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208-158
RECEIVED STATE OF ALASKA JUN L 9 201;1 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOd)GCr la. Well Status: ❑Oil ❑Gas 0 SPLUG 0 Other-®Abandoned 0 Suspended lb. Well Class 20AAC 25105 20AAC 25 110 0 Exploratory 0 Stratigraphic ❑ GINJ ❑WINJ 0 WAG 0 WDSPL 0 Other No. of Completions Zero - ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., Aband 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/30/2015 . 208-158 - 315-171 3. Address: 6. Date Spudded: 13. API Number P.O. Box 196612,Anchorage,Alaska 99519-6612 11/1/2008 50-029-20217-02-00 • 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/3/2008 PBU G-02B 2163' FNL, 1974' FEL, Sec. 12, T11N, R13E, UM 8. KB(ft above MSL): 71.03' 15. Field/Pool(s) Top of Productive Horizon: 1005' FNL, 1742' FWL, Sec. 07,T11N, R14E, UM GL(ft above MSL): 35.17' - Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool - 665' FNL, 2979' FWL, Sec. 07,T11N, R14E, UM 9790' 8710' 4b. Location of Well(State Base Plane Coordinates, NAD. 10.Total Depth(MD+TVD) 16. Property Designation: - Surface: x- 658243 • y- 5969486• Zone- ASP4 • 12171' 8947' - ADL 028280&028304 TPI: x- 661934 y- 5970724 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 663164 y- 5971090 Zone- ASP4 None 18. Directional Survey: ID 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 DIR/GR - 10278' 8966' - 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"x 30" Insulated Conductor_ 37' 117' 37' 117' 36" 8 cu yds Concrete - i 13-3/8" 72# N-80 37' 2696' 37' 2696' , 17-1/2" 5600 cu ft Permafrost II - 9-5/8" 47# N-80 36' 8400' 36' 7528' _ 12-1/4" 1420 cu ft Howco Lite.289 cu ft Class'G', 135 cu ft PF'C' 7" 29# NT-80S _ 8271' _ 10274' 7431' 8965' 8-1/2" 540 cu ft Class'G' 4-1/2" 12.6# L-80 10140' 10278' 8918' 8966' 6" 213 cu ft Class'G' 3-1/2"x3-3/18"x2-7/8"9 2#i 6.2#/6 16# L-80 10070' 12171' 8886' 8947' 4-1/8" 140 cu ft Class'G' 24. Open to production or injection? El Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET MD/TVD) of Top&Bottom; Perforation Size and Number): ( 4-1/2", 12.6#, L-80 10129' 9959'/8825' I 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. q Ago WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No SCAVIVIED SEP V a 2015 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? 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 250.071. None Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Only / VII-- 9lZ// S A ���/� RBDMS`c JUL = 1 2015 / �s.' JG 29. GEOLOGIC MARKERS(List all formations r 'arkers encounter 30. FORMATION TESTS • NAME .41D ND Well Tested? 0 Yes 0 No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test results. Attach separate sheets to this form,if needed,and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 1A 10292' 8970' None Zone 1A 10975' 8974' Zone 1A 11536' 8972' Zone 1A 11852' 8967' 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. J Kyle Raese,564-4629 Email: John.Raese@bp.com Printed Name: Title: Drilling Technologist Joe Lastufk Signature 564-4091 Phone Date. 024/15 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: G-02C 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9920' Set CIBP 9895' - 9900' Tubing Punch 9879' Set Cement Retainer -9737' 19 Bbls Class 'G' 9790' Set Whipstock G-02B, Well History (Pre-Rig Sidetrack) (ELINE - PLUG/PUNCHER/RETAINER - PRE CTD PREP). INITIAL = 2500/0/200. LRS LOAD/ KILL WELL W/ KCL& FRZ PROTECT (SEE LRS REPORT). RIH W/ 1ST 4-1/2" HALLIBURTON EZ DRILL CIBP &SET TOP OF PLUG @ 9920' (9921' MID ELEMENT) (PLUG SPECS = 3.66" MAX OD/2.09' OAL). LRS PERFORMED PASSING MIT-T 2000#ON 1ST PLUG. MADE TWO UNSUCCESSFUL RUN W/TBG PUNCHER (BOTH DETONATORS TESTED BAD ONCE OUT OF 4/13/2015 THE HOLE). CURRENTLY CHANGING ENTIRE TOOLSTRING AND TRY TBG PUNCH AGAIN. T/I/O= 2375/0/145 Temp. - SI Assist E-Line . MIT T PASSED to 2000 psi. ( pre CTD) Loaded tubing with 4 bbls meth and 240 bbls of !%KCL. Freeze protected tubing with 4 bbls meth and 60 bbls of Diesel. MIT T- pumped 12 bbls of dsl to reach test pressure. Tbg lost 60 psi. in the first 15 min and 14 psi. in the 2nd 15 min. for a total loss of 74 psi. in a 30 min. test. e-line to cut tbg for 4/13/2015 CMIT. E-Line cut tbg CMIT TXIA PASSED to 2000 (see mit data) , MIT T PASSED to 2000 psi. MIT T- pumped 2 bbls of diesel to reach test pressure. Tubing lost 59 psi. in the 1st 15 min. and 22 psi. in the 2nd 15 min. for a total loss of 81 psi. in a 30 min. test. Bled 2 bbls to Final WHP - 0/120/145. 4/14/2015 Tags hung, FP annulus sign hung, casing valves-OTG, E-Line on well at departure. (ELINE - PLUG/PUNCHER/RETAINER - PRE CTD PREP). RIH W/TUBING PUNCH. SHOT INTERVAL @ 9895' - 9900'. LRS PERFORM CMIT TxIA TO 2000#(PASSED). RIH W/4-1/2" HES EZ DRILL CEMENT RETAINER & SET MID ELEMENT @ 9880'. (TOP @ 9879') (PLUG SPECS = 3.66" MAX OD /2.09' OAL). LRS PERFORM MIT-T AGAINST 2ND PLUG TO 2000# (PASSED). FINAL T/I/O = 5/0/150. WELL SHUT IN ON DEPARTURE - NOTIFIED PAD OP OF WELL 4/14/2015 STATUS. CTU#6 - 1.75" CT Job Objective: Pump Cement in Annulus Pre-CTD. MIRU CTU. Perform weekly BOP Test. RU SLB pumpers. MU and RIH w/HES Stinger BHA(OAL= 10.88'). Sting into retainer at 9868'. Pressure up down backside to 450psi to confirm isolation from CT. Establish circulation down coil and up IA at 1.5bpm at 2500psi circ pressure, good communication with IA. Batch mix cement. Pump 1 bbl Fresh Water& 19 bbls 15.8ppg Unislurry Cement. After 16 bbls into the IA, shut in IA returns, drop to min rate & unsting from retainer. See whp bump to confirm retainer is isolated from IA. Begin reversing out cement 10' above retainer. Reverse circulate 50/50 meth freeze protect from 4/27/2015 2500'. RDMO. Estimted TOC in IA-8987'. T/I/.O=4/-3/150 Temp=S/I, MIT-T to 2500 PSI PASS, MIT-IA to 3000 PSI PASS (CTD prep) Pumped 8.5 bbls diesel for MIT-IA. 1st 15 min IAP lost 106 psi & 2nd 15 min IAP lost 40 psi for a total IAP loss of 146 psi in 30 min. Bled back- 5 bbls. Pumped 1.7 bbls diesel for MIT-T. 1st 15 min TBGP lost 53 & 2nd 15 min TBGP lost 22 for a total TBGP loss of 75 in 30 min. Bled back - 1.5 bls. DSO notified of well status per LRS departure. FWHP's=15/1070/157. SV,WV,SSV=C MV=O 5/1/2015 IA,OA=OTG. ***Fluid packed annulus sign already on wing**. (E-LINE WHIPSTOCK). INITIAL T/I/O =400/950/300 PSI. RIH W/4-1/2" BAKER WHIPSTOCK OAL =53' OAW=650LB MAX OD=3.625". SET TOP OF WHIPSTOCK AT 9790'. CCL TO TOW=14.08' TFO 176deg CCL STOP DEPTH=9775.92'. AT SURFACE, CONFIRM WHIPSTOCK SET. WELL SHUT IN ON DEPARTURE. DSO NOTIFIED. FINAL T/I/O = 370/950/300 PSI. 5/3/2015 ***TURNED WELL OVER TO PAD OP, LEFT SHUT IN***. DRIFT CLEAN TO 9,839' SLM W/20' x 3.70" DUMMY WHIIPSTOCK. ***WELL LEFT S/I ON 5/3/2015 DEPARTURE***. T/I/O = 0/885/150. Temp = SI. Bleed IA&OAP to 0 psi (Pre CTD). No AL. IA FL @ surface. OA FL near surface. Bled IAP to bleed tank, from 885 psi to 0 psi in 2 hours (2.9 bbls). IAP increased 1 psi in 30 min. Bled OAP from 150 psi to 0 psi in 3 hours. OAP increased increased 40 psi in 30 min. 5/18/2015 FWHPs= 0/1/40. SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 1710. T/I/0=90/0/250. Pre-CTD. Install CTD TS-04, Set 6" TWC#422, Pull 6" TWC#422. Final WHP's 5/22/2015 90/0/250. G-02B, Well History (Pre-Rig Sidetrack) T/I/O = SSV/23/132. Temp = SI. Bleed IA&OAP to 0 psi (Pre CTD). No AL, FL or wellhouse. Bled IAP from 23 psi to 0 psi in 15 min. IAP increased 10 psi in 30 min. Bled OAP from 132 psi to 0 psi in 1 hr. OAP increased 41 psi in 30 min. FWHPs= SSV/11/41. SV, WV, SSV= C. MV= O. IA, OA= 5/26/2015 OTG. NOVP. 1640. T/I/O = SSV/12/93. Temp = SI. Bleed IAP & OAP to 0 psi (Pre CTD). No AL. Well is demobed. No rig scaffolding on well. Bled OAP to BT from 93 psi to 0 psi in 1 hr(Gas). Bled IAP to BT from 12 psi to 0 psi in 1 min (Gas). Bled OAP to BT from 25 psi to 0 psi in 1 min, held open for 30 min. During monitor IAP increased 10 psi and OAP increased 25 psi. Final WHPs = SSV/10/25. SV, WV, 5/26/2015 SSV= C. MV= O. IA, OA= OTG. NOVP. 23:15. T/I/0 = SSV/18/115 Temp= SI WHPs ( Pre CTD ) Well disconnected. No well house. No flowline. IAP increased 8 psi. OAP increased 90 psi since 5/26/15. SV, WV, SSV= C. MV= O. IA, 5/28/2015 OA= OTG. 1130. North America-ALASKA-BP Page 1 Q 2 Operation Summary Report Common Well Name:G-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/28/2015 End Date: X3-016Y4-C:(4,555,765.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:NORDIC 1 Spud Date/Time.8/22/1976 12:00:00AM Rig Release Rig Contractor:NORDIC CALISTA UWI:500292021700 Active datum:G-02 A,B @71.03usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ,,. .(hr) (usft) 5/28/2015 13:30 - 14:30 ' 1.00 MOB P i PRE PREP FOR RIG MOVE 14:30 - 15:00 • 0.50 MOB P • PRE !HOLD PJSM TO MOVE RIG OFF P-10 15:00 - 16:30 1.50 MOB P 1 PRE STAGE RIG ON P PAD 1-BACK RIG OFF P-10 -DRILLER,RIG MANAGER AND NORDIC SUPERINTENDANT CONDUCT PRE-MOVE ROUTE DRIVE -MOVE SATELITE OFFICE TO G PAD 16:30 - 18:00 1.50 MOB P ! PRE !BEGIN RIG MOVE -SECURITY ON LOCATION -MOVE RIG FROM P PAD 18:00 - 00:00 6.00 MOB P PRE CONTINUE RIG MOVE -CREW CHANGE;DRILL AND TOUR PUSHER CONDUCT ROUTE DRIVE i-MOVE RIG FROM P PAD -LOTO G-30 -INITIATE G-02C WELL WORK TRANSFER - F.FORM WITH PAD OPPERATOR 5/29/2015 00:00 - 04:30 4.50 MOB P PRE !CONTINUE MOVING RIG FROM P PAD;STAGE : RIG ON PAD 04:30 - 06:00 1.50 MOB P PRE PREP PAD FOR RIG;LAY OUT HERCULITE — AND RIG MATS 06:00 - 06:30 0.50 MOB P PRE r CREW CHANGE 06:30 - 07:30 1.00 MOB P PRE PJSM TO FINISH LAYING HERCULITE AND RIG I MATS OA HAS 175 PSI,RU HOSE AND BLEED OFF. BLED OFF IN 2 MIN,MONITOR WHILE SPOTTING RIG MATS 30 MIN NO PRESSURE BUILD UP 07:30 - 07:50 i 0.33 MOB P PRE HOLD PJSM TO SPOT RIG OVER WELL 07:50 - 08:20 0.50 MOB P PRE MOVE RIG TO FRONT OF WELL 08:20 - 08:30 0.17 MOB P i PRE •RIG LINED UP,TEST ESD,MOVE RIG OVER WELL 08:30 - 09:00 0.50 RIGU P PRE RIG SPOTTED AND SET DOWN *****ACCEPT RIG AT 08:30 09:00 - 09:30 0.50 RIGU P PRE i HOLD RIG EVAC DRILL 09:30 - 09:45 0.25 RIGU P PRE HOLD PJSM TO CYCLE TREE VALVES,LTT THE MASTER&SWAB AND REMOVE THE TREE CAP 09:45 - 10:30 0.75 RIGU P PRE !CYCLE TREE VALVES LTT THE MASTER&SWAB REMOVE TREE CAP 10:30 - 14:30 4.00 RIGU P PRE NU BOPE i 14:30 - 15:30 1.00 RIGU P PRE CHANGE OUT KILL LINE CHECK VALVE !INSERT 15:30 - 16:30 1.00 BOPSUR P PRE FLUID PACK STACK AND SHELL TEST SLOW BLEED ON HIGH PT,BLEED OFF AND 'BLEED AIR OUT OF STACK SHELL TEST AGAIN Printed 6/8/2015 11:08:59AM North America-ALASKA-BP Page 2 of(,12 Operation Summary Report Common Well Name:G-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) , Start Date:5/28/2015 End Date- X3-016Y4-C:(4,555,765.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:NORDIC 1 Spud Date/Time:8/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292021700 Active datum:G-02 A,B @71.03usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) L 16:30 - 18:00 1.50 BOPSUR P PRE �TEST BOP PER BP,NORDIC AND AOGCC REQUIREMENTS • MATT HERRERA WITH THE STATE WAIVED WITNESSING OUR TEST ON 5/28/2015 AT I '06:21 AM,EMAIL ATTACHED 18:00 - 18:15 0.25 BOPSUR P PRE FUNCTION TEST BOP FROM OPPERATIONS CAB AND RIG FLOOR PANELS 18:15 - 00:00 5.75 BOPSUR P PRETEST BOP PER BP,NORDIC AND AOGCC 1 REQUIREMENTS MATT HERRERA WITH THE STATE WAIVED WITNESSING OUR TEST ON 5/28/2015 AT 1 106:21 AM,EMAIL ATTACHED LAY DOWN TEST JOINT AND CLEAR RIG FLOOR 5/30/2015 00:00 - 00:15 0.25 BOPSUR P PRE HOLD PJSM FOR CUTTING COIL,BOOTING ELINE AND SLACK MANAGEMENT 00:15 - 02:15 2.00 BOPSUR P PRE 1 ELINE SLACK MANAGEMENT i-MAKE UP NIGHT CAP,PICK UP INJECTOR AND BOOT ELINE I-STAB ON INJECTOR AND REVERSE OUT ELINE SLACK -RIG UP HYDRAULIC CUTTER AND CUT 310' ' COIL FOR SLACK MANAGEMENT 02:15 - 03:00 0.75 BOPSUR P PRE •STAB ON INJECTOR AND PRESSURE TEST INNER REEL VALVE AND PACK-OFF TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES 03:00 - 03:45 0.75 BOPSUR , P iPRE 1PREP COIL FOR BHA I-MAKE FINAL CUT WITH PIPE CUTTER AND I I GRIND DOWN COIL INSTALL DIMPLE CONNECTOR AND PULL TEST TO 40K# 03:45 - 05:00 1.25 BOPSUR P PRE PRESSURE TEST REEL HOUSE IRON -HOLD PJSM FOR HIGH PRESSURE TESTING AND INSTALL TEST PLATE • BLOW DOWN REEL IRON STANDPIPE TO SCHLUMBERGER PUMP TRUCK AND FLUID PACK LINES -PRESSURE TEST REEL HOUSE IRON FROM I I STANDPIPE TO COIL TEST PLATE TO 250 PSI I LOW/5000 PSI HIGH FOR 5 MINUTES;TEST I PLATE LEAKING ON HIGH TEST;BLEED —+ PRESSURE TO 0 PSI 05:00 - 05:15 0.25 BOPSUR ! P PRE HOLD RIG EVACUATION DRILL,EVACUATE TO 1 SECONDARY MUSTER AREA AND HOLD AAR 'WITH NIGHT CREW 05.15 - 05:45 0.50 BOPSUR P : PRE PRESSURE TEST REEL HOUSE IRON MAKE UP 1-1/2"MT CROSSOVER/NEW • TEST PLATE AND RE-TEST REEL HOUSE I IRON TO 250 PSI LOW/ 5000 PSI HIGH FOR 5 MINUTES 05.45 - 06:20 0.58 BOPSUR P PRE MAKE UP SWIZZLE STICK,STAB ON INJECTOR AND PUMP ELINE SLACK I 1 FORWARD 06:20 - 06:30 0.17 BOPSUR P PRE 1 HOLD PJSM TO HEAD UP BHI 06:30 - 07:30 1 1.00 + BOPSUR 1 P PRE PU INJECTOR,REMOVE NOZZLE AND HEAD UP 07:30 - 07:50 • 0.33 BOPSUR PPRE BHI UQC MADE UP,TEST DFCVS TO 250 LOW • :3500 HIGH GREASE CREW ON LOCATION TO CHECK 1 TREE BOLTS Printed 6/8/2015 11:08:59AM North America-ALASKA-BP Page 3 at, Operation Summary Report Common Well Name:G-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/28/2015 End Date: X3-016Y4-C:(4,555,765.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:NORDIC 1 Spud Date/Time:8/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA i UWI:500292021700 Active datum:G-02 A,B @71.03usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) •• --_L— (usft) 07:50 - 08:05 0.25 BOPSUR P 1 PRE HIGH PT SPRUNG A LEAK AT 1 OF THE CONNECTIONS,RETORQUE AND RETEST 08:05 - 08:20 0.25 I BOPSUR P PRE GOOD TEST OPN DFCV S • PRESSURE TEST CTC&UQC 108:20 - 08:45 0.42 BOPSUR P PRE GOOD PT,STAB ON AND PUMP SLACK FORWARD 08:45 - 08:55 0.17 ! BOPSUR P PRE ,OPEN WELL TO A CLOSED NO PRESSURE,FILL THE HOLE 08:55 - 09:10 0.25 BOPSUR P j PRE 1 HOLE TOOK 1.4 BBLS AND OUT RATE& 1 DENSITYARE STABLE SHUT DOWN CHARGE PUMP AND FLOW CHECK WELL MONITOR WELL WHILE HOLDING A PJSM TO 1 MU THE MILLING BHA 0910 - 09:45 0.58 DRILL P WEXIT ,GOOD NO FLOW,TURN ON CHARGE PUMP i TO MAKE SURE HOLE IS STILL FULL\ HOLE IS FULL,PU THE INJECTOR AND MOVE • ' TO THE SIDE MU WINDOW MILLING BHA 09.45 - 11:30 1.75 DRILL P WEXIT BHA MU AND INJECTOR STABBED ON,TEST TOOL,OPEN EDC AND RIH PUMPING AT 1.5 BPM TAKING ALL RETURNS OUTSIDE TO THE 1 TT THROUGH THE CHOKE FOR INITIAL ENTRY 11:30 - 12:00 0.50 DRILL P WEXIT LOG TIE IN 112:00 - 13:00 I 1.00 DRILL N MISC ' 9,780.00 WEXIT 1WHILE LOGGING THE CTS EQUIPMENT OPERATOR SAW ONE OF THE LINKS ON THE INJECTOR CHAINS WAS CRACKED AND NEEDS TO BE REPLACED I FILL OUT THE NORDIC EMRC FOR THE CTS I I REPAIR THE INJECTOR&POWER PACK WILL NEED TO BE LOTO AND PIPE/SLIPS CLOSED TO ENSURE THE PIPE IS SECURE AND WILL NOT MOVE 13:00 - 14.30 1.50 STWHIP P WEXIT REPAIR COMPLETED,BACK OUT MANUAL LOCK DOWNS,OPEN PIPE/SLIP COMBI 1 RAMS,PU AND INSPECT PIPE,PIPE LOOKS GOOD. ONLINE AT MAX RATE TO SWEEP THE WELL WITH REMAINDER OF KCL THEN SWAP TO I MUD RIH AND TAG TOWS TAG AT 9791.3,PU AND RETAG TAG SAME DEPTH 14:30 - 14.45 0.25 STWHIP P WEXIT WELLSWAPPED TO MUD,OBTAIN SPR'SAND BLEED IA FROM 972 PSI TO 500 PSI FLUID COMPRESSION BLEED OFF VOLUME TEST 2.88 BPM IN AT 2329 PSI SHUT DOWN PUMP AND ZERO OUT MM GOT BACK 0.9 BBLS THEN ZERO FLOW 14:45 - 15:00 0.25 STWHIP P WEXIT RIH TO START MILLING Printed 6/8/2015 11:08:59AM North America-ALASKA-BP Page 4 grey Operation Summary Report Common Well Name:G-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/28/2015 End Date: X3-016Y4-C:(4,555,765.