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204-250
· . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :¿CJ./f - ~ $0 Well History File Identifier Organizing (done) o Two-sided ""111111111111111 o Rescan Needed 111111111111 "" III R~CAN ).Ø' 9o'or Items: ~reYSCale Items: , p~ DIGITAL DATA ~iskettes, No.J- o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: VVlP Is~"IIIIIIIII~ "III W\ P Isl BY: ~ Date: Lf J~ D7 Project Proofing BY: ~ Date if / I /J- / 0 7 )l x 30 = It¡ () + Date If J I ;}-J 07 01 = TOTAL PAGES (p q ¡(Count does not include cover shee~ Isl mP Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date 4- J é}-Jo 7 If NO in stage 1, page(s) discrepancies were found: 11111111111111 III/I NO BY: Isl YVlp NO Stage 1 YES BY: Maria Date: Isl 11I111/1111111 "'II Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 ,,11/ BY: Maria Date: Isl Comments about this file: Quality Checked 111111111111 111111I 10/6/2005 Well History File Cover Page.doc RECEIVED ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 6 2014 WELL COMPLETION OR RECOMPLETION REPORT AND LeGCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other ®Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero 0 Development ®Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 12/17/2013 * 204-250 312-050 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 2/12/2005 50-029-20587-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 2/15/2005 PBU Y-10A 1410' FNL,205'FEL, SEC. 33,T11N, R13E, UM 8. KB(ft above MSL): 85.7' 15.Field/Pool(s) Top of Productive Horizon: 915' FNL, 2788'FEL, SEC. 33,T11N, R13E, UM GL(ft above MSL): 50.09' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 222' FNL, 1584'FEL, SEC. 33,T11N, R13E, UM 2781' 2781' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 644611 y- 5948841 Zone- ASP4 _ 11114' • 8965' ADL 028287 TPI: x- 642018 y- 5949287 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 643207 y- 5950003 Zone- ASP4 __ None 18.Directional Survey: ❑Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/EWR, SCMT 9507' 8891' 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"x 30" _ Insulated Conductor Surface_ 110' Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2709' Surface 2709' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 Surface, 9464' ,Surface 8850' , 12-1/4" 1270 cu ft Class'G', 130 cu ft PF'C' 7" 29# L-80 8985' 9507' 8396' 8891' 8-1/2" 336 cu ft Class'G' 3-1/2"x3-3/16" 8.8i#/6.2# L-80 8989' 11109'_ 8399' 8965' 4-118"x 3-3/4" 163 cu ft'G', 175 cu ft'G', 225 cu ft'G' • 24. Open to production or injection? 0 Yes 0 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 3507'-9037' 8701'/8130';8843'/8262';. 8935'/8349' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No SCANNED MAY 2 9 2.014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Injection 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 0 No Sidewall Core(s)Acquired? 0 Yes 0 No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBC MS MAR 21 20:- Form 10-407 Revised 10/2012Vt 4/�2 // CONTINUED ON REVERSE `ch Submit Original Only /�J 29. GEOLOGIC MARKERS(List all formations ai rkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? 0 Yes 0 No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. No new tops were penetrated. None Ivishak(From Y-10) 9578' 8959' 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: Garret Staudinger,564-4242 Email: Garret.Staudinger@bp.com Printed Name: Title: Drilling Technologist Joe Lastufk Signature: -Phone 564-4091 Date: I,3/I11V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leasesin 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 la: 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: Y-10A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8725' 22 Bbls Class 'G' 8621' - 8626' Tubing Punch —7270 69 Bbls Class 'G' 3507' Tubing Cut and Pulled 2801' Set EZSV 2781' Set Whipstock Y-10A, Well History (Pre Rig Sidetrack) Date Summary 08/10/13 T/I/0=100/0/0, Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS). Pre RST. PPPOT-T: Stung into test port (150 psi). Functioned LDS, all moved freely(1"). Unable to pump through void, single port. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(100 psi), bled to 0 psi. Functioned LDS, all moved freely(1"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 08/10/13 DRIFTED W/KJ, 2'x1-1/2",2.25"CENT, 1-3/4"S. BAILER TO DEV. @ 9680' SLM. (recovered 2tbsp schmoo). DRIFTED TO DEP SLEEVE @ 8963'SLM (8989'MD)W/3.5 LIB, (good impression). 08/13/13 T/I/O=Vac/4/0,Temp=S/l, Injectivity Test MIT-IA PASSED to 3000 psi, MIT-OA PASSED to 2000 psi (RWO Prep) Pump 10 bbls meth,40 bbls diesel,285 bbls 1% KCL for injectivity test. Establish a rate of 5 bpm at 1750 psi. Freeze protect tubing with 40 bbls diesel. Pump 9.4 bbls 60/40 to achieve test pressure on IA. IA lost 82 psi 1st 15 min and 36 psi 2nd 15 min for a total loss of 118 psi over 30 min test. Bleed IAP, approx 6 bbls. Pump 3 bbls diesel to achieve test pressure on OA. OA lost 92 psi 1st 15 min and 42 psi 2nd 15 min for a total loss of 134 psi over 30 min test. Bleed back OAP, approx 1.5 bbls. FWHP 0/0/0 SV,WV=closed, SSV,MV=open, IA and OA=OTG. 08/19/13 T/I/0- 1082/7/12 Temp.-SI Assist SLB w/Fullbore Cement P&A Stage 1 of 2. Pumped a 5 bbl meth spear followed by 40 bbls of 70*diesel and 290 bbls of 1% KCL to load tubing. SLB pumped 22 bbls of 15.8 ppg Class"G" CMT followed by 2 bbls fresh water spacer. Dropped balls and pumped 5 bbls fresh water spacer. LRS continued pumping 125.4 bbls of 70*diesel to spot the 2374'cement plug form the PBTD of 11074'MD to the estimated TOC of 7800' MD. CIP @ 17:32 hrs.The Schlumberger 12 hr UCA showed a compressive strength of 3090 psi. Final WHP-668/0/175. 08/21/13 DRIFT/BRUSH TREE W/2.50"CENT,4-1/2" BLB. DRIFT W/2.50"CENT, 1.75"S. BAILER,TAG TOC @ 8691'SLM(+34' KB/BF CORRECTION) =8725' MD, RECOVERED SAMPLE OF CEMENT LRS MIT-T TO 3000 PSI, 1ST TEST FAILED. TAG TOC W/2.50" S. BAILER @ 8689'SLM(+34' KB/BF CORRECTION) =8723' MD. LRS MIT-T TO 3000 PSI, 2ND TEST PASSED. 08/21/13 T/I/0=5/1/0 Temp=S/I Assist SLB,AOGCC MIT-TBG to 3000 PSI (Witnessed by Lou Grimaldi), PASSED 2nd attempt(RWO prep) Pumped 3.7 bbls (7.15 total for both tests-See log)AMB diesel to test. 1st 15 min TBG lost 188&2nd 15 min TBGP lost 53 for a total TBGP loss of 241 in 30 min. Bled back-3.7 bbls. FWHP's=0/1/0 Upon departure DSO notified SLB on well &in control of VLV's. 08/25/13 INITIAL T/I/O=650/0/0 PSI. RIH W/CCL/MPD/5'TUBING PUNCHER WITH SMALL CHARGES. SHOT INTERVAL=8621'-8626'- 1' BELOW TOP COLLAR OF FIRST FULL JOINT ABOVE PACKER @ 8701'. GOOD INDICATION PUNCH FIRED. LEFT WELL SHUT-IN AND SECURE, HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T/I/O =500/0/0. 08/26/13 Heat diesel for upcoming work on well (RWO prep) Heated 250 bbls diesel on tanker transport to 90*f. 08/27/13 T/I/0=486/0/0 Temp=S/I Assist SLB w/Fullbore P&A Stage 2(RWO Prep) Pumped 5 bbls MEOH followed by 15 bbls diesel then 450 bbls 1%KCI, then 158 bbls diesel followed by 274 bbls 1%KCI. SLB pumped 69 bbls 15.8 ppg Class"G"cement followed by 2 bbls fresh water spacer then dropped the wiper balls and chased w/5 bbls fresh water. Spotted the cement by displacing with 71 bbls 1% KCI followed by 38 bbls diesel for TBG freeze protect. Estimated TOC @ 7622', Length of CMT Plug- 1004', CIP @ 09:00 hrs; UCA=2000 psi @ 18:00 hrs. FWHP's=104/217/645 Upon departure DSO notified IAV,OAV=OTG&SLB on well & in control of all WHV's. Page 1 of 3 Y-10A, Well History (Pre Rig Sidetrack) Date Summary 08/28/13 PERFORMED PASSING MIT-T TO 3000 psi (pressure testing cement). BRUSHED TREE&BPV PROFILE W/2 x 4-1/2" BRUSHES. DRIFTED W/3.70"CENTRALIZER, 1-3/4"SAMPLE BAILER, S/D @ 7265'SLM (no sample). TAG TOC W/2.50"CENTRALIZER, 1-3/4"SAMPLE BAILER @ 7270'SLM (sample of cement recovered). 09/04/13 INITIAL T/I/O=350/0/0. RIH W/HEAD (9X3 WEAKPOINT)-CCL-4 WEIGHTS-SHOCK MANDRELS- 3.65"JET CUTTER. OAL=24.5 FT; WEIGHT= 175 LBS; MAX OD=3.65"; BARRIERS: GREASE AND WELLHEAD EQUIPMENT. JET CUTTER FIRED. CUT DEPTH =3507 FT; CCL TO CUTTER=22.38 FT; CCL STOP DEPTH =3484.62 FT. PERFORMED CMIT-TxIA. CMIT TO 3950 PSI ***PASSED***. LOST 70 PSI IN 1ST 15 MIN AND 34 PSI IN 2ND 15 MIN. FINAL T/I/O =0/0/0 WELL SHUT IN ON DEPARTURE. 09/05/13 T/I/0=260/240/0+Temp=SI CMIT-TxIA**PASSED**to 3000 psi (RWO prep) Pumped 6.9 bbls 40*neat methanol down Tbg to reach test pressure. 2nd attempt: 1st 15 minutes T/IA lost 35/32 psi.2nd 15 minutes T/IA lost 9/8 psi.Total T/IA loss in 30 minutes=44/40 psi. Bled TxIAP (—6 bbls). FWHP's=0+/0+/0+SV,WV, SSV=SI MV=0 IA&OA=OTG. 09/06/13 T/I/O =290/270/vac.Temp=SI. Bleed WHPs to 0 psi (RWO prep).TBG FL near surface. IA FL @ surface. See log for details. Bled TP& IAP to 0 psi in 5 hrs, 50 min (gas/-1 bbl liquid). SI, monitored for 30 min.TP increased to 40 psi. Job complete. Final WHPs=40/vac/0. SV,WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 1600. 10/22/13 T/I/O=SSV/960/0+.Temp=SI. WHPs(UIC). No AL. Unable to open SSV do to fittings on SSV barrel. SV,WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1620. 11/09/13 T/I/O = MV/950/0+.Temp SI. Bleed WHPs to 0 psi (ST prep). IA FL @ surface. Bled IAP from 950 psi to 0 psi in 3 hrs 30 min to slop tank(10.26 bbl). Monitored for 30 min. IAP increased to 0+.Job complete. Final WHPs= MV/0+/0. SV, SSV=C. WV, MV= LOTO. IA, OA=OTG. NOVP. 1430 11/24/13 T/I/O=SSV/5/0+.Temp=Sl.WHPs (Pre RWO).Well has no AL,FL, or Well House.There is no scaffolding to access SV or Tree Cap. MV is NOT LOTO. IA is fluid packed, OA has fluid near surface. OAP <1/2 psi. SV=?.WV,SSV,MV=Closed. IA,OA=OTG. NOVP. (1630). 11/25/13 T/I/O=?/5/0+.Temp=Sl.WHPs(Pre Rig). No AL,well house, or FL.WHPs unchanged overnight. Unable to obtain TP or SV position due to no scaffolding. SV=?. WV,SSV,MV=Closed. IA,OA=OTG. NOVP. (1330 hrs). 11/27/13 T/I/0=SI/0/0 install Piggy back IA/OA valves with intergal blind flanges.Temp valve 42 on OA and temp valve# 19 on IA. PT'd to 300/3500 PSI pass. Confirm VR plug in companion side OA install tapped blind flange. Make change out with night crew. Final T/I/0=SI/0/O. 11/28/13 T/I/O =TWCNAC/0.Temp=Sl.WHPs(Pre CTD). No FL or Well House. Drilling scaffolding on well,tree cap is©6" below grating of scaffolding. Dry hole tree on well. SV,MV=Closed. IA,OA=OTG. NOVP. (1200 hrs). 11/28/13 T/I/0=440/0/0 Barriers=TWC and MV. ND Upper Tree; NU 4"Temp Valve#24 as SV(dryhole tree)for Doyon 25. T/I/O=TWC/0/0. 12/02/13 T/I/O=TWC/0/0. Pull TWC#288, bleed TBG to 0 psi. Pressure up TBG thru I/A to 200 psi. Set TWC# 425, RDMO. Final WHP=TWC/0/0. Page 2 of 3 Y-10A, Well History (Pre Rig Sidetrack) Date Summary 12/03/13 T/I/O =0/0/0 Temp. = S/I Assist valve crew Pressure test TWC (ST Prep) Pumped 7 bbls amb. diesel down IA to assist valve crew with testing of TWC. Bled IAP to 6 psi. Bled back— .5 bbls. RDMO. SV, MV =closed. No SSV. IA and OA=OTG. FWHP's=0/6/0. 12/03/13 T/IA/OA=TWC/0/0. PT'd against TWC through IA to 200 Psi. for 5 Min. (PASSED). Bled IA to 0 Psi. RDMO. T/IA/OA=TWC/0/0. Page 3 of 3 North America-ALASKA-BP Page 1 qui Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292058700 Active datum:Y-10B Actual @90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 12/10/2013 12:00 - 18:00 6.00 MOB P PRE RIG DOWN OPERATIONS -BREAK MODULES AND RE LOCATE IN ORDER TO MOVE -TOOL SERVICES MOBILIZING RIG MATS ALONG RIG MOVE ROUTE 18:00 - 00:00 6.00 MOB P PRE SKID RIG FLOOR&LOWER DERRICK SPOT MODULES IN PLACE FOR MOVE -PUMP&POWER MODULES OFF P-PAD AT 20:00,ARRIVED ON Y-PAD AROUND MIDNIGHT. 12/11/2013 00:00 - 06:00 6.00 MOB P PRE MOBILIZE PIT AND PIPE SHED MODULES F/ P-PAD TO Y-PAD -SPOT MODULES ON Y-PAD,WELL 10B -TOOL SERVICES MOBILIZING RIG MATS ALONG RIG MOVE ROUTE ON Y-PAD ACCESS -RIG CREW WORKING ON STOMPER CYLINDER ON SUB MODULE 06:00 - 18:00 12.00 MOB P PRE MOBILIZE CASING AND SUB MODULES -ALL SIX MODULES ON LOCATION AT 18:00 18:00 00:00 6.00 MOB P PRE SPOT MODULES IN PLACE -TIGHT LOCATION MAKING FOR EXTRA TIME SPOTTING MODULES IN PLACE. 12/12/2013 00:00 - 04:30 4.50 MOB P PRE SPOT RIG SUB OVER WELL AND SHIM,WALK PIPE SHED IN POSITION UNDER SUB -STAGE OTHER MODULES IN PLACE -BEGIN RIGGING UP FOR DE-COMPLETE& DRILLING OPERATIONS 04:30 - 09:00 4.50 MOB N RREP PRE (CODE 8)-RIG REPAIR HEAT EXCHANGE FAILURE ON MAIN HPU FOR SUB SPILL CLEAN UP OPERATIONS "(04:30)-300 GAL HYDRAULIC OIL SPILL. -DUE TO MECHANICAL FAILURE OF HEAT EXCHANGE COOLER IN RIG SUB HYDRAULIC UNIT. ALL HYDRAULIC FLUID CONTAINED WITHIN SECONDARY CONTAINMENT. NOTIFICATIONS MADE.CLEAN UP IN PROGRESS. TRACTION REPORT* 2013-IR-4595685 09:00 - 17:30 8.50 MOB P PRE SPOTTING RIG SUB AND PIPE MODULES. -PIN IN PLACE "(17:00) -8 GAL MOTOR OIL LEAK ON P-PAD. TWO DRUMS OF MOTOR OIL WERE PUNCTURED BY RIG LOADER WHILE LOADING ON TO THE BED TRUCK.OIL LEAKED ONTO THE BED OF THE TRUCK(ON P-PAD)WITH NO OIL HITTING THE PAD.ALL NOTIFICATIONS WERE MADE AND CLEAN UP PROCESS STARTED. TRACTION REPORT#:2013-IR-4596192 Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 2 OE Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. I UWI:500292058700 Active datum:Y-10B Actual©90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 17:30 - 23:30 6.00 MOB N , RREP PRE (CODE 8)-RIG REPAIR REMOVING HYDRAULIC RAM F/C-SECTION OF DERRICK -PJSM WITH CH2 CRANE CREW,DDI,AND BP REP • LIFTING PERMIT AND HAZARD ASSESSMENT CONDUCTED.CH2 LIFT PLAN USED -DISCONNECT HYDRAULIC LINES AND CAP SAME,CUT RAM PINS W/SAWS ALL -REMOVED C-SECTION HYDRAULIC RAM. 23:30 - 00:00 0.50 MOB P PRE CONTINUE RIG UP -WALKING REMAINDER OF RIG MODULES IN 'PLACE TO BE CONNECTED. _ 12/13/2013 00:00 - 03:00 3.00 RIGU P PRE RIG UP ON Y-10B -POSITION PIPE SHED • -PJSM,RAISE DERRICK AND SKID FLOOR 03:00 - 12:00 9.00 RIGU P PRE RIG UP OPERATIONS: -WALK PUMP AND POWER COMPLEXES INTO POSITION -WALK CASING SHED IN PLACE SPOT REMAINING COMPLEXES IN PLACE LOWER&PIN C-SECTION -RAISE UPPER,LOWER AND MIDDLE CATTLE CHUTE SECTIONS&PIN IN PLACE -HOOK UP STEAM,WATER&AIR LINES HOOK UP PUMP PITS&SUB INTER-CONNECTS,HOOK UP ALL ELECTRIC INTER-CONNECTS -INSTALL HAND RAILS AND STEPS AROUND RIG -INSTALL STEAM TRAPS -INSTALL GAI-TRONICS 12:00 - 18:00 6.00 RIGU P PRE RIG UP OPERATIONS: -SPOOL UP DRILL LINE ON DRAWWORKS CONNECT STAND PIPE AND CEMENT LINES -UNPIN TOP DRIVE,BRIDLE UP&SCOPE DERRICK RIG ACCEPT @ 18:00 18:00 - 20:00 2.00 RIGU P PRE RIG UP AND TESTTWC. -ABOVE:250 PSI LOW&4000 PSI HIGH FOR 5 CHARTED MIN -BELOW:250 PSI LOW&3500 PSI HIGH FOR 5 CHARTED MIN. -ALL TEST PASSED BP CRITERIA FOR TESTING TWC/BPV'S -PRESSURE TEST PERFORMED W/DIESEL -RD&BLOW DOWN TEST LINES 20:00 - 20:30 0.50 RIGU P PRE RIG EVACUATION DRILL AAR: RIG ABANDONMENT WAS CALLED OVER THE GAI-TRONICS ALL PARTIES ON LOCATION MUSTERED TO THE CORRECT MUSTER POINT&WERE ACCOUNTED FOR. REPEATED ANNOUNCEMENTS WERE MADE OVER THE •HARMONY TO ENSURE THIRD PARTY PEOPLE WERE NOTIFIED -AN INSPECTION CREW WORKING UNDER A •SIM-OPS CARD MUSTERED WHEN THEY HEARD THE DRILL. Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 3 022_ Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292058700 Active datum:Y-1 OB Actual @90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (usft) 20:30 - 23:30 3.00 RIGU P PRE NIPPLE DOWN TREE&ADAPTER FLANGE -PJSM FOR ND -BREAK FREE AND SECURE TREE&FLANGE FOR TRANSPORT -CAMERON INSPECTED THE 4-1/2"MCA LIFT THREADS -MADE UP THE MCA X 4-1/2"IF XO TO THE TBG HANGER-16-3/4 TURNS -FUNCTION TESTED THE LDS-5.0"IN,5.5" TO 5.75"OUT BARRIERS FOR BREAKING CONTAINMENT: CEMENT PLUG AT 7,622'MD,TESTED TWC 123:30 - 00:00 0.50 RIGD P PRE PRE-SPUD MEETING WITH BOTH RIG CREWS -SLB MWD,GEO&MI MUD MAN 12/14/2013 00:00 - 08:00 8.00 RIGU P PRE NIPPLE UP BOPE -NIPPLE UP 11"X 13-5/8"ADAPTER SPOOL -N/U 13 5/8"BOP STACK. -INSTALL DRIP PAN&SEAL -INSTALL CHOKE HOSE&KILL HOSE -INSTALL FLOW RISER, -BLEED OFF IA F/100 PSI TO 0 PSI -NU PRESSURE TEST EQUIPMENT 08:00 - 16:30 8.50 RIGU P PRE TEST BOPE -TEST BOPE TO 250 PSI LOW,4,000 PSI HIGH FOR 5 MINUTES EACH -TEST(2)2-7/8"BY 5-1/2" VBR'S WITH 4-1/2" &5"TEST JOINTS -TEST ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH WITH 4"TEST JOINT -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS AOGCC GIVEN 24 HR NOTICE OF BOP TESTING. -TEST WITNESS WAIVED BY AOGCC REP JEFF JONES RD TEST EQUIPMENT -MU5"SHEAR JOINT 16:30 - 20:00 3.50 PULL P DECOMP RIG UP DUTCH RISER AND LUBRICATOR, -CLOSE ANNULAR ON DUTCH RISER AND TEST SAME TO 250 PSI LOW 5 MIN/4000 PSI HIGH 5 MIN.-GOOD TEST. -PULL TWC -RD LUBRICATOR &DUTCH RISER Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 4 024 Operation Summary Report Common Well Name:Y-10 •AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: :X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292058700 Active datum:Y-108 Actual @90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 PULL P DECOMP CIRCULATE OUT FREEZE PROTECT -RU AND CIRCULATE OUT DIESEL FREEZE PROTECT USING 100 DEG 8.5 PPG SEAWATER. -CIRCULATING DOWN THE KILL LINE AND TAKING RETURNS OUT THE IA. ALL RETURNS TAKEN TO 500 BBL TIGER TANK. -STAGE PUMPS UP TO 7 BPM(296)GPM, 280-400 PSI -ICP-280 PSI,FCP-400 PSI RECOVERED ROUGHLY-170 BBLS OF DIESEL,DIESEL SENT TO HYDROCARBON RECYCLE AT GC-2 -SHUT DOWN AND MONITOR THE WELL FOR 10 MIN-WELL STATIC CHANGE OUT SAVER SUB TO 4-1/2"IF DURING CIRCULATION 22:00 - 00:00 2.00 PULL P DECOMP PULL TUBING HANGER MAKE UP MCA X 4-1/2"IF XO TO 5"DP RIH AND MAKE UP TO HANGER WITH 16-3/4 TURNS -CAMERON REP TO BOLDS PULL HANGER OFF SEAT WITH 71 K -PU 2'AND MONITOR WELL FOR 10 MIN- WELL STATIC -PULL HANGER TO THE RIG FLOOR AND LAY DOWN -PUW-66K 12/15/2013 00.00 - 01:00 1.00 PULL P DECOMP FINISH LAYING DOWN TUBING HANGER -C/O SLIP INSERTS -BREAK OUT MCA X 4-1/2"(XO) 01:00 - 03:00 2.00 PULL P DECOMP CIRCULATE SURFACE TO SURFACE -CLOSE ANNULAR PREVENTER AND CIRCULATE THROUGH THE CHOKE -PUMP 40 BBLS OF DEEP CLEAN PILL -FOLLOWED BY 240 BBLS OF 8.5 PPG SEAWATER -250 GPM,125 PSI, -SHUT DOWN MONITOR WELL-WELL STATIC CONNECTED OA LINE TO THE TIGER TANK TO MONITOR PRIOR TO PACK OFF C/O.BLED PRESSURE F/150 PSI TO 0 PSI. 03:00 - 08:30 5.50 PULL P DECOMP PULL AND LAY DOWN 4-1/2",12.6#,L-80 TCII TUBING -LAY DOWN TUBING FROM 3,507' -MARKED EACH JOINT WITH#AND WELL -TOTAL JTS LAID DOWN=85+CUT-JNT= (5.15') -LD ONE X-NIPPLE ASSEMBLY -MONITORING DISPLACEMENT ON THE TRIP TANK 08:30 - 09:00 0.50 CLEAN P DECOMP CLEAN&CLEAR RIG FLOOR -RD 4-1/2"HANDLING EQUIPMENT TRANSFER TUBING OUT OF PIPE SHED AND LOAD CLEAN OUT BHA 09:00 - 10:00 1.00 CLEAN P DECOMP INSTALL WEAR BUSHING -ID=8-7/8",OD 15-1/4" -MU 5"SHEAR JOINT Printed 12/30/2013 1:19:27PM e North America-ALASKA-BP Page 56.24- Operation Gf -Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) l Start Date:12/10/2013 End Date: X3-011M4-C:(13,544:400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. I UWI:500292058700 Active datum:Y-10B Actual©90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 15:00 5.00 CLEAN N DECOMP µRECOVER RUBBER HOLE COVER FROM INSIDE THE BOP STACK -HOLE COVER FELL IN BOP STACK WHILE ATTEMPTING TO RELEASE FROM WEAR BUSHING. -ATTEMPT TO PULL WEAR BUSHING AND HOLE COVER SLIPPED BESIDE. -SCREW INTO JOINT WITH TOP DRIVE AND SET DOWN TO FREE WEAR BUSHING AND RUNNING TOOL. -HOLE COVER TORE IN(3)PIECES. -FAB TOOLS WITH TO RECOVER PIECES. (HOOK,SPEAR AND SCREW). -RECOVERY MADE USING TOOLS ATTACHED TO CONDUIT ROD. -SUCCESSFULLY RECOVERED ALL 3 PIECES OF HOLE COVER. '(11:30)10 GAL LEAK CH2 SUPER SUCKER LEAK.9 GAL IN SECONDARY CONTAINMENT • AND 1 GAL OF DEEP CLEAN LEAKED TO THE GROUND.CH2 DISPATCH CALLED SRT AND INITIATED A TRACTION REPORT.CLEAN UP WAS HANDLED BY SRT 15:00 - 17:00 2.00 CLEAN P DECOMP PULL AND INSPECT WEAR BUSHING AND WEAR BUSHING RUNNING TOOL. -SET WEAR BUSHING&RILDS -ID=8-7/8",OD 15-1/4" -INSTALL STRIP 0 MATIC DP WIPER SYSTEM 17:00 - 20:30 ' 3.50 CLEAN P DECOMP PU/MU BAKER CLEAN OUT BHA TO 880'MD PER BAKER REP DIRECTION 1 8-1/2"BIT,LOWER MILL,(2)WATERMELON MILLS,SUB,(2)BOOT BASKETS,BUMPER SUB,(9)DC'S,(18)5"HWDP -MONITOR DISP VIA THE TRIP TANK 20:30 - 00:00 3.50 CLEAN P DECOMP RIH WITH 9-5/8"CLEAN OUT ASSEMBLY RIH ON 5"SINGLES FROM THE CASING SHED F/880'MD TO 2,730'- -MONITORING TRIP VIA THE TRIP TANK • 12/16/2013 00:00 - 02:00 2.00 CLEAN P WEXIT RIH WITH 9-5/8"CLEAN OUT ASSEMBLY -RIH ON 5"SINGLES FROM THE CASING SHED F/2,730'MD TO THE TOP OF THE TUBING STUB AT 3,516'MD -PUWW-142K,SOW-146K -WORKED MILLS 3 X F/2,756'TO 2,816'-NO ROTATION -MONITORING TRIP VIA THE TRIP TANK. 8.5 PPG SEAWATER 02:00 - 03:00 1.00 CASING P WEXIT PUMP 30 BBL HIGH VIS SWEEP -648 GPM,1345 PSI,40%FLOW OUT -CIRCULATED UNTIL RETURNS CLEANED UP, 1.5 WELLBORE VOLUMES -A FEW SMALL PIECES OF SCALE RETURNED WITH THE SWEEP MONITOR WELL 10 MIN PRIOR TO PULLING 'OFF BOTTOM-WELL STATIC -8.5 PPG SEAWATER Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 6 o1: ".."-- Operation 13'."-- Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad 1 Rig Name/No.:DOYON 25 Spud Datemme:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292058700 Active datum:Y-10B Actual©90.54usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 07:00 4.00 CLEAN P WEXIT POOH RACKING BACK WITH 9-5/8"CLEAN OUT BHA FROM 3,516'MD TO 880'MD -MONITOR DISPLACEMENT VIA THE TRIP TANK -MONITOR WELL PRIOR TO PULLING BHA 'THROUGH THE BHA -LD BHA FROM 880'MD TO SURFACE 07:00 - 07:30 0.50 CLEAN P WEXIT CLEAN AND CLEAR RIG FLOOR -LD BAKER BOOT BASKETS,BUMPER SUB, &XO'S DOWN THE BEAVER SLIDE -SPOT SLB ELINE TRUCKS IN PLACE 07:30 - 08:00 0.50 EVAL P WEXIT RU SLB E-LINE UNIT -RU SHEAVES,LINE AND HALLIBURTON EZSV 08:00 - 13:30 5.50 EVAL P WEXIT RIH WITH 9-5/8"EZSV/GR/CCL -RIH ON E-LINE WITH AIR LINE WIPER -MONITORING DISPLACEMENT ON THE TRIP TANK -MAKE CORRELATION LOG PASS,CONFIRM WITH GEO FOR CORRECT SETTING DEPTH. LOCATE CLOSEST COLLAR TO KOP IN THE SV4-2,809' -SET EZSV 5'ABOVE COLLAR AT 2,809', -PLACING BOTTYOM OF EZSV AT 2,804'MD -TOP OF EZSV AT 2,801'MD(WLM) -POOH WITH E-LINE 13:30 - 15:00 1.50 CLEAN P DECOMP TEST EZSVAND THE 9-5/8"CASING -CLOSE BLIND SHEAR RAMS -PRESSURE TEST 250 PSI LOW 5 MIN,4000 PSI HIGH 30 MIN -ALL TESTS CHARTED -NOTIFY AND SEND MIT CRITERIA CALCULATOR SHEET TO WTL FOR ,APPROVAL -TEST APPROVED BY BP WTL JIM WILLINGHAM 15:00 - 15:30 0.50 CLEAN P DECOMP RIG DOWN SLB E-LINE -RD TEST EQPT 15:30 - 17:30 2.00 CLEAN P DECOMP PJSM -PU BHA,DDI,BAKER,BP -MU WHIPSTOCK,ANCHOR&MILLING ASEMBLY BHA AS FOLLOWS: -TRIP ANCHOR,WHIPSTOCK,STARTER MILL, (3)WATERMELLON MILLS,HWDP,FLOAT SUB, MWD,(9)6-1/2"DC'S,(18)HWDP,5"DP TOTAL BAH LENGTH:918.63 17:30 - 20:30 3.00 STWHIP P WEXIT RIH WITH WHIPSTOCK MILLING ASSEMBLY ON 5"DP STANDS FROM THE DERRICK @ 60'/MIN -SLOWLY IN AND OUT OF THE SLIPS -RIH ON ELEVATORS TO 2,717 MD 84'ABOVE THE EZSV -MONITORING DISPLACEMENT VIA THE TRIP TANK 20:30 - 22:00 1.50 STWHIP P I WEXIT RU GYRO DATA GYRO ON HALLIBURTON E-LINE -RU SHEIVES AND LINE WIPER 22:00 - 23:00 1.00 STWHIP P WEXIT RIH ON E-LINE WITH GYRO TO 2,717' -ORIENT WHIPSTOCK USING GYRO SEATED IN UBHO -ORIENT TO 116 DEG AZIMUTH-SLB DIRECTIONAL PLAN Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 7 Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292058700 Active datum:Y-10B Actual @90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 23:30 0.50 STWHIP P WEXIT SET WHIPSTOCK ANCHOR -RIH FROM 2,717'MD TAG TOP OF EZSV AT 12,803'MD(DPM) -PUW-128K,SOW-i 36 j ! -SET DOWN 19K AND SET TRIP ANCHOR -PICKED UP TO 20K OVER STRING WEIGHT TO VERIFY TRIP ANCHOR SET -SET DOWN WITH 48K DOWN WEIGHT TO SHEAR OFF WHIPSTOCK SLIDE -GOOD SET 23:30 - 00:00 0.50 DHB P WEXIT PJSM FOR PU AND SETTING THE RTTS STORM PACKER -POOH TWO STANDS F/2,803'TO 2622' -RIH TO 2,717'AND SET RTTS PER HALLIBURTON REP DIRECTION -RTTS SET-102'BELOW WELLHEAD 12/17/2013 00:00 - 00:30 0.50 DHB P WEXIT PRESSURE TEST RTTS STORM PACKER -PRESSURE TEST TO 250 PSI LOWAND 2000 PSI HIGH FOR 5 CHARTED MIN -BOTH TESTS GOOD 00:30 - 01:00 0.50 BOPSUR P WEXIT PU 5"DP JOINT AND PULL WEAR BUSHING -SUCK OUT STACK,PREP FOR ND OF RISER AND BELL NIPPLE 01:00 - 04:00 3.00 BOPSUR P WEXIT ND BOPE AND SET BACK -PJSM FOR ND BOPE -PULL AND SET BACK HIGH PRESSURE RISER 1-BREAK AND SET BACK TUBING SPOOL -BARRIERS IN PLACE FOR ND-CMT PLUG fa 7 622',RTTS STORM PACKER 04:00 - 07:00 3.00 WHSUR P DECOMP j CHANGE OUT MANDREL HANGER NECK SEA -PJSM FOR CHANGE OUT OF NECK SEALS ! I CHANGE OUT NECK SEALS PER CAMERON PROCEDURE AND INSPECT TUBING SPOOL- OK MU SPOOL TO CASING HEAD I I -LOWER RISER OVER TUBING SPOOL TO ENGAGE THE NECK SEALS -PU RISER AND SET BACK,TORQUE TUBING SPOOL TO CASING HEAD 07:00 - 07:30 0.50 WHSUR P DECOMP PRESSURE TEST THE 9-5/8"HANGER UPPER NECK SEALS -250 PSI LOW 5 MIN,3500 PSI HIGH 5 MIN ALL TESTS CHARTED-GOOD 07 30 - 10:00 2.50 BOPSUR P DECOMP NU BOPE -INSTALL FLOW BOX,DP WIPER,FLOW LINE, FLOW NIPPLE&HOLE FILL LINE 10:00 - 11:00 1.00 BOPSUR P DECOMP PRESSURE TEST THE BREAKS IN THE BOPE -INSTALL TEST PLUG,FILL STACK AND CLOSE BLINDS -250 PSI LOW,4000 PSI,5/5 CHARTED- GOOD TEST -BLOW DOWN CHOKE AND KILL LINES 11:00 - 11:30 0.50 DHB P DECOMP PULL TEST PLUG -INSTALL WEAR RING,ID-8.875",OD=13.5", LENGTH=15" Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 8022- Operation 2Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011 M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292058700 Active datum:Y-10B Actual©90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:30 1.00 DHB P DECOMP PULL RTTS STORM PACKER -RIH WITH RTTS STORM PACKER RETRIEVAL TOOL ON 5"DP TO PULL RTTS -RIH TO 103'&MU TO RTTS -POOH WITH RTTS&LD -RUN BACK IN THE HOLE AND TAG TOP OF WHIP STOCK-2,781'MD 12:30 - 13:30 1.00 DISPL P WEXIT DISPLACE WELL TO 9.5 PPG LSND -PULL UP TO 2,778'MD -PUW-117 K,SOW-130 K -PUMP 45 BBLS OF WATER AT 190 GPM,106 PSI -PUMP 50 BBLS OF HI-VIS SPACER AT 190 GPM,100 PSI -CONTINUE DISPLACING WELL UNTIL 9.5 PPG LSND IN/OUT -500 GPM,100 PSI, _ 9r '( 13:30 - 23:00 9.50 STMILL P WEXIT MILL WINDOWAS PER BAKER REP F/2,781' `) TO 2,815'.(TOW 2,781',BOW 2,798') 1-103 -400-450 GPM,400-500 PSI,2-10K WOB -80-90 RPM, TQ 3-8 K,MW-9.5 PPG PUW-117K,SOW-130K,ROT-127K TOW=2,781'MD,MOW=2,790'MD,BOW= 2,798'MD 305 LBS OF METAL SHAVINGS RECOVERED 23:00 - 23:30 0.50 STMILL P WEXIT BACK REAM WINDOW -WORK MILLS PAST THE WINDOW X 2 W/ ROTATION AND PUMPS -110 RPM,450 GPM,440 PSI -WORKED PAST WINDOW W/NO ROTATION AND PUMPS ON X 2 -110 RPM,450 GPM,450 PSI -WORKED PAST WINDOW WITH NO PUMPS AND NO ROTATE X 2 23:30 - 00:00 0.50 STMILL P WEXIT PUMP SUPER SWEEP PILL AND CIRCULATE HOLE CLEAN -500 GPM,910 PSI,20 RPM,1-2K TO, -TOTAL PUMPED: 1-1/2 BOTTOMS UP -MINIMAL CUTTINGS RETURNED FROM SWEEP 12/18/2013 00:00 - 01:30 1.50 STMILL P WEXIT POOH TO 2,726'MD. R/U TEST EQUIPMENT FOR LOT 01:30 - 03:30 2.00 STMILL P WEXIT RIG UP AND PERFORM LOT -MUD WEIGHT:9.5 PPG,-TVD=2,797',MD= 2,798' -PUMPED 5.5 BBLS,BLEED BACK 1.5 BBLS -LOT EMW=14.00 PPG(655 PSI SURFACE PRESSURE) -LOT APPROVED BY WTL MONITOR WELL FOR 10 MIN-STATIC R/D TEST EQUIPMENT 03:30 - 05:00 1.50 STMILL P WEXIT POOH FROM 2,726'MD TO 918'MD -MONITORING DISPLACEMENT VIA THE TRIP TANK-HOLE TAKING CORRECT FILL MW-9.5 PPG IN/OUT Printed 12/30/2013 1:19:27PM North America-ALASKA-BP Page 92y22_ Operation Summary Report Common Well Name:Y-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/10/2013 End Date: X3-011M4-C:(13,544,400.00) Project:Prudhoe Bay Site:PB Y Pad Rig Name/No.:DOYON 25 Spud Date/Time:7/5/1981 12:00:00AM •Rig Release: Rig Contractor.DOYON DRILLING INC. UW:500292058700 Active datum:Y-10B Actual @90.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 105:00 - 08:00 3.00 STMILL P WEXIT POOH FROM 918'MD TO SURFACE LAYING DOWN BHA -MONITOR WELL PRIOR TO PULLING BHA THROUGH THE STACK-WELL STATIC -STAND BACK 4 STANDS OF HWDP,LD DC'S &MILLING ASSEMBLY. 1 -STARTER MILL 3/8"OUT OF GAUGE -LOWER STRING MILL 1/4"OUT OF GAUGE -BOTH UPPER STRING MILLS IN GAUGE 08:00 - 08:30 I 0.50 STMILL i P WEXIT CLEAN AND CLEAR RIG FLOOR -LD BAKER MILLS 08:30 - 10:00 1.50 STMILL P WEXIT PULL WEAR BUSHING -RIH WITH 5"BOPE STACK JET RINSE TOOL &RINSE STACK -FUNCTION TEST VBR'S AND BLINDS -CLEAN AND FLUSH FLOW LINE AND SHAKER BEDS -INSTALL WEAR RING,ID-8.875",OD=13.5", LENGTH=15" C/O SLIP INSERTS 10:00 - 13:00 3.00 STMILL P WEXIT DRILL PIPE MANAGEMENT RIH WITH 5"DP SINGLES WITH MULE SHOE ON BOTTOM T/2,747'MD MONITOR TRIP ON THE TRIP TANK 13:00 - 14:30 1.50 STMILL P WEXIT 'POOH FROM 2,747'MD TO SURFACE -MONITOR WELL PRIOR TO PULLING BHA THROUGH THE STACK-WELL STATIC -C/O PS-21 SLIP INSERTS AND T/HAND INSERTS. 14:30 - 21:00 6.50 STMILL P WEXIT P/U INTERMEDIATE DRILLING BHA#1 AS PER SCHLUMBERGER DD -HOLD PJSM FOR P/U BHA -RIH T/647'MD&MONITOR WELL -RIH F/647'T/2400'MD PICKING UP SINGLES FROM THE PIPE SHED -SHALLOW HOLE TEST @ 1590'W/500 GPM, 1100 PSI -RIH F/2400'T/2,730'@ 720 FPH -TRIP MONITORED ON THE TRIP TANK -LOGGING PASS AS PER GEO- -2,400 TO 2,781'MD(TOP OF WINDOW) -WASH DOWN F/2,781'MD TO 2,815'MD -450 GPM,992 PSI 21:00 - 00:00 3.00 DRILL P INTI DRILL 8-1/2"INTERMEDIATE FROM 2,825'TO 2920'MD(2,920'TVD) RIH W/GYRO DATA T/2,825'T/ORIENT TOOL FACE,POOH W/GYRO DRILL AHEAD INTERMEDIATE -500 GPM,1270 PSI ON 1220 PSI OFF -MW 9.5 IN/9.5 OUT,ECD 10.20 PPG -30 RPM,2K TQ ON/1K TQ OFF -4-6K WOB -AST=1.38 HRS,ART=1.89,ADT=3.27 HRS -P/U=115K,S/O=125K -CONTINUE TAKING GYRO SURVEYS @ EACH CONNECTION T/ORIENT TOOL FACE SPR'S AT 2821'MD(2821'TVD),TIME 20:45, MW9.5PPG #1 MP-20/30 SPM=180/210 PSI #2 MP-20/30 SPM=160/190 PSI Printed 12/30/2013 1-19:27PM • T121EE= 4"CNV SAf K)TESS:H2S READINGS AVERAGE 125 ppm VVELLFEAD= _GRAY Y-1 OA WI-EN vNMI.WELLREQUIRES ASSSVWHEN ONML ACTUATOR= _ BAKER C WELL ANGLE >70°@ 965T. ***OVERSHOT GUIDE M_IAL KB.ELEb - 85.69' COVERS CUT STUB.SEE TELEX FOR DETAILS.*** BF.ELEV;- 51.59' f I CI-ROME NIPPLES IN TBG *" KOP= 2800' 2574' 1-9-5/8"EN FKR - - -- Max Angle= 98'@ 109_15' 120" CONDUCTOR - 144 Datum MD= 9502' Datum TVD=-----8800'SS /.4k 2781' .I..-9-5/8"WHIPSTOCK(12/16/13) 13-3/8"CSG,72#,L-80,D=12.347" - 2709' 7270' SLM -ESTMATEJ TOP OF CEMEPIT(08/28/13) 9-5/8"EZSV(12/16/13) --I 2801' lig 8621'-8628'I-TBG PUNCH(08/25/13 JET CUT(09/04/13) H 3507' r' '4"... lig 8670' -4-1/2"HES X NP(9CR),D=3.813" Minimum ID =3.813" @ 2032' m $701' r-9-5/8"x 4-1/2"BKR S-3 PKR,D=3.87" MEI 4-1/2" HES X NIPPLE 8725' N4-1/2"FES XNP(9CR),D=3.813" • '#.•+. 8725" TOP OF CBV4ENT(08/19/13) 4-1/2"TBG, 12.6#,L-80 TO,-0152 bpf,D=3.958" 8787' iv: +�� 4-1/2"TBG STUB(08/11/07) 8795' 'e •;4 8796' 1-9-5/8"X 4-1/2" UNIQUE OVERSHOT 8832' _4-112"HES X NP(9CR),1D=3.813" ' '%4:,,i, 8843" H9-5/8"x 4-1/2"TM/HBBP-T PKR,13=3.92" ' 4 - 886T I-4-1/2"HES X NP(9CR),ID=3-813" sNosAr. 4$11 # ill # 8888' 4-1/2"HES X NP(9CR),D=3.813" 4-1/2"TBG, 12.6#,L-80 NSCT,.0152 bpf,13=3.958" H 8903' 1-- 4.11/4+ 4• 4-1/2"TBG STUB(TAGG®11/03/95) 8907' *► `s• 8910' I-9-5/8"X 4-1/2"UNIQUE OVERSHOT 8915' }-BAKER TBG SEAL ASSY . 8935' 9-5/8"x 4-1/2"BKR R<R,D=4.000" I• 8979' -4-1/2"HES X NP,D=3.813" TOP OF 7"LNR $985' - .ii011 TOP OF 3-1/2"X 6-3/16""LNR -I 8989' .)ioirli� m 8989' H3.70"BKR DEPLOY SLV,ID=3.00" '4 II t 8998' 3-1/2"HES X NP,D=2-813" 3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,ID=2.992" - 9027' `I pi.I�1,1(19�' ' 9012' I-4-1/2"HES XN NP,MILLED TO 3-8"(02/05/05) �/ �►!, BBIND PIPE 4-1/2"TBG,12.6#,L-80 BUTT,.0152 bpf,D=3.958" H 9038' 1,/! (1�1 '/1 KIM 9027' �3-1/2"X 3-3/16"XO,D=2.786" TOP OF CEMENT(01/19/05) 9449' •..1 '1.•1 11111 9037'ELM _1CUT OFF TBG TAIL(02/17/88)(BEHIND PIPE) 1.44 9-5/8"CSG,47#,L-80 BUTT,D=8.681" H 9464' 1111 )1111 11 1/ 7"WHIPSTOCK(01/14/05) H 9503' �1�4 �1�1. *Al. `11114 7"LNR,29#,L-80,.0371 bpf,D=6-184" 9507' 141 ..k!.1 "4`v74 MLLOUT WINDOW(Y-10A) 9507'-9512' PERFORATION SUMMARY ,4vQ •••••••• REF LOG:CBL ON 07/21/81 111111111111111 4tIP. ANGLE AT TOP PERF: 95'@ 10820' 1111111/1/1/1/' 1111111 Note:Refer to Production DB for historical perf data /1.?1111 1/ 111. SIZE SPF_ INTERVAL Opn/Sqz SI-DT SQZ 111. 4114 1111�'4�111 2" 6 10820-10845 S 02/22/05 08/19/13 11111111 2" 6 10880-10905 S 02/22/05 08/19/13 4'4.4.444....' 11074' -PB1 D 2" 6 10930-10950 S 02/22/05 08/19/13 NPr 2" 6 10970-11000 S 02/22/05 08/19/13 2" 6 11050-11070 S 02/22/05 09/06/13 3-3/16"LNR,62#,L-80 TCI, H 11109' A,� .0076 bpf,D=2.80" `11F DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY INT 07/22/81 VAN II INITIAL COMPLETION 09/06/13 ATO/PJC TBG PUNCH(08/25/13) WELL: Y-10A 11/05/95 D14 F&JO 09/06/13 RWM/PJC JET CUT(09/04/13) PERMT No:2042500 02/22/05 NORDICI _CTD SIDETRACK(Y-10A) 09/06/13 TBD/PJC TAG TOC(08/25/13) API No: 50-029-20587-01 08/14/07 D14 RWO SEC 33,T11 N,R13E, 1410'FNL&205'FEL 05/24/13 PJC DRAWING UPDATES(PRE RIG) 09/06/13 REMR)C CMT SQZ(8/19&8/27/13) BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, December 02, 2013 2:44 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Wallace, Chris D (DOA); Warner, Scott; AK, OPS Well Pad YP Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: NOT OPERABLE: Injector Y-10A(PTD#2042500)Jet Cut Tubing All, Injector Y-10A(PTD#2042500) is scheduled for a rotary sidetrack in December 2013. The tubing has been cut in preparation for the sidetrack. The well is reclassified as Not Operable until tubing integrity is restored and confirmed, and will be added to the Quarterly Not Operable Injector Report. Please call with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator @bp.com WORM 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Ze1�2 1103 DATE: August 23, 2013 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector BP Exploration PBU Y-10A PTD 2042500 SCANNED L 4 �r 01.' Sundry #312-005 Wednesday, August 21, 2013; I witnessed the verification of wellbore plug integrity by tag and pressure test on BP Exploration well PBU Y-10A in the Prudhoe Bay Field. I met Jeremiah Galloway (BPX rep.) on location this morning at the Schlumberger Oilfield Services (SOS) wireline (W/L) unit and was provided an extremely complete packet of information on the history of the well along with the cement details and planned work yet to be performed. This helped greatly as I was lacking background on this operation. This plug will be used for isolation for upcoming rig workover on the MI injector. There was also a Little Red Services (LRS) pumping unit on location which would provide pumping for the pressure test portion of this operation. The W/L unit was already in the hole with a 1.75-inch "Drive Down" sample bailer with a 2.75-inch centralizer above it. The SOS W/L operator tagged and jarred through a few bridges between 8667 ft and 8690 ft measured from the tubing ✓ hanger flange (THF) where the tools fetched up and would go no deeper. The tools were withdrawn from the well without apparent sticking. Upon arrival at surface I had the operator check his zero again and found it to be -10 ft which is about expected for this depth of operation. The sample bailer was emptied of its contents which appeared to be soft cement with an unpleasant urea type odor. LRS was lined up on the well and a 30 minute pressure test was performed during which an excessive amount of pressure (psi) was lost. String Pretest Initial 15 Minutes 30 Minutes IA 1 15 16 16 OA 0 0 0 0 Tubing 5 3004 - 2766 - 2702 - z ; r6 S 2013-082 1_W ellbore_Plug_PBU_Y-10A_lg.docx 1 of 2 ! • I found this loss to be excessive and requested that the W/L unit tag the plug again to check for plug movement. This time I also asked that the 2.75-inch centralizer and 1.75-inch drive down sample bailer be dropped and a 2.5-inch" x 4-foot drive down bailer be used. I had the crew "dress" the bailer bottom before running. Second Tag with W/L The tools were zeroed at the THF, run in the hole to approximately the same depth of 8688 ft and jarred down to 8691 ft (wireline measurement; WLM). The --' tools stuck somewhat but were withdrawn with approximately 700 pounds of over- pull. The retrieval of the tools was uneventful and upon reaching surface the same 10-foot correction was observed. The bailer bottom was not marked significantly and there was the same material in the bailer as was in the earlier tag. I concluded the plug had not moved. It was agreed to try another pressure test. / Second Pressure Test with LRS LRS was lined up on the well and the second pressure was somewhat better, but not nearly as solid as I would have liked. String Pretest Initial 15 Minutes 30 Minutes IA 10 15 17 17 OA 0 0 0 0 Tubing 10 3018 2830 2777 Z 4(ps; 4 I again felt this was excessive loss during the test although everyone on location loss seemed to want to apply a 10% allowance during the test. I did not feel comfortable with passing this plug and suggested a 24 hour "Negative Pressure Test" be performed after I left with the results made available to us to aid in t' determination. I also am inclined to suggest that coil tubing be used to "wash down" to hard cement on these necessary plugs. Attachments: Y-10A AOGCC MIT-T#1 PBU 08-21-2013_DETAILED. pdf Y-10A AOGCC MIT-T#2 PBU 08-21-2013_DETAILED.pdf Non-Confidential 2013-0821_Wellbore_Plug_PBU_Y-10A_lg.docx 2 of 2 • • LITTLE RED SERVICES Pressv Ted- 44-/ Detailed Job Breakdown • • Little Red JOB REPORT Services COMPANY DETAILS Company: BP Contact: Fullbore WSL Phone#: 907-659-5588 JOB DETAILS DATE August 21, 2013 START TIME 14:05:10 Location: Y-10A END TIME 14:36:17 Operator: Kindred Unit#:62 Test Type: AOGCC MIT-T Fluid Pumped#1: Fluid Pumped#2: Fluid Pumped#3: Fluid Pumped#4: Comments: Pumped 3.47 bbls AMB diesel to test. "'FAILED**Test#1 OA WIRELESS(PSI) 3000 2500 2000 1500 1000 500 0 14:05 14:10 14:15 14:20 14:25 14:30 14:35 21 Wed Aug 2013 • • 14:05:13 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:05 13.190 2,993 14:05 18.170 3,004 14:05 23.170 2,990 14:05 28.200 2,994 14:05 33.140 2,994 14:05 38.200 2,983 14:05 43.170 2,985 14:05 48.200 2,982 14:05 53.170 2,976 14:05 58.170 2,974 14:06 3.200 2,970 14:06 8.170 2,968 14:06 13.220 2,964 14:06 18.250 2,964 14:06 23.190 2,962 14:06 28.220 2,959 14:06 33.250 2,955 14:06 38.280 2,953 14:06 43.220 2,950 14:06 48.250 2,947 14:06 53.280 2,946 14:06 58.310 2,942 14:07 3.230 2,942 14:07 8.270 2,940 14:07 13.310 2,938 14:07 18.260 2,935 14:07 23.300 2,933 14:07 28.330 2,931 14:07 33.360 2,928 14:07 38.300 2,926 14:07 43.340 2,926 14:07 48.380 2,924 14:07 53.330 2,921 14:07 58.370 2,920 14:08 3.330 2,917 14:08 8.390 2,915 14:08 13.340 2,913 14:08 18.390 2,910 14:08 23.310 2,908 14:08 28.340 2,908 14:08 33.370 2,908 14:08 38.420 2,905 14:08 43.370 2,903 14:08 48.410 2,901 14:08 53.340 2,899 14:08 58.380 2,897 14:09 3.420 2,896 14:09 8.340 2,896 _ Page 3 of 10 Report Created: 21-Aug-13 • • 14:09:13 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:09 13.390 2,894 14:09 18.390 2,892 14:09 23.340 2,889 14:09 28.440 2,888 14:09 33.380 2,885 14:09 38.420 2,885 14:09 43.450 2,884 14:09 48.380 2,883 14:09 53.420 2,880 14:09 58.450 2,878 14:10 3.390 2,878 14:10 8.420 2,877 14:10 13.450 2,875 14:10 18.410 2,873 14:10 23.440 2,872 14:10 28.470 2,870 14:10 33.410 2,868 14:10 38.440 2,867 14:10 43.480 2,866 14:10 48.420 2,866 14:10 53.450 2,863 14:10 58.480 2,862 14:11 3.420 2,862 14:11 8.450 2,859 14:11 13.480 2,858 14:11 18.420 2,857 14:11 23.450 2,856 14:11 28.480 2,854 14:11 33.410 2,854 14:11 38.450 2,851 14:11 43.480 2,850 14:11 48.410 2,850 14:11 53.480 2,848 14:11 58.410 2,848 14:12 3.440 2,846 14:12 8.470 2,844 14:12 13.500 2,843 14:12 18.420 2,842 14:12 23.450 2,841 14:12 28.500 2,841 14:12 33.530 2,840 14:12 38.450 2,838 14:12 43.510 2,837 14:12 48.550 2,836 14:12 53.470 2,835 14:12 58.510 2,834 14:13 3.560 2,832 14:13 8.520 2,831 Page 4 of 10 Report Created: 21-Aug-13 • • 14:13:13 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:13 13.550 2,831 14:13 18.580 2,829 14:13 23.520 2,829 14:13 28.550 2,827 14:13 33.590 2,827 14:13 38.550 2,826 14:13 43.580 2,824 14:13 48.630 2,824 14:13 53.560 2,823 14:13 58.610 2,823 14:14 3.640 2,821 14:14 8.560 2,820 14:14 13.590 2,820 14:14 18.640 2,818 14:14 23.690 2,816 14:14 28.620 2,817 14:14 33.670 2,815 14:14 38.610 2,815 14:14 43.660 2,814 14:14 48.690 2,813 14:14 53.630 2,812 14:14 58.670 2,810 14:15 3.720 2,810 14:15 8.660 2,809 14:15 13.690 2,808 14:15 18.730 2,807 14:15 23.670 2,807 14:15 28.720 2,806 14:15 33.670 2,806 14:15 38.750 2,804 14:15 43.670 2,803 14:15 48.700 2,802 14:15 53.730 2,801 14:15 58.670 2,800 14:16 3.700 2,799 14:16 8.760 2,799 14:16 13.690 2,799 14:16 18.720 2,798 14:16 23.760 2,797 14:16 28.800 2,796 14:16 33.720 2,794 14:16 38.750 2,794 14:16 43.810 2,794 14:16 48.780 2,793 14:16 53.810 2,793 14:16 58.750 2,792 14:17 3.780 2,791 14:17 8.780 2,790 Page 5 of 10 Report Created: 21-Aug-13 • 14:17:13 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:17 13.830 2,790 14:17 18.780 2,788 14:17 23.830 2,788 14:17 28.860 2,787 14:17 33.830 2,787 14:17 38.780 2,787 14:17 43.810 2,785 14:17 48.840 2,785 14:17 53.780 2,783 14:17 58.810 2,782 14:18 3.840 2,783 14:18 8.870 2,781 14:18 13.830 2,781 14:18 18.860 2,781 14:18 23.890 2,780 14:18 28.810 2,780 14:18 33.860 2,779 14:18 38.810 2,778 14:18 43.840 2,777 14:18 48.890 2,777 14:18 53.840 2,776 14:18 58.920 2,774 14:19 3.840 2,774 14:19 8.890 2,775 14:19 13.920 2,773 14:19 18.870 2,773 14:19 23.910 2,772 14:19 28.940 2,772 14:19 33.860 2,771 14:19 38.890 2,770 14:19 43.940 2,770 14:19 48.970 2,770 14:19 53.910 2,769 14:19 58.970 2,768 14:20 4.000 2,768 14:20 8.940 2,767 14:20 13.980 2,766 14:20 18.950 2,766 14:20 24.030 2,765 14:20 28.950 2,765 14:20 33.980 2,764 14:20 39.010 2,764 14:20 44.050 2,763 14:20 48.980 2,763 14:20 54.010 2,761 14:20 58.970 2,762 14:21 4.020 2,762 14:21 8.970 2,762 Page 6 of 10 Report Created: 21-Aug-13 • 14:21:13 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:21 14.000 2,759 14:21 19.030 2,760 14:21 24.080 2,759 14:21 29.060 2,758 14:21 34.020 2,758 14:21 39.080 2,758 14:21 44.110 2,757 14:21 49.030 2,757 14:21 54.060 2,757 14:21 59.090 2,755 14:22 4.030 2,755 14:22 9.090 2,755 14:22 14.120 2,754 14:22 19.060 2,753 14:22 24.120 2,753 14:22 29.120 2,752 14:22 34.060 2,752 14:22 39.110 2,752 14:22 44.140 2,752 14:22 49.080 2,751 14:22 54.110 2,751 14:22 59.140 2,750 14:23 4.190 2,749 14:23 9.110 2,749 14:23 14.140 2,749 14:23 19.170 2,749 14:23 24.110 2,747 14:23 29.140 2,747 14:23 34.200 2,747 14:23 39.140 2,746 14:23 44.190 2,745 14:23 49.230 2,745 14:23 54.170 2,745 14:23 59.220 2,744 14:24 4.250 2,744 14:24 9.190 2,744 14:24 14.230 2,743 14:24 19.170 2,743 14:24 24.230 2,743 14:24 29.270 2,742 14:24 34.190 2,741 14:24 39.230 2,741 14:24 44.270 2,741 14:24 49.200 2,741 14:24 54.230 2,740 14:24 59.260 2,739 14:25 4.310 2,739 14:25 9.280 2,739 Page 7 of 10 Report Created: 21-Aug-13 • S 14:25:14 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:25 14.250 2,738 14:25 19.280 2,738 14:25 24.310 2,737 14:25 29.340 2,736 14:25 34.300 2,736 14:25 39.330 2,736 14:25 44.360 2,736 14:25 49.330 2,735 14:25 54.360 2,736 14:25 59.390 2,735 14:26 4.310 2,734 14:26 9.340 2,733 14:26 14.390 2,733 14:26 19.420 2,733 14:26 24.360 2,733 14:26 29.420 2,733 14:26 34.360 2,732 14:26 39.410 2,732 14:26 44.340 2,732 14:26 49.390 2,731 14:26 54.440 2,730 14:26 59.360 2,730 14:27 4.410 2,730 14:27 9.440 2,730 14:27 14.370 2,728 14:27 19.420 2,728 14:27 24.450 2,729 14:27 29.390 2,728 14:27 34.440 2,727 14:27 39.470 2,727 14:27 44.500 2,727 14:27 49.420 2,727 14:27 54.450 2,727 14:27 59.500 2,727 14:28 4.450 2,726 14:28 9.480 2,726 14:28 14.520 2,725 14:28 19.480 2,724 14:28 24.450 2,724 14:28 29.480 2,725 14:28 34.510 2,724 14:28 39.550 2,723 14:28 44.470 2,723 14:28 49.520 2,723 14:28 54.560 2,723 14:28 59.500 2,722 14:29 4.550 2,722 14:29 9.580 2,722 Page 8 of 10 Report Created: 21-Aug-13 • • 14:29:14 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:29 14.560 2,721 14:29 19.590 2,721 14:29 24.560 2,721 14:29 29.630 2,721 14:29 34.550 2,721 14:29 39.590 2,720 14:29 44.630 2,720 14:29 