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186-034
by Date 20-MAY-2015 t-' Transmittal Number: 93426 401 BPXA WELL DATA TRANSMITTAL RE C E W E D Enclosed are the materials listed below. MAY 2 0 2015 (BPXA LOG DATA) AOGCC If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 04-21, 04-22, 04-33, C-01, C-31, L1-09, L2-03, L3-15, L3-31, L4-30, L5-01, L5-15, L5-16A, L5-16AL1, L5-16AL2, L5-31, L5-33, L5-36 04-21 185-212 251' • 04-22 185-233 ay'}45, /L l 04-33 186-035 ,2 5-N(0 Please Sign and Return ne copy of this transmittal to; C-01 172-030 )5441. C-31 188-006 251145 gancpdc@bp.comN L1-09 185-001 254149 L2-03 185-247 .251-54 Doug Dortch L3-15 185-266 25-4.51 Petrotechnical Data Center L3 31 186-034 ,251452 L4-30 188-101 25753. L5-01 189-009 25-1-9-1, Attn: State of Alaska - AOGCC L5-15 188-109 015/55 Attn: Makana Bender L5-16A 206-083 251 5G,• 333 W. 7th Ave, Suite 100 L5 16A L1 206-084 25757. Anchorage, Alaska 99501 SCANNED MAY 2 7 2015 L5-16A L2 206-085 25-158. L5-31 190-130 25151 • L5-33 189-047 250' L5-36 189-036 j5 4(01 • Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 19 2013 1. Operations Performed: AOCCC ❑Abandon ®Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ®Alter Casing ®Pull Tubing ❑Stimulate-Frac ❑Waiver ❑Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 186-034' 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-21544-00-00. 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 028325 • L3-31 • 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): USIT Prudhoe Bay Field/Lisburne Pool ' 11. Present well condition summary: Total depth: measured 12006' feet Plugs:(measured) 11548'(Sand Plug) feet true vertical 9614' feet Junk:(measured) —11564', 11180' feet Effective depth: measured 11829' feet Packer: (measured) 10731', 10906', 11477' feet true vertical 9468' feet Packer: (true vertical) 8576',8712',9174' feet Casing Length Size MD ND Burst Collapse Structural Conductor 102' 20" 102' 102' 1490 470 Surface 4032' 13-3/8" 4032' 3887' 3450 1950 Intermediate 11204' 9-5/8" 11204' 8948' 6870 4760 Production Liner 1020' 7" 10986'-12006' 8774'-9614' 8160 7020 SCAN JAN 2 , Perforation Depth: Measured Depth: 11256'- 11570' feet "��� True Vertical Depth: 8990'-9252' feet Tubing(size,grade,measured and true vertical depth): 3-1/2",9.2#x 2-7/8",6.4#; 13Cr85/13Cr80; 11098'; 8863'; 2-7/8",6.5# L-80 11477'- 11489' 9174'-9184' 9-5/8"x 3-1/2"HES TNT Packer; 10731'; 8576'; Packers and SSSV(type,measured and true vertical depth): 9-5/8"x 5-1/2"Baker S-3 Packer; r ^f8908 -^^�--mow• 8712'; 7"x 2-7/8"Brown I-B Packer 11477' 9174' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Cut and Pull 2-7/8",6.4#, 13Cr80 at 10874', Cut&Pull 9-5/8"Casing from 2256', Run 9-5/8",47#, L-80 Casing Patch Tie-Back to 2259', Cement 9-5/8"Tie-Back w/161 Bbls,Yield 1.18(766 sx) Class'G', Run 3-1/2",9.2#, 13Cr85 Tubing to 10875' 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 0 Subsequent to operation: 0 0 0 550 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic. ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: • IN Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Cody Rymut,564-5452 Email: Cody.Rymut @bp.com 313-470 Printed Nome• Joe La tufc\ Title: Drilling Technologist / /� Signature: Phone: 564-4061 Date: (1 / i q ) 13 Form 10-404 Revi 10/2012 // / I /t 2- /! / / RBDMS NOV w 0 4yn t Original Only L3-31 , Well History (Pre Rig Workover) Date Summary 08/29/13 SET RK-DGLV IN STA#1 (10,805 MD). LRS LOAD TUBING&IA, MIT-IA TO 3500 psi. (PASS). PULLED PX-PLUG BODY FROM 11,056'SLM/11,066'MD. 09/06/13 T/I/O=Vac/640/150.Temp=SI.T&IA FL(S/L request).AL SI @ casing valve,ALP=640 psi.T& IA FL near surface. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1350. 09/07/13 INITIAL T/I/O=0/600/150 PSI. RUN#1: RAN IN&SET HES 2-7/8"FASDRILL COMPOSITE PLUG @ 10970'MID ELEMENT. PERFORMED PASSING MIT-T TO 3500#. RUN#2: RAN IN W/2.125" POWERCUTTER&CUT TBG @ 10874'. GOOD INDICATION ON SURFACE. UNABLE TO PERFORM CMIT-TxIA DUE TO HOURING OUT. FULLBORE WILL RETURN AT LATER DATE TO PERFORM CMIT AND CIRC OUT. FINAL T/I/O=600/600/150 PSI. 09/11/13 T/IA/OA=393/390/133 Temp=SI CMIT-T/IA to 3500 psi(Pre RWO)CMIT-TxIA PASSED to 3500 psi. (2nd attempt) Pumped 13 bbls diesel down tubing to reach test pressure. 1st 15 T/IA lost 25/23 and 2nd 15 min T/IA lost 17/16 for a total T/IA loss of 42/39 in 30 min. Bled back-21 bbls. FWHP=11/63/129. 09/14/13 T/I/0=5/240/115 Temp=S/I Circ out(RWO EXPENSE). Rig up to reverse out skid and PT. 09/15/13 MIT-OA to 2000 psi FAILED 3 attempts(see log). Pumped 5 bbl meth spear,followed by 1085 bbls of seawater to circ-out hydro carbons out of wellbore.Took returns down adjacent L3-23 flowline. Pumped 180 bbls of DSL down IA for FP TBG/IA. Pumped 5 bbls of DSL down surface lines for FP. Pumped 2 bbls of DSL down OA to achieve test pressure of 2000 psi for MIT-OA. OA lost 53 psi in the 1st 15 min and 42 psi in 2nd 15 min for a total pressure loss of 95 psi in 30 min test. Bled OA down to 25 psi, bled back-2 bbls. Bled Tbg and IA down to 300 psi. SV,WV,SSV,AL=closed MV=open IA,OA=otg FWHP 280/280/40 DSO notified of well status on departure. 09/15/13 T/I/O=SSVNAC/51.Temp=SI. MIT-OA to 2000 psi w/Diesel-PASSED. (Pre RWO). OA FL @ surface. Used 3.25 bbls of Diesel to pressure OA from 51 to 2000 psi. OAP decreased 79 psi in 1st 15 min and psi 34 in 2nd 15 min for a total loss of 113 psi in 30 min. Bled OAP from 1883 to 0 psi in 30 min (3.25 bbls).Job Complete. Final WHPs=SSVNAC/0. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP.2330. 09/20/13 T/I/O=SSVNAC/10.Temp=SI.WHPs(Bleed IA&OA to 0 psi.). Bled OAP to 0 psi in 2 min. (bucket,gas).No well house,flowline,or scaffold. Monitored 30 min. OAP increased to 0+psi. Bled back to 0 psi in 1 min. Final WHPs=SSVNAC/0+. SV,WV, SSV=C. MV= LOTO. IA, OA=OTG. 1445. 09/27/13 T/I/O=0/0/0 Conduc PJSM Barriers= IA/OA valve gate. Piggy back IA valve with 3" FMC model 120 Torque flanges and PT'd Pass. Set VR plug in front side OA, remove OA vavle and install blind flange Torque flanges P'd Pass. Piggy back back side OA valve Torque flanges and PT'd pass.. RDMO Job complete. See log for deails. 09/27/13 T/I/O=0/0/0; Set 4-1/16"CIW"H"BPV#282 through tree for Doyon 14 pre-rig. Page 1 of 1 • North America-ALASKA-BP Page 1 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/30/2013 00:00 - 06:00 6.00 MOB P PRE PREPARE AND MOVE RIG OFF WELL. -PJSM. -PREP AND SKID RIG FLOOR TO RIG MOVE POSITION. -MOVE RIG OFF WELL. *NOTIFY PAD OPERATOR TO WITNESS MOVING OFF WELL.WAIVED WITNESS. -STAGE RIG IN MIDDLE OF PAD. -COMPLETE DDI MP2'S WHILE WAITING ON .RIG MOVING SUPPORT. 06:00 - 12 00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -REMOVE RIG MATS FROM AROUND WELL. -SKID RIG BACK TO DRILLING POSITION TO ENCLOSE FLOOR. -INSTALL FRONT BOOSTER WHEELS. -SIGN OFF AND COMPLETE WELL WORK TRANSFER PERMIT WITH DS12 PAD OPERATOR. -MEET UP AND OPEN WELL WORK TRANSFER PERMIT WITH LISBOURNE 3 PAD OPERATOR. -AGREED UPON WELL SITE LEADER OFFICE PLACEMENT WITH SITE SPECIFIC MAP PLACING OFFICE WELL BEYOND THE 300' RED ZONE AREA OF THE RIG WHEN RIG ARRIVES ON WELL 31. **PERFORM SPILL DRILL.GOOD RESPONSE AND PARTICIPATION BY THE CREW.** 12:00 - 18:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. '-REMOVE DRAWWORKS COVER FOR INSPECTION. WELDER WORKING ON RIG HYDRAULIC PUMP SYSTEM AND MUD LINES ON RIG FLOOR. CHANGE ROLLER BEARINGS ON PIPE SKATE RAMP. -WELDER CHANGED 2"VALVE ON CEMENTING LINE MANIFOLD. -INSTALL BRACKETS FOR AIR REEL IN REEL CELLAR. -ELECTRICIAN WORKING ON LIGHTS IN THE PIPE SHED. -SLIDE IN CONVEYOR#2 FOR RIG MOVE. MOB EQUIPMENT TO L-3. 18:00 - 00:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -CLEAN AND CLEAR PIPE SHED. -WORK ON MUD MANIFOLD. -MOB EQUIPMENT TO L-3. -INSTALL AIR REEL IN CELLAR. -REPAIR GUARD ON ST-80. -CLEAN RIG. **PERFORM TABLE TOP MAN DOWN DRILL. GOOD RESPONSE AND PARTICIPATION BY THE CREW.** Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 2 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/1/2013 00:00 - 06:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CLEAN AND CLEAR PIPE SHED. -PAINT,MUD MANIFOLD,DOORS ON RIG FLOOR AND LINES IN PITS. -MOB EQUIPMENT FROM DS-12 TO L3. -CHANGE LIGHT IN DERRICK. -CLEAN SKATE EXTENSION FOR WELDER TO MAKE REPAIRS. -CLEAN RIG. -CHECK PRE-CHARGE ON ACCUMULATOR BOTTLES. -COMPLETE DDI MP2'S WHILE WAITING ON RIG MOVING SUPPORT. **PERFORM SPILL DRILL IN HOPPER ROOM. GOOD RESPONSE AND PARTICIPATION BY THE CREW** 06:00 - 12:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -WELDER ATTACHING HATCHES IN ROCK WASHER. MAINTENANCE ON DRAWWORKS CLUTCH. -CLEAN RIG. PAINT LINES IN PITS. -MOB EQUIPMENT FROM DS-12 TO L3. 12:00 - 18:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CLEAN AND PAINT BOP RISER AND RIG FLOOR MUD MANIFOLD. -MECHANIC/WELDER WORKING ON RIG MOVING SYSTEM. -CONTINUE ROCKWASHER MODIFICATIONS. -WORK ON PIPE SKATE CARRIAGE GUARD. -SEAL GAPS IN PUMP ROOM. MOB EQUIPMENT FROM DS-12 TO L3. 18:00 - 00:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CONTINUE PREP AND PAINTING OF BOP RISERS. -RIG DOWN PIPE SHED BRIDGE CRANE ASSEMBLY. -MOB EQUIPMENT FROM DS-12 TO L3. **TABLE TOP DISCUSSION-DIVERTING SHALLOW GAS" 10/2/2013 00:00 - 06:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CLEAN AND PAINT BOP RISER,HANDRAILS, AND LINES IN PITS. -MOB EQUIPMENT FROM DS-12 TO L3. -CLEAN RIG. -COMPLETE DDI MP2'S WHILE WAITING ON RIG MOVING SUPPORT. 06:00 - 12:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CONTINUE STAGING EQUIPMENT ON L3. -PREP AND PAINT HIGH PRESSURE LINES IN SECOND LEVEL OF PITS. -PLUMB STEAM HEATER BY WATER TANK -LAY RIG MATS ON L3. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 3 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -SERVICE AND INSPECT GREASE LINES FOR DRAWWORKS. INSPECT HYDRAULIC LINES ON PIPE SKATE. -WORK ON ROCKWASHER VACUUM LINE CONNECTIONS. -INSPECT AND SERVICE BOOSTER HYDRAULICS. -SECURE PIPE SHED BRIDGE CRANE FOR RIG MOVE. -INSTALL BRACES FOR STEAM HEATER IN MUD PUMP ROOM. INSTALL GUARD OVER CROWN SAVER ACTUATING RAM. -WORK ON#1 BOILER. -CONTINUE STAGING EQUIPMENT FROM DS-12 TO L3. 18:00 - 00:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -INSTALL PINS ON TOP DRIVE RAILS. -CONTINUE PLUMBING STEAM LINES FOR HEATER IN MUD PUMP ROOM. -WORK ON HYDRAULIC PLUMBING FOR SMALL TUGGER ON RIG FLOOR. -PREP RIG FLOOR WALLS FOR PAINTING. -CLEAN AND PAINT ROOF CAP FOR MUD PUMP ROOM GAP COVER. -CONTINUE WORK ON#1 BOILER. -CONTINUE STAGING EQUIPMENT FROM DS-12 TO L3. 10/3/2013 00:00 - 06:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -CONTINUE PLUMBING STEAM LINES FOR HEATER IN MUD PUMP ROOM. PREP RIG FLOOR WALLS FOR PAINTING. -CONTINUE WORK ON#1 BOILER. -CONTINUE STAGING EQUIPMENT FROM DS-12 TO L3. *RECORDABLE INJURY ASSOCIATED WITH RIG -A CH2 TRUCK DRIVER SUFFERED A FRACTURED TOOTH INJURY WHILE SECURING A LOAD OF RIG MATS ONTO A LOWBOY TRAILER AT 0300 HRS. 2013-I R-4536310. 06:00 - 09:00 3.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -PREP AND PAINT RIG FLOOR WALLS. -CLEAR RAILS FOR SKIDDING RIG FLOOR. -MECHANIC SEALING DRUM CHAIN COVER ON DRAWWORKS. -COMPLETE DDI MP2'S WHILE WAITING ON RIG MOVING SUPPORT. **TABLE TOP DIVERTER DRILL** Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 4 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 11:00 2.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. -BLOW DOWN STEAM AND WATER TO RIG FLOOR. SKID RIG FLOOR TO MOVING POSITION. 11:00 - 12:00 1.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT. -PJSM. INSTALL REAR BOOSTERS. 12:00 - 16:00 4.00 MOB P PRE MOVE FROM DS-12 TO L3. -PJSM ON RIG MOVE FROM DS-12 TO L3 WITH SECURITY. MOVE FROM DS-12 TO PEAK BASE CAMP ON MAT BOARDS. -STAGING EQUIPMENT FROM DS-12 TO L3. *NPT TIME DUE TO NORMALLY TAKING 12 HOURS FORA 8.5 MILE MOVE. 16:00 - 18:00 2.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO LEAP FROG RIG MATS. -PJSM. -MECHANIC SEALING MAIN/LOW DRUM CLUTCH COVERS ON DRAWWORKS. LINE UP AIR TO TEST RUN DRAWWORKS. 18:00 - 00:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO LEAP FROG RIG MATS. -PJSM. -CLEAN SHOP WALLS AND CEILING. -PREP AND CLEAN MUD PUMP ROOM FOR PAINTING. -MOTOR MAN REPAIRING PLUMBING FOR STEAM HEATERS IN MUD PUMP ROOM. **SPILL DRILL** 10/4/2013 00:00 - 10:00 10.00 MOB N WAIT ! PRE WAIT ON RIG MOVE SUPPORT TO LEAP FROG RIG MATS. -PJSM. -CLEAN SHOP WALLS AND CEILING. -PREP,CLEAN AND PAINT MUD PUMP ROOM CEILING. -PJSM ON RIG MOVE FROM PEAK BASE CAMP TO L3. **SPILL DRILL IN PITS** 10:00 - 12:30 2.50 MOB P PRE MOVE FROM PEAK BASE CAMP TO TARMAC ROAD. -PJSM. -RIG MOVE SUPPPORT READY. -MOVE FROM PEAK BASE CAMP TO TARMAC ROAD. -WAIT ON RIG MATS. *NPT TIME DUE TO NORMALLY TAKING 12 HOURS FOR A 8.5 MILE MOVE. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 5 of 29 Operation Summary Report Common Well Name.L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date 10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:ORIG KELLY BUSHING©51.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 00:00 11.50 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO LEAP FROG RIG MATS. -PJSM. -PAINT MUD PUMP ROOM AND 1ROCKWASHER. CHANGE OUT HYDRAULIC OIL FILTERS ON PIPE SKATE. CHANGE VACUUM FITTINGS ON ROCKWASHER. PLUMB STEAM HEATER IN MUD PUMP ROOM. WELDER WORKING ON BREAK TRAILER. 10/5/2013 00:00 - 09:00 9.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO LEAP FROG RIG MATS. -PAINTING MUD PUMP ROOM. CLEAN SHOP WALLS AND CEILING. -STAGE DRILL PIPE ON L3 PAD. **SPILL DRILL;RESPONSE TIME 1:25** 09:00 - 12:00 3.00 MOB P PRE MOVE RIG FROM TARMAC ROAD. -PJSM. -MOVE RIG FROM TARMAC ROAD TO X-15 FLOW LINE ACCESS ROAD. 12:00 - 13:30 1.50 MOB P PRE MOVE RIG FROM X-15 FLOW LINE. -PJSM. -MOVE RIG FROM X-15 FLOW LINE ACCESS ROAD TOWARDS SURF COAT INTERSECTION. -ROAD SHOULDER GAVE WAY. FRONT TIRES BROKE THROUGH ROAD.RIG MOVE HALTED. • 13:30 - 00:00 10.50 MOB N HMAN PRE EXTRACT RIG FROM BROKEN DOWN ROAD SHOULDER. -PJSM -SHIM REAR OF RIG WITH 3 X 12 BOARDS -PLACE COMPOSITE MATS UNDER REAR. -SHIM LEFT FRONT OF RIG WITH 3 X 12 BOARDS AND PLYWOOD. *CODE 8. 10/6/2013 00:00 - 06:30 6.50 MOB N HMAN PRE EXTRACT RIG FROM BROKEN DOWN ROAD SHOULDER. -PJSM. -SHIM REAR OF RIG WITH 3 X 12 BOARDS. -PLACE COMPOSITE MATS UNDER REAR. -SHIM LEFT FRONT OF RIG WITH 3 X 12 BOARDS AND PLYWOOD. *CODE 8. 0630 - 11 00 4.50 MOB N HMAN PRE EXTRACT RIG FROM BROKEN DOWN ROAD SHOULDER. -PJSM WITH THIRD PARTIES. -LATCH CATS TO BACK OF RIG. -REMOVE CRIBBING FROM FRONT AND REAR OF RIG. -BACK RIG OUT OF HOLE AND PARK ON MAT BOARDS. -REMOVE AND LOAD OUT PLYWOOD AND CRIBBING FROM ROAD. *CODE 8. **HOLD FIRE DRILL;RESPONSE TIME 1:15** Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 6 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) I Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisbume I Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UVVI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 13:30 2.50 MOB P PRE MOVE RIG. -PJSM. -MOVE RIG TO DS-4. 13:30 - 20:30 7.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO MOVE RIG MATS. -RIG SUPPORT PLACING RIG MATS FROM DS-4 TO SURF COAT. -RE-INSTALL DRAVWVORKS COVERS. -REMOVE ICE FROM DERRICK AND CLEAN PIPE SHED. MAINTENANCE ON STEAM HEATER IN PUMP ROOM. "CONDUCT SPILL DRILL" 20:30 - 22:30 2.00 MOB N WAIT PRE MOVE RIG FROM DS-4. -PJSM. -MOVE RIG FROM DS-4 TO SURF COAT INTERSECTION. *NPT TIME DUE TO NORMALLY TAKING 12 HOURS FORA8.5 MILE MOVE. 22:30 - 00:00 1.50 MOB N WAIT � PRE WAIT ON RIG MOVE SUPPORT TO MOVE RIG MATS. -PLACE RIG MATS FROM SURF COAT(Y) INTERSECTION TO L3 PAD ON EAST DOCK ROAD. 10/7/2013 00:00 - 06:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO MOVE RIG MATS. -PJSM. -CLEAN IN SHOP. -CONDUCT DERRICK INSPECTION. -COMPLETE DDI MP2'S. II "CONDUCT MAN DOWN DRILL,CAMP FIRE/EVAC DRILL,AND H2S TABLE TOP DRILL** 06:00 - 12:00 6.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO MOVE RIG MATS. -PJSM. CLEAN IN SHOP. -WORK ON PLUMBING ON VAC SYSTEM. -REPAIR DERRICKMAN HEATER IN DERRICK -CHANGE#11 BLADDER ON ACCUMULATOR BOTTLE 12.00 - 12 30 0.50 MOB N WAIT PRE PJSM ON MOVING RIG. -REVIEW"PAD TO PAD"RIG MOVE SOP. -ALL HANDS CLEAR ON DUTIES AND RESPONSIBILITIES. Printed 11/4/2013 10.34.40AM • North America-ALASKA-BP Page 7 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 16:30 4.00 MOB N WAIT PRE MOVE RIG. -CONDUCT WALK AROUND IN WHEEL WELLS PRIOR TO MOVING. -CHECK MOVING SYSTEM. -RAISE BOOSTERS. -MOVE RIG FROM SURF COAT TURN-OFF TO L3 PAD ACCESS ROAD. -ENOUGH MATS ON ROAD TO GET THE RIG TO L3 PAD ASSESS ROAD. -PULL RIG OVER TO LAY MORE MATS. *24 HOUR NOTICE GIVEN TO AOGCC FOR WITNESSING INITIAL BOPE TEST AT 14:00HRS VIA E-MAIL. *NPT TIME DUE TO NORMALLY TAKING 12 HOURS FOR A 8.5 MILE MOVE. 16:30 - 21:30 5.00 MOB N WAIT PRE WAIT ON RIG MOVE SUPPORT TO MOVE RIG MATS. -LAY MATS ALONG L3 PAD ACCESS ROAD. -PJSM ON SLIDING#2 CONVEYOR INTO POSITION. -WORK ON HEATER ABOVE WATER PUMP ROOM 21:30 - 23 00 1.50 MOB N WAIT PRE MOVE RIG. PJSM ON MOVING RIG. -REVIEW"PAD TO PAD"RIG MOVE SOP. -MOVE RIG TO L3 PAD. -ARRIVE ON L3 PAD AT 22:45 HRS. -SET RIG DOWN. *NPT TIME DUE TO NORMALLY TAKING 12 HOURS FOR A 8.5 MILE MOVE. 23'00 - 00'00 1.00 MOB P PRE REMOVE BOOSTERS. -PJSM. -REMOVE REAR BOOSTERS AND SUPPORT FRAME. 10/8/2013 00:00 - 03:00 3.00 MOB P PRE REMOVE BOOSTERS -PJSM -REMOVE REAR AND FRONT BOOSTERS AND SUPPORT FRAME. 03:00 - 07:30 4.50 MOB P PRE MOVE RIG OVER WELL -PJSM -MOVE RIG OVER WELL L3-31 -TEST ESD ON MOVING SYSTEM BEFORE FINAL PLACEMENT. -SHIM UP. 07:30 - 09:00 1.50 MOB P PRE SKID RIG FLOOR INTO DRILLING POSTION -PJSM -REMOVE HECULITE,BRACE AND COVER FOR SERVICE LINES. -PICK UP U-TUBE FOR GAS BUSTER. -SKID RIG FLOOR AND TAKE PICTURES AND MEASURMENTS FOR UPGRADING DRIP PAN/RISER SET UP. -FINISH SKIDDING RIG FLOOR INTO DRILLING POSTION AND SECURE JACKING PINS&RIG FLOOR BRACES. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 8 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date.9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 11:00 2.00 RIGU P DECOMP *ACCEPT RIG AT 09:00 TAKE ON 8.5 PPG 120 DEGREE SEAWATER. -PJSM -CONNECT SERVICE LINES TO RIG FLOOR. -SECURE SUCTION LINES IN THE PITS AND TAKE ON SEAWATER. -PREP MUD PUMPS. -RIG UP HARD LINE CREW TO FLOW BACK TANK. 11:00 - 12:00 1.00 RIGU P DECOMP HELD RIG EVACUATION DRILL -FUNCTION TEST EMERGENCY SHUT DOWN SYSTEM. -HELD AAR DISCUSS WHAT WENT WELLAND WHAT COULD BE IMPROVED. 12:00 - 17:30 5.50 RIGU P DECOMP BRING ON 8.5 PPG SEAWATER INTO PITS. -LAY OUT 3'x12"LUMBER IN CELLAR. -HARDLINE CREW PT TEST FROM CHOKE SKID TO ISOLATION VALVE AT FLOW BACK TANK 250 LOW AND 4000 PSI HIGH FOR 5 MINS-TEST GOOD -SPOT ROCKWASHER INTO POSTION -RIG UP CONVEYOR#2 PIPING -ELECTRICIAN CALIBRATE AND FUNCTION TEST GAS ALARMS -ELECTRICIAN HOOK UP TOP DRIVE CABLES 17:30 - 20:30 3.00 RIGU P DECOMP TEST MUD LINES FROM MUD PUMP TO FLOWBACK TANK -PJSM ON PRESSURE TESTING MUD LINES -PRESSURE TEST LINES FROM MUD PUMP TO FLOWBACK TANK 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -INSPECTED LINES ON TESTING AND FOUND LEAK AT A TEE CONNECTION ON TREE -BLEED DOWN PRESSURE AND BLOW DOWN FLUID T FLOWBACK TANK -CHANGE OUT RUBBER SEAL IN 1502 UNION -RE-TESTED LINES TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH ON CHART.-TEST GOOD -BLEED DOWN PRESSURE TO FLOWBACK TANK AND BLOW LINES DOWN BACK TO FLOWBACK TANK 20:30 - 21:00 0.50 RIGU P DECOMP RIG EVACUATION DRILL -HELD H2S RIG EVACUATION DRILL -HELD AFTER ACTION REVIEW FOR DRILL 21:00 - 00:00 3.00 WHSUR P DECOMP RIG UP AND TEST BACK PRESSURE LUBRICATOR -PJSM WITH CH2MHILU BP AND DOYON -MOBE LUBRICATOR AND QUICK TEST SUB TO RIG FLOOR -MAKE UP CROSSOVER,QUICK TEST SUB, AND LUBRICATOR -CONNECT ASSEMBLY ONTO TREE -PRESSURE TEST ASSEMBLY TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH ON CHART ***SIMOPS-SPOT BREAK TRAILER INTO PLACE AND CONNECT WIRING Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 9 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/9/2013 00:00 - 01:00 1.00 WHSUR P DECOMP PULL BPV -PJSM -PULL BACK PRESSURE VALVE -DISCONNECT LUBRICATOR AT QUICK TEST SUB AND PULL TO RIG FLOOR -SWAP OUT BPV FOR TWO WAY CHECK -RE-INSTALL LUBRICATOR ONTO TREE AND •TEST QUICK TEST CONNECTION 01:00 - 03:30 2.50 WHSUR P DECOMP CIRCULATE OUT FREEZE PROTECT -PJSM -REVISE SOP TO LINE UP WITH CORRECT VALVE NUMBERS ON SOP FOR CIRCULATING WSLAND NIGHT TOUR PUSHER WALKED THRU LINE UP BEFORE STARTING TO CIRCULATE -CIRCULATE 20 BBLS DOWN IA TAKING RETURNS THRU TUBING TO FLOWBACK TANK -SHUT DOWN PUMPS AND SECURE WELLHEAD -LINE UP TO CIRCULATE DOWN TUBING THRU IA -WSL AND TOUR PUSHER WALKED LINE UP AND APPROVED -CIRCULATE 200 BBLS DOWN TUBING THRU IA TO FLOWBACKTANKAT 5 BBUMIN WITH MAX PRESSURE OF 1375 PSI -SHUT DOWN PUMPS AND FLOW CHECK WELL FOR 10 MINUTES-NO FLOW 03:30 - 08:00 4.50 WHSUR P DECOMP SET TWC AND TEST -PJSM -SET TWO WAY CHECK VALVE -TEST FROM BELOW TO 1200 PSI FOR 30 MINUTES ON CHART-GOOD TEST -TEST FROM ABOVE TO 250 LOW/3500 PSI •HIGH FOR 5 MINUTES EACH ON CHART-GOOD TEST -RIG DOWN BACK PRESSURE LUBRICATOR AND LAY DOWN BEAVER SLIDE 08:00 - 09:00 1.00 WHSUR P DECOMP RIG DOWN CIRCULATION MANIFOLD -PJSM -RIG DOWN ALL LINES,T'S,VALVES,AND HOOKUP'S TO WELLHEAD -SIMOPS:LAY DOWN LUBRICATOR AND EXTENSION FOR VALVE CREW,INSTALL NEW PULLY ON#1 CONVEYOR DRIVE END 09:00 - 11:00 2.00 WHSUR P DECOMP NIPPLE DOWN TREE -PJSM -CAMERON VOIDED PRESSURE FROM HANGER,DEMO-ED CONTROL LINE -NIPPLE DOWN TREE AND ADAPTER FROM WELL -REMOVE ADAPTER FROM TREE AND LAID DOWN OUTSIDE OF CELLAR -SIMOPS:LOAD PIPE SHED WITH 4"DRILL PIPE Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 10 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-OOX5W--C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 17:00 6.00 BOPSUR P DECOMP NIPPLE UP 2'SPACER SPOOL TO BOP'S AND NIPPLE UP BOP'S TO WELL -PJSM -HOOK UP BRIDGE CRANE TO STACK AND REMOVE ADAPTER FLANGE FROM STACK -NIPPLE UP BOP'S TO WELLHEAD -MOBE 2 7/8"HANDLING TOOLS TO RIG FLOOR -PREP TEST JOINTS FOR BOP TESTING -CENTER STACK WITH TURNBUCKLES SIMOPS: -ELECTRICIAN STRINGING NEW CABLE FOR CELLAR VIDEO CAMERA -MOTORMAN PLUMBING IN STEAM HEATER ABOVE WATER PUMP ROOM -STRAP AND RABBIT 4"DRILL PIPE IN PIPE SHED 17:00 - 20:00 3.00 BOPSUR P DECOMP PREP FOR BOP TESTING -PJSM -TORQUE UP TEST JOINT EXTENSIONS TO 2 7/8"AND 4"DONUT TEST JOINTS -MAKE UP CROSSOVERS NEEDED FOR TESTING -RAN IN 2 7/8"TEST JOINT WITH DONUT AND MARKED PIPE -FILLED BOP STACK WITH WATER.DUTCH LOCKDOWN SCREWS BEGAN TO LEAK 20:00 - 21:00 1.00 BOPSUR P DECOMP FIX LEAKING LOCKDOWN SCREWS ON DUTCH RISER -SUCK OUT BOP STACK BELOW LEVEL OF LOCK DOWN SCREWS -RESEAL LOCK DOWN SCREWS -FILL BOP STACK TO CHECK-NO LEAKS 21:00 - 23:30 2.50 BOPSUR P DECOMP TEST LOWER VBR'S -HELD KICK WHILE DRILLING DRILL -PRESSURE UP ON LOWER VBR'S WITH 2 7/8" TEST JOINT(DONUT),HAD TO BLEED AIR OUT -BLEEDER VALVE ON MANIFOLD BEGAN LEAKING.BLEED PRESSURE DOWN AND REPLACE BLEEDER NEEDLE VALVE. -PRESSURED UP AGAIN ON LOWER VBR'S -PRESSURE BLEEDING BY THE RAMS.BLEED OFF PRESSURE AND FUNCTIONED THE VBR'S.PRESSURE UP AND PRESSURE HELD. -BLEED OFF PRESSURE AND BEGIN TESTING PROCEDURES AS PER DOYON PROCEDURES -AIR PUMPS ON KOOMEY WOULD NOT AUTOMATICALLY STOP AT PRE-SET POINT. MECHANIC INSPECTED ACCUMULATOR AIR SHUT OFF VALVE AND FOUND IT BAD. MECHANIC LEFT TO LOCATE PARTS AND/OR REPLACEMENT. 23:30 - 00.00 0.50 BOPSUR N RREP DECOMP REPAIR AIR SUPPLY SHUT OFF VALVE ON BOP ACCUMULATOR AIR SUPPLY FOR AIR PUMPS 10/10/2013 00:00 - 01:30 1.50 BOPSUR N RREP DECOMP MECHANIC WORK ON REPAIR OF AIR SUPPLY SHUT OFF VALVE FOR AIR PUMPS ON BOP ACCUMULATOR. Printed 11/4/2013 10.34:40AM • North America-ALASKA-BP Page 11 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 13:30 12.00 BOPSUR P DECOMP TEST BOP'S TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH ON CHART -TEST WITH 2 7/8"AND 4"TEST JOINT (DO-NUT TEST JOINTS) -2 7/8"X 5"VBR'S INSTALLED ON LOWER AND UPPER PIPE RAMS -ALL TEST CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WAIVED BY AOGCC REP JOHN CRISP 10/8/2013 -PERFORMED KOOMEY DRAW-DOWN TEST AS PER DOYON SOP'S 13:30 - 16:00 2.50 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT -PJSM RIG DOWN TEST EQUIPMENT -BLOW DOWN CHOKE/KILL LINES -RIG DOWN CROSSOVERS ON TEST JOINTS RIG DOWN FOSV'S RIG DOWN TOP DRIVE CONNECTIONS 16:00 - 19:00 3.00 BOPSUR P DECOMP RIG UP DSM LUBRICATOR -PJSM ON BEAVER SLIDE OPS MOBILIZE DUTCH RISER TO RIG FLOOR -MOBILIZE LUBRICATOR TO RIG FLOOR •-RIG UP AND TEST DUTCH RISER AND LUBRICATOR 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH 19:00 - 20:00 1.00 BOPSUR P DECOMP PULL TWC -0 PSI ON TUBING -PULL TWC TO RIG FLOOR -MONITOR WELL -RIG DOWN LUBRICATOR AND DUTCH RISER 20:00 - 21:00 1.00 PULL P DECOMP RIG UP TO PULL 2 7/8"COMPLETION TUBING -MOBILIZE SHORT ELEVATOR LINKS TO RIG FLOOR -PICK UP CONTROL LINE SPOOLING UNIT TO RIG FLOOR AND SET IN PLACE -PICK UP BAKER SPEAR ASSEMBLY TO RIG FLOOR 21:00 - 23:00 2.00 PULL P DECOMP PULL TUBING HANGER TO FLOOR -PJSM ON MAKING UP SPEAR ASSEMBLY -MAKE UP SPEAR ASSEMBLY ON 1 JOINT OF 4"DRILL PIPE -RUN IN HOLE WITH SPEAR ASSEMBLY AND ENGAGE BELOW HANGER -CAMERON REP BACKED OUT LOCK DOWN SCREWS FOR HANGER -PULL ON HANGER AND HANGER CAME FREE AT 105K(55K PLUS TOP DRIVE WT OF 50K)) -PULL HANGER TO RIG FLOOR -TERMINATE CONTROL LINE AT 1 JOINT BELOW HANGER -DIS-ENGAGE SPEAR AND LAY DOWN SPEAR AND DRILL PIPE -BREAK OUT HANGER AND PUP JOINT BELOW HANGER AND LAY DOWN RIG UP TO CIRCULATE THRU MUD GAS SEPARATOR Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 12 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 PULL P DECOMP CIRCULATE BOTTOMS UP THRU CHOKE -SHUT IN ANNULAR ON TUBING -CIRCULATE THRU OPEN CHOKE AND THRU GAS BUSTER AT 5.5 BBLS/MINUTE @ 1470 PSI (TOTAL CIRCULATION=750 BBLS) SIM-OPS:DRY RUN ON PICKING UP ULTRA-HGH-TORQUE TONGS TO SEE IF THEY FIT THRU NEW BEAVER SLIDE DOORS WITH SKID MOUNTED TO TONGS. 10/11/2013 00:00 - 02:00 2.00 PULL P DECOMP CIRCULATE BOTTOMS UP THRU CHOKE -SHUT IN ANNULAR ON TUBING -CIRCULATE THRU OPEN CHOKE AND THRU GAS BUSTER AT 5.5 BBLS/MINUTE @ 1470 PSI (TOTAL CIRCULATION=750 BBLS) -10 MINUTE FLOW CHECK SIM-OPS:DRY RUN ON PICKING UP ULTRA-HGH-TORQUE TONGS TO SEE IF THEY FIT THRU NEW BEAVER SLIDE DOORS WITH SKID MOUNTED TO TONGS. 02:00 - 03:30 1.50 PULL P DECOMP RIG DOWN FROM CIRCULATING -PJSM -SHUT DOWN PUMPS -OPEN BAG -FLOWCHECK WELL -BLOW DOWN CHOKE LINE,MANIFOLD AND CEMENT LINE -MAKE UP FLOOR VALVE FOR LANDING TUBING 03:30 - 20:00 16.50 PULL P DECOMP PULL TUBING OUT OF HOLE -PULL OUT OF HOLE ON ELEVATORS FROM 10,874'TO SURFACE -PULL 338 FULL JOINTS OF 2 7/8",6.4 13CR-80 TUBING PLUS 3.38'CUT JOINT ALONG WITH SSSV NIPPLE,3 EA GAS LIFT MANDRELS, AND X-NIPPLE. -RECOVERED 69 OF 73 DOCUMENTED SS CONTROL LINE BANDS -HELD KICK WHILE TRIPPING DRILL WITH BP REPS ALONG WITH AAR 20:00 - 21:30 1.50 PULL P DECOMP CLEAR RIG FLOOR OF TONGS AND TOOLS -PJSM -CLEAN UP TUBING TOOLS -BREAK DOWN CROSSOVER FOR SAFETY VALVE -LAY DOWN TUBING TONGS AND CLEAR RIG FLOOR 21:30 - 23:00 1.50 PULL P DECOMP MOBE BHA TO RIG FLOOR -PJSM -BRING BAKER BHA UP TO RIG FLOOR TO DRESS OF TUBING STUB 23:00 - 23:30 0.50 WHSUR P DECOMP INSTALL WEAR BUSHING -LENGTH-10.5,ID-12.25",OD-13.375" 23:30 - 00:00 0.50 PULL P DECOMP PICK UP AND MAKE UP 2 7/8"TUBING STUB DRESS-OFF/9 5/8"CASING SCRAPER BHA -PJSM -PICK UP AND MAKE UP DRESS OFF ASSEMBLY Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 13 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/12/2013 00:00 - 02:30 2.50 PULL P DECOMP PICK UP AND MAKE UP 2 7/8"TUBING STUB DRESS-OFF/9 5/8"CASING SCRAPER BHA -PJSM -PICK UP AND MAKE UP DRESS OFF ASSEMBLY 02:30 - 04:00 1.50 PULL P DECOMP RIG SERVICE -SERVICE BLOCKS,TOP DRIVE AND DRAW WORKS -PUMP OIL INTO GEAR END AND INTO HYDRAULIC UNIT OF TOP DRIVE -ATTACH SAFETY WIRE TO FILL CAP 04:00 - 12:00 8.00 FISH P DECOMP RUN IN HOLE WITH 2 7/8"TUBING DRESS OFF/9 5/8"CASING SCRAPER BHA -PJSM -RIH FROM 338'TO 7586',PICKING UP SINGLES FROM PIPE SHED 12:00 - 12:30 0.50 FISH P DECOMP RIG SERVICE -GREASE DRAWWORKS AND IRON ROUGHNECK 12:30 - 15:30 3.00 FISH P DECOMP RUN IN HOLE WITH 2 7/8"TUBING DRESS OFF/9 5/8"CASING SCRAPER BHA -RIH FROM 7586'TO 10,814',PICKING UP SINGLES FROM PIPE SHED 15:30 - 16:00 0.50 FISH P DECOMP ESTABLISH PARAMETERS -OBTAIN SLOW PUMP RATES:#1 20 SPM=80 PSI,30 SPM=160 PSI #2 20 SPM=80 PSI,30 SPM=160 PSI @ 8.5 PPG FLUID(SEAWATER) -ESTABLISH SO/PU WEIGHTS:S/O 170K,P/U 220K,ROT 192K @ 50 RPM AND 6K TORQUE 16:00 - 16:30 0.50 FISH P DECOMP TAG AND DRESS OFF TUBING STUB -RIH AT 100 SPM ON PUMPS WITH 1400 PSI, 55 RPMS -RIH FROM 10814'TO 10883'(TAG STUB) -CLEAN OFF STUMP AT 10883'WITH 2-3 WOB, 50 RPM AND 6-7K TORQUE.DRESS OFF STUMP DOWN TO 10895'(12'SWALLOW) -TURN OFF ROTATION AND PUMPS.WORK STRING THRU STUMP WITH NO PROBLEMS 16:30 - 18:00 1.50 FISH P DECOMP CIRC HI-VIS SWEEP AROUND -PUMP 40 BBL HI-VIS SWEEP AROUND AT 10 BBL/MIN AT 1340 PSI. -WORK STRING MILL ACROSS PACKER DEPTH OF 10785'. -WORK STRING 65'WITH 50 RPM AND 5K ON TORQUE -SWEEP CAME BACK CLEAN,TURN OFF PUMPS 18:00 - 18:30 0.50 FISH P DECOMP FLOWCHECK WELL -10 MINUTE FLOWCHECK-WELL STATIC -BLOW DOWN TOP DRIVE. -LINE UP ON TRIP TANK -INSTALL STRIPPING RUBBER AND AIR SLIPS 18:30 - 19:30 1.00 FISH P DECOMP PULL OUT OF HOLE WITH CLEANOUT BHA -PJSM -POOH FROM 10839'TO 6919' -RACK BACK ALL STANDS(42 STANDS) 19:30 - 21:30 2.00 FISH P DECOMP SLIP AND CUT DRILL LINE -PJSM -SERVICE CROWN,IRON ROUGHNECK, DRAW WORKS,AND TOP DRIVE -SLIP AND CUT DRILL LINE-59.5' Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 14 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C.(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21.30 - 22:00 0.50 FISH P DECOMP PJSM ON LAYING DOWN DRILL PIPE 22:00 - 00:00 2.00 FISH P DECOMP PULL OUT OF HOLE -POOH FROM 6919'TO 3775',1X1 -LAY DOWN DRILL PIPE INTO PIPE SHED 10/13/2013 00:00 - 02:30 2.50 FISH P DECOMP PULL OUT OF HOLE -POOH FROM 3775'TO 275,1X1 -LAY DOWN DRILL PIPE INTO PIPE SHED 02:30 - 03:30 1.00 FISH P DECOMP LAY DOWN DRILL COLLARS -PJSM -LAY DOWN 6 EA.6.25"DRILL COLLARS DUE TO DOUBLE STACK BIG TONGS WILL BE NEEDING ROOM ON RIG FLOOR. -LAY DOWN COLLARS TO PIPE SHED 03:30 - 05:00 1.50 FISH P DECOMP LAY DOWN BHA -PJSM -PICK UP BHA -BREAK APART BHA AND LAY DOWN ON RIG FLOOR 05:00 - 05:30 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR -PJSM -CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS 05:30 - 10:00 4.50 FISH N WAIT DECOMP WAIT ON E-LINE -WAIT ON E-LINE TO MOBE OUT DIFFERENT UNIT DUE TO RADIATOR LEAK ON UNIT ON LOCATION(ALL CONTAINED,NO LEAK TO GROUND). 10:00 - 12:30 2.50 FISH P DECOMP RIG UP E-LINE -PJSM -BRING E-LINE TOOLS AND LUBRICATOR UP BEAVERSLIDE -RIG UP LOGGING EQUIPMENT -TEST TOOLS 12:30 - 19:00 6.50 FISH P DECOMP PERFORM USIT LOG -RIH WITH E-LINE TO 5000' -LOG FROM 5000'TO SURFACE IN CORROSION/CEMENT MODE -MAKE SECONDARY PASS -CHECK FOR VALID DATA 19:00 - 20:00 1.00 FISH P DECOMP RIG DOWN E-LINE -PJSM -RIG DOWN E-LINE EQUIPMENT FROM FLOOR -LAY DOWN E-LINE TO GROUND THRU BEAVERSLIDE 20:00 - 21:00 1.00 WHSUR P DECOMP PULL WEAR BUSHING -PJSM -PULL WEAR BUSHING -SET UPPER TEST PLUG TO TEST RAMS WHEN INSTALLED 21:00 - 23.30 2.50 BOPSUR P DECOMP CHANGE UPPER PIPE RAMS TO 9 5/8"SOLID RAMS -PJSM -CLOSE BLIND/SHEAR RAMS -REMOVE 2 7/8"X 5"VBR'S -INSTALL 9 5/8"SOLID RAMS IN UPPER RAMS Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 15 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23.30 - 00:00 0.50 BOPSUR P DECOMP TEST UPPER RAMS -PJSM -INSTALL 9 5/8"TEST JOINT AND RIG UP TO TEST TOP RAMS -TEST 9 5/8"SOLID BODY RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES ON CHART. 10/14/2013 00:00 - 01:00 1.00 BOPSUR P DECOMP RIG DOWN FROM TESTING BOP'S -PJSM -PULL 9 5/8"TEST JOINT -BACK OUT LOCK DOWN SCREWS -PULL TEST PLUG -INSTALL WEAR RING 01:00 - 01:30 0.50 FISH P DECOMP RIG UP TO RUN HES RETRIEVABLE BRIDGE PLUG -PJSM -CHANGE OUT ELEVATORS TO 4" -MOBE HALLIBURTON TOOLS AND BRIDGE PLUG TO RIG FLOOR 01:30 - 03:00 1.50 FISH P DECOMP RIH WITH HES BRIDGE PLUG -PJSM -MAKE UP HALLIBURTON 9 5/8"RETRIEVABLE BRIDGE PLUG AS PER HES REP -RUN IN HOLE WITH BRIDGE PLUG ON 4" DRILL PIPE FROM SURFACE TO 2350' • 03:00 - 03:30 0.50 FISH P DECOMP SET BRIDGE PLUG -SET DEPTH AT BREAK ON EVEN STAND -TRIP IN HOLE TO 2350'(CENTER OF ELEMENT)AND SET BRIDGE PLUG AS PER HES REP -POOH 15'AND CONFIRM SETTING OF BRIDGE PLUG AS PER REP -9 5/8"RETRIEVABLE BRIDGE PLUG SET AT 2350'(CENTER OF ELEMENT)WITH TOP OF PLUG AT 2345' 03:30 - 06:00 2.50 FISH P DECOMP LINE UP AND TEST BRIDGE PLUG -PJSM -FLUID PACK LINES -LINE UP CHOKE MANIFOLD AND TEST MANIFOLD TO TEST BRIDGE PLUG -TEST BRIDGE PLUG TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH ON CHART -BRING UP SAND TO RIG FLOOR AND SET UP TO DUMP SAND ON TOP OF PLUG. -POOH WITH 2 STANDS OF DRILL PIPE 06:00 - 10:00 4.00 FISH P DECOMP DUMP SAND ON TOP OF RETRIEVABLE BRIDGE PLUG -PJSM -BRING HOPPER AND SAND UP TO RIG FLOOR THRU BEAVERSLIDE -RIG UP HOPPER TO DUMP SAND -DUMP 2200 LBS OF RIVER SAND ON TOP OF RETRIEVABLE BRIDGE PLUG **SIMOPS: -PJSM -MOBE 14"DOUBLESTACK UHT TONGS TO RIG FLOOR AND ASSEMBLE FOR CASING DEMO. Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 16 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth i Phase Description of Operations (hr) (usft) • 10:00 - 10:30 0.50 FISH P ( DECOMP TAG SAND -RUN IN HOLE AND TAG SAND AT 2306'(43'OF • SAND) 10:30 - 11:30 I 1.00 FISH P DECOMP POOH WITH RBP SET TOOL -- i -PJSM -POOH FROM 2306'TO SURFACE -LAY DOWN HALLIBURTON RBP SETTING TOOL 11:30 - 12:30 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS -MOBE BAKER CUTTER TO RIG FLOOR -LATCH UP TO ONE STAND OF DRILL PIPE -MAKE UP BAKER MULTISTRING CUTTER BHA 12:30 - 13:00 0.50 FISH P DECOMP RUN IN HOLE WITH MULTI-STRING CUTTER -RUN IN HOLE FROM SURFACE TO 860' -TAGGED UP AT 860' ***NOTIFIED AOGCC WITH INTENT TO TEST BOPS AT 12:55 PM VIA WEB NOTIFICATIONS NOTIFIED WITH REQUESTED TIME AT 18:00 ON 10/15/2013. 