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Home My WebLink About201-198 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ;)0 / I q ~ Well History File # Digital Data Added to LaserFiche File CD's - # Yes No DVD's - # Yes No Diskettes - # Yes No Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC - Librarian@admin.state.ak.us Page 1 of 1 Fleckenstein, Robert J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, October 11, 2007 4:32 PM To: Fleckenstein, Robert J (DOA) Subject: PBU F-09A / PTD # 201-198 Hi Bob, it looks like there is another small error on this Completion Report. The bottom hole location is about 10' off. The numbers should be: X=649,635, Y=5,973,057 3696' FNL, 55' FWL, Sec. 02, T11 N, R13E Thanks! Terrie ~~~~~ NG~V l~ ~ 2007 10/12/2007 Well PBU F-09A Revision . . Page 1 of 1 Fleckenstein, Robert J (DOA) From: Stewman, Sondra 0 [Sondra.Stewman@bp.com] Sent: Tuesday, July 10, 20078:31 AM To: Fleckenstein, Robert J (DOA) Cc: Hubble, Terrie L Subject: Well PBU F-09A Revision Bob, Here's the Top of Productive Horizon data which was not listed on the recent 10-407 submission for Well PBU F- 09A, Permit # 201-198, Approval # 307-046 and API # 50-029-20403-01-00 Top of Productive Horizon: 3948' FNL, 595' FEL, SEC. 03, T11 N, R 13E, UM Location of Well (State Base Plane Coordinates, (NAD 27): TPI: X - 648991 Y - 5972792 Zone ASP4 Please advise if you require further information. SCANNED JUL 1 0 2007 Sondra Stewman ADW Drilling TA Diversity & Inclusion Resource D&I Info: httpjjalaska.bpweb.bp.comjdi 7/l 0/2007 . STATE OF ALASKA .~ ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission RECEIVED JUL 0 5 Z007 1 a. Well Status: o Oil o Gas o Plugged l8I Abandoned o Suspended 1 b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 l8I Development o Exploratory DGINJ OWINJ o WDSPL DWAG o Other No. of Completions Zero D Service o Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/9/2007 . 201-198 ( 307-046 3. Address: 6. Date Spudded 13. API Number . P.O. Box 196612, Anchorage, Alaska 99519-6612 12/27/2001 50-029-20403-01-00 - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/31/2001 PBU F-09A ;' 2467' FNL, 2405' FWL, SEC. 02, T11 N, R13E, UM 8. KB (ft above MSL): 67.3' 15. Field 1 Pool(s): Top ~produc'J~µS 'b ~ ~ $/::.- 7 - ~/n~' IJ Ground (ft MSL): 36' Prudhoe Bay Field 1 Prudhoe Bay Total Depth: ~ 7~t?-07 9. Plug Back Depth (MD+ TVD) Pool 3688' FNL, 45' FWL, SEC. 02, T11N, R13E, UM 9498· 8528 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: 651959 5974333 Zone- ASP4 10981 , 9059 . ADL 028280 x- y- -- 11. SSSV Depth (MD+ TVD) 17. Land Use Permit: TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 649625 y- 5973065 Zone- ASP4 N/A N/A 18. Directional Survey 0 Yes l8I No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and nrinted information oer 20 MC 25.050\ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): MWD, GR, Memory CNL, CCL 22. CASING, LINER AND CEMENTING RECORD SETTINé DEPTH MO SETTING DEPTH NO HOLE .... ......../ ...... ~.... \IVr.P'6R H>J4" GRADE Top BOTTOM Top BOTTOM SIZE... ..... c. ······.PI.JL.(Eb 20" x 30" Insulatèd Conductor Surface 110' Surface 110' 36" 7.9 cu vds Permafrost 13-3/8" 72# L-BO Surface 2700' Surface 2699' 17-1/2" 4269 cu ft Articset 9-5/8" 47# L-80 Surface 9390' Surface 8427' 12-1/4" 1230 cu ft Class 'G' 130 cu ft AS 7" 29# L-80 8899' 9823' 7993' 8834' 8-1/2" 391 cu ft Class 'G' 2-3/8" 4.7# L-80 9523' 10981' 8551' 9059' 3" 73 cu ft Class 'G' 23. Open to production or injection? D Yes l8I No 24. .. ..... UI:IING RECORD \i ····Xi> ...> ii/X»>X> If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MO) (MD+ TVD ofTop & Bottom; Perforation Size and Number): None None MD TVD MD TVD 125. . .ð¡CI[)... ,... ........... ¡;rq>· .·Y.<>y;/' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9905' Set CIBP in 2-318" Liner 9523' Set Whipstock at Top of Cement in 7" Liner 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date ofT est: Hours Tested: PRODUCTION FOR O,l-BBl: GAs-McF: WATER-BBl: CHOKE SIZE: I GAS-Oil RATIO: TEST PERIOD ... Flow Tubing Casing Press: CALCULATED O,l-BBl: GAs-McF: WATER-BBl: Oil GRAVITY-API (CORR): Press. 24-HoUR RATE" 27. CORE DATA Conventional Core(s) Acquired? DVes l8I No Sidewall Core(s) Acauired? OVes l8I No If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 MC 250.071. - - . None RBDMS BFL JUL 0 6 2007 ~..e~~~ þl{~ N Form 10-407 Revised 02/2007 OR' G 1 (\fAt:D ON REVERSE SIDE ~ 74-~.? ~ 28. GEOl.OGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste . DVes l8I No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 MC 25.071. 25N 9901' 8901' None 25P 9911' 8909' 22P 9997' 8970' 21N 10088' 9018' 21P 1 0092' 9019' Zone 1 B 10253' 9052' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram and a Pre Rig Well Summary. Signed ¡tie Technical Assistant Date PBU F-09A Well Number Prepared By NameINumber: Sandra Stewman, 564-4750 Drilling Engineer: Kris Hanas, 564-4338 201-198 307-046 Permit NO.1 A roval 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 02/2007 Submit Original Only t.lbEVOY OTIS 64.99' F-09B Actual SAFETYA:s: *""9-6/8- CSG WAS CUT @ Z030'. 7-, Z5#, I.uS WA~ BACK@ 890Z' AND RAN TO SURF. 7- WAS HUNG IN OLD9-lí18- CSG SPOOL WO" SLIPS- DRLG DRAFT TOP OF 9-518" (CtJr & TOP PULLED 4-1/2" X Nipple ID=3.813" 8T MD WD 2 3418 3408 1 6212 5813 GAS LIFTMANÐREts œv 'TYPE. VI..V LATCH PORT DATE 14 KBG-2 DV BK 06122/07 31 KBG-2 ÐCK Be< 06122107 Top of Cement 9214' 4-112" XNpple 10=3.813" 7" x 4-1/2" BOT 8-3 Packer TOP OF 7" LNR (150 SX CLASS 6 ACROSS TBPKR) 9321' 4-1/2" )eN Nipple 10=3.725 4-1/2", 12.6#, 13Cr-aO, Yam Top Tubing 9-5/S"CSG, 47#, L-BO, 11);; 8.681" BOT H PBTD I BOT 7" WhipstOGk Jet Cut 2-3/8" liner PERFORATION SI...II\rWIARY REF lOO: BHlGR ANGI..EATTOPÞERF:94@ 10560' Note: Relerto-A'oductionPBfor þistol'ÎCslperf data SIZE SPF JN11:R\IAI.. OpI"ll$qZ DATE 2.875" 6 105ô0 -loaSO 0 06I2D107 2.875" 610650 - 10680 0 06120I01 2.875" 6 10700 - 10840 0 06I2D107 2.875" 6 11080- 11195 0 06I2Dl07 17" lNR, 29#, l-8O, .0371 bpI, II) '" 6.184" H 10292'· I DATE REVBY .~ 12/1709 ORIGINAL COMPLETION 01/02/12 MCIKA cTDSIŒrRAcK 03/20102 GRO'TI.H LINER JDCORRECTION 05108104 Bt.lbJJKK A DPERFS 01/1'7/06 D"TRIPAGGI.. VClO 01120106 KSBI11.H PX TIP SET DA TE REV BY COPIMENTS 05/10106 CAZlTLH MAJOR CORRECTIONS 06124107 KSBfSV ÐRLG CORRECTIONS PRUDHOE BAY UNrr WELL: F-09A PERMlTNo: ~11980 API No: 50-029-20403-01 SEC2, T11N, R13E BPExploratîon (Alaska) Digital Wellfile . . Page 1 of 2 Well: F-09 Well Events for SurfaceWell - F-09 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> F -> F-09 Date Range: 01/Feb/2007 to 29/Jun/2007 Data Source(s): AWGRS Description PULLED TWC AFTER THE RIG TESTED THE TREE & SET A BPV FOR THE RIG TO MOVE OFF *** RIG JOB ON 9ES** EQUALIZE AND PULLED 3-1/2"XX PLUG FROM 2000'SLM ***JOB COMPLETED*** T/I/O = 2.5/Vac/Vac. Temp = S/!. Bleed WHPs to 0 psi (pre-RWO). No Flowline or AL. Bled TBGP to bucket from 2.5 psi to 0 psi in 5 sees. Post 30 min monitor TBGP unchanged. FWHPs = O/Vac/Vac. T/I/O = 2.5/Vac/Vac. Temp = S/!. Bleed WHPs to 0 psi (pre-RWO). TBG FL at surface. From yesterday TBGP decreased 847.5 psi, lAP and OAP went to vac. T/I/O= 850/0/0+. Temp= S/I. WHP's (post-bleed, pre-RWO). TBGP increased 850 psi overnight. T/I/0=230/VAC/VAC Temp=SI Bleed WHPs to 0 psi (Pre-Rig). Bled TBG pressure from 230 psi to 0 psi in 1 minute. Monitored for 30 min. No change in pressures. Final WHPs=O/VAC/VAC ***WELL S/I ON ARRIVAL *** (Pre SDTRK) DRIFT TBG W/2.805" G.RING & BRUSH TO SVLN @ 1972' SLM. SET 2.75" PX PLUG @ 1972' SLM, PLUG FAILED TO HOLD. PULLED 2.75" PX PLUG @ 1972' SLM TO INSPECT. SET 2.75" XX PLUG W/ 8 EQ PORTS (4) 1/8" (4) 3/16" @ 1972' SLM (PKG STACK = 2 PCS, O-RING, 5 PCS). MIT-T W/DIESEL TO 3500 psi "PASSED", BLEED TBG BACK TO 0 psi. ***NOTIFY PAD OP THAT PLUG IS SET, RDMO*** T/I/O = 200/60/220. (Rig ST Prep) Circ Out Wellbore. MIT-OA to 2000 psi. *FAILED* 4 attempts. Pump 5 bbls neat, 594 bbls 2% KCL, 2 bbls neat into the TBG with IA returns to flowline. Pump 2 bbls neat, 75 bbls diesel, and 2 bbls neat into the IA with TBG returns to flowline. U-Tube TxIA. Freeze protected flowline. MIT-OA to 2000 psi. *FAILED* 4 attempts. LLRT= too small for this pump to measure. Lost 140 psi / 1st 15 min & 140 psi / 2nd 15 min of test #4. Final WHP= 0/0/0. ***WELL SHUT IN ON ARRIVAL./ INITIAL T/ 1/ 0 = 0/0/ 220*** JET CUT TUBING AT 8755' USING 2.5" SLB POWER CUTTER. POSITIVE INDICATION OF CUT SEEN ON SURFACE. WELL LEFT SHUT IN. FINAL T/ 1/ 0 = 0/0/220. TURNED WELL OVER TO DSO. ***JOB COMPLETE*** T/I/0=100/100/100. (PRE SDTRCK) CMIT-TxIA to 3500 psi. *PASSED* the first attempt. Lost 60 psi / 1st 15 min & 20 psi / 2nd 15 min. Pumped 5.8 bbls of 80* crude to achieve test pressure. Well was 51 upon arrival. Final WHP=120/120/120. CTU #8, Verify Liner is Free (Catch and Release); MIRU unit. MU and RIH with BKR accelerator, jars and 3.0" GS hydraulic spear. Tag and latch liner at 8758' ctmd. PUH. Liner is free. Pull liner up hole 35' to 8723' ctmd. Observed weight swings from 4K to 12K over. RBIH and release liner. POOH. *** Job Complete *** **** JOB CONTINUED FROM THE 7TH MAY **** 1) RAN SCMT IN 2 3/8" LINER. TOC FOUND AT9498 FT. (COMPLETED 6TH) 2) RAN GYRO FROM 0 - 9819 FT. (COMPLETED 6TH) 3) RAN PLUG - CIBP SET AT 9905 FT (ME DEPTH), TESTED PLUG TO 900 PSI, TEST GOOD. 4) CUT 23/8" TUBING AT 9490 FT 5) RAN TUBING PUNCHER IN 3.5" TUB. SHOTS FROM 8680 -8682 FT. JOB COMPLETED **** WELL LEFT SHUTlN WITH DSO **** AWGRS F-09A 05/06/2007 ***WELL SHUTlN ON ARRIVAL *** 1) RAN SCMT IN 2 3/8" LINER. TOC FOUND AT9498 FT. 2) RAN GYRO FROM 0 - 9819 FT. **** JOB CONTINUED ON THE 7TH MAY **** Events Source Well Date AWGRS F-09B 06/22/2007 AWGRS F-09B 06/03/2007 P.WGR$ F-09A 06/01/2007 AWGRS F-09A 05/31/2007 P.WGRS F-09A 05/30/2007 AIliG.RS F-09A OS/29/2007 AWGRS F-09A OS/28/2007 AWGRS F-09A 05/19/2007 AWGP...5. F-09A 05/18/2007 AWGRS F-09A 05/18/2007 A'l'L.GRS F-09A 05/14/2007 P.WGR5. F-09A 05/07/2007 AIliG.R.5. F-09A 05/02/2007 *** WELL 51 ON ARRIVAL, SSV DUMPED *** (sdtrk prep) DRIFTED W/ 2.70" CENT SAMPLE BAILER TO 8708' SLM. BAILER M/T PULLED 3 1/2" PX PLUG BODY & PRONG FROM 8708' SLM DRIFTED W/ 1.85 CENT & SAMPLE BAILER TO 10,067' SLM (67 DEG. DEV). BAILER M/T *** JOB COMPLETE, WELL LEFT SI *** AWGRS F-09A 03/14/2007 T/IA/OA= 100/0/180 PRE RWO PPPOT-T (PASS) installed bleed tool into tubing test port. 50 psi bleed to 0 psi. Cycled and torqued all LDS to 500 ft/# . Pressured tubing http://digitalwellfile.bpweb.bp.comIW ellEventslHomelDefault.aspx 6/29/2007 Qigital Wellfile . . Page 2 of 2 # void 5000 psi for 30 minutes. 15 minutes SO psi loss, 30 minutes 0 psi lost. ( PA55) PPPOT-IC Installed bleed tool into IC test void 180 psi would not bleed off. Cycled all LD5 torqued to 500 ft/# . IC void would not bleed off. No broke or bent pins all functioned freely. Pulled internal check on adapter flange and installed external. Internal check was not replaced on IC hanger void wouldn't bleed off. *** NOTE 1 1- 5/8" stud on adapter not flush. Also 1 1-5/8" stud between casing and tubing spool not flush.*** AWGRS F-09A 03/12/2007 T/I/O = 80/70/100. Temp = 51. Bleed WHPs to 0 psi pre-PPPOT-IC (pre-RWO). TBG FL @ 150' (2 bbls). IA FL @ 320' (20 bbls). OA FL @ surface. Bled lAP to DHD UR from 70 psi to 0+ psi in 30 min (all gas). TBG pressure decreased to 45 psi. 51, monitored for 30 min. No change in lAP. Bled TBG pressure to bleed trailer from 45 psi to 0+ psi in 30 min (all gas). 51, monitored for 45 min. TBG pressure increased to 15 psi. Bled OAP to bleed trailer from 100 psi to 0+ psi in 15 min (gas and liquid). 51, monitored for 30 min. No change in OAP. Final WHPs = 15/0+/0+. http://digitalwellfi1e. bpweb. bp.com/W ellEventslHomelDefault.aspx 6/29/2007 Schlumberger NO. 4281 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 1 zom Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log DescriDtion Date BL Color CD 05-22A, 11745219 MEMORY CBL OS/24/07 1 09·15- 11667116 USIT 04/09/07 1 F-09A 11657123 CBL 05/06/07 1 MPS-01A 11686746 USIT (CORROSION) 05/18/07 1 MPS-01A 11686746 USIT (CEMENT) 05/18/07 1 MPF-99 11638629 SCMT 05/03/07 1 J·12 11686735 RST 04/14/07 1 1 L 1·14 11421033 RST 10/11/06 1 1 R-13 11686733 RST 04/11/07 1 1 J·19 11686738 RST 04/21/07 1 1 L2·33 11421034 RST 10/11/06 1 1 N-04A 11540226 RST 12/11/06 1 1 15-05A 11054307 RST 07/15/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 GambelJ Street, Suite 400 ""'''''''''', AK ""H"ú ATTN: Beth D Received by: C~ '"' ^ SCANNED JUN 2 1 2007 Date Delivered: c90l-/9 r ,0 06/06/07 . . Schlumbepger NO. 4249 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN; Beth é)O{-1915 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine MahnkEm 333 West 7th Ave, SuitEl100 Anchorage, AK 99501 SCANNE.D MAY 3 1 2007 Field: Prudhoe Bay Bl C Well Job# loa Description Date olor CD 06-24A 11637328 RST 04/16/07 1 1 l2-16 11414768 RST 10/07/06 1 1 06-07 11637123 RST 05/06/07 1 1 06-21A 11628766 MCNl 04/09/07 1 1 F-09A 11657123 CBl 05/06/07 1 09-15 11630475 CEMENT IMAGE lOG 05/06/07 1 03-36A 11745217 USIT CORROSION 05/03/07 1 03-36A 11745217 USIT CEMENT 05/03/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. i,~'.:;;ì.¡.:¡::..C· .~.~W= -'If: [) Petrotechnical Data Center LR2-1 ;~ \~,I\ì_ .._~, ,:,,..,..J. "";"." 900 E. Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 11', iJ, ' . ¡/ Received by: C -t/;'(~ ~, MAY 3 1 20m Date Delivered: Com'ln:',;,'" "1- OS/29/07 . . Re: F-09B change from Sundry . . Kris - ~6\-vr6 Thank you for the revised well schematic and description of the proposed changes to the well configuration (no EZSV and revised depth for production packer). These are not major changes in work scope as approved by Sundry 307-046 (PBU F-09A) and PTD 207-013 (PBU F-09B). Leaving the EZSV out of the P&A is acceptable. I will place a copy of this email and the revised well schematic in our files. No need to resubmit the sundry for approval. Jim Regg AOGCC Honas, Kristopher wrote, On 5/29/20073:10 PM: SCANNED JUN 0 1 2007 «F-09B Planned Final 150 ft lap.ZIP» Jim, Attached is the proposed schematic for the F-09B. The major change, as we discussed, is leaving out the 7" EZSV plug just below the whipstock. The old well bore will still be P&A'd with a CIBP in the 2-3/8" liner as well as a fully cemented 4-1/2" liner with Baker Flex Lock packer. The reason for the change is that cement will have to be milled up to allow our kick off point to be below the top of the Sag River formation. One other change you might notice is placing the production packer above the 7" TIW packer to keep us up in the 7" tieback. Please let me know if you have any concerns about this plan. My phone numbers are listed below. Thanks Kris Honas GPB Rotary Drilling 564-4338 440-2389 Jim Regg <iim regg(â;admin.state.ak.us> Petroleum Engineer AOGCC 1 of 1 5/29/2007 4:44 PM · . ~ v ~ V Œ ffi) ~ ~ ~ ~ ~ æ~ / SARAHPAUN, GOVERNOR AI,ASIiA. OIL AlVD GAS / CONSERVATION COMMISSION I 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK, 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, F -09A Sundry Number: 307-046 ;j.()\' \qC3 SCAJ"ED FEB 0 1 2007 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the condition~ of approval set out in the enclosed form. When providing 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. Sincerely, DATED this3( day of January, 2007 Encl. . STATE OF AlASKA (,'{l} 'r1itIJ it ~7 / ALASWOILANDGASCONSERVATIONCOMMWON ~p~ Il~q 07 APPLICATION FOR SUNDRY APPROVAL RECEIVED 20 AAC 25.280 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time j~Mstn6 Z007 o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver A!JIt;\~ & Gas Cons. Commission Anchora¡¡e 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 201-198/ 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20403-01-00.r 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: F-09A ./ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): I.- ADL 028280 ./ 67.3' ./ Prudhoe Bay Field / Prudhoe Bay Pool 12. .. ../i ...j/<jji;. . ....ii<j< WI::I..LlIIo. 'NUl i.ix ··i·ij·....;i·j;·'j... ...../. ... ·'x· Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10981 9056 10946 9055 8728 None Casina Lenath ize MD TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Surface 2700' 13-3/8" 2700' 2699' 4930 2670 Intermediate 9390' 9-5/8" 9390' 8423' 6870 4760 Production Liner 924' 7" 8899' - 9823' 7987' - 8831' 8160 7020 Liner 2223' 2-3/8" 8758' - 10981' 7869' - 9056' 11200 11780 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10198' - 10738' 9045' - 9042' 3-1/2",9.3# L-80 8813' Packers and SSSV Type: Baker '3-H' packer packers and SSSV MD (ft): 8813' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory ~ Development o Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: May 1, 2007 OOil o Gas o Plugged 181 Abandoned 17. Verbal Approval: Date: DWAG OGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the fo,regoi " is true and correct to the best of my knowledge. Contact Kris Honas, 564-4338 Printed Name Greg Hgbþ s~ Title Senior Drilling Engineer f;; ~j Date ¡/Ù/ot Prepared By Name/Number: Signature Phone 564-4191 Terrie Hubble, 564-4628 ø' If / Commission Use On Iv . / I Sundry Number: :307-04-ltJ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test o Mechanical Integrity Test D Location Clearance Other: '3S00 r=> '. vv-..