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Home My WebLink About200-080~~, ~~.. STATE OF ALASKA ~ S~D~ • ALASK~L AND GAS CONSERVATION COM~SION r1~, WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~, ~ __ ,~ . ; ~ ~, h _. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.,os zoAa,c zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. D_ ate Comp., Susp., or Aba 7/19/2008 12. Permit to Drill Number 200-080 308-177 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 07/12/2000 13. API Number 50-029-20802-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 07/15/2000 14. Well Name and Number: PBU 06-21A 466 FSL, 959 FEL, SEC. 02, T10N, R14E, UM Top of Productive Horizon: 18' FSL, 2412' FEL, SEC. 02, T10N, R14E, UM 8. KB (ft above MSL): 74' Ground (ft MSL): 37' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 98' FSL, 2703' FEL, SEC. 02, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 9456 9060 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 686026 y- 5941066 Zone- ASP4 10. Total Depth (MD+TVD) 9503 9103 16. Property Designation: ADL 028311 TPI: x- 684584 y- 5940583 Zone- ASP4 Total Depth: x- 684291 y- 5940655 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and Tinted information r 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR, MEM RES / RST, MEM CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP ':BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 1900 # Poleset 13-3l8" 72# L-80 Surtace 2510' Surface 2510' 17-1/2" 2259 sx Fondu 400 sx PF'C' 9-5/8" 47# L-80 Surface 8842' Surface 8596' 12-1l4" 500 sx Class 'G' 50 Bbls Class'C' 7" 29# L-80 8519' 9001' 8279' 8752' 8-1/2" 275 sx lass 'G' 2-3/8" 4.7# L-80 8782' 9503' 8537' 9103' 3" 54 sx LARC 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top $ Bottom; Pe nterval open rforation Size and Number): SRE DEPTH SET MD PACKER SET MD 5-1/2" x 4-1/2" x 3-1/2" 7790' - 8958' 8448' & 8930' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED `~`''°~~N~~ A~ ~ ~ ~ 2~~$ ~~ 8696' Set EZSV 8580' P&A w/ 17.5 Bbls Class'G' 7320' Set EZSV 7293' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATeD 24HOUR RATE OIL-BBL: GAS-MCP: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per~20 AAC 250.071. 149Fa.1(p~ ~ None ~~,~ Form 10-407 Revised 02/2007 -'-- -" CONTINUED ON REVERSE SIDE ~"~,, ~U~ ~ b ~ODB ~~~~ _ noir~n~~t ZS. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 8847' 8601' None Shublik 8870' 8624' Sadlerochit 8945' 8697' Zone 4A 9056' 8801' Zone 3 9204' 8893' Zone 2C 9366' 8982' Zone 2B 9402' 9012' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Drilling Technologist Date O~` ' ~/~ PBU 06-21A 200-080 308-177 Prepared ByName/Number.• Terrie Hubble, 564-4628 Well Number Drilling Engineer: Eleazar'Eli' Vi3zquez, ss4-5918 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex; 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only C] • 06-21 A, Well History (Pre-Sidetrack) Date Summary 6/17/2008 RUN STATIC AS PER PROGRAM, USED PREVIOUS STATIC CORRECTION FROM 6/17/07. PULL 5.5" DUMMY CAMCO SSSV DRIFT TUBING W/ 3.70" CENT, S.BAILER TO DEPLOYMENT SLEEVE C~3 8782' MD (8755' SLM ). LEFT WELL SHUT IN NOTIFIED PAD OP ON DEPARTURE. 6/23/2008 INITIAL T/I/O: 900/800/200. SET 4.5" HALLIBURTION EZ DRILL SVB SQUEEZE PACKER AS A CEMENT RETAINER. TOOLSTRING: HEAD/ 2 X WEIGHT BARS/ CCL /FIRING HEAD / HALLIBURTON 2.5" SHORTY SETTING TOOL / 4.5" EZ DRILL SVB SQUEEZE PACKER. MAX TOOL OD = 3.66 IN, TOOLSTRING LENGTH = 21 FT, WEIGHT = 214 LBS. SETTING DEPTH OF MID-ELEMENT = 8700 FT, CCL TO MID-ELEMENT = 6.7 FT. SURFACE AND VISUAL CONFIRMATION OF PACKER SETTING. TD NOT TAGGED. LEFT VALVES AS THEY WERE PRIOR TO JOB: MASTER=OPEN, SSV =CLOSED. NOTIFIED DSO AND CONFIRMED VALVE POSITIONS. WELL LEFT SHUT IN. FINAL T/I/O: 900/800/200. JOB COMPLETE. 6/24/2008 T/IA/OA= SSV/820/200 Temp=Sl PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre RST) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite cap. Cycle and torque LDS "Standard" all functioned no problems PPPOT-IC RU 1 HP bleed tool onto IC void, 820 psi would not bleed to 0 psi, which indicates secondary seal leak. Cycle and torque LDS "Standard" all functioned no problems 6/26/2008 T/I/0= 900/800/200. Temp= SI. T & IA FL (Pre sidetrack). A/L spool dropped. T FL C~ surface. IA FL C~3 1740' (77 bbls). 6/26/2008 T/I/0= 860/800/200 Load IA for CTU (Pre-Rig Sidetrack). Pumped 2 bbls of meth for spear, followed by 75 bbls of 60'`F diesel down IA. Bleed gas off IA bleed then let sit so gas swaps out and bleed more gas from IA (continued on 6/27/08) 6/27/2008 (continued from 6/26/08) Bled gas off IA. Rig up to IA to fill with crude and pumped 6 bbls crude down IA top off. FWHP=300/500/220 ~"*Swab closed, wing closed and locked, SSV open, Master open, Annulus valves open to guages. DSO (John) hands on verified valve positions 6/28/2008 CTU #6, P & A; MIRU. MU / RIH w/BOT-MHA + HES stinger to top of retainer at 8696' ctmd. Circulate to load well with 1 % KCL. Stab into retainer and establish aood infectivity into formation. Cool down and prep to cement. Pump 17.5 bbls of 15.8 ppg Class 'G' cement. Place 8 bbls of cement under retainer. Well locked up. Pull out of the retainer and lay in the remaining cement on top. WCTOC approx. 8200'. PULL to safe. RBIH and contaminate to 8580' ctmd. Circulate and chase out of hole at 80%. Lost seal on inner reel valve while POOH at 2100' just prior to complete clean up. Shut down circulating to repair valve. Decided to POOH repair inner reel vlv and change packoffs. RBIH with JSN to ensure hole is clean to bottom. Hard tag at 8580' ctmd. Make two jet passes from 8580 - 7500 with biozan. POH chasing bio pill and washing jewlery to surface. 6/29/2008 DRIFTED TO 8587' SLM W/ 2' 1 7/8" STEM, 3.45" CENT, SAMPLE BAILER. (NO SAMPLE RECOVERED). DRIFTED TO 8403' SLM W/ 2' 1 7/8" STEM, 4.50" CENT, SAMPLE BAILER. (NO SAMPLE RECOVERED) ATTEMPT TO CMIT- TxIA TO 3500psi. 6/29/2008 Washing tbg from 8580' - 7500', POH chasing Bio pill and washing jewelry to surface, FP well to 2000'. ,PT well to 2504 psi -lost 52 psi in 15 min to 2452 psi . RDMO. Job complete. 6/30/2008 INITIAL T/I/O: 0/900/400. TS: HEAD/CAL-B/WEIGHT BAR/ SHOCK MANDRELS/ FIRING HEAD/ 4.15" SLB POWER CUTTER. CUT TUBING AT 7790 FT. FINAL T/I/O = 0/420/120. JOB COMPLETE. 6/30/2008 CMIT- TxIA TO 3500psi (PASS). WELL LEFT S/I, DSO NOTIFIED. Page 1 of 2 L~ 06-21 A, Well History (Pre-Sidetrack) i- -. Date Summary 7/4/2008 T/I/O = 250/240/120 Circ-Out,, CMIT TxIA PASSED to 3500 psi, MIT OA PASSED to 2000 psi (Pre Rig Sidetrack) Circ-Out well bore with a 5 bbl neat methanol spear followed by 798 bbls of 9.3# NaCI brine. Freeze protected Tbg and IA with 8 bbls of diesel. Pumped 6.2 bbls of diesel into the Tbg to CMIT TxIA. CMIT lost 80 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 100 psi in the 30 min test. Pumped 1.6 bbls crude down OA to reach test pressure. MIT-OA lost 140 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 180 psi in 30 min test. FWHP=O/0/0 Tags hung, Casing valves tagged and open to gauges. 7/12/2008 T/I/0=0/0/0. Set 5-1/8" ISA BPV #519 thru tree, pre-rig. 1-2' ext used, tagged C~3 98". No problems. Page 2 of 2 • • BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Da#e From - To Hours Task Code NPT Phase Description of Operations 7/15/2008 15:00 - 17:00 2.00 MOB P PRE Release rig from DS 06-19A at 15:00 hrs. Bridle up and prepare derrick & lay down. Derrick down move due to soft gravel around DS 06-19A. 17:00 - 20:00 3.00 MOB P PRE Move rig down well row to DS 06-21. Lay mats, spread heroulite, spot sub unit over well. 20:00 - 22:00 2.00 MOB P PRE Spot pit module, coat bridle lines with sealant. Prepare and inspect derrick to raise. 22:00 -00:00 2.00 MOB P PRE PJSM. Raise derrick. Bridle down. Accept rig at 00:00 on 7-16-2008 7/16/2008 00:00 - 02:00 2.00 MOB P DECOMP Acre t ri at 00:01 16-Jul -2008. Rig up top drive. Connect lines in interconnect. Take on seawater to pits. Load pipeshed with drillpipe. 02:00 - 04:00 2.00 DHB P DECOMP Pressure test OA to 2000 psi for 30 minutes -Passed. Perform CMIT - TxIA to 3,500 psi for 30 minutes -Passed. Bleed down pressure and blow down all lines. 04:00 - 05:00 1.00 DHB P DECOMP Rig up Drill Site Maintenence with lubricator. Pressure test lubricator to 1000 si - OK. Pull BPV - OK. -- 05:00 - 06:00 1.00 KILL P DECOMP Reverse circulate -3 bbls diesel from tubing to cuttings tank. Shut down, swap lines. Circulate -5 bbls diesel out from IA to cuttings tank. 06:00 - 08:00 2.00 KILL P DECOMP Circulating 50 bbl soap sweep and seawater surface to surface down tubing and out IA displacing well from 9.3 ppg brine to clean up tubing prior to pulling. 5 bpm, 360 psi. 08:00 - 08:30 0.50 DHB P DECOMP Dry-rod in back pressure valve. Test from below to 1000 si or minutes. 08:30 - 10:00 1.50 WHSUR P DECOMP Nipple down existing tree and adapter flange. Check threads on tubing hanger and crossover. Install blanking plug into BPV. 10:00 - 11:30 1.50 BOPSU P DECOMP Nipple up BOPE. 11:30 -12:30 1.00 BOPSU P DECOMP RU for pressure testing BOPE. Install 4" test joint into blanking plug. Run pressure testing lines. 12:30 - 20:30 8.00 BOPSU P DECOMP Test BOPE upper rams, annular & all manifold valves and chokes) to 250 psi low and 3500 psi high pressure using 4" and 5.5" test joints. Lower ram test postponed to after pulling 5.5" tubing -tubing hanger and plugs extend too high to close lower rams without interference. Jeff Jones waived state witness of test. Test witnessed by NAD TPs B. Perry, C. Weaver and BP WSLs C. Clemens, M. Martyr. During 2 tests, blanking plug leaking by. Had to wash off plug w/ rig pumps to re-seat ball in plug. After washing seat, test good. 20:30 - 21:15 0.75 BOPSU P DECOMP Rig down from BOP testing. Lay down test joint. Blow down lines. Pull blanking plug from wellhead. 21:15 -22:30 1.25 WHSUR P DECOMP Rig up Drill Site Maintenence with lubricator extensions. Pressure test lubricator to 1000 psi - OK. Bleed off well pressure through IA valve. Retrieve BPV from well. No trapped pressure below. Rig down Drill Site Maintenence Lubricator. 22:30 - 00:00 1.50 PULL P DECOMP RU to pull 5.5" completion. Pull landing joint to rig floor. Screw into tubing hanger. Back out lockdown screws. 7/17/2008 00:00 - 01:00 1.00 WHSUR P DECOMP Attempt to back out lock down screws on tubing hanger. 2 lock downs will not back out. Cycle tension on tubing hanger with Printed: 8/13/2008 2:31:14 PM • • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 7/2008 00:00 - 01:00 1.00 WHSUR P DECOMP topdrive to assist - no change. AWGRS we11 service report from 24-June-08 lists all lock down screws cycled - OK. 01:00 - 03:30 2.50 WHSUR N SFAL DECOMP Continue to work at backing out 2 seized lock down screws 03:30 - 09:00 5.50 WHSUR N SFAL DECOMP RU and begin drilling out seized uo lock down screws. 09:00 - 09:30 0.50 PULL P DECOMP Pull tubing hanger to rig floor. Hanger pulled free at 175k hookload. Moving upweight was 145k. Monitor well -static. 09:30 - 10:00 0.50 PULL P DECOMP Circulate bottoms up with clean seawater ®480 gpm & 305 psi while rigging up control line spooling equipment. 10:00 - 20:30 10.50 PULL P DECOMP POH LD 191 joints of 5.5" 17 # 8rd tubi~, 1 cut joint 21.23' strap, 6 GLMs, 1 SSSV Nipple and 2 stainless steel control lines w/ 27 clamps and 5 stainless steel bands recovered as expected. 20:30 - 21:00 0.50 BOPSU P DECOMP RU to test lower BOPE rams. Install test plug on 4" test joint. Fill stack. 21:00 - 21:30 0.50 BOPSU P DECOMP Pressure test lower rams w/4" test jt. to complete BOP test 250 psi / 3500 psi low/high pressure. Note: Outer annulus open to bleed tank with no flow -continue to monitor. 21:30 - 22:30 1.00 BOPSU P DECOMP RD from pressure testing lower pipe rams. 22:30 - 00:00 1.50 CLEAN P DECOMP MU BHA #1 - 8.5" MXL-1 RR bit 9-5/8" casin scra er, Float sub, XO, 3ea 6-3/8" DCs, XO, HWDP. 7/18/2008 00:00 - 04:00 4.00 CLEAN P DECOMP PU 4" HWDP and 4" HT40 drill pipe 1X1 and RIH with BHA #1. Note: Outer annulus open to bleed tank with no flow. 04:00 - 05:00 1.00 CLEAN P DECOMP Taa uo on 5.5" tubing stub at 7.785' md. PU - 155k, SO - 145k. Circulate bottoms up ~ 488 gpm, 1710 psi. 05:00 - 06:00 1.00 CLEAN P DECOMP Rack back 5 stands. PJSM & MU HES 9 5/8" Storm Packer and RIH settin to of the packer ®35' & LD running tool. Test acker from above to 1000 si. Held. 06:00 - 09:00 3.00 WHSUR P DECOMP MU 9-5/8" Packoff running tool and engage packoff. BOLDS and pull packoff free with 40k. MU new 9-5/8" packoff and attempt to install, unable to run packoff pass TBG head. 09:00 - 10:00 1.00 WHSUR P DECOMP PJSM - ND BOP &TBG head and set stack on stump. Remove old TBG head from cellar. 10:00 - 14:00 4.00 WHSUR P DECOMP Clean & inspect mandrel hanger Install new 9-5/8" ackoff and ener ize LDS. NU new TBG head and BOP. Test 9-5/8" packoff to 5000 psi for 30 min. Test Held. 14:00 -15:30 1.50 WHSUR P DECOMP RU Test ui ment and test TBG head flan a to 2 i psi. Good Test RD /blow down test equipment. 15:30 - 16:00 0.50 WHSUR P DECOMP PJSM - MU HES Storm packer running tool and engage packer ® 35', Check pressures 0 psi, Release backer POH & LD same. 16:00 - 19:00 3.00 CLEAN P DECOMP POH from 7350' to BHA #1 19:00 - 20:00 1.00 CLEAN P DECOMP Stand Back 4" HWDP and Collar stand, LD 9-5/8" casing scrapper & bit, Clean and clear floor. 