1 68 0 0 1 68 0 0 1 08 0 0 1 68 0 0 1 68 0 0 i 68 0 0 I 68 0 0 1 68 0 0 i b8 0 0 68 0 0 1 68 0 0 1 68 0 0 I 08 0 0 L~iTR~ ELOC~S: 'I ~ P E 0 SIZE 1 REP CODE ~6 0 SHIP PCCC THANKS SHiPPiNG i i~ST~I~C T 10i~S tSSLIED 4=[q[}V-80 15: 12 Bk CMC PCCC
