The URL can be used to link to this page

Home My WebLink About197-039 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. I q '7 03'1 Well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. 11/28/05 Schlumberger ,~ ?"" ~~;:'':o C". ~ .1. ~ ~.-~ '~ ~,- ~v i~.¡ "'8' NO. 3613 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,. ; , '2 c; 2Q05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ':?:~ :¿;.~S (;Üns.~ CÚ(Om~~~i1 ,i1,nd1orage Field: Prudhoe Bay, Milne Pt. e 0 og eSCrlptlon ate o or PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 US IT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 C D.S. 03-3~ 10893093 SCM! I /. .'" 03/05/05 1 C-19B 10128&33 SCMT'" /' '.. '/' 05/15/05 1 09-20 10889215 SCMT 02/18/05 1 D.S.09-31C N/A SCMT 11/05/05 1 P-06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 D.S. 06-20 11062630 US IT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 WII J b # L D 'f D BL CI CD ~ I BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 :jCANNEL DEC 1 6 2005 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth " ~'~r Received b~ " V X . \..A !(j - ~ Date Delivered: Illlf:\ \05 J~ STATE OF ALASKA ) ALASKA" IL AND GAS CONSERVATION COMrvllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Zero Other 5. Date Comp., Susp., or Aband. 3/3/2005 6. Date Spudded 04119/1997 7. Date T.D. Reached 04/28/1997 8. KB Elevation (ft): 62' 9. Plug Back Depth (MD+ TVD) 11350 + 8933 10. Total Depth (MD+ TVD) 13150 + 8902 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL RECEIVED MAY 0 3 20lJ51 1 b. \4mÞ~º~: & Ga~ Cons. Commi3s~n o DevelopmentAp~lØtatory o Stratigraphic IBI Service 12. Permit to Drill Number 197-039 305-014 13. API Number 50- 029-21142-01-00 14. Well Name and Number: 1 a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 215' NSL, 821' EWL, SEC. 11, T10N, R15E, UM Top of Productive Horizon: 2402' NSL, 4645' EWL, SEC. 11, T10N, R15E, UM Total Depth: 3760' NSL, 2620' EWL, SEC. 11, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- _2~~~~~_" y- 593~~?~___ Zone- ___~~±___ TPI: x- 717873 y- 5938574 Zone- ASP4 Total Depth: x- 715808 y- 5939873 Zone- ASP4 ----......._--------------- ------------------------. ------------------- 18. Directional Survey 0 Yes IBI No 21. Logs Run: MWD, GR 22. PBU 03-33A 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028327 17. Land Use Permit: 20. Thickness of Permafrost 19001 (Approx.) CASING SIZE 20" 13-3/8" 9·518" GRADE H-40 L-80 L·80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE ·1 OP 1:50TTOM lOP 1:50TTOM SIZE Surface 110' Surface 110' 30'1 Surface 2506' Surface 2506' 17-1/2" Surface 10374' Surface 8706' 12-1/4" 10165' 10402' 8500' 87341 8-1/2" 10134' 13150' 8470' 8902' 3.69" CEMENTING RECORD 1910# Paleset 2300 sx Coldset III, 400 sx CS II 500 sx Class 'G', 300 sx CS I 300 sx Class 'G' 118 sx Class 'G' AMOUNT PULLED WT. PER FT. 91.5# 72# 47# 29# 6.5# 7" 2·7/8" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED MAY 11 2005 26. Date First Production: Not on Injection Date of Test Hours Tested TVD TUBING RECORD SIZE DEPTH SET (MD) 5·1/2",17#, L-80 96851.10123' 4-1/2",12.6#, L-80 10123' - 10219' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10038' P&A with 18 Bbls Class 'G' 9646' Set EZSV 9594' Set Whipstock 24. PACKER SET (MD) 101131 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil -BBl PRODUCTION FOR TEST PERIOD + Flow Tubing . Casing Pressure CALCULATED + Oll-BsL Press. 24-HoUR RATE GAs-McF GAS-Oil RATIO WATER-BSl CHOKE SIZE GAs-McF OIL GRAVITY-API (CORR) W ATER-Bsl 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 RBDMS 8Ft MAYO 4 2005 ORIGINAL GF CONTINUED ON REVERSE SIDE 28. ) 29. ) FORMATION TESTS GEOLOGIC MARKERS 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". Sadlerochit 10444' 8776' None Zone 3 10524' 8852' Zone 2 105921 8908' 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. 4/\ 11 ;.... L I IJ ¡:J 4 T tl T h· I A . t t Teme Hubble"- VJULo<..V ~_ i e ec mca SSIS an PBU 03-33A 197-039 305-014 Prepared By Name/Number: Well Number Drilling Engineer: Permit No.1 Approval No. INSTRUCTIONS Date OS/o;;t/O.<; Terrie Hubble, 564-4628 Dave Wesley, 564-5153 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 03-33B Prudhoe Bay Unit 50-029-21142-02-00 205-018 Accept: Spud: Release: Rig: 03/08/05 03/14/05 03/23/05 Nabors 2ES PRE-RIG WORK 02111/05 RAN 2 1/4 CENT, 1 1/2 S.B. SAT DOWN AT 10,268' SLM. JARRED DOWN, REAL STICKY, POOH. SAMPLE BAILER HAD BLACK POWDERY SUBSTANCE. TOP PERFORATIONS AT 10520' MD COVERED BY FILL. 02/19/05 SET C-SUB AT 2383' SLM. 02120/05 PULLED AVA BRAIN FROM 2169' SLM. SET LOCK OUT AVA BRAIN AT SAME. RAN FLAPPER CHECKER, (DID NOT CATCH FLAPPER) LOCKED OUT. BAILED OUT C-SUB AND PULLED FROM 2179' SLM. 02128/05 WELL SI UPON ARRIVAL. RIH W/2" JSN TO 10250' AND CIRC-OUT MI GAS TO 03-34 FLOWLINE. RIH AND JET SOFT SCHMOO TO 11,200' CTMD. CHASE SCHMOO OOH. 03/01/05 CONTINUE TO CHASE SCHMOO OOH. FREEZE PROTECT COIL AND WELL. 03/02/05 RIH WI TWO STINGERS/2" BDN. SIT DOWN AT SSSV. POOH FOR SLICK BHA. RIHW/2 STINGERSt1.75" BDN. SIT DOWN SAME SPOT. POOH. RIH WI CHECKS/3 STINGERS/1.75" DJN. RUN THROUGH SSSV NO PROBLEM. POOH FOR CEMENTING BHA. 03/03/05 STAB ON WELL AND PRESSURE TEST LUBRICATOR. MU/RIH WITH CEMENTING BHA (1.75" CRC, 3 STINGERS, 1.75" BDN). COOL SUMP AND LAY IN 18 BBLS 15.8 PPG CLASS G CEMENT FROM 11200'- 9600' CTMD. GET 800 PSI PRESSURE BUMP AND HOLD FOR 30 MINUTES. CONTAMINATE TO 10105' CTMD AND CLEAN OUT. ESTIMATED TOC = 10115' CTMD. FREEZE PROTECT TUBING FROM 2300' CTMD AND TRAP 290 PSI ON WELLHEAD. RDMO. READY FOR SLlCKLlNE TO DRIFTrrAG. JOB COMPLETE. 03/04/05 DRIFT TUBING TO 10,000' SLM, WI 3.25" CENTRALIZER & SAMPLE BAILER. DRIFT TO TBG PATCH AT 9,985' SLM W/4.5 CENTRALIZER. DRIFT TO CEMENT TOP AT 10,038' SLM, WI 2.5" CENTRALIZER. 03/05/05 LOG SCMT UP FROM 9865' - 8750' FOUND NO CEMENT IN IA. CUT TUBING AT 9685' WITH 4.435" JET CUTTER. RAN SCMT 8750' - 9865', FOUND NO CEMENT IN IA. PERFORMED JET CUT AT 9685' WITH 4.435 JET CUTTER (REF TBG TALLY). ) ) Page 1··_ i:3PEXPLOfqATION øf)eta~¡iÐ.AS..···Sì.JmR1.a.ty·.·.·Re.p()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: Date From-To Hours. Task· CodeNPT Phase Description of. Operations 3/7/2005 00:00 - 07:30 07:30 - 08:00 08:00 - 18:00 7.50 MOB 0.50 MOB 10.00 MOB 18:00 - 21 :30 3.50 MOB N 21 :30 - 00:00 2.50 MOB P 3/8/2005 00:00 - 01 :00 1.00 MOB P 01 :00 - 06:30 5.50 MOB P 06:30 - 08:00 1.50 DHB P 08:00 - 11 :30 3.50 MOB P 11 :30 - 12:00 0.50 WHSUR P 12:00 - 13:00 1.00 WHSUR P 13:00 - 16:30 3.50 WHSUR P 16:30 - 17:30 1.00 WHSUR P 17:30 - 20:30 3.00 WHSUR P 20:30 - 22:00 1.50 WHSUR P 22:00 - 00:00 2.00 WHSUR N 3/9/2005 15.50 WHSUR N 00:00 - 15:30 N P P WAIT PRE PRE PRE WAIT PRE PRE PRE PRE Waiting on Security to move. PJSM to move rig. Move sub from F pad to DS 3 Wire line has set up on DS 17 and would not allow rif=g to pass without additional snow removal. Call out roads and pads to remove snow. Up right tanks had been placed in rig move path after route was review and driven. Rig on stand-by waiting on snow removal to pass wire line operations on DS 17 Move sub base from DS 17 to DS 3 PJSM: Lay Herculite and spot sub base. PJSM: Rig up and raise derrick. Rig up rig floor and cellar. Berm area and cellar. DECOMP Install Secondary annulus valve and pull back pressure valve. Productive time for rig. PRE Lay matting & Herculite. Spot pits and camp. Hook up pits. Berm and spot cutting tank. DECaMP Pre-job and Spud meeting with both crews for rig accept. Review pre-spud check list and do walk through with driller and pusher. Rig accept. Rig has 1.5 hour working time installing secondary annulus valve and pulling BPV from 6:30 to 8:00 am today. This cost will be captured in daily cost section. DECOMP PJSM: Rig up lines to circulate well. Test lines to 4000 psi and chart same. DECaMP Circulate well to seawater First pump down annulus and recover freeze protect from tubing. Swap lines and pump soap pill down tubing, Circulate well to fresh sea water. Verify well is dead. DECOMP PJSM: Dry rod back pressure valve. Test from below to 1000 psi. Blow down surface equipment. Winds at 35 MPH visibility as < 20 feet. Security calling phase 2 but much worse on location. Plan to secure well and shut down operation for safety. DECOMP PJSM: Nipple down tree. and adapter flange. Verify tubing hanger flange and that the tubing hanger is not a welded hanger. Check threads with Cameron, WSL and Driller. DECOMP PJSM & review procedure: Nipple up BOP. Working towards securing well to do weather shut down. 20:15 hours Fuel truck drive scrapes against warm up shack. HSE and security notified. Incident report and traction started. Visibility is < 20 feet. Security call Phase 3. WAIT DECOMP Phase 3 conditions: Review safety condition, fuel and water level of rig and shut down operation. Weather very severe. WAIT DECOMP Phase 3 Waiting on weather. Very Bad! Winds 40 - 50 MPH wind chill - 70 degrees. Stack is set with 4 bolts tight. Not tested. Tested BPV in place. Printed: 3128/2005 8:05:37 AM ) ) BPEXPLORATION QperatlofIls$LJrnrnary· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page·2'-' 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: Date Description··.øfrQperatibns From~ToHours Task CodeNPT Phase WAIT DECOMP Will try to change out crews with heavy escort this morning. 3/9/2005 00:00 - 15:30 15.50 WHSUR N 15:30 - 17:30 2.00 WHSUR P 17:30 - 22:00 4.50 WHSUR P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 WHSUR P 3/1 0/2005 00:00 - 02:00 2.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 06:00 3.00 WHSUR N 06:00 - 11 :00 5.00 WHSUR N 11 :00 - 12:30 1.50 WHSUR P 12:30 - 14:00 1.50 PULL P 14:00 - 15:00 1.00 PULL P 15:00 - 15:30 15:30 - 18:00 0.50 PULL P 2.50 PULL P 18:00 - 18:30 0.50 PULL P DECOMP PJSM: Clear exit from pad. Hold PJSM to N/U BOP. Nipple up BOP. Witness waived by John Crisp AOGCC DECOMP PJSM & Review procedure to test BOP's: Test BOP's. 250 low test and 4000 psi high test. Top set rams failed. Test annular to 3000 psi high test. DECOMP PJSM amd review procedure: Change out top rams to 5 1/2" fixed bore. DECOMP Test 51/2" Rams 250 low 4000 psi high. Good test. DSM is unable to get crew to location to pull BPV till around 6 AM estimated. Drill Site Maintenance was on V pad 1 7ES and could not make it to puIlBPV. While waiting, repaired the variable 31/2" X 6" rams. Waiting on DSM. DECOMP Test valves on top drive 250 low and 4000 psi high. Waiting on Drill Site Maintenance. BOP test witness waived by AOGCC John Chrisp. DECOMP While waiting on DSM: Change out top rams to 3 1/2" variable and re tested 250 low and 4000 psi high to utilize rig time. Pull Blanking plug. Rig down test joint. Blow down top drive and kill lines. Phase 3 on Pads and Phase 2 on spine roads. WAIT DECOMP Waiting on DSM to pull BPV 1 Service rig and top drive while waiting. WAIT DECOMP Phase 3 conditions: All operations shut down. Unable to keep access to rig open. Will need DSM to start up operations. DECOMP DSM arrives: PJSM: Rig up lubricator. Pull back pressure valve. Rig down DSM and lubricator. DECOMP PJSM & Review procedure: Make up landing joint and Release lock down screws. DECOMP PJSM & Review procedure: Pull Hanger to rig floor. 180,000 # Up to free tubing spool from tree. Lay down hanger and landing joint. DECOMP PJSM with Schlumberger / Camco: Rig up Spooling unit. DECOMP Lay down tubing while spooling control line from 9700 to 7520'. Terminated control line. Recover 4 stainless steel bands and 27 clamps and pins. Phase conditions on Pad are getting worse. Will continue to safe point and secure well. DECOMP Rig down Camco spooling unit. Secure well and shut down due to weather and phase conditions. Printed: 3/28/2005 8:05:37 AM ) ) I3PEXPLORATION Ope~~t¡iºl1s.·$urr1"nary· ··R~pørt Page 3~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: Date From-To HoUrs Task çode NPT Phase Description of Operations 3/1 0/2005 18:00 - 18:30 18:30 - 19:30 0.50 PULL P 1.00 PULL N DECOMP WAIT DECOMP Waiting on weather. Well Site Leader and Toolpusher audit location for access and evaluate ability to get emergency assistance to and from rig. Fork lift operator able to keep access open. Phase 3 on pads and access roads and Phase 2 on spine roads. Snow blowing in as fast as we can move it. DRifts 6 - 8 feet on location. Able to keep road open. 19:30 - 00:00 4.50 PULL P DECOMP PJSM discuss conditions and weather: Resume operations at controlled pace. Pull out of hole laying down tubing form 7490' to 2755'. Running both loaders, 1 keeping access open and second moving tubing. Location is blowing in. Can not get large trucks turned around on location. Roads and pads can not support, working on fire lanes and main roads only. Work continuing at controled pace. Drifts 6 - 8 feet on pad. 3/11/2005 00:00 - 04:30 4.50 PULL P DECOMP Pull out of hole with 5 1/2" tubing and lay down same from 2755 to tubing cut @ 9660' 15' from collar t to cut. Cut flared and jagged. A full cut but not very clean, flared. Weather conditions have improved slightly but location has 6 - 8' drifts. Trucks unable to turn around on locations. Clear Rig floor and lay handling tools. Install 4" Rams and test stack and rams. 250 psi low and 4000 psi high. Test Bag to 3000 psi. Rig down test joint. PJSM: Pick up mills and BHA for clean out run. Pick Up BHA, DC's and HWDP to 955" Pick up 4" drill pipe from 955' to 9660' tag top of fish. Lay down one joint. Up weight = 205,000# Slack off = 165,000# DECOMP PJSM: Make up RTTS / storm packer. Set packer 3' below tubing spool. Test from below 500 psi. Blow down surface equipment. DECOMP PJSM: Nipple down BOP. DECOMP PJSM: Remove tubing spool, Remove spool and tree from cellar. Change out top seal on lower pack off. Install new tubing spool and test pack off to 3800 psi. DECOMP PJSM: Nipple up BOP. DECOMP PJSM: New Crew. Make up raiser and flow line. Derrick inspections. Run in test plug. 04:00 - 06:30 2.50 PULL P DECOMP 06:30 - 07:30 1.00 PULL P DECaMP 07:30 - 09:00 1.50 CLEAN P DEcaMP 09:00 - 15:30 6.50 CLEAN P DECOMP 15:30 - 16:30 1.00 CLEAN P 16:30 - 18:00 1.50 CLEAN P 18:00 - 23:00 5.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 3/12/2005 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 02:00 0.50 CLEAN P DEcaMP PJSM: Test break in stack at tubing spool. Test plug not holding. Rig down test plug and install wear bushing. 02:00 - 03:00 1.00 CLEAN P DECOMP PJSM: Pick up single drill pipe and TIW valve. Sting into RTTS and pick up to string weight 160,000#. Test against RTTS and upper rams. 250 low and 4000 psi high. Good test. Test plug showed signs of damage and needs to be changed out. Printed: 3/2812005 8:05:37 AM ) ) BPEXPLORATION Operations .SummaryReport Page 4"" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: .·Date . From-To HöursTa.sk Code NPT Phase Description of Operations 3/12/2005 02:00 - 03:00 1.00 CLEAN P DECOMP Release RTTS and pull to surface. Lay down RTTS and clear rig floor. Pick up single and tag fish at 9660. 