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
201-243
WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. cÞ/ gcf3well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or infonnation requests regarding this file. . RECEIVED STATE OF ALASKA MAY 0 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION C�GC WELL COMPLETION O ECOMPLETIO RE T AND LOG �./ C la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other Wbandoned lriuspended v` A lb. Well Class ✓ 20AAC 25.105 20AAC 25.110 Aa`" 0 Exploratory 0 Stratigraphic GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Com lets s Ze ®Development 0 Service 2. Operator Name: „ 5.Date Comp.,Susp.,or Aband.: V 12. Permit to Drill Number: r BP Exploration(Alaska) Inc. 4/12/2013 201-243 311-256 3. Address: 6.Date Spudded: ,i 13. API Number: v P.O. Box 196612,Anchorage,Alaska 99519-6612 1/31/2002 50-029-20433-02-00 4a. Location of Well(Governmental Section): 7.Date T.D. Reached: ✓ 14. Well Name and Number: / Surface: 2/8/2002 PBU 02-13B 4594' FSL,4407' FEL, Sec.36,T11 N, R14E, UM 8. KB(ft above MSL): 57.60' 15.Field/Pool(s) Top of Productive Horizon: 4220' FSL,2063' FEL, Sec. 36,T11 N, R14E, UM GL(ft above MSL): Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) ✓ 4511' FSL,3178' FEL, Sec. 36,T11 N, R14E, UM 2925' 2925' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) ,, 16. Property Designation: Surface: x- 687617 y- 5950516 Zone- ASP4 11000' 8986' ADL 028308 TPI: x- 689969 y- 5950201 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 688848 y- 5950464 Zone- ASP4 None 18. Directional Surve : 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): Y ❑Yes ®No N/A ft MSL 1900'(Approx.) (Submit electronic and printed information per 20 AAC 25.050) ( PP ) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD, GR, DEN, NEU, RES 9109' 8371' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT. PER FT. = GRADE ToP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 76' Surface 76' 30" ,431 sx Arcticset II 13-3/8" 72# L-80 Surface 2728' Surface 2728' , 17-1/2" ,2300 sx Fondu,400 sx PF II , 9-5/8" 40#/47# L-80 Surface 9109' Surface 8371' 12-1/4" 1335 sx Class'G', 828 sx Class'G' 2076' 4-1/2" 12.6# L-80 8903' 11000' 8189' 8986' 6-1/8" 310 sx Class'G' 24. Open to production or injection? 0 Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#, L-80 5430'-8912' 8855'/8147' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No DEPTH INTERVAL(MD)! AMOUNT AND KIND OF MATERIAL USED 1 NAY 2 2014 See Attached 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested. Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250 71. None RBDMS MAY - 9 201 29. GEOLOGIC MARKERS(List all formations and ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 9209' 8462' None 23SB/Zone 2B 9552' 8786' 22TS 9622' 8841' 21TS/Zone 2A 9689' 8887' Zone 1B 9843' 8960' Formation at Total Depth: 31.List of Attachment Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Rose,564-5271 Email: John.G.Rose@bp.com Printed Name: oe stufk Title: Drilling Technologist Signature. Phone 5644091 Date: 6/2-//3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only WELL NAME: 02-13B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8900' - 9951' 20 Bbls Class 'G' 6938' - 8441' 83 Bbls Class 'G' 5296' Set 9-5/8" EZSV 2946' Set 9-5/8" EZSV 2625' Set Whipstock 02-13B, Well History (Pre Rig Sidetrack) Date Summary 11/10/12 (Sidetrack) Heated 140 bbls of diesel to 70*on Ch2 transport for up coming job. 11/10/12 Perform Stage 1 of a 2 Stage Fullbore CMT P&A. Pumped 5 bbls Meth, 285 bbls 1% KCI, 10 bbls Chem Wash,20 bbls Class"G"CMT, 7 bbls Water, 1 bbl Meth, 127.3 bbls DSL. CIP @ 23:43 hrs. Calculated TOC in the TBG at 8900'. Job complete. 11/14/12 T/I/0=126/329/339.TEMP=S1 MITT to 3000 MIT IA to 3000 MIT OA to 2000 (Obj: RST Prep) MITT to 3000 psi. Failed.Tbg lost 25 psi in first 15 minutes&24 psi in second 15 minutes.Total loss=49 psi. Bleed tbg pressure down to 860 psi. MIT OA to 2000 psi. PASSED. OA lost 101 psi in first 15 minutes& 26 psi in second 15 minutes.Total loss= 127 psi. CMIT T x IA to 3000 psi. PASSED.T/IA lost 24/20 psi in first 15 minutes& 16/14 psi in second 15 minutes.Total loss=40/34 psi. Bleed tbg pressure down to 550 psi. MIT IA to 3000 psi. PASSED. IA lost 49 psi in first 15 minutes& 13 psi in second 15 minutes.Total loss=62 psi. Bleed IA pressure down to 450 psi. FWHP=550/450/230. Swab,wing, &SSV closed. Master, IA, &OA open. 11/17/12 (post-fullbore-p&a). RIG UP SWCP LL-11 TO DRIFT TO TD/PULL GLV. 11/18/12 (post-fullbore-p&a). BRUSH BPV PROFILE W/5-1/2" BRUSH. DRIFT W/2.85"CENT, 2.50"S. BAILER TO 8582'SLM. (rec. —3 cups cmt/pieces of orange wiper ball). 11/19/12 PULL RK-DGLV FROM ST#1 AT 8445'SLM/8441'MD. **ST#1 LEFT WITH OPEN POCKET PER PROGRAM**. ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS***. 11/20/12 T/I/0=480/500/220 Assist SLB pumpers(Obj: RST Prep) Pump down Tbg of 02-13 up the IA and slip- streaming returns into 02-33. Spear in Tbg with 5 bbls of meth then 130 bbls of 100* 1%KCL followed by 154 bbls of 70*diesel,then 163 bbls of 110* 1%KCL when the job scope changed due to leaking bonnet connection on WH just above SV. Pumped 60 bbls of 70*diesel down Tbg to FP Tbg and surface lines, then 19 bbls down IA to FP remaining surface lines(including hard line trailer and hard line to 02-33, LRS started to PT the P-sub for Rig Up Crew and the HP hose parted at the hose crimp,diesel spilled onto the pad. Informed SLB pumpers and Rig Up Crew about incident,then called dispatch to make the rest of the necessary calls. 11/20/12 T/I/O= SSV/400/200.Temp=SI.Assist Fullbore(RST Prep). No AL, no well house.Assisted Fullbore with OAP&cellar watch during cement pumping operations.Job shut down. See log for details. Final WHPs=SSV/859/100.23:45. 11/21/12 T/I/0=700/775/83 Assist SLB pumpers(Obj: RST Prep) Rig down from Hardline trailer. Secure incident area prior to departure FWHP=700/775/83 DSO notified at departure. 11/21/12 Heat diesel transport,rig up to upright tanks and reverse out skid low pressure test passed. 11/21/12 Perform Stage 2 of Stage 2 Fullbore CMT P&A. 11/22/12 T/I/0=139/350/62 Assist SLB on CMT P&A pumped 30 bbls neat down tbg followed by 130 bbls 1% kcl followed by 154 bbls dsl and 248 bbls kcl 1 bbl of neat to FP surface line. SLB to pump cement.After cement LRS pumped 65 bbls kcl,followed by 1 bbl neat methanol,followed by 37 bbls diesel for freeze protection. Pumped 5 bbls diesel to freeze protect surface lines going to 02-33 flowline. FWHP=0/1036/185. Page 1 of 3 02-13B, Well History (Pre Rig Sidetrack) Date Summary 11/22/12 T/I/O= 130/400/60 Temp=SI.Assist Fullbore(RST Prep). No AL, no well house. IAP decreased 459 psi and OAP decreased 50 psi overnight.Assisted Fullbore with OAP&cellar watch during cement pumping operations. Monitored 1 hr. Final WHPs SSV/870/50.Job complete. SV,WV, SSV=C. MV=0. IA, OA= OTG. 1100. 11/22/12 Perform Stage 2 of Stage 2 Fullbore CMT P&A. SLB Pumped 5 bbls FW,83 bbls Class"G" 15.8 ppg with no aggregate,2 bbls FW, opened ball launcher then 5 bbls FW. LRS pumped pre/post cement stages, see LRS WSR. Tree valves serviced post job. 11/23/12 T/I/O = SSV/0/30.Temp= SI. Monitor WHPs(Post RST Prep). No AL, no well house. IAP decreased 870 psi and OAP decreased 20 psi overnight.Job complete. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP 04:00 Hrs. 12/02/12 DRIFTED W/3.70"CENTRALIZER&2.5"SAMLE BAILER TO TOC AT 6925' SLM (no sample) DRIFTED WITH 2.50"SAMPLE BAILER&TAGGED CEMENT AT 6938' SLM (recovered a sample of cement). RAN 5-1/2"BLB AND BRUSHED TREE& BPV PROFILE, DRIFTED THE BPV PROFILE W/ 5.06"DRIFT. 12/04/12 ( ELINE-TUBING CUT). INITIAL T/I/O 250/0/0. RIH W/3.65" O.D. JET CUTTER&CUT TBG @ 5430' (4 FT BELOW COLLAR AT 5426 FT). TIED INTO TBG TALLY(GLM#3). FINAL T/I/O 50/50/0 WELL LEFT SI-DSO NOTIFIED OF WELL STATUS. 12/23/12 T/I/0=41/2/45 Temp=S/I CMIT-TxIA to 3000 PSI PASSED (RST prep) Pumped 8.75 bbls AMB diesel to test. 1st 15 min TxIA lost 59/65&2nd 15 min TxIA lost 25/25 for a total TxIA loss of 84/90 in 30 min. Bled back—8 bbls. FWHP's=45/0/44 DSO notified on departure SWV,SSV=S/I IAV,OAV=OTG. 03/11/13 T/I/O=ONac/50.Temp= SI. Bleed WHP to 0(Pre-CTD). No AL. OA FL near surface. Bled OAP from 50 to 0 in .2.5 hrs(see log). Final WHPs 0/vac/0. SV&WV=C. SSV&MV=0. IA&A=OTG. NOVP. 04:50. 03/14/13 T/I/O=42Nac/7.Temp=SI.WHPs. (Pre CTD). No AL.Tubing pressure increased 42 psi&OAP increased 7 psi since 03-11-13 bleed. SV, WV=C. SSV, MV=0. IA&OA=OTG. 09:20. 03/16/13 T/I/O=0/0/0 Temp=Sl. PPPOT-T(PASS), PPPOT-IC (PASS). Pre RST. PPPOT-T: Stung into test port(0 psi). Functioned LDS, all moved freely(1"). Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Hoke valve installed in test port. Stung into test port(0 psi), Functioned LDS, all moved freely (1"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi 30 min (PASS). Bled void to 0 psi. 03/20/13 T/I/0=150/0/0. Conducted PJSM. Barriers=MV, SSV. Start barriers list. Performed LTT on MV and SSV independently for 5 min. prior to removal of tree cap(passed). RU lubricator with 5"Gray K BPV#606. PT'd lubricator to 300 psi. low and 3500 psi. high for 5 min. (passed). Set BPV tagging at 127". Bled tree to 0 psi. and performed LTI on BPV(passed). RD lubricator. Performed LTT on IA, OA valves for 5 min. prior to removal of tapped blind flanges(passed). Removed tapped flange on both IA and OA valves and installed Piggy back valves and tapped flanges.Torqued to API specs(1-1/8" L7M 523 ft. lbs). Pt'd both IA and OA Piggy back valves through tapped flanges using original IA,OA valves as barriers to 300 psi and 3500 psi. independently for 5 min (passed). charted and documented. RDMO. Page 2 of 3 02-13B, Well History (Pre Rig Sidetrack) Date Summary 03/23/13 T/I/O =0/0/0. Conducted PJSM. Barriers= BPV&MV. Varrified by performing independent LTI (Passed). Evacuated fluid from upper tree, N/D 5-1/8"x 7- 1/16"Gray upper tree&N/U 5-1/8"x 7-1/16"HWO FMC Mod. 120 SV to MV(Dryhole conversion).Torqued MVx SV to API spec(1281 ft-lb, L7 non coated). Pressure tested against MV 200-300 psi low&5000 psi high for 5 minutes each (Passed). Charted and stored in TRP folder. 03/23/13 T/I/O-14/29/0 Assist Valve Crew, PT BPV to 2000 passed lost 19 psi in 5 min bleed pressure off well rig down (swab closed,wing closedf,ssv open master open annulus valves open to gauges) FWHP=13/3/0. 03/24/13 T/I/O = BPV/20/10.Temp= SI.WHPs(secure). No AL.Wellhouse removed. No WV or SSV. SV, MV=C. IA, OA=OTG. NOVP. 1600. Page 3 of 3 • North America-ALASKA-BP Page 1.otQ5- Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/27/2013 00:00 - 07:00 7.00 RIGU P DECOMP BEGIN PARKER 273 RIG OPERATIONS AT 00:00 ON 3/27/2013. PREP MUD MOD AND DRILL MOD FOR SEPERATION.ROTATE TIRES TO WARM FLUID IN MOVING SYSTEM.ORIENT TIRES ON MUD MODULE AND BEGIN TRAVEL DOWN THE WELL ROW.SPOT MATTING AND HERCULITE FROM UNDER MUD MODULE IN PLACE AROUND 2-13C WELL HEAD.FINISH PREP FOR SEPERATION BETWEEN UTILITY MOD AND DRILL MOD.PULL UTILITY MOD AWAY FROM DRILL MOD.BEGIN WARMING UP FLUID IN TRAVELING SYSTEM ON DRILL MOD. 07:00 - 14:00 7.00 RIGU P DECOMP STAGE MATS FOR SPOTTING DRILL MOD ON 02-13C.BEGIN MOVING DRILL MOD DOWN WELL ROW.SPOT MATS FOR DRILL MOD AROUN 02-13C.PULL DUMMY WELLHOUSE FROM 02-15B AND PREP AREA AROUND 02-13C WELL HEAD FOR DUMMY WELLHOUSE INSTALLATION.SET DUMMY WELLHOUSE IN PLACE. 14:00 - 22:00 8.00 RIGU P DECOMP MOVE AND SPOT DRILL MOD OVER 02-13C. MOVE AND SPOT UTILITY MOD OVER 02-13C, ALIGN MUD MOD AND UTILITY MOD TO DRILL MOD. •.RIG ON LOCATION WITH FIRST MODULE IN PLACE. DRILL MOD SPOTTED AT 14:00 ON 3/27/2013"' 22:00 - 00:00 2.00 RIGU P DECOMP SHIM THE MODULES AS REQUIRED.BEGIN TO HOOK UP INTERCONNECTS ON MODULES. 3/28/2013 00:00 - 03:00 3.00 RIGU P DECOMP PJSM,CONNECT ELECTRICAL AND SERVICE LINES FROM UTILITY TO DRILL MODULE/ DRILL MODULE TO MUD MODULE,PREP DRAW WORKS,HYDRAULICS AND POWER SYSTEMS FOR RAISING MAST,PREFORM PRE-RAISE DERRICK INSPECTION. 03:00 - 04:30 1.50 RIGU P DECOMP PJSM,RAISE MAST,510K OFF STAND,SKID FLOOR OUT OVER WELL HOUSE,RAISE PIPE SKATE RAMP,SKID HAUNCH INTO POSITION 04:30 - 09:00 4.50 RIGU P DECOMP R/U FLOOR EQUIPMENT,MANRIDERS, PRERPAIR TO BRIDLE DOWN AND PIN BLOCKS TO TOPDRIVE,HOOK UP KELLY HOSE,CONT TO RIG UP SERVICE LINE BETWEEN MODULES. 09:00 - 12:00 3.00 RIGU P DECOMP PJSM.BRIDLE DOWN RASING LINES AND PIN BLOCKS TO TOPDRIVE,M/U LINES AND VALVES TO I.AAND O.A F/DECOMPLETE 12:00 - 12:30 0.50 RIGU P DECOMP PRE-SPUD MEETING WITH BOTH RIG CREWS. 12:30 - 15:30 3.00 RIGU P DECOMP COMPLETE RIG UP OF LINES AND VALVES TO TEST I.A,OA F/DECMPLETE 15:30 - 16:30 1.00 RIGU P ! DECOMP PERFORM A FIRE DRILU RIG EVAC DRILL, HOLD AAR WITH ALL HANDS AFTER DRILL Printed 4/22/2013 10:50:31 AM • North America-ALASKA-BP Page 2steg,5, Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 I End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 21:30 5.00 WHSUB P DECOMP TEST ALL SURFACE LINES TO I.A,O.A,TEST I.A WITH SEA WATER TO 250 LOW/5MIN,3000 HIGH/30 MIN,CHART SAME,TEST THE O.A WITH DIESEL TO 250 LOW,2000 HIGH/30 MIN, PSI COMMUNICATION BETWEEN O.AAND I.A., RAN COMBO MIT TEST ON O.A TO 2000 AND IA TO 3000 TEST GOOD,SIMOPS,PICK UP 4" DP AND STAND BACK IN DERRICK (RIG ACCEPTED @1600 HRS) 21:30 22:00 0.50 WHSUB P DECOMP R/D,B/D ALL LINES USED FOR TEST, PREPAIR TO NIPPLE DN TREE. SIMOPS,PICK UP 4"DP AND STAND BACK IN DERRICK 22:00 - 00:00 2.00 WHSUB P DECOMP SUCK OUT TREE,NIPPLE DN DRY HOLE TREE ,NIPPLE DN ADAPTER AND LAY DN. SIMOPS, PICK UP 4"DP AND STAND BACK IN DERRICK 3/29/2013 1 W 00:00 - 02:00 2.00 + WHSUR P DECOMP PULL ROTARY BUSHINGS IN PREP FOR LOWERING RISER.PICK UP RISER SPOOL OUT OF PIPE SHED TO RIG FLOOR.REMOVE 2'SPOOL AND MAKE UP 29.5"SPOOL IN PREP TO NIPPLE UP BOPE.UTILIZING OFFLINE I STAND BUILDING SYSTEM TO MAKE UP 4" DP. 02:00 - 02:30 0.50 WHSUR P DECOMP ;HELD FIRE AND RIG EVAC DRILL WITH CREW AND PERSONAL 02:30 - 06:00 ' 3.50 WHSUR P DECOMP NIPPLE UP RISER SPOOLAND BOP,SIMOPS, PICK UP 4"DP AND STAND BACK IN DERRICK OBTAIN AND CONFIRM RKB MEASUREMENTS FROM BOPE STACK 06:00 - 08:00 2.00 WHSUR P DECOMP RIG UP TO TEST BOPE,MAKE UP TEST ASSEMBLIES,INSPECT TEST EQUIPMENT. 08:00 - 09:30 1.50 WHSUR P DECOMP PICKUP 4"TEST JOINT,AND MAKE UP 5.875" ACME XO TO TEST JOINT.RUN IN HOLE AND ATTEMPT TO MAKE UP 5.875"ACME XO TO TUBING HANGER,DART OD TOO LARGE FOR XO ID. 09:30 - 11:00 1.50 WHSUR N WSEQ 0.71 DECOMP RECEIVE FLUID IN PITS AND USE TO CALIBRATE AND FUNCTION TEST HIGH LEVEL ALARMS.MAKE UP T-BAR,RUN IN HOLE AND ATTEMPT TO PULL THE TEST DART,SET SCREWS ON THE TEST DART SHEAR. 11:00 - 12:00 1.00 WHSUR N WSEQ 0.71 1 DECOMP 1 PJSM,PULL FLOW RISER FROM ROTARY, BREAK BOLTS ON TUBING SPOOLAND RISER SPOOL TO RAISE BOP STACK AND RETREIVE TEST DART LEFT IN BPV. 12:00 - 16:00 4.00 WHSUR N WSEQ 0.71 DECOMP INSTALL NEW DART,ENSURE 5.875"ACME XO BOX FITS OVER DART ASSEMBLY,NIPPLE UP BOP AND FLOW RISER,PICK UP 4"TEST TOOLS AND MAKE UP TO TOP OF TUBING HANGER,FILL STACK/ALL LINES AND BLEED ANY AIR. 16:00 - 17:00 1.00 BOPSUR P DECOMP PERFORM BODY TEST ON STACK FOUND LEAK THROUGH THE LOWER RAM DOOR SEALS,BLEED PRESSURE AND OPEN ANNULAR. 17:00 - 20:00 3.00 BOPSUR P DECOMP SUCK OUT STACK FROM ABOVE,OPEN LOWER RAM DOORS,CLEAN,INSPECT,AND CHANGE OUT DOOR SEALS,CLOSE LOWER RAM DOORS,FILL STACK AND BLEED AIR. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 3 Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:30 1.50 BOPSUR P DECOMP PERFORM SECOND BODY TEST ON BOP AND CHOKE MANIFOLD,FOUND LEAK @ CHOKE FLANGE,TIGHTEN FLANGE AND CHECK OTHER FLANGES ON MANIFOLD. 21:30 - 00:00 2.50 BOPSUR P DECOMP FUNCTION TEST BOPE AND WORK AIR OUT OF BOP AND MANIFOLD.TEST BOP WITH 4" TEST JOINT.ALL TESTS 250PSI LOW AND 3500PSI HIGH FOR 5MIN. 3/30/2013 00:00 - 04:30 4.50 BOPSUR P DECOMP CONTINUE/COMPLETE TESTING BOPE, 250PSI LOW,3500PSI HIGH,5 MIN CHART ATTACHED. 04:30 - 09:00 4.50 WHSUR P DECOMP RIG UP DUTCH RISER SYSTEM,LUBRICATOR W/QUICK TEST SUB TO PULL BPV,CONT BUILDING STANDS OFFLINE 09:00 - 12:00 3.00 WHSUR P DECOMP TEST LUBRICATOR AND DUTCH RISER TO 250PSI LOW 3500PSI HIGH 5MIN.PICK UP T BAR,SEPERATE LUBRICATOR AT QUICK TEST SUB AND PULL TEST DART.MAKE UP LUBRICATOR EXTENSIONS AND LUBRICATE OUT BPV.NO PRESSURE SEEN BELOW BPV. MONITORING OA PRESSURE=0 PSI 12:00 - 13:30 1.50 WHSUR P DECOMP RIG DOWN LUBRICATOR AND DUTCH RISER .ASSMBLY AND LAY DOWN. 13:30 - 16:30 3.00 WHSUR P DECOMP REVERSE CIRCULATE 4OBBLS OF 140DEG SEA WATER©5BPM 1000PSI,CIRCULATE LONG WAY 486BBLS OF SEA WATER/PUMP SAFE-SURF-O-SWEEP @ 7BPM 1360PSI. 16:30 - 17:30 1.00 WHSUR P DECOMP MONITOR WELL,BREAK DOWN AND RIG DOWN ALL CIRCULATING LINES,DRAIN STACK. 17:30 - 19:00 1.50 FISH P DECOMP MAKE UP SPEAR ASSEMBLY,RIH TO 45.5', STACK 11K DOWN WEIGHT,PICK UP AND WORK 4X,TRIED TO HAND UP,16K OVER PULL,WORK 2X,PICK UP TO RIG FLOOR TO INSPECT,1/2 LOWER GRAPPLE MISSING AT SURFACE.FISH COULD BE SEEN VISUALLY ON TOP OF HANGER.WAIT ON MAGNET TO FISH WITH. 19:00 - 21:00 2.00 FISH N DFAL 0.71 DECOMP MAKE UP MAGNET FISHING ASSEMBLY,RUN IN HOLE AND RETRIEVE FISH.RUN IN HOLE WITH DRIFT ASSEMBLY TO DETERMINE ID OF CROSSOVER ON TUBING HANGER,PULL DRIFT OUT OF HOLE AND LAY DOWN. (ROUSTABOUT NOTICED LEAK FROM HARDLINE MADE UP TO TIGER TANK, REPORTED TO SRT,FLUID CLEANED UP AND DISPOSED TRACTION#2013-IR-4388091) 21:00 - 23:00 2.00 FISH N DFAL 0.71 DECOMP SEND SPEAR ASSEMBLY BACK TO BAKER TO REDRESS WITH NEW SIZED GRAPPLES.DSM ON LOCATION TO RE-TORQUE HARDLINE CONNECTIONS AND RE-PRESSURE TEST. 23:00 - 00:00 1.00 PULL P DECOMP MAKE UP NEW SPEAR ASSEMBLY,RUN IN HOLE AND ENGAGE SPEAR 41250',PICK UP 20K OVER TO VERIFY LATCH,BACK OUT LOCK DOWNS,CLEAR THE FLOOR,UNSEAT HANGER ON FIRST ATTEMPT @ 100K PICK UP WEIGHT. 3/31/2013 00:00 - 01:00 1.00 PULL P DECOMP PJSM,B/O HANGER AND SPEAR ASSEMBLY, RACK BACK 1 STAND OF DP,MONITOR WELL 10 MIN=STATIC Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 4 045-- Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 ' Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 09:00 8.00 PULL P DECOMP LAY DN 4.5 TUBING,LAY DN TOTAL OF 130 JTS,6 PUPS,1 GLM,1 CUT JOINT 4.3'LONG, MONITOR WELL 10 MIN TT=STATIC, 09:00 - 09:30 0.50 PULL P DECOMP RIG SERVICE 09:30 - 11:00 1.50 PULL P DECOMP R/D TUBING HANDLING EQUIPMENT,CLEAR AND CLEAN FLOOR,R/U BX ELEVATORS FOR T/5",PS-21 XOS TO PICK UP 8.5 CASING SCRAPER BHA. 11:00 - 12:00 1.00 PULL P DECOMP P/U 8.5 CASING SCRAPER TOOLS WITH TOOL CRANE AND STAGE ON RIG FLOOR 12:00 - 14:30 2.50 PULL P DECOMP PJSM,INSTALL WEAR BUSHING, P/U AND M/U CASING SCRAPER BHAAS PER BAKER 14:30 - 17:00 2.50 PULL P DECOMP P/U AND M/U 3 STDS 6-1/2 DC AND 6 STDS 5" HWDP 17:00 - 00:00 7.00 PULL P DECOMP C/O MASTER BUSHINGS TO PS-21,P/U 4"DP FROM PIPE SHED F/888 MD TO 5430 MD 4/1/2013 00:00 - 02:00 2.00 PULL P DECOMP P/U 4.5 DP,TAG TOP OF TUBING @ 5465 MD 02:00 - 03:00 1.00 PULL P DECOMP PUMP SWEEP,9.8 PPG SALT PILL,57 BBLS DP CAP 03:00 - 03:30 0.50 PULL P DECOMP STOP CIRC FOR 1/2 HR TO LET SALT SETTLE DOWN HOLE 03:30 - 04:00 0.50 PULL P DECOMP CIRC BOTTOMS 9.7+TO 9.8 PPG RETURN MUD WT 04:00 - 04:30 0.50 PULL P DECOMP STOP CIRC FOR 1/2 HR FOR FLUID TRANSITION 04:30 - 06:00 1.50 PULL P DECOMP CIRC BOTTOMS UP AND RUN CHECK ON SLB EQUIPMENT. 06:00 - 09:00 3.00 PULL P DECOMP TOH TO LOG,F/5465 MD TO 888 MD,MONITOR WELL VIA TT FOR 10 MIN=STATIC 09:00 - 10:30 1.50 PULL P DECOMP CHANGE OUT PS-21 FOR MASTER BUSHING, CHANGE INSERTS IN ELEVATORS,B/O X-OVER SUB,TOH F/888 MD TO SURFACE 10:30 - 12:00 1.50 PULL P DECOMP LAY DN CLEAN OUT BHA,CLEAN AND CLEAR FLOOR 12:00 - 14:30 2.50 PULL P DECOMP PJSM W/SLB E-LINE CREW,P/U AND R/U TOOLS FOR USIT LOG RUN.WELL CONTROL DRILL CRT 3 MIN 10 SEC.AAR AND TABLE TOP DRILL FOR WELL KILL W/BLINDS CLOSED 14:30 - 20:30 6.00 PULL P DECOMP RIH W/USIT LOG,LOG F/5400'MD TO SURFACE,MONITOR WELL VIA TRIP TANK=STATIC SIMOPS-BUILD STANDS DP _ OFF-LINE 20:30 - 23:30 3.00 PULL P DECOMP RIH W/USIT LOG FOR 2ND RUN F/5400"MD TO 4500"MD,POH WITH LOG FROM 4500"MD TO SURFACE,MONITOR WELL VIA TRIP TANK=STATIC,SIMOPS-BUILD STANDS DP OFF-LINE 23:30 - 00:00 0.50 PULL P DECOMP R/D USIT LOG,CLEAR FLOOR OF USIT LOG TOOLS,MONITOR WELL VIA TT=STATIC 4/2/2013 00:00 - 01:30 1.50 STWHIP P DECOMP MAKEUP E-LINE TOOLS FOR EZSV Printed 4/22/2013 10 50:31AM • North America-ALASKA-BP Page 5 Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: IX3-010G8-C:(12,228,000.00) Project:Prudhoe Bay 'Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 04:00 2.50 STWHIP N DFAL 5,465.71 DECOMP TROUBLESHOOT E-LINE ISSUES. -INITIAL HOT CHECK OF TOOLS PASSES BUT TOOLS STOP WORKING 10 MINUTES LATER. DISCOVER OPEN LINE IN E-LINE HEAD. REPAIR HEAD AND RE-CHECK TOOLS(PASS). -RIG CREW CONTINUING TO BUILD 4" DRILLPIPE STANDS WITH OFFLINE STAND BUILDER 04:00 - 05:00 1.00 STWHIP P DECOMP PRE-JOB MEETING WITH RIG TEAM. ARM PLUG. 05:00 - 09:30 4.50 STWHIP P DECOMP RUN IN HOLE WITH HES 9-5/8"EZ DRILL SVB SQUEEZE PACKER(EZSV)+GR/CCL,BHA OAL=20.8'. CORRELATE AND CONFIRM DEPTHS. SET EZSV WITH MIDDLE OF ELEMENT AT 5298'MD. PULL OUT OF HOLE AND CONFIRM PLUG SETTING TOOLS HAVE FIRED. WELLSITE GEOLOGIST CONFIRMS COMPETENT SAND AT SIDETRACK DEPTH. WELLBORE INCLINATION=33°. EXPECTED WINDOW DEPTH=2077'MD TO 5294'MD,CEMENT IS EXPECTED BEHIND 9-5/8"CASING 09:30 - 10:00 0.50 STWHIP P DECOMP RDMO SCHLUMBERGER E-LINE UNIT 2128. 10:00 - 00:00 14.00 STWHIP N WAIT 5,298.71 DECOMP HSE STAND DOWN(IN CONJUNCTION WITH PARKER RIG 272 STAND DOWN) -REVIEW RIG INCIDENTS,COVERING FIRST THREE MONTHS OF OPERATIONS. PRIMARILY FOCUS ON DROPPED OBJECT AND LEAK INCIDENTS. -DEVELOP ACTION PLANS TO IMPROVE FUTURE OPERATIONAL PRACTICES, CONTROL OF WORK,RISK ASSESSMENTS -MONITOR WELL WITH CONTINUOUS CIRCULATION OVER THE TOP AND INTERMITTENT PUMPS OFF FLOW CHECKS (STATIC 9.8 PPG BRINE KWF COLUMN) 4/3/2013 00:00 - 00:00 24.00 STWHIP N WAIT 5,298.71 DECOMP HSE STAND DOWN(IN CONJUNCTION WITH PARKER RIG 272 STAND DOWN) REVIEW RIG INCIDENTS,COVERING FIRST THREE MONTHS OF OPERATIONS. PRIMARILY FOCUS ON DROPPED OBJECT AND LEAK INCIDENTS. -DEVELOP ACTION PLANS TO IMPROVE FUTURE OPERATIONAL PRACTICES, CONTROL OF WORK,RISK ASSESSMENTS -SHUT BLIND RAMS AND MONITOR WELL FOR PRESSURE AT CHOKE(NO PRESSURE/FLOW,STATIC 9.8 PPG BRINE KWF COLUMN) -HOLD KICK WHILE TRIPPING(D1)DRILL AND AFTER ACTION REVIEW WITH RIG CREW. -PARKER 272 AND 273 RIGS CREWS HOLD CONFERENCE CALL TO DISCUSS JOINT PLANS. -WELD ON BOILER EXHAUST LINE CAPS TO BETTER SECURE AND ELIMINATE FUTURE 1 HAZARDS(4/2/13 DROPPED OBJECT) Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 6.,21.,5 Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) 1 Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 I Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 4/4/2013 I 00:00 - 19:00 19.00 STWHIP N WAIT 0.71 DECOMP HSE STAND DOWN(IN CONJUNCTION WITH PARKER RIG 272 STAND DOWN) -REVIEW RIG INCIDENTS,COVERING FIRST THREE MONTHS OF OPERATIONS. PRIMARILY FOCUS ON DROPPED OBJECT AND LEAK INCIDENTS. -DEVELOP ACTION PLANS TO IMPROVE FUTURE OPERATIONAL PRACTICES, CONTROL OF WORK,RISK ASSESSMENTS -SHUT BLIND RAMS AND MONITOR WELL FOR PRESSURE AT CHOKE(NO PRESSURE/FLOW,STATIC 9.8 PPG BRINE KWF COLUMN) -PARKER 272 AND 273 RIGS CREWS HOLD CONFERENCE CALL TO DISCUSS JOINT PLANS. 17:00-BEGIN RIG WALKAROUNDS AND EQUIPMENT CHECKS AS PART OF RIG STARTUP PLAN. CONFIRM CLEAR HARDLINE TO RETURNS TANK. 19:00 - 21:00 2.00 CUT P DECOMP RESUME OPERATIONS AFTER HSE STAND DOWN. LOAD TOOLS TO RIG FLOOR. OPEN BLINDS AND MONITOR WELL WITH CONTINUOUS HOLE FILL(STATIC). HOLD PJSM FOR MAKING UP BHA WITH NON-SHEARABLES. 21:00 - 23:00 2.00 CUT P DECOMP MAKEUP AND RUN IN HOLE WITH 8-1/4" MULTI-STRING CUTTER ASSEMBLY FROM SURFACE TO BHA OALAT 855'MD. BHA WEIGHT IN 9.8 PPG BRINE=85 KLBS. -8-1/4"BAKER MULTI-STRING CUTTER, CUTTERS SECURED WITH WIRE AND TAPE 8-1/2"STABILIZER,(3)STANDS 6-1/2"DRILL COLLARS AND(6)STANDS 5"HWDP 23:00 - 00:00 1.00 CUT P DECOMP RUN IN HOLE WITH 8-1/4"MULTI-STRING CUTTER ASSEMBLY FROM BHA AT 855'MD T02120'MD AT MIDNIGHT. 4/5/2013 00:00 - 02:30 2.50 CUT P DECOMP HOLD RETURN TO WORK MEETING WITH LINDSTROM RIG CREW. HOLD PJSM FOR CUTTING 9-5/8"CASING AND ARCTIC PACK DISPLACEMENT. 02:30 - 04:00 1.50 CUT P DECOMP CUT 9-5/8",47#,L-80 ORIGINAL PRODUCTION CASING AT 2076'MD/TVD,ESTIMATE 10' BELOW COLLAR. -LOCATE COLLARS AT 2141'MD AND 2107'MD -80 RPM,2-6 KFT-LBS TORQUE,230 GPM,740 PSI,ROTATING WEIGHT=97 KLBS. 'OBSERVE-200 PSI PRESSURE DROP AND CONTINUE ROTATING FOR ADDITIONAL 7 • MINUTES TO ENSURE COMPLETE CUT.. FINAL OA PRESSURE=275 PSI. -POSITIVE INDICATION OF CUT CONFIRMED BY(1)TAGGING CUT WITH CUTTER BLADES OPEN,(2)OBSERVING PRESSURE DROP WHEN SLACKING OFF PAST CUT DEPTH,(3) TAGGING CUT WITH BOTTOM OF CUTTER 1 TOOL. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 7 of5 Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 09:30 5.50 CUT P DECOMP DISPLACE OA FROM ARCTIC PACK TO 9.8 PPG BRINE AS FOLLOWS: -PUMP 22 BBLS(DRILLSTRING VOLUME) 6.8 PPG 95°F DIESEL TO CUTTER,2.3 BPM,100 PSI. SHUT IN ANNULAR PREVENTER. -PUMP 28 BBLS 6.8 PPG 95°F DIESEL(FOR TOTAL VOLUME OF 50 BBLS),2.3 BPM,50-600 PSI. CHASE WITH 22 BBLS 9.8 PPG 120°F BRINE. SHUT DOWN PUMPS AND ALLOW DIESEL TO SOAK IN ANNULUS FOR ONE HOUR. PUMP 2 BBLS 9.8 PG BRINE EVERY 15 MINUTES TO MOVE FLUID. -PUMP 120 BBLS 9.8 PPG 120°F BRINE TO GET BRINE BACK TO SURFACE,85 GPM, 200-390 PSI,1 DRUM DEEP CLEAN ADDED THROUGH CHEMICAL INJECTION LINE IN FIRST 10 BBLS. -PUMP 142 BBLS(SURF TO SURF VOL)9.8 PPG 120°F BRINE,254 GPM,1540 PSI. OPEN ANNULAR PREVENTER. -CIRCULATE ONE BOTTOMS UP IN 9-5/8"X 4" DRILLPIPE ANNULUS,254 GPM,750 PSI (DUMP-100 BBLS OF DIESEL CONTAMINATED FLUID FROM MIGRATION OVERBOARD). -MONITOR WELL FOR 10 MINUTES(STATIC). HOLD MAN DOWN DRILL WITH AFTER ACTION REVIEW DURING 1 HOUR DIESEL SOAKING PERIOD. 09:30 - 10:30 1.00 CUT P DECOMP PULL OUT OF HOLE WITH 8-1/4" MULTI-STRING CUTTER ASSEMBLY FROM CUT DEPTH AT 2076'MD TO BHAAT 855'MD. MONITOR WELL PRIOR TO PULLING BHA INTO BOP STACK(STATIC). 10:30 - 12:00 1.50 CUT P DECOMP RACK BACK 3 STANDS 6-1/2"SPIRAL DRILL COLLARS AND 6 STANDS 5"HWDP. LAYDOWN 8-1/4"MECHANICAL CUTTER TOOLS. 12:00 - 14:00 2.00 BOPSUR P DECOMP RIG DOWN CIRCULATING EQUIPMENT IN WELLHOUSE. CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING. PULL WEAR BUSHING. 14:00 - 16:30 2.50 BOPSUR P DECOMP DRAIN BOP STACK,CLOSE BLIND RAMS AND DE-ENERGIZE ACCUMULATOR. CHANGEOUT UPPER RAMS FROM 2-7/8"X 5-1/2"VBRS TO 9-5/8"SOLID BODY RAMS. RIG UP TESTING EQUIPMENT. OPEN BLIND RAMS. RUN IN HOLE WITH 9-5/8"TEST JOINT AND TEST PLUG. BARRIERS FOR RAM CHANGEOUT: -TESTED CEMENT PLUG,KILL WEIGHT FLUID,CLOSED BLIND RAMS 16:30 - 17:00 0.50 BOPSUR P DECOMP PRESSURE TEST 9-5/8"UPPER RAMS TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TEST,SEE ATTACHED CHART). 17:00 - 17:30 0.50 BOPSUR P DECOMP PULL TEST JOINT AND LAYDOWN. RIG DOWN TESTING EQUIPMENT. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 8.o0Q;L Operation Summary Report Common Well Name:02-13 ,AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 18:30 1.00 CUT P DECOMP LOAD TOOLS TO RIG FLOOR AND MAKEUP BAKER 9-5/8"ITCO SPEAR ASSEMBLY. BHA OAL=16' -9-5/8"SPEAR PACK-OFF, 8-1/4"BOWN ITCO SPEAR WITH 9-5/8"GRAPPLE,SPEAR EXTENSION AND STOP SUB. 18:30 - 19:30 1.00 CUT P DECOMP RUN IN HOLE WITH BAKER 9-5/8"ITCO SPEAR ASSEMBLY FROM SURFACE TO ENGAGE 9-5/8"CASING AT-50'MD(5'BELOW HANGER). CAMERON REPS ON LOCATION TO BACKOUT CASING HEAD LOCKDOWN SCREWS(APPLIED STEAM TO LDS FOR SEVERAL HOURS PRIOR). 19:30 - 19:45 0.25 CUT P DECOMP PICKUP TO 198 KLBS TO UNSEAT HANGER (80 KLBS OVER CALCULATED 118 KLBS STRING WEIGHT). PULL OUT OF HOLE FROM CUT DEPTH AT 2076'MD TO 2026'WITH RECOVERED 9-5/8"CASING(HANGER AT RIG FLOOR). PICKUP WEIGHT=120 KLBS. 19:45 - 21:00 1.25 CUT P DECOMP RELEASE BAKER ITCO SPEAR ASSEMBLY AND LAYDOWN. RIG UP DOYON CASING HANDLING EQUIPMENT AND PS-21 SLIPS. HOLD PJSM FOR LAYING DOWN CASING. 21:00 - 21:30 0.50 CUT P DECOMP CIRCULATE ONE BOTTOMS UP(120 BBLS); 508 GPM,460 PSI,DUMPING-50%RETURNS OUT TO CUTTINGS BOX. FLOWCHECK WELL (STATIC). 21:30 - 00:00 2.50 CUT .... P DECOMP LAYDOWN 9-5/8",47#,L-80 ORIGINAL PRODUCTION CASING FROM CUT DEPTH AT 2076'MD.TO 956'MD AT MIDNIGHT. 4/6/2013 00:00 - 00:30 0.50 CUT P DECOMP SERVICE RIG FLOOR AND PIPE BARN EQUIPMENT. 