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Home My WebLink About195-173Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages Poor Quality Original- P~ges: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, NoFrype OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ',~_., STATE OF ALASKA ',~.~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator ~~~'~ 7. Permit Number BP Exploration (Alaska)Inc. 3. Address !~~~;: 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612-~?-~"~-..i~' 50-029-22095-01 4. Location of well at surface 9. Unit or Lease Name 1636' SNL, 4011' WEL, Sec. 35, T12N, R12E, UM X - 619432, Y = 5979855 Prudhoe Bay Unit At top of productive interval 3667' SNL, 1384' WEL, Sec. 34, T12N, R12E, UM X = 616814, Y = 5977782 10. Well Number At total depth S-28A 3680' SNL, 2622' WEL, Sec. 34, T12N, R12E, UM X = 615576, Y = 5977751 11. Field and Pool :5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 64.86 ' ADL 028258 12. Date Spudded 04/18/1996 113' Date T'D' Reached 114' Date C°mp'' Susp'' or Aband'04/30/1996 1/14/2003 115' Water depth' if °fish°re N/A MSL 116' N°' of C°mpletions Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11050 8963 FTI 10624 8957 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 13-3/8" 68# L-80 33' 2531' 17-1/2" 2022 cu ft AS II1~ 1066 cu ft AS II 9-5/8" 47# NT80S 29' 9672' 12-1/4" 2068 cu ft Class 'G' 7" 26# NT80 9409' 9679' 8-1/2" 348 cu ft Class 'G' 2-7/8" 6.16# L-80 9390' 10624' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number), SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 8605' 9379' MD TVD MD 'r'VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9230' P&A with 50 Bbls Class 'G' // Sqzd to 1450 PSI 8587' Set CIBP 8582' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Press. 24:HOUR RATE ~, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ~E~~ED No core samples were taken. APR 1 6 2003 ~CA, I~E~; ~A¥ ¢j 5 2003 '--:~ Alaska 0il & Gas Cons. Commission ~orm 10-407 Rev. 07-01-80 ,i i Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sadlerochit 9787' 8900' · ..... RECEIVED APR 1 6 2003 Alaska 0il & Gas Cons. Commission Anchorage ,. ~. ,.., ~ ~ · ~. 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 32. I hereby certify that the foregoing is trUe and correct to the best of my knowledge Signed TerrieHubble~r~'~~ ~ Title TechnicalAssistant Date S-28A 195-173 303-002 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Ddlling Engineer' Rob Tirpack, 564-4166 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 sttachments. ITEM 16 AND 24: If this well is complete(~ 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORiGiNAL Well: S-28B Field: Prudhoe Bay Unit APl: 50-029-22095-02 Permit: 203-002 Accept: 01/18/03 Spud: 01/24/03 Release: 02/15/03 Rig: Nabors 9ES Date PRE-RIG WORK 01/03/03 T/I/O=1120/1280/1280 BLEED TBG/IA/OA (DRILLING SDTRK); INITIAL IA FL AT 7150' (382 EELS), BLED IA FROM 1280 PSI TO 280 PSI IN 3 HOURS, POST BLEED IA FL AT 6600' (TBG PRESSURE DROPPED TO 880 PSI DURING IA BLEED). INITIAL OA FL AT 160' (9 EELS), BLED OA FROM 1280 PSI TO 280 PSI IN 30 MINUTES TO PRODUCTION. INITIAL TBG FL AT 6450' (98 EELS). BLED TBG FROM 880 PSI TO 280 PSI IN 1 HOUR. MONITORED lAP FOR 1 HOUR WITH NO INCREASE. FINAL WHP'S = 290/280/280. 01/05/03 0/300/300. MONITOR WHP'S. (POST T X IA BLEED). TBG PRESSURE DOWN TO 0 PSI FROM YESTERDAY. IA & OA PRESSURES BOTH UP 20 PSI FROM YESTERDAYS BLEED. M.I.T. TUBING X I.A. TO 3000 PSI. 01/06/03 MIT I.A. X TBG. PASSED MIT. LOST 100 PSI IN 30 MINUTES. 01/08/03 TBG POT PASSED, lC POT FAILED UPPER SEALS ARE LEAKING. PRIMARY SEAL IS HOLDING. ALL LDS TORQUED TO 600 FT/LBS. 01/10/03 PPPOT-T PASSED TO 5000 PSI. LDS TORQUED TO 600 FT-LBS. PPPOT-IC FAILED. LDS TORQUED TO 600 FT-LBS. 01/12/03 DRIFT W 3.80" SWAGE, PULL EQ PRONG FROM 4 1/2" PXX PLUG. 01/13/03 PULL PXN PLUG BODY, DRIFT W/2.25 CENT TO 9640' SLM. 01/14/03 TIO= SI/75/375. IA FL @ 72'. (FOR COIL). ATTEMPT_ BOP TEST. PROBLEMS W/BOPS, TR,O ,~IL;,,~ ,E SHOOT ON LOCATION, UNABLE TO MAKE R,EPAIRS, SWAP~",T BOPS & TE~I~D OKAY. RIH WITH 2/~4.¢ BALL DROP NOZZLE. TAG LINER TOP AT 9436 C~I~ID. PUM¢ 30.EELS NEAT, I~5/I~BLS W/13 PPG AGG/5/I~BL NEAT 15.8# C~G CEMENT. BULLHEAD IN~/ · BBL~ CEMENT, SQZ P_R~SSURE BUILT TO 130gcPSI, LAY IN ANOTHEF~ 2/4' EBBS. PRE.S, SURE TO 1450~PSI IN ONE BBL AND HOLDING. DROP BALL & CHASE WITH BIOZAN. JET'E~OWN TO 9325 CTMD. POOH @ 80%. F/P TOP 2000' W/CRUDE. WELL READY FOR E-LINE. 01/15/03 T/I/O= 1550/1640/400 (PREP FOR RIG) TBG FL @ SURFACE. IA FL @ 654'. WELL SHUT IN UPON ARRIVAL. DRIFT W/3.62" TAG TOC 9204' SLM. (SAMPLE OF CEMENT). PT CEMENT TO 1600 PSI. DHD TO COMPLETE TESTING TO 2000 PSI. LEFT WELL SHUT IN. CHEMICAL CUT TUBING AT 9215': TAG TOC AT 9230' WITH TUBING PUNCHER. DEPTH REFERENCED TO TUBING TALLY. 20J TUBING PUNCHER SHOT FROM 9190'-9192'. 01/16/03 CHEMICAL CUT TUBING AT 9215'. DEPTHS REFERENCED TO TUBING TALLY. STRING SHOT FROM 9204'- 9216'. CHEMICAL CUT TUBING AT 9215'- 15' OFF TAG AS PER CHEM CUT SOP. GOOD INDICATION. PAD OPERATOR NOTIFIED, WELL LEFT SHUT IN. LRS RIGGING UP FOR CIRC OUT. CIRC OUT WELL W/1017 BBLS SEAWATER, FREEZE PROTECTED AND U-TUBED IA X TBG W/175 BBLS DIESEL BP EXPLORATION Page 1 of 16. Operati o:ns Summa Report Legal Well Name: S-28 Common Well Name: S-28 Spud Date: 1/18/2003 Event Name: REENTER+COMPLETE Start: 1/17/2003 . End: 2/15/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/15/2003 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NpT phaSe DeSCriPtionlof Operations : . 1/17/2003 12:00 - 14:30 2.50 MOB P PRE PJD Floor, Disconnect Inter Connect, Bridle - Up. 14:30 - 17:00 2.50 MOB P PRE Move Shop & Pit Complex to S-28 Location. 17:00 - 18:00 1.00 MOB P PRE Drop Beaver Slide, Un - Pin Derrick & Lay Derrick Down. 18:00 - 22:00 4.00 MOB P PRE Move Rig Off S-109. Move Rig to S-28B. 22:00 - 00:00 2.00 MOB P PRE Lay Rig Mats & Herculite. Spot Rig, Pits, Shop & Camp. 1/18/2003 00:00 - 02:00 2.00 RIGU P PRE MU Mud, Steam & Water lines 02:00 - 03:00 1.00 RIGU i P PRE PJSM Raise Derdck 03:00 - 05:30 2.50 RIGU P PRE RU Pipe Shed Chute, Bridle DN 05:30 - 06:30 1.00 WHSUR i P DECOMP RU Lubricator, Pull BPV, RD Lubricator TBG Press = 250 psi, 4 1/2 X 9 5/8 Press = 320 psi, 13 3/8 X 9 5/8 = 410 psi 06:30 - 08:30 2.00 CLEAN = P DECOMP RU To Reverse Circ. Freeze Protect From TBG & Annulus 08:30 - 10:00 1.50 CLEAN 'P DECOMP Test Lines to 3500 psi, Reverse Circ. Freeze Protect from TBG @ 2.5 BPM, 500 psi 10:00 - 15:00 5.00 CLEAN P DECOMP Displace Freeze Protect from IA with ICP 0.75 BPM @ 1900 psi, FCP 0.75 BPM @ 3000 psi 15:00 - 16:30 1.50 WHSUR P DECOMP Install TWC Valve Test From Below to 1000 psi 16:30 - 17:30 1.001WHSUR P DECOMP ND Tree & Adapter Flange 17:30 - 18:30 1.00 WHSUR P DECOMP Clean, Inspect Hanger, Pull Control Lines. 18:30 - 21:30 3.00 BOPSUF.P DECOMP NU BOP Stack & Related Equip 21:30 - 00:00 2.50 BOPSUF:P DECOMP RU Test Equip and Press Test BOP's 250 psi for 5 min Low and 3500 psi for 5 Min High. Witness of BOP Test Waived by John Crisp AOGCC 1/19/2003 00:00 - 02:30 2.50 BOPSUF.P DECOMP Test BOP's 250 psi Low 3500 psi High. Witness of BOP Test Waived by John Crisp AOGCC. Blow Down Choke & Kill Lines, Blow Down Choke Manifold 02:30 - 03:00 0.50 WHSUR P DECOMP PU MU Lubricator, Pull TWC, LD Same 03:00 - 06:00 3.00 PULL :) DECOMP MU Jt DP with XO to TBG Hanger, Unseat Hanger Attempt to Pull TBG, Work TBG String, Max Wt. Pulled 265K, No Go, LD Jt DP with XO 06:00 - 10:00 4.00 PULL N DPRB DECOMP WO SWS for Chemical TBG Cut 10:00 - 11:00 1.00 PULL N DPRB DECOMP PJSM with SWS, RU SWS for String Shot 11:00 - 14:00 3.00 PULL N DPRB DECOMP RIH with Stdng Shot to 9150', Fire String Shot @ 9150', POOH & RD Stdng Shot 14:00 - 15:00 1.00 PULL N DPRB DECOMP PJSM, RU & Arm Chem Cutter 15:00 - 18:00 3.00 PULL N DPRB DECOMP RIH with Chem Cutter/Jars on E-Line, Chemically Cut 4 1/2" TBG @ 9150', POOH with Same 18:00 - 19:00 1.00 PULL N DPRB DECOMP RD Chemical Cutter 19:00 - 20:00 1.00 PULL N DPRB DECOMP MU Jt DP with XO to TBG Hanger, Unseat Hanger Attempt to Pull TBG, Max Wt. Pulled 265K, No Go, Circ, 0.75 BPM @ 3000 psi 20:00 - 23:00 3.00 PULL N DPRB DECOMP RU String Shot #2, RIH and Fire String Shot #2 @ 9000', POOH & RD Stdng Shot 23:00 - 00:00 1.00 PULL N DPRB DECOMP RU TBG Equip. MU 4 1/2" Pup Jts Screw Into hanger 1/20/2003 00:00 - 00:30 0.50 PULL N DPRB DECOMP Pull 20klbs overpull in pipe & set slips. Install collar clamp above slips. MU safety valve & secure well. 00:30 - 01:30 1.00 PULL N DPRB DECOMP Wait on delivery of 4 1/2" IF pump in sub and packoff from SWS - phase 2 weather conditions. 01:30 - 02:00 0.50 PULL N DPRB DECOMP PJSM SWS, NAD, BP on handling chemical cutter @ surface & appropriate actions if problems. 02:00 - 04:30 2.50 PULL N DPRB DECOMP RIH with chemical cutter and Icg on depth at 9000' ELMD. Fire cutter to sever tubing.---- .... 04:30 - 05:30 1.00 PULL N DPRB DECOMP POH with cutter & RD wireline. Indication that cutter may not have made full circumferential cut. Printed: 2/1712003 2:28:50 PM BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: S-28 Common Well Name: S-28 Spud Date: 1/18/2003 Event Name: REENTER+COMPLETE Start: 1/17/2003 End: 2/15/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/15/2003 Rig Name: NABORS 9ES Rig Number: Date From-To Hours Task Code NPT PhaSe DescriptiOn Of Operations 1/20/2003 05:30 - 09:00 3.50 PULL N DPRB DECOMP Work pipe up to 80% tensile rating but won't come free. Attempt to establish circulation but no improvement from previous cut attempts. Suspect tubing is cemented in 9 5~8" casing to above 9000'. 09:00 - 10:00 1.00 PULL :N DPRB DECOMP RU to fire string shot at ~8625'. 10:00 - 11:00 1.00 PULL N DPRB DECOMP RIH with stdng shot. Cannot pass GLM at 3093' with string shot. POH & inspect shot - end bent over. Straighten same - OK. 11:00 - 14:00 3.00 PULL N DPRB DECOMP Re-run stdng shot and log on depth at ~8625' ELMD. Fire string shot. POH with string shot 14:00 - 15:00 1.00 PULL N DPRB DECOMP Pull 25klbs overpull in pipe & set slips. Install collar clamp obove slips. PJSM SWS, NAD, BP on handling chemical cutter. RU chemical cutter 15:00 - 17:00 2.00 PULL N DPRB DECOMP RIH with chemical cutter and log on depth at 8625' ELMD. Cutter misfired twice. Waited 2 minutes, Cutter misfie.d again 17:00 - 18:30 1.50 PULL N DPRB DECOMP POH with chemical cutter to 200' ELMD from surface 18:30 - 19:30 1.00 PULL N DPRB DECOMP PJSM SWS, NAD, BP on pulling misfired chemical cutter to rig floor. Pull chemical cutter to rig floor. Trouble shot tool, determined leaky O-dng caused misfire 19:30 - 21:30 2.00 PULL N DPRB DECOMP Redress chemical cutter. Re-run chemical cutter and log on depth at 8610' ELMD. Fire cutter to sever tubing, good indication of successful cut on rig floor. 