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XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. /~ ~' ~--~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: D Poor Quality Original- Pages: [3 Other - Pages: DIGITAL DATA [3 Diskettes, No. n Other, No/Type -OVERSIZED n .Logs of various kinds n Other Complete COMMENT~: Scanned by: Berry M~red-D'ar~th.(l~.~ Lovetl TO RE-SCAN Notes: Re-Scanned by: E~ve~ Mildred Daretha Nathan Lowell Date: /si RECEDED STATE OF ALASKA SEP 10 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION O RECOM - LETIO RE RT AND LOGAOGCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other Abandoned. Ii''uspende 1/1-i 1 l b. Well Class OAAC 25.105 20AAC 25.110 AS9A,vtAingt uJ 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Compl .ons Zero •®Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 8/12/2013 • 197-023• • 313-298 • 3. Address: 6. Date Spudded: 13. API Number: _ P.O. Box 196612,Anchorage,Alaska 99519-6612 5/12/1997 • 50-029-22708-60-00 • 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 5/15/1997 • PBU 02-38L1 • 4541' FSL, 3568' FEL, Sec.36,T11N, R14E, UM 8. KB(ft above MSL): 61' 15.Field/Pool(s) Top of Productive Horizon: 2178' FSL, 1100' FEL, Sec.25,T11N, R14E, UM GL(ft above MSL): 30.5' • Prudhoe Bay Field/Prudhoe Bay • Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 4131' FSL, 1349' FEL, Sec.25,T11N, R14E, UM 9795' 8736' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 688457 • y- 5950483. Zone- ASP4• 11599'. 8781' ' ADL 028308 TPI: x- 690850 y- 5953462 Zone- ASP4 • 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 690551 y- 5955408 Zone- ASP4 None 18.Directional Survey: ❑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, GR • 10580' 8845' • 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 31' 110' 31' 110' 30" 260 sx Arctic Set(Approx.) _ 9-5/8" 40# L-80 30' 3834' 30' 3553' 12-1/4" 305 sx Cold Set III,440 sx Class'G' 7" 26# L-80 28' 10197' 28' 8860' 8-1/2" 464 sx Class'G' 4-1/2" 12.6# L-80 10053'_ 10580' 8843' 8845' 6" 175 sx Class'G' 2-7/8" 6.5# L-80 10530' 11599' 8849' 8781' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? ❑Yes ®No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#, 13Cr85/L-80 10057' 9158'/8222' 9909'/8797' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9795' Set Whipstock SCANNED APR 2 3 2014 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? 0 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. None 1 Br \4 SEP 12 29. GEOLOGIC MARKERS(List all formations an kers encounter 30. FORMATION TESTS • NAME NuJ TVD Well Tested? 0 Yes 0 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 9217' 8273' None• Shublik 9266' 8315' Sadlerochit 9322' 8363' 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: Ron Phillips,564-5913 Email: Ron.Phillips@bp.com Printed:::ure:J0e Lastu a Title: Drilling Technologist ! 4� ' Phone 564-4091 Date: /al ` `✓ 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 02-38L1 , Well History (Pre Rig Sidetrack) Date Summary 07/18/13 T/I/O 6/5/221 Temp=SI CMIT-TxIA(post rig)CMIT-TxIA PASSED to 2500 psi Tubing and IA are tracking. Pump 3 bbls crude down tubing to achieve test pressure.Tubing/IA lost 33/35 psi 1st 15 min and 17/16 psi 2nd 15 min for a total loss of 50/51 psi over 30 min test. Bleed psi's,approx 3 bbls. Pump 3 bbls crude down IA to verify tubing by IA comunication from the backside. FWHP 1/4/220 SV,WV,SSV=closed, MV=open, IA and OA=OTG. 07/21/13 PULLED B&R FROM RHC-M @ 9813' SLM. PULLED ST#5 BEK-DCK2 SHEAR VALVE @ 3758'SLM (3776' MD). SET ST#5 BK-DGLV @ 3758'SLM (3776' MD). PULLED 4-1/2"RHC-M FROM X-NIP AT 9,817'SLM (9,831'MD). ATTEMPTED TO DRIFT TBG W/20'x3.70"WHIPSTOCK, SD AT 9,118'SLM, 9,146', 9,627' &9,634'. RAN 4-1/2" BRUSH&3.70"G. RING TO 9,847' SLM,WORK PAST&DRIFT FREELY TO 9,910'SLM. 07/22/13 DRIFT TBG W/20'x 3.70"WHIPSTOCK&SD AT 9,634'SLM,WORK TOOLS TO 9,695'SLM. DRIFT TBG W/10'x 3.70"WHIPSTOCK&SD AT 9,620'SLM. DRIFT TBG W/3.78"CENT,4-1/2" BRUSH, 3.80"CENT TO 9,414'SLM, UNABLE TO WORK PAST. DRIFT TBG W/4-1/2" BRUSH,3.70"G. RING TO 9800'SLM, MAKE SEVERAL PASSES TO CLEAR OBSTRUCTION. DRIFT TBG W/3.62" BAKER DUMMY WHIPSTOCK, S/D @ 9631' SLM, UNABLE TO WORK TOOLS THRU. DRIFT TBG W/3.805" G. RING,4-1/2" BRUSH, S/D @ 9852' SLM, MAKE SEVERAL PASSES FROM 9000-9831'SLM. DRIFT TBG W/3.62" BAKER DUMMY WHIPSTOCK, S/D @ 9631'SLM, UNABLE TO WORK TOOLS THRU. DRIFT TBG W/10'x 3"PUMP BAILER,TAG WRP @ 9940'SLM (no obstructions) (recovered several slivers of metal). DRIFT TBG W/10'3-3/8"(3.50") DUMMY GUN, S/D @ 9934'SLM (no obstructions), CURRENTLY POOH. 07/23/13 DRIFT TBG W/45 KB PKR DRIFT(3.70"max od,67"oal), S/D @ 9930'SLM. DRIFT TBG W/10'x 3.50" PUP JOINT&45 KB PKR DRIFT, S/D @ 9617'SLM (unable to work thru). RUN PDS 40-ARM CALIPER FROM 9941'SLM TO SURFACE (inconclusive data). RUN PDS 24-ARM CALIPER FROM 9941'SLM TO 8660'SLM (good data). ATTEMPT TO SET 4-1/2"X-LOCK @ 9831' MD (pulled back out of nipple). CURRENTLY POOH TO CHECK TOOLS. 07/24/13 SET 4-1/2"X-LOCK W/THREAD PROTECTOR @ 9821'SLM (9831'MD). RAN 4-1/2"CHECKSET TO X-LOCK @ 9821'SLM (sheared). 07/27/13 T/I/O =67/63/213.Temp=Sl. MIT-T to 2500 psi(Pre CTD). No well house,AL,flowline.T FL @ 2514' (-38.2 bbls). SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 1100. 07/29/13 T/I/0=200/50/140. (MITT to 2500 psi) MITT to 2500 psi. PASSED.Tbg lost 11 psi in first 15 minutes&8 psi in second 15 minutes. Total loss= 19 psi. Bleed tbg pressure down to 500 psi. FWHP=500/20/180. Swab,wing, &SSV closed. Master, IA, &OA open. 07/30/13 CTU#9 1.75"Coil (CV=38.8)Job Objective: FCO/Drift for Whipstock. MIRU, Rih w/CTC, DFCV, (2) Stingers, 3.25"JSN OAL=8.56'while circulating 1% Slick KCL with safelube. Cleaned out to plug @ 9831' POOH. 07/31/13 CTU#9 1.75"Coil (CV=38.8)Job Objective: FCO/Drift for Whipstock. RIH w/3.70"x 20'dummy whipstock tagged @ 9815' E&9824' M POOH freeze protect well from 2500'w/38 bbls of 50/50 methanol. Page 1 of 2 02-38L1 , Well History (Pre Rig Sidetrack) Date Summary 08/03/13 INTIAL T/I/O =0/0/160. SET NORTHERN SOLUTIONS 4.5"TANDEM WEDGE WHIPSTOCK. SET TOP OF WHIPSTOCK AT 9816', 58.3 DEGREES ROHS. CCL TO BOTTOM OF TOOL=30' ; BOTTOM OF WHIPSTOCK ON TOP OF X LOCK AT 9831'. OAL=15'. MAX OD=2.70". PIP TAGS INSTALLED 7 FT FROM TOP OF WHIPSTOCK.WHIPSTOCK DID NOT RELEASE AFTER SETTING. ATTEMPTED TO SHEAR OFF OF WHIPSTOCK UNSUCCESSFULLY. DECISION MADE TO RELEASE USING ERS. CURRENTLY ATTEMPTING TO RELEASE ERS. 08/04/13 MADE SEVERAL ATTEMPTS TO RELEASE ERS WITHOUT SUCCESS. DROPPED HES KINLEY CUTTER-SUCCESSFUL CUT AND RECOVERED ALL WIRE W/CUTTER EXCEPT APPROX 8"THAT WOULD BE LEFT ON TOP OF TOOLS STRING FROM CUTTER. ***FISH LEFT IN HOLE--ELINE TOOLSTRING W/WHIPSTOCK- 1.188" FISHING NECK ON TOP OF TOOLS W/APPROX 8"OF.23" ELINE CABLE/OAL OF FISH W/WHIPSTOCK=53.8'. RAN 3.50" LIB TO 9760'SLM. HAVE IMPRESSION OF FISHING NECK. 08/05/13 PULL E-LINE TOOLSTRING FROM TOP OF WHIPSTOCK @ 9760'SLM. TAG WHIPSTOCK/W BLINDBOX(x4 TATTLE TALE PINS)@ 9790'SLM. 08/06/13 T/I/0=200/0/0 conduct PJSM, Barriers=SV&SSV,Verified by bleeding pressure off of SSV&SV independently, Passed, serviced well, stabbed on CIW lubricator w/4"CIW TWC#278,Tested& documented SV A gate&SSV B gate through the Wing Valve to 300/3000 psi for 5 mins Passed,tested and doc. Swab through lubricator to 300/3500 psi for 5 mins Passed, RIH Set TWC at 115", Bled off tubing pressure torqued flanges to API specs, Performed shell test to 300/5000 psi for 5 mins passed, performed independent LTT on MV&SV Passed, removed tapped flange and installed untapped flange, tested&doc.to 300/5000 psi for 5 mins passed, RDMO. Page 2 of 2 North America-ALASKA-BP Page 1 et22' Operation Summary Report Common Well Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 End Date. X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/7/2013 12:00 - 18:30 4.50 MOB P PRE INSTALL FINGERS IN DERRICK CLEAN RIG. COMPLETE RIG MOVE CHECKLIST. CLEAN LOCATION OF TOOLS AND DEBRIS. 