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:NORDIC 1 Spud Date/Time:8/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292021700 Active datum:G-02 A,B©71.03usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:00 3.00 STWHIP P WEXIT START MILLING WINDOWAT 9791.0'FIRST `^A k MOTOR WORK I." ' FREE SPIN=2600 PSI AT 2.85 BPM C' RATE IN=2.84 BPM RATE OUT=2.86 BPM i'�OZ G MW IN=9.47 PPG MW OUT=9.47 PPG ECD =10.47 PPG ROP=<1 FPH WOB=4.39 K CIRC PSI= 2893 PSI IAP=612 PSI OAP=142 PSI PVT=107 BBLS 18:00 - 21:00 3.00 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 9793'TO 9795' FREE SPIN=2600 PSI AT 2.85 BPM RATE IN=2.76 BPM RATE OUT=2.78 BPM MW IN=9.45 PPG MW OUT=9.42 PPG ECD =10.45 PPG ROP=<1 FPH WOB=4-4.5 K CIRC PSI= 2754 PSI IAP=812 PSI OAP=125 PSI PVT=107 BBLS 21:00 - 00:00 3.00 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 9795'TO 9796.8' FREE SPIN=2600 PSI AT 2.85 BPM RATE IN=2.77 BPM RATE OUT=2.79 BPM MW IN=9.45 PPG MW OUT=9.42 PPG ECD =10.45 PPG ROP=<1 FPH WOB=4-4.5 K CIRC PSI= 2760 PSI IAP=894 PSI OAP=150 PSI PVT=108 BBLS 5/31/2015 00:00 - 01:15 1.25 STWHIP P WEXIT MILL THROUGH MID-POINT OF WINDOWAT 9797.6' 01:15 - 03:15 2.00 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 9796.8' TO 9799' FREE SPIN=2600 PSI AT 2.85 BPM RATE IN=2.75 BPM RATE OUT=2.74 BPM MW IN=9.44 PPG MW OUT=9.40 PPG ECD =10.41 PPG ROP=<1 FPH WOB=4-4.5 K CIRC PSI= 2890 PSI IAP=930 PSI OAP=155 PSI PVT=107 BBLS • 03:15 - 05:45 2.50 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 9799'TO 9801' FREE SPIN=2600 PSI AT 2.85 BPM RATE IN=2.75 BPM RATE OUT=2.74 BPM MW IN=9.44 PPG MW OUT=9.40 PPG ECD =10.41 PPG ROP=<1 FPH WOB=4-4.5 K CIRC PSI= 2920 PSI IAP=270 PSI OAP=153 PSI PVT=105 BBLS 05:45 - 06:45 1.00 STWHIP P WEXIT CIRCULATING PRESSURE DROPS TO 2700 PSI AT 9800.7';NO LOSSES MAINTAIN 1/10'PER 6 MINUTE CONTROL MILLING AND POLISH BOTTOM OF WINDOW 06:45 - 07:45 1.00 STWHIP P WEXIT 9800.7 LOOKS LIKE THE BOTTOM OF THE WINDOW WITH THE WOB DROPPING OFF AND THE WOB MILLING OFF WITH EACH 0.1' CONTINUE MILLING AT 1 FPH TO 9802.5 THEN START THE 10'OF RAT HOLE Printed 6/8/2015 11:08:59AM North America-ALASKA-BP Page 5 of...Q - Operation Summary Report Common Well Name:G-02 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/28/2015 End Date: X3-016Y4-C:(4,555,765.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:NORDIC 1 Spud DateTme:8/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA .UWI:500292021700 Active datum:G-02 A,B @71.03usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:45 - 08:30 0.75 STWHIP P WEXIT 9802.4 GETTING AN INCREASE IN MOTOR ' WORK,LOOKS LIKE THE STRING MILL IS KNAWING ON THE BOTTOM OF THE WINDOW CONTINUE 0.1'EVERY 6 MIN UNTIL IT CLEANS UP 08:30 - 10:30 2.00 STWHIP P WEXIT LOOKS LIKE WE ARE MILLING MFORMATION, 'START MILLING FORMATION BASED ON WOB • !AND PRESSURE + _ GEO CONFIRMS CHERT AND SAND AT 9803 10:30 - 12:45 2.25 STWHIP P _T WEXIT I VERY SLOW MILLING AND EASY TO STALL 12:45 - 13:00 0.25 STWHIP P , WEXIT !NOT MAKING MUCH PROGRESS PU ABOVE THE WINDOW AND GO BACK - 13:30 0.50 DOWN 13:00 -J-• STWHIP P - _! WEXIT �PU AND RIH CLEAN DOWN TO 9805.2' 13:30 - 14:00 0.50 STWHIP P WEXIT I CALL ODE AND DISCUSS SLOW MILLING i CONDITIONS WE HAVE MILLED 5'OF RAT HOLE AND HAVE STOPPED MAKING PROGRESS DISCUSS POOH TO CHECK THE MILLS AFTER i i MAKING REAM PASSES 12 OPTIONS,1)RERUN MILLS TO FINISH RAT --- HOLE 2)RIH WITH DRILLING BHA WITH 5' 14:00 - 16:00 2.00 STWHIP P WEXIT i•MAKE REAMING PASSES THEN POOH TO CHECK THE MILLS 16'00 - 16:10 0.17 iWWEXIT P DRY DRIFT DOWN THEN UP DRY DRIFTS ARE CLEAN IN BOTH DIRECTIONS,OPEN THE EDC TO POOH AT MAX RATE 16:10 - 17:35 1.42 STWHIP P WEXIT POOH 2300'OUT MM PACKING OFF,BLOW DOWN PRODUCED A LOT OF METAL HOLD PJSM TO PULL THE BHA 17:35 - 18:00 0.42 STWHIP P 1 WEXIT FLOW CHECK WELL i 18:00 - 18:20 0.33 STWHIP P WEXIT GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR AND PULL THE BHA TO CHECK THE MILLS 18:20 - 19:00 • 0.87 STWHIP N WAIT 9,805.70 WEXIT WINDOW MILL HAS SEVERE TAPPERED WEAR,THE STRING MILL GAUGED 3.79 GO • 3.78 NO GO;DISCUSS PLAN FORWARD WITH ODE 19:00 19:30 0.50 DRILL P PROD1 HANDLE BHA -HOLD PJSM FOR HANDLING BHA -LAY DOWN MILL ASSEMBLY(MOTOR) i-PICK UP BUILD BHA WITH 2-7/8"XLS MOTOR 'WITH 2.89 AKO AND 4.25"HELIOS C3 BIT 19:30 - 22:15 2.75 DRILL P PROD1 RIH WITH BUILD BHA -STAB ON INJECTOR,PRESSURE TEST QTS TO 250 PSI LOW/3500 PSI HIGH,TURN ON BHI,OPEN EDC AND RIH -IN/OUT RATE=3/3.5 BPM -IN/OUT DENSITY=9.47/9.45 PPG LOG TIE-IN(+8'CORRECTION),CLOSE EDC AND RUN TO BOTTOM;TAG AT 9805',PICK UP TO BREAKOVER AND STAGE UP PUMPS Printed 6/8/2015 11:08:59AM TRS 6"CNV G- 2 B SAMNOTES:P'ss M XADOGLBCa:38.7-@ 10452' 4-1/2" +W�l_I EAD 13 5/8"McEVOY ACTUATOR BAKER C OKB.ELEV, 61.6' BF.ELEV= 34.97' 2171` 4-1/2"SSSV I-ES WO LAND NP,D=3.813" KOP= 3513' I C Max Angle= 97°@ 12171' 9-5/8"FO Datum MD= 10045' 2180' — Datum TVD: 8800'SS 2683' —9-5/8"DV FKR 13-3/8"CSG,72#,N-80 BUTT,D=12.347" H 2686' ' GAS LFT MANDRELS ST MD TVD DEV TY PE VLV LATCH PDRT GATE I '••1 f 2 4223 4178 28 CAMOO DMY RM 0 03117/15 1 8228 7399 42 CAMCO DMY RM 0 02103/13 TOP OF 7"UR —i 8261' -k1 9-5/8"CSG,47#,N-80 BUTT,D=8.681" —8400 8261' —19-5/8"X 7"BKR LTP w/7.5"TEBK,D=7.5" � . 8275' —I9-5/8"X 7"BKR LNR HGR,D=6.317 t. i.i .: aMi " %moi. � Z - SDETRACK WINDOW(G-02A) 8400'-8450' ;Minimum Z:�t���;�� � 8987 — ESTIMATED TOP OF CMT(oa/27n5 ) 33/16" X 2-7/8LNR XO ... . ea... * G 9879' H4-1/2"HES EZ DRILL CMT RETAINER(04/04/15) ■itiet `.. 9920' ELM --14-1/2"FES EX DRILL CEP(04/13/15) 4-1/7 BKR XL MONDBORE WHIPSTOCK (05/03/15) --I 9790' , TBG PI.YVCHES(04/14/15) — 9890'-9895' i, 9946'— 9 ' �`1 1t2"FES X NP(9-Cly,ID=3.813" !&" Ci ` 9957' —j7"X 4-1/2"BKR S-3 PCR,D=3.875" • —i 9980' 4 1/2'FES X NIP(9-CR),D=3.813" 9991' 4-12"FES XN MP(9-C14), 45 HY D KB LTP w/4"GS PROFLE D=2.380" —1 10070• L®TO 3.80"(10/25/08) TOP OF 3-1/7 x 3-3/16'x 2-7/8"LNR --1 10089' 10089' —3.70'BTT DEPLOY SLV 3-12"LNR,9.2#,L-80 STL, .0087 bpf,D=2.992" —1 10108' J w/4"GS PROFILE,D=3.00" 4-12"TGB,12.6#,L-80 NSCT, —1 10128' 10108' H3-12"X 3-3/16"XO,D=2.676" .0152 bpf,113=3.953" }' '3 f 10128' —4-1/2"WLEG,ID=3.95" TOP OF 4-12"LNR H 10131' 4 10130' --I ELMD TT LOGGED 02/01/96 7"LNR,29#,NT-80S NSC C,.0371 bpf,D=6.184' H 10265' r w 10131' H5.75"BKR TEBACK SLV,D=5.25' 4-12'WFD HOLLOW WHIPSTOCK H 10278' •. w/RA TAG @ 10281' •: 10138'J-17"X 5"BKR HPLPO PKR,D=4.50" 4-12"LNR, 12.6#,L-80,.0152 bpf,D=3.953" —{ —10278 V" : , 10144' T X 5"BKR HY FLO HGR D=4.3T . 10149' —15"X 4-1/2"XO,D=3.95" P�FORATION SUMMARY J FIEF LOG:BKR HUG—ESI/MD/GR/ROP 11/03/08 * s., ANGLE AT TOP FEF:95°@ 10390' MILLOUT WINDOW(G-0213) 10278'- 10284' Note:Refer to Reduction DB for historical perf data . •. SIZE SPF INTERVAL OPP#SOZ SHOT SIV 2" 6 10390-10440 C 11/05/08 . 1111\-.... 11110713' —3-3/16'X 2-7/8'XO,D=2.347" 2" 6 10480-10530 C 11/05/08 4. 2" 6 10730-10770 C 11/05/08 ' 10945' —12-78P BKR CSP(09/09/13) 2' 6 10810-10920 C 11/05/08 - 11. 2" 6 11000-11070 C 11/05/08 444.14444 2" 6 11120-11180 C 11/05/08 Att..., ' Att...,� 2" 6 11200-11130 C 11/05/08BT 12132' H P ) 3-3/16"LINK6.2#,L-80 TO, — 10713' .:^ 'C' 2" 6 11430-11510 C 11/05/08 2" 6 11530-11680 C 11/05/08 0076 bpf,D=2.80" 2' 6 11730-11900 C 11/05/08 2-7/8"LW,6.16#,L-80 STL, —1 12171' AceNs#41,#' 2" 6 11970-12020 C 11/05/08 .0058 bpf,D=2.441" q DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/17/76 RWN 36 IMTIAL COMPLETION 03/17/15 JTMIPJC DGLV STA#2 WELL: G-028 05/29/95 D-14 SIDETRACK COMPLETION 03/26/15 JNU PJC TI-ENG SPECS CORRECTION PERMIT No:'208158 11/06/08 NORDIC 1 CTD SIDETRACK(G-028) 04/13/15 CJS/PJC SET EZ DRILL CEP API No: 50-029-20217-02 02/20/15 JNUJMD OKB/BF CORRECTION 04/14/15 CJS/PJC TBG PUNCHY EZ DRLL CMT RETNR '; SEC 12,T11N,R13E,2163'FNL& 1975'FEL 02/20/15 JNUJMD OKB/BF CORRECTION 0427/15 TA/PJC EST TOP OF CEMENT 03/16/15 PJC CORRH)TIONS PER TALLIES 05/03/15 BF/PJC SET MONOBORE WHIPSTOCK i BP Exploration(Alaska) �• (ow ��I�j . s, THE STATE Alaska Oil and Gas s���'i� ofALASKA Conservation Commission s#t�__ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALA51°' Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen Engineering Team Leader ���( 6r Q� BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-02B Sundry Number: 315-171 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, LU/iA,f Cathy P. oerster Chair 1,444- DATED this Z- day of April, 2015 Encl. STATE OF ALASKA RECEIVED ALAbr.A OIL AND GAS CONSERVATION COMMioSION MAR 2 6 2015 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 A,r~v-t 1. Type of Request: AOCCC ❑Abandon • ®Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 208-158 • 3. Address: 6. API Number: e,Alaska 99519-6612 ®Development ❑ Service P.O. Box 196612,Anchorage, 50-029-20217-02-00 ' 7. If perforating. 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU G-02B . Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10.Field/Pool(s): ADL 028280&028304 Prudhoe Bay Field/Prudhoe Bay Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured). 12171' • 8947' . 12132' 8952' 10945' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"x 30" 110' 110' Surface 2684' 13-3/8" 2684' 2684' 4930 2670 Intermediate 9311' 9-5/8" 9311' 8317' 6870 4760 Production Liner 2004' 7" 8261'- 10265' 7423'-8963" 8160 7020 Liner 1594' 4-1/2" 10131'- 10278' 8914'-8966' 8430 7500 Liner 210' 3-1/2"x 3-3/16"x 2-7/8" 10070'-12171' 8886'-8947' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10390'- 12020' 8973'-8960' 4-1/2" 12.6# L-80 10128' Packers and SSSV Type• 7"x 4-1/2"Baker S-3 Packer Packers and SSSV 9957/8824' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: I:3 Description Summary of Proposal ® BOP Sketch • 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation' April 10,2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended . 17. I hereby certify that the foreg o. is true .rrect to the best of my knowledge. Contact: J.Kyle Raese,564-4629 Printed Name: John ulle �' Title: Engineering Team Leader Email: John.Raese@bp.com Signature: Adip/ 4111' Phone: 564-4711 Date: 7/28/t'r- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: k 5•-k7 ❑Plug Integrity (g BOP Test ❑Mechanical Integrity Test 0 Location Clearance Other: 04p f-c_5' 7L fo 3 5CJ v (25 i . J-,1v?v/ar prrr«fry 7I-7-5 f to 251- /25 ' ) 4lfrr1'7a ¢t p1v9 pfatc�v-1.3rvr-i Gtppro✓e- Cr pr'' ZD ASIC 2 �, 11Z (1"Spacing Exception Required? ❑Yes E 'No Subsequent Form Required: IC — 4 C 7- APPROVED BY Approved By: ia �� COMMISSIONER THE COMMISSION Date: "Z"/5 Form 10-403 Revised 10/ 012 r• IacttkrfisAaItIfor 12 months fr m the date of approval / 4 1-2--'S Submit In Duplicate vn 4t/i /15 �^ RBDM APR - 6 213157 Pet4- - - 3 f, • To: Alaska Oil &Gas Conservation Commission From: Kyle Raese 0 bFi CTD Engineer Date: March 25, 2015 Re: G-02B Sundry Approval Sundry approval is requested to plug the G-02B liner perforations as part of the drilling and completion of the proposed G-02C CTD sidetrack. History and current status: G-02 was initially drilled in 1977. G-02A was sidetracked in May 1995 as a Zone 1N1 B horizontal. HOT was not encountered. The well went to high GOR in 2003 and a Borax/PPROF showed a channel connecting the perfs to gas. A channel squeeze was discussed but was found to have little IOR, and a CTD sidetrack was planned. G-02B was drilled in November 2008 as a horizontal Z1A/1 B producer. Within a few months, the gas climbed up and the well was cycled. It currently acts as a swing well with 41% 12-month on- time. Due to the low remaining value of the well, it was released for sidetrack. Proposed plan: G-02C will exit from well G-02B by the Nordic 1 Coiled Tubing Drilling rig on or around May 10. 2015. The G-02C sidetrack will perform a dual-string exit through the existing 4-1/2"tubing and 7" liner. Kick-off will occur in Zone 2C and target Zone 1A/2A reserves. The proposed sidetrack is a 3,000' horizontal Ivishak Zone 1A/2A producer which will access targets east of G-Pad. The lateral will be completed with a 3-1/2" x 3-1/4"x 2-7/8" L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing G-02B perforations via the G-02C liner cement job or liner top packer set post-rig (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. Cc"Cvf. f415 t4 // /Oro o%c s 0`'/74 q' 6OR crg W 4,' a is 4 eqr� t�-u 74( pcq/ o vt/,.c qac/ f*°"5 //Hie 1 f- gist tiel d•r 6'044 (>4. ,O/of 9 1.//, 7415 11,91/ )4>r Ad':ll Shop/c' 9/4)w for /frrd..e c /eco vel ii'o-� 7i4,y 11oPriOi1 dA roe `Oz/. , Pre-Rig Work(scheduled to begin April 10, 2015) 1. E Set CIBP. Punch 4-1/2" tubing. Set cement retainer. 2. F A/EL: Kill & load well. MIT-T. CMIT-TxIA. MIT-T. 3. C Cement up 4-1/2" x 7" annulus. 4. F MIT-IA to ensure annulus integrity. 5. S Drift dummy whipstock. 6. E Set whipstock. 7. V Pre-CTD tree work. Rig Work(scheduled to be.in Ma 10, 2015 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,405 psi). 2. Pull TWC and kill well (if necessary). 3. Mill 3.80"window and 10'of rathole. 4. Drill build: 4.25" OH, -550' (30 deg DLS planned). 5. Drill lateral: 4.25" OH, -2475' (12 deg DLS planned). 6. Run 3-1/2" x 3-1/4" x 2-7/8" L-80 liner leaving TOL at -9,740' MD. 7. Pump primary cement job: 35 bbls, 15.8 ppg, TOC at-9,900' MD.* 8. Liner cleanout and RPM/GR/CCL log. 9. Perform liner lap/injectivity test. 10. Perforate -1000' liner based on lo• inter.retation. 11. Freeze protect well to 2,500'TVDss. 12. Set TWC; RDMO. Post-Rig Work 1. V Pull TWC. 2. S Set LTP*(if needed) and GLVs (if needed). 3. T Test separator, if required. *Approved alternate plug placement per 20 AAC 25.112(i) Kyle Raese CTD Engineer 564-4629 CC: Well File Joe Lastufka Y NOTES: WELL ANGL TREE= 6"CM/ G-02B S ,-1/2"CHROME O E NIPPLES E W 'MAX DOGLEG: 8-LHERD 13-5/$"McEVOY .ACTUATOR BAKER C 38.7'010452' OKB.ELEV 61.6' BF.ELEV= 34.97' 2171' H4-1/2"SSSV HES IVO LAND NP,D=3.813" KOP= 3513' Max Angle= 97`@ 12171 Datum ND= 10045' r 2180' -9-5/8"FO 1 tumTVD 8800'SS �— 2683' �9-5/8"DN PKR 13-3/8"CSG,72#,N-80 BUTT,13=12.347" H 2686' 1 GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH FORT DATE LI 2 4223 4178 28 CAA/100 DMY RM 0 03/17/15 1 8228 7399 42 CAMCO DMY RM 0 02/03/13 TOP OF 7"LM -I 8261' -ki i 8261' -19-5/8"X 7"BKR LTP w/7.5"TRK,ID=7.5' 9-5/8"CSG,47#,N-80 BUTT,D=8.681' - --8400 8275' -19-5/8"X 7"BKR LNR HGR,D=6.312' ��.i :: :���/ SDETRACK WINDOW(G-02A) 8400'-8450' :..moi.....i.i •..--..-.. -.- Minimum .-.. - 9946' -14-1/2"HES X NP(9-CR),D=3.813" Minimum ID =2.347" ae 10713' 3-3/16" X 2-7/8" LNR XO E.--, 9957' 7"X 4-1/2"BKR S-3 PKR D=3.875" 9980' -14-1/2"HES X NP(9-CR),13=3.813" I 9991' 14-1/2'HES XN NP(9-CR), MLLED TO 3.80"(10/25/08) 45 HY D KB LTP w/4"GS PROFILE D=2.380" H 10070' TOP OF 3-1/2"x 3-3/16'x 2-7/8"LNR --{ 10089' 10089' H3.70"BTT DEROY SLV 3-1/TW ,9.2#,L-80 STL, .0087 bpf,D=2.992" 10108' li , w/4"GS PROFLE,D=3.00" 4-1/2"TGB, 12.6#,L-80 NSCT, - 10128' 10108' -13-1/2"X 3-3/16"XO,D=2.676' .0152 bpf,ID=3.953" ' `,6, 10128' H4-1/7w ,13=3.95' TOP OF 4-1/2'LF.R -1 10131' v • y.' 1 10130--I ELMD TT LOGGED 02/01/96 7'LNR,29#,NT-80S NSCC,.0371 bpf,D=6.184" I- 10265' -'~ '~! *' ' 10131' -5.75"BKR TEBACK SLV,D=5.25' 4-1/2'WFD HOLLOWW-IPSTOCK -I 10278' •' '+ w/RA TAG @ 10281' 10138' H7'X 5"BKR I-PLPO PKR,D=4.50" 4-1/2'LNR,12.6#,L-80,.0152 bpf,D=3.953" -{ -10278 .� 10144' HT' *' w, 10149'10149' --15'X 4-1/2"XO,D=3.95" .v •4.. PERFORATION SLL v4ARY .• .F REF LOG:BKR HUG-FS WAD/GR/ROP 11/03/08 .4 .* * ! MILLOUT WINDOW(G-02B) 10278'- 10284' ANGLE AT TOP FERE:95"@ 10390' '+ *. Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN'SOZ SHOT SQZ .1 ... 2" 6 10390-10440 0 11/05/08 r , ,•-.. *. 10713' -13-3/16'X 2-7/8"XO,D=2.347" 2' 6 10480-10530 0 11/05/08 2" 6 10730-10770 0 11/05/08 ! `7r, 10946' _-�2-78/"BKR CEP(09/09/13) 2" 6 10810-10920 0 11/05/08 •A'A'1'A'A�' •~'. 44 2" 6 11000-11070 C 11/05/08 1Att41 ' 2" 6 11120-11180 C 11/05/08 •vivAvA A A '' �' 2" 6 11200-11130 C 11/05/08 3-3/16"LNR,6.2#,L-80 TC1, - 10713' +' 12132' H PBTD 2" 6 11430-11510 C 11/05/08 .0076 bpf,ID=2.80" • , .41110,01,4 ' 2" 6 11530 11680 C 11/05/08 44411, 2-7/8"LM,6.16#,L-80 STL, 2171' * . 2" 6 11730-11900 C 11/05/08 .0058 bpf,D=2.441" 2" 6 11970-12020 C 11/05/08 DATE REV BY COMMENTS DATE REV BY COI/ANTS PRUDHOE BAY UMT 09/17/76 RWN 36 INITIAL COMPLETION 02/20/15 JMJJMD OKB/BF CORRECTION WEJ-L: G-02B 05/29/95 D-14 SIDETRACK COMPLETION 03/16/15 PJC CORREDTDNS PER TALLES PERMIT Nb:'208158 11/06/08 NORDIC 1 CTD SIDETRACK(G-02B) 03/17/15 JTMPJC DGLV STA#2 AR No: 50-029-20217-02 09/10/13 TTR/PJC SET CIBP)09/09/13) 03/26/15 JNU PJC TUBING SPECS CORRECTION SEC 12,T11 N,R13E,2163'FNL&1975'FEL 09/10/13 TTR/PJC PEFF CORRECTION(11/05/08) 02/20/15 JNUJMD OKB/BF CORRECTION BP Exploration(Alaska) f NOTES: L TREE 6"GRN G_0 2 4/1,... CHROME PPL ESNGLMAZ DOGLEG: #� rVUaLHEAD 13-518"McEVOY " ACTUATOR BAKER PROPOSED 0 •�"" IOKB.ELEV 61.6' I BF.REV= 34.9T ___.