Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-159
STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! WELL MPLETION OR RECOMPLETION REPO AND LOG • 1 a. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 2 ' Suspended 0 lb.Well Class: /X' -(V 20AAC 25.105 20AAC 25.110 / y-�� Developm ht Exploratory ❑ GINJ ❑ WINJ 0 WAG ❑ WDSPL 0 No.of Completions: Zero ' Service tratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Per it to Drill Number/Sundry BP Exploration(Alaska),Inc 12/7/2015 1857159 • 315-546 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 7/12/1985 50-029-21394-00-00- 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 7/26/1985 PBU 11-10 ' Surface: 1038'FSL,352'FEL,Sec.28,T11N,R15E,UM " 9 KB Ref Elevations 17. Field/Pool(s): 58' Top of Productive Interval: 1050'FSL,1556'FEL,Sec.21,T11N,R15E,UM GL 28 • BF 29.49 . PRUDHOE BAY,PRUDHOE OIL - Total Depth: 1412'FSL,1506'FEL,Sec.21,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: . 10960'/8343' ' ADL 028325&028322 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 707170 • y- 5952752 - Zone - ASP 4 • 11555'/8825' . 70-054 TPI: x- 705809 y- 5958009 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 705849 y- 5958373 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 21 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary DIL/BHCS/GR/SP,GR/CCL/DIL/SP,Gyro(GCT) 1-tkpmF11 FEB ¶ 2?r.-11 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 31' 111' 31' 111' 30" 2000#Poleset(Approx.) 13-3/8" 68#/72# K-55/L-80 30' 2521' 30' 2521' 17-1/2" 2500 sx PF'E',400 sx PF'C' 9-5/8" 47# L-80 29' 10918' 29' 8309' 12-1/2" 500 sx Class'G' 7" 26# L-80 10691' 11550' 8131' 8821' 8-1/2" 380 sx Class'G' 24. Open to production or injection? Yes ❑ No 2 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 10593' 10437'/7935' A4Afilft4f91/4° 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DATE Was hydraulic fracturing used during completion? Yes ❑ No 0. Z 1r 'j' RECEIVE Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEC 3 0 2015 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11280' Set Plug AOGGC11270' 15.6 Gal Cement 10960' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �m► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): •"".Press - 24 Hour Rate " Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only / * �6 VT'- 1/4// RBDMS .JAN 2 2 2016 /0 'y-i6,•i/ la 28. CORE DATA • Conventional Core,(s) Yes 0 No RI • • Sidewall Cores Yes ❑ No 11 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No Q • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10931' 8320' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 10931' 8320' Base Sadlerochit 11452' 8741' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tempel,Troy Email: Troy.Tempel@bp.com Printed Name: Joe Lastuf Title: Drilling Technologist Signature: e: +1 907 564 4091 Date: (2134/t5 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 11-10 Well History (Pre-Rig Sidetrack) ACTIVITYDATEg ' z. T/I/O = 248/454/25 Temp= SI (Pre E-Line Load and FP) Pumped 10 bbl Neat spear followed by 291 bbl 1% Kcl for load and then 41 bbl Diesel for FP, RDMO, SV,WV,SSV= C MV=0 10/9/2015 IA/OA= OTG FWHP=0/1168/48 ***WELL SHUT IN ON ARRIVAL***(ELINE MILL/PLUG/CEMENT/WHIPSTOCK) INITIAL T/I/O = 0/680/50 PSI MIRU ELINE EQUIPMENT. RUN 1: RIH WITH WELLTEC MILL ASSEMBLY. MILL XN NIPPLE @ 10546' FROM 3.725" ID TO 3.80".ID/ MILLED XN NIPPLE AND PASSED THROUGH WITH NO ISSUES. MIC BEFORE MILE = 3.805"/MIC AFTER MILL = 3.803". REHEAD WITH A SMALLER WEAKPOINT. MAKE UP POSISET ASSEMBLY AND OP CHECK. 10/9/2015 ***JOB CONTINUED ON 10-OCT-2015 *** ***JOB CONTINUED FROM 9-OCT-2015***(SLB ELINE - MILL/POSISET/CEMENT DUMP/WHIPSTOCK) STANDBY FOR WIND 10/10/2015 ***JOB CONTINUED ON 11-OCT-2015 **** ***JOB CONTINUED FROM 10-OCT-2015 *** (SLB ELINE - MILL/PLUG/CEMENT/WHIPSTOCK) CONTINUE TO STANDBY FOR WIND. RUN 2: RIH W/ HEAD/CCL/POSISET. SET POSISET PLUG AT 11280'/TOP OF POSISET SEALING ELEMENT @ 11280'/ CCL TO TOP OF PLUG =23.1'/CCL STOP DEPTH: 11256.9' RUN 3: DUMP BAIL CEMENT ON TOP OF POSISET PLUG. RUN 4: DUMP BAIL CEMENT ON TOP OF POSISET PLUG. RUN 5: DUMP BAIL CEMENT ON TOP OF POSISET PLUG. CURRENTLY RIH WITH RUN 5 (THIRD DUMP BAILER RUN) 10/11/2015 ***JOB CONTINUED ON 12-OCT-2015 *** ***JOB CONTINUED FROM 11-OCT-2015 ***(SLB ELINE - MILL/PLUG/CEMENT/WHIPSTOCK) RUN 5 (CONT): CONTINUE RIH WITH 3RD CEMENT DUMP BAILER RUN. DUMP BAIL CEMENT ON TOP OF POSISET PLUG. RUN 6: DUMP BAIL CEMENT ON TOP OF POSISET PLUG ESTIMATED TOC AT 11270' MD. 15.6 GALLONS CEMENT TOTAL. RUN 7: SET BAKER GEN II DELTA WHIPSTOCK 7"26#-29#. TOWS SET DEPTH = 10960', CCL TO TOWS = 14.1', CCL STOP DEPTH = 10945.9'. PIP TAGS 8.63' FROM TOWS 172 DEG TFO. CORRELATED TO SLB CBL DATED26-AUG-1985 MAIN PASS. RIG DOWN ELINE EQUIPMENT. WELL SHUT IN ON DEPARTURE. DSO NOTIFIED. FINAL T/I/O = 0/490/0 PSI 10/12/2015 ***JOB COMPLETE, WELL TURNED OVER TO DSO*** T/1/0= 0/450/13 Temp= SI Perform MITs (CTD) Pumped 12 bbls DSL down TBG to reach test pressure @ 2500 psi First 15 min loss 75 psi , Second 15 min loss 48 psi, Total loss of 123 psi FAIL 10/15/2015 End Ticket, ****Job continued on 10/16/15 **** 10/16/2015 M.I.T IA to 2500 psi - NO RAP on location ( Couldn't get OTL signature) -Job Postponed ****Job continued from 10/15/15 **** Pumped .2 bbls of DSL down TBG to reach test pressure @ 2500 psi. First 15 min test loss 44 psi, Second 15 min test loss 40 psi, total loss of 84 psi(((( FAIL)))) LLR of 12.6 gallons every 30 min. Bleed down TBG to 500 psi, rig 10/16/2015 down. • • 11-10 Well History (Pre-Rig Sidetrack) T/I/0=760/500/10 Temp=SI MIT-T PASSED to 2500 psi. MIT-IA PASSED to 2500 psi, MIT- OA PASSED to 1200 psi (CTD) Pumped 5.5 bbls of ambient DSL down IA for MIT-IA to 2750 psi. 1st 15 mins IA lost 29 psi. 2nd 15 mins IA lost 9 psi. Total Test IA lost 38 psi. PASS. Bled IA to 500 psi got back —5 bbls. Pumped .2 bbls ambient crude down OA for MIT- OA to 1400 psi. 1st 15 mins OA lost 53 psi. nd 15 mins OA lost 9 psi. TotaL Test OA lost 61 psi. PASS. Bled OA to 15 psi and got back —.2 bbls. Pressured up Tbg with 2 bbls diesel to reach 2728 psi. MIT-T lost 112 psi in 1st 15 minutes and 52 psi in 2nd 15 minutes for a total loss of 164 psi in a 30 minutes test. Bled down TP —2 bbls. DSO notified of well status per LRS departure. FWHP's=760/532/25. SV,WV,SSV=C MV=0 IA,OA=OTG 11/1/2015 ***Tags hung on IA and OA. Fluid Packed Annulus sign already on well. T/I/0 =SSV/530/20. Temp = SI. Bleed WHPs to 0 psi (Pre Rig). IA & OA FLs @ surface. Bled IAP to slop trailer from 530 psi to 0 psi in 5 min (1 bbl). Bled OAP to slop trailer from 20 psi to 0 psi in 1 min (5 Gallons). Monitor for 30 min. IAP& OAP remained at 0 psi. Job complete. Final WHPs =SSV/0/0. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:00. 11/3/2015 T/I/0=700/0/0. Install Nordic platform #07. Install TS#04 and CTD 4x7 cross over#01. Installed tree cap torqued and PT'd to API specs. (PASS) RDMO. ***Job Complete*** 11/18/2015 FW H P=700/0/0 11/19/2015 T/I/0 = T/I/0 =770/17/0. Temp =SI. Bled WHP's to 0 psi (pre rig). Well is disconnected from the system, no flow line or well house. T FL @ surface. Bled TP from 770 psi to 0 psi in 20 min (-0.97 Bbls). Bled IAP from 17 psi to 0 psi in —2 min (-5 gallons). Monitor for 30 min, during monitor TP increased 14 psi & IAP unchanged. Bled TP to 0 psi SI SSV. See log for details. Job complete. Final WHP's =0/0/0. 11/20/2015 SV, SSV=C. WV =LOTO. MV =0. IA, OA =OTG. 12:20. T/I/0 =SSV/10/0. WHP's (pre rig). Well is disconnected from the system, no flow line or well house. Unable to get TP due to scaffolding removed from well. IAP increased 10 psi over night. 11/21/2015 SV, SSV =C. WV=LOTO. MV=0. IA, OA =OTG. 09:10. T/I/0 = SSV/5/0. WHP's (pre rig). Well is disconnected from the system, no flow line or well house. Unable to get TP due to scaffolding removed from well. SV, SSV= C. WV = LOTO. MV = 0. IA, OA= OTG. 08:30 12/3/2015 • North America-ALASKA-BP Page 1 of 22 Operation Summary Report Common Well Name:11-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2015 End Date: X3-0171X-C:(3,237,905.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:7/12/1985 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292139400 Active datum:Kelly Bushing/Rotary Table(258.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (uaft) 12/3/2015 05:00 - 00:00 19.00 MOB C PRE RIG RELEASED FROM C-08 AT 0500. RIG IS STILL ON C-PAD WHILE DAY AND NIGHT CREWS ATTEND HISU CLASS.MOVE NIGHT CREW ARRIVED TO PREP FOR RIG STARTED WARMING UP MOVING SYSTEM. PUSHER/DRILLER PERFORMED ROUTE DRIVE 12/4/2015 00:00 - 01:00 1.00 MOB P PRE FINISHED ROUTE DRIVE SECURITY ARRIVED. 01:00 - 03:00 2.00 MOB P PRE START MOVING RIG TOWARDS PAD ENTRANCE. 03:00 - 07:00 4.00 MOB N RREP PRE HAVING ISSUES WITH MCC BREAKER ON RIG. ELECTRICIANS TROUBLESHOOTING. REPLACE MCC BREAKEER AND TEST. WORKING OK. 07:00 - 09:30 2.50 MOB P PRE MOVE RIG DOWN PAD ACCESS ROAD. 09:30 - 11:00 1.50 MOB N WAIT PRE WAIT ON SECURITY AT PAD ENTRANCE. 11:00 - 00:00 13.00 MOB P PRE MOVE RIG OFF C-PAD TO DS-11. FROM C-PAD RIGHT ON TWIN TOWERS ROAD TO K-PAD ROAD,RIGHT ON WEST DOCK ROAD TO SPINE ROAD TO DS-11. TOTAL 21.9 MILES. 12/5/2015 00:00 - 02:00 2.00 MOB P PRE FINISH MOVE TO DS11 02:00 - 03:30 1.50 MOB P PRE PJSM, SPOT T MATS AND RIG MATS 03:30 - 04:30 1.00 MOB P PRE MOVE RIG OVER WELL, ACCEPT RIG AT 04:30 04:30 - 06:00 1.50 MOB P PRE START RIGGING UP. 06:00 - 11:00 5.00 MOB P PRE PUT 2 HEATERS ON CELLAR TO WARM UP BOP STACK. OPEN SWAB,SSV,AND MASTER VALVE. ZERO PSI ON TUBING. CLOSE SWAB AND MASTER VALVE FOR LEAK TIGHT TEST. LEAK TIGHT TEST IS GOOD. REMOVE TREE CAP. 11:00 - 15:00 4.00 MOB N SFAs PRE THAW OUT STEAM LINE IN CELLAR FAR ENOUGH SO IT CAN BE DRAINED. HEATER CORE HAS FROZE. 15:00 - 17:00 2.00 MOB P PRE SET STACK DOWN,TORQUE UP. ASSEMBLE RISER AND QTS. CIRCULATE HOT WATER ACROSS STACK TO WARM IT UP. 17:00 - 17:30 0.50 MOB P PRE H2S RIG EVAC EXERCISE WITH DAY CREW. ALL PERSONS MUSTER AND ACCOUNTED FOR IN 2 MIN. REVIEW PROCEDURE AND AAR. 17:30 - 19:00 1.50 MOB P PRE CONTINUE CIRC WARM WATER ACROSS STACK. WORK ON STEAM LINES IN CELLAR. PREP TO SLIP AND CUT DRILL LINE. 19:00 - 21:00 2.00 MOB P PRE PJSM, SLIP AND CUT DRILLING LINE 21:00 - 22:30 1.50 BOPSUR P PRE CIRCULATE FRESH WATER/ MEASUREMENTS ON STACK Printed 12/17/2015 4:42:26PM • • North America-ALASKA-BP Page 2 of 22 Operation Summary Report Common Well Name:11-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2015 End Date: X3-0171X-C:(3,237,905.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:7/12/1985 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292139400 Active datum:Kelly Bushing/Rotary Table @58.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 BOPSUR P PRE BEGIN TESTING 7-1/16"BOPE. AOGCC WITNESSED WAIVED BY CHUCK SCHEVE 12/6/2015 00:00 - 03:30 3.50 BOPSUR P PRE PERFORMING DRAW DOWN TEST/ FUNCTION TEST FROM OPS CAB 03:30 - 06:00 2.50 BOPSUR P PRE CONTINUE WITH TEST. FINISHING ANNULAR ON 3-1/2" 06:00 - 08:30 2.50 BOPSUR N SFAL PRE THAW OUT KILL LINE. STEAM IT AND APPLY RIG AIR PRESSURE TO THE STACK. FILL STACK WITH MEOH TO HELP THAW THE ICE PLUG. 08:30 - 08:50 0.33 BOPSUR P PRE LINE IS CLEAR,FILL STACK WITH MEOH. PJSM FOR FILLING COIL. 08:50 - 10:00 1.17 BOPSUR P PRE FILL COIL FORWARD WITH 3 BBLS MEOH FOLLOWED BY WARM WATER. 10:00 - 11:20 1.33 BOPSUR P PRE M/U INJECTOR TO WELL,PUMP 3 BBLS MEOH BACKWARDS INTO CT TO PREVENT FREEZING DURING REEL VALVE AND STRIPPER PT. TEST INNER REEL VALVE AND CT STRIPPER 250/3500 PSI,GOOD. PUMP MEOH FORWARD OUT OF REEL. VALVE CREW CHECKS TORQUE ON TREE BOLTS,NO MOVEMENT IN ANY. 11:20 - 12:20 1.00 RIGU P PRE PJSM AND REVIEW PROCEDURE FOR PUMPING SLACK. LINE UP TO REVERSE CIRCULATE. REVERSE CIRCULATE WARM FRESH WATER 3.50 BPM/3330 PSI. CABLE IS HEARD MOVING FOR ABOUT 5 MIN AT THIS RATE. PUSH FLUID BACKWARDS WITH AIR SO CT IS DRY WHILE CUTTING. _ 12:20 - 14:00 1.67 RIGU P PRE INSTALL HYDRAULIC CT CUTTER. CUT 265 FT OF CT. INSTALL CT CONNECTOR,PULL TEST TO 35K IS GOOD. PRESSURE TEST 300/3900 PSI IS GOOD. 14:00 - 16:00 2.00 RIGU P PRE M/U STINGER AND NOZZLE,M/U INJECTOR TO WELL. PUMP SLACK FORWARD.CABLE IS HEARD MOVING AFTER 4 BPM/3900 PSI. PUMP UNTIL IT STOPS MOVING. LINE UP TO PUSH FLUID BACK WITH AIR,TO PREVENT FREEZEUP WHILE INSTALLING CABLE HEAD. TEST CABLE,GOOD. INSTALL BHI CABLE HEAD. 16:00 - 17:00 1.00 RIGU P PRE PRESSURE TEST CHECK VALVES,GOOD. PRESSURE TEST UQC,GOOD. 17:00 - 18:00 1.00 RIGU P PRE PJSM THEN M/U BHA#1. CAN'T RUN BHA PAST THE TUBING HANGER, LIKELY ICE PLUG HERE. CONFIRM WITH VALVE SHOP NO TWC IN THIS WELL. Printed 12/17/2015 4:42:26PM • • North America-ALASKA-BP Page 3 of 22 Operation Summary Report Common Well Name:11-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2015 End Date: X3-0171X-C:(3,237,905.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:7/12/1985 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292139400 Active datum:Kelly Bushing/Rotary Table @58.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 21:30 3.50 RIGU N HMAN PRE CLOSE SWAB AND MAST,PJSM FOR M/U NOZZLE BHA. -CREW CHANGE. DO SOME RESEARCH ON HOW THERE COULD BE ICE PLUG -DISCUSS WITH ODE ABOUT A PROCEDURE FOR ICE PLUG -CREW VERIFIED VALVES. PUT PRESSURE ON SSV TO SEE IF WE GET ANY MORE MOVEMENT. GOT APPROXIMATELY 1.5"- -TAKE CAP OFF/ STROKE CLOSED. CLOSED MEASUREMENT 5-3/8" OPEN MEASUREMENT 0.75" -CLOSED SSV VALVE.OPENED SWAB. RUN BHA INTO STACK. TAGGED AT SAME MARK FROM PREVIOUS RUN. SSV WAS ISSUE. -INSTALL NIGHT CAP. PT QTS LOW/HIGH. OPEN WELL UP TO CLOSED CHOKE. PERFORM 10 MIN FLOW CHECK. WELL STATIC 21:30 - 22:30 1.00 RIGU N HMAN PRE DISCUSS PLAN FORWARD. SWAP COIL OVER TO 1%KCL. SINCE WE ARE NOT GOING FOR ICE PLUG PJSM FOR RIGGING BHA UP. 22:30 - 23:00 0.50 RIGU P PRE RUN BHA#1 IN HOLE STAB INJECTOR(23:07)PRESSURE TEST QTS SUB 23:00 - 23:30 0.50 RIGU P PRE START CIRCULATING AT WARM 1%KCL TO TIGER TANK 23:30 - 00:00 0.50 RIGU P PRE RIH WITH BHA#1 WHILE TAKING FREEZE PROTECT/WELLBORE KCL TO TIGER TANK (DISCUSS FLUID MANAGEMENT POLICY) 12/7/2015 00:00 - 01:15 1.25 STWHIP P WEXIT RIH WITH BHA#1 8.3 PPG IN/8.31 PPG OUT 0.8 BPM IN/1.35 BPM OUT RIH AT 100'/MIN 01:15 - 02:17 1.03 STWHIP P WEXIT PICK UP WEIGHT 51K PERFORM TIE IN. TIE INTO FORMATION MARKER AT 10842.5' +13' CORRECTION 02:17 - 02:30 0.22 STWHIP P WEXIT DRY TAG WHIPSTOCK PINCH POINT. 10967.3' 02:30 - 03:15 0.75 STWHIP P WEXIT FINISH CIRCULATING 9.5 PPG MUD AROUND. BRING MUD BACK INSIDE. BLOW DOWN TIGER TANK LINE BLEED IA DOWN FROM 625#TO 125# 03:15 - 03:30 0.25 STWHIP P WEXIT PERFORM SLOW CIRCULATING RATES WWItl, 03:30 - 04:00 0.50 STWHIP P WEXIT WINDOW MILLING FREE SPIN 2850#@ 2.79 BPM 1 1131k 9.45 PPG IN /9.41 PPG OUT 2.80 BPM IN/2.80 BPM OUT CREPT INTO PINCH POINT. STALLED AT 10967.1 04:00 - 06:00 2.00 STWHIP P WEXIT FREE SPIN 2850#©2.79 BPM 9.45 PPG IN /9.41 PPG OUT 2.80 BPM IN/2.80 BPM OUT TIME MILLING AHEAD AT 1'/HR AVERAGING 1.5K WOB. 150#MOTORWORK PVT 364 Printed 12/17/2015 4:42:26PM • • North America-ALASKA-BP Page 4 of 22 Operation Summary Report Common Wet Name:11-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2015 End Date: X3-0171X-C:(3,237,905.00) Project:Prudhoe Bay Site:PB DS 11 Rig Name/No.:NORDIC 2 Spud Date/Time:7/12/1985 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW1:500292139400 Active datum:Kelly Bushing/Rotary Table(4)58.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 09:00 3.00 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 10968.5 FT. 2.80/2.82 BPM IN/OUT. 9.47/9.40 PPG IN/OUT. DWOB IS 2.12KAT 10971 FT,ROP AROUND 1'/ HR. 09:00 - 11:30 2.50 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 10971.0 FT. 11:30 - 12:30 1.00 STWHIP P WEXIT DWOB DROPS OFF AFTER 10973 FT,LIKELY CASING EXIT POINT. CONTINUE MILLING 1 FT/HR UNTIL STRING REAMER EXITS. 12:30 - 13:30 1.00 STWHIP P WEXIT MILL RAT HOLE FROM 10973 FT TO 10982 FT. 13:30 - 15:30 2.00 STWHIP P WEXIT ALLOW WEIGHT TO DRILL OFF. PICK UP FOR SLOW CLEANING PASSES. SAMPLE FROM 10976 FT IS MOSTLY FORMATION,SMALL AMOUNT OF METAL,NO CEMENT. PUMP A LO-VIS SWEEP DOWN. FIRST UP PASS SEE A LOT OF MOTOR WORK IN RAT HOLE,PICK UP AT 1 FT/MIN THROUGH WINDOW. SUBSEQUENT PASSES ARE CLEAN. 15:30 - 17:20 1.83 STWHIP P WEXIT DRY DRIFT WINDOW TO BOTTOM OF RATHOLE,CLEAN. TAG 10983 FT. PICK UP ABOVE WINDOW FOR FLOWCHECK. 110 MIN PUMPS OFF FLOWCHECK SHOW NO FLOW. POOH. NOTE: TOOL HAS SHORTED OUT AFTER OPENING THE EDC. 17:20 - 18:00 0.67 STWHIP P WEXIT CONDUCT PJSM WHILE POOH. TRIP SHEET IS-1 BBLS TO THIS POINT. 10 MIN PUMPS OFF FLOWCHECK NEAR SURFACE SHOWS NO FLOW. 18:00 - 19:00 1.00 STWHIP P WEXIT PARTIAL CREW CHANGE. TAG UP INJECTOR OFF(18:40) 19:00 - 19:30 0.50 STWHIP P WEXIT PJSM, LAY DOWN BHA#1 MILL GAUGED 3.79"GO/3.78"NO GO, STRING REAMER 3.80"GO/ 3.79"NOGO INSTALL NIGHT CAP. OPEN HOT WORK. MEG CABLE>2000 MEGAOHM, 54 OHM WITH SHUNT INSTALLED 19:30 - 20:30 1.00 DRILL P PROD1 STAB INJECTOR(20:07) PT QTS LOW/HIGH PVT=315 BBLS RIH WITH BHA#2 20:30 - 23:00 2.50 DRILL P PROD1 RATE IN=0.97 BPM RATE OUT=1.43 BPM MW IN=9.39 PPG MW OUT=9.40 PPG ECD =10.53PPG IAP=193 PSI OAP=5 PSI PVT=374 BELS END TRIP,TRIP SHEET/-1 23:00 - 23:25 0.42 DRILL P PROD1 PERFORM TIE IN LOG TO FORMATION MARKER AT 10842.5' +14.5' CORRECTION APPLIED 23:25 - 23:40 0.25 DRILL P PROD1 CLOSE EDC GO TO MIN RATE THROUGH WINDOW. NO ISSUES TAG AT 10982' PUW51K PICK OFF BOTTOM GET PARAMETERS Printed 12/17/2015 4:42:26PM Tom= aw NOTES:"'PWI ONLY/NO MI INJECTION WELLHEAD= MCEVOY • A WED""CHROMENIPPLES"' ACTUATOR= BAKERC 11 -10 KB.ELEV= 5_' :I BF ._ELEV= iof I KOP= 3500' 2075' H9-5/8"HES ES CEMENTER Max Angie= 59°@8100' Datum MD= _.� 11595 2093' —19-5/8"BKR ECP DatumTVD= 8800'SS 9-5/8"BKR BOWHV CSG PATCH H 2113' 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" — 2117' Ir. n ' 2233' —14-1/2"FES X NP(9-CR),D=3.813" 13-3/8"CSG,68#,K55/72#,L-80,ID=12.347' --1 2521' , , ' ' 10409' H4-112"HES X NP(9-CR),D=3.813" Minimum ID =3.725" @ 10546' p \� 10440' —I9-5/8"X 4-1/2"BKR S-3 RCR D=3.875" 4-1/2" HES XN NIPPLE /\ /\ ' 10474' H4-1/2"FES X NP(9-CR),D=3.813" 10546' —j4-1/2"HES XN NP(9-CR),D=3.725" 4-1/2"TBG,12.6#,L-80 TCI, —1 .0152 bpf,D=3.958" 10596' H 9-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG STUB(08/28/09) —I 10579' ` 11 10626' H5-1/2"BKR FBRASSY 5-1/2"TBG-PC,17#,L-80, H 10638' l / 10638' H5-1/2"X 4-1/2"XO,D=3.958" .0232 bpf,D=4.892" X p 10642' H9-5/8"X 4-1/2"BOT HB FKR TOP OF 7"LNR H 10687' .--I /� 10734' —14-1/2"CAMCO DB MP,D=3.813" Jil10746'1-14-1/2"BOT SFEAROUT SUB 4 1/2"TBG PC, 12.6#,L-80, 10747' I---- 10747' H4-1/2"TUBING TAIL,D 3.958" .0152 bpf,ID=3.958" 10732' H E MD TT LOGGED 05/02/86 9-5/8"CSG,47#,L-80 BTC,ID=8.681" —1 10916' I---, , 10960' - I7"WHIPSTOCK(10/12/15) PERFORATION SUMMARY REF LOG:BHCS ON 07/26/85 wAv1w11 11270' H TOC(10/12/15) ANGLE AT TOP PERF 35'@ 11414' Note:Refer to Production DB for historical perf data 11280' H POSISET PLUG(10/11/15) SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11414-11450 0 04/07/86 3-3/8" 1 11414-11432 0 07/24/89 ' 3-3/8" 4 11432-11450 0 07/24/89 I PBTD H 11505' 11111111 111111111111111 7"LNR,29#,L-80 BTC,_0371 bpf,D=6.184" --1 11546' 111111111111111 111111111111111 TD H 11555' 1.1.1.1.1.1.1.1 DATE REV BY COMMITS DATE REV BY C-014E fTS PRUDHOE BAY LNT 07/31/85 ORIGINAL COMPLETION WELL: 11-10 09/05/85 LAST WORKOVER PERMIT No:'1851590 09/05/09 D14 RWO AR No: 50-029-21394-00 09/06/09 SV DRLG HO CORRECTIONS SEC 28,T11N,R15E, 1038'FSL&352'FEL 03/08/10 MIJMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) (.----:OF T�j��1//7 ,v THE STATE Alaska Oil and Gas s�—'A of Conservation Commission ALAS 111. t;t_ 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 . Main: 907.279.1433 (7,14Z--A.,- ALAS' Fax 907.276.7542 www.aogcc.alaska.gov ,SGNNN° John McMullen 5b Engineering Team Leader g BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-10 Sundry Number: 315-546 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A , p)„.„....„& Cathy ''. Foerster Chair DATED this'ay of September, 2015 RBDMN SEP 0 9 201 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMP. DN • APPLICATION FOR SUNDRY APPROVALS . 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 4P 3./S Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redd! E " Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name' BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 185-159 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612Stratigraphic 0 Service WI• 6. API Number: 50-029-21394-00-00 • 7. If perforating' 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? YesNo Will planned perforations require a spacing exception? 0 PBU 11-10 •' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: �( ADL 028325&028322 • PRUDHOE BAY,PRUDHOE OIL • SEP 0 2 2015 11. PRESENT WELL CONDITION SUMMARY °► Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): JuaArO5GCC 11555 . 8825 • 11505 8784 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 -111 31 -111 1490 470 Surface 2491 13-3/8" 30-2521 30-2521 3450/4930 1950/2670 Intermediate 10889 9-5/8" 29-10918 29-8309 6870 4760 Production Liner 859 7"29#L-80 10691 -11550 8131 -8821 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11414-11450 8710-8739 4-1/2",12.6#x 5-1/2"17# L-80 26-10747 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10437/7935 4-1/2"BOT HB Packer 10642/8092 12.Attachments: Description Summary of Proposal IZI 13.Well Class after proposed work: BOP Sketch Q Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service Il. 14.Estimated Date for Commencing Operations: September 10,2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended I21• 16.Verbal Approval: Date: WIND 0 GINJ 0 WAG 0 Abandoned o Commission Representative' Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tempel,Troy Email Troy.Tempel@bp.com Printed Name John McMullen Title Engineering Team Lead Signature O C4tOP2/a Phone +1 907 564 4711 Date 9/2/i 5 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 10/- Mechanical Integrity Test 0 Location Clearance 0 Other: (3D/' .;'-e-5 t" fio 5 3 1'c p 51 (iv2 ASp 15 2.44-0 psi 1 � fl-rinlarpre- te55c,r5t Fa 2_5c1)5 , 7} l fit r rt or±c p 1L-7 p 10,«/ t h l a.pp%-o lir-d tomer a 0 ,�fFc Z-7, I ) Z �� Spacing Exception Required? Yes 0 No If/ Subsequent Form Required: /e, 467- APPROVED l_Q7- APPROVED BYTHE Approved by: r .vJ COMMISSIONER COMMISSION Date:9 .ls I 1 q./6 /15— RBDMS� SEP 0 � WI ����� oRIGINAL b Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. • To: Alaska Oil & Gas Conservation Commission *• byFrom: Troy Tempel CTD Engineer Date: September 3, 2015 Re: 11-10A Sundry Approval Sundry approval is requested to plug the 11-10 perforations as part of the drilling and completion of proposed 11-10A coiled tubing sidetrack. -. History and current status: 11-10 was drilled and completed in July 1985 as a sea water injector. In January 2006 the well was shut in due to a failed MIT-IA and MIT-OA. The well was repaired in September 2009 with a RWO tubing swap however the well was never returned online until November 2011 due to water injection line replacements.The well was shut in and fluid packed in May 2014 to attempt to bring more gas into DS11. Proposed plan: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around October 22, 2015. The 11-10A sidetrack will exit the existing 7" liner and kickoff in the Ivishak 4A sand and land in the Ivishak 1A sand. The sidetrack will be completed with a 3-1/2"x 3-1/4"x 2-7/8" liner and cemented in place. 11-10A will provide support to new producer 11-32A and existing producers 04-18, 11-09A, 11-23A, and 11-27. This Sundry covers isolating the existing 11-10 perforations via the 11-10A primary liner cement job and a liner top packer if the liner lap pressure ✓ test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. . n ��,�', - roe cvtre'r well h ,,o /110re, Goo, cop, T e ��9� o a„, ,S be/.s fi �uJe i c/'e/ ro qr 11 tw 4ciotrir"moi q/ 400/1 to be Swop t •� �' Pre-Rig Work(scheduled to begin September 10th,2015) 1. E Mill XN Nipple to 3.80" ID 2. E Set 7" Posi-Set plug 3. E Dump bail 20 gallons cement on top of plug 4. E Set 4-1/2" x 7" Baker Delta Whipstock Assist E-Line load and kill well 5. F Pressure test cement plug (MIT-T) 6. V Pre-CTD tree work.Set TWC if and only if MIT-T fails 7. 0 Remove wellhouse and level pad Rig Work(scheduled to begin October 22,2015) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high (MASP 2,440 psi) 2. PuII TWC 3. Mill 4-1/4" window and 10' rathole 4. Drill Build:4-1/4" OH, 380' (30 DLS planned) 5. Drill Lateral: 4-1/2" OH, 2060' (12 DLS planned) 6. Run 3-1/4" L-80 liner(TOL "10,556' MD) 7. Cement Liner: 29 bbls, 15.8 ppg(TOC to TOL) * 8. Perform liner cleanout and GR/CCL log 9. Pressure test 3-1/4" liner lap 10. Perforate 3-1/4" liner 11. Run to TD with nozzle and displace wellbore to clean fluids 12. Freeze protect wellbore to 2,500' MD 13. RDMO Post-Rig Work 1. 0 Re-install wellhouse,flow line 2. S Set liner top packer if needed * *Approved alternative plug placement per 20 AAC 25.112 (i) Troy Tempel CTD Engineer 907-570-1351 CC: Well File Joe Lastufka TREE= CM/ S Y NOTES:***PWI ONLY/NO MI INJECTION WELLHEAD' MCEVOY A, NED***CHROME NIPPLES*** 11 -10 ACTUATOR= BAKER C KB.ELEV= 58' BF.ELEV= 1 KOP= . . .. 3500' ,4 20752093'' I-:551/88,' — HESBKRESECPCEMENTER Max Angle= 59°@ 8100' ,(iDatum MD= 11595' 0� Datum TVD= 8800'SS !4 0 9-5/8"BKR BOWEN CSG PATCH — 2113' 9-5/8"CSG,47#,L-80 HYD 563,ID=8.681" -i 2117' X ' , 2233' I—4-1/2"HES X NIP(9-CR),ID=3.813" 13-3/8"CSG,68#,K-55/72#,L-80,ID=12.347" —I 2523' , ' ' 10409' —4-1/2"HES X NIP(9-CR),ID=3.813" Minimum ID = 3.725" @ 10546' „ \ 10440' —19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" 4-1/2" HES XN NIPPLE J� ■ 10474' —14-1/2"HES X NIP(9-CR),ID=3.813" 10546' —14-1/2"HES XN NIP(9-CR), ID=3.725" 4-1/2"TBG, 12.64,L-80 TCII, 10557' .0152 bpf,ID=3.958" . ` — L 10596' —9-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG STUB(08/28/09) 10579' 1 10626' —I5-1/2"BKR PBR ASSY J 5-1/2"TBG-PC, 174,L-80, —I 10638' IL I 10638' —I5-1/2"X 4-1/2"XO, ID=3.958" .0232 bpf, ID=4.892" 10642' —9-5/8"X 4-1/2"BOT HB PKR TOP OF 7"LNR —I 10684' 10734' I—4-1/2"CAMCO DB NIP, ID=3.813" 10746' —I4-1/2"BOT SHEAROUT SUB 4-1/2"TBG-PC, 12.6#,L-80, 10747' 10747' —14-1/2"TUBING TAIL,ID 3.958" .0152 bpf,ID=3.958" 10732' —1 ELMD TT LOGGED 05/02/86 9-5/8"CSG,47#,L-80, ID=8.681" — 10916' L PERFORATION SUMMARY REF LOG:BHCS ON 07/26/85 I ANGLE AT TOP PERF:35°@ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 6 11414-11450 O 04/07/86 3-3/8" 1 11414-11432 0 07/24/89 3-3/8" 4 11432-11450 0 07/24/89 I PBTD — 11505' 11111111 1111111 11111111 7"LNR,29#,L-80,.0371 bpf,ID=6.184" —I 11546' 1111/1/1/111111 111111111111111 TD -I 11555' 1*1�1�1�1�10 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/85 ORIGINAL COMPLETION WELL: 11-10 09/05/85 LAST WORKOVER PERMIT No:'1851590 09/05/09 D14 RWO API No: 50-029-21394-00 09/06/09 SV DRLG HO CORRECTIONS SEC 28,T11 N,R15E, 1038'FSL&352'FEL 03/08/10 MN/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) TREE= CNV S Y NOTES:***PWI ONLY/NO MI INJECTION 1NELLI-EAD= MCEVOY 11 -10 A i AL__NED***CHROME NIPPLES*** ACTUATOR= BAKER Proposed CTD KB.E.EV= 58' BF.ELEV= I ,4 11 Max Angle= 59° 8100' ,�� i • 2075' H 9-5/8"HES ES CEMENTER 1 Datum MD= @11595' •.4 �' 2093' 9-5/8"BKR ECP Datum 1VD= 8800'SS C1 11 • 9-5/8"BKR BOWBV CSG PATCH H 2113' i • 1 9-5/8"CSG,47#,L-80 HYD 563, D=8.681" —1 2117' I 2233' —14-1/2"HES X NP(9-CR),U=3.813" 13-3/8"CSG,68#,K-55/72#,L-80,D=12.347" —1 2523' I , 10409' —14-1/2"HES X NP(9-CR),U=3.813" 10440' H 9-5/8"X 4-1/2"BKR S-3 PKR,U=3.875" Minimum ID = 3.725" @ 10546' 4-1/2" HES XN NIPPLE 10474' H4-1/2"HES XNP(9-CR),D=3.813" I 10546' —14-1/2"HES XN NP(9-CR),D=3.725" op of 3-1/2"x 3-1/4"x 2-7/8"Liner — .-.10556' I I' LL XN TO 3.80" 10556' -1_1_3.-710/2"../3:4-112.. OY SLEEVED 3.00" 4-1/2"TBG, 12.6#,L-80 TCII, 10557' 0152 bpf,ID=3.958" . XXXX' H3-1/2" =2.813"5-1/2"TBG STUB(08/28/09) 10579' 10596' H9-5/8" UNIQUE OVERSHOT10626' H5-1/2" ASSY5-1/2"TBG-PC,17#,L-80, -I 10638' J.0232 bpf,D=4.892" il 10638' 5 XO,D=3.958" 111 10642' H 9-5/8"X 4-1/2"BOT HB R<R :1111 i! TOP OF 7"LNR 10684' . j ■ k i►1 10734' H4-1/2"CA MCO DB NP,ID=3.813" H i1 0 10746' --I4-1/2"BOT SHEAROUTSUB 4-1/2"TBG-PC, 12.64,L-80, 10747' r R . 10747' H4-1/2"TUBING TA L,U 3.958" .0152 bpf, D=3.958" '�1 ,4., 10732' H ELMD TT LOGGED 05/02/86 1 1. 11, i11 —109 '' H I/2"LNR,9.2#, 9-5/8"CSG,47#,L-80,U=8.681" 10916' 4i01 .,111 .,a` .4. 37°INC @ Window 4-1/2"x 7"Baker Delta Whipstock - 10960' NIkat,,,,, 4p,,,Aka,. !. —11800' —IRA Tag .' '. .. • ♦ % •` 3 bbls cement — 11220' �+ a 7"Posi-Set Rug -I 11300' ' PERFORATION SUMMARY I '.."A:... 4' REF LOG:BHCS ON 07/26/85 ♦N`Soo 7 ANGLE AT TOP PERF:35"@ 11414' I .„,,, ��� Note:Refer to Production DB for historical pert data `A SIZE SPF INTERVAL Opn/Sqz DATE I •� 3-3/8" 6 11414-11450 0 04/07/86N.'�` 3-3/8" 1 11414-11432 0 07/24/89 11111111 11111111 3-3/8" 4 11432-11450 0 07/24/89 1111111111111111 `:N.'�N N. 111111111111111 s-1/4"LNR,6.6#,L-80,TC-II I— —13340' `•. ♦ J FBT11D 11505' 11 11111111111 D 00079 bpf, =2.850" N. 4- .1.0..1 7"LNR,29#,L-80, .0371 bpf,D=6.184" —{ 11546' 2-7/8"LNR,6.5#,L-80,STL —I 13420' `' TD H 11555' 0.0058 bpf,13=2.441" DATE REV BY COMMENTS DATE REV BY COIV ENTS PRUDHOE BAY UNIT 07/31/85 ORIGINAL COMPLETION WELL: 11-10 09/05/85_ LAST WORKOV B2 PERMIT No:r1851590 09/05/09 D14 RWO AR Nb: 50-029-21394-00 09/06/09 SV DRLG HO CORRECTIONS SEC 28,T11 N,R15E, 1038'FSL&352'FEL 03/08/10 MN/JMD DRLG DRAFT CORRECTIONS 08/25/15 TT CTD Proposal BP Exploration(Alaska) 1 1 tio. I 1 i I 1 1 1 yj = U ,e; Y hIMI \ • • I E s °x U i U i. 1 \_ I IR 1 • ... .'. /41 .... •I. :4. I. ! • I . 1 1 * : . I 1 • �i� 1 am— A 1 � I i%g il Mill S iN I as N 1 14I I I Q r ►`, 1 g 1 d a • 1 , 1 o U ,1.- • II• ..� �,• OA O I I LL �� I N. I Z ` C‘ 1 M.. 1I Z I 1 U . I 0 I If I I A ' I 1 awi,e,sne s.o _ .. li U a - - 10\ I ; R 1 cL 1E1111 W o1: •. •• I• Y Zy \ II I Ce ; mN I I?'D MI 9il 1 w ~ � ,a i I 1. . UU Z v _ 1 1 N m s 'x = i V \ I Zf�. •,'e d. z i i n e • -- 3 i g-' , ` u I. V = ',1 = M� I'Ft w 1 Q oo LE. I I s .•••=.% R • 1 Ce O o I� I U I 1 Z F N � I 5 Ilk I -i u 1 Ell =3 i2 LT 3 o U v 1 •E� a �; K 1 'z G I . L e I f UIU I I s 1� 1 l ••I ■f o I. Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible _ 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" / boxes are also checked, cross out that erroneous entry and initial it on both I/ copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on / both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then (/ check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states"Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Roby, David S (DOA) From: Tempel, Troy <Troy.Tempel@bp.com> Sent: Thursday, September 03, 2015 4:11 PM To: Roby, David S (DOA) Subject: RE:Sundry application to plug PBU 11-10 (PTD 185-159) for redrill Dave, The proposed 11-10A injector will sweep 1A remaining lvishak oil south of the current 11-10 location.The current injector has been unable to get water into the 1A due to a channel behind pipe and has a failed squeeze attempt.The well is currently shut in for reservoir management purposes as 2A injection is not wanted and has no additional value. Thanks Dave, Troy T. Tempel CTD Engineer BP Exploration,Alaska Mobile:907-570-1351 Home:406-207-0766 Troy.Tempel@bp.com From: Roby, David S(DOA) [mailto:dave.roby(&alaska.gov] Sent: Thursday, September 03, 2015 3:49 PM To: Tempel,Troy Subject: Sundry application to plug PBU 11-10(PTD 185-159)for redrill Troy, I'm reviewing the above referenced well and was wondering why this well is being proposed for sidetrack? Is it that injection support at the current location is no longer needed? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 i ge Project Well History File' Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: o Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~ OVERSIZED (Non-Scannable) [] Other: ' ~O'-:, Logs of various kinds NOTES: [3 Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: Is/ Scanning Preparation BY; "~ x 30 = '~O + ~ I BEVERLY BREN VINCENT SHERYL~LOWELL Production Scanning Stage ~! PAGE COUNT FROM SCANNED F,LE: '11' Stage 2 BY[ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIREO ON AN INDiVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES} PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,/~ YES NO IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned Iindividual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd ain.ii.1: 4 .