00:30 - 03:00 2.50 CUT P DECOMP LAYDOWN 9-5/8",47#,L-80 ORIGINAL PRODUCTION CASING FROM CUT DEPTH AT 956'MD.AT MIDNIGHT TO SURFACE. -(1)GRAY CSG HGR W/5'PUP JT,51 FULL JOINTS,1 CUT JOINT,8 BOW-SPRING CENTRALIZERS(EXPECTED 13),NO STOP RINGS,AVERAGE BREAKOUT TORQUE=3 KFT-LBS -CUT JOINT LENGTH=9-1/2'(AS EXPECTED), FLARE OD=10-5/8",FLARE DAMAGE IS INDICATION OF CASING FALLING DOWN _ OVER ITSELF AFTER BEING CUT. 03:00 - 04:30 1.50 CUT P DECOMP RIG DOWN CASING HANDLING EQUIPMENT. CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING. 04:30 - 08:00 3.50 BOPSUR P DECOMP CLEANOUT BOP STACK WITH PORTED BULLNOSE SUB. DRAIN BOP STACK,CLOSE BLIND RAMS AND DE-ENERGIZE ACCUMULATOR. CHANGEOUT UPPER RAMS FROM 9-5/8"TO 2-7/8"X 5-1/2"VARIABLE BORE RAMS. RIG UP TESTING EQUIPMENT. BARRIERS FOR RAM CHANGEOUT: -TESTED CEMENT PLUG,KILL WEIGHT FLUID,CLOSED BLIND RAMS 08:00 - 09:00 1.00 BOPSUR P DECOMP HOLD RIG EVACUATION AND H2S DRILL, FOLLOWED BY AFTER ACTION REVIEW WITH ENTIRE RIG TEAM. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 9 saas. Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:30 1.50 BOPSUR P DECOMP COMPLETE RIGGING UP FOR BOPE TEST. OPEN BLIND RAMS. RUN IN HOLE WITH 4" TEST JOINT AND TEST PLUG. 10:30 - 15:00 4.50 BOPSUR P DECOMP PRESSURE-FUNCTION TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH WITH 4"TEST JOINT PER AKDWOP STANDARDS AND AOGCC REGULATIONS. JEFF JONES,AOGCC REPRESENTATIVE, WAIVES STATE'S RIGHT TO WITNESS TEST. ,-ALL BOPE TEST CHARTS AND REPORT ARE ATTACHED. -(2)HT38 FOSVS,(1)4-1/2"IF FOSV,&(1) HT38 DART VALVE TESTED. -CLOSURE TIMES FOR BOP COMPONENTS ALL MEASURED 14 N2 BOTTLES AVERAGE PRESSURE=2125 PSI !-H2S AND LEL GAS ALARMS CALIBRATED 1 AND TESTED. BOP COMPONENTS FUNCTIONED FROM ALL THREE CONTROL PANELS: RIG MANAGER'S OFFICE,LER,ACCUMULATOR 15:00 - 16:30 1.50 BOPSUR P DECOMP RIG DOWN PRESSURE TESTING EQUIPMENT 16:30 - 20:00 3.50 CLEAN P DECOMP MAKEUP AND RUN IN HOLE WITH 9-5/8" DRESS-OFF ASSEMBLY FROM SURFACE TO BHA OVERALL LENGTH AT 890'MD 12-1/4"OD X 9-5/8"ID DRESS-OFF SHOE 11-3/4"WASHPIPE EXTENSION,9-5/8"INNER MILL,11-3/4"WASH OVER BOOT BASKET 13-3/8"(11-1/4"OD)CASING SCRAPER PORTED FLOAT,BOWEN BUMPER SUB AND JARS,(3)STANDS 6-1/4"DRILL COLLARS,(6) STANDS 5"HWDP 20:00 - 20:30 0.50 CLEAN P DECOMP CIRCULATE 2 BOTTOMS UP. ONLY MINOR INDICATIONS OF ARCTIC PACK IN RETURNS. -840 GPM,1100 PSI,RECIPROCATING FULL STAND - 20:30 - 21:30 1.00 CLEAN P DECOMP TRIP IN HOLE WITH 9-5/8"DRESSOFF ASSEMBLY FROM 890'MD TO TAG 9-5/8" STUMP AT 2077'MD. 21:30 - 23:00 1.50 CLEAN P DECOMP WASH DOWN AND DRESS-OFF 9-5/8"CASING STUB PER BAKER REPRESENTATIVE FROM 2077'MD TO 2078'MD,OUTER MILL AT 2084' !MD. PICKUP OFF STUB AND UNSUCCESSFULLY ATTEMPT TO WORK MILLS BACK OVER STUB WITH NO ROTATION. ESTABLISH 10 RPM ROTATION TO WORK MILLS OVER STUB WITH 420 GPM. -420 GPM,450-500 PSI,60 RPM,5-8 KFT-LBS TORQUE 23:00 - 00:00 1.00 CLEAN P DECOMP CIRCULATE HOLE CLEAN WITH 1 DRUM SAFE-SURF-O PILL ADDED IN THROUGH CHEMICAL INJECTION LINE. CIRCULATE TOTAL 1.5 BOTTOMS UP. ONLY MINOR INDICATIONS OF ARCTIC PACK BACK TO SURFACE. FLOWCHECK WELL PRIOR TO PULLING OFF BOTTOM(STATIC) -840 GPM,1675 PSI,RECIPROCATING FULL STAND Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 10se7' . Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/7/2013 00:00 - 01:00 1.00 CLEAN P DECOMP PULL OUT OF HOLE WITH 9-5/8"DRESS-OFF ASSEMBLY FROM 9-58"CSG STUB AT 2076' MD TO BHA AT 890'MD,RACKING BACK 4" DRILLPIPE. FLOWCHECK WELL PRIOR TO PULLING BHA INTO BOP STACK(STATIC). 01:00 - 03:30 2.50 CLEAN P DECOMP RACK BACK(6)STANDS HWDP AND(3) STANDS 6-1/2"DRILL COLLARS. LAYDOWN BAKER 9-5/8"DRESS-OFF ASSEMBLY. 03:30 - 04:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR AFTER TRIPPING. 04:00 - 08:00 2.00 CUT P DECOMP RIG UP AND PERFORM DIAGNOSTIC PRESSURE TEST 13-3/8"CASING TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI HIGH FOR 30 MIN EACH AGAINST BLIND RAMS AND CLOSED CHOKE HCR(PASS,SEE ATTACHED CHART AND PASS/FAIL CRITERIA CALCULATOR). RIG DOWN TESTING EQUIPMENT. 06:00 - 13:00 7.00 BOPSUR P DECOMP LAYDOWN MOUSEHOLE. NIPPLE DOWN BELL NIPPLE,BOP STACK AND HIGH PRESSURE RISERS. SECURE BOP STACK ON STUMP AND LAYDOWN RISERS IN PIPE BARN. REMOVE WORKING ANNULUS VALVES FROM TUBING AND CASING SPOOLS. BARRIERS TO NIPPLE DOWN BOPE: -13-3/8"X 9-5/8"ANNULUS: TESTED 13-3/8" SHOE,9.8 PPG KWF(OA MONITORED FOR>3 TIMES EXPECTED TIME FRAME FOR WELLHEAD WORK). -9-5/8"CASING: TESTED CEMENT PLUG,KILL WEIGHT FLUID 13:00 - 15:00 2.00 WHSUR P DECOMP NIPPLE DOWN TUBING SPOOL("T2S"13-5/8" 5K STUDDED BOTTOM X 13-5/8"5K FLANGED TOP)AND CASING SPOOL. REMOVE BOTH FROM WELLHOUSE. RIG UP CASING RUNNING EQUIPMENT -SIDE DOOR ELEVATORS,LONG BALES, DOYON CASING EQUIPMENT,LOAD CENTRALIZERS TO RIG FLOOR, 15:00 - 18:30 3.50 WHSUR P DECOMP 1 MIRU WACHS CUTTER ASSEMBLY. MAKE INTERNAL CUT ON 13-3/8"CASING 38"BELOW TOP OF CASING HEAD. WACHS CUTTER DAMAGES ALL CUTTING BLADES DURING OPERATION DUE TO PINCHING PROBLEMS. MAKE EXTERNAL CUT ON 20"CONDUCTOR 40"BELOW TOP OF CASING HEAD. GOOD QUALITY CUT MADE. 18:30 - 19:00 0.50 WHSUR P DECOMP UNSUCCESSFULLY ATTEMPT TO LIFT CASING HEAD FROM 20"AND 13-3/8"CUT WITH BOP BRIDGE CRANE AND WITH LOADER. 13-3/8" 1 CASING IS NOT 100%CUT. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 11 efBS- Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UW: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 23:30 4.50 WHSUR N WSEQ 0.71 DECOMP UNSUCCESSFULLY ATTEMPT SEVERAL MORE j METHODS OF LIFTING CASING HEAD. MAKE INTERNAL CUT ON 13-3/8"CASING AT 38" BELOW TOP OF CASING HEAD WITH WELDER'S TORCH. LIFT OFF CASING HEAD. CEMENT FOUND IN 20"X 13-3/8"ANNULUS. -PLAN FORWARD TO PROCEED WITH TORCH AGREED TO BY ANCHORAGE TEAM AND OPS SUPERINTENDENT. 23:30 - 00:00 0.50 CASING P DECOMP COMPLETE RIG UP AND HOLD PJSM WITH RIG TEAM FOR RUNNING 9-5/8"CASING. 4/8/2013 00:00 - 01:00 1.00 CASING P DECOMP COMPLETE RIG UP AND HOLD PJSM WITH RIG TEAM FOR RUNNING 9-5/8"CASING. 01:00 - 05:00 4.00 CASING P DECOMP RUN IN HOLE WITH 9-5/8",40#,L-80, HYDRIL563 NEW SURFACE CASING TIE-BACK STRING FROM SURFACE TO 9-5/8"STUB AT 2078'MD. -CONFIRM ES CEMENTER PROPERLY PINNED WITH 6 SHEAR PINS(CALCULATED OPENING PRESSURE=3300 PSI) -TAKE 9.8 PPG BRINE DISPLACEMENT RETURNS TO CELLAR AND REMOVE WITH VAC TRUCK. -INSTALL(1)FREE-FLOATING CENTRALIZER ON EVERY JOINT -TORQUE-TURN EACH CONNECTION TO OPTIMUM 13 KFT-LBS MAKEUP -PICKUP WEIGHT ABOVE 9-5/8"STUB=105 KLBS,SLACKOFF=105 KLBS. -CALIPERED OUT DIAMETER OF CUT JOINT AT LOCATION FOR NEW WELLHEAD=9.73". 05:00 - 05:30 0.50 CASING P DECOMP 'ENGAGE STUMP WITH BOWEN CASING PATCH. ROTATE MOMENTARILY AT 10 RPM WITH TOP DRIVE PIPE HANDLER TO WORK 1 BOWEN PATCH OVER TOP OF 9-5/8"STUB. LAND NEW 9-5/8"SURFACE TIEBACK STRING ON DEPTH AT 2078'MD(3'PATCH SWALLOW OVER STUB). CONFIRM PATCH ENGAGEMENT BY SLACKING OFF FULL II STRING WEIGHT AND PICKING UP TO 100 KLBS OVER TWICE. 05:30 - 07:00 1.50 CEMT P DECOMP RIG UP HALLIBURTON CEMENT HEAD AND RIG FLOOR CIRCULATING LINES. PJSM FOR PRESSURE TESTING AND OPENING ES CEMENTER. 07:00 - 07:30 0.50 CASING P DECOMP WITH 9-5/8"STRING PULLED TENSION TO 100 KLBS OVER,PRESSURE TEST 9-5/8"CASING TO 1500 PSI FOR 10 MIN(PASS,25 PSI LOSS). PRESSURE UP TO 3160 PSI TO OPEN ES STAGE CEMENTING TOOL. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 12ale25+ Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date!Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 10:30 3.00 CEMT P DECOMP 1 CIRCULATE 200 BBLS 120°F 9.8 PPG BRINE (1/3 BOTTOMS UP)TO WARM UP ANNULUS IN I PREPARATION FOR CEMENTING 105 GPM,400 PSI,TAKING RETURNS TO CELLAR. FINAL OUT TEMPERATURE=81°F. MIRU SCHLUMBERGER CEMENTING EQUIPMENT. PRESSURE TEST SURFACE LINES TO 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). HOLD PJSM WITH RIG TEAM FOR CEMENTING. 10:30 - 13:00 2.50 CEMT P DECOMP CEMENT 9-5/8"SURFACE CASING TIEBACK STRING,WHILE TAKING RETURNS TO CELLAR AND MAINTAINING 100 KLBS OVERPULL(205 KLBS UP WEIGHT)AS FOLLOWS: -SLB PUMP 171 BBLS 15.8 PPG,CLASS G, 1.16 FTA3/SX,CEMENT AT 3-4.5 BPM,INITIAL CIRC PRESSURE=1450 PSI,FINAL=350 PSI. 'I-DROP HALLIBURTON ES CEMENTER CLOSING PLUG AND SLB KICK OFF PLUG WITH 5 BBLS 8.4 PPG FRESH WATER RIG PUMPS DISPLACE WITH 152 BBLS 9.8 PPG BRINE FOR TOTAL DISPLACEMENT OF 157 BBLS(96%PUMP EFFICIENCY). BUMP PLUG ON SCHEDULE WITH 669 PSI (COMPARED TO CEMCADE PREDICTION OF -750 PSI). ORIGINALLY CHASE CEMENT AT 6 BPM FOR FIRST 50 BBLS. 3-4.5 BPM UNTIL 125 BBLS AWAY,2 BPM UNTIL 140 BBLS AWAY,1 BPM UNTIL PLUG BUMP. -AFTER PLUG BUMP,SHIFT ES CEMENTER CLOSED BY PRESSURING UP BEHIND PLUG TO 1670 PSI(AS EXPECTED). HOLD 1650 PSI ON WELL FOR 10 MIN,THEN BLEED OFF,ES CEMENTER CLOSING PLUG HOLDING U-TUBE PRESSURE. FLOWCHECK 13-3/8"X 9-5/8" IANNULUS(STATIC). I-50 BBLS CEMENT RETURNED TO SURFACE 1-METAL GUSSETS INSTALLED AT CELLAR BOTTOM TO CENTER 9-5/8"CASING INSIDE 13-3/8" 9-5/8"CASING CEMENT IN PLACE AT 12:45 ON 4/8/2013 13:00 - 19:30 6.50 WHSUR P DECOMP WAIT ON CEMENT TO REACH 50 PSI COMPRESSIVE STRENGTH(6.5 HOURS PER 1 SLB UCA CHART). rr. RIG DOWN CEMENT HEAD,DRAIN 9-5/8" CASING FROM RIG FLOOR TO WELL CELLAR (IN PREPARATION FOR CASING CUT AND NEW WELLHEAD INSTALLATION). Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 13 Oa— Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: !X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 22:00 2.50 CASING P DECOMP SLACKOFF WITH BLOCKS AND RELEASE TENSION FROM CASING STRING. CAMERON REPRESENTATIVES CONFIRM WELLHEAD 'HEIGHT MEASUREMENTS WITH DRILLSITE OPERATOR. RIG UP WACHS CUTTER AND CUT 9-5/8"CASING AT 44.7'FROM ROTARY TABLE. LAYDOWN 9-5/8"XO PUP,FULL JOINT AND 12.4'CUT JOINT. -OUTER ANNULUS OUTLETS WILL BE 35" ABOVE TOP OF CELLAR BOX(SAME AS 02-15 NEW WELLHEAD) 22:00 - 23:30 1.50 WHSUR P DECOMP INSTALL NEW CAMERON TYPE S-3 9-5/8"5K SLIPLOCK WELLHEAD(11"FLANGE TOP) !OVER 9-5/8"CASING STUB(COMPLETE INSTALLATION AND PRESSURE TESTING ON 4/9/2013). RIG DOWN DOYON CASING EQUIPMENT ON RIG FLOOR. CHANGEOUT LONG BALES FOR SHORT BALES. 23:30 - 00:00 0.50 WHSUR P DECOMP HOLD H2S AND RIG EVACUATION DRILL WITH BOTH RIG CREWS ON LOCATION. CAPTURE LEARNINGS IN AFTER ACTION REVIEW (COMPLETED ON 4/9/2013 AT 00:30) 4/9/2013 00:00 - 00:30 0.50 CLEAN P DECOMP HOLD H2S AND RIG EVACUATION DRILL WITH BOTH RIG CREWS ON LOCATION. CAPTURE LEARNINGS IN AFTER ACTION REVIEW (CARRIED OVER FROM 4/8/2013 AT 23:30) 00:30 - 02:00 1.50 WHSUR P DECOMP INSTALL NEW CAMERON TYPE S-3 9-5/8"5K SLIPLOCK WELLHEAD(11"FLANGE TOP) OVER 9-5/8"CASING STUB. PRESSURE TEST CAHN SEAL PACK-OFF TO 250 PSI LOW FOR FIVE MIN AND 2400 PSI HIGH FOR 30 MIN (PASS,SEE ATTACHED CHARTS). NOTE: CREWMEMBERS FROM NOON TO MIDNIGHT TOUR STAY OVER TO ASSIST CAMERON REPRESENTATIVES. BUCKLER'S FULL CREW ON HSE STANDDOWN. 02:00 - 12:00 10.00 BOPSUR N WAIT 0.71 DECOMP PLANNED HSE STAND DOWN(REQUIREMENT OF RIG STARTUP PLAN TO CATCH EACH INCOMING CREWAFTER 4/2-4/5 STAND DOWN) -REVIEW RIG INCIDENTS,COVERING FIRST THREE MONTHS OF OPERATIONS. PRIMARILY FOCUS ON DROPPED OBJECT AND LEAK INCIDENTS. -REVIEW ACTION PLANS TO IMPROVE FUTURE OPERATIONAL PRACTICES, CONTROL OF WORK,RISK ASSESSMENTS -MONITOR WELL HOURLY(STATIC,9-5/8" CEMENT IN PLACE,KILL WEIGHT 9.8 PPG BRINE IN WELL). 12:00 - 21:00 9.00 BOPSUR P DECOMP NIPPLE UP DOUBLE-STUDDED ADAPTER, HIGH PRESSURE RISERS,13-5/8"BOP STACK AND BELL NIPPLE TO NEW 9-5/8"SLIPLOCK WELLHEAD. SET MOUSEHOLE. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 14.4a5_ Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 BOPSUR P DECOMP RUN IN HOLE WITH 4"TEST JOINT AND TEST PLUG. RIG UP TESTING EQUIPMENT. PRESSURE TEST BOP BREAKS TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN EACH (PASS,SEE ATTACHED CHART). -TEST PLUG LEAKING ON FIRST RUN. PULL AND RE-SET. RUN IN LOCKDOWN SCREWS ON TEST PLUG TO ENGAGE SEALS. 4/10/2013 00:00 - 01:30 1.50 BOPSUR P DECOMP RIG DOWN TESTING EQUIPMENT AND LAYDOWN TEST JOINT. SET WEAR BUSHING, ID=9-1/16". INSTALL 2-1/16"WORKING VALVE AND INTEGRAL FLANGE ON OA OUTLET. 01:30 - 04:30 3.00 CLEAN P DECOMP MAKEUP AND RUN IN HOLE WITH 9-5/8" CLEANOUT BHA FROM SURFACE TO OVERALL LENGTH AT 888'MD. -BHA MEANT TO REPLICATE UPCOMING WHIPSTOCK/MILL RUN 04:30 - 05:30 1.00 CLEAN P .DECOMP RUN IN HOLE WITH 9-5/8"CLEANOUT ASSEMBLY FROM BHA AT 888'MD TO TAG ES CEMENTER CLOSING PLUG AT 2047'MD(18', 1.4 BBLS OF CEMENT ABOVE PLUG AS EXPECTED FROM CEM ENTERS KICKING OFF PLUG). 05:30 - 08:30 3.00 CLEAN P DECOMP CLEANOUT CEMENT STRINGERS IN 9-5/8" CASING AND HALLIBURTON ES CEMENTER CLOSING PLUG PER HALLIBURTON GUIDELINES FROM 2047'MD TO 2066'MD. CIRCULATE 2 BOTTOMS UP AFTER MILLING PLUG,PRIOR TO NEXT CONNECTION. -300 GPM,310 PSI,60 RPM,3-4 KFT-LBS TORQUE,8-10 KLBS WOB I-1.5 HOURS TO MILL CLOSING PLUG. 08:30 - 11:30 3.00 CLEAN P DECOMP RUN IN HOLE WITH 9-5/8"CLEANOUT ASSEMBLY FROM ES CEMENTER DEPTH AT 2066'MD TO TAG EZSV ON DEPTH AT 5296' MD(TOP OF EZSV,MIDDLE OF ELEMENT IS AT 5298'MD). -ONE TIGHT SPOT OBSERVED AT 4675'MD ON TRIP IN HOLE. 4 KLBS DRAG REQUIRED TO PASS THROUGH TROUBLE SPOT ON ORIGINAL PASS. WORK DUAL 8-1/2" WATERMELON MILLS THROUGH SPOT FIVE TIMES UNTIL DRAG DROPS TO 1 KLBS. NOTE: CASING ANOMOLIES WERE ORIGINALLY IDENTIFIED AT 4675'MD AND 4860'MD ON 4/1/2013 USIT LOG. 11:30 - 13:00 1.50 CLEAN P DECOMP CIRCULATE HOLE CLEAN ON TOP OF EZSV AT 5296'MD. CIRCULATE AROUND HI-VIS SWEEP SURFACE TO SURFACE. PICKUP WEIGHT=141 KLBS,SLACKOFF=137 KLBS. 700 GPM,2900 PSI,RECIPROCATING PIPE. Printed 4/22/2013 10:50:31AM North America-ALASKA-BP Page 15 otl5, Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: ,X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To 'Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (us t) 13:00 - 15:30 2.50 CASING P DECOMP CLOSE UPPER PIPE RAMS AND UNSUCCESSFULLY ATTEMPT TO PRESSURE TEST 9-5/8"CASING TO 250 PSI LOW(PASS), 3500 PSI HIGH(FAIL). AFTER PRESSURING UP TO 3850 PSI WITH CORRECT VOLUME PUMPED AND HOLDING 1 FOR 3 MINUTES,PRESSURE IMMEDIATELY DROPS TO 0 PSI. NO ISSUES FOUND IN SURFACE EQUIPMENT. FLUID LEVEL IN WELL BEGINS DROPPING. STATIC LOSS RATE MEASURED AT 8 BPH. ONLY ABLE TO PRESSURE UP TO 85 PSI ON SECOND TEST ATTEMPT. -RETAG EZSV AT SAME DEPTH 5296'MD AFTER FIRST FAILED TEST TO CONFIRM PLUG WAS NOT PUSHED DOWNHOLE. 'DISCUSS RESULTS WITH ANCHORAGE TEAM. DECISION TO PULL OUT OF HOLE FOR RTTS TOOL LEAK DETECTION. FLOWCHECK WELL PRIOR TO PULLING OFF BOTTOM(WELL ON LOSSES). 15:30 - 19:30 4.00 CLEAN P DECOMP TRIP OUT OF THE HOLE FROM EZSV AT 5296' MD TO BHA AT 888'MD,RACKING BACK 4" DRILLPIPE AND MONITORING WELL ON TRIP TANK. FLOWCHECK WELL PRIOR TO PULLING BHA INTO BOP STACK(STATIC LOSS RATE=6 BPH). -NO ISSUES PASSING THROUGH TIGHT SPOT AT 4675'MD OR ES CEMENTER AT 2065' MD. 19:30 - 22:00 2.50 CLEAN P DECOMP RACK BACK(6)STANDS 5"HWDP AND(3) STANDS 6-1/2"SPIRAL DRILL COLLARS. LAYDOWN BAKER 9-5/8"CLEANOUT TOOLS. APPROX.3 LBS TRASH FOUND IN JUNK BASKETS. 22:00 - 22:30 0.50 CASING P DECOMP CLEAR RIG FLOOR AFTER TRIPPING. -MONITOR WELL WITH CONTINUOUS HOLE FILL(10 BPH STATIC LOSS RATE) 22:30 - 00:00 1.50 CASING N DFAL 5,296.71 DECOMP MAKEUP AND RUN IN HOLE WITH HALLIBURTON 9-5/8"RTTS(TEST PACKER) FROM SURFACE TO BHA OVERALL LENGTH AT 298'MD(3 STANDS 6-1/2"DC+TOP OF TOOL TO CENTER OF ELEMENT). 4/11/2013 00:00 - 01:30 1.50 CASING N DFAL 5,296.71 DECOMP TRIP IN HOLE WITH 9-5/8"RTTS PRESSURE TESTING ASSEMBLY FROM BHAAT 298'MD TO FIRST TEST DEPTH AT 2100'MD. 01:30 - 10:00 8.50 CASING N DFAL 5,296.71 DECOMP TRIP IN AND OUT OF HOLE WITH HALLIBURTON 9-5/8"RTTS AND PERFORM DIAGNOSTIC PRESSURE TESTS ABOVE AND BELOW RTTS AT FOLLWING DEPTHS: -2097'MD,2733'MD,4565'MD,4474'MD,3520' MD,3138'MD,3370'MD,3340'MD AND 3300' MD. IDENTIFY LEAK IN 9-5/8'TO BE BETWEEN 3300'MD AND 3340'MD. ABLE TO PUMP AWAY 9.8 PPG BRINE AT 1 BPM,125 PSI THROUGH LEAK. SEE ATTACHED CHARTS FOR PRESSURE TESTING RESULTS. Printed 4/22/2013 10:50:31AM • North America-ALASKA-BP Page 16 nfQS. Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 CASING N DFAL 5,296.71 DECOMP CLOSE UPPER PIPE RAMS AND PRESSURE TEST 9-5/8"SURFACE CASING AGAINST RTTS TO 250 PSI LOW AND 3500 PSI HIGH FOR 30 MIN FROM 3300'MD TO SURFACE(PASSING TESTS,SEE ATTACHED CHART AND INTEGRITY TEST CALCULATOR). OBTAIN APPROVAL TO PROCEED WITH WELL • PROGRAM FROM WELLS TEAM LEADER. 11:00 - 13:30 2.50 CASING N DFAL 5,296.71 DECOMP TRIP OUT OF THE HOLE FROM 3300'MD TO 'BHA AT298'MD,RACKING BACK 4" DRILLPIPE. FLOWCHECK WELL PRIOR TO PULLING OFF BOTTOM AND PRIOR TO PULLING BHA INTO BOP STACK(WELL ON LOSSES). 13:30 - 14:30 1.00 CASING N DFAL 5,296.71 DECOMP RACK BACK(3)STANDS 6-1/2"DRILL COLLARS AND LAYDOWN HES RTTS PACKER. 14:30 - 15:00 0.50 CASING P DECOMP SERVICE AND LUBRICATE RIG. 15:00 - 17:30 2.50 CASING N DFAL 5,296.71 DECOMP MIRU SCHLUMBERGER E-LINE UNIT. LOAD TOOLS TO RIG FLOOR. NO PRESSURE CONTROL EQUIPMENT,ONLY LINE WIPER. 17:30 - 20:00 2.50 CASING N DFAL 5,296.71 DECOMP RUN IN HOLE WITH GR/CCUEZSV. CORRELATE DEPTH AND CONFIRM GR TIE-IN WITH WELLSITE GEO. SET HES 9-5/8" 29.3#-70.3#EZ DRILL SVB SQUEEZE PACKER (EZSV)WITH TOP AT 2946'ELMD. PULL OUT OF HOLE WITH E-LINE. -PROPOSED WINDOW DEPTH: 2925'-2942' MD -MAINTAIN CONSTANT CIRCULATION OVER TOP OF WELL. AVERAGE 6 BPH LOSSES. 20:00 - 21:00 1.00 CASING 'N DFAL 5,296.71 DECOMP RIG DOWN SLB E-LINE UNIT. 21:00 - 21:30 0.50 CASING N DFAL 5,296.71 DECOMP CLOSE BLIND RAMS AND PRESSURE TEST HES 9-5/8"EZSV AT 2946'MD TO 250 PSI LOW AND 1000 PSI HIGH TO CONFIRM PLUG IS SET AND DOES NOT MOVE DOWNHOLE (PASSING TEST,SEE ATTACHED CHART) 21:30 - 22:00 0.50 CASING P DECOMP HOLD MAN DOWN DRILL AND AFTER ACTION REVIEW WITH RIG TEAM. 22:00 - 00:00 2.00 STWHIP P WEXIT MAKEUP AND SCRIBE IN HOLE WITH BAKER STIFF 3 STRING MILL GENERATION II WHIPSTOCK ASSEMBLY -NO MWD TOOLS. ADD UBHO SUB FOR GYRO ORIENTATION IN VERTICAL HOLE. 4/12/2013 00:00 - 01:30 1.50 STWHIP P WEXIT RUN IN HOLE VITH(3)STANDS 6-1/2"DRILL COLLARS AND(6)STANDS 5"HWDP TO COMPLETE 9-5/8"WHIPSTOCK/MILLING ASSEMBLY,OVERALL LENGTH=922'MD. 01:30 - 04:00 2.50 STWHIP P WEXIT RUN IN HOLE WITH 9-5/8"WHIPSTOCK/MILL ASSEMBLY FROM BHAAT 922'MD TO 2916', 30'ABOVE EZSV,1.5 MIN/STAND. 04:00 - 04:30 0.50 STWHIP P WEXIT RIG UP HALLIBURTON E-LINE UNIT AND MAKEUP GYRO SURVEY TOOLS ON RIG FLOOR. 04:30 - 06:00 1.50 STWHIP P WEXIT SET STRING IN SLIPS AND RUN IN HOLE WITH GYRO SURVEY TO UBHO SUB ABOVE WHIPSTOCK ASSEMBLY. ORIENT WHIPSTOCK TO 172°PER NEW DIRECTIONAL PLAN. Printed 4/22/2013 10:50:31AM North America-ALASKA-BP Page 17 eds. Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) ' Start Date:3/27/2013 End Date X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual©77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:00 1.00 STWHIP P WEXIT i RUN IN HOLE WITH WHIPSTOCK TO 2943'MD (3'PLANNED SETTING DEPTH AT EZSV). SET DRILLSTRING IN SLIPS AND RUN IN HOLE i WITH GYRO SURVEY TO CONFIRM ORIENTATION. 07:00 - 08:30 1.50 STWHIP P WEXIT RUN IN HOLE WITH WHIPSTOCK ASSEMBLY FROM 2943'MD TO TAG EZSV ON DEPTH AT '2946'MD. SLACKOFF 17 KLBS TO SET WHIPSTOCK ANCHOR. PICKUP 15 KLBS TO CONFIRM SET. SLACKOFF WITH 46 KLBS DOWN WEIGHT TO SHEAR MILLS OFF I WHIPSTOCK SLIDE. 08:30 - 16:30 8.00 STWHIP P WEXIT KICKOFF DS02-13C WELLBORE AT 08:30 ON 6 ^'�t 4/12/13. CIRCULATE NEW 9.8 PPG LSND v MILLING FLUID DOWN TO MILLS. MILL ( WINDOW+NEW FORMATION FROM 2925'MD (f TO 2953'MD. PUMP(2)20 BBL SUPER SWEEPS WHILE MILLING WINDOW(NO SIGNIFICANT INCREASE IN RETURNS). -450 GPM,650 PSI,100 RPM,4-7 KFT-LBS TORQUE,4-6 KLBS WOB SLOW PUMP RATES AT 2925'MD,9.8 PPG LSND MP#1: 20 SPM=105 PSI,30 SPM=139 PSI,40 SPM=181 PSI MP#2: 20 SPM=107 PSI,30 SPM=141 PSI, 40 SPM=181 PSI TOP OF WINDOW,SIDETRACK KICKOFF POINT=2925'MD,2925'TVD MIDDLE OF WINDOW=2933'MD BOTTOM OF WINDOW=2942'MD ✓ 16:30 - 18:00 1.50 STWHIP P WEXIT CLOSE UPPER PIPE RAMS AND PERFORM FORMATION INTEGRITY TEST TO 12.4 PPG EMW. OBTAIN APPROVAL TO PROCEED WITH WELL PROGRAM FROM WELLS TEAM LEADER -9.8 PPG LSND,2953'TVD,400 PSI APPLIED SURFACE PRESSURE(SEE ATTACHED DOCUMENTATION) 18:00 - 19:00 1.00 STWHIP P WEXIT MILL 8-1/2"NEW FORMATION FROM 2953'MD • TO 2959'MD(SECOND UPPER WATERMELON MILL OFF TRAY). -450 GPM,700 PSI,100 RPM,2-3 KFT-LBS TORQUE 19:00 - 20:30 1.50 STWHIP P WEXIT WORK MILLS THROUGH WINDOW THREE PASSES WHILE CIRCULATING AROUND 40 BBL SUPER SWEEP. NO ISSUES PASSING THROUGH WINDOW WITH PUMPS ON OR OFF. FLOWCHECK WELL PRIOR TO PULLING OFF BOTTOM(STATIC). 20:30 - 21:30 1.00 STWHIP P WEXIT TRIP OUT OF THE HOLE WITH 8-1/2"WINDOW MILLING ASSEMBLY FROM 2959'MD TO BHA AT 922'MD,RACKING BACK 4"DRILLPIPE. FLOWCHECK WELL PRIOR TO PULLING BHA INTO BOP STACK(STATIC). 21:30 - 23:30 2.00 STWHIP P WEXIT RACK BACK(6)STANDS 5"HWDP AND LAYDOWN(9)6-1/2"DRILL COLLARS. Printed 4/22/2013 10:50:31AM North America-ALASKA-BP Page 1845 Operation Summary Report Common Well Name:02-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/27/2013 End Date: X3-010G8-C:(12,228,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 273 Spud Date/Time:4/29/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI: Active datum:02-13C Actual @77.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 STWHIP P WEXIT HOLD KICK WHILE TRIPPING(D1)DRILL WITH NON-SHEARABLES ACROSS BOP STACK AND AFTER ACTION REVIEW WITH RIG TEAM. 4/13/2013 00:00 - 00:30 0.50 STWHIP P WEXIT LAYDOWN BAKER 9-5/8"WINDOW MILLING ASSEMBLY. -DUAL UPPER 8-1/2"WATERMELON MILLS IN GAUGE. 8-1/2"STARTER MILL 1/4"OUT OF GAUGE. NO NOTEABLE DAMAGE ON ANY PART OF ASSEMBLY. 00:30 - 01:00 0.50 BOPSUR P WEXIT DRAIN BOP STACK AND PULL WEAR BUSHING. 01:00 - 02:00 1.00 BOPSUR P WEXIT OPEN CHOKE AND KILL MANUAL VALVES AND FLUSH STACK CLEAN AFTER MILLING WINDOW. FUNCTION ALL BOP COMPONENTS. 02:00 - 03:30 1.50 BOPSUR P WEXIT RIG UP PRESSURE TESTING EQUIPMENT. RUN IN HOLE WITH 4"TEST JOINT AND SET TEST PLUG. FILL ALL SURFACE LINES. VOLUME TO FILL MUD-GAS SEPARATOR= 12.5 BBLS 03:30 - 08:00 4.50 BOPSUR -P WEXIT PRESSURE-FUNCTION TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH WITH 4"TEST JOINT PER AKDWOP STANDARDS AND AOGCC REGULATIONS. STATE'S RIGHT TO WITNESS TEST WAIVED BY AOGCC REPRESENTATIVE JEFF TURKINGTON. -ONE FAIUPASS RESULT FOR UPPER VBRS (FUNCTION AND RE-TEST) -ALL BOPE TEST CHARTS AND REPORT ARE ATTACHED. -(2)HT38 FOSVS,(1)4-1/2"IF FOSV,&(1) HT38 DART VALVE TESTED. -BOP COMPONENTS FUNCTIONED FROM ALL THREE CONTROL PANELS: RIG MANAGER'S OFFICE,LER,ACCUMULATOR 08:00 - 09:30 1.50 BOPSUR P WEXIT RIG DOWN PRESSURE TESTING EQUIPMENT. PULL AND LAYDOWN TEST JOINT/PLUG. INSTALL 9-1/16"ID WEAR BUSHING. 09:30 - 10:00 0.50 BOPSUR P WEXIT SERVICE RIG 10:00 - 11:30 1.50 DRILL C WEXIT LOAD BHA TOOLS TO RIG FLOOR. HOLD PJSM FOR MAKING UP BHA. WORK WITH DIRECTIONAL DRILLERS AND ANCHORAGE TEAM ON NEW 2 BHA PLAN FOR SIDETRACKING(DEDICATED 300'MILL TOOTH BIT,HIGH BEND ANGLE MUD MOTOR SIDETRACKING BHA FOR RUN#1). NOTE: "CHANGE IN SCOPE"TIMING CODE WILL APPLY UNTIL 8-1/2"INT DRLG BHA REACHES ORIGINAL WELL PROGRAM SIDETRACK DEPTH AT 5298'MD 11:30 - 14:00 2.50 DRILL C WEXIT MAKEUP AND RUN IN HOLE WITH 8-1/2" DIRECTIONAL DRILLING ASSEMBLY FROM SURFACE TO TOTAL LENGTH AT 692'MD. 8-1/2"HUGHES VM-3 MILL TOOTH,2.12° BENT MUD MOTOR,UBHO SUB,NO MWD I TOOLS. 14:00 - 16:30 2.50 DRILL C WEXIT TRIP IN HOLE WITH 8-1/2"DRILLING ASSEMBLY FROM BHA AT 692'MD TO 2865' MD(60'ABOVE WINDOW). Printed 4/22/2013 10:50:31AM , TREE= 5-1/8"GRAY WE LHEAD= GRAY SAE._.r NOTES:W ELL ANGLE>70 @ 9800'*** ACTUATOR= AXELSON 02-13B PRE 02-13B SDTRCK WELLBORE NOT SHOWN*** NTIAL KB.ELE 57.6' BF_ = = NA I KOP= 4300' Max Angle= 93°@ 10935 2925' H 9-5/8"WHIPSTOCK Datum AU= 9641' Datum TVD= 8800'SS 2946' —9-5/8"EZSV 13-3/8"CSG,72#,L-80,D=12.347" — 2728' 5296' H9-5/8"EZSV 1111111111 GAS UFT MANDRELS JET CUT TBG(12/04/12) — 5430' I ST MD I VD DEV TYPE VLV LATCH PORT DATE 3 3813 3812 0 MIG DMY RK 0 03/18/11 ESTIMATED TOP OF CEMENT(11/22/12) H—6938'-8441' 2 6342 6070 34 BRAG DMY RK 0 03/18/11 *1 8441 7791 32 MIG EMPN 11/19/12 STA#1=DMY BELOW CMT CAP @ 8441'SLM Minimum ID =3.725" @ 8900' 8844' H4-1/2"I-ESX NP,ID=3.813" 4-1/2" HES XN NIPPLE MI Par_ 8855' —{9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 8879' H4-1/2"FES X NP,D=3.813" ESTIMATED TOC(11/10/12) -'8900' 8900' H4-1/2^HES XN NP,ID=3.725" Pit TOP OF 4-1/2'LNR H 8903' kV NV 8903' H9-5/8"BKR TEBACK SLV,D=7.50" 4-1/2"TBG,12.6#,L-80,_0152 bpf,D=3.958" 8911' =, �� 8911' —{9-5/8"X 4-1/2"BKR ZXP LNR PKR,ID=6276" \ 8912' --Ia-1/z^vuLEG,ID=a.00^ 8919' H 9-5/8"X 4-1/2"BKR HMC LNR HGR,D=6.276"] kV eloein 9-5/8"CSG,47#,L-60,ID=8.681" — 9109' 9-5/8"CSG MLLOUT WNJOW (02-13B) 9109'-9125' 1744 Ple,41 44 t.tti 0 40,4 44 a IP Arra. 142 PERFORATION SUMMARY ree REF LOG:SPERRY SUV MD DATED 01/26/02lir%1 ANGLE AT TOP PETE:83°@ 9882' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE SQZ 2-7/8" 6 9882-9907 S 05/11/10 11/10/12 9951' —12-1/2"BKR BP(05/13/10) 2-7/8" 6 9907-9932 S 05/10/10 11/10/12 2-1/2" 4 10020-10590 C 02/11/02 I PBTD - 1091T 014,41 4-1/2"LNR,12.6#,L-80,.0152 bpf,ID=3.958" — 11000' 4� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/20/80 INITIAL COMPLETION 11/23/12 MK/PJC CMT CAP(11122112) VVEtL: 02-13B 02/28/95 CTD SIDETRACK(02-13A) 12/12/12 JCNYJMD JET CUT TBG(12/04/12) PB2MT ND:'2012430 02/13/02 D-16 SIDETRACK(02-13B) _ AR ND: 50-029-20433-02 05/26/11 BSE/PJC GLV CIO(03/18/11) SEC 36,T11N,R14E,685'FN &873'EWL 11/15/12 REMIJMD SET CEMENT PLUG(11/10/12) BP Exploration(Alaska) 11/23/12 T-VPJC GLV GO(11/19/12) zo\-2A 0 c) CO 'hi4 I 02 f 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 �, �_ OOOO Oc.00000c) L.) C.) 00000 o U o .r. r ,1 O U •' , o CO -- U c3 'j) i tv Z o ;.4 i p t. c s • N p a v) , a • r-1 N • E+ Z- ip co ° '5 rt z °' _o M P4 v DI `l r CIO o W ,-, C'7 Ul O r\7 N' � N Q (s °� 13 ,-+ M t,.� M M M M M M M �,., M N N M N N M M M = ' v Wv/ _ i r r r r r r r r' r r r ■\ -S 0) N co . /1 (:)) �L9 L L L L c _a _a _a C) w C C L 7:---...,:\J N ,- 1-J N , V lC a cu t0 a w d w d d a to V Q. Q d 4I O id of C, 2 -.) 1•L,. 5, W ' ' LL 0 0 7 7 O Q Q W �",, a) . .tO J O r '� to CO O tp NI. N r 1n r 00 raj v NNIP �, U] C'-+ r M N N N N f V (NI tD r N r N M N r X a Q R . , a O w 2 J Z Ce Ce X U. MI LL II"a O w O O O O ce S Q' x ce ce „ CC J W CL J H X m a � a -I a W s W a ce I 3 cc Ix ce 0 cc ce N re -, 3 U m p. J J J O O J O Y O O p_ a O J J J J N Z f.. Z Z 2 2 Z g Q 2 2 _ _ 2 Z Z F Z Z U cn U U W W O W W W W m m W O O m O O 1 Q Z m co C1 71 m �y = I- < X X X X X X X X X m N VI Z �' W X X X X X X X X X X O• H . I y 0 CD '� i. U N to Cr W M tD M r Co o O M r N- ap ap O o r N M o 04 N - O M N r us o - 6 t0 Z o r O r r O r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 >= O O o o O O O O W O O O o 0 o O Q ° m 2 X X n X X X m n _ 2 Q ce m m m to 0 a ° r- Q LL to to U to u') to d U Q W m U Q Q m -) Q a o0 p `t m m CO U U U U U U U Q U CO U U CO CO m U U CO =M o CJ tL Y O� N > O�1 N -F-7.- m (7)N co iU • ro cc z a m G o r` 0 N 1n J N W d ... s J <9 O z (� Z '� O O a r a 0 a) 0 m -C C2. y 'GI rr N v O N v a 0 C v, o t� N a Ca _ / x a m rn Q • • (' 2I 2430 Pegg, •James B (DOA) From: Regg, James B (DOA) Sent: Monday, April 01, 2013 10:32 AM effl, 4 I 1 (I 3 To: Ferguson, Victoria L (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: RE: 02 -13C PTD (211 -099) Attachments: 2012- 1215 _BOP_Parker273_PBU_02- 12C_Ig. pdf 3 different Inspectors have witnessed 3 BOPE tests with following results: 12/15/12 (initial) — 5 failures, long test due to crews; 2 13 — 4 failures; 3 13 — 0 failures. There have been only 2 component failures on tests performed training 19 5 // // Y p p without AOGCC witness. I reviewed the most recent test report and charts (3/30/13) — zero failures and no indications of any problems. 6hr test on 3/30/13 is consistent with recent tests. Observation about BPXA's "justification ": well risk associated with weekly BOPE testing? I'd love to see their formal risk assessment and data on the "well risk" associated with weekly BOPE testing (lots of historical drilling done on N.Slope under weekly BOPE test cycle; exploration still on 7day cycle). They sure like throwing around the "r" word; most often without anything tangible to back it up. Rarely do they drill continuous for 7days, and taking opportunity to test when have to trip to surface mitigates whatever "risk" they think exists. Recent BOPE test times for this rig are running 4 -6 hours (reflecting performance improvement with test procedure since earlier tests that were + /- 10hrs). We have ALWAYS worked with operators and granted time extensions (delayed — and even in some instances waived the requirement for — BOPE testing) where justified and warranted to avoid the concerns he raises. They are really only concerned about rig time an $$$$, which I guess is their job. Ours is to make sure ops are done safely and equipment will perform as intended when needed. Infusion of new rigs and less experienced rig personnel are strong arguments for testing on 7day cycle — more tests, more opportunity to become familiar with their equipment and how it works. Parker 273 can move to 14 day BOPE test interval commencing with drilling on PBU 02 -13C (PTD 2110990) with the following advisory: AOGCC will not grant time extensions for BOPE tests that must be performed at intervals not exceeding 14days; rig crew should take advantage of testing opportunities (e.g., trip to surface) before day 14. Only exception is if experiencing active well control at the time of the required test. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 SCANNED JUL' I 0 2013 From: Ferguson, Victoria L (DOA) Sent: Friday, March 29, 2013 11:10 AM To: Regg, James B (DOA) Subject: FW: 02 -13C PTD (211 -099) Importance: High Please review - From: Rose, John G (ASRC) [mailto:John.G.Rose b .c Sent: Friday, March 29, 2013 11:02 AM f To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Daniel, Ryan Subject: 02 -13C PTD (211 -099) Victoria, 1 411 • PgtPoz.- 13 1 1 430 Regg, James B (DOA) From: Rig 273 Senior Manager [ rig273srmgr @parkerdrilling.com] - R 41( �i Sent: Saturday, March 30, 2013 10:06 AM To: Bolling, Lynda ; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Moore, Chelsi; Brooks, Phoebe L (DOA); WSL 273 Subject: Parker 273 03 -30 -13 BOP test.xls Attachments: Parker 273 03 -30 -13 BOP test.xls All, Please see attached BOP Test form. This is the Initial test for Parker rig 273 on_ell DS02 -13B, This will be a Redrill. Once whipstock is set and window is milled in casing, the well name will become DS02 -13C. Regards, Daniel Blydenburgh Rig Manager 273 Parker Drilling Company 907-659-5849 Ri Harmony 4227 rig273srmgr @parkerdrilling.com ********** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** NOTICE BY Parker Drilling Company This message, as well as any attached document, contains information from Parker Drilling Company that is confidential and /or privileged. The information is intended only for the use of the addressee named above. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution or the taking of any action in reliance on the contents of this message or its attachments is strictly prohibited, and may be unlawful. If you have received this message in error, please delete all electronic copies of this message and its attachments, if any, destroy any hard copies you may have created, without disclosing the contents, and notify the sender immediately. Unless expressly stated otherwise, nothing contained in this message should be construed as a digital or electronic signature, nor is it intended to reflect an intention to make an agreement by electronic means. • • - 061zA30 Regg, James B (DOA) From: AK, D &C Rig 273 Well Site Leader [ AKDCRig273WetlSiteLeader @bp.com] Sent: Saturday, March 30, 2013 10:10 AM 4 I d ( 3 To: Rose, John G (ASRC); Ferguson, Victoria L (DOA) Cc: Regg, James B (DOA); Schultz, Mikel; AK, D &C Rig 273 Well Site Leader Subject: RE: 02 -13C PTD (211 -099) BOP Testing Attachments: BOP Test 3_30_13.1.pdf; BOP Test 3_30_13.2.pdf; Parker 273 03 -30 -13 BOP test.xls All, Attached is the BOP Test for well DS -02 -13 From: Rose, John G (ASRC) Sent: Friday, March 29, 2013 3:38 PM To: Ferguson, Victoria L (DOA) Cc: Regg, James B (DOA); Schultz, Mikel; AK, D &C Rig 273 Well Site Leader Subject: RE: 02 -13C PTD (211 -099) BOP Testing Victoria, I have ask the Wellsite Leader on Parker 273 to forward the requested BOP test data to Jim Regg after the completion of this 1 BOP test on this well (which should be completed later tonight), therefore, Jim should see this information sometime tomorrow morning. Thanks - jr John G. Rose BP Staff Engineer Anchorage, AK rose11@bp.com 907/564 -5271 Office 907/748 -5223 Cell 907/243 -8813 Home From: Ferguson, Victoria L (DOA) f mailto :victoria.fergusonPalaska govt Sent: Friday, March 29, 2013 1:00 PM To: Rose, John G (ASRC) Cc: Regg, James B (DOA) Subject: RE: 02 -13C PTD (211 -099) BOP Testing John, We will need the BOP test report and charts from today's test to review before determining whether a 14 day cycle can be used. Please forward them to Jim Regg as soon as they are available. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�.alaska.gov 1 • • From: Rose, John G (ASRC) [mailto:John.G.Rose@ bp.com] Sent: Friday, March 29, 2013 11:02 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Daniel, Ryan Subject: 02 -13C PTD (211 -099) Victoria, Just to be clear as it relates to our BOP test cycle requirement for our current well on Parker 273 (the 02 -13C well which we moved to on 3/27/13), we would like to move forward using the standard 2 week cycle in the drilling phase of the well for testing the BOP'S. This well (02 -13C) will be Parker 273's 3rd well and including today's BOP test, there have been 14 BOP tests to date as indicated below: 02 -12D - 7 tests (AOGCC requirement for a 1 week cycle throughout the well) 02 -15C - 6 tests (AOGCC requirement for a 1 week cycle throughout the well) 02 -13C - 1 BOP test today (no requirement for a 1 week cycle in current PTD (211 -099)) I would like to also emphasize that while there is a clear time /cost penalty for the weekly BOP test requirement, there is also a well "risk" factor associated with the 1 week cycle in the drilling phase of the well as casing our open -hole intervals in minimum time is part of our drilling strategy to minimize well problems associated with wellbore instability issues (this is particularly true for the intermediate hole through the Jurassic shale section as we try to top -set the casing /liner into the top of the Sag River formation to isolate the shales). Therefore, as there is no mention of a weekly testing requirement in the current PTD (211 -099), the intent of this e -mail is to make sure you are in agreement with our moving forward on a 2 week BOP testing cycle for the drilling phase of this well. Thanks for your consideration. - jr John G. Rose BP Staff Engineer Anchorage, AK rosel 1@bp.com 907/564 -5271 Office 907/748 -5223 Cell 907/243 -8813 Home From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson(a alaska.gov] Sent: Thursday, March 07, 2013 2:07 PM To: Rose, John G (ASRC) Cc: Schwartz, Guy L (DOA) Subject: RE: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) John, A sundry is not required for the changes outlined below. This e ' . it will suffice. The changes are approved. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 2 III • STATE OF ALASKA OIL AND GAS CONSERVATION Report COMMISSION BOPE Test Repo? i 3 Submit to: lim.reggaalaska.gov doa. aogcc. prud hoe. bav(a�alaska. qov phoebe. brooksaalaska. gov Contractor: Parker - Rig No.: 273 DATE: 3/30/13 Rig Rep.: Dan Blydenburgh /Jon Kir Rig Phone: (907)659 -5849 Rig Fax: 659 -8455 Operator: BP Exploration Op. Phone: (907)659 -5880 Op. Fax: 659 -8455 Rep.: Will Turner / Kieth Conat: E -Mail rig273srmgr @parkerdrilling.com Well Name: PBU 02 -13B - PTD # 2012430 Operation: Drlg: Workover: X " Explor.: Test: Initial: X , Weekly: Bi- Weekly Test Pressure: Rams: 250/3500 - Annular: 250/3500 - Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P - Well Sign P - Upper Kelly 1 P Housekeeping: P Drl. Rig P ' Lower Kelly 1 P - PTD On Location P , Hazard Sec. P Ball Type 3 P - Standing Order Posted P - Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P _ P , Annular Preventer 1 13 3/8 P _ Pit Level Indicators P _ P #1 Rams 1 2 7/8x 5 1/2 P, Flow Indicator P P #2 Rams 1 Blind /Shear P - Meth Gas Detector P - P - #3 Rams 1 2 7/8 x 5 1/2 P _ H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8 P - Inside Reel valves 0 NA HCR Valves 2 3 1/8 P - Kill Line Valves 2 3 1/8, 2 1/8 P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 2900 P _ CHOKE MANIFOLD: Pressure After Closure 1650 P _ Quantity Test Result 200 psi Attained 20 P _ No. Valves 15 P Full Pressure Attained 81 P - Manual Chokes 1 P - Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P - Nitgn. Bottles (avg): 14 ea 2125psi CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 - Test Time: 6.0 Hours Repair or replacement of equipment will be made within 0 clays. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: jim.regg(a7alaska.gov Remarks: Function all components from LER, rig managers office and koomey unit. Test jt size used 4" & 4 1/2" 24 HOUR NOTICE GIVEN YES x NO Waived By Lou Grimaldi Date 3/28/13 ' Time 06:31 Witness Test start 2330 3 -29 -13 Finish 0430 3 -30 -13 Form 10 -424 (Revised 02/2012) 2013 - 0330 _BOP_Parker273_PBU_02- 13B.xisx P1:3a0 „ g,...-..-.--...-_____...,.......,-..........,.. p-f-i) z.0( z.430 ...--„,,„..-„...,...,„.„.■ „...„------ ..,,,,,,,..,=,..„-..,,,.. , . ' I' ' '" , 0 ,, .' " ' " .7„ .. . 10 . .w. _ _'` -"" 7. . . .— . . . . . .. -- •••• ... LI . . . . . .. . . . . ,,, . „ .--- %,.....-,7::". . . . . , .. . . . .W . ■ , , , , . . / #:*/ oo, 0 ... i . .0 . . . . . ram%..==... . . ,.....■=".. . . . . .. . . . . .,'' . . ..444S,k . > , //1 , ,0,1,.....,----....—=......1Wi.."4,_■• .■ A'. A 1,1,:„V•nia.......=..........11,- ,ft.,■,.,4444,,,4i41, 1 0174 ,4 44 z., •- iiiin--::., . • 4\4... \ ‘ \ \ . kill1411 ?3°1212L 1111%144%1 ilk Ilk 111111114114/0* ,crt- 4 %%Ian 111111 1111114% ., 1.M.,, Im a - ' 114 1 mil MI17 1111 11111 I 111111 ° . ,t; t,.14WI , Ina Illinsin .) 1 Millillmi 1111 _ III 1111110„ I t li ii . x x , .#44144vokropuilli4 111 1141 4 -\\\\,.\\,,,,,,:\,\A-0.44,16. • 0.......00v:,404,,,,y.v, t 1 p 4.74NE,SOCO,04$ % / V fiiih ' ■g% ■ • , 4. ' 4 \ Mt ■::* t' * N%- S • 4„.."=-1.50-Aiv* / 4 // „.. ,, - ,......z..&..z:z...4.00,0,. •Y l . N 14 iN ii : 4 4 4. 1. 41% . *M ... ■= . =.11.1 . 10 0/ •/ .0 ' N o . .4 ,..L . ......■..47.M.FROIrAliol; _ 0 ,..4............. ... :::•=21.1_,■=:"..., 1 . '''"'',. .. '...... ., ......:ZO.‘ ..61,, • i OE \ NH l \ • • • Pat o l -13g P'bzd12 430 Parker rig 273 BOPE Test Order 03 -29 -13 Tests= 250 psi low & 3500 psi high for 5 min. each. Test jt. Rig up multiple test joint's / screw in top drive at start. Start BOP test with the smallest test joint for the annular test. ✓ 1. Close: Choke #1, 2, 3, 4 & 15, K #4, dart 4" valve, upper !BOP & Annular Preventer. Open: Everything else. 2. Close: Choke #5 & 6, HCR Kill, HT -38 FOSV #1, & LWCV, Upper 2 7/8" x 5 1/2" VBR Pipe rams. Open: Choke# 2, K#4 & Annular Preventer. Upper 180P, 4" dart valve. / 3. Close: Choke #7, 8 & 9, Manual Kill, & HT -38 FOSV #2, 5" FOSV on test joint. Open: Chok & 6, HT -38 FOSV #IA WCV J 4. Close: Choke#10, 11 & 12, Open: Choke#7, 8 & 9 5. Close: Choke #13 Open: F ke#.12 j 6. Close: Super Choke "A" and manual choke 1500psi. Open: Chc ke##13 '7. Close: Lower Rams, smallest test JT Open: Upper Rams "Unscrew Top Drive & change out Test Joints to largest. 8. Close: Upper Rams on largest test joint & HCR Choke. 9. Close: Manual Choke. Open: HCR Choke 10. Close Lower Rams on largest test joint /test. "PERFORM DRAW -DOWN TEST AS /PER COMPANY REP & RIG MANAGER" 11. "REMOVE TEST JOINT & CLOSE BLIND /SHEAR RAMS & CHOKE #14./TEST. RE: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) • Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 11, 2012 4:18 PM To: 'Rose, John G (ASRC)' Subject: RE: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) John, Sorry I didn't respond to the earlier email. I concur with the added cement plug as proposed. This email will suffice to document the change to the P & A sundry 311 -256. Guy Schwartz Senior AOGCC Petroleum Engineer HE� � g � f 793 -1226 (office) (cell) From: Rose, John G (ASRC) [mailto:John.G.Rose @bp.com] Sent: Tuesday, September 11, 2012 3:58 PM To: Schwartz, Guy L (DOA) Subject: RE: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) Guy, Note the typo in the original e-mail below (see the bold /italic /red print below): Currently reads - "isolation requirements between the top of the Sag River formation and the top of the West Sak formation" Should read - "isolation requirements between the top of the Sag River formation and the base of the West Sak formation" The bottom line is we are placing an additional cement plug on both sides of the tubing string to provide zonal isolation between the top of the Sag and the base of the West Sak. Given this clarification, please advise if you have any issues or concerns with our plan for this P &A /RST on the 02 -13 well as detailed below and thanks for your help. - jr John G. Rose BP Staff Engineer Anchorage, AK rose11@bp.com 907/564 -5271 Office 907/748 -5223 Cell 907/243 -8813 Home 9/11/2012 • RE: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) • Page 2 of 3 • From: Rose, John G (ASRC) Sent: Tuesday, August 28, 2012 3:17 PM To: Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov) Cc: Daniel, Ryan Subject: 02 -13B Sundry (311 -256) & 02 -13C PTD (211 -099) Guy, The 02 -13C RST is currently scheduled as the 3rd well for Parker 273 with a planned spud date of 12/25/12. That being the case, please note the following comments as the relate to the existing 02- 12B Sundry (311 -256) and the 02 -13C PTD (211 -099): A. In addition to the planned cement work as approved per Sundry #311 -256, the P &A plan for the 02 -13B leg of this well has been changed to include some additional cement work above the existing completion packer 8855' MD which involves placing — 1200' of 15.8 class G cement on both sides of the tubing string (from 7240' MD to 8441' MD) to satisfy our DPZ (distinct permeable zone) isolation requirements between the top of the Sag River formation and the top of the West Sak formation (see the revised 02 -13B schematic as attached which provides better detail as to both past and proposed cement work on this well). The revised P &A plan for this well is as follows: 1. F Injectivity Test. 2. F Fullbore P &A (Cement Perfs) with 20 bbls of class G cement. Plan TOC at 8900' MD. 3. F MIT -T to test cement. 4. S D &T cement. Pull DGLV in Sta #1 (8441' MD). 5. F Fullbore P &A (Balanced Plug) with 83 bbls of class G cement. Plan TOC at 7240' MD. 6. S D &T cement. Drift for Jet Cut. 7. E Jet Cut TBG. 8. F CMIT -TxIA. 9. V Set BPV (test from below). B. The PTD (211 -099) for the planned 02 -13C RST was approved on 8/23/11 and as I understand it, it is good for 48 months from issue. That being said and while our current RST plan is still within the scope of this approved PTD, I will advise your office of any significant changes to that drilling plan when and if they develop. Please let me know if you have any questions or concerns and thanks for your help. - jr 9/11/2012 ' RE: 02 -13B Sundry (311 -256 & 02 -13C PTD (211 -099) 411/ Page 3 of 3 • «File: 02 -13B Pre -Rig jr mod.pdf John G. Rose BP Staff Engineer Anchorage, AK rosel 1@bp.com 907/564 -5271 Office 907/748 -5223 Cell 907/243 -8813 Home 9/11/2012 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 41jp • it. Mr. Tom Maunder vs' Alaska Oil and Gas Conservation Commission Co 333 West 7 Avenue q i A Alaska 99501 �� Subject: Corrosion Inhibitor Treatments of GPB DS -02 at I Dear Mr. Maunder, U Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top 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 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -036 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -136 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -176 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02-40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 II • • SIT F E (11 AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02 -13B Sundry Number: 311 -256 Dear Mr. Egbejimba: L& � � A U G ` 4 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /' / Daniel T. Seamount, Jr. Chair DATED this W day of August, 2011. Encl. STATE OF ALASKA RECEJ ^ '""c' A' AUG 16 2011 ■4 ALASKA AND GAS CONSERVATION COMMISS V ,49:/,--// APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Cam �q�! 1. Type of Request: A fC'9r g8 ❑ Abandon - IN Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ® Development ❑ Exploratory 201 - 243 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20433 - 02 - 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 02 -13B - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): - ADL 028308 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11000 - 8986 10917 - 8990 - 9951 None Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" Surface - 76' Surface - 76' 1530 520 Surface 2728' 13 - 3/8" Surface - 2728' Surface - 2728' 4930 2670 Intermediate Production 9109' 9 -5/8" Surface - 9109' Surface - 8371' 6870 4760 Liner 2097' 4 -1/2" 8903' - 11000' 8189' - 8986' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9882' - 9932' 8970' - 8974' 4 - 1/2 ", 12.6# L - 80 8912' Packers and SSSV Type: 9 -5/8" x 4 - 1/2" BKR S - Packer Packers and SSSV 8855' / 8147" 9 - 5/8" x 4 - 1/2" BKR ZXP Packer MD (ft) and TVD (ft): 8911' / 8196' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - *- Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 1, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - I Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Takahiro Kosaka, 564 -5994 Printed Name ohn E. bejimba Title Engineering Team Leader i ce' Prepared By Name/Number: Signature Phone 564 -5859 Date g ig/i, C ommission Use Only � � Elizabeth Barker, 564 -5674 v Conditions of approval_: / Notify • mmis on so that a representative may witness Sundry Number l -,06(c) 0 Plug Integrity Lff BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 3 5 0 0 , , , - - , ,Bop — re -- S f Other: g ^ ) L, Subsequent Form Required: _ 07 , 1:1 APPROVED BY 3/ ( / f Approved By: • COMMISSIONER THE COMMISSION Da Form 10-403 Revi - - < 01 !` 21'.1( Submit In Duplicate ReDMS AUG ; 3 tel OR1G1NAL/4'. • • 0 b P GP . Date: 22 -July -2011 Well Name: 02 -13B Abandonment Sundry Request Well Type: Producer Current Status: 02 -13B is currently shut in. Sundry Request: Approval is requested for the P &A of Prudhoe Bay well 02 -13B. A rotary sidetrack to a new Ivishak target will be performed after the P &A. Well History: 02 -13 was originally drilled in 1980 and completed with 5 -1/2" tubing in 9 -5/8" casing. 02 -13A was CTD side tracked in 1995 to a new bottom hole location and completed with 4" and 2 -7/8" slotted liner. Rig work over was performed to replace leaking 5 -1/2" tubing with 4 -1/2" tubing with production packer. 02- 13B was rotary sidetracked in 2002 with perforations in Z1 B. The well was shut -in for annular communication in Aug 2005. DGLVs were set in March 2006 and the well produced with IAxOA communication managed with bleeds until 2009 when the well was then shut -in for high GOR. In May 2010 an IBP was set at 9951' above all open perfs and 50' of new perforations were shot above the IBP; however, the results were poor and the well was unable to flow naturally. With gas lift, IAxOA communication was not manageable with bleeds. The well was classified as Not Operable and remains shut -in. Reason for Sidetrack: The well requires gas lift to flow; however, IAxOA communication is unmanageable on gas lift. The proposed sidetrack targets Zone 1B wedge reserves in southeastern DS 02 and restore wellbore integrity. In preparation for the upcoming sidetrack, the abandonment request is to squeeze off all perforations and to leave an additional 1000' of cement in the tubing. During the rig sidetrack and after the tubing is pulled, a mechanical plug is planned to be set and tested to provide additional isolation to the Ivishak production zone. There is no Put River sand in the 02 -13B well bore. / Recent History: X CO1C /C. T° Cerre,T- infrre- Pip mf r f 05/13/10: IBP set @ 9958' for profile modification 1 0 e fee ° To �Sohiff tf ":" 05/26/10: Set LGLVs 06/22/10: PPPOT -IC Passed to 3500 psi fire, old The n 2044 rt 06/25/10: OA BUR -50 psi /hr on line with AL 03/08/11: PPPOT -T & IC Both Passed, cycled LDS 1�(' 1 45 PCtVGiAO 41 p, Q 7O 6 03/16/11: Caliper: 4.5" tbg 253 jts 0-27% STS 03/18/11: MIT -IA Passed to 3000 psi, MIT -OA Passed to 2000 psi W by eig r Coo aA 7.0 Pre -Rig Work: (Planned Start Date: 1- September -2011) 1 F Injectivity Test. MIT -IA. MIT -OA fidd ?o 'e4 . R' SH"�' et, 2 0 Install cellar liner. 4.(3 7 4, /ts ►1f 47ri, , 3 W PPPOT -T and IC. Function LDS. �! 4 F Fullbore P &A21 bbl f 15.8 ppg Class G cement. Cement Top at 8600' �,T4 ICI • • MD 5 S D &T TOC. PT Cement to 3500 psi. Pull GLV from Sta 1. 6 F Circ out well. pr 7 E Jet cut at 5400' MD. 8 V Set BPV - 9 F Test BPV Rig Work: (Planned Start Date: 1- October -2011) 1. De- Complete 02 -13B a. MIRU Doyon 25 b. ND tree, NU and test BOPE to 250/3500 psi a. Pull and LD 4 -1/2" completion. • b. RIH with 9 -5/8" clean -out assembly and clean -out to the top of the tubing. ' c. Run GR /CCL/USIT in 9 -5/8" casing to determine KOP & 9 -5/8" casing cut point. d. Set 9 -5/8" drillable squeeze packer -2600' at cemented 9 -5/8" section and test. e. Cut and Pull 9 -5/8" casing. e" f. Run and cement 9 -5/8" Hydril 563 casing with casing patch, ECP, ES Cementer to surface. g. Install 9 -5/8" Slip Lock casing head and a casing spool, NU and test BOPE c. RIH with 9 -5/8" clean -out BHA 74 d. Drill out cement plug, drillable squeeze packer and clean -out to EZSV setting depth 13C e. Set 9 -5/8" EZSV at -5300' and test C 05;41 L f. RIH with 9 -5/8" Whipstock, orient and set Whipstock. f 9` • g. Displace the well to milling fluid. (Following steps for new PTD 02 -13C) 2. Drill 8 -1/2" Intermediate Hole a. Mill a window plus 20' of formation and perform LOT N b. RIH with 8 -1/2" drilling BHA with PWD /DIR /GR /RES /NEU /DEN. PP) c. Drill 8 -1/2" intermediate interval to 7" casing point at the top of Sag River. d. Short trip to THRZ, RIH to TD, circulate wellbore clean O Z -i3C-• 3. Run and Cement 7" Intermediate Casing a. Change to 7" casing ram and test to 250/3500 psi b. Run 7" 26# L -80 VAM TOP HC casing to surface c. Cement 7" casing with 1500' of 15.8 ppg Class 'G' d. Pressure test 7" casing to 3500 psi for 30 minutes. Chart and record. e. Set 7" slips, RILDS and Torque to spec per Cameron. Test 7" pack -off. f. Install new tubing spool g. NU and test BOP 4. Drill 6 -1/8" Production Section a. RIH with 6 -1/8" BHA with DIR /GR /RES /NEU /DEN. b. Displace to drill -in fluid c. Drill out 7" shoe plus 20' of formation and perform FIT. d. Drill 6 -1/8" production hole to TD at Zone 1 B. e. CBU, trip to shoe and back to TD, circulate until clean. MAD pass where required. POH. 5. Run and Cement 4 -1/2" Production Liner a. Run 4 -1/2" 12.6# L -80 VAM TOP liner from TD to 150' liner lap inside the 7" shoe. b. Cement 4 -1/2" liner to TOL with 15.8 ppg Class G cement. c. Set liner top packer, POH and LD liner running tool. d. Pressure test casing and liner to 3,500 psi for 30 minutes. 6. Perforate Well a. RIH and perforate with DP conveyed perforation guns. Intervals to be determined. 7. Run 4 -1/2" Completion a. Run 4 -1/2" 12.6# 13Cr -85 VAM TOP completion to above Put River formation for future perforation in Put River sand. • • b. Reverse circulate to spot corrosion inhibited sea water followed by sufficient diesel for freeze protection. Allow diesel freeze protect to U -tube from IA to tubing. c. Drop ball and rod. Set 4 -1/2 production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Record each test. 8. ND / NU / Rig Release a. Install and test TWC b. ND BOPE, NU Tree and test to 5000 psi c. Pull TWC. Set BPV d. RDMO Attachments: Current Well Schematic Pre -Rig Well Schematic Proposed Well Schematic Contact Drilling Engineer Takahiro Kosaka (907) 564 -5994 Production Engineer Alice Kaminski (907) 564 -5676 Geologist Alec Duncan (907) 564 -4590 •TREE = 5 - /8" GRAY • SAFETY N•: WELL ANGLE> 70 @ 9800' * ** ACTUATOR OR = AXELSON 02-1 3 B ' PRE 02 -13B SDTRCK WELLBORE NOT SHOWN * ** KB. ELEV = 57.6' BF. ELEV = NA KOP= 4300' I I Max Angle = 93 @ 10935' Datum MD = 9641' 2202 —14 -1/2" HES X NIP, ID = 3.813" Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2728' I—A ■ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE J 3 3813 3749 0 MMG DOME RK 16 05/26/10 2 6342 6001 34 MMG SO RK 20 05/26/10 1 8441 7735 32 MMG DMY RK 0 02/13/02 Minimum ID = 3.725" @ 8900' 4 -1/2" HESXN NIPPLE 1 8844' —14- 1/2 " HESX NIP, ID = 3.813° 110-MI ��� 8855' —19 -5 /8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I • 8879' H 4 -1 /2" HES X NIPCA, ID = 3.813" 1 8900' I-14 -1/2" HES XN NIP, ID = 3.725" 1 TOP OF BKR TIEBACK SLEEVE, 10 = 7.50" I 8903' 8911' H4-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958 "I I9-5/8"X4-1/2" BKR ZXP PKR, ID = 6.276" I I 8911' *MI ill 891T 1-14-1/2" WLEG, ID = 4.00" 9 -5/8" X 4 -1/2" BKR HMC HGR, ID = 6.276" H 8919' 1 1 1 9 -5/8" CSG MILLOUT WINDOW (02 -13B) 9108' - 9125' ( OFF WHIPSTOCK ) 1 . PERFORATION SUMMARY '� 9951' — 12 - 1/2" BKR IBP (05113/10) REF LOG: SPERRY SUN MWD DATED 01/26/02 ,.. * * * * * * * *1 ...1111...1 Al- ANGLE AT TOP PERF: 83° @ 9882' 400000 Note: Refer to Production DB for historical perf data 400000 00000* 1r ‘ SIZE SPF INTERVAL Opn /Sqz DATE 4000044 2 -7/8" 6 9882 - 9907 0 05/11/10 4 2 -7/8" 6 9907 - 9932 0 05/10/10 *� 2 -1/2" 4 10020 - 10590 C 02/11 /02 . 4004 4 0 0 0 0 0 4 0 00000* e'Ot 1�t•�������������0 * I PBTD I 10917' ' �� *j *j* • 100000 .. , ••1 ∎/1 ∎� • � 1 14 -1 /2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" —1 11000 1 ( 9 -5/8" CSG, 47 #, L -80, ID = 8.681 " --I 9582' '.0.0'0'0AV DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/20/80 ORIGINAL COMPLETION 05/30/10 OPC/PJC GLV C/0 (05/26/10) WELL: 02 -13B 02/28/95 CTD SIDETRACK (02 -13A) PERMIT No: '2012430 02/13/02 RIG SIDETRACK (02 -13B) API No: 50- 029 - 20433 -02 03/01/02 CH /TP CORRECTIONS SEC 36, T11 N, R14E, 684' SNL & 873' EWL 12/02/05 TEL /PAG GLV C/0 BP Exploration (Alaska) 05/18/10 JDED /SV SET IBP /ADD PERF (05/13/10) TREE = ' 5 -1/8" GRAY III NELLHEAD= _GRAY SAFETY N : WELL ANGLE > 70 @ 9800' * ** ACTUATOR= — AXELSON 02-1 3 B P Le -R PRE 02 -13B SDTRCK WELLBORE NOT SHOWN * ** <B. ELEV = 57.6' <OP = 4300' Max Angle = 93 @ 10935' Datum MD = 9641' ' ' 2202' H4-1/2'' HES X NIP, ID = 3.813" Datum TVD = 8800' SS E still ated TO C - 2150'— 13 -3/8" CSG, 72 #, L -80, ID = 12.34T H 2728' DI GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Jut C ut - 5 4 0 0' 3 3813 3749 0 MMG RK 0 03/18/11 2 6342 6001 34 MMG DMY RK 0 03/18/11 T O C -8600' 1 8441 7735 32 MMG DMY RK 0 02/13/02 I I 8844' — 14 - 1/2" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 8900' 8855' — 19 -5/8" X 4 -1/2" BKR S -3 PKR, ID= 3.875" 4 -1/2" HES XN NIPPLE ' ' 8879' — 14 - 1/2" HES X NIPCA, ID = 3.813" ' ' 8900' —14-1/2" HES XN NIP, ID = 3.725" 8911' — 4-1/2'' TBG, 12.6 #, L -80, .0152 bpf, ID = 3.95W1 TOP OF BKR TIEBACK SLEEVE, ID = 7.50" 1 8903' / \ 8912' l4 -1/2" WLEG, ID = 4.00" I 9 -5 /8" X 4 -1/2" BKR ZXP PKR, ID = 6.276" 8911' 9 -5/8 "X4-1 /2" BKR HMC HGR, ID = 6.276" H 8919' 7-J /0 WV IV°LLV■ I VVIIVIJAJVV kVZ IJO) 010W c:11-.. r r1CC 1AMIDCTrIrI! 1 PERFORATION SUMMARY ` REF LOG: SPERRY SUN MVVD DATED 01/26/02 11.41TOTIVrf1 9951' —12-1/2" BKR IBP (05/13/10) ANGLE AT TOP FERF: 83° @ 9882' ••••••••••1 •••••••••• Note: Refer to Production DB for historical pert data *00000 SIZE SPF INTERVAL Opn/Sgz DATE ••••••••••1 %� ` •••••••••• J 2 -7/8" 6 9882 - 9907 0 05/11/10 ������� 01 2 -7/8" 6 9907 - 9932 0 05/10/10 � * � * � * � � � � � 1 � � � �. • * 2-1/2" 4 10020 - 10590 C 02/11/02 � � � � � � � � � � � 1 � � � � � * � . 1 000001 P BTD H 1 0917' ♦, � A � t � t v � 1� v �v � v ��� ��1 4-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" 11000' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9582 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/20180 ORIGINAL COMPLETION 05/30/10 OPC/PJC GLV C/O (05/26 /10) WELL: 02 -13B 02/28/95 CTD SIDETRACK (02 - 13A) 05/26/11 BSE/PJC GLV C/0 (03/18/11) PERMIT No: "2012430 02/13/02 RIG SIDETRACK(02 - 13B) API No: 50 029 - 20433 - 02 03/01 /02 CI-VTP CORRECTIONS SEC 36, T11 N, R14E, 684' SNL & 873' EWL 12/02/05 TELJPAG GLV C/0 BP Exploration (Alaska) 05/18/10 JDED/SV SET IBP/ADD PERF (05/13/10) TREE= 9 -5/8 Sliplock 1 WELLHEAD = Cameron - A - CTUATOR = AXELSON 02-13C (p iop o se d) KB. ELEV = 57.6' BF. ELEV = NA KOP = — -- _ 4300' as��- Max Angle = 93 Datum MD = 9641' C, Datum TV D = 8800' SS Cementer 1940' 9-5/8" 47# L30 Hyd 563 IECP H 1965' g I I 2200' 4 'X' ID = 3.813" Casing Patch H 2000' , � 2150' - Estnat 13-3/8"C SG 72# L-80 ID = 12347" - 2728' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LTCH PORT DATE 5 3475 3400 4 5965 5200 3 8128 6600 2 9300 7600 1 9992 8200 E stilt acedTOC H 5000' 8501' — TOC (1500'fmm TPTR) 9882' - 4 'X' I D 3.813" 63° @ 6800 9917' - 7 "x 4 1/2 "TNT PKR 9-5/8 "W h4)stock — 5250' ° 9952' - 4 1/2 "'X' ID 3.813" 32 ° @KO P , 9987' - 4 12 "'XN' ID 3.725" 9991' - 9 12 "TBG 12.6# 13C r 93/8 "EVSV H 5300' 10067' - Fhx Lock LNR HGR 10217' "CSG 26# LSO _T=6.151" 0 • Top ofBKR Tbback S beve 1 8903' �� v ' v ' v ' v ' • ' v ' v ' v ' v ' y 9-5/8 "x 4 12"BKR ZXP PKR — 8911' future P utR rerperEs 10001' (8185'TVDss) 10049'(8227'rVD ss) PBTD — 13347' 4 12 "LNR 12.6# L-80 — 13427' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/20/80 ORIGINAL COMPLETION 05/30/10 OPC/PJC GLV C/O (05/26 /10) WELL: 02 -13C 02/28/95 CTD SIDETRACK (02 -13A) 05/26/11 BSE/PJC GLV C/0 (03/18/11) PERMIT No: 02 -138 0 5/13/11 MSE PROPOSED p6 API No: 50- 029 - 20433 -0.7 02/13/02 RIG SIDETRACK ( ) p 03/01/02 CH/TP CORRECTIONS SEC 36, T11 N, R14E, 684' SNL & 873' EWL 12/02/05 TEL/PAG GLV CIO BP Exploration (Alaska) 05/18/10 JDED/SV SET IBP /ADD PERF (05/13/10) ~ • • Note: For 02 -13C RST, BOP stack will be NU on a spacer spool above the existing tubing spool and the diverter as included in this schematic does not apply. ,, 1 , I -R I 1 1 1 1 , N - .1 11 1 1 g , i s , ,' , ` .; -R y . 