13:00 - 13:30 0.50 FISH P DECOMP POOH WITH MULTI-STRING CUTTER -POOH DUE TO NOTABLE TO GET PAST 860' -POOH TO CHECK KNIVES 13:30 - 14:00 0.50 ,'FISH P DECOMP CHANGE KNIVES ON MULTI-STRING CUTTER -EXAMINED KNIVES AND FOUND 1 KNIFE DAMAGED -CHANGED OUT ALL KNIVES AND PINS ON MULTI-STRING CUTTER 14:00 - 15:00 1.00 FISH P DECOMP RUN IN HOLE WITH MULTI-STRING CUTTER -RUN IN HOLE FROM SURFACE TO 2251' -TAG COLLAR AT 2251' -PICK UP SINGLE JOINT OF DRILL PIPE 15:00 - 16:00 1.00 FISH P DECOMP FIND COLLARS AND CUT DEPTH 1-TAG COLLAR AT 2251' -RIH AND TAG SAND AT 2290' -POOH AND SET AT 2256'FOR CUTTING CASING 16:00 - 17:30 1.50 FISH P DECOMP CUT CASING -PJSM -LIL RED SERVICES TEST LINES TO 250/3500 FOR PUMPING OPERATIONS -POSITION CUTTERS AT 2256' • -PUMP 7 BBUMIN,AT 80 RPM ROTATION AND TORQUE AT 3-4K -CUT CASING ***AOGCC REP JEFF TURKINGTON REPLIED WITH WAIVING TEST WITNESS AT 17:06PM ON 10/14/2013 17:30 - 18:30 1.00 FISH P DECOMP ATTEMPT TO ESTABLISH CIRCULATION TO VERIFY CASING CUT -CLOSE BAG,OPEN OA TO SLOP TANK -BRING MUDPUMPS UP TO 2000 PSI WHILE WATCHING OA PRESSURE -NO FLOW,NO PRESSURE ON OA -BLEED OFF PRESSURE,VERIFY PRESSURE BLED OFF OF WELL i -OPEN BAG AND SHUT OA Printed 11/4/2013 10 34:40AM • North America-ALASKA-BP Page 17 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:00 0.50 FISH P DECOMP CUT CASING -FIND CUT AT 2256'AND POSITION KNIVES -BRING PUMPS UP TO 7 BBL/MIN AT 85 PSI -CUT ON CASING AGAIN FOR 3 MINUTES UNTIL PRESSURE DROPPED TO 500 PSI -TORQUE DROPPED TO 1K -SHUT DOWN,CLOSE BAG AND OPEN OA TO SLOP TANK -BRING PUMPS UP TO 350 PSI WITH RETURNS TO SLOP TANK -SHUT DOWN PUMPS AND BLEED PRESSURE OFF OF WELL -SHUT OA AND BLOW DOWN ALL OUTSIDE LINES 19:00 - 20:00 1.00 FISH P DECOMP RIG UP TO DISPLACE ARCTIC PACK -PJSM WITH ALL CREWS -RIG UP ON WELL WITH FOSV AND CEMENT LINE AND VERIFY LINEUP TO SLOP TANK 20:00 - 00:00 4.00 FISH P DECOMP CIRCULATE OUT ARCTIC PACK -LIL RED SERVICES PUMP 23 BBLS DIESEL DOWN DRILL PIPE-SHUT DOWN -SHUT IN WELL ON ANNULAR BAG AND OPENED UP OA TO SLOP TANK -LRS PUMP 80 BBLS HEATED DIESEL DOWN DRILLPIPE @ 2BPM,MAX PRESSURE 650 PSI -PUMP 23 BBLS DEEPCLEAN SOAP PIL DOWN DRILL PIPE @ 2 BPM MAX PRESSURE 500 PSI -LET DIESEL SOAK INTO OA FOR 1 HR -PUMP DOWN REMAINDER OF DEEP CLEAN SOAP PILL -LINE UP ON 9.8 BRINE TRUCK AND PUMPED 9.8 BRINE AT 2 BPM UNTIL DEEP CLEAN SEEN AT SLOP TANK 10/15/2013 00:00 02:00 2.00 FISH P DECOMP CIRCULATE OUT ARCTIC PACK -PJSM -PUMP 9.8 BRINE DOWN DRILL PIPE,TAKING RETURNS BACK THRU OA TO FLOW BACK TANK -PUMP 8.5 PPG SEAWATER TO DISPLACE OA FROM 9.8 BRINE TO 8.5 SEAWATER -FLOWCHECK WELL -OPEN BAG -PUMP ACROSS TOP OF WELL TO CLEAN UP DIESEL THAT HAD MIGRATED TO TOP OF 9 5/8"CASING "HELD SPILL DRILL AT 01:45 HRS** 02:00 - 03:00 1.00 FISH P DECOMP PULL OUT OF HOLE WITH MULTI-STRING CUTTER -POOH FROM 2250'TO SURFACE -LAY DOWN SINGLE TO HANDLE CASING ,CUTTER BHA 03:00 - 04:00 1.00 FISH P DECOMP BREAK DOWN MULTI-STRING CUTTER BHA -PJSM -BREAK DOWN BHA AND LAY DOWN ON RIG FLOOR -CLEAN AND CLEAR RIG FLOOR OF CUTTER BHA AND EQUIPMENT Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 18 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM 1Rig Release:10/22/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (u ) 04:00 05:00 1.00 FISH P DECOMP 1MAKE UP BHA FOR SPEARING CASING 1-PJSM -REMOVE WEAR RING- -PICKUP 1 JOINT DRILL PIPE,CROSSOVER, •SPEAR ASSEMBLY -MAKE UP SAFETY JOINT -ENGAGE SPEAR,SET DOWN 10K,PULL 10K, THEN SET DOWN 10K 05:00 - 06:00 1.00 FISH P DECOMP PULL 9-5/8"CASING FREE -WITH SPEAR ENGAGED,CAMERON REP BACK OUT LOCK DOWN SCREWS -CASING PULLED FREE AT 190K,PULLED AT 145K FOR 10' 06:00 - 07:30 1.50 FISH P DECOMP CIRCULATE HOLE CLEAN. -PJSM. -CLOSE ANNULAR -PUMP 130 BBLS SEAWATER AT 8 BPM WITH 560 PSI TAKING RETURNS TO FLOW BACK TANK. -FLOW CHECK FOR 10 MINS.-NO FLOW. -BLOW DOWN LINES IN CELLAR TO FLOW BACK TANK. 07:30 - 08:00 0.50 FISH P DECOMP PULL HANGER. -PJSM. -PULL HANGER TO RIG FLOOR. -BREAK DOWN 4"JOINT,XO AND SPEAR ASSY 08:00 - 12:00 4.00 FISH P DECOMP PULL AND LAY DOWN 9-5/8"CASING. -PJSM. -RIG UP CASING TONGS AND HANDLING EQUIPMENT. -BACK OUT CASING HANGER AND LAY DOWN SAME. -POOH AND LAY DOWN 9-5/8"CASING F/2249' 1 TO CUT JOINT • '51 JOINTS RETRIEVED AND CUT JOINT (FLARE ON CUT JT= 9-3/4") 12:00 - 14:30 2.50 CLEAN P DECOMP CLEAN RIG FLOOR EQUIPMENT OF ARCTIC PAC. -CLEAN CASING STACK TONGS,SLIPS AND ELEVATORS. -CLEAN DRIP PAN. -POWER WASH RIG TRACTION MATS. -REMOVE HANGER,CENTRALIZER AND CUT JOINT FROM RIG FLOOR. 14:30 - 15:00 0.50 CLEAN P DECOMP INSTALL WEAR BUSHING. -PJSM. -DRAIN STACK. -INSTALL WEAR RING. `WEAR RING=12-1/4"ID 15:00 - 18:00 3.00 CLEAN P DECOMP PICKUP AND MAKE UP DRESS OFF BHA. -MOB DRESS OFF SHOE/SCRAPER BHA COMPONENTS TO RIG FLOOR. -MU AND RIH WITH 12-1/8"x 9-5/8"DRESS OFF SHOE,13-3/8"CASING SCRAPER,FLOAT SUB, BUMPER SUB,OIL JARS AND DRILL COLLARS TO 237'. Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 19 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date 10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. I UWI• Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 19:30 1.50 CLEAN i P DECOMP RUN IN HOLE WITH DRESS OFF BHA. -RIH WITH DRESS OFF BHA F/237'TO 2231' -OBTAIN PARAMETERS "SLOW PUMP RATES AT 2231'-20 SPM AT 30 PSI,30 SPM AT 50 PSI. 'PUW--97K LBS,SOW-97K LBS,RTW-100,50 RPM W/TORQ 2-3K LBS. 19:30 - 20:30 1.00 CLEAN P DECOMP DRESS OFF 9-5/8"CASING STUMP. -TAG TOP OF 9-5/8"CASING STUMP AT 2256'. -WORK MILL DOWN TO 2263'WITH OVER SHOT. -DRESS 9-5/8"CASING STUMP,PUMPING 6 BPM WITH 130 PSI,50 RPM,WOB 2-3K,TORQ 2-3K. 20:30 - 21:30 1.00 CLEAN P DECOMP CIRCULATE WELL CLEAN. -PUMP 40 BBL DEEP CLEAN SWEEP AND CIRC SAME OUT AT 15 BPM W/850 PSI WHILE RECIPROCATING STRING. -FLOW CHECK WELL FOR 10 MINS.-NO FLOW. -BLOW DOWN TOP DRIVE. -LINE UP ON TRIP TANK. 21.30 - 00:00 2.50 CLEAN P DECOMP POOH WITH DRESS OFF BHA -POOH WITH DRESS OFF BHA F/2256'TO 310' -10 MIN FLOW CHECK BEFORE PULLING NON-SHEARABLES ACROSS THE STACK-NO I FLOW. i-STAND BACK DRILL COLLARS AND LD DRESS OFF BHA. -CLEAN AND CLEAR RIG FLOOR OF BHA 10/16/2013 00:00 - 01:00 I 1.00 WHSUR P DECOMP PULL WEAR RING -PJSM - ------------- -- -RU,PULL WEAR RING AND LD SAME 01:00 - 02:00 1.00 BOPSUR P DECOMP FLUSH STACK -RU AND FLUSH STACK ""HELD D5 WELL KILL DRILL." 02:00 - 14:30 12.50 BOPSUR P DECOMP TEST BOPE -PJSM. -TEST GAS ALARMS. -PERFORM DERRICK INSPECTION. -RU 3-1/2"TEST ASSY. -TEST LPR,HCR KILL,MANIFOLD VALVES#1, 12,13,14,AND ANNULAR TO 250/3500 PSI FOR 5 CHARTED MINS EACH. -PERFORM ACCUMULATOR DRAW-DOWN. -RD 3-1/2"TEST ASSY. -RU 4"TEST ASSY. -TEST LPR TO 250/3500 PSI FOR 5 CHARTED MINS.EACH. -RD 4"TEST ASSY. -RU 9-5/8"TEST ASSY. -TEST MANUAL IBOP,MANIFOLD VALVES#9, 11,5,8,10,4,6,7,2,3,MANUAL CHOKE AND i KILL,HCR CHOKE,2-FOSV,DART VALVE,UPR AND BLIND RAMS TO 250/3500 PSI FOR 5 CHARTED MINS EACH. -RD 9-5/8"TEST ASSY. -BLOW DOWN TOP DRIVE,CHOKE,KILL 'LINES AND CHOKE MANIFOLD. •1-FAILURE-HYDRAULIC OIL DRIPPING OUT OF WEEP HOLE ON UPPER PIPE RAM WHILE ACTUATING. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 20 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor DOYON DRILLING INC. UN: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 22:00 7.50 BOPSUR N RREP DECOMP REPAIR RAM DOOR SEALS ON UPPER RAMS. -HYDRAULIC OIL DRIPPING OUT OF WEEP HOLE ON UPPER PIPE RAM WHILE ACTUATING. -PJSM. -PULL MOUSE HOLE. -REMOVE 9-5/8"FIXED RAM. -PREP UPPER RAM OPERATOR FOR REMOVAL. -MONITOR IA EVERY 30 MINS. -PULL OPERATOR TO REPAIR SEALS AT SHOP. -RIG MECH AND HYDRILL REP REPAIRED SEALS IN UPPER RAM OPERATOR. '-PJSM. -INSTALL OPERATOR. -TEST UPR TO 250/3500 PSI FOR 5 CHARTED MIN. -RD 9-5/8"TEST ASSY. 22:00 - 00:00 2.00 CASREP P INTERV PREP RIG FLOOR FOR RUNNING 9-5/8" CASING PATCH. -LD SHORT BAILS,WEAR RING AND RUNNING TOOL. -PU LONG BAILS,CENTRALIZER AND CEMENT HEAD. • 10/17/2013 00:00 - 02:30 2.50 CASREP P INTERV RIG UP TO RUN 9-5/8"CASING PATCH TIE BACK. -PJSM. -MOB 53 CRENTRALIZERS TO RIG FLOOR. -RU TORO TURNS,CASING ELEVATORS AND SLIPS. 02:30 - 08:00 5.50 CASREP P INTERV RUN 9-5/8"CASING PATCH TIE BACK. -MU AND RIH W/9-5/8"47#L-80 HYD 563 CASING,CASING PATCH,EXTERNAL CASING PACKER AND ES CEMENTER TO 2257'. -OBTAIN PARAMETERS-PUW=142K, SOW=145K -RU 5'PUP JOINT W/1 JOINT OF 4"DP AND XO'S TO ALLOW ROTATING OF CASING OVER STUMP. -ATTEMPT TO RUN CASING PATCH OVER STUMP. DID NOT TAG STUMP. -LD 5'PUP DOWN AND PU 10'PUP. -LOWERED CASING PATCH DOWN OVER STUMP WITHOUT ROTATING. -SET DOWN 30K ON STUMP. -PULL 150K OVER PULL TO INSURE PATCH SET. Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 21 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 11:00 3.00 CASREP P INTERV SET EXTERNAL CASING PACKER AND RIG UP TO PUMP CEMENT JOB. -PJSM. -MU PUP JOINT,CEMENT HEAD XO,CEMENT HEAD AND LINE,PULL UP 250K ON CASING STRING(100K OVER) -TEST CEMENT LINE TO 3000 PSI. -OPEN CEMENT HEAD AND TEST 9-5/8" CASING T/1000 PSI FOR 5 CHARTED MINS. -BRING PSI TO 1200 FOR 1 MIN. -BRING PSI TO 1400 FOR 1 MIN. -BRING PSI TO 1500 FOR 1 MIN. -BRING PSI TO 1700-PACKER INFLATED AND A LOSS OF 100 PSI WAS SEEN. -BRING PSI TO 2000 AND HOLD FOR 10 MIN.- TOOK 3.2 BBLS. -BLEED OF PRESSURE-2-1/4 BBLS RETURNED. -CLOSE ANNULAR AND PRESSURE UP TO 2700 PSI. -BRING PSI TO 3000 TO OPEN ES CEMENTER -TOOK 3.4 BBLS. -BLEED OFF PRESSURE-3 BBLS RETURNED. -CONFIRM ZERO PSI UNDER ANNULAR AND •OPENED ANNULAR. *MANUAL CHOKE AND KILL LINE VALVES ARE CLOSED* 11:00 - 13:30 2.50 CASREP P INTERV CIRCULATE WELL BORE FLUID TO WARM WELL. -CIRCULATE 100 DEG.9.5 SEA WATER AT 5 BPM W/130 PSI UNTIL RETURN TEMP IS 70 DEG. -TEST LINE FROM RIG TO CHOKE SKID TO 2500 PSI. 13:30 - 14:00 0.50 CASREP P INTERV PRESSURE TEST SLB CEMENT LINES. -PJSM W/SLB AND CREW. -PUMP 10 BBLS OF FRESH WATER TO WARM LINES. -PRESSURE TEST CEMENT LINES TO 250/4000 PSI. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 22 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.Oousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 CASREP P INTERV MIX AND PUMP CEMENT JOB. -MIX AND PUMP 161 BBLS OF CLASS G CEMENT+.200 GPS D-47,.800%BWOC D-65, 1.5 GPS D-600G,.200%BWOC D-167,.230 GPS D-186,MIXED WITH 5.298 GPS FRESH WATER AT 15.8 PPG WITH YIELD OF 1.18 CUFT/S K. -DROP ES CEMENTER CLOSER PLUG AND CHASED SAME WITH 10 BBLS FRESH WATER AT 5 BPM WITH 150 PSI. -SHUT DOWN SLB CEMENT PUMPS AND LINE UP TO RIG. -DISPLACE CEMENT WITH RIG PUMPS AT 8 BPM W/880 PSI. -PUMP 141 BBLS OF SEA WATER. *CAUGHT CEMENT 64 BBLS AWAY. -SLOWED PUMPS TO 2 BPM W/940 PSI. '-PUMP 12.5 BBLS OF SEAWATER AND PLUG BUMPED. -PRESSURE UP TO 2000 PSI *ES CEMENTER CLOSED AT 1780 PSI. -HELD 2000 PSI FOR 2 MINS. -BLEED PRESSURE OFF. •*1.6 BBLS RETURNED. •-OPEN CEMENT HEAD TO SURFACE AND MONITOR 9-5/8"CASING AND IA FOR FLOW. *WELL STATIC* *TOTAL OF 31 BBLS OF CEMENT RETURNED TO FLOWBACK TANK LEAVING 130 BBLS IN WELLBORE. -SET SLIPS AND RD CEMENT HEAD. -LATCH UP TO 9-5/8"CASING AND MAINTAIN 100K OVER PULL. -FLUSH HARD LINE W/BLACK WATER. 16:00 - 00:00 8.00 WHSUR P INTERV CUT 9-5/8"CASING AND INSTALL TUBING SPOOL. -PJSM. -EVACUATE BOP STACK AND 9-5/8"CASING OF FLUID.. -WORK ANNULAR AND FLUSH W/WATER. -ND BOPS. -HOOK UP BRIDGE CRANES,LOOSEN TURN BUCKLES AND RISER AND PULL FLOW LINE. -RD TUBING SPOOL AND SPACER SPOOL. -CAMERON REPS RIG UP WACH CUTTER AND CUT 9-5/8"CASING. -RD PUP JOINTS AND XOs FOR CEMENT HEAD. -CUT 9-5/8"CASING AND LD 28.66'CUT JOINT. -PULL RISER AND SET TUBING SPOOL ON EMERGENCY SLIPS. -STAND BACK BOP STACK -REMOVE OLD TUBING SPOOL AND INSTALL NEW TUBING SPOOL. •-SET STACK ON TUBING SPOOL TO SLIP OVER SEALS. -TIGHTEN SPOOL DOWN EVENLY W/BOP BOLTS. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 23 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/18/2013 00:00 - 03:00 3.00 WHSUR P INTERV INSTALL TUBING SPOOL -NU NEW TUBING SPOOL -FILL PORT WITH PLASTIC PAC -TEST VOID TO 250/3500 FOR 5 CHARTED MINS EACH. -INSTALL PIGGY BACK VALVE ON IA AND TEST SAME TO 250/3500 FOR 5 CHARTED MINS EACH -STAB AND NU BOPS 03:00 - 06:00 3.00 WHSUR P WHDTRE CHANGE AND TEST UPPER RAMS -PJSM -CHANGE UPPER RAMS FROM 9-5/8"FIXED RAMS TO 2-7/8"x 5"VBR. -NU RISER,FLOW LINE,HOLE FILL LINE, 'BLEED OFF LINE AND INSTALL ENVIRO WRAP IN DRIP PAN. 06:00 - 09:30 3.50 WHSUR P WHDTRE TEST UPPER PIPE RAMS -PJSM -RU AND TEST 2-7/8"x 5"UPPER PIPE RAMS ON 3-1/2"AND 4"TEST ASSY TO 250/3500 PSI FOR 5 CHARTED MINS EACH. -TEST BREAK ON BOPS TO 250/3500 PSI FOR 5 CHARTED MINS EACH. -RD 3-1/2"AND 4"TEST ASSY. -INSTALL WEAR BUSHING *WEAR BUSHING ID=9-1/8",OD=13-3/8"AND LENGTH=10-1/2" 09:30 - 15:00 5.50 CLEAN P CLEAN DRILL OUT SHOE-TRACK -PJSM -PU,MU AND RIH WITH 8-1/2"ROCK BIT,7" BOOT BASKETS,6-1/4"BUMPER SUB,6-1/4" OIL JARS AND 2-STDS OF DRILL COLLARS, ON 4"DP TO 2133'. -OBTAIN PARAMETERS *PUW=92K,SOW=95K,RTW=95K,RPM= 60,TORQ=1-2K,PUMP RATE=6 BPM WITH 300 PSI *SPR=#1 MUD PUMP:20 SPM AT 30 PSI,30 SPM AT 70 PSI #2 MUD PUMP:20 SPM AT 40 PSI,30 SPM AT 70 PSI -RIH AND TAG PLUG AT 2212' -DRILL OUT SHOE TRACK FROM 2212'TO 2215'. 'PUMP RATE=6 BPM WITH 300 PSI,WOB= 3-5K,RPM=50,TORQ=2-4K -WASH FROM 2215'TO 2300' -PUMP 40 BBL HI-VIS SWEEP AND CIRC SAME OUT AT 8 BPM WITH 400 PSI,WHILE WORKING STRING -RIH AND TAG TOP OF SAND AT 2305' 15:00 - 16:00 1.00 CLEAN P CLEAN POOH WITH 8-1/2"DRILLING ASSY -PJSM -10 MIN FLOW CHECK.—WELL STATIC. -INSTALL STRIPPING RUBBER AND POOH WITH 8-1/2"DRILLING ASSY FROM 2305'TO 310'. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 24 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 17:00 1.00 CLEAN P CLEAN LD 8-1/2"DRILLING ASSY -PJSM -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE STACK —WELL STATIC. -POOH AND LD 8-1/2"DRILLING ASSY. 17:00 - 21:00 4.00 CLEAN P CLEAN RIH WITH RCJB/9-5/8"SCRAPER ASSY -PJSM -MOB RCJB ASSY TO RIG FLOOR -MU AND RIH WITH 7-7/8"RCJB,4-BOOT BASKETS,9-5/8"SCRAPER,6-1/4"BUMPER SUB,6-1/4"OIL JARS AND 2-STDS OF DRILL COLLARS ON 4"DP TO 2237'. -OBTAIN PARAMETERS '`PUW=96K,SOW=96K,RTW=96K,RPM= 35,FREE TORQ=500,PUMP RATE=11 BPM WITH 1600 PSI 'SPR=#1 MUD PUMP:20 SPM AT 30 PSI,30 SPM AT 70 PSI #2 MUD PUMP:20 SPM AT 40 PSI,30 SPM AT 70 PSI -DROP 1"BALL *BALL ON SEAT AT 100 STROKES •-RIH,PUMPING 1 BPM WITH 30 PSI AND TAG TOP OF SAND AT 2305' -PICK UP 10'FROM TOP OF SAND. -WASH AND REAM FROM 2295'TO 2311'. 'PUMP RATE=11 BPM WITH 1600 PSI,RPM= 35,TORQ=3-5K,WOB=3-5K -PICK UP FROM 2311'TO 2267'. -CIRC BOTTOMS UP AT 11 BPM WITH 1600 PSI. -10 MIN FLOW CHECK.—WELL STATIC. "D1 KICK WHILE TRIPPING DRILL AND AAR** 50 SEC TO SECURE WELL. 21:00 - 00:00 3.00 CLEAN P CLEAN POOH WITH RCJB/9-5/8"SCRAPER ASSY -POOH FROM 2267'TO 310'. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE STACK —WELL STATIC. -POOH FROM 310'TO RCJB. -CLEAN OUT AND INSPECT RCJB AND BOOT BASKETS *RECOVERED 5-LARGE PIECES OF ALUMINUM(LARGEST BEING 3-1/2"x 3-1/2"), 2.5 GALS OF SAND,ALUMINUM SHAVINGS AND RUBBER. 10/19/2013 00:00 - 00:30 0.50 CLEAN P CLEAN LUBRICATE RIG -SERVICE TOP DRIVE AND CROWN Printed 11/4/2013 10:34:40AM North America-ALASKA-BP Page 25 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:OOAM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 04:00 3.50 j CLEAN P CLEAN RIH WITH RCJB/9-5/8"SCRAPER ASSY -RIH AND TAG TOP OF SAND AT 2314'. —OBTAIN PARAMETERS *PUW=96K,SOW=96K,RTW=95K,RPM= 35,FREE TORQ=500,PUMP RATE=11 BPM WITH 1640 PSI *SPR=#1 MUD PUMP:20 SPM AT 70 PSI,30 SPM AT 120 PSI #2 MUD PUMP:20 SPM AT 70 PSI,30 SPM AT 120 PSI -WASH AND REAM FROM 2314'TO 2321'. -PICK UP TO 2237' -CIRC BOTTOMS UP AT 11 BPM WITH 1640 PSI. -10 MIN FLOW CHECK.—WELL STATIC. I-BLOW DOWN TOP DRIVE. 04:00 - 05:00 1.00 CLEAN P CLEAN 1-POOH FROM 2237'TO 240'. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE STACK —WELL STATIC. -POOH FROM 240'TO RCJB. -CLEAN OUT AND INSPECT RCJB AND BOOT BASKETS *RECOVERED HAND FULL OF 1-2"PIECIES OF ALUMINUM. 05:00 - 07:00 2.00 CLEAN P CLEAN RIH WITH RCJB/9-5/8"SCRAPER ASSY -RIH AND TAG TOP OF SAND AT 2324'. -OBTAIN PARAMETERS *PUW=96K,SOW=96K,RTW=96K,RPM= 20,FREE TORQ=0-1K,PUMP RATE=10 BPM WITH 1340 PSI. -WASH AND REAM TO 2334' *SPILL DRILL. 07:00 - 08:30 1.50 CLEAN P CLEAN POOH FROM 2334'TO 240'. -10 MIN FLOW CHECK. -BLOW DOWN TOP DRIVE. -POOH TO 240'. 08:30 - 12:00 3.50 CLEAN P CLEAN LAY DOWN BHA. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE STACK —WELL STATIC. -RACK BACK DRILL COLLARS. -CLEAN OUT JUNK HEAD AND BASKETS- FOUND TO BE EMPTY. -LD ALL COMPONENTS FOR BHA. -RUN DRILL COLLARS INTO MOUSE HOLE AND LD TO PIPE SHED. 12:00 - 14:00 2.00 TIEBAC P OTHCMP PRESSURE TEST CASING. -PURGE CHOKE,KILL LINES AND CHOKE MANIFOLD. -TEST 9-5/8"CASING TO 3620 PSI FOR 30 CHARTED MINS PRESSURE BLED DOWN TO 3585 PSI. -CONFIRMED PASSING TEST RESULTS WITH WTLAND GIVEN PERMISSION TO PROCEED WITH OPERATIONS. -OPEN BLINDS,CHOKE AND KILL HCRs. -BLOW DOWN CHOKE,KILL LINES AND CHOKE MANIFOLD. Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 26 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X4-00X5W C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 ■ Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Data From-To I Hrs I Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 15:30 1.50 DHB P INTERV RUN IN HOLE TO RETRIEVE RBP. -PJSM W/HALLIBURTON REP ON MAKING UP 'RBP RETRIEVAL TOOL. -MU TOOL AND RIH TO 2200'. 15:30 - 17:00 1.50 DHB P INTERV CUT AND SLIP DRILLING LINE. -INSTALL FOSV. -PJSM. -CUT 59.5'OF DRILLING LINE. -SERVICE TOP DRIVE,BLOCKS AND CROWN. -PULL FOSV. -RIH TO 2295' 17:00 - 19:00 2.00 DHB P INTERV RETRIEVE RBP. -WASH DOWN TO 2348' -PUMP A 30 BBL HIGH VIS SWEEP AROUND TO SURFACE AND SHUT BAG. -SET 5K LBS DOWN,PULL 10K OVER,SET 5K BACK DOWN ON RBP,PULL 10K OVER AND MARK PIPE,SET 20K DOWN AND TURN 1/4 TURN TO THE RIGHT,PULL 10K OVER W/ MARK ON PIPE AT 6"ABOVE SETTING DEPTH. -OPEN BYPASS W/NO PRESSURE ON CHOKE. -PULLED RELEASE 20K OVER. -BRING UP ANOTHER 5'. -PUMP BOTTOMS UP THRU CHOKE. -FLOW CHECK THRU GAS BUSTER AT 2300'- WELL STATIC. -BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD. 19:00 - 00:00 5.00 DHB P INTERV POOH AND LAY DOWN RBP. -POOH F/2300'TO 17'LAYING DOWN DP TO PIPE SHED. -LD RBP AND RETRIEVAL TOOL. -RIH WITH DP FROM DERRICK W/STACK WASHER F/3"TO 1630' -POOH LAYING DOWN DP TO PIPE SHED F/ 1630'TO 3" 10/20/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP LUBRICATE RIG -SERVICE TOP DRIVE AND DRAWVVORKS. 00:30 - 03:30 3.00 RUNCOM P RUNCMP RIG UP TO RUN 3-1/2"COMPLETION. -PULL WEAR RING. -MAKE DUMMY RUN WITH LANDING JOINT AND HANGER. -CHANGE FROM SHORT BAILS TO LONG BAILS. -MOBILIZE TORO TURN TONGS AND COMPENSATOR TO RIG FLOOR THEN RIG UP TO RUN. -INSTALL STABBING BOARD IN DERRICK 03:30 - 00:00 20.50 RUNCOM P RUNCMP RUN 3-1/2"9.2#13CR-85 VAM TOP COMPLETION. -PJSM. -RIH WI 3-1/2"COMPLETION STRING TO 8689'. 10/21/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP LUBRICATE RIG -SERVICE TOP DRIVE AND DRAWWORKS. Printed 11/4/2013 10:34.40AM • North America-ALASKA-BP Page 27 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X400X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 07:00 6.50 RUNCOM P RUNCMP RUN 3-1/2"9.2#13CR-85 VAM TOP COMPLETION. -OBTAIN PARAMETERS. *PUW=130K,SOW=110K -RIH W/3-1/2"COMPLETION STRING USING TORQ TURN TONGS AND COMPENSATOR.F/ 8689'TO 10875'. -SPACE OUT AND LAND TUBING HANGER. *BOTTOM OF OVER SHOT=10875",NO-GO 3' ABOVE STUMP AT 10862'WITH 10'OF SWALLOW. 07:00 - 11:30 4.50 RUNCOM P RUNCMP 'REVERSE CIRCULATE CORROSION INHIBITOR. -RUN IN LOCK DOWN SCREW AND TORQ TO 500FT/LBS. 'LDS MEASURE 3-1/2" -LD LANDING JOINT AND RU TO REVERSE CIRCULATE. -CLOSE BLIND RAMS. -REVERSE CIRCULATE 80 BBL OF 120 DEG. SEA WATER FOLLOWED BY 700 BBLS MI KL-3869 CORROSION INHIBITOR @ 5 BPM WITH 730 PSI. 11:30 - 12:00 0.50 RUNCOM P RUNCMP DROP BALL AND ROD. -CHECK FOR PRESSURE BELOW BLINDS. OPEN BLIND RAMS. -INSTALL LANDING JOINT. -DROP BALL AND ROD. -LD LANDING JOINT. -CLOSE BLINDS. 12:00 - 13:30 1.50 RUNCOM P RUNCMP ATTEMPT TO SEAT BALL AND ROD. -PJSM. -PUMP 8 BBLS SEAWATER DOWN TUBING, TAKING RETURNS UP IA. BALL AND ROD NOT ON SEAT -LINE UP AND PUMP 8 BBLS SEAWATER DOWN IA AT 4 BPM AT 350 PSI -LINE UP AND PUMP 10 BBLS SEAWATER DOWN TUBING AT UP TO 8 BPM AND UP TO 785 PSI,ROCKING PUMP TO ATTEMPT TO SEAT BALL AND ROD.NO SUCCESS. -CHECK FOR PRESSURE BELOW BLINDS. OPEN BLIND RAMS. -NOTIFY TOWN AND DISCUSSED PLAN FORWARD. 13:30 - 14:30 1.00 RUNCOM P RUNCMP ATTEMPT TO SEAT BALL AND ROD. -PJSM -MU LANDING JT TO TOP OF HANGER. -CAMERON BACK OUT LDS -PU COMPLETION STRING 4'AND RECIPROCATE SAME,ATTEMPTING TO WORK BALL AND ROD ON SEAT. -LAND HANGER AND CAMERON RUN IN LDS. -REMOVE LANDING JT. -CLOSE BLIND RAMS. -LINE UP AND PUMP DOWN TUBING, ROCKING PUMP AT UP TO 8 BPM AND UP TO 800 PSI,TAKING RETURNS UP IA, ATTEMPTING TO WORK BALL AND ROD ON SEAT. NO SUCCESS. *PUMP 10 BBLS TOTAL Printed 11/4/2013 10:34:40AM • North America-ALASKA-BP Page 28 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(1/VO) Start Date:9/30/2013 End Date:10/22/2013 1X4-00X5VV-C:(3,370,000.00) Project:Lisbume Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©51.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 17:00 2.50 DHB P RUNCMP SET AND TEST TWC -PJSM -INSTALL TWC WITH DRY ROD. -TEST TWC FROM BELOW TO 1000 PSI AND FROM ABOVE TO 3500 PSI FOR 10 CHARTED 1 MINS EACH. LEAK TIGHT TEST. -PJSM -BLOW DOWN CHOKE/KILL LINES,CHOKE MANIFOLD,BLEED OFF LINE AND HOLE FILL LINE. 17:00 - 20:30 3.50 BOPSUR P RUNCMP CHANGE UPPER PIPE RAMS AND ND BOPS -PJSM -CHANGE UPPER PIPE RAMS FROM 2-7/8"x 5" VBR TO 3-1/2"x 6"VBR. -ND BOPS. 20:30 - 00:00 3.50 WHSUR P RUNCMP INSTALL ADAPTER FLANGE AND DRY HOLE TREE. -PJSM. -NU 13-5/8"x 4.1/8"5M ADAPTER FLANGE. -TEST TUBING HANGER VOID AND SEALS TO 250/5000 PSI FOR 30 CHARTED MINS. -NU 4-1/8"5M DRY HOLE TREE. 10/22/2013 00:00 - 01:00 1.00 WHSUR P RUNCMP NU DRY HOLE TREE AND TEST SAME. -PJSM. -NU 41/8"5M DRY HOLE TREE. -TEST DRY HOLE TREE TO 250/5000 PSI FOR 1 _ i 5 CHARTED MINS EACH. 01:00 - 03:00 2.00 WHSUR P RUNCMP PULL TWC -PJSM -PU,MU AND TEST DSM LUBRICATOR TO 250/ 1 3000 PSI FOR 5 MINS EACH. LEAK TIGHT TEST. -PULL TWC. ir -LD DSM LUBRICATOR AND TWC. 03:00 - 08:30 5.50 WHSUR P RUNCMP FREEZE PROTECT -PJSM. -RU LITTLE RED SERVICE LINE TO IA. -RU JUMPER LINES TO TUBING,FOR U-TUBE OF FREEZE PROTECT. -ATTEMPT TO PRESSURE TEST LITTLE RED SERVICE LINES TO 250/3500 PSI FOR 5 MINS EACH. "OUTER VALVE ON IA LEAKING AT STEM. -CHANGE OUT OUTER IA VALVE. -PRESSURE TEST LITTLE RED SERVICE LINES TO 250/3500 PSI FOR 5 MINS EACH. 08:30 - 11:00 2.50 WHSUR P RUNCMP FREEZE PROTECT -PUMP 160 BBLS DIESEL FREEZE PROTECT DOWN IA AT 2 BBLS/MIN WITH 260 PSI. -ALLOW 1 HR FOR U-TUBE. Printed 11/4/2013 10 34:40AM • North America-ALASKA-BP Page 29 of 29 Operation Summary Report Common Well Name:L3-31 AFE No Event Type:WORKOVER(WO) Start Date:9/30/2013 End Date:10/22/2013 X400X5W-C:(3,370,000.00) Project:Lisburne Site:Lis DS 03 Rig Name/No.:DOYON 14 Spud Date/Time:2/11/1986 12:00:00AM Rig Release:10/22/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @51.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 15:30 4.50 WHSUR P RUNCMP INSTALL AND TEST BPV. -PJSM. -RIG UP AND INSTALL BPV. -TEST BPV WITH LITTLE RED SERVICES FROM BELOW TO 250/1000 PSI FOR 10 CHARTED MINS. *TEST BPV WITH DIESEL.TOOK 2.8 BBLS TO PRESSURE UP.BLED BACK 2.8 BBLS. -RD LITTLE RED SERVICES. -INSTALL JEWELRY ON TREE. -SECURE TREE AND CELLAR. *RELEASE RIG AT 15:30 HRS. Printed 11/4/2013 10:34:40AM L3-31 , Well History (Post Rig Workover) Date Summary 10/27/13 T/I/O=BPV/0/0 Conduct PJSM barriers=BPV and MV Remove temp SV#12 Install CIW 4"upper tree torque flanges. RU ciw lubricator w 4"h type pulling tool PT'd lubricator and upper tree against MV to 300/5000 PSI for 5 min pass. RIH and pull BPV#142. Barriers= IA/OA valve gate. RD IA/OA piggy back valves and install tapped blind flanges and torque to specs PT'd both to 2500 PSI pass. 11/04/13 PULLED B&R FROM 10761' SLM. RAN 10x1-3/4"PUMP BAILER TO 10764'SLM (recover 1 gallon of possible pipe dope). 11/05/13 MADE SEVERAL BAILER RUNS TO 10788-98'SLM (recovered aprox 15 gallons of rubber material). 11/06/13 MADE MULTIPLE BAILER RUN 10804-10816' SLM.ATTEMPTED TO PULL HRC PLUG BODY. RAN 2.805'G-RING TO 10731'SLM (UNABLE TO WORK PAST). 11/07/13 MADE MULTIPLE PUMP BAILER RUNS TO 10816'SLM (recovered 5 gallons of rubber material). 11/08/13 RAN 2.75" LIB TO 10815'SLM (circle impression unknown). RAN OVER SHOT TO 10815' SLM (recover sta#3 circ_valve). RAN 3-1/2" GR TO 10815'SLM (unable to latch rhc). MADE SEVERAL PUMP BAILER RUNS. 11/09/13 MADE THREE PUMP BAILER RUNS TO RHC @10821'SLM. PULLED RHC FROM 10841'MD SET SSC @ 5339' SLM. SET STA#3 RK-DGLV @ 5272' SLM (5289' MD). PULL SSC FROM 5339' SLM. RAN 2.805"G-RING, 3 1/2" BLB, BRUSH X-NIP @ 10,757'MD. SET 3 1/2" P-BODY @ 10,740' SLM (10,757' MD). SET P-PRONG @10736'SLM. LRS PERFORMED PASS MIT-IA AND MIT-T(see Irs log). 11/09/13 T/I/O=2/0/0 Temp=Sl Assist Slickline(Post RWO work) MIT-T to 3500 psi (PASSED) MIT-IA to 3500 psi. (PASSED) Pumped 1.7 bbls meth down tubing to verify SSL plug set. Pumped 1 bbls of meth down tubing to establish MIT-T to 3500. 1st 15 min Tbg lost 85 psi. 2nd 15 min Tbg lost 30 psi fora total loss of 115 psi in a 30 min test. Bled back— .6 bbls. Rig up to IA for MIT-IA. Pumped 9.2 bbls 50*crude down IA to reach test pressure. 1st 15 min IA lost 60 psi. 2nd 15 min IA lost 22 psi for a total loss of 82 psi in 30 min. Blede back—7 bbls. Valve positions upon departure: SV WV SSV=closed MV IA OA=open. FWH PS=1500/500/0. 11/12/13 PULL P-PRONG FROM 10,728'SLM. PULL 3 1/2" PLUG BODY FROM 10,735' SLM (10,757' MD). RAN 2.20"CENT,2.0" LIB TO 10831'SLM (no impression). 11/13/13 CTU 9 w/1.75"CT. Scope; Mill Composite Plug. Rig up. Function test BOPs PT BOPs. 11/14/13 CTU 9 w/1.75"CT. Scope: FCO+ Mill Composite Plug. MU MHA-pull test- PT, Standby for Weather, Return to unit and clear snow. 11/15/13 MU 1.75"JSN FCO BHA. (OAL= 11.25') RIH, Dry tag fill at 10889'-Clean Out- 10887'Tag Hard(5 times)- POOH-MU BOT ctc(1.75"x.29'), DBPV(1.7"x1.51'), FAU Disconnect(1.69"x1.36'),XO (1.69"x.49'),Venturi .25"Jet Full Mule Shoe(1.69"x7.64')-OAL= 12.21'-RIH-Tag 10902-3 times- POOH. LD venturi, recovered 1 tbls of debis packed in baskets. MU 1.75" DJN BHA(OAL= 14.45'). RIH. Dry tag at 10946' (Mech counter showed 10983').Attempt to clean out,could not make progress. Hard repreatable set downs w/clean PU. Suspect we are on CBP at 10970'. Wash plug and POOH chasing sweep. Page 1 of 2 L3-31 , Well History (Post Rig Workover) Date Summary 11/16/13 POOH. FP coil and well to 250'. LD FCO BHA, center nozzle jet plugged with piece of composite plug. Cut pipe. MU BTT milling BHA w/2.30"burn shoe(OAL=23.16'). RIH-Tag CBP @ 10,970'-Milled Pushed down to XN @ 11,066'- POOH -BD BTT BHA- RD lnj/Lub-Test BOPs. Change packoffs. MU BTT Mtr+2.18" mill. RIH bullheading 60/40 McOH down backside. 11/17/13 RIH bullheading 20 bbls 60/40 McOH down backside.Work through 2-7/8"stub at 10873'. Dry tag plug at 11063'. Push plug debris down hole.Worked plug through lower tailpipe @ 11493'. Pushed plug to 11564'CTM. POOH and FP coil. Page 2 of 2 • N O a) 0) co a M C o N O C O O O (a p)O C a c a — = a) a L C a N CO CO H O LIC LC) Q U CO a O O N C CO 0 v 0 cc) c a) O co X a) a o m m Li r a) L W 0 0 L.,_ 0 a a N^ O = a a O O O 0 CO a)0 f0 O N N 5 N 5 a0 X y W O O ,O O O N 0 W O U N a) U N a) o C E L L N co- O .1�- C C U0 C C N on X X X_ O E Lj N O O W " O E O W 0 csi cu c a) (n 0. r o z Xo a) o a d W O E O 0 O a) a 16 Q X m H >- o O cc m M J J) O w (1)) O r a) M 0 U) O N C V N N a) O =N 2 E O O_ o y > d > a CO a o o �- >N � L`r it N - r E M'O) C C E• E C O Ce V C O C co C) N C N O O O Q Q re CI ED' R N C 3 N y 0 a) N W 0 al _� Q E N E 0 o m X X 7 > co a) x X 3 > C7 © 0 O CD > O O W W U) a > N O W W V) a = C7 c °i o a. .- t_) C z a -a0 Cl) a) c=i) m a) 10 — Q T E E _ C as a 0 a 0 a Q w m (� E 2 a E s V )z a) Q O Z w m CT: o z M O Y N o E, 8 O co v) C ^ . m Z a N a E v U) w a a - a a a C a a M O O O 3] O O N U 0) CD O O O V 0 Z ,5 c N N (o CO o 0 in 0 m N N a) 0) U. m W O O a0 N M1 E a E c i 0 a) N a) r Z > 0 U) d m 0 fA co d' Q a E E H H Q' E C_ Z E N 0 > > 0 > > w a) m C w Q z O H m _X N m c m co M X U � 5 H OCR Qwosw � � o O W m O W CI-- Q _1 Z U Q O o W Q a a , 0 H Y H H a ■ I Z 2 Z o H U w a) W = Z Z M ;.:,..,j Z H �e a Z o0 W W Q M W 2 a > } m \ Z C U L0 W H Z U 2 H w Q O O O O o W J J Z CO Q O C W co (O Q O 2 c) co (,.) J co O Z ,. W O a co O a) V O U) CO ci W Z m E o > 0 co W 0) Z a N E 6 YO Z E r a) rn a` > V. o z c 0 0 c m (n CL 'C m a O E a) m 0) 6 Cl) 5 J a •`o o a aa) H m m CD m 0 m 0 aai Cl)0 a >, m > E a w ai co E a (� aj co u H m oa C C o m 0 CO �>, h = > T O 0 Z co HT w > > T o o N c .2' a) a) 2 ' a O co I- N. u) 0 r- (D 0 V) H ° > o -8 E E a) 1a .Ci Z` a -o Y a`) -0 w v en o m CO Z o v a`) 0 m a a) a) d O a 7 3 a) U L_ N O O 8 7 '5 a) L 7 N U a W U = -, U U d x x LL N R Y (o 0 2 0 O O O O O LL () a } (o 0 2 0 45 1 c ) § . E & , & G ^ to \ To —1 Li ci_ 4 $ / ° 4ay o \ / — \ tea zz o. a) ix fs \ � � - ® co ) \ 2 _ r = ) a k _ o z z _a) - E e = - & � ( \ \ f )ire ozx 0 _ ./ / k f § o 0. f - \ E e ge | f z z \ } : () % z 2 \ @ ) ) on 1 \ } t - } k } } - ( « k - m I J ) ; - 7 K a % - } % I w / / a = ez \ ) J \ E \ ■ k - > * f i ) - ) © a• § e ` : ® } ( ) CO § ° = 7 \ g _ ) ƒ / \ Efi . 2or % / ¥ > ) ( k Q / § f 11 J ■ \ \ E \ 0 § / E § \ 0 - co o f - - o a f � § ) EE » § \ : . § t .o ter ' O2 = >es a j % k \ a ) A f / 2 _ z ] ) \ Si 12 ° E , _ . . SAE rH \ C G / k E J z ) 34f \ f co ] \ _ _ 12 / = 2 / 0I /e ` //) \ z u 1:1 — > Eo © © - © > 0. \ CU a z z .-z.- r to oi I 0 \ \ ) >. Z {\ ( § ) _ ± u + CI) el K2 z ° 0 a) \ c 2 \ |\ j ( _ z n \ ) k / _ § § \ a - + o / % .. % ! R E { / 0 E 2 . § J ) § / a & o & 3 o \ m lo, ` CO k . \ ) \ \ { ED \ ] \ } TREE= OW WELLHEAD= McEVOY L3-31 TU NOTES: ***3-1/2"&2-718"CHROME ACTUATOR= BAKER C It111AL KB.ELE 51' BF. ELEV_ NA 13-3/8"CSG,68#, H 73' 1 KOP-= 2850' BTC, 2185' —13-1/2"HES X NIP,ID=2.813" Max Angle= 49°@ 7800' ID=12.415" 2212' H9-5/8"HES ES CEMENTER Datum MD= 11208' 20"CONDUCTOR, -I 102' • DatumTVD= 8900 Ki 9-5/8"CSG,47#,L-80 HY D 563,ID=8.681" —{ 2192' I '. 2234' —19-5/8"EXTERNAL CSG PKR 9-5/8"BOWBV PATCH,ID=9.060" - 2259' GAS LIFT MANDRELS 13-318"CSG,72#,L-80 BTC,ID=12.347" 4032' ST MD WI) DEV TYPE VLV LATCH PORT DATE 3 5289 4781 44 WIG DMY RK 0 11/09/13'' 2 8783 7201 46 MMG DMY RK 0 10/21/13 Minimum ID =2.205" @ 11066' 1 10638 8504 40 MMG DMY RK 0 10/21/13 2-7/8" HES XN NIPPLE 10698' H3-1/2"HES X NP,ID=2.813" �o 10731' I9-5/8"X 3-1/2"HES TNT PKR,ID=2.949" 10757' —I3-1/2"HES X NP,ID=2.813" I 3-1/2"TBG,9.2#,13CR-85 VAM TOP, H 10867 10841' —I 3-1/2'HES XN NIP,ID=2.750" 0087 bpf,ID=2.992" 10875' —I 9-518"X 2-7/8"UNIQUE OVERSHOT 2-7/8"TBG STUB(10/12/13) H 10874' 10901' H2-7/8"XO 5-1/2",D=2.380" t 10906' —19-518"X 5-112"BKR S-3 PKR,ID 4.760" II10911' J 1 5-1/2"X0 2-7/8",ID=2.400" 10941' H2-7/8"HES X NP,ID=2.313" L 10986' I—9-5/8"X 7"LNR HGRw/SEI SING SLV,ID? 11066' —I 2-718"HES XN NIP ID=2.205" 2-7/8"TBG,6.4#,13CR-80 VAM TOP, H 11098' i , .0058 bpf,ID=2.441" 11098' I 2-7/8"WLEG,ID=2.438" I 9-5/8"CSG,47#,L-80 BTC,ID=8.681" —I 11204' 11222' --1 UPPER 7"MARKER JOINT 1 ' 11244' I LOWER 7"MARKEUJONT 2-7/8"TBG,6.5#,L-80,.0058 bpf,ID=2.441" —1 11489' I PERFORATION SUMvIARY 1 ._ 11477' H 7"X 2-7/8"BROWN I-B PKR,D=3.250 REF LOG:LDT/CNL SOS ON 03/18/86 ANGLE AT TOP PERT:35°@ 11256' 11489' H CUT 2-7/8"TP,D=2_441" Nate:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 11564'CTM 1-FISH:CBP MILLED&PUSHED OH(11/17/13) 4" 4 11256-11346 0 10/23/99 ■ 2-1/8" 11400-11473 0 10/23/99 11548' —I SAND RUG TAGGED 09/07/91 2-1/8" 11490-11500 0 10/23/99 - 4" 4 11522-11570 0 05/02/86 11180° —FISH:21'OF TBG TAIL(07/28/91) &TAGGED 09/07/91??? veAvAvegrAvN 7"CSG,29#,L-80 BTC,_0371 bpf, D=6.184" —1 12006' c�f�c�c�Ovfl - DATE REV BY COMMENTS DATE REV BY COMVB'TTS ( LISBURNELt'JT 05/03/86 INITIAL COMPLETION 11/19/13 CRR/JMJ MLLED&PI.JSI-EDCBP(11/17/13) WELL L3-31 06/22/09 D-16 RN 0 PERMT No:'1860340 10/22/13 D-14 RWO API No: 50-029-21544-00 10/24/13 AID DRLG HO CORRECTIONS SEC 22,T11 N,R15E,1169'FNL&725'FWL 11/19/13 CR/JMJ RNAL ODE APPROVAL 11/19/13 RKT/JMD STA#3 DMY POST RWO(11/09/13) - BP Exploration(Alaska) " I%% ■ THE STATE Alaska Oil and Gas "' °fl 1L ���1 l Conservation Commission { GOVERNOR SEAN PARNELL 333 West Seventh Avenue .- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dave Bjork Sat* Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 ?J Anchorage, AK 99519-6612 i Re: Prudhoe Bay Field, Lisburne Oil Pool, L3-31 Sundry Number: 313-470 Dear Mr. Bjork: 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, Daniel T. Seamount, Jr. Commissioner DATED this ) day of September, 2013. Encl. STATE OF ALASKA 0\ikt .. RECEIVED ALAS•OIL AND GAS CONSERVATION COMMI1PON 11\e AUG 2 8 2013 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑Abandon ❑Plug for Redrill ❑Perforate New Pool 0 Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate 0 Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ®Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska)Inc. ❑Exploratory ❑Stratigraphic 186-034 • 3. Address: 6. API Numbe Development ❑Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21544-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? j L3-31 Will planned perforations require a Spacing Exception? ❑Yes No 9. Property Designatior 10.Field/Pool(s): • ADL 028325 ' Prudhoe Bay Field/Lisburne Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12006' • 9614' . 11829' 9468' 11066',11548'(Sand Plug) 11180' Casing Length Size MD _ TVD Burst Collapse Structural Conductor 102' 20" 102' 102' 1490 470 Surface 4032' 13-3/8" 4032' 3887' 3450 1950 Intermediate 11204' 9-5/8" 11204' 8948' 6870 4760 Production Liner 1020' 7" 10986'- 12006' 8774'-9614' 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11256'- 11570' 8990'-9252' 2-7/8",6.4#/6.5# 13Cr80/L-80 11098'/11477'-11489' Packers and SSSV Type: 9-5/8"x 5-1/2"BKR S-3 packer Packers and SSSV 10906'/8712' 7"x 2-7/8" Brown I-B packer MD(ft)and ND(ft): 11477'/9174' 12. Attachments: 13.Well Class after proposed work: • IS Description Summary of Proposal 0 BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic 0 Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. September 15,2013 , 0 Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Rymut,564-5452 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Cody.Rymut @bp.com Signature: 2/ Phone: 564-5683 Date: 5la4jl3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ,� Sundry Number: --‘‘"2, '4...--1 0 Plug Integrity I7 BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: 50%' f s t ¢cl .3 5 l-)(1 P s / RBDMS OCT 1 0 201 /,. Spacing Exception Required? ❑Yes ®No Subsequent Form Required: /J ��j�� - Approved By: COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 a ed 10/2012 Submit In Duplicate n� Approv a i tic i valid for 12 months from the date of approval ,� 1/['r b///3 0I�V i r � , ,,, ,i) bp • • Sundry Request for Casing Repair Well: L3-31 Date: 8/19/2013 Engineer: Cody Rymut MASP: 1952 psi Well Type: Producer Estimated Start date: September 15th, 2013 History: L3-31 was drilled in February 1986 with an 8-1/2"hole section through the Lisburne Wahoo section. Minor losses were reported during the drilling of the well,although no rate or volume was reported. After logging, the well was left secured until April the same year when a completion rig performed a remedial cementing operation on the 9-5/8"casing with several squeezes between 10,000' and 10,566'. The well was perforated in Wahoo zones 5 and 7. After a selective 2-7/8"completion was installed to isolate zone 7 from 5 behind a AVA sleeve,two small breakdown acid treatments were performed independently on zones 5 and 7.Apparently,zone 5 tested wet,although no further evidence of this remark can be found in the well files. Drawdown testing after stimulation showed that zone 7 would only flow at low rates under significant drawdown. After isolating zone 5,zone 7 was restimulated with HC1 after which time the well began to flow. A further HCl restimulation of zone 7 was performed,and after nitrogen(N2)was used to kick-off the well,poor-boy gas lift was connected from L3-11. From this time,the well struggled to produce and required oil treatments(HOTs)every two weeks to keep the wellbore clear,and would not flow without the poor-boy gas lift. In July 1989,permanent gas lift was installed to the well. Two years later,in July 1991,the lower tubing tail was cut-off to allow 16 lower zone 6 perforations to be added from 11,400'to 11,500'. A sand plug was then placed over zone 5,and zone 7 was isolated with a sleeve while zone 6 was stimulated with HC1. Reports indicated zone 6 would not sustain flow on its own,and kept loading up and dying,even when on lift gas. In December 1991,a closed fracture acid(CFA)treatment was pumped on zones 5 and 6,with no change in sustainable well performance. Up to this time the well was still requiring bimonthly HOTs to prevent the well from plugging off due to the low flow rate and flowing temperature. In January 1992 a CFA was performed on zone 7(zones 5 and 6 were isolated),that dramatically changed the well's performance. The well was suspected of having IAxOA communication in May 1991,although this was fixed by inner casing pack-off work in 1999. Since no IAxOA communication had been observed,the integrity waiver was cancelled in 2003.In 2004 during a slick-line attempt to pull the AVA plug,the tools became stuck and 1488' of slick-line wire was left in the hole. Further diagnostic work determined that the well had several holes in the tubing,and was a risky candidate for an extended patch. L3-31 was worked over in June 2009 to replace the tubing.IA x OA leak to gas developed within several months. Seal-tite mist treatment was unsuccessful on 11/29/2010,but the leak rate was reduced. Seal-tite determined that retreatment was not likely to be successful.A RWO is now the means to return integrity to this well. Scope of Work: Pull 2-7/8" 13Cr-85 tubing (pre rig cut), USIT log 9-5/8" CSG to determine cement top in 9-5/8" x 13-3/8" annulus, Mechanically cut 9-5/8" CSG, Pull 9-5/8" CSG, Run and fully cement 9-5/8"tieback, Run 3-1/2" 13Cr-85 completion tubing w/overshot. • • Pre Rig Prep Work: S Pull PXN from 11066'md. Drift past WLEG for 2- /8" Composite BP. S Set Composite bridge-plug in 2 2/8" tubing tail at 10,970'md (ref. Tubing Tally dated 6/22/2009). Fill tubing with crude and MIT-T to 3000 psi. E If MIT-T passes,jet cut 21/8"tubing at 10,875'md (ref. Tubing tally dated 6/22/2009). Cut should be—4' down from the top of the 1st full jt above the packer(note: tally mistakenly calls this a 29.56' "pup"jt). If MIT-T fails, notify RWO Engineer. F Circulate wellbore with seawater, freeze protect to 2000'md with diesel. MITOA to 2000 psi. W Check the tubing hanger LDS for free movement. Completely back-out and check LDS for breakage. PPPOT-T to 5000 psi f/30-min and PPPOT- IC to 3500 psi f/30-min. ✓ Set BPV O Pull well-house, flow-line, prep pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 718" x 5"VBRs, blind shears, mud cross and 2-7/8"x 5"VBRs). Test the VBRs to 3500 psi and the i annular to 3500-psi. 2. Pull 2-7/8" 13Cr-85 tubing from pre-RWO cut—10,874' MD. 3. Scrape the 9-5/8"casing and dress the 2-7/8" tubing stub. 4. RIH with USIT logging tools and determine top of cement in 13-3/8" x 95/8" annulus. 