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Home My WebLink About194-054Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. N u m ber of Well History File PAGES TO DELETE Complete RESCAN Color items- Pages: Gmyscale, halftones, pictures, graphs, charts .... Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned bY: Beverly Dian~athan Lowell TO RE-SCAN Date:.~ Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si U~ ,~~~ ,~ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COM~SION ~lAR 6 209 ~~=a9 WELL COMPLETION OR RECOMPLETION REPORT AND L~lt~aka llil ~ Gas G~r~s. Gorrlmissio~ Anch®ra 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 ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Abar~„~_ 2/10/2009 ~ 12. Permit to Drill Number 194-054 • 309-005 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 04/27/1994 13. API Number 50-029-21141-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 05/02/1994 14. Well Name and Number: PBU 03-32A 332 FSL, 796 FWL, SEC. 11, T10N, R15E, UM Top of Productive Horizon: 2597' FSL, 1945' FWL, SEC. 11, T10N, R15E, UM 8. KB (ft above MSL): 53.65' - Ground (ft MSL): 27.65' 15. Field /Pool(s): . Prudhoe Bay Field / Prudhoe Bay Total Depth: 2659' FSL, 1973' FWL, SEC. 11, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 5206' 4984' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 714086 y- 5936395 Zone- ASP4 10. Total Depth (MD+TVD) 9763' 9172' • 16. Property Designation: ADL 028327 TPI: x- 715168 y- 5938692 Zone- ASP4 Total Depth: x- 715193 y- 5938754 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted i formation er 20 AAC 25. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 1. H-40 urf 0' urface 80' 3 " 192 # Pol t 1 - / " 72# L- rf 2 14' rf 2 4' 17-1/2" 24 III 4 I 9-5/8" 47# L-80 Surface 7631' Surface 7 99' 12-1/4" 5 0 x lass'G' 3 sx S I 7" 2 13 r 0 742 ' 763' 6923' 9172' -1/2" 285 x I 'G' 23. Open to production or inject ion? ^ Yes ®No 24. Tuelwc 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 4-1/2", 12.6#, 13Cr80 8525' - 9106' 9043' MD TVD MD TVD 25. ACID, FRACTURE, CEMENY SQUEEZE,. ETC. `~- ~~_ ~J~~ ,. ~~ ~~- '_ _ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8571' P&A w/ 17.5 Bbls Class 'G' 5227' Set CIBP 5206' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Core s A uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ,...<.g None ~' Form 10-407 Revised 02/2007 : C~oN NuE ELI ~ J j ~~ ~ 2 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND M ERS ENCOUNTERED): 29. FORMATION TESTS ' NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Shublik 9245' 8659' None Sadlerochit 9264' 8677' Zone 2C 9474' 8885' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and oorect to the best of my knowledge. ~~ J / ~~ Signed Terrie Hubble Title Drilling Technologist Date ( PBU 03-32A 194-054 309-005 Prepared By Name/Number. Terrie Hubble, 564-4628 Drilling Engineer: Ryan Ciolkosz, 5645977 Well Number Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • 03-32A, Well History (Pre Rig Sidetrack) Date Summary 01/09/09 WELL SI ON ARRIVAL. DRIFTED W/3.50" CENT. TAGGED BTM @ 9466', CORRECTED FROM ELM. TAGGED FILL C~ BTM PERF, 0' RAT HOLE - PERFS OPEN. SAMPLE BAILER EMPTY. TURN WELL OVER TO DSO -LEFT WELL SHUT IN. 01/14/09 T/I/O = 1700/880/80 Injectivity Test (Pre Sidetrack )Pumped into the Tbg with a 5 bbl neat methanol spear followed by 290 bbls of 1 % KCL and capped with 58 bbls of crude. Injectivity rate was 5 bpm through out job. TBG pressure started at 1700 psi and went on a vac at the end of the job. Final W HP's = vac/1000/100 Valve positions at the time of departure: Swab, Wing, Companion =Closed /SSV, Master =Open / IA & OA are open to the gauges. 01/17/09 T/IA/OA= SI/1000/0 Temp=cold PPPOT-T (FAIL) PPPOT-IC (PASS) (Pre RST) PPPOT-T Attempted to bled void to 0 psi would not bled down. Cycle and torque LDS to 500 ft/Ibs slowed leak down, torqued to 600 ft/Ibs, leak stopped. (1) LDS C 3:00 position under protection shelf unable to RU torque multiplier stuck, all others were in good working and visual condition but extremely tight. Removed 1 " NPT plug, removed internal check, installed Alemite test fitting. RU HP BT onto THA, flushed void until clean returns achieved. Pressured to 5000 psi fora 30 minute test, 5000/ 15 min, 4900/ 30 min. Bled void to 0 psi, RD all test equipment. PPPOT-IC RU onto HOKE valve, flushed void until clean returns achieved. Pressure will not build above 1000 psi, RU elephant gun onto packing port, pressure to 6200 psi and flushed packing void. Attempted to pressure up void again, pressure still not getting above 2000 psi, cycle and torque LDS "Standard", several extremely tight but were functioned and in good working and visual condition (1) LDS C~3 9:00 left out. Pressured to 3500 psi for 30 minute test, 3500/ 15 min, 3450/ 30 min. Bled void to 0 psi, RD all test E 01/17/09 Fullbore P&A: Displaced well with 300 bbls of 1% kcl. Pumped 10 bbls of chemical wash then pumped 5 ^bbls of 15.8 PPG 'G" cement 12.5 bbls of 15.8 w/aggregrate, (17.5 bbls of cement). Pumped 2 bbls of water to flush lines then diverted 5 bbls of water to launch ball. (7 bbls total) Pumped 179 bbls of diesel C~3 5 bpm then dropped rate to 1 bpm to squeeze the cement. Pumped a total of 191.6 bbls of diesel and 7 bbls of water behind the cement. TBG pressure increased to 1391 psi while pumping the last 12.3 bbls of diesel. Shut down pump and monitored TBG pressure for 20 mins. TBG pressure decreased from 1343 psi to 304 psi. 01/18/09 T/I/0= 0/860/0. Temp= SI. Monitor WHPs & T FL. TBG FL near surface. SV, WV = C. SSV, MV = O., OA = OTG. NOVP. 01/22/09 T/I/0= 100/880/150, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RST. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Freed up stuck LDS in the 3 O'clock position, left disengaged. Did not function LDS. PPPOT-IC: Rigged to Hoke valve. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. Did not function LDS. LDS in the 9 O'clock position is blank, broken LDS inside has nose ground off. 01/23/09 WELL S/I ON ARRIVAL. DRIFTED TO 8571' SLM WITH 3.68" CENTRALIZER SAMPLE BAILER (sample of cement). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 01/25/09 T/I/0=60/840/50. Temp = SI. MIT-TBG to 2500 psi *"PASS" (pre E-line). AL SI C«~ lateral valve. IA does not have a companion valve. Flow line pressure = 20 psi. TBG FL Q 30' (2 bbls). IA FL @ 5785' (254 bbls). Grease crew serviced wing valve and master valve. Pressure TBG up to 2500 psi with 3 bbls of diesel. TP in the first 15 mins decreased 120 psi and in the second 15 mins TP decreased 20 psi for a total of 140 psi in 30 mins. Bled TP down to 60 psi. Final WHP = 60/840/50. SV, WV =closed. SSV, MV =open. IA, OA = OTG. NOVP. 01/25/09 WELL SHUT-IN ON ARRIVAL. (E-LINE TUBING JET CUT). INITIAL T/I/O = 0/880/0. RIH WITH JET CUTTER MAX OD = 3.65", LENGTH = 14.8'. Page 1 of 2 • t~~ 03-32A, Well History (Pre Rig Sidetrack) Date Summary 01/26/09 JET CUT TUBING AT 8525', MID TBG JOINT, TIED INTO XO AT 7410' ON TUBING TALLY DATED 5/4/94. OVERPULLED 750# AFTER CUT. WELL SHUT-IN ON DEPARTURE. DSO NOTIFIED OF VALVE POSITIONS. FINAL T/I/O = 0/880/80. JOB COMPLETE. 01/27/09 T/I/0= 0+/920/20. Temp= SI. T & IA FL (pre CMIT TxIA). TBG FL 30' (2 bbl). IA FL C«3 5010' (225 bbl), between sta #1 dome C«3 3574' & sta #2 SO ~ 5785'. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/28/09 T/I/O =vac/930/20. Temp = SI. TBG & IA FL (FB). TBG FL C~ 1140' (27 bbls). IA FL Q 5035' (89 bbls). A/L connected, SI @ lateral with no companion. SV & WV = C. SSV & MV = O. IA & OA = OTG. NOVP. 01/29/09 T/I/0= VAC/930/50. Temp= SI. T & IA FL (pre-FBj. AL spool removed, 3" integral installed on IA. T FL @ 1110' (25 bbls). IA FL C 4984' (between sta 1 & 2) (220 bbls). SV, W V = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/30/09 T/I/0=vac/880/80 Temp=Sl CMIT TxIA to 2500 psi. Bleed IA psi from 880 psi to 735 psi. Speared into Tbg with 5 bbls of meth followed by 5 bbls of diesel followed by 51 bbls of 90°F crude @ 3 bpm with c- pump, IA pressure increased from 735 psi to 840 psi. Pumped 27 bbls of 90°F crude down Tbg C~3 5 bpm. Continued to Bleed IA (gas). Outside ambient temp = -43°F, went on weather standby at 2300 hrs. 01/31/09 T/I/O=VAC/450/60 CMIT TxIA PASSED to 2500 psi, MIT OA PASSED to 2000 psi (Rig ST prep). Bled IA. Pumped 248 bbls of 100°F crude down Tbg while bleeding IA gas to neighboring well to reach 2500 psi for CMIT TxIA. T/IA lost 120/190 psi in the 1st 15 mins and 60/+10 psi in the 2nd 15 mins for a total pressure loss of 180/180 psi in 30 min test. Bled WHP's to neighboring well. Pumped 9.8 bbls of 80°F crude down OA to reach 2000 psi for MIT OA. OA lost 125 psi in the 1st 15 mins and 55 psi in the 2nd 15 mins for a total pressure loss of 180 psi in 30 min test. Bleed OA. Final WHP's = 100/100/20. SV = C, WV = C, SSV = C, MV = O, IAV = OTG, OAV = OTG. 02/01/09 T/I/0=150/50/40. Temp=S1. Bleed IA & OA to 0 psi, pre-LDS install. Note: LRS to circ-out T&IA. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/02/09 T/I/0=140/40/0 Circ-Out. Pumped down Tbg with 5 bbls meth & 915 bbls 1 % KCL followed by 147 bbls 80°F diesel through jet cut, taking returns up IA to the flowline of 03-31. RD Tbg RU IA, Pumped 5 bbls diesel to freeze protect hardline. U-tubed TxIA for 1 hr. Pumped 49 bbls 80°F diesel down 03-32's flowline to sweep crude for disconnect. Bleed W HP's. Final W HP's = 0/0/0. Swab =closed, Master = open, W ing =closed, SSV =open, IA =open, OA =open, Lateral =closed per DSO. 02/02/09 T/I/O = 160/50/40. Temp = SI. Bleed IAP & OAP to 0. AL spool dropped. Circ-out incomplete, return to bleed later. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/03/09 T/I/O=Vac/Vac/0+. Temp=S1. Monitor WHP's pre-LDS removal. ALP=O+ psi, Spool piece dropped. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/04/09 T/IA/OA _ SI/0/0. Temp =cold. Replaced field made blank pin with CIW manufactured blank pin. Opened SBS on IC test void, gauges on OA and IA to 0 psi, no pressure in void. Removed field made pin, chased threads with tap, installed blanking pin with flat washer and packing, installed gland nut and tightened up. Page 2 of 2 • BP EXPLORATION Operations Summary Report Page 1 of 15 ~ Legal Well Name: 03-32 Common Well Name: 03-32 Spud Date: 8/24/1984 Event Name: REENTER+COMPLETE Start: 2/4/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2009 00:00 - 07:00 7.00 MOB P PRE PJSM. Mobilize and move camp, truck shop and pit module from M-Pad (M-19B} to DS-03. Spot on DS-03. LD derrick and prep sub for rig move. 07:00 - 11:30 4.50 MOB N WAIT PRE Wait on Nabors 4ES to convoy both rigs across the field. 13:00 - 00:00 11.00 MOB P PRE Scarify DS-03 and level pad for rig sub. Lay down herculite and rig mats. Move rig sub off M-Pad; pick up mats and herculite from M-Pad. Move rig from M-Pad to DS-03; convoy with 4ES. 2/5/2009 00:00 - 09:00 9.00 MOB P PRE PJSM. Moving rig from M-Pad to DS-03. Convoy with 4ES to Sag river; double-mat river for 9ES crossing. 09:00 - 10:00 1.00 MOB P PRE Rig on location ~09:OOhrs. Attempt to spot rig over 03-32; unable to spot sub due to wing valve on tree. 10:00 - 12:00 2.00 RIGU P PRE Mobilize DSM for valve removal from tree in order to properly spot sub over 03-32. Rig accept ~ 12:OOhr on 2/5. 12:00 - 14:00 2.00 RIGU N WAIT PRE Wait on DSM for tree valve removal and blind flange installation. 14:00 - 22:00 8.00 RIGU P PRE Spot sub base and mud pits; RU and interconnect pits to sub and spot cuttings box. Take on seawater for diesel displacement. Raise derrick and bridle down. Move 4" DP into pipe shed. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM. Rig up LRS to test OA and IA; connect kill line to IA, secondary kill like to OA. Pressure test LR lines to 3500psi before pressure testing IA/OA; good test. 2/6/2009 00:00 - 03:30 3.50 WHSUR P DECOMP Test OA to 2000psi, chart for 30 minutes; good test. Bleed oft OA pressure. Test IA to 2500psi, chart for 30 minutes; good test. Bleed off any remaining pressure in prep for RU DSM. 03:30 - 05:00 1.50 WHSUR P DECOMP RU Drill Site Maintenance. RU lubricator and test to 500psi. Pull BPV in order to circulate diesel out of tubing and IA. LD lubricator. 05:00 - 11:00 6.00 WHSUR P DECOMP Reverse circulate 5lbbls from 5-1/2" tubing. Circulate down to displace diesel from annulus; circulate 96bbls from 9-5/8" x 5-1/2" annulus. Take returns through diffuser to 250bb1 open top tank. Circulate surface-to-surface volume (535bb1s) of seawater to ensure all diesel has been removed from the wellbore. 