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Home My WebLink About196-082Pages 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. i~(~--_,©~,x File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~ Vincent Nathan Lowell Date: Z- [ (i~' 's~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ RE(~EIVE AUG 2 5 Z005 J STATE OF ALASKA) ALASKA IL AND GAS CONSERVATION COMrvllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Com;.. Cornmissim Anchrrnm~:e 1 a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 Zero Other 5. Date Comp., Susp., or Aband. 6/23/2005 6. Date Spudded 7/20/95 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 138'FSL,1065'FEL,SEC.02,T10N,R14E,UM Top of Productive Horizon: N/A Total Depth: 788' FNL, 3348' FEL, SEC. 14, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685928 y- 5940735 Zone- ASP4 TPI: x- y- Zone- Total Depth: x- 683804 y- 5934476 Zone- ASP4 ---------------------- .---------------------. 18. Directional Survey 0 Yes IBI No No. of Completions ----------------..----- 21. Logs Run: MWD, GR 22. 7. Date T.D. Reached 7/22/96 8. KB Elevation (ft): 60' 9. Plug Back Depth (MD+TVD) 11948 + 8663 10. Total Depth (MD+ TVD) 12024 + 8716 11. Depth where SSSV set N/A MD 19. Water depth, if offshore NI A MSL CASING SIZE 20" 13-3/8" 9-518" 7" Wr. PER FT. 94# 72# 47# 29# CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE GRADE' OP BOTTOM , OP I:iOTTOM SIZE H-40 Surface 80' Surface 80' 32" MN-80 Surface 2719' Surface 2719' 17-1/2" MN-80 1 S-95 Surface 11946' Surface 8662' 12-1/4" MN-80 11613' 11974' 8409' 86831 8-1/2" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD S"V'''':,-\ k'NL'\ r "'> 'J J ,. O("~ ::",,'1.,."9" "oPt '0 ~;.U AU b <J. ¿ JJ 26. Date First Production: Not on Production Date of Test Hours Tested 24. SIZE 4-1/2", 12.6#, L-80 TVD 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 196-082 305-151 13. API Number 50- 029-20201-01-00 14. Well Name and Number: PBU 06-06A 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028315 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING 0 RECORD 300 sx Permafrost II (Approx.) 985 sx Arcticset 1000 sx 'G', 180 sx CS 1,105 sx AS 400 sx Class 'G' AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6800' - 11691' PACKER SET (MD) 11567' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 10890' 6571' 6548' AMOUNT & KIND OF MATERIAL USED P&A with 16 Bbls Cement Set EZSV Set Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil -BBl PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ~ OIL -BBl Press. 24-HoUR RATE""'" GAs-McF WATER-Bel CHOKE SIZE GAS-Oil RATIO GAs-McF WATER-Bel Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 ORIG!NI~L CONTINUED ON REVERSE SIDE RBDMS BFL AUG 3 0 Z005 28. GEOLOGIC MARKERS ) 29. ) FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Lower Cret. Unconformity 11826' 8570' None 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ _ ¢V ~ PBU 06-06A 196-082 305-151 Well Number Title Technical Assistant Date Cfð·;t"3 ·Ó~ Permit No.1 Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ken Allen, 564-4366 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 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Well: Field: API: Permit: ') ') 06/26/05 06/30/05 07/21/05 Nabors 2ES 06/15/05 DRIFTED WI 3.50" CENT, TT LOC, SAMPLE BAILER. LOC TT AT 11635' SLM + 65' = 11700' ELMO. TAGGED BOTTOM AT 11728' SLM + 65' =11793' CORRECTED. (HAD - 850 LB PICK UP WEIGHT OFF BOTTOM). SAMPLE BAILER CAME BACK WI FILL, HAD RUBBERY STUFF IN SPANGS. 06-06B Prudhoe Bay Unit 50-029-20201-02-00 205-098 Accept: Spud: Release: Rig: 06/23/05 MIRU. RIH FOR P&A. TAG TO 11812' CTM AND CORRECT DEPTH TO WL DEPTH - 11793', CIRCULATE BOTTOMS UP. RETURNS HAS EMULSION AND SOME GAS. STOP PUMPING AT 300 BBLS. RETURNS CLEAN AND 0 GAS. OBSERVE WELL. LAY IN 15.8 PPG CEMENT AT 1:1 FROM 11783' UP TO WC, TOC- 10890'. PUH TO SAFE DEPTH - 10709'. PRESSURE UP TO 500 PSI FOR BUMP. LAUNCH 5/8" BALL FOR FCO. MAKE 3 PASSES FROM 10700' - 11090' AND POOH AT 80% MAKING 3 PASSES ON WAY OUT ACROSS ALL JEWELERY. FP WELL TO 2500'. RDMO. JOB COMPLETE. PRE-RIG WORK 06/24/05 LOGGED CORRELATION PASS 6500 - 6400, GLM 6457. SHOT EXPLOSIVE SCP JET CUTTER AT 6800'. ) ) BP EXPLORATION Qpel"ationsSummaryReport Page 1 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-06 06-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/26/2005 Rig Release: 7/21/2005 Rig Number: Spud Date: 2/21/1976 End: 7/18/2005 Date From - To Hours Task Code NPT Phase Description of Operations 6/25/2005 17:00 - 20:00 3.00 DEMOB P DECOMP Rig down floor. Bridle up derrick. Lower cattle chute. Lower Derrick. Move pits and sub base off well & stage on pad. 20:00 - 00:00 4.00 DEMOB P DECaMP Standy by - Wait on OS 06-06B wellsite preparation - Removal of wing valve and level pad. Clean location OS 6 - 20A. 6/26/2005 00:00 - 02:00 2.00 DEMOB P DECaMP Set matts. Spot and level sub over OS 06-06B. Raise derrick. Set matts for pits. 02:00 - 04:00 2.00 DEMOB P DECOMP Spot pits. Hook up lines. Set & berm cutting pit. Set shop, camp, and buildings. Hook up intercoms. Rig accepted @ 0400 hrs. 04:00 - 05:00 1.00 DEMOB P DECaMP Bridle down. Pin blocks. Hang Bridle line. 05:00 - 06:30 1.50 WHSUR P DECOMP RU DSM lubricator. Pull BPV. Take on water. RD DSM lubricator. RU floor.. Clean floor. 06:30 - 08:30 2.00 DEMOB P DECaMP Install double valve on annulus. RU lines to circ well. 08:30 - 09:00 0.50 DEMOB P DECaMP Hold pre spud meeting with all personel. 09:00 - 11 :30 2.50 KILL P DECaMP Test lines to 1000 psi. Circ well wI clean 8.4 ppg SW - pumped 513 bbls @ 6 bpm - 500 psi. 11 :30 - 12:00 0.50 KILL P DECOMP Monitor well. RD circ lines and clear cellar. 12:00 - 13:00 1.00 WHSUR P DECaMP Set BPV. Test from below to 1,000 psi. 13:00 - 15:00 2.00 WHSUR P DECOMP NO tree and adaptor flange. 15:00 - 17:00 2.00 WHSUR P DECOMP NU BOPE. 17:00 - 17:30 0.50 WHSUR P DECOMP RU to test BOP's. 17:30 - 23:00 5.50 WHSUR P DECaMP Test BOPE as per BP policy to 250 psi low and 3500 psi high for 5 min I test. Unable to test lower pipe rams. Test witness waived by Jeff Jones wI AOGCC. Test witnessed by James Henson - Pusher, Mike Whiteley - Drilling supv. 23:00 - 23:30 0.50 WHSUR P DECaMP RD test joint. 23:30 - 00:00 0.50 PULL P DECaMP Pull Blank plug. RU DSM lubricator to pull BPV. 6/27/2005 00:00 - 01 :00 1.00 PULL P DECOMP RU DSM lubricator. Pulled TWCV. RD DSM. 01 :00 - 03:00 2.00 PULL P DECaMP MU landing joint in tubing hanger. Back out LDS. Pulled tbg hanger to rig floor - String wt 105K. Monitor well. Disconnect control lines. RU spooling unit. RU handling tools. LD hanger and landing JT. 03:00 - 04:00 1.00 PULL P DECOMP LD 5.5" pups, and XO. Change handling tools to 4.5/1.. 04:00 - 09:30 6.00 PULL P DECaMP POOH LD 4 1/2/1 tubing to SSSV - spool up control lines. LD SSSV. RD spooling unit. REC 31 SS bands. Continue POOH laying down 4.5" tubing. 10:00 - 10:30 0.50 PULL P DECaMP Service top drive, lub rig, adj brakes. 10:30 - 11 :00 0.50 PULL P DECOMP LD 4.5" tbg. RD tubing handling tools - clear and clean rig floor. Rec 162 jts 4.5" tbg + piece, 3- GLM', 1 - SSSV. 11 :00 - 12:30 1.50 DHB P DECOMP RU SWS. 12:30 - 13:00 0.50 DHB P DECOMP RIHw/8.48" GR I JB I CCL to 600'. Trouble wI CCL. POOH with wire line tools. 13:00 - 14:30 1.50 DHB N DECaMP Trouble shoot CCL. 14:30 - 16:30 2.00 DHB P DECOMP RIH with GR I JB I CCL to 41/2" stump @ 6800'. Ran CCL. Rec 4 gal partin and scale. 16:30 - 20:00 3.50 DHB P DECOMP MU 9 5/8" EZSV. RIH and set plug @ 6537'. POOH wI setting tool. RD SWS. 20:00 - 22:30 2.50 DHB P DECOMP MU mule shoe sub. PU 21 jts 5" HWDP, 9 5/8" storm packer. Set packer 5' below well head. Test csg I packer to 3,500 psi. Held. 22:30 - 23:30 1.00 BOPSUP P DECOMP ND BOP stack. 23:30 - 00:00 0.50 WHSUR P DECOMP RU to pull 9 5/8" pack-off bushing. Unable to rotate to left. 6/28/2005 00:00 - 00:30 0.50 WHSUR P DECOMP Attempt to pull 9 5/8" pack-off. Pulled 50K. Printed: 7/25/2005 8:04:26 AM ') ) BPEXPLORA TION Operatioi1$> Summary Report Page 2_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-06 06-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 6/26/2005 Rig Release: 7/21/2005 Rig Number: Spud Date: 2/21/1976 End: 7/18/2005 Date From - To H 0 lJ rs Task Code NPT Phase Description, of Operations 6/28/2005 00:30 - 01 :00 0.50 WHSUR P DECOMP ND tubing head. Pulled tubing head wi pack-off. Pulled 40k. 01 :00 - 03:30 2.50 WHSUR P DECOMP Installed new 95/8" pack-off and csg head. Test to 4,000 psi.for 10 min. Held. 03:30 - 05:00 1.50 BOPSUP P DECOMP NU BOP's. 05:00 - 07:30 2.50 BOPSUP P DECOMP RU to test BOPE. Test BOPE as per BP policy to 250 psi low and 3,500 psi high.Tested pipe rams, Hydril wi 5" DP. Test witness waived by Jeff Jones wi AOGCC. Witnessed by mike Whiteley - Drlg Supv, Jim Henson - toolpusher. 