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200-037
Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL KU 24-32 (PTD 220-037) ACX 08/04/2019 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 2200370 E-Set: 34241 Abby Bell 11/13/2020 \ STATE OF ALASKA ~. ALASKA ulL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25 105 20AAC 25 110 0 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: 4577' FNL, 1008' WEL, SEC. 02, T10N, R14E, UM Top of Productive Horizon: 2622' FNL, 144' EWL, SEC. 01, T10N, R14E, UM Total Depth: ,v EL 11,:1/ 2176' FNL, 4327',ÞWt, SEC. 01, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685970 y- 5941299 Zone- ASP4 TPI: x- 687073 y- 5943283 Zone- ASP4 -- Total Depth: x- 687870 y- 5943750 Zone- ASP4 18. Directional Survey 0 Yes IBI No 21. Logs Run: MWD & GR, MEM CNL / GR 22. Zero Other 5. Date Comp., Susp., or Aband. 5/28/2004 6. Date Spudded 4/21/2000 7. Date T.D. Reached 5/23/2000 8. KB Elevation (ft): 74' 9. Plug Back Depth (MD+ TVD) 10531 + 9015 10. Total Depth (MD+ TVD) 10638 + 9004 11. Depth where SSSV set N/A MD 19. Water depth. if offshore NIA MSL CASING SIZE 20" 13-3/8" 9-5/8" WT. PER FT. 91.5# 72# 47# 29# 6.16# CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE GRADE .1 OP bOTTOM .1 OP BOTTOM SIZE H-40 Surface 79' Surface 79' 30" L-80 Surface 2525' Surface 2525' 17-1/2" L-80 / S0095 Surface 9016' Surface 8516' 12-1/4" L-80 8697' 9520' 8235' 8941' 8-1/2" L-80 9110' 10638' 8597' 9004' 3-3/4" 7" 2-7/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 27. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 8657' 4-1/2", 12.6#, N-80 8754' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 24. TVD 25. DEPTH INTERVAL (MD) 9145' 9051' 9051' , -1'" 14 1b. Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 200-037 304-188 13. API Number 50- 029-20808-01-00 14. Well Name and Number: PBU 06.23A 15. Field / Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028311 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 1990# Poleset 2400 sx Fondu, 400 sx PF 'C' 500 sx Class 'G', 50 Bbls PF 'C' 325 sx Class 'G' 94 sx LARC AMOUNT PULLED PACKER SET (MD) 8644' AMOUNT & KIND OF MATERIAL USED Set CIBP Set Whipstock P&A with 10 Bbls Class 'G' GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR OIL-BBL TEST PERIOD -+ CALCULATED..... OIL-BSL 24-HoUR RATE""" GAs-McF WATER-BSL OIL GRAVITY-API (caRR) 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 (ì D I r.1 ~JA L CONTINUED ON REVERSE SIDE ~ , t\ f -' 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". Top Zone 2B 9549' 8964' None Top Zone 2A 9708' 9048' 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 --{~. tit I ~ Tille Technical Assistant Date 0'7., L{. DC{ PBU 06-23A 200-037 304-188 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit NO.1 Approval No. Drillmg Engmeer : Thomas McCarty, 564-4378 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 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 ror 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: Ir 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: 06-23B Prudhoe Bay Unit 50-029-20808-02-00 204-087 Accept: Spud: Release: Rig: 06/05/04 06/08/04 06/16/04 Nordic #1 PRE-RIG WORK 02/06/04 RAN SCMT LOG FROM 8654'-9625'. FOUND TOP OF CEMENT AT 9180'. DEPTH CORRECTED TO SLB PERF RECORD DATED 7-JAN-04. BOTH PASSES ARE FULL INTERVAL AS PER PROGRAM. LOGGED UP AT 1800 FT/HR, AFTER PUMPING 300 BBLS 1°0 KCL DOWN TUBING. LOGGED AT 0.5 BPM. PUMPED TOTAL OF 360 BBLS WATER, 15 BBLS MEOH, 100 BBLS CRUDE TO FREEZE PROTECT WELL. PAD OPERATOR NOTIFIED WELL LEFT SHUT-IN. 03/09/04 DRIFT WI 4.56 G-RING TO TOP OF DSSSV @ 2071' SLM. PULLED 51/2" CAMCO DSSSV. DRIFTED WI 3.80 CENT & SAMPLE BAILER. TAGGED TOP OF DEPLOYMENT SLEEVE @ 8664' SLM. CALlPERED TBG FROM 8662' SLM TO SURFACE (GOOD DATA). BRUSH SVN @ 2071' SLM. SET DUMMY SSSV @ 2073' SLM (ID 2.26"). OS/22/04 DRIFT W/4.7" GAUGE RING TO DSSSV @ 2068' SLM, PULLED 5-1/2" DSSSV W/2 SETS OF PKG. SET 4-1/2" XN C-SUB @ 8676' SLM. PULL RK LGL V 16/64" PORTS 1868# TRO @ 2914' SLM ST A 1. OS/23/04 PULL GLV'S, SET RK- DGLV'S STA # 1,3,6,9. SET 5 1/2 DB - DSSSV THREE SETS OF PKG @ 2070' SLM. LRS MIT-IA TO 3000# (PASSED) BLEED IA DOWN TO 220#. PULL 5 1/2 DB DSSSV 2070' SLM. PULL 4 1/2 XN - CS @ 8676' SLM (CS EMPTY). RDMO. OS/27/04 RAN 2.25 CENT & 1.75 SAMP BLR TO 9705' SLM (HAW). LATCHED DEPLOYMENT SLEEVE W/4 1/2" GR @ 8670'. JARRED UP UNTIL TOOL SHEARED INDICATING FISH NECK IN GOOD SHAPE. OS/28/04 SET WEATHERFORD 2.20" CIBP AT 9145', STRING SHOT 9110'-9122' AND SHOT CHC AT 9120' AS PER PROGRAM. CHC WAS 2 1/8" AND STRING SHOT WAS ONE STRAND. 05/30/04 RIH WITH 3.5" GS. TAG AND LATCH LINER TOP AT 8718 (DOWN). PICK UP AND LINER PULLS FREE. PUMP OFF AND POH. FREEZE PROTECT TO 2000 WITH 50/50 MEOH. NOTIFY DSO THAT WELL REMAINS SI. RDMO. BP EXPLORATION Operations Summary Report Page 1 418 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: Date From - To Hours Task Code NPT Phase Description of Operations 6/5/2004 04 :30 - 04:45 0.25 MOB P PRE Rig released from 02-06B @ 04:30Hrs on 6/5/2004. Prep to move rig off well. 04:45 - 05:00 0.25 MOB P PRE PJSM for moving rig off well. 05:00 - 06:30 1.50 MOB P PRE Pull rig off well. Clean up location. 06:30 - 07:00 0.50 MOB P PRE Held pre-move safety meeting. 07:00 - 14:00 7.00 MOB P PRE Move rig from 02-06B to 06-23. Conduct pre-operations pad inspection. 14:00 - 14:30 0.50 MOB P PRE Lay 8 matting boards & 2 composite boards in front of 06-23 well. Check WHP - Opsi with a closed SSV. 14:30 - 14:45 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 14:45 - 15:00 0.25 MOB P PRE Back rig over well & set down. ACCEPT RIG @ 15:00 HRS ON 06/05/2004. 15:00 - 17:30 2.50 RIGU P PRE PJSM with Peak crew on CT reel swap. P/U & lower reel to Peak double drop trailer. Replace reel drive bushing & bolts. art Critical Path Operations: - N/U BOPE, grease tree valves & open up SSV. 17:30 - 00:00 6.50 BOPSUP P PRE Perform initial BOPE function/pressure test. AOGCC test witness waived by John Crisp. Off Critical Path Operations: - Spot trailers & tanks & continue replacing reel drive bolts. IPRE - Swap seats and valves on SPM pump. 6/6/2004 00:00 - 02:00 2.00 RIGU P Continue to spot reel Slip and cut drilling line. 02:00 - 04:45 2.75 RIGU P PRE Connect and test coil/wire rope connection. Spool coil to injector head. 04:45 - 07:00 2.25 FISH P DECaMP RU and test Baker coil connector. - Pull 30k Pump coil volume. Pressure test coil connector to 3500 psi. Pressure test hardlines to 3500 psi. Install dart catcher. Load wiper dart. Launch & chase with 2~o KCL. Dart hit @ 57.8bbls. PT CTC to 3500 psi. 07:00 - 07:30 0.50 FISH P DECaMP Open up well & observe 200psi WHP. Attempt to bleed off to tiger tank - observe 2ndary 3" line to tiger tank on choke manifold plugged. Bleed off well to tiger tank thru primary line via MM out. Flow check well for 30m ins - stable. Meanwhile held pre-operations safety meeting. Reviewed well plan, potential hazards (H2S monitoring/response) & fishing BHA M/U procedures. 07:30 - 08:15 0.75 FISH P DECaMP M/U liner retrieval BHA # 1 with Baker 4" GS spear, up/down jar, 1 jt of PH6 tbg & MHA (OAL - 45.45'). Stab injector on well. 08:15 - 10:00 1.75 FISH N SFAL DECaMP Break open & attempt to unplug 3" line to tiger tank on choke manifold - plugged up with hard cmt. Review situation with ANC team. Decide to fix plugged line during summer shut-down after this well. Should still be able to operate with only one primary downstream line to tigger tank. Tag out plugged choke manifold line. 10:00 - 11 :40 1.67 FISH P DECaMP RIH with BHA #1 to 8600' taking FP contaminant fluid to tigger tank. Up wt check = 33k, Down Wt = 19k. Pr,nted' 6/22/2004 10'14 30 AM BP EXPLORATION Operations Summary Report Page 2" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: Date From - To H ou rs Task Code NPT Phase Description of Operations 6/6/2004 11 :40 - 13:50 2.17 FISH P DECOMP Circulate out gassy FP contaminant fluid @ 2.0bpm & 1400psi. 13:50 - 14:00 0.17 FISH P DECOMP Continue RIH BHA#1 to TOF tagged @ 8698'. Flag CT (EOP @ 8652.9'). 14:00 - 14:10 0.17 FISH P DECOMP P/U & confirm liner engagement with 36k up wt. 14:10 - 16:05 1.92 FISH P DECOMP POOH with liner fish pumping across the wellhead with 70psl WHP. 16:05 - 17:00 0.92 FISH P DECOMP OOH. Flowcheck well - stable. PJSM. SIB injector. UD BHA #1 & recovered 100% of cut liner assembly consisting of BKR deploy sub. XIO & 14.5 jts of 2-7/8" FL4S tbg. NORM tested recovered pipe - OK with max reading of 1-2 microRem/hr. 17:00 - 17:15 0.25 CLEAN P DECOMP Held PJSM & HAlHM for M/U under-reaming BHA#2. 17:15 - 17:50 0.58 CLEAN P DECOMP M/U under-reaming BHA #2 with 3-5/8" DB under-reamer, Baker mud motor, 1 jt of PH6 tbg & MHA (OAL - 54.26'). Stab injector on well. 17:50 - 20:00 2.17 CLEAN P DECOMP RIH to 8800' MD with under-reaming BHA #2 without pumping. - Correct depth -10' (-1' for EOP flag, -9' for tag). 