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192-137
'. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · n Logs-of various kinds [] Other COMMENTS: Scanned by: Beverly Diann~athan Lowell Date: '~/~~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ~~~`~~~ 1~~ ALASKI~L AND GAS CONSERVATION CO~SION FEB 1 2 209 11 G _, ~~ WELL COMPLETION OR RECOMPLETION REPORT AND ~QsTta Ojl & Gas Cons. Commission Ant:lilorape 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban~,~,,( 1/16/2009 ,~G~ 12. Permit to Drill Number 192-137 308-338 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 01/12/1993 13. API Number 50-029-20897-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 01/15/1993 14. Well Name and Number: PBU M-19A 1719 FNL, 195 FWL, SEC. 06, T11 N, R13E, UM Top of Productive Horizon: 729' FSL, 2747' FEL, SEC. 36, T12N, R12E, UM 8. KB (ft above MSL): 52.5' Ground (ft MSL): 26' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 990' FSL, 2704' FEL, SEC. 36, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 10551' 9177' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 629008 y- 5974651 Zone- ASP4 10. Total Depth (MD+TVD) 10595' 9217' 16. Property Designation: ADL 028257 TPI: x- 626024 y_ 5977049 Zone- ASP4 Total Depth: x- 626062 y- 5977310 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi I n' n i ' f i r 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): DLL / MLL /BRCS / GR 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 " r 11 11 n ,~ " / " 47# rf 7 - /4" 11 F 7" 7 1 4 1 ' 23. Open to production or inject ion? ^ Yes ®No 24. Tua1NG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 5-1/2", 17#, 13Cr80 8010' - 8589' MD TVD MD TVD 4-1/2", 12.6#, 13Cr80 8589' - 8849' 8714' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. / ~-~~, ~. $ LUU~Y 7 ~' ~~ .'t ~ ~ DEPTH INTERVAL MD AMOUNT & KIND OF MATERWL USED 6$ ts~ a . . i . 8550' Set EZ Drill SVB Squeeze Packer -8850' P&A w/ 48 BBIs Class 'G' 6806' Set EZSV 6785' Set Whipstock on top of EZSV 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ® No Sidewal l Core s A 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, ff needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~a~i1iY'L~~~IUi~ None ' .t-,~09 Form 10-407 Revised 02/2007 ~~I~INAL CONTINU II~~~ ~ ~ L~~~ ~~ , 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permaftost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Pemlaftost Base detailed test information per 20 AAC 25.071. Sag River 9847' 8546' None Shublik 9893' 8587' Sadlerochit 9992' 8675' 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 foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Drilling Technologist Date ~~ ~/~ PBU M-19A 192-137 308-338 Prepared By NameMumNer: Terrie Hubble, 564-4628 Well Number P Drilling Engineer: Joshua Mallery, 5645545 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-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. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this forrn and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 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. ITeM 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 Submlt Original Ony • • M-19A, Well History (Pre Rig Sidetrack) Date Summary 12/04/08 T/I/O=SSV/600/600, Temp=Sl. PPPOT-T (FAIL), PPPOT-IC (FAIL). Pre RST. PPPOT-T: External check previously installed. Stung into test port (500 psi), unable to bleed to 0 psi. Functioned LDS, ALL moved freely (600 Ib/ft). Still unable to bleed to 0 psi. Pumped into test port, unable to attain test pressure (FAIL). PPPOT-IC: External check installed over internal check, external check installed on PKG port. Test void has been plastic packed, will bleed to 0 psi, but slowly increases to 550 psi. Functioned LDS, (1) pin is broken (flagged), (2) pins have noses ground off and flats cut off. These should be drilled out and replaced pre RST. All others moved freely torqued to 600 Ib/ft. Unable to bleed test void to 0 psi. RU elephant gun to re-energize Y seal. Unable to move existing plastic in seal. Unable to pressure void above 2000 psi, drops off to 600 psi quickly. (FAIL) 12/04/08 WELL S/I ON ARRIVAL. EQUALIZED WRP C~3 8612' SLM. 12/05/08 PULLED 4 1/2 WRP FROM 8612' SLM. DRIFTED TO 4 1/2 CROSSOVER C~ 8588' SLM W/ 4.50" e CENT. WELL LEFT S/I, PAD OP NOTIFIED. 12/06/08 T/I/0=520/470/480. SI. TBG FL (Full Bore). TBG FL C~3 870' (20 bbls). SV, WV, SSV =Closed. MV = Open. IA & OA = OTG. 12/07/08 T/I/0= 500/500/520 Temp= SI Infectivity test Loaded the tubing w/ 5 bbls meth spear and 20 bbls crude. Pumped a total of 45 bbls crude during test. Results as follows: 1 bpm = 400psi 2bpm = 450psi 3bpm = 475psi 4bpm = 550psi 5bpm = 600psi FWHP's = 300/550/550 Swab, Wing, SSV =shut. IA, OA, Master =open. 12/15/08 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 250/500/500 PSI. SET HALLIBURTON 5.5" EZ DRILL SVB SQUEEZE PACKER AT 8550'. SURFACE AND VISUAL CONFIRMATION OF PKR SETTING. DISCUSSED FINAL VALVE POSITIONS WITH DSO. FINAL T/I/O: 50/500/500 PSI. WELL LEFT SHUTIN. JOB COMPLETE. 12/19/08 T/I/0= 180/500/500. Temp= SI. TBG FL (pre-Coil). ALP = 0+, SI & blinded C~ casing valve. TBG FL C~? 810' (19 bbls). 12/20/08 (P&A thru retainer) Start BOP test, problems w/ pump. Restart BOP test. Complete BOP test. MU and RIH with stinger assy. Stab into retainer ~ 8540'. 12/21/08 Establish rate/ pressure pumping thru retainers Pressure test CTxT, good seals Pumped 48 bbls 15.8 ppg Class G cmt followed by 5 bbls water thru retainer, leaving TOC -8850' (tubing tail). Unsting from retainer, flush coil with biozan and chase OOH at 80%. FP coil and well with 60/40 while POOH. At surface, perform combo MIT- TxIA to 2300 gsi. Pass. Final T/I/O - 140/360/0. RDMO. Notify Pad Op of well status. Job Complete. 12/22/08 WELL S/I ON ARRIVAL. DRIFT TO 8200' SLM WITH 4.50" CENT, S-BAILER (EMPTY). WELL LEFT S/I, PAD-OP NOTIFIED. 12/24/08 T/I/0= 130/380/6. Temp= SI. Bleed WHPs to 0 psi (WH REPAIR). AL blinded & shut in C~ casing valve, ALP=O psi. T & OA FL near surface. IA FL 210' (10 bbl). Bled IAP from 380 psi to 160 psi gas & fluid with 4 bbls of returns in 4 hr. During IAP bleed TP decreased to 0 + psi. Bled OAP from 6 psi to 0 psi in 3 min. Monitor for 30 min. IAP increased 30 psi. Final WHPs= 0+/190/0. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. Page 1 of 2 • M-19A, Well History (Pre Rig Sidetrack) Date Summary 12/24/08 T/I/0= 0+/190/0+. Temp = SI. Bleed WHPs to 0 psi (pre SDTRCK) (Drill out LDS). IA FL near surface. Bled IAP to bleed tank from 190 psi to 95 psi in 6 hrs (all gas). Monitored for 30 min. IAP increased 10 psi. Final WHPs= VAC/100/0+. 12/26/08 T/I/O = 0+/110/50. Temp = SI. IA FL post bleed. AL C~ 0+ psi & blinded ~ casing valve. IA FL ~ 276'. IAP increased 10 psi & OAP increased 50 psi over 2 days. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 12/27/08 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 0 / 100 / 50 PSI. CUT 5-1/2" TUBING AT 8010' WITH 4.15" JET CUTTER. FINAL T/I/O = 0 / 250 / 50 PSI. WELL LEFT SHUT IN ON DEPARTURE. JOB COMPLETE. 01/02/09 T/i/0=180/120/140 Circ-Out (Pre-RWO) Pumped down Tbg with 5 bbls neat meth spear and 14 bbls crude to verify Tx1A comm. Pumped 853 bbls 1 % KCI, 3 bbls neat meth, 148 bbls warm diesel and 3 bbls neat meth down Tbg taking returns up IA to the flowline. FP TxIA via U-tube. Freeze protect jumper with 2 bbls diesel, flowline with 5 bbls meth, 103 bbls crude, & 10 bbls diesel tail. 01/03/09 MIT OA PASSED to 2000 psi (Pre Sidetrack) Pumped 1.3 bbls crude down OA to reach test pressure. OA lost 100 psi in the 1st 15 mins and 50 psi in the 2nd 15 mins for a total pressure loss of 150 psi in 30 mins. Bled OA (-1 bbl). FWHP's=vac/5/15. Valve postions upon departure: SV, WV, SSV =closed. MV = open. IA & OA = OTG. 01/04/09 T/I/0= SSVNAC/0+. Temp= SI. Monitor WHPs pre RWO. AL blinded C«3 the casing valve. SW, WV, SSV =Closed. MV =Open. IA, OA = OTG. NOVP. 01/06/09 T/I/O=SSV/0/3. Temp=Sl. LDS Drill Out. (Pre RWO). Bled OAP from 3 psi to 0 psi in 60 seconds. Assist in LDS drill out. Final WHPs=SSV/0/3. WV, SV, SSV =closed. MV =open. IA & OA = OTG. 01/06/09 T/I/0=0/0/0, Temp=Sl. LDS drill out. Pre RST. 3 damaged LDS on casing hanger. Opened slotted bleeder screw to verify 0 psi in test void. Rigged up Wach's drill. Drilled LDS, installed one new 1 1/4" LDS assembly, and two blanks. Unable to remove nose on one pin. Nose is loose and spinning with drill bit, should not be a problem (blank). One has damaged threads in casing head (blank). 01!06/09 T/I/O Vac/0/0 Set 6 3/8" CIW J BPV #422, 1-2' EXT used, tagged C«? 108, no problems pre 9ES. 01/07/09 T/I/0=0/0/0, Temp=S1. Remove LDS nose from casing head (pre RST). One LDS nose left incasing head during previous LDS drill out (aprox 1/4"). Opened slotted bleeder screw to verify 0 psi in test void. Torqued LDS to 600 Ib/ft. Removed blank LDS. Attempted to push nose out of profile, no success. Rigged up Wachs drill and drilled out the final amount. Tapped threads and installed 1 1/4" LDS assembly. Page 2 of 2 • BP EXPLORATION Page 1 oi~ Operations Summary Report Legal Well Name: M-19 Common Well Name: M-19 Spud Date: 2/4/1983 Event Name: REENTER+COMPLETE Start: 1 /12/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/3/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To II Hours Task ~ Code' NPT Phase Description of Operations _ 1/12/2009 00:00 - 03:00 3.00 MOB P PRE __ _ Bridle up and lower pipe skate chute, secure bridle lines in derrick. Secure cellar and prep rig floor for lowering derrick. 03:00 - 05:00 2.00 MOB P PRE PJSM. Lay down derrick. Blow down pit complex and seperate pit complex from sub. 05:00 - 07:00 2.00 MOB P PRE Move sub off well, pick-up mats and herculite and clear location. 07:00 - 10:00 3.00 MOB N WAIT PRE Wait on Security before moving 9ES off R-Pad. 10:00 - 16:00 6.00 MOB P PRE Move sub from R-Pad to M-Pad. Sub on location at 16:00 hrs. 16:00 - 00:00 8.00 MOB N WAIT PRE Various mobilization and RU tasks: load 4" drill pipe in pipe shed and strap, raise cattle chute, plug in top drive, pin blocks and torque tube while waiting on trucks. 1/13/2009 00:00 - 01:30 1.50 RIGU N WAIT PRE PJSM. Hang bridal lines. MU hydraulic service loop. Hang rig tongs. Make up kelly hose, rack subs and secure lines. Rim acce tat 00:00 hours. 01:30 - 02:00 0.50 RIGU N WAIT DECOMP Change out saver sub. 02:00 - 07:30 5.50 WHSUR N WAIT DECOMP PJSM. Rig up LRS and test OA and IA. Test OA to 2000 psi for 30 minutes. Lost 30 si in first 15 minutes and 10 si in the second 15 minutes -PASS. Test IA to 2300 for 30 minute . Lost 35 si in the first 15 minutes and 0 si in the secon 15 minutes -PASS. Bleed off and rig down LRS. Trucks showed up at 16:30 hours, wait on security until 19:30 hours. 