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Home My WebLink About203-136 .. ) Image hbject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - t3 ro Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1III11I1I1111111111 RE?AN \If'Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. / o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: o Other:: BY: ~_CMaria ) Date: J~ Cf DS- .J /5/ vvt, 1111111111111111111 Project Proofing BY: ~arj;~ ) Scanning Preparation BY: ÇMariW Date: '~C' / Ó ~ , I ,2. X 30 =. (p () Date: ,¡ ~. 0[ {} 5' /5/ Vl1P + J 3 = TOTAL PAGES 1f3 (Count does not include cover s"e~) ~J1 A ,() /5/ r v~J Production Scanning Stage 1 Page Count from Scanned File: 7 Lf (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY c: ~) Date: ,a- 'c¡ /Os-' Stage 1 If NO in stage 1 page(s) discrepancies were found: YES 1111111111111111111 NO vvtP /5/ NO BY: Maria Date: /5/ Scanning is complete at this point unless rescanning is required. 11II -11111 ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • ~~ ~- ~.,. MICROFILMED 03/01/2008 DO NOT PLACE w,~" ~~ - ~= ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc RECEIVED /2 ,- 130 ~{)J o NO. 3843 Sc~lunIbl..gør dUN 1 4 Z006 Alaska Data & Consulting SerA/llska Oil &. Gas ConS. ('Á)mmission 2525 Gambell Street, Suite 400 AfI('~ Anchorage, AK 99503·2838 ATTN: Beth ~.-,,- Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 JUN Field: Prudhoe Bay WI! CI CD L D "f D t BL J b# e 0 00 eSCflD110n ae oar 15·208 10669980 MCNL 10/12/03 1 1 G·32A 10942216 MCNL 05/31/05 1 1 NK-65A 11221850 RST 02/23/06 1 1 L2-28 . N/A RST 11/04/05 1 1 L2-28 . 11225951 RST 04/07/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulllng ServIces 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,0 (1 c" Q)l,,-" G / I'll rh 06/09/06 e e e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 Joll3 RE: MWD Formation Evaluation Logs l5-20B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 IS-20B: LAS Data & DigitalLog Images: 50-029-21133-02 d03-1 ?)(¿¡ 1 CD Rom ~ YJ\ 'Jg \ Olp " J \ /) cJ. ( J)f.... DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031360 Well Name/No. PRUDHOE BAY UNIT 15-20B Operator BP EXPLORATION (ALASKA) INC f~ I ~~) AOÚ ) API No. 50-029-21133-02-00 MD 12021 / TVD 8906 /" Completion Date 8/24/2003 /' Completion Status 1-01L Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, DEN, NEU Well Log Information: Logl Electr Data Digital Dataset Type Med/Fnnt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH I Start Stop CH .~ Received Comments ("'ED D Las 12208 I nd uction/Resistivity 7717 11960 Open 1 0/1 0/2003 GR, EWR4, CNP, SLD, ROP JD 0 Las 12208 Neutron 7717 11960 Open 1 0/1 0/2003 GR, EWR4, CNP, SLD, ROP ED D Las 12208 Sonic 7717 11 960 Open 1 0/1 0/2003 GR, EWR4, cNP, SLD, ROP .lED 0 Las 12208 Rate of Penetration 7717 11960 Open 10/10/2003 GR, EWR4, CNP, SLD, ROP - f Rpt )\(- I nd uction/Resistivity 7717 11960 Open 10/10/2003 GR, EWR4, CNP, SLD, .~\.\i ROP Rpt ~ \.~ \~ ~î Neutron 7717 11960 Open 10/10/2003 GR, EWR4, cNP, SLD, ROP Rpt l \ Sonic 7717 11960 Open 10/10/2003 GR, EWR4, CNP, SLD, \r~ ROP - Rpt Rate of Penetration 7717 11960 Open 1 0/1 0/2003 GR, EWR4, CNP, SLD, ROP a,.ÆD D .pm. A- ) t., Directional Survey 7715 12021 9/24/2003 ~ AJirectional Survey 7715 12021 9/24/2003 (!;;. og Production 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem GRlCCUcNUPresslTemp/ J4 Spin Casing collar locator 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem GRlCCUcNUPresslTemp/ Spin DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031360 Well Name/No. PRUDHOE BAY UNIT 15-20B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21133-02-00 MD 12021 TVD 8906 Completion Date 8/24/2003 Completion Status 1-01L Current Status P&A Ulc N Lóg Neutron 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem I I GRlCCUCNUPressfTemp/ I ( Spin Log Pressure 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem GRlCCUCNUPressfTemp/ ~ Spin Temperature 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem GRlcCUcNUPressfTemp/ Spin ;(09 Spinner 2 Blu 7860 11918 Case 12/22/2003 Production Profile, Mem ~- GRlccUcNUPressfTemp/ Spin Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? V / N Daily History Received? &/N GIN Formation Tops Analysis Received? Y/N --- Comments: --~,. Compliance Reviewed By: ~ Date: )~~s '\ STATE OF ALASKA ) ALASKA v.t AND GAS CONSERVATION COMMh.lSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG SfP 1 2005 ¿;;~ 1a. Well Status: 0 Oil 0 Gas 0 Plugged a 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: 1408' SNL, 3946' WEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 2170' SNL, 4437' WEL, SEC. 22, T11 N, R14E, UM Total Depth: 4393' SNL, 3319' WEL, SEC. 22, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-__ 677267 y- 5960103 Zone- ASP4 TPI: x- 676799 y- 5959331 Zone- ASP4 Total Depth: x- 677973 y- 5957135 Zone- ASP4 18. Directional Survey 0 Yes a No 21. Logs Run: DIR, GR, RES, DEN, NEU 22. Zero Other 5. Date Camp., Susp., or Aband. 07/09/2005 / 6. Date Spudded 8/14/2003 7. Date T.D. Reached 8/21/2003 8. KB Elevation (ft): 57.83' 9. Plug Back Depth (MD+TVD) 11083 + 8871 10. Total Depth (MD+TVD) 12021 + 8906 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1 b. Well Class,::""":"il':";r:'( a Developme~t· t:J "E~þloratory o Stratigraphic 0 Service 12. Permit to Drill Number 203-136 305-150 13. API Number 50-029-21133-02-00 14. Well Name and Number: PBU 15-20B 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) i ,II '. (JA$ìNq:II,I...·I.,,';.', :",.,..'.; ..'.,;'.,' ,,".' ¡.,. ."",~,,¡,' ".1., 1'"" "SIZ¡:".,.li' 'I' I W' . 'T:"Þ~R' :FT,'.,:, ," 11", II'" 1,1,. ""I, ,'I' "" ,,,,,,,,,,,r,o ':,1 20" 91.5# 13-3/8" 72# 9-5/8" 4 7# 7" 26# 4-1/2" 12.6# CASING, LINER AND CEMENTING RECORD ,;I'S~r;fI~~:I'eER1;I'I:'~Ø:' ,'$E1i:rIt'J~I1)~~1i~I,:tYPI .!;:i¡:;:~ºLê.:I' ":1 :",;:iWQÞ:~I::;I¡:: IIBÖ:r1iCt>M' "II" :;:]Öpi::'II: ·BO:ntdM,il ,llllli:I,;;$IZE¡::'" 11,. Surface 112' Surface 112' 30" Surface 2532' Surface 2532' 17-1/2" Surface 7727' Surface 5993' 12-1/4" 7558' 8275' 5909' 6266' 8-1/2" 8120' 12021' 6188' 8906' 6-1/8" H-40 L-80 L-80 L-80 L-80 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not On Production Date of Test Hours Tested ':I~MOµN¡r;', '·;¡'::I::RÜ~á~bl',:1 2000# Poleset 1750 sx PF 'E', 400 sx PF 'C' 500 sx Class 'G', 276 sx PF 'C' 182 sx Class 'G' 454 sx Class 'G' 24;;:,1 " ". ':i,;,i': Tðå'NG lå~GbRDli: SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 8121' PACKER SET (MD) 8064' TVD :25. ,"··.1 ,~6IQ, FRÅê+,Ù~E:'CEMENJ'sðÚÈEZé,'ETP.:, ,I". ", "~, , '1;",1'," ':... ,,' ',' ,,:,'," :":. ''',"~ :: >' ,':.', ::', :.' " 'I, ' , ' I '" ;, ':, ',' " "",",:, ': : :'" ,',,' :', " , , ,",' ~> ,. .: I' ,I DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8575' Set Bridge Plug 8441' Set Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ~ Oll-BSl Press. 24-HoUR RATE""'" GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS 8Fl SEP 20 200S '. ,. "",., None : .7.,9.~~~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE OR\G\NAL '~ 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". Sag River 8272 8249' None Shublik A 8315' 8289' Shublik 8 8346' 8317' Shublik C 8362' 8332' Sadlerochit 8396' 8361' Top CGL 8610' 8509' Base CGL 8730' 8574' 23S8 8870' 8636' Zone 18 9416' 8799' Zone 1 A 9595' 8838' 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. ./" f\: /1 ~L 11 A /1- Teme Hubble ~ ~ IVUJt.. ~~ Title Technical Assistant PBU 15-208 203-136 305-150 Prepared By Name/Number: Well Number Drilling Engineer: Permit No. / Approval No. Date 09-l9·ós Terrie Hubble, 564-4628 Josh Chebul, 564-5220 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGcC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form 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 '" ') ) 15-20C Accept: 07/31/05 Prudhoe Bay Unit Spud: 08/02/05 50-029-21133-03-00 Release: 08/14/05 205-093 Nordic #1 PRE-RIG WORK OS/23/05 DRIFT WI 33/8" DUMMY GUN TO DEV. AT 8934' SLM. CALIPER LINER AND TUBING FROM 8930' TO SURFACE. DUMMIED OFF STA'S 2 & 3. 07/01/05 RUN 10' X 3.70" DUMMY WHIPSTOCK, SD AT 8378' SLM. RUN 3.70" CENT, BRUSH, 3.5" GAUGE RING TO 8600' SLM. RUN 14' X 3.68" WEATHERFORD WHIPSTOCK, DRIFT 8600' SLM. 07/09/05 DEPTH CORRELATED TO PDS MEMORY MULTI-FINGER CALIPER JOINT REPORT DATED 23 MAY 2005. HALLIBURTON EZSV BRIDGE PLUG SET AT 8575'. 07/21/05 ATTEMPTED TO SET WHIPSTOCK BUT COULD NOT GET PAST 8480' DUE TO TIGHT SPOT. ABORTED JOB FOR NOW AND TURNED OVER TO SLlCKLlNE TO RE-DRIFT. 07/23/05 TO TOP OF EZ DRILL PKR AT 8563' SLM. DRIFTED WI 21' 3.70" DMY WHIPSTOCK. UNABLE TO GET PAST 8340' SLM. DRIFTED WI 14' 3.68 DUMMY WHIPSTOCK TO TOP OF EZ DRILL PKR AT 8563' SLM, NO PROBLEMS. DRIFTED WI 10' 3.70 DUMMY WHIPSTOCK. UNABLE TO GET PAST 8385' SLM. 07/24/05 SET 4.5" WEATHERFORD WHIPSTOCK. SET TOP OF WHIPSTOCK TRAY AT 8441', BOTTOM OF WHIPSTOCK AT 8454.2', PIP TAGS AT 8449.9'. ANGLE AT SETTING WAS 8.6 DEGREES FROM THE LOW SIDE OF THE HOLE. JOB COMPLETE. ) ') Page 1 .. BPEXPLORA TION OperatiønsSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 7/31/2005 17:00 - 18:00 1.00 MOB P PRE 18:30 - 18:30 24.00 MOB P PRE 18:30 - 19:00 0.50 MOB P PRE 19:00 - 22:00 3.00 MOB N WAIT PRE 22:00 - 00:00 2.00 RIGU P PRE 8/1/2005 00:00 - 03:30 3.50 RIGU P PRE 03:30 - 13:00 9.50 BOPSUP P PRE 13:00 - 15:30 2.50 BOPSUPP PRE 15:30 - 21 :00 5.50 RIGU P PRE 21 :00 - 22:00 1.00 STWHIP N RREP WEXIT 22:00 - 22:15 0.25 STWHIP P WEXIT 22: 15 - 00:00 1.75 STWHIP P WEXIT 8/2/2005 00:00 - 00: 15 0.25 STWHIP P WEXIT 00: 15 - 00:45 0.50 STWHIP P WEXIT 00:45 - 01 :15 0.50 STWHIP P WEXIT 01:15-07:30 6.25 STWHIP P WEXIT Start: 7/31/2005 Rig Release: Rig Number: N1 Spud Date: 8/1/1 984 End: Description of Operations Rig released from summer maintence on OS 15 @ 05:00Hrs on 7/31/2005. Prep to move rig. Jack-up rig. Secure maintence location. Clean location & fold herculite. Held pre-move safety meeting with crew. Move rig to OS 15-20. Position rig in front of 15-20. Install dikes around tree & lay herculite in front of well. Confirm WHP of 0 psi on 15-20. Waiting on Veco Well Support to install working platform. Call was made at 0900 hrs by Jerry Middendorf to request platform. No return calls to TP, check with Veco at 1600 hrs and left message. Check at 1800 hrs, Veco had no clue about it. Veco told co. man 2000 hrs was absolute latest. Finally showed up on location at 2200 hrs. Supposedly searching for platform that had been on location the entire time. BP was charged $2,222 (3 hrs standby) for wait on Veco Wells Support. Rig accepted at 2200 hrs on 7/31/05. NU BOPE, RU around rig. RU and make ready CT equipment. General RU around rig. BOP testing: function and pressure per well plan. 250 psi/3500 psi for Combis, VBR, blind/shear, packott. 250 psi/2500 psi for Hydril. Trouble getting to test due to misconfigured stack (at SLB shop). Trouble getting VBR to test due to unknown causes. BOPE test eventually good after work. SLB took 4 hrs of downtime on BOPE tests. Computer system work by SLB. Alarm system work by Nordic. Test hardline on inlet and outlet sides. Pump coil volume. Pull test CTC to 40K lb. Pump dart. RIH. Generator failure. RIH. Hit obstruction at 227'. Worked through it, samples at shakers showed fibrous material, nut hulls, most likely LcM from previous wells' lost circulation problems. RIH. RIH. Mill 3.725" XN Nipple out to 3.80". Minimal gas back from swap over. Max wellhead pressure: 103 psi. RIH. Tag WS pinch point at 8431'. Paint EOP flag at 8346.3'. Mill window 8431' - 8437.6'. Printed: 8/15/2005 1 :09: 14 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') Page 2 .. BP EXPLORATION Operations Summary Report 15-20 15-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 8/2/2005 01 :15 - 07:30 From - To Hours Task Code NPT Phase WEXIT Date 07:30 - 08:30 08:30 - 10:30 10:30 - 11 :30 11 :30 - 13:45 13:45 - 14:30 14:30 - 17:00 17:00 - 18:30 18:30 - 19:10 19:10 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 22:15 22: 15 - 23:00 23:00 - 00:00 8/3/2005 00:00 - 03:30 03:30 - 05:30 05:30 - 07:00 07:00 - 07:45 07:45 - 08:30 08:30 - 08:45 08:45 - 09:15 6.25 STWHIP P 1.00 STWHIP P 2.00 STWHIP N 1.00 STWHIP P 2.25 STWHIP P 0.75 STWHIP P 2.50 DRILL P 1.50 DRILL P 0.67 DRILL P 0.33 DRILL P 0.50 DRILL N 0.50 DRILL P 0.50 DRILL P 1.00 DRILL P 0.25 DRILL P 0.75 DRILL P 1.00 DRILL P 3.50 DRILL P 2.00 DRILL P 1.50 DRILL P 0.75 DRILL P 0.75 DRILL P 0.25 0.17 DRILL P 0.17 DRILL P 2.33 DRILL P P WEXIT WAIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 7/31/2005 Rig Release: Rig Number: N1 Spud Date: 8/1/1984 End: Description of Operations PU wt: 35.5K Ib, so wt: 30.5K lb. Differental pressure: 110 psi. Drill 10' rathole in formation. Work up and down through window 4 times to ensure clean window (1 dry run). Wait on vac trucks to haul mud from MI plant. Call put into central dispatch at 07:30 hrs. Swap well fluid from milling fluid to fresh new Flo-Pro mud. POOH with only 1 motor due to overheating generators. PJSM. UD window milling BHA#1 & inspect mills. Window mill gauge 3.78" go I 3.77" no-go. String mill gauge 3.79" go I 3.78" no-go. Wear on window mill face indicates center crossed the liner wall. PJSM. Rehead & M/U DS CTC. Pull & pressure test. M/U build section BHA #2 with 2.83deg bend motor, MWD/GR & rebuilt Bit #2 [HYC DS100 3-3/4" x 4-1/4" bicenter]. RIH with BHA #2. SHT. Continue RIH. Meanwhile Cat Rep work on gen set #2; Correct CTD by -3.6' @ the flag. RIH to 8390 Log down GR & tie into Geology PDC log. Added 5' to CTD. Orient TF to LS. ,"II: W.O. Cat Rep to fix Gen set #2. Test generator. Works- RIH. RIH wI Build BHA to 8441'. Toolface in close orientation- Drill ahead Drill ahead from 8441' to 8480' . Q= 2.55, 3460 press (2950 free spin), 2000 WOB, 51 '/hr. Attempt to orient assy to 160 RHS. Drill ahead from 8480' to 8493'. Re-attempt to orient BHA. Moved to 90 RHS Drill ahead and orient while drilling from 3' to 8526'. Q=2.55, 3100 press, 2900 WOB, 3' r. Drill ahead from 8526' to 8577' =2.55, 3100- 3300 press, 2800-4300 WOB, 15 - 30' . Varying ROP's due to conglomerate format" . Altering WOB and press as needed. Attempt to orie ild assy +/- 45 RHS. Work pipe through window an ack to TD. Put wt. on assy and drill attempt to establ" orientation while drilling. No go. No orientation and s ng problems. POOH. POOH wI CT and BHA. OOH. SIB injector. P/U & UO bit & orienter. Bit gauge 2/3/1. Check motor with wrenches - seemed OK. PJSM. RJU hydraulic cutter & cut 200' of CT for fatigue management. Rehead & M/U eTC. Pull test CTC to 35k & P/test to 3500psi - OK. M/U build section BHA #3 with 2.83deg bend motor, MWD/GR & rebuilt Bit #3 [HC RWD2ST 3-3/4" x 4-1/8" bicenter]. RIH with build BHA#3. Orient TF to LS. Run clean thru window & continue RIH to btm tagged @ 8580'. PUH to 8480' for GR tie-in log. Log up GR & tie-into RA PIP tag - 0' correction. Orient TF to 90R. Lost pump & TF roll over to LS. Reorient again - Getting intermittent 10deg clicks. Finally mange to Printed: 8/15/2005 1 :09: 14 PM Date: To: From: Subject: ) ) June 16, 2005 File ^ .. r: . /) Jane Williamson {VUIl ,M/ Prudhoe Well 15-20B- Plug Back in Preparation for SIT Attached are plots of production history and decline for the subject well. Prudhoe Well 15-20B was drilled as a horizontal sidetrack in Zone 1. The GOC was significantly deeper than anticipated and the well has produced (cyclic) at extremely high GORs (about 50-60,000 scf/STB) and low oil rate (30-200 BPD). There are very little black oil reserves within this well and the plugback should be approved. 