21:30 - 22:30 1.00 PULL N DPRB DECOMP POH with chemical cutter & RD wireline 22:30 - 00:00 1.50 PULL P DECOMP Pull hanger to floor, stdng weight 125klbs. Break SSSV control lines off hanger and tie off 112112003 00:00 - 01:00 1.00 PULL P DECOMP Circ sweep around at 500+ GPM 700 psi. RU Sc, h/Camco ctrl line spooling unit. 01:00 - 01:30 0.50 PULL P DECOMP Flowcheck well o OK. Pump dry job. 01:30 - 04:00 2.50 PULL P DECOMP LD tubing hanger and landing jr. Pull 4.5" tubing & LD same to SVLN. 04:00 - 04:30 0.50 PULL P DECOMP LD SVLN. RD Camco. Recovered 25 control line clamps + 3 SS bands + all control line - OK. 04:30 - 09:00 4.50 PULL P DECOMP Cont pulling tubing & LD same - 214 jts, 1 cut off, 3 GLM's, 1 SVLN. 09:00 - 09:30 0.50 PULL P DECOMP RD tubing equ'pt. Clear rig floor. 09:30 - 14:30 5.00 WHSUR P DECOMP Bleed 400 psi pressure off OA to bleed tank prior to pulling 9-5~8" packoff. 14:30 - 17:00 2.50 WHSUR P DECOMP Latch into packoffwith pulling tool. Back out Iockdown screws. Unseat packoff with 45 klbs overpull and retrieve same. Install new packoff, torque Iockdown screws and gland nuts. Test to 5000 psi for 10 min. 17:00 - 18:00 1.00 BOPSUR P DECOMP Install test plug, test lower pipe rams - 250 psi Iow, 3500 psi high. LD test plug. Install wear bushing. 18:00 - 20:00 2.00 CLEAN P DECOMP MU Baker whipstock mill assembly with DC's, jars and HWDP 20:00 - 00:00 4.00 CLEAN P DECOMP RIH with mill assembly picking up single joints of 4" HT-40 DP. Break circulation at 2800' 1/22/2003 00:00 - 02:00 2.00 CLEAN P i DECOMP Cont. RIH with mill assembly picking up single joints 4" H-40 DP. Break circulation at 5800'. Tag tubing stub at 8605'. PU weight 195 klbs, SO weight 170 klbs, torque 3000 fflb @ 75 RPM. ~- ....... 02:00 - 03:00 1.00 CLEAN P DECOMP Circulate 25 bbl Hi-Vis sweep followed by seawater surface to surface, 13 BPM @ 1990 psi. Reciprocate pipe while i circulating. 8CANNEL%" 0 5 2003 Printed: 2/17/2003 2:28:50 PM BP EXPLORATION Page 3 of 16 Operations Summary Re:port Legal Well Name: S-28 Common Well Name: S-28 Spud Date: 1/18/2003 Event Name: REENTER+COMPLETE Start: 1117/2003 End: 2/15~2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/15/2003 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT 'Phase .Description of oPeratiOns 1/22/2003 03:00 - 04:30 1.50 CLEAN P DECOMP PJSM Little Red Services, NAD, BP on pumping hot diesel, pressure testing lines and spill prevention measures. RU Little Red. Pump 20 bbl Hi-Vis spacer. Switch over to Little Red test lines to 3000 psi - OK. Pump 80 bbl 150-170 degree diesel at 2 BPM. 04:30 - 05:30 1.00 CLEAN P DECOMP Chase diesel with 20 bbl Hi-Vis spacer followed by seawater to surface pumping 6 BPM @ 430 psi. 05:30 - 07:30 2.00 CLEAN P DECOMP Circulate diesel to cuttings tank, 2 BPM @ 100 psi. Continue until clean seawater to cuttings tank. 07:30 - 08:30 1.00 CLEAN P DECOMP Circulate 25 bbl Hi-Vis sweep followed by seawater surface to surface, 13 BPM @ 1990 psi. Reciprocate pipe while circulating. 08:30 - 11:30 3.00 CLEAN P DECOMP Monitor well, pump dry job. POH with whipstock mill assembly. PU weight 210 klbs, SO weight 160 klbs 11:30 - 12:30 1.00 CLEAN P DECOMP Cut and slip ddlling line 79'. 12:30- 13:00 0.50 CLEAN P DECOMP Service rig. 13:00 - 14:30 1.50 CLEAN P DECOMP Cont. POH. Stand back HVVDP and collars. Lay down jars, bit sub, casing scraper and orienting sub 14:30 - 18:30 4.00 STWHIP P WEXIT PJSM SWS, Halliburton, NAD, BP on rigging up, handling CIBP and explosives safety. RU E-line equipment. Log on depth to set top of ClBP at 8587' ELMD. SWS setting tool misfire. POH with E-line. '18:30 - 23:00 4.50 S-I-WHIP N DFAL WEXlT Safe out explosives. Trouble shoot Schlumberger tools, electrical malfunction in the wireline head, changout toolstring, changeout explosives. 23:00 - 00:00 1.00 STWHIP N DFAL WEXlT 2nd RIH with ClBP on E-line. 1/23/2003 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT Cont. RIH with E-line to set bridge plug at 8587' ELMD 00:30 - 01:30 1.00 S'I'WHIP N DFAL WEXIT Log on depth and set CIPB at 8587' ELMD. POH with setting tool. RD SWS. 01:30 - 02:00 0.50 S'I'WHIP P WEXIT Test 9 5/8" 47# casing to 3500 psi, hold for 30 minutes. Outer annulus pressure increase from 0 psi to 10 psi during pressure test., 02:00 - 03:00 1.00i S'I'WHIP P WEXlT PU and MU whipstock, orient same to MVVD. 03:00 - 04:30 1.50 STWHIP P WEXlT I MU BHA. Function test MWD at 945' - OK 04:30 - 08:30 4.00 STWHIP P WEXlT RIH with whipstock to 8587' at 90 seconds per stand. Fill pipe every 2000' 08:30 - 09:00 0.50 STWHIP P WEXIT Orient whipstock to 69 degrees left of high side (final position). Set anchor with 20 klbs down weight. Shear mills with 45 klbs down weight. Tagged up at 8582' 09:00 - 12:00 3.00 S'I'WHIP P WEXIT Circulate new 11.3 PPG mud surface to surface at 220 GPM @ 600 psi. Get slow pump rates: SPR#1 2 BPM = 310 psi, 3 BPM = 415 psi, SPI:~2 2 BPM = 315 psi, 3 BPM = 415 psi. MD = 8560', 'I'VD = 7820' 12:00 - 20:00 8.00 STWHIP P WEXIT Vlill window with whipstock assembly from 8560' to 8576' plus 14' of openhole to 8590'. PU wt. 195 klbs, SO wt. 165 klbs, ROT wt. 170 klbs. INITIAL CUT 160 SPM, 400 GPM, 1900 PSI, 3K - 5K WOB, 7K - 9K TQ. FINAL CUT 184 SPM, 450 GPM, 2170 PSI, 120 RPM, 20K - 22K WOB, 7K TQ. 80% recovery of metal. Work pipe through window rotating and sliding, no ~ 3roblems 20:00 - 21:00 1.00 STWHIP P WEXI'f Circui~"~-0'-i~ 'Hi-Vis sweep surface to surface 450 GPM @ STWHIP 2180 PSI to clean hole 21:00 - 00:00 3.00 , P WEXIT Monitor well - no flow. Pump dry job. POH, PU wt. 200 klbs, SO 2003 Printed: 2/17/2003 2:28:5OPM BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: S-28 Common Well Name: S-28 Spud Date: 1/18/2003 Event Name: REENTER+COMPLETE Start: 1/17/2003 End: 2/15/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/15/2003 Rig Name: NABORS 9ES Rig Number: Date From - To Hours 'Task !Code NPT Phase Description of: OPerations · 1123/2003 21:00 - 00:00 3.00 STWHIP P WEXlT wt. 160 klbs. No drag, hole appears to be clean. SPR#1 2 BPM - 330 PSI 3 BPM = 400 PSI, SPR#2 2 BPM -- 335 PSI, 3 BPM = 410 PSI. MD - 8590', 1-VD - 7847' 1/24/2003 00:00 - 00:30 0.50 STWHIP P WEXlT Stand Back HWDP 00:30 - 02:00 1.50 SI'WHIP P WEXlT LD BHA #2, 9 steel DC, MWD and mill assembly 02:00 - 03:00 1.00 SI'WHIP P WEXlT Flush BOP stack, clear and clean floor 03:00 - 05:00 2.00 DRILL P LNR1 PU BHA #3 05:00 - 08:00 3.00 DRILL :P LNR1 PU MU singles from pipe shed, 129 joints 08:00- 09:30 1.50 DRILL ;P LNR1 TIH to 8300' 09:30 - 10:00 0.50 DRILL P LNR1 FIT EMW = 12.5 ppg. Baseline ECD = 11.74 10:00 - 10:30 0.50 DRILL i P LNR1 Orient tool face to 60 degrees left. Continue TIH to 8590' 10:313 - 12:00 1~50 DRILL ' 'P' LNR1 Drill from 8590' to 8622'. 205 SPM, 505 GPM @ 2640 PSI. PUJ" weight 210 klbs, SO weight 160 klbs. AST = 1.13 hrs., ART/0 hrs. 12:00 - 00:00 12.00 DRILL !P LNR1 Continue drilling from 8622' to 8788', slide most of e~efi stand to drop angle. PU,weight 190 klbs, SO weight 155~bs. AST = 7.21 hrs., ART = 0.25 hrs. 1/25/2003 00:00 - 05:30 5.50 DRILL P LNR1 Drill from 8788' to 9011' 215 SPM, 525 GP~@ 3260 PSI. PU weight 194 klbs, SO weight 156 klbs, R/~T weight 178 klbs. Baseline ECD = 11.74 ppg, calc EC/I~= 11.70 05:30 - 08:00 2.50 DRILL P LNR1 Circulate and backream I stand/to'clean hole. ECD increase from 11.7 ppg to 12.4 ppg. O_/bS'erved a small amount of splintered shale across s/I,I,ha~ers. Weight up mud 0.1 to 11.4 ppg. Circulate hole de/ad. Calculated ECD = 11.85, actual ECD = 11.91 08:00 - 00:00 16.00 DRILL P LNR1 Drill from 90117d9235' MD. Backream full stands @ 80 RPM, reduce pum~os"on down stroke. Calculated ECD = 11.75, actual ECD = 11,~.82. PU wpi~t 198 klbs, SO weight 169 klbs, ROT weight 179 klbs. A~T"= 11.96 hrs., ART = 0.8 hrs, TVD = 8415' 1/26/2003 00:00 - 08:00 8.00 DRILL i P LNR1 ,Drill from 9235' to 9330'. PU weight 201 klbs, SO weight 168 klbs, ROT weight 180 klbs. 208 SPM, 510 GPM @ 3000 PSI. ART 0.0 hrs, AST 4.68 hrs. ROP Iow. 08:00 - 09:30 1.50 DRILL I P ~LNR1 Circulate sweep surface to surface. Max pump rate 520 GPM ..? @ 3095 PSI, 212 SPM. Reduce pump rate on downstroke to j prevent surging of formation. ECD = 11.84 ppg, calculated /' ECD = 11.78 ppg. Monitor well - NO FLOW. Pump dry job. 09:30 12:30 3.00 DRILL !P - LNR1 POH for bit chg. PU weight 206 klbs, SO weight 165 klbs. /.-/ ,j Intermittent increase in drag from 5-10 klbs in open hole / section. No noticeable increase in drag across window 12:30 - 14:00 1.50 DR~ILI~ :P LNR1 LD 2 joints of HWDP. Standback remaining HWDP, Jars, ~ Collars. LD MWD. Bit in gauge and no cutter damage. 14:00- 14:30 0.50 ~DRILL ~P LNR1 Clean and clear fig floor 14:30 - 17:30 I3.~0 BOPSUF!P LNR1 Pull wear ring. RU to test BOP. Test BOP - rams to 3500 psi / /' 250 psi, annular to 3500 psi 1250 psi. witness of BOP test · waived by John Spaulding, AOGCC. RD test equipment, blow .-/-' down lines. Install wear ring 17:30 71'9:00 1.50 DRILL P LNR1 PU new motor, MU bit (DS70). Adjust motor to 1.5 degrees. PU MWD, ARC/PWD. Orient same. RIH with collars, jars and 5" · · I HWDP. Shallow function test MWD at 500 GPM @ 1060 psi - '~ 'LNR1 OK. ' 19:00 - 21:00 2.00 DRILL P RIH to 5000', fill DP at 2500' · 21:00 - 22:00 1.00 DRILL P I I LNR1 Cut and slip 65' of drill line. Test and function Crown-O-Matic. I i ~ , 2003 Printed: 2/17/2003 2:28-50 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ CA GEL DIESEL DOWN SQZ Pull tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 65 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1636' FNL, 4011' FEL, Sec. 35, T12N, R12E, UM (asp's 619431, 5979855) S-28A At top of productive interval \ 9. Permit number / approval number 3678' FNL, 1402' FEL, Sec. 34, T12N, R12E, UM (asp's 616796, 5977771) "~ 195-173 At effective depth .,. 10. APl number 3629' FNL, 2200' FEL, Sec. 34, T12N, R12E, UM (, (asp's 615997, 5977808) 50-029-22095-01 At total depth 11. Field / Pool 3680' FNL, 2622' FEL, Sec. 34, T12N, R12E, UM (asp's 615576, 5977751) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11050 feet Plugs (measured) true vertical 8963 feet Effective depth: measured 10624 feet Junk (measured) true vertical 8957 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 c.f. concrete 138' 138' Surface 2562' 13-3/8" 3088 c.f. 2590' 2590' Production 9644' 9-5/8" 2060 c.f, 9672' 8797' Liner 270' 7" 348 c,f, 9409' - 9679' 8563' - 8803' Slotted Liner 1234' 2-7/8" Uncemented 9390'- 10624' 8546' - 8957' Perforation depth: measured Open Perfs 9649'-9672' REC~.~V ~) true vertical Open Perfs 8777' - 8797' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG to 9379'. 