07:30 - 08:30 1.00 WHSUR P DECOMP PJSM. Rig up DSM lubricator. Test to 1000 psi for 10 minutes - OK. Pull BPV. RD. 08:30 - 16:00 7.50 WHSUR P DECOMP Spot pit complex. Hook up interconnect. Spot truck shop and satelite camp. Rig up to tree with IA, second kill and second choke lines. Set cuttings box. Rig up line to cuttings box. Take on seawater in pits. Prime mud pumps and test surface lines to 3500 psi - OK. Continue to strap DP in pipe shed. 16:00 - 19:00 3.00 WHSUR P DECOMP Pump seawater down annulus and circulate out diesel from tubing. Swap and pump long way. Pump Safe-Surf pill. Continue to pump at 200 gpm with 450 psi until clean seawater back. Shut down and confirm well dead. 19:00 - 20:00 1.00 WHSUR P DECOMP Blow down lines and rig down. 20:00 - 22:00 2.00 WHSUR P DECOMP PJSM Run in and set TWC on drv rod Test from below to 1000 si for 10 minutes - OK. Blow down and rig down. Bleed off OA. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM. Bleed off void, adapter and control lines. Break tree from adapter and ND. 1/14/2009 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Finish ND of tree. Remove from cellar. 01:00 - 07:00 6.00 BOPSU P DECOMP PJSM. Remove 11" x 13" spacer spool and install new 13-5/8" spacer spool. NU BOP stack. NU riser. Make up turnbuckles and install mousehole. Rig up lines and prepare to test BOPE. 07:00 - 14:30 7.50 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low and 3500 psi high as per AOGCC. Test upper rams with 4" and 5-1/2" test joints and test hydril and lower rams with 4" test joint. Test witness waived by John Crisp with AOGCC. Test witnessed by WSL Joey LeBlanc and Toolpusher Charley Henley. Rig down test equipment and blow down lines. 14:30 - 21:30 7.00 DHB P DECOMP M lubric for and extension. Test to 1000 si - OK. Make 3 attem s to ull TWC with no success. Suck out stack and verif debris on to of lu . PU drill i e sin le and flush stack. Attem t again to screw into TWC - No Go. Neck down end of drill pipe, mix andpum~a hi-vis pill at 550 gpm Printed: 2/9/2009 2:00:11 PM • BP EXPLORATION Page 2 oi~- Operations Summary Report Legal Well Name: M-19 Common Well Name: M-19 Spud Date: 2/4/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/3/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To .Hours Task Code NPT Phase Description of Operations 1/14/2009 14:30 - 21:30 7.00 DHB P DECOMP with 650 psi. Screw into TWC and pull to rig floor. LD lubricator and extention. 21:30 - 22:00 0.50 PULL P DECOMP Make up 5-1/2" fishing spear on 4" drill pipe. 22:00 - 23:00 1.00 PULL P DECOMP En a e tubing hanger with 5-1/2" spear. Pull loose with 165k. Pull to rig floor with 155k. Break out and lay down tubing hanger and pup. Lay down spear assembly. 23:00 - 00:00 1.00 PULL P DECOMP Rig up Camco spooling unit, power tongs and handling equipment to pull 5-1/2" tubing. 1/15/2009 00:00 - 10:30 10.50 PULL P DECOMP PJSM. Pull 5-1/2" tubing from 8010' MD. Pull and lay down a total of 200 full joints, one cut joint at 16.22', one SSSV with control line and 4 GLM's. Recovered 27 clamps and 3 SS bands. 10:30 - 11:30 1.00 PULL P DECOMP Lay down handling equipment, clear and clean floor. 11:30 - 12:30 1.00 CLEAN P DECOMP PU casing scraper BHA and tools. Run in and set wear ring with 9-1/4" ID. 12:30 - 15:00 2.50 CLEAN P DECOMP Make up 9-5/8" casing scraper BHA to 797'. Up and down weig t 80 . 15:00 - 22:00 7.00 CLEAN P DECOMP RIH picking up 4" drill pipe to 7868'. Rack stand back. Pick up 3 more singles. PU stand, run in and tag tubing stub at 8010' MD. Pull and rack back 3 stands. 22:00 - 23:00 1.00 CLEAN P DECOMP Circulate hi-vis sweep surface to surface at 543 gpm with 1893 psi. Up weight 180k, down weight 155k. 23:00 - 00:00 1.00 CLEAN P DECOMP Monitor well, static. POOH to 6244'. Up weight 151 k, down weight 130k. 1/16/2009 00:00 - 02:30 2.50 CLEAN P DECOMP PJSM. POOH with 9-5/8" casing scraper assembly to 797'. 02:30 - 03:30 1.00 CLEAN P DECOMP Stand back HWDP and drill collars. Lay down 9-5/8" casing scraper and assembly. 03:30 - 04:00 0.50 CLEAN P DECOMP Clear and clean floor. 04:00 - 06:00 2.00 DHB P DECOMP PJSM. Pick up E-line tools. Rig up for GR/CCL run. Pick up EZSV. 06:00 - 09:00 3.00 DHB P DECOMP ~I -I with 9-5/8" EZSV on E-Line with GR/CCL. Locate collar and set plug top at 6806' ELM. POOH with E-Line. Close rams test to 2000 si for 5 minutes. RD E-Line unit. 09:00 - 10:00 1.00 DHB P DECOMP PJSM. Close blind rams. Test EZSV to 2100 si for 30 minutes. No loss of ressure -PASS. 10:00 - 10:30 0.50 WHSUR P DECOMP Run in test joint and pull wear ring. 10:30 - 11:00 0.50 W HSUR P DECOMP Attempt to pull 9-5/8" packoff. Recover one half of packoff_. 11:00 - 12:30 1.50 WHSUR P DECOMP Bleed off OA. Drain stack and monitor well. As well was monitored from the time we moved over the well we received dispensation approval from town to do wellhead work. 12:30 - 13:30 1.00 WHSUR P DECOMP Nipple down BOP stack and tubing spool. 13:30 - 15:00 1.50 WHSUR P DECOMP Remove rest of 9-5/8" packoff and install new packoff. NU tubing spool and BOP stack. 15:00 - 15:30 0.50 WHSUR P DECOMP Test stack break and packoff to 5000 psi for 30 minutes, OK. 15:30 - 18:00 2.50 STWHIP P WEXIT PJSM. Run in wear ring. MU GEN II whipstock and milling BHA to 854'. 18:00 - 18:30 0.50 STWHIP P WEXIT Shallow test MWD - OK. Up and down weight 85k. 18:30 - 22:00 3.50 STWHIP P WEXIT RIH with stands out of derrick to 6683'. Up weight 165k, down weight 145k. 22:00 - 23:00 1.00 STWHIP P WEXIT Make up top drive. Wash and orient to 16 RHS. Shut down. Pick up last stand drop down avid tag up at 6806' MD. Set bottom anchor with 20k down. PU 10k to verify set. Set down 30k and shear off of slide. Pick up 30' and verify shear. Slide Printed: 2/9/2009 2:00:11 PM m'~~~ BP EXPLORATION Page 3 0#' Y Operations Summary Report Legal Well Name: M-19 Common Well Name: M-19 Spud Date: 2/4/1983 Event Name: REENTER+COMPLETE Start: 1/12/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/3/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date ~ From - To Hours Task Code NPT Phase Description of Operations 1/16/2009 22:00 - 23:00 1.00 STWHIP P WEXIT final orientation at 16 degrees RHS. TOW 6785', BOW 6802'. 23:00 - 00:00 1.00 STWHIP P WEXIT Pump hi-vis spacer and displace seawater with 10.9 ppg LSND at 506 gpm with 2100 psi. 1/17/2009 00:00 - 00:30 0.50 STWHIP P WEXIT PJSM. Displace seawater to 10.9 ppg L ND. Shut own, get slow pump rates. 00:30 - 07:30 7.00 STWHIP P WEXIT Mill 8-1/2" window in 9-5/8" casing. Pump at 500 gpm with 2208 psi. Torque 5-8k at 90-100 rpm. WOB 3-12k. Mill window and new formation to 6827' MD. Up weight 163k, down weight 137k, RT weight 150k. 07:30 - 08:30 1.00 STWHIP P WEXIT Circulate super sweep, surface to surface at 500 gpm with 2200 psi. Work through window with and without pumps - no problems. 08:30 - 10:00 1.50 STWHIP P WEXIT Perform LOT to 13.75 ppg EMW with 900 psi. Monitor well. Pump dry job. Blow down lines. Mud weight in and out 10.9 PPg• 10:00 - 14:30 4.50 STWHIP P WEXIT POOH to 854'. Up weight 137k, down 113k. 14:30 - 17:00 2.50 STWHIP P WEXIT PJSM. Stand back HWDP. Lay down drill collars. Break out and lay down milling assembly. Upper window mill in gauge. Lay down handling equipment. Clear and clean floor. 17:00 - 18:00 1.00 STWHIP P WEXIT Service rig and top drive. Flush stack, function rams. Wash under shakers and flush flow line, possum bellies. Final weight of metal recovered - 295 lbs. 18:00 - 21:00 3.00 STWHIP P WEXIT PJSM. Pick up 8-1/2" intermediate drilling BHA to 831'. Change out handling equipment. 21:00 - 22:00 1.00 STWHIP P WEXIT PJSM. Cut and slip 95' of drilling line. Service blocks. 22:00 - 22:30 0.50 STWHIP P WEXIT Shallow test MWD - OK. Up and down weight 75k. 22:30 - 00:00 1.50 STWHIP P WEXIT RIH picking up 4" drill pipe singles to 1978'. Up and down weight 90k. 1/18/2009 00:00 - 01:00 1.00 STWHIP P WEXIT PJSM. PU 4" DP singles to 3500'. Fill pipe. 01:00 - 02:00 1.00 STWHIP P WEXIT RIH on stands to 6600' MD. Prepare to log to bottom. 02:00 - 05:00 3.00 STWHIP P WEXIT Run recorded logs with no pumps or rotary at 160 fph from 6600' to 6807'. Obtain calculated clean hole ECD at 11.34 ppg EMW. Get slow pump rates. 05:00 - 00:00 19.00 DRILL P INT1 Work way to bottom of 6827' MD. Continue to record log data to 6850'. Directional drill ahead to 7139'. Pump at 550 gpm with 3065 psi on bottom, 2903 psi off bottom. Rotate at 70-100 rpm with 7k torque on bottom, 6k torque off bottom. WOB 10k. Up weight 180k, down 130k, RT 145k. Continue drilling ahead to 8286' MD, 7261' TVD at 543 gpm with 3800 psi on bottom, 3480 psi off bottom. Rotate at 80-100 rpm with 7k torque on bottom, 6k off bottom. WOB 10-15k. Up weight 166k, down 140k, RT 156k. Calculated ECD 11.29 ppg, ECD 12.03 ppg. Mud weight in and out 10.9 ppg. AST - 4.78, ART - 7.28. 1/19/2009 00:00 - 00:00 24.00 DRILL P INTi PJSM. Drill ahead to 9146' MD. Pump at 530 gpm with 3530 psi off bottom, 3700 psi on bottom. Rotate at 80 rpm with 7k torque off bottom, 8k on bottom. WOB 12-18k. Up weight 187k, down 145k, RT 165k. Calculated ECD 11.35 ppg, ECD 11.8 ppg. Mud weight 10.9 ppg in and out. Continue to drill ahead to 9920' MD, 8558' TVD. Circulate samples up for Liner TD pick. Pump at 528 gpm with 3900 psi Printed: 2/9/2009 2:00:11 PM TREE= 4-1f16"` C1W WELLH~ti C7 = MCEVOY - -- A~:TUATOR = OTIS KB. ELEV = BF. F~EV = 27.5` KOP = 680fl` Max Angler . r_~ 101°~1081T I~tum Mb = _ ~; Datum TV D - ~ s8oD' SS ' ~~ ZD" CONDUCTOR 71 Q' 13-318" CSC, 72#, L-SC1, A] =12.347" 25'92' Mn9mum Id = 3.725" 9783'..... 4-1f2" HES XN wIPP'I..E 7" T1tBK LNR, 2611, L-8t3 TCIt f~` .0383 bpf, If3 = 6.276" TOP OF 7" LNR &fr' ~~ PERFORATK}N SUMMARY REF LOG: ANGLEATTOPPERF' ~~5' t+k~te: Refer to Produc#ion DB for his#orical perf data S¢E SPF lNTER1/AL OF~IWSQZ DATE 27d8 S 1"'U~.1?,: OPN GL p,:ic 9-518" LNR, 47#, L-80 BTRS, ID=$.681" I-I $83U' PBTD ~ °: ~ F' _,r _ ...~ .t1_.'~ GATE REV BY COMMENTS DATE REV t3Y COMMENTS yip ,.. .r.F. l,~. ~.C tSN~.. [' I ` I ~ ... _ ... ~ 1 . PRUL`jFiOE BAY UNR WELL ~, BP EzptoratPon {Ataska) S N£iTE: LlR1G WEL„LSQRE & SIDEfRRCK "A" T SMftWN BELQW iIVHIPSTC3CK ~ 68f1(i ' ** 4-1/2" CHF{{3ME TSG tIR LNR *~`: ' :.~ i~' 4-if2" HES X NIP, ID 3.81" 25'[~ 2'~ 9-x18"' [3V PKR ESTMATED TOP OF CENtENT GAS LIFT MANDRELS S~F MU 1'J D DPI. lY PE U LV LATCH PORT hA 'E ~ ~ _. ~,_ a ~ . ~ - - z 1 _._ ~,11LLC}U1' i(tjltVDt~'~1 {M-198) 6785' - 6802' c,, ,. 4-1/2" HES X NIP; I©= 3.813" - - -- '752' 4-112' HtS X NIP, #D 3:813'" -~-1f2" HES XN N9P, ID = t~ ''4-1/2" yhILEG, IC1= 3.958'• T' X 5"' ~:KR HRp ZXP LTP w t10" ~:, t17 = 4.80^ ,~ ..__ . I[? ~ 3.958" X~ 4-if2"' TBG, 12.6#, --~- 13CR-84 VAM TOP, .0152 bpf, ID = 3.958" 7" LNR.., 2~, L-8t3 BTC-M .'