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192-124
• • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 'ED AUG 0 7 2012 Mr. Jim Regg (,p 1 Alaska Oil and Gas Conservation Commission a I 333 West 7 Avenue _© '� Anchorage, Alaska 99501 1.&Y Subject: Corrosion Inhibitor Treatments of GPB AGI Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ___..r -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 t AGI -02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI -03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI -04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 AGI-05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 AGI-06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 AGI -07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 AGI-08 1930330 50029223480000 1.8 NA 1.8 NA 15.3 7/24/2011 AGI -09 1930350 50029223500000 Spirt conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~IAIS ON R~C~IVED DES a s zoo WELL COMPLETION OR RECOMPLETION REPORT A • ~~ Cl~ Comets 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended ~oa-c2s.~os 2oAAC2s.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1b. Well Class; ~n~~ pA ^ Development E "oratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 1/20/2010 12. Permit to Drill Number. 192-124 309-418 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded: 11/13/1992 13. API Number: 50-029-22307-00-00 4a. Location of Well (Governmental Section): Surfaces: ' ' 7. Date T.D. Reached: 11 /27/1992 14. Weli Name and Number. AGI-01 1583 FSL, 2390 FEL, SEC. 36, T12N, R14E, UM Top of Productive Horizon: 1262' FSL, 3248' FWL, SEC. 31, T12N, R15E, UM e. KB (ft above MSL): 49' GL (ft above MSL): 13.4' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1187 FSL, 3581' FWL, SEC. 31, T12N, R15E, UM 9. Plug Badc Depth (MD+TVD): 3915' 3490' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 688901 y_ 5979224 zone- ASP4 10. Total Depth (MD+TVD): 10850' 8571' 16. Property Designation: ADL 028301 & 034628 TPI: x- 694546 y- 5979047 Zone- ASP4 Total Depth: x- 694881 Y- 5978981 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: TVD 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, N offshore: N/A ft MSL ): 20. Thickness of Permafrost ( 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DSFL / CDL / CN /GR 22. Re-Drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD SErruac DEPTH nao SErrx~ DEwrH TvD HOSE Acnourrr CASIHG WT. PER FT. GRADE TOP B0T70b1 TOP BOTTOM 3izE CEN~NTMIG RECORD PULLED A ,~ " 1 1 1' 7 ' 24. Open to production or injection? ^ Yes ®No 25. TusarG RECORD If Yes, list each interval open (MD+TVD of To ~ Bottom Perforation Size and Number): SIZE DEPTH .SET MD PACKER SET nnD / ND ; p 7", 26#, NT-80 7152' - 10041' MD TVD MD TVD 5-1/2", 17#, L-80 10041' - 10129' 10049' / 7913' 26. ACfD, FRACTURE, GEMENT`SQUEEZE, ETC. ~ ~Q1~~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED _ ~ ~ f ~~;~;) ~' ~~ U ~ ~ 10082' Set EZSV, P8~A Perfs w/ 34 Bbls of Cement - " 9000' Set EZSV, Pump 67 Bbls of Cement 4150' Set EZSV (Cut & Pull 9-5/8" Casin f/ 3986') 3915' (TOW) Pum Kick Off Plu w/ 81 Bbls Cement - 27. PRODUCTION TEST Date First Production: Not on In'ection Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Teat: Hours Tested: Production For Test Period Ow-Bel: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-B®L: GAS-MCF: WATER-BBL: OIL GRAVmr-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ® No SidewaU Care(s) A~uired? ^ Yea ®No If Yes to either question, list formations and intervals gyred (MD+TVD of top and bottom of each), and summarize lithology and presence of oll, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, crore chips, photographs and laboratory analytical results ~;i~1~071. #~~ Y I None ' iF(~~ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE '`Sutxnit Original Onry ~. ~- /~ / o Ali ~/16~a on 29., GEOLOGIC MARKERS (List all formations and ma ncountered): 30. TION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations 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. Shublik 10233' 8060' None Top Sadlerochit 10241' 8067' Base Sadlerochit 10724' 8464' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoi is true and correct to the best of my knowledge. 9~ v ~~~ ~ tt~~ V Title: Drilling Technologist Date: Signed: Terrie Hubble AGI-01 192-124 309-418 Prepared By Name/Numher. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Frank Roach, 564-4373 INSTRUCTIOWS 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. 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. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Aftemating-Gas Injection, SaR Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 2t3. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the crorresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detaiad test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 1212009 Submit Original Only • • AGI-01, Well History (Pre Rig Sidetrack) Date Summary 12/13/2009 WELL S/I ON ARRIVAL. PULLED P-PRONG FROM 10,082' SLM / 10,117' MD. PULLED 5-1/2" PXN PLUG BODY FROM 10,090' SLM / 10,117' MD. TAGGED TD W/ 4.25" CENT & 2.50" S-BAILER AT 10716' SLM + 30' CORK = 10746' ELMD (-17' OF FILL) (sticky bottom). (sample of rubber debris and spring from wrsssv) LOC TT W/ 4.25" CENT & 5-1/2" TEL AT 10,097' SLM + 30' CORK = 10,127' ELMD. RAN DUAL PETREDAT SBHPS AS PER PROGRAM. LEFT WELL S/I, NOTIFY DSO ON DEPARTURE. 12/30/2009 MIRU. RIH w / PDS GR CCL log for depth control to set a cement retainer. Kill well w/ 1% KCL at 5.5 bpm. Prepare to change out BOPs. Nipple up 7 1/6" BOP's. 12/31/2009 Nipple up 7 1/6" BOP's. Function test BOP~s. Perform BOP test on 7 1/6" BOP's. Make up EZSV-B and kill well. Pump 650 bbls 1%KCI & RIH to 10000. RIH with HES EZSV-B 4.37" cement retainer. Re-kill the well. Correct to flag 10003', pump. 1/2" ball. Set cement retainer C~3 10082' CTM. PT retainer to 1000 psi. Called AOGCC representative, Chuck Scheve, who waived the right to witness the test. 1/2" ball has been recovered. 1/1/2010 RIH w /stinger. At 10000' Weather is at phase 2 and possibility going to phase 3, POOH. Secure well with night cap, PT night cap to 2000 psi. 1/3/2010 Off of weather standby at 06:00 1/3/2010. Begin clearing out snow and checking equipment. Pop on well and PT. PT coil, find coil has ice plug. RIH to warm CT up to melt plug. POOH to check BHA. Pop off well, BHA in tact. RBIH down to retainer set at 10,082'. Sting into retainer and circulate 1%KCI to cool wellbore. Pump 34 bbls 15.8# cement. Unsting from EZSV-B and pump out of hole. RIH w / BCF firing head & 5' 20DM gun, 4 spf. 1/4/2010 RIH w /BCF Firing head & 5' 20DM gun, 4 spf. Perform an MIT on retainer & cement oressu_r~un to _ 1051 psi hold for 30 mins lost 17 psi in the first 15 mins staved the same in 30 mins. Pumped down the IA and pressured up to 656 psi in 1.6 bbls away, appears the IA has a ice plug. Confirmed we have holes in gun & recovered 1/2" ball. RIH to 1000', at 1015'. Circulate 160 degree 1 %KCI down CT up backside at minimum rate to try and thaw plug in IA. Line up to pump McOH down IA to determine if ice plug is thawing. Pump at 0.4 bpm, Pressure increasing. At 1.2 bbls away, IA psi= 656. Pressure increased to 778 psi, drop rate to 0.3 bpm, pressure seemed to stabilize at 770 psi at 0.3 bpm. Pressure stayed at 770. Line up to pump down tubing to try to establish infectivity down tubing through tubing punch holes to cretaceous leak at 7150'.. 1/4/2010 Online w/ McOH at 0.4 bpm. WHP increase to 2050, IA icreased to 675 (thermal effects of pumping) once pumping down backside stopped, W HP steady at 2050, IA slowly decreases back to 660. POOH. Make up TCP to re-shoot through 5 1/2" tubing. Guns fired, pumped down the IA, got good Tx IA communication. Tagging at tubing hanger with 7" EZ drill SVB packer OD 5.50". Install WFD knuckle joint. 1/5/2010 Unable to get past tubing hanger with 7" EZ drill SVB squeeze packer with a OD of 5.5", add a WFD knuckle joint. RIH to 7 x 5 1/2 crossover. Pick up and park at 9000'. Launch 1/2" ball pump ball to seat. After 53 bbls (CT volume = 41 bbls), ball did not seat. Drop 1/2" steel ball. After 60 bbls, ball did not seat. POOH. At surface, break down HES EZSV-B and setting tool. No balls recovered. Break down and inspect MHA, no balls recovered. Make up nozzle straight onto coil connector. Pop on well, line up to pump water through choke down CT out to tanks to try and recover balls. Both balls found inside of EZSV-B setting tool as tools were being loaded up on to HES truck. Swap to McOH to freeze protect CT and surface lines. HES headed to shop to troubleshoot 7" EZSV-B & setting tool. HES back on location. PJSM to discuss making up tools. Open swab. RIH w/ 7" EZSV-B & setting tool. 1/6/2010 Stung into retainer, pump 67 bbls of 15.8 ppg cement. Freeze protect well from 2500' with 95 bbls of 60/40 methanol. Job is complete. 1/7/2010 WELL SHUT-IN UPON ARRIVAL. INITIAL T/I/O = /0/200 PSI. SSV CLOSED ON ARRIVAL. ON STANDBY UNTIL WINDS ARE SAFER TO RIG-UP 7" PRESSURE GEAR, CONSTANT SPEEDS OF 25 MPH, WITH GUSTS FROM 29-32 MPH. TREE CAP NOT REMOVED. Page 1 of 2 AGI-01, Well History (Pre Rig Sidetrack) Date Summary 1/7/2010 WELL SHUT IN ON ARRIVAL. DRIFTED W/ 5.74" CENT, S. BAILER TAGGED TOC AT 8,956' SLM, BAILER EMPTY. WELL LEFT SHUT IN, DSO WALK THROUGH ON DEPARTURE. 1/8/2010 INITIAL T/I/0=0/0/200. RIG UP FOR TBG PUNCH. O-RING IN OTS UNABLE TO HOLD PRESSURE DURING PT. REPLACE O-RING, DIFFICULTY GETTING INTERNAL RING TO RESEAT DUE TO LOW TEMPERATURES, -36 DEGF WITH 10-15 MPH. MONITORING WEATHER CONDITIONS CLOSELY. DELAYS DUE TO WAITING ON VAC TRUCK TO SUCK OUT SLOP TANK PRIOR TO RUNNING PT. 1/9/2010 T/I/0=0/240/200 Assist E-Line Circ Out Well (RWO Prep) Pumped 4 bbls 60/40 meth, 962 bbls 9.8# Brine, 2 bbls 60/40 meth & 15 bbls DSL down TBG while taking returns up IA, through choke skid to open top tanks. Pumped 1 bbl 60/40 meth & 6 bbls DSL through hardline & choke skid for FP. Attempted to U- Tube TBG to IA. TBG and IA both on a vac. Bullheaded 10 bbls DSL down IA to FP. Stby for E-Line to cut Tbg. 1/9/2010 VAC OUT SLOP TANK. PT COMPLETED. UNSTABBING TO ARM TBG PUNCH. SURFACE AND VISUAL CONFIRMATION OF SHOT INTERVAL 8930' - 8935'. SHOT STRING SHOT FROM 7150' - 7160'. 1/10/2010 Assist E-Line w/ CMIT TxIA FAILED to 1500 psi (Sidetrack). Pumped 13 bbls diesel down IA before catching pressure. Established LLR of 1.9 BPM C~ 1500 psi for 15 bbls. Bled down WHP. FWHP = 0/0/120 SW, WV shut. SSV, MV, IA, OA open. 1/10/2010 STRING SHOT SUCCESSFULLY SHOT FROM 7150' - 7160', GHAT 5.5" CHEMICAL_CUTTER TO CUT.. 7 INCH CASING AT 7152.4'. RDMO. FINAL T/I/0= 0/0/190. SSV=C, WING=C, CASING=OTG, MASTER=O. DSO NOTIFIED. WELL SHUT IN UPON DEPARTURE. JOB COMPLETE. 1/11/2010 T/I/0=0/50/180. Temp=Sl. Bleed WHP's to 0 psi. (RWO prep). IA FL C~ Surface. OA FL C«3 Surface. Bled IAP from 50 psi to 0 psi in 1 hour 15 minutes (7 bbl of fluid returned during bleed). OAP decreased 20 psi to 160 psi during IA bleed . Bled OAP from .160 psi to 140 psi in 45 minutes (8 bbl fluid returned), SI to have Vac truck empty bleed trailer, continue bleed. Bled OAP for an additional 40 minutes with no change in OAP (10 bbl returned for a total of 18 bbl bled from OA). Rig down for end of shift. Monitor for 15 minutes during rig down. No change in TP during bleeds or monitor. IAP increased 20 psi during OA bleed & monitor. No change in OAP during monitor. Final WHPs=0/20/140. SV & WV =CLOSED. MV &SSV =OPEN. IA & OA = OTG. NOVP. 1/12/2010 T/I/O=BPV/20/140. Temp=Sl. Bleed WHPs to 0 psi. WHPs unchanged since day crew. OA FL C~ surface. Bled OAP to a tank from 140 psi to 50 psi in 5 hrs 30 mins (30 bbls). Monitored OAP for 30 mins. OAP & OA FL were unchanged. Job incomplete. Final WHPs=6PV/20/50. SV, WV=Open. SSV, MV=Open. IA & OA=OTG. NOVP. 1/13/2010 T/I/O=BPV/15/70. Temp= SI. Bleed WHP's to 0 psi (RWO prep). No scaffold. OA FL C«? surface. Bled OAP to OT from 70 psi to 40 psi in 1 hour (5 bbls fluid). 30 minute monitor. OAP increased 10 psi. Job incomplete. IA,OA=OTG. Doyon 14 has control of valves. 1/13/2010 T/I/O=6PV/20/50. Temp=Sl. Monitor WHPs (pre-rig). WHPs unchanged overnight. SV, WV=Closed. SSV, MV=Open. IA & OA=OTG. NOVP. Page 2 of 2 BP EXPLORATION Page 1 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/7/2010 21:00 - 00:00 3.00 MOB N WAIT PRE 1/8/2010 00:00 - 00:00 24.00 MOB N WAIT PRE 1/9/2010 00:00 - 04:00 4.00 MOB N WAIT PRE 04:00 - 12:00 8.00 MOB P PRE 12:00 - 00:00 12.00 MOB N WAIT PRE 1/10/2010 00:00 - 00:00 24.00 MOB N WAIT PRE 1/11/2010 00:00 - 00:00 24.00 MOB N WAIT PRE 1/12/2010 00:00 - 03:00 3.00 MOB N WAIT PRE 03:00 - 22:30 19.50 MOB P PRE 22:30 - 23:00 0.50 MOB P PRE 23:00 - 23:30 0.50 MOB P PRE 23:30 - 00:00 0.50 MOB P PRE 1/13/2010 00:00 - 02:00 2.00 MOB PRE 02:00 - 03:00 1.00 MOB PRE 03:00 - 03:30 0.50 MOB PRE RIG RELEASED FROM CONOCO PHILLIPS WELL 2L-326 ON 6 JANUARY 2010 AT 14:30 HRS. MOVE RIG TO MILNE POINT TURN-OFF. ARRIVE AT TURN-OFF AT 21:00 HRS 7 JANUARY 2010. WAIT ON BP SECURITY AT THE MILNE POINT TURN-OFF IN ORDER TO CONTINUE THE RIG MOVE TOWARDS AGI-01 A. WAITING ON BP SECURITY AT THE MILNE POINT TURN-OFF DUE TO THE NABOBS 16E RIG MOVE ON SPINE ROAD. WAIT ON SECURITY AT THE MILNE POINT TURN-OFF DUE TO THE NABOBS 16E. MOVE THE RIG FROM THE MILNE POINT TURN-OFF TO IN FRONT OF MOBIL PAD AND STOPPED. UNABLE TO CROSS THE KUPARUK RIVER BRIDGE DUE TO AMBIENT TEMPERATIRE BEING BELOW -35 DEG F. STOPPED IN FRONT MOBIL PAD. UNABLE TO CROSS THE KUPARUK RIVER BRIDGE DUE TO AMBIENT TEMPERATIRE BEING BELOW -35 DEG F. WAIT IN FRONT OF MOBIL PAD FOR THE WEATHER TO WARM UP ABOVE -35 DEG F IN ORDER TO PLACE RIG MATS ACROSS THE KUPARUK RIVER BRIDGES AND THEN MOVE THE RIG ACROSS THE BRIDGE. WORKED ON ITEMS FROM BILL HOPKINS AUDIT. WAITING IN FRONT OF MOBIL PAD FOR THE WEATHER TO WARM UP ABOVE -35. DURING A BREAK IN THE WEATHER TODAY WHEN IT WARMED UP TO -31 CH2MHILL WAS ABLE TO PLACE SOME OF THE RIG MATS ACROSS THE KUPARUK BRIDGE BUT HAD TO SHUT DOWN WHEN THE WEATHER WENT BELOW -35. RIG CREWS STILL WORKING ON SOME ITEMS FROM THE BILL HOPKINS AUDIT AND DOING TABLE TOP DRILLS. WAITING ON THE WEATHER TO WARM UP IN ORDER TO MOVE THE RIG ACROSS THE KUPARUK RIVER BRIDGES. CH2MHILL BEGAN TO LAY MATS ON THE BRIDGES AGAIN BECAUSE THE WEATHER WARMED UP ABOVE -35. MOVE RIG FROM IN FRONT OF MOBIL PAD AND CROSS KUPARUK RIVER BRIDGE. CONTINUE MOVE ON SPINE ROAD. TURN ON TO OXBOW ROAD. TURN ON WEST DOCK AND CONTINUE MOVE TO AGI PAD. ARRIVE AT AGI PAD. START CHARGING RIG DAY RATE TO AFE. POSITION RIG. PJSM ON REMOVING BOOSTER WHEELS (REAR ONLY FOR RIG MOVE). REMOVE REAR BOOSTER WHEELS. TAKE ON FUEL AND WATER. POSITION BOP STACK TO BE LOADED INTO CELLAR CONTINUE TO TAKE ON FUEL AND WATER. POSITION BOP STACK TO BE LOADED INTO CELLAR LAY RIG MATS IN FRONT OF BOP CRADLE. WARM UP RIG. POSITION RIG OVER BOP CRADLE AND LOAD BOP STACK INTO CELLAR. PJSM FOR EXTENDING CONVEYOR. Printetl: 2/52010 1 L'Oy:52 AM • BP EXPLORATfON Page 2 awe Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: i Date From - To !Hours Task Code NPT Phase ' Description of Operations 1/13/2010 03:30 - 06:00 2.50 MOB PRE EXTEND CONVEYOR AND LOCK INTO PLACE. HOOK UP KOOMEY LINES TO BOP STACK. 06:00 - 09:00 3.00 MOB PRE LAY HERCULITE AROUND WELL AND SET RIG MATS TO COVER RIG FOOTPRINT. 09:00 - 10:00 1.00 MOB PRE MOVE RIG ONTO RIG MATS AND PREPARE TO MOVE OVER WELL. 10:00 - 12:00 2.00 MOB N WAIT PRE WAIT ON DSM TO BLEED WELLHEAD PRESSURES. WHILE WAITING ON DSM, CHANGE OUT DRIVE BEARING ON #1 CONVEYOR. 12:00 - 18:00 6.00 MOB PRE BLEED WELL PRESSURES TO ZERO. PRESSURE KEPT BUILDING AFTER ANNULI SHUT-IN. ULTIMATELY BLED 10 BBLS BACK AND PRESSURES STABILIZED AT ZERO. 18:00 - 20:30 2.50 MOB PRE SPOT AND SHIM RIG OVER WELL. LAY RIG MATS FOR ROCK WASHER AND CUTTINGS TANK. LAY HERCULITE ON TOP OF RIG MATS AND SPOT ROCKWASHER AND CUTTINGS TANK . 20:30 - 21:00 0.50 MOB PRE PJSM ON SKIDDING RIG FLOOR OVER WELL. 21:00 - 00:00 3.00 MOB PRE SKID RIG FLOOR OVER WELL. PROBLEMS WITH HYDRAULICS WHILE SKIDDING RIG FLOOR. HOOK UP SERVICE LINES TO RIG FLOOR. THAW OUT PITS WITH 290 BBLS HOT WATER. HOOK UP SUCTION LINES IN PITS. CH2MHILL HARDLINE CREW TO LAY HARDLINE FROM CELLAR TO OPEN TOP TANK. 1/14/2010 00:00 - 07:00 7.00 MOB PRE CONTINUE TO WARM UP AND THAW PITS AND LINES IN RIG. TAKE ON BRINE AS PITS BECOME READY. CLEAN RIG FLOOR IN PREPARATION FOR RIG OPERATIONS. 07:00 - 11:30 4.50 MOB PRE CONDUCT RIG INSPECTION/PERSONAL SAFETY AUDIT WITH BILL HOPKINS-AND ALLEN GRAFF. DURING INSPECTION, LOAD AND STRAP 5" DRILLPIPE AND TAKE ON BRINE. 11:30 - 12:30 1.00 MOB PRE PRE-SPUD/SAFETY MEETING WITH BOTH CREWS. EMPHASIS ON ADDITIONAL MEASURES/PRECAUTIONS FOR THIS WELL AND NEW SITE CONTROL POLICIES FOR ADW. 12:30 - 16:00 3.50 MOB PRE FINISH RIG INSPECTION/PERSONAL SAFETY AUDIT WITH HOPKINS/GRAFF. RIG ACCEPTED 16:00 HRS. 16:00 - 20:00 4.00 WHSUR WHDTRE RU SWAB VALVE AND SWAB CAP TO TREE. RU TO TEST T X IA AND OA. 20:00 - 21:30 1.501 WHSUR AT 500 21:30 - 23:00 1.50 WHSUR WHDTRE RU LUBRICATOR AND TEST TO 500 PSI. PULL BPV WITH LUBRICATOR. RD LUBRICATOR. 23:00 - 23:30 0.50 WHSUR WHDTRE LINE UP TO PUMP DOWN IA AND TAKE RETURNS UP THE TUBING AND OUT TO THE OPEN TOP TANK. REVERSE CIRCULATE 50 BBL 9.8 PG BRINE AT 3 BPM, 400 PSI TO CLEAR TUBING OF DIESEL FREEZE PROTECT. 19 BBLS DIESEL RECOVERED 23:30 - 00:00 0.50 WHSUR WHDTRE LINE UP TO PUMP DOWN TUBING AND TAKE RETURNS UP THE IA AND OUT TO THE OPEN TOP TANK. CIRCULATE 50 BBL SAFE-SURF-O PILL FOLLOWED BY 9.8 Printed: 2/5/2010 11:09:52 AM • • BP EXPLORATION Page 3 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2010 123:30 - 00:00 I 0.501 WHSUR 1/15/2010 100:00 - 02:30 2.501 WHSUR 02:30 - 03:00 0.50 WHSUR 03:00 - 06:30 3.50 WHSUR 06:30 - 08:00 I 1.501 WHSUR 08:00 - 10:00 2.001 WHSUR 10:00 - 18:00 8.00 BOPSU 18:00 - 23:00 5.00 BOPSU 23:00 - 00:00 1.00 BOPSU 1/16/2010 00:00 - 11:30 11.50 BOPSU P 11:30 - 12:00 I 0.501 BOPSUR P 12:00 - 14:30 I 2.501 WHSUR I P 14:30 - 16:00 I 1.501 WHSUR I P 16:00 - 18:00 ( 2.001 WHSUR I P 18:00 - 19:00 I 1.001 PULL I P WHDTRE PPG BRINE. CIRCULATE 80 BBLS TOTAL THE LONG WAY AT 3 BPM, 150 PSI TO CLEAR IA OF DIESEL FREEZE PROTECT. 12 BBLS DIESEL RECOVERED. WHDTRE CIRCULATE 9.8 PPG BRINE SURFACE TO SURFACE THROU H TUBING CUT AT 7152'. CIRC RATE 3 BPM AT 250 PSI. WHDTRE RUN AND SET TWC IN WELLHEAD WITH T-BAR. WHDTRE RU AND PERFORM ROLLING TEST ON TWC FROM BELOW TO 500 PSI. FLUID LEAKING BY TWC. LINE UP TEST PUMP AND TEST TWC FROM ABOVE TO 4000 PSI. HOLD TEST FOR 10 MINUTES. GOOD TEST. LINE UP AND ATTEMPT ROLLING TEST ON TWC FROM BELOW AGAIN TO 500 PSI. FLUID STILL LEAKING PAST TWC WITH FLOW DIMINISHING. SHUT DOWN, BLEED OFF AND RU TO TEST THIRD TIME. 500 PSI ROLLING TEST GOOD. TOTAL VOLUME PUMPED FOR BELOW TEST: 12.6 BBLS. WHDTRE ND TREE AND ADAPTER FLANGE. REMOVE FROM CELLAR (NEW TREE TO BE INSTALLED AT COMPLETION OF WELL). WHDTRE INSPECT WELLHEAD AND TUBING HANGER. CLEAN LIFT THREADS ON TUBING HANGER. CHECK NSCC LIFT THREADS BY SCREWING ON CROSSOVER. 9-TURNS SUCCESSFUL. WHDTRE NU BOPE. INSTALL HCR CHOKE AND KILL VALVES. RU CHOKE LINE, RISER AND FLOWLINE. WHDTRE INSTALL REDRESSED 4-1/2" X 7" VBR'S IN TOP OF STACK. INSTALL REDRESSED 3-1/2" X 6" VBR'S IN BOTTOM OF STACK. WHDTRE TE T BOPE. WHDTRE TEST BOPE PER BP/AOGCC REQUIREMENTS TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH WITH 5" AND 7" TEST JOINTS. TEST ANNULAR TO 250 PSI LOW, 3500 PSI HIGH WITH 5" TEST JOINT ONLY. NEEDED TO THAW TEST MANIFOLD, TROUBLESHOOT TOP DRIVE ISSUES, FUNCTION VBR THREE TIMES BEFORE SOLID TEST, TIGHTEN LEAKING CHOKE HCR LINE HOSE. TEST WITNESSED BY AOGCC REP JOHN CRISP, BP WSIS FERGUSON, HEFLEY, BUZBY AND ROACH, AND DOYON TPS EGHOLM AND GOCHENAUER. WHDTRE RD TEST EQUIPMENT. BLOW DOWN CHOKE AND KILL LINES. WHDTRE RU DSM LUBRICATOR. TEST LUBRICATOR TO 500 PSI FOR 5 MINUTES. PULL TWC. RD DSM. DECOMP MAKE UP CROSSOVER TO LANDING JOINT. MAKE UP TO HANGER. BACK OUT LOCK DOWN SCREWS. -UNSEAT HANGER WITH 2O5K UP WT. - PULL HANGER TO RIG FLOOR WITH 2O2K UP WT. DECOMP CIRCULATE BOTTOMS UP. 250 GPM ~ 190 PSI. LOSSES DURING CIRC -40 BBUHR. -WHILE CIRCULATING, RU TO LD 7" INJECTION TUBING AND DUAL CONTROL LINE DECOMP LD LANDING JOINT AND HANGER. HOOK UP DUAL Printed: 2/5/2010 11:09:52 AM • BP EXPLORATION Page 4 o Operations Summary Report Legal Well Name: AGI-01 Common. Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2010 18:00 - 19:00 1.00 PULL P DECOMP CONTROL LINE TO SCHLUMBERGER SPOOLER. 19:00 - 22:00 3.00 PULL P DECOMP LD 7", 26#, L-80 TUBING AND DUAL CONTROL LINE FROM 7,152' TO 4,950'. FILL HOLE EVERY 10 JOINTS. - STOP AT SSSV. - 51 BBLS LOST TO PC LEAK WHILE LD TO SSSV. AVG LOSS RATE: 15 BBL/HR. 22:00 - 22:30 0.50 PULL P DECOMP RD SCHLUMBERGER CONTROL LINE SPOOLER. 22:30 - 00:00 1.50 PULL P DECOMP LD 7" 26# L-80 NSCC TUBING FROM 4,950' TO 3,470'. 1/17/2010 00:00 - 00:30 0.50 PULL P DECOMP INSPECT AND SERVICE TOP DRIVE, BLO K , A DRAW WORKS. 00:30 - 03:30 3.00 PULL P DECOMP lD 7", 26#, L-80, NSCC TUBING FROM 3,470' TO SURFACE. - RECOVERED 28 SS BANDS, 180 JOINTS, 1 SSSV, 2 FLOW COUPLINGS, 2 PUP JOINTS, 1 CUT JOINT -CUT JOINT LENGTH 16.99' - CHEMICAL CUT LOOKED GOOD -GENERAL CONDITION OF TUBING IS GOOD. - 262 BBLS FLUID LOST WHILE LD TUBING FROM SSSV TO CUT. 03:30 - 04:30 1.00 PULL P DECOMP RD 7" HANDLING TOOLS, CLEAN AND CLEAR RIG FLOOR. 