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Home My WebLink About201-072 RECEIVED STATE OF ALASKA FEB 1 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND 1 a. Well Status: 0 Oil ❑Gas ❑SPLUG 0 Other ®Abandoned ['Suspended 1 b. Well Class • 2OAAC 25.105 20AAC 25 110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ ❑WAG ❑WDSPL ❑Other No.of Completions Zero - ® Development 0 Service 2. Operator Name: 5. Date Comp., Susp.,or band.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 1/20/2015 201-072 • 314-536 3. Address: 6. Date Spudded: 13. API Number P.O. Box 196612,Anchorage,Alaska 99519-6612 6/8/2001 50-029-23011-00-00 ' 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 6/19/2001 PBU L-01 2394' FSL, 3660' FEL, Sec. 34,T12N, R11 E, UM • 8. KB(ft above MSL): 76.7' 15. Field/Pool(s) Top of Productive Horizon: 1237' FSL, 2622' FEL, Sec. 34,T12N, R11 E, UM GL(ft above MSL): 48.7 Prudhoe Bay/Prudhoe Bay - Total Depth: 9. Plug Back Depth(MD+TVD) 1186' FSL, 2570' FEL, Sec. 34,T12N, R11E, UM 2703' • 2554' ' 4b. Location of Well(State Base Plane Coordinates, NAD. 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 583256 • y- 5978116 • Zone- ASP4 9528' . 9209' ADL 028239 • TPI: x- 584309 y- 5976971 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 584362 y- 5976921 Zone- ASP4 None 18. Directional Surve y: ❑Yes ® No 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD, RES/AIT, DT/BHC, CNL, LDL,GR,Caliper, SP,MRES, DIPOLE/SONIC, MDT, DPC,GR/FPT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 27' 107' 27' 107' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 27' 2760' 27' 2601' 12-1/4" 450 sx Arctic Set Lite, 208 sx Class'G' 7" 26#/29# L-80/13Cr95 24' 9509' • 24' 9190' 8-3/4" 186 sx LiteCrete, 145 sx Class'G' 2751' 24. Open to production or injection? 0 Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 4-1/2", 12.6#, 13Cr80 8763' 8706'/8404' 26. ACID. FRACTURE,CEMENT SQUEEZE, ETC. MAR 1 2 2I ) WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No • scoittED tligac DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached ". 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production 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 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ® No - Sidewall Core(s)Acquired? 0 Yes ® No • If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 CONTINUED ON REVERSE `y�-i--- Stitt Original Only !/TL- 3//c/i5" -- /4//,)---- RBDMS _;,` FEB 2 3 Vc, 29. GEOLOGIC MARKERS(List all formations a' 3rkers encounter 30. FORMATION TESTS NAME ...D ND Well Tested, Yes ®No —•- Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25 071 Sag River 8911' 8603' None Shublik 8952' 8643' Eileen 9088' 8776' Sadlerochit 9123' 8810' Zone 4A 9250' 8935' Zone 3 9318' 9002' Zone 2C 9392' 9075' Zone 2B 9464' 9145' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Troy Jakabosky,564-4868 Email. Troy.Jakabosky@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone 5644091 Date:2-Th/15 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8. The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 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. Form 10-407 Revised 10/2012 Submit Original Only WELL NAME: L-01 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8900' 14 Bbls Class 'G' 5863' 81 Bbls Class 'G' 3014' Cut & Pull Tubing 2751' Cut & Pull 7" Casing 2724' Set EZSV 2703' Set Whipstock L-01 , Well History (Pre-Rig Sidetrack) Date Summary 10/27/14 Fullbore/SLB Job Scope: Plug&Abandon. T/I/O 640/997/240 Pre-Job and Safety meeting. Pump l0bbl 60/60 spear. Pump 351 of 1% kcl, Pump 14 bbls of 15.8#class"G"cement. Pump 2 bbls of fresh water. Launch foam balls. Pump 78 bbls of fresh water. Pump 58.4 bbls of diesel. Seen pressure bump at 56 bbls. T/I/O 1392/825/180. Length of CMT Plug: 377'. Depth of CMT Plug:8900'. Type of CMT: Class "G". Wt of CMT Slurry: 15.8 ppg. Volume of CMT Slurry Pumped: 14 bbls. UCA: 10:18 hrs=2000psi. 10/30/14 BRUSHED BPV PROFILE W/3.805 GAUGE RING,4-1/2 BRUSH. RAN 1-3/4"SAMPLE BAILER, SD @ 8524'SLM, 200#OVER PULL(sample of cement). PERFORMED 3 FAILING 2500 psi MIT-T(see data tab). MADE ATTEMPT TO PULL STA#2, UNABLE TO LOC BUT S/D @ 8366'SLM (unable to latch, marks on tray). 10/31/14 CMIT-Tx IA PASSED to 2125/2513 Pumped 8 bbls down tubing and IA to achieve test pressure.T/IA lost 24/26 psi 1st 15 min, 15/15 psi 2nd 15 min for a total loss of 39/41 psi over 30 min test. Bled psi's, aprox 5 bbls. FWHP 119/534/174 Tags hung on wing and IA,fluid packed annulus sign hung on well. 10/31/14 PULLED STA#2 BK-DGLV FROM 8363'SLM/8390' MD. LRS PERFORMED PASSING CMIT IA x T TO 2500 psi (see Irs log). 11/06/14 Job Scope-Fullbore P&A-Sidetrack Prep/Stage#2 balanced cement plug-Cycle SSV-PJSM- Discuss barriers-T/I/O= 197/600/180. Pumped 81 bbls 15.8 ppg class G cement taking returns down L- 03 flowline. Launch foam ball and displace with 91.3 bbls. Freeze protect L-03 flowline with 10 bbls 60/40 McOH. Secure wells. 11/09/14 TAG TOP OF CEMENT AT 5,863'SLM W/2.50"S-BLR(Sample of cement&wiper ball). DRIFT TUBING TO 3,500'SLM W/3.70"CENTRALIZER(Target depth 3,200'md). BRUSH TREE FOR 30 MINUTES WI 4-1/2" BRUSH, 3.25"G-RING(No issues). LRS MADE EIGHT ATTEMPTS TO CMIT-T x IA TO 3500 PSI (Currently letting T& IA settle). 11/09/14 T/I/O=113/vac/161 Temp=Sl Assist Slickline. CMIT-TxIA to 3500 psi (INCONCLUSIVE) (SIDETRACK) Pumped 4 bbls of-5*diesel down IA using 1/2 jumper hose to equalize to TBG. 8 attempts, 1st 15 min T/IA lost 18/38 psi.2nd 15 min T/IA lost 16/33 psi for a total loss of T/IA 34/71 psi in 30 min test. Bleed TGB pressure to 1000 psi and perform MIT-IA to 3500 psi. 11/10/14 MIT-IA to 3500 psi (Inconclusive)CMIT-TxIA to 3500 psi(PASSED)MIT-OA to 2000 psi (PASSED) Bled TBG pressure to 1000 psi, bled back— 1 bbl. Pumped .25 bbls of 10*diesel down IA to reach test pressure. 1st 15 min IA lost 48 psi and TBG gained 25 psi. 2nd 15 min IA lost 29 psi and TBG gained 12 psi for a total IA loss of 77 psi. (CMIT-TxIA)9 attempts.Pumped 1.35 bbls(total of 5.35)diesel down IA using 1/2"jumper to bleed to TBG to reach test pressure.lst 15 min T/IA lost 60/28 psi.2nd 15 min T/IA lost 27/17 psi for a total loss of 87/35 psi in 30 min. Bled back—3 bbls. MIT-OA-Pumped 2 bbls diesel down OA to reach test pressure. 1st 15 min OA lost 93 psi.2nd 15 min OA lost 24 psi for a total loss of 117 psi in 30 min. BLed back—2 bbls.Tags hung on IA OA WV. **AFE**sign hung on well by pad op. SV WV SSV=closed. MV IA OA=open. FWHPS=680/795/140. 11/10/14 LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 3500 PSI. LRS PERFORMED SUCCESSFUL MIT- OA TO 2000 PSI. Page 1 of 2 L-01 , Well History (Pre-Rig Sidetrack) Date Summary 11/14/14 JET CUT TUBING. INITAL T/I/O=200/970/200, SSV CLOSED ON ARRIVAL. CUT TUBING AT 3014' ELMD DEPTH CORRECTED TO TUBING TALLY. DEPTH IS 3' BELOW FIRST COLLAR DEEPER THAN 3000'AS PER PROGRAM. TxIA COMM SEEN DURING CUT. FINAL T/I/O=50/100/150, DSO NOTFIED WELL SHUT-IN AND SECURE. 11/16/14 T/1/O=9/260/140. (Pre-RWO)(CMIT TxIA/MIT OA)CMIT Tx IA to 3500 psi. PASSED. Pumped 4 BBLs diesel.T/I lost 21/20 psi in first 15 minutes& 17/17 psi in second 15 minutes.Total loss=38/37 psi. Bleed T/IA pressures down to 306/339 psi. FWHP=306/339/102. Swab, SSV, &Wing shut. IA, OA, &master open.Tags hung. 11/17/14 T/I/O=SSV/0/80,Temp: SI, PPPOT-T(PASS), PPPOT-IC, (PASS) Pre RWO. PPPOT-T: Stung into test void, (0+psi)bled void to 0 psi. Functioned LDS, all moved freely.Torqued LDS assemblies to 350 fUlbs. Pumped through void,good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (100 psi)bled void to 0 psi. Functioned LDS,all moved freely.Torqued LDS assemblies to 350 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 150 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. 12/08/14 T/I/O= 1720/1770/210.Temp=SI.WHPs(Pre Sidetrack).ALP= 1770 psi,AL SI @ casing valve.Tbg FL @ surface. IA FL near surface. OA FL near surface. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 12:30 hrs. 12/15/14 T/I/O= 1620/1660/220. Temp=SI. Bleed WHPs to 0 psi (Verify TxIA comm Pre Sidetrack). No AL, flowline,wellhouse, hydraulics, or scaffold.T FL @ surface. IA&OA FLs near surface.Verified two direction TxIA communication then bled T& IA to 0 psi (gas& .85 bbls fluid)to slop tank in 1 hr. OAP decreased 10 psi. Started bleeding OA to slop tank. 12/16/14 Bleed WHPs to 0 psi(Verify TxIA comm Pre Sidetrack). Continued bleeding OA to 0 psi(gas&—10 gals fluid)in 1 hr.TP& IAP increased 8 psi. Monitored for 30 mins.TP& IAP unchanged and OAP increased 19 psi. Final WHPs=8/8/19. SV= Unk.WV&SSV=C. MV=O. IA&OA=OTG. 0120 hrs. 12/18/14 T/I/O=2/20/80 Installed second IA&OA(piggy back)onto existing IA&OA valves; FWP=2/20/80. 12/19/14 T/I/O=0/0/0. Pumped up tubing to 250 psi through IA. Set 4"CIW H-TWC#260. Bled Tree to 0 psi and verified LTI on TWC. Removed tree and installed dry hole tree(temp valve#10 and Temp valve#84. Torqued and Pt'd. Bled tubing to 0 psi through IA. RDMO. Final T/I/O=TWC/0/0. Page 2 of 2 • . North America-ALASKA-BP Page 1 gam' Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/11/2015 12:00 - 18:00 6.00 RIGD P PRE RIG DOWN IN PREPARATION TO MOVE RIG -DISCONNECT MUD AND CEMENT LINES -EMPTY DRAINS ON RIG FLOOR -DISCONNECT MUD INTERCONNECTS -CLEAN PITS IN PREPARATION FOR MOVE -PIN FORUM CRANE -PREP RIG FOR MODULE SEPARATION -REMOVE BLOCKS FROM TOP DRIVE -HOOK UP BRIDAL LINES PREP RIG FLOOR TO L/D DERRICK -SECURE PIPE SHED -DISCONNECT INTERCONNECTS BETWEEN ,MODULES BEGIN RON EVENT AT 12:00 ON 01/11/15 WITH PARKER 273 RIG. 18:00 - 22:00 4.00 RIGD P PRE SKID FLOOR -PJSM REMOVE ROOFTOP WALKWAYS -RIG DOWN MANRIDERS AND PREPARE RIG FLOOR PREPARE PIPE BARN -PERFORM DERRICK INSPECTION SKID RIG FLOOR INTO RIG MOVE POSITION. 22:00 - 00:00 2.00 RIGD P PRE LOWER MAST -PJSM AND LOWER DERRICK CHECKLISTS -LOWER DERRICK -FINAL SLACKOFF WEIGHT ABOVE DERRICK STAND=423 KLBS. 1/12/2015 00:00 - 02:00 2.00 RIGD P PRE PREPARE TO SEPARATE MODULES -PREP TIRES -SWITCH OVER POWER -DISCONNECT FUEL,HYDRAULIC,ELECTRIC LINES 02:00 - 04:30 2.50 RIGD P PRE PREPARE TO MOVE RIG FROM S-09ATO L-01 A -PREP MODULES FOR SEPARATION -WARM UP TIRES -SEPARATE MUD MOD FROM DRILL MOD AND STAGE DOWN PAD 04:30 - 17:30 13.00 RIGD P PRE MOVE UTILITY AND DRILL MODULES (SIMULTANEOUSLY)FROM S PAD TO L PAD. -STAGE DRILL MODULE BY S PAD EXTENTION -REMOVE WELL HOUSE FROM S-09A WITH CRANE -SEND WELLHOUSE TO L-01A -MOVE UTILITY MODULE FOLLOWED BY DRILL MODULE FROM S-PAD TO L-PAD 17:30 - 00:00 6.50 RIGD P PRE MOVE MUD MODULE FROM S PAD TO L PAD SIM-OPS ON L PAD WHILE MOVING MUD MOD -TEST RIG MOVE ESD PRIOR TO SPOTTING RIG -SPOT DRILL MODULE OVER WELL L-01A -LEVEL AND SHIM DRILL MODULE Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 231 Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date. X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1/13/2015 00:00 - 03:30 3.50 RIGD P PRE MOVE MUD MODULE FROM S PAD TO L PAD SIM-OPS ON L PAD WHILE MOVING MUD MOD -MOVE UTILITY MODULE INTO PLACE AND MATE UP TO DRILL MODULE -ELECTRICIAN AND RIG CREW WORKING ON RIGGING UP UM-DM INTERCONNECT -RAISE DRIVING CABS. 03:30 - 08:30 5.00 RIGD P PRE SPOT MUD MODULE ONTO L PAD -MOVE MUD MODULE INTO PLACE AND MATE UP RIG UP INTERCONNECTS -CONNECT STEAM,ELECTRICAL PLUG BOARD,ROOF AND FLOOR PANELS 08:30 - 09:00 0.50 RIGU P PRE SET UP ON L PAD, -SET UP SCS TRAILER -RIG CREW SETTING RIG MATS AROUND THE WELL. -REMOVE BOOSTER WHEELS -RAISE THE DERRICK,LIFT OFF HEADACHE AT 520K,MAX PULL 536K 09:00 - 12:00 3.00 RIGU P PRE RIG UP -PERFORM DERRICK INSPECTION PERFORM CROWN INSPECTION. -RAISE PIPE CAT -HOOK UP STEAM TO RIG FLOOR -TIE IN INTERCONNECTS "STATE NOTIFICATION PUT IN FOR BOP TEST AT 9:55 AM 12:00 - 16:00 4.00 RIGU P PRE BRIDLE DOWN,HANG&TIE BACK BRIDLE LINES -PSJM -INSTALL STAND BUILT MOUSE HOLES -UNPIN FORUM CRANE -DRAIN CONDENSATE FROM STEAM LINES -UNPIN IDM -HANG RIG TONGS -ATTACH BLOCKS TO TOP DRIVE -INSTALL TORQUE TUBE PIN -CALIBRATE DRAWWORKS 16:00 - 19:00 3.00 RIGU P PRE CONTINUE TO R/U RIG FLOOR -INSTALL ROOFTOP WALKWAYS -RIG UP MUD LINES IN MUD MOD -BUILD HANDRAIL AND WALKWAY FROM DRILL MOD TO WELL HOUSE -BUILD STAIRS BY UTILITY MOD TO COMPENSATE FOR ELEVATION DIFFERENCE 19:00 - 23:30 4.50 RIGU P ; PRE CHANGE SAVER SUB XT-39 TO NEW XT-39 -USE NEW ALUMINUM GAUGE TOOL -NEW SAVER SUB -FACE TO FACE GAP 2-3/4" -9 TURNS TO MAKEUP OLD SAVER SUB -FACE TO FACE GAP 2-1/8" -8 TURNS TO MAKEUP -CALIBRATE TOTCO PIT LEVEL SENSORS -TAKE ON SEAWATER -OPEN RAM DOORS AND INSPECT UPPER RAMS,LOWER RAMS,BLIND RAMS -CONTINUE TO BUILD STAIRS,HANDRAIL AND WALKWAY FOR ELEVATION DIFFERENCE Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 3 ofd Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UW:500292301100 Active datum:L-01 A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 123:30 - 00:00 0.50 RIGU P PRE HOLD RIG EVAC DRILL WITH MARQUESS WRICE CREW -AAR WITH RIG CREW 1/14/2015 00:00 - 00:30 0.50 RIGU P PRE HOLD RIG EVAC DRILL WITH LYLE BUCKLER CREW -AAR WITH RIG CREW 00:30 - 02:30 2.00 BOPSUR P PRE CHANGE OUT UPPER RAMS -REMOVE 2-7/8"X 5-1/2"VBRS AND INSTALL 7"CASING RAMS REPLACE RUBBER ON ODS BLIND/SHEAR -INSTALL WORK PLATFORM IN AND AROUND WELLHOUSE -TIGHTEN KELLY HOSE "SIMOPS:RIG UP AND PRESSURE TEST HARDLINE TO FLOWBACK TANK 02:30 - 09:30 7.00 RIGU P PRE CHANGE OUT DRILL LINE SPOOL -C/O WEIGHT INDICATOR SENSOR -SPOOL NEW DRILL LINE THROUGH SHEAVES AND WRAP OLD DRILL LINE ON DRAWWORKS DRUM -UNSPOOL OLD DRILL LINE AND SEND DOWN TOOL CRANE SPOOL NEW DRILL LINE ON DRUM -REPLACE DEAD LINE ANCHOR -FUNCTION CROWN SAVER -CALIBRATE WEIGHT INDICATOR AS PER QUADCO "SIMOPS:CONTINUE BUILDING WALKWAY IN AND AROUND WELLHOUSE **RIG ACCEPTED AT 9:30 AM 1/14/2015 09:30 - 12:00 2.50 DHB P DECOMP PRESSURE TEST TWC -250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH FROM ABOVE AND BELOW GOOD TESTS 12:00 - 15:00 3.00 WHSUR P DECOMP NIPPLE DOWN TREE -DRAIN TREE AND REMOVE AS PER FMC -REMOVE BLOCK HANGING LINES -INSPECT HANGER THREADS,THREADS GOOD -MAKEUP 4-1/2"NSCT XO TO HANGER,7-1/2" TURNS,FULL ENGAGEMENT "WELLBORE BARRIERS PRIOR TO NIPPLE DOWN TREE -TESTED TWC -TESTED CEMENT PLUG -ANNULAR VALVE,TUBING PACKOFF 15:00 - 21:30 6.50 BOPSUR P DECOMP NIPPLE UP BOP -PJSM -N/U HIGH PRESSURE RISER -N/U BOP -INFLATE AIR BOOTS FOR BELL NIPPLE AND FLOW LINE -INSTALL HOLE FILL&R/U BELL NIPPLE -INSTALL MOUSE HOLE Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 4 of.QY Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual©95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 121:30 - 23:30 2.00 BOPSUR P DECOMP RIG UP TO TEST BOP'S -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -M/U 4"TEST JOINT ASSEMBLY -FILL STACK -PURGE AIR FROM SYSTEM -PERFORM BODY TEST CHECK FOR LEAKS "STATE NOTIFICATION PUT IN FOR BOP TEST AT 9:55 AM 1/13/14 **WITNESS WAIVED BY AOGCC REP JOHN CRISP 23:30 - 00:00 0.50 RIGU P DECOMP PRE-SPUD MEETING -HELD PRE-SPUD MEETING WITH BOTH CREWS -DISCUSSED WELL CONSTRUCTION AND OBJECTIVES OF L-01A 1/15/2015 00:00 - 05:30 5.50 BOPSUR P DECOMP PRESSURE TEST BOP'S UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINS CHARTED -REST OF BOPE TESTS TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES CHARTED EACH -TEST VBRS WITH 4"AND 4-1/2"TEST JOINTS -TEST 7"CASING RAMS WITH 7"TEST JOINT PERFORM ACCUMULATOR DRAWDOWN TEST -ALL TESTS CHARTED,SEE ATTACHED BOP 'TEST CHARTS 05:30 - 06:30 1.00 BOPSUR P DECOMP RIG DOWN FROM BOP TEST -RIG DOWN TEST JOINTS -BLOW DOWN SURFACE LINES AND MANIFOLD 06:30 - 08:30 2.00 RIGU P DECOMP RIG UP LUBRICATOR -P/U AND INSTALL DUTCH RISER -P/U AND INSTALL LUBRICATOR -PRESSURE TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 MIN CHARTED 08:30 - 10:00 1.50 DHB P DECOMP PULL TWO WAY CHECK -SEAL ROLLED OFF CHECK VALVE -RIG DOWN LUBRICATOR AND DUTCH RISER **WELLBORE BARRIERS AFTER PULLING TWC -TESTED CEMENT PLUG -TESTED BOPS 10:00 - 11:00 1.00 PULL P DECOMP CIRCULATE OUT FREEZE PROTECT -PJSM -PUMP SEAWATER DOWN TUBING,TAKING DIESEL RETURNS INTO TIGER TANK -PUMP DEEP CLEAN SWEEP PLUS SURFACE TO SURFACE VOLUME OF 160 BBLS -9 BPM,1248 PSI Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 5 eat Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) j 11:00 - 12:30 1.50 PULL P DECOMP PULL HANGER TO RIG FLOOR PICK UP LANDING JOINT -BACK OUT LOCK DOWN SCREWS -PULL TUBING HANGER FREE WITH 68K,33K STRING WEIGHT 12:30 - 13:00 0.50 PULL P DECOMP CIRCULATE BOTTOMS UP 1.5X -8 BPM,235 PSI MONITOR WELL FOR 10 MINUTES:WELL STATIC 13:00 - 18:30 5.50 PULL P DECOMP POH ON ELEVATORS FROM 2975'MD TO SURFACE -L/D TUBING HANGER I-P/U=65K S/0=65K AT 2800'MD -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -72 JTS,1 X-NIPPLE.1 CUT PIECE 3.6'LONG, FLARE=4-3/4" -MONITOR DISPLACEMENT VIA TRIP TANK PROPER DISPLACEMENT **FALSE H2S ALARM IN SHAKER ROOM **ALARM WAS SPRAYED WITH WATER, SETTING IT OFF **NO H2S VERIFIED IN SWEEP WITH 'HANDHELD MONITOR **NOTIFICATION TO BP SUPERINTENDANT MADE 18:30 - 19:30 1.00 'PULL P DECOMP RIG DOWN DOYON CASING EQUIPMENT -CLEAN AND CLEAR RIG FLOOR -RIG DOWN TONGS AND MANDREL SLIPS 19:30 - 20:00 0.50 PULL P DECOMP RIG SERVICE -LUBRICATE RIG -GREASE TOP DRIVE AND BLOCKS 20:00 - 21:00 1.00 RIGU P DECOMP RIG UP TO RUN E-LINE -BRING TOOLS INTO PIPE SHED -BRING EQUIPTMENT TO RIG FLOOR -SPOT TRUCK 21:00 - 00:00 3.00 BOPSUR N RREP DECOMP ,TROUBLESHOOT HYDRAULICS IN ACCUMULATOR -DETERMINED HYDRAULIC OIL LEAKING OUT ANNULAR PREVENTOR IN STACK NOTIFIED BP SUPERINTENDENT,WTL,ODE -DETERMINED PLAN FORWARD WITH BP SUPERINTENDENT,WTL,ODE -MOBILIZE HANGER STYLE TEST PLUG FROM TOOL SERVICES -WAIT ON TEST PLUG AND FMC -RIG DOWN AND RELEASE E-LINE 1/16/2015 00:00 - 02:00 2.00 BOPSUR N RREP DECOMP INSTALL TEST PLUG -SET TEST PLUG INTO TUBING SPOOL H RUN IN LOCK DOWN SCREWS PER FMC REP **4.75"BACKED OUT,3.75"RAN IN,450 FT-LBS '-TEST FROM BELOW PLUG TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MIN,CHARTED i**WELLBORE BARRIERS AFTER INSTALLING 'TEST PLUG -TESTED CEMENT PLUG -TESTED TEST PLUG Printed 2/3/2015 8:11:41AM f North America-ALASKA-BP Page 6 gik Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 05:00 3.00 BOPSUR N RREP DECOMP RIG DOWN LOW PRESSURE EQUIPMENT IN BOP DECK -PJSM -PULL MASTER BUSHINGS NIPPLE DOWN LOW PRESSURE RISER -NIPPLE DOWN BELL-NIPPLE -DE-ENERGIZE AND ISOLATE ANNULAR HYDRAULIC CONTROL LINE -REMOVE CAP FROM SHAFFER ANNULAR PREVENTER 05:00 - 09:00 4.00 BOPSUR N RREP DECOMP TROUBLESHOOT HYDRAULICS IN ANNULAR PREVENTER -REMOVE RUBBER ELEMENT -REMOVE ADAPTER RING '-REMOVE PISTON 09:00 - 12:00 3.00 BOPSUR N RREP DECOMP REPAIR ANNULAR PREVENTER -REMOVE OLD ELEMENT AND PISTON VIA RIG FLOOR DAMAGE FOUND ON THE MAIN PISTON BODY(ADAPTER ID) -DAMAGE FOUNDON THE ADAPTER RING CLEAN ANNULAR HOUSING -MOVE NEW ELEMENT AND PISTON INTO PLACE -INSTALL UPPER AND LOWER PISTON ID SEALS -INSTALL UPPER AND LOWER PISTON OD SEALS 12:00 - 20:30 8.50 BOPSUR N RREP DECOMP CONTINUE ANNULAR PREVENTER REPAIR -INSTALL UPPER AND LOWER ADAPTER ID SEALS -INSTALL ADAPTER OD SEAL -INSTALL NEWANNULAR PISTON INTO ANNULAR HOUSING -INSTALL NEW ADAPTER RING -INSTALL NEW ANNULAR ELEMENT -INSTALL AND TORQUE CAP ONTO SHAFFER ANNULAR PREVENTER -FUNCTION TEST ANNULAR HYDRAULICS "SIMOPS:BUILD 4"DRILL PIPE STANDS OFFLINE 20:30 - 21:30 1.00 BOPSUR N RREP DECOMP NIPPLE UP LOW PRESSURE RISER -INSTALL DUTCH RISER ADAPTER -NIPPLE UP LOW PRESSURE RISER/AIR BOOT -NIPPLE UP BELL NIPPLE 21:30 - 22:30 1.00 BOPSUR N RREP DECOMP PRESSURE TEST ANNULAR PREVENTOR -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST ANNULAR ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINS CHARTED -CHART ATTACHED Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 7 o> Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date X3-015PL-C:(9,505,904.00) Project Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:00 0.50 BOPSUR N RREP DECOMP RETRIEVE FMC TEST PLUG -MONITOR IA PRESSURE,0 PSI BELOW TEST PLUG -BACK OUT LOCK DOWN SCREWS PER FMC REP "4.75"BACKED OUT,3.75"RAN IN,450 FT-LBS I-UNSEAT AND PULL FMC TEST PLUG "WELLBORE BARRIERS AFTER PULLING FMC TEST PLUG 1-TESTED CEMENT PLUG TESTED BOPS 23:00 00:00 1.00 WHSUR P DECOMP INSTALL WEAR RING -CLEAN AND CLEAR RIG FLOOR -INSTALL WEAR RING ID=7-1/8" -SPOT SCHLUMBERGER E-LINE UNIT -BRING E-LINE TOOLS ONTO RIG FLOOR 1/17/2015 00:00 - 01:00 1.00 RIGU P DECOMP RIG UP SCHLUMBERGER E-LINE -PJSM,COVERED RIG UP AND SIMOPS i DURING OPERATION -BRING TOOLS INTO PIPE SHED -ENSURE E-LINE SHEAVE ARE PLACED OUT OF IDM TRAVEL PATH -CONNECT AIRLINE WIPER SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 01:00 - 01:30 0.50 CLEAN P DECOMP MAKE UP AND RUN GAUGE RING/JUNK BASKET -RUN IN HOLE WITH 5.75"GAUGE RING/ JUNK BASKET(USIT OD:4.6") -LOST COMMUNICATIONS WITH TOOLAT 100' MD -POOH TO TROUBLESHOOT SIMOPS BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 01:30 - 03:30 2.00 CLEAN N DFAL DECOMP TROUBLESHOOT E-LINE -E-LINE HEAD FLOODED OUT,SHORT CIRCUIT TOOL -RE-HEAD E-LINE WITH BACK UP SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 03:30 - 05:30 2.00 CLEAN P DECOMP RUN GAUGE RING/JUNK BASKET -RUN IN HOLE WITH 5.75"GAUGE RING/ JUNK BASKET(USIT OD:4.6") -TAGGED 4.5"TUBING STUB AT 3,020'ELMD -FIRST 7"COLLAR AT 2,986'ELMD -ALL 40'SPACING BETWEEN COLLARS FROM 2,986'ELMD TO 2,400'ELMD -POOH WITH GAUGE RING/JUNK BASKET -LAYDOWN GAUGE RING/JUNK BASKET SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER Printed 2/3/2015 8:11:41AM Jb North America-ALASKA-BP Page 8 047 Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 12:00 6.50 CLEAN P DECOMP USIT LOG 7"CASING -MAKE UP AND RUN IN HOLE WITH USIT/MSIP/CCUGR(USIT OD:4.6")TO 2,990' ELMD -LOG FROM 2,990'MD TO SURFACE AT 30 FT/MIN -REPEAT USIT PASS FROM 2,830'ELMD TO 900'ELMD -PULL OUT OF HOLE AND LAYDOWN USIT TOOL -RIG DOWN E-LINE *TOC 2,775'ELMD(INTERPRETATION BY GERARDO CEDILLO) SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 12:00 - 12:30 0.50 CLEAN P DECOMP RIG DOWN SCHLUMBERGER E-LINE -PJSM -SEND E-LINE TOOLS OUT TOOL CRANE DOOR -CLEAN AND CLEAR RIG FLOOR 12:30 - 13:30 1.00 CUT P DECOMP RIG UP TO RUN MULTI-STRING CUTTER -INSTALL 4"PS-21 INSERTS -CHANGE OUT 4.5"YC ELEVATORS TO 4"BX ELEVATORS -DRILLER AND AD VERIFY ELEVATORS PROPER SIZE FOR 4"XT-39 DP 13:30 - 17:00 3.50 CUT P DECOMP RIH WITH MULTI-STRING CUTTER FROM 0' MD TO 2,751'MD -RIH ON ELEVATORS WITH 4"DP FROM DERRICK P/U=72K S/0=72K @ 2600'MD -MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT -LOCATE 7"COLLARS AT 2,739'MD AND 2,782' MD -PICK UP TO 2,751'MD AND START CUT -3 BPM,350 PSI,1.5K TORQUE -6 BPM,750 PSI,2-3K TORQUE -PICK UP AFTER CUT,10K OVERPULL TO PULL FREE -RIH,STACK 10K AT CUT INDICATING CASING SHIFT 17:00 - 18:00 1.00 CUT P DECOMP CIRCULATE OUT DEAD CRUDE TO OPEN TOP TANK -6 BPM,750 PSI -PUMP 30 BBL HIGH VISC SWEEP WITH 1 DRUM DEEP CLEAN -FOLLOWED BY HEATED SEAWATER SURFACE TO SURFACE 18:00 - 20:00 2.00 CUT P DECOMP PULL OUT OF HOLE WITH MULTI STRING CUTTER ASSEMBLY -MONITOR WELL FOR 10 MIN:WELL STATIC -POOH ON ELEVATORS FROM 2,751'MD TO SURFACE -P/U=72K S/O-72K AT 2600'MD -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT Printed 2/3/2015 8:11:41AM • North America-ALASKA-BP Page 9Af+s7 Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 21:00 1.00 PULL P DECOMP PULL WEAR RING -DRAIN STACK -BACK OUT LOCKDOWN SCREWS PER FMC "4.75"BACKED OUT,3.75"RAN IN,450 FT-LBS -PULL WEAR RING -VERIFY OA PRESSURE 0 PSI 21:00 - 22:00 1.00 PULL P DECOMP RIG UP TO PULL 7"CASING -RIG UP DOYON CASING TONGS -CHANGE OUT PS-21 INSERTS WITH BOWL INSERTS 22:00 - 23:30 1.50 PULL P DECOMP PICK UP 7"SPEAR -PJSM WITH BAKER REP -MAKE UP 7"CASING SPEAR -RIH WITH SPEAR AND ENGAGE CASING -MAKE UP TO TOP DRIVE -BLEED OFF PACK OFF VOID -BACK OUT LOCKDOWN SCREWS ON 7" CASING SPOOL PER FMC REP **4.75"BACKED OUT,3.75"RAN IN,450 FT-LBS 23:30 - 00:00 0.50 PULL P DECOMP UNSEAT 7"CASING HANGER -UNSEAT HANGER AT 117 K -PICK UP WEIGHT ONCE FREE 107K 1/18/2015 00:00 - 01:30 1.50 PULL P DECOMP PULL AND LAY DOWN 7"CASING HANGER -PULL 7"CASING HANGER AND CASING PACKOFF TO RIG FLOOR CIRCULATE 2X BOTTOMS UP -CIRCULATE HEATED SEAWATER -PUMP AT 8 BPM AND 150 PSI -MONITOR WELL FOR 10 MINUTES:WELL STATIC -DISENGAGE SPEAR AND LAY DOWN -4'PUP BELOW HANGER ON TALLY ACTUALLY 1.5' -BREAKOUT MANDREL HANGER AND LAYDOWN 01:30 - 06:00 4.50 PULL P DECOMP PULL 7""26#,L-80,BTC-M CASING -PSJM WITH DOYON,PARKER,BP -PULL CASING FROM 2,751'MD TO SURFACE -LAY DOWN 40'JOINTS IN PIPE SHED -LAY DOWN 65 FULL JOINTS -CUT JOINT=11.9' -PIPE WAS IN COMPRESSION WHEN CUT -THICK DEAD CRUDE COATING ON JOINTS 1-61 -JOINTS 62-66 PULLED CLEAN -CASING IN GOOD CONDITION,NO NOTICEABLE ISSUES NO CEMENT STRINGERS -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT 06:00 - 08:00 2.00 PULL P DECOMP RIG DOWN FROM 7"CASING PULL -RIG DOWN DOYON CASING TONGS -CHANGE OUT ELEVATOR INSERTS FROM 7" TO 4"DP INSERTS -DRILLER AND AD VERIFY INSERT DIAMETER -CLEAN AND CLEAR RIG FLOOR Printed 2/3/2015 8:11:41AM a► i North America-ALASKA-BP Page 10 OR Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 10:00 2.00 CLEAN P DECOMP BRING 9-5/8"CLEANOUT BHA TO RIG FLOOR -BRING 3 MILLS AND BUMPER SUB TO RIG FLOOR -INSTALL WEAR RING ID:9.875"PER FMC REP **4.75"BACKED OUT,3.75"RAN IN 10.00 - 14:30 4.50 CLEAN P DECOMP MAKE UP 9-5/8"CLEAN-OUT ASSEMBLY -MAKE UP BHA#3 -8-3/4"BIT,8-3/8"LOWER WATERMELON MILL,(2)8-3/4"UPPER WATERMELON MILL, 4-1/2"FLOAT SUB,6-1/4"BOWEN BUMPER SUB,1 JT 5"HWDP,(9)6-1/2 DRILL COLLARS, (15 JTS)5"HWDP,XO TO 4"XT39 -OAL OF BHA =814.34 FT -TIGHT SPOT AT 217'MD,15K DOWN 14:30 - 16.00 1.50 CLEAN P DECOMP RIH WITH 9-5/8"CLEAN-OUT ASSEMBLY -RIH WITH 4"DP FROM DERRICK -RIH FROM 814'MD TO 2,751'MD -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -P/U=107K,S/O=98K AT 2600'MD -TAG 7"CASING STUB AT 2,751'MD WITH 3K DOWN -PICKUP 10'TO CIRCULATE MONITOR WELL VIA TRIP TANK:PROPER DISPLACEMENT 16:00 - 17:00 1.00 CLEAN P DECOMP CIRCULATE 2.5X BOTTOMS UP -RECIPROCATE FROM 2,741'TO 2,715'MD PUMP 40 BBLS DEEPCLEAN PILL -PUMP HEATED SEAWATER AT 550 GPM AND 900 PSI DEAD CRUDE COMING BACK OVER SHAKERS -SHUT DOWN PUMPS AND MONITOR WELL FOR 10 MIN:WELL STATIC 17:00 - 20:00 3.00 CLEAN P DECOMP PULL OUT OF HOLE WITH 9-5/8"CLEAN-OUT ASSEMBLY -POOH ON ELEVATORS FROM 2,741'MD'TO SURFACE -P/U=107'K,S/O=98'KAT 2500'MD TIGHT SPOT AT 215-224'MD,15K UP,20K DOWN -WORK THRU MULTIPLE TIMES -TIGHT SPOT AT 215-224'MD,15K UP,20K DOWN -WORK THRU MULTIPLE TIMES -215-224'MD,10K UP,15K DOWN -DISCUSS WITH ODE MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK 20:00 - 22:30 2.50 CLEAN P DECOMP LAY DOWN 9-5/8"CLEAN-OUT ASSEMBLY -PJSM PRIOR TO PULLING HWDP INTO STACK -RACK BACK 5"HWDP -CONTINUE RACKING BACK HWDP AND DC -L/D MILLS MILLS IN GAUGE Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 11 9011,14-1 Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:00 0.50 CLEAN P DECOMP RIG SERVICE -LUBRICATE RIG -GREASE BLOCKS,CROWN AND WASHPIPE, -CHECK OIL LEVELS IN TDS-11 -CLEAN AND CLEAR RIG FLOOR 23:00 - 00:00 1.00 STWHIP P DECOMP RIG UP HALLIBURTON E-LINE -PJSM,COVERED RIG UP AND SIMOPS DURING OPERATION -BRING TOOLS INTO PIPE SHED -ENSURE E-LINE SHEAVE ARE PLACED OUT OF IDM TRAVEL PATH -CONNECT AIRLINE WIPER SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 1/19/2015 00:00 - 02:00 2.00 STWHIP P DECOMP I MAKE UP AND RUN GAUGE RING/JUNK BASKET/CCL/GR -RIH WITH JUNK BASKET/GAUGE RING(8.28" OD) -GAUGE RING 8.28"OD,EZSV IS 7.75"OD -TAG 7"CASING STUB AT 2,749'ELMD -FIRST COLLAR SEEN AT 2,689'ELMD -POOH FOR EZSV RUN 04:30 2.50 LAYDOWN GAUGE RING/JUNK BASKET 02:00 STWHIP P DECOMP MAKE UP AND RUN EZSV/CCL/GR -RIH WITH EZSV/GR/CCL ON E-LINE FROM SURFACE TO 2,729'ELMD -PULL UP AND SET EZSV AT 2,720'ELMD -TOP EZSV SET 31'ELMD BELOW 2,689' ELMD CASING COLLAR -GOOD INDICATION OF SET -PULL OUT OF HOLE WITH E-LINE -LAY DOWN FIRING HEAD 04:30 - 05:30 1.00 STWHIP P DECOMP PRESSURE TEST 9-5/8"CASING AND EZSV -CLOSE BLIND RAMS -PRESSURE TEST 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 CHARTED MINUTES,PASSING TEST -PUMPED 3.3 BBLS,BLEED BACK 3.3 BBLS -NOTIFY WTLAND OBTAIN PERMISSION TO PROCEED Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 12 gyre-7 Operation Summary Report Common Well Name.L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) - — Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 08:30 3.00 BOPSUR P DECOMP CHANGE OUT 7"CASING RAMS TO 2-7/8"X 5-1/2"VARIABLES -DRAIN STACK -PULL WEAR RING -CLOSE BLIND RAMS -CHANGEOUT UPPER RAM CAVITY FROM 7" CASING RAMS TO 2-7/8"X 5-1/2"VARIABLES -INSTALL TEST PLUG -PRESSURE TEST 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 5 CHARTED MINUTES WITH 4"TEST JOINT PASSING TEST -CHART ATTACHED -INSTALL WEAR RING **BARRIERS FOR CHANGEOUT -TESTED BLIND RAMS -TESTED EZSV -TESTED 9-5/8"CASING **DISCUSSED WITH ODE AND DECIDED TO RUN MORE FLEXIBLE STRING WITHOUT 'WATERMELON MILLS TO PASS WHIPSTOCK ASSEMBLY THRU TIGHT SPOT AT 220'MD 08:30 - 12:00 3.50 STWHIP P DECOMP MAKE UP WHIPSTOCK BHA PJSM WITH BAKER REP -MAKE UP BHA#5 -9-5/8"BOTTOM TRIP ANCHOR,9-5/8"GEN II WHIPSTOCK SLIDE,8-1/4"WINDOW MILL,1 JT HWDP,FLOAT SUB,MWD WITH CROSS OVERS,6-1/4"DRILL COLLARS(9),HWDP(15), XO TO 4-1/2"IF X 4"HT38 55K SHEAR BOLT OAL OF BHA:841.06' 12:00 - 15:00 3.00 STWHIP P DECOMP RUN IN HOLE WITH 9-5/8"WHIPSTOCK ASSEMBLY -RIH FROM SURFACE TO 2,704'MD -TIGHT SPOT AT 220'MD,4K S/O -P/U 107K,S/0101 KAT2,704'MD -RIH ON 4"DP FROM DERRICK -FILL PIPE EVERY 15 STANDS -450 GPM,575 PSI -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT 15:00 - 15:30 0.50 STWHIP P DECOMP SET WHIPSTOCK -ORIENT WHIPSTOCK TO 48 DEGREES LEFT USING MWD AS PER DD -TAG EZSV 2,724'MD -P/U 107K,S/O 101K -SET WHIPSTOCK PER BAKER REP -S/O 17K TO SET ANCHOR -P/U 15K OVER STRING WEIGHT TO CONFIRM ANCHOR SET -5/0 53K AND SHEAR WINDOW MILL OFF WHIPSTOCK SLIDE PROJECTED WINDOW:TOW 2,703',BOW 2,720'MD,2,558'TVD Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 13,p& Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual©95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 16:30 1.00 STWHIP P DECOMP PULL OUT OF HOLE WITH BHA#4 WHIPSTOCK RUNNING ASSEMBLY -POOH ON ELEVATORS FROM 2,724'MD'TO , 841'MD -RACK BACK 4"DP IN DERRICK -P/U=107K,S/O=101K AT 2724'MD -NO TIGHT SPOTS SEEN COMING OUT OF ' HOLE -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR TRIP VIA TRIP TANK:PROPER 'DISPLACEMENT 16:30 - 18:00 1.50 STWHIP P DECOMP LAY DOWN BHA#4 WHIPSTOCK RUNNING ASSEMBLY -POOH ON ELEVATORS FROM 841'MD TO 1 'SURFACE -FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK -SWAP OUT PS-21 INSERTS AND BX ELEVATORS INSERTS -VERIFIED USING CALIPER BY AD AND ' DRILLER '-RACK BACK HWDP IN DERRICK -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -MONITOR TRIP VIA TRIP TANK:PROPER 'DISPLACEMENT 18:00 - 18:30 0.50 STWHIP P DECOMP RIG SERVICE 1 GREASE TOPDRIVE,CROWN,BLOCKS, I , ST-80 -CLEAN AND CLEAR RIG FLOOR 18:30 - 22:00 3.50 EVAL , X DPRB 220.00 DECOMP WAIT ON SLICK LINE AND 40 ARM CALIPER I TO MOBILIZE TO RIG I -CHANGE IN SCOPE TO RUN 40 ARM CALIPER IN 9-5/8"CASING TO DETERMINE IF SUBSIDENCE INDUCED BUCKLING IN TIGHT SPOT AT 220'MD SIMOPS -BUILD 4"DP STANDS WITH OFFLINE STAND BUILDER 22:00 - 00:00 2.00 EVAL C 220.00 DECOMP RIG UP SCHLUMBERGER SLICK LINE -PJSM,COVERED RIG UP AND SIMOPS DURING OPERATION -BRING TOOLS INTO PIPE SHED -ENSURE SHEAVES ARE PLACED OUT OF IDM TRAVEL PATH 1/20/2015 00:00 - 03:00 3.00 EVAL C 220.00 DECOMP RUN 40 ARM CALIPER/CCL/GR -LOG WITH 40 ARM CALIPER/GR/CCL ON SLICK LINE FROM 2,600'MD TO SURFACE -LAY DOWN 40 ARM CALIPER/CCL/GR PER PDS REP RIG DOWN SLICK LINE Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 14 of* Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:30 2.50 STWHIP P DECOMP MAKE UP BHA#5 9-5/8"MILLING ASSEMBLY -MAKE UP BHA#5 PER BAKER REP -8-1/2"WINDOW MILL,8-3/8"LOWER WATERMELON MILL,(2)8-3/4"UPPER WATERMELON MILL,4-1/2"FLOAT SUB,6-1/4" BOWEN BUMPER SUB,1 JT 5"HWDP,(9)6-1/2 DRILL COLLARS,(15 JTS)5"HWDP,XO TO 4" XT39 -OAL OF BHA =806.15 FT -CHANGE OUT PS-21 BOWL INSERTS FOR SLIP INSERTS -CHANGE OUT BX INSERTS FOR 4"DP INSERTS -ID VERIFIED BY AD AND DRILLER -TIGHT SPOT AT 215'MD,18K S/O 05:30 - 06:30 1.00 STWHIP P DECOMP RUN IN HOLE WITH BHA#59-5/8"MILLING ASSEMBLY -RIH FROM 806'TO 2,703'MD -RIH ON 4"DP FROM DERRICK -FILL PIPE EVERY 15 STANDS -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT -MUD WEIGHT:8.5 PPG IN,8.5 PPG OUT -TAGGED TOP OF THE WHIPSTOCK AT 2,003' MD 06:30 - 08:00 1.50 STWHIP p DECOMP DISPLACE WELL FROM 8.5 PPG SEAWATER TO 9.3 PPG LSND -425 GPM,505 PSI -OBTAIN SPR'S 108:00 - 16:30 8.50 STMILL P WEXIT MILL 9-5/8"CASING WINDOW -MILL WINDOW IN 9-5/8"CASING PER BAKER 51-0504 REP -MILL FROM 2,703"MD TO 2,734'MD I .