5. Run a 95/8" RBP, set—100' below logged TOC, and stack 50ft of sand on RBP. 6. Change the upper pipe rams to 95/8" solid pipe ram and test. 7. Mechanically cut the 9-5/8" casing in 1st full jt above logged TOC. 8. Circulate out Arctic Pack in 133/8"x 95/8" annulus. 9. Pull 95/8" casing down to the cut. 10. Dress-off 95/8" casing stub and scrape 13-3/8" casing. 11. Run and fully cement 95/8"tie-back casing. 12. Drill out 95/8" shoe-track, PT casing to 3500 psi. 13. Retrieve 95/8" RBP. 14. Run 3-W 9.2#/ft 13Cr-85 VamTop tubing with HES TNT packer and overshot, set the packer at —10,745' MD. 15. Displace the IA to packer fluid and set the packer. 16. Test tubing and IA to 3,500-psi. Freeze protect to 2,200' MD. ✓ 17. Set BPV. ND BOPE. NU and test tree. RDMO. Post rig Work ✓ Pull BPV S Pull ball and Rod, Pull RHC seat, drift to PXN plug @ 11,066'md. E Run Jewelry Log PBTD to GLM#1 S Run GL Design TREE= . CNV 410 SA11111 NOTES: ***2-7/8"CHROME TLIBING& WELLT-EAD= lik EV OY L3-31 NIP Sm ACTUATOR= BAKER C .. _ INITIAL KB.ELE 51 I I BF.ELEV= NA KOP= 2850'1 I 2198" H2-718"XXO SSSV,ID=2.313" Max Angle= 49 @ 7800'1 0 ---,......,1 11208i SURFACE-2200' —StsIGLE 1/4"X.049'SS Datum ND= Datum ND= 8900 CONTROL LIKE 113-3/8'CSG,72#,L-80 BTC,ID=1234T H 4032' -- I1 GAS LET MAMFIELS ST MD ND DEV 'TYPE 'I VLV LATCH PORT DATE I 3 5306 4794 44 CAMEO DONE RK 16 10/11/10 2 8789 7205 46 CANICO DOME RK 16 10/11/10 Minimum ID =2.205" @11066' 1 10805 8633 39 CAMCO SO RK 20 10/11/10 2-7/8" HES XN NIPPLE 10870' H2-7/8"HES X NF,U=2.313' 10901' H2-7/8"X0 5-1/2',HI)=2.380" 2 10906' H 9-5/8"X 5-112"BKR S-3 FKR,ID 4.760' ---...................... 10911' H 5-1/2"X02-7/8',D=2.400" 10941' —2-7/8'I-ES X PC OD=2.313' ) , —_, E 10986' H9-5/8"X 7 LNR liGR w/SE t i ING SLV,R3? H 11066' 1-12-7/8"HES XN NIP,0=2.205* 11066' ---12-718'PXN FLUG(04/19/11) 2-7/8'TBG,6.4#,13CR-80 VAM TOP, — 11098' 11098* H2-7/8"VVLEG,ID=2.438" .0058 bpf,ID 2.441" 9-5/8"CSG,47#,L-80 EITC,ID=8.681" — 11204' • __......................,..il■ 11222' —1 UPPER 7'MARKER JOIsIT 1 11244' H LOWER 7"MARKER JOWT 2-718"TBG,6.5#,L-80,.0058 bpf,V=2.441" H 11489' N X 1147r --I 7"X 2-7/8"BROWN I-B PKR,13=3.250' PERFORATION SUMMARY 1 11489' H GUT 2-7/8'1P,ID=2_441" FEE LOG:LDTICNL SOS ON 03/18/86 — ANGLEAT TOP PERE:35'@ 11256' Nate:Refer to Production DB for historical pen f data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ — 1 11548' H SAND PLUG TAGGED 09/07/91 4" 4 11256-11346 0 10123/99 2-1/8" 11400-11473 0 10/23/99 di 2-1/8" 11490-11500 0 10/23/99 11180' —FISH:21'OF TTEIG TAIL(07/28/91) 4" 4 11522-11570 0 05/02/86 &TAGGED 09/07191??? WOW* ••••••• ...•••• 7"CSG,29#,L-80 BTC,.0371 bpf,ID=6.184" —1 12006' ' ....0.0A+.4 DATE REV BY COUNTS DATE REV BY COlvIvENTS LISBURNE MIT 05/03/86 ORIGINAL COMPLETION 07/24/10 BSE/AGR GLV 00(07/08/10) WELL: L3-31 06(22109 1)16 RWO 10/23/10 CJNIAGR GLV C/O(10111110) PERMIT Na: 1860340 06/28/09 TLH DRLG HO CORRECTIONS 04/29111 liA3M/PJC SET PXN(04119/11) AR No' 50-029-21544 00 07/21/09 NEYJIA3 DRLG DRAFT CORRECTIONS 08/27/13 JNL/JMD CORRECTED 7"X2-718"PKR CEPT1- SEC 22,Ti IN,R15E,1169'F14._&725 RM. 1 11/14/09 JNVRIC SET PXN PLUG I 07/11/10 GTW/SV GLV 00&R.LL PXN(07709/10) BP Exploration(Alaska) 1 i V1TREE=ELLFEAD= McEVOY Pr.see L3-31 NOTES: ***2-7/8"CHROME TUBING 8 ACTUATOR= BAKER C BF=aEy- nun 9-5/8" 47# L-80 Hydril 563 KoP=---- 2850' I I — 3-1/2" X Nipple, ID = 2.813" Max Angle= 49°@7800' �9-5/8" ES Cementer DatumWD= 1120( _ us — 9-5/8" ECP & Casing Patch DatumWD= 8900 13-3/8"CSG,72#,L-80 BTC,D=12.34T —I 4032' ■ GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =2.205 @ 11066 I LI 2-7/8" HES XN NIPPLE 3-1/2" VamTop TBG, 9.2# CR13, ID=2.992" ■ II 3-1/2" X Nipple, ID = 2.813" ® 51 9-5/8" x 3-1/2" TNT PKR iii ■ 3-1/2" X Nipple, ID = 2.813" 9-5/8" x 2-7/8" Unique Overshot — -- 10901' H 2-7/8"XO 5-1/2",D=2.380" 10906' H9-5/8"X 5-1/2"BKR S-3 PKR,D 4.760" \ 10911' —I 5-1/2"x0 2-7/8",D=2.400" 10941' ---I2-718"HES X NP,D=2.313" l J`� 10986' H9-5/8"X 7"LNR HGR w/SETTING SLV,U7 H 11066' H 2-7/8"I-ES XN NP,D=2.205" 11066' H2-7/8"PXN R_UG(04/19/11) 2-7/8"TBG,6.4#,13CR-80 VAM TOP, —j 11098' 11098' H 2-7/8"WLEG,D=2.438" .0058 bpf,ID=2.441" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" — 11204' i< 11222' H UPPB2 7"MARKER JO4t 11244' H LOVVER 7"MARKER JOINT 2-7/8"TBG,6.5#,L-80,.0058 bpf,13=2.441" H 11489' z 11475' H 7"X 2-7/8"BROWN LB PKR,D=3.250" PERFORATION SUMMARY REF LOG:LDT/CIL SOS ON 03/18/86 ANGLE AT TOP PERF:35°@ 11256' 11489' --I CUT 2-718"TP,D=2.441" Note:Refer to Production DB for historical perf data SIZE SPF 1'ITERVAL Opn/Sqz DATE 4" 4 11256-11346 0 10/23/99 2-1/8" 11400-11473 0 10/23/99 11548' —I SAND PLUG TAGGED 09/07/91 2-1/8" 11490-11500 O 10/23/99 4" 4 11522-11570 0 05/02/86 'i't l'` -FISH:21'OF TBG TAIL(07/28/91) &TAGGED 09107/91??? OVOTOV 7"CSG,29#,L-80 BTC,.0371 bpf,13=6.184" —I 12006' :NA:kW DATE REV BY COMM3JTS DATE REV BY C 0lvNENTS LISBURN'E UNIT 05/03/86 ORIGINAL COMPLETION 07/24/10 BSEAGR GLV C/O(07/08/10) WELL L3-31 06/22/09 D16 RWO 10/23/10 CJN/AGR GLV C/O(10/11/10) PERMT No: 1860340 06/28/09 TLH DRLG HO CORRECTIONS 04/29/11 MBM'PJC SET PXN(04/19/11) AR No: 50-029-21544-00 07/21/09 NUIJM1 DRLG DRAFT CORRECTIONS SEC 22,T11 N,R15E,1169'FNL&725'FWL 11/14/09 JMPJC SET PXN RUG 07/11/10 GTW/SV GLV C/O&PULL PXN(07/09/10) BP Exploration(Alaska) ■ i RIG FLOOR 33.7 ' AGL i SD-7 107257251 i VALVE LEGEND fa©T©MOT©�0�01 1 BYPASS U I I 2 KILL 3 CHOKE IP I e- I 4 BOTTOM RAMS II II 5 BLIND RAMS �I I I ° 6 TOP PIPE RAMS III ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR 13 5/8",5000 PSI,HYDRIL ANNULAR BOP, TRIPLEX PUMP: 575 VAC, 30 HP STUDDED TOP/FLANGED BOTTOM AIR PUMP: 1, NL SHAFFER • M ______________ FLANGED TOP .4 O CD 0 W I W 13 5/8",5000 PSI,10'MPL OPERATORS, i HYOHL PIPE RNA 1 1 1 3 1/8"5000 PSI SIDE OUTLET 1 1 1 1 1 1 1 1 , HS 5/8", ND PSI,14"MPL OPERATORS, C 3'CHOKE UNE �� �� F HYORIL BUND SHEAR RAN C - - : ] — BY PASS • • STUDDED BOTTOM BX 160 ■ • . • 3 1/8'5000 PSI HER VALVE •1500 3000 U:: OF 4II /"III/'1III.II■/II■/IIP 2"KILL UNE -, E. MS J 3 1/8"5000 PSI HCR VALVE-, 3 1/8"5000 PSI GATE VALVE ,•E • 3 1/8"5000 PSI GATE VALVE \SINGLE•41111111111.•" I / 5°°°P51,10'MPL OPERATORS, HYDE PIPE RNA l 'IT II '^^'7 1Ir!—'�K .B" .. B" Tr l I a «n STUDDED BOTTOM/FLANGED TOP BX 160 I P, ,• • MID ACCUMULATOR MANIFOLD ri 1a h 111 18 BOTTLES, 10 GALLONS EACH • • f OPEN LOSE AN • • CHOKE BOP STACK ELEVATION [ : : - REMOTE PANEL IN DOGHOUSE I AND UTILITY MODULE I • brad NITROGEN BACKUP BOTTLES 21 I/A•,2000 PSI, 18'150 PSI HYDR. MOP H11)RIL BOP/ONENIER OPERATED KNIFE GATE VALVE STUDDED TOP/FLANGED BOTTOM 1' C/N PLUG ■IN min• FLANGE/FLANGE RX 73 nM R A Iv ea f oy a mx�0a � m i a --------- 16'FLGD VENT UNE MI I 01/16/08 S °MB LEA WDAIE BOP STACK I P^""oI RIG 14 03/05/01 L oTre LEA UPDATE DTP snot �� FIANCE 01/31/00 3 DOB LEA MOW a01411E/DU 1169 1111E BOP SYSTEM I 1220-00 2 OKB LEA UPDATE BOP STOCK AND CONTROL SURFACE DIVERTER CONFIGURATION 11-26-98 1 Ali LEA MAW To ALUM DA11111/28/98 °ERPPR°Y AaPK81EU°M LEA R.5 MAW BY SW No. DATE , oESTCKP11811 TUTS JTH RI ABOPSTS&CONTROL 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 AUG0 112 May 20, 2012 Mr. Jim Regg 8 3 Li- Alaska Oil and Gas Conservation Commission _ , I 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Lisbume 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 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) GPMA Lisburne 3 Date: 03/08/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD it API It cement pumped cement date inhibitor sealant date L3 -01 1890750 50029219590000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3 -02 1861540 50029216440000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3 -08 1831430 50029210190000 3.0 N/A 3.0 N/A 27.20 11/29/2011 L3 -11 1852310 50029214520000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-12 1861610 50029216510000 Dust Cover N/A 0.0 N/A N/A 3/8/2012 L3 -15 1852660 50029214760000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-18 1861670 50029216570000 0.0 N/A 0.0 N/A _ 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-22 1861750 50029216630000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-24 1861820 50029216700000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 P&A 12/93 NA NA NA NA NA ' L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 2 7 L3 -31 1860340 50029215440000 0.0 N/A 0.0 N/A 8.50 11/29/2011 07/20/09 ~~~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Mnchorage, AK 99503-2838 AITN: Beth „~:NOi'S~19 i ~ ~ ~ i~~~ * ~ , k ; " ,~ ~ i~t,!~~ Company: State of .4laska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Sui4e 100 Anchorage, AK 99501 Log Description Date BL Color CD Well Job # ~ 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE - O6/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/Ot/09 1 1 G-31 B ANHY-00100 LDL ( 07/07/09 1 9 Z-32BL1 AV1H-00018 SBHP RVEY ~- 07/02/09 1 9 14-10 AY3J-00033 PRODUCTION PROFILE ~'$(0 07/01/09 1 1 A-20 AV1H-00021 SBHPSURVEY - "~ 07/07/09 1 1 01-30 AY3J-00034 LDL ~ 07/04/09 1 9 M-26A BOCV-00021 PRODU TION LOG ^ 07/12/09 1 1 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG (o - 07/09/09 1 1 L2-20 AYKP-00031 LDL / 07/10/09 1 1 E-09B B04C-00064 SCMT - 07/01l09 1 1 04-33 AY3J-00036 USIT ( 07/07/09 1 1 ~ WGI-07 BOCV-00020 USIT 07/11/09 1 1 1-31/M-21 B14B-00063 PRODUCTION PROFIL~ f O6/16/09 1 1 L3-02 AZCM-00028 RST - pg/15/pg 1 9 _W' 1-31/M-21 B14B-00063 RST ' OW77/09 1 1 18-18B ANHY-00097 RST '~ - ~" ' O6/09/09 1 1 oi GacG ecrtinw~ cnr_c oc rc~oT nv c~n.u .~n_ A\If1 ~CTI Inuu~~ .,...- ..,..,., ....,.. ~.. _._. --------- - -- -•_•--•-_-••--••-._..........,..~..... . ~....~~ ~.,. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. -~~~-.,~°--_.~~ ~_~~..-° Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~ 07/20l09 Scht~ber~r (;;~R~ ~~~9 ' Alaska Data & Consulting Services Com an S4ate of e4laska 2525 Gambell Street, Suite 400 ~ i, p y. Anchorage, AK 99503-2838 ~~ ~ ~~ ~~ ~ ~~~~ ~ 4 ~~~ ~~ ~ ~~ ~ Attn k Christine Mahnken~m~ a7TN: eeth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE 06/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 y G-31 B ANHY-00100 LDL ( 07/07/09 1 1 Z-326L1 AV1H-00018 SBHP RVEY ~ 07/02/09 1 1 14-10 AY3J-00033 PRODUCTION PROFILE ~'a(o 07/01/09 1 1 A-20 AV1H-00021 SBHPSURVEY - '~ 07/07/09 1 1 01-30 AY3J-00034 LDL ~ 07/04/09 1 1 M-26A BOCV-00021 PRODU TION LOG 07/12/09 1 1 06-23C L3-31 AXBD-00031 BOCV-00019 MEMORY PROD PROFILE - PRODUCTION lOG (o ~- 07/03/09 07/09/09 1 1 1 1 L2-20 AYKP-00031 LDL / 07/10/09 1 1 E-09B B04C-00064 SCMT - (p 07/01/09 1 1 04-33 AY3J-00036 USIT ( 07/07/09 1 1 ~ WGI-07 BOCV-00020 USIT 07/11/09 1 1 1-31/M-21 B146-00063 PRODUCTIONPROFIL~~ - O6/i6/09 1 1 L3-02 AZCM-00028 RST 06/15/09 1 1 1-31/M-21 B146-00063 RST - 06/17/09 1 y 18-18B ANHY-00097 RST a- ' 06/09/09 1 1 DI CeCC nt~~[~tnw~ cnnc o~ r~~nT ov ~~nwu ui. .u.~ ., BP Exploration (Alaska) Inc. ` M^~ "` • v.......M v..~ vvr ,~~v• , v. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. v.,._~~~r~~._°°"~_.- °~,~.I ~.....F Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • r~ U STATE OF ALASKA ALAS•OIL AND GAS CONSERVATION COMM~ ON REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~~/~~ Jt.l~ ~ ~ Z~J~~ .. .. . ,. ... Z .. ... .., ~ ~i~!! 1. Operations Performed: ~ ~ ~r~~~~,~~~~ ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 186-034 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21544-00-00 7. KB Elevation (ft): 5~, 9. Well Name and Number: L3-31 8. Property Designation: 10. Field / Pool(s): ADL 028325 Prudhoe Bay Field / Lisburne Pool 11. Present well condition summary Total depth: measured 12006 feet true vertical 9614 feet Plugs (measured) 11548~ (Sand Plug) Effective depth: measured 11548 feet Junk (measured) ~11548', 11180' true vertical 9234 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 102' 20" 102' 102' 1490 470 Surface 4032' 13-3/8" 4032' 3887' 3450 1950 Intermediate Production 11204' 9-5/8" 11204' 8948' 6870 4760 Liner 1020' 7" 10986' - 12006' 8774' - 9614' 8160 7020 ,i'~~ k. ~fi~~~~~1. .... 6~.`~Ii'!1k~ k1: 1'l~ ! Perforation Depth MD (ft): 11256' - 11570' s S_ ~ ~ 1n Perforation Depth TVD (ft): 8990' - 9252' 2-~~8 , 6.4# 13Cr80 11098' Tubing Size (size, grade, and measured depth): 2-7/R" R 5# I -RO - Packers and SS$V (type and measured depth): 9-5/8" x 5-1/2" BKR S-3 packer 10906' 7" x 2-7/8" Brown I-B packer 11475' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~~~. ~~ ~~~~~ Treatment description including volumes used and final p ressure: ~~ 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 320 Subsequent to operation: 636 2785 1316 2150 577 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed N , Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si ture Phone "~i ~C7 Date(~~-~5- Sondra Stewman, 564-4750 ~_____.~ Form 10-404 Revised 04/2006 ~~~~ ~~,,. ~ i~i (~ ~ '~~ 2 a0~ SubmittOriginal Only !~~ I ~ ~o ,~'';%%<' ,~'f~~t'~'~r TREE = CNV WELLHE4D= McEVOY ACTUATOR = BAKER C KB. ELEV = __~ 51' BF. ELEV = NA KOP = - 2850' Max Angie = 49° @ 7800' Datum MD = 11208 Datum ND = 8900 ~ ~ t~~~T Single 114" X O,b49" SS control line from surface to 220t7' 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 4032~ L ~ -~ ~ N~PPAF~~OTES; ***2-7/8" CHROME TUBING & L~** 2198' I-12-~is° xxo sssv, ID = 2.313° GAS LIFf MANDRELS Minimum ID = 2.205" @ 11066' 2-7/8" HES XN NIPPLE ST MD ND DEV TYPE VLV LATCH PORT DATE 3 5306 4794 44 CAMCO DOME RPK 16 06/30/09 2 8789 7205 46 CAMCO DOME RP 16 06/30/09 `l 10805 8633 39 CAMCO SO RP 20 06/30/09 10870~ - 10901' -~ 2-7/8" HES X NIP, ID = 2.313" ~ 2-7/8" XO 5-1/2", ID = 2.380" 10906~ 9-5/8" X 5-1/2" BKR S-3 PKR, ID 4.760" 10911 ~ 5-1 /2" xo 2-~/s", ID = 2.400" 2-7/8" TBG, 6.4#, 13CR-80 VAM TOP, .0058 bpf, ID = 2.441" 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" ( 11098' I I 11204' I I 2-7/8" TBG, 6.5#, L-80, .0058 bpf, ID = 2.441" ~ 11489~ 10941 ~ 2-7/8" HES X NIP, ID = 2.313" 10986~ 9-5(8" X 7" LNR HGR wlSEfTING SLV, ID'? ~ 1066~ 11098~ 2-7/8" HES XN NIP, ID = 2.205" 2-7/8" WLEG, ID = 2.438„ 1'~222' -iUPF'ER7"MARKFJ~JOINT 11244~ LOWER 7" MARKER JOINT 11475~ ~-~ 7" X 2-7/8" BROWN I-B PKR, ID = 3.250" PERFORATION SUMMARY REF LOG: LDT/CNL SOS ON 03/18/86 11489' CUT 2-7l8" TP, ID = 2.441" ANGLE AT TOP PERF: 35° @ 11256' ~ Note: Refer to Production DB for historical perf data ?? FISN: WRP EGE~9ENTS {~5115149j??? SIZE SPF INTERVAL Opn/Sqz DATE GONE C3R AT T~iE BO°CT'Ot~~? " 4 4 11256 - 11346 C 10/23/99 11548~ SAND PL.UG TAGGm 09/07/91 2-1/8" 1140Q - 11473 C 10/23/99 2-1/8," 11490 - 11500 C 10/23/99 4" 4 11522 - 11570 C 05/02/86 ~ 118~° FISH: 21' OF TBG TAIL (07/28/91~ & TAGGED 09/07l91??? 7" CSG, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 12006~ DATE REV BY COMMENTS DATE REV BY COMMEMS 05/Q3/86 ORIGINAL COMPLETION 06/22/09 D16 RWO 06/28/09 TLH DRLG HO CORREC710NS 07/15/09 ?/JMD DRLG DRAFf CORRECTIONS LISBURNE UNIT WELL: L3-31 PERMff No: ~1860340 API No: 50-029-21544-00 SEC 22, T11 N, R15E, 1169' FNL & 725' FWL BP Exploration (Alaska) • ~ I - BP EXF Operati Legal Well Name: L3-31 Common Well Name: L3-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 I 6/10/2009 117:00 - 00:00 I 7.00 I MOB I P 6/11/2009 00:00 - 19:30 19.50 MOB P 19:30 - 21:30 2.00 MOB P 21:30 - 22:30 1.00 MOB P 22:30 - 23:00 0.50 MOB P 23:00 - 00:00 1.00 MOB P 6/12/2009 100:00 - 04:00 I 4.001 DHB I P 04:00 - 07:00 I 3.001 WHSUR I P 07:00 - 09:00 I 2.00 I WHSUR I P 09:00 - 11:00 I 2.001 WHSUR I P 11:00 - 13:00 I 2.001 BOPSUR P 13:00 - 13:30 I 0.501 BOPSUFiP 13:30 - 19:30 I 6.001 BOPSUFi P -ns Summary Report Spud Date: 6/4/2009 Start: 6/12/2009 End: Rig Release: 6/22/2009 Rig Number: Phase Description of Operations PRE Prepare Rig to Move from A-35 to L3-31 -Bridal Up and Lay Over Derrick -Move Off A-35 and stage on pad -Install BOP on Traveling stand -Install Front Boosters -Install Rear Boosters -Clean up around location and Prep to move PRE Continue moving from A-35 to L3-31 PRE Remove Boosters and Place BOP Stack in cellar PRE Spot over well PRE Raise Derrick PRE Rig up cutting tank, Shim Rig, Rig Floor. Rig up to take on Seawater. DECOMP '*'Acce t Ri At 00:01 Hrs -Spot Slop Tank -Rig up circulating manifold in cellar -Pick u DSM Lubricator and Test to 500 si, ood test -Pull BPV -Take On Seawater and Make Up 40 bbl Safe-Scav Pill DECOMP Hold PJSM with Rig Crew, CH2MHill truck drivers, Tool Pusher, and WSL to discuss the well kill circulation procedure -Test lines to 3000-psi. -Circulate the long way, 5-BPM at 1000-psi, taking returns through the gas buster and to the cuttings tank.. -Pump 2(ea) 20-bbl Safe Scav pills during circulation. -Monitor well - Statia DECOMP Set & test TWC. -Hold PJSM on testing TWC. -Cameron rep t-bar in TWC. -Test TWC above to 3500- si for 10-charted minutes. Good Test. -Test TWC below to 1000-psi for 10-charted minutes. Good Test. -RD and blow down all test equipment and lines. DECOMP Drain & ND production tree. -Bleed control lines. -2 barriers for ND are 1) WRP at 10,955' and 2) Tested TWC. -ND Tree and adapter flange. -Terminate control lines. -Attem to install 2-7/8" 8rd XO. Unable to make up due to . Discuss situation with RWO engineer and Baker fishing. Baker fishing is mobilizing an ITCO spear to pull hgr. DECOMP NU spacer spool & BOP stack. -Use Sweeney wrench to properly torque all nuts. -Install riser. DECOMP RU to test BOPE. -Fill all lines. -Function rams. DECOMP Test BOPE. -Test to 250-psi low and 3500-psi high for 5-charted minutes. -Test VBRs with 4" and 2-7/8" test jts. Test annular using 2-7/8" test joint. Printed: 6/29/2009 3:04:48 PM r ! Legal Well Name: L3-31 Common Well Name: L3-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i i i i i 16/12/2009 I 13:30 - 19:30 I 6.001 BOPSUR P 19:30 - 20:00 0.50 BOPSUF~ P 20:00 - 21:00 1.00 DHB ~ P 21:00 - 22:00 I 1.001 PULL I P 22:00 - 00:00 I 2.001 PULL I P 6/13/2009 00:00 - 00:30 0.50 PULL P 00:30 - 12:30 12.00 PULL P 12:30 - 13:30 I 1.001 PULL I P 13:30 - 14:30 I 1.001 PULL I P 14:30 - 00:00 9.50 PULL P 6/14/2009 00:00 - 01:00 1.00 PULL P 01:00 - 02:00 1.00 WHSUR P -~~~ ~ry Repvrt Spud Date: 6/4/2009 Start: 6/12/2009 End: Rig Release: 6/22/2009 Rig Number: Phase Deserip#ian of Operations DECOMP -AOGCC rep Lou Grimaldi waived witness of BOP test at 2100 hrs on 6/10/2009. -Test witnessed by BP WSL (Abbie Barker & Dave Newlon)and Doyon Toolpusher (Sam Dye & Pete Martinusen). DECOMP Rig Down Test Equipment and Lay Down 4" Test Joint DECOMP Install Dutch Riser and DSM Lubricator to Pull TWC -Tested t Ri r and Lubricato -Pull TWC DECOMP Make up 2.43 ITCO Spear assembly and Engage In Pup joint below hanger -Back out lock down screws -Pull tubinq hanqer free at 100k (65,000 string +35,000 block wt). -Disengage hanger and lay down spear and Tubing Hanger No issues pulling hanger DECOMP Pump 20 bbl high vis sweep and circulate sweep out of hole -7.6 bpm / 2475 psi -Sweep did not bring anything out with it. Sweep was disburse over 1000 strokes DECOMP Monitor well, Static 8.4 Seawater In / Out -1 barrier - WRP at 10,955' DECOMP Lay Down 2 7/8" 6.5# L-80 EUE 8rd Tubing -Spooling one 1/4" Stainless Control Line and one 1/4" Stainless Chemical Line -79 of 84 SS bands recovered 5 left in hole -Start seeinq external corrosion on collars at it #239, minor pin end and internal corrosion. -Final joints had a thick coating of tan-colored gelatinous material on exterior. -Recover a total of 343-jts of 2-7/8" L80 EUE 8rd tubing, 1(ea)-SSSV, 1(ea)-Chemical Injection mandrel, 5(ea)-GLMs and 1-cut jt. Cut jt was 7.68' and the cut was flared to 3-3/8" OD. DECOMP Clean & Clear rig floor. -RD all 2-7/8" handling equipment. -Function rams and annular to check for SS bands - No more bandsrecovered. DECOMP MU BHA #1 to Dress off 2-7/8" stumn and retrieve seal assembl from PB -BHA consists of Guide shoe, Hollow Mill Container dressed for 2-7/8", Bowen Overshot with grapple to catch 2-7/8" tbg, Overshot extension, Bumper Sub, Oil Jar, Pump Out Sub, XO and 9-jts of 4-3/4" DCs. -Total BHA length = 308.66 DECOMP RIH with BHA #1 on 4" DP from Pipe Shed. -RIH from 308' to 10,738' md DECOMP Slip and Cut drilling Line -Service Rig, Draw Works, TDS and Crown DECOMP Pick up HES Storm Packer and RIH to 84' -Set Storm Packer -Test to 1000psi for 10 minutes ood test - on ipple Down BOP and Change out Casing Spool Printed: 6/29/2009 3:04:48 PM • • BP EXPLQRATfUN Pag~ 3'of 9 ' Operations Summary Report Legal Well Name: L3-31 Common Well Name: L3-31 Spud Date: 6/4/2009 Event Name: WORKOVER Start: 6/12/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 16 Rig Number: Date From - To Haurs Task Code NPT Phase De~cription of Operations 6/14/2009 02:00 - 03:00 1.00 BOPSU P DECOMP Ni le Down BOP Stack and set back on pedestal -2 barriers for ND BOP stack are 1) WRP at 10955' and 2) tested 9-5/8" Storm packer. 03:00 - 03:30 0.50 WHSUR P DECOMP Nipple Down McEvoy Tubing Spool 03:30 - 05:30 2.00 WHSUR P DECOMP Pull 9 5/8" Packoff -Back out Lock Down screws -Remove Metal Shavings and Debris from top of Pack off -Steam Spool and work lock down screws in and out to work pack off out -Change out 4-LDSs (1-broken, 3-bent) -Install new ackoff. -Run in Lock Down Screws. 05:30 - 07:30 I 2.001 WHSUR I P 07:30 - 08:30 I 1.001 BOPSUFI P 08:30 - 09:00 I 0.50I BOPSUF~ P 09:00 - 09:30 0.50 WHSUR 09:30 - 10:00 0.50 WHSUR P 10:00 - f 0:30 I 0.50I PULL I P 10:30 - 13:00 I 2.501 PULL I P 13:00 - 14:30 I 1.501 PULL I P DECOMP I NU new tubina spool and test Packoff tc 30-minutes. -Torque all nuts using sweeney wrench. -Good test on packoff / spool break. DECOMP NU BOP stack. -Take new RKB measurements. -Attach turnbuckles. -Install Riser. -Torque all nuts using sweeney wrench. DECOMP Test BOP break to 250-psi low and 3500-psi high for 5-charted minutes per test. -Good Test. DECOMP Pull test plug & Install Wear ring. DECOMP Retrieve 9-5/8" HES Storm acker. -PU retrieving tool and RIH. -Engage packer and release. -POH. -LD Storm packer and retrieving tool. DECOMP RIH w/ BHA #1 to enqaqe tubinq stub. -PU 2-jts DP from pipe shed. -RIH on 1-std DP from derrick. -Obtain parameters: PU wt = 205K-Ibs, SO wt = 150K-Ibs, Rot wt = 175K-Ibs. Rotate at 40-RPM w/ 5K-ftlbs free torque. -Pump on at 5-BPM with 440-psi. DECOMP RIH and taq fish at 10,865'. -Vary from 40 to 80-RPM with torque between 6 and 11 K-ftlbs. -Vary pump rate from 2-BPM with 100-psi up to 5-BPM with 440-psi. -Vary WOB between 5 and 10K-Ibs. -Slide over stump and set down 10K-Ibs. -PU and overpull up to 250K-Ibs on weipht indicator, firinq jars. -Tbe comes free. PU so seal assv is free of PBR. -RIH and confirm catch by tagging 15' high. -PU so fish is completely off of PBR. DECOMP Circulate Bottoms Up. -Pump at 10-BPM with 1940-psi. -Seeing a large quantity of tan colored gelatinous material across shakers. -Circulate until returns clean up. -Monitor well - Static. Printed: 6/29/2009 3:04:48 PM • • BP E~ Operations Legal Well Name: L3-31 Common Well Name: L3-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i i i t i, 6/14/2009 13:00 - 14:30 1.50 PULL P 14:30 - 17:30 3.00 PULL P 17:30 - 19:00 1.50 PULL P 19:00 - 20:00 I 1.00 I PULL I P 20:00 - 23:00 3.00 PULL P 23:00 - 00:00 1.00 PULL P 6/15/2009 100:00 - 02:00 I 2.001 PULL I P 02:00 - 03:00 I 1.00 I PULL ~ P 03:00 - 04:00 I 1.001 PULL I P 04:30 - 05:30 I 1.001 PULL I P 05:30 - 06:00 I 0.501 PULL I P 06:00 - 08:00 I 2.001 PULL I P RATIQN ~mary Report Spud Date: 6/4/2009 Start: 6/12/2009 End: Rig Release: 6/22/2009 Rig Number: Phase Descriptian of Operations DECOMP -Back out and blow down Top Drive. DECOMP POH with BHA #1, standing back 4" DP in derrick. -Seeing drag of 10 to 15K-Ibs over PU weight. DECOMP La Down Dress Off Bha and Fish -Recover Joint and Seal Assemblv -Punch Tubin , no as or residue -Total Length of Fish 45' DECOMP Make up Packer Spear BHA 3.636" Spear, Bumper jar, Oil Jar, XO, 9 x SDC, XO, ACC Jar, Pump out sub, XO DECOMP RIH from 319' - 10,931 DECOMP Soear Packer and Jar Packer Free -PUW 227k / SOW 143k -3 bpm / 430 psi -Engaged Spear ~ 10,895'md -Initiate Jarring at 75k over / 300k PUW -No Success, Increase Jarring to 100k -Continue Jaring without success as of midniqht DECOMP Continue Jarring on Brown HB 9 5/8" x 2 7/8" Top Packer -Jarring with 100k Overpull to 325kk PUW, After Jar fires pull to 350k -After 2 hrs of Jarrinq Packer Sheared out but still havina to work pipe up to 350k -Worked pipe to 10,843'md -PUW 300-350k / SOW 180k No Problem with downward motion DECOMP Drop Dart and CBU -Circ at 3 bpm / 480 psi till dart landed and open cire sub (12 min for dart to land) -Finish CBU with Circ. Sub open 10 bpm / 1765 psi -PUW 300k / SOW 180k -No fluid loss to well while CBU Total fluid for operation 12. bls DECOMP POH F/10,843 - 10,410' md -Monitor well , Static 8.4 ppg In / Out -POH pull 100- 125 k Overpull PUW 325k-350k -No Problem working down 170k SOW -Hole Swabbin not takin an fluid ast ack r II ti connections - 20 bbls ain DECOMP CBU -10 bpm / 1620 psi -Loss 5.bbls while CBU, no gas or influx on bottoms up -Monitor well,Static 8.4 ppg in / out DECOMP RIH to 10,895' md tag original hole depth -Hole took 27 bbls RIH -No issues RIH, 170k SOW DECOMP Work 10,843 - 10,895' md while circulating -7 bpm / 1080 psi -Slacking off to 10,895', cock jars, pull up to 325k, Fire jars and work pipe back up to 10,843, working 325 - 345k -Normal PUW 235k / SOW 170k -Work pipe until elements wear out. Printed: 6/29/2009 3:04:48 PM • • BP EXPLORATI~N Page 5 of 9' ~~~ Operations Summary Repo:rt Legal Well Name: L3-31 Common Well Name: L3-31 Spud Date: 6/4/2009 Event Name: WORKOVER Start: 6/12/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 16 Rig Number: ' Date From - To Hc~urs Task Code NPT Phase Descriptian of Operations 6/15/2009 06:00 - 08:00 2.00 PULL P DECOMP -Lost full returns. -Pump 110-bbls at 10-BPM, attempting to establish returns. Unable to establish returns. 08:00 - 09:00 1.00 DECOMP POH from 10,895' to 10,464'. -Attempt to catch fluid again by pumping at 3-BPM down DP and filling on the back side through the kill line. 09:00 - 13:00 4.00 PULL P DECOMP POH with 9-5/8" x 2-7/8" packer, standing back 4" DP in derrick. ' 13:00 - 13:30 0.50 PULL P DECOMP LD BHA #2. -Fill hole at 180-BPH while LD BHA. -Stand back 3-stds 4-3/4" DCs in derrick. -LD accelerator, bumper sub & jars. -Redress pump in sub. -10K-Ibs over block weight on weight indicator when BHA laid down. i 13:30 - 17:00 3.50 PULL P DECOMP Break out & LD packer and 2-7/8" tubinq. , -Hold PJSM with crew discussing hazards of LD tailpipe and assorted fish, punching tubing and spill potentials. -RU power tongs dressed for 2-7/8" tubing. -Recover PBR w/ e~ernal threaded scoop, 9-5/8" x 2-7/8" packer & pup, 8yts of 2-7/8" tbg (first 2-jts below packer are helically buckled), 2(ea) 10' pups, GLM (has SL, misc tool pieces and 1-bolt inside), 1-jt 2-7/8" tbg with wireline tool stuck in box and packed with grey granular material, 2-7/8" flow nipple with -15' SL tool string stuck through, 1-jt of 2-7/8" tbg, 5-Blast jts, Pup jt w/ bow-spring centralizer, seal assembly, and Mule shoe. -Total len th recovered = 486.81'. -Fill hole at 180-BPH while LD pkr & tbg. 17:00 - 18:00 1.00 PULL P DECOMP Clean & Clear Rig floor. -RD power tongs & 2-7/8" handling equipment. 18:00 - 19:30 1.50 FISH P DECOMP Make Uo BHA #4. Packer Millina Assemblv 19:30 - 23:00 3.50 FISH P DECOMP RIH from 333' to 11,363' -Tag TOL at 10,991 23:00 - 00:00 1.00 FISH P DECOMP Tag Packer at 11,371' -Mill 7" x 2 7/8" BOT Packer -PUW 250k / SOW 143k / RtWt 178k -80 rpm / 12 - 15k ft/Ibs of torque -5k WOB -Circ down DP at 5 bpm / 240 psi, Fillin~ Back side with 60 bbis/hr no returns 6/16/2009 00:00 - 01:30 1.50 FISH P DECOMP Continue milling on Packer at 11,371' to 11,374' md -PUW 250k / SOW 143k / RtWt 178k -80 rpm / 12 - 15k Wlbs of torque -5k WOB -Circ down DP at 5 bpm / 240 psi, Filling Back side with 60 bbls/hr 01:30 - 02:00 0.50 FISH P DECOMP Push packer to 11,470 -Dress off for spear -Bottom of Tail pipe ~ 11,492'md Printed: 6/29/2009 3:04:48 PM • ! BP EXPLORATiON Page 6 of ~ ' Operations Summary Report Legal Well Name: L3-31 Common Well Name: L3-31 Spud Date: 6/4/2009 Event Name: WORKOVER Start: 6/12/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 16 Rig Number: Date' From - To Hours Task Code NPT Phase Deseription of Operations 6/16/2009 01:30 - 02:00 0.50 FISH P DECOMP -Circ down DP at 5 bpm / 240 psi, Filling Back side with 60 bbls/hr, no returns 02:00 - 05:30 3.50 FISH P DECOMP POH f/11,470 to 333'md -Fillin back side at 180-BPH. 05:30 - 06:30 1.00 FISH P DECOMP LD packer milling BHA. -Stand back 3-stds of 4-3/4" DCs. -LD BHA. -Clean boot baskets and recover -50-Ibs of inetal cuttings / shavings. -Wear pattern on mill. Mill is in good condition. 06:30 - 07:00 0.50 FISH P DECOMP MU packer retrieval BHA. -BHA consists of ITCO spear, Bumper sub, Jar, 3-stds of 4-3/4" DCs, Accelerator, and Pump out Sub. -Total length of BHA = 319.13'. 07:00 - 10:00 3.00 FISH P DECOMP RIH with acker retrieval BHA on 4" DP from Derrick. -RIH from 319' to 10,937'. 10:00 - 11:00 1.00 FISH P DECOMP Slip & Cut 75' of drilling line. 11:00 - 12:00 1.00 FISH P DECOMP RIH with packer retrieval BHA from 10,937' to 11,300'. 12:00 - 12:30 0.50 FISH P DECOMP MU to Top drive and establish parameters. En a e acker fish with ITCO s ear. -RIH from 11,300' to 11,411'. -MU to TD and establish parameters. -PU wt = 260K-Ibs, SO wt = 147K-Ibs. -Pumps on at 4-BPM with 1270-psi. -Taq packer fish at 11.468'. _ -PU and then run back in hole, setting down 15K-Ibs to a final depth of 11,472'. Pressure increases 20-psi. -PU and see -5K-Ibs overpull. 12:30 - 15:30 3.00 FISH P DECOMP POH with~acker retrieval BHA from 11,472' to 319'. -Stand back 4" DP in derrick. 15:30 - 16:30 1.00 FISH P DECOMP LD BHA & 7" x 2-7/8" acker fish. -Break spear out of fish. -Recovered milled packer, XO, Millout extension, XO, 2-7/8" pup jt, AVA nipple, 2-718" pup jt and W LEG. -Total length of fish = 20.34' 16:30 - 17:00 0.50 FISH P DECOMP Clean and clear rig floor. 17:00 - 18:30 1.50 FISH P DECOMP Make up 9 5/8" casina scraoer BHA to 284'. BHA consists of: -8 1/2" Bit -9 5/8" Scraper -Bit Sub -(9) 4 3/4" Drill Collars 18:30 - 22:00 3.50 FISH P DECOMP Run in hole on 4" drill pipe from 284' to 10810'. Make up the top drive and scrape from 10810' to 10967' five times pumpinq 22:00 - 00:00 2.00 FISH P DECOMP I. Break out and blow down the top drive. Pull out of the hole from 10810' to 7013', racking back the drill pipe. 6/17/2009 00:00 - 01:30 1.50 FISH P DECOMP Continue pulling out of the hole from 7013' to 284'. 01:30 - 02:30 1.00 FISH P DECOMP Stand back 4-3/4" drill collars and lay down 9-5/8" scraper assembly. Clean and clear rig floor. 02:30 - 03:00 0.50 DHB P DECOMP Make up 9-5/8" RBP BHA 03:00 - 07:30 4.50 DHB P DECOMP Run in the hole with 9-5/8" RBP on 4" drillpipe from derrick. 