The URL can be used to link to this page

Home My WebLink About202-102 ~\ STATE OF ALASKA ) ALASKA JIL AND GAS CONSERVATION COMIVIISSION DEC WELL COMPLETION OR RECOMPLETION REPORT AND LOG' '\ ,EIVED AUG I 8 Z005 1a. Well Status: 0 Oil 0 Gas 0 Plugged III Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ D WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1937' SNL, 1438' EWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 2454' SNL, 4415' EWL, SEC. 22, T11 N, R14E, UM Total Depth: 1062' SNL, 4870' EWL, SEC. 22, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 67738~___ y- ~959578 Zone- ASP4 TPI: x- 680378 y- 5959132 Zone- ASP4 Total Depth: x- 680797 y- 5960535 Zone- ASP4 ---------------------- .---------------. .----------------- 18. Directional Survey 0 Yes III No 21. Logs Run: MWD, ROP, GR, Memory CNL, CCL 22. Zero Other 5. Date Comp., Susp., or Aband. 7/6/2005 6. Date Spudded 6/10/2002 7. Date T.D. Reached 6/13/2002 8. KB Elevation (ft): 64.6' 9. Plug Back Depth (MD+TVD) 12140 + 8783 10. Total Depth (MD+ TVD) 12214 + 8786 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING SIZE 2011 13-3/811 9-51811 GRADE H-40 L-80 NT80S NT80S L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH Me> SETTING DEPTH TVD HOLE "lOP tsOTTOM lOP tiOTTOM SIZE Surface 110' Surface 110' 3011 36' 3524' 36' 3524' 1611 32' 8952' 32' 8324' 12-1/411 8651' 10119' 8148' 8762' 8-1/211 9834' 12178' 8685' 8785' 311 SIZE 4-1/211, 12.6#, L-80 x 3-1/211,9.2#, L-80 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9816' - 9821' & 9502' - 9507' Perf'd Tubing for Cement Injection (Unsuccessful) 9765' Set CIBP & (Attempt) P&A wI 40 Bbls Cement 9656' - 9681' Perf'd for P&A 9662' Set Whipstock, P&A wI 8 Bbls Class 'G' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL -BBL WT. PER FT. 94.5# 68# 47# 26# 4.7# 711 2-3/811 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state IInonell): None MD TVD MD SC,{~N~~ED A,UG 3 0 2005 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BBL Press. 24-HoUR RATE 27. 24. TVD GAs-McF W ATER-BBL m8srl~fF~Sßis. COOs:... r.Qmm~~on III Develop~e~t U "ExpTorarory o Stratigr~AfE1101JmJ8ervice 12. Permit to Drill Number 202-102 305-134 13. API Number 50- 029-22285-01-00 14. Well Name and Number: 15-31A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: GAs-McF W ATER-BBL 20. Thickness of Permafrost 1900' (Approx.) CEMENTING ReCORD 2000# Coldset 2554 cu ft CS III, 460 cu ft Class 'G' 1644 cu ft Class 'G', 506 cu ft 'G' 493 cu ft Class 'G' 112 cu ft Class 'G' AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 10119' PACKER SET (MD) 9053' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Sub","-core cbip~;. if none, state IInonell. ;'¡ C(l:~i:-~:, None f~~i JI ~D I -t¡I, . '. _ ..___; '.,I~~1"'I,"---':OI"'1:.,\---...,-I Form 1 0-407 Revised 12/2003 CONTLJ~lbrN'Ä L RBDMS BFL AUG 23 200J -( 28. ) GEOLOGIC MARKERS 29. ) FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 10167' 8774' None TDF 10640' 8817' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the fo~oin.g is tru~ and correct to the best of my knowledge. Signed Terrie HUbbl~ M.<R. ¡. ~ Title Technical Assistant Date tla I, 7 / å'\ 15-31 A 202-102 305-134 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool Is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 15-31 B Prudhoe Bay Unit 50-029-22285-02-00 205-086 Accept: Spud: Release: Rig: 07/05/05 07/08/05 07/17/05 Nordic #1 PRE-RIG WORK OS/25/05 DRIFTED WI 2.7011 X 16' 511 LONG DUMMY WHIPSTOCK TO 9726' SLM (71 DEG DEV). HAD TO WORK DRIFT FROM 9480' SLM TO 9726', DUE TO HAWI LONG DRIFT. RAN THRU AREA SEVERAL TIMES BUT DIDN'T SEEM TO GET BETTER. 06/06/05 PERFORATING TWO 1 11/16 ",5' 4 SPF SMALL TUBING PUNCHERS. INTERVAL: 9816' - 9821', (TIED INTO PDC LOG 03-08-2000). 9502' - 9507'. BOTH GUNS WERE SHOT 2' BELOW TUBING COLLARS. 1 ST COLLAR LOCATED AT 9814'. 2ND COLLAR LOCATED AT 9500'. 06/08/05 RIH WITH 2.745 DJN FOR DRIFT I TAG. TAG TOP OF LINER AT 9802' UNCORRECTED CTMD. ACTUAL TOP OF LINER (REF 03-DEC-03 PDS COIL FLAG WHICH INCLUDES KB PKR ) IS 9825'. CORRECTION OF 23.5'. PUH TO 9700' CTM, PAINT BLUE FLAG AND POOH. POP OFF WELL AND SECURE W/NIGHT CAP. MU BOT CTC, PULL AND PRESSURE TEST. RD AND SECURE LOCATION FOR NIGHT. 06/09/05 MU BKR IBP. RIH TO FLAG; CORRECT DEPTH. SET IBP AT 9765' CORR CTMD (BETWEEN TBG PUNCH HOLES AT 9500' AND 9816'). PERFORM INJECTIVITY TEST AT 1.1 BPM AND 570 PSI, 1.7 BPM AND 980 PSI, 2.0 BPM AND 1728 PSI. RELEASE IBP AND POOH. 06/10/05 MU BKR CIBP. RIH TO FLAG; CORRECT DEPTH. SET CIBP AT 9765' CORR CTMD (BETWEEN TBG PUNCH HOLES AT 9502' AND 9816'). POOH. MU 2" BDJSN. 06/11/05 KILL WELL WITH 140 BBLS 1% KCL WHILE RIH W/2.0" BDJSN. UNDER BALANCE WELL WITH 62 BBLS DIESEL DOWN BACKSIDE. RIH AND TAG CIBP AND CORRECT DEPTH. PUH TO 9760' AND FLAG PIPE. PERFORM INJECTIVITY TEST AND HAVE 1.0 BPM AT 1750 PSI (W/O DIESEL ON BACKSIDE WOULD BE 1100 PSI). LA YED IN 40 BBLS 15.8 PPG CEMENT WHILE ATTEMPTING TO WORK CEMENT THROUGH TUBING HOLES AND DOWN TO PERFS. ONCE CEMENT REACHED TUBING PUNCH HOLES, WELL LOCKED UP. LAYED IN REMAINING CEMENT, ATTEMPTED TO BULLHEAD WITHOUT SUCCESS. ESTIMATE +/- 1 BBL THROUGH TOP TUBING PUNCH HOLES, PUH TO SAFETY, PRESSURE UP ON CEMENT AND COULD NOT INJECT. CLEANOUT CEMENT DOWN TO CIBP WHILE CONTAMINATING W/1.5# BIO. MADE MULTIPLE JET PASSES FROM 9400' TO CIBP AND CHASED OOH AT 70% WHILE JETTING ALL MANDRELS AND JEWLERY. FREEZE PROTECT TUBING W 50/50 FROM 2500' TO SURFACE. JET TREE AND BOP'S. LEAVE WELL SHUT-IN. JOB IS INCOMPLETE. 06/12/05 DRIFTED W/2.5 DUMMY GUN TO CIBP AT 9748' SLM, NO SAMPLE RECOVERED. 06/14/05 PERFORATED FROM 9656' - 9681' USING 2" HSD 27C UP HMX GUN WITH BIG HOLE CHARGES. DETONATION CONFIRMED AFTER POOH. TO TAGGED AT 9765' ELM. JOB COMPLETE. ) lO 2, - I 0 l- ) Winton We could not establish injection into the tubing punches, so we've perforated at the kick off point. The rig will then set the whipstock and pump cement, planning to squeeze cement best we can into the 3 1/2" x 7" annulus and leave it to swap with the fluid below the whip and above the CIBP. See attached revised sketch... ..Mary 1. 0 Establish injection rate into perfs 6/6/05 200psi at 3bpm 2. E Tubing punch (inclination 70deg) 6/6/05 shot Sf!: 4spf punches 9816-21' and 9502-01' 3. C Set R/IBP; est inj, 6/9/05 set IBP at 9765, 2bpm 1728 psi; set CIBP at 9765' est inj Ibpm, 1100psi; layed in 40bb115.8ppg cmt, locked up; est Ibbl behind pipe, clean out to CIBP. 4. S drift 6/12/05 with dummy gun to crBP 5. E Perforate at KOP 9656' - 81'elm 6/14/05 6. 0 Establish injection rate CTD RIG: Set whipstock at 9656' Pump ~8bbl of 15.8ppg cement (volume depending on injectivity), squeeze into annulus «15-31 Bplanned.ZIP» The present perfs will be isolated by a CIBP and the future liner cement. Thanks, Mary S. Endacott Coil Tubing Drlg Engr 907 -564-4388 741 endacoms@bp.com Content-Description: 15-31 Bplanned.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 15-31 SCANNED JUN 1 7 2005 TREE = WELLHEAD = ÄCTuA rÖR; KB. ELEV = BF. ËLEv ;;;.... KOP= Max Angle = Datum MD = Datum TVD = FMC crvv AXELSON 64.6' 5540' 95 @ 11219' N/A 8800' SS 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 113-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 1 TOP OF 7" LNR 1-1 19-5/8" CSG, 47#, NT-80S, ID = 8.681" 1-1 ) 15 -31 B Proposed CTD Sidetrack . 2926' ~ µ 3540' 8651' -. ~ 8962' ! ~ 8 ~ ¡ PERFORA TlON SUMMA RY REF LOG: SPERRY MWD GR/DENS/NEUT ON 09/27/92 A NGLE A T TOP PERF: 91 @ 10825' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 1-11/16" 4 1 0825 - 11150 isolated proposed 1-11/16" 4 11300 - 11875 isolated proposed 1-11/16" 4 11950 - 12120 isolated proposed 1.56" 6 1 0600 - 1 0640 isolated proposed 1 .56" 6 1 0665 - 1 0685 isolated proposed 2078' I 2926' I ) SAFETY NOTES: I 1- 4-1/2" CA MCO TRDP-4A -SC SSSV NIP, ID = 3.812" 1-1 4-1/2" X 3-1/2" XO 1 GA S LIFT MA NDRELS DEV TYPE VLV LATCH 1 CA-MMG-2 DMY RK 8 CA-MMG-2 DMY RK 28 CA-MMG-2 DMY RK 50 CA-MMG-2 DMY RK 55 CA-MMG-2 DMY RK PORT DATE o 04/17/04 o 04/17/04 o o o L ~ ST MD TVD 1 3188 3188 2 5497 5493 3 6970 6872 4 8377 7984 5 8503 8062 1-1 3-1/2" PARKER SWS NIP,ID= 2.813" l-f 1-1 1-1 3-1/2" X 4-1/2" XO 1 7" X 4-1/2" BAKER SABL-3 PKR 1 4-1/2" X 3-1/2" XO 1 3-1/2" PARKER SWS NIP, ID = 2.813" - Top of 2-3/8" Liner 1 - Top of Cement 1 I 9502 -07 1-1 Tubing PLlnch? 1 I 1 9816-21 9833' 9857' 9863' 9765' q I ~ DA TE REV BY COMMENTS 09/12/03 CMO/TLP DATUM MD & PERF ANGLE/REF 11/29/03 BJIV1cMITLF LNR TOP PKR, TBG ID/BPF 12/04/03 IV1c L/TL P PERFS 04/17/04 JLJ/KAK GLV C/O 06/16/05 MSE PROPOSED CTD SIDETRACK I ~ , 9031' 9050' 9053' 9057' 9071' 9350' 9350' ¡} 1-1 12050' 1 1 ~tt ~»r ',!I~ in \ 9656' - Mechanical Whipstock rT If 9656-81 Perfs 1 ~ni ,.1, ...... ~ ( ITBG PUNCH (05/30/02) 1-1 10000'-10010' 1 1 TOP OF WHIPSTOCK 1-1 10106' 1 13-1/2" TBG, 9.2#, L-80, TDS, 0.00868bpf, ID = 2.990" 1-1 10766' II 11728' I ~ la I .4 12-3/8" TBG, 4.7#, L-80, .00387 bpf, ID = 1.995" 1-1 12178' 1 IT' LNR, 27#, NT-80S, NSCC, 0.0383 bpf, ID = 6.276" 1-1 11084' DATE 10/01/92 09/01/93 06/16/02 06/24/02 08/1 5/02 06/1 3/03 14-1/2" LNR-SL TO, 12.63#, L-80, FL4S, 0.0152 bpf, ID = 3.958" REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVffi JDM/KK CTD SIDETRACK JM/KA K GL V C/O GC/KA K MIN ID CORRECTION CMOITLP KB ELEVATION CORRECTION 1-1 CIBP 1 1-1 Tubing Punch? KB LNR TOP PKR, ID = 1.75" I 3" BKR DEPLOYMENT SLV, ID = 2.700" -I 2-3/4" X 2-3/8" XO, ID = 1.995" 1 PRUDHOE BA Y UNIT WELL: 15-31 B ÆRMIT No: API No: 50-029-22285-02 SEC 22, T11 N, R14E, 4597.85' FEL & 2653.89' FNL BP Exploration (Alaska) tfù"'rr:rr:J, r~"~\ l6..1¡'·r:1l if? · \.i~ !! I' ,1, IU' ~ L, '¡ >;''': [f / /ì \, ¡ f :!' rÚ) u ,Ulj : I Lb ') (n~ :-6'" ¡r;,' i~¡ 1",1 :1 !' \j ¡ .,' ,U'181' II" I ; II I I ' : k I' ,,' 'I , , ! i . I I '; \\ ' I i j ! ) ~ : ,/' II, \. i, ~ t1J LJ iUL\ ~ ) r:-7'"\ " ¡n,.,.¡ '.<:>'1 ¡d ~ \~~ FRANK H. MURKOWSKI, GOVERNOR AItA~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 dvÖ~,.-( ó r Re: Prudhoe Bay 15-31A Sundry Number: 305-134 ,SCJ.\NNED JUN 1 4 20Œ) Dear Ms. Endacott: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd d following the date of this letter, or the next working day if the 23rd day falls on a oli ay or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. DATED thisL day of June, 2005 Ene!. (JJ:¡- (P-I- oS' ) STATE OF ALASKA O~ _}./ -.5- ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 WG¡\- 5/3 t I Z.ðOS· MAY 2 7 Z005 1. Type of Request: 181 Abandon / 0 Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver o Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Alaska Oil & G~s Cons. Commission Anchorage o Other o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current W ~JI Class: iii Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 202-102 /' 6. API Number: /' 50- 029-22285-01-00 99519-6612 64.6' 9. Well Name and Number: 15-31A / 8. Property Designation: 11. Total Depth MD (ft): 12214 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION· SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 8786 12140 8783 None Length Size MD TVD Burst Junk (measured): None Collapse ADL 028306 Liner 110' 20" 110' 110' 1530 520 3488' 13-3/8" 3524' 3524' 4930 2270 8920' 9-5/8" 8952' 8324' 6870 4760 1468' 7" 8651' -10119' 8148' - 8762' 7240 5410 2344' 2-3/8" 9834' - 12178' 8685' - 8785' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 10600' - 12120' 8814' - 8782' 4-1/2", 12.6# x 3-1/2" 9.2# Packers and SSSV Type: 7" x 4-1/2" Baker 'SABL-3' packer; 4-1/2" Camco 'TRDP-4A-SC' SSSV Nipple Tubing Grade: L-80 Packers and SSSV MD (ft): 9053' 2078' Tubing MD (ft): 10119' 12. Attachments: iii Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: June 2, 2005 16. Verbal Approval: Date: Commission Representative:,. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer Signature -r;IÂ~ 13. Well Class after proposed work: / D Exploratory iii Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ iii Abandoned D WDSPL Contact Mary Endacott, 564-4388 Phone 564-4388 Commission Use Only -/ 7 i Prepared By Name/Number: Date 5¡ 27;66 Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3oS-:-/3l.f D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: RBDMS 8FL JUN 0 G 2005 "1. COMMISSIONER APPROVED BY THE COMMISSION Date ~~c "-- ORIGINAL ) ) Ip To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: March 27, 2005 Re: P&A operations for well 15-31A as part of the CTD sidetrack Well 15-31A is a candidate for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, 15-31B, will exit the 3-1/2" tubing off a whipstock and target Zone 1. The proposed kick off point is above the existing perforations, which will be isolated by a cement plug. The following describes work planned for the P&A and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) Establish mechanical integrit~ MIT-IA and MIT-O~.5/-~/05É-- p~ Lit. ~ 2) Service coil tubing punch, ser,'ánd downsqueeze w'}(2~6115.8ppg cement "... C ,/ The pre CTD work is slated to begin on 6/2/05. -- Nordic 1 will set the whipstock. Expected spud date is June 13th. '.. 'I. It LJ" 'i\< ~. l .' r-'pcì ~ k1 ¿;A- '1IJ~~ Mary E¿dacott CTD Drilling Engineer 564-4388 CC: Well File Sondra Stewmanrrerrie Hubble -) TREE =' I' WELLHEAD = ACfU6. TOR = KB. EL8I =' B F~ ELEV ;;;" KoP=' MaxA.~.~ e = Datum MO = DatumTVD = FMC CrN AXELSON 64.6' 5540' 95($11219' N/A 8800' SS 14-112" TBG, 12.6#,L-80, .0152 bpf, 0 = 3.958" H 2926' 113-318" CSG, 68#, L-BO, ID = 12.415" H 3540' 1 TOPOF 7" LNR H 8651' 19-5/8" CSG,47#, NT-80S,10 =8.681" H 8962' Minimum ID = 1.75" @ 9853' KB LNR TOP PKR SEAL UNIT ITBG PUNCH (05/30/02) 1-110000'-10010' ~ TOP OF WHIPSTOCK 1-1 101 06' ~ OBP(05/28/02) 1-1 10150' 1 PERFORA llON SUv1Ml\RY REF LOG: SPffiRY MND GRlDENSlNBJT ON 09/27/92 ANGlE AT TOPPffiF: 91 @ 10825' Note: Refer to Production æ for historical perf data SIZE SPF INTERVAL OpnlSqz [)6.TE 1-11/16" 4 10825 - 11150 0 06115/02 1-11/16" 4 11300-11875 0 06115/02 1-11/16" 4 11950-12120 0 06115/02 1.56" 6 10600 -10640 0 12/04/03 1.56" 6 10665 - 10685 0 12/04/03 17' LNR, 27#, NT-80s, ,0383 bpf, ID = 6.276" H 11084' 14-1/2" Lt-.R, 12.63", L-BO, .0152 bpf, 0 = 3.958" H 11728' [)6. TE 10101$2 09101$3 06/16102 06124~2 08/15~2 06113A:>3 REV BY CO~ENTS ORIGINAL COM PLETION LAST WORKOVER J[N/I<K CTD SIDETRACK JM'KAK GL V ClO GClKAK MIN ID CO~S:::TION CWOIllP KB ELEV ATION OORRECTION DA TE ~ BY 00 MrvENTS 09112/03 CMO'TLP [)6. TUv1 MD & ÆRF A ~LElRS= 11/29103 3..1v1cfWTLF LNR TOP P\<R, lBG IDSPF 12/04103 WcLfTLP ÆRFS 04117/04 ..LJ/KAK GLV C/O PRLDkOE BAY U'JrT WELL: 15-31 A PffiMT!\b: 2021020 API!\b: 50-029-22285-01 SEC 22, T11 N. R14E, 4597.85' FEL & 2653.89' FNL ) 15-31 A SAFETY NOTES: ~ µ 2078' - 4-112" CAMOO lRDP-4A-SC <II> SSSV NP, ID = 3.812" ~ 2926' H 4-112" X 3-1/2" xo 1 GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 3188 3188 1 CA-~G-2 DMY RK 0 04/17/04 L 2 5497 5493 8 CA-~G-2 DMY RK 0 04/17/04 3 6970 6872 28 CA-~G-2 DMY RK 0 ± 4 8377 7984 50 CA-~G-2 DMY RK 0 5 8503 8062 55 CA-~G-2 DMY RK 0 rr.~ ~ ~ 1-1 r , 9031' 3-1/2" PARKERSWS NIP, 0=2,813" 9050' H 3-1/2" X4-1/2" XO I ~ ~ 9053' H 7" X 4-112" BAKERSABL-3 PKR I " ¡ 9057' 1-1 4-1/2" X 3-1/2" XO 1 9071' H 3-1/2" PARKER SWS NIP, 0 = 2.813" :81 ~ 9833' l-f KB LNR TOP PKR, 10 = 1.75" 1 9857' H 3" BKR DEPLOYMENTSLV, 10= 2,700" 9863' 1-1 2-3/4" X 2-318" XO, ID = 1,995" I 10725' H 10771' H ~ .. 12-3/8" TBG, 4.7#, L-80, ,00387 bpf, 10= 1,995" H 12178' I BP Exploration (Alaska) TREE = WElLH'ÉI\O = ACTUA TOR = ( KB. 8...EV = BF. 8...EV = KOP= Max Angle = Datum MO = Datum TVO = FMC CrN AXa.SON 64.6' ) 1 5 -31 B /' Proposed CTD Sidetrack 5540' 95 @ 11219' NIA 8800' SS ) SAÆTY NOTES: 2078' 1- 4-1/2" CAMCO TRDP-4A-SC . SSSV NIP, 10 = 3.812" I 2926' 1-1 4-1/2" x 3-1/2" XO 1 GAS LIFT MANOR8...S ~'ST MO TVO OEV TYÆ VLV LA TCH PORT DATE 1 3188 3188 1 CA-MMG-2 OMY RK 0 04/17/0 L 2 5497 5493 8 CA-MMG-2 OMY RK 0 04/17/0 3 6970 6872 28 CA-MMG-2 OMY RK 0 J 4 8377 7984 50 CA-MMG-2 OMY RK 0 iii 5 8503 8062 55 CA-MMG-2 OMY RK 0 .. " 14-1/2" TBG, 12.6#, L-80, .0152 bpf, to = 3.958" 1-1 2926' I r 113-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 3540' µ I TOP OF 7" LNR 1-1 8651' 19-5/8" CSG, 47#, NT-80S, 10 = 8.681" 1-1 8962' ~ , ÆRFORA TION SUMMARY REF LOG: SÆRRY MlNO GRlOENS/NBJT ON 09/27/92 ANGLE AT TOPÆRF: 91 @ 10825' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 1-11/16" 4 10825 - 11150 isolated proposed 1-11116" 4 11300 - 11875 isolated proposed 1-11116" 4 11950 - 12120 isolated proposed 1.56" 6 10600 - 10640 isolated proposed 1,56" 6 10665 - 10685 isolated proposed ITBG PUNCH (05/30/02) 1-1 10000'-10010' 1 I TOP OF WHIPSTOCK 1-1 10106' 1 3-1/2"TBG, 9.2#, L-80, IDS, 10=2.990" 1-1 10766' I 12-3/8" TBG, 4.7#, L-80, .00387 bpf, to = 1.995" 1-1 12178' 1 17" LNR 27#, NT-80S, NSCC, 0.0383 bpf, ID = 6.276" 1-1 11084' [4-1/2" LNR-SL ID, 12.63#, L-80, 1-1 11728' 1 FL4S, 0.0152 bpf, ID = 3.958" I DATE 10/01/92 09/01/93 06/16/02 06/24/02 08/15/02 06/13/03 REV BY COWMNrS ORIGINAL COM PLETION LAST WORKOVER JDM/KK CTD SIDETRACK JM'KAK GLV C/O GC/KAK MIN ID CORRECTK:>N CMOITLP KB 8...EV A TION CORRECTION DA TE REV BY COWMENTS 09/12/03 CMOITLP DATUM MD & PERF ANGL6'REF 11/29/03 BJM:M'11.PLNR TOP A<R, TBG IDt'BPF 12/04/03 M:UTlP PERFS 04/17/04 JLJ/KAK GLV C/O OS/27/05 MSE PROPOSED ern SÐETRACK Ij I .. ~ ~ 8 \ ¡ ----- 'c:J . ~ 9031' 9050' 9053' 9057' 9071 ' 9100' 9100' 9150' 9650' I I 9775' 9825' 9833' 9857' 9863' 1-1 3-1/2" PA RKER SWS NIP, 10 = 2,813" 1-1 3-1/2" X 4-1/2" XO 1 1-1 7" X 4-1/2" BAKER SABL-3 PKR 1 1-1 4-1/2" X 3-1/2" XO 1 3-1/2" PARKERSWS NIP, 10= 2.813" - Top of 2-3/8" Liner - Top of Cement - Tubing Punch ~. IJ 1-1 12050' c::=:J--C:::J 1-1 Mechanical Whipstock 1-1 CIBP 1-1 Tubing Punch ¥6 I I- q1r-O 1 9 f¿l,\-'/ KB LNR TOP PKR. ID = 1.75" 1 3" BKR DEA..OYMENT SLV, 10 = 2.700" 2-3/4" X 2-3/8" XO, ID = 1.995" 1 / PRUDHOE BA Y UNIT W8...L: 15-31 B ÆRMIT No: API No: 50-029-22285-02 see 22, T11N, R14E, 4597.85' F8... & 2653.89' FN BP Exploration (Alaska) Date: To: Prom: Subjeet: ) ) May 31,2005 Pile Jane Williamson Prudhoe Well 15-31A- Plug Baek in Preparation for SIT ~.;.. ··O:,...~·· ...."'0:-:. t···,,{),,·,··61- ·:\¡,:~I"I.' . ~ L'I'II\ Attaehed are plots of pro duet ion history and decline analysis for the subjeet well. The well has been SI sinee early this year. Last stable produetion was at around 500-600 BPD at a GOR of 45,000 scf/STB. At this high GOR, the produetion is likely nearly all condensate. I projeet roughly 140 MSTB remaining reserves if a limiting GOR of80 MSCP/STB is used (roughly 250 BPD end rate). The applieation eontents were poor. It's not clear whether the sidetraek is to Ivishak or Sag. The reasons for SIT were not stated. However, as there are few reserves remaining, and likely surrounding well will drain the small amount of oil and eondensate, I reeommend approval of this sundry. I've requested additional information for the reeord from Leslie Senden and I'll add to the file when I reeeive it. Oil Rate (CD) ( Mbblld ) Water Rate (CD) ( Mbblld ) Water I nj Rate (CD) ( MbbVd ) Gas Rate (CD) ( MMcf/d ) Gas Inj Rate (CD) ( MMcf/d ) Gas I Oil Ratio ( Mcf/bbl ) Water Cut Oil Rate (PO) ( Mbblld ) Gas Rate (PO) ( MMcf/d ) I 05 _-/m -~~--- v (1) -f- --. _u_~ Da:e I 04 I 2002 I 03 0.01 0.05 - 0.1- ~ 0.5 - 1- f 5- u>__ \~_~j_. ._ _.. .1_2"-_-'_- _- _mmm .:_ .- .,.- ..,..- .- .:;.! y:m i mnm_nL 1 50 ------- - 10- _-+___m 100 PRUDHOE BAY, PRUDHOE OIL PRUDHOE BAY PBU_DS15 15-31A " 1??oo 5000 --- '-' 750 600 Phase : Oi I Case Nane : Case1 b : 1 Di : 0_382493 Ae. q i : 391.329 bbI/d ti : 0513112005 te : 0813112006 End Rate : 250 bbI/d Final Rate : 244.099 bbI/d Cun Prcx:l. : 493.401 MbbI Cun Date : 03131/2005 Resen.es : 139.941 MbbI EUR : 633.342 MbbI Forecast Ended By : Rate Forecast Date : 450 CLI'll Oi I Prcx:l, M bbI 300 I 150 o "0 = .c .c Q- e:.. 1000- Q) ro a::: ð 500 - 100 f~ ~~~ À~~i DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 ¥~ (tJJ~),.c'-G ').- API No. 50-029-22285-01-00 Permit to Drill 2021020 Well Name/No. PRUDHOE BAY UNIT 15-31A Operator BP EXPLORATION (ALASKA) INC ---- MD 12214 ~ TVD 8786 ~ Completion Date 6/16/2002 ,-- Completion Status 1-01L UIC N --------- Current Status 1-01L REQUIRED INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~g --- +-t-og ~- - ---- - ----- DATA INFORMATION .bPg Log ~C ~ . Rpt ~C ~D ¡ Log ¡ ¡Log ! i Log I! Log r : / (/r! Log ¡,i ED D Ii ED D ii ED D Ii ED D I I \1 ED D ~ ~D -- -. ------ Mud Log No Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 25 Blu 1 25 Blu 25 Blu 25 Blu 25 Blu Interval OH/ ~ Start Stop CH Received Comments ----9ß83 12137 Case 1 0/14/2002 10119 12209 Open 11/6/2002 10119 12214 Open 7/19/2002 ~683 12137 Case 1 0/14/2002 10119 12209 Open 11/6/2002 --9690 12138 Case 10/14/2002 ~683 12137 Case 1 0/14/2002 10119 12209 Open 11/6/2002 10119 12209 Open 11/6/2002 10119 12214 Open 7/19/2002 19820 12120 Case 10/6/2003 Blueline Culled, Mylar Filed I 9820 12120 Case 10/6/2003 Blueline Culled, Mylar Filed 9820 12120 Case 10/6/2003 Blueline Culled, Mylar Filed ~;= ) 9820 12120 Case 10/6/2003 Blueline Culled, Mylar Filed J-420 12120 Case 10/6/2003 Blueline Culled, Mylar Filed 9820 12120 Case 10/6/2003 4 Zipped LAS files on disk 9820 12120 Case 10/6/2003 4 Zipped LAS files on disk 9820 12120 Case 10/6/2003 4 Zipped LAS files on disk \ 9820 12120 Case 10/6/2003 4 Zipped LAS files on disk ~820 12120 Case 10/6/2003 4 Zipped LAS files on disk 9717 1 0549 Case 1/20/2004 Direction.alSuïVéY o--eâsingcol!;:1rJÒþÇit()f Gamma Ray L---1Í176 Neutron ~amma.Ray LIS Verificatiol1 11272 LIS Directional~uïV~Y BM BM BM BM BM Las Las Las Las Las Las Casing collar locator 12177 Production 12177 Pressure 12177 Temperature 12177 Spinner 12177 Casingcollar()çøtè)f 12366 Casingcollarlocªtþt DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2021020 Well Name/No. PRUDHOE BAY UNIT 15-31A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22285-01-00 MD 12214 TVO 8786 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? y ,Ð Chips Received? ,_ Y / N Analysis Received? ~ ------- --.- ~._----- -~-- ~- Comments: ----- -_._---~ --------~----- Compliance Reviewed By: Completion Date 6/16/2002 Completion Status 1-01L \L J Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L UIC N Sample Set Number Comments ~ WN ~ Date: '}( ~t-)Ò\) '\' ~ Form Garry Catron Garry Catron J1CiAM{ 0-404 Revised 1~/2003 OR GlNAL Signature Ca~'Ö' Phone 564-4657 Date 3/10/04 Contact Printed Name Title Production Technical Assistant Daily Report of 17. Well Operations hereby certify that the foregoing X is true and correct to the best of my knowledge. GasD WAG D GINJD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A N/A if C.O. Exempt: OilŒJ Operational Shutdown 0 WINJD WDSPLD Copies of Logs and Surveys run 6. Well Status after proposed work: Well Class after proposed work: Exploratory 0 Development[! Service D 4. Attachments: 5. Subsequent to operation: Prior to well operation: 657 Oil-Bbl 580 24.7 final pressure: Representative Daily Average Production or Gas-Met Water-Bbl 24.1 3 6 1000 Iniection Data Casing Pressure 1170 915 Tubing Pressure 961 3 2. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and ¡ø)IiIS BfL WI Packers & SSSV type & measured depth): 4-112" 12.6# l 3-1/2" 9.3# L· 4-112" 12.6# l 3-1/2" 9.3# L· 3-112" Baker 4-1/2" Baker SA~ 7" Baker H Packer II .~ ',,:jj' :Ji', 1 1 20\1\ KB Liner Top Packer rSL-3 Packer @ @ @ 9053 8~ C~m r; f !~,~~on @ @ @ @ 30 2926 9050 9057 2926 9050 9057 10106 9833 'lïAR 1 0 200 (,,, . '~'" t, \/E: Tubing size, grade, and measured depth): True vertical depth: 8813.55 8817.13,8819.01 8819.96, 8819.87 - 8808.62, 8798.55 8786.02, 8782.34 - 8782.39 Production Surface Perforation depth: Measured depth: 10600 Liner Liner Liner Casing Conductor Length 80 1455 30 2315 8930 3504 10640, 10665 Size 20" 91.5# H-40 7" 26# NT80S 3-112" 9.3# L-80 2-3/8" 4.7# L-80 9-5/8" 47# NT80S 13-3/8" 68# L-80 10685, 10825 - 11150, 11300 -11875, 37 8651 9833 9863 32 36 TVD 117 37.0 10106 8148.4 9863 8684.2 12178 8693.6 8962 32.0 3540 36.0 11950 -12120 117.0 8759.2 8693.6 8784.7 8329.3 3539.5 Burst 1490 7240 10160 11200 6870 4930 Collapse 470 5410 10530 11780 4760 2270 MD true vertical 8782.9 feet Effective Depth measured 12140 feet Junk (measured) None true vertical 8785.9 feet Plugs (measured) None Total Depth measured 12214 feet 64.60 8. Property Designation: ADL-0028306 Well 11 Present Condition Summary: O. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation Stratigraphic D 9. Well Name and Number: 15-31A Exploratory D Service D 6. API Number 50-029-22285-01-00 3. 