�O -P/U=105K,S/O=99K,ROT=101K -420 GPM,500 PSI -90 RPM,3-10K TORQUE,3K WOB -MONITOR AND CLEAN DITCH MAGNETS -PUMP 50 BBL HIGH VIS SWEEP -MINIMAL CUTTINGS RETURNED -PULL INTO WINDOW AND FLOWCHECK WELL PRIOR TO LOT(STATIC) TOP OF WINDOW=2,703'MD,2,558'TVD MIDDLE WINDOW=2,711'MD, 2,564'TVD BOTTOM WINDOW=2,720'MD, 2,571'TVD 16:30 - 18:00 1.50 STMILL P WEXIT PERFORM LEAK-OFF TEST -MUD WEIGHT:9.3 PPG,2,558'TVD -PUMP 1.20 BBLS AT 0.5 BPM AND PRESSURE BREAKS OVER AT 522 PSI -BLEED BACK 0.8 BBLS -EMW 13.22 PPG -DISCUSS LOT WITH ODE -OBTAIN WTL AUTHORIZATION Printed 2/3/2015 8:11:41AM North America-ALASKA-BP Page 15 parr Operation Summary Report Common Well Name:L-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:1/11/2015 End Date: X3-015PL-C:(9,505,904.00) Project:Prudhoe Bay Site:PB L Pad Rig Name/No.:PARKER 273 Spud Date/Time:6/8/2001 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292301100 Active datum:L-01A actual @95.79usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 19:00 1.00 STMILL P WEXIT PULL OUT OF THE HOLE WITH 8 1/2"MILLING ASSEMBLY -POOH ON ELEVATORS FROM 2,734'MD TO 806'MD P/U 105K,S/O 99K AT 2,737'MD -POOH STANDING BACK 4"DP IN DERRICK -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT -MUD WEIGHT:9.3 PPG IN,9.3 PPG OUT -FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK:STATIC -3K OVER PULLLAT-215'MD 19:00 - 21:00 2.00 STMILL P WEXIT LAY DOWN 8-1/2"MILLING BHA -CLOSE ANNULAR PREVENTER -CHANGE OUT SLIP SEGMENTS -LAY DOWN 6-1/4"DRILL COLLARS -RACK BACK 5"HWDP -LAY DOWN BOT MILLING ASSEMBLY -CLEAN AND CLEAR RIG FLOOR MILL GAUGE WEAR: WINDOW MILL-1/4"UNDER GAUGE • LOWER STRING MILL- 1/4"UNDER GAUGE UPPER MILL 1-1/4"UNDER GAUGE _ UPPER MILL 2-IN GAUGE 21:00 - 22:00 1.00 DRILL P INTI 1FLUSH AND FUNCTION BOPS -DRAIN STACK -M/U BOP CLEANING TOOL TO 1 STAND OF 4" DP -WASH AND JET BOPS DOWN PAST WELLHEAD -FUNCTION TEST ALL BOP COMPONENTS 22:00 - 22:30 0.50 DRILL P INTI RIG SERVICE -GREASE TOP DRIVE,BLOCKS,IDM,ST-80, ELEVATORS,SLIPS 22:30 - 00:00 1.50 DRILL P INTI MAKE UP 8-3/4" DRILLING ASSEMBLY -BRING SLB SUBS AND X/O'S TO THE RIG FLOOR -DRILLER AND AD CONFIRM ALL LIFT SUBS CALIPERED AND PROPER SIZE FOR 5" ELEVATOR INSERTS -MAKE UP MOTOR BHA#6 PER SLB -8-3/4"MILLED TOOTH BIT,6-3/4"PDM,N/M STAB,ECOSCOPE LWD,TELESCOPE 675 MWD,IN LINE STABILIZER, (3)NM FLEX COLLAR,FLOAT SUB, (15 JTS)5"HWDP, HYDRAULIC JARS,(5 JTS)5"HWDP,XO TO 4" XT-39 OAL OF BHA:836.48 FT Printed 2/3/2015 8:11:41AM IF'h= 4-1/16"CNV TY NOTES: CHROME TBG&CSG. **'POTENTIAL A---IVIiiall-EAC= FTC L-O (SCALE 7) 0 ON TO 3.70"FROM 862T-9428'CTM ACTUATOR= BAKER C OIB.ELEV=----- 76.7' ------------------ -------- BF.REV= — — KOP_= 1100 1021' H9-5/8"TAM PORT COLLAR Max Angle= 36"@ 2535 2703' H9-5/8"VM-FSTOCK(01/20/15) Datum ND= 9191' Datum TVD= 8800'SS 2724' -19-5/8"EZSV(01/19/15) 2751' --17"CSG STUB(01/17/15) 9-5/8"CSG,40#,L-80 BTC,D=8.835" H 2760' , 4-1/2"JET CUT(11/14/14) H 3014' ELM GAS LFT MANDRELS TOP OF CEMENT(11/09/14 TAGGED) H 5863'slm ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3227 2999 29 KBG-2 DMY BK 0 11/17/07 7"CSG,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 8279' F--X X 5 3504 3248 24 KBG-2 DMY BK 0 06/19/14 4 5968 5671 1 KBG-2 *DMY BK 0 06/19/14 3 7571 7274 1 KBG-2 *DMY BK 0 06/19/14 2 8390 8093 8 KBG-2 EMPTY - 10/31/14 Minimum ID =3.725" @ 8750' e.,:. 1 8627 8326 11 KBG-2 *Dnnv BK 0 06/19/14 4-1/2" HES XN NIPPLE *STA's#1-#4 =CEMENTED(10/30/14) •4'•+. 8695' H4-1/2"FES X NP,ID=3.813" • . 1 PERFORATION SUMMARY =,. ►' i= 8706' 7"X 4-1/2"BKR S-3 PKR D=3.875" REF LOG: FE ARRAY INDUCTION ANGLE AT TOP PERF: 11°@ 9124' r) Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Scg SHOT SCIZ 8729' —14-1/2"I IM X NP,D=3-813" 3-3/8" 6 9124-9136 S 112/13/02 10/27/14 • 2-7/8" 6 9132-9136 S 01/05/10 10/27/14 2-7/8" 6 9142-9152 S 01/05/10 10/27/14 hp iip 3-3/8" 6 9142-9180 S 12/13/02 10/27/14 2-7/8" 6 9158-9178 S 01/04/10 10/27/14 #t 8750' H4-1/2"HES XN NP,D=3.725" iP 2-7/8" r 6 9180-9210 S 11/14/01 10/27/14 wf 2-7/8" 6 9188-9208 S 01/04/10 10/27/14 -' 2-7/8" 6 9220-9230 S 01/04/10 10/27/14 Ir• {•. 8763' H4-1/2"VVLEG,D=4-00" 2-7/8" 6 9220-9240 S 11/14/01 10/27/14 * 8752' HELMD TT LOGGED 11/14/01 2-7/8" 6 9252-9262 S 11/14/01 10/27/14 #, � # ... 9100' -17"RA TAG +' * 9092'ELM CORRECTED ? 1 FISH-1"DMY GLV w/BK LATCH BELOW 4-1/2"TBG,12.6#,13CR VAM ACE, H 8761' *. . 'x' STA#1 (06/19/14) .0152 bpf,D=4-00" . 4: #.. : 4164. iiiPr • .v"• ? 1 FISH-UNDERREAM ARMS &DEBRIS(09/01/07) PBTD H 9428' b r a 7"CSG,29#,13CR-95 VAM ACE, H 9509' * ``+{ * ia .0371 bpf,D=6-184" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/01/01 CI-VKAK ORIGINAL COMPLETION 07/09/14 PJC UPDATES-PRE PROPOSAL WELL: L-01 02/27/06 JRR'PJC GLV GO 10/30/14 JIM PJC P&A PERI IT No: ' 010720 08/29/07 DMS/GV FISH/MND CHG(SFTY NOTE) 10/31/14 STI/PJC GV GO-#2 EMPTY AR No: 50-029-23011-00 09/28/09 SWC/SV GLV GO(08/03/09) 11/09/14 SWG PJC TAG CEMENT TOP SEC 34,T12N,R11 E,2397 NSL&3659'VVEL 02/02/10 RRLYPJC PERFS(01/04-05/10) 11/14/14 DW/PJC JET CUT TBG 06/23/14 DLH/JMD GLV GO&FISH(06/19114) BP Exploration(Alaska) 0 c9 QJ ` .=^ v iiv) ro Y V > lN U1 ( c0 LL C N Q t Q Y CU O t h • L L C ti4 – > .. ,111 Ce VI' co O Yo W Z� Q O O O Q # W Q 0 C: iHU Q m In 0c. .0C C @ v acC NZ VR CU O aJ O >' 41 QE O ? * A JO d d co 7 7oo7o u -O CD °J °' � _ o H 1– r N N N Q 7 u Lo CO o 4-, U L Q C £ V pp C o 0 O • ,, v E - • O O o , O_ _o a.., c0 C 0 0 0 0 0 0 0 u co 0 u W. J J J J J J J N S v u L_ O. W W W W WWW cc — . r ., F LL LL LL LL LL LL LL O Y Q1 OU F.., Q Q Q Q Q Q Q ._ O C O Q z z z z z z z E v a ° µ ULL LL LL LL LL LL LL C O -0 C 41 Q1 N Y47- o-+ 3 F- > > C i QJ .0• ur Po F `'7 w tU m U '.) -J a a s U co et m :i; D Cl) C CO 8 c u re> 0 x IS cC Iv . ~ �.. 'w z i i i i i i i i i I' i o. z.....1 a' FE tY LU E 0 w U 5 O co � LcE5 �� NCT OA pON x N U I La w V m m m m m m m c; 2 • Lc) ( at uWWWWWWW 0 c0 0000000 xxxxxxx E 'crn• a yt ; u. 0 0 0 0 0 0 0 D MMDDDM CLCLCLCYCeCeee 1:3 tm on ro 0. 0_ a 0. 0. 0. 0. O 1 tics ea • u L N O N 1� 9 O N u O O O 0 M N 0 \ c r O N O C a 0 0 0 0 0 0 0 0 0 I H Da 1/1 0 0 0 0 0 0 0 'O o: 0V V os U x H oi O 0 0 V O O o v ° .= c C v E , , q ai m _CL2 ur yy u c0 p > O CID �+ �i g $ m ' 0 0 Q Q o: c _� LI 9J M1 r.1 4 N 9 M O N 0 f0 a)E 7 a+ .I 0 J Ero cel C11 CC 2 = d a N N u O Q^Q @ HIU �= a STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS . `.'1Ca 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ ~,3~,^A~ ~ , t. ~, , -, ,.~ ~r1'Df'11~3!~t Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extensi~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended W~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development Q Exploratory 201-0720 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23011-00-00 8. Property Designation (Lease N\mber) : 9. Well Name and Number` ADLO-028239 a PBU L-01 10. Field/Pool(s): PRUD HOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9528 feet Plugs (measured) None feet true vertical 9208.63 feet Junk (measured) None feet Effective Depth measured 9428 feet Packer (measured) 8706 true vertical 9110.01 feet (true vertical) 8404 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Surface 2733 9-5/8" 40# L-80 27 - 2760 27 - 2601 5750 3090 Production 8255 7" 26# L-80 24 - 8279 24 - 7982 7240 5410 Production 1149 7" 29# L-80 8279 - 9428 7982 - 9110 8160 7020 Production 81 7" 26# L-80 9428 - 9509 9110 - 9191 7240 5410 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 22 - 8763 22 -8459 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer 87.06 •- ~ 8404 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~ ~ ~~~ ,~~yq~~,qq ?I~EN~~.., 1~1~ U. r. •4°t .~~. . ~ Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 126 123 667 341 Subsequent to operation: 137 134 722 348 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Servic^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG- ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 1/12/2010 Form 10-404 Revised 7/2009 ~vDMS JfiN 14 ~~~~ ~ Sub~mit/Original Only L-01 201-072 PERF ATTAC:HMFNT n U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L-01 11/14/01 PER 9,180. 9,210. 8,866.09 8,895.56 L-01 11/14/01 PER 9,220. 9,240. 8,905.38 8,925.03 L-01 11/14/01 PER 9,252. 9,262. 8,936.83 8,946.65 L-01 12/13/02 APF 9,124. 9,136. 8,811.13 8,822.9 L-01 12/13/02 APF 9,142. 9,180. 8,828.79 8,866.09 L-01 9/4/07 BPS 8,664. 9,262. 8,363.02 8,946.65 L-01 12/15/07 BPP 8,664. 9,262. 8,363.02 8,946.65 L-01 1/4/10 APF 9,158. 9,178. 8,844.49 8,864.13 L-01 1/4/10 APF 9,188. 9,208. 8,873.95 8,893.59 L-01 1/4/10 APF / 9,220. 9,230. 8,905.38 8,915.21 L-01 1/5/10 APF / 9,132. 9,136. 8,818.98 8,822.9 L-01 1/5/10 APF 9,142. 9,152. 8,828.79 8,838.6 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • L-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY ACTIVITYDATE 1/4/2010[****WELL FLOWING UPON ARRIVAL****(E-LINE PERFORATE) =INITIAL T/I/O: 300/1500/400 PERFORATE THE FOLLOWING INTERVALS WITH 2-7/8" HSD GUNS LOADED WITH 2906 PJ OMEGA CHARGES: l '9220' - 9230', 9188' - 9208', 9158' - 9178'. RIH WITH LAST GUN. URE 1600 PSI. OPENED WELL UP FOR 200 PSI UNDERBALANCE TO PERFORATE AT 1400 PSI. API GUN DATA: PENETRATION = 36", ENTRANCE HOLE = 0.34", E ;EXPLOSIVE LOAD = 16 G/CHARGE j E****JOB IN PROGRESS AND CONTINUED ON 5-JAN-10 WSR**** 1%5/2010 /I/0=340/1570/420. Temp=95". IA FL (GLE). AL online. IA FL @ 7571' (Sta ~# 3 Dome), 1056' above SOGLV. GLR=0.8 mmscfpd. Operator SI well to stack bout and unload IA FL upon departure. ASV=Closed. WV=Closed. SSV, MV=Open. IA, OA=OTG. 1/5/20101*""*CONTINUE AWGRS FROM 4-JAN-10*'`**(ELINE: PERFORATION) SWELL FLOWING UPON ARRIVAL IN ITIAL T/I/O: 300/1500/400 ;PERFORATE THE FOLLOWING INTERVALS WITH 2-7/8" HSD GUNS =LOADED WITH 2906 PJ OMEGA CHARGES: =9132'-9136; AND 9142'-9152'. COULD NOT GET PAST 9165'. (POSSIBLE FSCALE FROM PREVI U F RUN) INITIAL SHUT IN PRESSURE 1600 PSI. OPENED WELL UP FOR200 PSI 'UNDERBALANCE TO PERFORATE AT 1400 PSI. API GUN DATA: PENETRATION = 36", ENTRANCE HOLE = 0.34", EXPLOSIVE LOAD = 16 G/CHARGE ;PAD OP TO BRING WELL ONLINE AFTER DEPARTURE. SWING-C, MASTER/SSV-O FINAL T/I/O: 1300/1300/400 E*** JOB COMPLETE *** FLUIDS PUMPED BBLS 8 METH 2 diesel 10 Total TREE= 4-1/16" CMV WELLHEAD=, FMC ACTUATOR= KB. ELEV = 76.7' BF. FlEV = KOP = 1100' Max Angle = 36 @ 2535' Datum MD = 91 91' Datum TV D = _ 8800 SS 9-518" CSG, 40#, L-80 BTC, ID = 8.835" SAFE~OTES: CHROMETBG &CSG. '** POTENTIAL `„~ ~~ 1 (SCALE 08129 0 ON TO 3.70" FROM 8627' - 9428' CTM 1021 ~ TAM PORT COLLAR 2256' 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS Minimum ID = 3.725" @ 8750' 4-112" HES XN NIPPLE 7" CSG, 26#, L-80 BTGM, .0383 bpf, XO TO 29#, 13CR-95 VAM ACE PERFORATION SUMMARY REF LOG: PE ARRAY ~ttWCT~N ANGLE AT TOP PERF: 11 9124 Note: Refer to Production DB for h~tortcal pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 9124 - 9136 O 12113/02 3-3/8" 6 9142 - 9180 O 12113/02 2-718" 6 9180 - 9210 O 11!14/01 2-7/8" 6 9220 - 9240 O i 1114101 2-718" 6 9252 - 9262 O i 1t14t01 ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3227 2999 29 KBG-2 DMY BK 0 11/17(07 5 3504 3248 24 KBG-2 DOME BK 16 12/14/07 4 5968 5671 0 KBG-2 DOME BK 16 12/14/07 3 7571 7274 1 KBG-2 DOME BK 16 12/14/07 2 8390 8093 8 KBG-2 DMY BK 0 07/01/01 1 8627 8326 11 KBG-2 SO BK 20 08/03/09 $695' }- -4112" HES X NIP, ID = 3.813" 8706' 7" X 4112" BKR S-3 PKR, ID = 3.875" 8729 67~ 4-1 i2" HES X NIP, ID = 3.813" 4112" HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, 13CRVAMACE, $763' f ~ 8763' ~4-t12" WLEG, ID=4.00° .0152 bpf, ID = 3.958" g75~ EL~3 TT LOGG®11/14101 9012' RA TAG (EL CORRECTED} ~~~ F'BTD 7" CSG, 29#, 13GR-95 VAMACE, .0371 bpf , ID = 6.276" DATE REV BY COMMEN~I~~S llATE REV BY COMMENT°5 07101!01 CHJKAK ORIGINAL COMPLETION 08/29/07 DMS/GV FISW MIN ID CHG (SFTY NOTE) 11114/01 TMN/KAK PERFS 09/28!09 SWCISV GLV C/O (08/03!09} 12113(02 CAO/KK ADPERFS 12/30(02 DAG/KK GLV CORRECTIONS 07/07/04 DAV/KA GLV C/O 02/27/06 JRP/PJC GLV C/0 FISH- UNDERREAM ARMS &D~RIS (09101107} PRUDHOE BAY UNIT WELL: L-01 PERMff No: x2010720 API No: 50-029-23011-00 SEC 34, T12N, R11 E, 2392' NSL & 3659' WEL BP Exploration (Alaska} • • BP Exploration (A{aska) fnc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 , a~ .~s~,~'~~~ f~` t~~:' ~~° 2~1~~ ~. ~, i:; bp , ~~~l~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0 5 2009 ~-las~ca ~ii ~a Gas Cons. Comtni~sio~n Anchora~e ~,oi~0~~- ~~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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 ietter 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploratio~ (Alaska ) Inc. ~J Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-oH Report of Sundry Operetiona (10-404) A9~N L pad RH'~/9009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Curro$io~ inhibdod seatant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA t.~ NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Neetl To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-i14A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-178 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 5002923t870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.6 NA 17 6/27/2009 09!28(07 >Il~i[il~~~~r~~pr~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ N~V ~ ~ 2007 WPII .Inh S l nn rlnserin4inn NO.4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay r1~in RI Cnlnr Rr1 15-39A 11661174 MEMORY PROD PROFILE 09/23107 W-42 11745235 MEM SBHPS/TEMP 09/14/07 Z-07A N/A SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE - b 08/31/07 1 X-33 11849931 SBHP SURVEY ~ - ~/L 08/31/07 1 E-14A 11686784 LDL -~ ~ 09/23/07 1 01-15A 11855509 DDL ~ - a~ b 09/22/07 1 D-21 11626119 PRODUCTION PROFILE ~'a - ~ 09/11/07 1 K-07D 71745234 MEM PROD PROFILE C - 09/06/07 1 11-32 11630498 PRODUCTION PROFILE ~ L - 09/03/07 1 L-01 11745233 MEM LDL a (~ (- ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION 08/28/07 1 Z-28 11630500 INJECTION PROFILE 'ZC 09/05/07 1 Z-16 N/A SBHPS/JEWELRY / a 09/13/07 1 14-26 11676959 LDL -/j 09/09/07 1 04-02A 11630504 LDL !r 09/11/07 1 14-37 11695075 LDL _ <f 09/13/07 1 3-35lL-36 11630502 PRODUCTION PROFILE 09/09/07 1 rl_tAat AcKNUWLtuGE RECEIPT t3Y SIGNING AND RETURNING O;NE COPY EACH TO: BP Exploration (Alaska) Inc. ^ '; Petrotechnical Data Genter LR2-1 f ` 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~~,~~~ E~ ~~~4~~ ~~ Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 , Anchorage, AK 99503-28 ATTN: Betfi Received by: • • · · · :. · · · · · · · · · · · · · · · :. · · · · · · · · · · · · · · · :. .- · · · · J..O (. 0/2 Determination of Residual Oil Saturation Before and After a Low Salinity Water Injection Through SINGLE WELL CHEMICAL TRACER TESTING Performed for BP EXPLORATION (ALASKA), INC. Prudhoe Bay Unit, WOA, Well L-Ol Ivishak Zone 4 API No 50-029-23011-00 '. Service Report September 2003 Chemical Tracers, Inc. 1814 Steele Laramie, Wyoming 82070 (307) 742-0418 www.chemtracers.com CONFIDENTIAL "-~ -.~ Determination of Residual Oil Saturation Before and After a Low Salinity Water Injection ~«, Prudhoe Bay Unit, WOA, Well L-Ol Ivishak Zone 4 API No 50-029-23011-00 REPORT SUMMARY '~ Two single well chemical tracer (SWCT) tests have been completed at the L-OI well. in the Western Operating Area, Prudhoe Bay Unit. The purpose of these tests, performed by Chemical Tracers Inc., was to measure residual oil saturation before and after low salinity water injection in the Ivishak Zone 4. The results of the first SWCT test, Test 1, show that produced water injection, 20,000 bbls, yielded a residual oil saturation (SOR) in the test zone of 0.19 ± 0.03. This saturation measurement represents the pore space in a 108-foot thick section of the Ivishak Zone 4, from the well bore to a radial position of about 8 feet. After this initial residual saturation measurement, the zone was treated with 2,900 bbls of low salinity water, one pore volume, followed by 5,600 bbls of produced water. A second SWCT test, Test 2, was then to be conducted to measure SOR(LoSAL) (SOR after Low Salinity Water injection) in the same pore space that the initial SWCT test investigated. The results of SWCT Test 2 show that the SOR(LoSAL) is 0.15 ± 0.03. A summary of the SWCT Tests 1 and 2 is shown below: '-~- Test 1, SOR Test 2, SOR(LoSAL) Test Size (bbls) 1,000 1,000 Depth<of Investigatiol) 8.5 feet 8.7 feet Sub~zønesc Recognized 3 3 Test Description SOR = 0.19 ±o.03 SOR(LoSAL) = 0.15 ±o.03 -=' The reported SOR and SOR(LoSAL) measurements represent fluid-injection weighted average oil saturation for the sub-zones penetrated by the tracer fluids during these. tests. The SWCT test results show non-ideal behavior of the chemical tracers. Pressure differences between perforated sub-zones caused cross-flow of the tracer fluids during the shut-in period. These test results were adequately simulated with a three-layer model incorporating 160 bbls of total cross-flow. The details of the field operations and the interpretation ofSWCT Test 1 and 2 are discussed in the following report. The primary field data recorded during these tests, profiles of tracer concentration vs. volume of water produced, are presented and compared with best-fit simulation model results. , ~="" ", -~ -'7 Joß 11 ~ Chemical Tracers, Inc. ~~. ·sle Determination of Residual Oil Saturation Before and After a Low Salinity Water Injection INTRODUCTION A detailed explanation of the Single Well Chemical Tracer (SWCT) test method is offered in Appendix A. The one-spot pilot program carried out at the L-O 1 utilized the SWCT test as an in-situ non-destructive oil saturation-measuring tool before and after a small low salinity water injection. This report summarizes the initial produced water flood and residual oil saturation measurement, Test 1, the low salinity water/produced water push injection, and the post-low salinity water injection oil saturation measurement, Test 2. Both Test 1 and Test 2 were completed on September 21, 2003. This report section describes the above-mentioned work. TESTING PROGRAM AND FIELD RESULTS The test well, L-O 1, was completed in July 1, 2001. Originally the 7" production casing was perforated twice: 9,124' to 9,136' and 9142' to 9,180'. Later three more sets of perforations were added: 9180' to 9,210', 9,220' to 9,240' and 9,252' to 9,262'. The overall Ivishak Zone 4 Sands penetrated by these perforations are about 108' thick and have an average porosity of 160/0. Reservoir temperature is 217 degrees Fahrenheit. The well is produced through 4-1/2" production tubing via gas lift. The well was on continuous oil production from December 13,2002 until the reported SWCT testing was carried out. During this production period, the test zone produced an average of 1,000 BOPD. During August and September 2003, Chemical Tracers, Inc. conducted two residual oil saturation tests. 2 Table 1: Testing Program Schedule -.;.=# Activity Date Started Date Completed Produced Water-Flood August 18,2003 Sept. 2, 2003 SOR Test 1 Sept. 2, 2003 Sept. 8, 2003 LoSAL Water Injection Sept 8, 2003 Sept. 9, 2003 Produced Water-flood Sept. 9, 2003 Sept. 13, 2003 SOR(LoSAL) Test 2 Sept. 13, 2003 Sept. 21, 2003 ~- -~ _. The SOR Test (Test 1) Since the well produced 1000/0 oil, it was necessary to inject a small volume of water into the test zone to reduce the oil saturation to residual. This volume of water was 19,967 bbls (185 bbls/ft.). The injection rate for this water-flood water was from 1,500 BWPD to 2,000 BWPD. Because the injection water was not filtered, (produced water manifold on L-Pad) it was necessary to back produce the well occasionally, to maintain clean perforations during injection. Initially, 10,450 bbls of water was injected at 1,500 BWPD and a wellhead pressure, WHP, of 1,875 psi (maximum WHP was 2,000 psi). After a 419 bbls production period, injection was resumed at 1,500 BWPD at a WHP of 1,750 psi, for 9,517 additional bbls. The well was then produced for 431 bbls and the SWCT test injection immediately followed. The total gross water- flood injection was 19,967 bbls water. The total injection water back produced for clean up was 850 bb1s. 'r~- "--0""'" '.~~ c__ .~ 'c~ Following water injection, the SWCT Test 1 to measure SOR was carried out. This test comprised a total injection of 1,090 bbls. The injection rate was constant at 1,500 BWPD and the maximUITI WHP encountered was 1,600 psi. The first 200 bb1s of water carried 10,OOO-ppm ethyl 3 - acetate (EtAc), 9,000-ppm methyl acetate (MeAc), 4,000-ppm nonnal propyl alcohol (NP A), and 4,500-ppm iso-propyl alcohol (IP A). These 200 bbls were followed by 890 bbls of water containing 4,500-ppm IP A. The well was then freeze protected with 65 bbls of arctic diesel. The total injection of 1,090 bbls plus the 65 bbl freeze protect fluids placed 1,000 bbls of water into the test zone (200 bbls with ester plus 800 bbls of push). The well was then shut-in for 3.3 days for the reaction period. Following the reaction period, the well was produced for two days, 1,673 bbls. Samples of the produced fluid, clean water, were taken every 10 to 20 bbls and immediately analyzed at the site for tracer content via gas chromatography. The field-measured tracer profiles are shown in Figures 1-6, plotted as tracer concentrations vs. produced bbls. The primary reactive tracer, ethyl acetate (EtAc), is plotted in Figure 1; with the product tracer, ethyl alcohol (EtOH). The second reactive tracer, methyl acetate (MeAc) is plotted with the product tracer, methyl alcohol (MeOH) in Figure 2; the cover tracer, n-propyl alcohol (NP A) is shown in Figure 3 and the material balance tracer, iso-propyl alcohol (IP A), is shown in Figure 4. Low Salinity Water Injection The low salinity water injection was carried out after the first residual oil saturation test was completed. Prince Creek low salinity water was hauled to location from Milne Point F-pad, via vacuum truck and injected using a First Energy hot oil truck. This injection comprised of 2,900 bbls of low salinity water heated to 150 degrees Fahrenheit. Injected rate was 2,000 BWPD. Produced water, from the L-Pad waterflood injection header, was then injected at 2,000 BWPD until 5,603 bbls were injected. The well was then produced for three and a half hours to clean accumulated solids from the perforations (316 bbls) and SWCT test two injection irnmediately followed. 4 SOR(LoSAL) Test (Test 2) The post-low salinity water SWCT test was then carried out to measure SOR(LoSAL). This h SOR(LoSAL) test comprised a total injection of 1,090 bbls. The injection rate was constant at 1,500 BWPD and the maximum WHP encountered was 1,650 psi. The first 200 bbls of water carried 10,500-ppm ethyl acetate (EtAc), 8,000-ppm methyl acetate (MeAc), 6,000-ppm normal propyl alcohol (NP A), and 5,000-ppm iso-propyl alcohol (IP A). These 200 bbls were followed by 890 bbls of water containing 5,000-ppm IP A. The well was then freeze-protected with 60 bbls of artic diesel. The total injection of 1,090 bbls placed about 1,000 bbls of water into the test zone (200 bb1s with ester plus 800 bbls of push water). The well was then shut-in for 5.9 days for the reaction period. Following the reaction period, the well was produced for 1.75 days, 1,932 bbls. Samples of the produced fluid, water, were taken every 10 to 20 bbls and immediately analyzed on site for tracer content via gas chromatograph y. Figures 22-27 show the field-measured tracer profiles for this Test 2. The profiles for EtAc and EtOH are shown in Figure 22. There is slightly less separation between these two ~~'- - - -~-. profiles compared to Test 1 Figure 1, indicating that the low salinity water process displaced some oil. The value of SOR(LoSAL) will be quantified below in the test interpretation section. A detailed daily journal of field activities is recorded in Appendix C. ~- 5 Table 2: Fluid Injection for Single Well Pilot Slug Name (2uaritìty ·VolumëIricremênf(bbls) Produçed Water Injection Volume Injected (bbls) LoSAL Water Injection V olmne Injected (bbls) Produced Water Push Volume Injected (bbls) Test 2 Ester Bank Volume Injected (bbIs) Test 2 Push Volume Injected (bbIs) 19,967 o through 19,967 2,900 19,967 through 22,867 5,603 22,867 through 28,470 200 28,470 through 28,670 890 28,670 through 29,560 This sequence of fluid injection is also shown in the following illustration. 6 c- ..--- ,,----- ..' . '--- "------ ,.