\~" ~\,,) ~ ~() V \c l. C'...' <; L EL '\ \ f 1)~OMMISSJONER APPROVED BY Date /~8/,1 Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 """ '-'1 .......--- " t Submit In Duplicate If .~ !'In "7 ORIGINAL RBDMS SF" tI A. LvD! . . To: AOGCC Date: January 16, 2007 From: Kristopher Honas - BPXA GPB Rotary Drilling Subject: F-09B Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the P&A of Prudhoe Bay well F-09A. F-09A is a Zone 2A Ivishak producer that is currently shut-in for tubing by IA communication and given the low volume of the remaining reserves and the poor condition of the current tubing string, the F-09B sidetrack has been proposed. The original F-09 well was completed in December 1979, but, was intersected by the F-20 wellbore during drilling operations July 1986. A subsequent rig workover was required to repair the well. In January 2002, a coil tubing rig was used to drill the F-09A sidetrack. Plans for isolating the existing perforations include the following: 1. Setting a CIBP in the existing 2-3/8" liner at -9905' MD. 2. After cutting and pulling the existing 2-3/8" liner from the top of cement (-9500' MD), a CIBP will be set in the existing 7" liner at -9525' MD. 3. After sidetracking the well, the new 4-1/2" production liner will be run and fully cemented into the existing 7" liner to -9313' MD. The sidetrack plan for the F-09B well (a Zone 2A producer) includes a whipstock departure from the 7" liner in the F-09 parent wellbore with a 6-1/8" drilling assembly at -9500' MD. The 6-1/8" hole will be drilled to a final well TD of -12,042' MD where a solid cemented liner will be run to TD and fully cemented. A 4-1/2" completion will then be run to complete the well. The F-09B sidetrack is currently scheduled for Nabors 2ES beginning July 2007. The pre-rig work for this sidetrack will be scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: 05/01/07 06/01/07 Kristopher Honas GPB Rotary Drilling Engineer Ph: 564-4338 F-09B Application for Sundry '. . . F-098 Operations Summary Current Condition: ../ F-09A is currently shut-in due to TxlA communication. A caliper was run in January 2006 and showed the tubing to be in poor condition. There are 30+ joints of tubing with greater than 50% penetrations. ../ TTP set @8728' MD on 1/20/06. ../ CMIT T x IA passed to 3500 psi on 8/18/06 ../ MITOA failed to 2000 psi on 8/18/06. ../ PPPOT- T & IC passed on 8/2/01. Pre-RiQ Work (F-09A Well): 1. Bleed OA, IA & tubing to 0 psi. PPPOT-T & IC. Function all LDS. 2. RU E-line and pull TTP set @8728' MD. 3. With E-line, set CIBP in 2-3/8" liner at -9905' MD. 4. With E-line, run SCMT to confirm top of cement behind the 2-3/8" liner in the 2-3/8" x 7" annulus (estimated top at -9500' MD). 5. Jet cut 2-3/8" tubing at top cement (-9500' MD). 6. With tubing punch, shoot hole(s) in the 3-1/2" tubing just above the 2-3/8" deployment sub at -8758' MD. 7. Fluid pack well w/seawater. 8. CMIT TxlA to 3500 psi. 9. MIT OA to 2000 psi. 10. Bleed tubing, casing and annulus pressures to zero. 11. Using service coil, RIH & pull 2-318" liner from cut point to just below the wellhead and hang on 3-1/2" hydraulic set tubing hanger. (NOTE: With the top of the 2-3/8" liner just below the wellhead, the drilling rig can pull and LD the liner after it moves over the well.) 12. Circulate the well to seawater through the tubing punch hole(s) at -8758' MD. 13. Freeze protect the well on both sides of the 3-1/2" tubing to 2200' with diesel. 14. Set a BPV and test to 1000 psi from tubing annulus. 15. Secure the well and level the pad as necessary. Pre-Rig Work (J-05A Well): 1. RU E-line and run a tie-in gyro on this well (Gyro Data) to as deep as possible to clear-up anti-collision issues currently existing with the F-09B directional plan. ~(. 1'\ ~ Rig Operations: 1. MI / RU 2. Test T x IA to 3500 psi f/10 min. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater and confirm well is "dead". Install TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. Pull TWC. 4. Pul~ner from just below wellhead. 5. RU E-line and make jet cut on the 3-1/2" tubing at -8768' MD. 6. PuIl3-W' tubing from -8768' MD. 7. TIH w/overshot and recover 3-1/2" PBR and/or latch assembly. 8. If not recovered with the PBR, TIH to recover latch assembly. 9. Mill and recover the 3-1/2" x 7" packer assembly. 10. MU 7" clean-out/milling assembly and clean-out the well to allow whipstock departure with a 6-1/8" drilling assembly at -9500' MD. (NOTE: With the top of the Sag River formation at 9483' MD, a certain amount of cement & 2-3/8" liner may need to be milled-up to accommodate a whipstock departure at a depth below the top of the Sag River formation. The target depth for setting the EZSV should be -9525' MD.) 11. RU E-line and RIH with 7" GR/JB & GR/CCL to TOC -9525' MD in preparation to set EZSV for whipstock. (NOTE: Use logging data to confirm whipstock departure to be below top of Sag.) 12. With E-line, run tie-in gyro from surface to -9525' MD (Gyro Data). 13. With E-line, set 7" EZSV retainer and set at ±9525' MD to allow for an 9500' MD whip-stock KOP (max hole angle to 9525' MD is 38 degrees at 8200' MD). 14. Set storm packer and change-out 7" pack-off (pull pack-off thru BOP stack if possible). F-09B Application for Sundry . . ;:1:- ~E Q 15. Pressure test 7" casing to 3500 psi for 30 minutes and chart. (NOTE: There is currently no evidence of inte rit roblems with this well and the ex ectation would be that we will ass this MIT. 16. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly and set on EZSV at -9525' MD. t Orient whipstock as desired and set on bridge plug at -9525' MD. Shear off of whip-stock. 17. Displace the well to the 8.4 ppg Flo-Pro milling/drilling fluid, mill the window and then drill an additional 20' formation and perform FIT to 10.1 ppg EMW. 18. RIH with 6 1/8" TCI bit / motor assembly with GR/Res/ABI and drill ±10,470' MD to land in horizontal section in Z2A. CBU, POH. 19. RIH with PDC / motor assembly with real-time Neu/Den. ':/..... 20. MAD pass build section from TD of the 1st bit run back to 100' above PGOC per the well-site geologist ~ (; and continue drilling to TD at ±12,042' MD. Y ~ 21. Circulate, short trip, spot liner running pill, POOH. . ~ r.f 22. Run and cement a 4 W', 12.6#, L-80, IBT-M solid production liner. POOH. <'" \( 23. RIH with 2-7/8" perf guns and perforate ±600'. POH and LDDP and perf guns. 24. R/U and run 41/2", 12.6#, 13Cr, VamTop completion tubing. Land the tubing RILDS. 25. Reverse circulate inhibited seawater to the packer depth. 26. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 27. Shear the DCK valve and pump each way to confirm shear. 28. Set a TWC and test to 1000 psi. 29. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC w/lubricator. 30. Freeze protect the well to -2,200' 31. Install BPV and secure the well. 32. Rig down and move off. Post-Ria Work: 1. Install well house and instrumentation. 2. MI / RU slick-line. 3. Pull the ball and rod / RHC plug from landing nipple below the production packer. 4. Install gas lift valves. Well Coordinates: Suñace Location Northin 5974332 Offsets 2468' FNL / 2404' FWL TRS 11 N, 13E,2 Target Location Northin 5972345 Offsets 4373' FNL / 3585' FWL TRS 11 N, 13 E, 3 Bottom Northing Easting I Offsets TRS Location 5972420 646950 I 4278' FNL / 2636' FWL 11 N, 13E,3 F-09B Application for Sundry ._TREE= , 6"CW . SAFETY a: ***9-518" CSG WAS CUT @ 2030'. 7",25#, WELLHEAD = McEVOY ACTUA TOR = OTIS F -09J ~:S WA BACK @ 8902' AND RAN TO SURF. 7" WAS UNG IN OLD 9-/58" CSG SPOOL Wf7" SLlPS*** KB. ELEV = 67.32' BF. ELEV = 38.17' KOP= 3200' Max Angle = 99 @ 10416' 1980' -13-1/2" OTIS SSSV LAND NIP, ID= 2.7S" 1 Datum MD = 9863' ~ -1 TOP OF 9-S/8" (CUT & TOP PULLED I Datum TV D = 8800' SS - 2030' 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2700' I ..4 ~ GAS LIFT MANDRELS CAUTION: DAMAGE AREA FROM F-20 COLLOSION I 2930' t- ~ ST MD TVD DEV TYÆ VLV LATCH PORT DATE J S 3188 3132 11 McMURRY DMY BK2 0 01/09/06 4 S324 S023 34 McMURRY DMY BK2 0 01/09/06 3 7144 6S24 36 McMURRY DMY BK2 0 2 8242 7403 38 McMURRY DMY BK2 0 1 8364 7499 38 McMURRY DMY BK2 0 Minimum ID = 1"92" @ 8764' ~ 8728' -13-1/2" OTIS SLIDING SLEEVE, ID = 2.75" 3-1/2" BKR DEPLOYMENT SLV I~ ~ - 8728' -13-1/2" PX TIP (01/20/06) .1 8758' -i3-1/2" BKR DEPLOYMENT SLV, ID= 1.92" I f I- ~ 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 8785' I I 8785' 1-1 BOT G SEA L ASSY W/ LA TCH (BEHIND CT LNR) I :8: :8: I 8813' 1-1 BOT 3-H PKR W/ MILLOUT EXT (BEHIND CT LNR) I 1 l-i ELMD TI NOT LOGGED I 1-11I . -I 8899' -i7" TW PKR I I TOP OF 7" LNR 8902' (1S0 SX CLASS 6 ACROSS TB PKR) 19-5/8" CSG, 47#, L-80, ID = 8.681" 1 9390' µ ~ I 9500' HTOPOF CMT PLUG I ~ I 9823' HTOPOFWlNDOW I 10182' HMARKERJOINT I ÆRFORA TION SUMMARY REF LOG: BHI GR ANGLE AT TOP ÆRF: 83 @ 10198' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.S6" 6 10198 - 10248 0 OS/18/04 1.56" 4 10380 - 10620 0 01/02/02 1.56" 6 10663 - 10738 0 05/18/04 I 10946' HPBTD I , 17" LNR, 29#, L-80, .0371 bpf, Ð = 6.184" I 10292' I 10981' 1 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/07 f79 ORIGINAL COM PLETION OS/10/06 CAZITLH MAJOR CORRECTIONS WELL: F-09A 01/02/02 DAC/KAK CTD SIŒTRACK ÆRMIT No: '2011980 03/20/02 GRC/TLH LINER ID CORRECTION API No: 50-029-20403-01 05/08/04 BMcUKK ADÆRFS SEC2, T11N, R13E 01117/06 DTRlPAG GLV C/O 01/20/06 KSBlTLH PX TIP SET BP Exploration (Alaska) ",.TREE= . WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = . F-098 PROPOSED SA~ES: "*"9-5/8" CSG WAS cur @ 2030'. 7",25#, IJ4S ~8) BACK @ 8902' AN) RAN TO SURF. 7" WAS HUNG IN OLD 9-/58" eSG SPOOL wn" SLIPS- 6"CW McEVOY OTIS 67.32' 38.17' 3200' 99 @ 10416' 9863' 8800' SS 113-3/8" CSG, 72#, L-80,ID= 12.347" CAUTION: DAMAGE AREA FROM F-20 COLLOSION I Minimum ID = 4-1/2" XN Nipple (3"725" ID) at 9296' MD TOP OF 7* LNR -I 8902' (150 SX CLASS 6 ACROSS TB PKR BOT S-3 Packer (7" x 5") -9250' MD 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9390' 1_ BOT HMC/ZXP Packer -9313' MD/ BOT 7" Whipstock -95223" MD'\. HES EZSV -9525' MD ~ 9525' !-iTOP OF CMT PLUG 1- CIBP in 2-3/8" Liner -9905' MD ÆRFORA TION SUMMARY REF LOG: BHI GR ANGLEATTOPÆRF: 83 @ 10198' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.S6" 6 10198 - 10248 0 05/18/04 1 .S6" 4 10380 - 10620 0 01/02/02 1.56" 6 10663 - 10738 0 05/18/04 I 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" I DA TE REV BY COMMENTS 12/07n9 ORIGINAL COMPLETION 01/02/02 DACIKA CTD SlœTRACK 03/20/02 GRC/TLH LINER ID CORRECTION OS/08/04 BMcLlKK ADÆRFS 01/17/06 DTRlPAG GLV C/O 01/20/06 KSBlTLH PX TTPSET 2030' HTOP OF 9-5/8" (CUT & TOP PULLED ?DA TE?} 4-1/2" X-Nipple (3.813" ID) -2201' MD ST MD ND 2 3410 3400 1 6204 S800 GAS LIFT MANDRELS DEV TY PE VL V LA TCH PORT DATE KBG-2 OCK KBG-2 Durrmy GLM Program - (To Be Developed) 4-1/2",12.6#. 13Cr, Vam Top Completion to -9317' MD (WLEG into 4-112" Liner Top) 4-112" X-Nipple (3.813" ID) -9229' MD - 7" TIW PKR - 8899' MD 4-112" X-Nipple (3.813" ID) -9275' MD 4-1/2" XN-Nipple (3.725" ID) -9296' MD TOW - 8320' MD - TOW -9500' MD 4-112", 12.6#, L-80, IBT-M Production Liner (Fully Cemented) set at 12,042' MD /9019' TVD) -lTOPOFWlNDOW I I 10182' HMARKERJOINT 10981' 1-12-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.99S" I DATE REV BY COMMENTS 05/10/06 CAZfTLH MAJOR CORRECTIONS 8/23/06 jgr F-09B sidetrack PRUDHOE BAY UNrr WELL: F-09B ÆRMrr No: 2011980 API No: 50-029-20403-02 SEC2, T11N, R13E BP Exploration (Alaska) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ,,. -\ STATE OF ALASKA ~). ALA... .A OIL AND GAS CONSERVATION COMI\",JSION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 67.3 KB ADL-028280 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Intermediate Production Liner Liner Perforation depth: measured 10981 true vertical 9056.33 measured 10946 true vertical 9054.99 Length 80 2671 9362 8871 924 2223 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# IJ45 7" 29# L-80 2-3/8" 4.7# L-80 Measured depth: 10198 - 10248 Closed True Vertical depth: 9044.71 - 9048.97 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development r;?" Stratigraphic Ci Stimulate 0 Other 0 Set TTP Waiver 0 Time Extension 0 to Secure well Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory C: 201-1980 Service 6. API Number: 50-029-20403-01-00 9. Well Name and Number: F-09A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool Rt:Cf::IVED feet feet Plugs (measured) ..... . .. ! _,:;..." J~nðl (~ôDijred) StÇA.NNE.L f Eb 2, «.J feet feet MD 30 - 110 29 - 2700 28 - 9390 28 - 8899 8899 - 9823 8758 - 10981 1 0380 - 10620 Closed 9050.83 - 9044.85 3-1/2" 9.3# 3-1/2" Baker 3-H Packer Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl 658 653 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatur k Form 10-404 Revised 04/2004 TVD 30 - 110 29 - 2699.22 28 - 8423.43 28 - 7987.26 7987.26 - 8831.07 7868.95 - 9056.33 10663 - 10738 Closed 9043.41 - 9041.55 L-80 8728 PX TTP FEB 2 7 2006· None Alaska 0" & Gas Cons Cn.rnnú . . ""HIIISSIO 1 Anchorage Burst Collapse 1490 470 5380 2670 6870 4760 8160 7020 11200 11780 26 - 8813 8809 RBDMS 8Ft FEB 2 8 2006 Title Data Mgmt Engr Phone 564-4424 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 19992 24 100 19731 25 100 15. Well Class after oroposed work: Exploratory r Developmentw 16. Well Status after proposed work: Oil W Gasr WAG r Tubing pressure 1141 1170 Service r GINJ r WINJ r WDSPL r Sundry Number or N/A if C.O. Exempt: N/A Date 2/24/2006 Submit Original Only ) ) F-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITY DATE I SUMMARY 1/19/2006 ***WELL S/I ON ARRIVAL*** (secure well) CONFIRMED SSD CLOSED. DRIFTED W/3 1/2" BRUSH, 2.74" GAUGE RING, TO X-NIP, BRUSHED BOTH NIPS. ***CONTINUED ON 01-20-06 WSR*** 1/20/2006 ***CONT FROM 1-19-06 WSR*** (secure well-TIFL) SET 2.75" PLUG BODY @ 8722' SLM. SET PRONG @ 8717' SLM (1 3/4" FN, 8' OAL, 1 3/4" BODY OD). PSI WHEN PLUG SET T/I/O- 2050/1850/100 PSI, BLED TUBING DOWN TO 600#, IA TO 900#. ***WELL LEFT S/I, TAG ON WING*** FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL F-09A (PTD #2011980) Classified as Problem Well . e Suh.icct: F-09A (PTD #2(11980) Classified as Problem Well From: "NSL.J, ADW Welllntegrily Engineer" <NSl.JADWWclllntcgrityEnginccr(q;BP.com> Datt·: Thu, 29 Dee 2005 05:56:27 -0900 To: "GP13, GC I Area Mgr" <GPBGC I TL«l~BP.com>, "Rossbcrg, R Steven" <Stevcn.Rossbcrg@ßP.com>, ":\SU, ADW Well Operations Supervisor" <NSLJADWWcIlOperationsSupervisor@BP.com>. "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Rcgg (E-mail)..<jim.Jegg@)admill.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<willton__aubcI1@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletioIlSupcrvisor@BP.conf>, "Kurz, John" <john.kurz@BP.com>, "(ìPB. GCI Wcllpad Lead" <GPBGCI WcllpadLcad@BP.com>, "GPB, Optimization Engr" <GPBOptimizmioIlEngr@ßP.com>, "GPB, Prod Controllers" <GPBProdControllers@BP.com>, "Zamora, Chris A" <Chris.Zamora@BP.com> ('(~' "\11' "1 ,J' ·k I "<-[ . ·""'Sp '''," "MCC'O[ L lJM ('ODY 0 (Vl;C()" .' ,. 'v 1115 0\\., dC .... - .yons\\ <fl.:; .com~·, ".J .'. " L:. , . <Cody.McCollum@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com>, "NSU, ADW Well Intcgrity Enginecr" <NSlJADWWelllntegrityEnginccr@~BP.com> All, Well F-09A (PTD #2011980) has sustained casing pressure on the IA and has been classified as a Problem well. Wellhead pressures on 12/28/05 were 2360/2130Nac and a TIFL failed on 12/28/05 due to IA fluid to surface. The plan forward for this well is as follows: 1. SL: C/O OGL V in Sta #4 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «F-09A.pdf» Thanks, Donald Reeves Well Integrity Engineer - Filling in for Anna Dube 907 -659-5102 907-659-5100 Pgr 1154 Content-Dt'scription: F-09i\.pd r F-09A.pdf Content-Type: application/octet-stream Content-Encoding: base64 .J-A SÇl' (p~) '2 ( 30fSI þ'~þ (¡'s.) B~o ~~P -----.. 2~ ./ ole. ð k: ~ C"..D 1Ft Z L.. 4S-<>(., ~ ¡> \< ~11 I Z- \ '?J.t jöç 1 of 1 12/30/2005 8:38 AM TREE = W8..LHEAD = ACTIJLI. TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = DatumMD= DatumTVD = 6"CIW IIttEVOY OTIS 67.32' 38.17' 3200' 99 @ 10416' 9863' 8800' SS F-09A SAFETY NOTES: 9-5/8" CSG WAS CUT @ 2030'. 7",25#, IJ4SWAS TIEDBACK@ 8902' AND RAN TO SURF. 7" WAS HUNG IN OLD 9-/58" CSG SPOOL W/?" SLIPS. . 