.y _0383 bpf, ID = 6.276" PBU M-19A (192-137) ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 12, 2008 9:03 AM To: 'Mallery, Joshua' Cc: Hobbs, Greg S (ANC) Subject: RE: PBU M-19A (192-137) Not a problem Josh. The completed zone should be effectively isolated. 1 will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Mallery, Joshua [mailto:]oshua.Mallery@BP.com] Sent: Thursday, December 11, 2008 5:19 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: PBU M-19A (192-137) ~,~~~~~ ~,~ "~~ ~ :~ ~~~~~ Tom, The wellbore for M-19A has 431' of fill from 10,120' to total depth at 10,551'. This alters the 66 bbl stated cement calculation within the Sundry. The calculations within the Sundry assume no fill. We intend to pump less cement than stated in the Sundry. The new cement calculation considering the 431' of fill in 7" 26# liner (.0383 bblJft) is 48 bbls. This will put cement from 8850' to 10,120'. The fill doesn't affect getting cement across the perforations. Thanks, Joshua Mallery BPX (Alaska) GPB Drilling Engineer 907.564.5545 (Office) 907.244.4351 (Cell) Josh ua. Mallery@bp. com 12/12/2008 • • `~ ~ ~ ~ e SARAH PALlN GOVERNOR OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~S~`RQATIOIQ COl-II-iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. ~ ;~ 200b PO Box 196612 ~,~~~ SEA '`° ~ ~~~~ Anchorage, AK 99519-6612 ~ ~, Re: Prudhoe Bay Field, Prudhoe Bay, Oil Pool, PBU M-19A Sundry Number: 308-338 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ft the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ ~ Chair DATED thi~3day of September, 2008 Encl. ..D .,w . _ P ~„. . „~ d w , ,~4j'~ STATE OF ALASKA ~ '~~ ~~ ALAS~OIL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVAL ~°~ 20 AAC 25.280 1. Type of Request: ®Abandon i ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time EMensibn ^ 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 192-137 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20897-01-00' 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 M-19A, Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028257 ' 52.5' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10595' 9217' , 10551' 9177' None None Ln i M I 11 11 ' 2 1-/" 2 2' 2592' 4 2 7 I 2' 7 4 P 1 4' 7" 74'- 74 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9992' -10138' 8675' - 8806' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 8849' Packers and SSSV Type: 7" x 4-1/2" Baker'SABL-3' Perm packer Packers and SSSV MD (ft): 8714' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ~ ^ Exploratory ®Development ^ Service ^ Detailed Operations Pro ram 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoi is true and correct to the best of my knowledge. Contact Joshua Mallery, 564-5545 Printed Name Gre bb Title Engineering Team Leader Prepared By N~ne/Number: Signature Phone 564-4191 Date ~~' (~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ ~ ~ S.Z4~CF ~5 ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~~~© ~S ~ ~~ ~~~5~. Subsequent Form Required: ~~ APPROVED BY ~~ A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Reid Ofi/2606 Submit In Duplicate ("`~ r ~ ~ ~~ ~I ~ ~. ~E€' ~ 2008 • M-19A Prepare to Sidetrack Well Type: Producer Current Status: This well is currently shut-in. • Request : BPXA requests approval to plug and abandon M-19A in preparation for sidetracking this well. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Scope of Work: Plug and abandon the perforations by squeezing cement past a fish at 8,626'. Drill a two-string Ivishak sidetrack. MASP: 2450 psi Estimated Start Date: December 2008 Pre-rig prep work: S 1 Retrieve the WRP at 8,609' MD. C 2 Set cement retainer at 8,550' MD and squeeze 66 bbls of cement to plug and abandon the perforations. TOC-8850' Volume per foot of 7", 26#, 13Cr-80: 0.0383 bbl/ft Pressure test the cement plug to 2300 psi prior to cutting the tubing. This is to ensure the cement plug could serve as a barrier. SBHP: 3,335 si SBHT: 205 °F E 2 Jet cut 5-'/z" tubin C~3 8,000' MD Ref on final com letion tubin tall F 3 Circulate well with seawater and cap with diesel thru the cut. MITOA to 2000 psi. Bleed casing and annulus ressure to 0 si. W Function tubing and casing lock down screws. Repair and replace as needed. Perform PPPOT- T and PPPOT-IC. O 4 Set a BPV in the tubin han er. O 5 Remove the well house and flow line. Level the ad as needed for the ri . • • l ~~.~~Q~ Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 5 1/2" tubing string. Test the lower set of pipe rams. 3. Cleanout 9-5/8" casing to the cut and dress-off stub. 4. Run whipstock to 7000' MD and mill window. 5. Drill 8-1/2 hole to TD. 6. Run and cement 7" L-80 casing from TD with 150' casing lap in 9-5/8". 7. Drill 6-1/8" production hole to TD. 8. Run and Cement 4-1/2" 13Cr-80 liner with 150" liner lap in 7". 9. Run 4-1/2" Chrome completion. 10. Set BPV. ND ROPE. NU and test tree. RDMO. Drilling Engineer: Joshua Mallery (907) 564-5545 Production Engineer: Don Brown (907) 564-4323 Geologist: Cole Abel (907) 564-5576 ATTACH: Current Schematic Proposed Schematic TREE= 7-1/16" CNV WELLHEAD = 13-5/8" McEVOY/5M ACTUATOR = 6" OTIS KB. ELEV = 62.8' BF. ELEV = 22.5' '~ KOP = 3100' Max Angle = 41 @ 8800' Datum MD = 10176' Datum TVD = 8800' SS SAFETY NOTE: NO ACID WORK 4-1 /2" ~ 5-1 /Z" . ~ - 19 A AVA~TH ACROSS GLM #6. NR. 2.34" ID @ 3061' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2592' Minimum ID = 2.313" @ 8838' 2-718" X NIPPLE REDUCER SET IN XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3061 2996 9 OTIS DOME BK 16 02/24/03 5 5103 4717 40 OTIS DMY RA 4 6702 5949 38 OTIS DOME RA 16 02/20/03 3 7825 6848 36 OTIS DMY RA 2 8455 7356 39 OTIS DMY RA 1 8527 7412 40 OTIS SO RA 20 02/20/03 ~5-1/2" TBG, 17#, 13-CR-80, .0232 bpf, ~ = 4.892" ~ $54$' g ¢$' 5-1/2" X 4-1/2" XO TOP OF 4-1/2" TBG 8548' j 8636' 7" BOT PKR/HGR W/TIEBACK IXT, TOP OF 7" LNR 8636' L-80 PLAIN CARBON 813" 1/2" PARKER SWS NIP ID = 3 8695' 4 - , . 8714' 7" X 4-1/2" BRK SABL-3PERM LATCHED PKR 'i i-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID= 3.958" I--~ $849' PERFORATION SUMMARY REF LOG: BHCS ON 01/16/93 ANGLE AT TOP PERF: 26 @ 9992' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPNISOZ DATE 3-3/8" 4 9992 - 10106 O 01/30!93 3-3/8" 4 10116-10138 O 01/30/93 3-3/8" 6 10000 - 10024 O 01/30/93 8783' 4-1/2" PARKER SWS NIP, ID = 3.813" 8838' 4-1/2" PARKER SWN NIP W/ 2-7/8" X NIP REDUCER, ID = 2.313" 8849' 4-1/2" TUBING TAIL -WLEG $$32' ELMD TT LOG NOT AVAILABLE 9-5/8" SIDETRACK WINDOW 8823-8878' 10301' (~ MARKER JOINT HES BRIDGE PLUG ~ 9085' 9-5/8" LNR 47#, L-80, BTRS PBTD - 7" LNR 26#, 13-CR-80, .0383 bpf, ID = 6.276" I 10551' I -t~54O DATE REV BY COMMENTS DATE REV BY COMMENTS 1983 ORIGINAL COMPLETION 11/29/03 ATD/TLP ADD 9-5/8" LNR INDICATION 01121/93 SIDETRACK COM PLETION 09/24/05 EZL/TLH WAIVER SFTY NOTE DELETED 02/28/02 RNITP CORRECTIONS 02/20/03 JB/KAK GLV GO 02/24/03 PWE/KK RUN HES DWP POGLM 08/18/03 TP/TLH WAVER SAFETY NOTE 2204' 5-1/2" OTIS SSSV LAND NIP, ID = 4.562" 2512' 9-5/8" DV PKR 3045' - 3075' HES DWP POGLM, ID = 2.34", 1" LGLV (02/24/03) GAS LIFT MANDRELS PRUDHOE BAY UNIT WELL: M-19A PERMff No: 1921370 API No: 50-029-20897-01 SEC 6, T11 N, R13E, 1719' FNL & 195' FWL BP Exploration (Alaska) '', TREE= 7-1116" CqN ~WEL~FFEAD=_ 13-5/8" McEVOY ACTUATOR = OTLS KB. ELEV = 62.8' BF. ELEV = 22.5' ICOP = 3100' Max Angle = ° (off' Datum MD = 12916' Datum TVD = 8800' SS JD DRA• M-19B t0" COI~UCTOR, ~ _ ? 13-3/8" CSG, 72~k, L-80, ~ =12.347" ~-259-2' Minimum ID = 3.73" @ 9807' 4-1 /2" HES XN NIPPLE 7" T~BK LNR, 265, L-80 TCq .0383 bpf, ~ = 6.278" TOP OF 7" LNR (xx/xwxx> H 7000' s-5~8" ¢sv (xxncx/xx) I~ 7025' ~5-112" TBG STUB (Xx/X)UXX) ~ PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF: ° (r~' Note: Refer to Production DB for historical pert data SIZE SPF gYTERVAL OPN/SOZ DATE LNR 475, L-80 BTRS, ID = 8.681" MATED TOP OF CEMENT ra S ~ i~ tutA t~RFI S ST ~ TVD DEl/ TYPE VLV LATCH PORT DATE 5 3400 4 5400 3 6800 2 8865 7700 1 9700 8350 X T' BKR PKR, ID = 6.30" M~LOUT WgVDOW (M-198) - ' 9737' 4-1 /2" HES X N~, ~ = 3.813" 9752' 7" X 4-1 /2" BKR S-3 PKR, ~ = 4.00" 9777' -~4-112" HES X N~, q) = 3.813 9$07' 4-1/2" HES XN N~, ID = 3.73" 9822' 4-1/2" WLEG, ~= 3.958" 9$22' 7' X 5" BKR ZXP LTP w~/10' TBG HGR, ~ = 4.80" / ~=3.9 8' XO 4-1/2" TBG, 12.8#, --I~ \ 13CR, .0152 bpf, ~ = 3.958" 7" LNR, 265, L-80 BTGM L._ .0383 bpf, ~ = 6.276" 4-1/2" LNR, 12.65, 13CR, .0152 bpf, q) = 3.958" DATE REV BY COMMEM'S DATE REV BY COMMENTS 1983 ORIGINAL COMPLETION 01121193 D-16 SIDETRACK M-19A) 310ETRACK (M-19B) 08/25!08 ?/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT 1NELL: M-19B PERMIT No: API No: 50-029-20897-02 SEC 6, T11 N, R13E, 1719' FNL & 195' FWL BP f3cploratlon (Alaska) S TE ORIdNAL WELLBORE NOT SHOWN BEL DGE PUK3 ~ 8830' "*" 4-1/2" CHROME TBG 8 LNR "*• 4-1/2" HES X NIP, ID= 3.81"1 2' 1 9-5/8" DV PKR7 Page 1 of 2 ~J Maunder, Thomas E (DOA) From: Nadem, Mehrdad [NademM@BP.com] Sent: Tuesday, September 23, 2008 8:54 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: M-19A (192-137) Plugging Tom: Attached is the requested information, 1 will call later on today to further discuss the submitted information. M-19B will target remaining Zone 4B oil in the vicinity of M-19A and bypassed Zone 46 oil farther north and west of M-26. M-26 was sidetracked to M-26A in 1992 due to a rapidly increasing and high water cut that is believed to be from a channel into Zone 4 (and possibly a fault in Zone 3) preventing effective sweep of Zone 4 reserves. M-196 wilt access 1,007 MBO of reserves. The M-19B horizontal sidetrack targets a "dead spot" in the M-Pad line drive water flood caused by the loss of the M-19A due to mechanical integrity issues. Best Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907!564-5941 Cell: 907/440-0213 Email: nademm@bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 23, 2008 8:42 AM To: Nadem, Mehrdad Cc: Hobbs, Greg S (ANC) Subject: RE: M-19A (192-137) Plugging Mehrdad, Thanks for the comments, however these only address the mechanical reasons for the plugback and redrill. Can you or the responsible reservoir engineer provide some comments or a statement regarding the status of the reserves that are presently accessed by the M-19A penetration and how these reserves will be affected by the new penetration M-19B? Catl or message with any questions. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Monday, September 22, 2008 3:18 PM To: Maunder, Thomas E (DOA) Subject: FW: M-19A (192-137) Plugging Tom: Hope all are well. Josh is in training, and Greg asked me to respond to your request. M-19A Sundry application is to seek AOGCC's approval to plug and abandon the existing perforations in 9/23/2008 Page 2 of 2 • • preparation for the upcoming side track. There is fish in M-19A at 8,626' MD. A such, a cement retainer will be set at 8,550' MD, and cement will be squeezed per the volumes provided in the Sundry. Cement top is expected to at 8,$50' MD. The tubing will then be cut at 8,000' MD. The well will then be circulated with seawater, and will be freeze protected with diesel to 2,200'. A BPV will be set in the tubing hanger, and the Pad will be prepared to accept Nabors 2ES. Please let me know if you need additional information. Best Regards, Mehrdad Nadem Operations drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 22, 2008 12:43 PM To; Hobbs, Greg S (ANC) Subject: M-19A (192-137) Plugging Greg, Please forward to Joshua, I don't have his eddress. I am reviewing the sundry for the abandonment of the present interval in M-19A. There is no statement regarding the reason for the work or regarding the reserves accessed by the present completed interval. Would you please have someone prepare and forward such adiscussion/statement? Such adiscussion/statement should be included with any work request regarding plugging/abandonment for redrill. Call or message with any questions. Tom Maunder, PE AOGCC 9/23/2008 FYI: M-19A Test Forms _ Subject: FYI: M-19A Test Forms Date: Wed, 21 May 2003 19:02:21 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> To: "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us> CC: "Cooper, Katrina N" <CooperKN@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Rossberg, R Steven" <RossbeRS~BP.com>, ,, · . ,, < ' . /x g,g-'- AOGCC hm Regg (E-mall) Jim Regg~adm~n. state.ak.us , (Dc'. ~)~'"AOGCC Bob Fleckenstein (E-mail-~" <Bob Fleckenstein@admin.state.ak.us>, 6\~ "Engel, Harry R" <EngelHR@BP.com> - Hi Winton. Tubing integrity has been restored to well M-19 and we are planning to return the well to production. It was classified as a "137B3" well and has remained SI. A POGLM has been reset and GLV's replaced, resulting in a passing TIFL, indicating competent tubing. Recent events: 02/24/03: POGLM set across GLM #6 03/14/03: TIFL failed 03/31/03: Set TTP 04/14/03: CMIT T x IA to 3000 psi - PASS. LLR IA to tbg at 2 BPM @ 600 psi 04/17/03: MITT to 3000 psi - PASS 04/28/03: Pulled GLV#4 accidentally RIH, pulled TTP, set GLV#4 05/09/03: TIFL PASS 05/11/03: MITOA to 3000 psi - PASS Plans are to return the well to production and monitor WHP's for any indication of a problem. Test forms for the TIFL and MITOA are attached. Please call if you have any questions. Joe Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com <<M-19 TIFL 05-09-03.xls>> <<M-19 MITOA 05-11-03.xls>> DM-19 TIFL 05-09-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) I I-)M-19 MITOA 05-11-03.xls Name: M-19 MITOA 05-11-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) ] Encoding' base64 l ofl ~6~~.~;' 30L 3 20 3 6/18/2003 9:45 AM ANNULAR COMMUNICATION TESTI ~ TUBING INTEGRITY FLUID LEVEL SURVEY Well: M-19 DATE: 05/09/03 TESTED BY: AARON B TIFL: PASS Well Status: FLOWING TBG: 280 Control: N/A INITIAL PRESSURE DATA GAS LIFTED: IA: 1380 OA: 100 Balance: NIA YES ORIFICE DEPTH: INITIAL FLUID LEVEL: 8527' BLED FROM 1380 POST BLEED PRESSURES: WELL BACK TO PRODUCTION: psi To TIFL SUMMARY LIVE GLV'S AT: POST BLEED FLUID LEVEL: 8527' 240 psi in 3 HRS and MINS TBG: 1580 IA: 240 OA: 0 NO FLUID LEVEL DATA TIME TBG IA OA FLUID LEVEL COMMENTS 10:30 1350 1380 100 8527' Started bleed. 11:30 SI 900 50 8527' 12:30 SI 520 0 8527' 1:30 SI 240 0 8527' SI monitored for 1 hr. 2:30 1580 250 0 8527' OBSERVATIONS I COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: ~_~i~ FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 05/11/03 John Cubbon P.T.D.I1921370 Type test Notes: MITOA Passed to 3000 psi. WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj, P.T.D.I Notes: WellI Type Inj, P.T.D.I Notes: Packer Depths (ff.) MD/'I'VDI NA INA Test psiI 30001 Pretest Initial 15 Min. 30 Min. IAI 2001 2001 2001 2001 IntervaI O OAI 401 30001 30001 30001 P/FI P Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 M-19 MITOA 05-11-03.xls PERMIT DATA ......... 'AOGCC Individual Well G .... ogicai Materials inventor~ T DATA_PLUS Page- 1 Date' 01./04/95 RUN DATE_RECVD 92-137 5565 92-137 SURVEY T 8812-10580 DLL/MLL/AC/GR R 8830-10543 92-137 DWOP 92-137 407 92-137 SSTVD R 01/07-01/22/93 R COMP DATE:01/30/93 L 8812-10580 92-137 PROD/LEAK DET. 92-137 PROD L SURFACE-88100 L 9800-10200 92-137 PFC L 9880-10360 92-137 PFC L 9900-10450 92-137 GR/CCL/JEWELRY L 8400-10531 92-137 DLL/ML/GR L 8812-10580 92-137 CL L 8950-9120 92-137 BHP L 8812-10580 92-137 BHC L 9780-10555 03/30/93 03/31/93 03/31/93 03/31/93 02/01/93 07/06/93 03/15/93 06/07/93 02/18/93 02/18/93 02/01/93 01/26/93 02/01/93 02/01/93 yes.And received? Are dry ditch samples required? Was the well cored? yes n~~)Analysis & description received? Are well tests required? yes ~ Received? yes~ W e il is in compliance~~ni~a1 yes ~ STATE OF ALASKA ALAS- 'OILAND GAS CONSERVATION COMMISSI(' REPORT SUNDRY WELL OPEIqATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 3560'SNL, 4695' WEL, SEC. 06, T11N, R13E, UPM At top of productive interval 901' NSL, 2581' WEL, SEC. 36, T12N, R12E, UPM At effective depth 4137' NSL, 2548' WEL, SEC. 36, T12N, R12E, UPM At total depth 1161'NSL, 2532' WEL, SEC. 36, T12N, R12E, UPM ORIGINAL 6. Datum elevation (DF or KB) KBE=52.5 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-19A (24-36-12-12) PBU 9. Permit number/approval number 92-137 / 10. APl number 50- 029-20897-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 10595 feet BKB 9229 feet Effective depth: measured 10551 feet truevertical BKB 9190 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c.y. concrete 145 Surface 2557 13 3/8 3720 c.f. Permafrost II 2592 Intermediate 8788 9 5/8 1190/575 c.f. "G'YPerm. 8823 Production -- Liner 1935 7 421 c.f. C/ass "G" 8655-10590 Perforation depth: measured 9992'- 10106' 10116'- 10138' True vertical depth BKB 145 2592 7698 7572-9224 true vertical subsea 8688'-8790' 8799'-8818' Tubing (size, grade, and measured depth) 5 1/2"x 4 1/2" @8850' Packers and SSSV (type and measured depth) 9 5/8"Baker SAB packer at 8714'; 5 1/2" SSSV at 2204 RECEIVEB JL.I[,i 1 4 199/! 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1450 ~ 1887 1257 1165 2540 4174 2906 1627 243 263 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 fore.qoing Form 10-404'Rev 06/15/88 is true and correct to the best of my knowledge. ~~~ Title Senior Technical Assistant I Date ~///~//~/ SUBMIT IN DI~PLliSATE :ssjon 5128/93 WELL M-19A(24-36-12-12) REPERF/FRAC The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10000' - 10006' MD 10006' - 10012' MD 10012'- 10018' MD 10018' - 10024' MD 6/03/93 Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: DATA FRAC: 140 239 FRAC: 76 32 5 8 11 14 16 18 65 101 76 239 460 BBLS 20# GEL 30 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK G EL PAD BBLS 20# GEL DATA FRAC FLUSH 30 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD Di~y 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 20/40 8 PPG 16/20 10 PPG 20~ LINEAR GEL FLUSH fjh 6/10/94 JIJN 1 4 & G~$ Coris. (~ot~tnlission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/09/93 T# 84652 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. D-il E-17~0 G-19~ H-25 3- GAS LIFT SURVEY 05/19/93 #1 PROD-F 05/13/93 #1 PROD-F 06/02/93 91 PROD-F 05/31/93 #1 PDK-100 06/02/93 91 LEAK DET 05/31/93 ~1 2870.00- 9650.00 ATLAS 2/5" 10800.00-11184.00 ATLAS 5 " 11200.00-11490.00 ATLAS 5 " 11200.00-11537.00 ATLAS 5 " 9940.00-10726.00 ATLAS 5 " 0.00- 8810.00 ATLAS 2 " Information Control Well Records RECEIVED JUL 0 6 Naska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/03/93 T# 84630 BPX/PBU~GS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B-34 -~S PDK-100 C-37~ _ PFC D-2~'~ SP INNER/TEMP G-16~[~z'~ SP INNER/TEMP H-0 6 ~'~'~)~, PROD-F MM-~BB7~'~ ssm - PFC M-19Ag~57PFC U-04 TUBING CUTTER 05/31/93 #1 05/27/93 #1 05/27/93 #1 05/26/93 #1 05/30/93 #1 05/29/93 %1 05/29/93 ~1 05/28/93 #1 05/29/93 #1 11500 00-12058.00 ATLAS 5 " 8800 00- 8900.00 ATLAS 5 " 1000 00- 9635.00 ATLAS 1 " 9750 00-10050.00 ATLAS 5 " 9350 00- 9740.00 ATLAS 5 " 7560 00- 9611.00 ATLAS 5 " 9000 00- 9400.00 ATLAS 5 " 9880.00-10360.00 ATLAS 5 " 10800.00-10910.00 ATLAS 5 " Information Control Well Records ALASK~ OIL AND GAS CONSERVATION C,..,,vlMISSIO WELL COMPLETION OR RECOMP LETION REPORT ,LOG OIL E'I GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permil Number BP Exploration 92-137 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20897-01 4. Location ol well at surface 9. Unit or Lease Name 3560'NSL, 4695'WEL, SEC. 6, T11N, R13E ! .': ~.! .i ii~:i~.'~ ~' ' '~-~:~.~--f Prudhoe Bay Unit · i 'V~{,j,, i lO. WellNumber 901.'NSL, 2581'WEL, SEC. 36, T12N, R12E :! //~/'~ ~;. .~.~ M-19A (24-36-12-12) : ':":~:;!:! i~ ): t¢J. ~'--~. 11. Field and Pool At Total Depth ~. /~f~ ' .... ' .............. '" Prudhoe Bay Field/Prudhoe Bay Pool 1161' NSL, 2532' WEL, SEC. 36, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. KBE = 52.5' ADL 28257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore J16. No. of Completions 1/12/93 1/15/93 1/30/93J N/Aeet MSLI One ,17. Total Depth (MD+TVD) 18. Plug Back Deplh (MD+TVD) 19. Directional Survey ~0. Depth where SSSV set ~21. Thickness of Permafrost 10595' MD/9229' TVD 10551' MD/9190' TVD YF_S E~ NO []~ 2204feet MD' ! 1870' (Approx.) 22. Type Electric or Other Logs Run DLL/MLL/BHOS/GR 23. CASING, LINER AND CEMENTING RECORD SE-Cf'lNG DEPTH MD . CASING SIZE WT. PER FT. GRADE TOP Bo'r-rOM HOLE SIZE CEMENTING RECORD AMOLt4T PULLED 20" x 30' Insulated conductor Surface 110' 36" 8 cu yds concrete 13-3/8' 72# L-80 Surface 2592' 17-1/2" 3720 cuft Permafrost II 9-5/8' 47# L-80 Surface 8823' 12-1/4" 1190 cu ft Class "G"/575 cu f Permafrost 7' 29# L-80 8655' 10590' 8-1/2" 421 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, Size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 4 s~p,~ MD, ,,~, 5-1/2" x 4-1/2" 8850' 8714' 9992'-10106' 868858790' 10116'-10138' 879958818, 26. ACID, FRACTURE, CEMENT SQUFF'7~. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 2/1/93 . I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKES[ZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. !24-HOUR RATE 28. CORE DATA Briel description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. .... Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30, GEOLOGIC MARKER.. ORMATION TESTS NAME Include inlerval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. Subsea Sag River 9847' 8496' Shublik 9893' 8537' Sadlerochit 9992' 8625' .... ~ .