3 , � , '' I - , -.1 4 �I e 1 ! 1 I 11 1 ril -1 1 , . . I H # II 4 j 1 iI ' t -- a F1 ! +,�+ a . 1 f • 1 . _, z_' w,1 a4 '4 1 a,a, , 1 I a @d x 1i ■ r 1 f . t , 1 n 1 $ 1 v i 13pu \ ' { y a v 1 !WI 171 . _ -- E 1 1 1 i i: I la NOT OPERABLE: Producer 02-13B~D #2012430) OA repressurization urageable by ble... Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~~ ~/t~'I~ Sent: Sunday, June 27, 2010 10:12 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; AK, OPS FS1 Facility OTL; AK, OPS FS1 Ops Lead; AK, OPS FS1 OSM; AK, OPS FS1 OSS Cc: AK, D&C Well Integrity Coordinator; Rico Hernandez, Claudia; Janowski, Carrie Subject: NOT OPERABLE: Producer 02-13B (PTD #2012430) OA repressurization unmanageable by bleeds Attachments: 02-136.pdf; 02-13B TIO Plot 06-27-10.doc All, Producer 02-136 (PTD# 2012430) has been found to have sustained casino pressure due to IAxOA commP unication. The wellhead pressures were tubing/IA/OA equal to 210/140. 0/1160 psi on 06/24/10. After a bleed on 06/25, the OA pressure built up ~50 psi/hr making it unmanageable by bleeds. The well has been reclassified as Not Operable and will remain shut-in until a misting Seal-Tite treatment can be performed to mitigate the IAxOA communication. A wellbore schematic and TIO plot have been included for reference. «02-13B.pdf» «02-13B TIO Plot 06-27-10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 Q~ 133/ " L~ac.7~ ~7Z~P~ ~(~~ ~3~~ 7/15/2010 PBU 02-13B PTD 2012430 6/27/2010 TIO Pressures Plot 4,000 3,000 2,000 1,000 D3/27t10 O4/10!10 04!24/10 We11:02-13 t Tbg -~ - IA -~- OA OOA OOOA On J • 05/08/10 05.22/10 06f05/10 Ofi/19110 TREE= 5-1/8" GRAY WELLHEAD = GRAY ACTUATOR = KB. ELEV = __- BF. ELEV = AXELSON 57.6' NA KOP = 4300' Max Angle = 93 @ 10935' Datum MD = 9641' Datum TV D = 8800' SS SAFETY ES: WELL ANC~E> 70 @ 9800' *** ® ~ PRE 02-1 SDTRCK WELLBORE NOT SHOWN *** 2202' ~--j 4-1 i2" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 272$' Minimum ID = 3.725" ~ 8900' 4-1 /2" HES XN NIPPLE GAS LIFT MANDRELS 5T MD TVD DEV TYPE VLV LATCH PORT DATE 3 3813 3749 0 MMG DOME RK 16 05/26!10 2 6342 6001 34 MMG SO RK 20 05/26/10 1 8441 7735 32 MMG DNIY RK 0 02/13/02 $$Q4' --j 4-1/2" HES X NIP, ID = 3.813" 8$55` 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" $$79' 4-1(2" HES X NIPCA, ID = 3.813" $900' 4-1/2" HES XN NIP, ID = 3.725" $911' 4-1(2" TBG, 12.6#, L-80, .0152 bpf, ID = 3. TOP OF BKR TIEBACK SLEEVE, ID = 7.50" $903' ~ .__..-_ ' " ,,,._,_ ! $g12' ~ L 4-1/2" WLEG, ID = 4.00" 1 8911 9-518" X 4-1 /2" BKR ZXP PKR, ID = 6.276 __ 9-518" X 4-112" BKR HMC HGR, ID = 6.276" 8919' 9-518" CSG MILLOUT WINDOW {02-13B) ~~ 9108' - 9125' (OFF WHIPSTOCK) PERFORATION SUMMARY REF LOG: SI~ERRY SUN MWD DATED 01!26/02 ANGLE AT TOP PERF: 83° @ 9882' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9882 - 9907 O 05(11/10 2-7(8" 6 9907 - 9932 O 05!10/10 2-112" 4 10020 - 10590 C 02/11/02 9-5/8" CSG, 47#, L-80, ID = 8.681" I PBTD 1 9951' ~-{ 2-112" BKR IBP (05!13110) 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" i--i 11000' DATE REV BY COMMENTS DATE REV BY COMMENTS 05!20180 ORIGINAL COMPLETION 05/30/10 OPGPJC GLV C/O (05/26110) 02/28/95 CTD SIDETRACK (02-13A) 02113102 R}G SIDETRACK (02-13Bj 03/01 J02 CH/TP CORRECTIONS 12!02105 TEUPAG GLV CIO 05/18/10 JDEDiSV SET IBP/ADD PERF (05/13110) PRUDHOE BAY UNIT WELL: 02-138 PERM(T No: 2012430 API No: 50-029-20433-02 SEC 36, T11 N, R14E, 684' SNL & 873' EWL BP Exploration (Alaska) STATE OF ALASKA ~'IAY :~ ~ Z~ASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1.Operations epair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Performed: Alter Ca Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development 0 Exploratory ^ 201-2430 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20433-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ` 5 ~'~~ ADLO-028308 PBU 4S.O~B (3 B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11000 feet Plugs (measured) 9960' 5/13/10 feet true vertical 8976.36 feet Junk (measured) None feet Effective Depth measured 10917 feet Packer (measured) 8855 8911 true vertical 8980.49 feet (true vertical) 8157 8207 Casing Length Size MD TVD Burst Collapse Structural Conductor 76 20" 94# H-40 SURFACE - 76 SURFACE - 76 1530 520 Surface 2728 13-3/8" 72# L-80 SURFACE - 2728 SURFACE - 2728 5380 2670 Intermediate 9109 9-5/8" 47# L-80/S-95 SURFACE - 9109 SURFACE - 8383 6870 4760 Production 8150 5080 Liner 2907 4-1 /2" 12.6# L-80 8903 - 11000 8200 - 8976 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# L-80 SURFACE - 8912 SURFACE - 8208 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR ~ 8855 8157 9-5/8"X4-1 /2" BKR ZXP PKR 8911 8207 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~~~ ~,~~ ' "~;',, ~ "-I;~? ~' ~ ~~ I 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 520 34243 36 967 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb a Title Data Management Engineer Signature Phone 564-4944 Date 5/14/2010 0 r~nn iv-vv~ r~cwacu ~icvva • •~V~~~V 1'IAI i I (V~(~~V~%_ ~ ••••••••••• ••.~/ ..,z' t\ SIG /m ~f ~G,?.~s . "~~ ~ ,.. 201-243 PERF ATTA(_NMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-13B 2/11102 PER 10,020. 10,590. 8,965.2 8,980.52 02-13B 4123/09 BPS 8,900. 10,590. 8,197.17 8,980.52 02-13B 5/10110 APF 9,915. 9,940. 8,963.34 8,964.28 02-136 5111/10 APF 9,890. 9,915. 8,961.29 8,963.34 02-13B 5112/10 BPS 8,900. 10,020. 8,197.17 8,965.2 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 02-13B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ' 5/10/2010 *""WELL FLOWING ON ARRIVAL""'"'(ELINE-ADPERF/SET CIBP) ~ INITIAL T/I/O = 2500/275/200, SHUT-IN WELL, LRS KILL WELL WITH 290 BBL CRUDE. PERFORATED 9915'-9940' WITH 2-7/8" HSD POWER JET 2906, 6 SPF, 60 DEG PHASING. DEPTH REFERENCED TO SLB RST DATED 26-MARCH-2009. ABLE TO FALL TO 9865' BEFORE STARTING TRACTOR. ***JOB IN PROGRESS, CONTINUED ON 11-MAY-2010*** 5/10/2010! 5/11 /2010 T/I/0= 2250/260/180 Temp= Hot Assist E-line pump as directed- Freeze protect Flowline with 5 bbls 60/40 MW and 90 bbls crude capped with 1 bbl meth. Load tubing with 325 bbls crude. Turn well over to a-line. Final WHP's= 100/300/280 "E-line has control of well at departure" *""JOB IN PROGRESS, CONTINUED FROM 10-MAY-2010*'`" PERFORATE INTERVAL 9890'-9915', WITH 2-7/8" HSD POWER JET 2906 HMX, 6 SPF, 60 DEG PHASING, API DATA, PENETRATION = 15", ENTRANCE HOLE = 0.39" ATTEMPT TO DRIFT WITH 3.70" GUAGE RING/JUNKBASKET/TRACTOR, SAT DOWN AT 8928' IN WLEG (REFERENCED TO SLB RST DATED 26-MAY-2009). CURRENTLY STANDBY FOR HIGH WINDS. **"JOB IN PROGRESS, CONTINUED ON 12-MAY-2010*** 5/12/2010 *""JOB CONTINUED FROM 11-MAY-2010*** (ELINE - ADPER/SET CIBP) DRIFT TO 9980' WITH 2.80" GAUGE RING AND JUNK BASKET RIH WITH BAKER 2.5" IBP AND WELLTEC 218 XR TRACTOR "***JOB IN PROGRESS AND CONTINUED ON 13-MAY-2010 WSR**"* 5/13/2010***LOG CONTINUED FROM 12-MAY-2010'"**(ELINE - ADPERF/SET CIBP) ;SET 2.5" BAKER IBP AT 9958' MID ELEMENT REFERENCED TO SLB RST- SIGMA LOG DATED 26-MAR-2009 FINAL VALVE POSITIONS: SWAB, WING CLOSED. MASTER, SSV, VALVES PTO GAUGES OPEN. DSO NOTIFIED OF DEPARTURE ` ~ FINAL T/I/O = 0/275/200 PSI ~ I****JOB COMPLETE. WELL LEFT SL**** 3 FLUIDS PUMPED BBLS 4 METH 4 Total I Ktt = 5- IltS" lihtH Y WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 57.6' BF. ELEV = NA KOP = 4300' Max Angle = 93 @ 10935' Datum MD = 9641' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-j 2728` GAS LIFT' MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3813 3749 0 MMG DMY RK 0 12102/05 2 6342 6001 34 MMG DMY RK 0 12!02105 1 8441 7735 32 MMG DMY RK 0 02/13/02 Minimum ID = 3.725" @ 8900' 4-1i2" HES XN NIPPLE TOP OF BKR TIEBACK SLEEV E, ID = 7.50" I 9-518" X 4-112" BKR ZXP PKR, ID = 6.276" 9-5/8" X 4-112" BKR HMC HGR, ID = 6.276" 8911' 8~~ PERFORATION SUMMARY REF LOG TCP PERF ANGLE AT TOP PERF: 90 @ 10020' Note; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 4 10020 - 10590 O 02!11/02 SAFETY~ES: WELL ANGLE> 70° @ 9800' & > 90° 42 -13 B @ 10123'. PRE- 02-13B SDTRCK WELLBORE NOT SHOWN 2202 4-112" HES X NIP, ID = 3.813" $$~-~4-1/2" HES X NIP, ID = 3.813" I $$55' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" $$7g' ~ 4-1/2" HES X NIPCA, ID = 3.813" 8900' -14-112" HES XN NIP, ID = 3.725" I $911 ` 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" $912' 4-1/2" WLEG, ID = 4.00" 9-5/8" CSG MILLOUT WINDOW (02-13B) T~ 9108' - 9125' (OFF WHIPSTOCK) ;~: ,w (~P ;~:~` ~~t PBTD ~-{ 10917' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I-j 11000' 9-5/8" CSG, 47#, L-80, ID = 8.681" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/20/80 ORIGINAL COMPLETION 06/16/03 JA/KAK WANERSAFETYNOTE 02128/95 CTD SIDETRACK (02-13A) 09124/05 FZLtTLH WAN ER SFTY NOTE DELETED 02!13/02 RIG SIDETRACK (02-13Bj 12/02/05 TEL/PAG GLV Cl0 03101!02 CHITP CORRECTIONS 11/08!02 KB/tlh WANER SAFETY NOTE 06!11103 CMOCTLP KB ELEVATION CORRECTION PRUDHOE BAY UNIT WELL: 02-13B PERMf f No: 1012430 API No: 50-029-20433-02 SEC 36, T11 N, R14E, 684' SNL & 873' EWL BP Exploration (Alaska) 05/14/09 !, i I! Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5235 Company: State of Alaska _~~, ~ ,1, ",- r ~;;-~ Alaska Oil & Gas Cons Comm ;~~~ `ti"~"~,~, , _ `-'~= ~ ~ ~~'~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Loa Description Date BL Color CD Z-06 AP3O-00035 STATIC PRESSlrEMP SURVEY 04/25/09 1 1 E-07A AYOO-00022 SCMT _ 04/24/09 1 1 V-04 AWJB-00031 MEM GLS -( 03/24/09 1 1 Y-16 AZ4D-00015 USIT (~ --p Ob 05/06/09 1 1 07-16A B2WY-00002 MEM CBL O 04/29/09 1 1 J-O6 ANHY-00009 PRODUCTION PROFILE (3U 05/08/09 1 1 R-21 AVYS-00038 LDL / -( ~ / v 05/02/09 1 1 18-01A B2WY-00003 MEM CBL ~9w -(~ 05/01/09 1 1 13-03 AYKP-00018 SCMT ~'.~~. ®(o~ ! a l a 05/01/09 1 1 4-04A/T-30 BOCV-00014 SCMT ~ 04/27/09 1 1 03-09 AXOY-00007 MCNL ..0~ 6~`j 12/13/08 1 1 K-16AL2 AXIA-00009 MCNL 01/10/09 1 1 02-13B AWL9-00028 RST 03/26/09 1 1 C-03B AVY5-00040 RST " - ) 05/05/09 1 1 YLtA,t AI:RIVUWLtUIat tttV tlY1 CT ,Ita1VIlVla AIVU tltl Vti1V11V1t VIVt t:VYT tX4~rl 1 V: BP Exploration (Alaska) Inc. ~ ~ Petrotechnical Data Center LR2-1 ,;~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ZQ~)g Date Delivered: ~~ 'iii ", "~~ y~~ti~~t®re / ~1~ (~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 838 ATTN: Beth 1 Received by . . MICROFilMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc i Date: September 12, 2005 ~ To: File ~~ ~" From: Jane Williamson ~~ Subject: Prudhoe We112-13B L g Term SI Prudhoe we112-13B has sustained casing pressure on the outer annulus and BP has cancelled their internal waiver for production. Attached are plots of production history and decline analysis for the subject well. DS 2- 13B was a good producer (over 700 BOPD) until early this year when the production dropped dramatically. The GOR was over 50,000 scf/STB when last produced. The reason for the precipitous decline was not provided. Decline analysis suggests no remaining reserves in the well. The well has little utilization with its current completion. No action is necessary. 10~ PRUDHOE BAY, PRUDHOE OIL PBU_DS2 PRUDHOEBAY 02-13B 04 02-1 38 ~ Oll Rate )cD) (Mbblle ) ~~ Wader Rata (CD) (MDDI/tl ) ~~ Ges Rate (CD) (MM[t/tl ) ~ cua, ou a~oe (MMbbi ) ~ Ges /Oil Ratio) Mcflbbl ) -~~~-~---- Water CUt ~~ ~~ `~~~~ t~~ , 0 ~0 ~~~ ~~~__ 103 ~~4: 10s 2002 03 ~5 Date Oil Rate (CD), bbl/d 0 8 TIT~~~~~J~~~,7~p'Y~ Q~~~ i4(~D Q fD F~- ~ fD .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ~c,~~~¢~cs8~~~oo O ~ R3~~~~~~~ ~_ ~~ ~O ~ Q r • ~ 02-138 (PTD #2012430) Classified as Problem Well ( Subject: 02-13B (PTD #2012430) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Tue, 09 Aug 2005 10:54:33' -0800 TO~·.·'~~1Jail)~An:deanj~~·,c~~r~"~:~·;-I!~ljSIP/$~~~~~1~(}~*~S1.~~B~·c?mIT~;!¿Jt2ef1 ".G..· PB;~SlpS,'Qp..... sL~ad..n<GP.I3F..,S.i.l~S. ~(). p.....s....Lëaê~B. >p.'. ...Ç?Il1:>"'."~()s~berg;... ~iête.v7P"·:i.:...·':.'.....·...·.··......'·....·..'.·:.....'...'."..;",;\. ~ \0\ Oš <DossbeDC@D"D com...... 'Nc,U A.T\UT uTell' nne~atlons Supenl1sor ,., .:,:,'....:.':,..'.'.....,-.'.-:..,:.,;:,,:.',:.'.>:.).';' ....JX:.........·............~ð,J:),':';':i.....'~·.·Q',~VV<i~~.·:':'J:if:·.,....,·..:....~;.i·~J>·;,:i'~.,".,'.·.··.· .. " .' " . . <NSUAÐWW ellOþerationsSupervìsor@BP.cöm>;· "GPB~WellsOptErig'" <GPBWellsOptEng@BP.com>, "AOGCC Jim:Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOaCC'Winton Aubert (E~mailY' <winton_aubert@admin.state.ak.us>, "NSU; ADW WL & ' CompletionSllp~rvisor" <NSU.ADWWL&.ç0n.1pletionSupervisor@BP.com>, "GPB~ FSl DS2, . Operator" <GPBFS 1 DS20perator@BP~com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com> All, Well 02-138 (PTO #2012430) has been found to have sustained casing pressure on the OA and has been classified as a problem well. The TIO's on 08/08/05 were 2220/2000/2070. The well is a natural flow producer currently waivered for TxlAxOA communication with a MAASP of 2000/2000 on the IA & OA but cannot be maintained below these limits. The plan forward for this well is as follows: 1. WIE/APE: Consider secure options 2. WL: Secure well ~-- tÇ'~"^ J:' \ì'>.\!!;'\\!\E ¡\ .' ~~'i;,fl.l~~:':I~ ,\....., .... I;:, -1 2'· n n¡:;1 (.: )i.. ....,.". '-' A wellbore schematic has been included for reference. Please call if you have any questions. «02-13B.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-51 02 907 -659-51 00 #1923 pg r Content-Description: 02-13B.pdf ., !02-13B.pdfi Content-Type: application/octet-stream :. . Content-Encoding: base64 ~ SdP MsYP q~ "-try? ~~O~i 6010 ~~ ZCI. i if4. 2ò 7Dps" 53£.Dr¡ 3~.s% ----;;> OA '-;:> v~- pe- pXSsuv-.e... '~~'3~(ds 4\ Co4C{z· ) 'TJ<>1J, ,,{)ft. r ~'lt I ~s ~ p& Bf pðl.~ ;SK~{'lh/DS' 1 of 1 8/10/2005 3 :36 PM 1REE= WELLHEA 0 = ACTUAlDR= KB. B..EV = BF. B..EV = KOP= Max Angle = !:atum MD = !:atum lVD = 5-1/8" GRAY GRAY AXB..SON 57.6' NA 4300' 93 @ 10935' 9641 ' 8800' SS 113-318" CSG, 72#, L-80, 10 = 12.347" 1-1 Minimum ID = 3.725" @ 8900' 4-1/2" HES XN NIPPLE ITOPOF BKRTIEBACK SLEEVE, 10= 7.50" 1-1 19-5/8" x 4-1/2" BKR ZXP A<R, 10 = 6.276" 1-1 19-5/8" x 4-1/2" BKR HMC HGR, 10 = 6.276" 1-1 PERFORA 1l0N Sl1JIl\N\ RY REF LOG: TCP PERF ANGLEA TTOP PffiF: 90 @ 10020' Note: Refer to Production DB for historical perf data SIZE SPF IN1£RVAL Opn/Sqz DATE 2-1/2" 4 10020-10590 0 02/11/02 I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9582' OA. TE 05120/80 02128/95 02/13/02 03/01/02 11/08/02 06/11/03 REV BY COrvrJlENTS ORK3INÞ. L COMPLETION CTD SIDElRACK (02-13A) RIG SIDETRACK (02-13B) CI-VTP CORRECTIONS KB/tlh WAfIIER SAFETY NOTE CMO/TLP KB ELEVATION CORRECTION 2728' 8903' 8911' 8919' 02-138 r ~ -b z I ~ l ~ t ~ 0A.1£ REV BY COMMENTS 06/16/03 JA/KAK WAfIIER SA FETY NOTE SAFETY NOTES: ***T X IA X OA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI; MAX OAP = 2000 PSI. (06/16/03 WAIVER)*** WELL ANGLE> 70° @ 9800' & > 90° @ 10123'. PRE-02-13BSDTRCKWB..LBORENOT SHOWN 2202' 1-14-112" t-ESX NIP, 10=3.813" I ~ ST MD NO 3 3813 3749 2 6342 6001 1 8441 7735 GAS LIFT MA NDRELS DEV TY Æ VL V LA TCH PORT o MWG DOME RK 16 34 MWG S/O RK 20 32 MWG DV RK 0 OA. 1£ 02/23/02 02/23/02 02/13/02 8844' 1-14-112" HES X NIP, 10 = 3.813" I 8855' 1-19-518" X 4-1/2" BKR 5-3 A<R, 10 = 3.875" 8879' 1-\4-112" HES X NIPCA, D = 3.813" 8900' 8911' 8912' 1-14-112" HES XN NIP, 10 = 3.725" I 1-14-112" lEG, 12.6#, L-80, .0152 bpf,lD = 3.958"1 1-14-112" \/VLEG, D =4.00" I 9-5/8" CSG MlLLOUTWlNDOW (02-13B) 9108'- 9125' (OFFWI-IIPSTOCK) I PBTD 1-\ 10917' I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10= 3.958" H 11000' I PRUDHOE BA Y UNIT WELL: 02-13B PffiMIf No: 2012430 A A No: 50-029-20433-02 SEC 36, T11 N, R14E, 684' SNL & 873' 8JVL BP Exploration (Alaska) t ) WELL: ~ WELL TYPE: Producer - Natural Flow Notice of Waivered Well DATE: 06-16-<13 Production Data: 05103103: 628 BOPD, 0 BWPD. 41,674 GOR. Pressures: Flowing 81 Tubing 1125 psi 2300 psi 9-518" ANN 1300 psi 1670 psi REASON FOR NOTICE: T X IA X OA Communication TUBING BY 9-518" COMMUNICATION? YES · TIFL Passed - 5/3103. · NFT-IA Passed· 6115103. Final rate was 120 selthr. 9-518" BY 13-318" COMMUNICATION? YES · MIT-OA Passed to 3000 psi· 6115103. . PPPOT-T Passed - 6112/03. IMPORTANT CONSIDERATIONS I COMMENTS: 13-318" ANN 820 psi 980 psi xx ,.NO · 2 Levels of Protection are the passing NFT and the surface casing has been tested to at least 1.2 times the maximum operating pressure. · This supercedes the waiver dated 11/2/02. xx NO PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group and the Operations Manager. · Monitor well head pressures;md log dally. · Perform the following waiver compliance testing: .~ Annual passing NFT. i Annual MIT-OA to·30oo psi w/ fluid levels. ,~ fA. , ~ 611'1/03 v.:ell ~t~,~lneer , Date ~ ~,Yï.... 6:tA'ßr.k ,¡nIb' ell ope~ns ~upel:VlsOr bate ~ I j U p/ç, lussheYq raJ¡K)3 B Well Operations I Workover M'n~ger ..J Ó~te Dl8trlbuUon: . DB I Pad Operator DS I Pad Engineer WOE Operating Limits Max lAP.. 2000 psi Max OAP .. 2000 psi 11 it '- i. 1"'t\ ~ ðw,.. G..J œ=.,~. .T~Lesde' ø~-. Operations Ma~~ t //'1/0'3 J' cite C7'/-ø.3 Cate ~ /""""'.., cfO I--~YS 18-Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 2-138 Dear Dear Sir/Madam: ~ Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,093.60' MD Window / Kickoff Survey 9,105.00' MD (if applicable) Projected Survey: 11,000.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) FEB 2 0 2002 AIa8k8 at & Gas Cons. Commi88Ioo Anchorage 1 5- M~ ;(. Ò-\l '1 DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012430 Well Name/No. PRUDHOE BAY UNIT 02-13B Operator BP EXPLORATION (ALASKA) INC MD 11000 ~- UIC N TVD 8976 /" Completion Date 2/13/2002 ~ Completion Status 1-01L Current Status 1-01L S IAlo A yJ J~ ~ ~'it.- API ~~029-20433-02-00 REQUIRED INFORMATION Mud Log No Samples No Directional Survey G;;)--- ~ --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt i Rpt JÆóD ¡ fED ¡ED C Asc C Pdf ED C Pdf C Pdf C Pdf !lED r ED ED ED C Pdf C Pdf Electr Dataset Number Name .. .. . . ..LI$VøtffiÇå(iOO....... ...If' 1467Ûà:vèrifi~íìóiii' Log Log Run Scale Media No 1 1 2,3 Final 1994ï.J$\¡f~riftèåt1on 11994111duçiïç~ø~$t1V.itý1 25 25 25 Final Final 25 Final 25 25 Final Final Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y I~ Chips Received? ~ Analysis Received? Daily History Received? Formation Tops Y/N (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received 9080 1 0941 Case 1/9/2003 9080 1 0941 Case 1/9/2003 , 9039 11000 Open 6/2/2003 9108 11000 Open 6/2/2003 9108 9108 9108 8976 Open 6/2/2003 11000 Open 6/2/2003 8976 Open 6/2/2003 -.".. Comments MWD-ROP, DGR, EWR- MD MWD-DGR, EWR-TVD MWD-DGR, SLD, CTN-MD MWD-DGR, SLD, CTN- TVD MWD-DGR, SLD, CTN-MD MWD-DGR, SLD, CTN- TVD ,~ Comments: 9108 9108 11000 Open 6/2/2003 8976 Open 6/2/2003 Sample Set Number Comments f)N (j)N DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012430 Well Name/No. PRUDHOE BAY UNIT 02-13B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20433-02-00 MD 11000 NO 8976 Completion Date 2/13/2002 Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: ~ Date: ~ -; ~- ~ y -", ,,~,~ r , ( dO\ -ðL13 \ \ ~ 9 kt WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage,AJaska 99501 May 20, 2003 RE: MWD Formation Evaluation Logs: 02-13B, AK-MW-22008 02-13B: Digital Log Images 50-029-20433-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign ;J~C") \. ~~ ,~---O ~~~ Date: f-'~I""""C ~ .'",:w, , ~ ~iL: IVED JUN 0 2 2003 Alaska oa (~ G8j~ CiJm~. CŒl1mi~n l\ndlcrage ~~~M~ ( (' ólO/-d.'-/3 I I CflQ 7 WELL LOG TRANS:MITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska January 07, 2003 RE: MWD Formation Evaluation Logs 02-13B, AK - MW - 22008 I LDWG formatted Disc with verification listing. API#: 50-029-20433-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. ~chorage, Alaska 99508 Sign~ ~ Date: RECEIVED JAN 0 9 2003 AlSIira 011 " Gas ~~ ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-243 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20433-02 4. Location of well at surface ^-, :" :.. ~ f~~. .~{ 9. Unit or Lease Name 684' SNL, 873' EWL, SEC. 36, T11 N, R14E, UM " ',":. '.'ii; I Prudhoe Bay Unit At top of productive interval ~ ;\;, ".: ¡ . ~ 930' SNL, 3184' EWL, SEC. 36, T11N, R14E, UM ~ ,~,:.l3:Þ.,Z¡ ~S.,;~.".. ".' 10. Well Number At total depth ¡ \.:~'::':",.:) \ ," ~ 02 13B 640' SNL, 2068' EWL, SEC. 36, T11 N, R14E, UM ~ '~'" ",iP, ,': t' " . ....,;,...:;,'7!5,: - >""""""."" 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 57.60' ADL 028308 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/31/2002 2/812002 2/13/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 11000 8976 FT 10917 8980 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, DEN, NEU, RES 23. CASING SIZE 20" 13-3/8" 9-518" 4-1/2" Classification of Service Well 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2202' MD 1900' (Approx.) WT. PER FT. 94# 72# 47# 12.6# GRADE H-40 L-80 L-80 I S-95 L-80 CASING. LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 76' 30" 31 sx Arcticset II Surface 2728' 17-1/2" 300 sx Fondu, 400 sx PF II Surface 9109' 12-1/411 1335 sx Class 'G' 8903' 11000' 6-1/8" 310 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/211 Gun Diameter, 4 spf MD TVD 10020' -10590' 8965' - 8981' 25. SIZE 4-1/211, 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 8912' PACKER SET (MD) 8855' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected 27. Date First Production February 23, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA~:5r,~~~,[:¡::'ií.:\ /'1""";;""'\ Brief description of lithology, porosity, fractures, apparent dips and presence&bNf'!1: ~~wate'r:/ Submit~~core chips. OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. 1'1° f11T"'\ ~.'.'" "1 "',' '."" -r" Vi¡JI,lh; ,;:; i: lLiU¿ l\""'r'~".') rw ~ I"'\l,d,j~',~:" ".,;C i.". (;n:'1S.:I:,,;;,: ',.,'Iì ,. Form 10-407 Rev. 07-01-80 <""'\ ff'.'\ ~ t'" g \1\ I ^ ¡ tJ t~\ I~ tJ ~ ~'~ i~-\ Cor: RBDMS BFl ~ i'f~b~ Duplicate ( i ~, 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit 9209' 8475' 23SB 9552' 8795' 22TS 9622' 8848' 21TS 9689' 8890' Zone 1 B 9843' 8953' , ' ',' ",I "I " c' -' .,-.. ('- ",-; ",,; ,:( ¡111.i 0"',," ,.,'" 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant Date 03. ~1. 0 02-13B Well Number 201-243 Permit No.1 A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 (""", r,,"' '~ ","""'~ ~ ~,', 1'1'( i i \, II 1: ," "f,: ." : ¡:~,:!:""'::",~'!,".v,'I:,\,""\' > ' I \ ~ If. ~' \:': i ,,~. ' """i"l'h\""",,"'<~i\.i; \'.~.., Legal Name: Common Name: . I Test Date 2/1/2002 02-138 02-138 SÜrfâêêPfesšure 915 (psi) FIT 9,125.0 (ft) 8,366.0 (ft) 8.40 (ppg) leak Off Pressure (BHP) 4,566 (psi) Page 1 of 1 EMW 10.51 (ppg) ---. Printed: 3/20/2002 2:44:49 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/21/2002 1/22/2002 ( ( Page 1 of 12 BP EXPLORATION Operations Summary Report 02-138 02-138 DRILL +COMPLETE DOYON DOYON 16 06:00 - 08:00 From - To Hours Activity Code NPT Phase P Date 08:00 - 09:00 09:00 - 09:30 09:30 - 14:00 14:00 -15:30 15:30 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 05:00 05:00 - 06:30 06:30 - 09:00 09:00 - 10:30 10:30 - 12:00 12:00 - 12:30 12:30 -15:00 2.00 MOB PRE 1.00 MOB 0.50 MOB P P PRE PRE 4.50 MOB P PRE 1.50 MOB P 2.50 MOB P 2.00 WHSUR P PRE PRE DECOMP 2.00 WHSUR P DECOMP 0.50 WHSUR P DECOMP 1.00 WHSUR P DECOMP 0.50 WHSUR P 2.00 WHSUR P DECOMP DECOMP 3.00 BOPSUF P DECOMP 1.50 BOPSUR P 2.50 BOPSUR P DECOMP DECOMP 1.50 WHSUR P DECOMP 1.50 PULL P DECOMP 0.50 PULL DECOMP P 2.50 PULL P DECOMP Start: 1/22/2002 Rig Release: 2/13/2002 Rig Number: Spud Date: 1/22/2002 End: 2/13/2002 Description of Operations PJSM. MOVE RIG OFF WELL. CLOSE CELLAR WALL, RID FLOOR & HOISTS. PJSM. LAY OVER DERRICK. SAFETY MEETING W/ REGARD TO RIG MOVE, ROUTE OF TRAVEL & ASSOCIATED HAZARDS. SECURITY, ELECTRICIANS & TOOL SERVICE PRESENT. MOVE RIG F/ OS 13 TO DS 02 THRU DEADHORSE & EAST CHECKPOINT. RAISE DERRICK & RIG UP FLOOR. SPOT & LEVEL RIG. TAKE ON SEAWATER & COMPLETE FULL DERRICK INSPECTION W/ REGARD TO POTENTIAL FALLING OBJECTS. RIG ACCEPTED @ 1800 HRS, 01-21-2002. RIG UP CIRCULATING MANIFOLD. CHECK PRESSURES, OA, IA & TUBING ALL ZERO PSI. RIG UP DSM & PULL BPV. SAFETY MEETING WITH REGARD TO LINES, VALVE ALIGNMENT & GOOD FLUIDS MANAGEMENT PRACTICES. DISPLACE OUT FREEZE PROTECT FLUID BY PUMPING SEAWATER DOWN THE I/A, TAKING RETURNS UP THE TUBING, (60 BBLS), & PUMPING DOWN THE TUBING, (200 BBLS), DISPLACING FREEZE PROTECT FLUID OUT OF THE IIA. SET BPV. HELD PJSM. N / 0 TREE AND ADAPTER FLANGE. CHECKED TUBING HANGER THREADS. HELD PJSM. N / U BOPE. PRESSURE TESTED CHOKE MANIFOLD AND VALVES TO 250 PSI LOW - 5 MINUTES, 3,500 PSI HIGH - 10 MINUTES. ALL TESTS HELD w/ NO PRESSURE LOSS OR LEAKS. FUNCTION TESTED BOPS. P / U AND TORQUED UP KELLY. R / U TO TEST BOPE. HELD PJSM. TESTED BOPE. TESTED UPPER PIPE RAMS, ANNULAR, VALVES, HCR, KILL LINE, CHOKE LINE TO 3,500 PSI HIGH /250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. WILL TEST LOWER PIPE RAMS & BLIND RAMS AFTER PULLING 51/2" TBG, OK'd WITH AOGCC. TESTED LEL AND H2S GAS ALARMS, LOU GRIMALDI w/ AOGCC WAIVED WITNESSING TEST. HELD PJSM. R / U DSM LUBRICATOR, PULLED BPV, R /0 DSM. HELD PJSM. M / U 1 JOINT OF 5" DP, TIW AND XO TO TUBING HANGER. SCREWED INTO TUBING HANGER THREADS. CHECKED lA, NO PRESSURE, BACKED OUT LOCK DOWN SCREWS. N / 0 CONTROL LINES AT WELLHEAD. HELD PJSM. PULLED ON TUBING STRING, TUBING HANGER BROKE FREE AT 250,000# OF PULL. CONFIRMED HANGER AND TUBING STRING FREE. R / U AND CIRCULATED WELL ONE COMPLETE CIRCULATION. PUMP RATE 6 BPM, SPP 500 PSI. NO GAS AT SURFACE. SHUT DOWN PUMP AND OBSERVED WELL, Printed: 2/20/2002 11 :25:22 AM ( (' BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/22/2002 12:30 -15:00 2.50 PULL P DECOMP WELL STATIC. 15:00 -15:30 0.50 PULL P DECOMP PULLED TUBING HANGER TO FLOOR, STRING WEIGHT 155,000#. BROKE OUT AND L / D 5" DP AND XO. BROKE OUT AND L / D TUBING HANGER. 15:30 - 00:00 8.50 PULL P DECOMP POOH, L /05-1/2" TUBING AND SSSV ASSEMBLY. SPOOLED UP CONTROL LINES. RETRIEVED 27 CONTROL LINE CLAMPS. 1/23/2002 00:00 - 03:30 3.50 PULL P DECOMP HELD PJSM. POOH, BREAK OUT AND L /05-1/2" TUBING. TOTAL L / 0 208 JTS 5-1/2" 17# TUBING, SSSV, SLIDING SLEEVE, SEAL ASSEMBLY. CHEMICAL CUT IN TUBING JOINT 40%. (4) HOLES IN JT# 97. 03:30 - 05:00 1.50 BOPSUR P DECOMP HELD PJSM. M / U TEST JOINT AND TEST PLUG. RAN AND SET TEST PLUG AND PRESSURE TESTED LOWER PIPE RAMS AND BLIND RAMS. 3,500 PSI HIGH - f/1 0 MINUTES / 250 PSI LOW - f/ 5 MINUTES. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. 05:00 - 05:30 0.50 BOPSUR P DECOMP PULLED TEST PLUG. RAN AND SET WEAR BUSHING. 05:30 - 06:30 1.00 PULL P DECOMP CLEARED RIG FLOOR. FINISHED LOADING 5" DRILL PIPE AND FISHING TOOLS INTO PIPE SHED. 06:30 - 07:30 1.00 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-3-1/2" SPEAR w/ "GS" TOOL - XO - 1 JOINT 2-7/8" PAC DP - XO - XO - BUMPER SUB - DRAIN SUB. BHA LENGTH 50.97'. TOP OF FISH 8,950'. 07:30 - 08:00 0.50 PULL P DECOMP SERVICED RIG. 08:00 - 12:00 4.00 PULL P DECOMP RIH w/ BHA P / U AND DRIFTED 5" DP. 12:00 - 12:30 0.50 PULL P DECOMP HELD PJSM. SERVICED RIG. 12:30 - 20:30 8.00 PULL P DECOMP RIH w/ BHA P / U AND DRIFTED 5" DP. RIH TO 8,863'. 21 :00 - 22:00 1.00 PULL P DECOMP SLIP & CUT 57.5' OF DRILLING LINE. 22:00 - 23:30 1.50 PULL P DECOMP PICK UP/ MAKE UP KELLY. PT UPPER & LOWER KELLY VALVES, 250/3500 PSI, 5/10 MINUTES, OK. WASH DOWN TO 8917'. 