1980' -13-1/2"011S SSSV LANDNP, ID= 2.75" I Minimum ID = 1.92" @8764' 3-1/2" BKR DEPLOYMENT SLV GAS LFT MA.NDRELS TVD DEV TYÆ VLV LATCH PORT [)lI.lE 3132 11 McMURRY DMY BK2 5023 34 McMURRY DMY BK2 6524 36 McMURRY DMY BK2 7403 38 McMURRY DMY BK2 7499 38 McMURRY DMY BK2 8728' -13-1/2" 011S SLIDING SLEEVE, D = 2.75" 113-318" CSG, 72#, L-80, ID = 12.347" 8758' 3-1/Z' BKR DER.OYMENTSLV, ID-1.9Z' 13-1/2" TBG, 9.3#, L-BO, .0087 bpf, ID = 2.992" I 8785' -1 BOT G SfA L A SSY W/LA TCH (BB-iIND CT LNR) I -1 BOT 3- H PKR W/ MILLOUT EXT (BB-iIND CT LNR) I H ELMD TT NOT LOGGED I 9-518" CSG, 47#. L-80, ID = 8.681" PERF ORA TION SUIIIfIIIARY REF LOG: BHI GR ANGLEA TTOP ÆRF: 83@ 10198' t-bte: Refer to Production DB for historical perf da1a SIZE SPF INlERlfAL Opn/Sqz [)lI.TE 1.56" 6 10198 -10248 0 05/18/04 1.56" 4 10380-10620 0 01/02/02 1.56" 6 10663 - 10738 0 05/18/04 -1 TOP OF GMT PLUG I HTOPOFWNDOW I -1 MA. RKER JOINT I 17" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 10292' DAlE 12/07/79 01/02/02 03/20/02 05/08/04 REV BY COMIllENTS ORIGINAL COMPLETION DACIKAK CTD SIDETRACK GRO'tlh LINER ID CORREC110N BJMcllKK ADPERFS DATE REV BY CO IIIfIII ENTS FRUDHOE BA Y UNrr W8..L: F-09A ÆRMrr No: # APIt-b: 50-029-20403-01 SEC. 2, T11N, R13E BP Bc:ploration (Alaska) JUL 1 ;}; ?..oü4 REPORT OF SUNDRY WELL OPERATIONS. " ~~,,,,.I.,,, ~¡C"I . 1. Operations Performed:'cl "'. l.. , AbandonD Repair WellD PluÇJ PerforationsD Stimulate D OtherD Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate [K] Re-enter Suspended Well 0 (" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION ~" If- r~ 11 "< ~.,~" r'OO 1.;1 ,\ 1.."" 11.."..., 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 201-1980 BP Exploration (Alaska), Inc. Development ŒJ Exploratory 0 Service 0 6. API Number 50-029-20403-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.30 8. Property Designation: ADL-028280 11. Present Well Condition Summary: Stratigraphic 0 9. Well Name and Number: F-09A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 10981 feet true vertical 9056.3 feet Effective Depth measured 10946 feet Plugs (measured) Junk (measured) None None true vertical 9055.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30.0 - 110.0 1490 470 Liner 7360 9-5/8" 47# L-80 2030 - 9390 2029.8 - 8423.4 6870 4760 Liner 2188 2-3/8" 4.7# L-80 8758 - 10946 7869.0 - 9055.0 11200 11780 Liner 924 7" 29# L-80 8899 - 9823 7987.3 - 8831.1 8160 7020 Production 8874.. 7" 26# IJ4S 28 - 8902 28.0 - 7989.8 4980 4320 Surface 2671 13-3/8" 72# L-80 29 - 2700 29.0 - 2699.2 4930 2670 Perforation depth: Measured depth: 10198 -10248,10380 -10620,10663 -10738 True vertical depth: 9044.71 - 9048.97, 9050.83 - 9044.85, 9043.41 - 9041.55 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 26 8813 Packers & SSSV (type & measured depth): 3-1/2" Baker 3-H Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 16.2 25 640 @ 8809 13 Prior to well operation: Subsequent to operation: Oil-Bbl 539 2284 17.1 425 532 Tubing Pressure 1174 248 14. Attachments: Copies of Logs and Surveys run- 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development ŒI Service 0 Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )1CU-t CcJ-<'Ø-. WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: N/A Title Production Technical Assistant Signature Phone 564-4657 Date 7/8/04 Form 10-404 Revised 4/2004 ORIGINAL RBDMS 6Ft. JUL 1 3 200~ ( f F-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/15/04 *** WELL FLOWING ON ARRIVAL***. DRIFT TBG WI 1.75 CENT TO 101501 SLM. RDMO. *** LEAVE WELL SHUT-IN RETURN TO DSO TO POP *** 05/16/04 CTU #9: PERFORATING. MIRU. WELL FLOWING UPON ARRIVAL. RIH WI PDS MEMORY GR/CCL. «<CONTINUED ON 5117/04»> 05/17/04 CTU #9: PERFORATING. «<CONTINUED FROM WSR 5/16104»>. CONTINUE RIH WI PDS MEMORY GR/CCL AND LOG FROM 108601 TO 9950. CORRELATE TO SLB MCNUGR/CCL SWS 02-JAN-02. RIH WI GUN #1 2511.56" 6 SPF PJ GUNS. SHOOT 10,7151 TO 10,7401 AND POOH. ALL SHOTS FIRED. MU GUN #2 251 1.56" 6 SPF PJ GUNS AND RIH. SHOOT 10,6901-107151 AND POOH. ALL SHOTS FIRED. MU GUN #32511.56" 6 SPF PJ GUNS AND RIH. SHOOT 10,6651 - 10,6901 AND POOH. ALL SHOTS FIRED. . PERF INTERVALS, CORRECTED TO REFERENCE LOG BHI GR MWD 12/22/01-12/31/01 ARE ACTUALLY 106631 - 107381 MD.. «<CONTINUED ON WSR 5/18/04»>. 05/18/04 CTU #9: PERFORATING. «<CONTINUED FROM WSR 5/17104»> BREAK DOWN GUN #3. MU PDS LOGGING STRING. RIH & LOG FROM 104001 - 9800. MD. CORRECT LOG TO SWS MCNL/GRICCL 02-JAN-02. MU GUN #4: 251 1.56" 6 SPF PJ GUNS AND RIH. CORRECT TOP TOP SHOT AT FLAG AND PERFORATE 102251 TO 10250 AND POOH. ALL SHOTS FIRED. BREAK DOWN GUN #4. MU GUN #5: 251 1.56" 6 SPF PJ GUNS AND RIH. CORRECT TO TOP SHOT AT FLAG AND PERFORATE 10,2001-102251 AND POOH. ALL SHOTS FIRED. LAY DOWN TOOLS, CONTACT PCC AND PAD OPERATOR TO POP WELL. WELL LEFT SHUT-IN. WELL NOT FREEZE PROTECTED. «< JOB COMPLETE »>. . PERF INTERVAL, CORRECTED TO REFERENCE LOG BHI GR MWD 12/22/01- 12/31/01 ARE ACTUALLY 101981 - 102481 MD.. FLUIDS PUMPED BBLS 125 110 92 327 Methonal Filtered 1 % KCL Diesel TOTAL Page 1 TREE = WELLHEAD = ACTLVHOR = KB. ELEV = BF. ELEV = KOP= ,Max An~e = Datum MD = DatumTVD = 6" CrN flkEVOY OTIS' 67.32' 38.17' 3200' 99 ~ 10416' 9863' 8800' SS 113-318" CSG, 72#, L-80, ID = 12.347" H 2700' Minimum ID = 1.92" @ 8764' 3-1/2" BKR DEPLOYMENT SLY 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 1-1 8785' 1 TOP OF 7" LNR 1-1 8899' 19-518" CSG, 47#, L-80, ID = 8.681" 1--1 9390' f-A PERFORATION SUMMARY REF LOG: BHI GR ANGLEATTOP ÆRF: 83@ 10198' I\bte: Refer to Production DB for historical perf data SIZE SPF IN1£RV AL OpnlSqz DA TE 1.56" 6 10198 - 10248 0 05/18/04 1.56" 4 10380 -10620 0 01/02/02 1.56" 6 10663 - 10738 0 05/18/04 I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 11 10292' DA 1£ REV BY COMMENTS 12107/79 ORIGINAL COMPLETION 01/02102 DACIKAK CTD SIŒfRACK 03/20/02 GROtlh LINER ID CORREC110N 05108104 BJMcLlKK ADPERFS F-09A .!. ~ .LL í . j z .. DATE REV BY { SAFETY NOTES: 9-5/8" CSG WAS CUT @ 2030'. 7",25#, IJ4SWAS TIEDBACK@8902' AND RAN TO SURF. T' WAS KJNG IN OLD 9-/58" CSG SPOOL WI7" SLIPS. 1980' H3-1/2"011S SSSV LANDNP, ID=2.75" I ~ L GAS LFT tv1A NDRELS ST tv[) TVD DB! TYÆ VLV LATCH PORT Ql\1£ 5 3188 3132 11 McMLRRY DMY BK2 4 5324 5023 34 McMLRRY DMY BK2 3 7144 6524 36 McMLRRY DMY BK2 2 8242 7403 38 McMLRRY DMY BK2 1 8364 7499 38 McMLRRY DMY BK2 8728' 1-13-1/2" 011S SLIDING SLEEVE, D = 2.75" 1 8758' 1"13-1/2" BKR DER...OYM8'JT SLV, ID = 1.92" 1 8785' 1-1 SOT G SEAL ASSY W/ LA TCH (B&lIND CT LNR) I 8813' 1-1 BOT 3-HPKRW/MILLOUTEXT(B&lIND CT LNR) 1 1-1 ELMD IT NOT LOGGED I I ... 9790' 1-1 TOP OF GMT PLUG I 9823' I-1TOPOFWNDOW 1 10182' 1-1 Ml\RKER JOINT 1 z 1 10946' 1-1A31D 1 1 10981' H2-3/8" LNR, 4.7#. L-80. .0039 bpf, ID = 1.995" I COMM8'JTS ffiUDHOE SA Y UNIT WELL: F-09A ÆRMIT No: # APII\b: 50-029-20403-01 SEC. 2, T11N, R13E 8P Exploration (Alaska) l2s ~ 10. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7rr'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 , F-09A ~O/-19? 5/17/04 Mech. CH /.;(, S- ;2 f? 1 Caliper Survey Print Name: ..,~/"I / 1 r¡~~J ' ,II / " fY Ò UJ'f1-J: 0- t . ~l~\dv"J C~h(cV\mJ Date: ~ J'-\~ ~Ó~ 0,-1 Signed: PRoAcri\JE DiACINOSTic. SER\Jius, INC, PO Box I ~69 STAffoRd IX 77477 Phonc:(28 1 ) 565-9085 Fax:(281) 565- 1369 E-mail: pdsl.~.mcmorylog.com Wcbsitc: ww\\.mcmorylog.com lr3s ~ 10. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 F-09A 5/18/04 Mech. CH 1 :2 ú' ,. I CI.'{ I .~, ç ~ ~ Caliper Survey Signed: / )L~~~ ò.~~~j Date: .À)' J~ ). (J ~ .,,{ 11 Ok It'-Vl ¿ Print Name: I ~ \Jv (\ V' ~ PlmAui\J1: DiACjNOSlic S[I(vill:~, INC.:., PO Box I ~69 SIAHoIU) IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pdsrq'menwryog.com Wð~site: \\w\\..n1êhlOrytdj.~(\nl ~ . .',- ,. .., ~ ~~4 Ì\.~ t{ DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2011980 Well Name/No. PRUDHOE BAY UNIT F-09A Operator BP EXPLORATION (ALASKA) INC Sf2w1- ,{, 1 ~ \ API No. 50-029-20403-01-00 MD 1 0 9 81 ....---- TVD 9056 /' Completion Date 1/2/2002 /' Completion Status 1-01L Current Status 1-01L UIC N ----------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ "I N:L. -- ------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) .- Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ !ßD D ðG-762 4--E D C c:..A"O580 Log Log Run Scale Media No 1 1 Interval OH / Start Stop CH Received 9701 10981 Open 4/18/2002 Comments 8564 10943 Case 2/19/2002 -~-l i i i ---1 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y I~ Daily History Received? ~ ~ Chips Received? ¥/M Formation Tops ~~- Analysis Received? ~ Comments: t1r~"':'" ~ v1 ~ f"\-I. C ~ I..V.. ~ I\J\}II. 'i-.rv...... VJv}. M f., ~ C RJ c.. I &; K { c. C. L.. ~ J Of- À. h ~ 6:> \( /lfV\w t\ q!' ~~.... - Lc Cf.fl 0 J-U"- Nt ~ fa Ý\ / MÞlD 9. y ~:) - (IJ Cf..t ( ~ 'ìv p c..o..J.ul '8:::' -ú. VI - l 0 C¿ '-l) ,M. ~ Compliance Reviewed By: Date: ;(,7 J fv,- J ô-.g~-- . .. ( STATE OF ALASKA ~ ALASKA -,I... AND GAS CONSERVATION COMrJ"-.JION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-198 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 '.,""- .. ,...~ 50-029-20403-01 4. Location of well at surfaceu""" ""~""'- ;"-, ì .~v'L.ß,~ ~ -. ~'" I 9. Unit or Lease Name 2467' SNL, 2405' EWL, SEC. 02, T11 N, R13E, UMÎ G.)IV.i?¡',::-;i';\ t 11 fal~1fjæ)\ Prudhoe Bay Unit At top of productive interval " . ,DÞ.TE -' I~ 3940' SNL, 604' WEL, SEC. 03, T11 N, R13E, UM ~ ,L : :.~~ ,: 10. Well Number At total depth II V~I. ';:'.. , .~~.:,~.~~~ ,. F-09A 3687' SNL, 44' EWL, SEC. 02, T11 N, R13E, UM t~.._Q._--- 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 67.30' ADL 028280 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 12/27/2001 12/31/2001 1/2/2002 N/ A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10981 9056 FT 10946 9055 FT 181 Yes DNo (Nipple) 1980' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, Memory CNL, CCL 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PUllED 20" X 30" Insulated Conductor Surface 110' 36" 7.9 cu vds Permafrost 13-3/8" 72# L-80 Surface 2700' 17-1/2" 4269 cu ft Arcticset 9-5/8" 47# L-80 Surface 9390' 12-1/4" 1230 cu ft Class 'G' 130 cu ft AS 7" 29# L-80 88991 9823' 8-1/2" 391 cu ft Class 'G' 2-3/8" 4.7# L-80 8758' 10981' 3" 73 cu ft Class IG' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 4 spf 3-1/2",9.3#, L-80 8813' 8813' MD TVD MD TVD 10380' - 10620' 9051' - 9045' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 25001 Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 20, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-Bel GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO 1/24/2002 24 TEST PERIOD 2542 4786 132 95.71 1883 Flow Tubing Casing Pressure CALCULATED OIL-Bel GAs-McF WATER-BBL Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 25.7 28. CORE DATA ~~Lt"L~~\\ 'l!r=n tL..,,¡¡¡ '.' "'"", if Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cor~ c\i~\",'\J~_1 VI No core samples were taken. FES 272002 - l2\!as!m O¡¡ & Gas Gûmt Gom~i~¡On1 l-\ncherage r ", i"""~ ~ "~"'!. I~,' l\ RBDMS Form 10-407 Rev. 07-01-80 ~ ¡} I ;' Þ mit In Duplicate .""'": . ,~. I , .' tJ ~ "\ ij t) ~ ~~ l'~;\ L~ 8Fl MAR ~ I~ 5~ ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 25N 9901' 8899' 25P 9911' 8907' 22P 9997' 8968' 21N 10088' 9016' 21P 1 0092' 9017' Zone 1 B 10253' 9049' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ rl, ßNJ¿ Title Technical Assistant Date 6 ';k ?-.. 7" o~ F-09A Well Number 201-198 Permit No. / Aooroval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/19/2001 12/20/2001 12/21/2001 ( ( BP EXPLORATION Operations Summary Report F-09 F -09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 00:00 - 04:30 04:30 - 18:00 18:00 - 00:00 00:00 - 06:00 06:00 - 11 :20 11 :20 - 13:30 13:30 -14:15 14:15 -15:00 15:00 -15:30 15:30 -16:00 16:00 - 21:00 21 :00 - 23:15 23:15 - 23:45 23:45 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 02:15 02:15 - 04:00 04:00 - 05:00 05:00 - 06:15 06:15 - 07:30 07:30 - 08:30 08:30 - 10:30 10:30 -12:15 12:15 -12:45 12:45 - 13:05 13:05 -15:00 15:00 - 18:00 18:00 - 19:15 Phase 4.50 MOB 13.50 MOB P N PRE WAIT PRE 6.00 MOB 6.00 MOB N N WAIT PRE WAIT PRE 5.33 MOB 2.17 MOB N N WAIT PRE WAIT PRE 0.75 MOB P PRE 0.75 MOB P PRE 0.50 MOB 0.50 MOB 5.00 MOB 2.25 MOB 0.50 MOB P N P P P PRE WAIT PRE PRE PRE PRE 0.25 MOB P 0.50 MOB P 1.50 BOPSUF P 0.25 BOPSUF P PRE PRE DECaMP DECaMP 1.75 RIGU P PRE 1.00 RIGU P 1.25 RIGU P 1.25 BOPSUF P PRE PRE DECaMP 1.00 RIGU P PRE 2.00 RIGU P 1.75 BOPSUF P PRE DECaMP 0.50 BOPSUF P 0.33 BOPSUF P 1.92 BOPSUF DECaMP DECaMP DECOMP 3.00 BOPSUF P 1.25 BOPSUF P DECOMP DECOMP Page 1 of11 Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations Move from DS 5-12B to WOA F Pad. Standby on weather. Winds gusting to 27 mph. Need gusts less than 20 mph prior to raising windwalls. Wait on wind. Wind at 21 - 35 mph. -80 F wind chill. Wait on Wind to raise derrick and wind walls. Wind at 25-35 mph, -27F, -80F chill factor. Continue to wait on weather. Winds moderating slowly. Winds 20 mph at 11 :20. This is the Nordic maximum. Watch for one hour to see if the winds remain below minimum prior to holding safety meeting. No good, continue to standby. Weather moderating, prep pad with loaders to remove drifting snow. Safety meeting prior to moving rig over well. Review SWS-Nordic policies and proceedures, also SSD PIP. Wind speed down to 8 mph, gusting to 15 mph. Now below maximums, can begin moving rig onto well. Call pad operator to arrive location for pad inspection walkthru. Square rig up in front of well to move on. Additional safety discussion about moving over well. Wait on pad operator. Raise derrick and wind walls. Secure derrick jack cylinders and pick up BOP stack. Safety Meeting. Review BPX SOP for backing over well. Flowline is shut in with 0 psi. No gas lift line. Well is dead and all valves closed. Chocks in place for rig. Nipple down tree cap. Back rig over well after Safety Meeting. ACCEPT RIG AT 00:30 HRS, 12-21-01. NIU BOPE. SAFETY MEETING. Review procedure and hazards of picking injector out of pipe bay. Pick injector head out of pipe bay. Stab injector head on riser. [ Part of rig move]. Make up guide arch to injector head. [Part of rig move] Prep to pull new CT off reel. Crew change. [Part of rig move]. SAFETY MEETING. Review procedure and hazards for pulling CT and stabbing into injector head. Continue with RU. Catch up on rig housekeeping items prior to stabbing coil into injector. [Part of rig move]. Stab pipe. [Part of rig move]. Weld on CTC. (Note - Using Baker weld on CTC to pass Baker dart for cementing liner. ID=1.0625", SWS CTC ID=1.0". API specs for 1-1/2" MT is 1.125"ID max.) Fire drill. Grease swab, master, wing valves, pump open SSV, (Grease crew). Inspect chains on injector. Safety meeting prior to starting pressure test. Review proceedures and policies for Nordic-SWS, BP, AOGCC. Begin BOP test, witness waived by AOGCC, John Spalding. SAFETY MEETING. Crew change and pre tour safety meeting. Reviewed BPX BOP test procedure and hazard mitigation. Printed: 1/7/2002 1 :47: 16 PM ,'- ( ( BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: F-09 Common Well Name: F-09A Spud Date: 12/21/2001 Event Name: REENTER+COMPLETE Start: 12/21/2001 End: 1/2/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/2/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12121/2001 19:15 - 00:00 4.75 BOPSUF P DECOMP Continue BOPE pressure I function test. Change out upper 2" combi rams. 12/22/2001 00:00 - 01 :30 1.50 BOPSUF P DECOMP Finished Initial BOPE pressure I function test. Send test report to AOGCC. 01 :30 - 03:00 1.50 STWHIP P WEXIT Pump BKR dart, On seat at 41.2 bbls. Sheared at 4200 psi. Pump second dart, on seat at 41.6 bbls, Sheared at 4600 psi. Dart went thru LBRT [Liner back door running tool] both times OK. Test was for this wells completion. 03:00 - 03:45 0.75 STWHIP P WEXIT Held Pre-Spud meeting with all personnel. Reviewed well plan and possible hazards. Held PJSM for making up BHA #1. 03:45 - 04:45 1.00 STWHIP P WEXIT MIU BHA #1 with 1.75 bend motor and 2.74" HCC, Parabolic diamond Mill. MIU BHI MWD tools. 04:45 - 07:45 3.00 STWHIP P WEXIT RIH with BHA #1. Add Biozan and friction reducer to water in rig pits. Shallow test MWD tools and orienter. Continue RIH. 07:45 - 08:45 1.00 STWHIP P WEXIT 9480', Did not see any obstructions while RIH. Begin tie in pass logging down. Make -13' correction. 08:45 - 09:00 0.25 STWHIP P WEXIT Continue RIH. Tag bottom at 9804' pumps down. PU clean at 28klbs. Kick on pumps. Free spin 1900 psi at 1.7 bpm. 09:00 - 09:25 0.42 STWHIP P WEXIT Orient around to 255 deg. 09:25 - 10:30 1.08 STWHIP P WEXIT Mill cement fr/9804', 120 fph. Easy drilling at first, as usual. Slowed down to 38 fph by 9832', and 300 Ibs motor work, continue to mill at 242 TF, and 38-45 fph. Drilling from 9850'.9857' was in the 32-35 fph range. Good enough cement for ramp. (Barely) 10:30 -10:50 0.33 STWHIP P WEXIT Orient around to 90R. 10:50 -10:55 0.08 STWHIP P WEXIT Mill ramp fr/9857'-9861', at TF=79 R. Good at first, then had drilling break, and ROP picked up to 75 fph. Cement probably not hard enough for ramp. Need to orient around to 240 deg again, and drill until we hit hard cement. 10:55 - 11 :20 0.42 STWHIP P WEXIT Orient around to 240 deg. 11 :20 - 11 :50 0.50 STWHIP P WEXIT 9861', Resume milling @ 77 fph, 244 TF, 250 psi motor work. Easy drilling to 9867', then ROP dropped back down to about 40 fph at best. Continue milling to 9885' to get to best possible cement. Unable to find any. ROP was up around 50-60 fph at the end. Drilled to 9885', deepest we could go and still make alternate window. Need to POOH, underream and lay in new cement. 