~, 31. LIST OF ATTACHMENTS 32. I hereby certify that the ioregoin9 is true and correct to the best o! my knowledge Signed , //~ Tit le Drilling Engineer Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. -- Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATION/ PAGE: 1 WELL: M-19A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/06/93 11:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 01/07/93 ( 1) TD: 9537 PB: 0 01/08/93 (2) TD: 9085 PB: 9085 01/09/93 TD: 9085 PB: 9085 .(3) 01/10/93 ( 4) TD: 8878 PB: 9085 01/11/93 ( 5) TD: 8878 PB: 9085 POOH. L/D TBG. MW: 8.5 Seawater MOVE RIG TO M-19A F/ PT MC. SPOT OVER WELL. RIG ACCEPTED @ 11:00 HRS, 1/6/93. PULL BPV. CIRC OUT F/P THRU CHOKE. N/D TREE. N/U BOPE. TEST BOPE. PULL TBG FREE. CBU. L/D TBG HGR. POOH W/ 5-1/2" TBG. RIH. MW: 8.5 Seawater POOH. L/D TBG. R/U ATLAS. RIH W/ GR/JB TO 9150' RIH W/ HOWCO BP. SET @ 9085' R/D ATLAS. RIH W/ SERVCO 'K' SECTION MILL. MILLING SECTION OF 9-5/8" CSG MW: 9.8 WBM RIH W/SECTION MILL, PU 5" DP, TAG BRIDGE PLUG @ 9085', DISPLACE WELL OVER TO 9.8PPG MILLING FLUID, COND MUD FOR SECTION MILL, SPOT 20 BBL BARITE PILL ON TOP OF BRIDGE PLUG, POH, L/D 10 JTS DP, SPOT SECTION MILL @ 8823', ESTABLISH INITIAL CUT IN 9-5/8" CSG @ 8823', MILLING SECTION OF CSG F/8823'-8830' POH W/SECTION MILL MW: 9.7 WBM MILL SECTION 9-5/8" CSG F/8830'-8857', FLOW LINE PLUGGED OFF, JET FLOW LINE CLEAN, MIX & PUMP HI-VIS SWEEP TO CLEAN HOLE, MILL F/8857'-8869', FLOW LINE PLUGGED OFF, JET FLOW LINE, REMOVE SECTION OF FLOW LINE, CLEAN OUT, INSTALL NEW SECTION FLOW LINE, JET FLOW LINE, OK, MILL SECTION OF CSG F/8869'-8878', ROP SLOWED DOWN TO 2'/HR, TOTAL SECTION MILLED 55', JET FLOW LINE, CIRC HI-VIS SWEEP,POH W/SECTION MILL, 1ST 3 STDS OFF BTTM PULLED TIGHT, NORMAL DRAG, POH TO LAY KICK OFF CMT PLUG TESTING BOP'S MW: 9.7 KC1 POH, L/D BHA #1, LUBE/SERV RIG EQUIP, CUT /SLIP DRLG LINE, RIH W/5" MULE SHOE TO 8978', P/U 28 JTS 5", CBU & REV CIRC ACROSS 9-5/8" MILLED SECTION, PUMP KICKOFF PLUG W/31 BBLS CLASS "G" CMT, TOP OF CMT EST @ 8581', POH 12 STDS, PUMP DP WIPER PLUG, PERFORM HESITATION SQUEEZE TO 2000 PSI, POH, L/D 45 JTS 5" 19.5# DP, PULL WEAR RING, REPLACE/TEST PACKOFF TO 5000 PSI, CLEAN BOP'S & FLOW LINE, TEST BOPE, STATE MAN ON LOCATION WELL : M-19A OPERATION: RIG : DOYON 16 PAGE: 2 01/12/93 (6) TD: 8916' (8916) 01/13/93 ( 7) TD: 9448' ( 532) 01/14/93 ( 8) TD: 9739' ( 291) 01/15/93 ( 9) TD:10197' ( 458) 01/16/93 (10) TD: 10595' ( 398) 01/17/93 (11) TD:10595' ( 0) 01/18/93 (12) TD:10595 PB:10551 01/19/93 (13) TD:10595 PB:10551 DRILLING @ 8916' MW: 9.8 VIS: 54 TEST BOPE. RIH W/ BHA #2 (K/O ASS'Y). WASH F/ 8470'-8678' TAG CMT. DRLG CMT F/ 8678'-8828' KICKOFF F/ 8828'-89i6'. DRILLING 8-1/2" HOLE MW: 9.7 VIS: 57 DRILL 8-1/2" HOLE F/8916'-9338', CIRC HI-LO VIS SWEEP, SHORT TRIP 6 STDS BACK INTO 9-5/8" TOP STUB, HOLE DRAG 75000~ ABOVE NORMAL P/U, RIH W/STD #6, REPEAT P/U THRU TOP STUB @ 8823', DRAG REDUCED, RIH TO 9338', HOLE COND. GOOD, DRILL 8-1/2" HOLE F/9338'-9448' REPAIR FILTER POD. MW: 9.7 VIS: 57 DRILL 8-1/2" HOLE F/9448'-9739', CIRC H I-LO VIS SWEEP, DROP SURVEY, POH W/BHA # RIH W/BHA #3 TO 8784', BREAK CIRC, CIRC PLUGGED NOZZLE IN BIT #3, CLEARED NOZZLE, REPAIR WELD FILTER POD TO SUCTION MANIFOLD DRILLING 8-1/2" PROD HOLE MW: 9.8 VIS: 66 RIH & BREAK CIRC EVERY 2 STDS IN OPEN HOLE TO 9660', P/U KELLY, WASH/REAM TO BOTM @ 9739', DRILL F/9739'-9888', CBU, PUMP HI-LO VIS SWEEP, TRIP TO 9-5/8" SHOE @ 8823' FOR HOLE COND~ PRIOR TO DRLG SAD. SECTION, PULL 12 STDS TO 9-5/8" SHOE, RIH DRILL 9888'-10197' R/U ATLAS W/L FOR OH LOGGING MW: 9.8 VIS: 58 DRILL F/10197' TO 10595', CIRC 5" DP X OH ANNULUS, SHORT TRIP 20 STDS, CIRC HI-LO VIS SWEEP W/PIPE ROTATION, DROP MULTI SHOT, POH FOR OH LOGGING DP STRAPPED RIH W/ 7" LINER MW: 9.9 VIS: 67 R/U ATLAS W/L, OPEN HOLE LOG 8-1/2" PROD. W/DLL/MLL/BHCS/GR, P/U BHA, RIH W/8~1/2" WIPER TRIP, SLIP & CUT DRLG LINE, RIH TO 10550', WASH & REAM F/10500'-10595', POH, DROP DP DRIFT, R/U TORQUE TURN, RIH W/ 7" 13CR80 LINER POLISH LINER TOP, CBU MW: 9.7 KC1 RIH W/7" LINER, CIRC DP & LINER VOL., CMT W/ 75 BBLS CLASS "G". RIH W/8-1/2" BIT TO LINER TOP, TEST LINER LAP, POH, L/D HWDP & DC'S, M/U POLISH MILL, RIH, WORK MILL THRU LINER TOP F/8639'-8646', CBU POH, L/D DP MW: 9.7 KC1 POH, L/D POLISH MILL, M/U SEAL ASSEMB, RIH, SLIP & CUT DRLG LINE, RIH TO TOP OF LINER TIE-BACK @ 8639', SET LINER HGR & TOP PKR, TEST, POH, M/U BIT & SCRAPER, RIH, TAG CMT @ 10532', DRLG PLUGS & CMT TO 10551', PBTD, CBU, TEST 7"X9'5/8" TO 3500 PSI, DISPLACE WELL OVER TO FILTERED SEAWATER, ADD INHIBITOR, TEST LINER LAP,POH, L/D DP TO RUN TBG WELL : M-19A OPERATION: RIG : DOYON 16 PAGE: 3 01/20/93 (14) TD:10595 PB:10551 01/21/93 (15) TD:10595 PB:10551 LAND TBG MW: 9.7 KC1 POH, L/D DP, PULL WEAR RING, R/U TORQUE TURN TO RUN CHROME TBG, RIH W/4-1/2" TAILPIPE, 7" PKR, 5-1/2" CR TBG W/6-GLM'S, M/U TBG HGR, TEST, LAND TBG RELEASED RIG @ 15:30 MW: 9.7 KC1 RILDS, SET 7" PKR, PRESSURE UP ON ANNULUS, SET TWC, N/D BOPE, N/U TREE, SECURE WELL, RELEASE RIG @ 15:30 HRS 01/22/93 (16) TD:10595 PB:10551 MW: 9.7 KC1 SIGNATURE: (drilling superintendent) DATE: . ,¢ SF"~'~RY-SUN DRTLLTNG SERV'rCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DR'[LLTNG PBU/M-19A 500292089701 NORTH SLOPE COMPUTATTON DATE: 3/24 /9 ORIGINAL 3 DATE OF SURVEY: 011693 ELECTRONZC MULT].-SHOT SURVEY dOB NUMBER: AK-EZ-30004 KELLY BUSH].NG ELEV. = 52.25 OPERATOR: BP EXPLORATZON FT. TRUE SUB-SEA MEASD VERT].CAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL [NCLN D[RECT[ON RECTANGULAR COORD[NATES DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8830 7704,00 7651.75 8920 7773.71 7721.46 9013 7846.36 7794.11 9106 7921.59 7869.34 9198 7997,12 7944.87 40 47 N 44.60 W .00 2049.00N 2679.00W 39 0 N 37.30 W 5.51 2092.90N 2717.18W 37 28 N 38,00 W 1,73 2138.22N 2752.15W 35 30 N 25.67 W 8.11 2185.15N 2781.45W 34 27 N 15,48 W 6.44 2234.43N 2800,01W 3333.42 3391.53 3448.45 3502.59 3551.00 9290 8073.45 8021.20 9382 8151.81 8099.56 9475 8232.85 8180.60 9568 8314.52 8262,27 9661 8396.04 8343.79 32 39 N 9.08 W 4.33 2283.83N 2810.83W 30 8 N 3.66 W 4.12 2331.32N 2816.21W 29 5 N ,19 E 2,33 2377,35N 2817.64W 28 6 N 5,03 E 2,71 2421.78N 2815,64W 29 2 N 9,07 E 2,32 2465,81N 2810.17W 3594.12 3632.11 3666.30 3696.97 3724.94 9755 8478.13 8425. 9847 8559.06 8506. 9940 8641.18 8588. 10031 8722.47 8670. 10127 8808.45 8756. 88 29 27 N 11.14 E 1.16 2511.07N 2802.10W 81 27 51 N 9.86 E 1.86 2554.56N 2794.02W 93 27 5 N 9.42 E .85 2596.65N 2786.87W 22 26 26 N 9.26 E ,72 2637,12N 2780,21W 20 26 21 N 9,35 E .09 2679.24N 2773.31W 3752,OO 3777.78 3803.19 3827,77 3853.37 10221 8892.87 8840. 10314 8976.37 8924. 10406 9059.65 9007. 10501 9144,54 9092. 10543 9182.47 9130. 62 26 8 N 9.31 E .23 2720,32N 2766.56W 12 25 58 N 9.10 E .20 2760,63N 2760.03W 40 25 43 N 9.26 E ,28 2800,46N 2753.59W 29 25 28 N 9,21 E ,26 2840.62N 2747.06W 22 25 24 N 9.18 E ,18 2858.43N 2744,18W 3878.34 3902.89 3927.17 3951.62 3962,47 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZMUM CURVATURE METHOD. HORZZONTAL DzSpLACEMENT = 3962.47 FEET AT NORTH 43 DEG. 49 HZN. WEST AT ND = 10543 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 316.17 DEG. Date ID. /,//t u(.,, ~,,. O01'fll'fljgSJOi' SP..'~"~--RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/M-19A 500292089701 NORTH SLOPE COMPUTATION DATE: 3/24/93 DATE OF SURVEY: 011693 JOB NUMBER: AK-EZ-30004 KELLY BUSHING ELEV, : 52,25 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 8830 7704,00 7651,75 2049,00 N 2679,00 W 1126,00 9830 8543,43 8491,18 2546,42 N 2795,44 W 1286.57 10543 9182,47 9130,22 2858.43 N 2744,18 W 1360,57 160.57 74.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, S~.RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/H-19A 500292089701 NORTH SLOPE COMPUTATION DATE: 3/24/93 DATE OF SURVEY: 011693 JOB NUMBER: AK-EI-30004 KELLY BUSHING ELEV. = 52.25 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8830 7704.00 7651.75 2049.00 N 2679.00 8893 7752.25 7700.00 2079.17 N 2706.25 9020 7852.25 7800,00 2141,81 N 2754,82 9144 7952,25 7900,00 2205,00 N 2790,09 1126.00 1140.85 14,85 1168.48 27.62 1192.07 23.59 9265 8052.25 8000.00 2270.32 N 2808.42 W 1212.97 20.90 9382 8152,25 8100,00 2331.56 N 2816.21 W 1230.53 17.56 9497 8252.25 8200,00 2388,14 N 2817.60 W 1245.46 14.93 9611 8352.25 8300.00 2441,87 N 2813,84 W 1259.06 13.60 9725 8452.25 8400,00 2496,73 N 2804.92 W 1273.47 14.41 9839 8552.25 8500.00 2551.01 N 2794.64 W 1287.73 14.26 9952 8652.25 8600,00 2602,24 N 2785,94 W 1300.43 12,70 10064 8752.25 8700,00 2651,73 N 2777.83 W 1312,30 11.87 10176 8852,25 8800.00 2700.63 N 2769.79 W 1323,91 11.61 10287 8952.25 8900.00 2749.02 N 2761.89 W 1335.28 11.37 10398 9052.25 9000.00 2796.95 N 2754.17 W 1346.44 11.16 10509 9152.25 9100.00 2844.25 N 2746.48 W 1357.33 10.89 10530 9170,69 9118.44 2852,91 N 2745,07 W 1359.31 1.98 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN. THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/24/93 T# 84405 BP/PBU OH MAGNETIC TAPE Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) M-19A OH/DLL FIN 01/16/93 #1 8812.00-10580.00 1600BPI API#500292089701 9298->TP# If you have any 564-4004. ATLAS REF#5863 Information Control Well Records RECEIVED MAR 5 0 199~ Alaska 011 & (3as Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03-11-93 T# 84395 BPX CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-19A 9~'1~7 ~u S-3R6~'t~-~.CH 03/05/93 REF#124762 03/03/93 REF#124805 03/04/93 REF#124806 03/04/93 REF#124761 PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS PRODUCTION LOGGING SERV ATLAS Information Services Well Records RECEIVED MAR 1 5 1993 Alaska 011 & Gas Cons. Commlgslon Anchorage BP EXPLORATION : . · BP Exploration (Alaska) Inc. .... ! 900 East Benson Boulevard · P.O. Box 196612 Anchorage, Alaska 99519-6612 · (907) 561-5111 -. DATE: 02/09/93 T# 84295 -' BP/PBU ~ CH LOGS --. : : -. EncloSed is your copy of the materials listed below. If you have any questions,~'"~ploase contact BP Well Records at (907) 564-4004. /-~32~~~ PRODUCTION LOG 01/31/93 #1 . -....~M- 19A ~'.~ ~ PFC 01/30/93 #1 ~.~M-19A ~ CCL 01/29/93 #1 ~.~- 36~% PFC 02/04/93 #1 10100.00-10744.00 ATLAS 5 " 9900.00-10450.00 ATLAS 5 " 8400.00-10531.00 ATLAS 5 " 9380.00-10200.00 ATLAS 5 " 8850.00- 9675.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/22/93 T# 84276 BP CH LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at (907) ~ PDK-100 01/13/93 #1 ~f9A'~~BHC 01/16/93 #1 -'~~~w-W,_~ga~m~ BOREHOLE PROFILE 01/16/93 #1 -J~--~9A_,,%/_ ,4 Q DLL~/~~ _ 01/16/93 #1 Information Control Well Records below. If you have any 564-4004. 