~ ~>~~' :"C.~ '~--- Well Bore, 148 bbls Depth (ft) SWCT Test 2 Push, 800 bbls 10.8 7.9 (EtAc) SWCT Test 2 Ester Bank, 200 bbls 9.9 (MeAc) Produced Water Push, 5,603 bbls 29.0 iii! LoSAL Water Injection, 2900 bbls 34.8 Produced Water Injection, 19.967 bbls 61.3 -~ ;;..- -"- Note: The depth notation in the illustration above refers to the radial depth of penetration for the -~. given aliquot of water considering a 108-foot zone with a 16% porosity and residual oil saturation of 0.15. No dispersion is considered here and the picture is offered as a simplistic illustration of '-.-~~ the fluid injection sequence. "~ :;C'-- 7 INTERPRETATION OF SWCT TEST DATA Ideal SWCT Tests The theory of the ideal SWCT1 test aSSUI11es that the tracer carrying fluid is injected along streamlines that extend radially from the well bore into the test formation, which is assumed to be a single homogeneous layer. When the \vell is shut in for the reaction period, the tracer is supposed to remaIn fixed while the reaction proceeds to form the product alcohol. During production, the tracer carrying fluid then returns radially along the same streamlines to the well. When these conditions are met, an ideal SWCT test is generated. Non-Ideal SWCT Tests In most cases, the tracer profiles obtained in the field display some non-ideal symptoms. There are four common reasons why a real test may depart from ideal behavior; each has its own characteristic symptoms. (1) Fluid drift - general movement of the mobile phase in the test formation, usually caused by production from or injection into nearby wells in the same reservoir. The streamlines around the test well are not the same during injection and production. Furthermore, the tracers continue to move during the shut in period. Tracer profiles tend to arrive too early, and have strange shapes~ separation is observed between the partitioning ester and the cover tracer, even though they were injected in the same fluid. (2) Flow irreversibility in layered test zones - individual layers may accept a different fraction of the injected fluid than they return to the well bore during production. Partial plugging of perforations during injection, if the injected fluid contains suspended solids, can cause this. The most obvious symptoms are early arrival of all tracers and late arrival, in the form of extended tails on the tracer profiles. 8 (3) Cross-flow between layers - in layered test zones, small pressure differences between individual layers can cause fluid with tracers to flow from one layer to another through the well bore during shut in. The same pressure differences will cause flow irreversibility as in (2) above. The symptoms are the same in the tracer profiles. :.~~ k_:..:"---~ (4) Complex Pore system effects - non-equilibrium flow conditions in most carbonate reservoirs usually cause distorted profile shapes in the individual tracer production profiles. Ester profiles arrive earlier than expected and have extended tailing. Material balance tracers arrive diluted and have extended tailing. Capacitance is reflected in each chemical profile shape and position. These effects can be extensive in some cases depending on lithology and distribution of pore space. The complex pore system effects are usually limited to carbonate reservoirs. Based on previous experience in sandstone reservoirs, we believe that effect (3) IS probably responsible for the minor non-ideal behavior observed in this well. Appendix B contains a detailed explanation of the simulation process and the available simulators. Matching The SOR Test Profiles CFSIM was first used with an ideal single layer model to simulate the L-O 1 SOR test results. Dispersion constant, hydrolysis reaction rate, and finally SOR were varied for the single layer to obtain the best fit of simulated profiles to field profiles. The results are shown for EtAc and EtOH in Figure 7, the MeAc and MeOH profiles in Figure 8, the NP A cover tracer in Figure 9, and IP A (material balance) in Figure 10. Sor used for the single layer model is 0.19. -~.- It is obvious from Figure 5 that the ideal simulation model fits the primary tracer EtAc reasonably well, but does not fit the EtOH profile taiL Similarly, the IPA material balance tracer is not fit well by the ideal simulation, Figure 10. Ideal simulation model fits of MeAc-MeOH and NP A are shown in Figures 8 and 9 respectively. 9 Each of the tracers used show small departures from the ideal model during early production and significant departures in the late production. These departures are considered irreversible flow effects or cross-flow. These effects are commonly observed in SWCT tests. Fines accumulating on the fonnation face during injection cause partial plugging; when production begins, the fines are flushed away, causing the effected perforations to produce more than they accepted during injection. In the cross-flow case, the tracers in the higher-pressure sub- zone back produce towards the well and adjacent sub-zones during th~ shut-in period. These effects are readily accounted for by using our multi-layer simulator, CFSIM. CFSINI Best-Fit Nlulti-Layer Nlodel, SOR Test 1 As would be expected, the fit can only improve if layers are added. Considering the EtAc and EtOH single layer match in Figure 7, the early arrival of tracer peaks (150- 400 bbls produced) seen in the pushed tracers, EtAc, MeAc, and NP A, requires a layer that accepted a portion of the ester bank and push fluid and produced back virtually all of the push fluid to the well-bore during the shut-in period. A third layer accepted this cross- flow fluid and generated the extended higher concentration of tracers during the later production. The concentration profiles observed at the surface are the mixed result of all the layers that produce fluid from the test formation into the well bore. The simulation progran1 is able to show the individual layer contributions as well as the mixeq production stream, which is all that is available from the field data. Figure 11 compares the best-fit CFSIM multi-layer model predictions with the field profiles for EtAcand EtOH for a SOR of 0.19. The contributions of the different layers are shown along with the composite simulation in Figures 15, 16 and 17 for EtOH, NP A and IP A. The same simulator model fit to the MeAc, MeOH profiles is shown in Figure 12 with an Sor of 0.22. Interestingly, the methyl acetate tracer penetrated deeper 10 ~ ."~~ ~ ~"':--~--':~ "--- ~~- -~ :.-~ 1 "7 '~- c~ into the zone than the ethyl acetate, 10ft vs 8 feet. The higher saturation measured by the methyl acetate represents the saturation profile generated by the small water injection carried out prior to testing. For this cross-flow case, the match can be made using the input shown in Table 4. Table 4: Distribution of SWCT Test 1 Fluids in Best-Fit Cross-flow Multi-Layer Model Layer Idenüfication 1 3 2 0.19 0.19 0.19 Test Step: fraction of fluid accepted by layer or produced from layer during step 0.26 0.26 0.24 200 bbl ester injection 800 bbl push 2,000 bbl production 0.22 0.22 0.22 0.52 0.52 0.54 In the cross-flow model, a total of 160 bbls of water flowed from layer 1 to layer 2 during the shut-in period. About 95 percent of the tracer profile features were matched with the cross-flow model. The cross-flow model has an average SOR of 0.19. This effect, caused by cross-flow, is observed commonly in SWCT tests carried out in wells that have multiple sets of perforations. This effect was readily accounted for by using our mùlti-Iayer simulator. However, this transfer of fluids during the shut-in compromised the Sor results. Since the layer one ester placed it's push fluids back in the well-bore during the shut-in, we were unable to see any leading edge profile features for this zone and sensitivity to Sor is lost. Equally, since layer two received the bulk of the cross-flow fluids, the leading edges of the layer two profiles are -q-:- pushed into the tail of layer three. As a result sensitivity to Sor is poor in layer two. The plus or ~~ c_~~ Ininus three saturation unit sensitivity reported for Test 1 represents the layer three results, about one half of the test fluids. 11 IVlatching The SOR(LOSAL) Test Profiles The best-fit single-layer, ideal, model fits for the SOR(LOSAL) test profiles are shown in Figures 28 - 31 with an SOR(LOSAL) of 0.15. When compared to the equivalent fits for the SOR test, the layering effects are identical. The same cross-flow model used to match Test 1 profiles matched Test 2 profiles. One exception was the volume of cross-flow used for Test 2. In Test 1 the cross-flow volume was 160 bbls and in Test 2 the best-fit cross-flow volume was 130 bbls. This consistency in flow models between two consecutive tests is of course encouraging. The ability of the cross-flow model to match each of the tracers used in the two tests is also encouraging. As in Test 1, the Sor results are heavily weighted to Layer 3, which represents 520/0 of the test fluids. Unfortunately, the methyl acetate-methyl alcohol tracers could not be interpreted for SOR(LOSAL) in Test 2. The high levels of methanol in the produced water used to carry out Test 2 had very high background levels of methanol that were not constant during Test 2 injection. Figures 29 and 33 show the MeAc-MeOH profiles for Test 2. The large peak on the leading edge of the !vleOH profile is MeOH contaminant that came from the produced water manifold during Test 2 injection. CFSIlYl Best-Fit 3-Layer Model Sor and SOR(LOSAL) Tests The best-fit parameters for the Test 1 and Test 2 models are. given below in Table 3. 12 '-~~ ~---- '~~-~ "?""", r ..?-~ ~~ " ---' ~ '~~ .--:-:~ ~. ,.- ~~ L,-__[;""'" ~.~. Table 3; Best-Fit 3-Layer Model Parameters Parameter Number of Sub-zones Fraction of total volume Test 1 Best-fit Model Input, SOR 3 entering zone during 0.22 ester injection phase Fraction of total volume entering zone 1 during push injection phase Fraction of total volume produced from zone 1 during production phase Oil Saturation in Zone 1 Fraction of total volume entering zone 2 during ester injection phase Fraction of total volume entering zone 2 during push injection phase Fraction of total volume produced from zone2 during production phase 0.22 0.22 0.19 0.26 0.26 0.24 13 Test 2 Best-fit Model Input, SOR(LOSAL) 3 0.22 0.22 0.22 0.15 0.26 0.26 0.24 Oil Saturation in Zone 2 0.19 0.15 Fraction of total volume entering zone 3 during 0.52 0.52 ester injection phase Fraction of total volume entering zone 3 during 0.52 0.52 push injection phase Fraction of total volume produced from zone3 0.52 0.52 during production phase Oil Saturation in Zone 3 0.19 0.15 Reaction rate 0.043 0.035 constant (days-I) V olume weighted average Sor 0.19 0.15 The cross-flow model is pictured below: 14 ~ Well Bore =~ Low I Pressure : Zone I I I Medium Pressure Zone ~t~~ High Pressure Zone -.~ ~ Well Bore Injection Zone 2, 26% of fluids 1 Low ). Pressure Zone ~ ' '~ill' ,.. ,...,..~ ,WÆ ,~, ,diOOl~ffi¥.~jWgÆm,JfØ ....... "-- Zone 3, 52% of fluids Medium Pressure Zone :--- ~ Zone 1,22% of fluids High Pressure Zone ) -~~ ~ -~ ~ Well Bore Shut-In Period ~. 130 bbl Cross-flow Low Pressure Zone --- A . *... v, "7:: Medium Pressure Zone '- High Pressure Zone - c=~ 15 ~ Well Bore Production t A : Zone 2, 24'lc OftlUlds I Low I Pressure : Zone ~.:m2:~~f::~~~f:~~}!:3t¡!~i~;I·~nfW;~;ª~~*Hfm0~;' :Ø!@tJ:iRMHgf:~~1@j;gtJ~mr n ~~~~~;f~ ! Medium i Zone 3.54% of IlUlds Pressure i Zone ". MffW.<WffiV&Æ ~1WY.~~.llim'ø.~~~~ "ili~j~.mr:Ø. % J:1mr~'@wÆ~~JffiW.rWæw~ðAWÆ~~ ^ Zone], 22% of tluids High Pressure Zone GENERAL CHARACTERISTICS OF THE SWCT TESTS AT L-Ol Hydrolysis Reaction Rate The fraction of ester reacted depends on hydrolysis reaction rate, which vanes with reservoir temperature, ester distribution coefficient, and SOR. The total conversion of the ester is listed below. Table 4: Ester Hydrolysis Esterffest Shutin time ~ Al110uütöfEster Converted to- Alcohol Ethyl Acetate/ SOR Test 1 3.3 days 11 % Ethyl Acetate/ SOR(LoSAL) Test 2 5.9 days 100/0 16 Investigation Depth Radial depth of investigation of each chemical tracer used is shown in Table 5: Table 5: Investigation Depth --=-/ Radial Depth otil1vestigation - Tracer SOR Test SOR(LoSAL) Tèst Ethyl Acetate (reactive) 8.1 feet 8.5 feet Methyl Acetate (reactive) 9.8 feet 10 feet N-Propyl Alcohol (cover) 11.2feet 11 feet Iso-Propyl Alcohol (Mat. BaL) 11.3 feet 1 L 1 feet =-==="" ...---' '--¿# The portion of Ivishak reservoir tested was about 17 feet in diameter and 108 feet talL The pore space tested for low salinity water injection response was about 600 bbls. Dispersion The dispersion used to match the L-O 1 results was 0.6 feet (cell size). This translates to a dispersivity of 0.3. ""'--=---- '---~" ~ '~ -~ "'=?'" 17 INTERPRETATION SUMMARY The following summarizes the observations made during interpretation: SOR was detennined with fair precision from both Test 1 and Test 2 production profiles. Both SWCT Tests 1 and 2 profiles were matched to a simple cross-flow model. The value obtained for SOR or SOR(LoSAL) was not affected by the choice of simulation model. Sensitivity to SOR and SOR(LoSAL) is fair, plus or minus three saturation units or better for 520/0 of the test fluids. CONCLUSIONS The two reported Single Well Chemical Tracer Tests 1 and 2 for residual oil saturation, SOR and SOR(LoSAL) respectively carried out at the WOA, L-01 show excellent profile definition and fair sensitivity to oil saturation. Both tests quantitatively detennined oil saturation within the reservoir pore volume penetrated by the tracer carrying fluid (about 600 bbls of pore space investigated). The only notable feature of either test is the cross flow features observed. The cross-flow movement of fluids during the shut-in period re-arranged the tracer fluids in two of the three zones recognized and caused about 480/0 of the test to lose sensitivity to SOL The remaining 52% of the fluids, zone 3, did however accurately measure Sor before and after the low salinity water flood within a confidence level of three saturation units. The primary objective of this series of SWCT tests was to evaluate the perfonnance of a small low salinity water flood carried out at well L-O 1. The results show that the initial oil saturation is 0.19 and the post-low salinity water flood oil saturation is 0.15, a 21 % reduction of pore space oil conten t. 18 ~ -.-"-~' References '-'-:~ 1. Deans. H. A., S. Majoros, "The Single Well Chemical Tracer Method for Measuring -"~~ Residual Oil Saturation", Final Report. Report No. DOE/BC/20006-18. (October 1980). ,,---::-.-.' -'----~ ~.~ 2. Deans, H.A., Carlisle, C.T., "Single Well Tracer Test in Complex Pore Systems," --, SPEIDOE Fifth Symposium on Enhanced Oil Recovery. Paper 14886. (April 1986). 3. Deans, H. A., "A mathematical model for dispersion in the direction of flow in porous media," Soc. Pet. Eng. J. (March 1963) 49-52; Trans., AIME, Vol. 228. .~ \ ·'c=' --.-) "~~\ '=>' -.- .-~" -} ·;-O-~'i "'~¡ \ ,i .-==~; -'-~ '~ :,J 19 \---¡ (C~) . . Â . . o 200 Â . .. 400 . . .. . 600 1 and EtAc SWCT 1 Field Â . . I . ~. . . . . tA Â 2000 ............................................ . 800 1000 .. . . . . .. . . 200 1600 1800 1400 .. ....,..,....... .............................................. 1 III III III Á .. III . E Q, Q, Á Á " . III I III . . III Á " III . . Á III . .. III III I) « ( ::¡¡¡ . . III. .. III 400 600 800 1000 1200 600 800 2000 Barrels bbls 1000 800 E Q. Q. <t. .. CL. 600 Z c:: 0 .. ~ - 400 c:: Q) (,) c:: 0 U 200 . . . . .. .. . o o . 200 400 Figure 3 NPA Material Balance Tracer L-01 SWCT Test 1 for Sor Field Measured Data . . .. . . . -------_._.~--- - ---..-'-.---- .. . .. . .. . . . . The cover tracer, normal propyl alcohol (NPA), field data are shown here. NPA tracer was placed in the first 200 bbls of the SWCT test injection water. The same 200 bbls also carried the Ethyl Acetate into the reservoir. The purpose of the NPA tracer is to serve as a cover or reflector of the Ethyl Acetate shape and position in case the Ethyl Acetate is distored because of solution stripping or excessive hydrolysis reaction. . . . . ... . . ...--------¡---.---.-- ..,,,- I . . . . 1200 -"--------r--·-~--~··-'T-------~'_r---·-·----·----···-__¡-··-- ---~ 1800 600 800 1000 Barrels Produced 1400 2000 1600 ............................................ ......_.~...___..~.J_.,_.... .......-..-...... ............ 4500 , 4000 3500 E C. C. 3000 <~ 0- c: 2500 0 ;:; ca 2000 ~ .. c: () 0 1500 C 0 (J 1000 500 0 0 . 200 . ... . . . 400 Figure 4 IPA Material Balance Tracer L-01 Sor SWCT Test 1 Field Measured Data .. . III . . . .. ~ .. . . . . . . 600 800 1200 1000 Barrels Produced The material balance tracer (IPA) field data are shown here. MeOH tracer was placed in all of th~ SWCT test injection water to distinguish the SWCT fluids from formation fluids. . .. . .--.. - .. . .. 1400 1600 2000 1800 600 500 1400 1300 200 100 000 900 800 700 600 500 400 300 200 00 o o . . . . . . . . .. . 800 . II . .... . .. . . . .. . . 200 400 600 1000 1200 .. .. .... . 1400 600 1800 o 2000 1600 1400 1200 800 1000 600 400 200 ............................................ ...... ............................................. .......... 000 600 « CI. Z . . . a . . .. . 400 · a . . . . . .. 600 . .:., II . . . . . . . . . . .. . .~ . ~ . .. . :. . . 800 1000 Barrels 1200 bbls 1400 1600 1800 2000 Á . . o 2000 ............................................ 1 . Á 200 600 1000 800 1200 1400 1600 1800 400 . The reactive tracer, methyl aelate field data and product tracer, methyl alcohol, field data are shown here with simulation results from the best-fit model. The simulation results are shown as a solid line. Sor =0.22 in the Ideal model. E Q. Q. . . . . . . . 400 600 800 1600 2000 1800 1000 Barrels 1200 bbls 1400 E Q. Q. u « ( :¡: Figure 9 NPA Cover Tracer L-01 SWCT Test 1 for Sor Field Measured Data With Ideal Simulation Results 1000 800 Field data for the cover tracer, n- propyl alcohol, are shown here with simulation results from the Ideal model. The simulation results are shown as a solid line. E Q. Q. <i a.. 600 Z t: o ;; co L. ... t: Q) () t: o o . . 400 . .. .. . 200 o o . 400 800 1000 1200 Barrels Produced 200 600 1400 1600 1800 2000 ............................................ ....-.~.~.~..-....--...~...:.._.,. ........ ..-. ..... ...... . .. . .... .... ..... . . _' _n __.,_ _..,~.. ,,___ _.,,- '-',.,_ '~" .. .. .' " .. ,',' ,,- 4500 4000 3500 E Q. Q. 3000 <i c.. c: 2500 0 ;:¡ ca 2000 .. L.. - c: Q) (.) 1500 c: 0 (J 1000 500 0 0 . 200 . ... . . . 400 Figure 10 IPA Material Balance Tracer L-01 Sor SWCT Test 1 Field Data The material balance tracer (IPA) field data are shown here. MeOH tracer was placed in all of the SWCT test injection water to distinguish the SWCT fluids from formation fluids. .. . III . . . . ~ .. . . . . - 600 1000 1200 2000 1400 1600 1800 800 Barrels Produced 200 400 800 1000 1200 1400 ............................................ 1600 1800 2000 600 o ,¡\ The field data for the reactive tracer, acetate and tracer, Alcohol are shown here with the best-fit simulation results. The horizontal between these two tracers is used to determine SOL Simulation solid Sor:=; 0.22. . .. .. ,¡\ 400 600 800 800 1000 Barrels 1200 bbls 1400 1600 2000 E c. c. u « ;: :::ä5 Figure 13 N P A Cover Tracer L-01 SWCT Test 1 for Sor Field Measured Data With Best Fit Simulation Results 1000 ,- 1000 800 Field data for the cover tracer, n-propyl alcohol, are shown here with simulation results from the best fit model. The simulation results are shown as a solid line. -- 800 E Q. Q. <i . . . a. 600 - 600 Z s:: . 0 ;:; CO L. .... 400 s:: 400 CD . (J s:: 0 0 200 - 200 o o . 200 400 600 800 1000 1200 1400 1600 1800 o 2000 Barrels Produced ............................................ ........-....~.=.,...-..-.-..-. ....~.,._.~._....... ... ......... ..... . Figure 14 MeOH Material Balance Tracer L-01 SWCT Test 1 for Sor Field Measured Data With Best Fit Simulation Results E c.. c.. :i 3000 o Q) :E r::: o +:i 2000 ca L.. - r::: Q) (.) r::: 8 1000 . . . .. The field data for the material balance tracer,iso propyl alcohol (IPA), are shown here with simulation results from the Best Fit model. The simulation results are shown as a solid line. Sor=O.19. The IPA tracer was placed in all of the SWCT test injection water. 4000 . . . o o 200 400 600 800 1000 1200 1400 1600 1800 2000 Barrels Produced it, Total from all 400 600 1200 2000 400 1600 1800 800 1000 Produced ............................................ .......:.c..:.:.:.c... .......................................................... 400 1000 2000 1200 1400 600 800 600 800 4000 3000 2000 1000 Data With ~ ~~ Total produced from al! layers ~ 26% of ìnjeclion 200 400 800 1400 800 2000 1000 1200 600 600 ............................................ = 0.19 or 200 400 600 800 1000 1200 1400 1600 800 2000 40 20 00 200 600 1000 1600 800 2000 80 60 1200 1400 400 800 ....................................... .... o 200 600 1400 1800 2000 800 1000 1200 600 400 200 400 800 2000 1000 1200 1400 600 800 600 ..... ............... ...................... ...............:.,".....".............................................. .......... ................ .. ".' ".... 'u. 'm .' .. '. '.' .. ....... ...... ....... ....... .. . Â Â . 400 Â Â Â Â .. . . . " . " . - . . Â " . . . Â . . . . . . . 600 800 1200 1000 1400 1600 1800 2000 E Q, Q, J: o () ~ . 200 I . . 400 III II II III III III III III ü· . A . . A A II III III III A A III III II II 1600 1800 2000 E Q, Q, u « () ~ ............................................ III 600 1000 Barrels bbls 800 1200 1400 ....-.'.._............'~..._.~.]t]t=.~...... .... -........ 1200 ---------------- 1000 E 0. 0. 800 <i a.. z c: 0 600 - .. CO ~ .... c: Q) 400 U c: 0 0 200 I I 0 L 0 . . ... ,.. . . 200 Figure 24 NPA Material Balance Tracer L-01 SWCT Test 2 for Sor(LoSAL) Field Measured Data . .. . .. ~ .. . .. . . . . . . 400 600 --. ,.--.---------- ---~--_._-------- . . .. . . . . . . .... .. 800 1000 Barrels Produced ----~---- .-. ----------------------- The cover tracer, normal propyl alcohol (NPA), field data are shown here. NPA tracer was placed in the first 200 bbls of the SWCT test injection water. The same 200 bbls also carried the Ethyl Acetate into the reservoir. The purpose of the NPA tracer is to serve as a cover or reflector of the Ethyl Acetate shape and position in case the Ethyl Acetate is distored because of solution stripping or excessive hydrolysis reaction. .. .. . .. . .. . . . . . . ---í----·--··-~ ! --~-------·_--··-·--r··--·-- -T···--'-··--~-----··-·..- 1200 1400 1600 1800 2000 4500- ..-. 4000 3500 - E c. C. 3000· <i c.. c: 2500 - 0 .- - ~ 2000 - - c: CI) () 1500 c: 0 0 . 1000 .. 500 . o o Figure 25 IPA Material Balance Tracer L-01 Sor SWCT 2 for Sor(LoSAL) Field Measured Data . .. . . .. jII~.... . ..... . . -. . . 200 600 400 The material balance tracer (IPA) field data are shown here. MeOH tracer was placed in all of the SWCT test injection water to distinguish the SWCT fluids from formation fluids. ... ... . . . . .. . . .. '. .. . .. ..- . . 800 1000 1200 1400 1600 1800 2000 Barrels Produced ............................................ .... ....'..~..~... ... ..............................................' ............ 200 . 800 700 . 500 400 . . 400 800 600 1000 800 . 600 . . . . . . II & 400 ¡ 200 I I 1200 o 2000 1600 1800 1400 200 200 "1000 '" E 800 Q. Q. . t '" 600 . ! . .. « . '" a.. 400 . t *t z . . . '" * t '" '" 200 . . . 400 600 800 1000 1200 Barrels bbls 600 1400 800 2000 ........................ ................... .......;.' /..c... ............................................. ..1............. 400 1000 800 1200 1400 1600 600 800 2000 ........ and MeAc 2 With The reactive tracer, methyl actate field data and product tracer, methyl alcohol, field data are shown here with simulation results from the best-fit model. The simulation results are shown as a solid line, Sor =0.15 in the Ideal model. o « () :e E 0. 0. 400 600 800 1000 600 2000 800 Barrels 1200 bbls 1400 ............................... ... _-=-... ... ..._._............ ..i._.,~..!.~._.___._.. ........ e..... Figure 30 NPA Cover Tracer L-01 SWCT Test 2 for Sor(LoSAL) Field Measured Data With Ideal Simulation Results 1000 800 . . .. . .. . E c. c. <l 0.. 600 Z C o .. ca ~ - c Q) o c o (.) 400 . . .. .. . .fII 200 . o - o 600 800 1000 1200 Barrels Produced 200 400 Field data for the cover tracer, n- propyl alcohol, are shown here with simulation results from the Ideal model. The simulation results are shown as a solid line. 1400 1600 1800 2000 4500 4000 3500 E Co Co 3000 <t.~ 0.. r:: 2500 0 :;; CO 2000 ... .... r:: Q) (.) 1500 - r:: 0 0 1000 500 0 0 Figure 31 IPA Material Balance Tracer L-01 Sor SWCT Test 2 for Sor(LoSAL) Field Data .... . . .. . . .. .,.~.-: . . . . . The material balance tracer (IPA) field data are shown here. MeOH tracer was placed in all of the SWCT test injection water to distinguish the SWCT fluids from formation fluids. . . . .. . . . 200 600 2000 800 1200 400 1000 1400 1600 1800 Barrels Produced ............................................ ·.....:- .............. ............... ................. . o 400 600 800 1000 1200 1400 600 1800 2000 E a. a. '" '" '" The field data for the reactive tracer, acetate and product tracer. Alcohol are shown here with the best-fit simulation results. The horizontal between these two tracers is used to determine SOL Simulation solid Sor 15. 1400 600 800 J: o Q ~ '" III III '" 200 400 600 E a. a. o < Q ~ 2000 ........................... ................ 800 1000 1200 Barrels bbls .-=-_..-....:...¿n~.·-L.·. ...,.-.,....-....-.. ...._...'. ...¡. Figure 34 NPA Cover Tracer L-01 SWCT Test 2 for Sor(LoSAL) Field Measured Data With Best Fit Simulation Results 1200 1200 200 . Field data for the cover tracer, n-propyl alcohol, are shown here with simulation results from the best fit model. The simulation results are shown as a solid line. 1000 1000 E c. C. 800 <i 0.. Z c o 600 :¡:; CO r... - C Q) o 400 C o U - 800 - 600 - 400 . . . . 200 o o 200 400 600 800 1000 1200 1400 1600 1800 o 2000 Barrels Produced 4000 E Q. Q. :i 3000 o CJ) :E c: o ;:; 2000 CO .... - c: CJ) () c: <3 1000- o o Figure 35 MeOH Material Balance Tracer L-01 SWCT Test 2 for Sor(LoSAL) Field Measured Data With Best Fit Simulation Results . The field data for the material balance tracer,iso propyl alcohol (IPA), are shown here with simulation results from the Best Fit model. The simulation results are shown as a solid line. Sor=O.15. The IPA tracer was placed in all of the SWCT test injection water. . .... .. . ... . . . . . . 200 400 1800 2000 600 800 1000 1200 1400 1600 Barrels Produced ............................................ ............................................ Results Total 3 in text 200 400 600 1000 2000 1200 1400 1600 1800 800 800 600 400 Total from all 200 400 600 800 1000 200 1400 1600 800 2000 ............................ . ............. 4000 3000 2000 000 8 T atal produced from all layers . 8 8 26% injection Sor O. .. 200 400 800 2000 1000 1200 1400 600 800 600 39 200 400 1000 = 0.15 or 600 800 1200 800 2000 1400 600 ............-........... .................. 200 400 1000 800 2000 1200 1400 1600 600 800 20 TABULAR FIELD DATA FIELD JOURNAL FIELD OPERATIONS SWCT TEST SIlVIULATION MODELS SWCT TEST METHOD AND INTERPRETATION APPENDIX E APPENDIX D APPENDIX C APPENDIX B APPENDIX A APPENDICES -- -5~ -~ ~ -~ ~.- '-"'t"~ c~. ~ ~ ~ ~. .~--...---:-' ~ "0.1 APPENDIX A S\VCT TEST METHOD AND INTERPRETATION The Single Well Chemical Tracer (SWCT) test is a method for measuring fluid saturations in oil producing reservoirs. Chemical Tracers, Inc performs the test as a contract service. The SWCT test is carried out on a watered out formation interval by injecting, and then producing ~8'=:::> ~ =o,=:::> o=o,=:::> 0 08=00°=00°= ~ 0 '0 ~ 0'0 ~ 0 ':::> ° = = ° 0 üOqüO_ooo~ooogoo~goo~ogpo~ =8'0°=0'=:::> =O'=:::>o 00= 00=°00= Q 00';2, 2; 00 '60~00 ':::> 0000=000000 0°00=0 -0.0'-''0 0-0 - co 0D~ 0D 0 0D""" =8'0 ~ =0'=:::>°=0'0 ¿ oC8=0 00= 0= 0= ~0'0~0'0~0'000=0 00°0 ~OqoO~ooooOqoopo~noO~ooPO~ A ·Watered Out Test Zone, 10 to 100 ft. v ~8;>"'"~0,& o~o;> 0 c.:8~ooo~<7c.:0~ ooq'60~Oo~~Oo~goo~goo~ogpo~ r',':=2R~_oc~e~_ ~o~_o _c:0':? _C:05?0~09 back from the same well, a volume of reservoir fluid labeled with appropriate chemical tracers. In the case of a single well residual oil (SOR) test, as reported here, a volume of water containing a suitable ester (ethyl acetate in this case) is injected into the target zone of the test well. A larger volume of water that does not contain ester is then injected to push the ester- carrying water until it reaches a position five to fifteen feet into the reservoir (5 to 15 feet radius from the well bore). 