18:30 - 17:00 0.50 MOB P PRE PJSM. MOVE RIG FROM PRICE PAD TO DS 02-38A. 17:00 - 18:00 1.00 MOB P PRE MOVE RIG FROM PRICE PAD TO BOC. 18:00 - 19:30 1.50 MOB P PRE CREW CHANGE NEAR BOC.CONDUCT ROUTE DRIVE. CONTINUE RIG MOVE TO DS 02-38A. 19:30 - 00:00 4.50 MOB P PRE CONTINUE ON SPINE ROAD FROM BOC TO OXBOW TO WEST DOCK ROAD. 8/8/2013 00:00 - 03:00 3.00 MOB P • PRE MOVE RIG DOWN WEST DOCK ROAD TO DS 02 PAD. PARK RIG ON SIDE OF LOCATION. 03:00 - 08:00 3.00 MOB P PRE DHD ON LOCATION,WELL BLED DOWN TO 8 PSI. SHUT IN WELL,PRESSURE INCREASE TO 190 PSI IN 30 MINS. WOS NOTIFIED OF SITUATION, AUTHORIZATION GIVEN TO PULL OVER WELL.LAYDOWN RIG MATS AROUND WELL. 06:00 - 06:30 0.50 MOB P PRE CREW CHANGE. DISCUSS RIG STATUS AND MOVE FOLLOWUP. CONTINUE TO RU ON DS 2. 06:30 - 13:00 6.50 MOB P PRE TEST TREE CAP. LEAK TIGHT TEST PRIOR TO TREE CAP REMOVAL. LIFT 2-3/8"COIL REEL IN TO RIG. PREP SARBER SPOOL LIFT AND NU BOPS. 13:00 - 16:00 3.00 MOB P PRE INSTALL NEW JUMBO LUBRICATOR THROUGH FLOOR. PREP COIL FOR STABBING. PULL AND STAB COIL. CALIBRATE SLB WEIGHT INDICATOR. INSTALL BOOT ON WIRELINE BOOT IN REEL HOUSE. RUN NEW CABLING TO SAT CAMP(POWER, GAI-TRONICS,INTEQ) 16:00 - 17:00 1.00 MOB P PRE PERFORM RIG EVACUATION DRILL. 17:00 - 18:00 1.00 MOB P PRE CONTINUE RIGGING UP RIG FLOOR. PREPARE FOR ROPE TEST. 18:00 - 18:30 0.50 MOB P PRE CREW CHANGE. DISCUSS RIG STATUS AND MOVE FOLLOW UP. CONTINUE TO RU ON DS 2 PREPARING FOR BOPE TEST. 18:30 - 19:30 1.00 MOB P PRE MUSLBCOILCONNECTOR,PULLTESTTO 35K CALIBRATE SLB WEIGHT SENSORS. STAND BACK INJECTOR. 19:30 - 21:30 2.00 MOB P PRE HELD PJSM FOR PICKING UP BHI TOOLS. LOAD BHI TOOLS IN PIPE SHED. 21:30 - 00:00 2.50 MOB N RREP PRE FILL BOPE STACK WITH WATER.PRESSURE UP AND CHECK FOR LEAKS. BOP LEAKING AT ALL BLIND FLANGES- TIGHTED ALL BOLTS GRAY LOCKS LEAKING-TIGHTED BLEED PORTS LEAKING-TIGHTED Printed 8/19/2013 2:47:11PM North America-ALASKA-BP Page 2422-- Operat la Summary Report Common Well Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 End Date: X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/9/2013 00:00 - 01:00 1.00 BOPSUR P PRE PERFORM SHELL TEST OF BOPE AND CHART SAME. NOTIFIED JEFF JONES OF GOOD SHELL TEST. PREPARE FOR BOPE TEST. 01:00 - 01:30 0.50 BOPSUR P PRE PERFORM RIG EVACUATION DRILL&AAR. 01:30 - 02:00 , 0.50 BOPSUR P PRE FILL PITS WITH KCL.PREPARE FOR BOPE TEST. WAIT ON STATE INSPECTOR JEFF JONES TO ARRIVE. 02:00 - 06:00 4.00 BOPSUR N RREP PRE I SHELL TEST STACK TO 4500 PSI. TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN TEST CHOKE VALVES,CHOKE AND KILL HCR, INSIDE MANUAL VALVES ON CHOKE AND KILL LINE,BOP RAMS AND ANNULAR PREVENTER. TEST 2 FULL OPENING SAFETY VALVES FUNCTION BOPE FROM BOTH REMOTE PANELS TEST IS WITNESSED BY TOOLPUSHER AND WSL. AOGCC INSPECTOR JEFF JONES WITNESSED TEST. INSPECTOR LEFT LOCATION WHILE REPAIRS AND LEAKS ARE FIXED/REPAIRED. 06:00 - 06:30 0.50 BOPSUR N RREP PRE CREW CHANGE. DISCUSS BOP TEST PROBLEMS.MAKE PLAN FORWARD. 06:30 - 22.00 15.50 BOPSUR N RREP PRE CONTINUE WITH BOP LEAK TROUBLE SHOOTING. FAILURES: BLIND RAMS-REBUILD BLIND/SHEAR RAMS. HCR/KILL-GREASED AND FUNCTION. CHOKE MANIFOLD VALVES#6-REBUILD ANNULAR FAILED TO CLOSE-HYDRUALIC HOSE NOT CONNECTED,RECONNECTED HOSE HYDRUALIC CHOKE FAILED TEST-REBUILD (FAILED)REBUILD#2(PASSED) TEST GAS ALARMS. 22:00 - 22.30 0.50 BOPSUR P PRE LINE UP NORMAL FLOW PATH AFTER BOPE TEST. CLEAN RIG FLOOR 22:30 - 00:00 1.50 BOPSUR P PRE HEAD UP WITH BHI. TEST CHECK VALVES&CHART SAME. 8/10/2013 00:00 - 01:00 1.00 BOPSUR P PRE RE-ADJUST SLB SERVICE LOOP ON INJECTOR. 01:00 - 03:30 2.50 BOPSUR I P PRE PJSM FOR RU OF LUBRICATOR/PULLING TWC. AWGRS REPORT SHOWS TWC SET @ 115'ON 08/06/2013. RU LUBRICATOR AND PRESSURE TEST SAME 250/3500. RIH TO 115',NO TWC FOUND.RIH TO 185' MAX DEPTH. OPEN WELL FLOW CHECKED FOR 15 MINS. SHUT WELL IN,NO PRESSURE INCREASE OBSERVED. NOTIFIED WOS OF SITUATION.RD LUBRICATOR. Printed 8/19/2013 2:47:11 PM North America-ALASKA-BP Page 3-0212' Operation Summary Report Common Well Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 End Date: X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table©61.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) , 03:30 - 04:00 0.50 BOPSUR P PRE PRESSURE TEST LUBRICATOR 250/3500- _ PASSED. 04:00 - 05:30 1.50 DRILL P WEXIT MAKE UP 3.80"WINDOW MILLING ASSEMBLY AND RUN IN HOLE. -3.80"NEW HCC DSM WINDOW MILL+3.80" DIAMOND STRING MILL -BAKER 2-7/8"XTREME STRAIGHT MUD MOTOR -2 JOINTS OF PH6 TUBING -3"BHI COILTRAK TOOLS W/NO RES -BHA OVERAL LENGTH=118.86' 05:30 - 06:00 0.50 DRILL P WEXIT STAB ONTO WELL WITH INJECTOR. TEST QTS 250/3500-PASS. 06:00 - 08:00 2.00 DRILL P WEXIT RIH WITH 3.8"MILLING BHA#1 F/118'-2700' MD. DISPLACE FREEZE PROTECT OUT TO TIGER TANK. 08:00 - 09:30 1.50 DRILL N RREP 3,179.00 WEXIT SWIVEL ON REEL LEAKING WHILE CIRCULATING. POOH TO REPLACE/REPAIR SAME. (SWIVEL HAD BEEN SERVICED AND PRESSURED TESTED DURING SUMMER MAINTENANCE) PRESSURETEST TO 250 AND 3500 PSI. CHART TEST. PASSED. 09:30 - 10:30 1.00 DRILL P WEXIT RUN IN HOLE. TEST INJECTOR CONTROLS AND MAKE ADJUSTMENTS TO HYDRAULIC CONTROL SYSTEM. 10:30 - 12:30 2.00 DRILL N DFAL 7,800.00 WEXIT MWD SYSTEM FAILED. TROUBLE SHOOT SAME. INDICATIONS ARE E-LINE PULLED OUT OH COIL CONNECTOR. CONTINUE TO RUN IN HOLE TO DIAL IN INJECTOR HYDRAULICS. 12:30 - 13:45 1.25 DRILL P 7,800.00 WEXIT DISPLACE WELL TO POWER PRO MUD. OA INCREASING SLOWLY TO 550 PSI. BLEED DOWN SAME. 13:45 - 15:15 1.50 DRILL N RREP 7,800.00 WEXIT HOLD PJSM.ISOLATE SINGL PIT FOR TRIP. CIRCULATE OUT OF HOLE. CONTINUE TO FILL PITS AND OFFLOAD VAC _ TRUCKS. 15:15 - 17:30 2.25 DRILL N RREP 7,800.00 WEXIT AT SURFACE. FLOW CHECK. HOLD PJSM. GET OFF WELL. UNSTAB COIL. LD BHA. DISASSEMBLE COIL CONNECTOR. FOUND PARTED PIG TAIL IN CONNECTOR. E-LINE STILL SECURE IN ANCHOR WITH SLACK BEHIND IT. RE-HEAD E-CONNECTOR. TEST SAME. Printed 8/19/2013 2:47:11 PM • North America-ALASKA-BP Page 4 Operation Summary Report Common Well Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 End Date. X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:00AM r Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 22:00 4.50 DRILL N RREP 7,800.00 WEXIT TROUBLSHOOT SLB POWER ISSUES.SLB LINE CONDITIONER NOT SUPPLYING ENOUGH POWER TO OPS CAB.SLB ELECTRONICS TECHNICIAN REMOVED BHI COMPUTER SYSTEMS FROM SLB POWER STATION.NOTIFIED WOS OF POSSIBLE POWER LOSS TO OPS CAB IF EXCESSIVE LOAD PLACE ON FAULTY LINE CONDITIONER, RECOMMENDATIONS MADE TO WAIT ON SURFACE UNTIL A NEW LINE CONDITIONER CAN BE INSTALLED. -CURRENT LINE CONDITIONER IS NOT OUTPUTTING CONSTANT 120V TO OPS CAB SYSTEMS. -BACKUP UPS(UNINTERUPTED POWER SOURCE)BEING DRAWN DOWN TO LOW FOR NORMAL OPERATIONS. -DECISON MADE TO WAIT UNTIL REPLACEMENT LINE CONDITIONER CAN BE LOCATED AND INSTALLED. 22:00 - 23:30 1.50 DRILL N RREP 7,800.00 WEXIT DECISION MADE TO MU BHA#2 AND RIH TO TROUBLESHOOT SLB SYSTEMS.PJSM HELD TO MU BHA#2,RIH AND TROUBLSHOOT POWER SYSTEMS. MU BHA#2,PU AND STAB INJECTOR ONTO WELL,PRESSURE TEST QTS 250/3500- PASSED. RIH F/188'-725'MD.BHI DEPTH ENCODER NOT TRACKING CORRECTLY. 23:30 - 00:00 0.50 DRILL N SFAL 7,800.00 WEXIT BHI DEPTH ENCODER NOT TRACKING CORRECTLY. TROUBLESHOOT ENCODER. 8/11/2013 00:00 - 01:30 1.50 DRILL N SFAL 725.00 WEXIT TROUBLESHOOT BHI DEPTH ENCODER. REPAIR DEPTHJ ENCODER. '01:30 - 05:00 3.50 DRILL N RREP 7,800.00 WEXIT RIH WITH BHA#2 F/725'-6000'MD.POOH F/ 6000'-5750'MD.SYSTEM APPEARS TO BE HANDLING LOAD. RIH F/5750'-8000'MD.POOH F/8000'-7250' MD.SYSTEM NOT FUNCTIONING PROPERLY. DECISION MADE TO POOH AND WAIT ON REPAIR PARTS.LD BHA#2. 05:00 - 06:00 1.00 DRILL N RREP 7,800.00 WEXIT WAIT ON REPAIR PARTS FOR SLB LINE CONDITIONER. 06:00 - 06:30 0.50 DRILL N RREP 7,800.00 WEXIT CREW CHANGE. DISCUSS RIG AND EQUIPMENT STATUS. CONTINUE TO WAIT ON LINE CONDITIONER EQUIPMENT FROM ANCHORAGE. 06:30 - 12:00 5.50 DRILL N RREP 7,800.00 WEXIT WAIT ON LINE CONDITIONER REPLACEMENT FROM ANC. Printed 8/19/2013 2:47:11 PM • North America-ALASKA-BP Page 5,o�i Operation Summary Report Common Well Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 iI End Date: X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table C 61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 DRILL N RREP 7,800.00 WEXIT POWER DOWN OPS CAB. REMOVE FAILED LINE CONDTIONER FROM PIPE SHED WALL. CONTINUE TO WAIT ON POWER LINE CONDITIONER FROM ANC. CONTINUE TO PREP REEL HOUSE EXTERIOR. INTEQ REPLACED SOME CABLING. CLEAN RIG INTERIOR. 