20:00 - 22:30 2.50 DHB P DECOMP PJSM - RU for E-Line EZSV setting run. 22:30 - 00:00 1.50 DHB P DECOMP RIH on E-Line w/Gamma Ray, Collar Locator, Casing Packer Setting Tool, HES 9-5/8" EZSV Plug. 7/19/2008 00:00 - 00:30 0.50 DHB N DECOMP Troubleshoot 65 feet of stranded armor. Cut away birdnested YlInt80: tl/7J/ZUW z:"37:74 rm • • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/19/2008 00:00 - 00:30 0.50 DHB N DECOMP wire, file down both ends, tape down single strand at ends to prevent further damage. 00:30 - 03:00 2.50 DHB P DECOMP Cont' E-Line, Tag up softly on top of tubing stump at 7785' E-Line md. Log up and see collar depth at 7325' md. Correlate and pull into position. Set Top of EZSV at 7320' E-Line and 5' above Collar. POH logging CCL to 200' md. 03:00 - 03:30 0.50 DHB P DECOMP Pressure test 9-5/8" csg / EZSV to 3500 psi and record on chart for 15 min. Held 03:30 - 06:30 3.00 STWHIP P WEXIT MU Smith 9-5/8" Trackmaster whipstock /MWD BHA /Surface test MWD and multi-cycle valve. Orient whipstock to BHA. 06:30 - 10:00 3.50 STWHIP P WEXIT RIH w/ whipstock BHA on 4" HWDP & DP from 209' to 7,318' md. 10:00 - 11:00 1.00 STWHIP P WEXIT Tag up on top of EZSV ~ 7,320' md. Pick up 2 feet and orient and set whipstock at 9 deg right of highside. Top of slide at 7,293' md, center window at 7,300' md, bottom of slide at 7,307' md. Set down 20k to confirm set, PU 50k to shear off. 11:00 - 12:30 1.50 STWHIP P WEXIT Displace well from seawater to 9.0 ppg milling fluid. 450 gpm, 1600 si. ~ 12:30 - 17:00 4.50 STWHIP P WEXIT Establish parameters. Mill wondow in casing from 7,293' - ,~ 7,307' and plus 20 feet of new formation from center of window to 7,320' md. PU - 147k, SO - 143k, RTW - 145k 100 rpm, 7k TO on, 2k TO off 500 gpm, 2250 psi. 17:00 - 18:30 1.50 STWHIP P WEXIT Circulate and reciprocate to clean up hole. 500 gpm, 2250 psi. Pump 50 bbl super sweep pill. 285 pounds of metal recovered from milling operations. 18:30 - 19:00 0.50 STWHIP P WEXIT PuII one stand. Perform FIT to 12.0 ppg. MW 8.9 ppg, 7,293' and / 7,091' tvd at top of window. Pressure up to 1,143 psi and hold for 10 minutes - OK. 19:00 - 21:30 2.50 STWHIP P WEXIT Pull 3 stands out of hole and encounter 20k overpull and swabbing. Work pipe. Bring pumps online and circulate rotate and reciprocate. PU 150k, SO 140k, RTW - 145k. Pump 2 x surface to surface volumes at 550 gpm, 2350 psi. One 25 bbl weighted sweep and one 50 bbl super sweep pill went around. Saw formation cuttings returning throughout circulation until second super sweep pill back to surface. After super sweep back to surface, cuttings load cleaned up. Shut down pumps and monitor well. 21:30 - 00:00 2.50 STWHIP P WEXIT Pump dry job and POH from 7,127' - 1,776' md. No overpulls or swabbing. 7/20/2008 00:00 - 00:30 0.50 STWHIP P WEXIT POH from 1,776' to top of BHA ~ 209' md. 00:30 - 01:30 1.00 STWHIP P WEXIT LD milling BHA #2. Bottom mill full gauge, middle mill 1/8" under gauge, watermellon mill 1/4" under gauge. 01:30 - 02:30 1.00 STWHIP P WEXIT Pull wear bushing. Function rams. Jet stack. Install wear bushing. 02:30 - 04:00 1.50 DRILL P WEXIT MU 8.5" drilling BHA #3 - DTX619M-D6 8.5" bit, 1.5 degree motor, ARC, MWD, NM Stab, tea NM Spiral DCs, NM Stab, lea Spiral DC, Float, Jars, HWDP. Shallow test -good. 04:00 - 07:00 3.00 DRILL P WEXIT RIH on DP to 6,831' and picking up 42 joints 1x1 before RIH w/ stands from derrick. 07:00 - 08:30 1.50 DRILL P WEXIT Slip/Cut 85' of drilling line. Inspect drawworks. Service top drive, blocks and crown. rnmea: wt~zuues z:~ta4rm ' VELLHEAD = FMC AXELSON ACTUATOR = ~ 0 ~ f :B.ELEV = 74' - CF. ELI/ :OP = 4200' ' Ilax Angle = 64 @ 9279' )atum MD = 9168' )atum TV D = 8800' SS ' 3-3/8" CSG, 72#, L-80, ID = 12.347" 2510' ' liner tap 1 BOT Liner Hanger $031' ' _ ally Cemented w i#h 15.8 ppg Cement 3031 and 11.5 pPg ~ ~-5/8° smith Whq~stock ~ SI~Y NOTES: ***4-1/2" CHROMETBG*** 200p` 4-112" HES X LAND~IG N'', ID = 3.813" GA S LIFT MANDRELS ST M[? ' TVD OE1C TYPE: VLV LATCH P(7RT DATE 5 3652 3652 Q KBG2 DOME BK 1'6 0$/08108 4 5668 5574 0 KBG2 SO BK 20 08108/08 3 6894 6714 20 KBG2 DMY BK 0 07/30/08 2 7797 7i9 20 KBG2 DMY BK 0 07130108 1 8640 8315 35 KBG2 DMY BK 0 07030/08 7293' ~ KOP /Top 9-5/&" Window \ $813' 4.5",12;6#, 13-CR, VAAATOP, 7gG. 8676' X4.5' HES X Landkrg fipple ID=,3:81 r 9-518" EZSV ~ Tubing Jei C ut ,,,-779 Estimated Top of 15.8 ppg Cement ~ 8600' ~1l2" Gem ent Retainer ^870@ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 8842' 15.8 ppg Latex Cement 873fr' 4-112" x 7" BOT S-3 Packer 8770' 4.5" HES X Landing Nippbe 1D=3.81: 8801' 4.5" HF~ XN Landing. Nipple ID=3.7 $807' 4:5" Top of Liner (BOT HMCtZXP) 8970' 7", 26#, L-80, BTC-M, Liner ~ 4.5", 12.6id, 1 ~~.~-SQL f3T?, Vam Toix, LN ' ;,A • ~. PERFORATION SUMMARY ~~~~~~~~ ';,~~~' REF LOG: ???? ~4 .~. ~ ,,,,' ANGLE AT TOP PERF: 990 @ 11080' ~ '~~ ~I' ~ Note: Refer to Production DB for historical Derf data'^~ ~ fi~~6 SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 2-718" 6 6 11080 - 11100 11540-11640 O O 07/31 /08 07/31/08 I 7" LNR. 29#. L-80..0371 bof. ID = 6.184" " LNR. 4 ~. IDS 9503' DATE REV BY COMMENTS DATE REV BY COMMENTS 09115/82 ORIGINALCOMPLETION 08/02/08 N7ES SIDETRACK(06-21 B) 07116/00 CTD SIDETRACK 08/09/08 /TLH CORRECTIONS & GLV C/O 10/21/01 CWKAK CORRECTIONS 03/02/05 JLG/TLH ADPERF 04/10!07 DMS/PA MILLED OUT OBSTRUCT~N ~niasm~ TFI ivlr. rl v rin 7" MILLOUT WINDOW (06-21A) 9000'- 9005' .. 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) ~1 ,~. ~ ~h,~ . PBTD 9466' PRUDHOE BAY UNIT WELL: 06-21 A PERMR No: 2000800 API No: 50-029-20802-01 SEC 2, T10N, R14E 4812' FNL & 958' FEL RP Fvnln ra4inn /Alas4al 06-21B EZSV Plug • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 15, 2008 8:26 AM To: 'Vazquez, Eleazar' Subject: RE: 06-21 B EZSV Plug Page 1 of 1 Eli, It appear that these changes should improve the planned operations. Maintaining the barriers whether permanent or temporary is important. Nothing further is needed. I will place a copy of this message in the well files. Also, please include the permit to drill numbers in the subject line of the message. In this case, it appears this message applies to both 06-21A (200-080) and 06-21B (208-099). Call or message with any questions. Tom Maunder, PE AOGCC From: Vazquez, Eleazar [mailto:vazge0@BP.com] Sent: Tuesday, July 15, 2008 7:14 AM To: Maunder, Thomas E (DOA) Subject: 06-216 EZSV Plug ~~/~~~~ JUL ~- ~' ~~~$ Good morning Tom, It is desired to run a new type of Whipstock assembly called Smith Trackmaster Pfus Whipstock that does not require an EZSV plug. The EZSV plug was also planned to be used as a mechanical barrier during the ND BOPE phase to change the tubing spool and pack offs. However, a tested storm packer can be set before this operation to comply with our mechanical barriers policy. Finally, after reviewing our drilling fluids design, it was determined that 10.4 ppg was not required to mill the 9-5/8" casing window. Instead, 9.0 ppg should be used and the system will be weighted up to 10.6 ppg at 150 - 200' above the HRZ. The kick tolerance remains infinite for this interval of the well. Please let me know if you need any additional information or if you have any questions. Thanks in advance, Eli Vazquez BP Exploration Alaska GPB Rotary Drilling Engineer Direct: 907.564.5918 Mobile 1:907.240.8137 Mobile 2: 915.346.6430 7/15/2008 ~~ ;~ •. .. ~ t i ? ,~~ ` ~ ~ € ~ ~"~ -°~ 1~ ~~.., r `,..~ ~ -y`4~`'~ ~ ` , j SARAN PAL(N, GOVERNOR ..ti f ~S'$~ OIL A1siD ~ !~ 333 W. 7tfi AVENUE, SU47Ei100 C01~5ERVATI021T COMA9Q55IOrIT ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. ~~~~ MAY ~. 3 200$ PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-21A Sundry Number: 308-177 Dear Mr. Hobbs: ~~b O$d Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Coriunission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this/3 day of May, 2008 Encl. ~'~ U'~. l3'0~ STATE OF ALASKA s~a'O~ MA A~ OIL AND GAS CONSERVATION COM~SION ~~~ ~,;~ Y ~ ~ ~ ~~ ~ ~~ APPLICATION FOR SUNDRY APPROVAL,4laska Oii & Gas Con , 20 AAC 25.280 n.,,.~.___ 1~5Sltft~ 1. Type of Request: ®Abandon a ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®~Development ^ Exploratory 200-080 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20802-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 06-21A" Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028311 - 74 - Prudhoe Bay Field / Prudhoe Bay Pool ~ 2. PRESENT` WELL. CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9503 9103 9456 9060 N/A N/A C sin Len th Size MD TVD Burst Colla se Structural Cond r 80' 2 80' 80' 1490 470 Surfa 2510' 13-3/8" 2510' 2510' 4930 2670 Intermediate Prod c i n 8842' 9-5/8" 8842' 8596' 6870 4760 Liner 482' 7" 8519' - 9001' 8279' - 8752' 8160 7020 721' 2-3/8" 8782' - 9503' 8537' - 9103' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9190' - 9314' 8886' - 8945' s-1rz" x a-1rz" x 3-112", 17# x 1216# x 9.3# L-80 8958' Packers and SSSV Type: 9-518" x 5-1/2" Baker FHL Packer Packers and SSSV MD (ft): 8448' 4-1/2" x 3-1/2" Baker FB-1 Packer 8930' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 16, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact EieaZar'e'~ Vazquez, 564-5918 Printed Name Gr g Ebbs Title Engineering Team Leader ~ Prepared By NamelNumber: Signature Phone 564-4191 Date ~ ~ c)~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: - Conditions of approval: Notify Commission so that a representative may witness p ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~NEc~~ ~C~`S~i~-eR3C3c3 5~ ~.~ ~! ~ ~ -c~'~ _ ~ Other: ~ ~ ~~'~ ~~`~ ~ ~ ~ ACS Subsequent Form Required: ~3 ~ A roved B U COMMISSIO ER THE COMMISSION Date Form 10-403 6/2006r ~ ~~ ~ ~ - ' ~~ ~~ Submit In Duplicate ~ • by G ~~ 06-21 A Well Type: Producer Current Status: This well is completed with 5-1/2" L-80 tubing and is currently shut-in. CMIT-T x IA Passed to 3000 psi 11/14/05 MIT-IA Passed 3000 psi 10/16/07 MIT-OA Passed to 2000 psi 10/16/07 Request: Approval is requested for the P&A of Prudhoe Bay well 06-21 A. 06-21 was originally completed in 1982 and currently has one sidetrack (well 06-21 A) which is a Zone 2 & 3 Ivishak producer that is shut-in. Additional perforations were added throughout 2001. However, results were disappointing with the well testing at less than 200 bopd and 300 bwpd. Well 06-21A has been uncompetitive for several years and shut-in for extremely high gas and water productions. A horizontal sidetrack is required to bring 06-21 back on production. Scope of Work: The sidetrack plan for the 06-21 B well (a Zone 2B/2C producer) includes a whipstock departure from the 9-5/8" liner at 7300' MD. The 8-1/2" hole will be drilled to the Top of the Sag River where a 7" liner will be run and fully cemented. In addition, a scab liner will be tied back and fully cemented to 3000' MD. The production hole will be drilled to a final well TD of 11,360' MD where a solid liner will be run and fully cemented to TD. A 4-1/2" completion will then be run to complete the well. The 06-21 B sidetrack is currently scheduled for Nabors 7ES beginning August 2008. The pre-rig work for this sidetrack will begin as soon as possible. MASP: 2384 psi Estimated Pre-Rig Start: May 16, 2008 Estimated Start Date: August 1, 2008 Pre-ria prep work: S 1 RU, drift for cement retainer and 'et cutter. S 2 Pull DSSSV @ 2153' O 3 Fluid ack the tubin and inner annulus w/seawater/diesel. C 4 Set a cement retainer inside the 4-1/2" at 8700' ands ueeze --10 bbls of cement into erfs and fill the tubing from a,4,~,F' ~~n to t3.7~n'_ Un-sting and lay 100' of cement (~ 1.5 bbls) of cement on top of retainer. i. 15.8 ppg class G cement calculations: " i. 2-3/8 liner = 9,466' - 8,782', 684' X .0039 = 2.7 bbls ii. 4-1 /2" tubing below cement retainer = 8,782'-8700', 82' x 0.0152 = 1.2 bblsf iii. 4-1/2" tubing above cement retainer = 100' x 0.0152 = 1.5 bbls ~/ iv. Cement squeezed into perfs = 10 bbls v. Total with 0.6 bbls excess) = 16 bbls F 5 Test to 3500 si. S 6 Ta TOC E 7 Jet cut the 5-1/2" tubin in the middle of a full ~oint at 7800' MD. F 8 OMIT - T x IA to 3,500 si for 30 minutes. MIT - OA to 2,000 si for 30 minutes • F 9 Circulate the well to sea water and freeze rotect with diesel to 2,200' MD. F 10 Bleed all casin and annulus ressures to zero si. W 11 Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. W 12 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form Proposed Procedure: 1. MI / RU Nabors rig 7ES 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Pressure test MIT-OA to 2,000 psi for 30 minutes. 4. Set TWC and test from below to 1,000 psi for 30 minutes. 5. Nipple down tree. Nipple up and test BOPE to 3,500 psi. Pull TWC. 6. RU and pull the 5-1/2" TBG-IPC, 17#, L-80 tubing from the pre-rig jet cut at 7800' MD. Spool up the control lines. 7. RU E-line. MU 8-1/2" gauge ring /junk basket /casing collar locator (CCL). RIH and tag tubing stump at 7800' MD to confirm access to run an EZSV. If gauge ring /junk basket indicates a scraper run is needed, PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out weH to 7450' MD. POOH. 8. On E-line, RIH with HES EZSV. Set bridge plug at 7325' MD, as required to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 9. Pressure-test the 9-5/8" casing to 3,500 psi for 30 charted minutes. 