-------t.92171' i4-1/2"SSSV HES FDCO LAND NE' D=3 813" I KOP= 3513' _"CONDUCTOR., - ? j 00 - - Max Angle= 97°@ 12171' _#, , Datum MD= 10045' D= ^ — I 2180' -19-5/8"FO i Datum TVD, 8800'SS P =..—i• 2683'- 1-9-5/8"DV PKR N-3-3/8"CSG,72#,N-80 BUTT,ID=12.347" H 2686' ' GAS LFT MANDRELS ST MD TVD DEV TYFE VLV LATCH PORT DATE LI - 2 4223 4178 28 CA WO DMY RM 0 03/17/15 4 1 8228 7399 42 CAMCO DMY RM 0 02/03/13 TOP OF 7"LNR— 8261' - .' -- 8261' --�9-5/8"X 7"BKR LIP w!7.5"TEBK,ID=7.5" Minimum ID = @ 8275' -19-5/8'X 7"BKR LNR HGR,D=6.312" 3-3/16" X 2-7/8" LNR XO SIDETRACK WINDOW(G-02A) 8400'-8450' 9-518"CSG,47#,N-80 BUTT,D=8.681" H -8400 • F STIAATED TOP OF CEMENT (XX/XX/15) -{ -9000 4 `4 w v 4 v 76: r TOP OF LNR/CEMENTED H -9740 + i 7 -9740-1-13.70"BKR DEPLOY SLV,13=3.00" r I7 v 3-1/2"LNR #,L-80 STL, -0087 bpf,ID=2.992" p -1 : ~ -9790 H3-1/2"X 3-3/16"XO,D=2.676' lc 4-1/2" WHPSTOCK (XX/XX/15) -1 -9790 r M w/RA TAG @ SIDETRACK WINDOW(G-02C) -9790 _ ' 4-1/2"LNR,12.6#,N T-80 NSCT, H ~9790 ► .0152 bpf,ID=3.953" 7"LNR,29#,NT-80S NSCC,.0371 bpf,D=6.184" H -9790 ` 0,.•,._ • CEMENT RETAINER (XX/XX/15) -1 ^-9880 9S TUBING PUN ]CH (XX/XX/15) -1 -9900 , L � TUBING * A L-10240 -13-3/16"X 2-7/8" XO,D=2 377" 4--1/2"BKR CIPS(XX/XX/15) --1 -9920 _ PERFORATION SUMMARY H2-7/8"RA PP TAG REF LOG: ON XX/XX/153-1/4"LNR,6.6#,L-80 TCI -10240 1 ANGLE AT TOP PERF:_°@ * p079 bpf,D=2.85" Note: Refer to Production CO for historical pert data SIZE SPF NTR'VAL OPNSQZ SHOT SQZ • [_ - PBTD_j S 154 2-7/8"LNR_#,L-80 STL, -f --12815 ___ 0058 bpf,D=2.441" MATE REV BY COMvEN[S DATE REV BY I COMMBNTS PRUDHOE BAY UNIT 09/17/76 RWN 36 INITIAL COMPLETION MIL: G-02C 05/29/95 D-14 SIDETRACK COMPLETION PERMT No: 11/06/08 NORDIC 1 CTD SIDETRACK(G-02B) AR No: 50-029-20217-03 XX/XXI15 CID SIDETRACK(G-02C) SEC 12,T11N,R13E,2163'FNL&1975'FR 03/19/15 PJC BUILD PROPOSAL BP Exploration(Alaska) r� I II I I1': IlaA NI • Na m sN : _y• un N. r I r A I =� In Cn I �. ~ " D I 5 >.I W 73 31 i O A 0 1 O 2 I 1 ' m 17.4. 6i g 61 E a 31 R m 73 Q � N N — I I E I o li • H 0 ..I 0 Will 0 2g r - I. I ji im D III III I �.,^ S I a O •AI a a* I Z III III 3 I V I. IIn y III v III -- i' i ' 0 Z N 11 - 11 = I III nil I 11 r mi I : II 1.11 is W o I I s ■J > I o 6 n v A a O rill s ; I I E E dSS m S q 4 ci ir_ I N. . 9 � ^s s S d I I 1 I 1 s iii E. s 1. 141 n r A -1 W 01 , N A ''III g r; m S VIII T - Q fi i I... 141 ®: Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work)the initial reviewer will cross out that erroneous entry and initial it on V both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states"Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code,she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • Ima a Pro'ect Well History File Cove~age g J XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ ~~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o,.o.,b~, iiuiiiiiii DIGI L DATA iskettes, No. ~~ ^ Other, No/Type: BY: Maria Date: 3/ _-- ~ Project Proofing BY: Maria Date: ~ ~ Scanning Preparation ~_ x 30 = QY: _ Maria Date: Production Scanning iu ~ R.,~~~e~ea iuiioiuiiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ P iiiimiiim imi m p + ~_ =TOTAL PAGES___L (Count does not include cover she t) +/~ /s/ r ~ Stage 1 Page Count from Scanned File: ~ (Count does include co r sheet) n Matches Number in Scannin Pre aration: YES NO Page Cou t 9 p BY: Maria Date: 3 g /D /sl ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s/ Scanning is complete at this point unless rescanning is required. II I II'lll III II I I III ReScanned III IIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIII III IIII III 10/6/2005 Well History File Cover Page.doc RECEIVED aKA OIL AND GAS CONSERVATION COMIPION REPORT OF SUNDRY WELL OPERATIONS OCT 0 8 2013 1.Operations Abandon U Repair Well U Plug Perforations U, Perforate U Other U AOGGer Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver 0 Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 208-158-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20217-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028304t Aol..oci 2,11C) • Pau G-02B - 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PPROF;CNL PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 12171 feet Plugs measured 10945 feet true vertical 8947.93 feet Junk measured None feet Effective Depth measured 10945 feet Packer measured See Attachment feet true vertical 8974.54 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 39-119 39-119 0 0 Surface 2658 13-3/8"72#N-80 38-2696 38-2695.9 4930 2670 Intermediate None None None None None None Production 8363 9-5/8"47#N-80 37-8400 37-7528.94 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED y i`E' U I Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-10128 32-8913.68 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 494 34058 7 0 1248 Subsequent to operation: 862 26273 26 0 306 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q . Gas ❑ WDSPIJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 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 Garry Catron Email Garry•Catron0BP.Com Printed Name Garry Catron Title PDC PE Signature 11 a.,4,17 6.4.7 --— Phone 564-4424 Date 10/8/2013 A, If _ i 40. /%3 RBr s OCT 11 Form 10-404 Revised 10/2012 Submit Original Only • 0 Packers and SSV's Attachment ADL0028304 SW Name Type MD TVD Depscription G-02B PACKER 8261 7349.92 7" Liner Top Packer G-02B PACKER 9957 8750.79 4-1/2" Baker S-3 Hydro Set Packer G-02B PACKER 10138 8843.97 4-1/2" Baker HPLPO Packer Casing / Tubing Attachment ADL0028304 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"x 30" 39 - 119 39 - 119 LINER 2004 7"29# NT8OS 8261 - 10265 7423.92 - 8963.4 8160 7020 LINER 38 3-1/2" 9.2#L-80 10070 - 10108 8886.77 - 8904.81 10160 10530 LINER 147 4-1/2" 12.6# L-80 10131 - 10278 8914.98 - 8967.03 8430 7500 LINER 1458 2-7/8"6.16# L-80 10713 - 12171 8970.38 - 8947.93 13450 13890 PRODUCTION 8363 9-5/8"47#N-80 37 - 8400 37 - 7528.94 6870 4760 SURFACE 2658 13-3/8" 72#N-80 38 - 2696 38 - 2695.9 4930 2670 • TUBING 10096 4-1/2" 12.6#L-80 32 - 10128 32 - 8913.68 8430 7500 III 1 Perforation Attachment ADL0028304 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top ND Depth Base G-02B 11/5/2008 PER 10390 10440 8973.92 8970.79 G-02B 11/5/2008 PER 10480 10530 8970.65 8972.05 G-02B 11/5/2008 PER 10730 10770 8970.56 8971.49 G-02B 11/5/2008 PER 10810 10920 8972.24 8974.42 G-02B 9/9/2013 BPS 11000 11070 8974.65 8976.63 G-02B 9/9/2013 BPS 11120 11180 8977.34 8978.17 G-02B 9/9/2013 BPS 11200 11300 8979.06 8979.65 G-02B 9/9/2013 BPS 11430 11510 8976.79 8973.92 • G-02B 9/9/2013 BPS 11530 11680 8973.21 8971.18 G-02B 9/9/2013 BPS 11730 11900 8971.22 8966.43 G-02B 9/9/2013 BPS 11970 12020 8963.49 8960.4 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 411 1 1 • Daily Report of Well Operations ADL0028304 SUMMARY CTU#6- 1.75" T Job Scope: PPROF/MCNL w/ Borax and contingent CIBP Standby for Wells Support to complete RU. 9/6/2013 ***Job continued on 9/7/13 WSR*** CTU#6- 1.75" CT Job Scope: PPROF/MCNL w/ Borax and contingent CIBP Standby for Wells Support to complete RU. Standing by for well to get POP'd. 9/7/2013 ***Job continued on 9/8/13 WSR*** CTU#6 - 1.75" CT Job Scope: PPROF/MCNL w/ Borax and contingent CIBP Standing by for well to unload., Well flowing on its own, In test thru PCC @ 04:00, PJSM, Start RU of CT. MU CTS 2.25" D/SJN Noz/Drift assembly, OAL 7.705'. PCC reported 10:00 am, 104 FWHT, 3100 BOPD, 24 MMSFC gas, 1340 FWHP. Stab on Function BOP's, PT PCE/WH, RIH w/2.25" drift assembly. Lock up @ 11,200', PU clean to 10600', PCC pinch in choke from 64 to 49 setting, RIH. Stopping same spot 11201'. PU clean, wing in well. RIH clean to tag depth, 12109', 12099'wgt back depth, PU 40' flag pipe 12059'. POOH. 9/8/2013 ***Job continued on 9/9/13 WSR*** CTU#6- 1.75" CT***Cont'd from 9-8-13 WSR*** Job Scope: PPROF/MCNL w/ Borax and contingent CIBP Log 60fpm up pass from 10300'-12087' and 80fpm up pass from 10000'-12087'. Perform stop counts (see log for details). POOH. Good data from PPROF. MU & RIH w/SLB MCNL logging string. Make up/down pass & repeat pass @ 60 FPM w/KCL from flag to 10,000'. Make 2x60fpm Borax up passes from Flag to 10,000'. POOH. MU BKR 2-7/8" CIBP & RIH. Set CIBP ME at 10945'. POOH. 9/9/2013 ***Job in Progress*** CTU#6 - 1.75" CT***Cont'd from 9-9-13 WSR*** Job Scope: PPROF/MCNL w/ Borax and contingent CIBP POOH after setting BKR CIBP. FP well w/30bbls of 50/50 methanol. RDMO. 9/10/2013 ***Job complete*** TFiEE= 6"OW S NOTES: WELL ANGLE>70°@ 10254'. WELLHEAD= 3-5/8"5MMcEVOY -O 2 B .::4-1/2°CHROME NIPPLES*** ACTUATOR= BAKER KB.EE/= 74.0' BE ELF/= 35.17' ) I 1 2171' —14-1/2"SSSV HE5 HXO LAND NP,D=3.813' I KOP= 3513' Max Angle= 97°@12171' 1 Datum MD= 10045' _ _ { 2683' —I9 518"DV PKR I Datum TVD= 8800'SS 113-3/8"CSG,72#,L-80,113=12.34r H 2684' I , ■ ST MD TVD DEV GAS LFT TYPE VLV LATCH PORT DATE 2 4223 4178 28 CAMCO DOME RM 16 04/18/13 I I DM 1 8228 7399 42 CAMCO ( 144 0 _02/03/13 TOP OF 7'LNR 8261' 1•, Minimum ID =2.37" @ 10713' / 3-3116" X 2-7/$" XQ 00,1s 9946'J--I4-1/2'HES X NP(9-Cli),D=3.813' I 40001.0 0, ,0/.0%■ 995T —17"X 4-1/2"BKR S-3 PKR,D=3.875" I 1 9-5/8"CSG,47#,L-80,D=8.681" 9311' / // // // i t/ /� 9980' —4-1/2"HES X NP(8-CR),D=3.813" I /� i :/ i e !�//j//0,0 9991' 4-1/2"HES XN PIP(9-CR), !//•/////, !00,°00/' MLLB)D=3.80"(10/25/08) .0 10070' —45 HY D KB LTP w/4"GS PROFLE D=2.380" 0 0I I 10089' I—3.70"BTT DEPLOYMENT SLV w/4" V ■P GS PRDFLE ID=3.00" • 3-1/2"LNR,9.2#,L-80 STL 10108' .4 I I '���1 14 I 10108' I-13-112"X 3-3116"X0,113=2.676" I .0087 bpf,D=2.992" `V II 10128' I-�4-1/2"VVLEG.D=3.95" TOP OF 4-1/7'LNR —1 10128' I 9 V ►�4+7 10130` —I H.HD TT LOGGED 02/01/96 1 7"LNR 29#,NT 80.5,.0371 bpf,ID=6.184' H 10265' /41 11 10131' I—T X 4-1/2"BKR HPLPO PKR D=3.875" I4-1/2"WFD HOLLOW WF#PSTOCK H 10278' �4� �4� w BKR C2 TRACK SLV,D=4.5" 4 • RA TAG —I 10281' .4� �• 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.953" H 11725' 0 4 1/ 141 144 14 11 PERFORATION SUMMARY .4/ 1•4 I REF LOG:BKR HUGHES M ACOGR/ROP 11/03/08 �'1 X44 VViNDOW(G 02S) 10278'-10284' 1 ANGLE AT TOP PE2F:95°0 10390' ' 4I4N•* Note:Refer to Production DB for historical pert data N 4`1 SIZE SPF MBtVAL YSQZ SHOT SOZ ``�, I 10713' I--1332"16"X 2-7/8"XO,D=2.347" I ■ 2 6 10390-10440 0 11/05/08 11111 ■ / 10846' H2-781"BKR CEP(09/09/13) 2 6 10480-10530 0 11/05/08 2 6 10730-10770 0 11/05/08 ►114• 2 6 10810-10920 0 11/05/08 14441414141 '' , 2 6 11000-11070 C 11/05/08 2 6 11120-11180 C 11/05/08 3-3116"LNR,6.2#,L-80 TO, -1 10713' I ,, 2 6 11200-11130 C 11/05/08 .0076 bpf,El=2.80" 2 6 11430-11510 C 11/05/08 4.444 2 6 11530-11680 C 11/05/08 P610 12132' 4,4*4 2 6 11730-11900 C 11/05/08 2 6 11970-12020 C 11/05/08 I2-718"LW,6.16#,L-80 STL,.0058 bpf,D=2.441' H 12171' DATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/05/76 INITIAL COMPLETION 02/25/13 MW/JMD TREE GO(02117/13) WELL: G-02B 05129/95 SIDETRACK COMPLETION 04/29/13 WS/PJC GLV C/O(04/18/13) PERMT No: 208158 10/26/08 RLM/TLH XN NP MLLE) 09/10/13 TTR/PJC SET COP)09/09/13) API No: 50-029-20217-02-00 11/06/08 NORDIC 1 CTD SIDETRACK(G-02B) 09/10/13 TTR/PJC PERF CORRECTION(11/05/08) SEC 12,T11 N,R13E,2163'FM_&1974'FEL 01/13/10 RPIJMD DRLG DRAFT CORRECTIONS 02/07/13 COI/PJC GLV C/O(02/03/13) BP Exploration(Alaska) • • bp BP Exploration (Alaska) inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg VOINEDAUG 03 ZOrZ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue a Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB G -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 ---7 G-02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 _ 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -198 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -238 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 1 DATA SUBMITTAL COMPLIANCE REPORT 2/23/2010 Permit to Drill 2081580 Well Name/No. PRUDHOE BAY UNIT G-02B Operator BP EXPLORATION {ALASKA) INC MD 12171 TVD 8948 Completion Date 11/5/2008 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR Well Log Information: Log/ Electr Data Digital Dataset API No. 50-029-20217-02-00 UIC N 4~ Samples No Directional Survey {data taken from Logs Portion of Master Well Data Maint Loa Lop Run Interval OH / Ty Med/Frmt umber Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 10254 12171 Open 1/5/2009 pt Directional Survey 10254 12171 Open 1/5/2009 pt LIS Verification 9476 12171 1/16/2009 LIS Veri, GR, ROP D C Lis 17475 Gamma Ray 9476 12171 Open 1/16/2009 LIS Veri, GR, ROP ` ,Log Gamma Ray 5 Col 10278 12171 Open 1/16/2009 TVD GR 3-Nov-2008 L g Gamma Ray 25 Col 10278 12171 Open 1/16/2009 MD GR 3-Nov-2008 og See Notes 5 Col 9470 12172 Open 1/16/2009 Depth Shift Monitor Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? 'T''hN. Analysis '`f'/-fd- Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? V/ N Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/23/2010 Permit to Drill 2081580 Well Name/No. PRUDHOE BAY UNIT G-02B Operator BP EXPLORATION (ALASKIy INC MD 12171 TVD 8948 Completion Date 11/5/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20217-02-00 UIC N ~a~ ~t~ Compliance Reviewed By: Date: -~~ ~ ~ INTEQ Log ~ Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: G-02B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) Sent by: Catrina Guidry Date: O1/12/OQ ~ - , , ~ ~ j ~ ~` ~; Received by: ~` • Date: ' i ~~ ,, , ~ j~~3;;1 PLEASE ACKNOWLEDGE RECEIPT BY SICI~IN~ ~~~2ETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 _ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 ,- ~ ~ ~~~ Direct: (907) 267-6612 ~?~~ _ lJ ~ ~ ~ 1 ~~ [IYTEQ FAX: (907) 267-6623 ---~ .~ - ,%'~ ._ BAitlR~ M~/6NE5 Copies of Copies Digital Copies of Copies Digital Each Log of Fihn Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIltKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUTTE 802 ANCHORAGE AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address COMPANY WELL NAME FIELD PRUDHOE BAY UNIT Baker Atlas PRINT DISTRIBUTION LIST BY EXYLUKAI'lUN (ALASKA) 1NC CUUN"1'Y NUR'1'H SLUPE BURUUGH G-02B STATE ALASKA THIS DISTRIBUTION LIST AUTHORIZED BY LYNNE BOURGEOIS SO #: 2281614 Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This Distribution List Completed Bv: ri(',U ~ i'J ~ !~ :'-~ DATE 1/14/2009 Page 1 of 1 ~/r~ BAKER HUGHES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: December ] 8, 2008 Please find enclosed directional survey data for the following wells: G-02B ~ Y-OSB ~-32B Y-OSBPBI L-01 B Y-25 C-30A C-23C Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ,State of Alaska AOGCC DATE: ~^_ J ,,,,~ ~~~~~ Cc: State of Alaska, AOGCC ~ b'- ~S~g -.e%Gf~P - STATE OF ALASKA iaa-v~ ALASK~IL AND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 2oAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ~ Development ^ ExploratAry ^ Service - ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban~d~./ 11 /2008 G~ " 12. Permit to Drill Number 208-158 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/1/2008 ' 13. API Number 50-029-20217-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/3/2008 - 14. Well Name and Number: PBU G-026 FEL, SEC. 12, T11N, R13E, UM 2163 FNL, 1974 Top of Productive Horizon: 1005' FNL, 1740' FWL, SEC. 07, T11 N, R14E, UM 8. KB (ft above MSL): 74' Ground (ft MSL): 34.97' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 665' FNL, 2977' FWL, SEC. 07, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12132' - 8953' - Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 658243 y- 5969486 Zone- ASP4 10. Total Depth (MD+TVD) 12171' ~ 8948' - 16. Property Designation: ADL 028304 TPI: x- 661932 y- 5970723 Zone- ASP4 th: x- 663162 - 5971089 Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y 18. Directional Survey ®Yes ^ No mi I ctroni an rinte informa io r 2 AA 2 . 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and MWD DIR / GR L,~/NdOill~J~ a8 printed inf ation per 20 AA 25.071): 0~M0 9 ~~ TY~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " x 30" In I t on r Surf ce 11 rf 110' 8 n r /~~ ~ _/~~ / " 47# N- Urf 1' rf 831 ' 1 -1 / " 1420 cu ft Howco Lite, 289 w ft'G', 135 a, ft PF'C' 7" L- 2 4' -1/2" I s 4-1 1 1 T I ' 3-~n^ x 3-3r~s° X s-ris° s.z# i s.2u i s.