07:30 - 08:00 0.50 BOPSUF P DECOMP Rig down test equipment. Set wearbushing. 08:00 - 09:00 1.00 DHB P DECOMP MU HES running tool. Retrieved storm packer. LD same. 09:00 - 10:00 1.00 DHB P DECOMP POOH wi 21 jts 5" HWDP. 10:00 - 11 :30 1.50 WHSUR P DECOMP Attempt to test 9 5/8" csg to 3,500 psi. Not holding. 11 :30 - 12:30 1.00 WHSUR P DECOMP Re-test 95/8" pack-off. Torque LDS to 600 ft/lbs. Test pack-off to 4,000 psi.held. 12:30 - 13:00 0.50 CASE P DECOMP Test 95/8" csg to 3,500 psi for 30 min. Lost 400 psi. 13:00 - 15:30 2.50 CLEAN P DECOMP MU Clean out BHA. 8.5" bit, 8.5" string mill, B.S., Jars, 9 DC's, HWDP 15:30 - 17:00 1.50 CLEAN P DECOMP PU 5" DP to 2517'. 17:00 - 17:30 0.50 CLEAN P DECOMP Fill pipe and CBU @ 2517'. 12 BPM @ 650 psi. 17:30 - 18:00 0.50 CLEAN P DECOMP Lubricate rig. Service top drive. 18:00 - 19:00 1.00 CLEAN P DECOMP Cut drilling line and adjust brakes. 19:00 - 22:30 3.50 CLEAN P DECOMP RIH picking up 5" DP to 6486'. Install blower hose. Tag 95/8" EZSV @ 6,571'. Set 30k on EZSV. Up 160K DN 130k. 22:30 - 00:00 1.50 CLEAN P DECOMP Pump hi vis sweep. Diplace well with 9.0 ppg LSND milling mud. Recipcate & Rotate. 12 bpm @ 800 psi. UP 155K, DN 135K, RT 145K, TQ 3-4 K. 6/29/2005 00:00 - 03:00 3.00 CLEAN P DECOMP POOH wi bit to BHA. 03:00 - 04:00 1.00 CLEAN P DECOMP Pulled BHA. LD bit, mill , bumper sub., and jars. 04:00 - 06:30 2.50 STWHIP P WEXIT PJSM. M.U. Milling BHA I Whipstock. Orient. Uplaoad tools. 06:30 - 08:30 2.00 STWHIP P WEXIT RIH wi Whipstock to 1136'. Shallow test MWD tools. 450 gpm @ 600 psi. 08:30 - 11 :30 3.00 STWHIP P WEXIT RIH wi Whipstock to 6529'. 11 :30 - 12:00 0.50 STWHIP P WEXIT Install blower hose. Service rig & TD. 12:00 - 12:30 0.50 STWHIP P WEXIT Orient whipstock to 85 LHS @ 6529'. Tag EZSV @ 6571'. Set down 30k to set Bottom trip anchor. PU 10K. Set down 50K 5X to shear off. UP 155k DN 135K RT 145K TQ 3-4K @ 85 RPM. Tip of whipstock @ 6548'. 12:30 - 13:00 0.50 STWHIP P WEXIT SPR's. CBU to shear mud. 13:00 - 19:00 6.00 STWHIP P WEXIT Mill window in 9 5/8"fl 6548'- 6564'. New hole to 6576'. 19:00 - 20:00 1.00 STWHIP P WEXIT Pump high vis super sweep around @ 6576' and polish window 490 gpm @ 1100 psi..Circ clean. Rec 180 Ibs metal cuttings. Work mills thru window. 20:00 - 20:30 0.50 STWHIP P WEXIT Pulled up into 9 5/8" csg. Performed FIT wi 9.0 ppg to EMW 11.1 ppg. Pumped in @ 600 psi. TVD 5432'. Notified BP Drilling eng. and AOGCC Inspector - Chuck Scheve of low FIT pressure. 20:30 - 21 :00 0.50 STWHIP P WEXIT Monitor well. Slug DP. Remove blower hose. 21 :00 - 00:00 3.00 STWHIP P WEXIT POOH wi window mills. Stand back HWDP. 6/30/2005 00:00 - 02:30 2.50 STWHIP P WEXIT PJSM. L.D D.C.'s. Down load LWD's. Finish L.D. BHA. Upper window mill full gage - 8.5". 02:30 - 03:00 0.50 STWHIP P WEXIT Clear rig floor. PJSM. 03:00 - 03:30 0.50 BOPSUP P WEXIT Flush out BOPE, flow line, shakers. Function Rams. 03:30 - 07:30 4.00 DRILL P WEXIT P.U. Drilling BHA. Set motor to 1.5 deg. Orient tools. Initalize Printed: 7/2512005 8:04:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 3 ~ BP EXPLORATION QperationsSummaryReport 06-06 06-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From- To Hours Task Code NPT Phase 6/30/2005 03:30 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 00:00 7/1/2005 00:00 - 00:00 7/2/2005 00:00 - 00:00 7/3/2005 00:00 - 12:30 12:30 - 14:00 14:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 22:00 7/4/2005 4.00 DRILL P 3.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL P 1.50 DRILL N DPRB INT1 2.00 DRILL N DPRB INT1 0.50 DRILL N DPRB INT1 0.50 DRILL P 5.00 DRILL P 24.00 DRILL P 24.00 DRILL P 12.50 DRILL P 1.50 DRILL P 2.00 DRILL P 1.50 DRILL P 22.50 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: 6/26/2005 Rig Release: 7/21/2005 Rig Number: Spud Date: 2/21/1976 End: 7/18/2005 Description of Operations LWD's. Finish M.U. BHA. Shallow test MWD. RIH P.U. 5" DP to 5,622'. RIH wi pipe from derrick to 6,474'. Service top drive - lubricate rig. Orient 85 LHS @ 6474'. SPR. UP 155k DN 135K. RIH to 6,569'. No problem going thru window fl 6548' - 6564'. Ream to btm @ 6576'. Drill fl 6576' - 6605'. CBU @ 6605'.425 gpm @ 1100 psi. Pull up into csg. Perform FIT wi 9.1·ppg to 10.9 EMW - 5 psi. TVD 5432'. RIH to bottom @ 6,605'. Spot 30 bbls 45 #1 bbl LC pill as per BP Anchorage office. Clear DP . POOH above pill to 6,153'. Squeeze LCM pill @ 6153'. Pumped 9 bbls. ge squeeze pressure up from 500 psi to 850 psi' waiti 5 min each time to allow pressure to stabilise. Got final pr sure of 775 psi that stabilised in 10 minutes. Perform FIT wi 9.1 ppg mud. EM = 11.84 ppg - 775 psi. TVD 5,432'. RIH to 6,548'. Orient. Run going thru window. Dir. Drlg fl 6,605' to , 20'. AST 2.09 ART 1.05. UP 155K DN 130K RT 145K T off 5K TO on 6K . ECD 9.99. OFF 1350 psi, On 1450 Psi. gpm. Drill from 6 0' - 7,894 '. UP 180K DN 150K RT 155K, 550 gpm O~ 1530 psi, ON 1,700 psi, TO OFF 5 -6K, TO ON 6- 7K, 70 rpm. ECD 9.9 ppg. Difficult sliding - nut plug s eps I added lubricant. Sliding still difficult. ir Drill from 7,894' - 8,925'. AST 8.54 hrs, ART 9.42 hrs. UP 200K DW 165K RT 180K, TO ON 9-10K TO OFF 7-8K, 545 gpm 1700 psi. ROT 80 rpm. ECD = 10.2 ppg. Sliding improved below -8000' once in to the CM3 formation. Dir Drill from 8,925' - 9,423'. ART 2.6hr AST 5.56hr. UP 230K, DN 165K, RT 194K, TO ON 11-12K, TO OFF 9-10K. 545 GPM @ 1800 psi. Difficulty sliding. Circ for wiper trip to window. POOH to 9,405'. Pump hi-vis sweep around to shoe @ 6,548'. POOH to 9,310'. Pump sweep around. ROT & REC pipe @ 80 RPM, 545 gpm @ 1800 psi.Circ hole clean. POOH to 6,615' for Mad pass log - no problems. MAD pass log 250 ftI hr fl 6,615' - 6,180' per geologist. Cut and slip drilling line. Service topdrive I drawworks I automatic driller. RIH to 6,474'. Orient tool face 85 L. Run thur window fl 6,548' - 6,564' - no problems. RIH to 9,405. No problems. Pump sweep. Start raising mud wt from 9.3 ppg to 11.3 ppg wi 16.0 ppg pre-mixed mud. 497 gpm @ 1720 psi. Adjust pump rate for trucks offloading. Rotate and Recip pipe. Circ and raise mud wt. to 11.3 ppg wi pre-mixed 16.0 ppg mud - pump 210 gpm - rot. & rec pipe. Drill from 9,423' - 10,369'. AST 10.43 hrs, ART 5.15 hrs. UP 230k, DW 160K, RT 185K. TO ON 10 -13K, TO OFF 9 - 10 K. 496 gpm @ ON 2550 psi, OFF 2,275 psi. ECD = 12.41 ppg. No Printed: 7/25/2005 8:04:26 AM ) ~~å\~Œr i. , I ¡ I ,~ '\, r il [I ¡ '\ I I í I 'I ). U ~ u ; 1011Pb' I I I, I r: ! L I I : I U' I ¡ :U: i0:1 FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 l~b---o~ ,,~··..,;"·,..H"'.E·r·: iU~I~ ') :1. 2005 \}..)CMh.~~ ["v ~J ~'i l..¡ Re: Prudhoe Bay 06-06A Sundry Number: 305-151 Dear Mr. Isaacson: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ .' aniel T. Seamount, Jr. Commissioner DATED thi4- day of June, 2005 Ene!. Date: To: From: Subject: ') ) June 16, 2005 File -J- O~A) Jane Williamson "7- ~ Prudhoe Well 06-06A Prudhoe Well 06-06A was an unsuccessful sidetrack drilled in 1996. The BRA assembly was lost in drilling and fishing was unsuccessful. I have not attached any production or decline plots as there has been no oil production. The original completion and sidetrack were cemented 3' below the 9 5/8" casing shoe and the flowline and well house were removed. Plans are to redrill to the Sag River formation. See the application for a more thorough discussion. The original wellbore and sidetrack have been squeezed already and there are no reserves. P &A for sidetrack should be approved. Mf (; -/lrt9.5 !:'Jc,1r ~ II~ /Zi!()5 ) STATE OF ALASKA y)73 C//6/S' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALRE:: 20 MC 25.280 JUN 1 6 2005 1. Type of Request: 181 Abandon / 0 Suspend 0 Operation Shutdown 0 Perforate 0 Oth1\laska l~, r:m'nm¡s~ ¡m~ o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspendr-~;'ttffih;i\\]¡'~ o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current W~Class: II Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 196-082.