21 :.'-:'F" ~-J -~. ~'="!!I'..-. '"~ "~ ~' .-. - .,..- ?::~: ¥ ~:~ ''c''~' The total volume injected IS typically labeled with a suitable non-reactive, non- ~8'=:> = =o,=:> o=o,=:> ° 08=° 00= C7 00= 000'=> 0=08'=>0,,';...,=> <7.!?r-,C7_~00C70 <7åoo Oo¿? o~ """,,00 """" t =8'=:>0=0'=:> = Water 00=°00= ~O,=>~O,=>"'=: 70C700C7 q,..oo oQ0o.0o 00 Containing 000 0000 0.0 '-J "'" 0.0 <7 0.0""'- =8'0 = =o'=:> 0= 1 % Ester (0) 0°=<7= 0= ooo'=> 0=0°0 '=>ò Uo ~V' 00 00' 00C70 <7 å0C70 \ ~ nO ~ 0 IDÔ?gÔO.n ~_ On <o-.c \~ IDo[ 0001 Displaced \~ IDOWJDol \ ~ . Injected IDOL ooo~ Þ \~ \-Vater ,000000. Formation ~ .0000001 188gggg. Water =8'=:> = =o'=:> o=o,=:> ° °8"=°0°= C7 00= ooo'=> 0""'08'=>000'=> <7 å00<700C70 <7 åoo 00 ¿? 0 ~ 00 """" ° """" 00 """" ............9R~_O~O~_ ~O~_o _c:..09 _c:..09°C?0Ç? partitioning (material balance) tracer, iso-propyl alcohol (IP A). During a shut-in period of one to ten days, a portion of the ester reacts with the reservoir water and forms ethyl alcohol (product tracer). The ethyl alcohol is virtually insoluble in the residual oil. The shut in period is designed to allow a measurable amount of ethyl alcohol to form. Typical ester to alcohol conversion is from 10% to 50%. ~8~ = ~o,& 0c; ~~ . ~~ - ;70= C7 00= o oo;g 0__00 'gc PortIon of :)0':0 goåo:J:? ~8~0~0~ c; Ester (0) 70=°00= 000'6000'gc forms !Joågåoo --0.0 '0 0.0 ~ .0 <7 0.0"'" =8'-:> "'" =o,=:> °c Alcohol (. ) 70= C7= 0= aoå'=> o""'db '=>000" V' 000<./ 00C70 <7 åoo -=- nO/"? 0 '.Ô~gÎIOf' n ~ Q n <o-.c :~~~~~~: Displaced .0.0.0., ..0.0.0, .~~~~~~I ·0.0.0.· ~8~ "'" ~o,& o~ö;:> 0 ~8?0 oo~ C7 ~o~ oOq'60__00'6~00~goo~goO..".ogpo~ ............<=2R~o~o~_ ~o:?_o _c:..°9 .c:09o~09 Injected Water Formation Water After the shut-in period, the well is back-produced. The produced fluid is periodically 22 sampled at the wellhead and immediately analyzed for content of the un-reacted ethyl acetate tracer, the ethyl alcohol tracer, and the material balance tracer, IP A. At the beginning of the production step, the un-reacted ethyl acetate and the product ethyl alcohol tracers are superimposed, located about 5 to 15 feet from the test well bore. Partitioning of the Sample Analysis~ . '~8'0"'=0'00=0'0 0 08=°00==00= \)=oo'60=ng';?,~On'0 q¡{nOnqnn=oqåoOo l' =8~ ° c Un-reacted Ester (0) and bo~ ,=>o'\::::) 00 q,..c;~o ~~ Product Alcohol (.) Separate Pû°..,p ~80 '0 C During Production ~o or;? \)OO~c~u~u~u~ouuu~uu~ooOo t: ^~ ~ ~:.~~~~O~~~" ~- ^ ~ /:...'- . ., ~ 00 0 ~ ~~:·kJ·~o~ ( '- '- .1 I(] 0 01 r".~.:J 01 ~8~ '" ~0'2? Q~D~ 0 ~8r;?° 00;;? = ~0r;? 0000'60.=-°0 '6q,.Oo ': g oQ2g oO-=. ° gpo~ ~~R~_Q~o~_ ~o~_Q _c:..0<;? _c:..0<;?0c:::'0S? un-reacted ethyl acetate tracer between the immobile residual oil phase and the mobile water phase delays production of the ester by an increment of volume directly related to the residual oil saturation. The product alcohol tracer, however, is not delayed, and flows back to the well at very near the same speed as the water. Since the ethyl alcohol does not spend time in the stationary oil phase, it is produced earlier than the ethyl acetate tracer, resulting in a separation between the product alcohol and un-reacted ester tracers. This chromatographic separation is observed in profiles of tracer concentrations vs. produced volume, as shown below. The amount of separation between the two tracers is used to calculate residual oil saturation. SWCT test results from high SOR cases show a large separation between the product alcohol and ester. Test results froIn low SOR cases show a small separation between the product alcohol tracer and ester. -')'..) .;...J -~ £~.-:~ ._~~. ~~ -~~ ·cc-r -;.,~ ~~ '--=-, . :~~- - .I~ -~'-: ~ -.'-. .--------..-.--.---.-----..-....---..-.-.----------.----_._~-_._._--_._-------_..._---_._-- Alcohol E Product §: Tracer Injected ^ ¡pI>OJq¡ - :.; ~ "\ 06' ~\ I Ester 0 Co) A A 8 !II ...c:::: t; A 'l 8 % Tracer - 8 ~ A ~ 8 'òo :;:; ¡: A 'l8 0 """-< .~ ð l' \ ¡: - ~!II £ j j: '\ <\.~. ~ ¡: A 41~ <bOq¡ _ ~ U A e16e <O<bo § A . ~16~~M"M"'M.AA"'AA.<bq¡::~~ U Volume Produced, Barrels E c.. -c.. In actual practice, a second non-reactive alcohol tracer, such as nonnal propyl alcohol (NP A), is added to the volume of water that carries the ester into the reservoir. This second material balance or cover tracer uniquely identifies the ester-water bank and allows for interpretation of the test in the event that all of the ester reacts, or that some of the ester is stripped away by gas breaking out of the produced water or by gas-lift gas. SWCT tests are non-destructive; after the production step, the fonnation is returned to its original condition. The test procedure can be repeated on a given completion as many times as needed without altering the fluid content of the pore space investigated. This non-destructive feature allows oil saturation measurements before and after an EOR injection from a single welL This test-inject-test strategy was employed on the L-Ol well to evaluate the performance of a low salinity water flood. The oil-water partitioning coefficient (K-value) of the ester, an important variable in test interpretation, is measured in the laboratory prior to the test. The K measurement is performed at reservoir conditions, using samples of reservoir oil and test water. In ideal cases, the SOR results can be calculated directly from field measured tracer concentration vs. produced volume profiles, by using the measured K-value and the degree of separation between the secondary tracer and the ester peaks. A more rigorous interpretation is 24 made through Inathematical modeling. Simulated SWCT production profiles are compared to field SWCT production profiles. A best-fit value of SOR is obtained from the simulation model. Simulation allows the interpreter to compensate for complications such as ester reaction during the flow period and K-value concentration dependencies, and to address possible flow irregularities encountered during the test. A more rigorous explanation is offered below. This version is based on the theory presented in "DETERMINATION OF RJ;:SIDUAL OIL SATURATION", Interstate Compact Commission, 1978, (pp 156-176). The basic mathematical premise used to calculate Sor from SWCT test results follows. Residual oil determination is identical theory with oil serving as the mobile phase and water as the stationary phase. The following explanation serves as a general explanation of Sor measurement. Let: Vi = velocity of tracer i moving through the pore space of the reservoir occupied by water. Vw = velocity of water in pore space. V 0 = velocity of oil in pore space. Pi = probability of tracer i being in water phase. I-Pi = probability of tracer i being in oil phase. Ki = partition coefficient for tracer i = Ci (oil)/Ci( water). Ka = partition coefficient for ester tracer. Kb = partition coefficient for ester hydrolysis product alcohol. Ci (oil) = concentration of tracer i in oil phase at equilibrium. Ci (water) = concentration of tracer i in brine phase at equilibrium. ni (oil) = number of i molecules in oil phase at equilibrium. ni (water) = number of i molecules in water phase at equilibrium. Sor = residual oil saturation. Sw = water saturation = I-Sor. During the injection and production steps of a SWCT test, the tracer i moves at the following rate: 25 -"ø ~ - - ::--~- :---r' r~ ~-. '-- --~ --~ ~' =-~ Vi = Pi Vw + (l-Pi)Vo (1) Since V 0 = 0 for a reservoir at residual oil saturation equation (1) may be restated as Vi = Pi Vw (2) The number of i molecules in the oil and water phase at a given point in time is related to the fraction of the pore space occupied by each phase and the concentration of tracer i in each phase, l.e I-Pi = ni (oil) Pi ni (water) = Ci (oil) Sor = Ki Sor Ci (water)Sw I-Sor (3) For simplicity let Ki (Sor)/( I-Sor) = ß where ß is the tracer retardation factor. This term is an expression of the relative velocities of the partitioning and non-partitioning tracers. Combining equation (2) and (3) the result is Vi = Vw/(1+ß) (4) In an SWCT test, this velocity is measured indirectly by measuring the volume required to produce tracer i from the reservoir. Since Vi ß ex 1/ Qi (5) where Qi = volume required to produce tracer i. During the production step of an SWCT test, the ester (tracer a) and hydrolysis product (tracer b) are being produced from a common point about IS' into the reservoir to the well-bore and surface. The volume required to produce each of these tracers is carefully monitored. Ka and Kb are measured in the laboratory and found to be: Ka> 0 (generally 2.0 to 8.0) Kb ::::0. For ethyl alcohol Kb = 0, and ßb = 0, so equation (4) becomes 26 Vb = VW/(1+ßb) = Vw (6) and considering equation (5) Vb ex: l/Qb (7) The volume required to produce ethyl formate is Qa and Va =Vw/(1+ßa) = Vb/(1+ßa) and from equation (5) and (7) VbNa = QaJ Qb = l+ßa In summary, ßa = (Ka)Sor/( l-Sor) and Sor = ßa /(ßa +Ka 27 0* -~.c.~ ~ ~. APPENDIX B SWCT TEST SIMULATION MODELS The program CFSIM mathematically simulates fluid flow during a Single Well Chemical Tracer test with a finite cell model. The model assumes radial flow in the test zone. Dispersion operates on the tracer fluids as they move through a system of mixing cells. Each cell is sized to accommodate the interval being modeled. Tests using one reactive tracer, and one product tracer can be modeled in a single run and the K-values are changed with variations in concentration of the tracers. This program allows parameters such as interval size, dispersion, and Sor to be operated independently in as many individual sub-zones (layers) as needed. SSIM also allows fluid produced from one zone to be injected into Qther zones during the shut in period of the test. This feature simul"ates cross-flow through the well-bore caused by subtle pressure differences in a layered reservoir. The program 2D5TRAMS is also a finite difference model. This model assumes radial flow in the test zone. The 2D5TRAMS program is capable of simulating cases with drift due to production or injection elsewhere. Dispersion, both radial and angular is proportioned to the magnitude of local fluid velocity. Tests using up to three tracers - a material balance tracer and two esters with or without product alcohol - can be modeled simultaneously and the K-values are changed with variations in concentration of the tracers. This program has a multi-layer feature that allows simulation of cases with heterogeneous reservoirs. Fractions of fluid injected into or produced from each layer may be specified for as many layers as necessary for the test. For each layer, parameters such as interval size, dispersion, Sor and drift are operated independently from other layers. Simulation Models Available Exxon Production Research Company and the U.S. Department of Energy provided the original models for simulating SWCT results to Chemical Tracers, Inc. These computer programs are DRIFTSIM and TRACRL respectively. The DRIFfSIM model is capable of simulating SWCT test results where fluid drift is present. TRACRL was extended by Chemi·cal Tracers, Inc., to accommodate a wider range of non-ideal flow features. The modified model is called CFSIM (cross-flow layered sandstone simulator). CTI also developed a dual porosity simulator to interpret SWCT tests in carbonate formations. Details of these programs are given in Appendix A. Generating the Best-fit Simulator Model for SWCT a Field Test Interpreting a SWCT test requires matching a single simulation model to the material balance tracer (IP A), the cover tracer (NP A), and the ester tracer (EtF) profiles. The product alcohol tracer (EtOH) profile is then matched with the same simulation model by adjusting SOR. The flow pattern of a particular test is delineated when the same model successfully matches all the-tracer profiles. Since the apparent reason for the non-ideal symptoms seen in the reported tests is layering, CFS IM was used to obtain the simulation results shown in this report. The usual procedure is to start the simulation process with a single-layer (ideal) model, then add layers to improve the match between field profiles and simulated profiles. 28 After each run, the simulation results were compared to the field measured production profile data for the tracer being modeled. Following each comparison, adjustments were made in the model input parameters; and the process was repeated until the best-fit model was attained. Input Parameters for CFSIlVI Known parameters are: well bore volume, well bore radius, perforated interval thickness and porosity. Known chemical and test timing parameters are: rate and total volume of fluid injected; rate and volume of fluid produced; injected concentration for each tracer chemical; shut- in time; and partition coefficient for each tracer. . Unknown (adjustable) parameters are: number of layers, fraction of fluid injected, fraction of fluid produced for each layer; SOR, dispersion constant, and hydrolysis reaction rate fO,r each layer. The best-fit model for the IP A and NP A tracers is essentially independent of SOR. After these two tracer profiles are well matched, the final step is to compare the position of the ethyl alcohol field data with the best-fit model ethyl alcohol results for various SOR cases. The best-fit SOR is then selected. 29 ~~~ ¡.-'~ ~-- --~~~. ~~.' - - 'O-.:......~ ·3~·· APPENDIX C FIELD OPERATIONS This series of L-Ol SWCT tests were carried out in the Prudhoe Bay field Dril~ Pad L. During the test a small portable laboratory building was positioned near the test well, L-O 1, throughout testing. The water used for injection came from a one inch temporary line about 50 feet long that was built off of the L-I09i injection line. . A choke was added below the L-I09i Casasco value to control flow. Also a small meter run containing a chemical addition point, static mixer and Halliburton turbine flow meter was installed to add/mix the chemical tracers and measure water injection rates and pressure. Pure chemical was pumped during injection into the chemical addition point by means of small high-pressure injection pumps. Samples of the injection fluid were taken each 30 minutes during the injection and analyzed for tracer content on location to assure quality controL During production, the well was produced through the L-pad test separator. Samples were taken at the wellhead and immediately analyzed on site. For each sample taken, an accurate measurement of the total produced volume, bbls, was also recorded by noting the volume produced as indicated on the Net Oil Computer monitoring the L-Pad Separator. When combined, the volume data and tracer analysis of each sample was plotted in production profile fonn for interpretation and presentation in this report. 30 APPENDIX D Field Journal L-Ol and L-122 SWCT Test Series Water Injection-Sor, Low Salinity Water Injection-Sor (LoSal) Measurement August 10, 2003 Sunday: Charlie Carlisle, CTC, and Lonnie Schultz travel to Anchorage from Laramie, WY. Arrive PM. Accommodations at Puffin Inn August 11, 2003 Monday: CTC arranged for meetings with Bruce Smith, Frank Paskvan, Danielle Ohms on Tuesday. Visited stores in Anchorage for N. Slope field gear. August 12, 2003 Tuesday: LS attended NSTC schooL CTC met with above to complete planning for L-pad tracer work. August 13, 2003 Wednesday: CTC and LC traveled to slope on 8:30 charter. Met with Jerry Middendorf, Randy Selman. Acquired pick up, ID badges, and room at BOC Arranged for well site lab building with Tool Services, Jim, 4636. Located CTI equipment and S\VCT test chemicals at BOC warehouse. All looked good. August 14,2003 Thursday: CTC attended toolbox meeting with production grouplpad operators. Arranged for electrical connection to portable lab to be made. Lab delivered to L pad late PM. Met with L-pad operator, Tim Okonek, PM and discussed of SWCT testing plan. August IS, 2003 Friday: Electrical generator delivered to L-pad PM and John Trojan made necessary connections. CTI equipment delivered to L-pad PM. Cleaned lab building and started unloading CTI analytical equipment. CTI equipment in good condition after shipping related damage. August 16, 2003 Saturday: Met with Brad, Well Support and Stan Coleman Well Support WOA to make necessary connections from L-115i to L-122 and from L-I09i to L-01 well. Meter run, static mixer, check valve, sampling valves, etc installed in small one inch spool in Well Support shop near GC-l. Assembly completed late PM. Arranged for hydrogen and helium cylinder to be delivered to L-pad next day. Co1eville supply, 659-3198 was he source of the Hc and H2. August 17, 2003 Sunday: Hydrogen and Helium delivered to L-pad AM. Well Support group, Stan Coleman et al arrived AM and installed temporary injection lines. Pressure test failed because of pipe thread leaks. Well Support group returned to their shop with each spool to dress and reassemble each threaded part that leaked. Returned P1v1 and pressure tested. Test failed at 1,000 psi with several thread leaks. Each spool was taken back to \Vel1 Support shop to re-make each thread with BakerLok. Left spools overnight under mild heat to cure BakerLok. August 18, 2003 Monday: Installed each mcter run/injection line and pressure tested to 3,000 psi. Good shape. Closed casing valve on L-O 1 at 12:00 noon. Casing pressure dropped from 1,100 to 650 psi in about 45 rrúnutcs. Started produced water injection into L-OI at 12:50 PM. Rate was 1,500 bId. \VelI went on vacuum after about 20 bbls and pressured up to 1,250 psi after 138 bbls. Stabilized injection àfter 220 bbls at 1 ,500 psi WHP at 1,500 bId water injection. Continued produced water injection throughout night. Total injected by midnight was: L-O 1, 694 bbls 31 ~ August 19,2003 Tuesday: Continued injecting into L-Ol at 1,500 bId. Shut in L-122 at 8:30 and started injecting produced water at 10:35. Well accepted injection fluids with no noticeable problems. Initial tubing pressure, shut in, was 400 psi. Injection rate was intended to be 800 bId with a max WHP during injection to be 1,371 psi. Well started pressuring after 40 bb1s injected at a rate of 500 bId. Increased rate to 800 after 42.7 bbls and well pressured to 1,450 after 58 bbls. Slowed injection rate to 540 and WHP continued to increase to 1,500 psi. Called Bruce Smith in Anchorage and discussed parting pressure. He said that the recorded breakdown pressure for the Borealis was 2,200 psi. Continued to inject with an elevated maximum WHP, 1,700 psi. Rate was maintained at 450 bId and WHP stabilized after 150 bbls were injected at 1,620 psi. Well-bore volume for L-122 is 78.7 bbls. Well bore volume for L-Ol is 147.4 bbls. Total produced water injected by midnight was: L-01 2184 bbls L-122 270 bbls Johnny Brown, IB, and Ray Carlisle, RC, arrive in Anchorage. Accommodations at Puffin Inn. ~-~~ August 20, 2003 Wednesday: JB and RC arrive on the Slope via the 1:50 charter. Continued water injection on both the L-Ol and L- 122 wells. L-122 injection rate slowed to 350 BPD as WHP increased to 1650. After discussing parting pressure, maximum WHP was increased to 1900 psi from 1700, this allowed L-122 injection rate to increase to 800 BPDL-Ol injection rate was 1480 BPD at a WHP of 1700 psi. Total produced water injected by midnight was: L-O I 3634 bbls L-122 7 16 bbls ?~ . . .~---- . August 21, 2003 Thursday: Injection continues on both wells. L-O 1 after discussing parting pressure was increased from 1800 to 1900 psi. L-OI injection choke was opened all the way rate increased to 1600 bpd and WHP increased 1800 psi L-122 rate steady at 800 bpd. Total produced water injected by midnight was: L-015158bbls L-122 1589 '~ August 22, 2003 Friday: L-122 from 8:30 am to 3:00 pm 210 bbls of fluid was back produced; in order to clean up the perfs, improve injection, and remove any oil left in the well bore. At 3:00 pm injection resumed on L-122 at a rate of 800 bpd, well pressured back up and WHP was back to 1800 by midnight. Injection continued on L-O 1 with the choke all the way open. By midnight the total produced water injected was: L-O 1 6781 bbls L-122 2174 bbls -~.:.- August 23,2003 Saturday: Injection continued on both wells. Total injection of produced water by midnight was: L-O 1 8328 bbls L-122 2973 bbls ~~ August 24, 2003 Sunday: Injection continued on both wells. Total injection of produced water by midnight was:Ol 9830 bbls L-122 3717 bbls ~-- August 25, 2005 Monday: Injection of produced water was completed on L-122 at 8: 15 am total volume injected 3895 bbls. Then 305 bbls was back produced from L-122 in order to clean perfs and remove any remaining oil from well bore. Finished back producing L-122 at 12:30pm and started injecting tracer test by 1 :00 pm. Tracer test design was to inject 150 bbls of 10,000 ppm ethyl acetate, 5,000 ppm n-propyl alcohol, and 2,500 ppm isopropyl alcohoL Followed by 450 bbls of 2,500 ppm isopropyl alcohol. Due to a decreased manifold pressure the injection rate fell from 800 BPD to 550 BPD this caused the IP A concentration to rise to 8500 ppm. The first 150 bb1s was injected by 6:00 pm, the remainder of the test will continue through the night and finish sometime on the 26th. Injection continued on L-Ol until I: 10 pm, total water injected 10450 bbls. L-Ol was then back produced until5:30 am August 26th; total fluid back produced 419 bbls. ..~~ .- 32 August 26, 2003 Tuesday: Finished tracer push injection on L-122 by 3:40 pm, well will be shut in for 10 days to allow for reaction. Freeze protect called and arranged to come out the 27Ùl at 9:00 am. Injection resumed on L-O 1 by 8:30 am. Surface safety valve shut at 4:00 pm, total water injected by then 10,914. Injection resumed at 7:40 pm. Total volume injected by midnight on L-O I 11,254 bbls. August 27,2003 Wednesday: LS left the slope. Injection continued on L-01 manifold pressure decreased significantly rate dropped from 1,550 BPD to 1,100 BPD. Total volume injected by midnight was 12,781 bbls. August 28, 2003 Thursday: Injection continued on L-O I, manifold pressure started picking up by 6pm. Injection rate at midnight was back up to 1550 bpd and total volume injected was 13,995 bbls August 29,2003 Friday: Produced water injection continues on L-Ol, WHP holding steady at 1,750 psi with a rate of 1550 BPD. Total volume injected by eleven pm was 15,445 bbls. August 30, 2003 Saturday: LaneIle Carlisle, LC, arrives in Anchorage, accommodations at Barrett Inn. Injection on L-O I proceeds. Total volume injected by midnight was 16,915 bbls. August 31, 2003 Sunday: LC arrives on the slope. RC left the slope. Injection continues on L-Ol. Average rate, 1,450 bid. Total injected by midnight was 18,498 bbls. Sept. 1, 2003 Monday: Kory Kumer, KK, arrives in Anchorage. accommodations at Barrett Inn. Continued L-Ol injection. Arranged to put L-O I in test separator about midnight to back produce for clean-up. Total injected by start of back production was 19,967 bbls. Sept. 2, 2003 Tuesday: KK attended NSTC school. Start L-01 production for clean-up. Started at 12:21 AM. Produced 431 bbls by 11:00 A1v1. Found best arrangement for continuous lift was a full open production choke and 3.5 MMSCFD gas lift rate. Actual gas lift rate was about 2 MMSCFD because the gas-lift gas manifold supply pressure was low at 1,560 psi. Continuous rate was 2, 100 B\VPD. Started SWCT Test 1 injection at L-O I at 13:00 at 1,500 bid. Injected 200 bbls carrying ethyl acetate (EtAc), methyl acetate (MeAc), normal propyl alcohol (NPA), and iso-propyl alcohol (IPA), continued with 1,090 bbls total with last 890 bbls tagged with IPA only. Total injected by midnight was 690 bbls. L-122 shut-in for soak period. Sept. 3, 2003 Wednesday: KK arrives on the slope via charter. Completed L-Ol SWCT Test 1 at 06:33 with 1090.2 bbls injected. Freeze protect arranged for on Tuesday, scheduled for later in day. L-122 shut-in for soak period (10 days). L-Ol shut-in for soak period (3 days). Sept. 4, 2003 Thursday:L-122 and L-O 1 shut-in for soak period. L- 122 scheduled for POP on Friday AM. Sept. 5, 2003 Friday: L-I 22 POP at 8:46 am to produce tracer test. Methanol pump used for gas lift to prevent hydrate formation. Methanol pumped set at a 3% (30,000 ppm) concentration. Total production by midnight 738 bbls. Sept. 6, 2003 Saturday: L-122 tracer production stopped at 12:45 pm, 965 bbls produced. \Vell shut in at 12:45 and HBR started injecting low salinity water at a rate of 800 bpd. LO 1 POP at 2: 10pm in order to produce tracer test. Total barrels produced by midnight for L-O 1 was 567 bbls. 33 Sept. 7, 2003 Sunday: HBR continued to inject low salinity water in L-122. At 9:45 pm HBR finished low salinity water injection and started to rig up on L-O I, total barrels of low salinity water injected into L-122 were 900 bbls. Produced water injection started at 10:00 pm on L-122, 63 total barrels of produced water injected by midnight at a rate of 800 BPD. Continued to produce L-01 for tracer test, total barrels produced by midnight was 1481 bbls. Sept 8, 2003 Monday: Dan Dycus, DD, arrives in Anchorage, accommodations at the Barrett Inn. L-Ol production finished at 6:40 am, total barrels produced 1685 bbls. HBR started to inject low salinity water there after at a rate of 2000 bpd. Produce water injection continued on .L-122. Sept 9, 2003 Tuesday: DD attends NSTC school in Anchorage. HBR finished low salinity water injection at 10:00 pm, total barrels injected 2,900. Produced water injection started at II :30 pm on L-O 1 at a rate of 2000 BPD. Produced water injection continued on L-122, total barrels injected by midnight 1500 bbls. Sept 10,2003 Wednesday: DD arrives on the slope via charter. Produced water injection finished on L-122 at 19:50 total volume injected 2018 bbls. Well POP at 21 :00. Finished back production at 00:00 September 11, total volume produced was 203 bbls at an average rate of 1600 BPD. Injection line was blown out to with gas to prevent freezing. Discovered that 2" Halliburton valve on injection line was leaking. L-Ol produced water injection continued, by midnight 1700 bbls injected at a rate of 2000 BPD. September II, 2003 Thursday: L-122 well shut in until leaking 2" Halliburton valve was repaired. Began injecting second tracer test (after low salinity water) at 21:30 at a rate of 800 BPD. Tracer test design was to inject 150 bbls of 10,000 ppm ethyl acetate, 6,000 ppm n-propyl alcohol, and 4,000 ppm isopropyl alcohol. Followed by 450 bbls of 4,000 ppm isopropyl alcohol. The first 150 bbls was injected by 03:30 pm. The remainder of the test will continue through the day and finish sometime on the 12th L-OI produced water injection continued. L-Ol surface safety valve closed due to the pad beginning closed in, injection was stopped from 8:30 to 14:45. Valve was opened and injection continued at a rate of 2,000 BPD, total injection by midnight was 3,148 bbls. September 12, 2003 Friday: L-122 SWCT test 2 injection completed at 19: 1 O. Total injection was 640 bbls. Freeze protect carried out immediately, 35 bbls diesel. Completed freeze protect at 19:45. Shut in for 12 day soak. L-O] continued produced water injection. Total injected by midnight was 4,900 bbls. ~- .