07:30 - 08:00 0.50 DHB P DECOMP Set 9-5/8" RBP at 10,950' COE 10,945.5' top) per HES rep. Printed: 6/29/2009 3:04:48 PM • ! BP E~PLORATIC)N' Page 7 af 9 ' Operatio:n$ Summary Repart Legal Well Name: L3-31 Common Well Name: L3-31 Spud Date: 6/4/2009 Event Name: WORKOVER Start: 6/12/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ' Descriptian of Operatic~ns 6/17/2009 07:30 - 08:00 0.50 DHB P DECOMP -PU and run back in hole to tag top of plug and confirm set. Set confirmed. -Stand back 1-std DP and fill backside, takinq -30-bbls to 08:00 - 08:30 I 0.501 DHB I P 08:30 - 12:30 4.00 DHB P 12:30 - 13:30 1.00 BOPSU P 13:30 - 16:00 2.50 BOPSU P 16:00 - 17:30 I 1.501 BOPSUFi P 17:30 - 20:00 I 2.501 BOPSUFI P 20:00 - 21:00 1.00 BOPSU P 21:00 - 00:00 3.00 DHB P 6/18/2009 00:00 - 01:00 1.00 DHB P 01:00 - 02:00 1.00 DHB P 02:00 - 12:00 10.00 DHB N 12:00 - 00:00 12.OQ DNS N 6/19/2009 I 00:00 - 14:00 I 14.00 I DHB ~ N 14:00 - 00:00 I 10.00 I DHB I N 6/20/2009 00:00 - 03:00 3.00 DHB N 03:00 - 05:00 2.00 DHB N 05:00 - 06:30 1.50 DHB P 06:30 - 07:30 1.00 DHB P DECOMP -Good test. -RD test equipment. DECOMP POH with RBP running tool, standing back 4" DP in derrick. DECOMP BOLDS and pull wear ring. RU to test BOPE. Set test plug. Fill BOP stack. DECOMP Test BOPE to 250 psi low, 3500 psi high. Test annular preventer to 3500 psi. All tests pass. Tested against test plug; 2-7/8" x 5" VBRs with 4" test joint to 250 psi Iow,3500 psi high. Good Tests. Test witness waived by AOGCC Rep John Crisp. Test witness by BP WSL Abbie Barker, Chris Kobuck and Doyon Tool Pushers Sam Dye and Pete Martinusen. DECOMP Started to see returns from the IA shut in and monitor pressure. Pressure climbed from 10 psi to 25 psi over a 30 minute eriod. Bleed off ressure, continue to monitor and saw no more ressure. DECOMP Continued to test the BOPE. Tested the annular preventer and 2-7/8" x 5" VBRs with the 2-7/8" test joint to 250 psi low, 3500 psi high. All good tests. DECOMP Rig down and blow down all testing lines. Pull the test joint and test plug. Prepare to RIH with 4" Drill pipe. DECOMP Make up the RBP retrieval tool and RIH on 4" drill pipe to ~ 9401'. DECOMP Continue in the hole from 9401' to 10812'. DECOMP Cut and slip 75' of drilling line. Service the draw works, top drive, and crown. WAIT DECOMP Clean and clear the rig floor, pipe skate, and scrub throughout the rig. Perform a hazard hunt. Waiting on completion jewelry. WAIT DECOMP Continue to clean and clear throughout the rig. Rig hands continue to work on smal! projects throughout their areas, along with scrubbing ,painting misc. items, and performing hazard hunts. WAIT DECOMP Continue cleaning throughout the rig and performing misc. maintenance projects while waiting on completion jewelry to arrive. Replace damaged signs throughout rig. WAIT DECOMP Continue cleaning and general light maintenance throughout rig while waiting for completion jewelry to arrive at rig. Incoming rig crew (Pickworth) perform Hazard Hunt. WAIT DECOMP Continue to clean throughout the rig and do general maintenance. WAIT DECOMP Strap and organize completion jewelry in the pipe shed. Wait for SW trucks to arrive on location. DECOMP RIH to'ust above RBP at 4 ' PU wt = 220K-Ibs, SO wt = 140K-Ibs. CBU at 11-BPM with 2520-psi to clean top of RBP. See some gas and crude at bottoms up. Monitor well - Static. DECOMP RIH and en~aqe RBP per HES rep. Open bypass and PU Printed: 6/29/2009 3:04:48 PM ~ ~ ~p Ex~~Q~~-ria~ Qperatior Legal Well Name: L3-31 Common Well Name: L3-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. i Rig Name: DOYON 16 Date Fram - Ta Hours Task Code NPT Phase 6/20/2009 06:30 - 07:30 1.00 DHB P DECOMP 07:30 - 12:00 4.50 DHB P DECOMP 12:00 - 15:30 3.50 DHB P DECOMP 15:30 - 16:00 0.50 DHB P DECOMP 16:00 - 17:00 1.00 DHB P DECOMP 17:00 - 18:00 1.00 DHB P DECOMP 18:00 - 20:00 2.00 RUNCO RUNCMP 20:00 - 21:30 1.50 RUNCO RUNCMP 21:30 - 00:00 2.50 RUNCO RUNCMP 6/21/2009 00:00 - 12:30 12.50 RUNCO P RUNCMP 12:30 - 13:30 1.00 RUNCO RUNCMP 13:30 - 17:30 4.00 RUNCO RUNCMP 17:30 - 19:00 1.50 RUNCO P RUNCMP 19:00 - 00:00 5.00 RUNCO RUNCMP 6/22/2009 00:00 - 02:00 2.00 RUNCO RUNCMP Spud Date: 6/4/2009 Start: 6/12/2009 End: Rig Release: 6/22/2009 Rig Number: Description of Operat~ons 25K-Ibs over string weight. Well goes on vac. Begin filling hole and RBP comes free. Begin to fill hole at 180-BPH. Stand back 1-std DP. Blow down Top Drive. POH from 10,945.5' to 5921', laying down DP to pipe shed. Maintain 180-BPH hole fill. Continue to POH from 5921' to 509', laying down DP to pipe shed. Maintain 180-BPH hole fill. Service rig floor equipment. POH & LD 4-3/4" DCs, HES RBP running tool and 9-5/8" HES RBP. RBP in good condition with all elements intact. RIH with 6-remaining stands of DP in derrick and LD to pipe shed. Pull wear ring. Rig up tubing handling equipment and torque turn equipment on the rig floor. Gather all materiais needed for running completion. PJSM with the rig crew, BP WSL, Doyon Tool Pusher, Baker hand, Doyon Casing hand. Run 2-7/8" 6.4# Vam Top 13Cr-80. All connections made up to optimum torque of 1850 fUlbs. Make up tailpipe, packer, XN nipple, X-nipples, and GLM. All joints below the packer are baker lok'd. Utilized Jet Lube Seal Guard on all connections above the packer. Continue to run 2-7/8" 6.4# Vam Top 13Cr-80 completion from joint 2 through joint 40. All connections made up to optimum torque of 1850 ft/Ibs. Utilized Jet Lube Seal Guard on all connections above the packer. Continue to run 2-7/8" 6.4# Vam Top 13Cr-80 completion from joint 41 through joint 270. MU SSSV assembly. All Connections made up to optimum torque of 1850 ft/Ibs. Utilized Jet Lube Seal Guard on all connections above the packer. Maintain continuous hole fill of 180-BPH. Hold PJSM on rigging up and running control fine with rig crew, Doyon casing rep, Baker Completions tech, BP WSL & WSLf, and Doyon toolpusher. RU spooling unit and hang sheave in derrick. HES test line to 5000-psi for 10-minutes. Good test. Begin using 120-degree SW to maintain continuous hole fill of 180-BPH. Continue to run 2-7/8" 6.4# 13cr80 Vam Top completion with single control line. Install 1-SS band per joint above SSSV for a total of 73-SS bands. Continue to fill hole at 180-BPH with 120-degree SW. Make up 4.5" CIW TCII tubinp hanper. Pick up and slack off weights after making up hanger: P/U wt 115K-Ibs, S/O wt 85K-Ibs. Land the hanger in the tubing spool and run in the lockdown screws. Make up drillpipe safety valve to landing joint and prepare to circulate completion fluids. PJSM with rig crew, CH2M truckers, WSL covering pressure test and circulating operations. Pressure circulating lines to 4000 psi. Reverse circulate 720 bbis of 120F inhibited seawater into inner annulus at 3 bpm / 10psi. Drop ball and rod with 30 minutes remaining in pumping operations to minimize loss of m i ite w s. Pump down the tubing and set the ball and rod. Set the packer and pressure test tubing to 3500 psi for 30 mins, document on Printed: 6/29/2009 3:04:48 PM • . BP EXPLORATION Page 9 of 9 Qperations Sumrnary Report Legal Well Name: L3-31 Common Well Name: L3-31 Spud Date: 6/4/2009 Event Name: WORKOVER Start: 6/12/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Gode NPi" Phase De~cription of Operatit~ns 6/22/2009 00:00 - 02:00 2.00 RUNCO P RUNCMP the chart recorder. Good test. Bleed tubin ressure to 1500 psi. Took 37 bbls to fill the annulus (fluid level - 570') and pressure IA to 3500 psi for 30 mins, document with chart recorder. Good test. Bleed tubin and shear DCR with 400 si on the tb . Pum 4 bbls both direction t 470 psi through the tubing and 340 psi reversing. 02:00 - 04:00 2.00 WHSUR P RUNCMP LD landing joint. Cameron rep t-bar in TWC. Test from below to 1000 psi for 10 mins charted, Good test. Test from above to 3500 psi for 10 mins charted, Good test. 04:00 - 05:30 1.50 BOPSU P RUNCMP PJSM covering ND BOPE and NU adaptor flange and tree. Nipple down BOPE. 2-barriers for ND BOP are 1) Ball & Rod on seat with KWF above and 2) tested TWC. 05:30 - 08:30 3.00 WHSUR P RUNCMP NU adapter flange. Cameron techs test adapter flange & seals to 5000-psi for 30-minutes, good test. Halliburton pressure test control lines to 5000 psi for 10 mins, good test. 08:30 - 10:30 2.00 WHSUR P RUNCMP Nipple up CIW 4-1/16" 5M Carbon tree. Fill tree with diesel and pressure test to 5000 psi for 10 charted mins, good test. 10:30 - 11:30 1.00 WHSUR P RUNCMP Drain tree. PU DSM Lubricator. Pressure test lubricator to 500- si - ood test. Pull TWC. LD Lubric t r 11:30 - 14:00 2.50 WHSUR P RUNCMP RU circulating lines. Hold PJSM with rig crew, LRS and WSL covering freeze protect operations. Rig up LRS and PT lines to 3500-psi. Reverse in 156-bbls of 80-degree diesel at 1.5-BPM with initial pressure of 100-psi. Near end of circulation pumping at 1.5-BPM with 550-psi. 14:00 - 15:00 1.00 WHSUR P RUNCMP Tie in tubing & IA and allow diesel to U-tube. 15:00 - 16:00 1.00 WHSUR P RUNCMP FMC tech T-bar in BPV. Test BPV to 1000-osi from below using LRS. Good Test 16:00 - 17:00 1.00 WHSUR P RUNCMP RD circulating equipment and LRS. Remove secondary annulus valve, secure the well, and prepare to move off of the well. All pressures at 0-psi. Rig released at 17:00-hrs. Printed: 6/29/2009 3:04:48 PM • L3-31 Well History Date Summary ~ 05/13/09 RAN 2.34" NO-GO CENT & TAGGED 2-7/8" CAMCO TRDP-1A C 2213' SLM. PERFORMED FUNCTION TEST ON 2-7/8" CAMCO TRDP-1A @ 2213' SLM. APPEARS FLAPPER IS NOT STROKING CLOSED. RAN 2.34" NO-GO CENT, 2-7/8" BRUSH & BRUSHED TRDP-1A @ 2213' SLM. RAN FLAPPER CHECKER TO TRSSSV AT 2213'SLM (GOOD FUNCTION TEST.) MADE TWO ATTEMPTS TO SET 2-7/8" Z-5 PERMANENT LOCK OUT TOOL. 05/14/09 ATTEMPT TO SET 2-7/8" CAMCO Z-5 LOCK-OUT TOOL IN 2-7/8" TRDP-1A AT 2,213' SLM. BRUSHED 2-7/8" TRSV AGAIN. CYCLED FLOW TUBE. MADE ANOTHER ATTEMPT TO SET 2-7/8" CAMCO Z-5 LOCK-OUT TOOL. NO LUCK. RAN 2.34" NO-GO CENT TO TOP NOGO ON TRSV. FLAGGED WIRE. RAN FLAPPER CHECKER AGAIN AND CONFIRM SPACING. SET 2-7/8" CAMCO Z-5 LOCK OUT TOOL IN 2-7/8" TRDP-1A. RAN 2.12" BLIND BOX & JARRED DOWN ON Z-5 FOR 1hr. PULLED 2-7/8" CAMCO Z-5. CYCLED FLOW TUBE. FLAPPER NOT LOCKED OUT. SET 2-7/8" CAMCO Z-5 AGAIN. RAN 2.12" BLIND BOX & JARRED DOWN ON 2-7/8" Z-5 FOR 40 MIN. RAN FLAPPER CHECKER TO TRDP-1A AT 2,213'SLM. CYCLED FLOW TUBE. NOT GRABBING PINS. GOOD INDICATION THAT TRSSV LOCKED OUT. CURRENTLY RIH W/ 2" LIB. 05/15/09 RAN 2" LIB TO 11.122'SLM (LIB SHOWS IMRESSION OF WRP). PULLED 2-7/8" WRP FROM 11122' SLM (MISSING BOTH RUBBER ELEMENTSI. RAN FLAPPER CHECKER TO TRDP-1A AT 2213'SLM (FLAPPER STILL OPEN). RAN 2-7/8" BRUSH, 2.25" WIRE GRAB TO FISH AT 11137' SLM. RECnVFRFn A 4" PIFCE OF RUBBER ELEMENT. DRIFTED TBG FOR WRP W/ 2.3" SWAGE, 2.25" LIB TO 11137' SLM. LIB INCONCLUSIVE 05/27/09 T/I/0=360/1280/0+. Temp=Sl. TBG, IA, OA FL (pre E-Line). TBG FL C~ 924' (5 bbls). IA FL C«~ 4660' (304 bbls). OA FL C«~ 66' (4 bbls). SV, WV-Closed. SSV, MV=Open. IA, OA-OTG. NOVP. 05/28/09 T/I/O =360/1280/0+. Temp=Sl. Bleed WHPs<500 psi. AL disconnected, ALP=2400 psi. Integral installed on companion. IA FL pre-bleed C~ 5200' (between sta #1 & sta#2, 340 bbls). Bled IAP to production from 1280 psi to 480 psi in 2 hr & 15 min. Monitored for 1 hr. TP & OAP unchanged, IAP increased 30 psi. IA FL C«~ 500', IA inflowed 4700'(35 bbls). Final WHPs=360/510/0+. SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. NOVP 05/29/09 T/I/0=440/680/0+. Temp=Sl. T& IA FL's for E-line (call-in). ALP-Disconnected C~ spool piece. T FL Cu~ 1320' (<10 bbls). IA FL ~ 2520' (above sta #1) (165 bbls). 05/29/09 INITIAL T/I/0=500/700/0 SET 2-7/8" WEATHERFORD WRP AT 10955' (MID-ELEMENT) STAND BY FOR LRS TO BLEED PRESSURE AND CMIT TxIA, MITOA 05/30/09 Temp= SI Assist E-line pump as directed- CMIT TxIA to 3500 psi PASSED MIT OA to 2000 psi PASSED (RWO Prep) Loaded and pressured up TxIA with 186.9 bbis 75' crude, 3rd test results= T/IA lost 40/40 psi in 1 st 15 min and 20/20 psi in 2nd 15 min for a total loss of 60/60 psi in 30 min, Bleed T/IA pressures, Bled back - 13 bbls, MITOA= Pumped 5.1 bbls down OA to reach test pressure, OA lost 140 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 180 psi in 30 min test, Bled OAP down. Bled back -2 bbls fluid. "'"Annulus casing valves left open to gauges upon departure'~' E-line still on well at time of departure. 05/30/09 STAND BY FOR LRS TO BLEED PRESSURE AND CMIT-T X IA AND MIT-OA BOTH CMIT-T X IA AND MIT-OA PASSED. JET CUT TUBING AT 10885' WITH 2.125" O.D. POWER CUTTER. FINAL T/I/O = 500/700/0 WELL SHUT IN ON DEPARTURE SSV OPEN, IA/OA OPEN TO GAUGES Page 1 of 3 ~ L3-31 Well History Date Summary 06/04/09 ~ 2.34" NO-GO CENT & TAGGED 2-7/8" CAMCO TRDP-1A . PERFORMED FUNCTIO - 8" CAMCO TRDP-1 A . APPEARS FLAPPER IS NOT STROKING CLOSED. RAN 2. T 2-7/8" BRUSH & BRUSHED TRDP-1A C 2213' SLM. R R CHECKER TO TRSSSV ' GOOD FUNCTION ADE TWO ATTEMPTS TO SET 2-7/8" Z-5 PERMANENT LOC T/I/0=300/300/0 Circ-Out Weli ( PRE RWO ) Pumped 10 bbls neat and 1190 bbls of sea water down tubing taking returns up IA to the flowline. Pumped 150 bbls of diesel into the IA then U- Tubed TxIA to freeze protect. Pumped 5 bbls neat and 15 bbls diesel to freeze protect flowline. CMIT TxIA Inconclusive at 1000 psi. after 2 attempts. First CMIT tx IA to 1000 psi lost 50/40 psi in the first 15 mins 30/30 psi in the second 15 mins for a total of 80/70 in 30 mins. re-pressure to 1010 psi. CMIT lost 40/40 in 15 mins, 30/30 in the secondd 15 mins 30/30 for the third 15 mins for a total of 130/130 in 45 mins. Bled pressure down to 500/500/40. CMIT TxIA was inconclusive at 500 psi. CMIT tx IA lost 20/20 in the first 15 mins, 30/30 psi inthe second 15 mins for a total of 50/50 psi in 30 mins. Bled TxIA to 0 psi. and let well rest for 1 hr. Attempted a CMIT TxIA Inconclusive at 1000 psi. Pumped 3.5 bbis of 50*F diesel to reach test pressure, T/IA lost 40/30 in the 1st 15 min. 30/20 in the 2nd 15 min. and 20/30 in an additional 15 min. for a total loss of 90/80 psi. in a 45 min. test. Bled WHP to 310/340/40. Pumped 0.5 bbls of 50'`F diesel to CMIT TxIA to 500 psi. Inconcl~ 06/05/09 T/I/0= VACNAC/VAC. Temp= SI. TBG & IA FL's. AL spool piece disconnected. TBG FL C~3 40' (.2 bbls). IA FL C~3 40' (2.6 bbls). SV, W V= C. SSV, MV- O. IA, OA= OTG. NOVP. 06/06/09 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T DHD bled WHP to 0 psi. RU 1 HP BT onto THA 200 psi bled to 0 psi, flushed void until clean returns achieved. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled IC void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. Bled void to 0 psi, RD all test equipment. PPPOT-IC RU 1 HP BT onto IC test void, 150 psi bled to 0 psi, flushed void until clean returns achieved. Pressured IC void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, cycle and torque LDS "Standard" (2) pins broke in wellhead (1) between 12:00 & 3:00 (1) C~? 3:00, all others were in good working and visual condition. RD all test equipment. 06/06/09 T/I/0= VACNAC/VAC. Temp= SI. CMIT-TxIA to 1000 psi (RWO prep). AL spool removed. F/LP= 500 psi. Pumped 4.3 bbls diesel to increase TP, IAP to 1000 psi. TP, IAP decreased 25 psi in the first 15 minutes, 5 psi in the second 15 minutes for a total loss of 30 psi in 30 minutes. Bled TP, IAP from 970 psi to 0 psi in 10 minutes. Bled back 3 bbls. Final WHP's= 0/0/0. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. P~ ~~ 06/07/09 T/I/0= 0/0/0 Set 2-9/16" CIW "H" BPV # 352 thru tree, no ext. used..tagged C~ 100"...pre-rig...no ~ problems. /~ 06/07/09 T/I/O = 0/0/0 Installed 2 1/16" CIW HWO valve on backside O/A. Tested to 3000 psi. Removed McEvoy I HWO valve from frontside O/A. Installed VR plug and tapped blind on frontside O/A. Pre RWO. 06/22/09 T/I/O=Vac/0/0. Pulled 4-1/16" CIW H TWC thru tree, post tree test. 1-2' ext. used, tagged @ 102". No Problems. 06/28/09 T/I/O = 0/0/0 Pulled 4" CIW H BPV w/ 1-2' ext. C«~ 102" Post Riq. Installed 2" FMC HWO valve on frontside O/A and pulled VR plug. ~ oS~ ~ ~ Page 2 of 3 ~ L3-31 Well History Date Summary ~ 05/1 4" NO-GO CENT & TAGGED 2-7/8" CAMCO TRDP-1A @ 2213' SLM. P FUNCTION TE " O TRDP-1A @ 2213' SL LAPPER IS NOT STROKING CLOSED. RAN 2.34" NO-G ' & BRUSHED TRDP-1A @ 2213' SLM. RAN F KER TO TRSSSV AT 2213'SLM (G E TWO ATTEMPTS TO SET 2-7/8" Z-5 PERMANENT LOCK OUT TOOL. 06/29/09 PULL DSSSV FROM SVLN C«~ 2184' SLM/2198' MD SET X- C.SUB IN NIPPLE C~3 10,873' SLM/10870' MD CURRENTLY RIH TO PULL STA#3 06/30/09 PULL DGLV'S FROM STA#3 (10,817' SLM), STA#2 (8797' SLM), DCR FROM STA#1 (5307' SLM) SET DEEP DESIGN (SEE DATA TAB #5) PULLED 2 7/8" "X" CATCHER SUB FROM 10,873' SLM PULL B&R FROM RHC-M PLUG BODY C~ 11,064' SLM PULL 2 7/8" RHC-M FROM "XN" NIP. C~ 11,068' SLM RAN 2.15" CENT, TEL, S.BAILER, LOC LWR TT C~ 10,502' SLM (-13' = 10,489' MD) TAG HARD BTM C«~ 11,581' SLM (-13' = 11,568' MD), FLAG LINE C~ 10,571' SLM ~ 07/01/09 Assist slick line with memory log; Pumped 5 bbls neat meth, 130 bbis 1% KCL, and 28 bbis crude down TBG while slick line logged. IA & OA valves left open to gauges upon departure FWP's=0/0/0 07/01/09 PERFORM STP / WARM BACKS / MEMORY SURVEY / SIBHPS, JEWELRY LOG (UNABLE TO do 40FPM passes) 07/04/09 T/I/0=530/2060/0+. Temp=Online. IA FL (for LPC). ALP=Online. IA FL C~ 10,320' (above sta #3, SO). SV=C. WV, SSV, MV=O. IA, OA=OTG. NOVP. 07/09/09 LOG PRODUCTION PROFILE WITH DEFT AND GHOST FROM 11500'-11200' SHUT-IN PASSES INDICATE NO CROSSFLOW PRODUCTION RATE 1: 642 BOPD, 1399 BWPD, 1.7 MM FORM GAS, 2.8 MM LIFT, 89 WHT, 587 WHP, 80 CHOKE FIELD PRODUCTION SPLITS: 100% OF PRODUCTION COMING FROM 11256'-11275'. MINIMAL PRODUCTION FROM BELOUV 11490' PRODUCTION RATE 2: WHP 880, 87 WHT, 3.2 MM LIFT, 1.2 MM FORM, 580 BOPD, 1066 BWPD, CHOKE 50 PRODUCTION SPLITS UNCHANGED JEWELRY LOG RUN FROM 11500'-10700' FINAL T/I/O = 2000/1800/0 PSI 07/11/09 DRIFT W/ 2.34" CENT, 3' X 1.25" STEM, 2 7/8" BRUSH, 2.26" GAUGE RING TO 2181' SLM. SET 2 7/8" FXE SSSV SER# FX2-01 C~ 2181' SLM. PERFORM SUCCESSFUL CLOSURE TEST. Page3of3 06/27/08 ~~i~~~m~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll .Inh it ~~~~~~ ~UL ~ (; ZQU~ 1 nn nncwv:..tiw.. NO.4763 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ^~(~ Anchorage, AK 99501 N-04A 11962603 PRODUCTION PROFILE , ,~~ .. _" "_ a_ ~ ,y 06/23/08 1 1 L2-06 11999020 PRODUCTION PROFILE ,., ~".~' ,;_ 06/15/08 1 1 L3-31 12005214 MEMORY SBHP •*~-y "' d.,l rf~>- ~ 06/11/08 1 1 C-02 11982437 PRODUCTION PROFILE ,~• ; ~ ~-~• e.r~: h'~'`~°a 06/20/08 1 1 E-39A 12066529 SCMT ~~'~~~ •=•P' ~+6~ ~/ %` ~°'`y 06/19/08 1 1 MPC-09 12005215 MEM PROD PROFILE p~r,°~" -•"•f `'C,,, i ::.,,:,k~_; ~ 06/12/08 1 1 W-31 12014027 LDL ,A ":f - (' f `"~ ' =-1 ~) ~ ~ ~' • ~' ` ~ 06/15/08 1 1 02-04A 11962602 USIT d~~,' - a;-j;~ "~P'~--~r,~~'y 06/22/08 1 1 02-04A 12086662 USIT ~ ~ , .. / ~"°°-^; ~ p ~~x~ ~ 06/20/08 1 1 r~.-.vr rev nnv~~ccvanc ncv car 1 v ~ v~un~~~V /11~V nGl Vn1YilYV VIYG liVri GNVfI 1 V: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 i'i ii ~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400', Anchorage, AK 99,503-2838 ATTN: Beth ,` '~ ti Received by: ~~ P • 1 '. ~ ~ . . {.(~" t:;^;,;;' f,"\ :::^::l t';,,:, ! ,U :) 1/" ! ¡ I ¡ ',', II" \ i )! 1 L, ")') ¡ 1..-1 \ II I [ æ~ L Ln.. ,~ L_, ("r') \ I" r'~.). illJ U~ ";, i'l I-', (';~-,ï'n 1"1-\ Ir',III.!f,¡,\i..JI"ifn\ 11\\I! m\\,".,I:i !fl. IrÙ L6 u~ cQ) l ~ Lf\i i Î FRANK H. MURKOWSKI, GOVERNOR l' AI,ASKA OIL AND GAS CONSERVATION COMMISSION ¡ 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. 0, Box 196612 Anchorage, AK 99519-6612 {~~~O3~ Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU L1 PBU L2 PBU L3 Date of SVS Test Apri123,2004 April 26, 2004 April 27, 2004 Failure Rate 30,0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \\\'t th SVS test. (l Sincerely, 2J~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) ~ ~ " t Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/27/2004 UnitlFieldlPad: Greater Pt McIntyre/Lisbume/L3 Separator psi: LPS 450 HPS 450 "Wllæ~ _¡m- 1118 "". EIl1JßlllltlþlllJ1l8 ~- Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L3-01 1890750 12/4/1993 SI L3-02 1861540 450 350 350 P 6 P OIL L3-05 1851950 1/14/2003 SI L3-08 1831430 7/2/1994 SI L3-11 1852310 9/9/2003 SI L3-12 1861610 4/19/1997 SI L3-15 1852660 12/22/1996 SI L3-18 1861670 2/16/1997 SI L3-19 1852860 11/17/2001 SI L3-22 1861750 6/4/2003 SI L3-23 1853060 6/26/1995 SI L3-24 1861820 5/12/1997 SI L3-28 1890660 9/7 /1993 SI L3-30 1861850 11/25/1996 SI L3-31 1860340 7/28/2003 SI Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service SSV Page 1 of 1 SVS PBU LIS L3 04-27-04,xls 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Repair well Plugging Perforate Pull tubing Other STATE OF ALASKA AL: ,,.,-,A OIL AND GAS CONSERVATION COMMI;:~rDN REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic' _ Service Location of well at surface 1170' FNL, 726' FWL, Sec. 22, Tll At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, Tll At effective depth 1603' FNL, 1342' FEL, Sec. 28, Tll At total depth 1632' FNL, 1353' FEL, Sec. 28, Tll N, R15E, UM N, R15E, UM N, R15E, UM N, R15E, UM 6. Datum elevation (DF or KB) RKB ,51' 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L3-31 9. Permit number/approval number 86-0034 10. APl number ~ 50-029-215.~4 -00 11. Field/Pool USBURNE OIL POOL feet 12. Present well condition summary Total Depth: measured 1 2006' feet true vertical 9593' feet Plugs (measured) None Effective depth: measured 1 1 950' feet Junk (measured) None true vertical 9547' feet Size Cemented 2 0" 1750# Poleset 13-3/8" 2950 sx AS III & 600 sx Class G 9 - 5 / 8" 1068 sx Class G 7" 318 sx Class G Measured depth True vertical depth 110' 110' 4032' 3882' Casing Length Structural Conductor 8 0' Surface 4 0 0 3' Intermediate Production 1 1 1 7 9' Liner 1 0 0 7' 1 1204' 8927' 10999'-12006' 8765'-9598' RECEIVED JUN - 8 392 Alaska 0il & 6as Cons. C0mmissM Anchorage Perforation depth: measured 11522'-11570', 11256'-11346', 11400'-11500' true vertical 9190'-9230', 8970'-9044', 9056'-9140' Tubing (size, grade, and measured depth) 2-7/8" L-80 rgb w/tail @ 11,358' wired Packers and SSSV (type and measured depth) Pkr @ 10931' md, single selective @ 11,356', 7" Isolation @ 11477' md & TRDP-1A-SSSV @ 2184' md 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Wahoo 7 Treatment description including volumes used and final pressure Please refer to the attached Tubing Pressure Prior to well operation Re[~resentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 479 Subsequent to operation 232 1570 542 525 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 760 2768 761 Service 16. Status of well classification as: Water Injector__ Oil X Gas Suspended SUBMIT IN D(JPLICA'I:E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_.~¢'~~.~~,~ Title Lisburne Operation Engineering Aide Form 10-404 Rev 05/17/89 Date 7/28/91: 8/18/91: 12/12/91: 1/15/92 Lisburne Well L3-31 Perforate and Stimulate Procedure-Wahoo 7, 6 & 5 Event Rigged up Dresser Atlas Wireline. Perforated Wahoo 6 at 11,400, 401,406, 407, 425, 426, 438, 439, 471,473, 490, 492, 494, 496, 498, 500 with a 2-1/8" 20.5 gram through tubing gun. Rigged up Halliburton Services. Pressure tested lines - ok. Acidized Wahoo 6 and 5 perforations from 11,400' to 11,570' MD With the following fluids: 100 BBL Gelled Acid 70 BBL Crude Shut down pumps. Return well to production. Made unseccessful attempt to treat Wahoo 7 interval. Acidized Wahoo 6 and 5 perforations from 11,400' to 11,570' MD With the following fluids: 1215 BBL Emulsified Acid 1555 BBL Gelled Water 562 MSCF Nitrogen 100 BBL 15% HCL Acid 30 BBL 60/40 Methanol/Water (freeze protect) Shut down pumps. Returned to production. Rigged up BJ Services. Pressure tested lines - ok. Closed Fracture Acidized perforations from 11256' to 12,346' MD With the following fluids: 1182 BBL Emulsified Acid 1370 BBL Gelled Water 250 MSCF Nitrogen 30 BBL 60/40 Methanol/Water (freeze protect) Shut down pumps. RD. Return well to production. RECEIVED JUN - 8 ! 92 Alaska Oil .& Gas Cons. Commission Anchorage ,~_Ac., OIL AND GAS CONSERVATION COMMIb,51Oh, APPLICATION FOR SUNDRY APPROVALS 1. ~ype CT Heques~: Abandon Suspend Operation shutdown__ Re-enter suspended well__ Alter casing' Repair well Change approved program Plugging Time extension Stimulate__~_X Pull tubing Variance Perforate~ Other 2. Name of Operator ARCO ALASKA INC. 5. Type of Well: Development Exploratory.__ Stratigraphic Service 3. Address P.O. BOX 100360 ANCH. AK 99510 4. Location of well at surface 1170' FNL, 726' FWL, Sec. 22, T11N, R15E, UM At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, T11 N, R15E, UM At effective depth 1603' FNI_, 1342' FEL, Sec. 28, T11N, R15E, UM At total depth 1632' FNL, 1353' FEL, Sec. 28, TllN, R15E, UM 6. Datum elevation (DF or KB) RKB 51 ' 12. Present well condition summar, y Total depth: measurea true vertical 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L3-31 9. Permit number 10. APl number 50-029-21544-00 11. Field/Pool LISBURNE OIL POOL iGiNA Perforation depth: Casing Length Size Cemented Measured depth Structural Conductor 80' 20" 1750# Poleset 110' Surface 4003' 13-3/8" 2950 sx AS III & 4032' Intermediate 600 sx G Production 11179' 9-5/8" 1068 sx Class G 11204' Liner 1007' 7" 318 sx Class G 10999' - 12006' Effective depth: measured 11950' feet Junk (measured) NONE true vertical 9547' feet 12006' feet Plugs (measured) NONE 9593' feet True verticalde~h 110' 3882' 8927' 8765'-9593' Measured Depth 11522'-11570', 11256'-11346', 11400-11500' True Vertical Depth 9190'-9230', 8970'-9044', 9056'-9140' Tubing (size, grade, and measured depth) 2-7/8" L-80 tbg w/tail @ 11,358' wlmd RECEIVED DEC - 2 !99t Alaska 0il & Gas Cons. C0mmissi~ Packers and SSSV (type and measured depth) ~,nm~0rage Pkr @ 10931' md, single selective @ 11,356', 7" Isolation @ 11477' md & TRDP-1A-SSSV @ 2184 , 13. Attachments Description summary of proposal X_~_ Detailed operations program. BOP sketch~ 14. Estimated date for commencing operation December 3~ 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil_,~_ Gas Suspended Service Approved by order of the Commission "l~orm 10-403 Rev 06/15/88 17. I hereby certify that the fo, r~~e and correct to the best of my knowledge. Signed ~"~'~ T.E. Krawietz Title: Sr. Operation Enqr. ATO 484 ~ -' ~ FOR COMMISSION USE ONLY Conditions of approvah Notify Commission so representative my witness I Approva, No~ ~/.~ Plug integrity__ BOPTest Location clearance ,/ Mechanical Integrity Test Subsequent form required 10- I 0~'?u~ C SN~IT}'~ CommissiOner Date /~/~//~/ Date SUBMIT IN TRIPLICATE feet Lisburne Well L3-31 Stimulation Procedure , . . . . . Pull gaslift valves and install dummy GLV's and BCP isolation sleeve to isolate lower Wahoo 5 and 6 zones. RU stimulation company. Well control provided by surface chokes and production valves. Closed Fracture Acidize Wahoo 7, at maximum treating pressure of 5,000 psi with the following stimulation fluids: 1,230 bbls 40 pptg gelled water. 1,200 bbls 30:70 crude/10% HCL emulsified acid. Pull BCP isolation sleeve and install BPI isolation sleeve to isolate Wahoo 7. RU stimulation company. Well control provided by surface chokes and production valves. Closed Fracture Acidize Wahoo 5 and 6, at maximum treating pressure of 5,000 psi with the following stimulation fluids: 1,220 bbls 40 pptg gelled water. 1,200 bbls 30:70 crude/10% HCL emulsified acid. Release service company and open well to flow. Estimated Static BHP = 2,700 psig at 8,900' ss. RECEIVED DEC - 2 991 Alaska Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA AL,-,,.,KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. l ype eT Hequest: Abandon Suspend Alter casing Repair well Change approved program Operation shutdown Re-enter suspended well Plugging__ Time extension Stimulate X Pull tubing Variance Pedorate_z~_ Other 2. Name of OperatOr ARCO ALASKA INC. 3. Address P.O. BOX 100360 ANCH. AK 99510 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 1170' FNL, 726' FWL, Sec. 22, T11N, R15E,UM At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, T11 N, R15E, UM At effective depth 1603' FNL, 1342' FEL, Sec. 28, T11N, R15E, UM At total depth 1632' FNL, 1353' FEL, Sec. 28, T11 N, R15E, UM 6. Datum elevation (DF or KB) RKB 51 feet 7. Unit or Property name prvdhQe/Lisburne Unit 8. Well number L3-31 9. Permit number 9-1006 10. APl number 50-029-21544-00 11. Field/Pool LISBURNE OIL POOL 12. Present well condition summar, y Total depth: measureo 12006' feet true vertical 9593' feet Plugs (measured) NONE Effective depth: measured 11950' feet Junk (measured) NONE true vertical 9547' feet Casing Length Size Cemented Structural Conductor 80' 20" 1750 lb. Poleset Surface 4003' 13-3/8" 2950 sx AS III & Intermediate 600 sx Class G Production 11179' 9-5/8" 1068 sx Class G Liner 1007' 7" 318 sx Class G Measured depth 110' 4032' 11204' 10999-12006' Trueverticaldepth 110' 3882' 8927' 8765-9593' Perforation depth: Measured Depth 11522'-11570', 11256-11346' True Vertical Depth 9190-9230', 8970-9044' Tubing (size, grade, and measured depth) 2-7/8" L-80, tbg w/tail @ 11,358' WLM Packers and SSSV (type and measured depth) RECEIVED JUN - G 1991 Alaska Oil & Gas Cons. Commission Pkr @ 10931', Single Selective @ 11,356', 7" ISOLATION @ 11477' & TRDP-1A-SSSVAjj)CfI(~e 13. Attachments Description summary of proposai_~. Detailed operations program BOP sketch_z~__ 14. Estimated date for commencing operation June 20, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil_j~_ Gas Suspended Service 17. I hereby certify that the fo. regoin i~ue and correct to the best of my knowledge. Signed 7 ,~ /,~l-'~,~ T.E. Krawietz Title: Sr. OperationEnqr. ATO484 Date ~,/~'/~/t ~_~",, FOR COMMISSION USE ONEY Conditions of approval: Notify Commission so representative my witness I Approval No. Plug integrity BOP Test Location clearance I Mechanical integrity Test Subsequent form required 10- Approved Copy ,,-,-7- //Returned -~/' Approved by order of the Commission ORIGINAL SIGNED BY C~o , ~.~ Form 10-403 Rev 06/15/88 LONNIF. C, SMIT~ ' ' '--- Date & "/0 "~/J SUBMIT IN TRIPLICATE Lisburne Well L3-31 Stimulation Procedure 1. Pull BPI sleeve. 2, Add 16 perforations to the Wahoo 6 (11400, 401, 406, 407, 425, 426, 438, 439, 471, 473, 490, 492, 494, 496, 498, 500). , RU stimulation company. Well control provided by surface chokes and production valves. 3, Acidize Wahoo 6 at maximum treating pressure of 1500 psi with 100 bbls 15% gelled HCL flushed with crude. Release service company and open well to flow. Static BHP = 2700 psig at 8900' ss 12/90. Alaska Oil & Gas Cons. Commissio~ Ar~chorage WIRELINE BOP EQUIPMENT ii iii , 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS! WIRELINE RAMS 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK OFF RECEIVED JUN - f ~a~ Ataska Oij & Gas Cons. Commission Anchorage ..... ' STATE OF ALASKA AL,-~ , OIL AND GAS CONSERVATION CO .... 3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other EX Restimulate ,y 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska INC. RKB 51 Feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay/Lisburne 4. Location of well at surface 1170' FNL, 726' FWL, Sec. 22, TllN, R15E, UM At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, TllN, R15E, UM At effective depth 1603' FNL, 1342' FEL, Sec. 28, TllN, R15E, UM At total depth 1632' FNL, 1353' FEL, Sec. 28, TllN, R15E, UM 11. Present well condition summary Total depth: measured 12006 feet Plugs (measured) true vertical 9593 feet 7. Well number L3-3! 8. Approval number 7-787 9. APl number 5O-029-21544 10. Pool Lisburne Oil Pool Effective depth: measured 11950 feet Junk (measured) true vertical feet 9547 Casing Length Size Cemented Structural Conductor 80' Surface 4003 ' Intermediate Production 11179' Liner 1007' Perforation depth: measured 11256'-11346', 11522'-11570' true vertical 8970'-9044' 9190'-9230' lubing(size, grade and measured depth) 2-7/8", L-80, 11358' Measured depth ~ue Verticaldepth 20" 1750# Poleset 101' 101' 13-3/8" 2950 sx PF "E" & 4032' 3883' 600 sx Class G 9-5/8" 1060 sx Class G 11204' 8927' 7" 318 sx Class G 10999'-12006' 8765'-9593' Packers and SSSV (type and measured depth) PKR: 9-5/8" @ 10931', 7" Single Selective @ 11356', 7" Isolation @ 11477': SSSV: Camco TRDP-la, 2.232 12. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo 7 Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 331 695 61 Casing Pressure 424 643 15 Tubing Pressure 451 426 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Technical Aide Date . 12-4-87 Submit in Duplicate~ ARCO ALASKA INC. HAS COMPLETED THE RESTIMULATION WORK ON WELL L3-31 FOR THE WAHOO 7 ZONE. THE SUMMARY IS AS FOLLOWS: 1. RIG UP COIL TUBES 2. RIH TO 10,200' W/CIRCULATION NOZZLE 3. PUMPED 50 BBLS 15 % HCL 4. DISPLACED ACID W/40 BBL DIESEL .... STATE OF ALASKA ALA .... OIL AND GAS CONSERVATION CO, ..... ..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other)i[] Rest 2. Name of Operator ARCO Alaska Inc. 3'Addressp.0. Box 100360 4. Location of well at surface 1170' FNL, 726' Anchorage, Alaska 9§510 FWL, Sec. 22, T11N, R15E, UM 5. Datum elevation (DF or KB) RKB 51' feet At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, T11N At effective depth 1603' FNL, 1342' FEL, Sec. 28, T11N At total depth 1632' FNL~ 1353' FEL~ Sec. 28~ T11N , R15E, UM , R15E, UM ~ R15E~ UM 6. Unit or Property name Prudhoe BaS Unit/Lisburne 7. Well number L3-31 11. Present well condition summary Total depth: measured true vertical 12006 feet 9593 feet Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 4003' Intermediate Production 11179' Liner 1007' Perforation depth: measured 11256'-11346', 11522' true vertical 11950 feet 9547 feet Size 20" 13-3/8" 9-5/8" 7" -11570' 8970' -9044' 9190' -9230' Tubing (size, grade and measured depth) 2-7/8" L-80, 11358' Plugs (measured) Junk (measured) Cemented 1750# Poleset 2950 sx PF "E" & 60C sx Class G 1060 sx Class G 318 sx Class G 8. Permit number tiff-34 9. APl number 50--029-21544 10. Pool Lisburne Oil Pool NONE NONE RE£E VED 0il & Gas Cons. C0mmissi0~¢ Anchorage True Vertical depth Measured depth 101' 101' 4032' 3883' 11204' 8927' 10~'99'-12006' 8765'-9593' Packers and SSSV (type and measured depth) 9-5/8" @ 10931' 7" single selective @ 11356', 7" Isolation @ 11477'; SSSV' Camcc TRDP-IA 2.232 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 12, 1987 Date approved 14. If proposal was verbally approved Name of approver that the foregoing is true and correct to the best of my knowledge ~~,~ Title Technical Aide Date 10-8-87 Commission Use Only 15. I here/~ certify Signed Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ¢. Commissioner Approved by Form 10-403 Rev 124-85 Approval No. '7 ~ by order of the commission Date /~-- Submit in triplicate~ L3-31 ACID RESTIMULATION PROCEDURE WAHOO 7 ARCO ALASKA INC. PROPOSES TO RESTIMULATE L3-31, WAHOO 7.. THE PROCEDURE IS SUMMARIZED AS FOLLOWS: 1. RIG UP COIL TUBES 2. RIH TO 10,200' W/CIRCULATION NOZZLE 3. PUMP 50 BBLS 15% HCL @ 1BPM 4. DISPLACE ACID W/40 BBL DIESEL. 5. POOH 6. OPEN WELL TO FLOW. STATE OF ALASKA ALASK ')IL AND GAS CONSERVATION COMM ~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other [] Stimulate/~ Plugging [] Perforate [] Pull tubing [] 2. NameofOperator ARCO ALASKA~ INC. 3. Address P.O.B. 100360, ANCHORAGE, 4. Location of well at surface 1.1A~3o~flucti'~:At'er~a~/L, Sec. 22, T11N, 1520' ~'NL. 1320' FEL Sec. 28, TiiN, ATeffec-tive depth ' 1603' FNLo 1342' FEL, Sec. 28, TllN, At total depth 11. Present well condition summary Total depth: measured 12006' feet true vertical 9593' feet AK. 99510 R15E, UM R15E, UM R15E, UM RI~.IIM 5. Datum elevation(DForKB) RKB 51 Fee 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number L3-31 8. Approval numbe~80 9. APl numbe~29_21544 50-- 10. Pool LISBURNE OIL POOL Plugs (measured) NONE Effective depth: measured . feet true vertical]. 1950' feet 9547' Casing Length Size Structural 80 ' 20" Conductor 4003' 13-3/8" Surface Intermediate 11179' 9-5/8" Production Liner 1007' 7" Perforation depth: measured Junk (measured) NONE Cemented Measureddepth ~ueVerticaldepth 1750# POLESET 110' 110' 2950 sx PF "E" & 4032' 3882' 600 sx class G 1068 sx class G & 11204' 8927' 318 sx class G 11522'-11570', i1256'-11346' truevertical 9190'-9230', 8970'-9044' ~bing(size, gradeand measureddepth) 10999-12006' 8765-9593' RECEIVED FEB .- 4 ].987 Naska 011 & Gas Cons. Commlssi::~:-~ 2- 7 / 8", L 80, 11358 ' AnchoraO$ r th Packers: 9-5/8" @ 10931, & 7" SINGLE Packers and~SI~E'(~'~:~:d~eals.~g§~ )7" ISOLATION @ 11477' SSSV: 2-7/8'@ 2184' 12. Stimulation or cement squeeze summary _ + Intervals treated (measured) I Treatment description including volumes used and final pressure - + SEE ATTACHED SUMMARY 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1470 1561 0 1300 1671 2083 0 1300 Tubing Pressure 430 425 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. i hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-40~ Rev. 12-1-85 Title LISBURNE OP. COORD. 