< :snn STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AO GCC 1. Operations Abandon U Repair Well U Plug Perforations (J Perforate U • Other L] Bright Water Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: , BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 185 -159 -0 - 3. Address: P.O. Box 196612 Stratigraphic❑ • Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21394 -00 -00 , 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028322 PBU 11 -10 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL ' 11. Present Well Condition Summary: Total Depth measured 11555 feet • Plugs measured None feet true vertical 8825.46 feet Junk measured None feet Effective Depth measured 11505 feet Packer measured See Attachment feet true vertical 8784.4 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 31 - 111 31 - 111 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10890 9 -5/8" 47# L -80 26 - 10916 26 - 8307.86 6870 4760 Liner 859 7" 29# L -80 10687 - 11546 8127.47 - 8818.07 8160 7020 Perforation depth Measured depth 11414 - 11432 feet 11432 - 11450 feet True Vertical depth 8709.78 - 8724.52 feet 8724.52 - 8739.27 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): t�€ +� Treatment descriptions including volumes used and final pressure: SCANNED JUN 1 8 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 2032 15222 0 0 1980 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 111 • Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil [J Gas U WDSPL[J GSTOR ❑ WINJ o . WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays( Printed Name Nita Summerhay Title Petrotechnical Data Technician / e./ Signatur J , / Phone 564 -4035 Date 5/21/2013 6 Lt �� o3 RBDMS MAY 2 3 2013 Form 10 -404 Revised 10/2012 , ‘4i Submit Original Only • • Daily Report of Well Operations ADL0028322 from 4/28/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 13,000 bwpd. Pumped 1056.5 gal. EC9360A (surfactant). Average of 68 gph for 16 Hours. Pumped a total of 1056.5 gal. since start of project. Pumped 5366.5 gal. EC9398A (polymer) Average of 350 gph for 15 Hours. Pumped a total of 5366.5 gal. since start of project. ** Establishing rates with proving pots ** ** *WSR continued on 4/30/13 * ** 4/29/2013 from 4/29/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 13,000 bwpd. Pumped 1561.5 gal. EC9360A (surfactant). Average of 65 gph for 24 Hours. Pumped a total of 2618 gal. since start of project. Pumped 7939 gal. EC9398A (polymer) Average of 331 gph for 24 Hours. Pumped a total of 13305.5 gal. since start of project. * *Establishing rates with proving pots ** 4/30/2013 ** *WSR continued on 5/1/13 * ** T /I /O = 960/20/0 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 4/30/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 13,000 bwpd. Pumped 1607 gal. EC9360A (surfactant). Average of 67 gph for 24 Hours. Pumped a total of 4225 gal. since start of project. Pumped 8035 gal. EC9398A (polymer) Average of 334.8 gph for 24 Hours. Pumped a total of 21340.5 gal. since start of project. * *Establishing rates with proving pots ** 5/1/2013 * ** WSR continued on 5/2/13 * ** • • Daily Report of Well Operations ADL0028322 T /I /O = 960/20/0 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/1/13 * ** Pumping brightwater chemicals down TBG while on water injection © 13,000 bwpd. Pumped 302 gal. EC9360A (surfactant). Average of 67 gph for 4.5 Hours. Pumped a total of 4527 gal. since start of project. Pumped 1158 gal. EC9398A (polymer) Average of 316 gph for 3.66 Hours. Pumped a total of 22498.5 gal. since start of project. * *Establishing rates with proving pots * ** Rig Down Move On to next Bright Water Treatment on 11 -07 Well on Inj. @ 13,000 bwpd SV = closed, WV, SSV, MV = open, IA and OA = OTG FWHP's= 929/20/40 5/2/2013 FLUIDS PUMPED GAL 4527.5 EC9360A (SURFACTANT) 22499 EC9398A (POLYMER) 27026.5 TOTAL Casing / Tubing Attachment ADL0028322 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 31 - 111 31 - 111 1490 470 LINER 859 7" 29# L -80 10687 - 11546 8127.47 - 8818.07 8160 7020 PRODUCTION 10890 9 -5/8" 47# L -80 26 - 10916 26 - 8307.86 6870 4760 SURFACE 42 13 -3/8" 68# K -55 30 - 72 30 - 72 3450 1950 SURFACE 2451 13 -3/8" 72# L -80 72 - 2523 72 - 2522.74 4930 2670 TUBING 10571 4 -1/2" 12.6# L -80 25 - 10596 25 - 8056.78 8430 7500 TUBING 42 5 -1/2" 17# L -80 10596 - 10638 8056.78 - 8089.33 7740 6280 • TUBING 109 4 -1/2" 12.6# L -80 10638 - 10747 8089.33 - 8174.4 8430 7500 • • • Packers and SSV's Attachment ADL0028322 SW Name Type MD TVD Depscription 11 -10 PACKER 10440 7879.17 4 -1/2" Baker S -3 Perm Packer 11 -10 PACKER 10642 8034.44 4 -1/2" BOT Perm Packer I WEL - CNV III S NOTES: *** PWI ONLY /NO MI INJECTION WELLHEAD = MCEVOY 1 • 1 1 0 AL ED***CHROMENIPPLES*** ACTUATOR = BAKER C KB. ELEV = 58 BF. ELEV = I f-1 Max Angle = 59° @ 8500' 2075' (— I9 -5/8" HES ES CEMENTER Datum MD = 11595' 2093' 19 -5/8" BKR ECP I Datum TVD = 8800' SS I9 -5/8" BKR BOWEN CSG PATCH H 2113' 19 -5/8" CSG, 47 #, L -80 HYD 563, ID = 8.681" H 2117' (—Ps 2233 4 -1/2" HES X NIP (9 -CR), ID = 3.813" 1 I L I 13 -3/8" CSG, 68 #, K -55/ 72 #, L -80, ID = 12.347" I—I 2523' HA I 10409' H4 -1/2" HES X NIP (9-CR), ID= 3.813" I Minimum ID = 3.725" @ 10546' p 10440' I�9 5/8" X4 -1/2" BKRS -3 PKR, ID= 3.875" I 4-1/2" HES XN NIPPLE /� 10474' H4-1/2" HES X NIP (9-CR), ID = 3.813" I ■ r 10546' 1-14 -1/2" HES XN NIP (9 -CR), ID = 3.725" I 4 -1/2" TBG, 12.6 #, L -80 TCII, 10557' I f .0152 bpf, ID = 3.958" � I 10596' H9 -5/8" X 5 -1/2" UNIQUE OVERSHOT I 15-1/2" TBG STUB (08/28/09) I 10579' 1 I 10626' 1-15-1/2" BKR PBR ASSY I 5 -1/2" TBG -PC, 17 #, L -80, —1 10638' I I I I 10638' 1H5 -1/2" X 4 -1/2" XO, ID = 3.958" .0232 bpf, ID = 4.892" 10642' H9-5/8" X 4-1/2" BOT HB PKR I 'TOP OF 7" LNR h 10684' I H I 10734' 1-14-1/2" CAMCO DB NIP, ID = 3.813" I 10746' I -1 4 -1/2" BOT SHEAROUT SUB I 4 -1/2" TBG PC, 12.6 #, L -80, 10747' I 10747' H4 -1/2" TUBING TAIL, ID 3.958" I .0152 bpf, ID = 3.958" I 10732' IH ELMD TT LOGGED 05/02/86 I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10916' I A • PERFORATION SUMMARY REF LOG: BHCS ON 07/26/85 ANGLE AT TOP PERF: 35° @ 11414' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/ Sqz DATE I 3 -3/8" 6 11414 - 11450 0 04/07/86 3 -3/8" 1 11414 - 11432 0 07/24/89 3 -3/8" 4 11432 - 11450 0 07/24/89 I I PBTD H 11505' r ► * 1�������� 01 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I-1 11546' 1 .1 I TD I—I 11555' .0.0:0.1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/85 ORIGINAL COMPLETION WELL: 11 -10 09/05/85 LAST WORKOVER PERMIT No: 1851590 09/05/09 D14 RWO API No: 50- 029 - 21394 -00 09/06/09 SV DRLG HO CORRECTIONS SEC 28, T11 N, R15E, 1038' FSL & 352' FEL 03/08/10 MN/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) ii • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6 C2,1 VZ- bt DATE: Tuesday, December 13, 2011 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 11 -10 FROM: John Crisp PRUDHOE BAY UNIT 11 -10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 11 -10 API Well Number: 50- 029 - 21394 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr1 1 1 125084704 Permit Number: 185 -159 -0 Inspection Date: 11/23/2011 Rel Insp Num: Packet- Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11 -10 Type Inj. W - TVD 7936 - IA 440 2415. 2389 2379 P.T.D 1851590 ' TypeTest SPT Test psi 1984 OA 27 20 20 21 Interval INITAL P /F, P Tubing 265 267 262 262 Notes: 4.6 bbls pumped for test. Post RWO. &MAW FEB 6 2012 Tuesday, December 13, 2011 Page 1 of 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ED JAN 2 4 2011 December 21, 2010 Mr. Tom Maunder AN 0 3 hi' Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 0,-,• N #' i !' 'Consa ,. 4sion Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 11 ( 86' 57 Dear Mr. Maunder, 11 /0 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 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, Torin Roschinger 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) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 11 - 01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11-05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 - 06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 - 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11-31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job 7f NQ. 5378 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color rn MPJ-19A 8581-00020 USIT ~ W-25A AXBD-00063 MEM LDL 12/19!09 1 1 W-25A AXED-00061 MEM PROD PROFILE 12/14/09 1 1 07-26 BALL-00007 RST _ 12/14/09 1 1 X-10 BALL-00001 PRODUCTION PROFILE 12/08/09 1 1 X-13A BALL-00002 PRODUCTION PROFILE 11/30/09 1 1 GC-2E 85JN-00027 PRESS/TEMP SURVEY 12/02/09 1 1 B-16A AZCM-00049 GLS 12/08/09 1 1 W-25A AWY2-00004 MEM DDL ~ _ 12/04/09 1 1 Z-16 85JN-00029 PRODUCTION PROFILE 12/08/09 1 1 X-32 BSJN-00024 PRODUCTION PROFILE 12/10/09 1 1 X-25 AYKP-00058 PRODUCTION PROFILE 12/04/09 1 y L-210 62NJ-00043 MEM INJECTION PROFILE 11/29!09 1 1 5-218 09AKA0176 OH MWD/LWD EDIT L 12/01/09 1 / 1 1 L-222 09AKA0148 OH MWD/LWD EDIT 0 12/09 2 1 2-D8/K-16 AZCM-00046 RST 11/03/09 2 1 11-10 AP30-00066 _ ~ RST 10!31/09 1 y - _ 11!01/09 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH Tn: ... ~~r,..,a,~.,~~ tniaana) inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ,. 1~~)~~ `f ~ tl; ~~ t Ut „ _..,~ ;t;.,, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~4~~ ~E~ 1 ~ 2(~l • • C~ f 10/08/01) Scbfumberpr NO. 5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 s� A A nchorag e , AK 99503 -2838 �� (� 4 ; j- ' Alaska Oil t ine Mahnken Gas Cons Comm T- t_ Attn: Christ 333 West 71h Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE 01/25/07 1 1-4 -03 AY1M -00032 PRODUCTION PROFILE 09/09/09 1 1-5 -05 AP30 -00061 PRODUCTION PROFILE 09/15/09 1 03 -24A AZCM -00042 LDL 09/14109 1 07 -32B BOCV -00027 JEWELRY LOG/GRW/PRESS/TEMP 15/09 1 W -214 AYS4 -00095 INJECTION PROFILE 09/12/09 1 04 -26 85JN -00014 PRODUCTION PROFILE / 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE - 09117/09 1 . W -04 B81(5 -00003 PRODUCTION PROFILE — 09/24/09 1 P2 -53 AP30.00060 PRODUCTION PROFILE 09/13/09 1 S-43 AWLB -00037 PRODUCTION PROFILE 09/25/09 1 12 -23 AWLS -00035 INJECTION PROFILE 09/19/09 1 05 -38 AYTO -00029 LDL - 09/18/09 1 W -29 AWJI.00050 MEM INJECTION PROFILE 09/20/09 1 W -30 AY1M -00034 PLUGBACK W/X -FLOW CHECK 09/12/09 1 3- 371L -35 B3S0 -00024 PRODUCTION PROFILE 09/16/09 1 NK -09 AP30 -00057 USIT ' — 09/07/09 1 W -07A AWJI -00047 MEM CEMENT EVAL ATION 09/07/09 1 11 -10 AYTU -00054 USIT 08/28!09 1 02 -06B ANHY -00111 USIT 09/21/09 1 G -18A AWJW048 MEM CEMENT BOND LOG C 09/17/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99S03 -2838 �2 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPO OF SUNDRY WELL OPE~IONS qy ~ ~~ . ~ . ~ a~ ~.x.i i+:~~ 1. Operations Performed: ` ° ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Wetl' ~ 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 185-159 / 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21394-00-00 / 7. Property Designation: 8. Well Name and Number: ADL 028322 ~ PBU 11-10 ' 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool / 10. Present well condition summary Total depth: measured 11555' / feet true vertical gg25~ feet Plugs (measured) 10734' Effective depth: measured 11505' feet Junk (measured) None true vertical 87g4~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2523' 13-3/8" 2523' 2523' 3450 1950 tntermediate 10916' 9-5/8" 10916' 8308' 6870 4760 Production Liner g62' 7" 10684' - 11546' 8125' - 8818' 7240 5410 ', ` : - r.~= ; ~~ 4 ~ ti:.. ~ . r PerForation Depth: Measured Depth: 11414' - 11450' '~; ~ True Vertical Depth: 8710' - 8739' Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# x 4-1/2", 12.6# L-80 10747' 8174' Packers and SSSV (type, measured and true vertical depth): g_5/8" X 4-1/2" BKR S-3 Packer ~ 10440' 7937' 9-5/8" x 4-1/2" Baker'HB' Packer ~~-ury~1 10642' 8092' 11. Stimulation or cement squeeze summary: Intervals treated (measured): jreatment description including volumes used and final pressure: Cut and pull tubing from 10579'. Cut and pull 9-5/8" casing from 2117'. Run 9-5/8" (47#, L-80, BTC) tieback to surface. Cement w/ 134 bbls Class 'G' w/ Gas-Blok (752 cu ft/ 648 sx). Clean out and run new tubing. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 14• Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily RepoR of Well Operations ~ Well Schematic Diagram 15. Well Status after wo~lc: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ~ WINJ ^ SPLUG 16. 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 Mehrdad Nadem, 564-5941 309-175 ~ Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. Sig ture Phone 564-5743 Date '' ,~ Sondra Stewman, 564-4750 Form 10-404 Revised 07/2009 ~~.~~ ~~4;~ ~°~' ~.,~ ~ Submit Original Only << ~ ~=~ ~~~~l,s ,~5~„}7- /~ TREE=CNV 4 1/8" 5M WELLHEAD = Cameron ACTUATOR = AXELSON KB. ELEV _ 58r BF. ELEV - KOP _ 3500' Max Angle = 59 @ 8100' Datum MD = 11595' Datum ND = 8800' SS ~ ~~~ ~~ ~9-5/8" BKR {B{3WEl~7} GSG PATCH ~ 1_ 9-5(8" CSG, 47#, L-80, NYD-563. tD = 8.684° -C 13-3/8" CSG, 68#, K-55/ 72#, L-80, ID = 12.347" ~ Minimum ID = 3.725 @ 10546' 4-1/2" HES XN NIPPLE 5-1/2" TBG STUB (08/28/09) - 4-112" TBG, 12.6#, ~-80, TCII, .0152bpf, ID = 3.958„ 5-1/2" TBG-f'C, 17#, L-80, .0232 bpf, ID = 4.892" - 2°! 13~ 2'I 9 7' SAFET~TES: *** PWI ONLY/NO MI INJECTION ALLO " CHROMEJEWELRY*"" 2~75" --j 9-516" E5 CEMEI~TER ~ ~~~$` 9-51&" SKR ECP ~~~3` 4-112" HES X 1~tiP, {9CRj, ID = 3.8~3" ~0409' -- ~4-1I2" HES X NIP, {gGRi, !~ = 3.813" ~ ~ ~0 0' 9-518" x 4-1i2" BKR S-3 ~{R, ID = 3.875" '10474" 4-112" HES X~lIP {9CR): IC3 = 3_813" ~ i}~46' 4-1i2" H~S XN NIF (9CR}, IE~ = 3.725„ 10579' ~ ~~ d ~~ 10~ 638' ~ -- '{0~6~ 9-518'" x 5-9/2" Ut~IQllEC7VERSHC)T 10638~ I-'I 5-1 /2" X 4-1 /2" XO, ID = 3.958" 9-5/8" X 4-1/2" BOT HB PKR TOP OF 7" LNR ~--~ 10684~ 14-1/2" CAMCO DB NIP, ID = 3.813" I 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 10746~ --j4-1/2" BOT SHEAROUT SUB I 10747~ 10747~ 4-1/2" TUBING TRIL, ID 3.958" 10732~ ELMD TT LOGGED 05/02/86 I 10916' I PERFORATION SUMMARY REF LOG: BHCS ON 07/26/85 ANGLE AT TOP PERF: 35 @ 11414' Note: Refer to Production DB for historical perf data SiZE SPF fNTERVAL Opn/Sqz DATE 3-3/8" 6 11414 - 11450 Open 04/07/86 3-3/8" 1 11414 - 11432 Open 07/24/89 3-3l8" 4 11432 - 11450 Open 07/24/89 ~a~ 11505' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11546~ T~ 11555' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/85 ORIGINAL COMPLEI'ION 09/05/85 LAST WORKOVER 09/05/09 D14 RWO 09/06/09 SV DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 11-10i PERMIT No: # 1851590 API No: 50-029-21394-00 SEC 28, T11 N, R15E, 1504.74' FEL & 3866.59' FNL BP 6cploration (Alaska) ~ ~ PBU 11-10 Well History 05/19/09 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (FAIL), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely (.75"). Unable to pressure void above 3200 psi, bled to 1200 psi in 4 min. Torqued LDS to 600 Ib/ft. Still unable to pressure void above 3200 psi, bled to 1200 psi in 6 min (FAIL). Bled void to 0 psi. PPPOT-IC: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (.75"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 500 psi in 15 min. Re-torqued LDS to 600 Ib/ft. Pressured void to 3500 psi, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 05/21/09 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS). Re-test TBG hanger pre RWO. PPPOT-T: Stung into test port (0 psi). Pumped through void, clean returns. Torqued LDS (600 Ib/ft). Pressured void to 5000 psi (3 gal fluid), lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 06/22/09 PULLED P-PRONG FROM PLUG BODY C 10,708' SLM. PULLED DBP PLUG BODY @ 10 714' SLM/ 10734' MD. DRIFTED OUT TBG TAIL TO 10,800' SLM W/ 7' x 3.75" DMY DRIFT. 07/05/09 T/I/O = 50/40/60. Temp = SI. TBG & IA FL's (pre e-line). SW I. No wellhouse or flowline. 2" integrals installed on IA & OA. TBG FL C~1 258' (6 bbls). IA FL @ 270' (12 bbls). SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 07/05/09 RIG UP TO SET FASDRILL, MIT-T TO 2,000 PSI FOR SECURE (PRE-RWO) JET CUT WELL SHUT IN ON ARRIVAL INITIAL TIO: 115/0/100. 07/06/09 SET 4.5" HES FASDRILL PLUG AT 10740' (REFERENCED TO TUBING TALLY DATED 2-SEPT-1985) POSITIVE SURFACE INDICATION OF SETTING, CONFIRMED WHEN TOOL BROUGHT TO SURFACE. LRS ATTEMPT MITT. IA TRACKING TBG. CMIT-TXIA TO 2000 PSI PASSED. MV = C, SW = C, SSV = C. POSITIONS CONFIRMED WITH DSO. FINAL T/I/O = 150/0/575. 07/06/09 T/I/0=0/0/100 Temp= S/I Assist E-line; CMIT-T passed to 2000 psi (RWO prep) Pumped 26.9 bbls diesel down TBG to reach test pressure. TBG/IA lost 40/30 psi in 15 minutes and 10/10 psi in second 15 minutes for a total 30 minute loss of 50/40 psi. Bled TBG psi (12.5 bbls). After pressuring up for the test the OA came up 120 psi (600) with a 50/40 psi (2010/1960) loss on TBG/IA. Monitored static W HP's for 1 hr 17 minutes after the end of the test. OAP came up an additional 200 psi (800 psi) and the TBG/IAP dropped 20/40 psi (1990/1920). OAP continued to rise throughout monitor. '"'Tag hung and IA/ OA valves left open to gauges upon departure"" FW P's=0/120/580 08/12/09 INITIAL T/I/O: 0/0/100PSI ALL VALVES CLOSED. RIH 4.15" POWERCUTTER. CUT TUBING C 10586'. GOOD INDICATION AT SURFACE, DID NOT TAG TD. FINAL T/I/O: 0/0/100 08/13/09 T/I/0=0/80/100, Temp=Sl, Circ-Out, CMIT TxIA PASSED to 1000 psi (RWO Prep) Pressured up Tbg and IA with 13.3 bbls of crude to reach test pressure. Tbg/IA lost 30/20 psi in the 1 st 15 mins and 10/0 psi in the 2nd 15 mins for a total pressure loss of 30/20 psi in 30 min test. Circ'd well with 5 bbls 60/40 meth spear, 1085 bbls of seawater capped with 135 bbls of diesel pumping down Tbg taking returns through Tbe cut up IA to well 11-23's flowline. U-Tubed TxlA for freeze protect, allowed to U-tube for 1 hour. 08/14/09 Circ-Out, MITOA FAILED to 2000 psi (Pre RWO) U-Tubed diesel Tbg to IA for freeze protect, bleed W HP's to 0 psi. Pumped 2.6 bbis crude down OA to reach test pressure. OA lost 1000 psi in 15 mins, aborted MITOA. TxIA gained 480/480 psi during 15 min test. Bled WHP's 0 psi. FWHP's=0/0/0. SV, WV, SSV shut. MV, IA, OA Open. Page 1 of 2 ~ ~ PBU 11-10 Well History 08/14/09 T/I/O=Vac/0/0. Set 5-1/8" Gray K BPV thru tree, pre rig. 1-2' ext used, tagged C~ 104". No problems. Removed 3-1/8" McEvoy HWO Companion, installed 3-1/8" 5000# tapped blind. Removed tree scaffolding. 09/05/09 T/I/0=0+/0/0. Pull 4-1/16" CIW H TVVC thru tree, post tree test. Set 4-1/16" CIW H BPV #254 thru tree, rig move off well. - ext use , tagged C~1 100". 09/08/09 T/I/0=0+/300/0. Pull 4-1/16" CIW H BPV #254 thru tree, post riq. 1-2' ext used, tagged Q 100". No problems. 09/09/09 PULLED B&R AND 4 1/2" RHC PLUG BODY (intact) FROM 10,535' SLM. TAGGED SOFT BTM C~ 11,423' ELMD W/ TEL, 3.00" S.BLR (27' OF FILL). RAN 2.50" CENT, PETRADAT DUAL GAUGES AS PER PROGRAM. Page 2 of 2 ~ ~ BP EXPLC7RATION Page 1 of 1 a Operation5 Summary Report Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date Frorn - To Hc~urs Task Code NPT 8/24/2009 00:00 - 06:00 6.00 MOB P 06:00 - 12:00 6.00 MOB P 12:00 - 18:00 6.00 MOB P 18:00 - 00:00 6.00 MOB P 8/25/2009 00:00 - 12:00 12.00 MOB P 12:00 - 14:00 2.00 KILL P 14:00 - 16:00 2.00 KILL P 16:00 - 19:30 3.50 KILL P 19:30 - 23:00 3.50 KILL P 23:00 - 00:00 1.00 WHSUR P Start: 8/18/2009 End: 9/5/2009 Rig Release: 9/5/2009 Rig Number: Phase ` Deseription of Operations PRE Lay over the gas buster stack, unpin the windwall braces, tie back the derrick lines, de-mob the stabbing board winch. Place the top drive in the cradle, continue preparing to lower the derrick. PRE Lay over the derrick, skid the rig floor,and move the rig off of the well. Install the front boosters. PRE Laydown the side and back windwalls and lay over the derrick. Install the rear boosters and prepare to move the rig to DS 11-10i. PRE Move from DSO4-02a to DS11-10i, raise the derrick and windwalls. Skid the rig floor into moving position, install the windwall braces. Remove the rear boosters. PRE Spot the rig over well DS11-10i. Skid the rig floor into position, pull out the conveyor and spot the rockwasher. Spot the bleed tank in position. Rig spotted at 0200 hrs. Continue rigging up and preparing to get ready to accept the rig. Hardline crew hook up hard line to Tiger tank. Instail double IA valve. Hook up mud manifold and electrical loops. "'Rig accept_ed_ at 1200 hrs on 8-25-09"` DECOMP RU mud manifold and lines. -Install pump "T" on wing valve -Take on seawater into pits -RU to test with lubricator DECOMP PU lubricator. Test to 500 psi for 5 min - passed. -Pull BPV with DSM crew -LD lubricator DECOMP Test hardline with air and test with seawater to 3,500 psi - good. -RU injection lines to IA to take returns from tubing to Tiger tank -Reverse circulate with 65 bbls at 3 BPM / 250-380 psi, returns at 3 bbls away, circulated out diesei -Swap to circulate down tubing and take returns up IA -Circulate 165 bbis down tubing at 4 BPM / 300 psi, shut in and allow well to migrate for 30 min. Pump additional 50 bbls at 4 BPM. RU to take returns back to pits DECOMP Continue circulating down tubing, taking returns to pits at 4 BPM / 400 psi. Circulate surface to surface. Returned traces of crude and diese wit goo seawa er on ina circu a ion -Monitor well for 20 min. IA and tubing visibly static. OA increased to 210 psi during circulation -Blow down lines DECOMP Install lubricator with DSM. 8/26/2009 00:00 - 02:00 2.00 WHSUR P DECOMP Test TWC from below to 1,000 psi for 10 min - charted. Test TWC from above to 3.500 psi for 10 min - charted. -RD test equipment and suck out tree. -Bleed hanger void and terminate control lines 02:00 - 04:00 2.00 WHSUR P DECOMP ND tree and adapter flange. 04:00 - 10:00 6.0~ BOPSU P DECOMP NU BOPE. 10:00 - 00:00 14.00 BOPSU P DECOMP PJSM. Test BOP's, Choke & associated valves. ---BOP Configuration; Printetl: 9/14/2009 10:49:52 AM ~ ~ BP EXPLORAT~~N Page 2 of 10- Operations Summary Repor# Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: ' Date From - To Hc~urs Task Code NPT Phase ` Description of Operations 8/26/2009 10:00 - 00:00 14.00 BOPSU P DECOMP -Hydril GK 13-5/8" 5000. -3-1/2" x 6" Variables. -Blind Rams. -Mud cross. -2-7/8" x 5" Variables. ---Test: -Test Hydril with 4" test joint to 250 psi low / 3,500 psi high for 5 charted min each. -Test all components to 250 psi low / 4,000 psi high. Hold each test for 5 charted minutes. -Test Upper & ~ower IBOP. -Test 4" TIW and Dart valves. Test 4-1/2" TIW valve. -Test 2-7/8" x 5" VBR with 4" test joint. -Test 3-1/2" x 6" VBR with 4" and 5-1/2" test joints. -Blind rams -Test all valves with 4" test joint. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 and 14. -Test Choke / Kill manual and HCR valves. 8/27/2009 I 00:00 - 01:00 I 1.001 BOPSUR P 01:00 - 04:00 I 3.001 BOPSUR P 04:00 - 05:00 I 1.00 I PULL ~ P 05:00 - 06:00 ~ 1.00 ~ PULL ~ P 06:00 - 06:30 I 0.501 PULL I P -Blanking plug on "K" style TWC leaking by during Kili and Choke manual valve test, had to change out to complete test. -Unable to achieve a 250 psi low pressure on Choke Manual gate valve - failure. -At 20:00 hrs the rig mechanic repaired Choke Manual gate valve (1 hour to repair valve}. -Retested Choke Manual gate valve - passed. Complete Koomey draw down test. Note: 26 seconds for 200 psi build up - 2 min 44 seconds for full PSI - 4 bottles average 2200 psi. -Test witnessed by T.P. & WSL. -AOGCC rep Jeff Jones waived the state's right to witness BOPE test on 8/25/2009 at 08:00 hrs. DECOMP Blow down lines and drain stack. LD test joint and test equipment. DECOMP PU T-bar and dry rod out blanking plug from "K" valve with Cameron tech. -RU and install Dutch system. -MU lubricator to wellhead and PT to 500 psi - passed. -Pull BPV with DSM - TBG is static. -LD lubricator and Dutch system. DECOMP PUMU tandem spear with packer cup as per Baker fishing hand. DECOMP PJSM. BOLDS with Cameron tech. -Unable to enqaqe tubinq hanqer with tandem spear in both latch and release positions, set 10K down - unable to bury spear. -ist grapple engaged with only 3 teeth. -Confer with Day WSL and town RWO engineer. DECOMP Decision made with Anchorage Engineering to lay down the s ear assem an attem t to u wi e an in oin . spear assembly with Baker Fishing rep. PUMU Landing Joint and 5-7/8" RH Acme XO for top threads on the Hanger. MU Printed: 9/74/2009 10:49:52 AM ~ ~ _ __ ___ _ _ BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: ' Date From - To Haurs Task Code NPT Phase Deseription of Operations 8/27/2009 06:00 - 06:30 0.50 PULL P DECOMP with 19 turns to torque up. 06:30 - 07:30 1.00 PULL P DECOMP Steam the wellhead for 15 minutes prior to pulling the Hanger. Work the pipe up in small increments to attempt and pull the Hanger free. The Hanger and Completion came free at 255K on the weight indicator (--50K over string weig t in seawater and 50K for the blocks). Pull the Hanger to the floor with a PUW = 225K on the weight indicator. 07:30 - 09:30 2.00 PULL P DECOMP Terminate dual control lines with Schlumberger rep. PU Control Line Spooling Unit and Tubing Handling Equipment to the Rig Floor. RU Casing Tongs, Slips and Elevators and prepare the floor for POOH. RU floor safety valve for existing 5-1/2" completion. 09:30 - 10:30 1.00 PULL P DECOMP Break out and lay down Tubing Hanger. 10:30 - 11:30 1.00 PULL P DECOMP Circulate bottoms up with seawater at 10 bpm / 760 psi. 11:30 - 12:00 0.50 PULL P DECOMP POOH la in down 5-1/2", 17#, L-80, Srd Tubin and encapsulated dual control line. Maintain continuous hole_fill 12:00 - 12:30 I 0.501 PULL I P 12:30 - 22:00 I 9.501 PULL I P 22:00 - 23:00 1.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 8/28/2009 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:00 0.50 CLEAN P 01:00 - 03:00 2.00 CLEAN P 03:00 - 13:30 I 10.501 CLEAN I P 13:30 - 14:00 I 0.501 CLEAN I P 14:00 - 15:30 I 1.501 CLEAN I P 15:30 - 19:00 3.50 CLEAN P 19:00 - 21:30 2.50 CLEAN P 21:30 - 23:00 I 1.50 I EVAL I P DECOMP Pre-tour checks, set PVT and service the Rig. Perform Derrick and Top Drive inspections. DECOMP Continue POOH laying down existing 5-1/2" Completion and spooling up control line with Schlumberger rep. Maintain continuous hole fill with seawater while POOH. At 1430 hrs, RD and LD Spooling Unit. Recovered all of the dual encapsulated control line, 26 clamps and 4 bands (full recovery). Continue POOH. -Pulled a total of 245 joints of 5-1/2" tubing, 9 GLM's, 1 SSSV, and 1 cut joint (1023' OAL. 6.438" OD flairl DECOMP Clean and clear rig floor. LD casing equipment. DECOMP Mobilize Baker BHA. DECOMP Continue to mobilize BHA to rig floor. PU handling equipment. DECOMP Service top drive. Install wear ring. DECOMP MU BHA #1 5.5" tubin dress off / 9-5/8" sra er assem I (OAL = 228.62') to dress the top of the 5-1/2" Tubing Stump. DECOMP RIH with BHA. Single in hole 1x1 from pipe shed with 4", 14#, HT38 drillpipe. Work the 9-5/8" Scraper across the interval of 10,465' to 10,525' three times while RIH. DECOMP PU Joint #327 and establish parameters: PUW = 225K , SOW = 135K. PU Joint #328. Tag the top of the 5-1/2" Tubing Stum 26' in on Joint #327 = 10,578'. Pick up off of it and break circulation down the drill pipe at 5 bpm / 575 psi. Establish rotation with the Top Drive at 50 RPM, 10000 ft-Ibs free torque and RW = 165K. Wash over to 10,595' dressing the 5-1/2" Stum to 10,579' (1' deeper . DECOMP Mix 30 bbls hi-vis sweep and circulate down the drill pipe at 13 bpm / 2,700 psi. Circulated a total of 780 bbls until the sweep cieaned up. Swallow the Stump with no rotat+on and no circulation down to 13.5' in on Joint #328 = 10,595' which puts the 5-1/2" Stump at 10,579'. Repeated twice to confirm. DECOMP POOH with BHA #1 standing back 4" Drill Pipe in the Derrick. DECOMP Stand back 6 ea Drill Collars. LD BHA #1 as per Baker. Inspect inner mill and shoe. Empry metal shavings from boot basket. Clear rig floor. DECOMP PJSM. Spot E-line unit by beaver slide. RU E-line equipment Printed: 9/14/2009 10:49:52 AM ~ ~ BP EXPLORATiQN: Page 4 of ~ o Qperations Summary Repor# Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: Date' From - To Hours Task Code NPT Phase Qescription caf Operations 8/28/2009 21:30 - 23:00 1.50 EVAL P DECOMP and MU USIT tools (OAL = 41'). MU air line wiper. Barrier is tested FasDrill plug in tubing tail. 23:00 - 00:00 1.00 EVAL P DECOMP Log with USIT tool while RIH. 8/29/2009 00:00 - 03:00 3.00 EVAL P DECOMP Beqin logging with USIT tool from 3,877' to surface in cement detection mode. 03:00 - 04:00 1.00 EVAL P DECOMP RD E-line equipment. Confer with RWO engineer to review log. TOC = 2,188'. 04:00 - 06:00 2.00 CASE P DECOMP MU Halliburton RBP with retrieving head on 2 stands drill collars. RIH with 4" drillpipe. PUW = 90K, SOW = 90K. Set RBP at 2 220' center of element at 2,224') and release retrieving head from RBP. POOH two stands of drill pipe. 06:00 - 06:30 0.50 CASE P DECOMP Test the 9-5/8" RBP and Casinq to surface to 2,000 psi for 10 charted mins ~ood test. OA did not show any signs of 06:30 - 08:00 1.50 CASE P DECOMP communication. Dump 2 200# of 20/40 river sand on top of the RBP at 2.220'. Circulate a drillpipe volume to ensure we are not plugged up at 1.5 bpm / 40 psi. 08:00 - 09:30 1.50 CASE P DECOMP Slip and cut drilling line. Service and inspect top drive. 09:30 - 10:30 1.00 CASE P DECOMP POOH with 9-5/8" RBP Setting Tool standing back 4" drilipipe in the Derrick. 10:30 - 11:00 0.50 CASE P DECOMP Break out and lay down RBP Setting Tool Assembly with Halliburton rep. 11:00 - 11:30 0.50 CASE P DECOMP PUMU BHA #2 as follows: 825" Multi-string cutter, XO, 8.5" stabilizer, XO. OAL = 11.28'. 11:30 - 13:00 1.50 FISH P DECOMP TIH with BHA #2 on 4" drillpipe from the Derrick to cut the 9-5/8" Casing. 13:00 - 13:30 0.50 FISH P DECOMP PU stand #23 and establish parameters: PUW = 85K , SOW = 85K. Taq top of sand 60' in on stand #23 = 2,167'. Pick up hole and re-tag to confirm - OK. Pick up and break circulation at 5 bpm / 500 psi to extend the Knives on the Cutter Assembly. Locate the bottom casing collar at 40' in on stand #23 = 2,144'. Break out, stand back #23. Pick up a single joint of drilipipe. Locate the upper casing collar at 2' in on the single = 2,106'. RIH 10' and oark the BHA with the Knives at 2.116'. 13:30 - 14:00 0.50 FISH P DECOMP Spot, back up and RU Little Red Services to the cement line in preparation for Arctic Pack circulation. Pressure test to 2,500 psi - good test. 14:00 - 14:30 0.50 FISH P DECOMP Pre-job safety meeting with the crew, mud engineer and Little Red on Arctic Pack circ out. 14:30 - 15:00 0.50 FISH P DECOMP Establish cutting parameters: 50 RPM , RW = 85K. Break circulation to extend the Knives out at 7.5 bpm / 1,150 psi. Cut the 9-5/8" Casin with 5 000 ft-Ibs of tor ue. Good indicatio o~ the cut observed with the pressure falling off to 500 psi. No pressure response observed on the OA. Stay on the cutting for a couple of minutes to ensure good cut. Pick up and come back down with the Knives extended to verify the cut - OK. The 9-5/8" Casing is cut at 2,116'. The two barriers are 1) Fadrill at 10,740' ELMD and 2) 9-5/8" RBP at 2,224'. Pick up, close the bag and attempt to circulate up the 13-3/8" x 9-5/8" Annulus. Establish returns at 1.5 bpm / 230 psi and shut down ~ immediatel . 15:00 - 16:00 1.00 FISH P DECOMP Break circulation with Little Red Services down the drillpipe taking returns up the 4" x 9-5/8" Annulus at a rate of 2 bpm / Printed: 9/14/2009 10:49:52 AM ~ ~ BP E~PLURATI~N Page 5 of 1a: Operations Surnmary Report Legal Well Name: 11-i0 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Descriptiorr of Operatit~ns 8/29/2009 15:00 - 16:00 1.00 FISH P DECOMP 600 psi with 110 degF diesel. Pump 23 bbis away (drillpipe volume) and shut down. Close the Annular and open up the 13-5/8" x 9-5/8" Annulus to the slop tank. Resume circulating 110 degF diesel with Little Red. Pumped a total of 100 bbls of hot diesel. Come online with the rig pump at 3 bpm / 100 psi and displace the drillpipe with 23 bbls of 9.8 ppg brine placing all 100 bbls of hot diesel in the 13-5/8" x 9-5/8" Annulus. Diesel in place at 1610 hrs. 16:00 - 17:00 1.00 FISH P DECOMP Allow the diesel to soak in the 13-5/8" x 9-5/8" Annulus for one hour. 17:00 - 18:30 1.50 FISH P DECOMP Open the OA to the slop tank and circulate 250 bbls of 9.8 ppg brine down the drillpipe taking returns up the 13-3/8" x 9-5/8" Annulus at a rate of 7.7 bpm / 1,800 psi to displace the diesel. Pump a 30 bbl pill of Safe Surf O and displace it with 160 bbis of seawater. Good seawater returns from OA on final circulation. 18:30 - 19:30 1.00 FISH P DECOMP Shut in OA and open annular. CBU 2 times annulus volume, clean seawater on final circulation. Monitor well for 15 min, no flow - static. 19:30 - 20:30 1.00 FISH P DECOMP POH with 4" DP standing back in Derrick. 20:30 - 21;00 0.50 FISH P DECOMP LD BHA #2 as per Baker. Knife blades on cutter indicate good cut. Clean and clear rig floor. Pull wear ring. 21:00 - 21:30 0.50 CASE P DECOMP PJSM. Mobilize casing spear. MU BHA #3 - Casing Spear to 1 joint drillpipe and XO. MU to Yop drive. 21:30 - 22:30 1.00 CASE P DECOMP Monitor OA thru 2" - static. Engage casing with spear (with packer cup). BOLDS with Cameron rep. Pull casing free with 165K. Pull hanger thru stack, casing to floor is 138K. 22:30 - 23:00 0.50 CASE P DECOMP Out of balance. CBU at 7.5 BPM / 60 psi. Returns have crude traces. 23:00 - 00:00 1.00 CASE P DECOMP Release spear and break out top drive. LD spear and drillpipe single. Clean and clear rig floor. Prep floor to LD 9-5/8" casing. 8/30/2009 00:00 - 01:30 1.50 CASE P DECOMP MU top drive to casing. CBU at 14 BPM / 140 psi while reciprocating casing 60'. PUW and SOW = 137K. Circulated a total of 150 bbls, returns cleaned up on final circulation. 01:30 - 04:30 3.00 CASE P DECOMP POH lavinq down 9-5/8" casing, pump across top of hole while POH. Centrilizer on every 3rd casing joint. Pulled 51 joints of casing, 13 centrilizers and 1 cut joint (10.55' OAL, 10.875" OD) 04:30 - 06:00 1.50 CASE P DECOMP Clear rig floor. RD double stacks and casing equipment. 06:00 - 07:00 1.00 CLEAN P DECOMP Pick up BHA components to the rig floor. 07:00 - 07:30 0.50 WHSUR P DECOMP Install 12-1/4" ID Wear Ring . 07:30 - 09:00 1.50 CLEAN P DECOMP PUMU BHA #4 as follows: Dress Off Shoe, Washpipe Extension, Dress Off Mill, Washover Junk Basket, Double Pin Sub, 13-3/8" Casing Scraper, Bit Sub, 13-3/8" Brush, XO, Float Sub, Bumper Sub, XO, 6 ea 6-i/4" Drill Collars, XO, XO. OAL = 232.33'. 09:00 - 10:00 1.00 CLEAN P DECOMP TIH with BHA #4 on 4" drillpipe from the Derrick to dress the top of the 9-5/8" Casing Stump. 10:00 - 10:30 0.50 CLEAN P DECOMP Establish parameters: PUW = 96K, SOW = 96K. Tag top of the 9-5/8" Stum at 2,116'. Break circulation at 5 bp~ psi. Rotate at 50 RPM, RW = 96K with 5,000 ft-Ibs of torque. Dress off 6" er Baker Fishin re . Shut down pump and rotation and swallow over stump several times to ensure good Printed: 9/14/2009 10:49:52 AM ~ • Qperat Legal Well Name: 11-10 Common Well Name: 11-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 ~N~~~ Page 6 of 10' ~y Report Spud Date: 7/12/1985 Start: 8/18/2009 End: 9/5/2009 Rig Release: 9/5/2009 Rig Number: Dater I From - To ~ Hours I Task I Code I NPT ~ P'hase I' Description of Oper~tions 8/30/2009 10:00 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 15:00 0.50 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P DECOMP dress off - OK. DECOMP Pump a 30 bbl Safe Surf O Pill and circulate it surface to surface at a rate of 14 bpm / 800 psi. Rotate and reciprocate the pipe while circulating at 50 RPM with 1,000 ft-Ibs of torque. DECOMP POOH with BHA #4 standing back 4" drillpipe in the Derrick. DECOMP Pre-tour checks and service the Top Drive. DECOMP Resume POOH with BHA #3. DECOMP Break out and lay down BHA components with Baker rep. Steam and clean the brush prior to laying down. TIEB1 Rig up to run 9-5/8" Casing Tie-back. Pick up shoe track components, centralizers and cement head. Load ES Cementer closing plug into cement head with Halliburton rep and witnessed by WSL. TIEB1 Pull Wear Ring. TIEB1 Pre-job safety meeting with the crew, Baker Completion rep, Baker Fishing rep, Doyon Casing rep and Halliburton rep. TIE61 Pick up shoe track assembly consisting of: 9-5/8" Bowen Patch, XO, ECP, XO. Pick up ES Cementer with Halliburton rep and make up to shoe track assembly. Pick up 9-5/8" BTC (pin) x 9-5/8" Hydril 563 (box) XO Joint and make up to ES Cementer. Bakerlock'd both connections and made up to the mark. Placed one free floating centralizer on the XO Joint. TIEB1 RIH with 9-5/8" 47# L-80, H dril 563 Casin . Utilizing Jet Lube Seal Guard on ail connections. Place one free floating centralizer on each Joint as RIH. Torque Turning each connection to optimum torque of 15,800 ft-Ibs. Ran a total of 53 joints of casing and 53 straight vane centrilizers. Inspect and caliper last casing joint. TIEB1 Obtain parameters. PUW and SOW = 140K. MU space out pup. Engage casing stump per Baker at 2,116', took 10K weight to swallow 3' over stump to 2,119'. Slack off 50K and pull test to 30K over and continue to 250K (110K over PUW). TIEB1 Swap to long bails. MU cement head XO pup and Halliburton cement head with HES rep. RU test chart, connect cement lines to cement head. Clear rig floor of excess equipment. Pull casina to 240K and set brake (100K over PUW). `~ TIEB1 Test rig surface lines to 4,000 psi. Test 9-5/8" casing to 1,000 psi for 10 min, bleed to 0 psi. Stage casing pressure up in 300 psi increments to 1,600 psi, beqin to in late wit .__s_, 15:00 - 16:00 I 1.001 CASE I P 16:00 - 16:30 0.50 WHSUR P 16:30 - 17:00 0.50 CASE P 17:00 - 17:30 I 0.50I CASE I P 17:30 - 20:00 ~ 2.50 ~ CASE ~ P 20:00 - 20:30 I 0.50I CASE I P 20:30 - 22:00 I 1.50I CASE I P 22:00 - 22:30 ~ 0.50 ~ CASE ~ P allow acker to e ualize. Continue to build casing pressure to 2,100 psi and hold for 10 min. Bleed to 0 psi. Chart all tests. Witnessed by Baker completion hand and WSL. 22:30 - 23:30 1.00 CASE P TIE61 Pressure up casing with rig pump, shear ES cementer at 2,600 osi - charted. Break circulation at 5.5 BPM / 100 psi. Circulate 23:30 - 00:00 I 0.50I CEMT ~ P 8/31/2009 I00:00 - 01:00 I 1.00 I CEMT ~ P cementers. TIE61 PJSM. Complete cement truck stall tests, test SLB lines to 4,000 psi. Batch up first tub to weight of 15.8 ppg "G" cement with GasBLOK. TIE61 240K on hook. Start pumping cement at 23:52. Pump 154 bbis of class "G" 15.8 1.16 ft3/sk 726 sacks cement at 5 BPM / 100-150 psi. Cement pumped away at 00:21 hrs. Drop wiper plug at 00:23 (good sign), displace cement with seawater Printed: 9/14/2009 10:49:52 AM ~ • ' BP EXPLORATION' Operat Legal Well Name: 11-10 Common Well Name: 11-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date' From - To Hours Task Code=- Spud Date: 7/12/1985 Start: 8/18/2009 End: 9/5/2009 Rig Release: 9/5/2009 Rig Number: ~se Description of Operations 8/31/2009 00:00 - 01:00 1.00 CEMT P TIEB1 from cement truck at 7 BPM / 180 - 300 psi (caught cement 62 bbls into circulation). Divert pit returns to rockwasher 90 bbis into circulation. Continue displacing cement at 5 BPM / 550-900 psi. Contaminated cement returns seen at surface at 110 bbls into displacement with good cement returns to surface throughout displacement. Slow pumps to 1.5 BPM / 880 psi to bump plug - Bump Plug. Displaced cement with 153 bbls, Bump plug with 2,200 psi (1,320 psi over FCP per Halliburton). CIP at 00:56 hrs. Bleed off pressure, check floats - good. Returned 20 bbls of cement to rockwasher. 01:00 - 02:00 1.00 CEMT P TIEB1 Flush BOP stack and all surface lines with inhibited pill. LD cement head. 02:00 - 04:00 2.00 WHSUR P TIEB1 ND BOP stack from bottom of tubing spool. 04;00 - 04:30 0.50 WHSUR P TIEB1 Install E-sli s with Cameron rep in casing head bowl. S/O casing weight in slips. 04;30 - 05:30 1.00 WHSUR P TIEB1 RU WACHS cutter to casing joint. Cut casing and LD joint, 27.87' OAL. RD WACHS cutter. Left 12.58' 9-5/8" cut joint in wellhead. 05:30 - 06:30 1.00 WHSUR P TIEB1 ND tubing spool and set BOP stack in stand. 06:30 - 08:30 2.00 WHSUR P TIEBi NU new Tubin S ool and Packoff with Cameron re . RILDS. Energize and test new seal to 3,800 psi for 30 mins with Cameron rep - OK. 08:30 - 10:30 2.00 BOPSU P TIEB1 NU BOPE and Flow Riser. 10:30 - 12:00 1.50 BOPSU P TIEB1 RU Test Equipment. Set Test Plug. Pressure test body break on BOPE to 250 psi low and 4,000 psi high for 5 charted mins - good test. RD Test Equiment. 12:00 - 12:30 0.50 WHSUR P TIEB1 Pull Test Plug and set 12.5" ID Wear Ring. 12:30 - 13:00 0.50 CLEAN P CLEAN Pre-tour checks, set PVT, inspect Top Drive. 13:00 - 14:30 1.50 CLEAN P CLEAN Pick up BHA components to the Rig Floor. Install bails and elevators. Make up BHA #5 as follows: 8-1/2" Bit, Junk Basket, Junk Basket, Junk Basket, Junk Basket, Bit Sub, Oil Jar, XO, 6 ea 6-1/4" Drill Collars, XO, XO. OAL = 216.43'. 14:30 - 15:00 0.50 CLEAN P CLEAN TIH with BHA #5 to drill out the cement and shoe track. 15:00 - 15:30 0.50 CLEAN P CLEAN Pick up stand #19 and establish parameters. PUW = 90K, SOW = 95K. Break circulation at 5 bpm / 140 psi and start rotation on the string at 50 RPM with 1,000 ft-Ib of torque and RW = 95K. RIH and stack 10K at 45' in on stand #20 = 2,070'. Pick up and RIH to confirm depth - OK. RIH and drill remnants of cement on top of ES Cementer down to 2,077'. 15:30 - 18:30 3.00 CLEAN P CLEAN Kick up the RPMs to 100 for drilling up the shoe track. Use 2-3K WOB for drilling with max torque of 2K to drill thru ES cementer. Circulate hi-vis sweep around. Observe cement remnants, rubber and metal across the Shakers. 18:30 - 20:00 1.50 CLEAN P CLEAN Continue to RIH and ta sand at 2,167'. Dry drill and spud thru hard junk, drill +5' thru sand to 2,172'. Circulate hi-vis sweep at 10 BPM / 500 psi, cement returns. Monitor well prior to POH. 20:00 - 21:00 1.00 CLEAN P CLEAN POH with BHA #5 standing back in Derrick. 21:00 - 21:30 0.50 CLEAN P CLEAN LD BHA #5. Boot baskets recovered minimal cement debris and good amount of aluminum and rubber chunks. All 4 boot baskets recovered fill and junk. 21:30 - 23:00 1.50 CLEAN P CLEAN Make up BHA #6 RCJB assembly. OAL = 226.93'. RIH on 4" 23:00 - 23:30 ~ 0.50 ~ CLEAN ~ P ~ ~ CLEAN ~ MU top drive and establish parameters. PUW = 95K, SOW = Printed: 9/14/2009 10:49:52 AM ~ ~ BP EXPLORATION' Page 8 af 10 ;. Op~rations Summary Reporf Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: Date` From - To Hours Task Code NPT Phase ' Deseription of (~perat~ons 8/31/2009 23:00 - 23:30 0.50 CLEAN P CLEAN 95K. Wash thru ES cementer at 2,076' at 5 BPM / 380 psi. Drop ball. Rotate and wash at 5 BPM / 1,500 psi thru sand top from 2,172' to 2,183'. P/U off bottom to 2,150' and slow pump to 1.5 BPM, and wait for 5 min. Rotate and wash back down to 2,183'. 23:30 - 00:00 0.50 CLEAN P CLEAN Circulate hi-vis sweep surface to surface at 5 BPM / 1,500 psi. Returned small amounts of cement. 9/1/2009 00:00 - 00:30 0.50 CLEAN P CLEAN Monitor well and flow check. Crew change, conduct rig and safety checks. 00:30 - 01:00 0.50 CLEAN P CLEAN Lubricate rig. Inspect top drive. 01:00 - 01:30 0.50 CLEAN P CLEAN POH with BHA #6 standing back in Derrick. 01:30 - 02:30 1.00 CLEAN P CLEAN LD scraper from RCJB assembly. Empty boot baskets and recover 8 aluminum chunks and 3 brass plugs from RCJB. Boot baskets recovered shavings and sand. 02:30 - 04:00 1.50 CLEAN P CLEAN MU RCJB assembl er Baker. RIH on 4" drillpipe to 2,183'. 04:00 - 05:00 1.00 CLEAN P CLEAN MU top drive and establish parameters. PUW = 96K, SOW = 96K. Rotate and wash at 5 BPM / 1,420 psi thru sand from 2,183' to 2,195'. P/U off bottom to 2,155' and slow pump to 1 BPM, and wait for 10 min for junk to fall into baskets. Wash back down to 2,195'. Circulate hi-vis sweep surface to surface at 6 BPM / 2,200 psi, noted sand at surface. 05:00 - 06:00 1.00 CLEAN P CLEAN POH with BHA standing back in Derrick. 06:00 - 07:30 1.50 CLEAN P CLEAN Stand back Drill Collars. Break out and lay down BHA components with Baker rep. The RCJB was empty. The Junk Baskets recovered 1 brass button (last one in the well), 1 chunk of cement and aluminum shavings along with sand. 07:30 - 08:00 0.50 CASE P TIE61 Close the Blind Rams and pressure test the 9-5/8" tie-back from the RBP at 2,220' to surface to 4,000 psi for 30 charted, mins. Lost 65 psi first 15 min, lost 20 psi last 15 min - good test. 08:00 - 08:30 0.50 CASE P TIEB1 PUMU Retrieving Tool and Drill Collars with Halliburton rep to pull out the 9-5/8" RBP. 08:30 - 09:00 0.50 CASE P TIEB1 TIH on 4" drillpipe from the Derrick to the top of the sand at 2,195'. 09:00 - 09:30 0.50 CASE P TIEB1 Establish parameters: PUW = 95K , SOW =95K. Circulated down at 7.5 bpm / 320 psi and tagged top of sand at 2,200'. Washed down and latched onto 9-5/8" RBP at 2,220'. Pull up 102K to verif latch. 09:30 - 10:00 0.50 CASE P TIEBi Pump a 30 bbl hi-vis sweep surface to surface and displace the well to clean seawater at a rate of 10.5 bpm / 510 psi. 10:00 - 10:30 0.50 CASE P TIEB1 Release the RBP and allow to relax per Halliburton rep. RIH below set depth to verify it was released. 10:30 - 11:30 1.00 CASE P TIEB1 POOH with RBP standing back 4" drillpipe in the Derrick. 11:30 - 12:30 1.00 CASE P TIEB1 Lay down 6-1/4" drill collars. Break out and lay down 9-5/8" RBP with Halliburton rep. 12:30 - 15:00 2.50 CASE P TIEB1 Ria up and test 9 5/8" casinq to 4000 psi for 30 minutes. Pass on 3rd attemnt after double blockina surface equipment. Lost 80 psi in first 15 minutes and 40 psi in second 15 minutes - PASS. No pressure on the OA during test. 15:00 - 16:00 1.00 BOPSU P OTHCMP Rig up for BOPE test. 16:00 - 20:30 4.50 BOPSU P OTHCMP Test BOPE to 250 psi low, 4000 psi high and Hydril to 250 psi low, 3500 psi high as per A G . est witnessed by Chuck Scheve with AOGCC. Test lower 2 7/8" X 5" variables with 2 Printed: 9/14/2009 10:49:52 AM ~ ~ BP EXPLORATIQN Page 9 of 1 Q Qperations Sumrrtary Report Legal Well Name: 11-10 Common Well Name: 11-10 Spud Date: 7/12/1985 Event Name: WORKOVER Start: 8/18/2009 End: 9/5/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/5/2009 Rig Name: DOYON 14 Rig Number: i Date From - To ~ Hc~urs ~ Task Cc 9/1/2009 16:00 - 20:30 4.50 BOPSU P 20:30 - 21:30 1.00 CLEAN P 21:30 - 00:00 2.50 CLEAN P 9/2/2009 00:00 - 07:30 7.50 CLEAN P 07:30 - 10:00 2.50 CLEAN P 10:00 - 11:30 1.50 CLEAN P 11:30 - 18:30 7.00 CLEAN P 18:30 - 21:00 2.50 CLEAN P 21:00 - 21:30 0.50 CLEAN P 21:30 - 23:00 1.50 RUNCO 23:00 - 00:00 I 1.00 9/3/2009 I 00:00 - 11:30 I 11.50 11:30 - 12:30 1.00 RUNCO 12:30 - 16:00 3.50 RUNCO 16:00 - 17:00 1.00 RUNCO 17:00 - 21:30 4.50 RUNCO 21:30 - 00;00 2.50 RUNCO 9/4/2009 00:00 - 05:30 5.50 RUNCO 05:30 - 07:00 1.50 RUNCO 07:00 - 08:00 1.00 BOPSU N NPT Phase ' Description of Operations OTHCMP 7/8" and 4" test joints. Test upper 3 1/2" X 6" variables with 4" and 5 1/2" test joints. Test Hydril with 2 7/8" test joint. Complete Koomey test. All tests charted for 5 min. Witnessed by WSL and Toolpusher. CLEAN Blow down lines. Install 12.5" ID wear bushing. CLEAN MU BHA #8 mill for FasDrill plug, OAL = 273.72'. CLEAN RIH with Junk mill assembl on 4" drilipipe. Ease thru ES cementer depth of 2,076' and continue to RIH at a reduced running rate to avoid shearing guide shoe. RIH to 10,550' (25' above tubing stub). CLEAN Circulate hi-vis sweep and displace well to clean seawater at 6-9 BPM / 2330-2,650 psi. CLEAN PUW = 200K, SOW = 130K, RTW = 162K, 50 RPM at 7-10K torque. Enter top of 5 5" stub at 10 579' Mill un FacDrill in 4-~" at 10.740' with 1-2K WOM. Push out end of tail pipe at 10,747' and continue in hole to 10 775'. Monitor well for static losses 90 bbl/hr. Brine weight in and out 8.5 ppg. CLEAN POH la in down Drill i e. Fill hole with 60 bbl/hr. , CLEAN LD junk mill BHA and assembly, mill in good shape. CLEAN Pull wear bushing. RUNCMP Mobilize 5.5" tubing handling equipment. RU single joint compensator and torque turn equipment. RU long bails and stabbing board. Fill hole with 60 bbl/hr. RUNCMP PJSM. MU and run 5.5" jewlery per running order. Bakerlok all connections below packer, torque to 4,350 ft-Ibs. Run Unique overshot assembly with 2 sets shear screws (13.90' swallow), XN assembly with RHC plug, X assembly and 9-5/8" x 5-1/2" S-3 packer per Baker. Fill hole with 60 bbl/hr. SFAL RUNCMP Run 5.5", 17#, L-80, TCII tubinq. Tubing made up to 4,350 ft-Ibs of torque. Use Jet Lube seal guard on all premium connections. Dirty threads from road trip, have to take time to clean threads between several connections. Maintain continuous hole fill with 60 bbl/hr while running completion. Unable to MU clean connections, taking 3-5 times to achieve SFAL ~ RUNCMP ~ Confer with RWO engineer about laying down completion Decision made to LD completion. SFAL RUNCMP LD 35 joints of 5.5" tubing and jewlery assembly's. Fiil hole at 60 bbl/hr. SFAL RUNCMP LD 5.5" handling equipment. Order tubulars for 4.5" completion as per BP asset. SFAL RUNCMP Remove 5.5" tubing and jewlery from shed. Mobilize overshot back to machine shoa for re-use on 4.5" comoletion. Fill hole at 60 bbl/hr. SFAL RUNCMP 4.5" tubing on location. Load and strap pipe. Fill hole at 60 bbl/hr. SFAL RUNCMP Continue to load and strap 4.5" tubing. Load and strap 4.5" jewelry. Fill hole fill at 60 bbl/hr. RU floor to 2-7/8" x 5" VBR. AOGCC rep Bob Noble waived the state's ri~ht to witness test ~~ ~y~~u~ -~R~ at 05:30 hrs on 9-4-09. SFAL RUNCMP Stacktubing~~inshed.~~ SFAL RUNCMP RU to test bottom rams with 4.5" test joint. Set test plug and Printed: 9/14/2009 t0:a9:52AM ~ ! BP EXPLORATION U~1~C1t Legal Well Name: 11-10 Common Well Name: 11-10 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 I I' I I I 9/4/2009 07:00 - 08:00 1.00 BOPSU N 08:00 - 09:00 1.00 09:00 - 00:00 15.00 9/5/2009 00:00 - 03:00 3.00 03:00 - 04:00 1.00 04:00 - 04:30 0.50 04:30 - 05:00 0.50 05:00 - 09:00 4.00 09:00 - 10:00 I 1.00 Spud Date: 7/12/1985 Start: 8/18/2009 End: 9/5/2009 . Rig Release: 9/5/2009 Rig Number: N`PT Phase Description of ~perations SFAL RUNCMP gravity feed IA with seawater during test. Test 2-7/8" x 5" VBR with 4.5" test joint to 250 psi low / 4,000 psi high for 5 min each - charted. Pull test plug and rig down test joint. SFAL RUNCMP RU to run 4.5", 12.6#, L-80, TCII completion. RUNCMP PJSM. MU and run 4.5" jewlery per running order. Bakerlok all connections below packer, torque to 3,850 ft-Ibs. Run Unique overshot assembly with 2 sets shear screws (13.90' swallow), XN assembly with RHC plug, X assembly and 9-5/8" x 4-1/2" S-3 packer per Baker. Run 4.5", 12.6#, L-80, TCII completion. Torque turn all connections to 3,850 ft-Ibs, use Jet Lube seal guard on connections. Fill hole with 60 bbl/hr while running completion. RUNCMP Continue to run 4.5" completion. RUNCMP Final weights: PUW = 162K, SOW = 126K. Swallow tubing stump at 10,586' TM, saw both sets of set screws shear. No-go on stump with overshot down to 10,600'. Space out 4' off bottom (puts overshot tail at 10,596'). LD excess joints. Ran a tota o ~oin s o ., .6#, CII tubing. RUNCMP MU tubing hanger with Cameron rep. Land hanger, RILDS. RUNCMP MU circulating pin. RU Little Red to pump down tubing. RUNCMP PJSM. Pressure test LRS lines to 2,000 psi. Pump 35 bbls of diesel down tubing at 2 bpm with 450 psi. Drop Ball & Rod. Pump 180 bbls inhibited seawater down IA with rig pump at 2-3 bpm with 200 psi climbing to 640 psi. Rig LRS up to IA, test lines to 4500 psi then pump 120 bbls of 80 deg diesel at 2 bpm with 375 psi. RUNCMP Attemat to pressure uo on tubinp to set packer. Ball not seating. ttring rate up m increments, z npm witn zuu psi, 4 bpm with 300 psi then 6 bpm with 1000 psi. Communication up IA, Ball & Rod still not seating. 10:00 - 11:00 1.00 RUNCO RUNCMP Discuss options and decide to rig up Slickline and look for ball and rod. 11:00 - 13:00 2.00 RUNCO RUNCMP When filling hole while waiting on Slickline decide to try and seat ball and rod. Pump down tubinq and ball and rod went on seat. Pressure u and test to 4 000 si for 30 minutes. Lost 75 psi in 1st 15 minutes and 0 psi in 2nd 15 minutes - PASS. Circulate seawater over the IA and fill the annulus in preperation for IA test. Test IA to 4,000 psi for 30 minutes. Lose 65 psi in ist 15 minutes and 30 psi in 2nd 15 minutes - PASS. 13:00 - 15:00 2.00 BOPSU P RUNCMP RD landing joint. Dry rod TWC with Cameron rep. Test from above to 4,000 si for 10 min - charted. RD test eqwpment. 15:00 - 18:00 3.00 BOPSU P RUNCMP ND BOPE. 18:00 - 21:30 3.50 WHSUR P RUNCMP NU adapter flang and tree. Test tubing hanger void to 5,000 psi for 30 min. Test tree with diesel to 5,000 psi for 5 min - charted. 21:30 - 23:00 1.50 WHSUR P RUNCMP RU lubricator and test with diesel to 500 psi. Pull TWC, well static. Set BPV. Unable to test BPV due to no mandrel in completion string. 23:00 - 00:00 1.00 WHSUR P RUNCMP Secure cellar. Normal wellhead and tree valves. Rig released at 24:00 hrs on 9-5-09. Printed: 9/14/2009 10:49:52 AM • ,,-- ~_ ~. r ~ F , ~ _ ~ _ z a 2 ~ u _ ~ ~.`~ ~x ~~; ALASS-A OIL A1~TD GAS CO1~T5ERQATIOI~T COMrIISSIOI~T SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 '' Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11-10 Well Sundry Number: 309-175 :~ '~~1~. ~~'` ` 2~CC• Dear Mr. Reem: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may tale with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner .~ DATED this day of May, 2009 Encl. SJf/~For q ; „ STATE OF ALASKA ~h 5 I~ 1 ~~ V~~. ALA OIL AND GAS CONSERVATION COM ION ~/'~, ~~Y ~ ~ ~~~~ APPLICATION FOR SUNDRY APPROVAL j~- ~a~ 20 AAC 25.280 Alaska fii! ~ rya r 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ArrchQ rage ® Alter Casing - - ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 185-159 3. Address: -® Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21394-00-00 _ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 11-10 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028322 - 58' - Prudhoe Bay Field / Prudhoe Bay O!I Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11555' 8825' ~ 11505' 8784' 10734' None in e h iz M TVD u C Ila r aural 1 11 1 1 rf 2 2' 13-3/ " 2 2' 2523' 34 1 In rm i 10916' 9-5/8" 1091 687 47 Pr i n Liner 62' 7" 106 4' - 11546' 125' - 8 1 7240 541 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11414' - 11450' 8710' - 8739' S-1/2", 17# x 4-1/2", 12.6# L-80 10747' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'HB' packer Packers and SSSV MD (ft): 10642' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name D vid Ree Title Engineering Team Leader / Prepared By NameMumber Signature Phone 564-5743 .Date s/ /~lB~ Terrie Hubble, 56a-4628 Commission Use Onl Sundry Number: ~ _ $ Conditions of approval: Notify Commission so that a representative may witness w E~~ SZ `1}a-O ~ ^ Plug Integrity 'BOP Test Mechanical Integrity Test ^ Location Clearance ~~ Other: ~O~Q~~.~G~~~G.S ~ `4!~`~~ c ~~5~ ~`'`~v~~aM~~C~.i~'i~`l~~`~~ Subsequent Form Required: ~~~ APPROVED BY ~ S A roved B COMMISSIONER THE COMMISSION Date ~ Form 10-403 Revised 06/206 ~ Submit In Duplicate $ ,` 3 i 4 7 ~ t. .,, ~ r,~hy ~ ? 2DD Slpii • by cr,~,~ 11-10i RWO Well Type: Injector Current Status: This well is currently shut-in. • Request : BPXA requests approval to restore production casing and tubing integrity on 11-10. Scope of Work: Repair IA x OA communication by cutting and pulling 9-5/8" surface casing, replacing it and fully cementing it to surface. Replace tubing with 5-1 /2" L-80 tubing with premium gas tight connections. MASP: 2,522 psi Estimated Start Date: July 2009 Production Engineer: Bob Chiwis Intervention Engineer: Mehrdad Nadem Pre-rip prep work: F 1 OMIT T x IA to 2,000 si. MIT OA to 2,000 si. DONE, March 2009 S 2 Pull CAMCO DB lu in the tubin tail at 10,734'. Drift the 4-1/2" tubin for FasDrill. E 3 Set FasDrill plug at 10,740' MD below X Nipple at 10,734'. Pressure test the FasDrill to 2,000 psi to establish it as a com etent barrier. Reference tubin tall dated 9/2/1985 E 4 Jet cut the 5-1/2" L-80 tubing at -10,586' MD (reference tubing tally of 9/2/85). This is 10' MD from the to of the first full 'oint above the Baker PBR. F 5 Pressure test the T x IA to 1,000 si to ensure the FasDrill remains a com etent barrier. F 6 Circulate well with seawater. FP with diesel throu h the cut. D 7 Bleed casin and annulus ressure to 0 si. W 8 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 9 Set a BPV in the tubin han er. Secure well. O 10 Remove the wellhouse & flow line. Level the ad as needed for the ri . 1. MIRU Rig. ND tree. and test BOPE to 250 psi low, 4000 psi high. Circulate out freeze protection fluid and circulate well to c seawater. 2. Pull and LD 5 1/2" tubing string fr ut. 3. Run USIT to determine TOC. ~~s~c.,\~~' ~t-ccS~' c'cc.~'tiE~G~o~k ~~ 4. Cut and Pull 9-5/8" surface casing. 5. Replace 9-5/8" 47#, Hydri1563 surface casing and ce t to surface. ~`~.ro J~ ~~~~~SE~v\~~~ 6. Run 5-1/2" Carbon stacker packer completion. c~sSuc~~S~ cc~s\r~S ;~' 7. Set BPV. ND BOPE. NU and test tree. RDMO. Q ATTACH: Current and proposed Schematics ~ ~a ~ -~ ~~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 21, 2009 10:56 AM To: 'Nadem, Mehrdad' Cc: 'Reem, David C' Subject: RE: DS 11-10 (185-159) Thanks Mehrdad. The only item that needs adding is with regards to drilling out the 9-5/8" cementing equipment and pressure testing the new casing, new step 6a. When you send in these procedures, the proposed operational steps should be "complete". I will include this message with the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Thursday, May 21, 2009 10:46 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 11-10 (185-159) Tom: attached please find more detailed information for 11-10i sundry. I am available to provide you with additional at your request. Thanks, Mehrdad Nadem Phone: 907/564-5941 Ceil: 907/440-0213 Email: nademm~bp.com Proposed Procedure: 1. MIRU Rig. ND tree. NU and test BOPE to 250 psi low, 4000 psi high. Test the 3-%" x 6" VBR with 4" and 5- 1/2" test joints and the 2-7/8" x 5" VBR with 2-7/8" and 4" test joints. Test the annular to 250psi low and 4,000 psi high with 2-7/8" test joint. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 5-112" tubing string from cut. 3. RU E-line, Run USIT in the 9-5/8" casing to determine TOC in the 9-5/8" X~ 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 3,500 psi for 10 minutes. ~~rl~ 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (FasDrill and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" L-80 47# Hydrill 563 casing with ECP; ES Cementer and casing patch to surface. 6a Drill out cementing equipment and pressure test 9-5/8" casing. 7. Retrieve bridge plug. ~ ~~ ~ ` ~~.. ~~`~~~ 8. Drill FasDrill and push below the tubing tail. ~ Q 9. Run 5-1/2" TCI1, 17# , L-80 stacker packer completion. 10. Displace the IA to completion fluid and freeze protect and set the packer. 11. Test tubing and IA to 4,000 psi. 12. Set BPV. ND BOPE. NU and test tree. RDMO. 5/21 /2009 Page 2 of 2 • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov~ Sent: Wednesday, May 20, 2009 5:17 PM To: Nadem, Mehrdad Cc: Reem, David C Subject: DS 11-10 (185-159) Mehrdad, I am reviewing the sundry application to workover this well. The procedure included is not complete. While the overall steps planned are included, they are significantly simplified/reduced from what has been previously submitted. Please provide a procedure similar to what has been provided for prior workovers. Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 5/21 /2009 I Ktt? CiKA Y CitN ;i WELLHEAD = GRAY ACT ATOR = AXELSON KB. ELEV..- ~ 58' BF. ELEV - KOP = 3500' Max Angle = 59 @ 8100' Datum MD = 11598' Datum TVD = 8800' SS 113-3/8" CSG, 68#, K-55/ 72#, L-80, ID = 12.347" SAFETY NOTES:'"'" PWI ONLY/NO MI INJECTION AL ~ 11-10 2183. I-j5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3033 3032 4 CA-MMIG RK 2 4291 4232 32 CA-MMIG RK 3 6346 5493 57 CA-MMIG RK 4 8636 6696 57 CA-MMIG RK 5 8801 6789 54 CA-MMIG RK 6 9906 7543 44 CA-MMIG RK 7 10059 7653 43 CA-MMIG RK 8 10383 7894 41 CA-MMIG RK 9 10541 8014 40 CA-MMIG RK Minimum ID = 3.813 @ 10734' 4-1 /2" DB NIP I J 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" J 5-1/2"BAKERPBRASSY I 5-1/2" X 4-1/2" XO,ID = 3.958" 9-5/8" X 4-1/2" BOT HB PKR OF 7" LNR I--I 10684' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 10734' --~4-1/2" CAMCO DB NIP, ID = 3.813" 10734' 4-1/2" DBP PLUG (04/14/08)) 10746' 4-1/2" BOT SHEAROUT SUB 10747' 4-1/2" TUBING TAIL, ID 3.958" 107 ELMD TT LOGGED 05/02!86 I 10747' I PERFORATION SUMMARY REF LOG: BHCS ON 07/26/85 ANGLE AT TOP PERF: 35 @ 11414' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11414 - 11450 C 04/07/86 3-3/8" 1 11414 - 11432 C 07/24/89 3-3/8" 4 11432 - 11450 C 07/24/89 ;'`_' PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ( 11505' I DATE REV BY COMMENTS DATE REV BY OOMMENTS 07/31/85 ORIGINAL COMPLETION 05/04/08 JCIWPJC PULL & RESET PLUG (04/14/08) 09/05/85 LAST WORKOVER 04/25/03 ATD/TLH WANERSAFETY NOTE 11/19/03 KDGPAG WAVER SAFETY NOTE 05!29/06 DFR/DTM CSG CORRECTIONS (11/24/04) 01/15/08 GJF/SV SET PLUG (06/25/07) PRUDHOE BAY UNR WELL: 11-10 PERMIT No: 1851590 API No: 50-029-21394-00 SEC 28, T11 N, R15E, 1504.74' FEL & 3866.59' FNL BP 6rploration (Alaska) TREE _ ~ GRAY GEN 3 WT1L'HEAD= GRAY ACTUATOR = AXELSON KB. ELEV = 58' BF. ELEV = KOP = 3500' Max Angle = 59 @ 8100' Datum MD = 11598' Datum TV D = 8800' SS SAFETY NOTES:'*' PWI ONLY/NO MI INJECTION ALL 2,000' 5-1/2" HES "X" Nipple 2,275` - 9-5/8" ECP 2,300` - 9-5/8" CSG Patch 2,300` 9-5/8", 47#, L-80 Hyd-563 11-~i Proposed ~ 13-3/8" CSG, 68#, K-55/ 72#, L-80, ID = 12.347" Minimum ID = 3.813 @ 10734' 4-1 /2" DB NIP HES 5-1/2" "X" Nipple, ID=4.562" BKR 9-5/8" x 5-1/2" S-3 , L-80 PKR HES 5-1/2" "X" Nipple, ID=4.562" HES 5-1 /2" "XN" Nipple, ID=4.455" 10586` 5-1/2" 17# TCII, ID=4.892" 10586` 9-5/8" x 5-1/2" L-80 Unique Overshot 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I 15-1/2" X 4-112" XO, ID = 3.958" 1 X I TOP OF 7" LNR 10734' 1~4-1/2" CAMCO DB NIP, ID = 3.813" 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-518" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 07/26/85 ANGLE AT TOP PERF: 35 @ 11414' Note: Refer to R~oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11414 - 11450 C 04/07/86 3-3/8" 1 11414 - 11432 C 07/24/89 3-3/8" 4 11432 - 11450 C 07/24/89 PBTD 11505' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I I TD I ~4-1/2" BOT SHEAROUT SUB i 4-1/2" TUBING TAIL, ID 3.958" ELMD TT LOGGED 05/02/86 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/85 ORIGINAL COMPLETION 05/04/08 JCMVPJC PULL 8 RESET PLUG (04/14/08) 09/05185 LAST WORKOVER 04/25/03 ATD/TLH WANERSAFETY NOTE 11/19/03 KDGPAG WANER SAFETY NOTE 05/29/06 DFR/DTM CSG CORRECTIONS (11/24/04) 01/'5/08 GJF/SV SET PLUG (06/25/07) PRUDHOE BAY UNfT WELL: 11-10 PERMfT No: 1851590 API No: 50-029-21394-00 SEC 28, T11 N, R15E, 1504.74' FEL & 3866.59' FNL BP Exploration (Alaska) 11-10 (PTD #1851590) Internal Waiver Cancellation - Trouble Well e e Subject: ] ]-10 (PTD #1851590) Internal Waiver Cancellation - Trouble Well From: "NSlJ, ADW Wc\llntcgrity Engineer" <NSUADWWellJntegrityEnginccr@BP.com> 0 ( J Date: Sat, 25 Feb 200609:04:23 -0900 'I"c?ff ëln/Ðlo To: "AOGCC - Winton Aubert (E-mail)..<winton_auber1@admin.statc.ak.us>. jim_regg@admin.state.ak.us, "NSU, ADW Well Operations Supervisor" <NSUAD\VWellOperationsSupervisor@iBP.com>, "Rossberg, R Steven" <Steven.RossbcrgC4jBP.com>, "GPB, FS2/COTU Area Mgr" <GPBFS2TL@BP.com>, "Kurz, John" <~iohn.kurz@BP.col1l>, "GPB, FS2 DS Ops Lcad" <GPBFS2DSOpsLcad@BP.com> cc: "NSLJ, ADW Well I.ntegrity Engineer" <NSlJADWWcl\JntegrityEnginecr@ßP.com>, "NSU, AD\-V WI Tcch" <NSUADWWITcch@BP.com>, "WinslO\\', Jack L." <LYOllSW@BP.com>, "Cooper, Katrina N" <Katrina.Coopcr@BP.com> All, An internal waiver was issued for IAxOA communication on well 11-1 0 (PTO #1851590) on 11/19/03. The well was also approved for injection under an AOGCC sundry for the same communication. Plans to update the waiver and sundry/AA are being placed on hold for injection line repairs. For now, the waiver and sundry are being cancelled. Once the line repairs are complete, the well will be retested and a request for Administrative Approval will be sent to the AOGCC. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 2/27/2006 12:25 PM e e ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 February 25, 2006 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: 11-10 (PTD 1851590) Application for Cancellation of Sundry #303-287 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-287. The sundry was for continued water injection with slow IAxOA communication. The well will remain shut-in in preparation of an administrative approval. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. (IlL- Anna Dube Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 .. , ... STATE OF ALASKA I AL~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D D RECEIVED MAR 0 1 ZOOS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic StimulateD Ala~~tt1i~ ~t~t?~~~· . W· D T· Ext . 18S1 n alver Ime enslon A Re-enter Suspended Well D ncharage 5. Permit to Drill Number: 185-1590 6. API Number: 50-029-21394-00-00 9. Well Name and Number: Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 58 KB 11-10 8. Property Designation: ADL-028322 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Total Depth measured 11555 true vertical 8825.46 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 11505 true vertical 8784.4 feet feet Casing Conductor Surface Production Liner Length Size MD TVD Burst Collapse 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 42 13-3/8" 68#/72# K-55/L 30 - 2523 30 - 72 3450 1950 10890 9-5/8" 47# L-80 26 - 10916 26 - 8307.86 6870 4760 862 7" 29# L-80 10684 - 11546 8125.13 - 8818.07 8160 7020 Perforation depth: Measured depth: 11414 - 11450 True Vertical depth: 8709.78 - 8739.27 Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# L-80 L-80 25 - 10626 10626 - 10747 Packers and SSSV (type and measured depth) 4-1/2" Baker HB Packer 10642 ~ 2. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL MAR {I 2 2006 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil 0 Gas 0 WAG Service [;'] Contact Anna Dube / Joe Anders 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: 303-287 , Printed Name Anna Dube Signatured~ Title Well Integrity Coordinator Form 10-404 Revised 04/2004 ~~ ORIGINAL Date 2/25/2006 Submit Original Only BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 11-10 (PTD 1851590) Application for Sundry ApprOval Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for Well 11-10. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known IA by OA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments ALASL STATE OF ALASKA 0I OILAND GAS CONSERVATION C ~,,¢IISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon [] Suspend ~] Operation Shutdown [] Perforater--J Variance~J~ Annuar Disposal[--] AlterCasin.q [--] RepairWell [--~ Plu.qPerforations BI Stimulater-'] Time Extension[-1 Other["-] Change Approved Pro.qram ~] Pull Tubin.q D Perforate New Pool ~] Re-enter Suspended Well[-] H20 INJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [~ ExploratoryE] 185-159 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 995'19-6612 Stratigraphicr"] Service[] 50-029-21394-00-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 58.00 11-10 8. Property Designation: 10. Field/Pool(s): ADL 028322 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):11555 ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): ]Plugs (measured): IJunk (measured):8825 I 11435 (06/29/1999) I 8727 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110 20" 25'- 143' 25' - 143' 40K 520 Surface 2490 13-3/8" 25' - 2523' 25' - 2523' 80K 2670 Production 10883 9-5/8" 25' - 10916' 25' - 8308' 80K 4760 Scab Liner 862 7" 10684' - 11546' 8125' - 8818' 80K 7020 Perf°rationDepthMD(ft): IPerforationDepthTVD(ft): I Tubing Size: I Tubing Grade: Tubing MD (ft): 11414'-11435' 8710'-8739' 5-1/2" 17¢, 4-1/2" 12.6¢ L-80 10747 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8" x 4-1/2" BOT H B PKR; 5-1/2" Camco BAL-O SSSVL PKR @ 10642', SSSVLN @ 2183' 12. Attachments: Description Summary of Proposal[] 13. Well Class after proposed work: Detailed Operations Program BI BOP Sketch E] ExploratoryE] DevelopmentE] service[] 14. Estimated Date for ~lI OIl~ ..~ 15. WeoIlil~..~tus afte~:o[~sed W~;uk;gedr..1 Commencing Operation: Abandoned~--I 16. Verbal Approval: Date: WAGE] GINJE] WINJ [~ WDSPLE] Commission Representative: Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed Name Joe Anders Title GPB Well Integrity Engineer Signature ~ (.~,.~/~ Phone 907/659'5102 Date 09J10/2003 "/ Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ..~'~ Plug Integrity B BOP TestB Mechancial Integrity TestB Location Cleara.~ ,~¢% r:' i~'~k ,¢'~ Subsequent Form Required: :~laska Oi~ & Gas 0ohs. 0oi~f~lssIo~ Anchorage Approved by: COMMISIO~fi8 TH~ COMMISSIO~ Date: Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE 11-10 Description Summary of Proposal 09112103 Problem Injector with IA by OA communication. Current Sundry requirements are not aligned with Sundry Matrix. Well History and Status Well 11-10 (PTD 1851590) is an injector with IA by OA communication. CMIT IAxOA's pass, demonstrating competent tubing and surface casing. Current Sundry requirements are not aligned with the Sundry Matrix dated 5/13/03. This proposal updates the Conditions of Approval to the current requirements. Pertinent well events: > 06/08/89 > 07/13/98 > 07/15/99 > 07/16/00 > 08/06/01 > 08/14/02 : Sundry #9-490 issued for T x IA comm : CMIT IA x OA Passed @ 2000 psi : CMIT IA x OA Passed @ 2000 psi : CMIT IA x OA Passed @ 2000 psi : MIT IA Passed : MITIA Failed. CMIT-IAxOA Passed @ 2000 psi > 02/14/03: MITIA Failed. CMIT-IAxOA Passed @ 2500 psi > 03/11/03: Canceled Sundry #9-490, Sundry #303-075 issued for IAxOA comm This request is to cancel the existing IA by OA Sundry and issue a new Sundry for IA by OA communication using current Conditions of Approval. The following supports the request: · A CMIT-IAxOA passed on 02/14/03 to 2500 psi, demonstrating competent tubing and surface casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a tubing leak. · A CMIT-IAxOA will be conducted every 2 years to confirm tubing and surface casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform CMIT-IA x OA every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of tubing or surface casing integrity. TREE = GRAY GEN 3 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 58' BF. ELEV = KOP = 3500' :Max Angle = 59 @ 8100' Datum MD = 11598' Datum TVD = 8800' SSI I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2523' J--~ Minimum ID = 3.813 @ 10734' 4-1/2" DB NIP 10638' 10638' I TOP OF 7" LNR Id 10684' 11-10 "'Y NOTES: ***RAPID IAxOA COMM. .ATING LIMITS: MAX lAP = 2000 PSI, MIN OAP = 2000 PSI (04/21/03) *** 2183' I-~ 5-1/2"CAMCOBAL-OSSSV NIP, ID:4.562" I 10626' Id GAS LIFT MANDRELS CA-MMIG CA- MMIG RK CA- MMIG RK CA- MMIG RK CA-MMIG RK CA-MMIG RK CA-MMIG RK CA-MMIG RK CA-MMIG RK 5-1/2" BAKER PBRASSY I I 10638' Id 5-1/2"X4-1/2" XOI 10642' I-~ 9-5/8"X 4-1/2" BOT HB PKR J DATE 10734' I~ 4-1/2" CAMCO DB NIP, ID:3.813" J 4-1/2" TBG-PC, 12.6#, L-80, Id 10747' 0.0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 10916' PERFORATION SUMMARY REF LOG: BHCS ON 07/26/85 ANGLEATTOP PERF: 35 @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11414-11450 O 04/07/86 3-3/8" 1 11414-11432 O 07/24/89 3-3/8" 4 11432-11450 O 07/24/89 I PBTD Id 5o5' 11546' I 7" LNR, 29#, L-80, 0.0371 bpf, ID=6.184" Id I-CC-Id 555' I 10746' I-[ 4-1/2" BOTSHEAROUTSUB I 10747' I"-] 4-1/2" TUBING TAIL J 10732' Id ELMD q-I' LOGGED 05/02/86 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/85 ORIGINAL COMPLETION 09/05/85 LAST WORKOVER 02/13/01 SIS-MD FINAL 01/04/02 RN/TP CORRECTIONS 02/28/03 JP/KAK DELETE WAIVER SAFETY NOTE 04/28/03 ATD/TLH WAIVER SAFETY NOTE PRUDHOE BAY UNiT WELL: 11-10 PERMIT No: 1851590 APl No: 50-029-21394-00 SEC 28, T11N, R15E, 1504.74' FEL & 3866.59' FNL , BP Exploration (Alaska) 11~10 T~O P~ot 4~000 i ~ Tbg 3,000 2,000 1,000 A OA OOA 9/10/2002 11/10/2002 1/10/2003 3/10/2003 5/10/2003 7/10/2003 9/10/2003 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 11-10 (PTD 1851590) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for Well 11-10. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known IA by OA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments 8CAINI IE 2.003 ORIGINAL , (, i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] SuspendE] Operation ShutdownE] Perforater-] VarianceE] Annuar Disposalr'~ After Casin.qFI RepairWellE] Plu.q Perforations[-~ Stimulater'"] Time Extension [-'l Other[] Change Approved Program[-'] Pull TubingF-~ Perforate New PeelE] Re-enter Suspended WellE] CANCEL 10-403 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement [] ExploratoryE] 185-159 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 995'19-6612 StratigraphicE] Service[] 50-029-21394-00-00 7. KB Elevation (ft): 9. Well Name and Number: 58.00 11-10 8. Property Designation: 10. Field/Pool(s): ADL 028322 Prudhoe Bay Field / Prudhoe Bay Oil Pool ,11. Present Well Condition Summary: Total Depth measured 11555 feet true vertical 8825 feet Plugs (measured) Effective Depth measured 11435 feet Junk (measured) true vertical 8727 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 143' 143' 40K 520 Surface 2490' 13-3/8" 2523' 2523' 80K 2670 Intermediate 10883' 9-5/8" 10916' 8308' 80K 4760 Liner 862' 7" 10684'-11546' 8125'-8818' 80K 7020 Perforation depth: Measured depth: Open Perfs 11414'-11435' Open Perfs covered with fill 11435'-11450' True vertical depth: Open Perfs 8710'-8727' Open Perfs covered with fill 8727'-8739' Tubing: ( size, grade, and measured depth) 5-1/2" 17# L-80 TBG-PC @ 10638'. 4-1/2" 12.6# L-80 TBG-PC @ 10747'. Packers & SSSV(type & measured depth) 9-5/8" x 4-1/2" BeT HB Packer @ 10642'. ECE V" 'F!iD 5-1/2" Camco BAL-O SSSV Landing Nipple @ 218 12. Stimulation or cement squeeze summary: SEP Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~Alaska 0il & Gas Cons. Comm~ssior~ 13 Representative Daily Avera.qe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 8908 1464 Subsequent to operation: 9024 1474 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: OilF'1 Gasr"] WAGF'-~ GINJE] WIN J[ WDSPLr'-1 Daily Report of Well Operations __ prepared by DeWayne R. Schnorr 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O, Exempt: Contact Joe Anders I 303-075 Printed Name JoeAnders Title GPB Well Integrity Engineer Signature /f,~ U~,~~,~-~ r~ll,~l(,'~l~lAIPhone 907/659-5102 Date Sept10,2003 ~' I I-~ I 1\! ....... ,., Form 10-404 Revised 2/2003 \J~~ ~«:.\\. '7 <- Summary of Sundry Changes 09/12/03 Well Request 10-403 10-404 04-45 Align Conditions of Approval with Sundry XX XX Matrix 09-12 Align Conditions of Approval with Sundry XX XX Matrix 11-10 Align Conditions of Approval with Sundry XX XX Matrix 11-29 Align Conditions of Approval with Sundry XX XX Matrix 14-21 Align Conditions of Approval with Sundry XX XX Matrix A-31 Align Conditions of Approval with Sundry XX XX Matrix P1-01 Align Conditions of Approval with Sundry XX XX Matrix P-14 Cancel Sundry XX Y -03 Cancel Sundry XX Contact Joe Anders or John Cubbon with questions. (907) 659-5102 ( Well is L TSI Well is L TSI / f.s- - /s-9 Comments SCANNED OCT 1 0 2004 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation CommissiOn 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 11-10 (PTD 1851590) Application.for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Cancellation form 10-404 and Application for Sundry Approval form 10-403 for well 11-10. This request is to cancel the current sundry for tubing by inner annulus communication and for'approval to continue produced water injection with known inner annulus by outer annulus communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, J¢ e Anders, P.E. Well Integrity Engineer Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request:/ Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ U20 Injection -- Alter casing _ Repair well_ Plugging_ Time extension_ Stimulate_ Variance Change approved program _ Pull tubing _ Variance _X Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 58.0 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service.__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4242' FNL, 352' FEL, Sec. 28, T11N, R15E, UM (asp's 707170, 5952753) .. 11-10 At top of productive interval 9. Permit number / approval number 4229' FNL, 1568' FEL, SEC 21, T11 N, R15E, UM (asp's 705797, 5958009) 185-159 At effective depth 10. APl number 3896' FNL, 1509' FEL, Sec. 21, T11N, R15E, UM (asp's 705846, 5958344) 50-029-21394-00 At total depth 11. Field / Pool 3867' FNL, 1506' FEL, Sec 21 T11N, R15E, UM (asp's 705849, 5958373) Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11555 feet Plugs (measured) true vertical 8824 feet Effective depth: measured 11505 feet Junk (measured) true vertical 8783 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 2000# PoleSet 145' 145' Surface 2488' 13-3/8 2500 sx PF 'E', 400 sx 2523' 2523' PF 'C' Production 10881' 9-5/8" 500 sx Class 'G' 10916' 8307' Liner 862' 7" 380 sx Class 'G' 10684' - 11546' 8125' - 8817' Perforation depth: measured Open Perfs 11414'-11432', 11432'-11450' true vertical Open Perfs 8708'-8723', 8723'-8738' Tubing (size, grade, and measured depth 5-1/2" 17# L-80 TBG-PC @ 10638'. 5-1/2" x 4-1/2" XO @ 10638'. 4-1/2" 12.6# L-80 TBG-PC @ 10747'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" DOT HB PKR @ 10642'. 5-1/2" Camco BAL-O SSSV Nipple @ 2183'. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: March, 2003 16. If proposal was verbally approved Oil_ Gas __ Suspended __ Name ofapprover Date approved Service wATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Well Integrity Engineer @ 659-5102. Signed ~nte0''~ ~'(~v~) Title: Well Integrity Engineer Date~ ~/~'//0'~ '- -- WeFIr t ~lrit)' En~lineer Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test__ Location clearance __ I ,, ,~' _ Mechanical Integrity Test Subsequent form required 10- ~/~ 1 ~'~- i. ~,, ,~'.e~, ~1~',,~_ ~pproved by oroer of the ~or~mis~ion ~ ~ ~=~.~.~ Comm~ss,oner Date 8CANNED MAR 1 0 2003 Form 10-403 Rev 06/i 5/88 · SUBMIT IN TRIPLICATE ""'"' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ CANCEL 10-403 Pull tubing _ Alter casing _ Repair well _ Other_X CANCEL 10-403 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 58 feet 3. Address Exploratory, 7. Unit or Property name P. O. Box 196612 Stratigraphic._ Anchorage, AK 99519-6612 servi~.__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4242' FNL, 352' FEL, Sec. 28, TllN, R15E, UM (asp's 707170, 5952753) 11-10 At top of productive interval 9. Permit number ! approval number 4229' FNL, 1568' FEL, Sec. 21, T11 N, R15E, UM (asp's 705797, 5958009) 185-159 / 389-490 , At effective depth 10. APl number 3896' FNL, 1509' FEL, Sec. 21, T11N, R15E, UM (asp's 705846, 5958344) 50-029-21394-00 At total depth 11. Field / Pool 3867' FNL, 1506' FEL, Sec. 21, T11N, R15E, UM (asp's 705849, 5958373) Prudhoe. Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11555 feet Plugs (measured) true vertical 8824 feet Effective depth: measured 11505 feet Junk (measured) true vertical 8783 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 2000~ PoleSet 145' 145' Surface 2488' 13-3/8" 2500 sx PF 'E', 400 sx 2523' 2523' PF 'C' Intermediate 10881' 9-5~8" 500 sx Class 'G' 10916' 8307' Liner 862' 7" 380 sx Class 'G' 10684' - 11546' 8125' - 8817' Perforation depth: measured Open Perfs 11414' - 11432', 11432'-11450' true vertical Open Perfs 8708'-8723', 8723'-8738' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 TBG-PC @ 10638' MD. 5-1/2" x 4-1/2" XO @ 10638'. 4-1/2" 12.6# L-80 TBG-PC @ 10747'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BOT HB Packer @ 10642'. 5-1/2" Camco BAL-O SSSV ~ 2183' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 01/01/2003 9778 1426 Subsequent to operation 01130/2003 9464 1427 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil__ Gas __ Suspended __ Service WATER INJECTOR 17. I hereby certify that the f_o. regoin_gis true and correct to the best of my knowledge. Questions? Call Well Integrity Engineer~ 659-5102. ~ Title: Well Integrity Engineer Date 3//~ 0 '~ Well Integrity En~limj/er SCANNED MAR ? 20 3 Fnrm 1 ~)-404 Rev 06115188 · S BFL SUBMIT IN DUPLICATE 11-10 Description Summary of Proposal 02/18/03 Problem: Injector with IA x OA Communication Well History and Status Well 11-10 (PTD 1851590) is an injector that failed an MIT-IA on 08/14/02' 11-10'has a Sundry (99-490) dated 06/08/89 for T x IA communication. However, multiple passing CMIT-IA x OA tests indicate that problem no longer exists. Recent events: > 07/13/98: CMIT IA x OA Passed @ 2000 psi > 07/15/99: CMIT IA x OA Passed @ 2000 psi > 07/16/00: CMIT IA x OA Passed @ 2000 psi > 08/06/01: MIT IA Passed > 08/14/02: MITIA Failed. CM1T-IAxOA Passed @ 2000 psi > 02/14/03: MITIA Failed. CMIT-IAxOA Passed @ 2500 psi > 02/15/03: PPPOT-IC PASSED This request is to cancel the existing T x IA Sundry, issUe a new Sundry for IA x OA communication, and allow for continued injection of water. The following supports the request: A CMIT-IAxOA passed on 02/14/03 to 2500 psi, demonstrating competent tubing and surface casing. Pressures and injection rates will be monitored and recorded daily and checked for indications of a tubing leak. A CMIT-IAxOA will be conducted every 2 years to confirm tubing and Surface casing integrity. Proposed Action Plan , 2. 3. 4. 5. Allow well to continue water-only injection.. Record wellhead pressures and injection rates daily. Submit a monthly report of dailY pressures and injection rate. Perform combination MIT IA x OA every 2 years. Stop injection and notify the AOGCC if there is any indication of loss of tubing or ' surface casing integrity. ~GANNE~D ~AR 1 0 21~ANNED MAR 1 3 2003 "'fREE = GRAY GEN 3 WELL HEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 58' BF. B. EV = KOP= 3500' Max An~lle = . 59 @ 81_001 Datum N1D = 11598' Datum TV D = 8800' SS i , 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2523' Minimum ID = 3.813 @ 10734' 4-1/2" DB NIP 11-10 SAFETY NOTES : WAIVERED WFaL- Tx lax OA COMMUNICATION. 2183' H 5-1/Z'CAMCOBAL-OSSSV NIP, ID=4.562" J GAS LIFT MANDRELS TYPE CA-MMG CA-MrviG CA-MMG CA-MInG 5-1/2" TBG-PC, 17#, L-80, 0.0232 bpf, ID= 4.892" I--I 10638' ITOP OF 4-1/Z' TBG-PC H 10638' ITOPOF7'' LNR It 10684' 10626' H lO642' H lO734' H 5-1/2- BAKER PBRASSY I 5-1/Z' X 4-1/2" XO I 9-5/8" X 4-1/2" BOTHB PKR I 4-1/2" CAMCO [33 NIP, Id =3.813" I 4-1/2"TBG-FC, 12.6/~, L-80, .1=-~ 10747' 0.0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID= 8.681" H 10916' PERFORATION SUNIvlARY REF LOG: BHCS ON 07126185 ANGLEATTOPPERF: 35 @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11414-11450 O 04/07/86 3-3/8" 1 11414-11432 O 07/24/89 3- 3/8" 4 11432-11450 O 07/24/89 I FI3TD H 7" LNR, 29#, L-80, 0.0371 bpf, ID= 6.184" H 11505' 11546' 11555' 10746' 10747' 10732' H 4-1/2" BOT SHEAROUT sUB I 4-1/2" TUBING TAIL ELrvD 'iT LOGGED 05/02/86 I DATE REV BY COMIVENTS DATE REV BY COrv'tvlENTS. 07/31/85' ORIGINAL COIVPL ETLON 09/05/85 LAST WORKOV ER 12/13/00 SIS-MD CONgERIE'DTOCANVAS 02/13/01 SIS-MD FINAL 01/04/02 RN/TP CORRECTIONS PRUDHOE BaY UNIT WB_L: 11-10 PERMIT No: 185-1590 APINo: 50-029-21394-00 SEC 28 Tll N R15E 1504.74 FEL 3866.59 FNL BP Exploration (Alaska) Wavier Check List Well Name: l } ' l{9 Operator: Date: PTD: {-~5 - I~ Sundry#: 3'O5 "O7~' Order(s): Item Y/N Comments 1. Notified of pressure communication or leakage? 2. Diagnostics planned/run? Method? 3. Form 10403 submitted requesting waiver? 4. Alternate MIT passed? Method? AOGCC witnessed? 5. MIT Part II verified? How? 6. Areamr Review examined? .t ~, ,, ,, Definition of Terms T IA OA MIT CMIT LLRT Tubing Inner Annulus (tbg x csg) Outer Annulus (csg x csg) Mechanical Integrity Test Combined test of annular spaces Leak Loss Rate Test Integrity # Barriers Condition AOGCC Notification Enhanced Operational Restrictions Category Affected Requirements Monitoring Requirements~ Normal 0 Full wellbore integrity MIT - 4 years Water, slurry, gas, MI upon approval TxIA communication (tubing Next business day if 200 psig Annual MITIA/LLRT 3 1 leak; packer leak quantifiable) change in annulus pressure CMIT TxIA - 2 yrs Water only IAxOA communication Annual MITIA & CMIT IAxOA Water only; ermu!u: PSVw?~,'~ x, ~,~ p~,int~ 2 1 Production casing leak MIT Tubing 2 yrs .c^. ~o~,J ,,,,,~ _~,_~.,~,~ ..... ;.,,. TxIAxOA communication Kill well; submit Sundry (10403) outlining 1 >1 Release beyond wellbore Next business day Daily reports until well secured repairs ~In addition to Monthly Report of Daily Operating Parameters; Annulus Pressure Monitoring Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis 2. Production casing designed for shut-in tubing pressure 3. USDW exemption or finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: ~.~ waiver chklst.doc:8/2/2002 -- ARCO ALA,.?KA: INC. I:' 0 ~...)× i,, .~ ANCHORAGE, ALASKA 995t¢) DA'FE ' 9--28'~9~ : ~z:~:FEF:EkiCE' ARCO CA,~ED HOLE t ~ ~.., ~ i i -26 9-'5-9¢, ,"~.~TA'¥iC TEHF' RUN i .. 5" i 2. ...... ~,. ''~ c;,_..~._~;:.,, .., , ._. IN. IECTTON_ .... PP. OF]iL.E RUN i , '=";- i 2-'2 9-.-9---90 iNJECTiOK.i PROFILE F,:I. JNi , 5:" i 2-'-i S 9-6-90 PRODLJC'.'-F]]L")N PRC.iF'!L_E RLIN i , 5:" i 2.._ 2 .-i, o,. .... :._~'"" ._. o ;:-,,..., .~'r~J,, ._!F F:i"'r F,,N.~ _ . F:,ROF ILLz_ n'UN~ ..i , '5:" i '...-'~ .... 28 9-.-5 ~" 9 £:. i::' R 0 D LJ C T I 0 N P R 0 F I L E R U N i , 5" i 5-.--2 9---7-..-9,3, F'ROD[JCTION F'ROF'iLI~' RUN i ,. '5 ~ i ~'~''.- i ...-. =' 9-?-90 PRO~)LiCTION.. PROFILE RUN i , _.~":" i,_,z .... o",.-~...._.. 9-4-9¢, PRODLJCTIFiN.. PROFILE RUN i , '.ii: ~ F'i...EA2E ,?/IGN ANi;, RETLJRN 'f'HE ATTACHED COPY A2 RECE;IF"f' OF DATA, Rt?CEZV[..r.D BY ~~'~ ~ HAVE A N.IC[.r DAY! ;!i;AL..LY HOFFECt< ER C A ['."i C 0 C; A .,"i C 0 C A i",i C 0 C A H C; C C A H I'_']: 0 '..; A ('.i C: 0 C A ,'"'i C 0 C: A Fi C 0 , .' ["1 I !L,. C: A Fi C 0 DI,?TRiBUI'ION · ~ CENTRAL FIL. E~ -ii: C l..J E V R 0 N D & H ~. EXTENJ;ION EXPLORATION :~ EXXON. MARATHON ~ MOBIL -"- PHILL~[PS' PB WELL F'ILE~' R & D · "- BPX ~ eTA'YE OF ALA3KA i"EXACO P'. FFFIVED o('r o I 'Ha~,a ~i,, ~, ,.~a~ I,klllS, COIIIITII$,.., Ar.~chorage sTATE OF ALASKA ---'- ALASI'"'-- AND GAS CONSERVATION.. 41SSION REPOR'I OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well ~ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1038' FSL, 352' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, T11N, R15E, UM At effective depth At total depth 1412' FSL, 1518' FEL, Sec. 21, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic ~ervice X 6. Datum of elevation(DF or KB) 58 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-10i 9. Permit number/approval number 85-159/8-750 10. APl number 50 - 029-21394 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11555 feet Plugs(measured) 8824 feet Effective depth: measured 11505 feet true vertical 8783 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2000# Poleset 110' 110' Surface 2465' 13-3/8" 2500 sx PF 'E'& 400 sx PF 'C' 2523' 2523' Production 10858' 9-5/8" 500 sx CI 'G' 10916' 8307' Liner 862' 7" 380 sx CI 'G' 11546' 8817' Perforation depth: measured 11414-11432'; 11432-11450' true vertical 8708-8723'; 8723-8738' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10638' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10747' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV nipple @ 2183' MD; BOT HB packer @ 10642' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure o 8 ]9? 14. Prior to well operation Representative Daily Averaqe Production or Injection Data ~ ~ ~rich0ragr~_ . OiI-Bbl Gas-Md Water-Bbl Casing Pressure iud) ng Pressure .... 7697 -- 1238 Subsequent to operation 5294 -- 1297 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~=-- ' ~ Title Date Form 10-404 Rev 06/15/88 CC- ' ~,'N d d'N I1,1 I ['N ...... 'P~ Cps n-lOO u~-~ SUBMIT IN DUPLICATE DS 11-10i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE · INJECTION PROFILE MODIFICATION 6/29/89 · MI RU, and PT CT and Stimulation equipment to 4000 psi. RIH w/3" swirl nozzle , and washed perforations at: 11414- 11450' MD Ref. Log: BHCS 7/26/85. Pumped the following treatment: 24 bbls 12% HCl w/10% Xylene, followed by, 25 bbls 12% HCI - 3% HF, followed by, 26 bbls 12% HCI. Displaced CT w/seawater. POOH. Rigged down. 7/7/89 : A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/531 bbls of seawater. Pumped 50 bbls of cement, squeezing perforations : 11414 - 11450' MD Ref. Log: BHCS 7/26/85. Put 12 bbls of cement behind pipe, at a maximum squeeze pressure of 2200 psi. Contaminated cement with 113 bbls of contaminant. POOH, while displacing CT w/69 bbls of Meth-Water. Rigged down. 7/8/89- Jetted out contaminated cement from wellbore. 7/10/89' MIRU, and RIH to tag bottom at 11503' MD. POOH. Rigged down. 7/18/89: MIRU, and RIH to change out DGLV at station #1 (3010' MD), w/a 5/16" OGLV, then RIH and tagged bottom at 11489' MD. POOH. Rigged down. 7/24/89' Reperforated: 11414- 11432' MD 11432- 11450' MD Ref. Log' BHCS 7/26/85. 7/25/89- MIRU, and RIH to change out OGLV at station #1 (3010' MD), w/a POOH. Rigged down. DGLV. Well was returned to injection and a valid injection test was obtained. ARCO ALASKA, INC~ F'~O~ BOX i~8360 ANCHORAGE, ALASKA 995 ~ 0 DATE' ~2-5-89 REFERENCE° ARCO CASED HOLE FINALS ~-'26 i t'"~.~/--'89 F']:I'S ~ RUN t-29 t~-~7-'89 PITS RIJN ~, 5" t-34 t t-i 7-89 PII'S RUN 5-2t t~-t8-89 GR/CCL RUN ~, 5' 7-~6 t~-~6~'89 INJECTION F'ROFILE RUN t, 5' 7-34 tt'-t5-89 INJECTION PROFILE R~JN tt-~ tt-t9-89 PRODUC'FION ~'ROF'ILE RUN t, 5' t t-t 8 t t-I 8-89 TEMF' RUN .t i-26 t t-'t 9-89 INJECTION PROFILE I:~UN t2-22 ti-"t6-89 PRODUC'FION F'ROFILE RUN t2-~t t t-'t 7-89 INJECI'ION F'ROFILE/I'EMP RUN t4-2 tt-t8-89 PRODUCTION PROFILE RUN t, 5' t4-26 t i -'i 8-89 F'I l'~ RUN i6-t6 tt-t9-89 INJECTION PROFILE RUN t, 5' t7-t4 tt-2~-'89 PRODUCI'ION F'ROFILE RUN t 8-8 t t -28-89 F'IT~ RUN PLEASE SIGN AND REI'LIRN THE ATTACHED COPY AS REC;EIPI' OF DATA, RECEIVED BY _ HAVE A NICE DAY'!' D.~~.IVED ~LkY HOF'FE~KER *~ ~PF'ROVED ' omge DISTRIBUTION ~' CENTRAL FILES ' -,- ,- F'HII_L IF'$ ' CHEVROn. F'B WELL FILES D & M'-' --' R & D ,,-~ EXTENSION. EXPLORATION ~' BF:'X ~' EXXON -: · .' " .~. ~ ~ S I'A I'E Of:' AL. ASKA MARATHON ~ ~ I'E:'XACO ~ MOBIL CAMCO C A f'i C 0 C A H C 0 CAHCO C A H C 0 C A H C 0 CAMCO · CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ARCO ALASKA, F'~O. BOX ANCI4ORAGE, ALASKA 995 t ~) DATE' 9-27-89 REFERENCE: ARCO CASED HOLE FINALS 2-24 9-~8-89 COLLAR/PERF RUN i, 5' 3-2 9- i 5-89 COLLAR/PERF RUN 4-t 9-7-.89 NOISE RUN t, ~' 5-ii 7-8-89 SPINNER 3'URVEY RUN 6-'2i 9-1 4-89 CNL-GAMMA RUN i , 5 7-27 7-2~,-89 PERF RECORD RUN i, i'i-iO 7-24-89 F'ERF RECORD RUN ii-t~ '~ 7-2¥-89. PERF RECORD RUN i, 5 ii-iT 9/i ~-i2/89 COt_LAR/PERF RUN i 2-t S 9-i 7-89 COLLAR/PERF RUN i4-Si 9-ti-89 COLLAR/PERF / RUN i, 5 PLEA,~E SIGN AND RETURN THE- ATTACHED COPY AS RECEIPT OF DATA. ATLAS' ATLA3~ J;CH HLZ~ A'[LA~' HL:£ HL£' HL,'~ ATLA~~ ATLAS ATLA3' HAVE A NICE DAy! SALLY HOFFECKER..~'~ ©C-i'-~i~O~l APF'ROVED ~__ ATO-t 529 Oil & Cons. CommissW ...._ 'rRA S Anchomg DISTRIBUTION CENTRAL FILES CHEYRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILE~ R & D BPX STATE OF ALA:~'KA TEXACO ARCO ALASKA: INC,. P,.O· BOX i0(~360 ANCHORAGE.. ALASKA 995t Ii DATE' 9-6-89 REFERENCE- ARCO CASED HOLE FINALS t-.~.° 8-t 6-89 TEMP/FLUID DENSITY RUN t, _,~' t .-i 4 8-t 7-89 F'I-;:ODUC'FION I':'I-~OFILE RUN 1., 'S" 2--2S 8-24-89 COLLAR/F'ERF RUN t, 5" S-6 8-28-89 COLLAR/F'ERF RUN t, 5" S-'-"B 8 t e 89 PRODUCTION PROFII. E-" RUN t '-" 6-2 8-i4-89 F'RODUCTION PROFILE RUN t : 5' ii-t0 8-t8-89 INJECTION PROFILE/TEMF' RUN t, 5' ii-iS 8-2t -89 PRODUCTION PROFILE RUN i , t2-28 8-tS--89 PRODUCTION PROFILE RUN i, 5' i4-S2 8-tS-89 LEAK DETECTION RUN ...,-~ 8--20-89 PITS RUN i , :;" t7-il 8-i8-89 PRODUCTION PROFILE RUN i, ~' Pl..EASE SIGN AND RETURN THE ATTACHED C[IPY AS RECEIPT OF DATA, CAMCO CAMCO ATLAS A f'I_AS C A M (": 0 C. AMCO CAMCO CAMCO CAMCO CAMCO (;AMC[} CAMCO RECEIVED BY HA'v'E A NICE DAY! E '~ APF'RO~ED _~__ SALI_Y=.HOFFECK ER ATO-t :..".,29 ,,., ,~,~~ TRANS~ 89:%78 DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL · ,-"" PHILLIPS PB WELL Fl'LES R & D ~' BPX $ STATE OF ALASKA $ TEXACO * THE CORRECTED AF'I$ FOR t-2 IS 50-~29 ARCO Alaska, Inc. ~ Prudhoe Bay .gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 31, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS# 11-10 Permit No. 85-159 Dear Mr. Chatterton: Attached is the Application for Sundry Approval to continue Water Injection into Well 11-10 as required by Rule #7 of Area Injection Order No. 4. Very truly yours, Attachment · I~-.P. Exploration L. L. Gantt, ATO 1520 J. W. Groth, ATO 1570 T. A. Billingsley/M. A. Lucich, PRB 24 C. P. Farmer/L. J. Sennett, PRB 24 PRB Files (11-10) Oper. Eng Files (11-10) RECEIVED JUN o Alaska Oil & Gas Cons. Comr~isSion Anchorage DFS/TAB/prm ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKAj AND GAS CONSERVATION CC 'tlSSION APPLICA, FOR SUNDRY AP ,ROVALS 1. Type of Request: Abandon Suspend Operation shutdown ~ Re-enter suspended well ~ Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate 2. Name of Operator 5. Type of Well ARCO Alaska, Inc. Development Exploratory 3. Address Stratigraphic P.O. Box 100360, Anchorage, AK 99510-0360 set, ce 4. Location of well at surface 1038 FSL, 352' FEL, Sec. 28, Tll N, R15E, UM At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, T11 N, R15E, UM At effective depth At total depth 1421' FSL, 1518' FEL, Sec. 21, T11 N, R15E, UM Other X 6. Datum of elevation(DF or KB) 58' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 11-10 9. Permit number 85-159 10. APl number 50 - 029-21394 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11555 feet 8824 feet Plugs(measured) Effective depth: measured 11505 feet true vertical 8783 feet Junk(measured) Casing Length Size Structural Conductor Surface 110' 20" Intermediate 2523' 13-3/8" Production 10916' 9-5/8" Liner 862' 7" Perforation depth: measured 11414-11450' Cemented R E C E IV E easured depth o 8 ]989 2000# Poleset 110' 2900 SxAlaska Oil & Gas Cons, Commission23, 500 Sx CL 'G' Anchorage 10916' 380 SX CL 'G' 10684-11546' True vertical depth 110' 2523' 8307' 8066-8817" true vertical 8708-8738' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10642' MD, 4-1/2", 12.68, L-80 @ 10747" MD Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2183" MD, Brown HB Packer @ 10642' MD. 13. Attachments Description summary of proposal Detailed operations program __ BOP sketch 14. Estimated date for commencing operation I N/A 16. If proposal was verbally approved Mike Minder 5-30-89 Name of approver Date approved Service X 17. I hereby c,~rtify that the fore. going is true and correct to the best of my knowledge. Signed .~. ~j/<~~ Title Operations Engineering Manager FI3R C{3MMI~SIi3N U.~I= {3NLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAl. SIGNED BY I, ON~IlE C. SMITH 15. Status of well classification as: Oil Gas __ Suspended Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Approved CoPY ' BeturneC~ SUBMIT IN TRIPLICATE T. A. Billingsley PRB-24, 659-5102 INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: 5-30-89 TIME: 10:30 A.M. NOTIFIED BY: E. W. Skaalure REASON: AOGCC CONTACT: Injection Well 11-10 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 Mike Minder DISCUSSION: Well 11-10 was a production well that was converted to water injection on 1-1-89. An AOGCC witnessed MIT was performed on 12-21-88 prior to conversion and the well passed the MIT. Currently, the TBG X 9-5/8" annulus pressure will slowly increase over a 2-3 day time period to equalize with the TBG injection gradient. Another MIT was performed on 5-11-89 to 2560 psi, which bled to 2420 psi in 30 minutes, so the well passes an MIT (TBG injection pressure was 1200 psi). Since the well has gas lift mandrels, a temperature log was run to try to determine if a gas lift valve dummy was leaking, but the leak was too small to detect. It appears that there may be a slight packer leak on this well. ARCO plans to continue to operate the well on water injection and perform quarterly MIT's to monitor the leak condition. If the leak worsens, further diagnostics will be run to determine where the leak exists. AOGCC RESPONSE: OK to continue injection. A Sundry notice must be filed within a week to obtain formal AOGCC approval. Sundry Notice Req'd at this time? YES. X NO RECEIVED Alaska Oil & Oas Cons. Commission Production Support Superintendent Orig: Problem Well Eng,(T.A. Billingsley/M.A. Lucich) PRB 24 cc: Prod Sup Supt, (E.W. Skaalure/S.J. Massey)PRB 20 Sr Wireline Supv, (K.M. Kennedy/W.S. Wilder) PRB 20 Field Area Eng, (C.P. Farmer/L.J. Sennett)PRB 24 DS Supv, FSi2 FS Supt, FS#2 DS Eng, DS-R. Payne, ATO#1592 (4-25-89) !)ATE ' '"~-"26- 89 REFERENCE' ARCO CASFD HOI..E FINALS S'"9 5-~ 8'-89 S-9 5 '-' i 8'- i39 S- i ~ 5-,~'"'89 S- ~.~ ''> 5 '"' S"- 89 ,1-2 5'-2~--89 4-5 5-- i 9-89 4- ? 5- ~ 9-89 - ~ ~' 5- ~.... 89 4-2[~ 4--'i -89 ~ - .] · ~:~. 4 .~.6 ..,--~ 8-.89 5-~ 7 3-29-89 7--S~) 5.-~ 7-89 7 - S (-) 5 - i 7 - 89 9-28 S..-S0-89 ~ ~-26 5-~-89 ~ 8- ~ ~-8-..89 ~ 8-9 5-8-89 ~ 8-2S S-26....89 F'ROD, F'I:;,'OF 111..E/I..E.AK TEMF'/FI..U I D DENSITY C 0 L.. L. A R / I::' E R F: CNL-GAMHA DIFF' I'EHP iNJECTiON F'IqOF I I_E ]]N,JECI'ION F'ROF'ILE/TE. HP []NI...-['-AMMA CNL.--GAMMA CNL-t~AMMA INUE. CI'ION PROF ]i L[:' COLI_AR/F'ERF 'CNt..-GAMMA COI_LAR/PER!z COL. I_AR/PERF DUAL BURS'F TD'F-P CNL COLI_AR TO SET PATCH LEAK I~EI-ECTION INJECTION PROFILE/TEMF' F'LUID DENSITY/TEMP t'-"l_lJ I D DEN£'i TY/'I'EMP C 0 l.. l.. A R / F' E R F' I)ETILC'I ]. ON RUN i, h,'UN I, RUN i , RUN t, RUN t, I;:tJNi, RUN t, RUN t, RUN i, RIJN t , F4UN i, RUN t , I:~:LJi',,I i, RUN i, RUN t , RUN t, RLIN t , RUN t, [;:UN i , RIJN ~, I:~:I.JN i , Ir<UN ~, RUN i, PLEASE SIGN AND F(ETURN TI4E A'F'¥ACHED COPY AS RECEIP'F JIF:' DA'FA, "&.ti" II ii II It H # ii · I I i II I · · # C A Fi C O C A il C 0 ATLAS Al'LAS A T L.A S CAHI. SO C A r,! C 0 A I'LAS ~,:~ FL..A;?/ A"f LAN HL$ A TL A,S' 14LS FILS ,S'CH ,S'CFI I--IL~ CAMCO CAMCO CAHCO CAHCO I-II...,.? I.~EbEIVED BY .......... HAVE A NICE DAY! ATO-t 529 JUN Alaska Oil & Gas Cons. DISTRIBUTION ~ CENTRAL FILES ~- F'H ILi..iF'S ~ ~..HEVRON PB WELl_ FILES I) & M F;: & D "" E. XI'IENS1 ON EXf:'LOF;:AT I ON '"' BI::' X '11' 'I' ~- I.:;XXON .~ SI'A'I'E OF ALASKA HAF~:AI'HON ~ 'f EXACO · ,-'"' MOBIl.. ARCO ALASKA, INC. F'.O. BOX i00360 ANCHORAGE, ALASKA 995i 0 DATE' 5-9-89 REFERENCE: ARCO CASED HOLE FINALS i-8 4-i6-89 INJECTION PROFILE RUN i , 5' i-24 4-8-89 PRODUCTION PROFILE RUN t, 5' 2-i.'. '~ 4-23-89. TEMP . RUN i , i '&'"~' 2-'i4 4-i5-89 PRODUCTION PROFILE RUN 2'-i7 2-i7-89 SPINNER/TEMF'/FLUID I)ENS/GR RUN i, 5' 2-23 4-t 5-89 PRODUCTION F'ROFILE RUN t, 5' 4-7 4-i6-89 PRODUCTION F'ROFILE RUN i ::' 4-25 4-i8-89 SF'INNER/TEMF' RUN t, 5" 7-".25 4-i0-89 ' LEAK DETECTION RUN i, 2'&5' 9-t 4-1 3-89 F'RODUCI'iON PROFILE RUN 'ti-3 4-24-89 LEAK DETECTION RUN i, 5" ti-tO 4-t4-89 LEAK DE't'ECTION RUN i , 5' il-J6 4-i 2-89 F'RODUCTION PROFILE RUN i i2-TA 4-i9-89- F'RODUCTION LOGGING SVCS. RUN t, 5' i.-~-iO 4-2i-89 GAS LIFT SURVEY RUN i i2-29 4-23-89 TEMF' RUN i, t'&5' t3-3 4-t 4-89 LEAK DETECTION RUN 1 i3-8 4-22-89 F'RODUC'fION PROFILE RUN i, 5' i3-2SA 4-..-.S-89 MI INJECTION PROFILE RUN i, i4-2 4-i9-89 PRODUCTION PROFILE RUN i i4-i8 4-6-89 PITS RUN t, 5" i6'-ii 4-24-89 LEAK DETECTION RUN i i7-6 4-i9-89 INJECTION F'ROFILE/TEMP h,'UN i, 5" i7-8 4-t 7-89 MULTI-RATE INJECTION PROFILE RUN i, 5" t8-3 4-2i-89 PRODUCTION LOGGING SVCS. RUN t i8-7 4-'2i-89 PRODUCTION LOGGING SVCS. -RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA CENTRAL FILES ~ ~ F'HILLIF'S CHEVRON ~ ~ MOBIL EXTENSION EXPLORATION ~ ~ BF'X EXXON ~ STATE OF MARATHON ..~ TEXACO ALASKA CAMCO CAMCO CAMCO CAMCO [;ANCO CAMCO CAMCO 0 T I $ CAMCO CAMCO CAMCO CAMCO CAMCO A'I'I_A$ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMUO ATLAS A'fI_AS . . ;) 0 ' 'D fi' :')'. * THE CORRECT AF'I~- FOR 2-12 IS 5¢ -0- 9-~.r'0~. 77 ** THE CORRECT AF'I~ FOR i6-t~ IS 50-029-205i6. ARCO ALA£KA, INC. F'.O. BOX J88368 ANCHORAGE, ALASKA DATE: 3-2t-89 _ REFERENCE: ARCO CASED HOLE FINALS 2-tt 3-3-89 COLLAR/PERF RUN 5-t 3-t2-89 DUAL BURST TDT-P RUN 5-t5 3-~3-89 DUAL BURST TDT-P RUN ?-26 3-t8-89 CNL-GAMMA RUN ?-26 3-t0-89 DIFF TEMP RUN tt-9 3-9-89 PDK-tGO/GR/CCL RUN ti-~0 3-t0-89 SPINNER/TEMP RUN t t-23 3-t G-89 PDK-t ~/GR/CCL RUN ~2-3t 3-9-89 PRODUCTION PACKER RUN t 8-t ~ 3-t 3-89 COLLAR RUN t8-23 3-2-89 PRODUCTION PACKER RUN i ! t, t, t, t, t, t, t, t, PLEASE £IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY ......... HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 Ar~chorage~O~~ APPROVED __~__ DISTRIBUTION 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' ATLAS $CH $CH ATLA~ ATLAS ATLAS OTIS ATLA£ ATLAS ATLAS ATLAS CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL - PHILLIPS PB WELL FILES SAF'C £TATE OF ALASKA TEXACO ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 6, 1989 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 11-10 Approval/Permit Number: 8-957/85-159 Enclosed is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RLP:bw Enclosures CC: Standard Alaska Production Company JoAnn Graber, ATO 1478 File PI(DS11-10)WI-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ~ ~... AL, ~, OIL AND GAS CONSERVATION COMIV- ON REPORT OF SUNDRY WELL OPERA rlONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing __ Alter Casing __ Repair well__ Perforate Other x 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 Type of Well: Development Exploratory Stratigraphic Service , Location of well at surface 1038' FSL, 352' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, T10N, R15E, UM At effective depth At total depth 1412' FSL, 1518' FEL, Sec. 21, T10N, R15E, UM 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 11-10 9. Approval number 8-957 0. APl number 50-029-21394-000 1. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary: Total depth: measured I I 5 5 5 feet true vertical 8824 feet Effective depth: measured I 1505 feet true vertical 8783 feet Casing Length Size Conductor I I 0 ' 2 0" Surface 2 523' I 3-3 / 8" Production I 09 1 6' 9- 5/8" Plugs (measured) Junk (measured) Cemented- 2000# Poleset 2500 sx PF "E" 400 sx PF "C" Measureddepth True verticaldepth 110' 110' 2423' 2523' 500 sx Class G 10916' 8307' Liner 862' 7" 380 sx Class G Perforation depth' measured I I 414'- 1 1450' true vertical 8708'-8738' Tubing (size, grade, and measured depth): Packers and SSSV (type and measured depth): 10684'-1 1546' 8066'-881 7' ~cn0rar~e 5-1/2", 17~, L-80, PC, 0-10642' MD 4-1/2", 12.6~, L-80, PC, 10642-10747' MD Camco BaI-O SSSV ~ 2183' MD Brown HB Packer ~ 10642' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2000 14000 0 N/A - - 75OO N/A Tubing Pressure 2000 1525 15. Attachments 116. Status of well classification as: I Copies of Logs and surveys run __ Daily Report of Well Operations x Oil__ Gas__ Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · // : : s, ned Form 10-404 Rev 10/01/88 Service x Title ~,~f... ~, ~ , Date SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS ARCO Alaska, Inc. converted DSl1-10 from producing service to water injection service on January 2, 1989. This well is part of the Flow Station 2 waterflood project. The well was initially placed on seawater injection. ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 15, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 11-10 Permit Number: 85-159 Enclosed is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RLP:sd Enclosures cc: Standa_rd Alaska Production Company JoAnn Gruber, ATO 1478 File Pi(DS11-10)WI-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA AL~'\ OIL AND GAS CONSERVATION COMM"~"gN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Operation shutdown Alter casing Repair well Plugging Change approved program ~Pull tubing 2. Name of Operator ARCO Alaska, Inc. 5. Type of Well: 3. Address P.O. Box 100360 Anchorage, AK 99510 . Re-enter suspended well 12. Development Exploratory Stratigraphic Service Location of well at surface 1038' FSL, 352' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, T10N, R15E, UM Time extension Stimulate Variance Perforate Other x 6. Datum elevation (DF or KB) 58' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DSl1-10 9. Permit number 85- 1 5 9 10. APl number t 50-029-21394-000 1. Field/Pool Prudhoe Bay Oil Pool At effective depth At total depth 1412' FSL, 1518' FEL, Sec. 21, T10N, R15E, Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical RECEIVE I 1 5 5 5 feet Plgg,sot,~f~p~JX~ons. C0mmiss't0ti 8 8 2 4 feet"~'"*-'---~ch0rage I I 5 0 5 feet Junk (measured) 8783 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 2000# Poleset 110' 110' Surface 2523' 13-3/8" 2500 sx PF "E" 2423' 2523' 400 sx PF "C" Production 10916' 9-5/8" 500 sx Class G 10916' 8307' Liner 862' 7" 380 sx Class G 10684'-11546' 8066'-8817' Perforation depth: measured 1 1 41 4' - 1 1 4 5 0' true vertical 8708'-8738' Tubing (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2", 17#, L-80, PC, 0'-10642' MD 4-1/2", 12.6#, L-80, PC, 10642'-10747' Camco BaI-O SSSV @ 2183' MD Brown HB Packer @ 10642' MD MD 13. Attachments: Description summary of proposal x Detailed operations program BOP sketch 14. 16. Estimated date for commencing operation lQ '89 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby.,, certify tha~the fore.9oing is true and correct to the best of my knowledge. S ig ned ~// ~/'/f//~~/~_~.--~ Title ~,0..~ FOR COMMISSION USE ONLY I Plug integrity BOP .Test Mechanical Integrity Test ~ Approved by order of the Commissioner CONDITIONS OF APPROVAL: Notify Commission so representative may witness Location clearance Subsequent form required 10-'~D~ ORIGINAL SIGNED I:~-~'~'AMNI~ ~ ~MITH Commissioner Form 10-403 Rev 06/15/88 Date /o2- / 7.,,,~::~ SUBMIT IN TRIPLICATE SUMMARY OF PROPOSAL ARCO Alaska, Inc. proposes to convert DSl1~10 from producing service to water injection service. This well is part of the Flow Station 2 waterflood project. The proposed conversion should occur during the first quarter of 1989. The well will initially be on sea water injection. RLP ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 3, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-10 Approval No. 85-159 Dear Mr. Chatterton: Attached is the Application for Sundry Approvals detailing work to be performed on the above-referenced well. Very truly yours, D. P. Scheve DPs/m,~/jp Attachment Sohio Alaska Petroleum Company J. Gruber, AT0-1478 ?l(D8 ll-10)W1-3 JMV/27 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,oSION 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 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 58' RKB feet 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1038' FSL, 352' FEL, Sec. 28, TllN, R15E, UM At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, TllN, R15E, UM At effective depth At total depth 1412' FSL, 1518' FEL, Sec. 21, TllN, R15E, UM 11. Present welt condition summary Total depth: measured 11555 feet Plugs (measured) true vertical 8824 feet Effective depth: measured 11505 feet Junk (measured) true vertical 8783 feet 6. UnitorProperty name Prudhoe Bay Unit 7. Wellnumber il-10 8. Permitnumber 85-159 9. APl number 50-- 029-21394 10. Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Structural Measured depth True Vertical depth Conductor 110' 20" Surface 2523 ' 13-3/8" Intermediate 2000# Poleset 110' Sx PF "~" + 2423' O0VSx PF "C' 110' 2523' Production 10916' Liner 862' Perforation depth: measured 11414-11450' true vertical 8708-8738' Tubing (size, grade and measured depth) 9-5/8" 7" 500 Sx Class "G" 10916' 8307' 380 Sx Class "G" 10684-11546' 8066-8817' 0Ci' o ' 0il & l as 6OHS. cor missior.., 5½", 17¢/, L-80 Plastic-coated tubing @ 10642' MD; 4M"2 12.6#, L'8' ' Of~' ~:~47' MD'~ .... Packers and SSSV (type and measured depth) Camco Ba'l-0 SSS~ nipple @ 2183' M~, ~ro~m ~B Packer @ 10642' MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~ certify that the foregoing is true and correct to the best of my knowledge . TRIo /~~ Eng~_neer-~n~anager Date ./,¢//,~//~-~, Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI .Approved Copy ,/~'-_-,/.-~/~~Returned O~ ORIGINAL SIGNED BY ~ Approved by LONNIE C. SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate DS 11-10 cOiled Tubing Unit Cement Squeeze Project AFE# 797961 Preliminary Procedure 1. Make a slickline tag nm to check PBTD. 2. Shoot squeeze perfs from 11340'-11350', and 11404'-11414'. Flow and test well. 3. RIH with CT. Wash the perforations with full strength mud acid. Perform a fill cleanout if needed. Flow well to produce out all the acid. 4. RIH with CT. Fluid pack the robing with trfltered water. 5. Pump 50 bbls of cement followed by 2 bbls of water and 100 bbls of contaminant. Hold 1500 psi surface squeeze pressure for 60 minutes. Squeeze off the following perforations: Zone Perforations SPF. lA 11414'-11450' 6 6. Jet or reverse out the contaminated cement. 7. Repefforate the following interval: (Ref.: BHCS 7-26-85) Zone_ lA 8. Test the well. Perforations SP___F_F 11414-11450 FSD (Ref.: BHCS 11-2-82) Reperf Other Well Information: Current stat6SJ: On product~-~ Expected static bottomhole pressure: 3700 psi. @ 8800' SS Expected fluid in wellbore at reperfomtion: seawater. ,5 4 2 COILED TLIBI~ UNIT BOP EOU l PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLAI~0£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/1~"HYDRAULIC SLIPS 4. 5000 PSI 4 1/t~"SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX II H)RELINE BOP EOUIPMENT 1. ~OO0 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF AtlanticRichfieldCompany wr Daily Well' History-Initial Report Instructions: Prepare and submit the "initial Rel~orr' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPudd!ng should be summarized on the form giving inclusive dates only. District ' . ~ - :~ ]State Alaska ~---~" ' ' I Field Prudhoe Bay'. Auth. or W.O. no. AFE 703460 ICounty or Parish North Slope Borough Lease or Unit ADL #28322 Title Drill Alaska lWell no. Il-10 Parker 176 AP1 50-029-21394 Operator ARCO Alaska· Inc. Spudded or W.O. begun Spudded IDate 7/12/85 Date and depth as of 8:00 a.m. 7/13/85 thru 7/15/85 7/16185 7/17/85 7/18/85 7/19185 Complete record for each day reported Hour 1500 hrs. A.R.Co's W.I. · 21 66?. IPrlor status if a W.O. 13-3/8" @ 2523' 2652' (2652'), Orient'g jet bit f/KO Wt. 8.5, PV 2, YP 2, PH 10, WL --, Sol 2.5 NU diverter sys. Accept rig @ 1200 hrs, 7/12/85. Spud well @} 1500 hrs, 7/12/85. Drl 17½" hole to 2535', CBU, POH. RU & rn-~ 61 its, 13-3/8", 72#, L-80 BTC csg w/FS @ 2523'. Cmt w/2500 sx PF "E", followed by 400 sx PF "C". Displ using rig pmps, bump~ plugs. ND diverter sys. NU & tst BOPE. RIH w/BHA, drl flt equip f/2438'-2523' + 10' new hole to 2545'. Conduct formation tst to 11.2 ppg EMW. Drl 12¼" hole to 2652'. Orient Jetting assy f/KO. 13-3/8" @ 2523' 4034' (1381'), Drlg Wt. 9.0, PV 6, YP 5, PH 9.0, WL 16.2, Sol 5 Drl, jet & surv 12¼" hole to 4034'. 2588', 3/4°, N6OE, 2588 TVD, .20 VS, .29N, .50E 2956', 4°, N16-1/2W, 2956 TVD, 17.32 VS, 17.70N, .65E 3327' 6-3/4° N17-3/4W, 3325 TVD, . , . . · , 50 25 VS 49 27N, 10 04E 3785', 17-1/2°, N30W, 3771TVD, 147.38 VS, 141.92N, 44.16E 13-3/8" @ 2523' 5138' (1104'), RIH Wt. 9.1+, PV 7, YP 5, PH 9.0, WL 18.6, Sol 6 Drl & surv 12¼" hole to 5138'. ''.~ (No surv's rept'd.) 13-3/8" @ 2523' 6896' (1758'), GIH Wt. 9.1, PV 9, YP 8· PH 9, WL 17.2, Sol 6 Drl & surv 12¼" hole f/5138'-6896'. 5358', 56-1/2°, N21-3/4W, 4963 TVD, 1091VS, 1034N, 419W 5970', 57-1/2°, N18-1/2W, 5296 tVD, 1596 VS, 1516N, 595W 6592', 57-1/4°, N14-1/4W, 5631TVD, 2117 VS, 2020N, 739W 13-3/8" @ 2523' 8035' (1139'), Drlg Wt. 9.2, PV 8, YP 6, PH 8.5, WL 19, Sol 6.4 Drl & surv 12¼" hole to 8035'. 7242', 59°, N14W, 5977 TVD, 2666 VS, 2553N, 883W 7526'· 58°, N13W, 6126 TVD, 2908 VS, 2789N, 940W Oil & .... (i;as Cons. Anchorage The above is correct Signature For form preparation and ~'istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate 8/07/85 ITM Drilling Superintendent AR3B-459-1-B Number all dally well history forms con~ecutively as they are prepared for each well. {Pa~e no. 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 Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Prudhoe Bay ADL #28322 Complete record for each day while drilling or workover in progress 7/20/8.5 thru 7/22/85 7/23/85 7/24/85 7/25/85 7/26/85 JState Alaska IWell no. 11-10 13-3/8" @ 2523' 9701' (1666'), Drlg Wt. 9.6, PV 10, YP 7, PH 9.5, WL 9, Sol 9 Left part of SS surv tl in hole, POOH, rec'd sinker bar. RIH, drl, DD & surv 12¼" hole f/8025'-9701'. 7950', 58-1/2°, N15W, 6349 TVD, 3267 VS, 3139N, 1019W 8356', 59°, N12-3/4W, 6559 TVD, 3614 VS, 3477N, ll00W 8728', 55-3/4°, N13-1/4W, 6757 TVD, 3928 VS, 3784N, 1169W 8975', 48-1/4°, N12-3/4W, 6908 TVD, 4123 VS, 3974N, 1212W 9312' 47° N3E, , ; 7139 TVD, 4367 VS, 4218N, 1236W 9621', 46- /2°, N3-1/4E, 7351TVD, 4587.VS, 4443N, 1224W 13-3/8" @ 2523' 10,372' (671'), Drlg Wt. 9.6, PV 13, YP 9, PH 10, WL 8, Sol 9.5 Drl & surv 12¼" hole to 10,372'. 9,932', 44°, N3-3/4E, 7570 TVD, 4802 VS, 4663N, 1210W 10,242', 41-1/2°, N5-1/2E, 7797 TVD, 5015 VS, 4883N, 1192W 13-3/8" @ 2523' 10,970' (598'), POOH to rn 9-5/8" Csg Wt. 9.8, PV 12, YP 7, PH9.5, WL 7.6, Sol 10.9 Drl f/10,372'-10,970', 20 std short trip, C&C, POOH. 10,547', 39-3/4°, N6-1/2E, 8029 TVD, 5196 VS, 5071N, 1173W 10,732', 38-1/2°, N7-1/2E, 8172 TVD, 5308 VS, 5186N, 1158W 9-5/8" @ 10,940' 10,970' (0'), Drl FC Wt. 9.1, PV 5, YP 5, PH 8.0, WL 12, Sol 5.7 Fin rn 270 its 9-5/8", 47#/ft, BTC, L-80 cmt, FC @ 10,830', FS @ 10,914'. Cmt w/500 sx CL "G", w/l% CFR2, + .12% HR-7 CIP 6 ' 2130 hr$, 7/24/85. Displ w/rig pmp, bmp w/3000 psi; OK. LD 12~" BHA. TIH w/8~" BHA, tag FC, drl same. 9-5/8" @ 10,916' corr't 11,555' (723'), TIH Wt. 9.0, PV 5, YP 6, PH 10.5, WL 7.6, Sol 4.9 Drl to 10,980', pack'g off. LD single, wrk pipe & cond mud to 9.1 ppg. Perform LOT to 12.2 ppg EMW. Drl 8½" hole to 11,555'. The above is correct Signature For form ~3r~paratio~ see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B IDate ITitle 8/07/85 Drilling Superintendent Anchorage INumber all daily well history forms consecutively as they are prepared for each well. JPag~no. ARCO Oil and Gas ComPany Daily Well History-Final Report Instructions: Prepare and st~bmit 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. ' IAcc°unting cost center code I District I S'tate Alaska North Slope Borough I Alaska County or Parish Field Lease or Unit I Well no, Prudhoe Bay ADL //28322 ~1 11-10 Auth. or W.O. no. Title AFE 703460 Drill Parker 176 Operator A.R.Co. W.I. 21.66% ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded 7 / 12/85 Date and depth Complete record for each day reported as of 8:00 a.m. 7/27/85 thru 7/29/85 7/30/85 7/31/85 API 50-029-21394 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 1500 hrs. 7" @ 10,916' 11,501' (0'), PU BHA Wt. 9.3, PV 6, YP 4, PH 9.0, WL 7.0, Sol 5 Fin TIH, CBU, TOH. RU DA, log; tl stuck @ 11,461' (top of tl @ 11,400'). RU & strip over WL to retrv tl; rec'd fsh. RIH, make cond'g rn. RU & rn GR/CCL/DIL/SP. TIH, C&C f/7", POH. RU & rn 26 jts of 7" to 11,546'. Cmt w/380 sx C1 "G" w/5% KC1, 10% CFR-2 & .3% Halad-24. Displ using rig prop, bmp plug. PU BHA w/3½" DP, 7" @ 11,546' 11,505' PBTD, Tst csg to 3000 psi Wt. 9.4, PV 15, YP 10, PH 10.5, WL 9.0, Sol 6 Fin PU 4-3/4" DC & 3½" DP, std in derrick. TIH, wsh & drl cmt 10,092'-10,687', circ, TOH. TIH w/7" scrpr, drl cmt 10,687'-10,825'. TIH to 11,311', drl cmt 1~,31i'-11,505', cir¢, tst csg to 3000 psi. 7" @ 11,546' 11,505' PBTD, RR 9.4 Brine Displ well to brine, POOH & LDDP & BHA. Set tbg hgr, chg out tbg hgr & tbg spool, set tbg hgr & tree; tst OK. Release Rig 0400 hfs, 7-31-85. Old TO I New TD I PB Depth i 1,505' PBTD 0400 hrs. I 7/31/85 I Rotary Released rig Date J Kind of rig Oil S ±ngle I Classifications (oil, gas, etc.) Flowing Producing method Type completion (single, dual, etc.) Prudhoe Bay Official reservoir name(s) 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 IDate 8/07/85 Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C ~' .~'.L~. ~- - Number all dally well histo~ for~s consecutively they are prepared tot each woll, Oage no. Dh~lalon of AtlantlcRIchfleidComl~my_ ARCO Oil and Gas Company 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 er 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. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 703460 ICounty or Parish Lease or Unit Title North Slope Borough ADL 28322 IAccounting cost center code State Alaska Well no. 11-10 Completion WWS #1 API 50-029-21394 Operator A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun Complete Date 9/2/85 Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig 8/31/85 thru 9/03/85 9/04/85 Iotal number of wells (active or inactive) on this i ost center prior to plugging and bandonment of this well I our I Prior status if a W.O, I 1130 hrs. 0530 hrs. 7" @ 11,546' 11,505' PBTD, RIH w/Completion 9.4 ppg NaC1 Move rig f/ll-9, Accept rig @ 1130 hrs, 9-2-85. Install BPV, ND tree, NU BOPE & tst. PU & MU 4½" tailpipe & HB pkr. MU Brown PBR to 5½" & RIH to ±400'. Circ diesel/crude cap off well. Well out of balance & flow'g. RU &circ brine, PU & RIH w/5½" tbg. 7" @ 11,546' 11,505' PBTD, Move Rig 9.4 ppg NaC1 PU & rn 246 its 5½", 17#, L-80, 8rd, AB Mod, IPC tbg , & 2 its 4½", 12.6#, L-80, BTC tbg. SSSV @ 2183', retrv pkr @ 10,642'. PU SSSV land'g nipple, tst to 5000 psi. PU Gray hgr, attach control ins, tst to 5000 psi; OK. Land tbg w/BPV installed, ND BOPE, NU tree, & tst to 5000 psi; OK. Pull BPV, tst plug, displ well w/crude/diesel. Secure well, RR @ 0530 hfs, 9-4-85. Move to 11-11. TT @ 10,747' Classifications (oil, gas, etc.) 011 I New j PB 11,505' PBTD TD I Depth Date l Kind of rig 9/4/85 [ Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Prudhoe Bay 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 · ~. _..,-, ?, .e cONGDON - r~....--- For form preparation and distribu ~'fl~n~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 9/30/85 ITM Drilling Superintendent AR3B-459-3-C I'Number all daily well history forms consecutively as they are prepared for each well. no. DIvlMo~ el Atl~tl~lle, hll~dComl~Y. ADDENDUM WELL: 8~28~85 11-10 Rn CBL f/10,544' -11,494' . Drilling -Su~rinten'dent Date ARCO A[as'ka, Inc~ F'~O~ Box ~00360 Anchorage, At.~s'l<a 995 t 0 DATE' October 13 , 1986 REFERENCE' ARCO Pres'~ure Da~a ~ ~ -'i ~) ~...."~ (.). .... ,_,°~',_, F Low i ring, PBLI. ~..."ta~. ir- (;rad ien~: C a hi C 0 F'[eaz~'e ~ig~"~ and re'~urn t'he att'ached copy a.s' 'receip'.~ of Received By HAVE A NICE DAY! Ro~a nr~e Peek ATO- ~ 529 DISTRIBUT]:ON Cenf. ra[ Fi les' Ch err on D & M [:]xter~ior~ Exp Lora'l:ion Exxoi~ Narathon Mob ~ ~ ~ F'hi PB WeLl Fi Les' -¢,- R & D -.--"' $ohio · ,."" $-t'a te of A La.sl.(a $ Texaco Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Prudhoe Bay r-,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 16, 1986 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-10 Approval No. 171 Dear Mr. Chatterton: Attached is the "Subsequent" Sundry Notice detailing work performed on the above-referenced well. VT~truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Sohio Alaska Petroleum Company PI(DS ll-10)W1-3 OCT 2 0 ~Jaska 0il & Oas Cons. Comrnissbr~ Anc~ora~je JMV/27 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI.._ OIL AND GAS CONSERVATION COMN. 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, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1038' FSL, 352' FEL, Sec. 28 TllN, R15E, UM At top of productive interval ' 1050' FSL, 1568' FEL, Sec. 21, TllN, R15E, UM At effective depth At total depth 1412' FSL, 1518' FEL, Sec. 21, TllN, R15E, UM 11. Present well condition summary Total depth: measured ! 1555 feet Plugs (measured) true vertical 8824 feet 5. Datum elevation (DF or KB) 58' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 11-10 8. Approval number 171 9. APl number 50-- ~?q-?l~q4 10. Pool Prudhoe Bay 0il Pool Feet Effective depth: measured 11505 feet Junk (measured) true vertical 8783 feet Casing Length Size Cemented Structure! Measured depth True Vertical depth Conductor 110' 20" Surface 2523 ' 13-3/8" ii i ~.Vl , i iv~,l l~l.v 2000# Poleset 110' + ' 110' 2523' Production 10916' 9-5/8" Liner 862' 7" Perforation depth: measured 11414-11450' true vertical 8708-8738' ~bing(size, grade and measured depth) 500 Sx Class "G" 10916' 380 Sx Class "G" 10684-11546' 8307' 8066-8817' OCT 2 0 !986 Alaska 0il & 0ss Cons. C,,,, miss 5½", 17#, L-80 Plastic-coated tubing @ 10642' MD; 4½" 12.6#, L-80"~"[0'747' MD Packers and SSSV(type and measured depth) Camco Bal-0 SSSV nipple @ 2183 'MD, Brown HB Packer @ 10642' MD 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) 11412-11448' MD Treatment description including volumes used and final pressure Mud acid treatment 1500 gals 15% HC1, 3000 gals 6% HCi-1½% HF @ 1500 psi (final pressur. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2802 3740.6 0 0 237 2786 5092.8 0 0 267 14. Attachments Daily Report of Well Operations 1~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~-- l,~- ~ Signed ~/~J~~~ Form 10-404 Rev. 12-1-85 J. M. Vitucci. ATO-150~. 263-4418 Submit in Duplicate DRILL SITE 11-10 SELECTIVE STIMULATION TREATMENT SIIMMARY DATE PERFORMED: 9/6/86 1. ARCO Alaska, Inc. performed the following stimulation on Well 11-10: ° 1500 gals of 15% HC1 atomized with 300 SCF/BBL of N2. ° 3000 gals of 6% HC1 - 1½% HF atomized with 300 SCF/BBL of N2. ° 1000 gals of 2% NH4C1 water atomized with 300 SCF/BBL of N2. ° 8200 gals of crude atomized with 300 SCF/BBL of N2. ° 420 gals of diesel atomized with 300 SCF/BBL of N2. ° 20 MSCF of N2. ° 550 gals of diesel atomized with 300 SCF/BBL of N2. 2. The well was returned to production and tested. OCT 2 0 1986 Alaska 0il & AR[;() ALaska, Inc. F'.O. Box 40(.)~6(-) Anchorage, ALaska DAI'E: ~'ep ~ emb er REFERENCE: ARCO ~ S-"t 0 9-'t 8-86 ~4-'t 9-2t -86 ~4-'.9 9-t 0-86 '~'4-9 9.-';-t5-86 ~4-.t 0 9-t 0-86 ~'4-- t 0 9-t 5-86 ~9-t2 9-t 1/t 2-86 ~-t 2 9-t t/t 2-86 ~9-'.t 2 9--t 5-86 ~-t 7 9-.t t-86 ~9-..t 7 9-t t-86 ~9-20 9--t2-86 ~--"~9- 25 o '~ , , -~.0-8~ ~'""~' ~ 9- ~ i i -~ ~ 4-86 ~ i -~ 8 9-.28/2t -86 ~ i -i ~ 9-i S/~ 4--86 ~~i 6-2 9-'~ 5-86 995 t (-) 26, t986 Cas;ed Hol. e Final Step Ra~e Inj~ Pro fi Le/GR Run t, 5' Camco F:'roduc:~ion F'rofi Le Run t, 5" Camc:o 'letup. Log/In j, Profi Le Run t, 5" Camco In j. F'rofi Le Run t, 5" Camco Temp. Log Run t, 5" Camco Inj. F'rofi [e Run 1, 5" Camco ~pinner/Inj. Pro fi Le Run 3, 5" Camco Temp. Log Run 3, 5" Camc:o Temp. Log Run t, ~" Camco Inj. F'rofi Le Run t, 5" Camco Temp~ Log Run t, 5" Camco Inj~ Profi Le Run t, 5" Cmmco Inj F'rofi Le Run t, 5" Camco ,S'pinner/Temp. ~'urvey Run t, 5" Camco c;" C8 fdc o ~'pinner Log Run t, ., ,~pinner/Produc~ion ProfiLe Run 2, 5" Camco Temp. Log Leak De~ec~ion Run t, 5" Camco F'l. em~e ~ign and rex~~he.~'mch/~d copy~ receip~ of dmt'a, HAVE ~~~Tn~r ~, i ~Oil & Gas Cons. uummissio~ R o s a n n e/Pe e k / ~chorage ATO-~ 5~ 'FRAN~' ~:86597 DISTRIBUI'ION Cent-raL Fi Le.s -.- Chevl"oi~ -..'"' Ex'ten.sion ExpLora'l'ion. ~, Ex xon Marakhon · ~ Mob i [ . · "'-.. Phi LLips F'B Well Fi Les R & D ~ $oh i o ~ Stake of Alaska T~ Texaco ARCO Alaska, In~f ' Prudhoe B~.. _ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 3, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re' DS 11-9 DS 11-10 DS 11-11 Permit No. 85-167 Permit No. 85-159 Permit No. 85-141 It has come to my attention that there was an error in the Well Completion Reports recently submitted for DS 11-9, 11-10, and 11-11. The TVD perforation intervals listed on these reports were actually subsea depths. The corrected completion reports are enclosed. Very .truly yours, D. F. Scheve DFS/PVL'sd Enclosures cc' Standard Alaska Production Company RECF"' D SEP o 5 l~ltli Oil & ~,~, CommlSS]Oll ARCO Alaska, inc. is a Subsidiary o~ AtlanticRichfieidCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~t ,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . 1. Status of Well REVTSED Classification of Service Well OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. _ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-21394 4. Location of well at surface 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec. 28, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1050' FSL, 1568' FEL, Sec. 21, TllN, R15E, UM 11-10 At Total Depth 11. Field and Pool 1412' FSL, 1518' FEL, Sec. 21, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indiCate KB, DF, etc.) 6~ Lease Designation and Serial No. Prudhoe Bay 0il Pool 58' RKB ADL 28322 ALK 2320 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/12/85 07/26/85 07/31/85' N/A. feet MSt 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+'rVD) lg. DirectionalSurvey ] 20. Depth where SSSV set I 21. Thickness of Permafrost 11555'MD, 8824'TVD l1505'MD, 8783'TVD YES~ NO[] 2183 feet MD 1900' (Approx.) 22. Type Electric Or Other Logs Run DIL/BHCS/GR/SP, GR/CCL/DIL/SP, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf. 110' 30" 2000# PolP_.~Pt (Annrnx~ 13-3/8" i.8.0/72.0# K-55/L-80 Surf.. . 2523' . .17~" 2500 s~ PF "E" & 400 sx IF "C" 9-5/8" 47.0# L-80 Surf. 10916' 12~" 500 sx Class "G" 7" 26.0# . .L,80 10684' . 11546' 8¥' 380 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) 5¥' l 0~? ' ~ n~,~, 4~" 10747" 11412'-11448'MD 8707 '-8737 'TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED _.N/A . . 27. PRODUCTION TEST Date First Producti~)'h, 1 Method of Operation (Flowing, gas lift, etc.) April 7, 1986 J Flowing . .Date of Test HOurs TeSted PRODUCTION FOR oIL-BBL. - GA'siMcF WATER-BBL CHOKE SIZE iGAS-OILRATIO -7/16/86 ._ . 12.1 TEST PERIOD ~_ 11.90 1101,.1 z~0.8 00°I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 23_4 .... 550 24-HOUR RATE a~' 2360 2184 81 27° 28. CORE DATA Brief description of litholOgy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. S£P0 5 1986 A~aska 0ii,& .Gas Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS 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 Sadlerochit 10931' 8319' N/A GOC 11338' 8647 ' Base Sadlerochit 11452' 8740' 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my-knowledge S,gned ~/~j~~ T,t,e Oper. Eng. Mgr. 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- lng 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 '~-~-'-'~ STATE OF ALASKA '----'" /~,~-/" ALASKA OIL AND GAS cONSERVATION Cu,vlMISSION WELL COMPLETION OR RECOMpLETION REPORT AND LOO 1. Status of Well REV I S E D Classification of Service Well OIL]~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21394` 4. Location of well at surface 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec. 28, TllN, R15E, UM Prudhoe Bay Unit .. At Top Producing Interval 10. Well Number 1050' FSL, 1568' FEL, Sec. 21, TllN, R15E, UM 11-10 At Total Depth 11. Field and Pool 1412' FSL, 1518' FEL, Sec. 21, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 58' RKB -'I ADL 28322 ALK 2320 12. Date Spudded07/12/85 13' Date T'D' Reached07/26/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °flab°re [ 16' N°' °f C°mpleti°ns07/31/85* N/A feet MSL 1 17. TotalDepth (MD+TVD) 18. Plug Back Depth (MD+-rVD) 19. Directior~alSurvey I 20. Depth where SSSV set ] 21. Th,ckness of Permafrost 11555'MD, 8824'TVD l1505'MD, 8783'TVD YES ~ NO [] 2183 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/OR/SP, OR/CCL/DIL/SP, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf. 110' 30" 2000~ Pnlesc_t (Apprn×/ 13-3/8" $8.0/72.0# K-55/L-80 Surf. 2523' 17~" 2500 sg PF "E" & 400 sx ?F "C" 9-5/8" 47.0~A L-80 Surf. 10916' 12~" 500 sx Class "G" 7" 26.0# L-80 10684' 11546' 8~" 380 sx Class "G" 24. Perforations open to Production (MDiTVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5~" 11361,9. ' ] n~/,? ' 4~" 10767" 114`12'-11448'MD 8649'-8679'TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A · 27. PRODUCTION TEST Date First Production .. I Method of Operation (Flowing, gas lift, etc.) April 7, 1986! Flowin~ :-Date of-TeSt Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/16/86 12.1 TEST PERIOD ~ 1190 ll01,l 40.8 90°] 9?5 FIGTM Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 234, 550 24-HOUR RATE ~ 2360 218# 81 ~7o 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE .,- ""i' ,~..,,-~:,.-,~, ~F :%?. . Form 10~07 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERs ~ 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 Sadlerochit 10931' 8319' N/A GOC 11338 ' 8647 ' Base Sadlerochit 11452' 8740' 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Oper. Eng. Mgr. 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 (GL) 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~,07 STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COM SION APPLICA1 ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate E~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska Inc. 58 feet 3'AddresSpo Box 100360 Anchorage, AK 99510 6. Unit or Property name · Prudhoe Bay Unit 4. Location of well at surface 1038'FSL,. 352'FEL, Sec. 28, TllN, R15E, UM At top of productive interval 1050'FSL, 1568'FEL, Sec. 21, TllN, R15E, UM At effective depth At total depth 1412'FSL, 1518'FEL, Sec. 21, TllN, R15E, UM 7. Well number DS 11-10 8. Permitnumber 85-159 9. APInumber 50-- 029-21394 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11555 feet Plugs (measured) 8824 feet Effective depth: measured 11505 feet Junk (measured) true vertical 8783 feet Casing Length Size Cemented Structural Conductor 110 ' 20" To Surface Surface 2523' 13 3/8" w/2900 SX Intermediate 10916' 9 5/8" w/ 500 SX Production 862' 7" w/ 380 SX Liner Perforation depth: measured Measured depth Wue Verticaldepth 110' 109.95' 2523' 2522.68' 10916' 8306.90' 10684-11546' 8124.14-8817.0 11412-11448'MD true vertical 8707.25-8736.73' ~bing(size, grade and measured depth) 5½", 17#, L-80 Plastic Coated Tubing @ 10747'MD Packers and SSSV(type and measured depth) Brown HB Packer @ 10642'MD, CAMCO Bal-O SSSV @ 2183'MD RECEIVED J U N 1 2 1986 A~asKa O~l a u~s Cons. C0mmiss]0f~ Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [~ BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver July 1, 1986 Date approved 15. I herebv,'~ertify that the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. , ..---/ ~n arance / / [] Plug integrity [] BOP Test [] Locat'o cie I , ' ~::---~- · ~ Commissioner the commission Date Form 10-403 Rev 12-1-85 C. E. Homoky ATO 1575 ext. 6872 , Submit in triplicate Drill Site 11-10 Preliminary Procedure 2~ 1. Stimulate the well as follows: a) 900 gal of 15% HCl w/additives and atomized w/N? b) 1450 gal of 6% HC1 - 1~% HF w/additives and atomized w/N2 c) 1200 gal of 2% NHACl water atomized w/N2 d) 550 gal of gelled NHAC1 water w/550 # of BAF e) 900 gal of 15% HC1 w/additives and atomized w/N? f) 1450 gal of 6% HC1 - 1½% HF w/additives and atomized w/N2 g) 1200 gal of 2% NH4C1 water atomized w/N~ h) displace to formation w/crude atomized ~/N2 Return well to production and obtain a new profile and capacity. RFF_F_IVED J u N 1 2 1986 AlasKa Oil ~. Gas Cons. Commissio~ Anchorage CEH/16 ARCO A ka'-:ka, Ir, c. P.O. :.'qn× i£.~¢,36£-~ Anchoraqe, ALaska DATE' ~ay ~, ~986 ~S-5 4-2i- 6 3-25 ~-i :-4-86 S-S4 6-86 '-~'3-S2 4-9-86 S-SS 4-2i-86 S-S4 4- f 6-86 ~4-4 4-24-86 ~ 4-24-86 ~4-~- ~_ ~ .~ 4-27--86 ~ ,- ,~-~'7-86 9-2 4-26-86 ~li-iC~ ~ ~ ..6 ~ i -i 3 5-5-86 ~ ~-2~ 5-i " ~6-86 ~i 6-4 ~-~ ~ ~ ~-~ ~, 4-26-o,~ ~ 7-~ 4-2S-°~ Da ±a Grad Grad i e'nt Grad i e'n± Grad i e'nt Grad i ant Grad lent Grad Grad ient ~- - ~.T.. . t~Tad i c,~ * Grad i ...:a:ic .... Fiowing G-'radie'n S±a±ic ,_:,.a,: · ' "-'- ' d i ...... L-:ta i: ~ c ,~, ~ -=,,: ~* * ~'Fad'ant .-.~--3 ~. ic .5 ii'i C 0 ,.'a iff'. 'Z 0 a m c o a ,l C ('-' a ,."i'! C C) C,'.~ - = · S ffl ~,Z ':.:) .a fi'~ C ,.-.: .--'. fii C 0 C:a hie 0 Ca mc o Ca mc o a flic o .-3 i,~ C 0 a a! c o Ca ~lc o Ca [~'~c o i---,r: and --,-:=-.-+..urr~ ±h~ a*±ach~H cop>' a~ '...--ace pi of da±a. Race red By___ HAVE A NiCE DAY! irma CarLin AT0-~529 TRAM~ ~ ...... DT~TRiBUTiON C:hevro:-:. :'? ~e !_ t '.:'- i Le:T E:::T'.---Z-r,:: :: C-:-~ E:<p Lc, raT_ io'n ~ .S'--_-T: ~a ~ -Ex:-::C--'i-; ~ -!-)t.E---.--~_ of e Laska Haraihoe ~ T e .:..= :- c, :~ , STATE OF ALASKA ~ "'" ALASKA O~L AND GAS CONSERVATION Cuw~MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21394 4. Location of well at surface 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec.28, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1050' FSL, 1568' FEL, Sec.21, T11N, R15E, UM 11-10 At Total Depth I 1. Field and Pool 1412' FSL, 1518' FEL, Sec.21, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 58' RKB ADL 28322 ALK 2320 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 07/1 2/85 07/26/85 07/31/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+I-VD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 11555 'MD ,8824 'TVD 11505 'MD ,8783 'TVD YES E~X NO []I 2183 feetMD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, GR/CCL/DIL/SP, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 2000# Poleset (Approx) 13-3/8" 72.0#/68.0 L-80/K-5.~ Surf 2523' 17-1/2" 2500 sx PF "E" & 400 sx PF "C" 9-5/8" 47.0# L-80 Surf 10916' 12-1/4" 500 sx Class "G" 7" 26.0# L-80 10,684' 11546' 8-1/2" 380 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) None 5½" 1 0,747 ' 10,642 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED~1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE . . · , Form 10-407 * N0lb: lubing was run 9/~/85. GRU12/WC11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Sadlerochit GOC Base Sadl erochit MEAS. DEPTH · 10,931 ' 11,338 ' 11,452 ' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) TRUEVERT. DEPTH 8319' 8647' 8740' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I he.reby certify that the foregoing is true and correct to the best of my knowledge ~ Associate Engineer Signed ~ Title 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 (GL) 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 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 28, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 11-10 Permit No. 85-159 Enclosed is the "Subsequent" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/BJN-jj Enclosure cc: SOHIO Alaska Petroleum Co. File PI(DS 3-34)W1-3 RECEIVED APR 0 19 6 Alaska Oil & ~.'l~} Cons. Corn,'"nission AnCh~rar..}e ARCO Alaska. lqc s ~ Subsidiary of Atf~-n~,r. Richfte~dCompany STATE OF ALASKA ALAS?. ,)IL AND GAS CONSERVATION COMN, 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging Alter Casing : Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360~ Anchoraqe~ Alaska 99510 4. Location of well at surface 1038' FSL, 352' FEL, Sec. 28, T11N, R15E, UN At top of productive interval 1050' FSL, 1568' FEL, Sec. 21, T11N, R15E, UM At effective depth 5. Datum elevation (DF or KB) 58 6. Unit or Property name Prudhoe Bay Unit 7. Well number 11-10 8. Approval number 85-159 9. APl number 5o-n?q-?1394 lO. P°~udhoe-- Bay 0il Pool Feet 11. Present well condition summary 11555 Total depth: measured true vertical 8824 feet feet Plugs (measured) Effective depth: measured -11505 feet Junk (measured) true vertical 8783 feet Casing Length Size Cemented Structural .... Conductor 20" To Surface Surface 13 3/8" W/2900 SX Intermediate 9 5/8" W/500 SX Production 7" W/380 SX Liner Perforation depth: measured Measured depth 110' 2523' 10916' 10684 - 11546' 11412 - 11448' MD true vertical 8707.25 - 8736.73' ~bing(size, grade and measured depth) 5~" 17# L-80 Plastic Coated Tubing @'10747' MD Packers and SSSV(type and measured depth) Brown HB Packer @ 10642' MD= CAMEO RAI_-O SSgV 0 21R3' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Rue Vertical depth 109.95' 2522.68' 8306.90' 8124.14 - 8817.09' RECEIVED APR 3 0 1986 Alaska 0il u~, Cons. Commission Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl GasoMcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4650 6950 0 9 5/8" - 720 psi 663 psi 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 ~b~~-~~ Form 10-404 Rev. 12--1:85 Date Submit in~/~u plicate REPORT OF WELL OPERATIONS Pressure tested equipment to 3000 psig. Run in with gun #1; tie in; fire gun I (11428-11448'MD). Flowed well I hour; pull out of hole with gun 1. (All shots fired.) Run in hole with gun #2; tie in; fire gun 2 (11412-11428'MD). Flowed well 2 hours; shut in well; oull out of hole with gun 2. (All shots fired.) Rig down. CEH/20 ARCO Alaska, Inc. ~ Prudhoe Bay [ ~eering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 30, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 11-8 DS 11-9 DS 11-10 DS 11-11 DS 11-13 Permit No. 84-229 Permit No. 85-167 Permit No. 85-159 Permit No. 85-141 Permit No. 84-213 Attached are the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:GP:vh RECEIVED Attachment CC: SOHIO Alaska Petroleum Co. File Pi(DS 11-8)W1-3 Pi(DS 11-9)W1-3 Pi(DS ll-10)W1-3 Pi(DS Il-il)W1-3 PI(DS 11-13)Wl-3 JAi~ 0 2 1986 Alaska u,, Ar~chorage. ARCO Alaska, Inc. is a Subsidiary of AllanticRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 1038'FSL & 352'FEL, Sec. 28 TllN, R15E, OM At Top Producing Interval: 1050'FSL & 1562'FEL, Sec. 21, TllN, R15E, UM At Total Depth: 1412'FSL & 15!8'FEL, Sec. 21, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 58' RKB 6. Lease Designation and Serial No. ADL 28322 ALK 2320 7. Permit No. 85-159 8. APl Number 50- 029-21394 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 11-10 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [-1XX Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate DS 11-10 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: Ref: BHCS 7-26-85 11340-11354 11370-11382 11386-11450 Cons, 00rnmissi0n A, Ich0rage ;. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Operations ~.ngineering Mgr. Signed '_~,.~,.~___~ ~ ~)./~'. ~'~_~,~.~,.~. Title / The space below for Commission use Date Conditions of Approval, if any: Approved Approved }[eturned By Order of COMMISSIONER the Commission R~v 7-1-R0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 11-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU12/LI02 Enclosures RECEIVED · Alaska Oil & Gas Con-~, Cornrnissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany j~ ' STATE OF ALASKA ALASK, .... AND GAS CONSERVATION (. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21394 4. Location of well at surface ~ 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec.28, TllN, R15E, UN1'~'-~'"~'-'~'~I~ VERIFIF_~y) ! Prudhoe Bay Unit At Top Producing Interval ! Sur[. ~' : 10. Well Number 1050' FSL, 1568' FEL, Sec.21, TllN, ELSE, UM ~[ 11-10 At Total Depth 11. Field and Pool 1412' FSL, 1518' FEL, Sec.21, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 58' RKBI ADL 28322 ALK 2320 12. Date Spudded 07/12/85 13. Date T.D. Reached 07/26/85 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re I 16' N°i °f C°mpleti°ns 07/31/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 1B.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11555'HD,8824'TVD 11505'MD,8783'TVD YES I~X NO [] 2183 feet MDI 1900' (Approx) :22. Tvpe Electric or Other Logs Run DIL/BHCS/GR/SP, GR/CCL/DIL/SP, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# U-40 Surf 110' 30" 2000# Poleset (Approx) 13-3/8" 72.0#/68.03 L-80/K-55 Surf 2523' 17-1/2" 2500 sx PF "E" & 400 sx PF "C" 9-5/8" 47.0# L-80 Surf 12159' 12-1/4" 500 sx Class "G" 7" 26.0# L-80 10,684' 11546' 8-1/2" 380 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) None 5½" 10~747 ' 10~642 ' 2'~. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, 9as lift, etc.) Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO ITEST PERIOD Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ' 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, NONE :RECEIVED Form 10-407 : Tubing was run ~J/~/85. GRU12/WC11 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~L' :"'~i ~ ..'.?:":~.~ii:-"-'~.~:.. '~. ~_':~':.!'~?~'~;'~','~.~-.L ?--' :~'~:-~.".'-'-: :~- ~"::~-.. ~';~.:~' ~.:--;~-"::; ;-' ,-'.-: ~_' .... :--.'--,'";.-'-~ "-~ "-. :,'-'-,,':- . -' ....... . '" (~Eo~oG~C~M~tI~ERS' ?~"~?"-;- ;: ~¢''''~'~'''';' "-"':~'".': '~:';": '~¢'"' ": '"'" ~;';FORMATION'TESTS" ' '"~' · : . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAn. DEPTH TRUE VERT. DEPTH . GOR, and time of each phase. ; · Top Sadlerochit i'0;931 ' 8319' N/A G0C 11,338 ' 8647 ' .. Base Sad] erochit 11,452' 8740' . . .. .. 31. LIST OF ATTACHMENTS Gyrosconin Survey (2 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~/ ,~ ~,z Title Associ ate Engi neet 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 (GL) 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". F~rm 1 f)~.FI7 :'------hc:ra~e: ~ ~a-v-xa ¢955 0 8-26 .... c-n~ F;.'.u'n i 5" Sc:h F--.: ,'.i 'n i 5" :"-?,:: h Rpre red By HAYE A NiCE DAY! TRANS .--~i~ ir ~q!~k2 Oil & Gas Cons. Commissbn D T :---.' T F.'- T T-i ! ! T T F! -:.'~ Chevro'n D & N Exp[ora±ion ..:.=:: v~ces E-,,:±~mz'- i --'"' r-....., ,_ ..... ;. ,_G?at ior~ rS-:.., r a ~ h o -n ~.-4 .~ I.-. :. Phi F --:." 6: ..... Sob i c: ,~'* .1. ,t- f ' --- !: ,.z- :8 -'.E' 0 Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- DS 11-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for DS 11-10. The bottomhole location, TVDs, and geologic markers will be when the gyroscopic survey is run. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L29 Enclosure submitted ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .- ~--' STATE OF ALASKA ~ '~ ' ALASK, _ _ AND GAS CONSERVATION £ ,IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Nurr;ber P. 0. Box 100360, Anchorage, AK 99510 50- 029-21394 4. Location of well at surface 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec.28, TllN, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 11-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i I Pool 58' RKBI ADL 28322 ALK 2320 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 07/12/85 07/26/85 07/31/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) i9. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11555'MD 11505'MD YES [] NO []X 2183 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run D I L/BHCS/GR/SP,; GR/CCL/DI L/SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 2000# Poleset (Approx) 13-3/8" 72. 0#/68. 0~ L-80/K-55 Surf 2523' 17-1/2" 2500 sx PF "ETM & 400 sx~PF "C" 9-5/8" 47.0# L-80 Surf 12159' 12-1/4" 500 sx Class "G" 7" 26.0# L-80 10,684' 11546' 8-1/2" 380 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) None 5:~" 10_~ 747 ' 10: 642' 26. ACID, FRACTURE, CEMENT SQUEEZE, E'TC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing 'Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE , ' iSKB '";~ " Form 10-407 Submit in duplicate Rev. 7-1-80 * NOTE: Tubing was run 9//+/8~.C)NTINuED ~F~ERSE SIDE .... · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. · , · To be submitted w~n gyro is run. N/A _ , 31. LIST OF ATTACHMENTS .w.e!! H~ ~tory 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~)~ ~ Ass°clare Engineer Signed __ Tide 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 (GL) 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". ARCO Oil and Gas Company 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. Accounting cost center code District ICounty or Parish State Alaska II North Slope Borough Alaska Field Lease or Unit Well no. Prudhoe Bay ADL 283~2 11-10 Auth. or W.O. no. ~Title AFE 703460 I Completion WWS #1 AP1 50-029-21394 Operator A.R.Co. W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and ARCO Alaskas Inc. 21.66% Jabandonment of this well I Spudded or W.O. begun Date IHour I Prior status if a W.O. ComDlel:e 9/2/85 ! 1130 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 8/31/85 7" @ 11,546' thru 11,505' PBTD, RIH w/Completion 9/03/85 9.4 ppg NaC1 Move rig f/ll-9, Accept rig @ 1130 hrs, 9-2-85. Install BPV, ND tree, NU BOPE & tst. PU & MU 4~"' tailpipe & HB pkr. MU Brown PBR to 5½" & RIH to +400'. Circ diesel/crude cap off well. Well out of balance & flow'g. RU & circ brine, PU & RIH w/5½" tbg. 9/04/85 7" @ 11,546' 11,505' PBTD, Move Rig 9.4 ppg NaC1 PU & rn 246 its 5½", 17#, L-80, 8rd, AB Mod, IPC tbg , & 2 its 4½", 12.6#, L-80, BTC tbg. SSSV @ 2183' retrv pkr @ 10,642' , PU SSSV land'g nipple, tst to 5000 psi. PU Gray hgr, attach control Ins, tst to 5000 psi; OK. Land tbg w/BPV installed, ND BOPE, NU tree, & tst to 5000 psi; OK. Pull BPV, tst plug, displ well w/crude/diesel. Secure well, RR @ 0530 hrs, 9-4-85. Move to 11-11. TT @ 10,747' _ Old TD New TD [jPB Depth 11,505 ' PBTD Released rig Date [Kind of rig 0530 hrs. 9/4/85 J Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Prudhoe Bay Potentia~ 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 Allowabl~ ;,~ ½f~ .,~ corrected ~ ~~-" (., !:E, ff?ctive date The above is correct S~ t~ ,~~ I Date [Title ' ~ _~. ~ ~ ~oNGDO~-~ 9/30/85 - rv~ , .... For form preparation and distribu~n~ see Procedures Manual. Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. , Post Office BOx 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' July 31, 1985 Reference' ARCO Directional Surveys ._ ~%,~li~R0?:~irect ional Survey 7- 24-85 Great land 17-12'Directionai Surve~ 4-10-85 Sch t (~ ~m ,-'- ~XJ I' ~ ~L Please sign as receipt of data. Received by '"-'"~"~O,Xd O',l 4, -:0::.b. Ct)OS. . . Pam Lambert ATO 1429C Trans 243 Anchorage Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon ~tate :J~f .:Alaska Marathon - Tmxaco Mobil ARCO Alaska, Inc. Post Office Bo,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 11-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for DS 11-10. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L78 Enclosure <ECE V£D SEP 5 1985 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .--'~--' STATE OF ALASKA ALASK,. . .~.AND GAS CONSERVATION C ilSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] _ ~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-159 3. Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510 50- 029-21394 4. Location of well at surface 9. Unit or Lease Name 1038' FSL, 352' FEL, Sec.28, TllN, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run, 11-10 At Total Depth 11'. Field and Po01 To be submitted when gyro is run. Prudhoe Bay Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 58' RKBJ ADL 28322 ALK 2320 12. Date Spudded 07/1 2/85 13. Date T.D. Reached 07/26/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' No' °f C°mpleti°ns 07/31/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) i9. Directional Survey 20. Depth where SSSV set [ 21. Thickness of Permafrost 11555'ND 11505'MD YES [] NO I-~X N/A feet MDJ 1900' (Approx) 22. Type Electric or Other Logs Run ..... D I L/BHCS/GR/SP, GR/CCL/D I L/SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 2000# Poleset (approx) 13-3/8" 72.0#/68.0; L-80/K-55 Surf 2523' 17-1/2" 2500 sx PF "E" & 400 sx PF "C" 9-5/8" 47.0# L-80 Surf 10916' 12-1/4" 500 sx Class G 7" 26.0# L-80 10,684' 11546' 8-i/2" 380 sx Class G , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING R ECOR D interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) None . N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A · . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} 1 Date of Test Hours TeSted PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~TEST PERIOD ~ I Flov~ Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. C~RE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED AlasKa 0il & Gas Cons. 00mmissi0r, Anchorage, Form 10-407 TEHP2/WC05 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' '..~ . .30. . ' · ' · : :' : - : GEOLOGIC MARKERS - ' : -':-: - ' FoRMATiON TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A . . · I 31. [IST OF ATTACHMENTS -32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~_~J ~ Title Associ ate Engi neeP Date ~-/~ '<:~L~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: .Attached supplemental records for this welt 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". · SUB. SURFACE DIRECI'IONAI. URVEY ~UIDANCE ~ONTINUOU$ ~OOL ., /~ECEIVED Alaska 0il & ,Gas Cons ~nChora~ 'Con,mission Company .....A.~t~_c RICHFIELD COMPANY i i i Will Nlml Ds 1,1710 I1038,_'FSL, 352'FEL, S2,8,, TllN, R15E, UM5 Field/Location PRUDHOE BAY, NORTH SLOPE ALASKA I i I II I I I~ · JOll I~llf, ll'tl'lCl 70975 HALFACRE 18-NOVEMBER- 85 C,o_ .reputed CUDNEY GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. DS 11-10 PRUDHDE BAY NORTH SLOPE,~LASK& SURVEY DATE: 26-AUG-S5 ENGINEER: HAL~ACRE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMU'TH OF NORTH 9 DEG 52 MIN WEST ARCO ~LASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA COMPUTATION INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -58.00 100.00 99.95 41.95 200.00 199.95 141.95 300,00 299,95 241,95 400,00 399,95 341,95 500.00 499.94 441.94 600.00 599.94 541.94 700,00 699.93 641.93 800.00 799.93 741.93 900.00 899.92 841,92 1000.00 999.91 941.91 1100.00 1099.90 1041.90 1200.00 1199.89 1141.89 1300.00 1299.89 1241.89 1400.00 1399.88 1341.88 1500.00 1499.88 1441.88 1600.00 1599.87 1541.87 1700,00 1699.87 1641.87 1800.00 1799.86 1741.86 1900,00 1899.85 1841,85 2000,00 1999.84 1941.84 2100.00 2099.84 2041.84 2200.00 219'9.82 2141.82 2300,00 2299.76 2241.76 2400.00 2399.71 2341.71 2500.00 2499.68 2441.68 2600.00 2599.66 2541.66 2700.00 2699.63 2641.63 2800.00 2799,52 2741.52 2900.00 2899.36 2841.36 3000.00 2999.15 2941.15 3100.00 3098.88 3040.88 3200.00 3198.47 3140.47 3300.00 3297.94 3239.94 3400,00 3397.11 3339,11 3500.00 3495.69 343?.69 3600.00 3593.43 3535.43 3700.00 3690.04 3632.04 3800.00 3785.73 3727.73 3900,00 3880,12 3822,12 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 0 0 N 0 0 E 0 6 N 85 31 W 0 15 S 24 51 W 0 22 S 14 20 E 0 26 S 40 59 E 0 26 S 57 52 E 0 34 S 71 46 E 0 30 S 75 36 E 0 32 S 74 15 E 0 46 S 69 3 E 0 54 S 73 51 E 0 47 S 70 36 E 0 36 S 62 28 E 0 25 S 38 2 E 0 35 S 34 0 E 0 37 S 29 45 E 0 36 S 14 50 E 0 43 S 0 56 E 0 48 S 0 27 E 043 S 1 8 W 0 20 S 20 54 W 0 36 N 19 43 W 1 32 N 1 52 E 2 14 N 29 28 E 1 34 N 37 41 E 1 19 N 39 49 E 1 7 N 32 58 E 2 3 N 15 8 E 25'7 N 1 50 E 326 N 9 8 W DATE: EVEN VERTIC SECTI FEE O. --0, --0. -1. --1. --2. --2e --3. -3. 15-NOV-85 -4. --5, --5- --6e --7. --8. --9, -10 · -11. -13. -14 13: -11. "9. --6. -5, --3, --1. 2. 8. 3 59 N 16 17 W 14. 4 34 N 18 32 W 21. 5 36 N 21 44 W 30. 6 28 N 21 36 W 40. 8 20 N 18 21 W 53. 10 46 N 14 20 W 70. 13 36 N 16 51 W 91. 15 58 N 25 8 W 116. 17 53 N 29 55 W 143. 20 35 N 29 11 W 174. 100 FEET OF AL DOGLEG ON SEVERITY T DEG/IO0 O0 0.00 04 0.37 11 0.27 67 0.22 32 0.25 89 0.15 40 0.11 79 0.09 1T 0.15 69 0.42 43 0.12 15 0.41 83 0.24 42 0.05 23 0.05 16 0.23 21 0.43 38 0.13 75 0.26 09 0.28 05 1.41 94 1.49 97 1.39 12 0.22 70 0.31 03 0.16 71 0.42 67 1.98 72 0.37 27 0.49 74 0.23 92 1.87 84 0.56 95 1.66 51 1.81 14 1.30 13 2.38 38 2.64 93 2.61 93 2.58 PAGE DATE OF SURVEY: 26-AUG-85 KELLY BUSHING ELEVATION: ENGINEER: H~LFaCRE 1 5~.00 FT MEASURED DEPTH RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET F~ET 9EG MIN 0.00 N 0.00 E 0.00 0.03 N 0.04 W 0.05 0.16 S 0.24 W 0.29 0.72 S 0.25 W 0.75 1.33 S 0.07 E 1.33 1.81 S 0.64 E 1.92 2.18 S 1.47 E 2.63 2.42 S 2.38 E 3.39 2.65 S 3.26 E 4.20 2.99 S 4.29 E 5.23 3.50 S 5.77 E 6.75 3.98 S 7.21 E 8.23 4.47 S 8.33 E 9.45 4.96 S 8.9~9 E 10.26 5.69 S 9.47 E 11.,05 6.54 S 10.04 E 11.98 7.52 S 10.50 E 12.91 8.70 S 10.60 E 13.71 10.08 S 10.60 E 14.63 11.45 S 10.60 E 115.60 12.45 S 10.43 E 16.24 12.34 S 10.38 E 16.13 10.40 S 10.04 E 14.46 7.30 S 11.24 E 13.40 4.54 S 12.97 E 13.74 2.58 S 14.53 E 14.76 1.01 S 15.81 E 15,84 1.22 N 16.79 E 16.84 5.80 N 17.44 E 18.37 11.36 N 17.07 E 20.50 17.66 N 15.50 E 23.49 24.59 N 13.47 E 28.04 33.07 N 10.18 E 34.61 42.6,8 N 6.44 E 43.16 54.68 N 2.15 E 54.73 70.77 N 2.49 W 70.81 91.09 N 8.12 W 91.45 115.09 N 17.44 W 116.41 140.67 N 31.16 W 144.08 169.28 N 47.58 W 175.84 N 0 0 E N 50 16 W S 57 35 W S 19 23 W S 3 4 E S 19 36(' S 34 4~ S 44 28 E S .50 50 E S 35 4 E S 58 47 E S 61 6 E S 61 47 E S 61 6 E S 58 59 E S 56 55 E S 54 22 E S 50 38 E S 46 26 E S 42 47 E S 39 58 E S 40 3 E S 43 58 E S 56 58 E S 70 42 F S 79 55~< S 86 19 ~ N ,35 50 E N 71 36 E N 56 ZO E N 41 16 E N 28 42 E N 17 6 E N 8 34 E N 2 15 E N 2 0 W N 5 5 W N 8 37 W N 12 29 W N 15 42 W ARCO ALASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 4000.00 3972.93 4100.00 4063.99 4200.00 4152.80 4300.00 4239.07 4400.00 4322.87 4500.00 4403,85 4600.00 4481.04 4700,00 4555.04 4800.00 4625.60 4900.00 4692.18 5000.00 4754.76 5100.00 4812.81 5200.00 4867.87 5300.00 4922.84 5400.00 4977.90 5500.00 5033.32 5600.00 5088.47 5700.00 5143.21 5800.00 5197.74 5900.00 5251.79 6000.00 5305.29 6100.00 5359,19 6200.00 5413.37 6300.00 5467.18 6400.00 5521.36 6500.00 5576.77 6600.00 5631.64 6700.00 5686.19 6800.00 5739.83 6900.00 5793.36 7000.00 5846,38 7100.00 5898.80 7200.00 5951.03 7300.00 6002.57 7400.00 6054.29 7500,00 6106.29 7600.00 6158.03 7700.00 6209.75 7800.00 6261.11 7900.00 6312.28 COMPUTATION INTERPOLATED VALUES FOR SUB-SEA VERTICAL DEPTH 3914.93 4005.99 4094.80 4181.07 4264.87 4345.85 4423.04 449?,04 4567.60 4634.18 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 23 7 25 51 28 45 31 53 34 16 37 49 40 47 43 42 46 35 49 51 4696.76 52 41 4754.81 56 0 4809.87 56 42 4864.84 56 45 4919.90 56 21 4975.32 56 27 5030.47 56 34 5085.21 56 54 5139.74 57 1 5193.79 57 37 5247.29 57 29 5301.19 57 21 5355.37 57 12 5409.18 57 29 5463.36 56 37 5518.77 56 33 5573.64 56 54 5628.19 57 10 5681.83 57 47 5735.36 57 46 5788.38 58 8 5840.80 58 29 5893.03 58 42 5944.57 58 52 5996.29 58 48 6048.29 58 49 6100.03 58 49 6151.75 58 54 6203.11 59 15 6254.28 59 10 N 27 24 W N 25 47 W N 24 26 W N 23 25 W N 22 15 W N 22 19 W N 22 20 W N 22 6 W N 22 7 W N 22 35 W N 22 37 W N 22 22 W N 22 18 W N 22 29 W N 21 54 W N 21 20 W N 20 59 W N 20 48 W N 20 9 W N 19 30 W N 18 58 W N 18 29 W N 17 34 W N 17 19 W N 16 53 W N 16 39 W N 15 59 W N 15 38 W N 15 41 W N 15 35 W N 15 42 W N 15 41 W N 15 27 W N 14 32 W N 14 18 W N 14 15 W N 14 9 W N 13 56 W N 13 49 W N 13 44 W DATE: 15-NOV-B5 EVEN 100 FEET VERTICAL DDGL SECTION SEVE FEET DEG/ 210.21 249.78 294.12 343.13 396.33 453.62 515.66 581.32 650.57 723.39 799.43 878.86 960,39 1041.93 1123.44 1204.94 1286.74 1368.89 1451.24 1534.10 1617.48 1700.70 1783.90 1867.47 1950.84 2033.47 2116.55 2199.91 2283.83 2367.93 2452.29 2537.01 2621.85 2707.20 2792.53 2877.69 2963.01 3048.36 3133.96 3219.67 PAGE DATE OF SURVEY: 26-AUG-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE MEASURED DEPTH EG RECTANGULAR RITY NORTH/SOUTH 100 FEET 2.73 3.68 3.29 2.95 2.90 4.24 3.28 2.86 3.19 3.21 3.75 2.27 1.04 0.57 0.85 0.47 1.00 0.54 1.08 0.91 0.67 0.92 1.17 0.09 1.38 1.75 0.52 O. 33 0.80 1.52 2 56.00 FT 0.19 0.72 1.73 0.49 0.39 0.76 0.44 0.48 0.96 0.49 COORDINATES HORIZ. DEP4RTURE EAST/WEST gIST. 4ZIMUTH FEET FEET O:G MIN 202.02 N 65.23 W 212.29 238.97 N 83.67 W 253.20 280.60 N 103.11 W 298.95 326.78 N 123.63 W 349.39 377.11 N 144.69 W 403.92 431.40 N 166.90 W 462.56 490.15 N 191.14 W 525.10 552.38 N 216.60 W 593.33 618.03 N 243.24 W 664.17 687.00 N 271.63 W 738.75 758.96 N 301.69 W 816.73 834.17 N 332.86 W 898.13 911.42 N 364,46 W 981.59 988.63 N 396.36 W 1055.13 1065.86 N 428.04 W 1148.60 1143.26 N 458.69 W 1231.84 1221.04 N 488.83 W 1315.25 1299.23 N 518.66 W 1398.93 1377.69 N 548.16 W 1482.74 1456,83 N 576.68 W 1566.82 1536.65 N 1616.40 N 1696.34 N 1776.78 N 1857.08 N 1936.78 N 2017.03 N 2097.67 N 2178.96 N 2260.32 N N 17 53 W N 19 17 W N 20 10 W N 20 43 W N 20 59 w N 21 9~ N 21 18 :: N 21 24 W N 21 29 W N 21 34 W 2341.98 2423.96 2506.08 2588.85 2671.78 2754.56 2837.49 2920.50 3003.80 3087.23 N Z1 40 W N 21 45 W N 21 47 W N 21 50 W N 21 52 W N 21 51W N 21 49 W N 21 45 W N 21 41W N Z1 35 W 604.40 W 1651.24 N 21 28 W 631.51 W 1735.38 N 21 20 W 657.43 W 1819.28 N 21 11 W 682.63 W 1903.40 N 21 0 W 707.45 W 1987.27 N 20 51 ~ 731.49 W 2070.31 N 20 41 ( 754.91 W 2153.67 N 20 31 "% 777.73 W 2237.21 N 20 20 W 800.43 W 2321.32 N ZO 10 W 823.11 W 2405.53 N 20 0 W N 845,92 W 2490.07 N 868.98 W 2575.01 N 891.97 W 2660.08 N 914.15 W 2745.51 N 935.33 W 2830.76 N 956.35 W 2915.86 N 977.48 W 3001.14 N 998.30 W 3086.41 N 1018.89 W 3171.90 N 1039.40 W 3257,50 N 19 51 W N 19 43 W N 19 35 W N 19 26 W N 19 17 W N 19 8 W N 19 OW N 18 52 W N 18 44 W N 18 36 W COMPUTATION ARCO ALASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN BO00.O0 6363,54 6305.54 8100,00 6414,65 6356,65 8200,00 6465,86 6407,86 8300,00 6517,32 6459,32 8400,00 6569,20 6511,20 8500,00 6621,81 6563,81 8600,00 6675,39 6617,39 8700,00 6730,23 6672,23 8800,00 6787,05 6729,05 8900,00 6847,67 6789,67 58 59 N 13 21 W 59 20 N 13 56 W 59 10 N 14 2 W 58 52 N 13 51 W 58 32 N 14 11 W 57 47 N 14 30 W 57 17 N 14 55 W 56 16 N 15 0 W 54 16 N 15 4 W 50 57 N 14 40 W 9000.00 6913.00 6855.00 9100.00 6982.02 6924.02 9200,00 7050,47 6992,47 9300,00 7118,57 7060,57 9400,00 7186,89 7128,89 9500,00 7255,74 7197,74 9600,00 7325,49 7267,49 9700,00 7395,68 7337,68 9800.00 7466.25 7408.25 9900,00 7537,59 7479,59 47 21 N 14 33 W 46 28 N 11 36 W 47 8 N 3 20 W 47 0 N 1 47 E 46 54 N 2 3 E 45 59 N 2 38 E 45 37 N 2 45 E 45 15 N 2 54 E 4~+ 44 N 3 1 E 44 18 N 3 23 E 10000,00 7609,44 7551,44 10100,00 7681,86 7623,86 10200,00 7755,30 '7697,30 10300,00 7830,01 7772,01 10400,00 7905,63 7847,63 10500,00 7981,88 7923,88 10600,00 8058,81 8000,81 10700,00 8136.58 8078'58 10800.00 8215.00 8157.00 10900,00 8294,13 8236.13 43 47 N 3 31 E '43 15 N 3 40 E. 42 17 N 3 4'9 E 41 13 N 4 22 E 40 35 N 4 39 E 40 7 N 4 58 E 39 19 N 5 25 E 38 38 N 6 9 E 38 6 N 6 45 E 37 21 N 7 34 E 11000.00 8373.92 8315.92 11100.00 8454.31 8396.31 11200.00 8535.03 8477,03 11300,00 8615.87 8557,87 11400,00 8697,42 8639,42 11500.00 87'79.31 8721.31 11555.00 8824,48 8766,48 '36 54 N 8 23 E 36 17 N 8 8 E 35 12 N ? 31 E 35 38 N 7 26 E 35 8 N 7 53 E 34 47 N 7 43 E 34 47 N 7 43 E DATE: 15-NOV-85 EVEN 100 FEET OF VERTICAL DOGLEG SECTION SEVERITY FEET DEG/iO0 3305.35 0.46 3391,12 1,14 3476,79 0,32 3562.31 0,79 3647.59 0,61 3732,3? 1,21 3816,50 1,75 3899,79 1,39 3981,73 2,73 4060,95 3,69 PAGE DATE DF SURVEY: 26-AUG-85 KELLY BUSHING ELEVATION: ENGINEER: H4LFACRE MEASURED DEPTH RECTANGULAR COOROiNATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FEET FEET FEET 3170,71 N 1059.49 W 3343,04 3254.22 N 1079,84 W 3428.70 3337.56 N 1100.62 W 3514,35 3420.77 N 1121.30 W 3599.86 3503,77 N 1141,83 W 3685.12 3586,16 N 1162,84 W 3769,98 3667,81 N 1184,34 W 3854,28 3748,60 N 1205,92 W 3937,79 3828,04 N 1227.37 W 4019,99 3904,92 N 1247,67 W 4099,40 3 58,00 FT 4136,37 4,36 3978,13 N 1266,88 W 4174,98 4208.55 5,57 4048,39 N 1284,12 W 4247,17 4281,31 6,64 4120,59 N 1293,68 W 4318,89 4353,40 0,69 4193,79 N 1293,49 W 438.3,74 4424,91 0,6'9 4266,78 N 1291,14 W 4457,85 4495,77 0,32 4339,22 N 1288,17 W 4526,39 4565,73 0,31 4410,81 N 1284,82 W 4594,13 4635,21 0.70 4481,95 N 1281,31 W 4661,50 4704.29 0,63 4552,70 N 1277,65 W 4728,58 4772.56 0,61 4622,67 N 1273,76 W 4794,95 4840,26 1,19 4907,31 1,36 4973,28 1,04 5037,78 0.70 5101.16 1.02 5163,77 0,97 5225.46 0,99 5286,02 3,16 5345.56 1,79 5404,04 1,67 4692.11 N 1269.64 W 4860.85 4760.92 N 1265.25 W 4926.18 4828,66 N 1260.83 W 4990.55 4894.94 N 1256,14 W 5053.55 4960,18 N 1250,94 W 5115,49 5024,65 N'1245,59 W 5176,74 5088.29 N 1239.77 W 5237.15 5150,84 N 1233,51 W 5296.48 5212,49 N 1226,52 W 5354,B5 5273.16 N 1218.95 W 5412.22 5461,37 1,46 5332,83 N 1210,46 W 5468,48 5517,84 1,00 5391,67 N 1201,74 W 5523,97 5574,13 0,43 5450,16 N 1193,90 W 5579,40 5630,31 1,25 5508,53 N 1186.18 W 5634,80 5685,48 0,58 5565,87 N 1178,44 W 5689,26 5740,19 0,00 5622,75 N 1170,68 W 5743.33 5770,10 0,00 5653,84 N 116b,46 W 5772.92 DEP4RTURE AZIMUTH DEG MIN N 18 28 W N 18 21 W N 18 15 W N 18 8 W N 1.2 3 N 17 57( N 17 53 ~ N 17 49 W N 17 46 W N 17 43 W N 17 39 W N 17 35 W N 17 25 W N 17 8 W N 16 50 W N 16 32 W N 16 14 W N 15 57 W N 15 40 W N 15 24 W N 15 8 W N 14 52 W N 14 38 W N 14 23 W N 14 9 ~ N 13 55 N 13 41 N 13 28 W N 13 14 W N 13 OW N 12 47 W N 12 33 W N 12 21 W N 12 9 W N 11 57 W Nil 45 W N 11 3'9 W ARCO ALASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPE,ALASK~ COMPUTATION TRUE MEASURED VERTIC DEPTH DEPT 0.00 O. 1000.00 999. 2000.00 1999. 3000.00 2999. 4000.00 3972. 5000.00 4754. 6000.00 5305. 7000.00 5846. 8000.00 6363. 9000.00 6913. 10000.00 7609. 11000.00 $373. 11555.00 8824. INTERPOLATED VALUES FOR DATE: 15-NOV-85 EVEN 1000 SUB-SEA COURSE VERTICAL AL VERTICAL DEVIATION AZIMUTH SECTION H DEPTH PEG MIN OEG MIN FEET O0 -58.00 0 0 N 0 0 E 91 941.91 0 54 S 73 51 E 84 1941.84 0 20 S ZO 54 W 15 2941.15 3 59 N 16 17 W 93 3914.93 23 7 N 27 24 W 76 4696.76 52 41 N 22 37 W 29 5247.29 57 29 N 18 58 W 38 5788.38 58 8 N 15 42 W 54 6305.54 58 59 N 13 21 W O0 6855,00 47 21 N 14 33 W 44 7551.44 43 47 N 3 31 E 92 8315.92 36 54 N 8 23 E 48 8766.48 34 47 N 7 43 E 0.00 -4.43 -14.05 14.74 210.21 799.43 1517.48 2452.29 3305.35 4136.37 4840.26 5461.37 5770.10 FEET OF DOGLEG SEVERITY PEG/lO0 0.00 0.12 1.41 0.23 2.73 3.75 0.67 0.19 0.46 4.36 1.19 1.46 0.00 PAGE DATE OF SURVEY: 26-AUG-85 KELLY BUSHING ELEVATION: ENGINEER: H&LFACRE 4 58.00 FT MEASURED DEPT RECTANGULAR COORDINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FEET FEET FEET 0.00 N 0.00 E 0.00 3.50 S 5.77 E 5.75 12.45 S 10.43 E 15.24 17.66 N 15.50 E 23.49 202.02 N 65.23 W 212.29 758.96 N 301.69 W 816.73 1536.65 N 604.40 W 1651.24 2341.98 N 845.92 W 2490.07 3170.71 N 1059.49 W 3343.04 3978.13 N 1266.88 W 4174.98 4692.11 N 1269.64 W 4860.85 5332.83 N 1210.46 W 5468.48 5653.84 N 1166.46 W 5772.92 OEP&RTURE AZIMUTH DES MIN N 0 0 S 58 47 S 39 58 N 41 16 N 17 53 N Zl 40(' N 21 N 19 51 N 18 28 N 1? 39 N 15 N 12 47 W N 11 39 W ARCO ALASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPEgALASKA COMPUTATION DATE: 15-NOV-85 INTERPOLATED VALUES FOR EVEN IO0 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTIC,~L DEPTH DEPTH DEPTH 0.00 0.00 -58.00 58.05 58.00 0.00 158.05 158.00 100.00 258.05 258.00 200.00 358.05 358.00 300.00 458.06 458.00 400.00 558.06 558.00 500.00 658.06 658.00 600.00 758.07 758.00 700.00 858.07 858.00 800.00 958.08 958.00 900.00 1058.10 1058.00 1000.00 1158.11 1158.00 1100.00 1258.11 1258.00 1200.00 1358.11 1358.00 1300.00 1458.12 1458.00 1400.00 1558.12 1558.00 1500.00 1658.13 1658.00 1600.00 1758.14 1758.00 1700.00 1858.15 1858.00 1800.00 1958.16 1958.00 1900.00 2058.16 2058.00, 2000.00 2158.17 2158.00 2100.00 2258.20 2258.00 2200.00 2358.27 2358.00 2300.00 2458.31 2458.00 2400.00 2558.33 2558.00 2500.00 2658.36 2658.00 2600.00 2758.43 2758.00 2700.00 2858.57 2858.00 2800.00 2958.75 2958.00 2900.00 3059.00 3058.00 3000.00 3159.35 3158.00 3100.00 3259.83 3258.00 3200.00 3360.51 3358.00 3300.00 3461.66 3458.00 3400.00 3563.61 3558.00 3500.00 3666.71 3658.00 3600.00 3770.92 3758.00 3700.00 3876.41 3858.00 3800.00 COURSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MIN FEET OEG/iO0 0 0 N 0 0 E O, O0 0 . O0 0 6 N 38 31 E 0,00 1,22 0 10 S 46 3 W 0,01 0,37 0 21 S 2 39 E -0,40 0,18 0 23 S 30 9 E -1.04 0.34 0 25 S 51 28 E -1.67 0.09 0 32 S 67 16 E -2.19 0.15 0 31 S 76 11 E -2.64 0.06 0 30 S 75 53 E -3.01 O.1T 0 37 S 71 32 E -3.43 0.27 0 56 S 71 45 E -4.13 0.19 0 52 S 70 56 E -4.85 0.21 0 41 S 65 14 E -5.55 0.18 0 24 S 48 38 E -6.16 0.27 0 31 S 31 46 E -6.84 0.29 0 33 S 35 42 E -7.76 0.06 0 36 S 25 53 E -8.77 0.16 0 42 S 3 14 E -9.87 0.20 0 48 S 1 27 W -11.15 0.52 0 46 S 0 5 W -12,55 0,09 0 34 S 11 38 W -13.72 0.32 0 5 N 32 10 E -14.14 0.48 1 13 N 11 10 W -12.96 0.53 2 0 N 2~ 47 E -10.36 1.29 1 42 N 32 16 E -7.52 1.30 1 23 N 38 39 E -5.68 0.42 1 4 N 40 7 E -4.25 0.46 1 23 N 23 46 E -2.77 1.58 2 45 N 6 52 E 0,68 1,33 3 15 N 4 41 W 5.85 O.TT 3 46 N 15 10 W 11.95 0.72 4 7 N 15 42 W 18.87 0.77 5 21 N 21 37 W 27.04 0.71 5 56 N 20 54 W 36.71 0.74 T 28 N 18 55 W 48,13 2,17 10 8 N 15 10 W 63,15 3,69 12 42 N 16 14 W 82.89 3.26 15 21 N 22 38 W 107.64 2.97 17 16 N 29 18 W 135.69 1.87 19 58 N 29 35 W 167,20 2,83 PAGE DATE O~ SURVEY: 26-AUG-83 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 5 58,00 FT SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 0,00 N 0,00 E 0,00 0,00 N 0,02 W 0,02 0,02 S 0,16 W 0,15 0,46 S 0,29 W 0.54 1,08 S 0,11 W 1,09 1.63 S 0.39 E 1.68 2.0~ S 1.09 E 2.31 2.33 S 2.01 E 3.08 2.55 S 2.89 E 3.85 2,82 S 3.81 E 4.74 3.30 S 5.13 E 6.10 3.77 S 6.62 E 7.62 4.25 S 7.90 E 8.97 4.73 S 8.78 E 9.97 5.34 S 9.24 E 10.67 6.18 S 9.81 E 11.59 7.10 S 10.34 E 12.54 8.18 S 10.58 E 13.37 9.47 S 10,59 E 14.21 10,89 S 10,60 E 15.20 1Z.lO S 10.53 E 16.04 12.54 S 10.44 E 16.31 11.3'9 S 10.13 E 15.25 8,69 S 10,50 E 13.63 5.49 S 12.28 E 13.45 3.34 S 13.91 E 14.31 1.65 S 15.35 E 15.43 0.04 N 16.40 E 16.40 3.70 N 17.30 E 17.69 8.96 N 17.36 E 19.54 14,96 N 16,27 E 22,10 21,65 N 14,36 E 25,98 2'9,47 N 11,63 E 31,68 38.65 N 8.00 E 39.47 49.52 N 3,87 E 49.68 63.98 N 0.'?0 W 63.98 83.13 N 5.76 W 83.33 106.86 N 13.77 W 107.74 133.06 N 26.82 W 135.73 162.13 N 43.56 W 167.88 N 0 0 E N 98 OW S 32 22 W S 32 9 W S 6 1 .~ S 13 28(I' S 28 3-,~. S 40 46 E S 48 30 E S 53 27 E S 57 12 E S 50 20 E S 61 41 E S 61 41 E S 59 58 E S 57 47 E S 55 29 E S 52 17 E S 48 12 E S 44 13 E S 41 2 E S 39 45 E S 41 39 E S 50 23 E S 65 53 ,F S 76 29 { S 53 52' N 8'9 50 N 77 55 N 62 42 E N 47 24 E N 33 33 5 N 21 31 E N 11 41 : N , 28 N 0 37 W N 3 57 W N 7 20 W N 11 23 W N 15 2 W ARCO ALASKA, INC. DS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA COMPUTATION INTERPOLATED VALUES FOR DATE: 15-NOV-85 EVEN 100 FEET OF TRUE SUB-SEA COURSE VERTICAL DOGLEG MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY DEPTH OEPTH DEPTH OEG MIN OEG MIN FEET OEG/IO0 3983.77 3958.00 4093.34 4058.00 4205.92 4158.00 4322.37 4258.00 4442.86 4358.00 4569.79 4458,00 4704,09 4558,00 4847,86 4658,00 5005,31 4758,00 5181,97 4858,00 5364,00 4958.00 5544,70 5058,00 5727.11 5158,00 5911.60 5258,00 6097.80 5358.00 6282.92 5458.00 6466.10 5558,00 6648,19 5658,00 6833,99 5758,00 7022.04 5858.00 3900.00 22 41 N 27 43 W 4000,00 25 38 N 25 53 W 4100,00 28 56 N 24 23 W 4200.00 32 28 N 23 5 W 4300.00 35 39 N 22 13 W 4400.00 39 59 N 22 24 W 4500,00 43 49 N 22 5 W 4600.00 48 14 N 22 22 W 4700.00 52 51 N 22 37 W 4800.00 56 44 N 22 13 W 4900,00 56 30 N 22 14 W 5000,00 56 31 N 21 12 W 5100.00 56 53 N 20 43 W 5200.00 57 41 N 19 23 W 5300,00 57 21 N 18 31 W 5400.00 57 30 N 17 19 W 5500.00 56 16 N 16 46 W 5600,00 56 52 N 15 48 W 5700,00 57 39 N 15 33 W 5800,00 58 15 N 15 43 W 5900,00 58 53 N 15 22 W 6000,00 58 47 N 14 19 W 6100,00 58 49 N 14 9 W 6200.00 59 13 N 13 49 W 6300.00 59 2 N 13 21 W 6400,00 59 12 N 14 2 W 6500,00 58 38 N 14 3 W 6600,00 57 37 N 14 48 W 6700.00 55 22 N 15 6 W 6800.00 50 20 N 14 42 W 6900,00 46 7 N 13 39 W 7000,00 47 9 N 2 20 W 7100,00 46 51 N 1 47 E 7200.00 45 58 N 2 38 E 7300.00 45 24 N 2 49 E 7400,00 44 48 N 3 0 E 7500.00 44 8 N 3 20 E 7600.00 43 35 N 3 44 E 7700.00 42 15 N 3 49 E 7800.00 40 56 N 4 31 5 7213,47 5958,00 7407,17 6058,00 7599,95 6158,00 7793,95 6258,00 7989.25 6358.00 8184.66 6458.00 8378.51 6558,00 8567,58 6658,00 8749,50 6758,00 8916,27 6858,00 9065,25 6958,00 9211,09 7058,00 9357,69 7158,00 9503,24 7258,00 9646,41 7358,00 9788,37 7458,00 9928,49 7558,00 10067,14 7658,00 10203,65 7758,00 10337,12 7858,00 204.17 2.77 246.99 3.66 296,87 3.40 354,73 2.43 420.31 3.21 496.58 2.17 584.09 2.95 684.97 2.90 803.53 4.13 945.66 1.26 1094.12 0.80 1241.47 0.41 1391.19 0.67 1543.76 1.01 1698,86 0,88 1853,19 0.14 2005,44 0,21 2156,67 0,60 2312.47 0,61 2470.92. 0.74 2633.32 1,71 2798.65 0,49 2962.97 0.44 3128.78 0.83 3296.16 0.71 3463,65 0.34 3629.30 0,83 3789,24 1.78 3940,59 1,87 4073,47 3,89 4183,47 3.26 4289.40 6.95 4394.65 0,56 4498,04 0,33 4598.04 0,23 4696.30 0.58 4791,90 0.62 4885.35 1.27 4975,67 1.14 5061.40 1.82 PAGE 6 DATE OF SU2VEY: 26-AUG-85 KELLY BUSHING ELEVATION: 58.00 ENGINEER: HALFACRE FT SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. &ZIMUTH FEET FEET FEET DEG MIN 196,40 N 62.31 W 206.05 N 1T 36 W 230,37 N 82.41 W 250.32 N 19 13 W 283.19 N 104.29 W 301.78 N 20 13 W 337.73 N 128.34 W 361.30 N 20 48 W 399.84 N 153.97 W 428.46 N 21 3 W 472.0~ N 183.70 W 506.57 N 21 15{' 555.00 N 217.66 W 596.16 N Z1 24 -,. 650.63 N 256.56 W 699.39 N 21 31 W 762.84 N 303.31 W 820.93 N 21 40 W 897.46 N 358.75 W 966.51 N 21 47 W 1038.06 N 416.76 W 1118.60 N 21 52 W 1177.98 N 472.20 W 1269.10 N 21 50 W 1320,47 N 526.71 W 1421.64 N Z1 44 W 1466,08 N 579,93 W 1576,61 N 21 34 W 1614,64 N 630,91 W 1733.52 N 21 20 W 1763.03 N 678,34 W 1889,02 g 21 2 W 1909.74 N 723.35 W 2042,14 N 20 44 W 2055.83 N 765.97 W 2193.88 N 20 26 W 2206,63 N 80~,17 W 2349.96 N 20 6 W 2360.01 N 350.99 W 2508.75 N 19 49 W 2517,19 N 895.03 W 2671.58 N 19 34 W 2677,72 N 936.85 W 2836,88 N 19 16 W 2837,45 N 977.47 W 3001.09 N 19 0 W 2998.76 N 1017.64 W 3166.72 N 18 44 W 3161.74 N 1057.37 W 3333.86 N 18 29 W 3324.78 N 1097.42 W 3501.21 N 18 15 '( 3485,97 N 1137,34 W 3666.82 N 18 4 3641.37 N 1177.29 W 3826.96 N 17 54 W 3788.16 N 1216.59 W 3978.72 N 17 48 W 3917,07 N 1250.87 W 4111.95 N 17 42 W 4023.91 N 1278.55 W 4222.15 N 17 37 W 4128.72 N 1294.12 W 4326.79 N 17 24 W 4235.88 N 1292.16 W 4428.59 N 16 57 W 4341.54 N 1288,06 W 4528,59 N 16 31 W 4443.89 N 1283,20 W 4625,45 N 16 6 W 4544,52 N 1278,09 W 4720.82 N 15 42 W 4642.50 N 1272.60 W 4813.77 N 15 .19 W 4738.38 N 1266.73 W 4904.78 N 14 58 W 4831.11 N 1260,67 W 4992.89 N 14 37 W 4919.24 N 1254,24 W 5076.62 N 14 18 W COMPUTATION ARCO ALASKA, INC. OS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA DATE: 15-NOV-85 INTERPOLATED VALUES FOR EVEN lO0 FEET OF COURSE VERTICAL OOGLEG OEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MIN FEET DEG/IO0 TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7900.00 8000.00 8100.00 ~200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8766.48 40 13 N 4 46 E 5144,24 0.22 39 19 N 5 24 E 5224.83 0.97 38 19 N 6 23 E 5302.32 0.65 37 39 N 7 8 E 5377.47 0.50 37 6 N 8 19 E 5449.94 1.03 36 15 N 8 4 E 5520.42 0,95 36 12 N T 34 E 5590.19 0,83 35 20 N 7 45 E 5658.91 0.21 34 47 N 7 43 E 5726,08 0,00 34 47 N 7 43 E 5770,10 0.00 10468,73 7958,00 10598.95 8058.00 10727.34 8158,00 10854,41 8258.00 10980,04 8358,0.0 11104,58 8458.00 11228.48 8558.00 11351.71 8658.00 11~74.05 8T58.00 11555,00 8834.48 PAGE DATE DF SURVEY: 26-aUG-85 KELLY BUSHING ELEVATION: ENGINEER: HaLFACRE 7 58.00 FT SUB-SEA RECTAN NORTH/ FEE 5004. 5087. 5167. 5245. 5320. 5394. 5466. 5538. 5608. 5653, DEPTH GULAR SOUTH T COORDINATES EaST/WEST FEET HORIZ. DIST. FEET 54 N 63 N 71 N 58 N 93 N 35 N 85 N 24 N 08 N 8~ N 1247.30 W 1239.83 W 1231.55 W 1 222.50 W 1212.21 W 1201,37 W 1191.67 W 1182.24 W 1172,67 W 1166.46 W DEPARTURE AZIMUTH DEG MIN 5157.63 N 13 59 W 5236,52 N 13 41 W 5312,46 N 13 24 W 5386,15 N 13 ? W 5457.26 N 12 50 5526.51 N i2 33< 5595.23 N 12 5663.02 N 12 2 W 5729.38 N 11 48 W 5772.92 N 11 39 W ARCO ALASKA9 INC. DS 11-10 PRUDHOE BAY NORTH SLOPEgALASKA MARKER TOP SADLEROCHIT TOP ZONE 3 TOP ZONE 2 G/O CONTACT TOP ZONE lB BASE SADLEROCHIT PBTO TD COMPUTATION INTERPOLATEO VALUES FOR MEASURED DEPTH BELOW KB 10931.00 11076.00 11154.00 11338.00 11355.00 11452.00 11505.00 11555.00 DATE: 15-NOV-85 CHOSEN HORIZONS ORIGIN= TVD FROM KB 8318.85 8434.96 8497.90 8646.82 8660.68 8739.89 8783.42 8824.48 PAGE DATE DF SURVEY: 26-AUG-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 8 58 .OD 1038' FSL, SUB-SEA 8260.85 8375.76 8439.90 8588.82 8602.68 8681.89 8725.42 8766.48 352 ° SURFACE LOCAT AT FEL, SEC 28, TllN RECTANGULAR COOR NgRTH/SOUTH EA 5291.70 N 12 5377.60 N 12 5423.25 N 11 5530.39 N 11 5540.13 N 11 5595.62 N 11 5525.58 N 11 5653.84 N 11 ION , R15E~ DINATES ST/WEST 16.41 W 03.80 W 97.42 W - 83.31 W( · 81.98 w 74.36 W 70.30 W 66.46 W FT DM COMPUTATION DATE: 15-NOV-85 PAGE 9 ARCO ALASKA, INC. OS 11-10 PRUDHOE BAY NORTH SLOPE,ALASKA DATE OF SURVEY: 25-AUG-B5 KELLY BUSHING ELEVATION: ENGINEER: H&LFACRE 58.00 MARKER TOP SADLEROCHIT TOP ZONE 3 TOP ZONE 2 G/O CONTACT TOP ZONE lB BaSE SADLEROCHIT PBTD TD ~~,~ STRATIGRAPHIC SUMMARY ORIGIN: MEASURED DEPTH TVD BELOW KB FROM KB 10931.00 8318.85 11076.00 8434.96 11154.00 8497.90 11338.00 8646.82 11355.00 8660.68 11452.00 8739.89 11505,00 8783.42 11555.00 8824.48 1038' FSL, SUB-SEA 8260.85 8376.96 8~39.90 8585.82 8602.68 8581.89 8725.42 8766.48 352 ' SUR~A FEL~ SEC RECTANGU N3RTH/S CE LOCATION AT 28, TllN, R15E, LAR COORDINATES OUTH EAST/WEST 5291.70 N 5377.60 N 5423.25 N 5530.39 N 5540.13 N 5595.62 N 5625.58 N 5653.84 N 1216.41 1203.80 1197.42 1183.31 1181.98 1174.36 1170.30 1165.46 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11555.00 8824.48 8766.48 HORIZONTAL DEPARTURE DISTANCE aZIMUTH FEET DEG MIN 5772.92 N 11 39 W FT UM W W W W W .SCHLUMBEROER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL DS 11-10 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE OOO0?09?5 WELL NAMe: DS 11-10 ' SURFACE LOCATION: 1038'FSL, 352'FEL,-S28, TllN, R15E, UM VERTICAL PROJECTION -~..4..~--~--.~.- .~.?..~-?--,. .... ...h¢.~..~.4..~..~..~..~_, ~..~--~..~..~..~..~...~... ~..~..~...;..~..~..~..~..~.., --,-+.~.-~-.~.-+--~--~- ~-, : : ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..~..~.-~.++.,-~-.~.~- . ...... ~..~...N..,.-4..4.-4.-4.--~!~J ~ ~ '~ ~ ~ ~ ~-,6.~ ........ L.i.,~..~. z.4 .... ~,, · -N-.~--~..~---~-~ ~--~--~'-~ ........ ~"~'";"~";'""~"9"i ~"h~"~ ..... :'" ..$ ........ ~,.;..~,,~,.~... :::::::::::::::::::::::::::: ~-~..,-.:..?:..::..?.?:: ,+::-...~...H..~...;,.~..?':.....,?.?.;.:..?:...i · · · ..... · :~ ...;..i.~ i.i.-',-~--~..L ~---i...;--~.-.--~---.:::' i--;--i+:--~--~ +-; ........ ;-.~..i-..i.-~ ~.-~ ,'"f'~':'!::?~'~:'i:':-'::i::i':~..,.:. ....... ~..~..~ .~ ...... iiiiii~iiiiE~iiii!i!i"'i"'i'"i'i~' ...... ::::::::::::::::::::::::::::: ============================ '"""~"~"'"'"~"~"~ ........ ~"~"~"~"~"' ............ ":? .... : : :. : '"!::.::~::~:: :~::~:i:~::: --:,,'--f-H--H--f.-"-- '~ i i i i i i i --+..4.-4.-,:--*-.;.-.~..4-..;.-.,..;,,---;...!--.H"+'-':,'--:"-f- . : : ~ : . '~' ..... ~ i i '. i ~ .;..u.~..'; - ........... . ............ t ....... -f-;.:--!'--f-f-i ! i f'+ i--?-~'-~ [:~::~:: :: :: :. ! ~ . i.'_.i.._~, t = : : ' : : ' . t''~ '" ;"~'?'~- "?"*.-'"'t'*,"?"T--:'". "~"*:"*"i";'";'";"I -;"?'"'i'"?:'"F'~"~"$"4. ;"; ....... ~"~"*"";'";"'; ~--~-i~;~i ' ~ i! ~'~' ............... ~ ............ ~" ' ....... '"'"":'"':"":"~"~""":'"*:"~ ............... $,. ~,..;...L .;.: ·; ...... L.. ........ ~'";"; ...... ~'-';"~"~"~'" .Z Z Z .-:..L..L L ;. i ..... L..: ,;. ' ' ' ' "!"i" ~;"~"-~ i ..,...~..~..?..,..,..:- ....... ? -*--?- . . . . . · '"'"*'":'~'" : .... .-*..---.. ...... r-*.--?-.----? ........... iliiiiE ii ii E iii E E .~..;..;..;..;..;..;..;..~ ....... .--~:--+--*.:-+-~..-+..~...~:..+... ....... ...... ....~..~..~"~"I':?,::I:-~::~::!-:;:!::I::~ ?'..- ?--'.~"?" F'-?-~ ..... · . .-.i..~:-'.".-::H::!..-?..'-.~ ..? ~...:.+.+.-.>.:..~ :::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ..... · '?"?"~"?"I ?" "?' "?'"~"~" .-~-.~- ~.-4..L-~.-4..~ ~ '- ~- ~, ~ -!-.~..~...4-.4..?.. · -;--:;...~--~.-.i--*.:--*.;-.I--~:--~---:..-~-.~..~..~--~";--' "'f'f"i"f", ...!..~.-~--:..4..?"4...~..~..,.~--~.-.!-.N.-¢--;:.--k:;... ::: ~ "'~"f"i"f'f ...... ~..?.'..+.+.~..+-.¢-.;'...-i-. ~..~..;~...-..$...~.. ~..~ · .... ~...~..~..,.-~-.~...F-.?-~--~. . ~ : : - ~ : : · · ' -.~-.+..'---~--__;_~--~--4..*..-~.-~-.~..~-.~'-~-- --t-..+-.t.-? ..':-..¢..~.4.+.¢..&.44 ..... ?. ........ i.~ii~i .~..~..i.~...~.. i..:.... < ..~-.~...~...L.L-~..~.~..~ .... ~--~-.~..~ ........ ~..~--~'" · :::, .... ..~..~..~..~..L.~..~..~...,L., ......... -- .~-'??"?'-'!"?"?" ,~"?.," ~-.,'-.-?'.-~--+'-~.--?"-~"?'"? ...... i"f'~'"!"~"~"?:"~"~ .... f-?;..-.;..-!--?... ~ --!-. :?... c~ :::::::::::::::::::::::::::...~...~...~...~..~..,.~..~..~... · .... i~ ..., .... --~-+--t--::--.i--,--~.-t---!--:::::::::::::::::::::::::::: "~;--~--+--~--t----'."-~--i--5-- --~'-+--?"?"t '?'- ~"? ..... - ....... ' '--...i--*---i..--i--;,--,i.-..-'i"*:",*~,"t'-t"?"'"? .... ?'?"~'~"?¢.,"*.,"*,."" : : : : : i : : : ; i'i;';:;2 '"'-'"'~"?~-"* "-"'---' '"?' :i"i"i'!'-~'~i "+'i~iJf'}'! ..~..:..~.,.~.:.- ': I : ;' · .4..-~.-~.;.-,...,--~..;~ .... "?."?'f'~'?7'*"t" : : ~ : I : : : ; ' ~ ~ ;. .:. ~.-;--.; "?..'"":',"?'" "T"T"?"?" --e--e-,*-.1..-- --~--*.-*- : : : : / : ; : · ........ ..,..~ ........ .~.,..,...~..~...~..:.:..,..,..~.~..~..~.~..~..-..~..~..~._~..~...~..~..: :.,:::: .... "'.?'-?'f'-*'f'~"?,..~...,..~...:..?;.!"~.'" ...... ,.,~.~---,--~-----,--:,,.,....,....~--~--- ::::::::::::::::::::: ~-?'.-+'?t-'??*:"? . ..... ... ':: ~ . ~:!i:!.:~::!:.~ ~': :--i.-~.--~...~: .-H-.i ....... · -~.-~-.*..~-.~-.~.--~--~--.~-..-?'--?-.'-+.~-?~--?'---:.-.. ::!::;::i:.i:: '~ ..~4 ....... ..:': ..,:.-?.-...' q.-f-,..'.?.--. . ~..~:...~...L.}.,i..~,..~...~.. ..?.f.f.'..f-f.' · ..~..g..~..L.¢..-k.g..L. :::::::::::::::::::::::::: · ' ~ f--i--t--t ........ PROJ[CTI01q ON VERT]CIqL PLRNE ~50, - 1'70. ,.!Q:tLE0 IN VERT)CRL DEPTI. t5 HOR]Z SCF:~.E = 1/1000 IN/FT ~URFACE LOCATION: 1038'FSL, 352'FEL, S28, TllN, R15E, UM NI~RTH '7000 SCI:~E = 1/IOCID IN/FT HORIZON~AL PROJECTION GREAT LAND DIRECTIONAL DRILLING INC. REPQRT OF SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA~ 'INC. COMPANY Well No. 10 WELL NAME AL785D18 Prudhoe Bay Drill Site 11 LOCATION MWD TYPE SURVEY .... DATE'--- Directional Supervisor TITLE SIGNATURE JOB NUMBER Tom Tuttl e NAME 7/13/85 7/23/85 DATES SURVEY TAKEN FROM TO 250Q 1Q547 DEPTH INTERVAL FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made fro~ E C E I V E D the original by any blueprint company. Alaska Oil & Gas Cons. Commission Anchoraf}e f-) F;.'. I!: A "1' I. A N I) I') ]. F;.: E' C 'T I 0 N A I.. I') F,'..11 I.. I... I N (3, I N (:'. 7-24 "" 8 5 14 e; 1. '1 ........................ : I:; 1. ost.lr',:!., D i r'.ec t i on .... : M,:i-:: (:lr~,:~'l,'.. i c: Dec t i n.:.'~'lL'., i on: NO. 10 Computmt i on: Sur've~.~ cim't.e.: Mo. tlqod ...... R f', 8. H e. i .(.lb t.: I.'(AI}IUS OF' CURVAi'UI;:E 7-24--85 MWI) I'OIE)I.. READINGS 58.0 f't 296'.5 4 0 2964.49 2906.49 .1.7,,6S N :1.6.50 W 18.0.1. N 0.65 E 18,02 N 2 :.~ 41 E 0.496 :5048 4 () 304 '7 ,, :29 2989 ,, '29 '2 ..~ ,, 40 N 1:5,75 W 2 ~'~. 60 N 0,86 W 23,6:2 N 2 5 ~ 2 W. 0,016 ~.. ~ ........ , " ')' ~) ' u 3:1. 4 "'.~ ~:~ :'~ (') 7 .1. 4 () 96 ,~ (. 8 ~.... S' 6 31 ,..1. 0 H ,,. '> 2,..1. '5 I,! 3 ].. 00 N ~. ,,.° 6' W :~ 1 17 N 6 0 5 W 1 .598 :52~.(, 5 45 :5'2',32.52 ~.1.74,,52 3'./',,94 N 20.50 W ~59.40 N 6.54 W 39.94 N 9 25 20 t4 0.272 L~327, 6 45 ~'~24.96 3266.96 49.93 N 17.75 W 48.96 N 9.85 W 49.95 N .1.1 22 47 W 1.076 :;~.4,'..!t .1. :1.0. 30. ,".~4"~'7. .,. ,, ,')('~ ..... :;.~4.1. 9 ,, :20 7'''~.<. ,, 91. N .1. ":).,. ,, !.:;n.. .... I,.I ';1., .25;.. N 15 ,, 88 W 72 .99 N .1. '.~,.. ;'.~ ;'.~ 48 W 2.., 438 557.1. :1.::~ :t.~'., :'5'..:,:;,6!;:i.26 '~5'50'7,,26 9.1..37 N 16.5(.) W 89..1.7 N 20.51 W 91,50 N 12 ,5:.; .19 W ~.~.064 ......... I:;' o'" I;:' --";j~ ,.."~, L A "),., ,.. .<.. :l.',::J 30 ..~..':).'.:.,,:: ,, 4:1. ,:,.:?,.~ ,, 4:1. :1..1. ~':.. ,, 59 FI 2:.5 , "i0,.. 14 110 ,39 N ':)8~. .2.4 W 113 .94 N 14 20 52 14 2.., 5 ,.~7~:..'::~17 ~:0 5 '2' '71 34 3 '7 .1.~'~ ::.~',4 14':7 0() N :'.~0 O0 W .1.41 56 N ,43 95 W 1.48 '23 N 17 14 50 W 1 69b L~. 907 :20 30 3886 ,, .58 :'.~ t.l"28 ,. 68 184 ,, .47 N 28.50 W 176.2. :t FI 63.35 id 187. '26 N 19 4 6 ;.~ 0 14 '2 ,, 464 406.2 24 :~0 4()29,,f.!5 397.'1. ,, ['~,5 24:1..:1.3 N 25,,50 W 229.05 N 90.27 W 246.20 N 21 30 3:9 W 2.602 4214 29 0 4165,,55 4:1.07,,'.55 307.23 N 24.00 W 291.16 N 118.91 W 31.4.51 N 22 12 54 W 2.970 4457 ~6 0 4~70,,36 4~.1.2.:~6 4~4.54 N 21,00 W 4].]..70 N .1.68.84 W 444,97 N 22 .1.7 55 W 2.912 46.11 /,0 0 ztz,'~?.1.,6? /t-(t~,,69 527.:'59 N :22.00 W .499.89 N 20~5,58 W 539,76 N 2:2 9 LSO W 2,,611 '"'~ 5 ':> '5') "~ '" 6 45 W 3 306 49':']. :)(. .1. 47.1.0 1 46 ,...1. '741 88 i'.J':)'? 00 W 703 3]. N 28'::i 76 W 769 .1.4 N ''>''' ~.. ~ a. ~ .~. . I~ · ~.. ~.. ~ ~ ... ~.. ~ ~ ~..~. ~ '::' ,55 0 . "~ 4 860 N ... 00 W 8.1.6 01 N 33:1. ~'.~0 W ',":~',::~(~ 69N ":)') 49 W .1.0,':., ,.~()74 .(t 8 (l 9.? 74.4 ':?'? '7':) 2":) '::i ',5 " . . .¢......' . lJ . ...' sd . .'... .%.. u # u ....... , ........'.. .... J~ 53,..'::i "J:~ '::',,~6, 30 z, 96.',?,, 8.1. .4904. lil:l. :1.090,3::5 N 2:L. 75 W .1.03L~ ..... 8',5 N 4.1.8 76 W 11].5 44 N. ')">,.,-.. ~.~ 1. W 0 ,, '-',.~,5~...~ t'S664 '.::;'7.., r'),. '.:':; 1~'50. . ,, !5,E! ',::lO''~'), .,... ,, 58 :1.:.'5.(,:1. ,, 5:1. N ")0,..,. ,, O0 W .1."~"~;~.., .,..., <?4 N 509 .94 W 1L'571 .29. N ':)1~.49. 52 W 0 ,434 !':;97(') '::"~ :'.~;(")',':;296 .1."') '"::")'~P :i.''~ .1.59'::; 4''~ N 18 50 W .1.'~:':1.5,.~ 91. N 5 94 '79W 1628 4,... '> N '~ .1.'.>5 24 W 0 ,5" El":',., .............. ,, .~",. n .,~'.. u i,, .".. - ....I / ........ ,,,'.. ,,..,~ ~,',, ,,.~ ...' . .... ,A.'.. p ,* . :.':> :'...,! Ei :1. '.':i '/..., :.':0. '::' ",5~'5,..,.,~,, ")"'~.,...<.. ':5/,('~':'i.. ,.. ,, .,..":)")~-.. :1. ~:1,.:,.~"' ~:"::' ,, 6,':.':, i',l :1.5 ,, ',':lO... W :1.766 ,, "~.1.., N 6"~ :1., , 4:7 !4 .1. i:!9'0 ,, 01 N '.;..>() z',i:l3;6 W 0 ,, ,51.]6 PRL![)HCIE I)1';~].t...I.. SI'l'ii!. 11 WISI..i... NO,, .1.0 7-24 .... 85 I:ilii;COl:(I) OF: SI.IRVIEY ()EF'TH ()C-i I'qN DEPTH DEF:'Ttt DISI' ANGL. E FRCIM WEL. I.-HEAD DISTANCE DG FIN S de.q/.1.00 6!::'.i92 ',fi7 .1.5 56S0.89 5572.89 21:1.6.59 N .1.4.25 bi 2019.86 N '?S8.70 bi 2150.70 N 20 5 ]1.9 W 0.29,".:.i 680? 57 .1.5 5748.28 5690.28 21~98.53 N 14.50 W 2:L96.65 N 784.01 W 2~'.~S2.37 N 19 ?18 3Z W 0.08~ , ...... 9 r) '76 c,~.,~ 59.1.8 9S 2665 .1.4 N .1.4 00 W 02 N 874 7526 58 0 6:I. 2G.SSt 6067.S;2 2906.80 N 1S.00 W ~,:]788..48 N 9S.1..0G W 29S9.81 N 18 27 49 W 0.4S,~ · ....,., ,.,;, 6S48 4S 6290 4S S266 S9 N .1.~'J (.)0W ~.~:l.~.~8 ~'¢0N 10.'1.8 27 W S299 8079 59 0 641'5.35 6S57,,35 SS76.S5 N 1S.50 W S245..1.9 N 1045.42 W 8S56 59 () 6558,.02 6500.02 S6].S.40 N 12.75 W S476.4"2 N :t. 099.SS W ':'"' (.~:1 08 3707 S5 N 1.':~ 00 W S568 ')7 N 1119 48 W 8 466 .., ~ ! S 0 6615 )" '~' '::: '::: ''~ 85'24 57 45 6672.1.1. 66].4.. :1.1 S798.96 N ].S.2',5 W S657.76 N 1:1. S9.5S W 8728 55 45 6756.,55 6698.55 S927.,5:~ N 1S..25 W S78S.;I. 2 N ..1..1.69.05 W S409.4:;~ N .1.7 5.1. 22 W S646.09 N :1.7 S2 54 W S739.76 N .1.7 2,5 6 W .1.,.1.6 N .1.? .1. 8 .1.3 W 9,6:5 ii ..1.'7 .1.0 19 W 0.9S8 0. 199 0 6 ''~ ','.~ i. / .1.. ()81 .1. "~99 u ,,,,% 888 .1. 5 ]. ..z, 0 6847.26 6789 ,, 26 4050 ,, 52 N .1. 2 ,, 25 I,.I S 903,24 N .1..1. 96.2 S W 8975 ,',iii :1.',5 6907,,8~'5 6849,,8S 4.1. S72.S.1. N 12,75 W 397t.~,40 N .1.2.1..1.,,78 W 908 S 46 1 ,,5 69 iii :1. ,, .1. 4 692 ~'.'l ,, 14 4 20 .1.. 57 N .1. 0 ,, 25 I,I 40,5 ],..1. 1 N .1. 227.59 W 9.1.45 ,46 50 702S,9::;~ 696','J ,, 92 .,"~;;746..<'~0 N 5,,00 W 409',;!J.tJJ7 N .1. 2:.'.¢. S . ',54 W 9 S .1. :? 47 0 7 ]. S 8. S 4 7080 ,, ~':.~ 4 4 S 66,49 N S. 00 E 4,1'...> 17.10 N .1. 2 S 5.67 W 0 Iii2 ,, 4 ;.'1N .1. 7 2 .1. 9 W .1. 54.0iil N .1.6 57 ','.~7 W "~ ..... .02 ':' .1. .i? 9 W .... .~..~ N .1.6 ,., 4;~77,,S1 N 16 45 42 W 4S94,40 ii .1.6 .1.9 5S W '~ 806 ;.'.~. 470 2.2 .1..1. 4.474 '~ 580 ,,,,"., n 96 :,::~ 1 46 30 7 ¥., !50 ,, 06 7292 ,, 06 4 ',:'.i 85 ,, 79N :.'.~ ,, 2'..'5 I!!: 44 f1.1.. ,<ii 3 N .1. 223.40 W ~:,~ 9 ;.'5 ":~ fi 4 0 "~ ':: ' 99 ':'i 9 9 5 ..... , ,..,,':: 8 ,, 7, ..... 1 0 , .4800 ,, 6 N S ,, 75 fi: 4662 .26 N 1 ,,-.. ''~ 0. 9 ,9 .1. W 10242 41 S0 "7796,,62 7751."1.6'~ 50o4 '~.'~ . ?,=,95 1.4 .......... .,,.~ N 5,50 E 4871 98 N .1. 1 ,r ,-~ 10547 S9 45 8C, 28..1.0 7970.10 519',:.:i,S7 N 6,,50 E 5069.47 N .1.1.72.19 W 0 ,..1. 6.";' 0 8((, 0, Iii.44 0.5 Iii 9 "R U D H I.) E I) R I I... I.,. S 1 i'1!!i I')Ai'A 1.1. WEi...I.. NO. .1.0 IHTERPOLAI'ED F'()R EVEN 100 F'EiET OF SLIE.,,.:,E.A DEF'TH 7.-~4--85 SEA MD....-i'VD VERTICAl... T I't D I F' I:: . C, 0 R R Ii:' I:.'.. T 0 0 0 100 0 0 200 0 0 S 0 0 0 0 40O 0 0 1058 10 ',58 1.1. 58 1:1. 58 1 '258 ~' ..... .I..<.. ::.', 8 ,.~ ,.~ 8 1 S 58 1458 14 5 8 16 tJJ 8 :1. 6 5 8 1 ? 5 8 17 5; 8 :1. Iii 5 8 .1. ii{ !5 ,<3 19 ~JJJli.). 1 .1. 000 0 0 1100 (.) 0 .1.200 0 0 1300 0 0 1400 0 0 15 (:) () 0 () 160 t) 0 0 1700 0 0 .1. 8 ~.) 0 0 0 19 0 0 C, 0 200 ~,) 0 2100 0 2200 0 2S()0 0 2400 0 0 0 0 0 ">~-. ..... 5 (') 0 0 () '..;! 6 00 0 0 2700 () 0 2 800 0 0 ,,"'~ ..... 9 0 0 0 0 R E: l.. A'f ]: V E: C 0 C) R D I N A I'E S FF<OM WFI...I...... HF Al) O. O0 0. O0 0. O0 0. O0 0.00 0.00 0. O0 0. O0 0.00 0.00 O. O0 0. O0 0. O0 0. O0 O. O0 0. O0 0. O0 0. O0 0,00 0.00 O. O0 0. O0 0.00 0. O0 0. O0 0. O0 0.00 0.00 0.00 0.00 0. O0 0. O0 0. O0 0. O0 0. O0 0. O0 0. O0 0. O0 0.00 0.00 0.00 0.00 0. O0 0.0'0 0.00 0. O0 0. O0 0. O0 0.00 0.00 0.:1.9 N 0.:1.6 .W 1.S7 N .1.,,55 E 5.42 N 2,,4S E .1. 2.4 N "2. "'~"'~ E ,, ,, .,.'....,.'.. '?,,58 N 0.77 E'. RLII)HOE DR '1L..I... S I '1'1!: .1. 1 WliEI...I... NO .. 10 DATA IN ....... '"' IERFOLAI'ED FO.R EVEN 100 FEET OF SUE~.SEA DEF'TI-I 7-24-85 MEAS. I'RU VERI' SUB SEA PID-..-TVD VE:RTI£.'.AL. D E P '1' I.J D I.E F:' T H D E P T H I) I F: F' L, (.)I.s k E C 1 SO':"'" · .;: '/ S058 :~000 .1. .1. :.~ 155' ?, .1. 58 S .1. 00 .1. 0 3 '260 '3:2 ',:513 :.~ 200 :2 1 S S 60 S S 58 S S 00 2 0 :.'.~ 46 '2 S 458 S 400 4 2 3564 3558 S500 6 2 S667 36S8 3600 9 S 377 .1. .'.': 758 S 700 13 4 S 877 S 858 S 800 19 6 S984 S958 S900 26 7 4094 40','!i 8 4000 S6 .1. 0 4206 4 .1. 5 iii 4 .1. 00 48 .1. 2 4S24 42'S8 4200 66 .1.8 444 2 4 S 58 4 S 00 84 .1. 8 4'568 4458 4400 .1. 10 26 t. ,., 4 ,.,,.~, ~ 4500 147 S'? 4847 4658 4600 189 42 5000 47',58 4700 242 5S 5 ]. 72 4858 4800 :314 72 5 S 49 4958 4900 S 9 .1. 77 ..... ..,.~,: .... ~0,.~, ~ 5000 474 57 .1. 5 '::i :1." ..... 8 ,:~ ~..~ ":~ .1. 00 · - ~... '... ~1 ~ t 5900 5:258 520 () 6 4 '2 iii 5 608,..'::~ 5 S 58 5 S 00 .... 7 ,,.>'7 8 ',fi 62 7 .1. ~:' z .::' ;', 5400 8.1. ..... , ~ ,.: o 86 · 6457 '5558 5500 899 86 6642 5658 5600 984 85 6132 '7 5 '? 58 5700 1069 85 *7017 ',5858 G 800 1159 90 7 ,,. 06 5958 5900 1248 89 RELAT]:VE COC)RDINAI'ES FROM WEL..L'-HEfil) '24.S4 N 1.05 W 41.86 N 7.48 W 52.9'~ · '.. N .1..1..16 W 67.40 N 16. '.::i8 W 87.55 N 20.04 W 111.56 N 28.75 W 137.95 N 41.90 W 166.77 N 58.84 W ,200.90 N :77..1.8 W 24 .1..05 N 96.04 W 286.75 N .1..1. 8.68 W S41.86 N 142.20 W 40.1.. 26 N 17.1.. 2.1. 474.68 N 19S.47 W 557.76 N 226.96 W 65:1..52 N 264.84 W 760.5S N S08.88 W 890.48 N :561.45 W 1026.88 N 4.1.7.0]. W 1168.07 N 1:~12.87 N 1458.28 N .1.607.7.1. N .1.754.7~'.~ N 47S.66 W 524.57 W 579.5'2 W 626., 50 W 6,8 .1.. 49 W 1909.2Z~ N 2060.70 N 2211.64 N 2S66,,',5S N 2522.56 N 7.1. 1.94 W 749..1. 0 W 787.89 W 828. S S W 869.69 W P R U DI--I 0 E D R I I... I... S I T I!.-: .1..1. W E I... I... N 0 ~ .1. 0 DATA INTERPOL. ATED F:'OR EVEN .1.00 F:'EET OF SUP. SEA DEPTH 7..-24 ..-85 MEAS. TRU VI::RT SLIP. SEA MD'"'TVD VERTICAL. D E P T H D Ii::. P l" H D E P T H D I I:= I::. C 0 R R Ii:' C. T 7 S97 60,58 6000 .1. SS9 91 7588 6:1. 58 6100 14 SO 91 '? 778 6.258 6200 .1. 5:20 90 7968 6:358 6S00 .1. 6.1. 0 90 8 .1. 6 '2 6458 6400 .1. 7 () 4 94 83',"!i6 6558 6500 .1. 798 ' 94 8547 6658 6600 1889 9 .1. 8730 6758 6700 .1. 972 83 8898 6854..1 6800 ',2040 68 904 9 6958 6900 209 .1, 5 .1. 9 .1. 95 7058 7000 2137 46 93.4 .1. 7 .1. 58 7 .1. 00 2183 46 9487 7258 7200 2229 46 96S2 7 S',"58 7S00 2274 45 9774 7458 7400 2S16 42 1 () () 5 ;'.~ 76,58 7600 2S95 10 .1. 89 7758 7700 243.1. S6 103'2S 7858 7800 2465 S4 10455 7958 7900 2497 R E: t.. A ]' I V E: C 00 R D I N A T E S I::' R(:)~ WE:I..I..'"'HEAI3 26(:1.1.. 55 N 2839.79 N 2996.65 N S.1.53.49 N 3314.17 N 907.22 W 943.03 W 981 ,,S9 W .1. 022.37 W 1062.:i. 2 W 3475.66 N 36S5.73 N 3785.09 N 39.1.5,93 N 4026.42 N 1102.35 W .1.134.40 W .1..1.69.51 W 1198.99 W .1.224.61 bi 4.1.3:1.. 49 N 4238.04 N 4344.36 N 4449.98 N 4551.74 N .1.237.44 W 1234.57 W 1229.15 W 1222.9S W 1217.39 W 4651.52 N 4745.57 N 48~7.4S N 4925.09 N 5010.6.1. N 1212.36 W 1204.95 W .1.200.66 W :1.187.96 W .1..1.80.45 W F'i:;;UIJI.~OE DRII...i.,. SITE .1..1. WEI...I... NO. 10 DA'fA INTERF'OL, A'I'ED ,FOR EVEN .1.000 F:'EE'I' OF MEASUREI..') DI:i'PI'H 7-24 .'-85 ~E~S. TRU UERT .SLJB SEfi Ij Ii:' P T I"i D E P T H D El I::' T H .1. 000 1000 94'2 2000 2000 :1.942 · .?;000 2999 2941 4000 S973 S915 ,5000 47,59 470.1. 6000 5;.'! 12 5254 7000 585 .1. 579 ~'.~ 8000 6S74 6S :1. 6 9000 6925 6867 10000 76 .1. 8 7560 R E I... A T I V E C 00 R D I N A T E S FROM WEI...I..'-HEAI3 0. O0 0. O0 0. O0 0. O0 20.S5 N 0.07 W 206.17 N '80.2S W 760.61 N S08.9:1. W 15S9.88 N 2S52.76 N S:1.79.46 N S99.1.. 51 N 4709.18 N 602.88 W 824.7:1. W i029.52 W 1215.97 W J. 207. O0 W Notes: All values ~n feet. Depths shown are TVO. Closure: 5203 ft at N 13 deg 1 min W 8ottom hole: TVD 8028 TMD 10547 Magnetic declination: 31 deg 15 min E HORIZONTAL VIEW ARCO ALASKA, INC. PRUDHOE DRILL SITE 11 WELL NO. ~ RADIUS OF CURVATURE MWD TOOL READINGS SCALE: ! inch = 800 feet DRAWN: 7-24-85 /V X tooo - VERTICAL SECTION 0 0.50 i.O0 i.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50" 8.00 8.50 9.00 -0.50 /ARCO ALASKA, INC. PRUDHOE DRILL SITE ll WELL NO. 1 RADIUS OF CURVATURE MWD TOOL READINGS SCALE' ! inch = 1000 feet DRAWN' 7-24-85 , 1VD 802B _1 5.50 0 O. 50 1. O0 t. 50 2. O0 2. SO 3. O0 3.50 4. O0 4.50 5. OD Departure { ftx ~ooo) ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: August 20, 1985 R~ference: ARCO Magnetic Tape 11-10 CN/Di fl/CDL 8-15-85 #ECC 2215 DA Please sign as receipt of data. Received by Pam Lambert ATO 14 29C ?{/Alaska 0ii & Gas Cons. Commission Anchorage Trans278 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mob i 1 Phillips PB Well Files R&D Soh i o State of Alaska Tex a co ARCO Alaska. Inc. is a Subsidiary Of AtlanticRichfieldComl~an¥ '-~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 RE: Receipt of the following material which was transmitted via /PA~ A~ ~ ~' /~ C ~ is hereby acknowledged: QgANTITY DESCRIPTION S// /I /! 5// ~ '/~.,5-// c~.// h RECEIVED: DATED: Copy sent to sender YES ~. NO ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: August 14, 1985 Reference: ARCO OH Finals 11-10 Gamma Ray 11-10 FDC 13-98 DIL 13-98 DIL 7-28-85 Run 1 5" DA 7-28-85 1 2"&5" DA 8-22-84 14 5" Sch 9-27-84 16 5" Sch Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 263 RECEIVED Alaska Oil & Gas Cons, Cor~lrrlissior,, Anchora.~ Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Sohio State of Alaska Texaco ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~ ~0360 Anchorage, Ala~"'~a 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) If you have any questions, please call me at 263-4944. L1-14 L2-20 Sincerely, Gruber Associate Engineer JG/tw GRUlO/L120 Enclosures RECEIVED AUG Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany ' " STATE OF ALASKA ALASKA G,.,-AND GAS CONSERVATION CO'k.~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling welJ(J~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-159 3. Address [3. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21394 4. Location of Well at surface 1038' FSL, 352' FEL, 5ec.28, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 58' RKB 6. Lease Designation and Serial No. ADL 28322 ALK 2320 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 11-10 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1500 hfs, 7/12/85. Drld 17-1/2" ho1e to 2535'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,970'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,555'TD (7/26/85). Ran logs. Stuck tool & recovered. Ran, cmtd, & tstd 7" csg. PBTD = 11,505'. Secured well & RR ~ 0400 hfs, 7/31/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 110'. Installed w/2000# Poleset (appro~). 13-3/8", 72.0#/68.0#/ft, L-80/K-55, BTC csg w/FS @ 2523'. Cmtd w/2500 sx PF "E" & 400 sx PF "C". 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe @ 10,916'. Cmtd w/500 sx Class G. 7", 26.0#/ft, L-80, BTC csg f/10,684' - 11,546'. Cmtd w/380 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHCS/GR/SP Depths are not available at this time. GR/CCL/DIL/SP 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--Repo on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with theAlaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. TEMP/MR86 Form 10404 Submit in duplicate MEMORANOUM TO: THRU: FROM: State-of ALASKA OIL AND GAS CONSERVATION COMI~ISSION : DATE: C. V erton Chai~~/ ~-~ FILE NO: Lonnie C. Smith /?~:'~ ~: ~ TELEPHONE NO: Commissioner Bobby Fo s t e~-i;~J SUBJECT: Petroleum Ins~ectbr AlaSka July 17, 1985 D.BDF.56 BOPE Test ARCO's PBU DS !1-10, Permit No. 85-159, Prudhoe Oil Pool. Sunday, July 14, 1985: The BOPE test began at 1:30 pm and ended at 3:00 pm. As the attached BOPE test report shows there were one failure. In summary, I witnessed the BOPE test on ARCO's DS 11-10. Attachment: Ray Springer notified me that the valve in the choke manifold had been repaired and tested on July 15, 1985. 02-O01A(Rev. 10/79) O&G t/4 5184 Inspector Operator Well Location: S STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Drilling Contractor Location, General General Housekeep' Reserve Pit Well Si Mud Svstems Visual Audio Ri Trip Tank Pit Gauge Flow Monitor Gas Detectors Representative Permit # /~asing Set ACCUMULATOR SYSTEM Full Charge Pressure J~f5 psig Pressure After' Closure' /~-~ psig Pump incr. clos. pres. 200 psig -- mind'sec. Full Charge Pressure Attained: ~ min/~ sec. N2 ~ ~ ~/~ /~ .~/~r~D psig Controls: Master Remotei.¥~Blinds switch cover C./~ ! Kelly and Floor Safety Valves BOPE Stack Annular Preventer Pipe Rams Blind Rams Test Pressure Upper Kelly Lower KellM Ball Type Inside BOP Test Pressure / Test Pressure / Test Pressure / Test Pressure Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Results: Failures Choke Manifold~-f~Test Pressure NO. Valves // ' No. flanges ~ ~ Adjustable Chokes / Hvdrauicallv ooerated choke ~ Tes~ Time '/ Y~'/hrs. Repair or Replacement of failed equipment to be made within / days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~/~~~ - / July 10, 1985 Mr. T. L. Fithian Area Drilling Engineer ARCO Alaska, Inc. · P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 11-10 ARCO Alaska, Inc. Permit No. 85-159 Sur. Loc. 1038'FSL, 352'FEL, Sec. 28, TllN, R15E, UM. Btmhole Loc. 1483'FSL, 1348'FEL, Sec. 21, TllN, R15E, Dear Mr. Fithian: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their.drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Admi~.istrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. .. Mr. T. L. Fithian Prudhoe Bay Unit DS 11-10 -2- July 10, 1985 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. Where 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ? C. V. Chattert6n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER 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 [' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 11-10, Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill DS 11-10, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° Proximity plots A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on earliest approval will be appreciated. please call Gregg Walz at 263-4792. July 12, 1985, your If you have any questions, T. L. Fithian Area Drilling Engineer TLF/GSW/tw PD/L119 Enclosures RECEIVED JUL 0 8 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~'"' ALASKA L,,L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT O I LX]~] DEVELOPMENT GAS [] SERVICE [] STRATIG~PHIC [] SINGLE ZON EX~ MULTIPLE it~~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1038' FSL, 352' FEL, Sec.28, T11N, R15E, UN At top of proposed producing interval 1320' FSL, 1320' FEL, $ec,21, T11N, R15E, UH ~ Target At total depth F~ ////'~/¥ -- t~/) ~"1~ ' ~//~/~'" 1483' FSL, 1348' , Sec.21, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 58', PAD 21' I ADL 28322 ALK 2320 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 6-1/2 mi. NE of Deadhorse miles 1320' @ Target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11334'MD, 8875' TVD feet 2560 19. If deviated (see 20 AAC 25.050) ~l~'~,q 20. Anticipated pressures KICK OFF POINT 2600 feet. MAXIMUM HOLEANGL~' o (see 20AAC25.035 (c) (2) 9. Unit or lease name Prudhoe Bay Unit 10. Well number '~/~ 11-10 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 3081 psig@ 80°F Surface 3969 psig@. 8875 ft. TD(TVD) Amount $500,000 15. Distance to nearest drilling or completed II1-11 we~l 113' @ 3600 feet 18. Approximate spud date 07/12/85 21 Proposed Casing, Liner and Cementing Program [ SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Len,.~h ! MD TOP TVD MD BOTTOM TVD (include stage data) 30" I 20" 91.5# H-40 Weld ~ 33' { 33' 11~ I 11~' 2000# Poleset {17-1/2"~ 13-3/8" 72.0# L-80 BTC 2467' 33' 1133' 25aJ5~~1 2500' 2500 sx Permafrost "E" & 2 jtsl 13-3/8" 68.0# K-55 I BTC at top of csg. storing. ~ I 400 sx Permafrost "C" 8-1/2- i 7- 29.0# IL-80 I.TC I 9 8' 10386' 18235' 1133 ' 8875' 300 sx Class C 22. DeScribe proposed program: ARCO Alaska, inc., proposes to directionally drill this Sadlerochit development well to 11,334'ND (8875'TVD). A 20", 2000 psi annular diverter will be installed and operationally tested prior to spud. The 13-5/8", 5000 psi, RERRA BOPE stack will be installed and tested (rams 5000 psi, annular 3000 psi) upon installation, weekly and operationally tested each trip. After reaching TD, logs will be run across selected intervals. The well will be completed using a workover rig at a later date. A tapered string of 5-1/2", 17#, L-80 and 4-1/2", 13#, L-80 tubing and packer will be run and set above the Sadlerochit. A downhole safety valve will be installed and tested upon completion of the job. Non-freezing fluids will be left in all uncemented annuli within the permafrost interval. Selected intervals will be perforated in the Sadlerochit formation and reported on subsequent reports. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process. Upon completion of the disposal process, the annulus will be sealed with 300 sx cement followed by Arctic Pac. -23. I hereby certify that/~ foregoing is true and correct to the best of my knowledge SIGNED T/_. -" TITLE Area Drilling Engineer The space below for Commission use DATE Samples required []YES '~I~LO Permit number APPROVED BY CONDITIONS OF APPROVAL Mud log required OYES ~ Approval date Directional Survey required I APl number I~(ES [-INO ] 50- O'L-~-"t...I SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE .Tuly 10, 1985 . . by order of the Commission Form 10~01 Submit in triplicate D811-10 lO00 2000 3000 4000 5000 6000 ?000 8000 9OO0 10000 lO00 2000 3000 4000 ~000 6000 [0" CASING T¥0 = !10 ARC :) ALA,SKA, INC. ~9'. . ,,~CALE I INJ -1000 F'T. · SHL 1038' :SL, 352' FEL t 13-318' CASING TVD - 2800 SEC.28, '11N, R15E, U I' 2.5 <op Tv,~-=eec THL 1320' F:;L, 1320' FEL 7.5 SFC~I '11N_ RIRF_ llldl l:2.b 17.5 22=) 2'2 ,5 ,~2.5 37.5 4-2.5 4-7.5 EOC TVD--4289 MD-4616 DEP--7!;4 5.8 F T K-10 T ~D -- 7268 MD -- 8924 DEP - 40~ ~ K-5 TVD -- 77; a MD -- 9632 DI;P = 4549 · ..... ,urage ..... I-~ii"CAilNI TVD--Sa73 MI3-10086 DEP' 5257 LCU TVD -- 8383 NID ~ 10~01 DEP 62~8 FOP SADLEROCHIT TVD--8383 11D=10601 DEP -~268 G/O CONTACT TVD -- 86,~3' MD -- 10~89 TARGET TVD ~72~ MD-111 I OEP-E040 BASE SADLEROCHIT TVD ~ - 8808 MD -- 112 14 DEP ' 5787 TE -7'CASING TVD ' 8B75 MO -- 11~ 34 DEP -- 5812 7000 0 t000 2000 3000 4000 5000 6000 7000 8OOO 9OOO 0 1000 2000 3000 4000 5000 6000 VERT I CBL SECT ION 10000 7000 o -5000 0 w CZ) 0 0 CD CD C_) 0 Z 0 0 0 '~-.E - N COORDINBT£S ~- -4000 -3b00 -2000 - 1000 0 1000 2000 i i i [ i i ! i i I I I I I i i I ! ! i ! i i ! i I I I I I I i I i i ! i i i i i ! ! i i i i i i i I i i i i i i i i i i i ~ SHL I~.~R' :RI R;~' SEC.28 T11N, R15E, THL 1320' F ;L, 1320' FEL SEC.21, TllN, R15E, tim . TARGET TVD ---- 872~' TMD = 11111' DEP = 5646' N 5562 W 968 _ REC:IVED 0 J u L ) 8 1~85 Alas~ 0il & Ga,, Cons, Commissi, ~n Anci orage i i i [ i i i i I i i i i i i i ! i ! i i i i i i I t i i i ! ! i ! i i i i i i ! i i i i i i i i , [ i i i i i i i i i i -5000 -4000 -3000 -2000 -1000 0 1000 2000 E - N COORDINBTES E - N COORDINRTES o -5000 -4000 -3000 -2000 -1000 0 1000 2000 o o o 0 i i I I I I I I I I I J J L o c~ 19.85 Oil ~Gas Cons, Corn Anchorage i i W CD I Z 0 o -5000 -4000 -3000 -2000 -1000 0 1000 E - N COOROINRTES 2000 o Fi. - W OOOROINFtZE5 -400 -~00 -~.00 -i°~lS1 1-g 0 100 ~.00 300 400 0 0 o o W z o I 0 mo 0 o I o o I o 0 -400 -300 -200 - 1 O0 0 ] O0 200 300 400 E - N OOOROINFtT£S SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC'. I O" HYD. OPR. BALL VALVE WE,L,L BORE (SEE DETAIL) lO' HYD. OPR. BALL VALVE I ALL 90" TURNS ARE "TEE" CUSHION I ~LL GBORE I RESERVE I PIT I' AREA I I I I I I i I I I I FLOWL INE DRILLING RISER . F L~ 20" 2000 PSI WP ANNULAR PREVENTOR ',,, / 20" CONDUCTOR PIPE "DETAIL II VALVES 2026O10203 IRNNULRR -PREVENTOR PIPE RRI'lS > ') BLIND ') P~'PE 13-5/8" BOP STACK DIAGRAM 10. 11. 12 14. 15. 16. 17. 18. Accunulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1S00 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the tim~ and pressure remaining after 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-$/8" BOP Stack Test 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 sea~ing depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annnlar preventer and upstream valves. 4. Functionally test chokes. -S. -In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of S minutes. Bleed pressure to zero. 7. Open annular preventer and close top set of pipe rams. Increase pressure to S000 psi and hold for at least 3 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 3 minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to $000 psi below the bottom set of pipe rams and hold for at least 3 min- utes. Test reamining untested manifold valves (if any) with $000 psi upstream of valve and zero pressure downstream. Bleed pressure to zero. Open bottom set of pipe rREL~. Back off ~uming joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 mir~tes. 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 $000 psi. Test Kelly cocks and inside BOP to $000 psi with Koomey pump. Check operation of Degasser. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. Perform complete BOPB test once a week and func- tionally operate BOPB daily. RECEIVED JUL 0 81 5 Alaska Oil & Gas Cons Commi,~ion Revised 2/21/84 ARCO Alaska, Inc. Post Office L _., 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: COnductor As-Built Location Plat - Revised DS 11 (Wells 8-13, A, B, C) Dear Elaine, Enclosed is a revised as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L125 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticR|chfieldCompany REV. Z~ RE, NUMBER CONDUCTORS B &t2 AS 12 81 8 RESI:F. CTIVELY PER ARCO DRILLING, ANCHORAGE. t-$1-65 LEGEND ,,/_._NOTES. · CONDUCTOR AS-gUILT EXIST. WELL FUTURE W!~LL c. 1.1.1 -// -/ WITHIN PROTRACTED SEC'S. 28 ~t 33,TWP I IN., ROE. 15 UMIAT MERIDIAN. NOTE~ NO NUMERICAL DESIGNATIONS HAVE BEEN ASSIGNED TO WELLS A,B 6C LDCATION$ ARE BASED ON MON'$. I I-A AND F.$.2'A PER H.V. LOUNSBURY & ASSOCIATES. ALL COORDINATES SHOWN ARE A~.R ZONE 4. 11-9 y~5,952~869.22 X~ 707~141.49 Y-$,952,752.49 707,170.07 I1-11 Y: 5,952 ~ 6 56 .12 X= 707~ 197.~!§ II-A Y, 5,g§2,§ I 9 . 12 707,22 §.76 Y · 5,952 ~402 .§0 X' 707~255.79 Y'-5~952 ~ 169,22 X' I07,$1 II'B Y= 5~9 52,05 2.86 X: tl-C Y, 5~9 51~956.,~0 X= 70 7~$66,04 !1-15 Y:§,951~702[.80 X: 707,422.42 ~ Il-t2 Y-'5~951~586.17 X~ 707~450. C0 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS AT THIS T~ME 8Y ARCO ORILLINB, ARE CORRECT, AS OF:OCT, 9~I984, DS,II DE6. J.B. CNK. j. B, VICINITY MAP ,, ~ NO ~lOi LE LONG,~ 148o I9'2T,$eO'' 377' F,E.L. LAT.--70°I6'27.6569" 1038' F.S.L_ LONG,=I48°Ig'26.643'' $52' F.E.L. LAT.,70°I6'26, 5153" 921' ES.L. LDNG=I48° 19'Z §.9Z7" 3~8' FE.L. LAT.,70~16' ?.$,$$ 74" ~05' IF. S.L. LDNG.=I48oIg'~5.20B" $03' FE.L. LAT.= 1;O° 16'24. ~ 055" LONG.= 148° 19' ;~4,486' LAT.' TO°16' ~ 1.8 944" LONG.-' 148° 19' 23.027" 686' ES.L. 279' REL. LAT.= 70°16' ~0,7429" LONG.' 148°19'22. $12" LAT.= 70°i 6' 19, 5893" LONG.* 148~19' 21.59 3" LAT.= 70°16'17 .Z 784" LONG.= 148°19'20. I $9" 70016. 16.1242" L~ NG." 14~°19'19.450? 461' F $,L.~ ?.?.9' F E,L.i $34' FS.L.i ?-OS' EE.I_ P. 17' 180' FE.L~ 18' EN,L~ i ,: 156' EN.L. 107' F.E.L. D.$,II-COND. 8-13,15, A~,C A$*BUI ARCO Alaska. Inc. SHEET OF CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~, ~ ITEM APPROVE DATE (1) Fee (2) Loc (3) Admin ~ 7~~ 9. (~'th, ru 12) , 10. ~l~ and .1,~.~/:/~'''' 1 ' 12. (4) Cas8 '(13 thru //://, " (22 thr6 '~6) YES NO 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ................. 3. Is well located proper distance from property line ....... 4. Is well located proper distance from other wells ....... '.. 5. Is sufficient undedicated acreage available in this pooli ' 6. Is well to be deviated and is wellbore plat included ..... 7. Is operator the only affected party ..................... . 8. Can permit be approved before ten-day wait .............. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 24. 25. 26. 27. bond in force ' Does operator have a .................................. 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, ~e~g~g~ ~'~g;~; 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 ............................ REMARKS Is a diverter system required ................................ Are necessarY diagrAm~~ 'Of dfverterand BOP. equipment Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. __ __,/~- Is the presence of H2S gas probable ................................. Additional requirements Additional Remarks: ~EAA /l-ID i~" Z~?£~?~8 T~. ~ 1!3' .?~.. I!-I/ Geology: En~ineerin$: tt~ ~ LCS BEW~ WV~~ MTM 7 HJH~ JAL~~, "" rev: 03/13/85 6.011 I ' INITIAL GEO. I UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE' i ~0 mm Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Company Well ARCo ALASKA~ INC. D. S. 11-10 LIBRARY TAPE CURVE SPECIFICATIONS ECC 2215 Page 1 of 2 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date AUGUST 14, 1985 Curve Name (A .... rev. ) Standard Curve Name Logs Used Scale GR RFOM I RIFDYI ~ RIDM ~ GRCN SPM CNM DENP CALM GRDP ACM GRAC GAM~ RAY 2500'-10980' tLESISTIVITY FOCUSED " ~'fEDIUM " DEEP SPONTANEOUS POTENTIAL i COMI°ENSATED NEUTRON DENSITY POROSITY CALIPER ACOUSTIC i GAMMA RAY GR DIFL/CN Alaska 0 - 100 .2 - 2000 0 - 100 6 - 16 0 - 100 150 - 50 0 - 100 BHC/AC CDL 60 - 0 60 - 0 -80 - 20 Company ARCO ALASKA, INC. LIBRARY TAPE CURVE SPECIFICATIONS PAGE 2 of 2 Well D.S. 11-10 Field PRUDHOE BAY County, State NORTH SLOPE, ALASKA Date AUGUST 14, 1985 Curve I~ame (Ah~brev.) Standard Curve :'tame Lc~,_,s l~sed Scale ~ REPEAT CALR ~ CALIPER BHC/AC 6 - 16 GRDR ACR GRAR ACOUSTIC ' GAi~iA RAY RFOC ! RESISTIVITY FOCUSED RII~M , " MEDIUM RILD ' " DEEP CN SP GRBD _ COMPENSATED NEUTRON SPONTANEOUS POTENTIAL GA~ RAY DIFL/CN Alaska Oil 0 - 100 150 - 50 0 - 100 .2 - 2000 60 - 0 -80 - 20 0 - 100 ....... 'Jb. · - -~..-A--T.E: ...... ~.-t.q.-5 / ~:-.:5 ........... T Z '.* F: 1 C: '~ C. · ~ Alaska Oil & GaS CO~. Comml~o~ ............. -A-.R ~ 0 -. A.L..~..$ ~ A ..................... t..t ..... t-0 ......................... ~.~:~..~.~:~=..~.?~?~??.::~-:~=~?~:.~:~??:~::~:~:~~?:~:~.:~??~:::¥:T~:.~F~:~T;T~%~;?~::~:~:~:~?· ~:~--::~;~..:.~:~.~ .~?':?:: :. ~:~ :%?.' :?-. · : ....... P '~'U '~"~'e'~ ..... ~ ...~. ~ ................ N.O--~...T-~ ........ S.. C.O~-:e'.::..--~-.E~:s..~.~Z:::~.~:?~Z:E~::%~%:~:~;~;::~:~.~:~:~~z::~:~.~:.:=~:~::`:~:~::::~;~=::~:~:~ :.-::~..:....~...:. ~?'~?~ ~- ~ ' R'.L ~ DEN r ~L · - ~ · . . . ~ ~e . ........... u-'zP'T". ,: .......... :'G'~ ...................... C ~: ~ C S; R F O C R T L '~ ...... . .. ~: !~N~~ = 'T".' ~...p .[. ........................... ::~ - T M V ~ ~ ~ n ~ ¥ "~ ~ ~ ~ ~'' ...................... , . ~ , ,~ ~ . ~ ~ · ~ .......................................................................................... · .............................................................................................................. ......... ' ..... ...... ' ....... ....................................................................................... · . .......... "t"0"0. 2"~"", ................ t"0'7' i' 0'0 ....... '3 ? · "'"'-"t'"'0"9-2"5'-, .............. ~ '~ '~' 3 ~'? L.. ..... :':--t-'u",~'C.~'.~' .................. ~"6'. 3/' 1 .:~ "3 ......... :.. -1--0..~ 30'-, .......... ""'"~"':'"..., = '~_ ~.. - ~ : ........ -1-~3-:9:'-3'~.'--, ................... 91.1 ~,. 3.4 "1-:'09 ~..-4-'-~ .................... 7 ! · ~ ~ 16 t.-093~,. · 5,~. ~.:, .......... ,.1-.-0.-9-3 ~--, ............ 30. :~ 1 2. 4 ' -.--t..09.-6.2... .............. ~ ? . 1 4 Z 3 ,-.. ,,.., ! ~ · . ~., .......... 1...u-,y-,~-.6,.~ ................ :: *: ';~ ". ';~ ''~ ...... 1:0-.-9-.~ 6.-. ............ 4 :!. ~. '~ 23 '~ ;" t :2 . :-----.¥$u-.y.~--,--,: ................. ~ 5. ~ ? 23. .............. t-09--5.0.., ............ 4 '~.. 5 '~ £/' · ,--"':' 2 x" .9 -~ 2.=. '."':' "'"[ ~'~'";~"'-"'.'~-":""T ......... ~ '~ j ' ........ '.t--0-95. 4:, ................. r~ 0, ,5. ? 2_ 7. ......... -t...~-.¢.-5. ~,.--, ........................ ;~..~..,...~ .-.~ ............. ~.-.7-, ......... 1-0.9-58...-, ........... :~.-6.-,.-9-5 ..................... 2.7 · ........ :tu-.~-t..,u-., ~ '* ''~ ............... ! 5. ~ .3 . .... '-, ........ 1 ~ ~, u. ~ C. ,,.,. z, ,, , 5F$~-~ ......... .~ - ~ ~ ~ .~ ~ ~ ,.. ~ ~ ~ ~ ~ .. ~ .......... ~. _. : ......................- .......... t"0 t't"2"~ ............... 9'5'"~" ~"~ ............. -7"~-'i"¥-7 ............. '~'"~-OT+'4' ................. ,"-*-¢'~' ...... -,=~,-~',)qA'~=>~::~,.~:,.'~=,7,$,,':~:=?~~*&'*'..:....-','~,..,~,'. ¢~,'.~.~6~ '.'.,..:-.::".-,', ........... '..:~'....~, ......... t"'0"9 't' '~ · ............ 1 6 '? '~" O '~" .... 5' ~"'~' 7 't ........ ,~' ~..~. _. · ,-a"'c .......................... ~_.,.~...~. ............................ .3... ~...~...~. .. .................................. ~...'.~"'9'5 ........................ t,.,-5~ ................... ~-2'~-.4-.~ ......................... ......... ~-,0-'~t--0"-~ ............. .t..7-6.-,'97 ............. 70 · ~-~ ............... +~--~-,-~--5 ............. ~'-',-"9-~ ............ ~.,~-~~-~4~=-?,. ..... :,.----;-1--e.9't.~'"-~ ............. t.--72 ~-.5..* ............ ~ 8. a: 1: ~. ~ ..... 3 ..... , - -. ~ ..... ' ..........~,..~,.~." "-.~:~....~ ..... ...... ~...:~- ~.~ 0-,~ ...... ~ ~_~ .., ......... '~, 1 , u~ '~. ~. ~. ~. ,7 ~. ~.. .~ t....-~. ................. ~,--~ .... ~-'~ ............ ~'"~'~ ............... ~~ ....... ~? 1~,1~ ~,7.0 ~,9C 3.33 4,~1 ~.~0 !5.~ 00 ~ ~ Z. ~ ~ ~ ,...-~---~ ............. ~-~---~~ ........ ~? ........... ~ ~- ~-- ~'~ 2 .... 