11 :50 - 12:30 0.67 STWHIP N CEMT WEXIT 9885', pump 15 bbl bio sweep. 12:30 - 14:05 1.58 STWHIP N CEMT WEXIT POOH with BHA #1. Paint flag at 9359.6', (9300' EOP). 14:05 - 16:30 2.42 STWHIP N CEMT WEXIT Tag up at surface with BHA #1. Stand back injector. Lay down BHA #1, Mill was in great shape, with little wear. Pick up BOT underreamer (2.65"x6.05"), straight motor, 2 joints of PH6 pipe, Bowen upldown jars and 2 disconnects. 16:30 -18:30 2.00 STWHIP N CEMT WEXIT RIH with BHA #2 for underreaming. Stop at flag and correct -21 ft CTD. RIH. 18:30 - 21 :30 3.00 STWHIP N CEMT WEXIT Ream down starting at 9700 ft. 1.7 11.7 bpm, 2850 psi. 10 fpm. Tag first cement at 9801 ft. Several stalls to get started. Underream down at 0.2 fpm. Several stalls. UR to 9821 ft. Pump 10bbl Biozan sweep. UR to 9825 ft. 21 :30 - 00:00 2.50 STWHIP N CEMT WEXIT UR. Average 3 ft per hour. 1.7/1.7 bpm, 2500 psi. UR to 9831 ft. 12/23/2001 00:00 - 02:00 2.00 STWHIP N CEMT WEXIT UR. Very slow progress. Several stalls. 1.7 11.7 bpm, 2400 Printed: 1/7/2002 1:47:16 PM ~' ~' ( BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: F-09 Common Well Name: F-09A Spud Date: 12/21/2001 Event Name: REENTER+COMPLETE Start: 12/21/2001 End: 1/2/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/2/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/23/2001 00:00 - 02:00 2.00 STWHIP N CEMT WEXIT psi. UR to 9836 ft. 02:00 - 04:30 2.50 STWHIP N CEMT WEXIT UR. Very slow progress. Several stalls. 1.7/1.7 bpm, 2400 psi. UR to 9841 ft. 04:30 - 06:30 2.00 STWHIP N CEMT WEXIT 9842.8',06:30 update. Continuing to UR slowly. Not making much progress. Call town discuss options. 06:30 - 06:50 0.33 STWHIP N CEMT WEXIT Continue to UR, waiting on confirmation from geo's that higher window depth by 30' would be acceptable. 06:50 - 08:35 1.75 STWHIP N CEMT WEXIT Pump 10 bbl bio sweep. Chase to tubing tail. Circulate bottom us from TT (29 bbls). 08:35 - 10:00 1.42 STWHIP N CEMT WEXIT Circulate across the top. Hold 200 psi back pressure with choke to prevent possible swabbing (Unknown casing quality - 30 year old well). Tagged tubing tail with UR on way into tubing. Had to work it for a minute to get through. Did not have to work it hard, did not use jars, and it popped thru easily. Possibly UR arms still open. 10:00 - 11 :20 1.33 STWHIP N CEMT WEXIT Lay down BHA #2. Underreamer showed wear in both reaming and backreaming. All arms recovered ok. Pick up BHA #3, cement stinger. 11 :20 - 13: 15 1.92 STWHIP N CEMT WEXIT RIH with BHA #3, to lay in cement plug. RIH to 8850', pull back up to 8750'. Didn't see any overpull at the TTail. RIH, tag TD at 9879'. Top of UR depth, bottom of old pilot hole? No depth correction made. 13:15 - 13:35 0.33 STWHIP N CEMT WEXIT Safety meeting prior to pumpting cement. 14 persons. 13:35 -13:55 0.33 STWHIP N CEMT WEXIT Circulate while waiting on cementers to take on water. 13:55 - 14:50 0.92 STWHIP N CEMT WEXIT Open up to cementers. Flood lines with fresh H2O. Pump 5 bbls fresh H2O lead. PT lines to 4000 psi. Passed PT ok. Swap to cement. Pump 15 bbls of 17.0 ppg class G. Follow by 5 bbls of fresh H2O. Swap to rig pumps. Displace cement with rig bio/water at 2.2 bpm. Cement to nozzle, slow rate to 1.0 bpm, nozzle 10' off bottom. Pumped 1 bbl around. tried at rate of 1.0 bpm, but cement was falling out of the coil. Bring rate up to 2.0 bpm, CTP1500 psi. After 1 bbl out, lay in cement at 100%. Top of cement plug at 9437', Pull up to safety depth 9200'. CIP @ 14:50. Cement thicking time 1.5 hours. 14:50 - 16:00 1.17 STWHIP N CEMT WEXIT 9200', Swap to 2# bio. Circulate 30 bbls to nozzle. RIH jetting cement with bio. clean out to 9720' CTM. Chase up to TTail at 80%. Wash back down to 9720', pull back to nail at 80%. 16:00 -17:40 1.67 STWHIP N CEMT WEXIT POOH, pumping at 80%. 17:40 -18:00 0.33 STWHIP N CEMT WEXIT Tag up at surface. Change out nozzles to JSN. Wash stack. 18:00 - 19:00 1.00 STWHIP N CEMT WEXIT Shut down for crew change and pre tour safety meeting. Review Procedures and hazards to rig up and cut CT. 19:00 - 20:30 1.50 STWHIP N CEMT WEXIT RIU Hyd Cutter and cut off 200 ft of CT. Weld on new 1.06" ID CTC. Pull test and pressure test CTC. 20:30 - 21 :00 0.50 STWHIP N CEMT WEXIT SAFETY MEETING. Review procedure and hazards for MIU BHA. 21 :00 - 21 :45 0.75 STWHIP N CEMT WEXIT MIU MWD BHA with 1.75 deg motor and 2.74" diamond parabolic mill. 21 :45 - 23:45 2.00 STWHIP N CEMT WEXIT RIH with BHA #4. 23:45 - 00:00 0.25 STWHIP N CEMT WEXIT Log Tie-in with GR to BHCS/GR. 12/24/2001 00:00 - 00:45 0.75 STWHIP N CEMT WEXIT Log Tie-in with GR to BHCS/GR. [-20 ft CTD.] 00:45 - 01 :30 0.75 STWHIP N CEMT WEXIT Tag firm cement at 9709 ft. Drill hard Cement at 26 fph, 4K WOB, 1.8/1.8 bpm, 500 psi motor work. TF = 90L deg. Drilled firm cement to 9720 ft. ROP went to Printed: 1m2002 1:47:16 PM ,c t' ( ", BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: F-09 Common Well Name: F-09A Spud Date: 12/21/2001 Event Name: REENTER+COMPLETE Start: 12/21/2001 End: 1/2/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/2/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12124/2001 00:45 - 01 :30 0.75 STWHIP N CEMT WEXIT 60 fph. Lost WeB. Lost TF. 01 :30 - 01 :45 0.25 STWHIP N CEMT WEXIT Orient TF to 150L. 01:45 - 02:15 0.50 STWHIP N CEMT WEXIT Drill hard cement at 9725 ft. TF = 11 OL. ROP inc. to 40 fph at 9730 ft. 2000 WeB, 300 psi motor work. ROP inc to 60 fph. Drilled to 9756 ft. Stop drilling cement. 02:15 - 04:00 1.75 STWHIP N CEMT WEXIT Wait on Cement to see if it firms up more. 04:00 - 04:10 0.17 STWHIP N CEMT WEXIT Drill cement. ROP = 60 FPH wi 1500# WeB. 04:10 - 06:30 2.33 STWHIP N CEMT WEXIT Wait on Cement. 06:30 - 07:10 0.67 STWHIP N CEMT WEXIT Orient to 150L. Free spin 2950 psi at 1.75 bpm. 07:10 - 07:20 0.17 STWHIP N CEMT WEXIT RIH at 150L, tagged top of cement at 9701', stalled motor. PU, RIH, getting 350 Ibs motor work, should be in pilot hole. Seeing reactive torque of 50 deg. Drilling break at 9709'. ROP 60 fph, 3420 psi CTP, TF 186 deg. Looks like drilling new hole, or more likely cement chunks in pilot hole? 07:20 - 08:00 0.67 STWHIP N CEMT WEXIT 9718', ROP 46 fph, CTP 3320, 1.7/1.7, 70 deg reactive torque. 9726', ROP 32 fph, CTP 3160, 1.7/1.7,45 deg reactive, 6000 WeB. Check free spin 2700 psi @ 1.7 bpm. 9727', Drilling break ROP 200 fph, no motor work, back in clean hole? 9755', ROP 44 fph, CTP2870, 1.7/17, no reactive torque. 9760', ROP 41 fph, CTP 2880,3000 WOB. No reactive. 9761', ROP 24 fph, CTP 2950 psi, 4500 Ibs WeB, No reactive. TF 150L (206 deg). 08:00 - 09:00 1.00 STWHIP P WEXIT 9761',08:00 update. Milling pilot hole in hard cement finally. CTP=2850, 1.7/1.7 TF 156L (204 deg), 18 fph. Weight check at 9764, free spin 2677 at 1.65 fpm. 09:00 - 10:00 1.00 STWHIP P WEXIT 9765', 09:00 update. Hard milling. 3500 Ibs WOB, only 3050 on CTP. Not getting much motor work. ROP very low. Only made 4.0' in last hour. Returns still 1 00%. 10:00 - 10:45 0.75 STWHIP P WEXIT 9772',10:00 update. Continued hard milling (Good!). 2200 Ibs WOB, 3250 psi CTP, getting good motor work. ROP up to 12 fph (Screaming along). 10:45 - 10:55 0.17 STWHIP P WEXIT 9780', tool face has walked around to 150R, Take 3 clicks to get it over to 180 out from window. 10:55 - 11 :30 0.58 STWHIP P WEXIT Resume milling, TF 120L (240 deg). 11 :30 - 11 :45 0.25 STWHIP P WEXIT 9792', continue milling, ROP 14 fph. TF back around to 190. PUmp 10 bbl bio sweep. 11 :45 - 11 :50 0.08 STWHIP P WEXIT Take 1 click. 11:50 -13:15 1.42 STWHIP P WEXIT 9794', Resume milling, ROP=20 fph, TF=117L (247 deg). 3350 psi motor work, 1500 Ibs WeB. 13:15 -13:50 0.58 STWHIP P WEXIT 9815', Finished drilling pilot hole, orient around to 60R to begin ramp section. 13:50 -14:40 0.83 STWHIP P WEXIT Mill ramp at TF =73R, 3375 psi CTP, fr/9815'-9823', ROP=25 fph during ramp section. Did not see any radical TF changes. Stopped after 8', at 9823' as per procedure. Pump 10 bbl bio sweep around. 14:40 - 16:20 1.67 STWHIP P WEXIT POOH. Paint flag at 9659' (9600' EOP). Chasing sweep COHo 16:20 - 16:40 0.33 STWHIP P WEXIT Safety Meeting prior to changing out BHA's. 16:40 - 17:20 0.67 STWHIP P WEXIT Lay down BHA #4, Pick up BHA #5, window milling BHa. sing 2.5 deg WF motor. 2.74" OD Hughes 1 step window mill, Sperry orienter, Baker MHA. Printed: 1/7/2002 1:47:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/24/2001 12/25/2001 ,c II ,~ ( Page 5 of 11 BP EXPLORATION Operations Summary Report F-09 F-09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 17:20 -17:45 From - To Hours Activity Code NPT WEXIT 17:45 - 18:30 18:30 -18:45 18:45 - 21:00 21:00-21:45 21 :45 - 00:00 00:00 - 03:00 03:00 - 05:30 05:30 - 06:30 06:30 - 06:45 06:45 - 07:15 07:15 - 07:40 07:40 - 09:05 09:05 - 09:55 09:55 - 10:45 10:45 - 11: 10 11:10 -13:10 0.42 STWHIP P 0.75 STWHIP N 0.25 STWHIP N 2.25 STWHIP P 0.75 STWHIP P 2.25 STWHIP P 3.00 STWHIP P 2.50 STWHIP P 1.00 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 0.42 STWHIP P 1.42 STWHIP P 0.83 STWHIP P 0.83 STWHIP N 0.42 STWHIP P 2.00 STWHIP P Phase WAIT WEXIT OPRB WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WAIT WEXIT WEXIT WEXIT Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations Attempt to RIH. Hitting every collar on way in. Can't work past wlo kicking on pumps. Try for 200'. This may take forever, and will probably end up trashing the mill. Call HC for new mill with brass guide ring brazed on. Tag up at surface, rig back injector to circulate and keep lines from freezing. M/U 2.74" window mill with brass guide. RIH. No problem in 3 1/2" tbg connections. RIH at 80 fph, no pump. sat down at 8448 ft. Roll pump, fell thru. sat down at 8510, 8540,8575, 8608, 8669,8699,8730,8792, 8796, and 8829 ft. Rolled pump each time and went thru OK. RIH inside 7" liner. Correct CTO at flag at 9659.3 ft. [-22 ft CTO.] Orient TF to 70L. Tag TO at 9823 ft. Flag CT at 9823 ft. Pick up 1 ft to 9822 ft. Start time milling procedure at 9822 ft. Top of window at 9823 ft. 1.7/1.7 bpm, 2900 psi, TF = 75R. Time Milling 2.74" window thru 7" liner. 1.6/1.6 bpm, 2500 psi. TF = 75R. Follow milling procedure. Top of window at 9823 ft. Mill to 9824 ft. 3500# WOB. Milling window as per procedure. TF = 80R. 1.6 11.6 bpm, 2400 psi, 3500 - 5000# WOB. Mill to 9825 ft. Stacked wt. Pick up and ream down thru window. Milling window. Mill Changeout Milling at 9825.2',5500# WOB, CTP=2650 psi. No reactive torque. Pickup. Sticky on pickup. Free spin 2600 psi. RIH and tag at 9823'. Start depth was 9823'. Same as start depth. (Pipe stretch with new coil?) whatever problem is, it may be with poor weight transfer, or trashed mill. POOH to inspect BHA. Call for new mill with brass ring very securely brazed on. Pick up for tie in pass prior to POOH. (Tie in pass down may also damage mill, but we will make a short one in 7" casing.) log tie in pass down in 7" from 9490'. Make +2' correction Paint flag at 9559.2', (9500', EOP). POH circulating across the top, holding 200 psi on well with choke. Tag up at surface, stand back injector. PT MHA to 2000 psi. Passed OK. Changeout motor. No suspected problems with motor, but making the change while we have the chance. Inspect mill. Found wear on face of mill for 3/4" in from edge, but no swirl pattern in center of mill. Suggesting we may have a lip started, but have not crossed the center of mill or exited the casing. Mill in good enough shape to have started a window. It was not damaged by trip in hole. Wait on Hughes to bring new mills to rig. Make up new mill with brass ring brazed on (Silver solder instead of brass brazing). Gauged at 2.74". RIH BHA #5, New 1 step window mill, new WF 2.5 fixed motor, MWO, Orienter, 2 jts PH6, MHA, CTC. Tagged up at 8794' while RIH. PU, tag again. Tag a third time, kick on pumps got thru it. RIH, stop at EOP flag from last run. Make -21' Printed: 1/7/2002 1:47:16PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/25/2001 12/26/2001 t' ( Page 6 of 11 BP EXPLORATION Operations Summary Report F-09 F -09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 11:10 -13:10 From - To Hours Activity Code NPT WEXIT 13:10-13:30 13:30 - 18:00 18:00 - 20:30 20:30 - 22:00 22:00 - 22:45 22:45 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:20 03:20 - 05:05 05:05 - 05:45 05:45 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 11 :30 11 :30 - 13:00 13:00 -13:15 13:15 - 15:00 15:00 -15:15 15:15 -16:45 16:45 - 17:15 2.00 STWHIP P 0.33 STWHIP P 4.50 STWHIP N 2.50 STWHIP P 1.50 STWHIP P 0.75 STWHIP P 1.25 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 1.33 STWHIP P 1.75 STWHIP N 0.67 STWHIP N 1.25 STWHIP N 1.00 STWHIP N 1.00 STWHIP N 1.50 STWHIP N 1.00 STWHIP N 1.50 STWHIP N 0.25 STWHIP N 1.75 STWHIP P 0.25 STWHIP P 1.50 STWHIP P 0.50 STWHIP P Phase WEXIT DPRB WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations correction. Consistent with last 2 trips in the hole. RIH dry. Tagged up at 9732' 2x. Pick up and orient to original pilot hole orientation. Kicked on pumps, orientation 11 OR. RIH, set down a couple of more times, worked it through. SI pumps, RIH slick to TD. Dry tag several times. Kick on pumps, orient to 60R. RIH, tag at 9824.7' with pumps on. Paint flag. PUH 1'. Begin time milling sequence at 9823.7'. Free spin 2830 psi, TF 72R, 1.6/1.6. Mill to 9825'. Continue time milling by schedule 9827.3' Continue time milling and starting to take weight, 4.4k 9828.6' woe is 6k. Mill by woe at 6k max. Lots of metal cuttings on magnets 9828.6' Have lost 100-200 diff, but no drill off. PU 28k and ease back to btm and begin stacking at 9827'. Still no diff incr and takes same wt. A couple PU's show a 8k overpull at btm and a second 5k overpull to 9817'. Backream to 9800' Work to get mill to make hole. Stack to 9k wi no diff. Acts like BHA is in a bind so that wt transfer is not getting to mill. Can see wt loss while RIH at 9827.0' which is official TD. Still on depth wi flag POOH to check BHA Mill had center wear as if it had just milled a normal window and gauged 2.74" -. Motor had a 3/4" wide x 6' long rub line from 6" above motor bend on high side indicating that motor was rubbing on the top of the window. Change mill, motor and MWD probe RIH wi BHA #6 (used 2.74" WS mill, 1.75 deg WF motor) to verify a window is cut and make 10' of hole Check TF at 9650' 1.7/3360/56L. RIH wlo pump. Tag at 9844.1' CTD (shy of flag by 5.5'). Measure to flag (at 9823.7') and correct to 9818.2' Check TF at 0 deg. Orient to 50R. RIH and stall at 9818.5' (twice) 1.6/3030/50R. RIH to 9820.7' and stall. 12k overpull. Mill ahead to 9824'. Some mtr work. Able to PU off btm with no overpull. Continue time milling to 9826'. Noted 10% formation solids in returns. Continue time milling to 9830'. Note 20% formation in returns. Orient 1 click to maintain 30 R TF. 3200 psi fs, 1 K# to 3K# woe. 100-200 psi mtr work. Mill to 9835'. Log gr tie in from 9490'. Add 8' correction. Paint EOP flag at 9500'. Estimate window top at 9823', window btm at 9828'. POOH for crayola mill. Hold pre job mtg for BHA handling and liner running tool test. Stand back milling BHA. MU Baker slim hole liner swivel assy. Pump wiper dart through coil to same. Landed and sheared at 4200 psi with 40.3 bbls pumped. MU 2.72" crayola mill assy. RIH with mill assy. Correct to EOP flag at 9500' (-22') Log gr tie in from 9535'. Add 4'[ correction (EOP flag now at 9504') Continue in hole Printed: 1/7/2002 1:47:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/26/2001 12/27/2001 12/28/2001 { , ( Page 7 of11 BP EXPLORATION Operations Summary Report F-09 F -09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 17:15 -17:30 17:30 - 20:30 20:30 - 21 :05 21 :05 - 22:25 22:25 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:45 02:45 - 03:20 03:20 - 03:30 03:30 - 05:45 05:45 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 13:00 13:00 -13:15 13:15 -14:00 14:00 -15:30 15:30 -16:00 16:00 -18:10 18:10 -19:05 19:05 - 19:15 19:15 - 19:30 19:30 - 21:10 21:10 - 23:10 23:10 - 23:45 23:45 - 00:00 00:00 - 01 :40 01:40 - 01:50 01 :50 - 02:00 02:00 - 05:30 05:30 - 07:00 07:00 - 08:30 08:30 - 09:45 0.25 STWHIP P 3.00 STWHIP P 0.58 STWHIP P 1.33 STWHIP P 1.58 STWHIP P 0.50 STWHIP P 0.50 DRILL P 1.75 DRILL P 0.58 DRILL P 0.17 DRILL 2.25 DRILL 1.75 DRILL 3.50 DRILL 0.50 DRILL 1.50 DRILL 0.25 DRILL 0.75 DRILL 1.50 DRILL 0.50 DRILL 2.17 DRILL 0.92 DRILL 0.17 DRILL 0.25 DRILL 1.67 DRILL 2.00 DRILL 0.58 DRILL 0.25 DRILL 1.67 DRILL 0.17 DRILL 0.17 DRILL 3.50 DRILL 1.50 DRILL 1.50 DRILL 1.25 DRILL P P P P P P P P N P P P P N N N N N N N N P P P P Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations Tag up at 9826' (estimate middle of window). Orient to 60R. Ream window with carbide crayola 1.6/2950 fs/74R with stalls starting at 9823.8', 9824.1' (several), clean to 9832.1' (stall) Ream 1.6/3080/52R from 9832.1' to tag 9841.3' which is TD from previous run Backream from TD to 9820' 1.6/2955/51 R, ream to TD. Get a click and repeat twice more to 109R. Dry tag twice from 9810', clean. Official window is 9823-28' POOH for drilling assy LD milling BHA. Mill gauged 2.72"- MU drillling BHA. Change out MHA and MWD probe RIH wi BHA#8 (2.12 deg motor) Begin tie-in to 9524' on BHCS logging up from 9570' 1.9/3900/90L Corr -20.0', RIH. Clean thru window. Tag at 9841'. Get TF at 62R. Life is good Drilling from 9841' 10-40'/hr 1. 