20:00 - 21 :00 1.00 CLEAN P DECOMP Ream with 7" underreamer to 9100 MD at 2.8 bpm/2.85 bpm; 2500 psi. - Open underreamer. - 19k SO 133k PU. - Pump 15 bbls biozan pill. - Underreamer opens to 6.101 h, I D of 29# 7" is 6.184". - Stacking up at every collar (averaging 38' joints): 8844', 8882',8920',8960',8998',9038', and 9077' MD. - Reaming at 18 fpm, slowing down before collars. - Minimizing stackup to 6k. POOH to 8700' MD, pumping 2.8/2.88 bpm; 2300 psi. No sign of collars. - Shut pumps off and ensure entry into tubing tail. 21 :00 - 22:15 1 .25 CLEAN P DECOMP Ream with 7" underreamer to 9100 MD at 2.8 bpm/2.85 bpm; 2500 psi. - Open underreamer. - 19k SO I 33k PU. - Pump remaining 15 bbls biozan pill. - Confirmed collar location at 8844' and 8882' MD. - Reaming at 18 fpm, slowing down to get past collars to minimize potential tool damage. - Drop 3/4" ball to open circ sub (50.1 bbls). 22: 15 - 00:00 1 .75 CLEAN P DECOMP Pump OOH at 3.0 /2.65 bpm. 200 psi. LD BHA. 6n /2004 00:00 - 01 :00 1.00 EVAL P WEXIT PJSM. RU slickline sheaves and equipment. Pickup PDS Caliper logging tools. 01 :00 - 01:45 0.75 EVAL P WEXIT RIH to 9100' SLM. 01 :45 - 02:45 1.00 EVAL P WEXIT POOH with Caliper log. Logging out of the hole from 9100 to 8600' SLM. 02:45 - 04:00 1.25 EVAL P WEXIT Lay down tools. Download data. Rig down slickline. 04:00 - 06:30 2.50 WHIP P WEXIT PJSM. Rig up E-line sheaves and equipment. Verify POS and CCL tools Insert RA tags into whipstock. RA PIP tag to TOWS = 10'. Pr,nled' 6/22/2004 10'14 30 AM BP EXPLORATION Operations Summary Report Page 3'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: Date From - To Hours Task Code NPT Phase Description of Operations 61712004 04:00 - 06:30 2.50 WHIP P WEXIT Calibrate POS tool to HS & orient whipstock 20degs LOHS. Pick up weight bar, POS, CCL and whipstock BHA. CCL to TOWS = 17.3'. 06'30 - 07:45 1.25 WHIP P WEXIT RIH with HD- swivel, POS tool, wt bar, setting tool, & Baker Gen II 4-1/2" x 7" whipstock (OAL - 40'). RIH to @ 9090' ELM. 07:45 - 08:00 0.25 WHIP P WEXIT P/U wt @ 9100' = 2.8k. Log up hole to 8670' ELM. Tie-into SWS Jewelry Log 2/8/2000. Subtract 6' from ELMO. RBIH to 9100' ELM. Log back up to CCL depth of 9032.7' (TOWS @ 9050' ELM). 08:00 - 08:20 0.33 WHIP P WEXIT Set W IS with good wt loss indication & tray orientation of 2.2degs LOHS. Log off, tag W/S, log off again & confirmed W IS setting depth. 08:20 - 09: 15 0.92 WHIP P WEXIT POOH Eline & W/S setting tools. 09: 15 - 09:30 0.25 WHIP P WEXIT UO SWS Eline tools & RID SWS. 09:30 - 10:00 0.50 STWHIP P WEXIT M/U slick cementing BHA with nozzle, PH6 stinger XJover to circ sub & disconnect. M/U injector. 10:00 - 11 :40 1.67 STWHIP P WEXIT RIH with cementing BHA#3 to 8800'. PUH clean into TT. Continue RIH & lightly tag WS pinch pt @ 9070'. P/U to up wt & correct CTD to the ELMO of 9055ft. P/U 10' to 9045' & flag pipe. 11 :40 - 12:00 0.33 STWHIP P WEXIT RU SLB Cementers & prime up. 12:00 - 12:15 0.25 STWHIP P WEXIT PJSM with all personnel concerning cementing operations. 12:15 - 13:15 1.00 STWHIP P WEXIT FlushlPT lines to 4k. Mix & pump 10bbls 15.8ppg class 'G' cmt slurry & 5bbls of water behind @ 2.0/2.0bpm & 1600psi. Chase with bio-KCL water @ 2.85/2.85bpm & 2450psi. Pump out 1 bbl of cmt past nozzle & lay-in 9bbls of cmt 1:1 to TOe @ 8770'. 13:15 - 13:30 0.25 STWHIP P WEXIT POOH to safety @ 8200' 13:30 - 14:00 0.50 STWHIP P WEXIT Shut-in well with 100psi WHP & W.O.C. to swap out. 14:00 - 14:30 0.50 STWHIP P WEXIT RBIH @ 50fpm circ @ 2.95/2.95bpm & 1550psi jetting down to 9045'. Make 2 more upldown passes washing tbg profiles. 14:30 - 16:40 2.17 STWHIP P WEXIT POOH jetting uphole chasing contaminated cement OOH & washing tbg profiles @ 2.9bpm. 16:40 - 17:00 0.33 STWHIP P WEXIT OOH. UD Cement nozzle BHA. 17:00 - 17:15 0.25 STWHIP P WEXIT M/U swizzle stick & jet BOP stack. UO swizzle stick & SIB injector. Flush choke manifold lines. 17:15 - 17:35 0.33 STWHIP P WEXIT M/U window milling BHA #4 with a 3.80" HC DWM, diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. 17:35 - 19:30 1.92 STWHIP P WEXIT RIH with BHA #4. - Tag pinch point at 9054.5'. (included -10' depth correction) 19:30 - 00:00 4.50 STWHIP P WEXIT Mill window. TOW at 9054.5' MD. - Flag EOP at 8970' MD. - 36k PU I 20k SO - Pump 100 bbls 2ppb Biozan. - 1750 psi free spin. - 2.72/2.88 bpm. - Milling pressure at 1950 psi with 1-3k WOB - Ditch magnets at shaker. 6/812004 00:00 - 00:45 0.75 STWHIP P WEXIT Mill through window at 9061.8' MD into open hole to 9072' MD. - 2.66/2.78 bpm. - 1400 psi free spin. - Milling pressure at 1550 psi with 1-3k WOB - Ditch magnets at shaker. Printed 6/22/2004 10'4 30 AM BP EXPLORATION Operations Summary Report Page 4" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N 1 Spud Date: 10/1/1982 End: Date From - To Ho u rs Task Code NPT Phase Description of Operations 6/8/2004 00:00 - 00:45 0.75 STWHIP P WEXIT EOP flag at 8970' TOWS at 9050' MD TOW at 9054.4' MD BOW at 9061.8' MD 00:45 - 02:20 1.58 STWHIP P WEXIT Backream window. Shut down pumps and run through window. Tag bottom. Repeat backream through window. - Window in good condition. - Swap well over to Flo Pro drilliing fluid. 02:20 - 04:15 1.92 STWHIP P WEXIT POOH with milling BHA at 110 fpm. - 2400 psi - 2.8 / 2.7 bpm - 33k PU - Replacing injector pins as needed. 04: 15 - 05:00 0.75 STWHIP P WEXIT LD BHA #4. - Mill wear to 3.76 no-go (3.77 go). - Reamer showed minimal wear. 05:00 - 05:15 0.25 DRILL P PROD1 Held PJSM. Reviewed dnlling BHA M/U procedures. 05:15 - 06:15 1.00 DRILL P PROD1 Rehead & M/U DS CTC. Pull & pressure test. M/U build section BHA #5 with new HYC DS100 3-3/4" x 4-1/4" bicenter bit, 1.69deg bend motor, MWD & orienter. M/U injector. 06:15 - 08:15 2.00 DRILL P PROD1 RIH with BHA #5. SHT MWD & orienter - OK. RIH to flag. Correct CTD by -14'. Run thru window with pumps down. RIH clrc @ min rate & tag btm @ 9072', Check TF - @ 60L. Establish freespin @ 2.6bpm/3400psi. P/U wt = 32k, S/O wt = 19k. PVT = 335bbls. lAP = 31psi, OAP = 88psi. 08:15 - 12:45 4.50 DRILL P PROD1 Commence driling build section. Drill to 9135' with 45-60L TF ~.... 2.6/2.6bpm, 3200/3500psi, 3k WOB & 15fph ave ROP. .../ 12:45 - 12:50 0.08 DRILL P PROD1 PUH to 9095' for tie-in log. .....-/ 12:50-13:15 0.42 DRILL P PROD1 Log up GR & tie-in RA Pip tag into the 7.-I"DC log - add l' to PIP tag depth. Revised window depths are: .../ TOWS = 9051' TOW = 9056' /... RA PIP Tagv BOW = 906 ' BOWS 069'. 13:15 - 13:25 0.17 DRILL P Q' t TF to 140L. 13:25-15:10 1.75 DRILL P Drill to 9200' with 140-160L TF, 2.6/2.6bpm, 3300/3600psi, 2k WOB & 60fph ave ROP. 15:10 - 16:50 1.67 DRILL P Drilling 159L TF at 70 fph. Q = 2.67/2.83bpm & P = 3250/3596 psi. Oriented 2 click twice 16:50 - 17:20 0.50 DRILL PROD1 Drilling 97L TF at 70 fph. Q = 2.57/2.783 bpm & P = 3250/3596 psi. Oriented 2 click twice PROD1 Wiper trip tp window. PROD1 RIH and tagged bottom, Oriented TF to 60 L PROD1 Drilling 63L TF at 80 fph. ROP @ 89 tto 45 fph. Q = 2.68/2.83 bpm & P = 3250/3757 psi. oriented TF perodically to adjust to plan curve. Getting close to 23 0.38 DRILL P PROD1 Drilled at 45L and hole angle BR are high 0.52 DRILL P PROD1 Orient TF around to reduce BR's , Pnnted 6/22/2004 101430 ArA '!. '!- ~, ~ STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVA4AAY 192004 20 AAC 25.280 Ala~ka nil R. Gas Cons. Commission Anchorage 0 Waiver D Other 0 Time Extension 0 Annular Disposal 1. Type of Request: III Abandon / 0 Suspend 0 Operation Shutdown 0 Perforate 0 Alter Casing 0 Repair Well II Plug Perforations'/ 0 Stimulate 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 74' 11. Total Depth MD (ft): 10638 C~sing Structural Conductor Surface Intermediate Production Liner 5. Permit To Drill Number 200-037 /' 6. API Number: / 50- 029-20808-01-00 9. Well Name and Number: ;' PBU 06-23A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool , " PReSÈN:TW~l!...:CaNDITIOÑ Sl!M.MARY , " 0 Total Depth TVD (ft): I Effective Depth MD (ft): I.Effective Depth TVD (ft): Plugs (measured): 9004 10531 9015 None :..t~ngth/ :0 ' . SiZe 0 ',' ," MD', , 'Burst 4. Current Well Class: 181 Development D Exploratory D Stratigraphic Test D Service 99519-6612 8. Property Designation: ADL 028311 Junk (measured): None Coltapsë' Liner 79' 20" 79' 79' 1490 470 2525' 13-3/8" 2525' 2525' 5380 2670 9016' 9-5/8" 9016' 8516' 6870 4760 823' 7" 8697' - 9520' 8235' - 8941' 8160 7020 1954' 2-7/8" 8684' - 10638' 8223' - 9004' 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9602' - 10530' 9000' - 9015' 5-1/2" 17# x 4-1/2" 12.6# L-80 / N-80 8754' Packers and SSSV Type: 5-1/2" Baker 'SAB' packer; Packers and SSSV MD (ft): 8644' 5-1/2" Camco 'Bal-O' SSSV Nipple 2099' 12. Attachments: 181 Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer SiQnature / ~-~ ~ ~ ~. Côrp:~~~O":U$.5~~378 May 25, 2004 Date: / 13. Well Class after proposed work: D Exploratory 181 Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ 181 Abandoned D WDSPL Contact Thomas McCarty, 564-4378 Prepared By NamelNumbe~ Date ~8z1t,~~:r.~:,~~bble, 564-4628 , '" ' ...., , " coo,..'>' '" , 'c.',"'..' '" '0 ,° ,° 0' I Sundry Number: 2¿4 - / ~ V /' Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: Ar p yo V t" J 10 - 4: vt 6 LV(' ~ J &> ý ~ (Lrl-v~k ~ l { 0,,"'- '2-~ 8. COMMISSIONER BY ORDER OF THE COMMISSION MAY i 0 1ß6~ Date 6lzð,~U: s¡m~I%~Zate -- BfL OR'G'NAL !. r---.. ~ bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: May 17,2004 Re: Well 06-23A prep for a CTD sidetrack Well 06-23A is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, 06-23B, will exit.QØt..ef the existing 7" liner from a thm tubing whipstock and target Zone 2 reserves. / The existing perfs will be isolated with a cast iron bridge plug set in the existing 2-7/8" liner. The following describes work planned for the P&A and sidetrack and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. cm Pre-IDe Summary r 1) Slickline - Drift/Caliper tubin a' er. Dummy gas lift valves. Pressure test IA to 2500 psi. 2) Eline - Set CIBP at approx. 