04:30 - 06:00 1.50 BOPSU P DECOMP RU TO TEST LOWER 3-1/2" X 6" VBR AND BLIND RAMS. 06:00 - 09:00 3.00 BOPSU P DECOMP TEST LOWER 3-1/2" X 6" VBR AND BLIND RAMS TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH. 09:00 - 09:30 0.50 BOPSU P DECOMP RD TEST EQUIPMEMNT. BLOW DOWN CHOKE AND KILL LINES. 09:30 - 20:30 11.00 CLEAN P DECOMP PU, BHA #1 8 1/2" BIT, CASING CSRAPER, BOOT BASKET, FLOAT SUB AND RIH ON 5" DP PICKING UP SINGLES FROM THE PIPE SHED TO 7,151' - TAG UP ON 7" TUBING STUB AT 7,151' - PU WT: 175K, SO WT: 145K. - FILL PIPE EVERY 25 STANDS 20:30 - 21:30 1.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP AT 390 GPM, 550 PSI. -18 BBLS LOST DURING CIRC. 21:30 - 00:00 2.50 CLEAN P DECOMP POH FROM 7,151' TO 2,130'. 1/18/2010 00:00 - 01:30 1.50 CLEAN P DECOMP POH FROM 2,130' TO SURFACE. -BOOT BASKETS WERE CLEAN 01:30 - 02:30 1.00 CLEAN P DECOMP LD BHA #1. CLEAN AND CLEAR RIG FLOOR. 02:30 - 06:30 4.00 EVAL P DECOMP PJSM WITH SLB E-LINE CREW. MOBILIZE E-LINE EQUIPMENT TO RIG FLOOR AND RIG UP LUBRICATOR WITH PUMP-IN SUB AND PACKOFF. 06:30 - 09:30 3.00 EVAL P DECOMP R H W TH .LOG UP FROM 5,100' TO 200' IN CEMENT EVAULATION AND CORROSION MODE. 09:30 - 11:00 1.50 EVAL P DECOMP LAY DOWN USIT TOOLS. 11:00 - 13:00 2.00 DHB P DECOMP PREP FIRING HEAD FOR EZSV. MAKE UP EZSV TO FIRING HEAD. ~ 13:00 - 14:30 1.50 DHB P DECOMP ET EZSV. POOH. 14:30 - 16:00 1.50 DHB P DECOMP RD E-LINE AND LUBRICATOR. 16:00 - 16:30 0.50 DHB P DECOMP CLOSE BLIND RAMS AND TEST EZSV TO 2,500 PSI FOR 10 MINUTES. GOOD TEST. 16:30 - 19:30 3.00 BOPSU P DECOMP PULL WEAR RING. INSTALL TEST PLUG AND 9-5/8" TEST JOINT. CHANGE TOP RAMS TO 9-5/8" FIXED PIPE RAMS. 19:30 - 20:00 0.50 BOPSU P DECOMP TEST 9-5/8" RAM 5 MINUTES EACH TEST. BOTH TESTS GOOD. Printed: 2/5/2010 11:09:52 AM • BP EXPLORATION Page 5~6. .Operations Summary Report. Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Daterr From - To Hours Task ~ Code NPT Phase Description of Operations 1/18/2010 20:00 - 21:00 1.00 BOPSU P DECOMP RIG DOWN BOP TESTING EQUIPMENT. LD 9-5/8" TEST JOINT. CLEAN AND CLEAR RIG FLOOR. 21:00 - 21:30 0.50 STCTPL P DECOMP PU COMPONENTS FOR BHA #2 -CASING CUTTER -8-1/2" STABILIZER 21:30 - 00:00 2.50 STCTPL P DECOMP RIH FROM SURFACE TO 3,875'. 1/19/2010 00:00 - 00:30 0.50 STCTPL P DECOMP INSPECT AND SERVICE TOP DRIVE, BLOCKS, AND DRAWWORKS. 00:30 - 01:00 0.50 STCTPL P DECOMP RIH FROM 3,875' TO 4,155' AND TAG EZSV. - PU WT: 120 SO WT: 116 01:00 - 01:30 0.50 STCTPL P DECOMP PJSM ON FLUID SWAP, CASING CUT, AND OA CIRC OUT. 01:30 - 02:30 1.00 STCTPL P DECOMP DISPLACE 9.8 PPG BRINE OUT OF WELL WITH 9.2 PPG LSND. - DISPLACE 250 GPM AT 900 PSI 02:30 - 03:00 0.50 STCTPL P DECOMP POH 2 STANDS. PU SINGLE JOINT. ENGAGE PUMPS TO OPEN KNIVES. SLACK OFF AND LOCATE COLLAR AT 3,975'. SLACK OFF 11' TO CUT DEPTH AT 3.986'. WITH PUMPS OFF, ESTABLISH CUTTING PARAMETERS - PU WT: 120K; SO WT: 116; ROT WT: 120K, 3K TORQUE AT 40 RPM. - OA PRESSURE 110 PSI 03:00 - 04:00 1.00 STCTPL P DECOMP LINE UP TO TAKE RETURNS FROM OA VALVE TO OPEN TOP TANK. BLEED OFF OA PRESSURE PRIOR TO CASING CUT. - OA PRESSURE AT ZERO BEFORE CUTTING CASING. BEGIN CASING CUTTING. - ROTATING 80 RPM CONTSTANT - STAGE UP PUMP PRESSURE FROM 350 PSI TO 900 PSI FINAL TO FULLY EXTEND KNIVES. - TORQUE BOUNCED FROM 1-5K. SETTLED AT 2K WHEN KNIVES FULLY EXTENDED. - CLOSE BAG AND PUMP DOWN DRILLPIPE, LOOKING FOR RETURNS OUT OA. 84 GPM ~ 150 PSI TAKING RETURNS OUT OA. SHUT DOWN PUMPS AND OPEN BAG. 04:00 - 06:00 2.00 STCTPL P DECOMP SPOT SAFE-SURF-O AND HIGH VIS SWEEP DOWN DRILLPIPE. - 190 GPM ~ 850 PSI. CLOSE BAG AND PUMP SWEEP TAKING RETURNS OUT OA AND TO OPEN TOP TANK. - 150 GPM ~ 500 PSI - DIESEL FREEZE PROTECT INITIAL RETURNS. 150 BBLS RECOVERED - BRINE RETURNS AFTER 180 BBLS DISPLACEMENT - OLD MUD IN RETURNS AT 222 BBLS DISPLACEMENT -NEW LSND MUD RETURNS AT 253 BBLS DISPLACEMENT - 280 BBLS TOTAL DISPLACEMENT SHUT DOWN PUMPS. CONFIRM WELL DEAD. 06:00 - 08:30 2.50 FISH P DECOMP BLOW DOWN TOP DRIVE AND HARDLINE TO OPEN TOP TANK. ATTEMPT TO OPEN PUMP-OUT SUB. NO SUCCESS. Printed: 2/5/2010 11:09:52 AM • • BP EXPLORATION Page 6e~36 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours ..Task Code NPT Phase Description of Operations 1/19/2010 06:00 - 08:30 2.50 FISH P DECOMP POH FROM 3,986' TO SURFACE. 08:30 - 09:30 1.00 FISH P DECOMP LAY DOWN CUTTER ASSEMBLY. CLEAN AND CLEAR RIG FLOOR. - KNIFE WEAR PATTERN SHOWED EVEN WEAR. 09:30 - 10:00 0.50 FISH P DECOMP PICK UP AND MAKE UP SPEAR ASSEMBLY WITH PACKOFF. 10:00 - 10:30 0.50 FISH P DECOMP RIH AND SPEAR CASING HANGER. VERIFY GRAPPLE IS SET 10:30 - 11:00 0.50 FISH P DECOMP BACK OUT LOCK DOWN SCREWS AND ATTEMPT TO UNSEAT HANGER. - P/U TO 225K. SLACK OFF. - WORK P/U WT TO 300K. SLACK OFF. - WORK PIPE BETWEEN 225K - 350K WHILE PUMPING 84 GPM ~ 250 PSI. RETURNS AT SURFACE. - CONTINUE TO WORK PIPE, INCREASING PUMP RATE TO 120 GPM ~ 500 PSI. - PIPE BROKE LOOSE. PU WT NOW 280K. 11:00 - 11:30 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH SPEAR, TAKING RETURNS OVER SHAKERS. - STAGE UP PUMPS TO FINAL RATE 550 GPM ~ 450 PSI. WHILE CIRCULATING, MOBILIZE CASING HANDLING EQUIPMENT TO RIG FLOOR. 11:30 - 12:00 0.50 FISH P DECOMP PULL HANGER TO FLOOR. -CIRCULATE WHILE PULLING TO FLOOR. 120 GPM ~ 180 PSI. 12:00 - 13:30 1.50 FISH P DECOMP RELEASE SPEAR AND LAY DOWN SAME. BACK OUT HANGER AND PUP JOINT. AND LAY DOWN SAME. RIG UP TO CIRCULATE. 13:30 - 15:30 2.00 FISH P DECOMP RU DOUBLE STACKED TONGS AND CASING HANDLING EQUIPMENT. -WHILE RIGGING UP, CIRCULATE 170 GPM ~ 150 PSI. 15:30 - 22:30 7.00 FISH P DECOMP LAY DOWN 9-5/8", 47#, L-80, NSCC CASING TO CUT AT 3,986'. - INTIAL CASING LOOKED GOOD - FROM JOINT 80 TO CUT JOINT, THICK MUD CAKED ON OD OF CASING. - CUT JOINT LENGTH: 5.75' - CUT FLARE OD: 10.25" - TOTAL JOINTS RECOVERED: 101 PLUS CUT JOINT. 22:30 - 00:00 1.50 FISH P DECOMP RIG DOWN CASING HANDLING EQUIPMENT. CLEAN AND CLEAR RIG FLOOR. 1/20/2010 00:00 - 02:00 2.00 FISH DECOMP CONTINUE TO RIG DOWN CASING HANDLING EQUIPMENT. CLEAN AND CLEAR RIG FLOOR. 02:00 - 04:00 2.00 BOPSU DECOMP INSTALL TEST PLUG AND 5" TEST JOINT. CHANGE TOP RAMS TO 4-1/2" X 7" VBR. FILL STACK AND RIG UP TEST EQUIPMENT. Printed: 2/5/2010 11:09:52 AM • • BP EXPLORATION Page 7 Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From-- To Hours Task Code NPT Phase Description. of Operations 1/20/2010 04:00 - 04:30 0.50 BOPSU DECOMP TEST 4-1/2" X 7" VBR TO 250 PSI LOW, 500 PSI HIGH FOR 5 MINUTES EACH. -GOOD TEST 04:30 - 05:00 0.50 BOPSU DECOMP RIG DOWN BOP TEST EQUIPMENT. PULL TEST JOINT AND TEST PLUG. 05:00 - 08:30 3.50 STCTPL DECOMP MOBILIZE 3-1/2" HANDLING EQUIPMEMT TO RIG FLOOR. MAKE UP 3-1/2", 9.2 #, NSCT STINGER BHA TO 937'. 08:30 - 10:30 2.00 STCTPL DECOMP OWLY ENTER 9-5/8" CASING STUB. CONTINUE TO RIH. TAG EZSV AT 4,150' PULL UP TO HAVE CEMENT HEAD AT GOOD WORKING HEIGHT. MULESHOE AT 4,145'. 10:30 - 12:30 2.00 STCTPL DECOMP MAKE UP HEAD PIN AND CEMENT LINE. CIRCULATE 390 GPM ~ 350 PSI. 12:30 - 13:00 0.50 STCTPL DECOMP PRE-JOB SAFETY MEETING WITH RIG CREW AND SCHLUMBERGER CEMENTERS. 13:00 - 14:30 1.50 STCTPL DECOMP BEGIN BATCH MIXING 17.0 PPG CEMENT - PUMP 5 BBLS MUD PUSH II -PRESSURE TEST LINES TO 4500 PSI - PUMP 36 BBLS MUDPUSH II; 3.9 BPM, 205 PSI - PUMP 81 BBLS 17.0 PPG CEMENT PLUG - - 30 BBLS AWAY 4.8 BPM, 340 PSI - - 40 BBLS AWAY 4.8 BPM, 301 PSI - - 50 BBLS AWAY 4.7 BPM, 310 PSI - - 70 BBLS AWAY 4.8 BPM, 333 PSI - - 81 BBLS AWAY 1.8 BPM, 228 PSI -PUMP 5 BBLS MUDPUSH II; 2.7 BPM, 255 PSI SWITCH TO RIG PUMPS AND BEGIN DISPLACEMENT WITH 9.2 PPG LSND MUD - DISPLACE AT 9.2 BPM; INITIAL PRESSURE 190 PSI. - - 45 BBLS AWAY 9.1 BPM, 590 PSI - - 55 BBLS AWAY 9.1 BPM, 590 PSI SHUT DOWN PUMPS. RIG DOWN SCHLUMBERGER CEMENTERS. 14:30 - 16:30 2.00 REMCM DECOMP 16:30 - 18:00 1.50 REMCM DECOMP DROP F AM WIPE B DOWN DRILLPIPE AND CIRCULATE 1.5 BOTTOMS UP WHILE RECIPROCATING PIPE. - 380 GPM ~ 270 PSI - PU WT 100K; SO WT 100K - NO CEMENT OBSERVED IN RETURNS, BUT INCREASED PH WAS NOTED. 18:00 - 19:30 1.50 REMCM DECOMP FLOW CHECK WELL. ZERO FLOW. POH TO 93T 19:30 - 22:00 2.50 REMCM DECOMP RU 3-1/2" HANDLING EQUIPMENT. PULL 3-1/2" STINGER BHA FROM 937' TO SURFACE. 22:00 - 00:00 2.00 REMCM DECOMP LAY DOWN 3-1/2" HANDLING EQUIPMENT. CLEAN AND Printed: 2/5/2010 11:09:52 AM ~JQ~ ~~~ BP' EXPLORATION Page 8 ofd Operations Summary Report Legal Well Name: AGI-01 Common Well Name: AGI-01 Spud Date: 11/13/1992 Event Name: REENTER+COMPLETE Start: 1/6/2010 End: Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT _Phase Description of ..Operations 1/20/2010 22:00 - 00:00 2.00 REMCM DECOMP CLEAR RIG FLOOR. 1/21/2010 00:00 - 02:00 2.00 REMCM P DECOMP CLEAN RIG WHILE WAITING ON CEMENT TO BUILD 500 PSI COMPRESSIVE STRENGTH. 02:00 - 03:00 1.00 REMCM P DECOMP PJSM ON PICKING UP DRILLPIPE. PU HEAVY WEIGHT AND DRILLPIPE SINGLES FOR DRILLPIPE MANAGEMENT AND IN PREPARATION FOR STRIPPING DRILL 03:00 - 03:30 0.50 REMCM N RREP DECOMP REPAIR HYDRAULIC LEAK IN PIPE SKATE. 03:30 - 04:00 0.50 REMCM P DECOMP CONTINUE TO PICK UP DRILLPIPE SINGLES. 04:00 - 04:30 0.50 REMCM P DECOMP PRE-JOB MEETING FOR STRIPPING DRILL. 04:30 - 08:00 3.50 REMCM P DECOMP CONDUCT STRIPPING DRILL WITH BEATTY CREW. - STRIPPED IN TWO STANDS OF DRILLPIPE POST DRILL DEBRIEF WITH ALL PARTIES INVOLVED. 08:00 - 09:00 1.00 REMCM P DECOMP POH. RACK BACK DRILLPIPE. 09:00 - 09:30 0.50 REMCM P DECOMP INSPECT AND SERVICE TOP DRIVE, BLOCKS, AND DRAW WORKS. 09:30 - 13:00 3.50 REMCM P DECOMP RIH ON SINGLES TO 3,000'. - BUILDING STANDS IN PREPARATION FOR STRIPPING DRILL 13:00 - 14:00 1.00 REMCM P DECOMP POH TO 1,200', RACKING BACK STANDS. 14:00 - 14:30 0.50 REMCM P DECOMP PRE-JOB MEETING FOR STRIPPING DRILL. 14:30 - 16:30 2.00 REMCM P DECOMP CONDUCT STRIPPING DRILL WITH SMITH CREW. - STRIPPED IN TWO STANDS OF DRILLPIPE POST DRILL DEBRIEF WITH ALL PARTIES INVOLVED. 16:30 - 17:00 0.50 REMCM P DECOMP LUBRICATE RIG AND INSPECT TOP DRIVE. 17:00 - 17:30 0.50 REMCM P DECOMP POH TO HEAVY WEIGHT AT 270'. 17:30 - 18:30 1.00 REMCM P DECOMP RIH WITH LAST 21 JOINTS OF DRILLPIPE FROM PIPE SHED. 18:30 - 19:30 1.00 REMCM P DECOMP POH TO SURFACE, RACKING BACK STANDS AND HEAVY WEIGHT. 19:30 - 22:30 3.00 BOPSU P DECOMP RIG DOWN RISER, BELL NIPPLE, AND FLOW LINE. MOBILIZE EQUIPMENT AND PARTS TO RIG FLOOR AND CELLAR TO CHANGE ANNULAR ELEMENT. 22:30 - 00:00 1.50 BOPSU P DECOMP NIPPLE DOWN TOP OF ANNULAR AND REMOVE ELEMENT. 1/22/2010 00:00 - 02:30 2.50 BOPSU P DECOMP CONTINUE TO NIPPLE DOWN TOP OF ANNULAR. PULL ANNULAR ELEMENT. - ELEMENT IN GOOD CONDITION. ONE SMALL TEAR IN RUBBER. 02:30 - 04:30 2.00 BOPSU P DECOMP INSTALL NEW ANNULAR ELEMENT AND RING GASKETS. NU TOP OF ANNULAR. 04:30 - 06:30 2.00 BOPSU P DECOMP NIPPLE UP BELL NIPPLE, RISER, AND FLOW LINE. 06:30 - 09:00 2.50 BOPSU P DECOMP PULL WEAR BUSHING. INSTALL NEW TEST PLUG. FUNCTION TEST NEW ANNULAR ELEMENT. RU BOPE TEST EQUIPMENT. 09:00 - 14:30 5.50 BOPSU P DECOMP TEST RAMS, BODY, CHOKE MANIFOLD, AND VALVES TO 250 PSI LOW, 4,000 PSI HIGH FOR 5 MINUTES EACH. PERFORM KOOMEY DRAWDOWN -GOOD TEST. TEST ANNULAR TO 250 PSI LOW, 2,500 PSI HIGH FOR 5 Printed: 2/5/2010 11:09:52 AM TREE _, WELLHEAD = CIW ACTUATOR = BAKER C KB. ELEV _ 49' BF. ELEV..._. KOP _ _ _ 1851 Max Angle = 46 3478' Datum MD = 11204' Datum ND = 8800' SS 13-3/8" CSG, 68#, K-55 XO TO NT-80 122' 13-3/8" CSG, 68#, NT-80, ID = 12.415" 3911' Minimum ID = 4.455" @ 10117' 5-1/2" OTIS XN NIPPLE TUBING PUNCH (01/08/10) 8930' - 8935' 7' TBG, 26#, NT-80-IPC NSCC, .0383 bpf, ID = 6.276" 5-1/2" HES EZSV (0/10) I• 11~37~~ AG 101 SES: LINER NOT CEMENTED. ALL TBG IPC W ITH NSCC THREAD 17 CO L- S~:937" ®~,~{~' EZSV 7152' CHEM CUT (01/10/10) 9000' 7" HES EZSV (01/06/10) 10041' -{7" X 5-1/2" XO, ID = 4.892" _~ 10046' ANCHOR 10049' 9-5/8" X 5-1/2" BKR FB-1 PKR, ID = 6.00" 10063' 7-5/8" MILLOUT EXTENSION, ID = 6.625" 10069' 7-5/8" X 5-1/2" XO, ID = 4.875" 10096' 5-1/2" PARKER SWS NIP, ID = 4.562" I 10041' I 10082' 10117' I 15-1/2" OTIS XN NIP, ID = 4.455" 5-1/2" TBG, 17#, L-80-IPC NSCC, I 10129' 0232 bpf, ID = 4.892" 10129' 5-1/2" WLEG, ID = 4.892 TOP OF 7" LNR 10129' 10127' ELMD TT LOGGED 05/20/93 10129' 9-5/8" X 7" BKR TYPE H LNR PKR, ID = ? 19-5/8" CSG, 47#, NT-80 NSCC, ID = 8.681" I I 10260' I PERFORATION SUMMARY REF LOG: BRCS ON 11/29/92 ANGLE AT TOP PERF: 36 @ 10301' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10301 - 10315 O 5/20/93 3-3/8" 6 10329 - 10529 O 5/20/93 3-3/8" 6 10540 - 10550 O 5/20/93 3-3/8" 6 10598 - 10648 O 5/20/93 3-3/8" 6 10665 - 10695 O 5/20/93 3-3/8" 6 10703 - 10733 O 5/20/93 3-3/8" 6 10743 - 10763 O 5/20/93 PBTD~~ 7" LNR, 26#, NTS-80 NSCC, I-~ .0383 bpf, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/29/92 AUDI 2 ORIGINAL COMPLETION 10/02/09 GBP/SV WHL CORRECTION 12/14/09 SEW/PJC PULL PXN (12/13/09) 02/02/10 LLVPJC EZSV's/ P&A(01/06/10) 02/02/10 RRD/PJC TBG PUNCH/ JET CUT (01/10/10) PRUDHOE BAY UNrf WELL: AGI-01 PERMff No: "1921240 API No: 50-029-22307-00 SEC 36, T12N, R14E, 1294.15' & FEL 4091.85' FNL BP Exploration (Alaska) SCIIIlllgll~l'g~P Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO. 5460 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 13-35 B14B-00084 INJECTION PROFILE - Q~- Z-27 17-09 05-38 63S0-00043 BSJN-00031 AYKP-00063 GLS / - p LDL ~ - p PRODUCTION PROFILE - 11/10/09 01/07/10 01/11/10 1 i 1 1 1 1 P2-52 17-09 AGI-01 01-19B H-13A 62NJ-00050 AYKP-00064 BBKA-00003 AWJI-00062 82NJ-00042 MEMORY XY CALIPER - USIT - / USIT - MCNL MCNL _ t{ '- 01/21/10 01/24/10 01/22/10 01/18/10 12/03/09 1 1 1 1 1 1 1 1 1 1 07-26 BALL-00007 RST - 11/29/09 1 1 07-19A 2-14/0-16 P1-24L1 63S0-00036 AZCM-00050 12034915 RST .~(~ RST (o - OH LDWG EDIT (FLEX - Q 12/08/09 12/25!09 12/08/09 08/08/08 1 1 1 1 1 1 1 W-217 W-217 P81 09AKA0091 09AKA0091 OH MWD/LWD EDIT ~ OH MWD/LWD EDIT 11/23/09 2 1 11/15/09 2 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH m• or ~xploranon tHiastca) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~~ _ -ry:, Alaska Data & Consulting Services • 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 SEAN PARNELL, GOVERNOR LL L AILA KA 011L AND GAS 333W. 7th AVENUE, SUITE 100 CONSIRRVAUON COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska), Inc. p-4 P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, AGI-0 1 Sundry Number: 309-418 swfAN NED FJE'kl 2 2 2009 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Norm Norm Commissioner DATED this if day of December, 2009 Encl. (� e STATE OF ALASKA EE. EIVED .. �I/ 1t ALASIAIL AND GAS CONSERVATION COMMI &N 10f I L 401 19 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Aingka f1d & 62SCong 0 1. Type of Request: Anchorage ® Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Specify: ❑ Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 192 -124 3. Address: ® Service , ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22307 - 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: AGI -01- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028301 8r 034628 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10850' - 8571' 10770' 8503' 10117' None Casing Lenoth Size MD TVD Burst Colla Structural Conductor 0" 75' 75' 1490 4 Surface 71' 13 - 3 /8" 911' 3487' 5020 22 Intermediate 10222' 9-5/8" 10260' 8 ' 6870 476 Production Liner 709' 7" 10141' 1 0850' 7986' 8 71' 7240 541 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10301' - 10763' 8115'- 8497' 7 ", 26# x 5 -1/2 ", 17# NT -80 / L -80 10129' Packers and SSSV Type: 9 -5/8" x 5-1/2" Baker'FB -1' packer Packers and SSSV 10049'/ 7913' I MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory ❑Development ®Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 20, 2009 ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ® Abandoned 16. Verbal Approval: Date: ❑ WINJ ❑ GINJ [I WAG ❑Plugged ❑ SPLUG Commission Representative: 17. 1 hereby certify that the fore in is rUe and correct to the best of my knowledge. Contact Frank Roach 564-4373 Printed Name Greg _ Title Engineering Team Leader Prepared By Name/Number Signature Phone 564 -4191 Date Terrie Hubble, 564 -4628 Commission Use Only Conditions of approval: tify Commission sot t a representative may witness y , �/ � L l4.14'.0f Sundry Number: 53 / Plug Integrity BOP Test jo. Aechanical Integrity Test ❑ Location Clearance eg d�v Other. I ✓L!c< y< �Q -}'e57�� o `1 L P e s mac. c.ce`o f w` Z" AAC. 75- 2 8:5 <<+ J Subsequent Form Required: la - APPROVED BY t - Approved By: COMMISSIONER THE COMMISSION Date // Form 10-403 Revised 07/2000 " - Submit In Duplicate *i L Obp GP 6A&zA"rAr AGI -01 Sundry Request Well Type: Gas Injector Current Status: This well is completed with 7" plastic coated x 5 -'/2" L -80 tubing and is currently shut -in. Request: Plug and abandon wellbore in preparation for Ivishak sidetrack. r Well History: AGI -01 is a Prudhoe gas injection well that was originally drilled and completed in November 1992. It was completed with a 7" x 5 -'/2" L -80 IPC TBG string and a 7" NT -80 production liner with 350' of perfs. The well has not required any major work since completion except for the occasional SSSV maintenance. The well failed the Pre - AOGCC MIT -IA on 8/17/09 and was immediately secured with a TTP set @ 10,117' and on 8/23/09. The ensuing MIT -T passed to 3,000 psi while the MIT -OA failed (open shoe) with a LLR = 4.5 BPM @ 1,150 psi. The 8/24/09 MIT -IA failed to 2,400 psi with a LLR = 11 GPM @ 500 psi. A TecWel LDL on 9/10/09 found a leak in the 9- Production Casing at 7,153' md. . Other Requests: Given rig floor height limitations, a MASP < 3,000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path - forward de- completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three -ram drilling BOP stack. Scope of Work: The pre - drilling rig work on this well will include the P &A the existing AGI -01 well perforations per AOGCC regulations and cutting the existing 7" x 5 - '/2" completion at 7,150' MD in preparation for the planned AGI -01A sidetrack. With a drilling rig on the well, the planned work will include pulling the 7" tubing above the cut at 7,150', USIT run to confirm 9-%" casing is free below surface casing shoe, setting CIBP at 4,100' and testing to 4,000 psi, cutting and recovering 9-%" casing -75' below the surface casing shoe, Laying in a 17.0 ppg kickoff plug from top of the CIBP to 300' inside the surface casing which will be used to sidetrack the well to the AGI - 01A BHL. �¢;L ✓<•, Wetl rt �Fin� 0'" 1/0 u1� ; Q � J�vt �`}f "�� uhf S:�rr��kr�f GC�� ire Khac.�✓� IP4I4 C9�t_"� �'t tv.��� T� �wf i.�Jc'Cf��. �P/ ✓, AGI -01 Sundry Application 1 12/10/2009 MASP: 2870 psi Pre -rig prep work: W 1 Function tubing and casing LDS. Repair /replace as required. Perform PPPOT -IC to 3,500psi and PPPOT -T to 5,000 psi. S 2 Pull PXN prong and plug body from XN nipple at 10,117'. S 3 Run a static bottomhole pressure and temperature surrey for determining MW needed for sidetrack operations and BHST for cement testing. C' 4 P &A existing perforations through coil and 5 -'/2" cement retainer with 32.1 bbl (Obbl excess), 15.8ppg G cement: Liner Size 26.0# 7" (.03830 bpf) from 10,141' to 10,770' MD Casing size (Lnr top to WLEG) 47.0# 9-%" (.07320 bpf) from 10,129' to 10,141' MD Tubing size (WLEG to retainer) 17.0# 5 -'/2" (.02320 bpf) from 10,082' to 10,129' MD Annular size (WLEG to packer) 47.0# 9-%"x5- (.04380 bpf) from 10,129' to 10,049' MD Bottom of plug 10,850' MD Top of retainer 10,082' MD Total Footage to retainer 688'(-29.6 bbls) Cement on top of retainer 75' ( -2.5 bbls) Top Perf 10,301' MD Bottom Perf 10,763' MD SBHP and SBHT to be determined by static survey from step 3. S 5 1 WOC. Drift to TOC. F 6 CMIT -T to 2,500 psi for 30 min. Notify State inspector for witness. Pressure test is required for competent barrier for rig operations. If test fails, contact ODE. Freeze Protect as necessary. E/F 7 Punch tubing above 5 -'/2" x 7" crossover at 10,020' MD (bottom of first full joint of 7" tubing) and circulate tubing and IA to clean 9.8 ppg brine. Power Jet cut 7" tubing at 7,150' MD (try to get cut -2' below a coupling to help with standoff from the intermediate casing). Establish circulation from the T to the IA. F 8 Attempt CMIT TxIA to 500 psi and establish LLR (LLR 11 gpm @ 500 psi on 8/24/09). MIT - OA to 2,000 psi. If combo doesn't track LLR from 8/24, contact ODE. D 9 1 Bleed casing and annulus pressures to zero. V 10 1 Set a BPV. Remove well house and flow line. Level pad as necessary. Proposed Drilling Rig Operations: 1. MI /RU. 2. CMIT -TxIA rolling to 500 psi and MIT -OA to 2,000 psi to confirm barriers (10 minute tests -expect MIT -OA to pass). 3. Pull BPV w /tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and test TWC to 500 psi rolling test from below and 4,000 psi from above for 10 minutes. 5. Nipple down tree. Nipple up and test BOPE to 4,OOOpsi. Pull TWC w /tested lubricator. 6. R/U & pull 7" tubing from the cut depth at 7,150' MD. 7. Test lower set of rams if required. 8. PU drill -pipe and make bit and scraper run to the top of the tubing stub. 9. RU E -line and RIH w /USIT log to confirm no cement behind pipe at desired cut depth. 10. RIH w /CIBP and CCL and set the CIBP at 4,100' MD and test well to 4,000 psi for 10 minutes. 