18:00 - 20:30 2.50 DRILL N RREP 7,800.00 WEXIT WAIT ON REPAIR PARTS FOR SLB LINE CONDITIONER. 20:30 - 23:00 2.50 DRILL N RREP 7,800.00 WEXIT HELD PJSM WITH ELECTRICIAN/SLB ELECTICAL TECHNICIAN FOR RU/TEST LINE CONDITIONER. INSTALLED LINE CONDITIONER,POWER UP OPS CAB,CHECK VOLTAGES IN OPS CAB. 23:00 - 23:30 0.50 DRILL N RREP 7,800.00 WEXIT HELD PJSM TO MU MILLING BHA#3. MU BHA,PICK UP INJECTOR STAB ONTO WELL. 23:30 - 00:00 0.50 DRILL N RREP 7,800.00 WEXIT PRESSURE TEST QTS 250/3500-PASSED. RIH F/188'-1000'MD. 8/12/2013 00:00 - 02:00 2.00 STWHIP N RREP 7,800.00 WEXITRIH F/1000'-8000'MD.POOH F/8000'-7850' MD.SLB SYSTEMS APPEAR TO BE • OPERATING PROPERLY. .RIH F/7850'-9000'MD.POOH F/9000'-7500' MD.ALL SYSTEMS OPERATING AT NORMAL LEVELS. RIH TO 9250'MD BEGIN LOGGING GR TIE-IN. 02:00 - 05:00 3.00 STWHIP P WEXIT LOG GR TIE-IN Fl 9250'-9350'MD.DEPTH CORRECTION-7.5'. RIH TAG PINCH POINT @ 9796'MD,20'HIGH. PU AND RE-LOGGED TIE-IN,ON DEPTH.RIH LOG CCL,VERIFY TOP OF WHIPSTOCK. C 05:00 - 12:00 7.00 STWHIP P WEXIT TIME MILL WINDOW F/9,795.5'MD. Skit/. 2400 PSI FS AT 2.68 BPM IN/OUT. MW IN/OUT:8.65 PPG/8.79 PPG. 02-33A 50-100 PSI MTR WORK. 0.5-0.8K#DHWOB. IA/OA PVT:475 PSI/386 PSI/394 BBLS. MILL TO 9798'. VERY SMOOTH WEIGHT TRANSFER. MILL BY WEIGHT AND DRILL OFF. 12:00 - 18:00 6.00 STWHIP P WEXIT TIME/WEIGHT MILL WINDOW FROM 9798.2'. 2401 PSI FS AT 2.73 BPM IN/OUT. 125-200 DIFF PRESS. DHWOB:2.74-3.25K# MW IN/OUT:8.62/8.80 PPG .BHP/ECD/TVD:4.424 PSI/9.88 PPG/8668' IA/OA/PVT:363 PSI/428 PSI/396 BBLS. MILL AHEAD TO 9800.7'. 18:00 - 00:00 6.00 STWHIP P WEXIT TIME/WEIGHT MILL WINDOW FROM 9800.0' MD. 2401 PSI FS AT 2.73 BPM IN/OUT. 125-200 DIFF PRESS. DHWOB:2.74-3.25K# MW IN/OUT:8.62/8.84 PPG .BHP/ECD/TVD:4431 PSI/9.88 PPG/8668' IA/OA/PVT:482 PSI/542 PSI/394 BBLS. • MILL AHEAD TO 9804'. Printed 8/19/2013 2:47:11 PM I , North America-ALASKA-BP Page 6 P 2' Operation Summary Report • Common Welt Name:02-38 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/7/2013 End Date: 'X3-01300-C:DRILL(3,164,138.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:NORDIC 2 Spud Date/Time:10/5/1996 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292270800 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/13/2013 00:00 - 03:00 3.00 STWHIP P WEXIT TIME I WEIGHT MILL WINDOW FROM 9804' MD. 2401 PSI FS AT 2.73 BPM IN/OUT. 125-200 DIFF PRESS. DHWOB:2.74-3.25K# MW IN/OUT:8.62/8.84 PPG .BHP/ECD/TVD:4431 PSI/9.88 PPG/8668' IA/OA/PVT:482 PSI/542 PSI/394 BBLS. MILL AHEAD TO 9815 MD. 03:00 - 04:00 1.00 STWHIP P WEXIT DRESS WINDOW.REAM WINDOW 3 TIMES. DRY DRIFT WINDOW TO TD.WINDOW IS CLEAN WITH NO ISSUES SEEN.OPEN EDC,PUMP 3.5 BPM I TO CLEAN CUTTING OUT OF HOLE. 04:00 - 06:30 2.50 STWHIP P WEXIT I POOH F/9780'-188'MD.WELLHEAD I PRESSURE INCREASED TO 500 PSI I AT 1500'MD.BACKFLUSH MICROMOTION,DID NOT CLEAR OBSTRUCTION. POOH F/1500'-188'MD.STAND BACK INJECTOR,LD MILLING BHA#3. GAGED DIAMOND MILL-3.78 NO GO GAGED STRING MILL-3.79 NO GO 106:30 - 07:00 0.50 STWHIP P WEXIT CHANGE OUT CREWS.CONDUCT WALK AROUND,INSPECT EQUIPMENT. 07:00 - 08:00 , 1.00 STWHIP P WEXIT BACK FLUSH MICROMOTION,CLEAR OBSTRUCTION FROM CHOKE MANIFOLD LINES. 08:00 - 09:00 1.00 DRILL P PROD1 MU BUILD BHA#1 WITH 2.0 AKO 2-7/8"MTR AND 4.5'HYCALOG BICENTER. STAB COIL. GET ON WELL. PRESS TEST QTS TO 250 AND 3500 PSI. CHART TEST. PASSED. 09:00 - 12:00 3.00 DRILL P PROD1 RUN IN HOLE. TAG ALL FIVE GLMS WITH BHA. PU AT EACH AND WORK THROUGH SAME. DID NOT PUMP OR ORIENT. 12:00 - 12:30 0.50 DRILL P PROD1 LOG GR TIE IN WITH(-9.5)'CORRECTION. CLOSE EDC. 12.30 - 16'00 3.50 DRILL P PROD1 DRILL BUILD SECTION FROM 9815 FREESPIN 2600 PSI AT 2.75 BPM IAP 177 PSI,OAP 308 PSI,PVT 384 BBLS SLIGHT LOSSES OF 0.25 BPM AT 9838', 'HEALING UP. 16:00 - 00:00 8.00 DRILL P PROD1 DRILL FROM 9885'. SLOW DRILLING WITH 5-25%CHERT IN SAMPLES. 2.0-3.0 K#DHWOB WITH 15-20 FPH ROP. 2.66 BPM IN/OUT AT 2450 PSI. BHP/ECD/TVD:4496 PSI/9.96 PPG/8758' IA/OA/PVT:516 PSI/676 PSI/383 BBLS. 8/14/2013 i 00:00 - 08:00 8.00 DRILL P PROD1 !DRILL FROM 10,015'MD. SLOW DRILLING WITH 5%CHERT IN SAMPLES. 2.0-3.0 K#DHWOB WITH 15-20 FPH ROP. 2.82 BPM IN/OUT AT 2720 PSI. BHP/ECD/TVD:4569 PSI/9.98 PPG/8776' IA/OA/PVT:546 PSI/269 PSI/375 BBLS. LAND BUILD AT 10,134'. Printed 8/19/2013 2:47:11 PM lip J TREE= 1/16"CNV as AER= BAKER 02-38/L1 SAFETY NOTES: WELL ANGLE>70°@ 9907'*"" f NfIIAL KB.ELEV= 61.16' BF E LEV= ? I 2505' -I4-1/2"ISS X NP,ID=3.813" KOP= 1154' GAS LFT MASS Max Angle= 97°@ 10905' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum MD= 10250' 5 3776 3502 30 KBG2- DMY - BK 0 07/03/13 Datum TVD= 8800'SS , 4 5762 5248 29 KBG2 DMY BK 0 07/03/13 fr 20"(bNDIX TOIL D ? H -110 3 7242 6522 28 KBG2 DMY BK 0 07/03/13 2 8189 7360 27 KBG2 DMY BK 0 07/03/13 9-5/8"CSG,40#,L-80 BTC,D=8.835" - 3834' 1 9053 8132 29 KBG2 DMY BK 0 07/03/13 9129' -14 Minimum ID = 2.377" 10531' v2" sxNP,FES =3.813" 3-1/2" X 2-7/8" LNR XO I i1 9158' -7"x 4-1/2"FES TNT PKR,D=3.856" 9233' H4-1/2"I-ES X NP,13=3.813" 7"x 4-1/2"WS WH3GE 13=3.958 -I 9248' 9269' H4-1/2"FES X NP,D=3.813" 7"x 4-1/2"WS WEDGE,D=3.958 H9404' 9426' -14-1/2"FES X NIP,ID=3.813" 7"x 4-1/2"WS WEDGE,ID=3.958 -I 9612' 19633' H4-1/2"FES X NP,ID=3.813" 7"x 4-1/2"WS W®GE,ID=3.958 -I 9810' b 9831' -4-1/2"FES X NP,ID=3.813" -0, 9831' -4-1/2"X LOCK w THREAD PROT SET, 4-1/2"NS WHPSTOCK(08/03/13) - 9795' ID=2.60"(7/24/13) 4-1/2"TBG,12.6#,13CR-85 VAM TOP, 9842' 1_.- 9870' -17"X 4-1/2"UNIQUE OVERSHOT .0152 bpf,D=3.958" IMI 1,--- 7"X 4-1/2"BAKER S-3 PKR ID=3.875" 4-1/2"TUBNG STUB(05/26/13) H 9852' di 9955' H4-1/'2"WRP(03/30/13) 10035' -14-1/2"FES X NP,ID=3.813" TOP OF 4-1/2"LNR - 10053' 4-1/2"TBG,12.6#,L-80 AB-MOD, -I 10057' iii 10053' 17"X 5"BKR ZXP PKR W 6'PER .0152 bpf,ID=3.958" /BKR HMC LNR HGR,ID=4.375" 10057' �4-1/2"WLC�,D=3.958"(STUNG 2'Km LTP) 17"CSG,264,L-80 BTC-M,ID=6.276" H 10197' , 10074' -5"X 4-1/2"XO,D=3.958" 4-1/2"TNV MLAS CV SUB WO/PROFILED=3.870" H 10588' - (COLLAPSED(05/97) PERFORATION SUMMARY r 'r_ 10530' -14-1/2"G FISI-i'ECK FIT LOG:????'»7?ON rrrr✓dd/yy? 10531' H3-1/2"X 2-7/8"XO,ID=2.377" ANGLE AT TOP PERF: NYA Note:Refer to Production DB for historical pelf data SIZE SPF UTE-R1/AL Opn/Sqz SHOT SOZ MLLOUT WINDOW(02-38L1) 10580'- 10605' r 02-38 2-7/8" 6 9990-10000 03/14/06 2-7/8" 6 10000-10010 03/14/06 2-7/8" 4 10120-10200 11/02/96 ` - `` 02-38L1 -.` ` 2-7/8" SLTD 10621 -11566 SLOT 05/16/97 -.- + PBTD(2-7/8"O-RING SEAL) -I 11566' / PB7D 11474' 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" - 11561' 2-7/8"LNR,6.5#,L-80,.0579 bpf,13=2.441" -i 11599' DATE REV BY COMMB'ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/07/96 N2ES INITIAL COMPLETION 09/08/13 CJN/PJC X-LOCK w/THR PROT(7/24/13) WaL: 02-38/L1 05/15/97 N4ES CTD LATGBZAL (02-38 L1) 09/08/13 RWM/PJC SET WHPSTOCK(8/3/13) PERMIT No: 1961610/1970230 07/06/13_ D-16 RWO AR No: 50-029-22708-00/60 07/12/13 PJC DRLG HO CORRECTIONS SEC 36,T11 N,R14E,739'FNL&1712'FWL 07/15/13 SMvVPJC FINAL ODE APPROVAL 09/08/13 CJN/PJC DGLV(07/21/13) BP Exploration(Alaska) • • V OF TA 6,4 I %% i t THE STATE Alaska. Gil and Gas = u se vatic n Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue VA *'` , Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen SUNNED v�� 2�� Engineering Team Leader - a g--3 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02 -38L1 Sundry Number: 313 -298 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. s erster Chair DATED this a day of June, 2013. Encl. • STATE OF ALASKA • ,-. , ,., : , 1 - '-- � ALASKA OIL AND GAS CONSERVATION COMMISSION , � i7? S 6 20 APPLICATION FOR SUNDRY APPROVAL �. , 20 AAC 25.280 J , \ i `0 ,+. ;A 1. Type of Request: ❑ Abandon ® Plug for Redrill . ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 197 - 023 • 3. Address: 6. API Numbe ® Development ❑ Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 . 50.029 22708 - 60 - 00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 02 -38L1 • Will planned perforations require a Spacing Exception? ❑ Yes ® No 9. Property Designatior 10. Field / Pool(s): ADL 028308 ' Prudhoe Bay Field/ Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft)'. Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11599' • 8781' • 11599' 8781' 9955' None Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 3834' 9 -5/8" 30' - 3834' 30' - 3553' 5750 3090 Intermediate 10169' 7" 28' - 10197' 28' - 8860' 7240 5410 Production ` Liner 527' 4 -1/2" 10053' - 10580' 8843' - 8845' 8430 7500 1069' 2 -7/8" 10530' - 11599' 8849' - 8781' 10570 11160 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 10622' - 11566' Slotted Liner 8041' - 8710' 4 -1/2 ", 12.6# L -80 10057' Packers and SSSV Type: 7" x 4 -1/2" Baker S -3 Packer Packers and SSSV 9909' / 8797' MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: - �_ Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: July 1, 2013 • ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Suspended . Commission Representative: ❑ WAG ❑ SPLUG C 17. I hereby certify that the fo going is true and correct to the best of my knowledge. Contact: Ron Phillips, 564 -5913 Printed Name: Jo ; A ar n r ` Title: Engineering Team Leader E il: Ron.Phillips atvbp.com Signature: " Phone: 564 - 4711 Date: r / Commission Use Only ,! ,e_ 3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number t 3 - D ' ❑ Plug Integrity taBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: B D p /eS f0 3546CpSt f C p5 - , / I Uk) �I t - r �4 . fiz p)v, p J a ,e4- � ' t �' ` a , f p -- r aU 4 7 RBDMS JUN 2 6 2. Spacing Exception Required? ❑ Yes L, (o Subsequent Form Required: it) — 4. e , APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: rp -2.1c l3 Form 10 -403 Revis 10/ 12 Appr l i v lid for 1 �\i� 2 months from the date of approval Submit In Duplicate � - 6 b V 13 -Ai\-t64 i.P\ • • • To: Alaska Oil & Gas Conservation Commission From: Ron Phillips bp CTD Engineer Date: May 28, 2013 Re: 02 -38 Sundry Approval Sundry approval is requested to plug the 02 -38 perforations as part of the drilling and completion of • proposed 02 -38 coiled tubing sidetrack. History and current status: The 02 -38 was completed in 1996. The well saw very little flow due to poor rock quality. In 1997 a CTD multi- lateral was attempted, but due to drilling complications, only one lateral was added via (02- 38L1). The lateral was completed as a slotted liner that came on strong with low GOR. The well gradually increased in GOR until perforations were added up hole in 2006 (these added very little if anything). The slotted liner was then SI in mid -2007, and the upper perforations flowed only gas. The well also had integrity problems in that stretch that were eventually remedied via GLV work. The well was returned to production in late 2008 when the slotted liner was co- mingled with the all -gas upper perforations. The well continued to rise in GOR until mid - 2011 until it was SI for high GOR. Several cycle attempts since then have proven unfruitful. Well 02 -38 is no longer a competitive producer due to high GOR and has no remaining well work options. The proposed sidetrack will access the Z1A sands to the east of the parent wellbore. Proposed plan 02 -38A is to drill a through tubing sidetrack with the SLB /Nordic 2 Coiled Tubing Drilling rig on or around July 15, 2013. The existing perforations will be isolated by a CIBP set pre -rig to mitigate lost circulation to existing perforations while drilling. The sidetrack, 02 -38A, will exit the existing 4 -1/2" liner and 7" casing, kicking off in zone Z2A. This Sundry covers plugging the existing • 02 -38 perforations via the 02 -38A liner cement iob (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. ... ell 1'70 �ePy ,�� go coo �� / <� 661( 6" ,till?ws /l'ti/ Gpy nP 1 fy0,4 y 7,,/< Cc, .4e dii'l /ei 1 /eca' So a / f rom T 4, s /b' t' G eke 6/7 -43/ • • Required Permit? Pre -Rig Work (scheduled to begin July 1st, 2013) 10 -403 PTD 1. F MIT -TxIA to 3,000 psi. No No 2. F MIT -OA to 2,000 psi. No No MIT -T /Test CIBP @ 9,925' to mitigate lost circulation during 3. C sidetrack. (After RWO) No No 4. V PT MV, SV, WV. (After RWO) No No 5. V Bleed wellhead pressures down to zero. (After RWO) No No Bleed production, flow and GL lines down to zero and blind 6. V flange. (After RWO) No No 7. 0 Remove well house and level pad. (After RWO) No No Required Permit? Rig Work (scheduled to begin July 15th, 2013) 10 -403 PTD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. No Yes 2. Mill 3.80" window at 9,840' and 10' of rathole. No Yes 3. Drill Build: 4.5" 765' OH, (24 deg DLS planned). No Yes 4. Drill lateral: 4.5" OH, 2395' (12 deg DLS planned). No Yes 5. Run 3 -1/4" liner leaving TOL at 9,680' MD. No Yes 6. Pump primary cement job: 38.6 bbls, 15.8 ppg, TOC at 9,680'. Yes* Yes 7. Perform liner cleanout and GR /CCL /MCNL log. No Yes 8. Perform liner lap test. No Yes 9. Perforate liner based on log interpretation (^'1,300'). No Yes 10. Freeze protect well to 2,500' MD. No Yes 11. Set BPV and RDMO. No Yes * Alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set GLV's 3. Set liner top packer with slickline (if liner lap test fails). 4. ASRC flowback /well test. Ron Phillips CTD Engineer 564 -5913 CC: Well File Joe Lastufka WTREE= H_LIAD = 1/16" CMV • 02-38 SAY NOTES: WELL ANGLE> 70° @ 9907' ACTUATOR = BAKER C L 1 KB. REV = 61' BF. ELEV = ? KOP= 1154' Max Angle = 97° @ 10905' Datum MD = 10250' I 2059' — 14 - 1/2" CAM BAL -O SSSV NP, D = 3.813" Datum TVD = 8800' SS 0 1 9-5/8" CSG, 40 #, L -80, D = 8.835" -{ 3834' I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE Minimum ID = 1.25" @ 11566' I 1 4089 3776 29 KBG DMY NT 0 04/01/08 2 7201 6486 29 KBG DMY INT 0 04/01/08 3 8897 7993 26 KBG DMY INT 0 04/16/04 2 -7/8" 0 -RING SEAL SUB ►�� 9909' —17" X 4-1/2" BAKERS -3 PKR 9955' 1- 14 -1/*2" WRP(03/30/13) J I I I 10035' —14 -1/2" HES X NP, D = 3.813" I TOP OF4 -1/2" LNR — 10053' 10053' I — 7" X 4 -1/2" BKR ZXP PKR 4 -1/2" TBG 4-1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" —I 10057' ►= TAL STUNG INTO R<R TOP 2' I 10057' I - - 1/2" TUBING TA WLEG , I-1 EMD TT NOT LOGGED I 7" CSG, 26#, L -80, D = 6.276" I- 10197' [----4 ■ 1 a 10530' H4 -1/2" G FISHNEC:K I TOP OF 2 -7/8" LNR H 10531' I — ; / 10531' H3-1/2" X 2 -78" XO I PERFORATION SUvTAARY REF LOG: ? ? ? ?''n ON rrrn/dd/yy? ANGLE AT TOP PERF: 73° @ 9990' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn /Sqz I DATE 02 -38 MLLOUT WINDOW 2 -7/8" 6 9990 - 10000 0 03/14/06 10580' - 10605' .gir 2 -7/8" 6 10000 - 10010 0 03/14/06 2 -7/8" 4 10120 - 10200 0 11/02/96 02 -38L1 SLID 10621 - 11566 0 05/16/97 11566' 12 -7/8" 0 -RING SEAL SUB, D = 1.25" 4 -1/2" LNR,12.6#, L -80, .0152 bpf, D = 3.958" H 10581' 2 -7/8" LNR, 6.5#, L -80, .0579 bpf, ID = 2.441" H 10621' \ TOP OF 2 -7/8" SLTD LNR —I 10621' I 2 -7/8" SLID LNR, 6.5#, L -80, .0579 bpf, D = 2.441" H 11566' TOP OF 2 -7/8" LNR 11567' 2 -7/8" LNR 6.5#, L -80, .0579 bpf, D = 2.441" I MEM I TD I 11599' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/07/96 ORIGINAL COMPLETION 11/20/08 RDB/ LH WRP PULLED (10/17/08) WELL: 02 -38 / L1 05/15/97 CTD LATERAL ST (02 - 38L1) 12/20/09 SV LATERAL NAMING FORMAT PERMIT No: 1961610 / 1970230 02/02/02 RN/1P CORRECTIONS 06/26/12 JO/JIVE) TREE C/O (06/19/12) API No: 50 -029- 22708 -00 / 60 11/10/06 TWS/TLH PERFS (03/13/06) 04/02/13 SWC/ PJC SET WRP (03/30/13) SEC 36, T11 N, R14E 1251.46 FEL 1149.6 FNL 07/06/07 JGM/SV SET WRP (07/06/07) 04/05/08 KJB /JPJC GLV C/O (04/01/08) BP Exploration (Alaska) - IFS= 1/16" CNVFLS • SOY NOTES: WELL ANGLE> 70° @ 9907' Q 2 — 3 8 L1 VvE LHEAD = FMC ACTUATOR = BAKER C Proposed RWO KB. ELEV = 61' ropd BE ELEV = ? - KOP= 1154' I I I 2,200' H4 -112" HES'X' Nipple, ID = 3.813" I Max Angle = 97° © 10905' Datum MD = 10250' GAS LET MANDRELS Datum TVD= 8800' SS + ST M? ND DEV TYPE VLV LATCH FORT DATE I - 9-5/8" CSG, 40#, L -80, U = 8.835" H 3834' I - 4 1 I 9,120' —14 -112" HES 'X' Nipple, ID = 3.813" R' 10 I 9,150' —14-1/2" HES 'X' Nipple, ID = 3.813" I • I 9,180' H4 -1/2" HES 'X' Nipple, ID = 3.813" .4 111 9,230' — 4 -1/2" x 7" CT w hOstock w edges .411 4111111 Aod 4141 9,430' — 4 - 1/2" x 7" CTwhipstockwedges Al 4 9,630' — 4 -1/2" x 7" CTwhipstockwedges 9,830' — 4 -1/2" x 7" CTwhpstockwedges ( ® C.4 9909' — 17" X 4 -1/2" BAKER S -3 PKR I , • I 9925' I -14 -1/2" Cast Iron BP I ■ I 10035' IH4 -1/2' HES X NP, 0 = 3.813" TOP OF 4 -1/2" LNR — I 10053' 10053' — 7" X 4 -1/2" BKR ZXP PKR 4 -1/2" TBG 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, 0 = 3 958" H 1005T 1■4 TA L STUNG INTO PKR TOP 2' gill 10057' - 14-1>2" TUBING TAL WLEG 7" CSG, 26#, L -80, 0 = 6 276" H 1019T 1 10530' I — 4 -1/2" G FISHNECK TOP OF 2 -7/8" LNR —I 10531' \ I I 10531' H3-1/2- x 2 -7/8' x0 I PERFORATION SUMMARY REF LOG: "'M'n? ON rrm+ddtyy? ANGLE AT TOP FERF: 73° @ 9990' Note: Refer to Production DB for historical pert data SIZE I SPF INTERVAL Opn /Sqz I DATE 02 -38 MLLOUT WINDOW 2 -7/8" 6 9990 - 10000 0 03/14/06 10580' - 10605' 2 -7/8" 6 10000 - 10010 0 03/14/06 2-7/8' 4 10120 - 10200 0 11/02/96 02 -38L1 ''''''') - : - ' SLTD 10621 - 11566 0 05/16/97 11566' I J2 -7/8" 0-RING SEAL SUB, U = 1 25" 4 -1/2" LNR,12.6#, L -80, .0152 bpf, 0 = 3.958" }-f 10581' J 2 -7/8" LNR, 6.5#, L -80, .0579 bpf, ID = 2 441" J 10621' I TOP OF 2 -7/8" SLTD LNR — 10621' I 12 - 7/8" SLTD LNR, 6.5 #, L - 80, .0579 bpf, 0 = 2 441" 11566' I TOP OF 2 -7/8" LNR 11567' 2 -7/8" LNR, 6 5#, L -80, 0579 bpf, ID = 2 441' 11599' I TD —1 11599' DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 11/07/96 ORIGINAL COMPLETION 11/20/08 RDB/TLH WRP PULLED (10 /17/08) VVE_L: 02 -38 / L1 05/15/97 CTO LATBZAL ST (02 - 38L1) 12/20/09 SV LATERAL NAMING FORMAT PERfvIT No 1961610 / 1970230 02/02/02 RN/TP CORRECTIONS 06/26/12 JO /JM) TREE CIO (06/19/12) AR No: 50- 029 - 22708 -00 / 60 11/10/06 TWSRLH PERFS (03/13/06) 04/02/13 SWC/ PJC SET VVRP(03/30/13) SEC 36, T11N, R14E 1251.46 F13 1149.6 FNL 07/06/07 JGMSV SET WRP (07/06/07) 04/05/08 KJB /JPJC GLV C/O (04/01/08) BP Exploration (Alaska) il1fILFEAD = 1/16" CtWFM • O 2 -38 Q SA Y NOTES: WELL ANGLE> 70° @ 9907' • ACTUATOR = BAKER C (� KB. ELEV = 61' BF. ELEV = ? KOP= 1154' Max Angle = 97° @ 10905' ■ Datum k V = 10250' ■ 2200' - 4 1 /2" HES x' NP, D = 3.813' Datum TV D = 8800' SS GAS LIFT MANDRELS 9 -5/8' CSG, 40#, L -80, D = 8.835' H 3834' — ST MD ND DEV TYPE VLV LATCH FORT DATE LI Minimum ID = I I 9120' H4 -1/2" FES X nipple, D = 3.813" 'g g 9150' -{ 7' X 4-1/2" BAKER S-3 RKR R32FORATIDN SUMMARY I I REF LOG: ????V ON nrddd/yy? 9180' - 172" I-ES X nipple, D ANGLE AT TOP PERF: 73° @ 9990' Note: Refer to Production DB for historical perf data 16' - I TSGt' SCE SPF NTHZVAL I Opn /Sqz DOTE 4 ` 9230' H4 - 1/2' x 7' WS Wedge . I 9430' H4 - 1/2" x 7" WS Wedge - 4-1/2" x 7" WS Wedge H 9630' 4 ■ 9630' H4 -1/2" x 7" WS Wedge 9680' -{ TOL/TOC 3.70' OP SLV 9690' -I 3 -1/2" S1L, 9.3# pip joint I - 9700' H3 -112' X ripple, D 9699' H3 -1/2' XO 3 -1/4', D 2.786" 4 11:.'" tk rthern `volutions - retr , ,k' WS 9840' -------- I4 -1/2" x 7" WS Wedge H 9850' ._. -- ,� 13 -1/4' LNR, 6.2#, L -80 TCIl --1 13000' 1 7" X 4-1/2" BAKER S-3 PKR H 9909' E, II 4 HES X NP, D = 3.813' - 10035' 1 {TOP OF 4 -1/2' LNR H 10053' 4 -1/2' TBG, 12.6#, L -80, .0152 bpf, D = 3.958" H 10057' --:____------1 7" X4-1/2" BKR ZXP PKR 41/2" — 10053' TBG TAIL STUNG INTO PKR TOP 2' 7' CSG, 26#, L -80, D = 6.276' H 10197' DATE REV BY COMIv64TS DATE REV BY COMIVBTTS F UJHOEBAY UNIT 11107/96 ORIGINAL COMPLETION 11/20/08 RDBITLH WRP PULLED (10/17/08) VVE L: 02 -38 / L1 05/15197 CTD LATERAL ST (02 -38L1) 12/20/09 SV LATERAL NAMING FORMAT PERMIT No: 1961610 / 1970230 02/02/02 I 'I/ TP CORRECTIONS 06/26/12 JO /JMO TREE C/O (06/19/12) AR No: 50- 029 - 22708 -00 / 60 11/10/06 TWS/TLH PEWS (03/13/06) 04/02/13 SVVC/ PJC SET WRP (03/30/13) SEC 36, T11 N, R14E 1251.46 Fa 1149.6 FNL 07 /06 /07 JGM/SV SET WRP (07 /06/07) 04/05/08 KJB/JPJC GLV GO (04/01 /08) BP Exploration (Alaska) NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM a 11 _ '` - ' I " Cho a Prat Standpipe 2•' Circulation Line - - I .. . M11 0 C t� //�!'`` Driller Gauge�� • • , M70 • j Manual Choke V 7 .,? aIlsl}} a x a � rt CIRCULATING MANIFOLD — MM s MM • MM 18 "^6•' a * a a�a MM 15 I I SLB Transducer - „.,., ��../ � ea S`MM8 PVT Sensor .— tom` ' #e'_ (' ' • r � I • MM awe Baker Choke Blind sne..n r MM 13 MM 4 ■ MM 17 KILL SIDE MANUAL VALVE CHOKE SIDE J I ': ' KILL HC0. 3 Comb, TOT MANUAL VALVE /� I MG: Rev Cir Line I / CHOKE HCR f An Blow tlown •� , MMi4 . - ✓ ” - ra ! 1A J' 1r a1 I e ■.rlt;daitki �l� •ao.y�1. �� a ., Choke Line 'sue a III s OA Coiled Tubing — is �; � � _ OrI■■1aTII 1C1tiGt �Irwrrr■wr ... ,z V� 1 1 Ba rChoke Knl Line - -. o b, ' ( MP2 ■ C I 46 MP ; e - I se I R I, W ,t t- u Kill Line _ I _ \ BOP 1 8 % I HP11 HP 10,.. Tnanducer COILED TUBING I / \ B OPI 7 / I a } - � CIRCULATING SYSTEM I % r' �' +. � `' ' t_ I . HP 18 - ' HP 14 P19 HP I I 1 - To Inner Reel I ... • Valve HP 15 HP7 HP5 HP HP3 I I . HP 13 I_ I I • • • • . I —, — — — • / _ - - — , I I Ill HP12 HP HP1 .. I HP 18 / ./.. I cement line N2 SLB / 1 i I CHOKE MANIFOLD / — I HP 17 N2 TrIFlow Ni ./ CM 85 MOs `t • y7y Gaups I ' .. 319' I I I CM 29 Ni ■ CHOSE uHe ! I : ' > oks BusTER , • I Test Pumo Inlet — CM 30 / - I 40 CM3 / / .�... l 1111 I / HDI'WUpe P131 I Flow a HCR / . O 4Wav Block .i CM24 Note CM14 CM7/ CMB In! PBI liquid I I CMS CMG leg is N _ - - Baker Choke Line m 10 .. I from L i I- Baker _ _ f high CM13 .1 • 1 N 1 I W E — CM2 POSSUM BELLY I CM28 01121 - — cMa • I a r I CM20 I es I cr,o � _ T I.. Tank I • — CM16 CM19 CM27 I ■ I TIGER TANK I O F • ~ 7-/~-()7 . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 61 KB / 8. Property Designation: ADLO-028308 11. Present Well Condition Summary: Total Depth measured true vertical 11599 /' 8781 / Effective Depth measured true vertical 11599 8781 Casing Conductor Surface Production Liner Liner Slotted Liner Perforation depth: Length Size 80' 20" 94# H-40 3805' 9-5/8" 40# L-80 10169' 7" 26# L-80 528' 4-1/2" 12.6# L-80 91' 2-7/8" 6.5# L-80 945' 2-7/8" 6.5# L-80 33' 2-7/8" 6.5# L-80 Measured depth: 9990' - 10200' True Vertical depth: 8828' - 8860' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 662 SHUT-IN x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic feet feet feet feet MD 30' - 11 0' 29' - 3834' 28' - 10197' 10053' 10581' 10530' - 10621' 10621' - 11566' 11566' - 11599' - - 4-1/2" 12.6# StimulateD Other D BRIDGE PLUG SET Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 9. Well Name and Number: 197 -0230 - 6. API Number: 50-029-22708-60-00 - PBU 02-38L 1 - 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool - Plugs (measured) Junk (measured) TVD 30' - 110' 29' - 3553' 28' - 8860' 8843' - 8845' 8849' - 8841 ' 8841' - 8781' 8781' - 8781' L-80 4-1/2" BAKER S-3 PACKER 4-1/2" BAKER ZXP PACKER o o None None Burst 1530 5750 7240 8440 10570 10570 10570 27' - 10057' 9909' 10053' o o f).CANNED JUL 182007 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 34598 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of m~'BFl JUL Contact Gary Preble Signature :E:; Q) (/. ~ Q) ~ ¡¡<õ Collapse 520 3090 5410 7500 11160 11160 11160 c_ c.: ,-- I ~ m () m - < m o 'p...1. \.~ ~ c;::J c;::J -..j Tubing pressure 761 o Service WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Management Engineer Phone 564-4944 Date 7/10/2007 IJ'" '\'"") ¿Iß 7r4¡P? . . 02-38Ll DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/5/2007 CTU #8, Set WRP (GSO); MIRU unit. MU and RIH with 3.7" OD drift. Drift tubing down to 10515' ctmd. POOH. ... Cant' on WSR 07/06/07 ... CTU #8, Set WRP ... Cant' from WSR 07/005/07... MU and RIH with 4.5" WFD WRP. Set WRP at 10500' ctmd. Cap well with 35 bbls of 50/50 meth. Slow down reel with N2. RDMO. *** Job Complete *** FLUIDS PUMPED BBLS 30 1 % KCL 35 50/50 METH 65 TOTAL . . WELL LOG TRANSMITTAL .---- ,-¡;.: ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/ Mechanical Logs and / or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 BL / EDE Disk 02-38L 1 Production Profile 16-Nov-06 1] 2] 3) 4) 5) 6) 7] ~NE.D APR O:} 2007 1 Cr1--0Q3 ~ I L( 5-3 ( Print Name: f { \ / - r J/\~ 0 7J'~ ¡, IJ'--P t~ fV~ i\J, iA- (¿p¡( ~IAR () 6 Z007 Date: .... ,. ..-. --1,,- )e!f:1 ¡.