100 50 10 5 0,5 0.1 0,05 0,01 SEP 2003 FEE PRUDHOE BAY, PRUDHOE OIL 15-20B , MAR APR MAY JUN JUL AUO SEP 2004 Date OCT NOV DEC Ga$ JAN FEB MAR APR :2005 ~-I ) ) 10000 1000 :g .0 500 .0 J! (II a::: Õ 100 50 PRUDHOE BAY, PRUDHOE OIL 5000 Phase Case Name b Di ql ti te End Rate Final Rate Cum. Prod. . Cum. Date Reserv es EUR Forecast Ended By Forecast Date 10 o 60 120 30 90 Cum Oil Prod, Mbbl : 10/31/2005 bblld MObl . 04130/2005 : 10.4606 MObl : 131.729 Mbbl . Rate 150 ~~å~Œ I ii" \ I - r ., I .1 I! , t· I. I [ ,,I u,/ 'L! I (m ìE 'I' II ; i :=:J ! I 'U' \0[1 ) 118~ i'll ¡'h' \ ,tñì i¡~/7,' ~c~' " rill \\' :! "I ". ~ \llW '. I." i, h,' .1 ! 'I. '. I I \ \ 'I' '\", ",,', I " I ill'", ii /,'\ '\)i!.\ /I\"~ bulb:: ÙcQ)UU!¡ J / / J 2tì ~3 -- 1~1 ~ FRANK H. MURKOWSKI, GOVERNOR '1 <.. AlASKA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 15-20B Sundry Number: 305-150 Dear Mr. Kolstad: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T.Seamount, Jr. Commissioner DA TED this/ i day of June, 2005 Ene I. (Jflt-~ -1/t7~(j5' }l.JGA-' I.plì~ /2-¡J() $ ì /J"b(/(,/S" ) STATE OF ALASKA cr:-) '{ , R",~ E',..... (~~ E,·"'. ~ ~\/E"""' r) ALASKA OIL AND GAS CONSERVATION COMMISSION c""l, '.":"~ . ..,,,.,,~,,. .' APPLICATION FOR SUNDRY APPROVAL JUN 15 2005 20 MC 25.280 A!aS~Œ Oil & Gas Com:;,. (;ormnission o Other tmctmH~ge o Re-Enter Suspended Well o Time Extension 1. Type of Request: II Abandon 0 Suspend 0 Operation Shutdown 0 Perforate .I o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: / iii Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 203-136 / 6. API Number: / 50- 029-21133-02-00 99519-6612 57.83' 9. Well Name and Number: PBU 15-20B ,,/ 8. Property Designation: ADL 028306 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ,'.,' ',', "'R· "R'6'dciKIT':~~'~·'E· 1;,'II:¡,:t¡,.~~IIi\I''r1¡'II'i''i'~¡'.'¿I;;!iÞ:''''W'¡~b~;'I'::;',11,':.1::':.·;:1.',',:.';1:.'::':1"1:1'1 :.,'1 'I' 1·!'}I:Ii'II' :1;11';;1":::: :,"'·""1,·1,,1,·.;1"'·','.11'. " ,.,1.:',..·.',',1,:, ,,:',,;'.',11.',1:,:,..'1"'.""".,·".:,',.1...':·,1...,·',','",:, ';',,',',:,··',1', ,.:1,':,.',':',,'1 :,·:,.,1".' " 1,,11',1' ,,:1 ,,'I'·' ~~I~~,I~I,I ~,I 'I"'~~" " "~,~,'I~~,,I'~'~I' I;,I,~',:; "~.'~:'~""9~,~:~:~~1~~~~'::';:11:,'1,1"11"1;1" ",II,I:'I,'"I,I,II:"',',I."¡'I,,I,: I' I',I~, 1 ",-"1' ,1'1.1,,111, 1",',1, :11':1,1:111'1' ,'1"1"1 :,1,1,," , Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11934 8901 11083 'MÒ'TVP: BUrst Junk (measured): None Collapse Total Depth MD (ft): 12021 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8906 ·,Length .. Size. Liner 112' 20" 112' 112' 1490 470 2532' 13-3/8" 2532' 2532' 4930 2670 7727' 9-5/8" 7727' 5993' 6870 4760 7717' 7" 7558' - 8275' 5909' - 6266' 7240 5410 3901' 4-1/2" 8120' - 12021' 6188' - 8906' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9740' - 10070' 7131' - 7335' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 8064' 2209' Tubing MD (ft): 8121' 12. Attachments: IBI Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: D Exploratory iii Development D Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Scott Kolstad Title CT Drilling Engineer Signature _ 2~ ~~/ June 22, 2005 Date: 15. Well Status after proposed work: DOil DGas D WAG D GINJ / D Plugged DWINJ iii Abandoned D WDSPL Phone 564-5347 Commission Use Only Contact Josh Chebul, 564-5220 Scott Kolstad, 564-5347 Prepared By Name/Number: Terrie Hubble, 564-4628 Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~S- -IS-o D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: ,(;) ~- 40·7 J RBDMS 8Fl JUN .2 (J [005 SUbsequentForm&e . ed: Approved By: Form 10-403 Re' 11/ 00 ORIGINAL COMMISSIONER APPROVED BY THE COMMISSION Date Cµ IS Submit In Duplicate ) ) JJ I To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Scott Kolstad/Josh Chebul CTD Engineer/CTD Intern Date: June 14, 2005 Re: Prep Prudhoe 15-20B for CTD sidetrack / Sundry approval is requested for well 15-20B. 15-20B is a Zone 1 horizontal GD sidetrack that was completed in August 2003. Because of a Zone 1 A underrun and a GOC significantly deeper than anticipated, the well quickly marginalized. It reached high GOR so adperfs were shot and a CIBP was set above the bottom perfs in an attempt to reduce gas production. The well is currently shut in and there are no other alternatives for gas shut / off for this well. 15-20B has been selected for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around July 10,2005. The sidetrack, 15-20C, will exit the existing 4 ~" liner from a whipstock in Zone 3 and will target Zone 1 sands. After a CIBP is set at ± 8,575'MD, a whipstock will be set at 8,525.' / Liner cement from the new sidetrack will serve as a second barrier to existing perfs. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. A Pre-Riø- Work 1) Complete integrity testing. /' 2) Set CIBP at ± 8,575'. Liner cement will act as a second barrier to existing perfs. 3) Set mechanical whipstock at 8,525' MD (8,459'TVD). 4) Remove flow line, remove well house, and level pad. The pre CTD work is slated to begin on June 22, 2005. Tk~ 10-- 40'S ~ fW'C/o....l . RiP Work 1) MIRV and test BOPE. 2) Mill window. 3) Drilllateral. 4) Run solid liner and cement. 5) Cleanout liner and MCNL/GR/CCL log. 6) Perforate liner. 7) Freeze protect well and RDMO. Post-Rip Work 1) Move well house, install production flow line. 2) Run GLVs. 3) Flowback well to separator. Scott Kolstad/Josh Chebul CTD Drilling Engineer/CTD Intern 564-5347 / 564-5220 CC: Well File Sondra Stewman/Terrie Hubble TREE = 5-1/8" FMC GEN 3 WèëtHEA 0 = FMC ÄCfUArÔR:;; .. ·····ÄXELSON ¡(B. ELEV; 71' BF.'ELEV; ? KOP= 8217' Max'A'ngle7M93@W412;' DatÜmMÖ;;' .... ...... .... "9420' batl.lmi\iÖ; . 8800' SS ) ~ 1 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 2532' Minimum ID = 3.725" @ 8108' 4-1/2" HES XN NIPPLE ÆRFORA TION SUMMARY REF LOG: A NGLE AT TOP ÆRF: 84 @ 9740' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2-7/8" 6 9740-9810 0 06/01/04 2-7/8" 6 9860 - 1 0070 0 06/01/04 2-1/2" 4 11250 - 11900 C 08/23/03 I 9-5/8" HES EZSV l-i 7758' I 95/8" CSG, 47#, L-80, 10 = 8.681" l-i 8536' SAFETY NO. ) ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. 15-208 ~ J ~I 2209' l-i 4-1/2" HES X NIP, 10 = 3.813" L ST MO ìVO 3 3190 3190 2 5709 5706 1 7437 7432 GAS LIFT MANDRELS OEV TYÆ VLV LATCH 2 KBG-2 OMY BK 4 KBG-2 OMY BK o KBG-2 OMY BK PORT OA TE o 08/29/03 o OS/23/05 o OS/23/05 z ~ 7557' l-i 9-5/8" X 7" BKR ZXP LNR TOP PKRI MILLOUT WINDOW 7727' - 7757' l-i 4-1/2" HES X NIP, 10 = 3.813" I 8064' l-i 7" X 4-1/2" BKR S-3 ÆRM PKR 1 8087' l-i 4-1/2" HES X NIP, 10 = 3.813" 1 l-i 4-1/2" HES XN NIP, 10 = 3.725" 1- 7" X 4-1/2" BKR ZXP LNR TOP PKR 1- 4-1/2" WLEG, 10 = 3.958" ~ I 2-3/8" LNR, 4.7#, L-80, .0387 bpf, 10 = 1.941" 1--1 10864' 4-1/2" TBG. 12.6#, L-80, .0152 bpf. ID = 3.958" 1--1 8120' 7" CSG, 26#, L-80, .0383 bpf. ID = 6.276" l-i I PBTD 1-1 11933' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 12021' DATE 1984 07/28/99 08/25/03 08/30/03 06/02/04 OS/23/05 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (15-20A) JLM/KK SIDETRACK (15-20B) JLJfTLH GL V C/O JLG/KAK ADÆRFS; SET CIBP KSB/PJC GL V C/O DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-20B ÆRMIT No: '2031360 API No: 50-029-21133-02 SEC 22, T11 N, R14E, 1408' FNL & 3946' FEL BP Exploration (Alaska) SAÆTY DIAGRAM. WElLBORE NOT SHOWN ON 13-3/8" CSG, 72#, L-80, Ð::;: 12.347" ~ 2532' I ~ J ..I 2209' 4-1/2" HES X NIP, ID::;: 3.813" I ST MD WO 3 3190 3190 2 5709 5706 1 7437 7432 GAS LIFT MANDRELS DE\! TYPE VLV LATCH :2 KBG-2 DOME BK 4 KBG-2 SO 5K o KBG-2 OMY BK PORT OA TE 16 08/29/03 20 08/29/03 o 08/23/03 81 PERFOAA 1101\1 SUMMARY REF LOG: ANGLE AT TOP PERF: 84 @ 9740' Note: Reter to Production DB tor historical perf data SIZE SPF INTERV AI... OpnlSqz OA TE 2-7/8" I) 9740 - 9810 2-7/8" 6 9860 - 10070 2-1/2" 4 11250 - 11900 I 9-5/8" HES EZSV 1557' 9-5/8" X 7" BKR ZXP LNR TOP PKR I MUOur WiNDOW 7727' - 7757' 95/8" CSG, 47#, 1...-80, ID::;: 8.681" , 8 8043' 8064' . 4-;'2" liES X NIP, 10::;: .3.813" I 7" S-3 4-1/2" HES X NIP, 10::;: 3.813" I 4-1/2" HES XN NIP, 10::;: 3.725" I , 2-3/8" LNR, 4,7#. L-80, .0387 bpt, 10::;: 1.941" 4-1/2" TaG, 12,6#, L-80, ,0152 bpt, ID::;: 3,958" I ~ 8108' 11933' 7" X 4-1/2" BKRZXPLnr Top Pkr WLEG, Ð ::;: 8120' I 7" CSG, 26#, L-80, .0383 bpf, ID::;: 6.276" 8215' I 4-1/2" LNR, 12.6#, L-60, .0152 bpf, ID::;: 3,958" 12021' DATE REV BY COMMENTS 1984 ORIGINAl... COMPLETION 07/28/99 1'18125/03 JLMIKK 08/30/03 JLJITLH GL V C/O 06102104 JLG/KAK SET ClBP DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 15-20B ÆRMITNo: 2031360 API No: 50-029-21133·02 see 22, T11 N, R14E, 1408' FNL & 3946' FEL SF Exploration (Alaska) ". 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 PluQ PerforationsŒ] Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate [K] 4. Current Well Class: Stimulate 0 OtherD WaiverD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 203-1360 Name: BP Exploration (Alaska), Inc. ExploratoryD Development Œ] 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 57.83 8. Property Designation: ADL-028306 11. Present Well Condition Summary: 6. API Number 50-029-21133-02-00 StratigraphicD ServiceD 9. Well Name and Number: 15-20B 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 12021 feet true vertical 8906.5 feet Effective Depth measured 111 05 feet true vertical 8873.5 feet Casing Conductor Production Surface Length 83 7701 2504 Perforation depth: Plugs (measured) Junk (measured) 111 05 None Size 20" 91.5# H-40 9-5/8" 47# L-80 13-3/8" 72# L-80 TVD 29.0 112.0 26.0 - 7722.0 28.0 - 2531.9 MD 29 112 26 - 7727 28 - 2532 Burst Collapse 470 4760 2670 1490 6870 4930 Measured depth: 9740 - 9810,9860 -10070 @ 23 RECEIVED AU G 1"7'2004 Alaska Oil & Gas Cans. Commission Anchorage True vertical depth: 8857.9 - 8863.7,8866.41 - 8870.58 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 8121 Packers & SSSV (type & measured depth): 4-1/2" Baker 5-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP Liner Top Packer @ 8064 @ 8127 @ 7566 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Prior to well operation: 545 28.2 0 945 Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations. X 2900 Tubing Pressure 1930 492 17.8 33 942 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development ŒI Service 0 WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Garry Catron Garry Catron A 1;1 Signature Form 10-404 Revised 4/2004 Title Production Technical Assistant ('A-Þ-~ Phone 564-4657 Date 8/13/04 OR1G1NAL RBDMS BFl AUG 1 8 200~ ) ) 15-208 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/31/04 Set CIBP @ 11105' 05/31/04 MIRU CTU # 9 - MU BOT/MHA/ PDS LOGGING TOOLS AND RIH. LOG FROM 11100' TO 9200' AT 40 FPM. LD LOGGING TOOLS, VERIFY DATA. GOOD DATA. MU AND RIH WITH BAKER CIBP. SET CIBP WITH CENTER OF ELEMENT AT 11083 CTMD. (TOP OF CIBP 11082 CTMD.) JOB IN PROGRESS. 06/01/04 Perforate 9740'-9810' 6 SPF, 9860'-10070' 6 SPF FLUIDS PUMPED BBLS 137 50/50 Methonal 215 Diesel 110 1 % KCL 28 Flo Pro 490 TOTAL Page 1 ~) TREE = 5-1/8" FMC GEN 3 WB..LHEAD = FMC ,.......... .............. ... .... ........."'....................................... ACfUATOR = AXELSON KB. ELEVn;;nuummuumnmm..mm---y:p Bi=:mËLËV',;;'·wuMnm ? K"ôÞ ^ ;.-mm..mmnn----··-,···"^~'·82-17'· 'Max"A¡'g~ = ·····g3"·@·1öLf1 il . bäfLiiTïMb =" . .......... . ····9lï":2Ö' 'DatÙiïïfVÖ';;;;~ .. 8SÖÖï'SS' ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2532' Minimum ID = 3.725" @ 8108' 4-1/2" HES XN NIPPLE PffiFORA TION SUMMA RY REF LOG: ANGLE AT TOP ÆRF: 84 @ 9740' f\bte: Refer to A"oduction DB for historical perf data SIZE SFf' INTffiVAL Opn/Sqz DA TE 2-7/8" 6 9740 - 9810 0 06/01/04 2-7/8" 6 9860 - 10070 0 06/01/04 2-1/2" 4 11250-11900 C 08/23/03 I 9-5/8" HES EZSV 1--1 7758' I 95/8" CSG, 47#, L-80, D = 8.681" 1-1 ~ 8536' ) 15-208 ~ J SAFETY NOTES: ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. 2209' 1-1 4-1/2" HESX NIP, ID=3.813" ~I L ST MD TVD 3 3190 3190 2 5709 5706 1 7437 7432 GAS LIFT MA.NDRB..S DBI 1Y PE VL V LA TOi 2 KBG-2 DOME BK 4 KBG-2 SO BK o KBG-2 DMY BK FDRT DATE 16 08/29/03 20 08/29/03 o 08/23/03 ~ 755T I~ 9-5/8" X 7" BKR ZXPLNRTOP FKR 1 Z' MLLOur WINDOW 7727 I - 7757' 1-1 4-1/2" HES X NIP, ID = 3.813" I 8064' H 7"X4-1/2"BKRS-3PffiMPKR 8087' 1-1 4-1/2" HES X NIP, D = 3.813" 1 1--1 4-1/2" HES XN NIP, ID = 3.725" I- 7" X 4-1/2" BKR ZXP LNR TOP FKR 1- 4-1/2"WLEG, ID = 3.958" 1 2-3/8" LNR, 4.7#, L-80, .0387 bpf, ID = 1.941" 1--1 10864' 4-112"lBG, 12.6#,L-80, .0152 bpf, ID =3.958" 1--1 8120' 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" H 8275' 1 FBTD H 11933' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12021' DATE 1984 07/28/99 08/25103 08130/03 06/02/04 REV BY COMrv'ENTS ORIGINAL COMPLETION SIDETRACK(15-20A) JLM/KK SIDETRACK (15-20B) JLJ/lLH GLV C/O JLG/KA K A œffiFS; SET aBP DATE RBI BY COMrv'ENfS PRLDI-OE BAY lJ\J1T WELL: 15-20B PffiMT f\b: 2031360 API f\b: 50-029-21133-02 SEC 22, T11 N, R14E. 1408' FNL & 3946' FEL BP Exploration (Alas ka) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/26/03 NO. 3050 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints CD ....."..,. A-02 i -1 \ ,()..:-s ~ 10674401 PSP LDL 11/24/03 1 D.S.06-02 . -61-. . 10674399 PSP PROD PROFILE 11/22/03 1 D.S. 07-04A ì¡Jl!-ow' 10687646 PRODUCTION PROFILE 09/19/03 1 J-06 '," 1-- 03(' ) 10563124 PRODUCTION PROFILE 11/10/03 1 16-21 ~-~I~ 10563125 PROD PROFILEIDEFT 11/11/03 1 N-18 ~:-3 -- I ~ 10674395 SBHP SURVEY 11/03/03 1 C-24 t IV ... I t...\ \ 10703945 LDL 10/30/03 1 R-19A i· :--I-=t \ 10703949 SBHP SURVEY 11/03/03 1 D.S. 15-01A ~ ~ ~~~ 10703946 SBHP SURVEY 10/31/03 1 2-40/S-22 í . ~ ,-l~ c.- 10703952 PROD PROFILE/DEFT 11/21/03 1 NK-62A ,99~ - oy 10572999 MEM INJECTION PROFILE 05/30/03 1 D.S.15-20B ~O-~-~~{ n 10669980 MEM PROD PROFILE 10/12/03 1 D.S.18-06A \ . T ~ 1- 10715358 MEM PPROF & IPROF 10/30/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ;~~~r=;~,S~~a~~~d'99508 ;:~: E C·E 1 \jE 0 Date Delivered: - , '100"'2. ,~', !:.., .) ') r v , ., \.' (- .-- - t, . '~_"¡"')'~'!I :<, ! ';;;1<;', l ;on5. vommission _.-";,;.~~:,:"..::.'"".~ ".-.;;. '-.:0 ~.w -...... """ /:.i1r;~~~1~ge -" Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~~ ' ~ Received by: ~"'\ ~ ."'f'...,. \---:>\.C ~~('J~ ) \ é9c13-- /3ÚJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7t11 Avenue, Suite 100 Anchorage, Alaska October 02, 2003 RE: MWD Formation Evaluation Logs I5-20B, AK-MW-2607108 1 LDWG formatted Disc with verification listing. API#: 50-029-21133-02 J 8 d(~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: .... 'C':'... Signed'W~ ~""'" ~'-~~ . ~·r R~~m~ , t . , ) STATE OF ALASKA .'. ALASK. . IL AND GAS CONSERVATION CO I\¡ \ ,~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ 1a. Well Status: iii Oil 0 Gas 0 Plugged ¡- 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: 1408' SNL, 3946' WEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 2170' SNL, 4437' WEL, SEC. 22, T11 N, R14E, UM Total Depth: 4393' SNL, 3319' WEL, SEC. 22, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 677267 y- 5960103 Zone- ASP4 TPI: x- --'676799- y_. 595933·1-" Zone-"'-ÃSp¡- Total Depth: x<:~~j~l~=~ y- _ 59~~!~_~.. Zone- ASP4-- 18. Directional Survey iii Yes 0 No 21. Logs Run: DIR, GR, RES, DEN, NEU 22. '·GÄSING SIZE 20" 13-3/8" 9-518" One Other 5. Date Comp., Susp., or Aband. 8/24/2003 6. Date Spudded 8/14/2003 7. Date T. D. Reached 8/21/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 57.83' 9. Plug Back Depth (MD+TVD) 11934' + 8901' Ft 10. Total Depth (MD+ TVD) 12021' + 8906' Ft 11. Depth where SSSV set (Nipple) 2209' MD 19. Water depth, if offshore N/A MSL CASING, LINER AND CEMENTING RECORD GRA¡:'E H-40 L-80 L-80 L-80 L-80 ,SETTING DEPTH ,T OF!, ' I, BOHOM Surface 112' Surface 2532' Surface 7727' 7558' 8275' 8120' 12021' I WT.PERFr. 