--, September 13,2003 Saturday: L-122 shut in. L-O I continued produced water injection at 1,900 BWPD. Completed 5,603 bbl injection at 9:50. Started back production for clean-up at 10:30. Produced 316 bbls by 14:00. Started SWCT test 2 injection at ] 9:30. Injection planned for was 200 bbls carrying ester pushed by 1000 bbls produced water with IPA only. Total injected by midnight was 195 bbls. September 14, 2003 Sunday: L-122 shut in. L-OI completed SWCT test 2 at 15:00, 1,090 bbls. Freeze protect carried out at 15:30,60 bbls diesel. Shut in well at 16:30. September 15,2003 Monday: L-] 22 shut in. L-O I shut in. September 16, 2003 Tuesday: L-] 22 shut in. L-O] shut in. Analyzed selected production samples from L-O I and L-122 test production to improve data quality where needed. KK left for home, PM. September 17, 2003 Wednesday: L-122 shut in. L-O I shut in. Continued sample re-runs. 34 September 18, 2003 Thursday: L-122 shut in. L-Ol shut in. September 19,2003 Friday: L-122 shut in. L-O I shut in. Charlie Carlísle, CC arrived back on Slope, PM. Arranged to produce L-02 into test header next day, Saturday_ September 20, 2003 Saturday: L-122 shut in. Started production of test 2 at L-O 1. Started at 13:00. Total produced by midnight was 602 bbls. September 21, 2003 Sunday: L-122 shut in. L-01 continued production of test 2. Total produced by midnight was 1,675 bbls. September 22, 2003 Monday: L-122 shut in. L-O 1 completed test 2 at 7 :30. Placed L-O 1 into production header and continued production. September 23, 2003 Tuesday: L-122 shut in. L-O 1 producing water into production header. September 24, 2003 Wednesday: Started production of SWCT test 2 at L-122 at 8:30. Total produced by midnight was 719 bbls. L-01 continued production until 13:00. Shut in to run shut-off/pressure recording tool for build-up test. Set timer to shut off production and start recording data at 08:00 on Thursday. September 25,2003 Thursday: Completed L-122 test 2 production at 15:37. Total produced 1,175 bbls. Continued production via production header until 20:00 when well was shut down to run pressure recorder/shut-off tool for build-up test. Ran drift to bottom successfully. Second slick-line run to set tool encountered ice at 1,200 feet. Unable to run tooL L-Ol, shut off tool appeared to stop production at 8:00 AM (well head started cooling). September 26, 2003 Friday: L-122 sent for hot-oil unit to thaw tubing. PI~n to freeze protect after thaw and wait until after pad shut- down scheduled for Sat. Sun. before producing more. CTI rigged down L-pad tracer lab, injection equipment and chemical drums. September 27, 2003 Saturday: L-122 Hot oil truck arrived and did not have enough fluid to thaw the tubing. Well shut-in for L-Pad shut do\'m. Rigged down Hot Oil unit. Rigged up BP methanol pump so methanol can be added to gas lift gas when L- 122 is returned to production. CTI Lab cleared and equipment boxed for shipment. CTI equipment taken to BOC warehouse for shipment to Laramie. Cleared off remaining containments, etc related to S\VCT testing & secured site. September 28, 2003 Sunday: CTC, LC and JB traveled to Anchorage, PM. \Vrapping up last details of report. September 29, 2003 Monday: Completed Report PM. Delivered to Kinko's in Anchorage to bind copies. September 30, 2003 Tuesday: CTC met with Frank Paskvan, Bruce Smith, Pat McGuire, Gil Buhler, Jim Young, and Doug Pollock, AM. Reviewed test results from L-01 and L-122. Delivered report copies to BP at 9:30 PÌ'v1. CTC, LC, JB departed Anchorage at II AS PM. October I, 2003 Wednesday: CTC, LC, and JB arrived home, Atvl. October 4, 2003 Saturday: CTI equipment arrived in Laramie, 35 ~ APPENDIX E TABULAR FIELD DATA The field analytical data recorded during the reported L-Ol SWCT SOR Test 1 is presented in tabular form here. These data are plotted in the Figures of this report and recorded here to accommodate data entry to other media. ~ BBLS. MeOH EtOH MeAc IPA NPA EtAc 0.0 68.0 78.0 9166.0 13.0 13.0 3870.0 87.0 1317.0 3984.0 " 99.0 342.0 3892.0 115.0 19.0 129.0 25.0 19.0 4844.0 14.0 53.0 140.0 4909.0 150.0 25.0 161.0 139.0 101.0 175.0 139.0 842.0 2232.0 540.0 961.0 185.0 195.0 205.0 215.0 76.0 225.0 76.0 682.0 3073.0 373.0 568. 0 236.0 246.0 256.0 267.0 81.0 .-;~ 278.0 81.0 604.0 3062.0 341. 0 518.0 292.0 71.0 304.0 55.0 600.0 3321.0 348.0 444.0 ~ ~- 316.0 327.0 60.0 337.0 65.0 594.0 3340.0 310.0 390.0 350.0 73.0 0.0 0.0 0.0 0.0 0.0 , - 362.0 539.0 3345.0 324.0 385.0 372.0 71.0 383.0 387.0 392.0 80.0 74.0 573.0 3448.0 325.0 437.0 402.0 416.0 '~~- 427.0 88.0 435.0 85.0 699.0 3426.0 376.0 554.0 445.0 449.0 463.0 101.0 475.0 485.0 93.0 657.0 3210.0 380.0 578.0 36 BBLS. MeOH EtOH MeAc IPA NPA EtAc 496.0 506.0 112.0 516.0 104.0 778.0 3249.0 455.0 682.0 531.0 540.0 545.0 111.0 699.0 3070.0 423.0 652.0 547.0 557.0 106.0 797.0 2956.0 489.0 696.0 567.0 107.0 112.0 572.0 776.0 2928.0 460.0 796.0 580.0 590.0 597.0 112.0 607.0 761.0 2724.0 487.0 767.0 615.0 625.0 112.0 632.0 109.0 643.0 113.0 859.0 2561.0 486.0 882.0 653.0 813.0 2630.0 518.0 826.0 662.0 670.0 679.0 108.0 963.0 2920.0 586.0 979.0 686.0 115.0 913.0 2775.0 568.0 961.0 686.0 697.0 109.0 708.0 714.0 124.0 115.0 900.0 2676.0 592.0 933.0 724.0 733.0 115.0 941.0 2637.0 622.0 998.0 737.0 753.0 765.0 102.0 768.0 118.0 949.0 2729.0 629.0 1042.0 780.0 792.0 800.0 111.0 1001 .0 2737.0 663.0 1111.0 803.0 814.0 823.0 102.0 828.0 845.0 105.0 976.0 2380.0 650.0 1060.0 866.0 886.0 906.0 105.0 981.0 2312.0 650.0 1068.0 926.0 99.0 940.0 957.0 97.0 952.0 2121.0 631.0 1037.0 977.0 1 001 .0 1021.0 90.0 90.0 855.0 1883.0 601.0 882.0 1057.0 37 38 - presented in tabular form here. BBLS. MeOH EtOH MeAc IPA NPA EtAc 0.0 90.0 1662 4443 108.0 285 4448 124.0 0 140.0 276 4730 19 153.0 167.0 314 73 1112 200 207 209 186.0 201.0 313 81 2109 361 325 283 216.0 356 0 2582 401 324 295 232.0 61 247.0 378 2833 412 328 245 260.0 364 45 3289 397 288 266 275.0 --=:~ r -'V-ð -0 _ ~, The field analytical data recorded during the reported L-O 1 SWCT SOR(LoSAL) Test 2 is -- ---==------:Y' BBLS. MeOH EtOH MeAc IPA NPA EtAc 1081.0 90.0 90.0 885.0 1863.0 644.0 881.0 1102.0 1124.0 84.0 84.0 814.0 1717.0 594.0 825.0 1146.0 1168.0 1190.0 81.0 81.0 703.0 1518.0 539.0 720.0 1210.0 1233.0 74.0 74.0 654.0 1358.0 512.0 671.0 ~ 1256.0 82.0 82.0 651.0 1381.0 489.0 662.0 1307.0 1333.0 86.0 86.0 591.0 1299.0 458.0 586.0 1362.0 64.0 73.0 511.0 1062.0 511.0 527.0 1381.0 c~ 1403.0 65.0 71.0 431.0 966.0 369.0 429.0 ~ 1425.0 76.0 76.0 381 .0 993.0 350.0 309.0 1438.0 67.0 67.0 422.0 964.0 363.0 415.0 1455.0 - 1481.0 1507.0 67.0 67.0 464.0 984.0 339.0 467.0 ._~ 1534.0 1562.0 76.0 61.0 443.0 900.0 274.0 469.0 1582.0 1604.0 78.0 59.0 384.0 850.0 282.0 402.0 1632.0 1656.0 55.0 55.0 323.0 704.0 206.0 365.0 1673.0 73.0 73.0 312.0 716.0 228.0 338.0 BBLS. MeOH EtOH MeAc IPA NPA EtAc 292.0 344 49 3011 404 304 212 307.0 350 0 3113 393 313 230 323.0 337.0 432 62 3329 478 333 264 352.0 367.0 591 0 3361 442 332 266 385.0 708 58 3250 454 377 293 400.0 771 63 3154 434 440 303 415.0 56 430.0 949 88 3297 501 350 264 445.0 866 0 3184 468 498 374 460.0 855 0 3261 529 449 387 475.0 757 92 3237 536 400 419 490.0 505.0 647 111 3188 627 513 454 520.0 651 115 3248 580 394 461 535.0 550.0 648 3213 590 519 484 572.0 590 132 3120 633 474 508 589.0 530 3033 614 425 535 602.0 649 136 3151 603 578 557 615.0 562 144 2953 622 583 543 628.0 644.0 599 149 3072 668 623 617 663.0 609 151 2954 668 617 640 675.0 621 2958 652 627 634 690.0 544 2792 686 664 626 705.0 584 156 3013 712 680 697 720.0 735.0 632 2918 799 727 771 750.0 589 155 2917 763 743 815 765.0 561 2769 750 761 797 780.0 569 2743 770 800 848 800.0 133 815.0 831.0 613 2642 830 738 917 845.0 674 123 2575 816 874 894 859.0 647 2510 828 798 881. 868.0 600 2301 851 846 834 886.0 533 100 2136 689 783 811 900.0 549 2268 771 825 843 925.0 605 2386 786 849 879 947.0 493 100 1861 672 744 730 969.0 560 2143 776 851 825 991.0 556 1978 732 771 804 1012.0 509 97 1675 694 737 703 1037.0 569 1888 750 751 763 1069.0 585 1925 715 770 790 1090.0 568 91 1754 675 746 732 1111.0 534 1569 590 697 657 1134.0 551 1641 602 700 682 39 "-~ 40 '-~ ~ -,-- -~: .,~ ".t"~' .~~ -.".. -. ~~ - - --- '--=-, ~~~ '~~ BBLS. MeOH EtOH MeAc IPA NPA EtAc 1160.0 503 80 1506 570 537 648 1181.0 451 1455 529 607 582 1195.0 450 1415 519 557 567 1213.0 489 1367 479 585 548 ~ 1252.0 485 1324 490 557 540 1279.0 439 1225 437 510 464 - 1308.0 469 1252 457 495 499 ~ 1335.0 372 1070 384 411 432 1391.0 385 1059 381 425 419 1434.0 407 83 1046 351 404 391 1478.0 424 68 940 311 347 350 1520.0 427 67 919 283 308 306 1564.0 399 68 959 249 307 284 -- 1612.0 370 55 793 251 200 285 1675.0 366 68 245 207 257 1734.0 349 70 722 233 189 267 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFichc\CvrPgs _ Inscrts\Microfilm _Marker. doc )E . REPORT OF SUNDRY WELL OPERATIO.N~R.r,ascQns. ~_..",..."'. 1 . Operations Performed: "'13;)1\" - Abandon 0 RepairWeliD PluQ PerforationsD Stimulate ŒI Other~chofage Alter Casing D Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionO Change Approved Program D Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 201-0720 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23011-00-00 7. KB Elevation (ft): 9. Well Name and Number: 76.70 L-o1 8. Property Designation: 10. Field/Pool(s): ADL-OO28239 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9528 feet true vertical 9208.6 feet Plugs (measured) None Effective Depth measured 9428 feet Junk (measured) None true vertical 9110.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Production 8255 7" 26# L-80 24 - 8279 24.0 - 7982.2 7240 5410 Production 1149 7" 29# L-80 8279 - 9428 7982.2 - 9110.0 8160 7020 Production 81 7" 26# L-80 9428 - 9509 9110.0 - 9189.9 7240 5410 Surface 2733 9-5/8" 40# L-80 27 - 2760 27.0 - 2601.4 5750 3090 Perforation depth: Measured depth: 9124 - 9136,9142 - 9180,9180 - 9210, 9220 - 9240,9252 - 9262 True vertical depth: 8811.13 - 8822.9,8828.79 - 8866.09,8866.09 - 8895.56,8905.38 - 8925.03,8936.83 - 8946.65 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 - 8763 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer @ 8706 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9124 - 9262 Treatment descriptions including volumes used and final pressure: 136 Bbls 9-1 HCL/HF Acid, 136 Bbls Clay Acid 64 Bbls 10% DAD Acid @ 1740 psig 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 260 0.01 46 1200 330 Subsequent to operation: 448 0.4 96 285 288 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development ŒI ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - ! OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature ~G ~ ûl. (:nk~ Phone 564-4657 Date 9/23/04 J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ RECE\\ p 2 9 200ft Form 10-404 Revised 4/2004 OR\G\NAL ~'i> ~~-- ~ 2 ~ ' <Jr! r---- .---... L-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/30/04 PUMP ACID TREATMENT AS FOLLOWS: FLUID PACK IA WITH 160 BBLS CRUDE. LOAD WELL WITH 150 BBLS OF SEAWATER AT 4.5 BPM AND INITIAL PRESSURE OF 2450 PSI. PUMP ADDITIONAL 50 BBL SEAWATER AND DO STEP RATE TEST AT 1, 2, 2.5, 3, AND 3.5 BBLS PER MIN. PUMP 50 BBLS OF 3% NH4CL @ 3.5 BPM, 1900 PSI, PUMP. (PUMPED FOLLOWING FLUIDS IN STAGES AS PER PROGRAM) 10% DAD ACID, 9-1 % HCL-HF, 3 % NH4CL, CLAY ACID, 30# HEC W/ 1 #/GAL DIVERTER STAGES. ALL STAGES PUMPED BELOW FRAC GRADIENT OF .66 PSI/FT. RATES VARYING FROM .75 BPM WHEN DIVERTER ON FORMATION TO 2.5 - 3.5 BPM WITH ACID BREAKS. DISPLACE WELLBORE WITH 109 BBLS OF NH4CL AND 38 BBLS CRUDE. TOTALS PUMPED: 200 BBLS SEAWATER, 50 BBLS 3 % NH4CL WITH ADDITIVES, 64 BBLS OF DAD ACID, 136 BBLS MUD ACID, 136 BBLS CLAY ACID, 750# WAX DIVERTER IN 24 BBLS OF 30# HEC. 109 BBLS NH4CL AND 38 BBLS CRUDE DISPLACEMENT. FINAL RATE OF 3.3 BPM, 1750 PSI ON DISPLACEMENT. FLUIDS PUMPED BBLS 136 9-1 HCUHF Mud Acid 136 Clay Acid 64 1 0% DAD Acid 50 3% NH4CL wI additives 560 3% NH4CL 560 Sea Water 200 Dead Crude 1706 TOTAL Page 1 ~ ìREE = 4-1/16" crvv L-O1 .---... WEll HEA D= FM:: AClUA TOR-,- KB, ElBl = 76,7' BF, 8..BI = KOP= 11 ()()' Wax Angle = 36 @ 2535' Datum M) - 9191' DatumlVD= 88()()' SS SAFETY NOTES: CHROMETBG& 7", 29# CHROME CSG @ 8279' - 9428'. ALL OTHER 7" CSG IN STRING IS 26#, L-80, BTC-M. 1021' HTAMPORTCŒ.LAR 9-518" CSG, 4û#, L-BO BTC, ID = 8,835" 2256' ST M) 6 3227 5 3504 4 5968 3 7571 2 8390 1 8627 Minimum ID = 3.725" @ 8750' 4-1/2" HES XN NIPPLE I 7" CSG, 26#, L-BO X 7" CSG, 29# BCRXO H ~ 8279' PERFORA liON SLMMA.RY REF LOG: PEARRAY INOJcrlON ANGLEATTOPPERF: 11 @9124' Note: Refer 10 Production œ for historieal perf data SIZE SA" INTERVAL Ocn/Saz DATE 3-318" 6 9124 - 9136 0 12/13/02 3-318" 6 9142 - 9180 0 12/13/02 2- 718" 6 9180- 9210 0 11/14/01 2-718" 6 9220 - 9240 0 11/14/01 2-718" 6 9252 - 9262 0 11/14/01 8695' 8706' 8729' 8750' 4-1/2"TBG, 12.6#, 13-CR, 0.0152 bpf, ID =3,958" 8763' 8752' 9092' 9428' T' CSG, 26#, L-80 BTC-M, ID = 6,276" 9509' 06. TE RBI BY COMMENTS 06. 1£ REVBY COMM:NTS 07m1/01 C WKAK ORIGINAL COM PlErION 11/14/01 TMI\VKAK PERFS 12/13/02 CAO/KK ADÆRFS 12130/02 DAC/KK GL V CORRECllONS 07107/04 06. V/KAK GLV C/O 4-112" I-ES X tIIP, ID = 3.813" GAS LIFT MANDRELS lVD DBI TYPE VLV LATCH 2923 29 KBG-2 DMY BK 3172 24 KBG-2 DOME BK 5595 0 KBG-2 DOME BK 7197 0 KBG-2 DOME BK 8016 8 KBG-2 DMY BK 8250 8 KBG-2 SO BK PORT 06.TE 0 11128¡Q2 16 11128¡Q2 16 11128¡Q2 16 11128¡Q2 0 07¡Q1¡Q1 22 071O7¡Q4 4-112" I-ES X tIIP,lD = 3.813" T' X 4-1/2" BKR 5-3 A<R, ID = 3,875" 4-112" I-ES X tIIP, ID = 3,813" 4-112" I-ESXN NIP, ID= 3,725" 4-112" WLB3, D =4,()()" H 8..M) TT LOGGED 11/14¡Q1 I RA TAG (8.. CORREcrED) PRLOHOE BA Y Ut\IT W8..L: L-01 ÆRMfTNo: 2010720 API No: 5O-029-23011-()() SEe 34, T12N, R11 E, 239Z NSL & 3659' WEl BP Exploration (Alaska) / tt-v.; . ,L~ u ) f DATA SUBMITTAL COMPLIANCE REPORT 7/30/2003 Permit to Drill 2010720 Well Name/No. PRUDHOE BAY UNIT L-01 MD 9528 ./ 9209 ~ Completion Dat 7/1/2001 -- Operator BP EXPLORATION (ALASKA) INC Completion Statu SUSP Current Status 1-01L ç p 4L g)w-.-- J--ß'ù { API No. 50-029-23011-00-00 UIC N ---~~-- TVD -- -- ---- --- REQUIRED INFORMATION Mud Log No Sample No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: ----~------- (data taken from Logs Portion of Master Well Data Maint) Log/ D . . Interval ata Digital Digital Log Log Run OH / Dataset Type Media Fmt Name Scale Media No Start Stop CH Received Number ~ e--- Ind Induction/Resistivity 1 2562 9425 Open ~O ¡ R R Directional Survey FINAL OH 6/22/2001 i k----- K- I ¡ I I ¡V'-- ¥- ~/ I ~- IV ! !~- I~ V I~ i~ I I i~~- i I~ I .- iL- I ~ Directional Survey ~~ ~I Result- _DS-t/TDD/CNL /~Plot- DSI ~dvisor SB Section þ:aéAdvisor Kup Section c-?~-~ ~- ~/ ---- C .< ~ ~ ~ V ~. ~- ~ / 10385 10386 £CDR Resistivity .tp¡fÓ CDR Resistivity .&8ïVD Log -Néutron / Density (~ole Sonic LAfray Induction ....f'Éx Triple Combo Cement Volume Well CoreslSamples Information: FINAL 2 FINAL 2 5 FINAL FINAL 5 FINAL 2/5 2/5 FINAL FINAL FINAL FINAL FINAL 5 2/5 FINAL FINAL 2/5 2/5 FINAL FINAL 2/5 2 FINAL 6250 2600 3750 6200 2562 143 2760 2760 2760 2760 2760 2760 143 143 7050 9350 4900 7000 9425 9530 9530 9530 9425 9425 9425 9425 9425 9425 OH 6/22/2001 OH 7/30/2001 OH 7/30/2001 9/28/2001 oh OH 9/28/2001 OH OH OH OH 10/16/2001 po385 10/15/2001 -4"0386 10/16/2001 10/16/2001 10/16/2001 OH OH OH OH OH CH 10/16/2001 10/16/2001 10/16/2001 10/16/2001 10/16/2001 Comments --- -- - --- --- Directional Survey, Paper Copy Directional Survey, Digital Data 6250-7050 Color Print 2600-9350 Color Print 3750-4900Color Print 6200-7000 Color Print 2562-9425 Digital Data 143-9530 Digital Data 143-9530 BL, Sepia 143-9530 BL, Sepia 2760-9425 BL, Sepia 2760-9425 BL, Sepia 2760-9425 BL, Sepia 2760-9425 BL, Sepia 2760-9425 BL, Sepia 2760-9425 BL~_epia---- ! ,- ,------- -_J /-<=,- ,-' ¡- '- Permit to Drill 2010720 MD 9528 TVD Name DATA SUBMITTAL COMPLIANCE REPORT 7130/2003 Well Name/No. PRUDHOE BAY UNIT L-01 Operator BP EXPLORATION (ALASKA) INC 9209 Completion Dat 7/1/2001 Completion Statu SUSP Current Status 1-OIL Interval Dataset Start Stop Sent Received Number Comments APl No. 50-029-23011-00-00 UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis R P. c.~.ivP, d ? Daily History Received? ~_.~N Formation Tops ~/N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing_ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development _X Explorato~__ Stratigraphic_ Service__ 4. Location of well at surface 2888' FNL, 3659' FEL, Sec. 34, T12N, R11 E, UM At top of productive interval 4044' FNL, 2620' FEL, Sec. 34, T12N, R11 E, UM At effective depth 4068' FNL, 2596' FEL, Sec. 34, T12N, R11E, UM At total depth 4094' FNL, 2569' FEL, Sec. 34, T12N, R11 E, UM (asp's 583257, 5978114) (asp's 667490, 5964894) (asp's 584351, 5976931) (asp's 584363, 5976920) 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-01 9. Permitnumber/approvalnumber 201-072 10. APInumber 50-029-23011-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 9528 feet Plugs (measured) 9209 feet Production 9304 feet Junk (measured) 8988 feet Length Size Cemented 109' 20" 260 sx Arctic Set (Aprox) 450 sx Arctic Set Lite, 2733' 9-5/8" 208 sx Class 'G' 186 sx LiteCrete, 145 sx 9485' 7" Class 'G' Tagged TD @ 9304'(12/10/2002). Measured Depth 136' True Vertical Depth 136' 2760' 2602' Perforation depth: ,..!,;,,l',l 5 "'i 2005 measured Open Reds 9124'-9136', 9142'-9180', 9180'-9210', 9;~¢~?.~8'i~i9(2~':~:~2;:;: 3~.'..!.'?".'~ true ve~ical Open Peris 8811'-8823', 8829'-8866', 8866'-8896', 8905'-8925', 8937'-8947' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10074' MD. 5-1/2" x 4-1/2" XO @ 10074'. 4-1/2" 12.6# L-80 @ 10217' Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Otis Packer @ 10074'. 5-1/2" Otis SSSV Nipple @ 2144' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/07/2002 Subsequent to operation 12/20/2002 OiI-Bbl 588 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 437 22 564 443 21 Casing Pressure Tubing Pressure 284 315 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge."- DeWayne R. Schnorr FEB 3 2_003 Form 10-404 Rev 06/15/88 · BFL Date December 20, 2002 Prepared by DeWayne R. Schnorr 564-5174 i?i,'.i'.'ii=? SUBMIT IN DUPLICATE L-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/10/2002 PERFORATING: DRIFT/TAG 12/12/2002 PERFORATING: PERFORATING 12/17/2002 TESTEVENT--- BOPD: 0, BWPD: 0, MCFPD: 3,398, AL Rate: 2,881 12/18/2002 PERFORATING: AC-FLUID LEVEL 12/19/2002 SECURE WELL: AC-FLUID LEVEL EVENT SUMMARY 12/10/02 DRIFTED TO SOFT BOTTOM @ 9,304' CORRECTED W/3.50 X 11' DUMMY GUN. RECIEVED SAMPLE OF FORMATION SAND. 42' RATHOLE PERFS FULLY OPEN. <<< WELL RETURNED TO OPERATOR TO POP >>> 12/12/02 PERFORATED 9124'-9136' AND 9142'-9180' IN THREE GUN RUNS, WITH 3 3/8" HSD, 6 SPF PJ GUNS. LOG TIE IN PASS TO SWS JL/PERF LOG DATED 14-NOV- 01, REF LOG SWS PE ARRAY INDUCTION LOG DATED 6/20/01 PER APE. WELL STACKED OUT W/GAS @1800 PSI. BLEED DOWN TUBING TO 850 PSI FOR SHOOTING PASSES, NO TAG. <<< SHUT IN >>> DSO TO POP 12/17/02 TESTEVENT --- BOPD: 0, BWPD: 0, MCFPD: 3,398, AL Rate: 2,881 12/18/O2 T/I/O = 350/1150/300 TEMP = 70? . IA FL FOR GLE @ 8640' (JUST BELOW STATION #1) . CURRENT GLR @ 2.88MM. 12/19/02 T/I/O=360/1180/340 (500 PSI +) OA FL NEAR SURFACE. Fluids Pumped BBLS 1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 1 TOTAL ADD PERFS 12/12/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 3-3/8" PJ, 6-SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9124' - 9136' 9142' - 9180' Page 1 TREE= 4-1/16" OW L01 iACTUATOR=- ~ CSG @ 8279' - 9428'. ALL OTHER 7" CSG IN STRING '~KB. ELEV = 76.7' IS 26#, L-80, BTC-M. BF. REV = KOP= 1100' MaxAngle= 36@2535'=.'' ; ~ 1021" ~--~TAMPORTCOLLAR Datum IVD = 9191' ' ~ 2256' H4-1/2"FESXNIP, ID:3.813"I Datum TV D = 8800' SS I i I I 9'5/8"CSG'40#'L-80BTC'ID=8'835" H 2760' ~ k GAS LIFT MANDRELS ST IVD TVD DEV TYPE VLV LATCH PORT DATE 6 3227 2923 29 KBG-2 RP BK-5 07/01/01 5 3504 3172 24 KBG-2 DV BK-5 07/01/01 L 4 5968 5595 0 KBG-2 DV BK-5 07/01/01 Minimum ID 3.725" '-'LC_. 8750' 3 7571 7197 0 KBG-2 DV BK-5 07/01/01 4-1/2" HES XN NIPPLE 2 8390 8016 8 KBG-2 DV BK-5 07/01/01 1 8627 8250 8 KBG-2 DV BK-5 07/01/01 I ~"cs~,~#,'-~0x~"cs~,~c~xoH8279' ~-~'~ :,C PERFORA TIO N SUM MA RY REF LOG: PEARRAY INDUCTION ANGLEATTOPPERF: 11 @ 9124' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sclz DATE Id i 3-3/8" 6 9124-9136 O 12/13/02 II 18695' 4-1/2" I-ES X NIP, ID: 3.813" I 3-3/8" 6 9142- 9180 O 12/13/02 2-7/8" 6 9180- 9210 O 11/14/01 X X i 8706' I'--I 7" X 4-1/2" BKR S-3 FKR, ID = 3.875" I 2-7/8" 6 9220- 9240 O 11/14/01 · ' I-t 2-7/8" 6 9252- 9262 O 11/14/01 I · I 8729' 4-1r2" HESX NIP, ID =3.813" ' i ~o' I-F~" .~s x~ ~,~, ,~-- ~'~" I i I 4-1/2"TBG, 12.6#,13-CF~0.0152bpf, ID=3.958"H 8761'I , 18763' Id4-1/2"WLEG, D=4.00" I8752' HELMD~LOGGED11,14,01 I ''"! II 9092' IdRA TAG (EL CORRECTED) I I.~T~ I-I 9428'I I ?' CSG, 26#, L-80 BTC-M, ID = 6.276" I--~ 9509' I · I I/ I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOEBA¥ UNIT 07/01/01 CH/KAK ORIGINAL COMPLETION WELL: L-01 11/14/01 TMN/KAK PERFS PERMITNo: 2010720 12/13/02 CAO/KK ADPERFS APl No: 50-029-23011-00 SEC 34, T12N, R11E, 2392' NSL & 3659' WEL BP Exploration (Alas ka) PERI:OPJ~ TIO N S UIVlMA RY REF LOG: PEARPJ~Y INDUCTION ANGLEATTOPPERF: 11 @ 9124' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sclz DATE 3-3/8" 6 9124 - 9136 O 12/13/02 3-3/8" 6 9142- 9180 O 12/13/02 2-7/8" 6 9180- 9210 O 11/14/01 2-7/8" 6 9220- 9240 O 11/14/01 2-7/8" 6 9252- 9262 O 11/14/01 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/01/01 CH/KAK ORIGINAL COMPLETION 11/14/01 TMN/KAK PERFS 12/13/02 CAO/KK A DPERFS f' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X INITIAL PERFS Pu, tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2887' FNL, 3659' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 4079' FNL, 2619' FEL, Sec. 34, T12N, R11E, UM At effective depth 4079' FNL, 2584' FEL, Sec. 34, T12N, R11 E, UM At total depth 4094' FNL, 2568' FEL, Sec. 34, T12N, R11 E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ (asp's 583257, 5978114) (asp's 584313, 5976939) (asp's 584347, 5976935) (asp's 584363, 5976920) 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-01 9. Permit number / approval number 201-072 10. APl number 50-029-23011 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 109' 2733' 9485' Production 9528 feet Plugs (measured) 9209 feet 9393 feet Junk (measured) 9076 feet Size Cemented 20" 260 sx Arctic Set (Approx 450 sx Arctic Set Lite, 9-5/8" 208 sx Class 'G' 186 sx LiteCrete, 145 sx 7" Class 'G' Tagged TD @ 9393' (11/12/2001) Measured Depth 136' 2760' 9509' True Vertical Depth 136' 2760' 9187' Perforation depth: measured Open Perfs 9180'- 9210', 9220' - 9240', 9252' - 9262' true vertical Open Perfs 8866' - 8896', 8905' - 8925', 8937' - 8947' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 8706'. 4-1/2" Tubing Tail @ 8752'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Packer @ 8706'. 4-1/2" HES X Landing Nipple @ 2256'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure RECEIVED DE[; ?. I ZOO1 A!~t~,~_ 0i~ & Gas Co~s. Commissio~ Anchorage 14. Prior to well operation 11/12/2001 Subsequent to operation 11/20/2001 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-in Production started on 11/14/2001. Casing Pressure Tubing Pressure 2281 3412 24 GL 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~/~~,~-~1.~/~'...-~-~..~-,/ Title: Technical Assistant DeWayne R Schnorr Form 10-404 Rev 06/15/88 · Date December 20, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATFX~ L-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/19/2001 10/20/2001 11/12/2001 11/14/2001 DRILL-POST WORK: DRIFT / SET GLV'S (POST DRLG ) IN PROGRESS DRILL-POST WORK: DRIFT / SET GLVS (POST DRLG) DRILL-POST WORK: DUMMY GUN DRIFT (POST RIG WORK) DRILL-POST WORK: PERFORATE & JEWELRY LOG (POST DRLG) EVENT SUMMARY 10/19/O 1 PULLED BALL & ROD @ 8724' SLM.. PULLED DGLV @ STA #4 - 5954' SLM . CONTINUED ON 10/20/01 WSR. 10/20/01 CONT FROM 10/19/01 WSR. PULL RP FROM STA #6 - 3211' SLM. SET LGLV IN STA #6 & OGLV IN STA #4 - 5954' SLM. PULLED RHC BODY @ 8729' SLM. DRIFTED WITH 10' X 2 7/8" DUMMY GUN TO TD @ 9406' SLM. RDMO. WELL LEFT SHUT IN. 11 / 12/O 1 RAN 3 3/8" DUMMY GUN W/TEL, TAG EOT @ 8730' SLM (TT NOT LOGGED) & TD @ 9393' SLM. WELL LEFT SHUT-IN. 11/14/01 LOG GAMMA RAY CCL FROM TD 9416'-8500'. TT ELM 8752'. PERFORATED 9252'-9562', 9220'-9240' & 9180'-9210' WITH 2 7/8" POWERJET 6 SPF, PENE 27.7", EH .36", 15 GMS. RA PIP TAG IS 9092'. *****WELL TURNED OVER TO PAD OP TO POP****** FLUIDS PUMPED BBLS 3 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (3 TESTS) 3 TOTAL INITIAL PERFS 11/14/2001 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" POWERJET, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9180'-9210' 9220'-9240' 9252'-9562' Page 1 TREE= 4-1/16' ClVV WELLHEAD= FIVIC ACTUATOR=- KB. ELEV = 76.7' BF. FIEV = KOP= 1100' Max Angle = 36 @ 2535' Datum IVD = 9191' Datum TV D = 8800' SS I 9-5/8"CSG, 40#, L-80 BTC, ID =8.835" H 2760' IMinimum D = 3.725" @ 8750' I 4-1/2" HES XN NIPPLE L-01 SAFETY NOTES: WELL HAS CHROIVETBG& 7', 29# CHROME CSG @ 8279' - 9428'. ALL OTFER 7" CSG IN STRING IS 26#, L-80, BTC-M. 1021' 2256' HTA M PORT COLLAR H4-1/2'' FESX NIP, ID = 3.813"I GAS LIFT MAKDRELS ISTI ~ ITVDIDEVITY~EIVLVlLATCHIS~EI DATE I I 5 1 3~04131721 24 1~21 DVI BK-5 I 10~/0~1 I ~ I ~1~1 0 I~1 DV I ~-~ I 10W0~I I ~1 ~ IZ~"~I 0 I~1 DVI ~-~ I 10W0~I I ~ I ~01~0~1 ~ I~1 DYI ~K-~ I 10W0~I I ~ I 8627 182501 8 1~21 DVI BK-5 I 10Z/0~I I 7"CSG, 26#, L-80 X7" CSG, 29~ BCRXO H 8279' FERFORATION S UIVIVIARY REF LOG: PE ARRAY INDUCTION ANGLE AT TOP PERF: 11 @ 9180' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2- 7/8" 6 9180- 9210 O 11/14/01 2-7/8" 6 9220- 9240 O 11/14/01 2-7/8" 6 9252 - 9262 O 11/14/01 I 4-1/2"TBG, 12.6#, 13-CR, 0.0152 bpf, ID=3.958" H 8761' 7" CSG, 26#, L-80 BTC,-M, ID = 6.276" H 9509' 8695' 8706' 8729' I--]4-1/2" HES X NIP, ID= 3.813" I 8750' H4-1/2"HESXN NIP, D=3.725" I 8763' 8752' Id4-1/2" WLEG, ID= 4.00"I IdFIIVD 'IT LOGGED11/14/01 I 9092' I--~RA TAG(FI CORRECTED) 9428' H PBTD I DATE REV BY COrVlVlENTS DATE REV BY COk, W1ENTS PRUDHOE BAY UNIT 07/01/01 CH/KAK ORIGINAL COMPLETION WELL: L-01 11/14/01 TIVI~I/KAK PERFS PERrvllT No: 201-072 APl No: 50-029-23011-00 2392' NSL& 3659' WEL, Sec. 34, T12N, R11E BP Exploration (Alaska) STATE OF ALASKA i' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-072 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23011-00 4. Location of well at surface ............. ~,.~,~,,,,.,...,,..,.,~. 9. Unit or Lease Name ~, ,, .... ~ 2392' NSL, 3659' WEL, SEC. 34, T12N, R11E, UM n.~. '.~ : . . .~A~,~;~i At top of productive interval /-~ , ~ ~;:..J.~IF!iZC, ~. Prudhoe Bay Unit 1235' NSL, 2620' WEL, SEC. 34, T12N, R11E, UM : tt .' ,t_~f' ~'~'~ ~ 10. Well Number At total depth ~ ~' ""~::~"'!I. 1184' NSL, 2568' WEL, SEC. 34, T12N, R11E, UM ~:.. i L-01 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation'and Serial'No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 76.70' ADL 028239 12. Date Spudded6/8/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'6/19/2001 11,14/2001 115' Water depth' if °ffsh°reN/A M S L 116' N°' °f C°mpleti°nsO n e 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 9528 9209 FTI 9428' 9110' FTI [] Yes [] NoI (Nipple) 2256' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES / AlT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, DIPOLE \ SONIC, MDT, DPC, GR \ FPT 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT, PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 109' 30,, 260 sx Arctic Set (Approx.) . 9-5/8" 40# L-80 27' 2760' 12-1/4" 450 sx Arctic Set Lite, 208 sx Class 'G' 7" 26# L-80 / 13Cr 24' 9509' 8-3/4" 186 sx LiteCrete~ 145 sx Class 'G' , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13-Cr 8763' 8706' MD TVD MD TVD 9180' - 9210' 8866'- 8896' 26.' ' ACID, FRACTURE, CEM'ENT sQuEEZE, ETC, 9220' - 9240' 8905' - 8925' .. . . . 9252' - 9262' 8937' - 8947' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 15, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 11/17/2001 4 TEST PERIOD 2390 1819 24 176I 761 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED DEC 1 3 2OO ,,-,, r.., , ,., , , , . , Alaska0il&.Gas.. Cms. C0mm~0~ Form 10-407 Rev. 07-01-80 0 R iGiN k.,,s B FL DEC; ,8 200, s~l~Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 8911' 8603' MDT was ran, log supplied for detail. Shublik 8952' 8643' Eileen 9088' 8776' Sadlerochit (Ivishak) 9123' 8810' Zone 4A 9250' 8935' Zone 3 9318' 9002' Zone 2C 9392' 9075' Zone 2B 9464' 9145' RECEIVED OEC 1 ZOO1 Alaska 0il & Gas toms. Commissi0~ A~omge 3'1'. Li~t' of Attachments: .... Summary of Post Rig W'0rk (Perf Operation) ................. Previously submitted: Summary of Daily Drilling Reports, Surveys, Leak Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,,'~i~ ~ Title TechnicalAssistant Date L-01 201-072 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Well: L-01 Rig Accept: 06/07/01 Field: Prudhoe Bay Unit Rig Spud: 06/08/01 APl: 50-029-23011-00 Rig Release: 07/01/01 Permit: 201-072 Drilling Rig: Nabors 9ES POST - RIG WORK 10/20101 Ran 3-3/8" dummy gun. Tagged bottom of tubing and TD. Well left shut-in. 11114/01 Log GR CCL from TD to 8500'. Perforated 9252'- 9562', 9220'- 9240' and 9180'- 9210' with 2-7/8" Powerjet, 6 spf. Well turned over to Pad operator to put on production. 