\jas¡{~ \J~ð òz ;.;as L\en~. \.AJI¡ ~~! I ¡j ~~ij --~ \1 Signed: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAil: PDSANCHORAGE@MEiVlORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Master _Copy _00 ]DSANC-20xx'\Z; _ W ord\Distribution\TmnsuùttaC Sheets\TmnsuùC Original.doc . STATE OF ALASKA ... fife- '1 / ~ / Q({ <'þJ ...1\- Al.A: Oil AND GAS CONSERVATION COM~ION -~lv0 1/ ~/¿J'ý REPORT OF SUNDRY WELL OPERATIONS D D [] 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: 61 KB ADL-028308 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Production Liner Liner Slotted Liner Perforation depth: measured 11599 true vertical 8781 measured 11599 true vertical 8781 Length 80 3805 10169 528 91 945 33 Size 20" 94# H-40 9-5/8" 40# L-80 7" 26# L-80 4-1/2" 12.6# L-80 2-7/8" 6.5# L-80 2-7/8" 6.5# L-80 2-7/8" 6.5# L-80 Measured depth: 9990 - 10010 True Vertical depth: 8828.29 - 8833.64 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic [J Stimulate D ...... ..... ~ther· .)/j.:~' ~ WaiverD Time Exfèn~nÐ ·"·t"",,, Re-enter Suspençled wetfQn¡ 5. PermittÖDrilJ.Number. 197-0230 ·co, 6. API Number:!,i' 50-029-22708-60-00 9. Well Name and Number: Exploratory Service 02-38L 1 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) feet feet MD 30 - 110 29 - 3834 28 - 10197 10053 - 10581 10530 - 10621 10621 - 11566 11566 - 11599 TVD 30 - 110 29 - 3552.84 28 - 8859.55 8843.19 - 8844.52 8849.12 - 8840.68 8840.68 - 8780.62 8780.62 - 8781 10120 - 10200 8851.94 - 8859.77 4-1/2" 12.6# L-80 4-1/2" Baker S-3 Packer 4-1/2" Baker ZXP Pakcer None None Burst 1530 5750 7240 8440 10570 10570 10570 Collapse 520 3090 5410 7500 11160 11160 11160 27 - 10057 9909 10053 Treatment descriptions including volumes used and final pressure: RBDMS 8Ft .ÄPR 2 8 2006 13. Oil-Bbl 486 440 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 29555 0 340 26296 0 325 15. Well Class after proposed work: Exploratory Development M 16. Well Status after proposed work: Oil MI Gas [J WAG Tubing pressure 917 1263 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~~ . Form 1 0-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 WDSPL Date 4/20/2006 Submit Original Only .. . . 02-38L 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 3/13/2006 Part 1 of 2 Depth correlated to Platform Express Log, dated 22-0ct-1996 Run #1: 1 A' HSD Gun, 6 spf, perforated Run #2: 1 A' HSD Gun, 6 spf, perforated 3/14/2006 Part 2 of 2 Perforation Record. Perforated from 9,990' to 10,000' FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 ~IS C~ ON OR BEFORE AN O1 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 05/24/99 PERMIT DATA T DATA PLUS RUN RECVD 97-023 MWD SRVY ~1Q551.8-11599. 07/17/97 97-023 NGP=MD ~/~//10623-11599 FINAL 08/27/97 97-023 NGP-TVD ~'781-8719 FINAL 08/27/97 97-023 8087 ~/~SPERRY GR/ROP 3 08/27/97 97-023 MWD SRVY ~.~PERRY 10551.80-10591 08/18/97 10-407 ~COMPLETION DATE @~//~/$~/ @~/ ? /~ DAILY WELL OPS ~RJ@~/[Q/~'2/ TO 3~/~'~/ @ ~3/I /~// Are dry ditch samples required? yes ~__~And received? Was the well cored? yes ~.Analysis & description received? ye~-~no ! Are well tests required? ~s ~Received? y~=s~n~~ Well is in compliance In~t'ia~l COMMENTS T D BOX -- WELL LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs D.S. 2-38L1, AK-MW-70141 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 2-38L1: 2" x 5" MD Gamma Ray Logs: 50-029-22708-60 2" x 5" TVD Gamma Ray Logs: 50-029-22708-60 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia AUG 2 7 1997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9,07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company C] !=1 I I_1_ I IM CS S~ Fl,,ti r- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 PorcuPine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 2-38L1, August 27, 1997 AK-MW-70141 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Yum Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22708-60. RECE ,/ED 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil_X Gas Suspended__ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-23 3 Address 8 APl Number P.O. Box 100360 Anchorage, AK 99510-0360 ........... 50-029-22708-60 , :.., ,:%t~:Tr;,;,iL-~ 4 Location of well at surface ~' ';':~ *-' ~,~i~ ~ ~ 9 Unit or Lease Name 4541' NSL, 3568' WEL, Sec 36, TION, R14E, UM.? _/.F.¢,TF, ~' .~1~!~ PRUDHOE BAY UNIT At Top Producing interval !',,,~//~/~ ! ~ 10 Well Number At To2t:ITD8~ptNhSL' 1100' WEL' Sec 25' T11N' R14E' UM'i ~JF~_ i t 1 Field2-S8Lland Pool 1148'FNL, 1347'FEL, Sec25, T11N, R14E, UM. '~'-~ .... ~ ' " ' PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 61' RKB ADL 28308 PRUDHOE BAY OIL POOL 12 Date Spudded t 3 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 5/12/97 5/15/97 5/16/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11599' MD / 8781' TVD 11599' MD / 8781' TVD YES_X NO__ 2059' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 110' 30,, 260 Sx Arcticset - 9-5/8" 40# L-80 Surf 3834' 12.25" 3305 Sx Coldset III & 440 Sx G - 7" 26# L-80 Surf 10197' 8.5" 464 Sx Class G - 4-1/2" 12.6# L-80 10053' 10580' 6,, 175 Sx Class G - 2-7/8" 6.5# L-80 FL4S 10530' 11599' 3.75" Uncemented - 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 10057' 9909' 2-7/8" Slotted Liner: 10622 - 11566' MD; 8840 - 8781' TVD. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST }ate First Production Method of Operation (Flowing, gas lift, etc.) 5/20/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GOR 5/22/97 6.6 TEST PERIOD __ 2017 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (con') 379 - 24 HOUR RATE _X 1986 4006 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. ORIGINAL * This 10-407 submitted as directed per the 10-401 form approved 2/19/97 (Permit # 97-23). R ~,~ ~ ~ V ~,. A(J6 7 1997 ... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 9217' 9322' TRUE VERT DEPTH 8273' 8363' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Summary of 2-38L1 Coil Tubing Multilateral Drilling Operations. 32 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~,~.~,_ '~1.,~ . ~ Engineerinq Supervisor _ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. 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 2-38L1 DESCRIPTION OF WORK COMPLETED COILED TUBING MULTILATERAL DRILLING 5/10/97: MIRU CTU. NDNUtree & BOP. 5/11/97: PT BOPS. RIH & displaced well to Seawater. POOH. MU & RIH w/window milling BHA. 5/12/97: Milling BHA landed on DGLV fish at 10436' MD; could not go deeper. POOH w/BHA. RIH w/overshot. Tagged up at 10599' MD w/no indication of fish. POOH; no fish. RIH w/3.8" milling BHA. Staded milling a window through the 4-1/2" liner at 10580' MD. 5/13/97: Milled window to 10599' MD. into formation to 10605' MD. POOH w/BHA. RIH w/dressing mill & reamed window smooth. Reamed POOH w/BHA. 5114197: MU & RIH w/drilling BHA. Swapped well to FIo-Pro & drilled a 3.75" horizontal multilateral hole to 11250' MD. 5/15~97: Drilled horizontally to 11344' MD w/mud losses to 30 - 35 bph. ST to 9800', CBU, & SD. Cleared flowline blockage of cuttings, then RIH to tag bottom & resumed circulating. Drilled to 11484' MD w/mud losses at 18 bph. Wiped hole to window, then RIH & resumed drilling to TD at 11599' MD. POOH. RIH w/2-7/8" slotted liner assembly. Landed liner on bottom at 11599' MD. Disconnected & POOH displacing well w/Seawater. Left liner assembly set at 10530 - 11599' MD. 5/16/97: RD CTU. Set BPV. ND BOP. NUtree. Released rig. Placed the well on production & obtained a valid welltest. SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PRUDHOE BAY / 2-38L1 500292270860 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/ 3/97 DATE OF SURVEY: 051497 MWD SURVEY JOB NUMBER: AK-MW-70141 KELLY BUSHING ELEV. = 61.