7/3500/50R. Swap to used Flo Pro mud 9862' Orient, then dri1l1.5/3250/80R 1 0-30'/hr in 16 API cherty sand. Drill to 9883'. Drilling. 1.5/3200fs/70R. 10-20 fph in cherty sand. Drill to 9915'. Complete off loading second batch of mud. Getting 35 deg dog legs. May trip soon. Drilling. 1.5/3200 fs/70R. 10-15 fph in cherty sand. Frequent stalls. Dog legs dropping to 25-30 (expected). Suspect bit may be trashed. Drill to 9920'. POOH for motor angle change and to check bit. Hold pre job mtg prior to handling BHA. Install memory probe in MWD. MU new 1.5 mtr with DPI bi center bit. Hughes bit pulled in 8/10 condition. Trouble programing mwd tool. Continue to mu build assy # 2 with 1.5 mtr & DPI bicenter. RIH. Shallow test mwd. Good. Continue in hole. Window smooth. Get TF @ 160R 1.5/3700 CT press is high Orient around. Twenty clicks and got one. PU into 7" Drilling 40'/hr 1.6/3700/51 R. Drill to 9928' and MWD lost GR Investigate problem wi MWD GR. Refer to prior BHI"First Alert" memo regarding settings and assume problem could be related POOH for MWD failure. Chk tool again at 1000' LD MWD probe. Program new probe. Check bit, motor, orientor MU drilling BHA wi new probe Phz 1 due to 32 deg F and rain! RIH wi BHA #10 (same as #9) Continue RIH wi BHA #10. SHT @ 3800' Corr -20' at 9820'. RIH and tag at 9927'. Corr l' to 9828' Orient around from 150L Drilling 25'/hr from 9828' 1.5/3600/50R Drilling 20'/hr from 10000' 1.5/3300/50R. Drill to 10010'. Unable to make any footage. Samples indicate 70% chert with quantities of pyritc cement. (It doesn't get any worse than this) POOH to check andlor change bit type. Printed: 1m2002 1:47:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/28/2001 12/29/2001 12/30/2001 Date f {' BP EXPLORATION Operations Summary Report F-09 F -09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 09:45 - 10:15 From - To Hours Activity Code NPT 10:15 - 12:15 12:15 -12:30 12:30 - 13:00 13:00 - 13:15 13:15 - 15:30 15:30 -16:30 16:30 - 18:00 18:00 -19:05 19:05 - 21 :00 21:00 - 21:40 21 :40 - 21 :50 21 :50 - 22:20 22:20 - 22:25 22:25 - 22:45 22:45 - 23:00 23:00 - 23:20 23:20 - 00:00 00:00 - 00:15 00:15 - 00:30 00:30 - 02:50 02:50 - 04:20 04:20 - 05:10 05:10 - 06:30 06:30 - 06:45 06:45 - 12:00 12:00 -12:30 12:30 - 14:30 14:30 - 15:30 15:30 -18:00 18:00 - 21:40 21 :40 - 00:00 00:00 - 00:30 00:30 - 00:55 00:55 - 01 :55 01 :55 - 02:10 02:10 - 03:40 03:40 - 04:55 0.50 DRILL 2.00 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 2.25 DRILL 1.00 DRILL 1.50 DRILL 1.08 DRILL 1.92 DRILL 0.67 DRILL 0.17 DRILL 0.50 DRILL 0.08 DRILL 0.33 DRILL 0.25 DRILL 0.33 DRILL 0.67 DRILL 0.25 DRILL 0.25 DRILL 2.33 DRILL 1.50 DRILL 0.83 DRILL 1.33 DRILL 0.25 DRILL 5.25 DRILL 0.50 DRILL 2.00 DRILL 1.00 DRILL 2.50 DRILL 3.67 DRILL 2.33 DRILL 0.50 DRILL 0.42 DRILL 1.00 DRILL 0.25 DRILL 1.50 DRILL 1.25 DRILL P P P P P P P P P P P P N Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 P P P P P P P P N N P P P N N N P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 8 of 11 Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations Remove bit. DPI completely worn out, no cutters left on pilot. MU HCC 2.7 x 3.0 bicenter. RIH with BHA #11. Window smooth. Tag TD, -5' correction, to 10010'. Orient to 60R. Drilling. 1.5/3150fs/60R. Drill to 10020'. Orient to 30R. Drilling. 1.5/3200/30R ROP 40-60 fph. Drill to 10078'. Drill to 10090', ROP dropped to zero. Suspect worn out bit. Samples still showing 70% chert, but with less pyrite. POOH for bit change. Change bit and motor. Bit had one lost cutter on nose and gauged 2.68" with a few worn cutters. Motor felt tight RIH wi BHA #12 (1.5 deg motor and another used STR324) Corr -20' at 9560'. Reboot MWD PC. Log tie-in down from 9540' Corr -1'. 1.4/2900/110L. RIH thru window wlo pump, clean Relog from 9915-35' to get GR that was missed during previous NPT 1.5/3050/17L Precautionary ream to TD and tag at 10089' Orient from 30L to 60R 1.6/3150 Drilling from 10088' wi multiple stalls to 10093' 50' backream Resume drilling wi multiple stalls frustratingly slow to 10100' Drill wi frequent stalls to 10104' At 10104' broke out of hard formation and back to normal penetration rate 1.5/3160/70R 60-1 OO'/hr. Drilled to 10117' and got into hard rock again Drill in and out of stalls from 10117-10151' 1.5/3020/60R Not getting required DLS. Getting 13's, needing 18's. POOH for motor LD drilling BHA Weekly BOPE test. Witnessed by AOGCC Hold PJSM after crew change to review BOP test proc. Continue BOP test. Witnesses by C. Scheve. No failures. PJSM, then MU drilling BHA, 2.1 mtr wi used STR324 bi-cent bit. RIH wi BHA #13. SHT mwd. Continue in hole. Window smooth. Tag up and correct to 10151' (-15' correction). Orient to 30R. Drilling. 1.5/3100/30R. Lots of stalls. Very slow drilling. Drill to 10164'. Drilling 1.7/3250/60R 1 O'lhr and stalls if pushed 10186' 50' wiper (just because), get 1 click. Drilling 1.8/3430/80R. Drill to 10202' Continue slow drilling in 20 API sand 1.5/3050/90R 10205' Orient around and prep to land at 8982' TVD 1.4/2930/60R Attempt to drill and stacking due to TF change. Ream 10150-205' Still stacking and assume dull bit. Drill to 10206' POOH to check bit Change motor, bit, MHA and MWD batteries. Motor ok, bit ok (2-2-1/16), MHA ok Printed: 1/7/2002 1:47:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/30/2001 12/31/2001 .' ( ( Page 9 of 11 BP EXPLORATION Operations Summary Report F-09 F-09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 04:55 - 07:00 From - To Hours Activity Code NPT PROD1 07:00 - 08:45 08:45 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 12:45 12:45 -14:15 14:15 -14:45 14:45 -15:00 15:00 - 15:15 15:15 - 15:30 15:30 -15:45 15:45 -17:15 17:15 - 18:00 18:00 - 18:20 18:20 - 19:15 19:15 -19:30 19:30 -19:45 19:45 - 21:10 21:10-22:10 22:10 - 00:00 00:00 - 00:25 00:25 - 01 :00 01 :00 - 02:50 02:50 - 03:30 03:30 - 03:45 03:45 - 04:10 04:10 - 04:30 04:30 - 05:00 05:00 - 06:20 06:20 - 06:45 06:45 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 -10:30 10:30 - 11 :00 11 :00 - 11 :30 11:30 -12:15 12:15 -14:30 2.08 DRILL 1.75 DRILL 0.25 DRILL 0.50 DRILL 2.50 DRILL 0.75 DRILL 1.50 DRILL 0.50 DRILL 0.25 DRILL 0.25 DRILL 0.25 DRILL 0.25 DRILL 1.50 DRILL 0.75 DRILL 0.33 DRILL 0.92 DRILL 0.25 DRILL 0.25 DRILL 1.42 DRILL 1.00 DRILL 1.83 DRILL 0.42 DRILL 0.58 DRILL 1.83 DRILL 0.67 DRILL 0.25 DRILL 0.42 DRILL 0.33 DRILL 0.50 DRILL 1.33 DRILL 0.42 DRILL 0.25 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.75 DRILL 2.25 DRILL Phase P P PROD1 P P PROD1 PROD1 P PROD1 P PROD1 P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 P P PROD1 PROD1 P P P PROD1 PROD1 PROD1 P PROD1 N N N N N DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 N P PROD1 PROD1 P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 P P P P P N P P P PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations RIH wi BHA #14 (2.1 deg motor, used Hycalog bit). Window smooth. Tag and correct to 10207'. Drilling. 1.5/3200/90R. Drill 60-120 fph, to 10318'. Cross fault (?). Losing 20% of rtns 1.5 in/1.2 out Orient to 70r. Begin displacement to new mud. Drill to 10375'. Inc:88 deg. Landed at 8986' TVD. Rtns healed up to 90%. POOH for lateral drilling assy. Slow down some to complete mud displacement. Hold PJSM. MU lateral assembly with 1.1 deg mtr and new 3.0 Hyc bicenter bit. Hycalog bit pulled had junked pilot hole cutters. RIH wi BHA #15. Log gr tie. -15' correction. RIH to TD. Window smooth. Tag at 10381'. Orient to 20R to begin build out of tar sand to +1-8975'. Drilling. 1.5/2800fs/30r. Frequent stalls. Drill to 10416'. Inc:98 deg. Orient to 170R to drop angle Drilling. 1.5/3000fs/170r. Drilling at 100-150 fph. Drill to 10550' . Short trip to window. Hole smooth. Orient to 90R. Drilling 1 00-150'/hr 1.5/1.4 2550/11 OR Drill to 10611' and stacking 100' wiper. Get back to btm and CTP was 1000 psi higher. Assume motor is chunking stator Wiper to window 1.3/3400 POOH for motor Change bit, motor. Bit was 3-3-1, motor wouldn't turn RIH wi BHA #16 (1.1 deg motor, used HTC bit) Continue RIH wi BHA #16. Tag TD at and corr -19' to 10611' 1.6/2800/110R Orient around Drilling 90-140'/hr to 10650' and start stacking. Drill to 10689' wi same problem Wiper to window Drilling and still stacking. Drill to 10700' Orient to drill on left Drill to 10706' and continue stacking Wiper to window POOH to check BHA Hold PJSM before BHA change. Change motor and bit. Both appear to be ok. MU 1.0 mtr with Hycalog bicenter (rebuild) RIH with BHA #17. Log gr tie-in from 9540'. Correct -24'. RIH to TD. 10706'. Orient to 170R to drop angle. Problem with MWD computer at surface. Correct same. Drilling. 1.6/3100/155r. Drill to 10740'. Orient to 170L Drilling. 1.6/3000/90L. Drill to 10840'. ROP:80-120fph. Printed: 1m2002 1:47:16 PM ^"" ff , .,- ( Page 1 0 of 11 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-09 F-09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 12/31/2001 1/1/2002 1/2/2002 From - To Hours Activity Code NPT 14:30 -15:45 15:45 - 16:30 16:30 -17:00 17:00 -18:50 18:50 -19:30 19:30 - 20:30 20:30 - 21 :50 21 :50 - 22:40 22:40 - 00:00 00:00 - 00:15 00:15 - 04:45 04:45 - 05:30 05:30 - 07:15 07:15 - 08:30 08:30 - 09:45 09:45 - 10:30 10:30 - 10:45 10:45 - 12:00 12:00 -13:30 13:30 - 13:45 13:45 - 14:00 14:00 - 16:20 16:20 - 17:30 17:30 - 18:15 18:15 - 20:00 20:00 - 20:30 20:30 - 20:45 20:45 - 22:00 22:00 - 22:15 22:15 - 22:30 22:30 - 23:30 23:30 - 23:50 23:50 - 00:00 00:00 - 01 :20 1.25 DRILL 0.75 DRILL 0.50 DRILL 1.83 DRILL 0.67 DRILL 1.00 DRILL 1.33 DRILL 0.83 DRILL 1.33 CASE 0.25 CASE 4.50 CASE 0.75 CASE 1.75 CASE 1.25 CASE 1.25 CASE 0.75 CASE 0.25 CASE 1.25 CASE 1.50 CASE 0.25 CASE 0.25 CASE 2.33 CASE 1.17 CASE 0.75 CASE 1.75 CASE 0.50 CASE 0.25 CASE 1.25 CASE 0.25 EVAL 0.25 EVAL 1.00 EVAL 0.33 EVAL 0.17 EVAL 1.33 EVAL P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations Wiper trip to window. Hole smooth. Drilling to 10973'. Try to orient to HS. Unable to hold TF, orienter apparently "free wheeling" Call TD here-will get corr TD on tie-in when POOH for liner Conditioning trip to window, back to TD. Tag at 10971' Wiper to window Log tie-in down from 9520' Add 10.0'. Corrected TD is 10981'. Paint EOP flag at 8600' POOH for liner LD drilling BHA RU to run liner. RD MWD tools on catwalk. Load Baker tools in pipeshed. MU drift assy Safety mtg re: liner/drift/well control MU 68 jts 2-3/8" 4.7# L-80 R-2 STL liner w/ float equipment, turbos and pup. Drift each connection w/1.85" drift. Phz 1 MU Baker CTLRT. Set 2-3/8" combis. Install LWP assy RIH w/liner on CT. Phz 2. Tag TD at 10981'. PU wt 28.6k#. Drop .625" ball. Displace with flopro. On seat at 31 bbls. Pressure to 3900 psi to shear from LBRT. PU wt after release: 18k#. Displace well to slick kcl water. 2.2 bpm/2900 psi. 15% losses. Slow rate to 1.0 bpm/550 psi. Batch mix 13+ bbls class g latex, 15.8 cement. Phz 0 Hold PJSM regarding cement job details & safety items. Pump 3 bbls water. Test lines to 4000 psi. Pump 13 bbls cement into coil. Shut down & clean up lines. Launch dart & verify same. Dispalce with rig using kcl water. 2.0 in/1.5 out rate with cement around backside. Estimate lost 3 bbls to formation. Plug bumped at 47.3 bbls (expected 48.5) Floats Held. Unsting with 21k# up wt. CIP at 12:00 noon. Circulate DOH. Full rtns. No cement to surface. LD Baker LBRT tools. All tools recovered. Hold PJSM before PU clean assy and CSH pipe. MU 1-11/16 Baker motor assy on 76 jts CSH. RIH w/ CT RIH thru TOL at 8758', clean. Start motor and precautionary ream to PBD 1.0/1975 Tag PBD twice at 10924' (should be at 10946', but will verify w/ CNL). POOH Tag up at surface, stand back injector. Safety meeting prior to pulling CS hydrill work string. Discuss dropping ball (1/2") if neccessary to open circ sub. Since KCL in hole, will try pulling first prior to dropping ball. Pull CS hydril work string. Pulling dry, did not drop ball for circ sub. Safety meeting prior to picking up SWS CNIL Radioactive logging tool. MU SWS CNL-GR-CCL tool. Trip in hole with 1" CS hydril work string. MU MHA and CT injector. RIH with CNL logging BHA. RIH with CNL logging BHA. Printed: 1/7/2002 1:47:16PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~" t \, BP EXPLORATION Operations Summary Report F-09 F-09A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 1/2/2002 01 :20 - 02:30 From - To Hours Activity Code NPT 02:30 - 04:00 04:00 - 04:50 04:50 - 05:10 05:10 - 05:25 05:25 - 06:00 06:00 - 06:30 06:30 - 07:10 07:10 - 07:45 07:45 - 08:30 08:30 - 08:45 08:45 - 09:15 09:15 -10:30 10:30 -12:15 12:15 -12:40 12:40 - 13:45 13:45 - 14:00 14:00 -15:20 15:20 -16:50 16:50 - 17:05 17:05 -18:30 18:30 - 19:35 19:35 - 20:30 20:30 - 21:10 21:10 - 23:45 23:45 - 00:00 1.17 EVAL 1.50 EVAL 0.83 EVAL 0.33 EVAL 0.25 EVAL 0.58 EVAL 0.50 EVAL 0.67 EVAL 0.58 PERF 0.75 CASE 0.25 PERF 0.50 PERF 1.25 PERF 1.75 PERF 0.42 PERF 1.08 PERF 0.25 PERF 1.33 PERF 1.50 PERF 0.25 PERF 1.42 PERF 1.08 RIGD 0.92 RIGD 0.67 RIGD 2.58 RIGD 0.25 RIGD P P P P P P P P P P P P P P P P N Phase COMP CaMP CaMP CaMP CaMP CaMP COMP COMP CaMP CaMP CaMP CaMP CaMP COMP CaMP DFAL CaMP CaMP P P P P P P P P P CaMP CaMP CaMP COMP CaMP CaMP CaMP CaMP COMP Page 11 of 11 Start: 12/21/2001 Rig Release: 1/2/2002 Rig Number: Spud Date: 12/21/2001 End: 1/2/2002 Description of Operations 8600', log down at 30 fpm. Pump 20 bbls of hi vis pill to lay in while logging up. Tag TD at 10923' CTM. Same depth as on motor run. Log up at 30 fpm. Laying in Hi vis flo pro mud on way up. 8600', Logging completed. POOH with coil. Tag up at top of CSH. Stand back injector. Safety meeting prior to pulling CSH. Pull CSH Shut down for crew tour change. PJSM on pulling CSH and source Fin POOH wi CSH Load perf guns in pipe shed while download CNL data Install tree cap. PT liner lap wi 2000 psi for 30 min. Lost 120 psi in 30 min. No change to IA. Cmt comp str = 2400 psi+ CNL found PBD at 10945', TOL @ 8753' ref BHCS. Fax log Safety mtg re: perf guns MU perf guns MU 33 stds CSH RIH wi CT Tag at 10930' CTD, corr 10945'. PUH and pump 15 bbls 150k cp mud. Position guns to shoot Load 1/2" ball and displace wi KCI1.3/3800. No press response after 50 bbls Load second 1/2" ball and displace wi KCI1.3/3200. After 8 bbls pumped lost 100 psi, gained 4k string wt and losing 0.1 bpm-assume guns shot wi first ball. Pump second ball over gooseneck Perforated 10380-10620' wi SWS 1-11/16" Powerjets at 4 spf POOH filling from BS Standback CSH Safety mtg re: perf gun handling LD perf guns-all shots fired. Recovered both balls. Load out perf guns RIH wi nozzle assy to FP well. Lay in neat methanol from 2500' to surface. Tag back up at surface. SI well, stand back injector. Safety meeting prior to nippling down stack. Change out 2-3/8" combi rams for VBR's. Nipple down stack, NU swab cap flange, PT same. Rig released at 23:45, 1/2/2002, as per new contract. Continue RD and move to J-17. ,,- ..-- Printed: 1/7/2002 1 :47: 16 PM ObP ( BP Amoco (' Baker Hughes INTEQ Survey Report IB¡¡8 BAIŒR HUGIll S --------- lNTEQ -------------- ---------,--- ----- .., -----. -- --u_- -..--------_u_--. -------- -- -- n_____-------._-._------_u_-------,-.- n ____n____'_--------- -------------.'--'---------.-...-_u_--- ---.--------- Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-09 Wellpath: F-09A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Field: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5972527.29 ft 650960.70 ft Well: F-09 F-09 ~ Well Position: +N/-S 1784.41 ft Northing: 5974332.00 ft +E/-W 1033.49 ft Easting: 651958.00 ft Position Uncertainty: 0.00 ft Wellpath: F-09A 500292040301 Current Datum: 9 : 09 11/15/1979 00:00 Magnetic Data: 2/5/2002 Field Strength: 57499 nT Vertical Section: Depth From (TVD) ft --- ------..--------.-.-- ---.-----.- H__--___--. -.--- ---- ---- 0.00 Survey: Company: Tool: ------,-------_..- --- Height 67.30 ft Date: 2/5/2002 Time: 14:58:40 Page: 1 Co-ordinate(NE) Reference: Well: F-09, True North Vertical (TVD) Reference: 9: 0911/15/197900:0067.3 Section (VS) Reference: Well (0.00N.0.00E,45.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2001 +N/-S ft 0.00 -----.-----. -- ------------u_---------------------------------------------, - Latitude: 70 19 55.283 N Longitude: 148 46 31.468 W North Reference: True Grid Convergence: 1.15 deg Slot Name: 09 Latitude: Longitude: 70 20 12.832 N 148 46 1.285 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft ---.------- ----- 0.00 F-09 9823.00 ft Mean Sea level 26.41 deg 80.81 deg Direction deg - - --- __on' .--------- --- 45.00 Start Date: Engineer: Tied-to: Annotation ~1¡g~~- ~~~=-==-~~~--=~--= -=:===:=~.-===_..:.