2/2/87 Date Submit in Duplicate DATE 12-29 1-2 1-3 L3-31 LOG OF EVENTS LOG ENTRY Test well pre-stim, rate test,1470BOPD/1561MSCFD/1062GOR Restimulate W7 through AVA nipple Fluid pumped: 10bbls diesel + 10% mutual solvent 96bbls 15% HCI 85bbls diesel flush Pumped easily with acid stage pumped at 350psig and 6BPM. Final rate with full column of diesel prior to SD of 9.5BPM at 2400psig. Acid additives: 42G Musol A, 0.2% HAl-75 , 0.4%Losurf 300 , 0.2% AS-5 0.1% FDPS 377(scale inhibitor) , 20#/MG FDPS 387(iron sequ. ag.) 10G/MG FR-5 friction reducer , ISIP = 425psig and remained stable Post-stimulation rate 1671BOPD/2083MSCFD/1264GOR RECEIVED FEB-- 4 ]987 Alaska 0il & Gas Cons. Anchorage LISBDRNE ENGINEERING Date: 1-22-87 From: Pam Lambert Enclosed are the following: OH Finals for L3-30 ---o RFT Tester (Raw) 1-2-87 Run 1 Sch RFT Interpretation 1-2-87 Run 1 Sch ~ LDT/CNL (Raw) 1-2-87 Run 1 2"&5" Sch "-OLDT/CNL (Poro) 1-2-87 Run 1 2"&5" Sch ~"'~DLL/SGR 1-2-87 Run 1 2"&5" Sch Cyberlook 1-2-87 Run 1 Sch ~ Geocolumn 1-2-87 Run 1 5" Sch ~ CBL 1-2-87 Run 1 5" Sch x---O' CNL in 9 5/8 Casing 1-2-87 Run 1 2"&5" Sch Received by: Please sign and return tol pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 145 Date: 1-28-87 From: Para Lamber t ARCO-ALASKA INC. LISBURNE ENGINEERING Enclosed are the following: CH Finals for L3-31 ~'OPacker Setting Record 5-1-86 Run 1 Sch ~""°CBT 4-22-86 Run 1 Sch '""~ GCT Directional Survey 4-21-86 Run 1 5" Sch x'° CBL 3-21-86 Run 1 5" Sch xx'° Squeeze Gun Record 4-22-86 Run 1 Sch ~.~ CBL 4-29-86 Run 2 5" Sch Received by_i_ Plea ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 152 STATE OF ALASKA ALASF-A OIL AND GAS CONSERVATION COM~-ISSION APPLICA.. ION FOR SUNDRY A, PROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown El Re-enter suspended well [] Alter casing E] Time extension [] Change approved program [] Plugging O Stimulstexl~X Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 4. Locationofwellatsurface 1170' FNL, 726' FWL, Attopofpmductiveinte~al 1320' FNL, 1320' FEL. Ateffectivedepth 1603' FNL, 1342' FEL, Attotaldepth 1632' FNL, 1353' FEL, Sec. 22, TilN, R15E, UM Sec. 28, TllN, Ri5E,UM Sec. 88, TllN, R15E, UM Sec. 28, TllN, R15E,UM 5. Datum elevation (DF or KB) RKB 51 feet 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number L3-31 8. Permit number 86-34 9. APl number 50-- 029-21544 10. Pool LISBURNE OIL POOL 11. Present well condition summary Total depth: measured true vertical 12006 ' feet Plugs (measured) 9593' feet NONE Effective depth: measured 11950' true vertical 9547' feet · Junk (measured) feet NONE Casing Length Structural Conductor 80' 4003' Surface Intermediate 11179 ' Production Liner 1007 ' Perforation depth: measured Size 20" 13-3/8" 9-5/8" Cemented Measured depth True Vertical depth 1750~ POLESET 110' 110' 8950 s× PF "E" & 4032' 3882' 600 sx class G 1068 mx class G & 11204' 8927' 11522'-11570' , 11256'-11346' true vertical 9190'-9230' , 8970'-9044' Alaska Oil & Gas Tubing (size, grade and measured depth) A c o- 2-7/8", L80, 11358' PackerS and S ,~~o~m[asMEe~p, th) Packers= 9-5/8" ~ t093i' [ 7" SINGLE bb liVb ~ 1 i~Ob , 7" ISOLATION ~ i 1477' SSSV: 2-7/8'~ 2184 ' 12.Atlachments Description summa~ of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation DECEMBER 26~. 1986 14. If proposal was verbally approved Name of approver LONNIE SMITH Date approved 12/23/86 15. I hereby certify th. Signed Conditions of approval Approved by the foregoi~ is true and correct to the best of my knowledge Ti' ; Li Commission Use Only Notify commission so representative may witness I Approval No. [] Plug Integrity [] BOP Test [] Location clearance~ Date Commissioner the commission Date Form 10-403 Rev 124-85 Submit in triplicate SUMMARRY OF WELL OPERATIONS LISBURNE WELL LB-B1 ARCO Alaska~ Inc. proposes to stimulate Wahoo zone ? of Lisburne well L3-B1 with 95 bbls of 15~ HC1. The acid will be pumped through tubing and the well will be cleaned up to the L3 drillsite facilities. .... STATE OF ALASKA ALA[ OIL AND GAS CONSERVATION COM .;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate'~ Plugging [] Perforate~ Pull tubing Alter Casing [] Other 2. Name of Operator ARCO ALASKA, 1' NC. 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 5. Datum elevation(DForKB) RKB 51 Feet 6. UnitorPropertyname Prudhoe Bay/Lisburne 4. Location of well at surface 1170' FNL, 786' FWL At top of productive interval 1320' FNL, 1320' FEL. At effective depth 1603' FNL, 13~+P' FEL, At total depth 1632' FNL~ 1353' FEE 11. Present well condition summary Total depth: measured true vertical Sec. 88, TllN, R15E, UM Sec. 28, TllN, R15E,UM Sec. 88, TllN, R15E, UM Sec. 28, TIlN, RI5E,UM 12006' feet Plugs(measured) 9593' feet 7. Well number L3-31 8. Approval number '73 9. APl number 0E~9-215/-+4 50-- 10. Pool LISBURNE OIL pOOL NONE Effective depth: measured i 1950' true vertical 9547' Casing Length Structural 80' Conductor AO03' Surface Intermediate 1 i 179' Production 1007 ' Liner Perforation depth: measured 11522 ' -11570 ' true vertical 9190'-9230' , Tubing (size, grade and measured depth) 2-7/8", L80, Size 20" 13-3/8" 9-5/8" feet Junk (measured) NONE feet Cemented Measured depth 1750# POLESET 110' 2950 sx PF "E" & 4032' 600 s× class G 1068 sx class G & 11204' 318 sx class G 10999-18006' 11256'-11346' 8970'-9044' BPF~i~s ,~r~ S~SS~ t~l;~-e6a, nd r~~e:d dEe.p~' 2" 11358' Packers: 9-5/8" BROWN HB @ CAMCO TRDP-1A @ 218A' ~ueVerticaldepth 110' 3882' 8927' 8765-9593' 10931' & 7" 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data ~:.. . OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation N/A 1500 1350 0 0 700 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 LISBURNE OP. COORD. 12/2/86 Title Date Submit in Duplicate Well L3-31 Wahoo 5 Acid Treatment S~ary/Log of Events Perforations: 11,522' - 11,570' ~D Date Time Pre-Stimulation Flow Test , Los of Events _ 8-21-86 RIH and pull AVA 'BCP' and replace w~th AVA 'BPI' to isolate Wahoo 7. Stimulation 8-24-86 0730-1026 hours Pump I0 bbls diesel + 10I mutual solvent pre-flush. Follow vith 90 bbls 151 HCL+ additives. Flush with 75 bbls diesel. Pre-flush nitrified @ 750 SCFM; acid nitrified @ 1000 SCFM; flush nitrified @ 600 SCFM; average pump- in rates of 2 BPM at 2500 psi. Post-Stimulation Test 8-24-86 Well flowed back to recover load. Total load to be recovered of 180 bbls. Well flowed 370 bbls total with final water cuts of 951. Well shut-in. L3-31 Acid TreatzeuC Sumury Wahoo Zone 7 Perforated Interval: 112&6-11346 Date Time 08-p6'-86 04. 08-07-86 1015 1157 1700 ~-vent Replaced circulatins valves v/dunny valves @ 10~5' and 11196' SI~. Pulled 'BPI' isolation sleeve frou 'BPL' @ I1251'ND and set 'BCP" combination plus and ported sleeve. RIH with HP/CCL to measure dravdown. A gradient stop vas made @ I1210'ND, P'4309.4 psi, T'182.5 des. F. The HP was set @ Ill00'HD for dravdovn measurement, P'4270.68 psi, T'180.5 deS. F with welt shut-in. Opened veil approximately 1 bean. Well produced 160 BOPD w/FBKP-3352.6 psi @ 182.4 des. F. Flowed 31 bbl. POOH w/HP, CCL and shut well in. Acid Breakdown Treatment: 08-09-86 1447-1744 Pumped Wahoo 7 perforation breakdown treatment, w/10 bbl diesel/101 mutual solvent preflush, 93 bbl Ii. Il HCL & additives and 84 bbl diesel flush. A total load of 187 bbl vas pumped. Well treated tight w/1.0 BPH @ 2700 psi. Increased injection pressure to 3500 psi @ 1.5 PBH. Well appeared to have mechanical problems. ISIP" 1700 psi. Flowback Summary: 1802-1820 08-10-86 0840 1200 Brought on well for flowback w/1500 psi initial tubing pressure. Pressure dropped to 0+ psi in 18 minutes. 37 bbls diesel recovered. Well shut-in. RIH and pulled "BCP" from 11239' SLH. Began commingled flowback of Wahoo 5 and 7. Well flowed back approximately 700 bbls in 13 hrs. ARCO Alaska Inc. Lisburne Engineering To: Stat~ mf Ak From: Pam Lambert ,Tnhn ~q,~yl e, Date: 8-15-86 Transmitted herewith are =he following: CH Final Prints for Lisburne Well L3-31 ~Collar Log 4-26-86 Run 1 5" DA ~ollar Log 5-1-86 Run 1 5" DA Return Receipt O Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmit~al No: To: State of Alaska ARCO Alaska Inc. Lisburne Engineering ~'rom: John Boyle Date: Pam Lambert ~A~ May 15, 1986 Transmitted herewith are the following: Directional Surveys for Lisburne Wells L3-31 5-12-86 LGI #12 4-25-86 Receipt Acknowledgement: Return Receipt to: ARCO Alaska In~!~i~ O, ii ~ <!'~ Pam Lambert ATO 477 ~.!'i~,~'.~ PO Box 100360 Anchorage, Alaska 99510 Transmittal No:-~~--- ~-' STATE OF ALASKA ~"" 0 R 16 I. lt/lt ALASKa, ~,,~_ AN D GAS CONSERVATION '.-~,,.,MISSIO" ~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LO ., 1. Status of Well Classification of Service Well OILX[~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-34 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 4. Location of well at surface 9. Unit or Lease Name 1170' FNL, 726' FWL, Sec.22, T11N, R15E, UM Prudho~. Bay IJnif./I i~h..rn~ At Top Producing Interval 10. Well Number 1251' FNL, 1133' FEL, Sec.28, T11N, R15E, UM L3-~1 At Total Depth 11. Field and Pool 1647' FNL_, 1262' FEL~ Sec,28, T11N, R15E: UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 51' RKBIADL 28325 ALK 25?3 12. Date Spudded 13. Date T.D. Reached 14. Date Co~p.,.Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 02/11/86 03/18/86 '~--, 05/03,/86* . N/A feet MSL 1 t 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. 'DireCtional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12,006'MD,9612'TVD 10,950'MD,9566'TVD YE~xI~ NO []I 72~? feet MD 1900' (~_pprox) 22. Type Electric or Other Logs Run DIL/NSFL/NC, T/.~P/£~I _ I DT/~.NI /Nir, rn]nn/FPT/~,[~ I ~/~.9 P~T/PPI /P.R~ ("RI ~.PT PP'T PRT 23. ' ........ ~' CA-~ING', LINI~R-'A'Nb-C'I~I~[:~I'T~'I~ ~I-E-C'OF~)' ' --'' SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2Ui~ ~91.5# H-40 Surf 101 ' 30'" 1750# Poleset 13-3/8" 68.0#/72.0~ K-55/L-80 Surf 4032' 17-1/2" 2950 sx PF "E" & 600 sx :lass G 9-5/8" 47.0# L-80 Surf 11204' 12-1/4" 1060 sx Class G 7" 29.0# L-80 10999' 12006' 8-1/2" 318 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25: TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 11,510'WLM 10,931', 11~385' WLM & 11,477' WLM 11,256'-11,346' . 11,522'-11,570' w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Plug f/9956'-10,213' 200 sx Class G 10,330'-10,332' 395 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ' . : :.~ * NOTE: Drilling completed 3/23/86. Form 10-407 Submit in duplicate Rev. 7-1-80 (DAM)WC1/015 CONTINUED ON REVERSE SIDE 29. R[K~.i~,S ,ii 30. ii' .. GEOL-O:GIC MA ' ' ~'~ '- 'FORMATION TESTS ; ,~.,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wahoo Zone 7 11,255' 8987' N/A Top Wahoo Zone 6 11,358' 9072' Top Wahoo Zone 5 11,504' 9194' Top Wahoo Zone 4 11,630' 9301' Top Wahoo Zone 3 11,869' 9499' Top Wahoo Zone 2 11,946' 9563' 31. LIST OF ATTACHMENTS ,*,'one - 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~ ~~ ~[~ TitleA.~.~or~i~, Fn0in~r- Date // , , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: .Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none"° Form 10-407 ~UB.$URFACE DIRECTIONAL ~URVEY r-~ UIDANCE ~ONTINUOUS ~OOL Company ~co ~, [~~ · , 'Well Name L[S~ L3-31 (1170' F~L, 726' FI4L, S22~ TI_INa R,15E, L~) Field/Location t~[s~n~-~/mua~ ~a¥, mm sm,m~ gas~ Job Reference No. Date, 71464 12-MAY-86 LO_ggg..~g~ Computed 8¥: SARBER /RU~ELL SCHLUMBERGER GOT DIRECTI3NAL SURVEY ~USTg~ER LZSTIN$ ARC~ ALASKA~' ZNC. L3-31 PRU~HDE BAY-LISBUR~ NORTH SLDPEtALASKA SURVEY DATE: II.APR-86 EN;ZNEER: G. SARBE~ qETH30S OF COqPJTATIO~ TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION .AND AZINJTH INTERP3LATI3N: LINEAR VERTICAL SECTI3N: ~ORIZo DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUT~ 20 DE; 38 qIN MEST AR:O ALAS(AT I~C. L3-3! PRUDHOE BAY-LIS3URqE N3RTH SLOPE,ALASKA CONPUTATION DATE: 1Z-HAY-86 TRUE SUB-SEA COJRSE ~EASURE] VERTI:AL VERTISAL 2EVZATION AZINUT,H DEPTH OEPTd 3EPTH 3EG qIN DEG MIq PAGE 1 DATE DF SURVEY: II-APR-86 KELLY BUSHING ELEfATION: ENGINEER: G. SARBER 'INTERPOLATED VAL~ES FOR EVEN 100 ~EEr OF HEASUREO DEPTH VERTICAL DOG.EG RECTANSULAR COORDINATES H3RIZ. DEPARTURE SECTZON SEVERZT¥ N~RTH/SOUTH EAST/NEST DISt. AZZNUTH FEET DE$/100 FEEt. FEET FEET DEG MZN O.OO 0.00 100.00 100.00 ZO0.O0 ZO0.O0 300.00 300.00 400.03 400.00 500.00 499.99 600.00 599.99 700.03 699.99 800.Og 799.~8 gO0.O0 899.~8 -51.00 0 0 N 0 0 E 49.00 0 6 S 26 27 E 149.00 0 20. S 61 51 N 249.00 0 17 S ~7 55 ~ 349.00 0 23 S 44 5~ N 448.99 0 24 S 42 5Z ~ 5~8.99 0 21 S 22 10 ~ 648.99 0 29 S 18 36 E 7e8.98' 0 31 S 23 11 E 848.98 0 32 S 1 55 ~ lO00.O0 999.97 948.97 1100.00 1099.96 1048.96 1200.00 1199.96 1148.96 1300.00 1299.95 1248.95 1400.00 1399.93 1348.93 1500.00 1499.~2 1448.92 1600.00 1599.91 1548.91 1700.00 1699.90 16~8.90 1800.00 1799.89 1748.89 1900.00 1899.88 1848.88 0 39 S 35 Z$ E 0 44 S 74 59 E 0 ~,6 S 77 31 E 0 51 S 57 55 E 0 51 S 57 23 E 0 58 S 62 58 E 0 ~7 S 28 43 i 0 r~Z S 12 32 E 0 ,50 S 10 15 E 0 ~,3 S 13 1Z ~1 2000.00 1999.88 1948.88 2100.00 2099.87 Z048.87 2200.00 2199.~6 Z148.86 2300.00 2299.85 2248.85 2400.00 2399.84 Z348.84 2500.03 2499.79 2448.79 2600.30 2599.58 25~6.58 2700.03 2699.09 2648.09 2800.00 2798.09 2747.09 9 15 2900.00 2896.½3 2845.~3 11 41 0 ~,0 S 28 15 E 0 37 S 24 11 E 0 36 S 61 40 E 0 56 S 88 ZO E 0 '58 S 87 7 E 2 ~5 S 14 ZZ E 432 S 2 15 ~1 6 50 5 11 52 ~1 S 15 15 Id S 15 6 ~ 3000.00 2993.91 29&2.91 13 59 3100.00 3090.46 3039.4~ 16 ZO 3200.00 3185.66 3134.66 19 15 3300.00 3279.17 3228.17 22 11 3~00.00 3370.54 3319.54 25 58 3500.00 3458.69 3407.69 30 31 3600.00 3542.58 3491.58 35 tO 3700.00 3622.96 3571.96 36 58 3800.03 3702.71 3651.71 37 9 3900.00 3782.39 3731.39 37 13 0.00 O.OO 0.00 N 0.00 -0.02 0.55 O.OT S 0.25 0.25 0.17 0.22 S 0.11 0.71 0.12 0.55 S 0.54 1.25 0.12 0.97 S 0.97 1.92 0.0~ 1.50 S 1.45 2.57' 0.50 2.04 S 1.87 3.21 0.07 2.78 S 1.72 3.89 0.10 3.62 S 1.42 4.59 0.5! 4.47 S 1.16 5.40 0.39 5.~8 S 5.58 O.11 6.06 S 5.40 0.06 6.35 S 5.44 0.06 6.86 S 5.75 O.OZ 7.68 S 5.87 0.23 6.37 S 6.44 0.26 9.38 S 7.41 3.23 10.59 S 8.53 6.90 11.87 S 9.87 g.56 13.22 S 10.87 0.18 14.39 S 11.62 0.84 15.37 S 12.08 1.02 16.06 S 11.99 0.87 16.49 S 11.09 2.21 16.18 S 12.78 Z.32 18.56 S 18.47 2.27 24.80 S 28.11 2.40 34.58 S 42.01 2.64 48.17 S 60.10 2.17 65.68 S S 13 5Z , 82.19 2.43 S 14 58 ~ 108.07 2.8! S 16 *5 M 138.49 3.01 S 18 3 ~ 173.81 3.30 S 19 ~ ~ 21k.38 ~.4~ S 21 19 ~ 261.52 4.97 $ 23 25 ~ 375.27 0.37 S 23 31N 435.53 0'14 S 23 52 ~ 495.86 0o51: 51.00 PT 0.79 ~ 5.53 S 8 14 ~ 0.24 E 6.06 S Z 18 E 1.55 E 6.54 S 13 41 E 2.80 E 7.~1 S ZZ 12 E 4.07 E 8.70 $ 27 55 E 5.55 E 10.04 S 33 33 E $.64 E 11.49 S 35 17 E 7.10 E 12.75 S 33 50 E 7.33 E 13.95 S,31 41 E 7.11 E 15.01 S 28 15 E 7.36 E 7.86 E 0.36 E 9.76 E 11.49 E 13.02 E 13.¢S E 12.05 E 8.71 E 3.87 E 16.16 S 27 5 E 17.26 S 27 4 E 18.10 S Z? 30 E 19.16 S 30 37 E 19.84 S 35 22 F 22.67 S 35 3 2B.22 S Z3 28 b 36.62 S 1~ 13 E 48.95 S 10 15 E 65.79 S 3 22 E 87.25 S 1.51 ~ 87.26 S 0 59 d 112.44 S 8.05 ~ 112.73 S 4 5 M 141.91 S 16.15 W 142.82 S 6 29 M 175.72 S 26.56 ~ 177.72 S 8 35 M 21&.10 S 39.74 ~ 217.76 $ 1~ 30 ~ 258.25 S 56.30 M 264.31 S 12 17 d 308.60 S 76.73 ~ 318.00 S 13 57 M 363.25 S 100.25 ~ 376.83 S 15 25 d ~18.59 S 12~.26 ~ ~36.65 S 15 32 ~ ~73.~4 S 148.48 M 496.66 S 17 23 ~ 0.00 N. 0 0 E 0.26 S 7r~ 43 E 0.2~', 5 25 44 ~1 O. 77 S 44 3 ~ 1.37 S 45 0 2.09 S 44 4 2.77 S 42 29 ~ 3.27 S 31 48 kl 3.89 S 21 24 ~J 4,.62 S 1~ 36 ~1 A~CO ALASKA, L3-31 P~UDHDE BAY-LISBURNE NORTH SLOPEtALASKA COMPUTATI]N DA[E: 12-MAY-86 TRUE SU~-SEA COJRSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTq ]EPTH DEPT~ DEPTH DEG qIN DEG NI~ PAGE 2 DATE OF SURVEY: Z1-APR-86 KELLY BUSHING ELEVATZON: ENGZNEER: .G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTI:AL DOGLEG RECTANGULAR COORDINATES H]RIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OISTo AZIHUTH FEET DEG/100 FEET FEET FEET DEG HZN ~000.~3 3861.~7 3810,87 31 37 4100.00 3g~o.z5 3889025 40 4 ~2gO,O0 4013.$6 3961,66 &5 33 4300.00 ~081.Z1 4030.21 48 17 ~400.3] ~1~7.99 ~0~5.89 ~7 ~5 4500.00 4216.01 4165.01 46 31 ~500.00 ¢285.24 ~23~.2~ &5 ~6 ~700.00 ~355.g8 ~30¢.88 ~& ~0 4800,00 &426.$7 ~375067 '~ ~& 4900.00 4~98.15 ~4¢7.15 44 0 5000,00 4570,81 45'13.81 43 16 5100,90 4643,37 5200.00 4715.72 4664,72 43 13 5300.00 4788.55 4737.55 43 ~3 5~00.00 ~859.54 4808.54 45 Z9 5500.00 ~919.$6 4878.66 ¢5 8 5600.00 5000.50 4949.50 44 45 5700.00 5071,85 5023,85 44 Z 5800.00 51&~.Z~ 5093.24 ~3 10 5900,00 5217.~4 516S,54 43 S 24 $ W 618.40 S 21 4~ W 686,12 S 18 3~ W 75~,82 S 17 3~ W 83~,27 S 15 23 W 907.26 S IS 12 W 979.09 S 16 8 d 1049oS9 S 16 49 W 1120,03 S 17 31 W 1189.84 S 18 46 W 1258.~8 S lg 23 W 1317.58 S 20 ZZ W 1396.28 S ZO 58 d 1464.80 S 21 5 W 1535,22 S 21 7 W 1606.52 S 21 20 W 1677009 S 21 g9 ~ 17~7.15 S 21 46 W 1816.13 S 21 ~Z W 188~.1~ S 20 8 W ~953,67 S 17 55 W 2024,60 S 18 27 W 209~,99 S 18 57 W Z155.06 S lB 50 d 1235.20 S 1~ 41 a 2306.35 S 19 lS W Z376.90 S 1~ ~g ~ 2S1~.90 S 18 55 W 258~,62 S 19 8 ~ 2654,$8 S 19 36 W. 1725,14 S 19 40 d 1796,83 S 19 5 W 2869,91 S 18 42 W S 18 11 W 3019.71 S 18 3 W 3094,77 5 17 59 W 3169,60 S 18 0 W 32~4.57 S 17 5~ W 3319.90 6000.00 5289,39 5238,39 44 ~5 6100,00 5359.83 5308.83 45 10 6200.03 5430.80 5379.80 44 35 6300,00 5502.11 5451.11 44 Z8 6~00.00 5573.35 5522.35 44 59 6500.00 5643.58 5592.58 45 17 6600.00 5714.~2 ~663.42 44 24 6700.03 5786.50 5735,50 43 28 6800,00 5859.16 5808016 43 ~4 6900.00 5930082 5879.82 44 26 7000.00 6002. Z6 5951.26 44 33 7100.00 6073.10 6022.10 45 16 7100.00 6142.80 6091.80 46 AS 7300.00 6211.34 516~.04 47 31 7400,00 6277o$~ 6225.64 48 ~5 7500,00 ~343,4~ 62)Z.44 48 51 7600,00 6409,~4 6359,~4 48 36 7700.00 6475.57 542~,67 48 18 7800.00 6541.75 S490.75 49 9 7900,30 6607.~3 6555.43 48 ~0 0.66 4.81 6.27 0.67 Z.13 1.03 0.99 1.00 1.26 1.33 1.06 1.13 1.77 0.79 0.79 0.33 0.9~ 1.OS 1.g8 g.lO o.g2 0.61 O.la .1.5! 0,72 1.27 o.g2 1,50 0,38 0,66 0,86 1.2~ 1.43 0.72 0,25 0.17 3,88 1.47 0.36 51.00 FT: 529.31 S 173.33 W 556.97 S 18' 7 d 585.92 S 198.82 W 618,73 S 18 44 ~ $48.18 S 225,66 W 586,34'i'"'.S 19 11 W 717.50 S 250.69 'W 760.03 S 19 15 d 788.25 S 274.07 W 834.54 S 19 10 858,51 S 294,62 W 907,66 S 18 56 ,~ 928.16 S 313.48 W 979,67 S 18 39 W 996,33 S 332.50 W 1050.3~ S 18 27 d 1064.04 S 352.56 W 1120.93 S 18 1.9 d 1130.85 S 373,26 W 1190.85 S 18 IS W 1196.14 S 394.64 W 1259.56 S 19 15 W I161.51 S 417.12 W 1328.68 S la 17 W 1326.09 S 4~0.57 W 1397.36 S 18 22 W 1390.20 S 464.75 W 1465.83 S 18 29 W 1455.88 S 490.16 W 1536,1.8 S 18 36 a 1522,~3 S 515,75 ~ 1607,~2 $ 18 42 d 15a8,22 s 541,31 W 1677,93 S 18 49 W 1653,44 S 566.91 W 1747.93 5 18 SS W 1717.59 S 592,29 ~ 1816.04 S 19 I d 1780069 S 617.71 W 1884.78 S 19 7 d 1845.53 S 642.84 W 195k.28 S 19 12 d 1912.65 S 665.g5 W 2025.24 S 19 11 1979.64 S 687.71 W 2995.69 S 19 9 d 2046.01 S 710.27 W 2165.79 S 1~ 8 W 2112037 S 733.09 W 2235.96 S 19 8 d 2179.80 S 755.90 W 2307.15 S 19 7 2246.57 S 778.78 W 2377.72 S 19 7 d 2311.85 S 802.10 W 2447.04 S 19 8 W 2376.34 S 825.78 W 2515.r3 S 19 9 2G42.20 S 849.72 W 2585.~7 S 19 9 W 2508.38 S 871.47 W 2655.45 S 19 g W 2574.9~ S 89¢.94 W 2726.03 S 19 9 W 2542.46 S 919.09 W 2797.73 S 19 10 W 2711.38 S 943.43 W 2870.82 S 19 11 ~ 2781.95 S 967057 W 2945.~1 S 19 10 W 2853.39 S 991.37 W 3020.70 S 19 9 W 2924.80 S 1014.73 W 3095.92 S 19 8 d 2996.04 S 1037.39 W 3170.72 S 1~ 6 a 3067.41 S 1061.09 W 3245.76 S 19 4 W 3139.16 S 1084.32 W 3321.16 S 19 3 d ARCO ~LASKA, INC. 13-31 PRdDHOE 5A¥-LISBURqE N3RTH SLOPEtALASKA COMPJTATI~N DATE: 12-MAY-85 PAGE DATE 3F SURVEY: 21-APR-a6 KELLY BUSHING ELEVATION: ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVE~ 100 FEET OF MEASURED DEPTH TRUE SJB-SEA. C3URSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTq DEPTH BEG ~IN DEG MIN 3 8000.09 6673.13 $622.13 49 6 8100.90 6738.75 S$87.75 &8 52 8ZO0.O0 $806.58 S753.58 48'52 8300.00 6870.56 6819.56 48 Z4 8400.00 6937.33 6886.33 47 68 8500.00 7004.87 6953.87 47 17 8500.33 7073.10 7022.10 46 32 8700.00 7142.29 7091.29 45 54 8800.00 7211.89 7160.89 46 2 8900.00 7281.40 7230.40 45 53 9000.00 7350.91 7299.91 46 Z 9100.03 7420.31 7369.31 46 16 9200.00 7489.17 7438.17 46 32 9390.00 7557.59 7506.69 47 9400.00 7625.70 7576.70 47 15 9590.00 7693.26 76~Z.Z6 47 9SO0.O0 7760.10 7709.10 48 1 9700.00 7827. Z0 7775.20 9890.00 7894.52 7843.52 47 37 9900.00 7962.16 7911.16 47 18 10000.00 9030.25 7979.25 46 36 10100.00 8099.50 8048.50 45 30 10200.00 8170.53 8119.53 44 10 10300.00 8243.37 8192.37 41 39 lO¢O0.OO 8319.51 326~.51 40 10500.30 $396.Z4 8345.2~ 39 37 10600.99 0473.33 8~22.33 39 36 10700.90 8550.37 8499.37 39 32 10800.00 8627.57 8576.57 39 16 10900.00 8705. Z3 8654.23 38 39 11000.0~ $783.34 973Z.34 38 34 11100.93 986Z.Z5 8811.25 36 50 11200.00 8942.$3 8891.63 35 ~9 11300.00 9024.15 8973.15 34 66 11400.00 9106.93 9055.93 33 30 11500.00 9191.0Z 9140.0Z 32 21 11600.00 9275.35 92Z¢.35 32 ~9 11700.00 9359.15 9308.15 33 22 11000.00 944Z. 36 9391.36 33 58 11900.00 9525.31 9474.01 34 34 51.00 FT. VERTICAL DOGLEG RECTANSULAR CD3RDI~ATE$ H3~IZ. DEPARTURE SECTION SEVERITY ND~TH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET' DEG MIN S 17 53 W 3395.20 S 17 43 W 3470.57 S 17 31 W 3545.74 S 17 37 W 3620.77 S 17 57 W 3695.12 S 18 16 W 3768.80 S 16 1~ W 3341.84 S la 50 W 3913.99 $ 19 22 d 3995.77 S 19 27 W 4057.65 S 19 26 d 6129.52 S 19 25 W ~Z01.50 S 19 27 d ~276.01 S 19 31 W 6346.83 S 19 33 ~ ~4Z0.12 S 19 ZO W 6493.83 S 19 9 d ~568.Z0 S 19 36 W 6642.33 S 19 45 W 6716.25 S ZO Z W 6789.90 0.52 0.29 0.62 0.75 0.56 3.95 1.15 0.20 0.17 3210.90 S 1107,50 W 3396.53 5 19 1 328Z.73 S 1130.59 W 3671,97 S 19 0 d 3354.4~ S 1153.37 W 3547.22 ..... ,S 18 58 3426.13 S 1176.00 ~ 3622.34 S 18 56 d 3697002 S 1198.72 W 3696.76 3567.10 S 1221.68 3536.50 S 3704.98 S 1267.55 W 3915.81 S 18 53 W 3772.79 S 1291.15 3840.58 S 1315.09 0.41 3908.37 S 1339.0Z W 4131.38 $ 18 54 d 0.84 3976.Z6 S 136Z.9~ W 4Z03.37 S 18 55 W 0.19 4044.65 S 1387.10 W 4Z75.89 S 18 55 W 0.51 0.53 0.76 0.53 0.32 0.49 0.20 4113.30 S 1411.42 W 4348,72 5 18 56 d 4182.40 S 1435.91 W 4kZZ.02 $ 1~ 56 W 4251.93 S 1~60.44 W 4~95.75 S 18 57 d 4322.17 S 1484.93 W 4570.14 $ 18 57 W ~392.14 S 1509.46 M 4644.28 $ 18 57 W 4~61.76 S 1534.35 W 4718.Z1 $ 18 58 W 4531.02 S 1559.43 W 4791.86 $ 18 59 d 0.76 1.82 1.21 3.57 0.24 0.34 0.95 2.31 4599.75 S 1584.68 W 4965.07 $ 19 0 W 4667.30 S 1609.99 W 4937.18 S 19 1 W ~733.46 S 1634.05 W 5007.57 S 19 Z W 4798.03 S 1656.89 W 5076.06 S 19 3 d 4859.06 S 1678.72 W 5140.87 ~ 19 3 al 4~19.23 S 1700.90 W 5204.99 S 19 4 ~ 4978.98 S 1722.99 W 5268.67 5 19 5 d 5038.92 S 17~.75 w 533Z.43 S 19 5 W 5098~16 S 1766.18 W 5396.00 S 19 6 ~ 5158.15 S 1707.14 W 5458.97 S 19 6 W 1.31 5.92 1.1~ 1.89 1.63 0.67 C).88 1.OZ 0.88 0.00 5217.16 S 1807.63 W '5521.44 S 1~ 6 W 5275.18 S 1827.78 W 558Z.86 $ 19 6 W 5331.16 S 1847.85 W 5642.33 5 1~ 7 ~ 5385.55 S 1867.76 W 5700.24 S 19 7 W 5638.43 S 1886.47 W 5756.32 S 19 7 W 5489.54 S 1904.27 ~ 5810.44 $ 19 7 W 5540.3Z $ 1921.86 W 5864.19 5 19 7 W 5592.20 S 1938.81 W 5918.76 S 19 7 d 5445.22 S 1955.01 W 5974.16 S 19 6 d 5699.22 S 1970.87 ~ 6030.37 S 19 4 ~ S 20 2Z W 6863.13 S 20 25 W ~935.26 S 19 34 d 5005.66 S 19 29 W 5074.13 S 19 57 W 5138.93 S 20 23 d 5Z03.07 S 23 7 W 5266.77 S 19 48 W 5330.53 S 19 36 W 5394.09 S 19 17 W 5457.05 S 19 6 W 5519.50 S 19 29 W 5580.90 S 19 57 W 5640.36 S 19 51 W 5698.28 S 19 1~ W 5754.35 S 19 13 W 5a08.46 S 18 41 W ~a62.18 S 17 31 W 5916.70 S 16 37 W 5972.04 S 16 15 W S0~8.16 CO~PUTAT~DN OATE: 1Z-MAY-86 PAGE ARCO ALA$~At IqC. DATE OF $~RVEY: 2%-APR-86 L3-31 KELLY BU'SHIN$ ELE~ATI3N= PRUOH3E B~Y-LISBJRNE NORTH SLOPEtALASKA ENGZNEER~ G. SAR3ER [NTE.RPOLATEO VALJES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COdRSE VERTICAL OOGLEG RE:TANSULAR COORDZ~ATES H3RZZo DEPARTURE qEASURED VERTZC~L VERTI:AL OEVZ&TIgN AZIMUTH SECTZON SEVERZTY NO~TH/SOUT~ EAST/WEST OISTo AZINUTH DEPTH DEPTH OEPrH OEG NZN DES HIq FEET OEG/~O0 FEET FEET FEET OE~ HIN ~ZO00.O0 ~607o36 ~556.36 3& 3& S ~ 15 W 508~o73 0°00 5753.59 S 1986o75 ~ 6087o0& S 19 g M ~Zg06 O0 ~6~Z 30 ~56! 30 3~ ~ S ~$ ~$ W 5088 ~2 O°O0 5TS6og6 S ~98T°70 N 60gOo&& ,S ~ Z M 51.00 COqPUTATI3N DATE: 1Z-MAY-8$ PAGE 5 ARCO ALASKAt INC. DATE DF SURVEY: 21-APR-86 L3-31 PRJDHOE BAY-LISBURNE NORTH SLOPEpALASKA KELLY BUSHING ELEVATION: ENGIMEER: G. SARBER 51.00 XNTERPOLATED VALJES FOR EVEN 100~ FEET 3~ NEASURED DEPT TRUE SJB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH 3EG VERTICAL DOGLEG RE:TANGULAR COORDINATES H3RIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. FEET DES/lO0 FEET FEET FEET DEG 0.00 0.00 -51.00 0 0 1000.00 999.97 948,97 0 39 2000.00 1999.88 1948.88 0 40 3000.00 2993,91 2942,91 13 59 4000.00 3861.87 3810.87 37 37 5000.00 4570.81 ~519.81 43 16 6000.00 5289.39 5238,39 4k 45 7000.00 6002.26 5951.26 4~ 33 8000.00 6673.13 5622.13 '49 4 9000.00 7350.91 7299,91 46 Z N 0 0 E 0,00 S 35 2S E 5,40 S 28 1S E 10,87 S 13 52 ~ 82,19 S 24 15 W 556.44 S 18 4S W 1258.48 S ZO 8 ~ 1953.67 S lg 8 W Z654.58 S 17 53 ~ 3395.20 S 19 26 W 9t29,52 0.39 0.18 2.43 0.66 2.10 0.66 0.48 0.41 0.00 N 0.00 E 0.00 N 0 0 E 5.48 S 0,79 W 5,53~. S 8 14 W 14,39 S 7.36 E 16,16'"' S 27 5 E 87.25 S 1.51W 87.26 S 0 59 529.31 S 173.33 W 556,97 S 18 7 1196,14 S 394,64 g 1259,56 S 18 15 1845,53 S 642.84 W 1954.28 S 19 12 d 2508,38 S 871,47 g 2555.~5 S 19 9 3210.90 S 1107,50 W 3396,53 S 19 1 3908,37 S 1339.02 W 4131,38 S 18 54 10000.00 8030.25 7979.25 46 36 11000.00 8783.34 8732.34 38 34 12000.00 9607.36 9556.36 34 34 lZO06.00 9612.30 9561.30 34 34 S ZO 2Z d ~]63,13 S 19 6 d 5519.50 S 16 15 g 5084.73 S 16 15 ~ $088.12 0.78 1,31 0.00 0.00 4599,75 S 1584,68 W 4865,07 S 19 0 d 5217,16 S 1807,63 W 5521.44 S 19 6 d 5753.69 S 1986.75 W 6087.04 S 19 Z d 5756.96 S 1987.70 ~ 6090.44 S 19 Z ~ ARCO AkAS~At IqC. L3-31 PqJDH3E BAY-LISBUR'dE N3RTH SCL)PEt ALASKA CD~PUTATI3q DATE: 12-MAY-86 PAGE DATE DF SBRdEf: 21-A>R-86 KELLY BUSHING ELEVATIgN: ENGINEER: $. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUSoSEA DEPTH 51,00 FT 0.00 0.00 -51.00 0 0 N 0 3 E 0.00 0.00 0.00 N 0.00 51.00 51.00 0.00 0 11 5 79 49 E -0.03 0.54* 0.02 $ 0.14. 151,00 151.00 100,00 0 15 S 76 19 d 0,08 0,18 0,13 S 0,13 251,00 251,00 200,00 0 18 S 50 9 M 0,49 0,22 0,39 S 0,35 351.00 351.00 300.00 0 21 S 4*6 35 id 0.96 0.0~ 0.75 S 0.74. 4.51.01 451,00 4.00.00 0 25 S 41 26 id 1.59 0.04 1,24 S 1.22 551.01 551.00 503,00 0 23 5 38 56 d 2.25 0,13 1,78 S lo69 651.01 651.00 600.00 0 28 S 16 29 E 2,88 0,23 2,38 S 1,85 751,31 751,00 700,00 0 31 S 19 9 E 3,55 0,08 3,20 $ 1,58 651.02 851.00 800.00 0 30 S 24 54* E 4'20 0.24 4.03 5 1.22 0,00 hi O, 0 E 0,15 $ 82 55 E 0.19~'"',$ 45 35 E 0,,53 S 42 16 1.06 S 1.74, S 44 26 2.4,5 S 43 35 id 3.02 S 37 52 id 3'57 S 26 15 951.02 951,00 900.00 1051,03 1051,00 1000,00 1151,04. 1151,00 1100.00 1251,05 1251,00 1200,00 1351o05 1351,00 1300,00 1451.07 1451,00 14.00,00 1551,38 1551.00 1500.00 1651.09 1651.00 1600.00 1751.10 1751.00 1700,00 1851.11 1851.30 1800.00 0 38 S 21 27 E 5.04 0.41 4.98 S 1.06 W 0 ~2 S 64 13 E 5.60 0.52 5.85 S 0.35 N 0 ~6 S 77 12 E 5.50 0.09 6.21 $ 0.90E 0 ~5 S 68 35 E 5.32 1,02 6,51 S 2.20 E O 52 S 56 55 E 5.60 0.04 7.28 S 3.45 E 0 57 S 69 52 E 5,84 0,20 6,04 S 4,78 E 0 50 S ~4 54* E 6.05 1,21 8.61 S 6.26 E 0 44 S 20 29 E 6,92 0,34 10,01 S 6.93 E 0 42 S 6 53 E 7,96 0,08 11,22 S 7020 E 0 4*8 S 13 3.3 ~ 9,21 0.23 12,58 S 7,29 E 5.09 S 12 3 id 5.86 S 3 27 ~ 6.28 S ~ 15 E 6,87 S 18 40 E 8.06 S 25 21 E 9.35 S 30 45 E 10.81 S 35 22 E 12.17 S 34 42 E 13,33 $ 32 41 E 14.54 S 30 4 E 1951.12 1951,00 1900.00 2051,13 2051,00 2000.00 2151,13 2151,00 2100,00 2251,14. 2251,00 2200.00 2351,16 2351.00 2300.00 24.51,18 2451,00 2400.00 2551,29 2551.00 2503.00 2651.62 2651.00 2600.00 2752.36 2751.00 2700.00 0 63 $ 17 5 E 10,45 0,'54 13,85 S 7.13 E 0 39 S 29 13 E 11,25 0,19 14,91 S 7,66 ~ 0 25 S 41 40 E ll,9g 0,72 15,84 S 8,03 E 0 52 S 72 4* E 12.12 0,38 16,34 S 9.01 E I 3 N 77 15 E 11,55 0,29 16,35 S 10,66 E i 60 S 34 1~ E 11,40 2,65 16,81 S 12.32 E 3 35 S 3 48 E 15.28 1.87 21.38 S 13.43 E 5 ~2 S 8 24* id 22.90 2,67 29,37 S 13,03 E ~ 5 5 13 4*8 id 3~,85 2,84 41.20 S 10.52 E S 15 30 id 51.22 2.56 57.06 S 2853,70 2851,00 2800,00 10 34 15.58 S 27 13 E 16.76 S 27 11 E 17,76 S 26 53 E 18.66 S 28 52 E 19,52 S 33 5 E 20.84 S 36 13 E 25.25 5 32 7 E 32.13 S 23 55 E 42.52 S 14 19 E 5.21 E : 57.40 S 6 12 E 2955,87 2951.00 2900.00 12 56 3059.00 3051.00 3000,00 15 19 3163,4*Z 3151.00 3100.00 1~ 11 3269.67 3251.00 3200.00 21 15 3378.30 3351.00 3309.00 25 2 3691.15 3451.30 3400.00 30 5 3610.~0 3551.00 3500.00 35 29 3735.13 3651.00 3600.00 37 4* 3~60,5~ 3751,00 3700.00 37 10 3986.29 3851.00 3800.00 37 31 S 13 56 N 71,99 2,37 S 14 43 ~ 96.g8 2,03 S 15 30 id 125.85 2,96 S 17 27 id 162,60 3,08 S 19 22 W 204.95 4.,27 S 21 11 ~ 251.13 4..86 S 22 55 W 321.9¢ 3,52 S 23 27 ~ 396.40 0.30 S 23 39 id 472.08 0.18 S 24* 15 id 543.10 0049 77026 S 0,91 E 77.27 S 0 40 E 101,68 S 5,18 M 101.81 S 2 54 ~ 130065 S 12.98 ~ 131.30 S 5 40 id 165.04 S 23.13 W 166.65 $ 756 id 205,22 S 36.57 id 208.45 S 13 6 d 254,15 S 54,72 id 259.97 S 12 9 d 314,21 S 79,12 ~ 324.02 S 16 8 id 362.S5 S 108.66 W 397.78 S 15 51 #' ~52.13 S 138,90 id 672.98 S 17 4 id 521.70 S 169.89 g 548.$6 S 1~ 2 id TRUE SJ3-SEA C]JRSE VERTI:AL DOGLEG RECTANGULAR COORDINATES H]RIZ, DEPARTURE ~EASUREO VERTICAL VERTI:AL OEVI~TION AZIMUTH. SECTION SEVERITY NO~TH/SOUTH EAST/IdEST DIST. AZIqUTH 3EPTH DEPTq DEPTH lEG ~IN DES MIq FEET DEG/IO0 FEET FEET FEET DEG MIN ARCD ALASKAt INC. L3-31 PRLIOH3E BaY-LISB~JR~E N':)RTH SLDPEtALASKA CO~PUTATI3~ DARE: 1Z-MaY-B6 PAGE DATE DF SURVEY: II-APR-86 KELLY 3USHXNG ELEVATION: ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SJB-SEA COJRSE ~EASURED VERTIC&L VERTI:AL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG 4114,03 3951.00 3903,00 40 4254,67 4051,00 4000,00 41 4404.6Z 4151.00 4100.00 47 4550,70 4251,30 4200,00 46 10 4693,13 4351.00 4309.00 44 37 4834.14 4451.30 4400.00 44 26 4972.89 4551.00 4500.00 43 16 5110,98 4651,00 4600,00 43 37 5248.37 4751,00 4700.00 43 12 5387,78 4851,00 4800,00 45 Z4 5530.18 4951.00 4900.00 44 5'8 5670,94 5051,00 5000,00 44 19 5809,28 5151,00 5100,00 43 5 5946.25 $251,00 5200,00 44 0 6087,43 5351,00 5300,00 45 12 6228.35 5451.00 5400.00 44 31 6368,55 5551,00 5500,00 44 40 6510.55 5651.00 5600.00 45 12 6550,95 5751,00 5700,00 43 53 6788,72 5851,00 5800,00 43 37 6928,24 5951,00 5909,00 44 25 7068,69 6051,00 5000,00 45 1 7211.91 6151.00 5100,00 46 33 7359.59 6251.00 5200.00 48 24 7511.48 6351,00 5300,00 48 ~9 7662,87 6451,00 5400.00 48 Z7 7814,23 6551,oo 55oo,oo 49 16 7966.17 6651,00 6600.00 48 59 8118.59 5751.00 6700.00 48 48 8270,47 6851,00 5803.00 4~ 35 8420,30 6951,00 5903,00 47 kO 8567,89 7051,00 7000,00 46 50 871Z.50 7151.00 7100.00 45 52 8856,31 7251.00 ?200.00 45 ~7 9000.13 7351.00 7300,00 46 2 9144,5~ 7451,00 7400,00 46 28 9290.18 7551.00 7503.00 46 58 9437,35 7651,00 7600.00 '47 25 9586,39 7751,00 7700,00 48 5 9735,40 7851,00 ?800,00 47 41 51.00 FT . VERTICAL DOGLEG RE:TANSULAR COORDINATES HDRXZ, DEPARTURE SECTION SEVERXTY NORTH/SOUTH EAST/IdEST DIST, AZX~UTH FEET DEG/IO0 S 2~ 0 a 6Z7,39 S 19 35 W 726,03 S 17 27 ~ 837,68 S 15 8 W 943,77 S 16 S. ~ 1044.76 S 17 $ Id 1143.94 S 18 25 W 1239.97 S 19 31 Id 1335.16 S 20 39 W 1429,37 S 21 8 W 1526,48 S 21 11 W 1627.86 S 21 27 Id 1726.92 S 21 49 W 1822,49 S 21 17 d 1916,07 S 18 8 Id ~015,68 S 18 40 Id 2114.87 S 18 55 a 2213.10 S 18 43 W 2313,87 S 19 39 W 2412.36 S 19 57 W 2507.12 S 13 56 W 260~.38 S 19 29 W 2702.96 S 19 39 d 2805.47 S 18 51 W 2914.09 S 18 10 Id 3028,35 S 18 0 W 3141,89 S 17 59 W 3255.38 S 17 53 W 3369.64 5 17 41 Id 3484,53 S 17 33 W 3598,69 S 18 I w 3710.12 S 18 18 Id ' 3818.45 S 18 56 d 3922.95 S 19 27 W 4026.27 S 19 25 Id 4129.62 S 19 25 Id 4233.79 S 19 31 W ~339.63 S 19 27 W 4447.59 S 19 9 W 4558.08 S 19 38 W 4668,52 5.49 3.13 2.26 0.72 0,97 0.97 1.58 1.24 0.47 1,12 0,99 1.10 2,06 1,32 0,43 1,00 1,02 1,33 0,25 0.80 1.22 1.58 0.3,! 0.73 0.99 0.87 0.26 0.69 O.6Z 0.94 1.18 0.19 0.41 0.09 0.64 0.44 0.32 FEET FEET FEET DEG 594.13 S 202.53 ~ 627.70 S 18 '49 685,52 S 239.75 W 726.23 S 19 16 d 191.51 S 275.10 W 837.95 893.91 S 304.21 W 944.26 S 18 47 d 991.59 S 331.14 W 1045.51 5 18 27 W 1086.96 S 359.54 W 1144.88 S 18 18 1178.60 S 388,70 W 1241.04 S 18 15 1268,&7 S 419,6¢ W 1336,27 S 18 18 1357,08 S 452,16 W 1430,43 S 18 25 1447,73 S 487,oz W 1527,45 S 18 35 154Z.33 S 523.46 Id 1628.74 S 18 44 1534.61 S 559,50 W 1727.71 S 1723.49 S 594.65 W 1823.19 S 19 2 1810.36 S 629.52. W 1916.69 S 1904.15 S 663.08 Id 2016.30 S 19 11 d 1998.49 S 694.03 W 2115.57 S 19 9 2091.45 S 725.91 Id 2213.84 S 1.3 8 W 2186.93 S 758.31 W 2314.67 S 19 7 2280.00 S 790.61 W 2413.19 S 19 7 id 2369.32 S 823.11 Id 2507095 S 19 g 2460.90 S 855.13 W 2605.24 S 19 9 2554.04 S 887.53 W 2703.85 S 19 9 d 2650.59 S 922.00 W 2806.37 S 19 10 2753.20 S 957,76 W 2915.03 S 19 10 d 2861.61 S 994.06 W 3029.35 S 19 9 W ~969.66 S 1029.31 W 314,?..98 S 3077.10 S 1064,45 W 3256.58 S 1.) 4 d 3186.54 S 1099.62 W 3370.94 S 19 2 d 3296,05 S 1134.84 W .3485.95 S la 59 3~05,04 S 1169,32 ~ 3500.23 S 18 57 3511.29 S 1203.37 W 3711.77 S 18 55 W 3614.2'1' S 1237.30 W 3820.19 S 3713,46 S 1270,45 W 3924,77 S 18 53 3810.99 S 1304.63 id 4028.11 S 18 53 3908.46 S 1339.05 W 4131.48 S 18 54 4006.72 S 1373.71 W 4235.67 S 18 55 W 4106.52 S 1409.01 W 4341.53 S 1~ 56 W 4208,30 S 1445,09 W 4449,50 S 18 57 W 4312.60 S 1481.62 W 4560.01 S 18 57 4416,81 S 1518.27 W 4670,48 S 18 ARCO ALA$~At L3-31 PRUDH3E BAY-LISBUR~E NORTH SLDPEtALASKA C3~PUTATION DATE: 1Z-HAY-86 PAGE DATE DF SdRdEY: 21-APR-86 KELLY BUSHING ELEVATION: ENGINEER: Go SARBER INTERPOLATED VALJES FgR EVEN 100 FEET OF SUa-$EA DEPTH TRUE SdB-SEA COURSE IEASURED VERTICAL VERTI:AL DEVIATION AZIHUTH DEPTH DEPTH DEPTH OEG ~ZN DEG 9883.56 7951.00 7900.00 47 18 ,0030.1Z 8051.00 8000.00 46 23 ,0172.7Z 9151.00 alO0.O0 44 27 ,0310.10 8251.00 8200.00 41 21 04~1.10 8351.00 8300.00 39 56 0571.0Z 8451.00 8¢00.00 39 34 0700.8Z 8551.00 8500.00 39 32 0a30.19 8651.00 8600.00 39 5 0958.61 8751.00 8700.00 38 48 1085.87 8851.00 8800.00 37 26 1210.3Z 8951.00 8900.00 35 61 1332.54 9051.00 9000,00 34 21 1~52.S0 9151.00 9100.00 32 43 1571.06 9251.00 9200.00 32 38 1690.Z3 9351.00 9300.00 33 18 1810.41 9451.00 9~00.00 34 3 1931.56 9551.00 9503.00 34 34 ZOO6.00 961Z.30 9561.30 34 3~ 51.00 FT S 19 59 d ~777.82 S 20 33 W ~884.97 S 19 44 W ~986,61 S 19 31 d 5080,75 S 20 11 W 5165.36 S 20 13 H 5248.30 S 19 47 ~ 5331.05 S 19 29 W 5~13o12 S 19 2 W 5493.65 S 19 17 ~ 5572.35 S ZO 0 W 5646.40 S 19 36 ~ 5716.67 S 19 12 ff 5783..05 S 18 5! W 5846.53 S 17 38 ~ 5911032 S 16 36 ~ 5977083 S 16 15 W $045.01 S 16 15 W 6088.12 O.Z6 0.81 1.11 3.20 0.63 O.3r, O.4g 1.52 3.20 0.96 0.90 1.34 0.85 1.12 0.96 0.00 0.03 4519.66 S 1555.30 W 4779.78 S 18 59 W ~6Z0,21 S 159Z.33 W 488&.91 S 19 0 W 4715.50 S 1627.68 W 498~.52 ,~,"S 19 2 W 4804.26 S 1659.10 W 5082.67 S 19 3 W 4a83.87 S 16a7.79 W 5167.29 S 19 3 w 4961.64 S 1716062 ~ 52500Z1 S 19 5 5039041 S 1744092 W 5332096 S 19 5 5116.70 S 1772054 ~ 5615003 5192.72 S 1799019 W 5~95,58 5 19 6 5267,11 S 1a2kog$ W 5574031 $ 19 6 5336.84 S 1849,90 W 5548.36 S 19 7 W 540Z.87 S 1873.95 # 5718.63 S 19 7 W 5465.55 S 1895.89 W 5785.03 S 19 7 W 5525.$2 S 1916.76 W 5~4~.53 S 19 7 W 5587.06 S 1937.20 W 5913.37 S 19 7 d 5650.79 S 1955067 W 5979.96 S 19 S d 5716.41 S 1975,88 W 6048.26 S 19 4 W 5756.96 S 1987070 W 6090044 S 19 2 W VERTICAL DOGLEG RECTANSULAR COOROIIATES HDRZZ. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZ[qUTH FEET DEG/IO0 FEET FEET FEET. DEG MIN AR~O ALASKAt I~C. L3-3! PRUDHOE ~Y-LZSBUR~E NORTH SLOPEtALASKA HANKER TOP WAHOO ZOnE T TOP WAHOO ZONE 6 TOP dAHOO ZOqE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAH3O ZONE Z PBTD TO CO~PUTATI)~ DARE: 1Z-HAY-85 PAGE 9 DATE 3F SUi:~V*EY: KELLY BUSHZNG ELEVATION: 51.00 FT . ENGZNEER~ G. SANDER INTERPOLATED VALJES FOR CHOSEN HORIZONS qEASURED DEPTH BELON K8 SURFACE LOCATION 3RI;GIN= 1170 FNLp 726 FkiLt SEC Z:Z r*llNt RIS' TVO RECTANGULIR COORDXNA~S FRON KI:I SUB-SEA NORTH/SDUT"I EAST/IdEST 11255.00 11358°00 11S30°00 11869°00 11946°00 11950°00 1Z006.00 9987,37 8936.37 5361.20 S 1'~58°87 9072.05 9021°05 5416.36 S 1878.73 9194o41 9143o~1 5491o55 S lg04o98 ~300.53 9249.53 5555°79 5 19Z?.O1 9499.47 9~48.47 5~8Z.38 S 1965.96 9562.89 9511.89 5724.28 S 1978.17 9566.19 9S15,19 5726.45 S 197~.8! 961Z.30 9561.30 5756.96 S 1987.73 C3HPUTATIO~ DATE: 12-M~¥-86 PAGE 10 ARCO ALASKAt I4C. DATE DF SURVEY: 21-APR-86 L3-31 PRJDHOE BAY-LISBURYE NORTH 5LOPEtALASKA KELLY BUSHZNG ELEVAT[gN: ENGZNEER= Go SAR~ER 51.00 Fr:. MARKER HEASJ'RED DEPTH BELOW KB SLIRFA2E LOCAl'[ON AT 3RZGIN= 1170 FNLt 726 FWLt SEC 22t TJlNt R15- TVD RECTANGULAR CDDi~DZIIIAFr~s t::ROH KB SUB-SEA NORTH/S3UTH EAST/MEST TOP WAH30 ZOVE TOP WAHDO ZI3~E TOP WAHOO ZONE TOP MA,"(30 ZDqE TOP idaH3D ZOME TOP WAHOO Zg~IE PBTD TD 11Z55.00 IIB58.00 11504.00 11530.00 11869.00 11946.00 11950.00 12006.00 8987.37 8936.37 5351.20 S l"858o87 ~ 9072.05 9021.05 5416.36 S 1878.73 W 9194.41 9143.41 5~91.55 S 1904.98 W 9300.53 9249.53 5555.79 S 1927.01 W 9499.47 9~48.~7 5682.38 S 1955.96 W 9562.89 9511.89 5724.28 S 1978.17 W 9566o19 9515.19 $726.45 S 1978.81 W 9612.30 9561.30 5756.96 S 1987.70 W FINAL WELL LOCATI3N AT'TD: T.qUE SUS-S~A qEASURE:) VERTICAL VERTI;,AL DEPTH DEPTH DEPTH HORIZONTAL 3EPARTURE DISTANCE AZIMUTH FEET g'EG MIN 12006.00 9612.30 9561.30 6090.4. S '19 Z W SCHLUMBERGER ,. O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL L3- 3 t F ! ELD PRUOHOE BAY/L I SBURNE COUNTRY USA RUN DATE LOOOED 21 - APR - 86 REFERENCE 0000~1464 ~E~L . LIS~URNE 133231 .--HORIZONTAL PROJECTION (Ili[70' FNL, 726"~.~, S2'2, TllN, R15E, UM) 2000 -1000 ~P4.E = I/1~ !N/FY !:"::'~::!..:!:'-:::~-:!, :. ,.,...~ .......... :. : , ':::! ':::i:::~::~:::~:::~,: ,: . ......~4...!...i ...... ;...;...~...~.. . :....,....i...,...t.~ .............. . ...:-...~...;..J....~.. :.,-t .~ ,. T.....,....,.--~...~. i ' ' .: ...... ~ ..... ~ ,...~...¢~-¥-I i! ' ~ ' ' : ' ' . . ..? ...... ?...,....?,.. ~...?... · ~ [ ~ ~ I : , · . . . . ·. :::::::::::::::::::::::: 9O00 4000 WELL: (1170' L'I SBURNE._~L 3- 3 ~ FNL, 72~ FWL, S22, TilN, R15E, UM) ~RTICAL PROJECTION 20. PROdECTION ON VEI~TICP, L PLgJ~E 200. - 20. SC~I.£D IN VERTICAL 0EPTHS HORIZ SCALE = 1/2000 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. RATOR; WELL NAME-AND' NUMBER - Reports and Materials to be received, by: ~--~--~ Date - Required Date Received Remarks Completion Report Samples ... ,~ - p > . . ~ ......... .. ~P /<' . , , Mud Log ...... ..,~~I)'~ Core Chips z ~:4 .~ .... , ...... ' .......... ....... Core Description Registered Survey Plat ... y~ ~-..a?-~., .. Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports , , Digitized ..........Data y .[j~,c ~ STATE OF ALASKA .... ALAS.,,-, ..,IL AND GAS CONSERVATION COM ._ ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ Com_p'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Ane. horage= Al( c)9~1r) 4. Location of well at surface 1170'FNL, 726'FWL, Sec.22, T11N, R15E, UN At top of productive interval 1251' FNL, 1133'FEL, Sec.28, T11N, R15E, UM At effective depth 1616'FNL, 1253'FEL, 5ec.28, T11N, R15E, UN At total depth 1647'FNL, 1262'FEL, Sec.28, T11N, R15E, UN 5. Datum elevation (DF or KB) RKB 51 ' 6. Unit or Property name Prudhee B_~y Un-.'t/L,.'sburnc 7. Well number L;~-31 8. Approval number 49 9. APl number 50-- 029-21544 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4003 ' Production 11 ,1 79 ' Liner 1007' 1 2,00 6 feet feet 9,612 11 ,950 9,566 Plugs (measured) feet Junk (measured) feet 200 sx.Class G cmt plug set on top of fish @ 10,213 with top of cmt ~ 9956'. Size Cemented Measured depth 20" 1750# Poleset 101 'MD 13-3/8" 2950 sx PF "'E" & 4032'MD 600 sx Class G 9-5/8" 1060 sx Class G 11,204'MD & 300 sx AS I 7" 318 sx Class G 10,99~'-12006'MD True Vertical depth 1 01 ' TVD 3992 ' TVD 8946'TVD 8772 ' -961 2 ' T1 Perforation depth: measured 11 ,256 ' -11 ,346 ' MD 11,522'-11,570' MD true vertical 8,988,- 9,062, TVD 9,209'- 9,250' TVD Tubing (size, grade and measured depth) 2-7/8", L-80 tbg w/tail ~ 11,510' WLM Packers and SSSV (type and measured depth) HB Pkr ~ 10,931' RECEIVED MAY 2 8 1986 Alaska 0il & Gas Cons. Commission Anchorage , 1-B Pkrs ~ 11,358' WLM & 11,477' WLM & TRDP-1A SSSV (~ 2232' 12. Stimulation or cement squeeze summary Intervalstreated(measured) 10,330'-10,332' ~eatmentdescriptionincluding volumes used and finalpressure Squeezed with 395 sx Class G cmt. 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. AttachmentsCompletion Well History w/Addendum dated 5/13/86 Daily Report of Well Operations xE~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-8¢ Title A~nri~f~ Fngi~eer SWO/030 Date Submit in Duplicate ARCO Oil and Gas Company g~, Well History- Initial Report- Daily Inatructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized On the form giving inclusive dates only. District Alaska Prudhoe Bay IState Alaska Well no. L3-31 County, parish or borough North Slope Borough Field Lease or Unit I ADL #28325 Auth. or W.O, no. ITitle AFE AL0176 I Recompletion WWS #1 API 50-029-21544 Operator ARCO Alaska, Inc. Spudded or W,O. begun [Date IHour ~ ~mPk+e, 4/19/86 CorWplete rec~'~ for each day reported Date and depth as of 8:00 a.m. 4/20/86' thru 4/21/86 4/22/86 · . 4123186 4124186 4/25~86 1630 Hrs. lARGO W.I. 50% Prior status if a W,O. 7" f/10,9~6'-12,006' 11,950' PBTD, C&C mud Wt. 9.7, PV 17, YP 13, PH 11.0, WL 7.2· Sol 10 Accept rig @ 1630 hfs,. 4/19/86. ND tree, NO & tat BOPE. 3½" DP, displ diesel cap to 9.7 ppg mud.. RIH, tag fill @ 11,246' 11,710', rotated to 11,950', C&C mud. 7" f/10,9~6'-12,006' 11,950' PBTD, RU to rn GCT gyro Wt. 9.7, PV 16, YP 12, PR 10.5, WL 7.8· Sol-13 C&C mud. Tst csg to 3000 psi, TOM. RU SCA1. 7" f/10,986'-12,006' 11,950' PBTD, Circ& balance fluids Wt. 9.7· PV 16, YP 8, PH 10.5, WL 7.8, Sol 13 Rn GCT f/surf-Il,880' WLM. Shot sqz perfs f/10,330'-10,332' w/5", 5 SPF gun. Press'd well to 3000 psi, bled to 2200 psi, RD WL. InJ 20 bbls diesel dn 9-5/8" x 13-3/8" ann. MU 9-5/8" sqz pkr, RIH & set pkr @ 10·306'. Est IR of 2 BPM, 2600 psi. RU Dowell. InJ 12 bbls 15% HC1 acid @ 1/4 BPM, 1850 psi. Inj mud @ 2 BPM, 2500 psi. C&C mud prior to sqz'g cmt. 7" f/10,9~6'-12,006' 10,148' PBTD, Drlg cmt Wt. 9.7, PV 14, YP 6, PH 10.5, WL 7.8· Sol 13 C&C, set pkr @ 10,014'. Est IR of 1BPM, 2100 psi. Circ 5 bbls wtr, 20 bbls 15.8 ppg cmt & 5 bbls wtr. Displ w/42 bbls mud. Sqz cmt, rel pkr, pull 3 stds, slug pipe, TOH. PU bit/scrpr, TIH to 9100', WOC. TIH, tag cmt top @ 9927', drl cmt. (Pmp'd total of 98 sx C1 "G" w/63 sx sqz'd into formation.) 7" f/lO,9g'-12,006' 10,148' PBTD, PU 2-7/8" wrk string Wt. 9.8, PV 16, YP 8, PH 12, WL 12, Sol 14 Drl cmt, CBU, tst csg, broke dn @ 2200 psi. TOH, LD colrs. PU RTTS, TIH, set RTTS below sqz perfs, tst lnr lap to 3000 psi; OK. Shut pipe rams, press ann to 2250 psi; slight pressure loss. Rel press & pkr, TOH to 10·152'. Shut rams, press to 2200 psi, broke dn. TOH, PU wrk string. RIH w/6" bit on: · wsh to..: The above is correct Date 5/12/86 ITitle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARC° Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field I County or Parish JState Alaska ILease or Unit North SloPe Borough Prudhoe Bay I ADL #28325 Alaska JWell no. L3-31 Date and depth as of 8:00 a.m. 4/26/86 thru 4/28/86 4/29/86 4/30/86 5101186 5/02/86 Complete record for each day while drilling or workover in progress 7" f/10,9~'-12,006' 10,375', Drl EZ Drl Wt. 9.8+, PV 17, YP 29, PH 13, WL 25, Sol 17 TIH w/2-7/8" wrk string to 10,350', pmp 30 bbls C1 "G" w/5% KCl, 1.2% D-60 & .1% D-133. Displ w/rig pmp. Hesitate sqz perfs f/10,330'-10,332', TOH. TIH w/bit/Scrpr, tag cmt @ 10,190', drl cmt to 10,400', tst csg. Drl cmt f/10,400'-10,566' f/sqz #2 . TIH, tag lnr lap, CBU, tst csg, TOH. RIH, set EZ Drl @ 10,375', POOH, tst csg; failed. TIH w/DP, sqz perfs w/wtr wsh, spot cmt on EZ Drl, TOH 10 stds. Hesitate sqz 38 bbls C1 "G" w/1.4% FL-28 & .3% D-31 thru perfs holding 2800 psi, WOC. Rel press, TOH. PU 8½" bit/scrpr, TIH, tag cmt @ 10,134', drl cmt to 10,350'. Tst csg to 2400 psi. Drl cmt f/10,350'-10,375'. Drl EZ Drl @ 10,375'. 7" f/10,9~'-12,006' 11,950, TIH w/7" x 9-5/8" csg scrpr Wt. 9.8, PV 18, YP 9, PH 13, WL 25, Sol 16 Fin DO EZ Drl. TIH to 7" lap, tst csg to 2400 psi; OK. RU Schl, rn CET log; log invalid below 10,150', POOH. RIH w/8.375" GR/JB; unable to get past 10,700' (lap @ 10,985'), POOH. RIH w/CBL, log f/10,985'-9200', cmt isolation @ sqz perfs, RD Schl. TIH w/bit & scrpr. 7" f/10,9~'-12,006' 11,944 PBTD, TOH w/6" bit 9.4 ppg NaC1 Brine TIH w/bit & scrpr on DP to 10,960', rev circ above lnr lap, drl junk/cmt. TIH to 10,976', drl to 11,100', tag l~, DO plug, rev circ 9.4 ppg NaC1 brine, bit plugged, TOH wet. 7" f/10,9 '-12,006' ~,~v PBTD, POH & LD 3%" DP 9.4 ppg NaC1 Brine TOH, LD bit & csg scrpr. TIH w/OEDP, displ well to brine dn ann, POH. 7" f/10,9~6'-12,006' 1tg~q'tl,"°n'~v PBTD, Rn'g 2-7/8" compl 9.4 ppg NaC1 Brine 11~5~' II~ RU DA, perf w/4" gun, 4 SPF f/~q~2~'-~' & {q-~'-~', RD DA. RU Schl, make 8.35" GR/JB rn. Make 5.9" GR/JB rn. RIH, set lower & middle perm pkrs, RD Schl. Chg rams to 2-7/8" Rn ~-~8"..pkr/PBR.& RE'CEI VEL) MAY 2 8 1986 Alaska 0il & 6as 0ohs. 6ommissio~ Anchorage The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date 5/12/86 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Reporl" on tt3e Hrst Wednesday after allowable has been assigned or well is Plugged. Abandoned or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when aw official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation f space is avadable. I Accounting cost center code District ICounty or Parish I State Alaska I North Slope Borough J Alaska Field ILease or Unit IWell no. Prudhoe Bay J ADL #28325 I L3-31 Auth or W.O. no. ~Title AFE AL0176 I Recompletion WWS #1 API 50-029-21544 Ope rator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~Date ~ CompL~_ I 5/03/86 Complete record for each day reported W.I 21.66% 4/19/86 Date and depth as of 8:00 a.m. Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our 1630 Hfs, I Prlor status if a w.o. 7" f/10,9~6'-12,006' 6.9 ppg Diesel /~ Fin rn'g 354 its, 2-7/8", 6.3%, L-80 EUE 8RD tbg w/SSS 2232', HB Retrv Pkr @ 10,931', 7" lB Pkr @ 11,358' WLM, TT @ 11,510'. Set BPV. ND BOPE, NU & Cst tree to 5000 psi. Displ well to diesel. Close SSSV, set BPV. RR @ 1015 hrs, 5/3/86. RECEIVED MAY 2 8 1986 Alaska Oil & Gas Cons, Com,,,~o,~to,~ Anchorage Did TD e J New TD PB Depth I Released rig ~ Date ~ K nd of rig 1015 Hrs. J 5/03/86 Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % i GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle 5/12/86 Drilling Supervisor WELL: 5/06/86 L3-31 Arctic Pak w/300 Pak. sx AS I, followed by 135 bbls Arctic RECEIVED MAY 2 8 i986 Alaska 0{i & {~as Cons, Oommissio,~'; A',:achoraoe To: State of Alaska John Boyle ARCO Alaska Inc. Lisburne Engineering From: Pam Lambert~ Date: May 14, 1986 Transmitted herewith are the following: Magnetic Tape for Lisburne Well L3-31 GCT LIS Run 1 Tape Number 71464 4-21-86 Sch~ Return Receipt to: ARCO A1 Para Lambte~r ~l~T'O 4 7 7 PO Box i 0U360 ' Anchorage, Alaska 99510 Transmittal No:~ ~q STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMM,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] feet~~t¢~i~ Time extension [] Change approved program [] Plugging [] StimulatexPull tubing [] Amend order [] Perforate/~ Other7 2. Name of Operator ARCO Al ASKA. ];NC. · 3. Address P.O. Box 100360t Anchorages, A]aska 99510 4. Location of well at surface 1170' FNL, 726' FWL, Sec. 22, T11N, R15E, UM At top of productive interval 1320' FNL, 1320' FEL, Sec. 28, T11N, R15E, UM (approx) At effective de[:)th 1603' FNL, 1342' FEL, Sec. 28, T11N, R15E, UN (approx) At tota~l~ FNL, 1353' FEE, See. 28, T11N, R15E, UM (approx) 11. Present well condition summary Total depth: measured true vertical 5. Datum elevation (DF or KB) RKB 51 ' 6. Unit or Property name Prudhoe Bay Un i t/L i sbur'ne 7. Well number L3-31 8. Permit number 86-34 9. APluz~-zn"u'c'lbe~rl 544 50-- 10'L~'°s~urne O i ] Pool 12006 feet Plugs (measured) None 9593 feet True Vertical depth 101' 3883' Effective depth: measured 11950 feet Junk (measured) true vertical 9547 feet None Casing Length Size Cemented Measured depth Structural Conductor 80' 20" 1750 ~ Poleset 101' Surface 4003' 13-3/8" 2950sx PF'~" & 600sx Class G 4032' Intermediate Production 11179' 9-5/8" 1060 sx Class G 1007' 7" 318sx Class G Liner Perforation depth: measured Wahoo 5 11,522' - 11,570' Wahoo 7 11,256' - 11,346' true vertical Wahoo 5 9,190' - 9,230' Wahoo 7 8,970' - 9,044' Tubing (size, grade and measured depth) 2 7/8", L80, 11,358' 11204' 8927' 10999'-12006' 8765'-9593' RECEIVED MAY- 9 1986 Alaska 0ti & Gas Cons. Commission Anchorage Packers a:nd SSSV (type and measured depth) 9-5/8" @ 10,931', 7" Single Selective @ 11,356' (WLM) & 7" Isolation ~ 11..477' (WLM). 2-7/8" SSSV @ 2..232" 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation May 20, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~'/~~ Title L..I Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. /-¢ [] Plug integrity [] BOP Test [] Location clearance I / by order of ~.~... ~ Commissioner the commission Date / Approved by Form 10-403 Rev 12-1-85 0060/BTK Submit in triplicate ATTACHMENT i L3 - 31 ARCO Alaska, Inc., proposes to conduct the following on L3-31. 1. Wahoo zone 5 flow test to establish rate. 2. Nitrofied acid stimulation of Wahoo zone 5 with 2520 gallons of 15% HC1. Acid will be pumped through tubing and the well will be flowed back to recover load and establish flow rate. If necessary, this will be accomplished by nitrogen lifting with a CTU. 3. Perforate Wahoo zone 6 using a 2 1/8" through tubing gun and 4 SPF (11,390' - 11,458' MD, 9,075' - 9,133' TVD). 4. Isolate Wahoo zone 6. 5. Stimulate Wahoo zone 6 with 2,856 gallons of 15% HC1. Acid will be pumped through tubing and the well will be flowed back to recover load and establish flow rate. 7. Potential fracturing of Wahoo zone 6. 8. Isolate Wahoo zone 6. 9. Stimulate Wahoo zone 7 with 3,780 gallons of 15% HC1. Acid will be pumped through tubing and the well will be flowed back to recover load and establish flow rate. 10. Pull isolation plug between Wahoo 6 and 7. 11. Flow well to establish rate. RECEIVED AJaska Oil & Gas Cons. Commission Anchorage SUNDRY NOTICE/BTK STATE OF ALASKA ALASKa, .,IL AND GAS CONSERVATION COMMh~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~;[ Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ,~ Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. O. Box 100360 Anchorage_. AK 9951n 4. Location of well at surface 1170'FNL, 726'FWL, 5ec.22, TllN, R15E, UN At top of productive interval 1320'FNL, 1320'FEL, Sec.28, T11N, R15E, UH (approx.) At effective depth 1603'FNL, 1342'FEL, Sec.28, TllN, ELSE, UM (approx.) At total depth 1632'FNL, 1353'FEL, Sec.28, T11N, R15E, UH (approx.) 5. Datum elevation (DF or KB) 51 ' RKB feet 6. Unit or Property name Prudho~ Ra~,, lln~ ~_./L~ 7. Well number L3 -~1 8. Permit number 86-34 9. APl number 50-- 029-21 544 10. Pool Lisburne 0il Pool 11. Present well condition summary Total depth: measured true vertical 1 2006 ' feet 9593 ' feet Effective depth: measured feet 11 950 ' true vertical feet 9547' Casing Length Size Conductor 80 ' 20" Surface 4003' 13-3/8" P roducti on 11179 ' 9-5/8" Liner 1 007 ' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) No ne Packers and SSSV (type and measured depth) N on e Plugs (measured) No ne Junk (measured) None Cemented Measured depth 1750# Poleset 101 ' 2950 sx PF "E" & 600 sx Class G 1060 sx Class G 318 sx Class G True Vertical depth 101' 4032 ' 3883 ' 11204' 8927' 10999'-12006' 8765'-9593' 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] Well Hi story 13. Estimated date for commencing operation July, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~ Title As sec i ate Engineer Date Conditions of approval Approved by Commission Use Only (DAM) SA/015 Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] location clearance No. by order of .,.~:_. Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel:)ort" on the first Wednesday after a well is spudded or workover operations are started. Daily worl( prior to spudding should be summ_arized on the form giving inclusive dates only. District ICounty. parish or borough Alaska I Field ~Lease or Unit Prudhoe Bay I Auth. or W.O. no. ITitle ' AFE AL0176 J Drill State North Slope Borough Alaska ' ADL #28325 - Parker #176 API 50-029-21544 Operator ARCO W,t. ARCO Alaska, Inc. 50% Spudded 2/11/86 1315 Hrs. Date and depth as of 8:00 a.m. 2/12/86 2/13/86 2/14/86 2/15/86 thru 2/18/86 Complete record for each day reported 20"@ 101' 1621', (1511'), Drlg Wt. 9.7, PV 16, YP 36, PH 9.0, WL NC, Sol 10 Accept rig @ 0400 hrs, 2/11/86. NU diverter sys. Spud well @ 1315 hfs, 2/11/86. Drl & surv 17½" hole to 1621'. 566', 0.5°, S23.9W, 566 TVD, 2.46 VS, 2.26S, 1.00W 1014', 0.7°, S37.3E, 1014 TVD, 6.44 VS, 6.70S, 0.48W 1346', 1.1°, S67.1E, 1345.9 TVD, 7.96 VS, 9.86S, 3.60E 20" @ 101' 2875', (1254'), DD Wt. 9.5, PV 12, YP 28, PH 9.0, WL 21, Sol 9' Drl 17½" hole to 2360', DD to 2875'. 2310', Assumed vertical 2605', 4.9°, S 2.1W, 2604 TVD, 11.96 VS, 12.59, .46W 2790', 9.4°, S15.5W, 2788 TVD, 34.53 VS, 35.06, 4.79W 20" @ 101' 3821',° (946'), Rm'g Wt. 9.6, PV 8, YP 17, PH 8, WL 22, Sol 9.4 DD, drl & surv 17½" hole to 3821', POOH. Chg out BHA, RIH, rm 3541'-3634'. 2992', 13.8°, S13.4W, 2986 TVD, 75 VS, 74S, 15W 3640', 38°, S24.6W, 3574 TVD, 336 VS, 320S, 105W 13-3/8" @ 4032' 5050', (+229'), Drlg Wt. 9.2, PV 12, YP 5, PH 10.5, WL 10.6, Sol 6 Drl 17½" hole to 4050', 10 std short trip, POOH. RU & rn 100 'its, 13-3/8", 72#, L-80 BTC csg & 2 its, 68#, K-55 BTC csg w/FS @ 4032', FC @ 3948'. Cmt w/2950 sx PF "E" & 600 sx C1 "G" w/l% CFR-2, 1% CaCI~. Displ using rig pmps, bump plug. ND diverter, NU &Ztst BOPE. TIH, tst csg to 2500 psi. DO cmt & fit equip, + formation to 4065'. Conduct formation tst to 12.5 ppg EMW. Navi-Drl & surv 12¼" hole to 5050'. 3763', 37.3°, S23.9W, 3671TVD, 411VS, 388S, 135W 3979', 37.5°, S24.6W, 3843 TVD, 542 VS, 508S, 189W 4180', 45°. S22W, 3994 TVD, 674 VS, 630S, 241W 4700', 45.3°, S16.9W, 4354 TVD, 1048 rS, 985S, 357W The above is correct Date For form preparation and distributior~ '~- see Procedures Manual, Section 10,- Drilling, Pages 86 and 87. 4/04/86 ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska I County or Parish I State North Slope Borough ILease ADL #28325 or UnR Prudhoe Ba'' Date and deptl~ as of 8:00 a.m. 2/19/86 2/20/86 2/21/86 2/22/86 thru ' 2/24/86 2/25/86 2/26/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 4032' 6306'~ (1256'), POOH f/bit chg Wt. 9.3, PV 6, YP 10, PH 8.5, WL 8.4, Sol 5.5 Drl & surv 12¼" hole to 6306'. 5190', 43.5°, S20.3W, 4704 TVD, 1391VS, 1310S, 468W 5554', 45.1°, S22.1W, 4965 TVD, 1645 VS, 1546S, 561W 5805', 43.2°, S22W, 5145 TVD, 1820 VS, 1708S, 627W 6082', 45.6°, S18W, 5343 TVD, 2013 VS, 1890S, 693W 13-3/8" @ 4032' 6968', (662'), Surv Wt. 9.2+, PV 8, YP 8, PH 8.0, WL 8.0, Sol 6.8 Chg bits, RIH, rm f/6248'-6306', drl to 6968'. 6423'. 45.9°, S19.7W, 5581TVD, 2257.46 VS, 2121.48S, 771.82W Alaska 13-3/8" @ 4032' 7442', (474'), Drlg Wt. 9.3, PV 10, YP 5, PH 12.5, WL 12.6, Sol 7.2 Drl & surv 12¼" hole to 7442'. 6885', 44.7°, S19.7W, 5905.94 TVD, 2585.82 VS, 2430.64S, 882.51W 7176', 46.6°, S20.4W, 6109.35 TVD, 2793.89 VS, 2626.10S, 953.87W 13-3/8" @ 4032' 8748', (443'), TIH Wt. 9.5+, PV 14, YP 6, PH 12.3, WL 8.2, Sol 7.5 Navi-Drl, drl & surv 12¼" hole to 8748'. 7543', 48.9°, S19.7W, 6356.09 TVD, 3065.52 VS, 2881.28S, 1046.97W 8192', 49.2°, S17.6W, 6781 TVD, 3556 VS, 3344.91S, 1206.11W 8622', 46.8°, S18.3W, 7069 TVD, 3875 VS, 3648.9 S, 1304.55W 13-3/8" @ 4032' 9530', (782'), Rm'g Wt. 9.7+, PV 12, YP 9, PH 12.0, WL 6.6, Sol 9.5 Drl & surv 12¼" hole to 9530', POOH 21-2/3 stds lk'g f/wshout. RIH, rm 9309'-9385'. 9058', 46.2°, S20.3W, 7369 TVD, 4191VS, 3946.89S, 1410.33W 9496', 47.7°, S20.4W, 7668 TVD, 4511VS, 4246.49S, 1522.93W Well no, L3-31 13-3/8" @ 4032' 9862', (332'), TOH lk'g f/wsh out Wt. 9.7+, PV 12, YP 10, PH 12, WL 7.0, Sol 11 Drl 12¼" hole to 9862', trip f/wsh out° The above is correct For form preparation and distribuC'on see Procedures Manual Section 10, Drilling, Pages 86 and 87 JOate ITitle 4/04/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequent a y Attach descr pt on of all cores. Work performed by Producin,.g, Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska ILease or Unit North Slope Borough I ADL #28325 Complete record for each day while drilling or workover in progress Field Prudhoe Bay 2/27/86 2/28/86 3/01/86 thru 3/03/86 3/04/86 3/05/86 3/06/86 Date and depth as of 8:00 a.m. 13-3/8" @ 4032' 10,275', (413'), Drlg Wt. 9.7, PV 13, YP 10, PH 12.5, WL 8.4, Sol 10 RIH, drl f/9862'-9945', POH lk'g f/wshout. RIH, drl 9945'-10,275'. 9897', 47.2°, S21.8W, 7939 TVD, 4866 VS, 4522S, 1629W 13-3/8" @ 4032' 10,700', (425'), Drlg Wt. 9.7+, PV 13, YP 10, PH 12, WL 8.2, Sol 10 Drl & surv 12¼" hole to 10,700'. 10,361', 43.4°, S21.1W, 8265 TVD, 5136 VS, 4829S, 1750W Alaska 13-3/8" @ 4032' 10,737', (37'), CBU Wt. 9.7, PV 13, YP 10, PH 12, WL 7.6, Sol 10 Drl 12¼" hole to 10,737', POOH lk'g f/wsh out, stuck pipe @ 4912'. Jar pipe, spot IMCO Spot. RU DA, RIH w/freept, POOH. RIH w/string shot, BO @ 4645' DPM, POOH. RD WL. RIH w/fsh'g assy, unable to screw into fsh, POOH. PU 11½" skirt & screw in sub, TIH, screw into fsh, jars failed, POOH. Chg out fsh'g assy, RIH w/OS & grapple, engage fsh, jar free, POH, dropped fsh pulling thru tight spot @ 4816'. TOH, PU drlg assy, TIH f/wiper rn, rm 4429'-4688'. GIH to 7425', no tight spots, CBU. 13-3/8" @ 4032' 10,737', (0'), POOH Wt. 9.8, PV 13, YP 7, PH 11.5, WL 7.8, Sol 11 GIH, tag bridge @ 8748', wsh & rm f/8748'-10,208', C&C, POOH. RIH w/fsh'g assy, att to engage fsh, POOH, no rec'y. 13-3/8" @ 4032' 10,737', (0'), POOH Wt. 9.7, PV 13, YP 7, PH 12, WL 8.7, Sol 9.5 POOH, chg out grapple to 6-1/8". RIH, engage fsh & wrk same free; grapple stripped off fsh, POOH. RIH w/pin tap, tag fsh @ 10,208', screw into fsh, stripped out. Att to re-engage fsh w/o success, POOH to PU 12¼" bit to cln out hole & locate TOF. 13-3/8" @ 4032' 10,737', (0'), RIH Wt. 9.8, PV 12, YP 6, PH 12, WL 8.2, Sol 9.5 LD fsh'g tls. PU bit, RIH, wsh & rm 10,146'-10,213' (TOF @ 10,213'), POOH. PU OS, RIH; unable to get over fsh, POOH. PU bent jt DP & RIH. ~ JWell no. L3-31 The above is correct For form preparation and distributio~ see Procedures Manual Section 10, -- Drilling, Pages 8§ and 87 IDate 4/04/86 Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptll as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Prudhoe Bay ADL #28325 Complete record for each day while drilling or workover in progress 3/07/86 3/08/86 thru 3/10/86 3/11/86 3/12/86 3/13/86 3/14/86 State Alaska IWell no. L3-31 13-3/8" @ 4032' 10,737', (0'), Mx cmt Wt. 9.8, PV 11, YP 4, PH 11.8, WL 9.0, Sol 10 Att to engage .fsh w/o success, POOH. RIH w/hook wall guide, unable to get over fsh, POOH, LD fsh'g tls. RIH w/OEDP, RU to set cmt plug. 13-3/8" @ 4032' 10,627', (516'), POOH Wt. 9.8, PV 9, YP 4, PH 12, WL 9.2, Sol 8 Spot 200 sx C1 "G" cmt plug on TOF, POOH. TOC @ 9956'. RIH w/BHA, rm 9801'-9969', tag cmt. Drl soft cmt f/9969'-10,010', LD 3 jts. Rm 9895'-9923' to under cut hole; unable to sidetrack @ 9923'. Rm 9895'-10,010', drl to 10,020'; unable to sidetrack. Wsh 10,020'-10,111', tag firm cmt again, sidetrack & Navi-Drl 12¼" hole to 10,627'. 10,082', 46.1°, S22.2W, 8066 TVD, 4941VS, 4646.82S, 1679.64W 10,538', 40°, S20.8W, 8405 TVD, 5246 VS, 4934.91S, 1784.45W 13-3/8" @ 4032' 10,709', (82'), Drlg Wt. 9.9, PV 10, YP 7, PH 12, WL 8.8, Sol 9 RIH w/BHA, rm 4624'-4731', 10,077'-10,145', 10,324'-10,627' Drl 10,627'-10,651', wrk pipe thru 10,574'-10,606', drl f/10,651'-10,709'. 13-3/8" @ 4032' 11,158', (449'), Drlg Wt. 9.9, PV 13, YP 10, PH 12, WL 6.8, Sol 8 Drl t2¼" hole to 11,158'. 13-3/8" @ 4032' 11,218', (60'), Wrk pipe Wt. 10.1, PV 12, YP 10, PH 12, WL 6.8, Sol 9 Drl 12¼" hole to 11,218', 15 std short trip, hole tight. Rm back to btm, CBU, POOH, stuck pipe @ 5246'. Wrk stuck pipe. 13-3/8" @ 4032' 11,218', (0'), GIH Wt. 9.8+, PV 11, YP 8, PH 12, WL 6.8, Sol 9 Jar stuck pipe, spot 62 bbls SFT pill, jar, pipe free, POOH,.LD BHA. GIH f/wiper trip. ~ 11,148', 37°, S21W, 3881TVD, 5626 VS, 5290S, 1920W The above is correct Signature ~ For form preparation and distribution see Procedures Manua Section 10; Drilling, Pages 86 and 87 IOate ITitle 4/04/86 Drilling Superintendent ARCO Oil and Gas' Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form, I) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. I County or Parish Alaska North Slope Borough I Lease or Unit Prudhoe Bay ADL #28325 Complete record for each day while drilling or workover in progress 3/15/86 thru 3/17/86 District Field Date and depth as of 8:00 a.m, 3/18/86 3/19/86 3/20/86 3/21/86 IState Alaska JWell no. L3-31 9-5/8" @ 11,204' 11,689', (471'), Drlg Wt. 9.3, PV 9, YP 5, PH 10, WL 9.8, Sol 6 RIH, rm f/10,980'-11,218', pmp hi-vis pill, CBU, POOH. RU & rn 259 its, 9-5/8", 47#, L-80 BTC csg w/FS @ 11,204', FC @ 11,119'. Cmt w/1060 sx C1 "G". Displ using rig pmps, bump plug. TIH w/8½" BHA, tst csg to 3000 psi. DO flt equip & cmt + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 11,689'. 11,386', 33.7°, S15.8W, 9076 TVD, 5764 VS, 5420S, 1963W 11,454', 32.8°, S16.2W, 9132 TVD, 5801VS, 5456S, 1974W 9-5/8" @ 11,204' 12,006', (317'), CBU Wt. 9.3, PV 11, YP 6, PH 10, WL 8.1, Sol 7 Drl & surv 8½" hole to 12,006', short trip, CBU; well slightly flowing, CBU. 11,673', 33.2°, S20.8W, 9317 TVD, 5920 VS, 5567S, 2016W 11,890', 34.6°, S19.3W, 9497 TVD, 6040 VS, 5681S, 2057W 9-5/8" @ 11,204' 12,006', (0'), RIH w/CET Wt. 9.3, PV 11, YP 6, PH 9.5, WL 8, Sol 6 CBU, POOH. RU Schl, rn DLL/MSFL/NGT/SP/CAL f/11,996'-11,194' WLM. Rn LDT/CNL/Micro log/EPT/GR f/11,9960'-11,194' WLM, cont w/CNL to 4032'. Rn LSS/GR f/11,194'-11,996'. PU CET/GR/CCL & RIH. 9-5/8" @ 11,204' 12,006', (0'), POOH Wt. 9.3, PV 10, YP 7, PH 10.5, WL 8, Sol 8 Rn CET f/11,190'-9200', RD Schl. Make cond'g trip f/7" lnr, POOH. CIP @ 2215 9-5/8" @ 11,204' 12,006', (0'), PU 3½" DP Wt. 9.3, PV 11, YP 6, PH 10, WL 8.2, Sol 8 Fin POOH. RU & rn 23 jts, 7", 29#, L-80 BTC csg w/FC @ 11,959', FS @ 12,006', LC @ 11,829', TOL @ 10,999'. Cmt w/318 sx Cl "G" w/4% gel, .5% FDP-344, .4% LWL & 5#/sx Gilsonite. hrs, 3/20/86. POOH w/rn'g tl. The above is correct For form preparation and distribution see Procedures Manual Section '10, Drilling, Pages 86 and 87' JDate 4/04/86 JTit,e Drillin~ Superintendent ~i AtlanticRichfieldCompany .~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District ICounty or Parish I State Alaska I North Slope Borough J Alaska Field ILease or Unit IWell no, Prudhoe Bay I ADL #28325 I L3-31 Auth. or W.O. no, JTitle AFE AL0176 I Drill Parker #176 AP1 50-029-21544 Operator I A.R.Co. W.I. ARCO Alaska, Inc. [ 50% Spudded or W.O. begun [Date Spudded I 2/11/86 Complete record for each day reported Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our [ Prior status if a W.O. I 1315 Hrs. Date and depth as of 8:00 a.m. 3/22/86 thru 3/23/86 7" @ 12,006' 11,950' PBTD, 12,006' TD, (0'), RR Diesel cap w/9.3 ppg mud below RIH, CO cmt to TOL @ 10,986', POOH. RIH w/7" scrpr/bit, drl cmt f/11,750'-11,950' & LC @ 11,828'. Tst lnr lap to 3000 psi; OK, POOH. RU WL, rn CBL f/10,986'-9200' w/1000 psi on csg & f/10,986'-10,300' w/0 psi on csg. RIH, C&C mud, POOH, LD DP. Circ in diesel cap @ 1970', POOH, LD DP. ND BOPE. NU tbg spool & hgr, tst to 5000 psi. RR @ 1430 hfs, 3/23/86. Stack rig. Old TD [ New TO I PB Depth I 12,006' [ 11,950' Released rig iOaie iKind of rig 1430 Hrs. 3/23/86 Rotary Classifications (o11, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. !Water % GOR Gravity Allowable Effective date corrected _. The above is correct Signature For form preparation and d~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle 4/04/86 Drilling Superintendent Lisburne Engineering To: State of Alaska John Boyle ~'rom: Pam Lambert Date: April 22, 1986 Traasmitted herewith are the following: Magnetic tape for Lisburne Well L3-31 OH LIS Shifted 3-18-86 Run 1 Tape Number 71364 Sch Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: J~-~ -~ STATE OF ALASKA ALASKA .~.._ AND GAS CONSERVATION Cb,,, ..ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS/ ' · Drilling well Yl~ Workover operation [] 2. Name of operator ARCO Alaska, Inc, 7. Permit No. 86-34 4. Location of Well 1170' FNL, 726' FWL, 5ec.22, T11N, R15E, UN at surface 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21544 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 51' RKB ADL 28325 ALK 2323 10. Well No. L3-31 11. Fieldand Pool Prudhoe Bay Field Lisburne 0il Pool For the Month of. Hatch , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1315 hfs, 2/11/86. Drld 17-1/2" hole to 4050'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,737'. Stuck pipe. Jarred and fished for pipe. Spot 200 sx Class 6 cmt plug on 'cop of fish. Top of cmt @ 9956'. Drld cmtd to 10,111' & sidetracked. Drld 12-1/4" hole 'co 11,218'. Ran, crntd, & ts'cd 9-5/8" csg. Drld 8-1/2" hole to 12,006'TD (3/18/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 11,950'. Ran CBL. Secured well & RR (~ 1430 hrs, 3/23/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ¢ 101'. Installed w/1750# Poleset. 13'3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe ~ 4032'. Cmtd w/2950 sx PF "E" & 600 sx Class 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe 8 11,204'. Cmtd w/1060 sx Class 6. 7", 29.0#/ft, L-80, BTC csg f/10,999' - 12,006'. Cmtd w/318 sx Class 6. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/MSFL/NGT/SP/Cal f/11,996' - 11,194' LDT/CNL/Microlog/EPT/GR f/11,996' - 11,194'; CNL to 4032' LSS/GR f/11,996' - 11,194' CET/CCL f/11,190' - 9200' CBL f/10,986' - 9200' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Reporl~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAH2/MR13 Submit in duplicate ARCO Alaska Inc. Lisburne Engineering To: State of. Alaska John Boyle From: Date: Pam Lambert 5~ April 10, 1986 Transmitted herewith are che~following: OH Finals for Lisburne Well L3-31 '~'~LSS 3-19-86 Run 1 2"&5" Sch ~LSS/Waveforms 3-19-86 Run 1 5" Sch ~'~Natural GR Spectorscopy 3-18-86 Run 1 2"&5" Sch ~'~LDT/CNL (Raw) 3-18-86 Run 1 2"&5" Sch ~'~LDT/CNL (Poro) 3-18-86 Run 1 2"&5" Sch ~EPT/GR 3-18-86 Run 1 2"&5" Sch "~Micro Log 3-18-86 Run 1 2"&5" Sch bo DLL/MSFL 3-18-86 Run 1 2"&5" Sch ~'~ CNL in 9 5/8 casing 3-18-86 Run 1 2~'&5'v Sch · ~ CET 3-19-86 Run 1 5" Sch Receipt ~Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box i00360 Anchorage, Alaska 99510 Transmittal No: ~~ Lisburne Engineering To: State of Alaska From: Para Lambert John Boyle Date: March 31~ 1986 Transmitted herewith are che following: Magnetic Tape for Lisburne Well L3-31 OH LIS Unshifted 3-18-86 Run 1 Sch Tape Number 71364 -/ Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 9951£~ Transmittal No:~_~ ---,~: STATE OF ALASKA ~. ~ c ALASKA ~., . AND GAS CONSERVATION CO ,¢IlSSION ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS , ,. Drilling well Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 1170' FNL, 726' FWL, Sec.22, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 51' RKB APL 28325 ALK 2323 7. Permit No. 86-34 8. APl Number 50-- 029-21 544 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L3-31 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool For the Month of February , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] (~ 1315 hfs, 2/11/86. Dr]d 17-1/2" hole to 4050'. Ran, cmtd, & tstd 13-3/8" csg. hole to 10,737' as of 2/28/86. 2-1/4" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 101'. Installed w/1750# Poleset. 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe ~ 4032'. Cmtd w/2950 sx PF "E" & 600 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run None i3. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor~on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 IbAM/MI~? Submit in duplicate MEMORANI" JM State of Alaska TO: TH RU' FROM' AIASKA OIL ~'~ ~ CONSF/RVATION CO~R~ISSION DATE- C~ai~ ~ FI LE NO,: ~e-C. ~th /';'""~"~ TELEPHONE NO,: ~ssi~r ~ $UBO5CT: ~bby Foster ~;;~' Petrole~ I~ctor February 19, 1986 DOPE Test on ARCO- P.B.U.-L3-31 Permit 86-34 Lisburne Oil Pool Sup. day,..... Febru~.....rv.' 16, 1986.:.. The ~PE test began at 12:30 a.m. and was C~pletAd at 2:%0 a'm, ~ the attached BOPE test report shcws there ~mre no failures. In sunmary, I ~tnessed the BOPE test on ARCO's .L3-31. Attachment ,0 I/4 /84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report 0 ?'/ - rive ,- l ' - Drilling Contractor ~/~/~ Rig Location, General ~// Well signO~~ General Housekeepi ig Reserve Pit ~_~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test PreSsure ACCUMULATOR SYSTEM Full Charge Pressure ~/O~ psis Pressure After Closure /~Y'D psis Pump incr. clos. pres. 200 psig ~-- min~Psec. Full Charge Pressure~Attained: ~ min~Jsec. N~ ~-----~/0~, ~/~.,~2_~,~P~ . psig Controls: Master Remote¥C 6 Blinds switch cover ~_~ Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure ~/p Test Pressure. ~ z~ Test Pressure ,_~'z~ Test Pressure ~-0 Choke Manifold ~~ Test Pressure ~-~ NO. Valves No. flanges Adjustable Chokes Hydrauicall¥ operated choke / Test Results: Failures ~> Test Time ~ Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: hfs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor February 4, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit L3-3! ARCO Alaska, Inc. Permit No. 86-34 Sur. Loc. ll70~:FNL, 726'F%~, Sec. 22, T].IN, R15E, lrM. Btmhole Loc. 188~'FNL, 1532'FEL, Sec.. 28, TllN, R15E, Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Iqhere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chattereon Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo,~ ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 29, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Lisburne L3-31 Permit to Drill Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Lisburne L3-31, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Diagrams showing the proximity to other wells in the area. Sadlerochit wells DS 11-9 and DS 11-11 are within 200' of L3-31, as discussed in the application. A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment o A copy of the certified "As-Built" conductor survey We estimate spudding this well on February 9, 1986. If you have any questions, please call Don Breeden at 263-4963. Sincerely, T. P. Oostermeyer Regional Drilling Engineer TPO/D~/tw PD/L222 Enclosures RECEIVED JAN 2 9 198S ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany a. Type of work. RECEIVED ~:~ STATE OF ALASKA --~ ALASKA O,-ANDI~ERMiTGAS CONSERVATIONTo DRILLC° "vllSSI°N ,jAF~, 2 9 ~"::~:8~ 20 AAC 25.005 ~,J~.Sk~ REDRILL [] DEVELOPMENT OIL I-X!X SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE 2. Name of operator 3. Address bUl~il ILILI~I i Po 0. Box 100360, Anchorage, Alaska 99510 : 4. Location of well at surface 1170' FNL, 726' FWL, Sec.22, T11N, R15E, UN At top of proposed producing interval & Target (9001 'TVD): 1320' FNL, 1320' FEL, 5eco28, T11N, R15E, UM At total depth 1883' FNL, 1532' FEL, Sec.28, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 51', PAD 21' I ADL 28325 ALK 2323 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Prudhoe Bay Unit/Lisburne 10. Well number L3-31 11. Field and pool Prudhoe Bay Fi eld Lisburne Oil Pool Amount $500,000 13. Distance and direction from nearest town 7-1/2 mi. NE of Deadhorse miles 16. Proposed depth (MD & TVD) 12179'HD, 9591 ' TVD feet 14. Distance to nearest property or lease line / 15. Distance to nearest drilling or completed 1320' ~ Target feet D~11-11well 177 feet 17. Number of acres in lease ! 