91.5# 72# 47# 26# 12.6# 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 4spf MD TVD MD TVD 11250' - 11900' 8883' - 8899' 26. Date First Production: September 5, 2003 Date of Test Hours Tested PRODUCTION FOR 9/18/2003 3.2 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 793 24-HoUR RATE : HOLE' $IZ~ 30" 17-1/2" 12-1/4" 8-1/2" 6-1/8" 1 b. Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-136 13. API Number 50- 029-21133-02-00 14. Well Number PBU 15-20B 15. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT 'PULLED'; : I , .,"::' , , " .'. I 'OI:MENTING RE<:;,6~D 2000# Poleset 1750 sx PF 'E', 400 sx PF 'C' 500 sx Class 'G', 276 sx PF 'C' 182 sx Class 'G' 454 sx Class 'G' 24.' SIZE 4-1/2", 12.6#, L-80 , TÙ.BINGRËCO~b DEPTH SET (MD) 8121' PACKER SET (MD) 8064' 25. ACID; FRACJLlRE, CEMENJ SQUEEZE. 'ETe: DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL 1 ,473 OIL -BSL 11,048 GAs-McF 50,374 GAs-McF 377,805 WATER-BsL -0- WATER-BsL -0- CHOKE SIZE 86° OIL GRAVITY-API (CORR) GAS-OIL RATIO 34,187 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attacþsepar:qt!3 sheet, if necessary). Submit core chips; if none; state "none"."":, ~':,": '" .,.",ì-·' None ". -" $;¿~ 1{[0li:P ..Lì~.,..: Form 10-407 Revised 2/2003 ORIGINAL ·'·1....·,'.;" n 3 L:.¡~.. F "þ; ',\"...", ...'Ii'.......~' ..' CONTINUED ON REVERSE SIDE /' -, (gf Mm~S 8Ft "::SÈÞ ~ µ . ' 28. GEOLOGIC MARKEl ) 29. . 'fORMATION TESTS Include and briefly sUmmarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8272 8249' None Shublik A 8315' 8289' Shublik 8 8346' 8317' Shublik C 8362' 8332' Sadlerochit 8396' 8361' Top CGL 8610' 8509' Base CGL 8730' 8574' 23S8 8870' 8636' Zone 1 B 9416' 8799' Zone 1 A 9595' 8838' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I ~erebY certify that the forego", is ~rue and correct to the best of my knowledge. Signed Terrie Hubble ....-ø.ÅJ\t.£, ~itle Techniæl Assistant Date (f{.;l3 ·Ö3 PBU 15-208 203-136 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tir:pack, 564-4166 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form 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 2/2003 I " :\t "\L 1 \¡ L. (, I,. ¡ Legal Name: Common Name: Test Date 8/13/2003 8/17/2003 FIT FIT 15-20 15-208 Test Type Test Depth (TMD) 7,731.0 (ft) 8,275.0 (ft) BP.EXPLORATION Leàk-OffTestSlIrnrtlary Test Depth (TVD) 7,725.0 (ft) 8,250.0 (ft) AMW 10.00 (ppg) 8.50 (ppg) SurfélcePtessLlre 805 (psi) 429 (psi) l..eak··OffPressur~{I3HP) 4,818 (psi) 4,072 (psi) EMW 12.01 (ppg) 9.50 (ppg) '-' ..~. Printed: 8/25/2003 9:06:49 AM ') ') BPEXPLORATION Operations Summary Report Accept Rig For Well Work On DS 15-20B At 03:00 Hours 08/11/2003 Hold Pre-Spud Meeting With All Personal For Well Work On DS 15-20B Take On KCL Water In Mud Pits - Install Secondary Annulus Valve - Rig Up Circulating Lines - Record Pressure On Outter Annulus 0 At Psi. And Inner Annulus At 0 Psi. Rig Up DSM Lubricator Attempt To Pull BPV - Unable To Pass Thru Production Tree Hydraulic Accuator Valve - Function Accuator And Repeat Process Still No Good - Accuator Valve Not Opening All The Way - Rig Down Lubricator Remove Accuator Valve And Wing Valve From Production Tree - Nipple Up Swab Valve And Adapter Back To Otis Nipple On Master Valve Rig Up DSM Lubricator And Pull BPV - Rig Down Lubricator Circulate Out Freeze Protection Thru Choke Manifold At 5 BPM With 580 Psi. - Shut Down And Monitor Well 0 Psi. On Tubing And Inner Annulus Install Back Pressure Valve - Test From Below At 1,000 Psi. (Test Good) Blow Down Circulating Lines And Remove From Well Head - Clean Up Celler Area Nipple Down Production Tree And Tubing Head Adaptor - Inspect Hanger Lifting Threads 5 3/4" Left Hand ACME - Install Blanking Cap Nipple Up 13 5/8" 5M BOP Stack And Equipment Hold Pre-Job Safety Meeting - Install 3 1/2" Test Joint - Rig Up Testing Equipment - Test BOP And Related Equipment- Witness Of BOP Test Waived By AOGCC Inspector Lou Grimauldi - Test Annular, Upper Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, 3 1/2" Floor Safety Valve And Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Test LEL And H2S Gas Detectors - Perform Accumulator Test - Rig Down Testing Equipment DECaMP Pull Blanking Plug - Blow Down Choke Manifold And Kill Lines DECaMP Rig Up DSM Lubricator And Pull BPV - Rig Down Lubricator - Verify Tubing And Inner Annulus Pressures At 0 Psi. - Inspect Well Head For Plastic Insert Fittings (None On Well Head) - For Verification Pump Hydraulic Fluid Thru 9 5/8" Pack Off Void Area Appears No Plastic Pumped In Void - Material Removed Was Hydraulic Oil And Traces Of Grease - Test 9 5/8" Pack Off At 3,200 Psi. For 30 Minutes (Test Good) Lost Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 8/10/2003 21 :30 - 00:00 2.50 MOB P PRE 8/11/2003 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 03:30 0.50 WHSUR P DECaMP 03:30 - 04:30 1.00 WHSUR P DECaMP 04:30 - 06:00 1.50 WHSUR P DECaMP 06:00 - 07:30 1.50 WHSUR N SFAL DECaMP 07:30 - 08:00 0.50 WHSUR P DECaMP 08:00 - 11 :00 3.00 WHSUR P DECaMP 11:00-11:30 0.50 WHSUR P DECaMP 11:30-12:00 0.50 WHSUR P DECaMP 12:00 - 13:30 1.50 WHSUR P DECaMP 13:30 - 15:00 1.50 BOPSUR P DECaMP 15:00 - 18:30 3.50 BOPSUR P DECaMP 18:30 - 19:00 19:00 - 19:30 0.50 WHSUR P 0.50 WHSUR P Page1of9 Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Description of Operations Hold Pre-Job Safety Meeting Regarding Rig Move - Move Camp Unit And Mud Pit Pump Room Complex Stage On Pad - Move Sub Base From DS 15-08C To DS 15-20B In Line Well To Well Move - Position Sub Base Over Well Lay Out Herculite And Matting Boards. Held Pre-Job Safety Meeting Regarding Rig Moving Operation - Position Mud Pit Pump Room Complex - Berm Around Sub Base And Cuttings Tank - Spot Truck Shop, And Welding Shop - Position Camp - Hook Up Utilities Between Sub And Pits Printed: 8/25/2003 9:07:06 AM ) ) BP EXPLORATION Operations Summary Repórt Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From- To Hours Task Code NPT Phase Description of Operations 8/11/2003 19:00 - 19:30 0.50 WHSUR P DECOMP 100 Psi. During Test 19:30 - 20:00 0.50 PULL P DECOMP Back Out Lock Down Studs - Pick Up Single Joint Of 4" Drill Pipe And Make Up Cross Overs For Tubing Hanger Threads 20:00 - 21 :00 1.00 PULL P DECOMP Pull FMC Tubing Hanger To Rig Floor With Up Weight At 97,000 Ibs. - Lay Down Landing Joint And Tubing Hanger 21 :00 - 22:00 1.00 PULL P DECOMP Rig Up Control Line Spooling Unit, Power Tongs And Equipment To Pull Completion String 22:00 - 00:00 2.00 PULL P DECOMP POH From 7,935' To 6,695' Laying Down 3 1/2" 9.3 lb. L-80 Tubing Completion String 8/12/2003 00:00 - 11 :30 11.50 PULL P DECOMP POH From 6,695' Laying Down 3 1/2" 9.3 lb. L-80 Tubing Completion String Recovered Following Items: (255) Joints Of 31/2" 9.3 lb. L-80 Tubing (1) Partial Cut Joint 16.33' (4) GLM (1) Chemical Injection Mandrel (1) SSSV (6) Stainless Steel Bands (259) Clamps For Control Line 11 :30 - 13:00 1.50 PULL P DECOMP Rig Down Control Line Spooling Unit, Power Tongs And Equipment - Clear Rig Floor 13:00 - 14:00 1.00 BOPSURP DECOMP Install Test Plug - Rig Up Testing Equipment - Test Upper And Lower Pipe Rams, 4" Floor Safety Valve And Dart Valve At 250 Psi. Low And 3,500 Psi. High - Rig Down Testing Equipment - Install Wear Bushing And Energize Lock Down Studs. 14:00 -17:00 3.00 EVAL P WEXIT Rig Up Schlumberger - Run NO.1 Make Up GRICCL With 8.525 0.0. Gauge Ring I Junk Basket - RIH Tag Tubing Stub At 7,929' WLM - POH With Junk Basket I Gauge Ring 17:00 - 21 :00 4.00 EVAL P WEXIT Change Logging Tools For Run NO.2 - Make Up GR/CCLlCPST And Haliburton 9 518" EZSV - RIH With EZSV Tie In With Previous Cased Hole Logs - Place On Depth And Set EZSV At 7,758' WLM - POH With Logging Tools - Rig Down Schlumberger And Clear Rig Floor 21 :00 - 22:00 1.00 EVAL P WEXIT Test 9 5/8" casing to 3500 psi for 30 minutes. 22:00 - 00:00 2.00 STWHIP P WEXIT Pick up Whipstock BHA #1 with 8" starter mill. 8/13/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT Pick up Whipstock BHA #1 with 8" starter mill. 01 :00 - 03:30 2.50 STWHIP P WEXIT Pick up drill pipe from pipe shed and RIH with Whipstock BHA #1. 03:30 - 05:00 1.50 STWHIP P WEXIT RIH with drill pipe from the derrick with Whipstock BHA #1 to 7697' . 05:00 - 06:00 1.00 STWHIP P WEXIT Rig up Sperry Sun E-line unit for Gyro surveys. 06:00 - 07:30 1.50 STWHIP P WEXIT RIH and orient Whipstock with Gyro and set same at 210 deg at 7751' 07:30 - 09:00 1.50 STWHIP P WEXIT POH with Gyro. Rig down Sperry Sun E-line. 09:00 - 1 0:00 1.00 STWHIP P WEXIT Displace well to 10 ppg LSND drilling mud at 12.5 bpm with 2700 psi. 10:00 - 17:00 7.00 STWHIP P WEXIT Mill window in 95/8" casing from 7727' to 7743' with 8" starter mill and 8.5" finishing mill plus 14' of open hole to 7757'. Recovered approx 222 Ibs of metal. 17:00 - 18:00 1.00 STWHIP P WEXIT Circulate around 20 bbl high vis sweep at 7 bpm with 1100 psi. 18:00 - 18:30 0.50 EVAL P WEXIT Perform FIT of 12.0 ppg EMW at 7725' TVD. Printed: 8/25/2003 9:07:06 AM ) ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES - To Hours Task Code NPT Phase 8/13/2003 18:30 - 21 :30 3.00 STWHIP P WEXIT 21 :30 - 23:00 1.50 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 8/14/2003 00:00 - 03:30 3.50 DRILL INT1 03:30 - 05:00 1.50 DRILL INT1 05:00 - 06:00 1.00 DRILL INT1 06:00 - 06:30 0.50 DRILL INT1 06:30 - 08:30 2.00 DRILL INT1 08:30 - 09:30 1.00 DRILL INT1 09:30 - 13:00 3.50 DRILL N SFAL INT1 13:00 - 15:30 2.50 DRILL N SFAL INT1 15:30 - 18:00 2.50 DRILL N SFAL INT1 18:00 - 22:30 4.50 DRILL P INT1 22:30 - 23:00 0.50 DRILL P INT1 23:00 - 00:00 1.00 DRILL P INT1 8/15/2003 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01 :00 0.50 DRILL P INT1 01 :00 - 08:30 7.50 DRILL P INT1 08:30 - 09:30 1.00 DRILL P INT1 09:30 - 10:00 0.50 DRILL P INT1 10:00 - 10:30 0.50 DRILL P INT1 10:30 - 11 :00 0.50 DRILL P INT1 11 :00 - 14:00 3.00 DRILL P INT1 14:00 - 14:30 0.50 DRILL P INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 16:30 0.50 DRILL P INT1 16:30 - 19:30 3.00 DRILL P INT1 19:30 - 23:30 4.00 DRILL P INT1 23:30 - 00:00 0.50 CASE P INT1 8/16/2003 00:00 - 01 :30 1.50 CASE P INT1 Page 30f 9 Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Description of Operations POH to BHA. Lay down milling BHA. Stand back drill collars and HWDP. Pull wear ring, flush BOP and reinstall wear ring. Make up 81/2" drilling BHA with used PDC bit. Mud motor bent housing set at 1.5 deg. Shallow test MWD. RIH with drilling BHA on 4" drill pipe from derrick to 7626'. Slip and cut 98' of drilling line. Service top drive and crown. Rig up Sperry Sun E-line unit and side entry sub. Run gyro. Orient bit and pass through window to 7748'. The wireline clamp on side door entry sub holding the 7/32" E-line slipped when the pumps were turned on allowing the line to go down into the drill pipe. The line was tensioned and the side door entry sub pulled to the floor, with the bit back into 9 5/8" casing. While POH the E-line was damaged when the side door entry sub reached the table and came in contact with the table bushings. Communication to the Gyro tool was lost. The clamp was removed from the side door entry sub, the line and gyro pulled from the well and the side door entry sub removed from the string. Rig down Sperry Sun E-line unit. Rig up Schlumberger E-line unit. Rig up side entry sub, connect to gyro, no communication. Indications show that the gyro is not working. Change out gyro tools and test. RIH with gyro to UBHO sub, confirm correct seat. Orient and pass bit through window. Drill 8 1/2" hole from 7757' to 7909'. Sliding. AST=4.4 hrs. POH from 7909' to 7655' to position side door entry sub at rig floor. Pull out with E-line and gyro. Rig down side door entry sub and E-line unit. RIH with drilling BHA to 7909'. Drill 8 1/2" hole from 7909' to 8276'. Slide and rotate to maintain angle and direction. ART=2.46 AST=2.66 Circulate 20 bbl sweep around. POH to 7710' inside 9 5/8" casing. Service top drive and crown. RIH to 8276'. Circulate 20 bbl sweep around. Gas cut mud on bottoms up. Mud weight cut to 9.5 ppg. Circulate and increase mud weight to 10.2 ppg. POH to 7710' inside 9 5/8" casing. RIH to 8276'. Circulate bottoms up. No gas. Spot liner running pill in open hole. Drop Spery Sun (ESS) Multi Shot Survey tool for JORPS compliance. POH to BHA. Lay down BHA. Down load MWD data. Recover Sperry Sun ESS tool. Rig up casing running tools and power tongs. Run 17 joints 7" 26# L-80 BTC-M liner. Check floats. Printed: 8/25/2003 9:07:06 AM ') ') BP EXPLORATION o perati OilS Su rn maryReport Page4 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From - To Hours Task Code NPT Phase Descriptionöf Operations 8/16/2003 01 :30 - 02:00 0.50 CASE P INT1 Make up Baker 7" x 9 5/8" HMC liner hanger with ZXP liner top packer. 02:00 - 02:30 0.50 CASE P INT1 Circulate volume of liner. Record liner weight at 16,000 Ibs. 02:30 - 05:30 3.00 CASE P INT1 Run 7" liner on 4" drill pipe to 7640' fill pipe every 10 stands. 05:30 - 06:00 0.50 CASE P INT1 Circulate 1 1/2 drill pipe and liner volumes at 7 bpm with 970 psi. 06:00 - 06:30 0.50 CASE P INT1 RIH with 7" liner on 4" drill pipe into open hole to 7713'. Make up cement head and lines. Run in to 8276', tag up on bottom. No fill. 06:30 - 08:30 2.00 CASE P INT1 Circulate. Stage pumps up slowly to 7 bpm with 1600 psi. Hold PJSM with all hands for cement job. 08:30 - 09:30 1.00 CEMT P INT1 Rig up Dowell cementing unit. Pump 5 bbl water. Test surface lines and equipment to 4,500 psi. (Test Good). Clear lines with Mud Push prior to going down hole. Pump 35 bbl1 0.5 ppg Mud Push, followed with 37.7 bbl (182 Sacks with 1.16 cuftlsx yield) 15.8 ppg Class "G" Tail Cement at 4 BPM. Wash up lines to floor. Drop dart and displace with 10.2 ppg LSND Mud at 5.0 BPM with 908 pi. Slow rate and latch liner wiper plug with 72.4 bbl pumped. Increase rate to 5.0 BPM continue to displace. Slow rate to 3.1 BPM with final circulating pressure at 1150 psi. Bump plug with a total of 95.7 bbl. Cement in place at 09:34 Hours. Increase pressure to 3,500 psi to set Baker Liner Hanger. Bleed off pressure and check floats (Floats Held). Note: When cement reached liner hanger hole attempted to pack off. Rate was reduced and displacement continued. 09:30 - 10:30 1.00 CEMT P INT1 Rotate 15 turns to the right and release running tool from liner. Pressure DP to 1000 psi with Rig pumps. Pick up to release pack-off from Tie-back Receptacle and extend running tool dogs. Circulate at maximum rate 10 BPM for 30 - 40 bbl staging cement up the hole. Slow pumps to 6 BPM, slack off 50K and rotate to set ZXP liner top packer. Continue to circulate contaminated Mud Push and cement back to surface PH went from 9.5 to 11.7. Estimated cement volume back to surface at 5 bbl. 10:30 - 11 :30 1.00 CEMT P INT1 Rig down cement head and lines. Clean shakers. 11 :30 - 14:00 2.50 CEMT P INT1 POH with liner running tools. 14:00 - 14:30 0.50 CEMT P INT1 Lay down liner running tools. 14:30 - 15:30 1.00 CEMT P INT1 Rig down casing running tools. Pull and inspect wear ring. 15:30 - 18:30 3.00 DRILL P PROD1 Pick up 6 1/8" bit and drilling BHA with bent housing set at 1.5 deg. 18:30 - 19:00 0.50 DRILL P PROD1 Service top drive. 19:00 - 22:00 3.00 DRILL P PROD1 RIH with BHA. Pick up 123 joints 4" drill pipe from pipe shed 22:00 - 23:30 1.50 DRILL P PROD1 RIH with 4" drill pipe from derrick. Tag up on landing collar at 8189' 23:30 - 00:00 0.50 DRILL P PROD1 Circulate at 6 bpm with 2100 psi prior to test casing. 8/17/2003 00:00 - 01 :00 1.00 CASE P PROD1 Test 9 5/8" casing, 7" liner and liner top packer to 3000 psi for 30 minutes (Test Good) 01 :00 - 04:30 3.50 DRILL P PROD1 Drill landing collar at 8189', firm cement to 8231' float collar at 8231' and firm cement to 8273'. 