(' 6. API Number: 50-029-20201-01-00 / 99519-6612 9. Well Name and Number: PBU 06-06A /" 10. Field / Pool{s): Prudhoe Bay Field / Prudhoe Bay Pool '" ,,::I,,:R~f:Sr=;NlIIWEL~;C~~Dlj[l'Ø:tiJ:,$tJfV1M*R'0,'!;':)' I Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8716 11948 8663 11948 Length ,SizéMD,TVQ, ,BUrst 60' 8. Property Designation: ADL 028315 tf Total Depth MD (ft): 12024 Casing " Structural Conductor Surface Intermediate Production Liner Junk (measured): None Qqllapse , 80' 20" 80' 80' 1530 520 2719' 13-3/8" 2719' 2719' 5380 2670 11946' 9-5/8" 11946' 8662' 6870 4760 361' 7" 11613' - 11974' 8409' - 8683' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): None None Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'DB' packer; 4-1/2" Otis "HRQ' SSSV Nipple Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 11567' 2203' Tubing MD (ft): 11691' 12. Attachments: liD Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: /' D Exploratory liD Development D Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Signature /~~ t~ 8,t.( ¿£~<""" Phone 564-5521 Commission Use Only June 20, 2005 Date: 15. Well Status after proposed work: DOil DGas DWAG DGINJ I D Plugged II Abandoned D WINJ D WDSPL Contact Ken Allen, 564-4366 Date o/1tþ Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance I Sundry Number: .30 ~-/sl Other: --r -e ~ t- fs (ÿ P f +c. . 3500 r~" RBDMS 8FL JUN 2 0 Z005 Approved B Form 10-403 COMMISSIONER APPROVED BY THE COMMISSION Date bit (s !t'~~u;:cate ORIGlf~AL ) ) bo G~.&r.Ar. To: Winton Aubert - AOGCC Date: June 15, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: 06-06A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well 06-06A. This conventional well is currently shut-in due to an unsuccessful Coil Tubing sidetrack attempt in 1996. The well is providing no production or value to the field as it currently sits. Well 06-06 was originally drilled in March 1976 and completed in November 1978. Initially, only Zn 4 was perforated and the well came on at 7000 bopd, 0% WC, at solution GOR. In 1981, water was present in the well tests. This must have been aquifer water as flooding the field did not begin until 1984. By 1985 the well was making 1200 bwpd and continuing to rise. The well was squeezed in 1990 in preparation for a Zn 4 frac. Prior to the frac, the well was making 2800 bwpd. Following the frac, the well made 8000 bwpd and relatively no change in oil rate. In 1994 20' of the Sag was perforated with insignificant change in production. By 1995 the oil rate had declined dramatically to just 2-300 bopd while the water remained constant. At this point the GOR made the well uncompetitive and a sidetrack was planned. In July 1996 a coil sidetrack was in progress when the BHA was stuck in the window at 11,963' md. For eight days attempts were made to fish the BHA, but none were successful. It was decided to abandon the well. There is cement in the tubing up to 11,948' md, 3' below the 9-5/8" shoe. The well has been abandoned and the flowline and well house were removed. Prior to the 1996 coil sidetrack, the well passed a MIT-OA to 2000 psi and a MIT-IA to 2500 psi. The well does have communication, most likely through thread leaks, from the IA to the OA when ~ well is on gas lift. This will be remediated in the new sidetrack by adding a 7" liner to surface. The proposed 06-06B horizontal well targets a Sag River play situated down dip and adjacent to the assumed Sag GOC at -8576 SSTVD. The target area is situated on the up thrown side of a large, E-W striking down-to-the-south fault. The proximity of the PGOC is critical to the play, as natural gas cap expansion is expected to provide the drive mechanism required for economic flow rates within the low permeability Sag River reservoir. The play area is located in the southern portion of OS 6, in the up dip waterflood area of the Ivishak. The surrounding offsets are Ivishak producers or injectors. A pilot hole will also be drilled to test a potential Ivishak Zone 4 waterflood attic play on the up thrown side of the E-W fault. Commercial Ivishak oil accumulations defined in the pilot hole will be targeted by a dedicated Ivishak horizontal sidetrack in the near future. I The well will be kicked off in the shallow Ugnu1 section and a 8-1/2" hole will be drilled to the intermediated 7" casing point at the top of the Sag River. A top job will be performed on the 13- 3/8" annulus to eliminate the possibility of water entering, and damaging, the conductor by 13-3/8" annulus. A 7" tie-back will be run from the top of the current 7" liner to surface. The top 3,000' of the 7" tie-back will have premium connections. Cement will be brought up to -2,200' in the 9-5/8" by 7" annulus. The 6-1/8" pilot hole will then be drilled as a simple slant design to test remaining Ivishak oil reserves. The pilot hole will be plugged back with cement and an 6-1/8" 1800' Sag 06-06A Application for Sundry ') ) horizontal will be drilled. The wellbore will turn north near the PTD to avoid crossing a N-S down- to-the-east fault. The 06-06B well will TO approximately 200' south of the 14-14, an Ivishak / waterflood injector. A 4-1/2" slotted liner will be run throughout the production interval. The 06-06B sidetrack is currently scheduled for Nabors 2ES beginning around 6/25/05, after completing the 06-20A sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Pre-Ri~ Work: 1. Rig up slickline. Drift 4-1/2" tubing through WlEG. Tag and record PBTD below WlEG. 2. Fluid pack the tubiJlQ and inner annulus. 3. P&A perfs in 7".AírÍer rom the top of the CTD fish (-11,963') to -11,100' MD. RIH with coil to PBTD. lay!Pf2"O. Is of cement to -11,100' MD. Wash down to confirm TOC@11,100'. POH with c~ a. Cement Calculations: · 3-3/4" Cement hole = 11,963' - 11,948' or 15' (0.2 BBlS) · 7" liner = 11 ,948' - 11,691' or 257' (-10.1 BBlS) · 4-1/2" tubing = 11,691' - 11 ,100' or 691' (9.1 BBlS) · Total cement volume of 19.4 BBlS 4. Rig up slickline, drift 4-1/2" tubing. Tag TOC. 5. Chemical cut the 4-1/2", 12.6#, l-80 tubing at - 6,800' MD. / 6. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 7. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to -2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. / 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. / 10. Remove the well house. level the pad. Please provide total well preparation cost on the handover form. ,\ Ri~ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well tOßeawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. r 4. Pull 4-1/2" tubing from the pre-rig Chemical cut -6,800'. Spool up SSSV control lines. 5. RU e-line. Run Gauge Ring / Junk basket and Gamma Ray tool for 9-5/8", 47# casing with CCl to tubing stub - 6,800'. 6. RIH with USIT and log from 2,800' to surface. /' 7. RIH with 9-5/8" EZSV on e-line. Set EZSV at -6,520 to avoid cutting a casing collar during window milling operations. RD e-line. 8. Close rams and pressure test the 9-5/8" casing and bridge plug. If PT fails PU RTTS to find leak. If there is a leak a contingency plan will be sent to the rig. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH picking up 4" DP to EZSV. Orient and set the whipstock. Swap well over to 9.0 ppg milling fluid. Note: If MWD signals are too weak to obtain toolfaces, swap over to milling fluid before setting the whipstock. 10. Mill a window in the 9-5/8" casing at ±6,500' MD plus 20' from mid window. Perform FIT to 11.9 ppg. POOH for Drilling BHA. Note: Verify that the mud weight is 9.0 ppg prior to cutting the window. 11. MU the 8-1/2" drilling assembly with DIR/GR/RES/PWD and RIH. Kick off and drill 8-1/2" intermediate inteNal to 7" casing point at the Top Sag River. Mud weight will be increased to 11.3 ppg before drilling into the THRZ. 12. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to -6,350' MD. Set hanger / liner top packer and displace cement with mud. POOH. /' 1 ' 9. -.~~ \0 ,- 40 ~ ~ P yfJ\l ,,--l . 06-06A Application for Sundry ') ) 13. RU and run 7" Tie-back liner to surface. Top 3,000' of 7" will have premium threads. Cement will be brought up to -2,200' MO. Remainder of 9-5/8" by 7" annulus will be freeze protected to surface. 