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10551.80 8847.20 8786.20 95 11 N 13.90 W .00 3880.70N 2513.00E 3288.76 10587.00 8843.64 8782.64 96 24 N 15.60 W 5.89 3914.56N 2504.09E 3323.73 10614.00 8841.02 8780.02 94 45 N 18.70 W 12.96 3940.23N 2496.16E 3350.48 10649.34 8838.68 8777.68 92 49 N 22.30 W 11.52 3973.26N 2483.81E 3385.32 10678.17 8837.40 8776.40 92 16 N 17.61 W 16.36 4000.32N 2473.99E 3413.82 10718.09 8835.65 8774.65 92 43 N 20.95 W 8.43 4037.96N 2460.82E 3453.35 10746.27 8834.15 8773.15 93 23 N 21.50 W 3.07 4064.19N 2450.64E 3481.10 10777.77 8831.97 8770.97 94 34 N 21.70 W 3.80 4093.41N 2439.07E 3512.06 10808.82 8829.36 8768.36 95 3 N 24.70 W 9.75 4121.84N 2426.88E 3542.38 10842.67 8826.32 8765.32 95 16 N 24.80 W .71 4152.46N 2412.77E 3575.22 10875.82 8822.94 8761.94 96 26 N 24.18 W 3.99 4182.47N 2399.10E 3607.38 10905.22 8819.44 8758.44 97 12 N 25.70 W 5.76 4208.93N 2386.79E 3635.80 10937.12 8815.68 8754.68 96 19 N 27.63 W 6.61 4237.24N 2372.57E 3666.40 10970.97 8812.10 8751.10 95 48 N 28.86 W 3.94 4266.89N 2356.65E 3698.67 11001.92 8809.14 8748.14 95 10 N 26.93 W 6.52 4294.11N 2342.24E 3728.26 11031.29 8806.65 8745.65 94 34 N 25.17 W 6.32 4320.40N 2329.39E 3756.61 11064.59 8804.20 8743.20 93 52 N 23.94 W 4.24 4350.60N 2315.59E 3788.99 11092.12 8802.55 8741.55 92 59 N 22.18 W 7.14 4375.88N 2304.82E 3815.93 11125.57 8801.04 8740.04 92 11 N 21.83 W 2.58 4406.87N 2292.30E 3848.81 11161.69 8799.65 8738.65 92 11 N 19.72 W 5.84 4440.61N 2279.50E 3884.45 11197.84 8798.29 8737.29 92 6 N 17.79 W 5.34 4474.81N 2267.89E 3920.29 11242.24 8796.52 8735.52 92 27 N 15.50 W 5.21 4517.30N 2255.18E 3964.49 11283.37 8795.04 8734.04 91 40 N 12.16 W 8.34 4557.21N 2245.36E 4005.56 11328.84 8793.85 8732.85 91 19 N 10.05 W 4.70 4601.81N 2236.61E 4051.00 11365.64 8792.33 8731.33 93 25 N 8.82 W 6.64 4638.07N 2230.58E 4087.73 11406.14 8789.90 8728.90 93 25 N 6.36 W 6.06 4678.13N 2225.24E 4128.04 11445.09 8787.37 8726.37 94 2 N 4.60 W 4.77 4716.82N 2221.53E 4166.67 11493.37 8783.82 8722.82 94 23 N 3.20 W 2.98 4764.85N 2218.26E 4214.37 11521.67 8781.89 8720.89 93 25 N 2.32 W 4.60 4793.05N 2216.90E 4242.26 11554.57 8780.56 8719.56 91 11 N .20 W 9.35 4825.91N 2216.17E 4274.58 11599.00 8780.78 8719.78 88 13 N 2.60 E 9.20 4870.32N 2217.10E 4317.87 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5351.22 FEET AT NORTH 24 DEG. 28 MIN. EAST AT MD = 11599 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 348.27 DEG. TIE-IN SURVEY AT 10,551.80' MD ORIGINAL .iNDO. OI.T PROJECTED SURVEY AT 11,599.00' MD RECEIVED JUL 1 7 ' 997 0il & Gas ~ns. Sommi~on SP~ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PRUDHOE BAY / 2-38L1 500292270860 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/ 3/97 DATE OF SURVEY: 051497 JOB NUMBER: AK-MW-70141 KELLY BUSHING ELEV. = 61.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10551.80 11551.80 11599.00 8847.20 8786.20 8780.62 8719.62 8780.78 8719.78 3880.70 N 2513.00 E 1704.60 4823.14 N 2216.19 E 2771.18 1066.58 4870.32 N 2217.10 E 2818.22 47.04 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPI Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 3 ARCO ALASKA INC. PRUDHOE BAY / 2-38L1 500292270860 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/ 3/97 DATE OF SURVEY: 051497 JOB NI3MBER: AK-MW-70141 KELLY BUSHING ELEV. = 61.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10551.80 8847.20 8786.20 10591.80 8843.12 8782.12 3880.70 N 2513.00 E 1704.60 3919.15 N 2502.78 E 1748.68 44.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 F:! I I--I-- I l~i G July 3, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 2-38L 1 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-38L1 MWD survey Tie-In point at 10,551.80', Window point at 10,587.00' and a Projected survey at 11,599.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company _ ALAS 0IL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 19, 1997 Erin M. Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re.' Prudhoe Bay Unit 2-38 L 1 .. ARCO Alaska, Inc. Permit No. 97-23 Sur. Loc. 4541'NSL, 3568~3[EL, Sec. 36, T11N, R14E, UM Btmnholc Loc. 1158'FNL, 1261'FEL, Sec. 25, TI 1N, RI4E, UM Dear Ms. Oba: Enctoscd is thc approved application for permit to redrill the above referenced wctl. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. The permit is for a new segment from existing well 2-38, API No. 50-029-22708-00. Production should continue to be reported as a function of the original well identifier. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a rcprcsentative 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 thc North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMIf:~iON PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill __ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 61' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28308 Prudhoe Bay/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 4541' NSL, 3568' WEL, Sec 36, T11N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2178' NSL, 1100' WEL, Sec 25, T11N, R14E, UM. 2-38A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1158' FNL, 1261' FEL, Sec 25, T11N, R14E, UM. February, 1997 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 2560 11568' MD / 8803' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10620' MD Maximum hole angle 95° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 LBO FL4S 1048' 10520' 8803' 11568' 8803' N/A (slotted liner) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11561 feet Plugs(measured) true vertical 8830 feet Effective depth: measured 11516 feet Junk (measured) true vertical 8827 feet Casing Length Size Cemented Measured depth Tru~VEtiC ~,thV E D Conductor 1 1 O' 2 0" 260 Sx Arcticset I 1 O' 1 1 O' Surface 3773' 9-5/8" 3305SxCo,dset,,,440SxG 2720' 259g'AN 3 1 1997 Liner 10136' 7" 464 Sx Class G 10197' 8859' Liner 1508' 4-1/2" 175 Sx Class G I 1561' 8830' Alaska Oil & Gas ~r~. Perforation depth: measured 10120 - 10200'; 10645 - 11055'; 11080 - 11100'; 11275 - 11395' true vertical 8852 - 8860'; 8839 - 8834'; 8833 - 8833'; 8826 - 8823' 20. Attachments Filing fee x Property plat __ BOP Sketch ~x Diverter Sketch _ Drilling program x_~ Drilling fluid program__ Time vs depth plot_ Refraction analysis _ Seabed repod _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (~o ¢s~'~¢~-~..=, .~ ¢.,-~1[ ~-{-6. V¢_ ~v,,~ f-~-- ,.'Z(¢ ~,~)"-~.'~O ~ Signed ~.?¢.(.¢..,,'h... -'c;~' ' ~"'J'l , ~"~.'-'/",.... Titlle Engineering Supervisor Date /~ ~/ -~"7 Commission Use Only Permit Number I APInumber j~ Appr_ovaldate~ I See cover letter for ? 7-- 2_ ~ 50-4:~..~_?--,~.,.~..~:~'-~ ~ -,- / ~'-- ~ '~ other requirements Conditions of approval Samples required .__Y e s ..~ N o M~"8 log rec~uired__' Y e s X_____ N o Hydrogen sulfide measures ~ Y e s N o Directional survey required ~ Yes __ N o Required working pressure forBOPE __2M; __ 3 M; __ 5 M · __ 1 OM; __ 1 5 M {'~ 3500 psi forCTU Other: ~.. ~ ~ r~- E~ ' by order of Approved byDavidW, Johnston Commissioner the commission Date¢:::~" / F'" Y~ ......... Form 10-401 Rev. 7-24-89 Submit in triplica 4-1/2"Camco Bal-O Nipple 9-5/8" Csg ~;hoe 4-1/Z" Otis "X" Nipple "Csg. Shoe 3834',~ .9921' 10197' [ I DS 2-38A Proposed Wellbore Sketch Multilateral Completion /Z" Production Tubing ~4-1/Z" CA-KBG-?-LS Mod GLM's = 03 X ..~0 7" Csg. set to 85.6° @ 1 O197' 4-1/2" Slotted Liner with MLAS sub 4-1/2" Baker whipstock & anchor --- 10620' DS 2-38A CT Lateral Leg Drilling and Completion Intended Procedure OBJECTIVE: Drill approximately 900' MD of formation out of the Multi Lateral Access Sub (MLAS) in the 4-1/2" horizontal liner. Run 2-7/8" slotted liner. INTENDED PROCEDURE: o Cleanout 4-1/2" liner and run tie-in GR/CCL log to determine the depth of the MLAS. . MU and run the whipstock assembly. Setting the assembly in the MLAS at ~ 10620'. o MU drilling 3-3/4" BHA on CT and drill ~- 900' MD out of the 4-1/2" liner. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). 4. MU and run a slotted 2-7/8" FL4S liner in open hole. 5. POOH with CT and RD. Put well on production. RECEIVED dAt 1 1997 Alaska Oil E Gas Cons. Comn,,issio~ Anchorag~ 11-31S--1.XLS 1:57 AM 2-38 A DIRECTIONAL SIDETRACK PAGE NO. 2 Comments MD Inc. Oir SS TVD VS N/(-S) E/(-W) Build Turn Dogleg ASP Y ASP X ft deg deg ft ft ft ft deg/100' Ideg/100' degll00' ft ft 11280.0 91.3 353.0 8745.8 656.9 4629.9 2186.6 -0.4 4.3 4.3 5955112.0 690645.4 11310.0 91.2 354.3 8745.2 686.7 4659.8 2183.3~ -0.4 4.3 4.3 5955142.0 690642.1 11340.0 91.1 355.6 8744.6 716.4 4689.6 2180.6 -0.4 4.3 4.3 5955172.0: 690639.4 11370.0 91.0 356.8! 8744.0 746.0 4719.6 2178.6 -0.4 4.3 4.3 5955201.5! 690637.4 11400.0 90.9 358.1 8743.6' 775.5' 4749.5 2177.3 -0.4 4.3 4.3 5955231.5 690636.1 .. 