9806.00- 8950.00 ATLAS 5 " 9780.00-10555.00 ATLAS 5 " 8812.00-10580.00 ATLAS 5 " 8812.00-10580.00 ATLAS 2/5" BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/22/93 T# 84278 BP OH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. vDCTION LOG 01/13/93 #1 9260.00- 9773.00 ATLAS 01/13/93 #1 01/16/93 #1 9560.00- 9740.00 ATLAS 8812.00-10580.00 ATLAS Information Control Well Records 1/2" · MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Griffin~[''' Commissioner thru: Blair E Wondzell Sr Petr Engineer from: ~'~U Grimaldi Petr Inspector date: January 27, 1993 file: LOUO1111.DOC subject: BOP T~ BPX We]l'Mc~.9 ~ ' '~. Prudhoe Bay Unit-------' PTD 92-137' Monday, January 11, 1993: I witnessed the weekly BOP Test on Doyon Rig 16 which was side tracking BPX Well M-19 in the Prudhoe Bay Unit. A thorough BOP Test was conducted and all equipment I observed functioned correctly and held its respective pressure test. Jim Willingham (Doyon toolpusher) conducted a good BOP Test. The area surrounding the rig was clean with good access provided. SUMMARY: I witnessed a good BOP Test on Doyon Rig 16 on BPX Well M-19: test time 2 hours - 0 failures. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg Y Operator ~g/ Wkvr TEST: Initial Rep /~//~1~ C~)<~)~/ Permit # 9~-~ Rig# Well Drlg contrctr Well sign R i g t._~ OrS~ csg set @ ft Location (general) C~.~Aj Housekeeping (general Visual Audio Rsrve pi t ~/4 MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Test Pressure BOPE STACK: Annular preventer .OH OK~ %'0o oo ~ o ~oo o Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Weekly ~ Other Rig phone # ~/~/tD Location: See ~ T ~[2~ R/L~'M C,)/~ Rep ~ ~/~1~ ~ ACCUHULATOR SYSTEH: Full charge pressure ~,~.,)(~]~ / Pump incr clos press 200 psig Full charge press a~tained ~ Controls: Nas~e~ ~( psig psig min ~/~> sec rain / ~ sec psig ~0 yO ~) KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges Test pressure Test pressure Test pressure Test pressure Test pressure Adjustable chokes Hydraulically operated choke TEST RESULTS: Failures Test time ~ hrs Repair or replacement of failed equipment to be made within '-~ days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. .~, · Remarks: 0(~ ! ~c.q~ / ,. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) STATE WITNESS REQUIRED? yes/ no 24-HR NOT I~GIVEN? yes/- no Waived by: Witnessed b AOGCC phone 279-1433 - FAX 276-7542 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 // DATE: 01-15-93 T9 84251 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-17 ~0'1%~ INJ 01/06/93 #1 lA-24~Z,~O CNL 01/03/93 91 A-24 GR 01/05/93 91 D-04A~?'I~PRODUCTION LOG 01/07/93 91 D-05 ~o-~ PRODUCTION LOG 01/07/93 91 D-26 ~-I~. PRODUCTION LOG 01/05/93 #1 F-02 ?e-~ PRODUCTION LOG 01/07/93 #1 F-10 %~'~7 PRODUCTION LOG 01/09/93 91 F-13~e'~_~ PRODUCTION LOG 01/08/93 #1 X-04 ~-~ PRODUCTION LOG 01/09/93 #1 X-14A~-1~3CL 01/09/93 #1 X-27~-~ PRODUCTION LOG 01/08/93 #1 9700.00-10750.00 ATLAS 5 " 10600.00-11355.00 ATLAS 5 " 10800.00-11350.00 ATLAS 5 " 10200.00-10700.00 ATLAS 5 " 10400.00-10729.00 ATLAS 5 " 9700.00-10925.00 ATLAS 5 " 10100.00-10600.00 ATLAS 5 " 9650.00- 9970.00 ATLAS 5 " 8960.00- 9198.00 ATLAS 5 " 8950.00- 9120.00 ATLAS 5 " 9250.00- 9850.00 ATLAS 5 " 9990.00-10230.00 ATLAS 5 " 11300.00-11600.00 ATLAS 5 " Information Control Well Records ' CEIVED JAN 2 6 199; Alaska Oil & Gss Cons, Commiss[o~ Anchorage · ALASKA OIL AND GAS /' CONSERVATION COMMISSION / WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 18, 1992 Bill Kirton Drilling Manager BP Exploration, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-19A BP Exploration, Inc. Permit No. 92-137 Sur. Loc. 3560'NSL, 4695'WEL, Sec. 6, TllN, R13E, UM Btmnhole Loc. l193'NSL, 2651'WEL, Sec. 36, T12N, R12E, UM Dear Mr. Kirton: 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. David W. ~ston~ __~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill EIIlb. Type of well. Exploratory l-] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 62.8feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. AnchoracTe. Alaska 99519-6612 ADL 28257 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~,e aD ^^c as.ms) 3560'NSL, 4695' WEL, SEC. 6, T11N, R13E Prudhoe Bay Unit At top of productive interval :8. Well number Number 953'NSL, 2600' WEL, SEC. 36, T12N, R12E M-19A (24-36-12-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 1193' NSL, 2651' WEL, SEC. 36, T12N, R12E 1/4/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28260-1193' fe et No close approach f eat ! 2560 10597' MD/9212' TVI~ e e t 16. To be completed for deviated wells 17. Anticipated pressure (s. 20 Mc 25.035 (e)(2)) Kickoff depth ae3ofeet Maximum hole angle4o.??o Maximum surface 3330psig At total depth (TVD) ~)~)'/~Opslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# ~3c~,~.eoNSCC 3102' 7495' 6737' 10597' 9212' 472 cu fl Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10700feet Plugs (measured) true vertical BKB 9222feet Effective depth' measured 10472feet Junk (measured) true vertical BKB 9027feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 8 cu yds concrete 145' 145 S u dace 2557' 13-3/8" 3720 cuft PF I! 2592' 2592' Intermediate 9866' 9-5/8" 1895 cu fi 9901' 8547' Production 1070' 7" 420 cuft "G" 9630;10700' 8327'-9222' _ Liner 1013' 5" 129 cuft "G" 9598;10611' 8301'-9146' Perforation depth: measured 10100;10193', 10202;10225', 10256;10280', 10448;10480' true vertical 8650;8971' SS (four intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling programrYl Drilling fluid program E'I Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] Signed~~~_ Title Drilling Engineer Supervisor / .ZT/'~,,~--~Date Commission Use Only Permit Number IAPI number IApproval da_t.e ISee cover letter 77-o / IIf°r other requirements Conditions of approval Samples required [] Yes ]~'NO Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~rec~ ,]~ Yes [] NO Required working pressure for BOPE 1-12M; []3M; J~hM; I-I10M; 1'-115M; Other: Approved by Ori~in~ Si,,gned ~¥ by order of _ _ _ .~.~,;id V',~. Johnston Commissioner me commission Form 10-401 -85 Submit in triplicate · -'ROPOSED SIDETRACK PR(,,~.~3AM MI~-A OBJECTIVE' The objective of this sidetrack is to move the bottomhole location of M-19 approximately 500 feet North-East of its current location. This will locate the well approximately 700 feet away from a conductive fault which is believed to be responsible for the well's high water production. The sidetrack will result in oil acceleration and reserves protection in the M- 13i and M-14i waterfiood patterns. Since the intent of this sidetrack is reserves protection, the expenditure will be classed as revenue expense. CURRENT STATUS: M-19 was drilled in February 1983 as a side producer in the M-13i and M-14i waterflood patterns. The well was initially perforated during May 1984, and resulted in an initial flow rate of 10,000 bpd with no measurable water production. By August 1988 the watercut had increased to 70% and the oil rate was down to 1600 bpd. No major workover operations had been performed during the first 4 years of production. During July 1988, a flow meter and pump in temperature survey indicated that 75% of the production was entering the lower Zone 4 perforations and a 135' channel extended below these perforations into Zones 2 and 3. In August 1988 the channel and Zone 4 perforations were squeezed using a coil tubing unit. The first set of reperforations ( 10256-10280 ) were shot at the base of Zone 4 with a density of 1 spf. These perforations were tested at a 60% watercut, indicating water influx into the base of Zone 4. The remainder of Zone 4 was shot with a density of 4 spf. The well returned to production at 2700 bopd and a watercut of 20%. By August 1989 the watercut had increased to 45% with an oil rate of 1900 bpd. The decrease in oil rate was attributed to scale build up. In September 1989 a 15% HCL acid wash was performed. The initial post treatment well test indicated that the gross fluid rate had increased by 50%. However, subsequent tests indicated that gross fluid rate was unchanged and that the watercut had increased to above 50%. In May 1990 a kinley survey of the liner indicated large holes at approximately 10284' md. A rig workover (RWO) was performed in June 1990. The major objective of the workover was to run a 5" scab liner to cover holes in the existing 7" liner and Provide access to a Zone 2 oil lens. Steel tubulars were used because it was believed that the holes were caused by erosion rather than corrosion, chrome tubulars were not readily available, and the marginal economics of the workover could not justify the additional cost. The post RWO well tests indicate that the oil rate was approximately 1400 bpd with 48% watercut. Since the post RWO oil rate was lower than the pre-RWO oil rate it was believed that the formation adjacent the perforations had been damaged. In May 1991 a selective perforation acid wash was performed. Subsequent well tests indicate that the acid wash increased the gross fluid rate by 100 - 200 bpd at a 55-60% watercut. A PNL PROPOSED ~;IDETRAC:K PR~RAM MlC,:j-A CURRENT STATUS CONT'D- borax log run in August 1991, indicates a channel above the zone 2 perforations. A kinley survey, also run in August, identified up to 56% corrosion in the tubing. By July 1992 the watercut had risen to 75-80% with an oil rate of approximately 900 bpd. During July a kinley survey of the liner and tubing indicates up to 82% corrosion in the tubing and up to 61% in the liner. In August 1992 a sand/cement plug was set across the lower zone 4 perforations. The major objective of the plug was to determine if Iow watercut oil could be produced from the top of Zone 4, and if so, establish if further expenditure on the well could be justified. Post plug back well tests indicate that the cement plug did cut the well productivity but a stable well test was difficult to obtain. Flow rates from the most stable well tests and data from fluid sample analysis indicate that upper Zone 4 is producing with a watercut in excess of 70%. Also, a hole in the tubing/ gas lift mandrel #1 has been diagnosed. The well is currently believed to be producing 700 bopd at a 74% watercut. PERMITTING' The attached sundry notice covers the plugback of the odginal well and the drilling permit covers the proposed drilling program. HROPOSED SIDETRACK M19-A PRO~RAM la . 3. 4o 5. o . ! 11. 12. 13. 14. 15. 16. 17. 18o 19, 20. M19-A SUMMARY PROCEDURE Pre-dg work: Kill well. Lay cement plug across pedorations to at least 100' above top perforation. Cut 5-1/2" tubing at 9500' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU 11" 5M x 13-5/8" 5M DSA and BOP's. Test BOP's to 5000 psi. Pull two-way check valve. Pull and lay down [;-1/2" tubing. RIH w/9-5/8" bridge plug and set at ~085' MD. Spot an 18 ppg pill on bottom. R.IH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 8825' MD. RIH with open-ended DP. Mix and pump 150 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. Replace intermediate packoff if necessary. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" packed hole assembly to total depth of 10597' MD / 9212' TVD or 150' MD below the OOWC at -8795' SS TVD. RU wireline and log with the DLL / Microlog / GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 26# 13CR FOX x 7" 26# L80 NSCC standard liner assembly to TD with liner top packer/hanger and tie-back extension w/+/- 150' lap. Crossover from 13CR to L-80 at 9582'MD. Cement liner with 400 sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RIH with 5-1/2" 17# NSCC 13CR-80 completion string w/9-5/8" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at 9682' MD based on 200' above TOP OF SAG RIVER. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 7-1/16" 5M CIW tree to 5000 psi with-diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. RU wireline and perforate. Anticipated BHP: 7.8 ppg equiv Drilling Fluid: 9.5 ppg Workover Fluid: 8.5 ppg. PRELIMINARY WELL PLAN WELL' M19-A Redrill PBU APl NQ.: 50-029-20897-00 (on the original M19 well) LOCATION: Surface: 1719' SNL, 195' EWL, Sec. 6, TllN, R13E Target: 4325' FNL, 3026' FEL, Sec. 36, T12N, R12E @ 8723' ssTVD BHL: 1193' FSL, 2561' FEL, Sec. 36, T12N, R12E @ 9149' ssTVD ESTIMATED ~;TART- 4 January, 1993 OPR. DAYS TO COMPLETE: 16 CONTRACTOR: Doyon Rig #16 DIRECTIONAL; Kickoff at 8830' MD. (11.09 degree angle drop and 53.76 degree east turn.) WELLBORE- Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR 11 0' 110' N/A 13-3/8" SHOE 2592' 2592' N/A KOP 7704' 8830' 9.7 TOP SAG RIVER 8591' 9882' 9.7 TOP SHUBLIK 8630' 9927' 9.7 TOP SADLEROCHIT 871 5' 1 0024' 9.7 TOTAL DEPTH 9212' 1 0597' 9.7 LOGGING PROGRAM- 8-1/2" Hole: DLL / GR / BHCS / SP NOTE: Open hole CNL sonde will not be picked up. MUD PROGRAM' The milling/drilling fluid program will consist of a 9.3 - 9.8 ppg XCD pOlymer / KCI water based mud. DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEl. GEl. ¢~;/30min (%) (%) 7704' 9.3 1 0 1 0 5 7 8 0 5 to to to to to to to to to 9212' 9.8 16 18 10 15 5 0 7 MUD TYPE Water Base Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole)' 9.7 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 3550 psi/8600' ss TVD. 3600 psi/8800' ss TVD. Overbalance Sag River: 700 psi. Overbalance Top Sadlerochit' 860 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible sudace pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH 7" 26# 13CR-80 NSCC 7" 26# L80 NSCC 9582' - 10597' MD 8675' - 9582' MD BURST COLLAPSE TENSILE 7240 psi 5410 psi 604 klbs 7240 psi 5410 psi 604 klbs CEMENT 7" LINER' CALCULATIONS: Measured Depth' Basis: Total Cement Vol: 8675'MD (Hanger)- 10597'MD (Shoe) 40% open hole excess, 40' shoe joints, 150' liner lap and 200' excess above liner with DP. 399 cu ft or 338sxs of Class G blend @ 1.1 8 Cu ft/Sk TUBING DETAILS: 5-1/2" 17# 13CR-80 NSCC (0'- 8575' MD) 4-1/2" 12.6# 13CR-80 NSCC (8575' MD - 8675' MD) DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ m m _ w _ t m Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console GR2~AT LAND D1R3~CTIONAL DRILLING, INC. Corporate Office 111! East @0th Avenum Anchorage, A/< 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PR~JDHOE BAY DRILLING Well ......... : M-19A Field ........ ~ PRUDHOE BAY M-PAD Computation..: MINIMUM CURVATURE Prepared ..... : 11/09/92 Section at...: 9.17 KB elevation.: 62.80 LEGAL DESCRIPTION Surface ...... : 3560 ?SL 4695 EEL S06 TllN R13E UM Tie-in ....... : 329 FSL 24S2 FEL S36 T12N R12E U~ Targe5 ....... : 953 ESL 2600 FEL $36 T12N R12E UM BHL .......... : 1193 FSL 2561 FEL S36 T12N R12E U~ X ASP ZONE 4 Y 629008.00 5974651.00 626295.09 5976653.60 626167.00 5977276.00 626201.64 5977516.51 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-ZN / KOP 4/100 MEAS INCLN DEPTH ANGLE 8830 40.77 8900 38.99 9000 ~6.62 9100 34.51 9200 32.72 VERT-DEPTH$ SECT BKB SUB-S DIST 7704 7641 1596 7758 7695 1623 7837 7774 1664 7918 7856 1707 8002 7939 1752 DIRECTION REL-COOPJ3INATES DL/ AZIMUTH FROM-WELLHEAD 100 -- 315.41 2049 N 2679 W <TIE 318.77 2082 N 2709 W 4.0 324.04 2!29 N 2747 W 4.0 329.89 2178 N 2779 W 4.0 336.35 2227 N 2804 W 4.0 END OF CURVE 9300 31.28 9400 30.26 9500 29.70 9600 29.62 9627 29.68 8087 8024 1798 8172 81!0 1845 8259 8196 1894 8346 828B 1943 8370 8307 1956 343.40 2277 N 2923 W 4.0 350.96 2327 N 2834 W 358.89 2376 N 2&38 W 4.0 6.98 2426 N 2836 W 9.!7 2439 N 2834 W 4.0 SAG RIVER SHUBLIK S~LEROCHIT Z4 T~GET OWC 9882 29.68 9927 29.68 10024 29.68 10106 29.68 1O189 29.68 8591 8528 2082 8630 8567 2104 8715 8652 2153 8786 8722 2193 8858 8795 2234 9.17 2563 iq 2814 W 0,0 9.!7 2585 N 2810 W 0,0 9.17 2623 N 2803 W 0.0 9.17 2673 N 2796 W 0.0 9.17 2714 N 2790 W 0.0 $A-DLEROCHI T Z3 S~-DLEROCHI T Z2 EEA%~i OIL TAR OOWC TD 10217 29.68 102BO 29.68 10396 29.68 10447 29.68 10597 29.68 8882 8819 2248 8937 8874 2279 9038 8975 2337 9082' 9019 2362 92!2 9149 2~36 9.17 2727 N 2787 W 0.0 9.17 2758 N 2782 W 0.0 9.17 28!5 N 2773 W 0.0 9.17 2840 N 2769 W 0.0 9.17 2913 N 2757 W 0.0 ~LDO (c)92 HIgA B1.F~ 10:52 AM 2) PRUDHOL BAY DRILLING A) TIE-IN / KOP 4/100 B) ENO OF COl:i'VE C) TARGET O) TD ~o N/S 8830 204g 2679 ~757 CLOSURE ' DECLINATION.' SCALE DRANN. ' PLAN VIE~ ~011 fL at Azimuth 316.57 30. O0 E :1 :~nch--500 feet ~]/09/92 2000 ~500 I 3250 3000 2750 ~-'LD: icjf~2 i~.lgA Bi.~ J.4:og Aw, 2} 2500 2250 2000 ~750 J500 ~1 , · 750 5OO 250 0 250 <- WEST' EAST -> TOTAL F'. 84 PFIUDHOE BAY DRILLZN6 Narker Identification MO BKB SECTN IN£LN A] TIE-IN / KOP 4/100 8830 7704 1596 40,77 8] END OF CURVE 9627 8370 1956 29.68 C) IARSET lOJ06 8786 2193 29.68 O) TO ~0597 9212 2430 29.68 I I I I I ; , 1800 1350 ~500 ]520 lvl- gA (P.1) VERTZCAL SECTION VZEN , Sect Jori at: 9 ~7 ~,':.' ~ --' ~:~' :~ ~ "'.:'"' '.,~-'~'~', TvD Scale · ~ inch = 300 Dep Scale.' ~ inch = 300 feet Drawn ' JJ/09/92 , ,,, , - , ..... i i , ' I 2100 2250 Section 08oarture i~, 2400 2550 . 2700 2~50 3~50 330D i. DOYON 1 6 13 5/8" 5,000 psi Stack t 10.15 4.5 5.02 F RKB I I HYDRIL ! RI~ i FLO 12.40 Variable 3.5" x 6" Pipe Ram Variable 4.5" x 7L" Pipe Ram ,R 15.40 17.60 I I , C2 1.80 '2.35 0.25 GROUND LEVEL MUD CROSS Blind Ram TBG SPOOL TBG SPOOL BASE FLG 20.70 24.85 25.10 I,,I-I~CMT.XLS State: WeE Field: State Permit ti:_ /,,¢,,- 194 PRLIDHL?E BAY 92.1,77 E n~rleeE V/ork Sheet: Date: (7.eme. nl Vo/ume E. blc~ ;lalion,¢ 1211~7t$2 Casing Type Casire Size -Inches Casing Length - Feet Hole Diameter -inches Cement- Sacks Cement-Yield Cernent - Cubic ft l:il Cement- Cubic it Cement-Sacks ~2 Cement- Yield ~2 Cement- Cubic it I:12 Cement- Cubic ft .i:I2 Cement- Sacks ~13 Cement- Yield ~3 Cement-Cubic tt:1:I3 Cement- Cubic It ~3 Cement- Cubic ft / Vol Cement- Fill Factor Casil'~j Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement-Sacks Cement-Yield Cement- Cubic it Cement- Cubic tt Cement- Sacks ~2 Cement- Yield ~2 Cement- Cubic It ~2 Cement-Cubic It Cement-Saok~ ti3 Cement- Yield ~3 Cement- Cubic itt:I3 Cement- Cubic itI:I3 Cement- Cubic tt /Vol Cement-inte[val It Top of Cement: - Feet Conducto[ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIWO! intermediate ~1 0.000 0.000 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O! ~DIV/O! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! Intermediate 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O! .~DIV/O! Line[ 7.000 3,102.000 8.500 0.000 0.000 0.000 472.O00 0.000 0.000 0.000 0.000 472.000 1.200 OK, Production 0.000 0.000 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIPlV/O! ~DIV/O! 1,4 er_,sured E)epth State: Alaska E~orough: Well: M-19A Reid: Prudhoe St. Perm ~ 92-137 Date 12/'10~92 Engr: M. Minder t.,~-I~CSG.XLS lA 2A 3A 4A 5A 6A 7A 6A 9A 10A Descriptionescriptionescription Tension Casing Interval Interval $~ze ~ottom Top Lenglh 7 9212 6737 3102 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 26 3CR/L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 lB 2B 4B 5B 6B 7B 9B 10B Mud Hydraulic Wieght Gradient ppg psi/ff 9.7 0.504 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 Maximum Minimum Pressure psi 8380 0 0 0 0 0 0 0 0 0 Yield psi BDF 724O 0 #DIV/0! 0 #DIVi0! 0 #DIVI0! 0 #DIVI0! 0 #DIVi0! 0 #DIVlO! o #DrY/O! 0 #DP,//0! 0 #DIV/0! lC 2C 3C 4c 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 80.652 0 0 0 0 0 0 0 0 0 KJLbs TDF 604 7.49 0 #DIVIO! 0 #DNIO! 0 #DlVlO! 0 #DIV/O! 0 #DIV/O! 0 #DIVIO! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi 4647 0 0 0 0 0 0 0 0 0 Resist, CDF 5410 1.164 0 #DIV/0! 0 #DNiO! 0 #DIV/O! 0 #DlVl0! 0 #DIVIO! 0 #DiV,/0! 0 #DIVIO! 0 #Drv'/0~ 0 #DP,//0! STATE OF ALASKA AL,-,_.,A OIL AND GAS CONSERVATION COMMISSi~JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x,... Suspend Operation Shutdown __ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging ~ Time extension __ SlJmulate ~ Change approved program ~ Pull tubing ~ Vadance ~ Perforate ~ Other x ~ Plugback for redrill 2. Name of Operator 5. Type of Well: BP Exploration Development x Exploratory 3. Address Stratigraphic . 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 set, ce ~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1719'SNL, 195'EWL, SEC. 06, T11N, R13E, UPM. At top of productive interval 875' NSL, 2253' EWL, SEC. 36, T12N, R12E, UPM At effective depth 1022'NSL, 2119'EWL, SEC. 36, T12N, R12E, UPM At total depth 1.110' NSL, 2039' EWL, SEC. 36, T12N, R12E, UPM 6. Datum elevation (DF or KB) KBE = 62.8 feet M-19 9. Permit number 83-8 10. APl number 50- O29-2O897 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10700 feet BKB 9222 feet 10472 feet BKB 9027 feet Plugs (measured) Junk (measured) Perf gun fish @ 10472' Casing Length Size Cemented Measured depth Structural Conductor 110' 20' 8 cu yds concrete 145' Surface 2557' 13-3/8" 3720 cuft PF Ii 2592' Intermediate 9866' 9-5/8" 1895 cuft "G" 9901' Production 1070' 7" 420 cuft "G" 9630'-10700' Liner 1013' 5" 129 cu ft Class "G" 9598'-10611' Perforation depth: measured 10100'-10193', 10202'-10225', 10256'-10280', 10448'-10480' true vertical 8650'-8971' SS (four intervals) Tubing (size, grade, and measured depth) 5-1/2" L-80 to 9580' True vertical depth 145' 2592' 8547' 9222' 8301'-9146' RECEIVED Gas Cons. C0p?.miss[c~ Packers and SSSV (type and measured depth) 9.5/8" BakerSABpacker@ 9537'; 5-1/2" SSSV@ 1992' Ancherag~ 13. Attachments Description summary of proposal x Detailed operations program x BOP sketch 14. Estimated date for commencing operation 12/12/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended~ Service 17. I hereby certify that theforecjoing is true and correct to the best of my knowledge. Signed ~-~ ://j/~~'"q/ Title Dr//ling Engineer Supervisor FOR COMMISSION USE ONLY Date Conditiohs of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~ O '~ J Approval No. ,c:~,,~ _..