14. Perform a top job on the conductor by 13-3/8" annulus. 15. MU 6-118" BHA with DIR/GR/RES/NEU/DEN and RIH to the 7" tie-back landing collar. 16. Pressure test wellbore to 3500 psi for 30 minutes. 17. Drill tie-back cementing equipment and RIH to 7" drilling liner landing collar. 18. Pressure test wellbore to 3500 psi for 30 minutes. 19. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 20. Drill the 6-1/8" pilot interval as per directional plan (holding inclination and azimuth) to an estimated TD of 11,529' md. Condition well bore for a cement P&A of pilot hole. POOH racking back 4" DP and LD drilling assembly. 21. MU stinger and RIH to TD of pilot hole. Set a balanced 17 ppg cement plug from TD to 50' inside 7" shoe. POOH and 3 stands and wash down so TOC is -5' inside of 7" shoe. POOH. 22. MU the 6-1/8" drilling assembly with DIR/GR/RES/ABI and RIH to TOC. 23. Drill the 6-1/8" production interval building to -97°, targeting the Sag River formation. POOH. 24. MU 6-1/8" BHA with DIR/GR/RES/ABI/Azimuthal Density and drill ahead to an estimated TO of 13,060' MD. 25. Run a 4-1/2" slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner 150'. 26. Release from liner, displace well to clean seawater. 27. Run the 4-1/2", 12.6#, 13Cr-80 completion tying into the 4-1/2" liner top. 28. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 29. Set and test TWC. 30. NO BOPE. NU and test the tree to 5,000 psi. 31. Freeze protect the IA and Tubing to -2,200' and secure the well. 32. ROMO. Post-RiQ Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-Rig Start: Estimated Spud Date: 06/20105 06/25/05 Ken Allen Operations Drilling Engineer 907.564.4366 06-06A Application for Sundry TREE = WELLHEAD = . , ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= FMC GEN 1 FMC AXELSON . 60' ) 3100' 63 @ 6500' 12224' 8800' SS 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892 1-1 19-5/8" CSG, 53.3#, L-80, .0707 bpf, ID = 8.535" 1-1 1 TOP OF 9-5/8" CSG 1-1 43' 1 2438' 1 2438' 1 113-3/8" CSG, 72#, MN-80, ID = 12.347" 1-1 2719' µ Minimum ID = 3.80" @ 11680' 4-1/2" OTIS XN NIP I TOP OF 7" LNR 1-1 11613' 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 11691' 19-5/8" CSG, 47#, MN-80, ID = 8.681" 1-1 11945' ~ PERFORA TION SUMMARY REF LOG: BHCS ON 04/04/76 ANGLE AT TOP ÆRF: 42 @ 11948' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/4" 0 11948 - 11963 S 08/07/96 I PBTD 1-1 12024' I 7" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" 1-1 12960' DATE REV BY COMMENTS DATE REV BY 11/26/78 ORIGINAL COMPLETION 08/07/96 LAST WORKOVER 02119/01 SIS-MD FINAL 09/21/01 RN/TP CORRECTIONS 02105/03 A TOITP DELETE WAIVER SAFETY NOTE 04/21/03 KBITLH DIAGRAM CORRECTIONS 06-06A Starting condition ) e Sf. )t NOTES: IA x OA COM M TO AL. AVOID PULLING ST #3 GLV. COULD NOT PULL ST #8 GLV. 43' 1-15-1/2" X 4-1/2" XO 1 2203' 1-14-1/2" OTIS HRQ SSSV NIP, ID = 3.813" 1 GAS LIFT MANDRELS I ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 2900 2900 3 MC-FMHO RK L 2 3750 3711 25 MC-FMHO RK .. 3 6457 5389 61 MC-FMHO RK 4 8681 6497 54 MC-FMHO RK 5 9499 6986 53 MC-FMHO RK 6 9650 7076 53 MC-FMHO RK 7 10467 7592 48 MC-FMHO RK 8 11236 8130 44 MC-FMHO RK 9 11347 8211 43 MC-FMHO RK d ~ 11564' 1- 4-1/2" BKR GBH SEAL ASSY, ID = 3.875" (4' OF SEALS) 11567' 1-19-5/8" X 4-1/2" BKR DB PKR , ... . I I I 11680' 1- 4-1/2" OTIS XN NIP, ID = 3.725" MILLED OUT TO 3.80" / ~ 11690' 1-14-1/2" BKR WLEG 1 " I 11691' 1-14-1/2" TBG TAIL 1 I 11700' 1-1 ELMD TT LOGGED 12/22/90 1 ~ ~ COMMENTS 11948' 1-1 TOP OF CEMENT 1 11963' 1-1 TOP OF FISH (53.7' BHA ON 08/07/96) 1 MILLOUT WINDOW - 11974' - 11980' PRUDHOE BA Y UNIT WELL: 06-06A ÆRMIT No: 1960820 API No: 50-029-20201-01 SEC 2, T10N, R14E, 3347.96' FEL & 785.03' FNL BP Exploration (Alas ka) TREE = 'J'{ELLHEAQ = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle ;; Datum MD = Datum lVD = FMC GEN 1 FMC AXELSON 60' ) 3100' 63 @ 6500' 12224' 8800'SS 15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892 1-1 43' 19-5/8" CSG, 53.3#, L-80, .0707 bpf, 10 = 8.535" 1-1 2438' I TOP OF 9-5/8" CSG 1-1 2438' 113-3/8" CSG, 72#, MN-80, 10 = 12.347" 1-1 2719' µ Chemical cut -6,800' 06-06A Pre-Rig ) 8 SJ )v NOTES: IA x OA COM M TO AL. AVOID PULLING ST #3 GLV. COULD NOT PULL ST #8 GLV. 43' 1-15-1/2" X 4-1/2" XO 1 2203' 1-14-1/2" OTIS HRQ SSSV NIP, 10 = 3.813" 1 GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 2900 2900 3 MC-FMHO RK , I 2 3750 3711 25 MC-FMHO RK 3 6457 5389 61 MC-FMHO RK L 4 8681 6497 54 MC-FMHO RK ~ 5 9499 6986 53 MC-FMHO RK 6 9650 7076 53 MC-FMHO RK 7 10467 7592 48 MC-FMHO RK 8 11236 8130 44 MC-FMHO RK 9 11347 8211 43 MC-FMHO RK ~~~ Top CMT P&A -11,100' _____ 11564' 1- 4-1/2" BKR GBH SEAL ASSY, _ 10 = 3.875" (4' OF SEALS) I 11567' 1-19-5/8" X 4-1/2" BKR DB PKR TOPOF 7" LNR 1-1 11613' 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 11691' 19-5/8" CSG, 47#, MN-80, 10 = 8.681" 1-1 11945' ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/04/76 ANGLE AT TOP ÆRF: 42 @ 11948' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/4" 0 11948 - 11963 S 08/07/96 I PBTD 1-1 12024' 17" LNR, 29#, MN-80, .0371 bpf, 10 = 6.184" 1-1 12960' DATE 11/26/78 08/07/96 02/19/01 09/21/01 02105/03 04/21/03 REV BY COMMENTS DA TE ORIGINAL COMPLETION . 06/06/05 LAST WORKOVER FINAL CORRECTIONS DELETE WA IV ER SA FETY NOT~ DIA GRAM CORRECTIONS SIS-MD RNlTP A TDITP KB/TLH ;!r:~~··.k . j,~7~,:.~.". I ',"':.'" I '<~'r".'~ I .. .,'~,'·",~'::'ot:..,:l:~" "',,... I r--- ,"1'·,.\. :"~~:',I:,,'~::.., !,:::,:\':',~ a r J888888t REV BY KWA COMMENTS A'e-Sidetrack work Minimum ID = 3.80" @ 11680' 4-1/2" OTIS XN NIP 11680' 1- 4-1/2" OTIS XN NIP, 10 = 3.725" MILLED OUT TO 3.80" 11690' 1-14-1/2" BKR WLEG 1 11691' 1-14-1/2" TBG TAIL 1 11700' 1-1 ELMO TT LOGGED 12/22/90 1 11948' 1--1 TOP OF CEMENT 1 11963' I-fTOPOF FISH (53.7' BHA ON 08/07/96) 1 MILL OUT WINDOW - 11974' - 11980' PRUDHOE BA Y UNIT WELL: 06-06A ÆRMIT No: '1960820 APt No: 50-029-20201-01 SEC 2, T10N, R14E, 3347.96' FEL & 785.03' FNL BP Exploration (Alaska) ) HES 4-1/2" X Nipple 10 = 3.813" - 2,200' _ 19-5/8" CSG, 53.3#, L-80, .0707 bpf, 10 = 8.535" 1-1 r TOP OF 9-5/8" CSG 1-1 13-3/8" CSG, 72#, MN-80, 10 = 12.347" 1-1 2438' 2438' 2719' 4-1/2" TBG, 12.6#, 13Cr-80, Vam TOP Top of Window -6,500' 9-5/8" EZSV -6,520' 4-1/2" Tubing Stub -6,800' TREE = WELLHEAD = ACTUATOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = V -2,200' TOC Datum TVD = .. 7" Tie-Back 26#, L-80 TC-II -3,000' 06-068 Proposed Completion 1 1 µ II \ ?::'~~1, . ~i~. A :,',A~~~ , '" /' ~ L Top CMT P&A -11,100' _____ 11564' 1- 4-1/2" BKR GBH SEAL ASSY,"¡i ID=3.875" (4'OFSEALS) l,).tJ I 11567' H 9-5/8" X 4-1/2" BKR OB PKR I:~,.~ ·'L'I.~~i' ,. "','~I" . ",.. 1·..,,~,.,·..',·~~.,~, I ~.<! ".,,'.-k ,:i'¡¡"',I: 1 1¡J.t. .~\r....I\', I I 19-5/8" CSG, 47#, MN-80, ID = 8.681" 1-1 11945' ~~"',\,,,;',,~.7·,,! ~ I I I TOP OF 7" LNR 1-1 11613' 1 I 11680' 1- 4-1/2" OTIS XN NIP, 10 = 3.725" MILLED OUT TO 3.80" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 11691' I PBTO l-i 12024' I 7" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" 1-1 12960' DATE 11/26/78 08/07/96 02/19/01 09/21/01 02/05/03 04/21/03 R8/ BY COMMENTS DA TE ORIGINA L COMPlETION 06/06/05 LAST WORKOVER FINAL CORRECTIONS DELETE WAIVER SAFETY NOT!;, OIA GRAM CORRECTIONS SIS-MD RNITP A TOITP KBfTLH -- REV BY KWA COMMENTS Proposed Completion WP08 ) FMC GEN 1 FMC 7" Tie-Back Seal Assy 26#, L-80 BTC-M -6,353' 7" LNR Top 26#, L-80 BTC-M -6,350' -10,870' HES 4-1/2" X Nipple 10 = 3.813" -10,890 BKR 7" x 4-1/2" BKR PKR /-10,910' HES 4-1/2" X Nipple 10 = 3.813" ~','":"",, -10,930' HES 4-1/2" XN Nipple 10 = 3.725" ~'. -10,948' 4-1/2" WLEG Ii' 7"x5" ZXP PKR -10 945' ,11-::-- ' " __7" LNR 26#, L-80 BTC-M -11,095' 4-1/2" 12.6#, L-80 'I / Solid LNR -11,135' - - - - - - - - - - - - - - - - - - . 1 - - - - - - - - - - - - - - - - - - - _I --- 4-1/2" 12.6#, L-80 Slotted LNR -13,060' ___6" Pilot hole TD -11,586' P&A'd with 17ppg Cement 11690' 1-14-1/2" BKR WLEG 1 11691' 1-14-1/2" TBG TAIL 1 11700' 1-1 ELMO TT LOGGED 12/22/90 1 11948' 1-1 TOP OF C8v1ENT 1 11963' I-iTOPOF FISH (53.7' BHA ON 08/07/96) 1 MILLOUT WINDOW - 11974' - 11980' PRUDHOE BA Y UNIT WELL: 06-06A PERMIT No: '1960820 API No: 50-029-20201-01 SEC2, T10N, R14E, 3347.96' FEL & 785.03' FNL BP Exploration (Alaska) :4 ---... 