11:00 - 12:30 f.50 WHSUR P DECOMP RU lubricator; install BPV and test from below to 1000psi; good test. 12:30 - 13:30 1.00 WHSUR P DECOMP Safety stand-down; discussed hammer wrench safety and recent incident with broken/lacerated finger. 13:30 - 17:00 3.50 WHSUR P DECOMP ND tree and adaptor flange- layout for NORM sweep. Install blanking plug in BPV. 17:00 - 20:30 3.50 BOPSU P DECOMP NU BOPs; two sets of variable bore rams, shear rams and annular preventor. PU test joint and crossovers. 20:30 - 22:00 1.50 BOPSU N SFAL DECOMP Attempt to test BOPS; blanking plug leaking. Call Cameron; redress blanking plug and install in BPV. 22:00 - 00:00 2.00 BOPSU P DECOMP Begin pressure testing BOPs and circulating equipment with 4" test joint; 250psi low, 3500psi high. Witnesses to test: AOGCC rep John Crisp, WSL Amanda Rebol and Toolpusher Roy Hunt. 2/7/2009 00:00 - 10:30 10.50 BOPSU P DECOMP PJSM, Test BOPs; 250psi low, 3500psi high. Annular tested with 4" test joint, upper rams tested with 4" and 5-1/2" test joints; tested against blanking plug. Change out upper VBRs (3.5" x 6") before getting good test on upper rams. Witnesses for test: AOGCC rep John Crisp, WSLs Joey LeBlanc and Amanda Rebol, Toolpushers Chris Weaver and Roy Hunt. Printed: 3/5/2009 12:39:56 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From'- To 03-32 03-32 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Hours Task Code NPT 2/7/2009 10:30 - 11:00 0.50 BOPSU P 11:00 - 12:00 1.00 PULL P 12:00 - 14:30 2.50 BOPSU P 14:30 - 16:30 2.00 PULL P 16:30 - 00:00 I 7.501 PULL I P 2/8/2009 100:00 - 05:00 I 5.001 PULL I P 05:00 - 07:00 2.00 PULL P 07:00 - 09:00 2.00 BOPSU P 09:00 - 20:00 I 11.001 CLEAN I P 20:00 - 22:00 I 2.001 CLEAN I P 22:00 - 00:00 I 2.00 I CLEAN I P 2/9/2009 100:00 - 06:00 I 6.001 WHSUR I P 06:00 - 13:00 I 7.001 WHSUR I P 13:00 - 16:00 I 3.001 BOPSUR P 16:00 - 17:00 I 1.00 I W HSU R I P 17:00 - 22:30 I 5.501 CLEAN I P 22:30 - 00:00 1.50 DHB P 2/10/2009 00:00 - 03:30 3.50 DHB P Page 2 of 15 Spud Date: 8/24/1984 Start: 2/4/2009 End: Rig Release: Rig Number: 9ES Phase Description of Operations DECOMP Lay down blanking plug and test joint, blow down lines. DECOMP RU tools for LD tubing; RU power tongs and elevators. DECOMP RU DSM; pull BPV with lubricator. RD lubricator extension. DECOMP PJSM. RU SLB spooling unit for control line. PU one joint of 4" DP and crossover; screw into tubing hanger. Back out LDS, remove tubing hanger and pull tubing from cut @ 8525'. 185k up to pull free, 165k up weight when pulling. DECOMP POOH with 5.5" 17# Cr13 tubin strip ,laying down joints from 8525' to -3245'. Spool control line while coming out of the hole; 28 control bands recovered (records indicate 30 control bands originally run). Inspect tubing in pipe shed- some pitting in tubing hanger pup and upper-most joints; no pitting visible in joints after 30 joints pulled. Some wear inside tubing from wireline; otherwise good condition. DECOMP PJSM. POOH with 5-1/2" 17# and 4-1/2" 12.6# 13Cr tubing from 3 4 ' t s .laying down and inspecting tubing joints and jewelry. Jet-cut jt pulled = 19.5' long. LD 4 GLMs, 1 Ball-o valve, 186jts of 5-1/2" tbg, 28jts of 4-1/2" tbg. DECOMP RD tubing running equipment; clean and clear rig floor. DECOMP RU to test lower VBRs 2-7/8" x 5" with 4" test'oint. Test to 250psi low, 3500psi high against test plug. AOGCC rep John Crisp waived witness of the test. Test witnessed by WSL Joey LeBlanc and Toolpusher Chris Weaver. DECOMP Set wear bushin and PU casin cleanout assembly, including string mills and 9-5/8" casing scraper. Single in with 4" drill pipe to 7406'. (7" liner top at 7428'). DECOMP PU two stands and circulate bottoms up at max rate. Pump high-vis sweep from surface to surface C~ 12bpm, 1700psi. Wrap casinghead with herculite and steam to ease in pack-off removal. While circulating and steaming, OA pressure increase to 40psi from fluid expansion; bleed pressure and monitor OA for 30minutes- Opsi build up on OA. DECOMP Pick up HES storm packer and space out pup; make up to 4" DP and five foot stick packer to 31' below rotary table (packer will be -4' below base flange when stack is removed). Set acker with 1/4 turn to the right and setting weight. Hang 185k up, 155k down. Pressure test packer; good. DECOMP PJSM. Break stack below tubing spoo . to mg spool bolts corroded; added difficulty to stack removal. DECOMP Pull 9-5/8" pack-off as per Cameron hand. Pull packoff w/ 10k. Remove tubing spool, replace packoff and tubing spool. Test new packoff to 5000psi for 30min; good test. DECOMP NU BOP stack and test at break. Test to 250psi low, 3500psi high for 5min each. Tests witnessed by WSL Joey LeBlanc and Toolpusher Chris Weaver. DECOMP PU stand of 4" DP and make up to HES storm packer. Pull to release acker. POOH with acker, LD. DECOMP Pump dry job, blowdown lines. POOH with cleanout assembly (including 9-5/8" casing scraper and full gauge string mill) from 7250' to surface, racking back 4" DP. DECOMP PU HES EZSV and RU SLB a-line unit. DECOMP PJSM. RIH with HES EZSV and GR/CCL via SLB a-line unit. RIH to 5400'. Log up past target depth twice to confirm GR Printed: 3/5/2009 12:39:56 PM • BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: 03-32 Common Well Name: 03-32 Spud Date: 8/24/1984 Event Name: REENTER+COMPLETE Start: 2/4/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 9ES Rig Number: 9ES I Date From - To Hours Task 'Code NPT Phase Description of Operations 2/10/2009 00:00 - 03:30 3.50 DHB I P DECOMP match with tie-in log. Pull up to 5227' (4' feet above casing 03:30 - 04:00 I 0.501 DHB I P 04:00 - 05:00 I 1.001 DHB I P collar, 35' feet from top casing collar); run sequence to set EZSV; good indication at surface that plug set. Weight indicator before set = 1606 Ib, after release = 1324 Ib. Release from EZSV. DECOMP Come out of hole with SLB a-line. EZSV in place C~? 5227' MD. RD SLB a-line. DECOMP Close blind rams and test EZSV to 3500psi for 30min. No I pressure loss for first 15 minutes or second 15 minutes - 2/11 /2009 05:00 - 09:30 4.50 STWHIP P 09:30 - 13:30 4.00 STWHIP P 13:30 - 14:00 ~ 0.50 ~ STWHIPI P 14:00 - 15:00 I 1.001 STWHIPI P 22:00 - 23:00 I 1.001 STWHIPI P 23:00 - 00:00 1.00 STWHIP P 00:00 - 03:30 3.50 STWHIP P 03:30 - 07:30 4.00 STWHIP P 07:30 - 09:00 I 1.501 STWHIPI P 09:00 - 12:30 3.50 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00 - 13:30 0.50 STWHIP P 13:30 - 15:00 1.50 STWHIP P 15:00 - 15:30 0.50 STWHIP P 15:30 - 19:00 3.50 STWHIP P 19:00 - 20:00 1.00 STWHIP P 20:00 - 21:00 1.00 STWHIP P 21:00 - 22:00 1.00 STWHIP P 22:00 - 00:00 I 2.001 DRILL I P 2/12/2009 100:00 - 00:00 I 24.001 DRILL I P WEXIT PU/MU whipstock BHA to 856'. Up and down weight 85k. WEXIT RIH with whipstock/milling assembly on 4" drill pipe to 5092'. Orient to 29 LHS. Hook up blower hose. RIH to EZSV at 5227. WEXIT Set EZSV with 20k down. Pull up 20k to verify. Set down 30k and shear slide pin. Up weight 150k, down 135k. WEXIT Displace seawater with 9.2 ppg LSND milling fluid. Pump at 495 m with 1110 si. WEXIT Mill window and new formation to 5246' MD. Pump at 562 gpm with 1330 psi off bottom, 1400 psi on bottom. Rotate at 80-100 rpm with 6k torque off bottom and 12k torque on bottom. WOB 2-5k. TOW 5206', BOW 5223'. WEXIT Pump a super sweep S-S at 560 gpm with 1330 psi. No significant increase in returns. Work through window with and without rotation and pumps. No problems. Mud weight in and out 9.2 ppg. WEXIT Perform FIT to 11.6 ppg EMW with 630 psi. WEXIT PJSM. Monitor well -static. POOH to milling BHA at 856'. WEXIT PJSM. Lay down milling BHA and collars. Upper mill in gauge. Clear and clean floor. WEXIT Pull wear ring. Flush stack and function test rams. Install wear ring. WEXIT PJSM. PU 8-1/2" intermediate drilling assembly to 727'. WEXIT PJSM. PU 4" drill pipe singles to 875'. WEXIT Shallow test MWD - OK. WEXIT PU 4" drill pipe singles to 3499'. WEXIT Service top drive. WEXIT PU 4" drill pipe singles to 4748'. WEXIT PJSM. Cut and slip 104' of drilling line. WEXIT Run in drill pipe stands to 5030'. WEXIT Orient to 29 degrees LHS. MAD pass from 5030' to 5226' at 300 fph with no rotation or pumps. INT1 Set benchmark 9.79 ppg clean hole ECD. Drill ahead to 5310' MD, 5031' TVD. Pump at 550 gpm with 1650 psi off bottom, 1750 psi on bottom. Rotate at 50 rpm with 5k torque off bottom, 6k torque on bottom. WOB 10k-20k. Up weight 145k, down 130k, RT 136k. Mud weight in and out 9.2 ppg. ECD 9.79 ppg EMW. AST - 1.15, ART - .63. INT1 PJSM. Drill ahead to 5703' MD. Pump at 550 gpm with 1680 psi off bottom, 1980 psi on bottom. Rotate at 60 rpm with 5k torque off bottom, 6k torque on bottom. WOB 15-20k. Up weight 158k, down 124k, RT 140k. Mud weight in and out 9.3 ppg. ECD 9.85 ppg, calculated ECD 9.66 ppg EMW. Printed: 3/5/2009 12:39:56 PM NELLHEAD= MCEVOY ACTUATOR = AXELSON /~, Yti 1 ~ 1 1 ~^E~ CB. ELEV = 53.2' ~ ~~ 3F. ELEV = :OP = Aax Angle = 2891' 31 @ 6891' T^ ~~,,, r'1 _ ~3_ O ~~ )atum MD = 9442' i )atum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2514' Minimum ID = 3.725" @ 9093' 4-112" HES XN NIPPLE TOP OF 7" LNR ~ 7428 9-518" CSG, 47#, L-80, ID = 8.681" 7631' PERFORATION SUMMARY REF LOG: BHCA ON 05/01(94 A NGLE AT TOP PERF: 8 @ 9270' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 9270 - 9290 S 05/05/05 3-318" 4 9322 - 9342 S 05/05!05 3-3/8" 4 9342 - 9348 S 05!05!05 3-3/8" 4 9410 - 9416 O 10/01/94 3-3/8" 4 9436-9466 O 10/01!94 3-3/8" 4 9544-9552 C 10/01/94 BRIDGE PLUG ~~ 7$15 ~4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 03-32A SAFETY NOTES: CHROM E TBG AND LNR GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 1 3574 3542 21 LBSPM DOME T-2 16 08116/0; 2 5785 5496 28 LBSPM SO T-2 24 08/16!0: 3 7095 6636 31 LBSPM DMY T-2 0 4 7391 6891 30 LBSPM DMY T-2 0 Cti B 5227' ~ 8525' JET CUT (01/26/09) -$571' TOP OF CEMENT (01/17109) 9021 4-1/2" HES X NIP, ID = 3.813" 9043 7" X 4-1/2" BKR SABL PKR 9076 4-1 /2" HES X NIP, ID = 3.813" 9093 4-112" HES XN NIP, ID = 3.725" 9106 4-1/2" TBG TAIL WLEG 9100' ELMD TT LOGGED 05/09/94 9106' QQQ 9478 ~ TOP OF CEMENT ~~QQ 9500 TOP OF SANC I7" LNR, 29#, NT-80, 0.0371 bpf, ID = 6.184" ~--I 9723' ~ ry/~/ TOP OF 7" LNR 9723' PBTD 9684' 7" LNR, 29#, 13CR-80, .0371 bpf, ID = 6.184" 9763' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03!13/86 ORIGINAL COMPLETION 05/10/05 JLCITCH SOZ PERFS WELL: 03-32A 05/06/94 SIDETRACK/WORKOVER 08/16/05 TWSITCH GLV C/0 PERMIT No: 194-0540 02/03/02 RN/TP CORRECTIONS 08/31/05 JRA/PJC SAND CLEAN OUT API No: 50-029-21141-01 06/26/02 BHCITCH PERF CORRECTION 05/30/06 DTM WELLHEAD CORREC110N SEC 11, T10N, R15E, 3305.82 FEL 2618.39 FNl 03/07/05 nn~~~mc RWUPJC rn V GLV C/O 02/02/09 r+l \/ /'~llppCl"Tr1~tC JKD/SV CMT S07JJET CUT (01/26109) nn r.__~___a:_~ rw~__~__~ • • ( ~. ~ r f r ~ ~ ~ ,, j} t ~ ; P ; I I ~ ~ r~ 4F it ~ F ~ 4 ~ \, 1 ~ ~, `\ + ` o- 1 ! o- \\ I ~ x ~' ) c ; ~ ` ` ~ ' ~ ~ ~' ' ~ ~ ~ ~ ~ t '~ SARAH PAUN GOVERNOR , ., ,s .:..., ., ,. _,r . :_ :....8 ~.; -~~ + .1 , ~ C t ~~ , , _ . . ~K1-7~L'1. OI1L to«1 t7[t 333 W 7th AVEN T S ~7 COZIT5ERQA'1`IO1~T COMM155IOI~T UE, UI E 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. ~~ PO Box 196612 ~ Q Anchorage AK 99519-6612 ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-32A Sundry Number: 309-005 Dear Mr. Tirpack: 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 Corxunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ! day of January, 2009 Encl. C l/1'~~ -0`1 STATE OF ALASKA ~~"~' V,~ ~~ !D ~ ALA OIL AND GAS CONSERVATION COM•SION JAN 0 ~ ~~''~ ., ~'I ~ 200 ~~ APPLICATION FOR SUNDRY APPRQ~~4L , 0 i 20 AAC 25.280 k8 ~I~ 8c CiBS ('.nnc. n~ ` ~ \/~ 1. Type of Request: ®Abandon . ^ Suspend ^ Operation Shutdown ^ Perforate ^ Tirr~lAt~i ~q„ iSSiOts ^ 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 194-054 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21141-01-00 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 03-32A' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~'L ADL 028327- 53.65' - 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): 9763' - 9172' - 9478' 8889' 9478' None in en th Siz MD TVD B r Ila e tructural " 14 47 rf 514' 13-3/8" 2514' 514' 4930 2 70 In rm di 7 1' 9-5/8" 7 1' 7 99' 687 476 Pr n Liner 3 5' 7" 7428' - 976 ' 3' - 9172' 81 70 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9270' - 9290' 8683' - 8703' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 9106' Packers and SSSV Type: 7" x 4-1/2" Baker'SABL' packer Packers and SSSV MD (ft): 9043' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: , Commencin O erations: January 15, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ryan Ciolkosz, 564-5977 Printed Name R bert Tir Title