~.. =--J Survey MD ft 31.80 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 I~~ --~JD -~f>_~: ~~= M~N ~PE ~~ ~J 0.00 0.00 31.80 -35.50 0.00 0.00 5974332.00 651958.00 0.00 0.00 0.02 151.00 100.00 32.70 -0.01 0.01 5974331.99 651958.01 0.03 0.00 0.30 251.19 200.00 132.70 -0.11 -0.23 5974331.89 651957.77 0.30 -0.24 0.42 219.19 300.00 232.70 -0.48 -0.71 5974331.51 651957.30 0.23 -0.84 0.73 221.50 399.99 332.69 -1.24 -1.37 5974330.73 651956.66 0.31 -1.84 0.93 214.29 499.98 432.68 -2.39 -2.25 5974329.57 651955.80 0.23 -3.28 1.25 194.29 599.96 532.66 -4.11 -2.97 5974327.83 651955.11 0.49 -5.01 1.32 186.19 699.94 632.64 -6.32 -3.37 5974325.62 651954.76 0.19 -6.85 1.20 188.50 799.91 732.61 -8.50 -3.64 5974323.43 651954.53 0.13 -8.59 0.90 189.60 899.90 832.60 -10.31 -3.93 5974321.62 651954.28 0.30 -10.07 0.60 179.20 999.89 932.59 -11.61 -4.05 5974320.32 651954.18 0.33 -11.07 0.10 102.31 1099.89 1032.59 -12.15 -3.96 5974319.78 651954.28 0.59 -11.39 0.50 49.29 1199.89 1132.59 -11 .88 -3.55 5974320.05 651954.70 0.45 -10.91 0.62 32.50 1299.88 1232.58 -11.14 -2.92 5974320.80 651955.30 0.20 -9.95 0.52 35.20 1399.88 1332.58 -10.31 -2.37 5974321.64 651955.84 0.10 -8.97 0.27 47.00 1499.87 1432.57 -9.78 -1.94 5974322.18 651956.26 0.26 -8.29 0.20 143.20 1599.87 1532.57 -9.76 -1.66 5974322.21 651956.54 0.35 -8.08 0.62 155.31 1699.87 1632.57 -10.39 -1.33 5974321.58 651956.88 0.43 -8.29 ObP ( BP Amoco f Baker Hughes INTEQ Survey Report BíI. BAKER MU&HlS ------------- tNTEQ ------------ -- ---------.------------------, ---'-'-'------ "'---______n______----- -- - -- ,,--,-,-,-, '.--'--------', ,---,~-- --'---------'--'-'-----'-------'--'--'---- ,- Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-09 Wellpath: F-09A Survey - - -------- Date: 2/5/2002 Time: 14:58:40 Page: 2 Co-ordinate(NE) Reference: Well: F-09, True North Vertical (fVD) Reference: 9 : 09 11/15/1979 00:00 67.3 Section (VS) Reference: Well (0.00N,O.00E,45.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle -------------,----------------------.------------ -------,---------~- ---------_u_---- -------------- ---------------- ----- -------'------'-'---'-'. VS ft MD ft 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 5950.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 Incl deg 0.70 0.75 1.10 2.27 2.72 2.78 2.73 2.45 2.30 2.20 3.12 5.43 8.82 9.38 10.97 12.72 14.43 16.28 18.45 20.95 23.53 25.10 27.80 29.43 30.45 30.62 30.57 31.15 31.87 32.32 32.32 32.90 33.33 33.07 33.47 33.88 34.77 35.70 36.00 36.07 36.30 36.32 34.33 31.95 30.32 31.57 32.83 33.77 33.93 34.13 34.28 34.87 Azim deg 153.81 142.20 85.40 58.29 62.50 70.19 91.31 116.31 152.40 156.40 218.39 222.19 230.00 232.79 232.60 230.60 230.89 232.19 232.39 231.79 232.10 232.29 233.10 233.69 234.29 234.69 235.00 236.29 238.00 238.10 238.69 241.00 242.00 242.19 242.89 244.29 245.69 248.19 249.39 250.69 251.00 251.79 248.79 244.10 235.39 234.60 234.89 234.69 234.50 235.00 235.69 236.19 TVD SSTVD ft ft 1799.86 1732.56 1899.86 1832.56 1999.84 2099.80 2199.71 2299.59 2399.48 2499.38 2599.30 2699.22 2799.13 2898.85 2998.06 3096.80 3195.23 3293.09 3390.30 3486.72 3582.16 3676.30 3768.85 3859.98 3949.50 4037.29 4123.94 4210.07 4296.15 4381.99 4467.25 4551.97 4636.48 4720.71 4804.47 4888.15 4971.76 5054.98 5137.56 5219.25 5300.30 5381.17 5461.88 5542.46 5583.26 5625.13 5710.77 5796.53 5881.15 5964.73 6047.78 6130.65 6213.36 6295.70 1932.54 2032.50 2132.41 2232.29 2332.18 2432.08 2532.00 2631.92 2731.83 2831.55 2930.76 3029.50 3127.93 3225.79 3323.00 3419.42 3514.86 3609.00 3701.55 3792.68 3882.20 3969.99 4056.64 4142.77 4228.85 4314.69 4399.95 4484.67 4569.18 4653.41 4737.17 4820.85 4904.46 4987.68 5070.26 5151.95 5233.00 5313.87 5394.58 5475.16 5515.96 5557.83 5643.47 5729.23 5813.85 5897.43 5980.48 6063.35 6146.06 6228.40 N/S ft -11.43 -12.50 -12.94 -11.82 -9.68 -7.77 -7.00 -8.00 -10.73 -14.26 -18.16 -23.80 -32.23 -42.09 -52.80 -65.56 -80.41 -96.87 -115.12 -135.84 -159.16 -184.40 -211.38 -239.93 -269.27 -298.78 -328.08 -357.02 -385.37 -413.49 -441.50 -468.56 -494.63 -520.26 -545.55 -570.21 -594.04 -616.62 -637.81 -657.89 -677.26 -696.15 - 705.88 -716.76 -742.67 -772.17 -802.93 -834.59 -866.86 -899.15 -931.12 -962.90 E/W ft -0.84 -0.16 1.19 3.84 7.62 12.01 16.67 20.97 23.82 25.51 24.59 19.72 10.67 -1.69 -15.74 -31.81 -49.99 -70.73 -94.34 -120.93 -150.73 -183.27 -218.70 -257.15 -297.52 -338.88 -380.49 -422.84 -466.74 -511.83 -557.36 -603.96 -651.97 -700.36 -749.03 -798.69 -849.80 -902.87 -957.47 -1012.76 -1068.53 -1124.65 -1151.87 -1176.92 -1221.52 -1263.64 -1307.15 -1352.01 -1397.41 -1443.11 -1489.35 -1536.37 MapN ft 5974320.55 5974319.50 5974319.09 5974320.26 5974322.47 5974324.48 5974325.34 5974324.43 5974321.76 5974318.26 5974314.35 5974308.61 5974299.99 5974289.89 5974278.90 5974265.81 5974250.60 5974233.73 5974215.00 5974193.75 5974169.83 5974143.94 5974116.25 5974086.93 5974056.78 5974026.44 5973996.30 5973966.51 5973937.28 5973908.26 5973879.33 5973851.33 5973824.30 5973797.70 5973771.42 5973745.77 5973720.91 5973697.26 5973674.97 5973653.78 5973633.28 5973613.26 5973602.98 5973591.59 5973564.78 5973534.44 5973502.81 5973470.25 5973437.07 5973403.86 5973370.96 5973338.24 MapE DLS ft deg/10OO 651957.40 0.08 651958.09 0.15 651959.45 651962.07 651965.82 651970.16 651974.81 651979.13 651982.03 651983.80 651982.95 651978.20 651969.32 651957.16 651943.33 651927.53 651909.66 651889.25 651866.02 651839.86 651810.53 651778.52 651743.64 651705.78 651666.02 651625.27 651584.26 651542.51 651499.20 651454.69 651409.74 651363.71 651316.24 651268.38 651220.23 651171.08 651120.48 651067.87 651013.72 650958.85 650903.49 650847.77 650820.76 650795.93 650751.87 650710.36 650667.48 650623.28 650578.55 650533.51 650487.93 650441.57 -8.67 -8.95 0.93 1.38 0.49 0.37 1.01 .8.30 -5.65 -1 .46 3.00 6.84 1.15 1.48 0.19 2.85 2.33 9.17 9.26 7.96 4.55 -2.88 3.52 0.71 1.59 1.80 1.71 -15.25 -30.96 -48.46 -68.85 -92.21 1.88 2.17 2.51 2.58 1.57 -118.51 -148.11 -181.56 -219.13 -259.98 2.72 1.65 1.06 0.26 0.17 -304.11 -351.49 -400.78 -450.89 -501.04 0.88 1.15 0.45 0.32 1.37 -551.45 -602.53 -654.29 -706.30 -758.39 0.70 0.28 0.55 0.88 1.19 -810.77 -863.10 -915.41 -967.96 -1020.95 1.72 0.76 0.77 0.29 0.47 -1074.44 -1128.03 -1181.33 -1234.46 -1287.50 5.28 6.99 4.79 1.31 1.27 -1313.63 -1339.04 -1388.89 -1439.54 -1492.05 0.95 0.19 0.34 0.42 0.65 -1546.15 -1601.08 -1656.23 -1711.53 -1767.25 ObP ( BP Amoco :( II.. BAKER HUGl8S Baker Hughes INTEQ Survey Report -----..---...----.-.-..--- INTEQ .- - ._- _"-n___--"""""""-",-, Company: BP Amoco Date: 2/5/2002 Time: 14:58:40 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: F-09, True North Site: PB F Pad Vertical (fVD) Reference: 9: 09 11/15/197900:0067.3 Well: F-09 Section (VS) Reference: Well (0.00N,O.00E,45.00Azi) Wellpath: F-09A Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~'.'----'----'-'._----~----"--"'-'---'-"-'---"'--"---'-"-"'-',,--~-------- -- -.-----..- """"----'-"'--'----,--,-"------,---,--",--,,, .--......._-. ...-- '-----'--'-"'-'---- -.. MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/10OO ft --" -..." --" --no .. ... .. - -- 0-""--- -.. 6900.00 35.28 236.50 6377 .54 6310.24 -994.75 -1584.20 5973305.43 650394.40 0.45 -1823.59 7000.00 35.78 237.10 6458.92 6391.62 -1026.56 -1632.83 5973272.64 650346.43 0.61 -1880.47 7100.00 35.95 236.60 6539.96 6472.66 -1058.60 -1681.88 5973239.61 650298.04 0.34 -1937.81 7200.00 36.02 236.29 6620.87 6553.57 -1091.08 -1730.84 5973206.15 650249.75 0.20 -1995.40 7300.00 36.32 235.69 6701.60 6634.30 -1124.09 -1779.76 5973172.16 650201.51 0.46 -2053.34 7400.00 36.67 235.60 6781.99 6714.69 -1157.65 -1828.86 5973137.61 650153.10 0.35 -2111.79 7500.00 37.07 235.89 6861.99 6794.69 -1191.43 -1878.46 5973102.84 650104.21 0.44 -2170.74 7600.00 37.27 235.89 6941.68 6874.38 -1225.31 -1928.48 5973067.96 650054.88 0.20 -2230.07 7700.00 36.77 236.60 7021.52 6954.22 -1258.76 -1978.54 5973033.50 650005.52 0.66 -2289.12 7800.00 36.80 236.10 7101.61 7034.31 -1291.95 -2028.39 5972999.32 649956.36 0.30 -2347.83 7900.00 36.70 235.60 7181.73 7114.43 -1325.53 -2077.90 5972964.73 649907.54 0.32 -2406.59 8000.00 36.37 235.50 7262.08 7194.78 -1359.21 -2126.99 5972930.07 649859.14 0.34 -2465.12 8100.00 36.95 235.50 7342.30 7275.00 -1393.03 -2176.20 5972895.27 649810.64 0.58 -2523.82 8200.00 37.78 235.60 7421.78 7354.48 -1427.36 -2226.24 5972859.93 649761.30 0.83 -2583.48 8300.00 38.58 235.79 7500.39 7433.09 -1462.19 -2277.30 5972824.07 649710.96 0.81 -2644.22 8400.00 37.43 235.39 7579.18 7511.88 -1496.99 -2328.10 5972788.26 649660.88 1.18 -2704.75 8500.00 36.62 234.69 7659.02 7591.72 -1531.49 -2377.45 5972752.77 649612.24 0.91 -2764.04 8600.00 36.00 235.39 7739.60 7672.30 -1565.42 -2425.98 5972717.86 649564.41 0.75 -2822.35 8700.00 34.82 236.10 7821.10 7753.80 -1598.04 -2473.87 5972684.28 649517.20 1.25 -2879.27 8800.00 33.45 237.79 7903.87 7836.57 -1628.65 -2520.89 5972652.72 649470.82 1.67 -2934.17 8900.00 31.77 240.50 7988.11 7920.81 -1656.31 -2567.13 5972624.14 649425.15 2.23 -2986.42 9000.00 30.65 241.50 8073.64 8006.34 -1681.44 -2612.44 5972598.10 649380.36 1.23 -3036.23 9100.00 29.00 244.00 8160.39 8093.09 -1704.23 -2656.63 5972574.42 649336.64 2.07 -3083.59 9200.00 26.25 247.69 8248.99 8181.69 -1723.25 -2698.89 5972554.54 649294.78 3.24 -3126.93 9300.00 22.93 249.50 8339.91 8272.61 -1738.48 -2737.61 5972538.54 649256.38 3.40 -3165.07 9400.00 20.67 257.89 8432.78 8365.48 -1749.00 -2773.12 5972527.29 649221.09 3.84 -3197.63 9500.00 20.47 262.60 8526.41 8459.11 -1754.96 -2807.72 5972520.64 649186.62 1.67 -3226.30 9600.00 19.87 260.89 8620.27 8552.97 -1759.90 -2841.84 5972515.01 649152.61 0.84 -3253.93 9700.00 19.20 262.29 8714.52 8647.22 -1764.80 -2874.92 5972509.44 649119.64 0.82 -3280.78 9800.00 18.27 263.50 8809.22 8741.92 -1768.78 -2906.79 5972504.82 649087.86 1.01 -3306.13 9823.00 18.12 263.75 8831.07 8763.77 -1769.58 -2913.93 5972503.87 649080.74 0.72 -3311.74 9858.28 30.76 286.50 8863.19 8795.89 -1767.60 -2928.12 5972505.56 649066.51 44.08 -3320.38 9889.06 35.33 306.30 8889.06 8821.76 -1760.07 -2942.89 5972512.79 649051.59 37.91 -3325.49 9929.52 40.43 319.66 8921.04 8853.74 -1743.11 -2960.85 5972529.39 649033.29 23.82 -3326.20 9964.79 46.76 327.05 8946.59 8879.29 -1723.57 -2975.27 5972548.62 649018.49 23.02 -3322.58 9994.11 50.27 330.56 8966.01 8898.71 -1704.79 -2986.62 5972567.17 649006.75 14.95 -3317.33 10025.41 54.93 336.19 8985.02 8917.72 -1682.56 -2997.72 5972589.17 648995.21 20.63 -3309.46 10054.62 60.38 341.11 9000.65 8933.35 -1659.59 -3006.67 5972611.96 648985.80 23.46 -3299.54 10096.63 67.68 349.90 9019.07 8951.77 -1623.07 -3016.02 5972648.27 648975.71 25.59 -3280.33 10127.08 70.84 352.71 9029.85 8962.55 -1594.93 -3020.31 5972676.32 648970.85 13.50 -3263.47 10157.63 76.99 356.93 9038.31 8971.01 -1565.71 -3022.94 5972705.47 648967.62 24.11 -3244.67 10186.97 82.97 4.66 9043.42 8976.12 -1536.86 -3022.53 5972734.32 648967.46 32.98 -3223.97 10222.05 85.25 13.10 9047.03 8979.73 -1502.42 -3017.14 5972768.87 648972.15 24.80 -3195.81 10285.22 87.63 31.38 9050.98 8983.68 -1444.32 -2993.37 5972827.43 648994.73 29.12 -3137.92 10318.02 86.22 40.17 9052.75 8985.45 -1417.77 -2974.24 5972854.36 649013.32 27.10 -3105.62 10382.38 97.73 58.10 9050.51 8983.21 -1375.90 -2925.90 5972897.19 649060.80 33.05 -3041.83 10416.03 98.53 58.80 9045.76 8978.46 -1358.4 7 -2897.51 5972915.20 649088.82 3.15 -3009.44 10451.35 95.45 58.80 9041.46 8974.16 -1340.31 -2867.53 5972933.96 649118.43 8.72 -2975.39 10484.83 91.67 59.86 9039.38 8972.08 -1323.27 -2838.79 5972951.57 649146.81 11.72 -2943.03 10523.88 87.19 64.43 9039.77 8972.47 -1305.04 -2804.29 5972970.50 649180.94 16.39 -2905.73 10559.53 85.87 66.54 9041.93 8974.63 -1290.27 -2771.91 5972985.92 649213.00 6.97 -2872.40 10586.95 86.13 69.35 9043.84 8976.54 -1280.00 -2746.56 5972996.70 649238.14 10.27 -2847.21 10624.00 90.88 74.62 9044.81 8977.51 -1268.56 -2711.36 5973008.86 649273.10 19.14 -2814.23 . .....-...-....". -..-...".. m --....m....._..... --".. . ----_.- --0 - . --..---.".-...-. - -- . ....-- - ...-.. --.... ... . ObP ( BP Amoco { Baker Hughes INTEQ Survey Report Bíl8 BAlŒR NUGHI S --------------- l~TEQ ----- ---- - -- --- - ----- Company: BP Amoco Field: Prudhoe Bay Site: PB F Pad Well: F-09 Wellpath: F-09A Date: 2/5/2002 Time: 14:58:40 Page: 4 Co-ordinate(NE) Reference: Well: F-09, True North Vertical (fVD) Reference: 9: 09 11/15/197900:0067.3 Section (VS) Reference: Well (0.00N,O.00E,45.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey ------------ ----- --------_u_---------- --- -----._-- - - ---- --- ----------- ----- ---------------- -- - ------- - -- ---- -------------------------- - --- -- u- -------- ----------------u_----- MD Incl Azim TVD SSTVD N/S EIW MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/10OO ft - - - -- ____un -- - -- ---- - -- - - ------- 10660.70 93.08 79.19 9043.54 8976.24 -1260.25 -2675.65 5973017.89 649308.63 13.81 -2783.10 10691.96 93.69 83.41 9041.69 8974.39 -1255.53 -2644.81 5973023.23 649339.36 13.62 -2757.96 10725.84 88.42 84.12 9041.07 8973.77 -1251.85 -2611.15 5973027.59 649372.94 15.70 -2731.56 10757.79 84.73 87.63 9042.98 8975.68 -1249.56 -2579.35 5973030.53 649404.69 15.92 -2707.45 10799.66 84.64 86.23 9046.86 8979.56 -1247.33 -2537.72 5973033.60 649446.26 3.34 -2676.43 10847.31 88.15 83.41 9049.85 8982.55 -1243.03 -2490.37 5973038.86 649493.51 9.44 -2639.92 10878.11 86.75 80.51 9051.22 8983.92 -1238.73 -2459.91 5973043.77 649523.88 10.45 -2615.33 10913.84 86.31 79.55 9053.38 8986.08 -1232.55 -2424.79 5973050.66 649558.87 2.95 -2586.13 10942.34 87.80 79.90 9054.85 8987.55 -1227.48 -2396.78 5973056.30 649586.76 5.37 -2562.74 10981.00 87.80 79.90 9056.33 8989.03 -1220.70 -2358.75 5973063.84 649624.64 0.00 -2531.05 T l LEGEND F-09,F-Q9A,Plan #4 F-09 (F-Q9) - F-Q9A Wellpath: (F-O9/F-09A) Created By: Brij Potnis Date: 215/2002 Azimuths to True North Magnetic North: 26.41' Magnetic Field Strength: 57499nT Dip Angle: 80.81' Date: 2/5/2002 Model: BGGM2001 BP Amoco ~ « , , , , , , , ~ , ""-"-~:: ObP Conl~cl 1f1lnf1n~t'nn WEllPATH DETAILS F-09A 500292040301 Drr.'ct I'IDII ),,/-I;;;n l-rn",1 hrr Im!",,:'!-,nl',') corn [1~~c,r H",¡lps INTH) ".I)/} )ii/ hi,r)() INTEQ ---- Parent Wellpath: Tie on MD: F-O9 9823.00 -950- Rig: Ref. Datum: Nordic 1 9: 0911/15/197900:00 57.3Oft ,£-O9.f:(19À,Plan #4: V.Section Angle 45.00' Starting From TVD Origin +N/-S 0.00 Origin +E}-W -1000 0.00 0.00 -1050 REFERENCE INFORMATION -1100 Co-ordinate (N/E) Reference: Well Centre: F.09, True North Vertical (NO) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 09 (O.OON,O.ooE) Measured Depth Reference: 9: 0911/15/197900:00 67.30 Calculation Method: Minimum Curvature -1150 _-1200 C .- - = -1250 Q !!!.-1300 TARGÐŒT"'--S ----- /- /// / // -,-/'~--------/,-/" - /,./ , /' ANNOTATIONS ..--..'" "" "'-5 .EJ,W ,""po N=,. TVD MD Annotation F_T31 "'"'00 -102205 ...."", -.. F- 132 ...,00 -1""02 .2750'" -.. F_133 ....00 -103"0 -236"8 _0 F_F..." 000 -145<" -261300 """"" F_F,U<) 000 -88'" -220148 Pd- F_F""" 000 -100129 -253385 """"" F__' 000 -13"" -300523 ""-' F-09A- 8763-77 9823-00 KOP 8989.03 10981_00 TO -TO - .:!:..-1350 .c 1:: 0 -1400 Z ::::::-"-1450 . - .c .. .1500 ~ 0 U) -1550 , ;' (/ , I / I ,/ \ I' // \ / \ \ ~ ,1 / \', // \ \ \ " \ \ \~':.. KOP, """ , ' --~- / 'KOPi (/ \\ \\ ", \ \~~ F-09A:, 8450 8500 -1600 8550 -1650 8600 -1700 ê8650 ~ .. Õ8700 an -a750 .c .. ~800 Q _8850 ns U '-8900 1:: ~8950 at ~9000 .. ... 9050 r F-Q9 (F-Q9)j -1750 -1800 -'- -3350-3300-3250-3200-3150-3100.3050-3OO0.2950.2900-2850~800-2750.2700-2650.2600-2550.2500.2450.2400.2350.2300-2250-2200.2150.2100-2050 West(-)/East(+) [50ft/in] ,TD, F-09,F-Q9A,Plan #4 9100 9150 '-F~~(E.-QN< 9200 -'------ - -3650.3600.3550.3500.3450.3400.3350-3300-3250-3200-3150-3100-3050-3000-2950-2900-2850-28oo-2750-2700.2650-2600~550.2500-2450-2400-2350-2300-2250.2200.2150.2100.2050.2000.1950.1900.1850.1800.1750-1700 Vertical Section at 45.000 [50ft/in] 2/5/2002 3:01 PM 02/12/02 ScblllDbepgep NO. 1804 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay c""- Well Job# Log Description Date Blueline Sepia Color Prints CD .~- F-09A rl() 1-' ~ \Ç 22015 MCNL 01/02102 1 1 1 D.S. 7-14A I CjS{... 07 d. 22034 MCNUBORAX 12122101 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECE\VED FEB 1 9 2.002 A\aSÌ8 O" & Gas eons. ~ An~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received ~~'-~ ./ Date Delivered: , ~1f~1fŒ (ill~ fÆ~fA\~[K{!Æ ALAS IiA. 0 IL AND GAS CONSERVAnONCO~SSION { / / / / / TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit F-09A BP Exploration Alaska, Inc. Permit No: 201-198 Sur Loc: 2467' SNL, 2405' EWL, Sec. 02, T11N, R13E, UM Btmhole Loc. 3496' SNL, 42' EWL, Sec. 02, TI1N, R13E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit F-09A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, b~ ~Ur Cammy chsli Taylo Chair BY ORDER OF THE COMMISSION DATED this 5th day of October, 2001 jj clEnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. \" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill III Redrill 0 Re-Entry 0 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 2467' SNL, 2405' EWL, SEC. 02, T11 N, R13E, UM At top of productive interval 4227' SNL, 436' WEL, SEC. 03, T11 N, R13E, UM At total depth 3496' SNL, 42' EWL, SEC. 02, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028281, 42' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9905' MD Maximum Hole Angle 18. casi~P7~rogram Specifications HnlA r.