49.560 2,720 14:29 54.620 2,719 14:29 59.670 2,719 14:30 4.610 2,718 14:30 9.660 2,718 14:30 14.690 2,718 14:30 19.640 2,718 14:30 24.670 2,717 14:30 29.700 2,717 14:30 34.640 2,717 14:30 39.690 2,717 14:30 44.730 2,716 14:30 49.670 2,716 14:30 54.730 2,715 14:30 59.670 2,715 14:31 4.730 2,715 14:31 9.670 2,714 14:31 14.700 2,715 14:31 19.730 2,715 14:31 24.670 2,714 14:31 29.720 2,714 14:31 34.770 2,714 14:31 39.730 2,714 14:31 44.780 2,713 14:31 49.700 2,712 14:31 54.750 2,713 14:31 59.780 2,712 14:32 4.730 2,712 14:32 9.780 2,712 14:32 14.810 2,711 14:32 19.730 2,711 14:32 24.780 2,711 14:32 29.840 2,710 14:32 34.780 2,710 14:32 39.840 2,710 14:32 44.800 2,709 14:32 49.830 2,709 14:32 54.880 2,709 14:32 59.800 2,710 14:33 4.840 2,709 14:33 9.810 2,709 Page 9 of 10 Report Created: 21-Aug-13 • • 14:33:14 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 14:33 14.890 2,708 14:33 19.810 2,708 14:33 24.860 2,708 14:33 29.910 2,708 14:33 34.860 2,707 14:33 39.890 2,707 14:33 44.920 2,707 14:33 49.950 2,707 14:33 54.870 2,706 14:33 59.910 2,707 14:34 4.940 2,706 14:34 9.970 2,705 14:34 14.890 2,705 14:34 19.940 2,706 14:34 24.970 2,705 14:34 30.000 2,705 14:34 34.920 2,705 14:34 39.950 2,705 14:34 44.980 2,705 14:34 50.020 2,703 14:34 54.940 2,703 14:34 59.980 2,704 14:35 5.020 2,704 14:35 10.050 2,704 14:35 14.970 2,703 14:35 20.000 2,702 14:35 25.030 2,702 14:35 30.060 2,702 14:35 34.980 2,702 14:35 40.020 2,702 14:35 45.050 2,702 14:35 50.080 2,702 14:35 55.000 2,701 14:36 0.030 2,701 14:36 5.060 2,701 14:36 10.090 2,701 14:36 15.020 2,701 14:36 17.530 2,701 Page 10 of 10 Report Created: 21-Aug-13 • LITTLE RED SERVICES Pre s5we les�— - Detailed Job Breakdown • • Little Red JOB REPORT Services COMPANY DETAILS Company: BP Contact: Fullbore WSL Phone#: 907-659-5588 JOB DETAILS DATE August 21, 2013 START TIME 16:34:22 Location: Y-10A END TIME 17:04:07 Operator: Kindred Unit#:62 Test Type: AOGCC MITT to 3000 Fluid Pumped#1:Diesel Fluid Pumped#2: Fluid Pumped#3: Fluid Pumped#4: Comments: Pumped 3.7 bbls AMB diesel to test. **PASSED**Witnessed by Lou Grimaldi OA WIRELESS(PSI) 3000 2500 2000 1500 1000 500 0 16:35 16:40 16:45 16:50 16:55 17:00 17:05 21 Wed Aug 2013 • • • 16:34:26 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:34 26.800 3,028 16:34 31.830 3,047 16:34 36.860 3,018 16:34 41.890 3,036 16:34 46.840 3,031 16:34 51.860 3,015 16:34 56.890 3,024 16:35 1.920 3,011 16:35 6.840 3,016 16:35 11.880 3,016 16:35 16.910 3,006 16:35 21.940 3,004 16:35 26.860 3,006 16:35 31.890 2,999 16:35 36.920 3,000 16:35 41.950 2,994 16:35 46.870 2,994 16:35 51.910 2,994 16:35 56.940 2,992 16:36 1.970 2,988 16:36 6.890 2,987 16:36 11.940 2,983 16:36 16.970 2,982 16:36 22.000 2,979 16:36 26.920 2,977 16:36 31.950 2,975 16:36 36.980 2,973 16:36 42.020 2,970 16:36 46.940 2,970 16:36 51.970 2,968 16:36 57.000 2,967 16:37 2.030 2,965 16:37 6.950 2,962 16:37 11.980 2,961 16:37 17.020 2,959 16:37 22.050 2,956 16:37 26.970 2,954 16:37 32.000 2,954 16:37 37.030 2,953 16:37 42.060 2,951 16:37 46.980 2,950 16:37 52.020 2,948 16:37 57.050 2,946 16:38 2.080 2,944 16:38 7.000 2,942 16:38 12.030 2,942 16:38 17.060 2,940 16:38 22.090 2,938 Page 3 of 10 Report Created: 21-Aug-13 • • 16:38:27 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:38 27.020 2,936 16:38 32.060 2,935 16:38 37.090 2,934 16:38 42.120 2,934 16:38 47.050 2,931 16:38 52.080 2,929 16:38 57.110 2,927 16:39 2.140 2,927 16:39 7.060 2,927 16:39 12.090 2,926 16:39 17.120 2,924 16:39 22.160 2,921 16:39 27.080 2,920 16:39 32.110 2,919 16:39 37.140 2,919 16:39 42.170 2,917 16:39 47.090 2,916 16:39 52.120 2,915 16:39 57.160 2,913 16:40 2.190 2,911 16:40 7.110 2,910 16:40 12.140 2,909 16:40 17.170 2,907 16:40 22.200 2,907 16:40 27.120 2,905 16:40 32.160 2,904 16:40 37.190 2,904 16:40 42.220 2,902 16:40 47.140 2,900 16:40 52.190 2,900 16:40 57.220 2,899 16:41 2.250 2,897 16:41 7.170 2,897 16:41 12.200 2,897 16:41 17.230 2,896 16:41 22.260 2,894 16:41 27.190 2,892 16:41 32.220 2,891 16:41 37.250 2,891 16:41 42.280 2,888 16:41 47.200 2,888 16:41 52.440 2,888 16:41 57.500 2,887 16:42 2.530 2,886 16:42 7.560 2,885 16:42 12.590 2,884 16:42 17.630 2,884 16:42 22.550 2,882 Page 4 of 10 Report Created: 21-Aug-13 • • 16:42:27 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:42 27.580 2,881 16:42 32.610 2,880 16:42 37.640 2,880 16:42 42.560 2,878 16:42 47.590 2,878 16:42 52.630 2,877 16:42 57.660 2,876 16:43 2.580 2,875 16:43 7.610 2,874 16:43 12.640 2,874 16:43 17.670 2,872 16:43 22.590 2,872 16:43 27.630 2,870 16:43 32.660 2,870 16:43 37.690 2,868 16:43 42.610 2,868 16:43 47.640 2,867 16:43 52.670 2,867 16:43 57.700 2,866 16:44 2.630 2,865 16:44 7.660 2,865 16:44 12.690 2,864 16:44 17.720 2,863 16:44 22.750 2,862 16:44 27.670 2,861 16:44 32.700 2,860 16:44 37.730 2,860 16:44 42.660 2,860 16:44 47.690 2,858 16:44 52.720 2,858 16:44 57.750 2,857 16:45 2.670 2,856 16:45 7.700 2,855 16:45 12.730 2,855 16:45 17.770 2,854 16:45 22.690 2,854 16:45 27.720 2,854 16:45 32.750 2,852 16:45 37.780 2,851 16:45 42.700 2,851 16:45 47.730 2,850 16:45 52.770 2,850 16:45 57.800 2,849 16:46 2.720 2,849 16:46 7.750 2,847 16:46 12.780 2,847 16:46 17.810 2,847 16:46 22.730 2,845 Page 5 of 10 Report Created: 21-Aug-13 • • 16:46:27 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:46 27.770 2,845 16:46 32.800 2,844 16:46 37.830 2,843 16:46 42.750 2,843 16:46 47.780 2,843 16:46 52.810 2,842 16:46 57.840 2,841 16:47 2.870 2,841 16:47 7.800 2,841 16:47 12.830 2,840 16:47 17.860 2,839 16:47 22.890 2,838 16:47 27,810 2,838 16:47 32.840 2,838 16:47 37.870 2,837 16:47 42.910 2,836 16:47 47.830 2,837 16:47 52.860 2,836 16:47 57.890 2,835 16:48 2.920 2,834 16:48 7.840 2,833 16:48 12.870 2,833 16:48 17.910 2,832 16:48 22.940 2,832 16:48 27.860 2,832 16:48 32.890 2,831 16:48 37.920 2,831 16:48 42.950 2,830 16:48 47.880 2,830 16:48 52.910 2,830 16:48 57.940 2,830 16:49 2.970 2,829 16:49 7.890 2,827 16:49 12.920 2,827 16:49 17.950 2,827 16:49 22.980 2,826 16:49 27.910 2,826 16:49 32.950 2,825 16:49 37.980 2,825 16:49 43.010 2,825 16:49 47.940 2,825 16:49 52.970 2,824 16:49 58.000 2,823 16:50 3.030 2,823 16:50 7.950 2,822 16:50 12.980 2,822 16:50 18.010 2,821 16:50 23.050 2,821 Page 6 of 10 Report Created: 21-Aug-13 • • • 16:50:27 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:50 27.970 2,820 16:50 33.000 2,820 16:50 38.030 2,820 16:50 43.060 2,819 16:50 47.980 2,819 16:50 53.010 2,818 16:50 58.050 2,819 16:51 3.080 2,817 16:51 8.000 2,817 16:51 13.030 2,817 16:51 18.060 2,816 16:51 23.090 2,817 16:51 28.010 2,815 16:51 33.060 2,815 16:51 38.090 2,814 16:51 43.130 2,814 16:51 48.050 2,813 16:51 53.080 2,813 16:51 58.110 2,813 16:52 3.140 2,813 16:52 8.060 2,813 16:52 13.090 2,813 16:52 18.130 2,811 16:52 23.160 2,811 16:52 28.080 2,811 16:52 33.110 2,811 16:52 38.140 2,810 16:52 43.170 2,810 16:52 48.090 2,810 16:52 53.130 2,808 16:52 58.160 2,809 16:53 3.190 2,809 16:53 8.110 2,808 16:53 13.140 2,807 16:53 18.170 2,808 16:53 23.200 2,807 16:53 28.130 2,808 16:53 33.160 2,806 16:53 38.190 2,806 16:53 43.110 2,806 16:53 48.140 2,805 16:53 53.170 2,805 16:53 58.200 2,805 16:54 3.120 2,804 16:54 8.160 2,803 16:54 13.190 2,804 16:54 18.220 2,804 16:54 23.140 2,803 Page 7 of 10 Report Created: 21-Aug-13 • • 16:54:28 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:54 28.190 2,803 16:54 33.220 2,802 16:54 38.250 2,802 16:54 43.170 2,802 16:54 48.200 2,801 16:54 53.230 2,802 16:54 58.270 2,801 16:55 3.300 2,800 16:55 8.220 2,800 16:55 13.250 2,801 16:55 18.280 2,799 16:55 23.310 2,800 16:55 28.230 2,799 16:55 33.270 2,799 16:55 38.300 2,799 16:55 43.330 2,798 16:55 48.250 2,798 16:55 53.280 2,798 16:55 58.310 2,798 16:56 3.230 2,797 16:56 8.270 2,798 16:56 13.300 2,797 16:56 18.330 2,797 16:56 23.250 2,796 16:56 28.280 2,796 16:56 33.310 2,795 16:56 38.230 2,795 16:56 43.270 2,796 16:56 48.300 2,795 16:56 53.330 2,794 16:56 58.250 2,794 16:57 3.280 2,794 16:57 8.310 2,794 16:57 13.340 2,793 16:57 18.270 2,793 16:57 23.300 2,793 16:57 28.330 2,793 16:57 33.360 2,793 16:57 38.390 2,792 16:57 43.310 2,792 16:57 48.340 2,792 16:57 53.370 2,792 16:57 58.410 2,790 16:58 3.330 2,791 16:58 8.360 2,791 16:58 13.390 2,790 16:58 18.420 2,791 16:58 23.340 2,790 Page 8 of 10 Report Created: 21-Aug-13 • • 16:58:28 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 16:58 28.380 2,790 16:58 33.410 2,790 16:58 38.440 2,789 16:58 43.360 2,789 16:58 48.390 2,789 16:58 53.420 2,788 16:58 58.450 2,789 16:59 3.380 2,788 16:59 8.410 2,788 16:59 13.440 2,788 16:59 18.470 2,787 16:59 23.390 2,788 16:59 28.440 2,788 16:59 33.470 2,786 16:59 38.500 2,787 16:59 43.420 2,787 16:59 48.450 2,786 16:59 53.480 2,785 16:59 58.510 2,785 17:00 3.440 2,785 17:00 8.470 2,785 17:00 13.500 2,785 17:00 18.530 2,785 17:00 23.560 2,784 17:00 28.480 2,785 17:00 33.510 2,784 17:00 38.550 2,784 17:00 43.580 2,784 17:00 48.500 2,784 17:00 53.530 2,783 17:00 58.560 2,783 17:01 3.590 2,783 17:01 8.510 2,783 17:01 13.550 2,783 17:01 18.580 2,782 17:01 23.610 2,782 17:01 28.530 2,782 17:01 33.560 2,782 17:01 38.590 2,781 17:01 43.630 2,781 17:01 48.550 2,781 17:01 53.580 2,782 17:01 58.610 2,781 17:02 3.640 2,781 17:02 8.560 2,781 17:02 13.590 2,780 17:02 18.620 2,780 17:02 23.660 2,780 Page 9 of 10 Report Created: 21-Aug-13 . . 17:02:28 Detailed Job Breakdown August/21/2013 OA WIRELESS Time (PSI) 17:02 28.580 2,779 17:02 33.610 2,780 17:02 38.640 2,780 17:02 43.670 2,780 17:02 48.590 2,780 17:02 53.640 2,778 17:02 58.670 2,779 17:03 3.700 2,778 17:03 8.630 2,778 17:03 13.660 2,778 17:03 18.690 2,778 17:03 23.720 2,778 17:03 28.640 2,778 17:03 33.670 2,778 17:03 38.700 2,778 17:03 43.730 2,777 17:03 48.660 2,778 17:03 53.690 2,776 17:03 58.720 2,776 17:04 3.750 2,777 17:04 7.250 2,776 Page 10 of 10 Report Created: 21-Aug-13 • • (T:pi: \'`, � ' /A-A Tr ir 0 , ' , ` , , G 9 . SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 John Egbejimba Engineering Team Leader FEB 1 e ZL ) BP Exploration (Alaska), Inc. a5V P.O. Box 196612 p,a Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y -10A Sundry Number: 312 -050 Dear Mr. Egbejimba: 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, 0, , Daniel T. Seamount, Jr. 09 t 6 Chair DATED this / day of February, 2012. Encl. „,A RECEIVED • STATE OF ALASKA a ,�l pT: ALASKA OIL AND GAS CONSERVATION COMMISSI N FEB 0 2 2012 APPLICATION FOR SUNDRY APPRO AL / 20 AAC 25.280 1 Alaska Oil 8, Gas Cons. Commicsion 1. Type of Request: �f IPL•3 1 Anchorage in Abandon L10 PIug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Cliang_p Anprnved.Pragram _. ____ _ Suspend ' ❑ Plug Perforations ❑ Perforate ❑ PuII 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 204 -250 3. Address: Pg. Se ice .� ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 2 .3.1 50- 029 - 20587 -01 -00 7. If perforating, closest approach in pool(s) opened by this operation to near st 8. Well Name and Number: property line where ownership or landownership changes: PBU Y -10A Spacing Exception Required? ❑ Yes No 9. Property Designation: 10. Field / Pool(s): ADL 028287 , 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): 11114. 8965' 11074 8967 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20” x 30" 110' 110' Surface 2709' 13 -3/8" 2709' 2709' 5380 2670 Intermediate 9464' 9 -5/8" 9464' 8850' 6870 4760 Production Liner 1285' 7" 8985' - 9507' 8396' - 8891' 8160 7020 Liner 2120' 3 -1/2" x 3- 3/16" 8989' - 11109' 8399' - 8965' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10820' - 11070' 8996' - 8968' 4 -1/2 ", 12.6# L -80 9037' Packers and SSSV Type: 9 -5/8" x 4 -1/2" Baker 'S -3' packer; 9 -5/8" x 4 -1/2" TIW Packers and SSSV 8701' / 8130'; 8843' / 8262'; 'HBBP -T' packer; 9 -5/8" x 4 -1/2" Baker packer MD (ft) and TVD (ft): 8935' / 8349' 12. Attachments: 13. Well Class after proposed work: Z, /.JY Description Summary of Proposal IS BOP Sketch ❑ Detailed Operations Program ❑ Exploratory • Development (Service 14. Estimated Date for 15. Well Status after proposed work: 6 Commencing Operations: March 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG . igi Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564 -5271 Printed Name John Egbejimba Title Engineering Team Leader y ■ PAZ Prepared By Name /Number: Signature i j Phone 564 - 5859 "�" Joe Lastufka, 564 -4091 Commission Use Only Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number Z r \ � r: ��....rr 11..�� v ❑ PIug Integrity ZBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance , -y 35 i os, /gdP /es7 Other: II , Subsequent Form Required: ' 0.... 0 APPROVED BY �7 fr l ' Approved By COMMISSIONER THE COMMISSION Date L 1 Form ", ; ��Tdda riCo � �� Sub 'tlnDupica zo - 7 2- 6./Z. O R I G N A L ��� �� 0 • 0 bP P. . ...... „, .„ ...,.,,,,,g ., i i. e : Well Name: Y -10Ai d Q 1 ° 1 7 Y ,C' Well Type: Injector s u � ✓G t.' r rOft i ? Current Status: Active �/ '�2 Request: P &A - Well Prep f /Rotary Sidetrack 1 (On ' ' ' L OEM) / O. 2/1712- , a,�, C R j, '� ' 10/15/11: MIT -IA to passed 2190 psi. G r .4 fro J. r � a ll � , p • !h 02/19/11: PPPOT -T pass, PPPOT -IC pass. C5 .cf / C l,e C .,,ac ; ii i 01/01/11: MIT -OA passed to 2000 psi. � �S r i n �,q 4,0c y�pvil 00 L,�re'l r. J G1 *ill Well � ��> �oa 1 Well History: Y -10 was originally drilled and completed as a pr ucer in July 1981. The well was le converted to a produced water injector in December 1991 and switched to seawater injection in June yy 1994. After a few years of WAG injection, it was determined that Y -10 had poor conformance due to J� injection into a fault/fracture system. The well was then sidetracked to its current location in February 2005. The well then had a RWO in August 2007 to replace the tubing so the well could inject MI. However, the well has injected a cumulative water value of 4.6 mmbbls and no MI to date. Very little well intervention was completed on this well except an IPROF that was run in July 2006. The well has been used as a pit dewatering well in 2010 and most of the wells in the pattern are currently shut in due to high water -cut or well integrity issues. This Pattern is considered uneconomic, very wet area with insufficient reserves to justify fixing any of the shut -in wells. Other Requests: None. Scope Planned Sundry Work: As currently planned, the P &A of the Y -10Ai well and the well work in preparation for the Y -10Bi rotary sidetrack will be as follows: 1. Pre -rig, perform a full -bore P &A cement job of the existing 3 -1/2" x 3- 3/16" coil production liner. Pr's • 2. Add a second P &A cement plug from TOC in step #1 to -7700' MD. • gap /254 3. Make tubing cut at 3500' MD. • • cC•(-) 4. With the drilling rig on the well, pull the 4 -1/2" tubing from 3250' MD. 5. Set and test an EZSV in the 9 -5/8" casing at -2770' MD' for a whipstock departure /sidetrack of the well from that depth. MASP 2360 psi (7.06 ppg pore pressure at TSAG) . Estrfiiated Pre -Rig Start Date: 03/15/12 Proposed Pre -rig prep work: 1. Drift tubing to 8989' MD. 2 Confirm injectivity down tubing to existing perfs (10,820' MD - 11,070' MD) for planned full - bore of the coild liner and to P&A the existing perforations. 3. Down - squeeze xx bbls of cement to P&A the coil liner f /PBTD at 11,074' MD to 8701' MD. 4. Tag TOC and pressure test the tubing to 2150 psi to confirm the integrity of the 1st P &A p � plug. — 3d sIL* ... (' 5. RU a -line and make tubing punch at 8700' MD and circ -out the TXIA to seawater. Perform FB cement job the tubing placing the TOC on both the T and IA at -7700' 6. MD (therefore, -1000' cement column on both sides of the tubing from 8700' MD) and freeze protect well on both sides of the tubing to 2200' MD. • • 7. MIT -IA to 3000 psi. 8. RU a -line and make a jet cut in the 4 -1/2" tubing at 3500' MD. 9 CMIT -TxIA to 3000 psi, MIT -OA to 2000 psi. 10. Function LDS. PPPOT -T to 5000 psi. PPPOT -IC to 3500 psi. 11. Install BPV / remove flow -line and wellhouse / level pad. Planned Rio Work: 1. MI /RU Doyon 25. 2. Pull BPV. Circulate out freeze protection and displace well to clean seawater. 3. Set a TWC and test from below to 2000 psi and above to 3500 psi for 10 minutes. 4. Nipple down tree. Nipple up BOPE. Test BOPE to 250 psi low /3500 psi high. Pull TWC. . 5. RU and pull the 4 -1/2" tubing from the pre -rig jet cut at —3500' MD. 6. PU 4" drill pipe and 9 -5/8" clean -out assembly to include a full -gage whipstock mill and clean -out well to the top of the tubing stub —3500' MD. (NOTE: With 9 -5/8" DV collar at 2574' MD, no casing scraper is suggested for the clean -out assembly.) 7. RU E -line, RIH with GR /CCL and 9 -5/8" EZSV for 47# casing. Tag tubing stub at —3500'. Set the EZSV at —2795' MD (competent sand / confirm with GR) as required to avoid cutting a casing collar while milling the window. POOH. Rig down E -line. 8. Pressure test the EZSV to 3500 psi for 30 minutes and chart. 9. PU and RIH with 9 -5/8" Baker bottom -trip anchor whipstock assembly and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Shear off the whipstock. ft` tk 10. Change -out the 9 -5/8" pack -offs if required. 11. Displace the well to 9.5 ppg LSND based milling fluid prior to 9 -5/8" casing milling operations and other path - forward 8 -1/2" drilling operations. Drilling Engineer: John Rose (907) 564 -5271 Production Engineer: Megan Kimmit (907) 564 -5851 Geologist: Mike McTeague (907) 564 -4640 S Ti442-'r" r' c Note: For the Y -11111)&A and the Y -10Bi RST, the BOP stackOetailed in the lower left portion of this schematic will be NU on a spacer s o above the existing tubing spool and the diverter as included in this schematic does t/ not apply. Note also, this BOP configuration includes 1 annular element, 2 - VBR's (2 -7/8" x 5 -1/2 ") /pipe rams and 1 blind /shear ram. i _ r 0 1 E 8 J J . " y y }-' - y I i 1 11;1! —. ... 5555 „ 11 �i 5 5 . . , . — _ - ? � -5555. 9 1 ,. Al. i i `'r'i' ' ' . , i .: ` .. . �-. ' M l 5 55 5 i I ,w-,? fy d Wg ill �. _, ,; 3 ; s, 3 l et s 1 L ,: a i 3v : is , ;.,.. i ; i ,, i — .- _ , 1 £ "; c 3 -.:. ;! i l', _... :.: . - z; : f ; #q{ s :: i s Y} i : .. ,55..31 � i" 3 5555 _ .. , i i 4.] j -! i , 1 S 1 ! -- • • .. -. .. ... _. _ _.. ... ._- 5_55_5_- - L ,....,,,,;,,, , E ki .g f.x. i' 3 3 _ • e TREE= 4' C'.1W SAFETY NOTES: WELL REQUIRES A SSSV W HEN ON . WELLHEAD= OW1 Mi. WRL ANGLE (SICETRACK"A) >78' (#1657'. A&Uo.TOR= BAKER CI Y-1 OA OVERDO:if GUIDE COVERS CUT STUB SEE TELEX FOR Jai. Lev = 85.691 DETAILS, "`" 0.010ME NIPPLES IN TBG BE RE/ = II 51.591 111 . KOP = 3300'1 2032' 4-17 HES X NP (9CF1), D=3.813 Max Angle = se a 1 09151 120' CONDUCTOR 1 144' Datum MD= 95071 I 041umTVD = 8800' SS1 .. 2574' 9-518' DV PKR 13-303' CSG, 724,1-80, 13= 12.34T H 2709' Minimum ID = 2.786" @ 9027' 1 8670" 1-14-1)2" HES X NP OCR), D = 3.813' i TOP OF 3-3/16" LINER IMI 11>M) 8701' H9-58°1 4-10 BKR S-3 FKR D= 3.87' [ [ 878T 180, 12.84, L-80 TOL .01 52 bp i. 0 =3058' I MI 8725' [--14-17 H6 XIV (9CR), D =3.813 14-1 [ 8796' 9-518' X 4-1)7 MOUE OVERSHOT 14-17 TBG S11113 (08111/07) H 8185. 8832' 1--14-17" FES X NP (SCR), D =3213 I $843' 9-503" x 4-1C" OW FP-T R<R, D=3.97' [ PM 1.1.1 I 52 tot .. I 8867 1-14-1)2' HES X NP (9CM, D =3213" I 8888' 11-14-1,7 HES X MP (OCR) 0=3.813' 14-1.7 TBG, 12 OR, L-80 NSCT, .01 f, ID =3958' H 8803. I 8910' Hg-sr X 4-1,7 UNCLE OVBISHOT 1 14-1.2" IBG S1UB ITAGGE011.033/95) I - I 890T 8915' HBAKBR IBC SEAL ASSY I 8935' H9-55" x 4-1/2 8KR PKR, ID= 4.000" [ 5 li.24 ICA I= 8979' 1_14-1a HEs X HiP, D=3.813' I I ITOP OF T LNR H 8985' r 8989' 3.70' 13KR CEPLOY SLV, D= 3.00" I i c II s' - 9 8998 3-1.7 HES X RP, D =2.817 6,44 $ I I 13-1.7 LNIFL 8.81A 1-80 ST1, .0087 Opt. 13 =2992" 1 9027' . 9012' 4-112' HES XS MP. MLLE) ID =3.8 (02) 1 I 14-1,2" lEa 1Z6X, L-80. .0152 bpf, ID = 395r ( 9038' 1111;4„e94111 moo PIPE 110 1:11 11 9027' 3-12 x 3-316" X0. D =2.786' I TOP Of CEMENT 01/1905) 1 9449' OH /* I.• • *4 9037' ELM LICUT OFF TBG TA L (02/17188) (BeIND PIPE) I 41/4 III 0 1 szor CSG. 47S. L-80, ID =8.681' [ 9464' 1.4 0•4 Olt 14).• IIIII 4* 4110 HIll )T WHIFSTOC( 101/14.435) H 9503' 10 4 • 014 1■41 11, 0114 I 7" LNIFt, 29*, 1-80, .0371 bpi. 12=6.186' 10270' ‘0 4,0 IMLLOUTWIIDOW (Y-10A) 950T- 9512 PEIFORAllONS1.11ALIARY , '.4; *'■ REF LOG' DEL ON 07121/81 romum 4 /14411.411.1 ANGLE AT TOP PERE 95" tit 10827 1.4••••• 11414444114 Slt 44,4.41 tide: Re r to Roduoton DB fa Iistalca1 pert data 1144!***4 144' *O.* 11410 SIZE SPF WIERVAL Opro'Sqz DATE • 0 111 44.111 1411,1 f 4 4 411411 2" 6 10620 - 10845 0 02)2205 11111011CtO 41 101.11,1114114 2' 6 10880 - 10905 0 02/22)95 .••4.•.•.44,11. 11074' mm 2' 6 1(8.30- 10950 0 0212245 2' 6 10970- 11000 0 02/22/05 41111111O 2' 6 11050-11070 0 02/22/05 3-3116" LW 6.26. 1-80 11109' "T ...., ...,,,,,. ; 0076 Opf, 0=2.80' ,.... -... DATE REV BY COMIENTS DATE REV BY COMMENTS PRANCE BAY MIT 07/22/81 VAN I OFIGINAL COMPLETION 0211601 1/0343 AWE) SS.SV SAFETY NOTE WELL: Y-10A 11/05105 1314 RWO FERMI' No: I 042500 02(22105 NORDC1 Cif/ SIDETRACK (Y-10A) API N): 50-029-20587-01 08114107 014 RV) 582 33, T11N R130, 1411' FM. 4205' FEL 0210/08 133/.11PJC DR.G DRAFTCORRECTIONS 01)9011 1TFOPJC SAFETY NOTE UPDATE ff Exploration (Alaska) • • ■ TREE = 4 OW SAFETY NOT: WELL REQ WIRES A 5S5VWHEN ON " WELIJ-4EA D = ChV ¥-1 °Ai P&A ML WELL ANGLE 1 "A" > 70* @ A CTUA TOR = BAKER C OV ERS HOT GUI CE COVE CUT STUB SEE TELEX FOR KB. aEv" = <55 DETAILS '"'• CHROME NIPPLES IN TBG '''' BF. ELEV = 51.5-3 II K DP = 3133 1-1 2032' 44- 1:2" liES X NIP (9CR), D = 3.61T Max A.-pg43 = 95 - 4: 13915 120" CONDUCTOR 1 144' Da Li m MD = 953 Datum Tv' D = 8830' SS mol ■ 2574' 9- 5 DV PKR I 13-16' C96,728,1-80. ID= 12.34T H v09' r --- ---- - ,...,- Minimum ID = 2.786" @ 9027' 07.4 H 8670' H4-1:2' HES ,. ',P 19C F5, D 3.813" i TOP OF 3-3/16" LINER &nil ...."7j. 8701' 9 x 4-1.2' BKR S-3 FKR 113= 3.8T /1.. .