2. Operator Name: Address: Development ŒJ BP Exploration (Alaska), Inc. Operations Performed: Abandon D Alter Casing D Change Approved Program D SuspendD RepairWellD Pull Tubing D 4. Current Well Class: Operation Shutdown 0 Plug Perforations D D Perforate New Pool Re-enter Stimulate iii D WaiverD Time Extension D Suspended WellD 5. Permit to Drill Number: 202-1020 Perforate OtherD REPORT OF SUNDRY WELL OPERATIONS ") STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION cOfv....isSION BBLS 179 158 337 60/40 Methonal 1 % KCL TOTAL Page FLUIDS PUMPED 12/02/03 MIRU, MU PDS 1-11/16" MEM GR/CCL, KNOCK WHP DOWN AND RIH. 12/03/03 CONTINUE RIH TO 11,0001 W/1-11/16" PDS TOOLS FOR COIL FLAG. LOG UP FROM 11,0001 AND FLAG COIL AT 10,5301 CTMD, LOG UP TO 97001, AND POOH. TIE IN TO SWS M CNL/GR/CCL 15-JUN-2002 WITH A + 19.51 CORRECTION. MU SLB 1.56" 00 X 20' 6 SPF 1606 PJ RANDOM ORIENTATION, 60 DEG PHASING, PERF GUNS. KNOCK WHP DOWN AND RIH WITH GUN # 1 (201) PERF INTERVAL 106651 -106851. RIH WITH GUN # 2 (201) PERF INTERVAL 106201 -106401. POH. ALL SHOTS FIRED. MU AND RIH WITH GUN #3 (201). JOB IN PROGRESS. 12/04/03 Perforate 106001-106401 6 SPF 15-31 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ) ) DA. TE 10/01192 09/01193 06/16/02 06f24IU2 08/15IU2 06/13IU3 COl'vllllf3\JTS ORIGINAL COM PLErION LAST WORKOVER JDM/KK CTD SIDETRACK JM'KAK GL V 00 GOKAK MIN ID CORRECTION CWIOIlLP KB EL BI A TION CORRECTION REV BY DA TE REV BY CO Mtv'ENTS 09112/03 Ov101TLP DA. TUv1 MD & ÆRF A I\G LEJ REF 11/29/03 BJMcM'TLf LNRTOPPKR, lEG IDßPF 12/04/03 I'v'cLffLP ÆRFS SEC 22, T1 BP Exploration (Alas ka) PRLO-()E BAY lJ'JrT WELL: 15-31A PffiMT f\b: 2021020 API f\b: 50-029-22285-01 N, R14E, 4597.85' ÆL & 2653.89' FNL 4-1/2" LNR, 7' LNR, 27#, NT-80s, .0383 Note: SIZE 1-11/16" 1-11/16" 1-11/16" 1.56" 1.56" REF LOG: ANGLE AT TOPPffiF: 91 @ 10825' Refer to Production 00 for historical perf data SPF INTERVAL Opn/Sqz DA. TE 4 10825 - 11150 0 06115102 4 11300-11875 0 06115102 4 11950 - 12120 0 06115102 6 10600 - 10640 0 12/04103 6 10665 - 10685 0 12/04103 PERFORA 1l0N SUMMA..RY SPffiRY MNDGRlDf3\JSlNBJT ON 09/27/92 aBP (05/28/02) TOP OF WHIPSTOCK 10106' ~ 2-3/8" TBG, 4.7#, L-80, .00387 bpf, ID = 1.995" H 12178' 12.63", L-80 .0152 bpf bpf, ID = 6.276" D = 3.958" H H 11728' 11084' .4 10725' 10771' H H aBP TIW ss PKR H PBTD 1-1 1-1 10150' 2078' ~ 4-1/2" CAMCO 1RŒ>-4A-SC SSSV NP, ID = 3.812" 2926' l-i 4-1/2" X3-1/2"XO I GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 31 88 3188 1 CA-I'vIv'IG-2 DOIvE RK 16 06/24/02 2 5497 5493 8 CA-I'vIIIIG-2 SO RK 20 06124/02 3 6970 6872 28 CA-I'vIIIIG-2 RK I 4 8377 7984 50 CA-I'vIIIIG-2 RK 5 8503 8062 55 CA-tv'MG-2 RKP ~ 1 9031' l-i 3-1/2" PARKERSWS NIP, D =2.813" 1 9050' 1-1 3-1/2" X4-1/2" XO 1 1 9053' 1-1 7" X 4-112" BAKERSABL-3 PKR I 9057' H 4-1/2" X 3-1/2" xo 1 9071' H 3-1/2" PARKERSWS NIP, D =2.813" 9833' l-i KB LNR TOP PKR, ID = 1.75" 1 9857' l-i 3" BKR DEPLOYMf3\JT SLY, ID = 2.700" TBG PLNCH Minimum ID = 1.75" @ 9853' KB LNR TOP PKR SEAL UNIT 9-5/8" 4-1/2" lEG, 12.6#, L-80, .0152 bpf, D =3.958" 1-1 2926' ~ 13-3/8" CSG, 68#, L-80, ID = 12.415" H 3540' µ CSG, 47#, NT-80S, ID = 8.681 (05/30/02) TOPOF7"LNR 1-1 1-1 1 0000'·1001 0' 1-1 8962' 8651 L 1 .. r , ~ ~ ¡ 81 ~ 9863' l-i 2-3/4" X 2-3/8" XO, ID = .995" 5540' ..-....... . ..... -...-...... M.~ ~.~.9 ~ ~ ..~.?.~.~._1.?..~..~~, Datum MD = N/A Datum TVD = 8800' SS - / TREE = WELLHEAD = XCfCiÄfoR";;; ï<ä···ËLEV···=·..·· 'ï§ï=:..ËLE\i"; m 'KOÞ·; . FMC CIW "AXËLSÖN ······è4jf ) 15-31 A ') I SAÆ1Y NOTES: ~~\"<\.~ PRoACTivE DiAGNOSTic SERviCES, INC., PO Box 1 ~69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ÄJ2ska on & Gas Cons, Commisskm Anchorage Print Name: Signed ~~\~\L ,~~ ("-~ ~ J:- rY\ I ~' Date: RECEIVEtI ?n '- ~- ~"" ~ (,VVl.T os 1 5-31 A 1 2-03-03 Caliper Survey Mech. CH 1 /):)<:~ (o&; Res. Eva!. CH 1 1 1 WELL DATE LOG TVPE Open Hole DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 1 BLUE LINE PRINT(S) REPORT OR COLOR Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BPExploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 The technical data listed below is being submitted herewith this transmittal letter to the attention of : Final Print( s J Please acknowledge receipt by returning a signed copy of RE Distribution State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage. Alaska 99501 To: ProActive Diagnostic Services, 'nc. WELL LOG TRANSMJIIAL ) ~ ðd- '- c)'~ Phone:(281) 565-9085 Fax:(281) 565-1369 ~~~~~ PRoAcTivE DiAGNOSTic SERVicES, INC. E-mail: PO Box pds@memorylog.com ~69 STAFFoRd ~~:~:~~ ~:;c:n~~,~~U{~1!1Ü85tOn Amt¡On~g~; Website: TX 77477 www.memorylog.com Signed ..-~\~ I;:. /'i::~"-~ "i-" -~/V"\.. Print Name: ,~\~¡~;¡~:8 ,: OCT 06 Date ~~~1. ft:::' ~2 G~; ~:~ ,,...~ r' ,\. f ~~"~ D>..·~ \ ¡f . š1w". ~. ~.- ~ \,'g(}1' ~,!I t ~~ ~ ~' 1 5-31 A 08-07-03 WELL DATE LOG TYPE Open Hole Res. Eva!. CH Mech. CH Caliper Survey 1 1 IB 11::r 1 1 DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 1 BLUE LINE PRINT(S) REPORT OR COLOR Joey Burton / Jeni Thompson ProActive Diagnostic Services, P. O. Box 1389 Stafford, TX 77497 Inc. BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 9S508 The technical data listed below is being submitted herewith this transmittal letter to the attention of : Final Print( s) Please acknowledge receipt by returning a signed copy of RE Distribution State of Alaska AOGCC 333 W. 7th Street Suite # 700 Anchorage, Alaska 99501 To: ProActive Diagnostic Services, 'nc. ( WELL LOG TRANSMIIIAL ') ) ß1Œ o~ aker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECE\VED ---" NOV 06 2002 Alask8 or. & Gas Cons. Commiaeion And1cnge - .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 B Received B (~~ Date: N ov 4, 2002 Date: Sent By: Glen Horel LAC Job#: 280415 -_..__._-_.~~-----~~-------_.__.~...__."~-_. ,_"'~_'__~_"_'N'____"'_~'_'_'__'_____'___" 1 1 blue line - GR/Directional blueline - GR/Directional Measured Depth Log TVD Log '&1. [r~~~~~~;~'~'~~T:;:~--1 BAKER_,~ _, .., ,. nw. HUGHES ¡:~ ..."",,~ ., ~w~ Anchorage GEOScience Center ~~~::-~~~~;-~ê---:---~:; :~N 1 1 LDWG Compact Disc (Includes Graphic Image files) LDWG lister summary Contains the following: "J!:-:"'~ Reference: ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie 15-31A ì~ aoa-JO-~ Ild-¡~ Schlullnrgel' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well L-105 d.OÃ.-D~~ V-104 ~~a... r~ ~ D.S.15-31A O~.J Dd. C-25A Jq _ -OJI Job# Log Description SBHP SURVEY SBHP SURVEY 22231 D.S.15·31A 22234 C-25A PLEASE ACKNOWlEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploralion (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508·4254 Date Delivered: RECEIVED OCT 1 4 2002 Alaska or; & Gas Cons. Cornm\ukm Anchorage 09/22/02 09/23/02 06/15/02 07/10102 10/07/02 NO. 2472 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P.Bay Date Color CD Sepia BL .~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Rt)~~LÝOO~' Form 10-407 Rev. 07-01-80 OD~h f\ ~ -~,J ~\{ -!~ L RBnll~ DC" r JUL t~nGhoraqe 29 200fubmit In Duplicate "" ,~ Glv P~J1{;1s:(a u n ',," ~~ LOÚ¡¡n¡Ss¡o No core samples were taken. Brief description of ithology, porosity, :' !¡ CORE DATA ."., _,,_ fractures, apparent dips and presence of oil, gas or water. Submit cor~~hiJ:s ,,'J ":, ,-~ ',,) (-¡ ri 1-' ;-~ / ¡ i ~ . ,,..1 ~.......W '..' :..,. l :1 10::- ~ :~¡ Flow Tubing Press. 28. CALCULATED 24-HoUR RATE Oll-Bsl 2749 Oll-Bsl GAs-McF 15227 GAs-McF WATER-Bsl -0- WATER-Bsl CHOKE SIZE I GAS-all RATIO 114 5538 Oil GRAVITY-API (CORR) Date of Test 7/8/2002 .56" MD 10825'-11150' 11300' -11875' 11950' - 12120' 4 spf TVD 8820' - 8809' 8799' - 8786' 8782' - 8782' PRODUCTION FOR TEST PERIOD PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing DEPTH INTERVAL 2000' 26. SIZE 4-1/2", 12.6#, L-80 x 3-1/211, 9.2#, L-80 ACID, FRACTURE, (MD) CEMENT SaUEEZE, ETC. AMOUNT & KIND OF MATERIAL USED Freeze Protected with 60/40 MeOH MD 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Gun Diameter, TVD TUSING RECORD DEPTH SET (MD) 10119' PACKER SET (MD) 9053' 23. CASING SIZE 2011 13-3/811 9-51811 711 2-3/811 Wr. PER FT. 94.5# 68# 47# 26# 4.7# GRADE H-40 L-80 NT80S NT80S L-80 25. CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 3011 36' 3524' 1611 32' 8952' 12-1/411 8651' 10119' 8-1/211 9834' 12178' 311 CEMENTING RECORD 2000# Coldset II 2554 cu ft CS III, 460 cu ft Class 'G' 1644 cu ft Class 'G', 506 cu ft 'G' 493 cu ft Class 'G' 112 cu ft Class 'G' AMOUNT PUllED in feet RKB = 64.6' ADL 028306 Date Spudded 113. Date T.D. Reached 114. Date Camp., Susp., or Aband. 6/10/2002 6/13/2002 6/16/2002 17. Total Depth (MD+ TVD) 118. Plug Back Depth (MD+ TVD) 12214 8786 FT 12140 8783 FT 22. Type Electric or Other Logs Run MWD, ROP, GR, Memory CNL, CCL if offshore NI A MSL Depth where SSSV setl21 (Nipple) 2078' MD 12. 19. Directional Survey aVes 0 No 115. 20 Water depth, 1 Thickness of Permafrost 1900' (Approx.) 16. No. of Completions One 27. Date First Production June 29, 2002 Hours Tested 3.1 Casing Pressure 5. 4. 196612, Anchorage, Alaska Location of well at surface 1937' SNL, 1438' EWL, SEC. 22, T11 At top of productive interval 2454' SNL, 4415' EWL, SEC. 22, T11 At total depth 1061' SNL, 4870' EWL, SEC. 22, T11 Elevation ~r..'C.OM. PLET~O. N, DATE " .' ',It: .'>2.- ~. lED N, R14E, UM ì:";;::,~:':v.,.,.. (indicate KB, DF, etc.) 6. Lease Designation and Serial No. N, R14E, UM N, R14E, UM a-.. """"'-11'\0 .IV~, .¡~~'~.i J;;'~' \:~. - '. ' ' ~ r~, ~~ ça... ",._,,~ ¡"", ~ì,~~.~-'''''''''; 11 10. 9. Field and Pool Prudhoe Bay Field API Number 50- 029-22285-01 Unit or Lease Name Prudhoe Bay Unit Well Number Prudhoe Bay Pool 15·31A 3. Address P.O. Box 99519-6612 8. 2. Name, of Operator BP Exploration (Alaska) Inc. Status of Well a Oil 0 Gas o Suspended o Abandoned o Service 7. Permit Number 202-102 Classification of Service Well ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Rev. 07-01-80 o· [) ¡ ß '\ "-' --- ~ .A ~ I:\~ i --.-- r: ~ ~ .. lJ~,) ii.- ~....../ ¡ ¡.; \ ¡ L 11...__ ITEM 28: If no cores taken, indicate 'none' ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. 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 21 Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM producing pertinent to such interval. 16 AND 24: If this well is completed for separate production intervals for only the interval reported in item 27. Submit from more than one interval (multiple completion), so state in item 16, and in item 24 show the a separate form for each additional interval to be separately produced, showing the data 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 Classification of Service Wells: injection for in-situ combustion. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, 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. Signed Permit No. that the foregoing is true and correct to Terrie Hubble ~ ~ 202-102 15-31 A Well Number INSTRUCTIONS Approval No. Technical Assistant Title Prepared By Name/Number: Date Terrie Hubble, 564-4628 07· ^3·D~ 32. hereby certify the best of my knowledge Summary of Daily Drilling Reports, Surveys 31 List of Attachments: ¡,~nGhOraç8 A!a~3IŒ c 8~ SS~(jJr~ IE ". 'j W"" liC'" ~~~ TDF 10640' 8817' Zone 1 B 10167' Measured Depth 8774' True Vertical Depth 29. Marker Name Geologic Markers ) Include interval tested, pressure data, all gravity, GOR, and time of each phase. 30. fluids recovered and Formation Tests ') 6/8/2002 23:30 00:00 02:30 23:00 00:00 02:30 04:00 23:30 0.50 CLEAN P 2.50 CLEAN P 1.50 S1WHIP P 0.50 CLEAN P DECOMP DECOMP WEXIT DECOMP Printed: swap. Stand back injector, LD cement milling BHA #1 Prepare for reel swap, unstab CT from injector, spool downhole end of CT over gooseneck and secure onto reel. Crane arrived on location at 21 :15 and began rigging up. SAFETY MEETING with Peak Crane operators. Emphasized good communication and the ability for anyone involved to halt the operation while swapping reels. Crane operations, swapping reels. Coninue swapping reels. PU injector. Stab CT into injector, RU hardlines in reel house, establish eline connection at bulkhead on reel outlet. Prep for 6/17/2002 11:31:32 AM Tag cement at 9780 ft. cement. 