03:00 - 05:30 2.50 CLEAN P DECOMP PJSM: Circulate and swap out seawater to 10.5 LSND Mud @ 10 BPM. 04: 15 During displacement the returns were diverted to cuttings box and the down snout was frozen off, causing fluid to back up and splatter over and drop onto the top rim of the cutting box and onto the herculite, Approximately 15 - 20 gallons all in containment. 5700 was called at 04:45 hours. SRT call the rig at 05:00. Discussed the event and advised us to continue and clean up. SRT:Vic Richart responded assessed the discharge as a leak contained by secondary containment / non-reportable. Traction Report # 2005-IR-1278522 Cleaned up the splatterand dirty snow around the cutting box. 05:30 - 07:00 1.50 CLEAN P DECOMP PJSM: Cut and slip 125' of drilling line. Service top drive. 07:00 - 10:00 3.00 CLEAN P DECOMP Pull out of hole 9660 to 955' 10:00 - 11 :00 1.00 CLEAN P DECOMP PJSM: Handle BHA stand back HWDP & DC's. Lay down bumper sub and mills. Mills look good. 11 :00 - 12:30 1.50 DHB P DECOMP PJSM and review procedure. Rig up Schlumberger wire line to set BP. 12:30 - 16:30 4.00 DHB P DECOMP Make up bridge plug and firing head. Run in hole and tag top of fish 9684 WLM. Log for collars. Set EZSV @ 9646 WLM. POOH with wire line and rig down Schlumberger. 16:30 - 17:30 1.00 DHB P DECOMP PJSM: Rig up and test 9 5/8" casing to 4000 psi for 30 minutes and chart. Good test. 17:30 - 21 :00 3.50 STWHIP P WEXIT PJSM: Pick up and make up whip stock BHA. Up load MWD. Surface test at 500 gpm 770 psi. MWD working. Make up BHA from 450 to 1035 feet HWDP and DC's. 21 :00 - 00:00 3.00 STWHIP P WEXIT Run in hole from 1035 to 7102 with pipe from derrick. Fill pipe every 3000' and test MWD. 3/13/2005 00:00 - 01 :30 1.50 STWHIP P WEXIT Run in hole to 9527 feet! Fill pipe and hook up blower hose to top drive. Establish whip stock tool face and set to 68 right of highside. 01 :30 - 02:30 1.00 STWHIP P WEXIT Set whipstock tool face to 68 right of highside and set at 9594' top of window. Tag BP @ 9616' MD bottom WS. Up weight = 215,000# whip stock on 205,000 off String weight 147,000# down Torque off bottom 10,000# Printed: 3128/2005 8:05:37 AM · , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: -) ) PageS. BP EXPLORATION Operations .SummaryRepørt 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3n /2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: Date From - To Hours Task Code NPT Phase DescriptionofOperatiörts 3/13/2005 01 :30 - 02:30 1.00 STWHIP P WEXIT Torque milling 12 -15,000# Higher than normal. Will increase lubes to attempt to decrease torque. WLM depth corrected to DP measurements. TOW 9594' 02:30 - 08:30 6.00 STWHIP P WEXIT Milling window: 9594' to 9610'. Continue making hole to 9622'. 1 00 rpm Torque = 12 - 15,000 5K WOB Milling at 2 - 4 feet per hour Top of window 9594' MD 8003.4' TVD Pumping at 510 gpm SP = 2250 psi Magnet in return lines and recovering & weighting cuttings Up weight = 180,000# Down Weight= 160,000# Rotating weight = 170,000# Torque dropped slightly with lube increase to 9 - 13K 08:30 - 09:30 1.00 STWHIP P WEXIT Pump sweep, work through window 190,000 # up //155,000# down Recovered 80 # metal total 09:30 - 10:30 1.00 STWHIP P WEXIT PJSM: Rig up to perform FIT while circulating. Perform FIT to 12.5 ppg 840 psi on surface @ 8003' TVD. Good test. 10:30 - 14:30 4.00 STWHIP P WEXIT Pump dry job and POOH with milling BHA from 9622 to 1013'. 14:30 - 16:30 2.00 STWHIP P WEXIT POOH 1013 to 386. Lay down drill collars and mills. Mills in good shape and full gauge. 16:30 - 17:30 1.00 STWHIP P WEXIT PJSM: Pull wear ring. Flush BOP's with Johnny whacker. Function BOP. 17:30 - 20:00 2.50 STWHIP P WEXIT PJSM: Make up 8 1/2" drilling BHA. Orient MWD / motor offset. Surface test MWD and motor. 20:00 - 20:30 0.50 STWHIP P WEXIT PJSM: Service top drive and skate. 20:30 - 00:00 3.50 STWHIP P WEXIT Run in hole 802 to 6402' Pick up single drill pipe to 5189' after running stands form derrick. Fill pipe every 3000' and test MWD.. 3/14/2005 00:00 - 01 :00 1.00 STWHIP P WEXIT Trip in hole from 6402' to 8730' to start MAD PASS. 01 :00 - 02:30 1.50 STWHIP P WEXIT Mad Pass 8730' to 8970' to tie in gamma log. Break circulating and estibilish clean hole ECD. 550 = 10.82 ppg 525 = 10.80 ppg With cold mud. 02:30 - 03:00 0.50 STWHIP P WEXIT Trip in to above window. Break circulation and estibilish tool face 65 R to exit. 03:00 - 04:00 1.00 STWHIP P WEXIT PJSM: Wash under gauge hole 961 ° to 9622' Up weight 185,000# Down weight= 155,000# ~ 04:00 - 06:00 2.00 DRILL P INT1 Drill from 9622 to 9850' COD IO.~ 10 11.1ppg Printed: 312812005 8:05:37 AM ) rnJ~ ) FRANK H. MURKOWSKI, GOVERNOR AIfASIiA. OIL AlVD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 rí"~I"Ð31 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99516612 Re: Prudhoe 03-33A Sundry Number: 305-014 Dear Mr. Isaacson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23r ay £ Jowing the date of this letter, or the next working day if the 23rd day falls 0 holiday or weekend. A person may not appeal a Commission decision to Super'. - Co u ess rehearing has been requested. . . DATED this1-1';¿y of January, 2005 Enc!. ,:':f'A" Ni\iED FES th <91 'JOO' 5. ~6I, ~\L,,,_,,, ~ t1 kJ Ii- \l-!4A- q1-~/W°5"' , 1Jff1. Ii LS¡:S ) STATE OF ALASKA ) REC - ALASKA OIL AND GAS CONSERVATION COMMISSION EIVED APPLICATION FOR SUNDRY APPROVAL JAN 13 Z005 20 AAC 25.280 Alaska Oil & Gas Cons. Commission Anclmrsge 1. Type of Request: II Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic H Service / 5. Permit To U!J..D.. (II Number 197-039 /' 6. API Number: /' 50-029-21142-01-00 99519-6612 62' 9. Well Name and Number: / PBU 03-33A 8. Property Designation: ADL 028327 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11350 8933 11350 MD TVD Burst Junk (measured): 11290 Collapse Total Depth MD (ft): 13150 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8902 Length Size Liner 1101 20" 110' 110' 1490 470 2506' 13-3/8" 2506' 2506' 5380 2670 10374' 9-5/8" 103741 8706' 6870 4760 237' 7" 10165' - 10402' 85001 - 8734' 8160 7020 30161 2-7/8" 101341 - 13150' 84701 - 89021 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): 105201 - 131141 8848' - 8899' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 13-H' packer; 5-1/2" AVA TRSV SSSV Tubing Size: 5-1/2', 17# x 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 10113' 2187' Tubing MD (ft): 102191 12. Attachments: H Description Summary of Proposal 0 BOP Sketch 0 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 Bill Isaacson Title Senior Drilling Engineer Signature Ù-Jl. t. t,. Phone 564-5521 Commission Use Only 13. Well Class after proposed work: 0 Exploratory 0 Development IBI Service , 15. Well Status after proposed work: January 31, 2005 /' 0 Oil 0 Gas 0 Plugged/a Abandoned Date: 0 WAG 0 GINJ 0 WINJ 0 WDSPL Contact Dave Wesley, 564-5153 Date 1/10/'5 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness ~IUg Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 4000 pt;t ' t 0 - 4-0 I ~~...:¿ ,,,,<d tv:;; rk i~ ()Aft I CJ 3 - ) ~ B ' I Sundry Number: .306" .. ~~t.I:. . COMMISSIONER APPROVED BY THE COMMISSION RBDMS BFL JAW 3 1 2005 Date i~t£ ORIGINAL \. ) ) ~bp . To: Winton Aubert - AOGCC Date: January 24, 2005 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: Reference: 03-33A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-21142-01 Approval is requested for the proposed P&A of PBU well 03-33. A. \¡...Ì4~ The 03-33Bi sidetrack is scheduled for Nabors 2ES. Current estimates have it beginning around March 01, 2005, following the completion of the F-29A. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-RiQ Operations: 1. The 5 ¥2", 17.0#, L-80 PC tubing has a MERLA tubing patch installed over the #9GLM (deepest) at 10,023' . 2. An IA cement squeeze was performed 9/26/2000. The tubing was punched at -10,065'. Approximately 7bbls cement was squeezed into IA. Estimated cement top in IA is -9,950' md. ~ 3. Last MIT-IA passed to 4,000psi on 11/02/2004. /' 4. Last MIT-OA passed to 2,000psi on 05/14/2002. Conduct an MIT-OA to 2,000psi. 5. Function all casing and tubing LOS and re-torque as recommended by Cameron. 6. R/U slick-line. RIH with lock-out t~ol a d lock open the AVA TRSV. POOH. / 7. R/U coiled tubing. RIH and plug a.' a..,. andon the open perforations. Leave top of cement at -10,125'. / The cement volume required is 17 bbls. This is based upon 15' of 4 %",12.6# tubing, 1,212' of 2 7/8",6.5# liner, and approximate ".Obbls to squeeze the open perforations. POOH. 8. Drift 5 %" tubing to top of cement plug at -10, 125'md, below the planned tubing cut depth of /' -9,700'md. POOH. 9. Pressure test cement plug to 1,000psi. 10. R/U SWS E-line. RIH with appropriate chemical cutter and cut the 5 %" tubing at -9,700'md. 11. Circulate the well to seawater through the tubing cut, until returns are clean. Conduct a CMIT T X IA to 3,000psi for 30 minutes. 12. Freeze protect to -2,200' MO with diesel. 13. Bleed casing and annulus pressures to zero. 14. Set a BPV. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install BPV. 3. Nipple down the tree. Inspect tubing hanger threads. Install "blanking glug" in hanger running thread. 4. Nipple up and test BOPE to 4,000psi. Pull blanking plug and BPV. / 5. R/U. Pull the 5 %" tubing from the tubing cut at -9,700'md and above. Be prepared to spool up the AVA TRSV control line. 6. M/U an 8 %" milling assembly and RIH, P/U 4" drill pipe. Tag the tubing stub at -9,700'. POOH. 03-33A Application for Sundry A. 7. R/U SWS E-line. M/U a HES 9 5/8" EZSV bridge plug. RIH with EZSV and set at -9,670'md. POOH and RID E-line. 8. R/U and pressure test the 9 5/8" casing to 4,000psi for 30 minutes. Record the test. 9. N/D the BOPE stack and the tubing spool. CIO the 9 5/8" slips seal pack-off. N/U a new tubing spool. Test the pack-off. I 10. N/U the BOPE stack and test.T~ S (O~' 4 û'~ tVf P h?V ~ , 11. M/U a ~aker 9 5/8" whip stock assembly. RIH to the EZSV bridge plug. Orient as desired and set the whip stock on the EZSV. 12. Shear free from the whip stock. Displace the well to 10.4ppg LSND milling fluid. 13. Mill a window in the 9 5/8" casing at -9,650'md. Drilllmill approximately 20 feet beyond the middle of the window. 14. Circulate the well clean. Pull into the 9 5/8" casing and attempt an FIT to 12.5ppg EMW. POOH. 15. M/U an 8 }'2" Dir/GR/Res/PWD assembly. RIH to the window. 16. Drill out and drill ahead, according to the directional program to section TO at the base of the HRZ I LCU. Circulate and condition the hole. POOH. 17. Run and cement the 7" liner. POOH with liner running tool. 18. R/U and run -6,500' of 7", 26.0#, L-80 scab liner. Tie into .the drilling liner tie back sleeve. Cement the scab liner per Dowell program. POOH and UD liner running tool. 19. M/U a 6 1/8" Dir/GR/Res/ABI drilling assembly. RIH to the scab liner float equipment. 20. Test the casing X liner to 4,000psi. Record the test. 21. Drill out the scab liner float equipment. Continue RIH to the drilling liner float equipment. 22. R/U and test the casing X liner to 4,000psi for 30 minutes. Record the test. 23. Drill out the drilling liner float equipment to the liner shoe. Displace the well to 8.5ppg Flo-Pro drilling fluid. 24. Drill out the shoe plus -20 feet of new formation. Conduct an FIT to 10.0ppg EMW. 25. Drill ahead, per directional proposal, to the end of the high dogleg section at -11 ,500'md. POOH for horizontal BHA. 26. R/U SWS E-line. Run a USIT log from the 7" liner shoe to the top of the drilling liner at -9,500'md. POOH and RID E-line. 27. M/U a 6 1/8" Dir/GR/Res drilling assembly. RIH and drill ahead, per directional program, to section TO at -13,037'md. 28. Condition the hole for running 4 1/2", 12.6#, L-80, IBT-M liner. POOH. 29. Run and cement the 4 }'2" production liner, extending the liner lap to -1 0,433'md. POOH. 30. R/U and pressure test the casing X liner to 4,000psi. Record the test. 31. R/U and run a 4 1/2", 12.6#, L-80, TC-II completion, stinging into the 4 1/2" liner tie back sleeve. 32. Space out and land the completion. RILDS. 33. Install a TWC. 34. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 35. Reverse circulate the well to seawater with Corrosion Inhibitor. 36. R/U LRHOS. Reverse in sufficient volume of diesel to freeze-protect the well to -2,200'md. Allow the diesel freeze protection fluid to U-tube to equilibrium. 37. Drop the ball and rod. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 38. Install BPV. Secure the well. 39. Rig down and move off. Post-RiQ Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 01/31/05 Estimated Spud Date: 03/01/05 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 03-33A Application for Sundry O~t33A SAFEr ,'.ÀTES: ASH IN HOLE - HORIZONTAL WB.L . 70° @ 10709' AND 90° @ 10800' TREE = McEVOY GEN 3 WELLHEAD = ~EVOY ACTUA TO,R = AXELSON KB. ELEV = 62' BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 3000' 100 @ 10969' 10536' 8800' SS 133/8",72#, L-80, - Casing 2506' Minimum ID = 2.00" @ 13100' XO FL4S PIN X STL BOX 12 bbllA cement squeeze (9/27/00). Estimated TOC. 9,950 \ / -'f'¥ 1 0023' ¥~'~¡\0 '.'~ I---lë"t I!';,;~'; 5 1/2"MERLA Tbg patch, 21.5', set acrosss GLM #9 151/2" BOTPBRassy I.., 10093' 51/2",17#, L-80, PC- - 10123' Tubing r}.""':1 ~>~. /:¿~~ f:':: .:: 95/8" X51/2" BOT - 10113' - ~ 3-H Packer 15 1/2" X 4 1/2" XO 1-1 10123' I.., 10138' I.., 10165' I I I-I TOp of 2 7/8" Liner I Top of 7" Liner 41/2", 12.6#, L-80, PC- Tbg 10219' I Tag cement I.., 10264' 1- 95/8",47#, L-80, Cas ing 10374' Sidetrack Window 10402' 7", 29#, L-80, liner, - ID = 6.184" 10936' DATE REV BY COMMENTS 03/86 ORIGINAL COMPLETION 04/30/97 SIDETRACK 12/13/00 SIS-JLH CONVERTED TO CANVAS 03/27/01 TP CONVERTED TO CANVAS 02/03/02 RNlTP CORRECTIONS 03/29/04 MJA/KK ADÆRFS . . I : I ..~:*: ~.:-...":. ~~ ~?f \ I I I ) ~ I DA TE REV BY 51/2" AVA TRSV SSSV Nip., I.D. 4.562" 2187' ST MD TVD 1 3002 3000 2 4342 4221 3 6085 5502 4 7425 6444 5 7537 6522 6 8794 7426 7 8906 7508 8 9917 8267 9 10028 8369 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 40 MMIG RK 43 MMIG RK 43 MMIG RK 42 MMIG RK 42 MMIG RK 40 MMIG RK 40 MMIG RK 23 MMIG RK 20 MMIG RKP PORT DATE PBR sheared 03/17/86 PERFORA TION SUMMARY REF LOG: BHCS ON 8/9/1984 ANGLE AT TOP PERF: 25 @ 10520' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 1 0520 - 10540 0 03/29/04 2" 4 10550 - 10570 0 03/29/04 2" 4 11220 -11290 0 02/05/00 2" 4 11770 -11840 C 02/18/99 2-1/8" 4 12375 -12440 C 03/26/98 2-1/8" 4 12970 - 13020 C 05/04/97 2-1/8" 4 13075-13114 C 05/04/97 I' " :8 I 10134' 1-1 I 10138' 1-1 I 10206' 1-1 I 10218' 1-1 I 10219' 1-1 A 4-1/2" G SEITING SL V 1 3-1/2" X 2-7/8" XO 1 4-1/2" OTIS XN NIP (BB-IIND LNR), ID = 3.72" 1 4-1/2" BOT SHEAROur SUB (BEHIND LNR) 1 4-1/2" TBG TAIL (BB-IIND LNR) 1 I 11350' 1-1 CIBP 1 I 11950' 1-1 I 1-1 CIBP 1 , PBTD 1-1 13115' 1 COMMENTS PRUDHOE BA Y UNIT W8...L: 03-33A PERMIT No: 197-0390 API No: 50-029-21142-01 SEe 11, T10N, R15E, 2658' Fa. & 1515.13' FNL BP Exploration (Alaska) " . TREE = McEVOY G8'J3 WELLHEAD = ~BlOY ACTUA TO~ = . AXELSOÑ KB. ELBI = 62' BF. ELBI = KOP= rv1ax Angle = Datum MD = Datum lÝD = 3000' 100 @ 10969' 10536' 8800' SS 133/8",72#, L-80, - Casing 2506' Minimum ID = 2.00" @ 13100' XO FL4S PIN X STL BOX 03-:;'SA Pre Rig SAFEr ,')TES: FISH IN HOLE. HORIZONTAL WELL. 700 @ 10709' AND 900 @ 10800' . 