145' 8552'TVDss), cut 2-7/8" liner at approx. 9120'. 3) Coil- Latch onto 2-7/8" Ii , pick up and confirm free. L--- 'T~~ ;0 - c(..O'~ tU)yyOl/&-Ll. cm Sidetrack Summary \ 1) MIRU CTD rig. 2) Pull 2-7/8" liner, Run Thru tubing whipstock set in 7" liner at approx. 9068' (8487'TVDss), cement whipstock in place. 3) Mill 3.8" window off of whipstock. 4) Drill4-l/4" x 3.75" openhole sidetrack to 11020' planned TD with MWD/gamma ray. 5) Run 3-3/16" x 2-7/8" liner completion. Top ofliner will be at 8680' md (8145'TVDss) in 4 W' tubing tail. Cement liner with approx. 25Bbls of 15.8 ppg cement, plan to bring cement top to 8800'md. 6) Run MCNL, Perforate. 7) RDMO. The pre CTD work is scheduled to begin May 25th, 2004. Thomas McCarty CTD Drilling Engineer 564-4378, 748-2598 CC: Well File Terrie Hubble I 4-1/2" TBG-PC, 12.6#, N-80, -i 8754' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9016' ~ 1 WHIPSTOCK H 9515' r 7" LNR, 29#, L-80, ,0371 bpf, ID = 6.184" Ii 9870' ~ r"-. TREE = W8..LHEAD = ACTUATOR = KB. 8..EV = BF. 8..EV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 3 FMC AX8..S0N 74' --_? 4600' 99 @ 10312' 9439' 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2525' I Minimum 10 = 2.38" @ 8695' I 3-1/2" X 2-7/8" XO 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID:: 4.892" H ITOPOF4-1/2"TBG-PC H 8657' 8657' TOP OF 2-7/8" LNR H TOPOF 7" LNR H 8695' 8697' PERFORATION SUMMARY REF LOG: SWS CNL OS/24/00 ANGLEAT TOP PERF: 57 @ 9602' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9602 - 9612 0 01/07/04 1-11/16" 4 9623-9648 0 11/16/01 2" 4 9684 - 9694 0 01/07/04 1-11/16" 4 9710-9740 0 11/16/01 2" 4 9840 - 10000 0 OS/26/00 2" 4 10050 - 10200 0 OS/26/00 1-11/16" 4 10291-10331 0 08/08/01 1-11/16" 4 10364 - 10404 0 08/08/01 1-11/16" 4 10490-10510 0 08/15/00 1-11/16" 4 10510-10530 0 09/24/00 DA TE REV BY COMMENTS 10/22/82 ORIGINAL COMPLETION OS/24/00 SIDETRACK COM PLETION 09/19/01 RNITP CORRECTIONS 11/16/01 TMNlKAK ÆRFS 08/19/03 CMOfTLP ÆRF A NGLE CORRECTION 01/20/04 MJAITLH ÆRFS (01/07/04) DATE 06-23A r\ I SAFETY NOTES: . 2099' 1-i5-1/2" CAMCO BAL-O SSSV NIP,ID = 4.562" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE ~ 1 2929 2929 0 MMIG RK 2 4763 4757 12 MMIG RK 3 6120 6023 32 MMIG RK 4 7211 6914 32 MMIG RK 5 7829 7450 28 MMIG RK 6 7906 7518 27 MMIG RK 7 8243 7820 25 MMIG RK 8 8312 7882 24 MMIG RK 9 8535 8087 23 MMIG RK 10 8607 8153 24 MMIG RK ~ L l J 8631' 8644' H 5-1/2" BAKERPBRASSY I H 9-5/8"X5-1/2"BAKERSABA<R I H 5-1/2" X 4-1/2" XO I H 3-1/2" DEPLOYMENT SLV, ID = 3.0" I :8 ~ ~ r. & 8657' 8689' 8695' H 3-1/2" X 2-7/8" XO, ID = 2.380" I . 11 4-1/2"CAMCODB-6 NIP, ID=3.813" I (BB-IIND CT LNR), l-i 4-1/2" TUBING TAIL (BB-IIND CTLNR) I H 8..MDTILOGGED09/17/87 I 8741' 8755' 8741' .. I MILLOUTWINDOW 9517'-9524' 10531' I 10638' I 12-7/8" LNR, 6.5#, L-80, .00579 bpf,lD = 2.441" H 10636' I REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 06-23A PERMIT No: 2000370 API No: 50-029-20808-01 SEC 2. T10N, R14E. 4325.36' Fa.. & 2175.84' FNL BP Exploration (Alaska) 1REE ::; . WB.LHEAD = ACTUATOR = KB. aev = BF. aev = KOP= Max Angle = Datum M) = Datum lVD = 06-238 FMC GEN 3 FMC AXaSON 74' _? r"-. Proposed CTD Sidetrack 4600' 99 @ 10312' 9439' 8800' SS - . 13-3/8" CSG, 72#, L-80, D = 12.347" H ~ 2525' L l J X :& I 5-112" ìBG-PC, 17#, L-80, .0232 bpf, D = 4.892" 1-1 8657' I TOP OF 4-1/2" ìBG-PC H 865T TOPOF 3-3/16" LN~-I 8680' 't=J 13.5" XN Nip 2.75" Iq-l 8690' t---- - , 1 TOP OF 7" LNR H 869T ~ . I 4-1/2" ìBG-PC, 12.6#, N-80, -I 8754' ~ .0152 bpf, ID = 3.958" TOP of Cement -I 8800' I 9-5/8" CSG, 47#, L-80, Ð = 8.681" 1-1 9016' ~ r WHIPSTOCK 1-1 9515' 7" LNR. 29#, L-80, .0371 bpf, D = 6.184" H 9870' 2099' ~ ST M) lVD 1 2929 2929 2 4763 4757 3 6120 6023 4 7211 6914 5 7829 7450 6 7906 7518 7 8243 7820 8 8312 7882 9 8535 8087 10 8607 8153 8631' 8644' 865T 8680' 8741' 8755' 8741' r'\ I SAFETY NOTES: 1-15-1/2" CAMCO BAL-O SSSV NP, D = 4.562" I GAS LFT MANDR8.S DE\! TYPE VLV LATCH PORT DAlE 0 MMIG RK 12 MMIG RK 32 MMIG RK 32 MMIG RK 28 MMIG RK 27 MMIG RK 25 MMIG RK 24 MMIG RK 23 MMIG RK 24 MMIG RK H 5-1/2" BAKERPBRASSY I 1-1 9-5/8" X 5-1/2" BAKER SAB A<R I 1-1 5-1/2" X 4-1/2" XO I 1-1 3-1/2" DEPLOYMENT SLV, Ð = 3.0" I 11 4-1/2" CAMCO DB-6 NIP, D = 3.813" I (BBiIND CT LNR), H 4-1/2" TUBING TAR.. (BBiIND CT LNR) I 1-1 aMDTTLOGGED09/17/87 I 1-13-3/16 x 2-7/8 X-over ..----. I} 11020' 1 1 I ..----. I 3-3/16" X 2-7/8" crrt'ed and perfedl-l 9068' 1-1 Mechanical Whipstock 9120' 1-1 Cern Cut 2-7/8" Liner 9145' HCIBPI / PERFORATION SUMMARY REF LOG: SWS CNL OS/24/00 ANGLE AT TOP PERF: 57 @ 9602' Note: Refer to Production DB for historical perf data SIZE SPF NTERV AL Opn/Sqz DA lE 2" 4 9602 - 9612 isolated proposed 1-11/16" 4 9623 - 9648 isolated proposed 2" 4 9684 - 9694 isolated proposed 1-11/16" 4 9710 - 9740 isolated proposed 2" 4 9840 - 10000 isolated proposed 2" 4 10050 - 10200 isolated proposed 1-11/16" 4 10291 - 10331 isolated proposed 1-11/16" 4 10364-10404 isolated proposed 1-11/16" 4 10490 - 10510 isolated proposed 1-11/16" 4 10510 - 10530 isolated proposed MUOUTWINOOW 9517' - 9524' ~ 10636' H 2-7/8" LNR. 6.5#, L-80, .00579 bpf, D= 2.441' , ~ 10531' I ~ 10638' I . DATE REV BY COMMENTS 10/22/82 ORIGINAL COMPLETION 05124100 SIDETRACK COM PLETION 09119/01 RNITP CORRECTIONS 11/16/01 TMNIKAK PERFS 08119/03 CMOfTLP PERF ANGLE CORRECTION 01120104 MJAfTLH PERFS (01/07/04) REV BY COM\1ENTS DATE PRUDHOE BA Y UNIT WaL: 06-23A PERMfT No: 2000370 API No: 50-029-20808-01 SEe 2, T10N, R14E 4325.36' Fa. & 2175.84' FNL . BP exploration (Alaska) - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Suspend 0 Repair Well 0 Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New PoolD 4. Current Well Class: Perforate [!) WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0370 OtherD Name: BP Exploration (Alaska), Inc. Development 00 StratigraphicD 9. Well Name and Number: 06-23A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Exploratory 0 ServiceD 6. API Number 50-029-20808-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 74.00 8. Property Designation: ADL-o028311 11. Present Well Condition Summary: Total Depth measured 10638 feet true vertical 9004.4 feet Effective Depth measured 10531 feet true vertical 9014.6 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 33 112 33.0 - 112.0 1490 470 Liner 28 7" 26# L-80 8629 - 8657 8173.2 - 8198.7 7240 5410 Liner 97 4-1/2" 12.6# N-80 8657 - 8754 8198.7 - 8286.1 8430 7500 Liner 1190 7" 29# L-80 8680 - 9870 8219.5 - 9056.1 8160 7020 Liner 7 3-1/2" 9.3# L-80 8689 - 8696 8227.6 - 8233.9 10160 10530 Liner 1940 2-7/8" 6.16# L-80 8696 - 10636 8233.9 - 9004.6 13450 13890 Production 8985 9-5/8" 47# L-80 31 - 9016 31.0 - 8515.8 6870 4760 Surface 2493 13-3/8" 72# L-80 32 - 2525 32.0 - 2525.0 4930 2670 Measured depth: 9602 - 9612,9623 - 9648, 9684 - 9694, 9710 - 9740,9840 - 10000, 10050 -10200,10291 -10311 10311 -10331,10364 - 10404, 10490 -10510, 10510 -10530 True vertical depth: 9000.41 - 9006.39, 9012.64 - 9025.5,9040.28 - 9043.54, 9048.11 - 9054.32,9055.72 - 9051.36,9051.61 - 9045.74 9038.82 - 9035.63,9035.63 - 9032.75, 9029.17 - 9023.9,9015.67 - 9014.97,9014.97 - 9014.6 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 28 8631 Packers & SSSV (type & measured depth): 7" Baker SAB Packer @ 8644 ~ : ,:' _: ~ ~. ;~ h. n.~ ~'" . " ~<.øt, J 'i" .' ~', " _.. >-> \~AR 1 R 20n. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Me! Water-Bbl Casing Pressure 29 53 920 to> . ¡. " . . . ;-:,~ Cfi. G,¡;T¡{m~S¡cn ),r..; i)r".~::" 13 282 13.4 129 1000 Tubing Pressure 377 514 Prior to well operation: Subsequent to operation: Oil-Bbl 914 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant. Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Ga!'] Catron Signature .t.J ~ Ca7tx ëY'- {J Form 10-404 Revised 12/2003 0 R \ G \ N ~t 564-4657 RBDMS BFL Date 3/16/04 MAR 1 ~ 1~~~ -' 06-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/04/04 DRIFT WI 8' X 2 -1/8" WEIGHT BAR, 2.25 CENTRALIZER TO 9720' SLM. STOP DUE TO DEVIATION. RECOMMEND USING ROLLERS TO PERFORATE. WELL LEFT SHUT IN. 01/07104 PERFORATED 9684'-9694' AND 9602'-9612' WITH 2" PJ 6 SPF, 18.1" PENE, 0.20" EH, 6.5 GMS, CORRELATED TO SWS MCNL DATED 5-24-2000. FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOT AL Page 1 I 4-1/2" TBG-PC, 12.6#, N-80, 1-1 8754' .0152 bpI, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9016' ~ I WHIPSTOCK 1-1 9515' 7" LNR, 29#, L-80, .0371 bpI, ID = 6.184" H 9870' TREE = WB.LHEAD = ACTUATOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum lVD = FMC GEN 3 FMC AXB.SON 74' --_? 