18. Approximate spud date 2560 / 02/09/86 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2350 feet. 21 MAXIMUM HOLEANGLE45½ ol 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 3420 4490 psig@___~0°F . Surface _psig@. 8951 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' I 30' 110' I 110' 2000# Poleset 17-1/2" 13-3/8" 68.0# K-55 BTC 70' 30' I 30' 100' 17-1/2" 13-3/8" 72.0# L-80 BTC 4092' 100' I I 100' 3000 sx PF "E" Lead & i 100' 4192' ] 4000' 400 sx C1 ass G Tail 12-1/4" 9-5/8" 47.0# L-80 BTC 11265' 28'II 28' 11 293' I 8971 ' 750 "G"/300 PFC&ArcticPk 8-1/2" 7" 29.0# L-80 BTC 1086' 11093' 18831' 12179' !9591' 400 sx Class G I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill this Lisburne development well to approximately 12,179'MD(9591'TVD). It is planned as a Wahoo production well. A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 p~i for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged. A string of 2-7/8", 6.5#, L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED /~ P ~ TITLE Regional Drilling Engineer The space below for Commission use ~' CONDITIONS OF APPROVAL Samples required Directional Survey required APl number Permit number SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE Februarv by order of the Commission Form 10-401 Submit in triplicate Mud log required []YES [~NO Approval date ~ 02/04./85 PDTPD222--- ~ - / PERMIT TO DRILL L3-31 (cont'd) Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Permafrost C cement). That annul,s will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig ~ 40°F was calculated from the Wahoo datum pressure of 4490 psig ~ 8951'TVD and 183°F. It assumes an oil column to 8651'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and present reservoir pressure in the Sadlerochit @ 8356'TVD, yields a maximum surface pressure of 2850 psig ~ 40°F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set @ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. The planned well path of L3-31 passes within 200' of Sadlerochit wells DS 11-9 and DS 11-11. L3-31 will pass above DS 11-9 at a calculated minimum distance of 193' at 7385'MD/6236'TVD. L3-31 will pass below total depth of DS 11-11 at a calculated minimum distance of 177' at 11,353'MD/9013'TVD. There are no other wells within 200' of L3-31. RECEIVED 1000 20OO 3OOO 4000 SO00 6OOO 7000 8000 9000 10000 11000 L3-31 1000 2OG,_ 3000 4000 5000 6000 7000 I I IO' CONDUC'rOR TVD=1171 ARC 3 AL ,SKA, iNC. ,:CALl:: I IN = 18n8 FT. 2000 SHL:1170 'FNL, 726'FWL, (OP TVD = 2360 2.5 SEC.22 T11N,I:115E,UI~ 7.5 THL: 1320 'FNL, 1320' FE L, : ~2.5 t ~FC. ')R T11N_R1.~F.lII~I 3000 17,6 22.i ) 2-5 2,5 37.5 4-2.5 EOC TVD -- 3987 MD -- 4173 DEP -- 687 4000 13-3/8' SURFACI! TVD --- 400( MD ---- 4192 DEP == 701 "~ K-15 TVD -' 4930 MD -- 5520 r~EP -- 1650 5000 $ 20 DEG 38 ~IN W 5803 FT{TO T,~RGET! AVERAGE ANGI.E ..... 6000 % ¢5 ucuo* ~i~ t DS 11-1C K-5 T'fD---7751 ME =9550 DEP---4528 __ !-!!G LCU TVD = 5356 MD I 1~414 DEP -- 5145 SADLER )CHIT TVD I 8356 MD I 10414 DEP == fi145 / = 8781 k D I 11022 DIEp m 5578 ~ KAVIK FVD c, -5/8' CASIN(; TVD =, 8971 MD I 11293 DEP == ~7_Z72 '~.= TAP, t31ET T¥!~ = ~00' I~ = 1133~ O~P = 5803 TD-~7' LINER TV[)==9591 MD =12179 DEP=,6405 0 1000 2000 3000 4000 5000 6000 7000 8OOC VERTICNL SECTION ,~HI '117 ~I'I=NI . 7~R'l=: ~l, SEC.22 ,T11N,R 15E, Ul~ THL:132 D'FNL, 1320'F EL, SEC.28 ,T11N,R15E,U ~ ~ - , _ . L3-3~ o 'ARGET : ~'VD ~ 9001' ~ ~'MD ~ 11336' I EP ~ 5803' o 5430 I E - ~ COORO]:N~T:S -6000 -5000 -4:000 -3000 -2000 - tO00 0 CD CD Z E N COORDINFITES -6000 -5000 -4000 -3000 -2000 DS 11-9 ,/ 7 875 DS 11-113 ~72 OS 11-11 ........................................... ~~ .... -,.~ ,.~ ~-,. ...... -6000 '5000 -4000 -3000 -2.000 -1000 0 1000 - H COORD I NST~S "' TM ~::: "'"' ~." o-lztO0 -1500 -1200 -1100 -1000 -900 -800 -7C0 11 9 ~ - 68t q - . /. 6538 59~5 '~ 6~72 I .i I 6~10 . OJJJ 6299 - lztO0 -lJO0 -1200 -1100 -1000 -900 -80~d-~' -?00 . g F,, N COORI3 INFITP, S .... 0-2500 -2400 -2500 -2200 -ai00 -2000 - 900 -1800 CE] r--q r'~ o o cJ CD CD OO Z CD CD I I I I I I I i I I I I I I I i I I I J I I I I I I I I'l I I f I I ~871 · L 8856 866S 8096 7908 ~,' ...'. ~.~ '~ -2500 -24:00 -2300 -2200 -2100 -2000 -1900 -!800 - N C00RDIN[qTES SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INC. SCHEMATIC 0" HYD. OPR. BALL VALVE WE,L,L BORE (SEE DETAIL) IO HYD. OPR. BALL VAL,V,E I ALL 90' TURNS ARE "TEE CUSHION I J SUB BASE~ I i RESERVE PIT I AREA I I I I I i NOTE: I I I I I FLOWL INE DR ILL lNG R I SER 20" 2000 PSI WP ANNULAR PREVENTOR lined open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 202601020,TM RNNULPJ~ -PREVENTOR PIPE RAMS 13-$/8" BOP STACK DIAGRAM Accumulator Capacity Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 5000 psi with 1S00 psi downstream of the regulator. Observe time, then close all un/ts simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on [ADC report. (The acceptable lower limit is 4S seconds closing time and 1200 psi remaining pressmre. 13-5/8" BOP Stack Test BLIND RAMS DRILLING SPOOL _ PIPE RAMS 1. Fill BOP stack and .manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 5: Close annular preventer and upstream valves. 4. Functionally t~st chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a minimt~n of 5 minutes, then test at the high pressu .~r~_~.. 6. Increase pressure to._~O00__R~ hold for a mimimum of 5 minutes. Bleed '~-~6~ to zero. 7. Open annular preventer and cl. ose-Z~l~set of pipe rams. Increase pressure tOf~S~0~0P.o~sifps~i and hold for at least 5 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to S000 psi and hold for at least 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to S000 psi below the bottom set of pipe rams and hold for at least 5 min- utes. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe Back off running joint and pull out of hole. Close blind rs~s and test to 5000 psi for at least 3 minutes. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with [~omey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOPE test once a week and func- tionally operate BOP£ daily. 10. 11. 12. 13. 14. 15. 16. 17. 18. Revised 2/21/84 · RNNULIqR · PP&'VENTOR PIPE RRI'I~ BLIND RRM~ ILLIN8 SPOOL _ PIPE RRMS BOP STACK DIAGRAM ~ccumlator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining a£ter all units are closed with charging pump off. 4., Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and .manifold with a non-freezing liquid. 3. ~eck that an hold down screws are ~uil7 retracted. Mark rurm&ng joint with predetermined plug seating depth. Run test plug on drill pipe ~ seat Ln wellhead. P~n in lock down screws. 3; Close annular preventer and upstream valves. 4. Functionally t6st chokes. · 5. -In each of the following tests, first hold a 250 psi low pressure test for a ~ of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum o£ 3 minutes. Bleed pressure to zero. ?. Open armular preventer and close top set of pipe rams. Increase pressure to 5000 psi ami hold for at least $ minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to 5000 psi and hold for at least $ minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams ami hold for at least utes. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe Back off? running joint and pull out of hole. Close blind rams and test to 5000 psi for at least $ minutes. Bleed pressure off all equipment. Open blind rams. Make sure mani£old and lines are full of non- freezing liquid and all valves are set in drilling position. Test standpipe valves to 5000 psi. Test Xelly cocks and inside BOP to 5000 psi with Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOP£ test once a week and ~unc- tionall¥ operate BOPE daily. 10. 11. 12. 13. 14. 15. 16. 17. 18. Revised 2/21/84 TIIN _._ 'PLANT NORTH grid North i's 13° East LEGEND W£~- WEST LINE OFFSET. NLO - NORTH LINE OFFSET ~ CONDUCTORS AS-BUILT - Cond ASP ZONE 4 2 Y=5 962 076. 16 X: 707 961.01 5 Y=5 961 949.12 X= 707 810.65 I0 Y--5 961 842..30 X= 708 014.97 12 Y=5 961 785,86 X: 708 0Z8.53 15 Y=5 961 598.34 X= 707 891.78 18 Y =5 961 608.42 X= 708 068.98 19 Y =5 961 481.43 X= 707 918.71 2:2 Y=5 961 491.63 X= 708 096.03 23 Y:5 961 364.52 X= 707 945.70 24 Y=5 961 453. f5 X= 708 I09.41 25 3'=5 961 306.08 X-' 707 959.10 28 Y=5 961 316,20 X= 708 136.4,8 30 Y=5 961 257:.72 X= 708 14991 31 Y=5 961 130.62 X= 707 999.72 Y=5 961 140.7'3 X= 708 176.93 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS .ARE CORRECT. DATE SURVEYOR SITE L'3 STO~AGE 26 VIClNITY MAP SECTION 22 OFFSET WLO NLO ', r15 223 LONG =148°18 56.1066 CAT: 70°i7',5Z9118'i,, 561 346 LONG = 148°19 00.5908 LC'NG = 148c'18 54.72.,27' /_AT:?O°17'~6.227~:' 774 518 LONG =i48°18 54.3746 LONG :148 I~ 58.5~95 LAT= 70°17'54.4919'', BIO 694 LONG = 148°18r53.3376' LAT= 70°17',5_3.284~,' 656 817 LONG =148°18 5Z8189 L T: '/o° LONG: 14~18 52.6435 I. AT= 70° 17'52.1275" 679 934 LONG = 148°18'5Z 1267" LONG = 148°18 52.3008 I_AT= 70°17'~1.5492",, 691 993 LONG '- 148°18 56.7835 zoo;r:Sl.6OO :: 868 LONG ~148°18 51.6063 I-AT: 70°17' ~1.0'ZI8'' 880 1047 LONG: 148°18 51.2622 LAT= 70°.17'49.8132",, 726 1170 LONG: 148~ 1~55.7413 o LAT: 70 'JT',flg.864~ ., 904 1165 LONG = 148~' Ig 50.569~ ' ARCO NO, ARCO Alaska' Inc. AS- BUILT DRILL SITE L-$ CONDUCTORS LOCATED IN PROTRACTED SECTION22~ TIIN~ RISE U.M. PREPARED BY LOUNSBURY & ASSOClATES~ INC. 723 W6th AVF.,~ ANCHORAGE,ALASKA DATE: Iq/Z9/85 , CHKD. BY: GEL SCALE: I *': 300' FLD. BK.: LHD 85-101 ARCO Alaska, Inc~-~- Post Offic, ~< 100360 :: ~ .: Anchorage, Alaska 99510-036 :i;"::~!:;:: Telephone 907 276 1215 November 6, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - L3 Pad (Wells 2, 3, 10, 12, 15, 18, 19, 22 - 25, 28, 30, 31, 34) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L74 Enclosure RECEIVED A!aska Oil & Gas Cons. Comm[ssior~ AnchoreD9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 'PLANT NORTH 4e ~ Orid North i's 13° East $. ~ Cond ASP ZONE 4 -ell ~ , 2 Y=5 962 076.16 * 13 X: 707 961.01 (~ 16 ' 3 Y=5 961 949.12 ~ X= 707 810.65 -o I? 2o° I0 Y-'5 961 842.30 .~y%-'~ ~ X = 708 014.97 ~ IZ Y=5 961 785.86 ~ 15 Y=5 961 598.34 ~~° X= 707 891.78 ~ 18 Y=5 961 608.42 -~ Z7 ~ X= 708 068.98 32., 19 Y =5 961 481.43 ~ X= 707 918.71 ~ 22 Y=5 961 491.63 32o X: 708 096.03 ~ 35 23 Y=5 961 3C:~.52 X= 707 945.70 24 Y=5 9Gl 455. t5 X= 708 109. 41 25 Y =5 961 306.08 X= 707 959.10 28 Y=5 961 316.20 X= 708 136.48 30 Y=5 961 257.72 X= 708 14~91 31 Y=5 961 130.62 X= 707' 999.7Z 54 Y=5 961 140.73 X= 708 176.95 LEGEND W£~- WEST LINE OFFSET NLO -NORTH LINE OFFSET ~ CONDUCTORS AS-BUILT ....... THIS S~RV~. . . . -- CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISIbN~ DATE SURVEYOR ,.. &. Gas Or;ns, .Anc~oraL~e ,i VIGIN ITY I._~T=70°17;59.1199'~; LONG =148°18 56.1066 CAT: 70°/7',57.9//8,. LONG = 148°19 00.5908 L T= 7O° LONG = 148018 54.7,?.27 LAT= 70° [7'~6. Z277,' LONG =148°18 54.3746 o t / . LAT=70 17 54.44 0, LONG = 148°18'58.5095 LAT= 70° 17'54.4919" LONG = 148°1~ ~53.3376' LONG =148~18 57.8159' LONG = 148°18 52.$455 I. AT= 70 o 17' 52.127'5 ' LONG = 148°18'57. 1267" b~T= LONG = 148°18'5~.300S ~= LONG = 148°18 56.7835 LONG =148°18 51.6065 LAT= 70° 17' ~.1.0218' LONG = 148°18 51.262.Z LAT= 70°JT'~gJ3132'. LONG = 148~ 18 55.7413 0 LAT=70 17'~9.864~ LONG = 148° 18r~'.56'~ ARCO No. MAP SECTION 22 OFFSET WLD NLO 715 223 561 346 762 459 774 518 632 599 810 694 .. 656 817 8.53 812 679 934 ~45 ET0 691 993 868 988 880 1047 726 1170 904 1165 I ARCO Alaska, Inc. AS- BUILT DRILL SITE L-3 CONDUCTORS LOCATED IN PROTRACTED SECTtON ZZ, TIIN~ RI5E U.M. PREPARED BY LOUNSBURY 8~ ASSOClATES~ INC. 723 W6fh AVE, ANCHORAGE,ALASKA DATE CHKD. BY: GEL ISCALE:J'_'-- .300__: FL D, BK.:· LHD 85-101,, . . . · ~.: ~i-.:/ITEM APPROVE. DATE / :(2) Loc '8 (2, thru le 5. 6. 7. (8) (3) Admtn ~ /--) ~"~,b 9. (¢ thru 12) 10. (10 and 1~2) t 12. <4) Cast ~.~.~_. (13 thru 21) ,' -:~/"-:' (22 t~ru 26) 13. 14: 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. &' Well No. YES NO Is the permit fee attached ........................................ Is well to be located in'a defined pool ................... Is well located ·proper distance from property line .... ~.. · .. Is well located proper distance from other'wells ......... ' Is suffiCien~ undedicated acreage aVailable in this pool .' . Is well to be deviated'and is wellbore plat included .... · Is. operator the only affected party ....... , .............. Can permit be approved before ten-day wait ............ ;. · __ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ' ' .~.'" Is conductor string provided ........................ , ............... Is enough cement used to circulate on conductor and surface ......... Will· cement tie in surface and intermediate'or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse,'tension and burst..//~ Is this well to be kicked off. from an existing wellbore .. ..... % ...... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation'proposed .... ..' ................. ..... Is a diverter system required ........................... Are necessary diagrams of diverter ;nd' i ~ BOP equ p e~t attac~ed .... Does BOPE have sufficient pressure rating - Test Does the choke manifold e0mply w/API RP-53 (Feb.78) .................. Is the presen6e of H2S gas probable ................................. Additional requirements .... ......................................... , REMARKS Additional Remarks: 0eo.logy: Eng~negring: rev.: 03/13/85 6.011 '{ "INITIAL GEO". uNIT ON/OFF" POOL CLASS STATUS AREA. NO. SHORE ., , Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. RECEIVED lot4 L ? ~T ~ P 3 L L M './ ) V 0 3 L L ,'~ V ; i 0 ] L L j F ,E q 3 ~' L L L ,i ~ ~ T C N L : C N L C f,~ L ? S 7 ~ q ~ C '~ L ~ ~k L } T .,' R ~4 L3 L 3 T ~ ;: F L 3 T ;~ L S L 0 T ;~SS - S L S T C ~ S LU L3T L.I T ~ LOT :J ? S SSI LOT S52 LOT CA L l L 3T i l E ~ ~ L J T L ~ G q N g T ] A ~ l P 3 1 A ',~ ,..~ T P j W 2 ~,t S :4 T C ) S :43 q :} N :}T C o S b~ ::" (3CT:,L) ,', ~:}O:}nO 5 :i: :} '3 ]n., 0 ...O 0 ,. '..,., ...... 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Z500 '~T E'.4 - 1 ] 3.7 Z 27 14T~{ >,~ '~T = N -:~9 9.2 5'3 O ]RZ,}iN '2300 'C]qllNd,~TlOt',~ ~ :31 ~ .... SCHLUMBERGER X~ .... -_-_- ...... - LIS TAPE V~E~I:FICATIO':N :LISTIN~ ,VP OIO.H02 VERI~IC&TI3N LISTINg :~ R:E~. HE&DER ~.~'~. ,ERVICE N4ME :GCT ~ATE :85105/12 'E~L NAME :R DEPTH ,ONTINJATI3N ~ :01 'REV!O~S R:EL : iOM~ENTS :SCHL~MEERGER WELL SERVICES PROPRIETARY FIELD TAPE · ~- T~mm HE&DER ;ER¥ICE NAME :GCT i~TE :B5/05/12 IRI~IN :0000 'AP~ NA~E :145% ~ONTiNg~TI2N ~ :01 'REVIO~S TAPE 'OMMENTS :SCHLUMBERGER FILE HE&DER ¢ .... :iLE N~ME :GCT .~01 ERVICE NAME : 'ERSION ~ : ~ATE : t&XIMUM LENGTH : 1024 :ILE TYPE : ~REVIOgS FILE : :~ INFDRMATION RECORDS INEM CONTENTS UNIT TYPE C~TE SIZE CODE N : ~RCO ALASKa INC N : L~-31 N : PR~DHOE BAY/LIS~URNE ANG: 15E 'OWN: liN. EST: 22 ,OUN: N.SLOPE ~T~/: AL~SK~ TRY: US~ CONTENTS 000 000 015' 065 000 DO0 005 055 000 O00 020 065 OOO 000 003 065 000 DO0 003 065 OOg DO0 OOZ 065 000 300 007 065 000 000 006 065 000 900 003 065 dNIT TYPc ' . ~TE SIZE CgDE 065 ,VO O!O.MOZ VERImIC~TIDN LISTING PAGE 2 SCHLUMBERGER ALASKA COMPOTIN~ CENTER CDMPAN~ = AR'2 ~LASKA~ INC. WELL = FIELD = PRJ~]HOE 8AY-LiSBURNE CDJNTY = NDRTH SLOPE AL~SK~ = AL.&SK~ J.~B NUMBER AT ~CC: 71~54 RJN #34E~ D~TE L]GSED: 21-~PR-a5 L2P: RICK KRUWELL C~SIN~ : ? ~ NA - )IT SIZE : Bo5 T2 N~& &ZIMUTH O~ ~L~N~Eg VERTICAL PLANE: GYRO CONTINU3~JS T']OL [SC'T) ,V~ OIO.H02 VE~IFIC~T!~4 LISTIN3 P,~GE 3 ',~ ]EFINITI:]qS: ~ HLAZ= AZIMUTH ~-' 2EVI= OEVI4TI3N ~ ~DEP= GYR] D:PTH ~ V2EP= TRUE VErTICaL DEPTH ~SDR: NORTH DR SOJTH DEPARTURE ~' E~DR: EAST DR WEST OEP~RT~RE ~ D~L : DOG L~ (CURVATURE ~F TH:, WELL) DATA FORMAT RECORD ~ !NTRY B~OCKS TYPE SIZE R~PR C02E ENTRY 2 1 68 0 ~ ~ 73 50 ~ 4 65 .lin 15 1 66 ~ O 1 56 0 ~T~M SPECIPIC~TION BLO~SKS INEM SERVISE SERVICE ~i4IT ~PI ~Pl ~PI .~P! FILE SIZE SPL I O )EPT ;DEP LgS IDEP LOS ILAZ L3S )E~'I LOS tSDR LDS !WDR LDS tGL LOS OR 2ER # :REPR PROCESS LOG TYPE CLASS MOD NO. FT O0 000 FT:~ 99 000 F~ O0 000 DEG O0 000 D:~.~ 99 620 F~'~ O0 000 ~T O0 000 P~ O0 000 O0 0 0 4' OD 0 0 4 O0 0 0 4~ O0 0 0 4 tl 0 O 4 O0 O 0 4 O0 0 0 4 0 ~ 0 0 4 CDDE (OCTAL) 58 00000000000000 SBiO0000000000000 58 00000000000000 5800000000000000 58 00000000000000 5& 00000000000000 58 00000000000000 58 O0000OO0000~O00 65536.5000 ~DEP 0o00~00 VDEP 0.0000 HLAZ: 0.0000 .V~ OlO.H02 VERIFICATION LISTIN~ PAGE )EVI 0,0000 NSDR )EPT 65500,0000 $DEP )EVI 0.$~82 NSDR )EDT 65700.0000 GDEP )EVZ ~8.6~18 NSDR )EPT 65762.5000 GDED )E~I 34.5679 NSD~ 0.0000 EWDR 1805.8494 VDEP -11.9586 EWDR ?935.3965 VDE~ -3143.0117 EWDR 115~1-0957 VDEP -56~8,92~8 EWDR 0,0000 DGL i805,7~22 HL~Z 7.3509 DGL 6510.9)61 HL~Z -1085.5706 DGL 9509.4512 HL~Z -1967.8528 DGL 0.0000 171.5268 1.0913 197.9059 0.2651 196.2591 2.5222 ~ FILE TRAILER *~ :ILE N~ME :GCT .DOl ;ERVICE NAME : ~ERSION ~ : )ATE : ~AXIMUM LENGTH : 1024 :ILE TYPE : ~EXT FILE NAME : :=~: TAPE TRAILER ,~, ;ERVICE NAME :GCT )ATE : )RIGIN :OOO0 rAPE NAME ',ONTINU4TION # :01 ~EX1r TAPE N~ME : ~OMMENTS :SCHL~BER~ER ~ELL SER¢iCES PROPRIETARY FIELD 'TAPE ~, REEL~TRAILER ,~ ;ERVICE NAME :GCT )ATE :86/05/12 )RI~IN':. ~EEL N~ME :R DEPTH ~ONTINU~TION ~ :01 ~EXT REEL: N~ME : ~OMMENTS :SCHLUMbERgER ~ELL SERVICES PROPRIETARY FIELD T&PE q/LL/oo LIS TAPE VERIfICaTION LISTIN~ ,VP 010.H02 VERIFIC&TiON LISTIN3 PAGE 1 .' NOTE ~ ~ ~ELL SITE DATA AND TABLES ARE NOT INCLUDED IN THIS LISTING -~ ~ WAVEFORMS' AND F~ST ~:HANNEL DATA.ARE NOT INCLUDED IN THIS LISTING ~ · VP OIO.H02 VERIFICATION LISTING PAGE 2 REEL HE&DER ~'~ ;ERVICE NAME :EDIT )ATE :86103121 )RIGIN : ~EEL N&ME :14930~ ;ONTINJ&TIDN ~ :0! 'REVIO~S R:EL : ;OMMENTS :LIBRARY T~PE TAPE HEADER ~ ;ERVICE NAME :EDIT )ATE :85/03/21 ]RI~IN :FS1A 'AmE N~ME : :ONTINU&T'ION ~ :01 ~REYZOUS T~PE : :OMMENTS :LIBRARY T~PE ,,k~:-' RECDR3 TYPE 137 '~:~ FiLE HE~DER ~ :ILE N~ME :EDIT .001 ;ERVICE N~ME : tERSION ~ : )~TE : ~AXIMUM LENGTH : 1024 :ILE TYPE : ~REV'IOUS FILE : COMMENTS ~ SCHLUMBERGER ALASKA COMP~T'ING CENTER 'OMPANY = ~RCO ALASKA INC. ~ELL = LISB~RNE L3-]1 :IELD = PR'U'~HOE BAY/LISBURNE ~OUNTY =' WOR?~ SLDPE BOROUGH .VP OlO.HOZ VERIFIC~TIO~ LISTIN3 PAGE 3 !O~ NUMBER AT ACC: UN ~ONE, 2ATE LO~ ~ED: 18-~R-85 ,Om: C. WILKIE ',~SING 'YPE FLUID ~ENSITY 'ISCOSITY 'H :L~iD LOSS : 9.625" @ 47.00' - BIT SiZE : 8.5" TO 12006' : LIGND S~LT : 9.3 LBtG RM : .389 @ 65.0 DF : 35'0 S RMF : .458 @ 65.0 DF : 10.0 RMC : .T28 @ 65.0 DF : 8.1 C3 RM AT BHT = .158 @ 170 DF IAT~IX LIMESTONE SERIAL NO. 5002921544 MAIN LOG DAT~ DISPLAYED H.~S NOT BEEN SHIFTED ,' ~ ~...' ""~'~ ~' ~"~"~ ~' ~' ~ ;~ ~,,~ ~.~ ,. ~ ~ ~ ~ X: ~ .~'' ~''~ ~° ~°'~ ~' ~''°''',--,. ~..... ~. ~. ~..~ '~ ' '~ ~' .~,. o,..~ ~...~..~.. ~. ~ (c ~..~' '~""°'~ ~'"~ ~ ~- ~- ~- ~- ~-.~- ~- .... ~-' ~ ~ ~- ~~..~"" '~ ~ ~ 4c~;~' ~.u,,~ ~ ~. ~., ~ ...... ~.o. o,. ~.,.~ ~ ;::..,~ ~ SCHLUMBER?sER LOGS INCLUDED WITH 'T~JIS MAGNETIC' TAPE: .VP OIO.HOZ VERIFIC~t'IOq LISTIN~ PAGE 4 MICROLOG (EP1) OJAL LATERLOro (DLL) LONG SP~CED SONIC LO:S (LSS) LITHD DENSITY COMPENSATED LO~ (LOT) COMPENSATED NEUTRON LOG (CNL) ELECTROMagNEtIC PROPAgaTION TOOL N~TUR~L ~MM~ TOOL (NGT) G4MM4 RAY IN CASING (GR.CHL) DATA FORMAT RECORD ~NTRY BLOCKS TYPE SIZE REPR CO2E ENTRY 2 1 66 0 ~ 1 66 1' 8 3 ~ 65 .1-IN 15 1 66 O 1 66 0 DATUM SPECIFICATION BLOCKS INEM SERVICE SERVICE UNIT API API APi &PI FILE SIZE SPL REPR iD DE~T SG~ DLL LL D OLL 'LS DLL SP DLL CALS DLL 2V9~ DLL DI 0 DLL SIO DLL ORDER ~ LOG TYPE CLASS 4OD NO. CODE PRO'CESS (OCTAL) FT O0 000 O0 gl 0 4 G4PI O0 310 O1 0 0 4 O~'MM O0 220 10 0 0 ~ OHMM O0 220 og 0 0 4 MV O0 010 01' 0 '0 ~ It O0 000 O0 0 0 ~ M~ O0 000 O0 0 0 ~ U4 O0 000 O0 0 0 ~ g~ O0 000 O0 0 0 4 i 6B 00000000000000 1 5~ 00000000000000 1 68 00000000000000 1 68 000000000000:00 1 58 0000000000'0000 1 58 00000000000000 1 5~ 00000000000000 1 58 00000000000000 1 58 00000000000000 .VP OIO.H02 VERIFICATION LISTIN3 PAGE 5 ;VD DLL MV O0 000 'ENS DLL L~ O0 535 IPHI CNL P~ O0 890 ~R CNL ~PI O0 310 ~R~T CNL O0 420 ICNL ~"NL ~r~S, O0 330 :CNL CNL CPS O0 ~NR~, CNL O0 000 'E~S <,"NL LB O0 535 )PHI LgT Pg' O0 ~H35 L3T $/C3 O0 350 ;R LOT G~PI O0 310 }RrtO LDT $/C3 O0 356 >EF LDT O0 358 )LS LDT O0 000 )SS LDT O0 OOD .S · LDT CPS O0 354 .L L~T C~S O0 354 .U LDT CPS O0 35/,. .ITq LDT CPS O0 354 ~S~ LDT CPS O0 000 ;S2 LOT CPS O0 OOO :ALI LDT IN O0 280 FENS LDT L~ O0 635 ~GR N~T GAPI O0 310 ~G~ N~T. ,SAPI O0 310 ~OT4 NGT PJ O0 719 ilNi~ N~T CPS O0 310 ~2NI9 NC, T CPS O0 310 ~3NS NGT CPS O0 310 ~¢NG NGT CPS O0 310 ~5)4G NGT CPS O0 310 rHOR N,ST PPM O0 790 J~RAN N~T PPM O0 792 FENS NGT LB' O0 635 ;R EP1 GAPI O0 310 :ALI EP1 IN O0 280 FENS EPl LB O0 635 'ALI EPT IN O0 280 SA EPT iN O0 280 ~R EPT. G~PI O0 310 FENS EPT LB~ O0 635 )T LSS US/F O0 5ZO ~R LSS G~PI O0 310 )TL LSS ~S/F O0 520 ~ENS LSS LS' O0 $35 ~PHI CHL Pg O0 890 4R~T CHL O0 ~20 qCNL' CML CPS O0 330 =CNL CHL CPS O0 330 RNRA CHL O0 000 ~R CgL G~PI O0 310 ~'ENS CHL LB O0 635 O0 0 21 0 0 O 0 O1 0 O1 0 31 0 30 0 O0 0 21 0 O0 0 02 0 O1 0 O1 0 OI 0 O0 O OD 0 O1 0 O1 0 Ol 0 O1 O0 0 O0 0 01 0 21 0 01~ 0 O1 0 50 0 O1 0 O1 0 O1 0 ~01 0 01 0 50 50 0 21 0 O1 0 O1 0 21 0 01~ 0 Ol 01 0 21 0 80 0 O1 0 80 0 Zl 0 O0 0 01 0 31 30 0 O0 0 O~ 0 21 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 4 4 4 4 4 4 4 4 4 4 ¢ 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 1 $8 OOO00000000000 1 58 00000000000000 1 55 00000000000000 1 58 OOOO0000000000 1 68 00000000000000 I 58 OOOO0000000000 1 68 00000000000000 I SB 00000000000000 1 58 00000000000000 1 58 00000000000000 I 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 O00000DO000000 1 58 O0000000000OO0 1 58 00000000000000 1 68 00000000000000 1 68 0000.0000000000 I $8 00000000000000 1 68 00000000000000 I 58 00000000000000 1 68 00000000000000 I 58 00000000000000 '1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 68 O000OO00000000 I 68 OOO00000000000 1 ~,8 00000000000000 1 58 00000000000000 1 6B 00000000000000 I 58 00000000000000 1 68 00000000000000 1 68 0000'0000000000 1 68 ~00000000000000 1, 68 OOO00000000000 I ~8 00000000000000 I 68 00000000000000 1 6B 00'000000000000 1 58 00000000000000 ' 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 000000000000.00 I 6B OOOO0000000000 I: 68 00000000000000 1 68 00000000000000 1 58 00000000000000 1 68 OOOO0000000000 I 58 00000000000000 1 58 00000000000000 1 68 00000000000000 .V~ OIO.HD2 VERI;ICATIO~ LISTIN3 PAGE 6 )EPT ;P ;IO ;R tNR~ ;R )SS .ITH ;R ~R~T )EPT ~IO ~SS .ITH .~R ~tR AT )EPT ~IO }SS .ITH TENS SR SR 12021.5000 SGR -999.2500 CALS -999.2500 SVO 18.8799 NRAT 1.0~89 TENS 18.8799 DR~3 0.0508 LS .52.1367 S$1 2305.5000 SGR -999.2500 W2NG -999.2500 THD~ 18.8799 CALI 0.5520 GR -999.2500 DTL -999.2500 NCNL -999.2500 TENS 12000.0000 SGR -39.7070 CALS 492.3906 SVO 18.8799 NR~T 1.0689 TENS 18.8799 DRH2 0.0215 LS 45.2517 SS1 5323.2500 SG~ 414.1~06 W2N~ 13'9785 THOR 18.8799 CALl 0.~$201 GR 26'9580 DTL -999.2500 NCNL -~99.2500' TENS llgO0.O000 -32.4883 CALS 357'89061 SVO 24.0.361 NRAT 1.5499 TENS 24.0361 DRH3 0.005~ LS 37.2305 63~7.2500 SGR 98-1523 W2N~ 2.0237 THOR 24'0361 CALI 0.7368 23.8686 DTL' -999.2500 NCq~ -999.2.500 TENS -999.2500 -9~9.2500 -999.2500 0.9932 2395.5000 0.1997 253.9375 253.6875 -999.2500 -999.2500 -9~9.2~00 8.5020 18.8799 -999.2500 -999.2500 -9~9.2500 123.2773 2.7756 5.2273 0.9932 5323.2500 0.0977 2~3.0625 227.8125 123.2'773 152.5875 12.0098 8.2363 18.8799 ~9.5117 -9~9.2500 -9~9.2500 Z7.5049 8.8535 10.6973 1.4346 63~7.2500 0.0034 202-4375 195.8125 27.5049 1o6~95 8.9D0~ 24-0361 57.5117 -999.2500 -999.2500 LLD DVO TENS NCNL DPHI PEF LL S52 CGR W3N~ TENS TENS TENS FCNL LLD DVO TENS NCNL DPHI PEF 'LL SS2 CGR UR~N TENS TENS TENS F~NL :LLD DVO TENS NC~L DPMI PE'F LL SS2 CGR W3~ TENS TENS TENS' FCNL -999.2500 -999'2500 -999.2500 5827.2500 1.1719 4.1882 128.3125 316.3~06 -999.2500 -999.2500 -999.2500 2305.5000 2305.5000 -999.2500 -999.2500 11-2254 5.8?57 3605.5000 5827.2500 5.7129 4.2312 123.4648 ~98.6406 109.7773 78.7773 1.8145 5323.2500 5323.2500 3591.5000 -999.2500 41.9813 14.3379 5747.2500 4723.2500 4.2480 3.9~56 100.7148 259.6406 17.3.543 14.1660 1.4561 6347.2500 6347.2500 4515.2500 -999.2500 LLS DID NPHI FCNL RHDB LU CALI PDTA W4N~ TENS CA.LI DT NPHI RNR4 LLS DID NPMI FCNL RHDB QLS LU CALI PO'T~ W4NG TENS CALI DT NPHI RNR~ LLS DIO NPHI FCNL RHDB. QLS LU CA~LI POTA W4NG TENS C~LI DT' NPHI RNR~ -999.2500 -999.2500 0.9766 5551.2500 2.6877 -0.0239 251.1875 8.5020 -999.2500 -999.2500 -999.2500 8.5020 -999.2500 -999.2500 -999.2500 15.4002 465.8906 1.1230 5551.2500 2.6116 -0.0117 239.06~5 8.2363 3.9551 5.0828~ 3605.5000 8.2363 ~5.8867 '999.2500 -999.2500 ~3.3477 304-1,406 5.8594 30~5.5000 2.5370 -0.0156 203.5625 8.9004 0.6836 2.0237 5747.2500 8.9004 58.5117 -999.2500 -999.2500 .Vm OlO.H02 VERIFICATI04 LISTINS PAGE T )EPT 11800.0000 SGR ;P -34.4258 CALS' ;IO' 357.1406 sro ;R 12.6738 NR&T ~NR~ 1.6573 TENS ;R 12.6738 DRY2 )SS -0.0015 LS .ITH 39.9492 SSI rENS 6083.2500 SGR ~1~S 44,6055 W2N3 ~5N$ 3.0413 THOR DR 12.5738 CALI iA 1.0176 SR ~R 17,9111 OTL ~R~T -999,2500 NCNL DR -999,2500 TENS )EPT 11700o0000 SGR SP -29.8701 C~LS SIO 255.1406 SVO ~R 25,4111 NR.&T ~NR~ 1.3204. TENS ~R 25,~1tI DR~2 25S 0,007~ LS ~ITH 3~,5117 SS1 TE~S 6967.,2500 SGR ~ING 74,0~98 W2N~ ~SNS 2'0295 THD~ SR Z5.~lll CALI SA 1-0176 GR 3R 25.8330 DTL iRAT -999.2500 NCNL SR -999.2500: TENS ]fPT 11600.0000 SGR SP -29.8857 CALS SIO 1.37.5625 SVO .~R 16.2080 NRAT RNR4 1.4503 TENS ~R 16. 2080 ~SS 0.0063 LS LITH 37.7~05 SS1 TENS 616T.2500 SGR ~1 N~ 51. 0742 WZN ~5~G 1.0~70 THOR SR 16- 2080 SA 0-9175 GR GR 16,473~ DTL: NRAT -999.2500' NC'NL' GR -999,2500 TENS DE:PT" I1500.0000 SGR SP -29.6570 CALS SIO 293.1406. ~SVO. I?.3486 9.1270 12.0801 1.5001 6083.2500 -0.0142 211.6875 I~8.8125 17.3486 36.5117 2.3948 9.1660 12.5738 58.5117 -9~9.2500 -999.2500 25.7080 9.0254 18.3643 1.3165 6057.2~00 -0.0044 183.9375 188.4375 25.7080 35.5430 1.0714 8.9941 25'4111 51.8867 -9~9.2500 -999.2500 17.7393 9.1191 Z3.8486 1.3575 6167.2500 0.0044 137.6875 195.3125 17-7393 27.1758 1.0772 9.2832 16.2080 ]53.5117 -999.2500 -999.2500 ~5.3867 9.6816 9.9551 LLD DVO TENS NCNL DP~I PEF LL SS2- CGR W3NS URAN TENS TENS TENS FC~L LL~ DVO TENS NCNL DPHI PEF LL SS2 CGR W3NG UR~N TENS TENS TE~S FCNL LLD DVO TENS NC~L DPNI PEF LL SS2 CGR W3NG U'RAN TENS TENS TENS FCNL L L D D V 0 TENS 68.0043 18.8643 5643.2500 5131.2500 6.9824 4.0710 105.4648 254.5625 17.4736 11,1504 -0.0386 6083.2500 6083.2500 4507.2500 -999,2500 97.6243. 21.0986 5687.2500 6531.2500 0.9277 4.8328 90'8398 2~5.9375 9.6816 10,1504 2.0881 6067.2500 6057.2500 -999.2500 314.8805 31,3~86 5395.2500 5639.2500 3.1738 3.9495 99-1523 257.6406 10.7285 9.7832 1.2051 6167.2500 615'7.2500 4357,2500~ -999,2500 62.7078 18.2236 5467.2500 LLS DtO NPHI FCNL RHO) QLS LU CALI POTA W4N$ TENS C~LI DT NPHI RNR~ LLS 010 NPHI FCNL RHOB QLS LU CALl POT~ W4NG TENS CALi DT NPHI RNR~ LLS DIO NPHI FCNL RHOB QLS LU CALI POTA W4NG TENS C~LI DT NPHI RNR& LLS DID NPMI 49.0521 246.9375 6.5430 3095.5000 2.5901 -0.0220 212.3125 9.1660 0.4883 2.0276 5543.2500 9.1660 58.6367 -999.2500 -999.2500 103.9764 192.4375 4.0039 49~7.2500 2.5936 -0.0054 186.0625 8,9941 0,3418 4.0593 :5687.2500 8,9941 53.1367 -999.2500 -999.2500 251.3495 88.5523 4.2480 3885.5000 2.6545 0.0049 197.0625 9.2832 0.3906 3.260'0 5395.2500 9.2832 54,0117 -999,2500 -999.2500 ~9.2623 258.6406 6.8359 .VP OlO.H02 VERIFICATIO,N LISTINg PAGE ;R ;R }SS .ITH 'ENS ;1NS ;R ~R JRt1' )EPT ;P ;R ~NRA .ITH ;A ~R tR AT )EPT ;IO ;R ~NRA }SS .ITH TENS ~IN~ t5N5 ;R ;R ;R )EPT ;P ~t0 ~NRA ;R 35.1055 NR~T 1.6583 TENS 36.1D55 DRM3 -0.0D49 LS 38.9805 SS1 6215.2500 SGR 155.3125 W2N3 2.0295 THO~ 36.1055 CALI 1.0206 GR. 33,1367 DTL -999.2500 NCNL -999.2500 TENS 11400.0000 -23.9?95 315.6~06 17.0205 1.6895 17.0205 0.0171 46,3555 5983.2500 63.9180 1.0831 17.0205 0.9175 18.4580 -999,2500 -999,2500 11300.0000 -31-4539 132.4375 38.~180 2.3713 38.4180 0'0083 60.7S17 5975.2500 116.1523 0.0000 38.,4180 0.8833 34,6055 -999,2500 -999,2500 11200.0000 7.9382 675.3125 64.8398 3.7874 64.8398 SGR CALS SVO NR&T TENS DRHD LS SS1 SGR W2N3 THO~ CALI GN DTL NCNL TENS SGR CALS NRaT TENS DRHD LS SS1, SGR W2N3 THOR CALl SR OTL~ NCNL TENS SGR CALS SVO NRAY TENS DRMD . 6215. -0. 198. 189. 65. 2. 9. 58. -999. -999, 19. 9. 11. 1. 5983. O. 221. 2O4. 19. 39- 1. 9. 17. 63. -999. -999. 33. 11. 26. 2. 5975. ' 0 ' 30'4. 203. 33. ~0. -0. 11. 38. 69. -999. -999. 3. 5867. ~0. 5616 2500 0073 1875 5625 3867 9648 3186 6582 1055 0117 2500 2500 7705 1504 3770 5753 2500 0151 1875 5625 7705 0117 3946 0801 0205 25'1.? 2500 2500 2305 3848 8174 2053 2500 0068 ~06 8125 230'5 3867 7822 1895 4180 6523 2500 2500 4648 5723 5176 2522 2500 0054 NCNL DPMI PEF LL SS2 CGR W3NG URAN TENS TENS TENS FCNL LLD DV3 TENS NCNL DPNI PEF LL SS2 CGR W3NG URAN TE~S TENS TENS FC~L LLD OVO T E'NS NCNL DPHI PEF LL SS2 CG.~ W 3 N G UR~N TENS TENS TENS FCNL LLD TENS NCNL DPHI PEF 4¢75.2500 3.9062 3.6995 98.7148 254.1875 16.7861 16.2393 4.9148 6215.2500 6215.2500 4395.2500 -999.2500 53.8672 15.8848 5547.2500 ~675. 2500 6.7383 3.1317 111.1523 269.6~06 15.7'363 13.0D20 0.5786 5983.2500 598.3-2500 4343.2500 -999.2500 45.5.8185 36.1055 5~51.2500 3271.50001 19.8242 4,6257 159,9375 283.6406 -2.8025 15,1504 4o7~68 5975.2500 5975,2500 %215.2500 -999,2500 4..0S48 2.3088 5195.2500 1157.6~75 47-8027 3.3147 FCNL RMOB QLS LU' CALl POTA W4N~ TENS CALl DT NPHI RNR~ LLS DIO NPMI FCNL RHD8 QLS LU CALI POTA W4NS TENS C~LI DT NPHI RNR~ LLS 010' NPHI FCNL RHDB QLS LU CALl POT~ W4N~ TENS C AL I DT] NPHI RNRA LLS DID NPH I FCN L RHOB QLS 2697.5000 -0.0083 198.9375 9.6582 0.4883 7.1062 5467.2500 9.6582 59.5117 -999.2500 -999.2500 52.2688 252.6~06 7.7637 2765.5000 2.5940 -0,0151 219.9375 9-0801 0.6348 1.0831 '55~7.2500 g. O801 63.3867 -999o~500 -999.~500 293.5739 70,5273 14,9414 1379.6875 2,3694 0,0034 289.1406 11.1895 0..0000 6'0593 5~51.25:00 11.1895~ 59,5273 -999,2500 -999.2500 3.2592 505.8906 39.5020 305.5406 1.8917 -0.0~49 .VP OlO.H02 VERIFIC&TIO~ LI.STIN~ PAGE 9 )SS .ITq 'ENS llNS ;R ;A ;R tR&T ;R ;IO ;R ~NR~ ;R ISS .iTH tENS 4RAT ;R )EPT ;P ;I0 ;R ~NRA )SS .ITH 'ENS ;R ;R ~R~T ;R )EPT ;P ;R ;R )SS .IT~ -0.0020 LS 167.8125 SSI 5~67.2500 SGR 216.1B75 WZNS 6.0593 THOR 64.8398 CALl 3.4065 GR 72.2773 DTL 3.5569 NCNL 38.8242 TENS 11100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -g99.2500 -999.2500 4.0125 53.8555 11000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -~99,Z500 -999.2500 -999.2.500 -999'2500 3.0022 48,1055 lOgO0.O000 -999,2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -ggg.2500 -ggg.2500 CALS SVO NRAT TENS OR,D LS SGR W2N$ THOR CALl GR DTL NCNL TE~S SGR CALS SVO NRAT TENS DRY3 LS SSl SGR THOR CALI GR DTL NCNL TENS SGR CALS sro NRAT TENS DR~O LS SS1 SGR 709.3125 231.3125 75.¢648 11!,0898 5,3875 9.8535 64,8398 125.7773 1265.6875 55~5.2500 -999.2500 -999,2500 -999.2500 -9)9,2500 -9~9,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 1363-6875 5491.2500 -999-2500 -999-2500 -999,2500 -939,2500 -999,2500 -9~9,2500 -999,250'0 -9~9,2500 -9)9,2500 -9~9,2500 '-999- 2500 -999. 2500 -999. 2500 -9~9. 2500 1819'6875 54~7.2500 -999.2500 -999,2500 -9~9.2500 -999.250'0 -999.2500 -939'2500 -999.2500 -939.2500 -939.2500 LL SS2 CGR W3N~ URAN TENS TENS TENS FCNL LLg DVO TENS NCNL DPHI, PE~ LL SS2 CGR W3NG UR~N TE~S TE~S TENS FCNL LLD TENS NC~L DP~I PEF LL' SS2 CGR W34G UR~N TENS' TENS TENS:. LLD DVO~ TENS NCNL DP~I. LL SS2 CGR 380,3906 356,8906 44.2617 42,4180 4,0671 5867,2500 5867.2500 4195. 2500 324.6406 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -~99,2500 -999.2500 -999,2~00 -999.2500 -999.2500 -999-2500 -999.2500 -999,2500 -999,250.0 324.6406 -999,2500 -999-2.500 -999,2500 -999, 2500 -999,2500 -999,2500 -999.2500 -999,2500 -9~9,2~00 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 501,8906 -999.2500 -999,2500 -999,2500 -999,2500 -9~9.2500 -999,2500 -999,2500 -999,2500 -999,2500 LU CALi POTa ~4NS TENS CALI DT NPHI RNR~ LLS DIO NPHI FCNL RHDB QLS LU CALt PDTA W44G TENS CALI DT NP~I RNR~ LLS DIO NPHI FCNL RHDB QLS LU CALI POTA W4NS TENS CALI DT' NPHI RNR~ LLS DtO NPHI FCNL RHOB QLS LU CALI POT~ 657.8125 9.8535 1.4648 10,0957 5195.2500 9.8535 83.7773 39,2578 3.8967 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 47,5586 4.2000 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29.1504 3.6252 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 .VP 010.H02 VERIFIC~TIDN LISTIN~ PAGE ~iNS ;R ;R JR~T ;R )EPT ~P ~IO ;R ~NR~ ;R DSS .IT9 tENS ;R ;R 4R~T ;R )EPT SP ~IO ~NR~ )R ,IT~ ~iNG ~R 2R DEPT SP SI 0 GR RNR~ GR QSS LITH TENS W1 N G WENG -999..2500 W2NS -999,2500 THDR -999,2500 CALI -999,2500 GR -999.2500 DTL; 3.1582 NCNL 36.3:167 TENS IOBO0,O000 SGR -999,2500 CALS -999,2500 SVO -999,2500 NR~T -999,2500' TENS -999.2500 DRH3 -999.2500 LS -999.2500 SS1 -999.2500 S~R -999.2500 W2~ -999.2500 THDR -999.2~00 CALI -999.2500. GR -999.2500 DTL 3.0276 NCNL 17.557~ TEN~ 10700.0000 SGR -999'2500 CALS -999.2500 SVO -999.2500 NRAT -999.2500 TENS -999,2500 DRH3 -999,2500 LS -999,2500 SS1 -999.2500 SGR -999.2500 WZN~ -999'2500 THDR -999,2500 CAL[ -999,2500 GR -999.2500 DTL 2.758! NCNL 17.9736 TENS I0~00.0000 -999.2500 -999.2500 -999.2500 -ggg.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2~00 SGR CALS SVO NR~T TENS LS SS! SGR W2NS THO~ CALI -999.2~00 -g~9,2500 -999.2500 -999,2500 -999.2500 15~1.6875 5375.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -g~g.2500 -9~9.2500 -9~9.2500 -9~9.2500 -9~9.2500 -9~9.2500 -999,2500 1609.6875 5335.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999,2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.~500 15~0.6575 5251-2500 -999o2500 -9~9.2500 -999.2500 -9~9.2500 -9~9.2500 -999.2500 -9~9.2500 -999.2500 -9~9.2500 -9~9.2500 -999.2500 -999.2500 TENS TENS TENS FCNL LLD DV3 TENS NCNL DPHI PEF LL SS2 CGR W3NG TENS TE4S TENS FCNL LLD DV'O TENS NCNL DPHI PEF LL SS2 C.GR W3N$ URAN TENS TENS ~CNL LLD DVO TENS NCNL DPflI PEF LL SS2' CGR W3NS URAN TE~S -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 486,8905 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 535.8125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 520.3[25 -999-2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9,2500 -999.2500 -999.2~00 TENS CALZ DT NPgI RNRa LLS DIO NP9I FCNL RHDB QLS LU CALI W4NS TENS CALI DT NPMI RNRA LLS DIO NPH I FCNL RHDB QLS LU C~LI PDT~ TENS CALI DT NPHI 'RN.R ~ LLS DID NPHI FCNL RHDB QLS LD CALI POT~ W 4 N 5 TENS CALI -999.2500 -999,2500 -999.2500 -999,2500 32,1777 3.1643 -999.2500 -999.2500 -~99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29.5898 2.9983 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999,2500 -999.250'0 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 24.6582 3.0002 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999-2500 -999.2500 .VP OlO.H02 VERIFICATION LISTINS PASE 11 ;R IR~T ;R )EPT ;P ;IO ;R tN.