11430.0 90.7 359.4 8743.1 804.8 4779.5 2176.7 -0.4 4.3 4.3 5955261.5 690635.4, 11460.0 90.6 0.7 8742.8 834.0 4809.5 2176.7 -0.4 4.3 4.3 5955291.5 690635.4 11490.0 90.5 2.0 8742.5 863.0 4839.5 2177.4 -0.4 4.3 4.3 5955321.5 690636.1 11520.0 90.4 3.3 8742.2 891.9 4869.5 2178.8 -0.4 4.3 4.3 5955351.5 690637.5 11550.0 90.3 4.6 8742.1 920.6 4899.4 2180.8 -0.4 4.3 4.3 5955381.5 690639.6 4. TO 11567.5 90.2 5.3 8742.0 937.2 4916.81 2182.3 -0.4 4.3 4.3 595'5399.0 ''690641.1 .... , .... VERTICAL SECTION PLANE USED 346.82 ° OFF OF GRID - ..... MAG DEC. i ' 28.67 TO TRUE REa: -~" 61.15 , , 'I~ _ ',', .... ' , GR!,D CONVERGENCE; ........ 1.45° ..... ~ ............ '~ , ,, Page2 1/30/97 11-31S-1.XLS 1:57 AM 2-38 A DIRECTIONAL SIDETRACK PAGE NO. 1 2-38A PLAN PREPARED ON JAN. 30. 1997 Comments MD Inc. Dir SS TVD VS NI(-S) E/(-W) Build Turn Dogleg ASP Y' ASP X ft deg deg ft ltl ft ft deglJO0' degllOO'!degllO0' ft ft 1. TIP 6 DL -90 TF 10616.0 94.9 343.9 8779.8 0.0 4004.3 2396.0 0.0 0.0 0.0 5954486.5 690854.8 10620.0 94.9 343.6 8779.5 4.0 4008.1 2394.9 0.0 -6.0 6.0 5954490.5 690853.7 10650.0 94.9 341.8 8776.9 33.8 4036.7 2386.0 0.0 -6.0 6.0 5954519.0 690844.8' 10680.0 94.9 340.0! 8774.4~ 63.5 4064.9 2376.2 0.0 .... -6.0 6.0 5954547.0 690835.0! 10710.0 94.8 338.2 8771.9 93.1 4092.8 2365.5 0.0 -6.0 6.0 5954575.0 690824.4 10740.0 94.8 336.4 8769.3 122.6 4120.4 2354.0 -0.1 -6.0 6.0 5954602.5 690812.8 10770.0 94.8 334.6 8766.8 151.9 414716 2341.6 -0.1 -6.0 6.0 5954630.0 690800.4 2. DROP 6 DL TO 8763 10791.0 94..8 333.3 8765.1 172.3 4166.4 2332.4 -0.1 -6.0 ...... 6.0 5954648.5 690791.3 10800.0 94.2 333.3 8764.4 181.1 4174.4 2328.4 -6.0 0.0 6.0 5954656.5 690787.2 3. ORIENT TO TD 10821.8 92.9 333.3 8763.0 202.2 4193.8 2318.6 -6.0 0.0 6.0 5954676.0 690777.4 4,3 DE 94.3 TF " 10830.0 92.9 333.7 8762.6 210.2 4201.2 - "2315.0 '0.3 4.-3 ' ' 4.3 5954683.5 - 690773.8 '' 10860,0 92.8'335.0 8761.1. 239.4 4228,2 2302.0 -0.3 ' '74.3 4.3 59547'10.5 690760.8 .... 1'0890.0! 92.7 --336.3 "8759.6 268.8 ~ 425~ .... 2289.6 ,0,3 --'4.3 ~,i'3 ' 595473715 690748.4 - 10920.0 92.6 337.5 8758.2 298.~ 4283.1 2277.8 -0.3 4.3 4.3 5954765.~ ...... 690736.7 -" 1-0950.0 92.5 --338.8 8756.9 328.0 4310.9 2266.7 " '0.3 4.3 4.3 '5954793.0 " 690725.5 ' 10980.'0 '9-2.4 ~011 8755.6 357.7 4338.9 2256.2 -0.3 '4.3 .... 4,'3 595482i'.0 - '690715.0 11010.0 9213 .... 341.4 8754.4 387.5 4367.2 "'2246.3 -0~3 '4.--~ .......... 4.3 .... 5954649.5 690705.1 11040.0 92.2 342.7 8753.2 417.4 4395.8 2237.1 -0.4~ 4.3 4.3: 5954878.0 - 690695.9 .... 11070.0 ''921'1 "' ~t4.0' '8752.1 447.3 ' '4424.5 .... 2228.5 '~),4 '413 ' 4--.~' '' 59549061~5- 690687.'3 1i100.(~ 9210 345.3 ' 8751.0 477.3 4453.4 2220.5 -0.4" 413 4.3 5954935.5 - ' 690679.3 11130.0 91.--~ 346.6 - 8750.0 507.3 4482.5 221312 -0.4 - '4.3 4.3 5954964.5 ' 690672.1 ~'~ 60.0 91.8 '347.8 87749.1 537.2 4511.7 2206.6 '-0~4 ...... 74.3 .... 4.3 5954994.0' 690665.4 11190.0 91.7 349.1 8748.2 567.2 4541.1 2200.6 -0.4 4.3 4.3 5955023.5 690659.4 11220.'0 ~ 91.5 350.4---'8747.3' --597.1 ' '4570'.6 2195.3 .~.4 ' ~t-.3" 4.3 5955053.0 690654.1 11250.0 91.4 -3~1.7---8746.5 627.1 ' 46'00.2 ..... 2190.6 ' -0.4 4.3 4.3 5955082.5 ' 6906~-~ Page1 1/30/97 I I ,ARCO ALASKA ~NC. 2-38STOG 2-38ORGR ARCO ALASKA INC. D~ 2-,18 A ~4DETRAGK NABOR~ 2 EG GOIL UNIT t PRUDflOE BAY 8600 9000 2 KOP TIP 3 DI 4.3°1100 Tf 94.31" / Old ~ell Bore 4TD g o g g g Vertical Section Scale I inch ' 200 ft PLANE OF VERT SECTn 346.82° RELATIVE TO GRID NORTH I IIIII II IIII I I I I I I I I NORTH REt.. TO GRID True (-1.45) ~ M~iP2'/'.~) ~00 480O Old Well Bore 4500 4200 3900 and NIS Scale 1 Inch: 300 It FILE NANE: C:~ARCOALK~-38t2-38A1.DW2 DRAWN BY : BIMO HADIPUTRO DATE : JAN. 30.1997 ii ii C T Drilling Wellhead Detail Head ~~~.~~ Stuffing Box (Pack-OfO, 10,000 psi Working Pressure Methanol Injection ~ I -- 7 Riser i i Otis7"WLAQuiCkconnect -- I , , I i ~ Annular BOP (Hydril),7-1/16'' ID 5,000 psi working pressure Alignment Guide Flange_ 7-1/16", 5M Ram Type Dual ~- ~ Gate BOPE Flanged Fire Resistant Manual Valve Kelly Hose To Dual \ ChokeManifold :Cutters or Combination Cutter/Blinds Slip/Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16% 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams 0.458' (5.5") Manual Master Valve 2" Pump-In Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree Hanger RECEIVED I ~ 9-5/8"Annulus JAN 3 1 1997 I- Alask~ Oil & Ga~ Oon~. Commission I Anchoraga Shop Fuel Boilers Water Mud 60/40 I Trplx I Ext. Pump Room Pipe rack Ext. i-(/) Dowell Drilling Equipment Trailer Fire Ext,, Preferred Major Equipment Layout for CT Drilling in DS 2-38A WELL PERMIT CHECKLISToo Y PROGRAM= expD dev~redrlD servD wellbore se~ann disp para reqD 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 drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling 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 ....... REMARKS 14. Conductor string provided ................ Y 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf cng. . Y 17. CMT vol adequate to tie-in long string to surf cng . . . Y 18. CMT will cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~-Y----N~ 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~--~-~ psig~ N 27. Choke manifold complies w/~I ~-53 (Ma~ 84) ...... 28. Work will occur without operation shutdown ....... Y~ N 29. Is presence of H2S gas probable ............ Y~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ _ 31. ~ Data presented on potential overpressure zones ..... Y / N 32. Seismic analysis of shallow gas zones ......... o/ ~ ~.~ 33. Seabed condition survey (if off-shore) ........ ~ Y N 34. Contact name/phone for weekly progress reports . . . / . Y N [exploratory only] %~ GEOLOGY: ENGINEERING: COMMI SS ION: HOW/dlf- A:\FORMS\cheklist rev 01197 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 19 10:14:28 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 3 AK-MW-70141 A. WORTHINGT KARA/GOODRI C ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Date_O( 2-38L1 500292270860 ~RCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 19-AUG-97 36 liN 14E 4541 3568 61.00 .00 .00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 3834.0 7.000 10197.0 4.500 10584.0 3.690 11599.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL TRUE VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (SSTVD). 3. THE WINDOW POINT IS AT 10,584'MD, 8781'SSTVD. 4. MWD RUN 1 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. MWD RUN 2 MADE FOOTAGE FROM 10581'MD, 8783'SSTVD TO 10599'MD, 8781'SSTVD. ALL GAMMA RAY DATA FROM THIS RUN IS BEHIND CASING, AND IS NOT PRESENTED. 6. A CLEANOUT RUN WAS MADE FROM 10599'MD, 8781'SSTVD TO 10623'MD, 8779'SSTVD. NO MWD DATA WAS COLLECTED DURING THIS RUN. 7. MWD RUN 3 IS DIRECTIONAL WITH NATURAL GAMMA RAY PROBE' (NGP) UTILIZING SCINTILLATION DETECTORS. 8. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DOUG KNOCK OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY SUN DRILLING SERVICES ON 8/19/97. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11599' MD, 8719'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10594.5 11571.0 ROP 10617.5 11598.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 3 10623.0 11599.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10594.5 11598.5 11096.5 2009 10594.5 GR 31.83 575.74 64.4202 1954 10594.5 ROP 14.72 3492 89.9605 1963 10617.5 Last Reading 11598.5 11571 11598.5 First Reading For Entire File .......... 10594.5 Last Reading For Entire File ........... 11598.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Corament Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10594.5 ROP 10617.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11571.0 11598.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 14-MAY- 97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11599.0 10623.0 11599.0 91.2 97.2 TOOL NUMBER NGP 233 3.750 3.8 FLO-PRO 8.80 .0 9.0 6.0 .000 .000 .000 .000 60.9 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10594.5 11598.5 11096.5 2009 10594.5 GR 31.'83 575.74 64.4202 1954 10594.5 ROP 14.72 3492 89.9605 1963 10617.5 Last Reading 11598.5 11571 11598.5 First Reading For Entire File .......... 10594.5 Last Reading For Entire File ........... 11598.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/19 Scientific Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File