~sa L- 1 7' 1 71' T 4-1 /" 14 I 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; p 6 spf 6 spf 2" Gun Diameter 2" Gun Diameter 4-1/2", 12.6#, L-80 10128' 9957' , , MD TVD MD TVD 10390' - 10440' 8974' - 8971' 11200' - 11300' 8979' - 8980' 10480' - 10530' 8971' - 8972' 11430' - 11510' 8977' - 8974' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10730' - 10770' 8971' - 8971' 11530' - 11680' 8973' - 8971' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10810' - 10920' 8972' - 8974' 11730' - 11900' 8971' - 8966' 12020' 8963' 8960' 11 11 7 7 77' 11970' ' ' ' 2200' Freeze Protected w/ McOH - - 000 - 0 0 89 5 - 89 11120' - 11180' 8977' - 8978' 26. PRODUCTION TEST Date First Production: November 29, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date Of Test: 11/29/2008 HOUrS Tested: 4 PRODUCTION FOR TEST PERIOD OIL-BBL: 825 GAS-MCF: 2,272 WATER-BBL: 12 CHOKE SIZE: 96 GAS-OIL RATIO: 2,755 Flow Tubing Press. 300 CaSing PreSS: 1,000 CALCULATED 24-HOUR RATE• OIL-BBL: 4,948 GAS-MCF: 13,633 WATER-BBL: 74 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^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 /j-S Q~ ~~`~~~~ ~~. ~;~;~: ~ X009 °~` . n.,,~., Form 10-407 Revised 02/2007 ~iONTINUE~Nv~~IgF, ~ A L ~~~ (~,. G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No ~emlafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 1A 10292' 8971' None Zone 1A 10975' 8975' Zone 1A 11536' 8973' Zone 1A 11852' 8968' Formation at Total Depth (Name): Zone 1 A 11852' 8968' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. / Si d ~ I~ gne ~ Terrie Hubble Title Drilling Technologist Date ! PBU G-02B 208-158 Prepared ByName/IVumber. Terrie Hubble, 564-4628 Well Number P mi . / A r v I N Drilling Engineer: Ron Phillips, 5645913 INSTRUCTIONS GeNewaL: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafoost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date ~~ From - To ~~~ Hours Task ~, Code ~ NPT ~~ Phase 1. Description of Operations ~~ _ ~_ , 10/30/2008 00:00 - 10:00 ~ 10.00 MOB ~ P PRE Move off pad and move rig from 18-06B to G-026. 10:00 - 15:00 5.001 BOPSU(~ P PRE 15:00 - 20:00 5.00 BOPSUp P PRE 20:00 - 21:00 1.001 RIGU P PRE 21:00 - 21:30 I 0.501 RIGU I P I I PRE 21:30 - 22:10 0.67 RIGU P PRE 22:10 - 23:00 0.83 RIGU P PRE 23:00 - 23:40 0.67 BOPSU P PRE 23:40 - 00:00 0.33 BOPSU P PRE 10/31/2008 00:00 - 00:45 0.75 RIGU P PRE 00:45 - 01:00 0.25 MOB P WEXIT 01:00 - 01:15 0.25 WHIP P WEXIT 01:15-02:10 I 0.921WHIP IP I IWEXIT 02:10-05:101 3.OOWHIP P IWEXIT 05:10 - 06:00 0.83 WHIP P WEXIT 06:00 - 06:25 0.42 WHIP P WEXIT 06:25 - 08:25 2.00 WHIP P WEXIT 08:25 - 09:40 1.25 WHIP P WEXIT 09:40 - 11:20 1.67 WHIP P WEXIT 11:20 - 11:35 0.25 WHIP P WEXIT 11:35 - 11:55 0.33 WHIP P WEXIT 11:55 - 13:45 1.83 WHIP P WEXIT 13:45 - 14:45 1.00 WHIP P WEXIT " 14:45 - 17:00 2.25 STWHIP P WEXIT .~ ` ~ ~~~ 17:00 - 17:15 0.25 STWHIP P WEXIT 7- 17:15 - 17:40 0.42 STWHIP P WEXIT 17:40 - 18:00 0.33 STWHIP P WEXIT 18:00 - 21:00 3.00 STWHIP P WEXIT Route of travel is from 18-06B onto West Dock road to K-pad access road to G pad. ACCEPT RIG AT 10:00 NU BOP. Install sump. grease tree. Test BOP. AOGCC 's Chuck Sheeve waived witnessing the BOP test. Test annular, blind shears, 2-3/8" combi, 3-1/2" x 2-3/8" VBR, 2-3/8" combi, HCR, Kill line valves. Test stabbing valves also. Cut off CT connector and inspect cable boot, looks ok. M/U CT to riser, line up to fill reel in reverse. Pump 40 bbls fresh water then displace with 2% KCL 2# biozan. Break off CT riser, rig up hydraulic cutter. Cut 190 ft of CT to find cable. Install SLB CT connector. Pull test to 35 Klbs, good. Install BHI cable head. PT and electric test, good. Line up to PT inner reel valve and CT connector. Test and chart to 250 / 3,500 psi, good. Load BPV tools to rig floor. PJSM then pull BPV. Well is on vac. Fill well with 14 bbls. Load WFT tools to rig floor. SAFETY MEETING. PJSM for picking up WFT whipstock anchor. Crew positions and overhead loads were discussed. M/U BHA #1 -WFT Packer and setting adaptor for 4-1/2, 2-3/4 Fury setting tool, 3" CoilTrak with HOT, DGS, and DPS. RA tags installed in whipstock while picking up BHA. RIH BHA #1. Circ 0.2 bpm through open EDC. Log GR down from 8,940 ft, then from 9,540 ft. Correct +5 ft. Continue RIH to log CCL. Log CCL up from 10,350 ft. Up wt is 46 Klbs. Stop at 9,900 ft and print out logs. RIH to 10296.6 (10280 TOWS) Pu Wt 45K. Close EDC. Pressure shear at 3000. Stack 5K. OK. POH Filling across the top of the hole. Static loss rate 8 bpm . LD anchor running tools . PU WS ,running tool and jars RIH with hollow tray WS. Tie -in +6 correction. RIH 10000' . PU Wt 41 K. RIH DN Wt 16K, tag at 10291. Set 10K dn. PU 47K. set 10K down. PU to 52K shear off. POH swapping well to milling fluid. LD WS setting tools. PU milling assembly. RIH to 9580 Replace valve on power pack. Log tie-in. Correction +5'. Tag at 10,279 ft at min rate. Pick up 39 Klbs and bring pump rate to 2.57 bpm ~ 2,300 psi off bottom. Ease back down to 10,278 ft, start time milling from there 1 ft/hr. .,,.... Printed: 11/25/2008 11:02:53 AM ~ ~ BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To 'Hours Task Code NPT Phase ~ Description of Operations 10/31/2008 18:00 - 21:00 3.00 STWHIP P WEXIT 18:00 - 10,278.11 ft 2.57 bpm C~ 2,300 psi DWOB = 0.1 Klbs. 21:00 - 22:20 I 1.331 STWHIPI P 22:20 - 00:00 1.671 STWHIP~ P 11/1/2008 100:00 - 02:30 ~ 2.501 STWHIP~ P 02:30 - 03:05 I 0.581 STWHIPI P WEXIT WEXIT WEXIT WEXIT 03:05 - 03:45 0.67 STWHIP P WEXIT 03:45 - 05:15 1.50 STWHIP P WEXIT 05:15 - 05:30 0.25 STWHIP P WEXIT 05:30 - 07:30 2.00 STWHIP P WEXIT 07:30 - 09:15 1.75 DRILL P PROD1 09:15 - 09:30 0.25 DRILL P PROD1 09:30 - 10:00 0.50 DRILL P PROD1 10:00 - 14:25 4.42 DRILL P PROD1 14:25 - 14:45 0.33 DRILL P PROD1 14:45 - 16:50 2.08 DRILL P PROD1 16:50 - 18:45 1.92 DRILL P PROD1 18:45 - 19:00 0.25 DRILL P PROD1 19:00 - 19:45 0.75 DRILL P PROD1 19:45 - 20:30 0.75 DRILL P PROD1 20:30 - 22:20 1.83 DRILL P PROD1 19:00 - 10,279.0 ft 2.54 bpm ~ 2,490 psi DWOB = 1.38 Klbs. 20:00 - 10,279.7 ft 2.55 bpm ~ 2,610 psi DWOB = 2.76 Klbs. 21:00 - 10,280.3 ft 2.56 bpm @ 2,660 psi DWOB = 3.0 Klbs. At 10,280.3 ft, partial loss of returns to 2.56 / 1.8 bpm, no effect on any pump parameters. Likely initial breakthrough of mill. Return rate slowly increases after that. PVT = 267 bbls at 21:00. 21:30 - 10,280.6 ft 2.56 / 2.47 bpm ~ 2,680 psi DWOB = 3.95 Klbs. Stall at 10,280.9 ft. Up wt is 38 Klbs. Continue milling at 10,280.5 ft. 23:00 - 10,281.00 ft 2.49 / 2.41 bpm C~ 2,480 psi. DWOB = 1.52 Klbs, PVT = 258 bbls. Mill to 10,281.9 ft. Continue milling from 10,281.9 ft at 2.50 / 2.40 bpm ~ 2,540 psi. PVT = 253 bbls. 01:00 - 10,282.91 ft 2.51 / 2.42 bpm C~3 2,560 psi DWOB = 2.38 Klbs. 01:30 -Stall at 10,283.4 ft. 02:00 - 10,283.71 ft 2.46 / 2.37 bpm ~ 2,500 psi DWOB = 1.04 Klbs. After 10,284.3 ft, DWOB falls off, likely casing exit. Drill rathole from 10,285 ft to 10,295 ft at 2.45 / 2.37 bpm ~ 2,400 psi. ROP is 10-20 ft/hr with DWOB = 0.27 Klbs. Start to swap hole to Flo-Pro. PVT = 251 bbls. Drill to 10,295 ft. Sample from 10,285 ft has Zone 1 B sand in it. Three up and down passes at full pump rate. Dry run through window is clean. POOH, pump flo-pro to surface. Tag stripper and flow check well. SAFETY MEETING. PJSM for changing out BHA. 3-man rule and pinch points were discussed. UD window mill and string reamer. Mill gauged 3.8 GO 3.79 NO GO. PU 3.3 motor assy. RIH. 9550 Log tie-in .Correction +5.5' RIH bauble at XN 9990. Thru window with 3.3 motor no problem. Tag at 10296'. PU wt 38K. Drill at 2.53/2.44 ~ 2760 psi PT 330 bbls, .8K WOB, ECD 9.89,ROP 35. Drill to 10450. W iper to window. Drill at 2.65/2.58 ~ 3135 psi PT 327 bbls, 1.55K WOB, ECD 9.98 ,ROP 60. Drill to 10.576 POH for lateral assv. Tag stripper and flow check well. PJSM for change out BHA. Three man rule, well control control contingencies were discussed. UD BHA #4. Bit is 1-1, will re-run. M/U BHA #5 - 4.125" HCC bicenter, 2-7/8" Xtreme with 1.4 deg AKO, 3" CoilTrak. RIH with BHA #5. Nnntea: i iie~euuts 71:UG:~:1 HM • i BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date I! Name: ell Name: e: Name: From - To G-02 G-02 REENTE NORDIC NORDIC Hours R+COM CALIST 1 I Task PLET A ~ Code E ~ NPT ' Start Rig Rig I Phase ! Spud Date: 8/22/1976 : 10/29/2008 End: 11/7/2008 Release: 11/7/2008 Number: N1 Description of Operations 11/1/2008 22:20 - 23:45 1.42 DRILL P PROD1 Log from 9,500 to 9,600 ft to tie in to PDC log. Correct +5 ft. Pass through window and tag bottom. 23:45 - 00:00 0.25 DRILL P PROD1 Tag bottom at 10,577 ft and drill. Drill at 2.51 / 2.42 bpm ~ 2,850 psi off bottom. PVT = 330 bbls. ROP is 60-100 ft/hr with DWOB 1-3 Klbs, CT wt = 7 Klbs. Drill with 90R TF for around 50 ft to complete right turn from last section. Hold 8,898 ft TVD for now. Drill to 10,600 ft. 11/2/2008 00:00 - 00:50 0.83 DRILL P PROD1 Continue drilling to 10,700 ft. At 10,640 start drilling 90L TF to stay in polygon. 00:50 - 01:20 0.50 DRILL P PROD1 Wiper trip from 10,700 ft to window. Up wt is 36 Klbs off bottom. Clean pass up and down. 01:20 - 04:00 2.67 DRILL P PROD1 Drill from 10,700 ft at 2.61 / 2.51 bpm ~ 2,850 psi off bottom. Maintain 90L TF. PVT = 324 bbls, ECD = 10.23 ppg. Some weight stacking problems after 10,710 ft. Hard drilling after 10,800 ft, likely fault crossing according to Geo. Drill to 10,850 ft. 04:00 - 04:40 0.67 DRILL P PROD1 Wiper trip from 10,850 ft to window. Up wt is 36 Klbs off bottom. Clean pass up and down. 04:40 - 05:50 1.17 DRILL P PRODi Drill from 10,850 ft at 80 - 120 ft/hr. Maintain 88 deg inclination to regain target sands. 2.53 / 2.44 bpm ~ 2900-3300 psi. 8.65 / 8.76 ppg with ECD = 10.23 ppg, mud swap scheduled after 0600. Drill to 11,000 ft. 05:50 - 07:00 1.17 DRILL P PROD1 Wiper trip from 11,000 ft to window, and tie-in log. Correction + 0.5ft Log GR down from 10,290 ft. 07:00 - 09:00 2.00 DRILL P PROD1 Drill 2.62/2.58 bpm ~ 3197 psi, 2985 psi FS, WOB 1.69K, ECD 10.21 90 inc, 75-120 ROP. Drill to 11150'. 09:00 - 10:00 1.00 DRILL P PROD1 Wiper to window. 10:00 - 12:20 2.33 DRILL P PROD1 Drill 2.55/2.51 bpm ~ 3344 psi. WOB 1/92K, ECD 10.29, 90 ROP, Swap mud system. Drill to 11300. 12:20 - 13:00 0.67 DRILL P PROD1 Wiper to window. 13:00 - 13:50 0.83 DRILL N RREP PROD1 Grease bearing on Gen 2 cooling fan. 13:50 - 14:30 0.67 DRILL P PROD1 Wiper to TD 14:30 - 17:00 2.50 DRILL P PROD1 Drill 2.63/2.57 bpm ~ 3170 PSI WOB 2.58K ECD 9.87, ROP 70-120. Drill to 11450'. 17:00 - 17:35 0.58 DRILL P PROD1 Wiper to window. 17:35 - 17:45 0.17 DRILL P PROD1 Log tie-in. Correction + 1.5". 17:45 - 18:20 0.58 DRILL P PROD1 Wiper to TD Bauble a 10690. 18:20 - 20:00 1.67 DRILL P PROD1 Drill from 11,450 ft. Hold 90L TF to continue left turn to TD, maintain 91.5 deg inc for now. 2.60 / 2.56 bpm ~ 2,750 - 3,300 psi ROP = 100 - 120 ft/hr with 1.5-3 Klbs DWOB. 8.54 / 8.58 ppg, ECD = 9.91 ppg. Frequently stacking weight. Drill to 11,600 ft. Printetl: 11/25/2008 11:0L:5:1 AM • BP EXPLORATION Page 4 of 8 ~ Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 8/22/1976 Start: 10/29/2008 End: 11/7/2008 Rig Release: 11/7/2008 Rig Number: N1 Date From - To Hours Task Code NPT 11/2/2008 20:00 - 21:20 1.33 DRILL P 21:20 - 23:20 2.00 ~ DRILL P 23:20 - 00:00 0.67 ~ DRILL ~ P 11/3/2008 00:00 - 00:40 0.67 DRILL P 00:40 - 02:45 2.08 DRILL P 02:45 - 04:30 1.751 DRILL P 04:30 - 07:00 2.501 DRILL ~ P 07:00 - 09:30 I 2.501 DRILL P 09:30 - 11:00 1.501 DRILL P 11:00 - 12:30 I 1.501 DRILL I P 12:30 - 12:40 0.17 DRILL P 12:40 - 13:55 1.25 DRILL P 13:55 - 16:15 2.33 DRILL P 16:15 - 17:00 0.75 DRILL P 17:00 - 18:40 1.67 CASE P 18:40 - 19:00 I 0.331 CASE I P 19:00 - 00:00 5.00 CASE ~ P Phase Description of Operations PROD1 Wiper trip from 11,600 ft to window. 38 Klbs off bottom. 8 Klbs overpull around 10,790 ft, small shale zone here. PROD1 Drill from 11,600 ft at 100-120 ft/hr. Continue to hold 91.5 deg inc and keep turning left. 2.59 / 2.51 bpm ~ 2,900-3,200 psi. 8.58 / 8.65 ppg, ECD = 10.01 ppg PVT = 267 bbls. Drill to 11,750 ft. ~ PRODi Wiper trip from 11,750 ft to window. 8 Klbs overpull at 10,790 ft, stack out there when RIH. PROD1 Continue wiper trip from 11,750 ft to window. PROD1 Drill from 11,750 ft. 2.57 / 2.56 bpm ~ 2,900 - 3,500 psi. ROP is 100 - 140 fUhr, frequent weight stacking. 8.64 / 8.68 ppg, ECD = 10.12 ppg. After 11,820 ft start right turn to aim for NE corner of polygon, will add around 60+ ft to MD of well. Continue to hold around 91.5 deg inc. Drill to 11,900 ft. PROD1 Wiper trip + tie-in. Overpull at 10,790 ft. Correct +2 ft, run back to bottom. PRODi Drill from 11,900 ft. 2.60 / 2.59 bpm ~ 2,900 - 3,500 psi. ROP is 40 - 80 Whr with DWOB 1-4 Klbs. 8.65 / 8.70 ppg, ECD = 10.23 ppg. Maintain 91.5 deg, continue right turn. PVT = 249 bbls. PROD1 Wiper to window. Seen motor work at , 11765. bauble at 11710 & 11800. PROD1 Drill at 2.59/2.50 bpm ~ 3430 psi, FS = 3000 psi, 4.49K WOB, ROP 90, ECD 10.36, Drill to 12170. TD. PROD1 Wiper to window. MW at 10791-10795 ream. 10710 10655 10407 45K over pull, Ream 10407 PROD1 Log tie - in. Correction. +1.5'. PRODi Wiper to TD.2.5 bpm ~ 3080 psi. Tag at 12171'. PRODi POH spotting liner running pill. Paint Flag 9900 EOP. PROD1 LD BHA. Bit has 2 plugged jets, 1 chipped cutter. RUNPRD Prep to run liner. Load running tools to rig floor. Pump 160 ft of cable out of CT. RUNPRD SAFETY MEETING. PJSM for running liner. Crew positions, lifting and hand traps were discussed. RUNPRD Run liner as per program. UNIQUE ROTATING GUIDE SHOE, 2-7/8" STL BTT FLOAT COLLAR, 2-7/8" STL 2-7/8" 6.16# STL L-80 BTT FLOAT COLLAR, 2-7/8" STL 2-7/8", 6.16#, L-80, STL pup BTT LANDING COLLAR, 2-7/8" STL 2-7/8" 6.16# STL L-80 LINER w/ cementra BTT XO, 2-7/8" STL P X 3-3/16" TCII B i 3-3/16" 6.2# TCII L-80 LINER w/ CEMENTRA XO, 3 1/2" STL Box x 3 3/16" TCII Pin 3-1/2", 9.2#, L-80, STL 10' Pup Jt BTT LINER DEPLOYMENT SLEEVE, 4" GS rnmea: i v~aic~~a i i vc:oo hm • BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ' Task 11/3/2008 19:00 - 00:00 5.00 CASE Code I NPT I Phase P 11/4/2008 00:00 - 00:30 0.50 CASE P 00:30 - 03:30 3.00 CASE P 03:30 - 05:30 I 2.001 CASE I P 05:30 - 09:10 3.671 CASE ~ P 09:10 - 11:00 1.83 CASE P 11:00 - 11:15 0.25 CASE P 11:15 - 13:15 2.00 CASE P Description of Operations RUNPRD BOT SELRT XO X-OVER BOT HYDRAULIC DISCONNECT, 3/4"BALL BOT X-O 2-3/8 PH-6 Tubing, Avg/Jt 32.14' XO BOT X-O BOT SWIVEL XO X-O BOT SLIP TYPE CTC BHA OAL = 2,287.76 ft. Fill liner with water prior to M/U CT. RUNPRD Continue M/U liner. RUNPRD RIH with liner. Stop prior to window and pump remaining fresh water out of liner. Wt check just above window is 42 Klbs. Pass through window and RIH to bottom. Tag at 12,170 ft. Up wt is 50 Klbs. RUNPRD Go back to bottom, establish circulation rate. Circ at 0.44 / 0.35 bpm ~ 1,470 psi. Pick up and find a ball drop position. Drop a 5/8" steel ball, launch with 700 psi. Run back to bottom, stack 6 Klbs down on it. Chase with flo-pro at 0.78 / 0.70 bpm. Ball is heard rolling in the reel. Slow pump at 35 bbl to see it land. After 60 bbls ball doesn't seat. RUNPRD After 60 bbls increase pump rate to 1.46 / 1.38 bpm ~ 2,190 psi. Pump at 2.6 bpm unable to hear ball rolling. Attempt of PU 60K No Go. 49K neutral wt. Surge CT 3600 psi. Circulate 2.27 bpm ~ 2900 psi, NO GO. Milx high vis pill. Pump 15 bbp to fill reel. Surge CT No evidence of ball movement. Circ coil vol. Launch 2nd ball 5/8" AL IN 17 BBL kcl. Heard ball for first 8 bbl of the 15 bbl on reel 2.9bpm ~ 3200. Didnt heard ball go over top. Surge well 3.7 bpm 4100 psi. After 35 bbl. reduce rate to .58 bpm ~ 1425 psi. Circulate CT volume Ball on seat 46.9 BBIs. Pressure 4200psi shear PU 33800#. OFF Llner RUNPRD Swap well to KCL. RUNPRD PJSM to cement job. RUNPRD Batch mix 27 BBI Flood lines with KCL. PT to 7000 psi. Pump is 25 bbls 15.8 ppg cement (~ 1600 psi 1.46 bpm. Close choke flush BIO to cementers. Open choke and displace cement with rig pump. Displacement Volume In Rate Out Rate Circ Pressure Out Total. 