Engineering Team Leader Prepared By Name/Number. Signature {,~ Phone 5-4166 Date l Terrie Hubble, 564-4628 Commission Use Onl Sundry Number. _ ^~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ " ~ ~ `-L ~ ~ Subsequent Form Required: ~~ APPROVED BY / A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 R sed 06 00_§/ Submit In Duplicate ~°e ( ~: f ~ I , ~ , • by cr,~,~ • 03-32B Rig ST Well Type: Producer Current Status: This well is completed with 5-1/2" x 4'/z 13-CR-80 tubing inside a 7" liner and is currently shut-in. Request: Abandon Reason for Sundry Application: As part of the rig sidetrack operation, the existing 03-32A perforation will be permanently abandoned as follows: - 12.5 bbls of 15.8 ppg Class G cement from TOC at 9,478' to 9,150'(120' above top perfs). Tested to 2500 psi. - Additional isolation from the perfs will be achieved with the cement in the new 7" x 9 5/8" liner lap, and a liner top packer. Reason for Sidetrack: The neighboring producing wells (03-02, 03-19, and 03-21) drilled in the area bordering the gravity drainage and waterflood interaction portion of the field (GDWFI), all have good oil production and or show positive hydrocarbon response associated with resistivity data in the Sag River sandstone. Current Status: 03-32A was sidetracked on 05/12/1994 and completed with a 7" production liner and 5 1/2" x 4 1/2" CR 13 tubing. This well has been shut-in since 2001 for low oil rate. In 2005 an attempt was made to re-squeeze the perfs from 9300'-9450' and to shut off water and restore oil rate. The job did shut off about 2000 BWPD, but did not increase the oil rate. Currently this well is shut-in and classified as operable. PBTD is ~ 9478' with the top of perfs at 9270'. It is estimated that zero reserves remain for the current 3-32A weft. Other Requests: ~ lL.,. ~~ 2--„ I~,,~ ~~ 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. ~ ~ ~~Y~. Scope of Work: Lay in 12.5 bbls cement from TOC at 9,478' to 9,150' in 7" casing (120' above top of perfs). Cut and Pull 5 1/2" x 4 ~h 13-CR-80 completion, MASP: 2,366 psi Estimated Start Date: January 15, 2008 Current Well Conditions 1. Open Perfs from 9270' - 9290'. PBTD ~ 9478' 2. Currently shut-in due to low oil rate 3. McEvoy Gen 3 Wellhead Pre Rig Operations 1. SLICK: Drift tubing to TOC in 7" production liner at 9,478' MD if possible. 2. COIL: Lay in 12.5 bbls of cement from TOC at 9,478' MD to 9,150' MD in the 7" with 15.8 ppg Class G cement" production liner'. The TOC must be a minimum of 9170' MD to comply with AOGCC regulations and should be kept below the 4-1/2" X-nipple at 9021' MD. Volume of 7"from 9,478' to 9150': 0.0382 bpf, 328' = 12.5 bbls If unable to tag 9,478' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Freeze protect tubing with diesel to 2200' TVD. SBHP: 3200 psi SBHT: 190 °F 3. SLICK: WOC. Drift to TOC. 4. E-LINE: Jetcut tubing at 9,000' MD. 5. FULLBORE: CMIT-T x IA to 2,500 psi. Test OA to 2000 psi. Pressure tests are required for competent barrier for rig operations. If test fails, contact ODE. 6. FULLBORE: Bleed casing and annulus pressures to zero. 7. WELLHEAD: Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-IC and PPPOT-T. 8. OTHER: Set a BPV. Remove well house and flow line. Level pad as necessary. Rip Operations 1. Move in. Rig up Nabors rig 9ES. 2. Test BPV to 1000 psi. 3. Nipple down tree. Install blanking plug. Nipple up BOPE. 4. Test BOPE to 3500 psi high, 250 psi low. Pull BPV and blanking plug. 5. Circulate out freeze protection and displace with 8.6 ppg seawater. 6. Screw in landing joint. Unseat and pull 5-1/2" tubing hanger to floor. 7. Lay down landing joint and hanger. 8. Pull 5-1/2" x 4-1/2" tbg to cut at 9000' MD. Spool up control line. Count bands and clamps. Send tubulars in for inspection. 9. Clean casing with 9-5/8" casing scraper to cut. Circulate well, surface to surface. 10. RU E-line. Run CIBP to 5262' MD. Run GR/CCL from CIBP to surface. 11. Test 9-5/8" casing above CIBP to 3500 psi. 12. ND BOP. Insure all pressure is bleed from annulus. 13. Change out 9-5/8" pack-off. Test to 5000 psi 14. NU and test BOP. 15. PU and RIH with whipstock. 16. Orient and set WS at 5245' MD. ~ ~ '~ ~ ~~. Q~~~ ~ 18. Mill window. Pump a sweep. Drill 20', perform LOT. 19. POOH, LD window milling assembly. 20. PU 8-1/2" drilling BHA (GR/Resistivity). RIH. 21. Drill to TD, increasing mud weight to 11.0 ppg prior to entering the HRZ. 22. At TD, Circulate sweep. Short trip to the window. Circulate sweep. POH and LD BHA. 23. Rig up Liner running equipment. Run 7" 26# L-80 liner. 24. Circulate bottoms up at the window. Continue in to TD. 25. Circulate hole prior to cement. 26. Cement liner in place. Set liner hanger/packer. 27. Circulate out contaminated mud and cement. POH. LD running tool. 28. MU and RIH with 6-1/8" build BHA (GR/Resistivity/Neutron-Density) to top of liner. Circulate bottoms up. 29. Test 7" liner to 3500 psi for 30 minutes. Chart same. 30. Drill cement and float equipment. Displace well to Flo-Pro drilling fluid. 31. Drill 20'. Perform FIT. 32. Drill build section to soft landing in the Sag River formation. POOH. LD BHA. 33. PU lateral BHA (GR/ResistivityNeutron-Density). RIH. 34. Drill horizontal section to TD. 35. Circulate sweep. Short trip. Circulate sweep. POOH, LD BHA. 36. PU and MU 4-1/2" liner. 37. RIH with 4-1/2" liner on DP. 38. RU cement equipment. Circulate liner at TD. 39. Cement liner in place. Spot perf. Pill. Set liner hanger/packer. 40. POH, LD excess DP. 41. RU and MU perf guns, RIH with 2000' of 2-7/8" PAC and 4" DP. 42. Perforate overbalance. Pull up to top of liner. Monitor well. Continue to POOH. 43. POH. LD 2-7/8" PAC and 4" DP. 44. RU to run tubing. 45. Run 4-1/2" 13CR-80 completion. 46. Space out and land tubing. 47. Reverse in corrosion inhibited brine 48. Drop Ball and Rod. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 49. Shear valve and Confirm circulation. 50. Install TWC and valve. Nipple down the BOPE. Nipple up the tree and test to 5000psi. 51. Remove TWC valve. Freeze protect the well to 2200' TVD. Install BPV. 52. RDMO. Release rig. Post Rig Operations 1. Pull BPV 2. Puil the ball and rod / RHC plug. 3. Install gas lift valves 4. Install well house and instrumentation. 5. "S" riser modifications will be required. Drilling Engineer: Ryan Ciolkosz (907)564-5977 Production Engineer: Chris Colbert (907)564-5135 Geologist: Daniel Schafer (907)564-5098 ATTACH: Current Schematic Proposed Schematic TREE = McEV OY GBV 3 WELLHEAD•= MCEVOY ACTUATOR = AXELSON KB. ELEV = 53.2' BF. ELEV = KOP = 2891' Max Angle = 31 @ 6891' Datum MD = 9442' Datum TV D = 8800' SS • 03-32A 13-3l8" CSG, 72#, L-80, ID = 12.347" I-i 2514' • SAFETY NOTES: CHROMETBG AND LNR 2192' I--15-1/2" CAM BAL-O SSSV NIP, ID = 4.55" rAS LET MANDRELS Minimum ID = 3.725" @ 9093' 4-1/2" HES XN NIPPLE I5-1/2" TBG, 17#, 13-CR-80,0.0232 bpf, ID = 4.892" TOP OF 4-1/2" TBG TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" ST MD TVD DtV TYPE VLV LATCH PORT DATE 1 3574 3542 21 LBSPM DOME T-2 16 08/16/05 2 5785 5496 28 LBSPM SO T-2 24 08/16105 3 7095 6636 31 LBSPM DMY T-2 0 4 7391 6891 30 LBSPM DMY T-2 0 7410' 7410' -~ 5-1/2" X 4-1/2" XO 7410' 7428' 9-5/8" MILLOUT WINDOW 7631' ~~~~T1 PERFORATION SUMMARY REF LOG: BHCA ON 05/01/94 ANGLE AT TOP PER2F: 8 @ 9270' Note: Refer to Production DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9270 - 9290 O 05/05/05 3-3/8" 4 9322 - 9342 S 05/05/05 3-3/8" 4 9342 - 9348 S 05/05/05 3-3/8" 4 9410 - 9416 S 10101/94 3-3/8" 4 9436 - 9466 S 10/01 /94 3-3/8" 4 9544 - 9552 C 10/01 /94 BRIDGE PLUG I-{ 7815' 1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 9106' (7" LNR 29#, NT-80, 0.0371 bpf, ID = 6.184" ~-~ 9723' I TOP OF 7" LNR 9723' PBTD 9684' 7" LNR. 29#. 13CR-80..0371 bof. ID = 6.184" 9021' ~-14-1/2" HE.S X N~, ID = 3.813" I 9043' 7" X 4-1l2" BKR SABL PKR 9076' 4-1/2" HES X NIP, ID = 3.813" 9093' 4-1 /2" HES XN N~, ID = 3.725" 9106' 4-1/2" TBG TAIL WLC~ 9100' H.MD TT LOGG®05/09/94 03113186 ORIGINAL COMPLETION .05/10/05 JLGTLH SQZ PERFS 05/06/94 SIDETRACKIWORKOVER 08/16/05 TWS/TLH GLV GO 02/03/02 RN/TP CORRECTIONS 08/31/05 JRA/PJC SAND CLEAN OUT 06/26/02 BHC/TLH PERF CORRECTION 05/30/06 DTM WELLHE4D CORRECTION 03/07/05 RWUPJC GLV GO 12/22/08 RRC Open perfs 04/02/05 /TLH GLV CORRECTIONS TOP OF CEMENT TOP OF SAND WELL: 03-32A PERMff No: 194-0540 AR No: 50-029-21141-01 SC-C 11, T10N, R15E, 3305.82 FEL 2618.39 FNL BP Exploration (Alaska) TREE= McEVOY GEN 3 WELLHEAD = MCEV OY ACTUI~TOR = AXELSON KB. ELEV = 53.2' BF. ELEV = KOP = 2891' Maz Angk: = 31 ~ 6891' Datum MD = 9442' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" -3 2A P re ~ ~' ~ SAFETY NOTES: CHROME TBG AND LNR O 2192' ~~5-1/2"CAM BAL-OSSSVNIP,ID=4.55" GAS LIFT MANDRELS Minimum ID = 3.725" a~ 9093' 4-112" HES XN NIPPLE TBG, 17#, 13~R-80,0.0232 bpf, ID = 4.892" ~ 7410' TOP OF 4-1/2" TBG 7410' STOP OF 7" LNR ~~ 74ZS- CSG, 47#, L-80, ID = 8.681" 7631' PERFORATION SUMMARY REF LOG: BHCA ON 05/01/94 ANGLE AT TOP PERF: 8 ~ 9270' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz GATE 3-3/8" 4 9270 -9290 O 05/05/05 3-3/8" 4 9322 - 9342 S 05/05/05 3-3/8" 4 9342 - 9348 S 05/05/05 3-3/8" 4 9410 -9416 S 10/01!94 3-318" 4 9436 -9466 S 10/01/94 3-3/8" 4 9544 -9552 C 10/01 /94 BRIDGE PLUG ~--~ 7815' 41 /2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~--~ 9106' 7" LNR, 29#, NT-80, 0.0371 bpf, ID = 6.184" ~~ 9723' ~ TOP OF 7" LNR 9723 LNR, 29#, 13GR-80, .0371 bpf, ID = 6.184" ~~ 9763' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/13!86 ORIGINAL COMPLETION 05!10/OS JLCIfLH SQZ PERFS 05/06/94 SIDETRACK/WORKOVER 08/16/05 TWS/TLH GLV GO 02/03/02 RN/TP CORRECTIONS 08/31/05 JRA/PJC SA ND CLEAN OUT 06!26/02 BHCITLH PERF CORRECTION 05/30/06 DTM WELLHEAD CORRECTION 03/07/05 RWUPJC GLV GO 04/02/05 /TLH GLV CORRECTIONS ST MO TVD DEV TYPE VLV LATCH PORT DATE 1 3574 3542 21 LBSPM DOME T-2 16 08/16!05 2 5785 5496 28 LBSPM SO T-2 24 08/16/05 3 7095 6636 31 LBSPM DMY T-2 0 4 7391 6891 30 LBSPM DMY T-2 0 7410' -js-1/z" x a-1/2" xo ~ 9-5/8" MILLOUT WINDOW 7631' 9000' Tubing Jet Cut 9021' 4-1/2" HES X NIP, ID = 3.813" 904$' 7" X 4-1/2" BKR SABL PKR 9076' 4-1/2" HES X NIP, ID= 3.813" 9093' 4-112" HES XN NIP, ID = 3.725" 9106' 4-1 /2" TBG TAIL W LEG 9100' ELMD TT LOGGED 05/09/94 9150' PSJ1 Cement Top 9478' -1 TOP OF CEMENT I 9500' TOP OF SAND PRUDHOE BAY UNfT WELL: 03-32A PERMfT No: 194-0540 API No: 50-029-21141-01 SEC 11, T10N, R15E, 3305.82 FEL 2618.39 FNL BP Exploration (Alaska) TREE= McEVOY GEN 3 WELLHEAD= MCEVOY ACTUATbR = AXELSON KB.'ELEV = 53.2' BF. ELEV = KOP = 2891' Max Angle = 31 ~ 6891' Datum MD = 9442 Datum N D = 8800' SS ~3 2 B P ro p o s ~ SAFETY NOTES: CHROM E TBG AND LNR GAS LIFE MANDRELS ~1/2" X Nipple 2000' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2514' ST MD N D DEV TYPE V LV LATCH PORT DATE 1 2 3 4 5245' 03-328 KOP Minimum ID = 3.725" aG~ 9093' 4-1/2" HES XN NIPPLE 10645' ~-"~ 4-12" HES X NIP, ID = 3.813" 10685' ~ 7" X 4-112" BKR S-3 PKR, ID = 10725' 4-1/2" HES X NIP, ID = 3.813" 10765' 4-112" HES X NIP, ID = 3.725" 10843' 4-1 /2" WLEG ~~ 10843' ~~ 4-12" x 7" Liner Top 7" L-80. 26#. ID=6.276" 1 PERFORATION SUMMARY REF LOG: A NGLEAT TOP PER F: Note: Refer to Productbn DB for historical erf data S¢E SPF INTERVAL O n/S z DATE 3-318" fi 3-3/8" 6 3-318" 6 3-3/8" fi 3-3/8' 6 3-3/8' 6 4-1/2" TBG, 12.61f, 13-CR-80, .0152 bpf, ID = 3.958" ~-~ 9106' BR~GE PLUG ~ 1 7815 ~' P8A TOC 9150' PBTD 9684' 7" LNR, 29#, 13CR-80, .0371 bpf, ID = 6.184" 9763' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 03N3186 ORIGINAL COMPLETION OS/10/OS JLGTLH SQZ PERFS 05106/94 SIDETRACK/WORKOVER 08/16/05 TWS/TLH GLV GO 02/03/02 RN/TP CORRECTIONS 08/31/05 JRA/PJC SA ND CLEAN OUT 06/26!02 BHGTLH PERF CORRECTION 05/30/06 DTM WELLHEAD CORRECTION 03/07/05 RWUPJC GLV GO 04/02/05 /TLH GLV CORRECTIONS PRUDHOE BAY UNff WELL: 03-32A PERMIT No: 194-0540 API No: 50-029-21141-01 SEC 11, T10N, R15E, 3305.82 FEL 2618.39 FNL BP Exploration (Alaska) ~- 105 4 10 3 10 102 10~ ~J 1994 95 96 dk ~Fa S/T DATE t 1 ~~ H~ %. + ~ SAc- 99 2000 01 ~ 9 09' , STATE OF ALASKA-, ALA.. À OIL AND GAS CONSERVATION COM\,., -,SiaN REPORT OF SUNDRY WELL OPERATIONS \',r-., Stimulate 0 r,?