2 ) \ ~RILL SITE Nl ~_ II . - - . --..,...-- . w:~ 1- "=t' ~IO:::: "~.¡,!o~ : TION ) 12 ,.1.___ SECTIONS 1,2,11,812 T10N, RI4E,u"v1 . ..-.. . .,', . --.-----...-. WELL NO 1 LA T '70 0 I 4' 4 0 '-1 3 " LONG, 148°¿9'57,22" 'r:lL NO.2 r 70<::'14'39.57" LONG, 14 8c 29' 56.49" Wfll ~~O. 3 LAT 70014' 38.4 I" L0t1.iG . 148°¿9' 55 77" WELL NO.4 LAT. 70° 14' 37,26" LONG 148°29' 5506 " WEll NO.5 LAT. 70° 14 1 36.1111 LONG. 148° 29' 54.3411 WEll NO.6 LAT. 70° 14 I 34.9611 LONG. 148° 29' 53.61" WEll NO. 7 LAT. 70° 141 33.80" LONG. 148° 29" 52.8711 WEll NO.8 LAT. 70° 14' 32.64" LONG. 148029' 52.15" 4000' ALASKA STATE PlANf y 5 941 3 I '7. 84 x f,b578973 Y r:; Y41 ¿01.36 X 68'5817,66 Y 5 941 084,09 X 685 8 4 5. 36 Y 5 94096754 X 685 872.80 Y 5940 851.18 X 685 900.32 Y 5 940 735.11 X 68-5 928.21 Y 5 940 617 .42 X 685956.53 Y 5 940 500 .66 X 685 984. 2 I I ,o_..J .-.l '-'-=4 ¡ I I lONF 4 ¡ ! ¡ i i L o;' N !" ~. : _o'.;'~ .. _1-' Wt'~1 ~O.I -r, ,. ,11~,~.Jy._~ ....", ,:: 'í: - ..\ : 'B';"~ '0 ~ Well No 2 ~, ' % ,:j,;:" _ . _ ~ ,.. .. I.! ~!L..J '( _~ 0'~ \ '~ ;. Well -' . ,.', t. í~ 0 \ \~,\~' ,...,tî t No3 '\ 1139 ';;i':c; ~ ~ ':C- . TO -::, - _. J\c . .. .. .,... ~) to s.' \ Well 1.~ '-n '~, No.4 ~\l14 . ~'-2. v~. ~ ~ c~~~ ~. '\. \~"'~15 j; \ '090 I ,~ \~ 01"' ~ ~' ~ -\j ;:.\' ';. .. ~.- -a, Well~.. I ~.\ ~ ~~NO.6 %I065~ ~ .: CD ", W II ¡:: .\., It),' 0'-" - j~O.7,I040 .~ . ._-~ '¡~~~~\ ~o ts:¡~· --.- \ ....,."0. lðO 12 \ en: "q" 3 2 184 " N ,"= 300' l,.,._ . .. ~,,"~"'~" , -..-- OF AI.. \" c E~TIF I CAT E OFSl) ~",F~O R ;. "'l....¢:.~....... ~".'~-:1-'" I HtJ<Et;YClRiIFY TriAl I AM Fk(}PE.F<L( F<E.GIS1ER~'?l + 'I~ ~~ AND LICENSED TO PRAll ICE LA'JL, S JRJfYING ~* :'491l:! )~ \.. ~ THE STATE OF ALAC;t<A ArJD lriAT THI~ PLAT ~."~GCllle.e"UIle;æ:1I1 1!I....e~..··i RfP~ESENTS A LOC¡,lION SURvl, Y MAL',E BY ME ~ - ~J9. ~ ~ OF< UNU:.R MY 5 'PfRVISION, ANr AI- L CIMfN· ~ ':.~~~.. =~:;;r;' ~ SlOW' ANL (ì~E:h GI:. ì.l.IL:; A--<E. ':Cf·H(ECì .,,'I.~ ~ Gary D. Drasky ¡ ~ l (í1 · oY.! ..s · ... , '~ ~ - 2",ù~ ... ~ t1fII ·4 ~ '. · .~ ." ~ '. .0- c::>'" .., ., {<'O p ...........e 'r-~~ .:' _\ ~OFESSION~\. \. ~.. "",,,,,,.,~" , u_ NOV. 23, 1977 . ,G.",/D. Drø.sJ<)I..., DtTE SURVEYOR NOTE ELEVATIONS ( M.L.L.W. DATUM) ON TOP WOOD CELLAR WELL NO.4 36.7 WELL NO.5 36.9 WELL NO.6 36.8 ~- . '\\" " jf;' I '-,,: AFE 291781 LEGEND ð. EXISTING WELL CONDUCTOR .\,1.0' II' :} AS BUILT ATLANTIC RICHFIELD CO. WELL NO. 7t 8 JR!Ll SITE ~JC.6 LOCATE';; 'III SE 1/4.CF ¡"'ROTRACTELI SEC L, 6 NE 1/4 OF PROTRACTED SEC. II, TION, R 14E, UMIAT MERIDIAN " . - ..~-.-. --.... _._--. PREPARED BY HfW¡TT V, LOUNSBURY a ASSOC. ì23 W. 6th AVE" ANCHORAGE, AL.ASK* _ DATE NOVEMBERJ~77 SCALE ~5-.!E'£._ CHKD BY u(,; 77- 46 FIELD BK,' . ON OR BEFORE ANUAR,( 03 200Z AOGCC Individual Well Geological Materials Inventory 96-082 Page: 1 Date: 07/07/98 i ~L~COMPLETION DATE -~/3 ~/cf ~/ T t~ I1o~°[ / PERMIT DATA T DATA PLUS RUN RECVD D DIR SRVY ~R~ S PERRY 11800-12024 ~,/~ p ¥~ L~ ~/"/~ ~. F~ ~ .:-'-~o - ~ ~ ) o 96-082 7920 ~D SPERRY GR 2-5 10 -407 09/03/96 03/12/97 DAILY WELL OPS R ~2/~0/~-~/ TO ~O / ~0/ q~/ :/I 7 I¥~ I Are dry ditch samples required? yes ~_~And received? yes~--~ Was the well cored? yes ~Dznalysis & description received? Are well tests required? Well is in compliance Initial COMMENTS Received? WELL LOG TRANSMITTAL March 12, 1997 To: State of Alaska Alaska Oil and Gas Conservation Comm. O~h c~ Q- ~ Attn.: Loft Taylor L°/ 3001 Porcupine Dr. hor e, Alaska 99501 Anc ag - , .- ..... D S. 06-06A, AK_MW-60095 1~: MWD Formation gvaluauon ~o~ · ' h · 'cal data listed below is being submitted herew~t . Please acknowledge receipt by returning a The t~hni ......... :-~ tter to the attention of: si ed copy otthis um~,,~ le Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50_029-20201-01- .., ..'qo:,:'lro~]e 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (907)563-3256 * Fax (907)563-7252 A Dresser industries, inc. Company WELL LOG TRANSMITTAL To: State of Alaska January 29, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 6-06A, AK-MW-60095 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Gamma Ray Logs: 50-029-20201-01 2" x 5" TVD Gamma Ray Logs: 50-029-20201-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ~,~_ASKA OIL AND GAS CONSERVATION CO~w~llSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED ['~ ABANDONED ~] SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-82 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20201-01 4 Location of well at surface ~ ~, 9 Unit or Lease Name 138' FSL, 1065' FEL, Sec 2, T10N, R14E, UM. ; t,,O¢-.~T .~; PRUDHOE BAY UNIT At Top Producing Interval 10 Well Number N/A i '~' "~ _~.....i 6-06A At Total Depth i 11 Field and Pool · 785' FNL, 3348' FEL, Sec 14, T10N, R14E, UM. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 60' RKBI ADL 28315 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 7/20/96. 7/22/96. 7/30/96 (Suspended).I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 12024' M D (8716' TVD) 12024' M D (8716' TVD) YES [~ NO D 2303' feet MD 1900' (approx.) 22 Type Electric or Other Logs Run MWD; GR. 23 CASING, LINER AND CEMENTING RECORD I SE'Tq'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-FOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 # H-40 Surf 80' 32" 300 Sx PF II (approx) 13-3/8" 72 # MN-80 Surf 2719' 17-1/2" 985 Sx AS 9-5/8" 47# MN-80/S-95 Surf 11946' 12-1/4" 1000 Sx CI G, 180 Sx CS I, & 105 Sx As 7" MN-80 I 11613' 11974' 8-1/2" 400 Sx Class G I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Tbg 11691' 11567' None. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Suspended. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO N/A TEST PERIOD ¢I - FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ¢' _ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEP 1 9 199G *Note: 6-6A Coil Tubing Sidetrack Drilling Operations summary attached. * This 10-407 submitted as directed per 10-401 approved on 5/1/96 (Permit # 96-82). Alaska 011 & Gas Cons. Commission A00R1GINAL Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Lower Cret. Unconformity 11 826' 8570' e£CEIv£D Alask~ O# & Gas Cons 31. LIST OF A-FFACHMENTS Summary of 6-6A Coil Tubing Sidetrack Drilling operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _'~~ '~ ~ Title Engineering Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 2~8; If no cores taken, indicate "none". Form 10-407 6-06A DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS 7/20/96: RIH w/window milling BHA. Tagged PBTD at 11972' MD. Started milling window for sidetrack through the 7" liner at 11972' MD. Milled window through 7" liner at 11974' MD. 7/21/96: Completed milling window to 11979' MD, then drilled formation to 11983' MD. Backreamed window & POOH w/milling BHA. MU & RIH w/drilling BHA. Drilled 3.75" sidetrack build w/FIo-Pro to 11996' MD. POOH w/BHA. 7/22/96: RIH w/drilling BHA & continued drilling build section to 12024' MD. POOH w/BHA. RIH w/reamer & reamed shale section of hole to 12008' MD, where BHA got stuck. Jarred on BHA & pumped Hi-Vis sweep. Couldn't move BHA. Disconnected from BHA & POOH w/CT. MU fishing assembly & RIH to latch & jar on fish. Couldn't free fish. POOH w/fishing tools. 7/23/96: MU & RIH w/fishing BHA. Tagged fish & circulated LSRV pill. Could not latch fish. POOH w/fishing tools. RIH w/nozzle & jetted Hi-Vis pill at 11953' MD on top of fish. Circulated CCH w/nozzle. RIH w/fishing BHA & latched fish at 11963' MD. Jarred on fish; no movement. POOH w/fishing tools. 7/24/96: RDMO CTU. Prep rig to PU drillpipe. MIRU pipe shed. Load & strap drillpipe. 7/25/96: Test BOPS. PU drill collars & 2-3/8" pipe. w/fishing BHA. Reversed out drill string. POOH to PU spear. RIH 7/26/96: MU & RIH w/drillpipe. 7/27/96: Continue RIH w/drillpipe & tagged TOF at 11963' MD. Latched spear & jarred on fish. Fish appeared to come free. PU weight indicated spear disconnected from fish. Couldn't relatch fish. POOH w/spear; no fish. MU & RIH w/fishing BHA. 7/28/96: Latched fish at 11963' MD. Overpulled on fish & grapple pulled out. Relatched & pulled four'more attempts; grapple kept pulling out. POOH w/fishing tools minus 75% of broke grapple tool on spear. MU spear & RIH. 7/29/96: Attempted to engage fish but could not latch. POOH w/spear. 