4-1/2" Tubing Tail @ 9459'. Anchorage Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" Baker SA-3 Packer set @ 9379' MD. 4-1/2" Otis SSSV Landing Nipple @ 2081' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data O~l-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation Shut-In 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best ct my knowledge. Title: Technical Assistant Date January 09, 2003 DeWayne R Sch .... ~C~NN~r~ ~' i~. ~) Pr~a,l~d I~l~¥ne R Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 10/11/2002 10/20/2002 10/21/2002 I O/22/2OO2 10/22/2002 10/31/2002 11/04/2002 11/23/2002 11/24/2002 11/25/2002 11/28/2002 11/29/2002 1 2/11/2002 12/1 2/2002 1 2/28/2002 12/31/2002 01/03/2003 01/05/2003 01/05/2003 01/06/2003 10/11/02 10/20/02 10/21/02 10/22/02 10/22/O2 10/31/02 11/04/02 S-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL GEL TREATMENT: AC-MONITOR GEL TREATMENT: GEL TREATMENT ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR GEL TREATMENT: GEL TREATMENT SECURE WELL: AC-FLUID LEVEL SECURE WELL: AC-FLUID LEVEL SECURE WELL: AC-MITOA ANN-COMM (AC-EVAL AND REPAIR): ANN-COMM (AC-EVAL ANN-COMM (AC-EVAL ANN-COMM (AC-EVAL AND REPAIR): AND REPAIR): AND REPAIR): ANN-COMM (AC-EVAL AND REPAIR): BOPD: 1,115, BWPD: 3,012, MCFPD: ANN-COMM (AC-EVAL AND REPAIR): SECURE WELL: AC-FLUID LEVEL CTD: AC-BLEED CTD: AC-MONITOR ANN-COMM (AC-EVAL AND REPAIR): MIT-IA ANN-COMM (AC-EVAL AND REPAIR): MIT-IA AC-EVAL; AC-TIFL AC-MONITOR GAS LIFT--FOR RATE AC-TIFL AC-FLUID LEVEL 3,788, AL Rate: 3,540 TUBING TAIL PLUG EVENT SUMMARY T/I/O: 1500/1100/1060. CA FL @ 2235'. (CA GEL LOAD). T/I/O/= 1500/1070/960 Monitor WHP's. PRE CA GEL JOB. PREP FOR CA GEL TREATMENT. TIC= 1520 1050/960 Initial CA FL @ 2200' (130 BBLS). BLED CA FROM 960 PSI TO 60 PSI IN 4 HOURS. FINAL WHPs: 1520/1040/60. T/I/O=1600/920/300 (POST CA BLEED) MONITOR WHP's. PLACED 2500# OF 100 MESH SAND, 4500# BENTONITE, 27# LAMINATED CELLOFLAKE IN A GEL DIESEL SLURRY INTO THE CA, DISPLACED PILL WITH 70 BBLS DIESEL. SECURED WELL WITH 980 PSI CAP. T/I/O: SI/1020/1020. (Weekly CA FL for WC). CA FL Near Surface. T/I/O = SSV/1170/1100. (Weekly CA FL for WC). CA FL Near Surface. SCANNED FEB 0 & 2003 Page I 10/11/2002 11/23/02 11/24/02 11/25/02 11/28/02 11/29/02 12/11/O2 12/12/02 12/28/02 12/31/O2 01/03/03 S-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COIVlM (AC-EVAL AND REPAIR): AC-FLU:ID LEVEL MIT OA TO 2400 PSI. PASS. FIRST 15 MINUTES LOST 60 PSI. SECOND 15 MINUTES LOST 30 PSI. TIO= 1460/1350/1340 TIFL FAILED LOW OA FL (EVALUATION FOR WAIVER). INITIAL IA FL @ 3760' (202 BBLS); STATION #5 @ 3093', STATION #4 @ 5517'. BLED lAP FROM 1350 PSI TO 470 PSI IN 2 HOURS & 45 MINUTES. IA FL @ 138'; FL ROSE 3622' OR 194 BBLS. MONITORED FOR 30 MINUTES; DURING THE 30 MINUTE MONITOR, THE TP CAME UP 10 PSI FROM 1450 PSI TO 1460 PSI, lAP CAME UP 40 PSI FROM 470 PSI TO 510 PSI, OAP WENT DOWN 60 PSI FROM 1300 PSI TO 1240 PSI. FINAL WHPs= 1460/510/1240. T/I/O = 1400/700/925. (MONITOR POST MITOA). SET CATCHER SUB. CHANGE OUT S/O GLV IN STA # 1 (BAD CHECK CONFIRMED). PULL CATCHER SUB. LEFT WELL SHUT IN ( PER RE-TIFL). T/I/O=1460/1400/700 (EVAL TBG, IA) TIFL FAILED INITIAL IA FL @ 3742'. BLED IA FROM 1400 PSI TO 400 PSI IN 4 HOURS. IA FL @ 366' IA FL, ROSE 3376'. MONITORED IA FOR 1 HOUR. IA PRESSURE INCREASED 20 PSI. FINAL WHP's 1460/420/720. T/I/O=1300/1050/620 OA FL @ 65'. TESTEVENT--- BOPD: 1,115, BWPD: 3,012, MCFPD: 3,788, AL RATE: 3,540 SET 4 1/2" PXX PLUG AND PRONG IN X-NIPPLE @ 9343' SLM <<< PRONG 98" LONG W/1.75" FN >>> BLEED TUBING FROM 1500# TO 1000#, ONLY CAME UP 30# AFTER 30 MIN --- ANNULAR COMMUNICATION--- IA CAME DOWN FROM 1640 TO 1560# (GOOD TEST). ***LEFT WELL SHUT IN*** TIO= 980/1480/1350. IA FL @ 7196' (385 bbls). TBG FL @ 6436' (98 BBLS). (DRILLING SDTRK). T/I/O=1120/1280/1280 BLEED TBG/IA/OA (DRILLING SDTRK); INITIAL IA FL @ 7150' (382 BBLS), BLED IA FROM 1280 PSI TO 280 PSI IN 3 HOURS, POST BLEED IA FL @ 6600; (TBG PRESSURE DROPPED TO 880 PSI DURING IA BLEED). INITIAL OA FL @ 160' (9 BBLS), BLED OA FROM 1280 PSI TO 280 PSI IN 30 MINUTES TO PRODUCTION. INITIAL TBG FL @ 6450' (98 BBLS). BLED TBG FROM 880 PSI TO 280 PSI IN ONE HOUR. MONITORED lAP FOR ONE HOUR WITH NO INCREASE. FINAL WHP's -- 290/280/280. SCANNED FEB 0 4 2003 Page 2 10/11/2002 01/05/02 01 ~O5/O3 01/06/03 S-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL 0/300/300. MONITOR WHP's. (POST T X IA BLEED). TUBING PRESSURE DOWN TO 0 PSI FROM YESTERDAY? IA & OA PRESSURES ARE BOTH UP 20 PSI FROM YESTERDAY'S BLEED. MIT TUBING X I.A. TO 3000 PSI. MIT IA x TBG. PASSED MIT. LOST 100 PSI IN 30 MINUTES. FLUIDS PUMPED BBLS 3O METHANOL 23 DIESEL 453 CRUDE 160 DIESEL WITH 2500# 100 MESH SAND, 4500# BENTONITE, 27# CELLOFLAKE. 666 TOTAL SCANNED FEB 0 4 2003 Page 3 S-28A Sundry Subject: S-28A Sundry Date: Mort, 6 Jan 2003 16:26:18 -0600 From: "Tirpack, Robert B" <TirpacRB~BP.com> To: "Winton Aubcrt (E-mail)" <winton_aubert~admin. state, ak.us> CC: "Hubblc, Terrie L" <HubbleTL~BP.com> Wint on, Operations on Nabors 9es for S-109 are currently running ahead of schedule and are expected to remain that way. This has reduced the amount of time we have available to perform the pre-rig operations on S-28A, the next well for N9es. The Sundry for S-28A is dated 1/10/03. Any additional time allowed to conduct the pre-rig work on S-28A would be greatly appreciated. If you have any questions, please call. Thanks, SCANNED JAN 4 2003 Rob Tirpack 564-4166 office 440-8633 cell STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1636' SNL, 1269' EWL, Sec. 35,' T12N, R12E, UM At top of productive interval 3667' SNL, 1384' WEL, Sec. 34, T12N, R12E, UM At effective depth 3629' SNL, 2200' WEL, Sec. 34, T12N, R12E, UM At total depth 3680' SNL, 2622' WEL, Sec. 34, T12N, R12E, UM [] Plugging [] Time Extension [] Perforate [] Pull Tubing [] Variance [] Other ,~' [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 5. Type of well: [] Development I"1 Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 64.86 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-28A 9. Permit Num~ber 195-173 10. APl Number 50- 029-22095-01 11. Field and Pool Prudhoe Bay Field /Prudhoe Bay Pool 12. present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11050 feet 8963 feet 10624 feet 8957 feet Length 110' 2498' 9643' 270' 1234' Size 20" x 30" 13- 3/8" 9-5/8" ii 2-7/8" Plugs (measured) Junk (measured) Baker Open Hole Retainer, cemented in place, TOC at approximately 10624' (05/1996) Cemented MD TVD 8 cu yds (Approx.) 2022 cu ft AS III, 1066 cuft AS II 2068 cu ft Class 'G' 110' 110' 2531' 2531' 9672' 8797' 348 cu ft Class 'G' Uncemented Slotted Liner 9409'-9679' 8563'-8803' 9390'-10624' 8546'-8957' Perforation depth: measured true vertical Slotted Section: 9649' - 9672' Slotted Section: 8777'- 8797' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9455' Packers and SSSV (type and measured depth) 5-1/2" Baker 'SA-3' packer at 9379'; 4-1/2" Otis SSSV Nipple at 2081' 3. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation January 10, 2003 16. If proposal was verbally approved Name o1 approver Date Approved Contact Engineer Name/Number: Rob Tirpack, 564-4166 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service SC NNE_ JAN Prepared By Name/Number: TerSe Hubble, 564-4628 17. I hereby Signed Bill Isaacson ,g is~true and correct to the best of my knowledge ~ ~.,.,-- Title Senior Drilling Engineer Conditions of Approval: Notify Commissio~) representative ma~vitness Plug integrity ~ BOP Test /% Location clearance Mechanical Integrity Test __ Subsequent form required 10- order of the Commission Form 10-40:3 Rev. 06/15/88 ORIGINAL SIGNED BY Date Approval No. _~o_']~-&'~,~ Commissioner Date ~// Submit In Triplioate To: From: Subject: Winton Aubert - AOGCC Date: January 2, 2003 Rob Tirpack - BPXA GPB Rotary Drilling S-28A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well S-28A. The well is currently producing ~a)<a high water cut through an uncemented slotted liner./'l'he proposed sidetrack will cross cut Zone 4 t~ access undrained periphery oil. S-28B is planned as a 4182' sidetrack (3260' in Ivishak reservoir). S-28B is planned as a solid liner completion to preserve the option of selective perforating. /'~ The S-28B sidetrack is currently scheduled for N,,ebbm 9~b/eginning around 1/24/03, after completing S- 109. The pre-rig work for this sidetrack will bl~S'Cheduled immediately after the Application for Sundry is approved. Scope Pre-Riq Work: 1. Pressure test OA to 2500 psi (passed 11/23/02). 2. Pressure test Casing and Tubing pack-offs to 5000 psi 3. Rig up slickli~e. Drift tu.b,i~a~d tag top of 2-7/8" liner. 4. Rig up coil./RIH to 938~.~v1D.,J 5. Bullhead and squee~,e~50 ~ cement into sidetrack and existing perforations. 6. Pull up and contami~ment to 9329' MD. 7. Pressure test cement plug and 9-5/8" casing t~).<30(~0 psi. 8. Rig up e-line. Chemical cut 4-1/2" tubing a~22~D. 9. Fluid pack tubing and OA. Freeze protect 10. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q Operations: 1. MIRU N9es. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from above pro-rig cut. 5. Rig up e-line. Make GR/JB run to top of 4-1/2" tubing stub. 6. MU bridge plug on e-line with CCL. RIH and set at 9130' MD, set as needed to avoid cutting a casing collar. 7. Test wellbore to 3500 psi for 30 minutes. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Mill window in 9-5/8" casing at 9108' MD. POOH 10. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval, building at 5°/100' to a 57° hold angle. 11. Drill ahead to casing point at Top Sag River to an estimated depth of 9,7~C~NED JAN [ z[ 2003 S-28B Application for Sundry 12. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 8958' MD. Displace well to seawater above liner top. POOH. 13. MU 6-1/8" BHA with Dir/GR/Res and RIH to the landing collar. 14. Pressure test wellbore to 3500 psi for 30 minutes. 15. Drill shoe track. Swap over mud and drill 20' of new formation. Perform FIT to 10.0 ppg EMW. 16. Drill the 6-1/8" production interval building at 12°/100' to horizontal, targeting Z4 Ivishak. Drill ahead to an estimated TD of 13,290' MD 17. Run a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" intermediate liner to 9,491' MD. 18. Displace well to clean seawater. 19. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 20. POOH. LD DP and perf guns. 21. Run 3-1/2", 9.2#, 13Cr-80 completion tying into the 4" liner top. 22. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 23. Set and test TWC. 24. ND BOPE. NU and test the tree to 5000 psi. 25. Freeze protect the well to ~2200' and secure the well. 26. RDMO Post-Riq Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-rig Start Date: Estimated Spud Date: Rob Tirpack Operations Drilling Engineer 564-4166 01/1 O/O2 01/24/O3 $C N£D JAN 2003 S-28B Application for Sundry TREE =" 4" CIW WELLHEAD = FM( a CTUATOE = OTIS KB. ELEV = 64.86' BF. ELEV: 36.96' KOP = 3012' Max Angle = 95 @ 11015' Datum MD = 10014' Datum 'rVD = 8800' SS I 13-3/8" CSG, 72#, L-80, ID: 12.347" Id 2531' IMinimum ID = 2.37" @ 9390' TOP OF 2-7/8" LNR S-28A SAI OTES: 3" FLOWLINE IN SKID PORTIONS OF THIS WELL'S FLOWLINE ARE 3" AND SUBJECT TO EROSION. THE GC SHOULD BE NOTIFIED OF ANY WELL OPERATION WHICH COULD INCREASE THE FLOW OR EROSION RATE 2081' H4-1/2. OTIS SSSV NIP, ID= 3.813" 2589' I-F GAS LIFT MANDRELS I TOP OF 2-7/8" LNR Id 9390' ITOPOF 7" LNR Id 9409' 9358' 9359' H 4-1/2" PARKER SWS NIP, ID= 3.813" 9379' H9-5/8"× 5-1/2" BKRSA-3 PKR, ID=4.75" I 9390' IdBKR RUNNING SUBW/GS PROFILE, ID = 3.75" I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id 9459' 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 9672' 19674' Top of Whipstock~" 19716' TOC ~ PERFORATION SUMMARY REF LOG: SPERRY SUN MWD/RLL ON 10/31/90 ANGLE AT TOP PEP, F: 27 @ 9649' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9649-9672 O 05/01/96 9423' 9455' I 9459' fl4-1/2" PARKER SWS X NIP, ! ID = 3.813" (BB-IIND CT LNR) Id4-1/2" PARKER SWS X NIP, ! ID = 3.813" (BEHIND CT LNR) Id4-1/2" TBG TAIL.W/LEG, ! ID = 3.958" (BEHIND CT LNR) HELMD -n- LOGGED 11/23/90 I Perforation Interval-I 9649'- 9672' I 10624' I~ BAKER OPEN HOLE RETAINER, I ~~ ~NOT SET, CMTTO 11050' \, ,"- ,','--.k" / 19682' Btm of Window ''~ 10,6024' MD 2-7/8" Slotted Liner, 6.16#, L-80 10,100' MD I FL4S, 0.00579 bpf, ID=2.37" 7", 26#, L-80, Butt I BCANNED JAN ~, ~: 2003 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/02/91 ORIGINAL COMPLETION 05/02/96 SIDETRACK COMPLETION 03/15/01 SIS-MH CONVER'I'B:) TO CANVAS 03/16/01 SIS-CS FINAL 08/14/01 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: S-28A PERMIT No: 95-1730 APl No: 50-029-22095-01 Sec. 35, T12N, T12E BP Exploration (Alaska) 4" CIW WELLHEAD = FM( ACTUATOI~ = OTIS KB. ELEV: 64.86' KOP = 3012' Max Angle = 95 @ 11015' Datum MD = 10014' Datum'rVD = 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" I'"~ 2531' Minimum ID = 2.37" @ 9390' "'F 2 7/8" I TOP u - LNR I TOP OF 2-7/8" LNR I--~ 9390' ITOPOF 7" LNR I"'~ 9409' S-28A 2081' 1--14-1/2" OTIS SSSV NIP, ID= 3.813" · I2589' +/- 9226' TOC @ +/-9329'I 9358' I-~4-1/2" PARKERSWS NIP, 19=3.813" I 9359' I--~BAKERE-22ANCHORSEALASSY, ID=4.00" 9379' 1~9-5/8"x 5-1/2"BKRSA-3PKR, IO=4.75" I 9390' I---~ BKR RUNNING SUB W/GS PROFILE, ID= 3.75" 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I--~ 9459' 9423' 9455' I 9459' I---~4-1/2" PARKER SWS X NIP, ! ID = 3.813" (BEHIND CT LNR) I--~4-1/2" PARKER SWS X NIP, ID= 3.813" (BEHIND CT LNR) I-~ 4-1/2" TBG TAIL W/LEG, ! ID = 3.958" (BEHIND CT LNR) 9-5/8" CSG, 47#, L-80, ID = 8.681" I"'~ 9672' 9674' Top of Whipstock Perforation Interval- 9649'- 9672' I 10624' BAKER OPEN HOLE RETAINER, NOT SET, CMT TO 11050' 197 6' TOG I---- 9682' Btm of Window k'110'100' MD 7", 26#, L-80, Butt 110,6~24' MD 2-7/8" Slotted Liner, 6.16#, L-80 FL4S, 0.00579 bpf, ID=2.37" Date Rev By Comments .... [:;RUDHOE BAY UNIT WELL: S-28A 10-7-02 RBT Final Pre-Rig PERMIT No' APl No: Location: Sec. 35, T12N, R12E GPB Rotary Drilling S'28B Nipple with 2.813" bore @ +/- 2200' MDI 9-5/8" X 7' Baker xxxx Liner Hanger w/xx Running Tool, ZXP Liner Top Packer and TBR @ +/- 8958' ITop of Window @ 9108' MDI I Btm of Window @ 9,126' MD l'op of BP @ 9130'I 9-5/8", 47#, L-80 -- 3-1/2", 9.2# 13CR80, VAM ACE Production Tubing 7" X 3-1/2" Baker SABL-3 I Packer @ +/- 9,491' MD I 7" X 4-1/2" Baker XX Liner Hanger w/ZXP Liner Top Packer and TBR @ +/- 9591' MD 7", 26#, L-80 9741' MD / 8761' TVD 4-1/2", 11.6#, '-~ol 13,297' MD / 8928'I S~NED JAN Date Rev By Comments PRUDHOE BAY UNIT WELL: S-28A 10-7-02 RBT Proposed Completion PERMIT No: APl No: 50-029-22095-01 Location: Sec. 35, T12N, R12E GPB Rotary Drilling P E RM I T DATA 95-173 GR/CCL/PERF 95-173 7328 AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~/MWD SLIM1-GR Page: 1 Date: 05/13/98 RUN 1 DATE RECVD -- 05/21/96 07/12/96 10-407 R COMPLETION DATE ~-/~ / ~ DAILY WELL OPS R 4//~ /qb / TO ~-//, / {~/ Are dry ditch samples required? yes ~ And received? Was the well cored? Are well tests required? yes ~_Received? Well is in compliance Initial COMMENTS yes ~zAnalysis & description received? BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date' October 31, 1996 Attention' Steve McMains Subject: Revised Completion Reports for Wells S-28A, S-02A, D-17A, R-39A A quality check of our surveys found that incorrect surveys were submitted for the wells S-28A, S-02A, D-17A, and R-39A. A miscommunication between vendors resulted in outdated geomagnetic models being used. The problems have been resolved and the survey data recalculated. The enclosed Completion Reports show the revised bottomhole locations. Corrected surveys are attached, and are the true and correct surveys for these wells. If there are any questions please contact me at 564-5894. Thank you. Sincerely, Theresa Mills Coiled Tubing Technical Assistant 3 -- STATE OF ALASKA '~ ALASKA O,-AND GAS CONSERVATION COM'rv~;SSION ,FELL COMPLETION OR REOOMP LETION REPORT AND LOG ~. Status of Well Classification of Service Well OIL [] GAS [] SUSPEh~ED [] ABANDONED [] SERVICE [] !:~. Name of Operator 7. Permit Number BP Exploration 95-173 3. Address 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-22095-012 7/8 ;4. Location of well at surface 9. Unit or Lease Name -~' ............... '-'" Prudhoe Bay Unit 1636' SNL, 4011'WEL, Sec. 35, T12N, R12E :j; ~:;t-~.'.....'~..,; .?. ~ At Top Producing Interval~.' ~¢~";':,~,,.~r....~.' I! 10. Well Number 3678' SNL, 14402' WEL, Sec. 34, T12N, R12E ~ ~ ,-~'f'~ i S-28A At Total Depth ~: .('A~ i 11. Field and Pool ....... Prudhoe Bay Field/Prudhoe Bay Pool 3689' SNL, 2620' WEL, Sec. 34, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 64.86 028287 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4/18/1996 4/30/96 5/2/96I n/a feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11050'MD, 8902'TVD 10624'MD, 8891'TVD YES [] NO []I n/a feet MD 1900 appx 22. Type Electric or Other Logs Run Gamma Ray 23. CASING, LINER AND CEMENTING RECORD SE'I-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-I-OM HOLE SIZE CEMENTING REC_,ORD AMOUNT PUl I ED 2 7/8" 6.16 L-80 9390 10624 3 3/4" Uncemented slotted liner 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9649'-9672' 8711'-8732', 3-3/8", 6spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10649'- 11050' 10 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) 6/3/96 GL Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ct oil, gas or water. Submit core chips. ?' .... ! ~i~,,.i..~ ~,',.;; .;. , .... ¢., ..:, !.. , ;; Form 10-407 ...... : Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. 30. GEOLOGIC MARKERS FOR .... lION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH GOR, and time of each phase. Sag R 9635' 8699'ss Shub/ik 9682' 8741 'ss Ivishak 9 754' 8806'ss 31. LIST OF A-I-I-ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge c~~~ Tubinq Driflinq En_qineer 10/21/96 Signed . ~ Title Coiled _ _ Date ( ,/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 S-28A Anadrill .... **************** Survey Program .................... Company Well Name Location 1 Location 2 Magnetic Declination Magnetic Model Magnetic Model Date Grid Convergence Angle Grid Zone KBE Date Anadrill Job Number AFE APl BP Exploration S-28A Prudhoe Bay North Slope Borough, Alaska 28.30 deg IGBG-95 4/16/96 Alaska State Plane Zone 4 64.86 ft 10/2/96 37891 F51 S28 50-029-22095-01 Well Head Location Grid X 619431.55 Grid Y 5979855.11 Lat (N/-S) 70° 21' 12.938" Long(E/-W) -149° 01' 48.621" 70.35359391 -149.03017256 Azimuth from Tie-In to TD is Departure from Tie-In to TD is 268.06 1272.83 deg ft Tie-In Point (TIP) Measured Depth True Vert Depth Inclination Azimuth Latitude (N/-S) Departure (E/-W) 9672.95 ft 8797.96 ft 26.73 deg 246.94 deg -2005.22 ft -2582,08 ft ********** Note: All Directions & Coordinates are referenced to TRUE North .......... Anadrill - Schlumberger Alaska District S-28A Anadrill Survey Calculations Minimum Curvature Method Measured Interval Vertical Target Station Azimuth Latitude Departure Displacement at Azimuth DLS Depth Depth Section Incln. +N/-S +E/-W ft ft ft ft deg deg ft ft 9672.95 0.0 8797.96 2648.62 26.73 246.94 -2005.22 -2582.08 9685.30 12.3 8808.86 2654.03 29.30 246.94 -2007.49 -2587.42 9699.60 14.3 8821.09 2660.98 33.10 248.99 -2010.26 -2594.28 9702.30 2.7 8823.34 2662.40 34.20 248.55 -2010.80 -2595.68 9712.80 10.5 8831.89 2668.10 36.70 246.43 -2013.14 -2601.30 deg/ ft deg 100ft 3269.25 232.17 0.00 3274.86 232.19 20.81 3281.99 232.23 27.59 3283.42 232.24 41.73 3289.30 232.26 26.53 9723.00 10.2 8839.79 2674.16 41.70 249.86 -2015.53 -2607.28 9733,00 10.0 8847.24 2680.50 42.10 249.86 -2017,82 -2613,55 9740.30 7.3 8852.66 2685,15 42.00 249,79 -2019.51 -2618.14 9752.50 12.2 8861,62 2692.99 43.40 249.32 -2022.40 -2625.90 9762,70 10.2 8868.84 2699.80 46.50 248.76 -2024,98 -2632.62 3295.49 232.29 53.41 3301.86 232.33 4.00 3306.52 232.36 1.51 3314.43 232.40 11.77 3321.33 232.43 30.64 9772.10 9.4 8875.16 2706,36 49.00 248.45 -2027,52 -2639.10 9782,40 10,3 8881,72 2713.87 51.90 249.70 -2030,35 -2646.52 9792.30 9.9 8887.65 2721,37 54.50 248.54 -2033.18 -2653,92 9802.30 10.0 8893.25 2729,16 57.40 247,94 -2036.25 -2661.62 9812.30' 10.0 8898,37 2737.25 61.00 248,94 -2039.41 -2669.61 3328.02 232.47 26.71 3335.62 232.51 29.67 3343.22 232.54 27.89 3351.20 232.58 29.42 3359.46 232.62 37.01 9822.20 9,9 8902.91 2745.57 64,30 249.24 -2042.54 -2677.82 9832.30 10.1 8907.04 2754.31 67.50 249,87 -2045.76 -2686.46 9842.20 9,9 8910,57 2763,11 70.70 250.47 -2048,90 -2695,16 9852,30 10.1 8913.66 2772.28 73.70 250.74 -2052.09 -2704.23 9862,20 9,9 8916.17 2781.45 76.90 251.61 -2055.18 -2713.29 3367.89 232.66 33.44 3376.71 232.71 32.19 3385.54 232.76 32.82 3394.69 232.81 29.81 3403.78 232.86 33,42 9873.00 10,8 8918.27 2791,63 80,70 252.62 -2058.43 -2723.37 9882.30 9.3 8919.51 2800.54 83.90 253.75 -2061.10 -2732.19 9892.00 9.7 8920.35 2809,93 86,20 255.21 -2063.68 -2741,50 9910,60 18.6 8921.24 2828.34 88.30 267.25 -2066.51 -2759.83 9925.60 15.0 8921.79 2843.33 87,50 268.15 -2067.11 -2774.81 3413.78 232.92 36.36 3422.42 232.97 36.45 3431.42 233.03 28.05 3447.77 233.17 65,63 3460.13 233.32 8.02 9945.30 19,7 8922.84 2863.00 86.40 268.75 -2067.64 -2794.47 9965,50 20.2 8924,32 2883.14 85.20 270.05 -2067.85 -2814.61 9986.10 20.6 8926.24 2903.63 84,10 270.95 -2067,68 -2835,12 10005.30 19,2 8928,38 2922.67 83.10 273,05 -2067.01 -2854.19 10026.00 20.7 8930.98 2943.10 82.50 274,65 -2065.63 -2874,68 3476.23 233.50 6.36 3492.57 233.70 8.75 3509.02 233.90 6.89 3524.05 234.09 12.05 3539.86 234.30 8.20 Anadrill - Schlumberger Alaska District S-28A 10045,30 19,3 8933,46 2962,10 82,70 275,35 -2063,96 -2893,75 10065,30 20,0 8935,88 2981,74 83,40 277,25 -2061,78 -2913,48 10085,40 20,1 8938,19 3001,45 83,40 277,25 -2059,26 -2933,29 .10105,70 20,3 8940,42 3021,31 84,00 279,25 -2056,37 -2953,25 10125,20 19,5 8942,37 3040,31 84,50 280,35 -2053,07 -2972,37 3554.39 234,50 3,74 3569,22 234,71 10.06 3583,95 234,93 0,00 3598,66 235,15 10.23 3612,49 235,37 6,17 10145,80 20,6 8944,24 3060,39 85,10 279,25 -2049,57 -2992,59 10165,40 19,6 8945,69 3079,55 86,40 279,65 -2046,37 -3011,87 10185,40 20,0 8946,76 3099,05 87,50 281,45 -2042,71 -3031,50 10230,30 44,9 8948,52 3142,73 88,00 281,05 -2033,96 -3075,50 10250,30 20,0 8949,20 3162,22 88,10 280,85 -2030,16 -3095,13 3627,17 235,59 6,06 3641,28 235,81 6,94 3655,50 236,03 10,54 3687,23 236,52 1,43 3701,53 236,74 1,12 10270,30 20,0 8949,88 3181,73 88,00 280,25 -2026,50 -3114,78 10290,40 20,1 8950,51 3201,39 88,40 279,75 -2023,01 -3134,56 10310,30 19,9 8950,98 3220,88 88,90 279,45 -2019,69 -3154,18 10329,90 19,6 8951,29 3240,13 89,30 278,25 -2016.68 -3173,54 10349,80 19,9 8951,53 3259,73 89,30 277,65 -2013.93 -3193.25 3715,98 236,95 3,04 3730,69 237,16 3.18 3745,40 237,37 2,93 3760,10 237.57 6,45 3775,28 237,76 3,01 10370,30 20,5 8951,82 3279,97 89,10 276,75 -2011,36 -3213,59 10390,40 20,1 8952,12 3299,85 89,20 276,15 -2009,10 -3233,56 10410,30 19,9 8952,38 3319,57 89,30 275,35 -2007,11 -3253,35 10430,30 20,0 8952,68 3339,41 89,00 275,15 -2005,28 -3273,27 10450,40 20,1 8952,99 3359,38 89,20 273,95 -2003.68 -3293,30 3791,13 237,96 4,50 3806,88 238,15 3,03 3822,67 238,33 4,05 3838,67 238,51 1,80 3854,94 238,68 6,05 10470,40 20,0 8953,34 3379,28 88,80 273,05 -2002.46 -3313,26 10490,20 19,8 8953,75 3399,01 88,80 273,05 -2001,41 -3333,03 10520,30 30,1 8954,12 3429,01 89,80 271,95 -2000,10 -3363,10 10560,30 40,0 8954,75 3468,93 88,40 271,05 -1999.05 -3403.08 10600,20 39,9 8955,86 3508,79 88,40 269,15 -1998,98 -3442,96 3871.38 238,85 4,92 3887,76 239,02 0,00 3912,90 239,26 4.94 3946.79 239,57 4,16 3981,19 239,86 4.76 10630,30 30,1 8956,89 3538,87 87,70 268,55 -1999,58 -3473,04 10660,20 29,9 8957,88 3568,75 88,50 267,95 -2000,49 -3502,90 10689,90 29,7 8958,58 3598,44 88,80 267,45 -2001,69 -3532,57 10720,30 30,4 8959,40 3628,83 88,10 266,55 -2003,28 -3562,92 10750,30 30,0 8960,69 3658,77 87,00 264,95 -2005,50 -3592,81 4007.53 240.07 3.06 4033.90 240.27 3.34 4060.27 240.46 1.96 4087.48 240.65 3.75 4114.64 240.83 6.47 10804,20 53,9 8963,79 3712,45 86,40 263,05 -2011,12 -3646,32 10862,60 58,4 8967,86 3770,26 85,60 259,15 -2020,13 -3703,87 10895,00 32,4 8969,14 3802,17 89,90 257,65 -2026,64 -3735,57 10925,30 30,3 8969,08 3832,04 90,30 259,05 -2032,76 -3765,25 10965,10 39,8 8968,28 3871,37 92,00 259,75 -2040,08 -3804,36 4164.16 241.12 3.69 4218.95 241.39 6.80 4249.91 241.52 14.05 4278.92 241.64 4.81 4316.83 241.80 4.62 10995,30 30,2 8966,83 3901,25 93,50 260,45 -2045,27 -3834.07 11015,70 20,4 8965,38 3921,45 94,70 261,85 -2048,40 -3854,18 4345.48 241.92 5.48 4364.70 242.01 9.03 .............. ****** End Of Survey *** .....