194K UP WT, 177K DOWN W/ PUMP OFF. 23:30 - 00:00 0.50 PULL P DECOMP CIRCULATE BOTTOMS UP, 5 1/2 BPM/2000 PSI SPP. SMALL AMOUNT OF GAS BUBBLING UP AFTER 225 BBLS PUMPED, (COMBUSTIBLE), 15-20% OF LEL @ BELL NIPPLE, NO FLOW. (4) HOLES IN JT # 97 @ 4125' OF COMPLETION STRING. 1/24/2002 00:00 - 02:00 2.00 PULL P DECOMP CONTINUED TO CIRCULATE BOTTOMS UP. PUMP RATE 4.25 BPM, SPP 2,000 PSI. SMALL AMOUNT OF GAS & CEMENT/GEL BACK. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. APX 100 BBlS OVER. 02:00 - 02:30 0.50 PULL P DECOMP SHUT DOWN PUMP. CHECKED PARAMETERS STRING WEIGHT UP 194,000#, STRING WEIGHT DOWN 180,000#. TAGGED FISH AT 8,954'. ENGAGED GS FISHING TOOL INTO GS FISHING NECK ON 4" LINER. SET DOWN 10,000#, PICKED UP 30' w/ 5,000# - 10,000# OF DRAG. 02:30 - 05:00 2.50 PULL P DECOMP PUMPED AND CIRCULATED AROUND 25 BBL HI-VIS SWEEP. PUMP RATE 5 BPM, SPP 1,800 PSI. RETAGGED BOTTOM TO ENSURE LINER ENGAGEMENT. BLEW DOWN AND RACKED BACK KELL Y. 05:00 - 10:00 5.00 PULL P DECOMP POOH w/5" DP. 10:00 -10:30 0.50 PULL P DECOMP BROKE OUT AND L / D BHA. 10:30 - 11 :30 1.00 PULL P DECOMP BROKE OUT AND L / D 4" LINER. RECOVERED 3 JTS AND 1 CUT JOINT. 128.61'. 100% RECOVERY. Printed: 2/20/2002 11 :25:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/24/2002 1/25/2002 ( ( Page 3 of 12 BP EXPLORATION Operations Summary Report 02-138 02-138 DRILL +COMPLETE DOYON DOYON 16 11:30 -12:30 From - To Hours Activity Code NPT P Date 12:30 -15:00 15:00 - 18:30 18:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 09:00 Phase 1.00 PULL DECOMP 2.50 PULL DECOMP P 3.50 PULL DECOMP P 2.50 PULL DECOMP P 1.00 PULL P DECOMP 2.00 PULL 2.50 PULL 1.00 PULL P P P DECOMP DECOMP DECOMP 0.50 PULL DECOMP P 2.00 PULL 0.50 PULL 2.50 PULL DECOMP DECOMP DECOMP P P P Start: 1/22/2002 Rig Release: 2/13/2002 Rig Number: Spud Date: 1/22/2002 End: 2/13/2002 Description of Operations CLEARED AND CLEANED FLOOR, HELD PJSM, SERVICED RIG. HELD PJSM. MADE UP FISHING BHA-5-3/4" DOUBLE SPEAR w/5-7/8" GRAPPLES - EXTENSION - STOP SUB- XO - BUMPER SUB - 6-114" OIL JARS - XO - 9 X 6" D.C. - XO - ACCELERATOR JARS BHA LENGTH 319.09'. RIH w/ BHA ON 5" DP TO 8,909'. M / U KELLY ON 90th STD & 1 SNGL. PARAMETERS STRING WEIGHT UP 212,000#, STRING WEIGHT DOWN 180,000#, ROTATING WEIGHT 199,000#. STARTED PUMP @ 3 BPM, 150 PSI. HELD PJSM. SLACKED OFF, SAW INCREASE IN PUMP PRESSURE 29' IN ON KELLY@ 8,938'. CONTINUED DOWN, BEGAN TAKING WEIGHT w/38' OF KELLY IN HOLE. TOP OF PBR @ 8,937' DPM. SET DOWN 30,000# TO ENGAGE SPEAR, PICKED UP TO 240,000#, BLED OFF JARS. SLACKED OFF TO 210,000# (11,000# OVER ROT WT). ROTATED RT 5 TURNS, TORQUED TO 7,500 FT-LBS, LOST TORQUE & WT. SLACKED OFF AND SET DOWN 20,000#, PICKED UP, NO OVERPULL. SPEAR RELEASED, (RT HAND RELEASE, LEFT HAND TO RE ENGAGE). SET DOWN 15,000# & ROTATED LEFT 2 TURNS TO RE-ENGAGE SPEAR. WORKED PIPE & P / U TO 240,000#, BLED OFF JARS & ROTATED 5 TURNS, LOST TORQUE & WT AS BEFORE, P / U NO OVERPULL. SET DOWN 20,000# AND TURNED LEFT 3 TURNS TO RE-ENGAGE SPEAR, P I U AND JARRED 3 TIMES @ 275,000#, OVERPULLED TO 320,000#, SLACKED OFF TO 230,000# AND ROTATED RT 5 TURNS, 9,000 FT/LBS, LOST WT & TORQUE, P / UTa 250,000#, SPEAR STILL ENGAGED. SLACKED OFF TO 235,000#, ROTATED RT 6, LOST TORQUE & WT, PI U TO 270,000# SPEAR STILL ENGAGED, SLACKED OFF TO 235,000#, ROTATED RT 7 TURNS, 12,700 FT-LBS, LOST TORQUE & WT. PICKED UP w/ NO OVERPULL. SLACKED OFF w/ PUMP ON, SAW PRESSURE INCREASE 29' IN ON KELLY AS BEFORE, SET 30,000# ON FISH w/41' IN ON KELLY, P / U AND JARRED 3 TIMES AT 270,000#, PULLED TO 320,000# AND SLACKED OFF TO 235,000#, ROTATED RT 12 TIMES, TORQUE 19,000 FT-LBS, LOST TORQUE AND WT. CIRCULATED BTMS UP, PUMP RATE 9 BPM, 700 PSI SPP. H2S DRILL & BOP DRILL WHILE CBU. WELL STATIC. POOH WI 5" DP. HELD PJSM. POOH w/5" DP. POOH w/ BHA. BROKE OUT AND L / D FISH, PBR & K ANCHOR = 21.15'. L /0 SPEAR. HELD PJSM. MADE UP MILLING BHA, 4-1/4" PRT TOOL w/ 6" GRAPPLE - 8-1/2" PACKER MILL - 3 x BOOT BASKETS- BIT SUB - BUMPER SUB - 6-1/4" OIL JARS - XO - 9 X 6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 327.21'. RIH w/ PACKER MILLING BHA ON 5" DP. SERVICED RIG. RIH w/ PACKER MILLING BHA ON 5" DP TO 8,920'. Printed: 2/20/2002 11 :25:22 AM ( (' BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/25/2002 09:00 - 09:30 0.50 PULL P DECOMP M / U KELLY. RECORDED PARAMETERS, STRING WEIGHT UP 205,000#, STRING WEIGHT DOWN 180,000#, STRING WEIGHT ROTATING 195,000#. RPM 70, TORQUE 7,000 ftIlbs. 09:30 - 14:00 4.50 PULL P DECOMP WASHED DOWN AND TAGGED TOP OF PACKER AT 8,953'. MILLED PACKER FROM 8,953' TO 8,961'. WOM 5,000#- 25,000#, RPM 70, TORQUE 7,000 - 9,000 ftIlbs, PUMP RATE 8 BPM, SPP 750 PSI. PUMPED 10 BBL HI-VIS SWEEPS TO CLEAN HOLE. PACKER FELL TO 9,030'. 14:00 - 16:00 2.00 PULL P DECOMP PUMPED AND CIRCULATED AROUND 25 BBL HI-VIS SWEEP. PUMP RATE 8 BPM, SPP 800 PSI. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. NO GAS TO SURFACE. OBSERVED WELL, WELL STATIC. ENGAGED PACKER, BLEW DOWN AND SET BACK KELLY. 16:00 - 20:30 4.50 PULL P DECOMP POOH w/5" DP. 10,000# OF DRAG FIRST 5 STANDS. 20:30 - 21 :30 1.00 PULL P DECOMP L / D BHA, NO FISH. NO DAMAGE TO PRT. 21 :30 - 22:30 1.00 PULL P DECOMP CLEANED OUT JUNK SUBS, RECOVERED 4 GALLONS OF METAL. CLEANED / CLEARED FLOOR. 22:30 - 23:30 1.00 PULL P DECOMP HELD PJSM. MADE UP MILLING BHA, 4-1/16" SPEAR wI 4.8" GRAPPLE - BUMPER SUB - 6-1/4" OIL JARS - XO - 9 X 6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 311.77'. 23:30 - 00:00 0.50 PULL P DECOMP RIH W/ FISHING BHA ON 5" DP. 1/26/2002 00:00 - 01 :30 1.50 PULL P DECOMP HELD PJSM. SLIPPED AND CUT 57' OF DRILLING LINE. 01 :30 - 04:00 2.50 PULL P DECOMP RIH w/ FISHING BHA ON 5" DP TO 8,997' 04:00 - 05:00 1.00 PULL P DECOMP P / U KELLY. CHECKED PARAMETERS, STRING WEIGHT UP 210,000#, STRING WEIGHT DOWN 181,000#. WASHED AND PUSHED PACKER DOWN TO 9,077'. SET DOWN ON PACKER 25,000#. 05:00 - 06:30 1.50 PULL P DECOMP CIRCULATED BOTTOMS UP. PUMP RATE 7 BPM, SPP 700 PSI. NO GAS. SHUT DOWN PUMPS. RETAGGED PACKER w/ 35,000#. BLEW DOWN AND SET BACK KELLY. 06:30 - 14:00 7.50 PULL P DECOMP POOH VERY SLOWLY w/5" DP. AVERAGE DRAG 10,000#. PACKER OCCASIONALLY HANGING UP FROM 3,700' TO SURFACE. RECIPROCATED PACKER AND WORKED THROUGH TIGHT SPOTS. 14:00 - 15:00 1.00 PULL P DECOMP POOH w/ BHA BROKE OUT AND L / D SAME. 15:00 - 16:30 1.50 PULL P DECOMP BROKE OUT AND L /0 PACKER, MILL OUT EXTENSION AND TAIL PIPE. TOTAL LENGTH OF FISH 52.19'.100% RECOVERY. 16:30 - 17:00 0.50 PULL P DECOMP CLEARED AND CLEANED FLOOR. BROKE DOWN FISHING TOOLS. 17:00 - 17:30 0.50 PULL P DECOMP SERVICED RIG. 17:30 -18:00 0.50 PULL P DECOMP HELD PJSM. M / U OVERSHOT 18:00 - 22:30 4.50 PULL P DECOMP RIH W/ 5" DP. 22:30 - 23:30 1.00 PULL P DECOMP HELD PJSM. M / U 5" DP PUPS, HEAD PIN & CIRC HOSE. CHECKED PARAMETERS STRING WEIGHT UP 190,000#, STRING WEIGHT DOWN 165,000#, PUMP RATE 4BPM, SPP100 PSI. TAGGED TOP OF 4" STUB AT 9,078', OBSERVED CORRESPONDING PRESSURE INCREASE, SHUT DOWN PUMP, SWALLOWED 4' OF TUBING STUB, SET DOWN 15,000#, PICKED UP TO 210,000# & SET SLIPS w/20,000# OVERPULL. Printed: 2/20/2002 11 :25:22 AM ..- BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/26/2002 23:30 - 00:00 0.50 PULL P DECOMP HELD PJSM. R / U E-LiNE. 1/27/2002 00:00 - 00:30 0.50 PULL P DECOMP HELD PJSM. R / U SCHLUMBERGER. M / U 2 WEIGHT BARS & 111/16" CCUGAMMA RAY LOGGING TOOL. 00:30 - 03:30 3.00 PULL P DECOMP RIH w/ SCHLUMBERGER 1-11/16" GAMMA RAY-CCL LOGGING TOOL. SET DOWN ON TOP OF 4" LINER STUB AT 9,071'. COULD NOT WORK BELOW 9,071'. MADE GR-CCL CORRELATION LOG FROM 9,071' TO 8,600'. POOH w/ E-LlNE, R / 0 SCHLUMBERGER. 03:30 - 04:00 0.50 PULL P DECOMP HELD PJSM. PULLED 240,000# ON TUBING STUB, THEN SLACK OFF TO 200,000#, (10K OVER UP WT), SET SLIPS AND ROTATED DRILL STRING 10 TURNS TO THE LEFT TO BACK OFF 4" LINER. MAXIMUM TORQUE 8,800 ftllbs. LOST 2,500 ftllbs OF TORQUE w/ 7 TURNS. SHUT DOWN ROTARY TABLE AND RELEASED ROTARY BRAKE, GOT BACK 1/2 TURN. PICK UP 6', NO OVERPULL. 04:00 - 06:00 2.00 PULL P DECOMP PUMPED AND CIRCULATED AROUND 20 BBL HI-VIS SWEEP. PUMP RATE 8 BPM, SPP 550 PSI. CIRCULATED BACK GEL AND SAND. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 06:00 - 09:30 3.50 PULL P DECOMP POOH w/5" DP. 09:30 - 10:00 0.50 PULL P DECOMP BROKE OUT AND L / 0 OVERHSHOT AND FISH. 10:00 -10:30 0.50 PULL P DECOMP DERRICKMAN STRUCK ON FOOT w/ STRING STABILIZER, SEE REMARKS. SAFETY SHUT DOWN. HELD REVIEW OF INCIDENT AND SAFETY MEETING w/ CREW. 10:30 - 12:00 1.50 PULL P DECOMP HELD PJSM. MADE UP MILLING BHA, 8-1/2" MILL - xo- STRING STAB - XO - 3 x BOOT BASKETS - XO - 6-1/4" OIL JARS - XO - 9 x 6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 324.79'. 12:00 - 12:30 0.50 PULL P DECOMP HELD PJSM. SERVICED RIG. 12:30 - 15:30 3.00 PULL P DECOMP REPAIRED KOOMEY UNIT. 15:30 - 19:30 4.00 PULL P DECOMP RIH w/ MILLING BHA ON 5" DP TO 9074', (92 STDS) 19:30 - 20:00 0.50 PULL P DECOMP KELLY UP ON STAND 92. CHECKED PARAMETERS: WHILE PUMPING 81/2 BPM, UP WEIGHT 215,000#, DOWN WT 180,000#, & ROTATING WEIGHT 198,000#. ROTATING TORQUE OFF BOTTOM IS 8200 FT/LBS. 20:00 - 00:00 4.00 PULL P DECOMP HARD TAG @ 9099'. MILLED 4" LINER F/9099' TO 9124' DPM, PUMPED 10 BBL HI VIS SWEEPS EVERY 1/2 HOUR. MILLED w/3,OOO#-7,OOO# WOM, 65 RPM, 8 1/2 BPM @ 375 SPP. TORQUE AVERAGE 9,500 ftllbs. MAX TORQUE ACHIEVED DURING MILLING OPS, 12,000 ftllbs. 1/28/2002 00:00 - 02:00 2.00 PULL P DECOMP HELD PJSM. MILLED 4" TUBING F/9124'-9132', WOM 12,000# - 15,000#, RPM 80-65, TORQUE 9,000 ft fibs, PUMP RATE 8.5 BPM, SPP 400 PSI. DRILL STRING TORQUING UP ON LAST FEW FEET, 13,000 FT/LBS MAX. 02:00 - 06:00 4.00 PULL P DECOMP HELD PJSM. PUMPED 25 BBLS HI VIS SWEEP, FOLLOWED BY 25 BBLS DIRT MAGNET PILL, FOLLOWED BY 40 BBLS FRESH WATER SPACER DISPLACED THE HOLE w/600 BBLS 8.4 ppg QUIKDRIL MUD. PUMP RATE 8.5 BPM, SPP 375 PSI. RECIPROCATED & ROTATED PIPE WHILE DISPLACING TO FACILITATE HOLE CLEANING. BLEW DOWN AND SET BACK KELL Y. 06:00 - 11 :00 5.00 PULL P DECOMP POOH w/ 5" DP. SLM. 11 :00 - 12:00 1.00 PULL P DECOMP POOH w/ BHA. (' ( Printed: 2/20/2002 11:25:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/28/2002 1/29/2002 Date ( ( BP EXPLORATION Operations Summary Report 02-138 02-138 DRILL +COMPLETE DOYON DOYON 16 12:00 - 13:00 From - To Hours Activity Code NPT DECOMP 13:00 - 14:00 14:00 - 14:30 14:30 - 18:00 18:00 - 20:30 20:30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30-11:30 11 :30 - 12:30 12:30 - 13:30 13:30 -14:30 14:30 - 15:00 15:00 -15:30 Phase 1.00 PULL P 1.00 WHSUR P LNR1 0.50 WHSUR P 3.50 WHSUR P LNR1 LNR1 2.50 WHSUR P LNR1 2.00 WHSUR P LNR1 1.00 WHSUR N 0.50 WHSUR P 2.00 WHSUR P RREP LNR1 LNR1 PROD1 1.00 WHSUR P PROD1 3.00 BOPSUF P 3.00 BOPSUF P PROD1 PROD1 0.50 BOPSUF P 1.00 BOPSUF P PROD1 PROD1 1.00 BOPSUF P PROD1 1.00 EVAL 1.00 EVAL P P PROD1 PROD1 1.00 STWHIP P PROD1 0.50 STWHIP P 0.50 STWHIP P PROD1 PROD1 Page 6 of 12 Start: 1/22/2002 Rig Release: 2/13/2002 Rig Number: Spud Date: 1/22/2002 End: 2/13/2002 Description of Operations HELD PJSM. BROKE DOWN AND CLEANED OUT JUNK BASKETS. RECOVERED 150# METAL. CLEARED AND CLEANED DRILL FLOOR. RIH w/3 STANDS OF 6" DC. M / U RTTS w/ STORM VALVE ONTO DC AND RIH TO 10' BELOW WELLHEAD. SET RTTS. RELEASED DP FROM RTTS AND POOH. M / U RETRIEVING TOOL AND PULLED WEAR BUSHING. M / U PACKOFF PULLING TOOL. RIH AND LATCHED UP ON PACKOFF. BOLDS. ATTEMPTED, (SEVERAL TIMES), TO PULL PACKOFF, LEFT ONE NUB OFF RETRIEVING TOOL IN J-SLOT, OTHER NUB ON RETRIEVING TOOL WAS LOOSE. ABANDONED EFFORT TO REMOVE PACKOFFF THRU BOP STACK. HELD PJSM, EMPHASIS ON COMMUNICATION & BODY PLACEMENT. N / 0 BOPE. N / 0 ANNULAR VALVES, PULLED TUBING SPOOL wI UPPER PACKOFF. P / U (1) JT OF DP & RETRIEVING TOOL, "J" INTO LOWER PACKOFF & PULLED SAME. REPAIRED MOUSEHOLE, (POTENTIAL SPILL). N / U VETCO GRAY GEN 11135/8" x 5M TUBING SPOOL. HELD PJSM. N / U VETCO GRAY 5M TUBING SPOOL. INSTALLED UPPER PACKOFF. PRESSURE TESTED UPPER & LOWER PACKOFFS TO 5,000 PSI f/10 MIN, OK HELD PJSM. N / U 13-5/8" BOP STACK. HELD PJSM. TESTED BOPE. TESTED UPPER AND LOWER PIPE RAMS, BLIND RAMS, ANNULAR PREVENTER, VALVES, HCR, KILL LINE, CHOKE MANIFOLD AND LINES, CHOKE LINE TO 3,500 PSI HIGH / 250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. JOHN CRISP w/ AOGCC WAIVED WITNESSING TEST. M / U TOOL AND SET WEAR BUSHING. PERFORMED ACCUMULATOR TEST, OK. P / U KELLY. PRESSURE TESTED UPPER & LOWER KELLY COCKS, STANDPIPE AND VALVES TO 3,500 PSI HIGH /250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. P / U 2 JOINTS OF 5" DP. M / U RETRIEVING TOOL. RIH LATCHED UP ON RTTS, CHECKED FOR PRESSURE, OK. RELEASED RTTS AND POOH. BROKE OUT AND L / D RTTS w/ STORM VALVE. POOH w/ 6" DC HELD PJSM. R / U TO TEST. CLOSED BLIND RAMS, PRESSURE TESTED 9-5/8" CASING TO 3,000 PSI f/30 MIN, OK. BLED OFF PRESSURE AND OPENED BLIND RAMS. P / U AND RIH w/18 JOINTS OF 5" HWDP AND 6 STANDS OF 5" DP BROKE OUT AND L / D 18 JOINTS OF 5" DP. CIRCULATED THROUGH 5" HWDP TO CLEAN OUT PRIOR TO M / U MWD. Printed: 2/20/2002 11 :25:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/29/2002 1/30/2002 1/31/2002 (' ( Page 7 of 12 BP EXPLORATION Operations Summary Report 02-138 02-138 DRILL +COMPLETE DOYON DOYON 16 15:30 - 16:00 From - To Hours Activity Code NPT PROD1 16:00 - 18:30 18:30 - 00:00 00:00 - 01 :00 01 :00 - 09:00 09:00 - 10:30 10:30 - 00:00 00:00 - 02:30 02:30 - 04:30 Phase 0.50 STWHIP P 2.50 STWHIP P PROD1 5.50 STWHIP N DFAL PROD1 1.00 STWHIP P PROD1 8.00 STWHIP P PROD1 1.50 STWHIP P PROD1 13.50 STWHIP P PROD1 2.50 STWHIP P PROD1 2.00 STWHIP P PROD1 Start: 1/22/2002 Rig Release: 2/13/2002 Rig Number: Spud Date: 1/22/2002 End: 2/13/2002 Description of Operations BLEW DOWN AND SET BACK KELLY. POOH AND STOOD BACK 5" HWDP. HELD PJSM. M / U 1 JOINT OF 5" HWDP, STARTER MILL, 2 - STRING MILLS, XO, FLOAT SUB AND STOOD BACK. P / U WHIPSTOCK, M / U WHIPSTOCK TO STARTER MILL w/ 45,000# SHEAR BOLT. RIH. P / U & M / U MWD TOOLS. ORIENTED TOOLS AND RIH. TESTED MWD w/ 325 GPM, NO PULSE. POOH, CHANGED OUT PULSER. ATTEMPTED TO TEST MWD, NO PULSE. CHANGED OUT PULSER, ATTEMPTED TO TEST MWD, NO PULSE. POOH. CHANGED OUT PULSER f/ THIRD TIME, ATTEMPTED TO TEST MWD, NO PULSE. NOTE: SPERRY SUN's PULSERS AND INTERNAL ELECTRONICS INCOMPATIBLE w/ SOFTWARE. HELD PJSM. LOADED NEW PULSAR w/ CORRECT SOFTWARE INTO MWD. M / U MWD AND RIH. TESTED MWD w/ 325 GPM GOOD PULSE 300 PSI - 350 PSI. RIH SLOWLY w/ WHIPSTOCK - MILLING BHA ON 5" DP. FILLED DP EVERY 25 STANDS. M / U KELLY, STARTED PUMPS. PUMP RATE 335 GPM, SPP 975 PSI. CHECKED PARAMETERS STRING WEIGHT UP 207,000#, STRING WEIGHT DOWN 190,000#. WORKED DRILL STRING AND ORIENTED WHIPSTOCK TO 87* LEFT OF HIGH SIDE. SET WHIPSTOCK ON BOTTOM, 9,132' DPM. SET DOWN 30,000#, SHEARED SET SCREWS AND TRIPPED BOTTOM SLIPS. PULLED UP TO 215,000# TO ENSURE WHIPSTOCK SET. SET DOWN 45,000# AND SHEARED MILL OFF OF WHIPSTOCK. NOTE: BOTTOM OF WHIPSTOCK SET AT 9,132' TOP OF WHIPSTOCK AT 9,108' BOTTOM OF WHIPSTOCK SLIDE 9,125' CHECKED PARAMETERS, STRING WEIGHT UP 207,000#, STRING WEIGHT DOWN 190,000#, STRING WEIGHT ROTATING 202,000#, RPM 70, TORQUE OFF BOTTOM 7,000 ft fibs. MILLED WINDOW FROM 9,109' - 9,125', OPEN HOLE FROM 9,125' - 9,130'. WOM 10,000# - 27,000#, RPM 65 - 75, TORQUE 7,250 ft fibs, PUMP RATE 350 GPM, SPP 950 PSI. PUMPED 10 BBL HI-VIS SWEEPS EVERY 45 MINUTES TO HELP CLEAN THE HOLE. RECOVERED 155# OF METAL. NOTE: TOP OF WINDOW 9,109' BOTTOM OF WINDOW 9,125' HELD PJSM. MILLED FROM 9,130' - 9,131'. WOM 15,000#- 27,000#, RPM 65 - 80, TORQUE 7,300 ft fibs, PUMP RATE 300 GPM, SPP 950 PSI. PUMPED 10 BBL HI-VIS SWEEPS EVERY 45 MINUTES TO HELP CLEAN THE HOLE. UNABLE TO MAKE HOLE. PUMPED AND CIRCULATED AROUND 40 BBL HI-VIS BARAFIBER SWEEP. PUMP RATE 300 GPM, SPP 950 PSI. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. FLOW CHECKED WELL, WELL STATIC. BLEW DOWN AND SET BACK KELLY. Printed: 2/20/2002 11 :25:22 AM ( (' BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/31/2002 04:30 - 10:00 5.50 STWHIP P PROD1 POOH w/5" DP. CALCULATED FILL 73 BBLS, ACTUAL FILL 77 BBLS. FLOW CHECKED WELL, WELL STATIC. 10:00 - 12:00 2.00 STWHIP P PROD1 BROKE OUT AND L / 0 EACH COMPONENT OF BHA. 12:00 - 13:30 1.50 STWHIP P PROD1 HELD PJSM. SLIPPED AND CUT DRILLING LINE, SERVICED RIG. 13:30 -14:30 1.00 STWHIP N RREP PROD1 REPAIRED KOOMEY UNIT. 14:30 - 16:00 1.50 STWHIP P PROD1 HELD PJSM. M / U SMITH 6.75" XR+ MILL TOOTH BIT AND BHA. 16:00 - 19:30 3.50 STWHIP P PROD1 RIH w/ BHA ON 5" DP TO 9,100'. CALCULATED DISPLACEMENT 71 BBLS, ACTUAL DIPLACEMENT 69.5 BBLS. 19:30 - 21:30 2.00 STWHIP N DPRB PROD1 M / U KELLY, ATTEMPTED TO BREAK CIRCULATION, SPP 3,000 PSI, STRING PLUGGED. WORKED DRILL STRING AND SURGED PRESSURE ON DRILL STRING, ESTABLISHED CIRCULATION. 21 :30 - 22:00 0.50 STWHIP P PROD1 CHECKED PARAMETERS, STRING WEIGHT UP 200,000#, STRING WEIGHT DOWN 185,000#, STRING WEIGHT ROTATING 195,000#. PUMP RATE 300 GPM, SPP 2,650 PSI. CIRCULATED DRILL PIPE CAPACITY. NOTE: PARTIALLY PLUGGED BIT. 22:00 - 23:30 1.50 STWHIP P PROD1 DRILLED 6.75" PILOT HOLE FROM 9,131' - 9,140'. WeB 10,000# -15,000#, RPM 80 - 90, TORQUE 7,200 ft fibs, ROP 5.3 ft / hr, PUMP RATE 300 GPM, SPP 2,650 PSI. 23:30 - 00:00 0.50 STWHIP P PROD1 PUMPED AND CIRCULATED 40 BBL HI-VIS BARAFIBER SWEEP. PUMP RATE 300 GPM, SPP 2,650 PSI. 2/1/2002 00:00 - 01 :30 1.50 STWHIP P PROD1 PUMPED AND CIRCULATED AROUND 40 BBL HI-VIS BARAFIBER SWEEP. PUMP RATE 300 GPM, SPP 2,650 PSI. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 01 :30 - 02:00 0.50 STWHIP P PROD1 PULLED BIT BACK INTO CASING ABOVE WHIPSTOCK. CLOSED ANNULAR AND PERFORMED F.I.T. AS FOLLOWS: TOTAL STROKES PSI 2 100 6 200 10 300 14 400 18 500 22 625 26 750 31 915 NO 8,366', MW IN HOLE 8.4 ppg SURFACE PRESSURE 915 PSI = 10.5 ppg EMW. BLED DOWN PRESSURE, OPENED ANNULAR. 02:00 - 02:30 0.50 STWHIP P PROD1 BLEW DOWN AND SET BACK KELLY. 02:30 - 03:00 0.50 STWHIP P PROD1 HELD PJSM. POOH AND L / 0 25 JOINTS OF 5" DP. 03:00 - 06:30 3.50 STWHIP P PROD1 POOH w/ 5" DP, RACKED IN DERRICK. 06:30 - 07:00 0.50 STWHIP P PROD1 SERVICED RIG. 07:00 - 09:00 2.00 STWHIP P PROD1 POOH L / D 18 Jts 5" HWDP AND 9 - 6" DC. 09:00 - 09:30 0.50 STWHIP P PROD1 BROKE OUT AND L / D BHA AND BIT. 09:30 - 10:00 0.50 STWHIP P PROD1 CLEARED EQUIPMENT FROM DRILL FLOOR. 10:00 - 12:30 2.50 STWHIP P PROD1 P / U AND RIH w/42 Jts 3-1/2" DP. 12:30 - 13:00 0.50 STWHIP P PROD1 M / U KELLY AND ESTABLISHED CIRCULATION THROUGH 3-1/2" DP TO CLEAN OUT PRIOR TO M / U MWD. PUMP Printed: 2/20/2002 11 :25:22 AM ( ( BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/1/2002 12:30 -13:00 0.50 STWHIP P PROD1 RATES: 100 SPM-200 PSI, 80 SPM-150 PSI, 60 SPM-100 PSI. 13:00 - 16:00 3.00 STWHIP P PROD1 M / U HTC 6-1/8" STX 20 BIT, SER# W84JY, TO SPERRY'S 4-3/4" 7/8 2.0 STG MUD MOTOR. SET PAD OFFSET AND BENT HOUSING TO 1.83*. M / U MWD TOOLS AND ORIENTED TO MOTOR. 16:00 -18:00 2.00 STWHIP P PROD1 HELD PJSM. M / U PULSERS AND INSERTED INTO MWD. CLEARED RIG FLOOR AND LOADED RADIOACTIVE SOURCES INTO MWD TOOLS. RIH w/ MWD BELOW ROTARY TABLE AND TESTED w/280 GPM, GOOD PULSE 1,340 PSI - 1,500 PSI. 18:00 -19:30 1.50 STWHIP P PROD1 M / U REMAINING BHA: HOC, 3 - FLEX DC, DRILLING JARS, 14 STANDS OF 3-1/2" DP. 19:30 - 00:00 4.50 STWHIP P PROD1 HELD PJSM. RIH w/ DIRECTIONAL BHA ON 5" DP. DRIFTED EACH STAND, BROKE CIRCULATION EVERY 25 STANDS. 2/2/2002 00:00 - 01 :00 1.00 DRILL P PROD1 HELD PJSM. RIH w/ BHA ON 5" DP. DRIFTED 5" DP WHILE RIH, BROKE CIRCULATION EVERY 25 STANDS. 01 :00 - 02:00 1.00 DRILL P PROD1 L / D 6 Jts OF 5" DP. 02:00 - 03:00 1.00 DRILL P PROD1 MADE WIPE LOG PASS FOR TIE-IN FROM 8,870' - 8,940' 03:00 - 03:30 0.50 DRILL P PROD1 RIH w/ BHA TO 9,080' 03:30 - 04:30 1.00 DRILL P PROD1 HELD PJSM. SLIPPED AND CUT 60' OF DRILLING LINE. 04:30 - 05:00 0.50 DRILL P PROD1 M / U KELLY, ESTABLISHED PARAMETERS, STRING WEIGHT UP 182,000#, STRING WEIGHT DOWN 168,000#. ORIENTED TOOLS, SHUT DOWN PUMP AND RIH THROUGH WINDOW INTO OPEN HOLE. 05:00 - 00:00 19.00 DRILL P PROD1 DRILLED DIRECTIONAL HOLE BY ROTATING AND SLIDING FROM 9,140' TO 9,556'. WOB 10,000# - 25,000#, RPM 10, MOTOR RPM 82, PUMP RATE 250 GPM, SPP OFF BOTTOM 1,400 PSI, SPP ON BOTTOM 1,500 PSI. TORQUE 6,000 ft / Ibs, ROP 33 ft / hr. AST = 10 HRS, ART = 2.5 HRS. 2/3/2002 00:00 - 19:00 19.00 DRILL P PROD1 DRILLED DIRECTIONAL HOLE BY ROTATING AND SLIDING FROM 9,556' TO 9,920'. WOB 15,000# - 25,000#, RPM 10, MOTOR RPM 82, PUMP RATE 250 GPM, SPP OFF BOTTOM 1,400 PSI, SPP ON BOTTOM 1,600 PSI. TORQUE 7,000 ft / Ibs, ROP 27 ft / hr. AST = 11.75 HRS, ART = 1.5 HRS. 19:00 - 21:00 2.00 DRILL P PROD1 PUMPED AND CIRCULATED AROUND 30 BBL HI-VIS BARAFIBER SWEEP. PUMP RATE 250 GPM, SPP 1,450 PSI. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 21 :00 - 22:00 1.00 DRILL P PROD1 BLEW DOWN AND SET BACK KELLY. MADE WIPER TRIP FROM 9,920' TO WINDOW AT 9,135'. MAXIMUM OVERPULL 25,000#, AVERAGE DRAG 10,000#. RAN BACK IN HOLE TO 9,920', AVERAGE DRAG 15,000#. 22:00 - 00:00 2.00 DRILL P PROD1 DRILLED DIRECTIONAL HOLE BY ROTATING AND SLIDING FROM 9,920' TO 9,950'. WOB 15,000# - 25,000#, RPM 10, MOTOR RPM 82, PUMP RATE 250 GPM, SPP OFF BOTTOM 1,400 PSI, SPP ON BOTTOM 1,600 PSI. TORQUE 7,000 ft / Ibs, ROP 20 ft / hr. AST = 1.5 HRS. 2/4/2002 00:00 - 12:00 12.00 DRILL P PROD1 DRILLED DIRECTIONAL HOLE BY ROTATING AND SLIDING FROM 9,950' TO 10,096'. WOB 15,000# - 20,000#, RPM 10, MOTOR RPM 82, PUMP RATE 250 GPM, SPP OFF BOTTOM 1,450 PSI, SPP ON BOTTOM 1,600 PSI. TORQUE 7,200 ft / Ibs, ROP 17 ft / hr. AST = 1 HRS, ART = 7.75 HRS, 195 Printed: 2/20/2002 11 :25:22 AM ( ( BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/4/2002 00:00 - 12:00 12.00 DRILL P PROD1 KRevs. 12:00 - 13:30 1.50 DRILL P PROD1 PUMPED AND CIRCULATED AROUND 30 BBL HI-VIS BARAFIBER SWEEP. PUMP RATE 250 GPM, SPP 1,450 PSI. 13:30 - 14:30 1.00 DRILL P PROD1 POOH FROM 10,096' TO 9,093', INTO THE 9-5/8" CASING ABOVE THE WHIPSTOCK. 14:30 - 00:00 9.50 DRILL N WAIT PROD1 CIRCULATING THE HOLE AT 105 GPM 500 PSI, WHILE WAITING ON WEATHER TO IMPROVE. 2/5/2002 00:00 - 06:00 6.00 DRILL N WAIT PROD1 CIRCULATE & WAIT ON WEATHER. 30 SPM@ 600 PSI. 06:00 - 07:00 1.00 DRILL N WAIT PROD1 ORIENT TOOL FACE & RIH FROM 9023 TO 10065'. 07:00 - 09:00 2.00 DRILL N WAIT PROD1 P/U KELLY BREAK CIRCULATION. RECIPROCATE DRILL STRING. CIRCULATE BOTTOMS UP. 09:00 - 09:30 0.50 DRILL N WAIT PROD1 PUMP DRY JOB, BLOW DOWN KELLY & MONITOR WELL, WELL DEAD. 09:30 - 10:00 0.50 DRILL N WAIT PROD1 POOH FROM 10065 TO 9023'. 10:00 -10:30 0.50 DRILL P PROD1 MONITOR WELL, WELL DEAD. PUMP 2ND DRY JOB. 10:30 - 15:00 4.50 DRILL P PROD1 POOH & STAND BACK 76 STANDS 5" DP. CON'T POOH & LID 40 JTS 5" DP TO 1575'. 15:00 - 16:30 1.50 DRILL P PROD1 POOH & STAND BACK 31/2" DP. LID JARS,PULL BHA TO MWD TOOLS. 16:30 - 18:00 1.50 DRILL P PROD1 HELD PJSM UNLOAD NUCLEAR SOURCE & DOWN LOAD MWD DATA. 18:00 -19:00 1.00 DRILL P PROD1 POOH & LID MWD COMPONETS, MOTOR & BIT. 19:00 - 22:30 3.50 DRILL P PROD1 PJSM. P/U TEST JT, PULL WEAR BUSHING & SET TEST PLUG. TEST BOPS, KELLY & ALL FLOOR VALVES. LP 250 PSI, HP 3500 PSI. INSTALL WEAR BUSHING & LID TEST JT. 22:30 - 23:30 1.00 DRILL P PROD1 CLEAN & CLEAR RIG FLOOR. BLOW DOWN CHOKE. 23:30 - 00:00 0.50 DRILL P PROD1 PJSM. P/U 3 1/2" DP & RIH. 2/6/2002 00:00 - 01 :30 1.50 DRILL P PROD1 P/U & RIH W/39 JTS 3 1/2" DP. 01 :30 - 02:00 0.50 DRILL P PROD1 CIRCULATE THRU DP & CLEAR SAME. 02:00 - 02:30 0.50 DRILL P PROD1 POOH & STAND BACK 31/2" DP. 02:30 - 03:30 1.00 DRILL P PROD1 M/U BIT, MOTOR & MWD. 03:30 - 04:30 1.00 DRILL P PROD1 UPLOAD MWD. 04:30 - 05:30 1.00 DRILL P PROD1 TEST MOTOR & MWD, PRESSURED UP - NO CIRCULATION 05:30 - 06:30 1.00 DRILL N DFAL PROD1 TROUBLESHOOT, FLOAT SUB PIN INTERFERING W/ ROTOR IN MOTOR. 06:30 - 07:00 0.50 DRILL N DFAL PROD1 BREAK OFF SAVER SUB, & LID MOTOR. 07:00 - 07:30 0.50 DRILL N DFAL PROD1 PULLED ROTOR CATCHER & INSTALL PLUG. MIU & TEST MOTOR, OK. 07:30 - 09:30 2.00 DRILL P PROD1 RIH W/ BHA & 3 1/2" DP TO 2792'. 09:30 - 12:00 2.50 DRILL P PROD1 RIH W/5" DP FROM 2792 TO 7540'. 12:00 -13:30 1.50 DRILL P PROD1 FILL DP & HELD PJSM. DOUBLE CUT DRILLING LINE. 13:30 - 14:30 1.00 DRILL P PROD1 RIH TO CASING SHOE. DRAWWORKS GETTING HOT. 14:30 - 17:00 2.50 DRILL N RREP PROD1 WORK ON DYNAMATIC, REPLACE SHIFTER RING. 17:00 - 17:30 0.50 DRILL P PROD1 RIH FROM 9100' TO 10017'. P/U KELLY 17:30 - 18:00 0.50 DRILL P PROD1 WASH & REAM FROM 10017' TO 10096'. 18:00 - 00:00 6.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 10096' TO 10367'. ROTATE 2 1/4 HRS, SLIDE 2 3/4 HRS. TORQUE 9000 FT-LBS WOB 15K ROT, 6K SLIDE. PUMP 80 SPM. MOTOR 219 RPMS, ROT @ 60 RPMS. PP 1700/2150 PSI. 2/7/2002 00:00 - 04:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 10367' TO 10440' 04:00 - 06:00 2.00 DRILL P PROD1 CIRCULATE, RECIPROCATE & ROTATE PIPE. WAIT ON MWD. PUMP BEADS. Printed: 2/20/2002 11 :25:22 AM ( (' BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/7/2002 06:00 - 11 :00 5.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 10440' TO 10536'. 11 :00 - 13:00 2.00 DRILL P PROD1 CIRCULATE HI/LO SWEEP PRIOR TO WIPER TRIP. CHECK FOR FLOW. 13:00 -14:30 1.50 DRILL P PROD1 MADE WIPER TRIP BACK UP INTO SHOE @ 9100'. (15 STANDS) 14:30 -19:00 4.50 DRILL P PROD1 P/U KELLY. ORIENT TOOL FACE & DRILL AHEAD FROM 10536' TO 10640'. 19:00 -19:30 0.50 DRILL P PROD1 PUMP 20 BBL LO-VIS FOLLOWED BY 20 BBL HI-VIS PILL W/ EZ GLIDE & BEADS. CIRC OUT BIT 19:30 - 00:00 4.50 DRILL P PROD1 DRI LL AHEAD FROM 10640 TO 10685'. 2/8/2002 00:00 - 00:30 0.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 10685' TO 10695'. 00:30 - 01 :30 1.00 DRILL P PROD1 PUMP BEAD PILL TO BIT. RECIPROCATE INTO FORMATION. 01 :30 - 09:00 7.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 10695' TO 11000'. 09:00 - 10:30 1.50 DRILL P PROD1 CIRCULATE & PUMP SWEEP AROUND. 10:30 - 12:00 1.50 DRILL P PROD1 FLOW CHECK. BLOW DOWN KELLY. SHORT TRIP INTO 9 5/8" CASING. 12:00 - 12:30 0.50 DRILL P PROD1 CLEAN & CLEAR RIG FLOOR. 12:30 - 14:30 2.00 DRILL P PROD1 CUT & SLIP 510' OF DRILLlNGLINE 14:30 - 15:00 0.50 DRILL P PROD1 SERVICE RIG. 15:00 - 16:00 1.00 DRILL P PROD1 TRIP IN HOLE TO TO TO. P/U KELL Y. 16:00 - 00:00 8.00 DRILL P PROD1 CIRCUL TAE & CONDITION HOLE. PUMP HI-VIS SWEEP. SPOT 75 BBL LINER PILL. 2/9/2002 00:00 - 01 :30 1.50 DRILL P PROD1 FLOW CHECK WELL, SET KELLY BACK. BLOW DOWN LINES. POOH W/5" DP F/10967' TO 9067'. 01 :30 - 02:00 0.50 DRILL P PROD1 FLOW CHECK WELL. PUMP DRY JOB. 02:00 - 05:30 3.50 DRILL P PROD1 POOH W/ DP TO 2792'., PULLING WET. 05:30 - 06:30 1.00 DRILL P PROD1 FLUSH 31/2" DP & BHA W/25 BBLS WATER. 06:30 - 09:30 3.00 DRILL P PROD1 POOH & LID 31/2" DP. 09:30 - 10:00 0.50 DRILL P PROD1 BREAK OFF BIT & LID MOTOR. 10:00 - 11 :00 1.00 DRILL P PROD1 DOWN LOAD MWD DATA. 11 :00 - 11 :30 0.50 DRILL P PROD1 LID MWD ASSY. 11 :30 - 12:30 1.00 DRILL P PROD1 CLEAR & CLEAN FLOOR. SERVICE RIG. 12:30 -13:30 1.00 DRILL P PROD1 R/U TO RUN 41/2" LINER. 13:30 -16:30 3.00 DRILL P PROD1 PJSM, RUN 41/2" LINER RAN 52 JTS TL = 2110'. 16:30 -17:00 0.50 DRILL P PROD1 P/U LINER SETTING EQUIP. + 1 JT DP & CIRCULATE 50 BBLS THRU LINER. 17:00 - 17:30 0.50 DRILL P PROD1 RID LINER HANDLING EQUIP. 17:30 - 23:00 5.50 DRILL P PROD1 RIH W/ LINER ON 5" DP TO TOP OF WHIPSTOCK& 9108'. FILLED EVERY 5 STANDS. 23:00 - 00:00 1.00 DRILL P PROD1 M/U CIRCULATING HEAD & CIRCULATE PIPE VOLUME. 2/10/2002 00:00 - 01 :30 1.50 DRILL P PROD1 CONTINUE TO RIH W/41/2" LINER. TAG BOTTOM @ 11000'. TOP OF LINER @ 8903'. 01 :30 - 04:30 3.00 DRILL P PROD1 R/U CEMENT MANIFOLD & CIRCULATE THRU LINER PRIOR TO CEMENTING. 04:30 - 05:30 1.00 DRILL P PROD1 PJSM. R/U & TEST LINES TO 5000PSI. MIX & PUMP 5 BBLS WATER FOLLOWED BY 35 BBLS ALPHA SPACER. MIX & PUMP 310 SXS PREMIUM CEMENT W/ CFR-3, HALAD 344, HALAD 413, HR5 & SUPER CBL. YLD 1.15 CUFT/SX, 15.9 PPG. PUMPED @ 5 BPM. DISPLACED W/ 30 BBLS PERF PILL & A53 BBLS SEAWATER. BUMPED PLUG TO 2000 PSI. INCREASED PRESSURE TO 3500 PSI & SET HANGER. RELEASE PRESSURE FLOAT HELD. Printed: 2/20/2002 11 :25:22 AM ( (' BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 02-138 Common Well Name: 02-138 Spud Date: 1/22/2002 Event Name: DRILL +COMPLETE Start: 1/22/2002 End: 2/13/2002 Contractor Name: DOYON Rig Release: 2/13/2002 Rig Name: DOYON 16 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/10/2002 05:30 - 07:00 1.50 DRILL P PROD1 RELEASE RUNNING TOOL 1000 PSI. CIRCULATE 500 STKS. SLACK OFF & SET PKR W/ 70K DOWN WEIGHT. P/U & CIRCULATE EXCESS CMT OUT. HAD 5 BBLE CMT RETURNS + CON TAMINATED WATER. 07:00 - 13:00 6.00 DRILL P PROD1 CLEAN PITS & DISPLACE WELL TO CLEAN SEAWATER. 13:00 - 17:00 4.00 DRILL P PROD1 PULL 1 STAND. BREAK & LID CEMENTING HEAD. POOH W/DP. 17:00 -18:00 1.00 DRILL P PROD1 BREAK & LID LINER RUNNING TOOL. CLEAR FLOOR. 