51/2" AVA TRSV SSSV Nip., 1.0.4.562" Pre rig: Lock flapper valve open to allow chern cutter 2187' l ST MD TVD 1 3002 3000 2 4342 4221 3 6085 5502 4 7425 6444 5 7537 6522 6 8794 7426 7 8906 7508 8 9917 8267 9 10028 8369 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 40 MMIG RK 43 MMIG RK 43 MMIG RK 42 MMIG RK 42 MMIG RK 40 MMIG RK 40 MMIG RK 23 MMIG RK 20 MMIG RKP PORT DA TE I . PERFORA TION SUMMARY REF LOG: BHCS ON 8/9/1984 ANGLE AT TOP PERF: 25 @ 10520' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 10520 - 10540 0 03/29/04 2" 4 10550 - 10570 0 03/29/04 2" 4 11220 -11290 0 02/05/00 2" 4 11770-11840 C 02/18/99 /' 2-1/8" 4 12375 -12440 C 03/26/98 2-1/8" 4 12970 - 13020 C 05/04/97 1 10125' l-t P&A cement 1 2-1/8" 4 13075 -13114 C 05/04/97 12 bbllA cement squeeze (9/27/00). Estimated TOC. 9,950 // \ == ??-. == I -9,700 14 5 1/2" Tbg cut I 151/2" X 41/2" XO l-t 10123' I 1 10134' 1-1 4-1/2" G SÐTING SL V 1 A 1 10138' l-i 3-1/2" X 2-7/8" XO I Top of 2 7/8" Liner 14 10138' I I l-i 4-1/2" OTIS XN NIP (BEHIND LNR), 10 = 3.72" 1 10206' I Top of 7" Liner l-f 10165' I-I 11 I 1-1 1 10218' 4-1/2" BOT SHEAROUT SUB (BEHIND LNR) 41/2", 12.6#, L-80, -! PC- Tbg 10219' 1 10219' l-i 4-1/2" TBG TAIL (BEHIND LNR) 1 5 1/2"MERLA Tbg patch, 21.5', set acrosss GLM #9 10023' 151/2" BOTPBRassy l-i 10093' 1- 51/2",17#, L-80, PC- - 10123' Tubing 95/8" X 51/2" BOT - 10113' 3-H Packer (Tag cement (4/18/97) 14 10264' 1- 95/8",47#, L-80, Casing 10374' Sidetrack Window 10402' 7",29#, L-80, liner, - 10936' 10=6.184" t£;~~f,~i$)~ ¡~~~:! .,' ;.'.~)~:~~ I 11350' l-i CIBP I I 11950' 1-1 CIBP I I 12540' 1-1 CIBP I PBTD l-i 13115' 1 13150' 1 DATE REVBY COMMENTS DATE REVBY COMMENTS 03/86 ORIGINAL COMPLETION 01/13/05 dew A"oposed pre rig work 04/30/97 SIDETRAO< 12/13/00 SIS-JLH CONVERTED TO CANVAS 03/27/01 TP CONVERTED TO CANVAS 02/03/02 RNITP CORRECTlONS 03/29/04 MJA/KK ADÆRFS PRUDHOE BAY UNIT WELL: 03-33A PERMIT No: 197-0390 API No: 50-029-21142-01 SEe 11, T10N, R15E, 2658' FEL & 1515.13' FNL BP Exploration (Alaska) , . ~~-33Bi Pr()~osed Comple..ìon . . -2200 l-i 41/2" 'X'landing nipple TREE = McEVOY GEN 3 WELLHEAD = McEVOY ACTUA TOR = AXELSON KB. ELEV = 56.40' GL. ELEV = 27.89' KOP = 3000' Max Angle = 100 @ 10969' Datum MD = 1 0536' Datum NO = 8800' SS 133/8",72#, L-80, - Casing 2506' 3,000 95/8" X 7" Baker Flex-Lock liner hanger, ZXP liner top packer w / TBS 7", 26.0#, L-80, Scab - Liner 9500' 9,500 95/8" X 7" Baker HMC liner hanger, ZXP liner top packer w / TBS q~ 10' 10,360 l-i 41/2" 'X'landing nipple 10,380 l-i 7" X 41/2" 'Baker S-3 Pkr 1 10,400 1-1 4 1/2" 'X' landing nipple I 10,420 1-1 41/2" 'XN' landing nipple 1 7" X 5" Baker HMC liner hanger, ZXP liner top packer w / TBS 10,433 Sidetrack Window 9,650 95/8" X 51/2" BOT - 10113' 3-H Packer I 10,583 1-1 7", 26.0#, L-80 BTC-M liner TOp of 7" Liner H 10165' I- . Tag cement (4/18/97) 1-1 10264' 1- 9 5/8", 47#, L-80, Casing 10374' 13,037 I.., 41/2",12.6#, L-80 IBT-M liner 1 Sidetrack Window 10402' 7",29#, L-80, liner, - 10=6.184" 10936' I 2-7/8" LNR, 6.5#, L-80, 0.0058 bpf, 10 = 2.441" 1-1 DATE 03/86 04/30/97 12/13/00 03/27/01 02/03/02 03/29/04 SIS-JLH TP RN/TP MJA/KK COMMENTS ORIGINAL COMPLETION SIDETRACK CONVERTS) TO CANVAS CONVERTS) TO CANVAS CORRECTIONS ADPERFS DATE REV BY COMMENTS 01/24/05 dew Proposed Col1l>letion PRUDHOE BA Y UNIT WELL: 03-33Bi ÆRMIT No: API No: 50-029-21142-02 SEC 11, T10N, R15E, 2658' FEL & 1515.13' FNL REV BY BP Exploration (Alaska) ) -) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~"'1't /II IZ/ott- DATE: Monday, November 08, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03-33A PRUDHOE BAY UNIT 03-33A /1'7-031 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -.JBL- Comm Well Name: PRUDHOE BAY UNIT 03-33A Insp Num: mitJCr041104123109 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21142-01-00 Permit Number: 197-039-0 Inspector Name: John Crisp Inspection Date: 11/2/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03-33A Type Inj. P TVD 8450 IA 100 4000 3920 3870 P.T. 1970390 TypeTest SPT Test psi 2112.5 OA 180 580 640 640 Interval OTHER P/F P Tubing 980 980 980 980 Notes: MIT to swap weU.tTom water injection to gas injection, SCANNE~) NO\J 21 4: 2004 Monday, November 08, 2004 Page 1 of 1 " " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter CasingD Change Approved Program D 2. Operator SuspendD RepairWeliD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool 0 4. Current Well Class: Perforate 00 WaiverO Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-0390 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 62.00 8. Property Designation: ADL-o028327 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: 03-33A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceŒ 6. API Number 50-029-21142-01-00 Total Depth measured 13150 feet true vertical 8902.3 feet Effective Depth measured 11350 feet true vertical 8932.6 feet Casing Conductor Liner Liner Production Surface Length 77 3016 237 10343 2474 Perforation death: Plugs (measured) Junk (measured) 11350,11950,12540 13145,13140,13135,13130,11290 Size 20" 91.5# H-40 2-7/8" 6.5# Lo80 7" 29# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD 33 110 33.0 - 110.0 10134 - 13150 8469.8 - 8902.3 10165 - 10402 8499.9 - 8733.7 31 - 10374 31.0 - 8705.9 32 - 2506 32.0 - 2505.9 Collapse 470 11160 7020 4760 2670 Burst 1490 10570 8160 6870 4930 Measured depth: 10520 -10540,10550 -10570,11219 -11290 True vertical depth: 8848.18 - 8865.89,8874.43 - 8890.88, 8942.07 - 8938.2 5-1/2" 17# L-80 @ 29 4-1/2" 12.6# L-80 @ 10123 5-1/2" Baker 3-H BOT Packer @ 10113 5-1/2" TRSV SSSV @ 2187 RECEIVED APR 2 1 2004 Alaskc1-oi1 & Gas Cons. COmlnlSSIOn Anchorage Tubing ( size, grade, and measured depth): 10123 10219 Packers & sssv (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Reoresentative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0 13133 20 13 Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl 0 Tubing Pressure 1192 1566 0 0 12311 0 15. Well Class after proposed work: ExploratoryD Development 0 ServiceŒl 16. Well Status after proposed work: Operational Shutdown 0 OilD GasD WAG D GINJD WINJŒ WDSPLD Daily Report of Well Operations X Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-017 Printed Name G] Catron Title Production Technical Assistant 8;900'"'0 .. ~ Af'R 2 2 aD R ! (J íÑ ÅL657 Og'o Form 10-404 Revised 12/2003 Copies of Logs and Surveys run - 4/15/04 "- 03-33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/19/04 ***WELL INJECTING ON ARR.*** (ADD PERF) TAG BOTTOM @ 10,702' (SLM), PAST TARGET DEPTH OF 10,570' WI 2.125 DUMMY GUN, SB HAS SAMPLE OF SCHMOO. *** WELL PUT BACK ON INJECTION AND TURNED OVER TO DSO *** 03/29/04 Perforate 10520'-10540' 4 SPF, 10550'-10570' 4 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 I TOTAL Page 1 " .. ... TREE = McEVOY GEN 3 Wa.LHEAD = McEVOY A CTIJI\ TOR = AXELSON KB. ELEV = 62' BF. ELEV = KOP = 3000' Max Angle = 100 @ 10969' DatumMD= 10536' DatumTVD = 8800' SS 13-3/8" COO, 72#, L-BO, ID = 12.34 T' H 2506' J IMinimum ID =2.00" @ 13100'1 XO FL4S PIN X STL BOX 15-1/2"TBG-PC, 17#, L-BO, 0.0232 bpf,lD =4.892" H 10123' ITOPOF4-1/2"TBG-PC H 10123' TOPOF2-7/8"Lr-R H 10138' 1 TOP OF 7" Lr-R H 10165' 14-1/2" TBG-PC, 12.6#, L-BO, 0.0152 bpf,lD = 3.958" H 10219' 19-5/8" CSG,47#, L-80, ID= 8.681" H 10374' PERFORA llON SLMM!\ RY REF LOG: BHCS ON 8/9/1984 Af'.X3LE AT TOP PERF: 91° @ 11220' IIbte: Refer to A"oduetbn œ for historieal perf data SIZE SPF IN1ERVAL Opn/Sqz DATE 2" 4 11220-11290 0 02/05/00 2" 4 11770-11840 C 02/18/99 2-1/8" 4 12375 -12440 C 03/26/98 2-1/8" 4 12970 -13020 C 05/04/97 2-1/8" 4 13075 -13114 C 05/04/97 T'LNR,29#,L-80,O.0371bpf,ID=6.184"/-i 10406' J II SAFETY NOTES: ASH IN HOLE. HORIZONTAL WELL 070" @ 10709' AtÐ 90° @ 10800' 218T H 5-112" AVA TRSV SSSV NIP, ID= 4.562" 1 GAS UFT MANDRELS ST MD TVD DEV 1YÆ VLV LATCH FORT DATE 1 3002 3000 40 Mv1IG RK 2 4342 4221 43 Mv1IG RK 3 6085 5502 43 Mv1IG RK 4 7425 6444 42 Mv11G RK 5 7537 6522 42 Mv11G RK 6 8794 7426 40 Mv11G RK 7 8906 7508 40 Mv1IG RK 8 9917 8267 23 Mv1IG RK 9 10028 8369 20 Mv1IG RKP 1 10023' H 5-1/2" MERLA TBG PATCH I I (21.5' SET 06/29/93 ACROSS GLM #9) I 10093' H 5-1/2" BOT FBRASSY ~ 10113' H 9-5I8"X 5-1/2" BOT3-HPKR 1 1 10123' H 5-112" X 4-112" XO I 1 10134' H 4-1/2"GSETTINGSLV 1 1 10138' H 3-1/2"X2-718"XO J. 1 10206' H 4-1/2"OllSXNfIIP(BEHNDLNR),ID=3.72" I 1 10218' H 4-1/2" BOT SHEAROUT SUB (BEHND LNR) I \ II. .. ~ 10219' H 4-1/2"TBG TAIL (BB-UI'Ð LNR) I ~ 10194' H ELMDTTLOGGED 04/06/86 10402.10406 H SIDETRAO<EDWINIJOW I 11290',11727',11729'H BAKERaBPFISH 1 11350' ~ 11950' ~ I 12540' ~ 13130' HCA-RKED I I 13135' H 13-3I8"ALUMPLUG 1 13140' /-i 1"X1I2"AECEOF I I PULLIf'.X3 TOOL SKIN 13145 H 24'CTUFISHIf'.X3TOOLS, I ' I BKR BRIDGE RUG 03-33A . ~ L - IJ 8: \ 1 1 1 r.1 1 . I f-- I 11 ~ 13115' 1 2-7/8" Lt'R, 6.5#, L-80, 0.0058 bpf, ID = 2.441" H 13150' I D<\ 1E REV BY COMv1ENTS DATE REV BY COMWENTS 03/86 ORIGINAL COMPLETON 04130/97 SIŒTRAO< 12113¡Q0 SIS-JLH CONV ER1ED TO CA NIl AS 03l27¡Q1 TP CONV ER1ED TO CA NIl AS 02l03¡Q2 RNIìP CORRtCllONS PRUDI-OE BAY lJIIfT WELL: 03-33A PERMT lib: 197-0390 AA No: 50-029-21142-01 SEC 11, T10N, R15E, 2658 Fa. 1515.13 HI... BP Exploration (Alaska) Re: Pending 403s] (( I , I( Subject: Re: Pending 403s] From:. sarah palin <spalin@mtaonline.net> Date: Fri, 23 Ian 2004 11 :40:08 -0900 To: Dan Seamount <dan_seamount@admin.state.ak.us> looks great - here's my approval. Sarah Palin ----- Original Message ----- From: "Dan Seamount" <dan seamount@admin.state.ak.us> To: "Sarah H Palin" <spalin@mtaonline.net> Sent: Friday, January 23, 2004 10:36 AM Subject: [Fwd: Pending 403s] Here are the 403's. the 401's will come later. thanks, dan -------- Original Message -------- Subject: Pending 403s Date: Fri, 23 Jan 2004 10:04:31 -0900 ~ From: Winton Aubert <winton aubert@admin.state.ak.us> Organization: State of Alaska To: Daniel Seamount <dan seamount@admin.state.ak.us> Dan, Pending 403s are Forest Oil well RU #7 - operations shutdown (received 1/15/04), BP well 03-33A - add perforations to existing injection zone (1/21/04), Marathon well KBU 42-07 - add perforations to existing producing zone (1/22/04). WGA 1 of 1 1/23/2004 ] : 1] PTv ii-JGA- , 12.2-1 ¿ao"¡" ~ ( STATE OF ALASKA /° ALASKA OIL AND GAS CONSERVATION COJ...,dSION APPLICATION FOR SUNDRY APPROVAL > 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown D PerforateŒ] / WaiverD Annular DisposalD Alter CasinQ D Repair Well D PluQ Perforations D StimulateD Time ExtensionD OtherD Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Nur:nber: Name' BP Exploration (Alaska), Inc. 197-0390/' . Development D Exploratory D 3. Address: P.O. Box 196612 6. API Number / Anchorage, Ak 99519-6612 StratigraphicD Service 00 50-029-21142-01-00 7. KB Elevation (ft): 9. Well Name and Number: 62.00 KB 03-33A /' 8. Property Designation: 10. Field/Pool(s): ADL-0028327 Prudhoe Ba Field / Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 13150 8902.3 13150 8840.3 See Attachment See Attachment aSlng engt Ize urst 0 apse to bottom to bottom Conductor 77 20" 91.5# H-40 33 - 110 33.0 - 110.0 1490 470 Liner 3016 2-7/8" 6.5# L-80 10134 - 13150 8469.8 - 8902.3 10570 11160 Liner 237 7" 29# L-80 10165 - 10402 8499.9 - 8733.7 8160 7020 Production 10343 9-5/8" 47# L-80 31 - 10374 31.0 - 8705.9 6870 4760 Surface 2474 13-3/8" 72# L-80 32 - 2506 32.0 - 2505.9 4930 2670 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11219 - 11290 8942 - 8938.2 4.5 " 12.6 # L-80 10123 - 10219 5.5 " 17 # L-80 29 - 10123 Packers and SSSV Type: Packers and SSSV MD (ft): 5-1/2" Baker 3-H BOT Packer 10113 5-1/2" TRSV SSSV 2187 12. Attachments: Description Summary of Proposal ŒJ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 DevelopmentD ServiceŒ] 14. Estimated Date for F b 4 2004 15. Well Status after proposed work: Commencin 0 eration: e ruary , Oil D GasO PluggedO AbandonedO 16. Verbal Approval: Date: WAG D GINJD WINJI!] WDSPLD Commission Representative: Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian Carlson Printed Name ~rian carl~ Title Petroleum Engineer Signature ~ 1ð- Phone 564-5046 1/20/04 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestO Mechanciallntegrity Test D Location Clearance D ,JAN 2 1 2004 Other: Alaska Oil & Gas Cons. Commission 'I- Anchorage BY ORDER OF Approved by: THE COMMISSION Date: ~C;A~~IE[} Jð1N 2 .~ 200~~ BFL JAM 2 6 200\ ()RIGl~JAL- Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE '-",- (" ( Attachment Plugs (md): Junk (md): 11350 11290 11950 13130 12540 13135 13140 13145 Page 1 ¿' .' . ( ..' bp ( ..\tf4t-l. PERFORATING PROCEDURE ...~~ ~~.. .':~ ~:. ' .,~t~"\~ ". Well: 03-33Ai API #: 50-029-21142-01 Date:jh~ö.~:: Prod Engr~~~~£~~~~ ~:~: :~:::::::::~~;.;~:::::::::: f.It2.!;NïÄ!~!:Mj;' Cost: .....................~~~!~~~..,.................... Cell/Pager: ,...........................~.~.~~~~!.......,..................... CC or AFE: PBD03WL33-C """"""""""""""""""""""""""'""""" lOR: 300 """""""""""""""""""""""""'",',',',''' WBL Entries ............I.9.~.........,.........,....I.y'!?~.............,~,~E~..~~~,~!.P..~!9.~................................................,...~.~.i.~E!~y.!.9.~~~.~.~~~.....""""""""'"'''''''''''''''''''''''' 1 ¡ 300 ¡ 0 ¡SBG ~ ¡ 2 L:::::::~gþ'::::::::::¡::::::::::::::::::~:::::::::::::::::¡:þ. r.¡fj:p':~~~~~p'~:~::::::::::::::::::::::::::::::::::::::::::::::::::::1:::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::] 3L.,.......?9.9...........L...,............5...............J:~~P'~,Œ.19.:;...~.9.??Q~.~9.?~Q!...~.9.??Q.~.~.9.??L......,.........................................,.............................,......,.¡ Well Obiectives and PerforatinQ Notes: Min ID = 2.441" @ 10138'MD, 2-7/8" Liner Top; Angle at perforations = 38 deg Max Angle to adperfs = 46 deg @ 7400'MD; Angle at perforations = 38 deg Desire to increase Victor injection in the area. Currently, the well only takes -3MBWD. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Add .......................Q....................... feet Log: .~YY..I?~§.B...... ....¥..WP~9.B.... to the tie-in log to be on Date: 4/20/1997 4/20/1997 depth with the reference log. Company: }~ì?~r.&::::::::::::: :::::::§.p.~Úÿ"::::::: Depths (from-to) Depths (from-to) Feet SPF Orient. I Phasing Zone Ad/Re/lperf ......J.Q!,??.9~...... - .....J9.!,?4.9~.... ..J.9ß?.Q~..... - ..,...1.9.!9..49.1...... .....?.9.... .........4......... .......B~n.g.9.~...... ...............,..ßQ~......,............. ......~...,................Ag.p.~.!:L........,... ......J.Q!.?9..Q~...... ....J.9.ß?.Q~..., ..J.9..!.??.9:..... - .....J.9.i?.?9..I...... .....?.Q.... .........4......... .......R~.Qg.9.!:D....... ....................§.Q~.................... ......~....................AgJ?~.rf............... ................,....,........... ............................. ............,................. """"""''''''''''''''''''1 ",,,,,,,,,,,,,,, .................... ..................................... "'"'''''''''''''''''''''''''''''''''''''''''''' ................,............................................. - - '................................ ............................. .............................. .............................., ................ .................... ...................,................ ................................................. ........................................................,..... ................................. """""""""""""'" .............................. ............................... """""""'" .................... """""""""""""""""" """"""""""'.......,.................... """"""""""""'"''''''''''''''''''''''''''''''....- ""'"'''''''''''''''''''''''''' '"'''''''''''''''''''''''''' "'''''''''''''''''''''''''''' ............................... "...........60.. """""""""" '''''''''''''''''''''''''''''''''''' .............................,................... """"""'''''''''''''''''''''''''''''''''''''''''''''''''' - - .......................... ,.,.... ,... ....................,.... ................... ........... .........,................. ..,. ........,....... ..................., """""""""""""""""" ..,.............................................. ......................................~.............. ......... Requested Gun Size: "............?'::.......".... Charge: ..?9.9§,..~.9.~.~r~~.t!..!::tM.X".....".........",,,,, Is Drawdown Necessary/Desired/Unnecessary During Perforating .Y.DD.~.~~~.~~.IY.................................,.................................................,"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''' Preferred Amount of Drawdown/Suggestions to Achieve Drawdown .~.ð....................................................................................................................................................................... Last Inj: ............~~........".. BOPD .........~!g9.9.......... BWPD ...............~.~..............GOR Last Tag: .......~,1.!g~Q......, ft MD on ....~9!1(?999.... Est Res. Pres. @ ...........~.Q!.~g9...".".., MD is ......".......""....,............~~?Q. psi Perforation Summary Summary Dist Well: 03-33Ai Town: ...................""""'........""'....-.............."" Date: API #: 50-029-21142-01 Prod Engr: Anch Prod Engr """"""".............,.. ............"......"..................'................ .............."............"........................."....,...... P.D. Center PBTD '"'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' General Comments: ....................,...................",.........."..........."",..".........................,.........................................,.....................................,...........,...........................,............."......,......... ....,...,.,.......""",.,.".............."" """"""""""""""""""""""""" ....,...............,...,.....,,,...............................................,,,,,.,,...."""""""'"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''."........,.,..."......,.....,,,............., Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0 / B / U """""'''''''''''''''''''' ~....................,......... """"""'"'''''''''''''''' """"""'''' ,................... """""""""""""""""" ............".......,........................... ....................................,.,...........,........... 0 / B / U ,............................. ~......................,..,.... ""'"'''''''''''''''''''''''' '''''''''''''''' .......,...........' ""'.....................,...".... """""""'"'''''''''''''''''''''''''''''''' ...........................,.........."...................... 0 / B / U ....................,.,...,... -.....,........................ ............".........."..". ................ .................... ..,................................, '"'''''''''''''''''''''''''''''''''''''''''''''' ......................".............."......".............. 0 / B / U .............................. ~............................., ............."..............., ................ ...,...,...........' .................................". """""""""..........,....,............... .........,..,..,...........................................,,, 0 / B / U ,..........."................ ~..................".......... .....,......................... """'''''''''' '''''''''''''''''''' '''''''''''''''''''''''''''''''''''. "'"'''''''''''''''''''''''''''''''''''''''''''' "'''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' 0 / B / U """"'''''''''''''''''''''' ~........................,..... ......................,......,. ................ .."........",,,... .....................,,,..........., """''''''''''''''''''''''"""""""""", ""'''''''''''''''''.................,.............,......... 0 / B / U """'.................".... ~...........................,.. ................,....,......... ................ .................... ..........,......................... ..........................,...................... .....................,............."............,............ 0 / B / U "'''''''''''''''''''''''''''' -.............................. "'"'''''''''''''''''''''''''' ...,........".. ...................' '"'''''''''''''''''''''''''''''''''' """"'"'''''''''''''''''''''''''''''''''''''' '''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''' 0 / B / U '''''''''''''''''''''''''''''' ~.............................. ........,....................., "'''''''''''''' ,.."......"....... .........................,.......... """"""'''''''''......,..................... """"'''''''''''''''''''''''''''''''''''''''''''''''''''''' .~ (' TREE= M::EVOY GEN 3 SAFETY NOTES: RSHINHOLE- WB.LHEAD ~ M::EVOY 0 3 3 3A HORIZONTAL WELL -70° @ 10709' AN) ACfU<\ TOR - , AXELSON - 90° @ 10800' KB. ELEV = 62' BF. ELEV = 5-1(2" AVA TRSV SSSV NIP ID= 4.562" KOP = 3000' (8 , Max Ange = 100 @ 10969' GAS LIFT MANDRELS DatumMD= 10536' ST MD TVD DEV lYPE VLV LATCH FORT DATE Datum TVD = 8800' SS 1 3002 3000 40 tv'MIG RK 2 4342 4221 43 tv'MIG RK 1 H 3 6085 5502 43 tv'MIG RK 13-3/8"CSG.72#.L-80,ID=12.347' 2506" 4 7425 6444 42 tv'MIG RK 5 7537 6522 42 tv'MIG RK 6 8794 7426 40 tv'MIG RK Minimum ID = 2.00" @ 13100' 7 8906 7508 40 tv'MIG RK 8 9917 8267 23 tv'MIG RK XO FL4S PIN X STL BOX 9 10028 8369 20 tv'MIG RKP 5-1/2" MERLA TBG PATCH (21.5' SET 06/29/93 ACROSS GLM #9) 5-1/2" BOT FBRASSY 9-518" X 5-112" BOT3-H PKR 5-1/2" TBG-PC, 17#, L-80. 0.0232 bpf, ID = 4.892" TOPOF 4-1/2" TBG-PC TOP OF 7" LNR 4-1/2" 011S XN NIP (BEHND LNR), ID = 3.72" I 14-1/2" TBG-PC, 12.6#, L-80. 0.0152 bpf, ID = 3.958" I 4-1/2" BOT SHEAROUT SUB (BEHND LNR) 9-5/8" CSG, 47#, L-80, ID = 8.681" 4-1/2" TBG TAIL (BB-iIND LNR) ELMD TT LOGGED 04/06/86 I SIDElRAO<ED WINDOW PERFORA 110N SlJv1MA.RY BAKER aBP FISH REF LOG: BHCS ON 8/9/1984 ANGLEAT TOP PERF: 91° @ 11220' I\bte: Refer to A'oductbn œ for historical perf data SIZE SPF INlERV AL Opn/Saz DATE 2" 4 11220 -11290 0 02/05/00 2" 4 11770-11840 C 02/18/99 2-1/8" 4 12375 -12440 C 03/26/98 2-1/8" 4 12970 - 13020 C 05/04/97 2-1/8" 4 13075-13114 C 05/04/97 1" X 1(2" AECE OF PULLING TOOL SKIN I 7' LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 10406" 24' CTU FSHING TOOLS, BKR BRIDGE R.lX3 2-7/8" LNR, 6.5#. L-80. 0.0058 bpf, ID = 2.441" 13150" DA lE RBI BY COtv'MENTS DATE REV BY COM~NTS PRUDI-DE BAY LNIT 03/86 ORIGINAL COMPLETON WELL: 03-33A 04130/97 SIDETRAO< PERMT I\b: 197-0390 12/13/00 SI8-JLH CONVERlEDTOCANVAS AA No: 50-029-21142-01 03127/01 TP CONVERlEDTO CANV AS SEC 11, T10N, R15E, 2658 FB. 1515.13 FI\l. 02/03/02 RN/lP CORRECll0NS BP Exploration (Alaska) ( (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU / Drill Site 03 12/21/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 03-33A Type Inj. F TVD 8,449' Tubing 1,520 1,520 1,520 1,520 Interval 4 P.T.D. 1970390 Type test P Test psi 2,112 Casing 0 2,500 2,450 2,420 P/F P Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) <J;:' ,I'" l~ t~1 ~ ~ ~ 11"'" ITì (' If\\ Gj) 11 ? n at) '~~ð\ì~\:Jð~&:.tl.J, IL9¡l,~~ ci) ~t t..U ;j MIT Report Form Revised: 06/19/02 2003-1221_MIT _PBU - 03-33A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate _X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_ RKB 62 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service~x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5060' FNL, 4459' FEL, Sec. 11, T10N, R15E, UM 03-33Ai At top of productive interval 9. Permit number / approval number 2402' FSL, 639' FEL, Sec. 11, T10N, R15E, UM 97-39 At effective depth 10. APl number 50-029-21142-01 At total depth 11. Field / Pool 1515' FNL, 2658' FEL, Sec. 11, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 13150 feet Plugs (measured) IBP set 4/24/2000 @ 10125' MD. true vertical 8902 feet CIBP set @ 11350' MD (2/05/2000). CIBP set @ 12540' MD (3/15/1998) Effective depth: measured 10125 feet CIBP set @ 11950' MD (2/17/1999) true vertical 8461 feet Junk (measured) Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 1910# Poleset 110' 110' Surface 2444' 13-3/8" 2300 Sx cs ~ &4co sx cs ~ 2506' 2506' Production 10312' 9-5/8" 500 sx C~ass G & 300 Sx CS ~ 1 0374' 8705' Liner 241' 7" 300 Sx Class G 10406' 8733' Liner 3012' 2-7/8" 24 bbls Class G~ i "'-~ ~;~ I ?~ i "' ~/-~ "[' 118150'I 8902' Perforation depth: measured 11220' - 11290'; (isolated below ClBP's 11770' - 11840'; 12375'- 12440'; 12970' - 13020'; 13075' - 13114'.) true vertical 8942' - 8938'; (isolated below CIBP's: 8930' - 8930'; 8919' - 8916'; 8898' - 8896'; 8897' - 8898'.) . Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 10123' MD; 4-1/2", 12.6#, L-80 PCT @ 10219' MD. i~%1~ '"~' Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BOT 3-H PACKER @ 10114' MD. "., ,~ ,.'.¥ 05 5-1/2" AVA TRSV SSSV @ 2188' MD. 13. Stimulation or cement squeeze summary /!".,i~,:i~i~:;. ~"':" · Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation (Shut in) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Ge;s ~ Suspended __ Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. "'~¢'~ ,,¢~'_ /'),n,, ~,'~" Title Arco Well Group Supervisor Date Signed Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03-33Ai DESCRIPTION OF WORK COMPLETED CT MUD ACID STIMULATION Date Event Summary 3/02/2000: 4/10~2000: 4/11/2000: 4/1 2/2000: 4/24/2000: 4/27/2000: 5/1/2000: Established injectivity of 0.8 bpm @ 2200 psi. Rate too Iow for MI injection. Attempted to perform a Mud Acid Stimulation Treatment to increase injectivity on this injector as follows: MIRU CTU. PT'd to 4000 psi. Loaded wellbore w/2% NH4CL down the BS - locked up @ 24 bbls. RIH w/stinger & nozzle & tagged obstruction @ 10900' MD. Pushed it to 10974'. Pressured up to 3000 psi - no movement. POOH. FP'd well. PT'd equip ot 4000 psi. Performed a CT Mud Acid Stimulation Treatment as follows: RIH w/ nozzle & tagged CIBP @ 11345' MD. Reciprocated treatment fluids across the open perforations listed below: 11220'- 11290' MD (Zone 2C/2B) Reference Log: MWD-GR 4/20/1997. Pumped: (a) 242 bbls of 2% NH4CL @ 2 bpm, followed by (b) 50 bbls of 50% Diesel, 50% Xylene @0.7 - 0.5 bpm, followed by (c) 100 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 1.5 bpm, followed by (d) 50 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 1.6 bpm, followed by (e) 50 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 2 bpm, followed by (f) 166 bbls of 2% NH4CL @ 1.6 bpm, followed by (g) 35 bbls of 60/40 Methanol Water @ 1.2 bpm, followed by (h) shutdown. Immediate breakback in WHP when acid hit perfs. POOH w/CT. RD. MITIAto 3000 psi - press fell to 2300 psi - failed. Leak rate less than 0.1 bpm. RIH &set IBP @ 10125' MD. Loaded tbg & IA w/Diesel, prep for CMIT. Comfirmed tubing leak. Well currently shut in while diagnosing annular communication problem. 0,5 200 ;' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (IA Cement SQZ) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 62 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5060' FNL, 4459' FEL, Sec. 11, T10N, R15E, UM 03-33Ai At top of productive interval 9. Permit number / approval number 2402' FSL, 639' FEL, Sec. 11, T10N, R15E, UM 197-039/(300-233 signed 9/14/2000) At effective depth 10. APl number 50-029-21142-01 At total depth 11. Field / Pool 1515' FNL, 2658' FEL, Sec. 11, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 13150 feet Plugs (measured) C/BP set @ 11350' MD (2/05/2000). true vertical 8902 feet CIBP set @ 11950' MD (2/17/1999) CIBP set @ 12540' MD (3/15/1998) Effective depth: measured 11290 feet true vertical 8938 feet Junk (measured) Milled ClBP pushed to 11290' MD 10/4/2000. Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 1910# Poleset 110' 110' Surface 2444' 13-3/8" 2300 sx cs ,, & 40o sx cs, 2506' 2506' Production 10312' 9-5/8" 500 sx c~ass G & 3O0 Sx CS ~ 10374' 8705' Liner 241' 7" 30o Sx Class G 10406' 8733' Liner 3012' 2-7/8" 24 bbls Class G 13150' 8902' Perforation depth: measured 11220' - 11290'; (isolated below CIBP's 11770' - 11840'; 12375' - 12440'; 12970' - 13020'; 13075' - 13114'.) true vertical 8942' - 8938'; (isolated below CIBP's: 8930' - 8930'; 8919' - 8916'; 8898' - 8896'; 8897' - 8898'.) Tubing (size, grade, and measured depth) 5-1,2", 17#, L-80 PCT @ 10123' MD; 4-1,2", 12.6#, L-80 POT @ 10219' MD. RECEIVED Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BOT 3-H PACKER @ 10114' MD. .5-1/2' AVA TRSV SSSV @ 2188' MD. J 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in due to annular communication) - Subsequent to operation(lO,11/2000) 15812 - - 3110 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ Gas __ Suspended __ Service MI Iniector 17. I hereby certify~.b,¢ the foregoing is true and correct to the best of my knowledge. Signed ~Z.~/~¢'.~ ~....~.¢-¢'~ Title DS 3 Surveillance Engineer Date Daniel/e ohms Prepared by Paul Rauf 584--5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICA'F~ 03-33Ai DESCRIPTION OF WORK COMPLETED ANNULAR ISOLATION CEMENT SQUEEZE Date Event Summary 6/24/2000 - 6/26/2000: 9/02/2000: 9/03/2000: 9/06/2000: 9/07/2000: 9/09/2000: 9/10/2000: 9/23/2000: 9/26/2000: 9~27/2000: 9/30/2000: 10/02/2000: 10/03/2000: 10/04/2000: 10/09/2000: 10/15/2000: RIH & retrieved IBP f/10125' (set 4/24/2000). Performed SBHP Survey. MIRU CTU. PT'd equip. RIH & performed FCO f/11285' to ClBP located @ 11350' MD. RIH w/FAS-DRILL Plug but could not get it past the tubing patch @ 10023'. POOH. Some slips left in hole as fish. RIH w/venturi junk basket - no recovery. (CTU still rigged up). RIH w/CT nozzle & drifted/washed to 11338'. POOH w/CT. RIH & set 2-7/8" HES Model M ClBP @ 10200' to isolate the open perf intervals @: 11220' - 11290' MD (Zone 2C/2B) Reference Log: MWD-GR 4/20/1997. PUH & PT'd plug to 2200 psi. POOH. RIH w/CT & pumped a gelled sand slurry containing 1100# of 20/40 mesh sand onto the CIBP. POOH. FP'd well. RD CTU. RIH & tagged TOS @ 10063' SLM. MIRU ELU. PT'd equip. RIH w/1-11/16" tubing puncher & shot circulation holes f/10060' - 10065' @ 4 SPF & 0° phasing. POOH w/tubing puncher. ASF. RD ELU. Fluid packed tubing & IA w/KCL Water. A CTU Annular Isolation Cement Squeeze was performed to squeeze a leaking tubing patch over GLM #9 @ 10028' as follows: MIRU CTU. PT'd equip. RIH w/CT & pumped 95 bbls of Non-Slick 1% KCL Water. Tagged TOS @ 10063'. Pumped 12 bbls of 15.6 ppg LARC. Placed 7 bbls into the IA & 5 bbls in tubing. TOC in IA N 9950'. Contaminated cement w/Biozan & cleaned out to 9930'. POOH w/CT. FP'd well. Left 100 psi on well. RD. WOC. MIRU CTU. PT'd equip. RIH & tagged TOC @ 9931' corrected to SLM. MIT tubing to 1000 psi f/30 min - no losses. RIH & UR'd to 9996' CTM. POOH w/UR. Having depth counter problems. RIH & tagged BTM @ 9998'. Milled cement to 10018' CTM & POOH. RU ELU. RIH & tagged TOC @ 10037' ELM. MITIA to 3000 psi - passed. POOH & RD ELU. RIH w/CT & tagged BTM @ 10016' CTM (no correction). Milled to 10030'. Milled cement to cement/sand interface. FCO'd to ClBP @ 10200'. Milled & pushed it to 11290'. Injectivitytest: 1570 psig @ 1 bpm. PT'd IAto 1000psi. POOH. RD. Placed 03-33Ai on MI injection. MITIA to 2200 psi - passed. Obtained representative injection data. RECEIVED J/IN 0 3 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforale _ (IA Sqz) Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5060' FNL, 4459' FEL, Sec. 11, T10N, R15E, UM At top of productive interval 2402' FSL, 639' FEL, Sec. 11, T10N, R15E, UM At effective depth At total depth 1515' FNL, 2658' FEL, Sec. 11, T10N, R15E, UM 5. Type of Well: Development __ Exploratory __ Stratigraph ic __ Service ~X ORIGINAL 6. Datum elevation (DF or KB feet) RKB 62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-33Ai 9. Permit number / approval number 197-039 10. APl number 50-029-21 142-01 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 1 1 0' Surface 2444' Production 10312' Liner 241' Liner 3012' Perforation depth: measured 13150 feet Plugs (measured) CIBP @ 10200' on 9/07/2000. 