~,~C"'~ Approved by order of the Commission Fcrm 10-403 Rev 06/15/88 ~~~.~- Commissioner Date /j~ - '~-? 2____ SUBMIT IN TRIPLICATE ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEVI WELL PERMITS ** /~/ROVE DANTE' thru 8 ]' [9 thru ,~ -'.'~".. [10 & 13] (:;4) C, asg /~¢~",'". F. ?Z-/1- ¢~ [14 thru 22] (5) BOPE - .,~,~- [23 thru 28] Company YES 1. Is permit fee attached ............................................... 2. f~s well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells.. 5. Is sufficient undedicated acreage available in this pool ............. ~__ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Lease 8 Well ~ /~. NO REMARKS e 10. 11. 12. 13 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... /~ Is a conservation order needed ....................................... I s adm i n i st rat i ve approval needed .................................... Is lease nunber appropriate .......................................... ]~ Does well have a unique name & number ................................ Is conductor string provided Wil to Is Wil Wil Wil Is Is Is Is 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. enough cement used to circulate on conductor & surface ............ 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wel 1 bore separat ion proposed ............................. a d iverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of_~~ll~,-~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to.5~o~¢ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Other E29 th'r~ co t ct geology' engineering: RP~ BEW' ' ODH ,~f~o,.V LAG 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions D~sented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requ i rements INITIAL Add i t ional GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE _ / ./ rev 08/18/92 jo/6.011 0 -4 -rz ~O ('bm FT1 Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve :the readability of the Well History file and to simp!ify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. M - 19A PRUDHOE BAY~ RECEIVED MAR b 0 1996 Oil & Gas Cons. Commission Anchorage Run 1' 16 - January - 1993 DLLIMLLIAClGR 8812 0580 Tape Subfile 2. is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5863.00 JOHN DAHL HAYWOOD / COOK M - 19A 500292089701 BP EXPLORATION (ALASKA) ATLAS WIRELINE SERVICES 23-MAR-93 RUN2 RUN3 6 liN 13E 1710 196 51.50 51.00 26.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 8823.0 PRODUCTION STRING 8.500 REMARKS: MLL/DLL/AC/GR CIRCULATION STOPPED: 00:30 16-JAN-93. MAIN PASS HAS REPEAT PASS SECTION SPLICED IN FROM 9840' TO CASING POINT (DONE IN FIELD). REPEAT PASS SUBJECT TO MORE TENSION PULLS THAN MAIN PASS. AFTER LOG CALIPER VERIFICATION DONE IN CASING. ACOUSTIC CYCLE SKIP ON MAIN PASS @ 10420' & ON REPEAT PASS @ 10326'. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL DT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 8812.0 10535.0 8812.0 10580.0 9776.0 10555.5 GR (MEASURED DEPTH) BASELINE DEPTH DT 8812.0 8812.0 8822.0 8850.5 8856.0 8857.0 8857.5 8860.5 8869.5 8874.0 8875.5 8876.0 8880.5 8881.5 8909.5 8932.5 8953.5 8954.0 8969.5 8977.5 8997.0 9003.0 9202.0 9221.0 9230.5 9232.0 9232.5 9233.0 9239.0 9239.5 9241.0 9242.0 9262.5 9264.0 9274.0 9276.5 9282.0 9285.5 9290.0 9291.0 9294.0 9298.0 all runs merged; MLL 8812.0 8822.0 -- EQUIVALENT UNSHIFTED DEPTH LL3 LLD 8812.0 8812.0 8850.5 8855.5 8856.5 8857.5 8860.5 8870.0 8873.5 8875.0 8876.0 8880.5 8881.0 8909.5 8932.0 8953.0 8954.0 8969.5 8977.5 8996.5 9003.0 9002.5 9201.5 9201.5 9220.5 9229.5 9231.0 9231.5 9232.0 9238.0 9239.5 9239.0 9240.5 9241.0 9261.5 9264.0 9263.0 9274.0 9276.5 9282.0 9285.0 9289.5 9291.0 9293.5 9293.5 9298.0 9296.5 9296.5 no case 9303.0 9307.0 9334.5 9343.5 9372.0 9372.5 9374.0 9381.5 9382.5 9384.0 9386.5 9388.5 9391.5 9409.5 9429.0 9539.0 9551.5 9552.0 9554.0 9555.0 9559.0 9559.5 9570.0 9572.5 9573.5 9578.0 9618.0 9626.5 9627.5 9635.0 9639.5 9658.5 9659.5 9666.5 9667.0 9667.5 9685.5 9707.0 9739.5 9755.5 9777.0 9786.5 9805.5 9814.5 9819.5 9820.5 9822.0 9826.5 9835.5 9842.0 9850.5 9871.0 9871.5 9884.5 9889.5 9893.0 9897.0 9902.0 9909.5 9913.5 9805.0 9814.0 9825.5 9842.0 9850.5 9913.5 9334.5 9372.0 9382.5 9392.0 9410.0 9429.0 9539.0 9559.0 9618.0 9628.0 9635.5 9639.5 9661.0 9739.5 9755.5 9822.0 9835.0 9851.0 9897.0 9914.0 9303.0 9334.5 9343.5 9372.0 9381.0 9391.5 9429.0 9659.0 9755.5 9849.5 9889.0 9897.0 9307.0 9374.0 9383.5 9386.0 9388.5 9551.5 9552.5 9554.5 9555.0 9559.5 9570.5 9573.0 9573.5 9578.0 9627.0 9667.0 9667.5 9668.0 9686.0 9707.0 9777.0 9786.0 9819.0 9819.5 9870.0 9871.0 9884.0 9893.0 9902.0 9910.0 9917.0 9917.5 9927.0 9929.0 9934.0 9935.5 9938.5 9941.5 9942.5 9946.0 9951.0 9951.5 9959.5 9960.5 9962.5 9963.0 9967.0 9971.5 9974.5 9985.5 9991.5 9992.0 9997.0 10011.0 10018.0 10031.0 10053.5 10054.0 10054.5 10084.0 10091.0 10100.5 10110.0 10140.5 10141.0 10141.5 10147.5 10148.5 10156.0 10164.0 10168.5 10179.0 10213.5 10232.0 10239.0 10241.5 10242.5 10246.0 10256.5 10265.0 10269.5 10280.5 10303.5 10311.5 10317.5 10320.0 10322.0 10323.5 10329.0 10331.5 9917.5 9928.0 9935.5 9938.5 9945.5 9951.0 9971.5 10010.5 10031.0 10084.0 10109.0 10141.0 10148.0 10154.5 10163.5 10329.0 9933.5 9934.5 9942.5 9950.5 9962.5 9974.0 9985.0 9997.5 10010.5 10084.0 10091.0 10100.5 10109.5 10140.0 10168.5 10179.0 10265.0 10331.5 9917.5 9934.5 9942.5 9951.0 9991.5 9997.5 10010.5 10109.5 10168.5 10213.5 10265.5 10319.5 10322.0 10331.5 9927.5 9941.5 9959.5 9960.0 9962.0 9967.0 9992.0 10017.5 10053.0 10053.5 10054.0 10140.5 10147.5 10232.0 10239.5 10242.0 10242.5 10246.0 10257.0 10270.0 10280.5 10303.5 10311.0 10317.0 10323.5 10342.5 10343.5 10344.0 10368.5 10370.0 10370.5 10371.0 10376.0 10380.0 10388.0 10389.0 10392.5 10400.0 10403.0 10408.0 10418.5 10420.0 10423.5 10429.5 10434.0 10461.0 10463.0 10469.0 10469.5 10470.0 10470.5 10473.5 10477.0 10507.0 10518.0 10518.5 10528.5 10529.0 10536.5 10537.5 10543.5 10553.5 10555.0 10574.0 10610.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DLL DT $ REMARKS: 10375.0 10388.5 10388.5 10342.5 10343.0 10343.5 10367.5 10369.0 10369.5 10370.0 10379.0 10387.5 10392.0 10399.5 10403.0 10406.5 10419.5 10419.5 10420.0 10424.0 10429.5 10434.0 10433.5 10461.0 10463.0 10468.5 10469.5 10470.0 10470.0 10473.0 10477.0 10477.0 10506.5 10517.5 10518.5 10528.5 10528.0 10536.5 10537.0 10543.0 10553.5 10555.0 10574.5 10610.0 10610.0 10610.0 10610.0 RUN NO. PASS NO. MERGE TOP 1 1 8812.0 1 1 8812.0 1 1 9776.0 TENS, TEND, MTEM, & CALl WERE SHIFTED WITH MLL. SP WAS SHIFTED WITH LLD. $ MERGE BASE 10535.0 10580.0 10555.5 CN : BP EXPLORATION WN : M - 19A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA (ALASKA) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 CALl DLL 68 1 IN 4 6 MLL DLL 68 1 OHMM 4 7 LL3 DLL 68 1 OHMM 4 8 LLD DLL 68 1 OHMM 4 9 SP DLL 68 1 MV 4 10 MTEM DLL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 157 Tape File Start Depth = 10610.000000 Tape File End Depth = 8812.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 39568 datums Tape Subfile: 2 440 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8800.0 8812.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PASS. $ : BP EXPLORATION (ALASKA) : M - 19A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) Total Data Records: 598 BYTES * Tape File Start Depth = 8812.000000 Tape File End Depth = 8794.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation Icode decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 149 datums 26 records... 62 bytes 598 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8800.0 10562.0 DLL 8804.0 10607.0 AC 9750.0 10582.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 16-JAN-93 FSYS REV. J001 VER. 1.1 30 16-JAN-93 821 16-JAN-93 10595.0 10584.0 8812.0 10580.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC MIS KNJT KNJT MLL $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICRO LATEROLOG TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EA 3967XA 3921XA 3921XA 1233XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 8823.0 8812.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): KCL/POLYMER 9.90 58.0 10.0 5.2 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : M - 19A : PRUDHOE BAY : NORTH SLOPE : ALASKA 193.0 0.120 75.0 0.049 193.0 0.099 75.0 0.000 0.0 0.214 71.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 CAL MLL 68 1 IN 4 11 RMLL MLL 68 1 OHMM 4 12 RS DLL 68 1 OHMM 4 13 RD DLL 68 1 OHMM 4 14 ED DLL 68 1 MV 4 15 ID DLL 68 1 A 4 16 SP DLL 68 1 MV 4 17 TEMP DLL 68 1 DEGF 4 18 SPD DAn 68 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 90 132 02 1 4 71 857 46 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 559 Tape File Start Depth = 10610.000000 Tape File End Depth = 8794.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 177604 datums Tape Subfile: 4 640 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE S~Y FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9840.0 10557.0 DLL 9840.0 10580.0 AC 9840.0 10577 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 16-JAN-93 FSYS REV. J001 VER. 1.1 30 16-JAN-93 903 16-JAN-93 10595.0 10584.0 8812.0 10580.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC MIS KNJT KNJT MLL $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICRO LATEROLOG TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EA 3967XA 3921XA 3921XA 1233XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 8823.0 8812.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) KCL/POLYMER 9.90 58.0 10.0 5.2 193.0 MUD AT MEA'SURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : M - 19A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.120 75.0 0.049 193.0 0.099 75.0 0.000 0.0 0.214 71.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 TlR1 AC 68 1 US 5 TlR2 AC 68 1 US 6 T2R1 AC 68 1 US 7 T2R2 AC 68 1 US 8 CHT AC 68 1 LB 9 TTEN AC 68 1 LB 10 CAL MLL 68 1 IN 11 RMLL MLL 68 1 OHMM 12 RS DLL 68 1 OHMM 13 RD DLL 68 1 OHMM 14 ED DLL 68 1 MV 15 ID DLL 68 1 A 16 SP DLL 68 1 MV 17 TEMP DLL 68 1 DEGF 18 SPD DLL 68 1 F/MN 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 90 132 02 1 4 71 857 46 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 72 * DATA RECORD (TYPE# 0) Total Data Records: 236 994 BYTES * Tape File Start Depth = 10605.000000 Tape File End Depth = 9840.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 58309 datums Tape Subfile: 5 315 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 6 is type: LIS 93/ 3/23 01 **** REEL TRAILER **** 93/ 3/24 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 24 MAR 93 7:29a Elapsed execution time = 52.95 seconds. SYSTEM RETURN CODE = 0