~& ;R )SS .II'H 'ENS ;R ;A ;R 4RAT )EmT ;P )NRA ;R )SS .ITH 'ENS ~ENG ;R ;R )EPT ;P ;R ~NR~ )SS .ITq FENS 41 NS ~R ~R ~RAT -399.2~00 GR -999.2500 DTL 1.9561 NCNL 21'8&86 TENS 1O5O0.OO00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250.0 -999.2~00 -999.2500 -999.2500 2,9944 32.1580 10~00.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2:500 -999-2500 -999-2500 -999-2500 -999.2500 -999.2500 -999.2500 4-9968 65.2773 10300.0000 -999.2500 -999.25010 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4-3875 SGR C~LS SVO NR~T TENS DRY3 LS SS1 SGR W2N$ THD~ CACI GR DTL NCNL TENS SGR CALS SVO NRA T TENS DRHD LS SS1 SGR WZN2 THOR CALI GR DTL NCNL TENS SGR C AL S SVO NR ~ T TENS DR~q j LS S S ! SGR WZN$ THOR CALI GR DTL NCNk.~ -9)9.2500 -999.2500 2093.5000 5227.2500 -9~9.2500 -999.2500 -9)9.2500 -999.2500 -999-2500 -999.2500 -999.25-00 -9)9.2500 -999.2500 -999.25'00 -9)9.2500 -999.2500 -999.2500 1630.6B75 5135.2500 -999.2500 -9~9.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 ,-999.2500 -9)9.2500 1115.6875 5083.2~00 -999.2500 -9)9o2500 -999.2500 -9)9.2~00 -9)9o2500 -9~9o2500 -999.2500 -9)9.2500 -999.250,0 -999.2500 -999,2500 -999.2500 -9~9.2500 -999.2500 1214.6875 TENS TENS FC~L LLD DVO TENS NCWL DPHI PEF LL SS2 CGR W3~ URAN TENS TENS TENS FCNL LLD DVO TENS NCNL DPHI PEF LL SS2 CGR. W3NG ORaN TENS TENS TENS FCNL LL2 OVO~ TENS NCNL DPHI PEF LL~ SS2 CGR W3NG URAN TENS T'E~S TENS FCNL -999.2500 DT -999.2500 NPHI 1046.6875 RNRA -999.2500 -999.2500 -999.2500 -999.2500 -939.2500 -999'2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 521.3125 -939.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 210.0525 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 259.1~06 LLS DIO NPHI FCNL RHOB QLS LU CALI POT4 W4NG TENS CALI DT NPHI RNR~ LLS OIO NP~I FCNL RHOB QLS LU CALI POTA W4NS TENS C4LI DT NPHI RNR4 LLS DIO NPHI FCNL RHOB QLS LU CALl POTA W4N2 TENS CALI DT N~HI RNRA -999.2500 12.5000 2.0002 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29.0039 3.1272 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999-~500 -999.Z500 $5.4755 5.3093 -999.2500 -999.2500 -999-2500 -999'2500 -999.2500 -999.2500 -9~9.2500 -999.2~00 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 54.3945 4.6843 .Vm OlO.H02 VERIFICATION L!STINS PAGE 12 ;R )EPT ~IO ~R ~ S S .IT~ tENS ~IN$ qR&T )EPT 5P 2NR~ ~SS .ITH 5A iR qR~T ~,R )EP?: SIO ~R 2NR~ LITH TE NS W1NG WSNF~. SR SA GR NR~T 55.2~30 TENS 10200.0000 S3~ -999,2500 CALS -999.2500 SVO -999.2500 NR~T -999.2500 TE{S -999,2500 DRH3 -999,2500 LS -999,2500 SS1 -999.2500 SGR -999.2500 W2NS -999.2500 THDR -999,2500 C~LI -999,2500 GR -999,2500 DTL 3.9827 NCNL 93.0273 TENS 10100.0000 SGR -999,2500 CALS -999,2500 SVO -999.2500 NR~T -999.2500 TE~S -999.2500 DRHD -999.2500 LS -999.2500 SS1 -999o2500' SGR -999,2500 W2N2 -999.2500 THDR -999.2500 CALI -999.2500 GR -999.250.0 DTL ~,0906 NCNL 50.3555~ TENS 10000.0000 SG~ -999,2500 CALS -999.25001 SVO -999,2500 NR~T -999.2500 TENS -999.25001 DRH~ -999.2500 LS -999.2500 SSi1 -999.2500 SGR -999.2500~ W2N~ -999.2500 'THOR -999,2500 CALI -999,2500 GR -999.2500 DTL 3-8659 NCNL~ 64,6523 TENS' 4987.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,~500 -999.2500 -999,2500 -999,2500 1171.6875 4907.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -9~9,2500 -999,2500 -999,2500 -999'2500 -999,2500 -999,2500 1235-6875 ~891.-2500 -999,2500 -999.2500 -999.2500 -999,2500 -9~9,2500 -999-2500 -9~)9.2500 -999-2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 1202'6875 4,7~,3. 2500 LLD TENS NCNL DPqI PEF LL S52 CGR. W3NG URAN TENS' TENS TENS F~NL LLD DVD TENS NCNL DPHI PEF LL SS2 CGR. URAN TEYS TENS TENS FCNL LLD DVO TENS NCNL DP~I PEF LL SS2 CGR W3Ng URAN TENS TENS TENS FCNL -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 267.8906 -999,2500 -999.2~00 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 283.8906 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2 500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999, 2500 283,8906 LLS DIO NPHI FCNL RHOB QLS LU CALI W~N$ TENS CALI DT NPHI. RNRA LLS DIO NPHI FCNL QLS L D~ CALI POT A W4NG TENS CILI DT NPHI RNR& LLS DIO NPflI FCNL QLS LU CALI POT& TENS CAL'I D'T NPHI RN~A -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 67.0215 4.3718 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 68.9746 4,3523 -999,2500' -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.~500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 64,5313 4,2351 DEPT 9900.0000 SGR 999.2500 LLD -999.2500 LLS -999.2500 .Vm OlO.W02 VERIFICATID~ LISTINS PAGE 13 ;R ~NR~ ;R ISS .ITH 'ENS t.1 NS ;R ~R ~R )EP T ~R ~SS ~R ~R~T )EPT SP )IO SR SR 2SS ~ITH fENS ~ING 45NG S~ SR ~R ~ T DEPT SP SIO -999.2500 CALS -999.2500 Sro -999.2500 NR~T -999.2500 TENS -999.2500 DRH~ -999.2500 LS -999.2500 SS1 -999.2500 SGR -999.2500 W2N~ -~99.2500 THOR -999.2500 C~Lt -999.2500 ~R -999.2500 DTL 4.9~68 NC~ 50.1680 TENS 9800.0000 SGR -999.2500 CALS -999.2500 SVO -999.2500 NR~T -999.2500 TENS -999.2500 -999.2500 LS -999.2~00 -999~2500 SGR -999.2500 W2NS -999.2500 THOR -999.2500 CALI -999.2500 GR -999,2500 DTL 4-~¢21 NCNL 64.9023 TENS 9'?00,0000 SGR -999.2500 CALS -999.2500 SVO -999.250:0 NR~T. -999.2500 TENS -999.2500 DRq~ -999,2500 LS -999.2500 SS! -999-2500 SGR -999.2500 WZN~ -999.2500 THOR -999.2500 C~LI -999,2~00 -999.2500 4-7078 NCNL 56.6~80 TENS 9500,0000 SSR -999,2500 CALS -999.2500 SVO -999.2500~ NR~T' -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -9~9o2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1097.6875 4735.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -939.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -9~9o2500 1133,6875 4695.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -999.25001 -999. Z500 -9~9.2500 -999.2500 1200.6875 4651.2500 '-999.Z500 -999.2500 -939.2500 -999.2500 DVO TENS NCNL DPHI PEm LL. SS2 CGR UR~ TENS TENS TENS FCNL LLD DVO TENS NC~L DPHI PEF LL SS2 CGR W3NG URAN TENS TENS TENS FCNL LLD DVO TENS NC~L LL SS2 CGR W3NG UR~N TENS TE~S TENS FCNL LLD OVO TENS NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999o2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 216.1~75 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 266.6~06 -999.2500 -999.2500 -999.25OO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -9~9.2500 -999.2500 233.3125 -999.2500 -999.2500 -999.2500 -999.2500 DIO NPMI FCNL RHDB QLS LU CALI POTA W4N$ TENS CALI DT. NPMI RNR~ LLS DIO NPHI FCNL RHOB QLS LU CALl POTA TENS CALt DT NPHI RNRA LLS DIO NP~I FCNL RHOB QLS LU CALI POTA W4N3 TENS CALI DT NPHI RNRA LLS NPHI FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 65.4?$5 5.0750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 55.3711 4.2507 -999.2500 -999.Z500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999-2500 -999.2500 60'2051 5.1~53 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICNT!g~ LISTIN~ PAGE ;R .ITq ;R ;R ,{RAT ;R )EPT ;P ;IO ;R ~NRA ;R )SS .ITH rENS W1NG ;R ;A ;R ~R )EPT ;P ~IO ;R ~NRA. ;R )SS .ITH rE~S iR 4R~T ~R ]EPT SP ~R OSS -999.2500 TENS -ggg.2500 DRM2 -999.2500 LS -999.2500 SS1 -999.2500 SGR -999-2500 W2N~ -999.2500 THDR -999.2500 CALI -999.2500 GR -999.2500 ~TL 4o2~68 NCNL 117.8398 TENS 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999-2500 -999-2500 -9gg.z500 -999.2500 -999,2500 ~.1531 39'32¢2 9~00,0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ¢°1335 ¢~.6367 9300.0000 -999-2500 -999-2500 -999.2500 -ggg.2500 -999.2500 -999.2500 SGR CALS SVO NRAT. TENS ORM3 LS SS1 SGR W2N~ THOR CNLI GR DTL NCNL TENS CALS S¥0 NRAT, TENS DR~ LS SGR W2~ THOR CALI DTL NC:~L TENS SGR CALS SVO NRAT TENS DRHD LS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~g.2500 -999.2500 -999.2500 -999.2500 1200.6B75 4623.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -9~9.2500 -9~9.2500 -9~9.2500 -9~9.2500 -9~9,2~00 -9~9.2500 -999. Z500 -999.2500 -999°2500 1150.6875 46~3.2500 -999,-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 -999.2500 1183-6875 4591.2500 -999.25'00 '-999.2500 -999.2500 -999.2500 '-9~9.2500 -939.2500 -999.2500 DPHI PEF LL SS2 CGR W3N2 URAN TENS TENS TENS FCNL LLD TENS NCNL OP9I PEF LL SS2 CGR W3NG URAN TEN~ TENS TENS FCNL LLD DVO TEqS' NCNL DPHI PEF LL SS2 CGR W3N$ UR~N T~NS TENS TENS' FCN~L LLD TENS NCNL DPHI PEF LL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 283.3906 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999.2,500 -999.2500 -ggg.2sO0 250.0625 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -9'99,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 266.6~06 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999'2500 RHDB QLS CNLI POTA Wq.N~ TENS CALl DT NPHI RNR4 LLS OlO NPHI FCNL RHDB QLS LU CALI Wq.N$ TENS CALl DT NPHI RNRA LLS OlO NPHI RHDB QLS L~? CALI TENS CALI O? NPHI RNR.& LLS DIO NPHI FCNL RHOB QLS LU -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 51.8066 4.2351 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -99'9.2500 -999-2500 50.0977 4.598~ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 ~9.7559 ~.~382 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 .V~ OIO.HOZ VERiFICaTION LISTINS P4GE 15 .ITM -999,2500 SS1 -939, 'ENS -999,2500 SGR -939, tiNS -999.2500 W2NS -999. ~SNG -399. 2500 THOR -999, ;R -999.2500 CALI -999. ~A -999.2500~ GR -999. ;R -999.2500 DTL -999. 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NPHI RNRA -999.2500 ¢2.2852 4.5906 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~4.2871 4.1570 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999-2500 '-999.2500 -999.2500 -999.2500 ~9.2576 5.0671 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 52.5391 4.6453 .VP 010.H02 VERZFIC~TIgN LISTIN$ PAGE 29 ;R )EPT ;P ;ID ;R )SS .ITH 'EqS ~ENS ;R ;A ;R ~R~T ;R )EPT ;P ~N R.A )SS' .iTH 'ENS 11N3 15NG ;R IR~T ;R )EPT ;P ;R ~NR~ ;R .ITH tENS ~ING ;R ;R JR&T ;R 36.5117 TENS 4800.0000 SGR -999.2500 CALS -999,2500 SVO -999.2500 NR&T -999.2500 TENS -999,2500 DRH2 -999.2500 LS -999.2500 -999.2500 SGR -999,2500 W2N~ -999.2500 THOR -999,2500 CALI -999,2500 GR -999,2500 DTL 3.9377 NCNL 3~.57~2 TENS ~700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999-2500 3.9~56 ¢6.8555 4600'0000 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2S00 3.91~3 ~-6055 SGR CALS SVO TENS DRM2 LS SS1 SGR WZNS THOR CALI GR .DTL NCNL TENS SGR CALS SrO N R ~k T O R q 3 LS SS1 SGR W2N2 'THO R CALI GR DTL NCNL TE~S 3005.5000 -999.2500 -999.2500 -999.2500 -999.2~00 -999. 2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 1257.6875 2961,5000 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999,2500 1179'6875 2965,5000 -9~9.2500 -939.25'00 -999,2500 -999°2500 -999,2500 -9~9.2500 -999.2500 -999.2500 -999,2500 -9)9.2500 -999.2500 -9~9.2500 -9~9.2500 -999-2500 1201.6875 2855-5000 LLD DVD TENS NC~'L DPHI PEF LL SS2 CGR W3NG TENS TENS TENS FCNL LLD DVO TENS NCNL DPHI PEF LL SS2 CGR W3N$ UR~N TENS TENS TENS FCNL LLD OVO TE~S NC~L OPMI PEF LL SS2 CGR W3NG 'UR:AN TENS 'TENS TENS FC~L -999.2500 LLS -999.2500 -999.2500 NPHI -999.2500 FCNL -999.2500 RHDB -999.2500 QLS -999.2500 LU -999.2500 CALl -999.2500 POTA -9~9o2500 W4N~ -999.2500 TENS -999,2500 CALI -999,2500 DT -999.2500 NPHI 345.6406 RNR~ -999.2500 LLS -999.2500 -999,2500 NPHI -999.2500 FCNL -999.2500 RHDB -999.2500 QLS -999.2500 LU -999.2500 CALI -999,2~00 POTA -999.2500 W'4N~ -9'99.2~00 TENS -999.2500 CALI -999.2~00 DT -999.2~00 NPHI 302.8906 RNRA -999.2500 LLS -999.2.500 DIO -999.2500 NPHI -999,2500 FCNL -999,2500 RHOB -999.2.500 QLS -999.2500' LU -999.2500 CALI -999.2500 POTA -999.2500 W4NG -999'2500 TENS -999.2500 CALI -999.2500 DT -999.2500 NPHI 312.8906 RNR~ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 46.1914 3.6663 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2~00 -999.2500 46.3379 3.8928 -999.2500 -99'9.2500 -999.2'500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 45,7520 3.8~01 )E~T ~500.0000 SGR -999.2500 LLD -999.2500 LLS -999.25:00 .VD OlO.H02 VE~!FICATID~ LI$TIN~ PAGE 30 ,P ~R ',NRa ;R ~SS .ITH 'ENS ;R ;A IRAT ;R )EPT ~P ,IO ;R ~R )SS ,ITH 'ENS ~R ,R iRAT ,R ~EPT P IO ~R NRA ,ITfl 'ENS I1N~ 15Nr~ ~R ~R IRAT ~R ~EPT. -999.2500 CALS -999.2500 SVO -999.2500 NRAT -999.2500 TENS -999.2500 DRH3 -999.2500 LS -999.2500 SS1 -999.2500 SGR -999.2500 W2N~ -999.2500 THOR -999.2500 CALI -999.2500 GR -999.2500 DTL 4.250? NCNL 40.0?42 TENS ~¢00.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 30'1924 ~300.0000 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2~00 -999,2500 3.9163 25.2080 4200.0000 -999.2500 -999.2500 -999.2500 SGR CALS SVO NRAT TENS DRH2 LS SS! SGR THD~ CALI DTL NCNL TENS SGR SV'O NRAT TENS DRHD LS' SS! SGR WZNG THOR CALI GR DTL NCNL TENS SGR CALS SVO: NRAT -999. -999. -999. -999. -9~9. -999. -9~9. -9~9. -9~9. -999. -9~9. -999. -999. 3.174. 2795. -999. -999. -999. -999. -9~9. -999. -9)9o -999. -9)9. -999- -999. -999. -999. -999. 1166' 2715. -9~9. -9~9. -999. -999. -999. -999. -999. -999. -999. -999. -999. '-9~9. -9~9. -9~9. 1234' 2611. -999. -999. -9~9. -9)9. 2500 250O 2500 250O 2500 2500 2500 25O0 2500 250O 2500 2500 2500 5000 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 6875 5000 2500 2S00 25O0 2500 250'0 2500 25,00 2500 2500 2500 2500 2500 2500 2500 6875 5000 2500 2500 2500 2500 OVO TENS NCNL DPHI PEF LL SS2 CGR W3NJ URAN TE~S TE~S TENS FCNL LLD D¥O TEYS NCNL. OPflI PEF LL SS2 CGR W3N2 URAN TENS TENS TENS FCNL LLD OVO TENS NCNL-~ OPHI PEF LL SS2 CGR W3NG URAN TENS TENS TENS ~CNL LLD D. 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O0 000 O0 O 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 ENTRY 0 1 5 .lIN 1 0 SIZE SPL REPR CODE 4 I 68 ~ I 68 4 i 58 4 1 68 4 1 4 I PROCESS (OCTAL) 00000000000000 O00000OO000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 12021,95701 HTEN -999.2500 MTEN' 12000,2910 HTEN -162.6875 HTEN 11900,2g10 ~T'E~ 996'8125 HTE~. 11800'2~I0 HTE~ 999,3125 HTEN 11700-2910 HTEN 991,8125 HTEN 11600o2910 HTE~ 973.8125 HTEN 11500o2910~ HTEN ~93,8125 HTE~ 11¢00,2910 HTEN 1005.3125 HTEN 11300,2910 HTEN 1052o6'875 HTEN 11200.2910 HTEN -999.2500 -1~1.3125 -152.6875 822.3125 996.8125 1425,6875 9~9-3125 1342.5875 991.8125 1283.6875 973.8125 13~?o6875 993.8125 1354.6875 1005o3125 1313.6875 1052.6875 1317.6875 1000o3125 HTEN HTE N HT EN HTEN HTEN HTEN HTE~ HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN - 1 ~, 1. -141. 822- 822, 1425o 1425, 1342. 1342. 1283. 1283. I347. 13~7. 1354. 1354. 1313.. 1313. 1317. 1317. 1 307. 3125 3125 3125 3125 6875 6875 6875 6875 6875 6875 6875 6875 6875 6875 6875 6875 6375 6875 HTEN HTEN HTEN HTE ~ HTEN. HTEN HTEN HTE N HTEN HTEN -1~1.3125 822.3125 1425,6875 13~2.6875 1283.6875 1347.6875 1354.6875 1313.6875 1317-6875 1307,6875 .V: OlO.H02 VERIFICATION LISTIN~ PAGE 35 tTEN 1000'3125 HTEN IEPT 11175.0410 HTEN ITEN 956.8125 HTEN FILE TRAILER ~ :ILE NAME :EDIT .003 ;ERVICE N4ME : ~ERSION ~ : ~ATE : iAXIMUM LENGTH : 1024 :ILE TYPE : IEXT FILE NAME : FILE HEADER ~* :ILE NAME :EDIT .004 ;ERVICE NAME : 'ERSION ~ : ~ATE : tAXIMUM LENGTH : 1024 :ILE TYPE : 'REVIDUS FILE : 1307.6875 HTEN 956.8125 HTEN -999.2500 HTE~ RECORD TYPE 137 ¢¢ 1307.6875 -999.2500 -999.2500 HTE~ -999.2500 DATA FORMAT RECORD !NTRY BLOCKS TYPE SIZE REPR CODE 2' I 66 ~ 1 66 8 4 73 g 4 65 16 I 66 O: I 66 ~ATUM SPECIFICATION BLOCKS INEM SERVICE SERVICE U~IT ID ORDER ~ ~EPT FT': ITEN CHL LB DATA iEPT 11211.9570 HTEN IEPT 11200.2910 HTE~ tEPT 11100.2910 HTEN. IEP:T 11000.2910 HTEN API LOG O0 API AP1 API FILE TYPE CLASS MOD NO. 000 O0 0 0 000 O0 0 0 I!4t.68T5 1177.6575 1098.6875 1073.6875 ENTRY 0 1 5 .liN 1 0 SIZE SPL REPR CODE t 68 1 5B PROCESS (OCTAL) OOOO0000000000 00000000000000 .VP OlO.H02 VERIFICATION LISTIN~ P~GE 36 )EPT 10900.2910 )EPT 10~00,2910 )EPT 10700,2910 )EPT. 10600,2910 )EPT 10500.2910 )EPT 10~00.2910 )EPT 10300,2~10 DEPT 10200,2910 DEPT 10100,2910 DEPT 10000,2910 ]EPT 9900.2910 )EPT 9B00o2910 ]EPT 9700.2910 }EPT 9500,2910 ]EPT 9500,2910 ]EPT '9~+00,2910 2EP? 9300.2910 ]EPT 9200.2}10 3EPT 9100,2910 ]EPT 9000,2910 2E PT 8900. 2910 ]EPT 8800,2910 3EPT BT00,2910 ]E~T 8600,2910 }EPT 8500.2910 ]EPT 8400,2910 ]EPT 8300,2910 HTEN HTE~ HTEN 4TE~ HTEN HTEW HTE~ HTE~ HTE~ HTEN HTEN HTEN HTE~ HTEN HTE~ HTEN HTEN HTEN HTEN HTEN HTEN HTE~ HTEN HTE~ HTEN HTEN HTE~ 1072,6875 1075.5875 1059,68?5 1054,6875 1057,6875 1058.6B75 1053.6875 1019.8125 1017.3125 988.8125 991.3125 974,8125 981.3125 972.3125 991.3125 996.8125 983.3125 1003.8125 1014.3125 936,8125 971,3125 991.3125 9~9,8125 974.3125 958,8125 973-3125 977.8125 .VD OlO.H02 VERIFICATION LiSTIN3 PAGE 37 8200.2910 HTEN 8100.2910 HTE~ 3000.2910 HTEN ,'900.2910 HTE~ 7800.2910 HTEN 7700.2910 HTEN T$00.2910 HTEN 7500.2910 HTEN 7~00.2910 HTEN 7300.2910 HTEN 7200.2910 HTEN 7100. Z910 HTE~ 7000.2910 HTEN 6900.2910 HTE~ 6800.2910 HTEN 6700,2910 HTENI 6600.2910 .HTEN 6500.2:)10 rtTE'~t 6~00,2910 HTEN 6300,2910 HTEN 62.00,29101 HTEN 6:!.00,2910 HTEN 6000,2910 NTEN 5900.2910 HTEN 5800.2910 HTEN 5700.2910 HTEN 5600o2910 HTE,N 956.8125 952.3125 959.3125 978.3125 941.3125 988.8125 957.8125 1094.3125 958.8125 983.8125 970,3125 995.3,125 997o3125 997.3125 1009,3125 1003.8125 973.3125 9~2.8125 993.,8125 976.8125 978.8125 1017.8125 99T.8125 9~1,3125 1005.3125 1000.8125 959.3125 .V~ OlO.H02 VERIFICMTIO~ LISTIN~ PIGE )EFT 5500.2g10 HTE4 )E~T 5~00.2g10 HTEN )EPT 5300.2910 HTEN )E~T 5200.2910 HTE~ )EFT 5100.2910 HTEN )EmT 5000o2910 MTEN )EmT 4900.2910 HTE~ )E~T 4800.2910 HTEN )EmT 4700o2910 HTE~ )E~T 4500.2910 HTE4 )E~T~ 4500.2}~0 HTE4 )EPT 4400.29~0 HTE~ )E~T 4300.2910 HTE~ )EPT 4200.29~0 HTEN )E~T 4100.2910 HTE~ )EFT 4000.ZglO H'TE~ )EPT 3995.~995 HTEN ~ FILE TRAILER.~ :ILE NAME :EDIT: .O04 ;ERVICE NAME : tERSION ~ : )ATE : ~AXIMUM LENGTH : t024 :ILE TYPE : ~EXT FILE NAME : ~¢ TAPE TRAILER ~,~ ;ERVICE NAME :EDIT )ATE :85/03/21. ]RIGIN :FS1A FA~E~ NAME : :O~TINUATION ~ :01 iEXT TAP~ NAME :. 984.8125 9%5.8125 984.3125 1008.8125 g~6.3125 1016.~125 1005.3125 1001.81~5 1026.6875 987.8125 989.8125 951.8125 g31.3125 9~?.3125 1036.6875 1056.68T~ 1078.6875 RECORD TYPE 137 ~ .VP OlO.H02 VERIFIC4TION LISTIN$ P4GE 39 'OM~ENTS :LIBRARY TAPE REEL TRAILER ~ ;ERVICE NAME :EDIT )ATE :86/03/21 ~RISIN : ~EEL NAME :149304 ~O~TINU~TION # :01 ~EXT REEL NAME : ~OMMENTS :LIBRARY TAPE ;ERVICE NA~E :EDIT ~RI~IN : ~EEL N~ME :14930~ iONTINUATION # :01 'R~VIOU$ REEL : 10MMENTS :LIBRARY T~PE RECORD TYPE 137.-~- RECORD TYPE 137 '~'~ :~.~ TAPE HE~,DER ;ERVICE NAME :EDIT lATE :$6/03/21 iRI$IN :FS1A 'APE NAME :ONTINUATIDN ~ :01 'REVIDUS~ T~PE : :OMMENT$ :LIBRARY TAPE RECORD TYPE 137 ~ :~ FILE HEADER ~ILE NAME :EDIt~ .001 ;ERVICE NAME : 'E RSION ~ : )ATE : I~XIMUM LENGTH : 102~ :ILE TYPE 'REVIOUS FILE : .V~ OlO.H02 YERI~ICATIgN LISTING PAGE 40 ' ALASKA CDMPUTIN$ CENTER ~OMP&NY = ARCO ALASKA INC. ~ELL = LISB,JRNE L~-~! :IELO : PRUD~OE BAY/L~SBURNE POOL ;DUNTY = NORTH SLOPE BOROUGH ;T&TE : ~DB NUMBER AT ACC: ?136~ {UN ~ONE, D&TE LOGGED: iS-MAR-85 .D~: C. WILKIE ~ ~ S I N G FYmE FLUID )E~JSITY FISCOSITY ~H :LJID L3SS 9.625" @ ~7.00' - BIT SIZE = 8.5" TO 12005' LIGND S< 9.3 LB/G RM = .389 @ 65.0 DF 35.0 S RMF = .458 @ 65.0 DF 10.3 RMC. : .728 @ 65.0 DF 8.~-C). RM AT BHT = .158 @ 170 DF ~ATRIX LIMESTONE ~PI SERIAL NO. 50029215~ REPEAT LOG DAT* DISPLAYED HAS' NOT BEEN SHIFTED · VP OiO'H02 VERIFICATIO~ LISTIN$ PAGE SDHLUMBERDER LOGS INCLUDED WITH THIS MAGNETI2 TAP;: MICROLOG (EP2) DUAL LATERLO~ (DLR) D~A,L LATERLO$ (DR2) LONG SPA:ED SONIC LOG (LSR) LZT'HO DENSITY COMPENSATED LOG CLDR) CDHPENSATED NEUTRON LOG CCNR) ELECTROMagNETiC PROPAGATION TOOL CEPR) NaTURaL $~M~A TOOL C~GR) N~TURAL ~M~ TOOL CN~2) ~ OAT& FORMAT RECORD !NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 65 0 .VP OIO'H02 VERIFIC~TIO~ LISTIN~ P4~E ~2 4NEM ]EPT SGR .LS ~P :ALS SIO SVO FENS ~PHI ;R JR~T' ~CNL :CNL ~NR~ FEW S )P~tI ;R )R ~ 3 .S .k' .U ;S1 ;S 2 ~LI ~OT ~ ~3Ng' FHOR JR~N FENS ~R :ALI 8 15 0 SPECIFICATION BLOCKS SERVICE SERVICE UNIT !0 OROER ~ DLR gLR OLR DLR DLR ,DLR DLR OLR OLR gLR CNR CNR CNR Cq'R CNR CNR CNR LDR LDR LDR L-DR LDR L D R LBR LDR LDR LDR LDR LDR LgR LOR LOR N~R NGR NSR NGR NSR NGR NSR N~R NG:R N~R EP2 EP2 FT $~Pt ~HMM OflMM IN M~ LB G~PI CPS CPS LB P J G~'C3 $ ~ P I ~?C3 C~$ CPS' CPS CPS C~S CPS LB G~P t CPS CPS C PS CPS CPS PPM PPM 2~ P I IN PI OG O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 00 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 API TYPE 000 310 220 220 010 000 000 000 000 000 635 310 ~20 330 330 000 890 350 310 355 3~B O00 000 3~¢ 35¢ 35¢ 000 000 635 310 310 310 310 310 310 310 792 635 310 280 API (LAS O0 S 4 O1 10 09 O1 O0 O0 O0 00 O0 21 O0 O1 O1 31 O0 21 O0 02 O1 O1 O1 O0 O0 O1 O1 O1 O1 O0 O0 O1 Z 1 O1 O1 50 O1 O1 O1 O1 O1 50 50 21 Ol O1 66 ? 3 66 66 PI FI OD 'J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LE 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SI 1 60 .lin 1 0 Z:,- SPL 4 1 4 1 4 1 4 1 4 I 4 1 4 1 4 1 4 1 4 1 4 1 4 4 4 4 1 4 1 4 4 1 4 4 1 4 1 4 1 4 1 4 4 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 4 1 4 1 4 1 4 ! 4 i 4 4 4 1 4 1 4 1 REPR CODE 58 58 58 58 58 58 5B 5B 68 58 58 58 58 58 6B 58 PROCESS (OCTAL) 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 0000000000.0000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O00000OO000000 00000000000000 68 00000000000000 6B 00000000000000 0000000000000'0 68 00000000000000 68 00000000000000 58 00000000000000 58 00000000000000 00000000000000 58 00000000000000 58.00000000000000 58 00000000000000 68 00000000000000 00000000000000 68 00000000000000 00000000000000 68 00000000000000 .V~ 010.H02 VE~IFIC~TI3N LISTIN~ PAGE 4`3 'ENS EP2 LB O0 ]ALI EPR IN O0 ~A EPR IN O0 ;R EPR ~API O0 'E~S EPR LB O0 )T LSR ~S/F O0 ;R LSR ~PI O0 )TL LSR JS/F O0 FENS LSR L5 O0 ;GR OR2 G~PI O0 .LD DR2 3qMM O0 .LS DR2 DiMM O0 ;P DR2 MV O0 ;ALS DR2 IN O0 )VO DR2 MV O0 )IO gR2 ~ O0 ;ID 3R2 UA O0 ;VO DR2 MY~ O0 tENS DR2 LB O0 ;GR NR2 ~PI 'GR NR2 G~Pl O0 ~DT& NR2 PU O0 IlN$ NR2 CPS iZNG NR2 CPS O0 13~G NR2 CPS O0 t4`~$ NR2 C~S O0 t5~G NR2 CPS O0 'H~R NR2 PPM O0 IR~N NR2 PPM O0 'ENS NR2 L~ O0 535 280 310 635 520 310 520 635 310 220 220 010 000 000 000 000 000 635 310 310 719 310 310 310 310 310 790 792 DATA IEPT ;IO ;R ;R )SS .ITH ~ENS ;R ;R .LD · )¥0 tENS 12017-0000 -999o2500 -999..2500 -999.2500 -999°2500 -999.2500 -999°2500 -999.2500 -999.2~00 -:999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -~99o2500 -999.2500 -9'99.2500 SGR C ~L .S SVO NR .~ T TENS DR'~g LS S S 1 SGR 'THDR CAL T GR DTL LLS SGR W2 THDR -9~9o2500 -999,2500 -999,2500 -999,2500 -9~9,2500 -999,2500 -999.2500 -999.2~00 -999-2500 -999,2500 -9~9o2500 -999.2500 -999.Z~00 -9~9.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -9~9.2500 O! O1 Ol 21 80 01 $0 21 O1 10 09 O! O0 O0 O0 21 01 50 O1 01 01 01 01 ~0 21 LLD DV'O TENS NC~L DPMI PEF LL SS2 CGR UR~N TENS TENS TENS SP CGR W3NG UR~N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999°2500 -999.2500 -999o2500 -999,2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°Z500 -999°2500 68 gO000000000000 58 O000000000OO00 $$ 00000000000000 65 O00000000OO000 58 00000000000000 58 00000000000000 68 00000000000000 58 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 OOO000OO000000 58 00000000000000 00000000000000 68 03000000000000 58 00000000000000 68 00000000000000 58 0000000'0000000 68 00000000000000 58 00000000000000 68 00000000000000 68 00000000000000 6B OOOO0000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 ~0000000000000 68 00000000000000 LLS DIO NPHI FCNL RHO) QLS' LU CALI POT~ 'TENS CALI DT SGR CALS SVO PO'TA W4NG TENS -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°250~0 -999'2500 -999,2500 -999.2500 -999.2500 -999.2500 .VP )EPT ;IO ;R ;R }SS .ITH 'ENS ;R ;A .L3 'ENS 15NG IEPT ;P ;IO ',NRA ;R ~S S ,iTH 'EN S ,R ,R ,LO ~VO 'ENS ~EPT P ~R ~R ~SS ,ITH 'ENS llNS ~SXiG OlO'H02 VERIFICATION LISTIN~ 12000.0000 SGR -999.2500 CALS -999.2500 SVO 20.5361 NR&r 1o0538 TENS 20.5361 DR93 O.ODT3 LS 37.7617 SS1 5 335. 2500 SGR -999.2500 W2N~ -999.2500 THOR 20.5361 CALI 0.5362 GR 23.6611 DTL 10.5082 LLS 5.5867 DIO 3665.5000 SGR 366.8306 W2NS 13.9551 THOR 11900.0000 -999o2500 -999.2500 23.6924 1.6522 23.692 4 -0.0044 34. 2305 6255.2500 -999.2500 -999.2500 23.6924 0.8770 28.6924 40.6935 14.0176 5755.2500 80. 5898 4.7 3'90 11800.0000 -999.2500 -999.2500 20.2393 1.6143 20.2393 0.0146 39'1680 6271.2500 -999.2500 -999-2500 20.2393 1.0176 17.6299 SGR CALS SVO. NRA? TENS DRH3 LS SS1 SGR W2N$ THOR CALI GR DTL LLS DIO SGR W2N$ SGR CALS SVO NR~ TENS DRH2 LS SS1 SGR W2N$ THO~ CALI SR DTL -999.2500 -999.2500 -999.2500 0.9976 5335.2500 0.0D63 195.1875 195.5625 -999.2500 -999.2500 -999.2500 8.1895 20.5361 ~8.2617 14.6848 473.3906 115.0273 184.0625 15.4160 -999.2500 -999.2500 -999.2500 1.5479 6255.2500 -0.0078 190.5625 188.1875 -999.2500 -999.2500 -999.2500 8.8457 23.6924 5?.6367 41.1057 306.6~06 26.'5674 ~8.~Z68 -999.2500 -999.2500 -9~9.2500 1-4454 6271.2500 -0,.0024 213.3125 194.6875 -999,2500 -999.2500 -999.2500 9.1426 ~0,2393 60.1367 LLD DV'D TENS NCNL DPHt PEF L L SS2 CGR W3NG UR~N TENS TENS TENS SP CGR W3 N 2 UR~N LLD DVO TE-~S NCNL DPHI PEF LL SS2 CGR W3NG UR~N TENS TENS TENS CG R W~NG UR~N LL D DVO TENS NC N L DPHI PEF LL SS2 CGR W3NG T E NS TENS TENS -999.2500 -999.2500 -999.2500 5675.2500 2.5391 3.7~24 97.8398 257.1406 -999.2500 -999,2500 -999.2500 5335.2500 5335.2500 361t.5D00 -32.1445 500.6406 115.6523 59.6367 -0.0385 -999.2500 -999.2500 -999.2500 5175.2500 2.4902 4.0671 94-7148 250.9375 -999.2500 -999-2500 -999.2500 6255.2~00 6255.2500 4535.2500 -I9.6514 371.8906 13.5176 14.2129 1.7120 -999,2500 -999.2500 -999.2500 5031.2500 6.6~06 4.4968 108.9023 286.8906 -999-2500 -999.2500 -999.2500 6271.2500 6271-2500 4523.2500 LLS 910 NPHI FCNL RHOB QLS LU CALI POTA WANG TENS CALI DT SGR CALS SVO POT~ WAN~ TENS LLS DID NPHI FCNL RHDB QLS LU CALI POTA WANG TENS CALI. DT SGR. CALS SV'O POT~ WAN. TENS LLS OIO NPHI FCNL RHOB QLS LU C~LI POTA WANG TENS CALI DT SG~ PAGE 44 -999.2500 -999.2500 1.2207 5353.2500 2.6663 0.0073 194.5625 8.1895 -999.2500 -999.2500 -999.2500 8.1895 44.3867 115.0273 1.6135 5.0710 3.5156 5.0750 3665.5000 -999.2500 -999.2500 7.6172 3111.5000 2.6663 -0.0024 191.5625 8.8457 -999.2500 -999.2500 -999.2500 8.8457 58.6367 26.5674 8.7676 10.5410 0.3906 2.8420 5755.2500 -999.2500 -999.2500- 5.7129 3115.5000 2.5959 0.0186 208.8125 9.1~26 -999.2500 -999.2500 -999.2500 9.1~26 60.7617 20,9893 .VP OlO.H02 VERIFICATION LISTIN3 PAGE 45 .LO 69.6808 LLS 51. )VO 18.8799 DID 2%1. 'ENS 5555.2500 SGR ZO. tlN$ 72.0898 W2N$ 29. 15N$ 0.0000 THOR O. )EOT ;P ;IO ;R ~NRA ;R }SS .ITH 'ENS ;R ;A ;R .LB 'ENS 15NG JEPT ;P ;IO ;R ~NRA ;R ~SS .ITH 'ENS ;R ;A ;R .LO 'ENS tING )EPT ;P ;I0 ;R ~NR~ ;R }SS' .ITH 11700.0000 -999.2500 -999.2500 30.1143 1.1837 30.1143 0.0283 35.6055 5827.2500 -999.2500 -999.2500 30.1143 1.0175 26.5830 87.9086 21.0205 5523.2500 59.?617 2.0256 11500.0000 -999.2500 -999.2500 16.8543 1.3917 16'8543 -0.0044 37.6055 5271.2500 -999.2500 -999.2500 16.8543 0-9834 14.6½26 298'7991 31.1924 5371.2500 49.6055 11500.0000 -999.2500 -999.2500 35.3555 1.7960 35.3555 -0.0063 69.1523 SGR CALS SVO NRAT TENS DRMD LS SS1 SGR WZ,N$ THOR CALl GR DTL LLS DIO SGR WZN~ THOR SGR CALS sro NRAT TENS DRH3 LS SS! SGR WIN3 THOR CALI GR DTL LLS DID SGR WRN~ THOR SGR CALS' SVO NRAT TENS DRH3 LS SS1 -999. -999. -ggg. 1. 5827. O. 185. 193. -gg9. -999. -ggg. g. 30. 52. 92. 212. 24. 36. 2. -999. -999. -999. 1. 6271. '0. 197. 19I, -999. -999. -999. g. t6. 53. 237. 92. 16. 27. 1. -999. -999. -999. 1. 6175- 295. 204. 0385 1875 9893 4111 1196 2500 2500 2500 OBO1 2500 0068 0625 9375 2500 2500 2500 0020 1143 511? 8148 93 ? 5 0049 4805 7522 2500 2500 2500 3018 250O 0039 3125 1875 25O0 2500 2500 2988 8643 0117 1456 8330 3174 3389 2500 2500 25O 0 7.208 2500 0039 6406 3125 SP SIO CGR URAN LLD DVO TENS NCNL OPMI PEF LL SS2 CGR W3NG URAN TENS TENS TENS SP SIO CGR W3NG URAN LLg DVO TENS NCNL OPHI PEF LL SS2 CGR W3NG UR&N TENS TENS TENS SP SIO CGR W3NG URA~. LLO OVO TENS NCNL OPHI PEF LL SS2 -27. 334. 5. 7. 2. -999. -999. -999. 6411. O. 4. 92. 2~6. -999. -999. -999. 5827. 58.27. 4471. -18. 282. 19. 13. O. -999. -999. -999. 5531. 3. 4. 97. 256' -999. -999. -999. 6271. 6271. 4351. 151. 12. 4. O. -999. -999. '-ggg. 4415. 18. 3. 153. 288. 1570 8~06 0437 5906 0354 2500 2500 2500 2500 3~,18 2507 5898 0,625 2500 2500 2500 2500 2500 2500 7295 3906 4893 1660 6074 2500 2500 2500 2500 5~45 0906 9023 1406 2500 2500 2500 2500 2500 2500 0420 9375 6895 0476 7 q, 32 2500 2500 2500 2500 3594, 6'2'41 9,) 75 6 CALS SVO POTA WNNG TENS' LLS DIO NPHI FCNL RHOB QLS LU CALI DOTA TENS CALI DT SGR CALS SVO POTA W~NG TENS LLS DIO NPHI FCNL RHDB QLS CALI POTA W4N$ TENS CALI DT SGR' CALS SVO POTA W4N$ TENS LLS DIO NPHI FCNL RMDB QLS LU CAL! 9.1191 11.7910 0.2441 2.8459 5655.2500 -999.2500 -999.2500 1.3184 5415.2500 2.7034 0.0166 184.9375 9.0020 -999.2500 -999.2500 -999.2500 9.0020 53.1367 24.0049 9.0254 18.0674 0.5371 2.0256 5623.2500 -999.2500 -999.2500 3.4180 3973.5000 2.6467 -0.0146 198.9375 9.2988 -999.2500 -999.2~00 -999.2500 9.2988 15.3.2617 16.8330 9-1035 24.8486 0.4395 2.0237 537'1.250'0 -999.2500 -999.2500 9.1309 2457.5000 2.3948 -0.0073 283.6406 9.7051 · V.~ OtO.H02 VERIFICATION LISTIN:~ P~GE 46 'ENS 6175.2500 SGR -999. I1N~ -999.2500 W2N5 -999. ~SNS -999.2500 THOR -9'99. ;R 35.3555 CALl 9. ;A 1.1583 GR 35. ~R 33.2930 DTL 59. .LD 49.9571 LLS 38. ~VO 16.8543 DI9 3DO. 'ENS 5491.2500 SGR 36. IiN$ 106.1523 W2NS 49. 15NG 5.0554 THOR 5. )EPT ;P ;IO ~R ~NR~ ;R ~SS .IT9 'ENS ilN$ ISqG ;A ,L3 ~VO 'ENS IiNG r5 NS tEPT ;P ;IO ;R ',NRA .ITH 'ENS 15NG ;A ;R ,LO ~VO 'EN S ~1 IEPT ;P 11¢00.0000 -35.9258 337.8906 17.2549 1.6055 17.2549 0.0~25 ~7.5~30 6043.2500 70.7148 2.0198 17.2549 1.0518 20.6143 68.3236 15.2832 5571.2500 71-7773 1.0108 S GR CALS SVO NRAT TENS DRHg · L S SSl SGR THOR CALI GR DTL LLS SGR W2NG THOR 2500 2500 2500 7051 355.5 0117 9393 6606 1367 5~30 6,'587 11300.0000 -49.6133 124.4648 35.251.7 2.2874 35.2617 -0.0005 60'0117 6163.2500 112'0898 4.0398 35,2517 0.9116 29.8485 ¢ 34.5963 35.82~2 5~15.2500 119.5273 1'0128 SGR CALS S VO NRA T TENS DR~ 2 LS SS1 SGR W2N~ THOR C~LI GR DTL LLS SGR W2NS THOR 22.4893 9.0332 11.0256 1.~B15 6043.2500 0.0249 232.6875 298.5525 22.4893 ~0.3857 0.8628 9.1270 17.2569 53.2617 ~7.7133 281.6606 20.3176 26.2861 0'5303 11200.0000 SGR -30.9014 CALS 32.7617 11.2988 27.3955 2.1956 6153-250'0 -0.0112 299.1406 200.9375 32.7617 ~3.4180 2.1~87 11.2285 35.2617 59.9023 282.2586 73.~023 36.1992 52.6680 1.1602 70.4648 18.0518 W3NG UR~N TENS TENS TENS SP SIO CGR W3NG UR~N LLD DVO TENS NCNL DPHI PEF LL SS2 CGR W3N'G URAN TENS TENS TENS SP W3N~ UR~N LLD DVO TENS NCNL DPHI PEF LL 5S2 CGR W3NG TENS TENS TENS SIO CGR W3~ U'RAN L L D DVO -999.2500 -999.2500 -999.2500 6175.2500 6175.2500 4363.2500 -23.0732 382.1¢06 35.4~05 14.1504 1.0545 47.7352 14.8066 5551.2500 4611.2500 8.1543 2.9338 118.9648 267.6~06 13.5723 15.1504 1.1885 6043.2500 6043.2500 6363.2500 -22L8545 338.6~06 5.5164 13.1~26 1,9664 495.8987 36.8867 5531.2500 3199.5000 19.433:6 3,9749 156.0625 281.3906 14.2832 18.1768 2-4202 6163.2500 6163.2500 4235.2500 -25.1982 136.9375 7.7039 14.1.816 3.7131 6.09t9 1.8399 PDTA W4NG TENS CALl OT SGR CALS SVO POTA W4NG TENS LLS DIO NPHI FCNL RHOB QLS LU CALl POTA W4N~ TENS CALI DT SGR CALS SVO POTA W4N~ 'TENS LLS DIO NPHI FCNL RHOB QLS LU CALI POTA W4N~ TENS C~LI DT SGR CALS S¥0 POTA W4NG TENS LLS DID -999.2500 -999.2500 -999.2500 9.7051 59.1367 36.1357 9.6973 10.2598 0.8301 5.0554 5491.2500 47.3198 275.1~06 6.2988 2871.5000 2.5686 0.0044 227.4375 9.1270 0.6348 2.0198 5551.2500 9.1270 53.2617 20.3174 9.119! 11.1426 0.1953 1.0108 5571.2500 319.2153 66.2148 14.7949 1398.6875 2.3772 -0-0059 286.3906 11.2285 0.3418 2.0198 5531.2500 11.2285 69.4023 36.1992 i1,3223 26.6611 0.1953 3.0393 5415.2500 3.2361 268.8906 .VP DiO.H02 YE~!FICATION LISTINg PAGE 4'? ~IO 829,8125 SVO DR 61,6992 NRAT ~NRA 3,9338 TENS ;R 51,6992 DRH2 ~SS 0,0112 LS .ITH 181.4375 SSi FENS 5595.2500 SGR ~iNS 224.4375 W2Ng ~SNg 6.0571 THOR ~R 61.6992 CALI ~A 3.~729 GR ~R 71.3398 DTL .LD 7.5025 LLS )VO 4,02~2 DID KENS 5231.2500 SGR dlN~ 231,1875 W2N$ ~SN~ 4.055~ THOR 1.8516 3.7659 5595.2500 -0.0020 792.8125 229.3125 ?0.~$~8 101.0898 6.2625 9.9785 51,6992 82.1523 3.3048 477.5~06 $7.8398 96.3398 5.0945 )EPT 11168,0000 SGR ;P -999,2500 CALS ;lO -999-2300 SVO ;R -999.2500 NRAT' ~NRA -999.2500 TENS ;R -999.25001 DRY3 )SS -999,2500 LS .ITH -999,2500 SSI 'ENS -999.2500 SGR I1NG -999,2500 W2NS ~SNS -999.2500 THOR ;R -999.2500 CALi ;A -999,2500 GR ;R 53.5430 DTL .LD -999.2500 LLS )VD -999.2500 DIO 'ENS -999,2500 SGR I1NS -999.2500 W2N2 15N~ -999.2500 THD~ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 55.0273 -9~9,2500 -999,2500 -999.2500 -999.2500 -9~9.2500 :~ FILE TRAILER :ILE NAME :EDIT .001 ;ER~ICE NAME : ~ERSION ~ )ATE : IAXIMUM LENGTH :. 102~ :ILE TYPE IEXT FILE NAME : ~:~ R 6 C 0 R D FILE HEADER ~x :ILE NAME :EDIT ;ERVICE NAME : ,002 TENS NCNL DPMI PEF LL SS2 CGR W3N5 URAN TE~S TENS TENS SP SIO CGR W3N~ U'RAN LLD DVD TENS NCNL DPHI PEF LL SS2. CGR W3N~ URAN TENS TENS TENS SP SIO CGR W3N2 URAN TYPE 137 ~ 5651.2500 1209.6875 52.2661 3.0549 418.1~06 351.8905 41.9805 33.3555 3.8¢79 5595.2500 5595.2500 4151.2500 0.6~84 712,3125 38.3555 33.4492 4.0007 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500. -999.2500 -999.2500 -999.2500 4207.2500 -999.2500 -999.2500 -99~.2500 -999.2500 -999.2500 NPHI FCNL RHgB QLS LU CALI POTA W~NS TENS CALI DT SGR CALS S¥0 POTA WANG TENS LLS DIO NPHI FCNL RMDB QLS LU CALI POTA WCNG TENS CALI DT SGR CALS sro POTA WAN~ TENS 39.5508 307.3906 1.8155 -0.0732 7~8.8125 9.9785 !,074Z 5.0554 5651.2500 9.9785 87.2773 $7.8398 17,2080 1,6231 1,1719 8,1113 5231,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999o~500 64.15Z3 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500' -999.2500 .VP OIO.H02 VERIFICATI~ LISTINS PAGE /ERSION ~ : )ATE : 4~XIMUM LENGTH : 1024 :ILE TYPE : ~R=V!OUS FILE : ~ DAT~ FORMAT RECORD !NTRY BLOCKS TYP SIZE REPR CODE 1 66 I 66 I 66 1 66 )~TUM SPECIFICATION BLOCKS )NEM SERVICE SERVICE iNIT API ID ORDER ~ LOG )EPT' FT: O0 ~SFL DLR DHMM O0 ISFL DR2 D~MM O0 IINV EPZ 3iMM O0 ~NOR EP2 D~MM O0 'PL EPR NS/M O0 :ATT EPR DB/M O0 )E~T tNOR tNDR )EPT INOR )EPT JN ~R )EPT INDR )E~T INOR )EPT )EPT INDR 12'016.3320 MSmL -999.2500 TPL 12000.1660 MSFL 2.7'83~ TPL 11900,1660: MSFL 1~.6270 TPL 11800.1660 MSFL~ 10,1035 TPL 11700-1660 M!SFL! 15.9941 TPLi 11600.1660 MSFLr 23.1143 TPL 11500'1560 MSFL 8.6~26. 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API A~I API FILE SIZE SPL R.EPR ID ORDER ~ tEPT FT ITEN DLR LB ITEN DR2 LBi ITEN CNR LS' ITEN LOR L~ ITEN NCR LB1 ~TEN NR2 L5 ITEN Em2 LB iTEN 'EPR LB LOG TYPE CLASS MOO NO. 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HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTE~ HTE~ HTEN HTEN HTEN -103.7227 -103.7227 -95.4102 -95.4102 937.8~25 937.8125 9~1.8125 9~1.8125 971.8125 971.8.125 920.3125 920.3125 938.3125 938.3125 976.8125 9';'6.8125 978.3125 978.312'5 977.3125 977.312S 929o8~25 929.8125 HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN MTEN -999.2500 -999.2500 850.8125 860.8125 1381.6875 1381.~875 1353.6875 1363.6875 1239.6875 1239.6875 1376.6875 1375.6875 1356.6875 1356.6875 1329.6875 1329.68T5 1371o6875' 1371.6875 1199.6875 1199.6875 -999.2500 -999.2500 ,VP 010.H02 VERIFICATIDN LISTIN~ PAGE 51 :ILE TYPE IEXT FILE NAME RECORD TYPE 137 ~ :* TAPE TRAILER ;ERVICE NAME :EDIT )ATE :86/03/Z1 )RI~IN :FS1A 'APE NAME : ~ONTINUATIDN ~ :0! ~EXT T~PE NAME [DMMENTS :LIBRARY TAPE ~: REEL TRAILER ;ERVICE NAME :EDIT )ATE :85/03/2]. 3RI~IN :, ~EEL" NAME ~ONTINUATION ~ :O1 ~EXT' REEL NAME :. 30MMENTS :LIBRARY TAPE ~ RECOR~3 TYPE 137 ~ RECORD TYPE