\gther Ö(-¡u , Waiver D TimeExten~,j(tJP[J" 1 Re-enter Suspended Wèll[I:', ' 5. Permit to Drill Number: Exploratory C 194-0540 Service 6. API Number: 50-029-21141-01-00 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 53.65 KB 8. Property Designation: ADL-028327 11. Present Well Condition Summary: Total Depth measured 9763 true vertical 9171.86 Effective Depth measured 9478 true vertical 8889.36 Casing Conductor Surface Production Liner Length 80 2485 7603 2335 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# 13Cr80 Perforation depth: Measured depth: 9410 - 9416 True Vertical depth: 8821.99 - 8827.94 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9300-9450 Treatment descriptions including volumes used and final pressure: see attached fluid summary TIO 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations o Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development '1'9\ Stratigraphic feet feet feet feet MD 30 - 11 0 29 - 2514 28 - 7631 7428 - 9763 9436 - 9466 8847.75 - 8877.48 5-1/2" 17# 4-1/2" 12.6# 9. Well Name and Number: 03-32A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) None None TVD 30 - 110 29 - 2513.92 28 - 7099.49 6923.14 - 9171.86 Burst 1490 4930 6870 8160 ("...1 Ifu ~ ¡,.. ~ ['" k, S'" r: \,"" ,tjt~,.A~~ß'~n'JK:¡[)! ,",."' [" ~,)J .~ .¡,: '2' oor ~~~ J, '_.,' J ~I )1 13CR80 13CR80 27 - 7410 7410 - 9106 4-1/2" Baker SABL Permanent Packer 9043 RBDMS 8FL SEP ~ 9 Z005 Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure SHUT - IN o I 0 I 15. Well Class after croposed work: Exploratoryr Development W o 16. Well Status after proposed work: OilW Gas r WAGr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. x Contact Sharmaine Vestal Printed Name Sharmaine Vestal... ~ I Signatur~ ?JAIJ Form 10-404 Revised 04/2004 GINJ r WINJ r Collapse 470 2670 4760 7020 Tubing pressure o Service í WDSPL r Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 9/15/2005 Submit Original Only ) ) 03-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/12/2005 CTU#4: Cement Re-squeeze. ***Well SI Upon Arrival*** MIRU. Fight leaky hardline all morning. Fluid pack IA w/ diesel. RIH w/ 2.25" JSN and tag bottom @9381' ctmd. Establish injectivity = 1820 psi @ 1.5 bpm. Pump 20 bbls 12% HCI followed by 50 bbls filtered 1 % KCI. Post Acid injectivity = 650 psi @ 1.5 bpm. POOH and rig down for the night. Will return tomorrow for cement squeeze. ***Continued on 8/13/05*** 8/13/2005 CTU#4: Cement Squeeze. ***Cont. from 8/12/05*** RIH w/ 2.5" BON. Circ XS water out of well w/ 210 bbls 1 % KCI. Bullhead 150 bbls diesel down backside to lighten fluid column. Lay in 45 bbls of 15.8 ppg LARC cement. Squeeze 3.8 bbls behind pipe. Hold 3000 psi squeeze pressure, which bled to 2880 psi after 30 minutes. Contaminate to 9300' ctmd, chase OOH @ 80% w/ XS 1 % KCI. Wash all jewelry and tree. FP tubing to 2500' md. Trap 550 psi on WHP. Flush surface lines. Leave Well SI. *** JOB COMPLETE*** 8/15/2005 ***WELL SiaN ARRIVAL *** (Post cmt sqz) RIH W/ 3 3/8" X 11' DUMMY, TTL- S BAILER, TT @ 9082' SLM, + 18' CaRR. TAG BTM. @ 9291' SLM = 9309' MD ***CONT. ON 8-15-05*** 8/16/2005 ***CONT. FROM 08-15-05*** (Post cmt sqz) SET 5.5" WHIDDON @ 7386' SLM PULLED ST. #2,1.5" DMY GLV W/ T2 LATCH FROM 5772' SLM PULLED ST. #1, 1.5" DMY DL V W/ T2 LATCH FROM 3561' SLM SET ST. #1,1.5" GLV (1500 DOME, 1/4" PORT) T2 LATCH @ 3561' SLM SET ST. #2,1.5" S/O (5/16" PORT) T2 LATCH @ 5772' SLM PULLED 5.5" WHIDDON FROM 7386' SLM ***WELL LEFT SI, TURNED OVER TO DSO*** 8/17/2005 CTU#4: Underream Cement. ***WELL SHUT IN UPON ARRIVAL*** MIRU. RIH w/5.75" Underreamer. U/R hard cement from 9303' CTMD to 9385' using XS 1 % KCI and 5 bbl sweeps (20 bbls total) of 1.5 ppb Biozan. Cement interface from 9382' to 9385' CTMD. Continue U/R to 9405' CTMD, pump 20 bbl 1.5 ppb Biozan pill and chase OOH at 80% of pump rate. Freeze protect with 55 bbls Meth. Sand in U/R blades. Blades wear pattern showed full opening. Well left Shut-In, waiting on CTU to return for FCO. 8/25/2005 CTU #4, 1.75" Coil, Fill Clean Out. Finish redressing BOP's. Swap to new reel (15,900 ft) and stab pipe. MIRU to 03-32. Shut down for night. ... Job in Progress - Conti on WSR 08/26/05 ... 8/26/2005 CTU #4, 1.75" Coil, Fill Clean Out. ... Cont' from 08/25/05 WSR... Drift new string of 1.75" Coil with 1.25" rubber ball and perform weekly BOP test. MU and RIH with 2.5" 00 JSN. Tag fill at 9388' ctmd, jet through fill down to 9408' ctmd with Biozan and XS 1 % KCL. Set down multiple times at 9408' ctmd while pumping up to 3.0 bpm without being able to make additional footage. POOH to pick up underreamer. ... Job in Progress - Cont' on 08/27/05 WSR ... 8/27/2005 CTU #4, 1.75" Coil, Underream. ... Cont' from WSR 08/26/05 ... MU and RIH with 2-7/8" PDM Motor and Reeves Underreamer with 5.65" 00 blades. Dry tag fill at 9392' ctmd. Underream down to 9420' ctmd with XS 1 % KCL making several Biozan gel sweeps (15 bbls total). No significant motor work observed. Drop 0.75" ball and POOH chasing returns to surface. Shut down for night. ... Job in Progress - Conti on WSR 08/28/05 ... ) ) 8/28/2005 CTU #4, 1.75" Coil, FCO. ... Cont' from WSR 08/27/05 ... RIH with 3.0" JSN. Tag fill at 9400' ctmd and clean out down to 9482' ctmd.. Make 4 short trips from 9482' to tubing tail pumping at 3.5 bpm with several gel sweeps (45 bbls total). Chase returns OOH at 80%. Gas lift was assisting clean out entire time at 2.0 MMscfpd. Perform injectivity at surface: achieved 3.25 bpm at 2000 psi. *** Job Complete *** 9/2/2005 PERFORATE INTERVAL FROM 9270' TO 9290' 33/8" PJ HSD 3406, 20' GUN, 6SPF, 60 DEG PHASING CORRELATION LOG: SWS ULTRA SONIC IMAGER CEMENT AND CORROSION, DATED 9-MAY-1994 FLUIDS PUMPED BBLS 623 1 % KCL 278 Diesel 20 12% HCL 2357 1 % XS KCL 45 Cement 309 Methanol 259 Biozan 42 Freshwater 3933 TOTAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: -Tom Maunder, P. I. Supervisor' DATE: January 15, 2001 FROM:' John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site 03 JanUary 15~ 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-1'4-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed, 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15,00jc cc; NON-CONFIDENTIAL SVS PBU DS 03 1-15-01jc.doc Alaska Oil and Gas Conservation Commission Safety valve System Test RepOrt Operator: BPX Submitted By: John Crisp Date: 1/15/01 Operator Rep: Mark Womble Field/Unit~ad: Prudhoe Bay Field DS 03 AOGCC Rep: John Crisp Separator psi: LPS 185 HPS 690 Well Permit Separ set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE 03~01 1750750 185 150 100 P P OIL 03-02 1760240 185 150· 120 P P OIL 03-03 1760390 185 150 110 P P OIL 03-04 1760510 · 03-05 1760570 03-06 1760600 03-07 1760530 03-08 1760730 ' 185 150 130 P P OIL 03-09 1790220 185 150 100 P P OIL 03-10 1790210 . 03-11 1790470 03-12 · 1790580 03-13 1790710 - · 03-14 1790820 185.' 150 100 ~.P P OIL 03-15A 1930150 185 150 100 P P OIL , 03-16A '1970330 03-17 1791020 03,18A 1930420 03-19 1830920 185 150 90 P P OIL 03-20A 1930470 185 150 100 P P OIL 03-21 1831120 - 185 150 100 P P OIL 03-22 1831230 690 600 420 P P OIL 03-23 1831270 185 150 0 '1. P OIL , 03-24A 1980060 690 600 530 P P OIL 03-25A 1930230 , 03-26 1831510 185 150 110 P P OIL 03-27 1840620 185 150 100, P P OIL 03-28 1840720 03-29 1840790 185 150 110 P P OIL 03-30 18408301' 185 150 90 P P OIL 03-31 1840920 185 150 140 . P P OIL · 03-32A ~1940540 185 150 110 P P OIL 03-33A 1970390 03-34B 2000110 185 150 0 1 P OIL 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15'01c.xls Well Permit! Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip. Code Code Code Passed OAS or 03-35 1910800 185' 150 90 P' P OIL 03-36 1930190 · Wells: 21 Components:. 42 Failures: 2 Failure Rate: 4.8% Elgo r>av Remarks: ~ ,~ o~a~ Pa~e 2 of 2 SVS PBU DS 03 1-15-01c.xls ON OR BEFORE AOGCC Individual Well:~ ogical Materials Inven~_Y PERMIT DATA T DATA_PLUS mmmmmmmm~ m mmmm 94-054 ~~' T 9200-9654, OH-AC/GR 94-054 ,~,BHCA/GR L 9200-9654 1 94-054 ~NL/GR L 9200-9599 94-054 ~/d~LL/GR/SP S 9200-9624 1 94-054 ~,~ERF S 9080-9430 1 9050-9985 1 94-0s4 ~,~'ROD L 3400-9590 1 9~-054 u/SSTVD S 9200-962~ 1 94-054 ~TIC (BLOELINE L 8995-9350 1 94-054 ~ USIT (C&C) L 8930-9675 1 Are dry ditch samples required? yes~~And received? Was the well cored? yes ~~A_~nalysis & descriptio~ ~ceived? Are well tests required?~ /yes__~_~Received? yes no Well is in compliance ~J ~ ' Initial COMMENTS Page' 1 Date: 10/13/95 RUN DATE_RECVD 05/27/94 05/27/94 05/27/94 05/27/94 05/27/94 06/08/95 12/06/94 05/27/94 06/20/94 05/27/94 yes no yes no STATE OF ALASKA ALASKA ~AND GAS CONSERVATION CC~SION REPORT SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perlorate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 332' NSL, 796' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2599' NSL, 1943' EWL, Sec. 11, T10N, R15E, UM At effective depth At total depth 2659' NSL, 1970' EWL, Sec 11, T10N, R151=, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number ;~-32A ~. Permit number/approval number 94-54 10. APl number 50 - 029-21141-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9763 feet 9172 feet Plugs(measured) Tagged PBTD @ 9617' MD (6/7/95) Effective depth: measured 9617 feet true vertical 9028 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1925# Poleset 80' 80' Surface 2460' 13-3/8" 2400 Sx CS III & 400 Sx CS II 2514' 2514' Production 7577' 9-5/8" 500 Sx G & 300 Sx CS I 7631' 7101' Liner 2335' 7" 285 Sx G 9763' 9172' RECEIVED Perforation depth: measured 9270-9290'; 9322-9348' JUL 2 4 1995 true vertical 8684-8704'; 8675-8700' Alaska 0il & Gas Cons. Commission Anchor: ~ Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCT Tbg @ 7410' MD; 4-1/2", 12.6#, 13 CR-80, NSCC Tbg @ 9106' MD Packers and SSSV (type and measured depth) Baker SABL-Packer @ 9043' MD; Camco BaI-O SSSV @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 466 1085 12019 - · 846 / 2603 12343 - Tubing Pressure 255 283 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~'erti.fy th.~t the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE cc: KZ. JWP 3-32A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/7/95: RIH & tagged PBTD at 9617' MD. 6/9/95: MIRU & PT equipment. RIH w/perforating gun & shot 20' of Add Perforations at: 9270 - 9290' MD (Z4) Ref. Log: BHCA 5/1/94. Used a 3-3/8" carrier & shot 4 spf at 90 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. A~ska Oit & Gas Cons. commission Ancho;[ .~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9521 Company: 6/19/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date ElL RF Sepia DIR MWD Disk ,,, D.S. 3-22 DUAL BURST TDT-P 950603 I 1 D.S. 3-29 PROD PROFILE 95 0530 I 1 D.S. 3-32A PERF RECORD 950609 I 1 D.S. 4-2A DUAL BURST TDT-P 950529 I 1 D.S. 4-35 PERF RECORD 950529 I 1 D.S. 6-19 DUAL BURST TDT-P 950530 I 1 .... D.S. 9-3 ~ BRIDGE PLUG RECORD 950531 I 1 D.S. 9-39 i PERF RECORD 95 06 04 I 1 D.S. 9-50 PROD PROFILE 950602 I 1 D.S. 12-15 GAS LIFT SURVEY 9506 06 I 1 ,,, D.S. 12-17 GAS LIFT SURVEY 950607 I 1 , D.S. 14-02B DUAL BURST TDT-P 950531 I 1 ,,, D.S. 15-36 DUAL BURST TDT-P 950602 I 1 ~ D.S. 16-11 MI INJECT PROFILE 950605 I 1 D.S. 15-15 951 82 CNT-D 950509 1 D.S. 14-33 951 70 CNT-D 950427 1 ....... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUN 19 1995 Alaska 0il & Gas Cons. C0mmissl0n Anchorage 12/5/94 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar PWDW 3-1 ~ ~'~.'- ('3 qJ~ STATIC BHP SURVEY (11-15-94) 1 : 1 D.S. 3-7 .'7~_-~ '-' ~'~ 5--~ PERF RECORD (11-20-94) I 1 D.S. 3-10 '2 ~-C~2-/ INJEC PROFILE (11-17-94) I 1 D.S. 3-32A ?/~' ~ ~";'--C3,5'- ~ PROD PROFILE (11-14;94) I 1 D.S. 4-19 ~'-~ - O ~-I DUAL BURST TDT-P (11-21-94) I 1 D.S. 7-19 ~'-'~-~7 CNL ((11-13-94) I 1 D.S. 9-21 /'/ ~-~--,/~O LEAK DETECTION (11-11-94) I 1 D.S. 9-21 ~ ~--- / ~ O TUBG PATCH RECORD (11-22-94) I 1 D.S. 9-47 .~ 0 ," ,/'¢'~, PROD PROFILE (11-15-94) I 1 D.S. 9-49 ¢, '~ _,-p_~_'~/,,~'r~ PROD PROFILE (11-14-94) I 1 D.S. 11-31~ . ~.--~'2-7 R.O.P.E. PERF RECORD (11-14-g4) I 1 D.S. 11-32 '/~. '.~'47/--_/,~_/ R.O.P.E. PERF RECORD (11-15-94) 1 1 D.S. '15-41 '~2.-- ~Y~' GR-CCL (11-11-94) I 1 D.S. 16-21 ~.~-'- ~/"/._ LEAK DETECTION (11-22-94) I 1 D.S. 17-7 ,~/'--d~,~ LEAK DETECTION (11-16-94) I 1 D.S. 17-13 .,~,--/?.~ LEAK DETECTION (11-16-94) I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. I, STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~'!ISSION REPORT OF SUNDRY WELL OPEdATIONS 1. Operations performed: Operation shutdown Stimulate Plugging _ Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. . 