04:30 - 07:00 2.50 DRILL P PROD1 Circulate and displace 10.2 ppg LSND drilling mud to 8.5 ppg Printed: 8/25/2003 9:07:06 AM ') ) BP EXPLORATION Operations Summary Report Page 5 öf9 Legal Well Name: 15-20 Common Well Name: 15-20B Spud Date: 8/1/1984 Event Name: REENTER+COMPLETE Start: 8/11/2003 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/24/2003 Rig Name: NABORS 2ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations 8/17/2003 04:30 - 07:00 2.50 DRILL P PROD1 new Flo Pro Drill-in Fluid with 4% lube. 07:00 - 07:30 0.50 DRILL P PROD1 Drill 7" Float Shoe At 8,295' - Drill New 6 1/8" Hole From 8,276' To 8,296' - POH To 8,269' 07:30 - 08:00 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 9.5 PPG EMW Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 40 psi 4 100 psi 6 150 psi 8 200 psi 10 270 psi 12 330 psi 14 390 psi 15 429 psi Held Test FI 10 minutes wI 20 Psi. Pressure Loss. MW 8.5 ppg, 7" Shoe TVD 8,250' Pressure 429 psi = 9.5 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams 08:00 - 00:00 16.00 DRILL P PROD1 Drilled 61/8" Directional Hole By Rotating And Sliding From 8,296' to 8,877' WOB Rotating 10,000# - 25,000#, WOB Sliding 5,000# To 20,000#, RPM 60 To 80, Motor RPM 83, Torque Off Bottom 2,000 ft I Ibs - On Bottom 4,000 ft I Ibs, Pump Rate 279 gpm, SPP Off Bottom 1,400 psi, On Bottom 1,600 psi. String Weight Up 165,000#, String Weight Down 155,000#, String Weight Rotating 165,000# - ART = 4.35 hrs. - AST = 5.46 hrs. 8/18/2003 00:00 - 14:00 14.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 8877' to 9295' WOB Rotating 22,000#, WOB Sliding 5,000# To 20,000#, RPM 60 To 80, Motor RPM 83, Torque Off Bottom 2,000 ft I Ibs - On Bottom 4,000 ft I lbs, Pump Rate 279 gpm, SPP Off Bottom 1,550 psi, On Bottom 1,750 psi. String Weight Up 165,000#, String Weight Down 155,000#, String Weight Rotating 165,000# AST=3.49 Hrs ART=8 Hrs 14:00 - 15:00 1.00 DRILL P PROD1 Circulate for sample. 15:00 - 16:00 1.00 DRILL P PROD1 POH from 9295' to 8276',7" shoe. Over pull25K at 8921'. 16:00 - 17:00 1.00 DRILL P PROD1 Drop ball and rod. Open circulating port in circulating sub above BHA. Circulate bottoms up at 9 BPM with 800 psi. 17:00 - 20:00 3.00 DRILL P PROD1 POH to BHA. 20:00 - 22:30 2.50 DRILL P PROD1 Down load MWD data. Lay down RA source. Break off bit. Clear rig floor. 22:30 - 00:00 1.50 BOPSUR P PROD1 Test BOP and associated equipment 250 psi low and 3500 psi high. Choke manifold tested while POH. Note: AOGCC waived witnessing test. 8/19/2003 00:00 - 02:00 2.00 BOPSURP PROD1 Test BOP and associated equipment 250 psi low and 3500 psi high. Note: AOGCC waived witnessing test. RID test joint. Set wear bushing. 02:00 - 03:00 1.00 DRILL P PROD1 PJSM with crew. Make up BHA to 138'. Printed: 8/25/2003 9:07:06 AM ) ) BP EXPLORATION Operations Summary Report Page 60f 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/19/2003 03:00 - 04:00 1.00 DRILL P PROD1 Upload MWD tools and shallow test same. Load RAS. M/U BHA to 238'. cIa elevators. 04:00 - 05:00 1.00 DRILL P PROD1 RIH with drill pipe from 238' to 3,505'. 05:00 - 05:30 0.50 DRILL P PROD1 Fill pipe. Function MWD tools at 280 gpm and 1,230 psi. 05:30 - 07:00 1.50 DRILL P PROD1 RIH with drill pipe from 3,505' to 8,276'. Fill pipe at 6,773'. 07:00 - 09:00 2.00 DRILL P PROD1 Slip and cut drilling line. Service top drive. 09:00 - 10:00 1.00 DRILL N RREP PROD1 Drawworks downtime. Replace key stock transmission linkage. 10:00 - 11 :30 1.50 DRILL P PROD1 Install blower hose. RIH with drill pipe from 8,276'. Wash from 9,109' to 9,295'. No fill on bottom. Sweep hole. 11 :30 - 00:00 12.50 DRILL P PROD1 Directional drill from 9,295' to 10,124'. ART = 2.39 hrs, AST = 5.43 hrs, ADT = 7.82 hrs P/U weight 168K, SIO weight 153K, Rot weight 163K. Slide I Rotate 829' (9,295' - 10,124') Slide at TF 30 to 90 LHS to maintain LH turn and complete build to horizontal Flow rate 325 gpm, on btm 2,250 psi, off btm 2,050 psi. WOB 10 K, Rap 50-150 fph Rotate at 80 RPM Flow rate 325 gpm, on btm 2,250 psi, off btm 2,050 psi. Torque on btm 5,000; Torque off btm 4,000 WOB 10K, Rap 120 - 180 fph 8/20/2003 00:00 - 10:30 10.50 DRILL P PROD1 Directional drill from 10,124' to 10,997'. ART = 3.73 hrs, AST = 2.06 hrs, ADT = 5.79 hrs P/U weight 170K, SIO weight 150K, Rot weight 160K. Slide I Rotate 873' (10,124' -10,997') Slide at TF 75 to 180 LHS to maintain LH turn and geosteer per Geologist instructions. Flow rate 325 gpm, on btm 2,500 psi, off btm 2,100 psi. WOB 10 K, Rap 50-150 fph Rotate at 80 - 1 00 RPM Flow rate 325 gpm, on btm 2,500 psi, off btm 2,100 psi. Torque on btm 6,000; Torque off btm 4,000 WOB 6 - 10K, Rap 150 - 200 fph 10:30 - 11 :00 0.50 DRILL P PROD1 Circulate hole at 10,997'. Monitor well. 11 :00 - 11 :30 0.50 DRILL P PROD1 POOH with drill pipe from 10,997' to 10,228'. 11 :30 - 12:00 0.50 DRILL P PROD1 MAD pass, with MWD, from 10,228' to 10,308'. Running speed of 150 -180 fph. Flow at 275 gpm and 1,700 psi. RIH with drill pipe from 10,308' to 10,509'. 12:00 - 12:30 0.50 DRILL P PROD1 RIH with drill pipe from 10,509' to 10,997'. CBU and await orders. 12:30 - 23:00 10.50 DRILL P PROD1 Directional drill from 10,997' to 11,815'. ART = 4.80 hrs, AST = 1.60 hrs, ADT = 6.40 hrs Printed: 8/25/2003 9:07:06 AM ) ) BP EXPLORATION Operations Summary Report Page 7of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From- To Hours Task Code NPT Phase Description of Operations 8/20/2003 12:30 - 23:00 10.50 DRILL P PROD1 P/U weight 175K, SIO weight 140K, Rot weight 160K. Slide I Rotate 818' (10,997' - 11,815') Slide at TF 30 to 180 RHS to geosteer per Geologist instructions. Flow rate 325 gpm, on btm 2,600 psi, off btm 2,200 psi. WOB 10 - 12K, Rap 50-80 fph Rotate at 100 RPM Flow rate 325 gpm, on btm 2,600 psi, off btm 2,200 psi. Torque 7 - 10K, Rap 150 - 200 fph 23:00 - 00:00 1.00 DRILL P PROD1 Circulate Hi Vis sweep at 320 gpm and 2,300 psi. 8/21/2003 00:00 - 03:30 3.50 DRILL P PROD1 POH with 2 stands. P/U 6 singles. Directional drill from 11,815' to 12,021'. Rig site geologist called well TD at 12,021' md, (8,906' tvd). ART = 1.27 hrs, AST = 0.43 hrs, ADT = 1.70 hrs P/U weight 185K, SIO weight 145K, Rot weight 160K. Slide I Rotate 206' (11,815' - 12,021') Slide at TF 180 RHS to geosteer per Geologist instructions. Flow rate 325 gpm, on btm 2,600 psi, off btm 2,200 psi. WOB 10 - 12K, Rap 50 fph Rotate at 100 RPM Flow rate 325 gpm, on btm 2,600 psi, off btm 2,200 psi. Torque 7 - 10K, Rap 100 fph 03:30 - 05:30 2.00 DRILL P PROD1 Pump Hi Vis sweep. CBU at 325 gpm and 2,100 psi. Monitor well. 05:30 - 07:30 2.00 DRILL P PROD1 POOH with drill pipe from 12,021' to 8,276', No problems. 07:30 - 08:00 0.50 DRILL P PROD1 Service top drive. 08:00 - 09:30 1.50 DRILL P PROD1 RIH with drill pipe from 8,276' to 12,021'. No fill on bottom. 09:30 - 11 :30 2.00 DRILL P PROD1 Pump Hi Vis sweep at 325 gpm and 2,300 psi. Spot liner running pill. 11 :30 - 13:30 2.00 DRILL P PROD1 Monitor well. POOH with drill pipe from 12,021' to 8,268'. 13:30 - 14:00 0.50 DRILL P PROD1 Drop dart to open circ sub. Pump dry job. Drop rabbit. 14:00 - 16:30 2.50 DRILL P PROD1 POOH with drill pipe from 8,268' to 238'. 16:30 - 19:00 2.50 DRILL P PROD1 UD BHA. Remove RAS, download MWD. Clear rig floor. 19:00 - 20:00 1.00 CASE P CaMP RJU floor to run 41/2", 12.6#, L-80, IBT-M liner. PJSM regarding running liner. 20:00 - 23:00 3.00 CASE P CaMP M/U 41/2", 12.6#, L-80, IBT-M liner to 3,878' (93 joints). Average M/U torque 3,900 ft-lbs. 23:00 - 23:30 0.50 CASE P CaMP M/U Baker HMC liner hanger I ZXP liner top packer. P/U weight 75K, SIO weight 70K. 23:30 - 00:00 0.50 CASE P COMP P/U one stand drill pipe. Circulate liner volume. 8/22/2003 00:00 - 02:00 2.00 CASE P CaMP RIH with liner on drill pipe to 8,258', at top of window. 02:00 - 02:30 0.50 CASE P CaMP Circulate liner and drill pipe volume at 100 spm and 500 psi. P/U weight 140K, SIO weight 140K. 02:30 - 04:00 1.50 CASE P CaMP RIH with liner, on drill pipe, to 11,998'. No problems. 04:00 - 04:30 0.50 CASE P CaMP RJU rotary cement head, manifold and hoses. 04:30 - 06:00 1.50 CASE P CaMP Tag bottom at 12,021 '. No fill on bottom. Stage pumps up to 6 Printed: 8/25/2003 9:07:06 AM ") ) BP EXPLORATION O,petationsSummary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From - To Hours· Task Code NPT Phase .. Description of Operations 8/22/2003 04:30 - 06:00 1.50 CASE P CaMP bpm and 1,200 psi. PJSM with all personnel. 06:00 - 08:30 2.50 CEMT P CaMP Pump 5 bbls water and test lines to 4,500 psi. Pump 15 bbl 8.3 ppg CW100. Pump 25 bbl1 0.0 ppg MudPUSH. Pump 97 bbl 15.8 ppg, 'G' cement. Wash lines, drop dart, and displace with 75 bbl perf pill, followed by 65 bbl mud. Latch dart and bump plug on calculated displacement. Increase pressure to 3,500 psi to set hanger. Check floats. O.K. CIP at 08:05 8/22/2003. 08:30 - 09:00 0.50 CASE P CaMP Rotate and release from hanger. Increase pressure to 1,000 psi. Sting out and circulate -30 bbl. Reduce rate, slack off and set packer with 50K. Increase circulating rate. 09:00 - 11 :00 2.00 CASE P COMP Circulate well at 12 bpm and 2,200 psi. 15 bbl cement returns. Displace well to seawater. 11:00-11:30 0.50 CASE P CaMP RID rotary cement head. 11:30-13:30 2.00 CASE P CaMP POOH from 8,119' to 4,580', 1 X 1. 13:30 - 16:30 3.00 CASE P CaMP POOH from 4,580'. LID liner running tool. Clear rig floor. 16:30 -17:30 1.00 PERF P CaMP Service top drive. 17:30 - 18:00 0.50 PERF P CaMP Pressure test casing to 3,500 psi for 30 minutes. Record test on chart. 18:00 - 20:00 2.00 PERF P CaMP PJSM with all personnel regarding tcp perforating. R/U tcp handling equipment. P/U HES 2 1/2" tcp guns. (4 spf) 20:00 - 23:30 3.50 PERF P CaMP P/U 2 7/8",10.5 ppf drill pipe from 674' to 3,842'. RID 2 7/8" handling equipment. 23:30 - 00:00 0.50 PERF P CaMP RIH with drill pipe from 3,842' to 5,337'. 8/23/2003 00:00 - 03:00 3.00 PERF P CaMP RIH with tcp guns on drill pipe to 11,928'. Tag depth twice to confirm. P/U weight 175K, SIO weight 150K. P/U to up weight, then strap to place shots on depth. Top shot at 11 ,250', bottom shot at 11,900'. 03:00 - 03:30 0.50 PERF P CaMP R/U shot recorder. Pressure to 3,200 psi to initiate firing head, then bleed off. At 5 1/2 minutes, good surface indication shots fired. Initial loss of -2 bbl. 03:30 - 04:00 0.50 PERF P CaMP POH with drill pipe to 11,200'. Monitor well for 15 minutes. Initial loss rate of -5.5 bph. Pump dry job. 04:00 - 07:00 3.00 PERF P CaMP POH LID 4" drill pipe 1 X 1, from 11,200' to 7,000'. 07:00 - 08:00 1.00 PERF P CaMP Slip and cut 108' drilling line. 08:00 - 10:00 2.00 PERF P CaMP POH LID 4" drill pipe from 7,000' to 3,843'. 10:00 - 14:00 4.00 PERF P CaMP RlU 2 7/8" handling equipment. LID 2 7/8" drill pipe from 3,843' to 674'. Loss rate slowed to -2 bph. 14:00 - 16:00 2.00 PERF P CaMP RID 2 7/8" handling equipment. cIa elevators. LID 2 1/2" tcp perf guns. All shots fired. Well bore perforated from 11,250' to 11,900', at 4 spf. Clear and clean rig floor. 16:00 -17:00 1.00 PERF P CaMP RIH with 4" drill pipe from derrick to 930'. LID drill pipe from 930'. 17:00 - 18:00 1.00 RUNCOrvP CaMP Pull wear bushing. RlU to run 41/2", 12.6#, L-80, IBT-M tubing. PJSM. 18:00 - 18:30 0.50 RUNCOrvP CaMP P/U tailpipe assembly and Baker S-3 packer. 18:30 - 23:30 5.00 RUNCOrvP CaMP M/U and RIH with 41/2", 12.6#, L-80, IBT-M tubing and jewelry Printed: 8/25/2003 9:07:06 AM ) ) BP EXPLORATION OperéttionsSummary Report . Page 9 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-20 15-20B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/11/2003 Rig Release: 8/24/2003 Rig Number: Spud Date: 8/1/1984 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/23/2003 18:30 - 23:30 5.00 RUNCOIVP COMP to 8,119'. Average M/U torque 3,800 ft-Ibs. Used Best-O-Life 2000 thread compound. 23:30 - 00:00 0.50 RUNCOIVP COMP Space out. 8/24/2003 00:00 - 02:00 2.00 RUNCOIVP COMP Space out tubing with 2 pups, (9.71' and 2.09'). M/U tubing hanger and land. RILDS. Top of TBS at 8,116', bottom of TBS at 8,123' (tubing measurement). Spaced out such that WLEG at 8,120.51' (tubing measurement). 02:00 - 05:00 3.00 RUNCOIVP COMP R/U and reverse circulate SW and SW with corrosion inhibitor at 3 bpm and 150 psi.. 05:00 - 06:30 1.50 RUNCOIVP COMP Drop ball and rod. Set packer. Test tubing to 3,500 psi for 30 minutes. Bleed tubing pressure to 1,500 psi. Increase pressure in annulus to 3,500 psi. Test and record for 30 minutes. Bleed tubing and shear DCK. 06:30 - 07:30 1.00 WHSUR P COMP Dry rod in BPV. Test from below to 1,000 psi. BID surface equipment. 07:30 - 09:00 1.50 BOPSURP COMP N/D BOPE. 09:00 - 10:30 1.50 WHSUR P COMP N/U tree and adapter flange. Test adapter flange to 5,000 psi. 10:30 -12:30 2.00 WHSUR P COMP Pull BPV with lubricator. Install tree test plug. Test tree to 5,000 psi. Pull tree test plug. 12:30 - 15:00 2.50 WHSUR P COMP R/U LRHOS. Reverse circulate 155 bbls diesel freeze protect. U-tube. 15:00 - 15:30 0.50 WHSUR P COMP Set BPV. Test from below to 1,000 psi. 15:30 -16:30 1.00 WHSUR P COMP Remove secondary annulus valve. Rig released at 16:30 hrs, 8/24/2003. Printed: 8/25/2003 9:07:06 AM ) ) ., I' §03--IOLf 12-Sep-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-208 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,715.83' MD Window / Kickoff Survey: 7,727.00' MD (if applicable) Projected Survey: 12,021.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ""\, [:~:~. ~ \ll::~: ~L) :)EP 2 <. ZGG() ,¿~j(,'i:',,~':~~~ '~:,~i~:, ~::~ '~~~\\\ ,-S Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-20B ~ Job No. AKMW00026017108, Surveyed: 21 August, 2003 Survey Report 11 September, 2003 Your Ref: API 500292113302 Surface Coordinates: 5960102.83 N, 677267.36 E (70017'47.4552" N, 148033' 52.0696" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -. Surface Coordinates relative to Project H Reference: 960102.83 N, 177267.36 E (Grid) Surface Coordinates relative to Structure Reference: 1242.14 N, 998.97 E (True) Kelly Bushing: 57.83ft above Mean Sea Level Elevation relative to Project V Reference: 57.83ft Elevation relative to Structure Reference : 57.83ft 5i ..... '''''Y-5UI'l DFflL<Ln,n::f'-se"Rv ìEe s A Halliburton Company Survey Ref: svy4091 Sperry-Sun Drilling Services Survey Report for P8U_EOA OS 15 - 15-208 Your Ref: API 500292113302 Job No. AKMW0002601710B, Surveyed: 21 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 7715.83 1.000 177.000 7652.97 7710.80 101.40 N 158.12 E 5960207.93 N 677423.05 E -76.92 Tie On Point MWD Magnetic 7727.00 1.000 178.430 7664.13 7721.96 101.21 N 158.13 E 5960207.74 N 677423.06 E 0.223 -76.72 Window Point 7741 .00 2.740 198.940 7678.13 7735.96 100.77 N 158.02 E 5960207.30 N 677422.96 E 13.122 -76.30 7767.70 5.010 203.140 7704.76 7762.59 99.09 N 157.36 E 5960205.61 N 677422.34 E 8.562 -74.74 ~ 7799.30 7.400 211.330 7736.18 7794.01 96.08 N 155.76 E 5960202.56 N 677420.81 E 8.047 -72.01 7826.00 9.470 216.410 7762.59 7820.42 92.85 N 153.56 E 5960199.27 N 677418.69 E 8.232 -69.13 7856.00 11 .540 217.170 7792.08 7849.91 88.47 N 150.28 E 5960194.82 N 677415.51 E 6.915 -65.28 7886.00 13.610 217.700 7821.36 7879.19 83.29 N 146.31 E 5960189.54 N 677411.66 E 6.911 -60.74 7913.43 15.500 218.060 7847.91 7905.74 77.85 N 142.08 E 5960184.00 N 677407.56 E 6.898 -55.99 7939.42 15.390 218.060 7872.96 7930.79 72.40 N 137.81 E 5960178.46 N 677403.42 E 0.423 -51.23 7989.83 14.900 219.050 7921.62 7979.45 62.10 N 129.60 E 5960167.97 N 677395.46 E 1.099 -42.26 8034.25 14.900 219.510 7964.55 8022.38 53.25 N 122.37 E 5960158.96 N 677388.44 E 0.266 -34.58 8126.19 15.340 221.600 8053.30 8111.13 35.04 N 106.78 E 5960140.38 N 677373.28 E 0.762 -18.87 8160.78 16.430 221 .160 8086.57 8144.40 27.94 N 100.52 E 5960133.13 N 677367.19 E 3.170 -12.77 8192.20 18.300 220.040 8116.56 8174.39 20.81 N 94.42 E 5960125.86 N 677361.26 E 6.046 -6.63 8216.66 20.020 218.480 8139.66 8197.49 14.60 N 89.34 E 5960119.53 N 677356.33 E 7.336 -1.23 8291.98 23.010 219.410 8209.73 8267.56 6.888 71.97 E 5960097.65 N 677339.47 E 3.995 17.44 8324.41 23.160 219.730 8239.56 8297.39 16.68 S 63.87 E 5960087.66 N 677331.61 E 0.603 25.94 8355.81 25.870 220.020 8268.13 8325.96 26.67 8 55.52 E 5960077.4 7 N 677323.49 E 8.639 34.59 8384.30 29.700 221.680 8293.33 8351.16 36.71 S 46.82 E 5960067.23 N 677315.04 E 13.714 43.23 8416.40 34.460 224.880 8320.52 8378.35 49.09 8 35.12 E 5960054.58 N 677303.63 E 15.741 53.74 .