8902 feet CIBP set @ 11350' MD (2/05/2000); CIBP set @ 12540' MD (3/15/1998) 1 0070 feet Junk (measured) claP set @ 11950' MD (2/17/1999) 8408 feet Size Cemented Measured Depth True vertical Depth 20" 1910# Poleset 110' 110' 13-3/8" 2300 Sx cs ~ & 400 sx cs H 2506' 2506' 9-5/8" 5oo sx C~ass G & 30O Sx CS ~ 10374' 8705' 7" 300 sx C~ass G 10406' 8733' 2-7/8" 24 bbls Class G 1 3150' 8902' (Isolated below ClBP's 11220' - 11290'; 11770' - 11840'; 12375' - 12440'; 12970' - 13020'; 13075'- 13114'.) true vertical (Isolated below CIBP's: 8942' - 8938'; 8930' - 8930'; 8919' - 8916'; 8898' - 8896'; 8897' - 8898'.) Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 PCT @ 10123' MD; 4-1/2", 12.6¢, L-80 PCT @ 10219' MD. 9-5/8" X 5-1/2" BeT 3-H PACKER @ 10114' MD. 5-1/2" AVA TRSV SSSV @ 2188' MD. 13. Attachments Description summary of proposal ___X Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation September 15, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Service MIST Injector Suspended __ 17. I hereby~oregoing is true and_.~rrect to the best of my knowledge. Signed {~,,"~¢,¢.~-~'~~/~'~ ~~~"~-~ 'ritle:BPXADS-03Engineer Danielle Ohms FOR COMMISSION USE ONLY Questions? Call Danielle Ohms @ 564-5759. Date Prepared by Paul Rauf 564-5799 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~' O f. rt. Approval no. 3~oo' ~'5~ Approved by order of the Com~nission Form 10-403 Rev 06/15/88 · .¢~-~GiNAL SIGNED BY Taylor Seamount SEP 11 2000 -~ SUBMIT IN TRIPLICATE - bp 03-33Ai Annular Isolation Squeeze BP Exploration (Alaska) Inc. 900 East Benson Boulevard Primary Objective ~.o. Box 196612 Anchorage, Alaska 99519-6612 ~907~ 561-5111 Cement the tubing x inner annulus with 15.6 ppg LARC cement to eliminate annular communication caused by a leaking tubing patch. . o 4. 5. 6. 7. 8. 9. 10. RU Slickline, pull IBP and drift liner. RU CTU. FCO to PBD, set CIBP at 111~,200' MD, and lay in sand plug to 10,070' MD. RU Slickline and tag sand top. RU E-line. Shoot circulation holes in tubing from 10,060' - 10,065' MD. Fluid pack tubing and IA, freeze protect. RU CTU. Pump 13 bbls LARC cement. Wait on cement 3 days. RU slickline and tag cement top. RU CTU. Underream cement, mill cement through patch, Pressure test, cleanout sand plug, and mill CIBP. FCO to TD. Put well on MI injection. O Subject File Calculations Sheet number Date ~/ // '2- . ¢lqiTCmP pA-n-cH io.2.oO/ ~ { 02...~o' r' t II ~SD c' 15~c Calculations C Subject File Sheet number Date _ 4L~.~,E5 .qqvT' mt:, .. 6 3 2 1 ,i _I COILED TUB!Ni3 UNIT BOP EOU ] PI,IENT 3 I. 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAJAS 5. 5000 PSI 4 1/6":BLIND RAklS 6. 5000 PSI 4 1/16" STUFFING BOX 2 BOP EOU ! PHENT 1. ~>OO0 PSI ?" WELLHEAD CONNECIOR FLANGE : 2. 5OD0 PSI W~RELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR , 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF Re: 03-33A Failed MITIA PERMIT TO DRILL # 197-c;'~o ~ . Subject: Re: 03-33A Failed MITIA PERMIT TO DRILL #197-039 Date: Fri, 26 May 2000 13:33:48 -0800 From: Blair Wondzell <blaiz_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 ~ppco.com> Paul, Thanks for the information. Blair PRB Problem Wells wrote: Blair: We performed a leak detect log on the well, and as suspected the patch is leaking (set 6/18/93 across GLM #9). Engineering is working on a repair procedure. It will remain shut-in until the repair is complete. Appropriate Sundry Notices will be submitted. Jerry Dethlefs Forwarded by PRB Problem Wells/AAI/ARCO on 05/26/2000 12:33 PM Blair Wondzell <blair wondzellSadmin.state.ak.us> on 04/17/2000 08:08:14 AM To: PRB Problem Wells/AAI/ARCO cc: Subject: Re: 03-33A Failed MITIA PERMIT TO DRILL #197-039 Joe, Thanks for the information. Please keep me in the loop. Thanks, Blair PRB Problem Wells wrote: > Hello Blair and Tom. > Well 03-33A (PTD 197-039) failed an MIT-IA today (4/14/00). Leak rate was 8 gpm > ~ 3000 psi. 3-33A is currently injecting produced water, 1600 bwpd ~ 1900 psi > and is scheduled to be shut-in and freeze protected tomorrow. Leak location is > unknown. The IA pressure is approximately tracking the tubing injection > pressure, indicating the leak is from the tubing into the IA. > > We are planning on running a leak detect log to locate the leak point. Call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 659-5102 email: plO418mail.aai.arco.com 5/26/00 1:34 PM · qe: 03-33A Failed MITIA PERMIT TO DRILL #1'~4)39 ' Subject: Re: 03-33A Failed MITIA PERMIT TO DRILL #197-039 Date: Mon, 17 Apr 2000 09:08:14 -0800 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 ~mail.aai.arco.com> Joe, Thanks for the information. Please keep me in the loop. Thanks, Blair PRB Problem Wells wrote: > Hello Blair and Tom. > Well 03-33A (PTD 197-039) failed an MIT-IA today (4/14/00). Leak rate was 8 gpm > ~ 3000 psi. 3-33A is currently injecting produced water, 1600 bwpd ~ 1900 psi > and is scheduled to be shut-in and freeze protected tomorrow. Leak location is > unknown. The iA pressure is approximately tracking the tubing injection > pressure, indicating the leak is from the tubing into the IA. > We are planning on running a leak detect log to locate the leak point. > Call if you have any questions. > Joe Anders > Problem Well Specialist > ARCO Alaska, Inc. > (907) 659-5102 > email: plO4!Smail.aai.arco.com 1 of 1 4/18/00 8:38 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (ClBP) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 62 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5060' FNL, 4459' FEL, Sec. 11, T10N, R15E, UM 03-33Ai At top of productive interval 9. Permit number / approval number 2402' FSL, 639' FEL, Sec. 11, T10N, R15E, UM 97-39 At effective depth 10. APl number 50-029-21 142-01 At total depth 11. Field / Pool 1515' FNL, 2658' FEL, Sec. 11, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 13150 feet Plugs (measured) ClBP set @ 11350' MD (2/05/2000). true vertical 8902 feet ClBP set @ 12540' MD (3/15/1998) ClBP set @ 11950' MD (2/17/1999) Effective depth: measured 1 1 350 feet Junk (measured) true vertical 8933 feet 0RIGINAL Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 191o# Poleset 1 10' 1 10' Surface 2444' 13-3/8" 2300 sx cs ~H & 400 sx cs ~ 2506' 2506' Production 10312' 9-5/8" 500 Sx Class G & 300 Sx CS I 10374' 8705' Liner 241' 7" 300 Sx Class G 10406' 8733' Liner 3012' 2-7/8" 24 bbls Class G 1 3150' 8902' Perforation depth: measured 11220' - 11290'; (isolated below ClBP's 11770' - 11840'; 12375' - 12440'; 12970' - 13020'; 13075' - 13114'.) true vertical 8942' - 8938'; (isolated below ClBP's: 8930' - 8930'; 8919' - 8916'; 8898' - 8896'; 8897' - 8898'.) Tubing (size, grade, and measured depth)5-1/2",17#,L-80POT@10123'MD;4-1/2",12.6#,L-80POT@10219'MD.RECEIVED Packers & SSSV (type & measured depth) 9-5/8" X 5.1/2" BeT 3-H PACKER @ 10114' MD. 5-1/2" AVA TRSV SSS V @ 2188' MD. M~ 2 8 200~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) A~i~,0it & Gas Cons. Commission Treatment description including volumes used and final pressure AJ'lChOfii~je 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation (Shut/n) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __ Gas __ Suspended __ Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢2.' Title Arco Well Group Supervisor Date ._~ .- .~,- ~j.)o ~', ErinOba~,¢-~ ~ ~~ ' . Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03-33Ai DESCRIPTION OF WORK COMPLETED SET CIBP & PERFORATING OPERATIONS Date Event Summary 2/04/2000: 2/05/2000: 2/25/2000: 2/29/2000: 3/02/2000: MIRU CTU. Pumped 420 bbls of Schmoo-B-Gone down tubing & let soak for 3 hrs. PT'd equip. RIH &tagged PBTD @ 11822'. Attempted to set a 2-7/8 CIBP. RIH &drifted to 11730' MD. Set CIBP @ 11350'. POOH. RIH &shot 70' of Add Perforations in 3 runs as follows: 11220'- 11290' MD (Zone 2C/2B) Reference Log: MWD-GR 4/20/1997. Used 2" carriers & all shots @ 4 SPF, underbalanced, 60°/120° phasing, & random orientation. POOH w/guns. ASF. MITIA to 2200 psi - passed. MITOA to 2000 psi - passed. Established injectivity of 0.8 bpm @ 2200 psi. Rate too Iow for MI injection. Well 3-33Ai is currently shut in, awaiting a future acid stimulation prior to return to service. RECEIVED 2 8 000 Alaska 0it & Gas Cons. Commissior., Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate _X Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 62 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5060' FNL, 4459' FEL, Sec. 11, T10N, R15E, UM 03-33Ai At top of productive interval 9. Permit number / approval number 2402' FSL, 639' FEL, Sec. 11, T10N, R15E, UM 97-39 At effective depth 10. APl number 50-029-21142-01 At total depth 11. Field / Pool 1515' FNL, 2658' FEL, Sec. 11, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 13150 feet Plugs (measured) CIBP set @ 12540' MD (3/15/1998) true vertical 8902 feet CIBP set @ 11950' MD (2/17/1999) Effective depth: measured 11940 feet Junk (measured) true vertical 8927 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 191o# Poleset 110' 110' Surface 2444' 13-3/8" 2300 Sx CS III & 400 Sx cs II 2506' 2506' Production 10312' 9-5/8" 500 Sx Class G & 300 Sx CS I 10374' 8705' Liner 241' 7" 300 Sx Class G 10406' 8733' Liner 3012' 2-7/8" 24 bbls Class G 1 3150' 8902' Perforation depth: measured 11770'- 11840'; (isolated below CIBP's 12375'- 12440'; 12970' - 13020'; 13075'- 13114'.) ': · true vertical 8930' - 8930'; (isolated below cIgP's: 8919' - 8916'; 8898' - 8896'; 8897' - 8898'.) ~'~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 10123' MD; 4-1/2", 12.6#, L-80 PCT @ 10219' MD. : Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BeT 3-H PACKER @ 10114' MD. ""1~[¢/2 0 /~' / ~,/ 5-1/2" AVA TRSV SSSV @ 2188' 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 9606 2675 Subsequent to operation 22.185 2471 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ig n e d ~:::~(.~,,,~, ~. ~ Title Arco Well Group Supervisor Date Erin Oba~ ~" "v ~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03-33Ai DESCRIPTION OF WORK COMPLETED CT MUD ACID STIMULATION Date Event Summary 6/06/1999: Performed a CT Mud Acid Stimulation on a horizontal MIST injector to increase injectivity as follows: MIRU CTU & PT'd equip to 4000 psi. Pressured up IA w/Triplex pump to 2500 psi. RIH w/CT & tagged PBTD @ 11940' MD. Pumped the following fluids schedule across the open perforation interval located @: 11770' - 11840' MD (Zone 2B) (a) 277 bbls of 2% NH4CL between 1-2 bpm, followed by (b) 50 bbls of 75% Diesel, 25% Xylene @ 1.5 bpm, followed by (b) 100 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 1.8 bpm, followed by (d) 50 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 1.7 bpm, followed by (e) 50 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 1.8 bpm, followed by (f) 400 bbls of 2% NH4CL @ 1.9 bpm, followed by (g) shutdown. POOH w/CT. RD. Returned well to MI injection & obtained valid injection rate. PERMIT DATA 97-039 MWD SRVY 97-039 MWD SRVY 97-039 NGP-MD 97-039 NGP-TVD 97-039 8068 AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~R~SPERRY 10300-131500 ~'SPE~RY 10300.-13150. ~-f64o2-1315o ,,.~'/~669-8839 ~SPERRY GR/ROP Page: 1 Date: 05/24/99 T / RUN RECVD D .............. 05/14/97 06/06/97 FINAL 08/13/97 FINAL 08/13/97 25-12 08/13/97 10-407 ~COMPLETION DATE @ DAILY WELL OPS R @ &~/[7/~/ TO Are dry ditch samples required? yes ~And received? Was the well cored? yes ,'_~o~Analysis & description received? Are well tests required? ]~es ~Recezved?.~. y~ .... Well is in compliance Initial CO~ENTS @ (,/~/~'7/ @ ¢/~ /~/ yes-~.no BOX 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 _ Olher _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 62' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 215' FSL, 821' FWL, Sec 11, T10N, R15E, UM. 3-33A At top of productive interval: 9. Permit number/approval number: 2402' FSL, 639' FEL, Sec 11, T10N, R15E, UM. 97-39 At effective depth: 10. APl number: 50-029-21142-01 At total depth: 11. Field/Pool: 1501' FNL, 2667' FEL, Sec 11, T10N, R15E, DM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 13150 feet Plugs (measured) CIBP set @ 12540' M D (3/15/98). true vertical 8902 feet CIBP set @ 11950' MD (2J17/99). Effective Depth: measured 11950 feet Junk (measured) true vertical 8927 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1910# Poleset 110' 110' Surface 2444' 13-3/8" 2300 Sx CS III & 2506' 2506' 400 Sx CS II Production 10312' 9-5/8" 500 Sx G & 300 CS I 10374' 8705' Liner 237' 7" 300 Sx CIG 10402' 8733' Liner 3016' 2-7/8" 24 Bbls CIG 13150' 8902' Perforation Depth measured 11770 - 11840'; [Isolated below CIBP's: 12375- 12440'; 12970 - 13020'; 13075 - 13114'] true vertical 8930 - 8930'; [Isolated below CIBP's: 8919- 8916'; 8898 - 8896'; 8897- 8898'] Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, POTbg @ 10123' MD; 4-1/2", 12.6#, L-80, PC Tbg @ 10219' MD . .. Packers and SSSV (type and measured depth) BOT 3-H Packer at 10113' MD; AVA TRSV SSSV @ 2187' MD. . , 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached U K i ~,,.