11/15/01 Schlumbe r Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1634 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD L-01 . ~-'~(~/."'07~,,. · 21320 MDT 06/19/01 1 1 P-02A (~ O1~- O~ 21453 MGR 1~2~00 D.S. 15-16 /yq ~~O ~ 21473 SCMT-A 10/26/01 2 D.S. 15-16 21473 SCMT-BB 10/26/01 2 F-22 / ~ ~ 21413 RST 09/14/01 I I 1 D,S. 5-23A~OI--/~ 21457 MCNL 10/16/01 D.S. 9-04A /q~q 21458 RST 10/18/01 I I 1 D.S. 9-42A [~ ~ 2145~ RST 10/2~01 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV I d 2001 AI~I~ 0il & ~s Co~s. Commit~:m A~ct~mge Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Receive 10/31/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATEN: Sherrie NO. 1582 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD ! D.S. 7-16A ~Ot-I ~ .=~ 21433 MCNL 09/12/01 1 1 I ~F-05 ! --~ I- O~)C~ 21411 RST 09/11/01 1 1 1 F-21 /_ .~.~. --O S~ 21412 EST 09/08/01 1 1 1 K-10A ~-'~'/-- ~,~ 21341 MCNL/BORAX 09/11/01 1 1 I D.S. 1-04A ~J~-I 53 21436 MCNL 08/31/01 1 1 1 J-13 ! ~L~-~O~'~ 21410 RST 09/06/01 1 1 I D.S. 1-0~1A- ~O)21E:~ 21435 MCNL 08/30/01 1 1 1 F-40 [ C~i_/i '/ 21415 EST-SIGMA 09/09/01 1 1 1 N-20A I~Ip- I~q 21441 USlT 09/21/01 2 L-01 (REDO) ~OJ-E~-~,~. 21320 DSI/AIT/PEX 06/19/01 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)lnc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED 0 2 2001 Alaslm Oii& Gas Cons. Commission Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571 ATTN: Sherrie Receivec~~' .~O~~ 10/09/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie N0.1520 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job it Log Description Date Blueline Sepia Prints CD L-01 21320 AIT/DSI/PEX 06/19/01 L-01 21320 PEX-AIT 06/19101 L-01 21320 PEX-NEUTRON/DENSlTY 061t9101 L-01 21320 PEX-TRIPLE COMBO 06119/01 L-01 21320 DSI 06/19/01 L-01 21320 PEX-SSTVD 06/19101 L-01 21320 CEMENT VOLUME LOG 06/19/01 L-01 21339 LDWG CDR/GR 06119101 L-01 2t339 MD CDR RESlSTIVI'rY 06119/01 L-01 21339 TVD CDR RESISTIVITY 06119101 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED OCT 1 2001 Alaska Oil & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie STATE OF ALASKAl" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] .;USP 2. Name of Operator ~;~.,~;.~. 7. Permit Number BP Exploration (Alaska) Inc. . ~i ,,J'?-'~,,~,-~¥'.',~ ~.,.. 201-072 3. Address ...........-~;' 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 Sun~~;...! 50-029-23011-00 4. Location of well at surface ............... '~ '~' :~ '~'- _,1~'5,_?:i~ 9. Unit or Lease Name 2392' NSL, 3659' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit At top of productive interval 1205' NSL, 2619' WEL, SEC. 34, T12N, R11E, UM At total depth : .~. 10. Well Number 1171' NSL, 2585' WEL, SEC. 34, T12N, R11E, UM ..............-.... L-01 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 76.70' ADL 028239 12. Date Spudded6/8/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'6/19/2001 7/1/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'I'VD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 9528 9209 FTI 9428' 9110' ETI [] Yes [] NoI (Nipple) 2256' MOI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, RES / AlT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, DIPOLE \ SONIC, MDT, DPC, GR \ FPT 23. CASINGt LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 109' 30" 260 sx Arctic Set (Apl)mX.) 9-5/8" 40# L-80 27' 2760' 12-1/4" ¢50 sx Arctic Set Lite, 208 sx Class 'G' 7" 26# L-80 / 13Cr 24' 9509' 8-3/4" 186 sx LiteCrete~ 145 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~zs DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, 13-Cr 8763' 8706' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not On Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE ...28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. !i7:?.' i:::i,:;i,; ,:i,'i~:'~~""' '~ ' Form 10-407 Rev. 07-01-80 NOV 2 i 2001 ~ .~ Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Ugnu 4 3025' 2825' Ugnu 1 3938' 3656' Top of Schrader Bluff 4250' 3959' Base of Schrader Bluff 5020' 4724' Top of Kalubik 6681' 6385' Top of Kuparuk 6804' 6508' Top of Miluveach 7239' 6943' Top of Kingak 8046' 7750' Top of Sag River 8911' 8603' Top of Shublik 8952' 8643' Top of Eileen 9088' 8776' Top of Sadlerochit (Ivishak) 9123' 8811' Ivishak Zone 4A 9250' 8935' Ivishak Zone 3 9318' 9002' Ivishak Zone 2C 9392' 9075' Ivishak Zone 2B 9464' 9146' .~!,ISsi,:;::~ C,,il ~i: C:,:;':! ',/,,: ~:,:,, C::,,~ ~, 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .,~[~~ Title TechnicalAssistant Date L-01 201-072 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM .5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · ., ' ....... ..' '.."' '~:'..' :.'.Bp EXPLORATION i · .. ':.:" :" '"'" .... '"" .... · ':' .', ' Page 1 of 1 " " "' ": '" ':' :'" ':'" '"": ":': :' .... '...' .".':' '-'-".-',~-:~-,.,. ------v'."'"'''~"~=~'r~'~.T"Q*"-~""~"~a. ry Legal Name: L-01 Common Name: L-01 Test Date Test TyPe' :' ".' "Test Depth.(TMD) ' "Test DePth(TVD). ' .' AMW :i :SUrface preSSure Leak Off Pressure (BHP) EMW 6/12/2001 LOT 2,760.0 (ft) 2,794.0 (ft) 9.60 (ppg) 536 (psi) 1,929 (psi) 13.29 (ppg) Printed: 7/2/2001 11:29:51 AM BP EXPLORATION Page 1 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/5/2001 09:00 - 13:00 4.00 MOB P PRE PJSM, R/D, Move pits and Shop in order to move out with Sub. R/D top drive, bridle up. Lay Down Derrick. 13:00 - 00:00 11.00 MOB P PRE PJSM with rig crew, Peak, Tool Services and all involvedin move. Move Sub off B-05B and B Pad. Move down Spine Rd. toward L Pad. 6/6/2001 00:00 - 00:00 24.00 MOB P PRE Continue moving Equipment to L Pad. Lay Mats and Herculite. R/U Diverter & Spot Sub over L-01 6/7/2001 00:00 - 06:00 6.00 MOB P PRE Spot Pits, Camp & Shop. R/U Fluid Interconnect. PJSM. Inspect and raise Derrick. R/U Floor, Bridle down, M/U Blocks to Top Drive. Hang bridle lines off in derrick. ACCEPT RIG @ 06:00 Hrs. 06:00 - 21:00 15.00 RIGU P PRE Continue R/U Floor to drill. Start mixing Spud Mud. Install valves on Conductor. Lengthen Diverter line. Modify and install 20" Riser. Modify Cellar door to close. Cont. mixing spud mud. Finish moving all Rig equip from various staging areas to L Pad. Strap and tally 4" Drill Pipe ,21:00 - 22:00 1.00 RIGU P PRE PJSM on P/U DP. Pre Spud meeting with Arnson's Crew, Anadrill, Baroid & Co. Rep. 22:00 - 00:00 2.00 RIGU P PRE P/U 4" DP in Trips. and stand back in Derrick. 6/8/2001 00:00 - 08:00 8.00 RIGU P PRE P/U 95 Stands 4" Dp and 5 Stands 5" HWDP 08:00 - 08:30 0.50 RIGU P PRE Bring BHA tools to floor 08:30 - 09:00 0.50 BOPSUF:P SURF Function test Diverter, Valves, Accumulator & gas alarms. Witnessed by John Crisp, AOGCC. 09:00 - 12:00 3.00 DRILL P SURF PJSM M/U BHA # 1, Orient Tool and Calibrate settings for MWD 12:00 - 12:30 0.50 DRILL P SURF Pre Spud Meeting with Hunt's crew and all Service personnel. 12:30 - 13:30 1.00 DRILL P SURF Fill conductor Bring pumps on line and check all connections. Flush Conductor. 13:30 - 18:00 4.50 DRILL P SURF Spud Well Drill from 109' to 220'. ART - 3.5 Hrs. 18:00 - 19:30 1.50 DRILL P SURF POH w/2 stands DP - P/U Drill Collars. 19:30 - 20:00 0.50 DRILL P SURF Pre Spud Meeting with Lunda's Crew and service Co. personnel. 20:00 - 00:00 4.00 DRILL P SURF Directional Drill 12 1/4" Hole from 220' to 485'. WeB = 6 to 25K. ROT = 60 590 GPM @ 1050 psi. AST = 1.5 ART = 1.5 6/9/2001 00:00 - 02:30 2.50 DRILL P SURF Drill 12 1/4" Directional Hole from 485' to 764'. 590 GPM @ 1070 psi. Torque = 1 to 3K. AST = 1.5 Hrs. ART = 1Hr. 02:30 - 04:00 1.50 DRILL P SURF POH - Change out 4" DP for 5" HWDP.RIH 04:00 - 21:00 17.00 DRILL P SURF Drill from 764' to 1756'. 590 GPM @ 1450 psi. WeB = 25 to 30K. P/U = 100K S/O - 90K ROT = 85K TQ = 4 to 5K @ 50 RPM ART = 4.5 Hrs AST= 8.25 Hrs. 21:00 - 21:30 0.50 DRILL P SURF Circulate weighted Barofiber Sweep. 21:30 - 22:30 1.00 DRILL P SURF Wiper trip to 728". Pulled 25K @ 1731'. Rest of Hole Slick. 22:30 - 23:00 0.50 DRILL P SURF Wash last stand to bottom. No resistance. Pumped @ 500 GPM w/1400psi. Assume one nozzle plugged. 23:00 - 00:00 1.00 DRILL P SURF Dir. Drill from 1756" to 1850". Some Hydrates from 1800' to 1835'. Mud rolling and bubbling, but no show on gas monitor, nor any gain. ART = 0.25 Hr. AST = 0.5 Hr. 500GPM @ 1500 psi. 6/10/2001 00:00 - 08:30 8.50 DRILL P SURF Drill 12 1/4" Directional Hole from 1850' to 2774'. TD as per Geologist. Hydrates steady from 2340 through 2500'. P/U 115K Printed: 9/25/2001 11:32:46 AM BP EXPLORATION Page 2 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/10/2001 00:00 - 08:30 8.50 DRILL P SURF S/O 90K ROT. 100K. WeB 30K. RPM 50 Circ 500GPM @ 1670 psi. Tq. 4 - 5 K AST 2.5 Hrs. ART 4 Hrs. 08:30 - 10:30 2.00 DRILL P SURF Circulate B/U, then weighted sweep. Pump Pill. 10:30 - 14:00 3.50 DRILL P SURF Wiper Trip to 1000'. 15 to 20K Drag at base of permafrost Wipe through - OK. 14:00 - 15:00 1.00 DRILL P SURF Pump Sweep. Spot Casing running Pill. 15:00 - 17:30 2.50 DRILL P SURF POOH. Encountered tight spots @ 2600,2435,2000 &1850 ( 15-35K OP ).Work through & wipe same. No other problems while POOH. 17:30 - 20:30 3.00 DRILL P SURF Stand back HWDP and Jars. L/D BHA # 1. !20:30 - 22:30 2.00 DRILL P SURF Clear floor & R/U to run 9 5~8" Surface Casing. 22:30 - 00:00 1.50 DRILL P SURF PJSM. RIH w/9 5~8" Surface Casing. Check Floats 6/11/2001 00:00 - 04:00 4.00 DRILL P SURF Complete running 66 Jts. 9 5~8" 40#, L-80, BTC Casing. Shoe @ 2760'. Hole slick - No Problems. Fill every Jt w/Frank's Tool. P/U - 140K S/O = 110K 04:00 - 05:00 1.00 DRILL P SURF RID casing equip, Franks tool. R/U Cement Head 05:00 - 08:00 3.00 DRILL P SURF C & C Mud to a 60 Vis and 14 PV. Pre treat w/Bicarb. Reciprocate w/6' srokes while circ. 140 P/U 110 S/O. Held PJSM prior to cement job. 08:00 - 12:00 4.00 DRILL P SURF Switch to SWS. pump 10 bbls CWl00. Test lines to 3500 psi. Drop bottom plug and pump additional 40 bbls CWl00. Pump 75 bbls 10.2 ppg. MudPush Spacer. Pump 356 bbls Lead cement: AS III @ 10.7 ppg. followed by 43 bbls "G" @ 15.8 ppg at 5 - 6 bbm. Drop top plug and chase w/10 bbls water. Switch to Rig pumps and complete displacement w/197 bbls Mud. Bumped plug w/3000 psi. Floats OK. 48 bbls cement contaminated Spacer and 50 bbls good 10.7 ppg Cement to surface. 12:00 - 13:00 1.00 DRILL P SURF Clean out flow line and possum belly. Lay down landing Jt. Clean Diverter and Knife valve. 13:00 - 15:00 2.00 DRILL P SURF N/D DiverterAssembly. 15:00 - 00:00 9.00 DRILL P SURF N/U Csg Head & Tubing spool. N/U BOP.Install Rams and function for Hydril Rep. Inspection. Stack will not fit under rig with normal configuration because of the required positioning of the landing ring - 22" higher than previous Grassroots wells. Reviewed options w/Drlg. Supt and decided to remove Tubing Head for now in order to proceed with program. Will reinstall ITbg. Head after running 7" casing. An 11" 5K X 13 5/8"5K Standard X-over flange was Located to eliminate this problem !for future L Pad wells. 6/12/2001 i00:00 - 02:30 2.50 DRILL P INT1 ~Cont nipple up bope. :02:30 - 09:30 7.00 DRILL P INT1 Prepare and test bope, (pipe, blinds, stack to 250 / 4000 psi, 15 min), (choke - kill lines, all related valving, 250 / 4000 psi 15 rain), (Hydril, 250/3500 psi 15 min), (floor valves, stand pipe to pumps, 250 / 4000 psi). All tests successful. Waived by John Spalding. Note: The Blind/Shear Rams would not test. They were changed out with Blind rams & tested to 4000 psi. 09:30 - 10:30 1.00 DRILL P INT1 Rig dn test equip, blow dn lines, clear floor. 10:30 - 13:00 2.50 DRILL P INT1 Make up bha, adjust motor to 1.15 deg, complete MU bha. 13:00 - 14:30 1.50 DRILL P INT1 Rih, shallow test MWD. The MWD would not test at this depth. TIH 10 stds to 2600' & re-test MWD, Printed: 9/25/2001 11:32:46AM BP EXPLORATION Page 3 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/12/2001 13:00 - 14:30 1.50 DRILL P INT1 test successful. 14:30 - 15:30 1.00 DRILL P INT1 Break ¢irc, test 9 5/6 csg to 4000 psi / 30 min. Test good. 15:30 - 17:30 2.00 DRILL P INT1 iWash to Float collar at 2675 ft, drill out float and shoe track. Clean out 12 1/4" Rathole to 2774'. 17:30 - 18:30 1.00 DRILL P INT1 Drill new 8 3/4 hole to 2794 ft. Flow check, displace with 9.6 ppg LSND mud. 18:30 - 19:30 1.00 DRILL P INT1 Perform LOT, resulting in 536 psi ( 13.5 EMW ) at break down, shut in and observe bleed to stable press 30 min at 200 psi ( 11.1 EMW ). Total pumped .91 bbls, bled back .5 bbl. 19:30 - 21:30 2.00 DRILL P INT1 Drill ahead 8 3/4 hole to 3055 ft. Flow check. Slight bubbling with losses, no gain. Well stable in 5 min. Cont flow check 10 min. 21:30 - 22:00 0.50 DRILL P INT1 Circ btms up, observe well, fluid column stable. 22:00 - 00:00 2.00 DRILL P INT1 Drill ahead 3055 - 3166 ft ART = 2 hr, AST = .25 hr 6/13/2001 00:00 - 01:00 1.00 DRILL P INT1 Circ, wait on tank trucks delayed in Prudhoe for cuttings removal. ~01:00 - 21:00 20.00 DRILL P INT1 Resume drilling 8 3/4 hole, 3166 - 5029 ft. Sweeps at 300 ft intervals. Good hole cleaning. No abnormal conditions. Up 125, Dn 100, Rot 120 ART 5 hrs, AST 1.75 hrs 21:00 - 22:00 1.00 DRILL P INT1 Flow check, Circ sweep, take survey, pump wt. pill, prepare poh for wiper trip. 22:00 - 23:00 1.00 DRILL P INT1 Flow check, poh to shoe. Pull 30K over, 4330 - 3400. normal drag remainder of trip. 23:00 - 00:00 1.00 DRILL P INT1 Flow check, pjsm, slip / cut drlg line. 6/14/2001 00:00 - 00:30 0.50 DRILL P PROD1 Service Top-Drive. 00:30 - 02:00 1.50 DRILL P PROD1 TIH from 9 5/8" casing shoe to 4936'. Break circulation. Wash to bottom at 5029'. 02:00 - 19:00 17.00 DRILL P PROD1 Drill 8 3/4" Directional hole from 5029' to 6246'. 19:00 - 19:30 0.50 DRILL P PROD1 Circ sweep, shaker clean. 19:30 - 20:30 1.00 DRILL P PROD1 Flow check, prepare and poh for wiper trip. Pull 25K over 5270 - 5230 ft. 20:30 - 21:30 1.00 DRILL P PROD1 Flow check, rih to 6146 ft. Hole good cond. No abnormalties. 21:30 - 22:00 0.50 DRILL P PROD1 Make up top drv, precautionary wash to btm at 6246 ft. No fill. ( Bolt fell from derrick. Perform derrick inspection. Replace bolt in Kelly hose safety clamp ). 22:00 - 00:00 2.00 DRILL P PROD1 Resume drill ahead 8 3/4 hole 6246 - 6370 ft. Up 180, Dn 120, Rot 145 ART 9 1/4 hrs, AST 3/4 hrs 6/15/2001 00:00 - 03:00 3.00 DRILL P PROD1 Drill 8 3/4" Directional hole from 6370' to 6565'. WOB 12K, RPM 110 w/7-8k Torq, GPM = 557 w/3300 psi. P/U 190K, S/O 125K, Rot Wt. 1489K. ART =1 1/2 hrs, AST = 0 hrs. 03:00 - 05:30 2.50 DRILL N RREP PROD1 Discover washout at saver sub and lower safety valve on top drive. Poh for repairs. Hole good condition, normal drag. 05:30 - 06:30 1.00 DRILL N RREP PROD1 Replace saver / safety valve assy. 06:30 - 07:00 0.50 DRILL P PROD1 Service top drive 07:00 - 09:00 2.00 DRILL N RREP PROD1 Replace bolts blower exhaust, top drive. Remove kelly hose clamp for modification. 09:00 - 12:00 3.00 DRILL N RREP PROD1 Flow check, rih to 6465 ft, break circ, wash / ream to btm at 6565 ft. No fill. No torque. 12:00 - 00:00 12.00 DRILL P PROD1 Commence drill ahead 8 3/4 hole, drctnl, 6565 - 7179 ft. WOB 10 - 15, RPM 110, Tork 9500, GPM 452, Printed: 9/25/2001 11:3Z:46AM BP EXPLORATION Page 4 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/15/2001 : 12:00 - 00:00 12.00 DRILL 3 PROD1 Up 215, Dn 125, Rot 165 ART = 8 1/4 hrs, AST = 1/2 hrs. 6/16/2001 00:00 - 10:30 10.50 DRILL ~ PROD1 Drill 8 3~4" Directional hole from 7179' to 7779'. WOB 12K, RPM 110 w/7-8k Torq, GPM = 557 w/3150 psi. P/U 225K, S/O 134K, Rot Wt./169K. ART =1 1/4 hrs, AST - 6 1/2 hrs. 10:30 - 13:30 3.00 DRILL N RREP PROD1 Flow check, poh to shoe for swivel packing. 25 K overpull at 7240. Work free. 13:30 - 18:00 4.50 DRILL N RREP PROD1 Repair swivel pkg, service top drive. Test pkg, leak continues. Replace wash pipe. Re-test, test good. 18:00 - 21:00 3.00 DRILL N RREP PROD1 Flow check, rih, ream / wash restriction at 7630 ft, cont wash to btm, no fill. 21:00 - 00:00 3.00 DRILL P PROD1 Drill 8 3~4" Directional hole from 7779' to 7831'. WOB 12K, RPM 110 w/7-8k Torq, GPM = 557 w/3150 psi. P/U 225K, S/O 134K, Rot Wt./169K. ART =1 1/4 hrs, AST = 0 hrs. 6/17/2001 00:00 - 00:00 24.00 DRILL P PROD1 Drill 8 3/4" Directional hole from 7831' to 8702'. WOB 1OK, ~RPM 110 w/7-8k Torq, GPM = 557 w/3150 psi. P/U 250K, S/O 145K, Rot Wt./180K. ART =6.75 hrs, AST = 9.5 hrs. No abnormalties, well bore good condition. 6/18/2001 00:00 - 06:30 6.50 DRILL P PROD1 Cont drill ahead 8 3/4 drctnl hole, 8702 - 8951 ft. WOB - 15, RPM - 75, Torq - 12 - 13, GPM - 514, Up - 262, DN - 155, ROT - 195, ART = 7 hrs, AST = 1 hr, ROP = 20 - 40 fph No abnormalties, well bore good condition. 06:30 - 07:00 0.50 DRILL !N RREP PROD1 Recip and cir¢ while replace 2" nipple on mud pump. 07:00 - 00:00 17.00 DRILL i P PROD1 Cont drill ahead 8 3/4 drctnl hole, 8951 - 9479 ft. WOB - 15, RPM - 75, Torq - 12 - 13, GPM - 514, Up - 262, DN - 155, ROT - 195, ART = 10.75 hrs, AST - 0 hr, ROP = 20 - 40 fph No abnormalties, well bore good condition. ROP dropped to 2 fph prior to TD. 6/19/2001 00:00 - 03:30 3.50 DRILL P PROD1 Drill ahead 8 3/4 hole to td 9528 ft. Up 262, Dn 155, Rot 195 ART - 3 1/4 hrs, AST = 0 03:30 - 05:00 1.50 DRILL P PROD1 Pump sweep, circ shaker clean. Recip pipe, no drag, torque. 05:00 - 08:00 3.00 DRILL P PROD1 Flow check, prepare and poh wiper trip to 6200 ft. Well bore good condition. Flow check. 08:00 - 11:30 3.50 DRILL P PROD1 Rih to 9500, precautionary wash to btm 9528. No fill. 11:30 - 15:00 3.50 DRILL P PROD1 Rop SSV, Poh, for E-logs, 3 shots survey 9500 - 9000 ft. Normal drag, well bore exc cond. 15:00 - 18:30 3.50 DRILL P PROD1 Handle bha, lay out mwd / motor / drctnl equip. 18:30 - 22:00 3.50 DRILL P PROD1 Prepare and test bope as follows: Hydril 250 / 3500, Rams 250 / 4000, Kill line and valves 250 / 4000, choke mnfld 250 / 4000, stand pipe, top drive, mud pumps 250 / 4000, floor valves 250 / 4000, Koomey unit BP specs. Test waived by Jeff Jones. AOGC 22:00 - 22:30 0.501 DRILL P PROD1 PJSM. Place Schlum equip rig floor, rig up same. 22:30 - 00:00 1.501 DRILL P PROD1 Rih wireline, run #1, PEX / DiPole / Sonic. observe well satic. 6/20/2001 00:00 - 05:30 5.50! DRILL P PROD1 Rih wireline, E log run #1, Pex / Dipole / Sonic. Wireline td at 9425 ft. Log 9425 - 2760 ft. Poh wireline, lay out PEX. 05:30 - 11:00 5.50 DRILL P PROD1 Assemble and rih wireline run #2 MDT. Tight hole at 9398 ft. Printed: 9/25/2001 11:32:46 AM BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/20/2001 05:30 - 11:00 5.50 DRILL P PROD1 Attempt work through tight interval. No success. Tool stuck fast at 9398 ft total depth. No movement possible. Ran stretch calculations. Cable stuck at approximately 3500'. Tension gauge @ tool shows no pull @ tool. 11:00 - 14:00 3.00 FISH N DPRB PROD1 Mobilize baker fishing service, wait on same. 14:00 - 16:00 2.00 FISH N DPRB PROD1 Cut wireline, MU wireline latch assy. 16:00 - 17:00 1.00 FISH N DPRB PROD1 Assemble Baker fishing bha. O shot assy. 17:00 - 22:00 5.00 FISH N DPRB PROD1 Latch wireline, attempt release t bar, E line pulled free of rope socket. Re-attach E line, remove T bar. 22:00 - 00:00 2.00 FISH N DPRB PROD1 Flow check, rib with O shot on hwdp, stripping over E line one stand hwdp. Relocate monel, lay dn drlg jars. 6/21/2001 00:00 - 04:00 4.00 FISH N DPRB PROD1 PJSM, install circ sub, change to long bales, adjust crown saver, prepare floor for stripping operation. 04:00 - 22:00 18.00 FISH N DPRB PROD1 Commence rih, stripping over wireline, 30 - 50 fpm. Follow bha with 4" dp, flow check at shoe. Resume rih. Attempt free wireline various intervals from 3550 - 7000 ft at drop section of hole. No success, cont strip down to 9326 ft. 22:00 - 00:00 2.00 FISH N DPRB PROD1 Work dn to TOF, can not engage, pipe sticking. Work pipe free, make up circ head, prepare circ and clean to TOF. 6/2212001 00:00 - 03:00 3.00 FISH N DPRB PROD1 Resume free stuck pipe, work pipe / E-line simultaneousely, latch fish, poh 90 ft. 310 K to free string. 03:00 - 03:30 0.50 FISH N DPRB PROD1 Verify fish engaged, press up to 1850 psi and shear circ disc. Circ clean bha X hole annulus. 03:30 - 06:00 2.50 FISH N DPRB PROD1 Flow check, prepare and pull E-line free with 10K. Line free. Fish engaged. 06:00 - 07:30 1.50 FISH N DPRB PROD1 Recip pipe, work free, remove T bar and tools, lay out same. 300 K to free string. 07:30 - 09:30 2.00 FISH N DPRB PROD1 Poh wireline, spool on to Schlum unit. Rig dn sheaves / related equip. 09:30 - 18:00 8.50 FISH N DPRB PROD1 Flow check, poh, all indicaitons fish latched. 18:00 - 20:30 2.50 FISH N DPRB PROD1 Handle bha, observe fish in rotary. Lay out all fishing assy, release Baker. 20:30 - 22:00 1.50 FISH N DPRB PROD1 Clear and clean rig floor. 22:00 - 00:00 2.00 FISH N DPRB PROD1 I Change out to trip bales, handle bha, rih hwdp. 6/23/2001 00:00 - 00:30 0.50 DRILL N DPRB PROD1 ;Rih bha, to 4" dp. 00:30 - 03:00 2.50 DRILL N DPRB PROD1 'Flow check, cut drlg line, re-adjust COM, ser top drv. 03:00 - 04:30 1.50 DRILL N DPRB PROD1 Resume rih to 2700 ft. 04:30 - 05:00 0.50 DRILL N DPRB PROD1 Flow check, break circ. Full returns. 05:00 - 09:30 4.50 DRILL N DPRB PROD1 Cont rih, break circ at 5400, 7700, 9200 ft. 09:30 - 11:30 2.00 DRILL N DPRB PROD1 Backream tight hole 9250 - 8800 ft. Note small splintered shale particles at shaker. 70 spin, 50 rpm, 1250 psi. 11:30 - 15:30 4.00 DRILL N DPRB PROD1 Flow check, slight losses, 1-2 bph. Wash / ream to 9526 ft. Regain 100% returns. 15:30 - 18:30 3.00 DRILL N DPRB PROD1 Pump hi vis sweep, note increased shales at shaker. Shaker clean, back ream to 8970 ft. Hole condition improved. 18:30 - 19:00 0.50 DRILL N DPRB PROD1 Flow check, wash / rotate to btm. 9528 ft. 19:00 - 23:30 4.50 DRILL N DPRB PROD1 Circ sweep, increase mud wt to 10.9 ppg. Spot "tork trim" lube pill on btm to 8800 ft. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Flow check, no loss / gain. Prepare poh for E-logs. 6/24/2001 00:00 - 05:30 5.50 DRILL N DPRB PROD1 Cont poh 4" dp for logs, 15 - 20 K drag at 7950 and 6875 ft, work free. Flow check at shoe. Printed: 9/25/2001 11:3Z:46 AM BP EXPLORATION Page 6 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/24/2001 00:00 - 05:30 5.50 DRILL N DPRB PROD1 05:30 - 07:30 2.00 DRILL N DPRB PROD1 Flow check, lay out hole opening bha. 07:30 - 08:30 1.00 DRILL N DPRB PROD1 Clear rig floor, prepare for PU logging tools. 08:30 - 10:30 2.00 DRILL N DPRB PROD1 Assemble logging bha, rih same, connect and test tools. 10:30 - 12:00 1.50 DRILL N DPRB PROD1 Flow check, follow bha with 4" dp to shoe. 12:00 - 13:00 1.00 DRILL N DPRB PROD1 Break circ, while place all SWS tooling on floor. Recieve full returns. 13:00 - 16:00 3.00 DRILL N DPRB PROD1 Resume rih 4" dp, break circ 2000 ft intervals, to 6740 ft. 16:00 - 21:00 5.00 DRILL N DPRB PROD1 Flow check, make up SES, rib wireline 200 ft above WC. Begin pump / flush WC. Rih wireline, latch in, clamp SES, make pull test. Rih slowly while latched in. 21:00 - 00:00 3.00 DRILL P PROD1 Commence MDT logs at the following intervals: 8914, 8915, 8918, 8920, 8928, 8928, 8935, 8938, 8938 ft. Note two repeats. 6/25/2001 00:00 - 13:00 13.00 DRILL P PROD1 Resume dpc e-logs ( MDT ), 8935 - 9398 ft. 13:00 - 21:00 8.00 DRILL P PROD1 Flow check, poh dp to 6740 ft. Well bore good cond. No anbnormal drag. 21:00 - 00:00 3.00 DRILL P PROD1 Correlate GR / FPT at 6833, 6839, 6854 ft. Prepare resume MDT logs. 6/26/2001 00:00 - 06:00 6.00 DRILL P PROD1 Cont E-logs, MDT, DPC, oil sample 6802, press intervals at 6884, 6991,6994, 6999, 7162, 7166, 7184 ft. 06:00 - 06:30 0.50 DRILL P PROD1 Poh to sdes, install wireline wiper. 06:30 - 07:30 1.00 DRILL P PROD1 Remove clamp, poh wireline. 07:30 - 09:00 1.50 DRILL P PROD1 Lay dn jt 4" dp, sdes, lay out all wireline related equip. 09:00 - 09:30 0.50 DRILL P PROD1 Flow check, pump wt pill, prepare poh. 09:30 - 13:00 3.50 DRILL P PROD1 Poh to 9 5/8 shoe. No abnormal conditions. Flow check, cont poh to hwdp. 13:00 - 15:00 2.00 DRILL P PROD1 Flow check, handle bha, lay out log tools, retrieve samples, clear floor. 15:00 - 18:30 3.50 DRILL P PROD1 Install test plug, test bope as follows: Rams 250 / 4000 15 min, annular 250 / 3500 15 min, Kill line, stack to pumps 250 / 4000 15 min, Choke mnfld 250 ! 4000 15 min, standpipe top dry to pumps - all valving 250 / 4000 15 min, floor valves 250 / 4000 15 min. Accumulator to BP specs. All tests successful, no re-tests, witness waived by Gremaldi AOGC. 18:30 - 19:30 1.00 DRILL P PROD1 Handle / make up clean out bha assy, rih same. 19:30 - 00:00 4.50 DRILL P PROD1 Flow check, follow bha with 4" dp to 7800 ft, breaking circ at 2720, 6200 ft. Full returns, well bore good cond. 6/27/2001 00:00 - 01:00 1.00 DRILL P PROD1 Cont rih 4" dp to 9345 ft, encounter fill / bridge. 01:00 - 02:30 1.50 DRILL P PROD1 Flow check, begin wash / ream 9345 - 9528 ft. Up 268, Dn 149, Rot 195, Torq 13K 02:30 - 05:30 3.00 DRILL P PROD1 Circ / cond mud, pump hi-vis sweep, note shakers clean, spot csg pill. 05:30 - 06:30 1.00 DRILL P PROD1 Flow check, poh, tight hole 9300 ft. 06:30 - 09:00 2.50 DRILL P PROD1 Backream to 8970 ft. Increased cuttings returns, ream to btm at 9528 ft. 09:00 - 10:30 1.50 DRILL P PROD1 Circ / cond mud, wt up to 11#, pump hi-vis sweep, receive sweep at surface, shakers clean. Printed: 9/25/2001 11:32:46 AM BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/27/2001 .10:30 - 12:00 1.50 DRILL N RREP 'PROD1 Replace saver sub and XO at top drive. ~12:00 - 16:30 4.50 DRILL P PROD1 Flow check, resume circ / cond, increase mud wt to 11 ppg, Spot 300 bbls TorqTrim csg pil. 16:30 - 23:00 6.50 DRILL P PROD1 Flow check, poh 4" dp, stand back 28 stds. Work tight intervals at 8980, 8320, 7090 ft. No reaming, circ. Resume poh to bha. 23:00 - 00:00 1.00 DRILL P PROD1 PU 4 jts hwdp, stand back same. Begin lay dn DCs. 6/28/2001 00:00 - 01:00 1.00 DRILL P PROD1 Cont lay dn remainder bha. 01:00 - 04:30 3.50 CASE P COMP Prepare and change to 7" rams, test same 3000 psi ! 15 min. 04:30 - 05:00 0.50 CASE P COMP Perform test run, land 7" hgr with Idg jt, record space out. 05:00 - 07:30 2.50 CASE P COMP PJSM, rig up Franks fill tool, change to long bales. 07:30 - 19:00 11.50 CASE =P COMP Commence make up 7" 26#, L80 BTC-M, shoe track. Thread lock guide shoe, 2 jts csg, float collar. Follow with 28 jts 7" 29#, Cr-95 VAM-Ace. Cont rih with 7" 26# to btm. 19:00 - 22:30 3.50 CASE P COMP Rig dn Franks tool, rig up loaded cmt hd, Stage circ slowly to 8 bpm. Note losses, cut back to 6 bpm, resume circ with full returns. Can not recip csg. 22:30 - 00:00 1.50 CASE P COMP PJSM, Test lines to 4000 psi, pump 5 bbls fresh water, drop btm plug, pump 75 bbls 11.5 ppg mud push, 105 bbls 12 ppg lead sluury, 6 bpm, 31 bbls 15.8 tail slurry., drop upper plug, flush lines with 10 bbls water, pump 30 bbls perf pill. Partial displace with rig pumps, salt water. 3500 strokes. 6/29/2001 00:00 - 01:30 1.50 CASE P COMP Cont displace cmt dn 7"csg, bump plug 1145 hrs with 330 bbls, 5660 stks. Build to 3000 psi, hold 30 rain, bleed, check floats. Floats holding. 01:30 - 05:00 3.50 CASE P COMP Back out Idg jt, drain / wash bop stack, install 7 X 9 5/8 pkf. 05:00 - 08:30 3.50 CASE P COMP Set RTTS pkr below ground level, test pkr / 7" pkf to 2500 psi 15 min. Test successful. 08:30 - 12:00 3.50 CASE P COMP Nipple dn bope for tbg hd install. 12:00 - 15:30 3.50 CASE P COMP Install tbg hd, test 7" PKF TO 4000 PSI. Good test. 15:30 - 20:00 4.50 CASE P COMP Nipple up bope to tbg hd, change to variable rams, test to 4000 psi / 15 min. Test good. 20:00 - 21:30 1.50 CASE P COMP Release RTTS, poh, lay out pkr, all related test equip, tubulars. 21:30 - 22:00 0.50 CASE P COMP Test 7" csg to 4000 psi / 30 min. Test successful. 22:00 - 00:00 2.00 RUNCOI~P COMP Place tbg handling tools on rig floor, rig up same, while injecting 93 bbls 11 ppg down 7 X 9 5/8 annulus. Initial press breakover 450 psi, final 520 psi @ 1 bpm. 6/30/2001 00:00 - 00:30 0.50 RUNCOI~P COMP Cont rig up, make ready for 4 1/2 completion. 00:30 - 17:00 16.50 RUNCOI~P COMP PJSM, make up comp bha, Baker S3 pkr assy, 5 GLM with dummy installed, 1 GLM with RP shear valve, follow with 4 1/2 Vam Ace prod tbg to landing point. 