12bbls 2.38 2.32 1890 9 bbl 25 2.34 2.27 1350 19.1 30 2.32 2.2 1700 29.1 40 2.52 2.41 2399 36.7 43 2.52 2.41 2380 41.5 Printed: 11/25/2008 11:02:53 AM • BP EXPLORATION Operations Summary Report Page 6 of 8 Legal Well Name: G-02 'Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date ', From - To ' Hours Task Code ~ NPT ~~, Phase ~ Description of Operations 11/4/2008 11:15 - 13:15 2.00 CASE P RUNPRD 43.8 42.2 43.8 cement at shoe zero 48 2.55 2.46 4.0 50 2.55 2.46 2900 5.9 53.3 9.2 53.5 9.8 PU 35K to Ehhaust 2bbl cement + 3 BIO to annulus. 1.97 bpm ~ 1666 psi Pressure to 2700 psi to shear LWP. Displace cement from liner In Vol In Rate Out Rate Circ Pressure Out Total 61.6 1.91 1.89 2219 16.9 64.0 1.91 1.76 19.2 66 1.93 1.81 21.1 68.2 1.93 1.81 2489 23.2 70 1.36 1.34 2100 24.9 71 1.36 1.27 2120 25.9 No Losses to formation. 71.7 landed anticipated landing 71.9 13:15 - 15:00 1.75 CASE P RUNPRD POH. LD running tools. Only the 5/8" AI ball recovered. 15:00 - 17:15 2.25 CASE N SFAL RUNPRD PU Nozzle and one joint PH-6 Stab on well. Circulate 3.1 bpm ~ 1985 psi. recover 5/8 Steel ball ~ 42.5 bbls. 17:15 - 17:30 0.25 EVAL P LOWERI PJSM for MU of Cleanout BHA 17:30 - 18:30 1.00 EVAL P LOWERi Stab injector into bunghole, RD nozzle, PU motor, circ sub, and 1/2" hyd disconnect. Shift change. PJSM to MU Cleanout BHA 18:30 - 19:20 0.83 EVAL N SFAL LOWERI Wait on power pack maintenance. 19:20 - 23:05 3.75 EVAL P LOWERI PU injector and set on legs, RU to PU CSH. PU 68 •nts 1-1/4" CSH XO, 7/8" Hyd Disconnect, XO, DBPV, XOs, 2 jnts PH-6, XOs, Lockable swivel, & XOs. Stab injector. 23:05 - 00:00 0.92 EVAL P LOWERi RIH w/ ceanout BHA pumping 0.35 bpm, 90 fpm. 11/5/2008 00:00 - 00:40 0.67 EVAL P LOWERI RIH 00:40 - 05:20 4.67 EVAL P LOW ER1 Mill cement from 9843' to 10094'. Set down on top of Cement/Aluminum profile at 10094.5'.uncorrected. Correction have been consistently +5-6' (Expected tag at 10097.= TOP deployment sleeve 10088 +9 to restriction) High motor work and frequent stalls through 10099'. RIH from 10099' to 12127' Un corrected PBTD w/little motor work. 05:20 - 07:30 2.17 EVAL P LOW ER1 POH to 10197' and paint end of pipe flag at 8000' & 6000' 07:30 - 09:20 1.83 EVAL P LOWERi Set back injector. Circulate bal to circ sub. Stand back 34 stands CSH. LD BHA 09:20 - 12:45 3.42 BOPSU P LOWERI Flush BOP with swizzel stick. Open lower ram doors. Body test BOP 12:45 - 13:15 0.50 ZONISO P LOW ER1 Test liner lap to 2000 psi Lost 550 psi in 10 minutes. Failed to test. rnrneu: i ucoicv~o i i.vc.oo nm BP EXPLORATION Operations Summary Report Page7of8~ Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2008 13:15 - 13:45 0.50 PERFO P LOWERI PJSM for PU perforating guns. Pinch point and sharp edged to beware of. 13:45 - 16:30 2.75 PERFO P LOW ER1 PU Perforating assy to perforate 10,390 - 10,440 10,480 - 10,530 10,730 - 10,770 10,810 - 10,920 11,000 - 11,070 11,120 - 11,180 11,200 - 11,300 11,430 - 11,510 11,530 - 11,680 11,730 - 11,900 11,970 - 12,020 16:30 - 17:30 1.00 PERFO N SFAL LOWERI Wait on replacement lower disconnect 17:30 - 18:00 0.50 PERFO P LOWERI PU 6 stands of 1-1/4 CSH tubing. 18:00 - 18:20 0.33 PERFO P LOWERI Crew change. SAFETY MEETING re: PU Perforating BHA 18:20 - 20:20 2.00 PERFO P LOWERI PU 28 stands of 1-1/4" CSH and remaining Perf BHA. Drift DBPV w/ 1/2" ball, Stab injector 20:20 - 23:50 3.50 PERFO P LOWERI RIH Perf BHA Flag at 9830.9' (6000 EOP), -0.3' correction Flag at 11830.7' (8000 EOP), -0.2' correction Tag TD at 12128' uncorrected. Correct depth to 12132'. PU to 12055'. Launch 1/2" AL ball w/ viscous pill (6 bbls ahead, 6 bbls behind). PU to 12025', Circulate ball at 1.5 bpm. Reduce rate to 0.8 bpm at 40 bbl away. PU to 12020'. Ball on seat at 60.8 bbls (56.8 bbl calc). Good shot indication w/ pressure increase to 3600 psi then shar dro . 23:50 - 00:00 0.17 PERFO P LOWERI POH 11/6/2008 00:00 - 01:00 1.00 PERFO P LOWERI Continue POH to surface. 01:00 - 01:15 0.25 PERFO P LOWERI SAFETY MEETING re: S/B CSH 01:15 - 03:20 2.08 PERFO P LOWERI Standback injector, standback 34 studs CSH. 03:20 - 03:35 0.25 PERFO P LOWERI SAFETY MEETING re: UD Perf guns 03:35 - 08:45 5.17 PERFO P LOWERI UD firing head, aluminum ball recovered UD 77 pert guns. - 08:45 - 09:15 0.50 PERFO P LOWERI Clear floor and prep to PU LTPacker. 09:15 - 10:00 0.75 CASE P RUNPRD MU Liner top packer BHA. 10:00 - 12:00 2.00 CASE P RUNPRD RIH.with KB acker. 12:00 - 14:00 2.00 CASE P RUNPRD PU Wt at 10000 38K. Sting in at 10078 uncorrected. PU breakover 10073'. PU to ball launch position. Launch 5/8" STL ball with 1600 psi. Circulate ball to seat at 1.96 bpm and 1130 psi. Slow to .75 bpm. after 55 bb increase rate to 1.5 bpm Ball on seat. 74.4 bbls total. RIH to 10078 (uncorrected depths) 14:00 - 15:15 1.25 CASE P RUNPRD Pu and set packer with 2100 psi Test back side to 2000 for 30 min. Good Test. Lost 40 si first five min held 'u ti ht last 25 min. Slack off to 6000. Pressure to shear off at 3888 psi. PU 15:15 - 17:15 2.00 CASE P RUNPRD POH. 17:15 - 17:45 0.50 CASE P RUNPRD LD KB packer running tools. rnmea: i uzoizuuu 1 I:UZ:JJ HM • BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/6/2008 17:45 - 18:00 0.25 BOPSU P POST Function Test BOP's. 18:00 - 18:30 0.50 WHSUR P POST 18:30 - 19:15 0.75 WHSUR P POST 19:15 - 19:45 0.50 WHSUR P POST 19:45 - 19:55 0.17 WHSUR P POST 19:55 - 20:30 0.58 WHSUR P POST 20:30 - 22:15 1.75 WHSUR P POST 22:15 - 00:00 1.751 WHSUR P POST 11/7/2008 00:00 - 02:00 2.00 RIGD P POST 02:00 - 04:00 2.00 RIGD P POST Crew change, SAFETY MEETING re: PU FP nozzle PU Cement stinger & nozzle to FP well, Stab on well RIH to 2200' Freeze protect w/ McOH from 2200' to surface. RU N2 truck for blowdown. Standback injector Flowcheck well. Well is dead. PJSM re: install BPV Set BPV SAFETY MEETING re: N2 blowdown of the reel. Pickle reel w/ McOH then blowdown w/ N2. Bleed pressure. PJSM re: Pull coil back and prep for reel swap Standback injector, remove stuffing box, install grapple, pull test, Pull coil back & secure to reel. Drop 2-3/8" ecoil reel. PU 2" ecoil reel. Change BOP rams Change gripper blocks on injector ND BOPE NU Tree cap and pressure test RDMO RELEASE RIG AT 04:00 , TOTAL TIME ON LOCATION = 8 DAYS, 18 HOURS Move to E-326 Printed: 11/25/2008 11:02:53 AM rt, ~ ~ BP Alaska ~ N~~~~'`° ~ Baker Hughes INTEQ Survey Report r~~r BAKER HUGHES u~ i c.~r Company: BP Amoco Uatc 11/6/2008 Timc: 15:02:53 Yage: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: G-02, True North Site: PB G Pad Vertical (TVD) Reference: 4:02 5/7/1 995 00:00 74.0 Well: G-02 Section (VS) Rcfereucc: Well (O.OON,O.OOE,73.17Azi) Wellpath: G-02B Survev Calculation Method: Minimum Curvature llb: Oracle 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: bggm2007 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-02 Slot Name: 02 G-02 Well Position: +N/-S 2612.33 ft Northing: 5969486.01 ft Latitude: 70 19 23.901 N +E/-W 1996.57 ft Easting : 658243.00 ft Longitude: 148 43 0.740 W Position Uncertainty: 0.00 ft Wellpath: G-02B Drilled From: G-02A 500292021702 Tie-on Depth: 10254.14 ft Current Datum: 4:02 5/7/1 995 00:00 Height 74.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/9/2008 Field Strength: 57679 nT Declination: Mag Dip Angle: 23.04 deg 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 39.00 0.00 0.00 73.17 Survey Program for Definitive Wellpath Date: 9/9/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 112.80 8300.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 8405.00 10254.14 MWD (8405.00-11727.00) (1) MWD MWD -Standard 10278.00 12171.00 MWD (10278.00-12171.00) MWD MWD -Standard Annotation MD 'C VD ft ft 10254.14 8960.20 TIP 10278.00 8967.03 KOP 12171.00 8947.93 TD Survey: MWD Start Date: 11 /4/2008 Company: Baker Hughes INTEO Engineer: Tool: MW D;MW D -Standard Tied-to: From: Definitive Path ~~~~ ~ BP Alaska ~ "~~~ 'w~: by '~~~m Baker Hughes INTEQ Survey Report r.~ r~ BAKER Hu~H~s INTEQ Company: BP Amoco Date: 11/6/2008 Time: 15:02:53 Page: 2 Field: Pru dhoe Bay Co -ordinate(NI;) KcFerence : Well: G-02, Tr ue Nort h Site: PB G Pad Vertical (TVD) 12 eference: 4:02 5/711 995 00:00 74. 0 ~Vcll: G-02 Se ction (VS) Reference: Well (O.OON,O. OOE,73 .17Azi) yVellpath: G-02B Su rvey Calculatio n bicdiod : Minimum Curvature llb: Oracle Survcv Mll Incl Azim "1'VD Sys TV ll N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 10254.14 72.44 57. 00 8960. 20 8886. 20 1138.88 3684.66 5970702. 24 661902.57 3856. 59 0.00 MWD 10278.00 74.30 57. 00 8967. 03 8893. 03 1151.33 3703.84 5970715. 09 661921.48 3878. 54 7.80 MWD 10296.62 76.94 61. 10 8971. 65 8897. 65 1160.60 3719.30 5970724. 68 661936.74 3896. 03 25.61 MWD 10327.82 86.87 67. 73 8976. 05 8902. 05 1173.89 3747.12 5970738. 56 661964.27 3926. 50 38.14 MWD 10358.94 93.16 74. 22 8976. 04 8902. 04 1184.03 3776.51 5970749. 31 661993.44 3957. 57 29.03 MWD 10389.60 94.64 85. 12 8973. 95 8899. 95 1189.51 3806.56 5970755. 42 662023.36 3987. 92 35.79 MW D 10420.22 93.53 95. 85 8971. 76 8897. 76 1189.25 3837.05 5970755. 81 662053.85 4017. 03 35.14 MW D 10451.88 91.23 107. 88 8970. 44 8896. 44 1182.75 3867.95 5970749. 97 662084.88 4044. 72 38.65 MW D 10481.00 87.82 118. 46 8970. 68 8896. 68 1171.31 3894.68 5970739. 09 662111.84 4067. 00 38.17 MW D 10511.78 88.34 128. 90 8971. 72 8897. 72 1154.28 3920.24 5970722. 60 662137.75 4086. 53 33.94 MW D 10542.52 90.43 139. 60 8972. 05 8898. 05 1132.86 3942.23 5970701. 65 662160.18 4101. 38 35.46 MW D 10577.72 91.38 147. 96 8971. 49 8897. 49 1104.49 3963.00 5970673. 73 662181.55 4113. 05 23.90 MW D 10604.72 91.81 156. 69 8970. 74 8896. 74 1080.61 3975.53 5970650. 13 662194.58 4118. 13 32.36 MW D 10634.78 90.71 162. 04 8970. 08 8896. 08 1052.50 3986.11 5970622. 24 662205.75 4120. 12 18.17 MW D 10668.34 89.29 157. 40 8970. 08 8896. 08 1021.03 3997.74 5970591. 03 662218.04 4122 .14 14.46 MW D 10696.38 89.85 153. 13 8970. 29 8896. 29 995.57 4009.47 5970565. 82 662230.31 4126 .00 15.36 MW D 10728.72 89.26 146. 63 8970. 54 8896. 54 967.61 4025.69 5970538. 21 662247.11 4133 .43 20.18 MWD 10756.82 88.31 143. 21 8971. 13 8897 .13 944.62 4041.84 5970515. 57 662263.73 4142 .23 12.63 MWD 10792.70 89.26 138. 30 8971. 90 8897 .90 916.85 4064.52 5970488. 29 662287.00 4155 .90 13.94 MW D 10817.90 88.15 135. 77 8972. 46 8898 .46 898.42 4081.69 5970470. 22 662304.55 4167 .00 10.96 MW D 10845.96 89.23 131. 02 8973. 11 8899 .11 879.15 4102.07 5970451. 39 662325.33 4180 .93 17.36 MW D 10875.66 88.47 128. 19 8973. 70 8899 .70 860.22 4124.95 5970432. 95 662348.60 4197 :35 9.86 MW D 10905.62 89.32 123. 83 8974. 28 8900 .28 842.62 4149.17 5970415. 86 662373.19 4215 .44 14.82 MW D 10940.20 89.88 118. 32 8974. 52 8900 .52 824.78 4178.77 5970398. 65 662403.16 4238 .61 16.02 MW D 10978.44 89.72 113. 15 8974. 66 8900 .66 808.18 4213.21 5970382. 78 662437.93 4266 .76 13.53 MW D 11008.58 90.56 108. 67 8974. 58 8900 .58 797.42 4241.36 5970372. 62 662466.30 4290 .59 15.12 MW D 11037.96 87.21 106. 36 8975. 15 8901 .15 788.59 4269.36 5970364. 38 662494.48 4314 .84 13.85 MWD 11074.64 87.57 101. 18 8976. 83 8902 .83 779.87 4304.94 5970356. 41 662530.23 4346 .37 14.14 MWD 11109.68 90.52 96. 89 8977. 41 8903 .41 774.37 4339.53 5970351. 64 662564.93 4377 .89 14.86 MW D 11146.48 89.82 90. 83 8977. 30 8903 .30 771.89 4376.23 5970349. 94 662601.67 4412 .30 16.58 MW D 11176.72 87.45 85. 51 8978. 02 8904 .02 772.86 4406.43 5970351. 54 662631.84 4441 .49 19.25 MW D 11207.40 87.51 82. 96 8979. 37 8905 .37 775.93 4436.92 5970355. 26 662662.26 4471 .56 8.31 MWD 11239.96 90.92 78. 54 8979. 82 8905 .82 781.17 4469.05 5970361. 17 662694.26 4503 .82 17.14 MW D 11270.16 89.57 74. 05 8979. 69 8905 .69 788.32 4498.38 5970368. 94 662723.44 4533 .97 15.52 MW D 11309.26 90.92 70 .76 8979. 52 8905 .52 800.14 4535.64 5970381. 54 662760.44 4573 .06 9.09 MW D 11340.97 91.07 67 .29 8978. 97 8904 .97 811.48 4565.24 5970393. 51 662789.79 4604 .68 10.95 MW D 11371.21 90.55 63 .99 8978 .54 8904 .54 823.95 4592.78 5970406. 55 662817.06 4634 .65 11.05 MW D 11404.92 92.06 60 .88 8977 .77 8903 .77 839.55 4622.65 5970422. 77 662846.60 4667 .76 10.25 MW D 11435.58 92.58 56 .06 8976 .53 8902 .53 855.56 4648.76 5970439. 33 662872.35 4697 .38 15.80 MW D 11473.03 91.57 51 .11 8975 .18 8901 .18 877.77 4678.87 5970462. 17 662901.98 4732 .63 13.48 MW D 11496.13 92.15 48 .15 8974 .43 8900 .43 892.72 4696.45 5970477 .49 662919.25 4753 .79 13.05 MWD 11527.81 92.00 42 .69 8973 .28 8899 .28 914.94 4718.99 5970500 .17 662941.32 4781 .80 17.23 MWD 11558.40 91.84 35 .21 8972 .25 8898 .25 938.70 4738.20 5970524 .33 662960.02 4807 .06 24.44 MW D 11596.90 90.64 29 .68 8971 .42 8897 .42 971.17 4758.84 5970557 .23 662979.97 4836 .22 14.69 MW D 11625.95 89.97 26 .75 8971 .26 8897 .26 996.76 4772.57 5970583 .10 662993.16 4856 .77 10.35 MW D 11655.49 90.28 20 .95 8971 .20 8897 .20 1023.77 4784.51 5970610 .35 663004.52 4876 .02 19.66 MWD 11687.87 89.72 16 .05 8971 .20 8897 .20 1054.47 4794.78 5970641 .26 663014.14 4894 .73 15.23 MW D 11729.91 90.25 11 .45 8971 .21 8897 .21 1095.29 4804.77 5970682 .28 663023.27 4916 .11 11.01 MW D 11755.37 92.39 6 .94 8970 .62 8896 .62 1120.41 4808.84 5970707 .48 663026.81 4927 .28 19.60 MW D 11782.87 91.20 3 .56 8969 .76 8895 .76 1147.77 4811.36 5970734 .89 663028.74 4937 .61 13.02 MW D 11808.43 90.65 359 .70 8969 .35 8895 .35 1173.32 4812.08 5970760 .44 663028.93 4945 .70 15.25 MWD 11838.97 91.78 4 .60 8968 .70 8894 .70 1203.82 4813.23 5970790 .96 663029.43 4955 .62 16.46 MWD 11869.21 92.15 8 .88 8967 .66 8893 .66 1233.82 4816.77 5970821 .03 663032.34 4967.70 14.20 MW D ~p ~ BP Alaska ~ "~~~~`~ Baker Hughes INTEQ Survey Report BAKER HuGNES INTEQ Company: BP Amoco Uatc: 11/6/2008 Timc: 15:02:53 Page: 3 Field: Prudhoe Bay Co-ordinafe(NF) Reference: Well: G-02, Tr ue North Site: PB G Pad Vertical (TVllj Keferencc: 4:02 5/7/1995 00:00 74. 0 WeIL• G-02 Section (VS) Reference: Well (O.OON,O. OOE,73.17Azi) ~Vcilpath: G-02B Survey Calculation Method: Minimum Curvature Ub: Oracle Survey AID Intl Azim TVD Sys TVD N/S E/W MapN MapF VS llLS 'Ibol ft deg deg ft ft ft ft ft ft ft deg/100ft 11898.55 92.45 13.18 8966.48 8892.48 1262.59 4822.38 5970849.91 663037.34 4981.40 14.68 MWD 11933.65 91.54 19.04 8965.26 8891.26 1296.28 4832.11 5970883.79 663046.36 5000.46 16.89 MW D 11964.91 93.75 20.76 8963.82 8889.82 1325.64 4842.74 5970913.36 663056.37 5019.13 8.95 MWD 11995.75 93.93 25.98 8961.75 8887.75 1353.87 4854.94 5970941.85 663067.97 5038.99 16.90 MWD 12026.51 92.09 28.44 8960.14 8886.14 1381.19 4868.98 5970969.45 663081.43 5060.34 9.98 MW D 12065.35 91.81 33.57 8958.81 8884.81 1414.45 4888.97 5971003.12 663100.71 5089.10 13.22 MW D 12097.01 96.13 35.06 8956.62 8882.62 1440.53 4906.77 5971029.57 663117.96 5113.69 14.43 MW D 12129.73 96.92 39.68 8952.90 8878.90 1466.36 4926.50 5971055.81 663137.13 5140.04 14.23 MW D 12171.00 96.92 39.68 8947.93 8873.93 1497.89 4952.66 5971087.88 663162.62 5174.21 0.00 MW D 'VELLHEAD = 13-5/8" 5M McEVOY ~ CTUATOR = OTIS :B. ELEV = 74.0' 3F. ELEV = 35.17' :OP= 3513 DRLG DRAFT Aax Angle = 97° @ 12130' )atum MD = 10045' )alum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2684' TOP OF 7" LNR ~-~ 8261' Minimum ID = 2.37" @ 10,713' XC _ ~ _. 