******* ..... Anadrill - Schlumberger Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) July 11, 1996 TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD SLIM1 GR for well S-28A, Job # 96185, was sent to: BP Exploration (Alaska) Inc. 1 OH LIS Tape Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 State of A!_.aska _A,nSka-Oi-F& Gas Conservation : Howard Okland 01 Porcupine Drive nchorage, AK 99501 1 OH LIS Tape ". ARCO Alaska, Inc. Dede Schwartz, ATO-1336 Attn: Records Processor Anchorage, AK 99510-0360 1 OH LIS Tape Exxon Company U.S.A. Alaska Interest Organization Attn: Susan Nisbet 800 Bell Street, EB3083 Houston, TX 77002-7420 1 OH LIS Tape Phillips Company Attn: Marty Gray, Room B-2 P.O. Box 1967 Houston, TX 77251-1967 1 OH LIS Tape PLEASE NOTE: NO DEPTH SHIF-i'ING PER STEVE JONES PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)lng Petrotectnical 900 E. Benson:~'~' .~-~'''~'~i~'~ Anchorage, Alaska 99519-6612 JUL 2 Date Deliv~ &~.chora§e Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL)MMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPI~IDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-173 3. Address 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 5o-029-22095-012 7/8 4. Location of well at surface 9. Unit or Lease Name 1636' SNL, 4011'WEL, Sec. 35, T12N, R12E i': i~,~ii.:~i~iZ~.~/;.~ ~-'~..~ Prudhoe Bay Unit ~ ...... ~ ..... ~u..f ~-!~ ~':~ ~?~!~. .... ~ 10. Well Number At Top Producing Interval ~,~.?,~-'~'£i~J!~ ~~~ ~.~ 3678' SNL, 14402' WEL, Sec. 34, T12N, R12E? '~-"/~- ~-~- ~'-' S-28A ~: ,~.~>,---, ~: 11 Field and Pool At Total Depth ~-'-.'-~,~'~.~ ~ - Prudhoe Bay Fiel~Prudhoe Bay Pool 3712' SNL, 2553' WEL, Sec. 34, T12N, R12E 5. Elevation in feet (indi~te KB, DF, etc.) ~6. Lease Designation and Serial No. 64.86 ]028287 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~15. Water Depth, if offshore ~16. No. of Completions 4/18/1996 4/30/96 5/~96~ n/a feet MSLJ one 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D] 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickness of Pe~afr~t 11050'MD, 8902'~D 10624'MD, 8891'TVD ~ ~ ~ ~~ n/afeet MD 1900 appx 22. Type Electric or Other Logs Run Gamma Ray 23. CASING, LINER AND CEMENTI~ R~ S~ DE~ MD CASING SIZE ~. PER ~. G~E TOP ~ ~LE SIZE C~l~ ~ ~OUNT PU~ED 2 7/8" 6.16 L-80 9390 10624 3 3/4" Uncemented slo~ed liner 24. Perorations open to Produ~ion (MD+TVD of Top and Bottom and ~5. ~BI~ RE~ inte~al, size and number) SIZE DEP~ S~ {MD) PACKER S~ {MD) , 9649~9672' 8711~8732', 3-3/8", 6spf 26. ACID, F~C~RE, CEME~ ~UE~E, ~C. DEPTH INTERV~ (MD) AMOUNT & KIND OF MATERIAL 10649'-11050' 10 bbls cement ,,, ~27. P~DUCTION TEST Date First Production lMethod of Operation (Flowing, gas lift, etc.) 6/3/96~ GL Date of Test Hours Tested P~UCTION FOR OIL-BBL GAS-MCF WATER-BBL C~SI~ IGAS-OIL RATIO TEST PERIOD '~low Tubing Casing Pressure 0~CU~TED~ OIL-BBL GAS-MCF ~ATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ORIGINAL R[C iV D JUN 1 7 igg~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKEho FORMATION TESTS NAME .... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , , Sag R 9635' 8699'ss Shublik 9682' 8741 'ss Ivishak 9754' 8806'ss RECEIVED 31. LIST OF Aq-I'ACHMENTs ........ ...... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ^-~~~ Title Coiled Tubino Drillina Enoineer Date 6/12/96 ........... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Well: S-28A Field: Prudhoe Bay APl: 50-029-22095-01 Permit: 95-173 Daily Operations Accept: Spud: Release: CTD Unit: 4/16/9 4/18/96 5/2/96 4985 Date: Day: Depth: 4/1 6/96 1 9692 Moved unit to S-28. Rigging up. 4/17/96 2 9692 Rig up Camco coiled tubing drilling unit #4985. Set in sub-structure, pick up tower sections. Run lines and hoses. 4/18/96 3 9755 Drill to 9735'. Anadril MWD quit getting signal. Ream out dog-leg to attempt to restore signal from Anadril (appears Anadril tool quits getting signal as dog-leg severity approaches 40°/100'). Pulled out. Found pulsar tool not working properly. Change pulsar tools and run smaller diameter impeller on pulsar. Run back in hole. Wash back to btm and orient tool face. Today's cum cost updates well cost for estimated well prep charges. 4/19/96 4 9798 Increase pump rate to attempt to get better signal from Anadril tools. Re-survey open hole section. Evaluate survey accuracy. POOH to change out Anadril tool. Replace impeller on pulsar. Check readings. Run back in. Orient toolface and continue drlg, building angle. 4/20/96 5 9910 Continue drlg building angle. Loosing 10-15 bbl mud per hour @ 2.5 bpm ciro rate. Try dropping rate to 2 bpm then Anadril having trouble getting signal. Started laying over toolface to 30r @ 9885. Turned over to 65r @ 9885. Drill to 9910, unable to make further hole. POOH to check tools. Azimuth readings also not looking to reliable. 4/21/96 6 9991 Ran in hole with BHA containing extra 5 ft monel between tool monel and monel mtr. Re-surveyed previously drilled hole. Same readings as before. Tried to drill ahead. Motor plugged. Pulled out. Found bottom few inches of stator tore off and plugged motor. Changed out to new Anadril tool package. Picked up new motor (3/4 deg bend). Ran back in. Took check shots in previously drilled hole. Azimuth still not very good. Drilled further. Azimuth readings cleaned up. Azimuth reading 10 deg higher than predicted. Continued drilling to 9991 ft. Loosing 20 bph mud. Treated hole w/ 14 sack mica. Keep in system. Losses improving slowly. 4/22/96 7 10455 Drill ahead and survey. Orienting as necessary. Pull GR log from 9820'-9891'. Short trip to keep hole clean. Drill ahead. Got partial diff stuck at 10265. Pulled free. Performed another wiper trip to whipstock-no tight spots. Drilled ahead, continued to be sticky after stops for surveys. Pulled heavy again at 10288. Mud losses variable from 2 to 20 bph. Currently averaging 10 bph. Drilled ahead to 10455, building .5 deg/100 and turning +/- 4 deg/100. 4/23/96 8 10800 Drilled to 10555. Got differentially stuck while taking survey. Worked pipe. Pumped 68 bbl dead crude. BHA popped free w/6 bbl crude around bit. Pulled into 7 inch and circulated out crude and discarded same. Washed to btm and continued drlg to 10800, Drilled shale stringer from 10630 to 655. Well continued to loose mud @ average 10-12 bbl/hr. Sands drlg easily. 4/24/96 9 10854 Lost 40% returns at 10802'. Pulled into csg. Spotted 30 bbl 30#/bbl LCM pill across open hole. Soaked and squeezed to 300 psi. Washed back to bottom wi full returns. Drilled to 10811' and lost full returns. Spotted 30 bbl 30#/bbl LCM pill. Squeezed to 850 psi. Full returns. Tagged whipstock and discovered 43' shallow. Corrected TD is 10854' washed to 10543'. Logged from 10543'- 10663'. MWD quit. Raised rate, circ pressure increased 300 psi. Vary rates. Plugging indicated. POOH. MU BHA #4. 4/25/96 1 0 1 0854 MU BHA #4. Pt and run in. Orient tool face in 7 inch. Drop into open hole and log across whipstock to correct depth. Wash down to btm. Tag btm @ 10858 MD Try to continue drilling. Had problems locking onto MWD signals. Losses on bottom as soon as bottom was tagged. Worked pipe on bottom and returns gradually improved to 31% . Very hard drilling on btm. Finally started making a little progress. Returns not improved. Drilled to 10868 MD Surveys now showing 300° azimuth (survey package on bottom, same configuration as in S-02a, suspect they're in error by 30°). Erroneous surveys designated by an * Stopped drilling and mixed and pumped LCM pill #3. Sqzd pill to 800 psi w/6 bbls. Drilled ahead to 10892 wi avg. losses of 25%. Losses increased to 75% then leveled off at 40%. Tried drilling another foot, 75% losses. Pumped LCM pill #4 and drilled with it. PUH and sqzd to 1000 psi. Losses improved to 25%. MWD stopped working. Plugging indicated. POOH. 4/26/96 11 10907 Ld BHA #4. Test BOP's while inspect Anadril tools. Piece of junk metal from mud system jammed the pulsar tool. LCM material also around the pulsar turbine. P/t'd remaining tool string-leaking. Inspect tools. Circ sub partially sheared and leaking. Replace circ sub and orienter. Reconfigured Anadril tools with GR on bottom. Also moved poney monel collar from above motor to below orienter. Ran back in hole. Resurveyed at 10858'. Azimuth back to 265+/-°. (the MWD with the survey package on bottom is reading incorrectly). Tagged at 10893'. Drilled to 10907'. Plugged. POOH. MWD plugged in the closed position with small pebbles and LCM debris. Flushed coil and BJ pump. MU BHA #6. Plugged again while RIH. POOH. Re-circulate suction pits through the centrifuge. Install finer screens in suction strainer and MU manifold. 4/27/96 1 2 1 0907 Install finer screens in suction strainer and MU manifold. Circulated pits over shaker and centrifuge same. Pt baker tools and orienter while clean mud. PU Anadril tools and motor. RIH. Fixed reel jacks on way in. Lost full returns by the time the BHA got to the 7 inch liner. Mix 25 Ib./bbl pill Pumped 15 bbls (10 ppb fine mica, 15 ppb liq csg). No response. 100% lost returns. MWD plugging again. POOH. Ld drilling BHA. RIH w/ nozzle. Mix hi-vis pill with chromic acetate x-linker 4/28/96 1 3 1 0938 Mix hi-vis pill with chromic acetate x-linker. Ran in hole w/ nzl. Pumped 50 bbl x-link rio-pro. Cooled dwn open hole w/200 bbl of rio-pro. (estimated BHCT @ 170°) set nzl at 10800 ft. Squeezed 35 bbl of XL away. Whp rose from 205 psi while bullheading mud to 500 psi at end of sqz. Left 15 bbl of XL in open hole and 7 inch liner. Pulled out, replacing coil displacement with mud not to disturb squeeze. Circulated surface mud again to remove small rocks that have been plugging the Anadril tool. Picked up the drilling string and washed back to bottom. Losing returns while RIH. Down 4 hours to repair Anadrill display. On bottom losses were 60%. Switched to slick seawater. Drilled to 10917'. Returns initially had some x- link goo. 5k# over pull off bottom. Pumped 10 bbl rio-pro sweep. Over pull improved, but still a little sticky. GR quit working. Drill to 10927', pumping sweeps. Not drilling off. Losses improved to 25%. Circulating seawater returns across the shaker, but not through centrifuge. Wiper trip back to the window. Clean. Drilled hard spot at 10927'. Possible pyrite nodule. Drilled ahead pumping sweeps. 25% losses. RECEIVED 4/29/96 1 4 1 1000 Drilled ahead pumping sweeps. 25% losses. Over pull up to 10870', possible loss zone. Tried to orient. Unable to do so. Try at rates up to 3.5 bpm. Also tried w/mud inside BHA. No success. Also not getting GR signals- GR module down. Spotted mud in open hole and pulled out. Found GR module dead, orienter oriented. Change out anyway. Blank off jets on bit to increase BHA pressure drop. RIH w/BHA #10. Check Anadrill signal at 3500'. No good. POOH. Down 2 hours to repair reel. Change out to larger impeller. Check tools at surface. OK. MU motor. Check signal at 2500'. Very noisy due to vibration. Tagged whipstock on depth while RIH. Tagged TD at 10944'. No correction made. Logged from 10850' - TD. Drilled ahead, short tripping every 10'. Pumping sweeps every 20'. 25% - 30% losses. Short tripped with sweeps. 3k# - 5k# drag for 50' - 55'. Wiper trip to window every 50'. A few tight spots (3k# - 4k#) in the horizontal section, but pretty clean. Sweep with mud on the way down. 4/30/96 1 5 1 1 050/1 0650 Drilled ahead, short tripping every 10'. Pumping sweeps every 20'. 25% - 30% losses. Short tripped with sweeps. 3k# - 5k# drag for 50' - 55'. Wiper trip to window every 50'. A few tight spots (3k# - 4k#) in the horizontal section, but pretty clean. Sweep with mud on the way down. Drilled from 11000 to 11050, making frequent short trips. Continued to build angle. Decision made to stop drilling @ 11050 cleaned up open hole and liner with several high vis pills. Washed out of hole. Laid down drill string. RIH w/ IBP. Position IBP element at 10649'. Cool down with 230 bbls seawater. Initial inj was 1.5 and 2.0 bpm @ 300 psi. Final inj was 2.1 bpm/245 psi. Pump 10 bbls cement. Pressured up and retainer pumped off coil as soon as cement hit it. Squeezed remaining cement away to a final pressure of 1550 psi, while recip pipe up to 10603'. Some over pull. Opened chokes and chased OOH. 5/0 1/96 1 6 1 0624 POOH. Ibp sheared off as expected. Put on 3-1/16 nzl. RIH . Set depth by flag. Washed to btm with frequent short trips. Tagged btm @ 10624. Firm bottom. Layed in fresh flowpro mud in open hole and 7 inch liner. P-test open hole to 500 psi. Bled 100 psi/10 min. POOH. Ld lubricator sections. R/U Atlas press equip, RIH with gun #1, 20 ft, 3 3/8", 6 spf, tie-in and perforate from 9649 - 9669 ft bkb. POOH All shots fired, whp = 0. RIH with gun #2, 10 ft. 5-02-96 1 7 1 0624 RIH with gun #2, 3 3/8" x 10 ft, 6 spf. Tie-in with jewelry log and perforate 9662 - 9672 ft bkb, btm shot located 2 ft above top of whipstock tray. Total interval perforated was 9649 - 9672 ft bkb. POOH. R/d Atlas, r/u Camco to run slotted 2 7/8" liner. Run guide shoe, 41 its slotted and 1 joint solid liner. Pu lubricator sections. Recover MeOH. Mu GS spear and Baker deployment sub. Total liner length is 1233.79'. RIH with slotted liner to PBTD of 10,624 ft with no problem. Release from liner with GS release on first attempt at 1.5 bpm leaving top of liner at 9390 ft bkb. POOH. Freeze protect ct and tubing. R/d Baker tools and lubricator sections. R/d surface hoses and lines. *********** SURVEY PROGRAM *********** COMPANY BPX ALASXA INC, WELL NAME S-28A LOCATION 1 PRUDHOE BAY UNiT LOCATION 2 ALASKA MAGNETIC DECLINATION 28.75 GRID CONVERGENCE ANGLE 0,00 DATE: 29-APR-% WELL NUMBER 0 AP! NO 50-029-22095-0! AFE NO FS128A WELL HEAD LOCATION: LAT' AZIMUTH FROM ROTARY TABLE TO TARGE! iS TiE IN POINT(TiP) : M£ASURED DEPTH 9673,00 TRUH VERT DEPTH 8733,10 INCLinATION ~',70 AZIMUTH 244,00 LATITUDE(N/-S) -2046,10 DEPARTURE(E/-~> -2549,90 DEP(E/-~) -t47+00 270,00 * = AZIMUTH iNTERPOLATED BY DRiLEX DO- DUE TO MAGNETIC iNTZRFERHNCE FROM MUD MOTOR RECEIVED ,JL!F,I l'~' 'i99G AIask~ Oil & 0~ Uu~. Commi~;o~ PAGE NO, 2 S-28A **********~** ANADRiLL ************** oURVE ~ ~LCuLM~ iONS ************* .... CIRCULAR. .R~* ~ ME?HOD******** MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 9673,00 0,0 8733,!0 9685,30 12,3 8743,96 9699,60 14.3 8756.19 9702,30 2,7 8758,44 97i2,60 i0.5 8766,99 TARGET STATION AZIMUTH LATITUDE SEC?ION tNCLH, N/-S ft deg de~ ft 0,00 26.70 246,00 -2046,10 5,27 29,30 246,00 -2048,45 12,i3 33,10 249,44 -2051,24 13,53 34,20 249,00 -2051,78 19,17 36,70 246,88 -2054,07 DEPARTURE DISPLACEMENT it ft ft -2549,90 3269,33 ~ 17 3274,91 -2)62,03 3282,01 -2563,43 3283,44 -2569,07 3289,27 AZIMUTH - 231,26 231,25 231,32 231,33 231,36 DLS ~eg/ lOOft 0,00 2!,14 29,34 41,72 26,53 9723,00 9733,00 9740,20 9762,70 10,2 8774,89 10,0 8782,34 7,3 8787,76 i2,2 8796,72 t0,2 8803,?4 25,i7 41,70 250,31 -2056,4! 31,46 42,!0 250,31 -2058,66 36,06 42,00 250,24 -2060,3! 43,84 .o'~.40 . 249,77 -2063,14 50,59 46.50 249,21 -2065,66 -2575,07 3295,42 -258!,36 3301,74 -2585,96 3306,.37 -2..,9...., 74 3314,21 -2600,49 3321 231,39 23i,43 231,45 231,50 231,54 53,41 4,00 1,53 !1,77 30,64 9772,i0 9792,30 9802,30 9812,30 9,4 8810,26 10,3 8816,82 9,9 8822,75 10,0 8828,35 10,0 8833,47 57,08 49,00 248,90 -2068,!5 64,52 51.90 250,15 -2070,93 71,95 54,50 248,99 -2073,69 79,67 57,40 248,39 -2076,70 87,68 61,00 249,39 -2079,80 -2606,98 3327,70 231,57 26,71 -2614,42 3335,26 231,62 29,67 PA , ~ . -_.21 85 334~,80 231,A6 27,89 -2629,57 3350,72 231,70 29,42 -2637,58 3358,93 231,74 37,0! 9822,20 9832,30 9842,20 9852,30 9862.20 .. o o 02 9,V 10,i 8842,14 9,9 8845,67 10,i 8848,76 9,9 885!,27 95,92 64,30 249,69 -2082,87 104,58 67,50 250,32 -2086,02 !13,30 70,70 250,92 -2089,09 i22,40 73,70 251,19 -2092,21 ...lql,49. 7A,90.. 2~.=, OA. -2095,23 -2645,82 3367,30 231,79 33,44 -265~,48. ~.~v~,Og. 231,84. 32,19 -2663,20 3384,81 231,89 32,81 -2672,30 3393,90 23i,94 2~,81 -2681,39 3402,91 232,00 33,42 9873,00 9882,~0 9892.00 9910,60 9925,60 !0,8 8853,37 9,3 8854,6! 9,7 ' ~ ~ 18,6 8856,34 15,0 8856,89 141,59 80,70 253,07 -2098,40 i50,43 83,90 254,20 -2101,00 159,76 86,20 ~,AA..~ ..-2103,51 178,11 88,30 267,70 -2106,19 193,09 87,50 268,60 -2106,67 -?Agl 49 ~ ~ A3 .... -2700,33 342!,40 -2709,66 3430,31 -2728,01 3446,46 -2742,99 3458,63 232,06 232,12 232,1~ ~3~,33 232,4E, 36,36 36,46 28,05 65,63 8,02 9945,30 9965,50 9986,10 10005.30 10026.00 19,7 8857,94 20,2 8659,42 20,6 886i,34 19,2 8863,48 20,7 8866,08 212,76 86,40 269,20 -2107,05 232,9i 85,20 270,50 -2107,1! 253,41 84,10 271,40 -2!06,77 272,48 83,10 273,50 -2105,95 292,95 82,50 275,10 -2104,41 -2762,66 3474,47 -2782,8! 3490,55 -2803,31 3506,71 -2822,38 3521,48 -2842,85 3537,00 232,87 232,87 233,07 233,27 233,49 6,36 8,74 6,89 12,05 8,20 10045,30 10065,30 10085,40 10105,70 !01 ~'20 19,3 8868,56 20,0 8870,98 20,1 8873,29 20,3 8875,52 19,5 8877,48 3i2,01 82,70 275,80 -2102,59 33!,72 83,40 277,70 -2100,26 35!,5i 83,40 277,70 -2097,58 371.45 84,00 ~.9,/0 -2094,53 390,54 84,50 280,80 -2091,08 -2861,91 3551,25 233,70 3,74 -2881,62 3565,79 233,91 10,06 -2901,41 3580,23 234,13 0,t0' -2921,35 3594,63 234,36 10,23 -2940,44 3608,16 234,58 6,17 10145.80 10165,40 10185,40 10230,30 10250,30 20,6 8879,34 19,6 8880,79 90,0 ~i 8A 44,9 8883,62 20,0 8884.30 410,73 65,10 279,70 -2087.43 429,99 66.40 280.10 -2084,07 449,59 87,~* ~ ,. . .v ~81 ~0 -2080,2A 493,52 88.00 281.50 -207i.16 513,12 88,i0 28!,30 -2067,21 -2960,63 3622,53 -2979,89 3636,35 -2999,49 3650,26 -3043,42 368!,~ ~ -3063,~2 3~V5,32 234,81 235,03 235,26 235,76 235,98 6,06 6,93 !0,54 1,43 1,11 PAG~ NO, MEASUREDiNTERVAL V£RTICAL DEPTH DEPTH ft ft ft , 10270,30 20,0 8884,98 10290,40 20,i 8885.62 ~n ~ 19,9 8886,08 10329,90 t9,6 8886,39 10349,80 19,9 8886,63 10370.30 10390,40 10410,30 10430,30 10450,40 10470.40 10490,20 10520,30 10560,30 10600,20 10630,30 10660.20 10689,90 10720,30 10750,30 10804,20 ~ 60 10925,30 10965.10 10995.30 11015,70 20,5 8886,72 20,1 8887,22 19,9 8887,48 20,0 8887,78 20,1 8888,09 20,0 8888,44 30,1 8889.22 .,, "' 39,9 8890,77 30,! 889i,99 29,9 8892,98 29,7 8893,68 30,4 8894,50 30,0 8895,79 53,9 8898.89 58,4 8902,96 32,4 8904,24 30,3 8904,18 39,8 8903.38 30,2 8901,93 20,4 u,O0,4~ ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC TARGET STATION AZIMUTH LAT!TUD~ SECTION tNCLN. N/-S ft deg deo ft 532,74 68,00 280,70 -2063,40 552,49 68,40 280,20 -2059,75 572,08 ~8,90 ..~79,90 -~w ~x., _o ?~ 591,42 89,30 278,70 -2053,11 611,1! 89,30 278,!0 -2050,21 631,42 89,10 277,20 -2047,48 651,38 89,20 276,60 -2045,06 671,16 89,30 275,80 -2042,91 69!,06 89,00 · 275,60 -2040,93 711,0~ 69,20 274,40 -2039,18 73!,03 88,80 273,50 -2037,80 750,78 88,80 273,50 -2036,59 780,84 69.80 272,40 -2035,04 820,81 88,40 271,50 -2033,68 860,6? 88,40 269,60 -2033,~0 890,77 87,70 269,00 -2033,66 920,65 88,50 268,40 -2034,34 950,32 88,80 267,90 -2035,30 980,68 88,!0 267,00 -2036,65 10i0,59 87,00 265.40 -2038,64 1064,!4 86.40 263,50 -2043,84 1121,76 65,60 259,60 -2052,40 1!53,51 8~,90 258,10 -2058,66 I~A~ ?~ ._ ~o,_~ 90,30 259,50 -2064,55 1222,40 ?2,00 260,20 -2071,56 !252,16 93,50 260,90 -2076,51 1272,29 94,70 262,30 -2079.48 S-28A DEPARTURE DISF'LAC£M£NT at AZIMUTH DLS E/-W deg/ it ft deo lOOft -3082,64 3709,48 236,20 3,04 -3102,39 3723,90 236,42 3,18 -3121,98 3738,32 236,63 2,93 -3141032 3752,76 236,83 6,45 -3161,01 3767,67 237,03 3,01 -31~1,32 3783,25 237,23 4,50 -320!,27 3798,74 237,43 3,02 -3221,0& 3814,2~ 237,62 4,05 -3240,96 3830,04 237,80 1,80 -3260,98 3846,06 237,98 6,05 -3280,93 3862,27 238,i5 -3300,66 3878,43 238,32 -3330,74 3~03,23 238,58 -3370,71 3936,69 238,90 -3410,59 3970,70 239,20 -3440,67 3996,75 239,41 -3470,55 4022,8~ 239,62 -3500,22 404fi,95 239,82 -3530,58 4075,90 240,02 -3560,49 4102,~2 240,21 4,92 0,00 4,94 4,16 4,7~ 3,06 3,34 i,96 3,75 6,47 -3614,04 415!,94 240,51 3,69 -3671,66 4206,35 240,60 6,~0 -3703,41 4237,14 240,93 14,05 -3733,13 4265,99 241,06 4,80 -3772,30 4303,67 241,23 4,62 -3802,06 4332,i5 241,36 -3822,I9 4351,25 241,45 5,48 RECEIVED LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501° Date: 9 May 1996 RE: ~; ++ Data Tran ....... al of Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ECC No. ~1-~;~;z- G-16 ~44-11-11-13) 1 PLS FINAL BL+RF Run ~ 1 1130.08 1PLS FINAL BL+RF 1 CN FINAL BL+RF 1 PLS FINAL BL+RF 1 CN FINAL BL+RF Run ~ 1 Run # 1 Run # 1 Run # 1 2413.02 2452.06 3385.03 4112.05 1 PFC/PERF FINAL BL+RF Run ~ 1 1 PLS FINAL BL+RF 4468.06 1 PLS FINAL BL+RF Run # 1 5609.04 1 CN FINAL BL+RF Run # 1 5627.13 I CN ~T~?~T BL+RF Run # 1 5665.11 Run # 1 6090.05 10T FiL?AL ~L+~? Run ~ 1 6103.05 ! PhS FINAL BL+RF Run # 1 6234.05 1 PLS FINAL BL+RF Run # 1 6624.03 1 PFC/PERF FINAL BL+RF Run # 1 ! GR/CCL FINAL BL+RF Run # 1 6667.00 6670.00 Cont/ ' 1996 STATE OF ALASKA AL/~'"-"\ OIL AND GAS CONSERVATION COMMISS' ., APPLICA' FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging Time extension __ Stimulate __ Change approved program x Pull tubing __ Variance __ Perforate__ Other_~ge prop. BH Iocqation 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 64.86 AMSL feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1636' SNL, 4011' WEL, SEC. 35, T12N, R12E S-28 A At top of productive interval 9. Permit number 3656' SNL, 1350' WEL, SEC. 34, T12N, R12E I 95-173 At effective depth 0RIGI~A~'' 10. APl number 50- 029-22095-01 At total depth 11. Field/Pool 3780' SNL, 2802' WEL, SEC. 34, T12N, R12E (New proposed Bottom Hole location) Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10100 feet Plugs (measured) 9181 feet feet Junk (measured) feet Casing Length Size Structural -- Conductor 80 20x30 Surface 2530 13 3/8 Intermediate 9672 905/8 Production .... Liner 10100 7 Perforation depth: measured 9754'-9802', 9824'-9854' Cemented 8 cu. yds. 3088 c.f. 2060 c.f. .. 348 c.f. Measured depth 138 2590 9672 9409- 10100 true vertical subsea Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9379' with 4 1/2" tailpipe to 9459' Packers and SSSV (type and measured depth) 9 5/8"Baker Packer @ 9379; 4 1/2" SSSV @ 2001 True vertical depth BKB 138 2552 8759 8526-9143 RECEIVED APR 0 5 199(; Alaska 011 & Gas Cons. C0mmissi~ Anchorage 13. Attachments Description summary of proposal Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation April 9,1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended ~ Service Signed ~¢/j,.F,¢~,,~,,. / Title Co/led' Tubing Drilling Engineer Date 4/3/96 "/ .¢/¢'~ FOR COMMISSION USE ONLY Conditions of approval': Notify Commission so representative may witness I Approval No.¢¢ Plug integrity_ BOP Test~ Location clearance__ Approved Cbpy Mechanical Integrity Test ~ Subsequent form required 10- Returned Original Signed By "'/// Approved by order of the Commission David W, Johnstor, Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRI'P'LICATE S-28 Plan -4,40 -4,20 -4,00 -3,80 ~3,60 -3,40 -3,20 -3,00 -2,80 -2,60 -2,40 -2,20 -2,( -1,80 -1 o o o o o o o o 0 0 o o o X distance from Sfc Loc -1,900 -2,100 -2,300 -2,500 -2,700 Well Name S-28 I CLOSURE Distance 4:599 ft I Az ~-,~1 deq I NEW HOLE Kick Off TD State Plane E/W (X) N/S (Y)I -2,5391 -2,°4~/ -~,o~I-~,~osI 615r3971 5r977'~6471 Surface Loc 619,431 5,979,855 Az Ch; MD (ft) 3.0 650 -3.0 450 1.0 1 1.0 1 1.0 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,561 Drawn: 4/3/96 6:58 Plan Name: Case I 868O S-28 Vertical Section Path Distance (Feet) 0 200 400 600 800 1,000 1,200 1,400 1,600 1,800 2,000 8700 ................................................................................................... TSGR @ K.O.= 27 deg MD:9647 8720 8740 ................ TSHU 8760 8780 ~8800 8820 884O 8860 8880 890O DL '1 28 degflO0 87 dec DL 2= 3 deg/lO0 DL.,.,--'-;- 3 de9/....il,.d..e..g ' D 8920 894O 11208 TD Tot Drld:1561 ft Marker Depths @ Oricj Wellbore rSHU TSAD 8,855[ 8,699[ft TVD 8,741 [ft TVD 8,806[ft TVD 8,855[ft TVD Kick Off Deprtr @KO 8,71 01ft TVD 9~6471ft MD 3r273 ft 9,647] 1561/ 11 ~208/ 8~820[ VlD KO Pt VID New Hole Total MD TVD TD Build Rt de~l100 MD (ft) 0.0 650 3.0 242 0.0 450 1.0 1 1.0 1 1.0 1 1.0 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,561 Drawn: 4/3/96 6:58 ./ STATE OF ALASKA ALASr.,~-~ OIL AND GAS CONSERVATION COMMISSIO,. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ~ Operation Shutdown ~ Re-enter suspended well Alter casing ~ Repair well Plugging ~ Time extension ~ Stimulate ~ Change approved program ~ Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1636' SNL, 4011' WEL, SEC. 35, T12N, R12E .5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 64.86 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-28 (43-34-12-12) feet At t.o,p of productive interval I 9. Permit number 3656 SNL, 1350' WEL, SEC. 34, T12N, R12E J 90-~39 At effective depth 110. APl ~umber At t,otal depth , ' ~][~L I~~~,~ool. _ 3716 SNL, 1491 WEL, SEC 34, T12N, R12E ~ I HrudH¢e Oil 12. Present well condition summaw / % ~ Total depth: measured 10100 feet Plugs (mea~u.red)) ~ trUe ve~ical ' 9181 feet ' ' L' ~ / / Effective depth: measured feet Junk (meas~ true ve~ical feet ~ . / Casing Length Size Cemen~ ~ Measured dept~ True vedical depth Structural -- ~ / BKB Conductor 80 20x30 ( 8cu. ydS. 13/ 138 Sudace 2530 13 3/8 ~ 3088 ~f. 25~0 ' 2552 Intermediate 9672 905/8~ ~ 2060~f~ ~72 8759 Liner 10100 /7 3~ c.f. 9409~ 10100 8526-9143 Pe'°rati°'depth:measured9754L9802',98~9~' / " ' , , sk& 0~[ & G~s 6ons C0Bmission Tubing (size, grade, and measured depth) 4 1/2 ' &-80 to 937~' with 4 1/2 tai~ipCto 9~9' ~8 ' ' ~ · ' ' ~ . ~ ~ch0rage Packers and SSSV (~e and measured depth) 9 ~8" Baker Packer ~ 93~ 1/2" SSSV ~ 2001 13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch _ 14. Estimated date for commencing operation Dec 9,1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify~ha/tCh~o~ is true and correct to the best of my knowledge. Signed ~L_~/(.~~///~-'¢/"~ TitleCT"-L~/t.r_.,/~'~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may w~tness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Date Approved by order of the Commission Commissioner Date Form 10-403 Rev06/15/88 - ....... :· --..- - .-' -. . . .- ... SUBMIT IN TRIPLICATE TONY KNOWLE$, GOVERNOR ALASKA OIL GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 21, 1995 Ted Stagg Coil Tubing Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage. AK 99519-6612 Re; Prudhoe Bay Unit S-28A BP Exploration (Alaska), Inc. Permit No: 95-173 Sur. Loc. 1636'SNL, 4011'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 4363'SNL, 1879'WEL, Sec. 34, T12N, R12E, UM Dear Mr. Stagg: Enclosed is thc approved application for permit to redrill the above referenced xvell. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by he North Slope pager at 659-3607. David W. Johr~ton '~ ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I'E"lllb. Type of well. Exploratoryl-] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration 64.86 KB feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorage, Alaska 99519-6612 ADL 28258 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1636' SNL, 4011' WEL, Sec. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3678'SNL, 1402' WEL, Sec34, T12N, R12E S-28A 2S100302630-277 At total depth 9. Approximate spud date Amount 4363'SNL, 1879' WEL, Sec34, T12N, R12E Nov. 9, 1995 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (uD and TV[:)) property line ADL 28261 @ 917 feet No close approach feet 2560 10686 MD, 8845 SS feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8740 feet Maximum hole angle ~o o Maximum surface 3330 psig At total depth (TVD) 8800/4390 psig 18. Casing program Setting Depth s~ze Specificati OhS Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 3 3/4" 2 7/8 6.16 L-80 FL4S 1286 9400 8490 10686 8845 90 cu. ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~'~' ~'~ "' Present well condition summary Total depth: measured 10052 feet Plugs (measured) 00~ true vertical 9138 feet Effective depth: measured 9788 feet Junk (measured) p, tS$~a, Uli & Gas Cons. 60fflrrliS,.sio['~ Anchorage true vertical 8901 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80 20x30 8 cu. yds 110 110 S u rface 2560 13 3/8 3088 cu. ft. 2590 2590 l nte r med late 9642 9 5/8 2068 cu. ft. 9672 8797 Production Liner 691 7 348 cu. ft. 10100 9181 Perforation depth: measured 9824'-9854'; 9754'-9802' true vertical 8868'-8895'; 8805'-8848' ss 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify~,ca~oing is true and correct to the best of my knowledge Signed '~-----~¢~''/~'''''~''¢'//~ Title Coil Tubin~lEngineer Date//o/~///~'- Commission Use Only Permit Number IAPI number ~,~".-./,",,~,..~ 150-CZ ¢- ,2-, .:2.0 ~'O~'-~ l~Approy'al d,a_te See cover letter /i/(~_j' //~f~"- for other requirements Conditions of approval Samples required [] Yes [] NoML~d'1(~ req~ir~l [] Yes ,~ No Hydrogen sulfide measures ,~ Yes [] No D~rectional survey required ,]~ Yes [] NO Required working pressure for DOPE []2M; 1-13M; FI5M; I-I1 OM; []15M; Other: Original Signed By ~ ~,5',~& by order of Approved by David W. Johnston Commissioner tne commission Bat ¢11¢/li¢ Form 10-401 Rev. 12-1-85 Submit plicate S-28A Proposed Sidetrack Program Current Status Well S-28A is a high TGOR producer that has been shut-in since, 9/93. Existing Ivishak perforations will be squeezed in preparation for sidetracking with coiled tubing. . The sidetrack will be conducted in two phases with an operational shut down between Phase 1 and Phase 2. Phase 1: Mill Window (planned for Nov. 3-8, 1995) Existing Ivishak perforations will be squeezed. A thru-tubing whipstock will be set on E- line in the Shublik formation and coiled tubing will be used to mill a window in the 7" liner at 9682' MD. Coiled tubing will then be rigged down and 1 to 2 weeks will lapse before drilling operations begin. Phase 2: Drill Sidetrack (planned for Nov. 9-18, 1995) A 3 3/4" hole wilt be drilled with coiled tubing to 10,686' MD per the attached directional plan. A steering tool will be used for directional control and surveys will be taken every 25 ft. No gyro will be run. Drilling Fluid Program: Phase 1: Seawater with Biozan sweeps. Phase 2: Solids Free FIo-Pro (8.8 ppg to provide approx. 500 psi overbalance) Logging Program: A Gamma Ray log will be used in geosteering while drilling and will be run over the entire drilled section. A GR/Induction log will be conveyed on CTE prior to running a liner. Liner / Completion Program: A 2 7/8", FL4S, L-80 liner will be run to TD and cemented with 90 cu.ft cement. A PBR at the top of the liner will be located in the existing 4 1/2" tubing tail at approximately 9400' MD. The liner will be displaced to filtered sea water and perforated with CT conveyed thru-tubing guns. Well Control: BOPE schematics for Phase 1, Phase 2 and completion operations are attached. The full production tree will remain in place during all drilling and completion operations. Anc~oraoe TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS S-28A Proposed Sidetrack KB. ELEV = 64.86' BF. ELEV = 36.96' 13-3/8", 72 #/ft, L-80, BTRS CMT'd 1 2590' KOP: 2600' MAX ANGLE: 35°/5000' 4-1/2", 12.6#/ft, L-80, TUBING TDS TUBING ID: 3.958" CAPACITY: .0152 BBL/FT PERFORATION SUMMARY REF LOG: SPERRY SUN - MWD/RLL - 10-31-90 SIZE SPF INTERVAL OPEN/SQZ'D 3-~8" 4 9824- 9854' Squeezed 3 ~8" 4 9754-9802' Squeezed I' I TOP OF9409' 7" LINER 9-5/8", 47#/ft, L-80, BTRS I 9672' SSSV LANDING NIPPLE I 2081'I (OTIS)( 3.813" ID) GAS LIFT MANDRELS (OTIS W/ RA LATCH) N° MD(BKB) TVDss DEV, 5 3093' 3024' 12° 4 5517' 5118' 35° 3 7545' 6841' 27° 2 9105' 8230' 29° 1 9329' 8426' 28° 4 1/2 .... X" NIPPLE I I PARKER SWS ( 3.813" ID) BAKER E-22 ANCHOR 19359'1 SEAL ASSY. (4.000"ID) 9-5/8" PACKER ( BAKER SA-3)(4.75"1D) 4 1/2" 12.6#/f L-80 TDS TAILPIPE 4 1/2 .... X" NIPPLE PARKER SWS(3.813" ID) I9423'1 41/~ .... x" PARKER SWS(3.813" ID) I9443'1 4 1/2" TBG TAIL[ (WLEG)(3.958"1D) (ELMD) 9459' SAG R. Cement top approx. 