8762 ft. Pump 60 bbl crude with Lil Red dn 7 X 9 5/8 annulus, while run tbg. 1.8 bpm @ 1000 psi. 17:00 - 18:30 1.50 RUNCOI~P COMP Make up tbg hgr, landing jt with circ hoses and safety valve. Lay out tbg handling equip, load out and release. 18:30 - 23:00 4.50 RUNCOI~I~I WAIT COMP Wait on tanker trucks / service personnel due to road closure. Accident blocking road. 23:00 - 00:00 1.00 RUNCOr~!:) COMP Take delivery truck arrival, commence reverse circ / displace well sea water with Corexit treated comp fluid. 7/1/2001 00:00 - 01:00 1.00 RUNCOr~P COMP Complete displacement with Corexit, 3 bpm @280 psi. Printed: 9/25/2001 11:3;~:46 AM BP EXPLORATION Page 8 of 8 Operations Summa Report Legal Well Name: L-01 Common Well Name: L-01 Spud Date: 6/8/2001 Event Name: DRILL+COMPLETE Start: 6/4/2001 End: Contractor Name: NABORS Rig Release: 'Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/1/2001 01:00 - 04:30 3.50 RUNCOI~ COMP Flow check, Ind hgr. Drop ball, lay dn Idg jt. Press tbg to 4000 psi to set pkr, hold press 30 min. Bleed tbg to 2000 psi, build 4000 psi on 7 X 4 1/2 annulus. Hold press 30 min. Bleed tbg to "0" psi to shear RP. Bleed all pressures. All tests successful. No re-test. 04:30 - 05:00 0.50 RUNCOI~ COMP Inspect top dry quill. 05:00 - 07:30 2.50 RUNCO~' COMP Set TWC, nipple dn bope. 07:30 - 10:30 3.00 RUNCOI~' COMP Nipple up prod tree. 10:30 - 11:30 1.00 RUNCOI~ COMP Test tree, tbg hd adptr, all flanges / seal areas to 5000 psi. All tests successful. No re-test. 11:30- 12:30 1.00 RUNCO~P COMP Rig up lubricator, pull TWC. Flow check. 12:30 - 15:00 2.50 RUNCO~ COMP Manifold in to tree / annulus, freeze protect. Pump 75 bbls diesel dn 4 1/2 X 7 annulus, allow controlled "U" tubing. 15:00 - 16:00 1.00 RUNCO~ COMP Set BPV, secure well. Release Nabors rig 9-ES this date at 1600 hrs. Printed: 912512001 11:32:46AM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Prudhoe Bay Field well ..................... : L-01 API number ............... : 50-029-23011-00 Engineer ................. : COUNTY: .................. : Nabors 9ES STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 48.70 ft KB above permanent ....... : N/A DF above permanent ....... : 76.70 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 140.35 degrees 19-Jun-2001 08:39:20 Page 1 of 5 Spud date ................ : 08-Jun-01 Last survey date ......... : 19-Jun-01 Total accepted surveys...: 105 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9528.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 08-Jun-2001 Magnetic field strength..: 1148.96 HCNT Magnetic dec (+E/W-) ..... : 26.33 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1148.96 HCNT Reference Dip ............ : 80.74 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.33 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.33 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 109.66 0.06 127.97 3 164.73 0.10 127.97 4 238.50 0.33 169.71 5 331.96 0.84 144.06 6 420.48 1.39 149.07 7 515.74 2.06 156.94 8 612.29 3.29 159.86 9 710.03 4.94 165.06 10 760.35 4.90 166.00 0.00 109.66 55.07 73.77 93.46 88.52 95.26 96.55 97.74 50.32 11 854.61 4.11 162.34 94.26 12 946.16 5.63 169.56 91.55 13 1037.47 8.42 167.82 91.31 14 1133.03 11.45 171.50 95.56 15 1225.81 11.89 163.91 92.78 16 1322.74 11.85 159.05 17 1414.27 13.61 151.52 18 1507.04 15.68 139.07 19 1601.73 15.23 135.11 20 1695.37 17.63 133.67 21 1790.24 20.97 137.52 22 1883.06 22.22 139.62 23 1975.00 23.43 139.09 24 2068.55 27.96 138.66 25 2162.03 28.24 138.48 26 2255.98 30.44 137.65 27 2348.77 32.53 137.61 28 2440.03 35.18 136.86 29 2535.00 35.60 135.40 30 2628.95 34.96 134.97 96.93 91.53 92.77 94.69 93.64 94.87 92.82 91.94 93.55 93.48 93.95 92.79 91.26 94.97 93.95 19-Jun-2001 08:39:20 Page 2 of 5 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 0.00 0.00 0.00 109.66 0.06 -0.04 164.73 0.13 -0.08 238.50 0.38 -0.33 331.95 1.30 -1.15 420.46 3.01 -2.60 515.67 5.79 -5.16 612.12 10.06 -9.36 709.60 16.53 -16.06 759.74 20.44 -20.24 853.70 944.92 1035.54 1129.65 1220.52 1315.38 1404.66 1494.44 1585.71 1675.52 27.20 -27.36 34.16 -34.91 44.00 -45.85 58.33 -62.07 74.97 -80.37 93.55 -99.25 113.02 -117.50 136.27 -136.57 161.45 -155.05 187.79 -173.56 219.02 -196.01 253.16 -221.63 288.82 -248.68 329.36 -279.22 373.37 -312.23 419.36 -346.47 467.77 -382.27 518.53 -419.58 573.37 -459.23 627.42 -497.72 0.00 0.05 0.11 0.19 0.64 1.58 2.84 4.48 6.53 7.60 9.60 11.41 13.64 16.51 20.52 26.85 35.35 48.77 65.93 84.87 106.73 129.32 152.56 179.24 208.37 239.14 271.80 306.32 344.44 382.69 1765.05 1851.35 1936.09 2020.37 2102.83 0.00 0.06 0.13 0.38 1.32 3.04 5.89 10.38 17.34 21.62 29.00 36.73 47.83 64.23 82.94 102.82 122.70 145.02 168.49 193.20 223.18 256.60 291.75 331.80 375.38 420.99 469.05 519.50 574.05 627.83 0.00 127.97 127.97 149.57 150.74 148.73 151.17 154.45 157.89 159.41 160.66 161.90 163.44 165.10 165.67 164.86 163.26 160.35 156.96 153.94 151.43 149.74 148.47 147.30 146.28 145.39 144.59 143.87 143.13 142.44 2184.72 2263.85 2339.63 2417.05 2493.75 0.00 0.05 0.07 0.36 0.60 0.63 0.74 1.28 1.73 0.18 0.89 1.79 3.06 3.24 1.72 1.03 2.64 4.05 1.21 2.60 3.77 1.58 1.33 4.85 0.31 2.38 2.25 2.94 0.99 0.73 Srvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report 19-Jun-2001 08:39:20 Page 3 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) depth (ft) 31 2716.05 34.49 134.82 87.10 2565.33 32 2813.16 33.21 134.81 97.11 2645.98 33 2904.57 32.28 134.48 91.41 2722.86 34 2998.26 31.40 139.78 93.69 2802.47 35 3092.10 30.56 139.50 93.84 2882.92 36 3186.46 29.89 139.55 94.36 2964.46 37 3276.66 27.51 139.59 90.20 3043.57 38 3369.67 26.47 135.72 93.01 3126.45 39 3463.46 24.75 135.46 93.79 3211.03 40 3556.90 22.68 138.45 93.44 3296.57 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 676.81 -532.74 730.64 -570.87 779.84 -605.61 829.15 -641.79 877.44 -678.59 417.83 456.20 491.38 525.00 556.28 924.94 -714.73 968.25 -747.69 1010.39 -778.89 1050.79 -807.86 1088.29 -835.28 587.11 615.20 643.60 671.97 697.64 41 3649.59 21.18 136.91 92.69 3382.56 1122.87 -860.89 720.93 42 3742.98 19.58 135.59 93.39 3470.10 1155.30 -884.39 743.41 43 3836.30 17.96 135.43 93.32 3558.45 1185.22 -905.81 764.45 44 3928.91 15.69 137.33 92.61 3647.09 1211.96 -925.19 782.96 45 4024.72 14.93 138.74 95.81 3739.50 1237.23 -943.99 799.88 46 4116.25 13.56 136.87 47 4211.48 12.37 137.09 48 4302.37 10.57 136.06 49 4396.74 8.85 135.02 50 4490.18 7.45 141.41 3828.22 1259.73 -960.69 3921.02 1281.06 -976.31 4010.09 1299.09 -989.44 4103.10 1314.95 -1000.81 4195.60 1328.17 -1010.63 4287.65 4381.06 4474.24 4566.72 4659.71 4755.71 4848.89 4941.72 5036.51 5129.78 51 4582.90 6.31 135.92 52 4676.72 4.38 134.18 53 4770.09 2.78 126.16 54 4862.63 1.48 98.36 55 4955.63 0.71 320.25 56 5051.63 0.22 247.62 57 5144.81 0.35 171.95 58 5237.65 0.37 177.68 59 5332.44 0.53 179.98 60 5425.71 0.56 181.09 91.53 95.23 90.89 94.37 93.44 92.72 93.82 93.37 92.54 93.00 96.00 93.18 92.84 94.79 93.27 814.99 829.57 841.98 853.12 861.98 1339.26 -1018.99 1347.96 -1025.19 1353.70 -1029.01 1356.77 -1030.51 1357.08 -1030.24 869.28 875.43 879.82 882.81 883.63 1356.43 -1029.85 1356.62 -1030.20 1357.10 -1030.78 1357.68 -1031.53 1358.36 -1032.42 883.08 882.96 883.01 883.02 883.01 At Azim (deg) 677 730 779 829 877 924 968 1010 1050 1088 1122 1155 1185 1212 1237 1259 1281 1299 1315 1328 1339 1348 1353 1356 1357 1356 1356 1357 1357 1358 .O5 .76 .89 .16 .46 .95 .26 .39 .79 .30 .88 .33 .27 .02 .31 .82 .16 .20 .08 .30 .40 .11 .86 .95 .28 .62 .81 .28 .86 .53 141.89 141.37 140.94 140.72 140.66 140.60 140.55 140.43 140.25 140.13 140.06 139.95 139.84 139.76 139.72 139.69 139.65 139.60 139.55 139.54 139.53 139.51 139.47 139.41 139.38 139.39 139.40 139.42 139.44 139.46 DLS (deg/ 100f) 0.55 1.32 1.04 3.13 0.91 0.71 2.64 2.19 1.84 2.56 1.73 1.78 1.74 2.52 0.88 1.58 1.25 1.99 1.83 1.78 1.42 2.06 1.79 1.76 2.22 0.71 0.39 0.04 0.17 0.03 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report 19-Jun-2001 08:39:20 Page 4 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5518.92 0.43 188.92 62 5612.75 0.51 194.88 63 5705.00 0.49 184.39 64 5801.44 0.55 185.65 65 5894.50 0.59 196.38 93.21 93.83 92.25 96.44 93.06 66 5988.15 0.74 204.73 67 6080.65 0.86 221.98 68 6170.58 0.91 227.17 69 6265.47 0.46 164.88 70 6360.49 0.61 170.28 93.65 92.50 89.93 94.89 95.02 71 6451.16 0.80 202.29 72 6544.00 1.07 210.23 73 6639.57 0.83 116.11 74 6733.65 1.39 104.28 75 6826.72 1.14 104.71 90.67 92.84 95.57 94.08 93.07 76 6920.81 1.23 105.30 77 7013.84 1.25 108.86 78 7105.41 1.14 115.76 79 7198.42 0.97 119.42 80 7291.79 0.95 116.81 94.09 93.03 91.57 93.01 93.37 81 7383.90 0.93 141.14 82 7477.74 0.94 145.13 83 7571.62 1.30 119.01 84 7665.18 1.45 113.78 85 7757.35 1.35 120.77 92.11 93.84 93.88 93.56 92.17 86 7850.17 1.46 116.72 87 7942.21 1.58 116.69 88 8035.70 1.44 117.70 89 8128.66 1.28 121.34 90 8221.03 0.69 131.61 92.82 92.04 93.49 92.96 92.37 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 5222.98 5316.81 5409.06 5505.49 5598.55 5692.19 5784.68 5874.60 5969.49 6064.50 6155.17 6247.99 6343.56 6437.62 6530.66 6624.73 6717.74 6809.29 6902.29 6995.64 7087.74 7181.57 7275.43 7368.96 7461.11 7553.90 7645.91 7739.36 7832.30 7924.65 1358.94 -1033.22 1359.41 -1033.97 1359.93 -1034.76 1360.56 -1035.63 1361.14 -1036.53 882.95 882.79 882.65 882.57 882.40 1361.67 -1037.55 1362.03 -1038.60 1362.17 -1039.59 1362.56 -1040.47 1363.34 -1041.34 882.01 881.29 880.32 879.86 880.05 1364.06 -1042.40 1364.66 -1043.75 1365.60 -1044.82 1367.14 -1045.40 1368.81 -1045.92 879.89 879.21 879.38 881.10 883.09 1370.39 -1046.42 1372.08 -1047.01 1373.76 -1047.73 1375.33 -1048.52 1376.78 -1049.26 884.97 886.89 888.66 890.17 891.55 1378.23 -1050.19 1379.76 -1051.41 1381.52 -1052.56 1383.56 -1053.55 1385.63 -1054.58 892.70 893.62 894.99 897.01 899.01 1387.74 -1055.67 1389.98 -1056.76 1392.24 -1057.89 1394.30 -1058.97 1395.83 -1059.88 901.00 903.18 905.37 907.29 908.59 1359.09 1359.56 1360.07 1360.69 1361.26 139.48 139.51 139.54 139.56 139.59 1361.78 1362.12 1362.24 1362.62 1363.40 139.63 139.68 139.74 139.78 139.80 1364.11 1364.70 1365.64 1367.19 1368.86 139.83 139.89 139.91 139.87 139.83 1370.46 1372.16 1373.85 1375.43 1376.89 139.78 139.73 139.70 139.67 139.65 1378.34 1379.86 1381.63 1383.69 1385.76 139.63 139.64 139.63 139.59 139.55 1387.89 1390.14 1392.42 1394.49 1396.02 139.52 139.48 139.44 139.41 139.39 DLS (deg/ 100f) 0.16 0.10 0.10 0.06 0.12 0.19 0.29 0.11 0.85 0.17 0.47 0.32 1.47 0.64 0.27 0.10 0.09 0.20 0.20 0.05 0.43 0.07 0.66 0.21 0.21 0.16 0.13 0.15 0.20 0.66 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report 19-Jun-2001 08:39:20 Page 5 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8317.41 4.64 130.73 92 8411.37 8.55 139.67 93 8503.99 8.46 140.25 94 8596.63 9.56 137.74 95 8691.32 13.53 128.52 TVD VerticaI Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) _ (ft) (ft) (ft) (deg) 96.38 8020.91 1400.25 -1062.81 911.98 1400.45 139.37 93.96 8114.23 1410.98 -1070.62 919.38 1411.20 139.35 92.62 8205.83 1424.68 -1081.10 928.20 1424.90 139.35 92.64 8297.33 1439.18 -1092.04 937.73 1439.40 139.35 94.69 8390.09 1457.89 -1104.76 951.69 1458.15 139.26 96 8784.21 14.34 131.82 92.89 8480.25 1479.90 -1119.20 968.76 97 8876.71 13.43 132.52 92.50 8570.04 1501.87 -1134.10 985.22 98 8970.69 12.78 132.23 93.98 8661.58 1522.97 -1148.46 1000.96 99 9064.24 11.67 132.96 93.55 8753.00 1542.60 -1161.86 1015.54 100 9157.81 11.01 134.31 93.57 8844.75 1560.87 -1174.55 1028.86 92.93 94.10 90.85 20.68 101 9250.74 10.63 133.73 102 9344.84 10.28 134.36 103 9435.69 9.83 133.71 104 9456.37 9.70 134.64 71.63 Final Projected Survey at TD 105 9528.00 9.26 138.00 1480.24 139.12 1502.27 139.02 1523.44 138.93 1543.13 138.84 1561.45 138.78 8936.02 1578.21 -1186.68 1041.41 1578.84 138.73 9028.56 1595.18 -1198.55 1053.68 1595.86 138.68 9118.02 1610.94 -1209.57 1065.08 1611.67 138.63 9138.40 1614.43 -1212.02 1067.60 1615.16 138.62 1626.19 -1220.54 1075.75 9209.05 1626.95 138.61 DLS (deg/ 100f) 4.10 4.29 0.13 1.26 4.61 1.22 1.00 0.70 1.20 0.76 0.43 0.39 0.51 0.99 0.99 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Projected [(c)2001 Anadrill IDEAL ID6 lC 10] 09/13/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1454 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 16-06A r--'~(~/"'"Oi"')~'"' 21371 MGR (PDC) 02/23/01 H-3?A ,:::~0 -(~ ':"'1 21368 MGR 09/01100 L-0t '~ ~% t -- £"~'-) ~, 21375 FRAC ADVISOR TVD (KUPARUK SECTION) 06/19/01 2 L-01 ~;~[-J' ~/ I C:~ 21378 FRAC ADVISOR TVD (SCHRADER BLUFF) 06/19/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Rece 07/26/01 Schlumberger NO. 1332 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay )~0'~ ~ Color Well Job # Log Description Date Blueline Sepia Prints CD L-01 21319 PROCESSED DSI & CROSS DIPOLE ANISOTROPHY RESULTS 06/19101 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~j- ~: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received by: '"~---~'~c.~ ,- ~// bp BPXA WELL DATA TRANSMITTAL Date: 06-22-2001 Transmittal Number:92148 Enclosed are the materials listed below. ~-h;o ~,,~ :~ ,.~: ..... , *. ...... o~, ................. ~, ..... acpaza~ ,~,~c ..... the confia_.anti~.~naturc, If you have any questions, please contact me in the PDC at 564-4091. SW Name ,Date Media Title L-01 06-19-2001 Paper Directional Survey; (Hardcopy) Survey Report; Diskette Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) RECEIVED JUN 2 2 2001 ~Oil&O~sCons.~ Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ALASKA 01L AND GAS CONSERYA~ION COPl~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Neil Magee Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit L-01 BP Exploration (Alaska) Inc. Permit No: 201-072 Sur Loc: 2392' NSL, 3659' WEL, SEC. 34, T12N, R11E, UM (Planned) Btmhole Loc. 1129' NSL, 2568' WEL, SEC. 34, T12N, R11E, UM Dear Mr. Magee: Enclosed is the approved application for permit to drill the above referenced well, The permit to drill does. not exempt you from obtaining additional Permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 2 ~ ¥'~ day of April, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~.;' ALASKA (~',,.. AND GAS CONSERVATION COMMI~,. ON PERMIT TO DRILL 20 AAC 25.005 -- ~ [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Drill [] Redrill1 lb. Type of well [] Service [] Development Gas [] Single Zone [] Re-Entry [] Deepen [] Multiple Zone __ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 77.0' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2392' NSL, 3659' WEL, SEC. 34, T12N, R11E, UM (Planned) Prudhoe Bay Unit At top of productive interval 8. Well Number 1340' NSL, 2761' WEL, SEC. 34, T12N, R11 E, UM L-01 Number 2S100302630-277 At total depth 9. Approximate spud date 1129' NSL, 2568' WEL, SEC. 34, T12N, R11 E, UM 05/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028241, 1129' MDI No Close Approach 2560 9450' MD/9100' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 4000' MD Maximum Hole Angle 19.00 ° Maximum surface 3282 psig, At total depth (TVD) 8940' / 4176 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casing Wei,qht Grade Coupling Length MD TVD MD TVD (include stare data) 30" 20" 91.5# H-40 WLD 80' Surface Surface 109' 109' ;)60 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 2450' Surface Surface 2450' 2450' 377 sx Arctic Set Lite, 202 sx Class 'G' 8-3/4" 7" 26# L-80 / 13Cr BTC-U / NSCC 9450' Surface Surface 9450' 9100' 177 sx Class'G', 178 sx Dowell LiteCrete 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Intermediate ....... ~" '~ "+'" '~¢ Production Liner ~ ~':)I;~ :l. '7 ~ 0 O 1 Alaska, ",[)ii ,L ,Gas Corm, Commissior,~ Armhoraqe Perforation depth: measured true vertical ~20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neff Magee, 564-5119 Prepared By Name/Number: Sondra Stewman, 564-47'50 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone <::~... ';¢¢1. ~ Title Senior Drilling Engineer Date '.t I :.:.? !.!. :; ..:: :... :. '.: !'.' !: '.'.?'.' '..:.:':::.':..:::.: .;'i:': ~' :.':.:: ;.:;. ;.: ;;:, ..;:.~::,:...,:.;':,.'~?..;~,:,:~om~m:,is,~ibii:. u~:,..'0~i~;!:..'i: !'!.'?:.!,~.: i:. ::.~.: :',!.. ?.,.",' i :'!'..,; ;..::;~:.~ ,.:?. ::.:.;.i~, !..:~.; i'!:.,. :!. :,..;...;:: :i?!.i), :/..:;.:.~. :'"Permit~:"::'"'"'"": :':!'.'.:'i., ::.";.'.:"';.i'...:?.,:,.':;:;";".:".:;. ,Number I APl N'umber ........... "'" ...... i""Ap aQa ' "prov-I"' te ...... I See'c;:)~er letier ........ zo/-- o z I 0- o*- ?--- z IZ-/(~],~'7 ,L/',,) / I for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log~equired [] Yes J~! No Hydrogen Sulfide Measures [] Yes ~ No Directional Survey Required ~[Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~I~.5K psi Other: )RiGINAL SIGNED BY O Taylor Seamount by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate [Well Name: IL-01 Drill and Complete Plan Summary I Type of Well (service ! producer / injector): I Producer Surface Location: Target Location: Kuparuk Target Location: Ivishak Bottom Hole Location: X = 583,256.2 Y = 5,978,114.8 2392' FSL 3659' FEL S34 T12N, R11E X = 584,168.04 Y = 5,977,073.0 1340' FSL 2761' FEL S34, T12N, R11E X = 584,295.59 Y = 5,976,937.12 1203' FSL 2636' FEL S34, T12N, R11E X = 584,363.64 Y = 5,976,864.13 1129' FSL 2568' FEL S34, T12N, R11E I AFENumber: 14P1698 I I Estimated Start Date: 15/15/2001 I~D:19~50' I I TW=19100' I Ri~l: I Nabors 7ES I Operating days to complete: 118 I BE/MS= 147' I tEES= 177.0' I Well Design (conventional, slimhole, etc.): I Ultra-Slim I Obiective: I Ivishak Formation 4A/4B Mud Program: 12-1!4" Surface Hole (0-2450'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV pH Fluid (ppg) (seconds) (Ib/100ft2) Loss Initial 8.5-8.6 300 .50-70 20-25 8.5-9.5 15-20 Interval TD 9.0-9.6 100 25-35 12-19 8.5-9.5 <10cc 8-3/4" Production/Interval (2450'-9450') Fresh Water LSND Interval Density 15V YP' MBT APl FL HTHP pH (ppg) (cp) Filtrate Production 10.8 15-18 20-24 <8 <3 <7.5 8.5-9.5 Hole L-01 Permit to Drill Page 1 Directional: KOP: 14000' Maximum Hole Angle: Close Approach Wells: 19° at 4460' MD - Intermediate hole There are no close approach issues Evaluation Program: Surface Logging Production Hole Logging and Coring Drilling' MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Sonic / Neu / Den Formation Samples Open Hole: PEX / Dipole Sonic, MDT w/samples Cased Hole: USIT (Contingency) Formation Markers: Formation Tops MD SS TVDss Comments Base Permafrost 1877' 1800 8.5 Estimated pore press, ppg SV3 1930 1853 8.5 .... SV 2 2116 2039 8.5 .... SV1 2423 2346 8.5 .... UG4 2857 2780 8.8 .... UG4A 2893 2816 8.8 .... UG1 3485 3408 8.8 .... Top Schrader Bluff 3834 (MA sand) 3757 8.8 .... Schrader Oa (WS1) 4140 8.7 .... Base Schrader Bluff (Obf base) 4478 8.6 .... eM2 4808 8.5 .... CMl 5357 8.5 .... THRZ 6006 8.5 .... BHRZ 6177 8.5 .... TKUP 6370 10.4 " " LCU 6488 10.4 " " TMLV 6769 8.5 .... TKNG 7730 8.5 .... TJF 7730 8.5 .... TJE 7904 8.5 .... TJD 8031 8.5 .... TJC 8338 8.5 .... TJB 8428 8.5 .... TJA 8492 8.8 .... TSGR 8590 9.0 .... L-01 Permit to Drill Page 2 Shublik A 8630 9.0 .... Shublik B* 8707 9.0 Shublik C 8722 9.0 " " Shublik D 8744 9.0 " " TElL 8758 9.0 " " TSAD 8790 9.0 " " HOT 8940 9.0 " " POWC 8945 TD Criteria: Below the base of the OWC to allow sufficient rat hole for logging. Planned tvdss -9100' Casincl/Tubing Proqram: '~P' V ""liP' Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/I'VD ss 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC 2450 GL 2450'/2450' 8-3/4" 7" 26# L-80 BTC-M -8500' GL 8500'/8440' 8-3/4" 7" 26# 13Cr NSCC -850' 8500 9450'/9100' Tubing 4-1/2" 12.# 13Cr Prem -8800' GL 8750' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casinc. Size 19-5/8" Surface Basis: Lead: Based on 1800' of annulus in the permafrost @ 175% excess and 150' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe tract volume. Tail TOC: At -1950' MD ITotal Cement Volume: Lead 299 bbl / 1677 ft~ / 377 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 42 bbl / 235 ft~ / 202 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. There may be a requirement to bring cement to 1000' above the top of the Kuparuk at 6370' TVDss. Casing Size 17" Production Tail I ~ " Basis: I Tail: to 8450' MD and 30% excess + shoe track Total Cement Volume: I Tail 138 bbls / 215 ftc/177 sks of Dowell Premium G blend at I 1 15.8ppg and 1.20 cf/sk. Casing Size 17" Pr°ducti°n Lead Basis: I Lead: Lead/te-~00' above the Kuparuk plus 30% excess I Lead TO(~ 557~7~MD, BOC at 8450' Total Cement Vo~,tl~ I Lead I 100bbls/561 ftc/178 sks of Dowell"LiteCrete" at 11.7 '~l I PPg and 3.16 cf/sk. L-01 Permit to Drill Page 3 Well Control: Surface hole will be drilled with a diverter. See L-Pad Data sheet regarding potential charged up surface casing on S-30 as a result of a potential gas leak -gas lift gas at 1200 psi. Well control equipment consisting of 5000 p~i working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed on surface casing and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- - Maximum anticipated BHP: · Maximum surface pressure: 4176 psi @ 8940' TVDss - Base Ivishak Target 3282 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fO · Planned BOPtest pressure: 3500 psi · Planned completion fluid: 8.6 ppg seawatedPerf pill/6.8 ppg Diesel Drilling Hazards/Contingencies: Hydrogen Sulfide- H2S: L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. Surface Hole Section: · Gas hydrates were observed by both the NEW 1-01 and 1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. They may be encountered again near the surface shoe setting depth in the SV4, SV3, SV2 and SV1 to 2500' SS. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation. · Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) · Note that S-30 has reported 1200 psi pressure on the outer annulus S-30 is approximately 7 miles from L-Pad and the effects are not expected to reach L-Pad. Precautions should be taken while drilling the through the upper Sagavanirktok (1660' to 2700' SS) until the casing leak can be repaired. · The effects of Cretaceous over-pressure from produced water injection will probably not be seen at L-Pad. · No faults are mapped in the direction of the well plan surface hole. L-01 Permit to Drill Page 4 Production Hole Section: · Note that S-30 has reported 1200 psi pressure on the outer annulus S-30 is approximately 7 miles from L-Pad and the effects are not expected to reach L-Pad. Precautions should be taken while drilling the through the upper Sagavanirktok (1660' to 2700' SS) until the casing leak can be repaired. · A fault is anticipated in the HRZ/Kalubik at approximately 6294' TVD ss. Estimated throw is 170' in a Westerly direction. · A fault is anticipated in the Kingak (TJF) at approximately 7834' TVD ss. Estimated throw is 140' in a Southerly direction. · A fault is anticipated in the Kingak (TJE) at approximately 7884' TVD ss. Estimated throw is 40' in a Westerly direction. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-01 Permit to Drill Page 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig ~'~, ~ 1. ~,,~k~-C' 2. 3. 4. 5. 6. 7. Operations: Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. MU 12-1/4" drilling assembly and drill surface hole. The actual surface hole TD will be +/-100' TVD below the SV1 sand top. Run and cement the 9-5/8", 40# L-80 surface casing back to surface. A TAM port collar will be positioned at +1000' as contingency in the event cement does no fully circulate to surface. ND drilling spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. MU 8-3/4" directional drilling assembly with tri-cone bit and RIH to float collar. Test the 9-5/8" casing to 3000 psi for 30 minutes. Drill out shoe track while displacing well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a FIT to 12.5 ppg EMW. Directionally drill through KOP at 4000' and build well to 18.74 degrees at an azimuth of 139 degrees. Drill ahead or trip for PDC as ROP/bit life dictates and drill ahead to TD maintaining sail angle and direction to 100' below the base of the OWC at 8945' TVD ss (prognosed). 8. TD is based on providing 15' of rathole below the float collar after running casing. 9. Perform PEX +Borehole Sonic wireline log. Run MDT (plan on wireline conveyed) and perform pretests and sample as directed. Perform wiper trip, circulate and condition mud and POH. Lay down excess drillpipe. Retrieve bowl protector 10. MU and run 7" 26#/ft 13Cr/L-80 long string casing to TD and cement to 1000' above the Kuparuk at 6370' TVD ss as per Dowell cement program. Displace cement with seawater/perf pill and bump plug to 3500 psi. 11. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000'TVD. 12. MU 4-1/2" 13CR completion assembly and RIH. See completion schematic and Baker recommendation for details. Reverse circulate well over to clean seawater weighted with KCl to provide required overbalance for perforating. 13. Land tubing hanger and test hanger pack-off to 5000 psi. 14. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3500 psi and annulus to 3500 psi. Shear RP valve in preparation for installation of TWC. 15. Install two-way check and test to 3300 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Pull two-way check. Freeze protect the tubing and annulus to 2000' TVD. 17. Install BPV. Secure the well and rig down / move off 7ES. Neil Magee BP Alaska Drilling and Wells 564-5119 mageedn@BP.com L-01 Permit to Drill Page 6 TREE= Cam 4-1/16" , WELLHEAD= FMC 5M ACTUATOR= KOP = 4100q'VD ss Max 'A ~'~i~' '= ........ 'i 9 '@Z{460' Datum MD = Datum TV D= I 9-5/8" 401b/ft L-80 2450' 4-1/2" 13Cr 12.61b/ft I I Sur'8756'l L-01 Proposed 8690' 8756' SAFETY NOTES I GAS LIFT MANDRELS KBG-2 I BK-S I K~S-~ i E~K-S I I ,r2'x am3' I PERFORATION SUMMARY REF LOG: ANGLE ATTOP PERF: I I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" 261b/ft L-80 above packer 7" 291b/ft 13CR below packer 9450' DATE REV BY COMMENTS 04/01/01 NM Proposed Completion PRUDHOE BAY UNIT WELL: L-01 PERMIT No: APl No: Sec., N, E, FEL, FNL BP Exploration (Alaska) L-01 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in both NEW offset wells. These are expected to be encountered near the base of the Permafrost at 1800' and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · On S pad well S-30 has reported 1200 psi pressure on the outer casing annulus. Although this well is some 7 miles away, precautions should be in place while drilling through the upper Sagavanirktok (1600' to 2700' SS) . Production Hole Section: The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale and Kingak shale section. Read the Shale Drilling Recommended Practice. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. Three minor faults are anticipated. 6294' TVD 7834' TVD 7884' TVD .. HYDROGEN SULFIDE- H2S · This drill-site not designated as an H2S drill site. Recent wells NEW 1-01 and NEW 1-02 did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page ! of 1 Csk'ulafio. ~e~aJ: Mi~msJmCwrau~ I~t S),~em: I SCq~/SA :Enor Surfao~: Ellip&ll · ¢'amg ANNOTATIONS No. TVD MD Annotation I 4000.00 4000.00 Start Dir 4°/100': 4000' MD, 4000'TVD 2 4460.17 4468.48 End Dir: 4468.48' MD, 4460.17' TVD 3 0.00 9449.34 Total Depth: 9449.34' MD, 9177' TVD IOOO 2000 3000 . 4000 i 5000 ~ : 6000 '~ 7000 : : : ::8000:: ~ RI-~I( ' E INFORMATION ('o-onlmle {N/E) Rcfer~ee: W¢~1C~: Plan I.-01. Trim Iv. aah V~ical {TVD) Rel-a'en~.. Temp Phn ek-v'atioe T7 T/.0 S~tkm (VS) Refenm~: S~ - S-M (0.00,0.C~) ~ ~ Rcrer¢me: T~lp Plan t:levalion C~k~l~k~ Metho~ Minimum Cu~aa~: DcpUs Fm I~'~ To 77.OO 5OO.0O Ptanr,:d: I.-OI 'WI'O2 VI .~o.oo 9449.14 ~ L-OI ~T02 VI FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8667.00 8910.79 Tsgr 2 8707.00 8953.03 Tshu 3 8867.00 9121.98 Tsad 4 9017.00 9280.38 HOT 5 90t7.00 9280.38 POWC CAS[NO DETAILS No. TVD MD Name I 2577.00 2577.00 9 5/8" 2 9176.99 9449.33 7" Size 9.62 7.00 SURVEY PRO(iR. AM Iqarc I.-oi WPO2 (PlJn I.-Ol/i%n I..nl l'(~d C~,,lled By: Aull~M~.'d U~.'.t I)-al¢: 2/I 912001 ('B-MAG-SS MWD [)al+:: .~ n~,,,~.,,i- v,q 5lJ. I)E-F^II.S Nan~ , IV4,; +E/.W Northml~ F~i~ I~d~ L,m~ilu~ Sh,I · l%n I.-OI -120.78 .~ R.0R 597~ 114.g3 ~81236.21 7tz'21'~O.615N Nam: I.-OI TA ROI'.