9-5/8" CSG, 47#, L-80, ID = 8.681" ~--~ 9311' 45 Hyd. "KB" Liner Top Packer 10070' Top 3-3/16 X 2-7/8 liner 10089' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10128' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 10265' G -0 ~ ~ ~ SA~ NOTES: 2171' ~-~ 4-112" SSSV HES HXO LAND NIP, ID = 3.813' 2683' -j 9-5/8" DV PKR GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 2 4223 4176 29 CAMCO DOM RA 16 11/09/08 1 8228 7395 41 CAMCO SO RA 20 11/09/08 MILLOUT WINDOW (G-02B) 10278' - 10284' 9946' ~ 4-1/2" HES X NIP, ID= 3.813" 9957' 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 9980' 4-1/2" HES X NIP, ID = 3.813" 9991' 4-1/2" HES XN NIP, ID =milled to 3.80" 10128' 4-1/2" TTL WLEG, ID = 3.95" 10130' ELMD TT LOGGED 02/01 /96 10278' ~ 4-1/2" WFO HOLLOW WHIPSTOCK 10713' 3-3/16" x 2-7/8" crossover, ID = 2.37" 3-3/16" X 2-7/8", 6.16#, L-80, STL solid cemented LNR ~--~ 12171' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11725' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 09/05/76 ORIGINAL COMPLETION WELL: G-026 05/29/95 SIDETRACK COM PLETION PERMIT No: 208-158 11/06/08 Nordic 1 CTD SIDETRACK (G-02B) API No: 50-029-20217-02 11/10/08 GJF/SV GLV C/O (11/09/08) SEC 12, T11N, R13E, 2163' SNL & 1974' WEL RP FYnlnratinn fAlacka\ PERFORATION SUMMARY REF LOG: Baker Hughes MWD/GR/ROP 11/03-2008 ANGLE AT TOP PERF: 95° @ 10390' Note: Refer to Production DB for historical ~~crf daia SIZE SPF INTERVAL OPN/SOZ DATE 2 6 10390 - 10440 O 11 /05/08 2 6 10480 - 10530 O 11 /05/08 2 6 10730 - 10770 O 11 /05/08 2 6 10810 - 10920 O 11 /05/08 2 6 11000 - 11070 O 11 /05/08 2 6 11120 - 11180 O 11 /05/08 2 6 11200 - 11300 O 11/05/08 2 6 11430 - 11510 O 11 /05/08 2 6 11530 - 11680 O 1 1 /05/08 2 6 11730 - 11900 O 11 /05/08 2 6 11970 - 12020 O 11 /05!08 a'~ ue C®lOTSERQAI`I®1~T C SCI®1`T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-02B BP Exploration Alaska Inc. Permit No: 208-158 Surface Location: 2163' FNL, 1974' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 695' FNL, 2856' FWL, SEC. 07, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ALAS~IL AND GAS CONSERVATION COMMI~ON ~ J PERMIT TO DRILL ~ `~ 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-02B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12200' TVD 8884'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028280 & 028304 Pool 2163 FNL, 1974 FEL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 1284' FNL, 1238' FWL, SEC. 07, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 7, 2008 Total Depth: 695' FNL, 2856' FWL, SEC. 07, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 14,180' 4b. Location of Well (State Base Plane Coordinates): Surface: x-658243 y-5969486 Zone-ASP4 10. KB Elevation (Height above GL): 74' feet 15. Distance to Nearest Well Within Pool: 350' 16. Deviated Wells: Kickoff Depth: 10280 feet Maximum Hole An le: 95 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3234 Surface: 2354 m• ' i T- e in h- B m f m .f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/ " 3-3175'x2-~/e" .2# / .4# TCII / STL 1 T 12 0 ' 4' I r 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11725' Total Depth TVD (ft): 7 ' Plugs (measured): None Effective Depth MD (ft): 11635' Effective Depth TVD (ft): 8974' Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 11 1 ' Surface 2 4' 1 II 4' ' Intermediate 11' / " 1420 cu ft Howco Lite, 289 cu ft'G', 135 cu ft PF'C' 11' 1 ' Liner 7" I 1' - 1 7 ' - ' r 1 -1 I 1 1 1'- 17 - Perforation Depth MD (ft): 10380' - 11625' Perforation Depth TVD (ft): 8984' - 8974' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the ore oin is true and correct. Printed Name John c ! Si nature ~ J ~ Contact Ron Phillips, 564-5913 Title En ineerin Team Leader ~1 C Prepared By NameMumber: Phone 564-4711 Date~~ ~ V tJ Terrie Hubble, 564-4628 ~ Commission Use Onl Permit To Drill u r: API Number: 50-029-20217-02-00 Permit Apr a~ ~ See cover letter for h r 'r m n Conditions of Approval If box is checked, well may not be used to explore for, test,. or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ~No Mud Log Req'd: Yes ~No HZS Measures: Yes ^ No .Directional Survey Req'd: Yes ^ No Other: ~~Q PSG X30'7 ~ E.'S `v ~ Date APPROVED BY T COMM SSIONER Form 10-441 Revisedl2/2005 ~ ~ F 1~ ~ ' Submit In Uupucate ry~ti~~~~ • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips, CTD Engineer Date: October 3, 2008 RE: G-02B Permit to Drill Request The sidetrack, G-02B, is scheduled to be drilled by Nordic 1 around November 22, 2008. The plan calls for a bighole lateral with a solid cemented liner in build section and slotted liner in lateral Zone lA/1B. Pre-Rig Work: 1. MIT-IA, and OA. 2. Dummy drift for WFD Hollow WS to 10,320' (74 deg incl) 3. PDS Caliper Log 4. Mill XN at 9,991' to 3.80" with left handed motor, mill. 5. Set BPV. 6. AC-LDS; AC-PPPOT- T 7. Test MV, SV, WV 8. Bleed gas lift and production flowlines down to zero and blind flange 9. Remove wellhouse, level pad The pre CTD work is slated to begin on October 1, 2008. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high, Pull BPV 2 Set 4-1/2" hollow whipstock C~ 10280' 3. Mill 3.80" window at 10280' and 10' of openhole. Swap the well to Flo-Pro. 4. Drill build/turn section with 3-3/4 x 4-1/8" bicenter bit, and land well. 40 deg/100 (plan #5) 5. Drill lateral section with 3-3/4 x 4-1/8" bicenter bit to TD at 12200'. 12 deg/100 (plan #5) 6. Run 3-3/16" solid/ cemented liner by 2-7/8" slotted liner leaving TOL at 10100' and transition form slotted to solid, 100' beyond landing point at 10660'. 7. Pump primary cement job from slotted liner to TOL, 6.8 bbl of 15.8 ppg cmt planned. ~~ S ~~~~ 8. Run CO assembly 9. Test liner lap to 2000 psi. 10. Freeze protect well, Set BPV, RDMO Post-Rig Work: 2. Pull BPV 3. Re-install wellhouse and FL's. 4. Generic GLV design. 5. Flow well to portable test separator. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. • Hole size: 4-1/8" Casing Program: • 2 7/8", 6.4# , L-80, STL connection slotted liner: 12200'-10660' MD. • 3-3/16", 6.2#, L-80, TC-II Solid liner: 10660'-10100' MD. • A minimum of 6.8 bbls 15.8 ppg cement will be used to cement the solid liner. • TOC planned at 10100' (TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 14,180' • Distance to nearest well within pool - 350' ft to E-24B. Anticollision Summary • With Global Scan Applied E-24APB2 fails major risk with a ctr-ctr of 352' at 11805'. The E-24APB2 has been P/A'ed. Logging • MWD directional, Gamma Ray will be run over all of the open hole section. Hazards • The maximum recorded H2S level on DS-02is 25 ppm on G-02. • There are no mapped/ planned fault crossings. This area of the field does have moderate potential for manageable losses. Reservoir Pressure • Res. press. is estimated to be 3,234 psi at 8,800'ss (7.07 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2354 psi. Ron Phillips CTD Drilling Engineer 564-5913 CC: Well File Sondra Stewman/Terrie Hubble TREE _ ' 6" -5M -CNV WELLHEAD = 13-5/8" 5M McEVOY ACTUATOR- OTIS KB. ELEV = 74.0' BF. ELEV...- 35.1 T KOP = 3513' Max Angle = 94 @ 10935' Datum MD = 10045' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2684' I TOP OF 7" LNR I Minimum ID = 3.725" @ 9991' 4-1/2" HES X NIPPLE 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9311' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10128' TOP OF4-1/2" LNR 10128' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 10265' 7" X 4-1/2" BKR HPLPO PKR, ID = 3.875" W/ BAKER G2 TIEBACK SLV, ID = 4.5" 10131' PERFORATION SUMMARY REF LOG: SPERRY/SUN MWD ON 05/95 ANGLE AT TOP PERF: 87 @ 10380' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPN/SOZ DATE 2-3/4" 4 10380 - 10500 O 05/26/95 2-3/4" 4 10600 - 10730 O 05/26/95 2-3/4" 4 10850 - 11130 O 05/26/95 2-3/4" 4 11270 - 11625 O 05/26/95 2171' ~ 4-1/2" SSSV HES HXO LAND NIP, ID = 3.813" 26$3' J1 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 2 1 4223 8228 4176 7395 29 41 CAMCO CAMCO DMY DMY RA RA 07/04/03 07/04/03 SIDETRACK WINDOW - 8400' -8450' 9946' - j 4-1 /2" HES X NIP, ID = 3.813" 9957' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9980' 4-1/2" HES X NIP, ID = 3.813" 9991' 4-1/2" HES XN NIP, ID = 3.725" 10128' 4-1/2" TTL WLEG, ID = 3.95" 10130' ELMD TT LOGGED 02/01/96 PBTD -~ 11635' f 4-1/2" LNR 12.6#, L-80, .0152 bpf, ID = 3.953" -{ 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/05/76 ORIGINAL COMPLETION 07/13/03 CMO/TLP KB ELEVATION, MAX ANGLE 05/29/95 SIDETRACK COM PLETION 02/15!01 SIS-Isl CONVERTED TO CANVAS 03/01/01 SIS-MD FINAL 09/20/01 RNITP CORRECTIONS 07/04/03 JJ/TLP GLV GO PRUDHOE BAY UNIT WELL: G-02A PERMIT No: 1950230 'I API No: 50-029-20217-01 '~ SEC 12, T11 N, R13E, 2163' SNL & 1974' WEL BP 6cploration (Alaska) i' TREE _ ~ 6" -5M -CMJ WELLHEAD = 13-5/8" 5M McEVOY ACTUATOR = OTIS KB. ELEV = 74.0' BF. ELEV = 35.17' KOP = 3513' Max Angle = 94 @ 10935' Datum MD = 10045' Datum TV D = 8800' SS -O ~ ~ SAFETY NOTES: Proposed CTD Sidetrack O ' ~-( 4-1/2" SSSV HES HXO LAND NIP, ID = 3.813" 2683' ~~ 9-5/8" DV PKR ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ TOP OF 7" LNR I Minimum ID = 3.725" @ 9991' 4-11'm„ ~-~ =~ ~~ ~~9~~~ ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-~ 10128' { TOP OF 4-1 /2" LNR 10128' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 10265' PERFORATION SUMMARY REF LOG: SPERRY/SUN MWD ON 05/95 ANGLE AT TOP PERF: 87 @ 10380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SOZ DATE 2-3/4" 4 10380 - 10500 O 05/26/95 2-3/4" 4 10600 - 10730 O 05/26/95 2-3/4" 4 10850 - 11130 O 05/26/95 2-3/4" 4 11270 - 11625 O 05/26/95 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11725' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4223 8228 4176 7395 29 41 CAMCO CAMCO DMY DMY RA RA 07/04!03 07/04/03 SIDETRACK WINDOW - 8400' -8450' 9946' -~ 4-1/2" HES X NIP, ID = 3.813" 9957' 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 9980' 4-1/2" HES X NIP, ID = 3.813" 9991' 4-1/2" HES XN NIP, ID =nulled to 3.80" 10128' 4-1 /2" TTL WLEG, ID = 3.95" 1 X130' ELMD TT LOGGED 02/01/96 10280' ~-~ 4-1/2" WFD HOLLOW WHIPSTOCK 10660' ~~ 3-3/16" x 2-7/8" crossover ~JI--- ------- -----I 3-3/16" X 2-7/8" L-80 BONSAI 12200' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/05/76 ORIGINAL COMPLETION 07/13/03 CMO/TLP KB ELEVATION, MAX ANGLE 05/29/95 SIDETRACK COM PLETION 09/04/08 MSE PROPOSED CTD SIDETRACK 02/15/01 SIS-Isl CONVERTEDTOCANVAS 03/01/01 SIS-MD FINAL 09/20/01 RN/TP CORRECTIONS 07 ~~' 3 ~ _ ~ ~ ___-- PRUDHOE BAY UNIT WELL: G-026 PERMfr No: API No: 50-029-20217-02 SEC 12, T11 N, R13E, 2163' SNL 8~ 1974' WEL BP Exploration (Alaska) by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 9/19/2008 Time: 13:26.54 Page: I :Field: Prudhbe Bay Co-ordinate(NE) Reference: Well: G-02, True North Site: PB G Pad Vertical (TVD) Reference: 4:02 5/7/1 995 00:00 74.0 Well: G-02 Section (VS) Reference: Well (O.OON,O.OOE,70.OOAzi) ~ Wetlpath: PIarr5, G-026 Survey Calculation Method: Minimum Curvature Db: Sybase !, Field: Prudhoe Bay - - _- _ ', j North Slope UNITED STATES ' Map System:US State Plane Coordinate System 1927 'i~ Geo Datum: NAD27 (Clarke 1866) !i Sys Datum: Mean Sea Level Srte PB G Pad TR-11-13 ' UNITED STATES :North Slope ~!, Site Position: Northing: ', From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: bggm2007 5966832.87 ft Latitude: 70 18 58.211 N 656301.39 ft Longitude: 148 43 59.013 W North Reference: True Grid Convergence: 1.19 deg j Well: G-02 Slot Name: 02 ' G-02 ' Well Position: +N/-S 2612.33 ft Northing: 5969486.01 ft Latitude: 70 19 23.901 N +E/-W 1996.57 ft Easting : 658243.00 ft Longitude: 148 43 0.740 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, G-02B Drilled From: G-02A ', 500292021702 Tie-on Depth: 10254.14 ft Current Datum: 4:02 5/7/1995 00:00 Height 74.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/9/2008 Declination: 23.04 deg ', Field Strength: 57679 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 39.00 0 00 0.00 70.00 Plan: Plan #5 copy Mary's plan 5 Principal: Yes Targets __ __ Date Composed: Version: Tied-to: Name - Description TVD +N/-S Dip.:.. Dir. ft ft G-026 Polygon ! 74.00 1226.05 , -Polygon 1 74.00 1226.05 ', -Polygon 2 74.00 1051.03 ', -Polygon 3 74.00 781.58 -Polygon 4 74.00 694.68 -Polygon 5 74.00 938.04 i -Polygon 6 74.00 1524.95 -Polygon 7 74.00 1441.19 ', -Polygon 8 74.00 1121.76 -Polygon 9 74.00 940.90 ', -Polygon 10 74.00 963.60 ' -Polygon 11 74.00 1211.51 G-026 Fault 1 -Polygon 1 -Polygon 2 G-028 Fault 2 -Polygon 1 -Polygon 2 G-026 Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 ' -Polygon 4 G-026 Fault 4 9/9/2008 7 From: Definitive Path Map Map <---- Latitude ---->' <--- Longitude ---> +E/-W Northing Easting Deg Min Sec Deg .Min Sec ft ft ft,. 3713.94 5970790.00 661930.00 70 19 35.950 N 148 41 12.327 W 3713.94 5970790.00 661930.00 70 19 35.950 N 148 41 12.327 W 3475.18 5970610.00 661695.00 70 19 34.230 N 148 41 19.299 W 3919.63 5970350.00 662145.00 70 19 31.578 N 148 41 6.330 W 4482.97 5970275.00 662710.00 70 19 30.720 N 148 40 49.888 W ', 5038.26 5970530.00 663260.00 70 19 33.110 N 148 40 33.675 W ', 4955.61 5971115.00 663165.00 70 19 38.883 N 148 40 36.076 W 4658.76 5971025.00 662870.00 70 19 38.061 N 148 40 44.743 W ''~ 4627.01 5970705.00 662845.00 70 19 34.919 N 148 40 45.676 W ', 4428.14 5970520.00 662650.00 70 19 33.142 N 148 40 51.484 W I, 4063.51 5970535.00 662285.00 70 19 33.367 N 148 41 2.127 W ,~ 3928.70 5970780.00 662145.00 70 19 35.806 N 148 41 6.058 W ', 74.00 1030.59 4206.97 5970605.00 662427.00 70 19 34.025 N 148 40 57.939 W j 74.00 1030.59 4206.97 5970605.00 662427.00 70 19 34.025 N 148 40 57.939 W ', 74.00 1259.87 4623.92 5970843.00 662839.00 70 19 36.278 N 148 40 45.763 W ' 74.00 503.88 4375.91 5970082.00 662607.00 70 19 28.844 N 148 40 53.016 W 74.00 503.88 4375.91 5970082.00 662607.00 70 19 28.844 N 148 40 53.016 W ~I 74.00 1010.85 5237.85 5970607.00 663458.00 70 19 33.824 N 148 40 27.847 W , 74.00 1777.40 3657.55 5971340.00 661862.00 70 19 41.373 N 148 41 13.965 W ', 74.00 1777.40 3657.55 5971340.00 661862.00 70 19 41.373 N 148 41 13.965 W ', 74.00 1864.96 4106.53 5971437.00 662309.00 70 19 42.231 N 148 41 0.857 W ' 74.00 1872.59 4787.89 5971459.00 662990.00 70 19 42.303 N 148 40 40.966 W ' 74.00 1864.96 4106.53 5971437.00 662309.00 70 19 42.231 N 148 41 0.857 W ' 74.00 634.87 3761.49 5970200.00 661990.00 70 19 30.135 N 148 41 10.948 W by ~ BP Alaska Baker Hughes INTEQ Planning Report ~~a~ s u. _..,,~ .Company: -BP Amoco Field: Prudhoe Bay Site: PB G Pad .Well: G-02 Wellpath: ':Plan 5, G-02B Targets Name Description TVD +N/-S Dip. Dir. ft ft -Polygon 1 74.00 634.87 ', -Polygon 2 74.00 337.66 G-026 Target 3 8957.00 840.50 G-026 Target 6 8959.00 1482.81 ', G-026 Target 4 8962.00 953.10 ', G-026 Target 5 8962.00 1121.60 ~, G-026 Target 2 ! 8964.00 880.93 ~ ', ', G-028 Target 1 8989.00 1045.86 Map. Map <---- Latitadc ----> <--- Long-tude ---> j tE/-W Northing Fasting' Deg Min Sec Deg Min Sec I, ft - ft ft i 3761.49 5970200.00 661990.00 70 19 30.135 N 148 41 10.948 W '~, 3625.19 5969900.00 661860.00 70 19 27.213 N 148 41 14.931 W ' 4446.03 5970420.00 662670.00 70 19 32.154 N 148 40 50.964 W II 4819.68 5971070.00 663030.00 70 19 38.469 N 148 40 40.045 W I 4798.51 5970540.00 663020.00 70 19 33.259 N 148 40 40.673 W 4872.08 5970710.00 663090.00 70 19 34.916 N 148 40 38.522 W '', 3951.74 5970450.00 662175.00 70 19 32.554 N 148 41 5.391 W ' 3720.15 5970610.00 661940.00 70 19 34.178 N 148 41 12.149 W ', I Annotation -- -- MD TVD ft n 10254.14 8960.20 TIP 10280.00 8967.57 KOP 10300.00 8972.66 End of 9 Deg/100 DLS 10330.00 8977.23 4 10360.00 8977.50 5 10390.00 8975.66 6 10560.00 8966.77 End of 40 Deg/100 DLS 10610.00 8966.10 8 10810.00 8963.53 9 11110.00 8960.13 10 11310.00 8957.51 11 11410.00 8958.96 12 ', 11550.00 8962.00 13 11650.00 8961.98 14 111830.00 8962.27 15 12200.00 8958.03 TD Plan Section Information MD Intl Azim TVD +N/-S +E/-W DLS: Build Turn ft deg deg ft ft ft deg/1OOft deg/100ft deg/i00ft ' 10254.14 72.44 57.00 8960.20 1138.88 3684.66 0.00 0.00 0.00 i, 10280.00 74.46 57.00 8967.57 1152.38 3705.45 7.81 7.81 0.00 '.10300.00 76.02 57.93 8972.66 1162.78 3721.76 9.00 7.80 4.64 ~, 10330.00 86.47 63.91 8977.23 1177.15 3747.63 40.00 34.83 19.93 10360.00 92.50 74.29 8977.50 1187.83 3775.61 40.00 20.08 34.61 10390.00 94.51 86.14 8975.66 1192.91 3805.06 40.00 6.72 39.51 10560.00 90.76 154.13 8966.77 1112.47 3943.31 40.00 -2.20 39.99 ' 10610.00 90.76 160.13 8966.10 1066.42 3962.73 12.00 -0.01 12.00 10810.00 90.69 136.13 8963.53 897.82 4067.54 12.00 -0.03 -12.00 '', 11110.00 90.56 100.13 8960.13 758.71 4327.76 12.00 -0.04 -12.00 ', 11310.00 90.92 76.13 8957.51 765.19 4526.18 12.00 0.18 -12.00 11410.00 87.42 64.65 8958.96 798.68 4620.20 12.00 -3.50 -11.48 11550.00 90.12 48.06 8962.00 875.96 4736.29 12.00 1.93 -11.85 11650.00 89.90 36.06 8961.98 950.06 4803.17 12.00 -0.21 -12.00 11830.00 89.91 14.46 8962.27 1111.88 4879.53 12.00 0.00 -12.00 '.12200.00 91.34 330.08 8958.03 1469.40 4831.05 12.00 0.38 -11.99 TFO Target ~' deg,. 