~ i i"~A L Intervals treated (measured) 14. Representitive Baily Average production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In - - Subsequent to operation - 12419 - 3172 15. Attachments 16. Status of well classification as: ~C~i~ Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed_ ~4~--,~:.,. ~')~. ~ Title: Engineering Supervisor Date '~'"' / ~ -~'¢ Form lev 06/15/88 SUBMIT IN DUPLICATE 3-33A DESCRIPTION OF WORK COMPLETED CIBP INSTALLATION & ADD PERFORATIONS 2/16/99: RIH w/CT & tagged PBTD at 12464' MD. 2/17/99: MIRU CTU & PT equipment. RIH w/Cast Iron Bridge Plug & set plug in the 2-7/8" liner at 11950' MD, to isolate the open perforation interval at: 12375- 12440' MD PT CIBP to 2500 psi; passed. POOH w/CT. MU & RIH w/perforating guns & shot a new Add Perforation interval above the CIBP at: 11810- 11840' MD Used 2" carriers & shot the perfs at 4 spf at 60 degree phasing at balanced pressure. Noted ASF. RD. 2/18/99: RIH w/perforating gun & shot an additional Add Perforation interval at: 11770- 11810' MD Used 2" carriers & shot the perfs at 4 spf at 60 degree phasing at balanced pressure. Noted ASF. RD. POOH w/guns. POOH w/guns. Placed the well on miscible gas injection & obtained a valid injection rate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate X Plugging_ Perforate_X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 62' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchora~]e, AK 99510-0360 Service_X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 215' FSL, 821' FWL, Sec 11, T10N, R15E~ UM. 3-33A At top of productive interval: 9. Permit number/approval number: 2402' FSL, 639' FEL, Sec 11, T10N, R15E, UM. 97-39 At effective depth: 10. APl number: 50-029-21142-01 At total depth: 11. Field/Pool: 1501' FNL, 2667' FEL, Sec 11, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 13150 feet Plugs (measured) CIBP set @ 12540' MD (3/15/98). true vertical 8902 feet Effective Depth: measured 12540 feet Junk (measured) true vertical 8906 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1910# Poleset 110' 110' Surface 2444' 13-3/8" 2300 Sx CS III & 2506' 2506' 400 Sx CS II Production 10312' 9-5/8" 500 Sx G & 300 CS I 10374' 8705' Liner 237' 7" 300 Sx CIG 10402' 8733' Liner 3016' 2-7/8" 24 Bbls CIG 13150' 8902' Perforation Depth measured 12375- 12440'; [Isolated below ClBP: 12970- 13020'; 13075- 13114'] true vertical 8919- 8916'; [Isolated below ClBP: 8898- 8896'; 8897- 8898'] Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC Tbg @ 10123' MD; 4-1/2", 12.6#, L-80, PC Tbg @ 10219' MD Packers and SSSV (type and measured depth)BeT 3-H Packer at 10113' MD; AVA TRSV SSSV @ 2187' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached J U L 2 Intervals treated (measured) Alaska 0il & (3as Cons. Commission ~nnhnr,~nn 14. Representitive Daily Average Production or Iniection Data .......... ~'" Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 31356 3043 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~'~_.Z,c.-~.~ ~k'/ ,. ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 3-33A DESCRIPTION OF WORK COMPLETED CIBP INSTALLATION, CTU ADD PERFORATIONS, & ACID STIMULATION TREATMENT 3/14/98: Killed well w/600 bbls of 2% KCI Water & 60 bbls Meth Water. 3/15/98: MIRU CTU & PT equipment. RIH w/Cast Iron Bridge Plug & set plug in the 2-7/8" liner at 12540' MD, to isolate the open perforation intervals at: 12970 - 13020' MD 13075 - 13114' MD PT CIBP to 2500 psi; passed. POOH. RD. 3/25/98- 3/26/98: MIRU CTU & PT equipment. Made 3 runs w/CTC perforating guns & shot Add Perforations at: 12375- 12440' MD Used 2-1/8" carriers & shot all perfs at 4 spf at 60 degree phasing at balanced pressures. POOH w/guns & noted all shots fired on all 3 gun runs. RD. Placed well on MI (4/15/98). 4/30/98: Performed a CT Acid Stimulation Treatment to increase injectivity rates as follows: MIRU CTU & PT equipment. Loaded wellbore w/230 bbls of 2% NH4CI Water, then RIH w/CT to CIBP. PU & reciprocated treatment fluids across the open perforation interval (above). Pumped: a) 33 bbls 50% Diesel - 50% Xylene, followed by b) 100 bbls 12% HCI, followed by c) 50 bbls 9% HCI- 1% HF @ 1 bpm, followed by d) 50 bbls 12% HCI, followed by e) 190 bbls 2% NH4CI Water, followed by f) Shutdown. Saw good injectivity increase response during treatment. POOH w/CT. RD. Returned the well on miscible gas injection & obtained a valid injection rate. STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C(_ ,MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation shutdown Alter casing Repair well Plugging X Change appr~'ed program Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate 2. Name of Operator ARCO Alaska, Inc. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 215' FSL, 821' FWL, Sec 11, T10N, R15E, UM. At top of prod?ctive interval 2402' FSL, 639; FEL, Sec 11, T10N, R15E, UM. At effective depth 2415' FSL, 592' FEL, Sec 11, T10N, R15E, UM. At total depth 2419' FSL, 576' FEL, Sec 11, T10N, R15E, UM. Other 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8, Well number 3-33i 9. Permit number 84-110 10. APl number 50 - 029-21142 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10937 feet 9264 feet Plugs(measured) PBTD Tagged @ 10673' MD (2/25/96). Effective depth: measured true vertical Casing Length Conductor 77' Surface 2475' Production i 0343' Liner 771' FCEiV;:D, 10673 feet 8999 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1910 Poleset 110' 110' 13-3/8" 2300 Sx CS III & 400 Sx CS II 2506' 2506' 9-5/8" 500 Sx Cl G & 300 Sx CS I 10374' 8705' 7" 300 Sx Ci G 10936' 9263' '~ !-P~rforatlor~?d~¢'th: measured 10385 - 10455" 10471 - 10477'; 10484- 10490'; 10600 - 10620'; 10630 - 10650'; 10678 - 10688'; 10694 - 10699' ., , mp,,i%icn true vertical 8716 - 8785'; 880i - 8807'; 8814 - 8820'; 8928 - 8947'; 8957 - 8977'; 9004 - 9014'; ~ ~'...2~ Coi~$. U0 ..... AF, ch0rarj.'.-', 9021 - 9026' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10123' MD; 4-1/2", 12.6#, L-80, PCT @ 10219' MD. Packers and SSSV (type and measured depth) BOT 3-H Packer @ 10113' MD; 5-1/2", AVA SSSV @ 2187' MD. 13. Attachments Description summary of proposal x Detailed operations program BOP sketch . x i4. Estimated date for commencing operation 15. Status of well classification as: March, 1997 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Q',~¢~Y~'on5 Signed -~'~ '~. ~ Title Engineering Supervisor Date ,2- 2. 7- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity . BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approval No.~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well Oil__ Gas__ Suspended__ Abandoned_ Service_X Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-39 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-029-21142-01 215' FSL, 821' FWL, Sec 11, T10N, R15E, UM. i B/.i':: ! PRUDHOE BAY UNIT At To pProducing interval _.~,/~ ~c~/~,~_ 10 Well Number 2402' FSL, 639' FEL, Sec 11, T10N, R15E, UM. ",/?,i,,-i~ !~ 3-33A At Total Depth ~--/~'.~ ~,[d,.~,[d,.~,[d~~ 11 Field and Pool 1501' FNL, 2667' FEL, Sec 11, T10N, R15E, UM. ~, ............. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 62' RKB ADL 28327 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 4/19/97 4/28/97 5/3/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 13150' MD / 8902' TVD 13115' MD / 8899' TVD YES_X NO__ 2187' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30" 1910# Poleset 13-3/8" 72# L-80 Surf 2506' 17.5" 2300 Sx CS III & 400 Sx CS II 9-5/8" 47# L-80 Surf 10374' 12.25" 500 Sx Class G & 300 Sx CS I 7" 29# L-80 10165' 10402' 8.5" 300 Sx Class G 2-7/8" 6.5# L-80 FL4S 10134' 13150' 3.69" 24 bbls Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2" Tbg 10123' 10113' 12970 - 13020' M D; 8898 - 8896' TVD; at 4 spf. 4-1/2" Tbg 10123 - 10219' 13075 - 13114' MD; 8897- 8898' TVD; " I 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Injecting Miscible Gas Date of Test Hours Tested INJECTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR N/A TEST PERIOD _24 Hrs 28827 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 3015 (WHIP) - 24 HOUR RATE __ - 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 3/12/97 (issued PERMIT # 97-39). RECEIVED Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME nclude interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Top Sadlerochit 10382' 8713' N/A 31 LIST QFATTACHMENTS Summary of 3-33A Coil Tubing Sidetrack Drilling Operations. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~'~u~ '~, ~'~'~ Engineering Supervisor Date ~"- ~-~ '7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementin ~ and the location of the cementing tool. ~ :~ Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection '~z . .~--~ Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". ~ Form 10-407 3-33A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 4/17/97: MIRU CTU & PT equipment. PT BOPS. RIH w/milling BHA. 4/18/97: Tagged cement plug top at 10264' MD. Milled pilot hole through cement to 10400' MD. POOH w/BHA. 4/19/97: RIH w/window milling BHA. Milled a window through the 7" liner at 10402 - 10406' MD, then drilled formation to 10411' MD. Backreamed window & POOH w/BHA. 4/20/97: RIH w/drilling BHA. Could not pass through window. window smooth. POOH w/milling BHA. POOH w/BHA. RIH w/milling BHA & reamed 4/21/97: RIH w/drilling BHA. RIH w/drilling BHA. Drilled 3.69" sidetrack build section w/FIo-Pro to 10465' MD. POOH w/BHA. Drilled to 10646' MD. POOH w/BHA. RIH w/drilling BHA & drilled to 10760' MD. 4/2:2/97: Drilled to 10796' MD. RIH w/drilling BHA. POOH w/BHA. RIH w/drilling BHA. Drilled to 10894' MD. Drilled to 10839' MD. POOH w/BHA. 4/23/97: POOH w/BHA. RIH w/drilling BHA. Drilled horizontally to 11195' MD. w/BHA. Blew down CT reel w/N2, changed out packoffs, & RU ROC. Backreamed hole & POOH 4/24/97: RIH w/drilling BHA. Drilled to 11642' MD w/periodic shod trips. POOH w/BHA. PT BOPS. 4/25/97: RIH w/drilling BHA. Resumed drilling to 12335' MD. POOH w/BHA. 4/26/97: RIH w/drilling BHA. RIH w/drilling BHA. Drilled to 12542' MD. Drilled to 12805' MD. Swept to window then drilled to 12705' MD. POOH w/BHA. 4/27/97: Drilled to 13120' MD. Pumped Hi Vis pill & swept hole to window. 4/28/97: Drilled to TD at 13150' MD. Pumped Hi Vis pill & POOH w/BHA. MU & RIH w/2-7/8" blank liner assembly. 4/29/97- 4/30/97: RIH w/liner to bottom at 13150' MD. Released liner. POOH. RIH w/cementing stinger to TOL. Pumped 24 bbls of Class G cement to set the liner at 10134 - 13150' MD. Displaced cement w/biozan & landed wiper plug. Unstung & POOH jetting Seawater. FP top 2000'. ND stack & NU tree. RD & MOL. 5/2/97: RIH w/milling BHA to tag PBTD at 13115' MD. POOH displacing well w/filtered Seawater, biozan, & MW. JUN 6 1997 Alas.~a .0il .& 6as 00ns. ,Anchorage 3-33A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 5/3/97: RIH w/perforation guns & shot initial perforation intervals at 4 spf at: 12970-13020' MD 13075-13114' MD 5/8/97: Performed an injectivity test; 13.5 gpm @ 1200 psi. 5/14/97: Performed a FB Non-Reactive Perforation Breakdown Treatment. 5/23/97: Performed a CT Acid Stimulation Treatment to increase injectivity rates as follows: MIRU CTU & PT equipment. RIH w/CT to bottom, then reciprocated treatment fluids across the open perforation intervals (listed above). Pumped: a) 44 bbls 2% NH4CI Water, followed by b) 48 bbls 50% Diesel - 50% Xylene, followed by c) 71 bbls 12% HCI w/10% Xylene, followed by d) 50 bbls 9% HCI - 1% HF @ 2 bpm, followed by e) 25 bbls 12% HCI w/10% Xylene, followed by f) 199 bbls 2% NH4CI Water w/5% Musol @ 2 bpm, followed by g) Shutdown. POOH w/CT. Rigged down. Placed the well on miscible gas injection & obtained a valid injection rate. :lU,~i G]99 4las/~a .Oil .& Gas Cons. AncDorag~ tY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PRUDHOE BAY UNIT/ DS 3-33A 500292114201 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 042897 MWD SURVEY JOB NUMBER: AK-MW-70108 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10300.00 8632.00 8570.00 10400.00 8731.14 8669.14 10406.00 8737.10 8675.10 10451.10 8782.01 8720.01 10463.20 8793.87 8731.87 8 18 N 85.40 E .00 2200.10N 3798.80E 6 40 N 82.30 E 1.67 2201.46N 3811.76E 6 40 N 82.07 E .47 2201.55N 3812.45E 10 11 N 82.80 W 37.09 2202.42N 3811.07E 12 23 N 84.30 W 18.34 2202.68N 3808.72E -1888.00 -1897.92 -1898.43 -1896.81 -1894.71 10471.30 8801.76 8739.76 10477.70 8807.96 8745.96 10487.70 8817.56 8755.56 10497.99 8827.31 8765.31 10519.82 8847.49 8785.49 13 48 S 87.30 W 29.13 2202.73N 3806.89E 15 0 S 81.30 W 29.89 2202.56N 3805.30E 17 23 S 75.80 W 28.46 2202.00N 3802.58E 19 58 S 76.39 W 25.04 2201.21N 3799.38E 24 46 S 81.82 W 23.96 2199.68N 3791.22E -1893.18 -1891.97 -1890.04 -1887.85 -1881.98 10527.97 8854.81 8792.81 10541.74 8866.86 8804.86 10551.87 8875.48 8813.48 10559.29 8881.65 8819.65 10573.14 8892.84 8830.84 27 15 S 83.70 W 32.07 2199.23N 3787.67E 30 40 S 86.03 W 26.08 2198.64N 3781.03E 32 46 S 85.86 W 20.85 2198.27N 3775.72E 34 32 S 85.68 W 23.76 2197.96N 3771.62E 37 42 S 86.03 W 22.86 2197.37N 3763.48E -1879.31 -1874.17 -1870.00 -1866.79 -1860.41 10587.74 8904.09 8842.09 10602.19 8914.60 8852.60 10616.84 8924.58 8862.58 10630.72 8933.34 8871.34 10645.92 8942.10 8880.10 41 28 S 87.09 W 26.30 2196.82N 3754.19E 45 10 S 86.56 W 25.73 2196.27N 3744.29E 48 52 S 87.62 W 25.74 2195.73N 3733.59E 52 49 S 88.67 W 29.06 2195.38N 3722.83E 56 46 S 89.37 W 26.32 2195.17N 3710.42E -1853.07 -1845.22 -1836.70 -1828.03 -1817.91 10671.89 8955.28 8893.28 10682.22 8959.94 8897.94 10698.37 8966.42 8904.42 10708.79 8970.07 8908.07 10727.89 8975.87 8913.87 62 13 N 88.88 W 21.77 2195.28N 3688.05E 64 4 N 87.99 W 19.40 2195.53N 3678.84E 68 36 N 86.52 W 29.32 2196.24N 3664.07E 70 26 N 88.17 W 22.99 2196.69N 3654.32E 74 11 N 87.76 W 19.79 2197.34N 3636.14E -1799.40 -1791.66 -1779.08 -1770.79 -1755.43 10747.87 8980.67 8918.67 10757.39 8982.49 8920.49 10763.89 8983.51 8921.51 10769.87 8984.24 8922.24 10785.04 8985.42 8923.42 77 57 N 88.45 W 19.11 2197.98N 3616.76E 79 58 N 88.87 W 21.66 2198.20N 3607.42E 82 5 N 89.22 W 32.89 2198.30N 3601.00E 83 53 N 87.91 W 37.13 2198.45N 3595.07E 87 11 N 89.57 W 24.34 2198.78N 3579.95E -1739.08 -1731.26 -1725.90 -1720.93 -1708.27 10792.74 8985.65 8923.65 10800.39 8985.60 8923.60 10811.84 8985.20 8923.20 10820.92 8984.79 8922.79 10839.49 8983.72 8921.72 89 18 N 89.22 W 27.78 2198.87N 3572.25E 91 29 N 89.04 W 28.73 2198.98N 3564.61E 92 27 N 88.52 W 9.61 2199.23N 3553.17E 92 48 N 87.81 W 8.71 2199.52N 3544.10E 93 46 N 87.64 W 5.30 2200.25N 3525.58E -1701.88 -1695.51 -1685.94 -1678.30 -1662.61 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PRUDHOE BAY UNIT/ DS 500292114201 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 3 -33A 9/97 DATE OF SURVEY: 042897 MWD SURVEY JOB NUMBER: AK-MW-70108 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10859.87 8981.91 8919.91 10874.69 8980.16 8918.16 10887.54 8978.41 8916.41 10914.97 8974.51 8912.51 10943.54 8970.25 8908.25 96 25 97 7 98 31 97 49 99 19 N 87.29 W 13.07 2201.15N 3505.30E N 87.64 W 5.27 2201.80N 3490.60E N 86.58 W 13.62 2202.44N 3477.88E N 82.89 W 13.56 2204.93N 3450.85E N 77.62 W 18.98 2209.71N 3423.02E -1645.38 -1632.89 -1622.04 -1598.34 -1572.69 10968.99 8965.92 8903.92 10989.19 8962.42 8900.42 11021.39 8957.13 8895.13 11039.09 8954.51 8892.51 11057.24 8952.33 8890.33 ** 16 99 40 99 13 97 49 95 58 N 74.28 W 13.47 2215.80N 3398.69E N 70.94 W 16.56 2221.74N 3379.71E N 66.37 W 14.07 2233.30N 3350.14E N 64.26 W 14.23 2240.61N 3334.24E N 62.68 W 13.32 2248.66N 3318.12E -1549.18 -1530.17 -1499.24 -1481.99 -1464.15 11067.87 8951.29 8889.29 11086.42 8949.82 8887.82 11111.87 8947.99 8885.99 11140.19 8945.52 8883.52 11174.52 8942.91 8880.91 95 93 94 95 93 11 52 23 37 4 N 61.40 W 14.05 2253.62N 3308.77E -1453.64 N 58.98 W 14.85 2262.81N 3292.73E -1435.21 N 55.64 W 13.25 2276.52N 3271.37E -1409.84 N 50.55 W 18.42 2293.45N 3248.82E -1381.67 N 45.80 W 15.65 2316.27N 3223.32E -1347.73 11206.02 8941.80 8879.80 11235.77 8941.00 8879.00 11271.87 8939.06 8877.06 11304.89 8936.30 8874.30 11331.89 8933.70 8871.70 90 58 92 6 94 2 95 32 95 31 N 45.10 W 7.06 2338.35N 3200.89E N 40.88 W 14.69 2360.10N 3180.62E N 37.36 W 11.11 2388.06N 3157.88E N 33.14 W 13.52 2414.92N 3138.89E N 30.72 W 8.92 2437.73N 3124.68E -1316.75 -1287.72 -1253.15 -1222.30 -1197.68 11361.79 8931.18 8869.18 11386.42 8929.61 8867.61 11402.92 8928.77 8866.77 11447.87 8927.29 8865.29 11478.27 8926.94 8864.94 94 9 93 9 92 38 91 8 90 10 N 27.91 W 10.41 2463.70N 3110.10E N 27.52 W 4.36 2485.46N 3098.66E N 26.64 W 6.19 2500.13N 3091.16E N 26.82 W 3.36 2540.25N 3070.96E N 27.70 W 4.28 2567.27N 3057.04E -1170.96 -1149.23 -1134.74 -1095.39 -1068.62 11502.59 8926.90 8864.90 11552.02 8927.28 8865.28 11615.19 8928.43 8866.43 11642.42 8929.03 8867.03 11678.37 8929.84 8867.84 90 0 89 7 88 48 88 39 88 46 N 27.34 W 1.66 2588.84N 3045.80E N 27.17 W 1.81 2632.78N 3023.16E N 26.22 W 1.59 2689.21N 2994.79E N 26.97 W 2.81 2713.55N 2982.60E N 29.10 W 5.93 2745.27N 2965.71E -1047.15 -1003.63 -948.31 -924.50 -892.63 11708.17 8930.16 8868.16 11737.79 8930.00 8868.00 11774.07 8929.97 8867.97 11806.59 8930.35 8868.35 11845.27 8930.32 8868.32 90 0 90 37 89 28 89 12 90 52 N 31.21 W 8.20 2771.03N 2950.75E N 33.32 W 7.42 2796.07N 2934.94E N 35.78 W 7.48 2825.95N 2914.37E N 38.42 W 8.16 2851.88N 2894.75E N 41.23 W 8.45 2881.58N 2869.98E -865.71 -838.51 -804.64 -773.80 -736.57 .qY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PRUDHOE BAY UNIT/ DS 3-33A 500292114201 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 042897 MWD SURVEY JOB NUMBER: AK-MW-70108 KELLY BUSHING ELEV. = 62.