“ ng Punch al H'.. r1,12, %ID 8725' 4-1/2" HES X NP (OCR), D = 3.813' 1 TB 3, 1266 L-83 T01..0152 tot, D = 3.95r H 8787. 11 , ■ '`. N, — C r . '. ). '.-1 c; at —8701' MD --I 8796' (-19-543' X 4-112' MOLE OVERSHOT I 14-1/2' TBG s1 tA3t38intrr) H 8795' __.--- 1 I 8832 H4- 1/2" HES X NP (SCR), ID = 3.813 I I 8843' H3-5:8" k 4-1:2' 110.0111130R FKR, IC = 3. 33 [ I 1-1:2" MG. 12.11(1, L-83 NS:: -. .3152 WI. ID =3 115r (-1 8903' I X 361 I 8867' H4-1:2' HES NP (9C F8.1D = 3' I I 8 888 I-14-12" I-ES X hl. (SCR). D=3.813 I Ir 14-12 STUB ( H 8907' II - - - I 8910' H - 9-56 X 4- 1..2 UNDUE OV EFtSHOT [ ---I 0915' f__IBAKER 1BG SEAL ASSY I MI 1 I 8979' 1--14 X NIP. D = 3.61T I 8985' — I — A r 8' H_ - 3' BICR CEPLOY SW, ID= 133 I ;4 0 0 I 8998' H :- 2...-Es X NIP, D =2.81T I • 1 13-1:7 U4R.8.614. L-80 ST -0087 tbt. ID = 2 -.■ "J:.' [1 9027' 1 4 l ' I 9012' 1 - . 2' I-ES /04 NIP. MLLED D = 3.r 132:D5:051 I I BERM PPE 1 4-12 - 1BG, um, L-80..ols2 to, e = 3958' 1 9038' Ns. 0 ___ ITOP Of CENEN 9 F-1 9449' Ir L t'io a iv --- ---1 9c12.Lj_i 3 - " 2" X 3-311 D 6 X D =2.78r I 166 II, 9037' ELM :LI II OFF TBG TAL (G2i171196) (BEHIND PIPE) I 9 6 1., I 9-51f CSG,4ro, L-83, D=8.681- [ 9 4 6 4 ' V. Ir vsn m1.14,405. H 95 03 ' 1101 00,1■, Fr4 4'4' 44 0 r LP 29#.1-83, ..3'1 tisf, ID= 6.164' 10270' k . • ' MILLCX/1 W NOON (Y-19A) 1150T- 9512' \ PERFCRATION SUMP" RY \ 4 ..., REF LOG: CM ON 07121/81 reeee••••••%* "--,.. •••••■•40 . A/CLEAT FERF: 95 la 10620 14444444 • • • 44* 4 4 • "Ns ') 14 4 0 e Nob: Fidel' 4:t Rodiacion De tcr historical pert data • 6* ' 4*. I 114 44 SZE SPF KIERVAL ObrieScg DATE SkISS• 9,0 I1 OSS T 6 10820 - 10845 0 0=05 41/1.041.1 MI 4464 4 44 2' 6 13880 - 13905 0 02;22:05 4.6.6.11.4.4,41.1: ' "........%•) 11074' PBTD 2' 6 10933 - 13950 0 02122/05 2' 6 10970 - 11000 0 02:22105 111"N) 5 11353- 1137 3 0 02122/35 3-3116" LW( 626 1-80 TCI. 11109' .1 ., .01376 trot, D =2.813 N. DATE REV Er COMMENTS DATE RE BY COMMENTS PRUCHOE BAY LINT 07172 VAN I ORIGINAL COMPLETION 32 1 1 MAID A COED SS SV SAFETY NOTE WILL: Y -10A 11/9 5 DI 4 RWO FERIAT No: 02122 NORDIC 1 C TD SI DET RA CK ly -10A ) API NO: 50-029-20587-01 0191407 1314 RWO SEC 33, T11N. R13E. 1411' FNL & 205' Fia 02313 CB kIRIC t. G DRA FT CORRECTIONS 01:3911 TTRPJC SAFETY NOTE UPEA 1E BP Exploration (Alms k al • • Roby, David S (DOA) From: Rose, John G (ASRC) [John.G.Rose c@bp.com] Sent: Tuesday, February 07, 2012 2:20 PM To: Roby, David S (DOA) Subject: FW: Y -10Ai P&A Dave, Does this provide you with the information you need? - jr John G. Rose BP Staff Engineer Anchorage, AK rosel 1 @bp.com 9071564 -5271 Office 907;748-5223 Cell 907/243-8813 Home From: Peltier, Megan Sent: Tuesday, February 07, 2012 2:16 PM To: Rose, John G (ASRC) Subject: RE: Y -10Ai P&A Hi John, Here are the offset producers for the Y -10Ai. Y -19 - currently SI due to a packer leak. Last online with 98% WC and less than 40 bopd. Plan to sidetrack this summer to Y -19A Sag target. Y -31 - currently SI due to high watercut. Last online at 98% WC and Tess than 20 bopd. Y -30L1 - currently SI due to high watercut. Last online at 99% WC and Tess than 50 bopd. Y -28 - currently SI due to high watercut. Last online at 98% WC and less than 50 bopd. Y -13 - currently SI due to TxIA communication. Bad tubing, so not a patch candidate. Last online at 99% WC and Tess than 50 bopd, so not economic for RWO. These "last online" oil rates include the oil "buzz" that we tried to get by shutting in the wells for a while and then bringing online, so sustained oil rates are even lower than those quoted above. Let me know if you need any other information. Megan Peltier Petroleum Engineer New Well Delivery (907) 564 -5851 Desk 638B Megan.Peltier @bo.com 1 • • From: Rose, John G (ASRC) Sent: Monday, February 06, 2012 3:33 PM To: Peltier, Megan Subject: Y -10Ai P&A Megan, Note the attached Sundry request for the P &A of the Y -10Ai well that was sent to the AOGCC. Given the comments in the "Well History" section of the Sundry request (the last 2 sentences), The AOGCC has requested a list of the wells that this injector is supporting and their current status, i.e., producing or SI. Can you help? - jr « File: Y -10A AOGCC Sundry.ZIP » John G Rohe BP Staff Engineer Anchorage, AK rose11 @bp.com 907/564 -5271 Office 907/748 -5223 Cell 907/243 -8813 Horne 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 17, 2011 TO: Jim Regg 7 P.I. Supervisor " , e,i Z 11( �i +1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y -10A FROM: Matt Herrera PRUDHOE BAY UNIT Y -10A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT Y - 10A API Well Number: 50 029 - 20587 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111017073545 Permit Number: 204 - 250 - Inspection Date: 10/15/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y -]OA ' Type Inj -I ' TVD � 8130 - ' IA 110 f 2190 ' 2155 ' 2145 - P.T.D 2042500' TypeTest ! SPT Test psi ' 2032 - OA o 0 0 0 Interval 4YRTST _ P/F P , Tubing 0 0 0 0 Notes: Monday, October 17, 2011 Page 1 of 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 vtattiNED .JA �i 1�14� ,W, r JAN 0 3 AM f Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ^ ;� ►tiris�'. .Sion 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Y Pad ao _ ® Dear Mr. Maunder, ( 0 f\ Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y -04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y - 05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 1 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y -11 C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y - 18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y - 19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y - 22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y - 238 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y - 25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y - 27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y -28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y - 30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y - 35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y - 36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 Page 1 of 1 ~ ~ Maunder, Thornas E (DC~A) From: NSU, AQW Weli Int~grity Engin~er [NSUADWWeIIlntegrityEnginee~~,'c0' BP.comJ Se~t: Tuesday, October 0~, 24~7 3:29 PM To: Regg, Jam+es B(~OA); NSU, ADW Well Integrity Engineer Cc: Mauncl~r, Thomas ~ (D4A) ~ubj~e~#: RE: PBU Y-7 Q Sundry 3QQ-103 caneellation O,~ t.. `~,~ ~Att~chment~: Y~1QA.~lP ~, ~~~ Jim - ~1 R1~VQ uvas completed an Y-10A on 08-14-07, at wh~c~ ~imc n~w 4 1/2" tubing was eun in tl~e well, ~li~ninating th~ TxIA communicatipr~. I hav~ included ~ schematic for your reference. If this does not addres5 your cancerns, please a~ivis~. Th~nk ypu - ;~d'~k ~,. 'S~Vi~~caztj ~c~~ ~r~a Dtt~~) Well Inte~rity ~ngin~er cTffice - ~559~51 Q2 ~<~ ~p ~ 7 AS+~,hi~ ~~' 4o~~"a;w~ x-.: F f',:, f ~~. ~~~~_ pag~r - 659-51(}t}, 1154 Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, October 02, 2007 2:49 PM To: 'NSU, ADW We~l Integrity Engineer' Cc: Maunder, Thomas E (DOA) Subject: PBU Y-10 Sundry 300-103 cancellation ,~~~.lo~ 1 l~ ~~ .~ This one is complicated and confusing. I've checked our files and do not find any approval to operate PBU Y-10A with known TxIA (between the dates of 6/30/2005 and 7l18/2007). Sundry approval 300-103 (TxIA communication) should have expired with the P&A of Y-10 (P&A approved by sundry 304- 486; 12/20/2004). Well Y-10A (PTD 204-250) was drilled as a through tubing sidetrack using CT; a 3-3/16" liner was installed with the top at 8989 ft. There does not appear to have been any work done to eliminate the TxIA communication (holes at 3369 and 3744 ft MD). I found several well schematics in our files that accompanied the CT workover indicating tubing patches were considered but can't confirm if the work was ever done. It appears an application for admin approval under AIO 3 should have been requested and approved prior to commencing injection in Y-10A (6/30/3005). This might have been done verbally or with email given the circumstances. Do you have anything from the Commission in your files granting approval to inject with known TxIA communication in Y-10A? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ?'R~ ~ e~ ~ ~~H~At~ = CFil~.~ ~CTU~lT~TR ~34~1.~4~hi - ~4~. ~!~! ~. ._ .... .. ~.£~' S~: ~L~t! - 51 ~` _.,_- _ KC~Fs = _ ~~__ ~ ~~}' iNax A~~ ~ ~ ~ ~ ~fl~11~' ~~ ~turra ~ ~~ - €~ti2' ~atum NL~ = ~~ ~ _ ~A~~ ~~: tliil ~1~ ~6i1 ~Ufi ~fiU~. ~ ~~~ ~/4~~. ~ACK 7~' ~ !8#4' ~~~ ~~ **~'fix~A M, ~~~1MI~~; MA~(fAF~= PSi, M~14 tS~F~ ~ i0~0 ~4 (~f10~10~ W~~ - l1KiT~ ~ti~ ~ ~.. ~„~ ~ ~~~ ~~ ~" ~ ~~~ PVII~ ~.Y/~ Mi iN,l~fif~ 1-L,L ~~ ~ i~M~t~ ~1! 4-#1~" i.-#0 T~"~ t~ ~b 1~ (4CRj, I~t = ~V ~6~~ ~ 93-~l~" ~t:3, ~2~. 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C)N 07121 l£ij A td~~~ A? ~'~J~ t'~J~F: ~~ 19~~~~ f~t~: ~f~~ fa I~sdt~t~!~ ~ f~t ~t~t~~l ~ff d~t~ ' ~~~ ~~ ~! 4~nrl~ !`~~ , ~" ~r 19~~- 1~~A~ ~ A~'t~"~t9~ 2" ~ 1 ilt~~(1= 1~~ ~1 t3~f2~14~ 2'" ~ 10~3~ - 1{J~0 e~ i~i2'~~ ~'~ ~ ~c~7s - ~ ~ ~a ~ ~'~r~ 2" ~ t tt7~tf = ~! ~i~~ ~ 4~r~~i~ PR~bHV d ii/~ i 1$~Y~~ . . ~~ ~ ~rPYAt '_ , {~-~i~~~ ~r~a, e.~; ~-~rs ~r~; ~o~r~ ~r, ~ = ~.~ ~ ~€f - - O STATE OF ALASKA ~~~ D,7 ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~E~EIVED ~EP 0 7 2007 ~laska Oil ~ Gas Cons. Commission 1. Operations Performed: ^ Abandon ~ Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 204-250 ' 3. Address: ~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20587-01-00 " 7. KB Elevation (ft): 85 ~~, 9. Well Name and Number: ` PBU Y-10A 8. Property Designation: 10. Field / Pool(s): ADL 028287 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11114 " feet true vertical 8965 " feet Plugs (measured) None Effective depth: measured 11074 ~ feet Junk (measured) None true vertical 8967 _ feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2709' 13-3/8" 2709' 2709' 5380 2670 Intermediate 9464' 9-5/8" 9464' 8850' 6870 4760 Production Liner 1285' 7" 8985' - 9507' 8396' - 8891' 8160 7020 Liner 2120' 3-1/2" x 3-3/16" 8989' - 11109' 8399' - 8965' Perforation Depth MD (ft): 10820' - 11070' Perforation Depth TVD (ft): 8996' - 8968' 4-1/2", 12.6# L-80 9037' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 9-5/8" x 4-1/2" TIW 8701'; 8843'; 8935' 'HBBP-T' packer; 9-5/8" x 4-1l2" Baker packer ~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 307-127 Printed Name errie Hubble Title Technical Assistant • Prepared By NamelNumber: ~ S Signature Phone 564-4628 Date D O ~7 Sondra Stewman, 564-4750 -~ _ Form 10-404 Revised 04/2006 ~~o\'~a1 Subm' riginal Only ~ M ~,, ~~ ~ ~~ ~ ~ . ... .. ~ ~~~. ~<<:r I. :}~ 2D0~ -~'3 ~- Gi~~~//~~ ` ~ ~~ .._. Digital Well File ~ ~ Page 1 of 1 Well: Y-10 Well History Weil Date Summary Y-10A 7/18/2007 T/I/0= 50/100/0 Freeze protect F/L Pumped 35 bbls neat methanol down Flowline FWHP'S= 50/i00/50 Y-10A 7/18/2007 "'WELL INJECTING ON ARRIVAL'"" (rig prep) BRUSH & FLUSH TBG W/ 3.805 G-RING & BRUSH TO 8954' SLM. SET 4-1/2" XX PLUG @ 8837' SLM. (SITP = 225#, FL @ 250'.) LRS PERFORMED CMIT T X IA - PASSED, SEE LRS WSR FOR DETAILS. RAN 3.5" X 10' DUMP BAILER - DUMPED 2-BAGS (10'+) OF SLUGGITS ON TOP OF XX PLUG. "" TURN WELL OVER TO DSO - LEFT WELL SHUT IN "" Y-10A 7/18/2007 T/I/0=100/50/0 Assist S-Line W/ Brush & Flush, CMIT TxlA PASSED to 3000 psi ( RWO Prep) Pumped 140 bbls 180' Diesel while S/L brushed TBG, S/L set plug, CMIT TxIA to 3000 psi....Pressured Tubing and IAP with 21 bbls diesel , T/I lost 20/0 psi 1 st 15 mins, T/I lost 20/40 psi 2nd 15 mins for total loss of 40/40 psi in 30 mins....Bled back - 11.5 bbls of fluid FWHP's =100/50/0 Y-10A 7/19/2007 Road to location/ meet pad operator for permit *"Continued on 720-07'*' Y-10A 7/20/2007 T/I/0= 100/60/0 MIT OA PASSED to 2400 psi [RWO Expense] Pumped 3.1 bbls crude down OA to reach test pressure, OA lost 30 psi in 1st 15 min's, 20 psi in 2nd 15 min's, for a total loss of 50 psi in 30 min's- PASS FWHP's = 100/60/0 Y-10A 7/25/2007 ""' WELL SHUT-IN ON ARRIVAL, INITIAL WHP 100/0/0 PSI *""' SMAL~ 2' TUBING PUNCH, 4SPF, FROM 8784'-8786' 2 STRAND STRING SHOT FROM 8792'-8804' 3-5/8" CHEMICAL CUTTER CUT 4.5" TUBING AT 8795' OAL = 30.1', MAX OD = 3.625" ON POOH TOOL STUCK AT 850' FROM DAMAGE TO CABLE AFTER SHOOTING CHEMICAL CUTTER. CLOSED BOPS, SLACKED OFF WIRELINE AND ARE ATTEMPTING TO REPAIR CABLE. FINAL T/I/0 = ""CONTINUED ON 7/26/2007"' Y-10A 7/25/2007 Standby to assist E-Line Y-10A 7/26/2007 ""CONTINUED FROM 25-JULY-2007"' ON POOH TOOL STUCK AT 850' FROM DAMAGE TO CABLE AFTER SHOOTING CHEMICAL CUTTER. CLOSED BOPS, SLACKED OFF WIRELINE AND FOUND DAMAGED CABLE. CABLE REPAIRED AND POOH WITH NO ADDITIONAL PROBLEMS. WELL LEFT SHUT-IN FINAL T/I/0 = 0/0/0 "'JOB COMPLETE"' Y-10A 7/26/2007 Standby to assist E-line Y-10A 8/1/2007 T/IA/OA= 0/0/0 Temp= SI PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU NP bleed tool onto THA test void, 100 psi, bleed to 0 psi. Cycle LDS "Standard" all moved free with no bent pins. Flushed test void until clean returns achieved. Pressured test void to 5000 psi for 30 minute test, 4950/ 15 minutes, 4950/ 30 minutes. Bleed THA void off to 0 psi, RD test equipment re installed Alemite test cap. PPPOT-IC RU HP bleed tool onto IC test void 0 psi. Cycle LDS "Standard" all were in good condition. all moved free with no bent pins. Flushed IC void until clean returns achieved. Pressured test void to 3500 psi for 30 minute test, 3450/ 15 minutes, 3400/ 30 minutes. Bleed IC test void off to 0 psi, RD test equipment re installed Alemite test cap. Print Date: 9/6/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx ~ 9/6/2007 ~ ~ '. BP' E~CPLORATION'' Page 1'of 4-'' Operatic~n~ S~ammary Report Legal Well Name: Y -10 Common W ell Name: Y -10 Spud Date: 7/5/1981 Event Nam e: WORKO VER Start : 8/3/2007 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 8/14/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Pt~ase ' Description of Operatic~ns 8/4/2007 06:00 - 09:30 ~ 3.50 RIGD P PRE Lay hercutite and matting board on Y-pad for camp 09:30 - 11:00 1.50 RIGD P PRE Install booster rack and booster on front of rig 11:00 - 12:00 1.00 RIGD P PRE Remove doors and mouse hole from celiar. Install BOP on stand for removal from cellar 12:00 - 00:00 ; 12.00 MOB P PRE Instali rear boosters. Stand by to move rig to Y-pad: waiting to ~ lay rig mats on acees road to H-pad, and pulling well house covers on adjacent wells to Y-10. 8/5/2007 00:00 - 12:00 12.00 MOB P PRE Move rig from N-pad to H-pad (on way to Y-pad) 12:00 - 13:00 1.00 MOB P PRE Move through H-pad toward Y-pad access road. 13:00 - 19:30 6.50 MOB P PRE Wait on mats to be laid on Y-pad access road. 19:30 - 00:00 4.50 MOB P PRE Move down Y-pad access road on leap frogging. S/6/2007 00:00 - 12:00 12.00 MOB P PRE Moving rig (leap frogging) down Y-pad access road (effective i time moving forward on mats: 2.5 hrs ; time shifting mats: 9.5 hrs) 12:00 - 00:00 12.00 MOB P PRE Moving rig (leap frogging) down Y-pad access road (effective time moving forward on mats: 1 hr ; time shifting mats: 11 hrs) 8/7/2007 00:00 - 10:30 10.50 MOB P PRE Move rig (leap frogging) to end of access road and into Y-pad ' (effective time moving forward: 2.5 hrs ; time shifting mats and moving rig back to shift mats: 9.5 hrs) 10:30 - 12:00 1.50 MOB P PRE Shift mats forward and lay them on road around end of pad to access wells area. 12:00 - 17:30 5.50 MOB P PRE Cont. shifting mats forward and laying them on road around end of pad to access wells area 17:30 - 20:00 2.50 MOB P PRE Finish moving rig and position on pad near well Y-10 20:00 - 22:30 2.50 MOB P PRE Remove rear boosters. Remove front boosters and frame. Place BOP stack in cellar and MU koomey hoses. Hang cellar doors 22:30 - 00:00 1.50 MOB P PRE Slick line unit working on weil Y-6. Wait for slick line unit to finish before positioning rig on well Y-10 8/8/2007 00:00 - 02:00 I 2.00 MOB P PRE Wait until slick line finish working on well Y-6 before positioning rig on well Y-10 02:00 - 04:00 2.00 MOB P PRE Position rig on well Y-10. Shim rig. 04:00 - 05:00 1.00 RIGU P PRE Skid rig floor to driiling position 05:00 - 06:00 1.00 RIGU P PRE Spot a~d berm rock washer. RU rig floor. Rig accepted at 06:00 08-08-2007 06:00 - 06:30 0.50 CLEAN P DECOMP RU lines to tree to displace freeze protect out 06:30 - 09:00 2.50 CLEAN P DECOMP RU DSM lubricator and test to 500 psi. Pull BPV. RD lubricator 09:00 - 12:30 3.50 CLEAN P DECOMP RU hard line from tiger tank to annulus. Finish RU and test lines to 3,500 psi to circulate freeze protect out 12:30 - 16:00 3.50 CLEAN P DECOMP Circulate 120 deg. sea water down the tubing taking returns through annulus to tiger tank and displacing diesel (freeze protect). Wait 30 min. for diesel migration. Circulate additional 40 bbls sea water. Confirm well is dead. 16:00 - 17:00 1.00 WHSUR P DECOMP Install TWC. Test from below to 1,000 psi, and above to 4,000 psi. 10 min each test. Record tests on chart. 17:00 - 21:00 4.00 WHSUR P DECOMP RD lines. ND tree. Check threads on top of tubing hanger. Wait on appropriate XO and check same on tubing hanger 21:00 - 00:00 3.00 BOPSU P DECOMP NU spool, BOP stack, flow line. Remove choke hose spool. RU to test BOP 8/9/2007 00:00 - 01:00 1.00 BOPSU P DECOMP Cont. RU to test BOP 01:00 - 01:30 0.50 BOPSU P DECOMP PJSM - Started testing BOP. When pressuring annular preventer to 3,500 psi, ffange in spacer spool leaked through Printed: 8/26/2007 1:3126 PM ~ • BrP EXPLC7RATIC}f~t' Page 2 of 4 ; Operations Summar~y Rep~r# Legal Well Name: Y-10 Common Well Name: Y-10 Spud Date: 7/5/1981 Event Name: WORKOVER Start: 8/3/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/14/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task i Code ~ NPT Phase ' Description of Qperations ---~--' _-- - -- 8/9/2007 01:00 - 01:30 0.50' BOPSUR P DECOMP plug. Check plug and flange. Thread in flange is gauled. 01:30 - 03:30 2.00 BOPSU N SFAL DECOMP Change defective flange in spacer spool 03:30 - 08:00 4.50 BOPSU P DECOMP Test BOP and related equipment as per BP / AOGCC I regulations. Test to 250 psi low - 4,000 psi high (annular ; preventer to 250 psi low - 3,500 psi high) w/ 4" test joint, and I 4-1/2" test joint (on top rams). Perform koomey test. Record ! % test on chart. BOP test witnessed by W SL and Toolpusher. Jeff Jones, AOGCC Rep, waived witness of test. 08:00 - 10:00 2.00 PULL P DECOMP Install bails and elevators on top drive. Bring tubing equipment to rig floor. Locating blind flanges for mud cross (spacer) spool 10:00 - 12:00 2.00 BOPSU P DECOMP Proceed to ND BOP stack and mud cross spool (blind fianges not available). Eliminated mud cross spool from stack. Added ~ extension on choke line. NU BOP stack. 12:00 - 14:30 2.50! BOPSUF~ P DECOMP NU BOP stack. C/O choke hose spool. RU flow line 14:30 - 15:30 1.00; BOPSUR P DECOMP Test BOP breaks to 250 psi low - 4,000 psi high. Hold 5 min each. Chart test. RD 15:30 - 17:00 1.50 BOPSU P DECOMP RU DSM lubricator. Test. Pull TWC. Flow check 17:00 - 18:30 1.50 PULL P DECOMP MU spear. RIH and engage tubing hanger. Back out LDS. Pull to 280k twice. Pull free, PUW 180k. Pull hanger to rig , floor. MU top drive. 18:30 - 23:00 4.50 PULL i P DECOMP Monitor well. Circufate surface-surface through choke and gas ; ' I separator. Flow check. Pump 40 bbl Save Surf O pill and circulate surface to surface. Flow check. 23:00 - 00:00 1.00 ~ PULL P DECOMP Disengage spear. LD spear and tubing hanger. 8/10/2007 00:00 - 01:00 1.00 PULL P DECOMP RU and test casing to 1,000 psi x 10 min. Chart test. RD testing equipment 01:0~ - 11:30 10.50 PULL P DECOMP POOH and LD 4-1/2" tubing and completion equipment. Initial PUW 150k. ~ Total LD: 210 jts 4-1/2" 12.6 # L-80 NSCT tubing + 13.45' cut ~ i joint - X-nippie w/ pup joints - 2 ea. 10' pup joints - 2 ea 6' pup i joints - 1 ea 3' pup joint. ~ Cut came out clean with good edge. 11:30 - 13:00 1.50 CASE P DECOMP Clear floor. Close blind rams. RU testing equipment and test casing to 4,000 psi x 30 min. Chart test. RD testing equipment 13:00 - 13:30 0.50 RUNCO P RUNCMP Mobilize BHA tools to rig floor 13:30 - 15:30 2.00 RUNCO P RUNCMP MU BHA w/ Dress off shoe - Wash pipe extension - Dress off ( mill - Casing scraper to dress tubing stump and condition casing. 15:30 - 20:00 4.50 RUNCO RUNCMP RIH on 4" DP 1 x 1(126 jjts) 20:00 - 21:00 1.00 RUNCO RUNCMP PU and MU 9-5/8 RTTS packer. RIH and set @ 103'. Close blind rams. RU testing equipment. Test packer to 1,~00 psi x 10 min. Chart test. RD testing equipment. 21:00 - 21:30 0.50 BOPSU P RUNCMP Blow down choke line. Pull wear bushing. 21:30 - 22:30 1.00 BOPSU P RUNCMP ND BOP, choke hose and flow line. Stand BOP back 22:30 - 00:00 1.50 WHSUR P RUNCMP ND tubing spool. Clean and check hanger neck and ring grooves. 8/11/2007 00:00 - 03:00 3.00 WHSUR P RUNCMP Install gaskets in hanger neck. Install new ring gasket in ring groove. NU tubing spool. Run wear bushing, check profile and pull. Test tubing spool flange and packoff to 5,000 psi x 15 min. 03:00 - 06:30 3.50 BOPSU P RUNCMP NU BOP, choke hose and flow line. Add extension on choke line because new tubing spool is shorter than old one. 06:30 - 08:30 2.00 ~ BOPSU P RUNCMP Testing BOP breaks to 250 psi low - 4,000 psi high x 5 min Printed: 8/26/2007 1:31:26 PM • ~ BP EXPLORATIQN I Page 3' of 4' C?peratior~s Summary Repc~rt Legal Well Name: Y-10 Common Well Name: Y-10 Spud Date: 7/5/1981 Event Name: WORKOVER Start: 8/3/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/14/2007 Rig Name: DOYON 14 Rig Number: ' Date From - To Hours Task Code NPT Phase Description af Operations 8/11/2007 06:30 - 08:30 2.00 ~ BOPSIJ P RUNCMP -- - -- each. Chart tests. RD testing equipment 08:30 - 09:00 0.50 ~ BOPSU P ~ RUNCMP Pull test plug. Install wear bushing 09:00 - 10:30 1.50 RUNCO P ; RUNCMP Retrieve RTTS packer - LD same 10:30 - 12:00 1.50 RUNCO P ~ RUNCMP Cont RIH w/ dress BHA on 4" DP 1 x 1 to 6,075' 12:00 - 13:00 1.00 RUNCO P RUNCMP Service rig 13:00 - 13:30 0.50 RUNCO RREP RUNCMP C/O hose on pipe skate 13:30 - 16:00 2.50 RUNCO P RUNCMP Cont. RIH w/ dress BHA on 4" DP 1 x 1. Tag Q 8,787' 16:00 - 17:00 1.00 RUNCO P RUNCMP Dress tubing stump from 8,787' to 8,795' 17:00 - 18:30 1.50 RUNCO RUNCMP Pump 30 bbl hi-vis sweep and circulate until clean. 