10. Bleed 9-5/8" annulus pressure. 11. Change 9-5/8" pack-off (the mandral pack-off can be pulled through the BOP stack without nippling down). 12. Test pack-off to 5,000 psi or as recommended by FMC Rep. 13. ~~ ~ 14 ND BOPE and set back. ND and remove the tubin spool ~ . ~ ~=,~ 15. g . Change tubing spool and test to 5,000 psi or as recommended by FMC Rep. ~yQ 16. NU and test BOP. tA''t~ 17. P/U and RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly on 4" drill pipe. Orient whipstock per Schlumberger Rep and set on bridge plug. Shear off the whipstock. 18. Displace the well to 10.4 ppg LSND based milling fluid. Completely displace the well prior to haninninn tha millinn nncra+innc 19. Mill window in 9-5/8" casing at ± 7,300'MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 20. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg. POOH. 21. M/U 8-~/z" GR/RES/PWD/MWD assembly. RIH, kick off and drill the 8'/z" intermediate section with 10.4 - 10.8 ppg LSND drilling fluid. 22. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well clean, short trip to THRZ or higher as needed. POOH. 23. Change out to 7" rams, and test. 24. MU and run 1,753' of 7", 26#, L-80, BTC-M liner to bottom on drill pipe. Circulate and condition the hole. 25. Cement the entire 7" liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at 7,150' MD. Set the hanger and packer, displace cement with mud. 26. Circulate bottoms up, POOH, UD liner running tool (LRT). 27. Run a 7" scab liner from the top of the 7" liner to 3000' MD. Fully cement the scab liner. Stab into the 7" liner tieback receptacle, and set the packer. 28. Pressure test the 7" tieback to 3500 psi for 30 minutes after sufficient compressive strength is obtained. • • 29. M/U the first 6-%8" Dir/GR/Res assembly with a roller cone bit and RIH. Wash down to the cement plug in the 7" liner. 30. Test the liner to 3,500 psi for 30 charted minutes. 31. Displace to 8.4 ppg Flo Pro Fluid. 32. Drill out of cement and float equipment to shoe. 33. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.1 PPg• 34. Drill the 6-1/8" production interval as per directional plan to end of the build section. 35. POOH for PDC bit. 36. POOH, PU second 6-1/8" Neu/Den/GR/Res BHA with PDC. 37. RIH, drill ahead to TD. 38. POOH. VD BHA. 39. Run and fully cement 2,200' of 4-1/2", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. Cement the liner. A pert pill will be left in the 4-1/2" liner. 40. Set liner top packer and displace well to clean seawater above the liner top. 41. POOH, UD LRT. 42. Pressure test casing and liner to 3,500 psi for 30 minutes. 43. RU DPC pert guns, RIH and perforate. Pert intervals to be supplied by asset. 44. R/U and run a 4~h", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-1/2" liner tie back sleeve. 45. Space out and make up tubing hanger per Cameron Rep. 46. Land the tubing hanger, and run in lock down screws. 47. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 48. Set a BPV. 49. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 50. Freeze protect the well to 2,200' TVD. Secure the well. 51. RD and Move Off. Drilling Engineer: Eli Vazquez (907) 564-5918 Production Engineer: Ana Maria Seltenright (907) 564-4418 Geologist: Doug Stoner (907) 564- 5652 ATTACH: Current Schematic Pre-Rig Schematic Proposed Schematic YREE= ~ 5-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4200' Max Angle = 64 @ 9279' Datum MD = 9168' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID =1.75" @ 9192' CTM 2-7/8" LINER ~5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9-5/8" X 7" BKR LNR HGR, ID = ? ~ 8519' 3-1 /2" X 2-3/8" LNR XO, ID = 1.910" 9-518" CSG, 47#, L-80, ID = 8.681" ~-~ 4-1/2" TBG-PC, 12.6#, .0152 bpf, ID = 3.958" -{ 15.8 ppg Latex Cement 3-1/2" TTRPC, 9.3 #, .0087 bpf, ID = 2.992" ~-j 8957' PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLEATTOPPERF: 61 @9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9190 - 9240 O 02/14/05 1-11/16" 6 9250 - 9270 O 12!05/03 1-11/16" 4 9270 - 9286 O 10/20/01 1-11/16" 4 9286 - 9296 O 04/17/01 1-11/16" 4 9296 - 9306 O 02/24/01 1-11/16" 4 9306 - 9314 O 11/23/00 1-11/16" 4 9306 - 9314 O 09/28/00 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 2-3/8" LNR 4.6#, L-80, .0039 bpf, ID = 1.941" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 09/15/82 ORIGINAL COMPLETION 04/10/07 DMS/PAG MILLED OUT OBSTRUCT~N 07/16!00 CTD SIDETRACK 04/23/07 SPF/TLH DSSSV C/O 8 UPDATE 10/21/01 CH/KAK CORRECTIONS 10/15/07 TEL/PJC GLV C/O 03/02/05 JLG/TLH ADPERF 05/01/08 EV 2-3/S' LNR CEMENT 09/24/05 EZLlPJC WA V ER SFTY NOTE DELETED 12/04/05 DAV/TLH GLV C/O PRUDHOE B WELL: 06 PERMfr No: X20 API No: 50 f10N, R14E 4E BP Exploratio 0~6-21 A II W 5-1/2" CAMCO BAL-O SSSVN, ID = 4.562" WfTH DSSSV, ID = 2.75" (04/23/07) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2908 2834 0 MMIG DMY RK 0 10/15/07 2 4781 4681 20 MMIG DMY RK 0 10/15/07 3 6186 5980 23 MMIG DMY RK 0 10/15/07 4 7127 6860 18 MMIG DMY RK 0 07/16/00 5 7631 7340 18 MMIG DMY RK 0 07/16/00 6 7706 7412 16 MMIG DMY RK 0 07/16/00 7 8020 7714 14 MMIG DMY RK 0 07/16/00 8 8099 7791 14 MMIG DMY RK 0 07/16/00 9 8293 7982 8 MMIG DMY RK 0 10/15/07 10 8369 8057 11 MMIG DM Y' RK 0 08/24/02 'DMY HAS EXTENDED PKG $406' 5-1/2" CAMCO SLD SLV, ID = 4.50" $434' 5-1 /2" BKR PBR ASSY, ID = ? $44$' 9-5/8" X 5-1 /2" BKR FHL PKR, ID = ? 8457' 5-1/2" X 4-1/2" XO, ID = 3.958" 8782' 3.70" BKR DEPLOY SLV, ID = 3.00" 8924' ~4-1/2" X 3-1/2" XO, ID = 2.992" $930' -~4-1/2" X 3-1/2" BKR FB-1 PKR 8939' 3-1/2" CAMCO NO-GO NIP BEHIND LINER 3958' ~ 3-1/2" WLEG, ID = 2.992" 3956' ElMD Tf LOGGED ON 04/28/83 7" MILLOUT WINDOW (06-21A) 9000' - 9005' I 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) ~~--r 9466' 1 TREE_ 5-1/8" FMC ~ 06-21A ~PRE-RIG F-1 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2510' Minimum ID =1.75" @ 9192' CTM 2-7/8" LINER Tubing Jet C ut 7800' ~ ~ 5-1 /2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9-5/8" X 7" BKR LNR HGR, ID = ? H $519' 4-1/2" Cement Retainer -8700' 3-112" X 2-3/8" LNR XO, 1D = 1.910" $7$T 9-5/8" CSG, 47#, L-80, ID = 8.681" $842' 4-1/2" TBG-PC, 12.6#, .0152 bpf, ID = 3.958" 8923' 15.8 ppg Latex Cement 3-1/2" TTP-PC, 9.3 #, .0087 bpf, ID = 2.992" 8957' PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLE AT TOP PERF: 61 @ 9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9190 - 9240 O 02/14/05 1-11!16" 6 9250 - 9270 O 12/05/03 1-11/16" 4 9270 - 9286 O 10/20/01 1-11/16" 4 9286 - 9296 O 04/17/01 1-11116" 4 9296 - 9306 O 02!24/01 1-11/16" 4 9306 - 9314 O 11/23/00 1-11116" 4 9306 - 9314 O 09/28/00 ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ . ~~ ~ .. 2" CAMCO BAL-O SSSVN, ID = 4.562" 1 DSSSV, ID = 2.75" (04/23/07) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2908 2834 0 MMIG DMY RK 0 10/15/07 2 4781 4681 20 MMIG DMY RK 0 10/15/07 3 6186 5980 23 MMIG DMY RK 0 10/15/07 4 7127 6860 18 MMIG DMY RK 0 07/16/00 5 7631 7340 18 MMIG DMY RK 0 07/16/00 6 7706 7412 16 MMIG DMY RK 0 07/16/00 7 8020 7714 14 MMIG DMY RK 0 07/16/00 8 8099 7791 14 MMIG DMY RK 0 07/16/00 9 8293 7982 8 MMIG DMY RK 0 10/15/07 10 8369 8057 11 MMIG DM Y* RK 0 08/24/02 *DMY HAS EXTENDm PKG 8406' S-1/2" CAMCO SLD SLV, ID = 4.50" 8434' S-1 /2" BKR PBR ASSY, ID = ? $t{4$' 9-5/8" X 5-1/2" BKR FHL PKR, ID = ? 8457' 5-1/2" X4-1/2" XO, ID= 3.958" $7$2' 3.70" BKR DEPLOY SLV, ID = 3.00" 06-21A Perforations plugged and abandonded with 15.8 ppg cement to -8600' 8924' 4-1/2" X 3-1/2" XO, ID = 2.992" 1 PKR 1/2" BKR FB ' 7" X 3 - - 8930 ~~ •;~, ~, 8939' 3-1/2" CAMCO NO-GO NIPI BEHIND LINER ' - ,,` 8958' 3-1/2" WLEG, ID = 2.992" { °''' $956' ELMD TT LOGGED ON 04/28/83 '~~ ~ 7° nnn L Oi n-wwnnW (n6.21A) 9000' - 9005' _ I 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) PBTD 9466' 4.6#, L-80, .0039 bpf, ID = 1.941" I~ 9503' i , DATE REV BY COMMENTS DATE REV BY COMMENTS 09115182 ORIGINAL COM PLETION 04/10/07 DMS/PAG MILLED OUT OBSTRUCTION 07116100 CTD SIDETRACK 04/23/07 SPF/TLH DSSSV C/O & UPDATE 10/21/01 CH/KAK CORRECTIONS 10/15/07 TEL/PJC GLV C/O 03102/05 JLG/TLH ADPERF 05/01J08 EV PROPOSED PRE-RIG WORK 09124/OS EZL/PJC WANER SFTY NOTE DELETED 12/04/05 DAV/TLH GLV C/O PRUDHOE B WELL: 06 PERMIT No: X20 API No: 50 f10N, R14E 4f BP Exploratio 'TREE= ~ 5-1/8" FMC WE4 LHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4200' Max Angle = 64 @ 9279' Datum MD = 9168' Datum ND= 8800'SS 06-21 B ~'ROPOSED 13-3/8" CSG, 72#, L-80, ID = 12.347" 2510' 7" scab liner top / BOT Liner Hanger 3000' Fully Cemented w ith 15.8 RPa Cement -3000' 9-5/8" BOT Whipstock ~ 7322' 9-518" ¢SV Plug 7325' Tubitg Jet C ut ~ 7800' 5-112" CAMCO SLD SLV, ID = 4.50" 8406' 5-1/2" BKRPBRASSY, ID=? 8434' 9-5/8" X 5-1/2" BKR FHL PKR, ID = ? 8448' Estimated Top of 15.8 ppg Cement 8600' 4-1/2" Cement Retainer -8700' 9000' I-i T', 26la`, L-80, BTGM, Liner ~ 15.8 ppg Latex Cement ~ PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLEAT TOP PERF: 61 @ 9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9190 - 9240 O 02/14/05 1-11/16" 6 9250 - 9270 O 12/05/03 1-11/16" 4 9270 - 9286 O 10/20/01 1-11/16" 4 9286 - 9296 O 04/17/01 1-11/16" 4 9296 - 9306 O 02/24/01 1-11 /16" 4 9306 - 9314 O 11 /23/00 1-11/16" 4 9306 - 9314 O 09/28/00 L-80..0371 bof. ID = 6.184" H Qd2f1' °= i SAFET~ES: SAFETY NOTES: BKR FHL PKRS HAVE mTEST PRESS. LIMITS. CALL WIE @X5102 PRIOR TO ANY PT WORK. DON'T PULL DGLV #10 -REQUIRES IXT. PKG FORANN COMM PROBLEM. 2100' 4-1/2" HES X LANDING NIP, ID = 3.813" GAS LIFT MANDRELS iT MD N D DEV TYPE V LV LATCH PORT DATE 6 5 4 3 2 1 7150' T', 26#, L-80, BTGM, Scab Liner 7150' T' LNR Top Packer (BOT HCM2XP) 7300' KOP /Top 9-5/8" Window 4.5", 12.6#, 13-CR, VAM TOP, TBG. Fully Cemented Liner 15.8 ppg Class G 8755' 4.S' HES X Landing Nipple ID=3.813" $771' 5' x T' BOT S-3 Packer 8796' 4.S' HES X Landing Fipple ID=3.813" 8839' 4.S' HES XN Landing Nipple ID=3.7S' 8850' 4.S' LNR Top Packer (BOT HCM2XP) 11360' I~ 4.5", 12.6#, 13Cr-80, V am Top, Liner ~ 7" MILLOUT W INDOW (06-21A) 9000'- 9005' 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) .. '- ''"~. , PBTD 9466' ID = 1.941" 11 9503' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/15/82 ORIGINAL COMPLETION 04/10/07 DMS/PAG MILLED OUT OBSTRUCTION 07/16/00 CTD SIDETRACK 04/23/07 SPF/TLH DSSSV GO & UPDATE 10/21/01 CWKAK CORRECTIONS 10/15/07 TEL/PJC GLV GO 03/02/05 JLG/TLH ADPERF 02/25/08 EV 06-216 PROPOSED 09/24/05 ¢L/PJC WAIVER SFTY NOTE DELETED 12iQ4iu5 DAVI~LH GL\i C;~~ PRUDHOE BAY UNIT WELL: 06-21 A PERMIT No: 2000800 API No: 50-029-20802-01 SEC 2, T10N, R14E 4812' FNL & 958' FEL BP Exploration (Alaska) Schlumbepger NO. 4249 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, SuitEt 100 Anchorage, AK 99501 ð()()-OðÒ 151 (¿; '3 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 06-24A 11637328 RST 04/16/07 1 1 L2-16 11414768 RST 10/07/06 1 1 06-07 11637123 RST 05/06/07 1 1 06-21A 11628766 MCNL 04/09/07 1 1 F-09A 11657123 CBL 05/06/07 1 09-15 11630475 CEMENT IMAGE LOG 05/06/07 1 03-36A 11745217 USIT CORROSION 05/03/07 1 03-36A 11745217 USIT CEMENT 05/03/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. ~~E,.;;(~r= -\./E: rj Petrotechnical Data Center LR2-1 ,:1'\.""" "~\) ~!..".- ~ . .,'''''' ,..... 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street. Suite 400 Anchorage. AK 99503-2838 ATTN Beth /1 fl. I j! Received by: J J:.f~.(~ '-..... t1AY 3, 1 Z007 sCANNED MA'f 3 1 2007 Date Delivered: Com:H::""· -'j- OS/29/07 . . STATE OF ALASKA ) ~!Of:r . . ALASKA OIL AND GAS CONSERVATION COMMISSION . veo REPORT OF SUNDRY WELL OPERATIONS APR I 9 2005 Alaska Uil & Gas Cons. Comm,'s . Stimulate 0 A QtherU S'O 1 nCnoraga WaiverO Time ExtensionLJ Re-enter Suspended Well 0 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: ) Repair Well 0 Pull Tubing D Operation Shutdown D Pluç PerforationsD Perforate New PoolD Perforate ŒJ 4. Current Well Class: Development Œ] Exploratory 0 5. Permit to Drill Number: 200-0800 6. API Number 50-029-20802-01-00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 74.00 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Stratigraphic 0 Service 0 9. Well Name and Number: 06-21 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 9503 feet true vertical 9103.0 feet Effective Depth measured 9456 feet true vertical 9059.7 feet Casing CONDUCTOR LINER LINER LINER PRODUCTION SURFACE Perforation depth: Length 80 481 1 716 8812 2479 Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 7" 29# L-80 3-1/2" 9.3# L-80 2-3/8" 4.7# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 33 113 33.0 - 113.0 1490 470 8519 - 9000 8278.6 - 8751.1 8160 7020 8786 - 8787 8541.2 - 8542.2 10160 10530 8787 - 9503 8542.2 - 9103.0 11200 11780 30 - 8842 30.0 - 8596.2 6870 4760 32 - 2511 32.0 - 2510.9 4930 2670 Measured depth: 9190 - 9215,9215 - 9240,9250 - 9270,9270 - 9286,9286 - 9296,9296 - 9306,9306 - 9314 True vertical depth: 8885.8 - 8897.71,8897.71 - 8909.5,8914.16 - 8923.23,8923.23 - 8930.39,8930.39 - 8935.31,8935.31 - 8940.66 8940.66 - 8945.26 Tubing ( size, grade, and measured depth): 5-112" 17# L-80 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 @ 28 @ 8457 @ 8924 8457 8924 8956 Packers & SSSV (type & measured depth): 3-1/2" Baker FB-1 Packer 5-1/2" Baker FHL Packer @ 8930 @ S~~NED APR 2 ~) LDOS 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations _ Oil-Bbl 138 302 Representative Daily Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 0.8 5370 210 10.3 1867 250 Tubing Pressure 211 373 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil[!] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Contact Printed Name Development ŒJ Service D Garry Catron Garry Catron .ø~ C--~ Signature Form 10-404 Revised 4/2004 Title Production Technical Assistant Phone 564-4657 o F~ I h 1.1 IA\ Lc~:::M (\N\ ( ,.... ¡ I\.. ~jJLV Date 4/13/05 9/~ ) 06-21 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/14/05 Perforate 92151-92401 6 SPF 02/15/05 Perforate 91901-92151 6 SPF BBLS 438 1 % KCL 212 60/40 Methanal 275 Dead Crude 650 TOTAL FLUIDS PUMPED Page 1 ) TREE = WELLHEA;D = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = 5-1/8" FMC FMC AXELSON 74' ) 4200' 64 @ 9279' 9168' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2510' Minimum ID = 1.910" @ 8787' 3-1/2" X 2-7/8" LNR XO 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 8434' 9-5/8" X 7" BKR LNR HGR 1-1 8519' 3-1/2" X 2-3/8" LNR XO, ID = 1.910" 1-1 8787' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 8842' ~ 4-1/2" TBG-PC, 12.6#, .0152 bpf, ID = 3.958" 1-1 8923' 3-1/2" TIP-PC, 9.3 #, .0087 bpf, ID = 2.992" 1-1 8957' ÆRFORA TION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLEATTOPÆRF: 61 @ 9190' Note: Refer to Production DB for historieal perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 6 9190-9240 0 02/14/05 1-11/16" 6 9250 - 9270 0 12/05/03 1-11/16" 4 9270-9286 0 10/20/01 1-11/16" 4 9286-9296 0 04/17/01 1-11/16" 4 9296-9306 0 02/24/01 1-11/16" 4 9306 - 9314 0 11/23/00 1-11/16" 4 9306 - 9314 0 09/28/00 7" LNR, 29#, L-80, ID = 6.184" 1-1 9420' DATE 09/15/82 07/16/00 10/21/01 10/20/01 09/20/03 12/05/03 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CH/KA K CORRECTIONS JLJ/KAK ADPERFS CAO/KK SET DSSSV JRC/TLP ADD ÆRF 06-21A ~.".:1..'" .. ~ L ~ ~ L' :8: I Z ---i . 1 SAFETY NOTES: ***IAxOA COMM. OPERATING LIMITS: MAX lAP = 200 ), MAX OAP = 2000 PSI (12/28/04 WAIVER)*** BKR FHL PKRS t-tÁVEREDUCEDTEST PRESS. LIMITS. CALL WIE @X5102 PRIOR TO ANY PT WORK. DON'T PULL DGLV #10 . REQUIRES EXT. PKG FOR ANN COM M PROBLEM. 2172' 1- 5-1/2" CAMCO BAL-O SSSVN, ID = 4.562" DSSSV (09/20/03) GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT o MMIG DOME RK 16 20 MMIG DOME RK 16 23 MMIG DOME RK 16 18 MMIG DMY RK 0 18 MMIG DMY RK 0 16 MMIG DMY RK 0 14 MMIG DMY RK 0 14 MMIG DMY RK 0 8 MMIG SO RK 22 11 MMIG DMY RK 0 I I \ ST MD 1VD 1 2908 2834 ~ 2 4781 4681 3 6186 5980 4 7127 6860 5 7631 7340 6 7706 7412 7 8020 7714 8 8099 7791 9 8293 7982 10 8369 8057 DATE 03/10/04 03/10/04 03/10/04 07/16/00 07/16/00 07/16/00 07/16/00 07/16/00 03/10/04 08/24/02 8406' 1-1 5-1/2" CAMCO SLIDING SLV, ID = 4.50" 8434' 1-1 5-1/2" BAKER PBRASSY 1 8448' 1-1 9-5/8" X 5-1/2" BKR FHL PKR 1 8457' 1-1 5-1/2" X 4-1/2" XO, ID = 3.958" 1 8782' 1-1 3.70" BKR DEPLOYMENT SLV, ID = 3.00" ... 8924' 8930' 8939' 1-1 4-1/2" X 3-1/2" XO (BEHIND LNR) 1 1-1 4-1/2" X 3-1/2" BKR FB-1 PKR (BEHIND LNR) 1-1 3-1/2" CAMCO NO-GO NIP (BEHIND LNR) 1 8958' 8956' 1-1 3-1/2" WLEG (BEHIND LNR) 1 1-1 ELMD TI LOGGED 04/28/83 (BEHIND LNR) 7" LNR MILLOUT WINDOW 9000' - 9005' (OFF CMT RAMP) 9466' 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.941" 1-1 9503' DA TE REV BY COMMENTS 03/18/04 JLJ/TLH GL V C/O 12/28/04 RDJ/PAG WAIVER SAFETY NOTE 03/02/05 JLG/TLH ADPERF PRUDHOE BA Y UNIT WELL: 06-21A PERMIT No: 2000800 API No: 50-029-20802-01 SEC 2, T10N, R14E 4812' FNL & 958' FEL BP Exploration (Alaska) MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc REPORT OF SUNDRY WELL OPER lQ~ ;]1 2004 T l:r?2<: rnn<: ~ 1. Operations Performed: RepairWellD PluQ PerforationsD Stimulate ŒI ~ge Abandon 0 Alter Casing D Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionO Change Approved Program D Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒI ExploratoryD 200-0800 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20802-01-00 7. KB Elevation (ft): 9. Well Name and Number: 74.00 06-21 A 8. Property Designation: 10. Field/Pool(s): ADL-o028311 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9503 feet true vertical 9103.0 feet Plugs (measured) None Effective Depth measured 9456 feet Junk (measured) None true vertical 9059.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 - 113 33.0 - 113.0 1490 470 Liner 481 7" 29# L-80 8519 - 9000 8278.6 - 8751.1 8160 7020 Liner 1 3-1/2" 9.3# L-80 8786 - 8787 8541.2 - 8542.2 10160 10530 Liner 716 2-3/8" 4.7# L-80 8787 - 9503 8542.2 - 9103.0 11200 11780 Production 8812 9-5/8" 47# L-80 30 - 8842 30.0 - 8596.2 6870 4760 Surface 2479 13-3/8" 72# L-80 32 - 2511 32.0 - 2510.9 4930 2670 Perforation decth: Measured depth: 9250 - 9270,9270 - 9286,9286 - 9296, 9296 - 9306,9306 - 9314 True vertical depth: 8914.16 - , 8923.23 - 8923.23, 8930.39 - 8930.39, 8935.31 - 8935.31, 8940.66 - 8940.66 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 28 - 8457 4-1/2" 12.6# L-80 @ 8457 - 8924 3-1/2" 9.3# L-80 @ 8924 - 8956 Packers & SSSV (type & measured depth): 3-1/2" Baker FB-1 Packer @ 8930 5-1/2" Baker FHL Packer @ 8448 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9250 - 9314 Treatment descriptions including volumes used and final pressure: 65 Bbls HCL, 65 Bbls 9-1 HCL-HF @ 3551 psig 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: 171 0 4026 911 227 Subsequent to operation: 169 0 3976 100 218 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development[! ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - ~ OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907} 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature Jj _. .. C .-;/-;-;;.. Phone 564-4657 Date 10/13/04 ~ r" r-.. , - . . . .. Form 10-404 Revised 4/2004 U K ILJ 1/\1 A L g STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION 5 Ð;cM5 ~ 06-21 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/04/04 COMPLETE BOP TEST. FCO. MU 1.5" SLICK BHA W/1.5" JSN. FLUID PACK IA W/1% KCL FOLOWED BY 50/50 METH. BLEED DOWN WHP AND RIH WHILE FLUID PACKING WELL AND TAKING RETURNS. TAG UP ON GLM AT 4781' CTM. ATTEMPT TO WORK BY W/O SUCCESS, POOH. ATTEMPT TO STRAIGHTEN REMAINING MEMORY OUT OF COIL, ADD ANOTHER STINGER, ROUND OFF NOZZLE, AND RBIH. CLEAN OUT LINER W/23 BBLS OF NEW FLO PRO, SHORT TRIPPING THROUGH 9130', AND CIRCULATE OUT.1ST STAGE PUMP 25 BBL 3 % NH4CL, 10 BBL 12% HCL AND 10 BBL 9 % - 1 % HK. SAW GOOD WHP DROP WHEN ACID HIT PERFS. 09/05/04 COMPLETE 2 ND STAGE ACID TREATMENT. MAKE SEVERAL PASSES FROM 9200'- 9350' PER PROGRAM. PUMP 55 BBLS 12% HCL, 55 BBLS 9% -1% HCL - HF, OVER DISPLACE WITH 106 BBLS 3 % NH4CL. SAW VERY GOOD HF ACTION ON PERFS. POOH. FREEZE PROTECT COIL WITH METHANOL. TURN WELL OVER TO ASRC FOR ACID FLOWBACK. FLUIDS PUMPED BBLS 349 Filtered 1 % KCL 174 50/50 Methonal 23 FloPro 131 3% NA4CL 65 12% HCL 65 9%-1% HCL-HF 807 TOTAL Page 1 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull Tubing D Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Perforate Œ] WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0800 OtherD Name: BP Exploration (Alaska), Inc. 74.00 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Development Œ] Stratigraphic 0 9. Well Name and Number: 06-21 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20802-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9503 feet true vertical 9103.0 feet Plugs (measured) Junk (measured) None Effective Depth measured 9456 feet true vertical 9059.7 feet None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 33 113 33.0 113.0 1490 470 Liner 481 7" 29# L-80 8519 - 9000 8278.6 - 8751.1 8160 7020 Liner 1 3-1/2" 9.3# L-80 8786 - 8787 8541.2 - 8542.2 10160 10530 Liner 716 2-3/8" 4.7# L-80 8787 - 9503 8542.2 - 9103.0 11200 11780 Production 8812 9-5/8" 47# L-80 30 - 8842 30.0 - 8596.2 6870 4760 Surface 2479 13-3/8" 72# L-80 32 - 2511 32.0 - 2510.9 4930 2670 Perforation depth: Measured depth: 9250 - 9270, 9270 - 9286, 9286 - 9296, 9296 - 9306, 9306 - 9314 True vertical depth: 8914.16 - 8923.23, 8923.23 - 8930.39, 8930.39 - 8935.31, 8935.31 - 8940.66, 8940.66 - 8945.26 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# L-80 3-112" 9.3# L-80 3-1/2" Baker FB-1 Packer 5-1/2" Baker FHL Packer @ 28 @ 8457 @ 8924 @ @ 8457 8924 8956 8930 8448 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RØ)MS BfL -- .l _l 1004 13 Prior to well operation: Subsequent to operation: Oil-Bbl I Gas-Met Water-Bbl Casinq Pressure Tubing Pressure 42 I 3.9 257 550 254 Well Shut-in 540 229 ReDresentative Dailv Averaae Production or Iniection Data 14. Attachments: ~(I"¡:~t~U¡~¡rE:fï:I' ß~jYH) j .c::tJ 2004. ~~nU'\Oð~G{!"» mJ~h'~ .." /49 ' Copies of Logs and Surveys run - 15. Well Class after proposed work: ExploratoryD Development ŒJ Service D Daily Report of Well Operations. 2:{ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garr Catron 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A 1f C.O. Exempt: N/A Signature Title Production Technical Assistant Phone 564-4657 Date 3/10/04 Form 10-404 Revised 12/2003 OR 06-21 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/04/03 MIRU CTU # 9 - RIH WITH PDS GR/CCL LOGGING TOOL, UNABLE TO GET BELOW 926T LOG FROM 926T TO 9000'. -POH. GOOD OAT. MU AND RIH WITH GUN#1. (20') JOB IN PROGRESS. 12/05/03 Perforate 9250'-9270' 6 SPF FLUIDS PUMPED BBLS 152 60/40 Methonal 149 1 % KCL 301 TOTAL Page 1 TRŒ= 5-1/8" FMC WELU-EA D = FMC AC1UATOR= AXB..SON KB. ELBI = 74' BF. ELBI = KOP= 4200' Max AnQle = 64 @ 9279' Datum MD = 9168' Datum lV D = 8800' SS 06-21A SAÆ1Y NOTES: BKR AiL PKRS HAVE RBJUCED TEST PRESSURE UMITS. CALL WIE, EXT. 5102, PRIOR TO ANYPTWORK. DO NOT PULL OOLV #10 - REQUIRES EXT. PKG FOR ANN COM M PROBLEM. 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 1.910" @ 8787' 3-1/2" X 2-7/8" LNR XO 5-1/2"TBG-FÇ, 17#, L-80, .0232 bpf, ID =4.892" 8434' 9-5/8" X 7" BKR LNR HGR 8519' I 3-1/2" X 2-3/8" LNR XO, ID = 1.910" 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I I 4-1/2" TBG-Fe, 12.6#, .0152 bpf, ID = 3.958" I 8923' 3-1/2" TIP-Fe, 9.3 #, .0087 bpf, D = 2.992" 1 PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLEATTOP ÆRF: 64 @ 9270' t\bte: Refer to Produetion DB for historieal !Srf data SIZE SA= NTERV A L Opn/Sqz DATE 1-11/16" 6 9250 - 9270 0 12/05/03 1-11/16" 4 9270 - 9286 0 10/20/01 1-11/16" 4 9286 - 9296 0 04/17/01 1-11/16" 4 9296 - 9306 0 02/24/01 1-11/16" 4 9306 - 9314 0 11/23/00 1-11/16" 4 9306 - 9314 0 09/28/00 7" LNR, 29#, L-80, ID = 6.184" I (I) 2172' 5-1/2"CAMCO BAL-O SSSVN, ID =4.562" DSSSV (09/20/03) GAS LIFT MANæELS TVD ŒV 1YÆ VLV LATa-i FORT 2834 0 rvtv1IG DOME RK 16 4681 20 rvtv1IG DMY RK 0 5980 23 rvtv1IG DOME RK 16 6860 18 rvtv1IG DMY RK 0 7340 18 rvtv1IG DMY RK 0 7412 16 rvtv1IG DMY RK 0 7714 14 rvtv1IG DMY RK 0 7791 14 rvtv1IG DMY RK 0 7982 8 rvtv1IG SO RK 20 8057 11 rvtv1IG DMY RK 0 [)6. TE 12A:>1/03 07/16/00 12A:>1/03 07/16/00 07/16/00 07/16/00 07/16/00 07/16/00 12A:>1/03 08/24/02 5-1/2" CA rv"C0 SLIDING SL V, ID = 4.50" 5-1/2" BA KER PBR ASSY --1 9-5/8" X 5-1/2" BKR FHL PKR I 5-1/2" X 4-1/2" XO, ID= 3.958" ¡ 3.70" BKR DEA...OY MENT SLV, D = 3.00" --t 4-1/2" X 3-1/2" XO (BEHND LNR) I --t 4-1/2" X 3-1/2" BKR FB-1 PKR (BEHND LNR) I --1 3-1/2" CArv"CO NO-GO NIP (BEHND LNR) I 8958' --1 3-1/2" WLEG (BEHNDLNR) I 8956' 1--1 ELMO TI LOGGED 04128/83 (BB-IIND LNR) I DATE REV BY COMMENTS DATE RBI BY CO M'v1 ENTS 09/15/82 ORIGINAL COMPLETION 09/20103 CAO/KK SET DSSSV 07/16/00 CTD SIDETRACK 12/05103 JRC/1LP A 00 ÆRF 02/21/01 MH'tp CORRECTIONS 02/12104 KBlKAK GLV CORRECTIONS 10/21/01 CHIKA K CORRECTIONS 10/20/01 JLJIKAK ADÆRFS 08/31/02 DTRlTP GL V C/O ST MD 1 2908 2 4781 3 6186 4 7127 5 7631 6 7706 7 8020 8 8099 9 8293 10 8369 8782' 7" LNR MlLOUTWINDOW 9000' - 9005' (OFF Ov1T RAMP) 9466' 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.941" -I 9503' ffiLDHOE BA Y UNIT WELL: 06-21A PERMIT No: 2000800 AR No: 50-029-20802-01 SEC 2, T10N, R14E 4812' Ft\l & 958' FB.. BP Exploration (Alaska) i ;9oo'-o<6ò ( ~ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration (Alaska), Inc. ProActive Diagnostic Services, Inc. Petrotechnical Data Center LR2-1 P. O. Box 1369 900 E. Benson Blvd. Stafford, TX 77497 Anchorage, AK 99508 LOG DIGITAL MVLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 Res. Eva!. CH 1 1 1 OS 06-21 A 12..04..03 Mech. CH J¡3l =s 20a Caliper Survey Signed: ""'\<.é)\;"~ I\(~~O ~ ~~^''\ Date:.. Print Name: R~ 2 f1Qt\A !t\ ~J n (.i Vt.t ~¡'11 a U Alaska Oil & Gas Cons. Commsn Anchorage PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 }69 STAFFoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com .,,~.~~~,'/\, ~..§(ÇA~~EL ~j ~¿ lOn~, \" '\~ L\':>' \ ~ 10/07/03 Schlumberger NO. 2984 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD P2-11 I C..~ ~:~ '"lQ ~, SBH TEMP & PRESSURE SURVEY 10103107 GNI-0'I 'iQ -~ -c~-~,-~," TEMP & PRESS SURVEY 10/04103 D.S. 13-27~ [~ ~ l~ ~- LDL ~0101/07 D.S. 6-24A ~-~~ LDL ~0/01/03 D.S. 14-32 I~' )~ LDL J0103/03 C-23B ~-~ ~O~ MEM PPROF & IPROF LOG 09/01/03 F-13A I~ ~1 ~ ~ MEM PPROF & IPROF LOG 09108103 F-~A '~~ ~ ~ MEM PPROF & IPROF LOG 09109103 ~~ ,..~c~,o...o.,~ ,o,o.,o~ MPS-O= 'i~ ~ ~oss.23. CH EDiT SCMT (PDC) 03/03/03 MPS-20 ~ ~ M.S-=O ~~q ~ ~oss.=3. SCaT 03/03/03 = _ " PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 , ?'~05 Date Delivered: 0 CT 0 8 ,-~. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Permit to Drill 2000800 MD 9503 TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT 06-21A Operator BP EXPLORATION (ALASKA) INC 9103 Completion Dat 2/24/2001 Completion Statu 1-OIL Current Status 1-OIL ! APl No. 50-029-20802-0t-00 UIC N REQUIRED INFORMATION Mud Log N_.~o Sample N_.~o Directional Survey N_~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~,. Fit ED ~ Cn See Notes Log Log Run Name Scale Media No final /,.'I~W.D S u rvey Report FINAL ~,t/'D Survey Report FINAL ~ 2/5 FINAL 9582 FINAL ~GR/MCNL ~--,~ ~ ~ ~ FINAL 9794 FINAL ~ GR 5 FINAL q~'~GR 5 FINAL ~ FINAL LIS Verification FINAL (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 8984 8750 8700 OH I Dataset CH Received Number Comments 9500 Open 4/6/2001 '-'09979 F"8~84-9500 9308 Case 11120/2001 ~447/Coil Flag 9500 Open 712112000 -'09582 '/~750-9500 9124 Case 1/3/2001 09794-" 8700-9124 2/2/2001 Digital Data 9503 2/2/2001 8994-9503 Paper Copy 9500 OH 7/21/2000 8750-9500 OH 7121/2000 ~82 -~-"~S IL 9724 CH 1/3/2001 8700-9724 BL, Sepia 9724 CH 1/3/2001 · ~'~' 8700-9724 Digital Data 9500 oh 4/6/2001 9013-9500 BL, Sepia 9500 oh 4/6/2001 9013-9500 BL, Sepia 9500 4/6/2001 ~9~J'79 -/8984-9500 Digital Data 9500 4/6/2001 8984-9500 Paper Copy 8994 8750 8700 8700 9013 9013 8984 8984 Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2000800 MD 9503 TVD Well Cored? Y ~) Chips Received? -Y-f'N'-- Analysis ~ R~.ceived? DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT 06-21A Operator BP EXPLORATION (ALASKA) INC 91 O3 Completion Dat 2/24/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? (~ N Formation Tops ~ N APl No. 50-029-20802-0J-00 UIC N Comments: Compliance Reviewed By: Date: LOG .. ,,.TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite Cf 700 Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joe¥ Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Dpen Hole I I 1 Res. Eval. CH I I 1 ... 06-2 lA 1 O/19/01 Mech. CH 1 Caliper Survey Signed · Print Name: Date · RECEIVED Alaska 0ii & Gas Cons. Commi~0n Mci-er-age PROACTIVE Di~qNOSTiC SERVICES, INC., 3 IO K STREET SUITE 200, ANChORAqE, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-maih pdsanchorage~memorylog.com Websit¢: www.mcmor~log.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing_ Repair well_ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratory_ Stratigraphic__ Service_ 4. Location of well at surface 4812' FNL, 958' FEL, Sec. 02, T10N, R14E, UM At top of productive interval 5225' FNL, 2518' FEL, Sec. 02, T10N, R14E, UM At effective depth 105' FSL, 2593' FWL, Sec. 02, T10N, R14E, UM At total depth 5181' FNL, 2703' FEL, Sec. 02, T10N, R14E, UM (asp's 686026, 5941066) (asp's 684478, 5940616) ~sp~ 684308, 5940663) ~sp~ 635251, 594698~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2478' Production 8810' Liner 482' Sidetrack Liner 721' 9503 feet Plugs (measured) 9103 feet 9456 feet Junk (measured) 9060 feet 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-21A 9. Permit number ! approval number 200-080 10. APl number 50-029-22802-01 . , .. ~.,r ~, ,.~ .... f!. /"";:';.'" ~"~ 11. Field / Pool I~'~, Prudhoe Bay Oil Pool 0il & Gzs Co~]s. comm~somn" ' ~' Anchora§e Size Cemented Measured Depth True Vertical Depth 20" 1900# Poleset 112' 112' 13-3/8" 2259 sx Fondu, 400 sx 2510' 2510' PFC 9-5/8" 500 sx 'G', 50 bbls 'C' 8842' 8596' 7" 275 sx Class 'G' 8519' - 9001' 8279' - 8752' 2-3/8" 11.5 bbls LARC 8782' - 9503' 8537' - 9103' Perforation depth: measured Open Perfs 9270'- 9286', 9286' - 9314' true vertical Open Perfs 8923' - 8930', 8930' - 8945' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 TBG @ 8457'. 5-1/2" x 4-1/2" @ 8457'. 4-1/2" 12.6# N-80 @ 8786'. 4-1/2" x 3-1/2" @ 8786'. 3-1/2" 9.3# @ 8930'. Tubing Tail @ 8957'. 9-5/8" x 5-1/2" BKR FHL Packer @ 8448'. 7" x 3-1/2" BKR FB-1 Packer @ 8930'. 5-1/2" Camco BAL-O SSSVN @ 2172'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/18/2001 Subsequent to operation 10/22/2001 OiI-Bbl 514 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 4459 799 943 7942 1473 Casing Pressure Tubing Pressure Gas Lift 229 Gas Lift 253 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~W,~a~e~~r~~.~ Title: TechnicalAssistant Form 10-404 Rev 06/15/88 · ORIGINAL Date October 23, 20.01 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE~~ 10/20/2001 10/20/01 06-21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF): ADD PERF. EVENT SUMMARY COMPLETE MEMORY TIE IN LOG. RIH AND PERFORATE 9270-9286' WITH 1- 11/16" PJ LOADED AT 4 SPF WITH 60 DEG. PHASING AND RANDOM ORIENTATION. 45 BBLS PUMPED, LITTLE SHOT INDICATION. POOH. ALL SHOTS FIRED. RDMO. ***WELL LEFT SI, OPR NOTIFIED TO POP AND TEST*** FLUIDS PUMPED BBLS 45 METHANOL WATER 45 TOTAL 10/20/2001 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1-11/16" HSD POWER JET AT 4 SPF, 60 DEGREES PHASING, AND RANDOM ORIENTATION. 9270'-9286' Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 5225' FNL, 2518' FEL, SEC 2, T10N, R14E, UM At effective depth At total depth 5181' FNL, 2703' FEL, Sec. 2, T10N, R14E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service_ (asp's 686026, 5941066) (asp's 684478, 5940616) (asp's 684291, 5940655) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-21A 9. Permit number / approval number 200-080 10. APl number 50-029-20802-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9503 feet Plugs (measured) 9103 feet Effective depth: measured true vertical 9350 feet Junk (measured) 8970 feet Casing Length Conductor 80' Surface 2436' Production 8768' Liner 482' Liner 721' Size Cemented Measured Depth True Vertical Depth 20' 19oo# Poleset 80' 80' 13-3/8" 2259 sx Fondu & 400 Sx PF 2510' 2410' 9-5/8" 500 Sx Class G & 50 bbls C 8842' 8596' 7" 275 Sx C~ass e 9001' 8752' 2-3/8" 11.5 bbls 15.8 ppg LARC 9503' 9103' Perforation depth: measured 9286' - 9314'. true vertical 8930' - 8914'. Tubing (size, grade, and measured depth) RECEIVED 7 Alaska Oil & Gas Cons. Commi~on 5-1/2", 17#, L-80 PCT O 8457' MD; 4-1/2", 12.6#, N-80 PCT O 8923' MD; 3-1/2", #, PCT ~ 8957' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER FHL PACKER e 8448' MD; 7" X 3-1/2" BAKER FB-1 PACKER (BEHIND LINER) ~ 8930' MD. 5-1/2" CAMCO BAL-O SSSV ¢~ 2172' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 288 Representative Daily Avera.qe Production or Injection Data Gas-Mcr Water-Bbl 2252 440 493 1434 762 Casing Pressure Tubing Pressure - 221 247 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil _X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title: DS 6 Suweillance Engineer Deidre Taylor Date April 24, 2001 Prepared by Paul Rauf 564-5799 ~. Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-21A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/1312001: 4/1712001: RIH & jetted hot water to break through hydrate plug @ 2234'. Drifted to 9350' CTM. MIRU CTE. PT'd equip to 3500 psi. RIH CTE conveyed perf guns & shot 10' of add perforations f/: 9286' - 9296' MD (Zone 3) Used 1-11/16" carriers & all shots @ 4 SPF, random orientation, & 60° phasing. POOH w/ guns - ASF. RD CTE. Placed well BOL & obtained representative production test. Page 1 ,. bp April 5, 2001 " "ONLY - ommi BP ~.xpiorafion (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorag~ Alaska 99519.-6612 (90'/) ~61-$111 I Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & l_isburne Well Work, , This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342, .This is a list of well work tentatively scheduled for April 2 - 9, 2001' ' Well 02-19 Work PI.armed. ADD PERFORATION 02-21 0$-I?B 07-08A 11-22A 15-43 16-05Ai lS-04A 18-13A ADD ,PERFORATION ADD PERFORATION CTE PERFORATION CT REMOVE 2-3/8" GL COIL ADD PERFORATION SET CIBP W/CT ' CT REPERFORATION / ACID STIMULATION CT REMOVE 2.,3/8" GL COIL CT SET CIBP FOR GSO' 18-18A SET CIBP W/,CT Starting next week, I will be including WOA, 'Milnc Pt, & Endicott wcllwork. If additional data. or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc@bp.com. Sincerely, Technical Assistant, BPXA Alaska Drilling & Wells. TRANSMITTAL FORM BAKER HUGHES Baker Atlas Canada Geoscience Centre TO: State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attn: Lisa Weepie Reference: Prudhoe Bay 6-21A Package contents · 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print RECEIVED APR 0 6 ,?.001 Alaffm 011A Gm Oon~, Aac~m~ge Sent by: Received by: Glen Horel Date: April 3, 2001 Date: q" ~)-O ./ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas, 1300, 401 - 9a Avenue S.W., Calgary, Alberta T2P 3C5 (403) 537-3400 Fax (403) 537-3767 "" STATE OF ALASKA JM ALASKA OIL AND GAS CONSERVATION CO I$SlON ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas D Suspended D Abandoned r'] Service D 2. Name of Operator .. ~'"'~'~'~'~'~ 7. Permit Number BP Exploration (Alaska), Inc. ' : 200-080 i~ural~,~-' ~ 8. APl Number 3. Address P. O. Box 196612, Anchorage, AK 99519-6612 £~,~ .1~.-~ 50-029-20802-01 4. Location of well at surface .... 9. Unit or Lease Name 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM (asp's 686026, 5941066) '-'""~:~;;~':'";i;it; Prudhoe Bay Unit At Top Producing Interval ' ._..~r~.._~.../_. ' 10. Well Number 5225' FNL, 2518' FEL, SEC 2, T10N, R14E, UM (asp's 684478, 5940616) ...... 06-21A At Total Depth ..... ii~ ....... ' 11. Field and Pool 5181' FNL, 2703' FEL, SEC 2, T10N, R14E, UM (asp's 684291, 5940655) ...................... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 74 feetI ADL 28311 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions ! July 12, 2000 July 15, 2000 February 24, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9503' MD / 9103' TVD 9456' MD / 9060' TVD YES [~] No ~]I 2172' feetMD 1900'(approx) 22. Type Electric or Other Logs Run MWD/GR, Mem ResistMty/RST, & Mem CNL 23. CASING, LINER AND CEMENTING RECORD SE'I-I'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 80 30" 1900# Poleset 13-3/8" 72# L-80 Surface 2510' 17-1/2" 2259 Sx Fondu & 400 Sx PFC 9-5/8" 47# L-80 Surface 8842' 12-1/4" 500 sx G & 50 bbls Class C 7" 29# L-80 8519 9001' 8-1/2" 275 Sx Class G 2-3/8" 4.7# L-80 8782' 9503' 3.0" 11.5 bbls 15.8 ppg LARC 24. Perloratlons open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 8457' 8448' 9296' - 9314' MD; 8936' - 8945' TVD;@ 4 SPF& w~ 1-11/16" carriers 4-1/2" 8923' 8930' 3-1/2" 8957' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 25, 2001 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/26/2001 6.0 Test Period >I 5778 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (cow) Press 239 psi 24-Hour Rate > 262 1514 325 28. CORE DATA ~1~ Brief description of Iithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved May 26, 2000 (Permit #200-080) Alaska AnGas' Con~. C~or~3o Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORiGiNAL Submit in duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and tirue of each phase. Top of Sag River Sand 8847' 8601' Top of Shublik 8870' 8624' Top of Sadlerochit 8945' 8697' Top of Zone 4^ 9056' 8801' Top of Zone 3 9204' 8892' Top of Zone 2C 9366' 8982' Top of Zone 2B 9402' 9112' 31. LIST OF ATTACHMENTS Summary of 06-21A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certily that the following is true and correct to the best of my knowledge. Signed '~..~~ ~, ~tle Coil Tubina Drilllno En.qineer Date __Februalt/27, 2o01_ Lamar L. Gantt Prepared by Paul Rau! 564-5799 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 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". RECEIVED Form 10-407 ORIGINAL MAR 0 1 2001 Alaska Oil & Gas Cons. Commission Anchorage DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 6110~2000: MIRU CTU#5 & work platform. PT'd BOPE. RIH & tagged TOC @ 8951'. Milled cement to 9000' MD & POOH. 6/1112000: RIH & commenced window milling operations. Milled window fl 9001' - 9005'. Drilled FM to 9013' MD. Reamed / backreamed window interval. POOH. RD. 7/1012000: 7111/2000: MIRU Nabors CDR1. Accepted rig 1200 hrs. Continued RU. PT'd BOPE. 7/12/2000: 7/13~2000: RIH & tagged BTM @ 9013'. Performed LOT to EMW of 9.2 ppg. Drilled to 9185' & POOH. RIH & drilled to 9268'. POOH. RIH & drilled to 9270'. 7/14/2000: Drilled to 9294' & POOH. RIH & drilled to 9344'. POOH. 7/1512000: 7/16/2000: RIH & drilled to TD @ 9503'. Conditioned OH f/liner run & POOH. RIH w/Mem Res & logged OH. POOH w/logging tools. RIH w/CT & layed in new mud to TD. POOH. RIH w/2-3/8" 4.6# FL4S L-80 liner & landed it @ 9503'. TOL = 8782'. PBTD = 9466'. Pumped 11.5 bbls of 15.8 ppg LARC to cement liner in place. Pulled out of back door flapper & contaminated Cement w/Biozan. Cleaned contaminated Cement from the wellbore. POOH. WOC. 7/17/2000: RDMOL. 8/0812000: RIH & FCO'd f/9100' to 9450' CTM. 8/16/2000: RIH & FCO'd to 9470' CTM. 8/19/2000 - Installed new gas lift design. 