~~inn Weiaht Grade Couolinn Lenath 311 2-3/811 4.6# L-80 ST-L 2320' 1 b. Type of well 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10300 feet 9288 feet 10235 feet 9225 feet Length Size 110' 2700' 9390' 2011 X 3011 13-3/811 9-5/811 1393' 711 Perforation depth: measured 20. Attachments jt'\ ¿'{ v' )ùj/.(/Oi ft\°l-~ bC75' , jD/ð)/O I 0 Exploratory 0 ~tratigraphic Test III Development Oil 0 Service 0 Development Gas GYSingl~ff>ne 0 Multiple Zone 5. Datum Elevation (DF or KB) 1 O. Field and Pool KBE = 51.43' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool f.) zS 2f/ I ~ ADL 028280 ..s D 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number "-":"; 'I" ,"", ',~ be 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 9. Approximate spud date :ji~I.lfll Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11070' MD /8984' TVDss 0 17. Anticipated pr~,20 AAC 25.035 (e) (2)} 92 Maximum surfa~ At total depth (TVD) 8800' / 3200 psig Setting Depth- Too DUI lJl Owmtitv nf r'om~ nt MD TVD MD TVD finclude stane data) 8750' 7862' 11070' 8984' 95 cu ft Class 'G' Plugs (measured) ii:~'~:,;:<,il:',""~["\>I/""'"!,1\', "",',.-"""", lí Îk tL""" \i;,.,ß::,:.:: Ii '1uf ¡¡;""" Ii S[p 2 1;( 2001 Alaska Oil ¿k Ga'è ", i ,- "", e' , '" C)lh LUlllilll1 "Ç'l(í"~ , ,,)", I, Perf Gun Fish at 1 0162' (09/89) l\nchorage " Junk (measured) Cemented 7.9 cu yds Permafrost 4269 cu ft Arcticset 1230 cu ft Class 'G', 130 cu ft AS 391 cu ft Class 'G' ADDroved Bv Form 10-401 Rev. 12-01-85 Original Signed By Cammy Oechsli A_.. Commissioner 0 K I {j \ 1"J A L by order of the commission Open: 9880' - 9888" 9985' - 9995', 10060' - 10070' Sqzd: 9904' - 9924" 9934' - 9952', 9963' - 9985', 9995' - 9996', 10006' - 10050' true vertical Open: 8885' - 8893', 8986' - 8995" 9057' - 9067' Sqzd: 8908' - 8927', 8937' - 8954', 8964' - 8986', 8995' - 8996', 9006' - 9048' III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregc.¡ljng . ue and correct to the best of my knowledge / Signed Dan Kara ~. Title CT Drilling Engineer Date q lc..{o' " ¡ ';,"'," ':',: ,.:.::,.,:":,;;,::::",,,,;:;(,;':,¡:;:::;,;<;:;:;',' ,':::,':',';,::::,':,Cømril,i:St\liqiiU.ë::Q,ï1'ly'::;:,';'".:::~I,:, :,),;:: ;i:'¡:::::,':),,':':', ,..::";::::",:;::::: ;, ,>": ;,"" , , Permit Number J Q¿"/ API Number & /.1 ~ate See cover letter :2.D - I (Ã 50- 029-20403-01 10:, rn I for other reQuirements Conditions of Approval: Samples Required 0 Yes I8J No Mud Lbg Required 0 Yes fiL No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required IE Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU Other: Date t J{Í(j südmrl/n Tri~ licate MD TVD 110' 2700' 9390' 110' 2699' 8423' 8899' - 1 0292' 7987' - 9280' ( ( BPX Prudhoe Bay Producer F-O9A CTD Sidetrack Summary of Operations: F-09 is being sidetracked to improve recovery of lower Zone 2/upper Zone 1 reserves. This sidetrack will be conducted in two phases. if. ~'iiD : . Phase 1 Prep Work: P&A well, mill window from cement Plans are to begin prep work by November 01, 2001. Drift tubing, perform integrity test of inner annulus. Cut and drop 2-7/8" tubing tail, top of 2-7/8" fish should be at 9980' Service CTU pump 20 bbls of 17 ppg cement. Clean cement -9800' . Mill 2.75" window in 7" liner at 9905'. Phase 2: Drill and Complete sidetrack: Plans are to be ready to sidetrack by November 15, 200l. Coiled tubing drilling will be used to drill and complete the directional hole as per attached plan. Mud Program: . Phase 1: Seawater for window milling . Phase 2: Flo-Pro (8.5 ppg) for drilling operations. Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 2-3/8",4.6# STL L-80 liner will be run from TD (11070' md) to approx. 8750' MD and cemented with approximately 17 bbls. Top of cement is planned to be at -9500'. The liner will be pressure tested and perforated with coiled tubing conveyed guns. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2000 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. \ ( Logging . A Gamma Ray log will be run in the open hole section. . A Memory CNL may be run in cased hole. Hazards . Lost circulation risk is low. . H2S was measured at 10 ppm on 8/12/00. monitoring systems are fully operational. This is not an H2S Drillsite. Always make sure H2S Reservoir Pressure . Res. pressure is approx. 3200 psi @ 8800 tvd (7 ppg EMW) . Max. surface pressure with gas (0.1 psi/ft) to surface is 2325 psi. ( " ~l F -09 A Potential Drilling Hazards Post on Rig 1. Please perform pre-job Hazard ill and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S was measured at 10 ppm on 8/12/00. This is not an H2S Drillsite. Always make sure H2S monitoring systems are fully operational. 3. Reservoir pressure is approx. 3200 psi @ 8800 tvd, or 7 ppg EMW. 4. Maximum anticipated well head pressure w/ full column of gas 2325 psi. 5. The well will be drilled through a small fault in the middle of the polygon (10-15' throw). Risk of lost circulation is expected to be low. NOTE: Standard operating procedure for slimhole drilling should be to replace voidage down the coil anytime while POOH, when operating in 3-1/2" tubing. Do not fill the hole down the backside. Wells have been swabbed in a few times during CTD operations while POOH with a drlg assy in 3-1/2" tubing, trying to fill down the back side with Flopro. 3-1/2" tubing x 2" CT annular volume to the tubing tail is 42 bbls. Ensure accurate pit volume monitoring. (' TREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS Note: 9 5/8" csg was cut @ 2030'. 7" 25# IJ4S was tied back @ 8902' Foe - ~~-~kl,l~~ iM~' 7" w~c: h"no il1-- e-go BTRS I 2 700 1 9 5/8" csg spool wI?," slips. KOP: 2400' MAX ANGLE: 39° @ 8300' 3-1/2" 9.3 #/ft, L-80 EUE MOD 8rd TUBING TUBING 10: 2.992" CAPACITY: 0.0087 BBLIFT 27/8" 6.5#/ft. EUE AB- mod. IPC TUBING TAILPIPE 7"x9 5/8" TIW I 8,899 Tieback Packer 9-5/8",47 #/ft, L-80, BTRS 19,390 PERFORATION SUMMARY REF. LOG: SWS - 12-02-79 SIZE SPF INTERVAL ~PEN S4!Z 0 9880-9888' OPEN 3-1/8" 4 9904-9924' SQZ'D 3-1/8" 4 9934-9952' SQZ'D 3-1/8" 4 9963-9985' SQZ'D 2" 4 9985 - 9995' Open10/28/9 3-1/8" 9995 - 9996' 4 2-1/8" 4 10006-10050' SQZD 2-1/8" 4 10060-10070' Open 2" 'i\ 10040-10050' OPEN VJt:11 O~~W~~~~235 7", 29 #/ft, L-80, BTRS 1'10,292 ~- ~ 1- (' KB. ELEV = 67.32' BF. ELEV = 38.17' SSSV LANDING NIPPLE 11,980 (OTIS) (2.75" 10) . GAS LIFT MANDRELS 5 3188 ~049 10. 4 34. 3 5324 4940 36. 2 38. 1 7144 6440 38. 8242 7320 31/2" OTIS8~~ltING sIt11 8728 (2.75" MIN. 10) , BOT "G" SEAL ASSY I 8 785 W/LATCH . ' BOT 3H PACKER I 8,813 W/MILLOUT EXT. ~;~~~;~~:'3~~,~~~E I 8,855 ~;~~~;~~'.'3~~,~~~E I 8,888 2 7/8" BOT WLEG I 8,922 (ELMO) I 8,908 , MARKER JOINT I 9,798 Top of Perf Gun 10,162'wlm 9/30/89 DATE REV. BY COMMENTS PRUDHOE BAY UNIT 12 - 07 - 79 INITIAL WELL: F-09 44-03-11-13 02/09/94 JAM 'Rè~.P+O~þ¡~W RWO OF API NO.: 50-029-20403 PPA 8/86 SEC 02: TN 11N: RGE 13E 10/28/94 04/04/95 KSC ADD PERFS BP Exploration (Alaska) TREE = WELLHEAD= McEVOY . A-cwÃioR;---'.-.-------"ofis KB. ELEV = 67.77' ..-.........-....-.....-.-...-..-...-----..-.-...-..--- BF- ELEV = 38.17' -----'-"---.'------ KOP = 2400' ---~'.""--"------'--_.'-'._.'- Max Angle = 39@8300 ---.---------- - -.-. Datum MD = 9861 ..-----..--..--- Datum 1VDss= 8800' (F~~ ( PROPOSED CTD SIDETRACK SAFETY NOTES: 9-5/8" CSG. WAS cur @2030',7"25#1J4S WAS TIED BACK @ 8902',AND RAN TO SURF. 7" WAS HUNG IN OLD 9-158" CSG SPOOL WI?" SLIPS 1980' -i 3-1/2" OTIS SSSV LAND. NIP, ID= 2.75" I 0 2030' -i 9-5/8" Casing was cut & pulled 113-3/8" CSG, 72#, L-80, ID=12.347 ITOPOF 7" LNR I Cement ST MD 5 3188 4 5324 3 7144 2 8242 1 8364 1VD DEV 3132 11 5023 34 6524 36 7403 38 7499 38 GAS LIFT MANDRELS 1YPE VLV LATCH McMURRY BK2 McMURRY BK2 McMURRY BK2 McMURRY BK2 McMURRY BK2 SIZE DA TE 3-1/2 3-1/2 3-1/2 3-1/2 3-1/2 2700' Minimum 10 = 2.31"@ 8785'? 3-1/2" x 2-7/8" XO I 3-1/2" mG, 9.3#, L-80, 0.0087 bpf, ID=2.992 I ITOPOF2-7/8"TBG I I Top of Proposed 2-3/8" Liner I 8728' 8785' 8785' -i 3-1/2" OTIS SLIDING SLEEVE,ID=2.75" -1 BOT G SEAL ASSY WI LATCH I -i3-1/2"X2-7/8" XO I -i BOT 3-H PKR WI MILLOur EXT 8813' 8899' 8899' -i 7"x9-5/8" TIW TIEBACK PKR 17" Tieback I 19-5/8" CSG, 47#, L-80, ID=8.681 I 8902' 9390' I 9500' l--l Top of Cement (Liner Job) ÆRFORA TION SUMMA RY REF LOG: SWS BHCS 12/02/79 ANGLE A T-fõp.'ÆRF':'-'18@9880' Note: Refer to Production DB for historical perf data Top of Cement (P&A) Cement Ramp KOP (TOW) I I SIZE SPF INTERV A L Opn/Sqz DATE 2 4 9880-9888 0 10/28/1994 3-118 4 9904-9924 S 3-1/8 4 9934-9952 S 3-1/8 4 9963-9985 S 2 4 9985-9995 0 10/28/1994 3-118 4 9995-9996 0 10/28/1994 2-118 4 10006-10050 S 2/1/8 4 10060-10070 0 10/28/1994 2 4 10040-10050 0 10/28/1994 2 4 10060-10070 0 10/28/1994 .i I 2-318" L-80 LINER, Cemented & Perforated I 11 070' Cut Tubing Tail & push it to bottom I PBTD I 10235' 10162' -i TOP OF ÆRF GUN I I 7" LNR, 29#, L-80, 0.0371 bpf, ID=6.184 I 10292' DATE REV BY COMMENTS 12/07/79 ORIGINAL COMPLETION 02/09/94 LAST WORK OVER 02/15/01 SIS-MH CONVERTED TO CANVAS 03/05/01 SIS-MD FINAL 05/15/01 pcr F-09A Proposed ST PRUDHOE BAY UNrT WELL: F-09A ST Proposal ÆRMrT No: 79-0760 API No: 50-029-20403-01 Sec. 3, T11N,R13E BP Exploration (Alas ka) aNlASl.J[AlE œtDO1 Well F-ODA ( ( BOP-Tree KB Elevation Rig Floor lubricator ID == 6,375" w~1h 6° Otis Unions' , \Pit " "ijt~IW'WiI~¡~W 1-' ~ '~6 ::."'0:". '\""1 ~~~n'., ., ..."'... ..",....~ .), 10 -. 7,06 ~ ~ 17 1"6 5~0(ì [.':~I HX..,1~ ~ ... , ... 1':-1 ¡urn :..TV~1;'IÜ , 5:00 ::'~~I õ,X.,46 ~ 50:0 ')~:i : RX-2~ I I ? I 10:3 ~ ',',',','.',','"", ','.','.',',',',',', :::::::::¡::::::f f¡:~:f¡:f~; -. I. 16' 50ü~) p:h ,nx 4~=i m 4 1. '6' 50CO 1':01 :F,X.39,' ~ .. Swab Valve ~ Tree Size ~ ~,~ \'~~':'~'~r.~~~,.:.rt~'ln"'r':;';::~':, ". -.Il1o... ". ,,',,', Trs.".....:ti> , ",,:,:":,>:L--""'- " , " w , ..., , . " .' , Master Valve ~ SSV ~ ~ ~~~~~~~~~(~~~~~~~' ~~~~~~~~~~~~~~~~~ ~ ,..,.. ",",,' ." " ",,"',.. ,.. ..' "..,' ",' ,',"" , ',.,', ,',,' Þ ~~\:t:~;,:~:,¡~\.;,,:' :i:i~hm .,.::~:~:,.:.,~.:"",:':~, ~ :"':;:~:~'~:=-,:¡ ~"::": ':::~:::" Base Flan~e ~ , ""'" " , ." ..... ,"" " " ,,"," ,,' .,., . , .. '.' '" ,., , ," , ., ,. ,... .,.", , ",', .""", .."" .'"" ,,',,' ", . .... '", ",," .', ",' ", ., '" " "',",', "" " .""" , ,',' ",', , '" , " ,,' " ", ,',' ,""',',,',, , , , , ","", '", ',' .. , , "..' " " , . " '. ., , ", , """""""'" ,. '....' .. " Page 1 BP Amoco Magnetic FIetd Strength: 574g4nT Dip Angle: 80.81' Date: 9/25/2001 Model: BGGM2001 LEGEND Azimuths to T rue North I Plan Plan #2 (F,G9/PlanO2 F'D9AI Magnetic North: 26.53' Cmated By Bri) Potn;s Date 9/25/2001 tn;ormaUon WEClPATH DETAilS PO,."F,OS' soomo....' P"o"Wo"P"" Tr,.. MD, F." ....... .~, "'.O,tom, V.S~tr"' AnSI' ,,"""'1""..". .risr. oNI.$ ~~!~ Stortl.S F~mTVD -950 REFERENCE INFORMATION -1000 67.30 -1050 .... 8600 C ;¡;¡ 8650 .... 0 It) 8700 .... .c 'So 8750 ell Q 8800 ~ 8850 i 8900 :> ell 8950 :::¡; ... I- 9000 "mo, ",.", .".W "" TPo," -1100 -3300 -3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400-2350 -2300 .2250 -2200-2150 -2100 -2050 -2000 West(-)/East(+) [50ft/in] 9200 -3650 -3600 -3550 -3500 -3450 -3400 -3350 -3300 -3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600 -2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200 -2150 -2100 -2050 -2000 -1950 -1900 -1850 -1800 -1750 -1700 Vertical Section at 45.000 [50ft/in] 05," "r,,' , "'"... n." """ om... .m"" ~",." 0." 0." ."".DO ! :mm *!! ¡¡H! ¡!¡¡~ :m¡¡¡!~¡¡¡ ¡¡ii :¡~¡!¡¡¡¡ ¡ ¡¡¡¡!ll 1m ¡Ii! ¡!!¡¡1m¡!! :¡¡¡~¡¡ ¡ii! ,¡¡~ :¡¡¡¡¡¡ -1150 :5 -1200 ~ -1250 0 !:2. -1300 .-. + :ë -1350 t: 0 -1400 Z 7-1450 :ë '$ -1500 0 In -1550 I F.O9A PoIY90n2 1 ANNOTATIONS MD An.,t,tr,. om." ......, TIP "".82 ....... KOP ""." '."2." , ......, "269.11 2 0992.44 '."'.11 , "'..97 ,...,." . ,...." ,mo.'. TD 8450 8500 -1600 8550 -1650 -1700 -1750 -1800 F.09A T2" 9050 9100 9150 9/25/2001 5:19 PM ( ( ObP BP Amoco Baker Hughes INTEQ Planning Report .ii8 -=- lNTEQ - -------._------ Date: 9/25/2001 Time: 17:20:04 Page: ---i--l Co-ordinate(NE) Reference: Well: F-09, True North Vertical (TVD) Reference: System: Mean Sea Level I Section (VS) Reference: Well (0.00N,0.00E,45.00Azi) I Survey Calculation Metbo~~~in~um _Cu~atur~_____Db-=-_Ora~le ---_.J ---------------- ------------- -- ---- ------------l I ; I , i Company: BP Amoco ¡ Field: Prudhoe Bay . Site: PB F Pad I Well: F-09 i WeUpatb: Plan#2 F-09A ~--- ----- --------------------- ¡- -- Fi;ïd~-------P~dh;;-~B~y------------- : North Slope I UNITED STATES I Map System:US State Plane Coordinate System 1927 Map Zone: Alaska. Zone 4 l- ~:; ;~~~;:_-;~~~~~I_t~;:~~~)----_._------------------ g;;~;;;!~y~~~~_:_--__~~~~3;!____------ -----_.----- - I i ------------------.--------_____--1 m_-- -- ---------------------------- ---...-------------------------- ------------------------------------------ -- --------- -- ---------------- ------------- _-_on, Site: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: 70 19 55.283 N Longitude: 148 46 31.468 W North Reference: True Grid Convergence: 1.15 deg ---------------------- --- ----- .-- _.------ - - -------------------------------- --------- ------ --------------------- --- ----------------- -------------------------------------------------------- ------...-----..------- ----- ---- ----------------------- --- -------- ------- - -------- ------------------------------------- --------------------.-- --.- ---------------------------------------------------------------------.---------------------------------------------------- h______----------- --------- ------- ------- Well: F-09 F-09 Well Position: +N/-S 1784.41 ft Northing: +E/-W 1033.49 ft Easting: Position Uncertainty: 0.00 ft 5974332.00 ft 651958.00 ft Latitude: Longitude: 09 70 20 12.832 N 148 46 1.285 W Slot Name: -- - ---..--- -----------.------ ----------.-.-- -------------------------------------------------------------------------- -------------------------------.---, __m_-__.._----------.---------'---"-------- -",--"-"'--,,,---,-..--- ., . -- ""--- -- -. ------ -- ,---""..--.,--- - -,,-------------.." ------- - ,,--_.._------, -".--. ---- --,--- ",-------- ,----- ----,-- -",--- -- ---- ------.- ,.------. --------------------------- --- ---, -------------- -----,-------.-.....,-.----."----------------- -----,---- -- Wellpath: Plan#2 F-09A Drilled From: F-09 500292040301 Tie-on Depth: 9905.00 ft Current Datum: 9: 09 11/15/197900:00 Height 67.30 ft Above System Datum: Mean Sea Level Magnetic Data: 9/2512001 Declination: 26.53 deg Field Strength: 57494 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg -,- - -----._-- - ------------,------------ ._--,-- ----------------_..-----------------,,--------_._------,--- --,---_.._,---------,---------------,--,----------,,---------------. --,,- ------------------------------, ----------,,------- 0.00 0.00 0.00 45.00 ..- --------- -------- -"..-.-- --- --------.---.----..--- -,-----,--------- -----------------------.-.---.--.------------. ----,.-----------..-,---.----------""-------,-.---,----.-.-,-.----.---- ---------,--,,------.---.----------------..------- _,__n_" ---.-------------------.------------..,- --- ::~::!J~:~:~~:~==~~==;;:~=r;~~~==~~"-:~] Targets ------------ --------. --.- -'--.._-- ---- -...-.------ --, -- ---- - - -- ..--.., ---. -_..- --- -- ,--- ---.---- -- -----------.-------- ---------- --'-------'------' - - Map Map <- Latitude--> <- Longitude --> ¡ Name DescriptionTVD +N/-S +E/-W Northing Easting Deg Min Sec ' Deg MiriSec I --... ---------- --".._----------- --------. "..---.--------..----__--C'_n.." ...--""------,-------,---"---------..----,_.._-~~--_._.:_------".._-:..._--...__:~~-----..---_.__..-----_...---~,:._---,,------------------ --~------_.._--,-- --"...---------_!!:-----.--,------ ".'------"---------"'----"'----"--""-- '--------,,--,--:,,----------..---------"'----.-------------.--.----------.- ---- F-09A T2.1 8995.00 -1475.72 -2916.50 5972797.60 649072.21 70 19 58.313 N 148 47 26.446 W F-09A T2.2 8990.00 -1325.28 -2737.43 5972951.62 649248.19 70 19 59.793 N 148 47 21.219 W F-09A T2.3 8985.00 -1004.93 -2352.87 5973279.68 649626.14 70 20 2.945 N 148 47 9.992 W F-09A Polygon2.1 0.00 -1311.89 -3005.23 5972959.59 648980.19 70 19 59.924 N 148 47 29.039 W -Polygon 1 0.00 -1311.89 -3005.23 5972959.59 648980.19 70 19 59.924 N 148 47 29.039 W -Polygon 2 0.00 -791.12 -2539.62 5973489.65 649435.12 70 20 5.047 N 148 47 15.448 W -Polygon 3 0.00 -1192.81 -2212.61 5973094.69 649770.17 70 20 1.098 N 148 47 5.895 W -Polygon 4 0.00 -1606.18 -2796.09 5972669.62 649195.23 70 19 57.030 N 148 47 22.928 W -----,----- .--- ." -. ".--_._--------,------------_.,..,-, ----..-----------.--. ----...-----.--------.-,.----.-----,---....--..----,....---------..-----"'.-----------"---".'--.--.-----------"---"------'--------------..---------..-.-,-...----, ,.._--,---------------., ,,-.