4600' 99 @ 10312' 9439' 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2525' I Minimum ID = 2.38" @ 8695' I 3-1/2" X 2-7/8" XO 15-1/2" TBG-PC, 17#, L-80, .0232 bpI, ID = 4.892" H TOPOF4-1/2"TBG-PC H 8657' 8657' TOPOF 2-7/8" LNR H TOPOF7"LNRH 8695' 8697' ÆRFORA TION SUMMARY REF LOG: SWS CNL OS/24/00 ANGLEATTOPPERF: 57@9602' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9602 - 9612 0 01/07/04 1-11/16" 4 9623- 9648 0 11/16/01 2" 4 9684 - 9694 0 01/07/04 1-11/16" 4 9710-9740 0 11/16/01 2" 4 9840 - 10000 0 OS/26/00 2" 4 10050 - 10200 0 OS/26/00 1-11/16" 4 10291 - 10331 0 08/08/01 1-11/16" 4 10364-10404 0 08/08/01 1-11/16" 410490-10510 0 08/15/00 1-11/16" 4 10510-10530 0 09/24/00 DA TE REV BY COMMENTS 10/22/82 ORIGINAL COMPLETION OS/24/00 SIDETRACK COMPLETION 09/19/01 RNITP CORRECTIONS 11/16/01 TMNlKAK ÆRFS 08/19/03 CMOfTLP ÆRF A NGLE CORRECTION 01/20/04 MJAfTLH ÆRFS (01/07/04) DATE 06-23A I SAFETY NOTES: . - 1-\5-1/2" CAMCO BAL-O SSSV NP, ID = 4.562" 1 2099' ~ ST MD lVD 1 2929 2929 2 4763 4757 3 6120 6023 4 7211 6914 5 7829 7450 6 7906 7518 7 8243 7820 8 8312 7882 9 8535 8087 10 8607 8153 GAS LIFT MANDR8..S DEV TYÆ VLV LATCH PORT DATE 0 MMIG RK 12 MMIG RK 32 MMIG RK 32 MMIG RK 28 MMIG RK 27 MMIG RK 25 MMIG RK 24 MMIG RK 23 MMIG RK 24 MMIG RK ~ L l J I 8631' H 5-1/2" BAKERPBRASSY I 1 8644' H 9-5/8" X 5-1/2" BAKER SAB A<R 1 8657' H 5-1/2" X 4-1/2" XO 1 8689' H 3-1/2"DEPLOYMENTSLV,ID=3.0" I g x I I 0 ~ r-" 8695' 1-\ 3-1/2" X 2-7/8" XC, ID = 2.380" I . 8741' 11 4-1/2" CAMCO DB-6 NIP, ID = 3.813" I (BEHIND CT LNR), l-i 4-1/2" TUBING TAIL (BEHIND CT LNR) I H B.MD TT LOGGED 09/17187 I 8755' 8741' .. I MILLOUTWINDOW 9517'- 9524' I 10531' I 10638' 1 2-7/8"LNR,6.5#,L-80,.00579bpf,ID=2.441" H 10636' I REV BY COMMENTS PRUDHOE BA Y UNIT WB.L: 06-23A PERMIT No: 2000370 API No: 50-029-20808-01 SEC 2, T10N, R14E, 4325.36' FB. & 2175.84' FNL BP Exploration (Alaska) Permit to Drill No. 2000370 MD 10638 TVD DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. PRUDHOE BAY UNIT 06-23A Operator BP EXPLORATION (ALASKA) INC 9004 Completion Date 5/27/2000 ~"'~ Completion Status 1-OIL Current Status 1-OIL AP1 No. 50-029-20808-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No __ -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format ~ EOW SRVY ~'""McNL ~D GR ~is Verification ,,.~ TVD GR Interval Log Log Run Scale Media No Start Stop 9400 10638 2 FINAL 8200 10526 5 FINAL 9530 10638 FINAL 5 FINAL 9530 10638 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments OH 7/13/2000 BHI · CH 7/7/2000 oh 5/29/2001 BL, Sepia O 5/29/2001 10055 ~ 9522-10638 ch 5/29/2001 .~LIS Verification C 7/7/2000 09665 8200-10526 oh 5/29/2001 BL, Sepia Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~/'~N) Chips Received? __-Y-,aN.--- Analysis Received? Start Interval Stop Sent Received Daily History Received? Formation Tops Receuived? Dataset Number Comments ~/N Comments: Compliance Reviewed By: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ 4. Location of well at surface 4577' FNL, 1008' FEL, Sec. 02, T10N, R14E, UM At top of productive interval 2561' FNL, 5079' FEL, Sec. 01, T10N, R14E, UM At effective depth 2130' FNL, 861' FWL, Sec. 01, T10N, R14E, UM At total depth 2176' FNL, 4325' FEL, Sec. 01, T10N, R14E, UM (asp's 685970, 5941299) (asp's 687128, 5943346) (asp's 687777, 5943793) (asp's 687869, 5943748) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-23A 9. Permit number / approval number 200-037 10. APl number 50-029-20808-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10638 feet Plugs (measured) 9004 feet Effective depth: measured 10535 feet Junk (measured) true vertical 9014 feet Tagged PBTD @ 10535' CTM (08/06/2001) Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 79' 20" 1900# Poleset 111' 111' Surface 2493' 13-3/8" 2400 sx Fondu, 400 sx 2525' 2525' PFC Production 8984' 9-5/8" 500 sx 'G', 50 bbls PF 'C' 9016' 8516' Liner 820' 7" 325 sx Class 'G' 8697' - 9517' 8235' - 8939' Sidetrack Liner 1943' 2-7/8" 20 bbls 15.8 ppg LARC 8695' - 10638' 8233' - 9004' Perforation depth: measured Open Perfs 9623' - 9648', 9710' - 9740', 9840' - 10000', 10050' - 10200', 10291' - 10331 ', Open Perfs continued 10364' - 10404', 10490' - 10530' true vertical Open Perfs 9013' - 9026', 9048' - 9054', 9056' - 9052', 9052' - 9046', 9039' - 9033', Open Perfs continued 9029' - 9024', 9016' - 9015' i'ubing (size, grade, and measured depth) 5-1/2", 17#, L-80 TBG @ 8657'. 5-1/2" x 4-1/2" XO @ 8657'. 4-1/2" 12.6# N-80 @ 8754'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAB Packer @ 8644'. 5-1/2" Camco BAL-O SSSVN @ 2099'. RECEIVED 13. Stimulation or cement squeeze summary NOV 2 0 2001 Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure itlt. la~ 0il & C~3S COOS. ~[~ 14. Representative Dailv Averaqe Production or Injection Data ,AllChOl'age OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Well Shut-in due to High GOR. Subsequent to operation 11/19/2001 1541 14211 54 GL - 976 psi 334 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 anS..correct to the best of my knowledge. ~/~' ./~/f~ ~,~ ¢~,/~...., Title: DS 6 Petroleum Engineer Deidre Taytor %*~¢~ ~/ Form 10-404 Rev 06/15/88 · ORIGINAL Date November 20, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 06-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/20/2001 10/21/2001 11/15/2001 PERF(ADD-PERF): ADD PERF PERF(ADD-PERF): DRIFT RUN PERF(ADD-PERF): ADD PERF (55') EVENT SUMMARY 10/20/01 MIRU UNITS 3. MU MHA AND MEMORY TOOLS. JOB IN PROGRESS. 10/21/01 OPEN WELL. WELL IS FLOWING AT 1500 PSI WITH A 50 DEG. CHOKE. RD CTU AND TEST WELL FOR RE-EVALUATION BEFORE ADDING PERFS. 11/15/01 KILL WELL . RIH AND LOG GR/CCL FROM 9500-9830. POH. VERIFY DATA. GOOD. RE-KILL WELL. RIH W/GUN #1. PERFORATE 9720' - 9740' @ 4 SPF. POOH. ASF. RIH W/GUN #2. PERFORATE 9710' - 9720'. POOH. ASF. RIH W/GUN #3. PERFORATE 9623-9648 @ 4 SPF WITH I 11/16" POWER JETS. ASF. RDMO. NOTIFY DSO TO PUT WELL ON PRODUCTION. FLUIDS PUMPED BBLS 155 60/40 METHANOL WATER 269 1% KCL WATER 100 CRUDE 524 TOTAL 11/15/2001 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 1-11/16" HSD POWER JET AT 4 SPF, ZERO DEGREES PHASING, AND RANDOM ORIENTATION. 9623'- 9648' 9710' - 9740' Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4577' FNL, 1008' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 2561' FNL, 5079' FEL, SEC 1, T10N, R14E, UM At effective depth At total depth 2176' FNL, 4325' FEL, Sec. 1, T10N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 685970, 5941299) (asp's 687128, 5943346) (asp's 687869, 5943748) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-23A 9. Permitnumber/approvalnumber 200-037 10. APInumber 50-029-20808-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Surface 2451' Production 8942' Liner 823' Liner 1954' 10638 feet Plugs (measured) Tagged PBTD @ 10535' CTM on 8/06/2001. 9004 feet 10535 feet Junk (measured) 9014 feet Size Cemented Measured Depth True Vertical Depth 20" 1990# Poleset 79' 79' 13-3/8" 2400 Sx Fondu & 400 Sx PFC 2525' 2525' 9-5/8" 500 Sx Glass G & 50 bbls PFC 9016' 8516' 7" 325 Sx Class G 9520' 8941' 2-7/8" 20 bbls 15.8 ppg LARC 10638' 9004' Perforation depth: measured 9840'-10000'; 10050'-10200'; 10291'-10331" 10364'-10404'; 10490'-10530'. true vertical 9056'-9052'; 9052'-9046'; 9039'-9033'; 9029'-9024'; 9o16'-9015'~ ~(,. F ~V FD Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8657' MD; 4-1/2", 12.6#, N-80 PCT @ 8754' MD. AUG ] 3 200] Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8644' MD. 5-1/2" CAMCO BAL-O SSSV @ 2099' MD. Alaska 0il & Gas Cons. Commission 13. Stimulation or cement squeeze summary AIIU;~O['~.,~6 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 Oil-Bbl Gas-Mcr Water~Bbl Casing Pressure 316 9746 12 - (Untested due to test separator being offline) Tubing Pressure 281 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil _X Gas _ Suspended __ Service 17. I hereby certify that the foreg~ng is true and correct to the best of my knowledge. Signed Title: DS 6 Surveillance Engineer Deidre Taylor ORIGINAl Date Au.qust 9, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-23A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 8/06/2001- 8/06/2001' 8/07/2001 - 8/08/2001' RIH & drifted to 9000' SLM (HAW). MIRU CTU. PT'd equip to 4000 psi. RIH w/logging tools & logged from 10100' to PBTD @ 10236'. POOH w/logging tools. RIH w/CT conveyed perforating guns & shot 40' of add perforations in the 2-7/8" liner from: 10291'- 10331' MD (Zone 2A) Reference Log: CH CNL Log 5/24/2000. 10364' - 10404' MD (Zone 2A) Well was flowing during perforating. Used 1-11/16" PJ carriers & all shots @ 4 SPF, random orientation, 60°/120° phasing, and underbalanced press. POOH w/guns - ASF. RD CTU. Placed well BOL. Test separator is down for maintenance and will be out of service for the near future. Page I Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska 06-23A Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print Sent ~e~g Date: May 23, 2001 Received.. y~.~/~2~ ~/D.-~.