0.00 -- - _ - 0.00 30.00 30.00 60.00 80.00 91.00 90.00 270.00 270.00 271.00 253.00 279.00 ', 269.00 ', 270.00 272.00 Date: 9/19/2008 Time: 13;26:54 Pager 2 ~', Co-ordinate(NE) Reference: Well: G-02, True North" VerticaT(TVD) Reference: 4 ;.02 5/7/1995 00:00 74.0 I! Section (VS) Reference: Well (O.OON,O;OOE,70.OOAzi) Survey Calculation Method:... Minimum Curvature Db: Sybase by ~ BP Alaska Baker Hu hes INTEQ Plannin Report g g ~s u.. -••~c Company: BP Amoco Field: Prudhoe Bay Site: PB G Pad Well: G-02 Wellpath: Pfan 5, G-026 Survey Date: 9/19/2008 Timer 13:26:54 Pagec 3 Co-ordinate(NE)$eference: Welf; G-02, True North Vertical (TVD) Reference: 4:02 5/7/1995 00:00 Z4.0 Section (VS) Reference: Well-(O.OON,O.OOE,70.OOAzi) Survey Calculation Method: Minimum Curvature Ub: Sybase MD Inch Azim SS TVD N/S E/W ft deg deg ft fT ft 10254.14 72.44 57.00 8886.20 1138.88 3684.66 ii 10260.18 72.91 57.00 8888.00 1142.02 3689.50 10267.10 73.45 57.00 8890.00 1145.62 3695.05 10275.00 74.07 57.00 8892.21 1149.76 3701.42 10280.00 74.46 57.00 8893.57 1152.38 3705.45 10300.00 76.02 57.93 8898.66 1162.78 3721.76 10325.00 84.72 62.93 8902.84 1174.92 3743.17 ', 10330.00 86.47 63.91 8903.23 1177.15 3747.63 10350.00 90.49 70.83 8903.76 1184.83 3766.07 ', 10360.00 92.50 74.29 8903.50 1187.83 3775.61 10375.00 93.52 80.21 8902.71 1191.13 3790.21 10390.00 94.51 86.14 8901.66 1192.91 3805.06 10400.00 94.43 90.15 8900.88 1193.23 3815.02 10425.00 94.14 100.18 8899.01 1190.99 3839.82 ', 10450.00 93.71 110.19 8897.29 1184.47 3863.86 10475.00 93.18 120.19 8895.78 1173.86 3886.41 10500.00 92.55 130.19 8894.53 1159.49 3906.79 ', 10525.00 91.84 140.17 8893.57 1141.79 3924.37 ', 10550.00 91.08 150.14 8892.93 1121.30 3938.64 10560.00 90.76 154.13 8892.77 1112.47 3943.31 ~, 10575.00 90.76 155.93 8892.57 1098.87 3949.64 ', 10600.00 90.76 158.93 8892.24 1075.79 3959.23 10610.00 90.76 160.13 8892.10 1066.42 3962.73 10625.00 90.76 158.33 8891.91 1052.40 3968.04 ~ 10650.00 90.76 155.33 8891.57 1029.42 3977.88 !~ 10675.00 90.75 152.33 8891.24 1006.98 3988.90 10700.00 90.75 149.33 8890.92 985.16 4001.08 ', 10725.00 90.74 146.33 8890.59 964.00 4014.39 ', 10750.00 90.73 143.33 8890.27 943.57 4028.79 ~' 10775.00 90.71 140.33 8889.96 923.92 4044.23 10800.00 90. 70 137.33 8889.65 905.10 4060.69 10810.00 90. 69 136 .13 8889.53 897.82 4067.54 10825.00 90. 69 134 .33 8889.35 887.17 4078.10 10850.00 90. 69 131 .33 8889.05 870.18 4096.43 10875.00 90. 69 128 .33 8888.74 854.17 4115.63 10900.00 90. 68 125 .33 8888.45 839.19 4135.64 10925.00 90. 67 122 .33 8888.15 825.27 4156.40 10950.00 90. 66 119 .33 8887.86 812.46 4177.86 10975.00 90. 65 116 .33 8887.57 800.79 4199.97 11000.00 90. 64 113 .33 8887.29 790.30 4222.65 11025.00 90.62 110.33 8887.01 781.00 4245.86 11050.00 90.61 107.33 8886.74 772.94 4269.51 11075.00 90.59 104.33 8886.48 766.12 4293.56 11100.00 90.57 101.33 8886.23 760.57 4317.93 11110.00 90.56 100.13 8886.13 758.71 4327.76 11125.00 90.59 98.33 8885.98 756.30 4342.56 11150.00 90.64 95.33 8885.71 753.33 4367.38 11175.00 90.69 92.33 8885.42 751.66 4392.32 11200.00 90.74 89.33 8885.11 751.30 4417.31 11225.00 90.78 86.33 8884.77 752.24 4442.29 11250.00 90.83 83.33 8884.42 754.50 4467.18 11275.00 90.87 80.33 8884.05 758.05 4491.92 11300.00 90.91 77.33 8883.67 762.89 4516.45 --- p Ma N -- -- p Ma E - _ - DLS V5 TFO _„_-._~ Too ft ft degl100ft ft deg ~,, 5970702. 24 661902. 57 0. 00 3851 .97 0. 00 MWD' 5970705. 48 661907. 34 7. 81 3857 .59 360. 00 G-028 a 5970709. 20 661912. 81 7. 81 3864 .04 0. 00 G-02B a 5970713. 47 661919. 09 7. 81 3871 .43 360. 00 MWD', 5970716. 17 661923. 07 7. 81 3876 .12 360. 00 MWD 5970726. 92 661939. 15 9. 00 3895 .00 30. 00 MWD 5970739. 50 661960. 30 40. 00 3919 .28 30. 00 MWD' 5970741. 82 661964. 71 40. 00 3924 .23 29. 16 MWD 5970749. 90 661982. 98 40. 00 3944 .19 60. 00 MWD' 5970753. 09 661992. 45 40. 00 3954 .17 59. 82 MW D ~, 5970756. 70 662006. 98 40. 00 3969 .02 80. 00 MW D I, 5970758. 80 662021. 79 40. 00 3983 .59 80. 31 MWD', 5970759. 33 662031. 74 40. 00 3993 .06 91. 00 MWD 5970757. 61 662056. 58 40. 00 4015 .59 91. 31 MW D ~' 5970751. 59 662080. 75 40. 00 4035 .95 92. 06 MWD' 5970741. 46 662103. 52 40. 00 4053 .51 92. 75 MWD', 5970727. 52 662124. 19 40. 00 4067 .75. 93. 35 MWD'' 5970710. 20 662142. 15 40. 00 4078 .22 93. 85 MWD'', 5970690. 02 662156. 84 40. 00 4084 .61 94. 24 MWD', 5970681. 29 662161. 69 40. 00 4085 .98 94. 49 MWD' 5970667. 83 662168. 31 12. 00 4087 .28 90. 00 MWD' 5970644. 96 662178. 39 12. 00 4088 .40 90. 02 MWD', 5970635. 67 662182. 08 12. 00 4088 .48 90. 06 MWD', 5970621. 76 662187. 69 12. 00 4088 .68 270. 00 MWD', 5970598. 99 662198. 01 12. 00 4090 .06 269. 98 MWD' 5970576. 80 662209. 50 12. 00 4092 .75 269. 94 MWD 5970555. 24 662222. 14 12. 00 4096 .73 269. 90. MWD' 5970534. 37 662235. 89 12. 00 4102 .00 269. 86 MWD'', 5970514. 24 662250. 71 12. 00 4108 .54 269. 82 MWD', 5970494. 92 662266. 57 12. 00 4116 .34 269. 78 MWD' 5970476. 46 662283. 41 12. 00 4125 .36 269. 74 MWD' 5970469. 33 662290. 42 12. 00 4129 .31 269. 71 MWD', 5970458. 90 662301. 20 12. 00 4135 .60 270. 00 MWD' 5970442. 30 662319. 89 12. 00 4147 .01 269. 98 MWD'. 5970426. 70 662339. 41 12. 00 4159 .57 269. 94 MWD',, 5970412. 15 662359. 73 12. 00 4173 .25 269. 91 MWD 5970398. 67 662380. 78 12. 00 4188 .00 269. 87 MWD 5970386. 32 662402. 51 12. 00 4203 .79 269. 83 MWD' 5970375. 12 662424. 85 12. 00 4220 .57 269. 80 MWD 5970365. 10 662447. 75 12. 00 4238 .29 269. 76 MWD' 5970356. 30 662471. 14 12. 00 4256 .92 269. 73 MWD 5970348. 74 662494. 96 12. 00 4276 .39 269. 70 MWD 5970342. 43 662519. 15 12. 00 4296 .66 269. 67 MWD', 5970337. 39 662543. 63 12. 00 4317 .66 269. 63 MWD'. 5970335. 74 662553. 49 12. 00 4326 .26 269. 60 MWD', 5970333. 65 662568. 34 12. 00 4339 .34 271. 00 MWD'', 5970331. 20 662593. 22 12. 00 4361 .65 270. 98 MW D ~I 5970330. 05 662618. 18 12. 00 4384 .51 270. 95 MWD' 5970330. 22 662643. 18 12. 00 4407 .88 270. 91 MWD !, 5970331. 69 662668. 13 12. 00 4431 .67 270. 88 MW D ~~ 5970334. 47 662692. 97 12. 00 4455 .83 270. 84 MW D ~~, 5970338. 54 662717. 62 12. 00 4480 .30 270. 80 MWD 5970343. 90 662742. 03 12. 00 4504 .99 270. 75 MWD', by ~ BP Alaska ~ ~~ Baker Hughes INTEQ Planning Report >urTE Q Company: BP Amoco Date: 9/19!2008 Time: 13:26:54 Page: 4 .Field: ' Pru dhoe Bay Co-ordinate(NE) Reference: WeIL• G-02, True North , .Site: -PB G Pad Vertical (TVD}Reference: 4'. 02'5/7/t995 00:00 74.0 Well: G-02 Section (VS)Reference: Well (O .OON,O;OOE,70.OOAz i) Wellpath: Pla n 5, G-026 Survey Calculation Method: Minimu m Curvature Db: Sybase Survey MD Inc! Azim ' SS TVD N/S E/W MapN MapE DLS VS TFO Too ft deg. deg ft ft ft ft ft deg/100tt ft deg 11310.00 90.92 76.13 8883.51 765.19 4526.18 5970346.40 662751.72 12.00 4514.92 270.70 MWD'~ 11325.00 90.39 74.41 8883.33 769.00 4540.68 5970350.52 662766.14 12.00 4529.86 253.00 MW D j 11350.00 89.51 71.54 8883.35 776.32 4564.58 5970358.34 662789.88 12.00 4554.82 252.98 MW D 11375.00 88.64 68.67 8883.76 784.82 4588.09 5970367.34 662813.19 12.00 4579.82 252.98 MWD', ~! 11400.00 87.76 65.80 8884.54 794.49 4611.12 5970377.49 662836.02 12.00 4604.77 253.03 MW D', 11410.00 87.42 64.65 8884.96 798.68 4620.20 5970381.87 662845.00 12.00 4614.73 253.12 MW D 11425.00 87.70 62.87 8885.60 805.31 4633.64 5970388.77 662858.30 12.00 4629.63 279.00 MW D ', 11450.00 88.18 59.91 8886.50 817.27 4655.57 5970401.20 662879.97 12.00 4654.32 279.08 MWD'I 11475.00 88.66 56.94 8887.19 830.35 4676.86 5970414.72 662900.98 12.00 4678.80 279.18 MWD'' 11500.00 89.14 53.98 8887.67 844.52 4697.44 5970429.32 662921.26 12.00 4703.00 279.26 MW D I~ 11525.00 89.63 51.02 8887.94 859.74 4717.27 5970444.95 662940.76 12.00 4726.84 279.32 MWD', 11550.00 90.12 48.06 8888.00 875.96 4736.29 5970461.57 662959.44 12.00 4750.26 279.35 MWD'. ', 11575.00 90.06 45.06 8887.96 893.14 4754.45 5970479.13 662977.22 12.00 4773.19 269.00 MW D ~, I, 11600.00 90.01 42.06 8887.94 911.26 4771.67 5970497.61 662994.06 12.00 4795.57 269.00 MWD' !, 11625.00 89.96 39.06 8887.95 930.25 4787.93 5970516.93 663009.91 12.00 4817.34 268.99 MWD' 11650.00 89.90 36.06 8887.98 950.06 4803.17 5970537.06 663024.73 12.00 4838.44 268.99 MWD' 11675.00 89.91 33.06 8888.02 970.65 4817.35 5970557.94 663038.47 12.00 4858.81 270.00 MWD 11700.00 89.91 30.06 8888.06 991.95 4830.43 5970579.51 663051.10 12.00 4878.39 270.00 MWD 11725.00 89.91 27.06 8888.11 1013.90 4842.38 5970601.71 663062.59 12.00 4897.13 270.01 MW D ', 11750.00 89.91 24.06 8888.15 1036.45 4853.17 5970624.48 663072.89 12.00 4914.98 270.01 MWD' 11775.00 89.91 21.06 8888.19 1059.54 4862.76 5970647.76 663082.00 12.00 4931.88 270.02 MWD' 11800.00 89.91 18.06 8888.23 1083.09 4871.13 5970671.48 663089.87 12.00 4947.81 270.02 MWD' 11825.00 89.91 15.06 8888.27 1107.05 4878.26 5970695.59 663096.49 12.00 4962.70 270.03 MWD'. 11830.00 89.91 14.46 8888.27 1111.88 4879.53 5970700.45 663097.66 12.00 4965.55 270.03 MWD'. 11850.00 90.00 12.07 8888.29 1131.35 4884.12 5970720.00 663101.84 12.00 4976.52 272.00 MWD'', 11875.00 90.10 9.07 8888.27 1155.92 4888.71 5970744.67 663105.90 12.00 4989.23 272.00 MWD', I~ 11900.00 90.20 6.07 8888.20 1180.70 4892.00 5970769.51 663108.67 12.00 5000.80 272.00 MWD' 11925.00 90.31 3.07 8888.09 1205.62 4893.99 5970794.46 663110.13 12.00 5011.19 271.99 MWD''~, 11950.00 90.41 0.07 8887.93 1230.61 4894.68 5970819.45 663110.29 12.00 5020.38 271.98 MWD''i ~', 11975.00 90.51 357.07 8887.73 1255.59 4894.05 5970844.42 663109.14 12.00 5028.34 271.96 MW D I, ~ 12000.00 90.61 354.08 8887.48 1280.52 4892.12 5970869.29 663106.69 12.00 5035.06 271.93 MW D , ~I 12025.00 90.71 351.08 8887.20 1305.30 4888.89 5970894.01 663102.94 12.00 5040.50 271.91 MW D I,i ~! 12050.00 90.81 348.08 8886.86 1329.88 4884.37 5970918.49 663097.90 12.00 5044.66 271.87 MW D ~! 12075.00 90.90 345.08 8886.49 1354.20 4878.57 5970942.67 663091.59 12.00 5047.52 271.83 MW D 12100.00 91.00 342.08 8886.07 1378.17 4871.51 5970966.49 663084.02 12.00 5049.08 271.79 MW D 12125.00 91.09 339.08 8885.62 1401.74 4863.20 5970989.87 663075.21 12.00 5049.33 271.74 MWD'i 12150.00 91.17 336.08 8885.13 1424.85 4853.67 5971012.77 663065.20 12.00 5048.28 271.68 MW D I, i 12175.00 91.26 333.08 8884.60 1447.42 4842.94 5971035.11 663054.00 12.00 5045.92 271.62 MW D ~'I 12200.00 91.34 330.08 8884.03 1469.40 4831.05 5971056.83 663041.65 12.00 5042.26 271.56 3.5" ~, BP Alaska WELV~TN DET~ILB Pax lOO3N3031ie? Nut. Oawm. 6:025A/t8B5 N00N i9.NNlt D W N e ~ a u »> LEGEND - G-02 (G021 G-02 (G02A) - Plan S G-020 a v~ n.,,xs lcawn..s caz c. uau a w. a~axua - by , - Phan p5 m e~cl m. x~ y x ~K~~sF~a moxi~W9~m oven inrovn auoCellM BOi)9l1^~5)0 E~mN~~: scnV~~nlry wm ven~cai seonon at ~o.oo• ~sow~n~ BP Alaska WELVdTX DETMLd - c-DxB Bid: kr. mr+m: +. o: smidas o00o va.owr _ v o.~ °~w r.om itro REFERENCE INFORMATION Co-ortlinale (N/E) Reference: Well CenOe: G-02, True North VeNCaI (ND) Reference: 4:02 517/1995 OP.00 74.00 - E' Scnion (VS)Rekrence: Slot-02 (O OON,O.OOE) E' Measurztl DUPIh Rolvroncc: 4:02 51711995 OU_00 74.00 _ Culc~la:lon Me~FOtl. Mii lllnu~n Curv~lr~ru as MD irc Ki rvD aEC.iw jD iu ~~ DM n.o. vsw iarpr 1E 11!]0.00 ~ ~~ N0.M ddu.TT t~it.N ILW fldiY ~=,6{ - E~ 09N.00 000fD0 fiM 3] 200 ~ , .-. -..i 1. :._ _ ~ _ --' f i~ :.,I. .. _ i~ ~ ~ I~ ~_ 190 Y ~~ t .1.- F j ~. ,.. ..._.. ~_.._ _..._ i _ _ - .. lsoo a.t _ rE-25 (E 25~~ , i _ ~ + no~ .. I } r - + ~-- .~ -rlifi ..._ T I- ~ , ii r t ~ `s ~I - }/ + tw ~ ~ r ~ I - I two- I,r~ - ~ ~ 'Tr ~~ _il ~ i._ C 140 l i' f f +- Fi '~ i-~1 T t- f ~ i 1 r _. 0130 ~-.._~ )'i ~ ~ ~ f+T*' A 1.., _' _.~: X720 -. ~ r ~ r Yt1n ;t 1~ , ' r- , ~~ i Z I , rj- t t~ r -~r 7~ - + ~, ^looo-~ ~ r I liI t. 11 `_ I ~I t+ ~l '-t- y 6700 ~ 900- ~- r _ _ H I 1 ~. ~ 8400 aoo~ ~ 5100.... ~ -...... nn 1~\0 ^R... T ~~~ N s NuG~ by EQ Tl-Y'-lT~ Y-Y1-~-ft f{ ri t T"'-~1 i~ 1~~ 1-1-iT i 1'. ?~T.il alT~ Tflll~lT~IITTF. ~VTTT. T~- 1 .I G-0 I ' G-25 G-25A - ~ ': - - - " -- - ~ T ' 2500 2fi00 2700 2800 2900 r ' i "' - 3000 3100 3200 TI . , rl I I 3300 3400 I I 1 1 1 i l l I ~ 'T T' T T 3500 3600 3700 3800 I I I ITI 1 I fTl I ITI r, rTl I I~I I I ITr l„ I I I I I I I I I ~T T 3900 4000 4100 4200 4300 4400 4w0 4600 4700 4 West(-)/East(+) [100ft/in] 400 Plan: Plan b5 tG-02/Plan 5, G-02B) Crealetl By: BP Dala: 911912008 char.~da: Da,e: conu~i m/omenon Bill Mlcneelson Gell I'J01130t-35]0 B ~XU mn ~~~ceaalson~~~w9.mm tt'Y! ~ ' F, , T • wrF.F. m: rnas AN"fl-COLLI SION SETTINGS cuml nvv ulanas suxver rxoclc nm wF:u.rnru uF:rnus val,. ~ +va *Fa-w wlnmll F:..{II, F.mn~a. Luo•ma.~ x x t/ sw, Lveq,olatiun MelhodMU Interval: SQW ur m..,. Iam~wll„~, m.~Xl~,em ,. w.,lw. IXpm Fm Ucpm'm Survcyrrlm, -I,nll rwll s, c-xzx wxxvzoznoz C:-UE 2612.1.1 1996.5] 596WXfi.U1 b5X2J1.U0 ]U°19'21.9U 1\' IJN°J1'UU.]JUW 02 DUPih RanPc Ft'Um: 10254. Maximum Kangc IUWU. 14 TU: 12200.U0 UU Kcfcrcnce: Plan: Plan NS . ICI ~WRn ,<. i~iilm~ yw„ ~ 1 III]SJ.IJ I?]W.INI rlalmcJ: 1'lun nS V] hiWU ul WeI1paIU: G-U2A r r.•Ul,vu: mzsi.u 1x~F. Nul. W.r b i .Iw..,1 lUx: xel. Uatlunl: 1: U3 ~l]IIYYi W:xx )4.W11 3U1 I I ~ jU ~____-- _-__ -- r.Xvcliou nrixin Orixio Xlerliux nuxle i.Y/-] *F:/-W tram l\'U 293 281 _ -__ - /'_~= - _.. 2v3 ___~- 281 - -~..-\ )U.W° x.W n.W 19.UU 270 25Y ~ ~ 3aU JI/ ,Y \ ~ ~, I ~ LEGEND L 02A (E-02A), Mai or Kisk L 02A1'BI (E-02APH1), Majur Kisk tax ~ _ ]d8 % ~ L 02 (L 021 Majur Klak 236 ~ _ - _,u - ~ ~ ~ ~ -... . ELI (E ?I). Ma3ur Klsk IA) Ma or Kl k LEI IF' 225 ~ )2, C ~/Q O~ ~ Y3j ~C'~ , , j s = L ~ I (E 216), Ma3ur Klsk E 41E 24 Ma ur Ki k 214 203 ~ _ ;I 1 205 ,' 0> 9\ ). 3 s E ]4 jE-~'-4A1. Majur Kl~k E )4 t 24AP81 M Ki k - / ~ ai or s f 1. ~ ' 191 I9i f C~ L li?), M,z)ur Kisk 41t 2~1AI ~ 180 lei/ / `rU L: ~ IE-?413). M,{jur Klsk i ~ E 25 (C 25), Mawr Kmk 169 158 ~ - l09 15s ~l~ - G U2 (G U2 ). Major Kuk G 02 (G OvA), Ma3ur Kisk to ~ ~' y>> u G 25 (G b), Ma3ul Kuk 146 135 -12d _ I G /~ 15 ! 1 ~ ~OY ~ I - - -- G 25 (G 25A), Ma3ol Klsk G 25 (G 2SA1'BI ). Major Klak G 25 (G 2~APB2), Mawr Kisk C. 25 M G b8 Ki k 113 ~ 6~ .1 \ 1, ajur s 1 G 25 (G 2SBI'B I ). Major Kisk 101 if,l G 30 (G-3U). Ma3ur Kuk 0 £6G(I~ C 30 (G-30A), Mu3m Klsk / ~Oy¢ - i G 301G-3066 Major Klsk 79 ~ Y U81Y-UH), Majur Klsk 8 - ~ 6.i Y O81Y-OhA), Ma3o1 Klsk 1 __ Major Kisk I O r 56 /~~3 Y-09 (Y 09A). M. u Nisk 45 ~ tii n I:,IL611 Y-29A (Y-29A) Majur Kisk ~ i. ~ Y-29 (Y ~9) M 3or Kisk 34 d ~ 3~% ~ :. n Y 32 (Y 32) Maur Risk 23 I I ~ ••; Y 32 (Y 32L1). Majur Kisk ~ 'v ~~ ' ~ ~ Plan s. G-o2B I 1 , , , Plan NS 0 '71 -- -- _. __.. __ _ - .f03pp -_-- --- --._ _.. 6hblf {~./u _-- .. .I~,.w~,.r ~„~~v, ~ 23 I I 1 I ~ ... \ I i e. w Ws 34 1 I I ~ I 1. ._ \ \ \ ~ - ~ , ~ u r,, y. I I t I 11 I ~ .~ \ , ~ I \ \ I s6 ~ I ~ ~ ~ ~ ~ ~ `~ZG~11 6x I 1 ~ ~ ~ ~~\ \ ~ ~ ~ ~ ~~ ~ ~ ~ '~ rg 79 ~ I ~ A. ' '~ `~ ~ ~ - e , ~ ~y~ ~, « t~6/, b 101 , . 101 113 It3 124 135 ~ ~ 123 175 aalu/ r 146 .,\ 211 \ Iir, / I?u 158 .. ISS 169 ~v'~1 _ ~~~~ 180 191 ~ ,, / BAKER 2113 n HUSHES ! 214 - .. , j 225 236 248 'S _tr, ''4X INTE(~ 259 vl - '_59 - ~ 50 rcnuv u - ernus -_ _ _ __ _.. _- _.-- -_ _ 270 ,~,I 281 \ '_'; 1 / s„~ mu III. n.I IVU Ivry Il.w Ir'N va.. F I 293 _- ISII \ '_9J ~ ~ 1 1112>J la J2.ii ?J.W _ IU2tlU.W ]i.40 SJ.UII YlN1.211 %9fi)<) Intl%% IIt29X 3RXi fil. 1>US a3 II IY 1 U I JNI I-Y] I-XI U.UII 3N)1,.12 3UI . _- le llrcl-- l IIIi1N1.W ]L 112 <)91 III131)INI tl6.4] fi3!)I 1113WW ){?Y IUlwuNl 9181 %6-14 IILilNIW I?; Il %9], Lfi J RY]]SU %YJS OG I00 JJ IIU+Jtl IIJ]-IS IItlJ-NJ IIY2Y1 III2 4] JT UJfi 1]{?43 1]] SLI 3tlU5 (I0 3Y{]~I 9-W 3U.W 3b9~0U 4U.W 3U.W 3Y`4.23 iUINI 40.1X1 39_i-I] Nlnq _ YI2NI 4U%5 )% , IUfi IU.IX) IW-13 11413 11X113 III IO.IN) J0-IJ t . R9041U %v1,i57 XW-0-13 %95JSI . UIL 42 ItlIJ.R2 JSM.]I ](.5 19 3Y6U JJ 9W].ii 432].]1, 45~4 Itl Iu.Ull YIUNI JI1X%.J% 12.W 1]4W ~Y.31 Il W 2]4W W {SIJ Y~~ 12 Travelling Cylinder Azimuth (TFO+AZI) [d eg] vs Centre to Centre Separ ation [2311/in] i- II,IOIN, i fiaJS I3 IISALNI 90.12 iKUI. la IIO~U IxI %9~N1 30. W. I I%31uNI %YYI IJaI I0 I-WINI 91N ]311 u% Y9t%•~fi _. I %402.2] NYSx u] , )Y%.fiR RBAM1 tU.IM Illlktl I44Y.i11 . 4(21F20 ir, 1Y ae]953 {tl31.U5 . 