------- ---,,---,-------,,-----_.._----_._----,,--- ---- Annotation 9900.00 9905.00 10162.14 10269.11 10369.11 10669.11 11070.00 8837.05 8841 .82 8997.83 8996.06 8992.44 8980.87 8984.35 TIP KOP 1 2 3 4 TO ObP i( ,( BP Amoco Baker Hughes INTEQ Planning Report .ii. .... INTEQ [ Company: BP Amoco Date: 9/25/2001 Time: 17:20:04 Page: 2 \ i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: F-09, True North I I Site: PB F Pad Vertical (TVD) Reference: System: Mean Sea Level ! : Well: F-09 Section (VS) Reference: Well (0.00N,O.00E,45.00Azi) I L We~~!~~~!an#2 ~~~-----_.__._----_._-----------_._-___~urvey_~alcula~n ~etbo~- Mi~~~~~_CurvatU!~___.~~~---~~~~-_J Plan Section Information [-~_f--=J;~_~~m__- ___3 -- _~N~ __-=:fi ~-~;!~~':~ ~ d~~~;__:~ --~-~= =.J '9900.00 17.63 264.60 8837.05 -1771.98 -2937.44 0.00 0.00 0.00 0.00 9905.00 17.63 264.60 8841.82 -1772.12 -2938.95 0.00 0.00 0.00 0.00 10162.14 90.00 354.60 8997.83 -1613.81 -3003.71 35.00 28.14 35.00 90.00 10269.11 91.82 32.00 8996.06 -1511.57 -2979.55 35.00 1.70 34.96 87.00 10369.11 92.32 41.99 8992.44 -1431.86 -2919.49 10.00 0.49 9.99 87.00 10669.11 92.01 72.01 8980.87 -1270.47 -2670.93 10.00 -0.10 10.01 90.00 11070.00 87.04 32.22 8984.35 -1029.35 -2360.91 10.00 -1.24 -9.93 263.00 Survey "'--'-""'-"""'----..,..--- - ----,---_. --'-----........-....--_,__,.n_._._....--.--....------------------..--.---.----.-..--..----______n_._.__--.---.------...-----.---.---.-...----.--....- '-"'------'--- . ---------.-. --"----"-' --------'-'---'----"-'--"-"--'--'------- -- -----..-.. --'---'------------"--- ------- .- -.- .------.-- ..---- MD Incl Azim SSTVD N/S EIWMapN MapE DLS VS TFO Tool .. ._.._--~.__..---_..__._~.~~- -----,_._~.~~-_...__._,-~_._--_._- _._~--_._- _._-~~-_._~_._~~~.._---~-_._----_.~-----_._~-~~~~~._----~----_._--_.._._--~:~_. ------,-..------..-- .... 9900.00 17.63 264.60 8837.05 -1771.98 -2937.44 5972501.00 649057.28 0.00 -3330.06 0.00 TIP 9905.00 17.63 264.60 8841.82 -1772.12 -2938.95 5972500.82 649055.78 0.00 -3331.23 257.59 KOP 9925.00 18.93 286.67 8860.83 -1771.48 -2945.08 5972501.34 649049.64 35.00 -3335.11 90.00 MWD 9950.00 23.47 307.56 8884.16 -1767.27 -2952.92 5972505.39 649041.71 35.00 -3337.68 69.02 MWD 9975.00 29.86 320.99 8906.51 -1759.38 -2960.80 5972513.12 649033.67 35.00 -3337.68 49.50 MWD 10000.00 10025.00 10050.00 10075.00 10095.29 10100.00 10110.06 10125.00 10150.00 10162.14 10175.00 10200.00 10225.00 10250.00 10269.11 10275.00 10300.00 10325.00 10350.00 10369.11 10375.00 10400.00 10425.00 10450.00 10475.00 10500.00 10525.00 10550.00 10575.00 10600.00 10625.00 10650.00 10669.11 10675.00 10700.00 10725.00 10750.00 10775.00 37.15 44.91 52.92 61.07 67.76 69.32 72.64 77.62 85.95 90.00 90.24 90.69 91.12 91.53 91.82 91.85 91.98 92.11 92.23 92.32 92.32 92.31 92.31 92.29 92.28 92.26 92.23 92.20 92.17 92.13 92.09 92.04 92.01 91.93 91.63 91.32 91.00 90.69 329.81 336.01 340.70 344.48 347.13 347.71 348.90 350.60 353.31 354.60 359.09 7.83 16.57 25.32 32.00 32.59 35.09 37.59 40.08 41.99 42.58 45.09 47.59 50.09 52.59 55.09 57.60 60.10 62.60 65.10 67.60 70.10 72.01 71.43 68.95 66.47 63.98 61.50 8927.36 8946.21 8962.63 8976.24 8985.00 8986.72 8990.00 8993.83 8997.40 8997.83 8997.80 8997.60 8997.21 8996.62 8996.06 8995.88 8995.04 8994.15 8993.20 8992.44 8992.21 8991.20 8990.19 8989.19 8988.19 8987.20 8986.22 8985.25 8984.30 8983.36 8982.44 8981.54 8980.87 8980.66 8979.89 8979.24 8978.74 8978.37 -1748.00 -1733.38 -1715.88 -1695.88 -1678.15 -1673.87 -1664.56 -1650.35 -1625.88 -1613.81 -1600.98 -1576.05 -1551.64 -1528.32 -1511.57 -1506.59 -1485.84 -1465.72 -1446.26 -1431.86 -1427.50 -1409.48 -1392.24 -1375.80 -1360.20 -1345.46 -1331.62 -1318.69 -1306.72 -1295.71 -1285.69 -1276.67 -1270.47 -1268.63 -1260.16 -1250.68 -1240.21 -1228.76 -2968.53 -2975.93 -2982.83 -2989.06 -2993.54 -2994.49 -2996.42 -2998.98 -3002.44 -3003.71 -3004.42 -3002.91 -2997.63 -2988.71 -2979.55 -2976.41 -2962.50 -2947.69 -2932.03 -2919.49 -2915.53 -2898.23 -2880.16 -2861.36 -2841.85 -2821.69 -2800.89 -2779.52 -2757.60 -2735.17 -2712.29 -2688.99 -2670.93 -2665.34 -2641.83 -2618.71 -2596.02 -2573.80 5972524.34 5972538.80 5972556.16 5972576.02 5972593.66 5972597.92 5972607.19 5972621.34 5972645.74 5972657.78 5972670.59 5972695.54 5972720.05 5972743.55 5972760.48 5972765.52 5972786.55 5972806.97 5972826.74 5972841.38 5972845.82 5972864.18 5972881.79 5972898.61 5972914.60 5972929.74 5972944.00 5972957.35 5972969.77 5972981.23 5972991.72 5973001.20 5973007.77 5973009.72 5973018.66 5973028.61 5973039.54 5973051.43 649025.71 649018.02 649010.77 649004.13 648999.30 648998.26 648996.15 648993.29 648989.35 648987.83 648986.86 648987.86 648992.64 649001.09 649009.91 649012.95 649026.44 649040.83 649056.09 649068.34 649072.21 649089.14 649106.85 649125.32 649144.50 649164.36 649184.87 649205.98 649227.65 649249.84 649272.52 649295.63 649313.56 649319.11 649342.44 649365.36 649387.84 649409.82 35.00 35.00 35.00 35.00 35.00 35.00 34.79 35.14 35.00 35.01 34.99 35.00 35.00 35.00 35.00 10.01 10.00 10.00 10.00 9.98 10.08 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.97 9.93 10.00 10.00 10.00 10.00 -3335.09 -3329.99 -3322.49 -3312.76 -3303.38 -3301.03 -3295.81 -3287.58 -3272.71 -3265.08 -3256.51 -3237.81 -3216.82 -3194.02 -3175.70 -3169.96 -3145.45 -3120.75 -3095.92 -3076.87 -3070.99 -3046.02 -3021.05 -2996.12 -2971.30 -2946.62 -2922.13 -2897.87 -2873.90 -2850.26 -2827.00 -2804.15 -2786.99 -2781.73 -2759.12 -2736.07 -2712.62 -2688.81 37.46 MWD 30.10 MWD 25.40 MWD 22.31 MWD 20.25 F-O9A 19.10 MWD 18.89 F-O9A 18.50 MWD 18.06 MWD 17.68 1 87.00 MWD 87.01 MWD 87.08 MWD 87.22 MWD 87.45 2 86.69 MWD 87.02 MWD 87.10 MWD 87.19 MWD 87.17 3 90.36 MWD 90.02 MWD 90.12 MWD 90.23 MWD 90.33 MWD 90.43 MWD 90.52 MWD 90.62 MWD 90.72 MWD 90.81 MWD 90.91 MWD 91.00 MWD 90.97 4 262.54 MWD 262.98 MWD 262.90 MWD 262.84 MWD 262.79 MWD ..- '-"'--"-"----"-'-----------------------'--'--'------------'-"-""---'-"---'------------'--'--"--------'" .,"'-"--..--__...__n____--_..----..----...----.--.---.---. """""....-...---"---'" --,-------"'-----". ..--.,....-------. ....----.--.--.-.-.-...--..-.....-.----"""-- ObP ,( (' BP Amoco Baker Hughes INTEQ Planning Report ... BA- IIUGIIIS INTEQ ,- -, I Company: BP Amoco Date: 9/25/2001 Time: 17:20:04 Page: 3 I II! Field: Prudhoe Bay Co-ørdlnate(NE) Refe- rence: Well: F-09, True North I I Site: PB F Pad Vertieal (TVD) Reference: System: Mean Sea Level I I Well: F-09 Section (VS) Reference: Well (0.00N,O.00E,45.00Azi) ~_~!~pa~_}:_~~!.:E.~~---------------------------------__.-!~~~I Calculation Method~ Minimum C~rvature ------~~:___<?_~cl~____.J Survey '------~~-----~~~----~~=- S~~:~:=--Ñ~S_-=~~~~==~::~~~----- M!E --- d~~OOft ~s --~~:~;~~~T~~:=I 10800.00 90.37 59.02 8978.14 -1216.36 -2552.09 5973064.27 649431.27 10.00 -2664.70 262.75 MWD II 10825.00 90.06 56.54 8978.04 -1203.03 -2530.94 5973078.02 649452.14 10.00 -2640.32 262.73 MWD 10850.00 10875.00 10900.00 10925.00 10950.00 10975.00 11000.00 11025.00 11050.00 11070.00 89.74 89.42 89.11 88.79 88.48 88.17 87.87 87.57 87.27 87.04 -1188.81 -1173.70 -1157.75 -1140.98 -1123.43 -2510.39 -2490.47 -2471.23 -2452.69 -2434.90 -2417.89 -2401.69 -2386.34 -2371.85 -2360.91 5973092.66 5973108.16 5973124.50 5973141.64 5973159.55 5973178.19 5973197.53 5973217.54 5973238.17 5973255.10 649472.40 649492.01 649510.92 649529.11 649546.54 649563.17 649578.98 649593.94 649608.00 649618.61 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 -2615.72 -2590.96 -2566.07 -2541.11 -2516.12 -2491.15 -2466.25 -2441.46 -2416.83 -2397.28 262.72 MWD 262.72 MWD 262.74 MWD 262.77 MWD 262.82 MWD 262.88 MWD 262.95 MWD 263.04 MWD 263.14 MWD 263.28 TO --- --- --- -- --- --------- --------.._------------------- ._._~-------------------_.-.- .---- .-.------..------------.--.---- ------.--.-.------.------ ------.-.--.------------------------.-----------.--.----------------------- 54.06 51.58 49.10 46.62 44.14 8978.09 8978.27 8978.59 8979.05 8979.64 41.66 39.18 36.69 34.21 32.22 8980.37 8981.23 8982.23 8983.36 8984.35 -1105.12 -1086.10 -1066.40 -1046.06 -1029.35 It ( DATE 07/31/01 CHECK NO. 00194722 H 194722 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 072701 CK072701M P YMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it To Drill ee S/H - Terrie Hub Ie X4628 f:OqA- TOTAL ~ HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 1000 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 194722 CONSOLIDATED COMMERCIAL ACCOUNT I. , . 56-389 412 00194722 ".......'... PAY . .. ... ". . ',..d.'. ." .,..'. ONE HUNDR ED & 00 11 OO~**-If1f'***********~~*if:'§;:*~**~*********** uS nØLLAR DATE .:. ::'\*,Moä~T 97i/:1i/Ol!l!i :::1 . ." ~ÎI. o~'~~~.1 NqTVALIOAFTERi20. DAYS '" ""'"....,.--;i.:,.." To The ORDER O-f . d '. .. ... . . : . .... .ALASKA QILANP G~8 . . COI\iSERVPaTION.COMMISSION ::3:3t3>WESj: 7T~AVENVE . SUITE lqo ....., :.....' '. ANCHORAGE AK 99501 III ~ g ... 7 2 2 III I: 0 ... ~ 2 0 jag 5 I: 0 0 a ...... ~ g III ~ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT RED RIL:;; PILOT HOLE (PH) EXPLORA TION / ANNULAR JiISPOSAL ( V ) NO INJECTION WELL ANNULAR DISPOSAL L-> YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL ft3¿t rrY1Æ "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. 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 number (50__-70/80) from records, data and logs acquired for wel~ (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved, sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. Permit fee attached. . . ',' . . . . . . . .. : / '. . . . . : . 2. Lease number appropriate~ . $?? . 1c:/.4,"f7.CI71. r- /O:"~! 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells. . . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . N 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N All) ~~fról 12. Permit can.be issued without administrative approval.. . . . . N a 13. Can permit be approved before 15-day wait. . . . . . . . . . Y N 15. Surface casing protects all known USDWs. . . . . . . . A/L1 Y g~~./I q'~/sh;"/ t;;ëJ? .,gl> ::: ::~::O~dS~:::t:r:;:;I~t~ ~n '~n~~~o~ ~ ~~ñ' ~g', ',: ': ': rr: N ~~~" \ \\ ~ ~,~~ \ ,~ ,- - ~ k \ \ 17. CMT vol adequate to be-In long string to surf csg. . . . . . . . Y N ' ':, 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C. T. B & permafrost. . . . . . . N À-\ I ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N h\.~ "'-.J'C' ~~~>,-""~\ ~. 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~ ~-:2~:> \ ~ \'" f'. ~ 22. Adequate well bore separation proposed.. . . . . . . . . . . . N .\t'o.~ ~ \r.:..~'Q: o...9\'~C-""\..~~~\~~t!:c)' 23. If diverter required. does it meet regulations. . . . . . . . . . ~~ 24. Drilling .fluid program schematic & equip list adequate. . . . . .Cð N . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~ N \ . 26. BOPE press rating appropriate; test to ~sig. @ N ~':>~"""?\~ .).~d-S- ~~,. '.' 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . . . ~ N . ~~: ~~~:::~~~rH~~h:~~ ~~:~:~~; ~~u~d~~n: : : : : : : : : : : y ~M-~ .",~GJ ~~\~~ ~ð-> ~ ~~~ \ L~ \~ ~~d\~,,~ .~~(~~~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ~ Ñ /0 f'~ #Z -$ hvLq,:¡, v re-d ~ r - 6'7:..... A"ß u..;~ 7 t'"x'¥), <>. '" 31. Data presented on potential overpressure zones. . . . . . . Y v 32. Seismic analysis of shallow gas zones. . . . . . . . . . ~.. A ' N ~&,f) pATE, 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N . , '1.2.!tol 34. Contact name/phone for weekly progress reports [explq ory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate fréshwater; or cause drilling waste. .. to surface;' . (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:.' UICI nnular COMMISSION: ~~8 . -61) ~E W WM 9gs ENGINEERiNG RATE .fJJ('3 GEOLOGY APPR DATE WELL NAME ¡;::'-e>9. PROGRAM: exp - dev ~ redrtl V'" serv well bore seg _ann. disposal para req- -;:t?GV l' ¿;;/ L- GEOL AREA f39 UNIT# ð / I b ÇD ON/OFF SHORE C)ÞJ Y N N ..:5"-r-Îcu!-~ ~t4td.7, 'D, ~ HÞi- 0282.eD;' r~ ~d~.:':h£.~ ~1.'¡c'!¡--v4f N t4.- A z? t- 6 z.8 zB /. sÞ c 0 Z 0 -I :E ::c (' - -I m - Z -I .:1: - en » ::c m » ( Y N Y N Comments/Instructions: l 0 /t-II LŸ c:\msoffice\wordian\diana\checklist (rev. 11/01/100) <i' "I ~ ( Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically , . organize this category of information. ~ " A ( **** REEL HEADER **** MWD 02/04/08 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/29 239381 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 9701.0000: STOP.FT 10981.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD. FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 2 TOWN. N llN RANG. 13E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 67.30 DMF KB EKB .F 67.30 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Tie in log with Schlurnberger BHCS/GR. (5) Well F-09A is a sidetrack of the original well F-09r kicked off through window at 9823' MD (8764' SSTVD). Well F-09A was drilled to TD at 10981' MD (8989' SSTVD). Memory log was produced from 9908' MD. The interval from 10964' MD (8988' SSTVD) to 10981' MD (8989' SSTVD) was not logged due to sensor to bit offset. Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. F-09A Prudhoe Bay Unit 1784' NSL, 1033' EWL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 31-Dec-01 500292040301 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ( 6) (7) (8 ) Ò\ D J- J c¡<:¡? /Dllo;;;Z ( i( (9) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 02-Jan-02). (10) A Magnetic Declination correction of 26.41 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depthr feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL RUN GAMMA DIRECTIONAL 1 19.10 ft. 24.68 ft. 2 19.10 ft. 24.68 ft. 3 19.02 ft. 24.60 ft. 4 19.12 ft. 24.70 ft. 5 19.35 ft. 24.93 ft. 6 19.95 ft. 25.53 ft. 7 18.99 ft. 24.57 ft. 8 18.08 ft. 23.66 ft. 9 18.08 ft. 23.66 ft. 10 18.08 ft. 23.66 ft. 11 18.08 ft. 23.66 ft. 12 18.46 ft. 24.04 ft. 13 18.30 ft. 23.90 ft. 14 18.08 ft. 23.66 ft. 15 18.46 ft. 24.04 ft. 16 18.18 ft. 23.76 ft. CURVE SHIFT DATA BASELINEr MEASURED, DISPLACEMENT 9899.57r 9899.37, -0.202148 9915.73, 9916.14, 0.404297 9954.12, 9954.32, 0.202148 9975.84, 9977.05, 1.21191 10013.4r 10011.0, -2.42383 10085.5r 10084.9r -0.606445 10095.6, 10094.8, -0.808594 10113.8r 10114.0, 0.202148 10798.7r 10798.9, 0.202148 10870.5, 10873.8r 3.23242 EOZ END ! BASE CURVE: GROHr OFFSET CURVE: GRAX Tape Subfile: 1 97 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ( ( ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. F-09A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 02-Jan-02. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GRM ROP GR GRM ROP GRAX10 GRAM10 ROPS10 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 63 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 GRM RWD 68 1 API 3 ROP MWD 68 1 F/HR Size Length 4 4 4 4 4 4 ------- 12 Total Data Records: 41 Tape File Start Depth 9701.000000 Tape File End Depth 10981.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subtile: 2 51 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 ~' ( *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. F-09A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAM ROPS GRAX GRAM ROPS GRAX GRAM ROPS 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 63 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth 10: F 3 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 API 2 GRAM RWD 68 1 API 3 ROPS MWD 68 1 F/HR Size Length 4 4 4 4 4 4 ------- 12 Total Data Records: 41 Tape File Start Depth 9701.000000 Tape File End Depth 10981.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 51 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD .I ( ~l . 02/03/29 239381 01 **** REEL TRAILER **** MWD 02/04/08 BHI 01 Tape Subtile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR GRM Rap 9701.0000 15.3390 -999.2500 -999.2500 9701.5000 13.6850 -999.2500 -999.2500 9800.0000 16.3797 -999.2500 -999.2500 9900.0000 65.5271 -999.2500 12.1528 10000.0000 24.3769 23.2625 20.4786 10100.0000 28.2926 25.8118 21.3204 10200.0000 23.3510 24.1718 8.9979 10300.0000 19.4411 18.7253 207.3651 10400.0000 23.3531 23.5696 112.0969 10500.0000 20.8201 21.8324 122.5421 10600.0000 26.3719 24.4695 50.5742 10700.0000 20.9185 20.1949 116.4657 10800.0000 55.3697 52.6672 128.5922 10900.0000 27.3856 28.0079 107.3911 10981.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth 9701.000000 Tape File End Depth 10981.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = teet Tape Subtile 3 is type: LIS DEPTH GRAX GRAM RapS 9701.0000 15.3390 -999.2500 -999.2500 9701.5000 13.6600 -999.2500 -999.2500 9800.0000 16.4420 -999.2500 -999.2500 9900.0000 60.3710 -999.2500 10.9070 10000.0000 27.6680 27.3460 20.1700 10100.0000 23.4350 22.7610 40.9250 10200.0000 23.7630 24.6250 8.2720 10300.0000 19.4980 18.8470 207.0480 10400.0000 22.8450 23.3610 112.5770 10500.0000 20.7660 21. 6250 121. 5900 10600.0000 26.2270 24.3850 47.4540 10700.0000 21. 0470 20.0680 109.7740 10800.0000 52.8950 50.5910 128.5200 10900.0000 26.6080 25.0920 109.9150 10981.0000 -999.2500 -999.2500 86.5380 Tape File Start Depth 9701.000000 Tape File End Depth 10981.000000 Tape File Level Spacing = 0.500000 II. ( , Tape File Depth Units Tape Subfile 4 is type: LIS ( = feet