8/20/2000: 9/04/2000 - 9/05/2000: 9/18~2000: 9/27/2000 - 9/28/2000: RIH & Ran Mem CNL log f/8700' to 9133'. RIH & FCO'd to 9451'. RIH & tagged 9134' - unable to get any further. RIH & FCO'd to 9450'. Ran Mem CNL/GR log to PBTD. MIRU CTU. PT'd equip. RIH w/CT conveyed perforating guns & PBTD @ 9467'. Shot 8' of Initial Perforations f/: 11113~2000: 9306' - 9314' MD (Zone 3) Reference Log: Mem CNL/GR 9/18/2000. Used 1-11/16" carriers & shot all Perfs @ 4 SPF, 60° phasing, & random orientation. POOH w/guns. ASF. FP'd well. RD CTU. Placed well BOL but no flow. MIRU CTU. PT'd BOPE. RIH & FCO'd to 9450'. Fluid packed well w/dead Crude. Performed Injectivity test: 0.5 bpm @ 1328 psi. RECEIVED Sidetrack Summary Page I MAR 0 I ZOO1 Alaska Oil & Gas Cons. Commission Anchorage "' 06-21A ( DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/1412000: 11/23/2000: 12/1412000 - 12/15/2000: 12/29/2000 - 1/01/2001: 1/18/2001: 2/1412001: 2/15/2001: 2/24/2001: Pumped 20 bbls of 7.5% HCL & reciprocated acid across open perforations. Flushed w/1% KCL Water & POOH w/CT. RD CTU. Placed well BOL - no hydrocarbons. MIRU CTU. RIH w/perforating guns & reperforated 12' f/: 9306' - 9314' MD (Zone 3) Used 1-11/16" carriers & all shots @ 4 SPF, 60° phasing, & random orientation. POOH w/ guns - ASF. RD CTU. Pulled LGLV's. Installed new GLV design. Attempted CTE reperforation. Need FCO. MIRU CTU. PT'd BOPE. RIH & performed FCO f/9456' to 9330' CTM. FP'd w/47 bbls of Methanol Water. RD CTU. MIRU CTE. PT'd to 3000 psi. RIH w/perforating guns & logged tie-in pass. Shot 10' f/: 9296' - 9306' MD (Zone 3) Used 1-11/16" carriers & all shots @ 4 SPF, 0° phasing, & random orientation. POOH w/ guns - ASF. RD CTE unit. Placed well 06-21A BOL. Obtained a valid welltest. Sidetrack Summary Page 2 RECEIVED MAR 0 ], 2001 Alaska Oil & Gas Cons, Commission Anchorage BP Amoco WELLPATH DETAILS 06~1A $002920~201 Parent Weilpath: 06.2! Tle on MD: 8994.00 Verifc~lSe¢tlonOrlgln: Slot-21 (0.0~0.00) Verfi~l Section Angle: 26~.43' R~r~n~., CDR ~ Depth 31: 21 &~2'//~982 00:00 74~OOft RBq~R~CE INFORMATION Co~r~nats {N~E) Refem~e: W.~ Cenbe: 06-21, Tree N~th Vedical ('1*VD) Refemm:~ r-mid - Mean Sea Levd Seclion (VS) ReJemm:~c SI0~-21 (0.00,0.00) ANNOTATIONS No. TVD MD Amlo~B~n / 84~0.94 8~00.00 l'le-~Po~! B67t~ W94.(X) l~ck-offPo~t 3 g029.19 g~0310~ ~)zI~4d~aTD TA.~-.-~I' DETALS LEGEND 05-21,06-21A.Pkn ~2 06-21 ~8-21) 06-21A ssoo--i----~ ...................... i ...................... : ...... 'i .... ~ __,__~_ _~ .... L_.,----~--~--r.--~-..--..~ ..................... ' ........... ~ .......... ~ ........................................... i .................... ' ....... ' .......... ' ............... ,-. i~ ~ ~~ ~- ~ : ' , , ~ ' ' , ' ' ' · ...... i ~ i i : -1900 -1800 -1700 -1600 -1500 -1400 -1300 i i i West(-)/East(+) [lOOft/in] +"i .......... ! .......... i .......... i .......... i ........ i .......... i .......... i .......... ~' .......... i .......... i .......... ~' .......... ! .......... ~ .......... ~ ......... i .......... ~.'-- i"'"~'"'"'"! .......... !' .......... :' ......... i ....................... i ...................... · .................. i ........ ---i..-i .......... .L..- ....... ~ .......... ~. .......... :: ...... ~ .......... : ........... ~ .................................. : ...................... ~ .................................................... i- ............................. 0000 106-21 (06-21) I ;' :- ~ ~ : ~ - ' ~ ' : ' i - i : 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 Vertical Section at 269,43' [lOOft/in] Prepared by Baker Hughes INTEQ INTEQ End of Well Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Company: Field: Well: Job No: AFE No: AP1 No: BHI Rep: BP Exploration Alaska, Inc. Prudhoe Bay Unit 06-21A 52254 3B-1373 50-029-20802-01 Rig: CDR 1 RKB Height: 74.000 Vertical Sect. Plane: 269.430 Mag. Declination: 27.190 Grid Correction: 1.400 Job Start Date: Job End Date: Survey Date: 'i Survey Type: 'iM~:!?i':'i:i::::::::::::::::::::::: Meas. Depth (ft) 8800.00 Incl. Angle (deg) 10.50 TRUE Azi. 259.00 TRUE V. Depth (it) 8554.94 Subsea TVD (tt) 8480.94 Coords. - True N(+)/S(-) (ft) -431.59 E(+)/W(-) (rt) -1391.76 Coords.- ASP N(+)/S(-) Lat. (Y) 5940599.85 E(+)/W(-) Dep. (X) 684644.95 Dogleg Severity (°/lOOft) 0.00 Vertical Section (ft) 1395.9¢ 8900.00 11.50 255.00 8653.10 8579.10 -435.91 -1410.33 5940595.07 684626.49 1.26 1414.6¢ 8994.00 11.30 253.00 8745.25 8671.25 -441.03 -1428.19 5940589.52 684608.76 0.47 1432.51 9025.00 25.00 255.00 8774.~ 8700.64 -443.62 -1437.47 5940586.69 684599.55 44.23 1441.81 258.00 35.60 9055.00 8800.50 8726.50 -447.09 -1452.18 5940582.87 684584.94 35.68 1456.55 9090.00 41.00 276.40 8828.05 8754.05 -447.93 -1473.64 5940581.49 684563.51 35.91 1478.02 9128.00 54.10 285.20 8853.67 8779.67 -442.48 -1501.02 5940586.27 684535.99 38.41 1505.35 9170.00 60.90 302.50 8876.35 8802.35 -428.06 -1533.13 5940599.89 684503.55 38.25 1537.31 9209.00 61.70 298.90 8895.08 8821.08 -410.61 -1562.54 5940616.61 684473.72 8.35 1566.54 9240.00 62.00 292.30 8909.72 8835.72 -398.81 -1587.17 5940627.80 684448.81 18.79 1591.0~ 9279.00 64.00 289.80 8927.42 8853.42 -386.33 -1619.59 5940639.47 684416.08 7.68 1623.3~ 9310.00 55.00 289.00 8943.14 8869.14 -377.46 -1644.76 5940647.71 684390.71 29.12 1648.4~ 9342.00 43.30 287.70 8964.04 8890.04 -369.83 -1667.69 5940654.77 684367.60 36.69 1671.28 9379.00 35.50 284.20 8992.61 8918.61 -363.33 -1690.22 5940660.72 684344.91 21.91 1693.7( 9409.00 30.00 275.00 9017.85 8943.85 -360.54 -1706.16 5940663.12 684328.91 24.68 1709.6{ 9445.00 24.50 264.10 9049.86 8975.86 -360.52 -1722.58 5940662.73 684312.50 20.58 1726.08 9476.00 22.80 245.20 9078.29 9004.29 -363.70 -1734.44 5940659.26 684300.72 24.96 1737.9~ 9503.00 22.80 245.20 9103.19 9029.19 -368.09 -1743.94 5940654.63 684291.33 0.00 1747.51 RECEIVED MAR 0 1 200! Alaska Oil & Gas Cons. Commission Anchorage ObP BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Fkid: Prudhoe Bay Site: PB DS06 WeB: 06-21 Wdlpnth: 06-21A Bate: 1/23/2001 Tame: 09:43:34 Page:. 1 Co-ordinate(NE) Reference: Well: 06-21, True Nor'th Vertiml (TV~) Eeferonce: 31: 21 8/2711982 00:00 74.0 Section (V$) Reference: Well (0.00E,0.00N,269.43Azi) Snrv~y Calmktlon Method: Minimum Gurvelum Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gm Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Goomagaetie Model: BGGM2000 Site: PB DS 06 TR-10-14 UNITED STATES: North Slope Site Position: Nor~ing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5941880.59 ft Latitude: 70 14 46.529 N 684674.88 ft Longitude: 148 30 29.224 W North Reference: True Grid Convergence: 1.40 deg Well: 0621 Slot Name: 21 06-21 Well Positlon: +NI-S -647.86 ft Northing: 5941065.63 ff Latitude: 70 14 38.189 N +~-W 1330.38 ff Kasting: 686025.55 ff Longitnde: 148 29 50.545 W Position Uncertainty: 0.00 It Wellpath: 06-21A Drilled From: 06-21 500292080201 Tlo-on Bap~: 8994.00 ft Current Datum: 31: 21 8/2711982 00:00 Height 74.00 ff Above System Datum: Mean Sea Level Magnetic Data: 9/7/2000 Declination: 26.97 deo FloM Strength: 57481 nT Mag Dip Angle: 80.76 cie0 Vertical Section: Depth From (TVD) +N/-S +E/=W Direction ff ff fl deg 0.00 0.00 0.00 269.43 SuFvey: MWD Staff Date: 7114/2000 Measured While Drilling Company: .Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD , 8994.00 8745.25 Kick-off Point 9503.00 9103.19 Projected to TD Survey MD Incl· Azim TVD SSTVD N/S' E/W MapN · 'MapE DLS VS ' ff. deg ' ' deg ff :. ff" . It lt. It ff deg/100ft It 8994.00 11.30 253.00 8745.25 8671.25 ,441.03 -1428.19 5940589.52 684608.76 0.00 1432.51 9025.00 25.00 255.00 8774.64 8700.64 -443.62 -1437.47 5940586.69 684599.55 44.23 1441.81 9055.00 35.60 258.00 8800.50 8726.50 -447.09 -1452.18 5940582.87 684584.94 35.68 1456.55 9090.00 41.00 276.40 8828.05 8754.05 -447.93 -1473.64 5940581.49 664563.51 35.91 1478.02 9128.00 54.10 285.20 8853.67 8779.67 -442.48 -1501.02 5940586.27 684535.99 38.41 1505.35 9170.00 60.90 302.50 6876.35 8802.35 -428.06 -1533.13 5940599.89 684503.55 38.25 1537.31 9209.00 61.70 298.90 6895.08 8821.08 -410.61 -1562.54 5940616.61 684473.72 8.35 1566.54 9240.00 62.00 292.30 8909.72 8835.72 -398.81 -1587.17 5940627.80 684448.81 18.79 1591.06 9279.00 64.00 289.80 8927.42 6853.42 -386.33 -1619.59 5940639.47 684416.08 7.68 1623.36 9310.00 55.00 289.00 8943.14 8869.14 -377.46 -1644.76 5940647.71 684390.71 29.12 1648.43 9342.00 43.30 287.70 8964.04 8890.04 -369.83 -1667.69 5940654.77 684367.60 36.69 1671.28 9379.00 35.50 284.20 8992.61 8918.61 -363.33 -1690.22 5940680.72 664344.91 21.91 1693.76 9409.00 30.00 275.00 9017.85 8943.85 -360.54 -1706.16 5940683.12 664328.91 24.68 1709.66 9445.00 24.50 264.10 9049.86 8975.86 -360.52 -1722.58 5940662.73 664312.50 20.58 1726.08 9476.00 22.80 245.20 9078.29 9004.29 -363.70 -1734.44 5940659.26 664300.72 24.96 1737.97 9503.00 22.80 245.20 9103.19 9029.19 -368.09 - 1743.94 5940654.63 664291.33 0.00 1747.51 ., , BP WELl. PA TH DETAIL8 08-21A Paint Wellpath: 0~-~1 Tie on MD: 8994.00 Verti~l ~ecdon Odgin: 8iot. ~1(0.00~0) VMIkml Secdon Angle: 2~9.43° Rig: CDR 1 Dep~ Refemn=e: 31: 21 REFERENCE I~=Ol~lATION ~~ ~~k~Wea C(l~eFkad' .'21Mllm ~a Lgvla(O.(X).O~O): 06-21 . Tme NCllh u ~,,~- 31: 21 ~/2fl1962 00:00 740 aborn Metal Se~ LMel CidoJlab~ Megtod: No. ~ -'-N/-$ *E/W Target I 6880.00 ,.44g.67-167&18 06.21T2.1 2 89g0.G0 .449.87-16"/&18 06-21T2.2OTD BPAmoco LEGEND -- ~._~.,~;,~...,. Azimzths to Truc Ninth ~lAagnctic North: 26.97°i C'~=ated B~. ark) Potai$ Da&c: 9;712(JOU M.gnctic Ficldl Strength: 57481 nTI co,(,~.; ...... ~..~, Dip Ansl¢: 80.7§° I ....... ,~ ...... ~ ....... ~ ....... i ........ ........................................ ~ ...... . ....... J ........ , .............. ; ....... ! .............. .:. ............... : ............. :.. ............ : : ; i I ; ] ; ; i ; ~ ; ; / i i ! ' ; : ~ ; ....... ~ ...... ~ ............. ~ ...... ~ ....... * ........................................ ~ ....... ~' ' ' ....... i'"'"i ....... [ ....... [ ............... i ...... i ....... 1 ....... ~ ............... ' ....... ~ ....... ~ ....... ~ .............. ~ ...... i ....... t ........ t ............... ~ .............. I ....... :...' .............. i ....... i ....... ....: ....... I ....... : i l: , .... ,---:--i~ ............... [ .... , ...... I ....... T.: ............ t ....... [ ....... :? ....... : ....... [ : J I ~ [ [ ....... ...... .............. ] ] [ ...... ....... ...................... [ .............. ] ] ....... .............. [ [ ~ ~ ....... ........ ....... -i'.......~. ...... ~ ............... [ ............ ~ ...... ~ ....... ! ...................... [ ..................... ~ ............. ~. ....... ~ ....... .'; .............. il ! [ i i i ] : : i " ..m~.. : , : .: , i fi i ....... f ...... ~ ............... ~ ...... t ....... t ....... i ....... ~ ........ l ...... [ ............... ] ............... l ....... } ....... { ....... i .............. ~ ...... t: ....... 1 ...................... ,~ ...................... } ............. ;.. ....... } ....... i ............... [ ; ; I ! [ i [ ! : ; ! I I : .. : : : ' ; ; i i I [ I ....... : , ; : ;l: : .... ] :' : ' .... - : : 'l I : I : : ' i : '-T-- :I : r ~ ........ ~ ...... ............... ... ...... ....... ....... 1!, ....... ~i i i , i i i iI i ! i . ! ~ i : . i i ~ , + ~ .... .b---~ .... F-+-- 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 VerUoal Seotion at 269.43° [lOOft/in] Plot 1/23/2001 9:46 AM 11/28/00 Seldlaa..k_erger NO. 726 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'YFN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job it Log Description Date BL Sepia CD l~S. 2-33A 20431 MCNL (PDC) 000916 I I 1 ~.S. 6-21A 20432 MCNL 00091 e I I 1 ~).s. 11-38A 20437 EST-SIGMA 001003 I I I SIGNE~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 11/1/00 Sc--blumberger NO. 660 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 t~5-5O l Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 6-15 J PRODUCTION PROFILE 001025 I 1 D.S. 13-20 LEAK DETECTION LOG 001024 I 1 D.S. 4-24 20423 RST 000921 I I 1 D.S. 6-21A 20378 MCNL 000904 I 1 1 SIGNED: ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To: Phillips Alaska, Inc. AOGCC Lori Taylor RE' Distribution - Final Print[s) The technical data listed below is being submit~d herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 ~ CD-ROM MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[SI OR FLOPPY FILM BLUELINE 6-21 7-15~)0 Open Hole I I 1. Res. Eval. CH I I ' 1 Mech. CH 1 Caliper Survey . I Rpt or n crc \lg:13, 1BL/1F Print Name: Alaska 0ii & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK. 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mai]: pdsprudho~NA800.n~ %Vebsite: ~.memor~log. com · %Big_boy~ - big boyWly Documents~Distn'bution_Forms~ahillips_pb_f~rm.doc. (" ( To Whom It May Concern: August 7, 2000 Please find enclosed corrected copies of 6-21 induction log data, dated July 15, 2000. The only correction was made to the APl number. All data and well information is now accurate. PDS apologizes for any inconvenience this may have caused. If there are any questions or comments please direct them to our office. Thank you, Jerry Morgan Field Service Engineer 907-659-2307 Prudhoe Bay, AK RECEIVED AUG 0 9 ' 000 Alaska Oil & Gas Cons. Commission Anchorage TRANSMITTAL ~roActive Diagnostic Services, Inc. To' Phillips Alaska, inc. AOGCC Lori Taylor RE' Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey PDS, Inc. Mail Pouch 34011 E Prudhoe Bay, AK 997 34 LOG CD-ROM MYLAR / BLUE LINE ,.~REPORT WELL DATE TYPE OR SEPIA PRINT(S), ......'~',..,,": OR ~ FILM "%'""~ '"BLuELINE 6-21 7-15~30 Open Hole ---_1 ~.1 .---,..1' . ,. ."