~ 8447.51 39.390 223.780 8345.38 8403.21 62.46 8 22.07 E 5960040.90 N 677290.90 E 15.988 65.04 8477.69 42.080 222.880 8368.25 8426.08 76.79 S 8.56 E 5960026.26 N 677277.73 E 9.123 77.21 8511.81 47.910 221.940 8392.37 8450.20 94.60 8 7.69W 5960008.07 N 677261.90 E 17.197 92.43 8541.67 50.930 221.220 8411.79 8469.62 111.57 S 22.74 W 5959990.76 N 677247.26 E 10.278 106.98 8570.57 54.880 219.720 8429.22 8487.05 129.108 37.69 W 5959972.87 N 677232.72 E 14.280 122.11 8664.43 57.830 215.190 8481.24 8539.07 191.13 S 85.14 W 5959909.74 N 677186.75 E 5.100 176.45 8698.21 58.090 214.830 8499.16 8556.99 214.588 101.57 W 5959885.91 N 677170.88 E 1.187 197.21 8729.61 58.340 213.650 8515.70 8573.53 236.65 8 116.59 W 5959863.50 N 677156.39 E 3.292 216.82 8757.44 60.230 213.800 8529.91 8587.74 256.55 8 129.87 W 5959843.29 N 677143.58 E 6.807 234.53 11 September, 2003 - 15:31 Page2of5 OrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 -15-20B Your Ref: API 500292113302 Job No. AKMW0002601710B, Surveyed: 21 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 8792.37 62.590 214.550 8546.62 8604.45 281.92 8 147.10 W 5959817.52 N 677126.95 E 7.014 257.08 8823.55 65.440 215.000 8560.28 8618.11 304.948 163.09 W 5959794.13 N 677111.51 E 9.232 277.48 8852.70 67.570 217.170 8571.91 8629.74 326.54 8 178.83 W 5959772.17 N 677096.28 E 10.000 296.52 8886.76 68.960 217.650 8584.52 8642.35 351.678 198.05 W 5959746.59 N 677077.66 E 4.286 318.53 8918.09 72.500 217.870 8594.86 8652.69 375.04 8 216.16 W 5959722.79 N 677060.11 E 11.318 338.97 ~ 8946.36 73.790 218.140 8603.05 8660.88 396.36 S 232.82 W 5959701.09 N 677043.95 E 4.654 357.59 9039.70 74.320 216.500 8628.70 8686.53 467.73 S 287.23 W 5959628.45 N 676991.24 E 1.782 420.14 9132.93 71.210 218.930 8656.32 8714.15 538.178 341.67 W 5959556.75 N 676938.47 E 4.162 481.75 9226.48 71.150 218.320 8686.50 8744.33 607.358 396.95 W 5959486.29 N 676884.85 E 0.621 542.00 9260.06 71.530 219.250 8697.24 8755.07 632.148 416.88 W 5959461.03 N 676865.51 E 2.858 563.58 9290.42 73.590 215.720 8706.34 8764.17 655.13 S 434.49 W 5959437.64 N 676848.44 E 13.003 583.71 9319.67 74.560 212.240 8714.37 8772.20 678.45 8 450.21 W 5959413.95 N 676833.28 E 11.911 604.45 9353.23 73.860 207.020 8723.51 8781.34 706.50 S 466.17 W 5959385.53 N 676817.98 E 15.111 629.84 9384.83 73.740 202.620 8732.33 8790.16 734.04 S 478.91 W 5959357.70 N 676805.90 E 13.376 655.19 9413.80 73.860 198.520 8740.42 8798.25 760.08 S 488.68 W 5959331 .44 N 676796.74 E 13.597 679.50 9446.75 74.750 194.040 8749.33 8807.16 790.52 S 497.57 W 5959300.79 N 676788.58 E 13.365 708.29 9478.17 75.660 193.000 8757.36 8815.19 820.06 8 504.67 W 5959271.10 N 676782.17 E 4.316 736.45 9506.47 77.570 190.130 8763.91 8821.74 847.028 510.18 W 5959244.01 N 676777.30 E 11.953 762.31 9540.23 79.770 188.440 8770.54 8828.37 879.698 515.52 W 5959211.23 N 676772.73 E 8.158 793.83 9571.92 80.080 187.910 8776.09 8833.92 910.578 519.96 W 5959180.25 N 676769.02 E 1.915 823.72 9598.63 80.510 187.430 8780.59 8838.42 936.67 8 523.47 W 5959154.08 N 676766.13 E 2.394 849.00 9630.76 81 .080 187.890 8785.73 8843.56 968.10 S 527.70 W 5959122.55 N 676762.64 E 2.268 879.47 ~ 9662.58 81. 640 187.740 8790.51 8848.34 999.27 S 531.98 W 5959091.30 N 676759.10 E 1.821 909.66 9692.27 82.450 187.360 8794.62 8852.45 1028.41 S 535.84 W 5959062.06 N 676755.92 E 3.008 937.92 9725.78 83.880 184.230 8798.61 8856.44 1061.51 S 539.20 W 5959028.90 N 676753.35 E 10.209 970.15 9756.64 84.870 179.430 8801.63 8859.46 1092.208 540.18 W 5958998.20 N 676753.09 E 15.808 1000.36 9784.24 85.370 176.130 8803.98 8861.81 1119.678 539.11 W 5958970.75 N 676754.81 E 12.050 1027.69 9818.37 86.480 172.110 8806.41 8864.24 1153.538 535.62 W 5958936.99 N 676759.09 E 12.190 1061.69 9849.71 87.280 169.240 8808.11 8865.94 1184.41 8 530.55 W 5958906.24 N 676764.89 E 9.494 1092.98 9877.30 87.720 169.130 8809.32 8867.15 1211.488 525.38 W 5958879.29 N 676770.70 E 1.644 1120.52 9971.23 89.140 171.330 8811.89 8869.72 1304.01 8 509.45 W 5958787.17 N 676788.81 E 2.787 1214.38 10006.19 89.750 169.130 8812.23 8870.06 1338.458 503.52 W 5958752.87 N 676795.55 E 6.530 1249.33 1 0037.43 89.440 168.750 8812.45 8870.28 1369.11 8 497.53 W 5958722.36 N 676802.26 E 1.570 1280.54 10065.72 89.510 168.180 8812.71 8870.54 1396.838 491.87 W 5958694.79 N 676808.57 E 2.030 1308.78 10099.60 88.700 163.960 8813.24 8871.07 1429.708 483.72 W 5958662.12 N 676817.50 E 12.682 1342.50 11 September, 2003 - 15:31 Page 3 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-20B Your Ref: API 500292113302 Job No. AKMW00026017108, Surveyed: 21 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 10130.86 88.830 161.020 8813.91 8871.74 1459.508 474.31 W 5958632.54 N 676827.60 E 9.412 1373.36 10159.16 89.940 158.190 8814.22 8872.05 1486.038 464.45 W 5958606.26 N 676838.09 E 10.741 1401.05 10193.36 91.170 153.280 8813.88 8871.71 1517.198 450.40 W 5958575.44 N 676852.87 E 14.799 1433.95 10224.18 92.100 150.250 8813.01 8870.84 1544.33 S 435.83 W 5958548.65 N 676868.07 E 10.280 1462.95 10252.78 91.980 149.200 8811.99 8869.82 1569.01 8 421.42 W 5958524.31 N 676883.06 E 3.693 1489.49 ~ 10347.36 92.160 148.740 8808.57 8866.40 1650.01 8 372.70 W 5958444.49 N 676933.68 E 0.522 1576.79 10412.22 92.720 148.040 8805.81 8863.64 1705.198 338.74 W 5958390.12 N 676968.94 E 1.381 1636.39 1 0440.17 91.230 147.180 8804.85 8862.68 1728.788 323.77 W 5958366.90 N 676984.45 E 6.154 1661.93 10473.00 89.440 145.580 8804.65 8862.48 1756.128 305.60 W 5958340.00 N 677003.27 E 7.313 1691.66 10504.54 89.570 144.860 8804.93 8862.76 1782.02 8 287.61 W 5958314.52 N 677021.86 E 2.320 1719.93 10531.93 89.750 143.730 8805.09 8862.92 1804.26 8 271.62 W 5958292.67 N 677038.37 E 4.178 1744.29 10625.77 89.380 141 .150 8805.80 8863.63 1878.64 S 214.42 W 5958219.65 N 677097.31 E 2.777 1826.31 10718.95 89.810 140.840 8806.46 8864.29 1951.058 155.78 W 5958148.65 N 677157.64 E 0.569 1906.59 10813.03 90.370 141.370 8806.31 8864.14 2024.27 8 96.71 W 5958076.84 N 677218.42 E 0.820 1987.74 10906.26 89.440 142.060 8806.47 8864.30 2097.45 8 38.95 W 5958005.05 N 677277.90 E 1.242 2068.65 10956.61 89.630 141.870 8806.88 8864.71 2137.108 7.92W 5957966.13 N 677309.84 E 0.534 2112.46 10997.62 87.530 142.700 8807.89 8865.72 2169.538 17.15 E 5957934.31 N 677335.68 E 5.506 2148.24 11090.31 84.560 140.580 8814.29 8872.12 2242.03 8 74.53 E 5957863.18 N 677394.75 E 3.933 2228.42 11121.15 84.870 143.660 8817.13 8874.96 2266.27 8 93.38 E 5957839.40 N 677414.17 E 9.995 2255.18 11184.27 86.230 141.510 8822.02 8879.85 2316.248 131.61 E 5957790.34 N 677453.57 E 4.022 2310.26 11277.56 88.090 142.430 8826.65 8884.48 2389.63 S 189.01 E 5957718.32 N 677512.68 E 2.224 2391.32 11309.05 88.330 143.330 8827.63 8885.46 2414.738 208.01 E 5957693.68 N 677532.26 E 2.957 2418.95 ~ 11371.62 89.010 140.510 8829.08 8886.91 2463.96 8 246.58 E 5957645.37 N 677571.99 E 4.635 2473.35 11465.21 89.010 142.430 8830.70 8888.53 2537.16 8 304.87 E 5957573.56 N 677631.99 E 2.051 2554.36 11559.10 89.070 143.320 8832.27 8890.10 2612.01 S 361.53 E 5957500.07 N 677690.40 E 0.950 2636.76 11651.91 89.510 141.970 8833.42 8891.25 2685.78 S 417.84 E 5957427.65 N 677748.43 E 1.530 2718.04 11746.21 88.890 146.860 8834.74 8892.57 2762.44 S 472.69 E 5957352.31 N 677805.07 E 5.227 2801.96 11812.46 88.890 145.220 8836.02 8893.85 2817.37 S 509.69 E 5957298.26 N 677843.36 E 2.475 2861.76 11840.15 87.040 145.050 8837.01 8894.84 2840.088 525.51 E 5957275.94 N 677859.71 E 6.709 2886.56 11872.74 86.110 142.870 8838.95 8896.78 2866.38 S 544.65 E 5957250.09 N 677879.46 E 7.261 2915.40 11932.36 86.290 143.520 8842.91 8900.74 2914.01 8 580.29 E 5957203.31 N 677916.22 E 1.129 2967.78 12021.00 86.290 143.520 8848.64 8906.47 2985.14 S 632.88 E 5957133.45 N 677970.47 E 0.000 3045.89 Projected Survey 11 September, 2003 - 15:31 Page 4 of 5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-20B Your Ref: API 500292113302 Job No. AKMW00026017108, Surveyed: 21 August, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 171.500° (True). Magnetic Declination at Surface is 25.828°(12-Aug-03) .~ Based upon Minimum Curvature type calculations, at a Measured Depth of 12021.00ft., The Bottom Hole Displacement is 3051.49ft., in the Direction of 168.030° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7715.83 7727.00 12021.00 7710.80 7721.96 8906.47 101.40 N 101.21 N 2985.14 S 158.12 E 158.13 E 632.88 E Tie On Point Window Point Projected Survey Survey tool program for 15-208 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -..-I 0.00 7715.83 0.00 7715.83 7710.80 12021.00 7710.80 BP Conventional Gyro (15-20) 8906.47 MWD Magnetic (15-20B) 11 September, 2003 - 15:31 Page 5 of 5 DrillQuest 3.03.02.005 ). ) ì:J r '; ; ,J i:;'l~ IJ ( ~l'r ®n ®\QJ[Wr£) l.~.~~.r l.J~l~ Ll:¡ Lr\\ Q¿) J\\ ln~ FRANK H. MURKOWSKI, GOVERNOR AI/A.~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 15-20B BP Exploration (Alaska), Inc. Permit No: 203-136 Surface Location: 1408' SNL, 3946' WEL, Sec. 22, TIIN, RI4E, UM Bottomhole Location: 4059' SNL, 3541' WEL, Sec.22, TIIN, RI3E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, .. 'i2/....a' .l ~' .../ //~ ~~~(/! ---L- Sarah Palin Chair BY ORDER OF THE COMMISSION DATED thiS+- day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ì¡J4/~ i J IIz.-c10 3 1 a. Type of work D Drill II Redrill D Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 677267, Y = 5960103 14081 SNL, 3946' WEL, SEC. 22, T11N, R14E, UM At top of productive interval x = 676918, Y = 5958475 3028' SNL, 4340' WEL, SEC. 22, T11 N, R14E, UM . At total depth x = 677743, Y = 5957464 4059' SNL, 3541' WEL, SEC. 22, T11 N, R14E, UM " STATE OF ALASKA ALASKl..JIL AND GAS CONSERVATION COMh..}SION PERMIT TO DRILL 20 AAC 25.005 / 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 57.8' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028306 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 15-20B 9. Approximate spud dat~ 08/11/03 / Amount $200,000.00 / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 ~ 11647' MD / 8848' TVD o 17. Anticipated pressure {~20 AAC 25.035 (e) (2)} 92 Maximum surface 2713 psig, At total depth (TVD) 8790' I 3246 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 662' 7600' 7595' 8262' 8239' 3535' 8112' 8100' 11647' 8848' I' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 028309,1221' MD 15-13 is 280'away at 11129'MD 16. To be completed for deviated wells Kick Off Depth 7600' MD Maximum Hole Angle 18. CaSingJ~~gram Specifications Hole Casing Weight Grade CouDlina 8-1/2" 7" 26# L-80 BTC-M 6-1/8" 4-1/2" 12.6# L-80 IBT-M Quantity of Cement (include staae data) 170 sx Class 'G' ",.. 426 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10865 feet Plugs (measured) true vertical 8868 feet Effective depth: measured 10847 feet Junk (measured) true vertical 8867 feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Liner 112' 20" 2532' 13-3/8" 8336' 9-5/8" 5691 7" 2875' 2-3/8" 2000# Poleset 1750 sx PF 'EI, 400 sx PF 'C' 500 sx Class 'G', 276 sx PF ICI 112' 2532' 8336' 112' 2532" 8331! 325 sx Class 'G' 126 sx LARC 8012' - 8581' 7990'.~, t08651 I ' " -. .~ 8007' - 85761 7985' - 8868' Perforation depth: measured 9022' - 10032', 10142' - 10452', 10692' - 10842' I' \ " .t,..,!.:t;. ,1,',11_ ·1··· true vertical 8858' - 8845', 8840' - 8838', 8854' - 8867' 20. Attachments II Filing Fee D Property Plat D BOP Sketch D Diverter Sketch II Drilling Program II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirpack, 564-4166 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I ~erebY certify that th~ f~n:poinç is -rue and correct to the best of my ~nowl~~ge . Signed Bill Isaacson J-j.JL.... A.. - Title Senior Drilling Engineer Date 1-/ ~O I O~ '.."':.:: \,~j.¡QQ::QØ:r:ØþljJ!~.I~:::i:';~ii"(v.:: '::>';..,:"';.....,~i.,,;.?,.':. Permit Number API Number AP~z~t~ See cover letter < 0 .3 - /.:3 ç; 50- 029-21133-02 ~: t 17 for other requirements Conditions of Approval: Samples Required 0 Yes ŒI No Mud Log quO ed 0 Yes 181 No Hydrogen Sulfide Measures 181 Yes 0 No Directional Survey Required 1:81 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: r~s.t- ßJPS fc ~SOO pç¿. ~~A..? Original Signed Sy by order of '.../j r L Approved By Sarah Palin Commissioner the commission Date ! I IV ?; Form 10-401 Rev. 12-01-85 U R I (j I N A L S mi n Triptcate ) ) t 1 Well Name: 115-208 Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 677,267.356 Y = 5,960,102.832 / 1409' FNL 1330' FWL Sec. 22, T11 N, R14E Umiat X = 676,918 Y = 5,958,475 TVDss 8802' 3028' FNL 940' FWL Sec. 22, T11N, R14E Umiat / X = 677,743 I Y = 5,957,464 TVDss 8790' 4059' FNL 1738' FWL Sec. 22, T11N, R14E Umiat / 1 AFE Number: I PBD4P2122 I I Estimated Start Date: I 08/11/03 I RiQ: I Nabors 2ES /' I OperatinQ days to complete: 118.5 1 MD: 111,647' II TVD: 18,848' 1 1 GL: 129.3' I 1 KB: 128.5' I 1 KBE: 157.8' I Well DesiQn (conventional, slim hole, etc.): I Two String Horizontal Sidetrack I Objective: 1 Ivishak Zone 1 A/1 B Formation Markers Formation Tops (wp05) MD TVD TVDss Comments CM2 6756' 6731' 6680' 8.3 ppg EMW CM 1 7503' 7484' 7421' 8.3 ppg EMW Kick off Point 7750' 7745' 7681' 8.3 ppg EMW THRZ 7785' 7780' 7722' 8.3 ppg EMW 8HRZ 7972' 7965' 7901' 8.3 ppg EMW LCU 8021' 8018' 7960' 8.3 ppg EMW Kingak C 8021' 8018' 7960' 8.3 ppg EMW Kingak 8 8060' 8050' 7992' 8.3 ppg EMW Kingak A 8161' 8146' 8088' 8.3 ppg EMW Sag River 8263' 8239' 8181' Hydrocarbon bearing 7.1 ppg EMW Shublik 8308' 8280' 8222' Hydrocarbon bearing 7.1 ppg EMW TSAD - Zone 48 8388' 8348' 8290' Hydrocarbon bearing 7.1 ppg EMW Zone 3 CGL 8611' 8500' 8442' Hydrocarbon bearing 7.1 ppg EMW Zone 2 8739' 8568' 8510' Hydrocarbon bearing 7.1 ppg EMW Zone 18 9481' 8801' 8743' Hydrocarbon bearing 7.1 ppg EMW Zone 1 A 9652' 8845' 8781' Hydrocarbon bearing 7.1 ppg EMW TD 11641' 8848' 8790' Hydrocarbon bearing 7.1 ppg EMW TD Criteria: 8ased on 1000' of perfable sand in horizontal. Driller's polygon is hardline. \~.cJ / ~,~ 15-208 Permit to Drill Page 1 ....200 in the 8-1/2" intermediate section ....920 in the 6-1/8" horizontal section 15-13 passes BP's anti-collision policy when minor risk based at 1/200. 