~ j Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 RECEIVED Baker Atlas #1300, 401~9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX.' (403) 537-3767 Alas~ OD & Oas Cons. Comm~ton ,. · ., -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 74 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4577' FNL, 1008' FEE, Sec. 2, T1 ON, R14E, UM (asp's 685970, 5941299) 06-23A At top of productive interval 9. Permit number / approval number 2561' FNL, 5079' FEL, SEC 1, T10N, R14E, UM (asp's 687128, 5943346) 200-037 At effective depth 10. APl number 50-029-20808-01 At total depth 11. Field / Pool 2176' FNL, 4325' FEL, Sec. 1, T1 ON, R14E, UM (asp's 687869, 5943748) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10638 feet Plugs (measured) Tagged PBTD (1/05/2001) @ 10517' MD. true vertical 9004 feet Effective depth: measured 10517 feet Junk (measured) true vertical 9015 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 20" 1990# Poleset 79' 79' Surface 2451' 1 3-3/8" 2400 Sx Fondu & 400 Sx PFC 2525' 2525' Production 8942' 9-5/8" 500 Sx Glass G & 50 bbls PFC 9016' 8516' Liner 823' 7" 325 Sx C~ass G 9520' 8941' Liner 1 954' 2-7/8" 20 bbls 15.8 ppg LARC 10638' 9004' Perforation depth: measured 9840'-10000'; 10050'-10200'; 10490'- 10530'. RECEivED true vertical 9056'- 9052'; 9052'- 9046'; 9016'-9015'. U~/v Alaska 0il & Gas Cons. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8657' MD; 4-1/2", 12.6#, N-80 PCT @ 8754' MD. AnChorage Commission Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8644' MD. 5-1/2" CAMCO BAL-O SSSV @ 2099' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation(12/22/2000) 319 8865 132 246 Subsequent to operation(I/6/2001) 667 13008 420 279 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~b~ ~ ~ Title: DS 6 Surveillance Engineer Deidre Taylor .,~ Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · KiGiitAL SUBMIT IN DUPLICATE~ ,. '~'-'" 06-23A DESCRIPTION OF wORK coMPLETED " CT ACID STIMULATION TREATMENT 12/27/2000: 12/2712000: 110512001 TIFL passed. RIH & drifted to 9730' MD (HAW). periormed a CT Acid stimulation Treatment as follows: MIRU CTU & pT'd BoPE. RIH w/ CT Nozzle & displaced well to 1% KCL Water. performed iniectWit¥ test: final iniectWity was 2.4 bpm @ 330 psi WHP. Tagged pBTD @ 10517' cTM & pUH to above peris. Reciprocated across the following perforation intervals: 9840' - 10000' MD (Zone 10050' - 10200' MD (Zone 10510' - 10530' MD (Zone 110612001' 75 bblS of 10% HCI - 10% X¥1ene @ 1.6 - 1.8 bpm, followed by ((~ reduced to minimum rate t/30 rain soak, followed by 150 bbls of 1% KCL Water flush @ 2.2 - 2.4 bpm, followed by (e) ShutdoWn. No stimulation indicated- pOOH w/CT Nozzle. RD cTU & MOL. Placed weIi BOL. obtained representative production data. RECEIVED JAN 1 8 2001 Alaska 0il & Gas Cons. Commission Anchorage Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,.'.'.'SlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perlorate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 74 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4577' FNL, 1008' FEL, Sec. 2, T10N, R14E, UM (asp's 685970, 5941299) 06-23A At top of productive interval 9. Permit number / approval number 2561' FNL, 5079' FEL, SEC 1, T10N, R14E, UM (asp's 687128, 5943346) 200-037 At effective depth 10. APl number 50-029-20808-01 At total depth 11. Field / Pool 2176' FNL, 4325' FEL, Sec. 1, T1 ON, R14E, UM (asp's 687869, 5943748) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10638 feet Plugs (measured) Tagged PBTD (9/25/2000) @ 10531' MD. true vertical 9004 feet Effective depth: measured 10531feet Junk(measured) O R ! Gl NAL true vertical 9014 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 20" 199o# Poleset 79' 79' Surface 2451' 13-3/8" 2400 Sx Fondu & 400 Sx PFC 2525' 2525' Production 8942' 9-5/8" 500 Sx Glass G & 50 bbls PFC 9016' 8516' Liner 823' 7" 325 Sx C~ass G 9520' 8941' Liner 1954' 2-7/8" 20 bbls 15.8 ppg I_ARC 10638' 9004' Perforation depth: measured 9840' - 10000'; 10050' - 10200'; 10490' - 10530'. true vertical 9056' - 9052'; 9052' - 9046'; 9016'- 9015'. !Fi~,~ ~'~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8657' MD; 4-1/2", 12.6#, N-80 PCT @ 8754' MD. ¢} ~'~- Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8644' MD. ,;~, ,,~.,- ri'ii ~!i: ',' ~'-~;~:L:~;:,'; 5-1/2" CAMCO BAL-O SSSV @ 2099' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 336 5508 8 240 Subsequent to operation 1091 7278 0 290 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is tru~nd correct to the best of my knowledge. Signed ~ ~. ~v//(~~,~~ Ti tle:'---~~(~fd '~,3(tLJ.~U,~. Date Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-23A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 8/14/2000: 8/15/2000: 9/24/2000: 9~25/2000' MIRU CTU. PT'd equip to 4000 psi. RIH w/Mem GR/CCL logging tools & tagged PBTD 10531'. Logged up to 10050' MD & POOH w/logging tools. Well flowing. LDFN. RIH w/CT conveyed perforating guns & shot 20' of add perforations @ 10490' - 10510' (Zone 2B) Reference Log: 5/24/2000. Used 1-11/16" carriers & all shots @ 4 SPF, 60° phasing, random orientation, & underbalanced press. POOH w/guns - ASF. RD CTU. Performed FCO to 10153' MD. MIRU ELU. PT'd equip. RIH & logged well f/10531' to 10150' MD w/Mere GR/CCL. POOH w/logging tools. RIH w/perforating guns & shot 20' of add perforations @ 10510' - 10530' (Zone 2B) Used 1-11/16" carriers & all shots @ 4 SPF, random orientation, & underbalanced press. POOH w/guns - ASF. RD ELU. Placed well BOL & obtained production data. Page 1 STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COM,~,,,SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! well Classification of Service Well Oil r~ Gas E] su.s..pended E] Abandoned E] Service 2. Name of Operator ~ ~.~j~'~ 7. Permit Number Phillips Alaska, Inc.~~~ 200-037 3. Address l'~. I~?.;~ 8. APl Number - , P. O. Box 100360, Anchorage, AK 99510-0360 50-029-20808-01 4. Location of well at sudace ~'~'~;~' ;~ *' ::'::i'i~; -~ 9. Unit or Lease Name 4577' FNL, 1008' FEL, Sec. 2, TION, R14E, UM (asp's 685970, 5941299) ~' "?~'~"~'"'::~ ~'~'; : Prudhoe Bay Unit At Top Producing Interval~i ................ ,,~_ ~_.~,, ~_~ 10. Well Number 2561' FNL, 5079' FEL, SEC 1, T10N, R14E, UM (asp's 687128, 5943346) ~ :,,;:!,.,..~ :~. ~ 06-23A 2178' FNL, 4328' FEL, SEC 1, T10N, R14E, UM (asp's 687869, 5943748) ~:~.:~:..~.~5.,~.:~-)~_~.;_.i Prudhoe Bay Field 5. Elevation In feet (indicate KB, DF, etc.) J6. Lease Designation and Sedal No, RKB 74 feetI ADL 28311 Prudhoe Bay Oil Pool 12. Date Spudded 13. Da{e T;D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, ii offshore 16. No. el Completions I April 21,2000 May 23, 2000 May 27, 2000 N/A feet MSL 1 17. Total Depth (MD + TVD) i18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10638' MD /9004' TVD 10531' MD /9014' TVD YES F~] No E]I 2099' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & GR, MEM CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD J CASING SIZE VVT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 79' 30" 1990# Poleset 13-3/8" 72# L-80 Surface 2525' 17-1/2" 2400 sx Fondu & 400 Sx PFC 9-5/8" 47# L-80/S00-95 Surface 9016' 12-1/4" 500 Sx Glass G & 50 bbls PFC 7" 29# L-80 8697' 9520' 8-1/2" 325 Sx Class G 2-7/8" 6.16# L-80 8684' 10638' 3-3/4" 20 bbls 15.8 ppg LARC 124. Perforations open to Production (MD + TVD o! Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 8657' 8644' 4-1/2' 8754' 9840' - 10000' MD; 9056' - 9052' TVD; @ 4 SPF 10050' - 10200' MD; 9052' - 9046' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method o! Operation (Flowing, gas lift, etc.) June 1, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 6/9/2000 6.0 Test Period ·I 8083 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -247 psi 24-Hour Rate · 730 2943 75 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence o! oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved April 12, 2000 (Permit ~Y200-037) · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... Submit In duplicate 29. 30. GEOLOGIC MARKER~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time o! each phase. Top of Sag River Sand 9039' 8536' Top of Shublik 9078' 8569' Top of Zone 2B 9505' 8929' Top of Zone 2A 9658' 9030' 31. LIST OF ATTACHMENTS Summary of 06-23A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the lollowing is tree and correct to the best of my knowledge. Signed ~''''-'~antt ~ ~ Title PAl Coil Tubin,q Ddllin,q Supervisor Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 06-23A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 4/21/2000: 5/19/2000: 5/20/2000: 5/21/2000: 5/22/2000: 5/23/2000: 5/24/2000: 5/25/2000: 5/26/2000: 5/27/2000: MIRU CTU#5 (service coil unit). PT'd equip. RIH & tagged 9515' MD. Milled window off 7" Liner. TOW = 9520' & BOW = 9525'. Milled into FM to 9535' & POOH. FP'd well. RD. MIRU Nabors 3S. Continue RU of 3S & MIRU CTU. NU BOPE. PT'd BOPE. RIH & log tie-in. Drilled FM to 9548' MD. Displaced coil & lower well to mud. Performed LOT to EMW of 9.15 ppg. Drilled to 9795'. POOH. RIH & drilled to 10020'. POOH. RIH & drilled to 10060'. Drilled horizontal section to TD @ 10638' MD. Conditioned OH & POOH. MU 2-7/8" liner. RIH w/2-7/8" FL4S Liner & landed it @ 10638'. Cemented liner in place by pumping 20 bbls of 15.8 ppg LARC. Launced dart. Dart & plug landed @ correct displacement. 