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 332' NSL, 796' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2599' NSL, 1943' EWL, Sec. 11, T10N, R15E, UM At effective depth At total depth 2659' NSL, 1970' EWL, Sec. 11, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service Oi ii$ihiAL 6. Datum of elevation(DF or KB) 54 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-32A 9. Permit number/approval number 94-54 10. APl number 50 - 029-21141-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9763 feet 9172 feet Plugs(measured) PBTD Tagged @ 9623' MD (10/1/94) Effective depth: measured 9623 feet true vertical 9034 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical deptl~ Conductor 80' 20" 1925# Poleset 80' 80' Sudace 2460' 13-3/8" 2400 sx CS III & 400 sx CS II 2514' 2514' Production 7577' 9-5/8" 500 sx G & 300 sx CS I 7631' 7101' Liner 2335' 7" 285 sxG 9763,p~E(E~ ¢~7~) Perforation depth: measured 9322-9348'; 9410-9416'; 9436-9466'; 9544-9552' NtqV - '~ ~994 true vertical 8736-8762'; 8823-8829'; 8849-8878" 8956-8964' ~,~ska u~ ~, Gas Cons. Commission ' Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCT Tbg @ 7410' MD; 4-1/2", 12.6~, 13 CR-80, NSCC Tbg @ 9106' MD Packers and SSSV (type and measured depth) Baker SABL-Packer @ 9043'; MD; camco BaI-O SSSV @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation .R..epresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 554 1311 5886 -- 1093 2252 11799 -- Tubing Pressure 343 295 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil .x Gas Suspended ..... Service 1~. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. O'1~. Engineer Date Form 10-404 Rev 06/15/88 1P44/1R nc.' K7 .IWP SUBMIT IN DUPLICATE.~ 3-32A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 0/1/94: MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 9623' MD, then PU & shot 44' of add perforations as follows: Added perforations: 9410 - 9416' MD (Z4) 9436 - 9466' MD (Z3) 9544- 9552' MD (Z2) Ref. Log: BHCA 5/1/94. Used 3-3/8" carriers & shot 4 spf at 60/120 degree phasing, at underbalanced pressures. POOH w/perforating guns; noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED NOV - 1 1994 Ataska 0il & Gas Cons. Commission Anchorage NO. 8989 Company: Alaska Oil & Gas Cons Comm , Mtn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Deecription BL RR Sepia RF Sepia Mylar D.S. 3-20A c[ %'-~'7 PROD LOG (9-30-94) '... 1 1 D.S. 3-21 ~:~ '~ "11 ~.... LEAK DETECTION (9-28-94) ... 1 1 D.S. 9-7 PERF RECORD (9-29-94) I 1 D.S. 13-~ ' ~ ~ ~ ~PROD PROFILE(9-28-94) 1 1 D.S. 16-~A ~' ( ~ ~ ~ PROD LOG (9-30-94) I 1 , SIGNED: Please sign and relum or~e copy of this transmittal to Sherrle at the above addreN. Thank you.- 10/12~94 STATE OF ALASKA ALASK~ AND GAS CONSERVATION ~ISSION REPOR'[ OF SUNDRY WELL OP rl:ATIONS 1. Operations performed: Operation shutdown ..-.-- Stimulate X, Plugging ,,, Perforate X, ,,. Pull tubing Alter casing , , Repair well-- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 332' NSL, 796' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2599' NSL, 1943' EWL, Sec. 11, T10N, R15E, UM At effective depth At total depth 2659' NSL, 1970' EWL, Sec. 11, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54 RKB 7. Unit or Property Prudhoe Bay Unit feet 8. Well number 3-32A 9. Permit number/approval number 94-54 10. APl number 50 - 029-21141-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9763 feet 9172 feet Plugs(measured) Fill Tagged @ 9329' MD (7/4/94) Effective depth: measured 9329 feet true vertical 8682 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 1925# Poleset 80' Sudace 2460' 13-3/8" 2400 sx CS III & 400 sx CS II 2514' Production 7577' 9-5/8" 500 sx G & 300 sx CS I 7631' Liner 2335' 7" 285 sx G 9763' True vertical depth 80' 2514' 7101' 9172' RECEIVED Perforation depth: measured 9322-9348' AU(~ '~ 2~ lcJ°j4 true vertical 8675-8700' Alaska 0il & {~as Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCT Tbg @ 7410' MD; 4-1/2", 12.6#, 13 CR-80, NSCC Tbg @ 9106' MD Packers and SSSV (type and measured depth) Baker SABL-Packer @ 9043' MD; Camco BaI-O SSSV @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. 14. Treatment description including volumes used and final pressure Representative Dai'ly Average production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 6 486 540 -- Subsequent to operation 693/'"~' 1589 6090 -- Tubing Pressure 269 235 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x. Gas .. Suspended..._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 "-"' 117R/12 c.c.: KZ JWP SUBMIT IN DUPLICATE~,, 3-32A FRACTURE TREATMENT OF ZONE 4 DESCRIPTION OF WORK COMPLETED 5/1 2/94: Shot Initial Perforations: 9322 - 9348' MD (Z4) 7/2/94: Ref Log: BHCA 5/1/94. MIRU & PT equipment to 9000 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the perforations (listed above). Pumped Data Frac: a) 350 bbls 20# Pre Pad Gel @ 25 - 40 bpm, followed by b) Shutdown. ISIP @ 2080. Resumed pumping Data Frac: c) 475 bbls Datafrac Pad @ 35 bpm, followed by d) 205 bbls 20# Linear Flush @ 35 bpm, followed by e) Shutdown. ISIP @ 1820. Resumed pumping Fracture Treatment: f) 20 bbls 40# Linear Startup stage @ 35 bpm, followed by g) 170 bbls Cross Linked Pad @ 35 bpm, followed by h) 557 bbls Slurry, w/proppant concentrations at 1 to 10 ppg, followed by i) 202 bbls Flush, followed by j) Shutdown. Placed a total of 99,000 lbs of proppant into the formation. Rigged down. 7/3/94: RIH w/CT & jetted a proppant fill cleanout down to 9349' MD. 7/4/94: RIH & tagged PBTD at 9329' MD. Placed well on initial production & obtained a valid production test. RECEIVED AUG 1 2 1994 Ataska 0il & Gas Cons. Commission Anchorage F'~E HO, ~ HE~ I,OCA?IOH: L~T(I,L/-5) 0.00 D~P(K'-tl) ~?IPIJ'I'H T'R1]I'I R1Tr~¥ TABLE TO TARGET lC.. ]U.~ IH POll, iT(TIP) ~A~JI?~ Dff"rH 7~5,00 IT~L~ t,L:'RT DI~:"/'i.! 7103o00 .'I;~LI~TI~ 29.12 ~IHLrrH S~9,97 I~.TITUI)£(H/-S) 1926,11 OEF'ARTURE(E/-W) ~,62 RECEIVED JUN 2 7 1994 At~ska 0it & Gas Cons. Commission Anchorage 7VNIgI IO P~E ~, i'E~EI) I)EPTH fi: 7635,00 8060,53 8092,21 8123,90 8215,80 INTERUAL '?l~?I~L TARGET STATION AIlltlll~ Dt~?~ SECTION I~, ft :t ft d~ d~ 0.0 7102,~ ~81,49 ~.12 ~.97 4~,5 74~6,~ ~,53 14,~ ~,~ 31.7 7~.37 ~48.~ 14.~ ~.09 31,7 ~7,7C ~.72 14,~ ~.~ 91.9 7~.~ ~9,98 14.63 ~.~ I~TZIUI)£ I)EPAE'I~E I)ISPIJtC~ at AZIHUTH ft ft ft deg lOOft' 1926,11 993,62 2140,45; 25,86 0.¢0 2::)'32,3'2 1030,52 2296,52 26,66 3,37 ~59,21 1034.91 2304.64 26,68 0.73 20~,06 :039,30 2312,74 26,70 0,90 2085,67 1052,07 2336,00 26,77 0,29 8308,88 8403,75 8497,61 8590,36 86~,25 93.1 77, F:6.6~2303.16 14.39 32,07 94,9 7~0.fi5 2326.33 14.04 33.61 93,? ~19,~ 2349,07 14,11 35,13 ~2,8 83¢~,~ 2371,18 13,~ 34,28 31,9 80.10,77 2378,51 13,14 3,h20 2105,26 !064,73 2359,19 26,83 2124,7~ 1077.50 2382,34 26,89 2142,59 !090,39 2404,98 26,96 216i,82 1103.02 2426,96 27.03 2167,?L ~.107,16 2434.26 Z7,05 0.25 0,42 0.40 0.~3 1.~ 86b'7.41 35,2 83,"'5.3! 2386,43 13.02 33,61 2174,5! 1111.~0 2442,17 27,08 0.31 ~l'l:'AIf/ PRUI)HOE BAY I)RL~ ·'ELL ~ 1)$ 03-32/I LEEATION I I)RILLSITE 03 LOCATION 2 PRUL'flDE Bi1't ill( ~P.-N~ETIC DE~LII~TION 2~,70 OATE: 29-~R-94 ~LL ltII'iBER 3~ ~ ~ I.t~TION: I.AT(W-S) 0,00 IIE IN POI~(TIP): ~EA~UR~ ~PTH I~t'l UERT DEPTH F.~LI~TION qZII~J?H MTITUDE(H/-$) B~'ARTURE(E/-W) 7103,00 29.12 3%?7 1~26,11 AZIMUTH ~ ROTARY TABLE TO TARGET IE d~' deg lOOft 25,86 26,66 3,37 26,71 0.20 26.77 26,83 0.25 8403,75 ?4.9 78~8,64 2326,37 14,04 33.61 2124.70 .'.'077.63 2382.35 8497,61 93.9 7~'%'!,8 2349.11 14.11 35.13 2143,54 1090.52 2404.99 8590.36 92.8 90C9,7,1 2371.22 13.56 34.28 2161.77 1103.15 2426.97 8657.41 67.0 8374.-28 2386°57 13.02 33,61 2174,55 1111.76 2442.28 26.89 26.?6 0.40 27.04 0,63 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/3-32A 500292243501 NORTH SLOPE COMPUTATION DATE: 5/ 5/94 ORiGiNAL TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN DATE OF SURVEY: 050194 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-40042 KELLY BUSHING ELEV. = 53.25 FT. OPERATOR: ARCO ALASKA INC cOURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 7635 7103.00 7049.75 29 7 N 40.10 E .00 1926.11N 933.62E 7694 7155.71 7102.46 25 7 N 29.52 E 10.55 1948.09N 949.11E 7786 7240.84 7187.59 19 44 N 29.62 E 5.85 1978.66N 966.45E 7878 7328.43 7275.18 16 53 N 33.54 E 3.35 2003.39N 981.57E 7970 7416.68 7363.43 16 19 N 32.78 E .66 2025.44N 995.97E VERT. SECT. 2081.49 2108.31 2142.95 2171.66 2197.83 8064 7506.54 7453.29 14 56 N 31.50 E 1.53 2046.72N 1009.36E 8157 7596.78 7543.53 14 47 N 31.98 E .21 2067.09N 1021.96E 8251 7687.68 7634.43 14 34 N 31.60 E .25 2087.34N 1034.51E 8344 7778.32 7725.07 14 26 N 32.22 E .22 2107.25N 1046.91E 8437 7868.18 7814.93 14 10 N 33 .-27 E .40 2126,.53N 1059.30E 2222.78 2246.53 2270.14 2293.40 2316.17 8530 7958.15 7904.90 14 9 N 34.08 E .21 2145.44N 1071.90E 8624 8049.25 7996.00 13 23 N 33.59 E .82 2163.99N 1084.34E 8716 8139.11 8085.86 13 10 N 33.47 E .24 2181.69N 1096.07E 8807 8228.13 8174.88 12 17 N 33.15 E .98 2198.50N 1107.12E 8901 8320.07 8266.82 11 16 N 33.03 E 1.08 2214.57N 1117.59E 2338.78 2361.02 2382.13 2402.14 2421.21 8992 8409.53 8356.28 10 20 N 31.26 E 1.09 2229.02N 1126.69E 9087 8503.13 8449.88 9 26 N 29.00 E 1.03 2243.13N 1134.89E 9181 8595.68 8542.43 7 49 N 26.91 E 1.76 2255.52N 1141.49E 9272 8685.95 8632.70 7 55 N 25.56 E .23 .2266.71N 1147.01E 9364 8776.94 8723.69 7 46 N 24.98 E .19 2278.05N 1152.36E 2438.15 2454.26 2468.03 2480.19 2492.35 9456 8868.41 8815.16 7 48 N 23.58 E .21 2289.46N 1157.51E 9549 8960.59 8907.34 7 41 N 23.97 E .13 2300.95N 1162.57E 9581 8991.43 8938.18 7 36 N 23.80 E .30 2304.74N 1164.24E 9620 9030.09 8976.84 7 31 N 23.82 E .23 2309.,43N 1166.32E 9663 9072.72 9019.47 7 31 N 23.82 E .00 2314.58N 1168.59E 2504.43 2516.52 2520.52 2525.46 2530.89 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2592.85 FEET AT NORTH 26 DEG. 47 MIN. EAST AT MD = 9663 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 39.34 DEG. ,JUN ~ 6 1994 Oil & Gas Cons. Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/3-32A 500292243501 NORTH SLOPE COMPUTATION DATE: 5/ 5/94 DATE OF SURVEY: 050194 JOB NUMBER: AK-EI-40042 KELLY BUSHING ELEV. = 53.25 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 7635 7103.00 7049.75 8635 8059.64 8006.39 9635 9044.96 8991.71 9663 9072.72 9019.47 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1926.11 N 933.62 E 532.00 2166.06 N 1085.71 E 575.36 43.36 2311.23 N 1167.11 E 590.04 14.68 2314.58 N 1168.59 E 590.28 .24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING DATE OF SURVEY: 050194 PBU/3-32A 500292243501 JOB NUMBER: AK-EI-40042 NORTH SLOPE KELLY BUSHING ELEV. = 53.25 FT. COMPUTATION DATE: 5/ 5/94 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7635 7103.00 7049.75 1926.11 N 933.62 E 532.00 7691 7153.25 7100.00 1947.08 N 948.48 E 538.22 6.22 7799 7253.25 7200.00 1982.46 N 968.64 E 546.25 8.03 7904 7353.25 7300.00 2009.68 N 985.73 E 551.30 5.05 8008 7453.25 7400.00 2034.44 N 1001.77 E 555.56 4.26 8112 7553.25 7500.00 2057.34 N 1015.87 E 559.12 3.55 8215 7653.25 7600.00 2079.71 N 1029.82 E 562.53 3.42 8319 7753.25 7700.00 2101.79 N 1043.47 E , 565.85 3.31 8422 7853.25 7800.00 2123.38 N 1057.24 E 569.07 3.23 8525 7953.25 7900.00 2144.41 N 1071.21 E 572.21 3.14 8628 8053.25 8000.00 2164.79 N 1084.87 E 575.18 2.97 8731 8153.25 8100.00 2184.45 N 1097.89 E 577.92 2.74 8833 8253.25 8200.00 2203.08 N 1110.11 E 580.38 2.46 8935 8353.25 8300.00 2220.12 N 1121.19.E 582.43 2.05 9037 8453.25 8400.00 2235.83 N 1130.80 E 584.11 1.68 9138 8553.25 8500.00 '2250.33 N 1138.86 E 585.48 1.37 9239 8653.25 8600.00 2262.61 N 1145.05 E 586.42 .94 9340 8753.25 8700.00 2275.12 N 1151.00 E 587.38 .96 9441 8853.25 8800.00 2287.55 N 1156.67 E 588.30 .93 9542 8953.25 8900.00 2300.04 N 1162.16 E 589.23 .93 9643 9053.25 9000.00 2312.23 N 1167.55 E 590.12 .88 9663 9072.72 9019.47 2314.58 N 1168.59 E ,590.28 .17 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ? :~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C ' ISSION WELL COMPLEI'ION OR RECOMP LETION REPOFIT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ARCO Alaska,/nc." Ut'j ' ~''~ . ' * ' - 7.94-54Permit Number 3. Addressr~ I ~-~-~ II~¥~A L 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21141-01 4. Location of well at surface _J~__ 9. Unit or Lease Name 332' NSL, 796' EWL, SEC. 11, TI ON, R15E i~~ ; Prudhoe Bay Unit At Top Producing Interval i 10. Well Number 2599' NSL, 1943' EWL, SEC. 11, TION, R15E 3-32A I 11. Field and Pool At Total Depth EWL, 1, TION, j[~7- VF'r~'"IFIEO * Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 53.65' ! ADL 28327 12. Date SpUdded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore J16. No. of Completions 4/27/94 5/2/94 5/12/94I N/A leer MSL ~ One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey ~0. Depth where SSSV set ~21. Thickness of Permafrost / 9763' MD/9172' TVD 9688' MD/9097' TVD ,~s [] N~ [] 2192' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SEI'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 1925 # Polseset 13-3/8" 72# L-80 Surface 2514' 17-1/2" 24oo sx cs #1& 4oo sx cs ll 9-5/8" 47# L-80 Surface 7631' 12-1/4" 500 sx "G" & 300 sx CS I 7" 29# NT80/13CR 7441' 9763' 8-1/2" 285 sx 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 (MDI Gun Diameter 3-3/8" 4 spf MD TVD (SS) 5-1/2"x 4-1/2" 9106' 9043' 9322'-9348' 8675'-8700' ;~. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of OperatiOn (Flowing, gas lift, etc.) 5/13/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF tNATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure ;ALCULATED OIL-BBL GAS-MCF iNATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE !28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence el oil, gas or water. Submit core chips. ECEIVED JUN 1 6 1994 Alaska Oil & Gas Cons. Commission Anchorage :orm 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOL~ MARKERS ,-,~ ION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP'n-I TRUE VERT. DEPTH GOR. and time of each phase. Subsea Shublik 9252' 8606' Top Sadlerochit 9271' 8624' Zone 2 8834' 8832' RECEIVED JUN 1 6 1994 Atsska 0il & Gas Cons. Commission Anchorage 31, LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is lrue and correct Io the best of my knowledge Signed ~ Title Drilling ~-no_ineer Suoorvisor Date (~"/j° ~J 9 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: WELL: DS 3-32A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/21/94 08:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 04/22/94 ( 1) TD: 9979 PB: 9931 04/23/94 ( 2) TD: 9979 PB: 9931 04/24/94 ( 3) TD: 9979 PB: 9931 04/25/94 ( 4) TD: 9979 PB: 9931 NU BOPE MW: 8.5 Seawater MIRU. SET NEW DRAWWORKS TRACT. MOTOR ON RIG FLOOR THRU HOLE CUT IN WIND WALL. SPOT/SHIM RIG. SPOT TIGER TANK, DIKE SLOP TANK/CUTNG TANK. ACCEPT. @ 20:00 HRS 4/21. RU SURF LINES T/CIRC. TAKE ON SEAH20. DSPLCE FRZ PROTCT. F/ANNUL/TBG. SET TREE TEST PLUG. ND ADAPT. FLNG/X-MAS TREE. NU BOP STK. MU FISHING BHA MW: 8.5 Seawater NU BOP STK. TEST UPPER PIPE RAMS/BLIND RAMS/C & K LINES/VALVES/MANIFOLD/FLOOR VALVES T/250/5000. ANNUL T/250/2500. RU TBG PULLING & LUB. EQUIP. PULL TREE TEST PLUG/ RD LUB. MU LNDG JT.CBU. POOH LD COMP STRING. PULLED 179 JTS TBG. 34 REMAINING IN HOLE. BOP TEST LOWER RAMS/KELLY VALVES. CUT DL. SLIP ON NEW REEL. MU FISHING BHA. FISHING F/TBG MW: 8.5 Seawater RIH W/GRAPPLE T/PU 88 JTS. E DP. MU KELLY. WASH OVER FISH. POOH W/OS RECOVERED 4 JT SEVERE PITTING IS INDICATED ON TBG. MU 4" SPEAR/GRAPPLE ON 5" DP. T/TOF @7716. POOH-NO RECOVERY. MU 6" GRAPPLE/BHA & RIH F/FISH PU. RIH W/SECTION MILL MW: 8.5 KCl COMP. RIH W/SVERSHOT T/TOF. MU KELLY. W/O FISH & PU. POOH W/OVERSHOT. RECOVER 3 JTS. TBG. INCLUDING SPEAR. MU 9-5/8" BRIDGE PLUG. RIH ON 5" DP T/7815. SET PLUG. RU CIRC HD LINES. TEST BPV & CASG T/3500/10 MIN. 50 PSI PRESS LOSS. DISPLACED HOLE T/9.7 PPG MILLING FLUID, SPOTTED 50' 18PPG HI VIS PILL ON BTTM. POOH W/SETTING TOOL. LD EXCESS DC'S. PU SECTION MILL ASSY. MU BHA & RIH. RECEIVED JUN 1 6 1994 Amska Oil & Gas Cons. Commission Anchorage WELL : DS 3-32A OPERATION: RIG : DOYON 16 PAGE: 2 04/26/94 ( 5) TD: 9979 PB: 7815 04/27/94 ( 6) TD: 9979 PB: 7815 04/28/94 ( 7) TD: 7780 PB: 7815 04/29/94 ( 8) TD: 8715' ( o) POOH W/SECTION MILL MW: 9.7 KCl RIH W/SEC MILL T/6975. MU STORM PKR. MU PACK-OFF PULLING TOOL. BOLDS. RIH ENGAGE WELLHEAD PACK-OFF. COULDN'T PULL FREE. BACKED OUT ALL PKG GLANDS ON LOCK DOWN SCREWS. 1 SCREW BROKEN. ND BOP STK/BROKE CONNECTION @ BTTM. OF TBG. SPOOL. GROUND OFF END OF LOCK DOWN SCREW - PULL PACK OFF IN 1 PC. INSTALL REPLACEMENT PCKOFF. RILDS. NU BOP STK. TEST PACK-OFF TBG SPOOL BREAK T/4200. RAN TEST PLUG. /TEST BLIND RAMS,C&K LINES T/5000. PULL TEST PLUG. RAN WB. RETRIEVE STORM PAKR. LDSAME. RIH T/7631. INITIATED CUT. IN 30 MIN. WINDOW F/7631 T/7676. GOOD METAL RECOVERY. PUMP LO/HI VIS SWEEPS. CBU. CIRC HOLE CLEAN. JETTED FL. POOH W/SECTION MILL. RIH W/KO DRLG ASSY MW: 9.7 KCl POOH W/SECT. MILL. PU MIX SUB. RIH ON 5" DP T/7695, & 7766. 90' BELOW BTTM OF WINDOW. PU T/7735. CBU. METAL CUTGS ON RETURN. RIH T/7766 RIBJ SET 180 SX 17PPG G CMT PLUG F/7766 T/7431- 200' ABOVE TOW. CIP @ 13:12 HRS. POOH 10 STNDS. CBU CLOSE TOP PIPE RAMS HESIT.SQZ CMT IN .5BBLS INCREM. @ 5MIN INTRVLS AFTER 3BBLS PUMP T/840. EXCESS. BLEED OFF/ PRESS T/430. CHK SURF. EQUIP. ISOLATE WELLBORE/PUMP OVER INTRVLS & CON'T T/SQZ. STOP AFTER 8.4 BBLS 114' VOL IN 9-5/8" 47 PPF CASG PUMPED. LD 41 JTS DP. POOH W/MIX SUB. CHANGE LINERS T/6.5. CLEAN BOPE. TEST STK T/5000. MU 8.5 PDC BIT T/KO BHA. SURF TEST SMM/MWD. RIH.SLM. DRILLING DIRCT. HOLE MW: 9.7 KCl COMP RIH W/KO. DRILL BHA T/7332. MU KELLY, SINGLED IN F/7332 T/TOC @ 7631,TOW. ORIENTED/TIME DRLG SMM/SURV. MWD/ 8.5 HOLE F/7631 T/7677. DRLG DIRECTIONAL HOLE T/7677 T/7717. CBU CLEAN MUD PITS. DISPLACE WELL TO GEL FREE MUD. ORIENTED/DRILL & SURV. T/7780. DRILLING MW: 9.6 VIS: 44 ORIENTED/ DRILLED & SURVEYED 8.5" HOLE F/7780 T/7997. CBU. MADE SHORT TRIP T/7578. NO WINDOW OBSTRUCTUON. HOLE & WINDOW OK. DRILL/SURV/DIRCT'L HOLE F/7780 T/8715. AVG ROP=77.3 FPH. AVG. ROP SLIDING =23.9 FPH. RECEIVED JUN 1 6 1994 Alsska Oit & Gas Cons, Commission Anchorage WELL : DS 3-32A OPERATION: RIG : DOYON 16 PAGE: 04/30/94 (9) TD: 9080'( 365) 05/01/94 (10) TD: 9594'( 514) 05/02/94 (11) TD: 9731' ( 137) 05/03/94 (12) TD: 9763 PB: 0 05/04/94 (13) TD: 9763 PB: 9684 DRILLING MW: 9.7 VIS: 42 WORKED BIT T/BTTM. NO PROGRESS W/PDC BIT. ROP REDUCED. CBU. DROPPED DUAL SINGLE SHOT SURV. F/CHECK SHOT. POOH F/BIT/BHA CHANGE. LD SMM, MWD BHA. RECOVER SURV. HOLE GOOD. RAN TEST PLUG. TEST RAMS, PRESS C&K LINES/VALVES/MANIFOLD T/250/5000. ANNUL, T/250/2500. BOPE T/5000. SLIP & CUT DL. PU 8.5 LONG INSERT BIT. MU LOCKED UP BHA. RIH T/BTTM. HOLE OK. DRLG 8.5 HOLE T/9080. RIH W/BIT MW: 9.7 VIS: 44 DRLG T/9175. CBU. DROP DUAL SS SURV. POOH T/SHOE ON SHORT TRIP. HOLE & WINDOW OK. RECOVEREC SURV. ON SLICK LINE. SURV. RIH T/BTTM @ 9175. HOLE GOOD. DRLG 8.5 HOLE T/9594. ROP DROPPED T/10FPH. CBU. POOH F/BIT CHANGE. HOLE OK. PU NEW INSERT BIT. MU BHA. RIH. DRILLING MW: 9.7 VIS: 45 RIH W/NEW BIT T/BTTM @ 9594. HOLE GOOD. DRILLED T/9663. CBU. POOH T/LOG. RECOVERED ESS SURV. RU ATLAS WL. SONIC TOOL FAILED. RERAN W/GR. RD ATLAS. AFTER LOG EVAL. DETERMINED T/PROCEED 100'ADDT'L TVD. MU RR3 BIT & RIH T/9663. HOLE OK. DRILL T/9731. CMT. 7" LINER MW: 9.9 KCl ROT. DRILL F/9731 T/REVISED TD @ 9763. CBU. POOH T/RUN LINER LD EXCESS BHA COMPONENTS. NO FURTHER LOGGING NEEDED. RU CASG EQUIP . RAN 21 JTS 7" 29 PPF 13CR80 R3 CASG FOLLOWED W/MARKER JT/36 JTS 7" CASG. CHKD FLOATS AFTER PU.OK. MU LINER HNGR/PCKR/C-2 TIE BACK SLEEVE ASSY. RIH ON 1 STND 5" DP. CIRC LINER VOL. RIH LINER ON 5" DP T/9763. HOLE OK. WASHED DOWN LAST STD. CBU AT 10 BPM. CIRC WHILE COMP. BATCH MIX CMT SLURRY. CMT LINER IN PLACE. POOH LD 5" DP MW: 8.5 Seawater CONP. LINER CMT. JOB. CIP @0615. SHOE/9763;LC/9684. POOH W/RT. LD 5" DP. RIH LD 6.25 BHA. RU 6" RR BIT. MU 7" CASG SCRPR, RIH PU 4.75 DC'S, 3.5" DP. RIH ON 5" DP T/TOC @9630. CO HARD CMT F/9630 T/LC @9684. CBU. TEST LINER LAP/CASG T/3500. 50PSI BLEED OFF IN 30 MIN. COMP. CLEANING MUD PITS. DISPLACE HOLE T/SEAH20. BROKE KELLY. POH LD 5" DP. Gas Cons. Commission Anchorage WELL : DS 3-32A OPERATION: RIG : DOYON 16 PAGE: 4 05/05/94 (14) TD: 9763 PB: 9684 05/06/94 (15) TD: 9763 PB: 9684 ND'BOPE MW: 8.5 Seawater TRIP OUT L/D 5" DP. STAND BACK 3.5" DP. L/D 4.25" DCS. TEST CSG. RIG UP WEATHERFORD CSG. TOOLS. RUNNING 4.5 & 5.5" CR-13 80 COMPLETION STRING. P/U CAMCO SSSV M/U CONTROL LINES. TEST. P/U AND RUNNING 5.5 COMPLETION STRING. P/U HANGER M/U CONTROL LINES AND TEST. LAND TBG, DROP BALL. INSTALL BPV. NIPPLE DOWN BOPE. RELEASE RIG MW: 8.5 Seawater NIPPLE DOWN BOPE. NIPPLE UP ADAPTER FLG & TREE. TEST CONTROL LINES, TEST TREE. PULL TEST PLUG. SET PACKER. TESTED ANNULUS. SET BPV. RIG DOWN LINES TO TREE. CLEAN CELLAR & PITS. P/U CELLAR AREA. MOVE RIG OFF WELL. PICK UP MATTS, SAVE HERCULITE, CLEAN UP LOCATION. RELEASED RIG @1900 HRS ON 05/05/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED JUN '1 6 1994 Aisska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: From/Location- Telephone: To/Location: May 24, 1994 P.O. Box 10036q.-,~orage, AK Transmittal #: 94043 ARCO Static Pressure Surveys John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well I Number 2-6 3'32A I4-5A 6-16 ~ 17'094 7-o5 Log Date (M-D-Y) 03-03-94 05-13-94 05-18-94 05-13-94 03-06-94 04-01-94 03-23-94 03-24-94 03-24-94 03-24-94 03-23-94 Tool Type { Run, . Scale Static Pressure { 1 5" Static Pressure Static Pressure Static Pressure Static Pressure Contractor ! 1 5" f 1 5" i 1 5" l 1 5" ! 1 5" i 1 5" Sch Sch Static Pressure Static Pressure Sch Static Pressure Sch Static Pressure ! 1, 5" Static Pressure i 1, 5" Static Pressure i 1, 5" Sch Sch Sch Sch Sch Sch Sch Number of RecOrds: 11 John E. DeGrey Distribution: Central Files -Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M Please acknov~ledge receipt by signing and returning a copy of transmittal. By: ..../¢'t~'C/~6L~I Date: t - ARCO Alaska, Inc. !s a Subsidiary of AtlanlicRIchfleldCompany ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: May 23, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution P.O. Box 100360, ~orage, 94O38 AK Well ' Log Date Tool Type i Run, ScaleI Contractor Number i (M-D-Y) -7~'/~ 1-10 05-10-94 ~/~ Collar Log i 1,5" Atlas i~'-~Z. 3-19 ~04-24-94 ~/ CollarLog i 1,5" Atlas 3-24 l 05-10-94 q'~ CollarLog ~ 1, 5" Atlas ii'ct W 3-~ 05-01-94 V~ Dual Laterolocj I I 2"&5" Atlas 3-32A 05-01-94 v/' BHCA/GR ~ 1, 2"&5" Atlas 3-32A 05-01-94 iV CNL/GR 1,2"&5" Atlas 3-32A 05-01-94 vf SSTVD 1, Atlas 1 "&2"&5" 4-5A- I 5-5-94 v~PFC/GR/Collor 1,5" Atlas 4-5A 5-3-94 ~/' SSTVD i 1, 1"&2" Atlas ~;~o 4-5A f 5-3-94 ~ 1, 2"&5" Atlas l Y' Borehole Prof \ 4-5A 5-3-94 t,/f CNL/GR i 1, 2"&5" Atlas '\\11 4-5A 5-3-94 lv"DuaiLaterolo~ i 1, 2"&5" Atlas 4-5A 5-3-94 J,/ BHCA/GR I 1, 2"&5" Atlas 11-29 04-27-94 ~/IWD:TVD/GRC,i 1, 2"&5" Sperry 5'7- v'. EWR,FXE 11-29 04-27-94 .~WD:MD/GRC, l 1, 2"&5" Sperry .v EWR,FXEI. 11-36 05-08-94 v/ Borehole Prof I 1, 2" Atlas [o(~ 11-36 5-8-94 v" SSTVD~ 1; 2'&5" Atlas 11-36 5-8-94 v' DIFL./GR/SP 1, 2"&5" Atlas \ 11-36 05-08-94 ,/ Z-Densilo~ 1, 2"&5" Atlas 15-32 03-25-94 ,,J~/IWD:TVD/DGR, 1-13, 2"&5" Sperry "CNP,DSFD ~ 15-32 04-25-94 ./MWD:MD/DGR, 1-13, 2"&5" Sperry "EWR~FXE 15-32 04-25-94 ~IWD:TVD/DGR, 1-13, 2"&5" Sperry v EWR,FXE I 15-32 03-35-94 ,/MWD:MD/DGR, 1-13, 2"&5" Sperry vCNP, DSFD * 15-32 05-04-94 V~limhole Section / Sperry ~LI* /i 15-33 05-04-94 VSlimhole Section! 1-13, 2"&5" Sperry '~ 15-33.f 03-29-94_~/_MWD:MD/DGR !1-20, 2"&5" Sperry , 17-19 I 04-01-94 !,/ CollarLo~] ! 1, 5" Atlas * Includes diskette Number of Records: 27 ARCO Alaska, Inc.. Is a Subsi(lary of AtlantlcRIchfleldCompany '~,Ci~ora~' Coeei~$1o~ ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~'~age, May 24, 1994 Transmittal #: ARCO open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94041 AK IWell 'i Log Date Tape Type · Number (M-D-Y) , I 03'32A ! 05'01'94 i~'C/GR & DLL/cN/GR !v 4CAL/GR 9- 03-06-94 34APH i !Dv'~j'L/AC/CN/G R 11-04A !03-01-94 !,~)LL/ZDL/CN/GR 11-35 ! 5-19-94 !`/. ZDL/CN i 11-36 l 05-08-94 ?'DIFL/ZDL/CN/GR i 12'13AI 03'31'94! i Dv~I-L/AC/CN/GR i 15'34 I05'16'941,,~L/ZDL/CN/GR Run, Footage 11786- 12637 Contractor i Atlas 9200-9654 Atlas 8250- 10292 9120- 11658 8410-9341 8670-9471 9300-9969 8607- 10380 1,9971- 8767 10560- 11282 .1,9635- 7999 Atlas Atlas Atlas Atlas Atlas Atlas Sch Sch Sch Number of Records: 11 · DeGrey Distribution: Bob Ocanas Phillips BPX Exxon ~S t'~"t~;O f :Ai'~k~ Please acknow~dge receipt by signing and returning a copy of transmittal. By: ~.~/,, /~/,~_ _ Date: ~. ~ ¢" r" ~ ~./E ~ ,'-_ ,,.. E; L Alaska Oil & Gas Cons. Commission Anchorage ARCO AlasKa, In,3. I$ a Subt, ldlary of AtlantlcRichflaldCompany ARCO Alaska, Inc. Date: May 24, 1994 P.O. Box 100360, ~°rage,? AK Transmittal #: 94040 99510 Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Nu~er Well ~e Tool ~ Run, ~-Log Type Con~or (M-D-Y) S~ ~ ow~W-~w ~'=~'~ ~ ~s ~, ~" sc. 1-9A 5-14-94 ~ ~Ped R~ 1, 5" SCH 1-20 5-7-94 ~ Peal R~ 1, 5" SCH 2-4 5-11-94 ~ Prod Prof 1, 5" SCH 2-4 5-11-94 ~ CNL 1, 5" SCH 5" SCH 2-5 5-7-94 ~ Prod Prof 1~ 5" ~-~o .-~0-.. ~ P~o~ P,o~ .~, ~"SCH 3-19 4-4-94 ~. Brid~e PIu~ 1, 5" SCH Brid~e Plu~ 1 5" SCH 3-32A 5-9-94 ~SIT (Cern & Coif) ~ 1, 5" , SCH . 3-32A ~ 5-12-94 ~ PedR~ j 1, 5" SCH 4-5A ~ 5-17-944 ~ PedR~ ~ 1, 5" SCH 4-5A ~ 5-17-94 ~ USIT 1, 5" SCH 5-6 4-30-94 ~ Prod Pmf 1~ 5" SCH 5-35 5-3-94 / TDT-P 1.5" SCH 6-10 4-5-94 / Leak Det~t · 1.5" SCH 6-11 5-14-94 ~acker Set R~ 1.5" SCH 6-22A 5-14-94 ¢ Pe~R~ 1~ 5" SCH 7-3 5-8-94 Prod Pmf 1~ 5" SCH 7-3 5-7-04 ~ Peff R~ 1~ 5" SCH 7-23 5-10-94 ~Jewel~ Set R~ 1.5" SCH 7-23 5-15-94 ~ompletion R~ 1.5" SCH 9-13 5-16-94 /.Bdd9e Plug 1.5" SCH 9-26 4-6-94 ~ Pe~ R~ 1.5" SCH 9-42 5-15-94 ~ Leak Det~t ' 1, 1" 2" 5" SCH 9-47 5-16-94 V Packer Set R~ 1~ 5" SCH 11-36 5-18-94 ~ USIT 1, 5" SCH 12-8B ~ 5-4-94 ~ Prod Prof 1, 1" 5" SCH 13-8 ~ 5-2-94 ~ InjPmf 1, 5" SCH 13-31 ~ 5-2-94 ~ USIT 1, 5" SCH ~3-3s ~ S-lO-94 ~ usam~1, s"SCH 14-41 ! 