15-13 fails against 15-20B while in the production interval. The center to center distance is ....280'. MWD with IIFR+MS (Casandra) ') Directional - Sperry wp05 KOP: I 7750' MD Maximum Hole Angle: Close Approach Wells: Survey Program: ) CasinQITubinQ PrOQram Hole Size Csgrrbg WtlFt G~e c~'n Length Top Btm 0.0. MOITVO MOrrVO 8-1/2" 7" 26# L-80 BTC-M 662' 7,600'/7,595' 8,262'/8,239' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3,535' 8,112'/8,100' 11,647'/8,848' Tubing 4-1/2" 12.6# L-80 IBT-M 7,994' GL 8,052'/8,042' Mud ProQram Section Milling Mud Properties: LSND Density (ppg) Viscosity PV 10.0 50 - 65 11-13 Intermed~· te Mud Properties: LSND Dens~.... (p g) Viscosity PV e,9 45 - 55 12-15 Production Mud Properties: Quickdril Density (ppg) ,Viscosity PV 8.3 - 8.6 ./ 45-55 4 - 7 LOQQinQ ProQram 8-1/2" Intermediate: Sample Catchers - None Drilling: Oir/GRlRes- Real time Open Hole: None Cased Hole: None I Whip Stock Window 9-5/8", 47# I YP TauO HTHP FL PH 25-30 5-9 <12 8.5 - 9.0 I 8-1/2" hole section YP TauO 20-25 3-7 I HTHP FL PH <12 8.5 - 9.0 YP MBT 20 - 28 < 3 pH API FI 8.5 - 9.0 N/C 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Oir/GR - Real time; Oen/Neu - recorded mode for GOC Open Hole: None Cased Hole: None 15-20B Permit to Drill Page 2 ) ) Cement ProQram Casing Size I 7" 26#, L-80 Intermediate Liner Basis: lead: None Tail: Based on 80' shoe track, 512' of 7" X 8-1/2" open hole with 40% excess, 150' 7" X 9-5/8" lap, and 200' of 9-5/8" X£. DP excess. Tail TOC: 7600' MD (Top of Liner)",/') /; 1 Total Cement Volume: 1 Tail 135 bbls, 197 ft~j)"saCks Class G @ 15.8 Ppg~3/sack Casing Size I 4.5" 12.6#, L-80 Production Liner I Basis: lead: None Tail: Based on 80' shoe track, 3385' of 4-1/2" X 6-1/8" open hole with 400/0 excess, 150' 4-1/2" X 7" Liner lap, and 200' 91.:.7" X 4" DP excess. Tail TOC: 8112' MD (Top of Liner) /l /) I Total Cement Volume: I Tail 188 bbls, 494 ft3e,~plsacks Class G @ 15.8 PP0ß'ft3/sack ç/ Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3531 psi (8.3 ppg @ 8181' TVDss) 271...3"'Psi (.10 psi/ft gas gradient to surface) Wini~S' with a 12.0 ppg FIT R-a,rrfs test to 3,500 psi/250 psi. " Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' from middle of window 3246 psi (7.1 ppg @ 8790' TVDss) 23p;rp~J (.10 psi/ft gas gradient to surface) ln1ini1e'/with 9.5 ppg FIT Rãnîs test to 3,500 psi/250 psi."""- Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.5 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 15-20B Permit to Drill Page 3 ) ) .Sidetrack and Complete Procedure Summary Pre-RiQ Work: 1. P&A existing perforations with 16 bbls cement from PBTD to -7975' MD 2. Drift 3-1/2" tubing and tag top of cement. 3. Chemical cut the 3-1/2",9.3#, L-80 tubing at -7920' MD. 4. Fluid pack T X IA with seawater and freeze protect same. 5. Flush Chemical injection line and install lock-out sleeve in SSSV. 6. Function all lock-down screws. Repair or replace as needed. 7. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU N2es./ 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. /' 3. Nipple down tree. Nipple up and test BOP7, Pull TWC. 4. Pull 3-1/2" tubing from above pre-rig cut. 5. Rig up e-line. Make GR/JB run to top of 3-1/2" tubing stub. 6. RIH with 9-5/8" CIBP. Set at -7780' MD. /' 7. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on CIBP. 8. Swap over to milling/drilling fluid. 9. Mill window in 9-5/8", 47# casing at 7750' MD. Drill 20' past middle of window. Perform FIT. POOH 10. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate interval, building at 5°/100' to a 20° hold angle. .// 11. Drill ahead to casing point at Top Sag River to an estimated depth of 8,262' MD. 12. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 7,750' ,,/,/' MD. Displace cement with mud. POOH. 13. MU 6-1/8" BHA with Dir/GR/Res/Den/Neu and RIH. / 14. Drill the 6-1/8" production interval building at 14°/100' to horizontal, targeting Z1A Ivishak. Drill aheaíV to an estimated TO of 11,647' MD. 15. Run and cement a 4-1/2" solid liner throughout the 6-1/8" well bore and back into the 7" liner. 16. Displace well to clean seawater. / I 17. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 18. POOH. LD DP and perf guns. / 19. Run 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 20. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 21. Set and test TWC. 22. NO BOPE. NU and test the tree to 5000 psi. I' 23. Freeze protect the well to -2200' and secure the well. 24. RDMO Post-Riq Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 15-20B Permit to Drill Page 4 ) 15-208 Drilling Program Job 1: MIRU Hazards and Contingencies > No wells will require well house removal or shut-in for the rig move onto 15-20B. The closest neighboring well is spaced as follows: 15-07 at -120'. Care should be taken while moving onto the well. Spotters will be used at all times. > Drill Site 15 is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name 15-07B 15-08B 15-39 15-06A H2S Reading 3ppm 9ppm No Data 8 ppm Date 02/07/01 03/08/01 N/A 03/05/01 The maximum level recorded of H2S on the pad was 33 ppm at 15-44 in 03/23/96. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP mmm);J;.mmm)mmmmmm»!mmm;.mmmmmmmmmmmm;-)mmmmmm~mmM.m:mmmm-m;);'mN;AA!mmmA;mm!AAfflu»mlmJImmmfflmmmmmmmm¡.;mmmm¡.mm¡.»;m,-lilllllaalllllllllllllllllllll1AA-¡.mmmm;;;.;m¡mmm;;¡ym;'¡'¡'II¡'.W,II)¡'I);p;m;,IA~~lm.l,Ißmm;.mmmmmmmmmmmmmmm;;.~;~D);JA:~mmmmmJ,w¡.m'-'-'-'-mmmm: Job 2: De-complete Well Hazards and Contingencies > 15-23 is currently Shut-in. Pre-Rig operations will include P&Aing the perforations in the 2-3/8" liner with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. > Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. > Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ¡-¡-IUII:I-U__lUmmlmmIlIIllIllIIllILUUIII_ _lIlInllll_IIIIIILIIILIlUlllmlmllllllllll_IUllllmmlll""'IIIIIIIII..nmllmmmmw"11I111I11I1111I111'411I11I1""_ JIIIIIII_ _11I111 -; IIInllllllllllllll_II_LlIIIIIIIIIII_I_IIJIIIIIIIII'''''IIINII.!I_ -1:mIllIIlIIllIIIllIIllIUIIIIILIIIIIII__L .II_JI. --I I-,T -lIdlll--_'- _1_ _L _11I11I11.111.1_ _1_ -on Job 4: Window Mill Hazards and Contingencies > Position bridge plug to avoid cutting a casing collar while milling the window. ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP 15-20B Permit to Drill Page 5 ) ') Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the CM1 sand package and TD at the top of Sag River. Since 15-20B will be at _200 inclination at a 2110 azimuth, maintain mud weight at minimum 10.0 ppg to interval TD. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12/.0 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP '11I1111\1111.- --~:IIIII:¡-- --11I1111:- _ t. -'11,11,:, --UWIU;I,-'-_-",=,L _'.I:III,Ll.lal_III:T,~_ ':I.-,-:III-.-IIIII-lIIr --L---'-, 1'\4.1\:1. :.,I~:u:,unUlII':U:II,_IL-.l.I-.lIII__III'_lIIunm"III,I,lllIIlIIllImlllnnlllIUII.,III:UIIII&IL,IUI_II_I,.. .,IIIIIIIIIIII,III,IIIUIIIIIIIIIIIIIIIIIIAIIIIII,IIIIIIII,IIII- _nnlll.llllllllllumm:- -¡I,II- _ mlll~III',IIIW·"'I!·"·W~.IIIIII,Ulllmlll'~mUI,IIIIII_, JL\L'IL_llllm:IllIlliI:I:m- Y'I. -:11I1111,1' Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There are no expected fault crossings in the production section. Lost circulation is considered low risk. There are no LCM restrictions. Follow the lost circulation decision tree should LC become problematic. ~ 15-13 has been 1/200 minor risk based to pass BP's anti-collision policy. It has a center to center distance of 280' at the closest point. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a / fracture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. 15-208 Permit to Drill Page 6 ) Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ~-~-WWl.-J- x" 'It.':I,-IAt,-- -~-_\'<XiJ!}(KI'<);I!K\-_'AA-- X'.\4,\I,--J(J)fJ«1-_"--ìl,\I,~f¡->mÞW}(;~:IAI.I.w.:.w.w.I,W,I,II.¡A~Ijõ,II',I,I,I~I,I,I~';'I;II~II~WJ.I.I.w¡"~~IA~w:m"'¡\;~I';'-,,-mwAlfl'-'-FfÞmmAAAA-~-~-fNrmm:,I~~-», w.m1AW~AAAI;.,-~I;.JA~- -,W,WAI.I:,W,W ~-¡,~::.--- --I<mM"I~AAW.IAW. /N.WJ,WAIJ.-""m_nv.'W!!J!I!ffT:rf.'~1¡., Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be ....650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend ....150' back up into the T intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program L -;1. .mLUlllml:TI....I. - 1,.:11"...1 1II1I:1;:1I:omo;:, -LUm_":I.;~_L)' l:m!l:~IIUlI;......;;aw:mm~a;L..I\....I,.I\.;;mmllllllmmHlmr;.....)mmmma--'llalllIlIl" . .......-111111I1-- X-11II111aI1I mr:-;-- .1. .nn. .aumnu-;....>.........;;IIi:.ml Job 10: DPC Perforate Production Casina Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP I'··· u'II,lmm'Lua::.aal,mll_···..···~,m__L..·V:IJ.IC,,!aU_C~_LU~V··.''''''\m~aaIfW'''''~IInmlm,aClal\~n~WU,mrv''~:,mllaumL~I,IU_V' V>c-·:~:,~L,~_C_..'v-··\I'~!:I/'· _U~," \I",U ,r 'U:I,IL,:_UU_ ,U¡~U., "~¡,-¥_~ -.r ,ICAI. ,-""-'f........" ...........I¡I.~........,,,,.........,.......y.\I'..... '-,- ...-,,'. ,''-'''11'' ..·..·......··...·.,~,:,"Y\I"G,I,'. ...., ....~.,'of' Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is .... 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 15-20B. The closest neighboring well is spaced as follows: 15-07 at ....120'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-208 Permit to Drill Page 7 ) 15-208 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no expected fault crossings in the intermediate hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · There are not close approach issues in the intermediate hole section. · Kick tolerance is infinite with a 12.0 ppg EMW FIT and 10.0 ppg mud. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · The intermediate hole section will be drilled with a recommended mud weight of 10.0 ppg to ensure shale stability in the HRZ and Kingak. Production Hole Section: · There are no expected fault crossings in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · 15-13 has been 1/200 minor risk based to pass BP's anti-collision policy. It has a center to center distance of 280' at the closest point · Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S // · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE DS15 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 15-208 Permit to Drill Page 8 15-20A s,...,lTY NOlES: 70° @ 8963' & > 90° @ 9191'. TREE = 5-1/8" FtvC GEN 3 WELLHEAD = FtvC 'ACfU£\ TOR = AXELSON KB. ELEV = . 71i B F.ËLË\/ = ? KOP::'; 8591' Max Äng Ie =96@9950' Datu m MD = 1 0869' DatumTVD = 8800' SS ) 1 13-3/8" CSG, 72#, L-80, ID = 12.347" 14 ~ 1 - ~I 2180' l-i 3-1/2" A VA TRSV SSSV, D = 2.812" I c ST rvD TVD 1 7876 7876 GAS LIFT M6..NDRB...S DEV TYPE VLV LATCH 1 FM10 DMY RK 3 KBUG DMY RK 4 FM10 DMY RK 1 FM10 DMY RK CHEMCAL M6..I'DRB...S DEV TYPE VLV LATCH 1 CA-KBUG DMY BK FDRT DATE o 09/27/02 o 09/27/02 o 09/27/02 o 09/27/02 2532' L ST rvD TVD 1 2907 2907 2 4880 4878 3 6627 6622 4 7736 7731 Minimum ID = 1.941" @ 7995' LINER TOP L FDRT DATE o 09/27/02 :8: Z" 7955' H 9-5/8" X 3-1/2" BAKERSB 3A PKR 1 I TOPOF2-3/8"LNR,D=1.941" 1--1 7995' 7990' H 2-318" DEA..OY MENT SLV, ID = 1.969" I I TOP OF 7" LNR H 8012" "'II I . 1 8043' r- 3-1/Z' 011S XN NO-GO NIP, ID = 2.80" (BEHND LNR) 1 I 8053' H 3-1/2" TUBING TAIL (BEHIND LI\R) ~ ~ 8045' H ELrvD IT LOGGED 11/04/89 1 13-1/2" lEG, 9.3#, L-80, .0087 bpf, ID= 2.992" H 8053' 95/8" CSG, 47#, L-80, ID= 8.681" H 8536' 1 TOPOF Cev1ENT H 8573' 1 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" H 9029' 1 PBlO H 10847' 1 2-3/8" Lt-R-Cf, 4.7#, L-80, .0387 bpf, ID = 1.941" H 10864' 7" SIDETRACK WII'DOW 8584' - 8586' ÆRFORð.110N SUMM6..RY REF LOG: N'A ANGLE AT TOP PERF: 85 @ 9022' Note: Refer to Production DB for historical perf data SIZE SPF INTERJ AL OprVSqz [)6. TE 1-11/16" 4 9022 -10032 0 07/26/99 1-11/16" 4 10142 - 10452 0 07/26/99 1-11/16" 4 10692 -10842 0 07/26/99 1 10 H 10865' 1 DAlE ÆVBY COMM:NTS DATE REV BY OOfvfv1ENTS PRUCHOE BAY UNrr 1984 ORlGNAL COMA..ETlON WB...L: 15-20A 10/30189 ÆRMT No: 1990480 07/28/99 SDETRACKED API No: 50-029-21133-01 04/03102 RNffP CORREC110NS sæ 22, T11 N, R14E 1408' FNL & 3946' FB... 09128/02 M-I/KA K GLV 00 02/13/03 OJ.Vtlh CORREC110NS 8P Exploration (Alaska) 15-20 Pre-Rig .- ~ ~I 2180' GAS LIfT !lllANDRElS ST MO TVDOEV TYPE VlV lATCH 1 2907 2907 FMHO OM'( RK [) 12.347" 2532' I 2 4880 4878 3 KBUG RK 0 6627 6622 4 FMHO DMY RK 0 4 7736 7731 1 FMHO OM'( RK 0 CHEMICAL TYPE =1 .. -1Tubing cut @ 7920' MDI 1955' x 3-1/2" BAKER S8 3A ---.,Top of Cement @ 7975' MD I 2·3/6" 4]#, L·80, .0387 [) '" 1.941" 1900' 2-3/8" DEPlOYMENT 2·318" LNR, ID: 1.941" 1995' I TOP OFf" LNR 8012' 8043' 3· 1 12" OTIS XN NO-GO NIP, 10: (8EHJND LNR) .0087 8053' I ~ ~ 8053' 8045' TUBING TAIL (BEHJND ELMO 1T LOGGED 11/04/89 8536' 8573' T' SIDETRACK WJNDOW 8584' . 8586' PERF ORA TION SUMIVIARY REF LOO: NlA TOP PERF: 85 @ 9022' Opn/Sqz o o o data DATE 07126/99 07126/99 [) 9029' I 10865' I SAFETY NOTES: 10" 8963' 8o:> 90" 9191', COMMß,¡rs 1984 ORIGINAL COMPLETION REV8Y COMMß,¡TS PRUDHOE SAY UNIT WELL: 15·20A PERMIT No: 1990480 API No: 50~029·21133·01 SEe 22, T11N, 1408' FNL 1& 3946' SIDETRACK (is-2M) CORRECTIONS MHlKAK GLV CORRECTIONS SP Exploration (AJa¡¡¡luI) 2532' ~ 7600' 7750' 7780' 7920' 7955' 8536' ~ 9029' 07-22-03 1 os Co Pr on - - '" ~ 13-3/8",72#, L-80 ""i4-1/2" X Nipple @ 2200'J - --14-1/2", 12.6#, L-80, IBT-M Tubing 1 9-5/8" X 7" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool Permanent Packer @ 8052' I 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool @ 8112' -<:::::: 17',26#, L-80, BTC-M @ 8,262'1 ,.. 9-5/8",47#, L-80 GLI\(I pe$ign: #3 - 3200' TVD - 4-1/2" X 1" #2 - 5700' TVD - 4-1/2" X 1" #1 - 7450' TVD - 4-1/2" Xi" Tij.bing TaU: -10' Pup Joint 3") Joint -Packer -20' Pup Joint -20' -XN Nipple (3.725") -10' Pup Joint -WLEG 14-1/2",12.6#, L-80, IBT-M Production Liner@ 11,647'1 2-3/8",4.7#, L-80 @ 10,864' TD @ 10,865' e .- ...--.--- ' 1·- . ,.-.a" ~ \~ .. ..i r r \ , ~i ~!E\..L to --~ ~ ~. tl; I ~ :~ Y·S9~Oln2.Ð32 ~~ x.677267.3S~ LAT-70o 17' 47.~5~" LONG-1480 33' S2,07~' CELLAR onx ElEV-29.33 \'.5'59985. 5'¡~ X..677Z~" .4$5 LAT-7C1° 17' 46.:'!1t,1I LONG-ll¡8° 33' 51.~(·1", CELLAR SOX ELEV·29.~7 7 8 Y.5~'59S69. 006 x-677321 .21" LAT "f700 17' ,. S. 14:,' · lONG.'~Bo 33' 50.~ÞO'~ CELLAR sox ElEVG~~.49 ~ V·595~7S~.056 ~ X-67734a.3tG ~ lATw700 171 '43.~P7' ~ LONGa 1 ~$O ;3' t¡~L !\~~fI CELLAR BOX ElEV-29.G] 9 10 Existing 11 Y"5~:9!iIS,'33 X..67ì402.o86 lAT-7C1o 171 It I. (,7:',11 LONGwl450 33' ~S.~~~ CELLAR ~~X £LEV~~~.14 \'.::5~·59Z¡(\ 1 . 8C· 1 X.677L.:!$.~Sb lAT-70o 17' 40.S=~' LONG-illS'" 33' 1;¡.~!.Z" CELlA~ fOX El(V-29.~3 12 t 3 Yr.~~\~~:!~4. 5' 3 x.~77!¡~6. 307 LAT-ìOo 171 39. 3~,:if! LONC..148° H' 47.'~7" CtLL^n ~ox tL£V·~~.¡~ .. - - ì e 5/9601102.832 EHTERt 677;267.3569 ~EQ P- H HEW=1/014.8279 E HEW=1/23B.2692 TttU . ~ 14&.. U ,.M.. .,. , .' Ii ~ ~ . , .' .1 5.959/985.545 ENTERt 6771294.4550 XEQ P. H HEW=894.4423 '1. E HEW:: 1. 230 ~ 2900 gt!f~¡..!~i~ l' ! ~ 1:·E ¡:¡ u. w ;1 5,959/S69.ee6 EHTERt 6771321.2740 XEQ ~ N HEW:::774.8486 8. E HEW=lJ230.2062 ~ 5.959,752.056 EHTE~t 677,348.3168 XEQ ~ H HEW=654.S042 ~. E HEW= L 230. 2473 t ~ 5/959,518.333 EHTERt 677,402.0860 XEG R , H NEW=414.9~e5 , . E HEW=1,230.9&33 . ~~ °M1a ....;O~ 0., ~ ~ .. ~1·.,oOøC.-ð, .. ~C.II ~, t~_.-~-~ ~'..m ~: z· -'·0 ~~:~ ... .. flfi"~ . ~' L I:' Yr'!,·'!.9Jt~7.6S6 . r .--J'ß't.(P·'bð Xr(.'!71IS3.202 ,II ....~,...."\'\'\\\ l^T.-7()c, 17' 38.21::" -~ OF Ai. \, . lONGr I:t r-o 33 4L "2.3" ;--:....;.........·;.,..~.S~t. CCL L/Î~ (' C'X !:L t V.2~. (~$ '~/·· "':7.. "Va,. *' .. . 49th;';" \ · ~ ...... ~.r.:.",,~O, S~7 g~. ,._..~U .......... ..1... ~ >.1!..:ì~.O.O\O ~... «.. · ..~ J 'T'" ,c· 171 37 05Z" ~ '\ GAil'" CIIEI4S"~W ~i! \, I. , . . ..... II.. .:71.S ... ~~ lo::r,,'I:.~¡\\ )31 {¡S.:'::')·' "'f .... "-~~ nu,\!; H'~ CL(\!·~9.::'!J ,. 5,959,167.856 ENTERt ,. HEREBY CERTIFY 677 /4S3. 2920 XEQ ~ PROPERLY AEGI$l4.. H NEW::55.1911 I.ICENSEO TO pr E NEW=l,239.2697 SURVEYING IN T AI.ASKA At'lt> TH REPRESENTS AN AI MADE BY ME. A DIMCNSIONS AND I ARE CORRECT. AS ~ 5/959,481.891 EHTEP.~' 677i42a.986B XEQ R t2.. H HEW-=295.4314 E HEW=1/239.0?60 5,959,284.513 EHTERt 677/456.3978 XEg ~ . \~. N HEW=-174.9169 . E HEW=-1/239.2969 . ' ... ¿t 1'+ t !. 5J95919S8.587 EHTERt 6771519.0190 XEQ A ~ H HEW=--65.1115 , · E HEW;1 i 2)13. BB2e . - - - - . D.S. 1151.WE:LL~ ~1-', \1-\? ~10 A.S-5·UILT AU::ntlcRlchfieldCompany 0 . DATE: . DRAV/INO No: NORTH AMERICAN PRODUCING DIVISION .,... IAI . A_\O'fSLA . ALASKA DISTRICT - PRUDHOE BAY II WiI¡CJ ~ Mil"" _.... ... _1 0'-' II r\ T J 0 ,/ ~ '" / e t""'I O~T7~* ~~~~n~~NH WO~~ COMPANY DETAILS BPe Amoco JŒFERENC£ INFORMATION SURVEY PROOR..4M Depth Fro J:'Ñ1AA To Sl,Ii'YeyIPIan 1751100 llMno Planned; JS~2{}Bwp05 VIS Created By: Ken AUen Clwcked; Pm"' 15·20B wp05 itS-lO!?"," 15·208; Date; 112812:003 Date-:_ FORMATION TOP DETAILS No. TVDPaÛ1 MDPaÛ1 J:"ormation 1 7779.83 2 7964.83 3 8017.83 4 8049.83 5 8145.83 6 8238.83 7 8279.83 8 8347.83 9 8499.83 10 8567.83 ¡¡ 8800.83 12 8844.83 CASING DETAILS No. TVD MD Name Size I 8262.40 7" 7.000 2 11647.19 4112" 4.500 Tool MW(} Reviewed: WF.LL DETAILS ~ +N!