3000# WOB, cement at 9852 ft. Tag cement again at 9885 ft. at 9896 ft. Ream in hole. Mill hard cement at 9948 ft. Mill Short trip to 9760 ft. Clean trip. Mill cement. Mill at 30 fph, 1500 # WOB, 2200-2400 psi. Milled to 9916 ft. Mill cement. Mill at 40 fph, 2500 # WOB, 2200-2600 psi. Milled to 10,075 ft. Mill cement. Mill at 40 fph, 2500 # WOB, 2200-2600 psi. Drilled cement to 10,114' CTD. Tagged Whipstock. 30 bbl high vis pill. Back reamed cemented interval. Clean hole. POH with milling BHA #1. Swap coil fluid to rig water, reel swap. OOH, SAFETY MEETING: 20:00 20:30 20:30 23:00 0.50 CLEAN 2.50 CLEAN P P DECOMP DECOMP 19:45 8:00 20:00 9:45 0.25 CLEAN .75 CLEAN P P DECOMP DECOMP LD milling bha and prep for reel prior to Circulated 6:45 8:00 .25 CLEAN P DECOMP .7 I 1 .7 bpm, 4:30 12:30 6:45 14:30 2.25 CLEAN 2.00 CLEAN P P DECOMP DECOMP to 9960 ft. .7 .7 /1 I 1 .7 bpm .7 bpm, 11 :00 2:30 .50 CLEAN P DECOMP Mill cement at 60 fph no cement 6/7/2002 09:00 21 :05 - 21 :40 21:40-23:15 23: 15 - 00:00 00:00 - 04:35 07:15 04:35 04:55 11 :00 09:00 04:55 07:15 2.00 CLEAN 0.58 RIGU P 1.58 RIGU P 0.75 BOPSURP 4.58 BOPSUR P 0.33 2.33 .75 CLEAN CLEAN CLEAN P P P P DECOMP Replace radiator on Gen 1. Spot Tiger and slop tanks. PRE SAFETY MEETING prior to backing CTD rig over the well. Reviewed procedure, hazards and responsibilties. Emphasized good communication and clear directions over the radios. PRE Position rig over wellhead. PRE NU, rig up hardlines. DECOMP BOP test, witness waived by Jeff Jones. DECOMP Continue BOPE test, waived by Jeff Jones. Send test report to AOGCC. DECOMP Pre Job Safety Meeting. Emphasizing well hazards DECaMP RU Injector over wellhead, MU Milling assembly BHA #1. 2.125" motor and 2.80" HC D331 Mill #1. DECOMP RIH with Milling BHA #1. Load 2# Biozan water to drill cement. Milling cement at 60 fph, 1.5/1.5 bpm, 2300 psi. Firm, solid Drilled out of 20:55 21:05 0.17 MOB P Rig positioned in front of well. Found 250psi on flowline. Wait for pad operator/DSM to bleed down flowline/S-riser to zero psi, service lateral valve (Grove valve) and wing valve. 6/6/2002 7:00 20:55 3.92 MOB P PRE Legal Well Name: 5-31A Common Well Name: 5-31A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: slack mgmt. Wait for electrician to repair junction box & wire on reel collector that was damaged during the reel swap. SLACK MGMT: Unstab & cut CT to expose e-line, place plastic boot/shrink-wrap on exposed e-line. Stab CT back onto well & reverse circulate bio-water through the CT at 3-4bpm. Rig back injector and cut 45' of CT, cut 10' of eline. Inspect eline core wI BHI, appears to be dry. Total of 30' of slack pumped. Wait on electrician to repair reel collector(same as above) prior to performing resistivity test on e-line. Test resistiviy on eline. Re-head BHI CTC. Pull test, pressure test. SAFETY MEETING. Review BHA make-up procedure and hazards. M/U BHI MWD BHA #2 with 2.5 deg fixed WFD motor and 2.80" HC diamond Window mill. Fat radius type. Test Coiltrak tools at surface. OK. Pump slack management. 40 bbls, 2.5 bpm, 3500 psi. RIH with BHA #2. Log tie-in with GR/CCL of 03/08/2000, at 9971 ft. Added 4 ft to CTD. Unable to orient. Try moving CT, vary pump. No luck. Orienter failure. POOH. OOH. CIO orienter. RIH with BHA #3. Same 2.5 deg WFD motor and 2.80" HC diamond window mill. Close circ sub, Tie-in at 9,970' to: 3/08/02 Perf depth control Memory GR/CCL. Add 6' to CT. (Vac trucks unavailable for swapping to Flo-Pro, both 141 & 27E have cement jobs going on, therefore, milling fluid is 2ppb bio, LSRV=21200, 8.5ppg) Dry tag whipstock @ 10,119', TF90. PU, orient TF to 243, Dry tag whip @ 10, 119'md. PU 15', off bottom circ= 1.6bpm/3020psi. Tag whip with pumps on 1.6bpm/3080 seeing small amount of motor work. Stall motor. PU 10' RIH to tag depth with pumps on 1.6bpm/3030. Start time milling procedure 0.1 '/9min. 10,119.1' 1.6bpm/3060psi PVT=244bbls 10,119.2' 1.6/3160 DHWOB=150Ib Watch DHWOB drill off. 10,119.3' 1.6/3195 DHWOB=205Ib let it drill off... 10,119.4 1.6/3150 DHWOB=200Ib TF=243 10,119.5 1.6/3190 DHWOB=205Ib TF= 240 10,119.5 1.6/3210 DHWOB=407Ib TF=233 10,119.7 1.6/3240 DHWOB=377Ib TF=240 10,119.8 1.6/3240 DHWOB=534Ib TF =240 10,119.9 1.6/3250 DHWOB=432Ib TF=240 10,120.0 1.6/3200 DHWOB=631Ib TF=234 10,120.1 1.6/3200 DHWOB=500Ib TF=239 10120.2 1.6/3180 DHWOB=575 TF= 242 10120.3 1.6/3170 DHWOB=603 TF=249 Circulating pressure is slowly cycling between 3130 and 3180. 10120.4 1.6/3110 DHWOB=521 TF=233 10120.5 1.6/3100 DHWOB= 500 TF=243 21:40 - 21 :50 21 :50 - 22:00 0.17 STWHIP P 0.17 STWHIP P WEXIT WEXIT Printed: 6/17/2002 11 :31 :32 AM 19:45 19:50 19:55 20:00 20:10 20:20 20:30 20:40 20:50 21:00 21 :10 21:20 21:30 09:15 04:15 09:00 06:30 05:40 18:50 13:45 15:30 17:00 13:15 2:15 10:00 9:15 19:50 19:55 20:00 20:10 20:20 20:30 20:40 20:50 21:00 21 :10 21:20 21:30 21:40 - 15:30 - 17:00 - 18:50 0:00 09:15 09:00 06:30 05:40 19:45 2:15 9:15 3:45 3:15 0.08 STWHIP P 0.08 STWHIP P 0.08 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.17 STWHIP P 0.50 STWHIP P 2.25 STWHIP P .42 STWHIP P 0.75 STWHIP P 0.25 STWHIP P 2.50 STWHIP P 0.83 STWHIP N 0.42 STWHIP N 0.50 STWHIP N .75 STWHIP N .50 STWHIP N .83 STWHIP N .00 STWHIP P DFAL SFAL DFAL DFAL DFAL DFAL WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 6/8/2002 02:30 04:00 04:00 04:15 1.50 STWHIP P 0.25 STWHIP N SFAL WEXIT WEXIT Legal Well Name: 5-31A Common Well Name: 5-31A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: 20:15 - 22:10 .92 STWHIP P 22: 1 0 - 23:00 0.83 STWHIP P 23:00 - 23:30 0.50 STWHIP P 22:30 - 00:00 .50 STWHIP P 6/10/2002 00:00 - 01 :00 .00 STWHIP P 6/8/2002 22:00 - 00:00 2.00 STWHIP P WEXIT 6/9/2002 00:00 - 03:30 3.50 STWHIP P WEXIT 03:30 - 05:35 2.08 STWHIP P WEXIT 05:35 - 06:00 0.42 STWHIP N DFAL WEXIT 06:00 - 07:40 1.67 STWHIP N DFAL WEXIT 07:40 - 08:30 0.83 STWHIP N DFAL WEXIT 08:30 - 10:15 1.75 STWHIP N DFAL WEXIT 10:15 - 10:45 0.50 STWHIP N DFAL WEXIT 10:45-11:50 1.08 STWHIP P WEXIT 11 :50 - 12:40 0.83 STWHIP P WEXIT 2:40 - 13:00 0.33 STWHIP P WEXIT 3:00 - 14:40 1.67 STWHIP P WEXIT 4:40 - 15:20 0.67 STWHIP P WEXIT 5:20-17:15 1.92 STWHIP P WEXIT 7:15 - 20:15 3.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Printed: Flag pipe, PU 1', commence time milling sequence over the next 3'. 1.6bpm/2950psi WOB startting out negative and slowly increasing. Continue time milling sequence over the next 3'. WOB slowly increasing with each 0.1' as we encounter the 7" liner. Completed time milling procedure. Continue milling ahead at 1 '/hr. WOB still climbing, 1.6bpm/3400psi. Pump 10bbl high vis pil (4ppb bio). Send flo-pro down hole at 04:50. PU at 10,124.6'. Orienter stuck at 180deg, not responding. Will rotate CW but will not rotate CCW. Freespin: 1.6bpm/3180 POH for new orienter. OOH. C/O Orienter. Mill in gauge [2.80"], good condition, wear across face. motor still tight. RIH with Coiltrak milling BHA #4, 2.5 deg fixed WFD motor, 2.80" HC diamond mill [re-run]. Test orienter. OK. RIH. Log tie-in. Added 4 ft. Milling window. TF = 233 deg, 1.7/1.7 bpm, 3300-3600 psi. exit 7" casing at 10125.3 WINDOW TOP at 10,119'. WINDOW BOTTOM at 10,125'. Milling formation. TF = 230 deg. 1.7/1.7 bpm, 3300 - 3400 psi. 12 fph, 2500# WOB. Drilled to 10,135 ft. Backream thru window, clean window. Ream down. TF = 240 deg. Clean hole to 10,135'. Backream thru window. Clean again. POH to change out motor and mill. OOH, L/O motor and mill. M/U 1.75 deg WFD motor and 2.78" CTC taper mill. RIH with Coiltrak milling BHA #5. Ream down at 235 deg TF. 1.7/1.7 bpm, 3300 psi, Stall 10,120'. Ease in and ream at 10120'. Ream restriction at 10120-10121'. Ream down 10124' and stall. Ream past 7" and into OH, stall on bottom. Seems to be a hard spot on bottom. PU, back ream thru window @ TF233, Ream down at TF 233. PU, backream up through the window at TF 215. Ream down TF 215, 0.5fpm, 1.6/1.6bpm/3620psi, negative DHWOB. Pump 20bbl 60KLSRV FloPro pill. Stall as we near TD, PU, let the motor work, 1.6/1.6bpm/4160psi(circ. pressure higher due to pill on bottom, not all motor work), let the motor drill off, TF 210. Make l' of progress. PU, back ream through window wI TF 255. Down ream @ TF 255, 1.6/1.6bpml 2880psi. Stall near TD. Drift dry, no bobbles. Bring pumps back on near TD, work hard spot. Multiple near-stalls, 600-8001b motor work. Make 3'. PU above whipstock and RIH dry, no bobbles. Geo confirms Z2 cuttings from sample. PU to 9960' and RBIH at 2.5fpm to tie-in, correct CT depth -2.5ft. RIH dry (pumps off) to TD and flag pipe. TD @10135.4 after correction. Did not see any bobbles on weight indicator RIH past window. Open circ port and POH. POH 6/17/2002 11:31:32 AM Legal Well Name: 5-31A Common Well Name: 5-31A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 6/6/2002 Rig Release: 6/16/2002 Rig Number: Spud Date: 9/6/1992 End: PJSM, prior to LD tools, pinch points. Stand back injector, LD milling BHA. PU CoilTrack BHA with 1.1 deg motor and used HC Bicenter (srl# 1905126). RIH, open circ sub. Log tie-in while RIH, 2.5fpm. Add +8 ft to CT. RIH, Start drilling. Freespin= 1.6/1.6bpm/2850psi Unable to get consistent TF, orientor is sitting across whipstock face. Function test near bottom, PU and re-set orienter. RBIH. Orienter OK. Drilling, 1.7/1.7bpm/3040-3280psi PVT=322bbls (fyi...PVT=pit volume totalizer). ROP = 40fph. Drilled to 10190 ft Drilling, 1.61 1.6 bpm, 3040 - 3600 psi, TF = 60-80L, ROP = 60-100 fph. Incl = 81 deg. PVT = 314, Drilled to 10,300 ft. Wiper trip to window. Clean hole. Drilling, 1.61 1.6 bpm, 3040 - 3600 psi, TF = 90L, ROP = 40 FPH. Drilled to 10400 ft. Drilling, 1.61 1.6 bpm, 3040 - 3600 psi, TF = 55R, ROP = 40 FPH. Drilled to 10450 ft. PVT = 314 Landed well at 10,440 ft at 8745' TVDSS. Wiper trip to window. Drilling, 1.7/1.7 bpm, 3130 - 3900 psi, TF = 90R, ROP = 80 FPH. Drilled to 10600 ft. Wiper trip to window. Clean hole. Drilling, 1.7/1.7 bpm, 3130 - 3900 psi, TF = 50L, ROP = 90 FPH. Drilled to 10750 ft. PVT = 305 BBLS. Wiper trip to window. Clean hole. Log Tie-in with RA tag at 10,125 ft. Added 2.5 ft. to CTD. RIH to TD. Clean hole. Drilling, 1.61 1.6 bpm, 2950 - 3600 psi, TF = 90L, ROP = 80 FPH. Drilled to Mix lubetex pill and send downhole. Stacking wt and difficulty getting motor work, 10,80Tmd. PU, RBIH continue making progress. Mud has 630'+60' prior to recond. Lube tex on bottom, take off drilling @1 OOfph. 1.6/1.6 3660psi DHWOB=1761Ib Wiper trip to 8300' (50deg inc. inside tubing), clean hole. Open circ sub just outside window, pumping 2bpm up inside tubing. On bottom drilling, 10,881'md. 1.5/1.5bpm/3454psi, ROP=100fUhr, DHWOB=1580Ib PVT=302bbl (freespin= 2690psi, 1.5bpm) Drill to 10900'md. Drilled 765' in last 24hrs. On bottom drilling, 10,900'md. 1.7/1.7bpm/3800-3880psi, ROP=120fph, DHWOB=1454Ib PVT=302bbl (freespin= 3000psi, 1.6bpm). Drill 50' to 10,950' stacking wt, difficulty getting drill off. Drill to 11,000. Short Trip. Back to drilling, 1.7bpm, 3580psi DHWOB=2385Ib ROP=120fph PU (after 150' of progress) for wiper @ 11031 'md, overpull, RBIH, stuck. Shut down pumps & relax pipe, wait 8min, RIH quickly and PU, pull to 58000K and pull free. 6/11/2002 01:55 01:20 00:00 23:45 21:00 09:00 - 09:20 09:20 - 11 :00 05:40 02:45 - 04:40 04:40 - 04:55 04:55 - 05:00 05:00 - 05:40 17:20 17:45 18:10 18:30 4:30 5:30 12:00 12:30 11 :00 07:00 9:30 09:00 07:00 02:05 01:20 23:45 21:00 5:30 7:20 12:30 14:30 00:00 17:45 18:10 18:30 19:30 01:55 2:00 0.17 0.25 DRILL 2.75 0.42 0.42 0.33 1.00 0.50 DRILL 2.00 DRILL 0.33 DRILL 1.67 DRILL 2.00 1.92 STWHIP P 0.25 STWHIP P 0.08 STWHIP P 0.67 STWHIP N 0.58 DRILL 50 00 .33 DRILL .00 DRILL .83 DRILL .33 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL N P P P P P P P P P P P P P P P P P P STUC DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 Printed: 6/17/2002 11:31:32 AM 6/10/2002 01 :00 - 01 :10 01:10 - 02:45 0.17 STWHIP P 1.58 STWHIP P WEXIT WEXIT Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 15-31 A 15-31 A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: ') ) Legal Well Name: 5-31 A Common Well Name: 5-31 A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 c: 6/11/2002 02:05 - 02:50 0.75 DRILL P 02:50 - 04:00 1.17 DRILL P 04:00 - 05:00 1.00 DRILL P 05:00 - 06:00 1.00 DRILL P 06:00 - 08:00 2.00 DRILL P 08:00 - 09: 1 0 1.17 DRILL P 09: 10 - 11 :45 2.58 DRILL P 11 :45 2:15 0.50 DRILL P 23:45 - 00:00 0.25 DRILL P 6/12/2002 00:00 - 01 :30 1.50 DRILL P 01 :30 - 04:30 3.00 DRILL P 04:30 - 06:45 2.25 DRILL P 06:45 - 06:50 0.08 DRILL P 06:50 - 08:00 1.17 DRILL P 2:15 3:45 .50 DRILL P PROD1 13:45 - 14:05 0.33 DRILL P PROD1 14:05 - 14:45 0.67 DRILL P PROD1 14:45 - 16:45 2.00 DRILL P PROD1 16:45 - 18:00 1.25 DRILL P PROD1 18:00 - 18:20 0.33 DRILL P PROD1 18:20 -19:00 0.67 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 20:00 0.50 DRILL N SFAL PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 23:45 3.25 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed: Wiper to window. Send new flo-pro system down hole, plan to have new mud exit the bit when we get back on bottom. Footage on old mud system = 972' + window milling. Drilling, new mud at the bit, 1.6bpm /3600-3700psi DHWOB=2500 ROP=120 Drilling, 11, 144'md, 1.6/1.6bpm, 3600-3800psi, DHWOB=31 00, ROP=90-100fph TF=285, Inc.