18:30 - 22:00 3.50 RUNCO P RUNCMP LD top single. Flow check. POOH and stand back DP from 8,778' to 141' 22:00 - 23:00 1.00 RUNCO P RUNCMP Stand back DCs. Break and LD BHA. 23:00 - 00:00 1.00 RUNCO P RUNCMP Ciear rig floor. Mobilize Baker tools to rig floor. 8/12/2007 00:00 - 02:00 2.00 RUNCO P RUNCMP PU and MU BHA w/ reverse circulation junk basket and 2-7/8" i PAC DP 02:00 - 06:30 4.50 RUNCO P RUNCMP RIH on 4" DP to 8,780' 06:30 - 07:30 1.00 RUNCO P RUNCMP Break circulation. Wash down to top of stump @ 8,787'. Insert ~ reverse circulation junk basket into stump and wash down w/ 2-7/8" PAC DP into tubing to top of XX plug @ 8,867' 07:30 - 09:00 1.50 RUNCO P RUNCMP Pump sweep and circulate surface - surface until hole clean. 09:00 - 17:00 8.00 RUNCO P RUNCMP POOH and LD 4" DP 17:00 - 19:00 2.00 RUNCO P RUNCMP C/O elevators. LD BHA w/ 2-7/8" PAC DP. 19:00 - 20:00 1.00 RUNCO P RUNCMP LD Baker tools. Pull wear ring 20:00 - 21:00 1.00 RUNCO P RUNCMP C/O bales. RU single joint compensator. RU tubing tong and i ~ torque turn unit 21:00 - 22:00 1.00 RUNCO P i RUNCMP MU and RIH tai! pipe assy: Unique Overshot - 4-1/2" pup jt - 4-1/2" 12.6# L-80 TC II tubing jt. - 4-1/2" pup jt - X-nipple w/ RHC sleeve - 2x 4-1/2" pup jt - Baker "S-3" packer - 3x 4-1/2" pup jt - X-nippie - 4-1/2" pup jt. Baker lock all connections below packer. Torque turn all connections 22:00 - 00:00 2.00 RUNCO P RUNCMP RIH 4-1/2" 12.6# L-80 TC II tubing 1 x 1 w/ tail pipe assy. to ~ 1,400'. Torque turn all connections 8/13/2007 00:00 - 10:00 10.00 RUNCO P ~ RUNCMP Cont. RIH 4-1/2" 12.6# L-80 TC II tubing w/ tail pipe assy. to +/- 8,787'. Torque turn all connections. 10:00 - 12:00 2.00 RUNCO P RUNCMP Space out completion over tubing stump 12:00 - 13:00 1.00 RUNCO P RUNCMP MU hanger. Land completion on hanger. RILDS. Bottom of Unique overshot Q 8,796'. Baker "S-3" packer @ 8,700'. 13:00 - 13:30 0.50 RUNCO P RUNCMP RU lines to reverse circulate down IA taking returns through tubing. 13:30 - 18:30 5.00 RUNCO P RUNCMP Reverse circulate 370 bbis of clean seawater followed by 380 bbls of corrosion inhibited seawater Q 3 BPM - 290 psi 18:30 - 19:30 1.00 RUNCO P RUNCMP RU Hot Oil. Pump 160 bbls ot diesel down IA @ 3 BPM - 350 psi 19:30 - 20:30 1.00 RUNCO RUNCMP Jumped IA to tubing and U-tube diesel 20:30 - 21:00 0.50 RUNCO P RUNCMP Drop rod-and-ball down tubing to set Baker "S-3" packer 21:00 - 00:00 3.00 RUNCO P RUNCMP Pressure up tubing to 4,000 psi. Hold pressure x 30 min and ~ test tubing. Pressure dropped 100 psi in 20 min and stabilized. Tubing test OK. Bleed pressure in tubing to 1,500 psi and pressure up IA to 4,000 psi. Hold pressure x 30 min and test IA. Pressure dropped 50 psi in first 10 min and stabilized. IA test OK. Bleed off IA. Bleed off t~bing. Chart all tests. Use Hot Oil unit to pressure in all tests. 8/14/2007 00:00 - 01:00 1.00 RUNCO P RUNCMP RD test lines. LD landing joint Printed: 8/262007 1:31:26 PM • • BP EXPLORATION Page 4 ot 4 C)perat~c~ns Summary Report Legal Well Name: Y-10 Common Well Name: Y-10 Spud Date: 7/5/1981 Event Name: WORKOVER Start: 8/3/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/14/2007 Rig Name: DOYON 14 Rig Number: Date From - 7o Haurs Task Code NPT Phase i Descripfion Qf Operations 8/14/2007 01:00 - 02:00 1.00 BOPSU P POST Install TWC. Test to 1,000 psi from above x 10 min. Chart test. 02:00 - 03:30 1.50 BOPSU P POST ND BOP, flow line, choke hose, lines 03:30 - 06:00 2.50 WHSUR P POST NU adapter flange and X-mas tree. Test adapter flange to 5,000 psi x 30 min as per Cameron rep. - RU test equip - Test tree to 5000 psi f/ 5 min. - Record on chart 06:00 - 07:00 1.00 WHSUR P POST Install DSM lubricator on tree - Test lubricator to 500 psi - Pull TWC - Install BPV 07:00 - 08:00 1.00 WHSUR P POST Inspect and secure well - Release rig @ 08:00 hrs. I I ~ I ( Printed: 8/26/2007 1:31:26 PM Y ~ R Jl1LL' ^l~.u l..riNY WELLHEAC~ GRAY ACTL~T~3R ~s. ~L~v ~~.. ~ AXELS£~N _ _.. _.. s~ ~~: B~. ~~V = FCf~P= _.__ ~ 51 59' _~_.~~_33t~tI` M&x Angle -= [}aturn ~'#~ .- _ 98 ~ #~i915' ~ ,__ _ 95C3~' c~~u~TVC~- s$a~~ s~, ~ ~d~~L1~ t~~~. YK ~A RJ R ti?1A~R~ W AAY 5J\wl MliJ! 4I A VLT~ 3EE T FtJ~R [?ETA#LS. S!C'!t? RACK 7Q° ~ 8654" ~ ~~ Tx~A MAM. tJP~2AtING L.~~+1lTS. 34TAX IAP = 2t1110 ~ Ps[, ~n~x oAA = ~~ao ~s~ {~t~ro~~~rs w,atv~ - t~~: ~~~~ ~~ ~ ; ,,~ ~,~ ~~, ~w~ ~ ~ P1M iJNLYlt+tO MI INJC-GT'IOIU ALLt?WBY** "'Ct~20ME t+I1P"PLES IN d-9P2" L-S{1 TBG'°" ~{a-~~~°~ ~ES x,u~~{sc~t}, ~r~r ~.a~~.. ' I- s-~fs° crv ~c~ 1~-~r~~~ c~~r 7~#: L-e~, ~~ =~~.s~~~ I--~! 27t~8' 8670` ~~-ar~•°~~sxr~t~4~ct~:~=~~~t~" 41f2" "f~9= 12.6#, L-St3 TC-It, f7.152 Frpt, IC? = 3.958'" 8670~ $7 9-Si8" x 41J2'" Baker FiKR ~Ci" ID= 3 , . 4-i f2"• HES X 1~P (9CR~, IC~ = 3.813," 7q ~~V ERSHC3T GUI[~E, 9~d8`° x 41 t2" __ $$32" _ d-112"' HES X ~IIP {9iGI~. it~ = ~.813"' 8843' '~-5~$" x 4-~ f2" `i'Md HB~P-T PICR, IR = 3:9f7" $8~~'" 4-1I2'° HE~ X NIP (9r~Rj~ tC? = 3.813" $$$8' 4-1 J'2° HES X NiF' {J~~` . ID = 3.813" $'~Q7' _ 01lEF25N{~7 C~L1ILs~ ~(3~2 CIST STUB> It7 = 4.55,• ~It11t~11.t1T1 IC~ = ~.T~~'P ~ ~{I~T& = $9'15' BAKER TBG SEAI. AS~Y T~}~ ~F a~-.~`~"~ ~*M ~.,.~~ ~~ $~~~J' g_5/8° x -0mi{2" $}CR PKR, ~-` 4.~J~ ~'~'~~' 49f2" HES X tUIF, i~ ~ 3.Si3" TOP C?F 7°' I.NR 8~$~' li $J$~' 3.7Q° SK£2 L7EPLC?Y SL.1f, t[7 = 3.OQ" a'~.~'~~~ 3-! iZ" HES X RlIP, 1[.3 =~.E31 ~,• ~'~~" ~4-1 t2" H~S XP3 NiP~', M~.LEL? IC7 =~.S" (8~k1iNN€~ Pt~'~} 3-i12" LhIF~', 8.Si#, L-8U STt.., .Q~87 bpf, I[~ = 2.992" 9l1~~# ~i327'' 3-1 /2°' X 3-3116" XC7, H} = 2.$tl" 4-112'° TB~, 1~.~, L-$D, .~1'152 bpf, ICi = 3.9~8" ~~(}3$" ~}~~~ ~~J[ --- CUT C~~F TBG T#tl~ (Q2t171$8} ( RtG PIFsE} 9-5i$.' CSG: ~7#, L-8Q, ~E7 = 8,68'~" 9,~~.' 9" ~TU~' C7~ GF~1t~.t~l7 (i71115fU~) ~~-~t~°~ x ~~ vv~iG~s-rac~ go~r~aro~~ i ~~na ~~~. ~c~enrr .~337f bp(, t~ = 6. t 84" t~RFflRATl~N SCJ RY :[~~# &{.~L.:?~.L.t~"~ .iE'~d€71 ~~;rSl ~tVIJGGtt 1 #~V~f E=d1~. 35 ~~ ILiU~V~. Nc~t~: Reter tca Frtsduction DB fcsr historica! perf data 5}~~ 5€~ INT~f~VAL Opn.rSq2 DAT€ ~ 2" ~~ ItlEi2CI - 14845 U Q2122/fl~ 2" 6 1 Q`~$0 - t 0~Q5 (~ 02f220f1~ z" s ~ ~~~~ - i o~5~ ~a ~2rz2o~s 2•• 6 1 tt97t1 - 11 QCl4 f3 LD2l22105 ~" 6 110~ - 11i}7[7 C3 (321~21{l z MILLt?4J31lkttt+~t'3W (Y-illAj ' rt~~ ~ sso~ ~TD 14 {374' 3-3r~s°' ~ra~, s.2~. ~-s~ rc~~ .~a~a~ a~r, ir~ = 2.~r~., 91 t9?t22I8i tft)FF p~C~i#1dAL GOMPLETI€~PI 41131#Q6 ~R~iTLF{ aRLG I7RElFTCf1F2REC71t?RIS "I1d€~5t95 f~7li+U {33t1~i#06' ~LIPAG WAIVERSR~ETY htL?TE~~131C79J06) U2J231fl5 Nfl#~t3[{G1 CTI? 51[~fF!'PtCK (Y-1~A~ t35105tfl~i JRP(PJC 5ET F'X FLUG ~ S~t38' t15P09ft35 ~fHF/PJC S~ UC'~RILGUVER PATGNES t19129li~6 JC[V~PA PCli~LED P~ f*~~ ~ 8888' 08t28i~~ lTLti Pt~TG}-IES FULLEQIPLUG SE7' 4~ti3107 [)14 RM#~ f o~~a~~~s ~ rr~~ [ ~x ~u~ PRt1LfHC?E B,RY Ul~i£f WELL: Y-1 UA P!ERMPT tV~: 2ttJ~++#25~~ API A1a: 5t1-~3~9-2t5,~"ik37-t11 S~C 33, T'f 1 N, R13E ~3P Explora~tion (Ataska) RE: 04-11A (PTD #1931580), 13-22 (PTD #1820770), 13-32A (PTD #2Q12350) MIT Fo... Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWe111ntegrityEngineer@BP.com] Sent: Tuesday, September 04, 2007 6:22 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Well integrity Engineer; NSU, ADW WI Tech Subject: RE: Y-10A {204-250) 404 Cancel Sundry Hi Tom, Thank you for your note. We've prepared a new sundry cancellation and are sending it your way. Thank you, Anna ~u6e, ~.~'. ~. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Maunder, Thomas E {DOA) [mailto:tom.maunder@alaska.govJ Sent: Monday, August 27, 2007 1:01 PM To: NSU, ADW Well Integrity Engineer Subject: Y-10A (204-25Q) 404 Cancel Sundry Andrea and Anna, A 404 to cancel sundry 300-103 was recently submitted. The well that presently exists is Y-10A, however the sundry was issued for Y-10 (181-054). Would you all please submit a revised 404 with the proper well name and permit? It may be appropriate to include a note on the form, maybe in lower right portion of Block 11 or in Block 12 noting that Y-10 was redrilled as Y-10A. Call or message with any questions. Tom Maunder, PE AOGCC 10/3/2007 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 17, 2007 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. 7t" Ave. Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well Y-10A (PTD #2042500) Application for Cancellation of Sundry #300-103 Dear Mr. Norman: ~~~~I~~~ ~II~G22200~ Alaska Oit $~ ~,~,~ ~an~ C~mission ~~ - -- Anchorag~ This request is to cancel Sundry #300-103 for Prudhoe Bay Unit well Y-10A (PTD #2042500). The Sundry, originally issued 04/20/00, was for continued water injection with tubing by inner annulus communication. The well has been worked over with new tubing installed, therefore the Application for Sundry Cancellation form 10-404 to cancel Sundry #300-103 is attached. If you require any additional information, please contact Anna Dube or myself at (907) 659-5102. Sincerely, ~ Andrea Hughes Well Integrity Coordinator ~~.~E1VtU # , ~ ~~ • # STATE OF ALASKA ~ ~lU~i ~ ~ ~UO~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~ EPORT OF SUNDRY WELL OPERATIC~~~~~~ & Gas Cans. Carnmissian Anchara~e 1. Operations Performed: Abandon~ Repair Well~ Plug Perforations^ Stimulate ^ Other^X 10-403 Canc Alter Casing~ Pull Tubing~ Perforate New Pool~ Waiver~ Time Extension~ Change Approved Program~ Op ation Shutdown~ Perforate ~ Re-enter Suspended Well~ 2. Operator BP Exploration (Alaska), I Name: 4. Current Well Class: Development ~ Exploratory~ 5. Permit to Drill Number: ii' 3. Address: P.O. Box 196612 6: PI Number Anchorage, Ak 99519-6612 Stratigraphic~ Service~X 50-029-20587-01-00 7. KB Elevation (ft): 9. Well Name and Number: 85.70 ~f ~~ 8. Property Designation: 10. Field/Pool(s): ADL-028287 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11114 feet Plugs (measured) None true vertical 8965.0 feet Effective Depth measured 11074 feet Junk (measured) None truevertical 8967.0 ~ feet ~~.~-~~~-~--~~ Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 29 - 139 29.0 - 139.0 1490 470 SURFACE 2680 13-3/8" 72# L-80 28 - 2708 28.0 - 2708.0 5380 2670 PRODUCTION 9437 9-5/8" 47# L-80 7 - 9464 27.0 - 8850.0 6870 4760 LINER 518 7" 29# L-80 8 5- 9503 8396.0 - 8887.0 8160 7020 LINER 38 3-1/2" 8.81# L-80 89 - 9027 8399.0 - 8435.0 10530 10160 LINER 2082 3-3/16" 6.2# L-80 9027 - 11109 8435.0 - 8965.0 8520 7660 Perforation depth: Measured depth: 10820-10845, 10880-10905, 10930-10950, 10970-11000, 1 50-11070 True vertical depth: 8996-8995, 8991-8987, 8984-8981, 8979-8976, 8970-8968 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 ~ 24 - 8795 4-1/2" 12.6# L-80 @ 8795 9038 `~v ~r ~Oa - \~3 w ~S \sSv~J Packers & SSSV (type & measured depth): 9-5/8" Baker S-3 Packer C~ 8706 r ~`~ I 1~~~~ i~~~ +, ~~~ '~ ~ y> " TIW HBBP-T Packer ~ 8843 9-5/8 9-5/8" Baker Packer C~ 8935 4-1/2" X Nipple C~ 2033 ~j1 ~~~ ~/~~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Re resentative Dail Avera e Production or In Data oil-Bbl Gas-Mcf water-Bbl sing Pressu ubing Pressure Prior to well operation: --- --- -~ °- "' Subsequent to operation: --- --- --- --- '- 14. Attachments: 15. Well Class after proposed work: Exploratory~ Develop nt~ Service^X Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X Oil~ Gas~ WAG ^X GINJ WINJ~ WDSPL~ Prepared by DeWayne Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Su ndry Number or N if C.O. Exempt: H t A D / A d C t b hes 300-103 nna e n rea on ac u Printed Name Anna ube drea ghes Title Well Integrity Coordinator Signature Phone 659-5102 Date 8/17/07 Forri~ 1p-404 Hevlsed 4/"LUU4 1 1 L.! f~ I~\L ~` ~ Vt~l Y ~ Sundry Cancellation. • Maund~r, Thor~rtas E (QQA~ From: Prebis, Gary B(SAIC) (Gary.Prebie c(„~'~bp.com] Sent: Tuesday, A~gust 14, 2QQ7 4:05 PM To: Maunder, Thomas E (D4A) Subject: RE: Sundry Canceflation. ~t~~n~c~ ~r~r~ ~ ~~ • ~;:~~ ' ~~ ~ From: Maunder, Thomas E (DOA) [mailt~:tom.maunderCajalaska.gov] Senfi: Tuesday. ~ugust 14, ZOQ7 3:29 PM To: Preb~e, Gary B (SA~C~ Subject: RE: Sundry Canceilation. Page 1 of 2 ~~, ~t a~ ~r~~~~ ~~t ~ ~~~t ~ ~~ ~ i~~~ ~a~ ~~a~e~~.. 4~ ~ ~ ~ ~ r~ ~~~~ ~~ n ~~~~ w~~~ ~`-1 t~ vvv~~ pfu~~~d ~~d ~Y-'f Ci~ dr~i~~d. Nt~t ~urpr~~ing it f~l! ~~r~ugh ~h~ c~~~ic~. `~~rn~ M~ur~d~~; ~~ ~ ~~ From: Preble, Gary B (SAIC) [mailto:Gary.PrebleCa~bp.com) Sent~ Tuesday, August 14, 20Q7 3:23 RM TQ: Maunder, TE~omas E (DOA) Subject: RE: Sundry Cancellation. Well Y-10 is c~rrenfily under gaing a ri~ wnrkover tcz repair damaged tubing and retu:rr~ the wel{ tQ suitable op~erating condition. ~r~r~ ~'~~L~/~ ~rom: Ma~nder, Tho~rtas E (Dt}A) [mailto:tom.maunc~r@alaska.govj Sen~; Tuesday, August 1~4, 2407 ~:18 PMI To: Preble, Gary F3 (SAIC) Subject: RE: Surtr.lry C;anceltatieron. ~~~, Y'~1 t~ w~~ ~~~~d in ~~riy ~~~~ ~r~d ~5~ ~id~tr~~k ~~1 ~~ ~~pi~~~ ~/z2/~~, ~~~r°din~ t~ ~~r rrt~~tf~~y r~~1't~ng ~a~~; ~~_~~~ i~ ~~it~ ~~~ ~~ ~~~~ t~ ~~~fl,~, ~11~~ , ~ ` ~a ~p~i ~ ~~ ~~ ~~r~~~ t ~~ ~ ~~ ~ sil~i2oo~ ~r~~~~ c~co Sundry Cancellation. ~ ~ ~e~~ From: Pr~ble, Gary B (SAIC) [mailto:Gary.Prebl~~bp.com] Sent: Tuesd~y, August 14, 2Qt}7 2; ~8 PM Tu: Maunder, Thc~rnas E (fX?A) Subject: RE: Sundry Canceliation. ~'-~~ 9~~~~ ~d`/"'~/ P'f"itb~'~~ From: Maunder, Thomas E (DOA) [mailta:torr~.maunder@alaska.gov] Sen#: Tuesday, Aug~ast 14, 2407 2;57 PM To; Preble, Gary B (SAIC) !5t~ttjeck: RE: Sundry Gancettatian. ~~~r, VVt~at w~~ th~ w~ll ~~r~~ ~nd p~~mit ~ ~~~ From: Preble, Gary B (SAIC) [mailto:Gary.PrebleC~bp.com] S~nt: Tuesday, August 14, 2Q07 1:25 PM To: Niaun~ler, Tttomas E (QQA) Sub3ect: 5undry Cancellation. Hi Tom, Page 2 of 2 Do i need tp submit a 10-AQ4 to cancel an approved Sundry (300-103)? it was f4r a Variance back in 2QqQ, 'Your help is greatly appreciated. t~CT/'~/ /~l~'~~ Petro%um Dato Manog~ment Engineer S~#lG' 907-5b4-4A44 p~b/~,gb~bp. ~cr~tt 8/12/2~Q9 ~ • ~.•~, ... ~. , MICRQFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PACE F:\LaserFiche~CvrPgs_Inserts\Microfilm Marker.c~c MEMORANDUM To: Jim Regg r"7 P.I. Supervisor ~~l/ ~/~~~'1~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 31, 2007 SUBJECT: Mechanical Integrity'I'ests BP IXPI.ORAT70N (ALASKA) INC Y-l0A PRUDHOE BAY UNIT Y-l0A Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~_ Comm Well Name• PRUDHOE BAY UNIT Y-l0A API Well Number: 50-029-20587-0 i-00 Inspector Name: Bob Noble Insp Num: mitRCN071029064G51 Permit Number: 2o4-2so-o Inspection Date: 1oi25i20o7 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ,. __ __ Well I _..YaoA ,Type Inj. w ;_T~ ar3o / IA Aso neo ~ zzzo zzto P.T. zoa2soo TypeTest ; sPT ~ Test psi zzeo OA szo szo zo szo Interval IN[TAL p/I,~ P ~ Tubing ~za no szo ,, r-o Notes: ~~d~~ ~~~ ~` ~~~~ Wednesday, October 31, 2007 Page I of 1 Y-IOA (PTD #2042500) Internal wa, Cancellation Regg, James B (DOA) e Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Thursday, August 16, 20072:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, GC1 OTL; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: ysu, ADW Well Integrity Engineer; Subekti, Herry; NSU, ADW WI Tech Subject: Y-10A (PTD #2042500) Internal Waiver Cancellation ðl\blo7 ?-t1 ~ D All, An internal waiver was issued for TxlA communication on well Y-10A (PTD #2042500) on 03/09/06. The well received new tubing during a rig workover completed on 08/14/07, thus restoring tubing integrity. The well is reclassified as Operable. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. A 10-404 will be sent to the AOGCC to cancel Sundry #300-103 issued on 04/20/00. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED AUG 272007 8/16/2007 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 17, 2007 RE: MWD Formation Evaluation Logs: Y-lOA, AK-MW-3530513 V-lOA: Digital Log Images: 50-029-20587-01 SCANNED APR 232007 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Signed: ,'\Jaska Oil & Gas Coos. Commissic~ APR 1 7 2007 Date: Ancr:<jrage ê U~ dtf-I-CiS-Ó I£;Ot3 e e V~VŒ (ffi~ ~~~~~!Æ / AI4ASIiA. OIL AND GAS / CONSERVATION COMMISSION / SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 dv()~-JSD Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-10A Sundry Number: 307 -127 Dear Mr. Reem: SCANNED APR 1 7 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this J 2.cIay of April, 2007 Encl. a .. 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program ~ Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5, Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 204-250 ./ 3. Address: o Stratigraphic 181 Service 6. API Number: ../ P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20587 -01-00 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 Y-10A Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028287 85.70' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUMMARY ....... >. .< ,«« ... Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 11114 8965 11074 8967 None None Casina Lenath Size MD TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Surface 2709' 13-3/8" 2709' 2709' 5380 2670 Intermediate 9464' 9-518" 9464' 8850' 6870 4760 Production Liner 1285' 7" 8985' - 9507' 8396' - 8891' 8160 7020 Liner 2120' 3-1/2" x 3-3/16" 8989' - 11109' 8399' - 8965' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10820' - 11070' 8996' - 8968' 4-1/2",12.6# L-80 9037' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP-T' packer I Packers and SSSV MD (ft): 8843' 9-5/8" x 4-1/2" Baker packer 8935' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencinç¡ ODerations: June 1 , 2007 DOH o Gas o Plugged o Abandoned 17. Verbal Approval: Date: 181 WAG DGINJ oWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Namgav;d R_ Title Drilling Engineer . f-C" J( 4,ø-l. t¡ i:¡JD~ Prepared By Name/Number: Signature J I Phone 564-5743 Date Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: ../)'{)"1-- I&. í Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~echanicallntegrity Test o Location Clearance Other: ':> 5Cù ~~\ \Sa V ~~. Subsequent FO~ u;re);' 41;) Approved Bv: ) 7 ~ APPROVED BY 4/ J2-/7 COMMISSIONER THE COMMISSION Date Form 10-403 ReVISed 06Jt"006 y Subn#lt In Du~licàte . STATEOFA~J-I¡-cr1 . , RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION ~ (\ ~PR ] 1 /ùO! APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas COI1$. Cúmmission 20 MC 25 280 OR\GINAL RBDMS BFl APR 1 3 2007 e e Y-10Ai Rig Workover Reason for RWO: There are multiple leaks in the 4 1/2" tubing. Scope of Work: Pull 4 1/2" L-80 completion, run 4-W' L-80 Premium threaded completion. MASP: 2830 psi Well Type: Ivishak WAG Injector Estimated Start Date: June 1, 2007 Pre-ria prep work: S 1 Drift to 8950' for 4 W' XX plug. Set TTP (non-equalizing XX plug) in X-Nipple at 8867' md. F 2 CMIT to 3000 psi. E 3 Punch holes in tubing at -8800' md (near the top of the first full joint of tubing above the packer). Chemical cut the 4-1/2" L-80 tubing at -8807' MD in the middle of the first full joint above the production packer. F 4 Circulate well with seawater and FP w/ diesel thru the cut. 0 5 Bleed OA, IA & T to zero psi. PPPOT - T & IC. Function all LDS and repair / replace as necessary. 0 6 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the tubing punch holes. 2. Pull and LD 4 1/2" tubing string. 3. Run new 4-1/2" L-80 Premium-threaded tubing completion with stacker-packer set -8760' md. 4. Displace the IA to packer fluid and freeze protection. 5. Test tubing and IA to 4000 psi. 6. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = DatumTVO= 4"CrN GRAY AXELSON 85.69' 51.59' 3300' 98 @ 10915' 9502' 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" H 2708' Minimum ID = 2.786" @ 9027' TOP OF 3-3/16" LINER 1 TOP OF 7" LNR I 8985' 13-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, 10 = 2.992" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 19-5/8" CSG, 47#, L-80, 10 = 8.681" 14-1/2" X 7" WHIPSTOCK (01/14/05) I 9503' 1 MARKER JOINT 1 1 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" ÆRFORA TION SUMMARY REF LOG: CBL ON 07/21/81 ANGLEATTOPPERF: 95 @ 10820' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2" 6 10820 - 10845 0 02/22/05 2" 6 10880 - 10905 0 02122/05 2" 6 10930 - 10950 0 02122/05 2" 6 10970 - 11000 0 02/22/05 2" 6 11050 - 11070 0 02/22/05 OA TE REV BY COMMENTS 07/22/81 HOFF ORIGINAL COMPLETION 11/05/95 RWO 02/23/05 NORDIC1 CTD SIDETRACK (Y-1 OA) 05/09/05 NBF/PJC SET UPPER/LOWER PA TCHES 08/28/05 ITLH PATCHES PULLED/PLUG SET 09/03/05 /TLH PX PLUG PULLED Y -1 OA SAF OTES: OVERSHOT GUIDE COVERS CUT STUB. SEE TB.EX FOR DETAILS. SIDETRACK 70· @ 9654' ***TxIA COM M . OPERATING LlM ITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (03109106 WAIVER) - NOTE: PWI ONL YINO MIINJECTION ALLOWED**" -CHROM E NIPPLES IN 4-112" L-80 TBG- 4-1/2" HES X NIP (9CR), 10 = 3.813" 9-5/8" OV PKR 8832' 8843' 8867' 8888' 14-1/2" HESX NIP (9CR), 10= 3.813" 1 19-5/8" x 4-1/2" TI\/II HBBP- T PKR, 10 = 3.90" 14-1/2" HES X NIP (9CR), 10 = 3.813" I 4-1/2"HESXNIP(9CR),10=3.813" 1 OVERSHOT GUIDE FOR CUT STUB, 10 = 4.55" I BAKER TBG SEAL ASSY I 8935' 9-5/8" x 4-1/2" BKR PKR, 10 = 4.000" I 8979' 4·1/2" HES X NIP, 10 = 3.813" I 8989' 3.70" BKROEPLOY SLV, 10-3.00" I 8998' 3-112" HES X NIP, 10=2.813" 1 9012' 4-1/2" HES XN NIP, MILLED 10 = 3.8" (BEHIND PIPE) 9027' 13-1/2" X 3-3116" XO, 10 = 2.80" 9037' ELM J CUT OFF TBG TAIL (02/17/88) (BEHIND PIPE) 9449' TOP OF CEMENT (01/19/05) MILLOUT WINDOW (Y-10A) TOP @ 9503' PBTD I 13-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, 10 = 2.80" 1 OA TE REV BY COMMENTS 01/31/06 ORFITLH ORLG DRAFT CORRECTIONS 03/16/06 EZLlPAG WAIVER SAFETY NOTE (03/09/06) 09/06/06 JRP/PJC SET PX A..UG @ 8888' 09/29/06 JCMlPAG PULLED PX PLUG @ 8888' PRUDHOE BAY UNIT WB.L: Y-10A ÆRMIT No: "2042500 API No: 50-029-20587-01 SEC 33, T11 N, R13E BP Exploration (Alaska) TREE = WELLHEAD = ACTIJA TOR = KB. 8.E.V = BF. 8.E.V = KOP= Max Angle = Datum MJ = Datum lVD = 4"CJN GRAY AX8.SON 85.69' 51.59' 3:D)' :J8 @ 10915' 950Z 8800' SS Y -1 OA Proposed SAF ES: OVERSHOT GUDE COVERS CUT STUB. SEETB.EX FOR DETAILS. SIDETRACK 70" 09854' -rxlA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX CAP = 1000 PSI (03109106 WAIV~ . NOTE: PWI ONL YINO MIINJECTION ALLOWED""* """'CHADMENlPPLES IN 4-112" L-80 TaG- TOP OF 7" LNR 8985' 14-112" HES X NIP (9CR), ID = 3.813'; 19-518" x 4-112" Baker PKR, ID = 3.90" 14-112" HESXNIP(9CR), ID=3.813" I OVERSHOT GUIDE, 9 518" x 4 112" 4-1/2" HES X NIP (9CR), 10= 3.813" 9-518" x 4-112" TW HBBP- T PKR, 10 - 3.90" 4-1/2" HES X NIP (9CR) , ID = 3.813" 4-1/2" HES X NIP (9CR) , ID = 3.813" 113-3/8" CSG, 7211, L-80, ID= 12.347" H 2708' 4-112"1bg, 12.6#, L-BO TC-H, 0.152 bpf, ID = 3.958" r Minimum ID = 2.786" @ 9027' TOP OF 3·3/16" LINER MARKER JOINT 8979' H4-112" HES X NIP, 10= 3.S13" I 8989' H3.70" BKRDEPLOY SLV, ID=3.oo" I 8998' 3-112' HES X NIP, ID = 2.813" 9012' H4-112" HES XN NIP, MILLEO 10 = 3.8" (BEHIND PIPE) 9027' 3-112" X 3-3116" XO, ID = 2.80" 19037' ELM I~CUT OFF TBG TAIL (02117/88) (BEHIND PIPE) 9449' TOP OF CEMENT (01/19105) 13-112" LNR, 8.81#, L-BO STL, .0087 bpf, ID = 2.992" 14-112" TaG, 12.6#, L-BO, .0152 bpf, ID = 3.95S" 9-5IS" CSG, 47#, L-SO, ID = 8.681" 14-1/2" X 7" WHIPSTOCK (01/14105) I 9503' MILLUU I .w,,,""".. '1- IUKI Tna A..".