~S +FJ·W Nt>rtWng 15·20 1242.44 999$5 S960lf.11Jß Basting Latìtude 671261,35 1Wl1'41A55N 148"33'52.070W 20 TARGET DETAILS ""'" _s¡,.", , I SECTION DETAILS I See MD Ine Azì TVD +Nj·S +EI·W DLeg TFaæ I I 7750.00 0.99 11!1.40 7744.96 HJO.81 158.13 0.00 0.00 ; 2 7770.00 3.39 181.40 7764.94 100.04 158.11 ¡/ 12.00 0.00 3 8240.4 1 24.56 221.39 8218.83 0.48 108.73 4.95 24.53 I 4 8262.40 2456 221.39 8238.83 -6.38 102.68 0.00 0.00 5 8277.40 24.56 221.39 8252.47 -11.06 9856 0.00 0.00 I 6 8611.09 57.93 221.39 8499.83 -173.80 -44.85 IQ.OO 0.00 SIart Oil' 121100': 7750' MD. 7744.%'TVD 7 8739.16 57.93 221.39 8567.83 -255.22 ·I1MI 0.00 0.00 .I 8 8905.68 74.55 220,21 8634.69 -370.25 -215.77 10.00 -3.96 Start D"4.9$/IOO': 7770' MD, 7764.94'TVD 9 9220.49 74.55 220.21 871 855 -601.97 -411.67 0.00 0.00 I 10 9286.71 71.63 214.00 8737.83 -652.44 449.89 10.00 ·Jj7.!J4 11 9408.1!6 71.63 20U3 .754.95 -503.40 10.00 -92.03 7800 .I 12 9513.57 71.63 20U3 -847.65 -539.22 0.00 0.00 13 9695.93 81.00 185.00 -1019,53 -578.59 10.00 -61.25 ~ 14 10016.10 92.22 154.91 -1330.04 -523.09 10.00 -70.90 15 10335.68 92.22 154.91 -1619.24 -387.67 0.00 0.00 16 10486.99 90.74 145.95 -1750.67 -313.10 6.00 -99.25 17 11027.12 90.74 145.95 -2198.15 -10.69 0.00 0.00 18 11205.85 90.00 135.25 -2336.05 102.59 6.00 -93.89 19 11647.20 90.00 135.25 -2649.49 413.30 0.00 0.00 8100 ¡;¡' :E g t1 i Q ~ 8400 '12 ~ ~ End [)i, : 824O.4!' MD, 8218.83' TVD Start D¡, 10/100' ; 8277.4' MD, 82$2.47'TVD Start Pi, 101100'; 8739.16' MD,8567.83'TVD 8700 9000 o 300 600 900 1200 1500 Vertical Seclion at 171.15" [300!ìlin] 1800 2100 Dltte:_ ~ Slot vSec Target 575.42 15-2013 TU 668.47 754.55 918.33 15-20B n.l 1233.67 1540.28 15-20B T3.1 1681.61 2170.31 2324.00 2681.53 ¡ ¡ 2400 2700 COMPANY DETAILS fir Amoro REFERENCE INFORMATION SURVEY PRQQR;.--\M Depth Fro !)eptb To SurvcyJPlan 77S¡¡,W H647.20 ~ 1$-200 wp% VIS P!;¡n, 15·2013 wpOS (! 5·201Plan 15-208) Too' MW¡¡ Created By: Ken Allen Checked: DMe:1JZ8!2003 ¡¡are RevÎewed: Dare,_ WELL DETAILS Name +N/·S t£j·W Nortb.íng 15-20 1242.44 999.85 5960-102$3 - L_ LQtjg~ Slot 671ZÕ73S 1if1T47A55N !4&*3J'5;!.07o-W 2Q TARGET DETAILS "- TVD -iN/-S +Ef~W Northing _5"",", SECTION DETAJLS See MD Ine Azi TVD +NI-S +EI-W DLeg Thee VSee Target 0 I 7750,00 0.99 181.40 7744,96 100,81 158,13 0.00 OJJO -75.27 2 7770.00 339 181.40 7764.94 100.04 158JI 12.00 0,00 -74.52 3 2456 22139 8218.83 0.48 108.73 4.95 24,53 16.27 4 24.56 22139 8238.83 -6.38 102.68 0.00 0.00 22.11 5 24.56 221.39 8252.47 -11.06 98.56 0,00 0.00 26.10 6 8611.09 57.93 221.39 8499.83 -173.80 -44.85 10.00 0.00 164.82 7 8739.16 57,93 221.39 8567.83 -255.22 -116.61 0.00 0.00 234.23 8 8905.68 74.55 22021 8634.69 -370.25 -215.77 10.00 -3.96 332.63 9 9220.49 74.55 22021 -601.97 -41L67 0.00 0.00 531.43 10 9286.71 7L63 214.00 -652.44 -449.89 10.00 ·117.04 575.42 15·2013 TU II 9408.86 7L63 20Ll3 -754.95 -503.40 10.00 -92.03 668.47 -600 12 7L63 20U3 8809.47 ·147.65 ·539.22 0.00 0.00 754.55 13 81.00 185.00 8852.83 -101953 ·578.59 10.00 -61.25 918.33 1 5-20B T2. 1 14 92.22 8872.19 - 1330.04 -523.09 10.00 ·70.'JO 1233.67 15 92.22 8859$3 -161924 -387.67 0.00 0.00 1540.28 15·20B T3J 16 90.74 8855.92 ·1750.67 -313.10 6.00 -99.25 168L61 " !7 90.74 8848. 98 ·2198.15 ·10.69 (tOO 0.00 2170,,1 I 18 90.00 8847.83 ·2336.05 102.59 6.00 ·93.89 2324.00 19 90JJO 8847.83 -2649.49 4l3.30 0.00 0.00 268L53 :£ CASING DETAILS "Ë ·1200 No, TVD MD Name Size '" ~ 1 8238.83 7" 7.000 :ã 2 8847,83 4112" 4.500 Š '" FORMA.TION TOP DETAILS No. TVDPatb MDl'ath FormalÌon ø I 7779.83 THRZ ·1800 I 2 7964.83 BHRZ 3 8017.83 ; 4 8049.83 5 8145.83 ; 6 8238.83 7 8279.83 ; 8 8347.83 9 ; 10 11 ;. 12 8844 ·2400 JP ; .I I l ·3000 ·1800 ·1200 -600 0 We5t(- )lEast( +) [60{)ftJlnj ) BP KW A Planning Report ) Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: Alaska, Zone 4 Well Centre bggm2003 70 17 35.236 N 148 34 21.213 W True 1.34 deg Well: 15-20 Slot Name: 20 15-20 Well Position: +N/-S 1242.44 ft Northing: 5960102.83 ft Latitude: 70 17 47.455 N +E/-W 999.85 ft Easting : 677267.35 ft Longitude: 148 33 52.070 W Position Uncertainty: 0.00 ft Wellpath: Plan 15-20B Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 57.83' 5/22/2003 57569 nT Depth From (TVD) ft 26.83 +N/-S ft 0.00 Height 57.83 ft Plan: 15-20B wp05 Date Composed: Version: Tied-to: Principal: Yes Casing Points 15-20 7750.00 ft Mean Sea Level 25.75 deg 80.86 deg Direction deg 171.15 5/27/2003 15 From: Definitive Path 8262.40 8238.83 7.000 8.500 7" 11647.19 8847.83 4.500 6.125 41/2" Formations ··MD ~~th~.o~Y J)ip ~lIgle J)ip J)ireçtii)n It . ·.:d~g d~g, ... .. 7784.92 7779.83 THRZ 0.00 0.00 7972.04 7964.83 BHRZ 0.00 0.00 8026.60 8017.83 LCU/T JC 0.00 0.00 8059.84 8049.83 TJB 0.00 0.00 8161.23 8145.83 TJA 0.00 0.00 8262.40 8238.83 TSag 0.00 0.00 8307.86 8279.83 Shu 0.00 0.00 8387.77 8347.83 TZ4B 0.00 0.00 8611.09 8499.83 TCngl 0.00 0.00 8739.16 8567.83 TZ2 0.00 0.00 9486.16 8800.83 TZ1B 0.00 0.00 9650.79 8844.83 TZ1A 0.00 0.00 Targets Map Map <- Latitucle --> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg. 1\1In ·Sec Dip. Dir. ft ft ft ft ft 15-20B T1.1 8737.83 -652.44 -449.89 5959440.00 676833.00 70 17 41.038 N 148 34 5.182 W 15-20B T4.1 8847.83 -2336.05 102.59 5957770.00 677425.00 70 17 24.480 N 148 33 49.080 W ) BP KW A Planning Report Targets 15-20B T5.1 8847.83 -2649.49 413.30 5957464.00 677743.00 70 17 21.397 N 148 33 40.027 W 15-20B T2.1 8852.83 -1019.53 -578.59 5959070.00 676713.00 70 17 37.428 N 148 34 8.932 W 15-20B Poly 8852.83 -1073.90 -436.83 5959019.00 676856.00 70 17 36.893 N 148 34 4.801 W -Polygon 1 8852.83 -1073.90 -436.83 5959019.00 676856.00 70 17 36.893 N 148 34 4.801 W -Polygon 2 8852.83 -1098.91 -733.52 5958987.00 676560.00 70 17 36.647 N 148 34 13.447 W -Polygon 3 8852.83 -1506.89 -613.10 5958582.00 676690.00 70 17 32.635 N 148 34 9.937 W -Polygon 4 8852.83 -1744.20 -433.64 5958349.00 676875.00 70 17 30.301 N 148 34 4.707 W ·Polygon 5 8852.83 -2231.82 -287.09 5957865.00 677033.00 70 17 25.505 N 148 34 0.435 W ·Polygon 6 8852.83 -3127.04 684.13 5956993.00 678025.00 70 17 16.701 N 148 33 32.137 W -Polygon 7 8852.83 -2785.89 810.22 5957337.00 678143.00 70 17 20.056 N 148 33 28.462 W -Polygon 8 8852.83 -2235.59 551.11 5957881.00 677871.00 70 17 25.468 N 148 33 36.011 W -Polygon 9 8852.83 -1338.38 -420.06 5958755.00 676879.00 70 17 34.292 N 148 34 4.312 W 15-20B T3.1 8859.83 -1619.24 -387.67 5958475.00 676918.00 70 17 31.530 N 148 34 3.367 W Plan Section Information ¡:' ..··:Ï)...~¡:::aµ~I~, ... , ,¡~eg/~ PP~ld:~9/1PQ~ 7750.00 0.99 181.40 7744.96 100.81 158.13 0.00 0.00 0.00 0.00 7770.00 3.39 181.40 7764.94 100.04 158.11 12.00 12.00 0.00 0.00 8240.41 24.56 221.39 8218.83 0.48 108.73 4.95 4.50 8.50 24.53 8262.40 24.56 221.39 8238.83 -6.38 102.68 0.00 0.00 0.00 0.00 8277.40 24.56 221.39 8252.47 -11.06 98.56 0.00 0.00 0.00 0.00 8611.09 57.93 221.39 8499.83 -173.80 -44.85 10.00 10.00 0.00 0.00 8739.16 57.93 221.39 8567.83 -255.22 -116.61 0.00 0.00 0.00 0.00 8905.68 74.55 220.21 8634.69 -370.25 -215.77 10.00 9.98 -0.71 -3.96 9220.49 74.55 220.21 8718.55 -601.97 -411.67 0.00 0.00 0.00 0.00 9286.71 71.63 214.00 8737.83 -652.44 -449.89 10.00 -4.41 -9.38 -117.04 15-20B T1.1 9408.86 71.63 201.13 8776.47 -754.95 -503.40 10.00 0.00 -10.54 -92.03 9513.57 71.63 201.13 8809.4 7 -847.65 -539.22 0.00 0.00 0.00 0.00 9695.93 81.00 185.00 8852.83 -1019.53 -578.59 10.00 5.14 -8.84 -61.25 15-20B T2.1 10016.10 92.22 154.91 8872.19 -1330.04 -523.09 10.00 3.50 -9.40 -70.90 10335.68 92.22 154.91 8859.83 -1619.24 -387.67 0.00 0.00 0.00 0.00 15-20B T3.1 10486.99 90.74 145.95 8855.92 -1750.67 -313.10 6.00 -0.98 -5.92 -99.25 11027.12 90.74 145.95 8848.98 -2198.15 -10.69 0.00 0.00 0.00 0.00 11205.85 90.00 135.25 8847.83 -2336.05 102.59 6.00 -0.41 -5.99 -93.89 15-20B T4.1 11647.20 90.00 135.25 8847.83 -2649.49 413.30 0.00 0.00 0.00 0.00 15-20B T5.1 Survey . MD Incl Azim TVD Sys 'fVD MaþN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/100ft deg 7750.00 0.99 181.40 7744.96 7687.13 5960207.33 677423.05 -75.27 0.00 0.00 MWD 7770.00 3.39 181.40 7764.94 7707.11 5960206.57 677423.05 -74.52 12.00 360.00 MWD 7784.92 4.07 182.60 7779.83 7722.00 5960205.60 677423.03 -73.56 4.54 7.22 THRZ 7800.00 4.74 183.95 7794.87 7737.04 5960204.44 677422.99 -72.43 4.54 9.38 MWD 7900.00 9.24 192.45 7894.10 7836.27 5960192.38 677421.45 -60.83 4.61 17.20 MWD 7972.04 12.53 198.23 7964.83 7907.00 5960179.21 677418.06 -48.47 4.81 21.21 BHRZ 8000.00 13.74 200.95 7992.07 7934.24 5960173.21 677416.09 -42.91 4.86 28.42 MWD 8026.60 15.01 202.97 8017.83 7960.00 5960167.03 677413.76 -37.24 5.13 22.48 LCUIT JC 8059.84 16.50 205.90 8049.83 7992.00 5960158.78 677410.17 -29.76 5.06 29.71 TJB 8100.00 18.24 209.45 8088.17 8030.34 5960148.08 677404.87 -20.16 5.09 32.92 MWD 8161.23 21.07 214.57 8145.83 8088.00 5960130.41 677394.33 -4.65 5.40 33.82 TJA 8200.00 22.74 217.95 8181.82 8123.99 5960118.58 677386.08 5.53 5.41 38.51 MWD 8240.41 24.56 221.39 8218.83 8161.00 5960105.87 677376.03 16.27 5.64 38.74 MWD 8262.40 24.56 221.39 8238.83 8181.00 5960098.87 677370.15 22.11 0.00 180.00 TSag 8277 .40 24.56 221.39 8252.47 8194.64 5960094.10 677366.14 26.10 0.00 180.00 MWD ) BP KW A Planning Report ) ......::::::.::,::...::..:. .....":" ::.... ::."': ,Pª<> ~g¡~::·;:¡2é·:>:< .'........ ...... ,. e..·;.,3> '.. :.i~~~~ ;.. ..;'. ,..·..';·····š'*tl. . ·.~.~.··ñry~...,~~~~.··...;...';'... ...,.':..¡... (VS) Reference: . . Wëli (0.00N,0.ÖOE.171.15Äzi)· , ... ··.S~ry~ý:ÇJ~~~~~~tl<fti.~~r~pª::) T ···MihjmºmgºrY~tlirØ: ··'·:pþ:Q'rac,le' Survey 8300.00 26.82 221.39 8272.84 8215.01 5960086.60 677359.84 32.37 10.00 360.00 MWD 8307.86 27.61 221.39 8279.83 8222.00 5960083.84 677357.52 34.67 10.00 0.00 Shu 8350.00 31.82 221.39 8316.42 8258.59 5960067.86 677344.09 48.02 10.00 360.00 MWD 8387.77 35.60 221.39 8347.83 8290.00 5960051.81 677330.61 61.43 10.00 0.00 TZ4B 8400.00 36.82 221.39 8357.70 8299.87 5960046.28 677325.96 66.05 10.00 0.00 MWD 8450.00 41.82 221.39 8396.36 8338.53 5960022.03 677305.59 86.30 10.00 360.00 MWD 8500.00 46.82 221.39 8432.12 8374.29 5959995.29 677283.12 108.64 10.00 0.00 MWD 8550.00 51.82 221.39 8464.70 8406.87 5959966.27 677258.74 132.88 10.00 0.00 MWD 8600.00 56.82 221.39 8493.85 8436.02 5959935.18 677232.62 158.85 10.00 0.00 MWD 8611.09 57.93 221.39 8499.83 8442.00 5959928.04 677226.61 164.82 10.00 360.00 TCngl 8700.00 57.93 221.39 8547.04 8489.21 5959870.35 677178.15 213.01 0.00 0.00 MWD 8739.16 57.93 221.39 8567.83 8510.00 5959844.94 677156.80 234.23 0.00 0.00 TZ2 8750.00 59.01 221.30 8573.50 8515.67 5959837.87 677150.86 240.15 10.00 356.04 MWD 8800.00 64.00 220.92 8597.34 8539.51 5959804.10 677122.77 268.41 10.00 356.09 MWD 8850.00 68.99 220.57 8617.27 8559.44 5959768.68 677093.68 298.12 10.00 356.27 MWD 8900.00 73.98 220.25 8633.15 8575.32 5959731.87 677063.82 329.05 10.00 356.41 MWD 8905.68 74.55 220.21 8634.69 8576.86 5959727.62 677060.39 332.63 10.00 356.51 MWD 9000.00 74.55 220.21 8659.81 8601.98 5959656.83 677003.35 392.19 0.00 0.00 MWD 9100.00 74.55 220.21 8686.45 8628.62 5959581.79 676942.88 455.34 0.00 0.00 MWD 9200.00 74.55 220.21 8713.09 8655.26 5959506.74 676882.41 518.49 0.00 0.00 MWD 9220.49 74.55 220.21 8718.55 8660.72 5959491.36 676870.01 531.43 0.00 0.00 MWD 9250.00 73.23 217.47 8726.74 8668.91 5959468.87 676852.76 550.51 10.00 242.96 MWD 9286.71 71.63 214.00 8737.83 8680.00 5959440.00 676833.00 575.42 10.00 243.73 15-20B T1.1 9300.00 71.59 212.60 8742.02 8684.19 5959429.30 676826.33 584.77 10.00 267.97 MWD 9350.00 71.52 207.33 8757.85 8700.02 5959387.68 676803.62 621.71 10.00 268.41 MWD 9400.00 71.60 202.06 8773.68 8715.85 5959344.15 676784.84 661.22 10.00 270.08 MWD 9408.86 71.63 201.13 8776.47 8718.64 5959336.27 676781.93 668.47 9.99 271.75 MWD 9486.16 71.63 201.13 8800.83 8743.00 5959267.23 676757.11 732.02 0.00 0.00 TZ1B 9500.00 71.63 201.13 8805.19 8747.36 5959254.87 676752.66 743.39 0.00 0.00 MWD 9513.57 71.63 201.13 8809.47 8751.64 5959242.75 676748.31 754.55 0.00 0.00 MWD 9550.00 73.41 197.80 8820.41 8762.58 5959209.74 676737.51 785.14 10.00 298.75 MWD 9600.00 75.94 193.32 8833.63 8775.80 5959163.01 676725.69 829.03 10.00 299.75 MWD 9650.00 78.55 188.95 8844.67 8786.84 5959114.97 676717.42 874.85 10.00 300.94 MWD 9650.79 78.59 188.88 8844.83 8787.00 5959114.20 676717.32 875.59 10.00 301.90 TZ1A 9695.93 81.00 185.00 8852.83 8795.00 5959070.00 676713.00 918.33 10.00 301.92 15-20B T2.1 9700.00 81.13 184.61 8853.46 8795.63 5959065.99 676712.76 922.23 10.00 289.10 MWD 9750.00 82.80 179.85 8860.45 8802.62 5959016.50 676712.00 970.80 10.00 289.16 MWD 9800.00 84.52 175.13 8865.98 8808.15 5958966.94 676715.35 1020.18 10.00 289.82 MWD 9850.00 86.28 170.43 8869.99 8812.16 5958917.68 676722.78 1069.98 10.00 290.34 MWD 9900.00 88.05 165.75 8872.46 8814.63 5958869.09 676734.24 1119.83 10.00 290.72 MWD 9950.00 89.85 161.08 8873.38 8815.55 5958821.55 676749.63 1169.35 10.00 290.95 MWD 10000.00 91.64 156.41 8872.73 8814.90 5958775.41 676768.83 1218.17 10.00 291.04 MWD 10016.10 92.22 154.91 8872.19 8814.36 5958760.91 676775.81 1233.67 10.00 290.98 MWD 10100.00 92.22 154.91 8868.94 8811.11 5958685.85 676813.14 1314.17 0.00 0.00 MWD 10200.00 92.22 154.91 8865.08 8807.25 5958596.38 676857.63 1410.11 0.00 0.00 MWD 10300.00 92.22 154.91 8861.21 8803.38 5958506.92 676902.13 1506.05 0.00 0.00 MWD 10335.68 92.22 154.91 8859.83 8802.00 5958475.00 676918.00 1540.28 0.00 0.00 15-20B T3.1 10350.00 92.08 154.06 8859.29 8801.46 5958462.23 676924.4 7 1553.99 6.00 260.75 MWD 10400.00 91.59 151.10 8857.69 8799.86 5958418.44 676948.52 1601.36 6.00 260.72 MWD 10450.00 91.10 148.14 8856.52 8798.69 5958375.93 676974.80 1647.85 6.00 260.63 MWD 10486.99 90.74 145.95 8855.92 8798.09 5958345.38 676995.65 1681.61 6.00 260.56 MWD 10500.00 90.74 145.95 8855.76 8797.93 5958334.78 677003.18 1693.38 0.00 0.00 MWD BP KW A Planning Report ) Survey 10600.00 90.74 145.95 8854.47 8796.64 5958253.28 677061.11 1783.86 0.00 0.00 MWD 10700.00 90.74 145.95 8853.19 8795.36 5958171.78 677119.03 1874.33 0.00 0.00 MWD 10800.00 90.74 145.95 8851.90 8794.07 5958090.28 677176.95 1964.81 0.00 0.00 MWD 10900.00 90.74 145.95 8850.62 8792.79 5958008.79 677234.88 2055.29 0.00 0.00 MWD 11000.00 90.74 145.95 8849.33 8791.50 5957927.29 677292.80 2145.77 0.00 0.00 MWD 11 027.12 90.74 145.95 8848.98 8791.15 5957905.18 677308.51 2170.31 0.00 0.00 MWD 11050.00 90.64 144.58 8848.71 8790.88 5957886.70 677321.98 2190.89 6.00 266.11 MWD 11100.00 90.44 141.59 8848.23 8790.40 5957847.45 677352.94 2235.00 6.00 266.09 MWD 11150.00 90.23 138.59 8847.94 8790.11 5957809.87 677385.91 2277.83 6.00 266.06 MWD 11200.00 90.02 135.60 8847.83 8790.00 5957774.07 677420.80 2319.25 6.00 266.05 MWD 11205.85 90.00 135.25 8847.83 8790.00 5957770.00 677425.00 2324.00 6.01 266.04 15-208 T4.1 11300.00 90.00 135.25 8847.83 8790.00 5957704.72 677492.84 2400.27 0.00 0.00 MWD 11400.00 90.00 135.25 8847.83 8790.00 5957635.39 677564.89 2481.28 0.00 0.00 MWD 11500.00 90.00 135.25 8847.83 8790.00 5957566.05 677636.94 2562.29 0.00 0.00 MWD 11600.00 90.00 135.25 8847.83 8790.00 5957496.72 677708.99 2643.30 0.00 0.00 MWD 11647.20 90.00 135.25 8847.83 8790.00 5957464.00 677743.00 2681.53 0.00 0.00 15-208 T5.1 P055110 DATE INVOICE I CREDIT MEMO GROSS DESCRIPTION 7/14/2003 INV# PR071 003 PERMIT TO DRIll ~EE ,5~ ~Oß 11 i: J t.) L~ [.~ '¿ *.1 ~..,,- THE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATIONAL CITY BANK Ashland, Ohio PAY: .................................. C!J.. .....U\D..· .. . tf.. /'lpr (llIb.t t":.t.........·.(......·.:::..·" :::-:--:-D .. r- . . ~ 111,1- trip - -. ~U'íl DATE TO TH E ORDER OF: ... . ".-- - _. __,"_ __ _n -.- --.-".-. -"---"--- . -. ALASKA Oil &GA.·.·.S. CQNSËRV.