9700' MD ONLY THIS MARKER JOINTIS I 9710'1 7" 29# (6.184"ID) 7" OTIS TWD PACKER I 9806' I 4 1/2 .... X" NIPPLE ( OTIS ) ( 3.813" ID) 9814' 4 1/2 .... XN" NIPPLE ~ (OTIS) (3.725" ID) I 981 9' 4 1/2 "WLEG [ 9820' (OTIS)(3.958"1D) ! PBTD ~ 7" , 26#/ft, L-80, BTRS %/%,..%/%/%/% '...%/%/%/%/%/ ',..%/%/%/%/%/ %%%% SHUBLIK IVISHAK 8699 ss 9635 MD 8741 ss 9682 MD 8806 ss 9754 MD TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS S-28A Proposed Completion KB. ELEV = 64.86' BF. ELEV = 36.96' 13-3/8", 72 #/ft, L-80, BTRS CMT'd -- 1 2590' KOP: 2600' MAX ANGLE: 35o/5000' 4-1/2", 12.6#/ft, L-80, TUBING TDS TUBING ID: 3.958" CAPACITY: .0152 BBL/FT PERFORATION SUMMARY REF LOG: SPERRY SUN - MWD/RLL - 10-31-90 SIZE SPF INTERVAL OPEN/SQZ'D 3-3/8" 4 9824- 9854' Squeezed 33/8" 4 9754-9802' Squeezed TOP OF 7" LINER 9409'I 2 7/8" FL4S Cemented Liner 9-5/8", 47#/ft, L-80, BTRS I 9672' Cement top approx. 9700' MD ONLY THIS MARKER JOINT I$ 971 0'I 7" 29# (6.184"ID) 7" OTIS TWD PACKER I 9806' 4 1/2 .... X" NIPPLE OTiS ) (3.813" ~D) I 9814' ( 4 1/2 .... XN" NIPPLE I (OTIS) (3.725" ID) I 981 9' 4 1/2 "WLEG I 9820' ( OTIS ) (3.958"1D) PBTD 7", 26#/ft, L-80, BTRS Ilo.loo' I %,,,%¢,%¢,%,¢%~,% ,,, %¢. % ,,. % ~,% ¢,' ' ,¢,. ""' ¢. % ,¢,. % ,g, % ,F % ~,' % ".. % % % SSSV LANDING NIPPLEI 2081 (OTIS)( 3.813" ID) I GAS LIFT MANDRELS (OTIS W/ RA LATCH) No- MD(BKB) TVDss PLY, 5 3093' 3024' 12° 4 5517' 5118' 35° 3 7545' 6841' 27° 2 9105' 8230' 29° I 9329' 8426' 28° 4 1/2 .... X" NIPPLE I _1 PARKER SWS (3.813" ID) ~ BAKER E-22 ANCHOR I 9359'1 SEAL ASSY. (4.000"ID) -- 9-5/8" PACKER I ( BAKER SA-3)(4.75"1D) ~ 4 1/2" 12,6#/f L-80 TDS TAILPIPE 4 1/2 .... X" NIPPLE I PARKER SWS (3.813" ID) I 4 1/2 .... X" NIPPLE I PARKER SWS (3.813" ID) I 4 112" TBG .T,,A.,IL I (WLEG)( 3,958 ID) (ELMD) 9423'I 9443'I 9459'1 9459' SAGR. SHUBLIK IVISHAK 8699 ss 9635 MD 8741- ss 9682 MD 8806 ss 9754 MD Oil & Gas Cons. Cornmis¢ r, Anchorage S-28 Vertical Sectiol Path Distance (Feet' 3,000 3,200 3,400 3,600 3,800 4,000 4,200 4,400 / / 1 8820 ~ ! ~ ~ ~T.Target~_ .... Marker Depths TSAD I T.Target I Base J 8,699Jft TVD 8,805Jft TVD 8,825Jft TVD 8,845Jft TVD Kick Off Deprtr @KO 8,740Ift TVD 9~6811ff MD 3,288 ft Predict From Survey #: Length IMD KO Pt MD New Hole Total MD TVD TD 21 100 9,6811 1005I 10~686J 8,8381 Build Rt decj/lO0 MD (ft) ~1.0 20~ 0.0 400 0.0 400 Curve 1 Curve 2 Curve 3 Drawn: 9/26/95 16:52 -3,600 S-28 Plan View -3,400 -3,200 -3,000 -2,800 -2,600 -2,400 X distance from Sfc Lo I -2,200 1 800 -2,000 -2,200 -2,400 -2,600 -2,800 -3,000 ~ IWellName S-28 I CLOSURE I Distance 4,161ft I Az 228 de~l NEWHOLE E/W (X) NIS (Y) Kick Off -2,553 -2,048 Top Sad -2~635 -2~083 State Plane 616,796 5,977,772 TD -3~100 -2~776 State Plane 616,331 5,977,079 Surface Loc 619,431 5,979,855 I TSAD1 Step Out 4:1 TSAD2 Step Out 4 IMD of TSAD1 -> TD 8801 Az Ch~l MD 0.(~ 205 -12.0 400 0.0 400 Curve 1 Curve 2 Curve 3 Drawn: Plan Name: 9/26/95 16:51 Case I 2 7/8" LINER DEPLOYING / CEMENTING CONFIGURATION T.O.T. QUAD 13/4" SCHAFFER HYDRIL ~- 2 7/8" Blind / Shear HYDRIL 2 7/8" Pipe and Slip Mud Cross CTDM:2.3.2A IOoil Tubing BOPEI I Pump-In SublI Blind/Shear Bind/Shear Pipe Rams Slip Rams BOP Stack Type A To be used for drilling with mud Spacer Spools (as needed for Height) I To Choke Manifold I Hydraulic Actuated ValveI Manual Valve Mud Cross IIVlanual Valve Manual Swab Valve I Hydraulic Actuated Valve ~1 Existing Flowline I I Manual Wing ValveI Manual Mast er Valve C :2.3.2B ICoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I Pump-In SubI BCP Stack Type B To be used when no mud will be circulated Spacer Spools needed for Height I(as Manual Swab Valve Existing Flowline I I Hydraulic Act uat ed Valve I Manual Wing Valw Manual Mast er Valve Anchorage Lift Gas In ] (if applicable)J FLUID FL .... SCHEMATIC (with Type '~' BOP) CTDM:1.2.25V6 Seaw~ ier MeOH Dead Crude (vac trucks) Green ~ Tank Farm Tank (Divert) Clean Fl~pro I I I Cosasco Valve ~ E~ ~ I I/ // i M~,,.,b~,~anif°ld Charge / Pump icro motion ~ill Cuttings~ MI Van 3 Squeeze Manifold CTU BJ Pumper Normal flow Gas Dived Fluid transfer from tank farm/upright tanks to B J/MI Manually operated valve ICTDM:I.2~.3v~ Site PlanTD ~ WE LL HO US E I[] CHARGE PUMP SEAWATER GREEN (DIVERT) TANK -I.. HEATERSt TOWER WIND SOCK S I, DIV lAND DIV II ~ BLEED TRAILER I CHOKE MANIFOLD i I LAB e I ' TANK FARM ~ +. i×1~1× · ~ + · CLASS I, DIV I* SOZ MANIFOLD CLASS I, DIV I'~' · MI VAN 3 ~ s BJ PUMPER FIRST AID STATIONS EMERGENCY ESCAPE PACKS SCOTT AIR PACKS PRESSURIZED N2 BOTTLES OTHER FIRE HAZARDS - PAINT, LUBRICANTS, RAGS, CHEMICALS .... HALON DUMP/STORAGE EYE WASH STATION FUEL STORAGE H2S SENSORS OR WARNING LIGHTS H2S/LEL SENSORS OR WARNING LIGHTS GLYCOL STORAGE e o X E WELL (Safed Out) · ESD WELLS SHOWN ON 50' CENTERS ~ TOOL TRAILER/ CAM CO -~~%~7 · ~ GENERATOR BOOM TRUCK .. '~F~ROX 120' P( SCS HEATER · ~%,%,,~ PLANT GENERATOI~ MAN LIFT WIND SPEED SOHIO TRAILER DIRECTIONAL DRILLERS + FIRE EXTINGUISHERS OPS CAB WELL PERMIT CHECKLIST GEOL ~ ~.~C3 UNmT# PROGRAM: exp [] dev ~ redrll~.serv [] ON/OFF S~ORE ~ i ADMINISTRkTION ENGINEERING 2. 3. 4. 5. 6. ~ 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............ Well located proper distance from drlg unit boundal-y. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............. Operator has appropria~e bond in force ........ Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... N N N · N N N · Y N N N N GEOLOGY 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs'. ........ Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N~ ' - I - 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CM~will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B'& permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been appr/~ ~ N 22. Adequate wellbore separation proposed ...... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate .................... .~ N 26. BOPE press rating adequate; test to 3~~'~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. 'Is presence of H2S gas probable . . ~.. ..... ....~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/ ~/~ 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION Comments/Instructions: Z HOW/~o - A:~FORMo-~chekJist rev 03~)4 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 Simp!ify finding information, informati;3n 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. * * * ALASKA COMPUTING CENTER * . . ....... SCHLUMBERGER ....... . ............................ . COMPANY NAM~ : BP EXPLORATION WELL NAME : S-28A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUF3~ER : 50-029-22095-01 REFERENCE NO : 96185 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-JOZ-1996 1~7~I' PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/07/ 9 ORIGIN : FLIC REEL NAME : 96185 CONTINUATION # : PREVIOUS REEL : COGENT : B.P. EXPLORATION, PRUDHOE BAY S-28A, API #50-029-22095-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/07/ 9 ORIGIN : FLIC TAPE NAME : 96185 CONTINUATION # '. 1 PREVIOUS TAPE : COFff4ENT : B.P. EXPLORATION, PRUDHOE BAY S-28A, API #50-029~22095-01 TAPE HEADER PRUDHOE BAY MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER '. LOGGING ENGINEER: OPBRATOR WITNESS: SURFACE LOCATION BIT RUN 1 96185 KEMP BARTELL SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING S-28A 500292209501 BPEXPLORATION SCHLUMBERGER WELL SERVICES 9-OY3L-96 BIT RUN 2 BIT RUN 3 35 12N 12E 1636 4011 66.60 39.20 37.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3. 750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-JUL-1996 15:31 3RD STRING PRODUCTION STRING REMARKS: The log data on this tape is from SLIM1 GR acquired on coiled tubing. The data was considered as one run. No depth shifts were made per Steve Jones via Dave Douglas of BP. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UMBER: 1 EDITED MERGED~fWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUAE4ARY LDWG TOOL CODE START DEPTH MWD 9670.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: This file contains the interpolated and raw Gamma Ray and the ROP curve. No depth shifts were made per Steve Jones via Dave Douglas of BP. $ STOP DEPTH 11050.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD ....... BIT RUN NO. MERGE TOP ~fERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-JOZ-1996 1~'.~'3"~' PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API APIAPI FILE NUMB NUIqB SIZE REPR PROCESS ID ORDER # LOG TYPE' CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRRWMWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11050.000 GRRW. MWD -999.250 GRIN. MWD -999.250 ROP.MWD DEPT. 11000.000 GRRW. MWD 17.500 GRIN. MWD 17.500 ROP.MWD DEPT. 10000.000 GRRW. MWD 16.380 GRIN. MWD 16.380 ROP.MWD DEPT. 9670.000 GRRW.MWD 15.680 GRIN. MWD 15.680 ROP.MWD 26.300 53.200 24.900 -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-0-0Z-1996 1S:~[ PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 9670.0 11050.0 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GR $ 28-APR-96 5.5C 5.5 REAL-TIME 11050.0 9672.0 11050.0 26.7 94.7 TOOL NUMBER ........... SLIM1 006 LIS Tape Ve~i~f ication Listing Schlumberger Alaska Computing Center 9-JUI.,-1996 I$~..~i' PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT) : 3. 750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) '. FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): FLO PRO NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: This file contains the raw and interpolated GR and ROP curves from SLIM1GR acquisition. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 i LIS Tape Ve~l'~ication Listing Schlumberger Alaska Computing Center 9-JOL-1996 PAGE: 6 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR RAW CPS O0 000 O0 0 2 1 1 4 68 0000000000 GR MWD AAPI O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ROP5MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 INT F/HR O0 000 O0 0 2 1 1 4 68 0000000000 VDEPMWD FT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. ROP.MWD 11050.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT -999.250 20.600 ROPS.MWD 26.300 ROPS.INT 26.300 VDEP.MWD 10185.301 DEPT. 11000.000 GR.RAW 17.500 GR.MWD ROP.MWD 88.800 ROP5.MWD 53.200 ROPS.INT 17.500 GR.INT 17.500 53.200 VDEP.MWD 10148.600 DEPT. 10000.000 GR.RAW 16.400 GR.MWD ROP.MWD 8.700 ROPS.MWD 24.900 ROPS.INT 16.380 GR.INT 16.380 24.900 VDEP.MWD 8862.900 DEPT. 9670.000 GR.RAW 15.700 GR.MWD 15.680 GR.INT 15.680 ROP.MWD -999.250 ROPS.MWD -999.250 ROPS.INT -999.250 VDEP.MWD -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~IS Tape Verification Listing Schlumberger Alaska Computing Center 9-JUL-1996 15.~. PAGE: **** TAPE TRAILER **** SERVICE NAPiE : EDIT DATE : 96/07/ 9 ORIGIN : FLIC TAPE NAME : 96185 CONTINUATION # : 1 PREVIOUS TAPE : COMFiENT : B.P. EXPLORATION, PRUDHOE BAY S-28A, API #50-029-22095-01 **** REEL TRAILER **** SERVICE NAFiE : EDIT DATE · 96/07/ 9 ORIGIN · FLIC REEL NA~E : 96185 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, PRUDHOE BAY $-28A, API #50-029-22095-01