7/30/96: ND BOPE, NU tree, & handled pipe. RD & released rig. Additional welIwork has been suspended to evaluate possible future work options. AOGCC Howard Okland 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 6-06A Dear Mr. Oakland, Enclosed are two hard copies of the above mentioned file(s). Well6-06A MWD survey, tie in point 11,800.00', ~ interpolated depth 12,024.00' Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. September 3, 1996 window point 11,979.00', 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SP5 ARCO ALASKA INC. PBU/DS6-06A 500292020101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/96 'f-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE DATE OF SURVEY: 072496 MWD SURVEY JOB NUMBER: AK-MW-60095 KELLY BUSHING ELEV. = 60.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11800.00 8549.90 8489.90 40 30 S 38.00 W .00 6088.90S 2184.20W 11900.00 8626.22 8566.22 40 0 S 39.50 W 1.09 6139.29S 2224.64W 11960.00 8672.45 8612.45 39 12 S 39.50 W 1.33 6168.80S 2248.96W 11976.12 8684.68 8624.68 42 5 S 39.50 W 17.99 6176.90S 2255.64W 11979.00 8686.82 8626.82 42 5 S 39.50 W .00 6178.39S 2256.87W 6458.62 6520.78 6557.44 6567.51 6569.36 11997.78 8699.85 8639.85 49 55 S 39.50 W 41.64 6188.81S 2265.46W 12012.81 8709.22 8649.22 52 54 S 39.50 W 19.89 6197.87S 2272.93W 12024.00 8715.97 8655.97 52 54 S 39.50 W .00 6204.76S 2278.61W 6582.30 6593.56 6602.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6609.92 FEET AT SOUTH 20 DEG. 9 MIN. WEST AT MD = 12024 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 202.95 DEG. TIE-IN SURVEY AT 11,800' MD WINDOW POINT AT 11,979' MD PROJECTED SURVEY AT 12,024' MD SPE ' SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PBU/DS6-06A 500292020101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/96 DATE OF SURVEY: 072496 JOB NUMBER: AK-MW-60095 KELLY BUSHING ELEV. = 60.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11800.00 8549.90 8489.90 12024.00 8715.97 8655.97 6088.90 S 2184.20 W 3250.10 6204.76 S 2278.61 W 3308.03 57.93 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE :-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC. PBU/DS6-06A 500292020101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/29/96 DATE OF SURVEY: 072496 JOB NUMBER: AK-MW-60095 KELLY BUSHING ELEV. = 60.00 FT. 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 11800.00 8549.90 8489.90 6088.90 S 2184.20 W 3250.10 11813.28 8560.00 8500.00 6095.70 S 2189.51 W 3253.28 3.18 11943.93 8660.00 8600.00 6160.96 S 2242.50 W 3283.93 30.65 12024.00 8715.97 8655.97 6204.76 S 2278.61 W 3308.03 24.10 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS OIL GAS OMMISSION / ! / /' TONY KNOWLE3, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 1, 1996 Erin Oba, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 6-06A ARCO Alaska, Inc. 96-082 138'FSL, 1065'FEL, Sec 02, T10N, R14E, UM 1707'FNL, 4095'FEL, Sec 14, T10N, R14E, UM Dear Ms. Oba: 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 (approxirnately 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. S' · David W Johnston BY ORDER OF THE COMMISSION ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill X I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-Entry__ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 60' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28315 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 138' FSL & 1065' FEL, Sec 2, T10N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 847' FNL & 3396' FEL, Sec 14, T10N, R14E, UM. 6-06A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1707' FNL & 4095' FEL, Sec 14, T10N, R14E, UM. June, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 13328' MD / 9040' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11970' MD Maximum hole angle 90° Maximum sudace 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD ']-VD MD 'rVD (include stage data) 3-3/4" 2-7/8" 6.4 LB0 FL4S 1678' 11650' 8436' 13328' 9040' 15 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12966 feet Plugs(measured) Fill @ 12290' (4/15/94) & Cmt Plug @ 12332' MD. true vertical 9412 feet Effective depth: measured 12290 feet Junk (measured) true vertical 8922 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 2 0" 300 Sx PF II 8 0' 8 0' Surface 2696' 13-3/8" 945 Sx Arcticset 2719' 2719', ._~?) Production 1 1924' 9-5/8" 1000 SxG, 180 SxCS I, & I 1946' 8671 ~,~ - 105 Sx AS Liner 1347' 7" 400 Sx CIG 12960' 9439' Perforation depth: measured 12036- 12056'; 12206-12246'; 12258-12290' r~F~ ?. '~ true vertical 8729 - 8745'; 8859 - 8889'; 8898 - 8922' ~,j~.,~l~. 0JJ ~. G~.S 00~,. CC~ 20. Attachments Filing fee ~x Property plat __ BOP Sketch _Z_x Diverter Sketch _ Drilling program x_Z_ Drilling fluid program__ Time vs depth plot_ 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 ~'~ ,4,,~--~ %. ~ Titlle Engineering Supervisor Date ZT~ -/'~ - Commission Use Only "~'~'"i~-- I APInumber I Approval d, ate/~(/¢, I See cover letter for · -' 5 0- ~,, ~' ~ ~ O ,~,~ ~' - ~::~J ~ / I other requirements Conditions of approval Samples required __Y e s ~L N o Mud log required __ Y e s ,~ N o Hydrogen sulfide measures ,~ Y e s N o Directional survey required ~ Yes __ N o Required working pressure forBOPE __2M; __ 3 M' __ 5 M · __ I 0M' __ 1 5 M X~3500 psi for CTU Other: Original Signea By David W. Johnston byordero,~.//~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplica DS 6-06A CT Sidetrack and Completion Intended Procedure Objective: Directionally drill-725' horizontal well in the Sag, drop angle and drill a conventional well to the Zone 4 target. Complete with 2- 7/8" cemented liner. Intended Procedure: P&A existing interval. Mill window in 7" casing at ~11,970' md. Build angle to horizontal at -40°/100. with 3-3/4" bit. Directionally drill -725' horizontal wellbore in the Sag formation. Drop angle through the Shublik, place a deviated wellbore through Zone 4. Run openhole logs. Run and cement 2-7/8" liner to TD. Perforate selected intervals. · Return well to production. April 16, 1996 DS 6-06A Potential Drilling Hazards POST ON RIG Tested as high as 70 ppm H2S production (9/14/93). DS-6 is an H2S drillsite. Follow H2S precautions while onsite. BHP' 3510 psi @ 8800' ss (7.7 ppg EMW), BHT 215 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas: 2800 psi. Kickoff depth will be in the Kingak shale. Monitor hole stability closely. There is an 80' down thrown fault in the Kingak shale. Monitor pit volume for potential LC when crossing the fault. Potential high perm intervals in Zone 4. Hydrostatic pressure will be-1000 psi overbalance with 10 ppg mud. Watch for differential sticking tendencies or LC. Avril 16, 1996 DS 6-06A Proposed Sidetrack Items in Bold to be Installed by Coiled Tubing 2203' 4-1/2" Otis HRQ Nipple (3.813" ID) 4-1/2" Tubing 11,567' · 9-5/8" X 4-1/2" Baker DB Packer. 11,613' 11,680' 11,700' 11,945' 7" Liner Top Top of Liner ~11,650' 4-1/2" XN Nipple 4-1/2" Tubing Tail ELM 9-5/8" Casing Shoe Window Cut in 7" 3-3/4" Open hole casing with CT @ ~ 11,970'. / :::::::::::::::::::::::: ~-- :::::::::::::::::::::: TD @ + 13,328' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 12,960' 7" liner 4/16/96 DTK DRII.EX ARCO ALASKA (INC.) 6-06 OIREC1tONAL SlIDE'I'~ACK PRLI[3HOE EI~¥ l~'tl~ ReL TO ~Frue I pag _J ARCO/tJ_ASKA INC. I TE. ~1 POtN~ 14N MD tllOO 40,5' 860O - -- 88oo ,= ..i gO00 - 9200 2 OI 3~.'5--i100 TI 0-' ~t9 SS KOP .. MO 72101 ORIGINAL WELLBORE 1'; :1 [1'1 ~ I 11;'[ ~-' o Vertical Section Scale 1 inch ' 200 ff ST..O43T ~IDE'I'RAGK PLAN tN TRUE NORTH 6-OSTRJEORIGINAL WELL IN TRUE RELATIVE COORD:5. E/W SCALE 1 INCH · 400 FT .[.[.~.1..:.~.1 [.1 I. I..LI I z[~.lt ILL, I ~ - ~ ,_~ uo ~ ~,~ 7~ ~ ~---7200 FILE NAME : O:'b~RCOALK~6-,GA~6-.~A2 OW2 DRAWN BY ' BiMO HADIPU TRO DATE . APRIL 16, PLANE OF VERTICAL SECTION 202,g5° REFERENCED FROM TRUE NORTH. I ~i..I. JU 411'[5f~5 '~l '~ :-~ A~ ' ............. '~-~0 6~'A'SIDETRACK ApriI'~¥996'PLA~ PREPARED FOR Dan"Ka'r~-i'P'~E. 'Arco Alaska) VERTICAL SECTION USED, ........ ?~-2~'95= Relative"~'~"~'~'~-~-~ah . ' ............. ~ .... .-'.",'. ................................................................... ..... : ........ 6'0" .... : ......................... ........................ .......... "Relative Cooaina'tes are off ~f.t_rue Noah/A'SP,'aZ.