· REF LOG: CBL ON 07/21/81 ANGLE AT TOP PERF: 95 @ 10820' I'bte: Refer to A-oduction DB for historical perf data SIZE SPF INTER\! AL OpnlSqz DATE 2" 6 10820 - 10845 0 02J22I05 2" 6 10880 - 10905 0 02J22I05 2" 6 10930 - 10950 0 02J22I05 2" 6 10970 -11000 0 02J22I05 2" 6 11050 - 11070 0 02J22I05 13-3116" LNR, 6.211, L-BO TCII, .0076 bpf, ID = 2.80" I DATE RBI BY COMIIENTS 07122181 HOff ORIGINAL COM PLETION 11105195 RINO 02123/05 NORDlC1 CTDSlDETRACK(Y-10A) œ.œ.œ NBFIPJC SET UPPERILOWER PATCHES 08128105 ITLH PATCHES PULLEDlPLUG SET 0s.œt05 ITLH PX PlUG PULLED DATE RBI BY COMIIENTS 01131/06 DRFITLH IH...G DRAFr CORRECTIONS 03116106 EZUPAG WAIVER SAFETY NOTE(03J09I06) 09J06I06 JRf¥PJC SET PX PLUG @ 8888' 09129106 JCM'PAG PULLED PX PLUG @ 8888' PRUDHOE BAY UNIT WELL: Y-1OA ÆRMT I'b: ~ APlI'b: 50-029-20587-01 SEC 33, T11 N, R13E BP exploration (Alaska) Permit to Drill 2042500 MD 11114 ./ ?J.-~ DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 )tL¿ ·IJh&J..~!>~ A>¡( No. 50-029-20587-01-00 .~~~. Well Name/No. PRUDHOE BAY UNITY-1OA Operator BP EXPLORATION (ALASKA) INC TVD 8965 Completion Date 2/22/2005 ...../ Current Status WAGIN Completion Status WAGIN ____._.~....._. ______..___..__ _______________·_u__ - --~- _..--- -------- -----.---- ____...___.___.__~._~ ____~.__.._n_.__.. _. __n__·_~_____ _ ________·_·___w____ REQUIRED INFORMATION ____._n.__·_·. Mud Log No Samples No Directional Survey /"Y~ ) -_.._--~-=~~=-~-==~~~~=~- ._________.,,__ - ___ __~..____" ---·----·__--_.0·--·- _"_'_____'__~___"_ - ______.__._ ________n___'._ _.______. - -~,----------_.- DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, SCMT Well Log Information: Log/ Data Digital Type Med/Frmt -tro-uDAsc- .. œó D Asc ~ ¡;,( ~. ~. :c (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number - Interval Start Stop 9400 11114 Log Log Run Scale Media No OH/ CH Received Comments _.~--- " .. - ------------ 3/29/2005 Name Directional Survey Directional Survey Directional Survey Cement Evaluation 9400 11087 3/29/2005 9400 11087 3/29/2005 5 Col 8700 9650 Case 11/29/2005 Slim Cement Bond Log SCMT-CB / PBMS-A 21- February-2005 5 Blu 10451 11 038 Open 9/12/2006 <e, Injection Profile, PSP, CCL, GR, Pres, Temp, Spin 18-Jul-2006 Injection Profile Las LIS Verification 14359 Induction/Resistivity GR, ROP, RPS, FET, RPD, RPX, RPM, 9433 9433 9878 9878 Open 1/29/2007 Open 1/29/2007 - _________ ._. _______" _~_ __ _________n.. _ ___________.__ _ ______.______".. Well Cores/Samples Information: - Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? v I t\I _ Analysis Received? Daily History Received? ÐN (3/N Formation Tops ~ Comments: _._-~~--- - - -----~,,---.._.~ ..-. --------. ------------ _______~_~_.."...~____.__~_..n__" _.___n_______._ ________."._ ____." ..._________..___________._ ________ ---,,----~.--.. --.---.-----------.------ Permit to Drill 2042500 MD 11114 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Well Name/No. PRUDHOE BAY UNITY-1OA Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20587-01-00 TVD 8965 Current Status WAGIN UIC Y Completion Date 2/22/2005 Completion Status WAGIN ~==~~~ -~~- ---------- --".--.----- ~---==~~t::~=ttrrJi/)~7_- ---.------'.- e e . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 November 27, 2006 RE: MWD Formation Evaluation Logs: V-lOA, AK-MW-3530513 1 LDWG formatted CD rom with verification listing. API#: 50-029-20587-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A.~D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center ME33 900 E. Benson Blvd. Anchorage, Alaska 99508 ,¡b.N9 £í Date:'"' ,i." Signed: (}. i1-- , ,,,<1...-/, 1 ) --.!'\ 1..'""1 A:4. ._.~ l,..J V.4-~ CI'\,.) ¢ ;43::;'1 .. :+ MEMORANDUM . TO: JimRegg ?Ø/c crlzzfl(J P.I. Supervisor\ '\ (7 I FROM: Jeff Jones Petroleum Inspector Well Name: PRUDHOE SAY UNIT Y-IOA Insp Num: mitJJ060913121820 Rei Insp Num Well 1 P.T. Packer "~- I, [-. ¡Type Inj. , N I TVD I -+--------+- I ITypeTest , SPT i Test psi Y-IOA 2042500 State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Monday, September 18, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-IOA PRUDHOE BA Y UNIT Y-IOA Src: Inspector NON-CONFIDENTIAL ~rØ fJ9 Reviewed By: P.I. Suprv,j1S}2- Comm API Well Number 50-029-20587-01-00 Permit Number: 204-250-0 Inspector Name: Jeff Jones Inspection Date: 9/11/2006 -~~._- 8262 ! IA 20655 i OA Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 80 3000 2960 ~~-~_._--- 0 0 0 3040 3000 Depth Interval REQV AR P/F P / Tubing --~-'----'---~"------------------'- Notes 7.6 bbls methanol pumped. This well has known TxIA communication & TTP set@ 8888' MD for the test. Monday, September 18,2006 Page I of I r .. TREE = '. WELLHEAD = A CTUA TOR = KB. ELEV = ~ ~F. ELEV = 1:0P= 'ax Angle = ·ltum MD = :;atum TVD = . 4" CrN GRAY AXELSON 85.69' 51.59' 3300' 98 @ 10915' 9502' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2708' Minimum ID = 2.786" @ 9027' TOP OF 3-3/16" LINER ,~ ". I TOP OF 7" LNR H 8985' -1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.992" H 9027' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9038' 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9464' 14-1/2" X 7" WHIPSTOCK (01/14/05) H 9503' MARKERJOINT H 9578' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10270' PERFORA TION SUMMARY REF LOG: CBL ON 07/21/81 ANGLE AT TOP PERF: 95 @ 10820' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 6 10820 - 10845 C 02/22/05 2" 6 10880 - 10905 C 02/22/05 2" 6 10930 - 10950 C 02/22/05 2" 6 10970 - 11 000 C 02/22/05 2" 6 11050 - 11070 C 02/22/05 IDA TE REV BY COMMENTS 07/22/81 HOFF ORIGINAL COMPLETION : 11/05/95 RWO ].2.2/23/05 NORDIC1 CTD SIDETRACK (Y-10A) :)2/07/03 /KAK WAIVER SAFETY NOTE 05/09/05 NBF/PJC SET UPÆRlLOWER PATCHES 08/28/05 /TLH PA TCHES PULLED/PLUG SET Y -1 OA I~ ~ =-t . SAFETY NOTES: OVERSHOT GUIDE COVERS CUT STUB. SEE TaFOR DETAILS. SIDETRACK 70° @ 9654' ***Txl~ M . OPERATING LlM ITS: M AX lAP = 2000 PSI, MAX OAP = 1000 PSI (03/09/06 WAIVER) - NOTE: PWI ONLY/NO MIINJECTION ALLOWED*** ***CHROM E NIPPLES IN 4-1/2" L-80 TBG*** 2182' 1-14-1/2" HES X NIP (9CR), ID = 3.813" 2574' H9-5/8" DV PKR I 8832' 8843' 8867' 8888' 8888' 1-14-1/2" HESXNIP(9CR), ID=3.813" I I-r9-5/8" x 4-1/2" TrN HBBP- T PKR, ID = 3.90" 1-14-1/2" HES X NIP (9CR), ID = 3.813" I 1-14-1/2" HES X NIP (9CR), ID = 3.813" I 1-14-1/2" HES PX PLUG (06/06/06) I g z fl" 8907' H OVERSHOT GUIDE FOR CUT STUB, ID = 4.55" 8915' HBAKER TBG SEAL ASSY I 8935' H9-5/8" x 4-1/2" BKR PKR, ID = 4.000" I 8979' H4-1/2" HES X NIP, ID" 3.813" I 8989' 1-13.70" BKR DEPLOY SLV, ID = 3.00" I H3-1/2" HES X NIP, ID" 2.813" I 1-14-1/2" HES XN NIP, MILLED ID = 3.8" (BEHIND PIPE) I 9027' H 3-1/2" X 3-3/16" XO, ID" 2.80" I 19037' ELM IJCUT OFFTBG TAIL (02/17188)(BEHIND PIPE) 9449' HTOPOFCEMENT(01/19/05) I MILLOUT WINDOW (Y-10A) TOP @ 9503' IPBTD H 11074' 13-3/16" LNR, 6.2#, L -80 TCII, .0076 bpf, ID" 2.80" H 11109' DATE REV BY COMMENTS 09/03/05 ITLH PX PLUG PULLED 01/31/06 DRFITLH DRLG DRAFT CORRECTIONS 03/16/06 EZL/PAG WAIVER SAFETY NOTE (03/09/06) 09/06/06 JRP/PJC SET PX PLUG @ 8888' PRUDHOE BA Y UNIT WELL: Y-10A PERMIT No: ~2042500 API No: 50-029-20587-01 SEC 33, T11 N, R13E BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Well C-11A 8-25 F-06A G-18A P-24 8-28 8-01 W-39A Z-02A G-03A C-26A F-268 F-268 W-39A F-04A Y -08A C-068 X-27 K-07D Y-10A F-12 K-07D X-04 A-30A 17-048 Z-30A 17-048 P81 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 11225983 11217247 11258688 11209612 11216206 11221590 11211508 11216197 11212856 11211493 11225979 N/A N/A 11216197 11221602 11221604 11212883 11217274 10942217 11209611 11225984 11058256 10919925 11054295 40010183 40010092 40010183 L).I c... t9C/{ - ;) S-è Log Description Date 07/02/06 05/11/06 03/20/06 07/19/06 07/06/06 07/04/06 06/23/06 OS/29/06 05/02/06 OS/24/06 06/07/06 06/06/06 06/06/06 OS/29/06 08/18/06 08/20/06 08/15/06 08/26/06 06/15/05 07/18/06 07/02106 11/28/05 12/15/04 04/06/05 03/09/04 01/27/04 03/08/04 LDL LDL PROD PROFILE W/DEFT MEM INJECTION PROFILE MEM INJECTION PROFILE LDL PROD LOG W/DEFT MEM PROD PROFILE INJECTION PROFILE LDL LDL MEM PROD & INJECTION MEM BORAX LOG MEM BORAX LOG SCMT SCMT USIT USIT MEMORY SCMT MEM INJECTION PROFILE LDL SBHP SURVEY PROD PROFILE W/DEFT CH EDIT OF PDC LOG W/GR OH EDIT OF MWD/LWD (REDO OF TVD DATA) OH EDIT OF MWD/LWD (REDO OF TVD DATA) OH EDIT OF MWD/LWD NO. 3941 Company: R· ,i r::- _:r-' :r-:- . , ,. <'- ", . .:>...... ~;: '., : .,; ¡) ~r..( J. ~ '"i..uo 08/28/06 ~CiI&GasCons,C~ ,A.nchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 8L 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color Field: Prudhoe 8ay CD 1 1 1 1 1 1 2 . 1 1 1 1 1 . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Schlumberger r~~ ~~r~~ t:~ '} ~V /. i».~ ;~~c,,~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ; , ! '2 ] 20G5 Cüns.~ c(¡(nn11~~f\ '~}Jf (ivJragtZ- Well Job # Log Description Date BL PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 US IT 10/06/05 S-14A 10987547 USIT 09/13/05 Y-10A 10889216 SCMT ~o4 -;)5'0 02/21/05 D.S. 03-33A 10893093 SCMT 03/05/05 C-19B 10928633 SCMT 05/15/05 09-20 10889215 SCMT 02/18/05 D.S.09-31C N/A SCMT 11/05/05 P-06A 11076455 SCMT 07/29/05 2-22A 11084275 SCMT 07/10/05 K-20B 11075899 SCMT 07/04/05 D.S. 06-20 11062630 USIT 06/14/05 C-18A 10621788 SCMT 06/06/04 P1-07A 10621778 SCMT 04/21/04 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: I ,__ II í~:' \Q:J NO. 3613 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne pt. Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY! ~.J'l0.~)7~.U G Ú~ 11/28/05 . . RE: MITs Due . . Pit ~ Wi) -ZÇU Jim, Well S-22B (PTD 1970510)passed an AOGCC witnessed MITIA 10/08/05 with AOGCC representative John Spaulding. I will send the MIT form tomorrow. Well Y-10A is a PWI currently operating under Variance #300-103 (04/20/00)and an internal waiver. Most recent compliance testing was a passing CMIT-TxIA to 4000 psi on 09/03/05. Attached, please find the MIT test form for this test. Please call with any questions. Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: Ec:JÞE:.E~:..~~~~lke@bp.com -----Original Message----- From: James Regg [mailto:jim reg9@admin.st:aLe.ak.us] Sent: Wednesday, October OS, 2005 4:18 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: MITs Due The Commission's records show MITs are due on the following wells: PBU S-22B (PTD 1970510) - last MIT 8/15/2001 PBU Y-10A (PTD 2042500) - initiated injection 6/2005; no record of MIT being performed Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. Jim Regg AOGCC PBU Y-10 10-07-05 Content-Description: MIT PBU Y-I0 10-07-05 (4).xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 10/10/2005 1:06 PM · . STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION~I.'-~t~ Mechanical Integrity Test _ ''l'''f!)~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state..ák.us;om_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Pad Y 09/03/05 Don Reeves Packer Depth We" Y-10A I Type Inj. IN TVD I 8,262' P.T.D. 2042500 Type test P Test psi 4000 Notes: CMIT-TxIA to 4000 psi pre RWO, waiver compliance TUbing Casing OA Pretest 100/ 80 o Initial 15 Min. 30 Min. 4'02o[ 4,050 o 4'0201 4,050 o Interval I P/F 4,0201 4,050 o o P we"l I Type Inj. I I T:~PSil TUbingl I I I I Interval P.T.D. Type test Casing P/F Notes: OA we"l Type Inj. I T:~PSil TUbing I I I I Interval P.T.D. Type test Casing P/F Notes: OA we"l Type Inj. I T:~psil TUbing I I I I Interval I P.T.D. Type test Casing P/F Notes: OA we"l Type Inj. I T:~psil TUbing I I I I Interval P.T.D. Type test Casing P/F Notes: OA NOTE: AOGCC did not witness testing. TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly SUlVey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT PBU Y·10 10-07-05 (4).xls MITs Due . The Commission's records show MITs are due on the following wells: PBU S-22B (PTD 1970510) - last MIT 8/15/2001 PBU Y-10A (PTD 2042500.) - initiated injection 6/2005; no record of MIT being performed Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. Jim Regg AOGCC 1 of 1 10/5/20054:18 PM PBU Y-lOA . . Our records show PBU Y-IOA''íl:(¡t'¡'D12042500) initiated injection in June 2005¡ we do not have a record of any MITs for this injector. Please make arrangements for an inspector to witness an MIT¡ also, if a test has been performed on this well, please provide the data on MIT report form. Thanks. Jim Regg AOGCC 1 of 1 10/4/2005 8:53 AM I STATEOFALASKA a ALASKA AND GAS CONSERVATION COM~ION WELL COMPLETION OR REcOMPLETION REPORT AND LOG. .... 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended IBI WAG 20MC 25.105 20MC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1410' SNL, 205' WEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 915' SNL, 2788' WEL, SEC. 33, T11N, R13E, UM Total Depth: 222' SNL, 1584' WEL, SEC. 33, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 644611 y- 5948841 Zone- ASP4 TPI: x- 642018 y- 594928Y i Zone- ASP4 Total Depth: x- 643207 y- 5950003· Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD GR I EWR, SCMT 22. One Other 5. Date Camp., Susp., or Aband. 2/22/2005 6. Date Spudded 2/12/2005 7. Date T.D. Reached 2/15/2005 8. KB Elevation (ft): 85.70' 9. Plug Back Depth (MD+ TVD) 11074 + 8967 10. Total Depth (MD+TVD) 11114 + 8965 11. Depth where SSSV set (Nipple) 2182' MD 19. Water depth, if offshore NIA MSL Revised: 06/30/05, Put on Injection fb'. Well Class: o Development 0 Exploratory o Stratigraphic IBI Service 12. Permit to Drill Number 204-250 13. API Number 50- 029-20587-01-00 14. Well Name and Number: PBU Y-10A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028287 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" x 30" 13-3/8" 9-518" WT. PER FT. Insulated 72# 47# 29# 8.81# 16.2# GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE lOP BOTTOM lOP BoTTOM SIZE Surface 110' Surface 110' 36" 8 cu yds Concrete Surface 2709' Surface 2709' 17-1/2" 3720 cu ft Permafrost II Surface 9464' Surface 8850' 12-1/4" 1270 cu ft Class 'G', 130 cu ft PF 'C' 8985' 9507' 8396' 8891' 8-1/2" 336 cu ft Class 'G' 8989' 11109' 8399' 8965' 3-3/4" x 4-1/8" 163 cu ft 'G', 175 cu ft 'G', 225 cu ft 7" 3-1/2" x 3-3/16" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 10820' - 10845' 8996' - 8995' 10880' - 10905' 8991' - 8987' 10930' - 10950' 8984' - 8981' 10970' - 11000' 8979' - 8976' 11050' - 11070' 8970' - 8968' 26. Date First Production: June 21,2005 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""" 24. SIZE 4-1/2", 12.6#, L-80 TOeING. RECORD DEPTH SET (MD) 9037' PACKER SET (MD) 8843' & 8935' 25. ACID, FRACTURE, CEMENT SQUEEZE, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 55 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-Bsl GAs-McF WATER-BsL Oll-Bsl GAs-McF W A TER-Bsl CHOKE SIZE I GAS-OIL RATIO Oil GRAVITY-API (CORR) .. 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 RBDMS 8Ft. .JUl. 13 2005 CONTINUED ON REVERSE SIDE 6;::: ·-.. . 29. -tRMATION TESTS 28. GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". No new tops were penetrated. None Ivishak (From Y-10) 9578' 8959' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I ~erebY certify that the fO~ing ~s true and correct to the best of my knowledge. Signed TerrieHubbl~IOfv'\d) Ü)~ Title Technical Assistant Date D0"30..os PBU Y-1 OA 204-250 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit No. I Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only · STATE OF ALASKA . ALASK IL AND GAS CONSERVATION COM " SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended ~ WAG 20AAC25.105 20AAC25.110 One Other 5. Date Camp., Susp., or Aband. 2/22/2005 6. Date Spudded 2/12/2005 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1410' SNL, 205' WEL, SEC. 33, T11 N, R13E, UM Top of Productive Horizon: 915' SNL, 2788' WEL, SEC. 33, T11 N, R13E, UM Total Depth: 222' SNL, 1584' WEL, SEC. 33, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- ~~~ y- ~948841 Zone- __ AS~~ TPI: x- 642018 y- 5949287 Zone- ASP4 Total Depth: x- 643207 y- 5950003 Zone- ASP4 -~-------~~--------~- ------~--------~- 18. Directional Survey ~ Yes 0 No No. of Completions 21. Logs Run: MWD GR I EWR, SCMT 22. 7. Date T.D. Reached 2/15/2005 8. KB Elevation (ft): 86.59' 9. Plug Back Depth (MD+ TVD) 11 074 + 8967 10. Total Depth (MD+ TVD) 11114 + 8965 11. Depth where SSSV set (Nipple) 2182' MD 19. Water depth, if offshore NI A MSL RECEIVED MAR 3 0 2005 1 b. we~~:Uil & Ga, r. o Development r¡lJi.l<rJfBIMo40IfNrtr,,¡,. o Stratigraphic II'SflIfIJJè " 'vij 12. Permit to Drill Number 204-250 13. API Number 50- 029-20587-01-00 14. Well Name and Number: Y-10A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028287 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" x 30" 13-3/8" 9-518" 7" 3-1/2" x 3-3/16" GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE lOP BoTTOM lOP BOTTOM SIZE CEMENTING RECORÖ Surface 110' Surface 110' 36" 8 cu yds Concrete Surface 2709' Surface 2709' 17-1/2" 3720 cu ft Permafrost II Surface 9464' Surface 8850' 12-1/4" 1270 cu ft Class 'G', 130 cu ft PF 'C' 8985' 9507' 8396' 8891' 8-1/2" 336 cu ft Class 'G' 8989' 11109' 8399' 8965' 3-3/4' x 4-1/8" 163 cu ft 'G', 175 cu ft 'G', 225 cu ft WT. PER FT. Insulated 72# 47# 29# 8.81# 16.2# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 10820' - 10845' 8996' - 8995' 10880' - 10905' 8991' - 8987' 10930' -10950' 8984' - 8981' 10970' - 11000' 8979' - 8976' 11050' - 11070' 8970' - 8968' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested 24. SIZE 4-1/2", 12.6#, L-80 AMOUNT PULLED TUBING ReCORD DEPTH SET (MD) 9037' PACKER SET (MD) 8843' & 8935' 25. ACID, FRACtURE, CEMENTSduËËZE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 55 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA O'l-BBl GAs-McF WATER-BBl PRODUCTION FOR TEST PERIOD .. CALCULATED ...... 24-HoUR RATE""'" Oil -BBl Flow Tubing Casing Pressure Press. 27. GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips;rifmne, state "none". \'''''''< C None .~þ;'/~ '~Il /j·'·"·'l..... . ·"h:4- : 'E::::..-: I, .'~_,~ ~~--,..""..,i< DUPL/CATg CONTINUED ON REVERSE SIDE Form 10-407 Revised 12/2003 RBDMS BFl MAR 3 1 20D5 Gf 28. GEOLOGIC MARKER. 29. .ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". No new tops were penetrated. None Ivishak (From Y-10) 9578' 8959' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble-{~ ~ Title Technical Assistant Y -1 OA Well Number 204-250 Prepared By Name/Number: Drilling Engineer: Date 03/2/;)/05 Terrie Hubb/e, 564-4628 Mary Endacott, 564-4388 Permit No. / Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/3/2005 00:00 - 08:00 8.00 MOB P PRE Take off guide arch. Set injector head in pipe bay. Lay down wind walls. 08:00 - 11 :30 3.50 MOB P PRE Wait for rig tour. Gave one hour tour to media group. 11 :30 - 14:00 2.50 MOB P PRE Lay down derrick and close pipe shed doors. 14:00 - 14:30 0.50 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for rig move to Y pad with Security, Nordic, SWS, CPS and tool service personnel. 14:30 - 00:00 9.50 MOB P PRE Move rig to Y pad with no incidents. On Y pad at 0000 hrs. 2/4/2005 00:00 - 01 :00 1.00 MOB P PRE Position rig in front of well. Well is dead. 01 :00 - 01 :15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for raising derrick and wind walls. 01:15 - 05:00 3.75 MOB P PRE Raise derrick and wind walls. -22 F, 12 mph wind. No problems. 05:00 - 09:00 4.00 MOB P PRE Make up and tighten 12 guy wires for derrick and wind walls. Pick up injecter head and stab coil. Held PJSM before backing over well. Back rig over well with no incidents. 09:00 - 11 :30 2.50 MOB P PRE ACCEPT RIG AT 0900 HRS, 02/04/2005. NIU BOP grease swab, master & pump open SSV. 11:30 -13:30 2.00 RIGU P PRE Wait on gravel. Level Pad for cutting tank. Continue with general rig up of trailers. 13:30 - 16:00 2.50 RIGU P PRE Spot cutting box with bed truck. 16:00 - 00:00 8.00 BOPSUF P PRE Test BOP. Thaw frozen bleed line. Witnessing of BOP Test waived by AOGCC's Chuck Schieve. Heat tree and BOPE. Re-grease tree valves to get good tests. BOP test witnessed by WSL's Bob Laule and Rick Whitlow. All equipment tested OK, except 2-3/8" TIW valve. It will be re-built and tested. 