=I' DI'.q'AILS TVI) · f~/~; , I~,.w R~67.00 .i 189.29 IO26.31 597(~J17.11 SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target I 77.00 0.00 139.21 77.00 0.00 0.00 0.00 0.00 0.00 2 4000.00 0.00 139.21 4000.00 0.00 0.00 0.00 139.21 0.00 3 4468.48 18.74 139.21 4460.17 -57.49 49.61 4.00 139.21 75.94 4 9121.98 18.74 139.21 8867.00 -1189.32 1026.29 0.00 0.00 1570.91 5 9449.34 18.74 139.21 9177.00 -1268.94 1095.00 0.00 0.00 1676.08 All TVD depths are ssTVD plus 77' for RKBE 0 1800 3600 5400 7200 9000 Vertical Section at139.21°[1800ft/in] 10800 12600 14400 16200 C~)MPANY En~' S),s~'m: ISCWSA Scan M~hod: High ~ FJvtw Snffa~: I'~lli[~:al Wam~ M~ Ru~ ~ ~OTATIONS No. ~D MD Annotation I 4000,004000.00Start Dir 4~/100': 4000' MD, 40~VD 2 4460.174468,48End ~r: 4468.48' MD, ~60.17' TVD 3 9176.999~9.33 Total Depth: 9~9.34' MD, 9177' TVD 50O- RI ~"ERI*~Ig*E INFg ~RMATII ~'q ['o-onlim~ fN/l~ P, efi:n.n~n: Wdl Ccs~. ~ L-OI, Tr~ No~h ~ion O'S) Rcf~-nmc~: Slol - S-M (0.00,0.00) Cakadlt~n Mehhod: MH/n~n C'u~v'ala~ 8I~Vl~ I~{ ~SRAM rJepth Fm ]~-~lh To Sue,'eg',~n~m~ 77.00 500.00 Ha'u~: L.OI WP02 ¥1 .'O0.00 9449.14 ~ I.-OI %T02 VI FORMATION TOP DETAILS No. TVDPath MD?ath Formation I 8667.008910.79Tsbn' 2 8707.008953.03Tshu 3 8867.009121.98Tsad 4 9017.009280.38HOT 5 9017.009280.38POWC CASING DETAILS No.TVD MD Name I 2577.002577.009 5/8" 2 9176.999449.337" Size 9.62 7.00 · I I~n; I,-01 WI'O] {Pla~ I,-Ol/Plan L-OI ) Tool I ('tc~qed Ily: Autht~ J,.M tlnt D'al¢: 21191200 I ('B-MAG-SS (q~wked: Date: MWD Reviewed: Date: A nntn¥cd' Wl:J.I. I)l~l'AllAN Plan U.OI .120.7g 25&0~ 59~114.g3 581256.21 70"21'0o.615N 14,/' I ~)'26..n,~ W L-Ol TA RG h'l' DI~AII,$ 8867.00 -IIg).2*) 1026.51 ?~6917.1:1 5x42nlS. 59 I'otylpm SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target I 77.00 0.00 139.21 77.00 0.00 0.00 0.00 0.00 0.00 2 4000.000.00 139.21 4000.00 0.00 0.00 0.00 139.21 0.00 3 4468.4818.74 139.21 4460.17 -57.49 49.61 4.00 139.21 75.94 4 9121.9818.74 139.21 8867.00 -I 189.321026.29 0.00 0.00 1570.91 5 9449.3418.74 139.21 9177.00 -1268.94 1095.00 0.00 0.00 1676.08 6000 ._ -1500- .................. : ................................... ~ ............................................... · · : · - ~' ~ i ...... ~ ' · : -500 0 All TVD depths are ssTVD plus 77' for RKBE 500 1000 1500 2000 2500 3000 3500 4000 West(-)/East(+) [500ft/in] BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/19/2001 Time: 07:33:00 Page: 1 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well: Plan L-01, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-01 Section (VS) Reference: Well (0.OOE,0.00N,139.21Azi) Wellpath: Plan L-01 Plan: L-01 WP02 '~'--~-'-~----'; --:7--'"~':-"='~-~--~:----~--"~----:~.---:------'--~:"--'--~----'~- .". ........................................................................................ ~ ~---:-~-~'~':. -- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PB L Pad UNITED STATES: North Slope Site Position: Northing: 5978232.73 ft Latitude: 70 21 1.823 N From: Map Easting: 582996.83 ft Longitude: 149 19 34.141 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.63 deg Well: Plan L-01 Slot Name: S-M Surface Position: +N/-S -120.78 ft Northing: 5978114.83 ft Latitude: 70 21 0.635 N +E/-W 258.08 ft Easting: 583256.21 ft Longitude: 149 19 26.598 W Position Uncertainty: 0.00 ff Reference Point: +N/-S -120.78 ft Northing: 5978114.83 ft Latitude: 70 21 0.635 N +E/-W 258,08 ff Easting: 583256.21 ft Longitude: 149 19 26.598 W Measured Depth: 77.00 ff Inclination: 0.00 deg Vertical Depth: 77.00 ft Azimuth: 0.00 deg Wellpath: Plan L-01 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Temp Plan elevation 77 Height 77.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/11/2001 Declination: 26.46 deg Field Strength: 57446 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ff ff deg 0,00 0.00 0.00 139.21 Plan: L-01 WP02 Date Composed: 1/15/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information MD Incl Azim TVD +N/-S i +E/-W ::: i DLS Build: Turn TFO Target 'ft deg deg ff ft : deg/100ft deg/100ft: deg/100ft deg 77.00 0.00 139.21 77.00 0.00 0.00 0.00 0.00 0.00 0.00 4000.00 0.00 139.21 4000.00 0.00 0.00 0.00 0,00 0.00 139.21 4468.48 18.74 139.21 4460.17 -57.49 49.61 4.00 4.00 0.00 139.21 9121.98 18.74 139.21 8867.00 -1189.32 1026.29 0.00 0.00 0.00 0.00 9449.34 18.74 139.21 9177.00 -1268.94 1095.00 0.00 0.00 0.00 0.00 *L-01 Section 1 : Start MD lncl Azim TVD ft deg deg ft +N/-S:: +E/'W : VS DLS Build Turn i TFO ft ft ft deg/100ft deg/100ft deg!lO0ft deg 77.00 0.00 139.21 77.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 139.21 100.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 200.00 0.00 139.21 200.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 300.00 0.00 139.21 300.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 400.00 0.00 139.21 400.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 500.00 0.00 139.21 500.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 600.00 0.00 139.21 600.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 700.00 0.00 139.21 700.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 800.00 0.00 139.21 800.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 900.00 0.00 139.21 900.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 1000.00 0.00 139.21 1000.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 1100.00 0.00 139.21 1100.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 1200.00 0.00 139.21 1200.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 1300.00 0.00 139.21 1300.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 1400.00 0.00 139.21 1400.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 BP Amoco Planning Report - Geographic Company: BP Amoco Field: Prudhoe Bay Site: PB L Pad Well: Plan L-01 Wellpath: Plan L-01 Section 1 : Start Date: 211912001 Time: 07:33:00 Page: 2 Co-ordinate(NE) Reference: Well: Plan L-01, True North Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Section (VS) Reference: Well (0.00E,0.00N,139.21Azi) Plan: L-01 WP02 MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 1500.00 0,00 139,21 1500.00 0,00 0.00 0.00 0.00 0.00 0.00 139.21 1600.00 0,00 139.21 1600,00 0,00 0,00 0,00 0,00 0.00 0.00 139.21 1700.00 0.00 139.21 1700,00 0.00 0.00 0.00 0,00 0,00 0,00 139.21 1800,00 0.00 139,21 1800.00 0.00 0,00 0,00 0,00 0.00 0,00 139,21 1900.00 0,00 139,21 1900,00 0.00 0.00 0.00 0.00 0,00 0.00 139.21 2000.00 0.00 139.21 2000.00 0,00 0,00 0,00 0.00 0,00 0,00 139,21 2100,00 0,00 139.21 2100,00 0,00 0,00 0,00 0,00 0,00 0,00 139.21 2200,00 0,00 139,21 2200.00 0,00 0.00 0.00 0.00 0,00 0,00 139,21 2300.00 0.00 139.21 2300,00 0.00 0.00 0,00 0,00 0.00 0.00 139,21 2400.00 0.00 139.21 2400,00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 2500,00 0,00 139,21 2500,00 0.00 0.00 0.00 0,00 0,00 0.00 139,21 2600.00 0,00 139.21 2600.00 0.00 0,00 0,00 0,00 0.00 0.00 139,21 2700,00 0.00 139.21 2700,00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 2800,00 0,00 139,21 2800,00 0,00 0.00 0,00 0,00 0,00 0,00 139.21 2900,00 0.00 139.21 2900,00 0,00 0,00 0,00 0,00 0.00 0,00 139.21 3000,00 0.00 139.21 3000.00 0.00 0.00 0.00 0.00 0,00 0.00 139.21 3100,00 0.00 139,21 3100,00 0,00 0,00 0,00 0,00 0,00 · 0,00 139,21 3200,00 0,00 139,21 3200,00 0,00 0.00 0.00 0.00 0,00 0.00 139.21 3300.00 0.00 139.21 3300,00 0.00 0,00 0.00 0.00 0,00 0.00 139.21 3400,00 0,00 139,21 3400,00 0,00 0.00 0,00 0,00 0.00 0.00 139.21 3500.00 0.00 139.21 3500,00 0.00 0,00 0,00 0,00 0,00 0,00 139.21 3600.00 0,00 139,21 3600.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 3700.00 '0.00 139.21 3700,00 0,00 0,00 0,00 0,00 0,00 0.00 139,21 3800,00 0,00 139.21 3800,00 0.00 0,00 0,00 0,00 0.00 0,00 139,21 3900,00 0.00 139.21 3900.00 0.00 0.00 0.00 0.00 0.00 0.00 139.21 4000.00 0.00 139.21 4000,00 0.00 0,00 0,00 0,00 0,00 0.00 139.21 Section 2: Start MD lncl Azim : TVD +N/-S: +E/-W , . DLS~ Build Turn ' TFO ft deg deg ft ft ff deg/100ft deg!100ft deg/100ft deg 4100,00 4,00 139,21 4099,92 -2,64 2,28 3,49 4,00 4,00 0,00 0,00 4200.00 8,00 139.21 4199,35 -10,55 9,11 13,94 4,00 4,00 0,00 0.00 4300,00 12.00 139.21 4297,81 -23,70 20.45 31.30 4.00 4.00 0.00 0,00 4400,00 16,00 139,21 4394,82 -42,01 36,25 55,49 4,00 4,00 0,00 0,00 4468,48 18,74 139,21 4460,17 -57,49 49,61 75.94 4,00 4,00 0,00 0.00 Section 3: Start MD Incl 'i Azim TVD +N/-S +E/-W ~ VS DLs :Build' Turn~ TFO: ' ft ~ deg :deg ft ft ~ ~ ft ft deg/100ft deg/100ft :deg/100ft deg 4500.00 18.74 139.21 4490,02 -65.16 56.23 86.06 0.00 0.00 0.00 0.00 4600.00 18.74 139.21 4584.72 -89.48 77.21 118.19 0.00 0.00 0.00 0.00 4700.00 18.74 139.21 4679.42 -113.80 98.20 150.32 0.00 0.00 0.00 0.00 4800.00 18.74 139.21 4774.11 -138.13 119.19 182.44 0.00 0.00 0.00 0.00 4900.00 18.74 139.21 4868.81 -162.45 140.18 214.57 0.00 0.00 0.00 0.00 5000.00 18.74 139.21 4963.51 -186.78 161.17 246.70 0.00 0.00 0.00 0.00 5100.00 18.74 139.21 5058.21 -211.10 182.16 278.83 0.00 0.00 0.00 0.00 5200,00 18.74 139.21 5152.91 -235.42 203.14 310.95 0.00 0.00 0.00 0.00 5300.00 18.74 139.21 5247.61 -259.75 224.13 343.08 0.00 0.00 0.00 0.00 5400.00 18.74 139.21 5342.31 -284.07 245.12 375.21 0.00 0.00 0.00 0.00 5500,00 18,74 139,21 5437,01 -308,40 266,11 407,34 0,00 0,00 0,00 0,00 5600,00 18.74 139.21 5531,70 -332,72 287,10 439,46 0,00 0,00 0.00 0.00 5700,00 18.74 139,21 5626,40 -357,04 308.09 471,59 0.00 0,00 0.00 0,00 5800,00 18.74 139,21 5721.10 -381,37 329,08 503,72 0,00 0,00 0,00 0.00 5900,00 18,74 139.21 5815.80 -405.69 350,06 535,85 0,00 0,00 0,00 0,00 6000,00 18,74 139,21 5910,50 -430,02 371.05 567,97 0,00 0.00 0,00 0,00 6100.00 18,74 139.21 6005,20 -454,34 392,04 600.10 0,00 0.00 0.00 0.00 6200,00 18,74 139,21 6099,90 -478,66 413,03 632,23 0,00 0,00 0,00 0.00 6300,00 18.74 139.21 6194,59 -502,99 434,02 664,36 0,00 0,00 0,00 0,00 6400,00 18,74 139,21 6289,29 -527,31 455.01 696,48 0.00 0,00 0.00 0,00 6500,00 18,74 139,21 6383,99 -551,64 476.00 728,61 0,00 0,00 0,00 0.00 6600.00 18,74 139,21 6478,69 -575.96 496.98 760,74 0.00 0,00 0.00 0,00 6700,00 18,74 139,21 6573.39 -600,28 517,97 792.87 0,00 0,00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BPAmoco Date: 2/19/2001 Time: 07:33:00 Page: 3 Field: Pmdhoe Bay Co-ordinate(NE) Reference: Well: Plan L-01, True North Site: PB L Pad Vertical fi'VD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-01 Section (VS) Reference: Well (0.OOE,0.00N,139.21Azi) Wellpath: Plan L-01 Plan: L-01 WP02 Section 3: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ff deg deg ft ff ft ft deg/10Oft deg/10Oft deg/lOOft deg 6800.00 18.74 139.21 6668.09 -624.61 538.96 824.99 0.00 0.00 0.00 0.00 6900.00 18.74 139.21 6762.79 -648.93 559.95 857.12 0.00 0.00 0.00 0.00 7000.00 18.74 139.21 6857.48 -673.26 580.94 889.25 0.00 0.00 0.00 0.00 7100.00 18.74 139.21 6952.18 -697.58 601.93 921.38 0.00 0.00 0.00 0.00 7200.00 18.74 139.21 7046.88 -721.90 622.91 953.50 0.00 0.00 0.00 0.00 7300.00 18.74 139.21 7141.58 -746.23 643.90 985.63 0.00 0.00 0.00 0.00 7400.00 18.74 139.21 7236.28 -770.55 664.89 1017.76 0.00 0.00 0.00 0.00 7500.00 18.74 139.21 7330.98 -794.88 685.88 1049.88 0.00 0.00 0.00 0.00 7600.00 18.74 139.21 7425.68 -819.20 706.87 1082.01 0.00' 0.00 0.00 0.00 7700.00 18.74 139.21 7520.37 -843.52 727.86 1114.14 0.00 0.00 0.00 0.00 7800.00 18.74 139.21 7615.07 -867.85 748.85 1146.27 0.00 0.00 0.00 0.00 7900.00 18.74 139.21 7709.77 -892.17 769.83 1178.39 0.00 0.00 0.00 0.00 8000.00 18.74 139.21 7804.47 -916.50 790.82 1210.52 0.00 0.00 0.00 0.00 8100.00 18.74 139.21 7899.17 -940.82 811.81 1242.65 0.00 0.00 0.00 0.00 8200.00 18.74 139.21 7993.87 -965.14 832.80 1274.78 0.00 0.00 0.00 0.00 8300.00 18.74 139.21 8088.57 -989.47 853.79 1306.90 0.00 0.00 0.00 0.00 8400.00 18.74 139.21 8183.27 -1013.79 874.78 1339.03 0.00 0.00 0.00 0.00 8500.00 18.74 139.21 8277.96 -1038.12 895.76 1371.16 0.00 0.00 0.00 0.00 8600.00 18.74 139.21 8372.66 -1062.44 916.75 1403.29 0.00 0.00 0.00 0.00 8700.00 18.74 139.21 8467.36 -1086.76 937.74 1435.41 0.00 0.00 0.00 0.00 8800,00 18.74 139.21 8562.06 -1111.09 958.73 1467.54 0.00 0.00 0.00 0.00 8900.00 18.74 139.21 8656.76 -1135.41 979.72 1499.67 0.00 0.00 0.00 0.00 9000.00 18.74 139.21 8751.46 -1159.74 1000.71 1531.80 0.00 0.00 0.00 0,00 9100.00 18.74 139.21 8846.16 -1184.06 1021.70 1563.92 0.00 0.00 0.00 0.00 9121.98 18.74 139.21 8867.00 -1189.32 1026.29 1570.91 0.00 0.00 0.00 0.00 Section 4: Start MD Incl Azim TVD +N/-S +E/-W ff deg deg ft ft: ft VS iDLS: BUild Turn TFO ft ~deg/!00ft deg/100ft deg/100ft deg 9200.00 18.74 139.21 8940.88 -1208.30 1042.67 1595.97 0.00 0.00 0.00 0.00 9300.00 18.74 139.21 9035.58 -1232.62 1063.65 1628.10 0.00 0.00 0.00 0.00 9400.00 18.74 139.21 9130.28 -1256.95 1084.64 1660.23 0.00 0.00 0.00 0.00 9449.34 18.74 139.21 9177.00 -1268.94 1095.00 1676.08 0.00 0.00 0.00 0.00 Survey ' MaP : ',:Map <--- Latitude ---> <'" LongitUde.' MD::: Incl Azim WVO +N/-S +E/-W Northing Easting~ :: Deg Mia Sec Deg Min::'Sec ff deg deg ft ff ff ffe i~-99~.26 598 W 77.00 0.00 139.21 77.00 0.00 0.00 5978114.83 5832o6.21 70 21 0.635 N ~' . 100.00 0.00 139.21 100.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 200.00 0.00 139.21 200.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 300.00 0.00 139.21 300.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 400.00 0.00 139.21 400.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 149 19 26.598W 149 19 26.598W 149 19 26.598W 1000.00 0.00 139.21 1000.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1100.00 0.00 139.21 1100.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1200.00 0.00 139.21 1200.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1300.00 0.00 139.21 1300.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1400.00 0.00 139.21 1400.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1500.00 0.00 139.21 1500.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1600.00 0.00 139.21 1600.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1700.00 0.00 139.21 1700.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1800.00 0.00 139.21 1800.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 1900.00 0.00 139.21 1900.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 500.00 0.00 139.21 500.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 600.00 0.00 139.21 600.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 700.00 0.00 139.21 700.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 800.00 0.00 139.21 800.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 900.00 0.00 139.21 900.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/19/2001 Time: 07:33:00 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-01, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-01 Section (VS) Reference: Well (0.00E,0.00N,139.21Azi) Wellpath: Plan L-01 Plan: L-01 WP02 Survey Map MD lncl Azim TVD +N/-S +E/-W Northing ft deg deg ff ft ff ft 2000.00 0.00 139.21 2000.00 0.00 0.00 5978114.83 2100.00 0.00 139.21 2100.00 0.00 0.00 5978114.83 2200.00 0.00 139.21 2200.00 0.00 0.00 5978114.83 2300.00 0.00 139.21 2300.00 0.00 0.00 5978114.83 2400.00 0.00 139.21 2400.00 0.00 0.00 5978114.83 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 38OO.O0 39OO.O0 4000.00 4100.00 42OO,0O 4300,00 4400.00 4468.48 4500.00 4600.00 ; 4700.00 ~ 4800.00 : 4900.00 15000.00 5100.00 5200.00 , 5300.00 5400.00 5500.00 : 5600.00 ~ 5700.00 : 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 Map <-- Easting Deg 583256.21 70 583256.21 70 583256.21 70 583256.21 70 583256.21 70 Latitude ----> <m Longi~de Min Sec Deg Min Sec 21 0.635 N 149 19 26.598W 21 0.635 N 149 19 26.598W 21 0.635 N 149 19 26.598W 21 0.635 N 149 19 26.598W 21 0.635 N 149 19 26.598W 0.00 139.21 4000.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 4.00 139.21 4099.92 -2.64 2.28 5978112.21 583258.52 70 21 0.609 N 149 19 26.532W 8.00 139.21 4199.35 -10.55 9.11 5978104.38 583265.43 70 21 0.531 N 149 19 26.332W 12.00 139.21 4297.81 -23.70 20.45 5978091.36 583276.92 70 21 0.402 N 149 19 26.001W 16.00 139.21 4394.82 -42.01 36.25 5978073.23 583292.92 70 21 0.222 N 149 19 25.539W 18.74 139.21 4460.17 -57.49 49.61 5978057.90 583306.45 70 21 0.070 N 149 19 25.149W 18.74 139.21 4490.02 -65.16 56.23 5978050.30 583313.15 70 20 59.994 N 149 19 24,955W 18.74 139.21 4584,72 -89.48 77.21 5978026.22 583334.40 70 20 59.755 N 149 19 24,342W 18.74 139.21 4679.42 -113.80 98.20 5978002.13 583355.66 70 20 59.516 N 149 19 23.729W 18.74 139.21 4774.11 -138.13 119.19 5977978.04 583376,92 70 20 59.277 N 149 19 23,115W 18.74 139.21 4868.81 -162.45 140.18 5977953.96 583398.17 70 20 59.037 N 149 19 22.502W 18,74 139.21 4963.51 -186,78 161,17 5977929.87 583419.43 70 20 58.798 N 149 19 21.889W 18.74 139.21 5058.21 -211.10 182.16 5977905.78 583440.68 70 20 58.559 N 149 19 21.275W 18.74 139.21 5152.91 -235.42 203.14 5977881.70 583461.94 70 20 58.320 N 149 19 20.662W 18.74 139.21 5247.61 -259.75 224.13 5977857.61 583483.19 70 20 58.081N 149 19 20.049W 18.74 139.21 5342.31 -284.07 245.12 5977833.52 583504.45 70 20 57.841N 149 19 19,435W 18.74 139.21 5437.01 -308.40 266.11 5977809.43 583525.70 70 20 57.602 N 149 19 18.822W 18,74 139.21 5531.70 -332.72 287.10 5977785,35 583546.96 70 20 57.363 N 149 19 18.209W 18.74 139.21 5626.40 -357.04 308.09 5977761.26 583568.21 70 20 57.124 N 149 19 17.595W 18.74 139.21 5721.10 -381.37 329.08 5977737.17 583589.47 70 20 56.884 N 149 19 16.982W 18.74 139.21 5815.80 -405.69 350.06 5977713.09 583610.73 70 20 56.645 N 149 19 16.369W 18.74 139.21 5910.50 -430.02 371.05 5977689.00 583631.98 70 20 56.406 N 149 19 15.755W 18.74 139.21 6005.20 -454.34 392.04 5977664.91 583653.24 70 20 56.167 N 149 19 15.142W 18.74 139.21 6099.90 -478.66 413.03 5977640.82 583674.49 70 20 55.927 N 149 19 14.529W 18.74 139.21 6194.59 -502.99 434.02 5977616.74 583695.75 70 20 55.688 N 149 19 13.915W 18.74 139.21 6289.29 -527.31 455.01 5977592.65 583717.00 70 20 55.449 N 149 19 13.302W 18.74 139.21 6383.99 -551.64 476.00 5977568.56 583738.26 70 20 55.210 N 149 19 12.689W 18.74 139.21 6478.69 -575.96 496.98 5977544.48 583759.51 70 20 54.971 N 149 19 12.076W 18.74 139.21 6573.39 -600.28 517.97 5977520.39 583780.77 70 20 54.731N 149 19 11.462W 18.74 139.21 6668.09 .-624.61 538.96 5977496.30 583802.02 70 20 54.492 N 149 19 10.849W 18.74 139.21 6762.79 -648.93 559.95 5977472.22 583823.28 70 20 54.253 N 149 19 10.236W 18.74 139.21 6857.48 -673.26 580,94 5977448.13 583844.54 70 20 54.014 N 149 19 9.622W 18.74 139.21 6952.18 -697.58 601.93 5977424.04 583865.79 70 20 53.774 N 149 19 9.009W 0.00 139.21 3500.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3600.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3700.00 0.00 0.00 5978114,83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3800.00 0.00 0.00 5978114,83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3900.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3000.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3100.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139,21 3200.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3300.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 3400.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 2500,00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 2600.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 2700.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 2800.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W 0.00 139.21 2900.00 0.00 0.00 5978114.83 583256.21 70 21 0.635 N 149 19 26.598W BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/19/2001 Time: 07:33:00 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-01, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-01 Section (VS) Reference: Well {0.00E,0.00N,139.21Azi) Wellpath: Plan L-01 Plan: L-01 WP02 Survey Map Map <-- Latitude ----> <-- Longitude --> MD lncl Azim TVD +N/-S +E/-W Northing Easting I)eg Min Sec Deg Min Sec fl deg deg fl fl ft fl fl 7200.00 18.74 ..... ~'~9~2-1- ~3~)i-~-~ ...... ~-~';1".-~'-----~'2-2.~i ...... 5977399.95 583887.05 70 20 53.535 N 149 19 8.396 7300.00 18.74 139.21 7141.58 -746.23 643.90 5977375.87 583908.30 70 20 53.296 N 149 19 7.783 7400.00 18.74 139.21 7236.28 -770.55 664.89 5977351.78 583929.56 70 20 53.057 N 149 19 7.169W 7500.00 18.74 139.21 7330.98 -794.88 685.88 5977327.69 583950.81 70 20 52.817 N 149 19 6.556W 7600.00 18.74 139.21 7425.68 -819.20 706.87 5977303.61 583972.07 70 20 52.578 N 149 19 5.943W 7700.00 18.74 139.21 7520.37 -643.52 727.86 5977279,52 583993.32 70 20 52.339 N 149 19 5.330W 7800.00 18.74 139.21 7615.07 -867.85 748.85 5977255.43 584014.58 70 20 52.100 N 149 19 4.716W 7900.00 18.74 139.21 7709.77 -892.17 769.83 5977231.34 564035.83 70 20 51.860 N 149 19 4.103W 8000.00 18.74 139.21 7804.47 -916.50 790.82 5977207.26 584057.09 70 20 51.621 N 149 19 3.490W 8100.00 18.74 139.21 7899.17 -940.82 811.81 5977183.17 584078.35 70 20 51.382 N 149 19 2.877W 8200.00 18.74 139.21 7993.87 -965.14 832,80 5977159.08 584099.60 70 20 51.143 N 149 19 2.264W 8300.00 18.74 139.21 8088.57 -989.47 853.79 5977135.00 584120.86 70 20 50.903 N 149 19 1.650W 6400.00 18.74 139.21 8183.27 -1013.79 874,78 5977110.91 584142.11 70 20 50.664 N 149 19 1.037W 8500.00 18.74 139,21 8277.96 -1038.12 895.76 5977086.82 584163.37 70 20 50.425 N 149 19 0.424W 8600,00 18.74 139.21 8372.66 -1062.44 916.75 5977062.74 584184,62 70 20 50.186 N 149 18 59.811W 8700.00 18.74 139.21 8467.36 -1086.76 937.74 5977038.65 584205.88 70 20 49.946 N 149 18 59.198W 8800.00 18,74 139.21 8562.06 -1111.09 958.73 5977014.56 584227.13 70 20 49.707 N 149 18 58.584W 8900,00 18.74 139.21 8656.76 -1135.41 979.72 5976990.47 584248.39 70 20 49.468 N 149 18 57.971 W 9000.00 18.74 139.21 8751.46 -1159.74 1000,71 5976966.39 584269.64 70 20 49.229 N 149 18 57.358W 9100.00 18,74 139.21 8846.16 -1184,06 1021.70 5976942.30 584290.90 70 20 48.989 N 149 18 56.745W 9121.98 18.74 139.21 8867.00 -1189.32 1026.29 5976937.09 584295.55 70 20 48.938 N 149 18 56.611 W 9200.00 18.74 139.21 8940.88 -1208,30 1042.67 5976918.30 584312.14 70 20 48.751 N 149 18 56.132W 9300.00 18.74 139.21 9035.58 -1232.62 1063.65 5976894.21 584333.39 70 20 48.512 N 149 18 55.519W 9400.00 18.74 139.21 9130.28 -1256.95 1084.64 5976870.12 584354.65 70 20 48.272 N 149 18 54.906W 9449.34 18.74 139.21 9177.00 -1268.94 1095.00 5976858.25 584365.14 70 20 48.155 N 149 18 54.603W Targets Map Map <m LatitUde __> <-- Longitude --> Name Description TVD +N/-S +EI.W NOrthing Easting Deg Min SeC DegMin Sec : ft: ft ft = ~ L-01 8867.00 -1189.29 1026.33 5976937.13 584295.59 70 20 48.938 N 149 18 56.609W -Polygon 1 8867.00 -1300.04 904.53 5976825.04 584175.04 70 20 47,849 N 149 19 0.169W -Polygon 2 8867.00 -1075.98 992,02 5977050.04 584260.03 70 20 50.052 N 149 18 57.611W -Polygon 3 8867.00 -1168.58 1226.03 5976960.05 584495.03 70 20 49.141N 149 18 50.774W -Polygon4 8867.00 -1392.65 1138,54 5976735.04 584410.04 70 20 46.938 N 149 18 53.332W -Plan hittarget L-01 Permit to Drill Subject: L-01 Permit to Drill Date: Fri, 20 Apr 2001 14:02:27 -0500 From: "Magee, D Nell" <MageeDN@BP.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak. us> CC: "Stone, Dan M" <StoneDM@BP.com> Tom, Find below the responses to your questions. 1. Regarding the use of the diverter, our intention is to rig up a functioning diverter system for the L-01 well. The Drilling Program mentions "Function Test Diverter" however I'll ensure that the use of the diverter is clear. 2. Regarding the "Field and Pool "designation for this well, I confirmed with the Asset Geologist and the Field/Pool is Prudoe Bay Field/Prudhoe Bay Pool as designated on the Permit application. If the well designation was 100 or 200, that would be a Schrader(Borealis Field) or Kuparuk(Borealis Field) well. This is an IPA Ivishak (NWE) well drilled from the new L-Pad. 3. Our offset well review of RFT data and DST's from NWE indicates a 10.4 ppg formation pressure in the Kuparuk Reservoir. This is thought to be overpressured from the Kuparuk gas injection program. This being the case, the LOT at the surface casing shoe is critical from a kick tolerance standpoint. NWE 102 had a leakoff test conducted to 14.7 ppg at 2713' TVD and NWE 101 conducted a FIT to 12.5 ppg at the surface casing shoe. Our intention is to conduct a leak-off test to confirm at least 13.5 ppg to meet our kick tolerance limit of 25 bbls minimum. We will consider doing an intermediate FiT prior to entering the Kuparuk if the surface LOT is marginal. 4. Regarding Production Interval cementing, we plan as a minimum, bringing cement to 1000' above the Kuparuk. If logs indicate the Schrader to hold commercial quantities of hydrocarbons, cement will be brought up to cover this interval. Regards, Nell Magee 564-5119 .... Original Message ..... From: Tom Maunder [mailto:tom maunder~admin.state.ak, us] Sent: Friday, April 20, 2001 8:00 AM To: Neil Magee Subject: L-01 Sorry for the delay, I had an extra "." in your eddress, i also copied the original note to Dan. Nell, Good to talk to you. As discussed, I am sending this note to capture the points we talked about this morning regarding this well. In no 1 of 2 4/20/01 11:31 AM L-01 Permit to Drill particular order. -A close read of your procedure indicates you will have a diverter, but your nipple up statement just mentions the spool and riser. --The pool and field indicated is Prudhoe for both. I thought this is a Borealis well, but I know that designation is likely not official yet. I will check with our geologist regarding the designation. The drill site is likely in that never-never land between Prudhoe and Milne. --We discussed the 10.4 ppg pore pressure potential in the Kuparuk. You indicated that there is a possibility of injected gas effects from Kuparuk. That point is indeed a caution item at DS 1D and 1J in Kuparuk. I'm not sure of the effect on your location given the distance, but it is prudent to be cautious. One other item you might consider is a deep leak off test to confirm that you have sufficient formation strength to account for your planned mud weight and ECD. PPCo uses this practice on their 1D and 1J wells prior to drilling into the Kuparuk. If they do not establish sufficient EMW tolerance, they top set. --We also discussed the latest LOT information I have from that area. On one well, the formation "broke" at 15.1 EMW and they pumped into it at a little over 12.1. --In your cementing plan, you plan to cover the Kuparuk. You indicated that you will be running logs looking for oil in the Schrader, but it is not expected. Thanks for your time to discuss theSe issues. After reviewing your reply, I will move the application on. Tom Maunder 2 of 2 4/20/01 11:31 AM 14 ."I. 8,4... 3 5 4 I o=,'%;~'o,I I O0184354 I VENDOR ALASKAO I LA O0 ........ n~..nl.~r~n~ i I.--n ~--'v DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 012~01 CKO12~OIO 100. O0 100. O0 PYMT :OMMENTS' Peri,it To D~ill =ee HANDL:;NG INST' S/H - Te~ei Hubb [e X4~28 FOR ~MS DE~RIBED ABOVE. ~ 1 OO. OO 1 OO. OO THE A~ACHED CHECK IS IN PAYME~ !:BP EXPLORATION (A'LASKA)~.,INC:. ..:.i., :~.O,.'::.~X" 196i~12 '~'' !::'?'. ......" ~:::~:.',;."' "- ':.. ANCHO~AG~E:?ALASKA...: .... .., .... .:.:,. 99519-6612 PAY · TO..-The ::ALASKA OIL AND ,:.iOA~."ii :;.:. .i ..ORDER.. :'"~"'/ ?"...~oNS~VAT I ON:i!'~!'c!~M~:~.i"s~.I oN ::i ;i!.: '::: i~i::ii!: Ot~ '.i:.':. .:.;'3.'33':' .~EsT 7TH "( ~E~I~E!?',' ~'UI~' !:.'::1 O0 ANCHORAGE AK 99501 ,' l,.°.h:ISh,' ~-'Ohl, i~O:IS~IS,'- O0,q,h[, ,, , WELL PERMIT CHECKLIST COMPANY WELL NAME PROGRAM: exp dev ,~' redrll serv wellbore seg ann. disposal para req - FIELD & POOL INIT C~ASS _,~_-~ ,,2_ O, ~/ ADMINISTRATION ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor stdng provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive hodzons ..... ' ..... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed .............. GEOLOGY If diverter required, does it meet regulations .......... Drilling .fluid program schematic & equip list adequate .... . BOPEs, do they meet regulation ...... _. ...... . . . BOPE press rating appropriate; test to '~, ~'r,...%(,_~ psig. Choke manifold complies w/APl RP-53 (May 84) .......... Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued wlo hydrogen sulfide measures ..... GEOL AREA ~N ~N UNIT# ,//~. 5'~ ON/OFF SHORE ~.-'t.) 30. 31. Data presented on potential overpressure zones ....... Y ~ ~, ,,,~,,~ j///_"-~" "~' 32. Seismic analysis of shallow gas zones ............. ,Y/' N /L/,~, . 33. Seabed condition survey (if off-shore) ............. /Y N ~ / 34. Contact name/phone for weekly progress reports [exploratory o~y] Y N (B) will not contaminate freshwater; or cause drilling waste .... to surface; (C) will not impair meChanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) wi!l not cimumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE GEOLOGY: ENGINEERING:. 'UlC/Annular COMMISSION: Comments/instructions: ) .? _ ,~/~-~ "' c:~msoffice\wordian~diana\checklist (rev. 111011/00)