1:1 rtns during job. Unstung f/Liner & contaminated Cement w/Biozan. Cleaned out to 10531' POOH w/CT. RIH w/CNL/GR logging tools. Logged well. Layed in FIo Pro. POOH w/mem logging tools. RIH to condition well. POOH. Performed liner lap PT - passed after fluid packing IA. RIH w/Perf guns & taggged PBTD @ 10531' MD. Shot 310' of initial perforations @' 9840'-10000' MD (Zone2A) 10050' - 10200' MD (Zone 2A) Used 2" carriers & shot all Perfs @ 4 SPF, overbalanced press, & random orientation. POOH w/guns. ASF. RIH &~displaced well to Crude. POOH. RDMOL CTU & Nabors 3S. Placed well 06-23A on initial production & obtained a valid well test. Sidetrack Summary Page I [Ul/'dO0~] (+)q~PoN~(-)q;nos © oo [ub'~O0;~] q~leQ leo!:ua^ an,~l End of Well Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: PHILLIPS Alaska, Inc. Rig: Nabors 3S Fldd: Prudhoe Bay Unit ' RKB Height: 74.000 Well: 06-23A Vertical Sect. Plane: 62.000 Job No: 408.57 Mag. Declination: 27.270 AFE No: AP-1524 Grid Correction: 1.420 API No: 50-029-20808-01 Job Start Date: 20-May-00 BHI Rep: C. Seyler / M. Dalton Job End Date: 22-May-00 Survey Date: 22-May-00 Survey Type: MWD Meas. Incl. TRUE TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Depth Angle Azi. V. Depth TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section (de~) (de~) (ft) (ft) Lat. (Y) Dep. (X) Lat. (Y) De[~. (X) (°/100ft) ~Wellhead) 9400.00 33.25 49.00 8841.05 8767.05 1899.50 1087.16 5943224.95 687009.75i 0.00 0.00 9500.00 33.25 49.00 8924.68 8850.68 1935.47 1128.54 5943261.94 687050.23 0.00 53.43 9535.00 37.10 49.00 8953.28 8879.28 1948.70 1143.75 5943275.53 687065.11 11.00 73.07 9559.00 43.20 49.00 8971.62 8897.62 1958.85 1155.43 5943285.97 687076.53 25.42 88.14 9592.00 50.40 41.00 8994.21 8920.21 1975.89 1172.33 5943303.42 687093.01 28.05 111.06 9624.00 56.60 41.00 9013.24 8939.24 1995.29 1189.20 5943323.23 687109.39 19.37 135.07 9659.00 64.10 39.90 9030.54 8956.54 2018.43 1208.91 5943346.85 687128.53 21.60 163.33 9690.00 71.20 39.20 9042.32 8968.32 2040.53 1227.15 5943369.39 687146.22 23.00 189.81 9722.00 77.10 35.00 9051.06 8977.06 ' 2065.07 1245.69 5943394.39 687164.15 22.34 217.71 , 9754.00 85.40 29.00 9055.93 8981.93 2091.87 1262.42 5943421.59 687180.20 31.87 245.05 9794.00 92.10 26.60 9056.80 8982.80 2127.22 1281.05 5943457.39 687197.96 17.79 278.10 9835.00 90.70 27.30 9055.80 8981.80 2163.75 1299.63 5943494.37 687215.63 3.82 311.66 9863.00 88.50 23.30 9055.99 8981.99 2189.06 1311.59 5943519.96 687226.96 16.30 334.10 9906.00 93.30 30.10 9055.32 8981.32 2227.44 1330.89 5943558.811 687245.31 19.35 369.16 9941.00 93.00 35.00 9053.39 8979.39 2256.89 1349.69 5943588.71 687263.38 14.01 399.58; 9978.00 91.80 43.40 9051.84 8977.84 2285.51 1373.03 5943617.90 687286.01 22.91 433.63 10023.00 89.20 43.00 9051.45 8977.45 2318.31 1403.83 5943651.45 687315.99 5185 476.22 ... 10060.00 90.30 47.00 9051.61 8977.61 2344.46 1429.99 5943678.24 687341.49 11.21 511.60 10101.00 94.001 55.80 9050.07 8976.07 2370.00 1461.97 . 5943704.56 687372.83 23.27 551.82 10137.00 94.00 55.70 9047.56 8973.56 2390.21 1491.66 5943725.50 687402.01 0.28 587.52 10170.00 90.90 57.20 9046.15 8972.15 2408.43 1519.13 5943744.39 687429.02 10.43 620.33 10211.00 90.40 63.50 9045.68 8971.68 2428.70 1554.74 5943765.53 687464.12 15.41 661.29 10247.00 93.90 66.30 9044.33 8970.33 2443.96 1587.31 5943781.59 687496.31 12.45 697.21 10280.00 99.10 74.40 9040.59 8966.59 2454.98 1618.15 5943793.37 687526.86 29.03 729.62 10312.00 99.20 78.20 9035.50 8961.50 2462.46 1648.83 5943801.61 687557.36 11.73 760.22 10347.00 95.60 82.80 9030.99 8956.99 2468.18 1683.05 5943808.17 687591.42 16.60 793.12 10410.00 98.90 93.70 9023.02 8949.02 2470.11 1745.41 5943811.63 687653.72 17.94 849.09 10449.00 94.80 100.40 9018.36 8944.36 2465.35 1783.81 5943807.82 687692.22 20.03 880.76 10491.00 92.60 100.40 9015.65 8941.65 2457.78 1825.03 5943801.28 687733.62 5.24 913.60 10521.00 90.60 106.40 9014.81 8940.81 2450.84 1854.19 5943795.05 687762.94 21.07 936.08 10553.00 94.40 111.30 9013.42 8939.42 2440.52 1884.43 5943785.48 687793.42 19.36 957.94 10593.00 96.60 119.70 9009.58 8935.58 2423.40 1920.33 5943769.25 687829.74 21.61 981.60 10638.00 96.60 119.70 9004.40 8930.40 2401.25 1959.16 5943748.07 687869.10 0.00 1005.49 RECEIVED JUL ;5 2000 Alaska Oil & Gas Cons. Commissior~ Anchorage Schlumberg NO. 295 6/28/00 Schlumberger Technology CorpOration, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD p.s. 1-04 STA?ZC BOTTOM HOLE 000615 I 1 D.S. 4-29A STATZC BOTTOM HOLE 000610 I 1 D.S. 4-45 LEAK DETECTION L0e 000611 I 1 D.S. 13-31 LF_~DETECTZO. LOG 000617 I 1 D.S. 14-24 PRODUCTZO. PROFZLE 000620 I 1 p.s. 15-35 LS~DSTECTZO. LOG 000610 I 1 D.S. lS-33 STATZC SOTTOM HOLE 000617 I 1 D.S. 6-23A 20243 MCt~TL ~7 q(~(~'~ 000524 I I 1 D.S. [5-[5A 20242 HC~ ~ ~.~ 0005~5 I I I SIGNED DATE: JUL 07 .000 klaska Oil & Gas Cons. Oommission t~Sh0ra~e Please si[In and return one ~op~ of this transmittal to Shorrie at tho above address or fax to {007) 501-8a17. ~ hank ~ou. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 12, 2000 Mr. Robed N. Christenson, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. Christenson: Re: Prudhoe-EOA, Pt. Mac, & Lisburne Well Work This listing is provided as required under the terms of Conservation Order No. 341 (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for June 12 - 18, 2000: Well 02-23A 06-17 15-12 15-13A 15-37 15-45A P1-03 Work Planned CT SIDETRACK (NABORS 3S) TUBING PUNCH & CHEM CUT TBG CT P&A / SET WHIPSTOCK CT FISH PERFORATION GUNS CT P&A CT SIDETRACK (NABORS CDR) CT CEMENT SQUEEZE If additional data or scheduling information is needed, please call me at 263-4990 or E-mail me at prauf@ ppco.com. Sincerelyi"~'~ Paul C. Rauf Engineering Aide Phillips Wells Group Cc: Kris Fuhr ATO-420 Laura Lahrson ATO-462 ALASKA OIL AND GAS CONSERVATION COI~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Bruce E. Smith, P.E. AAI Coiling Engineerr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re' Prudhoe Bay Unit 06-23A ARCO Alaska, Inc. Permit No: 200-037 Sur Loc: 4577'FNL, 1008'FEL, Sec. 2, T10N, R14E, UM Btmhole Loc. 2191'FNL, 4264'FEL, Sec. 1, T10N, R14E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chair BY ORDER OF TH.~COMMISSION DATED this {Z. ~'~ day of April, 2000 dlffEnclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Enviromnental Conservation ,~v/o encl. ARCO Alaska, Inc. Post ~fice Bo>~ 196105 Anchorage, AI~ g9519-6105 April 11, 2000 Mr. Robert N. Christenson, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. Christenson: ARCO Alaska, Inc. requests a short turnaround approval of the attached Permit to Drill for the Drill Site 06-23A sidetrack. The DS 06-23A permit was originally requested for May 10, 2000. Due to scheduling constraints associated with our coiled tubing drilling rigs, we anticipate moving in before the above date. We request the permit be returned to us by April 17, 2000. Your immediate attention would be greatly appreciated. If you have any questions, please contact Lamar Gantt at 263-4235. Sincerely, Lamar Gantt Coiled Tubing Drilling Supevisor Arco Wells Group RECEIVED Cc: Paul Rauf ATe-1509 APR 1 2 .000 Alaska Oil & Gas Cons. Post-it, Fa)< Note 7671 [~-ax # ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill ~] Redrill [~] I lb. Type of well. Exploratory [-'] Stratigraphic Test E~] Development Oil [~] Re-entry [~ Deepen E~]] Service D Development Gas D Single Zone r~ Multiple Zone r"] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 74 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28311 Prudhoe Bay Oil Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 4577' FNL, 1008' FEL, Sec. 2, T10N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2770' FNL, 33' FEL, SEC. 2, T10N, R14E, UM 06-23A #U-630610 At total depth 9. Approximate spud date Amount 2191' FNL, 4264' FEL, Sec 1, T10N, R14E, UM May 10, 2000 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) ADL 28308, 2191' @ TD feet No Close Approach feet 2560 10625 MD / 9019 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035 (e)(2)) Kickoff depth: 9520' MD Maximum hole angle 98° Maximum surface 2438 psi~ At total depth (TVD) 3318 psig @ 880o' 18. Casing program Setting Depth size Specifications Top Bottom Quant~ of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data1 4-1/8" 2-7/8" 6.4 L-80 FL4S 1950' 8675' 8215' 10625' 9019' 20 bbls15.8 ppg Cement 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9875 teet Plugs (measured) Tagged PBTD @ 9660' MD on 2/08/2000. true vertical 9238 feet ~"~ r-~ I ~% I F, IAI Effective Depth: measured 9660 tee, Junk(measured) true vertical 9058 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 79' 20" 1990# Poleset 79' 79' Surface 2451' 13-3/8" 2400 Sx Fondu & 400 Sx P F C 2525' 2525' Production 8942' 9-5/8" 500 Sx Glass G & 50 bbls PFC 9016' 8516' Perforation depth: measured 9598' - 9612'; 9640' - 9650'; 9654'- 9660'. ' t' ~ ,2~ 0 8 ~.'.1".; , true vertical 9007' - 9018'; 9042' - 9050'; 9053'- 9058'. 20. Attachments Filing fee [~] Property Plat D BOP Sketch [~] Dive,er Sketch D Drilling Ddlling fluid program Time vs depth plot [~ Refraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Stephen Ward @ 265-1305. r~ce~~ ~/-~'~~ ~/'4,~'~ Tubing Drilling Supervisor ~'/(/~) Signed B.~~ Title: AA, Coil Date , . . Prepared b~/Paul Rauf 263-4990 Commission Use Only Permit Number APl number date '2_4:~ C:) ,- ~::~ ...~ ~ C~ ;~.