Ä.uTION CeM... MIS. S.ION . . ._ ___ - __ u._ ____ 333 WEST 7TH AVE NljE, STE 100u.. ANCHORAGE,ALJ\SKA 99501-3539·· 111055 ~. .0111 1:0 ~ ¡. 20 ~B '15-: O1. 2 ?B 9 bllll DATE 7/14/2003 CHECK NO. 055110 VENDOR DISCOUNT NET H 56~389 412 No. P 055110 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *~~;t**$1ØO. 00******« .:- ---" - . --. . NrALlotFA nQ~\;':' .;.\j;;',~ </\, ;;~.;::.:~~\ I. ". ¡.~::~. ...... "'~' ...... ...... ."... 4t,T ¿,-";i'u;"~~;I;;;;~~~\¡;ii~:¿:::J;;j -" ) ) , TRANSM1TAL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production. should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055.. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~~'J:»~~.,~:r·~~~~~~l~!: Company .JiE...EXP.L.QJ3ATIO[\l(A.L8SJSALIJ~.c __._.____________.___ Well Name: J~BU.QtI.QI;:__':~8':CU.~Jj____L5~2.P.6..__.._..___. Program J1E~___. Well bore seg PTD#: 2031360 Field & Pool _ERUJ:>.I:lQE..BAY.J?RUQHQE.QI.L...::..6A.Qj.5.0_._____________ Initial Classrrype _QE.V_lJ.:-.QlL._ GeoArea _8_9..0 Unit .1..1.6..50_ On/Off Shore -ºD_ Annular Disposal Administration 11 .Permitfe~ attache.d. Yes. 12 .Lßase.numÞ~rappropriate. Yes. . . . . . . . . . . . . . . . . . !3 .U.n[que well.n.ame.anQ IJLl.IlJb.er . . _ _ . . . . . . . . .. . . _ . .. .. . . .. . . . . . . . . . . . . . . . . Yes. . . . . . . . . _ _ .. . . . _ _ .. .. . . . . . .. . _ . _ . . .. . . _ . .. . . . . .. . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . 14 .WelUQcated in.a. d.efine.d .PPol. . . Yes. i5 WelUQcated pr.oper .distance. from drilling unit b.ounda(y Yes i6 .Well.lQcated prop~r .distance. from Qtb~.r WßI!s . . . . . . . Yes. . . . . . . . 17 .S.ufficißnt.acrßage.ayailable in.d.rilJing un.it. . . . Yes. . .. . . . 18 .If.deviated,.is. weJlbQre platinclu.ded . Yes ...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .Qpßrator only affected party. . Yes. . . . . . . . . . . . 10 .Qperatorbas.apprppriate.QOIlq [nJQrçe . . ." .. .. . . . . . . . . . . . . . . . . _. . . . . . . Yes. .. . . . . _ . . . . . . . . . . . . '" . .. . . . . . . .. . . .. . . . . . . . . . _... . .. . ... . . . . . . . . . . . . . . . . . . . . . . 11 .Permit c.ao be issu.ed .wjtbQut co.ns~rva.tion ord~r.. Yes. . 12 .Permit c.ao þe i.s$u.ed .witbo.ut ad.ministrati\(e.apprpval . . . . . . . . . . Yes 8/1/2003 13 Can permit be approved before 15-day wait Yes 14 .WeJI.lQcated within area an.d.strata .authorized by.lnjectiPIJ Order # (put 10# in. cpmm.ents). (For. NA. . . . . . . . . . . . . . . . . . . . . . 15 _AJI welJs. within .1l4.llJile.area.of reyiew jdeot[fieQ (Fpr s.ervjc.e well 9nly). . . . . . . . . . . . . . . Nf\. . . . . . . . . . . . . . . . . . . . _ . .. .. . . . . .. . . . .. . . . . . . . . . . . . _ . . . . .. . . . . . . .. . . . . .. . . . . . . . . .. . . . .. 16 .p.re-proQuçed. injector; .duratio.n.of pre,,:pro.ductiOIJ less. than. 3 months. (For.service well QnJy) . . Nf\. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 A.GMP. fin.ding .of CQn.si.ste0 cy. h.as Þee.n.is.sued. for. tbis pr.oj.ect. . . . . . . . . . Nf\. . . . . .. . . . . . . . . . . . . . . . . . . .. . . . . . . . --- --,"------.'"..-.----...-----.--,--.-----------------.--.."--.---------. --~.._-~-----,---. -_.._---~------ Appr RPC Date -----~-~._-_..._-- Engineering Appr Date WGA 8/1/2003 [J [] - - - - - - - ~ - - - ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - ( ~ - - - - - _._..._._._--~----._..- 18 .C.OnQU.ctor strin.g.p.rQvided. . . . . . . . . . . . . . . . . . .. ... .NA . . . . . . . . . . . . . . . . . 19 .S.urface.cas.ing.PJQtec.t6. alLknown USDWs . . . . . NA .. 20 .CMTv.ol.adequ.ate.to çircJJl.até.o.n.cond.uctor.& su.rtcsg . . . . . . . . . . . . . . . . .NA . _ .. . . . _ . . . . . . . . . . _ .. . . . . . . 21 .CMT v.ol. adequ.ate.to tie-i.nJQng .string to.s!JrJ csg. .. ".' . . . . . .. . .. . . . . .. . . . . NA 22 .CMT. wil.1 coyer.aJll<lJo.w.n.Pfo.ductiye bQri:ZQn.s . . . . . . . . . . . . .Yes 23 .C.asi(1g de.signs aclequa..t~ fp( C,.T., B.&.permafrpst. . . . . . . . . . . . . . _ . . . . . . . _ . Yes. . . . _ . . .. . .. . . . .. .... ....... 24 .A.dequate.tan.kage.oJ fe.Serye pit. . . . . . . . . . Yes. _ . . . .. _ ~ab.ors.2.ES.. . . 25 Jf.a.re-.drill., has.a. 1.0:-4,03 fo.ral;>andon.ment þeen apprQved . . . . . . . . . . . .Yes .. . .. . . . . 7/25/20.03... 26 .A.dequate.we!lþore s.epªratjo.n.Pfop9se.d. . . . . . . _ . . . . . . . . _ . . . . . . _ _ _ . . . . . . . .YJ3$ _ _ . . . . . . . _ _ . . . _ _ . _ . . . . _ _ .. . .. . _ . .. .. _ . _ .. . . . . .. . . . _ .. . . _ . _ . . . _ .. . . . _ . . . _ . . . . . . . . .. . . 27 Jf.djvect~r .req.ui.red, dQeß jt meet rßguJatiolJs. .. . . . .. . . . . . .NA . . . Sid~traçk. .. . . . . . . . . . . . . . _ . . .. . . . . 28 .D.rillio9 fluid. prog.ram sc.hematic.& eq.uipJistadequale. . . . . . . . . . . . . Yes. . . . .. . . Max MW.1.0,0.Ppg· ~ ....... . . . . . . . . 29 .BOPEs,.d.othey meetrßgu.la.tiolJ . . . . . . . . . . . . . . .. . . . Yes . . . . . . . . . . . . . . . .. . .. . . .. . . . . . . . . . . . 30 .B.OPE.PfeS$ ratiog approp(iate; .testto.(pu.t PSig in.commßlJts). . Yes. . Testtp .3500. psi. .M$R 27.13 psi.. . . . '. . . . . . . .. . . . . . . _ . . . . . . . . . . . . 31 .C.hoke..manjfold CQnJpJies. w/API. RP-53 (May ß4) . . . . . _ _ .. Yes. . . . . . . .. . . . . . . . . . . 32 .WQrk wi.! I occ.urwithoyt.operatio.n.shl!tdo.wn.. . . . Yes. . . . . . . . . . . . . .. . . . . . . . . . ., . . . " ........ _ . . . .. 33 .Is. pres.ence. o.f H2S gas. prob.aÞh3. . . .. . .. . . . . . . . . . . . . . .. .. No.. . . . _ . . . . . . 34 Meçha.nicaLcondJt[on pf wells wi.thin AOR y~rified (Fors.ervjce weU Qn.ly) NA - - - ~ - - - - - - .. - - - - - - -. - - - - - - . - - - - - - - - .. - _. - ~ - - - - . - - - - - ~ ~ - - - ~ - .. - - - - ~ - - - ~ . - - .. - - - - - .. ~ - - - - . - - - - - - - - - - - - . - - - - - - - - - - ~ ~ - - - - - - - - - . .- - - - - - - - - - - - - - - - ~ - -. - - .- - - - . - - - - - - - - - - - - - - - - - - - - - . (" - - - - - - . - - - - - - - - .. - - - - - - - - - - - - - - ~ - - - - ------.--.--.-----.-.-..--------...-..--..--. --------- ---_..__._-~-----_._,_._--_...---_.__.- --- ----,,---._-,-,._---_._-_.-..,,---"'-,.~,,_.. --- -, - . -- - ----- .-.--.,...- Geology iÎ4'. _..,,_..__._~_. '-'.'-~.._.-- . .-.-.---..----- --.,.-.-.----------. - -. - - - - ~ Appr RPC Date 8/1/2003 Geologic Commissioner: DT's 35 Permit.c.ao þe i.ssu.ed .wlo. hyçlrogen.s.u!.fide meas.!J(eß. . . . 36 .P.ata.p.r~sßlJted. on. pote.ntial pven~res.surj3 .zones. . . . . . . . . 37Sßi.smicanalysJs. Qf .sba.llow gas.zpnes. 38 .Seç¡þeçl.cor)djtiOO survey .(if Qff-sh.ore) . . . . . . . . . . .. . . . . . 39 _ CQnta.ct l1a!TlelphQl1eJQr.wee~ly progress.reports [explQratpry .only]. .. . _ . . . .. . No. . . .NA . NA .. . .NA . . _ . _ . . . . . .NA. . . .. ., - . - . - - - - - ,. - .. - - - - - - - - - -- . - - - - - -. - - .. - - - ~ - - .. - - - - - - - - . ~ . -- - - - - - - - - - - - - - - - - . _ H _ _ _ _ _ _ .. - - - - - - - - - .. - - - - - - . Date: S/7J3 Engineering Commissioner: Public ~ ~ Commissioner Date ~ Date ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the tlistory file. To improve the readability of the Well History file and to sim'plify finding infonnation, 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 infonnation. Sperry-Sun Drl )ng Services LIS Scan Utility ) Ci03~-13ÚJ $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 01 09:17:15 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU/WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-20B 500292113302 BP Exploration Sperry-Sun Drilling Services 01-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002607108 J. SACK D. GREEN / D MWD RUN 2 MW0002607108 J. SACK D. GREEN / D MWD RUN 3 MW0002607108 J. SACK J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 11N 14E 1410 1330 57.83 29.33 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7600.0 6.125 7.000 8275.0 # ~~'~\n~ REMARKS: ) ) 1. ALL DEPTHS· ARE BIT DEPTHS UNLESS OTHERWISE l\¡vrED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ COMPENSATED THERMAL NEUTRON POROSITY (CTN) ¡ AND STABILIZED LITHO-DENSITY (SLD) . 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 6' SHALLOWER PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 9/4/03. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL 15-20B WITH API#: 50-029-21133-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12021'MD/8906'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.5 - 8.6 PPG MUD SALINITY: 8500 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation....... )10/01 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPX RPS RPM RPD GR ROP NPHI FCNT NCNT PEF DRHO RHOB $ 1 ) and clipped curves; all bit runs merged. .5000 START DEPTH 7709.5 7709.5 7709.5 7709.5 7709.5 7717.5 7749.5 8269.5 8269.5 8269.5 8270.5 8270.5 8270.5 STOP DEPTH 11967.5 11967.5 11967.5 11967.5 11967.5 11960.0 12015.0 11924.0 11924.0 11924.0 11939.0 11939.0 11939.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- BASELINE DEPTH 7709.5 12015.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 7715.5 12021.0 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 7715.5 8275.0 9295.0 MERGE BASE 8275.0 9295.0 12021.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 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 API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S ) 1 68 32 9 ) FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7709.5 12015 9862.25 8612 7709.5 12015 ROP MWD FT/H 0.75 276.24 122.308 8532 7749.5 12015 GR MWD API 14.25 545.67 60.8577 8486 7717.5 11960 RPX MWD OHMM 0.43 2000 347.656 8517 7709.5 11967.5 RPS MWD OHMM 0.42 2000 280.784 8517 7709.5 11967.5 RPM MWD OHMM 0.4 2000 290.44 8517 7709.5 11967.5 RPD MWD OHMM 0.43 2000 334.513 8517 7709.5 11967.5 FET MWD HOUR 0.22 48.44 1.6826 8517 7709.5 11967.5 NPHI MWD PU-S 4.22 36.98 19.7482 7310 8269.5 11924 FCNT MWD CNTS 243.4 3819.4 862.432 7310 8269.5 11924 NCNT MWD CNTS 18756.6 51824.4 31013.3 7310 8269.5 11924 RHOB MWD G/CM 1.534 3.179 2.26067 7338 8270.5 11939 DRHO MWD G/CM -0.466 0.894 0.0318361 7338 8270.5 11939 PEF MWD BARN 0.6 9.58 1.83157 7338 8270.5 11939 First Reading For Entire File........ ..7709.5 Last Reading For Entire File......... ..12015 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/01 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...... .03/10/01 Maximum Physical Record..65535 File Type............ ... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET 2 header data for each bit run in separate files. 1 .5000 START DEPTH 7715.5 7715.5 7715.5 7715.5 7715.5 STOP DEPTH 8235.0 8235.0 8235.0 8235.0 8235.0 GR ROP $ 7723.S 7755.5 ) 8243.0 8275.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . .Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Dep th Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 15-AUG-03 Insite 65.37 Memory 8275.0 7755.0 8275.0 1.0 20.0 TOOL NUMBER 124725 163840 8.500 7600.0 LSND 10.00 88.0 9.4 1800 3.6 1.100 .590 .900 1.200 70.0 136.0 70.0 70.0 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 RPX MWDOI0 OHMM ) 1 68 12 4 ) RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 OHMM 4 1 68 20 6 RPD MWDOI0 OHMM 4 1 68 24 7 FET MWDOI0 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7715.5 8275 7995.25 1120 7715.5 8275 ROP MWDOI0 FT/H 1.36 258.74 75.5966 1040 7755.5 8275 GR MWDOI0 API 65.44 404.53 168.559 1040 7723.5 8243 RPX MWDOI0 OHMM 0.43 1137.6 6.60009 1040 7715.5 8235 RPS MWDOI0 OHMM 0.42 1059.89 6.59 1040 7715.5 8235 RPM MWDOI0 OHMM 0.4 1343.11 7.35527 1040 7715.5 8235 RPD MWDOI0 OHMM 0.43 2000 31.984 1040 7715.5 8235 FET MWDOI0 HOUR 0.38 9.29 1.55091 1040 7715.5 8235 First Reading For Entire File......... .7715.5 Last Reading For Entire File.......... .8275 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/01 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...... .03/10/01 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD FET RPS RPX GR NPHI FCNT NCNT ROP PEF DRHO 3 header data for each bit run in separate files. 2 .5000 START DEPTH 8235.5 8235.5 8235.5 8235.5 8235.5 8243.5 8275.5 8275.5 8275.5 8275.5 8276.5 8276.5 STOP DEPTH 9248.0 9248.0 9248.0 9248.0 9248.0 9242.0 9205.0 9205.0 9205.0 9295.0 9219.5 9219.5 RHOB $ 8276.5 '.) 9219.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # 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..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 18-AUG-03 Insite 65.37 Memory 9295.0 8275.0 9295.0 23.0 74.3 TOOL NUMBER 184054 150253 113413 159436 6.125 8275.0 FLO-PRO 8.50 57.0 10.0 13000 5.6 .320 .170 .300 .380 68.0 132.0 68.0 68.0 Name Service Order DEPT ROP MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD020 API ) 1 68 8 3 ') RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8235.5 9295 8765.25 2120 8235.5 9295 ROP MWD020 FT/H 1.8 162.49 54.1106 2040 8275.5 9295 GR MWD020 API 14.25 545.67 48.1856 1998 8243.5 9242 RPX MWD020 OHMM 0.69 1101.4 107.932 2026 8235.5 9248 RPS MWD020 OHMM 0.82 1911.65 182.371 2026 8235.5 9248 RPM MWD020 OHMM 0.57 2000 269.397 2026 8235.5 9248 RPD MWD020 OHMM 1.29 2000 307.51 2026 8235.5 9248 FET MWD020 HOUR 0.6 48.44 3.30592 2026 8235.5 9248 NPHI MWD020 PU-S 4.22 32.92 14.1564 1860 8275.5 9205 FCNT MWD020 CNTS 336.9 3819.4 1288.23 1860 8275.5 9205 NCNT MWD020 CNTS 18999.3 51824.4 33763.4 1860 8275.5 9205 RHOB MWD020 G/CM 1.967 3.179 2.25882 1887 8276.5 9219.5 DRHO MWD020 G/CM -0.466 0.448 0.0196343 1887 8276.5 9219.5 PEF MWD020 BARN 0.68 9.58 1.76907 1887 8276.5 9219.5 First Reading For Entire File......... .8235.5 Last Reading For Entire File.......... .9295 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/01 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...... .03/10/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 4 header data for each bit run in separate files. 3 .5000 VENDOR TOOL CODE FCNT NCNT NPHI PEF RHOB DRHO GR RPX RPS RPM RPD FET ROP $ )H STOP DEPTH 11930.0 11930.0 11930.0 11945.0 11945.0 11945.0 11966.0 11973.5 11973.5 11973.5 11973.5 11973.5 12021.0 START L 9205.5 9205.5 9205.5 9220.0 9220.0 9220.0 9242.5 9248.5 9248.5 9248.5 9248.5 9248.5 9295.5 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # 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..................O ') 21-AUG- 03 Insite 65.37 Memory 12021.0 9295.0 12021.0 71.1 92.7 TOOL NUMBER 184054 150253 113413 159436 6.125 8275.0 FLO-PRO 8.60 51.0 9.0 8500 6.0 1.520 .710 1.820 1.430 65.0 147.0 65.0 65.0 Data Specification Block )e. . . . .0 Logging Direction................ . Down Optical log depth units.... ...... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 MWD030 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9205.5 12021 10613.3 5632 9205.5 12021 ROP MWD030 FT/H 0.75 276.24 156.737 5452 9295.5 12021 GR MWD030 API 16.2 160.78 44.9454 5448 9242.5 11966 RPX MWD030 OHMM 6.53 2000 501.825 5451 9248.5 11973.5 RPS MWD030 OHMM 11.84 2000 369.676 5451 9248.5 11973.5 RPM MWD030 OHMM 21.55 2000 352.27 5451 9248.5 11973.5 RPD MWD030 OHMM 35.03 2000 402.269 5451 9248.5 11973.5 FET MWD030 HOUR 0.22 24.27 1.10438 5451 9248.5 11973.5 NPHI MWD030 PU-S 10.05 36.98 21.6565 5450 9205.5 11930 FCNT MWD030 CNTS 243.4 1696.6 717.112 5450 9205.5 11930 NCNT MWD030 CNTS 18756.6 38849.3 30074.7 5450 9205.5 11930 RHOB MWD030 G/CM 1.534 3.058 2.26131 5451 9220 11945 DRHO MWD030 G/CM -0.154 0.894 0.03606 5451 9220 11945 PEF MWD030 BARN 0.6 5.5 1.85321 5451 9220 11945 First Reading For Entire File......... .9205.5 Last Reading For Entire File.......... .12021 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/10/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .03/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN '" ' Continuation Number. . . . .. ) ') Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File