~?.,.,..." ,,.,.,.,.,.?..?:.!:.. Res. Eval. CH 1 I 1 Mech. CH 1 Rpt or Caliper Survey. R F C _F V F r) 1 BL/1F Signed' Print Name: Date ' JUL 2 1 ; 000 Alaska Oil & Gas.Cons. Commission AJi'~moe ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdspmdhoe~,NAg00.net Website: %Big_boy~c - big boy, ely DocumentskDistributim_FormskPhillips_.pb_form.doc ALASILA OIL AND GAS CONSERVATION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar L. Gantt Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 6-21A ARCO Alaska, Inc. Permit No: 200-80 Sur Loc: 4812'FN , 958'FEL, Sec. 02, T10N, R14E, UM Btmhole Loc. 5173'FNL, 2670'FEL, Sec. 02, T10N, R14E, UM Dear MrGantt: Enclosed is the approved application for permit to redrill the above referenced well. 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 contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. (,~//,,Dani~...Seamount, Jr. - Cofiamissioner BY ORDER OF THE COMMISSION DATED this '~_ ~ day of May, 2000 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i~IAY 22 ~000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~'.'~'.~,:~ u~,. ~,~ ~.~.:~'~'~,~:~,~%~. c~,~',.'~r..!,~i0. PERMIT TO DRILL A~ "F:~e 20 ~C 25.005 ~ ~,¢ ~.~ '.'~L~. la. Type of worlc Drill O Redrill [~ I lb. Type of well. Exploratory E] Stratigraphic Test O Development OII Re-ently BI Deepen DI Service D Development Gas D single Zone [~] Multiple Zone D / ~~of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Alaska, Inc.~T~ RKB 74 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28311 Prudhoe Bay Oil Pool 4. Location of well at surface .~_ ,~' ,./ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Unit Statewide At top of productive Interval 8. Well number Number 5249' FNL, 2379' FEL, Sec. 02, T10N, R14E, UM 06-21A #U-630610 At total depth 9. Approximate spud date Amount 5173' FNL, 2670' FEL, Sec 2, T10N, R14E, UM June 10, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 28312, 2611' ¢~ TD feetI No Close Approach feet 2560 9454 MD /9064 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 9000' MD Maximum hole angle 55° Maximum surface 2438 psi~l At total depth ITVD) 3318 psi~l @ 8800' 18. casing program Settin~l Depth size Specifications Top Bottom Quantity of Cement Hole Casln~l Wei~lht Grade CoupIIn~l Len~h MD TVD MD TVD Iindude sta~le data) 3' 2-3/8" 4.6 L-80 FL4S 654' 8800' 8555' 9454' 9064' 7 bbls 15.8 ppg Cement 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured. 9452 feet Plugs (measured) Tagged PBTD @ 9217' MD on 4/15/2000. true vertical 9196 feet ORIGINAL Elfective Depth: measured 9217 feet Junk (measured) true vertical 8964 feet Caeirlg Length Size Cemented Meaeured depth True Yertlcal depth Conductor 80' 20" 1900¢ Poleset 80' 80' Surface 2436' 13-3/8" 2259 Sx Fondu & 400 Sx PFC 2510' 2410' Production 8768' 9-5/8" 500 Sx G & 50 bbls Class C 8642' 8596' Uner 901' 7' 275 Sx Class 61 9420' 9164' Perforation depth: measured 9210' - 9216'; 9220' - 9226'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. true vertical 8957' - 8963'; 8967' - 8973'; 8982' - 8992'; 8997' - 9036'; 9050' - 9060'. 20. Attachme.ts F,~ngfee E] ,repe,y,~, E] Bo, S*etc~ E] Dive,erS~e, oh I--I D,,~.g program El Drilling fluid program Time vs depth plot [~ Refraction analysis r'~ Seabed report BI 20 AAC 25.050 requirements [~ 21, I hereby certify that the foregoing is true and correct to the best of my knowledge Questions'/ ¢all Stephen Ward ~ £~$- Signed ~~ ¢ ~ Title: collTublng Drilling Supervisor Date ~"/'~'/~) ' ~ Pre~ed b~ Paul Rauf 265-~-~90 Commission Use~ Only Perm, Number I APInumber I ISee c°ver letter ~..~::)(~)- ~::)~ 50- O~--'?"' ~.~~'" (5)/w Appr°valdat~"¢;~'~'~:~) If°r°therroquirements Conditions of approval Samples required D Yes ~ No Mud Icg required r-~ Yes ~' No Hydrogen su,~e measure. !~' Yea I--I ,o D~r~ct~on~.u..eyr~quirod 121 Yas I--I ,o Required working pressure for BOPE ' D2M; D 3M; D 5M; r'l lOM;D {[~3~oopsiforCTU Other. ORIGINAL SIGNED BY D Taylor Seamount by order ct Approved by Commissioner the commission Date ..- Form 10-401 Rev. 12/1/85 ° Submit in triplicate DS 6-21A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a high angle twin well from the existing wellbore. Complete with 2-3/8" cemented liner. Intended Procedure: Service CTU: Cement squeeze the current perforations and plugback the existing completion to - 8940' md. Mill cement from 3-1/2" TT, Mill pilot hole in 7" from - 8958' - 9000' and mill window in 7" casing at -9000' md. CT Drillina Ri~ Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. · Directionally drill twin well to access Zone 3/2 reserves. · Run memory CNL/Resistivity log. · Run and cement 2-3/8" liner to TD. · Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. May 18, 2000 DS 6-21A Potential Drilling Hazards POST ON RIG HeS was measured at 54 ppm back in 12/96. Insure that all H2S monitoring equipment is operational. BHP: 3318 psi @ 8800' ss (7.2 ppg EMW) based on offset well. Plans are to drill with 8.5 ppg Flopro. This will provide an overbalance on the formation of approximately 572 psi. Maximum anticipated WHP w/ full column of gas: -2438 psi assuming 0.1 psi/ft gas gradient. GOC is currently at ~ 9166' md. May 18, 2000 DS 6-2(...~ PROPOSED CT TWIN SlDg" .:lACK 5-1/2" Production Tubing SSSV @ 2172' 5-1/2" Camco MMIG GLM's Baker FHL Packer @ 8448' 9-5/8" Casing to 8842' Baker FB-1 Packer @ 8930' 3-1/2" Camco Nipple@ 8939' 3-1/2" TT @ 8958' 7" Liner & Perfs P&A'd with 17 ppg Cement 4-1/2" Production Tubing from 8457' - 8923' Top of 7" Liner @ 8519' Top of 2-3/8" Liner @ +/- 8800' Straddle Perfs 8920 - 8922' Top of P&A Cement @ TT Mill Window in 7" Casing @ 9000 - 9005'. 2-3/8" FL4S 4.6# Liner Cemented & Perforated 3" Open hole 7" Shoe @ 9420' TD@ ~ 9454' ~IAY 2~.. 2000 PHILLIPS Alaska, Inc. WELLPATH DETAILS 06-21A Coiled Tubing Sidetrack Parent Wellpath: 0621 17e on MD: 9000.00 VerUcalSectionOdgin: UearDeflned(.1391.80,.431.60) Vertical Section Angle: 282.82° Rig: Nebore 3S Depth Reference: 0621 74.00ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Wellhead: 06-21, True North Vertical (TVD) Reference: Field. Mean Sea Level Section{VS)Reference: UearDefined(-1391.80,-431.60) Measured Depth Reference: 06-21 74.0 above Mean Sen Level Calculation Method: Minimum Curvature ANNOTA~ONS No. TVD MD Annotation 1 8480.94 8800.00 Tie-In Point 2 8677.14 9000.00 Kick-off Point 3 8723.94 9050.00 1 4 8744.32 9073.20 2 5 8799.69 9148.20 3 6 8879.99 9280.50 4 7 8990.00 9454.00 TD BAKER ~i~PHILLIP$ Alaska, Inc. All Angles Relative To Tree North True North: 0.00 Magnedc Norlh: 27.19 Wellpath: (06-21/06-2 IA) Created By: Brij Potnis Date: 5117/2000 Checked: Date: Approved: Date: Tie-in Point ] I I i j i I I I " -1800 [ 06-21A T2*TD ] x[06-21A TI I ~ ~ i Tie-in Point ] '~] ', ~ [] 1 yack-orrroin!l -1700 -1600 -1500 -1400 -1300 0 West(-)/East(+) [100ft/in] 2 2 2000 l~:t./-~ I -200 0 200 400 600 SO0 i 000 1200 1400 1600 Vertical Section nt 282.82° [200fl/'m] Proposal Calculations HII~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: PUILLIPS Alaska~ Inc. Vertical Sect. Plane: 282.820 TRUE Job No: 0 Field: Prudhoe Bay, Alaska Mag. Declination: 27.192 AFE No: 0 Well: 6-21A Plan #1- Grid Correction: 1.410 API No: 50-029-20802-01 Rig: Nabors 3S Total Correction: 25.782 BHI Rep: 0 Surface Location Dip: 80.697 Job Start Date: 00-Jan-00 X: 686025_g RKB Height: ' 0.740 Job End Date: 00-Jan-00 Y: $941065.$ Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (deg) (deg) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) (Wellhzad) (°/100ft) (°/100ft) 8800.00 10.50 259.00 . 8480.94 -431.59 -1391.76 5940599.69 684644.82 0.00 -0.04 0.00 0.00 0.00 Tie-in Point 8900.00 11.50 255.00 8579.10 -435.91 -1410.33 5940594.91] 684626.35 1.26 17.12 -39.33 1.00 -4.00 9000.001 11.25 253.00 8677.14 -441.34 -1429.29 5940589.02 684607.54 0.47 34A0 -123.34 -0.25 -2.00 Kick-off Point 9010.00 14.75 253.00 8686.88 -442.00 -1431.44 5940588.31 684605.40 35.00 36.35 0.00 35.00 0.00 9020.00 18.25 253.00 8696.47 -442.83 -1434.16 5940587.41 684602.71 35.00 38.81 0.00 35.00 0.00 9030.00 21.75 253.00 8705.86 -443.83 -1437.43 5940586.33 684599A6 35.00 41.78 0.00 35.00 0.00 9040.00 25.25 253.00 8715.03 -445.00 -1441.24 5940585.07 684595.68 35.00 45.24 0.00 35.00 0.00 9050.00 28.75 253.00 8723.94 -446.32 -1445.58 5940583.64 684591.37 35.00 49.17 0.00 35.00 0.00 1 9060.00 28A9 260.31 8732.72 -447.43 -1450.23 5940582.42 684586.75 35.07 53.47 97.46 -2.61 73.05 9070.00 28.62 267.64 8741.51 -447.93 -1454.98 5940581.80 684582.02 35.07 57.98 91.05 1.33 73.35 9073.25 28.75 270.00 8744.36 -447.96 -1456.54 5940581.73 684580A6 35.07 59.50 84.61 3.93 72.60 2 9080.00 31.11 270.00 8750.21 -447.96 -1459.91 5940581.64 684577.09 35.00 62.78 0.00 35.00 0.00 9090.00 34.61 270.00 8758.61 -447.96 -1465.33 5940581.51 684571.67 35.00 68.07 0.00 35.00 0.00 9100.00 38.11 270.00 8766.66 -447.96 -1471.26 5940581.36 684565.74 35.00 73.85 0.00 35.00' 0.00 9110.00 41.61 270.00 8774.33 -447.96 -1477.67 5940581.21 684559.34 35.00 80.10 0.00 35.00 0.00 9120.00 45.11 270.00 8781.60 -447.96 -1484.53 5940581.04 684552.47 35.00 86.79 0.00 35.00 0.00 9130.00 48.61 270.00 8788.44 -447.96 -1491.83 5940580.86 684545.18 35.00 93.91 0.00 35.00 0.00 9140.00 52.11 270.00 8794.82 -447.96 -1499.53 ' 5940580.67 684537A8 35.00 101Al 0.00 35.00 0.00 9148.25 55.00 270.00 8799.72 -447.96 -1506.17 5940580.50 684530.85 35.00 107.89 0.00 35.00 0.00 3 9150.00 54.82 270.72 8800.72 -447.95 -1507.60 5940580A8 684529.42 35.00 109.28 107.42 -10.36 40.86 9160.00 53.87 274.86 8806.55 -447.56 -1515.71 5940580.67 684521.30 35.00 117.28 107.01 -9.53 41.45 9170.00 53.06 279.10 8812.51 -446.58 -1523.68 5940581.45 684513.30 35.00 125.27 104.59 -8.07 42.39 9180.00 52A0 283.42 8818.57 -445.03 -1531.48 5940582.81 684505.47 35.001 133.22 102.06 -6.54 43.21 9190.00 51.911 287.81 8824.70 -442.91 -1539.09 5940584.74 684497.81 35.001 141.11 99.45 -4.93 43.88 - ~Y200.00 51.58 292.25 8830.90 -440.22 -1546.46 5940587.25 684490.37 35.00! 148.89 96.75 -3.28 44.38 9210.00 51.42 296.72 8837.12 -436.98 -1553.58 5940590.31 684483.18 35.00 156.56 94.00 -1.60 44.68 9220.00 51.43 301.19 8843.36 -433.19 -1560.42 5940593.92 684476.25 35.00 164.06 91.22 0.11 44.77 9230.00' 51.61 305.66 8849.58 -428.88 -1566.95 5940598.07 684469.61 35.00 171.39 88.43 1.81 44.65 9240.001 51.96 310.09 8855.77 -424.06 -1573.15 5940602.74 684463.30 35.00 178.50 85.65 3.49 44.33 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (del~) (del~) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°llOOft) (Wellhead) (°/lOOft) (°/lOOft) 9250.00 52.48 314.47 8861.90 418.75 -1578.99 5940607.91 684457.32 35.00 185.38 82.91 5.14 43.81 9260.00 53.15 318.78 8867.95 -412.96 -1584.46 5940613.56 684451.71 35.00 192.00 80.22 6.73 43.12 9270.00 53.98 323.01 8873.89 -406.71 -1589.53 5940619.68 684446.49 35.00 198.32 77.62 8.26 42.28 9280.50 55.00 327.35 8879.99 -399.70 -1594.41 5940626.57 684441.44 35.00 204.64 75.10 9.75 41.30 4 9290.00 53.69 323.59 8885.53 -393.34 -1598.78 5940632.82 684436.91 35.00 210.31 -114.22 -13.75 -39.61 9300.00 52.45 319.49 8891.54 -387.08 -1603.75 5940638.95 684431.79 35.00 216154 -112.02 -12.43 -40.93 9310.00 51.35 315.27 8897.71 -381.29 -1609.07 5940644.61 684426.33 35.00 223.02 -109.56 -10.97 -42.24 9320.00 50.41 310.92 8904.02 -375.99 -1614.74 5940649.77 684420.54 35.00 229.72 -106.95 -9.41 -43.45 9330.00 49.64 306.47 8910.44 -371.20 -1620.71 5940654.41 684414.44 35.00 236.61 -104.21 -7.75 -44.54 9340.00 49.04 301.92 8916.96 -366.94 -1626.98 5940658.52 684408.07 35.00 243.67 -101.35 -6.00 -45.46 9350.00 48.62 297.31 8923.55 -363.22 -1633.52 5940662.07 684401.44 35.00 250.87 -98.39 -4.19 -46.17 9360.00 48.39 292.64 8930.17 -360.06 -1640.31 5940665.07 6'84394.58 35.00 258.19 -95.35 -2.32 -46.63 9370.00 48.34 287.96 8936.82 -357.47 -1647.31 5940667.49 684387.51 35.00 265.59 -92.26 -0.43 -46.83 9380.00 48.49 283.29 8943.46 -355.45 -1654.51 5940669.32 684380.26 35.00 273.06 -89.14 1.47 -46.75 9390.00 48.83 278.65 8950.07 -354.03 -1661.88 5940670.57 684372.86 35.00 280.56 -86.04 3.35 -46.41 9400.00 49.35 274.07 8956.62 -353.19 -1669~39 5940671.21 684365.34 35.00 288.07 -82.97 5.19 -45.81 9410.00 50.04 269.57 8963.09 -352.95 -1677~01 5940671.27 684357.71 35.00 295.55 -79.97 6.97 -44.98 9420.00 50.91 265.17 8969A5 -353.31 -1684.71 5940670.72 684350.02 35.00 302.98 -77.06 8.67 -43.96 9430.00 51.94 260.89 8975.69 -354.26 -1692.47 5940669~58 684342.29 35.00 310.33 -74.26 10.28 -42.80 9440.00 53.12 256.74 8981.78 -355.80 -1700.25 5940667.85 684334.55 35.00 317.58 -71.59 11.79 -41.53 9450.00 54.44 252.72 8987.69 -357.92 -1708.03 5940665.53 684326.83 35.00 324.69 -69.07 13.19 -40.19 9454.00 55.00 251.15 8990.00 -358.94 -1711.13 5940664.44 684323.75 35.00 327.49 -66.69 14.10 -39.24 TI.) I ' '' CDR Rig #~~ -~ AlaSkaLAY 0 UT 2000 ARCO ALASKA, INC. SSSVNIP Tubing-PC Casing Gas Lift MandrelNalve 3 SLS PBR PKR XO Tubing-PC STR Perf XO Tubing-PC Liner PKR (3-1/2" Camco No-Go / i...,.N.,ip.,p..!..e..). ......................................................... / NOGO "-'" TTL SOSUB ISO '1 06'21' . APli. 500292080200 SSSV Type: Annular Fluid: Diesel/9.6 NaCl Raf Lng Date: 9/6/82 Reference Lng: BHCS RKB: 74 ff Last Tag: 9258 TD: 9420 ftKB Last Tag Date: 6/13/99 Max Hole 23 dag ~} 5900 Angle: Prudhoe Bay O6-21 -,, , '-,, .., , ,, , · ,'., ............. , Orig Compltn: 9/15/82 Angle ~ TD:'"'~'~ d~g ~ 9452 Last W/O: 9/14/82 Rev Reason: Driff/w dummy gun; PERFS by IrnO Last Update: 11/26/99 Well Type: PROD Angle ~t TS: ! !. deg Q 8945 ..... '..'