7. ,,,.t 3,,_ ~ .... .,_.1~ ~ ..... -.~ ..-.,~ ..3.0 1~.1e. 1,,. ;~ 4.5.~ 3.76 4.~5 5~.85 1~.50 .9~; t~,~. 9,~ I .~ 4.~,, ........ , .... .08 1~;.~1 -?.. 7~ ~.30 ,,9,. 1~ 11 .01 ~ ~.0'3 14.~C ,, , ':~ · t.7 1~3.~1_ -i'*~.1;, 11.'", U',~ ' .t,'~, , .... 1~.,,_~-~: 1~,..5~. .37 92.41 -8'. &~ '6,.',9',4', "'~.3i 7."01 33.8~ la.45 , '~ ~.~1 .. -' Z"~ .'", O.~ "' .:1:.'~.".3~ '" '.1' ~. , .1.2. 13,?'~ ~.75 1~.~~. 93 ~ 9, '0 ¢ -.'29,8 '5:' .1:...;~, ~ '~1 5. '89 . 2. '5 · '49 29.89 1 · . · . .... . ...~ .. , .'. . ~.. .... . ~ ~ ~ ~. 3'~ -"~"1 '. '~'9"' ",' ~ ~... ~........'~ .... :..~' ': .... ,"'~..'.~...".t....8 ............... z ~. ~ 7 1 ~. r;,~ · .... ~.:S~',7,0,,' "2'.7,81' 3~ 74 . o o o o,-, ? :. ,, :a, ........ ... ~ ~ Io 7.3 7 ,-,~:,,4 ~, 1, '~'......" ... ,.,,3',8,,',~ ¢,:,2,',' .' ...' ~."~':"~':.:',5....2....:.. ,.. ........... 5...~......~'....7...~ ................. 3.o, 5 e 1 '"',~ ' ,1'~a'"0.7"' -"5 i" ~'7'L ......... ~'7';"'75 .... "3'"'~',2:',:~'" .... ....... 6~.'2~ ',, ~-~" ........ ~ 1' ~7 , , ,, ~ 1 1 01.1 3 - 50. ~ 1 55 · 44 '"'3,,:8: ""9'2' ," 68,48 .¢ ,0 · 09 1 3..7 .~' .. ,,,, 2~ !32.41 -4~.~5 5~.9'~, ' 3',2. e.'~ ..... 62~45 30. ~..3 1~.73 ' '~I .I~1..7..r: -.4.9.3~. 53. ~* ...*'~ · · , ., .. ~.,.. ,) 9.~ ............... -~-~' ~-~ .......... ::--:-..--f:-,3... 96.0-.., ..................... .~...4.., 9 ~76 . 75 1 9 ~ · ~ 7. - ~ 8 ~ .8..$.. ................... ~~.., ', ~ ........ ~5'5 ~-.9-.8_ ~ ........ ~-~:::,~:='-;~,:~7~:,~:7";~:~.',~::~~;~;:~;:~:.::::":~:~':;:;:~~ 7 . ~;~'.~-~,.";¢;~::..~:~;;:~~;;. · .... - :~ c~ ' ' 4~,~;, ~1 ..... 1~ ..... ' ................ ~'.-~'"'~.. '- ~ ~ · .......... ~.0..962 ,- .......... ~.-.9.6 4 ' 5 .- .... ~ ~ . , ~ .,J ........... ~..G9 ~.-~.., ................... ~.-~...,., ' 24.3 ~ ..... ~ '~. . ).~- ~.~.. 6 u '~ :~. ~.. Z ~.6.1 6. 7~ ..~ ~. ~ ........... :.~-~...9-6-~ ..,.~ ............. .,~..7.. 7=. ~e.~-.. , ca,.,. ¢~..-53.:~_ ~.27 ~5..~4_.. . o~.~, p~.~,. 1~.,~1., ~--.:-:.-q-...O..9 ~¥-..-.- ................... ~-~...,,-..~,7 ~ ~ . ~ O. 1 3 ~ ~ 9 3 ...... ~4-~ .... ~---9,,~ .....~-~-.,2-..5 .......... 7~,~~',~:?~&,'~~ : .......... 4-0.9-7 0.. ,-.:-. .......... ~., -9:','"-~-'.~ ~ ~ . 95 10 ~ · ~ ~ - ~ ~ . _~ 7 ~ 1 . o ~.. 3 ~.. ~ 1 ~.. ~ . e 8 ~.. ~ . ~ 1 1 ~-'~ 9.~ ~ ........... '~ ~ ~ ' ~ 3 7 ~ t. 0 ~ P ~ .-.5 ~.. 3.~ · .76 5 ~' 4.~ 5.5. ' '~' '~' ~ ....... ~'~' ............. z.,~.-..,~,~ ......... .... I ~' . ~ ~ · ~ ~' · ~- ~' '~ ~ . ~ ~ " " ' ~ ~' ~ ~ ~ ~ ~ ~ ~' ~ ~ ~ ~ ~ ' :,~:.'.~:K,.:'.,:~:;.~ 'f.:i::L "~ ".-:..t.'0~-7-~.,. . ...... ' ~.-~.~. . , ~.7.~_ lr',3.~1, .. -5t.~, ~..., .~1 5~.35 ~&.05_ .... ~.~5 .~ " ~ ~.7--,..~.~ ................ ~-%-.5~ ..... ~'"~-~-~ ..... ........ t--~--.~-7.-~.-'.., ................. ~ .............. . : ~.:~,978., .......... ~ t....,..?~.. ~.73 10~.~~ 47. "~ 1'' ............. ,._ . .... ~ ..... v~.47 41.~4 1~.0~ 5.14 , ~ ~ ~ ~ ................. . ......... t...09.8-0.'-~ ................... ~-7-..~ 8--~., 2' · .5 ! ............. -t--'~--~'~-~ ........ ~~ .... ~~ ....... ~~-~-9'~:~,',,~:~~~:: m t L / ..~ '~ m ~ . m ~ .~ m ~ & . ~ ~ . . ~ / ~ .~ ~ ..... ~ ..... : ........... I-'-0'9"8'-4-~' ................... 5-.~...,-..-t..~ ........... .24 i'. .......... -t. g98.6---, .......... ~..~..~ ,3..o .......... 2 ..'- .......... 1-.-u,~-~-~-~ ..................... r.-~-...~--7--.6 ............. ~ ~ , . ; .......... t--.0' ""' .... ,~..:z ....... '~ 5 .:)..~, ~..~ ........................ :Z.,"...~ . ._ ......... 1.-..0.-.9:7.-?:---,, ................. ~.-7.~-.-4-.*,:-, ................. ? 5 i * "P'R U D'HO'"5 ....... ~'"'~"¥ .......... 11-i..3 NCRT ]'. ........... G"E~T"'H ..................... G'~ ........................ CN : ............ I'" t"3'.3"8' ~ ................ :7"~'"'~'"0"3 ........... 25 ............ t' "1 "0 't' ~"~'"~, ............. ~" q"-;". 5' ''~.. ....... ._'~ ;:. .......... 1-"1-.'0--1' 2', .......... c..:%..n...9 ...... '~ 7 ........... --1..-t--e t. ,~..--~ ................ t-. 9-8...~-.. 4.~ ........ ~- ¢ .... ~'m ~.... ....... =---t'.-t'-G '%6--w ......... ..:'-~ ...... ~-.--5 ......... ;~ ~ : '"'" .......~..t.~.~. ··4-.-,~ ...... ;~ 1 ............ %-.t.,¢ 1-'~, ............. _ ... ': ......... t'"'%'~'E-'.3"-, ................. ~"t'"~'t-5 .................. 23 .. :.i ........ t...t-.-.9-22"-'~ ............. 3-~.'-~-"9'-5 ................... 24 "" ~' ................... 9-5"F9"~ ............... 23 7} ......... 1"-!"-~"["~'"i' . ........... '--$10-2 ~-.-., ............... .7,,..-E..-~ -.-9...?. ............. '? 3 110£~. /,t ..j2 2~ '!!030. ~: '~ · 1,"' 23 'iI"'~;' .. "4 '1 i 1S'7'," . ~! .!? 23 11 .".-~ .':.. -,,, 9., ~ 11 - 4". -" ~- ·: :~, 2'4. 1i"4'. .7' ~. Z4 2z 1i"'4. '~ :"~ 23 ~.~ i.~ · m · I 1.3 ~ *, · ~ ~. ,2 '.-; 21 1 1 jz, ', .'.'.2, ~;~' I 9 ~,..' m ,. · ~-~ ............ t 1.0..3.D-, ............... s ,% 14 ;2 r. ¢.C 3= RFOC RILM T T '": V O F,'~. "' ~ , , , i'i i~' . ..... t.-105 4-., ........ 27. tO 21 ........ 1' t-03 "5'", .................. 2' 5'i'5'~' .................... t ~ ........... t..1-.05.-~- ~ ................. 2.-8..J,.--'9 ........... '1 f : ......... t-t'08' O""., ................... Z'"e"i'4 % ............... 1 8 .......... t'-'t'0'5 2',-' ............. -3'--1 '-~"'~*"0 .......... ? 0 ........... t-"t-'u-~",,","' .................... '?"7"-"~' $-7-. ................ 2-0 : ......... t'..t. 06'6, ............... '~-'-t :-,'-~,-~ .......... ~ 1 .......... t-'t'"0'6"-5'i ........................ 5"B.""i" '5"! ................ ~ '2 ...... 1 .t.-.070--, .............. ~ ~-.~-5..~ ...... 23 : .......... t--i-~ :7.-?..-.,- .................. 4.9..,.....5-4 ............ 1 ..'4. .~ .57 ',77. ~t . '.,!. ~ 75.61 7/.. 77 .."'7 .54 ~0,3'6 · 1? .... · ,~ , · , · · · - , .: · ~ .,, ,4~ i01~39 .47 I~' .~? .~1 ~8.93 .38 1~.93 .86 .08 9~,. 57, .~8 '1C2.77' .... .73 131.5C i., ,, :~ i .. ~ I i , ,~?. a~,.~_ .. ~ :'. ~ '~ 1 ~ '? i · ~ , J i .~E . 95,.~? . ~1 ,a,~,,. ~ 9 .49 S~.6= .7o '1 .,~ ,,.'"~M GCC iN. 71 · c'= 1'21.52 1 1~-~...~3 -50.76 -~:~J .C5 .... 57; 1 d ' -'+5.6~ z.,6. g .F.. 117..70 4.9,93.. 1..Z2,78 60.9? 1 '.'6'~ ',. 2..5" '2 01 i 21 6 $:.,..~ 8.2'0 ~. 3 6.9,94 2~8.27 '~:/.,..,.1 ~ .97.'5, .3. '..~ ........... · 3' F5'6 ....................... 31 .&7 9.77 33,. 54 '~.77 25.1,R 9.7c 26.34 ~. 7,.~ ~4.., .c4 ').?~. 32.91 9.79 .. .,~ . ., ..,, 9.79 9.7& ¢.74 ;-' .74 9.7,';,- C.74 -z~ 1~ ~'~ 64 ln3 ~'.0 ~9¢ f.O P..3 06 o 74 ....... · .... ~ 'ii, i i · .... 1 · .. · ' · · - '$ 2.1,7 '3 7,,2,-i.,.4.--7 ............... ~-~--i~-2 ........ 6-99.-i~ .......... ~-~-~-~ ..........~'7'% .................. :, -71.0~ 1~1 .~1 ~.~ ~. -:.~ ~.~ ~.~ .... 7..5& ..44.63 ~9, ,7.5 38.~ 72 19.23 9.77 , -8.29 3~.90 32,.~8 42.90 19.10 ~.7~ . -~.~:~9. ~3~.,47 69.17 99.53 19·,43. 9.75 ....... t-..1090, ...~/' ~..0.o ............ 1...5..;3..=.. ~.9, ."' ? -'"p. 5i ~:~7. z.? ,~.-,. S ~ ........... i..t.0 ;--Z-., ................ 2 :.,--.5.7- .................. t-.0-..,--5.-~- .................... ~.~..-,-.--?.-~:- ............. ....... '1... t '.094-, ........ ~. ~.,. ;..,~ ........................ ~..-.., -'. .......... 1..I 0--~'.6., ............... ;-.8. ~-.~....~ 1 '. ......... .l..l...~q.a.. ~...., ........................ ~...7......,..% ~ 1G.7q · "1"1 t C"-4'. .............. F"5'"~'--3'8 .............. I C'. ~ 1 ....... t' t' t' 0 6. ..................... ?"7-'~' 5"g ........ ,n. ~ 7 ........ t"-i"t'6 ~' ~ ...... ~'7 ~-- 2-~ ......... 11 · ~0 ...... i"1'1'"10'~ ........... ** '~ ..... 1~ ...3.~ ............ .".."C '~"~ ,.,- " . · ......... 1'"1'1 t z;,., .......... ~"8"i--"9"1 ......... I 3 · ? '= :4 "., · ,.%.~. ';'~,. $ 3 '-,.'I.1'.- : ......... 1.--t.-.q'--I--"-' - .. ~ "' - ? ~ ; a _ ~ ¢ ~ , , ~, ~' · ? 1 c"~ .............. ~'O'"~"2''''~ .... 1~.~7 "'1.2:3 -..*.7. "' ~., .6 ''4. !10' ~0.~'~ ....... t-'1'"-1 'E"0"~ .............. ~'"5"'~C'"6 ............ 1' t" ~ '5' ~ ................. ~"7"'~""5-1 ............... 6"7-ir"9'G-'-"'t'"4-5-~"~-5-e' ....... -t'-85TZ- -04--0-8'e{)"-i'--8-6 ............... 2'-'3-~-5-"1- .............. 9T7-"'$' ' '"t":t"t' Z' 2", ......... ? 6' ~"?'~ 1' 't' ."t' .'5, ......... E 9'~"'7'"'~ ............. 6'S'"'~'"2"3 .......... t'"'5'7'~'"~'"96 ................ t'":3"4 '~" 7"7'"t'"0"0"3"0'"~"t3'0 ....................... 2'"~" ~ ":3' 7' ............................ 9"~'"'?'6 .................. · : ....... -t--'td--;~--4-' ~' ............... }.'~--~'-9--~ ................. t-"~'"-~-~-~ ....... ".~4,'--~-'-'~-:.z, ............ ~, ,~-~4,--4-~-.t.-.~-~ .~--5 ...... ~4~, ~G~',8...6.~--8'6 ............. ~ ~,."~ -~'~.'3? -~'~.~. .110.... 041~r"0r' .30 ~...~7 '.', ?0 , ii . ~ ~ , ; ,., . ,. ~, ,,,, ~,~ - · . ~ -..,., ,.' · . : ---1.1-12~-. ~.6c ~'.'~.~7 -~9.3! 9.~... 1 1'0'6,'~.5"1000u,00 2S.?O 9.~..:'; ......... -1.11-zn ,, .. ........... ~.'.5...35 ~ ~'~5,05 -?c.....4,~.. 1"151'~, ... 119.~81003'0. .00 ..... ~.44 ¢..~.. ............ t...--1--.-.t.-5---~-~ ................. ;;.~..-.. 5. '.-'...¢-.16. -.7.0.~'z 175~...8..2 8"~.0~.10'.0.00.00 ....... t.1.1 ~. 4-..-~... ~; r, c c ":' ~ · ~ '~ -'7'0 · 00 90'1. ~' n "1' 1 3...'z. 21 '30.0 O 0 O ~ -~. ~ c r~ ? 0 .................. .~ j ... ,,., · ~ .. ~ , , '.., .,, , · .. ~. ~, . . . .............. i-.1.-1.5-6..-.~ .............. .. ~,~.o.~ 7 · ~.?'5 .... -6'~.1'~" '.?.~'-',~ ..... ,z~ 105~"7'1 2"7:3':~'. ~ ..... 08, 2c 97 9.7'.' ............. t.--1.-.t .z~.,_...~..s ...... ' -- ....... 4 ~ ~ ~ 8 · 5.4...-.6..:9.., 7....5'.... 8.4 3. ~..7'5..: .... 1'""0....~ ~1~' ' '""" '"'0.....¢ ~,t'n'~"'t" ......... :-1--.-t-1-.~..g--~ .................. ~ S · ~ ~ 5, .~ v· 19 ." ' :7' 1 ... 7"6. '":' 1".'.7' 9. '3'."," ~. 4.'"" ":'..,'.'. 1..1 '6 ,...23' ' "'1. 0':"00'O"';"'00' ............... ~_ 1 · ¢ 1 ¢. ~ ~. ':..---'--.--t.-..t-.!-4-.~--., ..... :7 1~ ~. a'~ 'c...t -73 14 ~13 73" 1..'.3"~2",6."t'1n"~00.nn 14 '~' c ~ ....... · ~ ~ . . m · ~ · . ·, , J~ f~ ~ ~J~ · , ~J' ' ~'° " ",'9..'?'. 381. 00 gO '00' ~. 1-, 9.6" ...... .4---t--.1 -.-4-. -~.-- ~ .................... ? ~ · '.-': 7.. ~ ~:. 4 4.... - ? 2. ~ 3.I 3 b 1. ~ ....,_ . ' ., '. .......... t.t. 14.6....,-.- ~,7" 7. ~.f.t ~ ~1.3r;. 1~1~..0o, 1r~6.O2~.~ono.00 -~ ':~ ~ 71 ............... . " ., '"' ..... , · i ,,. ,,,, .... · '%. - · .... .-t--~J...t-.4.~:-~- ................... ~...5-..~....8.7~ ............ 8. ¢,.2,6....1 ..... ?0...6.5.. !.182.,.4. g 1.0.~..6410000.0O ]0.04 .... '--9...6.~. ....... -..L.t'..t....t.,.5..0...~ ......... ' ........ .~..~*.~...t..~'. ......... ?. ~ /-,'. -70.4's ~8.-~'= 10~ 541n~-,9 -.- %. ,.., ... ... ·.,., . ..... , .. .., ~ ~.. ~.. · . - ... : .......... t.'-t t'"~-'~'.~-'-: ............. ~-"?'~"-,~"¢-' .... ~ . ... 07. ~ 4~. -'~-9. ;'. 5,.. ....t 320..7 s'.. I 'z9 ..¢ 7.1.00aa., .. ... 00. 2m: · r,?,. .9 . .-~.n: ,. . · , r~ ~ "~ ' ................ ~ · m ,, , ~ · . · ~, .. ., ,,~ . ',. · · t--..-I.t.-5'4-, ............... ~.-7.,.~9.-6 .... 1. '~ /~ ~.60 11~s ~ ~'~.~.'31'~'-~'~v.':':0 ~;.~'~ ' "t""0 '~'L3"U"-~'--~ ,~ .............. ,'., .-"?.-¢ .... . i' ~,~ ......... :-.-.$..~d..-5-6--~- .................... ~-., .5-.-.~-.-.1.-.~. ...... ~.. 9 '~_...-',. 0. - 6. 8. e 4t ~..,, u. '~ .r, . 3.7. ...... ~-6. ,.. 5 -1 a. n - n n ..... z..~, ..... ~_ ................... a._. ' ~_ ......................... ............ t..:-.1, t5~ '...'~7--i-5..-8--. 17 o5 ~ -~ ~? 112~ ~6 135 741000n nn ~..)....~ ............... ~, · . · ....... ~ ,.,.,. · ! ~ .~., . -~. · . ~ e ,,.~.,~ .,,,,. ~ · ~ · , _ . .......................... .-_ ............ ¢..% ......... , ........ ~ _ _ .~.~, . .... ;% ................... 0- ......................... ?-:-:-t--t-."%'6.',D-~ .................. .?. ..,~- -~. ..--1.- 7- ........ ~. '~. 7 .4 ~ 7. -t ...-~eT~ -9-~9-. ~ , ~ · ~ ~;, ,..9~3. ........... t.-'--:-t." ........ ?---6-'~;z'-5· ~' ? '~ .3 .,:,~.'~'~',~,,~'~ -n ~,~, -n ', · .t. 6..---.-...,-.. _. 1 c, · 71 97 -, - ', . 4 .~ :~ ;~' - · ,~ ; 9 ? .~. .... . ~ .. .., ,. ~ ~ .... ~ .......... -I---t..1...~.~., ................ ..- :.?-.--t-.-.-,- 4 -'~. .... 2.i. 5/, '~.... -t...'".- · -66... ~g....,3" nu ~. 1 ~, .... oo,,. ~,t.. 1 0000 .00 .34 . '25 · 9 . ..~c,, '... -':-..1--rt-.-t. 66, ....... ~...a-.i5~ ~1.~._':.' 1"2.49 -~.5¢ 55~.~: 77.~5 4z,.71 ?,~. '41 ~.-.-': o 7! ........... t"'-t-'4.-,5-8--'-.- ....................... 5:'t"",'-'8'"~ ...... 2 2 · 1"3 1 ,.; 1', 4...'z -'o-9"'~-"a-8 ............. ~'6""f-~-~'~ ......... -,~-'3-.--~-D--%Z,.8.gT.2_-1- ......... -~-?-r-."Ae, ...... -a-.rT-~ ............................. ............. -t.--.t-:.-1- 7.0 .. ............... 3...4.-,.-.6.-.7- Z I. 5 ? I '" i · ;~ 5- 72 · 3 ? 7 ~ O..,~ ~ '37. 58 41 8 -: ........... $.t.--.-t.-7D,.-~ .................... 3....~-.-~.--t.7 ............. ,~2 74 1"'..0;~ -.~ 2'.3 8.~.g R4.. .~-4.45.1~nnn _ . .... '~' ~' ' ' , ,,. i" · , , . . '~"~ ~' ',.;" i'"'J'~ ...................... ; '~-i- ..¢'c ..................... .. "i-r-'~ .......................... ....... '...t4-.t..7..4..-., .................. %8..~.5.3 ............. ;,3.6'.). 10£.?~ -?0.~.'~ c~,.44 94.291C00C..00 zz,.42.- ~.71 :- ......... %-I..t--.76..--~ ................... ~..7-...~.--4--~, ...... 1 9.1. ~ 104 .. 02 . -.~ .7 ~.~ .7. .............. ~--~.-~--~.-~.5- .............. ~l-,--3~--$-.~z?,t6~3-~-G'*3 ........... .,z-e.-~-~.-t .......... o_~..~ ....................... ........ · -1-..-.t.--:t.7.-8.. ................. .-.2...4 .,---~..1. ~c. ~,... ~'~ .41 -~,~.... . ~'~ ?09 . r.?._ ~, . '~ 110 000., .0'~. ..; .... ~? .17 a .71 ..... ..--.i.-..t--t' -8..0.-.~ .............. ..-." ~'. · 5 :. ~ ¢.. 6 ~;' '~ 4., P_ 1 . .. -.~,. ?, .. 6 ::.? /. ~,' ~.. · ?..1 ......... ~,.~...,, ........... ?..,',.., ........... z..O...~.4,,,., ....... · ~-~-, ,, .......... P-7-..~4-.z.. · ., ................ -g, ..... · ,~..-~... .................... · " . .. .. · *a ~1 ~,~':.,' o? 78 /,-~ 4'~.~9.'~5 ~c, ~;:, c. 71 ............ -t.-.t--...t--8.-2-..., ................. '.' 6.4 ~ ~ 1 ~ ~ !..3 ~ - ..................... -.: ......... t-t--..~-~ ~.., ................ ~..~...,- -1.-.t ................ ..... ~u.-~..~' ~' ~ ~, . · ·-t. ,0.,?.~,-9..--1 ............... ¥~.~--.~-~. ..... .~-~ .-~2~ ...... -~.,~-~--~--~4-~-C~.~ ............. ~T~-~ ............. ~-~'-~'~ ....................... ' -' . ~ -) . .. .,. . ,, J..' . .,' , · ......... t...-t.--..:].;3-o"'. ............ ?'6.u ................. t..9".~C';'..- aT·.~? -'"E.4; 3"'~5.~'~ c,'~' -~4 1~,1a F,'.C ~o.75 ........ ~1-..t--t.,.-&6---., ................. ~--~....,...g. 7 ............. -. 1 '~ .77' a, 4 . ~. ,..' "" '~.., ..,"'. ,2 1 ' '3 .... ~ :'4, ..... :~...:~,.. ........................ ~_~, .,, ........ ~.-7__.._._~..n.~....-o-.-~--=,-~, _ . ,., ,., ,: ., . ................... ~..9-.~.-..~.... . ............ e,-~--6-9.. . .................................. ..... :.-...t.--.t...1.---;.0., ........... ;-.-2.4-,..1...1 ............. ?'E.I~. ~-,. · ?.~. "..-.5 . :~, ...z ,.) 5..~1 7~.75. I 4 c 1 . ,~ o. ~?.Ol. -'.,. ? ~': .. 111 9; ~ ~ .~ '~ -.-t a .,~: ............ ~a......_~z_~__---~-~__~_~___:z~__~c~ ..... =-~=~,-E. ....... ~-~,,~-~ .............. ~,q__.,.~q..z .............. ~..~,._~.,,o, ....................... j ... · ...... / i' --~ .... ., , · . ~. ,.,., · .- ... ~- -, u · "T ~, , ~ . ., . ...... . .. : 111¢,..'.. ~7.41 71.~~, ~7.92 -64.67, '~,~,.6e, 84.'77 5?95.26 ~9.75 9.'69 [,---:---.-1..---1--~t'-2..5..,-.-"- ............ ? 5. g ;'. 1 5 · 8 ;~ 13.49 I 1 !.'9 1 1' 5..= 1 _28 1 6:; 1 0'i · 1 94 ! 75 ' - ................. ~. R-.6-¢3 ,....6.L..~. S..K:.,~ ............ ...... = ...... E'A'"'¥ ............. : ................. ' ~' ×"U'u'"H'O"- . 11-17 ';0PT, SLC'¢'~= 11223. ;c.3! E.O. 7. Q .... ~3~3 11'2_;2. ,~-' .~'~ 18.8E -,-,. 3. ,~ ? 1122~. '3~.~ 16.n7 ~3.~1 11~Z" . ~c.7~ ,, 25.3~ ~5.81 1123'~.. . ~4 . ~. 31.32 ~.~2 11252. ~.~ ,~4 2'7'. 12' E 2.',~8 11234. ~x.9-~ 28. ~,2 76.,09 1iZ=,~. ~.1~ .. ~5.0~ 7'7.'00 ~ ~ i . · ., , ,,,, t1Z~ .... ~ 7~ 11;~2, c~.7~. ~.~_ . 7x.~'$ :. ..... t.-I.-2.-4.4.-, ................... : 4,5 ~ . ~ i, 4 c .. 7 5....,. 51. ~..---.-.'.-.-t--t-..2- 4-6.-, ............. ~ ~, 1 7 35,6 ~ 7 ~, ~ 4 " ........ t ··t-~ ;.,.-.~." ~ ,' ........ ?--3.. ~..?-~ .................. 2.-~-.--,. I 1 ~ ~ , ~ ~ ~ ........ 1.....t--.~.-.5.~..-~ .................... 5.7...~-9.7 .... Z 1,5~- . .~ ~ ~ x~. : ............ -$-t 25.4., ............... 4. ·2-.,-.8-4 ............... 2.0-.., 1 C' c !, e ~ '- .......... t-4-.2--..S5.~ ................ ~-.2-i-5---~ .... 2 ~., ~ ~:. -5,'+, 25 ~.R~,64 e./., 4 7 241,71 2 ';', 7 · - 5.-0,4..3 - 21. 1., 93 · 6:3,76 .... 1 9..S~..1..3 .................... ~--t..-.Ft.-t ............................. ~--~..-69 ..................... -17,u~ 1~ 04 .7..:2,~3 ~2Q -'7 ~1 ~ ~ 7C '.~ I , ~ ,- · . i ... i ~ i .... 4'C", 47 .... 1..'2 ~. 7.t ' '.'5::':.1:. , 3.5" ':'154.11 -25,9~. 1'3o,'70 ~9.99 ~g5 51 . ~ , ~ , , , -" i ..... ~ i · ,, .,,. i -1,7., 82 6'~, ~ 8 i'8. ,1 2,' 41 '. 35 ~ 6. ~ 5 ~. '; 3 " 1, ". :10.'.3 .1'~.94 ~.0 '.?b 1'3..., ' ..... . · , ,, , .' ' . ..... ,, . . .9', "'" ""~ 7'.'3 '16 ,.'8.7 '" ..¢ ,..2..' ....... . ', '. 3. ~"&::O, .' "':'""1 .~.' ;'..".:~..C'" ,,',,:",'""'?,'"" '"0','~:',,,4-9 ' ,' ....... 7. ,,, ..... ' ' ' .,..'.'... 1.~......~.~ . '.'5'.;:.:?'."~?"". ...... '"' ..... '""" "" ......... . .... ' ...... 21....1. ,0'",,, ,,:,:',~,.. 9?0. "" '"'":'" '"' .......... *"~ ........ .... ;, , ,,,,,, :,,, ...... ,,, ..... ,,,,, , , , , -10.70 1',~ 01"",, ",:1", ,1~,,,58 1 ,, I ',',,', ~ , ~ , i , - 1 2.40 1 9.5.3 "' 1.'.".'~ .'.."1..3'" 1.4 .~ .0 -1F,,~.~ ~6 "~ 7.~ , ~'7 · 10 10 ,_ -.8.,35 .....11.,8.~ ... 7,..0.1 ... 8,19 -7,6P 11,~z, ~,¢:.z .~ .z~ ; ~1 ~,~1 - 1.8 "23 ................ t...-e.-F~-5 ............... t~-?~---4~-~7~ ....... ~-'FS'~ . ~., '.~?' ;7..:' .'.. '~:~: :.'.~':t::'""~i' '~'..'~ -.~a.~,..41 47.. =j~.~ .37,43 .... ' ~3. ~.~ ~3.1~ 36 '~5 ~S · . .... i ~ ,: i ........... 1 .t--25--8-, ......... Z--7 -i..t .-0-- 20. : ........... 1-'"'t'"'~'~ a'"~ .................. ~-'~---~-' 7- ............... 2'7"'F~,'".. ...............9'"'F9'"2' ........ · . · . . - ~ ~ ,~ .., 9 ................. .,'"'="'.8"'"F,,'4'" 0 ..,0 - "' i':'"":---t-'-t' 2 '6 -~"-,- ......... ~..rz..'~ ..n.6~- ? ~..,...~ t 0..~ .,...~.....t... ~ '~ ~' ,= ~ n ?.. ~..~ .~ .a .~ ."3'"E"'FS'"0 ........................................................... ~L- .......... t...-t...~.4.., ...... ~...,~.~ 25.4..E- .t0.z..~· .-Sb..C~ 4.3g,49... 60.!.1 142.94 33.5~ Q.~2 !L .......... 1.-t--..-2.~-6. "'7 :.!.'~ · ...;. . · N -- ~ , , ,. ',' ,., , . _ , _ i l ........... 1-..t..-~.6 ~3-,- .................... .P_.-~, " · "" ~ ' · ~ .... """""5' ~...9..t .......................... "t"%'"S'"q ............................ ........ t.-.t :.'2' 7-O"~ .................. : "t'--i ..5'""J .................... -1 6 · ? .~'"~" 2 '",'"~ '-~ .................. /,""2 "F't'"'~ ................. -t'-6".P.'""~'"'".:2'"'~ ........................... D'"~'"'"'~"' ;'",~ ........................ ..'.'* ~-'~."?:~ ..................... .. ........ t---1""": "? ..~..-" .-z~ ... .. 44.17 7".~ -~.17 I..., · -/---r'~'-'.~ .............. 37.Z? 19.6 :' ........... t.127-4.-. ' ~ I ' ......... -t.-..-t.-~-? e -, ............. a..-2.-,...7---~ .......... ......... t.-.-t---.?-7 "" ....... ~... .............. a-.-t-.-~ 6-,~... t-.t..2.~ 0-..-, ........ t-.-.~.-..5. '" '" ................ ~'f ............. ....... 1.t .~ ~. 2- "~ · '"'"' '.~'- '" -- ,~ '! .......;~.': --.-" .' ~ " ............ t' "t'"E"~'4"~ .................. ~"7'i'7"I .......... ........... t.-...r 2._~''' 'o.. .......... ~--8, t.-..~:· ........... t...-.t-.~-.~.c,- -. ~...$. 7; Z.,..:. ~ 4. 2.9 0--,.'. ....................... .~'..~ . 2 ? · ~. ;A ;5.~''' -."? ?~, 7_m.~P 12.=~, 19.1~ -.5.c~ 1a 3A 2c.~ 7~.z~ ~.~6 10.,<~ 7.25' ~ 57 '9.76 i~.4~ ,0.14 ~.23 10.c. 6 9.~'' o r,~ = ~A C.~ 1n 44 ' ~ i ,, J' ..... ., I ~ ,. .. i ~.~ rc 22 ,,9 , ......... .. ... ~ ~ .- ~ , . ~ .... . ~. .,,, .. ., .~.~ ~ :~9 10. ~ ......... ~ ~ :~. ~ .~..,:~ ...... ~ _~ ........................... o.~ ................ ~ ..... $ ............... ~:,~. ................. ~. ........ ~:'6'4 ............... : ................. · ,~ ~., '~ "t-', .................... · "-...'"~'4 .............. .,., ~, :'· .~, .-. ' ........ ~ · . -. ' .......... ~ ,::.. ~:.:~:: :. ~...."~,~..:....,,~...:~:9.~-~.~%.....:?.~.?, '~.....~,...~.~.:?.?.':"-.~.~ .:.......-.:~...'...'~, ~7 P7 r~ l& -l, &..7 .10,7~ '6 ,9~ 7 &~, 1,7P 1~ ~2 ~ . · . ' ~ . · . .. ~ ~ ' ~ ,~ , ...~ ~ ,~ . ~4,~ '7~,~3 -~,5~ B,Te 5,~6 5,~~ .~, ~. ln,7'~.. ... ......................................................................................................................................................................................................... °~'GE .......... .5 .............................. ......... 0.~ T. E: ....... ~..-/1.5/.'~ 5 .......................... T. ~-'H-'-E- :- 1" '3 ": '4 9'": ........ ~ ....................................................................................... ~TL~ r-cN 2 H,,'q ......... t-t,2.9.-~, .-, .............. ~..6.,,..-5.6 ............. :.. ~ 6..~ 1 ? e. 77 ' ". .- " 7~,.4P ............ ;1"t"'~ c~6'"'~ ............. 9"0.,r94 ....36 · Z .: . .. - .. ....... t' t-'Z-'9'-~'-, ................ 'z-7'"~"'3"? .... 3 G. ~ ,~ :; ? · ~- ~ ....... t-q 5-0 O- ~ .......... 87 ,~..;. ~. ; 3. I 3 7 ':. 91 ......... $-t'":~,-e'?"'~ ........... ~-7"-~' .5 ~ '," :;. ? "" ' '. "'~ ........... t'"1 ':S',3' 4, i ............. ,-9:. O 'i' o'-7'- ............... 2' 9'., ............ 1..1.--3.C.-, 6 ..~ .......... 1-.-0.0-~. ~.'~ ......... ....... t4 $-G'~"~ ........... -1--0-"t' ~'--6.'o" ' 5 5.5'6 ........... 1'"-'t-'"3"t '9', ................. t'"06'-'~"S"~ ............. :' ....... 1'--t ~-1'-'~"~ ............... t"$",~'~- 6' 8.- 3 3 · · .: ..... t..1-3.-~t.-~· ~......' ..... 1.0.9 ?-:..!-. : ...... -1-:-,t'"'3't'"o:~ ............ 't4--"8'-','6:¥ ...... 32 · .. : ....... 1' t ...3-1. -~... ................ t..:.'..".-7.-,-' 1t3~C..- ~'4'~-3'~ ........ 25.'11 ....... '. t.-t.--3-2-.2., . ..~..~ .,,.-6..4 ..... 2 7.93 ....... -.1-.-t.-..3-2.~.-i 3.2. " ~ 5 ~'0'9 " ........... :t 't '3'"2'6'"~ ................ ~'t", 67 ........ 26 · ~ 1 .......... ~'."t'""3"2"8-"~ ..................... ~"5'"~-6'"~ ......... 2"?'. ......... 1-'i" 3' 3"0'"~- ................ ~. C ',"C'",'"'~ ........ 2 7. ~ 2 ?'-~-t"--'1'--'3"~'"'2"-'~ ..................... ~-~';--9'-~ ........ 2 6 · 1 7 ..... 't4-3--~4-.-, ' -'2 ~'-',-8'-'0 .......... .2 8.1' 3 ....... .'44-3~'6'-',, .................... 2' ..~','"~, ......... 2, 6 · 11 -' ......... t:' t' 3 '-3 ~",, ................ ~'.'e' '~-- a'~ ...... ;_ 4 · '51 -?.~4 7.~'; 5.74 6.67 .~. "'? 5 lq.17 - 5 ·/'" 7 ................ ~.. ~.. 9.-z, ......................... 7-'~-'4-9 ................... 7"-73'~ .................. ~-3".-4-"2 ............. -7.3'~ 5.°0 5.';7 6.!7 3.7~ 10.1(: -2,.69 O 9'~ 5.:3 5 61 -~ 11 10 .. , m ,~ ~ m ..~' m m ,,, .......... 1:'--1-3-4' 6 :i- ............. 3"2--,~ 6 3 ............. ,-'t"~.'~,' . o 'i- ................ 4-'-d'-.i- ~'-,~- .............. t4-3.5.0.-.,, ............. 'z.'-4",:---2'-0 "" "' ~ "' 71 :' ....... 't:""t' -';2--;2"~.-"~ ......... ,, :.' ........ 1--t-.55..4...~ ........ z..3.6 '-. .1 ! 55~. :7..15 ..... 1.135¢.!. 111 .~1 7.-t.-q-.-3o,..3-, ............. t" 't '"'~'"!' 5'~1' ' -:":t'"'1'-'56-2', ............ t-"-1'-5--'~--O' ......... t...t-:-5,.~, 4-...i..o-.: ....... .~.-!...9-i.. ~..~, .......... t'-'-1-366'"'~'""' ............... 9'9-'i-'-5"0 ' : ......... ~:-'1-"5-'b-$:~ .................... ?'.4.-~-'~-'-5 ............ ..... &'r'"i-'~"u .......... ............. I'" l'""J' f'" ~"i ...................... '~'" %'"i"' '." ' .. ' ........... 21511 II' '2'~ ................. 9-0'"i'"3''' ''',~ ................... ~I161 li'"ll'~ "~'I' I:'"'I"'I':'~"t"'7 '"'~ '"i'-'81-9 ~:.~. ~ ~ -74.~0 101 '"~ ,, ~ ~. ........ ~ ~ ........ ~~ .... ~ ~ :7:9 .... ~~~.~~a ............. ~,,~..,~ .......... ~.~?~.--~ .......... ~.- ...... ... ~ '~ ~ .~ ~. ~ ..... ~ , 1 ~. ~ . . . w - · ~ . , - --" ..... ~.' ' .c~:q.. '~:~::.::..'.~:.~;' "f.Z..' :'.'~;L. 97. ~x -~ z. r ~ I ~ . ~ 5,. .6 t. ~-8, · ,6,,. -~ ~ ....... ~ 1.. 0 ~, .1,8 ~ ,,0 ~ 2 ~. 7 ! -.2. ? 2, 9. ~ 1 ;1. ~.55 ~.e~ ~1 .75 10.0,~ 1~.0° -~.nl ~ .'~" ~9. 77 ~5 -1~ G1 12 2 7. .. 7 ~.~ 0 6 -.4 7 ..., 5 4 ......... t ~...~....9.-5 ................ -~ 9 7---~~'~"-~ ........... ~-5-~ ........~ · --?:~?~?' .. _ i . ~c.. ...... 17 .~.o7~ 17.9 ...... 1.1. -1.95.. 54- ......... .................. .... - . .. ~ ~ ~ x,j ~15. ~1 I ....1~ .1...~ ,.: .... · ..... : ....... ~2-~'-~-', ................... 9"~ ............................ o9.11, 105.71 1, 3':,,. a'? 101 .95 95.~4 ?~-.3~ , -5.1~- ~·24 9.18 S.?a -_ 7'~..'""'.. ,;~. -5.x~... .7.34 6~17, 7,~.. -~.6! ~.9 74.~q -,6.¢ ~ ~.9~ 5.o~ A.~ -,..~ o ~'~ 77.~7 -1 .7~ 5.or, ~.1n ~ ~v , .. ~ . .~. i ; I ~ ,,.' ~0.~ .-8.7'/ 17.5p 1~.33 9.~1 37.<]9 105.33 -5'1 .9~' 3'92 ~'g8 4~.,28 6~.'0~ 36.~1 0.47 · '~' ' '""'" ~" 49 ~5: '88 7;; 36, 77 I u'.'., 3 '2-,07 ,5 ~' ' "~ " ' · ,,, · ,,,¢'01 ,,,'0~ , , · · - · · · I0~.¢~ -70.'26, '356.:87 ~3', 7~ '99.'5~ 35.4~ '~. '~ ~ 134.9.3' -'6"9 ."4"8 .... "..5.3,:'5 ',"! ~ '""' ....... 5 .~..i.0.9" .': .'".1.~ ~.'..1 4 ". 35.91 c. ' · ' 1C~. 77... ,.6'.9 ,'..'56...:.'.'..'..'.'::~8.~.,.~ 6.. ~..:~""'~:8...~.,.5.....~ ............. 2 ~ 55 ~. 4,: ',, . - "' ~ 7'" ~ ',' :...5 . .8 ' ...;r.~....~.~...i..~..1 ............. . ......... 110..68"' . .67 ..... ~ ........ ' ..... .4.. ."..'.., , ,, ,, , , ,, ' , ,,,,,, ,,' , , In 5 ."6 i~ "~ '"~, ....... .o~""'" ........... '~'.~ :' 7'"'~".,. ~'~' "" ...... ~30, ~ 1 ~7 1~. ~ . ~C'.. 9~.8~ -60..~4 ~07.46 '"~.~",'55 112.80 ~E.1 ~.~7 -50.~ .~6.'7't 49.60 '107.!0 ~7.67 .......... O'E'P"-~ H ...................... G' R ...... C ~'~ ~, ~. , ~ u C R I L ~" ~ ~ ~: N r 4 L F'T'". .......... ~"P '~' % T T ~.~ v 0 ~ ~ n ~ r~ 0 ~ v ~'. ~ ~ ~.. .................... . ~ .... ~ ~ . ~ ~ , . . ~ , , , , ,~.~ ~ ....................................................................................................................................................................................................... ' ........ '~- ....... "~ ..... '-~ .... '~'~-'~"~'~'~'~'~--'"~'~--"~'~'"'~ ~"~'"'~'~?- ?':"~'~?~'"'~"=~ ' ........ ~""'""~??~:~'"-:~'?'~'"~'"'~'"'rT'T?TZ '. ................................................. ................................................ ..................................................................................... ......... I.-.'~-.390-"~- ................ ~..7....~.-t.'~ ..... ' 7. ~ t ~ ~. 4 ~ - ~ ~ ~. 5 ! .1 ~ ~. '~ ~ 7 2. ~ ~ ~ 9 ~. 5 ~ ~ 7. ~ ~ ~. ~ '; ..... t..,'~-5-'~'~2", ........ ~C.~5 ~ 4C ~z.3~ -I~.~~ 531.11. 79 77 50a.~~ ~.81 ~,'5~ ..................................... ............... . .. ' ~. $ ' ~ _ , · , ~ ,~.,~ ., ,. . . ,~ ....~ ~ ~ ~ ~ --1""t-"-3'~"'~ ................ ~7.1~ ~1.)~.. ~.~r,. , -la~.~,... ~,~.7,~,, . ~.~, ,.. ~,~.,.1~.,. a~..,.~.. ". ' 1-1~-96'. '~ ~ ~ ~ ..... ~...z ........ p_.:~ ............. ~_p ..... ~ ......... ~~.~ ..... ~.~.~.~,~ ....... ~~ .... ~-~-,~.~ ............. t~-~ ................. ~.~-.~.~9 .... ...~ ......... :~......~ ......... ~'" ~"~ ............ ~ .. · -- ~ . - · ..... . . , '~ · ~ ..... ~ ~ " ' .... ............ ~..-..t...-3--~-'~. ~,.~/-- ,~7.~.. '~'~.. .5C -1'~.;~ ,'~.~?... ~.11_ ".~._....~. ~7.4~_ ~.~.,. ........ ~-..~.-,-.t.~~' . .. ~6.~ 5z.~ 1, P~..~7 ~1~.~ ~.50 ~55 ~ ~ ., ~ ~0 · ~--~-., ....... 4,.~'~ . .- _... " - . ~ ~.~0 ,. ......... :i't49-%;. .............. ~a. .c~ ,..~5.7~, $5.~~ ....-1~'~,.~., ~'2~.~.:., 76.~ ~71.~5. ~n,..~: ~.71 : .......... t'-~"'40~. ~C'.~. 2=~.~,, ~,~.~., ..-I~.67~. 2C~.1~. ~4.00 7~5.'~... Xl.~~ . ~'.7'0 ~t4~. 4=.-~.. ~'.2~. ~q. .,.~1 -~." .5~ ~=~.5~ ~1.~r' 1~ ~ ~5.9~ ~.73 .................. ~ .... , . .... ~ ~ ,~ e ~ . / ~ ~. .... '-:--t'"'t"~-'~'c:'"'~ ................ ~-'t--~---F'5 ..... ~ 0 .97 - 9 ~ . "u'~ 1 - 1 ~ ~ ,~. '~'. ~,. .............. 5'"'~'"'2'"'~-"0''=. ............ ~'~, , , ...... F~'~'~-, ,., ..... ~'~-. · . ........... ~-~. ....................... . ' -.. ' a'O ....'~5 ~ .... . ................ ~=5 :~0 ~1 ~ o 71 t"t:'4't'"9'"~ ................... ~'"'~'"~', _ ., ~.~- -1~ ~. ~5.~I ~ 77 ~'.'.~ ........ 1i41Z. 45.~ ~'.3'~ · '.~ ~C'-'t~"~.' ~' .. ' ,. ..~ ~ ~ '71' ..... · '.;i.,. ...... ~'~' 61"7'i 24 71', ~4 1'5'62 · 0~ .... ~. .'. 11~1~. f17.P~ 27.5c o, ~1 -"1" ~ OlI I~ 7.~ ~9 .b.30.73 34 11 '; ~9 1141~' ~.~ ~7.91 '~C.27-1~ ..... ,, ~'~0 2x4 2o ~ 3~ o v1 , " ... U c · 98 'I .3 u .,' ~ 5 .... .', ............ 11~2C'. ~3.5; 27.54 ~4.75 .... 1'0'9,0'3 1'4',1'.'5',~,' , ~."~2, 2'33~,'5~ 3'1.57 ' :;.7~ ,,, 1142p :- ~o >~ 71 o~ ~4'-10~.04' '1'2.":~"8~, 5~'6..8.. 2'~..31 ~c 14 ~ 7n -- · ~ i i ~ ~ m ~ ,. ~. ~ ~,,, '1 , ,, ,,, ,,~ , ,' i · , m -. "' ' ' 1~ ..... :,,~ ,168.9'6 31 ~,< ~.6'~ . ~." , ,3~ ~6.,~,,7,,,',' ,' 11~_~-. .~1., . ~n 2"6,~ ~.~....~'~.. -I"'"0'o,~''''' 1 '"" · . · .-' ~.~- ~ ~ ~.79 ~..~.,~,1..o~..,.~..?.........:.~:...::.'~...~.,."~...~..~¥".":.'::~ ~'":"'~"~'"7"~'~ .'~ ..... ~ · · ~ .... , , ,,, ,, ,,, ,,,, , ,,,, ', · · ~. , ,,,~, ",~'9'":,;:'9"t,"' ........... 1 2.1 ~ 9.7 ~ ~ ~; ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~..", ~.~. '-'1'~."1 .,..~'".'..'."' ".'. .... ~'"~'".'. "''''~'''', ...... · .. '' · -, ' 1 .... , .... ':']':",';':"'~":,'" , ...... .... ,' ' I 1 ,~ 30. ~ O ..... ~. ~ ~ 7 ; 7 "c 2 0 ~... - 97 · 5 ~. ~ 8 "'3 '9 ",,, ...... ,4~'~:8',,, ;~'::~,' ": I 8 "' '"'.4~ ' ' ~ .8-~ 9.7~ 1!~3'. ~.~.7':. d5.65 ~9.47 -94.77 78.81 "'""57".10 129.60 ,3.83 c.71 1143-~. :r.4A., ,~7, .~.~ :~.-~.5n.. .~ -~$2.4,~, , 11~.'1~,, . 58.05 14'1.'~7_ 1~, .,~. 9.~1. ....... -t-..-t-4.~-.6-..~ ...... ~.. ~,; '6.1 2. ~2, 2~ ....... 8~.. ~.,~. 7.,,~..0c ~8.,,.,~4 1,1..~,7,9 ,,,~2.9.3 ;. 71, 'x"' .~ , ~ ~4 -;~r~.6" ~.9~ ~2.~4 s~.~o °3.v2 ~.71 ........... t-..t--~-..,..~-., · ~ C. · (~ ~ ~ ~ · ~ r, ........................... . . -~-~-~..~---, .................. -~.~9--~-6.-~ .................... ~-6 ~ ~ S ~., 3 ~ - - 77 · ' ~' ...... ,35 ~ ,~ x 7 ~ ....... :--1-. ' ' ~ ., · 9.v.. ..1 .;s3 , 21.93 ~.7.3 ........................ : ........... 1-1..4 "" ... ' ~ ' ~ ~6 · 4' 4-..i ...... S..6-,-.- 6-~ ..... ~5.~: n~.~ -7~.8~ ~1.;~" ~.~. ~1 ~ P )' .................. ~. ..., · , ~ ,,. .. . ,,~ ~ ~.., , ...... ~ -- . e . ............. ¢ .~. .. ~ . m ,.. m ¢ ~., m . m ..¢ . ~ ,.. m , ,~ ~ .. . ~ : :..--.-:.4-.-~-4-4..~-.., .................... ~-.0.~..6..~. .............. ~7.27 .~5.91 ........ 5..3.,.,'~1.. .46...71 ... ~.2...98 50. ~8 2~. ~.6. 9-?.6 ...................................... : -- r''~. . 30 ~ ,, * . :t--t..4-5..0.., ............. ~ .~..~-e...~ .......... 77.27 ~ ~.=. 32- -41.Gx 37.~c .;~ 42.5· ~3.0~' ~.. :~--:--4--t..-4-52-.~- ................... ~.0 ~--6--2 ............... ::-.-,8-7-...~....?- ............ 8~--~--$6 ........ ~.¢~-.~~7-~-~~9 ....... ~-~,,.~.~-~ ........ ~,~-,~ ..... -.,~:~8=~ ....... .?? ....... ,~.; ' ----.-1..I-.454-. .............. ~-.0--.~ 6-. 2 .......... ?~.~7 77.5z -~.;4 1&.19 13.14 17.52 ~.&S '9. ~3 ~ . :. :t--:t-,-~-6.,. ....... .................... ~.O.,--E,..~ ...... ,7.27 7,',,.¢~.. -x 4z 12 4~-.. ~....~6 17 56 ~ ¢.4 .. e..,~...z .............. : ................ L.. ...... t..~--4.~--8 ....... ~0.,-~-.2 ..... ~7 P~ "~ x3 -,¢ '~ 15 /'~ 12 7~ I~ ~ ~ .~C' ~ ;:~ .... ~ .... ~ . ~ .. · ~ .. ~ m ~ ~ ¢ ~ ¢ .~ ~ . ,. , m ~ ~, · m .,.~ m -.. ~. .;~ '~"t::"'"'~'~ ........ t-.....t-. ~-¢,-¢.-, ..................... .>.~., ,~ .~ .............. ¥.~-...- ~-; ............ ~--.S..~.~;~.;~ .............. ~,-Gq- ............ 4~-~ ...... ~,-7,,~ ........ -t-~,,.,8,~ ............... &~,~ .......... ~.~... P7 P~ ~_ ~.; -*_ 2~' I 1 .~¢' 1~.~4 1;'-~4 -0. &~.. ~. r.'~ ' ',' ........... .$.-t.. 4.e...2·, .......... ;..o ,..~ .. ....... · ................................ ~: ........... 1.4 4-~:.6-... ................. 5.0.-.,.6. ~- ......... : ~. ? 7 ~ .4.1 ~ - 6.4 ~; 1 ,.:. ~ 1 1 2. ~ 2 1 ~. ~ 4 5. ~ ~ 9. ...... I...-t.--4~..~-, .......... ~* ~" - , *~ 12 7~ 1~.~4 4.~* 0 ...... ~-.b .,--.-.~...¢ .......... 27.27 ~ ~, 77 - 6 · ~ ~ ~ O · = ~.. ..... ; ...... ......... -t.-.I--.47.0... ............... ........ F..6-.,--~.-?... o_ 7. Z TM .... ~ 1 '; 5 - ~ 3 ~ ! ...... ~* ~ 1 1 2.71 ~,~'. .... · s - ~; ....... o sl ........... t-t-4...72--., ..... ~..0.-.,...¥~ .................. 2..7.*,..--27¢..-.')......9..7. ................ ~.-~-.-5-4 ............... ~--~.~.4 ............. ,~-~--~--.-~-.-~ ................ ~--,~%i7~:~¢:?:.?:7":-?:?:;~.?'~;:~:'-~....:7:?:::;;;'"z:~::9:.i:;~:8'"~;?"77c7'"'7'"~ . . . _ ....., .... , ,.,.~1 1 ....2 I ,.~4 ~.~$: ... 7 . .......... I-..t.47-.6...-, .... ........ ~-~:-,--6.-.?.,., ............ ...... Z7 . ':~7_. * * .1 3 -~,. "44¢ 1 ~.'*. ~n.., 1 ,). ~. ,. 1 ~: · ~4_ 1 . 1 fi q . ~;. ............ 1-..I-..4.7 ~. ~..,.3 -,..~ P ~ ~. 7. 7 ~ ~. ":;' - ~. ~ 4 I 0.2 '.. · ~ · · .¢ .. · ........ .... ,' .. ~ . .. , . "~.-Sr',..., .......... 5..0-,.-6-2--. ?7.27 ~I.~ .. -6.34 10.~0 12.7~ · 1R.?~ 8.79 10.04 4.8:.2., ............... .... ~,...0...,...e..?z-~' ....... *~.7.'7~ ~1.1~. .... -6.~ 1O.~u' 1~.7~,_ ~1~.2~ 3 .4,:~ 1O.Oz ,. .......... D.RUDHO..~...E..a.¥ ............. NC~T~ SLCD: .............. ~':-~'t"~ ................. CN 6C T.-. .......... 6...~..~ .................. ~ TT t 14-a.,'.5 G '-r. ~ .~.~ *' .............. · ' ~ ................... I=.J . L.' i .~ .J " ~ ~ .m 0 ,, ""~'~ .... ~..t...,+-.9. u.. ..... n, ."" ....... t .t..-,~ 92.., ............. 0.~..-,3 O ......... O. gO / .~ / ,-,, ,.~ .) /'" .,-,. ......... t-1' ',*'","~. .................. g"~'u"~"~ ................ · ; "" / ............ tT'.ii'"G't;2- ........... t-"t-'~...7-c,.. .................. P-"'-. · -::'5'-0..' "' '~ t.:1 4--9..$.-. .................. n...i....R n ..... ¢, ~- ......... _ ~ ,, · .......... .~ ',"'u'O' ~-! . O:~ i ........ .1:'--1 .S'..'t.-G, ....................... O-'.i'~'O': 0 · OO ~ ~. 1 ~, ' I I ~1 2.' ~.,..-.mu ~.., ..... 0'. '30 ' ~,',:,. · -".':.. .......... 1---.t.5 t.z, .. ............. O'-',--Og- · '3. O0 84.33 .:- ........ t,-t--"'5-'-t- b', ................... G'~' a'(.'?'.' C · 'O 0 .~ 4 · ~ 1 .......... '-t.-.t.'-5.'1-...rs..... ............ 0.-','-~30. · C', -S. 3 ~ 4, ~- ,_'2 ..... .--...--1-.--1..F,-~.0.., ............. 0-.-,, .G..-C, .... 0 ~ 0 0 ,:~ 4.2 ~' · ' ............ -t...$..57~.-. .............. 0.,.,.3.3.. O..OC 8.4.28 ? ....... .t--.-t--¢-2-~-,,. ........................ O--,-g-8 ....0 · 3 ,.0 8'4.32' · :: .......... -t-I-:.-5-.?- 6.. ................ 0.., O.O. C · ~ O ' 77 . 27 0 u ~ & · 6 'J ......... · 1---1-,~ "' ....... '" "' r=5-'", ............................. ~'",'~"':/ ..... 0 · .......... 1...-.t.-.5-3 0..-.. ........ ' ............... g..-,----~..g .... C.. 0 '7! ~ 4. ~ O 0.00 . O.O ... , O.CO. ,,co ' ', uO u.,O0' ,,,0'."0,0 ..0.00 ,~ n ~ C · O0 . O0 O..~,.,.. '~ I '-I ,: O.,".CC. Q"..'~"'""":'"' .......... .,.,.,.....:o,~.~. · ,.,~',,'~,',,~'., ',",,:,,,,,, , ,,,,, ......... .~...:~..~ ~ i'.'n-e ........ < 1'~ 2.4~, 4.14 4,58 4 ·