18:00 - 21:00 3.00 DRILL P PROD1 PULL WEAR BUSHING. CHANGE TOP RAMS TO 2 7/8" X 5". TEST SAME 250/3500 PSI, OK. 21 :00 - 22:00 1.00 DRILL P PROD1 LID REST JT. INSTALL WEAR BUSHING. 22:00 - 23:00 1.00 DRILL P PROD1 PRESSURE TEST CASING/ LINER TOP TO 3000 PSI FOR 30 MIN. TEST GOOD. 23:00 - 00:00 1.00 DRILL P PROD1 M/U PERF GUNS & RIH. 2/11/2002 00:00 - 02:00 2.00 PERF P COMP PJSM. M/U 592' OF PERF GUNS & RIH W/ SAME. 02:00 - 04:00 2.00 PERF P COMP P/U & RIH W/36 JTS 2 7/8" PAC. 04:00 - 09:30 5.50 PERF P COMP RIH W/5" DP FROM 1710' TO 8903'. TAG TOP OF NO GO. 09:30 - 10:00 0.50 PERF P COMP R/U TIW & CIRCULATING HOSE. BREAK CIRCULATION. P/U 17' FOR SPACE OUT. 10:00 -10:30 0.50 PERF P COMP PRESSURE UP TO 2300 PSI. & PERFORATE 10020 TO 10590'. FLOW CHECK WELL. 10:30 - 11 :00 0.50 PERF P COMP PULL 6 STANDS DP. TO 10042'. 11 :00 - 12:30 1.50 PERF P COMP RlU & CIRCULATE BOTTOMS UP. NO GAS. 12:30 - 20:00 7.50 PERF P COMP POOH & LID 5" DP. 20:00 - 20:30 0.50 PERF P COMP R/U 2 7/8" HANDLING TOOLS. BREAK DOWN X-OVERS. 20:30 - 21 :30 1.00 PERF P COMP LID 2 7/8" PAC. 21 :30 - 23:00 1.50 PERF P COMP PJSM. LID 29 JTS PERF TOOLS. ALL SHOTS FIRED. 23:00 - 00:00 1.00 RUNCO~ P COMP RID 2 7/8" HANDLING TOOLS. PULL WEAR BUSHING. RlU TO RUN COMPLETION. 2/12/2002 00:00 - 00:30 0.50 RUNCO~ P CaMP CONTINUE TO R/U TO RUN COMPLETION. 00:30 - 01 :30 1.00 RUNCO~ P COMP PJSM. R/U STABBING BOARD. 01 :30 - 16:30 15.00 RUNCO~ P COMP RIH W/4 1/2",12.6# L-80, TCII COMPLETION STRING. 16:30 - 17:00 0.50 RUNCO~ P COMP SPACE OUT & TAG UP @ 8926'. 17:00 - 23:00 6.00 RUNCO~ iF' COMP CIRCULATE HI-VIS PILL. DISPLACE WELL W/ HOT (140 DEG) INHIBITED SEAWATER. 23:00 - 00:00 1.00 RUNCO~ P COMP RETAG & DO FINAL SPACE OUT WI TBG PUPS. 2/13/2002 00:00 - 02:00 2.00 RUNCO~ iF' COMP M/U HANGER & LAND COMP STRG. 02:00 - 04:30 2.50 RUNCO~ P COMP SET PACKER & TEST TUBING TO 3500 PSI/ 30 MIN, OK. BLEED TO 1000 PSI. TEST ANNULUS TO 3000 PSI/ 30 MIN, OK. BLEED TUBING & SHEAR RP VALVE. 04:30 - 05:00 0.50 WHSUR P COMP SET BPV 05:00 - 08:30 3.50 WHSUR P COMP N/D BOPE 08:30 - 11 :30 3.00 WHSUR P COMP N/U ADAPTER FLANGE & TREE, TEST TO 4000 PSI, OK. 11 :30 - 12:30 1.00 WHSUR P COMP PULL BPV. 12:30 - 16:00 3.50 WHSUR P COMP FREEZE PROTECT & U-TUBE WELL TO 2000' ON ANNULUS & TUBING. 16:00 - 16:30 0.50 WHSUR P COMP SET BPV 16:30 -18:00 1.50 WHSUR P COMP REMOVE SECONDARY ANNULUS VALVE, SECURE WELL. RIG RELEASED @ 1800 HRS 02-13-2002. Printed: 2/20/2002 11 :25:22 AM DEFINITIVE --"- North Slope Alaska BPXA PBU_EOA OS 02, Slot 02-13 02-13 - 2-13B Job No. AKZZ22oo8, SURVEY REPORT 18 February, 2002 --, " Your Ref: 500292043302 Surface Coordinates: 5950516.02 N, 687616.89 E (70016' 10.7219" N, 148028' 57.4424" W) Surface Coordinates relative to Project H Reference: 950516.02 N, 187616.89 E (Grid) Surface Coordinates relative to Structure Reference: 1716.30 N, 19.44 E (True) Kelly Bushing: 57.6Oft above Mean Sea Level Sp E!""""" V - SU I! DRILLING SERVices A Halliburton Company Survey Ref: svy11107 Sperry-Sun Drilling Services ::;.: . Survey Report for 02-13 - 2-138 Your Ref: 500292043302 DEFINITIVE Job No. AKZZ2200B1 BPXA North Slope Alaska PBU_EOA DS 02 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9093.60 27.250 107.000 8311.31 8368.91 441.16S 2488.61 E 5950137.03 N 690115.72 E 2470.35 Tie On Point 9105.00 27.220 107.000 8321.44 8379.04 442.69 S 2493.60 E 5950135.63 N 690120.75 E 0.263 2475.28 Window Point AK-6 BP.JFR-AK 9130.52 27.430 104.060 8344.12 8401.72 445.82 S 2504.88 E 5950132.78 N 690132.11 E 5.351 2486.44 ----'" 9164.79 21.540 99.000 8375.30 8432.90 448.72 S 2518.77 E 5950130.22 N 690146.06 E 18.229 2500.20 9194.27 15.700 93.060 8403.22 8460.82 449.78 S 2528.10 E 5950129.39 N 690155.42 E 20.804 2509.49 9226.66 11 .590 84.420 8434.70 8492.30 449.70 S 2535.72 E 5950129.66 N 690163.03 E 14.130 2517.11 9257.53 10.240 72.770 8465.01 8522.61 448.59 S 2541.43 E 5950130.92 N 690168.71 E 8.356 2522.85 9289.66 11 .220 56.160 8496.59 8554.19 446.00 S 2546.76 E 5950133.64 N 690173.97 E 10.056 2528.27 9320.78 11.930 35.590 8527.09 8584.69 441.70 S 2551.14 E 5950138.05 N 690178.25 E 13.384 2532.82 9352.03 1 2.430 11 .450 8557.65 8615.25 435.77 S 2553.69 E 5950144.04 N 690180.65 E 16.259 2535.59 9383.80 14.730 351.580 8588.55 8646.15 428.42 S 2553.78 E 5950151.39 N 690180.56 E 16.264 2535.95 9414.99 18.870 337.790 8618.41 8676.01 419.82 S 2551.29 E 5950159.93 N 690177.85 E 18.340 2533.79 9446.15 24.140 332.880 8647.39 8704.99 409.48 S 2546.48 E 5950170.15 N 690172.78 E 17.858 2529.36 9477.76 28.900 328.350 8675.67 8733.27 397.21 S 2539.52 E 5950182.23 N 690165.52 E 16.352 2522.87 9510.07 33.010 324.140 8703.38 8760.98 383.42 S 2530.26 E 5950195.78 N 690155.92 E 14.371 2514.13 9541.54 36.700 318.940 8729.20 8786.80 369.38 S 2519.06 E 5950209.55 N 690144.37 E 15.047 2503.46 9572.90 39.900 314.570 8753.82 8811.42 355.25 S 2505.73 E 5950223.34 N 690130.70 E 13.363 2490.67 9606.87 43.670 310.530 8779.15 8836.75 339.97 S 2489.05 E 5950238.20 N 690113.64 E 13.632 2474.57 9638.04 47.460 305.780 8800.97 8858.57 326.26 S 2471.54 E 5950251.47 N 690095.79 E 16.311 2457.59 9668.48 52.430 301.830 8820.56 8878.16 313.33 S 2452.17 E 5950263.92 N 690076.11 E 19.106 2438.73 ---~.. 9701.33 56.800 299.380 8839.58 8897.18 299.71 S 2429.12 E 5950276.95 N 690052.73 E 14.625 2416.20 9733.10 61.170 297.780 8855.94 8913.54 286.70 S 2405.22 E 5950289.37 N 690028.51 E 14.416 2392.80 9763.85 65.870 295.980 8869.65 8927.25 274.26 S 2380.67 E 5950301.18 N 690003.66 E 16.157 2368.73 9795.37 69.960 293.260 8881.50 8939.10 262.11 S 2354.12 E 5950312.67 N 689976.82 E 15.240 2342.66 9826.89 74.020 292.110 8891.25 8948.85 250.55 S 2326.47 E 5950323.53 N 689948.88 E 13.340 2315.46 9858.55 78.430 289.820 8898.78 8956.38 239.56 S 2297.77 E 5950333.81 N 689919.91 E 15.600 2287.19 9891.10 83.790 287.420 8903.81 8961.41 229.30 S 2267.30 E 5950343.30 N 689889.20 E 18.005 2257.13 9921.43 87.790 285.630 8906.04 8963.64 220.70 S 2238.31 E 5950351.18 N 689860.01 E 14.442 2228.48 9953.72 88.600 282.730 8907.06 8964.66 212.80 S 2207.02 E 5950358.30 N 689828.53 E 9.320 2197.51 9985.16 89.870 284.660 8907.48 8965.08 205.35 S 2176.48 E 5950364.98 N 689797.81 E 7.348 2167.27 --_U .. __m_- --_u- ,..., u"'-- 18 February, 2002 - 14:47 Page 2 of 4 Drí/lQucst 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for 02-13 - 2-138 Your Ref: 500292043302 Job No. AKZZ22008~ BPXA North Slope Alaska PBU_EOA DS 02 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings ' Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10017.78 89.750 284.290 8907.59 8965.1 9 197.20 S 2144.90 E 5950372.34 N 689766.04 E 1.192 2136.01 10058.70 89.470 281.920 8907.86 8965.46 187.92 S 2105.05 E 5950380.63 N 689725.97 E 5.832 2096.54 10091.44 89.670 280.860 8908.11 8965.71 181.46 S 2072.95 E 5950386.29 N 689693.72 E 3.295 2064.71 10122.95 90.000 280.350 8908.20 8965.80 175.66 S 2041.98E 5950391.31 N 689662.62 E 1.928 2033.97 ~ 10154.65 90.080 280.500 8908.18 8965.78 169.92 S 2010.80 E 5950396.27 N 689631.31 E 0.536 2003.03 10186.13 89.970 280.770 8908.16 8965.76 164.11 S 1979.87 E 5950401.31 N 689600.23 E 0.926 1972.33 10218.32 89.920 281.130 8908.20 8965.80 158.00 S 1948.26 E 5950406.63 N 689568.48 E 1.129 1940.98 10249.60 89.870 281.160 8908.25 8965.85 151.95 S 1917.57 E 5950411.91 N 689537.65 E 0.186 1910.54 10281.53 89.880 280.720 8908.32 8965.92 145.89 S 1886.22 E 5950417.19 N 689506.16 E 1.378 1879.44 10313.89 89.700 280.920 8908.44 8966.04 139.82 S 1854.44 E 5950422.47 N 689474.24 E 0.831 1847.90 10343.31 89.600 281.630 8908.62 8966.22 134.07 S 1825.59 E 5950427.50 N 689445.25 E 2.437 1819.29 10375.74 89.560 281.590 8908.86 8966.46 127.54 S 1793.82 E 5950433.23 N 689413.33 E 0.174 1787.79 10406.80 88.450 280.980 8909.40 8967.00 121.46 S 1763.37 E 5950438.55 N 689382.74 E 4.078 1757.58 10438.27 86.520 280.890 8910.78 8968.38 115.50 S 1732.50 E 5950443.74 N 689351.73 E 6.139 1726.96 10470.55 85.660 281.210 8912.98 8970.58 109.33 S 1700.89 E 5950449.12 N 689319.98 E 2.842 1695.61 10501.80 85.560 281.380 8915.37 8972.97 103.22 S 1670.34 E 5950454.46 N 689289.28 E 0.630 1665.30 1 0533.76 85.570 282.420 8917.84 8975.44 96.65 S 1639.16 E 5950460.25 N 689257.95 E 3.244 1634.39 10565.36 84.480 283.450 8920.58 8978.18 89.61 S 1608.48 E 5950466.53 N 689227.10 E 4.737 1603.99 10597.28 84.690 283.340 8923.60 8981.20 82.25 S 1577.56 E 5950473.12 N 689196.01 E 0.742 1573.38 10629.16 84.950 283.750 8926.47 8984.07 74.81 S 1546.70 E 5950479.79 N 689164.97 E 1.518 1542.81 --- 10660.68 86.590 284.800 8928.80 8986.40 67.06 S 1516.23 E 5950486.78 N 689134.32 E 6.173 1512.66 10692.71 88.940 286.930 8930.05 8987.65 58.31 S 1485.45 E 5950494.76 N 689103.33 E 9.898 1482.23 10724.15 91 .560 289.470 8929.91 8987.51 48.49 S 1455.59 E 5950503.83 N 689073.24 E 11.606 1452.75 10755.18 92.050 290.630 8928.93 8986.53 37.86 S 1426.46 E 5950513.73 N 689043.85 E 4.056 1424.04 10786.60 91.800 290.100 8927.88 8985.48 26.93 S 1397.02 E 5950523.92 N 689014.14 E 1.864 1395.03 10818.82 91.920 290.000 8926.83 8984.43 15.89 S 1366.76 E 5950534.20 N 688983.63 E 0.485 1365.21 10851 .19 92.200 290.020 8925.67 8983.27 4.82 S 1336.37 E 5950544.51 N 688952.96 E 0.867 1335.25 10882.50 92.380 290.230 8924.42 8982.02 5.94N 1306.99 E 5950554.54 N 688923.33 E 0.883 1306.30 10913.00 92.670 289.740 8923.07 8980.67 16.36 N 1278.36 E 5950564.24 N 688894.44 E 1.865 1278.07 10934.91 92.870 289.030 8922.02 8979.62 23.62 N 1257.71 E 5950570.98 N 688873.63 E 3.363 1257.72 0 OuO 0- 00-0'___- ------- -- , 18 February, 2002 - 14:47 Page 3 of 4 DrlllQuest 2.00.09.008 North Slope Alaska Measured Depth (ft) Azlm. Sub-Sea Depth (ft) Incl. 11000.00 92.870 289.030 8918.76 Vertical Depth (ft) 8976.36 Sperry-Sun Drilling Services Survey Report for 02-13 - 2-138 Your Ref: 500292043302 Job No. AKZZ22008, Local Coordinates Northlngs Ealtlngs (ft) (ft) 44.82 N 1196.26 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.515° (18-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 87.8540 (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 11 OOO.OOft., The Bottom Hole Displacement is 1197.1 Oft., in the Direction of 87.854° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9093.60 9105.00 11000.00 8368.91 8379.04 8976.36 441.16 S 442.69 S 44.82 N Survey tool program for 02-13 - 2-138 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) 0.00 9105.00 0.00 8379.04 9105.00 11000.00 8379.04 8976.36 18 February, 2002 - 14:47 2488.61 E 2493.60 E 1196.26 E Comment Tie On Point Window Point Projected Survey Survey Tool Description Tolerable Gyro (02-13) AK-6 BP _IFR-AK (2-138) Global Coordinates Northlngs Eastlngs eft) (ft) 5950590.64 N 688811.66 E Page 4 of 4 Dogleg Rate (0/100ft) 0.000 Vertical Section 1197.10 . BPXA PBU _EOA OS 02 Comment Projected Survey ~"'"" ..- Dríl/Ouest 2.00.09.008 ~, North Slope Alaska BPXA PBU_EOA DS 02, Slot 02-13 02-13 -2-138 MWD Job No. AKMW22008, Surveyed: 8 February, 2002 SURVEY REPORT 18 February, 2002 .~ Your Ref: 500292043302 Surface Coordinates: 5950516.02 H, 687616.89 E (70016' 10.7219" H, 148028' 57.4424" W) Surface Coordinates relative to Project H Reference: 950516.02 H, 187616.89 E (Grid) Surface Coordinates relative to Structure Reference: 1716.30 H, 19.44 E (True) Kelly Bushing: 57. 60ft above Mean Sea Level spel'l'\{-sul'l DRILLING SERVices A Halliburton Company Survey Ref: svy111 06 Sperry-Sun Drilling Services . Survey Report for 02-13 - 2-138 MWD Your Ref: ,500292043302 Job No. AKMW22008, Surveyed: 8 February, 2002 BPXA North Slope Alaska PBU_EOA DS 02 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9093.60 27.250 107.000 8311.31 8368.91 441.16 S 2488.61 E 5950137.03 N 690115.72 E 2472.78 Tie On Point 9105.00 27.220 107.000 8321.44 8379.04 442.69 S 2493.60 E 5950135.63 N 690120.75 E 0.263 2477.72 Window Point MWD Magnetic 9130.52 27.430 104.060 8344.12 8401.72 445.82 S 2504.88 E 5950132.78 N 690132.11 E 5.351 2488.90 ~, 9164.79 21.540 99.000 8375.30 8432.90 448.72 S 2518.77 E 5950130.22 N 690146.06 E 18.229 2502.68 9194.27 15.700 93.060 8403.22 8460.82 449.78 S 2528.10 E 5950129.39 N 690155.42 E 20.804 2511.97 9226.66 11 .590 83.630 8434.70 8492.30 449.66 S 2535.72 E 5950129.71 N 690163.03 E 14.389 2519.59 9257.53 10.240 85.270 8465.01 8522.61 449.09 S 2541.53 E 5950130.42 N 690168.83 E 4.487 2525.42 9289.66 11 .220 56.330 8496.60 8554.20 447.12 S 2546.99 E 5950132.53 N 690174.23 E 16.859 2530.93 9320.78 11.930 35.790 8527.10 8584.70 442.83 S 2551.39 E 5950136.93 N 690178.52 E 13.366 2535.48 9352.03 12.430 11.660 8557.66 8615.26 436.91 S 2553.96 E 5950142.91 N 690180.95 E 16.252 2538.24 9383.80 14.730 351.760 8588.56 8646.16 429.56 S 2554.07 E 5950150.26 N 690180.87 E 16.284 2538.59 9414.99 18.870 337.970 8618.42 8676.02 420.95 S 2551.61 E 5950158.80 N 690178.20 E 18.340 2536.41 9446.15 24.140 333.190 8647.41 8705.01 410.59 S 2546.84 E 5950169.05 N 690173.17 E 17.810 2531.99 9477.76 28.900 328.550 8675.69 8733.29 398.29 S 2539.94 E 5950181.16 N 690165.96 E 16.413 2525.49 9510.07 33.010 325.210 8703.39 8760.99 384.40 S 2530.84 E 5950194.83 N 690156.52 E 13.783 2516.85 9541.54 36.700 319.230 8729.22 8786.82 370.23 S 2519.80 E 5950208.72 N 690145.13 E 15.970 2506.28 9572.90 39.900 314.670 8753.83 8811.43 356.05 S 2506.52 E 5950222.56 N 690131.51 E 13.609 2493.48 9606.87 43.670 310.540 8779.16 8836.76 340.76 S 2489.85 E 5950237.43 N 690114.46 E 13.736 2477.32 9638.04 47.460 305.640 8800.98 8858.58 327.07 S 2472.33 E 5950250.68 N 690096.60 E 16.542 2460.26 9668.48 52.430 301.060 8820.57 8878.17 314.30 S 2452.86 E 5950262.96 N 690076.82 E 19.973 2441.22 - 9701.33 56.800 299.590 8839.59 8897.19 300.79 S 2429.74 E 5950275.89 N 690053.38 E 13.793 2418.56 9733.10 61 .170 297.980 8855.96 8913.56 287.69 S 2405.88 E 5950288.39 N 690029.20 E 14.424 2395.14 9763.85 65.870 296.170 8869.67 8927.27 275.17 S 2381.38 E 5950300.29 N 690004.39 E 16.166 2371.06 9795.37 69.960 295.340 8881 .52 8939.12 262.49 S 2355.08 E 5950312.32 N 689977.78 E 13.203 2345.19 9826.89 74.020 294.070 8891.26 8948.86 249.96 S 2327.85 E 5950324.16 N 689950.25 E 13.438 2318.39 9858.55 78.430 294.100 8898.80 8956.40 237.42 S 2299.79 E 5950336.00 N 689921.88 E 13.930 2290.75 9891.10 83.790 285.090 8903.83 8961.43 226.67 S 2269.53 E 5950346.00 N 689891.36 E 31.913 2260.86 9921.43 87.790 287.970 8906.06 8963.66 218.06 S 2240.54 E 5950353.88 N 689862.17 E 16.235' 2232.17 9953.72 88.600 280.830 8907.08 8964.68 210.04 S 2209.30 E 5950361.12 N 689830.74 E 22.243 2201.21 9985.16 89.870 280.500 8907.50 8965.10 204.22 S 2178.41 E 5950366.16 N 689799.71 E 4.174 2170.53 ------ - --- ---------, n___.,_-, 18 February, 2002 - 14:47 Page 2 of 4 DrIllOuesI2.00.09.008 Sperry-Sun Drilling Services .. Survey Report for 02-13 - 2-138 MWD . . Your Ref: 500292043302 Job No. AKMW22008, Surveyed: 8 February, 2002 BPXA North Slope Alaska PBU__EOA DS 02 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10017.78 89.750 278.790 8907.61 8965.21 198.765 2146.25 E 5950370.82 N 689767.43 E 5.255 2138.57 1 0058.70 89.470 280.170 8907.89 8965.49 192,02 5 2105.89 E 5950376.55 N 689726.91 E 3.441 2098.45 10091.44 89.670 280.830 8908.13 8965.73 186.05 5 2073.70 E 5950381.72 N 689694.58 E 2.106 2066.47 10122.95 90.000 280.600 8908.22 8965.82 180.195 2042.74 E 5950386.80 N 689663.49 E 1.277 2035.72 ~. 10154.65 90.080 280.660 8908.20 8965.80 174.35 S 2011.58 E 5950391.87 N 689632.19 E 0.315 2004.77 10186.13 89.970 280.780 8908.19 8965.79 168.49 5 1980.65 E 5950396.95 N 689601.13 E 0.517 1974.05 10218.32 89.920 281 .330 8908.22 8965.82 162.32 5 1949.06 E 5950402.34 N 689569.39 E 1.716 1942.68 10249.60 89.870 281 .380 8908.27 8965.87 156.16 S 1918.39 E 5950407.73 N 689538.58 E 0.226 1912.23 10281.53 89.880 281 .280 8908.34 8965.94 149.89 S 1887.08 E 5950413.22 N 689507.12 E 0.315 1 881 . 15 10313.89 89.700 282.810 8908.46 8966.06 143.13 S 1855.44 E 5950419.18 N 689475.32 E 4.761 1849.74 10343.31 89.600 281.920 8908.64 8966.24 136.83 5 1826.70 E 5950424.76 N 689446.43 E 3.044 1821.22 10375.74 89.560 281.520 8908.88 8966.48 130.25 5 1794.95 E 5950430.56 N 689414.53 E 1.240 1789.70 10406.80 88.450 282.000 8909.42 8967.02 123.92 S 1764.54 E 5950436.13 N 689383.98 E 3.893 1759.53 10438.27 86.520 282.390 8910.80 8968.40 117.28S 1733.82 E 5950442.00 N 689353.09 E 6.257 1729.03 10470.55 85.660 282.450 8913.00 8970.60 110.35 5 1702.37 E 5950448.14 N 689321.48 E 2.671 1697.82 10501 .80 85.560 282.100 8915.39 8972.99 103.73 S 1671.92 E 5950454.00 N 689290.88 E 1.162 1667.61 10533.76 85.570 282.850 8917.87 8975.47 96.84 5 1640.81 E 5950460.11 N 689259.60 E 2.340 1636.74 10565.36 84.480 283.380 8920.61 8978.21 89.705 1610.15E 5950466.48 N 689228.77 E 3.833 1606.34 10597.28 84.690 283.800 8923.62 8981.22 82.23 5 1579.26 E 5950473.18 N 689197.71 E 1 .466 1575.71 10629.16 84.950 284.100 8926.50 8984.10 74.58 5 1548.45 E 5950480.06 N 689166.71 E 1.242 1545.16 10660.68 86.590 285.440 8928.82 8986.42 66.56 $ 1518.05 E 5950487.32 N 689136.13 E 6.712 1515.05 .-, 10692.71 88.940 287.190 8930.07 8987.67 57.57 5 1487.34 E 5950495.54 N 689105.20 E 9.145 1484.65 10724.15 91 .560 289.160 8929.93 8987.53 47.775 1457.47 E 5950504.60 N 689075.10 E 10.426 1455.12 10755.18 92.050 289.730 8928.96 8986.56 37.44 5 1428.23 E 5950514.19 N 689045.61 E .2.422 1426.23 10786.60 91.800 288.680 8927.90 8985.50 27.11 5 1398.57 E 5950523.78 N 689015.70 E 3.433 1396.93 10818.82 91.920 288.310 8926.85 8984.45 16.90 S 1368.03 E 5950533.23 N 688984.92 E 1.207 1366.74 10851.19 92.200 288.220 8925.69 8983.29 6.765 1337.31 E 5950542.60 N 688953.96 E 0.909 1336.37 10882.50 92.380 288.360 8924.44 8982.04 3.06N 1307.61 E 5950551.67 N 688924.02 E 0.728 1307.01 10913.00 92.670 287.930 8923.1 0 8980.70 12.55 N 1278.66 E 5950560.44 N 688894.83 E 1.699 1278.38 10934.91 92.870 287.920 8922.04 8979.64 19.28 N 1257.83 E 5950566.65 N 688873.85 E 0.914 1257.79 ,- _H- ------., 18 February, 2002 - 14:47 Page 3 of 4 Dri/lQuest 2.00.09.008 North Slope Alaska Measured Depth (ft) Incl. 11000.00 92.870 '. ,". .!"1.:¡<,!~:t¡,- Sperry-Sun Drilling Services"~~" Survey Report for 02-13 - 2-138 MWD Your Ref: 500292043302 Job No. AKMW22008, Surveyed: 8 February, 2002 Azim. Sub-Sea Depth (ft) Local Coordinates Northlngs Eastlngs (ft) (ft) Vertical Depth (ft) 287,920 8918.78 8976.38 39.28 N 1195.98 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.5150 (18-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 88.1190 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11 OOO.OOt1., The Bottom Hole Displacement is 1196.62ft., in the Direction of 88.1190 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 9093.60 9105.00 11000.00 8368.91 8379.04 8976.38 441.16S 442.69 S 39.28 N 2488.61 E 2493.60 E 1195.98 E Tie On Point Window Point Projected Survey Survey tool program for 02-13 -2-138 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 9105.00 0.00 8379.04 ------ -'.- - 18 February, 2002 - 14:47 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 9105.00 11000.00 Tolerable Gyro (02-13) MWD Magnetic (2-138 MWD) 8379.04 8976.38 Global Coordinates Northlngs Eastlngs (ft) (ft) 5950585.10 N 688811.52 E Page 4 of 4 ---------_._-- ,.. ....,.------ Dogleg Rate (0/100ft) 0.000 Vertical Section 1196.62 .. BPXA PBU_EOA DS 02 Comment Projected Survey ~~-. "--"- DrlllQuest 2.00.09.008 ,I ~VlA\VŒ lID~ lA\~~~[ß~ ALAS KA. 0 IL AND GAS CONSERVAnONCO~SSION / ( / / / / TONY KNOWLES, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson . Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 02-13B BP Exploration (Alaska) Inc. Permit No: 201-243 Sur Loc: 684' SNL, 873', EWL, Sec. 36, T11N, R14E, UM Btmhole Loc. 467' SNL, 1411' EWL, Sec. 36, T11N, R14E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 02-13B. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S incerel y, ~/ ~~-/ Cammy echsli Taylor Chair BY ORDER OF THE COMMISSION DA TED this 21th day of December, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ", STATE OF ALASKA. ALASKA L.- AND GAS CONSERVATION COMMl PERMIT TO DRILL 20 AAC 25.005 ¡ON kit;A (Lli <;j 10 ( 4- \~J~" 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory Dßtratigraphic Test II Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas ~ Single Zone };P 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64' Prudhoe Bay Field I Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 684' SNL, 873' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 938' SNL, 3049' EWL, SEC. 36, T11 N, R14E, UM 02-13B Number 2S1 00302630-277 At total depth 9. Approximate spud date 467' SNL, 1411' EWL, SEC. 36, T11N, R14E, UM 01/20102 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MDt~ TVD) ADL 028326, 3868' MD 02-34 is 746' away at 9100' MD 2560 11652' MD I 898 '. D 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9100' MD Maximum Hole Angle 91 Maximum surface 2458 psig, At total depth (TVD) 8922' I 3350 psig 18. Casing Program Specifications Setting Depth Ouantitv of Cement Size Too Bottom Hole Casino Weioht Grade Couolina Lenath MD TVD MD TVD (include staae data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2700' 8950' 8242' 11650' 8879' 1340 sx Class 'G' ,.. !' ~ . § . <:::> ~ j 19. To be completed for Redrill, Re-entry, and Deepen Operations. jjj ~ II Present well condition summary 'r-f Total depth: measured 10804 feet Plugs (measured) Baker IBP set at 9038' (02/01) (.) C,,) true vertical 8963 feet LCJ ~ c::JJ Q5 Effective depth: measured 9038 feet Junk (measured) Q:; ã true vertical 8320 feet to Casing Length Size Cemented MD Structural Conductor 76' 20" 431 sx Arcticset II 76' 76' Surface 2728' 13-3/8" 2300 sx Fondu, 400 sx PF II 2728' 2728' Intermediate Production 9582' 9-5/8" 1335 sx Class 'G' 9582' 8806' Liner 905' 4" 28 Bbls Cement 8966' - 9871' 8256' - 8957' Pre-Drilled & Slotted Lnr 1002' 2-7/8" Uncemented Slotted Liner 9676' - 10678' 8883' - 8962' Perforation depth: measured Pre-Drilled Section: 9739' - 10368' Slotted Section: 10368' - 10645' true vertical Pre-Drilled Section: 8920' - 8951' Slotted Section: 8951' - 8961' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Skip Coyner, 564-4395 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fOregOing~, e ~~yo the best of my knowledge Date ( zll L¡ ) 'D J Signed Brian Robertson (A N . Title Senior Drilling Engineer I,.",' """";"'"i' ""'"",,.,',1: '.:.:,' "11"11;,;,,.,;, ,"~"': """""!"""".""'I""".'I""""""""tJ"I'I"":'lcf""'J""f'I,"'II,:I""'I:"'I"",:,"I':;',"r".cI"'I""""":,,':'I::""":f':',,i""¡":"I""",:..",""'d':""il,"I",...i'I""':",i:,~':I"""':""';il""""""I",""i"""'i:"""".'li'::-,',",I":," I':':,"" "::"-"1,.:,,.,, S1Iornm~.~,I~pl'¡¡'le'I¡I', ",' '~']:;llill'I'I";:I'I¡I':III"":'I",:,'¡'I'i":I"I'",11"';""",:1;,'1"':":/"'1"'1:"';"""":"":"""'1' ","", '. '.,,',.: ,I' '., " ", ,', ,'!, ; ',"," ",'.. ..,,:',' I, ",""'!"'" ',"'" ",,':' I," , "I '/",1,:,,',' " '.."':", ,."" "::ii,": ,:' :",:.., ""I. <,,':: .,:' ":",::..",,, , ","""",' .. '::""': ",," ," "'I".," ',", , '."':',,' ',1."""'; . , ;, :' I.' Permit Number. 2. Lf-.3 API Number Ap'p rtm I \~'a I See cover letter 2-D {,., . 50- 029-20433-02 .,~ .\ 'I for other reQuirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log Áelquirèét 0 Yes mNo Hydrogen Sulfide Measures DYes ,r&(No Directional Survey Required ÐYes ONo Required !'orking Pressure for ~OPE p 2z. ~K 04K 05K 010K 015K 0 3.5K psi for CTU Otheç .1 ~sf~ ~~PE to 3500 fS>{, ~ ~ IS A\h I Onglna Igne y by order of Aooroved By ... -.' f"Þor1is:"pl the commission Date I I - ~o s e A . Form 10-401 Rev. 12-01-85 UI r< lJ i\ AL SuÞ mit ¡l Triplicate ( ( I Well Name: 102-138 Drill and Complete Plan Summary L!ïPe of Well (service 1 producer 1 injector).:j Producer Surface Location: X = 687,616.9 Y = 5,950,516.0 684' FN L 873' FWL T 11 N, R 14E, S 36 Umiat Target Location: X = 689,799.77 Y = 5,950,318.07 938' FN L 3049' FWL T 11 N, R14 E, S 36 Umiat Bottom Hole Location: X = 688,150 Y = 5,950,747.01 467' FN L 1411' FWL T 11 N, R 14E, S 36 Umiat I AFE Number: 4P0475 I I Estimated Start Date: 101/20/2002 I lB!9 : I Doyon 16 l.Qperatin~s to complete: 122 1 MD: 111 ,652' I ITVD: 18,980> I Top Edge Cellar/MSL: 30' RKB: 64' (original) I Well Desi~(conventional, slim hole, etc.}J Horizontal Sidetrack ~ective: I Ivishak Zone 1 A & 1 8 Mud Program: 6-1/8" Production hole: QuickDrii N Interval Density Viscosity VP PV Tauo pH (ppg) (seconds) (I b/1 00ft2) Milling 8.3- 8.5 50 - 70 35 5-8 4-8 8.5- 9.0 Production 8.4- 8.7 45 - 60 20 - 25 5-8 4-8 8.5- 9.0 Di rectional: KOP: 1-9,100' MD Maximum Hole Angle: 910 Close Approach Wells: 02-04: 993' center to center distance at 11,578' in 02-138 02-22: 777' center to center distance at 9,475' in 02-138 02-31: 780' center to center distance at 9,995' in 02-138 02-34: 746' center to center distance at 9,100' in 02-138 02-35: 1247' center to center distance at 11,121' in 02-138 02-138 Permit to Drill Page 1 ( ram: 1'; ~ Drilling: MWD / GR / DEN / NEU / RES Open Hole: None Cased Hole: None Formation Markers: Formation To s MD - RKB SGR 9,087.3' Window/KOP 9,100.0' SHB 9,128.5' TSAD 9,205.8' Zone 4 9,205.8' Zone 3 9,293.4' Zone 2C 9,455.8' 23SB 9,549.8' 22TS 9,584.9' 21TS 9,647.1' TZ1 B 9,738.2' TDF Z1 A 10,576.0' TD 11,651.8' TVD 8,364.0' 8,375.3' 8,400.5' 8,472.5' 8,472.5' 8,658.5' 8,715.5' 8,796.5' 8,824.5' 8,869.5' 8,922.5' 8,989.5' 8,979.5' Comments 7.43 7.43 7.43 7.43 7.43 7.43 7.43 7.43 7.22 7.43 7.43 si EMW, 10' vertical uncertaint EMW, 10' vertical uncertaint EMW, 10' vertical uncertaint EMW, 10' vertical uncertaint EMW, 10' vertical uncertaint EMW, 15' vertical uncertaint EMW, 15' vertical uncertaint EMW, 20' vertical uncertaint EMW, 20' vertical uncertaint , 3350 EMW, 20' vertical uncertaint EMW Casin lTubin Pro ram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tb O.D. MDrrVD MDrrVD bkb 6-1/8" 4-1/2" 12.6# L-80 IBTM 2,700' 8,950' / 8,242' 11 ,650' / 8,80' Tubin 4-1/2" 12.6# L-80 TC-II 8,950' Surface 8,950' / 8,242' Cement Calculations: Liner Size 4-1 12" Hole Size 6-1/8" Basis: Based on a fully cemented liner with 30% excess, 82' shoe track, 150' of 4-1/2" x 9 5/8" annulus, and 200' of cement in the 5" DP x 9-5/8" annulus. Tail TOC: 8,750' MD, 8,066' TVD Cement 70 bbls I 391 ff'1 340 sks of Halliburton Premium 'G' + 0.5% UCS + 0.50/0 Volume: Halad-344 + 0.25 fisk Super CBL + HR-5 mixed at 15.8 ppg & 1.15 cf/sk. Inte rit Testin Test Point Test De th 6-1/8" Window 5' minimum of new hole 02-13B Permit to Drill Test T e FIT EMW 10.5 ppg Page 2 ( ( Well Control: For production hole drilling, well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3,500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Max. anticipated BHP (SAD): . Max. surface pressure (SAD): . Planned BOP test pressure: . Planned completion fluid: 3,350 psi (7.2 ppg) @ 8,922' TVDss - Ivishak Sands 2,458 psi @ surface (8HP minus full column of gas @ 0.10psi/ft) 3,500 psi sea water I 2,200' of .6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S . DS 2 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. There have been no reports of any well havingH2S of 10 ppm or higher on DS 02. DRilliNG CLOSE APPROACH . Wells 2-22, 2-31, 2-34 and 2-35 all pass BP risk based close approach guidelines: Well 2-04 2-22 2-31 2-34 2-35 Minimum Closure 993' 777' 780' 746' 1247' DISPOSAL . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. 02-138 Permit to Drill Page 3 (' (' DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rica Work: ~\ ? t:J \ ::') * Notify the field AOGCC representative with intent to plug and abandon * 1. Retrieve the HES "DWP" tubing patch at 4157' MD (2.992" 10). 2. Retrieve the IBP from the 4" liner at 9038' MD. 3. Drift the 4" liner to +/- 9600' with 3.125" tools. 4. Open the sliding sleeve at 8852' MD. 5. Flush the tubing & IA with seawater. Bullhead seawater into the "A" lateral. Freeze protect. 6. Run SCMT in the 4" liner: 9600' - 8600'. Find TOC in 4" x 9-5/8" annulus. 7. Set an EZSV cement retainer (3.12" 00) in the 4" liner below the TOC and below 9200' MD. 8. Sting into the EZSV. Bullhead +/- 35 bbls of class "G" cement below the EZSV to plug the "A" lateral. Circulate the well clean above the EZSV. Freeze protect. 9. Jet cut the 4" tubing at +/- 9200' MD (but above the TOC). 10. Chemical cut the 5-1/2" tubing in the middle of the 1 5t joint above the PBA: at +/- 8925' MD. 11. PPPOT the 9-5/8" packoffs to 3000 psi and the 5-1/2" tubing hanger to 4000 psi. Check the LOS for free movement. 12. Freeze protect tubing and annulus with diesel from 2200' to surface. 13. CMIT to 3000 psi against the EZSV and cement. 14. Set a BPV and remove the well house and flow lines 15. Clear and level pad in preparation of the rig move. RiQ Workover Procedure 1. MIAU Doyon 16. 2. Circulate out freeze protection fluid and circulate well to clean seawater. 3. Set TWC. NO tree. NU and test BOPE to 250/3500 psi. 4. Pull and LD 5-1/2" tubing string to the cut at +/- 8925' MD. 5. Spear and retrieve the 5-1/2" tubing stub and the PBR seal assembly. 6. Spear and retrieve the 4" liner above its jet cut at +/- 9200' MD. 7. Spear and retrieve the PBA and anchor. 8. RIH with a packer picker. Mill and retrieve the SAB packer and tubing tail. 9. Make a bit and scraper run to +/- 9200'. Displace with QuikDrill. POOH. 10. AU E-Line. Set a CIBP in the 9-5/8" casing at +/- 9125' MD. RD E-Line. Test to 3000 psi. 11. AIH. Orient and set the Baker bottom trip whipstock on the CI~"with the top at:t 9100' MD. 12. Mill the window. Circulate the hole clean. Perform FIT to 10.5 ppg EMW. POOH. 13. AIH and drill the 6-1/8" build section at 14-15°/100ft and land at horizontal in Zone 1B as directed. 14. Trip for bit and MWD configuration as required. 15. Drill the 6-1/8" lateral "B" in Zone 1 B and then drop down in search of Zone 1 A. 16. Continue drilling the 6-1/8" lateral "B" as directed. The planned TMD is 11652'. 17. At TO, set & cement a 4-1/2" liner from TO to +/- 8950' MD. Displace the liner with "Perf Pill". Bump the plug and set the liner hanger. Set the ZXP packer. Circulate the hole clean. POOH. 02-13B Permit to Drill Page 4 (' ( 18. PU OPC perforating guns. RIH and space out. Perforate as directed. Circulate bottoms up. Flow Check. POOH checking for proper fill up. 19. Run the 4-1/2",12.6#, L-80 completion with S-3 packer. 20. Set the packer. Test the tubing to 4000 psi. Test the IA to 3000 psi. 21. Set BPV. NO BOPE. NU and test the tree to 4000 psi. Freeze protect to + 2200'. 22. ROMO. Post RiQ Procedure 1. Install flow line and re-set wellhouse. 2. Pull the BPV using a OSM lubricator. 3. RU slickline and retrieve RHC sleeve, etc. 4. Run live gas lift valves as needed (replace the RP valve). Job 1: MIRU Hazards and Contingencies ~ Wells 02-33 and 02-12A located over 100' from 02-138. These wells should not require the well houses to be removed and will not need to be shut in. Reference RPs .:. "Drilling/Work over Close Proximity Surface and Subsurface Wells Procedure" ",.,., """""'"'. " .""'~ Job 2: Decomplete Well Hazards and Contingencies ~ Trapped gas below the packer ~ NORM test all equipment recovered from the well Reference RPs .:. "De-Completions" Job 3: Run Whipstock Hazards and Contingencies ~ Cement is expected behind the 9-5/8" casing at the window depth ~ The minimum T/whipstock depth is 9100' MD (8375' TVD) Reference RPs .:. "Whipstock Sidetracks" Job 6: Drilling Production Hole Hazards and Contingencies ~ No mapped faults along the 02-138 well path ~ Differential sticking may be a problem if the drill string or liner is left stationary for an extended period of time across the Ivishak Sands. Minimize ECD. ~ Hole cleaning is critical in the 3-1/2" x 9-5/8" annulus. ~ Torque and drag may become excessive ~ The kick tolerance for the 6-1/8" production section would be infinite assuming an influx from the Ivishak formation at 9738' MD (8922' TVD). This is a worst-case scenario based on a 7.22 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the window, and 8.5 ppg mud in the hole. 02-13B Permit to Drill Page 5 .( ( (' );> There are no close approach wells for the 02-138 well trajectory. distance in Directional section above. Reference RPs .:. "Prudhoe 8ay Directional Guidelines .:. "Lubricants for Torque and Drag" See center-to-center Job 7: Install 4 Y2" Production Liner Hazards and Contingencies );> Differential sticking could be a problem in the Ivishak sands. Minimize the time the pipe is left stationary while running the liner. );> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight to set the packer. If the stinger is pulled out of the liner top prior to setting the packer, POOH to remove the stinger prior to setting the packer. Reference RPs .:. "Casing and Liner Running" .:. "Production Interval Cementing" .:. "Running and Cementing a Liner Conventionally" Job 8: Perforate with DPC Guns Hazards and Contingencies );> Tag the liner wiper plug to get on depth. );> Differential sticking may be a problem after the well is perforated. );> Seepage and/or swabbing may be seen while POOH. Reference RPs .:. "Drill Pipe Conveyed Perforating" Job 9: Run Completion Hazards and Contingencies );> Clean and drift the new tubing. Use a stabbing guide and Torque Turn service. );> Displace the IA with + 1300 F packer fluid before spacing out and setting the packer );> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ..... 0.1 psia at 100° F. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protecting an Inner Annulus" """ --.. ,...".._", .. AI"""" Job 10: ND/NU/Release RiCl Hazards and Contingencies );> See hazards related to the MIRU in Job 1. Reference RPs .:. "Drilling/Work over Close Proximity Surface and Subsurface Wells Procedure" , , 02-138 Permit to Drill Page 6 PRUDflOE BAY UNIT WELL: 02-13A PERMIT No: 94-165 API NO: 50-029-20433-01 SEC 36 TIN RI4E ORIGINAL COMPLETION OS/20/80 CTD SIDETRACK 02/28/95 ( RKB = 64' (' 02-13A ( Current) ~';,;. 'of' ~;::, .--. ,/', .", , ,t', ,". ""-, ~¡":, .", '.1'" ,", "t, ,", . "'" .",' ...' ."" .... 2728~" '.,~'i. " '.' ;'~'.~ "., .'..' ", . .'..' "", "'.' ;:,: .~ :,:.) "., .'..' "., .'..' "., ,t'.' "., '..' . , 13-3/8", 72#, L-80 RQM SSSV Nipple at 2205' Tubing Patch 4157' at 4157' ID = 2.992" I. 5-1/2", 17#, L-80 Tubing ~ SAB PKR at 8965' T/SAG at < 9100' MD, 8365' TVD 5-1/2" Tail Pipe assembly EOT at 8966' MD Calculated TOC at +/- 9200' MD 4", 1 0# Hydril F J Liner Did not make it to TD TOL in the PKR: 8950' , ., " .'" , :,', , 9-5/8", 47#, L-80, BTC ~ "" M~ .. .. ~~, .. ',' .. .. , ," , ' , . , '" " . ",:,',' ,. "'...' 02-138 Permit to Drill Page 7 PRUDHOE BAY UNIT WELL: 02-13A PERMIT No: 94-165 API NO: 50-029-20433-01 SEC 36 TIN RI4E ORIGINAL COMPLETION OS/20/80 CTD SIDETRACK 02/2R/9~ (' RKB = 64' ( 02-13B (Proposed) :~':: ,". ,? ,". .¿. ,". , ,!'" ,". '.. " ,.'. "¡<" ,". ',!", ,". ,,¡<. ..'. '¿" ,". . "" ..', '.. .' , . ., ...' "",' "" .',,' ..... ."'.' ...' .",.' .".' .".,' "..' ",,' "., .".,' "., .'.,' .... .",.' .".' .',,' ..... ..' , . 13-3/8", 72#, L-80 BTC 2728 "X" Nipple at + 2200' 4-1/2", 12.6#, L-80, TC-II Tubing ..... 8-3 PKR at + 8900' MD - ..... HMC & ZXP at + 8950' MD - KOP @ 9100' MD 11652' MD . ... .- , ..- ....... I () . , ' , ' , ",", '. -. -" " '..", ", " ',' 4-1/2", 12.6#, L-80, BTC Liner wI DPC Perforations TBD 9-5/8", 47#, L-80, BTC . .. -. -. -" -. ,.. -. -" .. , " , . ,',";"",',. ", ,,':.. ' ' "', :- ' .. :'.~:' J' ~,'.-: 02-138 Permit to Drill Page 8 (OMPA"'" 7200 - 7500 7800- ';:: :§ 8100- g :::è ~ g- O ¡j E > ~ i: 8400- 8700- 9000- 300 ( 600 INIl""',' I ION PROGRAM "h", 2-lm wpO7 IO2.liiph", 2-lm L,mg",w,lI; '""N",," """ I 2i]!2()O I 11'1'1 '",AIi", I'bl'"",1 2.111) we'" VI MW" ("hex-k,n' ",,' Dòll Will ""AIIS Nm'h"'g Sim 11 02. ) (71627 21" \95051654 "'761721 IARGET "ETA II'S N"'k IV" .w-s 'L.W NmO""g Shop, l I I .I I ¡ø 1fP I ¡; l ,l See Ine SECTION DETAILS Azi TVD +N/-S +EI-W DLeg TFace VSec Target 106.00 8375-26 -440.77 2488.69 0.00 0.00 2143.18 100.87 8392.98 -442-92 2497.71 12.00 -85.00 2150.74 305.25 8774.79 -390.92 2498.41 14.90 -164.62 2170.84 305.25 8791.59 -384.42 2489.21 0.00 0.00 2164.74 286.00 8974.50 -252.89 2177.29 14.50 -22.81 1924.66 2-13B TI 286.00 8974.50 -252.83 2177.06 8.00 7.41 1924.47 286.00 8974.35 -129.39 1746.64 0.00 0-00 1571.46 286.00 8974.50 -124.71 1730.32 6.00 -179.86 1558.08 2-13B1'2a 286.00 8980.54 -100.23 1644.97 6.50 ] 79.96 1488.07 286.00 8988.32 -82.21 1582.14 0.00 0.00 1436.55 286.00 8994.50 -53.49 1482.00 6.50 -0.03 1354.42 2-I3B 13 286.00 8994.23 -47.28 1460.34 6.00 -0.14 1336.66 286.00 8984.62 64.98 1068.77 0.00 0.00 1015.50 286.00 8984.50 66.59 1063.14 6.00 179.48 1010.87 2-13BT4 286.01 8984.39 68.79 1055.4 7 6.00 179.19 1004.58 286.01 8979.50 217.13 538.40 0.00 0.00 580.53 2-13B T5 MD 9100.00 9120.00 3 9523.61 4 9543.84 5 9945.70 6 9945.93 7 10393.71 8 10410.69 9 10499.73 10 10565.54 II 10669.97 12 10692.50 13 11099.96 14 11105.82 15 11113.80 16 11651.75 27.50 27.80 33.85 33.85 90.00 90.02 90.02 89.00 83.21 83.21 90.00 9135 9135 91.00 90.52 90.52 .#,#' #' ~ '/~ #' FORMATION TOP DETAILS No. TVDPath MDPath Formation 8400.50 9128.45 Shublik 8469.50 9202.64 Eileen 8472.50 9205.76 TSAD/TZ4B 8558.50 9293.40 TZ3 5 8715.50 9455.77 TZ2C 6 8796.50 9549.78 23SB 7 8824.50 9584.85 22TS 8 8869.50 9647.12 2JTS 9 8922.50 9738.17 TZIB 10 8989.50 10576.03 TZIA CASING DETAILS No. TVD Size MD Name 8979.50 11651.74 41/2" 4.500 All TVD depths are ssTVD plus 64.5' for RKBE. 900 T 2400 Vertical Section at 68.04" [300Mn] (i""'ANY )1 (MIS MW ) SURVEY PROGRAM Ikp,"E" "WI> In "';;IF CASING DETAILS 1)1 IAJlS N"", N"""me TVD 8979.50 MD Size Name 2ur \950516.54 ""61721 11651.74 41/2" 4.500 rARGET DETAR.S 1\'" N.S "bo2-UBwpil7iO2-IWE",2-IJBL""gccwdii Bv K", .\11", (,"cr-ke'd WJi20!1I ),lc' "",iewed lJ,," L","",k ¡"""i,m', SI," 70"16'l0.727N 14'--manw N"""",, Slwp..' SECTION DEl AILS See MD Inc Azi TVD (N/-S +E/-W DLeg TFace VSec Target I 9100.00 27.50 106.00 8375.26 -440.77 2488.69 0.00 0.00 2143.18 2 9120.00 27.80 100.87 8392.98 -442.92 2497.71 12.00 -85.00 2150.74 3 9523.61 33.85 305.25 8774.79 -390.92 2498.41 14.90 -164.62 2170.84 4 9543.84 33.85 305.25 8791.59 -384.42 2489.21 0.00 0.00 2164.74 5 9945.70 90.00 286.00 8974.50 -252.89 2177.29 14.50 -22.81 1924.66 2-I3B TI 6 9945.93 90.02 286.00 8974.50 -252.83 2177.06 8.00 7.41 1924.47 7 10393.71 90.02 286.00 8974.35 -129.39 1746.64 0.00 0.00 157L46 8 10410.69 89.00 286.00 8974.50 -124.71 1730.32 6.00 -179.86 1558.08 2-I3B1'2a 9 10499.73 83.21 286.00 8980.54 -100.23 1644.97 6.50 179.96 1488.07 10 10565.54 83.21 286.00 8988.32 -82.21 1582.14 0.00 0.00 1436.55 II 10669.97 90.00 286.00 8994.50 -53.49 1482.00 6.50 -0.03 1354.42 2-13B'1'3 12 10692.50 91.35 286.00 8994.23 -47.28 1460.34 6.00 -0.14 1336.66 13 11099.96 91.35 286.00 8984.62 64.98 1068.77 0.00 0.00 1015.50 14 I 1105.82 9LOO 286.00 8984.50 66.59 1063.14 6.00 179.48 1010.87 2-13B T4 15 11113.80 90.52 286.01 8984.39 68.79 1055.47 6.00 179.19 1004.58 16 1165L75 90.52 286.01 8979.50 217.13 538.40 0.00 0.00 580.53 2-13B 15 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 8400.50 9128,45 Shublik 2 8469.50 9202.64 Eileen 3 8472.50 9205.76 TSA))/TZ4B 4 8558.50 9293,40 TZ3 5 8715.50 9455.77 TZ2C 6 8796.50 9549.78 23SB 7 8824.50 9584.85 22TS 8 8869.50 9647.12 2 ITS 9 8922.50 9738.17 TZIB 10 8989.50 10576.03 TZIA 400' :s § '" C'::, 0- All TVD depths are ssTVD plus 64.5' for RKBE. :E 1:: 0 ~ :E 0; 0 en -400-' -800 400 800 1200 1600 West(-)IEast(+) [400ft/in] 2000 2400 2800 02-13 3200 ,( BP Amoco { Planning Report - Geographic ]. - -~~~~a~~~--~~~~~~y "'----"----"-----'-'---------'-"----- ~~~din~~~~ ~eference:T~I~ 0~~1:~~~~:"'~O~h -'---p~;~~--'-'---~---"-1 Site: PB DS 02 Vertical (fVD) Reference: 2-13B 64.5 64.5 ¡Well: 02-13 Section (VS) Reference: Well (0.00N,0.00E,68.04Azi) I L,~~_II_~~~~_.,.~~~!'._2-13B Long!r ~!~--------- Plan!...___,_--~! 3B wpO~-------------_.._.._------------_._--_____..1 "'., --'----""--"---'--'---,-..--_.._'_m_. .------..-,.--------..-------..--..--.-,---.,-.--..-,----.,-..-.,-----,-------------,----.----.-----------,------..- --'-OO-----------'-------'-..- - ..- Field: Prudhoe 8ay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Goo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre c_~y_s D~~~:..~~~~~~,~_~~,,:,:I____._--- --_._------------_.._-,----_.._---___._~eomagn~~..~~de~~----,-- 8GG~~~~-~- -------------- ---""'----'---'-"---.- '.'- --- --. -----------,-------,-,---,- ----.------ __m._____.-_._..._.-.,_._--_.__.._,..._-----~_._-_.._.._, --.-..---.----------..--.--... ,-_.. -,.,- .-..--,.----.- _._--,_..,- ,....-...-.- - . --- P8 DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5948800.37 ft 687638.44 ft Latitude: 70 15 53.847 N Longitude: 148 28 58.060 W North Reference: True Grid Convergence: 1.43 deg ,.. ..,. ....- -., .,.. "'-"'-'-..-...--.-..----- -- -..... .-- ,...,-,. ""'-'---"---, ---"""'--'--'---'-----'--'----""'----- - "'----"'---'-------"-----""--'-'-------"- u..-"...-- ----""-'-----'--"-'--"'-""--.-....'--' ,,""--'---,-..-.. -,.-...,--.. -.... ..... ....-..-.........,..-..-.....-.,--..---.-.-...-.-,.-,..---..,...--"""""-'-------'---""--'--"'--'---"-"------"---"----'-.-.--.-.-..-.,--,.---..----.--,---..---.,..--....---...----"-'--'-'----""'- -.....,.----------.,-,..,...-. .. ... .--.".,-,..---...--,. ...- - ..._--,.._-,- Well: 02-13 Slot Name: 13 02-13 Surface Position: +N/-S 1716.27 ft Northing: 5950516.54 ft Latitude: 70 16 10.727 N +E/-W 21.55 ft Easting : 687617.21 ft Longitude: 148 28 57.433 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 1716.27 ft Northing: 5950516.54 ft Latitude: 70 16 10.727 N +E/-W 21.55 ft Easting : 687617.21 ft Longitude: 148 28 57.433 W Measured Depth: 34.50 ft Inclination: 0.00 deg Vertical Depth: 34.50 ft Azimuth: 0.00 deg .. ....,.... --. ..".,_.,.'u ......---.,.--,.,-.... ..,.--,..,......----,-. --'-"'---"-""-'-""-'--'-'------'---'--"---"'---"--.......,-.,-.-,.---..---------.,.-.,----.--., "----"-"'-..,..------,._.____n._____-.,.-,.-,.--.--..-..-..-.-.-...,--.-..-.--. ..,.,-..---. -.. .--_...... -.-..-.-., ... ...,.-.......-,......-..,. ,- ,...... --,--..,.-.-..- ,-.- "_"m_.."_'..,',-"-,,-,,,---,- ".'._, "-"-""'-'-"-"'-"---"-"--'-"'--'---'-"""-'" - "-"""'---"-""-"'-'-------'-' .,.---.. .--.-.-...,...------.-..-.--..-.-,...--,.-----...-..-..-....----.-.. ...---..----.....---.-... ....., ,. --"-.......,..--.,..-- Wellpath: Plan 2-138 Longer well Drilled From: 02-13 Tie-on Depth: 9100.00 ft 2-13864.5 Height 64.50 ft Above System Datum: Mean Sea Level 2/21/2001 Declination: 26.86 deg 57498 nT Mag Dip Angle: 80.79 deg Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ... -, ..-.... ,_......_,- .,--..------........_-_., ,.--.-....-..-.-- .-.-,-....------.....,.--.-..--...--.-,--...------.-------.-----,-,-----,._------,.__._,---_._,---,_.._- 0.00 0.00 0.00 68.04 --'--'--""---"'.__'__m_'__'_-",-,,- Current Datum: Magnetic Data: Field Strength: Vertical Section: . ....._...'-'...,.,...,.., -'.'.'._,... . -...-..,.,.-,-.....,.,.-,......-,.-,.-.--,..,---.,-.....-... -'--------"-""".,..-,..,---..---.."...,.--,------....--..--""'--""-'-"""-"---'-""'-"---"""- '-"'--'---""""--""-"""--""'-"'-"-"""-"'-------"--"'-""-"--"---'--'---'--"'--""'-'-'-""'-..-.-,.....,-..,,-,.,.---.-.,--..-....,--. .-,-..,..-. --.".....,-..-..,.,....-- ..- -...-..--........--..-.....----., -,. Plan: 2-138 wp07 Date Composed: Version: Tied-to: 12/3/2001 1 From: Definitive Path Principal: Yes -""--'--'-."'-"'" -..--.,. ......_,.._,-_... ""'-"'-""""-'-"-"-"""""--'-"""'----'-"""-'""-""""'-'---"'-"'-"'-'--'-""""-"-'-"----""-'---..-.-,-...,.....-,..--,.-,.,.,-.,....-...---..-...---..----...--....,...,..---.---,.--.,--.-., -----.-.,---.,.. Plan Section Information '-':'~:';:ë7 .':;":;~...__.;:.:":'~,.. ':' ":'ê"~""~':;ë'::-..!7...,"'-ë,:";-'..,.':'7,""::"': """"~- ""ë;'77c7'T"'::~;""'7';-"~;':":'":""":::'7~:,,-r-:""~"'7~~ë"-":"~::':"-:"":-;-::"......'7::'~?;'-":~:7'-:;;?7:'?,.."TF~:;"-"":-¡ ':':;"'-";:"""'ë:-7'":,,,~::,:"¡'."""--'7" ,.-.. .",-.;; :-c:-c -"""".' c: ,::M~ ,"'... ,"..,..~n~~ ":":':'. '..,.:.Azim..'"",....,.,""",' ,;ry-p.'..... ,"'.,..~lS(::~, .." ".,.,tEZ.,'Y."',.:.:'."...'...,~.ç§'i:~,IJUil~,.,:x;~rll'~ '",,',',,~:FQ,l:)'l'get ',""""""". .',.,....'..'" ....,.,' .'" .,' f,ì.'.".'.:,'.:'....'.'.'.':.'.:'..,:.d, S..g':'.'.,..".'.'..i."..:::'.::'..d.e.'.g..':..'."....'.",:,:.,'::,..::"..':..,.,.<.::..:.,.:"...ft...':.'..,""..':::,:.".'.,;.:.,'..:.:".'."'."':.'.'.:'.'. :ft..'.~'.:'. ".'.'.'.:..'..""':.:.'.,'..',,:..'ft..":,.'.".'.'i.i',..d.8.'.'.:.:g/"".'~.'Ð.Oft...'...'..,,.,'~.".eg./l0.'..'O..J+..,'.:.".'~.:,.e.'.."gl..1.0.0. ft..'. :,,"".:.:'. "...""". d. e.'..'.S".":'.'.:.'....:':"'.'.'.'::':""":":"':""::":'.':,""::".'..':.".,.:...':..""":":'.",:'.,.'.i..,.'."":',::",::.'. "".....:'."",::,,",",",::"""." . ...._, ....'... ..::.., -.,~ .:c ..~ -'-' c. :....... ...".,._.....~_c" ,:..~: --~.: _m:':".,.. -""'" ._-CC--,- ,..;.:..~". ~ \.,_:.:..~":""'::.:~~"..:::.~-,- ,..,::"~~"':";,_"::,:_:.'~~,.,,..:i~:~..--,~LL"~i:..:L,:::.:..,:..i:~_£.",","":.~~..,~.~,~..,~~.1:"::.,.~-,.:::,,~i:'__:_L"'c...,,_..._",,.:i-,"_;:';:~..;..c::.:';-~,~.:.~-_.~._':':.i::..,:~..:_.."._::_c.,_.._"': .':".:.,..,,:- :.- .",c 9100.00 27.50 106.00 8375.26 -440.77 2488.69 0.00 0.00 0.00 0.00 9120.00 27.80 100.87 8392.98 -442.92 2497.71 12.00 1.52 -25.66 -85.00 9523.61 33.85 305.25 8774.79 -390.92 2498.41 14.90 1.50 -38.56 -164.62 9543.84 33.85 305.25 8791.59 -384.42 2489.21 0.00 0.00 0.00 0.00 9945.70 90.00 286.00 8974.50 -252.89 2177.29 14.50 13.97 -4.79 -22.81 2-138 T1 9945.93 90.02 286.00 8974.50 -252.83 2177.06 8.00 7.93 1.03 7.41 10393.71 90.02 286.00 8974.35 -129.39 1746.64 0.00 0.00 0.00 0.00 10410.69 89.00 286.00 8974.50 -124.71 1730.32 6.00 -6.00 -0.01 -179.86 2-138 T2 a 10499.73 83.21 286.00 8980.54 -100.23 1644.97 6.50 -6.50 0.00 179.96 10565.54 83.21 286.00 8988.32 -82.21 1582.14 0.00 0.00 0.00 0.00 10669.97 90.00 286.00 8994.50 -53.49 1482.00 6.50 6.50 0.00 -0.03 2-138 T3 10692.50 91.35 286.00 8994.23 -47.28 1460.34 6.00 6.00 -0.01 -0.14 11099.96 91.35 286.00 8984.62 64.98 1068.77 0.00 0.00 0.00 0.00 11105.82 91.00 286.00 8984.50 66.59 1063.14 6.00 -6.00 0.05 179.48 2-138 T 4 11113.80 90.52 286.01 8984.39 68.79 1055.47 6.00 -6.00 0.09 179.19 11651.75 90.52 286.01 8979.50 217.13 538.40 0.00 0.00 0.00 0.00 2-138 T5 . -"""""'.'...m__.'_.,-"---",--"""",-""""",,-""---""-'.'-"-'-'-"--"'-"""""""-'----"""""'--,-.---..--....-,.-.--..-...---.-.-.-.-.,...-.---,---,-,-"-'------------'-'---"--'--"---"""'----'---'----'-""",-------""""-"'-"--""--"'----...............,...--,---.....--'--'----'-----"'--' ,.'... Section 1: Start ,. - .' ,- --," """'"C'C:"""-'-'- ----- ,..--"...-,-."..,. -, -"-"""'--""'--"'-""""'-"'--;--"'---"""""",,- .---~'ë":--~"""---""""""""""-'-",.......,..,..""":----"""'-"~'7""-",,--._-c=-;:--..,...-c,,..,.,,. '-------,-'~ ....-.,..,--"" -",,-"""- -~- '.... -',_.. 'MD" ""Incl." . Adm"" :1VD. "+Nl..S""" .f'Et;.yv." VS "" ,DhS', > Build "" "Turn '."" "1FO' "ft.' .";deg. "..deg ,""",,"...ft,,". ".' ,'""""ft'...",.","".",.."..,ft..".".",, ,.,.",tt ,,".'.." "...de9/10Ó~9~St10Òftde9doQft .,,",,"deg .,," ..".. .. ".. " '- . ...... -,---- ..-'.",. ..-....- '----.. "--- .--- -_.,-_._.~ - ...- _.-.,--,-"---- .. -..--- --, --~.. - --, _"0_._- ---.. ~-~ -.. _._-,- -- ..~---, ,---- o,----,"~,_.__.. ~"._~._-, -0.__.. ,-. ~._-"-"_.,_.""--_._- ,---. .-. -,,- --...- -.........., _.0. _.. -, "...".~ 9100.00 27.50 106.00 8375.26 -440.77 2488.69 2143.18 0.00 0.00 0.00 0.00 9120.00 27.80 100.87 8392.98 -442.92 2497.71 2150.74 11.99 1.50 -25.65 -85.09 . . 0-"_'_" -'..,.-..,-.........,-..-"'---"'-'-"-_.._..m.'..""--'-'-"--""----"---""-'-'--"'--"---"'--"--'---""'--'---""'-""-"--"'----""---..--..--.--.,..-.--.-.-,.-....---.'--"""'-"--.-""'-'------"'---'--"'--""--""'--""'-"- .,-,_.._.... ..--.---...-----,.-....- ---,.,....,-.---.-,-.. .--,.."'--'" ...,-...-.-. ( BP Amoco ( Planning Report - Geographic ,- Company: BP Amoco Date: 1213/2001 Time: 15:50:38 Page: 2 ~I ' Field: Prudhoe Bay Co-ordinate(NE) Referenœ: Well: 02-13. True North . Site: PB DS 02 Vertical (TVD) Referenœ: 2-13B 64.5 64.5 I I Well: 02-13 Seetion (VS) Referenœ: Well (O.00N,O.00E.68.04Azi) l_~~~~~!~~-_£>~~~..~~ 13~u ~~ng_~~_~~I~..___..- ---- --------------- -------------_!Ia~~---------_._------~~ 3~ ~~7______._--------,----, -..-------... -----------..- __I Section 2: Start r---"---"-"-'----------'---------' -. ----------------~ l_.,._---,~:_.._---_..;------;~.._-,__,__T~ --- +N~___~E;~_- V:_---~~~~OOft d~~~?Oft_..~;~~~,---~~~---------_._------____,_l '9125.00 27.08 100.44 8397.42 -443.35 2499.97 2152.68 14.90 -14.35 -8.68 -164.62 i 9150.00 23.52 97.90 8420.02 -445.06 2510.52 2161.81 14.90 -14.26 -10.14 -164.23 9175.00 20.01 94.53 8443.23 -446.09 2519.72 2169.97 14.90 -14.04 -13.50 -161.94 9200.00 16.59 89.81 8466.97 -446.41 2527.56 2177.11 14.90 -13.68 -18.88 -158.81 9225.00 13.33 82.79 8491.12 -446.04 2533.99 2183.22 14.90 -13.05 -28.06 -154.32 9250.00 10.37 71.63 8515.59 -444.97 2538.98 2188.25 14.90 -11.81 -44.66 -147.54 9275.00 8.08 53.11 8540.27 -443.20 2542.52 2192.20 14.90 -9.18 -74.08 -136.61 9300.00 7.11 25.57 8565.05 -440.75 2544.60 2195.03 14.90 -3.88 -110.14 -118.32 9325.00 7.96 357.60 8589.85 -437.63 2545.19 2196.76 14.90 3.42 -111.89 -91.02 9350.00 10.19 338.45 8614.54 -433.84 2544.31 2197.35 14.90 8.92 -76.59 -63.28 9375.00 13.11 326.90 8639.02 -429.40 2541.95 2196.82 14.90 11.69 -46.20 -44.36 9400.00 16.36 319.67 8663.20 -424.34 2538.12 2195.16 14.90 12.99 -28.90 -33.04 9425.00 19.77 314.84 8686.97 -418.68 2532.84 2192.39 14.90 13.65 -19.35 -26.05 9450.00 23.28 311.39 8710.22 -412.43 2526.13 2188.50 14.90 14.02 -13.79 -21.45 9475.00 26.84 308.81 8732.86 -405.62 2518.03 2183.53 14.90 14.25 -10.33 -18.24 9500.00 30.44 306.79 8754.80 -398.29 2508.55 2177.49 14.90 14.39 -8.05 -15.90 9523.61 33.85 305.25 8774.79 -390.92 2498.41 2170.84 14.87 14.46 -6.54 -14.19 --, "'--"""""-" '-------'. --., "'-'--'-'-----'-"" ...-..". ---"'.----,-----..--.-.---------------,----------------------,-.'._----------------------------- Section 3: Start .. -'- '-'cc :--'è"--"" '~'- : ""7-:--"' ""--"--'---'--'" "7:"-_"C,.,-,:--e""---"":-:--':"""~~-':-:--":ry;-'-----c-,~'-,:-:r-::~:-".,...,. -: ""'i":-: -'7'".~-:-~-""-::':;-:--':-:-----ë'...."..,,-,. ::,,":'",ë'-:TT'T~:':~7-: .""";':"::-;:,.... -::-::-:-:-:,...:.-"C:- ...,..".-.,..,..-",..:--..,,:"-:,.. "'--.--"'" ,.,.---:;--,..---.,... MI) ":,'".',~}nCl,:."'"",,"", Azini"::.",:,'.~":'r:yJ>' '¡i "..:~+N/~~,"'¡;E/;'W~:""::~,:VS,':{)l;.iS,,'Buil(l:::Turn.':.',...',"'.,<TFo.'¡:'" . .......,,"'> "".".,':. '".:"'" .,., - .L.. ....-- .'~b.._.'...- .,._::.:_~-~~_..:.' . ._,.__.__.:...'...~!~.:.;.~::.._'~~L~.,.I- '_....~,"~.::,L.ij,:,:...L..,_:L.~I~h.~iL--_~__.~~:_~_:,¿L.- _".:..:Æ' ~'_.._ŒL,¿...~:*:~i1"~~ "~~~tj~9~~i~~Ø!J~?~~~L --~~~..::..... _.,...~L.._~--_..'~" ---_.:,:: .'-,..:,_~.:L- 9543.84 33.85 305.25 8791.59 -384.42 2489.21 2164.74 0.00 0.00 0.00 0.00 - - . . --..... .....--.. -......-.. -.--,- ---,--- '...._...,-, ---.---. '--,._..,------- ----"".------. "..-...-----...,----'-----"_--- ..---...--..----"'..,--.----.-------.---....-------------.----,-,.._---_..."...... ."..'-'" .-.... ----,-_....----- --,.. ".--.........,----.-..---.. - ,-,- . Section 4: Start r"'--"---'-".""" .'."-"-'--""--"""".'."""T-~-'.-"'"--_._"-'""'--".",'.-"-'--"'-----"-'-----""-"-'~_."'-,, --'----""---~".-"'---"'",,"'---,,.-"----'."---. -. '~'-----.-. ""-----"r--:',,-,, -'---""--"'-.-:-"'-. ---."-" -",,-"'-.-. :.-.-"'~-.""""".'--_."-'._"""".'-------'----'-'-'.,---..-......--- MD Incl ", ~hn ' . TVD +N/':S, , ,+E/-W,' , VS ' "', DLS " Build, ' Turn', TFO " ft deg deg ft. ft', ff'" .ft .' deg/100ft deg/1QOft deg/1()Oft deg," " i ........ ,-- ......,.-'-...-..-...--....-.-,-...,-,-.----..-....-..,..-......-......,...---_.---- ,..-....-......-,--.-,.....-..---"---...-"..-,-..--.....--.-----......-..-....-.-....,------",,-,.:.....-.---------...--."-.--.,......-..----,-------..-.-.......-----.....------..,-----...-----....--..........-..-..-...--- ----_._- 9550.00 34.67 304.64 8796.68 -382.43 2486.37 2162.84 14.50 13.39 -9.88 -22.81 9575.00 38.05 302.41 8816.81 -374.26 2474.01 2154.44 14.50 13.50 -8.93 -22.31 9600.00 41.46 300.49 8836.03 -365.93 2460.37 2144.91 14.50 13.65 -7.67 -20.51 9625.00 44.90 298.82 8854.26 -357.47 2445.50 2134.28 14.50 13.76 -6.70 -19.03 9650.00 48.36 297.34 8871.42 -348.93 2429.46 2122.61 14.50 13.84 -5.93 -17.81 9675.00 51.84 296.00 8887.45 -340.32 2412.33 2109.93 14.50 13.91 -5.33 -16.79 9700.00 55.33 294.79 8902.29 -331.70 2394.15 2096.30 14.50 13.97 -4.84 -15.94 9725.00 58.84 293.68 8915.88 -323.09 2375.02 2081.78 14.50 14.01 -4.45 -15.22 9750.00 62.35 292.65 8928.15 -314.53 2355.00 2066.41 14.50 14.05 -4.13 -14.62 9775.00 65.87 291.68 8939.07 -306.04 2334.17 2050.27 14.50 14.08 -3.87 -14.11 9800.00 69.39 290.77 8948.58 -297.68 2312.63 2033.42 14.50 14.10 -3.66 -13.69 9825.00 72.92 289.89 8956.65 -289.46 2290.44 2015.92 14.50 14.12 -3.50 -13.34 9850.00 76.45 289.05 8963.25 -281.43 2267.71 1997.84 14.50 14.13 -3.37 -13.06 9875.00 79.99 288.23 8968.36 -273.60 2244.53 1979.26 14.50 14.14 -3.27 -12.83 9900.00 83.53 287.43 8971.94 -266.03 2220.98 1960.26 14.50 14.15 -3.20 -12.67 9925.00 87.07 286.65 8973.99 -258.73 2197.16 1940.90 14.50 14.16 -3.15 -12.55 9945.70 90.00 286.00 8974.50 -252.89 2177.29 1924.66 14.51 14.18 -3.12 -12.43 .--' - -, -. -..-------...------.- ---,---..------,.....---.,-----..-.,------...-------------...--".--- ,..,.-'",'---"-'-""- .- -.----...--,-..--,..-.-,..--..-.-..---.., ,----_..-----,,-_.._---, -, ----." ..---.--,.- .......--.-.... ....."" -"-""" .,...,,- "'-"""'.-"".-',--..,..- , Section 5: Start -..- ,..:- ',.-'.. '7 "-"-:-'" ,,- ...,,-..,. "--'~'..:-;-;:-'-..~ ...,.-..:"......" :.:-; ". -'"'- '..... ~"':':-: c-,.,....,-~:- T""- """""""'~',.,... .:-c.. :--"'7':-:"""'" 7.. .---rrè-7-"-;""'...."'T:""","':'.....'7-Q:;':7"-""""" ;"';"T",,~,,;~'~' T-::-:-'-'T'7' -"-.." -~~ :"""..-,",,~...........-, --,"--:"-7- "'-, ';7" '."MD: ':\, ";""Ind~."'"A2:im::'"""'""".',,,,,""1'VU':'+~l..S'i+E1 W"/":-:V:$',,"DLS':I~uild,,1'Ul'lll~,,'~ 'T~O',..:>,,"',," ."".'" """.".",:""" "X' 9945.93 90.02 286.00 8974.50 -252.83 2177.06 1924.47 8.70 8.70 0.00 0.00 -... ...,,-_., -,........" "'-"-""'.....""'" '-"-"'-"."'-"'-""-----.""------""'-"'-"-"--""'-"-"""--..--..""..,.....,...........,"...---,..----.... ..,--._----,---- --,---.......,-,...-...---..-.-....-..---.-----..--....-..---..-"-----"""----.-"----..""----"'-""""'---'."-.'-"""--"'-...--" ...._........-,- Section 6: Start -- "", '--"¡ïn:" "C--"""". :"I~çìë---"'---~-ìm '--"'--"""-"TVD".-""'-"~:' . '* N¡S7"~~'-.+E/:)V-::"':-T"c-"VS"""-"'~'-:-DLS--"--'-'B;ïrd-'""-;'TÛI"fi~--"':i~TFó-¡~--~-"-'-""'-',"ë'-""'~""""~---" . ft '. deg deg '.' . .'.ft, " .,ft '.. ,ft, . ... ftdegi1þb#.d~9i1Q9#~e9110()ft de~r", ,', " -..,'. """-"'-'."'" ,:,~-,_..'"_.C;..-,_.......cc....." --,:c_..-..-. .c",... -_":",,;::',,,""","-,.:..- ",:':;_c_:__...-,--,--,--"..c:~_..':': .,,'"-'-- - ":","-,-"-,-,-';_::.:..-~:"-~-,,,--,--,,,-,,,-.-.,,"-" -'_'~...-,~.C_....:,"':"";_.,_,ë_~:,_,:c.:::l....c.:;.':::""::':":..,;:;""..._.,,-,c...;""..""",.., .'..-""......~~:,:,-.._",-'-_.." -"",,c,.. - .',,' _..:,- -.... : ..-"-..:..... ..,...- 10000.00 90.02 286.00 8974.48 -237.93 2125.08 1881.84 0.00 0.00 0.00 0.00 10100.00 90.02 286.00 8974.45 -210.36 2028.96 1803.00 0.00 0.00 0.00 0.00 10200.00 90.02 286.00 8974.41 -182.80 1932.83 1724.16 0.00 0.00 0.00 0.00 10300.00 90.02 286.00 8974.38 -155.24 1836.71 1645.32 0.00 0.00 0.00 0.00 10393.71 90.02 286.00 8974.35 -129.39 1746.64 1571.46 0.00 0.00 0.00 0.00 .... -.,. -. ......_.... _."...--..__.._-,--,-----,--,--,----_._-----_....-.~-_.__._---"---'----'-'---"---'-'.----'----- -------,-..,..,-----,-,_.--_......_----_.- -....---. ...-.-.--' ---.--... ( ( BP Amoco Planning Report - Geographic - -- -- -..-, .-- ì Company: BP Amoco Date: 12/3/2001 Time: 15:50:38 Page: 3 I Field: Prudhoe Bay CO-Grdinate(NE) Reference: Well: 02-13, True North Site: PB DS 02 Vertical (fVD) Reference: 2-13B 64.5 64.5 ; WeD: 02-13 Section (VS)Reference: Well (O.OON,O.OOE,68.04Azi) I !- ~e~~~~~_._-_~~~__2~~.~~~~~~~ ~~~~----,---_.._------- ------------- --_..._!~~------------------~~!~!i w£~~_____m___.__._--- - --.---.-...----._____1 Section 7: Start r-----~D-l~~ -~~;------~ ------+N~S --' +FJfiW---- ~--- d~~~OOft d,=~~dOOft ¿:~~OOO T:~-.---I I~gi;;f=;;; =--;;=-~~~~~--= : ~ ~¡t.- ~ ~~.- ..~~;~-J: g~-]:g~ -=~_~1~~==~~=-= _oj Section 8: Start r-._'--MD...-"---Inel--.---Ãzi;---------TvD --+i~Ù-s -- +E/-W---.----VS---. DLS---Bulld _._-Tu;~-----"---iFO----"--_._--"--- ft deg deg ft ft ft ft deg/10OO deg/10OO deg/100ft deg -,." -. ..., - ,.. --.--, ...-- --.------- -. .----.---.-....-,... .---.-,......--,...-.-----------,-.- ---'---.--. .--......., ---,,- '-- .-..--..-....-----..----- --..---"--.-" .., -- _...,- -- -. - .,-.-. '- .----..----. "-..-.. - ---'...' ..., -.. -, ,.... 10450.00 86.44 286.00 8976.06 -113.88 1692.57 1527.11 6.50 -6.50 0.00 179.96 10499.73 83.21 286.00 8980.54 -100.23 1644.97 1488.08 6.50 -6.50 0.00 -179.97 .--- .... ".,-.'.". ---..- ,..-,'..---"--...---.. '.-"'-.--"'..""'.-'--".""-"-""..'.'-"".---------'--'-.-.