~-' ,Z4~'~'~ ,o<~'-(~/ I Appr°val ~//~,; ~ 4) ISee cOver letter 50- Ifor other require,.ments co..,,,o.so, a ..ow, S m.,es.e.u,re. D .o I--I Hydrogen sulfide measures ~es D No' Direclional survey required ~YesD NO' Required wo~ng pressure for BOP~ ~2M~ I--I 3~ I--I 5~ I--I ~OM~I--I 1~l~500ps, forCTU Other: ~proved by Rol~rt N. Christen,on Commissioner the commission Date J~ () , Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 6-23A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. If scheduling permits, a service CTU will mill window in 7" casing. Directionally drill a horizontal well from the existing wellbore. Run and cement 2-7/8" liner. Perforate and produce. Intended Procedure: Service CTU · Set whipstock top at -9515' md. Cement squeeze and plugback the existing completion to - 9525' md. · RU CTD unit and test BOPE. Mill window in 7" casing at -9520' md. CT Drilling Rig · Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. Directionally drill 4.125" x 1100' horizontal well to produce from Zone 2A. Build angle to -98° and then drop to 90° at TD. · Run and cement 2-7/8" liner to TD. Test liner top to 2000 psi. · Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. RECEIVED ?300 A aska & Gas Cons. Commis on March 6, 2000 5-t/2" Tubing 5-1/2'! Camco BaI-O Nipple@ 2099' Packer @ 8644' 7, Liner To 8697' 4-1/2" DB6 Npl @ 8741' 5-1/2" Camco MMIG GLM's(10) ~ of 2-7/8" Liner in 4-1/2" TT @ 8675' TOC in 7" 9250' Whipstock set and cemented n p ace with top @ -9515' 9-5/8" Casing shoe @ 9016' Initial Perfs 7,Casing Shoe @ 9870' ]Wind~owcutin 7" -9520-9525' 4-1/8" Open hole Current perforations cement squeezed 2-7/8" liner RECEIVED TD @ - 10625' 000~/90/80 IH8 ~q peJedeJd 03AI303 ooo; w--oo[g (- 4- ~- oogg I oocz V Tg-9 woJj. /~ 00'0 'N 00'0 aouaJa.~aJ 4H,v, 00'~9 L'unw!z¥ . 9 ~ · oocg oogE ootg oooE 006~ 00~ oo/t ooob ooCb oo~.t oo~t oogk O0~t 000~ 006 009 00/- i!.0-9090~-6~0-0cj 'UOld VTg-9 : Ila~ 9 'S'O : ........... :'"s'~"~ .......... ':~'~ ~'~'~'~ ........ 55'~'¢ ............................. i 0036 '*" 006~ g .-,- ooz~ -- 0099 ~ oo~ ilX'Ueld OOMV Proposal Calculations ~g~i~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Alaska~ Inc. Vertical Sect. Plane: 62.000 TRUE Job No: 0 Field: Prudhoe Bay~ Alaska Mag. Declination: 27.270 AFE No: 0 Well: 6-23A Version#1 Grid Correction: 1.420 AP1 No: 50-029-20808-01 Rig: Nabors 3S Total Correction: 25.850 BHI Rep: 0 Surface Location Dip: 80.700 Job Start Date: 00-Jan-00 X: 685969.8 RKB Height: 74.000 Job End Date: 00-Jan-00 Y: 5941299.2 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (deg) (de~) fit) Lat. (Y) Dep. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 9400.00 33.25 49.00 8767.05 1899.50 1087.16 5943224.97 687009.44 0.00 1851.67 0.00 0.00' 0.00 Tie-in Point 9425.00 33.25 49.00 8787.96 1908.49 1097.51 5943234.22 687019.56 0.00 1865.02 0.00 0.00 0.00 9450.00 33.25 49.00 8808.86 1917.49 1107.85 5943243.46 687029.68 0.00~ 1878.38 0.00 0.00 0.00 9475.00 33.25 49.00 8829.77 1926.48 ! ! ! 8.20 5943252.71 687039.80 0.00 ! 891.74 0.00 0.00 0.00 9500.00 33.25 49.00 8850.68 1935.47 1128.54 5943261.95 687049.91 0.00 1905.09 0.00 0.00 0.00 9520.00 33.25 49.00 8867.40 1942.67 1136.82 5943269.35 687058.01 0.00 1915.78 -19.00 0.00 0.00 Kick-off Point 9525.00 34.19 48.39 8871.56 1944.50 1138.90 5943271.23 687060.05 20.05 1918.48 -19.00 18.80 -12.20 9530.00 35.14 47.81 8875.67 1946.40 ! 141.02 5943273.19 687062.12 20.05 1921.24 -19.00 19.00 -11.60 3 9550.00 39.68 45.24 8891.56 1954.76 1149.82 5943281.77 687070.71 24.00 1932.94 -17.00 22.70 -12.85 9575.00 45.42 42.65 8909.97 1966.94 1161.53 5943294.23 687082.11 24.00 1949.00 -16.00 22.96 -10.36 9600.00 51.21 40.53 8926.59 1980.91 1173.91 5943308.50 687094.14 24.00 1966.48 -14.00 23.16 -8.48 9625.00 57.03 38.72 8941.24 1996.51 1186.81 5943324.42 687106.65 24.00 1985.20 -13.00 23.28 -7.24 9650.00 62.87 37.14 8953.751 2013.58 1200.10 5943341.80 687119.51 24.00 2004.94 -12.00 23.36 -6.32 9675.00 68.73 35.72 8964.00 2031.92 1213.63 5943360.47 687132.58 24.00 2025.50 -12.00 23.44 -5.68 L_ 9700.00 74.60 34.41 8971.86 2051.33 1227.25 5943380.22 687145.72 24.00 2046.64 -11.00 23.48 -5.24 9725.00 80.47 33.17 8977.26 2071.61 1240.82 5943400.83 687158.77 24.00 2068.14 -11.00 23.48 -4.96 9750.00 86.35 31.97 8980.12 2092.53 1254.18 5943422.07 687171.61 24.00 2089.76 -11.00 23.52 -4.80 9765.50 90.00 31.24 8980.62 2105.73 1262.30 5943435.46 687179.40 24.00 2103.12 87.00 23.55 -4.71 4 9775.00 90.05 32.19 8980.61 2113.81 1267.29 5943443.66 687184.19 10.00 2111.33 87.00 0.53 10.00 9800.00~ 90.18 34.68 8980.56 2134.67 1281.07 5943464.86 687197.44 10.00 2133.28 87.00 0.52 9.96 9825.00 90.31 37.18 8980.45 2154.91 1295.74 5943485.46 687211.61 10.00 2155.74 87.00 0.52 10.00 9850.00 90.44 39.68 8980.29 2174.49 1311.27 5943505.42 687226.65 10.00 2178.65 87.00 0.52 10.00 9875.00 90.571 42.17 8980.07 2193.38 1327.65 5943524.70 687242.55! 10.00 2201.97 87.00~ 0.52 9.96 9900.00 90.70: 44.67 8979.79 2211.53 1344.83 5943543.28 687259.28' 10.00 2225.67 87.00 0.52 10.00 9925.00 90.82 47.17 8979.46 2228.92 1362.79 5943561.11 687276.80 10.00 2249.69 87.00 0.48 10.00 9950.00 90.95 49.66 8979.08 2245.51 1381.48 5943578.15 687295.07 10.00 2273.98 87.00 0.52 9.96 9975.00 91.07 52.16 8978.64 2261.27 1400.88 5943594.39 687314.08 10.00 2298.51, 87.00 0.48 10.00 10000.00 91.19 54.661 8978.14 2276.17 1420.95 5943609.78! 687333.77 10.00! 2323.22 87.00 0.48 10.00 10025.00 91.31 57.16 8977.60 2290.18 1441.65 5943624.29 687354.11 10.00 2348.07 87.00 0.48 10.00 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 10050.00 91.43 59.65 8977.00 2303.27 1462.93 5943637.91 687375.06 10.00 2373.01 87.00 0.48 9.96 10075.00 91.54 62.15 8976.35 2315.42 1484.77 5943650.60 687396.59 10.00 2398.00 87.00 0.44 10.00 ~ 10100.00 91.65 64.65 8975.66 2326.61 1507.11 5943662.34 687418.65 10.00 2422.98 87.00 0.44 10.00 10125.00 91.76 67.15 8974.91 2336.81 1529.92 5943673.10 687441.19 10.00 2447.91 87.00 0.44 10.00 10150.00 91.86 69.65 8974.12 2346.01 1553.15 5943682.88 687464.19 10.00 2472.74 87.00 0.40 10.00 10175.00 91.96 72.15 8973.29 2354.19 1576.76 5943691.63 687487.58 10.00 2497.42 87.00 0.40 10.00 10200.00 92.06 74.65 8972.41 2361.33 1600.70 5943699.36 687511.34 10.00 2521.91 87.00 0.40 i0.00 10225.00 92.15 77.15 8971.49 2367.42 1624.93 5943706.05 687535.41 10.00 2546.16 87.00 0.36 10.00 10250.00 92.24 79.65 8970.53 2372.44 1649.40 5943711.68 687559.74 10.00 2570.13 88.00 0.36 10.00 10275.00 92.33 82.15 8969.54 2376.39 1674.06 5943716.24 687584.30 10.00 2593.76 88.00 0.36 10.00 10300.00 92.41 84.65 8968.50 2379.26 1698.87 5943719.73 687609.03 10.00 2617.01 88.00 0.32 10.00 10325.00 92.48 87.15 8967.44 2381.05 1723.79 5943722.14 687633.89 10.00 2639.85 88.00 0.28 10.00 , )--~ 10350.00 92.55 89.65 8966.34 2381.75 1748.75 5943723.45 687658.82 10.00 2662.22 88.00 0.28 10.00 10375.00 92.62 92.15 8965.21 2381.36 1773.72 5943723.68 687683.79 10.00 2684.08 88.00 0.28 10.00 10379.50 92.63 92.60 8965.01 2381.17 1778.21 5943723.61 687688.29 10.00 2687.96 -59.00 0.22 10.00 5 10400.00 93.65 90.82 8963.88 2380.56 1798.67 5943723.50 687708.76 10.01 2705.74 -60.00 4.98 -8.68 10425.00 94.90 88.64 8962.02 2380.68 1823.60 5943724.24 687733.67 10.01 2727.80 -60.00 5.00 -8.72 10450.00 96.14 86.46 8959.61 2381.74 1848.46 5943725.92 687758.50 10.01 2750.25 -60.00 4.96 -8.72 10475.00 97.37 84.27 8956.67 2383.75 1873.20 5943728.53 687783.18 10'.01 2773.04 -60.00 4.92 -8.76 10488.00 98.00 83.12 8954.94 2385.16 1886.01 5943730.27 687795.95 10.01 2785.01 125.00 4.85 -8.85 6 10500.00 97.31 84.11 8953.34 2386.48 1897.82 5943731.88 687807.73 10.00 2796.07 125.00 -5.75 8.25 10525.00 95.87 86.17 8950.47 2388.59 1922.57 5943734.60 687832.41 10.00 ~818.90 125.00 -5.76 8.24 10550.00 94.42 88.21 8948.23 2389.81 1947.44 5943736.44 687857.24 10.00 · 2841.43 125.00 -5.80 8.16 10575.00 92.96 90.24 8946.62 2390.15 1972.38 5943737.39 687882.16 10.00 2863.61 125.00 -5.84 8.12 10600.00 91.501 92.28 8945.64 2389.60 1997.35 5943737.46 687907.14 10.00 2885.40 125.00 -5.84 8.16 10625.00 90.04 94.30 8945.31 2388.16 2022.31 5943736.65 687932.12 10.00 2906.76 125.00 -5.84 8.08 10625.70 90.00 94.36 8945.31 2388.11 2023.00 5943736.61 687932.82 10.00 2907.36 0.00 -5.71 8.57 TI) RECEIVED I,!A?, 0 8 tO00 Aia Oil&Gas s. mi n C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ I Otis 7" WLA Quick I' ' I Connect " I 5,000 psi working pressure Alignment Guide Flange I, I I ,-.--0.29' (3.5") .-.. 7-1/16", 5M Ram Type Dual ~ ~ Combination Cutter/Blinds Gate BOPE ~ ~ Slip / Pipe rams Flanged Fire Resistant Kelly Hose to Dual HCR Man Choke Manifold Manual Valves Drilling spool 7-1/16", 5M ~ by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic ~ 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") rl 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus RECEIVED Mu, Tanks 60/40 [ I Trplx[ Ext. Fuel Shop Boilers Water Pump Roo Fire Ext. I-ire Ext. ,~~Pipe rac2 Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT At JNT P.O. BOX 102776 ANCHORAGE, AK 99510-2776 PAGE 1 OF 1 FEBRUARY 2, 2000 TRACE NUMBER: 225126817 CHECK NUMBER: 225126817 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION 3OO1 PORCUPINE DRIVE ANCHORAGE AK 99501 AMOUNT PAID : $100.00 PAY ENTITY: 0201 ,- VENDOR NO: N00072020221 INQUIRIES:(907) 263-442214988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 INVOICE DATE INVOICE NUMBER VOUCHER GROSS AMOUNT DISCOUNT/ADJUSTMENT :~5::::;::;5::::::::::::~;~;~:~:~:~:+;~:~:`:~:~:~:~:~:`:~:~:~:~;~:~:`~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 5:i:i:i:i:i:i:E:i:!:~:E:!:E:i:i:i:i:i:i:i:i:i:i:E:i:i:i:!:i:i:i:!:i:!:!:E:E:i:~ :i:i:i:i:i:i:i¢i:E:~:E:i:i:~:i:!:~:i:i:~:5:i:i:i:~:E:i:i:~:!:i:i:[:!:i:i:i:i:!:i:!:! :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: NET AMOUNT $1 OO. OO Chicago, Illinois ,': ..: ~':: :':!.:ii':;ii:i~:'! Payable Th[OUgh Republ!i:C):.Bank -.:~ ";::!!:!:": :" .