=91.5deg. Plan to build at 92-93deg Inc. with strike. 120GR shale @11200' (8741'tvd), At this point we are 2' TVD below the plan. Drilled to 11,200' PU, wiper trip and tie-in to PIP tag. Subtract 4' from CT depth. Drilling 1.6/1.6bpm 3400-3500psi ROP=75-90fph Inc=93.7 WOB=22001b TF = 90R, Drilled to 11258 ft. Drilling 1.6/1.6bpm 3400-3500psi ROP=20fph Inc=94.9 WOB=22001b Slow drilling from 11240 ft. 120GR shale. Ave DLS for this 1.1 deg motor has been 16.5 deg. Pull for 0.8 deg motor to drill closer to well plan and to provide more available WOB near TD. OOH. Adjust motor to 0.80 deg bend. C/O bit to Hycalog Bi-center [3 bladed pilot]. Bit #6 in perfect condition, no chipped cutters, but had 3 plugged nozzles out of 4 on pilot part of bit. RIH with Coiltrak BHA #7 with 0.80 deg motor and rebuilt HYC Bi-center bit #7. Tie-in with RA marker, +5 ft to CTD. RIH to TD. Clean trip to bottom. Tagged TD at 11,258 ft. Drilling 1.6/1.6 bpm, 3100-3500psi, ROP=40fph, Inc=94, WOB=22001b, Drilled to 11355 ft. Bring up mud system to 4% lubetex. Drill to 11438' @ 245TF, 1.6/1.6bpm, 3100/3500psi, 2.5k WOB, & 70fph ave ROP. Wt stacking @ 11438'. Wiper to 11150' Drill to 11456'. Stacking here. Wiper to window. No OP's. Reboot BHI database. RIH. Hole in good shape. Drill 1.6/2950. No obvious difference in annulus pressure. Drill to 11475', stack, stall 8 times, finally got thru hard spot. Drill to 11505', hit another brick wall here, more stalls, stacking. Add one drum lubetex to 30 bbls mud. Pump half of this. Finally took off drilling before pill hit. Drill with 1400 Ibs DWOB. Still have positive 10k weight at surface while on bottom drilling. Drill to 11614'. Wiper to window. Finish wiper trip to window. Hole in good shape. Drill starting at 11614'. Good positive wt (10k) on bottom drilling, then hit hard spots with stacking/stalling. 8% lubetex pills help to grind thru. Tough getting past 11700'. Progress too slow by 11734'. Wiper to 8600' (55 deg). RBIH to 10150'. Log & tie-into RA PIP tag @ 10125'. Added 2' to CTD. RIH, set down & ream thru shales from 11520' to 11680' 6/17/2002 11:31:32 AM PROD1 Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: ) Legal Well Name: 5-31 A Common Well Name: 5-31 A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 C 6/12/2002 06:50 - 08:00 1.17 DRILL P 08:00 - 08:45 0.75 DRILL P 08:45 - 09: 15 0.50 DRILL P 09:15 - 09:40 0.42 DRILL P 09:40 - 10:30 0.83 DRILL P 11 :00 0:30 - 10:50 0.33 DRILL P PROD1 0:50 - 11 : 15 0.42 DRILL P PROD1 11:15-13:45 2.50 DRILL P PROD1 13:45 - 17:20 3.58 DRILL P PROD1 17:20 - 17:35 0.25 DRILL N STUC PROD1 17:35 - 18:25 0.83 DRILL P PROD1 18:25 - 19:00 0.58 DRILL P PROD1 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 6/13/2002 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01 :00 0.25 DRILL P PROD1 01 :00 - 02:15 1.25 DRILL P PROD1 02:15 - 03:15 1.00 DRILL P PROD1 03: 15 - 03:45 0.50 DRILL P PROD1 03:45 - 04:45 1.00 DRILL P PROD1 04:45 - 06:30 1.75 DRILL P PROD1 06:30 - 06:45 0.25 DRILL P PROD1 06:45 - 07:15 0.50 DRILL P PROD1 07:15 - 07:30 0.25 DRILL P PROD1 07:30 - 08:45 1.25 DRILL P PROD1 08:45 - 09:10 0.42 CASE P COMP 09:10-10:40 1.50 CASE P COMP 0:40 - 11 :00 0.33 CASE P COMP PROD1 14:15 3.25 CASE P PROD1 PROD1 COMP Printed: Precautionary ream to TD. Resume drilling from 11734' to 11788' @ 270TF, 1.6/1.5bpm, 3000/3300psi, 2k WOB & 307bbls PVT. Wt stacking with occasional 40-1 OOfph take-offs. 0.9% drill solids in mud with 703' footage. Call for 300bbls new fresh FP mud. Drill to 11808' @ 290-300TF, 1.6/1.6bpm, 3000/3300psi, 2k DWOB & 40fph. Short wiper trip to 11500'. RBIH clean to btm. Drilling @ 260-300TF, 1.6/1.6bpm, 3000/3300psi, 1.4k DWOB, +3k surface wt, & 58fph ave ROP. Still stacking wt. Pump down 20bbls of lubetex pill. With pill out of bit, take off & drill sandlshale to 11855'. Short wiper trip to 11500'. RBIH clean to btm. Drill to 11870' @ 250-260TF, 1.6/1.6bpm, 3000/3300psi, 1.4k DWOB, -1 k surface wt. Start taking returns to outside tank. Wiper to 8600' (55 deg). RBIH & start new mud downhole from 11210'. Observe few bobbles from 11550' - 11650'. New mud @ the bit. Drill to 12041' @ 225-250TF, 1.6/1.6bpm, 3100/3550psi, 2k DWOB. Still stacking wt with occasional takeoffs. Pump 28bbls of 7% lubetex pill. P/U for wiper trip & pull heavy. Differentially stuck. P/U & SID pumps for 15mins. Pull free with 45k (1 Ok O/P). Wiper to window. Slight O/P & motorwork @ 11560'. Log tie-in at RA tag 10125'. Correct depth (+12'). RIH. Tag with MW 11525'. PU. RIH dry clean. RIH to TD. Clean the rest of the way. Drill 1.6/3250. By 12100', drilling with negative surface weight; 1500 - 2000 Ib DWOB. Drill to 12180', pump 30 bbl8% lubetex pill. Drill to 12200'. Wiper to window. Log tie-in. Correct depth (+2'). RIH. Tag with motor work 11250'. Fell thru dry. Tag 11520', fell thru dry. Drill to 12210'. Differentially stuck. SD pump. Pull free. Tough drilling, stacking, to 12214'. Willi be a struggle getting liner any further. Call this corrected TD. POOH laying in 8% lubetex mud in open hole. PM -- Replace pins in injector chains. POOH Safety meeting. SB inj. LD drilling BHA. PJSM for BID CT with N2. RIU, PT N2 unit - OK. BID CT with N2 & bleed off. PJSM for securing CT prior to reel removal. Clamp CT end. Spool CT across pipe shed roof & onto reel. Clamp CT tip with u-bolts & chain in place. PJSM with all personnel for simops on RIH liner assy & swapping reel. Reviewed HA/HM for planned activities & contingencies for well control without CT reel. Stress good communication & need to STOP any unsafe activities during simops. RIU, M/U & RIH 72 its of 2-3/8" P/jt, O-ring 6/17/2002 4.7# L-80 STL with 11 :31 :32 AM PROD1 PROD1 Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: ) 11 :00 10:00 0:15 09:30 2:20 0:15 11 :00 0:00 .33 0.25 0.75 0.50 CASE CASE CASE CASE P P P P COMP COMP COMP COMP Printed: Reduce rate: 1.0/0.7/1900. Increase rate to 1.5bpm in & getting 0.7 - 1.2bpm out. Decide to go ahead with cement job. Call for cementers & 20bbls pumpable cmt slurry. Meanwhile bypass & cleanout macromotion out. Pump around 10bbls biozan sweep - didn't get plenty of solids back. R/U DS cementers. Meanwhile circulate 2% KCL water @ 1/0.7bpm & 2300psi. PJSM & HA/HM with all crew on cement job. Batch up cement. Meanwhile circulate 2% KCL water @ 1/0.7bpm & 2300psi. Cement slurry at 15.8 ppg wt. at 10:50 Hrs. DS flush & PT lines to 4000 psi. Pump 20bbls 15.8 ppg G cement slurry & 5bbls of water behind @ 1.0/0.6bpm & 2300psi. Displace with 35 bbls 2ppb biozan-KCI water, 6/17/2002 11:31:32 AM 06:00 07:15 07:15 09:30 1.25 2.25 CASE CASE P P COMP COMP 6/14/2002 03:00 02:15 21 :30 - 21:45 21 :45 - 22:20 22:20 - 00:00 18:30 19:30 19:45 7:00 14:15 00:00 06:00 02:15 9:30 9:45 21:30 8:30 7:00 03:00 3.00 0.75 2.25 0.25 0.58 1.67 1.00 0.25 1.75 2.75 CASE CASE CASE CASE CASE CASE .50 CASE CASE CASE CASE CASE P P P P P P P P P P P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP .8/0.2/4000. Minor improvement and stabilization at .1/0.4/2200. Try lowe rate 0.5/0.3/1100. Try bringing rate back up again, seeing some improvement 1.1/0.7/2000 ncrease rate again, but no improvement in out rate .7/0.8/3950. sub, float equipment & turbos. Did not drift the M/U STL connections based on the outcome of the overtorquing test (see remarks). Meanwhile swap out e-line reel to used 2" coil & hook-up hard line connections to reel. P/U injector over well & prep to stab CT into injector. Pull CT with tugger & place into counter. Secure CT with spooler clamp. Pull CT into rig floor. Prep CT tip for stabbing. Stab CT into injector. Fill liner with 6bbls flo-pro mud. Prep & install weld-on CTC. Pull/Pressure test CTC. Pump dart (0.9" OD neck). Bump at 39.8 bbls. Safety meeting. MU 37 stands CSH on slick joint. Sting into flapper valve, space out with pups. PT CSH x 2-3/8" annulus to 500 psi -- good. MU LBRT. Stab coil. RIH. At window, 30k up. 0.75 BPM; 2600 psi. RIH tag 11,280'. Fell thru but ratty RIH. Tag 11,380'. Work through. Continue RIH with liner. Struggle starting 11,280'. Lots of drag and not a lot of weight. Work liner down in a few feet increments, stacking and even losing ground sometimes. 38k up. Cycle pumps. Work to 11850'. Toughest working past this depth, then started getting easier (no idea why). Work to 12100' without much difficulty and positive RIH weight. Very slow again starting 12140'. Brick wall at 12170' CTM. Pulls to 60k. Don't think we'd get liner out. No further progress down. Should be able to get all requested perfs. Call it good here. Drop 5/8" ball. Circulate to seat 1.0 BPM; 3950 psi. Return rate only at 0.3 BPM. Land ball in LBRT at 31.5 bbls. Shear at 4300 psi. PU 28k. Free. Displace well to slick 2% KCL water. Displacing: 1.0/0.3/3700 initial, 1.5/0.1/3540 before KCL water even turned the corner, then lost it all. ncrease rate to maintain rickle back: 6/13/2002 11:00 -14:15 3.25 CASE P COMP Legal Well Name: 5-31A Common Well Name: 5-31A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: ) ) Printed: 6/17/2002 11:31:32 AM Legal Well Name: 5-31 A Common Well Name: 5-31 A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 C 6/14/2002 11 :00 - 12:20 1.33 CASE P 12:20 - 12:30 0.17 CASE P 12:30 - 14:50 2.33 CASE P 14:50 - 16:50 2.00 CASE P 16:50 - 17:15 0.42 CASE P 17:15 - 17:30 0.25 EVAL P 17:30 - 19:45 2.25 EVAL P 19:45 - 21 :00 1.25 EVAL P 21 :00 - 00:00 3.00 EVAL P 6/15/2002 00:00 - 00:45 0.75 EVAL P 00:45 - 02:00 1.25 EVAL P 02:00 - 03:45 1.75 EVAL P 03:45 - 04:00 0.25 EVAL P 04:00 - 04:30 0.50 EVAL P 04:30 - 10:30 6.00 BOPSURP 14:15 - 14:30 0.25 PERF P 14:30 - 15:00 0.50 PERF 15:00 - 17:00 2.00 PERF P 17:00 -17:15 0.25 PERF P 7:15 - 18:45 1.50 PERF P 8:45 - 20:30 1.75 PERF P 0:30 - 13:30 3.00 BOPSUR N SFAL COMP 13:30 - 14:15 0.75 EVAL P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP under-displacing by 2bbls. Pump 16.5bbls cement behind shoe @ 0.8/0.7bpm & 4150psi. CIP @ 12:20 Hrs. Pumped cmt thru filter between batchmixer and pump truck & caught 6 pcs of cmt rocks - largest rock @ 1" long x 0.5" wide. Bleed off - floats held OK. Unsting from POB. Lay-in remaining 2 bbls of cement while PUH to 11500'. Continue displacing & RBIH to ORS contaminating cmt with 2ppb biozan-KCI water @ 1.0/1.2 bpm & 2800 psi. Getting 1:1 returns. POOH chasing contaminated cmt out with 2ppb biozan-KCI water. Continued 1:1 returns. Circulate at TOL (@ 9840') & continue POOH. Got back @ 5 bbls excess cmt from behind liner & 2 bbls contaminated [underdisplaced] cmt. OOH. Flush surface lines. LID LBRT & stand back 1" CSH. M/U nozzle & stab on well. Flush BOP stack. POOH nozzle & SIB injector. PJSM on P/U & RIH MCNLlGR/CCL tools & 1" CSH. M/U SWS MCNLlGR/CCL tools. RIH on 76 jts of 1" CSH workstring. RIH. Log down 30 FPM from 9680' 1.4/3500 and full returns. Clean to PBTD. Tag 12135' uncorrected CTM (1000 Ib down max at surface). Log up at 30 FPM, laying in 150k LSRV Flo-Vis pill in liner. Continue logging up at 30 FPM. POOH. Set inj aside. Standback CSH. Had to pump air first few stands -- wet, not draining easily. Safety meeting. LD logging tools. Perform weekly BOPE test. Witness waived by AOGCC's Chuck Scheve. Meanwhile download MCNLlGR/CCL data & fax to ANC. PBTD was tagged @ 12140' ELMD & TOL @ 9854' ELMD. ANC Geo confirms no changes to MWD perf picks. Call for perf guns. Outer stack drain valve leaking. Pull off, rebuild & retest - fail test. Replace valve with rebuilt spare & retest - OK. Meanwhile load perf guns into pipeshed. Line up to & test liner lap. Compressive strength of cement @ 05:30 was @ 2660psi. I/A 600psi @ onset of test. Staged up in 500psi intervals, monitoring I/A. PT @ 2000 psi, leaked 1700 psi in 10 mins, no change in IA pressure thoughout test. Review forward plan with ANC & plan to run KB 1m top Pkr after perforating. PJSM on P/U & RIH perf guns. RIU to run guns. RIU safety jt. M/U 62 SWS 1.56" HSD 4spf perf guns, blanks & BCF firing head. PJSM on RIH 1" CSH. M/U 42 stands (doubles) of 1" CSH. Stab inj. RIH. Started losing RIH weight at 11950', negative weight by 12030', had to slow to 20 FPM to maintain positive weight (perf pill was a little thick). 