12~ >~w u.l~n L 2JY.INI iJ31}!o I'_INI iN3X.4{ _ i9(.LS> I_.W _J_W SUa_ fi easurements are trom top of Riser i ~_ of bag of bag le of slips pipes cross middle middle of pipe/slips Blind/Shears 2 3/8" combi ram/slips Mud Cross variable bore pipe 3 1/2"-2 7/8" 2 3/8" combi ram/slips Swab Valve • 1 G-02B BAG TOTs Mud Cross TOTs Flow Tee Page 1 of 1 Maunder, Thomas E (DC>A) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 3:21 PM To: 'Phillips, Ron' Subject: RE: G-02B Thanks Ron. From: Phillips, Ron [mailta:Ron.Phillips@bp.com) Sent: Wednesday, October 15, 2008 3:19 PM To: Maunder, Thomas E (DOA) Subject: RE: G-02B Tom, L~ When going back and looking at the history of H2S tests on G Pad, the highest recorded H2S test was 25ppm and that was taken from well #02. I mistakenly listed Drill Site 02 well #02, when it should have read G Pad well #02. Thanks, Ron Phillips Coil Tubing Drilling Engineer Aiaska Drilling & WeNs Office (907) 564-5913 Cel1(907) 748-7868 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Wednesday, October 15, 2008 2:38 PM To: Phillips, Ron Cc: McMullen, John C Subject: G-026 Ron, I am reviewing the permit application for this well. The H2S information statements says "The maximum recorded N2S level on DS-02is 25 ppm on G-02." Could you decipher this statement for me? Thanks in advance, Tom Maunder, PE AOGCC 10/15/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~~ -~, • • See Township, Range, Section and Acreage? ~` Yes t"` No New Search ~ ~S I~~nu ~ Case. Abstract ~ Case Detail i Land Abstract ~., l~rlc~: '~nT 282'ifl Search for ]tatus Plat lJpd~ates 1 ~,I 1(1;'1 ~'~(ll)ti Ctastonaer~: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1.96612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99~ 196612 Case Ti~pe: t'~3~~~ OIL & GAS LI/ASE COMP DNR Ua-air: 7S0 OIL AND GAS File Locutiura: DOG DIV Oll, AND GAS Case Stcatirs: 35 ISSUED Stataas Date: 08/(9/1965 Total ACa"L'S': 2560.000 Date haitiatecl: 05/28/1965 Office of Prirnaay IZespoarsibility: DOG DN-0IL AND GAS Last Ti~ansactioa~a Date: 12/0/2006 Case Subtype: ~;~ NORTH SLOPE Last Ti~crnsactiora: AA-NRB ASSIGNMENT APPROVED A%~eridian: 'U Toti,ras)ai~~: O1IN R~ua;~~~: 4liE~ Sr~~~ainja.~ (11 Seclinaa .~er~~~~: G~0 S=arch Plats [Ller•idian. l' 7uirtrt~/ar/~: (11 I N I~uja~c~: 1)131; S'cclirua.~ (C ,ti'~c~~i~,ar .l~~r~c~~~: b 1U ~~Ieridiaa~.~ l' 7~,lrn.~~Fai/>: (l l I \ l~ara,~r.~ O13L .5'c~cllrua: 1 1 ~'~~~~ai~,fa _ Ic~rc~~: Ei~U 1C'l7c/Iclf7.' ~! TO1471 <<I1~>.' ~) 1 ~ ~ 1~U1]~~c': ~) ~ ? 1 _ ~Cc"/a/~i7.~ ~ ~ ,~i'L'altl/7 r~('l'~',C: ~~~~) Lebal Desci•ipti~n 0~-28-196 ~~* SALE NOTICE LEGAL DESCRIPTION *** CII-91 TIIN. R13E, UM1, 2, 11, 1?2.~60.00 Oi-0'-195%' TTY`TI.SBI%Rl~'EPARTICIP.-1T1~'~'G:1RF,.1 DF.SCRIPTIOIV ~'k* T 11 N., R. l3 E., U. ill SECTION 1:.<1LL 6=10 ACRES SECTIONN 12: ALL 610 ACRES http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28280... 10/ 15/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~! See Township, Range, Section and Acreage? ~``' Yes fi NO _ New Search i_A`~ Mc~nra i Case Abstract I Case Detail I Land Abstract ~. h~ile: .41)1. 28301 °''>' Search for Status P!ai E_1~clates 1~ cal Illi l x'2005 Custo~;~~~~: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 1 966 1 2/900 E. BLNSON BL ATTN: LAND MANAGER- ALASKA ANCHOKAGE AK 995196612 Case Ty~~e: ~~~~ OIL & GAS LEASE COMP DNR Uj~zit: 780 OIL AND GAS File Locution: DOG DIV OIL AND GAS Case Status: 35 ISSUED Stuti~s Dale: 09/14/1965 Total Acres: 2469.000 Date Initiuleca~ OS/? 8/ 1965 Office of Primar~~ Res/~o~t.cibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype : NORTH SLOPE Last Transaction: AA-NRB ASS IGNME NT APPROVED 1~~~rir~rcn~: 1' ~ Township: O11N l~~m~r: ('11~1E .~~~-~~ti~~r1: OS .Section~lcr~~ . ~ h~(1 Search iii ~~S Urri~/i~nr.~ l' ~ ~~nrjrslu/~: O1 I V' R~rnL=r.~ U I ~I: S'cc~~iott: 06 S`r~~liuir .I ~~r~e~~.~ 593 1j~'T'l[~l~ll1.~ ~ ~~ ~Ull'11,~f11~~: ~) I I ~' ~~[7i1~'C.' I)1-1i~ ~c'CUUI]: O i .~~~'~'llUl1 .~)CI'C~~.~ ~~)t) Llet~rcliun ~ l ! l ~,~iiis/iii>: U I I ~'~ Range: I'l l ~l : ~~~<~tr~~r~.~ ~)~ ti'c~r~i~ur l c~r~~s~: t;-lU Legal Description 0~ -28-196 * * *.S~ LE NUTICE LEUAL DESCRIPTION* C1=~-12~ IIIV 1~{E Ull1 ~, 6, 7, <4 2=169.00 U- 3- 7 Ott ~~ Sum Last updated on 10/15/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=283 04... 10/15/2008 TRA-NSMI1'TAL LE1~I'ER CIiECI{I.IST WELL NAME ,~,~,/,~ G . ~? ~ PTD# v?O~ fS .,.~ Developmeint~ ,_ Service ______ Exploratory Strati ..,_Non-Conventional Well ~phtc Test FIELD: __s~,e~,o,~D~~ Ay POOL: ~.e~.d~/o~ ,oy Oi~ Circle Appropriate Letter /Paragraphs to be Inc[aded in Transmittal better CHECK ~t3-ONS WHAT (OPTIONS) APPLIES TEXT' FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. APJ number are . AP[ No. 50-_ between 6{)-bg) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and APt number (SO--= _~ from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approve! to perforate and ~oducg /,~'niect ;s cont;ngeRt upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur, "" ` "" "" All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the from where samples at+e first caught and IO' sample n~rvals throu ct zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well until after (Comuanv Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. om an „Name must contact the Commission to obtain advance approve! of such water well testing DroQram_ Rev: 1/i 1/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT G-026 Program DEV Well bore seg ^ PTD#:2081580 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal ^ Administraation 1 Pe[mikfeeattached - --------- - - --- --- ~A- ------ -- --- -- -- -------- -- -- 2 Lease number appropriate -- --- --- - --- -- --- Yes ------- -- -- ---- -- -- - - - - 3 Unigt~eweilRame apd number - - - - - - - - - - - - - - - Yes - .. - - - ----------------------------------------------- 4 Welllocakedin_a-definedpool - - ----- - - ----- ---- Yes ------- - -- --- -- - ------ - - - ----------------- 5 WelllocakedDroperdistancef[omdrillingunit_boundary----------------_-_-_ Yes- -------__--_-.---------------------------------------------------____-- 6 Well locatedp[operdisiancefCOmotherwells----------------------------- Yes- ---------------------------------------------------------------------- 7 Sufhcientacreageayailableindtillingunit________------------------- Yes- ------2560aores.__--______--_______.______________-_--_-____ 8 If deviated, isweliborepiat_included_--___------------------------- Yes- ----------------------------------------- -- 9 Opt:[atofOnlyaffectedDarb' -- ----- - - - -- - ------ Yes- -- --- -- - - -- ------------ - - 10 Ope[atorhas_appropriatebondinf4rce---------------------------------- Yes- ------BlanketQond#6194193•---------_------------------------------------------- 11 Permit can beisSUedwj#houtco>tservationorder.-------------------------- Yes- ------------------------------....--------------------------------__---- Appr Date 12 PermikGaDbeissuedwlthoutedmioigt[ali~te_appcov?1---------------------- Yes- ------..-----.-.---------.------------------------------------------- ACS 10/15!2008 13 Can permjt be approved before 15-day_wait - - - - - - - - - - - - - ~ - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 14 WBIIIQCatedwlthinsreaandstr6teauthorizgdby_InjectionOtde[#(pui_IQ#in_comments)-(For_ _NA_- --_------------------___-___-----_-_--------_----------_----_---_--- 15 Allwelis-+K~.hin114_mileareaofreyiewjdentified(forgervicewellonly)_______________ NA__ -___-_---__--__-_-___-__-______-__-____-_-___---__- ---------------------- 16 Pte-producedinje~or,duration_ofpreproductiontessthan3months-(For service well only)_- NA- --------------------_----_--.___._-___-___--___.__-__--__--___-_____ 17 Nonconven,gas-conforms tc AS31.05 030(y1.A),42.A-D) - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorstrirlg_provided----------------------------------------- NA_ ___Conductorset_inG,02_(176,050).---------------------..----------------__--- 19 Surface_cagingproteetsalLknownUSDWs---------------------------- -KA-- ------Surfa~Gasin9setinG-02.-------------------------------------------------- 20 CMT-voladequate to circulate on conductor 8, surfcsg____________________- _NA-- -----_Surface casing set in G-02.____________________________________ _ _-- 21 CMT-voladequateiotie=n long string toss~rfosg_______________--_-________ NA__ ______T'linerset-inG,02Aj195-023),--__________________-__-__--_..-___-_-________-_ 22 CMT-wilicoverali krlownproductivehorizons___________________________ ha_- --_---Sio@edlinercompletionplanned~--____-__-.____-_____--_____-___-_________ 23 Casing designs adequate for C, T B &_ permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _KA_ Anginal well met design spec cations. _ NA for slotted liner._ _ _ _ _ _ - _ _ _ - - - - - _ _ - - - _ - _ _ - - - - _ - - _ 24 Adequate tankage_or reseryepit - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ Yes - - _ - - - -Rig equipped with steel pits, No_niseNe pit planned._ Atl waste_io approved disposalwell(s), - _ - - - 25 Ifa_re-drill,has_a10.403forabandonment been aPRrQved---------------------- Yes- ------308-361--------------------_----------------------------------------- 26 Adequate wellbore separatjonproposed - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - Yes - - _ - - _ _ Proximity anatysis performed, Nearest segment is P$~A portion of G-02A and paths diverge, _ _ _ _ - - _ 21 Ifdiverterrequired,doesittneetregulations__,--------------------------- NA- -_---_@QPStaokwillalreadY-be inplaee._--------------------------------------------- Appr Date 28 Drilling fiuidprogram schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ - Yes _ _ _ _ Maximum expected formation pressere 7,1_EMW: MW piarlned $.$ ppg. - - - - - - - - - - - - - - - - - _ - - - _ - - _ TEM 1011512008 29 BOPls,_dotheymeetregulation-- - - - -- -- ---- -- Yes ------ - -- -- ---- --- - - - --- -- -- - --- 30 BOPf_ptess rating appropriate; lest to-(put prig incomments)- - - _ - - - - _ - Yes MASP calculated at 2354 psi. 3$00-psi_BQP kestplanned. _ _ _ - - - - - - - - - - - - - - - - - 31 Choke-manjfold complies w/API-RP-53 (,May $4)- - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Workvrilloccurwithoptoperationshutdown_________---------------- Yes- ----------------------------------------------------------------.-__ _-- 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Ho- _ Low H2S. is reported at G pad. -Mud_should preclude H2S on rig._ Rig has sensors and alarms. - - - - _ - - _ - - . _ 34 Mechanical condition of wails within AQR verified (For service well onlya - - - - - - - - - - - - -k!A_ _ _ - - _ _ - - - - - - - _ --------- - ---------------------- - ---- - -------------------- Geology 35 Permit can be issued wlo hyd[ogen_ sulfide measures - - - - - - - - - - - - - - No- _ _ - - - _ _ Max level H2S on pad DS,02 is 25ppm forwell G-02._ _ - _ _ _ _ _ _ _ _ - _ _ - - _ _ - _ . - 36 Data_ptesented on potential ovetpretsurezones _ - _ _ - - _ _ - - _ _ _ _ _ _ _ - - . - - KA _ _ _ - _ - - --------------------------------------------------------------- Appr Date 37 Seismicanalyaisofshallowgas_zones__-___-__________________________ NA__ __-______--__-_-_ ACS 10!15/2008 38 Seabed conditionsurvey_(rfoff_-shore)---------------------------------- NA_- _____-_ 39 Contactnamelphoneforweekly_progressrepode[explordtoryoniy]__________._ Yes- .--._-ROnPhiilips-5$4.5913._____________________________________________________ Geologic fngineering Public Commissioner: Date Commissioner Date Date: Commission er: f ' C Welt History File APPENDIX Information of detailed nature that is not s 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. ! • **** REEL HEADER **** MWD 09/01/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/11/03 2281614 Ol 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9476.0000: Starting Depth STOP.FT 12171.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: G-02B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 23.901"N 148 deg 43' 0.740"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 03 Nov 2008 API API NUMBER: 50029202170~.ts'~ Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 74 DMF DF EKB .F 0 EDF .F 74 EGL .F 0 CASE.F N/A OSl DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~~~ -- /5 ~ '~l ~ `~~~~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 22 May 1995 from well G-02A per Roger Sels with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from G-02A through a milled window in a 4.5 inch liner. Top of window 10278 ft.MD (8893.1 ft.TVDSS) Bottom of window 10288 ft.MD (8895.7 ft.TVDSS) (9) Tied to G-02A PDC log at 9531 feet MD (8450.9 feet TVDSS). (10) The interval from 12143 feet to 12171 feet MD (8877.3 feet to 8873.6 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9480.37, 9480.37, ! 0 9482.03, 9482.03, ! 0 9486.38, 9486.18, ! -0.207031 9492.19, 9491.98, ! -0.207031 9495.09, 9494.47, ! -0.62207 9499.86, 9498.82, ! -1.03613 9500.48, 9500.27, ! -0.208008 9502.14, 9501.31, ! -0.829102 9503.59, 9503.17, ! -0.415039 9505.25, 9504.83, ! -0.415039 9510.64, 9509.6, ! -1.03613 9512.71, 9511.67, ! -1.03711 9516.44, 9516.44, ! 0 9523.9, 9523.28, ! -0.621094 9527.22, 9526.39, ! -0.829102 9529.09, 9527.84, ! -1.24316 9531.16, 9530.54, ! -0.62207 9534.68, 9534.27, ! -0.414062 9541.67, 9540.43, ! -1.24316 9549.76, 9549.14, ! -0.62207 9554.94, 9554.32, ! -0.62207 9557.63, 9556.81, ! -0.829102 9564.27, 9563.23, ! -1.03613 9578.07, 9578.07, ! 0 10269.7, 10271.1, ! 1.47461 10271.7, 10273.4, ! 1.65918 10278, 10278, ! 0 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 98 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** • MWD .001 1024 *** LIS COMMENT RECORD *** !!!~~~~~!!!!!!~~!!! Remark File Version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 22 May 1995 from well G-02A per Roger Sels with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 65 Tape File Start Depth = 9476.000000 Tape File End Depth = 12170.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 74 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!~!~~!~~~~~~~!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 129 Tape File Start Depth = 9477.000000 Tape File End Depth = 12170.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 138 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/11/03 2281614 O1 **** REEL TRAILER **** MWD 09/01/12 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 9476.0000 -999.2500 -999.2500 9476.5000 -999.2500 -999.2500 9500.0000 116.4463 -999.2500 9600.0000 -999.2500 -999.2500 9700.0000 -999.2500 -999.2500 9800.0000 -999.2500 -999.2500 9900.0000 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 10100.0000 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 10300.0000 127.4699 22.9391 10400.0000 56.3410 43.2383 10500.0000 60.5016 85.5527 10600.0000 53.2004 87.4602 10700.0000 87.2363 104.8168 10800.0000 142.5375 102.4867 10900.0000 58.5367 107.0805 11000.0000 65.3820 121.2391 11100.0000 71.8754 114.3805 11200.0000 110.4019 115.3621 11300.0000 111.3457 102.5938 11400.0000 77.2867 78.1367 11500.0000 64.7184 111.0582 11600.0000 54.3809 109.0176 11700.0000 103.6203 124.4410 11800.0000 79.4000 109.7594 11900.0000 159.2551 74.5016 12000.0000 80.0375 122.9996 12100.0000 64.2238 100.2383 12170.0000 -999.2500 102.6594 Tape File Start Depth = 9476.000000 Tape File End Depth = 12170.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ~ ~ Tape Subfile 3 is type: LIS DEPTH GR ROP 9477.0000 -999.2500 -999.2500 9477.2500 -999.2500 -999.2500 9500.0000 145.0000 -999.2500 9600.0000 -999.2500 -999.2500 9700.0000 -999.2500 -999.2500 9800.0000 -999.2500 -999.2500 9900.0000 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 10100.0000 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 10300.0000 138.8000 27.5000 10400.0000 59.7000 45.3000 10500.0000 58.9000 97.7000 10600.0000 53.8000 86.4000 10700.0000 95.6000 108.4000 10800.0000 144.7000 90.7000 10900.0000 59.9000 108.3000 11000.0000 62.8000 122.5000 11100.0000 73.0000 114.5000 11200.0000 111.7000 112.6000 11300.0000 105.4000 86.4000 11400.0000 96.6000 100.1000 11500.0000 67.7000 111.5000 11600.0000 52.4000 111.5000 11700.0000 95.2000 123.5000 11800.0000 77.1000 108.2000 11900.0000 171.3000 100.5000 12000.0000 89.5000 122.2000 12100.0000 63.0000 109.7000 12170.0000 -999.2500 101.3000 Tape File Start Depth = 9477.000000 Tape File End Depth = 12170.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