11. RIH and cut 9-%" casing -75' below surface casing shoe (cut at 3,985' MD) and circulate through cut. If unable to circulate, cut casing just inside surface casing and establish circulation. 12. Spear hanger and pull casing to floor. 13. RIH w/ open -ended drillpipe and set 17# kickoff plug on top of CIBP. Bring plug -300' inside 13-%" surface casing. WOC until desired compressive strength reached. Pressure test to 3,500 psi. AGI -01 Sundry Application 2 12/10/2009 (End Work Under Sundry Approval #xxx -xxx / Begin Work Under PTD #xxx -xxx) 14. M/U 12 -1/4 g " Dir /GR/Res /PWD assembly. RIH, control drill to kick off of plug and 20' of new hole beyond � cement. Circulate wellbore clean 15. Pull up into casing and conduct LOT. 16. Run back to bottom and drill the 12 - '/4" intermediate section to the TD target at 10,270' MD, per directional plan. 17. Circulate, short trip and POOH to run the 9 Ya" intermediate casing (manage drill -pipe as required). 18. Run and cement a 9-%", 47.0 #, L -80, Hydril 563 intermediate casing. TOC 1,000' above casing shoe. 19. After cement has reached a minimum 500 psi compressive strength, test the 9 -%" casing to 4,000psi for 30 minutes and record the test. 20. M/U 8 -'/2" drilling assembly w /Dir /GR + insert bit to drill -out the shoe track, displace to the well to the planned drill -in fluid, drill 20' of new hole and run FIT. 21. Drill ahead per the directional plan to TD at 10,800' MD. 22. Circulate, short trip, spot liner running pill. POOH to run the production liner. 23. Run and set 7 ", 26 #, BTC -M, slotted production liner. "NOTE: Due to running 7" slotted pipe, rams will not be changed to 7" casing rams. There will be a joint of 5" drillpipe with a DP to 7" BTC -M crossover on bottom and TIW valve on top (TIW valve in open position with valve key ready to use). In the event the BOP stack would need to be used, the crossover joint would be made up to the liner, run in hole to where the drillpipe joint is across the BOP stack, and the pipe rams closed on that joint of drillpipe. 24. POOH L/D all drill pipe. 25. R/U and run 7-%", 29.7 #, L -80, VamTop HC, IPC completion tubing. 26. Land the tubing RILDS. 27. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. Chase corrosion inhibited fluid with diesel freeze protect. 28. Drop ball & rod. Set packer and individually test the tubing and annulus to 4,000psi 30 minutes and record each test. " *Notify state inspector 24 hrs before test for opportunity to witness" 29. Set a TWC and test to 1,000 psi from above. 30. Nipple down the BOPE. Nipple up the tree and test to 5,000psi with diesel (new adapter flange required). 31. Pull TWC w /lubricator. 32. RU slickline and retrieve ball & rod. 33. Freeze protect tubing with diesel. 34. Install BPV and secure the well. 35. RDMO. Post -Rig Operations: (S -Riser Modification will be Required) 1. MI / RU slick line. 2. Pull the ball and rod/ RHC plug from landing nipple below the production packer. 3. Install injection safety valve. 4. Install well house and instrumentation. Estimated Pre -rig Start Date: 12/20/2009 Estimated Spud Date: 01/01/2010 Drilling Engineer: Frank Roach (907) 564 - 4373 Production Engineer: Nathan Sinyangwe (907) 564 - 5062 Geologist: Doug Stoner (907) 564 - 5652 ATTACH: Current Well Schematic Post P &A Well Schematic AGI -0 1 Sundry Application 3 12/10/2009 TREE= WELLHEAD = CIW • AGI-01 S TES: LINER NOT CEMENTED. CTUATOR = BAKER C AL lPC WITH NSCC THREAD KB. ELEV = 49' BF. ELEV = KOP = 1851' Max Angle = 46 @ 3478' ' Datum MD = 11204' 2178' T' CAMCO BAL -O SSSV NIP, ID = 5.937" Datum TVD = 8800' SS 13 -3/8" CSG, 68 #, K -55, ID = 12.415" 122' 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 3911' 7" TBG, 26#, NT- 80 -IPC NSCC, 10041' 10041' 7" X 5 - x - 356 = 4.892" .0383 bpf, ID = 6.276" 10046' ANCHOR 10049' 9-5/8" X 5 -1/2" BAKER FB -1 PKR 10096' j 5 -1/2" PARKER SWS NIP, ID = 4.562" Minimum ID = 4.455" @ 10117' 5 -1/2" OTIS XN NIPPLE 10117' 5 -1/2" OTIS XN NIP, ID = 4.455" 10117' S -1l2" PXN PLUG (08/23/09) 1 5-1/2" TBG, 17 #, L- 80 -IPC NSCC, 10129' 10129' 5 -1/2" WLEG, ID = 4.892" .0232 bpf, D = 4.892" 10127' HELMD TT LOGGED 05/20/93 TOP OF 7" LNR 10141' 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" 10260' PERFORATION SUMMARY REF LOG: BRCS ON 11/29/92 ANGLE AT TOP PERF: 36 @ 10301' Note: Refer to Production DB for historical perf data SIZE SPF AdTERVAL Opn /Sqz DATE 3 -3/8" 6 10301 - 10315 C 5/20/93 3 -3/8" 6 10329 - 10529 C 5/20/93 3 -3/8" 6 10540 - 10550 C 5/20/93 3-3/8" 6 10598 - 10648 C 5/20/93 3-3/8" 6 10665 - 10695 C 5/20/93 3 -3/8" 6 10703 - 10733 C 5/20/93 3 -3/8" 6 10743 - 10763 C 5/20/93 PBTD 10770' 7" LNR, 26#, NT-80,.0383 bpf, ID = 6.276" 10850' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 ORIGINAL COMPLETION 10/01109 BSE/PJC SET PXN PLUG (08/23/09) WELL: AGI-01 01/29/01 SIS-LG REVISION 10/02/09 GBP/SV WHL CORRECTION PERMIT No: 1921240 05/21/01 RWKAK CORRECTIONS API No: 50 -029- 22307 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T1 2N, R1 4E, 1294.15' & FEL 4091.85' FNL 03/26/03 JP/KAK I CSG DEPTH CORRECTION 05/12/03 JRCJKK CSG DEPTH CORRECTION BP Exploration (Alaska) TREE LLHEAD = CIW A v I -O 1 SA TES: LINER NOT CEMENTED. W E ACTUATOR = BAKER C ALL T S IPC WITH NSCC THREAD KB. ELEV = 49' Pre-Rig BF. ELEV = KOP = 1851' Max Angle = 46 @ 3478' > > Datum MD = 11204' 2178' 7" CAMCO BAL -O SSSV NIP, ID = 5.937" Datum TVD = 8800' SS O 13 -3/8" CSG, 68 #, K -55, ID = 12.415" 122' 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 3911' 7150' TUBING CUT 7" TBG, 26 #, NT -80 -IPC NSCC, 10041' 10041' 47 7 X 5 -1/2" XO, ID = 4.892" .0383 bpf, ID = 6.276" TOC 10007' 10046' ANCHOR 10049' 9 -5/8" X 5 -1/2" BAKER FB -1 PKR 5 -1 /2" CMT RETAINER 10096' 5 -1/2" PARKER SWS NIP, ID = 4.562" Minimum ID = 4.455" @ 10117' 5 -1/2" OTIS XN NIPPLE 10117' 5 -1/2" OTIS XN NIP, ID = 4.455" 1 5-1/2" TBG, 17 #, L -80 -IPC NSCC, 10129' 10129' S -1/2" WLEG, ID = 4.892" .0232 bpf, ID = 4.892" 10127' ELMD TT LOGGED 05/20/93 TOP OF 7" LNR 10141' 9 -5/8" CSG, 47 #, NT -80, ID = 8.681" 10260' PERFORATION SUMMARY REF LOG: BHCS ON 11/29/92 ANGLE AT TOP PERF: 36 @ 10301' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10301- 10315 S 5/20/93 3 -3/8" 6 10329- 10529 S 5/20/93 3 -3/8" 6 10540- 10550 S 5/20/93 3 -3/8" 6 10598- 10648 S 5/20/93 3 -3/8" 6 10665- 10695 S 5/20/93 3 -3/8" 6 10703- 10733 S 5/20/93 3 -3/8" 6 10743- 10763 S 5/20/93 PBTD 10770' 7" LNR, 26 #, NT-80_0383 bpf, ID = 6.276" 10850' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/29/92 ORIGINAL COMPLETION 10/01/09 BSE/PJC SET PXN PLUG (08/23/09) WELL: AGI-01 01/29/01 SIS -LG REVISION 10/02/09 GBP /SV WHL CORRECTION PERMIT No: 1921240 05/21/01 RN/KAK CORRECTIONS API No: 50- 029 - 22307 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 1294.15'& FEL 4091.85' FNL 03/26/03 JP /KAK CSG DEPTH CORRECTION 05/12/03 JRC /KK I CSG DEPTH CORRECTION BP Exploration (Alaska) u~' PaoAcrive DiagNOSric SeRVicES, Inc. 1) 2j • . ~E~,~ ~Q~ T~,~4~5~/T~`~dL To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907~ 793-1225 RE : Cased HQIe/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed betow is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the follawing : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 `s °' ~,~ _. . _ ~~ ~~~~_ Fax (907~ 245-8952 ~ Leak Detection - WLD 10,Sep-09 AGI~Q1 BL / EDE 50-029-22307-00 ~~~ l`~~'~ 2~( Signed Print Name: / ~ i ~. ~~~ ~~ ~, ~, ~---__- ~~~~ ~ Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 9951$ PHONE: (907)245-8951 FAx: (907~245-88952 E-NIAIL : :_ ~_ _.__.__.. _.~ ,We_ _ _~___ _ WEBSITE ___Y_..________ a_ ~.~_ C:\-ocumenls and Settings\Owner~Desktop\Transmit_Conoco.doc.r NOT OPERABLE: AGI-O1 (PT~1921240) for failing an MITIA • Page 1~~~~~~ Regg, James B (DOA) From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~~~~~d ~ Sent: Tuesday, August 25, 2009 8:32 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Hoit, Ryan P(ASRC); Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: AGI-01 (PTD #1921240) for failing an MITIA AI I, Well AGI-01 (PTD #1921240) had a TTP set on 08/23/09 and passed an MIT-T. The well then failed a CMIT-TxIA on 08/24/09. These pressure tests indicate a PC leak or a packer leak but have confirmed the well is secured with the TTP. The well has been re-classified as Not Operable and will remain shut in until a well repair has been completed. Piease contact me with any questions or concerns. Thank you, Taylor Taylor Wellman filling in for Anna Dube/Torin Roschinger Office: 659-5102 Pager: 659-5100 x 1154 ~%~~ ~ ~ ; ~~~~ °' ~~ ~~~ ~. r_t ~:~ From: Roschinger, Torin T. Sent: Thursday, August 20, 2009 9:46 PM To: NSU, ADW Well Integrity Engineer Subject: AGI-O1 (PTD #1921240) Under Evaluation for failing an MITIA All, Well AGI-01 (PTD #1921240) failed an MITIA on 08/19/09. The failing test verifies that one of the barriers has been compromised. The well has been classified as Under Evaluation and has been shut-in. The plan forward for this weli is as follows: 1. Slickline - Set TTP for secure A wellbore schematic and a 90 day TIO plot have been included for reference. « File: AGI-01.pdf» « File: AGI-01 TIO Plot.doc» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 9/16/2009 AGI-O1 (PTD #1921240) Under F,~aluation for failing an MITIA Page 1 of 2 ~ • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, August 20, 2009 9:46 AM ~ 9~'~ ~~~ To: Regg, James B (DOA) ` ~ Subject: RE: AGI-01 (PTD #1921240) Under Evaluation for failing an MITlA Mr. Regg, I apologize for the previously sent email. The well will not be injected in for 28 days and has already been shut- in. A work request has been submitted for slickline to secure the well with a downhole piug. Torin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 20, 2009 8:17 AM To: NSU, ADW Well Integrity Engineer Cc: Schwartz, Guy L (DOA) Subject: RE: AGI-01 (PTD #1921240) Under Evaluation for failing an MITIA Boiler plate wording ("may be produced") is not appropriate. Also, I question allowing one of these high rate/pressure gas injectors to continue operating for 28 days with a failed MITIA. That is not consistent with the AIO rules. We have allowed in some instances a well to continue injecting water or a gas injector to be swapped to water while diagnostics are ongoing pending a decision to SI or seek Admin Approval when there is an indication of pressure communication as identified on TIO plot - none of these situations apply here. Again, I hope this is just boiler plate wording and the pian forward wording "set TTP for secure" will be accomplished immediately, not within 28 days as suggested. At a minimum the well should be SI if not already done. Jim Regg AOGCC ~ ' `~; 7 ~~k~~ ,,, ... : "w: ,~~~.._~~ . ? ~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, August 19, 2009 9:59 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr North (Gas Plants/GPMA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Sinyangwe, Nathan Cc: NSU, ADW Well Integrity Engineer Subject: AGI-Ol (PTD #1921240) Under Evaluation for failing an MITIA All, Well AGI-01 (PTD #1921240) failed an MITIA on 08/19/09. The failing test verifies that one of the barriers has been compromised. The well has been classified as Under Evaluation and may be produced under a 28-day clock. 8/20/2009 AGI-O l(PTD # 1921240) Under F,yaluation for failing an MITIA • Page 2 of 2 ~ The plan forward for this well is as follows: 1. Slickline - Set TTP for secure A wellbore schematic and a 90 day TIO plot have been included for reference. «AGI-01.pdf» «AGI-01 TIO Plot.doc» Please cail with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Weil Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/20/2009 PBU AGI-O1 PTD 1921240 8/19/2009 TIO Pressures ~ 3.000 2.000 7.ot~r~ f Tbg -~- IA ~ OA OOA ~- OOOA ~- On • 05123~09 05130/rJ9 06!~]6/09 06/13.~09 0612Ci%0y Oh~27109 07~qdI09 D7l11i09 0?I18I09 07!25;04 r~;rri1/09 04I08/09 08/75/09 TRFF = WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = 49' BF. ELEV = KOP = 1851' Max An le = 46 3478' Datum MD= 11204' Datum TVD = 8800' SS 13-3l8" CSG, 68#, K 55, ID= 12.415" H 122' I 13-3/8" CSG, 68t~, L-80, ID = 12.415" ~ 3911' ~ 'BG, 26fk, P!T-80-IFC, NS(:C, .0383 bpf, ID = 6.276" 10041' ~TOP OF 5-1/2" 'BG ~"1 10041' Minimum ID = 4.455" @ 10117' 5-1/2" OTIS XN NIPPLE S1/2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID= 4.892" H 10129' oF 7" LNRH 10141' I 9-5/8" CSG, 47#, NT-80, ID = 8.681" H 10260~ ~- PERFORA?lON SUMMARY REF IOG: BHCS ON 11/29/92 ANGLE ATTOP PERF: 36 @ 10301 ' Note: Refer to PraJuction DB fur historical rf data SIZE SPF INTERVAL OpNSqz DATE 3-3/8" 6 10301 - 10315 O 5/20l93 3-3/8" 6 10329 - 10529 O 5/20/93 3-3/8" 6 10540 - 10550 O 5/20/93 3-3/8" 6 10598 - 10648 O 5/20/93 3-3/8" 6 10665 - 10695 O 5/20/93 3-3/8" 6 10703 - 10733 O 5/20/93 3-3/8" 6 10743 - 10763 O 5/20/93 T' LNR, 26#, NT-80, .0383 bpf, ID = 6.276" H 10850~ AG I 01 SAFETY NOTES: LINER NOT CEMENTm. ~ ALL TBG IS IPC WI7H NSCC THREAD 2178' ~'"'~ ~" ~MCO BAL-O SSSV NIP, ID = 5. 93T' 10041' ~~" xs~ir~ xo 10046' ANCHOR 10049' H 9-5/8" X 5-1/2" BAKER FB-1 PKR I 10096' S-1/2" PARI~R SWS NIP, ID = 4.562" 10117' ~-~ 5-~~2~~ OT1S XN NIP, ID = 4.455" ~ 10128' Hs~i2" wL~ I 10127' ~NDTTLOGGED05I20/93 DATE REV BY COMv1B~1TS Q41E REV BY COMNENTS 11/29/92 OWGIHAL COMPLE110N 01/29/01 SIS-LG REVISION OS/21/01 RWKAK CORR~~IONS 03/13/03 AS/TP ADD IFC/THRE4D FOR TBG 03/26/03 JP/KAK CSG DEPTH CORRECTION OS/12/03 JRC/KK CSG DEPTH CORRECTION PF2UDHOE 6AY UMT W~L: AGI-01 PERMIT No: 1921240 API No: 5Q029-22307-00 SEC 26, T12N, R14~ 1294.15' & FEL 4091.85' FNL BPF~cploration (Alaska) MEMORANDUM ) TO: Jim Regg \/~ 01,..,).-- P.I. Supervisor 1'é:11. II ¡ '1!) S FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT AGI-01 lnsp Num: mitJCr050825 125501 Rellnsp N urn State of Alask£o. ,) Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-OI PRUDHOE SAY UNIT AGI-O 1 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22307-00-00 Permit Number: 192-I24-0 Packer Depth Pretest Initial :';~l I ~~~;~~. ~~:;:E: s~ I }:~siFl:;;:5···t~: 1- ':: 1-- '::0 -'I~;~~~~~~TST .-- PIF-d--~-.m TUbi~-g¡35õo--135õo ____...... .____.._"".. .._.L._.__ Notes 4.6 bbls pumped for test. Tuesday, August 30, 2005 .I \C} 0( \; fA.. ~ Reviewed By: ,.:.-:- n...." Pol. Suprv--. }'¡~.i'':''- Comm Inspector Name: John Crisp Inspection Date: 8/23/2005 I !- I I 15 Min. 30 Min. 45 Min. 60 Min. 2190 'I -';-190 1----"1--·- 20 1-- ~ 20 --·-I·-·----~I' ",-. ----- 3500--+-1 -3500--·+----·-·;---·-···- ___._.l...____---L_____ ·SÇ/~~H~E(j SEP ~:~ J. 2DŒ] Page I of 1 MEMORANDUM State of A~aska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~"-t~,~ DATE: May 27, 2001 Commissioner · SUBJECT: Mechanical Integrity Tests THRu: Tom Maunder ,~.~~i.~ BPX P.I. Supervisor AGI Pad g[c~--O \ AGI-01, 02, 03, 04, 05 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI AGI~01 I Typelnj. I G [ T.V.D. I 7910 I Tubingl 3500 I 3500 I 3500 I 3500 I lntervall 4 P.T.D.I 192-124 Type testI P I Test psiI 1978 I CasingI 450 I 2100 I 2090 I 2080 I P/F I 13 Notes: WellI AGI-02 I Typelnj. I G I T.V.D. 17858 I Tubing I 3500 J 3500 J 3500 I 3500 ]IntervalI 4 'P.T.D.I 192-120 Type testI P I TestpsiI 1965 I CasingI 325 I 21001 21001 21001 P/FI P Notes: WellI AGI-03 I Type,nj.I G'I T.V.D. 17870 I Tubing 13500 I 3500 I 3500 135oo I,nterva,! 4 P.T.D.I 192-135 ITypetestl P ITestpsiI 1968 I Casingl 600 I 2120 I 2110 I 2110 I P/F I 13 Notes: We,,J AG,-04 J Type,,j.J 6 J T.V.D. I7898 I Tubing J3500 13500 I3500 13500 J lnterva, J 4 P.T.D.I 192-146 JTypetestJ P ITestpsil 1975 JCasingI 360 I 21801 22001 22001 P/F I 13 Notes: we,,I AGI-05 I Typelnj. J G I T:V.D. ] 7745'1 Tubing J3500 I~00 I~,00 I~00 i,nterva, I 4 P.T.D.I 193-002 JTypetestI P J TestpsiI 1936 I Casingj 600 I 2100J 2100I 2100I PIE J'13 Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, ~ 27, 2001: I traveled to BPX's AGI Pad to witness 4 year M_IT's on gas injection wells AGI-0I, 02, 03, 04, and 05. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MITs. The test data above indicates these wells are suitable for continued injection. Sumrna~: I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: 0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-01,02,03,04,05 5-27-01 JJ 6/9/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E PL W M ATE IA L U N D ER TH IS M ARK ER C:LOR.~MFIL~DOC STATE OF ALASKA ALASI OIL AND GAS CONSERVATION ~MISSION REPORi OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1583' NSL, 2390' WEL, Sec. 36, T12N, R14E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 49' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number AGI-1 At top of productive interval N/A At effective depth N/A At total depth 1205' NSL, 1280' WEL, Sec. 31, T12N, R15E, UM. 9. Permit numbedapproval number 92-124 10. APl number 50 - 029-22307 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 75' Surface 3871' Production 10222' Liner 709' 10850 feet Plugs(measured) 8540 feet 10770 feet 8477 feet Junk(measured) Size Cemented Measured depth True vertical depth 30" 11 Yds Arcticset 75' 75' 13-3/8" 1500 sx PFE & 400 sx G 3911' 3487' 9-5/8" 375 sx G 10260' 8082' 7" 170 sx G 1 0850' 8540' Perforation depth: measured 10301-10315'; 10329-10529'; 10540-10550'; 10598-10648'; 10665-10695'; 10703-10733'; 10743-10763' true vertical 8115-8126'; 8137-8301 '; 8310-8318'; 8358-8400'; 8414-8439'; 8447-8472'; 8481-8498' Tubing (size, grade, and measured depth) 7", 26#, NT-80, NSCC Tbg @ 10041' MD; 5-1/2", 17#, L-80, NSCC Tbg @ 10129' MD. t ECEIVED Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 10049' MD. 13. Stimulation or cement squeeze summary /~/~ Y ~ 7 199~ Intervals treated(measured) See Attached Treatment description including volumes used and final pressure ~aska Oil & Gas Cons. Cor~r~ission AnChora. ,, 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 234578 Tubing Pressure 3487 219775 - 3483 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 .~' Date KRF cc: KZ, JWP SUBMIT IN DUPLICATE AGI-1 STIMULATION TREATMENT DESCRIPTION OF WORK COMPLETED 4/15/95: RIH & tagged sticky bottom fill at 10490' MD. 4/16/95: MIRU CTU & PT equipment. Loaded wellbore w/1% NH4CI Water, then RIH w/CT & reciprocated an acid stimulation across the perforation intervals located above fill at: 10301 - 10315' MD (Z4) 10329 10529' MD (Z3/2) Ref. Log: BHCS 11/29/92. Note: Open perforation intervals initially covered by fill located at: 10540 - 10550' 10598 - 10648' 10665 - 10695' 10703 - 10733' 10743 - 10763' MD (Z2) MD (Z2) MD (Z2) MD (Zl) MD (Z1) Pumped: a) 200 bbls 75% Diesel/25% Xylene @ 2 bpm & washed down to 10754' MD, followed by b) 200 bbls 10% HCI w/10% Xylene @ 2.1 bpm, followed by c) 100 bbls 9% HCI - 1% HF @ 2.6 - 3.2 bpm, followed by d) 100 bbls 10% HCI @ 3 bpm, followed by e) 200 bbls 1% NH4CI Water Overflush, followed by f) Shutdown. POOH w/CT. Rigged down. Returned well to gas injection & obtained a valid injection rate. RECEIVED MAY -.. 1 1995 Alaska Oil & Gas Cons. Commission Anchora..~ PERMIT .~GCC Individual Well Page: 1 Geological Materials Inventory Date: 11/08/94 DATA T DATA_PLUS RUN DATE_RECVD 92-124 BHP L 10256-10808 1 12/30/92 92-124 DIL/FL/GR L 10256-10844 1 12/30/92 92-124 DPR/GR L 8043-10215,MD 5 12/30/92 92-!24 DPR/GR L 8043-10215,TVD 5 12/30/92 92-124 JWL L 10000-10261 1 07/30/93 92-124 PERF L 10000-10761 1 07/30/93 92-124 SBT/GR/CCL L 9094-10761 1 12/30/92 92-124 SSTVD L 10256-10844 1 12/30/92 92-124 ZDL/CNL/GR L 10256-10808 1 12/30/92 92-124 407 R COMP DATE:05/20/93 08/26/93 92-124 DAILY WELL OP R 11/08/93-04/06/93 08/26/93 92-124 SURVEY R 0-10200 MD&TVD TELECO 01/28/93 92-124 SURVEY R 0-10200 MD&TVD TELECO 02/01/93 92-124 SURVEY R 0.00-10850 GCT 08/26/93 92-!24 5481 T 10256-10844 OH/FINALS ALL 12/30/92 92-124 5864 T 8041-10270 OH/LWD/DPR/GR ALL 10/29/93 Are dry ditch samples required?_ yes/no/And received? ye~~ Was the well cored? yes nalysls & description received. Are well tests required~eceived* y~ Well is in compliance In~r~af COMMENTS ARCO .~l~s~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 4-17-93 opt 10-7-93 oa 3-31-93 11/1/,-80/92 11-23-92 4-15-93 1-29-93 2-13-93 4-28-93 3-6-93 5-8-93 3-28-93 MWD: DPR/GR DLL/AC/CN/GR MWD: DPR/GR MWD ~?~-t tq~O MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR. MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR Job#1209 Job#6055 Job# 1202 Job#~x~2112s Job#1152 Job# 1168-450 Job# 1172-450 Job#1181 Job# 1185-450 Job# 1190 Job# 1195-450 Job# 1205-450 Sperry BI-II HHI BX-H %~-o~-- BFH Please sign and return the attached copy as receipt of data.I~'/'~ RECEIVED BY_ .~,~_ k 0C729 /995 Have A Nice Day! _~..~ Sonya Wallace APPROVED ATO- 1529 Trans# 9312~~-' '~g~ . ** # PHILLIPS # BOB OCANAS (OH/GCT) # BPI # EXXON # STATE OF ALAS~ : The correct API# for 3-18A is 50-029-20421-01. The correct API# for 9-28A is 50-029-21292-01. The correct API# for AGI-1 is 50-029-22307-00. INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 92-124 BHP 92-124 DIL/FL/GR 92-124 DPR/GR 92-i24 DPR/GR 92-124 JWL 92-124 PERF 92-124 SBT/GR/CCL 92-124 SSTVD 92-124 ZDL/CNL/GR 92-124 407 92-124 DAILY WELL OP R1,10256-10808,5" RI,10256-10844,2&5" R5,8043-10215,2&5"MD R5,8043-10215,2&5TVD 5" RUN 1 5" RUN 1 R1,9094-10761,5" OH RI,10256-10808,2&5" COMP DATE:05/20/93 11/08/93-04/06/93 92-124 SURVEY 92-124 SURVEY 92-124 Are well tests required? Was well cored? Yes No... MWD DIRECTIONAL SS DIRECTIONAL 5481 OH Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No Yes No 08/30/1993 PAGE: 1 WELL IS ON COMPLIANCE. INITIAL COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO vlMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SLISPEI'~)ED [] ABANDONED [] SERVICE EF A/3~x Ga~ Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-124 3. Address 9. APl Number P. O. ~x 196612, Anchorage, Alaska 99519-6612 50- 029-22307 4. L~ation of well at surface 9. Unit or Lease Name 15B3' NSL, 2390' WEL, SEC 36, T12N, RI~7;;:::~.~ ...... ~~ Prudhoe Bay Unit At Top Producing Inte~al ~ .... "~'. ~..~?0,"J ~'. ~ ~ED t 10. Well Number At Total D~th ~ ~'~IFI~ ~ ~:;~;~b,:;~ ~' Prudhoe Bay Field/Prudhoe Bay Pool 1205' NSL, 1280' WE~ SEC. 31, T12N, R~7~ ..... 5. Elevation in f~t (indicate KB, DF, etc.) ~6. Le~e Designation and Serial No. KBE = 49' ~ ADL 34628 ~12. Date Spudded 13. D~e T.D. Re~ 14. Date Comp., Su~. ~ Aband. ~15. Water Depth, if offshore 16. No. of Completions 11/13/92 11/27/92 5/20/93~ N/A f~t MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back D~th (MD+TVD~ 19. Directional Survey ~0. D~th where SSSV set 21. Thickness of Permafrost 10~0' MD/~40 ~D 10770 MD/8477' ~D ~ ~ ~ D~ 2178' feet MD 1900' (Approx.) ~2. Ty~ Electric or Oth~ L~s Run DSF~CD~CN/GR 23. CASI~, LINER AND CEMENTI~ ~ ~ DEP~ MD CASING S~E ~. ~R ~. G~DE T~ ~ ~LE SIZE C~~ R~RD A~UNT ~LLED 30" 91.~ H-40 Suffa~ 75' 30" 11 yds Amticset 13-3/8" 6~ NT-80 40' 3911' 16" 1500 sx PF 'E"/400 sx "G" 9-5/8" 47~ NT-80 38' 10260' 12-1/4" 375 sx Class "G" 7" 26~ NTS-80 10141' 10850' 8-1/2" 170 sx Class "G" 24, Pedorations open to Production (MD+TVD of T~ and Bottom and 25. ~BINGR~RD interval, size and number) SIZE DEP~ SET(MD) PACKER SET (MD) Gun Diameter 3-3/8' 6 spf 7" x 5-1/2" 10129' 10049' MD ~D 10301~ 10315' 8115~8126' NT-80/L-80 10329~10529' 813~-~01' 26. ACID, F~C~RE, CEME~UE~,~C. 1~40~10~0' ~10~18' DEPTH I~ERVAL(MD) AMOUNT& KIND OF MATERIAL~ 10598~ 106~' ~8~8400' 106~10695' ~14~8~9' 10703~10733' 8~7~8472' 107~107~' 8~1~8498' 27. ~O~N TEST Date First Production lMethod of Operation (Flowing, gas lift, etc.) 5/31/93 J lnjecting Date of Test Hours Tested ~O~~ ~R OIL-BBL ~S-~F WATER-BBL C~E~E IGAS-OIL RATIO ~ST PER~D ~ I Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-~F WATER-BBL OIL GRAVITY-APl (corr) Press. 24-~UR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fracture, a~amnt dips, and pr~ence of oil, gas or water. Submit ~re chips. RECEIV D Alaska Oil & Gas Cons. Comm~ss~o~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS ~-~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10300' 8114' Zone 3 10329' 8137' Zone 2 10484' 8262' Zone 1 10700' 8444' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -' ' Title Drilling Engineer Suoervi$or Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECE VE ) Form 10-407 Alaska Oil Anchor~]e BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI-1 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-22307 PERMIT: APPROVAL: ACCEPT: 11/12/92 05:00 SPUD: 11/13/92 05:00 RELEASE: 04/05/93 08:30 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 11/08/92 (1) TD: 110' ( 110) MOVE RIG MOVE RIG TO AGI -1. MW: 8.5 VIS: 0 11/09/92 (2) TD: 110'( 0) MOVE RIG. MOVE RIG. MW: 8.5 VIS: 0 11/10/92 ( 3) TD: 110' ( 0) MOVE RIG. MOVING RIG. MW: 8.5 VIS: 0 11/11/92 ( 4) TD: 110'( 0) MOVE RIG. MOVE RIG TO AGI PAD. MW: 8.5 VIS: 0 11/12/92 ( 5) TD: 110'( 0) RIG MOVE. MOVE RIG. MW: 8.5 VIS: 0 11/13/92 ( 6) TD: 200'( 90) 11/14/92 ( 7) TD: 1900' (1700) 11/15/92 ( 8) TD: 3920'(2020) 11/16/92 ( 9) TD: 3920' ( 0) 11/17/92 (10) TD: 3920' ( 0) DRLG. MW: 8.7 VIS: 85 RIG UP. RIG ACCEPTED @ 21:00 HRS, 11/12/92. P/U BHA. TEST DIVERTER. SPUD WELL @ 05:00 HRS, 11/13/92. DRLG F/ 100'-200'. DRILLING DRILLING TO 1399' 1900'. MW: 9.1 VIS: 90 SERVICE RIG & TOP DRIVE. DRILL TO WIPER TRIP MW: 9.2 VIS: 80 DRILL TO 2057' CIRC. SHORT TIP. DRILL TO 3464' SERVICE RIG. DRILL TO 3920' CBU. NU WELLHEAD MW: 9.3 VIS: 75 SHORT TRIP. CIRC HI-VIS SWEEP. POOH. RUN 13-3/8 CASING. SHOE AT 3911' CEMENTED. DO TOP JOB ON 13-3/8 ANNULUS. PRESSURE TESTING CASING MW: 8.9 VIS: 36 NU BOPS. TEST BOPS. SERVICE RIG. RIH W/BHA#2. CBU. CIRC. Anchora,qe WELL : AGI-1 OPERATION: RIG : AUDI 2 PAGE: 2 11/18/92 (11) TD: 6100'(2180) 11/19/92 (12) TD: 6573' ( 473) 11/20/92 (13) TD: 8067'(1494) DRILLING MW: 9.3 VIS: 37 TESTED CASING. CBU. CIRC & COND. DRILLED TO 4684' CBU. SHORT TRIP TO 13-3/8. CIRC. SHORT TRIP TO BOTTOM. DRILL TO 6100' CUTTING DRILL LINE MW: 9.2 VIS: 39 DRILL TO 6108' MOTOR FAILURE. DROPPED SS SURVEY. POH. REPLACED BROKEN MUD MOTOR SHAFT. TIH. DRILLED TO 6573'. MWD TOOL FAILED. CIRC. POH. TESTED MWD. DRILLING TIH. DRILLFROM 6573 - 8067' MW: 9.3 VIS: 40 11/21/92 (14) TD: 8552' ( 485) 11/22/92 (15) TD: 9420' ( 868) DRILLING MW: 9.3 VIS: 38 SERVICED RIG. DRILLED TO 8088' CIRC. TOH. CHANGED BHA. TIH. DRILL TO 8376' REPAIRD PUMP #1. DRILLED TO 8552'. DRILLING MW: 9.4 VIS: 41 DRILLED TO 9108'. CBU. DRILL TO 9420' 11/23/92 (16) TD:10027' ( 607) 11/24/92 (17) TD:10270' ( 243) 11/25/92 (18) TD:10270' ( 0) 11/26/92 (19) TD:10479' ( 209) 11/27/92 (20) TD:10850' ( 371) DRILLING MW: 9.8 VIS: 42 DRILLED TO 9455' REPAIRED MUD PUMP #2. DRILL TO 9849'. CIRC. SHORT TRIP. CBU. DRILL TO 10027'. RUNNING CASING MW: 9.8 VIS: 43 DRILLED TO 10270' CIRC. SHORT TRIP. CIRC. RAN CASING TO 13-3/8 SHOE. RUNNING 9-5/8 CASING. RIH TO DRILL OUT CMT MW: 9.9 VIS: 44 CONT'D TO RUN 9-5/8" CSG TO 7000', CBU, RUN & LAND CSG, CIRC & COND MUD, BATCH MIX CMT, PUMPED 375 SX CMT, SQUEEZE 175 BBLS MUD DOWN 9-5/8" X 13-3/8" ANNULUS, R/D LNDG JT & CSG TOOLS, TUN PACKOFF & TEST, CHG PIPE RAMS, RUN WEAR RING, FREEZE PROTECT ANNULUS TO 1500' W/90 BBLS DIESEL, CUT DRLG LINE, L/D BHA, RIH TO TAG UP ON FLOAT COLLAR & DRILL OUT RIH. MW: 8.9 VIS: 55 RIH. TEST CSG. DRLG FC, FS, 10' NEW HOLE. CBU. FIT (12.5 PPG EMW). CLEAN PITS. DISP WELL W/ KCL. DRLG TO 10479'. CBU. POOH. RIH. CIRC. MW: 9.2 VIS: 63 RIH. REAM F/ 10369'-10479' DRLG TO 10522'. POOH FOR BIT. RIH. DRLG TO 10850'. TD WELL @ 06:00 HRS, 11/27/92. ALI 2 6 Alaska Oil & 6as Co,Is. Anchorage WELL : AGI-1 OPERATION: RIG : AUDI 2 PAGE: 3 11/28/92 (21) TD:10850 PB: 0 11/29/92 (22) TD:10850 PB: 0 11/30/92 (23) TD:10850 PB:10770 04/02/93 (24) TD:10850 PB:10770 RIH W/ 7" LNR. MW: 9.3 KC1 CBU. SHORT RTIP TO SHOE. CIRC. POOH. R/U ATLAS. LOG RUN: DSFL/CDL/CN/GR. RIH W/ BHA. CBU. POOH. L/D BHA. R/U WOTCO. RIH W/ 7" LNR ON DP. POOH. MW: 9.0 NaC1 RIH W/ LNR. TAG @ 10850' LC @ 10770'_,G CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 170 SX ' CMT @ 15.8 PPG. BUMP PLUG. SET HGR, PKR. RELEASE F/ LNR. CIRC. POOH. RIH W/ CSG SCRAPERS. TAG LC @ 10770'. CIRC. TEST CSG. DISP WELL W/ BRINE. TEST CSG. OK. CIRC. RIG RELEASED. MW: 9.0 NaCl POOH. F/P TOP 600' W/ DIESEL. POOH. L/D BHA. N/D BOPE. N/U TREE. TEST TREE. OK. RIG RELEASED @ 16:30 HRS, 11/29/92. MOVE RIG. MW: 9.0 NaC1 SKID RIG TO AGI-1. 04/03/93 (25) TD:10850 PB:10770 MOVE RIG. MW: 9.0 NaC1 MOVE RIG. 04/04/93 (26) TD:10850 PB:10770 04/05/93 (27) TD:10850 PB:10770 04/06/93 (28) TD:10850 PB:10770 CIRC 9.3 PPG BRINE TO WELL. MW: 9.3 NaCl MOVE RIG. ACCEPT RIG @ 10:00 HRS, 4/3/93. N/D TREE. N/U BOPE. TEST BOPE. RIH W/ BAKER 'FB-i' PKR & 5-1/2" TAIL ASS'Y ON DP. DROP BALL. SET PKR @ 10049' W/ 2500 PSI. CIRC 9.3 PPG BRINE. N/U TREE. MW: 9.3 NaC1 POOH. L/D RUNNING TOOLS. RIH W/ 7" TBG, CAMCO SLVN. SPACE OUT TBG. PUMP 127 BBLS DIESEL TO F/P TOP 2000' LAND TBG. TEST TBG, ANNULUS, PKR @ 4000 PSI. TEST CNTRL LINES. OK. N/D BOPE. N/U TREE. RIG RELEASED. MW: 9.3 NaC1 TEST TBG, TREE. OK. SECURE WELL. RELEASE RIG @ 08:30 HRS, 4/5/93. SIGNATURE: (drilling superintendent) DATE: ARCO Alaska~ Inc. P.O2~lx 1OO36O Anchorage, .~l~.~lr~ 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 5-13 77~ 2{~ 5-28-93 5-24 ~/-/~ 5-22-93 5-32 ~ J~?~ 5-27-93 6-14A 4~75-19-93 7-14~I 5-25-93 9-3 5-18-93 9-3 7~~ 5-24-93 9-4A ~-~ 5-26-93 9-5A ~-~ ~ 5-30-93 ~28A ~-~ 5-28-93 9-3 lA ~ff35-19-93 9-32 ~1/~5-30-93 12-15 e~ -~ z 5-27-93 12-23 ~ ~- ~ 5-27-93 14-22A .~. 5-23-93 14-22A~l ~5-23-93' ~ ~. (~ ~ 18-29A ~5-18-93 AGI-I~.! ~ 5-20-93 AGI-1 5-20-93 AGI-2 ~.~¢c~J-23-93 AGI-2 ~-23-93 Pe~ Record AGI-3 ~, ~5s 5-20-93, AGI-3 , ~5-21-93 ~m~ Pe~ Record AGI-4 ~A~ 5-22-93 Intt~ Ped Record Sonya wsllsce A~1529 Completion Record Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Collar Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch TDTP (Borax) R~m 1, 5" Sch Production Log R~_m 1, 5" Sch Prod Profile R~m 1, 5" Sch Perf Record Run 1, 5" Sch Frod Profile Run 1, 5" Sch Production Log R~_m 1, 5" Sch Completion Record Rim 1, 5" Sch Production Log R~m 1, 5" Sch CBT Run 1, 5" Sch · Completion Record R,n 1, 5" Sch Completion Record Run 1, 5" Sch ' Leak Detection R-n 1, 2" Sch Perf Record R~_m 1, 5" Sch PITS R~m 1, 5" Sch Perf Record R~m 1, 5" Sch Jewelry Run 1, 5" Sch Perf Record Run 1, 5" Sch Jewelry Run 1, 5" Sch Run 1, 5" Sch R-n 1, 5" Sch R~_m 1, 5" Sch Run 1, 5" Sch The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 7, 1993 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 95501 RES ENG ~ ~ ENG EN'(3 ASST I FILE ---~- Re: Notice of Gas Injection Dear Mr. Johnston: -- , This is to inform you that on May 30, 1993 ~ARCO began gas iniection on the Apex Gas Injection pad. AGI wells #1, #2, #3 and #4 _are p-erf0rat~d an~l gas is being injected' at this time. Injection volumes, tubing and casing pressure information will be reported with the other gas injection wells on form 10-406. Donald F. Scheve Manager, Prudhoe Bay Operations Engineering DFS:llp C: M. L. Bill C. J. Phillips S. J. Wysocki AAI, ATO- 1528 BPX, MB9-2 AAI, ATO- 1554 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company REEEIVED JUN - 9 1995 Alaska 011 & Gas Oons. (;ommissio~ Anchorage MEMORANDUM TO: David Jo~.~,'~'/' Chairman" THRU: Blair Wondzell, P. i. Supervisor FROM: Jerry Herring, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April4, 1993 FILE NO: jh-rep35.doc SUBJECT: B.O.P. Test - AU D/I--~-----~ ARGO Alaska, Inb., AGI-1 PTD 92-124 '~,. Saturday, April 3, 1993: I witnessed a Blow Out Preventer Equipment (BOPE) test on AUDI rig 2 which is currently in a completion mode on the AGI gas injection pad. Refer to the BOPE Test Report attached for details. The BOPE test began at 5:00 p.m. and took 2-1/2 hours to complete. There were no equipment failures. The rig is scheduled to be stacked upon completion of the (10) AGI wells according to company man, Steve Walls. The crew seemed distracted and was obviously bothered by this recent announcement that the rig is to be stacked by mid May. During testing of the equipment, several components were missed by the crew and not tested. Because I was there to witness the test, I was vigilant and made the crew test al__J of the components which resulted in a good test. The crew has been working on the rig for several years and is a good crew. However, with the news that they would be unemployed soon, made it difficult for the crew to concentrate. I spoke to Steve Walls about this and he indicated there was nothing that could be done. It is interesting that AUDI 2 rig is to be stacked because the company is the only wholly owned Alaskan drilling company and has a good safety record. Summary: I witnessed the successful BOPE test on AUDI rig 2. The test took 2-1/2 hours and there were no failures. Attachment STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Drlg Contractor: Operator: Well Name: Casing Size: 9-5/8" Test: Initial x Workover: AUDI Rig No. 2 PTD # ARCO Alaska, Inc. Rep.: AGI-1 Rig Rep.: Set @ 10,278' Location' Sec. Weekly Other DATE: 4/3/93 92-124 Rig Ph.# 659-4605 Steve Walls Jack Boehler 36 T. 12N R. 14E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Drl. Rig OK Reserve Pit N/A BOP STACK: Quan. Annular Preventer 1 Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves 1 Check Valve N/A MUD SYSTEM: Visual Trip Tank OK Pit Level Indicators OK Flow Indicator OK Gas Detectors OK Test Pressure P/F 250/2500 ~ 1 250/5000 1 250/5000 1 250~000 1 250/5000 2 250/5000 250~000 N/A Alarm OK OK OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 11 250/5000 P 29 250/5000 P 2 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 1950 Ave. 3,100 P 1,300 P 0 minutes 16 sec. minutes 50 sec. OK Remote: OK Psig. Number of Failures 0 Test Time 2 1/2 Hours Number of valves tested 40 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: AUDI Rig 2 is to be stacked upon completion of the(10) AGI wells according to Company Man, Steve Walls. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Jerry P. Herring FI-021L (Rev. 2/93) BOP-AUD2.XLS ARCO Alas~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-21-92 REFERENCE: ARCO DIRECTIONAL DATA Q2--ILD ~ -!l-13A 11-9-92 MWD Directional Survey Ana q~ t ~14-22A 11-29-92 MWD Directional Survey Ana a~lL~17-20 10/4-15/92 MWD Directional Survey Job~ 1149 Teleco ~ 7~ ~~17-21 12-3-92 MWD Directional Survey Job~1153 Teleco ~~18-22 11-30-92 'MWD Directional Survey Job#AK-MW-20092 Sperry '~~AGI- 1 11-23-92 MWD Directional Survey Job~ 1152TAK Teleco rr~~~I-2 12-15-92 MWD Directional Survey Job~ 1156 Teleco Please sign and return tl~e attached copy as receipt of data. RECEIVED B ¥__~~~.~ ~'~/x~ ~ ATO-1529 ~ CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PHILLIPS # PB WELL FILES R&D # BPX # ST. OF AK, (2 COPIES) TEXACO RECEIVED- FEB 0 1 199~] Alaska Oil & Gas Cons. ~chorag. e STATE OF ALASKA ALASKA L)IL AND GAS CONSERVATION CO~v, MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPEI',DED [] ABANDONED [] '~F-~CI~"D< A~ex Gas Iniector 2. Name of O~rator 7. Permit Numar ARCO Alaska, Inc, 92-124 3. Address 8. APl Number P, O. ~x 196612, Anchorage, Alaska 9~19-6612 50- 029-22307 4. L~ation of well at surface 9. Unit or Le~e Name 1583' NSL, 2390' WEL, SEC. 36, T12N, R14E~ ~;~,,~U~y~ ~?~ ~ : ::'~- ~ ~ ..... ~r. Prudhoe Bay Unit At Top Producing Inte~al ~ .... ;~ ~~ 10. Well Number N/A ~/4~_?~&,~~ ~ ~F~ ~ AGI-1 ~ ~,~: ~_~ :-~. ~ ~ 11. Field and P~I At Tot~ D~th ~ ~ ~~ Prudhoe Bay Field/Prudhoe Bay Pool 1205' NSL, 1280' WEL, SEC. 31, T12N, R15E: ..... 5. Elev~ion in f~t (indicate KB, DF, etc.) j6. Le~e Design~ion ~d Sedal No. KBE = 49' ~ ADL 34628 12'. Date Spudded 13. D~e T.D. Re~ 14. Date Comp., Su~. ~ Aband. J15. Water Depth, if offshore J16. No. of Completions 11/13/92 11/27/92 11/29/92~ N/A feet MSL ~ Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where ~SV ~t ~1. Thickness of Permalrost 10850' MD/8540' ~D 10770 MD/84 ~' ~D ~ ~ ~ D~ Nonefeet MD' ~ 1900' (Approx,) 22. Type El~tric or Other L~s Run DSF~CD~CN/GR ,,. 23. CASI~, LINER ~D CEM~I~ ~ D~ MD CASING S~E ~. ~R ~. G~E T~ ~OU ~E ~ C~~ R~D ~~ ~LLED 30" 91.~ H-40 Sudace 75' 30" 11 yds Arcticset 13-3/8" 6~ NT-80 40' 3911' 16" 1500 sx PF "E"/400 sx "G" 9-5/8" 47~ NT-80 38' 10260' 12-1/4" 375 sx Class "G" 7" ~ 26~ NTS-80 10141' 10850' 8-1/2" 170 sx Class "G" 24. Pedorations o~n to Production (MD+TVD of T~ and Bottom and 25. ~HGR~RD interval, size and number) S~E DEP~ S~ (MD) PACKER SET (MD) None None 26. ACID, F~C~RE, CEME~ ~UE~, ~C. DEPTH I~ERVAL (MD) A~U~ & KIND OF MATERI~ 27. PRO~N TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) Not Yet Inj~ting ~ N/A Date of Test Hours Tested ~O~T~R OIL-BBL ~S-~F WATER-BBL C~E~E IGAS-OIL RATIO T~T P~D I Flow Tubing Casing Pre~ure ;~CU~TED OIL-BBL ~S-~F WATER-BBL OIL GRAVITY-APl (corr) !Press. 24-~UR RATE 28. CORE DATA Brief description of lithology, porosity, fracture, a~arent dips, and pr~en~ of oil, gas or water. Submit ~re chips. · ~: ..~ ~:,: ~' ~ :, ~.: · ~.~ ,,.-..,.~-~ ;.~-.~:.~ :- ,.~ ~,,..,..~., ,~; ...... ~,., ~ ;i ~ ~.. -=. ~ .,_:~. ~;., ~': ~;~ .~;.~,-: Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GECt_OGIC MARKERS r,.,RMATION TESTS NAME Include interval tested, pressure data, all tluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Shublik 10233' 8055' (ss) Top Sadlerochit 10241' 8061' (ss) Base Sad/erochit 10724' 8441' (ss) 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~' ~ Title D ri//ingEngineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ; .. .: ' ,,.~ :., ? ,,-' Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI-1 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/12/92 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 11/08/92 ( 1) TD: 110' ( 110) MOVE RIG MOVE RIG TO AGI -1. MW: 8.5 VIS: 0 11/09/92 ( 2) TD: 110'( 0) MOVE RIG. MOVE RIG. MW: 8.5 VIS: 0 11/10/92 (3) TD: 110'( 0) MOVE RIG. MOVING RIG. MW: 8.5 VIS: 0 11/11/92 ( 4) TD: 110' ( 0) MOVE RIG. MOVE RIG TO AGI PAD. MW: 8.5 VIS: 0 11/12/92 (5) TD: 110'( 0) RIG MOVE. MOVE RIG. MW: 8.5 VIS: 0 11/13/92 ( 6) TD: 200'( 90) 11/14/92 ( 7) TD: 1900' (1700) 11/15/92 ( 8) TD: 3920' (2020) 11/16/92 ( 9) TD: 3920' ( 0) 11/17/92 (10) TD: 3920' ( 0) DRLG. MW: 8.7 VIS: 85 RIG UP. RIG ACCEPTED @ 21:00 HRS, 11/12/92. P/U BHA. TEST DIVERTER. SPUD WELL @ 05:00 HRS, 11/13/92. DRLG F/ 100'-200' DRILLING MW: 9.1 VIS: 90 DRILLING TO 1399'. SERVICE RIG & TOP DRIVE. DRILL TO 1900' WIPER TRIP MW: 9.2 VIS: 80 DRILL TO 2057' CIRC. SHORT TIP. DRILL TO 3464' SERVICE RIG. DRILL TO 3920' CBU. NU WELLHEAD MW: 9.3 VIS: 75 SHORT TRIP. CIRC HI-VIS SWEEP. POOH. RUN 13-3/8 CASING. SHOE AT 3911' CEMENTED. DO TOP JOB ON 13-3/8 ANNULUS. PRESSURE TESTING CASING MW: 8.9 VIS: 36 NU BOPS. TEST BOPS. SERVICE RIG. RIH W/BHA#2. CBU. CIRC. WELL · AGI-1 OPERATION: RIG : AUDI 2 PAGE: 2 11/18/92 (11) TD: 6100' (2180) 11/19/92 (12) TD: 6573' ( 473) 11/20/92 (13) TD: 8067' (1494) DRILLING MW: 9.3 VIS: 37 TESTED CASING. CBU. CIRC & COND. DRILLED TO 4684' CBU. SHORT TRIP TO 13-3/8. CIRC. SHORT TRIP TO BOTTOM. DRILL TO 6100' CUTTING DRILL LINE MW: 9.2 VIS: 39 DRILL TO 6108' MOTOR FAILURE. DROPPED SS SURVEY. POH. REPLACED BROKEN MUD MOTOR SHAFT. TIH. DRILLED TO 6573' MWD TOOL FAILED. CIRC. POH. TESTED MWD. DRILLING TIH. DRILLFROM 6573 - 8067' MW: 9.3 VIS: 40 11/21/92 (14) TD: 8552' ( 485) 11/22/92 (15) TD: 9420'( 868) DRILLING MW: 9.3 VIS: 38 SERVICED RIG. DRILLED TO 8088'. CIRC. TOH. CHANGED BHA. TIH. DRILL TO 8376'. REPAIRD PUMP #1. DRILLED TO 8552' DRILLING DRILLED TO 9108' MW: 9.4 VIS: 41 CBU. DRILL TO 9420' 11/23/92 (16) TD:10027' ( 607) 11/24/92 (17) TD:10270' ( 243) 11/25/92 (18) TD:10270' ( 0) 11/26/92 (19) TD: 10479' ( 209) 11/27/92 (20) TD:10850' ( 371) DRILLING MW: 9.8 VIS: 42 DRILLED TO 9455'. REPAIRED MUD PUMP #2. DRILL TO 9849' CIRC. SHORT TRIP. CBU. DRILL TO 10027' RUNNING CASING MW: 9.8 VIS: 43 DRILLED TO 10270' CIRC. SHORT TRIP. CIRC. RAN CASING TO 13-3/8 SHOE. RUNNING 9-5/8 CASING. RIH TO DRILL OUT CMT MW: 9.9 VIS: 44 CONT'D TO RUN 9-5/8" CSG TO 7000', CBU, RUN & LAND CSG, CIRC & COND MUD, BATCH MIX CMT, PUMPED 375 SX CMT, SQUEEZE 175 BBLS MUD DOWN 9-5/8" X 13-3/8" ANNULUS, R/D LNDG JT & CSG TOOLS, TUN PACKOFF & TEST, CHG PIPE RAMS, RUN WEAR RING, FREEZE PROTECT ANNULUS TO 1500' W/90 BBLS DIESEL, CUT DRLG LINE, L/D BHA, RIH TO TAG UP ON FLOAT COLLAR & DRILL OUT RIH. MW: 8.9 VIS: 55 RIH. TEST CSG. DRLG FC, FS, 10' NEW HOLE. CBU. FIT (12.5 PPG EMW). CLEAN PITS. DISP WELL W/ KCL. DRLG TO 10479'. CBU. POOH. RIH. CIRC. MW: 9.2 VIS: 63 RIH. REAM F/ 10369'-10479' DRLG TO 10522' POOH FOR BIT. RIH. DRLG TO 10850'. TD WELL @ 06:00 HRS, 11/27/92. WELL : AGI-1 OPERATION: RIG : AUDI 2 PAGE: 3 11/28/92 (21) TD:10850 PB: 0 11/29/92 (22) TD:10850 PB: 0 11/30/92 (23) TD:10850 PB:10770 RIH W/ 7" LNR. MW: 9.3 KCl CBU. SHORT RTIP TO SHOE. CIRC. POOH. R/U ATLAS. LOG RUN: DSFL/CDL/CN/GR. RIH W/ BHA. CBU. POOH. L/D BHA. R/U WOTCO. RIH W/ 7" LNR ON DP. POOH. MW: 9.0 NaC1 RIH W/ LNR. TAG @ 10850' LC @ 10770' CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 170 SX 'G' CMT @ 15.8 PPG. BUMP PLUG. SET HGR, PKR. RELEASE F/ LNR. CIRC. POOH. RIH W/ CSG SCRAPERS. TAG LC @ 10770' CIRC. TEST CSG. DISP WELL W/ BRINE. TEST CSG. OK. CIRC. RIG RELEASED. MW: 9.0 NaCl POOH. F/P TOP 600' W/ DIESEL. POOH. L/D BHA. N/D BOPE. N/U TREE. TEST TREE. OK. RIG RELEASED @ 16:30 HRS, 11/29/92. SIGNATURE: (drilling superintendent) DATE: 632416116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269 1 Fax: (907) 563-5865 Phone: ¢07) 562-2646/Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY WELL - AGI NO. 1 Apex Gas Injection Pad AUDI Rig #2 Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · No Interpolation · 100' MD Interpolated · 100' TVD Interpolated MEASURED DEPTH NO INTERPOLATION Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : AGI No.1 : Apex Gas Injection Pad : : : Nov. 23, 1992 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. · ..~.~.~'...'~..~.. COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI No.1 Location : Apex Gas Injection Pad : : No Interpolation Date Nov. 23, 1992 Filename : l152TAK Plane of Vertical Section : 93.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI No.1 Location : Apex Gas Injection Pad : : No Interpolation MD C~L INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 421 421 0.2 10.1 421 872 451 0.7 276.6 872 1053 181 1.5 118.1 1053 1240 187 4.2 108.2 1240 VS ft 0 0 -3 -2 7 LAT ft 0 1 2 1 -2 Page 1 of 2 Date Nov. 23, 1992 Filename : l152TAK DEP D'LEG BUILD TURN o o o ft /100 /100 /100 0 0.0 0.0 0.0 0 0.0 0.0 2.4 -2 0.2 0.1 -20.7 -1 1.2 0.4 -87.6 7 1.5 1.4 -5.3 1428 188 6.8 106.5 1427 1616 188 8.3 108.6 1613 1803 187 11.8 108.2 1797 1992 189 19.1 94.5 1979 2181 189 25.2 96.3 2154 25 49 80 130 201 -8 24 1.4 1.4 -0.9 -15 48 0.8 0.8 1.1 -26 79 1.9 1.9 -0.2 -34 128 4.3 3.9 -7.2 -41 199 3.2 3.2 1.0 2368 187 31.2 85.0 2319 2557 189 31.8 91.0 2480 2744 187 36.0 91.7 2636 2931 187 38.7 92.1 2784 3119 188 41.7 93.5 2928 289 -41 287 4.3 3.2 -6.0 387 -38 386 1.7 0.3 3.2 491 -40 490 2.3 2.2 0.4 605 -44 603 1.4 1.4 0.2 726 -50 724 1.7 1.6 0.7 3305 186 44.8 94.2 3063 3493 188 45.9 90.6 3195 3681 188 44.8 90.3' 3328 3855 174 44.1 88.2 3452 4055 200 44.3 89.6 3595 853 987 1121 1242 1381 -58 852 1.7 1.7 0.4 -64 985 1.5 0.6 -1.9 -65 1119 0.6 -0.6 -0.2 '63 1241 0.9 -0.4 -1.2 -61 1380 0.5 0.1 0.7 4243 188 46.1 89.6 3728 4525 282 45.4 89.9 3924 4806 281 45.2 89.9 4122 5088 282 45.5 89.9 4320 5367 279 45.1 89.9 4516 1514 1716 1915 2116 2314 -60 1513 1.0 1.0 0.0 -59 1715 0.3 -0.2 0.1 C59 1915 0.1 -0.1 0.0 -58 2116 0.1 0.1 0.0 -58 2314 0.1 -0.1 0.0 5649 282 44.0 93.5 4717 5931 282 44.2 93.5 4920 6229 298 44.4 94.2 5133 6508 279 43.8 93.8 5334 6791 283 44.2 93.8 5537 2511 -64 2512 1.0 -0.4 1.3 2708 -76 2708 0.1 0.1 0.0 2916 -90 2915 0.2 0.1 0.2 3110 -103 3109 0.2 -0.2 -0.1 3306 -116 3305 0.1 0.1 0.0 7072 281 44.6 96.3 5738 7352 280 45.1 94.9 5936 7631 279 45.0 91.4 6134 7910 279 44.6 91.7 6332 8201 291 43.0 91.4 6542 3503 -134 3501 0.6 0.1 0.9 3700 -153 3698 0.4 0.2 -0.5 3898 -164 3895 0.9 -0.0 -1.3 4094 -169 4091 0.2 -0.1 0.1 4295 -174 4292 0.6 -0.5 -0.1 8483 282 43.6 91.0 6747 8759 276 43.6 91.7 6947 9033 274 43.1 93.5 7146 9323 290 42.1 95.2 7359 9604 281 42.1 98.7 7568 4489 -179 4486 0.2 0.2 -0.1 4679 -183 4676 0.2 0.0 0.3 4867 -192 4864 0.5 -0.2 0.7 5063 -206 5060 0.5 -0.3 0.6 5251 -229 5247 0.8 0.0 1.2 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI No.1 Location : Apex Gas Injection Pad : : No Interpolation MD CkL INC DIR TVD ft ft deg deg ft 9882 278 39.4 98.4 7779 10200 318 36.5 102.6 8029 VS ft 5432 5626 LAT ft -256 -292 Page 2 Date Nov. Filename DEP ft 5426 5618 D'LEG o/ oo 1.0 1.2 of 2 23, 1992 · l152TAK BUILD o/ 00 -1.0 -0.9 TURN °/100 -0.1 1.3 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5626 ft 93.0° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : AGI No.1 : Apex Gas Injection Pad : : : Nov. 23, 1992 : · Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI No.1 Location : Apex Gas Injection Pad : : Date Nov. 23, 1992 Filename : l152TAK Interpolated 100 ft of MD Plane of Vertical Section : 93.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI No.1 Apex Gas Injection Pad Page 1 of 3 Date Nov. 23, 1992 Filename : l152TAK Interpolated 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 100 100 0.0 2.4 100 200 100 0.1 4.8 200 300 100 0.1 7.2 300 400 100 0.2 9.6 400 5OO 6OO 700 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OOO 3100 3200 3300 3400 3500 3600 3700 3800 3900 100 0.3 56.8 500 100 0.4 115.9 600 100 0.5 175.0 700 100 0.6 234.1 800 100 0.8 252.1 900 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 1.3 164.5 1000 2.2 115.6 1100 3.6 110.3 1200 5.0 107.7 1299 6.4 106.8 1399 7.4 107.3 1498 8.2 108.4 1597 9.9 108.4' 1696 11.7 108.2 1794 15.5 101.2 1891 19.4 94.6 1987 22.6 95.5 2079 25.8 95.2 2171 29.0 89.1 2259 31.3 86.0 2347 31.6 89.2 2432 32.8 91.2 2516 35.0 91.5 2599 36.8 91.8 2680 38.3 92.0 2760 39.8 92.6 2837 41.4 93.4 2913 43.0 93.8 2987 44.7 94.2 3060 45.4 92.4 3130 45.9 90.6 3200 45.3 90.4 3271 44.7 90.1 3341 44.3 88.9 3412 44.1 88.5 3484 VS ft 0 0 0 0 0 -0 -1 -2 -2 -2 -2 1 5 13 22 34 47 63 8O 106 133 171 210 257 306 LAT ft 0 0 0 1 1 1 -0 -2 -4 '--7 -11 -15 -20 -25 -30 -34 -38 -41 -41 -40 DEP D ' LEG BUILD TURN o ft °/100 °/100 /100 0 0.0 0.0 0.0 0 0.0 0.0 2.4 0 0.0 0.0 2.4 0 0.0 0.0 2.4 0 0.0 0.0 2.4 -0 0.2 0.1 47.2 -1 0 . 4 0 . 1 59 . 1 -1 0.5 0.1 59.1 -2 0.6 0.1 59.1 -2 0.3 0.2 18.0 -2 1.5 0.4 -87.6 1 1.6 0.9 -48 . 9 5 1.5 1.4 -5.3 13 1.4 1.4 -2.7 22 1.4 1.4 -0.9 33 1.0 1.0 0.6 46 0.8 0.8 1.1 62 1.7 1.7 -0.0 78 1.9 1.9 -0.2 104 4.1 3.8 -7.0 131 4.3 3.8 -6.6 169 3.2 3.2 1.0 208 3.2 3.2 -0.4 255 4.2 3.2 -6.0 304 2.8 2.3 -3.1 357 -39 356 1.7 0.3 3.2 411 -38 410 1.6 1.1 2.0 467 -40 465 2.3 2.2 0.4 525 -41 524 1.8 1.8 0.3 586 -43 584 1.4 1.4 0.2 649 714 782 85O 921 -46 -49 -54 -58 -61 -64 -65 -65 -64 -63 992 1063 1134 1204 1274 648 1.6 1.5 0.6 712 1.7 1.6 0.7 780 1.7 1.7 0.4 848 1.7 1.7 0.4 919 1 . 4 0 . 6 -1.8 990 1.4 0.5 -1.8 1061 0.6 -0.6 -0.2 1132 0.6 -0.6 -0.4 1202 0.9 -0.4 -1.2 1272 0.3 -0.2 -0.3 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI No.1 Apex Gas Injection Pad Page 2 Date Nov. Filename Interpolated of 3 23, 1992 : l152TAK 100 ft of MD MD ft 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5OOO 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6OOO 6100 6200 6300 6400 65OO 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL ft 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 INC DIR TVD VS LAT deg deg ft ft £t 44.2 89.2 3556 1343 -62 44.7 89.6 3627 1413 -61 45.7 89.6 3697 1484 -60 46.0 89.7 3767 1555 -60 45.7 89.8 3837 1627 -59 DEP D ' LEG ft °/100 1342 0.5 1412 0.6 1483 1.0 1554 0.3 1626 0.3 BUILD TURN °/100 °/100 0.1 0.7 0.5 0.4 1.0 0.0 0.3 0.1 -0.2 0.1 45.5 89.9 3907 1698 -59 1698 0.3 -0.2 0.1 45.3 89.9 3977 1769 -59 1769 0.1 -0.1 0.0 45.3 89.9 4047 1840 -59 1840 0.1 -0.1 0.0 45.2 89.9 4118 1911 -59 1911 0.1 -0.1 0.0 45.3 89.9 4188 1982 -59 1982 0.1 0.1 0.0 45.4 89.9 4258 2053 -58 2053 0.1 45.5 89.9 4329 2124 -58 2124 0.1 45.3 89.9 4399 2195 -58 2195 0.1 45.2 89.9 4469 2266 -58 2267 0.1 45.0 90.3 4540 2337 -59 2337 0.4 44.6 91.6 4611 44.2 92.9 4683 44.0 93.5' 4754 44.1 93.5 4826 44.2 93.5 4898 44.2 93.7 4969 44.3 93.9 5041 44.4 94.1 5112 44.2 94.1 5184 44.0 94.0 5256 0.1 0.0 0.1 0.0 -0.1 0.0 -0.1 0.0 -0.2 0.4 2407 -61 2407 1.0 -0.4 1.3 2477 -63 2477 1.0 -0.4 1.3 2547 -66 2547 0.5 -0.2 0.6 2616 -70 2617 0.1 0.1 0.0 2686 -74 2686 0.1 0.1 0.0 2756 -79 2756 0.1 2826 -84 2825 0.2 2896 -88 2895 0.2 2965 -93 2965 0.1 3035 -98 3034 0.2 3104 -1~03 3103 0.2 3174 -107 3173 0.1 3243 -112 3242 0.1 3313 -117 3311 0.2 3383 -123 3381 0.6 43.8 93.8 5328 43.9 93.8 5400 44.1 93.8 5472 44.2 93.9 5544 44.4 94.8 5615 44.5 95.7 5687 44.6 96.2 5758 44.8 95.7 5829 45.0 95.2 5900 45.1 94.3 5970 3453 -129 3451 0.6 3523 -136 3521 0.4 3593 -142 3591 0.4 3664 -149 3661 0.4 3734 -155 3731 0.6 45.0 93.0 6041 3805 -159 3802 0.9 45.0 91.8 6112 3876 -162 3873 0.9 44.9 91.5 6183 3946 -165 3943 0.2 44.8 91.6 6254 4017 -167 4014 0.2 44.6 91.7 6324 4087 -169 4084 0.2 0.1 0.2 0.1 0.2 0.1 0.2 -0.1 -0.0 -0.2 -0.1 -0.2 -0.1 0.1 -0.0 0.1 0.0 0.1 0.1 0.1 0.9 0.1 0.9 0.2 0.5 0.2 -0.5 0.2 -0.5 0.1 -0.9 -0.0 -1.3 -0.0 -1.3 -0.1 -0.3 -0.1 0.1 -0.1 0.1 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI No.1 Apex Gas Injection Pad Page 3 Date Nov. Filename Interpolated of 3 23, 1992 : l152TAK 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 44.1 91.6 6397 8100 100 43.6 91.5 6469 8200 100 43.0 91.4 6541 8300 100 43.2 91.3 6614 8400 100 43.4 91.1 6686 8500 100 43.6 91.0 6759 8600 100 43.6 91.3 6832 8700 100 43.6 91.6 6904 8800 100 43.5 92.0 6977 8900 100 43.3 92.6 7049 9000 100 43.2 93.3 7122 9100 100 42.9 93.9 7195 9200 100 42.5 94.5 7269 9300 100 42.2 95.1 7343 9400 100 42.1 96.2 7417 9500 100 42.1 97.4 7491 9600 100 42.1 98.7 7565 9700 100 41.2 98.6 7641 9800 100 40.2 98.5 7716 9900 100 39.2 98.6 7793 10000 100 38.3 100.0 7872 10100 100 37.4 101.3 7950 10200 100 36.5 102.6 8029 VS LAT DEP D'LEG ft ft ft °/100 4156 -171 4153 0.5 4226 -173 4223 0.6 4295 -174 4292 0.6 4363 -176 4360 0.2 4432 -177 4429 0.2 4500 4569 4638 4707 4776 BUILD TURN o o /100 /100 -0.5 -0.1 -0.5 -0.1 -0.5 -0 · 1 0.2 -0.1 0.2 -0.1 -179 4498 0.2 0.2 -0.1 -180 4566 0.2 0.0 0.3 -182 4635 0.2 0.0 0.3 -184 4704 0.3 -0.1 0.4 -187 4773 0.5 -0.2 0.7 4844 -190 4841 0.5 4912 -195 4909 0.5 4980 -200 4977 0.5 5048 -205 5044 0.5 5115 -213 5111 0.7 5182 5249 5314 5379 5443 -0.2 0.7 -0.3 0.6 -0.3 0.6 -0.3 0.6 -0.1 1.1 -221 5177 0.8 0.0 1.2 -229 5244 0.8 0.0 1.2 -238 5309 0.9 -0.9 -0.1 -248 5373 1.0 -1.0 -0.1 -2'58 5437 1.0 -1.0 0.1 55O4 5565 5626 -269 5497 1.2 -0.9 1.3 -280 5558 1.2 -0.9 1.3 -292 5618 2.4 -1.8 2.6 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5626 ft 93.0° TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : Apex Gas Injection Pad No.1 : Apex Gas Injection Pad : : · Nov. 23, 1992 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE Eastman Teleco Client · Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Pad No.1 Location : Apex Gas Injection Pad : : Date Nov. 23, 1992 Filename : l152TAK Interpolated 100 ft of TVD Plane of Vertical Section : 93.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° +0° 0' 0' ' (T) Client Well Name Location Prudhoe Apex Gas Apex Gas Eastman Teleco Bay Drilling Group Injection Pad No.1 Injection Pad Page 1 of 3 Date Nov. 23, 1992 Filename : l152TAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS LAT ft ft deg deg ft ft ft 0 0 0.0 0.0 0 0 0 100 100 0.0 2.4 100 0 0 200 100 0.1 4.8 200 0 0 300 100 0.1 7.2 300 0 1 400 100 0.2 9.6 400 0 1 5OO 6OO 700 8OO 9OO 1000 1100 1200 1301 1401 1502 1603 1704 1806 1910 2014 2122 2233 2346 2463 2581 2701 2825 2952 3083 3218 3357 3500 3642 3782 3922 4062 4204 4347 4490 100 0.3 56.8 500 -0 1 100 0.4 115.9 600 -1 1 100 0.5 175.0 700 -2 1 100 0.6 234.1 800 -2 2 100 0.8 252.1 900 -2 2 100 100 100 100 100 101 101 101 102 104 105 108 110 113 117 118 121 124 127 131 136 139 142 142 141 140 140 142 143 143 1.3 2.2 3.6 5.0 6.4 164.5 1000 115.6 1100 110.3 1200 107.7 1300 106.7 1400 7.4 107.3 1500 8.2 108.5 1600 10.0 108.4' 1700 11.9 108.0 1800 15.9 100.5 1900 19.8 23.3 26.9 30.5 31.5 32.3 35.0 37.2 39.0 41.1 43.4 45.1 45.9 45.0 44.4 44.2 44.4 45.7 45.8 45.5 -2 1 5 13 22 34 47 64 81 108 1 -0 -2 -4 -7 -'11 -15 -20 -26 -30 94.7 2000 138 -35 95.7 2100 179 -39 93.2 2200 225 -41 86.3 2300 279 -41 88.0 2400 338 -39 91.1 2500 400 -38 91.5 2600 467 -40 91.9 2700 540 -42 92.3 2800 618 -45 93.2 2900 703 -49 93.9 3000 794 -54 93.2 3100 891 -60 90.6 3200 992 -64 90.4 3300 1093 -65 89.1 3400 1192 ~64 88.7 3500 1289 -63 89.6 3600 1386 -61 89.6 3700 1487 -60 89.7 3800 1589 -60 89.9 3900 1691 -59 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 2.4 0 0.0 0.0 2.4 0 0.0 0.0 2.4 0 0.0 0.0 2.4 -0 0.2 0.1 47.2 -1 0.4 0.1 59.1 -1 0.5 0.1 59.1 -2 0.6 0.1 59.1 -2 0.3 0.2 18.0 -2 1.5 0.4 -87.6 1 1.6 0.9 -48.9 5 1.5 1.4 -5.3 13 1.4 1.4 -2.6 22 1.4 1.4 -0.9 34 1.0 1.0 0.6 46 0.8 0.8 1.1 63 1.7 1.7 -0.0 80 1.9 1.9 -0.4 107 4.2 3.9 -7.2 137 4.1 3.7 -5.5 177 3.2 3.2 1.0 223 3 . 4 3.2 -2.3 277 4.3 3.2 -6.0 336 1.1 0.9 1.4 399 1.6 0.7 2.6 466 2.3 2.2 0.4 539 1.7 1.7 0.3 617 1.5 1.5 0.3 701 1.7 1.6 0.7 792 1.7 1.6 0.5 889 1.3 1.3 -0.5 990 1.4 0.5 -1.8 1091 0.6 -0.6 -0.2 1190 0.8 -0.5 -0.9 1288 0.3 -0.2 -0.3 1385 0.5 0.1 0.7 1486 1.0 1.0 0.0 1588 0.1 0.1 0.1 1690 0.3 -0.2 0.1 Client Well Name Location : Prudhoe : Apex Gas : Apex Gas : : Eastman Teleco Bay Drilling Group Injection Pad No.1 Injection Pad Page 2 Date Nov. Filename Interpolated of 3 23, 1992 : l152TAK 100 ft of TVD MD ft 4632 4775 4917 5059 5201 5344 5484 5624 5764 5903 6043 6183 6322 6461 6600 6739 6879 7019 7160 7301 7442 7583 7725 7865 8005 8143 8281 8419 8556 8694 8832 8970 9106 9242 9378 9512 9646 9778 9909 10036 CkL INC DIR TVD VS ft deg deg ft ft 142 45.3 89.9 4000 1792 142 45.2 89.9 4100 1893 142 45.3 89.9 4200 1994 142 45.5 89.9 4300 2095 142 45.3 89.9 4400 2196 142 45.1 89.9 4500 2297 141 44.6 91.4 4600 2396 140 44.1 93.2 4700 2494 139 44.1 93.5 4800 2591 139 44.2 93.5 4900 2688 LAT DEP D'LEG ft ft °/100 -59 1792 0.1 -59 1893 0.1 -58 1994 0.1 -58 2095 0.1 -58 2196 0.1 BUILD TURN °/100 °/100 -0.1 0.0 -0.1 0.0 0.1 0.0 0.1 0.0 -0.1 0.0 -58 2297 0.1 -0.1 0.0 -60 2396 0.8 -0.3 1.1 -63 2495 1.0 -0.4 1.3 -69 2592 0.2 -0.0 0.2 -75 2688 0.1 0.1 0.0 140 44.3 93.8 5000 2786 -81 2786 0.1 140 44.4 94.1 5100 2883 -88 2883 0.2 139 44.2 94.1 5200 2980 -94 2980 0.1 139 43.9 93.9 5300 3077 -101 3077 0.2 139 43.9 93.8 5400 3174 -107 3173 0.0 0.1 0.2 0.1 0.2 -0. 1 -0. 0 -0.2 -0. 1 0.0 -0.0 139 44.1 93.8 5500 3271 -114 3269 0.1 0.1 0.0 140 44.3 94.6 5600 3368 -122 3366 0.4 0.1 0.6 140 44.5 95.8' 5700 3466 -130 3464 0.6 0.1 0.9 141 44.8 95.9 5800 3565 -140 3562 0.2 0.2 0.0 141 45.0 95.2 5900 3664 -149 3661 0.4 0.2 -0.5 141 45.1 93.8 6000 3764 -156 3761 0.7 142 45.0 92.0 6100 3864 -162 3861 0.9 141 44.9 91.5 6200 3964 -165 3961 0.3 141 44.7 91.7 6300 4063 -168 4060 0.2 139 44.1 91.6 6400 4160 -171 4157 0.4 139 43.3 91.5 6500 4256 -173 4253 0.6 138 43.2 91.3 6600 4350 -176 4347 0.1 137 43.5 91.1 6700 4445 -i78 4442 0.2 138 43.6 91.2 6800 4539 -180 4536 0.1 138 43.6 91.5 6900 4635 -182 4632 0.2 0.0 -1.0 -0.0 -1.3 -0.1 .-0.4 -0.1 0.1 -0.4 -0.0 -0.5 -0.1 -0.1 -0.1 0.2 -0.1 0.1 0.1 0.0 0.3 -222 5186 0.8 0.0 1.2 -233 5274 0.6 -0.3 0.8 -246 5359 1.0 -1.0 -0.1 -259 5443 1.0 -1.0 0.2 -273 5519 1.2 -0.9 1.3 135 42.1 97.6 7500 5190 134 41.7 98.7 7600 5279 132 40.4 98.5 7700 5364 131 39.2 98.8 7800 5448 127 38.0 100.4 7900 5526 138 43.5 92.2 7000 4729 -185 4726 0.3 -0.1 0.5 138 43.2 93.1 7100 4824 -190 4821 0.5 -0.2 0.7 137 42.8 93.9 7200 4917 -195 4914 0.5 -0.3 0.6 136 42.4 94.7 7300 5009 -202 5005 0.5 -0.3 0.6 135 42.1 95.9 7400 5100 -211 5096 0.6 -0.2 0.9 Eastman Teleco Client · Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Pad No.1 Location : Apex Gas Injection Pad : : Page 3 of 3 Date Nov. 23, 1992 Filename · l152TAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS ft ft deg deg ft ft 10163 127 36.8 102.1 8000 5603 10200 37 36.5 102.6 8029 5626 LAT ft -287 -2.92 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 5596 1.2 -0.9 1.3 5618 1.6 -1.2 1.7 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5626 ft 93.0° SUB- SURFACE DIRECTIONAL SURVEY F~ UIDANCE ONTINUOUS F~ OOL RECEIYfD Alaska Oil & Gas Cons. Anchorage Company ARCO ALASKA, INC. Well Name AG[-1 11583' FSL, 2390' FEE, SEC 26, T12N, R14E) Field/Location PRUi)HOE BAY, NORTH SLOPE, ALASKA Job Reference No. 93186 Logcied By: SARBER Date /~ / J / ~b Computed By: /' / S~[FIES · SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA SURVEY DATE- 4-APR-1993 ENGINEER' SARBER METHODS OF COMPUTATION TOOL LOCATION' MINIMUM CURVATURE R C£1 - 4i~s~ 0~ ~ G'a~ Cons. Cummission Anchorage INTERPOLATION- LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 86 DEG 46 MIN EAST COMPUTATION DATE' 27-APR-93 PAGE I ARCO AGI-1 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 4-APR-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG BIN DEG BIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIBUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 99 90 199 90 299 9O 399 90 499 599 699 799 899 90 89 89 89 88 -49 O0 50 90 150 9O 250 90 350 90 450 90 550.89 650.89 750.89 850.88 0 0 N 0 0 E 0 12 S 58 17 W 0 15 S 73 27 E 0 19 N 46 6 E 0 19 N 16 6 W 0 19 N 83 30 W 0 8 N 10 14 W 0 31 N 37 13 W 0 34 S 84 44 W 0 28 N 43 14 W 0 O0 -0 18 -0 09 0 35 0 51 0 05 -0 33 =0 50 -1 36 -2 21 0 O0 0 42 0 45 0 39 0 3O 0 38 0 29 0 53 0 75 0 63 0 O0 N 0 01S 0 28 S 0 12 S 0 33 N 0 62 N 0 66 N I 24 N I 56 N 167 N 0 O0 E 0 18 W 0 11 W 0 34 E 0 53 E 0 09 E 0 30 W 0 43 W 1 28 W 2 12 W 0 O0 N 0 0 E 18 S 86 3 W 30 S 21 28 W 36 S 70 36 E 62 N 58 13 E 63 N 8 0 E 72 N 24 18 W 31 N 19 10 W 01 N 39 22 W 70 N 51 46 W 1000 OO 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 88 O0 1099 O0 1199 O0 1299 O0 1398 O0 1498 O0 1597 O0 1696 O0 1794 O0 1891 950.88 0 40 S 39 6 E 84 1050.84 2 15 S 67 18 E 72 1150.72 3 31 S 73 25 E 42 1250.42 5 18 S 74 22 E 91 1349.91 6 11 S 75 5 E 27 1449.27 6 44 S 75 14 E 47 1548,47 8 5 S 74 9 E 06 1647.06 10 41 S 73 35 E 15 1745.15 11 45 S 72 35 E 54 1842.54 15 10 S 79 2 E -2 34 0 O0 4 68 12 29 22 O7 33 16 45 46 61 75 80 63 102 74 0 92 1 65 1 41 1 64 1 20 0 7O 0 89 2 32 0 98 2 33 1 69 N 0 50 N 1 10 S 3 24 S 5 89 S 8 76 S 12 10 S 16 71S 22 51S 28 2 25W 0 4 12 21 32 44 60 79 32 S 101 2 81 N 53 5 W 03 E 0 62 E 4 13 E 12 78 E 22 72 E 33 85 E 46 90 E 63 48 E 82 30 E 105 50 N 3 31E 75 S 76 38 E 56 S 75 3 E 56 S 74 52 E 87 S 75 1E 45 S 74 54 E 15 S 74 39 E 61 S 74 11E 18 S 74 23 E 2000 O0 1986 78 1937 78 19 27 2100 2200 2300 2400 25OO 2600 2700 2800 O0 2080 O0 2171 O0 2258 O0 2344 O0 2429 O0 2514 O0 2596 O0 2676 41 2031 28 2122 57 2209 25 2295 93 2380 72 2465 40 2547 56 2627 41 22 18 28 27 3 57 30 44 25 30 58 93 31 19 72 33 18 40 36 11 56 37 35 2900 O0 2755 O1 2706 O1 38 39 3000 O0 2832 53 2783.53 40 2 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2908 O0 2982 O0 3054 O0 3125 O0 3195 O0 3265 O0 3336 O0 3407 O0 3479 29 2859.29 41 19 69 2933.69 42 50 85 3005 85 44 25 67 3076 67 45 35 31 3146 31 45 58 19 3216 19 45 9 O0 3287 O0 44 49 57 3358 57 44 3 35 3430 35 44 6 S 84 56 E S 83 33 E S 86 15 E N 85 7 E N 85 7 E N 88 3 E S 87 28 E S 88 19 E S 87 39 E S 87 43 E 133 07 168 12 209 74 258 30 309 29 360 48 413 41 471 07 530 84 592 83 S 87 30 E 655 99 S 86 49 E 721 S 86 43 E 788 S 85 26 E 857 S 86 34 E 927 N 89 3 E 999 N 88 57 E 1070 N 89 36 E 1141 N 88 58 E 1211 N 89 23 E 1280 26 07 29 87 56 88 32 O0 44 3 74 3 94 4 22 5 25 0 45 1 O6 2 32 3 12 2 42 1 59 0 94 1 29 1 47 1 59 1 70 2 18 2 O1 1 49 0 87 0 60 31 98 S 131 47 E 135 31 S 76 20 E 50 S 166 62 S 207 87 S 256 05 S 307 75 S 359 52 S 412 46 S 469 63 S 529 35 39 38 34 3O 31 33 35 38 E 170 84 E 211 51E 259 85 E 309 32 E 360 29 E 413 93 E 471 67 E 530 12 S 77 57 E 58 S 79 12 E 44 S 81 23 E 73 S 83 41E 63 S 85 7 E 49 S 85 38 E 12 S 85 56 E 87 S 86 g E 38 08 S 591 62 E 592 85 S 86 19 E j.,~ECL~I~/~D~,~ 40 74 S 654 74 E 656 O0 S 86 26 E ~ 43 97 S 719 92 E 721 26 S 86 30 E ~* 47 52 57 59 57 56 55 54 73 S 786 35 S 855 85 S 926 17 S 997 63 S 1069 87 S 1139 96 S 1209 87 S 1279 63 E 788 7O E 857 08 E 927 81E 999 33 E 1070 93 E 1141 77 E 1211 38 E 1280 08 S 86 32 E 30 S 86 30 E ~{-!G 2 ~ 89 S 86,~;E 57 s 86 ,~ Oil & Gas Cons. Commission 88 S 86 55 E 35 S 87 9 E ancn0rage 06 S 87 2I E 56 S 87 33 E COMPUTATION DATE' 27-APR-93 PAGE 2 ARCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- 4-APR-1993 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3551 02 3502.02 44 28 4100 4200 430O 4400 4500 4600 4700 4800 4900 O0 3622 O0 3692 O0 3762 O0 3831 O0 3901 O0 3972 O0 4042 O0 4113 O0 4183 19 3573.19 44 41 64 3643.64 45 44 23 3713.23 45 58 84 3782.84 45 42 88 3852.88 45 20 28 3923.28 45 12 80 3993.80 45 5 40 4064.40 45 14 85 4134.85 45 21 N 89 59 E 1350 05 S 89 45 E 1420 S 89 38 E 1491 S 89 33 E 1562 S 89 32 E 1634 S 89 37 E 1705 S 89 45 E 1776 S 89 46 E 1847 S 89 54 E 1918 N 89 56 E 1989 19 O7 8O 50 8O 72 53 24 10 0 6O 0 53 0 7O 0 61 0 45 0 26 0 5O 0 3O 0 16 0 25 54 57 S 1349 12 E 1350 22 S 87 41 E 54 55 55 56 56 57 57 57 57 75 S 1419 18 S 1490 71S 1562 25 S 1633 86 S 1705 19 S 1776 49 S 1847 72 S 1918 72 S 1989 36 E 1420 34 E 1491 15 E 1563 93 E 1634 31E 1706 33 E 1777 23 E 1848 05 E 1918 O2 E 1989 42 S 87 47 E 36 S 87 53 E 14 S 87 57 E 9O S 88 2 E 26 S 88 5 E 25 S 88 9 E 13 S 88 13 E 92 S 88 17 E 86 S 88 20 E 5000 O0 4254 18 4205 18 45 18 5100 O0 4324 5200 O0 4394 5300 O0 4465 5400 O0 4536 5500 O0 4607 5600.00 4679 5700.00 4751 5800.00 4823 5900.00 4895 44 4275 97 4345 65 4416 45 4487 88 4558 72 4630 69 4702 71 4774 67 4846 44 45 25 97 44 59 65 44 54 45 44 51 88 44 8 72 43 56 69 43 56 71 43 57 67 44 3 N 89 52 E 2060 08 N 89 51E 2131 S 89 44 E 2201 S 89 31E 2272 S 89 3 E 2343 S 86 39 E 2413 S 86 25 E 2482 S 86 32 E 2552 S 86 11E 2621 S 85 56 E 2690 10 89 54 O9 O6 62 O5 42 85 0 24 0 19 0 28 0 39 0 47 0 94 0 98 0 73 0 29 0 28 57 60 S 2060 11 E 2060 92 S 88 24 E 57 57 57 58 61 65 70 74 79 42 S 2131 43 S 2202 99 S 2272 68 S 2343 57 S 2413 89 S 2482 10 S 2552 50 S 2621 3O S 2690 26 E 2132 16 E 2202 90 E 2273 52 E 2344 43 E 2414 86 E 2483 16 E 2553 4O E 2622 67 E 2691 04 S 88 27 E 91 S 88 30 E 64 S 88 32 E 25 S 88 34 E 22 S 88 32 E 74 S 88 29 E 13 S 88 26 E 46 S 88 22 E 84 S 88 19 E 6000 O0 4967 61 4918 61 43 59 6100 6200 6300 8400 6500 6600 6700 6800 6900 O0 5039 O0 5111 O0 5182 O0 5254 O0 5327 O0 5399 O0 5471 O0 5542 O0 5614 46 4990 24 5062 84 5133 78 5205 05 5278 11 5350 08 5422 89 5493 31 5565 46 44 2 24 44 15 84 44 12 78 43 47 05 43 41 11 43 54 08 44 2 89 44 11 31 44 20 S 85 45 E 2760 30 S 85 35 E 2829 S 85 19 E 2899 S 85 12 E 2969 S 85 0 E 3038 S 84 56 E 3107 S 85 5 E 3177 S 84 55 E 3246 S 84 44 E 3316 S 84 23 E 3385 84 45 23 67 74 O5 44 O0 95 0 23 0 22 0 6O 0 44 0 34 0 31 0 36 0 3O 0 26 0 35 84 36 S 2759 95 E 2761 24 S 88 15 E 89 95 100 106 112 118 124 131 137 58 S 2829 06 S 2898 89 S 2968 78 S 3037 83 S 3106 85 S 3175 96 S 3244 20 S 3313 79 S 3383 30 E 2830 72 S 88 11 E 71 E 2900 27 S 88 7 E 28 E 2969 99 S 88 3 E 49 E 3039 36 S 87 59 E 33 E 3108 38 S 87 55 E 41 E 3177 63 S 87 51 E 57 E 3246 97 S 87 48 E 88 E 3316.48 S 87 44 E 57 E 3386.38 S 87 40 E 7000.00 5686 03 5637.03 44 8 7100.00 5757 37 5708.37 44 42 7200.00 5828 52 5779.52 44 44 7300 O0 5899 37 5850.37 45 0 7400 O0 5970 04 5921.04 45 2 7500 O0 6040 82 5991.82 44 54 7600 O0 6111 71 6062.71 44 53 7700 O0 6182 65 6133.65 44 46 7800 O0 6253 79 6204.79 44 33 7900 O0 6325 08 6276.08 44 31 S 83 41E 3455 55 S 83 11 E 3525 50 S 85 1E 3595 70 S 85 2 E 3666 24 S 85 51 E 3736 96 S 87 37 E 3807 60 S 87 41E 3878 12 S 87 47 E 3948 59 S 88 4 E 4018 86 S 88 16 E 4088 96 0 55 0 69 0 92 0 75 0 59 0 76 0 75 0 41 0 54 0 36 145.05 S 3452 87 E 3455.92 S 87 36 E 153.23 S 3522 47 E 3525 80 S 87 31 E 160.23 S 3592 39 E 3595 96 S 87 27 E 166 38 S 3662 69 E 3666 47 S 87 24 E ' 172 25 S 3733 19 E 3737 16 S 87 21 E 175 94 S 3803 73 E 3807 80 S 87 21 E 178 80 S 3874 20 E 3878 33 S 87 21E ,,~:,~,/~, 181 61S 3944 64 E 3948 81 S 87 22 184 16 S 4014 87 E 4019 09 S 87 22 .... 186 36 S 4084 96 E 4089 21 S 87 23 E ARCO AGIo1 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 27-APR-93 PAGE 3 DATE OF SURVEY: 4-APR-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES hORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6396 69 6347.69 43 50 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6469 O0 6542 O0 6615 O0 6688 O0 6761 O0 6834 O0 6907 O0 6979 OO 7052 27 6420.27 43 5 36 6493.36 42 55 70 6566 70 42 39 85 6639 85 43 46 26 6712 26 43 25 O0 6785 O0 43 12 10 6858 10 42 58 71 6930 71 43 25 54 7003 54 43 5 S 88 19 E 4158.74 S 88 22 E 4227.50 S 88 18 E 4295.72 S 88 16 E 4363.67 S 89 4 E 4431.82 S 88 51 E 4500.73 S 88 41 E 4569.32 S 88 18 E 4637.53 S 87 30 E 4706.26 S 87 13 E 4774.79 0 37 0 61 0 63 0 39 0 56 0 70 0 64 0 36 0 67 0 72 188 48 S 4154 72 E 4159 O0 S 87 24 E 190 192 194 196 197 198 2O0 203 206 46 S 4223 41S 4291 48 S 4359 03 S 4427 28 S 4496 78 S 4565 56 S 4633 08 S 4702 26 S 4770 49 E 4227 70 E 4296 65 E 4363 81E 4432 77 E 4501 38 E 4569 6O E 4637 30 E 4706 76 E 4775 78 S 87 25 E O1 S 87 26 E 98 S 87 27 E 15 S 87 28 E 10 S 87 29 E 70 S 87 30 E 93 S 87 31E 68 S 87 32 E 21 S 87 31E 9000 O0 7125.58 7076.58 43 3 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7198.70 7149.70 42 59 O0 7272.19 7223 19 42 17 O0 7346.25 7297 25 42 4 O0 7420.61 7371 61 42 6 O0 7494.29 7445 29 42 23 O0 7568.30 7519 30 41 57 O0 7642.93 7593 93 41 31 O0 7718.51 7669 51 40 12 O0 7795.73 7746 73 38 48 S 86 49 E 4843 09 S 86 5 E 4911 30 S 84 46 E 4979 10 S 83 48 E 5046 23 S 82 55 E 5112 97 S 82 14 E 5180 41 S 81 14 E 5247 40 S 82 37 E 5313.70 S 81 55 E 5378.98 S 81 11E 5442.25 0 55 0 38 0 64 0 73 0 73 0 88 0 95 0 96 1 19 1 42 209.82 S 4838 96 E 4843 51 S 87 31 E 213.98 S 4907 219.40 S 4974 226 15 S 5041 233 88 S 5107 242 57 S 5174 252 19 S 5241 261 81S 5307 270 43 S 5372 279 79 S 5435 05 E 4911 65 E 4979 51E 5046 91E 5113 97 E 5180 53 E 5247 38 E 5313 29 E 5379 13 E 5442 71 S 87 30 E 48 S 87 28 E 58 S 87 26 E 27 S 87 23 E 65 S 87 19 E 59 S 87 15 E 84 S 87 11E 09 S 87 7 E 32 S 87 3 E 10000 O0 7874 08 7825 08 37 57 10100 10200 10300 lO400 10500 10600 10700 10800 10850 O0 7953 O0 8033 O0 8114 O0 8195 O0 8277 O0 8360 O0 8444 O0 8528 O0 8570 38 7904 52 7984 21 8065 29 8146 30 8228 22 8311 04 8395 56 8479 80 8521 38 37 16 52 36 10 21 36 20 29 35 16 30 34 38 22 33 28 04 32 33 56 32 20 80 32 20 S 79 56 E 5504 03 S 78 40 E 5564 S 77 17 E 5623 S 77 5 E 5681 S 77 14 E 5739 S 77 33 E 5795 S 77 42 E 5851 S 77 35 E 5904 S 77 50 E 5957 S 77 50 E 5984 43 55 74 48 92 10 94 79 21 .39 .39 .53 .30 .18 .95 .04 .83 O. O0 . O0 289.96 S 5496 43 E 5504.08 S 86 59 E 301.24 S 5556 313.71S 5614 327.02 S 5672 339.92 S 5729 352.45 S 5785 364.49 S 5839 376.18 S 5893 387.50 S 5945 393.14 S 5971 29 E 5564.45 S 86 54 E 79 E 5623.55 S 86 48 E 33 E 5681.74 S 86 42 E 43 E 5739.50 S 86 36 E 25 E 5795.98 S 86 31 E 84 E 5851.20 S 86 26 E 10 E 5905.09 S 86 21 E 39 E 5958.00 S 86 16 E 53 E 5984.46 S 86 14 E RECEIVED Aiaska Oil & Gas Cons. Commission Anchorage COMPUTATION DATE: 27-APR-93 PAGE 4 ARCO AGI-1 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 4-APR-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1OO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 999 O0 1986 O0 2832 O0 3551 O0 4254 O0 4967 O0 5686 O0 6396 O0 7125 -49.00 0 0 88 950.88 0 40 78 1937.78 19 27 53 2783.53 40 2 02 3502.02 44 28 18 4205.18 45 18 61 4918.61 43 59 03 5637.03 44 8 69 6347.69 43 50 58 7076.58 43 3 N 0 0 E S 39 6 E -2 S 84 56 E I33 S 87 3O E 655 N 89 59 E 1350 N 89 52 E 2060 S 85 45 E 2760 S 83 4I E 3455 S 88 19 E 4!58 S 86 49 E 4843 0 O0 34 07 99 05 08 3O 55 74 09 0 O0 0 92 3 74 0 94 0 60 0 0 0 0 0 24 23 55 37 55 0 O0 N 1 31 40 54 57 84 145 188 209 69 N 2 98 S 131 74 S 654 57 S 1349 6O S 2060 36 S 2759 05 S 3452 48 S 4154 82 S 4838 25 W 2 47 E 135 74 E 656 12 E 1350 11E 2O6O 95 E 2761 87 E 3455 72 E 4159 96 E 4843 0 O0 E 0 O0 N 0 0 E 81 N 53 5 W 31 S 76 20 E O0 S 86 26 E 22 S 87 41E 92 S 88 24 E 24 S 88 15 E 92 S 87 36 E O0 S 87 24 E 51 S 87 31E 10000.00 7874.08 7825.08 37 57 10850.00 8570.80 8521.80 32 20 S 79 56 E 5504,03 S 77 50 E 5984.21 1.39 0. O0 289.96 S 5496.43 E 5504.08 S 86 59 E 393.14 S 5971.53 E 5984.46 S 86 14 E Gas Cons. Anch0~'a~ COMPUTATION DATE' 27-APR-93 PAGE 5 ARCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' 4-APR-I993 KEELY BUSHINg ELEVATION. 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DE~ 0 O0 49 10 149 10 249 10 349 10 449 10 549 11 649 11 749 11 849 11 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49.00 0 0 N 0 0 E 0.00 0 13 N 64 21 W 100.00 0 12 S 12 4 E 200.00 0 17 N 71 22 E 300.00 0 17 N 26 32 E 400.00 0 20 N 58 57 W 500.00 0 16 N 89 41W 600.00 0 22 N 4 16 W 700.00 0 34 N 71 51W 800.00 0 30 S 84 23 W 0 O0 0 O0 -0 23 0 13 0 49 0 32 -0 19 -:-0 32 -0 87 -1 82 0 O0 0 O0 0 44 0 43 0 33 0 35 0 32 0 37 0 61 0 71 0 O0 N 0 O0 N 0 15 S 0 26 S 0 08 N 0 54 N 0 63 N 0 89 N 1 54 N 1 50 N 0 O0 E 0 O0 E 0 24W 0 12E 050E 0 35 E 0 16W 0 27W 0 78W 1 74 W 0 O0 N 0 0 E O0 N 0 0 E 28 S 57 16 W 29 S 23 58 E 50 N 81 9 E 65 N 33 4 E 65 N 13 57 W 93 N 16 57 W 72 N 26 53 W 30 N 49 7 W 949.12 1049.13 1049 1149.20 1149 1249,40 1249 1349 82 1349 1450 40 1449 1551 10 1549 1652 17 1649 1753 93 1749 1856 15 1849 949 O0 900 O0 O0 1000 O0 O0 1100 O0 O0 1200 O0 O0 1300 O0 O0 1400 O0 O0 1500 O0 O0 1600 O0 O0 1700 O0 1800 0 15 N 44 20 W 1 30 S 62 59 E 2 43 S 70 40 E 4 30 S 74 2 E 5 42 S 74 28 E 6 30 S 75 20 E 7 8 S 74 36 E 9 50 S 74 4 E O0 11 16 S 72 29 E O0 13 5 S 74 50 E -2 4O -1 54 2 03 8 07 16 97 27 54 39 18 53 42 71 74 92 29 0 49 1 41 1 58 1 52 1 49 0 90 0 62 1 7O 2 24 1 46 1 90 N 1 18 N 0 27 S 2 07 S 4 53 S 7 31 S 10 35 S 14 34 S 19 73 S 25 89 S 2 29W 1 48W 2 02 E 7 96 E 16 74 E 27 17 E 38 66 E 52 69 E 70 74 E 90 97 E 2 98 N 50 21W 1 89 N 51 25 W 2 04 S 82 29 E 8 23 S 75 24 E 17 35 S 74 52 E 28 14 S 74 56 E 40 02 S 75 0 E 54 61 S 74 47 E 73.44 S 74 25 E 94.59 S 74 7 E 1960 06 1949 O0 1900 O0 18 20 2066 2175 2288 2405 2522 2641 2765 2892 3021 21 2049 15 2149 88 2249 54 2349 35 2449 51 2549 41 2649 30 2749 56 2849 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 20 41 O0 25 49 O0 30 31 O0 30 57 O0 31 32 O0 35 22 O0 36 50 O0 38 38 O0 40 25 S 84 2 E S 84 2 E S84 47 E N 85 46 E N 85 13 E N 89 28 E S 88 5 E S 8746 E S 87 45 E S 87 24 E 120 14 155 68 198 74 252 70 312 11 372 09 436 82 509 94 588 02 669 91 3 . 44 3 84 4 23 4 97 0 47 1 54 2 84 2 70 1 7O 1 05 30 74 S 118 60 E 122.51 S 75 28 E 34 14 S 153 38 73 S 196 39 3O S 25O 33 81S 310 30 5O S 37O 32.45 S 435 34.79 S 508 37.89 S 586 41.36 S 668 99 E 157 73 S 77 30 E 87 E 200 88 E 253 69 E 312 96 E 372 68 E 436 79 E 509 82 E 588 64 E 669 64 S 78 52 E 94 S 81 6 E 53 S 83 47 E 21 S 85 18 E 89 S 85 44 E 98 S 86 5 E 04 S 86 18 E 92 S 86 28 E 3154 42 2949 O0 2900 O0 41 51 3291 82 3049 O0 3000 3433 42 3149 O0 3100 3576 98 3249 O0 3200 3718 29 3349 O0 3300 3857 71 3449 O0 3400 3997.17 3549 O0 3500 4137.83 3649.00 3600 4280.97 3749.00 3700 4424.SS 3849.00 3800 O0 44 22 O0 45 51 O0 45 26 O0 44 39 O0 44 11 O0 44 27 O0 45 5 O0 45 58 O0 45 38 S 86 47 E 757.37 S 85 35 E 851.57 S 88 10 E 951.79 N 88 44 E 1054.56 N 89 33 E 1154.17 N 89 4 E 1251.05 N 89 59 E 1348.07 S 89 39 e 1446.85 S 89 34 E 1549.13 S 89 30 E 1652.04 1 32 1 61 1 93 1 99 1 30 0 72 0 6o 0 6O 0 65 0 4o 45.99 S 755.98 E 757 38 S 86 31 E 51.91 S 850.00 E 851 58 S 86 30 E 58.94 S 949.98 E 951 57.97 S 1052,97 E 1054 56 77 S 1152 80 E 1154 55 27 S 1249 93 E 1251 54 57 S 1347 14 E 1348 54 90 S 1446 06 E 1447 55 60 S 1548 46 E 1549 56 40 S 1651 50 E 1652 81 S 86 27 E 57 S 86 51E 20 S 87 11E 15 S 87 28 E '~' g 993 24 S 87 41E 10 S 87 50 E'~;i~:.'~U~I& ~;C0ns. Commi 46 S 87 57 E ~"g*nc~ora-e 46 S 88 3 E COMPUTATION DATE' 27-APR-93 PAGE 6 ARCO aGI-1 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 4-APR-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG 4566 95 3949.00 3900 O0 45 14 4708 4850 4992 5134 5276 5417 5557 5696 5835 78 4049.00 4000 53 4149.00 4100 64 4249.00 4200 93 4349.00 4300 48 4449.00 4400 70 4549.00 4500 28 4649.00 4600 27 4749.00 4700 12 4849.00 4800 O0 45 4 O0 45 9 O0 45 17 O0 45 14 O0 44 57 O0 44 41 O0 44 5 O0 43 55 O0 43 54 S 89 48 E 1753.29 S 89 46 E 1853.74 N 90 0 E 1954.05 N 89 52 E 2054.86 N 89 55 E 2155.90 S 89 28 E 2255.94 S 88 35 E 2355.56 S 86 24 E 2452.93 S 86 33 E 2549.46 S 86 2 E 2645.79 0 63 0 28 0 18 0 24 0 21 0 37 0 56 0 97 0 75 0 29 57 09 S 1752 87 E 1753 79 S 88 8 E 57 57 57 57 57 58 64 69 76 51S 1853 75 S 1953 61S 2054 37 S 2156 84 S 2256 91S 2355 02 S 2453 94 S 2549 16 S 2645 45 E 1854 91E 1954 88 E 2055 11E 2156 28 E 2257 99 E 2356 23 E 2454 58 E 2550 71E 2646 34 S 88 13 E 76 S 88 18 E 69 S 88 24 E 87 S 88 29 E 02 S 88 32 E 73 S 88 34 E 07 S 88 30 E 54 S 88 26 E 81 S 88 21E 5974 14 4949 O0 4900 O0 43 58 6113 6252 6391 6530 6669 6808 6948 7088 7228 27 5049 74 5149 99 5249 39 5349 29 5449 51 5549 44 5649 23 5749 86 5849 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 550O O0 5600 O0 5700 O0 5800 O0 44 1 O0 44 17 O0 43 49 O0 43 52 O0 43 59 O0 44 14 O0 44 10 O0 44 42 O0 44 51 S 85 46 E 2742.35 S 85 34 E 2839 07 S 85 10 E 2936 S 85 2 E 3033 S 84 59 E 3128 S 84 53 E 3225 S 84 43 E 3321 S 84 I E 3419 S 83 5 E 3517 S 85 2 E 3616 25 12 76 12 92 72 24 O3 0 24 0 22 0 52 0 35 0 33 0 31 0 25 0 43 0 69 0 89 83 03 S 2742 04 E 2743 30 S 88 16 E 90 98 106 114 123 131 141 152 162 29 S 2838 11S 2935 30 S 3031 68 S 3127 06 S 3223 75 S 3319 21S 3417 25 S 3514 O0 S 3612 50 E 2839 40 E 2937 96 E 3033 27 E 3129 32 E 3225 78 E 3322 21E 3420 25 E 3517 64 E 3616 94 S 88 11E 04 S 88 5 E 82 S 88 0 E 38 S 87 54 E 66 S 87 49 E 40 S 87 44 E 12 S 87 38 E 55 S 87 31E 27 S 87 26 E 7370 21 5949 O0 5900 O0 45 6 7511 7652 7793 7933 8072 8209 8345 8483 8620 54 6049 60 6149 28 6249 52 6349 21 6449 O7 6549 3O 6649 12 6749 57 6849 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 44 52 O0 44 49 O0 44 33 O0 44 24 O0 43 17 O0 42 55 O0 42 46 O0 43 26 O0 43 5 S 85 16 E 3715 87 S 87 39 E 3815 S 87 45 E 3915 S 88 3 E 4014 S 88 16 E 4112 S 88 21E 42O8 S 88 17 E 4301 S 88 39 E 4394 S 88 55 E 4489 S 88 39 E 4583 74 21 15 43 49 89 37 14 38 0 62 0 76 0 68 0 55 0 31 0 56 0 63 0 34 0 68 0 59 170.61 S 3712 17 E 3716 08 S 87 22 E 176.28 S 3811 180.30 S 3911 184 O1S 4010 187 08 S 4108 189 92 S 4204 192 6O S 4297 195 32 S 4390 197 05 S 4485 199 11S 4579 87 E 3815 28 E 3915 16 E 4014 42 E 4112 48 E 4208 87 E 4302 35 E 4394 17 E 4489 44 E 4583 94 S 87 21E 43 S 87 22 E 38 S 87 22 E 68 S 87 24 E 76 S 87 25 E 19 S 87 26 E 69 S 87 27 E 49 S 87 29 E 77 S 87 31E 8757 64 6949 O0 6900.00 43 40 8895 9032 9168 93O3 9438 9573 9708 9839 9968 15 7049 03 7149 56 7249 71 7349 46 7449 99 7549 11 7649 73 7749 11 7849 O0 7000.00 43 5 O0 7100.00 43 0 O0 7200.00 42 37 O0 7300.00 42 4 O0 7400.00 42 42 O0 7500.00 42 15 O0 7600.00 41 26 O0 7700.00 39 34 O0 7800.00 38 21 S 87 51E 4677 09 S 87 14 E 4771 48 S 86 38 E 4864 94 S 85 10 E 4957 89 S 83 46 E 5048 71 S 82 42 E 5138 S 81 34 E 5230 S 82 43 E 5319 S 81 37 E 5404 S 80 20 E 5484 86 03 05 37 46 0 49 0 72 0 42 0 52 0 73 0 83 0 91 0 97 1 33 1 39 201.88 S 4673 15 E 4677 51 S 87 32 E 206.11S 4767 211.07 S 486O 217.53 S 4953 226.42 S 5043 237.13 S 5133 249.58 S 5224 262.50 S 5312 274.08 S 5397 286.58 S 5477 45 E 4771 78 E 4865 51E 4958 98 E 5O49 66 E 5139 28 E 5230 71E 5319 50 E 5404 O2 E 5484 9O S 87 31E 36 S 87 31E 29 S 87 29 E 06 S 87 26 E 13 S 87 21E 24 S 87 16 E 19 S 87 10 E 46 S 87 6 E 51 S 87 0 E COMPUTATION DATE: 27-APR-g3 PAGE 7 ARCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: 4-APR-19g3 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 10094 50 7949 O0 7900 O0 37 12 10219 14 8049 O0 8000 O0 35 54 10343 06 8149 O0 8100 O0 35 56 10465 57 8249 O0 8200 O0 34 45 10586 55 8349 O0 8300 O0 33 32 10705 88 8449 O0 8400 O0 32 31 10824 20 8549 O0 8500 O0 32 20 10850 O0 8570 80 8521 80 32 20 S 78 45 E 5561 14 S 77 1E 5634 64 S 77 22 E 5706 77 S 77 24 E 5776 57 S 77 37 E 5843 77 S 77 36 E 5908 06 S 77 50 E 5970 57 S 77 50 E 598~ 21 1 39 1 53 1 33 1 07 1 05 0 83 0 O0 0 O0 300 59 S 5553 03 E 5561 16 S 86 54 E 316 22 S 5625 76 E 5634 64 S 86 47 E 332 63 S 5697 07 E 5706 77 S 86 40 E 348 21 S 5766 10 E 5776 61 S 86 33 E 362 90 S 5832 58 E 5843 86 S 86 26 E 376 86 S 5896 18 E 5908 21 S 86 21E 390 23 S 5958 04 E 5970 81 S 86 15 E 393 14 S 5971 53 E 5984 46 S 86 14 E R E E IV E rj AU G 2 6 Alaska Oil & Gas Coi~s. Anchorage ArCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER GCT LAST READZNG TD COMPUTATION DATE: 27-APR-93 PAGE 8 DATE OF SURVEY: 4-APR-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1583' FSL A 2390' FEE, SEC26 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10750.00 8486.22 8437.22 381.90 S 5919.33 E 10850.00 8570.80 8521.80 393.14 S 5971.53 E -'Alaska Oil & Gas Cons. Comrnissicl~ Anchorage ARCO AGI-1 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 2?-APR-93 PAGE 9 DATE OF SURVEY: 4-APR-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1583' FSL & 2390' FEE, SEC26 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10850.00 8570.80 8521.80 393.14 S 5971.53 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10850.00 8570.80 8521.80 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 5984.46 S 86 14 E DIRECTIONAL SURVEY COMPANY ARCO FIELD PRUDHOE BAY WELL AGI-1 COUNTRY USA RUN I DATE LOGGED ;4 - APR - 93 DEPTH UNIT FEET REFERENCE 93186 All interpretatfons are opinions based on Inferences from electrical or other measurements and we cannot, and do not .......... guarantee the accuracy or correctness of any Interpretations. and we shall not. except In the case of gross or wlffull negligence on our part. be liable or responsible for any Toss. costs, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These Interpretations are also subject to our General Terms and Conditions as set out in our current price Schedule. _ WELL' AGI-1 (1583' FSL, 2390' FEL, SEC 26, T12N, R14E) HORIZONTAL PROJECTION NOI=ITH 4000 REF 9~ee SCALE: I / 1000 IN/FT 3000 ,: : :::: :::. :::: -::: :::: :::: :::: ::;: :: : :::: :: :: : :::. , .: .... : . , . . , - i i .~.i i.~ .... i '..~..i ...... ~..~ i i..i.i i .i..i ~.i i ,..i i .i i ~ ~ .i . ~ ~ ~ ~ ~.;...i..i ,. i.. i i : . i ........ ~ , , . . . .. .: ,. : : :: ::.: :: : :::. :.: :.: :: ..: .. ................... ....................... : . . : .......................................... ..................... ~-~ 7000 .~ ...... · ~ : .::: i:.: ::.: :.:: ::. :::~ .:.: .::: .~:' :!: ~... i~i:. ~.i; i2:i.liLi i.~i. i;il i.:; ;.;; .22 .... i .:;: i! ...... : · :-:: :: : ::.: :::: :: : ..:: i-;~i~---i-~---i--{ ...... L-~--i--i--.~--~-~---i-.I-i--i-.-i---;-.i---i--.i---i .... i--i-..i---i---i-i--.i.--i. -;-~..;~i-~:; ......;-~.-.~-~ ;~ .......... : ::: :i.: :-:: i~i! i:~ :ii. ::ii i :!Z; ~ ~;ii :!.: !,.. :11-4. ~.~-: ~4;:-,-:-.:.~.: .......... :. :..: ...... : ....... ' : : ; : ., ,.i i .... i.z ,..z.i.i z i. ;..s.i i !..i ~ i .; i.~.: ~.: i z i : i. .:.: ; : : : !., , . :.: : : : : . ' . . . -1000 .... · .:ii [i!! ~['~ !:![~ ~' ~ : ' ': ............... ! ................ ~ i i i ~ ...... ~ !.i... i ! ! i~i i ! i i ! ! i.~ ...... ~ : : ..... ! : . -~:' :::: :::. :.~ ............................. : i i i i .....h-i..i i-.i i .i.i ;...i...i i-~ i i i-;.i .;.i..i i .i i.i i .., ~ i ............ ; . i ...... :. :..: :.:..:: :..: :.:: ,::..:. , ;ili .......................................................... iZ~ '' :.:: .............. ::: ........ .: .: : · : . : : : ........ : . . . · . : i!!- !!-i-! i-!-i--i-- ii-ii ~iii iii-i ~i~: :iii i~;-.~;: :~:.: . ....... ::: .- i ~i .... i!:~ i~. Z;i: ;;.~ : .... ' ..... --: i !:': i~:: i:!' ~!!' ~':! :! : · ': i;.- !!: ~ : i;, ; .... ......... ! , i ....... ....................................... '' '':: -1000 0 1000 2000 3000 4000 5000 6000 WEST Al~ka Oil a Gas Cons. Cornmissio~ hnehora~e 70O0 EAST WELL' AGI-1 (1583' FSL, 2390' FEL, SEC 26, T12N, R14E) VERTICAL PROJECTION 273.00 -1000 0 0 1000 2000 3000 4000 5000 6000 7OOO ).00 PROJECTION ON VERTICAL PLANE 273.00 93.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 1000 IN/FT Alask~ Oil & Gas Oons. Oornmissio¢ COMPLETION DATE }1. ! ~cl i~ CO. CONTACT 'cheCk off Or list data as it is receive~l.*liSt received datc for 401. if not required list as NFl 41}7 !* )[Z_..~i~drillin~histo~ _V_. survey! ! ! welltests ~lcorcde~cript~o~e- cored intcrval~ core analysis~0~- dry' ditch intervals di~lital data j~:~ ' , , ~q1~L ~ , iii i i LOG TYpE RUN INTERVALS SCALE , NO. po the nearest foo, tJ[inchll00') i 9) ~<~~ v i ii) i i i i i i i31 ~ i i4) ._ i6) i i i I I I I I II I I I ARCO Alash, P.O.Box 100360 Anchorqe, Alash O9510 DAT~ 13-18-03 Al/CO CA~ED HOLE PINALS 1-SST ?o .~/o 10-11-02 2-S ?~- ~-o10-23-02 3.20 ~/o/ 11-7-02 ~3.33 l~O-O2 ~3.30 11-12-03 1~3.02 ¢3.33 ~/~//~ ~3.33 10-18-92 4-308T 11-8-03 4-30 ¢/- ~?, 1~o-02 4-40 ~/-//? lO-11-o2 ~-~ s-o 10-2~02 7-~-~ ~ 8-0-0~ L28 ~ ~-~ 0-24-02 ~-~/~ [0~20 a-28-02 L20 2-28-02 11-3A ?/-/~- ll-I 1-02 ~/-/~ 12-8B . 10-13-02 12-20 ~~1~4-02 1~2 1~8-o2 ~ - ~ 14~1 10-3~02 1~12 ~/-~ 10-2L02 1~14 ~/~ 10-22-02 1~2~-~/~ 10-22-02 ~ _ ~ ~1~0 0-27~2 ~3o Ia-IL02 17-18 ?~-?/~ lO~O-O2 Leak Detect (flezstak~ Run 1, ~'&10' Perf Record Run 1, ~ Perf Record Run 1, F Collar (IBP) Run 1, F InJ Profile (Step hte) Run 1. ~ Leak Detect(flexotak) Run 1, F Collar (IBP) Run 1. ~ GR/ColIar Run 1,6' Prod Profile Run 1, ~' Collar (IBP) Run 1, ~ Prod Profile Run 1. F Perf Record Run 1, ~ Prod Profile itun 1, F InJ Profile/PITS/Collar Run 1, F Prod Profile Run 1. S' Perf Record Run 1, ~ Perf Record Run 1, ~' PITS Run 1, ~' Perf Record Run 1, ~' Perf Re~or~ Rum !. ~' PSG/GR (Computed ReoulteJ Run 1, ~' PSG/GR ~/ Run 1, F Leak Detect (flexstek) Run 1, ~ Set IBP Run 1, ~ Perf Record Run 1, ~ Collar Run 1, S' Perf Record Run 1, ~ InJ Profile/PITS ~ Run 1, ~' Perf Record ~ Run 1, ~ Prod Profile (flmtak) Run 1, ~' Perf Record Run 1, ~' Perf Record Run 1, ~' Perf Record / Run 1, ~' Prod Profile (flexstak) ~ Run 1, ~' InJ Profile/Temp/ Run 1. ~' Perf Recird ~ Run 1, ~' GR/Collar / Run 1. ~ 8BL/GR/CCL ~' Run 1. ~' Ple~e ~ and return the attached copy as receipt of data. Have A Nice Dayt Sonya Wallace ATO-1529 RECEIVED DEC ~ O 1992 # MOBIL . Camco HI,8 HL8 Camco Camco Camco Camco Camco Camco Camco Camco HIS Camco Camco Camco Camco HIS HIS Camco HIS HIS HIS HIS HIS Camco Camco HIS Camco HIS Camco HIS Camco HIS HIS HIS Camco Camco HIS Camco Atlaa ARCO Alaska,, Inc. P.O.,Box 1~ Anchorage, Alaska 99510 DATE: 12-18-92 REFERENCE: ARCO OPEN HOLE FINALS ('14-23A )14-Z~A ,17-21 17-21 17-21 17-al. 17-31~ 17-~1' .17-111./ '18-22 18-33 18-22 ~-~ 18-2~ AGI-1 AGI-1 12-6-93 8STVD 13-6-93 DLL/MIA,/GR 12-6-92 BHCA/GR 13-6-93 CNL/GR 13-6-92 BH Profile 11/3~13/1/92 DPa/aa 11/30-12/1/92 Den Poro/GR 11/30-12/1/9:i DPR/Den P~ro/GR 11/30-12/1/93 Bulk Density/GR 11130.1211192 DPR/~a 11/30.12/1/92 Den Poro/G_~_~ 11/30-12/1/92 DPR/~_~.~ro/GR UWD: I~R/EWR/FX~ MWD: DGRfNear-Far Ave. MWD: DC~R/CNP/DSPD/Cal MWD: DGR~Near-Far Ave. UWD: D~a/¢~P/Da~/C~I DPR/GR DPR/GR Run 1. l"&~r' Atlas Run 1.3"&5' Atlas Run 1.3"&5' Atlas Run 1.3"&5' Atlas Run 1. ~" Atlas Run 8, 2"&~D Teleco Run 8, 3"&~D Teleco Run 8, 3*'&i~'MD Teleco Run 8, 5'~MD Teleco Run 8, :F'&5"FVD Teleco Run 8, 2"&5"rVD Teleco Run 8, 3"&5'TVD Teleco Runs 7-14, 3~'&5"MD Sperry R~n- 7-14, 5"MD Sperry R~nl 7-14. :r'&5"MD 8perry Ru,~l 7-14, 3~'&5'~I'VD Sperry Runm 7-14. 5~'TVD Sperry Runs 7-14, ~'&5'~l~D Sperry Run 5, 2"&~MD Teleco Run 5, 3~'&5"I'v'D Teleco Please sign and return the attached copy a~ receipt of data. RECEIVED BY ~-~ ~-J--~-~~--ff~7 Have A Nice Day~ AT0-1529 Alaska ~ Trans 9 69~ --- # CENTRAL FH.F~ # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # # PB WELL ~ R&D #BPX # STATE OF ALASKA #TEXACO ARCO ~ Inc. P.O.Box 100360 Anchorage, ~ 99510 DATE: 13-18-92 ARCO OPEN HOLE FINALS Atlas Aths Atl~ Teleco Teleco Atlss Atlas Aths Atl~ Atl~ Atlss Atl~ Atlas Please sign and return the attached copy as receipt RECEIVED BY Have A Nice Dayl ATO-1529 DEC 3 0 1992 Alaska 011 & Gas Cons. Commission Anchorage # CI~VRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL RECEIVED APPROVED__~ Trans# 92268" # PHILliPS # PB WELL FILES R&D # BPX # STATE OF ~KA #TEXACO ARCO Ahsk~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-21-92 REFERENCE: ARCO MAGNETIC TAPE{S) WITH LISTINGS DLLi~CI~ICm ~ ~ DIFLI4-Ann CallG~ ]~m 1 DIFLICN-ZDLIGR ~am I Job~5776 Job~5~ Job~5~ Please sign and return the attached copy as receipt of dat~ RECEIVED BY Have A Nice Dayl Sonya Wallace AT0-1~29 RECEIVED DEC; ~ 0 199~ Alaska Oil & G~s Cons. Commission Anchorage CENTRAL FILES (CH) CHEVRON D&M # BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL # PHHJAPS PB WELL FILES R&D #BPX # STATE OF ALASKA TEXACO At~ Atlas Atla~ MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: Leigh Griffin date: Commissioner file: Wondzell(~~' thru: Blair E ~[~¢.~ subject: Sr Petr Engineer from: ~ou Grimaldi Petr Inspector November 24, 1992 ., LOU111992.DOC Rig BOPE Inspection Audi Rig #2 ARCO Well #AGI-1 PTD 92-0124 Thursday, November 19, 1992: I made a Rig/BOPE Inspection on Audi Rig #2 drilling well #AGI-1 for the gas handling expansion project in the Prudhoe Bay Unit. Audi 2, although old, is a well maintained rig. I found all BOP Equipment to be in place and apparently in good operating condition. Gene Cooper (ARCO Representative) was cordial and seems genuinely appreciative of the inspectors'visits. Although the pad is quite narrow and AUDI 2 is a large rig, it is situated well and provides good access for support equipment. The area surrounding the rig was kept clean and orderly and appears to have as much priority as any other phase of the drilling program. SUMMARY: The Rig/BOPE inspection I made on AUDI-2 revealed all to be in compliance. Attachment 1.() 2.() $.() ~.() ~' S.() " 6.() .f ?.() !' ~ '"11. ~() '' i' 1~. 15. 16. (~ 8. (~~~ () 9. () lo. ( ) () () () () () () () () () () 2~. (~k). () 22. (~;L ( ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C0MMI,,,.,ON · Wkvr U I C_._/,~ .~./ DATE;. , //"- Well name Representatt ye_ , _L~/~x.~' /~/~":G ~ ~£ "7-:-' 25. (~'/~ () .2~. C,~' ( ) -: :. 25. ~'~ () .,. , 26.~:~ ( ) 27. ( ) 28.~q () 29. (~/ () 3o.(~ () , 3~.~', () c) ~. ~,. ?' RE3qARKSz ( ) (~ line sz & length ( ) ~ line corm & anchored ( ) bifurcated & dwn wind ( ) ~C~ gOe target;ed turns ( ) ()~ vlvs= auto & simultaneous ( ) ~ annular pack-off ( ) ('/~ condition B, BOP STAC~ ( ) wellhead flg wkg p~e~s ( ) stack wkg press ( ) annular preventer ( ) ptpe rams ( ) bltnd r~ma ( ) stack anchored ( ) chke/kt11 11ne az ( ) 90° turns targeted (ohke & kill ln) ( ) HCR vlvs (ch~e & kill) ( ) manual vlvs (chke & kt11) ( ) connections (flgd~ ~hd~ ¢lmpd) ( ) dr1 ap~ol ( ) fl o~ nipple ( ) flm~ monttor' ( )"control 11nas fi re prote~ted C. CLOSING U~ITS ( ) wkg press ( ) flutd level ( ) oprtg press ' ( ) press gauges ( ) aufftctent vlvs ( ) regulator bypasa ( ) ~-way vlvs (actuators) ( ) blind handle cover ( ) drtller control panel ( ) remote control panel IN C0NPL I ANCE ~ .' ~f~.~. n~o n/a )s. ~.. () 36'i~' () )7. ( ) 38. ( ) 39.(~ () ~o. (,~(1 ~+l. ( ) ~2. ()a' ( ) ~3.(~ () 45: ' ' ( ) ,~..A. ic~ () ~7.~ ( ) ~8. (~ ( ) fi rewal 1 nitrogen power source (back-up ( ) condition (leaks, hoses, etc) O. MUD SYSTEM ( ) pit level floats installed ( ) flow rate sensors ( ) mud gas separator ( ) degasser ( ) separator bypass ( ) gas sensor ( ) chke I n conn ( ) trip tank E. RIG; FLOOR ( ) kelly cocks (upper,lower,lBOP) ( ) floor vlvs (dart vlv, ball vlv) ( ) kelly & floor vlv ~renches ( ) driller's console (flo~ flow rate indicator, pit lev, indicators, gauges) ( ) kill sheet up-to-date ~9. k) ( ) ( ) gas ~etectton monitors (H-S & methane) 50, (~4 ( ) ( ) hydr chke panel S1,~ ( ) ( ) chke manifold F. MiSt EQUIPMENT 52. '(/k~ ( ) ( ) flare/vent line $3,(~---~ ( ) ( ) 900 turns targeted (dwn strm choke lns) ~4. ( ) ( ) '~K~'~ reserve pit tankage 55. ~ ( ) ( ) personnel protective equip ava 56. ~C)y ( ) ( ) all drl site suprvs trained for procedures 57, ~ ( ) ( ) H2S probes 58. ~ ( ) ( ) rig housekeepih9 RECORDS= i Date of la&t BOP inspection: ,~" ? ~ Reaulting non-compllance~ Non-compliances not corrected Date of last; BOP test:: /'/Z_... /,/ -.. ~ ';.' Date corrections will be completed: ~ BOP test & results properly entered on daily record/. ,//~. Kill sheet current? / - WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 10, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit AGI-1 ARCO Alaska, Inc. Permit No. 92-124 Sur. Loc 1583'NSL, 2390'WEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 4044'FNL, l149'FEL, Sec. 31, T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested, in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by Contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION CL~t,,1MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of" work Drill [] Redrill l"]llb. Type of well. Exploratoryl"] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-iI Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool _ARCO, A/as.k. a, /nc. KBE = 49feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 34628 4. Location of well at surf-aCe 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1583' NSL, 2390' WEL, SEC. 36, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1250' FSL, 1390' FEL, SEC 31, T12N, R15E AGI-1 U-630610 At total depth 9. Approximate spud date Amount 4044' FNL, 1149' FEL, SEC 31, T12N, R15E 11/10/92 $200,000.00 1~. Distance to nearest 13. Distance to nearest well 4. NUmber of acres in property15. Proposed depth (MD and TVD) property line 1149 feet LGI-08: 217'@ 6900'MD feet 2560 10910'MD/8566' TVD[eet 16. To be c'~)mpleted for deviated wells !17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooofeet Maximum hole angle 44 o Maximum surface 2993pang At total depth (TVD) ~,~66/3850pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" Cond. H-40 Weld 80' Surface Surface 110' 110' 320 sx Coldset ~ 13-3/8" 68# L-80 BTC Surface Surface 3905' 3500' 973 sx PF "E"/400 sx Class "G" .. 12-1/4" 9-5/8" 47# NTSO-S NSCC 102~~' Surface Surface 10278' 8109' 31~sx Class "G" 8-1/2" 7" 29# L-80 NSCC 782" 10128'i 8001' 10910' 8566' 108 sx Class 'G" - / ~'~. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface · IntermediateN 0V "9 1992 Production Liner Ala~ ~JJ ~ 6a$ C. orl$, Perforation depth' measured .......... .~'~__~_ra~~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling] fluid program [] Time y~ depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify t,,hat t_.b.e f~regoing is true and correct to, the best of my knowledge ~ .~... Commission Use Only Permit Number ~-IAPI number IApproval date ... ISee cover letter ?.z.-/.2_. ~ I~0- o~. ~ - ~. z. ~,~ ? I ~/-' / ~ ~'~'.-9-~1~°' oth,~ r,~q~ir~,m~,~t~ Condrtions of a~droval Samples req_uir?d [] Y~ ..~rr~ Mud tog required []Yes'-' J~'No Hydrogen sulfide measures [] Yes .,~E~' No Directional, survey requ~re~ ~ Yes [] No Required working pressure for BOPI~ []2M; r-13M; ,J~5M; I-i1OM; I-I15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: APEX GAS INJECTOR # 1 (AGI #1) LOCATION: Surface: Target: T.D.: 1583' FSL, 2390' FEL, Sec. 36, T12N, R14E 1 250' FSL, 1390' FEL, Sec. 31, T12N, R15E 177' FNL, 788' FEL, Sec. 34, T12N, R1 2E ESTIMATED START: 9 NOV92 OPR. DAYS TO COMPLETE: 26 (20 days drilling, 6 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 44 deg/S86.76E/1 O00'/2.O/6128' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(BKB) Mud Wt, 20" CONDUCTOR 80 80 8.5 1 S-3/8"'SHOE 3500 3905 9.0 9-5/8" SHOE 8109 10278 TOP SADLEROCHIT 8114 10285 9.2-10.0 7" SHOE 8566 10910 9.2-10.0 TARGET 8315 10563 9.2-10.0 TOTAL DEPTH 8566 10910 9.2-10.0 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top Btm 30" 20" 91.5# H-40 WELD 80 32 11 2 1 6" 13-3/8" 68# L-80 BTC 3874 31 3905 1 2-1/4" 9-5/8" 47# L-80 NSCC 10248 30 10278 8-1/2" 7" 26# L-80 NSCC 782 10128 10910 COMPLETION: Tubing: 7" GLMs: None Packer: Baker LOGGING PROGRAM: Open Hole- Cased Hole 26# 9-5/8" L-80 NSCC 10231 29 10315 x 6" BORE Baker set at 10068 or +/- 50' above Top of liner _ RECEIVED 9-7/8" Hole: None 6-3/4" Hole: DIL/CNL/GR/SP/SDT CBT/CET IN 7" AND 9-5/8" before running tubing NOV - 9 1992_ Alaska 0il & Gas Cons. (:;ommissio~ Anchorage; APEX GAS INJECTOR #1 (AGI #1 ) DRILLING DISCUSSION AGI #1 is the first of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the. additional gas injection requirements associated with the GHX-2 project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the lvishak sand injection interval (target interv~-:.l) comprised of Zones 1, 2, 3, and partially truncated Zone 4. lvishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2_" tailpipe will be the completion assembly. This assembly will be run with a completion rig after the drilling has moved off the well. ANNULAR INJECTION There are no annuli available for injection on this pad at present. Fluids can be injected at the central CC-2 injection facility. AOC-,SC has informed Prudhoe Bay Drilling that only associated fluids from drillin9 operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. FREEZE PROTECTION The 7" tubing along with the 7"x 9-5/8" annulus will be freeze p;-otected with diesel before the drilling rig moves off the well. CLOSE APPROACHES There are no wells within 200' of the planned wellbore trajectory of AGI #1. The closest well is LGI-08 which comes within 217' at 6900' md. PROPOSED DRILLING AND COMPLETION AG! #1 Procedure PROGRAM · . · . . · o , o 10. 11. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: Notes: MIRU drilling rig. N/U diverter and function test same. Drill 16" hole to surface casing point. Run and cement surface casing. test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. leak off test. Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. Bump cementing plug with mud. RIH and drill 8-1/2" hole through reservoir to TD. RU and run e-line logs. MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. MU casing scraper & clean out 7" liner. Run 7", L-80 and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. NU tree and test to 5000 psi. Release drilling rig. 3850 psi @ 8800' TVD SS 2970 psi 9.8 ppg filtered brine Nipple up BOPE and function Drill 10' of new hole and perform The drilling fluid program and surface system will conform to the regulations set fodh in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. No potential productive zones are anticipated above 8125' TVD (9-5/8" casing shoe). d. No potential hazardous levels of H2S are anticipated in this well. R CE V .D N 0V - 9 &lask~ 0il .& Gas Cons. CEIVi PROGRAM - HALLIBU,-.FON SERVICES 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 1329 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD:l.16 fta/sx APPROX #SACKS: 400 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 _TOP JOB.....CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps FW APPROX #SACKS: 250 PUMP TIME: 2:30 hrs Mix water temp: 50-65 -. SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50~65F CEMENT VOLUME 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. 9 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER' 5.00 gps FW APPROX #SACKS-:.iI~'3~8~'~PUMP TIME: 4 hrs Mix water temp- 70-80 F SPACERS: Pump 20 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix tail slurry. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show. 2. Tail Slurry to 1000' MD above shoe w/30% excess. RECEIVED 7", 26# 140° F 7" LINER _CASING SIZE: CIRC. TEMP: CEME Nov -- 9 !992 Alaska. 0ii & 6as Cons. 60mrEIss~-B NT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant)+0.4% HR-5(Retarder)+0.3% Econolite (extender) + 0.4% HALAD 344 (Fluid Loss) + 2% KCI (Clay control) + 4-0.01% D-AIR-3 (defoamer)+0.9% LAP-1 (Fluid Loss) +0.1 gps Stabilizer 434B. WEIGHT: 15.7ppg YIELD-1.20 ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 150 PUMP TIME: 3:30 hrs + 1 hr mixing @surface FLUID LOSS: 150 cc Mix water temp: 70-80 F PREFLUSH: 20bblsARCOpreflush+2% KCL SPACER: 50 bbls ARCO spacer + 2% KCL, weighted to 11 ppg OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (8 1/2" X 7") annulus + 40% excess. 2. 7" 26# casing capacity below landing collar (80 feet). 3. 150' liner lap (9 5/8" x 7" liner) 4. 100' of cement on top of the liner in the 9 5/8" casing (without DP in hole). ith International, Inc. Proposal Report Medical Sectfon P~ane: 93.24 deg, erie ~'(rtd 6e~inat~: tat. 73.~.52.57 N - L~. 148.27.5P.00 V er~e (RiD S'¢t~: AL~a Slate ~[~m 2c~: ALaska ~ erie (RID C~rd~at~: (f~t): 59~22~.7Z ~ ~,&5 E %~eLtpath ]5: A~I-C, II~P ,, LDst Revi .~i on'. cboe l~a¥ Dritlir~ L: e: AG[ -011,~ Course Stlc~e~ T 0 ~ A L lit) 1~0.00 O.OO $51.00 O.Cx3 { O. O0 1199.84 1~0.00 1150.84 0.~0 ~ 1~.45 1~0.00 12~.45 0.~ $ 15.&7 1398.~ lOO.~ 1349.~ 1.~ ~ 27.84 1497,47 lOG.Q0 14~.~T 2.~ S 1595.~ ICG.~ 15~.6~ 3.55 S 62.50 16~.~ tC~.~ 1~.'~ 4.82 5 1~9.~ ~<G.~ 17~-~ 6.25 S 110.~ 1~5.27 ~(~.~ 1~.2~ 7.~ g 1~9.~ ~.17 !C0.~ 2024.1T 11.&t 2~5.84 100.~ 22~.~ ~.~I s 234&.g& 100.~ 2295.9~ ~_~ S 2~.39 lO0.~ 23~.59 21.~ S 2~.28 l~O.~ 2~4.~ 30.97 2~1,45 10~.~ 27~.~5 37.~ S ~,16 Z916.~ 1'GO.OD Z~.7.gZ 41.65 S ~,66 297~,44 ~.gl ~29.4~ 44.~ S ~.62 5Z67,74 I~,GO 3218.74 ~.~ s 1~7.42 E 5gr~9223.7~.. 686'9Q1, ~5 0.00 8 E 59~222.35 6~,95 4~.52 8 93.2~ E ~221.05 ~.~0 ~5.10 O E 59~2'19.51 ~9~,1.59 140.21 8 E S~215.~ ~9149. a0 247.6r a 93.2~ E 59~214.61 689191.2~ 2&9.93 ~ 9~.2~ [ S~qO,OS ~.53 435.~1 u ~ 59~,55 ~94~,29 547.13 a 93.2~ E 5,9T~,~ ~5~.~4 607.~ O E 5P'~202.6~ ~9571,~4 670.~ a 93.2% t" 5PF~I~d.dP ~97~2.~ ~1.~ 8 93.24 E 59~194,52 ~9~1.98 931.0t ~ 93.24 E E 597'Slli9'2.3~ 6'B~;GI.OO IO0~.OF ~ 93.:Z~ ~akk 3utld Vertical Ra~¢ Rate ~ect~on (~10,3{c) (c%q/lOOlt) cfr) (d~/lOOft) O,~3Q 2.~ 1.2'5 2.~ O,OO 2.~ 15.69 0.00 2.~ 27.~ O.OO 2.~ 43.52 0,~0 2.~ ~.!~ 0.00 2.~ 110.~ ~.(Q 0.00 2.~ 1~0.21 ~.(~ ' O.QO 2.~ 172.~ . 0,~0 2.~ 247.67 2.(~ 0.00 2.~ 335.~ 0,00 2.~ 2~.81 ~,(O ' 0.~0 ~.~ ~5.31 ~,(O O.O0 2.~ ~9.~ O.O0 ~.~ 470.~ 0,00 2,~ ~'5.&~ 0,00 .2.C0 ~.~ Z.CO 0.00 0.~ ~1.~ O.CO O. O0 O.~ 931.01 O.CO O. O0 0.~ ~e69.1~ -nith International, Inc. Proposal Repor~ Page 2. O&[e: 1 lj6/92 ID: RG:-01~ S6~.91 43.6~ 93.24 :~34D.06 100.110 ~2:9T.06 · 64.43 S It36.57 E 592"918.8.U4 45'~,039.05 37~%:'~.91 43.68 93.24 ~12.3S I~0.00 3.L5_~.~8 6...~.~..~ S 1~05.32 E 5979185.[::J~ 6S"C1C~:L08 12t~?.Z5 4~,91 ~.~ ~.2~ 3~1-67 1~.00 ~2.6~ 8].9T S li&l.12 E 59~1~.~ 6~(,~II8 14~.50 *' ~.~ ~.2~ 3846_~Z 1~.00 ~7.~2 91.~ s 1619.02 E ~9~1~.~ 6~.Z~ 1~I.&2 4~.91 43.~ 93.~ 42~.25 1~.~ ~l.2& 115.25 S ~23Z.~ E S9~0.~ 5~.91 43.~ 93.2~ 43~.55 1~.~ 4~$.56 11P.16 $ 2101,67 E 59~157.EF 691~,41 51~.91 ~.~ 93.~ 4424.~ 1~.~ ~.~ 12~.06 S ~170,6~ E 59~155.~ 5~.91 ~.~ 93.~ 45~.55 t~.~ 4520.55 ~3D.~ $ Z~.52 E 59~1~1.4~ 5~.91 43.~ ~,~ 4~1.~ 1~.'~ 4~.87 134.~ $ 2577,z7 E 5979149.27 691~.51 S5~.91 ~.~ 93.~ 4714.20 1~.')3 ~5.ZO 138.~ S 2~6,z2 E 59~147.1~ 491~0.5~ 2~0.35 5~.91 43.~ ~,~ 47~.5Z 1~.~2 4~7.5Z 142.61 ~ 2515,37 E 5~144.~ ~91419.56 2519.~1 5~.91 43.~ g3.~ 50~.49 1~.~ 495~.~9 15~.3~ S 2ZZZ.2~ E 5~138.5~ ~91~.~ . ~,, 43.~ 93.24 5292.~ 1~0.~ 52~3.~ ~9,9~ S ~8,0~ E 59~129.9T ~,91 43.~ 93,24 5365.10 1QO.0~ 5~16.1~ 1~ S 3~,9~ E 5P~1~7,~ 6~1971~ 3071,89 ~.91 43,~ 93.24 5~37.43 100.~ 53~.~3 1~.7'¢ S 3135.9Z E 5';~125.~ 692~0.~ 3140.~ ~,91 ~.~ 93.~4 55~9.~ 1~0.00 5~.~ 181.~ S 320~.67 E 59~12~.5~ 6~,91 43.~ ~3.24 55~.07 1QO.O0 55~.0T 1~.61 ~ 32~.82 E 59~121.40 ~,91 ~.~ 93.2~ 5~6.~ 1QO.O0 56~.~ 1~.~5 3 3~11.72 E 59~117.1~ 6~316.89 341~.Z0 ~,~l z].~ ~.2~ 6016.01 1G~.~ 5~7.01 2~.3~ ~ ~T. SZ E 59~1~8.5~ 7~.91 ~3.~ 9~.24 6~.~ ICQ.~ ~9.~ 212.~ S ~6.~ E 59~1C6.4~ 692~.02 37~.50 75~.91 z3.~ 9].24 6160,~ I(G,~ 6111.&5 2t6.~ g ~5,~Z T 5~91C4,31 O.CO 1138.19 O,qO O.CO 1267,2S 0,00 O.OO !276.3} C.O] ~290.9~ O.C~ 0.00 . t414.4~ 0.(0 e. DO .'.552.5& O. CO O.DO Q.IX) :759.7~ O.O0 2105.04 2174.10 mith lnterna[ional, Inc- Proposal Report ~ttl~th I,): ~.6I-Dtv~ O~¢th ~ir, Lenath 'bcpth i~ctm~jut&r O{~sets ~r[.5[~ East~ ~[sl. Dir, [ate ~ate S~t~ ~.~ ~3.~ 93.24 ~65,30 I00.~ 6256.30 2Z~.70 S 3~3.~ E 5~1~0.64 ~9,1d ~9.~ ~ 93.24 7~.~ 43.~ 9I,Z4 ~.62 Ioo. Oa gZ8.~ ~28.61 s ~2.27 E 5~7.~ ~9~,13 ~8.74 ~ 9~.24 ~.9J 43.~ 93,24 ~49,~ lO0.OO ~0~.~5 ~32.52 S 4t01.~ E 5~P5.~ ~3007,15 ~lOT.~ ~ 93,24 ~.~ 8083.9~ 4~.~ 93.24 652Z.27 1~O.gO ~.~7' ~36.43 S' 41~.17 E 5g~.~ ~30T6.1g C176.~6 ~ ~.2~ 82~.9J 43,~8 93,2Z ~.92 ~OO.OD ~17.S~ 2~.25 S ~(.8.07 E 5~.3& 693214,23 ~3J4.~ ~ 9~.24 · ~.91 43,~8 93.Z~ ~11.56 1~6.~a 6762.56 252.07 s ~45.~E 5~5.12 ~3352,29 445~.11 ~ ~,24 ~.~1 ~.~ 95.Z4 ~O~.&5 IOO,~Q ~51.&5 Z&T,7~ s ~?21.~ ~ 5g~T&.61 ~628,39 ~F29.35 ~ 9].24 ~.gl 4~.~ ~.24 ~45.50 lOO,~O 71~.50 2~.52 s ~59.67 E 59~.36 ~3~.44 R~.47 ~ 9~.24 0_00 91~.91 ~$.~ ~.24 ~tT.&2 lOO.GG ~.~ ~79,z3 S ~9E8.~ E 59~.23 6~5.47 49~6.53 ~ 9~.2~ 92~.gI ~].~ ~.Z4 ~90.15 IOD,QG ~41.15 Z~,3~ S 4~7.57 E 59~.11 ~3~4,5Q 5005.5~ ~ 9~.24 9~.gI ~].~ ~.2& 76~.~7 IOB.~ ~1~.47 28~,25 S 5~.52 ~ 5g~5.9~ ~39~.52 5074.65 ~ 9].24 94~.~! 43.~ ~.2~ ~34.~ 10~.8~ 74~5.~ ~t,l~ S 513~.47 E 5g~$,86 ~04Z.55 5143,71 ~ 93.24 9~.91 ~3,~ ~.24 7~)7.12 106.~0 ~5~.12 ~5,Q7 S 5Z~.42 ~ 59~J.TZ ~II1,5~ 5~iZ.~ ~ 93.24 96~.91 ~3.~ ~3.24 76~.44 lOO.O6 r~O.4& ~8,~ S 52~,~ E 59~59,62 6~,180,~Q 5281,~ B 93.24 9~.91 ~3,68 P~.~ ~1,74 100.~ ~2.7d ~2.89 s 5~42.~ E 5g~57;50 ~,Z49,~ ~350.~ ~ 9~.24 0.00 9~.91 ~3,6& ~.24 ~,88 I00.00 ~.~ ~.~ S 5411.27 { 59'¢~55.38 ~318.44 5419.~ ~ 93.24 O.O0 ~.9~ g3.~ P3.~4 ~,41 100.00 ~7.41 310.Z1S 5480.~ E 5g~53.Z& ~387,4~ 5489.(~ g 93.24 a.go 180~.93 ~3.~ ~.Z4 ~.~ 100.00 ~[9.~ ~14.61 s 554g.17 [ 5g}gOSl.la ~456,~1 555B,(8 B 93.24 0.00 101~.~1 ~.~ ~.~4 ~,05 100.00 ~Z.05 ~18.52 s 5618.12 [ 5g~9.02 ~525.~ 56~.14 ~ 93.24 0.00 5/gm CSG. PT. 10Z77.~ G3.~ ~3.~ 81~,0Q 9~.95 ~9,00 ~22.2~ ~ 5682.~ E 59~T.03 ~590.58 569Z.02 ~ 93.~ lOZ ~. ¢3.68 93.Zi 8t1~.0D O,g ~65,0Q ~2.47 S 5687.~ E 5S~6.~ ~595.36 569b,~ · 9t.24 O.aO 10~,91 G3,~ ~.Z~ ~5~.0~ l'~,OO B2~,02 ~30.Z5 S 582Z.gY E 5g~Z.&~ ~Z.81 583~.32 ~ ,~GEI 1056Z,69 &3.~ 93,~ ~15.0~ 78,78 ~.80 33~.3~ S 58~.~ E 5g~l.~ ~T.19 5~.~ ~ 9).~ O.OO 107~,69 4~.~ ~.2¢ ~5~.65 IOO.~O ~10.65 ]~1.15 S ~17.~9 E 59~6.~7 ~25.~5 ~Z6,25 8 93.24 ~E ~. IT,%L 1~2~.~ 45.~ ~.Z~ 85~.00 69.1~ ~I~.~ ~6,90 S 6118.~ E 59~5.~ 6~26.76 6128.41Q 93.24 0.00 3~00,62 O.Ol} 3~69,6~ O.OO 40)8,74 0.00 41D7,~ 0.00 417&.~ 0.00 42%5,92 0.00 4~,5~, 11 O. O0 452Z.17 0.08 4591.23 O. OO 4660.29 D. O0 47-~,35 O. O Om 4 i~'&, 41 (].00 ' D. OO O.OO O. OO 5D0~.59 toO.OD O. Od) O.~ O.O,O 5_>&l 0.04) 5)50.90 0.00 .54,19.96 0.00 555~.0~ O. O0 5~7.14 a.ao O.OO 56'2Z.02 a.o0 O.O0 5696.2'0 O.QO 5?65.26 0.00 5957.~ O.O0 D.OO 0.00 ~). O0 60~0 O.OO O,~O 6~28,41 Prudhoe .Prudhoe Say .We~l' #AGt-Ol Bay Drilling VF, RT[CAL ViEW SCALE 1000 ft. / DIVISION REFERENCE' ~¥ELL HEAD \\ \ \. 'x H 0 RIZO.~'['A.L SCA[,E ~.000 122t~'ERF~,NCE: \ ',% ',,. "k ......... ~,1;~ ........... ~ODI '1 'VERTICAL SECTION PLA. NE' VIEW WELL' HEAD 93.84' MUD PROGRAM' Well AGi #1 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD $.P. ECIFICATIONS- SURFACE HOLE Surface: _Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt --300 < 100 YP lbs/100ft2 40 - 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel ibs/lOOft2 60- 80 20- 30 pH - 9.0 - 10 9.0 - 10' APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS-INTERMEDIATE HOLE Surface casing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/10Oft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 min 6-8 pH -- 8.5 - 10.0 Hardness mg/I <200 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point lbs/100ft2 10 - 20 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 15 - 25 APl Fluid loss mi/30 min 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness mg/Itr < 200 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at 10,000 - 20,000 ppm chlorides. NOV - Alaska Oil .& Gas Cons, ;Anchorage' AGI #1 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (Cf) TJYS (Cf) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (.14.0 ppg) at the surface casi~-,' shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SI PRESSURE 1 4 35OO 2548 Burst S.F. I .35 Collapse Calculation Collapse ~ating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2900 1433 Collapse S.F. 1.58 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 29O5 PBYS Tension S.F. 6.33 Mud Wt. 9.5 ppg TJYS 7.70 String Wt. (#) 168857 AGI #1 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 687O COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3420 Burst S.F. 2.01 Collapse Calculation Collapse.rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8109 0.1 3490 Collapse S.F. 1.36 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 10248 PBYS Tension S.F. 2.67 Mud Wt. 10.2 TJYS 2.86 String Wt. (#) 406566 AGi #1 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 351 2 3420 2.06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weigh1~ behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 8566 0.1 3687 I .47 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 782 Mud Wt. String Wt. (#) 10.2 17162 Tension S.F. PBYS TJYS 35.19 38.86 SUP,... (' 'HOL~. DIVERTER SYSTEM ...... Two lines venling gO deg. ;~p:~rl in directions that ensure sale down wind venling, and ex- tending to ~ point at least 100' from any potential source ol ignilion. 10' Full Opening Valves 35' or ~,s required .... Dresser Sleeve .o 1. All pipe connections 150¢ ANSI Flanges or welded conned, ions and secured to prevent movemenL 2.. Manual 10" lull opening valves m~ha. nically oonnc~d, ed to ensure that one valve is lail-saie open at all limes. 10' Diverler Line 3. All tums are go deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar 2C]' Diverter Spool wf 10' Side Outle( MEM 1FJ/"g 0 r.$,d D PUt~F~ T~.J ( 1 - Bra]~dt Doal Tand~n Sl~a].e Shaker ].- [~zo 6-12" Cone Shale Desander 1- [~n~ 41611 ~/16 ~nes ,1811 v~/16 ~nes (~silter) 1 - Dt:il~ Ah~spheric Hud ~gasser Dftk~O ,llt,'ll · ~0 ' T^~ 3 1 - 200 gpm Operating Capacity. Cenhri[uge 15 - Brandt t. UI5 Hud l,t[x hg].tabors 1 - 150 bbl. Trip Tank 1 - Recording drilling fluid pkh level indicator with bo~] visual and audio · r^,,~ z 5*0 ~,l '~ '"~'" TT~I D f ) I w~rning.devices at driller's console ' )(~u ~Y (~ 1- Drflltng fluid fl~,.] sansor~,~;_ wi~] res~ut at drill'~k(.',s console AUDI #2 13 5/8" 5,000 psi Stack 2.00 4.12 / RKB 1 I I RIG FLOOR DRIP PAN 12.72 4.50 i, 3.01 i 3.01 1.83 3.01 2.52 HYDRIL PIPE RAM 17.88 BLIND RAM MUD CROSS PIPE RAM 22.38 25.3 30.23 i34.25 MUD 1.5 I CROSS .... ~ASE FLG/ GROUND LEVEL 35.75 State: Alaska Borough: Well: AGi-1 Field: Prudhoe Bay St. Perm ;92-424 Dale 11/9/92 Engr: M. Minder AGI-1 Y, LS Casing Interval Interval Size Bottom Description escriptionescription Tension Top Length Lbs Grade Thread IA 13.