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11881.97 8929.33 8867.33 11921.57 8927.60 8865.60 11952.19 8926.47 8864.47 11981.32 8925.76 8863.76 12012.64 8924.87 8862.87 92 11 N 43.52 W 7.20 2908.68N 2845.26E 92 48 N 45.80 W 5.95 2936.82N 2817.46E 91 24 N 47.74 W 7.81 2957.77N 2795.17E 91 24 N 49.84 W 7.21 2976.95N 2773.26E 91 50 N 50.90 W 3.65 2996.92N 2749.15E -700.85 -662.01 -631.78 -602.86 -571.69 12029.42 8924.38 8862.38 12072.37 8923.40 8861.40 12124.34 8922.32 8860.32 12169.04 8921.57 8859.57 12207.77 8921.00 8859.00 91 29 N 52.31 W 8.65 3007.34N 2736.01E 91 8 N 55.12 W 6.59 3032.75N 2701.40E 91 13 N 58.11 W 5.75 3061.33N 2658.02E 90 41 N 60.22 W 4.87 3084.24N 2619.65E 90 58 N 62.15 W 5.03 3102.90N 2585.72E -554.96 -512.04 -460.10 -415.50 -376.97 12258.62 8919.76 8857.76 12296.99 8919.05 8857.05 12315.02 8919.05 8857.05 12341.09 8919.13 8857.13 12372.19 8918.82 8856.82 91 50 N 63.91 W 3.86 3125.95N 2540.42E 90 15 N 65.14 W 5.22 3142.45N 2505.79E 89 44 N 66.02 W 5.67 3149.90N 2489.38E 89 54 N 71.64 W 21.57 3159.32N 2465.08E 91 13 N 73.93 W 8.50 3168.52N 2435.37E -326.57 -288.69 -270.93 -245.57 -215.87 12412.54 8917.40 8855.40 12454.34 8914.74 8852.74 12487.54 8911.44 8849.44 12517.04 8908.01 8846.01 12545.49 8905.22 8843.22 92 48 N 77.44 W 9.53 3178.49N 2396.31E 94 28 N 79.90 W 7.10 3186.68N 2355.41E 96 56 N 78.50 W 8.52 3192.87N 2322.97E 96 25 N 76.04 W 8.47 3199.33N 2294.39E 94 49 N 73.40 W 10.79 3206.79N 2267.08E -178.02 -139.66 -109.40 -82.19 -55.44 12583.72 8902.73 8840.73 12631.77 8901.55 8839.55 12668.39 8901.80 8839.80 12709.59 8902.84 8840.84 12738.47 8903.66 8841.66 92 38 N 69.88 W 10.83 3218.80N 2230.89E 90 10 N 67.07 W 7.77 3236.43N 2186.21E 89 1 N 64.61 W 7.42 3251.41N 2152.80E 88 4 N 59.51 W 12.59 3270.70N 2116.43E 88 40 N 57.40 W 7.60 3285.80N 2091.83E -18.80 28.01 64.04 104.95 133.77 12776.39 8903.92 8841.92 12815.22 8903.33 8841.33 12845.02 8902.44 8840.44 12880.30 8900.95 8838.95 12921.12 8899.41 8837.41 90 31 N 54.06 W 10.07 3307.15N 2060.50E 91 13 N 51.78 W 6.14 3330.55N 2029.53E 92 11 N 49.67 W 7.79 3349.41N 2006.48E 92 38 N 48.09 W 4.65 3372.59N 1979.93E 91 40 N 47.03 W 3.52 3400.11N 1949.82E 171.68 210.46 240.13 275.14 315.53 12945.12 8898.64 8836.64 12985.07 8897.29 8835.29 13012.05 8896.55 8834.55 13044.72 8896.17 8834.17 13059.39 8896.30 8834.30 92 1 N 46.50 W 2.65 3416.54N 1932.35E 91 50 N 48.09 W 4.00 3443.62N 1903.01E 91 19 N 47.21 W 3.79 3461.79N 1883.08E 90 0 N 45.45 W 6.73 3484.34N 1859.45E 89 1 N 45.10 W 7.03 3494.66N 1849.03E 339.24 378.75 405.46 437.70 452.13 SP 2Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 4 ARCO ALASKA INC. PRUDHOE BAY UNIT/ DS 3-33A 500292114201 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 042897 MWD SURVEY JOB NUMBER: AK-MW-70108 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 13074.02 8896.67 8834.67 88 4 N 45.10 W 6.56 13095.54 8897.52 8835.52 87 24 N 43.42 W 8.38 13111.27 8898.38 8836.38 86 18 N 44.22 W 8.64 13150.00 8901.78 8839.78 83 35 N 46.20 W 8.65 3504.98N 1838.67E 3520.38N 1823.67E 3531.71N 1812.79E 3558.89N 1785.42E 466.52 487.60 502.98 540.93 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3981.64 FEET AT NORTH 26 DEG. 38 MIN. EAST AT MD = 13150 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 304.45 DEG. TIE-IN SURVEY AT 10,300.00' MD WINDOW POINT AT 10,406.00' MD PROJECTED SURVEY AT 13,150.00' MD RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC. PRUDHOE BAY UNIT/ DS 3-33A 500292114201 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 042897 JOB NUMBER: AK-MW-70108 KELLY BUSHING ELEV. = 62.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10300.00 8632.00 8570.00 2200.10 N 11300.00 8936.77 8874.77 2410.86 N 12300.00 8919.04 8857.04 3143.72 N 13150.00 8901.78 8839.78 3558.89 N 3798.80 E 1668.00 3141.57 E 2363.23 695.23 2503.06 E 3380.96 1017.73 1785.42 E 4248.22 867.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. OF:III--LING S ~:: I:! ~-/I I~ ~ S WELL LOG TRANSMITTAL To: State of Alaska August 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D.S. 03-33A, AK-MW-70108 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21142-01. 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company -- CI I::! ! I--I-- I IM G To: WELL LOG TRANSMITTAL __ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 _. August 13, 1997 MWD Formation Evaluation Logs D.S. 03-33A, AK-MW-70108 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 03-33A: 2"x 5" MD Gamma Ray Logs: 50-029-21142-01 2" x 5" TVD Gamma Ray Logs: 50-029-21142-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 -- A Dresser Industries, Inc. Company May 12, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 3-33A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 3-33A MWD survey Tie-In point at 10,300.00', Window point at 10,406.00' and a Projected survey at 13,150.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9,07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino, Company ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 12, 1997 Erin M. Oba Engineering Supervisor ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 3-33A ARCO Alaska, Inc. Permit No. 97-39 Sur. Loc 215'FSL, 821'FWL, Sec. 11, T10N, R15E, UM Btmhole Loc. 1357'FNL, 2562'FEL, Sec. 11, T10N, R15E, UM Dear Ms. Oba: 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the field inspector on the North Slope pager at 659-3607. David W. Johnston Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,~ION PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill __ Redrill X I lb. Type of Well Exploratory__ Stratigraphic Test _. Development Oil _ Re-Entry__ Deepen --I Service ~ Development Gas __ Single Zone x_~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 62' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28327 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 215' FSL, 821' FWL, Sec 11, T10N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2402' FSL, 639' FEE, Sec 11, T10N, R15E, UM. 3-33A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1357' FNL, 2562' FEL, Sec 11, T10N, R15E, UM. March 30, 1997 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 13400' MD / 8912' TVD 16, To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10400' MD Maximum hole angle 92° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program I Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 3200' 10200' 8533' 13400' 8912' 25 Bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ~,,~ ~ V.~O Total depth: measured 10937 feet Plugs(measured) true vertical 9264 feet Effective depth: measured 10673 feet Junk (measured) F~B 2 , 1997 true vertical 8999 feet ' Casing Length Size Cemented Measured depth True ~'~c~r'g~t~ mm~ssioll ~cn0rage Conductor 77' 20" 1910 Poleset I 1 0' 1 1 0' Surface 2475' 13-3/8" 2300 Sx CS III & 400 Sx Cs II 2506' 2506' Production 1 0343' 9 -5/8" 500 Sx CIG & 300 Sx CS I 1 0374' 8705' Liner 771 ' 7" 300 Sx CIG 1 093 6' 92 63' Perforation depth: measured 10385 - 10455'; 10471 - 10477'; 10484 - 10490'; 10600 - 10620'; 10630 - 10650'; 10678 - 10688'; 10694 - 10699' true vertical 8716 - 8785'; 8801 - 8807'; 8814 - 8820'; 8928 - 8947'; 8957 - 8977'; 9004 - 9014'; 9021 - 9026' 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~x Diverter Sketch_ Drilling program x__ Drilling fluid program __ Time vs depth plot_ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~z,~l-~ci.~5 Signed '~~ '~ . ~ Titlle Engineering Supervisor Date .~-,~ S - ~' 7' Commission Use Only ~,,~--,,~ ~' 50-0,9~/'-.-~,. // c/'-7--' O/ ,._~-'/64 '~'~ other requirements Conditions of al:;proval Samples required __Y e s ~ N o Mud log required __ Y e s ~ N o Hydrogen sulfide measures .z~"Y e s N o Directional survey required )(' Yes N o Required working pressure for BOPE __2M; __ 3 M' ~ 5 M · ~ 1 0M' __ 1 5 M 3500 psi for OTU Other: Original Signed By Oavid W. J0hrlst0ll by order of _.~ ...-/_~ ....~'~ Approved by Commissioner the commission Ddt DS 3-33A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to - 10370' md. Mill window in 7" casing at --10400' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to ~-92°. · Directionally drill 3-3/4" x 3000' horizontal well to access Victor reserves. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Place well on MI. February 24, 1997 5-1/2" Tubing Tbg patch Packer 10113' 7" Liner Top 10165' XN Nipple 10706' Tbg Tail 10Z19' DS 3-33A Proposed CT Sidetrack Horizontal I III 9-5/8" Casing shoe @10374' Top of Z-7/8" Liner in 4-1/Z" Tbg. tail. Initial Perfs~ ZOO' cut in 7" at ~10400 - 10405' % % % % % % % % % % % % % % TD @ ~ Z-7/8" liner 13400' 3-3/4" Open hole Current perforations cement squeezed .,~: ,by' DR;LEX - ALASKA 9075624452 02/17/97 12:58PM . . J ob 29! Page 2/4 3-33 A OlIRI=~.,TK:;II~AL ~4OEI'RACK PLAN ;213,'~j." 1L Zf: ;'M tVE.RI'ICAI': $E¢~I~N I~SE~t ..................... J,- ................... i. i 313 74' R~LATIVE TO GRID ,NORTH . , . !.. 1~4JRFACE LOC. ~ / .............. 7 ................ T ......... i ...................... f,~LIRI=ACE LOCATION I~. D~c.~o~u~.. !' t ! I. ~'~ 7~. '~ ........................... ~ftt~ ! MO Into. Dirl ~,~D~TN: VSJ N/-~i EI-W BulI~I[ Turn I ~ ............ r .... 1 -' I - ' : . . TIP ~ 10~0 83 ~ 8; 85700~ -~!03.01 2~7 3: 3734.6~ OC, ' .~.~ .. i03:~00' 8~* ~2~ 85E~g~ ' .!1~[ -~7~ -~7'37'5t -! 8; -5C -30[ 2. ~OP~DLLOW~' ........ ~ ' ~ ' ~ .._ ~ 134100 39:. ~8 ~7~1: -!111 6] 23~21 3748a .280 3C~ 28C,I ~ 104400' 4.5 ~.9~ 8709.1i -!111.5j 2~9 2~ 3748 3 220; -~o'. ~'0] ....... 2u"6 I · 1071C el 8~ 3,1 289 6: ~ 4. -~ O- 23~2 7- 3~5 7 28'9 ' 1~C0 927' ~28' ~g 7~1~ 2417 4~ ~18Ol -01 ' - i ~ i ~ i~200~ 9~7 ' 2~.4 ~75~ -770.1: 24292 ~5, -01 20. 20 ......................... : ..... i-i~b-b~ .......... ~-~ ......... ~:~l' - '~ 41 -~5.s~ ~ ~I ~ ~i .o ~ : ' ~,0~:; .......... ~'sT ..... ~-'U .... ~.~] ' -~.~,~-~..~~,:~ .... :~T¢ ......... ~"~'" : c ~ *~.Ol 92_4i ~7.5T ~Te ~ ...... ~i70~--'~¢'~--'~6~ ...... :~f ............ ...... ~ .... ~ -~..- ~ ........... : ................. ~ .......... : _, ......... ---j ..... ~ .... ~ ' . ,c bY: DRZLE× - ALASKA Job 291 Page 3/4 9075624452 02/17/97 12:59PM . · 3,-,3~ A DIRECTIONAL, $iDI~T'RACK PLAN ....................... t ...... i-~7~ ........ ¢~'87 ...... 3,d ~ 8~5 7' 7~ 7 2~7 1 '. 2~* 2f -0 2 ~ D: 2 n' ..... t ...... '-- - "- " '* "-'- -' ~ ~8~=I ~ 4] 3~1 ? 8854 2] !37 ......... ~ .... 1~ 8~'b~ ...... ~¥~ ...... ~4~ ~'[ ....... ~53'~; ..... ~676[ ~5i' 2~7.~[ -021 2 o 20 .... , .... , ........ ~ ...... ~ f .... ~ 11910.0: 913; 312.81 ~52.9~ 197.6~ I : "~ ...... ~ ......... ~ ................. + ................. ~ ............................ '"~¢d:~'~ ..... ~'~L ~.o~ ~ !2~.0 :: 9!~ 314~ ~510 287 8~ 3029 C~ 2~6~ .021 201 2o ....................... ; ..... -{~-~ ..... ~¥11 ............. ~-~'t -" ~'~ ...... .................... f .......a"~-~ TOi ......... ~'b~ ......... ~5-~ ......~ ...... f 12~o.o ~ 9~.oI a~e. 4: ' ~9a-' : .......... ..... ..... ...... ....... ........ ............. a',I ........... ,'o! ....... ' ...... 4'~-~8d'~? ......... ~' ..... ~;.'if'~- -' ~'~ ..... '4~'4 .... ~'~'6:'" 2~' 5: ":o2: 2 o! 2 c' ........................ ~ ..... 3~'~8~ --'-~-~ ...... ~'I ........ ~"~T .......... ~.~; ..... 3'~: ' '23/~; ..... -~ ~; '2 O' 2 C ........ ~ ............... ~ . ~ , 122~0 0 ~6 3187~ ~74~ ~2; 5181 7i 23~5~ -02: 20~ 20 '' ~2~T ....... ~8; 3~g~ 8~70 --527.1 32~3 23~.8 ...... :~2: .... 20'; 20; - ,, ~ .......................................................................................... ~ ............... ........ ; ...... i~' ...... ~-~ .... 525.~--~31 ~[ ' 52502/ Z2~2~ ~2~ 20, 20' : 12a~.~: --- ~.~ .... ~{1-I' -~.OI 618-_5[ - '-32/~.4[ 2279.2'~- -'~3 2~ 2 0 2 C ' ': ¢~.c.; ~.~ ..... ~.h .... ~.d - .......... T .... ~-2~ ..... ~T,~,,. ~'--~'~ '--- ' ~5 4~ ' ' '~'~ 9[ .... ~ ~ 2242' G~ -D 2' 2 C ........................... , ........... ......... ...... . ...... :__~ ............. ~ .................... 2 0 ................................... % ................. ~ ...... l : ~ ...... ~ ....... .......................... ~ ...... ~61 ....... =~--~'~%---~3T--"~-~ .... ~4~'~'-~T .... )11o.'~: ............ :o 2: ' 2 c; 2.0 ................................................... ~ .............. ~ .............. J ............ ; ............. ......... -f ,-~¢d-o~ ......... ~¢ '~'.~ ~'~,~' ~1 ~! "] .... I~ ~-- '~¥ '- '884~ .... ~23 ....... ~i'~' 21196. -02' 201 20 ~ ~2e~'gT .... ~-~ ........... ~fb-- '-~4-' ' e'~i-~- --'~i8:~7 -~:~- '- :d2' 2.oi' z'o .............. t .... ~ ~.-8~ .... -~: '5'2'~: ~4~ ...... ~r? ......... a:~i-~-; ..... 2~ E ......... :b'2- .... Z':b]" z'o : ~ 2~.0] ~0~ ~2~.2~ 88440: ~98: ~5~8 ~710 -02 20~ 20 4 ~ . _. , ........ ; ..... : ............. ~ . i 12720 Oj . ~.0 328.8 8844.0 ' ~2750.0t ~.9: 3~.4 88440- ~77' ~8~i ~9: 42; 20~ 20 ' ' [ ,2e~O'O~ ' "~.~; ' "5-~-'5- - ~-' ~7~- ~ ~ ~ 2'.'~/ ......... 2'5 ~ .......................... ~ .............. T ...... ~ .............. . ............ ~ .... '' .............. 12~0~P ...................... ~1 ~32 3[--' ....... ~u¢=f .............................. 1171 t; 3749 ~ l~B7t -02~-' n", O ',. 0 .................................12~.0, ; ............... ~6i 4 ................. 332.9~ ~ ........... ~44.7~ ............ 1 lgg. SiF ............ ~T75. F. :"'~" .......... l~..g~ ~' .......................... -02~ 2 9 2~ 0 ' .............................. ~ ........... % ........................................ , ............. · ........... i ...............ff ................. ' ' ...... 4 ; ............ 4.. : / . ............................ l~.'O'~' ' ' e~:~ ......... ~7~ .....~/ ..... 13110.0 ~ 4] ~B 4 ~46 3! 136~ ~ 3; 1875 9i -0 2 2 O! 2 0 .......... , .......... ~ ................................................ L ............ ~ .................................... L ........... : .............. ; 13!70.~ 89.3 ~37 8 8~7 O: 1422 7 ~ 6' 1~2 5 0.2 20[ 2 0 ~ 13~.0i 8S2~ 3~2 ~474; 14~.1' ~1 3: 1841 2 ~.2' 20.l 2.0 ............. t .... ~3~ .... ~¢~ .... ~-~ ...... ~'~e~ .... i~-~' ......~7' --3e~ .... o~' ' ~ o~ ' : o ............................. ~';;-~'~.-~ ....... ~-~: ........ :~Tz ...... ~q~-~i ....... . ,~.o: 8e.~i~ ......... ..... ~6 ~ ........ ~4~.b'[~ ..... .......................... f~- ....... ~'~-~:~ ..... ie6dO ....... -0.:' ' 2 o~ 2.u i 133~.0 890~ 3~6 ~3! ' I" -:f~O ........ ~.0~ ~:.~: ~e8[ i IIII IIIII II I I I IIIIIILU ...... J IIIII DlULE . I III ... II I I I ARCO ALASKA INC. IIIIIIIIII1.1 J .Ill Iiiiiiiii IIIll I I NORTH REF. TO GRIO ti ,.. I MaO (,27'.1) 333STOG 333ORGR ARCO ALASKA INC. 420O 36OO iiI~IP 2 D128'Y100 'Pr 11}0' KOP 3 2100 1800 Vertical Section Scale I inch ' 300 ft 6 6 2 I NtS and ERV Scale 1 Inch · 600 ff ,, ,t tilt i ; 6TO FIL~ NAME: C ~t~RCOALK~,~-~33.!,&l DiN= DRAWN E3Y BIM~, HADIPDTRO DATE · FEB 17. PLANE OF VERT SECTn 313.74° RELATIVE TO GRID NORTH ,,, . . . *--,I O) C T Drilling Wellhead Detail ~ CT Injector Head .__.~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure O.e 7" W,^ Qu~ck I I Connect 7-1/16", SM [tam lypa Dual Combination Gutter/Blin0s Gate BOPE Slip ~ipe rams Flanged Fire Resistant Manual Valve Kelly Hose 1o Dual \ Manual Valves Drilling spool 7-1/1 ChokeManifold~, by 7-1/16", 5M Ram Type Dual Gate BOPE 2" Pump-In Manual over Hydraulic ~ Pipe/Slip Rams (5.5") Manual Master Valve Hanger Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree 9-5/8" Annulus 13-3/8" Annulus Shop Fuel Boilers Water 6O/4O I Trplx Mud Pump Room ExL Pipe rack Dowell Drilling Equipment Trailer Fire Ext. Preferred Major Equipment Layout for CT Drilling in DS 3-33A Ext. WELL PERMIT CHECKLISToo. Y ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS 15. Surface casing protects all known USDWs ......... Y i~~- 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ NJ 19. Casing designs adequate for C, T, B & permafrost .... ~ 20. Adequate tankage or reserve pit ............. (~ t 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N ~%_, p;~~ 22. Adequate wellbore separation proposed ......... (~_~ N . ~Zk 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to~~ ...... psig.~_ N ~~....~~ ' 27. Choke manifold complies w/API ~-53 (May 84) ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ........ ./~ N 34. Contact name/phone for weekly progress reports . . . //. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Aug 08 13:16:18 1997 Reel Header Service ns/ne ............. LISTPE Date ..................... 97/08/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Date 61-o3--Ol MWD RUN 2 AK-MW-70108 A. WORTHINGT BASS/KARA RECEIVED AUG 1 $ 1997 AiWa Oit & Gas Cons. Commission Anchorage 03-33A 500292114201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 08-AUG-97 MWD RUN 5 MWD RUN 6 AK-MW-7 0108 AK-MW-7 0108 A. WORTHINGT A. WORTHINGT BASS/KARA BASS/KARA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-70108 A. WORTHINGT BASS/KARA MWD RUN 8 MWD RUN 9 AK-MW-70108 AK-MW-70108 A. WORTHINGT A. WORTHINGT BASS/KARA BASS/KARA JOB NUbfBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 AK-MW-70108 A. WORTHINGT BASS/KARA MWD RUN 11 AK-MW-70108 A. WORTHINGT BASS/HUPP MWD RUN 12 AK-MW-70108 A. WORTHINGT BASS/HUPP JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 13 AK-MW-70108 A. WORTHINGT BASS/HUPP MWD RUN 14 AK-MW-70108 A. WORTHINGT BASS/HUPP 11 10N 15E 215 821 62.00 .00 .00 SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... 'Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 2506.0 2ND STRING 9~625 10374.0 3RD STRING 7.000 10406.0 PRODUCTION STRING 3.690 13150.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1,3, AND 4 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THESE RUNS CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 4. MWD RUNS 2,5,6,7,8,9,10,11,12,13, AND 14 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 5. ONLY SMOOTHED RATE OF PENETRATION (SROP) DATA UTILIZED FROM MWD RUNS 2 AND 5. 6. NO GAMMA RAY DATA (SGRD) AVAILABLE UNTIL 10422'MD, 8691'SSTVD. 7. DEPTH SHIFTING.CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DOUG KNOCK OF ARCO ALASKA, INC. ON JULY 24, 1997. 8. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13150'MD, 8840'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 10402.0 13149.5 GR 10421 . 5 13122 . 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 10402.0 10413.0 MWD 5 10413.0 10465.0 MWD 6 10465.0 10646.0 MWD 7 10646.0 10792.0 MWD 8 10792.0 10836.0 MWD 9 10836.0 10894.0 MWD 10 10894.0 11196.0 MWD 11 11196.0 11642.0 MWD 12 11642.0 12335.0 MWD 13 12335.0 12714.0 MWD 14 12714.0 13150.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10402 13149.5 11775.8 5496 10402 Last Reading 13149.5 ROP 0.68 2869.31 113.775 5496 GR 19.26 158.74 35.2819 5403 10402 10421.5 13149.5 13122.5 First Reading For Entire File .......... 10402 Last Reading For Entire File ........... 13149.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10402 . 0 10413 . 0 $ LOG HEADER DATA DATE LOGGED: 20-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10413.0 TOP LOG INTERVAL (FT) : 10402.0 BOTTOM LOG INTERVAL (FT): 10413.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 2.6 MAXIMUM ANGLE: 6.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE NGP 277 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.700 3.7 Sea-Water .00 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 77.3 First Name Min Max Mean Nsam Reading DEPT 10402 10413 10407.5 23 10402 ROP 0.68 651.46 123.952 23 10402 Last Reading 10413 10413 First Reading For Entire File .......... 10402 Last Reading For Entire File ........... 10413 File Trailer Service name ............. STSLIB.002 Service Sub Level Name;.. Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10411.0 10465.0 $ LOG HEADER DATA DATE LOGGED: 21-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10465.0 TOP LOG INTERVAL (FT) : 10413.0 BOTTOM LOG INTERVAL (FT): 10465.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 10.2 MAXIMUM ANGLE: 12.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): TOOL NUMBER NGP 277 3.700 3.7 FLO-PRO 8.80 .0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHl~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.4 6.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 65.6 First Name Min Max Mean Nsam Reading DEPT 10411 10465 10438 109 10411 ROP 32.5 2505.95 160.808 109 10411 Last Reading 10465 10465 First Reading For Entire File .......... 10411 Last Reading For Entire File ........... 10465 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10421 . 5 10618 . 5 ROP 10464 . 0 10646 . 0 $ LOG HEADER DATA DATE LOGGED: 21-APR- 97 ~ SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10646.0 TOP LOG INTERVAL (FT): 10465.0 BOTTOM LOG INTERVAL (FT): 10646.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 13.8 MAXIMUM ANGLE: 56.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE NGP 277 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.700 DRILLER' S CASING DEPTH (FT): 3.7 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G) : 8.80 MUD VISCOSITY (S): .0 MUD PH: 9.4 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 60.9 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY ( HZ ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10421.5 10646 10533.8 450 10421.5 GR 20.86 158.74 53.851 395 10421.5 ROP 33.91 531.26 117.096 365 10464 Last Reading 10646 10618.5 10646 First Reading For Entire File .......... 10421.5 Last Reading For Entire File ........... 10646 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10618 . 0 10768 . 0 ROP 10646 . 0 10792 . 0 $ LOG HEADER DATA DATE LOGGED: 22-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10792.0 TOP LOG INTERVAL (FT) : 10646.0 BOTTOM LOG INTERVAL (FT): 10792.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 83 . 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NK3MBER NGP 277 BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.700 3.7 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.3 5.9 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .3 # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10618 10792 10705 349 10618 GR 20.34 100.01 31.0349 301 10618 ROP 15.98 2932.62 165.007 293 10646 Last Reading 10792 10768 10792 First Reading For Entire File .......... 10618 Last Reading For Entire File ........... 10792 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10766.0 ReP 10791.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMLTMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 10809.5 10835.5 22-APR-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 10836.0 10792.0 10836.0 87.2 92.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP 277 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3.7OO 3.7 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 FLO-PRO 8.80 .0 9.3 5.9 .000 .000 .000 .000 60.9 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10766 10835.5 10800.8 140 10766 GR 25.87 140.73 80.3951 88 10766 ROP 4.54 500 85.0211 90 10791 Last Reading 10835.5 10809.5 10835.5 First Reading For Entire File .......... 10766 Last Reading For Entire File ........... 10835.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Nu/mber ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SIH4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10808 . 0 10869 . 5 ROP 10835.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ 10894.0 NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 23-APR-97 MSC V. 1.32 NGP; SPC V. MEMORY 10894.0 10836.0 10894.0 5.74 93.8 97.1 TOOL NUMBER NGP 277 3.690 3.7 FLO-PRO 8.80 .0 9.3 5.9 .000 .000 .000 .000 60.9 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10808 10894 10851 173 10808 GR 27 153.53 83.0378 124 10808 ROP 9.51 650.54 77.0176 119 10835 Last Reading 10894 10869.5 10894 First Reading For Entire File .......... 10808 Last Reading For Entire File ........... 10894 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10869.0 11169.0 ROP 10894.0 11196.0 $ LOG HEADER DATA DATE LOGGED: 23-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OH/dM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 NGP; SPC V. 5.74 MEMORY 11196.0 10894.0 11196.0 97.8 100.3 TOOL NUMBER NGP 277 3.690 3.7 FLO-PRO 8.80 .0 9.2 5.6 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 AAPI 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 63.3 Name Min Max Mean DEPT 10869 11196 11032.5 GR 20.15 155.33 36.3614 ROP 15.93 154.81 84.4592 Nsa/n 655 601 605 First Reading 10869 10869 10894 Last Reading 11196 11169 11196 First Reading For Entire File .......... 10869 Last Reading For Entire File ........... 11196 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER F I LE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11169 . 0 11614 . 5 ROP 11195 . 0 11642 . 0 $ LOG HEADER DATA DATE LOGGED: 24-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11642 o 0 TOP LOG INTERVAL (FT) : 11196.0 BOTTOM LOG INTERVAL (FT): 11642.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMtTMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 89.1 95.5 TOOL NUMBER NGP 198 3.690 3.7 FLO-PRO 8.90 .0 9.2 5.3 .000 .000 .000 .000 63.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11169 11642 11405.5 947 11169 GR 20.23 61.29 29.6679 892 11169 ROP 20.44 1517.06 140.816 895 11195 Last Reading 11642 11614.5 11642 First Reading For Entire File .......... 11169 Last Reading For Entire File ........... 11642 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE lqUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ArgMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11614.0 12308.0 ROP 11641.0 12335.0 $ LOG HEADER DATA DATE LOGGED: 26-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWN-HOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12335.0 TOP LOG INTERVAL (FT): 11642.0 BOTTOM LOG INTERVAL (FT): 12335.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE ~TOOL TYPE TOOL NUMBER NGP NATURAL GAlVSViA PROBE NGP 277 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHFiM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.690 3.7 FLO-PRO 8.90 .0 9.1 5.2 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 68.0 First Name Min Max Mean Nsam Reading DEPT 11614 12335 11974.5 1443 11614 GR 19.26 86.52 28.8279 1389 11614 ROP 20.72 830.29 102.868 1389 11641 Last Reading 12335 12308 12335 First Reading For Entire File .......... 11614 Last Reading For Entire File ........... 12335 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE ~ER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12306.0 12687 . 5 ROP 12334 . 0 12714 . 0 $ LOG HEADER DATA DATE LOGGED: 26-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12714.0 TOP LOG INTERVAL (FT): 12335.0 BOTTOM LOG INTERVAL (FT): 12714.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 96.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NIIMBER NGP NATURAL GAMMA PROBE NGP 277 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.690 DRILLER' S CASING DEPTH (FT): 3 .7 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.70 .0 .1 6.9 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 63.3 First Name Min Max Mean Nsam Reading DEPT 12306 12714 12510 817 12306 GR 21.45 56.54 28.7207 764 12306 ROP 41.63 1685.08 128.028 761 12334 Last Reading 12714 12687.5 12714 First Reading For Entire File .......... 12306 Last Reading For Entire File ........... 12714 File Trailer Service name ............. STSLIB.011 Service Sub Level Ns_me... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12686.0 ROP 12714.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (FiE14ORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIFIUMANGLE: MAXIFIUMANGLE: STOP DEPTH 13122.5 13149.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BoREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MF_JkSURED TEMPERATURE (MT) : 28 -APR- 97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 13150.0 12714.0 13150.0 86.3 92.6 TOOL NUMBER NGP 277 3.690 3.7 FLO-PRO 8.70 .0 .1 6.9 .000 MUD AT MAX 'CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 63.3 First Name Min Max Mean Nsam Reading DEPT 12686 13149.5 12917.8 928 12686 GR 22.05 115.7 38.1035 874 12686 ROP 6.22 1934.13 120.132 872 12714 Last Reading 13149.5 13122.5 13149.5 First Reading For Entire File .......... 12686 Last Reading For Entire File ........... 13149.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/08 Origin ................... STS Tape Name ............ - .... UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNK/qOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/08/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File