2" TIW valve with XO will be used as backup. 2/5/2005 00:00 - 01 :30 1.50 BOPSUF P PRE Pressure I function test BOPE. AOGCC waived witnesss. Test witnessed by WSL, Rick Whitlow. All BOPE pressure I function tested OK, except for 2-3/8" TIW valve which will be re-built and re-tested. The 2" TIW valve with XO will be used as a backup. Test report sent to AOGCC. 01 :30 - 03:30 2.00 STWHIP P WEXIT M/U Baker eTC. Pull I Press test CTC. C/O Coil packoff. Fill coil with 2# Biozan. Pressure test inner reel valve. 03:30 - 04:15 0.75 STWHIP P WEXIT M/U 3.80" Baker window milling BHA with 3.80" HC diamond mill and 3.79" string reamer. OAL = 82.00'. 04:15 - 06:10 1.92 STWHIP P WEXIT RIH with 3.80" window milling BHA #1. Take returns to cuttings tank. RIH to 9450'. Up wt = 41K, Dwn wt = 24.5k. Tagged cement top at 9462 ft. 06:10 - 06:25 0.25 STWHIP P WEXIT Mill cement, 2.5 bpm, 1500 psi, Tag pinch point and correct +28' to 9507.6'. Paint flag. 06:25 - 15:30 9.08 STWHIP P WEXIT Mill window 2.45/2.55 bpm @ 1626 psi. FS =1500 psi. Milled to 9528 . Never seen any specific indication of bottom of window. Less than normal metal on magnets initially. Window Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/5/2005 06:25 - 15:30 9.08 STWHIP P WEXIT milled with low weight on bit and releatively small amount of motor work. Geo unable to confirm formation. Samples primarily cement. Drill open hole at 16 fph. Drilling ratty like Shulblik. Ream thru window without any problems. Dry tag. Flag EOP 9400'. 15:30 - 17:15 1.75 STWHIP P WEXIT POH Over pull @ 9144. Over pull at nipples correcting for the depth correction. PE reports for milling XN also had a similar correction +25'. 17:15 - 17:30 0.25 STWHIP P WEXIT LD BHA. Mill shows signs of wear across the center of the mills. Wear looks normal. Mill in gauge. 17:30 - 19:00 1.50 DRILL P PROD1 MIU MWD build BHA #2 with 3.2 deg short radius motor and 3.75" M09 Bit #2. M/U CTC. Pull/ Press test CTC. OAL = 64.61'. 19:00 - 21 :00 2.00 DRILL P PROD1 RIH with BHA #2 to 9200'. No pump due to high bend motor. Orient TF to 40R. Correct CTD to Flag at 9464.6'. [added 23' CTD). RIH and tagged TD at 9528'. Did not see wt loss thru window. 21 :00 - 23:30 2.50 DRILL N DPRB PROD1 Attempt to drill build section. 2.7/2.7 bpm, 3100 -3900 psi, 30R. No sign of window. Several stalls at 9531 ft. Several stalls at 9540'. Unable to get past 9540'. Motor stalling with no WOB. Incl not showing increase from whipstock. Geo samples only had cement and metal scale. Appear to be at whipstock pinch point at 9540' CTD. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Log up from 9539' with MWD GR to prove present depth. GR Tie-in correction was -31' CTD, so corrected drilled depth is 9509', which is very close to whipstock pinch point of 9507.6'. 2/6/2005 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Log MWD GR tie-in to prove drilled depth. [-31' CTD correction) . Drilled depth is 9509'. Which is pinch point of whipstock in 7" Liner. Whipstock still in place. 00:30 - 02:15 1.75 STWHIP N DPRB WEXIT POH with MWD build BHA. Flag CT at 9300' EOP. Ordered 2# Biozan to mill window. 02:15 - 02:45 0.50 STWHIP N DPRB WEXIT Layout MWD build BHA. 02:45 - 03:45 1.00 STWHIP N DPRB WEXIT MIU 3.80" Baker window milling BHA. MIU Baker CTC, pull I press test eTC. 03:45 - 05:30 1.75 STWHIP N DPRB WEXIT RIH with window milling BHA #3. circ at 0.2 bpm, 600 psi. RIH to Flag at 9300' EOP. Correct -6' CTD at flag. RIH to 9430'. Had pinhole leak in coil at reel. Flag pinhole on reel. 05:30 - 06:45 1.25 STWHIP N SFAL WEXIT POH for pinhole leak in coil at 9430'. Coil has 436,800 ft on it. 06:45 - 07:00 0.25 STWHIP N SFAL WEXIT LD milling BHA. 07:00 - 09:45 2.75 STWHIP N SFAL WEXIT Circulate while waiting on N2 services. 09:45 - 10:00 0.25 STWHIP N SFAL WEXIT PJSM for N2 blow down. 10:00 -11:20 1.33 STWHIP N SFAL WEXIT RU N2. Circulate 30 bbl H20 followed by 10 bbl methanol. Blow down reel with N2 11 :20 - 15:00 3.67 STWHIP N SFAL WEXIT Set back injector.Pull coil to reel and secure. Pull bushings. Remove hard line from reel. 15:00 - 16:00 1.00 STWHIP N SFAL WEXIT Wait on crane. Wind 15 mph gusts to 24mph 16:00 - 16:30 0.50 STWHIP N SFAL WEXIT Safety evaluation meeting for reel swap. Attended by Peak, J. Killfoly, Nordic #1 team, SLB unit 7 team. Evaluate operating Printed: 2/23/2005 11:59:16AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/612005 16:00 - 16:30 0.50 STWHIP N SFAL WEXIT conditions for tag line handlers. Weather conditions worsening 18 mph with gusts to 29mph. Reel wt 90,000 #. Boom angle would allow the reel to hit boom if wind spins reel. Decided to go on standby. 16:30 - 22:00 5.50 STWHIP N SFAL WEXIT Wait on weather for reel swap. Wind at 20-30 MPH. -15F, -60 WC. 22:00 - 00:00 2.00 STWHIP N SFAL WEXIT Wait on weather for reel swap. Wind at 25-40 MPH. -15F, -62 WC. 2/7/2005 00:00 - 18:00 18.00 STWHIP N SFAL WEXIT WOW to swap reels. Wind at 18-30 mph, -50 WC. Phase 1. 18:00 - 00:00 6.00 STWHIP N SFAL WEXIT WOW to swap reels. Wind at 20-40 mph, -64 we. Phase 1. 2/8/2005 00:00 - 12:00 12.00 STWHIP N SFAL WEXIT WOW for reel swap. -19F, 22 - 36 mph, -64 WC. Phase 1. 12:00 - 00:00 12.00 STWHIP N SFAL WEXIT WOW for reel swap. -9F, 22 - 40 mph, -50 we. Phase 2. 2/9/2005 00:00-21:15 21.25 STWHIP N SFAL WEXIT WOW for reel swap. Phase 2, 22 - 36 mph, -9F, -50 WC. Wind average 2 hrs 15 mph with wind gust to 24 mph 21:15 - 21:30 0.25 STWHIP N SFAL WEXIT MIRU Peak 150 T crane, Revieved new reel and cleaned snow off 21 :30 - 21 :50 0.33 STWHIP N SFAL WEXIT Held Safety meeting with Nordic, Peak and Schlumberger on lift and wind conditions. I Dave Hildreth signed the Safety Sheet allowing the lift with stipulations that the wind remain at 15 deg with gust no higher than 25 MPH. Will check the wind speeds on the reel house prior to making lift. This will be the determining factor on making the lift along with BOC parameters. Wind gust on the reel house at 28 mph, will wait and monitor the wind 21 :50 - 00:00 2.17 STWHIP N SFAL WEXIT WOW and monitor wind on reel house and BOC Wind speed at midnight = 23 mph with gust to 35 mph 2/10/2005 00:00 - 01 :00 1.00 STWHIP N SFAL WEXIT RD Peak Crane. Wins at 23 mph with gust to 35 mph, Phase I driving conditions. 01 :00 - 09:00 8.00 STWHIP N SFAL WEXIT WOW. Open well, WHP = Opsi, filled hole with 5 bbl mud 09:00 - 09:30 0.50 STWHIP N SFAL WEXIT WOW. Performed weekly BOPE function test. 09:30 - 00:00 14.50 STWHIP N SFAL WEXIT WOW to swap reels. Wind at 20-34 MPH. -10F, -50WC. 2/11/2005 00:00 - 08:15 8.25 STWHIP N SFAL WEXIT WOW to swap reels. Wind at 20-34 MPH. -10F, -50WC. Forecast calls for winds to subside to 5-10 mph on Friday, Ordered crane for 0700 hrs to swap reel if possible 08: 15 - 08:30 0.25 STWHIP N SFAL WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for picking reel with Peak crane. Wind at 8-20 mph, -6F. 08:30 - 09:30 1.00 STWHIP N SFAL WEXIT Pick used reel out of reel house with Peak 150 ton crane. 09:30 - 10:30 1.00 STWHIP N SFAL WEXIT Set in new reel with crane. Set on reel jacks and release Peak crane. 10:30 - 12:30 2.00 STWHIP N SFAL WEXIT Tighten reel bushings. MIU internal grapple to pull coil. 12:30 - 13:30 1.00 STWHIP N SFAL WEXIT Pull coil to injecter head and stab coil thru injecter chains. 13:30 - 14:30 1.00 STWHIP N SFAL WEXIT Install hardline inside reel. Had cleanance problem. Called for SWS welder to cut out inside of reel plate to expose more coil to give room to M/U hardline and valve. 14:30 - 15:30 1.00 STWHIP N SFAL WEXIT M/U Baker CTC. Pull test with 37K. C/O coil pack-off. 15:30 - 17:30 2.00 STWHIP N SFAL WEXIT Cut out inside of reel and expose one additional foot of coil. M/U hardline inside reel. 17:30 - 18:45 1.25 STWHIP N SFAL WEXIT Wait on MEOH. Open well 24 turns WHP = 0 psi. Filled hole 18:45 - 20:15 1.50 STWHIP N SFAL WEXIT Spot MEOH trailer and RU to rig Pumped 5 bbl MEOH, 5 bbl rig water PT inner reel valve 4500 psi, then pumped 60 bbl flo-pro. Launched dart, displace with Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 211112005 18:45 - 20:15 1.50 STWHIP N SFAL WEXIT flo-pro Vol 53.2 bbl (Question volume). PT CTC to 4000 psi. 20:15 - 20:45 0.50 STWHIP N SFAL WEXIT PU I MU BOT Milling BHA. Checked all connections BHA len = 81.78 ft 20:45 - 22:50 2.08 STWHIP N SFAL WEXIT Set Mechanic! counter, RIH, remove shipping plastic and tighten reel bolts Conducted Mud swap while RIH PU at 9450 ft = 33k Tagged at 9508. 3 ft. 22:50 - 23:00 0.17 STWHIP N SFAL WEXIT Pulled tight, PUH and cir Flo-Pro out CTP = 2014 psi Rig charges start again at 2300 hrs. For Dims we are still on NPT until we start drilling build section. 23:00 - 23:10 0.17 STWHIP N DPRB WEXIT RIH and stalled at 9507.4 ft Qp = 2.24 bpm Stalled at 9506.9 ft. Painted white flag at this depth. Depth is tricky with new CT 23:10 - 00:00 0.83 STWHIP N DPRB WEXIT Milling Window. D1 = 9506.9 ft 6 min/0.1 ft Qp = 2.50/2.65 bpm CTP = 2000 psi Started slow due to possible WS /Iiner damage from PDC bit 4 stalls on window getting started. Top of window at 9507. 2112/2005 00:00 - 01 :05 1.08 STWHIP N DPRB WEXIT Milling Window as per BOT / BP Increased time to 7min / 0.1 ft Qp 2.66/2.75 bpm CTP 2070/2267 psi At 9,507.6 ft, window milling smooth out as expected. 01 :05 - 02:30 1.42 STWHIP N DPRB WEXIT Milling Window as per BOT Qp 2.66/ 2.75 bpm CTP 2070/2241 psi WOB at 4000 Ib INOA =415/11 psi 02:30 - 04:00 1.50 STWHIP N DPRB WEXIT Milling Window Qp 2.74/2.86 bpm CTP 2070/2300 psi WOB at 5,300 Ib 04:00 - 05:10 1.17 STWHIP N DPRB WEXIT Milling Window Qp 2.66/2.79 bpm CTP 2070 /2150 psi IA I OA = 417 /12 psi Vp = 300 bbl 05:10 - 06:00 0.83 STWHIP N DPRB WEXIT Milling Window from 9,506.9 ft to 9,512.0 ft (5.1 ft) Qp 2.66/ 2.73 bpm CTP 2070 / 2180 psi IA I OA = 424 /15 psi Vp = 297 bbl 06:00 - 07:15 1.25 STWHIP N DPRB WEXIT Milling window from 9512.0 to 9513 ft. Exit casing at 9513'. 2.7/2.7 bpm, 2200-2400 ft. Top of window at 9507', Bottom of window at 9513'. 07:15 - 08:30 1.25 STWHIP N DPRB WEXIT Milling formation, 2.7/2.7 bpm, 2200-2500 psi, Milled to 9521'. 08:30 - 10:20 1.83 STWHIP N DPRB WEXIT Back ream up thru window to 9500'. Ream down clean to 9521'. Ream up and down 3 times. Window is clean. RIH with no pump. Clean window. Circ. in FloPro drilling fluid while reaming. 10:20 - 12:15 1.92 STWHIP N DPRB WEXIT POH with window milling BHA. Flag coil at 9300' EOP. 12:15 - 13:00 0.75 STWHIP N DPRB WEXIT UO milling BHA. Mill was 3.79/3.78 Go/NoGo. String reamer was same. Mill had full wear across face and formation samples were seen in cuttings. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/22/2004 2/22/2005 1 Spud Date: 7/5/1981 End: 2/22/2005 2/12/2005 13:00 - 13:15 0.25 DRILL N DPRB PROD1 PRE-SPUD MEETING AND PJSM. Review well plan and hazards for this well. Review procedure, hazards and mitigation for MIU MWD drilling BHA. 13:15 - 14:50 1.58 DRILL N DPRB PROD1 MIU BHA #5, MWD Build BHA with 3.28 deg SR motor and 3.75" M-09 Bit. OAL = 64.61'. 14:50 - 17:15 2.42 DRILL N DPRB PROD1 RIH with minimum pump [0.15 bpm), due to high bend motor. Correct to flag at 9300' EOP. [-12 ft CTD). Tightened reel bushings. 17:15 - 17:40 0.42 DRILL N DPRB PROD1 Orient TF to 56R to go thru window. Went thu window and tagged TD at 9514'. Correct depth to 9521' [+7' CTD). 17:40 - 18:10 0.50 DRILL P PROD1 Drilling build section in Shublik, 2.7/2.7 bpm, 3100 - 3800 psi, 62R, 40 fph, Drilled to 9532'. 18:10 - 20:20 2.17 DRILL P PROD1 Drilling build section in Shublik, TF = 62R Op = 2.7 12.7 bpm CTP = 3100/3800 psi. No RA Pip tag was installed by PE Wells Group 20:20 - 20:30 0.17 DRILL P PROD1 Drilling build section in Shublik, TF = 79R Op = 2.75/2.84 bpm 0 at 1:1 ratio CTP = 3100/3900 psi. 20:30 - 21:10 0.67 DRILL P PROD1 PUH to orient TF Tried above WS and flipped 180 deg, RIH below WS and orient TF 21:10 - 21:34 0.40 DRILL P PROD1 Drilling build section in Shublik, TF = 101 R Op = 2.75/2.84 bpm. CTP = 3100/3900 psi. TF rolled up, orient TF on bottom 21 :34 - 21 :45 0.18 DRILL P PROD1 PUH to WS to orient TF. Working CT to keep TF 21 :45 - 22:04 0.32 DRILL P PROD1 Drilling build section in Shublik, TF = 35R Op = 2.75 / 2.84 bpm. CTP = 3100/3290 psi. Drill with low WOB to get past this area. TF still rolling up to 10R, need 35 to 40R 22:04 - 22:15 0.18 DRILL P PROD1 PUH to window to orient TF 22:15 - 22:50 0.58 DRILL P PROD1 Drilling build section in Shublik, TF = 23-34R. Op = 2.73/2.91 bpm. CTP = 3000 I 3300 psi. No LC at this time Vp = 302 bbl Pulled up to window to get 1 click on bottom at 9,600 ft 22:50 - 23:05 0.25 DRILL P PROD1 PUH and pump up survey Surveys no in limits 23:05 - 23:25 0.33 DRILL P PROD1 Drilling build section in Shublik, TF = 28R. ROP 83 fph Op = 2.73/2.91 bpm. CTP = 3000 I 3300 psi. 23:25 - 23:31 0.10 DRILL P PROD1 PUH and pump up survey. Good survey 23:31 - 23:50 0.32 DRILL P PROD1 Drilling build section in Shublik, TF = 39R Op = 2.66/2.87 bpm. CTP = 3000 / 3250 psi. 23:50 - 00:00 0.17 DRILL P PROD1 PUH orient 2/13/2005 00:00 - 00:45 0.75 DRILL P PROD1 Drilling build section, TF = 45R Op = 2.74/2.91 bpm. CTP = 3000 I 3350 psi. 00:45 - 01 :00 0.25 DRILL P PROD1 PUH I wipe to get 1 click 01:00 - 01:15 0.25 DRILL P PROD1 Drilling build section, TF = 62R Printed: 2/23/2005 11:59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/13/2005 01 :00 - 01 :15 0.25 DRILL P PROD1 Qp = 2.74/2.91bpm. CTP = 3000 / 3350 psi. Will land high in vertical section. At 9,720 ft, need to turn TF into all turn, Projection at bit is +94 deg 01:15-01:31 0.27 DRILL P PROD1 PUH to 9530 ft to get 1 click 01 :31 - 01 :50 0.32 DRILL P PROD1 Drilling build section, TF = 80R. ROP 50 to 180 fph Qp = 2.74/2.91 bpm. CTP = 3000/3430 psi. Put TF at 80 to 90 R and drill approximately to 9,840 ft MD to land plan view Projected Fault 1 from 9,760 ft to 9,810 ft. 01 :50 - 02:09 0.32 DRILL P PROD1 PUH to 9530 ft to orient 02:09 - 03:05 0.93 DRILL P PROD1 Drilling build section, TF = 120R, ROP = + 100 fph Qp = 2.54/2.72bpm. CTP = 2950 / 3600 psi. Hole angle got up to 94.75 deg at 9,736 ft MD /8,924 ft TVD 03:05 - 03:15 0.17 DRILL P PROD1 PUH to 9,525 ft to orient TF 03:15 - 03:30 0.25 DRILL P PROD1 Orient TF at 9,541ft to 9,530 ft 03:30 - 03:45 0.25 DRILL P PROD1 RIH. Some motor work at 9,780 ft MD. RIH TF at 5L at 9820 ft 03:45 - 04:15 0.50 DRILL P PROD1 Orient TF on bottom unable to get clicks, PUH to base of window 04:15 - 04:21 0.10 DRILL P PROD1 Drilling build section, TF = 84R Qp = 2.74/2.62 bpm. CTP = 2950/3475 psi. Vp = 278 bbl at 0415 hrs. Lossing fluid at 0.20 bpm /12 bph started at 9,800 ft MD 8,921ft TVD. IA was first indicator of lossing circulation. Ordered fluids Started to lose cir at 9,845 ft. Lost all returns at 9,846 ft 04:21 - 04:50 0.48 DRILL N DPRB PROD1 PUH losing 100% returns 04:50 - 05:45 0.92 LCR N DPRB PROD1 Stopped at 9,379 ft,above whipstock Ordered 290 bbl Flo-Pro and ordered 600 bbl 2% KCL with 4ppb KlaGard. Lined out to fill hole down backside. Pumping 4 bpm. IA pressure climbing up. Took 18 bbl to fill hole. Reduced Qp to min losses. Losing 2.3 bpm. Pumped down CT at 0.5 bpm to keep from freezing. Wait on fluids. Pump 10 bbl down backside IA = 0 psi. Taking 1 bbl fluid to catch fluid in CT after filling backside. 05:45 - 06:30 0.75 LCR N DPRB PROD1 Pump down backside at 4 bpm to catch fluid Filled hole with 20 bbls. 2,061 ft fluid level Cir down CT. 1st Vac truck unloading in pits 06:30 - 06:50 0.33 DRILL N DPRB PROD1 Orient TF to HS to get through window. Ran thru window with 20L. 06:50 - 07:20 0.50 DRILL N DPRB PROD1 RIH to bottom 07:20 - 07:45 0.42 DRILL P PROD1 Drilling Z4 turn section. 2.710.0 bpm, full losses, 2800 psi, 110R, Drilled to 9875'. Completed build / turn section. 07:45 - 09:30 1.75 DRILL P PROD1 POH. Fill hole down backside with KCL water. Backside full of FloPro to start. Pump 1.0 bpm. No returns. 09:30 - 12:00 2.50 DRILL P PROD1 Layout MWD BHA. PJSM. Cut off 200' of coil. M/U CTC. Pull/ press test CTC. 12:00 - 12:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/1312005 12:00 - 12:15 0.25 DRILL P PROD1 mitigation for MIU MWD BHA. 12:15 - 13:30 1.25 DRILL P PROD1 MIU lateral MWD BHA #6 with 1.04 deg motor and 4.125" HCC Bi-center Bit #6. Use 11/32" orifice to help orient. OAL = 65.27'. 13:30 - 15:20 1.83 DRILL P PROD1 RIH with Lateral MWD BHA #6. Circ at 0.25 BPM while RIH. SHT at 3100 ft. No returns. Corrected to flag, -10 ft CTD. Ran thru window clean at 60R. 15:20 - 15:50 0.50 DRILL P PROD1 Log GR tie-in at window. Added 5 ft CTD. 85R at 9530'. 15:50 - 16:00 0.17 DRILL P PROD1 RIH clean to bottom. Tag at 9876'. 10L TF at bottom. Circ. 2% KCL with 4 PPB KlaGard. 16:00 - 17:30 1.50 DRILL P PROD1 Orient TF. No clicks on bottom. Pull to window. Not able to Orient. Pump down backside at 5 bpm and coil at 1 bpm 30 bbls to load well. Orient while pumping down backside at 1 bpm, No luck. Still 85R TF. RIH to bottom. Spud on bottom. Orient. No clicks. Pull up into 7" liner above window. No clicks. 17:30 - 19:10 1.67 DRILL P PROD1 POH for orienter. Flag at 8870' bit depth. POH. FL at 2000 ft from CT weight 19:10 - 19:45 0.58 DRILL P PROD1 OOH, break down orienter, found broken carbide sleeve. PU new orienter, checked bit scribe line 19:45 - 20:15 0.50 DRILL P PROD1 RIH to 3200 ft SHT MWD and orienter 20:15 - 20:25 0.17 DRILL P PROD1 SHT MWD & orienter unable to get clicks after 3 tries 20:25 - 21 :30 1.08 DRILL P PROD1 RIH. Corrected to flag at 8870 ft (-13 ft) Tried 5 times to get oriented and was unable. Called Weatherford, ordered out 2 Tomahawks Orienters. They work better in LC wells 21 :30 - 23:05 1.58 DRILL P PROD1 POOH to PU WFT orienter 23:05 - 23:45 0.67 DRILL P PROD1 Changed out orienters to WFT Tomahawk 23:45 - 00:00 0.25 DRILL P PROD1 RIH 2/14/2005 00:00 - 01 :15 1.25 DRILL P PROD1 RIH. SHT at 3200 ft unable at 3200 ft, RIH to 9100 ft Corrected to flag at 8870 ft (-9.6 ft Correction) 01 :15 - 01 :45 0.50 DRILL P PROD1 Test WFT Orienter Tried 7 times and got no clicks, tried yo-yo CT see if I can get a ckick. No luck. Called town and conversed on way forward 01 :45 - 03:00 1.25 DRILL P PROD1 POOH to FP well, blow down CT and move to DS15-8, DSM is working with electrical, instrumention and Veco to pre to pull wellhosue. 03:00 - 03:45 0.75 DRILL P PROD1 Tested orienter, got 2 clicks. Worked OK. RD drilling BHA 03:45 - 04:30 0.75 DRILL P PROD1 RU to pump MEOH down tubing and diesel down IA for freeze protection IA on vacuum. Pumped 25 bbl MEOH down wellbore. Closed SV. 04:30 - 06:00 1.50 DRILL P PROD1 Cir CT and pump 50 bbls diesel down IA to load IA with diesel. 06:00 - 09:00 3.00 DRILL N WAIT PROD1 Wind to high for rig down. 20-40 mph winds with forcast of high winds for 2 days. Decide to try another method to orient with full losses. Call for vac trucks for fluid. 09:00 - 15:00 6.00 DRILL N WAIT PROD1 Found pin of Sperry Hydrostatic Control Valve, HCV had bad 2-3/8" threads, sent it to Baker machine shop to cut new pin. Wait on tool. 15:00 - 15:45 0.75 DRILL P PROD1 M/U MWD lateral BHA with 2 orienters and HCV and 1.04 deg Printed: 2/23/2005 11:59:16AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/14/2005 15:00 - 15:45 0.75 DRILL P PROD1 motor and 4.125" HC Bi-center bit. OAL = 82.46'. 15:45 - 16:00 0.25 DRILL P PROD1 Test tools at surface, good press pulse. HCV opening at 1400 psi, stopped pump and HCV holding 1100 psi static, or 2400 ft of 8.6 ppg fluid. 16:00 - 17:45 1.75 DRILL P PROD1 RIH to 3100 ft. Test orienter. got 2 for 2 clicks, test again, got 2 for 2 clicks. Continue to RIH. Correct -12 ft at flag. RIH to 9400'. 17:45 - 18:00 0.25 DRILL P PROD1 Orient TF. one for one click [ 20 deg). orient again. one for one clicks [40 deg). 18:00 -18:10 0.17 DRILL P PROD1 Run thru window clean with 40R TF. Stop at 9532'. 18:10 -18:15 0.08 DRILL P PROD1 Orient TF to 138R. 18:15 -18:20 0.08 DRILL P PROD1 RIH to bottom. Tag at 8876'. correct to 8878'. TF = 10R. 18:20 - 18:30 0.17 DRILL P PROD1 Orient TF to 31 R. got three 10 deg clicks. 18:30 - 18:40 0.17 DRILL P PROD1 Drilling 24 Lateral. TF 53R Op = 2.59 I 0 bpm CTP = 2267 psi ROP 150 fph 18:40 - 18:50 0.17 DRILL P PROD1 100 ft wiper trip. Check hole for solids. Clean 18:50 - 19:15 0.42 DRILL P PROD1 Drilling 24 Lateral. TF 53R ROP = 100 fph. Drilled to 9,950 ft Op = 2.40 / 0 bpm CTP = 2073 psi. Building hole angle up from 84.90 deg 19:15-19:22 0.12 DRILL P PROD1 100 ft wiper trip. Check hole for solids. Clean 19:22 - 19:36 0.23 DRILL P PROD1 Drilling 24 Lateral. TF 53R ROP = 60- 100 fph. Op = 2.65/ 0 bpm CTP = 2,265 to 3,125 psi. CTP inc to 875 psi 19:36 - 20:15 0.65 DRILL P PROD1 Wiper trip to window. Pump 20 bbl Flo-Pro pill PU wt = 39k. Pp climbed 250 psi pulling through fault area. Hole seems to be filling up 200 psi motor work in Shublik shale at 9,600 ft. RIH some motor work in shale. Orient 1 clicks, 50 deg click with flo-pro in orienter 20:15 - 20:25 0.17 DRILL P PROD1 Drilling 24 Lateral. TF 100 to 90 R ROP = + 100 fph. Op = 2.69 / 0 bpm CTP = 2,950 I 3,300 psi IA pressure is climbing, indication of circulation possibilities. then fell off. 20:25 - 20:36 0.18 DRILL P PROD1 Orient TF to 90L. 45 deg clicks 20:36 - 21 :30 0.90 DRILL P PROD1 Drilling 24 Lateral. TF 106-65 L. ROP = 60 to 150 fph. Op = 2.69 / 0 bpm CTP = 2,950 I 3,300 psi. Pump 10 bbl Flo-Pro. Cycled pumps to get click @ 10,033 ft, got 45 deg Hole tries to fill up (IA pressure) while drilling, but during wiper, the IA pressure drop back. 21 :30 - 22:05 0.58 DRILL P PROD1 Wiper trip after drilling 109 ft, started 10 bbl flo-pro sweep. Clean wiper trip. 22:05 - 23:00 0.92 DRILL P PROD1 Drilling 24 Lateral. TF 65 L. ROP = +100 fph. Op = 2.69 / 0 bpm CTP = 2,950 13,100 psi. Pumped 10 bbl Flo-Pro Pill at 10,147 ft 23:00 - 23:25 0.42 DRILL P PROD1 Wiper trip after drilling 95 ft to tie-in 23:25 - 23:45 0.33 DRILL P PROD1 Tie-in starting at 9540 ft logging up (+6 ft) 23:45 - 00:00 0.25 DRILL P PROD1 RIH Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/15/2005 00:00 - 00:15 0.25 DRILL P PROD1 RIH, pump 10 bbl Flo-Pro sweep 00:15 - 00:25 0.17 P PROD1 Orient TF around to L (40 deg clicks) 00:25 - 01 :54 1.48 DRILL P PROD1 Drilling Z4 Lateral in sand I shale stringers TF48-65-121 L. ROP = 50-90 fph. Qp = 2.651 0 bpm IA CTP = 3,025/3,150 psi. Pump 20 bbl at 10,232 ft. Out at 10,250 ft Pumped 10 bbl 10,255 ft 01 :54 - 02:48 0.90 DRILL P PROD1 Wiper trip at 10290 ft IA = 59 psi, dropped off to 7 psi after wiper trip. Pump 18 bbl flo-Pro sweep down CT while TIH Clean wiper trip 02:48 - 03:00 0.20 DRILL P PROD1 Orient TF. Getting 40 deg/ clicks 03:00 - 03:46 0.77 DRILL P PROD1 Drilling Z4 Lateral TF@ 60 to 14 L. ROP = 80-150 fph. Qp = 2.68 I 0 bpm. CTP = 3,125 / 3,250 psi. With 20 bbl flo-Pro sweep out, the IA climbs from 7 to 50 psi then stablizes Pumped 16 bbl Flo-Pro sweep, sweep out at 10,374 ft. IA = 34 psi 03:46 - 04:00 0.23 DRILL P PROD1 Orient TF to 60 - 70L Orienting @ 50 deg/ click 04:00 - 04: 19 0.32 DRILL P PROD1 Drilling Z4 Lateral TF@ 6046 L. Qp = 2.64/ 0 bpm. CTP = 3,125 I 3,450 psi. Hard drilling at 10,404 ft Pumped 10 bbl sweep. Possible fault at this depth. 