--,-.--....--..,..------.--, '--'-'..-.---------'-"-""----'-----'---'----'.-'-""--'-..--.,.-.----..-,...., '...._.........-_....__.._,----,. .-.'..",...,-. ".,- Section 9: Start -'-"-"'.'-"-."'- . -.. '--- -.. .-- -- -- ----- - - ------------'.. '--'" -~ ----- --- - "'--"-'."--'.". - -..- -.. .--'" -" . -- MD lncl AzllnTVD +N/-S +E/-W VS DLS Build Turn TFO . . ._.~., .._~-_..,' - --. ~~:..~._-_.- ..__.~~~ -..-: .... ...- -_.~._~_... ".,..__...._~-_:.._..!t._- ...,."'-.., . .._...._-~. .,._~...-. ..~.~~..._"--,-- de~{~EP!.~de.~{1 0 Eft "d e~~~- ?~~..... _._~..~~-_.._.._.__.. .--.-,...-... -'" - .c._. -..-.,..- 10565.54 83.21 286.00 8988.32 -82.21 1582.14 1436.55 0.00 0.00 0.00 0.00 .--.. -.........,.,.,,-,....,...-.,,-.-...-.-.-, -" ...,...-.....,.- ....,-.....-.,--.... ...'.'-....".'.-...."""""-'..'-"""."'-.'.'.-'.'...-,.---.....--.,'.-."-....-,-...,....,....-. --"---'- -."..'-'.."".'.-.-'-"-".'--.-"..".-....."""."""'.--."'-'.----"""--'-""-""-"'-"..-"-"...-.--"..'.'--""-"-...--....-......--.........,... Section 10: Start '-,.--- - -..,.~-..,-,....,-..,...." """""'.-"'--". c.---.....,....""""..,... -.,-.-.-- ----,-,.. " ...,.. -,.,.,..".. --..."... -.....,,-,-.,. --,--c-.", '-"'-'-'-'" ,-- ---""-"".,,.-,..-..., ~..,._,......,...."......,.... -..,...,-,-...,..,..-~------....,---------,....., -,... ---.----.- .. -..' ..."..".. ...,-_. .., -...."... , MD 'Ind,.'.",., "..,.,.;." Azlln -_.'...i',~.TVll,..,..,+NMS',,~+E/~W', ~.';V~,~i~DI.$.'BuUd,j'~..n"""".,'.:,'TF'(),'...,,',.,.. ,.".".."..",... ..,',..',.."... :,' .- ... ,......,.,-~ ~t,.,_...c.__.".:~:~~-,..~::".~.~~:~.~g , ~--~-,-~ -,~.-.:.ft.~.,-,~:"~.~.~~~~._" ~~~~}....,":~,_~__L~,._~,~,,-.:..~~,..~..__.__¿,~~~/1 q:~f1Œ~~~~1, 9~~~,~]~/J2E!t_..;,.._~~~-;~.~,...,.:.._...._-_.,......... ..~~'"~, .~."...,' 10600.00 85.45 286.00 8991.72 -72.76 1549.18 1409.51 6.50 6.50 0.00 -0.03 10650.00 88.70 286.00 8994.28 -59.00 1501.18 1370.15 6.50 6.50 0.00 -0.03 10669.97 90.00 286.00 8994.50 -53.49 1482.00 1354.42 6.51 6.51 0.01 0.13 .'.-....'..""......'."..'.. ."'.'.""_.'" ... .."".",-"-"."...-,.-..--.-......---.,..,---.-",-"",-.,,,.--,..,--.-,-...-..-..-..-".-.......-.,--...,,-.. ..---..,---....,....-----....-.--..-.-..-.,--.-..---....-,---,---..-,-.-----....".,...-,-..-.....--.-..,--...-.....-...,.......,...-...........-....,.,..---.-...,.....-....---,-.,..,.,'. '. Section 11 : Start ""...-."..,;, .,. ,.,......" .,...,.,,-- ..-,..... -.-..."...,.. -....,....-:",...,. -'-.:;"""""C;-..':".-;-".-"-,.'---'-".'-"."""'7"----' "...,' ...,,-:-- 7.'-~...._-'-- ..'.~7--::::,"y-_.".:"'r-"-- _.:-';-,--:--""""ii."."'::-"'._"'---.~ ..- --;7~-è~""""-.';--'-""'---._.-"--"'i:.'.""""--:: ""'.-'_",-,..,...,,:...._----:; "'."',," .,-,.. :,.~...,...,.,~ MIl ,Incl Azim', TYD>,~' "" +N/;'S.' ',+E/~:W~' ',YS',.,""iÐLS, ",:tludd,.""Jua;n ", ,..."..TFO ' ,Oft ,',' ,:d~g, ".'dègi ;".:, ",ft',..:,,": ,'.',;ft":,.,.".,.,'"",,tt,,':",."',',"".' ,;:ff:,,",d/:iS)100ftdeg/1"OOftdE!Qt10,Oft :,døg , . .. .........,....;..':...".'...,... .~." """..."',...~_.._-_.......,,~~,"..C,...,--,_.,-,,.:'.__:..,',,_...,._"..-.._."-."..,,~,~'c:...".~..._.,,,.....::o....:,-_....":~..:_~..:.........;."",-...~....._-,.:..__._-:c",-..."-..-,:"""..,.,-_._......_:,,,..,"-.-,--...,~._..:.-,_.,.._,".":._'-_c~,.........-...,~..".........._c._-"-...."':.:..,.... ..'....""...'.' ",...."...:_."...,.,......,.'..- 10692.50 91.35 286.00 8994.23 -47.28 1460.34 1336.65 5.99 5.99 0.00 0.00 ,...""., ...'.'...".'...-"..,..,-...."""."".- ..."'-"'---'--'-."..'--..'.'."-"-.-..""""'--.'..-""..,-.....-......,-....,.....--...-,-......,....,,-,.,.,.---.,-....-.-""'.'..-'..'-".--"...".....-.."."-'.'--".'.""--""-,--."..-.,-.,.....--..,..-.,--.-.,-....-.....,.....,..-,.'..-".."."'--'--'.".."-.-"--"".""..' .'."'.-,....,-..,..."......"._."...."."......,.._-, Section 12: Start ... ...----..- -"-- ---,...--..'-..-.-.... ..--- ..1 '-" ._, -.-.--- -," -- -~_...., -.. ......,' "'."'-""'---"'- ,-. ,_...., .._-:--:----,- -- ~._~.,- --.-, .,-,- --'.-"....----.,. --' --r-- -,...,... - ,-- -.. --'--... --;.. -, -.-."" n.""- ... - ."-...'-- - -...- MD Jnel" Azim TVD., +N/-S, ,+E/-W, VS' . DUS"Øuild ,Turn" TFO' , ...-- ,_._!~..:,----,._-,~~~..,_._-,---- d~g_,.._--_..~--_!.~,-_._.,---~...--.:..-,-"~._,!~ ':.ft' , _~~~~/100ft .d~gl~OOft...de~/1 O~~...._~~-_.._.._._,_:.__...._~-_._,_.~ 10700.00 91.35 286.00 8994.05 -45.21 1453.13 1330.74 0.00 0.00 0.00 0.00 10800.00 91.35 286.00 8991.70 -17.66 1357.03 1251.93 0.00 0.00 0.00 0.00 10900.00 91.35 286.00 8989.34 9.90 1260.93 1173.11 0.00 0.00 0.00 0.00 11000.00 91.35 286.00 8986.99 37.45 1164.83 1094.29 0.00 0.00 0.00 0.00 11099.96 91.35 286.00 8984.62 64.98 1068.77 1015.50 0.00 0.00 0.00 0.00 .....', ..,.. --..-"-...'-..""-."".""'-"-.."'-"'."'.-'.--..........'.......----....._'." ...- .---..-....- ,-,-...,...."."'.........-....-..".-,....-...."-.-...--...--"--""--.-.'"-..-.--..-,.,.,--..---...-,,----,,-,,,.- ---.-......-.-, , ......-,...---....-.......,.-.....--........-,-.-.. --..--.-."-.---....... ,-, ..'..' ----." .. .- ,..-...- ...-.-.,... Section 13: Start : è ,--' :-:-:'CT"'7...,"--"'-:"-":; :-:-."".'7";;---77':- ~~"'~\;,,'-;-1';:-~7è""I""""'-' ---77-;:7;:-';---:7-- =::,::"77~'-~=.~. -;-'1"'-:- --;::- ";"7,-:"" 'ê" ~,":¡-:-"D¡:-7'7-'T':,;;7"7-7:""T"7""'-:""'7ë';T:::~ '-:.. ": -" --.'-C;"C-:""'" ë:._.;':"-:'.:-T':-:;':T"n.."':.-7'T~.-"'" ""~:MJ)::,',.',lnc¡';""'/",',:A!ziQl,,,:',.,;":'tYO:I'i'.'";,+N/,,S':'i,!:+El:.:\V,' "::'"¥S:,'i,;/",:"DI;,S':""iBuUd"";,,::1!Qltrr,,,,',,,,;;"',TFO',.,,,.. ":",,.""',,' .",'.' ,.."..."'.,, ,,; ",' ""',, ',' ,) .i.,', "',,', ".. ',,' "',, ""."" .." ."::,.,, '" ,,:.,,': ", ,,' .. .", ..' "',, ,,' "",.,,' :', ,",.".' '. ":"',"" .""," "',, , "",. ..",.", ",,'. ", , : '::. .:. .. "" . '.: ." '." ,,' ,," ':, "'-... .... ".- .',. "'ift ,"'.'.::..,i:dåg,' ',",'),Qeg,~~>ft~.:,i ""'..~:ft:~:..fti",;:"'t,~id~gM90~degttPQftØ~g/1;pØft.,.,,.,,"".",;..,..,deg..""""~",.,..,,"..,,,.' ""'.,i".... .,i .,..' ...,.."~_.:..,,,-~,~.,",,"......~.i:".,,:_":c...;_.,;, "'c',,:, ':"'~'...;'c...,'_.""~._,,~,..,_.,-,,,-,.:... ,:_,:'-,"-'c.,....:L..c:"",~"c...::.~":::~...c.,,-~,,.....:"..:...c~:_.h:..",,".::":',,_.;_.:.:c,:: '-':~cL:._,;":~,:...;2..:,"-,.~-_.:..c,-"-._~,:,::c:.L_..:cc,",::".::.,¿" ,:"'c-C:"'"i_.,.,-', .,,":':"...:.. -,:c.:_."..,- .:,-..,...':"'.~,~',..."._c...., _.::" 11105.82 91.00 286.00 8984.50 66.59 1063.14 1010.88 5.97 -5.97 0.00 180.00 ,-...,.".....,.,.-"..,......,...""..,.,.",.,....,...--..,.----"-.""-""."'-'.""""'..".--...'.-"".----"'-"..'.""'.'-...'-"'.-.-'..--..""."-'-'."'-..----'--"-.--"""--.'-....,-.---.............-...--,.""".,.....-"..-......".-,-...,.".'-...'....'.".---.--.-.........,-.....,--,.......-."",-,"'-.".'.'."..-.".'-'" ....-.-.--...-..,....,...--.., .. ,......,.,....' .-...,- .--.'."".'.."-"'. Section 14 : Start . .. ,_.,'. .., n."""'" ""CO-." "-----,,. ,..---..--,.", .-.. -:- """-'... '-' T' ;-,...,.....".. ,..,.,... ---"...' ---"'" .,,-:~,......,...,.' "..""",- T:--T:'c7'-:-----C-::-7ë:;--~,-,.---.".'~"""'" ".ee ~~,.",._~:.~, -r-:7"';-;-:""""'~ !-----, .-"~7" '-,""""'" ..... .~'-e,-...:;. '."---"---- .....,..."'. .- .,..,.,., "......., ',..'.,."MO' ',".,..Incl.".'".,!...,Azim...,..",,'.,,;..,.;.".','...'. TVDi'+N/;;,S",...,;.'.",.,'".+E/-W'.,;'.,,"'VS' DtS'ßu ild/Tûrn .,.,".,,'.'.,'TFO,,",'.. ','. .'.'.,'.".,',.!".,.,,',.'.';.' ".' ,., ...' '" '.',. '... ...... "'.. . ",,' . ",.' ,',.'" ... , """:' """,.' "", .'.,." ."": .", "."" ',. '::" .' ," '.'..: ,..,," "..,."'...: .,,' '.,' ,.,..,."" ."..," ,.," .. ... .. ", .". ,": '. ,;ft "'.. ,.,,',. ,:..deg".'.:.'.."'..."'..,.d!:lg~,,.;,.ff,',;~",~~~':..,."ft,,:<f~'i',..~~QI'~:O9~,d~$l~'O9ff~~9/,tpOft.,. ,d,åg;.',i .,';, ",'".;."..' ".. ..., ..',:, .,.'..','.', , ,.,-,.,...,.., ..,-....,-..... ,..".... ........._-,.,_.,-"_.~.,..,,. ...-... '---_.'.'..__.."~'.._-_..'_."_.__. -,-,. "...--..-.......---.-.---....,.,.,.,...--"- ~-_.. .,.!.---.-..-..-.. ,--- ---.---"'--'.. --, "~-_.__.'.'- .."'._---"_..._---"..,---- .,.,--..-....., ,--..-,.. '...-'.-" _....-, ...--.-. 11113.80 90.52 286.01 8984.39 68.79 1055.47 1004.59 6.02 -6.02 0.13 178.81 ,'. .."-"""..'.'."".'.""""".".'.."..'-".""....--...,........-......,..--.......--...-.--.....,....,....",........,",-...,---,.-...---.-.-.-...".".,...,--,.."---,--,---,,,-.-'..-.-.'.'.-".-"---'.."-".".-.-.-.".'---"'---'-'--"-..-....,-...-......---,...--,...-,....,...- ."""'....'."--."""-"'......,., ._, .. Section 15: Start ~~~-=--};~=--~ =-~t,,~!t c .... ~';f. ~;'t9O\Ì;~"'1~~;Æ~~ ~~=--==-~ 11200.00 90.52 286.01 8983.61 92.56 972.62 936.64 0.00 0.00 0.00 180.00 11300.00 90.52 286.01 8982.70 120.14 876.50 857.82 0.00 0.00 0.00 180.00 11400.00 90.52 286.01 8981.79 147.72 780.38 778.99 0.00 0.00 0.00 180.00 11500.00 90.52 286.01 8980.89 175.30 684.26 700.17 0.00 0.00 0.00 180.00 11600.00 90.52 286.01 8979.98 202.88 588.15 621.34 0.00 0.00 0.00 180.00 11651.75 90.52 286.01 8979.50 217.13 538.40 580.53 0.00 0.00 0.00 180.00 "'.'.'..-.......--.....-..... -.."-...-""".",.---,."""",--....-.."".,.-..-...-".,,....--.."..........-..,...-......--.-....,.--,.......-,...---......-.-..---......-....-...,...,.,-..,.,..-.-.....-,...---,-..-...--"......".-".,......,......---....-,,-....-.--,-.-.---.,.-..........-.,..,.,....-.,......--......-....".,..- .,.-.., ,-.-,.._..."_-..,... ,--...- '..'-'.'-'_. ( BP Amoco ( Planning Report - Geographic - -- ., -. .. .., ""1 Company: 8P Amoco Date: 1213/2001 Time: 15:50:38 Page: 4 : Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-13. True North : Site: P8 DS 02 Vertical (fVD) Reference: 2-13864.564.5 I Well: 02-13 Section (VS) Reference: Well (O.OON,O.OOE.68.O4Azi) I ! WeUpatb: Plan 2-138 Longer well Plan: 2-138 wp07 ..,.. , .. ,... --""-" ',-""""---',,----,"'-,,-,"'-'---__""__h__"'__--"----..'--- --------------..-.--..------..----------------------------.--.-------.----,....--- --- .,.--.-----------,--. --"----'--' Survey í ---. ----.---- ..,- --- --- - --- --------- ...----. ..--..---.----- I Map Map <- Latitude --> <-- Longitude -> I MD Incl Azim TVD +N/-S +.EI-W Northing Easting Deg Min See Deg Min See I ft des des ft ft ft ft ft r" - '--..,.. ----------'- ..-,----_... ----. ----.-------------.--.-.--....---,--,------,----..-.----------..--.--- ----,._---- -,-,----.----.----.-.----. _.....-- .-. I 9100.00 27.50 106.00 8375.26 -440.77 2488.69 5950137.96 690115.97 70 16 6.388 N 148 27 44.991 W 9120.00 27.80 100.87 8392.98 -442.92 2497.71 5950136.04 690125.04 70 16 6.367 N 148 27 44.729 W 9125.00 27.08 100.44 8397.42 -443.35 2499.97 5950135.67 690127.31 70 16 6.363 N 148 27 44.663 W 9150.00 23.52 97.90 8420.02 -445.06 2510.52 5950134.22 690137.89 70 16 6.346 N 148 27 44.356 W 9175.00 20.01 94.53 8443.23 -446.09 2519.72 5950133.42 690147.12 70 16 6.336 N 148 27 44.088 W 9200.00 16.59 89.81 8466.97 -446.41 2527.56 5950133.29 690154.96 70 16 6.332 N 148 27 43.860 W 9225.00 13.33 82.79 8491.12 -446.04 2533.99 5950133.83 690161.38 70 16 6.336 N 148 27 43.673 W 9250.00 10.37 71.63 8515.59 -444.97 2538.98 5950135.02 690166.35 70 16 6.347 N 148 27 43.527 W 9275.00 8.08 53.11 8540.27 -443.20 2542.52 5950136.87 690169.84 70 16 6.364 N 148 27 43.424 W 9300.00 7.11 25.57 8565.05 -440.75 2544.60 5950139.37 690171.85 70 16 6.388 N 148 27 43.364 W 9325.00 7.96 357.60 8589.85 -437.63 2545.19 5950142.51 690172.37 70 16 6.419 N 148 27 43.346 W 9350.00 10.19 338.45 8614.54 -433.84 2544.31 5950146.28 690171.39 70 16 6.456 N 148 27 43.372 W 9375.00 13.11 326.90 8639.02 -429.40 2541.95 5950150.65 690168.92 70 16 6.500 N 148 27 43.441 W 9400.00 16.36 319.67 8663.20 -424.34 2538.12 5950155.62 690164.97 70 16 6.549 N 148 27 43.552 W 9425.00 19.77 314.84 8686.97 -418.68 2532.84 5950161.15 690159.55 70 16 6.605 N 148 27 43.706 W 9450.00 23.28 311.39 8710.22 -412.43 2526.13 5950167.23 690152.69 70 16 6.667 N 148 27 43.901 W 9475.00 26.84 308.81 8732.86 -405.62 2518.03 5950173.83 690144.42 70 16 6.734 N 148 27 44.137 W 9500.00 30.44 306.79 8754.80 -398.29 2508.55 5950180.92 690134.77 70 16 6.806 N 148 27 44.413 W 9523.61 33.85 305.25 8774.79 -390.92 2498.41 5950188.04 690124.44 70 16 6.878 N 148 27 44.708 W 9543.84 33.85 305.25 8791.59 -384.42 2489.21 5950194.30 690115.08 70 16 6.942 N 148 27 44.975 W 9550.00 34.67 304.64 8796.68 -382.43 2486.37 5950196.22 690112.19 70 16 6.962 N 148 27 45.058 W 9575.00 38.05 302.41 8816.81 -374.26 2474.01 5950204.08 690099.63 70 16 7.042 N 148 27 45.418 W 9600.00 41.46 300.49 8836.03 -365.93 2460.37 5950212.07 690085.79 70 16 7.124 N 148 27 45.815 W 9625.00 44.90 298.82 8854.26 -357.47 2445.50 5950220.15 690070.72 70 16 7.207 N . 148 27 46.248 W 9650.00 48.36 297.34 8871.42 -348.93 2429.46 5950228.30 690054.48 70 16 7.291 N 148 27 46.714 W 9675.00 51.84 296.00 8887.45 -340.32 2412.33 5950236.47 690037.13 70 16 7.376 N 148 27 47.213 W 9700.00 55.33 294.79 8902.29 -331.70 2394.15 5950244.64 690018.75 70 16 7.461 N 148 27 47.742 W 9725.00 58.84 293.68 8915.88 -323.09 2375.02 5950252.77 689999.41 70 16 7.546 N 148 27 48.299 W 9750.00 62.35 292.65 8928.15 -314.53 2355.00 5950260.83 689979.18 70 16 7.630 N 148 27 48.882 W 9775.00 65.87 291.68 8939.07 -306.04 2334.17 5950268.79 689958.15 70 16 7.713 N 148 27 49.488 W 9800.00 69.39 290.77 8948.58 -297.68 2312.63 5950276.61 689936.40 70 16 7.796 N 148 27 50.115 W 9825.00 72.92 289.89 8956.65 -289.46 2290.44 5950284.27 689914.02 70 16 7.877 N 148 27 50.760 W 9850.00 76.45 289.05 8963.25 -281.43 2267.71 5950291.74 689891.10 70 16 7.956 N 148 27 51.422 W 9875.00 79.99 288.23 8968.36 -273.60 2244.53 5950298.98 689867.73 70 16 8.033 N 148 27 52.097 W 9900.00 83.53 287.43 8971.94 -266.03 2220.98 5950305.97 689844.00 70 16 8.107 N 148 27 52.782 W 9925.00 87.07 286.65 8973.99 -258.73 2197.16 5950312.67 689820.01 70 16 8.179 N 148 27 53.476 W 9945.70 90.00 286.00 8974.50 -252.89 2177.29 5950318.01 689800.00 70 16 8.237 N 148 27 54.054 W 9945.93 90.02 286.00 8974.50 -252.83 2177.06 5950318.07 689799.77 70 16 8.237 N 148 27 54.061 W 10000.00 90.02 286.00 8974.48 -237.93 2125.08 5950331.67 689747.44 70 16 8.384 N 148 27 55.573 W 10100.00 90.02 286.00 8974.45 -210.36 2028.96 5950356.83 689650.66 70 16 8.655 N 148 27 58.371 W 10200.00 90.02 286.00 8974.41 -182.80 1932.83 5950381.98 689553.89 70 16 8.927 N 148 28 1.169 W 10300.00 90.02 286.00 8974.38 -155.24 1836.71 5950407.14 689457.11 70 16 9.198 N 148 28 3.967 W 10393.71 90.02 286.00 8974.35 -129.39 1746.64 5950430.73 689366.43 70 16 9.452 N 148 28 6.589 W 10400.00 89.64 286.00 8974.37 -127.66 1740.59 5950432.31 689360.34 70 16 9.469 N 148 28 6.765 W 10410.69 89.00 286.00 8974.50 -124.71 1730.32 5950435.00 689350.00 70 16 9.498 N 148 28 7.064 W 10450.00 86.44 286.00 8976.06 -113.88 1692.57 5950444.88 689311.99 70 16 9.605 N 148 28 8.163 W 10499.73 83.21 286.00 8980.54 -100.23 1644.97 5950457.35 689264.07 70 16 9.739 N 148 28 9.548 W 10565.54 83.21 286.00 8988.32 -82.21 1582.14 5950473.79 689200.82 70 16 9.917 N 148 28 11.377 W 10600.00 85.45 286.00 8991.72 -72.76 1549.18 5950482.42 689167.63 70 16 10.010 N 148 28 12.336 W 10650.00 88.70 286.00 8994.28 -59.00 1501.18 5950494.98 689119.31 70 16 10.145 N 148 28 13.733 W 10669.97 90.00 286.00 8994.50 -53.49 1482.00 5950500.01 689100.00 70 16 10.199 N 148 28 14.292 W 10692.50 91.35 286.00 8994.23 -47.28 1460.34 5950505.67 689078.19 70 16 10.261 N 148 28 14.922 W 10700.00 91.35 286.00 8994.05 -45.21 1453.13 5950507.56 689070.94 70 16 10.281 N 148 28 15.132 W . ......' """"""""""'-""-""'--"-""""-""--""-""""'-"-' ..-....-.--..-,......-...-.... """"""'-"'---'-'-"'-'..---........-.....-,....""""'-"'-""--"...-. --"""'-"""--""'.-.............--.-..-..-..,..........-.........-..--..-..,-......-.-.-.---...........-....-....--.............-..-....---......-.,......-,--.--.......-.....-......... <: (- ( BP Amoco Planning Report - Geographic r ' : Company: 8P Amoco Date: 12/312001 Time: 15:50:38 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-13. True North , Site: PB DS 02 Vertical (TVD) Reference: 2-13B 64.5 64.5 . Well: 02-13 Section (VS) Reference: Well (O.OON,O.OOE.68.04Azi) I WeUpatb: Plan 2-138 Longer well Plan: 2-13B wpO7 l- ,-- .- .,----- - ----- --------,-- ---------------------------------------- ----_.---- -,----, ---.------------- ---------,_.- -------------------- ---------- -- Page: 5 Survey I ~ ~: ~:-~ - +N~-:FJft~ NZ'iblg E;?~ ~ ~:":: ---> ;; ~~s:: .:;¡ r'-108ÕO~ë),---- 91 ~35---'-'---286.00----"- 8991--. 7Õ-'-----:17.66---'1357~æ-5950532.71----6ãã974:18------70-16 '--10~'552 N----:¡4S28--17. 92.'9-W-- 10900.00 91.35 286.00 8989.34 9.90 1260.93 5950557.86 688877.43 70 16 10.823 N 148 28 20.727 W 11000.00 11099.96 11105.82 11113.80 11200.00 91.35 91.35 91.00 90.52 90.52 286.00 286.00 286.00 286.01 286.01 8986.99 8984.62 8984.50 8984.39 8983.61 37.45 64.98 66.59 68.79 92.56 1164.83 5950583.01 1068.77 5950608.13 1063.14 5950609.60 1055.47 5950611.61 972.62 5950633.31 688780.68 688683.97 688678.30 688670.58 688587.16 70 16 11.094 N 148 28 23.524 W 70 16 11.365 N 148 28 26.320 W 70 16 11.381 N 148 28 26.484 W 70 16 11.403 N 148 28 26.708 W 70 16 11.637 N 148 28 29.119 W 11300.00 90.52 286.01 8982.70 120.14 876.50 5950658.48 688490.39 70 16 11.908 N 148 28 31.917 W 11400.00 90.52 286.01 8981.79 147.72 780.38 5950683.66 688393.62 70 16 12.179 N 148 28 34.715 W 11500.00 90.52 286.01 8980.89 175.30 684.26 5950708.83 688296.86 70 16 12.451 N 148 28 37.513 W 11600.00 90.52 286.01 8979.98 202.88 588.15 5950734.00 688200.09 70 16 12.722 N 148 28 40.311 W 11651.75 90.52 286.01 8979.50 217.13 538.40 5950747.01 688150.00 70 16 12.862 N 148 28 41.759 W . -" ,--_.,....-._.._.~, .-----.-.--- .--------- --, -.-------.---,- ..._-- --.- - .---.- .---.-------, -.---..'.'.----.-- -'---,-'-- ----. ,-- '----'-. --,-,------------_._------------- -,..--...-------- ."-..------ ,.---,-...-- - - -,..-..,--,-----,---.....--......-----. ,----- I ... { ./ I ./ / ..,°' ( I~ ,", .... "'0,. ,.. '" ../' DATE 09/28/01 CHECK NO. 00198754 H 198754 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 092701 CK092701R PYMT OMMENT5: HANDL NG INST: 100.00 Per it to Drill ee 5/H - Terri Hubb e X4628 OÁ -\3ß DEC 1 Alaska Oil & Gas C I. Commiss\or~ . Anchor TOTAL ~ 100.00 100.00 IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 198754 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 ~ 00198754 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 09/28/01 I I AMOUNT $100. ooJ NOTVALID AFTER 120 DAYS To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 n /1t¡ ill \ (.. e-J ""~~ .I'~ III ~ g 8 7 5 ... III I: 0 ~ ~ 2 0 3 8 9 5 I: 0 0 8 ...... ~ g III t \ t( , TRANSMIT AL LETTER CHECK LIST " CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME f13t) 02 - /3 ß CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDIDLL ¡ EXPLORA TION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIFS ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) / ANNULAR 1J ISPOSAL \( / ) NO \7 ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, , API No. . . Production should continue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to dril1 the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME 02 - ) 3 ~ PROGRAM: exp - dev - redrll FIELD & POOL ) ~ INIT CLASS - V ,,) L--. GEOL AREA ,) ADMINISTRA TION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . ,N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . ) N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Pennit can be issued without conservation order. . . . . . . . N 12. Pennit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided .. . . . . . . .. . . . . . . . . . Y N ,v./ A , J ,y , / 15. Surface casing proted~ all known USDWs. . . . . . . . . . . /'fit- y-r;r - t::U;;Ln'/( ,41 ~/5i7'~ 16. CMT vol adequate to CIrculate on conductor & suñ csg. . . . . Y N ¡...itA ¿) 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y N At/A . 18. CMT will cover all known productive horizons. . . . . '. . . " '(j) N <v;CS ~ -~tCR<:"S C'-vlA-t 19. Casing designs adequate for C, T, B & permafrost. . . . . . . iN. 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N _Dc~c;",- lb , 21. If a re-drill, has a 10-403 for abandonment been approved. . . I ~ N '3 (- ~ i.f' App' l1-l t ~ i.:? l 22. Adequate well bore separation proposed.. . . . . . . . . . . . lD N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N ï\liJ\ 24. Drilling .fluid program schematic & equip list adequate. . . . . ,- N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . / N 26. BOPE press rating appropriate; test to 350 (/ psig. .? N J.llA <;. P '= 245'6 f s--:' . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .. . N ~~: ~~~~~~~rH~h;: ~~~:~f: ~~u~d~~n: : : : : : : : : : : Y ij; ~ c> fýJ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. ~ N 31. Data presented on potential overpressure zones. . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . ~. . .. It Y N AP"~ DATE ( 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ~ r'L. (q..)) I 34. Contact name/phone for weekly progress reports [ex,,) tory only} Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; . .' (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO Y: ENGINEERING:.' UtC/Annular COMMISSION: ~~ t/ .Ø- VJC¡1'r WM ' 8t»s JMH ~~~ j~~1f.D\ ENGINEERING APPR DATE _'tJ4Æ jzJ/'fIOI ..IIl2:m ' ìl h , GEOLOGY APPR DATE serv well bore seg _ann. disposal para req- ON/OFF SHORE O/t UNIT# Á.x:A: ,£1> Y N Y N $.-v í~ds 'þ G f' t. , \~fO~C> Com m ents/lnstructions: ,~, 2) ¡ D I c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -f :E ::0 f - -f m - Z -f ,J: - en » ::0 m » ( .~ \ ( Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. ( ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 06 15:50:50 2003 Reel Header Service name............ .LISTPE Date.....................03/01/06 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Conunents.................STS LIS Tape Header Service name............ .LISTPE Date.....................03/01/06 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Conunents................ .STS LIS Physical EOF Conunent Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22008 T MCGUIRE C. GALLOWAY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 2-13B 500292043302 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 06-JAN-03 MWD RUN 3 AK-MW-22008 J. SACK C. GALLOWAY 36 llN 14E 4595 873 57.60 30.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 9.625 9108.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 2. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE Õ<O/-ay 3 114107 ,L' ( (" WHIPSTOCK (THE TOP OF WHICH WAS AT 9108'MD/8381'TVD) - NO RUN 1 DATA ARE PRESENTED. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). MWD RUN 2 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). 4. NEUTRON DATA WERE REPROCESSED WITH A FORMATION WATER SALINITY VALUE OF 25,000 PPM CHLORIDES. FIELD DATA HAD BEEN PROCESSED USING A VALUE 10,000 PPM. 5. LOG AND DIGITAL PER E-MAIL FROM D. SCHNORR DATED ORIGINAL DEPTH REFERENCES. DATA (LDWG) ONLY WERE BLOCK SHIFTED 3/22/02. LOG HEADER DATA RETAIN 6. MWD RUNS 2 & 3 REPRESENT WELL 2-13B WITH API#: 50-029-20433-02. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11000'MD/8976'TVD. SROP ~ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC ~ SMOOTHED GAMMA RAY COMBINED. SEXP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE ~ SMOOTHED FORMATION EXPOSURE TIME. TNPS ~ SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED HOLE SIZE) . SBD2 ~ SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 ~ SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 ~ SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE ~ NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.3 - 8.5 PPG MUD SALINITY: 800 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ PPM CHLORIDES File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD 1 "', Depth shi fted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI GR RPX RPS RPM RPD RHOB DRHO PEF FET ROP $ of ( ( and clipped curves; all bit runs merged. .5000 START DEPTH 9033.0 9033.5 9033.5 9080.5 9087.5 9087.5 9087.5 9087.5 9094.0 9094.0 9094.0 9131.0 9131.0 STOP DEPTH 9991.0 9992.0 9991.0 10941.0 10377.0 10377.0 10377 . 0 10377.0 10007.0 10007.0 10007.0 10377.0 10993.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9033.1 10993.6 $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: GR 9039.5 11000.0 BIT RUN NO 2 3 MERGED MAIN PASS. $ MERGE TOP 9039.5 10096.0 MERGE BASE 10096.0 11000.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9033 10993.5 10013.3 3922 9033 10993.5 ROP MWD FT/H 0 901.64 66.9756 3726 9131 10993.5 GR MWD API 14.14 525.99 57.3499 3722 9080.5 10941 RPX MWD OHMM 0.55 1168.12 36.9852 2580 9087.5 10377 RPS MWD OHMM 0.62 1261.96 48.7225 2580 9087.5 10377 RPM MWD OHMM 0.67 1768.03 63.1295 2580 9087.5 10377 RPD MWD OHMM 0.48 1947.35 88.3906 2580 9087.5 10377 (' ( FET MWD HOUR 0.5392 56.9164 4.11495 2493 9131 10377 NPHI MWD PU-S 6.17 69.9 24.6541 1916 9033.5 9991 FCNT MWD CNTS 77.86 2471.88 602.736 1918 9033.5 9992 NCNT MWD CNTS 12317.2 45417.3 25707.1 1917 9033 9991 RHOB MWD G/CM 0.882 2.971 2.32867 1827 9094 10007 DRHO MWD G/CM -1.269 0.841 0.0490071 1827 9094 10007 PEF MWD BARN 1. 41 17.21 2.71839 1827 9094 10007 First Reading For Entire File......... .9033 Last Reading For Entire File.......... .10993.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT GR RPD RPS RPX RPM PEF DRHO RHOB FET ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 9039.5 9040.0 9040.0 9087.0 9094.0 9094.0 9094.0 9094.0 9100.5 9100.5 9100.5 9137.5 9137.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 9997.5 9997.5 9998.5 10045.5 10052.5 10052.5 10052.5 10052.5 10013.5 10013.5 10013.5 10052.5 10096.0 04-FEB-02 Insite 66.16 Memory 10096.0 9108.0 10096.0 10.2 89.9 TOOL NUMBER (' DGR SLD CTN EWR4 $ DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ( 91360 154267 100547 162742 6.125 9108.0 Quikdril-N 8.40 58.0 9.0 850 10.6 1.940. .970 1.910 1.950 70.0 147.0 82.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9039.5 10096 9567.75 2114 9039.5 10096 ROP MWD020 FT/H 0.07 211.2 35.024 1918 9137.5 10096 GR MWD020 API 14.14 525.99 46.5075 1918 9087 10045.5 RPX MWD020 OHMM 0.55 1168.12 39.3203 1918 9094 10052.5 RPS MWD020 OHMM 0.62 1261.96 54.1501 1918 9094 10052.5 RPM MWD020 OHMM 0.67 1768.03 72.8224 1918 9094 10052.5 RPD MWD020 OHMM 0.48 1947.35 104.882 1918 9094 10052.5 FET MWD020 HOUR 1.1977 7.3796 2.47679 1831 9137.5 10052.5 NPHI MWD020 PU-S 6.17 69.9 24.6541 1916 9040 9997.5 FCNT MWD020 CNTS 77.86 2471.88 602.736 1918 9040 9998.5 (" ( NCNT MWD020 CNT8 RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN 12317.2 0.882 -1.269 1. 41 45417.3 2.971 0.841 17.21 25707.1 2.32867 0.0490071 2.71839 1917 1827 1827 1827 9039.5 9100.5 9100.5 9100.5 9997.5 10013.5 10013.5 10013.5 First Reading For Entire File......... .9039.5 Last Reading For Entire File.......... .10096 File Trailer 8ervice name............ .8T8LIB.002 8ervice 8ub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .8T8LIB.003 Physical EOF File Header 8ervice name............ .8T8LIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 10046.0 10053.0 10053.0 10053.0 10053.0 10053.0 10096.5 STOP DEPTH 10947.5 10383.5 10383.5 10383.5 10383.5 10383.5 11000.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 08-FEB-02 Insite 66.37 Memory 11000.0 10096.0 11000.0 84.5 92.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 913 60 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 9108.0 # BOREHOLE CONDITIONS ( ( MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Quikdrill-N 8.40 44.0 9.6 600 3.0 1. 300 .560 2.800 1. 300 70.0 172.0 65.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10046 11000 10523 1909 10046 11000 ROP MWD030 FT/H 0 901. 64 100.871 1808 10096.5 11000 GR MWD030 API 21.13 306.78 68.8775 1804 10046 10947.5 RPX MWD030 OHMM 14.86 39.2 30.2198 662 10053 10383.5 RPS MWD030 OHMM 20.41 52.6 32.9973 662 10053 10383.5 RPM MWD030 OHMM 23.9 57.32 35.0463 662 10053 10383.5 RPD MWD030 OHMM 29.84 78.75 40.6106 662 10053 10383.5 FET MWD030 HOUR 0.5392 56.9164 8.64588 662 10053 10383.5 First Reading For Entire File......... .10046 Last Reading For Entire File.......... .11000 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF ( Tape Trailer Service name............ .LISTPE Date.....................03/01/06 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.................STS LIS Reel Trailer Service name............ .LISTPE Date.....................03/01/06 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. (: Scientific Technical Services Scientific Technical Services