5-8-94 ~ual BumTDT-P 1, 5" SCH 16-26 5-6-94 ~ Pe~R~ 1, 5" SCH 17-19 5-12-94 ~ Peal R~ ~ 1, 5" SCH 18-1 5'1~ ~ Pe, R~ ARCO Alaska, Inc. la a ~13Mgllary of AtlmltlcRlclfflM~ Memorandum State of Alaska Oil and Gas Conservation Commission To: DS 3-32A Well File April 7, 1994 Permit # 94-54 ,~ J. Hartz ~~ Cement Material For Kick Off Plug Fm~ Subj: Dan Stolz of the PBU Shared Service Drilling Group has informed me that they want to try bla~st furnace slag (BFS) cementing material instead of class G cemen~_..t in the kick off plug the sid/~irac~ell DS 3-32A. Physical composition' and properties are similar to cement and design criteria such as compressive strength, viscosity, thickening time, density, and water loss are controlled with additives in the same way as cement materials. BFS may also be used in drilling mud to control fluid loss and then be converted to a cement material by activating the fluid with chemicals or heat. Shell has done research and field work demonstrating the universal application of BFS to drilling and cementing operations. Hal_[iburton, Baroid and BJ Services are working with Shared Services personnel to apply the process to North Slope wells. Potential saving will be achieved by less drilling fluid treatment costs to clean up cement contaminated mud, less mud wasted after cement contamination and less drilling mud to be disposed at the end of each well. Evaluation of the BFS plug will occur when it is tested. The normal test is to apply weight to the plug and then upon passing, polish the plug and drill out of the casing for the sidetrack. Failure of the plug would be indicated by inability to bear weight or drill out of the casing. Either failure would require setting another kick off plug and starting again. The attached diagram shows the schematic of the plug and sidetrack. The sidetrack liner will be packed off in the casing above the window and will be cemented (50% excess) which will provide additional isolation. The environmental and operational cost savings make this effort worthy of our support. I have two technical papers documenting research and field applications of this material and process if interested. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 7, 1994 Terry Jordan, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 3-32A ARCO Alaska Inc 94-54 332'NSL, 4484'WEL, Sec 11, T10N, R15E, UM 2702'NSL, 3177'WEL, Sec 11, T10N, R15E, UM Dear Mr Jordan: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-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 a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North SlOpe pager at 659-3607. Y Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ~) printed on recycled paper b y C. ~. ' / STATE OF ALASKA ~ ALASKA UlL AND GAS CONSERVATION C ' ISSION PERMIT TO DRILL 20 AAC 25.005 :ia. Type of work Drill [] Redrill E'lllb. Type of well. Exploratoryl-! Stratigraphic Test r"i Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool _ARCO Alaska, Inc. KBE = 53.3' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28327 4. Location of well at surface 7. Unit or property Name 11. Type Bond(=es 20 ~,c 25.025) 332' NSL, 4484' WEL, SEC. 11, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2702'NSL, 3177' WEL, SEC. 11, TION, R15E 3-32A U-630610 At total depth 9. Approximate spud date Amount 2702' NSL, 3177' WEL, SEC. 11, TION, R15E 4/10/94 $200,000.00 ~2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and mVD) property line . ,~DL 28332-2702' feet No close approach feet 2560 9824' MD/9164' TVD feet -- 16. To be completed for deviated wells 17. Anticipated pressure (=ce 20 AAC 25.035 (e)(2)) Kickoff depth eeoc feet Maximum hole angle2~.69 o Maximum surface 3330 pslg At total depth-(TVO) 8800'/4390 pslg 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" 29# L-80 NSCC 511' 8650' 8009' 9161' 8502' 8-1/2" 7" 29# CR80 NSCC i 663' 9161' 8502' 9824' 9164' 210 sx Class "G" .. 19. To be completed for Redrill, Re-entry, and Deepen OPerations. R E C Present well condition summary Total depth: measured 9980 feet Plugs (measured) true vertical 9259 feetAPR -6 1994 Effective depth: measured 9843 feet Junk (measured) Alaska 0il & Gas Cons. Commission true vertical 9128 feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural rend uctor 80' 20" 1925 # Poleset 80' 80' Surface 2514' 13-3/8" 2400 sx CS III & 2514' 2514' Intermediate 400 sx CS II P rod uction 9832' 9-5/8" 5o0 sx'G'/'J~ sx cs ~ 9382' 9689' Liner 9979' 7" 300 sx Class "G" 9979' 9245' Perforation depth: measured 9383'-9426', 9441'-9481', 9502'-9510', 9524'-9534; 9550'-9558', 9576'-9584', 9619'-9623', 9672'-9676', 9700'-9710' true vertical ~6~o'.873o', 8744'-a781', 8801'.8808; 8827'-8836', 8851'.8859', 8876'.a883', a915'.8919', 8964'.a96a', 8991'.8998' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report• 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~f~// ~ Title Drilling Engineer Supervisor Date v Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ?P'-,5'5" 15°-~ ?- .7_./? ~,/'-~ ! I ~'~- '~- ~ Jfor other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~reo J~l Yes I-1 No Required working pr~j~lf,~§EByl-12M; 1-13M; llllSM; r-ll0M; I-I15M; Other: ;'~av;O W. Johnston by order of ,Approved by Commissioner tne commission Date'S- Form 10-401 Rev. 12-1-85 Submit in triplicafi BP EXPLORATION SUBJECT ENGINEERING DATA SHEET NO BASED ON ENGINEER DEPT. APP'VL DATE BUDGETIAFE NO. FILE NO. J AK 2337-1 (10/93) I WellName: IDS 3-32A Redrill Plan Summary I Type of Redrili (producer or injector): I Producer Surface Location: 1 332 FSL, 4484 FEL, SI 1, T10N, R15E Target Location: I 2702 FSL, 3177 FEL, Sll, T10N, R15E UM I Bottom Hole Location: 2702 FSL, 3177 FEL, S 11 T10N, R15E, UM I AFE Number: 14J8022 I I Estimated Start Date: 104/10/94 IMD: 19824' I I Well Design (conventional, slimhole, etc.): I conventional I Rig: I Doyon #16 I I Operating days to complete: I 12 I TVD: 19164' rkb I I~cgE: 153.3' Objective: I Replace well integrity by replacing corroded tubing with chrome tubing and to I optimize perforating strategy with open hole logs. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. I Special design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 5 0 8 Directional: I KOP: [ 8,800' MD ImaximumCiose ApproachH°le Angle:Well: [ 21.69NoNEde~rees (sidetrack portion) The above listed wells will be secured during the close approach. RECEIVED Redrill Plan Summary APR -6 1994 Alaska Oil & Gas Cons. Comnlt~l Anchorage Casin bin,, ram: .... Hole Siz~ Csg/ '-Wt/Ft- Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# L-80 NSCC 511 8650/8009 9161/8502 8.5" 7" 299 Cr80 NSCC 663 9161/8502 9824/9164 Cement Calculations: I Liner Size: I I Basis:] 20% open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: 210 sxs of Class G Blend @ 1.17 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Red_rill Plan Summary RE¢£1V£D Alas~ Oil & Gas Cons. Commissio. Anchorage Page 2 DS 3-32A INFORMATION Objective The tubing in well 3-32 is severly corroded with four .known holes. This sidetrack will restore tubing integrity to the well. Also, an improved perforation strategy may be realized from the open hole logs obtained during sidetrack operations. 1) P & A existing well per state regulations. 2) Pull existing 5-1/2" tubing. 3) Mill window in 9 5/8" casing. 4) Set kickoff plug and drill 8 1/2" hole to TD. 5) Run OH logs, GR/BHCS/DLL/CNL. 6) Cement 7" chrome liner in place. 7) Run 5-1/2" x 4-1/2" chrome tubing completion. Doyon #16 will be making a well to well move from well DS 3-02 to DS 3-32A on or about April 10, 1994. A?P, - 6 1994 0il & Gas Cons. Comm%ssio~ Anchorage Redrill Plan Summary Page 3 . . . . . . 10. 11. 12. 13. DS3-32A APR -6 1994 SUMMARY PROCEDURE Alaska 0ii & Gas Cons. Commission Anchorage Pre-rig worE: Comp]em pre-rig annular communications diagnostics and packoff test to evaluate the presence or absence of annular communication. Kill we]]. Lay cement plug across perforations to at ]east 100' above top perforation (upper most perfs are at 9383' md). Freeze protect. MIRU workover rig. Send out rig move notification form 72 hfs in advance of rig move. Pull BPV. Circulate out freeze protection fluid. Insure packoff has been tested to 5000 psi. If not, have Drill Site Maintenance test packoff. Set BPV. ND tree and tubing head adapter. NU BOP's. Install tree test plug. Test BOP's to 5000 psi. Test annular to 250/2500 psi. Pull tree test plug and BPV. Note AOGCC witness of waiver on the morning report. Pull and lay down 5-1/2" tubing. Note on the morning report the visual condition of the tubing. Test the 9-5/8" casing to 3500 psi for ten minutes. Replace packoff if pre-rig PPPOT failed. RIH with a 9-5/8" section mill and displace well to Biozan milling fluid - spot 18 ppg hi- vis pill from prodution packer top at 9137' md to base of proposed 9-5/8" section. Cut a 45' section in the 9-5/8" casing starting at +8795' md. RIH with open-ended DP. Mix and pump a minimum of ~ sack: ofacement to spot balanced kick-off plug from 100' below the base of the section to 20fi'above the top of the section. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below the top of section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" directional assembly to total depth of 9524' md/9164' tvd rkb. Multi- Shot survey w/Sperry-Sun ESS on final trip out of the hole for AOGCC survey requirements. RU Atlas wireline and log with GPUCNL/DLL/BHCS. Log from TD to +100' above the top of the Sag River. If hole conditions dictate - the logging sonde length may be reduced and two logging runs may be used. Upon completion of logging, make wiper trip prior to running 7" liner. If hole conditions are good and minimal logging time was required, a wiper trip may not be needed. Note; If an extended period of time was needed to reach TD, a four arm caliper log may be run to calculate hole size for a more accurate cement volume. Caution should be used while running this tool because of the extra length (18') it adds to the logging sonde. Run 7" 29# 13CR80 NSCC x 7" 29# L-80 NSCC standard liner assembly to TD with liner top packer and +150' lap. XO to 7" 29# L80 liner +300' md above top of Redrill Plan Summary Page 4 14. 15. 16. 17. 18. 19. 20. 21. Sadlerochit. Liner too packer and hanger assembly lire to De plain 4140 _erade carbon steel. Note: To ensure the 9-5/8" x 7" liner top packer is fully sheared and set, pressure up to 4200 psi when setting. Cement liner with the standard sidetrack liner cement blend noted in the "Recommended Sidetrack Practice Version 3.0". L/D extra 5" DP that will not be required for clean out run. Clean out finer to PBTD and test to 3500 psi. Change over to clean inhibited seawater. Test to 3500 psi for 30 minutes. RIH with 5-1/2" x 4-1/2", 12,Or 13 Cr80 comPletion string w/7" x 4-1/2" packer positioned +_200' md above top of Sadlerochit. M/U 5-1/2" tubing hanger - test SSSV lines to 5000 psi for 10 mins. Orient SSSV balance line towards reserve pit. Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adapter and 5" tree. Test control lines to 5000 psi. Test 5" tree and adapter to 5000 psi. Pull the test plug with a lubricator. Pressure up on the tubing to 4000 psi to set the production packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. Bleed off tubing pressure to +1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing pressure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2200' tvd. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by the PE's in the WOA or Drill Site Maintenance in the EOA. A potential gas source nearby will be required- high GOR well or artificial gas lift line. i~\ss?,a Oil & GaS Cons. £ommiss'to~ Redrill Plan Summary Page 5 i-ll-ll~.--f_.~--j.~j.g- m~,¢ rllUl'l gl(ICH I I--HI~iJ, J/Hr'iHJ,jlKIi-i-- ii Illl I '~ PRUBHOE BAY OR]: Marker Identification A] TIE-IN B] END OF 6/I00 DROP C] ....... TARGET ....... O) TO MD BKB SECTN INCLN 8800 8~49 2588 2].89 glB! 8502 2656 0.00 9337 8677 2656 0.00 9824 9164 2656 O.O0 I t~ r'J3&) r_lNi. J J, INr=.r"[%,-~ r · _LINGGROUP ' ii i i i ii i ] ii i i · I ii DS 03-32A (P.3) VERTICAL SECTION VIEW · i ii i Section at: 39.84 TVD Scale.' I inch = 200 feet · i i Dep Sca]e.' 1 inch -- 200 feet " J ~naYr:]] SC~]umaerger [- , m m , M3S~a u- ~'G~ ~ons. Col An~O~age 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 Section Departure ~n~ori]] (c)93 033~F3 B.1,52 2:40 P~ Jj ~ ~nA ~ z;;~ zg, ug I-IKUI'I C1K~H I I_HI~IJ/HI'IPIJJI~LI-- I U r~ r--I~I.I~I~F--F--I~ PNUDHOE BAY DRILLING GROUP DS 03-32A (P3) PLAN V]EN n CLOSURE .... ' 2706 feet at Azimuth 28.81 DECLINATION.: 30.000 E SCALE ' ~ inch = ~00 feet DRAWN.,, ' 03/22/94 m ~lnadri ll Schlumberger Harker IOenti f~cetion MD N/S ~) TIE-IN 8BO0 2319 §) END OF G/lO0 DROP 9161 2371 C) ....... TARGET ....... 