$75 $500 S 1 3874 68 L-80 BTC 2A 9.625 8109 30 10248 47 NTS0-S NSCC 3A 7 8566 8160 782 26 NT80--S NSCC 4A 0 0 0 0 0 0 0 5A 0 0 0 0 0 0 0 6A 0 0 0 0 0 0 0 7A 0 0 0 0 0 0 0 SA 0 0 0 0 0 0 0 9A 0 0 0 0 0 0 0 10A 0 0 0 0 0 0 0 Lbs 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/ft 1B 9.0 0.468 2B 10.0 0.520 3B 10.0 0.520 4B 0.0 0.000 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 9B 0.0 0.000 1 Ol9 0.0 0.0C~ Maximum Minimum Pressure Yield psi psi BDF 2998 3450 1.2 3330 6870 2.1 3330 7224 2.2 0 0 #DIVI0! 0 0 #DIV/O.I 0 0 #DIM/0! 0 0 #DIVI0! 0 0 #DIVi0! 0 o #DIVIOI. 0 0 #DIVIO! Tension Strer~gth K/lbs K/Lbs 1C ~9.492 1069 2C 481.656 10~ 3C 20.332 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 2.25 604 29.71 0 #DIV/0! 0 #DiV/O! 0 #DIV/O! 0 # D iV/O'., 0 # DP,//O.! 0 #DIVIO! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. C:DF 1638 1950 1.190 4217 4750 1.126 4454 5410 1.215 0 0 #DIV/O! 0 0 #DNIO! 0 0 #DNIO! 0 0 #DIVi0! 0 0 #DIV/0! 0 0 #DIVi0! 0 0 #DIV/0! ) 'vt . ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc ~ ~i~/~,,-' ~ '[~ ~hru [9 th~u 13]/ [10 & 13] [14 thru 22] [23 thru 28] Company z~K, 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ e 10. 11. 12. 13 14 15. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is 1 ease nk~nber appropriate .......................................... Does well have a unique name & number ................................ I s conductor st r i ng prov ided ......................................... Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel i bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease & Well YES NO · 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. REMARKS (6) Other Ci~thru 3:~]' (:7) ~ .~3~_] (8) Add1 geo 1 ogy' rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions m~sented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. ~_ Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' 0 ~0 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. LIS VERIFICATION LISTING FOR: ARCO ALASKA, INC. AGI-1 PRUDHOE BAY ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA INC. AGI-1 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB mmho/m mmho/m MWD-API deg deg mins ohm-m ohm-m fi/hr ft/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. Ail rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Fri 1 OCT 93 10:27a != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 12345678901234567890123456789012345678901234567890123456789012345678.9012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode US Comment records: 0=OFF, 1 =ON 4 INFORECS = 1 , ! Decode US Information records: 0=NO,I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1=tape units 6 LISTFREQ = 100, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , !Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0=NO, I=YES 12 SPLITLIS = 1 , ! If I and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 100, LISTMAX = 0, STATS = 0, FORCETYP = 0 , WRITEASCll = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES = /0/, INTERPOLATE= 'YES' END I_. PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. !-- CONSTANT PARAMETERS AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 LISTFREQ= 100.000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 ddength= O.O00000E+O0 listwave= O.O00000E+O0 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 tfendep = O.O00000E+O0 tflevsp = O.O00000E+O0 tfstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcdevsp= O.O00000E+O0 wcrtop = O.O00000E+O0 !-- ARRAY PARAMETERS ............................................. ! SUBFILES(1) = O.O00000E+O0 SUBFILES(2) = -9999.00 SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) = -9999.00 SUBFILES(10) = -9999.00 SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) - -9999.00 SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999,00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) -- -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) - -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999,00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 !-- STRING PARAMETERS INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1152\1152.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 100) units of Depth. Listing output limiting (USTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS--1) has been enabled by user input. LIS information record decoding (INFORECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC = 1) Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 93/10/I 1152 01 **** TaPE HEADER **** MWD 93/10/1 1152 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s): 1234567890123456789012345678.9012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN1 JOB NUMBER: 1152 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD AGI-1 50-029-22289 ARCO ALASKA INC. BAKER HUGHES INTEQ 01 OCT 93 BIT RUN2 BIT RUN3 36.00 13.00 P. SMITH G. COOPER 36 12N 14E 1583 2390 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 112.0 2ND STRING 16.000 13.375 3910.0 3RD STRING 12.250 PRODUCTION STRING REMARKS: $ **** FILE HEADER **** MWD .001 1 O24 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8035.0 10264.0 $ BASELINE CURVE FOR SHIFTS: GRC CURVE SHIFT DATA (MEASURED DEPTH) -~ EQUIVALENT UNSHIFTED DEPTH ......... BASEUNE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 5 8035.0 10264.0 $ REMARKS: ALL DATA IN THIS FILE HAS BEEN DEPTH SHIFTED -6 FEET TO ATLAS WIRELINE CASED HOLE GAMMA RAY DATA. $ CN : ARCO ALASKA INC. WN : AGI-1 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT :ALASKA US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678.901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA THAT HAS BEEN DEPTH SHIFTED -6 FT. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 GR MWD 68 1 GAPI 4 4 98 660 71 6 2 RA MWD 68 I OHMM 4 4 98660 71 6 3 ROP MWD 68 1 FPHR 4 4 98 660 71 6 4 liP MWD 68 1 OHMM 4 4 98 660 71 6 16 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length Indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 90 Tape File Start Depth = 8035.000000 Tape File End Depth -- 10264.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4916 datums Tape Subfile: 2 160 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8041.0 10270.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 23 NOV 92 M1.33 M1.33 MEMORY 0.0 8041.0 10270.0 0 36.5 43.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2257-32 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 42.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1300 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.228 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 144.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 8043 TO 8088' MD (6426 TO 6459' TVD) WAS LOGGED 11 HOURS AFTER BEING DRILLED. INTERVAL FROM 9795' TO 9847' (7710 TO 7750' TVD) WAS LOGGED 10.5 HOURS AFTER BEING DRILLED DUE TO CONDITIONING AND WEIGHT UP OF MUD, INCLUDING A SHORT TRIP. INTERVAL FROM 10215 TO 10270' MD (8041 TO 8086' TVD) WAS NOT LOGGED DUE TO SENSOR SPACING IN STRING. $ CN : Arco Alaska Inc. WN : AGI-1 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0 0 0 1 0 0 O0 0 O0 1 O0 0 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl AP! APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 1 MINS 4 10 RACMMWD 68 1 OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPA MWD 68 1 FPHR 4 13 ROPSMWD 68 1 FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 RPDEMWD 68 1 OHMM 4 16 TCDMMWD 68 1 DEGF 4 498660 71 6 49866O 71 6 49866O 71 6 49866O 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 4 98660 7.1 6 49866O 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 637 Tape File Start Depth = 8041.000000 Tape File End Depth = 10270.000000 Tape File Levet Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19494 datums Tape Subtile: 3 710 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: US **** TAPE TRAILER **** MWD 93/lO/1 1152 01 **** REEL TRAILER **** MWD 93/lO/1 1152 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 1 OCT 93 10:28a Elapsed execution time = 48.83 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR ROP RP 8035.0000 -999.2500 -999.2500 -999.2500 -999.2500 8035.5000 -999.2500 -999.2500 -999.2500 -999.2500 8100.0000 78.3968 6.4072 42.6974 6.6651 8200.0000 55.3519 3.1335 177.1942 3.4349 8300.0000 81.1827 4.3174 83.2298 4.8603 8400.0000 50.3828 4.9652 28.6102 5.0924 8500.0000 88.1405 7.7759 61.0517 7.7271 8600.~ 83.2816 7.8799 63.2836 7.7049 8700.0000 90.9931 5.2216 58.0251 4,5396 8800.0000 90.4361 8.7762 66.5838 8.6286 8900.0000 81,9011 10.7402 48.1856 10.7884 9000.0000 85.6133 7.7537 50.8626 7.8028 9100.0000 86.6379 5.5373 45.7764 5.8227 9200.0000 103.8071 3.8513 42.0932 4.0001 9300.0000 107.9387 5.0078 52.3158 4.9687 9400.0000 98.1503 7.1947 42.1891 7.0264 9500.0000 104.2786 6.7664 53.8545 6.4554 9600.0000 94.0240 6.5790 52.8938 6.0413 9700.0000 92.5079 6.5246 27.1054 5.3788 9800.0000 172.1 481 4.7453 66.5638 4.9337 9900.0000 106.4500 10,1937 61.1014 8.5358 10000.0000 104.0567 4.4254 56.1111 3.8943 10100.0000 129.4652 5.4575 31.3618 5.1012 10200.0000 176.8658 7.8869 59.0647 6.3035 10264.00(X) -999.2500 -999.2500 43.2400 -999.2500 Tape File Start Depth = 8035.000000 Tape File End Depth = 10264.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8041.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 8041.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8100.0000 0.4867 0.6707 167.2628 180.7432 313.8369 78.3968 10.4097 9.5358 -999.2500 8.4628 5.9786 -999.2500 -999.2500 4.8407 5.5327 -999.2500 8200.0000 1.0404 1.2210 334.4236 359.3859 428.2541 55.3519 15.6429 14.6889 43.4500 3.6381 2.9902 237.3416 243.0663 2,5088 2.7825 112.1000 8300.0000 0.5804 0.7592 191.8842 195.0974 324.7344 81.1827 10.9059 10.0229 79.2167 7.0251 5.2115 33.5652 34.5482 4.5009 5.1256 118.1750 8400.0000 0.7571 0.9366 243.8500 252.9813 365,0424 50.3828 12.7474 11.8300 105.2833 5.2482 4.1009 42.1262 35.1849 3.5113 3.9529 119.1875 8500.0000 0.3736 0.5522 135.5648 136.0143 276.6588 88.1405 8.7244 7.8940 68.2500 11.0887 7.3765 58.7840 58.0620 6.3438 7.3522 123.5750 8600.0000 0.3307 0.5116 125.0566 129.2173 270.4911 83.2816 8.4466 7.6241 52.5833 12.5172 7.9964 52.8665 50.8626 6.6600 7.7389 127.2875 8700.0000 0.4376 0.6166 152.6025 154.4143 292.6180 90.9931 9.4459 8.5958 111.2667 9.4460 6.5530 60.0907 65.6275 5.6231 6.4761 130.2125 8800.O(XX) 0.2383 0.4141 100,5072 97,4962 239.2117 90.4,361 7.0482 6.2730 60.8167 17.1729 9.0495 78.4372 82.4159 8.6961 10.2568 129.5375 DEPTH DCCM RACM RPDE ATCM GRAM RADE TCDM ATDC PDCM ROPA CADE PDDC ROPS CPDE PDEM RPCM 8900.0000 244.5800 18.1801 9.7451 9000.0000 271.1266 11.8046 7.6977 0.2243 81.9011 10.1626 132.9125 0.3509 85.6133 7.7135 133.9250 0.4055 7.2867 54.9851 0.5294 8.4752 47.5728 98.4001 6.5026 59.0647 129.6426 7.6518 45.7403 102,6157 68.2833 8.2853 129.9093 71.7167 6.6263 9100.0000 286.7758 9.3575 6.7779 9200.0000 373.6588 4.5671 3.7548 0.4416 86.6379 6.5476 137.1875 0.8560 103.8071 3.6687 134.6000 0.6171 9.1814 44.3336 1.0300 13.1423 40.6858 152.7263 8.3382 42.5827 272.5768 12.2183 38.5182 147.5388 265.2666 5.8720 268.3227 96.6657 3.3424 9300.0000 336.7996 6.2365 4.7272 9400.0000 287.1184 9.8093 6.7602 0.6479 107.9387 4.7431 137.1875 0.4218 98.1503 6.7519 138.3125 0.8254 11.4570 45.4432 0.5999 9.1975 47.5103 210.8336 10.5608 48.5463 148.1054 8.3540 49.2206 211.5415 72.9490 4.1648 147.9246 193.9167 5.8569 9500.0000 306.2460 8.2780 5.8456 9800.0000 281.4828 13.5000 7.0705 0.4971 104.2786 5.9280 136.7375 0.3063 94.0240 8.2477 139.5500 0.6761 10.0648 48.4229 0.4968 8.9428 53.7948 168.6913 9.1999 45.7403 121.2453 8.1061 53.8545 171.0689 67.6333 5.1007 141.4336 71.6167 6.1120 9700.0000 288.8726 13.0107 6.6693 0.3180 92.5079 8.0083 1 38.0625 0.5109 9.2769 29.6488 124.8711 8.4300 31.5699 149.9397 68.3167 5.7808 9800.0000 344.5939 5.8291 4.4901 0.6892 172.1481 4.4893 142.3625 0.8661 11.8144 64,6432 222.7503 10.9142 60.0346 222.7115 596.7167 3.9673 9900.0000 238.5052 22.0415 10.3240 O. 1822 106.4500 11.2518 130.5500 0.3665 7.0194 62.1319 88.8746 6.2455 60.0346 96.8621 77.0667 8.7525 DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10000.0000 0.6013 0.7890 200.3328 227.8605 348.1795 104.0567 11.9782 11.0743 81.5500 6.7646 4.9917 44.6275 44.2986 3.8811 4.3886 135,9500 10100.0000 0.3873 0.5549 136.2553 118.0221 259.9250 129.4652 7.9744 7.1668 95.6000 10.6974 7.3392 37.5193 38.4891 7.2594 8.4730 138.8750 10200.0000 0.3758 0.5640 138.6223 157.0121 294.7933 176.8658 9.5467 8.6930 76.5167 11.0264 7.21 38 38.5738 37.3040 5.5345 6.3689 142.3625 10270.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 43.2400 43.2400 -999.2500 -999.2500 142.7000 Tape File Start Depth = 8041.000000 Tape File End Depth = 10270.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 4 is type: IlS ARCO ALASKA INC AGI- 1 PRUDHOE BA'~ ~ DEC 3 0 1992 Alaska 0ii & Gas Cons. Commiss)on Anchorage Run 1' 27 - Nov - 1992 DIFL/CN-ZDL/GR 10256 0844 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: AGI-1 500292230700 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 04-DEC-92 RUN1 5794.00 BRAD ESARY S. WALLS RUN2 M. WILSON RUN3 26 12N 14E 1583 2390 49.00 13.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 10259.0 DIFL/CN-ZDL/GR CIRCULATION STOPPED AT 08:30 27-NOV-92. CNC POROSITY IS CALIPER CORRECTED. CHISM FILTERING NOT ACTIVE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR 2435 SDN DIL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 10256.0 10784.0 10256.0 10791.0 10256.0 10808.0 10256.0 10844.0 GR (MEASURED DEPTH) BASELINE DEPTH NPHI 10256.0 10256.0 all EQUIVALENT UNSHIFTED DEPTH RHOB LL8 ILM 10256.0 10256.0 10256.0 10268.5 10269.0 10269.5 10286.0 10286.0 10288.5 10290.5 10289.0 10289.5 10290.5 10290.0 10290.5 10290.5 10297.5 10299.0 10300.0 10300.0 10303.0 10303.5 10303.5 10305.5 10306.0 10311.5 10313.0 10313.5 10314.0 10314.0 10322.0 10323.5 10322.5 10323.5 10323.0 10323.5 10323.5 10326.0 10326.5 10326.5 10342.5 10347.5 10348.0 10349.5 10352.0 10352.0 10353.0 10354.5 10356.0 10355.0 10356.0 10356.0 10373.0 10377.0 10378.5 10396.0 10397.5 10401.5 10402.5 10402.5 10413.5 10424.5 10425.0 10425.0 10425.0 10424.5 10433.5 10435.0 10441.0 10442.5 10442.0 10450.5 10451.0 runs merged; ILD 10256.0 10269.0 10290.5 10303.5 10312.0 10343.0 10349.5 10353.5 10356.0 10373.0 10397.5 10403.0 10414.0 10424.5 10442.5 no case 10467.5 10469.0 10470.0 10482.5 10484.0 10484.5 10485.0 10488.5 10489.0 10511.0 10522.5 10524.5 10529.0 10532.0 10532.5 10533.0 10540.0 10541.0 10546.0 10547.5 10558.5 10561.5 10562.5 10563.0 10572.5 10574.5 10578.5 10579.0 10579.5 10589.0 10592.0 10595.0 10607.0 10615.0 10615.5 10641.0 10642.0 10651.0 10652.0 10666.0 10666.5 10667.5 10669.5 10670.0 10670.5 10673.0 10675.5 10677.0 10679.5 10680.5 10687.0 10688.5 10692.0 10694.5 10701.0 10714.0 10715.0 10715.5 10726.5 10737.5 10469.5 10485.0 10532.0 10546.0 10563.0 10574.5 10579.0 10470.0 10485.0 10522.5 10529.5 10540.0 10559.0 10563.0 10574.0 10579.0 10589.0 10595.0 10668.0 10671.0 10682.5 10701.0 10715.5 10469.5 10485.0 10532.0 10562.5 10579.5 10652.0 10668.0 10671.0 10469.5 10490.0 10542.0 10563.0 10580.0 10592.0 10607.0 10615.5 10641.5 10652.0 10668.0 10673.5 10679.0 10681.0 10688.0 10695.0 10716.0 10727.5 10738.0 10469.5 10483.5 10489.5 10512.0 10525.0 10533.5 10548.0 10562.0 10579.5 10615.5 10643.0 10670.5 10673.5 10677.0 10681.0 10689.0 10692.0 10716.5 10738.0 10738.0 10744.5 10744.5 10748.5 10748.5 10751.5 10752.0 10752.0 10752.5 10752.5 10770.0 10770.0 10773.0 10773.5 10860.0 10860.0 10860.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 3 2435 1 3 SDN 1 3 DIL 1 3 $ REMARKS: CN WN FN COUN STAT 10738.0 10752.0 10752.5 10752.0 10860.0 10860.0 10860.0 MERGE TOP MERGE BASE 10256.0 10784.0 10256.0 10791.0 10256.0 10808.0 10256.0 10844.0 FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. MTEM, TENS, & TEND WERE SHIFTED WITH LL8. SP WAS SHIFTED WITH ILD. CNC POROSITY IS CALIPER CORRECTED. CHISM FILTERING NOT ACTIVE. $ : ARCO ALASKA INCORPORATED : AGI - 1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units GR 2435 68 1 GAPI NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS NUCT 2435 68 1 CPS TEND 2435 68 1 LB TENS 2435 68 1 LB RHOB SDN 68 1 G/C3 DRHO SDN 68 1 G/C3 PEF SDN 68 1 BN/E CALl SDN 68 1 IN LL8 DIL 68 1 OHMM ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM SP DIL 68 1 MV MTEM DIL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 * DATA RECORD (TYPE# 0) Total Data Records: 81 966 BYTES * 60 Tape File Start Depth = 10860.000000 Tape File End Depth = 10256.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19345 datums Tape Subfile: 2 273 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10179.0 10256.0 2435 10239.0 10256.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH - BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CN WAS CALIPER CORRECTED. NO CASING CORRECTIONS OR CHISM FILTERING APPLIED. THE NEUTRON DATA WAS NOT DEPTH MATCHED TO GRCH SINCE THERE WAS ONLY 17' OF CN DATA & IT WAS NOT CORRELATABLE TO THE GAMMA RAY OVER SUCH A SHORT INTERVAL. $ : ARCO ALASKA INCORPORATED : AGI - 1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 4 08 501 10 0 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 19 912 29 5 4 19 912 29 5 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 Tape File Start Depth = 10256.000000 Tape File End Depth = 10172.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1184 datums Tape Subfile: 3 35 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10179.0 2435 10239.0 ZDL 10203.0 DIFL 10239.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10790.0 10796.5 10814.0 10850.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN PCM ZDL KNJT TEMP KNJT PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSTAED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE KNUCKLE JOINT PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 27-NOV-92 FSYS REV. J001 VER. 1.1 830 27-NOV-92 1525 27-NOV-92 10850.0 10847.0 10256.0 10844.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517NA 1309XA 2435XA 3508XA 2222EA/2222MA 3921NA 2806XA 3921NA 3506XA 1503XA 8.5OO 10259.0 10256.0 KCL MUD 9.20 61.0 9.1 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI - 1 : PRUDHOE BAY : NORTH SLOPE : ALASKA 8.0 149.0 0.260 0.101 0.281 0.000 0.476 0.000 THERMAL SANDSTONE 2.65 0.000 1.5 54.0 149.0 54.0 0.0 54.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR 2435 68 1 GAPI CNC 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS TTEN 2435 68 1 LB CHT 2435 68 1 LB SPD 2435 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM CILD DIFL 68 1 MMHO VILD DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 19 912 29 5 4 19 912 29 5 4 54 376 29 5 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 34 704 23 6 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 76 * DATA RECORD (TYPE# 0) Total Data Records: 230 966 BYTES * Tape File Start Depth = 10860.000000 Tape File End Depth = 10172.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 74406 datums Tape Subfile: 4 312 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10450.0 2435 10450.0 ZDL 10450.0 DIFL 10450.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10798.0 10805.0 10822.0 10852.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN PCM ZDL KNJT TEMP KNJT PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSTAED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE KNUCKLE JOINT PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 27-NOV-92 FSYS REV. J001 VER. 1.1 830 27-NOV-92 1610 27-NOV-92 10850.0 10847.0 10256.0 10844.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517NA 1309XA 2435XA 3508XA 2222EA/2222MA 3921NA 2806XA 3921NA 3506XA 1503XA 8.500 10259.0 10256.0 KCL MUD 9.20 61.0 9.1 8.0 149.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI - 1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) 0.260 0. 101 ~0. 281 0.000 0.476 0.000 THERMAL SANDSTONE 2.65 0.000 1.5 54.0 149,0 54.0 0.0 54.0 0.0 ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 TTEN 2435 68 1 LB 4 7 CHT 2435 68 1 LB 4 8 SPD 2435 68 1 F/MN 4 9 ZDEN ZDL 68 1 G/C3 4 10 ZCOR ZDL 68 1 G/C3 4 11 PE ZDL 68 1 BN/E 4 12 CAL ZDL 68 1 IN 4 13 RFOC DIFL 68 1 OHMM 4 14 RILM DIFL 68 1 OHMM 4 15 RILD DIFL 68 1 OHMM 4 16 CILD DIFL 68 1 MMHO 4 17 VILD DIFL 68 1 MV 4 18 SP DIFL 68 1 MV 4 19 TEMP DIFL 68 1 DEGF 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 19 912 29 5 4 19 912 29 5 4 54 376 29 5 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 34 704 23 6 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 76 * DATA RECORD (TYPE# 0) 966 BYTES * Tape Subfile 6 is type: LIS 92/12/ 3 01 **** REEL TRAILER **** 92/12/13 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 13 DEC 92 9:48a Elapsed execution time = 31.14 seconds. SYSTEM RETURN CODE = 0 Total Data Records: 142 Tape File Start Depth = 10868.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35125 datums Tape Subfile: 5 222 records... Minimum record length: Maximum record length: 62 bytes 966 bytes