29k up. RIH tag 12128'. Correct depth 12140' (corrected PBTD). PU to shooting depth. Circulate 1:1 COMP Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: 6/16/2002 09:20 - 10:20 .00 RUNCOrvP COMP 10:20 - 11 :25 1.08 RUNCOrvP COMP 11:25-11:50 0.42 RUNCOMN WAIT COMP 11 :50 - 12:50 1.00 RUNCOMN COMP 12:50 - 13:20 0.50 RUNCOMN COMP 13:20 - 13:35 0.25 RIGD N COMP 13:35 - 14:30 0.92 RIGD N COMP 14:30 - 14:45 0.25 RIGD N COMP 14:45 - 15:00 0.25 RIGD N COMP 15:00 - 15:30 0.50 RIGD N COMP 5:30 6:15 0.75 RIGD N COMP 6:15 6:30 0.25 RIGD N COMP 21 :30 - 22:45 22:45 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 08:30 04:15 05:15 06:15 01:30 09:20 05:15 06:15 08:30 04:15 1.00 1.00 2.25 2.75 PERF 0.83 1.25 PERF 1.25 PERF 1.00 PERF 0.50 PERF RUNCOrvP PERF P RUNCOrvP RUNCOrvP P P P P P COMP COMP COMP COMP COMP COMP COMP COMP COMP Printed: Drop 1/2" ball, circulate to seat 1.2/2400. Land at 40 bbls. Pressure to 3300 psi to shear seat in firing head. Perforted the following with 1-11/16",4 SPF guns: 10825' - 11150' 11300' - 11875' 11950' - 12120' POOH. LD CSH in singles. LD 84 jts CSH in singles. Safety meeting -- trapped pressure; only SWS personnel break out guns. LD guns. After completely breaking off one of the blank guns and after an additional few second delay, trapped pressure was released in the blank gun hanging in the slips. A 20' long loading strip squirted out of the gun, then a blast of mud and debris shot up into the derrick. No injuries. Discuss. Procedures followed correctly as reviewed in pre-job -- crew commended. Will investigate further. Load out guns, clear and clean floor. Bring Baker tools to floor. MU KB iner top packer. RIH KB Pkr assy to 9750'. Check up wt @ 26.5k. RIH & see seals going-in @ 9845.7'. Sting in seals with 9k slack off wt @ 9853.2'. Unsting & P/U to ball drop position @ 9809'. Drop 5/8" ball & chase ball @ 1 bpm/750psi. Ball on seat @ 35bbls away. Stab-in seals to 9850'. P/U up wt + 1.5' to 9847'. Pressure-up CT to 1500psi to set packer. P/U 2' from up wt - didn't O/P. Stop immediately. Bleed off & attempt to restab-in - taking wt' Pressure CT to 1000psi & pull 5k over - OK. Slack 5k & bleed CT to Opsi. Have - 3.5' of seal unit above PBR, leaving - 2.34' stung in w/4 Ava seals on btm. P/test pkr elements via annulus to 2000psi - OK. Pressure CT to 2500psi & release 'GH' running tool. Top of KB Pkr (TOL) @ 9833.5'. POOH KB Pkr running assy to 2000'. W.O. Methanol. Supply trailer had a flat tyre. Meanwhile circulate well @ 1.3/1.3bpm & 1050psi. Hook-up to MeOH & displace to BHA. POOH from 2000' freeze protecting well to 60/40 MeOH. Tag @ surface. LID KB Pkr running tool. SI master (23-1/2 turns). PJSM for BID CT with N2. R/U, PT N2 unit - OK. B/D CT with N2 & bleed off. SI swab (23-1/2 turns). Cut CTC. PJSM for securing CT prior to reel removal. Remove injector gooseneck & unstab coil. Store injector in stabbing box. Meanwhile clean out pits/tanks & load out misc equipment to G-10. Clamp CT end. Spool CT across pipe shed roof & onto reel. Clamp CT tip with u-bolts & chain in place. PJSM with all personnel for simops on N/D BOPE & swapping reel. Reviewed HA/HM for planned activities. Stress good communication & need to STOP any unsafe activities during 6/17/2002 11 :31 :32 AM 6/15/2002 20:30 21:30 .00 PERF P COMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-31 A 15-31A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: ) ) Printed: simops. N/D BOPE. N/U & P/test tree cap. Meanwhile swap out 2" CT reels. Rig Released @ 18:00 6/16/2002. 6/17/2002 11:31:32 AM COMP COMP Legal Well Name: 15-31A Common Well Name: 15-31A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 6/6/2002 6/16/2002 Spud Date: 9/6/1992 End: 10406.79 10437.11 10257.84 10287.04 10317.55 10347.47 10376.18 84.78 88.77 83.11 82.71 82.40 82.34 82.71 56.38 59.35 78.78 73.98 68.65 62.97 56.86 8807.67 8809.38 8789.06 8792.67 8796.62 8800.60 8804.34 8743.07 8744.78 8724.46 8728.07 8732.02 8736.00 8739.74 -451.38 -435.28 -511.04 -504.21 -494.53 -482.38 -468.12 3201.48 3227.11 3067.61 3095.77 3124.41 3151.45 3176.07 5959202.71 5959219.40 5959139.91 5959147.40 5959157.76 5959170.54 5959185.38 680600.57 680625.81 680468.15 680496.14 680524.55 680551.29 680575.56 1313.74 1340.97 1192.20 1212.91 1236.31 1260.93 1286.08 6.94 16.39 19.89 16.37 17.35 18.82 21.14 10119.00 10136.84 10166.24 10197.01 10226.67 78.08 72.53 76.74 80.17 82.00 98.30 96.06 92.39 88.58 84.93 8761.95 8766.47 8774.26 8780.42 8785.02 8697.35 8701 .87 8709.66 8715.82 8720.42 -512.59 -514.75 -516.83 -517.07 -515.41 2932.28 2949.39 2977.65 3007.79 3037.03 5959135.17 5959133.41 5959132.00 5959132.46 5959134.81 680332.90 680350.06 680378.36 680408.49 680437.69 1119.17 1126.41 1139.62 1155.38 1172.29 DLS deg/1000 0.00 33.38 18.70 16.47 13.63 Survey MD ft loci deg Azim deg TVD ft SSTVD ft N/S ft EIW ft MapN ft MapE ft VS ft Company: Tool: Baker Hughes INTEQ MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path 6/13/200:f\lsaka Oil & Gas COns. ClJn1ßliui\) Ancborage Survey: MWD Start Date: 10119.00 12214.00 8761.95 8785.91 KOP TD JUL 1 9 2002 Annotation MD ft TVD ft Rt-( :~'VE:U- 432.24 10119.00 Survey Program for Definitive Wellpath Date: 7/17/2002 Validated: Yes Actual From To Survey ft ft 10119.00 12214.00 1 : MWD - Standard (0) MWD MWD MWD Version: Toolcode MWD - Standard MWD - Standard Tool Name Wellpath: 15-31A 500292228501 Current Datum: 45: 31 9/6/199200:00 Magnetic Data: 5/21/2002 Field Strength: 57535 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 64.60 ft 4 Drilled From: Tie-on Depth: Above System Datum Declination: Mag Dip Angle: +E/-W ft 0.00 15-31 10119.00 ft Mean Sea Level 26.29 deg 80.82 deg Direction deg 32.00 +N/-S +E/-W Position Uncertainty: Well 15-31 15-31 Position: 715.24 ft 1109.70 ft 0.00 ft Northing: Easting : 5959578.38 ft 677389.53 ft Slot Name: Latitude: Longitude: 70 148 31 17 33 42.270 N 48.870 W Well: Site Position: From: Map Position Uncertainty: Ground Level: 0.00 ft 0.00 ft PB DS 15 TR-11-14 UNITED STATES: North Slope Northing: Easting: 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 70 148 17 34 35.236 N 21.213 W True 1.34 deg ):::. ,...= G") ("0 en r''\.) C:~I f¿j Site: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level 927 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 :0 a:J t:::J 3: en a::J ....." ...... Company: Field: Site: Well: Wellpath: Field: BP Amoco Prudhoe Bay PB DS 15 15-31 15-31A Date: 7/17/2002 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Time: 10:20:06 Well: 15-31, True North 45: 31 9/6/199200:0064.6 Well (0.00N,O.00E,32.00Azi) Minimum Curvature Db: Oracle ;I o bp BP Baker Hughes INTEQ Survey Report ) ) Page: INTEQ .¡¡. BAKU. MUGMI. ~Od- 0;) ) BP ) lliíì. ObP BAKD HUGHI,S Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 7/17/2002 Time: 10:20:06 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-31, True North Site: PB DS 15 Vertical (TVD) Reference: 45: 31 9/6/199200:0064.6 Well: 15-31 Section (VS) Reference: Well (0.00N,0.00E,32.00Azi) Wellpath: 15-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 10466.99 90.40 63.61 8809.59 8744.99 -421.02 3253.35 5959234.28 680651.71 1366.97 15.26 10497.15 89.85 70.20 8809.53 8744.93 -409.19 3281.08 5959246.76 680679.15 1391.69 21.93 10529.40 89.45 69.66 8809.73 8745.13 -398.13 3311.37 5959258.53 680709.16 1417.13 2.08 10558.86 87.15 74.30 8810.60 8746.00 -389.02 3339.36 5959268.30 680736.93 1439.69 17.57 10589.50 85.18 84.74 8812.65 8748.05 -383.46 3369.38 5959274.56 680766.81 1460.30 34.60 10620.14 84.65 83.76 8815.37 8750.77 -380.41 3399.75 5959278.33 680797.09 1478.99 3.63 10649.90 85.42 81.86 8817.95 8753.35 -376.70 3429.16 5959282.74 680826.41 1497.72 6.87 10680.84 87.70 77.55 8819.80 8755.20 -371.18 3459.54 5959288.97 680856.64 1518.50 15.74 10726.38 90.46 73.61 8820.54 8755.94 -359.84 3503.62 5959301.34 680900.45 1551.48 10.56 10756.53 90.52 71.73 8820.28 8755.68 -350.86 3532.40 5959311.00 680929.01 1574.34 6.24 10787.43 90.15 67.67 8820.10 8755.50 -340.14 3561.38 5959322.40 680957.72 1598.79 13.19 10816.80 90.40 61.86 8819.96 8755.36 -327.63 3587.93 5959335.54 680983.97 1623.47 19.80 10847.08 91.90 56.84 8819.35 8754.75 -312.20 3613.97 5959351.57 681009.63 1650.35 17.30 10877.79 91.01 52.28 8818.57 8753.97 -294.40 3638.97 5959369.95 681034.21 1678.69 15.12 10906.17 91.29 46.01 8818.00 8753.40 -275.85 3660.42 5959389.01 681055.21 1705.79 22.11 10941.57 92.42 40.00 8816.85 8752.25 -249.99 3684.55 5959415.43 681078.72 1740.51 17.27 10974.80 91.96 37.29 8815.58 8750.98 -224.06 3705.28 5959441.84 681098.83 1773.49 8.27 11008.14 91.54 30.13 8814.56 8749.96 -196.35 3723.76 5959469.97 681116.65 1806.78 21.50 11037.53 93.53 23.20 8813.26 8748.66 -170.13 3736.93 5959496.49 681129.20 1835.99 24.51 11067.09 93.04 18.82 8811.56 8746.96 -142.59 3747.51 5959524.28 681139.12 1864.95 14.89 11098.43 91.53 12.44 8810.31 8745.71 -112.45 3755.94 5959554.61 681146.84 1894.98 20.90 11128.90 91.59 6.93 8809.48 8744.88 -82.44 3761.06 5959584.73 681151.25 1923.15 18.08 11158.60 93.74 2.30 8808.10 8743.50 -52.87 3763.45 5959614.34 681152.94 1949.48 17.17 11189.21 93.19 355.99 8806.25 8741.65 -22.34 3762.99 5959644.85 681151 .77 1975.14 20.65 11219.42 94.95 1.78 8804.10 8739.50 7.77 3762.41 5959674.94 681150.47 2000.36 19.98 11266.52 93.69 10.60 8800.55 8735.95 54.42 3767.47 5959721.69 681154.43 2042.60 18.86 11300.98 93.14 6.52 8798.50 8733.90 88.43 3772.59 5959755.81 681158.74 2074.16 11.93 11330.96 92.93 4.53 8796.91 8732.31 118.22 3775.47 5959785.66 681160.92 2100.95 6.67 11360.70 94.30 1.84 8795.03 8730.43 147.86 3777.12 5959815.32 681161.87 2126.96 10.13 11391.00 93.44 355.62 8792.99 8728.39 178.06 3776.45 5959845.50 681160.49 2152.22 20.68 11421.29 92.89 351.86 8791.31 8726.71 208.12 3773.15 5959875.47 681156.48 2175.96 12.53 11451.15 91.78 349.07 8790.10 8725.50 237.54 3768.21 5959904.77 681150.84 2198.29 10.05 11483.15 91.14 351.31 8789.28 8724.68 269.06 3762.76 5959936.15 681144.65 2222.14 7.28 11514.87 89.45 357.42 8789.12 8724.52 300.61 3759.65 5959967.61 681140.80 2247.24 19.98 11545.50 89.82 1.07 8789.31 8724.71 331.23 3759.24 5959998.21 681139.67 2273.00 11.98 11575.29 89.29 359.48 8789.54 8724.94 361.02 3759.39 5960027.99 681139.11 2298.33 5.63 11605.99 88.10 355.14 8790.24 8725.64 391.67 3757.95 5960058.60 681136.95 2323.56 14.65 11636.68 89.42 351.48 8790.91 8726.31 422.14 3754.37 5960088.97 681132.66 2347.51 12.67 11667.26 90.18 349.91 8791.01 8726.41 452.32 3749.43 5960119.02 681127.00 2370.48 5.70 11697.42 89.48 346.98 8791.10 8726.50 481.86 3743.39 5960148.42 681120.27 2392.33 9.99 11727.96 90.03 343.05 8791.23 8726.63 511.36 3735.49 5960177.71 681111.68 2413.16 12.99 11757.64 90.22 339.64 8791.17 8726.57 539.47 3726.00 5960205.60 681101.52 2431.98 11.51 11787.25 91.63 337.03 8790.69 8726.09 566.98 3715.07 5960232.84 681089.95 2449.52 10.02 11817.06 92.70 333.80 8789.57 8724.97 594.07 3702.68 5960259.62 681076.92 2465.92 11.41 11847.09 93.80 331.48 8787.86 8723.26 620.69 3688.90 5960285.92 681062.52 2481.20 8.54 11876.27 93.78 326.91 8785.93 8721.33 645.70 3674.00 5960310.56 681047.03 2494.50 15.63 11906.69 92.19 325.85 8784.35 8719.75 670.99 3657.18 5960335.45 681029.62 2507.04 6.28 11936.81 92.98 321.40 8782.99 8718.39 695.21 3639.34 5960359.24 681011.21 2518.13 14.99 11967.09 92.25 320.80 8781.61 8717.01 718.75 3620.34 5960382.32 680991.67 2528.03 3.12 11997.00 89.35 317.53 8781.19 8716.59 741.37 3600.79 5960404.48 680971.59 2536.85 14.61 12026.09 90.03 314.47 8781.35 8716.75 762.30 3580.59 5960424.91 680950.90 2543.89 10.78 12056.64 90.06 312.09 8781.32 8716.72 783.24 3558.35 5960445.32 680928.18 2549.86 7.79 12086.93 88.40 309.72 8781.73 8717.13 803.07 3535.46 5960464.61 680904.83 2554.55 9.55 ObP ) BP ) II.. B.AKat HUGIIIs Baker Hughes INTEQ Survey Report ----.'