9337 237! D) TD g824 2371 E/W 126t 1304 1304 .1304 I 900 950 1000 JO50 1300 EAST -> I150 t200 ~250 1300 ~3§0 t400 t450 1500' J550 I600 '; STATE OF ALASKA A _J OIL AND GAS CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend _ , , Operation Shutdown Alter casing .... Repair well Change approved program .... Plugging ..)L_ Time extension Pull tubing_ Vadance Re-enter suspended well .,. Stimulate .... Perforate Oilier X Plugb&ck Ior redrill 6. Datum elevation (DF or KB) RKB = 62' feet 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 332'NSL, 76'EWL, SEC. 11, TION, R15E At top of productive interval 2487' SNL, 2196'EWL, SEC. 11, TION, R15E At effective depth 2385' SNL, 2306' EWL, SEC. 11, TION, R15E At total depth 2354'SNL, 2339'EWL, SEC. 11, TION, R15E 5. Type of Well: Development X Exploratory __ Stratigraphic Service RECEIVED APR -5 1994. u, & Gas Cons. Commiss! t L chorage ' 12. Present well condition summary Total depth: measured true vertical 9980 feet Plugs (measured) 9259 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 3-32 9. Permit number 84-107 10. APl number 50- 029-21141 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth: measured true vertical 9843 feet Junk (measured) 9128 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 20" 1925 # Poleset 80' 80' 2514' la.3/s' 2400 SX CS I/I/400 $X CS II 2514' 2514' 9832' 9-5/8" SOO $x 'G'mOO sx CS I 9382' 9689' 9979' 7" 300 sx C/ass "G" 9979' 9245' measured 9383'-9426', 9441'-9481', 9502'-9510', 9524'-9534', 9550'-9558', 9576'-9584', 9619'-9623', 9672'-9676', 9700'-9710' true vertical 8690'-8730', 8744'-8781', 8801'-8808', 8827'-8836; 8851 '-8859', 8876'-8883', 8915'-8919', 8964'-8968', 8991 '-8998' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9148'MD;4-1/2", 12.6#, L-80, PCT tail @ 9245'MD Packers and SSSV (type and measured depth) BOT 3-H pkr @ 9137' MD;5-1/2" Otis ROM SSSV @ 2197'MD 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 4/8/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Fo~ 7-. ~'~rol~,n Title Dri/ling EngineerSupervisor Conditions of approval: Notify Commission so repreSentative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- r,/r~ ~ Original Signed By Approved by order of the CommissionFiRVid W, J0,hnst0n Form 10-403 Rev 06/15/88 i Appr°va' O ... Approved Copy Returned Commissioner Date ~'~'f',~/7 ~ SUBMIT {N ThlPLICATE IIADMINISTRATION II 1. Permit fee attached ................... II 2. Lease number appropriate ................ I~ 3. Unique well name and number .............. II 4. Well looated in a defined pool. II 5. Well located proper distance from drlg unit boundary. II ,=o,.r ro. ..... II - 8. If deviated, is wellbore plat included ........ II .9. Operator only aff.ct.d p~ty .............. II 10. Operator has appropriate bond in force ......... II ~- ~-~*~ :-" ~' ,..u.~ w,~ou~ oo--~.~,o, or~.= .... ~ D~ 12. Pe~it can be issued without a~inistrative approval. ENGI~ERIN~ UNIT# ~,~o~sm,~: exp [] der ~ r~rll.JH serv [] /) ~$~ o~/o~ .~o~ o~J 15. Surface casing protects all known USDWs ......... 16. CM~vol adequate to circulate on conductor & surf csg. 17. CM~ vol adequate to tie-in long string to surf csg . . 18. CMTwi11 cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22.' Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic& equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~' psig.~, 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY APPR D 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Da~a presented on potential overpressure zones ..... Y ~/ ~ 32. Seismic analysis 9f shallow gas zones .......... Y//N //~/~% 33. Seabed condition survey (if off-shore) ......... y N 34. Contact name/phone for weekly progress reports .... /Y N [explora~only] GEOLOG"f: ENGINEERINg: COMMISSION: DW=~ C~men~s/Instruotions: HOW/jo - A:~FORMS~cheldist rev 03/94 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 simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ., No special 'effort has been made to chronologically organize this category of information. O ALASKA INC D.S. 3 - 32A PRUDHOE BAY Run 1' 01 - May - 1994 AC/~R DLL/~N/GR 9200 9654 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: OWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6193.00 J. DAHL SEE REMARKS REMARKS: D.S. 3 - 32A 500292114101 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 05-MAY-94 OPEN HOLE RUN 2 RUN 3 11 i0N 15E 332 4484 53.20 53.20 28.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7631.0 8.500 9663.0 AC/GR & DLL/CN/GR. LOGS WITNESSED BY: T. CAHALANE & B. CAMPBELL. CIRCULATION STOPPED AT 13: 45, 01-MAY-94. NO AC REPEAT SECTION RECORDED PER CLIENT'S REQUEST. NOTE AC CYCLE SKIP AT 9434 - 9436'. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, 8.5" BOREHOLE CORRECTION, CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9201.0 9631.0 9201.0 9654.0 all runs merged; no GR 9205.0 DLL 9205.0 2435 9205.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH 9199.0 9209.5 9215.5 9223.0 9223.0 9223.0 9223.5 9238.5 9238.5 9250.5 9250.0 9250.5 9253.5 9254.0 9255.5 9255.5 9256.0 9256.5 9258.0 9258.0 9258.0 9259.5 9259.5 9261.5 9261.5 9261.5 9592.0 9624.0 9598.0 GR from AC TOOL STRING. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH DT GRI LL3 NPHI 9199.0 9199.0 9199.0 9199.0 9209.0 9215.5 9264.5 9270.0 9270.5 9274.5 9274.5 9288.5 9288.5 9289.0 9308.0 9308.5 9308.5 9308.5 9309.0 9311.0 9314.5 9315.0 9319.5 9320.0 9320.0 9320.5 9331.0 9334.5 9334.5 9335.0 9344.0 9344.0 9344.5 9344.5 9348.5 9349.0 9360.0 9360.5 9360.0 9362.5 9362.5 9363.0 9364.5 9364.5 9366.5 9371.0 9371.0 9374.0 9374.0 9374.5 9375.0 9385.5 9385.0 9386.0 9389.0 9224.0 9250.5 9255.5 9255.5 9258.5 9261.5 9261.5 9264.5 9288.0 9310.0 9318.5 9333.0 9343.0 9358.5 9309.5 9321.0 9331.5 9367.0 9388.5 9393.0 9394.0 9399.0 9399.5 9424.5 9431.5 9439.5 9445.5 9446.0 9457.5 9461.5 9473.0 9476.5 9486.0 9489.0 9491.0 9512.5 9539.0 9540.5 9550.5 9552.5 9564.0 9569.5 9570.0 9570.5 9573.0 9575.0 9575.5 9577.0 9577.5 9579.5 9583.5 9587.5 9592.5 9593.0 9600.5 9607.5 9620.5 9674.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS 9393.0 9394.5 9399.5 9432.0 9446.0 9446.5 9461.0 9462.0 9487.0 9486.5 9489.0 9491.5 9539.5 9541.0 9550.5 9553.0 9564.5 9570.0 9571.0 9574.0 9576.5 9578.0 9580.0 9583.5 9584.5 9588.5 9592.5 9601.0 9674.0 9674.0 RUN NO. PASS NO. 1 5 1 5 9399.0 9439.5 9445.5 9473.5 9491.5 9570.0 9575.5 9584.0 9593.5 9608.5 9620.0 9674.0 9399.0 9425.0 9445.5 9458.0 9477.5 9512.0 9578.0 9584.0 9593.0 9674.0 MERGE TOP MERGE BASE 9201.0 9631.0 9201.0 9654.0 GR DLL 2435 $ REMARKS: 1 2 9205.0 9592.0 1 2 9205.0 9624.0 1 2 9205.0 9598.0 MERGED MAIN PASS. "GRI" REFERS TO GAMMA RAY FROM DLL/CN TOOL STRING. MTEM, TEND, & TENS (from AC TOOL STRING) WERE SHIFTED WITH DT. LLD, SP, MTEM, TEND, & TENS (from DLL/CN TOOL STRING) WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2 . OUT / ? ?MATCH3 . OUT / ? ?MATCH4 . OUT $ : ARCO ALASKA INCORPORATED : D.S. 3 - 32A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 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 MTEM BCS 68 1 DEGF 4 4 TEND BCS 68 1 LB 4 5 TENS BCS 68 1 LB 4 6 GR DLL 68 1 GAPI 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 11 TEND DLL 68 1 LB 4 12 TENS DLL 68 1 LB 4 13 NPHI 2435 68 1 PU-S 4 14 FUCT 2435 68 1 CPS 4 15 NUCT 2435 68 1 CPS 4 4 20 789 90 0 4 84 653 71 5 4 20 789 90 0 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 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 64 Tape File Start Depth = 9674.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15217 datums Tape Subfile: 2 246 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 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: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 .2500 VENDOR TOOL CODE START DEPTH GR 9202.0 DLL 9205.0 2435 9202.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9604.0 9636.0 9610.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 01-MAY-94 FSYS REV. J001 VER 1.1 1345 01-MAY-94 1932 01-MAY-94 9663.0 9662.0 9200.0 9624.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB 8.500 7631.0 0.0 GEL FREE KCL 9.80 46.0 9.0 6.6 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: DLL/CN MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 32A : PRUDHOE BAY : NORTH SLOPE : ALASKA 168.0 0.136 0.061 0.114 0.000 0. 179 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 72.0 168.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 RS DLL 68 1 OHMM 4 3 RD DLL 68 1 OHMM 4 4 ED DLL 68 1 MV 4 5 ES DLL 68 1 MV 4 6 ID DLL 68 1 A 4 7 IS DLL 68 1 A 4 8 SP DLL 68 1 MV 4 9 TEMP DLL 68 1 DEGF 4 10 CHT DLL 68 1 LB 4 11 TTEN DLL 68 1 LB 4 12 SPD DLL 68 1 F/MN 4 13 CNC 2435 68 1 PU-S 4 14 CNCF 2435 68 1 PU-S 4 15 CN 2435 68 1 PU-L 4 16 LSN 2435 68 1 CPS 4 17 SSN 2435 68 1 CPS 4 4 57 515 01 4 40 514 81 4 39 859 45 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 23 415 80 4 84 503 82 4 46 103 82 4 46 103 82 4 11 639 82 4 98 211 23 4 98 211 23 4 52 326 75 4 84 023 70 4 83 368 34 68 6 0 0 0 0 0 0 5 1 1 1 1 1 1 5 1 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 135 Tape File Start Depth = 9674.000000 Tape File End Depth = 9202.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34003 datums Tape Subfile: 3 Minimum record length: Maximum record length: 216 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9201.0 AC 9201.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9640.0 9664.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR PCM AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY PULSE CODE MODULATOR BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 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: 01-MAY-94 FSYS REV. J001 VER 1.1 1345 01-MAY-94 2237 01-MAY-94 9663.0 9662.0 9200.0 9654.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 3506XA 1603MA/1609EB 8.500 7631.0 0.0 GEL FREE KCL 9.80 46.0 9.0 6.6 173.0 0. 136 0.060 0. 114 0.000 0. 179 0.000 72.0 173.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: AC MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 32A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 TEMP AC 68 5 CHT AC 68 6 TTEN AC 68 7 SPD AC 68 1 GAPI 1 US/F 1 1 DEGF 1 LB 1 LB 1 F/MN 4 4 06 969 49 6 4 4 48 852 89 4 4 81 285 47 0 4 4 61 008 99 5 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 61 Tape File Start Depth = 9671.000000 Tape File End Depth = 9199.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30330 datums Tape Subfile: 4 134 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 9201.0 DLL 9201.0 2435 9201.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9602.5 9635.0 9609.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 01-MAY-94 FSYS REV. J001 VER 1.1 1345 01-MAY-94 2009 01-MAY-94 9663.0 9662.0 9200.0 9624.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB 8.500 7631.0 0.0 GEL FREE KCL 9.80 46.0 9.0 6.6 168.0 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: DLL/CN REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 32A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.136 0.061 O. 114 0.000 O. 179 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 72.0 168.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 RS DLL 68 1 OHMM 4 3 RD DLL 68 1 OHMM 4 4 ED DLL 68 1 MV 4 5 ES DLL 68 1 MV 4 6 ID DLL 68 1 A 4 7 IS DLL 68 1 A 4 8 SP DLL 68 1 MV 4 9 TEMP DLL 68 1 DEGF 4 10 CHT DLL 68 1 LB 4 11 TTEN DLL 68 1 LB 4 12 SPD DLL 68 1 F/MN 4 13 CNC 2435 68 1 PU-S 4 14 CNCF 2435 68 1 PU-S 4 15 CN 2435 68 1 PU-L 4 16 LSN 2435 68 1 CPS 4 ' 17 SSN 2435 68 1 CPS 4 4 57 515 01 4 40 514 81 4 39 859 45 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 4 23 415 80 4 84 503 82 4 46 103 82 4 46 103 82 4 11 639 82 4 98 211 23 4 98 211 23 4 52 326 75 4 84 023 70 4 83 368 34 6 0 0 0 0 0 0 5 1 1 1 1 1 1 5 1 1 68 * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 135 Tape File Start Depth = 9673.000000 Tape File End Depth = 9201.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 68006 datums Tape Subfile: 5 214 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 94/ 5/ 5 01 **** REEL TRAILER **** 94/ 5/ 6 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 6 MAY 94 9:24a Elapsed execution time = 13.74 seconds. SYSTEM RETURN CODE = 0