~?~.~ve t~"g}~No~ ........................ ~ .................. NOTE ..................................... ~ ..................... , ................... ..................................... MD' ' Inc." ....... 5~'~'; SS DEPTH: VS N/~ E/-W Build Turn~ D~I~ ......... -~'~- ........ ~'P X':c°mments .................. ff d~ deg ff fi' ~ ff~ d~'gl100 d~llO0~ deg/100 fl~ 1180~b ...... 405 2-i'~.~- ..... 8489.9 .... 64~8'~'~ .... ~g~9---~2184.2~ O~- 0'.0; 0'-0 5~'345~'4~0 ....... 68~'8~.9"1. ~IE'IN ·POINT '1'1820,0 40.5 2i9.0 ....... 850~'.'~ .....6471.1 -6099.0 "21'~-~'~ ....... -~'0 .........0,b~ ........ 0.0 5934584,0 683887,0 .................... 11850~0: 4~'~ ..... '~9.0 8527'.9 ........ ~4-~:8 .....:6i"i4.'1~ '2204.6~ 0~0 ...... 0,0' 0~0 ......... 5934568.5 683875 1 .......... '1'188~ ........... ~5~' 219.0 ~550,7 6508.5, -6129.3~':2~-1-6.9 0.0 0.0' 0.0 ..... 5934'5~3'~0 .....6~38632 11910,0 405: ~9.0" e~y~ ...... ~-5'~'~"~3~ :6144,4'-2229.2. 0,0 o.0' 0.0' 5934537.5 683851.3 ....................... ~ .......... ~ .......... ......................................................................................................................... 11940.0 40,5 219.07'---8596.3 11970.0! 40.5 219.0~ 8619.1 12000 0 ~'.5 21'9.0- ....~640,0 12030,0 62.4' 21-~-0-" 8656.3:' 12060.0 73:4'' 219.0 866:7.6; 6546.0 -6159.6 -2241.4 0.0 0.0 0.0 '65641'7 -6174.7' -2253.7 ..... 0.0 0.0 0.0 6585.'4 .61911'4 ..... -2---2-6-7~2 .... 36..5 0.0 36.5- 6609.5 -6210.9 -2~83---.~-- ......~6~$ Q0' 36.5 66362 -6232.~) ;~-300--~- 36.5: 0.0 36.5 5934522.0 683839.4 5934506.5 683827,6 2. KOP 35.5° BUILD 5934489 5 683814,4 5934470.0 683799,1 ' 5934448.0-' 6837822 . . 12090~-0 84.3 2'i9':'0- ' 12101.8:~ 88.6 219.0' 12120.01 888 ' 219.2' 12150.0 88.6 219.5'~ 12180.0. 88.6.. 2.'19.8 12210.0 -88.6' 12240.0 -88.6 12270.0 '88.6 :{2300.0 88:6 ..... 12330.0. 88.6 123'-8-1;J. 0 '88.6 22-i .-6' 123c~0-.'~ ....88.6 22! .9' 1242{~-- 88.6 222.2 867'3.4 8674.1 6664.4 -6255.3 -2319.0 6675.'/'' -6264.5 -2326.~t' 8674.6 6693,2 -6278.6 -2337.9 8675.3 ' 6722'.0' ":630i.8: -2356.9' 8676.0 6750,7. -6324.9~ -23~6.0-- 36.~'[ .............. '-0:0 ..... 36.5 5934424.5 36.5 0.0 36.5 59344'15.0 0.0: 1.0 1,0 5934401.0 683764,3 683757.1 3. EOB EXTEND 725' TO 8692' 683745,9 220:'i------~'67~8' 6779.4 -6347.9' -2395.3~ .... '-22'0':'4' 81~7~ ...... -6808.1 -6370.8' -2414:6: '- 220.7 8678,Z; 6836.6 -6393.6t -2-;434.1 221,0 8679.0 6885.2 -6416.3; -2453.7' 221.3 8679.7! 6893~17- -6438.9' -2473.5~ o.oi 0.01 0.0 , 1.0 5934330.0 683690.3 1.0 1.0 5934306.5 683671.5 1.0 I 0 ..... ~-9-34283.5 683652.6 1.0 '-~.0 5934260.5 '(~8~3633.5 1.0 I 0 5934237.0. 683614 3 8680.4- 6922.i -6461.4: -2493.3' 8681 2 6950.5 -6483.7 -2513.3 i~-~':9' 6978 9 -6506.0 0.0 1.0 1.0 5934214.0' 683595,1 O.O' 1.0' 1.0 ....... ~,'~,'2,. 19---1~'~- ...... 683575.6 -2533.4. ...... ~d ............... ~ ....... ~-.'0"' 5934168 5' 683556.1 0.0' 1.0 1.~ 0.0 1.0 1.0 5934377.0 683727 5 5934353.5 683708,9 x llJ I--I 88.6 222.5 8682.6 7007.2 -6528.2 -2553,6 Ot~'tjU 1 0 1 0 5934146 O 683536.5 4/i6/96' 11 :Ltg'A,~-~ 12-~80,0' 88.6 22-2-.'~ ..... 8683.4 7035.4 -6550.3 -25739 0,0 1 0 1.0 5934123 5 683516.7 ..... 12~100 88.6: 22~.~-" 8684.1 7063.6 ~572,2 -2594.3 0,0 10 1.0 5934101,0 683496.8 125'40.0 88.6i'' 223.4 8684,8i 7091.'/" --6594.i' -2~614'.i~'i ..... '(]lb' 10 1.0 5934078~5 683476.8 .... 125'7'0,0; 88,6 .....~23.7 868515 7i'1-9.8 .... -66'j5.8i -2635,5!' 0,0 I0 '-1.~~' 5~'3A'~§6,5 6'8~4~;~'i~ ................................. ':1~600.0 88.6 22~'.-0-- .... -~86,3 71478' -6637.4i' --2--6-~';~ ...... 0.0 1.0 1.0 5934034,0 683436.5 _ 1263010- ......~8.6 .... 224.3 8687.0 717~'.§ :6659.01 -2{7-~.-~-- ........~'i~) .... 1"~' ........... -~'i'~)' '5934012~O 6834'161i .... 12660,0 ..... ~.6: .... 224.6 ..... ~i~87.'7' 72(]3.7 -6680.4 -2698,2' O.0 1.0' 1,0~ 5933990,0' 683395.7 .... ' .......... 126-90.0 88.6 .... Z-2'~.'~- ...... ~688,5 7231.5 -6701.7 --271~,3 ......... 01'0 ...... 'i10 ......1,d' -593;3~6815' 683;~7511 ..... '12'~)i0: .......... 88.6 225'12 -'-8~J~§.2 7259.3 -6~22.9' '~7'40-~.§ ...... Oi0" 1.0" 1.0i 5933946'.'~ .... ~-83354.4 ....................... 12750.(J .... '~.~3' 225.5; 8689.9 7287.0 -6744.0 -276~".-8- .... -0~'0- .......... 1.0 1 01 ..... {§~'~§'~5'O 127~8~-' 88,6'~- 225.8. 8690.7 ............. ~-;J'~4'.7 ..... :67~'i'{~ .... -2783,3 0.0 1.0: 1.0~ 5~'~-~9'~"~.~> ..... 683312.7_ ' ................... '." .... 12810.0- 88.6 ......... 22----6.1 ;'- 869'1.4 .... ~'342.3 -6785.8 "--'2804.8 0.0 ' 1-.0'i ..... 1 ~) ..... 5933882,0 ..... 683291.6 ............ 12826.8: 88.6 .....2-26.3 ..... 8691,8 -'73~';7- ......... -6797.4. -2816.9: "" 010 ..... '1.0'i ..... i.0. 5933870.5 683279.8'4. 8692Ss'REAcHED .......... "~'2-840,0 86,0 .... 225.4 86i~'.'4 ....... ?~369.9': -6806.6;-282~1-~ '~-.'~- -6.2~i 20.7 '5933861.0 683270.6'DROP DOWN TO 128701'b ..... 80 1 223.'6-- §i~'96.0 ¥3§7.6~ -':1~8~'.;8-":~28472- 19.7 ....... -6'.3'i 20.7· 5933839.0 683250.3' 1290-0-.~-" 74,2! .......... 221.6 ~-0~77 .......7425.1 .6849.4i-2867.0':' 19,7 -6.5 20.7 5933817,'0' '683231.0, · _ -'12930 0 ...... 68.3 21·9.5 8712.4 74522. --6~70.9 .-2885.5- '19,6 -6.9' 20.7' '5{i-3~7-9-51~' -~'~.~2i'3.'1 .............. 12960.0 62.4 217.3' 8724.-9 .... 747-815 -6892,3':-29021;4- 19.5 ..... -'7'1'5~ ........... -~0~7'; ..... 5-93~773-:'5" -683196':? ......................................... 12990.0 56.6· 214.8 8740.1 7503.'6 -'6cji3.2-2917.6- 19,4· -8.3: 20.7' 5933752.0 683.182.0 ............. 1302{Ji~-- ....~)'0.cj''- 211.9' 8757.8 7527.4 -6933.3 -2930 9- 19.2 ..... '-'~'~5 ...... -~'0','~ ..... 5933731.5 683~6{)12+ ................................ 13050.0~ 45.2· 2~:"6" 877'~'~9-- f~§'~ .....-6952'6"-2942.2- 18.9; -1i.2; 20.f" 5933712.0 13060.o'- 431~' ...... 207-~----8785.0 7556,5 -6958,8:2945.5- 18,7- -'12,7~' -20,7 5933706,0 683155.3 5. TARGET 1 8785'-$S 13080.0' 43.3 207.0 8799.6 75'~0.'i-' -.-697':i'.0"'-2951.7 0.0-- -1"~: ........ 1.0 5933693 5'- 683149.3'EXTEND ~0'~198~"S$ 13110.0 4.3:~- 206.6 8821.4 7590.7 -69893' -296i.0- 0.0 -1.5! 1.0! 5933675.0 683140.5 -- 13140.0~- 43.3 206.1 8843.2' 7611.~)- "--7-~0~7:8 -2970',1 0':b .......:~.~;-' 1.0! 5933656,5 683131.9 .................... 13170.0 43.3! 205.7 8865.1 7631.8' -7026.3 -2979.1 ......... 0.0' -1.5~ ..... ~'.i3;~5933637 5 683123.3 13200.0 43,3! 205~:, 8886.9 7652.3 -7044.9 -2988.0 0.0 -1.51 1.0 5933618.5 683114.9 13230.0' 43.31 ....~)4.8! 8§08.7! 7672.9 -7063.5'-2996.7 0.0 -1.51 1.0~ 593360~3'.0- ........ ~8~:1"06.7 ....... 13260.0 437~ 204.41 .... ~--~-,'-0'~5':7693.5 -7082.3-3-0'0~12' 0.0 -1.5~ 1.0:5933581.0' 683098.6 13290.0 43.4 203,9 8952.3' 7714.1 -7101.1 -30"i~,'~-6- ...... d'i-O! .......... --'~.-5'~ ....... '~'~'0' 5933562.0 68309-0.-6 i'3~20~0 43.4 203.5 8974.2~ '773';l'.7 -7119.9 -3021 9 0.0' ' ';'1.51 1.0 - 5~3-3-,~43.0" -6-83082.8 13328.1 43.4 203.4 8980.0" 7740.2' -71250 :~'O~.~.'.~ .... 0.0' -1.5 ...... '~.~3' 5933537.5 683080.715. TD Ell i JGI!E~J.L /ap~ uns ,~JJeds Tiger Tank Open Top Tank Open Top Tank C T Drilling Wellhead Detail ~' CT Injector Heed . ~ .~L~ Stuffing Box (Pack-Off), 10,000 psi WorkJng Pressure o,~ ~' w~ o.k,k [ I co~ct ~ L I 21 Pure Inl 5.1/8- ID CT BOP Stack ~j~l'~" P'i ~= Cuttars or Combination Cutler/Blinds ~ ]11 ~'~ ! ~ Slip /Pipe rams $'000 PSI w°l'~ing Fes'~ur' RECEIVED Alignment Guide Flan; Ram Type Dual Gate BOPE~ ManuaJ over Hydraulic 7-1/16" ID with Pipe/Slip Rams Flanged Fire Resistant Kelly Hose To Dual \ ChokeManifold \ APR 2 2 1996 Alaska Oil & Gas Cons, Commission Anchorage Manuel Valves Ddlllng spool 7-1/16", 5M by 5-1/8", 1 OM j Tubing Hanger o.4~ (5.5") 9-5/8' Annulus 13-3/8' Annulus X Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 1 O' from Tree l--.. STATE OF ALASKA .... ALASKA ,_AND GAS CONSERVATION CO ,ISSION APPLICATION FOR SUNDRY APPROVALS' 1. Type of Request: Abar~on X Suspend Operation shutdown Re-enter suspended well , , Alter casing Repair well Plugging X ,L Time extension Stimulate Change_ .aporov'--=~ omgram Pull tubing Vanance Perlor~te 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage. AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 138' FSL & 1065' FEL, Sec. 2. T10N, R14E. UM. At top of productive interval 824' FNL & 1873' FWL, Sec. 14. T10N, R14E. UM. AT effective depth 1196' FNL, 1561' FWL, Sec. 14, T10N, R14E. UM. At