-..:..'::'?:? .:i '::i:-i:.: ::}::::;;' :;~':;:!;' .:':~RAcE:'::Nu~BE~? ..PLEASE DETACH_BEFORE DEPOSITING CHECK ..... ;(~;~.:.:.:::;.:::~..::??.;:- -':::~.:~.::..::.::::.:;.~?:; :~:~;;;:-::?;:~;;~:?:::.~;.;;?-: :":::;;;;;::::::..~.;;:; .:....::: ¢,¢:' ======================= ';;:;~:;~:::.::::.~. ;~:::::" ~: ~;.:.:.::.:..:~.(' :;~:~.:;.~.~:'~(;;:/:.~,~ ":FEBRUARY.~:.2~· 2000 :~:,.:'. ;::: ;:"~:.::' ;~ :-' :.7-;' ; pay'-" '-'." .... ":' '"' "'" '"'" :':-' ........ '-:'::::':'". '" :.:'.: :::::::-:" '-'" .......... "".:: '-: .... '.":'.' :.""'" : .... TO THE .... K ' :::6.~ER o" ........ ST**E:'O%~LaS,~?:. ....-:.-?:~?::;:.. .... :-....::.'.:- .....-..-.- .... ..:....:-: ¥?.. :?.: . ..-:...:...:,-.... ..... .:.:.....,.,..... -:::.:::::: .:.. ::::::::::::::::::::::::::: A~A'SKA::..';:O~'"-;'.. &::'~:~e'""S'}"':cOd:S'~'RgAt:!ON CO~'~i?: ::'::?::.:.?;;~ .. ::::;~'?:'::~:';;';;'::,:::::::?:;.;.-: ::?:.'"':':""::~;;::::.:. :"?::?:'":"/:":::?:::/'~: ..::: :. "?;:.:.: ::::.:~:;:.:..::.:.~?~: ~.:?:;::: ::;$O0;::I:~:'PORC-U~iN~ ~IVE::. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~;~:?~?;:.. ~;.~:~:~;~:~: ..::~:~::~.~ ..:.;::~;:::::::: .~;;..:;~:::~:;~:.:~::::X~,.. 9o?xts ..~/:~:~;;.::.::.' :::..::.:: ;:' ?'. :;.:::~:~: .:.::'.:~..~:.::.:? Th; Fi'~'~i'" ~,tion.l a~'~E':"~¥":Chi~ago-'~:¥0 .... :"~ :"~"':':':::"::' ...... ::::::::::::::::::::::::::::::::::::: :'":'~'??;"?¥:' ' ':":':' .... ~:::'":":':'""~'::::" ......... ':' ':"" 1. Type of request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perlorate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4577' FNL, 1008' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 2770' FNL, 33' FEL, SEC. 2, T10N, R14E, UM At effective depth At total depth 2502' FNL, 5004' FEL, Sec. 1, T10N, R14E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic __ Service__ ~sp's 68597~ 594129~ (asp's 686899, 5943131) (asp's 687199, 5943406) 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-23 9. Permit number / approval number 182-133 10. APl number 50-029~20808 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 79' 20" Surface 2451' 13- 3/8" Production 8942' 9-5/8" 1173' 7" 9875 9238 9660 9058 feet Plugs (measured) feet feet Junk (measured) feet Cemented 1990# Poleset 2400 Sx Fondu & 400 Sx PFC 500 Sx Glass G & 50 bbls PFC 325 Sx Class G Tagged PBTD @ 9660' MD on 2/08/2000. Measured Depth True vertical Depth 79' 79' 2525' 2525' 9016' 8516' 9870' 9233' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9598' - 9612'; 9640' - 9650'; 9654' - 9660'. 9007' - 9018'; 9042' - 9050'; 9053' - 9058'. RECEIVED 2000 5-1/2", 17#, L-80 PCT @ 8657' MD; 4-1/2", 12.6#, N-80 PCT @ 8754' MD. 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8644' MD. 5-1/2" CAMCO BAL-O SSSV @ 2099' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation May 1, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~(~)q(~ ~, ~~-~-O~ ~'l'itle: AA, Coil Tubing Drilling Supervisor FOR COMMISSION USE ONLY Questions? Call Stephen Ward @ 265-1305. Prepared b~/ Paul Rau~ 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test __ Subsequent form required 10- Approved by' order of the Commission Commissioner Approval no.,~ ~])~)- ~)j ¢ Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY ~/~ WELL NAME PROGRAM: exp dev v~ redrll V'" serv~ wellbore seg ann. disposal para req FIELD & POOL INIT CLASS ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11 APB. R DATE 12. ~ '/D. ~13. ,/~-- Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. GEOL AREA N UNIT# , ~.~//~ ~""'['~_...) , ON/OFF SHORE N N N 23. If diverter required, does it meet regulations .......... ,,Y---N ~,~ 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................. (..'t') N ~1~1~_ ~ DATE 26. BOPE press rating appropriate; test to . ~O~ psig. ~'~ N $//'1,~,-(30 27. Choke manifold complies w/APl RP-53 (May 84) ........ -' ' 28. Work will occur without operation shutdown ........... {Y) N 29. Is presence of H2S gas probable ................. Y'" N~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ...... /t,/,,~'_. Y "lq~' 32. Seismic analysis of shallow gas zones ............ /t,/~/~. Y N AP, J~ DATE 33. Seabed condition survey (if off-shore) ............ ,cf/, ~ Y N I/.~?~.~ '~_~:C~ 34. Contact name/phone for weekly progress reports [exploratory o~/], ~ N I ANNULAR DISPOSAL35. With proper cementing records, this plan ' ' (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool;and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: rn z --I -!- c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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 **** REEL HEADER **** MWD 01/05/24 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/24/21 40857 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!J!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame %MNEM.UNIT Data Type Information STRT.FT 9522.0000: Starting Depth STOP.FT 10638.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: PHILLIPS Alaska, Inc. WELL. WELL: 06-23A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 4577' FNL, 1008' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 22-May-00 API. API NYUMBER: 500292080801 ~Parameter Information Block ~MNEM.UNIT Value Description SECT. 2 : Section TOWN.N 10N : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 74 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 74 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 06-23A was kicked off @ 9530' MD (8875' SSTVD) from the original wellbore of Well 06-23. (5) Well 06-23A was drilled to 10626' MD (8932' SSTVD) on Run 4. After a depth tie in, bottom was tagged at 10638' MD (8930' SSTVD). (6) The interval from 10602' MD (8935' SSTVD) to 10638' MD (8930' SSTVD) was not logged due to sensor to bit offset. (7) The data presented is final and has been depth shifted to a PDC (Primary Depth Control) suppled by BPXA (Schlumberger, 24-May-00). (8) A Magnetic Declination correction of 27.27 degrees has been applied to the Directional Surveys. ~s~I~ ~doIs q~ON N~OD ~un X~s soypnxa NS ~£E-90 NM 'DUI '~SeI~ S~I~IH~ ND DD~ ~A ~ZNIA SNOD :Z%~i NOIIIfI~/OMNI ~ I00' ss%Xq E£I :qSBusI pxoosa umm~xe~ ss~Kq 8 :q~busI pxoosx · ''sploos~ £6 I :sI~qns Sd~L Xlf~ :ZA~D IZS~O 'HO~ :ZA~D ZS~S ELI9L§'O i 60ILSE'O i ELI9L§'O- i EIOE9'9 i ~6£~0'9 I0£££'9 i EIOE9'9 ~L89~'~ i 9908I'~ i ~L89~'~ i 6699I'£ i ~£68'5 i LEO£O'~ i £~§09'~ i 8£LI£'5 ~099I'£ i ~6£~'I i I8E£98'0 i '0§'E086 '89 8~L6 '8I 6£L6 'EE §0L6 '6~ 9696 '~0 8L96 '~E 8996 'I~ ~996 'L~ £§96 '9~ I§96 '§~ L£96 '8I 0E96 '§I 9196 '66 EI96 'IE £8~6 'E£ 6~§6 '0L '£6 ~§6 QN~ 'E6 I086 '6£ 8~L6 '9L 6£L6 '09 8696 '5§ 0696 'IL IL96 '£9 I996 '~0 6~96 '68 8P96 '60'9~96 '6E P£96 '6E §I96 'EI EI96 '8£ 8096 '68 8£§6 '98 §~6 '£§'6~§6 '6P'£~§6 £ I ~noq/~s~ 'uo~u~ So s~ <- SdO~ (s~un Id~-~MN) [~M~] Ia~-~MM K~ ~um~ <- X~ :SDINO~ZN~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPXA 3. The PDC used is a Schlumberger Gamma Ray dated 24-MAY-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXll 0.0 2 ROP ROPSll 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GR MWD 2 ROP MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Total Data Records: 27 Tape File Start Depth = 9522.000000 Tape File End Depth = 10638.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 36 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU Length 4 4 8 WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska~ Inc. WN FN COUN STAT 06-23A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE#' 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Total Data Records: 27 Length 4 4 8 Tape File Start Depth = 9522.000000 Tape File End Depth = 10638.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 36 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/24/21 40857 01 **** REEL TRAILER **** MWD 01/05/24 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes [] 00000§'0 = 5uToeds Iens~ eIT~ ed~i 000000'8£90I = q~dso pu~ sIT~ ~del 000000'Eg§6 = q%dsG ~$ aITM ~d~i 00§~ 0£I£ 0990 009I 0§8£ 0£§I 0£g£ 09§£ 0££~ 0616 06gE 0609 OOgE 00§~ 666- 00§~'666- 0000 6§ 000£'9I 0000 88 09£0'I~ 0000 9£ 0699'LI 0000 98 0L£§'8I 0000 Oil 00g£'6I 0000 66 0600'£I 0000 06 O~t§'8I 0000 98 Ot§9'g~ 0000 '0£I 0£0~'9g 0000 '98 06££'£9 0000 '98 08I~'9~ 0000 '666- 0198'£I 000§ '666- 06~£'§I 0000 $~0~ Xtf~D 8£90I 0090I 00~0I 00901 00£0I 00EOI 00IOI 0000I 0066 0086 OOL6 0096 ~g6 ~gg6 H~G SI% :sdX$ ST £ @TT~qns [] ~@e~ = S]TUfl qsdso SyT~ 00000§'0 = BUToeds ISA~% eTT~ ~d~ 000000'8£90I = q~deo pu~ eIT~ 000000'~§6 = q~d@o ~ze~S ~IT~ 00§E'666- £I99'99 96EE'68 09EE'LL I§LL'98 6£66'60I 9£9L 00I 90I~ 06 60£I 98 §LA9 6~I EO08 ~£ 8998 98 00§E'666- 00§~'666- dO~ 00§E'666- 9910 9I 966I 8I ~I§E LI §E96 8I §OE6 ~I 86~0 6I LEI9 Lg 6069 8§ §O§L'O£ §££8'8I 98£8'9I £896'8I 0000'8£90I 0000'0090I 0000'00§0I 0000'00901 0000'00£0I 0000'00~0I 0000'00IOI 0000'0000I 0000'0066 0000'0086 0000'00£6 0000'0096 O00g'E~g6 0000'~§6 Hi~O SI% :sdKj sT E aTT~qn$ adei [] SI~ :sdK~ sT I @TT~qn$ ede£