--....----.- INTEQ Company: BP Amoco Date: 7/17/2002 Time: 10:20:06 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-31, True North Site: PB DS 15 Vertical (TVD) Reference: 45: 31 9/6/199200:0064.6 Well: 15-31 Section (VS) Reference: Well (0.00N,O.00E,32.00Azi) Wellpath: 15-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 12120.56 89.32 307.92 8782.40 8717.80 824.15 3509.26 5960485.06 680878.14 2558.54 6.01 12150.52 86.74 304.50 8783.43 8718.83 841.83 3485.11 5960502.17 680853.58 2560.74 14.29 12181.29 88.09 301.14 8784.82 8720.22 858.49 3459.28 5960518.21 680827.37 2561.18 11.76 12214.00 88.09 301.14 8785.91 8721.31 875.39 3431.30 5960534.45 680799.00 2560.69 0.00 BP Amoco Parent Wellpath: Tie on MD: Rig: Ref. Datum: WELLPATH DETAILS 15-31A 500292228501 15-31 10119.00 Nordic 1 45 : 31 9/6/199200:00 64.6Oft V.Sectlon Origin Origin Angle +N/-S +E/-W 32.000 0.00 0.00 Starting From TVD 0.00 REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: 15-31, True North Vertical (WD Reference: System: Mean Sea Level Section (VS Reference: Slot - 31 (O.OON,O.OOE) Measured Depth Reference: 45: 31 9/6/199200:00 64.60 Calculation Method: Minimum Curvature ANNOTATIONS !VO MO Annotation 6697.35 10119.00 KOP 6721.31 12214.00 TO +NI-S +EPN Sf-.ap.e !~¡H :h1~ ~* illi~ æ; 8050 8100 8150 8200 - .58250 = 08300 II) - .c 8350 .. D. G.l8400 Q ¡ 8450 U :e 8500 G.I > 8550 G.I 28600 ... 8650 8700 8750 8800 950 600--c-- . - - C ~5~ .... - o ::: 0400- ... - - _300--=-- + :ë 200--: t: ::: o ::: ~100-::: "":'" :ë O-~- .. g-100-~ -- en _ -200-:: - -----~ --------. ObP 1000--:-:- - 900---::: 800u 700---:::- -300--:: _íï. BtlLl INTßQ LEGEND T 1t~1·~iii~·Plan~106 ^ M ,~" ¿ Wellpath: (15-31/15-31A) Azimuths to True North Magnetic North: 26.290 Stre~~t~~~~~~~~~ Dip Angle: 80.82" Date: 5/2112002 Model: BGGM2002 /fr i~,.~ Created By: Bnj Potnis Date: 7/1712002 Contact InformatIon Direct (907) 267-6613 E -mailbrij ÒOlnis@inleQcom Baker Hughes rNTEQ: (907) 267-6600 --.------- - --- ----~~ - - - ------. ----~---- ----------- -----~---- -- -- -- ------- "------ -- .- - - . ----- -"--- - ------~-_._- - ------- -------- ------ -------~- ._---~----- ----.~--~--- '-' - - ----~---- ------~----- .---~------ ------~------ ---------...-.------ - -------- - ---~------ --- __-_--0------- - ~.- -------------- ----- - ----.-- - ---~~- ~ - ---~--~--- .--- ---~----------- - ---~----. -500--::· ··-----ì-~~- - - ------.-- - ------------- --~-~- ~~ ---------... =-=====~=~~-~-=- -6OQ----j- . --~~-- 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 West(-)/East(+) [100ft/in] -- -_.----~-- ----~----- -----~--_._.-~------ ----- - -- --- ---------- - - --------> - --------- ----- - ---------- .- -- ------------ -. _.--~--- .------ - .-------. ------------ --------- 1S.31.1S.31A,Plan #1061- ----------- - ---- ---._---~--_._- --. ----------- - - .- .-- --------.-- ---- · . - ~IA; ___ _~___ __~____.____------O----_~__ ________________ _ -_____~ . - - n_ _ . __ __ _ _ _ _ __ _. ___. __ - . n. __ ___no. .. _ _ __ _. _ __ - _ _ - - - -- -------:-._-:-------:-:-,-----,---_.:---:-,..--,.----,------:--:---=---~,,---,---~--_.~----:---~,-.,.-~~..,-~-~~------:-----,--~:--- ---------------------,------ ---- - --- -- --- -- -- ------ 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950200020502100215022002250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 Vertical Section at 32.000 [50ft/in] 7/17/2002 10:23 AM Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. cc jjclEncIosures BY ORDER OF THE COMMISSION DATED this 7f'h day of May, 2002 Sincerely, (;~()uU' ~/ Cammy Ôechsli T¡yló1 ~ Chair 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. 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. Enclosed is the approved application for permit to redrill the above referenced well Dear Mr. Stagg: Prudhoe Bay Unit 15-31A BP Exploration (Alaska), Inc. Permit No: 202-102 Sur Loc: 1937' SNL, 1438' EWL, Sec. 22, T11N, R14E, UM Btmhole Loc. 1092' SNL, 5045' EWL, Sec. 22, T11N, R14E, UM Re: Ted Stagg CT Drilling Engineer BP Exploration (Alaska), PO Box 196612 Anchorage AK 99519 Inc. AI¡ASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~VL%lfŒ (ffi _",I rc I f~ d ) {M j r1 \ ",.j \J ~~ U::1 tn_J. (QJ \\ æ) í1· 7 fA\ !ì \ ¡ lJ \ U·\\¡,nt I' l1 nO"' ~_.. ) TONY KNOWLES, GOVERNOR the best of Title Commission Use Only I AP~Zll)¥1~(} I See cover letter - J / I U r- for other requirements Mud Log Re uire 0 Yes ~o Directional Survey Required ':8~Yes 0 No 3K D4K D5K D10K D15K 0 3.5K psi for CTU ).J~. ~A- by order of the commission Approved By Form 10-401 Permit Number ;¿ 0 ::>_ -_.' I (J ¿___ Conditions of Approval: Rev. 12-01-85 I API Number 50- 029-22285-01 Samples Required 0 Yes æ:No Hydrogen Sulfide Measures }aYes 0 No Required Working Pressure for BOPE 0 2K 0 Other: Te ~ t- f~ f c- 'fJ:/ ~ SO 0 o f··'~ ) "\ (: tJ r,. I ~\J ~. tmmissioner t . J Date i~hßate Engineer Name/Number: hereby certify that Signed Ted Stagg :ÿ~ CT Drilling Engineer Date r(a /<' ~ B Filing Fee B Drilling Fluid Program Ted Stagg, 564-4694 and correct to my knowledge Contact 21 o Property Plat o Time vs Depth Plot B BOP Sketch o Refraction Analysis o Diverter Sketch o Seabed Report Prepared By Name/Number: B o Drilling Program 20 AAC 25.050 Requirements Terrie Hubble, 564-4628 20. Attachments true vertical 0450' - 10700', 10850' - 11050' Slotted Section: 10846' - 11704' 8800' - 8801', 8801' - 8802' Slotted Section: 8801' - 8767' AlasIca OJ! &. G.as Cons. L;ormms61on Anchorage Perforation depth: measured Production Liner Liner 2433' 957' 7" 4-1/2" 493 cu ft Class 'G' Uncemented Slotted Liner r~' S'( .1 c ¡S6~'l F&~)' "07711 - "~8' ._~ '....1 2002 8149' 8801' 8802' 8764' Casing Structural Conductor Surface Intermediate 110' 3488' 8920' 20" 13-3/8" 9-518" D 11\ ~ ~, 2000# Coldset II 2554' cu ft CS III, 460 cu ft Class 'G' 1644 cu ft Class 'G', 506 cu ft 'G' ~,,''''' ('" t ~ , 110' 3524' 8952' 110' 3524' 8324' Length Size Tagged PBTD at 11698' (03/2000) Fish at 11723' (06/1995) Cemented MD TVD 22, T11 N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028307,234' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 0100' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Grade Couplina 3" 2-3/8" L-80 ST-L Effective depth: 9. To be completed for Redrill, Re-entry, Present well condition summary Total depth: measured true vertical Weiaht 4.6# measured true vertical 11728 feet 8764 feet 11698 feet 8767 feet and Deepen Operations. Lenath 2163' Junk (measured) Plugs (measured) Setting Depth Top Bottom MD TVD MD TVD 9900' 8640' 2063' 8705' Quantitv of Cement (include staae data) 56 cu ft Class 'G' ~ 930 ./ 17. 14. Number of acres in property 2560 $200,000.00 15. Proposed depth (MD and TVD) 12063' MD 18705' TVDss Anticipated pressure {s, 20 AAC 25.035 (e) (2)} Maximum surface 2244 psig, At total depth (TVD) 8800' I 3300 psig At total depth 1092' SNL, 5045' EWL, Box 196612, Anchorage, Alaska Location of well at surface 1937' SNL, 1438' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 2281' SNL, 3389' EWL, SEC. 22, T11N, R14E, UM SEC. 9. 8. Approximate spud date 06/05/02 ""'"',. Well or Property Name Prudhoe Bay Unit Number ./' 15-31A Amount Number 2S100302630-277 Type Bond (See 20 AAC 25.025) 4. 7. Unit 11 3. Address P.O. 99519-6612 6. Property Designation ADL 028306 Field and Pool Prudhoe Bay Field Bay Pool 2. Name of Operator BP Exploration (Alaska) 1 a. Type of work nc. o Drill ORe-Entry B Redrill o Deepen ALASKA 01... 1b. STATE OF ALASKA tlND GAS CONSERVATION COMMIS,-. PERMIT TO DRILL 20 AAC 25.005 Type of well 0 Exploratory 0 Stratigraphic Test o Service 0 Development Gas 0 Single Zone 5. Datum Elevation (DF or KB) 10. RKB = 64.6' 1N yJc; A- ~~ Prudhoe B Development Oil o Multiple Zone 5/iÇlo"J- Reservoir Pressure Res. press. is estimated to be 3300 psi at 8800' ss (7.2 ppg emw) psilft) to surface is 2244 psi. Max. surface pressure with gas (0.12 Hazards . . The maximum recorded H2S on DS 15 is 50 ppm on well 15-21 This sidetrack will be drilled just above the Kavik shale. If the Kavik is inadvertently penetrated. a plug back and re-drill may be required. Logging · MWD Gamma Ray will be run in the open hole section. Directional · See attached directional plan. Max. planned hole angle is 93 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · · Wel · 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 2500 psi. Casing Program: The production liner will be 23/8" ST-L from TD to approx. 9900'MD (8640 'ss) The liner will be cemented with a minimum of 10 9bls to bring cement up to the top of the lin~. A liner top packer will be used if the lap fai Is to test. Disposal: · All drilling and completion fluids and all other Class · All Class I wastes will go to Pad 3 for disposal. wastes will go to Grind & Inject. Mud Program · Phase 1: Seawater · Phase 2: Mill with seawater/biozan. drill with Flo-Pro (8.6 - 8.7 ppg) ...---' Phase 2: Mill window, Drill and Complete sidetrack: Planned for June 5, 2002. Drilling coil will be used to mill the two string window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 93 degrees. 2. Phase 1 1 Prep work. Planned for May 20, 2002. Service coil to set CIBP's at 10,725 and 10,125. The whipstock will be set at 10,100' holes will be punched in the 3 %" at 9700-9704. ) Service coil to pump a minimum of 45 bbls 15.8 ppg cement through the punched holes at 9700- 9704 in order to stabilize the 3 Y2" inside the 7" for window milling. Squeeze The 15-31 a window will be milled through two strings, 3 Y2" and 7" , in Zone 2. The target is Zone 1 B. No significant faulting or lost circulation is expected. 15-31a will be completed with a fully cemented 2 3/8" liner. Summary of Operations: A CTD through tubing sidetrack is planned for 15-31. The coil sidetrack, 15-31 a, will e~"'the 7" liner in Zone 2 and target Zone 1 B. 15-31a will be completed with a fully cemented 2 3/8" liner. The existing slotted liner and perfs will be isolated by bridge plugs and cement as described in the 10-403. ) BP 15-31a CTD Sidetrack DATE 10/01/92 09/01/93 12/18/00 02/14/01 01/09/02 REV BY SIS-lsl SIS-MD RN/TP COMMENTS ORIGINAL COMPLETION LAST WORKOVER CONVERTED TO CANV AS FINAL CORRECTIONS DATE 03/13/02 REV BY JLJ/tlh COMMENTS REÆRF OF SLOTTED LNR PRUDHOE BA Y UNIT W8...L: 15-31 ÆRMIT No: 192-0870 API No: 50-029-22285-00 SEC 22, T11 N, R14E, 4597.85 F8... 2653.89 FNL BP Exploration (Alaska) 4-1/2" LNR, 4-1/2" LNR-SL TO, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 2.6#, L-80, .0152 bpf, ID = 3.958" 1-1 TOP OF 4-1/2" LNR 1-1 1-1 11728' 11704' 11704' 112 SPINNER CAGE ARMS (LOST 06/29/95) ÆRFORA TION SUMMARY REF LOG: GRC/CCI10/31/92 ANGLEATTOPÆRF: 90 @ 10450' Note: Refer to Production DB for historical perf data SIZE I SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 1 0450 - 1 0700 0 03/08/00 SLOTTED 10846 - 11704 SLOT 10/02/92 2-1/2" I 6 0850 - 11050 0 03/11/02 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 1/2"X16" Minimum ID = 2.750" @ 10752' 3-1/2" PARKER SWN NIPPLE 7" LNR, 26#, NT-80S, 0.0383 bpf, ID = 6.276" 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 TOP OF 4-1/2" LNR - SL TO 1-1 1-1 10846' 10846' 11084' Proposed tbg. punch 9700- . ./ !iilllll' Top of proposed 2 3/8" liner 9900 / Ilill:!I'¡!I!I' v Illilll]lj"l P d L S'd Who 1 01 00 "I"I'i'" ropose ow I e Ip ]11!i',I¡i Proposed CIBP 10125 - ,,!lllil!!il,lil!li III : i i 1II1I ~ Proposed CIBP 10725 :llil,l'I::II:1111 '1IIil'II"I,II. ','1'11"1" ""I;llll'I'I,' iilil:11111 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1-1 10765' ~ j¡lli'!li!I:,¡ '11'I'lj,!" - 1:1:1:11' "'1"1' ~~:'!'!i Top of 4 1/2" liner wI TIW 55 Horiz. Pkr. 10, 771 ~ ~ :~ (this 55 Horiz. Pkr. is D.Q1 holding pressure) ~~ 4-1/2" LNR, 10772' 10805' Perfs 10752' 1-1 10765' 1-1 ~ \ ~ \ : \ j\ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ I \ I Perfs ~ 1-1 3-1/2" X 4-1/2" XO (existing) 3-1/2" PARKER SWN NIP, ID = 2.75" 4-1/2" 4-1/2" TIW OVERSHOT SEAL ASSY (SEALS REMOVED) 10850 - 11050 (existing) PORTED JOINT (40.38') 10450 7" X 4-1/2" 4-1/2" 3-1/2" X 3-1/2" XO I PARKER SWS NIP, ID = 2.813" - 10700 ~. Proposed TD ¡/ 12,063 3-1/2" PARKER SWS NIP, 3-1/2" X 4-1/2" XO I BAKER SABL-3 PKR 9031' 90~O' 9-5/8" CSG, 47#, NT-80S, ID = 8.681 TOP OF 7" LNR 1-1 1-1 1-1 8962' 8651 I t----4 ~ ~ L ~ I ST MD lVD 1 3188 3188 2 5497 5493 3 6970 6872 4 8377 7984 5 8503 8062 ID = 2.813" GAS LIFT MANDR8...S DEV TYPE VLV LATCH 1 CA-MMG-2 RK 8 CA-MMG-2 RK 28 CA-MMG-2 RK 50 CA-MMG-2 RK 55 CA-MMG-2 RKP 13-3/8" CSG, 68#, L-80, ID = 12.415" 35401 ~ PORT DATE 1-1 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 2926' ~xJ\ngl:= Datum MD = Datum lVD = 5540' 97 @ 11662' 10631 ' 8800' SS . , 2926' 1-1 ~ 4-1/2" X 3-1/2" XO 4-1/2" CAMCO TRDP-4A-SC SSSV NIP, ID = 3.812" TREE = WELLHEAD = ACTUATOR = 1<s:äBi'; BF. 8...EV = KOP= FMC CIW AXELSON 65' 2078' ) ) 15-31a Proposed Prep Work & Completion SAFETY NOTES: HORIZONTAL WB..L 70° @ 9726' AND 90° @ 10648' Vertical Section o 8500 8550 - 8600 - ..... +J Q) Q) !tS650 c ~ 8700 - 8,705 -8.745 8750 - 8800 - rei MS 8,728, - --------- 1 5-31 Path Distance (Feet) 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 1 5-31 a case 1 08 April 30, 2002 Ted x4694 .~ Angle @ K.O.= 78 . '~;J~ .....~~~ Top perf @ 10,450' 7" shoe Tot Drld:1963 ft 12063 TD - - --------------~~ Marker Depths @Orig Wellbore 01 Oft TVD 8,7451 8,745ft TVD 8,7281 8,728ft TVD a,70sl 8,7051ft TVD Kick Off 8,693 ft TVD 1 0,1 00 ft MD Deprtr @KO 2,973 ft ~ MD KO Pt MD New Hole 10,1 00 1963 12,063 8,705 DLS deg/100 Tool Face Length 10 180 18 11 -110 30 ~ 11 -45 165 11 -88 480 11 83 180 11 -90 490 11 -90 320 11 87 280 1,963 Total MD TVDTD Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 - ------ - 15-31 (well Name 1 5-31 1,500 - CLOSURE Distance 3,702 ft Az 75 deg NEW HOLE E/W (X) N/S (Y) Kick Off 2,925 -441 1 ,000 -7- . TD 3,583 930 State Plane 680,973 5,960,508 Surface Lac 677,389 5,959,578 .~ u 500 DLS 0 ....J deg/100V Tool Face Length ~ II) . Curve 1 10 180 18 E Curve 2 11 -110 30 .g CI) Curve 3 11 -45 165 u c: o,fi Curve 4 11 -88 480 en :s Curve 5 11 83 180 >- 0 Curve 6 11 -90 490 Curve 7 11 -90 320 Curve 8 11 87 280 1,963 -<> - -500 1 5-31 a Case 1 08 April 30, 2002 Ted x4694 I-- -1,000 2,500 3,000 3,500 4,000 4,500 5,000 X distance from Sfc Lac Drawn: 5/1/2002 -- ---~-- 10:25 Plan Name: Case 122 ') ) All Measurements are from top of Riser 5/1/2002 L- CD en -- c::: h;I~',: ;~: ,~r, II~'/ top of bag I I BAG bUm of bag middle of slips Blind/Shears ................... I I TOTs I"~ middle of pipes 2" combi ram/slips ....../..~._.~ ~ ,---- middle of flow cross Mud Cross Mud Cross "--' - middle of blind/shears 2 3/8" ram ..................... I I ) TOTs middle of pipe/slips 2" combi ram/slips ----.-----....... Flow Tee DATE -()4i'i~lijß02 CHECK NO. 00206699 H 206699 VENDOR DISCOUNT ALAShAOILA NET 00 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 040902 CK040902A PYMT COMMENTS: HANDL:NG INST: iOO. 00 iOO.OO H PERMIT TO DRILL FEE S/H - TERRIE HUBBLE X4628 n~""'.r~J'!r~u· ,- -9" ~'C; J ~n~!" '. '-' ~ ~ _ ll!\~ L ~~ f~ ~ \J ~~.; \S-31 A- ?f ro ,-,. '-'k tV'jAil 0 3 J.iJasl<a UH & Gas Ccns.l.omrmSS1QE1 ~- ~ Anchorage - TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. iOO.OO 100. 00 \. No. H20 6 8 9 9 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO ./ CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206699 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 04/11/02 AMOUNT $100_ 00 NOTVALlD AFTER 120 DAYS To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 - Q. Jie~' /1.i;¡'_~o } ~ \ e:.. :¡; . '\-;!~. ¡.. . - . ~-7.1. ...~ '-. II- 20 b b 9 9 II- I: 0 L. ~ 20 3 B 9 5 I: 00 B ~ ~ ~ 911- Templates are loa¡ted m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. SPACING EXCEPTION <---> YES + DISPOSAL ANNULUS INJECTION WELL REDRILL INTO OTHER ANNULAR DISPOSAL THIS WELL Please note that an disposal of fluids generated. .. Annular Disposal of drilling wastes wiU not be approved <---> YES be approved INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not EXPLORA TION DEVELOPMENT RED RILL CHECK 1 STANDARD LEITER DEVELOPMENT v ANNUL~ DJSjPOSAL O:::::::JNO (If api number last two (2) digits are between 60-69) .............".....,~"~ jJ!ß(1 Pn.,OT HOLE (PH) CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL Annular disposal has ~ot In accordance with 2.0 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). "CLUE" The permit is for a Dew 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. been req uested 'WELL NAME TRANS1\fiT AL LE'rfER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ) ) /("' . ::/ /\ ~ '\ - v /-"j (Y~ Y N Y N Y IN Y N Y N Y N Y N Y N Y N Y N , Y N \"y) N ¥ N .y N IA -¥ N ¡J/~ !~'eTD~ *@~ at-~ ~ N/Æ- , ,,' ~ I'USp;: 1-W" 'f't.: " N N Permit can be issued w/o hydrogen sulfide measures. §y ~ Data presented on potential overpressure zones . . y );í A. Y1 Seismic analysis of shallow gas zones. . . . . . . . Y '/(, /7 Seabed condition survey (if off-shore). . . . . . . . . . . N Contact name/phone for weekly progress reports [exploratory on Y N Ann. disposal para req _ ON/OFF SHORE O;~ Redrll~ Serv _ Well bore seg UNIT# /1 ç, ,é 0 Exp _ Dev_ ?/~ ,~ I A PROGRAM: GEOL AREA WELL NAME f/J(~ IS- INIT CLASS /ìej/ )~ ñ: ) !1fJ V WELL PERMIT CHECKLIST COMPANY FIELD & POOL C YO.! ,5 C> ADMINISTRATION Permit fee attached. . . . . Lease number appropriate. . . Unique wen name and number. . Well located in a defined pool.. . . . . . . . . . . . . . Well located proper distance from drilling unit boundary. Well located proper distance from other wens.. .' Sufficient acreage available in drilling unit.. . . . . . If deviated, is wenbore plat included.. . . . . . . . . Operator only affected party.. . . . . . . . . . . . . Operator has appropriate bond in force. . . . . . . . Permit can be issued without conservation order. . . Permit can be issued without administrative approval Can permit be approved before 15-day wait. 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. ( . . psig. Conductor string provided . . . . . . . . Surface casing protects an known USDWs. . . . . CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg. . CMT will cover an known productive horizons. . . . . . Casing designs adequate for C, T, B & permafrost. . Adequate tankage or reserve pit.. . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved. Adequate wellbore separation proposed.. . . . . . . If diverter required, does it meet regulations . . . . . Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation . . . . . . . . BOPE press rating appropriate; test to 3 $'"00 Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown. Is presence of H2S gas probable. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 'Ill 5~2 ENGINEERING APPR D¡A1E \¡1GÞr ~ (PI o~ ( 30. 31. 32. I)ftfR DATE 33. ¡ffL L¢;t/(?l-- 34. ANNULAR DISPOSAL GEOLOGY /I.) (; Ii Y N MC 25.412. UIC/Annular: COMMISSION: 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause drilling waste to surface; (C) will not impair mechanical integrity of the well used for disposal (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 ENGINEERING: DATE øj/2-· APPR /fPc, Comments/Instructions: COT DTSO~J()1/0~ JMH ~ . WGA ~It -z}¡<- GEOLOGY: RPc/~ SFD . ) ') We H ¡story File APPENDIX nformation of detailed nature that IS not particularly germane to the Well Permitting Process but is part of the history file. " To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information ! ! ! ! ! ! ! ! ! ! ! ! ~Version VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------ STRT.FT 10100.0000: STOP.FT 12214.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF . EKB .F EDF .F EGL .F CASE.F OSl . -Remarks (1) All depths 22 IlN 14E MSL o RF 64.6 RF N/A 64.6 N/A N/A DIRECTIONAL are Measured Depths MD unless Section Township Range Permanent Datum Elevation Of Perm 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 otherwise Line noted 1 Datum Description Starting Depth Ending Depth Level Spacing Absent Value BP Exploration Alaska 15-31A Prudhoe Bay Unit 70 deg 17' 42.770"N North Slope Alaska Baker Hughes INTEQ 2 3/8" Coil Trak 13-June-02 500292228501 148 Inc deg 33' 48.870"W ! ! ! ! ! ! ! ! ! ! ! ! ! ! Information **** REEL HEADER **** MWD 02/10/24 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/10/24 306151 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** 1 Remark Extract 20 NO ) aW-1 0 ~ ) Jd -¡ 0{ File Version 1.000 File: ldwg .las CWLS log ASCII Standard -VERSION 1.20 One line per frame Information * FORMAT RECORD TYPE# 64 GR ROP *** MNEM GR ROP INFORMATION TABLE CHAN DIMT GRICX02 GROPA02 CIFO CNAM 0.0 0.0 ODEP ! 1 2 3 ! ! ! ! ! ! Remark File Version 1.000 The data presented has been edited from the The data has been depth shifted to match the The PDC used is schlumberger Gamma Ray dated field raw data. PDC supplied by BPX 15-Jun-02 ! *** WDFN LCC CN WN FN COUN STAT LIS COMMENT RECORD *** mwd 150 BP Exploration Alaska 15-31A Prudhoe Bay North Slope Alaska Unit Inc *** MNEM xtf INFORMATION TABLE VALU CONS 1024 MWD 001 **** FILE HEADER **** Minimum record Maximum record length length 14 132 bytes bytes Tape Subfile SENSOR OFFSETS: RUN GAMMA 5 24.27 ft 6 23.22 ft 1 60 DIRECTIONAL 22.87 ft 22.82 ft records MNEMONICS GR1CX GROPSA -> Gamma Ray MWD-API [MWD] (MWD-API -> Rate of Penetration, feet/hour 7 8 5 2 3 4 6 units All depths are Bit Depths unless otherwise noted All Gamma Ray data presented is realtime data. Well 15-31A was sidetracked off .well 15-31 @ 10119' MD 8697 SSTVD) and was drilled to TD @ 12209' MD (8721' SSTVD) on Run 6. Baker Hughes Inteq utilized CoilTrak downhole tools and the Advantage surface system. The data presented here is final and has been depth shifted to match the PDC supplied by BPX (Gamma Ray dated 15-Jun-02. Gamma ray detector type is a scintillator. The interval from 12209' MD (8721' SSTVD) to 12188 MD (8720 SSTVD) was not logged due to sensor to bit offset. ) ) ) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255 Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 API 4 4 2 ROP MWD 68 1 F/HR 4 4 - 8 Total Data Records: 51 Tape File Start Depth = 10100.000000 Tape File End Depth = 12214.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 60 records Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ----------------------------- WDFN mwd.xtf LCC 150 CN BP Exploration Alaska I WN 15-31A FN Prudhoe Bay Unit COUN North Slope STAT 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 --------------------------------------------- ----- GRCX GRCX GRICX 0.0 ROPS ROPS GROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRCX MWD 68 1 API 4 4 2 ROPS MWD 68 1 F/HR 4 4 - 8 Total Data Records: 51 Tape File Start Depth = 10100.000000 Tape File End Depth = 12214.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 60 records Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 02/10/24 306151 01 **** REEL TRAILER **** ,) MWD 02/10/24 BHI 01 Tape Subfile: 4 Minimum record length Maximum record length 2 records 132 bytes 132 bytes ) Tape Subfile 1 is type LIS ) Tape File Start Depth = 10100.000000 Tape File End Depth = 12214.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet DEPTH 10100.0000 10100.5000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12214.0000 GR -999.2500 -999.2500 30.0413 18.7546 50.5953 28.0292 42.2050 63.5919 64.2632 44.8887 45.3398 41.4121 50.5657 72.2962 63.5673 115.8242 51. 7073 39.3081 43.6192 107.7373 53.5036 34.7653 -999.2500 999.2500 ROP -999.2500 -999.2500 99.5270 39.3610 54.8589 114.1154 26.2309 46.6353 112.2515 92.3743 123.4292 122.2525 153.2764 50.1861 64.4552 81.9707 84.2376 21. 9084 75.9546 51.9586 93.9117 118.8973 58.5669 -999.2500 Tape Subfile 2 is type LIS ,) Tape File Start Depth = 10100.000000 Tape File End Depth = 12214.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet DEPTH 10100.0000 10100.5000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12214.0000 GRCX -999.2500 -999.2500 41.6369 15.2514 50.2357 32.4869 41.5728 49.9020 56.1808 42.1941 46.4818 36.8329 46.7466 95.0592 69.7984 63.8138 57.3649 41.5331 41.1724 119.6144 52.4374 -999.2500 999.2500 999.2500 ROPS -999.2500 -999.2500 98.9200 15.5255 46.5864 101.3166 8.7635 91.5600 113.3200 94.7000 84.7930 117.5200 2.2497 54.5800 59.4659 31.4623 74.4000 13.5000 90.9000 74.6700 54.9200 79.8000 84.2900 76.7000 ) Tape Subfile 3 is type: LIS ) ) Tape Subfile 4 is type: LIS )