total depth 1242' FNL & 1523' FWL. Sec. 14, T1 ON, R14E, UM. Ot he'r 6. Datum of elevation(DF or KB) 6O' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-06 9. Permit number 76-2O 10. APl number 50 - 029-20201 11. Field/Pool Prudhoe Bay Oil Pool feet !2. Present well condition summary Total depth: measured true vertical 12966 feet 9412 feet Plugs(measured) Fill: 12290' (4/15/94) & Cmt Plug: 12332' MD. Effective depth: measured true vertical 12290 feet 8922 feet Junk(measured) Casing Length Conductor 80' Surface 2696' Production 11924' Liner 1347' Perforation depth: Size Cemented 20" 300 Sx P F II 13-3/8" 985 Sx AS 9-5/8" 1000 Sx Cl G, 180 Sx CSI. & 105 Sx AS 7" 400 Sx Cl G measured 12036 - 12056" 12206 - 12246'; 12258- 12290' Measured depth True vertical depth 80' 80' 2719' 2719' 11946' 8671' 12960' 9439' true vemcal 8729 - 8745': 8859 - 8889'; 8898 - 8922' Tubing (size, grade, and measured depth) 5-1/2'. L-80, 17~, Tbg ~ 43' MD; 4-1/2", 12.6~, L-80,f~r~ 1691' MD. Packers and SSSV (type and measured depth) Baker DB Packer @ 11567' MD: 4-1/2", Otis HRQ SSSV @ 2203' MD. 13. At'tachments Description summary of proposal x Detailed operations program .. BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: June. 1996 ' 16. if proposal was verbally approved ' Oil X Gas Suspended ~ Name of al)prover Date approved Service 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~_~ ")'/,q, , ~ Title Engineering Supervisor Date ~"~ -/~'- ~.~, .o. Con,itions of approval: Notify. Ccmm,ssion so representative may witness Il Approval No~,/;. ~/v_., 0~,(77 Plug integrity __._ BOP Test Location clearance Mechanical Integrity Test ,. Subsequent form required 10- Approved by order of the, Comrmssioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY /~C---CD I~i~ CL~S _/~~ · PROGRAM: exp [] dev~ redrll~serv [] wellbore seg [] ADMINISTRATION 1. Permit fee attached .................. N · 2. Lease number appropriate ............... ' N 3. Unique well name and number .............. ' N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ...... N 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. ' N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order ..... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ........ N ENGINEERING REMARKS 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf cng. 17. CMT vol adequate to tie-in long string to surf cng . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. reserve pit If a re-drill, has a 10-403 for abndnmnt been approved. Adequate tankage or ............. 21. 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 5~-~-~ 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 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. ~eabed condition survey (if off-shore) ........ ~/~ N ' 34. Contact name/phone for weekly progress reports . . . .//. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DW~ Comments/Instructions: HOWlljb - A:\FORMS-~cheklist rev 11195 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. Tape Subfile 2 is type: 3 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW- 60095 B. JAHN BASS/MOONEY D.S. 6-06A 500292020101 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 03-MAR-97 MWD RUN 3 B. JAHN BASS/MOONEY MWD RUN 4 B. JAHN BASS/MOONEY MWD RUN 5 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD B. JAHN BASS/MOONEY 2 i0N 14E 138 1065 60.00 MICROFILMED Date OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 13.375 2719.0 3RD STRING 9.625 11946.0 PRODUCTION STRING 3.750 12030.0 REMARKS: MAR ~2 1997 Ng~-sk.,a O;1 & Oas Cons. ~mmission MWD - GR. ALL DEPTHS ARE MEASURED DEPTHS ALL GAMMA ILAY DATA WAS DOWNHOLE RECORDED. THERE WAS NO LOGGING DURING MWD RUN 1. MWD RUNS 2 THROUGH 6 WERE DIRECTIONAL WITH SCINTILLA- TION TYPE GAMMA RAY (NGP/SGRD) . THE WINDOW WAS CUT IN THE 7" CASING FROM 11974' TO 11979'. THE TOOL WAS STUCK ON MWD RUN 6. NO LOGGING WAS ACCOMPLISHED AND NO DATA IS PRESENTED. THIS WELL REACHED A TOTAL DEPTH OF 12030'. NO DEPTH SHIFTS WERE APPLIED, PER CONVERSATION WITH MIKE IRWIN OF ARCO ALASKA (13-FEB-97) . FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11929.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12003.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 11950.0 11970.0 3 11970.0 11984.0 4 11984.0 11996.0 5 11996.0 12030.0 MERGED MAIN PASS. CN WN FN COLIN STAT : ARCO ALASKA, INC. : D.S. 6-06A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 12050.000000 Tape ~ile End Depth = 11900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 904 datums Tape Subfile: 2 96 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11929.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11946.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) · REMARKS: MWD RUN 2. 20-JUL-96 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 11970.0 11950.0 11970.0 0 38.9 38.9 TOOL NUMBER NGP 246 3.750 11946.0 SALTWATER 8.60 .0 .0 0 .0 .000 .000 .000 .000 .0 89.1 .0 .0 .00 .000 .0 0 se~Xq ~IOT se~Xq ~9 :M~BueI p~ose~ mnmlxeH :M~BueI p~ose~ mnmlulH · -'sp~ose~ £9 £ :elT~qn$ ede$ smn~p ~06 89 :epo0 deH :X~mmns Bulposep epos uol~e~uese~de~ qeeg = SqTUQ qqdeG elis 00000S'0 = BUToeds IeAeq elT~ 000000'006II = q~de~ puz eil~ 000000'0S0~I = q2deG 2~e2S ell~ :sp~ooeH ~eG Ie~O& 66 666 06 f I0 0I£ 06 f ~ Id~-tf I 89 GMH ~© I poH sIO clXL clK£ q~6ueq ez!s A~D A~O IdV Id~ Id~ s2lufl seIdme$ epoo IOOL emeM :SeA-n0 ~ ~ :GI q~dep ZHtf~ ~Zd H£dZ~ ZNO (~9 #ZdX,T,) GHOOZH ,T,Ifk~O,~ ~ tr'~SVq~ : ZdOqS HLHON : X~ ZOHG~Hd : ~90-9 'S'C : 'OMI 'tf>tsvq~ OO~ltf : L',LrlOD NM 0 0' 000 ' 00' o O' £'0/. O' 000 ' 000 ' 000 ' 000 ' U'~ 00L9I 0'0I 0'~9 00'0I OHd - 0'9~6II 0S£'£ HZ~MflM qOO~ 9'~ ~'6£ 0 0'~86II 0'0L6II 0'~86II ~£'T DSM ' (ZH) XOMZO~ZH,~ HM~ : (MI) ,~,4OQbI~fdlS qOOJ, :(MI) MOILDZHHOO ZqOH (~©ZG) ZHflL~ZdMZL i~ (MMHO) XLIAILSISZH : (Hdd) SZ~IHOqHD :Hd : (S) X~ISOOSIA : (e/~q) X~ISMZG GOH SMOILI~HOO ZqOHZHO~ : (MI) ZZIS LI~ ZqOH ~L~G ©MIS~O ~k~g ZqOHZHO~ $ ZdX£ qOO,T, ZGOD qOO,T, (MOLLO~ O.T. dO,T,) D~IIHLS qOO.T. 0'I96II HLdZ~ dOLS 'SeIT~ eq~edes uT un~ qTq qoee xo~ eqep ~epeeq 8oI pue sexxn0 HZ(I~ZH ZqI~ SIq :ecL4q sT ~ elT~qns ede~ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 6-06A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 O1 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 4 Tape File Start Depth = 12050.000000 Tape File End Depth = 11900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1808 datums Tape Subfile: 4 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11961.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11979.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) · REMARKS: MWD RUN 4. 22-JUL-96 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 11996.0 11984.0 11996.0 0 .0 .0 TOOL NUMBER NGP 256 3.750 11946.0 FLO-PRO 10.00 64.0 10.0 16700 4.2 .000 .000 .000 .000 .0 70.3 .0 .0 .00 .000 .0 0 :q~6usI p~oos~ mnmTx~~ :qjBusI p~oos~ mnm~uT~ smn~p 808T 89 :spoo d~H :X~emmns Buypoo~p ~poo uoy~e2u~s~d~ SI% ~g = s~TuQ q~d~G ~ITg ~de~ 00000~'0 = 6UTo~ds I~q eITg ~d~ 000000'006II = q~d~G pu~ ~IT~ ~d~ 000000'0fi0~I = qqda~ q~qS ~IT~ ~d~ :sp~oo~H ~q~G I~qO~ 66 S66 06 f I0 0I£ 06 f ~ IdtFf I 89 ~MN H© pon sIO clXi dA£ qqBusq SZTS SqTU~ s~Idmes ~poo IOOi sm~M %fM Stfq~ : ,qdO~IS Hdl%{O~I : Xtf~t ,~OH~fl~td : tf90-9 'S'(I : · O~II 'tf){Stfq~f OOHtf : NflOO Ng NM ND Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11979.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12003.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: MWD RUN 5. 22-JUL-96 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 12030.0 11996.0 12030.0 0 .0 .0 TOOL NUMBER NGP 256 3.750 11946.0 FLO-PRO 10.00 64.0 10.0 16700 4.2 .000 .000 .000 .000 .0 70.3 .0 .0 .00 .000 .0 0 :q25u~I pxoo~ mnmTxeM :q2Bu~I p~oo~ mnmTuT~ · ''sp~oo~ L9 9 :SIT~qns 89 :~poo :X~mmns BuTpossp ~poo uoTje~usss~ds~ SI~ 00000S'0 = 5UTomds i~q aiT~ adeL 000000'006II = q~dsG puz sIT~ sd~L O00000'OSO~I = q~d~c ~e~S ~IT~ sdeL 66 ~66 06 ~ IO 0I£ 06 9 pox sIO dXi dXi q~Buaq sz~s Y){S~fT~ : ZdOqS HLHON : X~ ZOHJ~Hd : ~90-9 'S'G : 'OMI '~QI$~T~ OO%t%f : N_GOD NM Tape Subfile 7 is type: LIS "~ 97/ 3/ 3 O1 **** REEL TRAILER **** ~7/ 3/ 3 O1 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~nd of execution: Mon 3 MAR 97 8:51a Elapsed execution time = 1.81 seconds. SYSTEM RETURN CODE = 0