.::'-".." .',: , ".. '.:""' "'" .'.'..:'..:.::.-.':.'"'.;.-:.. ' ... .:- . .:":' :' :' ':' .." .', Depth Comment 8939 8939' Min ID=2.813" (3-1/2" Camco No-Go NiPple) ............... .~Sa~'.N~.:;~'::.'::: .:,'. :'....::' :;.:~: ;::,'?,: :!...:.'i':..:'?'.: :.'.:...i .'...:'",.,..".:'.'.:.:'.:'.' .:':,..' '. ..:;.'..! : ./:,;..::,.:.::i ,..:.'.';. :::'..:...'."..'i.,.'.:.,'::!.:'.:...'..:.::!:i::.:..;: Data Note FHI./TIW HBBP pkrs have reduced test pressure limits in some cases. Contact ACE (x5102) prior G~ii~!i ~'~',::?.:':~ .!,~:~':.::.!'::".::.::...!;.~..:.i...ii:..:::..:,!.:?.:' ,:::::'.::!:.'.'!.:!.:'".?:::. :,?.:i'~'.:":,:..,.,'.:{),:;'..::~!;??...?:!~;:&~.i,.i'.i~:~:~i~i~;:~;~:~:~:~?~:~L~::?~.:::?:::;~4~:`:.::=:;!~:::L.:~`i::' ~:·'=~i: Data Note 9/15/82 TTL ELM ~ 8956: ELM Tubing Tail (L...ngged 04/28/83) · :~...~. '~'?...'.::...':':;,~'. :"""""~'"'"":': ' ~ ............ '~'=~'=.:'~'":~'~:""~' "~'.:.."':'"~":'"':'¥'"i: :r::~ ............ ~L" "~;~ ::: '~. ? ..'; :~ ?: ? ~:'~;?~":?~!~' '''~'~;: :'='i'::'.: '::"~:?,%?:. :, .':.::' :¥, ~: '~ :~:{~i;~:.~i~?,~.'."~ ~,.'.~.:: ¥ r:.' =~ sr., lu .:.,e ul ,-:. ..),-3 ~ ~. ,~..~..~ .............. ~ .......... ,~,.,=,,,.:~...=.. ......... · ....... .,..:..,.. ..... ,~ ...... .,,:~....:~..,.,..~.. :.. ..... '.~..::~:.,~::,~.~.,~,,-:.~.'~ ,~.,.....IpLl[,,.~,..,..!q._,~,~..i~ ........... [~ .............................................................................................................................................................................. Depth TVD Type Deecdptlon ID 2172 2172 SSSVNIP 5-1/2" Camco BAL-O SSSV Nipple. 4.562 8406 8167 SLS 5-1/2" Camco Sliding Sleeve 0.000 8434 8195 PBR 5-1/2" Baker PBR Assembly 0.000 8448 8209 PKR 9-5/8" x 5-1/Z' Baker FHL Packer 0.000 8457 8217 XO Crossover 5-1/2" x 4-1/2" 4.500 8923 8676 XO Crossover 4-1/2" x 3-1/2" 3.500 8930 8683 PKR 7" x 3-1/2" Baker FB-1 Packer 0.000 8939 8691 NOGO 3-1/Z' Camco No-Go Nipple 2.813 8957 8709 TTL 3-1/2" Tubing Tail 0.000 8958 8710 SOSUB 3-1/2" Camco Shearout Sub 0.000 Size ' Weight Grade Top Btm Feet Description 7.000 29.00 L-80 8519 9420 901 Liner 9.625 47.00 L-80 0 8842 8342 Casing 13.375 72.00 L-80 0 2510 2510 Casing Size Weight Grade Top Btm Feet Description 5.500 17.00 L-80 0 8457 3457 Tubing-PC , 4.500 12.60 N-80 8457 89__2.3 466 Tubing-PC ~00 0.00 .~ , ~ 8923 · ~ 8957 34 Tubing-PC Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Data Vlv Mfr Type Run Comment 1 2908 2908 CAMCO MMIG CAMCO R20 "1.5 RK 0.250 1650 6/13/99 RD 2 4781 4755 CAMCO MMIG HES DMY 1.5 RK 0.000 0 6/11/94 D-14RP 3 6186 6054 CAMCO MMIG CAMCO OV 1.5 DC 0.000 0 7/24/99 (1) 4 7127 6934 CAMCO MMIG HES DMY 1.5 RK 0.000 0 3/7/94 D-14R 5 7631 7414 CAMCO MMIG CAMCO DMY '1.5 RK 0.000 ,.0 1/1/80 RD 6 7706 7486 CAMCO MMIG HES DMY 0.0 RK 0.000 0 1115/95 D-14R 7 8020 7789 CAMCO MMIG CAMCO DMY 1.5. RK 0.000 0 111/60 RD 8 8099 7865 CAMCO MMIG CAMCO DMY 1.5 RK 0.000 0 1/1/60 RD 9 8293 8056 CAMCO MMIG CAMCO DMY 1.5 RK 0.000 0 111/60 RD 10 8369 8131 CAMCO MMIG HES DMY 1.5 RK 0.000 0 9114/94 D-14RP f. RDO 20 7/16" Orifice Zone Status FeetSPF Data Type Comment Interval 'FVD 8920 - 8922 8673 - 8675 O 2 0 9/20/82 IPERF 9212 - 9215 8959 - 8962 ZONE 3 O 3 2 9/4/93 APERF 9215 -,9217 8962 - 8964 ZONE 3 O 2 0 9/20/82 IPERF 9215 - 9217 8962 - 8964 ZONE 3 O 2 2 9/4/93 RPERF 9217 - 9222 8964 - 8969 ZONE 3 O 5 2 9/4/93 APERF 9220 - 9225 8967 - 8972 ZONE 3 5 4 12/5/99 RPERF 9222 - 9228 8969 - 8975 ZONE 3 O 6 2 3/18/93 APERF 9235- 9245 8982 - 8992 ZONE O 10 4 3/18/93 APERF 3,ZONE 2 9235 - 9245 8982 - 8992 ' ZONE 10 4 11/26/99 APERF 3,ZONE 2 9250- 9290 8997 - 9036 ZONE 2 O 40 4 5/1/83 APERF 9250 - 9288 8997 - 9034 ZONE 2 O 38 0 5/3/87 RPERF 9304 - 9314 9050 - 9060 ZONE 2 O 10 4 2/22/92 APERF Interval Data Type Comment 8920 - 8922 9/25/82 STR i;:..:'.~.':i. ! ......... .~i:':.'..'::. ~ ......... ;=: ':~ ,,?".r'".'"" ~':'.::~- ;~.:.,.: ~ ',:...,,:... ,,..,,~ ',:! ~:~. 9160-9235 5/18/99 ISO ,:',:~::" ~ ~:"""", ' ,. ,:"' ,!;.,.?~,-.;: ~. '.~:i' ,.:.=:~,~ ,:.~..,~,,~.~ 9210-9236 5/16/99 SQZ ;~ ";':'"~'"""~:'"4:~ .... " 9215-9217 g/25/82 SQZ 2000' CDR1 Drilling Wellhead Detail lin .~lin~ ~ ~ 7 _ I Hydraulic ~ CT Injector Head ].~ Annular BOP (Hydril),7-1/16" ID ',1. I i ' I~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Ram Type Dual Gate BOPE 7-1/16" ID with ~ Pipe& Blind/Shear Rams Choke Line to dual HCR~ h ~ Ma.~.nual Valves Drilling spool 7-1/16", 5M Choke M~ ~~~~'~~ 7-1/16", 5M 7-1/16" ID with Slip & Pi Kill Line Manual Master Valve ~Tubing Hanger 9-5/8" Annulus ~AY 22 2000 CASH ADVANCE DRAFT ~- ~oo0 THE ORDER OF ~ Issued by Intel,'aeed ~ S~ I ~ ~' Nm'we~ Bank of Grand Junction _ Gnnd Junction, PERIOD ENDING 0 G ' ~ 104 82-40/1021 19,__ I $ I; oo. oo DOLLARS VALID FOR AMOUNT OVER $1000 STATE OF ALASKA ("' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4812' FNL, 958' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 5249' FNL, 2379' FEL, Sec. 02, T10N, R14E, UM At effective depth At total depth 4' FNL, 2465' FEL, Sec. 11, T10N, R14E, UM 5. Type of Well: Development Expiorato~ _ Stratigraphio _ Service_ (asp's 686026, 5941066) (asp's 684617, 5940595) (asp's 684532, 5940559) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. unit or Property name Prudhoe Bay Unit 8. Well number 06-21 9. Permit number I approval number 182-127 10. APl number 50-029-20802 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2436' Production 8768' Uner 901' 9452 feet Plugs (measured) 9196 feet 9217 feet Junk (measured) 8964 feet Size Cemented Measured Depth 20' 19oo# Poleset 80' 13-3/8' 22s9 sx Fondu & 400 Sx PFC 2510' 9-5/8' SOO Sx G & SO bb~s C~ss C 8842' 7' 275 Sx Cless G 9420' Tagged PBTD @ 9217' MD on 4/15/2000. ORIGINAL True vertical Depth 80' 241 O' 8596' 9164' Perforation depth: measured 9210' - 9216'; 9220' - 9226'; 9235' - 9245'; 9250' - 9290'; 9304' - 9314'. Tubing (size, grade, and measured depth ,5-1/'Z', 17#, L-80 PCT 0 8457' MD; 4-1/2', 12.6~, N-80 PCT · 8923' MD; 3-1/2' PCT 0 8957, MD. 'Peckers & SSSV (type & measured depth) 13. Attachmante Description summary of proposal 14. Estimated date for commencing operation June 1, 2000 16. If proposal was verbally approved Name of approver 9-5/8' X 5-1/2' BAKER FHL PACKER 0 8448' MD; 7' X 3-1/2' BAKER FB-1 PACKER 0 8930' MD. 5-1/2' CAMCO BAL-O SSSV NIPPLE. O 2172' MD. Detailed operations program __ BOP sketch __X Date approved 15. Status of well ciassificetion as: Oil __X Gas __ Suspended __ Service 17. I hereby certlly that the foregoing is true and correct to the best o! my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integdty __ BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form required 10- Questions? Call Stephen Ward O 265-1305. Pre~_~ed b~ Paul Rauf IApproval no. Approved by order of the Commission Form 10-403 Rev 06/15/88 · Commissioner SUBMIT IN TRIPLICATE ' '.,"-g; '~.~., ¥::i'- ', ;. , ' . ,...."~ ...,....._. ,. ! .' ..~!;,~!.';,' ', .... ,...., ., ... WELL PERMIT CHECKLIST 'FIELD & POOL INIT CLASS ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. .,5-- Z.~..~:::(~ 13. COMPANY ENGINEERING WELL NAME 0~-- ~/~:~ PROGRAM: exp Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... 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 appropriate 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 ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ........ t ........ 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~_%~L"'~ psig. dev V" redrll I/' serv wellbore seg ann. disposal para req GEOL AREA ,~'"~ · N UNIT# (~//~' ,~"'"'~ ON/OFFSHORE DATE 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. IIAPPR DATE 33. ~'~ ~,ZS"z)D 34. v'~'''' ~m~ II'ANNUI.~R DISPOSAL35. APPR DATE Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... _ ~...Y.~,N Seismic analysis of shallow gas zones ........... ; ~ Y N Seabed condition survey (if off-shore) ......... ./,~..' Y N Contact name/phone for weekly progress reports ~ratory only] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; .... .... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlCIAnnular COMMISSION: Comments/Instructions: c:~msoffice~wordian~diana~checklist (rev. 02/17/00) 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 . simpl, ify finding information, informati~)n 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. Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 01/04/02 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD o11o4/02 52254 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): 1234567890~23456789~~234567890~234567890~234567890~23456789~~23456789~~234567890 !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM,UNIT Data Type STRT.FT 8984.0000: STOP.FT 9500.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value SECT. 2 : TOWN.N 10N : RANG. 14E : PDAT. MSL : EPD .F 0 : LMF . RKB : FAPD.F 74 : DMF KB : EKB F 74 : EDF F N/A : EGL F N/A : CASE F N/A : OS1 DIRECTIONAL : -Remarks (1) (2) (3) CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value PHILLIPS Alaska, Inc. 06-21A Prudhoe Bay Unit 4812' FNL, 958' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 14-Jul-00 500292080201 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line I Ail depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. (4) Well 6-21A was kicked off from the original wellbore of Well 6-21. (5) Well 6-21A was drilled TD @ 9500' MD (9026' SSTVD) on Run 5. (6) The interval from 9475' MD (9003' SSTVD) to 9500' MD (9026' SSTVD) (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Exploration (15-Jul-00). (8) A Magnetic Declination correction of 27.15 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -~ Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 18.19 ft. 23.17 ft. 2 18.19 ft. 23.17 ft. 3 18.19 ft. 23.17 ft. 4 18.19 ft. 23.17 ft. 5 18.19 ft. 23.17 ft. CURVE SHIFT DATA BASELINE 9014.78 9028.33 9037.08 9043.42 9073.05 9084.88 9089.96 9103.85 9112.41 9129.16 9137.57 9155.07 9168.38 9204 07 9221 97 9229 50 9231 36 9329 89 9368 94 9376 76 9438 13 9441 26 9443 12 9445 28 9447 04 9454 96 9469 82 MEASURED, 9014.59 9030.48 9037.87 9043.81 9073.63 9087.03 9091.33 9105.22 9114.76 9130.72 9137.96 9157.23 9169.94 9205.44 9224.52 9230.29 9231.76 9332.05 9370.50 9379.11 9437.35 9440 87 9443 32 9444 69 9446 84 9454 37 9471 00 Tape Subfile: 1 Minimum record length: Maximum record length: [] DISPLACEMENT -0.195312 2.15137 0.783203 0.390625 0.586914 2.15234 1.36914 1.37012 2.34766 1.56445 0.391602 2.15137 1.56445 1.36914 2.54297 0.783203 0.391602 2.15234 1.56445 2.34766 -0.782227 -0.390625 0.195312 -0.586914 -0.195312 -0.586914 1.17383 97 records... 8 bytes 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska, Inc. WN 6-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~234567890~234567890~234567890~234567890~234567890~234567890~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Phillips Gamma Ray dated 15-Jul-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXl4 0.0 2 ROP ROPSl4 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( l) Repcode(66) Data record type is: 0 Entry Type( 2) Size( l) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 i i I 1 i 0 0 i I 0 I 0 i 0 0 i Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size i GR MWD 68 1 API 4 2 ROP MWD 68 i F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 Tape File Start Depth = 8984.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 i datum Rep Code: 68 3103 datums Rep Code: 79 2 datums Tape Subfile: 2 22 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 API API API API LOg Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska, Inc. WN 6-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~234567890~234567890~234567890~234567890~234567890~234567890~234567890 ................................................................................ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN D I MT CNAM ODE P 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) 'Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: i 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 I i i i i 0 0 i I 0 i 0 i 0' 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod i GRAX MWD 68 i API 4 4 99 995 99 i 2 ROPS MWD 68 1 F/HR 4 4 8 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 Tape File Start Depth = 8984.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 3103 datums Rep Code: 79 2 datums Tape Subfile: 3 22 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 01/04/02 52254 01 99 995 99 **** REEL TRAILER **** MWD 01/04/02 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 2 APR ** 1:43p Elapsed execution time = 0.33 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 8984.0000 -999.2500 -999.2500 8984.5000 -487.2076 -999.2500 9000.0000 20.3955 -999.2500 9100.0000 28.2220 126.2474 9200.0000 130.0176 138.3759 9300.0000 19.5719 41.4603 9400.0000 23.6787 22.1367 9500.0000 -999.2500 71.4643 Tape File Start Depth = 8984.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 8984.0000 -999.2500 -999.2500 8984.5000 -490.3755 -999.2'500 9000.0000 20.3560 -999.2500 9100.0000 22.6600 76.4740 9200.0000 146.9040 144.8100 9300.0000 19.8850 34.0580 9400.0000 19.2970 42.9100 9500.0000 -999.2500 -999.2500 Tape File Start Depth = 8984.000000 Tape File End Depth = 9500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS