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204-104
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS • WELL MPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned ® • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development RI Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero • Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc ,S/?272017 v,j3 (-7 2 204-104 • 317-105 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 7/4/2004 50-029-21485-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 7/14/2004 PBU L2-21A • Surface: 1726'FSL,1058'FWL,Sec.18,T11N,R15E,UM• 9 Ref Elevations KB 52.00 17. Field/Pool(s): Top of Productive Interval: 1204'FSL,3917'FEL,Sec.13,T11N,R14E,UM GL 14.23 • BF 14.89 • PRUDHOE BAY,LISBURNE OIL• Total Depth: 571'FSL,3486'FEL,Sec.13,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10261'/8544' ADL 028321&028307 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 692749 'y- 5963621• Zone - ASP 4 • 12139'/8961' • 84-62 TPI: x- 687789 y- 5962973 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 688236 y- 5962351 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No H 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 10756'/8891' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/ROP/PRESS,CML/MD/DLL/SHE,CML/MD/TVD/PDDSN,CML/MD/TVD/CS,CML/MD/TVD/DLL/SHE 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 40' 120' 40' 120' 30" 1810#Poleset 13-3/8" 72# L-80 39' 3732' 39' 3660' 17-1/2" 2500 sx AS III,600 sx Class'G' 9-5/8" 47# L-80 37' 10630' 37' 8803' 12-1/4" 1126 sx Class'G',300 sx AS I 7" 29# L-8O 10423' 10756' 8658' 8891' 8-1/2" 450 sx Class'G' 3-3/16"x2-7/8"6.4#/6.16# L-80 10599' 12139' 8782' 8961' 4-1/8"x3-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No WI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 10671' 10335'/8596' sCANMED . A N 2 6 /) R 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Age Oo4 RECEIVED ter, Was hydraulic fracturing used during completion? Yes 0 No Per AAC 25.283(i)(2)attach electronic and printed O. '��1���F information SEP 0 7 201'7 /,•l3 /7 / DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L.- See Attached ACCC ,/ 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .�. . Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ""r Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only VTC 1/2/1e A,7ARBDMS cV SEP - 8 2017 , ;, 4,> • 28. CORE DATA • Conventional Core(s) Yes 0 No H • Sidewall Cores Yes 0 No lI • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10732' 8874• separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Wahoo 6 10732' 8874' Kicked off from Parent Well(L2- 10756' 8891' 21) Wahoo 5 10865' 8947' Formation at total depth: Wahoo 5 10865' 8947' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Eller,John(CONOCOPHILLIPS) Authorized Title: for tion and Da rolller Contact Email: John.Eller@bp.com Authorized Signature: t}, Date: ci /1 ft 1 Contact Phone: +1 9075291979 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.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 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • • WELL NAME: L2-21A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 10499' Set CIBP 10354' Set Cement Retainer 10345' 76 Bbls Class 'G' 10261' Set Whipstock • Daily Report of Well Operations L2-21A ACTIVITYDATE SUMMARY PULLED 4-1/2" WHIDDON CATCHER SUB FROM DEPLOY SLV @ 10,599' MD.(empty) LRS LOADED TBG W/ 160 BBLS OF CRUDE.(see Irs log) SET 4-1/2" PX PLUG IN X-NIPPLE @ 10,392' MD. LRS PRESSURED UP TBG TO 1000psi W/81 BBLS OF CRUDE.(see Irs log) LRS PRESSURED UP IA TO TEST PRESSURE W/ 151 BBLS OF CRUDE.(see Irs log) LRS ATTEMPTING TO PERFORM MIT-IA 7/19/2017 ***CONT ON 7-20-17 WSR*** ***CONT FROM 07-19-2017 WSR*** (Pre CTD) LRS PERFORMED PASSING MIT-IA TO 2500psi.(see Irs log) PULLED 4-1/2" PX PLUG FROM 10,392' MD 7/20/2017 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** ***WSR Continued from 07-19-17*** (LRS Unit 42 -Assist Slickline: Load &Test) MIT-IA**PASSED** @ 2511 psi (5th attempt) Max Applied pressure= 2750 psi, Target pressure=2500 psi (CTD) Pumped 1 bbls crude to reach test pressure, IA lost 30 psi in 1st 15 min and 24 psi in 2nd 15 min for a total loss of 54 psi in 30 min, Bleed TP, Bled back - 8.5 bbls, Pumped 7.6 bbls 50/50 down TBG to reach test pressure, IA lost 20 psi in 1st 15 min and 19 psi in 2nd 15 min for a total loss of 39 psi in 30 min, Bled back 5.5 bbls. Caution tags/AFE sign hung on well. SSL on well upon departure. 7/20/2017 FWHP=-1/445/107 CTU#8 1.5" CT Job Scope: P&A(Pre-Rig) MIRU CTU. MU HES 2-7/8" Logging Carrier&3.67" JSN. 7/22/2017 ***In Progress*** CTU#8 1.5" CT Job Scope: Set CIBP, Tubing punch, Set WFT one trip cement retainer, P&A(Pre Rig) RIH w/2-7/8" HES Logging Carrier& 3.67" JSN. Tag deployment sleeve 10604' down/ 10601' up. Log from compression up to 10150'. Flagged pipe at 10450'. Pooh. Bullhead 291 bbls 1% KCL w/Safelube. Lay down logging tools. Tie-in using SLB RST log dated 19-July-2012. (-3' correction) RIH with WFT 4-1/2" CIBP. Correct depth at flag. Set CIBP Middle Element at 10,500', 102' above liner top. Top of CIBP at 10499.45'. Fill hole with 70 bbls of 1% KCL w/safelube and apply 529 psi on top of cibp, holding solid. Pooh. Lay down tools, ball recovered. RIH with HES 2"x 5'tubing punch (4 spf, 0 degree phasing /0.07" pen., .33" ent. hole). Tag CIBP & correct to btm shot. Punch Tubing at 10401' - 10406'. Puh to 10350' and flag pipe. Injectivity 4bpm at Opsi. Pooh. All shots fired, ball recovered. MU & RIH w/4-1/2"WFT One Trip Cement Retainer. Correct depth at flag. Set cement retainer middle element at 10355'. Top of retainer at 10354.45'. Pump down backside to test retainer. 7/23/2017 ***Continued 07/24/17*** Daily Report of Well Operations L2-21A CTU#8 1.5" CT Job Scope: Set CIBP, Tubing punch, Set WFT one trip cement retainer, P&A(Pre Rig) Pump 64 bbls down backside to catch fluid. Pressure up backside to 500psi. Pressure kept slowly bleeding off at a rate of 25-35psi/min. Could not get retainer to hold from above. Decision made to mill retainer&set another one. Unsting from retainer. Pooh. At surface, pressure test cement retainer to 500psi. Lost 39psi in 20 mins. Retainer is holding. Appears leak was around the stinger seals. MU & RIH w/WFT Stinger BHA. Sting into retainer at 10374' down. PT backside to 500psi, holding solid. Holding 100% better than before. Pump down coil into formation. Verify we are stung in. Line up Slb Pumpers. 7/24/2017 ***In Progress*** CTU#8 1.5" CT Job Objective: Set CIBP, Tubing Punch, Set WFT one trip cement retainer, P&A(Pre-Rig) Pump 76 bbls 15.8ppg Class G Cement. Swap to fresh water. Displacement cement 1 bbl over gooseneck. Shut down pump & let cement fall & balance with formation. Decision made to do this to help ensure cement will still be in the coil when coil unstings due to the low bottom hole pressure. No squeeze achieved. After 10 mins, unsting from retainer. Lay in cement(assuming 16.5 bbls in Coil which was goosneck to retainer volume). Lay in up to 9280'. Reverse circulate back down to Flag — 10' above retainer. Pooh while reverse circulating. Freeze Protect Tbg w/38 bbls of diesel. 7/25/2017 ****Job Complete*** ***WELL S/I ON ARRIVAL**** DRIFT&TAG TOC @ 10,323' SLM W/ KJ, 3' 1-7/8", 2-1/2" CENT& 1-3/4" S.BAILER. —1/2 CUP CEMENT RECOVERED. PASS MIT-T TO 2,500 PSI (see log). DRIFT W/4-1/2" GR &20' 3.70" DUMMY WHIPSTOCK. TAG TOC @ 10,323' SLM. 7/26/2017 **WELL S/I ON DEPARTURE, DSO NOTIFIED** T/I/0=45/232/130 (LRS Unit 42 -Assist Slickline: AOGCC MIT-T Post Cement Squeeze) AOGCC MIT-T**PASS**@ 2645 psi Witnessed by Brian Bixby Max applied pressure 2750 psi Target pressure 2500 psi. Pumped 3.9 bbls of diesel to achieve test pressure. 1st 15 min TBG lost 75 psi, 2nd 15 min TBG lost 28 psi for a total loss of 103 psi in a 30 min test. Bled back 1.7 bbls. 7/26/2017 Hung MIT caution tag on well. SSL in control of well upon departure. ***JOB STARTED ON 05-AUGUST-2017*** (SLB ELINE SET WHIPSTOCK) WELL SHUT IN ON ARRIVAL. RU. PT. RIH W/4.5" STANDARD MONOBORE BAKER WHIPSTOCK, OAL = 12.45, MAX OD = 3.625". TOWS SET AT 10262', CCL TO TOP OF WHIPSTOCK 14.1', ORIENTED 3 DEG LOHS, 357 DEGREES. PIP TAGS INSTALLED 9' FROM TOWS @ 10271'. LOG CORRELATED TO SLB RESERVOIR SATURATION LOG DATED 19-JULY- 8/5/2017 2012. T/I/O = 10/vac/120. Temp = SI. T& IA FLs, bleed OAP to 0 psi (Pre Rig). T FL @ surface, IA& OA FLs near surface. Bled OAP from 120 psi to 10 psi in 30 min. Monitored for 30 min, OAP increased 25 psi. Final WHPs = 10/vac/35. 8/6/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:30 hrs. T/I/0=12/VAC/0. Pre CTD. CDR tree#4 was installed on L2-21 . Installed IA piggyback valve. Torqued and PT'd to API specs. RDMO***Job Complete*** SEE LOG FOR 8/7/2017 DETAILS. Final T/I/O=SINAC/0. • • Daily Report of Well Operations L2-21A T/I/O = 10/Vac/100. Temp = SI. Bleed WHPs to 0 psi (pre Rig). OA FL near surface. Bled OAP from 100 psi to 0 psi in 30 mins and held open for 1 hr. Monitored for 30 mins, OAP increased 5 psi. Final WHPs= 10Nac/5. 8/8/2017 SV, WV, 2nd WV, = C. MV= O. IA, OA= OTG. 12:00 • • North America-ALASKA-BP Page 1 Operation Summary Report Common Well Name:L2-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/10/2017 End Date: X3-018F3-C:(2,840,469.00) Project:Lisbume Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:11/12/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001090 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 8/10/2017 23:00 - 00:00 1.00 DEMOB P PRE RELEASED RIG OFF L2-29A. HOOKUP TRUCKS -PHYSICAL BARRIERS:12"X 12"SEAL -VERIFIED RADIO COMMUNICATION. STAGE NABORS HAND WITH PEAK DRIVER -EVERYONE AGREED UNIVERSAL COMMAND • IS"STOP" VERIFIED PRESSURES AND VALVE ALIGNMENT ON BOTH WELLS PRIOR TO I STARTING. ALL ZERO PRESSURE AND CLOSED MOVE MUD MODULE MOVE SUB OFF L2-29, MOVE OVER AND SET DOWN ON L2-21 8/11/2017 00:00 - 02:00 2.00 RIGU P PRE SET DOWN WITH SUB SPACE OUT FOR MUD MODULE. SET MUD MODULE. 02:00 - 06:30 4.50 RIGU P PRE RIG ACCEPTED AT 02:00 BEGIN RIG UP CHECKLISTS PERFORM VISUAL LEAK TIGHT TEST TO 3500#NO LEAKS MAKE UP MPD LINE AND PREP TO NIPPLE UP ROPE. 06:30 - 09:00 2.50 BOPSUR P PRE NIPPLE UP 7-1/16"BOPE BOP CONFIGURATION:ANNULAR,BLIND SHEAR RAMS,2-3/8"COMBI RAMS,3"PIPE SLIP RAMS,2-3/8"X 3-1/2"VARIABLE RAMS, BLIND SHEAR RAMS,2-3/8"COMBI RAMS I FILL LINES,BLEED AIR AND SHELL TEST BOPS 09:00 - 10:00 1.00 RIGU P PRE CONDUCT PRE-SPUD MEETING WITH RIG CREW DISCUSS H2S EVACUATION PROCEDURE, SOUND ALARM AND CONDUCT RIG EVACUATION DRILL 10:00 - 13:15 3.25 BOPSUR P PRE CONDUCT BOPE TEST PER AOGCC,BP,AND NABORS POLICIES ALL TESTS TO 250 PSI LOW/3500 PSI HIGH BOP CONFIGURATION:ANNULAR,BLIND SHEAR RAMS,2-3/8"COMBI RAMS,3"PIPE SLIP RAMS,2-3/8"X 3-1/2"VARIABLE RAMS, BLIND SHEAR RAMS,2-3/8"COMBI RAMS TEST CONDUCTED WITH 2-3/8",3"AND 3-1/2" TEST JOINTS,RAM LOCKS TESTED CONCURRENTLY '13:15 - 13:30 0.25 BOPSUR P PRE SAFETY STAND DOWN WITH RIG CREW TO DISCUSS INCIDENT ON THE RIG • Printed 8/21/2017 10:46.29AM *All depths reported in Drillers Depths* • I North America-ALASKA-BP Page 2 qf . Operation Summary Report Common Well Name:L2-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/10/2017 End Date: X3-018F3-C:(2,840,469.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:11/12/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001090 Active datum:KB©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 13:30 - 21:00 7.50 BOPSUR P PRE CONTINUE TO CONDUCT BOPE TEST PER AOGCC,BP,AND NABORS POLICIES ALL TESTS TO 250 PSI LOW/3500 PSI HIGH BOP CONFIGURATION:ANNULAR,BLIND SHEAR RAMS,2-3/8"COMBI RAMS,3"PIPE SLIP RAMS,2-3/8"X 3-1/2"VARIABLE RAMS, BLIND SHEAR RAMS,2-3/8"COMBI RAMS I TEST CONDUCTED WITH 2-3/8",3"AND 3-1/2" TEST JOINTS,RAM LOCKS TESTED CONCURRENTLY PERFORMED ACCUMULATOR DRAW DOWN TEST. 21:00 - 00:00 3.00 BOPSUR P PRE TEST C9/C10 FROM BACKSIDE. PREP TO PERFORM INNER REEL VALVE/ PACKOFF TEST 250 PSI LOW/3500 PSI HIGH. PERFORM PRE-SPUD WITH COYNE CREW 8/12/2017 00:00 - 05:30 5.50 RIGU P PRE VALVE CREWTORQUE TREE BOLTS INTALL FLOATS IN UQC, PRESSURE TEST CTC/UQC TO 3500# TEST FLOATS TO 3500# STAB INJECTOR/ SWAP COIL OVER TO METHANOL SPEAR/FRESHWATER PUMP AT 2.0 BPM TO PUMP SLACK FORWARD. 05:30 - 06:00 0.50 - RIGU P PRE FLOW CHECK WELL,(30 MIN). _-WELL BORE STABLE 06:00 - 08:15 2.25 STWHIP P' WEXIT PJSM.MAKE UP WINDOW MILLING BHA. -3.81 WINDOW MILL,1.25 DEG MTR BEND. -MAKE UP TO WELL W/INJECTOR. -PT QTS @ 250/3500 PSI,OK. 08:15 - 10:45 2.50 STWHIP P 10,226.00 WEXIT PJSM.RIH W/WINDOW MILLING BHA. -RIH PUMPING MIN RATE TO 10,226'. 10:45 - 12:30 1.75 STWHIP P 10,226.00 WEXIT PJSM.DISPLACE WELL BORE TO DRILLING MUD. -DISPLACE TO 8.9 PPG QUICKDRILL. 12:30 - 12:45 0.25 STWHIP P 10,226.00 WEXIT ,LOG TIE IN F/9910'-9934' -MINUS 3'CORRECTION. 12:45 - 13:30 0.75 STWHIP P 10,250.00 WEXIT RBIH,CLOSE EDC. -ESTABLISH PARAMETERS 13:30 - 17:00 3.50 STWHIP P 10,264.30 WEXIT PJSM.COMMENCE MILLING WINDOW IN 4 1/2"TUBING. -2.88 BPM IN/2.88 BPM OUT.- -PUMPING 2.88 BPM/.3600 PSI FREE SPIN. ON BOTTOM MILLING PRESSURE=3760 PSI. -WOB 1-2K.MILLING SPEED=1'/HR. _ -MILL F/10,261.5'-10,264.3'. 17:00 - 00:00 7.00 STWHIP P 10,268.80 WEXIT MILL 3.80"WINDOW IN 4-1/2" PER BAKER REP -RATE:2.89 BPM IN,2.90 BPM OUT -MUD WEIGHT:9.00 PPG IN,9.04 PPG OUT -DWOB:0—2.0 KLBS -CIRC PRESSURE:3572 PSI -DWOB FELL OFF AT 10265.32' AND MOTOR WORK -STACK WEIGHT TO MAX 4.5K. MINIMAL MOTOR WORK. STOP AT 10268.24' -STOP AND LET MILL OFF. TAKING 20-30 MINUTES TO MILL OFF FROM 4.5K TO 4.0K -10268.8' STOPPED AND LET MILL OFF SLOWLY. Printed 8/21/2017 10:46:29AM `AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 3 Qeir" Operation Summary Report Common Well Name:L2-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/10/2017 End Date: X3-018F3-C:(2,840,469.00) Project:Lisbume Site:Lis DS 02 Rig Name/No.:CDR-2 I Spud Date/Time:11/12/1985 12:00:00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001090 Active datum:KB @52.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 8/13/2017 00:00 - 01:30 1.50 STWHIP P 10,270.50 ' WEXIT !MILL 3.80"WINDOW IN 4-1/2"TUBING RATE:2.88 BPM IN,2.88 BPM OUT !-MUD WEIGHT:9.01 PPG IN,9.0 PPG OUT -DWOB:2.5-4.5 KLBS -CIRC PRESSURE:3614 PSI SWAB ON MUD PUMP#1,SWAB#2 LEAKING. SWAP OVER TO MUD PUMP#2 HAD TO REDUCE RATE. MILL 3.80"WINDOW IN 4-1/2"TUBING -RATE:2.54 BPM IN,2.54 BPM OUT -MUD WEIGHT:9.01 PPG IN,9.0 PPG OUT -DWOB:2.5-4.5 KLBS -CIRC PRESSURE:3169 PSI 01:30 - 03:00 1.50 STWHIP P 10;270.50 WEXIT PERFORM BACKREAMING PASS AT 1 FPM ABOVE WHIPSTOCK PU WEIGHT 42K RIH WEIGHT 22K 2.55 BPM IN/2.54 BPM OUT 18.99 PPG IN /9.04 PPG OUT REAM BACK DOWN AT 0°. NO ISSUES GET 5 BBL HIVIS SWEEP COMING OUT BIT. 2ND BACKREAMING PASS AT I FPM GEOLOGIST PULLED SAMPLE. METAL AND CEMENT ONLY DRY DRIFT WITH NO ISSUES, CONTINUE INTO A DRY TAG OF 10271' PERFORM 10 MIN FLOW CHECK. WELL I STATIC 'LOG TIE IN. NO CORRECTION. 03:00 - 04:45 1.75 STWHIP P 10,270.50 WEXIT -MUD WEIGHT:8.99 PPG IN,9.02 PPG OUT -RATE:3.10 BPM IN,2.60 BPM OUT -VERIFY TRSSSV CONTROL LINE PRESSURE OF 4800# _ -SLOW DOWN THROUGH SSSV 04:45 06:00 1.25 STWHIP P 10,270.50 WEXIT MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -POWER DOWN I-INJECTOR OFF:05:00 -LAY DOWN BHA#1 -GUAGE WINDOW MILL/3.80"GO,3.79"NO GO. 1,-STRING REAMER/3.79"GO,3.78"NO GO. 06:00 - 07:00 1.00 STWHIP P 10,270.50 WEXIT MAKE UP SECOND STAGE WINDOW MILLING BHA. MAKE UP NEW MILL,REMOVE STRING REAMER. -ADJUST MOTOR ANGLE TO 2.5 DEGREES. -MAKE UP INJECTOR TO BHA,TEST QTS,250 /3500 PSI. 07:00 - 09:00 2.00 1 STWHIP P 10,270.50 WEXIT PJSM.RIH W/WINDOW MILLING BHA. -SAW GLM©8503',PICK UP AND ORIENT TO GET THRU,OK. I- CONTINUE IN HOLE. 09:00 - 09:15 0.25 STWHIP P I 10,270.50 WEXIT I LOG TIE IN F/9980'-9901'. MINUS 5 1/2'CORRECTION. 09:15 - 09:45 0.50 STWHIP Pi 10,270.50 WEXIT !CONTINUE TO RIH. I-CLOSE EDC. 39K UP WT,21K DOWN. Printed 8/21/2017 10:46:29AM `AII depths reported in Drillers Depths* • North America ALASAP Page 4*114 „ ... .. ,f:.. .r 1. f Operation Summary Report Common Well Name.L2-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/10/2017 End Date: X3-018F3-C:(2,840,469.00) Project:Lisburne Site:Lis DS 02 Rig Name/No.:CDR-2 Spud Date/Time:11/12/1985 12:00.00AM Rig Release: Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001090 Active datum:KB @52.00usft(above Mean Sea Level) Date From Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:45 14:20 4.58 STWHIP P • WEXIT COMMENCE MILLING ON WINDOW,(9 5/8"). t`1211— C 1-FOLLOWING THE TIME MILLING 1 PROCEDURE AS LAID OUT IN THE PROGRAM. 1/2- ' -HOLDING TF 12-15 DEG RIGHT OF HS. -2.82 BPM IN/2.82 BPM OUT. 3550 PSI FREE SPIN. -8.99 PPG IN/9.03 PPG OUT. 3715 PSI ON 'BOTTOM PRESSURE. -MANAGED PRESSURE DRILLING....ECD= 11,03 PPG.WOB 0-500 LBS. -WOB UP TO 2.7K BY 10,272.5'.MOTOR WORK=150.PSI. 14:20 - 16:30 2.17 STWHIP P 10,275.00 WEXIT 'CONTINUE,MILLING WINDOW.NOW MILLING 1 FT/HR. r-2.84 BPM IN/2.85 BPM OUT.8.99 PPG IN/ 9.04 PPG OUT. SAMPLE FROM 10,273.6'SHOWS METAL AND CEMENT. 10,274.6'WOB SLOWLY INCREASING. @ 10,274.9'WOB 3K,ON BOTTOM PRESSURE 4000 PSI..350 PSI MOTOR I WORK. -@.16:00 HRS,BLED I/A F/550 PSI TO 450 PSI, (GAS),THEN SHUT IN AS IT WENT TO FLUID. -BLED 0/A F/325 TO 100 PSI.(GAS). 16:30 - 22:08 5.63 STWHIP P 10,281.50 WEXIT CONTINUE MILLING @ 1 FT/HR. -OBSERVE WOB DROPPING OFF TO 2.1K,300 -350 PSI MTR WORK. -WOB CONTINUING TO DROP TO 1.4K.@ 10,275.5'.MTR WORK 250 PSI. -FIRST SIGN OF FORMATION IN SAMPLES AT 10275.5' -CONTINUE DRILLING AT 1 FPH PER WELL PROGRAM. PULLING SAMPLES EVERY 0.5'. 22:08 - 23:30 1.37 STWHIP P 10,286.50 WEXIT END 1 FPH MILLING. START MILLING 5'OF RATHOLE RATE:2.79 BPM IN,2.79 BPM OUT l-MUD WEIGHT:9.05 PPG IN,9.00 PPG OUT DWOB:2.7—3.5 KLBS -CIRC PRESSURE:3830 PSI -ROP AT 3-3.5 FPH -WH PRESSURE=268#/ECD @ 11.03 PPG/ .0578 PSI/FTANNULAR FRICTION -IA/OA PRESSURE=618#/189# 23:30 - 00:00 0.50 STWHIP P 10,286.50 WEXIT PERFORM 1ST BACKREAMING PASS AT 1 FPH -AS DRILLED 0°TOOLFACE 1 -37K UP WEIGHT i -100#MOTORWORK SEEN AT TOWS AT 10261 Printed 8/21/2017 10:46.29AM *AII depths reported in Drillers Depths* 11-4±r WEILFEAD= FMS • S NOTES: H2S 75(PPM)***LNR TOP 1_2-21 ACTUATOR= AXELSONA DAMAGED DURING MIWNG OF QUCKDRILL PLUG KB.ELEV= 52' (12114106)*** REF ELEV= 52' BF 13.EV= 14.89' KOP= 2775' 2202' —14-1/2"I C3 CP2 TRSSSV,ID=3.813" Max Angle= 99"@ 12085' GAS LET MANDRELS Datum MD= 10,861' ST M3 ND DEV TYPE VLV LATCH PORT DATE OatumTVD= 8900'SS VA 5 3024 3015 16 MMG-M MY RK 0 07/20/04 13-3/8"CSG,72#.L-80 BTC,D=12.347"j—i_ 3687' 4 5210 4764 43 MMG M CxuR RK 0 07/19/17 3 6856 5992 42 MMG-M DMY RK 0 11/19/06 ESTMA T tl)TOC --7700' 2 8503 7240 39 MMG-M MY RK 0 07/19/17 \ 1 10235 8531 44 MVIG-M DMY' RK 0 11/19/06 Minimum ID =2.380" @ 11017' ' .CMT BE3ItClNCSG+AROUNDMAY&LATCH-CANT FILL 3-3/16" x 2-7/8" XO _ 10262' _—4-112"BKR MONOBORE WHIPSTOCK w/PP 9-5/8"CSG TOC LOGGED 11/07/16 -{ 10200' S�.•': 'to TAGS(08/05/17) 1 MO Vi4.4 '4' " 10306' -4-1/2"HES X NIP,D=3.813" A TBG PUNCH 4 SPF 12/08/06 ���� ••• 10326' --j9-58"X4-112"BKR(CR)S-3 PKR,D=3.875" ( v ) 1- 10311-10313' ..•..II 1 1 ' 4' '� !'*�" 10346'CTM EST TOC(07/25/17)j 1BG PUNCH,4 SPF(07/23/17) 10401-10406' 'A QIC --al*.-- tei* 10366' ---14-1/2"WFr 1 TRP CMT RET(07/23!17) 1 ;:.4 \ A 10392' H 4-1/2'HES X tom,D=3.813"(06/29/04) TOP OF 7"LNR —, 10423' S kiItir ., ,' 10600' --14-1/2-VVFTCBP(07/23/17)3 ►, ` 5�►. 1--13.70"10699' � {3.70"BKR DEPLOYMBVT SLV,D=3.00" X 4 ,' 10603' —3-1/2"X 3-3/16"XO,D=2.813" 9-5/8"CSG,47#,L-80,0=8.681" --I 10629' i 1� 1♦ I _ Ote 4-112"TBG,12.6#,L-80,.0152 bpf,ID=3.958" — 10661' ti 10661' --4-1/2"VVLEG,D=3.958" 09.;fp Ili.P414A .dItif, a4 p‘k4 N• ,• ►� ► MLLOUT VVINDOW 10756'-10766' 4 0.410760' --ITOP OF SLID LNR FERFORATION SUMMARY � ,• .......• . 11017' —1 3-3/16"X 2-7/8"XO,D=2.380" REF LOG: ;1�♦♦♦♦♦♦♦♦.♦♦♦���� ,',ir�.t ►4,♦♦♦♦♦♦♦♦♦♦♦♦♦♦, . . b ANGLE AT TOP PERF: 46 @ 10760' ►•t••••••♦'0 •• •`** Note:Refer to Production DB for historical perf data ►j • SIZE SPF INTERVAL Opn/Sgz DATE j1 rj (SLOU)LINER "i►�� 10 \44#44"111, .v:+ TT . 10760-11016 0 07/20/04 .j A •..`«••'"- *' , 11018-12127 0 07/20/04 i►• �4 `*�*. t • 12127' P61D II 4• • No VIIII • M4 044 ' '2`y,+, •4 F r LNR,29#,L-80,.0371 bpf,D=6.184" —I 11550' 3-3/16"LNR,6.4#,L-80,.0076 bpf,D=2.80" —{ 11017' 2-7/8"LN2,6.16#,L-80,D=2.441" H 12139' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBUR<EUNIT 11/28/85 ORIGINAL COMPLETION 07/27/17 JMG/JMD GLV C/O(07/19/17) WELL L2-21A 07/20/04 KAK MNO/CTD SIDETRACK 07/27/17 MSS/JMD CMT P&A(07/23/17) FERMI'No:" 041040 11/14/16 JUAN) GLV C/O(11/09/16) 08/07/17 NXW/JMD SET WS w/F63 TAGS(08/05/17) API No: 50-029-21485-01 11/29/16 JMD MINOR PRE-RD CLEANUP SEC 18,T11N,R15E,4503.47'FEL&3908.28'Ft'L 01/30/17 JT/JMJ FRE-RIG CLEANUP 03/09/17 i JNUJMD ADDED REF&BF ELEV BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, September 4, 2017 10:47 AM To: AK, OPS EOC Specialists;AK, OPS GPMA Field O&M IL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Sauve, Mark A; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel, Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer L2-21 (PTD#2041040) Coil tubing sidetrack complete, post rig MIT-IA passed. All, Producer L2-21 (PTD#2170310) is a newly completed coil tubing sidetrack. The rig performed a passing MIT-IA to 2628psi on 8/14/17 proving two competent well barriers. The well is now reclassified as Operable. Please mind fluid pack annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SEP p SCANNED ,. E♦ 201?, From: AK, GWO Well Integrity Engineer [mailto:AKGWOWeIISiteEnginee@bp.com] Sent: • •••• July 24, 2017 7:38 AM To: AK, GWO S A ell Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, • 'CC Ops Lead;AK, OPS LPC DS Operator;Cismoski, Doug A;Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special ' •' ;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Sauve, Mark A Cc: AK, GWO DHD Well Integrity;AK, GWO Proje ell Integrity;AK, OPS FF Well Ops Comp Rep;Sternicki, Oliver R;Worthington, Jessica;Dickerman, Eric;Munk, Corey;O•• • Kristine;Rupert, C. Ryan;AK, GWO Completions Well Integrity;Hibbert, Michael;Janowski, Carrie;Montgomery,Travis ,s•rigewitch, Beau;Pettus, Whitney;Worthington, Aras J;AKIMS App User;AK, OPS EOC Specialists;AK, OPS Prod Controllers; •.s West Area TL;AKOpsProdEOCTL;Burton, Kaity;Duong, Lea;Schultz, Kirsten L Subject: NOT OPERABLE: Producer L2-21 (PTD #2041040) Sidetrack Prep 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission �. SI2iI11 2 17 Jim R �� DATE: 26, 0 TO: Regg � l July P. I. Supervisor FROM: Brian Bixby SUBJECT: Plug Verification Petroleum Inspector PBU L2-21A BP Exploration Alaska Inc. PTD 204-104-Sundry 317-105 - 07/26/2017: Arrived at location and got up with Rob Bryan (BP Wellsite Leader) and talked about witnessing the tag and pressure test of the tubing. This was for the plugback of PBU L2-21A in preparation of redrilling as PBU L2-21 B. Slickline unit tagged the top of cement at 10,203 feet (slickline measured depth) with a bailer; they set down with 150 lbs on the plug. In the process, they got a sample of the cement and pulled out of the hole. Little Red was all rigged up and we did a pressure test on the tubing. BPXA wanted a - minimum of 2500 psi. Tubing (psi) IA (psi) OA (psi) Tbg Pressure Difference Pretest 43 3 126 n/a 15 min 2673 - 89 125 -75 30 min 2645 - 91 126 -28 It appeared to me we got a good tag of the cement and the pressure test was good. Attachments: Pressure Test Chart SCANNED EEB b2118 2017-0726_Plug_V erification_PBU_L2-21 A_bb.docx Page 1 of 1 • • T17T ILLIERSERVICESTNC. JOB REPORT &mows P8 Lk. Lz-zea ern 204-io o) COMPANY DETAILS Company: BP Email: Contact: Phone: JOB DETAILS DATE 7/26/2017 11:13:07AM START TIME 7/26/2017 11:13:07AM Location: L2-21 END TIME 7/26/2017 12:00:56PM Operator: Johnny R Unit#: 42 Ticket#: Test Type: MIT-T Fluid Pumped#1: Diesel Fluid Pumped#2: Fluid Pumped#3: Fluid Pumped#4: Comments: AOGCC MIT-T**PASS'"@ 2645 psi Max applied 2750 psi Target pressure 2500 psi L-WIRELESS 1 TBG(PSI) L-WIRELESS 2 IA (PSI) L-WIRELESS 3 OA(PSI) 2500 2000 1500 1000 500 0 11:15 11:20 11:25 11:30 11:35 11:40 11:45 11:50 11:55 12:00 26 Wed Jul 2017 `AV OF T�� • • e����y/,SSA THE STATE Alaska Oil and Gas F -Z� o f A A Conservation Commission tilitt j__k_ 333 West Seventh Avenue " "� ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *,,, (4' ;-.. , Main: 907.279.1433 ALAlfj.' Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor ", , , L BP Exploration(Alaska), Inc. stisaj P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L2-21A Permit to Drill Number: 204-104 Sundry Number: 317-105 Dear Mr. Egbejimba: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P241U- 1(1- - Cathy . Foerster Chair DATED this Zty of March,2017. RBDIVIB h. o — 3 2U STATE OF ALASKA II,LASKA OIL AND GAS CONSERVATION COMM! APPLICATION FOR SUNDRY APPROVV 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-104• Exploratory 0 Development 0.• 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-21485-01-00 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU L2-21A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028321 &028307 PRUDHOE BAY,LISBURNE OIL POOL - MAR 0 7 2017 11. PRESENT WELL CONDITION SUMMARY l Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 12139 • 8961 • 12139 8961 2456 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 40-120 40-120 1490 470 Surface 3648 13-3/8" 39-3687 39-3622 4930 2670 Intermediate 10593 9-5/8" 37-10630 37-8803 6870 4760 Liner 335 7" 10423-10756 8658-8892 8160 7020 Liner 1530 3-3/16 x 2-7/8" 10599-12139 8782-8961 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10760-12127 8893-8963 4-1/2"12.6# L-80 35-10671 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10335/8596 4-1/2"HES CP2 TRSSSV 2212/2212 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development IZ1 Service 0 14.Estimated Date for Commencing Operations: April 15,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Tempel,Joshua be deviated from without prior written approval. Email Joshua.Tempel@bp.com Printed Name John EgbejimbaTitle Drilling Supervisor Signature 7a. a. hone +1 907 564 4139 Date 0 3/0 7/z 00 7 �- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1� ; l1- l06- Plug Integrity Er BOP Test L9' Mechanical Integrity Test 0 Location Clearance 0 �1 9 ty �Sr --3,651 I,� Other: BCP •tz 5 ! o 3.J CC p5-kc ..-Yiicti.., to c' p 1,-rye vi,f r P f-e-$ f 1 2 c-e /).5 ) Post Initial Injection MIT Req'd? Yes 0 No e Spacing Exception Required? Yes 0 NoFe Subsequent Form Required: 1— /1 b APPROVED BYTHE Approved by:ale" �J __.. _ COMMISSIONER COMMISSION Date: 3 /7 TV7 Z-I3/23 Jl 2 / ORIGINAL , 34/7 RBDMS 1,\-/A1-1,‘' - 3 2017 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /1 5. g,r? bp Sundry Request for Suspension Well: L2-21A(Lisburne Producer,A Lateral) Date: 03/07/2017 Engineer: Josh Tempel MASP: 723 psi from Lisburne(Lateral to be abandoned) 2456 psi from Ivishak(Planned sidetrack) Well Type: Producer Estimated Start date: April 15th, 2017 History: L2-21A is a 3-3/16"x 2-7/8" slotted liner Lisburne producer. L2-21 was originally drilled in 1985, worked over in 2004, and sidetracked with CTD in 2004. The Lisburne A lateral is at the end of its useful life with no viable remaining Lisburne targets. The well is no longer competitive due to low oil production, and the well has no future wellwork options. The well has not been consistently online since 2004 and is currently cycled for 3-5 days every 1-2 months. The well has passed integrity and is fit for a sidetrack. • Scope of Work: The primary objective of this wellwork is to abandon the Lisburne lateral L2-21A by cementing the formation through the slotted liner completion and by achieving zonal isolation between the Lisburne and Ivishak reservoirs. This work is in support of a planned Ivishak sidetrack from the L2-21 parent wellbore. Proposed plan: L2-21 B will be drilled from well L2-21A by the Nabors CDR 2 Coiled Tubing Drilling rig on or around August 1st, 2017. The L2-21B sidetrack will exit through the existing 4-1/2" tubing in the cemented 4-1/2"x 9-5/8" annulus above the production packer. The sidetrack will kick off in the Ivishak targeting, Ivishak reserves. The proposed sidetrack is a 2,238' horizontal producer, which will access reserves in the northern part of DS18. The lateral will be completed with a 3-1/4"x 2-7/8" L-80 liner which will be cemented and perforated. .- The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. r M, � / �i�e� "fres a a+.. Compepr, , � yy'^� 4's Well Foy redf i 11 gOsoCoP a�lo, k r 'gad le carol� Cram At. . 3//y/ • Pre-Rig Work(scheduled to begin April 15th,2017) 1. S Set Dummy GLVs 2. F A/SL: Load IA. MIT-IA to 2500 psi 3. E Tubing punch at 10,343'. Set cement retainer at 10,335' MD. CC 4. F NEL: Load TBG with 1% KCL. MIT-T to 2500 psi L1 5. C Downsqueeze 36bbls of 15.8ppg class G cement JAY �� 6. S Tag TOC. Drift for whipstock to 10,335' MD. ,C 7. F MIT-T to 2500 psi. (Pressure test cement plug) / 1(1�A ,k-v �-a 8. E Set monobore WS at 10,262' MD D� p S 5 9. V Set TWC. \)• 10. 0 Remove wellhouse and level pad. Rig Work(scheduled to begin August 1st,2017) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,456 psi) 2. Mill 3.80"window and 10' of rathole. Swap well to drilling mud. 3. Drill build: 4-1/4" OH, 853' (30° DLS planned). 4. Drill lateral: 4-1/4"OH, 1,385' (12° DLS planned). 5. Run 3-1/4" x 2-7/8" L-80 liner leaving TOL at 10,210' MD. 6. Pump primary cement job: 35 bbls, 15.3 ppg, final TOC at TOL'' 7. Perform cleanout run if needed. 8. Perform liner lap test to 2500psi. ✓ 9. Perforate-600' 7. Freeze protect well to 2,500' MD. 8. Close in tree, RDMO. Post-Rig Work 1. V Pull TWC. Tree Work as Necessary 2. S Set LGLV's. Run RPM. 3. S Set liner top packer if needed 4. F Test liner top packer if needed 5. S Obtain static bottom hole pressure 6. T New well kick off Josh Tempel CTD Engineer 907-891-5930 CC: Well File Joe Lastufka IRLE= ? III smer) VELLFEAD= FMC TES: H2S 75(PPM)"*"UR TOP ACTUATOR= AXELSON L2-2 1 A DNAAGIED DURING MIWNG OF QUICKDRILL PLUG KB.REV= 57 (12t14/06)*** -BF.REV= KOP= 2775' Max Angle= 99',., 12085' bah=TVD Datum11)= 10,861' • 2202' —4-1/2"HES(P2 TRSSSV,D=3.813" _ 8900' = SS _ GAS LFT MILS 13-3/8'CSG,72#,L-80 BTC,10=12,347' —1 368T ST M) TVD DEV TYFE VLV LATCH FORT [ATE 5 3024 3015 16 14C-M OW RK 0 07/20/04 W' I 4 5210 4764 43 MAG-M DOME RK 16 11/09/16 ESTMAA TED TOC H —7700 3 6856 5992 42 P.1.13-PA DAN RIK 0 11/19(06 ' t 2 8503 7240 39 LeiG-N SO FIK 20 11/09/16 Minimum ID =2.380" @ 11017 4: '. 1 10235 8531 44 PAG-LI MY* RK 0 11/19/06 3-3/16" X 2-7/8" XOt: "CM T BBIND IN CSG+AROUM)pal Y&LATCH-CANT PULL „i 7, 9-5/8'CSG TOC LOGGED 11/07/16 H 10200' '4 4 4. WI X oAtt V°....1 Y'T'' 10305' H4-1/2"HES X NP,ID=3.813' 0 t rffl A A-A. 4. • TBG PUNCH,4 SFF(12/08/06) H 10311-10313' 47f" .*1'4 1•• .. 1032W H9-5/8'X 4-1/2'BKR(CR)5-3 PKR,13=3.875" • g 0 Pi • .1 ,' II . 10302 —14-1/2"FES X NP,D=3.813"(06/29/04) w TOP OF 7'LNR —1 10423' , t: R n • %V %V N • 14 4• t4 N . 14 •0. 0 P4 14 , 4• •• 4. 14 0 •• • ,, 106w --III(/'BKR DEFLOYMENT SLV,0=3.00' I ••ti *I 0 ..4s4 110 A 10603' ---13-1r2-X 3-3/16'XO,I)=2.813' 4 • 9-5/8"(SL.,47#,L-80,ID=8.681" --I 10629' , c s , • 0 s, 0 • s, •4 • a , 4 10661' 1—4-1/7'WLD EG, 4-1/2"TBG, 12.6#,L-80„0152 bpf, 0=3,958' H 10661' • •4 .,; — •7 • 0 •4 :••;444 4 61i.••:: MILLOUTIMICOW 10756'-10766' 1 10760' H TOP OF SLED LNR PERFORATION SUIMARY • ,,, ., , , , 11017' —3-3/16'X 2-7/8'XO,ID=2.380T • r w v•vvv,.. , FEF LOG: 0&•••••••••••.• • • 5 4 •••••••• , 5 NZ • *••••••0 • , ANGLE AT TOP FERE 46 ,., 1076(Y . _ _•_•_ _•_••••••• • • • •4 --"1111.1111.— t . '5 Note:Refer to Production CO for historical pert data •4 • • „. SIZE SFF INTERVAL Opn/Sqz DATE lel , , „ I SLOTTED UNBi *4 '• :4 \I 't • , 10760- 11016 0 07/20/04 4 • , • 5, 5 • MIMI PaID 11018- 12127 0 07/20/04 , 0 „ - , 0 • , •4 • . „ 0 'I N. 0 , . 4 • 'i.4.04.it i NI.......0. S. ........4,, L-80,.0371 bpi,D=6.184" — 11550' I 3-3/16'LMR,6,4#,L-80,.0076 bpf,D=2.80' J 11017' 2-7/8"LNR,6.16#,L-80,D=2.441' H 12139' DATE REV BY COMMENTS DATE RB/BY COM LISBURI•E INT 11/28/85 ORGINAL COMPLETION 11/14/16 JUJM) GLV C/0(11/09/16) WR_L: L2-21A 07/20/04 KA K IVO/CTO SIDETRACK 11/29/16 JM) P44OR PRERIG CLEAMJP FERMI hb:It041040 11/21/06 JCMPAG BKR CIUCKDRLL PLUG 01/30/17 JT/J14) PI -RIG CLEANUP API No: 50-029-21485-01 12/20/06 JFPIPAG CMT,TBG FUNCH,PILL PLUG SEC 18,T11N,R15E 4503.4T FEL&3908.28FM_ 01/13/07 JRP/PAG GLV C./0(01/11/07) 03/01/07 RI_ DATUM M) EP Bcploration(Alaska) TREE= WELLHEAD= FMC • SAFOTES: ���� •ACTUATOR= PROPOSED KB.EE\/= 52' REV 3 BF.REV= KOP= 2775' I 2202' 1-14-1/2 HES CP2 TRSSSV,D=3.813" Max Angle= @ ' Datum MD= Datum ND= 8900'SS GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347' H 368T J--41 5 3024 3015 16 MMG-M 0M' RK 0 07/20/04 4 5210 4764 43 MMG-M DOME RK 16 11/09/16 3 6856 5992 42 MMG-M DMY RK 0 11/19/06 Minimum ID =2"377" @ 11100' 2 8503 7240 39 MMG-M SO RK 20 11/09/16 3- 16" X 2-7/8" XO 1 10235 8531 44 MMG-M DMY' RK 0 11/19/06 *CMT BEHIND IN CSG+AROUND DMY&LATCH-CANT PULL 9-5/8"CSG TOC LOGGED 11/07/16 -I 10200' ♦v i TOP OF 3-1/2"X 3-3/16"X 2-7/8"LNR H 10210' ��, C 10210' -13.70"DEPLOY SLV,D=3.00" 3-1/2"LNR, #,L-80 STL, H 10250' ':'i' '1111( 1.4,E AA 10260' -13-1/T X 3-3116"X0,D=2.786" I .0087 bpf,D=2.992" to N i rev • 4-1/2"KB PKR WS w/XL TRAY& H 10262' ';';� MLLOUT WNDOW(L2-216) 10262'-_' RA TAG(_/_/_) 04�. ••, 1.1 1.1.1 11100' 3-3/16"X 2-7/8"XO, TBG PUNCH,4 SPF(12/08/06) -I 10311-10313' 'AtI ..��1 D=2.377" I9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 10326' / 1 PUP JT w/ -- RA TAG ICMT RETAINER(_/ t!) 10336' (TBG PUNCH(_/_/_)I 10340'-10346' ,F,V - ONIMPI , `,I i•• 3-1/4"LNR,6.6#, 11100' L-80 TC11,.0079 bpf, �� TOP OF 7"LNR 10423' 1.110•,0411141441.1 "� .,NO • �.( D=2.85" t:? 4•�4;,�4�( �4••,�1�( PBTD I- 01,0, its 6 '1 Am • k r( 2-7/8"LNR,6.5#,L-80 STL, .0058 bpf,0=2.441" -I 12883' 9-5/8"CSG,47#,L-80,D=8.681' H 10629' • , 1 40! f A t 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" '10661' 4.10410**4 F '•41140•4 648 641 04114141 111,111**0410 0�•••41 MLLOUT WINDOW(L2-21A) 10756'-10766' .40,1141••• 7"WHIPSTOCK(07/02/04) -10763'ELM '41.� •••41k4A4 60.74 ♦4+i 4444••44•@ 7"LNR,29#,L-80,.0371 bpf,D=6.184" -10763'ELM 6N1174-. ♦•'p•••*40, VI n4:•:•i•:• o•' 4• PERFORATION SUMMARY .44 4A4 ,6,41.. REF LOG: ON /_/ 4`kd 1•* •#•44••4• i•4•# •446,41,4,40•404110,.4 •+ Nv ANGLE AT TOP PERF: 0 cQ ••444, 4 . 8444•• •444*.s Nate:Refer to Roduction DB for historical pert data 'N.•10111.4*,• SIZE SPF INTERVAL Opn/Sqz DATE ♦•••• •• •••••••4,4• 4*.• � 4-i I"'TD� 12127' 1 I2-7/8"LNR 6.16#,L-80,-16=-2714-171--i----- 12139'1 DATE REV BY COMIVENTS DATE REV BY COMVB'fTS LISBURINE UNIT 11/28/85 ORIGINAL COMPLETION 03/07/17 JT/AID BUILT PROPOSAL REV 3 VVH-L: L2-218 07/20/04 KAK MO/CTD SIDETRACK PEf214E1 No: t /_ CTD ST(12-218) AR No: 50-029-21485-02 11/29/16 MD BUILT PROPOSED SEC 18,T11N,R15E,1725'FSL&1058'Mt 11/29/16 JM) BUILT PROPOSED REV 1 03/07/17 JT/A/D BUILT PROPOSED REV 2 8P Exploration(Alaska) Well Blank •DR2AC BOP Schematic "pate _ Quick Test Sub to Otis I -1.1 ft — — - Topof7"Otis 0.0ft — —.—.—.—.—.—.—. 't CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub r nr no i `� Top of Annular 7 rf I 7-1/16"Sk Flange X 7"Otis Box U Hydril71/16" Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft e. ,3;-Rob Blind/Shear pp CL Blind/Shears I 3.3 ft I ""'l 2-3/8"Pipe/Slips CL 2-3/8"Com bi's 4.1 ft B5 I 68 """ "' =7 '$ :: DeploymentLine �" aa "" vliK4` 1Mud ! -aar"r III III Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft —* 2-3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft B1 I B2 B3 I B4 Choke Line Kill Line !r• IE:: P:4 "* "l !w •: low.r rr4 wraa w,0� I aaimN Ill III Blind/Shear CL Blind/Shears 10.0 ft �..• 2-3/8"PipelSlips II/ CL 2-3/8"Combi's 10.7 ft - • • uuuuu rv-xiro • CL of Top Swab 13.3 ft Swab 2 Test Pump Hose .m®b 4/Swab 1 CL of Bottom Swab 14.8 ft tIlls.,, 1 T1 Ale T2 CL Flow Tee 16.2 ft I * •�• .. BOP2 CL of SSV 17.5 ft p _ 1 Master 2 Fusable CL of Master Valve 19.0 ft BOP1 AI Master 1 LDS 20.5 ft —moi._ _ „ „ ., .. .. tom. H 11 H II 11 II II II II II Gound Level d,` ed, Ii II II II II • . Roby, David S (DOA) From: Tempel, Joshua <Joshua.Tempel@bp.com> Sent: Friday, March 10, 2017 11:28 AM To: Roby, David S (DOA) Cc: Mclaughlin, Sean M Subject: Sundry application for PBU L2-21A (PTD 204-104) Hi Dave, Your suspicion is correct. I've attached a snapshot of the production for the past couple years. Basically, each spike you see lasts for 4-5 days and occurs every couple months following a shut-in period to rebuild localized reservoir pressure. While the peaks are equivalent to great production,the average total production over a year is uncompetitive. In each event the well is produced until production drops off. Please let me know if this answers your question, and if you need anymore information. Regards, Josh 891-5930 Chart . . s• ■ ■ . . . = o . • is • 0 1200 pec 900 > co • f O • 0 i 600 i rt rt 300 0 04 I 01 '15 02 I 03 1 04 I 01 '16 I 02 Q3 f Oil VoI(bbls) Al-Water Vol(bbls)-e-Gas Vol(mscf) -l-On-Line/OfI Line From: Roby, David S (DOA) rnailto•dave.roby@alaska.gov] Sent: Thursday, March 09, 2017 6:28 PM To: Tempel, Joshua Subject: Sundry application for PBU L2-21A(PTD 204-104) Joshua, In reviewing the subject application the statement is made that the well is no longer competitive due to low oil production. In reviewing production information for this well I notice that when the well is on production it produces in the neighborhood of 350-400 BOPD on a producing day basis,which is a higher daily rate than a several L2 pad wells that are in continuous production, and the GOR and water cut is comparable to other wells. Which on the face of it doesn't sound like an uncompetitive well. I suspect what is happening, and why the well is considered uncompetitive, is that when the well is brought online you get great flush production for a day or two but then the well dies after a couple of more days and you have to wait a month or so for the well to recharge before it can be brought back on production. Is my assumption correct,or is there another process in play here that makes this well an uncompetitive producer? 1 • • Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@alaska.gov. 2 S Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist,, in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). fi 2 If the "Abandon"box is checked in Box15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial thea 1 it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. 7" r- • • o mCD o O > W 1 W 0 UJ E " 3' C 4 73 0NW v O P \., m ) ° N OA ? CO N Q Y N,.,.::.N. r0 4- 0.1 N ate- + ~ u O > ..:� .' D: co a C OC 0 v O C a M "0 y_ CU o a c C v �. Q Q o E a a m Q a W to 4) .- .- .- tO C a) � o o N Q r_ 0 O 0 0 U L -0 N U CL W O Z Z Z Z Q C CCp u Cl., G ii � Q co r 4 e4- N N u0 v \ �C+ crl V Z Q v > E -a vQ , a-, O C cr. '' u +' ro O CO v p N u C i N I-0 0000001 pA C w= } wwwwww N v 'L H LL LL LL LL LL LL , N iv 0 -C 0 Q J J J J J J a C w w 0 Q z z z z z z CD av 0 � - LL U.. L.L. LL LL LL CC -0 C f D � > - N E a) r0 C 41 = O A E v u N h. .� = a n 2 I- c u a o "o ttl "� µ v tV y F F' Q N a C a Ni. bO p � a 0 w a ' . V J J J ms ` d d tt R E U �, CO UU E Ezli WU N 1+1 42td J U U Q) 1�. LI o V ® Q C7 W N is toS )v�• P'i I \ 04 ►/ CC CO w 0 T T T T T C > a J O O O O O ` Q 8 z `' w aEi aEi waEi m v p.... no CP, f Q CD 61.8 40" A E Z m Z m m m m z o L1.1 0 0 0 r0 Qimiiii4.4 J O N Q Q Q Q v T A .I' a. 11 FT- C‘ CLCLCLCC 0 a a a a a ro u Aii '� ( , °A f6 v W r O t- CO M CO X V1 N Q O N N M t{ C r O o O O O CO Ems (iV IR 0 0 0 0 0 0 V 0 0 0 0 0 0 V (� O O O O h G (-) ® a N N N N 2 et Y !1J w Q Q Q Q Q Q m wO O M N 0 O O O O O Oon Q (4 If) O M U) t` 71E 0 CO c0 M et O n r N O e ,_ O'. - e- 0 - 0 0 V N N N N N N N g OO O O O) ) N N N N N N L 0 0 0 0 0 O 7 )O )n )n 10 is, u) a u 4"' w un c c C7 S1 E `u' m v U. d +. CC C C Q7 u Q uw C a'i 9 Z a Z co to r O a+ S 4.4 Ln �) I- OTCeI ? J.1-1 _, c� O o M E co a a Q O N 0 J 4- o U D '^ Z tll ts, .. OCA aLba2. F- a` aQ'' e e Image Project Well History File Cover Page XHVlE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q Y- - J º l.J- Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 111111111111111111I R5ßCAN '¢' Color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: o Other:: BY: ( Maria J Date ß I:v¡ /0 to 151 mP BY: ~ III 1111111111111111 Date gj;).9 /0 b /s/ V11f ~ x 30 = h' 0 + ;}. d-.. = TOTAL PAGES 'is':i- Date g / ~ /0 b (Count does nOU~~;~I~ I~;;~;II;~~; ~~ Project Proofing Scanning Preparation BY: CMaria ~ Production Scanning Stage 1 Page Count from Scanned File: 7S'.3 (Count does include cover sheet) 0ES NO Stage 1 Page Count Matches Number in Scanning Preparation: ~ Date:'i?/~q /O(p If NO in stage 1, page(s) discrepancies were found: 151 \1\11' BY: YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 1II11 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. RECEIVED' j 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 AUG 31 2011 Anchorage, Alaska 99519 -6612 Oaks 011 & Gars toot. Scmrnission Anctr rage August 22, 2011 I L Mr. Tom Maunder 4 Alaska Oil and Gas Conservation Commission J 333 West 7 Avenue Anchorage, Alaska 99501 S .r= Subject: Corrosion Inhibitor Treatments of GPMA L2 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 02 Date: 7/7/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 L2 -13A 1980780 500292144001 Top Plate NA NA NA NA NA L2 -14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA C L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA • • ~sps-~~-^fii~~ffic""-^,y -,.. .; °_ ~: MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc 01;'" E1~~ (\ f:: ~ '\l~.;L- fr~)u If"\, ¡\---, ~"--../' n~ ¡. fL..., ¡J.._ rì('" ~' .~ 0 200::" '.' j J. _ 1,1 10/06/06 Sc~lum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth J{Ji(- / DL( J\RSUt.O.'6I Oil r) (' r' " r")\~\T' ,'('1;:;1"'''1'1 ~0 ..nn r,\ ,~"i1~~¡u!m~, uC,PI",/I,\·""..··u:11 NO. 3982 . At~chPrag~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL 3-29/J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 1 L2-21A 11421023 LDL 09/11/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 A-17 11414381 USIT 09/07/06 X-01 11422961 US IT 09/09/06 H-04A 11285942 SCMT 09/17/06 15-39A 11212888 SCMT 09/16/06 C-09A 11209608 MCNL 06/16/06 C-18A 11285934 MCNL 07/29/06 Z-14B 40013765 OH EDIT OF MWD/LWD 07/31/06 Color CD 1 1 1 1 1 ( Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED OCT 3 1 2005 Permit to Drill 2041040 MD 121~ ~ '1 *'A. ~~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Well Name/No. PRUDHOE BAY UN LIS L2-21A Operator BP EXPLORATION (ALASKA) INC AP!l.~{029!~~r:~ TVD 8967 ..--completion Date 7/24/2004 -- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlROP/PRESS, CMUMDIDLUSHE, CMUMDITVD/PDDSN, CMUM Well Log Information: Logl Data Digital T)'p;.- Med/Frmt /5Ø D Asc Rpt ~LiS Rpt ¿.k69 L~ Electr Dataset Number 13803 13803 Name Directional Survey Directional Survey Gamma Ray ç.:"m"1õ1 ROIj 1.. t~ Gamma Ray Gamma Ray Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? y\E) Chips Received? ~ Analysis Received? Comments: ~ Compliance Reviewed By: ~ .; Log Log Scale Media Run No Ue"'J~~....J:;;::.. MD jV t> 25 Blu 5 Blu Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval Start Stop 10753 12139 10753 12139 10765 12139 10765 12139 10765 12139 10765 12139 . OHI CH Received Comments 9/3/2004 MWD 9/3/2004 MWD 3/13/2006 GR ROP 3/13/2006 GR ROP 3/13/2006 GR ROP 3/13/2006 GR ROP Open Open Open Open Sample Set Number Comments ~: . Date: ~3 ~~c" . . Scblumberger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well NK-43 NK-22A l4-12 l2·21 A 13-06A 01·178 09-08 09-19 09-25 04-09 04-10 17-21 18-038 X-15A J-018 15-12A Z-148 S-400 D-03A 05-28A Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 11211388 10568415 N/A 10670034 11217266 11209602 11296705 11296704 11296703 11211398 11211380 11223104 11057071 11212877 11511430 11221595 11217268 10987564 11217269 11217267 :jcll - ¡ DL/ log Description PROD PROFILE W/DEFT PROD PROFilE W/DEFT WFUlDl MEM PROD PROFilE INJECTION PROFilE MEM PROD PROFILE INJECTION PROFilE INJECTION PROFilE INJECTION PROFILE INJECTION PROFILE INJECTION PROFilE PROD PROFilE W/DEFT SBHP US'T US IT USIT US IT CH EDIT PDC-GR OF USIT USIT USIT Date 04/02/06 02/26/03 05/09/06 09/20/04 07/12/06 04/27/06 07/21/06 07/20/06 07/19/06 04/28/06 03/23/06 03/22/06 12/02/05 07/18/06 07/24/06 07/25/06 07/29/06 01/26/06 07/31/06 07/28/06 R~v¿~ V 1-Ù AUG 0 8 2006 08/01/06 .~ Oil & Gas Cons. Co~ NO. 3883 Ançhorage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Problem Well Notice: L2-21A (PTD 2041040) . . Hello all. Well L2-21A (PTD 2041040) has been classified as a Problem well. A recent TIFL failed and the well is capable of unassisted flow. TIO's on 6/27/06 are 1430/1200/290. Current plans: - Set TTPIWRP - CMIT TxlA, LLR - Eval for LDL Attached is a wellbore schematic. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com «L2-21A.pdf» Content-Description: L2-21A.pdf Content-Type: application/octet-stream Content-Encoding: base64 10fl 7/13/20062:18 PM TREE = _? WElLHEAD = FMC ].CcrGiATOR';,- AXElSON ~~~n~ "^~~>~"'~";"~"'~_~<'~ ~ KB. ELEV " 52' " _ ~ C~ _~~_ ~.._~~·,,~.«_~~m'm BF. ElEV = ~>~~m~,,~ ..'_~>~~~'~ KOP = 2775' MäxÃngle = 99 @ -1"20ás;^ Dãtu^;;;MD = ~- 1"Õ692~ Datum TVO = 8800' SS . 113-3/8" CSG, 72#, L-80, 10= 12.347" H 3687' Minimum ID = 2.380" @ 11017' 3-3/16" X 2-7/8" XO TOPOF7" LNR H 10423' I 19-5/8" CSG, 47#, L-80, ID = 8.681" H 10629' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10'" 3.958" H 10661' PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 46 @ 10760' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LINER 10760 - 11016 0 07/20/04 11018 - 12127 0 07/20/04 rLNR,29#,L-80,.0371bpf,10"6.184" H 11550' I DA TE REV BY COMMENTS 11/28/85 ORIGINAL COMPLETION 07/20/04 KAK RWO / CrD SIDETRACK 07/26/04 DAV/KAK GLV ClO . 09120104 TMNITLP Sl TO LNR TOP CORRECTION 06/25/06 OTRlPJC GL V ClO DA TE REV BY l2-21 A ~TES' H2S75 (PPM) . --1 2202' H4-1/2" HESCP2TRSSSV, 10=3.813" I ~ .. GAS LIFT MANDRElS ST MD TVD DEV TYÆ VLV LATCH PORT DATE L 5 3024 3015 16 MMG-M OMY RK 0 07/20/04 4 5210 4764 43 MMG-M DOME RK 16 07/26/04 --- 3 6856 5992 42 MMG-M DOME RK 16 07/26/04 2 8503 7240 39 MMG-M DOME RK 16 07/26/04 1 10235 8531 44 MMG-M SO RK 22 06/25/06 10305' -j4-1/2" HESXNIP, 10=3.813" I 6 6---i IIf I r~ ... ... ~~ I \ - 10326' H9-S/8" X 4-1/2" BKR S-3 PKR, 10" 3.875" I 10599' -{3.7" BKR DEPLOYMENT SLY, ID" 3.0" 10603' H3-1/2" X 3-3/16" XO, 10 = 2.813" I I MllLOUT WINDOW 10756' - 10766' I 10760' H TOP OF Sl TO LNR I , I 11017' H3-3/16"X2-7/8"XO,10=2.380" I , '/ "" 'y , I 12127' HPBTD I ',', f ' , , , , , , , , , ' , " " ... , ~' ! 3-3/16" LNR, 6.4#, L-BO, .0076 bpf, 10 '" 2.80" H 11017' I [2-7/8" LNR, 6.16#, l-80, 10 = 2.441" H 12139' I COMMENTS LlSBURNEUNff WElL: L2-21A ÆRMff No: '2041040 API No: 50-029-21485-01 SEe 18, T11 N, R15E, 4503.47' FEl & 3908.28' FNL BP Exploration (Alaska) - . Transmittal Form r&l_ BAKE. HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: L2-21A Contains the following: 1 LDWG Compact Disc J4 I j 1 () '7 (Includes Graphic Image files) i1 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log LAC Job#: 709876 Sent By: G" 'orel /1 ~ /1 Re<eived By: ~ð~ Date: Mar.07,2006 Date: I J IIfvt)}j Û l; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ 0 l.{ -(Q c.( II _.._~,..._ I I .IW~.;"'¡' ~,"'.'_.".,"~.,-_.-':!--"-."'.---'~j': t l:~ ~:; . n> Ø!~II:tØ\. ~,'!'._- --~- ---' -~t-~ _~____'~~;.ti~_ ;ø.'f',¡/i(I-,I\>;o;¡. .....,., "" "... ....~ _JI''' ",.-"".. "':''"''''>"':- I ! t ¡ ¡ ¡ ! f . I i~É~ -""""~''¥:I;!. __ _ .".- ..1.l'I!i:-: "'.... ".,. u =~~A' ~~~~:~ ~ ;-¡. ~,-...,,_._.. .-<. F:f-Æ -'<0 _ STATE OF ALASKA _ ECEIVE ALAS~IL AND GAS CONSERVATION CO.SSION REPORT OF SUNDRY WELL OPERATIONSCT 152004 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AI< 99519-6612 7. KB Elevation (ft): 52.00 8. Property Designation: ADL-028307 11. Present Well Condition Summary: Repair Well 0 Pull TubingD Operation Shutdown 0 on & f;as Stimulate 00 Othe~hoHig¡'2i WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 204-1040 6. API Number 50-029-21485-01-00 PluQ PerforationsD Perforate New Pool D Perforate D 4. Current Well Class: Development 00 Total Depth measured 12139 feet true vertical 8967.0 feet Effective Depth measured 12139 feet true vertical 8967.0 feet Casing Conductor Liner Liner Liner Liner Production Surface Length 79 333 4 414 1122 10591 3648 Perforation depth: Size 20" 91.5# H-40 7" 29# L-80 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L·80 Measured depth: 10760 - 11016, 11018 - 12127 True vertical depth: 8899.51 - 8980.39, 8980.37 - 8968.86 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: L2-21 A 10. Field/Pool(s): Prudhoe Bay Field I Lisburne Oil Pool Plugs (measured) Junk (measured) None None MD TVD Burst Collapse 40 119 40.0 119.0 1490 470 10423 - 10756 8664.5 . 8896.7 8160 7020 10599 - 10603 8787.7 - 8790.4 10160 10530 10603 - 11017 8790.4 - 8980.4 11017 - 12139 8980.4 - 8967.0 13450 13890 38 - 10629 38.0 - 8808.5 6870 4760 39 - 3687 39.0 - 3622.8 4930 2670 @ 36 10671 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer 4-1/2" HES CP-2 10 TRSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10900 - 12050 Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Signature Form 10-404 Revised 4/2004 @ 10336 @ 2212 774 Bbls 15% HCL @ 3750 psig Oil-Bbl 588 654 Representative Dailv Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 3.6 0 775 3.8 0 1540 Tubing Pressure 542 557 ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ ServiceD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron -,tf~. ~~ WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant Phone 564-4657 Date 10/13/04 lîl L RßcPtf'E ~ . . L2-21 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/10104 ACID STIMULATION: LOAD WELL WI 200 BBLS FILTERED 2% KCL (FLUID PACK). RIH WI 2" JSN JETTING 100 BBLS DIESEUXYLENE FROM 1500' TO 8000' (NO SIGN OF HEAVY PARIFFIN). INJECTIVITY TEST WI ALL DIESEL IN WELLBORE: 710 PSI AT 2 BPM; 1040 PSI AT 4 BPM. RUN DOWN TO 12070' CTM (BELOW TREATING INTERVAL- ALL CLEAR). BEGIN TREATING FROM 10900' WI 15% HCL DOWN TO 11710'. STAGE 8 IS IN PROGRESS. CONTINUED ON 09/11/04 WSR. 09/11/04 CONTINUED FROM 09/10104 WSR. CONTINUE WI STAGE 8 AND 9 OF 15% HCL DOWN TO 12050' @ MAX RATE OF 3.5 BPM/O WHP. TOTAL 774 BBLS ACID. JET 150 BBLS FLUSH OF 2% KCL WI ADDITIVES ACROSS 12050'-10900'. POOH TO 9335' AND PERFORM INJ TEST DOWN BACKSIDE WI DIESEL. POST INJECTIVTY = 50 PSI WHP @ 4 BPM (PRE-INJ WAS 1040 PSI WHP @ 4 BPM). POOH, FREEZE PROTECTING COIL WI WATER/METH. WELL TURNED OVER TO ASRC FOR FLOWBACK & SAMPLING. FLUIDS PUMPED BBLS 241 2% KCL 100 80/20 Diesel/Xylene 774 15% HCL 170 Diesel 158 2% KCL w/0.2% F103 + 0.2% W54 49 50/50 Methonal 1492 TOTAL Page 1 " TREE = WELLHEAD = ACTU>ÜOR;' KB. ËLEiJ ,,; SF. B.EV = Kop = ~.....~~... MIx Angle = Datum M) = Datum TVD = ? Fr./C AX~ËlSbN m "--52' . 27"75' 99 @ 12085' 10692' 8800' SS 113-318" CSG, 72#, L-80, ID= 12.347" H 3687' ~ IMinimum ID = 2.380" @ 11017' I 3-3/16" X 2-7/8" XO TOPOF7" LNR H 10423' 1 19-5/8" CSG, 47#, L-BO, ID = 8.681" H 10629' 14-1/2"TBG, 12.6#, L-80, .0152bpf, ID= 3.958" H 10661' PERFORATION SUM'vIARY REF LOG: ANGLEATTOPÆRF: 46 @ 10760' Note: Refer to Production DB for historical perf data SIZE SPF INlERV AL OpnlSqz I)L\ TE SLOTTED LINER 10760 - 11016 0 07f20104 11018-12127 0 07f20104 17" LNR, 29#, L-80, .0371 bpf, ID= 6.184" H 11550' DATE REV BY COM'vlENfS 11/28/85 ORIGINAL COM PLETJON 07/20/04 KAK RNOI CTDSIŒTRACK 07/26/04 I)L\V/KAK GLV C/O I)L\ lE REV BY L2-21A I .~ - . SAFETY NOTES: H2S 75 (PPM) 2202' H4-1/2" HES CP2 l'RSSSV, ID = 3.813" I ~ ST GA S LIFT fIM NDRB.S MD TVD DEV TYÆ VLV LATŒi PORT DATE L-~ 3024 3015 16 M'vIG- M DMY RK 0 07/20/04 5210 4764 43 M'vIG-MDOME RK 16 07/26/04 3 6856 5992 42 M'vIG-MDOME RK 16 07/26/04 2 8503 7240 39 M'vIG-M DOME RK 16 07/26/04 1 10235 8531 44 M'vIG- M SO RK 22 07/26/04 . ~ Z Z-i ... I ~~ All ~ y I , ~ 10305' H4-1/2" HES X NIP, ID= 3.813" I 10326' 1-l9-518" X 4-1/2" BKR 5-3 A<R, ID = 3.875" I 10599' H3.7" BKRDEPLOYIllENTSLV, ID = 3.0" 10603' H3-1/2"X3-3/16"XO,ID=2.813" 1 MLLOur WlNOOW 10756' - 10766' I 11017 H3-3/16"X2-7/8"XO,D=2.380"1 , ,'" ,( , , ' , I 12127 ~ ',', j , , , , , , " , " ' '" ...... "' I ~ 3-3I16"Lf'.JR,6.4#,L-80,.0076bPf,ID=2.80" H 11017 1 12-7/8" LNR, 6.16#, L-80, ID= 2.441" H 12139' I COMIllENTS LISBURNE ll'J1T WELL: L2-21A PERMIT No: 2041040 A A No: 50-029-21485-01 SEC 18, T11N, R15E, 4503.47' FB. & 3908.28' FNL BP Exploration (Alaska) · STATE OF ALASKA I ALASKA~L AND GAS CONSERVATION COMMI'SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GR I ROP I PRESS, CML I MD lOLL ISHE, CML I MD I TVD I PDDSN, CML / MD I TVD I CS, CML I MD I TVD I DLL I SHE CASING, LINER AND CEMENTING RECORD SEI'!"Níi>Ds.ett-t MD $eTr1f' G·DêP1êflT'\1Ø ToÞ BOTTOM BOTTOM Surface 119' Surface 119' Surface 3687' Surface 3623' Surface 10630' Surface 8810' 10423' 10758' 8665' 8898' 10599' 12139' 8788' 8967' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1726' NSL, 1058' EWL, SEC. 18, T11N, R15E, UM Top of Productive Horizon: 1232' NSL, 3915' WEL, SEC. 13, T11N, R14E, UM Total Depth: 598' NSL, 3485' WEL, SEC. 13, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 692749 y- 5963620 Zone- ASP4 TPI: x- 687791 y- 5963001 Zone- ASP4 Total Depth: x- 688237 y- 5962378 Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. 20" 13-3/8" 9-518" 91.5# 68# I 72# 47# 29# H-40 K-55 I L-80 L-80 L-80 L-80 7" 3-1/2" x 3-3/16" x 2-7/8" 8.81# / 6.4# / 6.16# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/16" Slotted Section 2-7/8" Slotted Section MD TVD MD TVD 10760' -11017' 8900' - 8980' 11018' -12127' 8980' - 8969' 26. Date First Production: July 27,2004 Date of Test Hours Tested PRODUCTION FOR 8/5/2004 18.7 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 510 1,710 24-HoUR RATE One Other 5. Date Camp., Susp., or Aband. 7/20/2004 6. Date Spudded 7/412004 7. Date T.D. Reached 7/14/2004 8. KB Elevation (ft): 52' 9. Plug Back Depth (MD+ TVD) 12139 + 8967 10. Total Depth (MD+TVD) 12139 + 8967 11. Depth where SSSV set 2202' MD 19. Water depth, if offshore N/A MSL RECElveö AUG 1 720a4 1 b. Wel~a~': Oil & 063 Cons. ComtT'ssion IBI Development ~f!~IðiU8ry o Stratigraphic 0 Service 12. Permit to Drill Number 204-104 13. API Number 50-029-21485-01-00 14. Well Name and Number: PBU L2-21A 15. Field I Pool(s): Prudhoe Bay Field I Lisburne Pool Ft Ft 16. Property Designation: ADL 028307 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 30" 1810# Poleset 17-1/2" 2500 sx AS III, 600 sx Class 'G' 12-1/4" 1126 sx Class 'G', 300 sx AS I 8-112" 450 sx Class 'G' 4-1/8" x 3-3/4" Uncemented Slotted Liner SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 10661' PACKER SET (MD) 10326' DEPTH INTERVAL (MD) 10600' AMOUNT & KIND OF MATERIAL USED Freeze Protected with Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl GAs-McF WATER-Bsl 170 662 1 Oll-Bsl 218 GAs-McF 849 WATER-Bsl 3 CHOKE SIZE I GAS-Oil RATIO 176 3,895 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit ~~~~;_~~one, state "none". AlIG 1 ~ 'In\\~ None;;¡j¿/ .-BFL .' .~.~ j ORIGINAL Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 2ß· e GEOLOGIC MARKERS NAME MD TVD Top of Wahoo Zone 6 (From 10732' 8880' L2-21) 10790' 8919' Wahoo Zone 6.1.2 10838' 8942' Wahoo Zone 6.1.1 10865' 8953' Wahoo Zone 5.3 10979' 8981' Wahoo Zone 5.2 11179' 8992' Wahoo Zone 5.1.2 11870' 8995' Base Wahoo Zone 5.2 29. e FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", None E.C~\\Jt.D ~ . "'1\\\\~ 1\' \\') \ ~ ~~\()\\ r'\ Y . C,()",rol;> ce"'!I· .~ $. ~t' .. ~~.,~~t)\. . ,,~(.\\~(~~ ~ 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble~~ .~ PBU L2-21A 204-104 Well Number Title Date ()8~' Co <JCf Technical Assistant Permit No. / Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mark Johnson, 564-5666 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 ORIGlr~AL Submit Original Only e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 6/23/2004 04:00 - 06:00 2.00 MOB P PRE Perpare to move from DS 18-33A to L -21. Accept rig at 0600 hrs on 6/23/04 06:00 - 07:45 1.75 MOB P PRE Move from DS18 to L2 pad. Set mat boards down around wellhead. Set spill dikes prepare to move onto well. IAP=TP=O, OAP=50 psi. SSV, MV, SV closed. 07:45 - 08:10 0.42 MOB P PRE Safety meeting prior to moving over well. 08:10 - 08:45 0.58 MOB P PRE Move rig over well. 08:45 - 12:15 3.50 RIGU P PRE Set rig down over well. Rig up hard line to flowback tank. Set cuttings box. Fill pits with KCL. Install integral flange on companion valve, and jumper hose to cellar manifold to kill well. 12:15-15:45 3.50 KILL P DECOMP Pump down the tubing, taking returns thru bottom GLM with an empty pocket, backside open to take returns. Kick on pumps pumping 4 bpm, getting no returns. All fluid going into the formation. Pump 120 bbls to flush tubing. Swap to pumping down the lA, taking returns from the tubing. On line at 6.5 bpm, 830 psi. After 300 bbls away, started getting slight returns from the tubing. Pump 800 bbls down the IA. Swap back down the tubing pump an additional 100 bbls. 15:45 - 16:05 0.33 BOPSUP P DECOMP Safety meeting Re: Setting BPV and ND tree. 16:05 - 18:00 1.92 BOPSUF P DECOMP Set BPV, ND production tree. 18:00 - 19:00 1.00 BOPSUP P DECOMP Install blanking plug in tbg hanger neck. RU kill line to 9-5/8 x tbg anulus. Fill hole with 35 bbls. Noted leaking sssv line through hanger. Cannot easily "plug" leak mechanically. Install lower crossover flange. Pack top of tbg hanger with gel/water paste. 19:00 - 23:00 4.00 BOPSUP P DECOMP Continue to NU bops. Pump 30 bbls every hour down tbg ann. Install variable, blind, annular and mud cross components. 23:00 - 00:00 1.00 BOPSUF P DECOMP NU riser components. Silicone seal same. Inspect riser boot seals. COntinue to pump 30 bbls per hour down tbg ann. 6/24/2004 00:00 - 01 :30 1.50 BOPSUP P DECOMP Continue to torque all connections on BOP equipment. 01 :30 - 03:00 1.50 BOPSUF P DECOMP Begin loading 3-1/2" PH-6 drill pipe into pipe shed. Drift & strap same. Bring Camco spooler in through pipe shed and spot on rig floor. 03:00 - 06:00 3.00 BOPSUF P DECOMP MU hydraulic control lines to BOP components. Function test BOPs. Continue to load drill pipe. 06:00 - 07:15 1.25 BOPSUF P DECOMP Pull mousehole. Hook up 2" line from charge pump to IA. Pump 30 bbls to fill IA. Continue to pump 15 bbls every 30 minutes to keep IA full. 07:15 - 14:30 7.25 BOPSUP P DECOMP Pressure test BOP stack. Perform body test, pressure held like a rock. The gel on the tubing hanger worked great. Continue with BOP test. All passed ok. 14:30 - 14:45 0.25 PULL P DECOMP Pull FMC blanking plug out of profile in tubing hanger. 14:45-16:10 1.42 PULL P DECOMP Pull BPV from profile in tubing hanger. 16:10 - 17:00 0.83 PULL P DECOMP Pump a tubing volume to clear tubing prior to pulling tubing hanger. 17:00 - 19:00 2.00 PULL P DECOMP Pull tubing hanger to floor and lay down. RU to LD tubing. Begin spooling sssv lines. Small flow of diesel from tbg annulus. Complete loading 3rd layer of PH6 work string in pipe shed to facilitate rolling tubing to pipe elevator. Hold PJSM with night crew to discuss job. 19:00 - 22:00 3.00 PULL P DECOMP Lay down 2-7/8" 8rd EUE tbg. SSSV lines pulling ok. Recovered 70 of 72 stainless control line bands. Install thread Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/23/2004 7/20/2004 N2 Spud Date: 6/23/2004 End: 7/20/2004 6/24/2004 19:00 - 22:00 3.00 PULL P DECOMP protectors. Verify pipe is dry before placing on sills out on pad. Add displacement every 15 joints and an additional 20-25 bbls seawater every hour. Able to get fluid to surface. 22:00 - 00:00 2.00 PULL P DECOMP At sssv. RU to fill tbg and displace diesel from back side. Pump 1.5 bpm in/1.1 0 bpm out, 30-40 psi pump pressure. Take diesel rtns outside. 6/25/2004 00:00 - 01 :00 1.00 PULL P DECOMP Continue to circulate diesel & crude from tbg annulus. 2.0 bpm in 11.4 bpm out rate at 250 psi pump pressure. 01 :00 - 01 :30 0.50 PULL P DECOMP Shut down pump. Monitor well for flow. Remove SSSV. RD spooler. 01 :30 - 06:00 4.50 PULL P DECOMP Continue to POOH with 2-7/8" completion. Fill hole with seawater as required 06:00 - 10:20 4.33 PULL P DECOMP 200 joints of 2-7/8" OOH at 06:00, continuing to pull tubing I completion jewelry. Another 127 joints to go. 10:20 - 11 :30 1.17 FISH P DECOMP All 2-7/S" tubing recovered down to the PBR seal stem. All seals recovered on seal stem, it looks good. Layout recovered GLM's, and last of 2-7/8" production tubing. 11 :30 - 15:30 4.00 FISH P DECOMP Load last 100 joints of 3-1/2" PH6 and strap. Load 16 4-3/4" drillcollars and fishing BHA. 15:30 - 16:00 0.50 FISH P DECOMP Set wear bushing. 16:00 - 16:15 0.25 FISH P DECOMP Safety meeting pre making up fishing BHA. Found wrong size wear bushing in hole for packer we are fishing. Tool Service inspected all completion equipment for norm. None found. 16:15 - 17:15 1.00 FISH N HMAN DECOMP Contact FMC. Get a fullbore wear bushing brought out to rig. Standby on hand & wear bushing. 17:15 - 17:30 0.25 FISH N HMAN DECOMP Retrieve first wear ring. Set new wear bushing. RILDS. 17:30 - 17:40 0.17 FISH P DECOMP Safety meeting re: BHA. 17:40 - 18:45 1.08 FISH P DECOMP RU floor to make up Fishing BHA #1 (spear, collars, jars, accel) 1S:45 - 19:00 0.25 FISH P DECOMP Hold PJSM with night crew regarding plan forward & BHA handling. 19:00 - 22:00 3.00 FISH P DECOMP MU spear, 164-3/4" drill collars, jars & accel. 22:00 - 00:00 2.00 FISH P DECOMP PU 3-1/2" PH6 singles from pipe shed. Drift each joint while picking up. Fill hole every 1 hr with +1- 30 bbls seawater. 6/26/2004 00:00 - 02:00 2.00 FISH P DECOMP Kelly up at 50 stands. Tighten same. 02:00 - 02:30 0.50 FISH P DECOMP Circulate 2 dp volumes to ensure rust & scale are cleared. Stand back kelly. 02:30 - 06:00 3.50 FISH P DECOMP Continue to pick up 3-1/2" PH6 singles from pipe shed, with fishing BHA#1 (spear). Continue to fill hole every hour, taking +1- 30 bbls per fill. 06:00 - 09:00 3.00 FISH P DECOMP Continue to PU 3-1/2" PH6 workstring in singles from pipe shed. Dropping a drift thru every joint. 135 jts run, 175 jts to go. IAP=O, OAP=O, Pit vol=330 bbls. Filling the hole 30 bbls/hr by pumping accross the top. Pumping 1.5 DPV down the pipe every 50 joints to flush rust etc out. 09:00 - 11 :00 2.00 FISH P DECOMP 200 Joints in, 112 to go. Fill the DP with 1.5x volume. 11 :00 - 13:30 2.50 FISH P DECOMP 250 Joints in, 62 to go. Fill the DP with 1.5x volume. 13:30 - 14:00 0.50 FISH P DECOMP Pick up Kelly. 14:00 - 14:25 0.42 FISH P DECOMP Check weights. PU=147klbs, slack off=105 klbs. Circulation pressures are 1270 psi at 3 bpm, 645 psi at 2.0 bpm. Slack off and engage fish. PU to 210 klbs jar 2 licks. PU to 230 klbs jar 1 lick. PU to 250 klbs jar 1 lick. Stack 10 klbs, and PU with fish moving at 25 klbs over. Engaged fish at 10312' DPM. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 6/26/2004 14:00 - 14:25 0.42 FISH P DECOMP Pulled up hole 20'. 14:25 - 18:30 4.08 FISH P DECOMP Circulate bottoms up prior to pulling fish to surface. 18:30 - 18:45 0.25 FISH P DECOMP Shut down pump. Monitor well for flow. Hold PJSM to review job assignments & sim ops while tripping out of hole. 18:45 . 00:00 5.25 FISH P DECOMP Stand back kelly. PU H-YT elevators. POOH. Having to pull very slow due to swabbing. (2-3 min per double). Load pipe shed with 4-1/2" IBT-M pipe. Drift and strap same for completion. Stage completion jewelry on location. 6/27/2004 00:00 - 06:00 6.00 FISH P DECOMP Continue to POOH with straddle fish. Well continues to swab. Pulling very slow. 06:00 - 06:45 0.75 FISH P DECOMP Crew change and PJSM prior to breaking down BHA. 06:45 - 07:30 0.75 FISH P DECOMP Stand back 8 stands of drill collars, lay down jars and bumper sub. 07:30 - 11 :15 3.75 FISH P DECOMP Lay down fish, including; spear, 9-5/8" packer, 2-7/8" tubing, blast joints and chemical cut pup joint. All recovered ok. Found 2 missing control line bands on top of 9-5/8" packer. Found 9 perf holes in first full joint of 2-7/8" tubing below the packer. Found top 18" of the 4' chemical cut pump joint on bottom of the last blast joint. All rubber elements recovered off of packer. All is as expected. 11 :15 - 14:30 3.25 CLEAN P DECOMP Make up BHA #2, 7" & 9-5/8" casing scrapers to clean casing for completion. 14:30 - 18:00 3.50 CLEAN P DECOMP Trip in hole with 3-1/2" PH-6 work string. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change out and PJSM to discuss operations. 18:30 - 22:30 4.00 CLEAN P DECOMP Continue to RIH with tandem csg scrapers on PH-6 workstring. Well still taking 30 bph. Switch to 2%KCL water. Seawater plant is tied up loading water for Nabors 7ES. 22:30 - 00:00 1.50 CLEAN P DECOMP Continue to RIH. Load additional 19 jts PH6 in pipe shed for BHA. Drift & strap same. 6/28/2004 00:00 - 00:30 0.50 CLEAN P DECOMP Reach TD of 10801' with 7" csg scraper, 10,373' with 9-5/8" scraper (25' in on jt #328). Did not see top of liner, or any sign of junk etc. 110K# dn wt. 00:30 - 02:00 1.50 CLEAN P DECOMP POOH. LD PH6 work string. 02:00 - 03:00 1.00 CLEAN N RREP DECOMP Rig tongs sprung a hydraulic leak. Replace hose. 03:00 - 04:00 1.00 CLEAN P DECOMP Unload singles from pipe shed. 04:00 - 06:00 2.00 CLEAN P DECOMP Continue to POOH and lay down singles. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew change and safety meeting with day tour prior to continuing to pull pipe out of the hole. Discuss operations forward, including Simops with pulling pipe, and rolling pipe out of pipe shed. Discuss 2 new individuals on rig today. Discuss the fact that anyone can shut down the job at any time, and should do so if they see any kind of safety issue that should be discussed. 06:30 - 11 :00 4.50 CLEAN P DECOMP Continue to POOH and lay down singles. 100 joints OOH at 06:30. Total run in string was 328. 228 to go. 11 :00 - 15:30 4.50 CLEAN P DECOMP 208 joints OOH at 11 :00, 120 to go. 15:30 - 15:50 0.33 CLEAN P DECOMP All PH-6 OOH. Hold rig evacuation drill. Simulated fire in the manifold building behind the rig. The well was secured, and all rig hands, including the derrick hand from the derrick, the fishing hand from the rig floor, and the vac truck driver from the back side of the rig were at the muster area in 2 minutes. Good response by all hands. 15:50 - 19:00 3.17 CLEAN P DECOMP Lay down fishing BHA; drill collars, scrapers, junk mill over Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 6/28/2004 15:50 - 19:00 3.17 CLEAN P DECOMP completion in pipe shed. 19:00 - 23:00 4.00 RUNCOMP RUNCMP Load remaining 4-1/2" tbg into pipe shed (42 jts). Drift & strap same. Load completion jewelry into pipe shed. RU floor to run tbg. 23:00 - 23:15 0.25 RUNCOMP RUNCMP Hold PJSM with crew to discuss running completion. Discuss hazards, job assignments, running order. 23: 15 - 00:00 0.75 RUNCOMP RUNCMP MU 4-1/2", L-80, IBT-M tbg completion with jewelry. Find average torque to mark on threads 0 first 7 jts. Use to mu rest of pipe. pipe. 6/29/2004 00:00 - 06:00 6.00 RUNCOMP RUNCMP Continue to MU and run 4-1/2" , L-80, IBT-M tbg completion. 06:00 - 06: 15 0.25 RUNCOMP RUNCMP Shut down for crew change. 06: 15 - 09:45 3.50 RUNCOMP RUNCMP Continue to run 4-1/2" completion. On joint 137 at 06:00. Going to joint 250. 09:45 - 10:45 1.00 RUNCOMP RUNCMP At top of joint 198. Install HES CP2 TRSV. Bring HES control line spooler into rig. RU same. Attach control line and PT. All looks good. 10:45 - 15:00 4.25 RUNCOrvP RUNCMP Continue running 4-1/2" tubing. Installing 1 stainless steel control line clamp per joint. 15:00 - 17:00 2.00 RUNCOMP RUNCMP MU FMC tubing hanger and TClllanding joint. Install sssv control line. Pressure test same to 5000 psi. Land tubing. Verify visually. RILDS. 17:00 - 19:00 2.00 RUNCOMP RUNCMP RD floor. Clear pipe shed. MU coil BOPS outside cellar. Mix corrosion inhibitor in vac truck and in pits. Continue filling hole every hour 19:00 - 19:45 0.75 RUNCOMP RUNCMP MIRU LRS w/ dead crude onboard to IA Safety mtg re: displ annulus 19:45 - 00:00 4.25 RUNCOMP RUNCMP PT LRS @ 2500 psi. Displ annulus wI 435 bbls SW wI 25 gal/100 bbl Corexit heated to 130F at 2.5/500 while taking avg 2.0 bpm returns thru tubing. Displ wI 135 bbls dead crude for FP. SIIA wI 250 psi. RDMO LRS 6/30/2004 00:00 - 03:00 3.00 RUNCOMP RUNCMP Drop ball on rod and wait to fall. RU kill line to IA Tee. IA 90, OA 176. Pressure tubing to 4000 psi with 2.8 bbls and monitor IA 190, OA 177 for 30 min. Final pressures 3970 psi, IA 153, OA 178. Bleed tubing to 1650 psi. Pressure IA to 3485 psi wI 8.1 bbls and tubing rose to 2180 psi and held. IA bled to 3390 in 30 min, OA 177. Bleed IA down to 500 psi and tubing bled to 1650 psi. Bleed tubing to zero 03:00 - 03:45 0.75 RUNCOrvP RUNCMP LD landing jt. Close TRSSSV. RD spooling unit and load out 03:45 - 04: 15 0.50 BOPSUP P RUNCMP Dry stick TWC 04:15 - 08:30 4.25 BOPSUF P RUNCMP ND riser and load out. ND 13-5/8" BOPE. 08:30 - 09:30 1.00 BOPSUP P RUNCMP Remove BOP components from cellar. Load out used completion equipment, excess 2-7/8 liner, mise items to stores. 09:30 - 10:30 1.00 BOPSUF P RUNCMP Place 7-1/16" BOPs in cellar. Secure and suspend from bridge crane. 10:30 - 12:30 2.00 BOPSUPP RUNCMP NU tubing head adapter flange with FMC hand. Install SSSV line connection. Test both. 12:30 - 14:30 2.00 BOPSUF P RUNCMP NU tree. Test tubing head adapter to 5000 psi. Test tree valves to 5000 psi. Ok. 14:30 - 16:30 2.00 BOPSUP P RUNCMP RU lubricator to 4-1/2" tre. DSM valve crew pull TWC from hanger. 16:30 - 20:00 3.50 BOPSUF P RUNCMP NU 7-1/16" BOPs. Install mousehole 20:00 - 23:00 3.00 BOPSUP N SFAL RUNCMP Fill stack/PT and leaked at Hydril to blindlshear flange. Retighten and retest several times wlo success. The lifting Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 6/30/2004 20:00 - 23:00 3.00 BOPSUP N SFAL RUNCMP plate is hindering makeup of nuts. The individual BOP components had just been annually inspected and new seal rings installed. Remove annular and inspect seal ring and groove. Remove R46 seal ring and install a RX46 (raised profile) seal ring (which are installed in all other BOP breaks). Retest to 4000 psi 23:00 - 00:00 1.00 BOPSUP P RUNCMP RU to PT tubing and IA. Reboot DS PC 7/1/2004 00:00 - 03:00 3.00 BOPSUF P RUNCMP Pressure test tree cap to 4000 psi prior to repressure test tubing and IA Time Tubing P lAP OAP TRSSSVp Comment 0003 0 100 172 4027 Initial conditions 0025 0 88 172 1850 After open tree valves-begin pump dn tbg 0027 3490 221 172 4385 Begin 30 min test after 2.3 bbls pumped Appears control line pressure is tracking-discuss wI FMC, PE's 0055 3450 222 225 4390 End of tubing test. Bleed off pressure 0106 0 192 225 4040 After tubing bled off and pressures stable Bled back less than 1 bbl-suspect flapper may have shut 0113 0 192 225 0 Intentionally bleed TRSSSVp to zero to chk CL integrity 0120 4000 237 225 35 After repress tubing to 4000 psi wI 0.9 bbls WO DSO to open TRSSSV 0207 3973 233 225 28 End of test-DSO needs 2500 psi over well press to open flapper-find higher rated gauge 0235 4003 228 225 6500 Flapper opened, bleed off tbg press slow 0251 0 72 222 4735 Bled back 1.8 bbls. DSO left 4735 psi on CL 03:00 - 04:00 1.00 BOPSUF P RUNCMP Pressure tubing to 1500 psi 0303 1510 122 222 4865 Begin pressure IA to 3500 psi 0308 1600 700 223 4980 After 1.6 bbls 0311 1825 2250 236 4999 After 4.3 bbls 0313 2040 3505 247 5475 After 7.7 bbls. Begin 30 min test 0343 2040 3445 250 5460 Bleed off IA to 200 psi 0348 1534 250 227 4855 Bleed off tubing to zero 0355 0 222 226 4785 Back to where we started 04:00 - 11 :00 7.00 BOPSUP P RUNCMP SI master and swab. PJSM. Install test joint. Begin initial BOPE test wi AOGCC inspector on site. Rebuild leaking kill line valve. Spot SLB slickline unit. 11:00-11:15 0.25 RUNCOMP RUNCMP Hold PJSM with crews to discuss s-line rig up, procedures, hazards. 11: 15 - 12: 15 1.00 RUNCOMP RUNCMP RU slick line. Bring tools to floor. 12:15 - 14:00 1.75 RUNCOMP RUNCMP RIH. Recover ball& rod assembly. POOH. LD same. Well now taking 60 bph seawater. 14:00 - 16:00 2.00 RUNCOrvP RUNCMP MU next tool string. RIH to recover RHC profile sub. POOH. Printed: 7/20/2004 12:59:45 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/112004 16:00 - 21 :45 5.75 CLEAN P WEXIT 21 :45 - 22:15 0.50 CLEAN P WEXIT 22:15 - 22:30 0.25 WHIP P WEXIT 22:30 - 00:00 1.50 WHIP P WEXIT 7/2/2004 00:00 - 02:30 2.50 WHIP P WEXIT 02:30 - 03:35 1.08 WHIP N DFAL WEXIT 03:35 - 04:45 1.17 WHIP N DFAL WEXIT 04:45 - 06:30 1.75 WHIP N DFAL WEXIT 06:30 - 08:00 1.50 WHIP P WEXIT 08:00 - 09:00 1.00 WHIP P WEXIT 09:00 - 09:45 0.75 WHIP P WEXIT 09:45 - 12:30 2.75 ZONISO P WEXIT 12:30 - 14:45 2.25 ZONISO P WEXIT 14:45 - 15:15 0.50 ZONISO P WEXIT 15:15 -17:15 2.00 ZONISO P WEXIT 17:15 - 18:00 0.75 ZONISO P WEXIT 18:00 - 18:15 0.25 ZONISO P WEXIT 18:15 - 19:15 1.00 ZONISO P WEXIT 19:15 - 20:15 1.00 ZONISO P WEXIT 20:15 - 20:55 0.67 ZONISO P WEXIT 20:55 - 23:15 2.33 ZONISO P WEXIT MU 3.625" dummy WS drift tool string. RIH to 10800', clean. POOH. Slow run due to fluid packed well bore and large OD. Fill across top at 33 bbls/hr LD dummy WS assy. RDMO SWS slickline Safety mtg re: MU WS assy on eline Load BTT Gen II WS and SWS eline tools to floor and RU. Check POS tool orientation. Load 2 RA pips in WS. MU WS to running tools RIH w/ WS on eline to 10800'. Log tie-in to PDC log and attempt to set WS wI top at 10753' wlo success POOH w/WS Found slo-burn fuse started the burn, but ignitor pellet did not finish. Chk WS, okay. Install another #10 slo-burn charge, MU to same WS RIH wI WS on eline to 10800'. Log tie-in. Set packer. Verify did not fall down hole. Log GR/CCL jewelry log from TOW to first GLM to determine ELM tbg tail etc. Pull out of hole with e-line tools RD SLB e-line equipment. Stab coil in to injector. Head up with dart catcher. RU to pump dart through e-free coil. Pump Baker 2-3/8" dart through reel. After 70 bbls, nver saw it hit dart catcher. Pump 2nd dart. First dart found, 2nd dart hit after 70 bbls. Replace dart catcher with small id xo. Dart hit after 53.9 bbls. MU coil connector. Pressure & pull test same. MU cementing nozzle on stinger. Get on well. Call for cementers. RIH. RU cementers. Hold PJSM while RIH. DIscuss hazards, pump schedule, roles & respons, clean up. Tag WS and correct coil depth to 10757'. Flag pipe and PU 10'. Shut in well. Pump injectivity test: 245 psi WHP @ 1.0 bpm. Begin mixing cement. Fill lines with water. Pressure test lines to 4000 psi. DS load CT wI 5 bbls neat, 20 bbls wI 15#/bbl agg, 9 bbls neat G cement at 15.8 ppg at 2.5/1.7/2000. IA 400, OA 275 Displace wI rig KCI. Park at 10743'. With 3.7 bbls above noz and 2.4/1.4/400 start PUH at 4'/min 53k and close choke. Red rate to 1.5/200 after 10 bbls cement out and WHP slowly rising to 150 psi. With 14 bbls left and no further incr in WHP, bleed off press to zero. Returns initially were about 1/1, but then declined to 1.010.3/130 at 25'/min while fin displ the rest of cement while PUH in tubing. Last bbl out noz at 10350' (WCTOC) Total returns were 10 bbls. TT 5:00 @ 80 ml, CIP 1915 hrs. PUH to safety Park at 10000'. Swap to 40 bbls 1.5# bio water and circ 0.30/0.22/40 while wo cement to settle SI choke and apply 100 psi wI 1.4 bbls which bled to 50 psi in two minutes and held for 15 min. Increase to 150 psi WHP wI 0.9 bbls and bled to 60 psi in 10 min and to 40 psi in 20 min. Bleed off 30 psi and open choke Fire in motor room drill Fin circ biozan to nozzle 2.6/2.6/1560 while RIH to WCTOC. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/23/2004 7/20/2004 N2 Spud Date: 6/23/2004 End: 7/20/2004 7/212004 20:55 - 23:15 2.33 ZONISO P WEXIT Jet and dilute cement to 10700' (top perf at 10734') 2.8/2.8/1850. Jet remainder of bio water then KCI 3.25/2450 while POOH jetting across jewelry. Dump 80 bbls of dirty water wI max density of 8.7 ppg 23: 15 - 23:35 0.33 ZONISO P WEXIT LD cement stinger. Jet stack wi swizzle stick 23:35 - 00:00 0.42 STWHIP P WEXIT Cut off CTC. Install BTT CTC. PT 35k, 3500 psi 7/3/2004 00:00 - 00:30 0.50 STWHIP P WEXIT MU milling BHA 00:30 - 02:15 1.75 STWHIP P WEXIT RIH wI BHA #3 (3.80" window mill, 3.80" SR) 02:15 - 03:15 1.00 STWHIP P WEXIT 10680' start motor 2.7/2.7/1450. RIH looking for cement at 10700' (ELM D). RIH at 60'/hr after 50 psi incr in diff at 10733' CTD (prior carr was -18'). PVT 310 Wt chk at 10745' 42k 2.7/2.7/1450 Drill cement wI 100 psi diff 60'/hr from 10745' to 10768.6' and stall-assume pinch point. PUH 43k. RIH to first motor work at 10768.2' 2.7/1340 (adding biozan). Corr to 10757.6' and flag 03:15 - 06:00 2.75 STWHIP P WEXIT Mill window from 10757.6' 2.7/1340 per BTT instructions at 0.1'/5 min PVT 310 06:00 - 10:00 4.00 STWHIP P WEXIT Mill window to 10764.5' 2.7/1340 per BTT instructions at 0.1'/5 min PVT 308 ROP has slowed, should be mostly in formation. 10:00 - 14:00 4.00 STWHIP P WEXIT Mill window to 10769' 2.7/1850 per BTT instructions at 0.1'/5 min PVT 308. ROP has slowed, should be mostly in formation. Motor work 600-800 psi. 14:00 - 15:00 1.00 STWHIP P WEXIT Mill window to 10765.5 . 2.7/1340 per BTT instructions at 0.1 '/5 min PVT 308. ROP increased at 10769'. Mill formation to 10775.4'. 15:00 - 15:15 0.25 STWHIP P WEXIT Back ream window to dress same. Run through dry. Looks smooth. TOW: 10757.6', BOW 10765.5'. 15:15 - 17:15 2.00 STWHIP P WEXIT POOH to swap reels & BHA. Paint EOP flag at 10547'. Continue to circ out of hole. 17:15 - 18:15 1.00 STWHIP P WEXIT At surface get off well. LD milling BHA. 3 miles of caribou. . . 18:15-18:30 0.25 DRILL P PROD1 Safety mtg re: N2 blowdown 18:30 - 19:45 1.25 DRILL P PROD1 PT DS N2 lines. Blowdown reel wI N2 and bleed off Cut off CTC 19:45 - 19:55 0.17 DRILL P PROD1 Safety mtg re: pull CT back 19:55 - 22:25 2.50 DRILL P PROD1 Install internal grapple and PT. Pull CT back to reel and secure. Open bombay doors and load out e-free CT. Load in E-CT. Install internal grapple and PT. Pull CT to injector and stab 22:25 - 23:30 1.08 DRILL P PROD1 Install temporary CTC and stab onto lub. Fill CT wI KCI and reverse slack back 23:30 - 00:00 0.50 DRILL P PROD1 Cut off 140' CT to find eline 7/4/2004 00:00 - 02:15 2.25 DRILL P PROD1 Prep eline and test. Install Kendall CTC 02: 15 - 03:00 0.75 DRILL P PROD1 MU drilling BHA 03:00 - 03:30 0.50 DRILL P PROD1 RIH wi BHA #4 (2.7 deglM09X) pumping thru EDC 1.75/750 Tag up on TRSSSV at 2211' CTD (CL shows 3800 psi, should be open). Orienting didn't work either 03:30 - 05:00 1.50 DRILL N DPRB PROD1 WO DSO to cycle TRSSSV 05:00 - 05:50 0.83 DRILL P PROD1 Work for 10 min and get thru SSSV-assume big bend motor and square shoulder bit are catching profile. Continue RIH 05:50 - 06:00 0.17 DRILL N SFAL PROD1 Park at 6000' to replace packoff 06:00 - 06:50 0.83 DRILL P PROD1 Continue to RIH. 06:50 - 07:45 0.92 DRILL P PROD1 Log initial gr tie in from 10655' to 10737'. Correlate with WS Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/23/2004 7/20/2004 N2 Spud Date: 6/23/2004 End: 7/20/2004 7/4/2004 06:50 - 07:45 0.92 DRILL P PROD1 setting record/jewelry log (712104), which was tied into orginal Litho-Density log from parent well. -18' correction. 42K# up, 18K# dn wt. 07:45 - 09:45 2.00 DRILL P PROD1 RIH through window. Tag TD at 10775'. Orient to 60L. Drill ahead. 2100 psi @ 2.6 bpm inlout. 200-300 dpsi. WOB: 3K-4K#. Begin displacement to new flo pro. Install sssv panel in cellar with help from DSO. Drill to 10783' 09:45 - 12:00 2.25 DRILL P PROD1 Drill ahead. New mud around all the way around. Haul off biozan returns. 3300 psi fs @ 2.65 inlout. 200-400 dpsi. WOB: 2.5k#-3.5k#. TF:45-60L. ROP:2-3 fph 12:00 - 15:00 3.00 DRILL P PROD1 Drill ahead. 3200 psi @ 2.5 bpm inlout. 300-600 dpsi. DHWOB: 6k#-7k#. TF:45-60L. ROP: 5-10 fph. Very hard drilling. Occassional stalls. No recorded surveys yet. Near bit incl showing good build rate. 15:00 - 18:00 3.00 DRILL P PROD1 Drilliing ahead. Continue build and tum to left. 3200 psi @ 2.5 bpm inlout. 300-500 dpsi. DHWOB: 7k#. TF:45-60L. ROP: 5-10 fph. Drilling very hard. Near bit inc: 58 deg. 18:00 - 19:45 1.75 DRILL P PROD1 Drill ahead 2.6/2.6/3270 w/1 00-300 psi diff, 7k wob, ECD 9.9 and are projected to be in harder formation and past first mudstone. Near bit at 60 deg PVT 396 19:45 - 21 :15 1.50 DRILL P PROD1 Wiper to window. POOH to chk bit. Clean thru SSSV nipple 21:15 - 21:45 0.50 DRILL P PROD1 Bit was better than expected 2-5-1 wI chipping damage on taper. Change out for another good used M09X 21 :45 - 23:40 1.92 DRILL P PROD1 RIH w/ BHA #5 (2.7 deg). Work 10 min to get thru SSSV. See most of GLM's also while RIH 23:40 - 00:00 0.33 DRILL P PROD1 Log tie-in down from 10700' and carr -15'. Log baseline tie-in to parent well from 10750' to TD 7/5/2004 00:00 - 00:30 0.50 DRILL P PROD1 Fin tie-in log to parent well bore and tag TD at 10832' PVT 394 00:30 - 02:00 1.50 DRILL P PROD1 Break in bit, then drill ahead 2.63/3200/80L wI 100-300 psi diff, 1-3k wOb, ECD 10.0 at 20-25'/hr 02:00 - 04:10 2.17 DRILL P PROD1 Drill ahead 2.7/3280/100L w/ 100-200 psi diff, 2-5k wob, ECD 10.0, 20-25'/hr PVT 393 Get first good survey from 10830' 04:10 - 04:30 0.33 DRILL P PROD1 Wiper to window while BHI reboots PC 04:30 - 06:00 1.50 DRILL P PROD1 Drill ahead 2.66/3260/95L w/1 00-250 psi diff, 3-6k wob, ECD 10.0, 15-20'/hr at 70 deg 06:00 - 07:30 1.50 DRILL P PROD1 Drilling ahead. 2350 psi @ 2.7 bpm in/out. 250-500 dpsi. WOB: 3k-4k#. TF:45-15L. Inc:70 deg. ECD:10.0 ppg ROP: slowing. Unable to get stall when running into btm. Make repeated attempts to get bit to drill. 07:30 - 09:15 1.75 DRILL P PROD1 POOH to check bit & mtr. Circulate at full rate while tripping. 09:15 - 10:00 0.75 DRILL P PROD1 At surface. Get off well. Unstab coil. Break out M-09. Cutters on nose significantly worn, but not chipped or broken. 3-3-0. Cutters clearly lost their sharp edge. MU M-27BQPX. Has sharpest looking cutters on bit rack. Stab coil. Get on well 10:00 - 12:30 2.50 DRILL P PROD1 RIH. Set down in SSSV. PU & orient to 160L. Run through ok. Continue in hole. Having to RIH at reduced rate of speed due Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/23/2004 7/20/2004 N2 Spud Date: 6/23/2004 End: 7/20/2004 7/512004 10:00 - 12:30 2.50 DRILL P PROD1 to tgb collars (another disadvantage of BTC connections) 12:30 - 13:00 0.50 DRILL P PROD1 Correct to flag at 10400'. Minus 9'. Begin gr tie in with bit at 10760. -2 correction. 13:00 - 15:00 2.00 DRILL P PROD1 Drilling ahead. 3200 psi @ 2.55 bpm inlout 200-300 dpsi. WOB: 2k#-4k#. TF: 45-60L Inc:83. ECD: 10.08 ppg. ROP: 20 fph avg. 15:00 - 18:00 3.00 DRILL P PROD1 Drilling ahead. 3200 psi @ 2.55 bpm in/out. 300-400 dpsi. WOB: 2k# - 3k#. TF/lNC: 45-60L/83 deg. Drilling break @ 10976' - 10982'. Fault? Porosity? Still no fluid losses. Land build at 8929' TVD/11 ,000' MD. 18:00 - 19:00 1.00 DRILL P PROD1 Drill ahead 2.5/3190/45L at 86 deg and finish turn to prep for lateral at 11060'. Getting to be a struggle to make hole 19:00 - 19:20 0.33 DRILL P PROD1 Wiper to window 19:20 - 19:55 0.58 DRILL P PROD1 Drill ahead 2.7/3250/45L Got a few stalls, then stacking full wt wi 300 psi and no progress. Revised start of lateral is 11100'. Based on markers appear to be 10' TVD above target PVT 393 19:55 - 20:05 0.17 DRILL P PROD1 Wiper to window 20:05 - 21 :35 1.50 DRILL P PROD1 POOH for bit 21:35 - 22:10 0.58 DRILL P PROD1 Change bit, chk motor. Bit was quite good 3-4-1 wI chipped cutters on taper and normal wear on all other cutters. Also had a mudball between blades 22:10 - 23:55 1.75 DRILL P PROD1 RIH wi BHA #7 (2.7 deg, DS111). Did not tag on SSSV wi rounded nose bit, but did see connections and jewelry. The bits are probably being chipped on the taper from the connections 23:55 - 00:00 0.08 DRILL P PROD1 Log tie-in down from 10780' 7/6/2004 00:00 - 00:15 0.25 DRILL P PROD1 Fin log tie-in down from 10780', corr -19' 00: 15 - 00:25 0.17 DRILL P PROD1 Wiper to TD tagged at 11067' PVT 388 00:25 - 00:40 0.25 DRILL P PROD1 Drill ahead 2.68/3390/90L wI 100-200 psi diff, 0-4k wob, ECD 10.1 at 88 deg and 60'/hr when drilling, but becoming sticky and having 10-20k overpulls 00:40 - 00:50 0.17 DRILL P PROD1 Wiper while discuss wI geo. Need to get TF pointed out of it so decide to head down quicker 00:50 - 03:00 2.17 DRILL P PROD1 Attempt to drill ahead 2.7/3400/150L wI 100-300 psi, 2-6k wOb, but between stalls with clean pickups, there are periods of going nowhere wI 6k wob. Acts like an interface between mudstone and limestone 03:00 - 04:00 1.00 DRILL P PROD1 Drill ahead 2.6/3300/11 OL and may be getting thru this spot. A few more stalls when attempting to feed too fast-bit is obviously too aggressive for what we are drilling. Revised start of lateral is 11110' 04:00 - 05:00 1.00 DRILL P PROD1 Start making slow, steady headway 2.7/3300/110L 1-3k PVT 386 05:00 - 05:50 0.83 DRILL P PROD1 Find another hard spot wi multiple stalls 05:50 - 08: 15 2.42 DRILL P PROD1 Drill ahead. 3300 psi @2.7 bpm in/out 200-300 dpsi WOB:5k-7k# Tf/lnc: 45-60U86 deg ECD: 10.17 ppg Continued very slow drilling. Projected TVD: 8934', Inc: 86 deg. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/612004 08:15-10:15 2.00 DRILL P PROD1 ROP very slow. Decide to pull for bit & lateral assembly. POOH. 10:15-12:15 2.00 DRILL P PROD1 Change out MWD, motor & bit. DS 111 had several chipped cutters, ringed out on nose, and under gauge. 4-6-1 Replace MWD assy and motor. MU Hycalog 3.75" concentric bit. Stab coil. Get on well. 12:15 - 13:55 1.67 DRILL P PROD1 RIH wI BHA #8 (1.5 deg/CRXE) 13:55 - 14:15 0.33 DRILL P PROD1 Log tie-in down from 10750', corr -18' 14:15 - 14:30 0.25 DRILL P PROD1 RIH to TD. Precautionary ream 15'/min over last bit run and clean to TD tagged at 11113' 14:30 - 15:30 1.00 DRILL P PROD1 Drill ahead 2.6/3360/75L wI 200-400 psi diff, 2-5k wob, ECD 10.16 at 30-60'/hr Bit took off drilling wlo any stalls-a pleasant change from last run PVT 380 15:30 - 15:50 0.33 DRILL P PROD1 Slow wiper while sort out depth difference between BHI and DS counters 15:50 - 18:05 2.25 DRILL P PROD1 Drill ahead 2.6/3220/90L at 85 deg wlo stalls at avg 45'/hr 18:05 - 19:00 0.92 DRILL P PROD1 Wiper trip above 7" csg. 19:00 - 23:50 4.83 DRILL P PROD1 Directionally drill ahead fl 11230' to 11325'. No stalls. 2.65/2.65 4-6k wob 40-45'/hr. ROP slowed to <30'/hr around 11315' made a short BHA wiper trip. ROP leveling off 30-35'/hr with 6k wob 100% returns. ROP increase 45'/hr at 11365'. Drilled to 11395' then lost 30% returns. 23:50 - 00:00 0.17 DRILL P PROD1 Wiper trip 7/7/2004 00:00 - 00:35 0.58 DRILL P PROD1 Continue with wiper trip. 00:35 - 03:40 3.08 DRILL P PROD1 Continue drilling ahead f/11305'. Returns slowly coming back to > 90% by 11408' 3-4k wob 46'/hr Adjust TF f/1141 0' to 11416' fl 90L to 90 Rand rop dropped to 12'/hr. 2.60/2.56 03:40 - 04:35 0.92 DRILL P PROD1 Wiper trip with 90L TF backream through dogleg. Make several trips without much success. Drilled to 11443' with minimal losses 2.60/2.55 Total losses to well 25 bbls. 04:35 - 06:20 1.75 DRILL P PROD1 TOH 06:20 - 07:10 0.83 DRILL P PROD1 Change bit, adjust motor down to 1.2 deg. Bit was 1-2-1 and BU 07:10 - 09:00 1.83 DRILL P PROD1 RIH wI BHA #9 (1.2 deglnew CRXE bit) 09:00 - 09:25 0.42 DRILL P PROD1 Log tie-in down from 10750', carr -17' 09:25 - 09:50 0.42 DRILL P PROD1 RIH to TD tagged at 11440' PVT 320 09:50 - 11 :30 1.67 DRILL P PROD1 Drill ahead 2.5/2.44/3300/85R wI 200-400 psi diff, 4k wob, ECD 10.3 at 20'/hr while break in bit, then drill 40-50'/hr wI 6k wob, start stacking. Do a couple 100' wipers to smooth out 180 deg TF change 11 :30 - 11 :50 0.33 DRILL P PROD1 100' wiper 11 :50 - 12:30 0.67 DRILL P PROD1 Drill ahead 2.5/3300/85R wI 200-500 psi diff, 4-6k wob, ECD 10.4 and stacking-need new mud, but all we have is 'lite' Flo Pro. Add lubetex in the meantime while MI mixes a system. Fault is 200' away, but no guarantees of losses there either 12:30 - 14:00 1.50 DRILL P PROD1 Gained 10k string wt and able to slide continuously now. Drill ahead at avg 30'/hr 14:00 - 14:30 0.50 DRILL P PROD1 Wiper to window before TF change and to check out weak orientor. Hole is clean 14:30 - 16:15 1.75 DRILL N DFAL PROD1 Orientor is responding too slow. Will trip to change it out Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/7/2004 16:15 - 17:45 1.50 DRILL N PROD1 Change out orientor. Chk bit and motor, like new, will rerun 17:45 - 19:35 1.83 DRILL N PROD1 RIH wI BHA #10 to 10780'. 19:35 - 19:40 0.08 DRILL N PROD1 Log tie-in -12' correction (record tie-in time!) 19:40 - 20:10 0.50 DRILL N PROD1 Continue RIH to bottom. pumping min rate through mudstone areas with TF "as drilled". Clean to bottom. 20: 10 - 22:00 1.83 DRILL P PROD1 Diectionallly drill ahead f/11540'. 2.62/2.62 3500psi fs 2-300psi mw. 4-5k wob 25'-30'/hr 10.36ppg ecd. Prepping to swap mud. Drilled to 11568 and starting to loosing returns. Pick up off bottom 100' RIH. Drilling ahead 2.61/1.79 by 11575' returns 2.03 2-3k wob 60-70'/hr to 11592 backing off to 30'/hr by 11592'. Returns 1.95 Drill to 11594'. 22:00 - 22:15 0.25 DRILL P PROD1 Wiper trip 22:15 - 00:00 1.75 DRILL P PROD1 Drill ahead f/11594' 2.60/2.403300 fs 3-400psi mw 2-3k wob 30-40'/hr drilled to 11690'. Have lost 80 bbls mud to formation since taking losses at 11568'. 7/8/2004 00:00 - 00:55 0.92 DRILL P PROD1 Wioper trip to tbg tail 00:55 - 01:10 0.25 DRILL P PROD1 Directionally drill ahead f/11690' 2.65/2.05 3200psi fs drilled to 11699' became differentually stuck. returns also dropped to 1.8 01 :10 - 01 :15 0.08 DRILL N PROD1 Circulate. Work pipe. Came free. 01 :15 - 01 :30 0.25 DRILL N PROD1 Wiper trip 200'. 01 :30 - 03:45 2.25 DRILL P PROD1 Drill ahead f/11699' returns increasing 2.6/2.3 slower drilling good weight transfer with little mw. Might have balled bit. Drill to 11734'. 03:45 - 04:00 0.25 DRILL P PROD1 Wiper trip 300' 04:00 - 05:20 1.33 DRILL P PROD1 Drill ahead f/ 11734'. Slow drilling. Try stacking out and stalling motor. Making some headway. Drilled to 11743'. 05:20 - 07:15 1.92 DRILL P PROD1 TOH to check bit and motor. Total losses to well 170 bbls. 07:15 - 07:45 0.50 DRILL P PROD1 Change bit. Bit was well worn and starting to ring 5-3-1 07:45 - 09:30 1.75 DRILL P PROD1 RIH wI BHA #11 (rebuilt CRXE, 1.2 deg) 09:30 - 09:55 0.42 DRILL P PROD1 Log tie-in down from 10775', corr -12' 09:55 - 10:25 0.50 DRILL P PROD1 RIH to TD, clean PVT 310 10:25 - 11: 10 0.75 DRILL P PROD1 Drill ahead 2.52/2.35/3050/90L wI 200-300 psi diff, 2-4k wob, ECD 10.08 at 60'/hr for 15' and then had trouble getting differential and wob. Had some sticky pickups too 11: 10 - 11 :35 0.42 DRILL P PROD1 Drill ahead 2.5/2.4/3060175L wI 300-500 psi ditt, 2-4k wob, ECD 10.16 at 60-80'/hr and got good string wt back from -3k to +8k 11 :35 - 12:00 0.42 DRILL P PROD1 Started losing 1.0 bpm at 11800', PUH w/8k over. Resume drilling and returns slowly healed to losing 0.8 bpm. Now having to drill w/ neg wt and pentration rate has slowed to 20'/hr. Turn TF up to begin slow invert PVT 280 12:00 - 12:30 0.50 DRILL P PROD1 Drill ahead 2.5/1.6/2990/50L wI 400-600 psi ditt, 1-3k wob, ECD 9.95 and penetration rate has picked up to 60-90'/hr after getting string wt back to + 1 Ok 12:30 - 12:40 0.17 DRILL P PROD1 100' wiper to test the waters and clean past 11800' 12:40 - 13:15 0.58 DRILL P PROD1 Drill ahead 2.5/1.6/3000/85L wI 400-700 psi ditt, 2-4k wob and returns slowing increasing as penetration rate is increasing 50-90'/hr 2.5/2.2 13:15 - 13:30 0.25 DRILL P PROD1 100' wiper. On RBIH, losses increased to 1.5 bpm Printed: 7/20/2004 12:59:45 PM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/812004 13:30 - 14:00 0.50 DRILL P PROD1 Drill ahead 2.5/1.0/2890/80L and drill wI -5k at 20'/hr and hold 92 deg from 8944' TVD Returns improved to 2.5/1.6 PVT 180 14:00 - 14:30 0.50 DRILL P PROD1 Wiper to window 14:30 - 14:40 0.17 DRILL P PROD1 Log tie-in down from 10760', no corr 14:40 - 15:15 0.58 DRILL P PROD1 Wiper to TD, clean PVT 120 15:15 - 17:45 2.50 DRILL P PROD1 Drill ahead 2.6/1.8/3050160L w/200-400 psi ditt, 2-5k wob, ECD 10.0 and drill wI neg wt at 1 O'lhr avg at 92 deg and wait for a drilling break, but it never came. Losses healed to 2.6/2.3 PVT 54 and start adding fresh mud 17:45 - 20:00 2.25 DRILL P PROD1 Wiper to windowand POH 20:00·21:10 1.17 DRILL P PROD1 Change out DPS on BHi tools and plu new bit. Function test BOP's. 21:10 - 22:20 1.17 DRILL P PROD1 RIH with BHA #12 to 6107'. Drillers side gear box for coil reel drive chain cracked. 22:20 - 00:00 1.67 DRILL N SFAL PROD1 Wait on SLB mechanic and parts. 7/9/2004 00:00 - 04:15 4.25 DRILL N SFAL PROD1 Remove and changeout coil reel's drillers side drive gears and housing.. 04:15 - 05:15 1.00 DRILL P PROD1 Continue RIH to 10780'. 05:15 - 05:25 0.17 DRILL P PROD1 Tie-in -17' correction. 05:25 - 06:20 0.92 DRILL P PROD1 Wiper to bottom. Several wt loss points 06:20 - 06:45 0.42 DRILL P PROD1 Set down at 11725' and had 15k overpull, twice. Attempt to ream/redrill this area of hard formation 2.6/2.2. Have sharp stalls, heavy pickups at bit and can't make an inch. Try to get by w/o pump and set down and have 5k pickups-bicenter should pass 3.70" hole. Assume slightly eccentric/hard formation which was at the end of bit run #7 (which was in gauge). Discuss and decide to finish well wI 3.75" bits 06:45 - 07:25 0.67 DRILL P PROD1 Wiper to window-see 5k overpulls and MW at same spots as RIH 10790-10940', 11110', 11300', 11625', 11703' 07:25 - 08:45 1.33 DRILL P PROD1 POOH for bit 08:45 - 09:15 0.50 DRILL P PROD1 Change bit. Bicenter had one sli chipped cutter on gauge 09:15 - 10:55 1.67 DRILL P PROD1 RIH wI BHA #13 (3.75" FM2533r, 1.2 deg) 10:55 -11:10 0.25 DRILL P PROD1 Log tie-in down from 10775', corr -19' 11:10 -12:00 0.83 DRILL P PROD1 Wiper to TD 2.3/2.1/2720 30'/min and was clean to TD tagged at 11927'. No set downs or wt loss spots PVT 325 12:00 - 12:55 0.92 DRILL P PROD1 Break in bit, then drill ahead 2.6/2.13/3150/90L 150-300 psi ditt, 1-3k wob, ECD 10.0 at 10-20'/hr 12:55 - 14:25 1.50 DRILL P PROD1 Start adding wt and penetration rate stayed the same. Back in 15-20 api rock from 11910'. lincl at 95 deg 14:25 - 15:30 1.08 DRILL P PROD1 Drill ahead 2.6/2.4/3200/85L 100-300 psi ditt, 4-5k wOb, ECD 10.05 at 5-10'/hr 15:30 - 16:00 0.50 DRILL P PROD1 Spud a few times and get 50 psi ditt wI 4k wob and no more progress 16:00 - 16:30 0.50 DRILL P PROD1 Wiper to window 16:30 - 18:15 1.75 DRILL P PROD1 POOH for bit 18:15-19:30 1.25 DRILL P PROD1 Change out bit and motor. 19:30 - 21 :25 1.92 DRILL P PROD1 RIH with BHA #14 and rr CRXE bit to 10780' 21 :25 - 21 :35 0.17 DRILL P PROD1 Log tie-in -17' 21 :35 - 22:15 0.67 DRILL P PROD1 Continue RIH to TD 22:15 - 23:30 1.25 DRILL P PROD1 Directionally drill ahead f/ 11971' 3170 free-spin 2.6/2.48 1-200psi mw Started drilling fair first several feet then tapered ott. Tryed running in to bottom to have some motor work. Just not drilling. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/912004 23:30 - 00:00 0.50 DRILL P PROD1 TOH 7/10/2004 00:00 - 01 :20 1.33 DRILL P PROD1 Finish TOH 01 :20 - 01 :50 0.50 DRILL P PROD1 Change bits. Inspect BHA 01 :50 - 03:25 1.58 DRILL P PROD1 RIH wI BHA #15 to 10780'. 03:25 - 03:35 0.17 DRILL P PROD1 Log tie-in. -16' 03:35 - 04:00 0.42 DRILL P PROD1 RIH to bottom no problems. 04:00 - 07:00 3.00 DRILL P PROD1 Directionally drill ahead f/11980' 2.46/2.30 2950 psi FS. Spend last hour 2.84/2.72/3430/90L wI 50 psi diff, 5k wOb, ECD 10.07 rotating orientor and having no progress 07:00 - 07:35 0.58 DRILL P PROD1 Wiper to window, clean 07:35 - 09:05 1.50 DRILL P PROD1 POOH for bit 09:05 - 09:40 0.58 DRILL P PROD1 Change bit. Bit was 1-2-1 wI worn cutters 09:40 - 11 :20 1.67 DRILL P PROD1 RIH wI BHA #16 (M07, 1.2 deg) 11 :20 - 11 :30 0.17 DRILL P PROD1 Log tie-in down from 10780', carr -20' 11 :30 - 12:05 0.58 DRILL P PROD1 Wiper to TD was clean PVT 297 12:05 - 13:05 1.00 DRILL P PROD1 First motor work was at 11973.7' Drill ahead from here 2.67/2.53/3300/90L 50-100 psi diff, 0.5-2k wob, ECD 10.07 wi 20.9k hanging wt!, 95 deg at bit 13:05 - 14:45 1.67 DRILL P PROD1 2-4k wob, 10-12k hanging wt=10976' no progress 3-5k wob, Ok hanging wt=10979' 0-100 psi diff no progress. Acts like we are spinning on glass Recheck true depth and was at 11974.8' w/1 k wob 13k hanging PVT 272 14:45 - 15:15 0.50 DRILL P PROD1 Wiper to window 15:15 -17:00 1.75 DRILL P PROD1 POOH for bit 17:00 - 18:00 1.00 DRILL P PROD1 Check last 200' CT for wear-one minor flat spot. Change bit and motor. Bit had a little wear on most cutters, but inner nose cutters were missing and center of bit was cored. MU a roller cone insert bit on a new motor 18:00 - 20:05 2.08 DRILL P PROD1 RIH wI BHA #17 (STR30DX, 1.2 deg) to 10780' 20:05 - 20:15 0.17 DRILL P PROD1 Log tie-in -16'. 20:15 - 20:55 0.67 DRILL P PROD1 RIH tagged at 10854'. Work at different TF's without success. 20:55 - 23:00 2.08 DRILL P PROD1 TOH. 23:00 - 00:00 1.00 DRILL P PROD1 Inspect coil above CTC. Needs to be cut and reheaded. R/U and cut coil. 7/11/2004 00:00 - 02:10 2.17 DRILL P PROD1 Finish cutting 50' of coil. Install dimple CTC. Pull test to 35k. Install BHi wet connect and test. PT to 3500psi. 02: 1 0 - 02:40 0.50 DRILL P PROD1 Adjust BHi motor from 1.2 deg to 2 deg. P/U HC Diamond Impreg bit. 02:40 - 04:30 1.83 DRILL P PROD1 RIH with BHA #18 to 10780' 04:30 - 04:40 0.17 DRILL P PROD1 Log tie-in -17' 04:40 - 05:25 0.75 DRILL P PROD1 RIH at 90L stopped at 10853'. Roll up to different TF's in this quadrant and try without success. Setdown and roll TF around from HS to 130L with 5k WOB no wt drop seen. PU to 10833' get weight off and RIH 1 last time starting and stopping coil at 100L TF and it went through! 05:25 - 06:00 0.58 DRILL P PROD1 RIH tag at 11975' and stall 06:00 - 06:30 0.50 DRILL P PROD1 PUH 38k and ease back down to TD at 11975.7' wI <1 k wob PVT 327 06:30 - 08:00 1.50 DRILL P PROD1 11975.7' 2.83/2.71/3550/90L wi 0-50 psi diff, <2k wob, ECD 10.17, hanging wt 18.5k 08:00 - 11 :45 3.75 DRILL P PROD1 11976.3' 2.85/2.73/3550 wI 0-50 psi diff, <2k wob, ECD 10.18, 18.1k Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/11/2004 11 :45 - 12:55 1.17 DRILL P PROD1 11978.7' 2.85/2.74/3550 wI 50-100 psi diff, 3-4k wob, ECD 10.15, 13.8k PVT 290 12:55 - 13:45 0.83 DRILL P PROD1 11979.0' 2.85/2.74/3500/90L wI 50-100 psi diff, 4-5k wob, ECD 10.16,11.3k PUH 40k, 2.83/3500 RIH to check true depth and had 1k on bit at 11977.7' wI 18.7k Wiper to window was clean. PUH thru mudstones and window using normal procedures to 10700'. RBI H thru window and mudstones to 10950' and no wt bobbles. PUH thru window, clean 13:45 - 15:15 1.50 DRILL P PROD1 POOH for bit 15:15 - 15:40 0.42 DRILL P PROD1 Change bit. Bit was 5-5-1 wI 60% worn and 40% chipped PDC's 15:40 - 17:15 1.58 DRILL P PROD1 RIH wI BHA #19 (Hedgehog, 2.0 deg) 17:15 - 17:30 0.25 DRILL P PROD1 Log tie-in down from 10770', corr -19' 17:30 - 18:20 0.83 DRILL P PROD1 Wiper to TD was clean thru mudstones and on to TD. 18:20 - 00:00 5.67 DRILL P PROD1 Tag bottom at 11977.9' break-in new bit first hour. Drill ahead fl 11980' 2.8/2.74 3500psi FS 50-100psi 3k wob EDC 10.15ppg MW Drilled to 11994'. 7/12/2004 00:00 - 04:00 4.00 DRILL P PROD1 Continue drilling ahead f/11994' 2.81/2.75 3500 FS 100-150psi mw 3-4k wob 5'/hr Drilled to 12003.8' motor work is flatlining and not drilling off. Samples showing considerably less chert. 04:00 - 06:30 2.50 DRILL P PROD1 TOH No problems passing mudstones areas. 06:30 - 07:00 0.50 DRILL P PROD1 Change bit. Change BHllower quick connect. Hedgehog is definitely a self-sharpening bit. It had uniform wear (guessing <1mm) in all areas and the diamond dust impregnated in the PDC's was exposed-essentially, the original paint was missing! Will definitely be the future bit of choice when PDC's will not cut 07:00 - 08:30 1.50 DRILL P PROD1 RIH I BHA #20 (M09, 2.0 deg) 08:30 - 08:40 0.17 DRILL P PROD1 Log tie-in down from 10780', corr -16' 08:40 - 09:15 0.58 DRILL P PROD1 Wiper in hole thru mudstones, clean 09:15 - 09:35 0.33 DRILL P PROD1 Precautionary ream from 11970' 2.65/3300/90L3-5'/min and first MW at 12002.5' wI 15k wt PVT 380 09:35 - 10:15 0.67 DRILL P PROD1 Break in bit 2.65/2.61/3300/90L wI 50 psi diff. 1-2k wob, ECD 10.13, 16.2k for first 40 min and still a little hard 10:15 - 12:00 1.75 DRILL P PROD1 Start adding wt 2.68/2.62/3300/90L wI 100-150 psi diff, 2-4k wob, 8.7k and confirm it's still hard, but make steady progress at 10'/hr 12:00 - 14:30 2.50 DRILL P PROD1 2.66/2.62/3300/85L w/1 00 psi diff, 3-4k wob, 10.1 k and avg 5-10'/hr, then picked up to 15-20'/hr at 12034', but slowed way down at 12050' 14:30 - 15:10 0.67 DRILL P PROD1 Appears we have got the good out of this one-stacking wt, no MW, no progress. Recheck depth at 12050.4' PVT 362 15:10 - 15:55 0.75 DRILL P PROD1 Wiper to window, clean 15:55 - 17:20 1.42 DRILL P PROD1 POOH for bit 17:20-19:15 1.92 DRILL P PROD1 Change bit and orientor 19:15 - 21 :20 2.08 DRILL P PROD1 RIH to 10780' 21 :20 - 21 :30 0.17 DRILL P PROD1 Log tie in -19' correction 21:30 - 22:10 0.67 DRILL P PROD1 RIH past 10850' area with 100L TF and pumping 1bpm no problems tagged bottom at 12050' RIH wt 15.3k 22:10 - 00:00 1.83 DRILL P PROD1 Drill ahead f/12050' 2.60/2.57 3250FS 150psi MW 1 k wob to Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/12/2004 22:10 - 00:00 1.83 DRILL P PROD1 break-in bit. Continue maintaining 150 psi mw 3-4k wob 6-8'/hr Drilled to 12066'md 8931 'tvd 7/13/2004 00:00 - 04:50 4.83 DRILL P PROD1 Continue drilling ahead fl 12066'. 2.60/2.54 3250psi free-spin maintaining 150 psi motor work 3-4k wob 5-7'/hr Started slowing down. Increase wob to 5k and 250psi mw without drilling off <4'/hr rate. Drilled to 12086.6' 04:50 - 05:00 0.17 DRILL P PROD1 TOH. Coil "pin holed" (3/4 separation) at 11898' while just coming over backside of the reel. No spills. Shutdown pump, switch to filling hole across top. Continue TOH 05:00 - 06:00 1.00 DRILL P PROD1 TOH into cased hole with bit at 9864'. Plan forward is to secure parted sections then weld patch over break allowing us to blowdown reel once out of hole. 06:00 - 09:15 3.25 DRILL N SFAL PROD1 Safety mtg re: secure horizontal split by welding sleeve Gather tools. DS welder fabricate split sleeve and weld over hole 666,000 RF on reel 11594e including this run. Depth is very near a factory weld 09:15 - 10:30 1.25 DRILL P PROD1 Resume POOH for bit (and to swap CT) 10:30 - 11 :00 0.50 DRILL P PROD1 LD drilling BHA. RU DS N2 11 :00 - 12:30 1.50 DRILL P PROD1 Safety mtg re: displace CT Pump 20 bbls FW then follow wi N2. Have problems wI N2 pumper (30 min). Displ mud wI N2 and bleed off to flowback tank 12:30 - 14:00 1.50 DRILL P PROD1 Cut-off CTC. Install internal grapple and unstab coil. Secure EOP to reel. 14:00 - 17:00 3.00 DRILL P PROD1 Disconnect hardlines. Swap reels. Reconnect hardlines. Install internal grapple. 17:00 - 19:45 2.75 DRILL N SFAL PROD1 Stab pipe into injector. Make up electrical connection in reel house. 19:45 - 20:15 0.50 DRILL N SFAL PROD1 Safety meeting re: pumping slack management. Discuss SOP, and written proceedures. Hands not involved with the proceedure were advised of the safe areas and hazard areas to avoid. 20:15 - 20:50 0.58 DRILL N SFAL PROD1 Install boot on end of eline. Install CTC and Nozzle. Secure umbilical in reel house. 20:50 - 22:25 1.58 DRILL N SFAL PROD1 Stab onto well. Reverse pump mud at 1 bpm to fill new coil with mud. Then pump slack at 3.5 bpm until wire stopped. 22:25 - 00:00 1.58 DRILL N SFAL PROD1 Pop off well with injector. Cut pipe until finding wire. Cut off total of 65' of coil. Attach CTC and upper quick connect. Pull test the CTC to 35 klbs. 7/14/2004 00:00 - 01 :00 1.00 DRILL N SFAL PROD1 Continue to rnake up E-line upper quick connect. Check electrically with meg ohrn meter. Pressure test CTC to 01 :00 - 01 :30 0.50 DRILL P PROD1 Make up BHA #22. Hedgehog bit and 2.0 deg motor. 01 :30 - 03:50 2.33 DRILL P PROD1 RIH with BHA #22 to resume drilling lateral section of hole. Pumping 1.0 bpm while RIH to finish slack management. (EDC open). 03:50 - 04:00 0.17 DRILL P PROD1 Log tie in pass over RA tag at 10763'. Make -20' correction. 04:00 - 04:45 0.75 DRILL P PROD1 Continue RIH, no problems observed at claystones. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/14/2004 04:45 - 06:00 1.25 DRILL P PROD1 Free spin 3080 psi at 2.5 bpm. Back on bottom. Break in bit with 1000 Ibs WOB. 2.5/2.45/3110 psi. After 15 minutes break in, resume drilling. 2.47/2.43/3200 psi, 5 fph. Drilled to 12095' 06:00 - 07:30 1.50 DRILL P PROD1 Drilling ahead f/12095' Inc pump rate 2.88/2.85 3530fs 250psi diff pressure 6-9'/hr. Gave AOGCC notice of pending BOP test. 07:30 - 10:00 2.50 DRILL P PROD1 Drilling ahead f/12107' same parameters as above. Drilled to 12123 10:00 - 13:00 3.00 DRILL P PROD1 Drilling ahead f/12123' same parameters as above to 12134' 13:00 - 14:30 1.50 DRILL P PROD1 Drilling ahead f/ 12137' pushing as hard as possible only able to apply 300 diff pressure 5k wob. Pick -up and etag with 1 k TD 12139' . 14:30 - 16:50 2.33 DRILL P PROD1 TOH (called AOGCC and gave BOP test notification) 16:50 - 17:30 0.67 DRILL P PROD1 UD BHA #22 and bit #19. Bit worn more than previous Hedge Hog. Bit may need beefer shoulder protection which was the only area that did not have a great amount of cutting structure left. 17:30 - 00:00 6.50 BOPSUP P PROD1 Perform bi-weekly BOP testing. 7/15/2004 00:00 - 01:1 0 1.17 BOPSUP P PROD1 Finish bi-weekly BOP test. No failures. 01 :10 - 01 :40 0.50 DRILL P PROD1 Safety meeting prior to cutting drilling line. 01 :40 - 03:35 1.92 DRILL P PROD1 Cut and slip 100' of drilling line. 03:35 - 04:25 0.83 STKOH C PROD1 Make up BHA #23, Bit #20. 2.0 deg motor with Hycalog R60 STbit. 04:25 - 06:30 2.08 STKOH C PROD1 RIH with sidetrack BHA. 06:30 - 06:40 0.17 STKOH C PROD1 Log tie-in -18' correction 06:40 - 07: 15 0.58 STKOH C PROD1 RIH no problem going past 10850' area RIH to 11662'. 07:15 - 08:40 1.42 STKOH C PROD1 Start the open hole sidetrack trough f/ 11662' - 11672' with a 180' toolface. Up wt 40k 16.6k dn 2.62/2.59 3300fs 150 diff. 10.2ppg ECD. Made 2 passes 08:40 - 11 :50 3.17 STKOH C PROD1 Time drill from 11672' - 11682' apllied weight to drill ahead but slipping into old hole 11 :50 - 14:45 2.92 STKOH C PROD1 Rework the trough area 11662' - 11672' three more times. Adding MI Flo-Lube for better weight transfer. 14:45 - 18:45 4.00 STKOH C PROD1 Time drill from 11672' at 2.93/2.93 3850fs 18:45 - 20:00 1.25 STKOH C PROD1 Got back 3000 Ibs in string weight instantly at 11675.2'. Possibly popped off lip. 20:00 - 21 :00 1.00 STKOH C PROD1 PU 25'. RIH dry. Tag up at 11664', roll pumps to get thru. Set down at 11671.8'. This should be our lip from previous attempts. PU 3'. Kick on pumps. Resume time milling. Popped off ledge again. Not being able to stay on lip. 21:00 - 23:10 2.17 STKOH C PROD1 Consult with town. POOH to pick up new bit, new motor with bigger bend, and swap to new mud with 5% lubtex and 1 % flolube. Hold PJSM re: BHA swap while POOH. 23:10 - 00:00 0.83 STKOH C PROD1 Tag up with BHA #23, bit #20. Stand back injector. Lay down motor. Pick up new motor, and R60ST bit. Adjust the motor to 2.7 deg. Note - the first R60ST bit was found very badly damaged when recovered. There was 1 piece missing from the gauge section that covered about 50% of the gauge of the bit. If this damage Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/15/2004 23:10 - 00:00 0.83 STKOH C PROD1 7/16/2004 00:00 - 00:20 0.33 STKOH C PROD1 00:20 - 00:45 0.42 STKOH C PROD1 00:45 - 01:15 0.50 STKOH C PROD1 01:15 - 01:35 0.33 STKOH C PROD1 01 :35 - 02:35 1.00 STKOH C PROD1 02:35 - 04:45 2.17 STKOH C PROD1 04:45 - 04:50 0.08 STKOH C PROD1 04:50 - 05:45 0.92 STKOH C PROD1 05:45 - 06:30 0.75 STKOH C PROD1 06:30 - 06:50 0.33 STKOH C PROD1 06:50 - 09:45 2.92 STKOH C PROD1 09:45 - 10:30 0.75 STKOH C PROD1 10:30 - 12:45 2.25 STKOH C PROD1 12:45 - 13:00 13:00 - 14:20 0.25 STKOH C 1.33 STKOH C PROD1 PROD1 14:20 - 16:50 2.50 STKOH C PROD1 happened prior to attempting a sidetrack, there is no possibility that the sidetrack would have been successful. Pictures sent to CTD engineer in Anchorage. Continue with BHA swap. RIH with BHA #24, Bit #21 to sidetrack well. Running 2.7 deg bend on motor and new Hughes R60ST bit. Hanging up at SSSV. Can't get through. Suspect 2.7 deg motor not helping us. SSSV panel pressure=4000 psi. Should be enough to keep flapper open. Have DSO pump panel up to 5k psi anyway. Set down several times. Try kicking pumps on to get thru. No success. POOH to inspect the bit and adjust the motor back to 2.0 deg, so we can get thru the SSSV. Tag up. Stand back injector. Inspect bit. It has 3 chipped cutters on the leading edge of the gauge section, but is still in good enough condition to ST with. Adjust motor to 2.0 deg. Stab on injector. RIH again with BHA #24, bit #21. Hung up at SSSV. Had to spin motor with pump at 1.5 bpm for 10 seconds to get thru SSSV. Hope there is some bit left. Continue RIH. Log tie in pass over RA tag. Make -18' correction. Continue RIH to begin sidetrack. Setdown at 10854'. Attempt to pass 10854 useing different TF's in LH quadrant w/wo pump without success. TOH to 10750' discuss problem with oncoming crews. RIH to 10854'. Make another attempt gingerly trying to work past 10854' without success. Discuss with town engineer. Open EDC and continue with mud swap while TOH. Will pick-up a M-07 bit and adjust motor to a 2.7 deg bend then try again to work past 10854'. Change motor to a 2.7 deg and plu M-07 bit (duck tape bit). RD-60 bit that was pulled: main outside cutters 4 of the 5 damaged would not have stood a chance sidetracking. This bit also differs in design from the previous RD60 bit pulled lastnight. This one has a normal 45 deg slope to the back shoulder of bit. (to prevent hang-ups while TOH). The other one has a 90 deg shoulder and most likely was the cause of damage suffered to that bit while tripping out. RIH to SSSV at 2202' no problem passing. Continue RIH slowing for each GLM Log tie-in minus 15' RIH 1 bpm 90L TF tagged at 10854' pick up several times made it to 10860' with 140L tf backream slowly holding 120L tf to 10850' RIH to 10866' pu slowly to 10858' TF swapped around to 60L RIH continue RIH min rate (must have been the duck tape). Slight mw at 11000' slight setdown at 11740' then recovered. RI H wt at 11800' 20k at 20'/min stop at 11900' hopeing to push lost chuck of bit#21 beyond sidetrack area. PUH to 11700' 40k. RIHt011840' Start troughing at 15'/hr 2.66/2.64 3100psi fs having some difficulty with weight transfer for the first 90 min then got better. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/16/2004 14:20 - 16:50 2.50 STKOH C PROD1 Made 10 passes. 16:50 - 18:30 1.67 STKOH C PROD1 Start time dilling. Appears to be doing it's thing. 18:30 - 18:40 0.17 STKOH C PROD1 Not getting smooth weight transfer. Feeding in 2'/hr coil from surface, but downhole WOB and motor work are O. Free spin 2930 psi at 2.5 bpm. 100% returns. IAP=520 psi, OAP=330 psi. SSSVP=4400 psi. Pit vol=385 bbls. 18:40 - 19:10 0.50 STKOH C PROD1 Have 10150 Ibs stacked at surface, 0 Ibs WOB downhole. 0 motor work. Concerned the pipe is going to stick then slip and jump the lip. Lock down the brake and wait to see if we get some weight transfer due to vibration. No change. After 1/2 hour the weight stacked at surface stayed the same with no motor work or downhole WOB. 19:10 - 19:30 0.33 STKOH C PROD1 Resume feeding pipe in at 2.0'/hr. 19:30 - 19:52 0.37 STKOH C PROD1 11853.7', WOB surface=15390 Ibs, WOB downhole=O Ibs, 19:52 - 20:10 0.30 STKOH C PROD1 11854.4', WOB=16800, WOB downhole=O, Bring pump rate up to 2.8 bpm to increase vibration from motor. Free spin 3280 psi at 2.8 bpm. Got 100 Ibs downhole WOB when pump rate brought up. 20:10 - 20:25 0.25 STKOH C PROD1 Set brake, cycle pump rate to attempt to work pipe down hole. No improvement in weight transfer. 20:25 - 21 :05 0.67 STKOH C PROD1 Not getting any weight transfer, make wiper. Pulled 52 klbs to get BHA moving. Cleaned up to 35 klbs. Possibly differential sticking on bottom. Wiper trip uphole 500' clean, and clean back in hole. Orient to low side, RIH dry to find lip. Tagged up on lip at 11850.5'. 21 :05 - 21 :30 0.42 STKOH C PROD1 PU clean, ease back into it at 1.5 bpm pump rate. Looking for the lip with pumps on. Good weight transfer while RIH. Stop at 11849.7' when saw 50 psi increase in motor work and 300 Ibs downhole WOB. String weight=21400 Ibs at surface. Increase pump rate slowly from 1.5 bpm to 2.9 bpm. Free spin 2890 psi at 2.48 bpm. 21 :30 - 21 :50 0.33 STKOH C PROD1 Resume time drilling at 2'/hr. String weight=20350, Surface stacked weight=O, downhole WOB=11 0 Ibs. 3240 psi at 2.79 bpm. 21 :50 - 22:20 0.50 STKOH C PROD1 11850.5', Stacked wt until we had 3200 Ibs stacked, (17 klbs string wt), and got a little bite. We got motor work, wt back at surface, and 150 Ibs downhole wob. Continue to time drill at 2.0'/hr. 22:20 - 23:15 0.92 STKOH C PROD1 11851.5', Got several little bites and drill offs at 2'/hr. Weight transfer appears to be better. Begin fast time drilling at about 6'/hr. Downhole WOB increasing. Getting motor work to 300 Ibs. 23:15 - 00:00 0.75 STKOH C PROD1 11859.8', Started stacking again. Pick up at 42 klbs. Looked much better on pick up. Backream up slowly 70', then ream in slowly. 7/17/2004 00:00 - 00:50 0.83 STKOH C PROD1 RIH with pumps at 1.2 bpm. Didn't see any1hing until 11857.5' . Bring pumps up slowly. Start time drilling at 2'/hr. Free spin=3220 psi at 2.74 bpm. 00:50 - 01 :30 0.67 STKOH C PROD1 Try drilling at 40 fph. Jumped ledge and are still in old well bore. RIH to 11906' and get a survey. Survery confirms we are in old wellbore. PU to 11840', and try to drytag lip again. Found lip at 11850.0, but jumped over it easily. We don't have much of a lip, and it is just about where it has Printed: 7/20/2004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/17/2004 00:50 - 01 :30 0.67 STKOH C PROD1 always been. Not making any progress. 01 :30 - 04:00 2.50 STKOH C PROD1 POOH to look at bit and make a plan forward. 04:00 - 05:00 1.00 STKOH C PROD1 Tag up, stand injector back. Lay down BHA #26, Bit #23. Bit #23, a Smith M-07 was graded 1,8 and was 1/4" undergauge at 3.5". All the cutters on the shoulder of the bit were broken or missing. Confir with town. Make up Smith M-09 bit to RIH and resume sidetracking. 05:00 - 07:40 2.67 STKOH C PROD1 RIH with BHA #27, bit #24. Tagged the SSSV and worked through by rolling pump. 07:40 - 08:00 0.33 STKOH C PROD1 Log tie-in minus 22' 08:00 - 09:30 1.50 STKOH C PROD1 RIH setdown at 10853' PU to 44 RIH 45L 1 bpm tag 10852 pu to 51 rih 1 bpm 90L tag pu rih setdown push hard pu once more RIH make it through. RIH to 11850 wo pump and lightly touched ledge. 09:30 - 14:20 4.83 STKOH C PROD1 P/U 2' and start time drilling f/11848' to 11856.9' 2.5/2.5 2910 fs 165R TF start seeing mw f/11854' to 56.9 P/U make 50' wiper RI H to 11840' then 2'/min .5bpm see MW starting at 11856' and encouageing signs we could be sidetracked. Continue moving ahead past 11860' into the zone that was originally drilled 150'/hr. Keep pushing with 100psi MW though this area down to 11890'. Indications are we are not sidetracked. Move back up to 11850' and start over there. 14:20 - 16:20 2.00 STKOH C PROD1 Drillingltroughing 14'/hr f/ 11755' to fault zone at 10765'. First pass 80'/hr seeing 300psi MW and 2k wob at 11755', PU and make 2nd pass 20'/hr. Start 3rd. Town called and decided to stop sidetrack operations. 16:20 - 16:50 0.50 DRILL C PROD1 RIH to cleanout with TF's as drilled. Setdown at 12089' PU 37k RIH tagged again. PU adjust TF RIH to 12319' TD 16:50 - 17:20 0.50 DRILL C PROD1 TOH to 11740'. RIH wo pump to 11770' okay RIH to 11840' down pump RIH found ledge at 11852 with 90R TF orient to highside.. .clear 17:20 - 18:00 0.67 DRILL C PROD1 TOH 18:00 - 19:45 1.75 DRILL C PROD1 Continue POH. IAP=700 psi, OAP=360 psi. SSSVP=4500 psi. Pit vol=288 bbls. 19:45 - 20:10 0.42 DRILL C PROD1 Tag up at surface with BHA #27, Bit #24. Stand back injector. Blow down BHA and lay down. Bit recovered graded 0,1, and it was in gauge, and it very good shape. 20:10 - 20:30 0.33 EV AL P PROD1 Safety meeting Re: picking up Reeves logging tools. Discuss proceedure for RU, radiation safety, operational parameters, hazards and mitigations. 20:30 - 00:00 3.50 EVAL P PROD1 PU Reeves logging tools, BHA #28. 7/18/2004 00:00 - 01 :00 1.00 EVAL P PROD1 Continue RIH with Reeves memory logging tools. 01 :00 - 02:30 1.50 EVAL P PROD1 Make a -20' correction. Start down logging pass from 10600' at 30 fpm. Very small weight bobble at 10850', but nothing to worry about. Same at 11850', weight bobble, but not anything bad. Stop logging tools at 12129', 10' shy of TD. 02:30 - 03:20 0.83 EVAL P PROD1 Start logging pass up at 30 fpm. Caliper should be open. 03:20 - 05:10 1.83 EVAL P PROD1 Logging pass completed. POOH with logging tools. Pumping 2.0 bpm on way OOH. Printed: 7/20/2004 12:59:45 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/23/2004 7/20/2004 N2 Spud Date: 6/23/2004 End: 7/20/2004 7/18/2004 05:10 - 05:30 0.33 EVAL P PROD1 Stand back injector. Lay down BHI BHA. 05:30 - 08:00 2.50 EVAL P PROD1 Download Reeves Memory tool to ensure we have good data. 08:00 - 09:50 1.83 EVAL P PROD1 WOO to either sidetrack or run liner. 09:50 - 10:00 0.17 CASE P RUNPRD PJSM: review plan forward to run liner. 10:00 - 10:40 0.67 CASE P RUNPRD Setback injector. RIg up to run liner. 10:40 - 13:30 2.83 CASE P RUNPRD P/U 10' pup jt with 2 deg bend placed 3' from bottom. Make up 36jts slotted 2-7/8" 6.16# STL, 8 jts slotted 3-3/16", 5jts solid 3-3/16" 6.4# TCllliner. (1539.92') 13:30 - 15:30 2.00 CASE P RUNPRD Make-up BHi tools. Make-up Baker CTLRT and BHi equipment to liner. Stab on injector. 15:30 - 16:15 0.75 CASE N DFAL RUNPRD RIH with liner and Baker's EDC open. No problem past SSSV. Made it to 6232'. Lost communications with BHi tools. 16:15 -17:15 1.00 CASE N DFAL RUNPRD TOH 17:15 - 18:00 0.75 CASE N DFAL RUNPRD Setback injector. Make repairs to electrical short in BHllower quick connect. 18:00 - 19:50 1.83 CASE P RUNPRD RIH with liner on coil tubing. 19:50 - 20:25 0.58 CASE P RUNPRD Make -20' correction to get on depth at window. Check weight up=43 klbs. Continue RIH at 30'/min. Set down 3 times at 10852'. Current non scribed orientertool face is 75L. PU, orient to 0 deg RIH and tagged up at 10853'. PU, orient to 45R, RIH and bounced thru. I love Coiltrack!!! Continue RIH. Tagged up at 11900', and had overpull at PU. TF currently 90R, non scribed. Try to orient to 45R. TF stay the same and we twisted the coil. RIH, tag up at 11905'. Continue to PU and tag up. Now at 11908'. Nothing on the caliper log at this depth. Looks like we are pushing something down hole. DD reports that Reeves left the 3.25" nylon bottom nose off of their logging BHA in the hole. This may be it. Continue to work it in the hole. 20:25 - 20:45 0.33 CASE P RUNPRD Bottom is now hard at 11908'. Continue to PU and set down on the obstruction. Moving tool face with the orienter around clockwise each time we tag up. Orienter is torquing up the coil, but we get our TF change as we yo-yo pipe. Orient all the way around to the right, then back to the left in 30 deg steps. Hard tag up each time. Finally managed to beat our way thru it after hitting it for 20 minutes. PU weight was 52 klbs. 20:45 - 21 :55 1.17 CASE P RUNPRD Continue to RIH. Tagged up at 12140'. Stack weight. Close EDC. Bring pumps up to release from liner. Got good indication of shear at 34 klbs. Drop pumps, PU at 39 klbs. Liner is in place and on depth at TD. 21 :55 - 22:40 0.75 CASE P RUNPRD POOH with CTLRT. At 6000' while POOH mud returns transitioned from clean brown mud to a very thick "chocolate moose". The mud coming back looks crosslinked. It is very thick and will support shear. It looks like pudding. Start junking mud, and continue to POOH. 22:40 - 23:30 0.83 CASE P RUNPRD Tag up at surface. Stand back injector. Lay down CTLRT. Ball recovered from CTLRT. 23:30 - 23:45 0.25 CONDHL P RUNPRD Safety meeting prior to running CSH. 23:45 - 00:00 0.25 CONDHL P RUNPRD Begin running 54 joints of 1-1/4" CS hydril work string in the hole. Dropping a 3/4" ball thru each joint as a drift. 7/19/2004 00:00 - 01 :45 1.75 CONDHLP OTHCMP Continue RIH with 54 joints of 1-1/4" CS hydril work string. 01:45 - 03:15 1.50 CONDHLP OTHCMP Make up BHI BHA. Printed: 7/20/2004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 OTHCMP RIH with the CS hydril on coil tubing with BHI BHA. Tried pumping 2.0 bpm to clean any remaining "moose" OOH. The moose was climbing up out of the possum belly and wouldn't drain through a 3" drain line. Drop pumps to min, and continue RIH taking moose mud returns. Better get some shovels if it doesn't get better soon. Mud returns have cleaned up considerably. The mud is back to being a fluid again. Continue RIH. Pumping 1.7 bpm at 2750 psi. Saving mud. Tag PBTD, PU 10'. Pump 30 bbl biozan spacer at 2.25 bpm, 3900 psi. Swap to KCL. PJSM reviewing handling procedures for bleach. Pump 30 bls bleach from vac truck. From 12127' spot 15bbls around liner then PUH laying in remainder. Pull to 10000'. Shut-in backside. Squezze 5 bbls at .5bpm rate Final WHP 760psi. Wait 5min bleed to 550psi. TOH to top of 1-1/4" hydril. Setback injector. UD 1-1/4" CSH P/U BHA #31 RIH 10000' Shut-in backside. Sqeeze 5bbls away at .5bpm Volume Pumped Pressure 0.5 70 1.0 185 1.5 458 2.0 475 2.5 510 3.0 560 3.5 600 4.0 640 4.5 670 5.0 695 Increase rate 1bpm 6.0 780 8.0 815 10.0 825 Increase rate 1.5 bpm 12.0 875 16.0 890 20.0 895 30.0 908 OTHCMP TOH to 9570' laying diesel. HMAN OTHCMP Notice a mistake in the plans. The BHA is slightly too long to close the Master Valve with the BHA above it. The well would be underbalanced and would have presure on it when at surface. Isolate the coil and keep hole full pumping down the backside with 2% KCLwhile TOH. HMAN OTHCMP Tag up at surface. Check for flow. No flow observed. Stand back injector. Lay down BHI BHA. Make up nozzle BHA. Gauled threads on BHI upper quick connect. Had to change out. 7/19/2004 03:15 - 04:15 1.00 CONDHL P 04:15 - 05:30 1.25 CONDHL P OTHCMP 05:30 - 05:50 0.33 CONDHL P OTHCMP 05:50 - 07:45 1.92 CONDHL P OTHCMP 07:45 - 07:55 0.17 CONDHL P OTHCMP 07:55 - 09:00 1.08 CONDHL P OTHCMP 09:00 - 09:30 0.50 CONDHLP OTHCMP 09:30 - 11 :15 1.75 CONDHLP OTHCMP 11:15-13:30 2.25 CONDHL P OTHCMP 13:30 - 13:45 0.25 CONDHL P OTHCMP 13:45 - 15:40 1.92 CONDHL P OTHCMP 15:40 - 16:30 0.83 CONDHL P OTHCMP 16:30 - 17:10 17:10 - 18:35 0.67 CONDHL P 1.42 CONDHL N 18:35 - 19:50 1.25 CONDHL N Printed: 7/20/2004 12:59:45 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 7/19/2004 19:50 - 21 :50 2.00 CONDHL N HMAN OTHCMP 21 :50 - 23:50 2.00 CONDHL P OTHCMP 23:50 - 00:00 0.17 CONDHL P OTHCMP 00:00 - 00:10 0.17 RIGD P POST 00:10 - 01:15 1.08 RIGD P POST 7/20/2004 01 :15 - 01 :30 0.25 RIGD P POST 01 :30 - 02:05 0.58 RIGD P POST 02:05 - 02:15 0.17 RIGD P POST 02:15 - 03:10 0.92 RIGD P POST 03:10 - 04:45 1.58 RIGD P POST 04:45 - 05:30 0.75 RIGD P POST 05:30 - 12:00 6.50 RIGD P POST RIH with BHA #32 to displace well to diesel. POOH laying in diesel from 10600'. Tag up with nozzle. Hold PJSM prior to blowing coil down with N2. Continue with safety meeting Re: N2. PT hard lines from N2 unit to 4000 psi. Lines test fine. Open up to coil, taking returns accross the top of the closed master to the tiger tank. Pumping 1500 cfm for 15 minutes, then bleeding off to tiger. Lay down nozzle BHA. Cut BHI CTC, Rig up cabling system to unstab coil from injector. PJSM prior to unstabbing coil. Unstab coil and secure end to shipping reel. Rig down gooseneck, and packoff. Set the injector on the rig floor. Continue to clean pits. Drop reel down out of reel house. ND BOPE. Clean mud tanks. Install tree cap and test to 4000psi. Rig Released at 1200hrs Moved to DS #18 for Summer Maintenance Printed: 7/20/2004 12:59:45 PM Obp e BP-GDB Baker Hughes INTEQ Survey Report e -.I: INTE.Q Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-21 Slot Name: L2-21 Well Position: +N/-S 6126.20 ft Northing: 5963620.00 ft Latitude: +E/-W 3582.18 ft Easting: 692748.94 ft Longitude: Position Uncertainty: 0.00 ft 21 70 18 18.289 N 148 26 18.302 W Wellpath: L2-21A 500292148501 Current Datum: 18 : 21 11/11/1985 00:00 Magnetic Data: 7/1512004 Field Strength: 57607 nT Vertical Section: Depth From (TVD) ft 39.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angie: +E/-W ft 0.00 L2-21 10755.00 ft Mean Sea Level 25.30 deg 80.89 deg Direction deg 138.00 Heigbt 52.00 ft Survey Program for Definitive Wellpath Date: 8/2/2004 Validated: Yes Version: 6 Actual From To Survey Toolcode ft ft 55.30 10753.39 1 : Schlumberger GCT multishot (55.30-115~ 10755.00 12139.00 MWD (10755.00-12139.00) MWD Tool Name Schlumberger GCT multishot MWD - Standard Annotation 10753.39 8894.91 TIP 10755.00 8896.04 KOP 12139.00 8967.02 TO Survey: MWD Start Date: 7/14/2004 CoilT rak Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 10753.39 45.60 281.40 8894.91 8842.91 -490.81 -4987.65 5963001.41 687775.81 -2972.64 0.00 10755.00 45.61 281.40 8896.04 8844.04 -490.59 -4988.78 5963001.61 687774.68 -2973.57 0.62 10775.32 49.15 281.40 8909.79 8857.79 -487.63 -5003.43 5963004.19 687759.95 -2985.57 17.42 10804.29 58.25 277.00 8926.93 8874.93 -483.96 -5026.45 5963007.27 687736.85 -3003.70 33.70 10830.05 65.27 271.30 8939.12 8887.12 -482.35 -5049.06 5963008.29 687714.20 -3020.02 33.49 10850.48 65.78 263.93 8947.59 8895.59 -483.13 -5067.62 5963007.04 687695.67 -3031.87 32.92 10879.19 68.89 255.38 8958.67 8906.67 -487.90 -5093.65 5963001.60 687669.78 -3045.73 29.53 10919.98 73.47 245.19 8971.86 8919.86 -500.94 -5129.91 5962987.63 687633.87 -3060.30 26.17 10959.67 83.94 236.50 8979.64 8927.64 -519.91 -5163.79 5962967.81 687600.48 -3068.88 33.99 10991.06 91.33 232.37 8980.93 8928.93 -538.14 -5189.28 5962948.93 687575.47 -3072.39 26.96 11014.04 91.18 226.89 8980.43 8928.43 -553.01 -5206.78 5962933.61 687558.37 -3073.05 23.85 Obp e BP-GDB Baker Hughes INTEQ Survey Report e -.I: 1NTßQ Survey 11044.67 86.52 218.66 8981.04 8929.04 -575.46 -5227.55 5962910.64 687538.17 -3070.26 30.87 11079.24 85.90 205.37 8983.34 8931.34 -604.64 -5245.80 5962881.00 687520.68 -3060.79 38.40 11111.46 84.11 191.12 8986.16 8934.16 -635.04 -5255.82 5962850.35 687511.44 -3044.90 44.41 11143.12 85.52 184.91 8989.02 8937.02 -666.25 -5260.22 5962819.05 687507.85 -3024.65 20.04 11178.93 86.30 178.28 8991.58 8939.58 -701.94 -5261.21 5962783.35 687507.77 -2998.80 18.60 11206.29 86.14 171.90 8993.39 8941.39 -729.12 -5258.87 5962756.23 687510.81 -2977.03 23.28 11240.84 87.43 162.88 8995.33 8943.33 -762.75 -5251.35 5962722.81 687519.19 -2947.01 26.33 11266.97 91.37 156.24 8995.60 8943.60 . -787.21 -5242.23 5962698.59 687528.93 -2922.72 29.54 11295.04 91.79 149.00 8994.83 8942.83 -812.11 -5229.34 5962674.03 687542.46 -2895.59 25.83 11325.00 90.44 142.39 8994.24 8942.24 -836.84 -5212.46 5962649.74 687559.96 -2865.92 22.51 11351.88 89.95 136.58 8994.15 8942.15 -857.27 -5195.01 5962629.77 687577.93 -2839.06 21.69 11380.58 89.74 131.83 8994.23 8942.23 -877.27 -5174.44 5962610.31 687599.01 -2810.44 16.57 11410.08 90.08 125.63 8994.28 8942.28 -895.72 -5151.44 5962592.45 687622.47 -2781.33 21.05 11444.85 89.65 130.10 8994.36 8942.36 -917.06 -5124.00 5962571.83 687650.45 -2747.12 12.92 11476.01 89.71 137.32 8994.53 8942.53 -938.58 -5101.49 5962550.90 687673.50 -2716.06 23.17 11504.87 90.75 142.63 8994.42 8942.42 -960.67 -5082.93 5962529.29 687692.62 -2687.23 18.75 11535.00 91.39 147.77 8993.85 8941.85 -985.39 -5065.75 5962505.01 687710.43 -2657.36 17.19 11566.45 89.12 144.84 8993.71 8941.71 -1011.56 -5048.30 5962479.31 687728.54 -2626.24 11.78 11607.10 89.65 138.13 8994.15 8942.15 -1043.34 -5023.01 5962448.19 687754.64 -2585.69 16.56 11644.37 90.17 132.24 8994.21 8942.21 -1069.77 -4996.75 5962422.44 687781.57 -2548.48 15.86 11672.15 90.29 127.32 8994.10 8942.10 -1087.54 -4975.41 5962405.23 687803.36 -2521.00 17.72 11712.09 88.54 124.24 8994.50 8942.50 -1110.89 -4943.01 5962382.72 687836.34 -2481.97 8.87 11741.18 88.82 119.86 8995.17 8943.17 -1126.32 -4918.37 5962367.93 687861.37 -2454.01 15.08 11770.17 88.69 114.06 8995.80 8943.80 -1139.45 -4892.55 5962355.46 687887.52 -2426.98 20.01 11800.70 89.15 110.63 8996.38 8944.38 -1151.05 -4864.32 5962344.59 687916.04 -2399.46 11.33 11836.37 91.68 106.57 8996.12 8944.12 -1162.43 -4830.52 5962334.09 687950.11 -2368.40 13.41 11864.31 91.12 102.82 8995.44 8943.44 -1169.51 -4803.51 5962327.70 687977.30 -2345.06 13.57 11893.39 94.01 98.67 8994.14 8942.14 -1174.93 -4774.98 5962323.02 688005.95 -2321.94 17.38 11923.19 95.58 95.76 8991.65 8939.65 -1178.66 -4745.52 5962320.04 688035.50 -2299.46 11.07 11939.20 95.09 92.94 8990.16 8938.16 -1179.86 -4729.63 5962319.24 688051.41 -2287.93 17.80 11972.87 95.02 87.34 8987.19 8935.19 -1179.95 -4696.10 5962320.02 688084.93 -2265.43 16.57 12004.15 96.33 81.77 8984.09 8932.09 -1177.00 -4665.13 5962323.77 688115.81 -2246.90 18.21 12025.62 95.83 76.74 8981.82 8929.82 -1173.02 -4644.16 5962328.28 688136.67 -2235.83 23.41 12055.13 95.21 69.51 8978.97 8926.97 -1164.49 -4616.07 5962337.52 688164.53 -2223.37 24.48 12085.14 98.84 61.73 8975.30 8923.30 -1152.22 -4588.96 5962350.49 688191.31 -2214.35 28.43 12139.00 98.84 61.73 8967.02 8915.02 -1127.01 -4542.09 5962376.89 688237.52 -2201.72 0.00 T Azimuths to True North Survey: MWD (l2-21/L2~21A} L2-21 (l2-21) Magnetic North: 25.30' Created By: Brij Potnis Date: 812f2004 L2~2tA I MWO tion: West(.)/East(+ Vertical Section at 138.00' [50ft/in] 8/2/2004 1 :02 PM BP Amoco WELLPATH DETAILS L2·21A 500292148501 Parent WeUpath: L2-21 Tie on MO: 10755.00 Rig: Nordic 2 Ref. Datum: 18: 2111111/1985 00:00 52.00ft V.Section Origin Origin Starting Angle +W·S +EfvW From TVD 13ß.00· 0.00 0.00 39.50 REFERENCE INFORMATION Co-ordinate WE) Reference Well Centre L2·21. True North Vertica1 ( D Reference: ~Slem: Mean Sea Level Sec1ion rys Refarence: ot· 21 \O.OON.O.OOE) Measured Depth Reference: 18: 211 1111198500:00 52.00 Calculation Method: Minimum Curvature ~EJ.w $/J;!f>~ TARGErOBA,lLS TVD +JIII-$ (¡.M ¡¡OC g:gg K8Z ANNOTATIONS 1V1J MD Annotation 8842.91 88443)4 8915;02 8951 ! 13-3/8" CSG, 72#, L-80, 10::; NOTES: L2..21 A Sidetrack Completion 3681'· r-Á I TOP OF 7" LNR I- 10423' 19-5/8" CSG, 47#, L-80, ID::; 8.681" 10629' LJ j " ... 12-718" TBG-IPG, 6.5#, L-80, .00579 bpf, ID::; H 10952' I PERFORATION SUMMARY REF LOG: LOT/CNL ON 11129/85 ANGLE AT TOP PERF: 46 @ 10734' Note; Refer to Ffoductiol1 DB for historical perf data SIZE SPF INTERVAL Opn/Sq~ 4" 4 10734 - 10814 4" 4 10842 - 10920 2-1/8" 6 10965 - 10975 2" 4 10968 - 11075 2-1/8" 6 11006-11016 2-1/8" 6 11042-11062 4" 4 11122 - 11170 I 7" LNR, 29#, L-80, .0371 bpf, OA TE REV BY COMMENTS 11/28/85 ORIGINAL COM PlErION 11/05/01 RN/TP CORRECTIONS 06/16/03 CMO/TLP MAX ANGLE CORRECTION 02/07/04 MJA/KK ADPERFS 02/21/04 MDClTLP PFS STIM TUBES SHOT 07/01/04 cjs After RWO/before CTDST 04/14/86 04/14/86 02/07/04 10/09/87 0'2/07/04 02/07/04 04/14/86 11502' 11550' " \ BY COMMENTS ~ 10930' ¡-IT' X 2-7/8" BROWN I-S PKR·I 10952' 10949' 10965'-10915' J- .PFS 11006-11016' I- PFSSTIMTUBESHOT02l21/04 11090' 11110' BROWN I-B PKR I 112-7/8"CAM 0 NIP, W/PLUG ANO SAND COVERING PLUG 11122' SEC18, T11N, BP . . ® L~\~ FRANK H. MURKOWSKI, GOVERNOR A I/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 F~ (907)276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L2-21A (Revised) BP Exploration (Alaska) Inc. Permit No: 204-104 Surface Location: 1726' NSL, 1058' EWL, SEC. 18, T11N, R15E, UM Bottomhole Location: 498' NSL, 3278' WEL, SEC. 13, TUN, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). BY ORDER O~E COMMISSION DATED this~~; of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. WGIt ~'I¿sl Z-Ðof o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1726' NSL, 1058' EWL, SEC. 18, T11N, R15E, UM Top of Productive Horizon: 1229' NSL, 3915'WEL, SEC. 13, T11N, R14E, UM Total Depth: 498' NSL, 3278' WEL, SEC. 13, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 692749 y- 5963620 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 10755 feet Maximum Hole Angle: 94 ... STATE OF ALASKA ... . ALASKTOI~D GAS CONSERVATION COM~ION PER~~¿~O~5RILL Æf6=-=-'dn rb. Current Well ClaÖ Stratigraphic Test B ~~~?~tOry ~ g:velog~:~: g~s ~~~~~~~;~~e 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU L2-21A / 6. Proposed Depth: 12. Field I Pool(s): MD 12360 TVD 890055 Prudhoe Bay Field I Lisbur~ 7. Property Designation: Pool ADL 028307 8. Land Use Permit: 13. Approximate Spud Date: June 29, 2004 / 14. Distance to Nearest Property: 16,236' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 52' feet None within this pool less than 500' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3195 Surface: 2305 Hole Casing 4-1/8" x 3-3/4" 3-3/16" Weight 6.2# Grade Coupling Length MD TVD MD /' TVD (including stage data) L-80 TCII 1760' 10600' 8737' 12360' 8900' Uncemented Slotted Liner PRESENT. W f;1..1... CONP.\TI()N$QJv1MARY(Td beèOrYlpl~.e(!fQr~edril.IAND8ª",ently()peråti()I1$) Total Depth MD (ft): Total Depth TVD Plugs (measured): Depth MD (ft): Depth TVD Junk (measured): 11550 9429 11110 11502 9397 None Structural Conductor 119' 20" 1810# Poleset 119' 119' Surface 3687' 13-3/8" 2500 sx AS III, 500 sx Class 'G' 3687' 3623' Intermediate 10630' 9-5/8" 1126 sx Class 'G', 300 sx AS I 10630' 8810' Production Liner 1117' 7" 450 sx Class 'G' 10423' - 11540' 8665' - 9422' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8882' - 9177' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements Perforation Depth MD (ft): 10734' - 11170' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ted Stagg Title CT Drilling Engineer Date: Contact Ted Stagg, 564-4694 Phone 564-4694 Permit To Drill API Number: Permit A~~~V , I Number: 204-104 50- 029-21485-01-00 Date: !;/ltJ.{Zt1¿1 '7 'Conditions of Approval: Samples Required 0 Yes .J8No Mud Log Re uired ~ .. . t:!Ydro en ~ulfide Measures ~es 0 No Directional Survey Required Other: l est ED P L:- ~S{){) pSt P-RY C, 0, S 17. DCC? , See cover letter for other requirements o Yes ~NO ~Yes 0 No APPROVED BY THE COMMISSION Date ~:Atœ ORIGINAL -e -e BP L2-21A RWO/CTD Sidetrack (Revision: 6/24/2004 for BHL change) Summary of Operations: Nordic 2 rigged up on L2-21 on June 22 to swap tubing and sidetrack the well through tubing. All workover phase plans rema~·n. .p~tted but the bottom hole location for the L2-21A sidetrack has been moved laterally by approximatel 00 iéet. The new target BHL and the directional plan are given in this application for a new Permit to Drill. . /~ summary below, changes from the existing Permit to Drill 204-104 are shown in underlined bold. Approximately 1.605 ft of 3.75"-41/8" open hole is planned to access the target. The well will be completey with a 3 3/16"slotted, un-cemented liner. Pre-rig work: See Sundry 10-403 filed for this job. Nordic 2 RWO - Tubing swap: Planned for July 1,2004 (ri2 actually accepted 06:00 6/23/04) 1. RU Nordic 2 with 13-518" BOPE. Test stack. 2. Pull 2 7/8" tubing. Recover 2 7/8" packer and tailpipe. 3. Install 4 W' tubing with packer, 4 GLMs and TRSSSV, and 4 1/16" tree. 4. PT completion. Nordic 2 CTD - Set Whipstock and Sqz. cel)1ent, Mill window, Drill and Complete sidetrack: 1. NU 7-1/16" CTD BOPE. Test. / 3. Set mechanical whipstock at approx. 10,755' MD (8,845'ss). 4. Squeeze cement to shut-off uppermost perforations. 5. Mill 3.80" window in 7" liner. 6. Directionally drill-l.6050f 3.75"-41/8" open hole. 7. Log open hole with GR/Resistivity/Density/Neutron/Sonic. 7. Run 3 3/16" slotted liner from TD up to approx. 10,600' MD (8737'ss). 8. Displace well to diesel. RD Nordic 2. Mud Program: · RWO: 2% KCI and ~~ Biozan for milling. · CTD: Plo-Pro (8.6 [Jppg). Viscosified 6% KCI will be used for drilling if losses are total. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 1.760 ft of 3 3/16" slotted un-cemented liner. Well Control: · BOP diagrams are 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. Directional · See attached directional plan. Max. planned hole angle is approx. -98 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. A full suite of memory open hole logs will be run at TD consisting of GR/Resistivity/SoniclDensity/Neutron. -e -e Hazards · L2 is not an H2S Pad. Most wells on L2 Pad measure between 25 and 50 ppm H2S in produced fluids. ,;.~._......-- · Lost circulation risk is considered high. Drilling may be done with viscosified water if losses are total. Reservoir Pressure · Pore pressure is estimated to be 3195 psi at 8900'TVDss (6.9~. · Maximum surface pressure with gas (0.1 psi/ft) to surface iS~ psi TREE = WELLHEAD = ACTIJð. TOR = KB. 8..EV = BF. 8..EV = KOP= Mix Angle = ~tum M> = ~tum TVD = --- ? FM::: AXa.SON 52' 2715' 50 @ 11200' 10691' 8800' SS 1'3-3/8" CSG. 72#,l-80,1D= 12.347" H 3687' ~ (Minimum'D = 2.259" @ 10694' I AV A BPL NIPPLE TOPOF7" LNR H 10423' 9-5/8"CSG, 47#,l-80,1D =8.681" H 10629' I 12-7/f!' TOO-PC, 6.5#, l-80. .00579 bpf, ID= 2.441" rt. 10952' ÆRFOAA TON SUMMRY REF lOG: LOT/CN.. ON 11/29185 ANGLEATTOPÆRF: 46 @ 10734' Note: Refer to Production DB fO( hi¡torical perf data SIZE SPF INTER\! Al Opn/Sqz DA 1E 4" 4 10734 - 10814 0 04/14/86 4" 4 10842 - 10920 0 04/14/86 2-1/f!' 6 10965 - 10975 0 02107/04 2" 4 10968 - 11075 0 10109187 2-1/8" 6 11006-11016 0 02107/04 2-1If!' 6 11042 - 11062 0 02107/04 4" 4 11122 - 11170 0 04/14/86 ~ 11502' 17"U.R, 29#,l-80, .0371 bpf. 0=6.184" H 11550' ~ TE RBI BY COM\1eITS 11/28185 OAGINAL COMPlETION 11A>5A>1 RNI1P CORRB:TONS 06116.03 CM:>lTlP MAX ANGLE OORRECTION 02A>7A>4 MJ6.11<K AIPER=S 02/21A>4 MOCI1lP PFS S11M TUBES SHOT DA 1E REV BY L2-21 ., SAI£1Y NOtES, CAT 'SSSV, H2S 75 (PPM] . - 2178' H2-7/8" CAM:::O TRDP-1A SSSV ,ID = 2.312" Q-fEMlCAl MANDRElS fST' MD NDI IEV TYÆ , VlV I LATCH' PORTI Qð.ì 1 2234 2234 0 KBM3 DV BK-2 11/f L. GAS lFT M6,tIORElS ~ ST MD ND lEV TYÆ VLV LATCH PORT Qð.l 2 2804 2801 11 Mc.FMiO DV BK-2 11/11 3 5615 5063 42 Mc.FMiO DOtÆ BK-2 1/4 11/11 4 7863 6743 40 MC-FMiO DV BK-2 11/f 5 9458 7973 43 Mc.FMiO DV BK-2 11/f 6 10244 8538 44 Mc.FMiO DOtÆ RK 5/16 11/11 PROWCTION MANm8..S IST MD IND IEVI TYÆ VlV ILATCHI PORT Qð.l 7 10641 8817 43 Mc.Ftvt-lO DV BK-2 11/f - CL - l L Z f Z ---i 10342' H9-5/8" X 2-718" BroWN f-B A<R I ... .... 1 10694' H2-7/8" AVA BR. NPW/OSlV,ID=2.259" D I 1072S' H2-7/8" BROWN BLAST JOINTS Z L 10930' Hr X'-7"·OR>WN" A<R I ~ 1096S'"1097S'HPFS S11M lUBE SHOT 02121/04 ~ \ I 10952' H2-7/8"lUBlNGTALW/WlEG 1 10949' H8..M> TT lOGGED 07/27/86 1 (j---111000-11016' HPFS S11M lUBE SHOT 02121/04 [j-111042-11057' HPFSSTlM lUBE SHOT 02121/04 1 11090' H7" X 2-7/S" BroWN I-B A<R I l 11110' H2-718"CAMDNP,WIFlUG I AND SAND CCN ERING PlUG y I 11122' H2-718" CAM:::O TLBING TAL 1 11122' H8..M>TTlOGGED04/15/86 I -- COMM:NTS USBUR-IE UNIT WELl: l2-21 PERMT tb: 1852750 API tb: 5O-029-21485~0 see 18, T11N. R15E. 4503.47' FB. & 390828'ft, BP Exploration (Alaska) l2-21A Proposed Sidetrack Completion 113-3/8" CSG, 72#, L-80, ID:::: I 9-5/8" CSG, 47#, L-80, ID:::: 8.681" 12-7/8" TBG-IPG, 6.5#, L-80, .00579 bpf, ID:::: 2.441" 4" 4" 2" 2-1/8" 2-1/8" 4" ¡ 7" LNR, 29#, L-80, .0371 ID:::: 6.184" DATE 11/28/85 11/05/01 06/16/03 02/07/04 02/21/04 REV BY ORIGINAL RNlTP CORRECTIONS CMOITLP I\AAX MJA/KK ADPERFS MDC/TLP PFS 3687' 1-1 04/14/86 04/14/86 02/07/04 10/09/87 02/07/04 02/07/04 04/14/86 ~ ~ 11006-11016' v RE\lBY 11090' PERFORATION SUMI\AARY REF LOG: LDT/CNL ON 11129/85 ANGLE AT TOP PERF: 46 @10734' Note: Refer to Production DB for hi$torlcal perf data SPF INTERV AL Opn/Sqz 4 10734 - 10814 0 4 10842 - 10920 0 2-1/8" 6 10965 - 10975 0 4 10968-11075 0 6 11006-11016 0 6 11042 - 11062 0 4 11122 -11170 0 BP Amoco WElLPATH DETAILS PIar¡#iS L2-21A 500292'148501 P.rertt W~ path: '-2·21. Tko ort MD: 10753.$9 ...' fteIf.DatumJ V.$ec.t1cm """.. 138.00' Nofdh:2 18:2111/111198500:00 52.0Øft ~r:z~ ~~= 0.00 0.00 :=;v,o 39.50 REFERENCE INFORMATION Co-ordinate (NJE¡ Reference: Well Centre: L2-21 , True North Vertic8! (TVD Reference: System: Mean Sea Level Mea~~on~~h ~= T~~ 2j'i Wi~~j'j¡g5<gbo 5200 Calculatioñ Method: Minìmum Curvature ... , ~ . , , 7 . ~o &EC1"WN УTAJL$ TV. ..., ;I-'" ..... Tatget ..... 2#1.40 ffØ:42.91 490AJ-1 -49&1.$5 .... 1),00 .2972.64 ...., U1,40 &144.04 -49D.Æ9 49ð1U8 .... ...... 4913;$1 "".., 2#1.40 ðf51.:8o -41&7.12 _5003.00 .... 0.:00 4935.21 ..... :41.54 892'3.68 0$14.81 ~13tkt.2 32.33 303.96 -3053.44 ~9_AO 200.14 8031l.S8 .tSi2A1 .sz19.21 aMI3 276.1'6 4U37.22 ..... 142,03 $37.18 "1oø~M)3 ..si51.62: 14.00 269.11 ·2104.24 üAUt 111.26 ð113$,.31 ·1134,76 ....~.. 13.-9$ 27i:t92 ·2MU.13 ~"U .3.1M &931,42 -11&0.441- 47".98 13.94 278.34- ~340.72 ".85 114,$.1 IW16,22 -11.94.68 >4S't.2.B1 14.00 ..... ·21n.oa "'.., 80.41 889$.50 -122$,89 -43311.03 14.00 271.11 -1D$U.$1 ANNOTATIONS 'I'D MD Anrtotatiolt TIP KO_ · · · · T · · TD TARGETDETAILB WD '.00 ggg T LEGEND L2-21 (L2-21) P!an#151-2-21A Plan #15 Azimuths to True North Plan; Plan #15 (L2-211PIan#15 L2-21A) Magnetic North: 25.33' Created By; Digital Business Client UserOate; 6/2412004 Ma netic Field 57605nT gle: 80.88° : 612412004 Model: bggm2003 lNTEQ -~-_..~ ..... c:: ~ C 'I'" .... -e BP-GDB Baker Hughes INTEQ Planning Report -e Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-21 Slot Name: 21 L2-21 Well Position: +N/-S 6126.20 ft Northing: 5963620.00 ft Latitude: 70 18 18.289 N +E/-W 3582.18 ft Easting : 692748.94 ft Longitude: 148 26 18.302 W Position Uncertainty: 0.00 ft Wellpath: Plan#15 L2-21A 500292148501 Current Datum: 18: 2111/11/198500:00 Magnetic Data: 6/24/2004 Field Strength: 57605 nT Vertical Section: Depth From (TVD) ft 39.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-21 10753.39 ft Mean Sea Level 25.33 deg 80.88 deg Direction deg 138.00 Height 52.00 ft Targets L2-21A Fault 1 0.00 -257.83 -4999.49 5963234.00 687757.99 70 18 15.737 N 148 28 44.083 W -Polygon 1 0.00 -257.83 -4999.49 5963234.00 687757.99 70 18 15.737 N 148 28 44.083 W -Polygon 2 0.00 -376.08 -5030.54 5963115.00 687729.99 70 18 14.573 N 148 28 44.986 W -Polygon 3 0.00 -495.36 -5060.61 5962995.00 687702.99 70 18 13.400 N 148 28 45.861 W -Polygon 4 0.00 -592.36 -4984.07 5962900.00 687781.99 70 18 12.447 N 148 28 43.627 W -Polygon 5 0.00 -688.36 -4907.50 5962806.00 687860.99 70 18 11.503 N 148 2841.393 W -Polygon 6 0.00 -794.97 -4885.23 5962700.00 687885.99 70 18 10.455 N 148 28 40.741 W -Polygon 7 0.00 -902.61 -4861.98 5962593.00 687911.99 70 18 9.396 N 148 28 40.062 W -Polygon 8 0.00 -1022.88 -4892.08 5962472.00 687884.99 70 18 8.213 N 148 28 40.937 W -Polygon 9 0.00 -1117.89 -4815.49 5962379.00 687963.99 70 18 7.279 N 148 28 38.702 W -Polygon 10 0.00 -1225.50 -4793.24 5962272.00 687988.99 70 18 6.221 N 148 28 38.051 W -Polygon 11 0.00 -1332.14 -4769.97 5962166.00 688014.99 70 18 5.172 N 148 28 37.371 W -Polygon 12 0.00 -1441.77 -4746.77 5962057.00 688040.99 70 18 4.094 N 148 28 36.692 W -Polygon 13 0.00 -1536.75 -4671.18 5961964.00 688118.99 70 18 3.161 N 148 28 34.487 W -Polygon 14 0.00 -1441.77 -4746.77 5962057.00 688040.99 70 18 4.094 N 148 28 36.692 W -Polygon 15 0.00 -1332.14 -4769.97 5962166.00 688014.99 70 18 5.172 N 148 28 37.371 W -Polygon 16 0.00 -1225.50 -4793.24 5962272.00 687988.99 70 18 6.221 N 148 28 38.051 W -Polygon 17 0.00 -1117.89 -4815.49 5962379.00 687963.99 70 18 7.279 N 148 28 38.702 W -Polygon 18 0.00 -1022.88 -4892.08 5962472.00 687884.99 70 18 8.213 N 148 28 40.937 W -Polygon 19 0.00 -902.61 -4861.98 5962593.00 687911.99 70 18 9.396 N 148 28 40.062 W -Polygon 20 0.00 -794.97 -4885.23 5962700.00 687885.99 70 18 10.455 N 148 28 40.741 W -Polygon 21 0.00 -688.36 -4907.50 5962806.00 687860.99 70 18 11.503 N 148 2841.393 W -Polygon 22 0.00 -592.36 -4984.07 5962900.00 687781.99 70 18 12.447 N 148 28 43.627 W -Polygon 23 0.00 -495.36 -5060.61 5962995.00 687702.99 70 18 13.400 N 148 28 45.861 W -Polygon 24 0.00 -376.08 -5030.54 5963115.00 687729.99 70 1814.573N 148 28 44.986 W L2-21A Fault 2 0.00 -1076.18 -4881.44 5962418.99 687896.99 70 18 7.689 N 148 28 40.626 W -Polygon 1 0.00 -1076.18 -4881.44 5962418.99 687896.99 70 18 7.689 N 148 28 40.626 W -Polygon 2 0.00 -1151.75 -4977 .42 5962340.99 687802.99 70 18 6.945 N 148 28 43.423 W -Polygon 3 0.00 -1228.31 -5073.42 5962261.99 687708.99 70 18 6.191 N 148 28 46.220 W -Polygon 4 0.00 -1304.85 -5170.42 5962182.99 687613.99 70 18 5.438 N 148 28 49.047 W -Polygon 5 0.00 -1381.42 -5266.43 5962103.99 687519.99 70 18 4.684 N 148 2851.844 W -e BP-GDB Baker Hughes INTEQ Planning Report -e Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-21 Slot Name: 21 L2-21 Well Position: +N/-S 6126.20 ft Northing: 5963620.00 ft Latitude: 70 18 18.289 N +E/-W 3582.18 ft Easting : 692748.94 ft Longitude: 148 26 18.302 W Position Uncertainty: 0.00 ft Wellpath: Plan#15 L2-21A 500292148501 Current Datum: 18: 21 11/11/198500:00 Magnetic Data: 6/2412004 Field Strength: 57605 nT Vertical Section: Depth From (TVD) ft 39.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-21 10753.39 ft Mean Sea Level 25.33 deg 80.88 deg Direction deg 138.00 Height 52.00 ft Targets L2-21A Fault 1 0.00 -257.83 -4999.49 5963234.00 687757.99 70 18 15.737 N 148 28 44.083 W -Polygon 1 0.00 -257.83 -4999.49 5963234.00 687757.99 70 18 15.737 N 148 28 44.083 W -Polygon 2 0.00 -376.08 -5030.54 5963115.00 687729.99 70 18 14.573 N 148 28 44.986 W -Polygon 3 0.00 -495.36 -5060.61 5962995.00 687702.99 70 18 13.400 N 148 28 45.861 W -Polygon 4 0.00 -592.36 -4984.07 5962900.00 687781.99 70 18 12.447 N 148 28 43.627 W -Polygon 5 0.00 -688.36 -4907.50 5962806.00 687860.99 70 18 11.503 N 148 2841.393 W -Polygon 6 0.00 -794.97 -4885.23 5962700.00 687885.99 70 18 10.455 N 148 2840.741 W -Polygon 7 0.00 -902.61 -4861.98 5962593.00 687911.99 70 18 9.396 N 148 28 40.062 W -Polygon 8 0.00 -1022.88 -4892.08 5962472.00 687884.99 70 18 8.213 N 148 28 40.937 W -Polygon 9 0.00 -1117.89 -4815.49 5962379.00 687963.99 70 18 7.279 N 148 28 38.702 W -Polygon 10 0.00 -1225.50 -4793.24 5962272.00 687988.99 70 18 6.221 N 148 28 38.051 W -Polygon 11 0.00 -1332.14 -4769.97 5962166.00 688014.99 70 18 5.172 N 148 28 37.371 W -Polygon 12 0.00 -1441.77 -4746.77 5962057.00 688040.99 70 18 4.094 N 148 28 36.692 W -Polygon 13 0.00 -1536.75 -4671.18 5961964.00 688118.99 70 18 3.161 N 148 28 34.487 W -Polygon 14 0.00 -1441.77 -4746.77 5962057.00 688040.99 70 18 4.094 N 148 28 36.692 W -Polygon 15 0.00 -1332.14 -4769.97 5962166.00 688014.99 70 18 5.172 N 148 28 37.371 W -Polygon 16 0.00 -1225.50 -4793.24 5962272.00 687988.99 70 18 6.221 N 148 28 38.051 W -Polygon 17 0.00 -1117.89 -4815.49 5962379.00 687963.99 70 18 7.279 N 148 28 38.702 W -Polygon 18 0.00 -1022.88 -4892.08 5962472.00 687884.99 70 18 8.213 N 148 28 40.937 W -Polygon 19 0.00 -902.61 -4861.98 5962593.00 687911.99 70 18 9.396 N 148 28 40.062 W -Polygon 20 0.00 -794.97 -4885.23 5962700.00 687885.99 70 18 10.455 N 148 2840.741 W -Polygon 21 0.00 -688.36 -4907.50 5962806.00 687860.99 70 18 11.503 N 148 2841.393 W -Polygon 22 0.00 -592.36 -4984.07 5962900.00 687781.99 70 18 12.447 N 148 28 43.627 W -Polygon 23 0.00 -495.36 -5060.61 5962995.00 687702.99 70 18 13.400 N 148 28 45.861 W -Polygon 24 0.00 -376.08 -5030.54 5963115.00 687729.99 70 18 14.573 N 148 28 44.986 W L2-21A Fault 2 0.00 -1076.18 -4881.44 5962418.99 687896.99 70 18 7.689 N 148 28 40.626 W -Polygon 1 0.00 -1076.18 -4881.44 5962418.99 687896.99 70 18 7.689 N 148 28 40.626 W -Polygon 2 0.00 -1151.75 -4977 .42 5962340.99 687802.99 70 18 6.945 N 148 28 43.423 W -Polygon 3 0.00 -1228.31 -5073.42 5962261.99 687708.99 70 18 6.191 N 148 28 46.220 W -Polygon 4 0.00 -1304.85 -5170.42 5962182.99 687613.99 70 18 5.438 N 148 28 49.047 W -Polygon 5 0.00 -1381.42 -5266.43 5962103.99 687519.99 70 18 4.684 N 1482851.844W -e -e BP-GDB Baker Hughes INTEQ Planning Report Targets Annotation -Polygon 6 -Polygon 7 -Polygon 8 0.00 -1304.85 -5170.42 5962182.99 687613.99 70 18 5.438 N 148 28 49.047 W 0.00 -1228.31 -5073.42 5962261.99 687708.99 70 18 6.191 N 148 28 46.220 W 0.00 -1151.75 -4977.42 5962340.99 687802.99 70 18 6.945 N 148 28 43.423 W 0.00 -942.28 -5304.17 5962541.99 687470.99 70 18 9.003 N 148 28 52.954 W 0.00 -942.28 -5304.17 5962541.99 687470.99 70 18 9.003 N 148 28 52.954 W 0.00 -962.53 -5411.73 5962518.99 687363.99 70 18 8.803 N 148 28 56.089 W 0.00 -1039.10 -5507.74 5962439.99 687269.99 70 18 8.049 N 148 28 58.887 W 0.00 -955.73 -5637.65 5962519.99 687137.99 70 18 8.868 N 148 29 2.676 W 0.00 -1039.10 -5507.74 5962439.99 687269.99 70 18 8.049 N 148 28 58.887 W 0.00 -962.53 -5411.73 5962518.99 687363.99 70 18 8.803 N 148 28 56.089 W L2-21A Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 10753.39 10755.00 10775.00 10930.00 11062.00 11477.00 11697.00 11897.00 12117.00 12360.00 I Plan: Principal: 8842.91 8844.04 8857.80 8923.68 8932.58 8937.18 8938.31 8931.42 8916.22 8899.50 TIP KOP 3 4 5 6 7 8 9 TO Plan #15 Similar to Ted's Case115 Yes Date Composed: Version: Tied-to: 6/24/2004 7 From: Definitive Path Plan Section Information 10753.39 45.60 281.40 8842.91 -490.81 -4987.65 0.00 0.00 0.00 0.00 10755.00 45.61 281.40 8844.04 -490.59 -4988.78 0.62 0.62 0.00 359.99 10775.00 47.41 281.40 8857.80 -487.72 -5003.00 9.00 9.00 0.00 0.00 10930.00 83.20 241.54 8923.68 -514.87 -5135.12 32.33 23.09 -25.72 303.96 11062.00 89.40 200.14 8932.58 -612.41 -5219.21 31.63 4.70 -31.36 276.76 11477.00 89.44 142.03 8937.18 -1005.03 -5157.62 14.00 0.01 -14.00 269.71 11697.00 89.99 111.26 8938.31 -1134.76 -4983.22 13.99 0.25 -13.99 270.92 11897.00 93.88 83.64 8931.42 -1160.48 -4786.98 13.94 1.94 -13.81 278.34 12117.00 93.85 114.51 8916.22 -1194.68 -4572.87 14.00 -0.01 14.03 88.99 12360.00 93.81 80.41 8899.50 -1225.69 -4336.03 14.00 -0.02 -14.03 271.11 -e BP-GDB Baker Hughes INTEQ Planning Report -e Survey 10753.39 45.60 281.40 8842.91 -490.81 -4987.65 5963001.41 687775.81 -2972.64 0.00 0.00 TIP 10755.00 45.61 281.40 8844.04 -490.59 -4988.78 5963001.61 687774.68 -2973.57 0.62 359.99 KOP 10775.00 47.41 281.40 8857.80 -487.72 -5003.00 5963004.11 687760.39 -2985.21 9.00 0.00 3 10800.00 52.25 272.92 8873.94 -485.39 -5021.92 5963005.95 687741.41 -2999.61 32.33 303.96 MWD 10825.00 57.62 265.53 8888.31 -485.71 -5042.35 5963005.11 687721.00 -3013.04 32.33 309.44 MWD 10850.00 63.38 259.00 8900.62 -488.67 -5063.88 5963001.59 687699.55 -3025.25 32.33 313.70 MWD 10875.00 69.40 253.11 8910.64 -494.21 -5086.08 5962995.49 687677.50 -3035.98 32.33 316.92 MWD 10900.00 75.60 247.68 8918.16 -502.22 -5108.52 5962986.91 687655.28 -3045.04 32.33 319.28 MWD 10925.00 81.93 242.54 8923.03 -512.54 -5130.74 5962976.02 687633.34 -3052.24 32.33 320.92 MWD 10930.00 83.20 241.54 8923.68 -514.87 -5135.12 5962973.58 687629.02 -3053.44 32.33 321.92 4 10950.00 83.98 235.22 8925.91 -525.28 -5152.03 5962962.74 687612.38 -3057.02 31.63 276.76 MWD 10975.00 85.07 227.35 8928.30 -540.83 -5171.43 5962946.69 687593.38 -3058.45 31.63 277.47 MWD 11000.00 86.24 219.51 8930.20 -558.92 -5188.56 5962928.17 687576.73 -3056.46 31.63 278.22 MWD 11025.00 87.48 211.69 8931.57 -579.20 -5203.08 5962907.53 687562.74 -3051.11 31.63 278.82 MWD 11050.00 88.77 203.88 8932.39 -601.29 -5214.71 5962885.15 687551.67 -3042.48 31.63 279.24 MWD 11062.00 89.40 200.14 8932.58 -612.41 -5219.21 5962873.92 687547.46 -3037.22 31.63 279.50 5 11075.00 89.39 198.32 8932.72 -624.69 -5223.49 5962861.54 687543.50 -3030.97 14.00 269.71 MWD 11100.00 89.38 194.82 8932.99 -648.64 -5230.62 5962837.41 687536.98 -3017.93 14.00 269.73 MWD 11125.00 89.36 191.32 8933.26 -672.99 -5236.27 5962812.92 687531.96 -3003.62 14.00 269.77 MWD 11150.00 89.35 187.82 8933.54 -697.64 -5240.43 5962788.18 687528.44 -2988.08 14.00 269.81 MWD 11175.00 89.34 184.32 8933.83 -722.49 -5243.07 5962763.27 687526.44 -2971.38 14.00 269.85 MWD 11200.00 89.34 180.82 8934.12 -747.46 -5244.19 5962738.28 687525.96 -2953.57 14.00 269.89 MWD 11225.00 89.34 177.32 8934.40 -772.45 -5243.78 5962713.31 687527.01 -2934.73 14.00 269.93 MWD 11250.00 89.34 173.82 8934.69 -797.37 -5241.85 5962688.45 687529.58 -2914.92 14.00 269.97 MWD 11275.00 89.34 170.31 8934.98 -822.13 -5238.40 5962663.79 687533.66 -2894.21 14.00 270.01 MWD 11300.00 89.34 166.81 8935.27 -846.63 -5233.44 5962639.43 687539.24 -2872.69 14.00 270.05 MWD 11325.00 89.35 163.31 8935.56 -870.78 -5227.00 5962615.45 687546.30 -2850.43 14.00 270.09 MWD 11350.00 89.36 159.81 8935.84 -894.49 -5219.09 5962591.95 687554.81 -2827.52 14.00 270.13 MWD 11375.00 89.37 156.31 8936.12 -917.67 -5209.76 5962569.02 687564.74 -2804.04 14.00 270.17 MWD 11400.00 89.38 152.81 8936.39 -940.24 -5199.02 5962546.73 687576.05 -2780.09 14.00 270.21 MWD 11425.00 89.40 149.31 8936.66 -962.12 -5186.93 5962525.17 687588.70 -2755.74 14.00 270.25 MWD 11450.00 89.42 145.81 8936.92 -983.21 -5173.52 5962504.43 687602.65 -2731.09 14.00 270.28 MWD 11475.00 89.44 142.31 8937.17 -1003.45 -5158.85 5962484.58 687617.83 -2706.24 14.00 270.32 MWD 11477.00 89.44 142.03 8937.18 -1005.03 -5157.62 5962483.03 687619.10 -2704.24 14.00 270.36 6 11500.00 89.49 138.81 8937.40 -1022.75 -5142.97 5962465.69 687634.20 -2681.27 13.99 270.92 MWD 11525.00 89.55 135.32 8937.61 -1041.05 -5125.94 5962447.84 687651.69 -2656.27 13.99 270.95 MWD 11550.00 89.61 131.82 8937.79 -1058.28 -5107.83 5962431.08 687670.23 -2631.35 13.99 270.98 MWD 11575.00 89.67 128.32 8937.95 -1074.37 -5088.71 5962415.49 687689.77 -2606.60 13.99 271.01 MWD 11600.00 89.74 124.83 8938.07 -1089.26 -5068.63 5962401.11 687710.21 -2582.10 13.99 271.03 MWD 11625.00 89.80 121 .33 8938.17 -1102.91 -5047.69 5962388.01 687731.50 -2557.94 13.99 271.05 MWD 11650.00 89.87 117.83 8938.25 -1115.25 -5025.95 5962376.24 687753.55 -2534.23 13.99 271.06 MWD 11675.00 89.93 114.34 8938.29 -1126.24 -5003.50 5962365.82 687776.27 -2511.04 13.99 271.07 MWD 11697.00 89.99 111 .26 8938.31 -1134.76 -4983.22 5962357.82 687796.76 -2491.13 13.99 271.08 7 11700.00 90.05 110.85 8938.30 -1135.84 -4980.42 5962356.82 687799.59 -2488.46 13.94 278.34 MWD 11725.00 90.56 107.40 8938.17 -1144.03 -4956.80 5962349.24 687823.40 -2466.57 13.94 278.34 MWD 11750.00 91.06 103.95 8937.82 -1150.78 -4932.74 5962343.11 687847.63 -2445.45 13.94 278.32 MWD 11775.00 91.56 100.50 8937.25 -1156.07 -4908.32 5962338.44 687872.18 -2425.18 13.94 278.27 MWD 11800.00 92.05 97.05 8936.46 -1159.88 -4883.63 5962335.27 687896.96 -2405.82 13.94 278.20 MWD 11825.00 92.54 93.60 8935.46 -1162.20 -4858.76 5962333.59 687921.88 -2387.46 13.94 278.09 MWD 11850.00 93.01 90.14 8934.25 -1163.02 -4833.80 5962333.41 687946.84 -2370.16 13.94 277.95 MWD 11875.00 93.48 86.69 8932.83 -1162.33 -4808.86 5962334.74 687971.76 -2353.98 13.94 277.78 MWD 11897.00 93.88 83.64 8931.42 -1160.48 -4786.98 5962337.15 687993.58 -2340.72 13.94 277.59 8 11900.00 93.89 84.06 8931.22 -1160.16 -4784.01 5962337.55 687996.55 -2338.96 14.00 88.99 MWD -e BP-GDB Baker Hughes INTEQ Planning Report -e Survey 11925.00 93.94 87.57 8929.51 -1158.34 -4759.14 5962340.01 688021.36 -2323.67 14.00 89.02 MWD 11950.00 93.98 91.08 8927.78 -1158.04 -4734.20 5962340.94 688046.28 -2307.21 14.00 89.26 MWD 11975.00 94.00 94.58 8926.04 -1159.27 -4709.30 5962340.35 688071.21 -2289.63 14.00 89.50 MWD 12000.00 94.01 98.09 8924.30 -1162.03 -4684.52 5962338.23 688096.05 -2271.00 14.00 89.74 MWD 12025.00 94.00 101.60 8922.55 -1166.29 -4659.95 5962334.60 688120.72 -2251.39 14.00 89.99 MWD 12050.00 93.98 105.11 8920.81 -1172.05 -4635.69 5962329.47 688145.12 -2230.88 14.00 90.23 MWD 12075.00 93.94 108.62 8919.08 -1179.28 -4611.82 5962322.85 688169.16 -2209.53 14.00 90.48 MWD 12100.00 93.89 112.13 8917.37 -1187.96 -4588.44 5962314.77 688192.75 -2187.44 14.00 90.72 MWD 12117.00 93.85 114.51 8916.22 -1194.68 -4572.87 5962308.46 688208.49 -2172.03 14.00 90.96 9 12125.00 93.87 113.39 8915.68 -1197.92 -4565.58 5962305.41 688215.86 -2164.74 14.00 271.11 MWD 12150.00 93.93 109.88 8913.98 -1207.11 -4542.39 5962296.81 688239.27 -2142.40 14.00 271.03 MWD 12175.00 93.97 106.37 8912.26 -1214.87 -4518.69 5962289.66 688263.16 -2120.77 14.00 270.79 MWD 12200.00 93.99 102.86 8910.53 -1221.16 -4494.57 5962283.99 688287.44 -2099.95 14.00 270.55 MWD 12225.00 94.01 99.35 8908.78 -1225.97 -4470.10 5962279.82 688312.02 -2080.01 14.00 270.31 MWD 12250.00 94.00 95.85 8907.04 -1229.26 -4445.38 5962277 .16 688336.82 -2061.02 14.00 270.06 MWD 12275.00 93.98 92.34 8905.29 -1231.04 -4420.51 5962276.02 688361.72 -2043.05 14.00 269.82 MWD 12300.00 93.95 88.83 8903.57 -1231.30 -4395.58 5962276.40 688386.65 -2026.18 14.00 269.57 MWD 12325.00 93.90 85.32 8901.85 -1230.02 -4370.67 5962278.31 688411.52 -2010.46 14.00 269.33 MWD 12350.00 93.84 81.81 8900.16 -1227.23 -4345.89 5962281.74 688436.22 -1995.96 14.00 269.09 MWD 12360.00 93.81 80.41 8899.50 -1225.69 -4336.03 5962283.54 688446.03 -1990.51 14.00 268.85 TD -e -e All Measurements are from top of Riser 6/8/2004 '- <D en .- cr: bttm of bag middle of slips Blind/Shears .......................... /' TOTs l .' middle of pipes 23/8" combi ram/slips ....................... ....---. r----' middle of flow cross Mud Cross Mud Cross '---' '---' I r middle of blind/shears variable bore pipe 31/2"·2 7/S" ................. '.. .... / I TOTs l ." 2 3/8" combi ram/slips ..... middle of pipelslips ........ ........... BAG top of bag Flow Tee ~H:~~~ADõc~ ,$ lOa. ~OlLARS :::~5tiir~'Re~~ðf) ~ < è/(çf£~ TERaU; L H.QBSf.,E BP EXPLORATION AK INC "Mastercard Check" POBOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 I: ~ 25 2000 bOI: ~ ~ ~ ".11 b 2 27.., .55 b'" 0.. ~ 89-6/1252 119 DATE OCo· 2. Lf-OL( . e . e e. e. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) M1JLTI LATERAL (Jf API number last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE" Tbe permit is for a new weHbore segment of existing well Permit No, API No. Productionsbould continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). Pu..OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to full compliance witb 20 MC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing .exception tbat may occur. AU dry ditch sample sets submitted to the Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample inter-vals through target zones. . e . e . e . e Well bore seg D Annular Disposal D Field & Pool PRUDHOE BAY, LISBURNE OIL - 640144 Well Name: PRUDHOE BAY UN LIS L2-21A Program DEV PTD#: 2041 040 Company BP EXPLORATION (ALASKA) INC nitial ClassfType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Administration 1 Pe (Il) it fee attacheJ:!. - - - - - - · Yes ~ ~ - - - - - - - - 2 .Lease .numberapprQpriate. . . . Y.es. Revjsed BottomholeLocation 6/24/04 3 .U.nlq!Je well n.ame .and lJumb.er . . . . . . . . . . . . . . . . . . . . . . ........ Yes.. - - ~ . - - - - - - - - - - . - - - - - 4 WeJlJocated ina. d.efineJ:! .pool. . - - - - - - - - - - - - - .... Yes. - - - - - - 5 WellJocated prpper .dlstance from driJling unitb.o!Jnd.acy Yes. 6 WeUJocated prpper .dlstance. from Qtber wells. . . . - - - - - .... Yes - - - - - - 7 S.u{ficienl.acreage.ayailable indrilJilJg unjl. . . - - - - - - Yes 8 Jfdeviated' js. weJlbore platincJu.ded . . . . . . . . . . . . . . . · Yes - - - - - - - - - - - - 9 .Operator only affected party. . ... Yes - - - - - - - 10 .Ope~ator bas.apprppriate.Qond in.force . . . . . . . . . . . . . . . . . ........ Yes - - - - - - - - - - - - - - - - - - - - 11 Permit can Þe issued wjtbout conservation order. . ... Yes - - - - - - - - - - - - - Appr Date 12 Permit ~an Þe issued wjtbout admioistratille.approvaJ . . - .. - - Yes - - - - -- RPC 6/10/2004 13 Can permit be approved before 15-day wait Yes 14 Well .located within area and. strata ;:¡uthorized by.lnjectiolJ Order # (p!Jt 10# in. cpmmellts). (For. NA - - - - - - 15 AJI wells. wit)liD.1l4.llJile.areaof reyiew idelltified (For servjce .V(elJ only). . . . . . . . . . . . . . . NA - - - - - - - - - - - - - - - - - - -- 16 Pre-produçed injector; J:!!Jr;:¡tionof pre-proJ:!!Jctioo less than 3 montbs. (For service well QnJy) . NA - - - - - - 17 ACMP FInding of CQnsistencyhas Þeen jss!Jed. for. tbis project - - - - - - -- · .NA - - - - - - - - - - Engineering 18 .C.ollductor st(ingpJQvided . - - - - .NA 19 .S.urfacecasingpJQte~ts alLkDQWn USDWs . - - - - - NA - - - - - - - - - - - - 20 .CMT v.ol adequate to circ.ulate oD.cooductor. 8< SUJfcsg . - - - - -- NA 21 CMT vol adequate. to tie-in .long string tos!Jrf csg - - - - .... .NA - - - - - 22 .CMT wil! coyer.a]l koo.w.n .prod!Jctiye borizon.s - - - - - - . . . N.o Slotte.d, - - - - - - 23 .C.asillg de.siglls ad.equate fpr C,T, B&.perllJafrpst . . . .. Yes 24 AJ:!equ<ltetan.kage.oJ re.seI'Ye pit - - -- - - - - - - .. Yes CTDU. . - - - - - - 25 Jf.aJe-J:!rilt hasa. tOA03 for <lbandonmeDt beell apPJQved . . · Yes 6/10/20.04. - - - - - 26 Aøequ;:¡te.V(e!!bore separ¡¡tjo.nproposeJ:!. . . . . . . . . . . . . . . . . . . . . . . .. Yes - - - - - - - - - - - - - - - - - 27 Jfdjvecter req!,lired, does it meet reguJatioos. . . - - - - - - NA Sidetrack. . Appr Date 28 .Drillillg fluid prQgram s~hematic& equip Jistadequate. . · Yes Max MW8, 7. ppg.. . WGA 6/25/2004 29 BOPEs, do Jhey meet. reguJaJion . ~ ~ - - - - - ~ - - .Yes 30 .BOPEpress raiillg appropriate; Jest to (puJ psig iD.comments) .Yes Test to .3500_ psi.MSF' 23.05 psi. 31 .C.hokellJanjfold cQmpJies w/APIRF'-53 (May 64) - ~ - - - .. Yes 32 WQrk wi!! occur withoutoper¡¡tjonsbutdown_ . . - - - - - - - - - - - · Yes - - - - - - 33 .Is presence. Qf H2S gas. prob.able. . - - - - . _.. No. I\IQtall H2S pad. '34 Meçba.nic¡¡lcPIJc!itlon pt wells within AOR yerified (fo~~ervjce welJ only). . _ . .NA. Geology 35 Permit call be issued w!Q hydr.ogen sulfide meCls!,lres . - - - - - - .. No 36 .D_ata.preseoted on. pote.ntiClI oveJpressure .zooes. . . . . . . - - - - NA Appr Date 37 Sei.smicaDalysjs Qf sbaJlow gas.zolles. NA - - - - - - RPC 6/10/2004 38 Seabed .cOl'!ditioo survey (if oft-shore) . . _. NA. - - - - - - - - 39 . Conta.ct namelp)loneJor_wee~ly progre!;sreports [exploratpry .only] ._NA Geologic Engineering Public Commissioner: Date: Commissioner Date Commissioner Date DTS 6/14/2004 JKN 6/14/2004 /J"/::J'I1'0 () (,I?.r J 4- . (ill} . @ -.r¡ QD ,~\\ FRANK H. MURKOWSKI, GOVERNOR AI,ASIi& OIL AM) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L2-21A BP Exploration (Alaska) Inc. Permit No: 204-104 Surface Location: 1726' NSL, 1058' EWL, SEC. 18, TllN, RI5E, UM Bottomhole Location: 63' NSL, 4107' WEL, SEC. 13, Tl1N, RI4E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to reOOll the above development well. This permit to redrill does not exempt you :ITom obtaining additional permits or approvals required by law :ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. PIe provide at least twenty-four (24) hours notice for a representative of the Commission to 'tn ss any required test. Contact the Commission's petroleum field inspector at 9 59-3 er). BY ORDER OF THE COMMISSION DATED thisLeday of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1726' NSL, 1058' EWL, SEC. 18, T11N, R15E, UM Top of Productive Horizon: 1229' NSL, 3915' WEL, SEC. 13, T11N, R14E, UM Total Depth: 63' NSL, 4107' WEL, SEC, 13, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 692749 y- 5963620 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18····GãsirigprOgrãri1 Size Casinç¡ 4-1/8" x 3-3/4" 3-3/16" ALAS' OIL AND ~:~~g~S~':~~ON !MMISSlcR PERMIT TO DRILL JUN 0 9'2004 20 MC 25.005 : ." _ ;',~iû\; 1b. Current Well Class 0 Exploratory aa!;\(flIQ )ri1entOl - '·,E!]Mdftfpré fane o Stratigraphic Test 0 Service [j'ðevelopmenh~~~,J:;;!,~ngle Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU L2-21A 6. Proposed Depth: 12. Field I Pool(s): MD 12167 TVD 8925 Prudhoe Bay Field I Lisburne ~ 7. Property Designation: Pool ADL 028307 WúÆ &/10/2.004 o 8. Land Use Permit: 13. Approximate Spud Date: July 1, 2004 14. Distance to Nearest Property: 13,582' 9. Acres in Property: 2560 Maximum Hole Angle 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 52' feet None within this pool less than SOD' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) . Downhole: 3195 psig Surface: 2305 psig /' 10755 ft 980 Hole Weiç¡ht 6.2# Grade L-80 Coupling Length TCII 1567' MD TVD MD 10600' 8789' 12167' TVD (including staç¡e data) 8925' Uncemented Slotted Liner PRESENT WELL. CQNDITIONSUMMARY (To .b~CQO"Ipleté( fOrRedrj AND~e-eritryºp~rations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): I Effective Depth TVD 11550 9429 11110 11502 9397 Structural Conductor 119' 20" 1810# Poleset 119' 119' Surface 3687' 13-3/8" 2500 sx AS III, 500 sx Class 'G' 3687' 3623' Intermediate 10630' 9-5/8" 1126 sx Class 'G', 300 sx AS I 10630' 8810' Production Uner 1117' 7" 450 sx Class 'G' 10423' - 11540' 8665' - 9422' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8882' - 9177' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements Perforation Depth MD (ft): 10734' - 11170' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ted Title CT Drilling Engineer Date: Contact Ted Stagg, 564-4694 Phone 564-4694 Permit To Drill Number: ..2. 0 ~ Conditions of Approval: Samples Required DYes J8'No Hydro en Sulfide Measures ftYes DNa 3,S"C>D y?d pe.v C. 0, Permit Approval Date: Mud Log Required Directional Survey Required Sj'7.000. See cover letter for other requirements QYes ~o ftYes fj No Approved By: ".. Form 10-401 Revised 12/2W BY ORDER OF OR' G J N A L THE COMMISSION ~~ðc/~ Date ( . ubm' In Duplicate . . BP L2-21 A RWO/CTD Sidetrack Summary of Operations: Well L2-21 is scheduled for a through tubing sidetrack with coiled tubing. Prior to CTD sidetracking, the 2 7/8" tubing and packer will be recovered and new 4 Y:z" tubing and packer will be installed per the proposed ,/ schematic. The sidetrack, L2-21A, will kick off from a window milled from a mechanical whipstock set in // Lisburne Zone 6 and will target Lisburne Zone 5. Approximately 1,412 ft of 3.75"-4 1/8" opeyole is planned to access the target. The well will be completed with a 3 3/16"slotted, un-cemented liner. Pre-rig work: See Sundry 10-403 filed for this job. Nordic 2 RWO - Tubing swap: Planned for July 1,2004 1. RU Nordic 2 with 13-5/8" BOPE. Test stack. 2. Pull 2 7/8" tubing. Recover 2 7/8" packer and tailpipe. 3. Install 4 Y2" tubing with packer, 4 GLMs and TRSSSV, and 4 1/16" tree. 4. PT completion. Nordic 2 CTD - Set Whipstock and Sqz. cel!1ent, Mill window, Drill and Complete sidetrack: 1. NU 7-1/16" CTD BOPE. Test. .,/ 3. Set mechanical whipstock at approx. 10,755' MD (8,845'ss). 4. Squeeze cement to shut-off uppermost perfora~s. 5. Mill 3.80" window in 7" liner. 6. Directionally drill -1,412' of 3.75"-41/8" open hole. 7. Log open hole with GR/Resistivity/Density/Neutron/Sonic. / 7. Run 33/16" slotted liner from TD up to approx. 10,600' MD (8737'ss). 8. Displace well to diesel. RD Nordic 2. Mud Program: · RWO: 2% KCI and ~~liozan for milling. · CTD: PIo-Pro (8.6 (;lppg). Viscosified 6% KCI will be used for drilling if losses are total. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: // · 1567 ft of 3 3/16" slotted un-cemented liner. Well Control: · BOP diagrams are 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. Directional · See attached directional plan. Max. planned hole angle is approx. -98 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. A full suite of memory open hole logs will be run at TD consisting of GR/Resistivity/Sonic/Density/Neutron. . . Hazards . L2 is not an H2S Pad. Most wells on L2 Pad measure between 25 and 50 ppm H2S in produced fluids. .- · Lost circulation risk is considered high. Drilling may be done with viscosified water if losses are total. Reservoir Pressure · Pore pressure is estimated to be 3195 psi at 8900'TVDss (6.9 ppg). / · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2305 psi . TREE = WELLHEA D = Actï:itïfoR -;--- KB. ELEV-;;-~ BF~'ELEV = k6Þ= ~.- IvIax A n91e = Datum rJí5 =- Datum TVD = ? FWC À-XELSON ~--52'; --277S; 50 @'112oo; 10691' 8800' SS 113-318" CSG, 72#, L-80, ID = 12.347" H 3687' r---.4 IMinimum ID = 2.259" @ 10694" AVA BPL NIPPLE TOPOF7" LNR H 10423' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I-l 10629' I 2-7/8"TBG-PC,6.5#,L-80,.00579bpf,ID=2,441" H 10952' I ÆRFORA TON SUMV1ARY REF LOG: LDT/CNL ON 11/29/85 ANGLE AT TOP PERF: 46 @ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTffiV AL Opn/Sqz DA TE 4" 4 10734- 10814 0 04114/86 4" 4 10842 - 10920 0 04/14/86 2-1/8" 6 10965- 10975 0 02/07/04 2" 4 10968 - 11075 0 10/09/87 2-1/8" 6 11006- 11016 0 02/07/04 2-1/8" 6 11042-11062 0 02/07/04 4" 4 11122 - 11170 0 04114/86 ~ 11502' /7"LNR,29#,L-80,.0371bpf,D=6.184" H 11550' DATE 11/28/85 11105101 06/16103 02107104 02121104 REV BY CO MV1 ENTS ORIGINAL COMPLETION RN/lP CORRECTONS CWO/1LP MAX ANGLE CORRECTION MJA/KK AŒ'ERFS MDC/1LP PFS STlM lUBES SHOT DATE . L2-21 SAFETY NOTES: CAT I-SSSV, H2S 75 (PPM) . - 2178' H2-7/8" CAWCOTRDP-1A SSSV, ID = 2.312" Œi8v1ICAL MANDRELS ISTI MD NDI DEVI TYÆ I VLV LATCH PORTI 1 2234 2234 0 KBMG DV BK-2 . GAS LFT fvV\NDRELS .. ST MD ND DEV TYÆ VLV LATCH 2 2804 2801 11 Mc.FrvHO DV BK-2 3 5615 5063 42 Mc.FrvHO DOrvE BK-2 1/4 4 7863 6743 40 Mc.FrvHO DV BK-2 5 9458 7973 43 Mc.FrvHO DV BK-2 6 10244 8538 44 Mc.FrvHO DOrvE RK 5/16 PRODUCTION MANDRB...S ISTI MD IND DEV TYÆ I VLV LATCH PORT I 7 10641 8817 43 Mc.FrvHO DV BK-2 - CL - DATE 11/85 L PORT DA TE 11/11/91 11/11/91 11/85 11/85 11/11/91 DATE 11/85 L :8: :8:---1 10342' Hg..518"X2-7/8"BROWNI-BA<R I I .. ~ I 10694' -i2-718" AVA BA.. NIP W/OSLV, 10=2.259" ~ 10728' H2-718" BROWN BLAST JOINTS Z L 1093U Hrx 2-7/B" BROWN 'B A<R I ~ 1 0965'-10975'HpFS STlM ruBE SHOT 02/21/04 I" 110952' H2-718"ruBINGTAILW/WLEG I 10949' HB...rvÐ IT LOGGED 07/27186 [j---i 11006-11016' HPFS STlM ruBE SHOT 02/21/04 (]---111042-11 057' H PFS STlM ruBE SHOT 02/21/04 I 11090' 1-17" X 2-7/8" BROWN I-B A<R 1 , 11110' H2-718"CAMDNIP,W/A..UG lAND SAND COV ffilNG PLUG 11122' H2-718" CAWCO TU3ING TAIL I 11122' H B...rvÐ IT LOGGED 04115186 I I - REV BY COMrvENTS LISBURNE UNIT WELL: L2-21 PffiMT f'.b: 1852750 API f'.b: 50-029-21485-00 SEC 18, T11 N, R15E, 4503,47' FEL & 3908.28' FNL BP Exploration (Alas ka) A Proposed Sidetrack Completiora /' SAFETY NOTES: CAT I-SSSV, H2S 15 (PPM) 113-3/8" CSG, 72#, L-80, 10 = 12.347" H 3687' ~ I TOP OF 7" LNR H 10423' 19-5/8" CSG, 47#, l-80, 10=8.681" H 10629' ~ 12-7/8" TBG-IPG, 6.5#, L-80, .00579 bpf, 10 = 2.441" H 10952' ÆRFORA TION SUMMARY REF lOG: lDT/CNl ON 11/29/85 ANGLE AT TOP PERF: 46@ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/sqz DATE 4" 4 10734 - 10814 0 04/14/86 4" 4 10842 - 10920 0 04/14/86 2-1/8" 6 10965 10975 0 02/07/04 2" 4 10968 - 11075 0 10/09/87 2-1/8" 6 11006 - 11016 0 02/07/04 2-1/8" 6 11042 -11062 0 02/07/04 4" 4 11122 - 11170 0 04/14/86 11502' I T' LNR, 29#, l-80, .0371 bpf, 10 = 6.184" H 11550' DATE 11/28/85 11/05/01 06/16/03 02/07/04 02/21/04 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS CMOfrlP MAX ANGLE CORRECTION MJAlKK ADÆRFS MDCfrLP PFS STIM TUBES SHOT DATE H4 .. '. I ~ REV BY COMME:NTS .. Uppermost squeezed after setting 10930' H7" X 2-7/8" BROWN I-B PKR I 10952' 1---12-7/8" TUBING TAIL W/WI.£G I 10949' HELMOTTLOGGED07/27/86 I 10965'-10975' STIM TUBE SHOT 02/21/04 11006-11016' STIM TUBE SHOT 02/21/04 11090' 11110' HPFS STIMTUBESHOT02/21/04 X 2-7/8" BROWN I-B PKR I 112-7/8"CAM D NIP,W/PLUG AND SAND COVERING PLUG I 1"122' . ....JELMDTTLOGGED01ii5/86 I 11122' 1:z..7!ß" CAMCO TUß:NC ¡All.. LISBURNE UNIT WELL: L2-21 ÆRMIT No: 1852750 API No: 50-029-21485-00 SEC 18, T11 N, R15E, 4503.47' FEL & 3908.28' FNL BP Exploration (Alaska) · BP-GDB. Baker Hughes INTEQ Planning Report INTEQ Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: Alaska, Zone 4 Well Centre bggm2003 18.046 N 2.759 W True 1.44 deg Well: L2-21 Slot Name: 21 L2-21 Well Position: +N/-S 6126.20 ft Northing: 5963620.00 ft Latitude: 70 18 18.289 N +E/-W 3582.18 ft Easting : 692748.94 ft Longitude: 148 26 18.302 W Position Uncertainty: 0.00 ft Wellpath: L2-21A 500292148501 Current Datum: 18: 2111/11/1985 00:00 Magnetic Data: 6/8/2004 Field Strength: 57604 nT Vertical Section: Depth From (TVD) ft 39.50 Height 52.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Targets L2-21 10707.85 ft Mean Sea Level 25.35 deg 80.88 deg Direction deg 190.00 L2-21 A Polygon -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 0.00 0.00 0.00 0.00 0.00 -591.47 -591.47 -1861.91 -1872.41 -673.71 -5505.75 -5505.75 -5468.77 -4670.10 -5010.61 5962887.49 687260.49 5962887.49 687260.49 5961618.49 687330.05 5961628.49 688128.68 5962817.99 687757.55 Annotation 70 18 12.452 N 70 18 12.452 N 70 17 59.957 N 70 17 59.859 N 70 18 11.646 N 148 28 58.838 W 148 28 58.838 W 148 28 57.733 W 148 28 34.449 W 148 2844.399 W 10707.85 8811.20 TIP 10755.00 8844.03 KOP 10775.00 8857.74 3 10925.00 8918.91 4 11035.00 8930.46 5 11090.00 8933.81 6 11510.00 8940.21 7 11767.00 8943.73 8 11907.00 8940.55 9 12167.00 8925.02 TD Plan: Plan #1 Coiled Tubing Sidetrack Principal: Yes Date Composed: Version: Tied-to: 6/8/2004 4 From: Definitive Path · BP-GDB. Baker Hughes INTEQ Planning Report Plan Section Information 10707.85 46.10 281.31 8811.20 -497.25 -4955.61 0.00 0.00 0.00 0.00 10730.64 45.87 281.36 8827.03 -494.03 -4971.68 1.02 -1.01 0.22 171.13 10755.00 45.61 282.80 8844.03 -490.38 -4988.74 4.37 -1.07 5.91 104.65 10775.00 47.83 282.77 8857.74 -487.16 -5002.93 11.10 11.10 -0.14 359.48 10925.00 84.50 247.78 8918.91 -504.10 -5134.03 32.02 24.45 -23.33 309.85 11035.00 83.83 212.37 8930.46 -573.17 -5216.60 32.02 -0.61 -32.19 267.09 11090.00 89.18 206.85 8933.81 -620.87 -5243.70 13.96 9.73 -10.04 313.96 11510.00 89.23 148.05 8940.21 -1022.23 -5225.85 14.00 0.01 -14.00 269.60 11767.00 89.25 184.03 8943.73 -1267.54 -5164.88 14.00 0.01 14.00 90.22 11907.00 93.33 164.94 8940.55 -1406.19 -5151.52 13.94 2.91 -13.64 282.17 12167.00 93.29 201.40 8925.02 -1660.98 -5165.64 14.00 -0.02 14.02 88.97 Survey 10707.85 46.10 281.31 8811.20 -497.25 -4955.61 5962995.80 687808.01 1350.23 0.00 0.00 TIP 10725.00 45.93 281.35 8823.11 -494.83 -4967.71 5962997.91 687795.85 1349.94 1.02 171.13 MWD 10730.64 45.87 281.36 8827.03 -494.03 -4971.68 5962998.61 687791.86 1349.84 1.02 171.11 MWD 10750.00 45.66 282.50 8840.54 -491.16 -4985.25 5963001.12 687778.22 1349.38 4.37 104.65 MWD 10755.00 45.61 282.80 8844.03 -490.38 -4988.74 5963001.82 687774.71 1349.21 4.37 103.85 KOP 10775.00 47.83 282.77 8857.74 -487.16 -5002.93 5963004.67 687760.44 1348.50 11.10 359.48 3 10800.00 53.23 275.10 8873.64 -484.21 -5021.97 5963007.13 687741.33 1348.91 32.02 309.85 MWD 10825.00 59.05 268.48 8887.58 -483.60 -5042.70 5963007.20 687720.60 1351.91 32.02 314.74 MWD 10850.00 65.17 262.64 8899.28 -485.35 -5064.70 5963004.90 687698.65 1357.45 32.02 318.43 MWD 10875.00 71.50 257.35 8908.51 -489.40 -5087.55 5963000.26 687675.91 1365.41 32.02 321.17 MWD 10900.00 77.96 252.45 8915.09 -495.69 -5110.81 5962993.37 687652.82 1375.65 32.02 323.13 MWD 10925.00 84.50 247.78 8918.91 -504.10 -5134.03 5962984.37 687629.83 1387.95 32.02 324.42 4 10950.00 84.15 239.75 8921.38 -515.09 -5156.32 5962972.82 687607.83 1402.65 32.02 267.09 MWD 10975.00 83.91 231.70 8923.99 -529.08 -5176.85 5962958.30 687587.67 1419.99 32.02 267.88 MWD 11000.00 83.79 223.65 8926.67 -545.80 -5195.21 5962941.12 687569.74 1439.65 32.02 268.72 MWD 11025.00 83.79 215.59 8929.38 -564.93 -5211.05 5962921.59 687554.40 1461.23 32.02 269.58 MWD 11035.00 83.83 212.37 8930.46 -573.17 -5216.60 5962913.21 687549.06 1470.32 32.02 270.46 5 11050.00 85.29 210.86 8931.88 -585.89 -5224.43 5962900.30 687541.56 1484.20 13.96 313.96 MWD 11075.00 87.72 208.35 8933.40 -607.58 -5236.76 5962878.30 687529.80 1507.70 13.96 314.10 MWD 11090.00 89.18 206.85 8933.81 -620.87 -5243.70 5962864.84 687523.19 1521.99 13.96 314.25 6 11100.00 89.17 205.45 8933.95 -629.84 -5248.11 5962855.75 687519.02 1531.60 14.00 269.60 MWD 11125.00 89.15 201.95 8934.32 -652.73 -5258.16 5962832.62 687509.56 1555.88 14.00 269.62 MWD 11150.00 89.13 198.45 8934.70 -676.18 -5266.79 5962808.95 687501.54 1580.48 14.00 269.67 MWD 11175.00 89.11 194.95 8935.08 -700.12 -5273.97 5962784.84 687494.97 1605.30 14.00 269.72 MWD 11200.00 89.10 191.45 8935.47 -724.45 -5279.68 5962760.37 687489.89 1630.25 14.00 269.77 MWD 11225.00 89.09 187.95 8935.86 -749.09 -5283.89 5962735.63 687486.31 1655.25 14.00 269.83 MWD 11250.00 89.09 184.45 8936.26 -773.94 -5286.59 5962710.73 687484.25 1680.18 14.00 269.88 MWD 11275.00 89.09 180.95 8936.66 -798.90 -5287.77 5962685.74 687483.71 1704.98 14.00 269.94 MWD 11300.00 89.09 177.45 8937.06 -823.89 -5287.42 5962660.77 687484.70 1729.53 14.00 270.00 MWD 11325.00 89.09 173.95 8937.45 -848.81 -5285.55 5962635.90 687487.21 1753.74 14.00 270.05 MWD 11350.00 89.10 170.45 8937.85 -873.58 -5282.16 5962611.24 687491.23 1777.54 14.00 270.11 MWD 11375.00 89.11 166.95 8938.24 -898.08 -5277.26 5962586.86 687496.76 1800.83 14.00 270.16 MWD 11400.00 89.13 163.45 8938.62 -922.25 -5270.88 5962562.87 687503.76 1823.52 14.00 270.22 MWD 11425.00 89.15 159.95 8939.00 -945.98 -5263.03 5962539.35 687512.21 1845.52 14.00 270.27 MWD 11450.00 89.17 156.45 8939.37 -969.18 -5253.75 5962516.40 687522.08 1866.77 14.00 270.32 MWD 11475.00 89.19 152.95 8939.73 -991.78 -5243.07 5962494.08 687533.34 1887.16 14.00 270.37 MWD 11500.00 89.22 149.45 8940.07 -1013.68 -5231.03 5962472.50 687545.94 1906.64 14.00 270.42 MWD 11510.00 89.23 148.05 8940.21 -1022.23 -5225.85 5962464.08 687551.34 1914.16 14.00 270.47 7 11525.00 89.22 150.15 8940.41 -1035.10 -5218.15 5962451.42 687559.37 1925.50 14.00 90.22 MWD 11550.00 89.21 153.65 8940.75 -1057.15 -5206.37 5962429.68 687571.70 1945.17 14.00 90.19 MWD · BP-GDB. Baker Hughes INTEQ Planning Report Survey 11575.00 89.21 157.15 8941.10 -1079.88 -5195.97 5962407.23 687582.68 1965.74 14.00 90.14 MWD 11600.00 89.20 160.65 8941.45 -1103.19 -5186.97 5962384.15 687592.28 1987.14 14.00 90.09 MWD 11625.00 89.20 164.15 8941.79 -1127.02 -5179.42 5962360.53 687600.44 2009.29 14.00 90.04 MWD 11650.00 89.20 167.65 8942.14 -1151.26 -5173.33 5962336.45 687607.15 2032.11 14.00 89.99 MWD 11675.00 89.21 171.15 8942.49 -1175.83 -5168.73 5962312.01 687612.37 2055.50 14.00 89.95 MWD 11700.00 89.21 174.65 8942.83 -1200.63 -5165.65 5962287.30 687616.10 2079.39 14.00 89.90 MWD 11725.00 89.23 178.15 8943.17 -1225.57 -5164.08 5962262.41 687618.30 2103.69 14.00 89.85 MWD 11750.00 89.24 181.65 8943.51 -1250.57 -5164.04 5962237.42 687618.99 2128.29 14.00 89.80 MWD 11767.00 89.25 184.03 8943.73 -1267.54 -5164.88 5962220.43 687618.58 2145.16 14.00 89.75 8 11775.00 89.49 182.94 8943.82 -1275.53 -5165.37 5962212.44 687618.30 2153.11 13.94 282.17 MWD 11800.00 90.22 179.54 8943.89 -1300.52 -5165.91 5962187.44 687618.40 2177.81 13.94 282.18 MWD 11825.00 90.96 176.13 8943.63 -1325.50 -5164.96 5962162.50 687619.98 2202.24 13.94 282.19 MWD 11850.00 91.69 172.72 8943.05 -1350.37 -5162.53 5962137.70 687623.05 2226.32 13.94 282.16 MWD 11875.00 92.41 169.31 8942.16 -1375.04 -5158.64 5962113.14 687627.58 2249.94 13.94 282.08 MWD 11900.00 93.13 165.90 8940.95 -1399.43 -5153.28 5962088.90 687633.56 2273.02 13.94 281.96 MWD 11907.00 93.33 164.94 8940.55 -1406.19 -5151.52 5962082.18 687635.49 2279.38 13.94 281.79 9 11925.00 93.37 167.4 7 8939.50 -1423.64 -5147.23 5962064.85 687640.22 2295.82 14.00 88.97 MWD 11950.00 93.42 170.97 8938.02 -1448.15 -5142.57 5962040.47 687645.52 2319.15 14.00 89.12 MWD 11975.00 93.45 174.48 8936.52 -1472.90 -5139.41 5962015.81 687649.31 2342.97 14.00 89.33 MWD 12000.00 93.48 177.98 8935.01 -1497.80 -5137.77 5961990.96 687651.59 2367.21 14.00 89.54 MWD 12025.00 93.48 181.49 8933.49 -1522.75 -5137.65 5961966.03 687652.34 2391.76 14.00 89.75 MWD 12050.00 93.48 185.00 8931.97 -1547.66 -5139.06 5961941.09 687651.57 2416.53 14.00 89.96 MWD 12075.00 93.46 188.50 8930.46 -1572.43 -5142.00 5961916.25 687649.28 2441.44 14.00 90.17 MWD 12100.00 93.43 192.01 8928.95 -1596.99 -5146.44 5961891.59 687645.47 2466.39 14.00 90.39 MWD 12125.00 93.39 195.51 8927.46 -1621.22 -5152.37 5961867.21 687640.15 2491.29 14.00 90.60 MWD 12150.00 ~3.33 199.02 8926.00 -1645.05 -5159.78 5961843.20 687633.36 2516.04 14.00 90.81 MWD 12167.00 93.29 201.40 8925.02 -1660.98 -5165.64 5961827.13 687627.91 2532.75 14.00 91.01 TO BP Amoco P....nt Wellp.th: Tie on MD: WlLLPATH DITAILS L2·21A 500292148501 L2·21 10707.85 Rig: fl..... D.tum: V.aec:tlon Angle 190.00' Nordic 2 1.: 2111/11/198' 00:00 S2.00ft ~~,= ~~= ::::~D 0.00 0.00 39.50 REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Welf Centre: L2-21, True North Vertical (TVO Reference: System: Mean Sea Level Section (VS Reference: Slot - 21 (D.DON,a.ODE) Measured Depth Reference: 18: 2111/11/1985 00:00 52.00 Calculation Method: Minimum Curvature aECTION OETAIIA 1 10707.115 48.10 281.31 2 10730.'4 4S.87 281.38 3 45.81 282..0 .. 47.83 28Z.77 , ....50247.78 ø 83.83 212.37 7 8~1.18 206.85 II 11510 88.2314a.05 111787 110.2518.&.03 ~~ g~~~:~~ :~:~: ~:t:: Obø .... 1.02171.13 4.31104.85 11.10389.48 32.02309.85 32.02 287.08 13.1H1 313.lIe 14.00 281t.80 14.00 90.22 13.0" 282.17 14.00 88..7 1350.23 134..84 134..21 13411.50 1387..$ 1470.32 1521." 1.14.1e 2145.1e 227..38 2532.75 Target 8811.20 iiH~i~ 8930.411 8.33.81 ::::~: 8840.55 8.25.02 -4S17.25 ~:iJ: -504.10 .573.17 -620.87 :;:~::1 .14Oe.1. -1eeO..8 "'.55.81 -4.71.88 ....88.74 ·5002..3 ·5134.03 -521e.80 .8243.70 '5225.85 ·5184.88 -5151.52 -51e5.e4 ANNOTATIONS TVD MD AnnotaUan 8811.2010707.85 TIP 8844.03 10755.00 KOP 8857.7410775.00 3 89'8." 4 8930.48 5 8'33." 1 00 6 8940.21 1 .[to 7 8943.73 1 .00 a 8940.55 1 .00 9 8925.02 12167.00 TD iARGETOETAlLS TVD Snap" L2.21APo~gon 0.00 -591A7 ~505,75 Polygon LEGEND L2-21 (L2·21) L2-21A Plan #1 T ^M Azimuths to True North Magnetic North: 25_350 Magnetic Field Strength: 57604nT Dip Angle: 80.880 Date: 6/8/2004 Model: bggm2003 Baker HLiL~t1es Plan: Plan #1 (L2-21/L2-21A) Created By: Digital Business Client UserDate: 61812004 Contact Inforrnatío;1; é /:'';'''' INTEQ ,,.~Ìf ... C ~ Q ... .... +,-1000 -- J: 1::: o Z -1200 - - . :c -1300 .. . ~ 0-1400 U) -1500 -1600 -1700 -1800 '.j -1900 -6500 -6400 -6300 -6200 -61 00 -6000 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -51 00 -5000 -4900 -4800 -4700 -4600 -4500 -4400 -4300 -4200 -41 00 -4000 -3900 West(-)/East(+) [10Oft/in] 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 Vertical Section at 190.00· [50ft/in] 6/8/200"1 3:30 PM . . . BP-GDB Anticollision Report . r GLOBAL SCAN APPLIED: All welIpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.00 ft Depth Range: 10707.85 to 12167.00 ft Maximum Radius: 1412.75 ft Reference: Error Model: Scan Method: Error Surface: --------, Plan: Plan #1 & NOT PLANNED PROGRA VI ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 3687.00 10629.00 10755.00 L12167.00 3622.84 8808.48 8896.03 8977.02 13.375 9.625 7.000 3.188 17.500 12.250 8.500 4.125 13 3/8" 9 5/8" 7" 3 3/16 Liner Plan: Plan #1 Coiled Tubing Sidetrack Principal: Yes Date Composed: Version: Tied-to: 6/8/2004 4 From: Definitive Path Summary Lis DS 02 L2-21 L2-21 V1 FAIL: Major Risk PB DS 18 18-08 18-08 V1 Out of range PB DS 18 18-08 18-0BA V1 Out of range PB DS 18 18-08 18-08APB1 V1 Out of range PB DS 18 18-27 18-27 V1 11487.08 10900.00 326.78 192.46 134.32 Pass: Major Risk PB DS 18 18-27 18-27A V1 11441.85 10900.00 316.43 147.36 169.07 Pass: Major Risk PB DS 18 18-27 18-27B V1 11441.85 10900.00 316.43 147.36 169.07 Pass: Major Risk PB DS 18 18-27 18-27C V7 11441.85 10900.00 316.43 147.36 169.07 Pass: Major Risk -~~- Site: Lis DS 02 Well: L2-21 Rule Assigned: Major Risk Wellpath: L2-21 V1 Inter-Site Error: 0.00 ft ! 10799.80 8925.52 10800.00 8927.44 37.40 37.84 92.00 176.84 2.40 177.78 -175.38 FAILS 10883.87 8963.16 10900.00 8996.26 37.49 38.47 45.47 149.89 39.86 198.31 -158.46 FAIL 10938.39 8972.21 11000.00 9063.85 36.02 37.42 31.62 148.14 108.43 183.77 -75.34 FAIL. 10979.07 8976.42 11100.00 9130.46 33.27 34.93 15.46 145.07 188.96 177.57 11.39 Pass 11006.06 8979.33 11200.00 9195.69 31.00 32.93 3.83 142.14 275.68 170.71 104.97 Pass 11024.20 8981 .29 11300.00 9260.59 29.44 31.54 355.87 140.01 366.67 164.10 202.57 Pass 11037.32 8982.70 11400.00 9327.08 28.49 30.74 350.86 138.72 460.71 158.41 302.30 Pass 11049.64 8983.85 11500.00 9394.72 28.30 30.83 348.71 137.81 556.42 154.49 401.94 Pass 11059.72 8984.60 11600.00 9462.36 28.16 31.06 347.04 137.16 652.98 151.13 501.84 Pass 11061.09 8984.69 11615.10 9472.58 28.14 31.10 346.82 137.08 667.61 150.67 516.94 Pass Site: PB DS 18 Well: 18-27 Rule Assigned: Major Risk Wellpath: 18-27 V1 Inter-Site Error: 0.00 ft 12075.00 8982.46 9200.00 8337.34 27.98 11.23 125.82 297.31 1409.42 112.87 1296.54 Pass 12075.00 8982.46 9300.00 8392.80 27.98 11.62 125.31 296.81 1314.27 114.56 1199.71 Pass 12065.79 8983.01 9400.00 8442.73 27.82 12.56 123.67 296.46 1218.68 117.39 1101.30 Pass 12057.30 8983.53 9500.00 8489.27 27.68 13.58 122.27 296.25 1123.43 120.17 1003.26 Pass 12050.00 8983.97 9600.00 8533.04 27.55 14.62 121.18 296.18 1028.88 122.80 906.08 Pass 12036.43 8984.80 9700.00 8573.11 27.35 16.31 119.37 296.28 935.38 126.82 808.57 Pass 12025.00 8985.49 9800.00 8609.19 27.19 17.96 118.19 296.70 843.33 130.25 713.08 Pass 12008.51 8986.49 9900.00 8641.08 27.00 20.24 116.68 297.50 753.00 134.83 618.17 Pass 11991.04 8987.55 10000.00 8668.73 26.82 22.77 115.59 298.86 665.18 139.27 525.92 Pass . BP-GDB Anticollision Report . INTEQ Site: PB DS 18 Well: 18-27 Wellpath: 18-27 V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 11970.54 8988.79 10100.00 8691.93 26.65 25.75 114.85 301.00 580.77 143.73 437.04 Pass 11946.32 8990.24 10200.00 8709.41 26.52 29.26 114.81 304.35 501.56 148.60 352.96 Pass 11916.72 8991.99 10300.00 8720.12 26.46 33.45 115.77 309.46 431.19 152.29 278.90 Pass 11763.73 8995.69 10400.00 8724.54 25.99 20.15 141.82 318.24 365.79 94.27 271.51 Pass 11739.91 8995.38 10500.00 8725.56 25.77 23.36 151.36 331.12 310.10 90.70 219.40 Pass 11705.72 8994.91 10600.00 8724.46 25.56 28.18 163.22 347.77 278.50 99.59 178.91 Pass 11655.30 8994.22 10700.00 8720.92 25.52 35.33 173.96 5.57 276.33 122.29 154.03 Pass 11577.17 8993.13 10800.00 8716.15 26.12 45.73 177.78 20.32 297.21 159.31 137.90 Pass 11487.08 8991.90 10900.00 8711.92 26.72 51.73 181.72 30.45 326.78 192.46 134.32 Pass 11435.33 8991.15 11000.00 8706.82 25.70 47.08 197.26 38.75 366.80 204.49 162.31 Pass 11408.76 8990.75 11059.80 8703.48 25.30 44.43 205.39 43.17 396.26 207.62 188.64 Pass Site: PB DS 18 Well: 18-27 Rule Assigned: Major Risk Wellpath: 18-27A V1 Inter-Site Error: 0.00 ft 12075.00 8982.46 9200.00 8337.34 27.98 11.25 125.82 297.31 1409.42 112.94 1296.47 Pass 12075.00 8982.46 9300.00 8392.80 27.98 11.64 125.31 296.81 1314.27 114.63 1199.64 Pass 12065.79 8983.01 9400.00 8442.73 27.82 12.58 123.67 296.46 1218.68 117.48 1101.20 Pass 12057.30 8983.53 9500.00 8489.27 27.68 13.61 122.27 296.25 1123.43 120.27 1003.15 Pass 12050.00 8983.97 9600.00 8533.04 27.55 14.65 121.18 296.18 1028.88 122.92 905.96 Pass 12036.43 8984.80 9700.00 8573.11 27.35 16.35 119.37 296.28 935.38 126.96 808.43 Pass 12025.00 8985.49 9800.00 8609.19 27.19 17.90 118.19 296.70 843.33 130.15 713.18 Pass 12007.56 8986.55 9900.00 8638.60 26.98 20.03 116.70 297.65 754.72 134.09 620.63 Pass 11984.00 8987.98 10000.00 8650.78 26.75 22.98 115.66 299.92 680.78 138.24 542.54 Pass 11956.07 8989.66 10100.00 8656.57 26.57 26.54 114.85 303.03 615.36 143.08 472.28 Pass 11924.69 8991.52 10200.00 8656.37 26.46 30.51 114.65 307.23 557.73 148.02 409.71 Pass 111747.83 8995.48 10300.00 8659.93 25.83 20.54 134.70 313.35 491.34 101.03 390.31 Pass 11724.12 8995.16 10400.00 8666.33 25.64 23.54 139.17 321.14 424.53 96.74 327.79 Pass 11691.09 8994.71 10500.00 8670.48 25.51 27.80 144.49 331.08 372.39 95.69 276.70 Pass 11645.74 8994.08 10600.00 8675.17 25.55 33.58 149.70 342.64 335.94 98.51 237.44 Pass 11584.96 8993.24 10700.00 8679.65 26.03 40.90 153.39 354.84 316.60 101.58 215.02 Pass 11507.66 8992.18 10800.00 8685.88 27.22 48.68 155.02 6.64 310.11 118.42 191.69 Pass 11441.85 8991.25 10900.00 8692.63 25.80 43.31 175.94 18.35 316.43 147.36 169.07 Pass 11392.17 8990.50 11000.00 8690.08 25.11 38.60 194.51 29.96 348.75 169.38 179.37 Pass 11360.22 8990.01 11100.00 8678.78 24.83 35.32 208.78 39.76 407.10 181.44 225.66 Pass 11343.31 8989.74 11200.00 8672.91 24.73 33.53 219.52 48.13 477.28 188.54 288.73 Pass 11336.00 8989.63 11300.00 8671.56 24.70 32.74 227.26 54.85 555.51 192.77 362.74 Pass 11325.00 8989.45 11400.00 8665.88 24.65 31.50 233.42 59.46 640.37 192.46 447.90 Pass 11317.23 8989.33 11500.00 8665.99 24.64 30.70 238.43 63.39 725.70 191.89 533.81 Pass 11309.69 8989.21 11600.00 8668.51 24.64 29.87 242.74 66.64 813.24 190.33 622.91 Pass 11300.00 8989.06 11700.00 8669.37 24.63 28.69 246.61 69.15 903.67 187.21 716.46 Pass 11300.00 8989.06 11800.00 8676.38 24.63 28.86 249.02 71.57 994.32 187.47 806.85 Pass 11300.00 8989.06 11900.00 8678.93 24.63 29.04 250.81 73.36 1087.98 187.65 900.33 Pass 11291.23 8988.92 12000.00 8678.43 24.65 27.85 253.38 74.70 1183.21 184.08 999.13 Pass 11286.85 8988.85 12100.00 8681.40 24.66 27.37 255.29 76.00 1277.65 182.36 1095.29 Pass 11275.00 8988.66 12200.00 8684.81 24.68 25.70 258.06 77.11 1372.14 177.26 1194.88 Pass . BP-GDB . Anticollision Report INTEQ Site: PB DS 18 Well: 18-27 Wellpath: 18-27B V1 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 12075.00 8982.46 9200.00 8337.34 27.98 11.25 125.82 297.31 1409.42 112.94 1296.47 Pass 12075.00 8982.46 9300.00 8392.80 27.98 11.64 125.31 296.81 1314.27 114.63 1199.64 Pass 12065.79 8983.01 9400.00 8442.73 27.82 12.58 123.67 296.46 1218.68 117.48 1101.20 Pass 12057.30 8983.53 9500.00 8489.27 27.68 13.61 122.27 296.25 1123.43 120.27 1003.15 Pass 12050.00 8983.97 9600.00 8533.04 27.55 14.65 121.18 296.18 1028.88 122.92 905.96 Pass 12036.43 8984.80 9700.00 8573.11 27.35 16.35 119.37 296.28 935.38 126.96 808.43 Pass 12025.00 8985.49 9800.00 8609.19 27.19 17.90 118.19 296.70 843.33 130.15 713.18 Pass 12007.56 8986.55 9900.00 8638.60 26.98 20.03 116.70 297.65 754.72 134.09 620.63 Pass 11984.00 8987.98 10000.00 8650.78 26.75 22.98 115.66 299.92 680.78 138.24 542.54 Pass 11956.07 8989.66 10100.00 8656.57 26.57 26.54 114.85 303.03 615.36 143.08 472.28 Pass 11924.69 8991.52 10200.00 8656.37 26.46 30.51 114.65 307.23 557.73 148.02 409.71 Pass 11747.83 8995.48 10300.00 8659.93 25.83 20.54 134.70 313.35 491.34 101.03 390.31 Pass 11724.12 8995.16 10400.00 8666.33 25.64 23.54 139.17 321.14 424.53 96.74 327.79 Pass ,11691.09 8994.71 10500.00 8670.48 25.51 27.80 144.49 331.08 372.39 95.69 276.70 Pass 11645.74 8994.08 10600.00 8675.17 25.55 33.58 149.70 342.64 335.94 98.51 237.44 Pass 11584.96 8993.24 10700.00 8679.65 26.03 40.90 153.39 354.84 316.60 101.58 215.02 Pass 11507.66 8992.18 10800.00 8685.88 27.22 48.68 155.02 6.64 310.11 118.42 191.69 Pass 11441.85 8991.25 10900.00 8692.63 25.80 43.31 175.94 18.35 316.43 147.36 169.07 Pass 11392.17 8990.50 11000.00 8690.08 25.11 38.60 194.51 29.96 348.75 169.38 179.37 Pass 11360.22 8990.01 11100.00 8678.78 24.83 35.32 208.78 39.76 407.10 181.44 225.66 Pass 11343.31 8989.74 11200.00 8672.91 24.73 33.53 219.52 48.13 477.28 188.54 288.73 Pass 11336.00 8989.63 11300.00 8671.56 24.70 32.74 227.26 54.85 555.51 192.77 362.74 Pass 11325.00 8989.45 11400.00 8665.88 24.65 31.50 233.42 59.46 640.37 192.46 447.90 Pass 11317.23 8989.33 11500.00 8665.99 24.64 30.70 238.43 63.39 725.70 191.89 533.81 Pass 11309.69 8989.21 11600.00 8668.51 24.64 29.87 242.74 66.64 813.24 190.33 622.91 Pass 11300.00 8989.06 11700.00 8669.37 24.63 28.69 246.61 69.15 903.67 187.21 716.46 Pass 11300.00 8989.06 11800.00 8676.38 24.63 28.86 249.02 71.57 994.32 187.47 806.85 Pass 11300.00 8989.06 11900.00 8678.93 24.63 29.04 250.81 73.36 1087.98 187.65 900.33 Pass 11291.23 8988.92 12000.00 8678.43 24.65 27.85 253.38 74.70 1183.21 184.08 999.13 Pass 11286.85 8988.85 12100.00 8681.40 24.66 27.37 255.29 76.00 1277.65 182.36 1095.29 Pass 111275.00 8988.66 12200.00 8684.81 24.68 25.70 258.06 77.11 1372.14 177.26 1194.88 Pass Site: PB DS 18 Well: 18-27 Rule Assigned: Major Risk Wellpath: 18-27C V7 Inter-Site Error: 0.00 ft 12075.00 8982.46 9200.00 8337.34 27.98 11.25 125.82 297.31 1409.42 112.94 1296.47 Pass 12075.00 8982.46 9300.00 8392.80 27.98 11.64 125.31 296.81 1314.27 114.63 1199.64 Pass 12065.79 8983.01 9400.00 8442.73 27.82 12.58 123.67 296.46 1218.68 117.48 1101.20 Pass 12057.30 8983.53 9500.00 8489.27 27.68 13.61 122.27 296.25 1123.43 120.28 1003.15 Pass 12050.00 8983.97 9600.00 8533.04 27.55 14.65 121.18 296.18 1028.88 122.92 905.96 Pass 12036.43 8984.80 9700.00 8573.11 27.35 16.35 119.37 296.28 935.38 126.96 808.42 Pass 12025.00 8985.49 9800.00 8609.19 27.19 17.91 118.19 296.70 843.33 130.15 713.18 Pass 12007.56 8986.55 9900.00 8638.60 26.98 20.03 116.70 297.65 754.72 134.09 620.63 Pass 11984.00 8987.98 10000.00 8650.78 26.75 22.98 115.66 299.92 680.78 138.24 542.54 Pass 11956.07 8989.66 10100.00 8656.57 26.57 26.54 114.85 303.03 615.36 143.08 472.27 Pass 11924.69 8991.52 10200.00 8656.37 26.46 30.51 114.65 307.23 557.73 148.02 409.71 Pass 11747.83 8995.48 10300.00 8659.93 25.83 20.54 134.70 313.35 491.34 101.03 390.31 Pass 111724.12 8995.16 10400.00 8666.33 25.64 23.54 139.17 321.14 424.53 96.74 327.79 Pass 11691.09 8994.71 10500.00 8670.48 25.51 27.80 144.49 331.08 372.39 95.70 276.69 Pass . BP-GDB . Anticollision Report Site: PB DS 18 Well: 18-27 Wellpath: 18-27C V7 Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 11645.74 8994.08 10600.00 8675.17 25.55 33.59 149.70 342.64 335.94 98.51 237.44 Pass 11584.96 8993.24 10700.00 8679.65 26.03 40.91 153.39 354.84 316.60 101.58 215.02 Pass 11507.66 8992.18 10800.00 8685.88 27.22 48.69 155.02 6.64 310.11 118.42 191.69 Pass 11441.85 8991.25 10900.00 8692.63 25.80 43.31 175.94 18.35 316.43 147.36 169.07 Pass 111392.17 8990.50 11000.00 8690.08 25.11 38.60 194.51 29.96 348.75 169.39 179.37 Pass 11360.22 8990.01 11100.00 8678.78 24.83 35.32 208.78 39.76 407.10 181.44 225.66 Pass 11343.31 8989.74 11200.00 8672.91 24.73 33.53 219.52 48.13 477.28 188.55 288.73 Pass 11336.00 8989.63 11300.00 8671.56 24.70 32.74 227.26 54.85 555.51 192.78 362.73 Pass 11325.00 8989.45 11400.00 8665.88 24.65 31.50 233.42 59.46 640.37 192.47 447.90 Pass 11317.23 8989.33 11500.00 8665.99 24.64 30.70 238.43 63.39 725.70 191.89 533.81 Pass 11309.69 8989.21 11600.00 8668.51 24.64 29.87 242.74 66.64 813.24 190.34 622.90 Pass 11300.00 8989.06 11700.00 8669.37 24.63 28.69 246.61 69.15 903.67 187.22 716.45 Pass 11300.00 8989.06 11800.00 8676.38 24.63 28.86 249.02 71.57 994.32 187.47 806.85 Pass 11300.00 8989.06 11900.00 8678.93 24.63 29.04 250.81 73.36 1087.98 187.66 900.32 Pass 11291.23 8988.92 12000.00 8678.43 24.65 27.85 253.38 74.70 1183.21 184.08 999.13 Pass 111286.85 8988.85 12100.00 8681.40 24.66 27.37 255.29 76.00 1277.65 182.36 1095.29 Pass 11275.00 8988.66 12200.00 8684.81 24.68 25.70 258.06 77.11 1372.14 177.26 1194.88 Pass _._~ . ( "-- Blind ram ~ Choke line I HCR valve ~J8X[@ I Pipe ram ~ Empty Cavity ~ or VBRs ~ I 2c{J@ I DTK 12/08/03 . Nordic 2 11" & 13-5/8" Workover BOP Stack «5000 psi) " 11" or 13-5/8" Annular Preventer ~ 11" or 13-5/8" BOP o ~ / \ Kill line HCR valve ~=0- =0J I 11" or 13-5/8" BOP o o 11" or 13-5/8" tubing head þ= ~ // ~@ · All Measurements are from top of Riser ~ CD (j) .- cr: top of bag j'"".."""",.. ~ ",'.' ~-.>, bttm of bag It. ~: ~,HIM!I~ 111('-. .~:' Blind/Shears middle of slips middle of pipes 2 3/8" combi ram/slips .---. middle of flow cross Mud Cross ----... I I I variable bore pipe 3 1/2"-2 7/8" I 23/8" combi ram/slips middle of blind/shears middle of pipe/slips Flow Tee 6/8/2004 BAG .......... .................., TOTs I ........... .......... ................... ............. Mud Cross '----' t·· ......................., TOTs l ......... ........ ....................... TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 114 Anchorage, AK 99501 MEMO ~2~?-\A DATE do-cf( - Q(-{ 6~6lROJ~E ~~0-(lQ~Q!~Cc., $ J(){)\ 00 ~~o~~ crA2- aJlÍoo DOLLARS- ~QN0,èR,~- "Mastercard Check" . -: ~ 25 2000bOI:1111 ~a..lllb 2 2 711. ~ SSb"· 0 ~ ~a.. . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~Aq/ 2-2-1,,4 PTD# 7_ð~- /n"l >< Development Service CHECK WßA T APPLffiS ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE" Tbe permit is for a new weUbore segment of existing weD Permit No, API No. Productionsbould continue to be reponed as a function' of tbe original API number stated above. HOLE In accordance witb 20 AAC 25.005(1), aJI records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for wen (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compJiance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ;¡ conservation order approving a spacing eneption. (Company Name) assumes tbe liability of any protest to tbe spacinge:JceptioD tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater ·than 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iIitervals tbrough target zones. o o Well bore seg Annular Disposal On Program DEV On/Off Shore 11650 Well Name: PRUDHOE BAY UN LIS L2-21A DEV /1-0IL GeoArea 890 Unit . Initial ClasslType Yes .Yes Y.es Yes Y~s Y~s Y~s Yes Yes Y.es Yes .Y~s Yes .NA NA NA NA PRUDHOE BAY, LISBURNE OIL - 640144 - INC P~rmit fee attacheJ:! leas~numberappropriate .U.nlque welt n.am~ .a[1d ol!mb.er Well Jocat~d in.a d.efioeJ:! J)ool. ,^,~llJocat~d prpper .distance from driJling uoitbouod.ary. Jocat~d proper .distance. from other wells cient acrea~e.ayailable in.drilliog unjt '(iated, js weJlbore platiocJuded Field & Pool _VY~1 Well 2 3 4 5 6 7 8 9 Administration in.cQmm.e[1ts) (For Qperator onl)' affected party .0J)erator has. appropriate. bond lnJorce Permit c;a[1 be lssl!ed without ccnserva!ion order Pe(rY)it c;a[1 be lssl!ed without ad.mioistratilleapprovaJ Can permit be approved before 15-day wait I Jccated wlthio area and.strç¡ta .authorized by.l[1jectioo Order # (put 10# lells.withi!1 Jl4J'Dile.area.of reyi!:1W id~otifj!:1d (For servjc.e we[l onl)'>- . . produJ:ed i[1jector; Duration. of pre-produGtioo tess than 3 mootl:Js (FoLservlce wel Consi$te[1çy.has been Jssued. forJhis project Wel 10 11 12 13 14 15 16 Date 6/10/2004 Appr RPC only) - Slotted, CTOU * NA .NA .NA NA No. Yes Yes Yes Yes NA 17 .AGMP F.indjny .of .CQndu.ctor string.provided .S.urfac~ .casing. pJotec;ts all.known USOWs .CMT v.ol adequate. to circ.utate.oJlCQod.uctor & surtc$g .CMT v.ol adequate. to tie-in Jony .string to.surf csg .CMTwill çoyer.aJll<oownpro.duGtiye horizons. . . .C.asi[1g designs ad.ec¡ua.te fpr C,.T" B.&permafr.ost . Adequatelankageor re.serve pit. JtaJe-drilt hasß 10:403 for abandonment bee[1 aPproved AJ:!equate we[lbore separatjo.n proposeçJ . Sidetrack. Max MW8, I ppy, Test to.35QO psi. MSFl23.05 psi.. Yes Yes Yes Yes Yes No NA Jtdjv~rter Jeq.uiJed, does jt me~t reguJatioos. .Drilling flujdprogram schematic.& ect-uipJistadequate .BOPEs,.doJhey meet reguJatioo .BOPE.press rati[1g aPpropriate; Jest to.(pu! PSig in comments) .Choke.manjfold compJies w/APtRFI-53 (May 84) WQrk will oçcur withoutoperation .shutdown Js presence. of H2S gas probable. Mecba.n[caLcoodjlion p{ wells within ,ð.OR yerified (For s.ervjce w~1J onJ)') 118 19 20 21 22 23 24 25 26 27 Date 28 6/10/2004 29 30 31 32 33 34 Engineering Appr WGA - - NQta[1 H2S pad. No. .NA NA. NA NA P~rmit c;a[1 be lssl!ed wlo hydrogen sulfide meaSJjres .D.ata.PJeseoted on. Rote.ntial oveJRres.sure .ZOnes. .S~lsm[c.a!1alysjs. of shaJlow gas.zooes . .S~abeçJconditioo sl!rvey(if oft-shore) . . . CQnta.ct name/phon.eJorweels.ly progress.reRorts [exploratory .o[1ly] 35 36 37 38 39 Date 6/10/2004 Geology Appr RPC ~~y Date Engineering Commissioner 4-- o Date: ) b Geologic Commissioner oí{"S e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding 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. . . **** REEL HEADER **** MWD 06/03/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/07/17 709876 01 3.125" CTK ;q n~~) *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10718.0000: STOP.FT 12139.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. L2-21A Lisburne 70 deg 18' 18.289"N 148 deb 26' 18.302 W North Slope Alaska Baker Hughes INTEQ 3.125" NaviGamma - Gamma Ray 17-Jul-04 500292148501 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks 22 llN 14E MSL o RKB 65 KB 65 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ?J1c.( -[ ~'1 (1) (2) (3) (4) (5 ) (6) SSTVD) (7) mg/1 (8 ) depth (9) applied . . All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is real time data. Well 15-19A was kicked off @ 8810' MD (8622' SSTVD) from the wellbore of Well 15-19. Well 15-19A was drilled to 11097' MD (8759' SSTVD). The TD was shifted to 11060' MD (8759' SSTVD) following a -37' depth adjustment after a tie-in. The interval from 11079' MD (8759' SSTVD) to 11096' MD (8759' was not logged due to sensor to bit offset. The KCI content in the mud was changed from 15000 mg/l to 34000 from 10724' MD (8730' SSTVD). The data presented here may not be final and will possibly be shifted to a PDC (Primary Depth Control) log later. A Magnetic Declination correction of 27.38 degrees has been to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 8757.92, 8757.43, DISPLACEMENT -0.493164 Tape Subfile: 1 64 records... Minimum record length: Maximum record length: 14 bytes 132 bytes MWD .001 **** FILE HEADER **** 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT L2-21A 5.xtf 150 BP Exploration (Alaska) Inc. L2-21A Lisburne North Slope Alaska *** LIS COMMENT RECORD *** !!! !! !!!!!!!! ! ! ! ! !! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by Reeves, 17-Jul-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP . . ---------------------------------------------------- GR ROP GR ROP GRAX 13 ROPA13 0.0 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 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 34 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10718.000000 12139.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 43 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN L2-21A.xtf 150 BP Exploration (Alaska) L2-21A Lisburne . COUN STAT North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS 0.0 0.0 GRAX ROPS GRAX ROPA * 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: 0.250000 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 = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 68 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 10718.000000 12138.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 77 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/07/17 709876 01 . ..~ . **** REEL TRAILER **** MWD 06/03/07 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS r . Tape Subfile 2 is type: LIS DEPTH 10718.0000 10718.5000 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 12139.0000 GR 66.7800 71.9630 30.8080 126.7811 17.4662 28.2051 25.3788 48.5914 44.8112 14.2362 25.7157 31.8547 18.7485 18.6849 22.8347 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP -999.2500 -999.2500 8.4421 21.1104 30.8551 15.1736 47.1663 42.0279 46.4696 19.5929 67.2196 43.2833 62.1747 15.8452 8.5165 8.1438 -999.2500 ", 10718.000000 12139.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 10718.0000 -999.2500 -999.2500 10718.2500 -999.2500 -999.2500 10800.0000 26.7200 14.0400 10900.0000 155.5100 16.2100 11000.0000 18.6600 31.1600 11100.0000 23.1100 22.1400 11200.0000 26.4800 45.7500 11300.0000 51.5400 43.4200 11400.0000 62.5200 51.1300 11500.0000 23.5982 29.1600 11600.0000 25.9200 67.2900 11700.0000 27.3300 44.9000 11800.0000 77.4400 78.4200 11900.0000 55.7600 17.8000 12000.0000 30.7100 4.2100 12100.0000 18.8800 9.6700 12138 _ 7500 -999.2500 -999.2500 Tape File Start Depth 10718.000000 Tape File End Depth 12138.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ~ . . Tape Subfile 4 is type: LIS