04:19 - 05:25 1.10 DRILL P PROD1 Wiper trip at 10,406 ft. Pump 12 bbl sweep while TIH, out at 10,120 ft. IA pressure at 50 psi following wiper trip 05:25 - 06:00 0.58 DRILL P PROD1 Drilling Z4 Lateral TF@ 43 L. Qp = 2.64 / 0 bpm. CTP = 3,325 I 3,550 psi. IA at 64 psi "best all night" Possible fault at 10,405 ft MD, ratty drilling with stalls. Pumped 10 bbl sweep, out at 10,440 ft Sweep out at 10433 ft IA pressure dropped off at 10,405 ft 06:00 - 06:10 0.17 DRILL P PROD1 Orient TF 06:10 - 07:45 1.58 DRILL P PROD1 Drilling Z4 Lateral TF@ 71 L. Qp = 2.641 0 bpm. CTP = 3,325 I 3,550 psi. Drilled to 10,551'. 07:45 - 09:00 1.25 DRILL P PROD1 Wiper trip to window. Clean trip. Circ. 20 bbl FloPro sweep. 2.7 bpm, 3000 psi, no returns. RIH clean to bottom. 09:00 - 11 :15 2.25 DRILL P PROD1 Drilling Z4 Lateral. 2.7 bpm, 3200-3800 psi, no returns, 60R, 94 deg incl, 90 fph, 42K up wt, 20K down wt. Drilled to 10,700'. Circ. 20 bbl FloPro pills. 11:15 -12:00 0.75 DRILL P PROD1 Wiper trip to window. Clean trip to window. Circ. 20 bbl FloPro pill. 12:00 - 12:15 0.25 DRILL P PROD1 Log GR tie-in at 9500'. Added 3' to CTD. 12:15 - 12:45 0.50 DRILL P PROD1 RIH clean to bottom. Tag at. No returns. Orient TF to R-Side 12:45 - 14:30 1.75 DRILL P PROD1 Drilling Z4 Lateral TF@ 10-80R. Inverted section Qp = 2.64/0 bpm. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/15/2005 12:45 - 14:30 1.75 DRILL P PROD1 CTP = 3,125 / 3,450 psi. Pump 20 bbl sweep, out at 10,758 ft. Pumped 17 bbl sweep, out 10,700 ft 14:30 - 14:45 0.25 DRILL P PROD1 Orient TF 14:45 - 15:00 0.25 DRILL P PROD1 Drilling Z4 Lateral TF@ 40R. Inverted section Qp = 2.641 0 bpm. CTP = 3,125 I 3,450 psi. 15:00-16:10 1.17 DRILL P PROD1 Wiper trip at 10,850 ft 16:10 - 16:25 0.25 DRILL P PROD1 Orient TF with high speed orienter 16:25 - 18:00 1.58 DRILL P PROD1 Drilling Z4 Lateral TF@ 90- 109 R. Qp = 2.66/ 0 bpm. CTP = 3,125 / 3,550 psi. 20 bbl sweep going out at 10,870 ft Pump 18 bbl sweep at 10,900 ft, Pumped 20 bbl sweep at 10941 ft PUH at 10,919 ft and got 1 clicks out at 10,925 ft BHA slides better with flo-pro in annulus 18:00-18:15 0.25 DRILL P PROD1 Drilling Z4 Lateral TF@ 109 R. ROP = 100 fph Qp = 2.65 / 0 bpm. CTP = 3,125 / 3,550 psi. 18:15-18:30 0.25 DRILL P PROD1 Orient TF around 18:30 - 18:50 0.33 DRILL P PROD1 Drilling Z4 Lateral TF@ 70 R. ROP = 60 fph Qp = 2.70 I 0 bpm. CTP = 3,300 / 3,550 psi. - Pumping 20 bbls flo pro sweeps every 50' drilled. 18:50 - 20:45 1.92 DRILL P PROD1 Wiper trip to window - Motor work at 10,850', 10,800', 10,560' MD. - Minimal motor work while RIH. 20:45 - 22:40 1.92 DRILL P PROD1 Drill ahead in Z4 lateral at 70 ROHS to TD at 11,110' MD - 8879' TVD - 2.61 0.0 bpm - 3200 / 3500 psi - Pumping 20 bbls flo pro sweeps every 50' drilled. 22:40 - 00:00 1.33 DRILL P PROD1 POOH. - PU 43k; SO 18k - 15k overpull at 10,900' MD, with motor work. Wipe same, flo pro at bit. - 1 Ok overpull at 10,840' MD, pulled through. - 1 Ok overpull at 10,470' MD, pulled through. 2/16/2005 00:00 - 02:00 2.00 DRILL P PROD1 Continue to POOH. - Pumping at 1.5 / 0.0 bpm @ 1700 psi. 02:00 - 04:00 2.00 DRILL P PROD1 Change out BHA. - LD one orienter. - Pick up RES - Upload to RES tool. 04:00 - 05:45 1.75 DRILL P PROD1 RIH. - Pumping at 1.5 I 0.0 bpm @ 2000 psi - SHT at 3400' MD. - RI H at 1.1 I 0.0 bpm @ 1700 psi. 05:45 - 06:45 1.00 DRILL P PROD1 Tie in to formation from 9565' MD with real time data. SD pumps and PUH through window recorded data for liner tie-in to open hole. (Corrected -6.5 ft) Qp/CTP = 2.43/ 0.0 at 2900 psi. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/16/2005 06:45 - 07:30 0.75 DRILL P PROD1 Orient TF prior to going through window 07:30 - 08:30 1.00 DRILL P PROD1 Rig Service 08:30 - 10:30 2.00 DRILL N RREP PROD1 SD, reel swivel joint is leaking, wait on new swivel kit coming in from N2 Endicott SD pump, isolate reel, fill well across top with rig Change out swivel joint. 2nd one leaked worst than 1st, Wait on repair kit for swivel #1 Installed 3rd swivel on and tested. PT to 4500 psi 10:30 - 11: 15 0.75 DRILL P PROD1 RIH, pumping flo-pro / liner pill 11:15-12:11 0.93 DRILL P PROD1 Tagged at 10,400 ft, (Fault 2) PUH orient to 58L RIH at red Qp tagged, checked orient TF at 41 L, work through tight spots at 10,403 ft, 10,405 ft, 10,410 ft. RIH to 10,430 ft, backed reamed to 10,400 ft Pulled little tight at 10,412 ft. RI H 500 psi motor work at 10,404 ft, PUH, RIH motor work at 10,404 ft 10,406 ft and 10,410 ft RIH to 10,420 ft, backed reamedcleaned up 12:11 -12:50 0.65 DRILL P PROD1 RIH, pumped another 20 bbl flo-pro to 10,887 ft PUH after CTP increased PUH clean, RIH and tagged 10,114 ft 12:50 - 13:17 0.45 DRILL P PROD1 Work CT and pump 100 bblliner pill 13:17 - 15:20 2.05 DRILL P PROD1 PUH logging with Res. tool at 12.9 fpm /762 fph and laying in liner pill 15:20 - 17:15 1.92 DRILL P PROD1 POOH to run liner 17:15 - 19:00 1.75 DRILL P PROD1 LD drilling BHA and down load Res Tool 19:00 - 19:30 0.50 DRILL P PROD1 PJSM for running liner. 19:30 - 20:45 1.25 DRILL P PROD1 MU CTC and pump dart. Coil volume 55.9 bbls. - Pull test to 40k; Pressure test to 3500 psi. 20:45 - 00:00 3.25 CASE P RUNPRD MU liner as per talley. 2/17/2005 00:00 - 01:15 1.25 CASE P RUNPRD RIH to window. - Correct -10' at the flag - At window: PU 45K; SO 28K - Pumping flo pro ahead. 01:15 - 03:30 2.25 CASE P RUNPRD Run in OH to TD. - Stack up at 10,405' MD. Attempt various pump rates and pipe speeds. Not sticking at PU. Tagging repeatedly at 10,398' MD, stacking to 10,404.6' MD. - RU to pump down backside and coil, attepting to get passed faulted area. Success! - Tag bottom at 11,109' MD. Confirm tag. 03:30 - 04: 10 0.67 CASE P RUNPRD Circulate well to KCI down coil and backside. 04:10 - 06:00 1.83 CASE P RUNPRD Insert and pump down 5/8" phenolic ball. - RBIH to 11,109' MD, 11,110' MD with 10k down. - Ball on seat at 46.5 bbls away. Shear at 3000 psi. - PU wt 35.5k Ibs. - Rigging up cementers. 06:00 - 10:30 4.50 CASE P RUNPRD Repair MP2 transducer cable. Changed out MP2 transducer Changed out pump gasket in MP 2. Qp = 1 bpm, getting required fluid inventory on location for cement job. 10:30 - 11 :00 0.50 CEMT P RUNPRD SAFETY MEETING on mixing and pumping cement and KCL transfer. 11 :00 - 11 :45 0.75 CEMT P RUNPRD Batch mixing 34 bbl cement and 35 bbl 2ppb Bio water Cement at density at 1130 hrs 11:45 - 13:00 1.25 CEMT P RUNPRD Pumped 2 bbl 2% and PT to 4500 psi. Pumped 2 bbl %KCL Loaded annulus with 24 bbl and cir well head Qa 3.5/0.5 bpm. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/1712005 11 :45 - 13:00 1.25 CEMT P RUNPRD across top Pumped 29 bb116.03 bbl cement at 2.5 bpm. Dropped dart, cleaned up cement truck. Pumped 35 bbl 2ppb bio water with DS, switch to rig. Oa = 3.54/1.08 bpm. acroos top Pumped 56.4 bbl, lWP bumped and sheared at 3800 psi. Oa = 3.54/2.02 bpm. Pumped 15.4 bbl and plug bumped, released pressure, floats held. Unstung from deployment sleeve PU weight 38k, contamient possible cement above deployment sleeve. 13:00 - 14:50 1.83 CEMT P RUNPRD POOH contaminating cement, no circulation Estimated FL at 850 ft, increase in 1425 ft of annular space, 622 psi 14:50 - 15:20 0.50 CEMT P RUNPRD lD CTlRT PU cement nozzle BHA 15:20 - 17:10 1.83 CEMT P RUNPRD RIH with nozzle BHA wo/ pumping 17:10 - 22:00 4.83 CEMT P RUNPRD Stopped at 8000 ft and WOC. - Cement at 500 psi UCA 22:00 - 22:30 0.50 CEMT P RUNPRD RU cementers. 22:30 - 22:45 0.25 CEMT P RUNPRD PJSM 22:45 - 23:30 0.75 CEMT P RUNPRD FilllA and backside with diesel, maintaining 0.2 bpm down coil. - Pressure test rig and truck lines for Hot Oilers to 4000 psi with diesel. - Open up to IA. Pump diesel at 1.5 bpm with HOT. Pump 10.5 bbls away to achieve IA pressure of 100 psi (equivalent to 200' in 9-5/8" x 4-1/2" annulus). SIIA. - RIH to 8,985' MD Oust above TOl). - Open up to backside. Pump diesel at 1.5 bpm with HOT. Positive WHP (60 psi at 1.5 bpm) at 20.4 bbls away, IA at 100 psi. - While at TOL, increase lR to 2 bpm. WHP@ 170 - IA@ 110 (total of 35 bbls pumped on backside). Bring rate up to 3 bpm. WHP @ 340 - IA @ 200 (total of 37.6 bbls). SD, IA = WHP - 40 psi. Bring rate up to 3 bpm, WHP increasing to 560 psi, IA to 360 psi (total diesel pumped = 44 bbls). Increase rate in coil to 1.25 bpm, caught fluid at 6 bbls away. Bottom of diesel at 4639' MD. - Conduct injectivity test. Pumping 2.7 bpm through coil with 1650 psi. WHP at 264 psi. IA at 174 psi. 23:30 - 00:00 0.50 CEMT P RUNPRD Batch mix cement with silica flour to 15.8 ppg at 23:40. - Decrease rate to 2.0 bpm while batch mixing. - Maintaining positive WHP with lR. Well is fluid packed. - Pressure test cement lines to 4000 psi with fresh water. 2/18/2005 00:00 - 01 :00 1.00 CEMT P RUNPRD Cement TOl. - Pump 1.5 bbls fresh water. - Little Red off line and isolated, total of 60 bbls of diesel pumped. - Pump cement at 2.4 bpm, 1250 - 2400 psi. 24 bbls away, cement over goose neck. - Total cement pumped: 31.2 bbls 15.8 ppg cement. - Pump 2 bbls fresh water. - Follow with Little Red pumping diesel at 2.5 bpm down coil. IA 115 psi, WHP 165 psi, CP 1550 psi. Pressure increasing to Printed: 2/23/2005 11:59:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/1812005 00:00 - 01 :00 1.00 CEMT P RUNPRD IA 220 psi and WHP 300 psi, CP decreasing to 600 psi. At 15 bbls cement out of nozzle, decreasing rate to 1.5 bpm. At 24 bbls cement out nozzle, decrease rate to 1.0 bpm. At 29 bbls cement away saw CP pressure increase, decrease rate to 0.5 bpm. Max pressure seen 165 psi. At 31.2 bbls cement away, shut down LR. - Total of 60 bbls diesel pumped, bottom of diesel at approx 6000' MD. - PUH 1500 feet to 7500' MD, pumping 1.5 bpm with LR with choke fully open. - Shut down pumps. 01 :00 - 07:05 6.08 CEMT P RUNPRD Wait on cement to reach 500 psi compressive strength. Comp, Strength at 0600 psi = 125 psi 07:05 - 08:30 1.42 CEMT P RUNPRD POOH to PU CO BHA, replacing CT voidage UCA on cement at 580 psi at 0805 hrs. SD LR and started KCL down CT to replace voidage. Noticed FL at 1500 ft while POOH. Pumped 25 bbl witout returns 08:30 - 10:15 1.75 CEMT P RUNPRD RIH due to underbalance possiblity with full diesel in well bore At 2,600 ft, regained circulation with diesel up the annulus. SD, SWI to check WHP OK. Open choke, RIH at min flow rate taking intermitted returns to TT 10:15 - 10:45 0.50 CEMT P RUNPRD Stopped at 8975 ft circulate out diesel with 2% KCL Circulated 65 up annulus 10:45 - 13:40 2.92 CEMT P RUNPRD POOH chasing diesel out of well. Stopped at 6,461 ft and circulated clean 2% KCL to surface. Pumped 197 bbl up the annulus, cleaned up, POOH to 4756 ft and returns are intermitted and still diesel laded. Cir diesel out, feeding diesel from from lA, POOH to above holes in 4-1/2" Fixed out MM. Density at 8.4ppg and Qp = 2.87 I 0.98 bpm, Lossing 1.9 bpm 13:40 - 14:10 0.50 CEMT P RUNPRD POOH 14:10- 14:30 0.33 CEMT P RUNPRD Check flowrates Lossing 2.98/1.08 bpm, lossing 1.81 bpm 14:30 - 17:30 3.00 CEMT P RUNPRD LD Nozzle BHA and PU 2.71" D331 DSM and straight motor with 73 jts 1-1/4" CSH 17:30 - 19:00 1.50 CEMT P RUNPRD RIH with motor and mill. 19:00 - 21 :45 2.75 CEMT P RUNPRD RIH through liner. - PU 30k - 1.7 I 0.0 bpm 2300 psi free spin - Mill cement 8995 - 9010' MD at 50 - 100 fph - Stringers at 9025, 9233, and 9253' MD - Wipe at 9300' MD. - Established partial returns at approx 10,800' MD, 1.6/0.6 bpm. - RIH to TD at 11,085' MD. 21 :45 - 00:00 2.25 CEMT P RUNPRD POOH, laying in 30 bbl Bio pill. 2/19/2005 00:00 - 02:15 2.25 CEMT P RUNPRD Drop ball to open circ sub. Stand back injector. Rack back CSH. 02:15 - 12:15 10.00 CEMT P RUNPRD Pressure test BOPE. - Grease swab and master. - Repaired Valves 3-4 - Well site leader to witness test. - John Spalding with AOGCC waived witness. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/19/2005 12:15 - 14:45 2.50 CEMT P RUNPRD Weld on CTC, Pulled test 45.5k and PT to 3600 psi Tested inner reel valve. PT lubricator to 4000 psi 14:45 - 16:30 1.75 CEMT P RUNPRD RIH, cir at well Wt check at 8973 ft = 34k RIH through 3-3/16" Liner PU wt at 9800 ft = 39.8 Ib at 65 fpm 16:30 - 17:05 0.58 CEMT P RUNPRD Start 16ppg barite 11.6 bbl slug down CT Qp = 2.12/ 0.80 bpm CTP = 1326 psi 17:05 - 17:17 0.20 CEMT P RUNPRD Pull out of liner laying in 16ppg slug. 17:17 - 18:00 0.72 CEMT P RUNPRD PUH above liner, no circulation allowing slug to gravity to go behine liner 1.78 bbl slug went behine liner once above liner, Top of slug at 8718 ft Cir at 8600 ft and took 25 bbl to fill pipe, Qp = 2.07/1.23 bpm 18:00 - 19:30 1.50 CEMT P RUNPRD RU LR HOT 19:30 - 20:00 0.50 CEMT P RUNPRD PJSM on diesel pumping and operational concerns associated with plan forward 20:00 - 22:15 2.25 CEMT P RUNPRD Bull headed 200 bbl diesel down IA Qp = 2.0 bpm Backside closed in. 22:15 - 23:30 1.25 CEMT P RUNPRD Bull headed 100 bbl diesel down CT annulus Qp = 1.5 bpm WHP increased to 890 psi. IA=785 psi 23:30 - 23:45 0.25 CEMT RUNPRD Injection Test stablized at 2.00 bpm at WHP = 800 psi IA = 700 psi 23:45 - 00:00 0.25 CEMT P RUNPRD PJSM on cement job 2/20/2005 00:00 - 00:30 0.50 CEMT P RUNPRD Batch up cement. Mixed 5 bbls neat, 15 bbls aggregate, 20 bbls neat 00:30 - 02:00 1.50 CEMT P RUNPRD Inc Qp to catch fluid, took 1 bbl, filled cement line with 3 bbl water and PT to 4000 psi Qp Volume Pumped IA WHP 2.5 50 670 750 2.5 55 746 830 2.5 60 800 900 2.5 65 857 948 1.5 68 1000 1100 1.5 71 1150 1248 1.5 75 860 960 1.0 79 780 860 1.0 82 570 650 0.5 85 460 527 0.5 89 380 439 0.5 90.5 430 500 0.5 92 400 450 PUH laying in cement 1:1 0.5 94 410 470 02:00 - 02:20 0.33 CEMT P RUNPRD PUH to safety at 7000 ft and wac 02:20 - 06:00 3.67 CEMT P RUNPRD wac Cement at 587 psi compressive strength at 09:30 hrs. 06:00 - 09:30 3.50 CEMT P RUNPRD wac till 0930 hrs, cement at 587 psi 09:30 - 09:50 0.33 CEMT P RUNPRD Lined LRHOT to PT wellhead. PT wellhead to 1411 psi for 15 minutes without pressure losses. 09:50 - 10:30 0.67 CEMT P RUNPRD Bleed pressure off, RIH and tagged at 8829 ft (hard) while Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/20/2005 09:50 - 10:30 0.67 CEMT P RUNPRD pumping at 2.00 bpm 164 ft cement and 2.5 bbl cement in liner 10:30 - 11 :30 1.00 CEMT P RUNPRD PUH chasing diesel to surface. Stopped at 3780 ft to cir 11 :30 - 12:00 0.50 CEMT P RUNPRD Circulated at 3786 ft, Density at 8.28ppg. Still diesel in fluid 12:00 - 13:00 1.00 CEMT P RUNPRD POOH, Rigged off well and walked CT OOH (no NO/GO on CTC) 13:00 - 14:15 1.25 CEMT P RUNPRD LD jetting BHA, Cut off weld-on CTC and install dippled CTC, pull and pressure tested. 14:15 - 15:45 1.50 CEMT P RUNPRD RIH with cement drilling BHA Cir at 1:1 while RIH Pumping 2 ppb Bio down CT 15:45 - 17:40 1.92 CEMT P RUNPRD Tagged at 8,829 ft Found hard cement at 8,857 ft. Drilling with 600/2,000 Ib WOB Qp = 2.67/2.74 BPM. Pumping 10 bbl Bio sweeps and PUH every 25 ft for water spacer. UCA at 1100 psi at 1615 hrs Real hard possible aggregate at 8,902 ft with 200 psi motor work Stalled at 8,956 ft. Drilled to 8,958 ft 17:40 - 19:15 1.58 CEMT P RUNPRD PUH cir well bore clean and wait on SW, SIP is backed up. 19:15 - 20:00 0.75 CEMT P RUNPRD Continue to drill cement to TaL at 8995' CTMD. 20:00 - 20:45 0.75 CEMT P RUNPRD Circulate hole clean with bio sweep to surface. - UCA at 1841 psi compressive strength. 20:45 - 21 :00 0.25 CEMT P RUNPRD Pressure test TaL to 600 psi for 15 minutes without pressure loss. 21 :00 - 22:50 1.83 CEMT P RUNPRD POOH with cleanout BHA. 22:50 - 00:00 1.17 CEMT P RUNPRD Stand back injector. POOH with BHA. - Bit stuck in Tubing hanger. - Try again, no-go. - Lay down 1 joint of PH6. - Rig up air to top of 2nd joint of PH6. - Pump through with air. RD air hose. - PUH through tubing hanger. - Lay down BHA. No evidence on bit of any cement or debris. 2/21/2005 00:00 - 01 :30 1.50 CEMT P RUNPRD MU BHA for 3-3/16" liner cleanout. MU injector. - 3.71" mill - 36 stands of CSH. 01 :30 - 02:30 1.00 CEMT P RUNPRD RIH with BHA #12, circulating minimum rate. 02:30 - 05:30 3.00 CEMT P RUNPRD At TOL, bring rate up to 1.6 bpm 11800 psi with full returns. PU 35k; SO 17k. Tag at 8,992' MD. Milling cement at 60 fph for l' at TOL. RIH through liner slow at 5 fpm, circulating pill out of hole. Short trip at 9600'MD. RBIH. Continue cleanout, pumping bio sweeps. Tag TD at 11,080.5' CTMD. 05:30 - 10:30 5.00 CEMT N WAIT RUNPRD Waiting on trucks. Worked mill from 11,080 to 8,900 ft and pumped 20 bbl Bio pill followed with 10 bbl fresh 2%KCL, 20 bbl Bleach and 10 bbl fresh 2% KCL. 10:30 - 10:45 0.25 CEMT P RUNPRD PJSM on bleach handling and correct PPE be worn by operators 10:45 - 11:30 0.75 CEMT P RUNPRD Pumped 25 bbl fresh 2%KCL, 19 bbl Bleach and 10 bbl fresh 2% KCL. Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/2112005 11 :30 - 12:05 0.58 CEMT P RUNPRD POOH laying in 20 bbl bleach @ 1:1 PUH to 8,800 ft 12:05 - 13:13 1.13 CEMT P RUNPRD Dropped 5/8" ball and chase with 10 bbl biozan pill and clean 2% KCL. Open CS at 2600 psi, inc Qp to 2.5 bpm 13:13 - 14:20 1.12 CEMT P RUNPRD POOH chasing clean fluid to surface 14:20 - 15:45 1.42 CEMT P RUNPRD POOH and stand back 72 jts of 1-1/4" CSH 15:45 - 16:00 0.25 CEMT P RUNPRD SAFETY MEETTING I PJSM on conducting Eline operations 16:00 - 16:30 0.50 EV AL P LOWER1 RU SLB Eline to run SCMT Log 16:30 - 20:40 4.17 EVAL P LOWER1 RIH and logging with SCMT Tool Stopped at 9600 ft Good bond at window and free pipe near top of liner. POOH. RD SLB Eline. OFF CRITICAL PATH: - Clean pits. - Fill coil with clean KCI - Line up for pressure test. 20:40 - 21 :35 0.92 CEMT P RUNPRD Bring pumps on line to ramp up pressure slowly to 3000 psi. IA pressure tracking Tubing pressure with 200 psi differential. Allow pressure to stabilize at 3000 psi prior to initiating test. TIIME PRESS DELTA IA PSI DELTA 0 3000 3190 5 2970 30 3170 20 10 2952 18 3154 16 15 2944 8 3147 7 20 2937 7 3140 7 25 2930 7 3134 6 30 2926 4 3130 4 Good test. Bleed off pressure slowly. 21 :35 - 23:00 1.42 PERFOB P LOWER1 PJSM. New perforating hand. MU 12 perf guns. 23:00 - 23:45 0.75 PERFOB P LOWER1 Make up 32 stands of CSH. PU injector. 2/22/2005 00:00 - 01 :30 1.50 PERFOB P LOWER1 RIH with perf guns. Tag TD at 11,074' MD. 01 :30 - 02:30 1.00 PERFOB P LOWER1 Perforate liner on the fly. - Pump 10 bbls of bleach and 1/2" aluminum ball. - 2.3 bpm, 3700 psi - Slow pumps at 42 bbls away to 0.75 bpm I 500 psi. - Ball on seat at 53 bblsw away. - Slow rate to 0.5 bpm, pressure increasing as PUH with coil at 4fpm. - Shots fired at 11,070.5' MD at 2600 psi. - Loss approximately 6 bbls to formation. 02:30 - 03:30 1.00 PERFOB P LOWER1 POOH in liner at 30 fpm replacing voidage holding 350 psi backpressure. 03:30 - 04:00 0.50 PERFOB P LOWER1 Open well and flow check at top of liner. Took 1.5 bbls to catch fluid. 04:00 - 05:00 1.00 PERFOB P LOWER1 POOH with guns. - Pump at 1.17/ 0.5 bpm at 1200 psi, holding 300 psi back pressure. 05:00 - 05:30 0.50 PERFOB P LOWER1 Flow check at surface. 05:30 - 08:30 3.00 PERFOB P LOWER1 Lay down CSH (32 stands). 08:30 - 09:00 0.50 PERFOB P LOWER1 SAFETY MEETING Handling perf guns Printed: 2/23/2005 11 :59: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-10 Y-10 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/22/2004 Rig Release: 2/22/2005 Rig Number: 1 Spud Date: 7/5/1981 End: 2/22/2005 2/22/2005 09:00 - 10:15 1.25 PERfOB P LOWER1 LD 12 perf guns. Columbia Drive System is on location looking at ways to lower reel without usage of crane 10:15-10:25 0.17 WHSUR P POST RU LR to fluid pack. PT LR pumps & Lines to 3500 psi 10:25 - 11 :45 1.33 WHSUR P POST fluid pack the tubing using 35 bbl diesel Qp= 0.75 bpm at 1970 psi (IA 1964 psi) with 35 bbl diesel in tubing SD and switch to IA. Pressure dropped 1000 psi in 5 minutes Pumped 20 bbl diesel down IA at 0.75 bpm at 1835 psi (stable) 11 :45 - 12:08 0.38 WHSUR P POST SWI at IA & MV (23.5 turns) Bleed pressure down and RD LR HOT 12:08 - 13:20 1.20 WHSUR P POST RU and Blow down reel. - 326 total gallons used. 13:20 - 15:30 2.17 WHSUR P POST ND goose neck and injector. Basic rig down for derrick down move. Ready location for RDMO. 15:30 - 18:00 2.50 WHSUR P POST ND BOPE. NU and test tree cap to 4000 psi. Cleaning out pits RIG RELEASE AT 18:00 HRS. Printed: 2/23/2005 11 :59: 16 AM . . Y -1 OA Prudhoe Bay Unit 50-029-20587-01-00 204-250 Accept: Spud: Release: Ri: POST RIG WORK 03/19/05 RIH WI D&D TOOL PRESSURE TEST AT 3180' SLM TO 1000 PSI. 03/20/05 RUN DUMMY PATCH TO 4000' SLM. 03/21/05 RAN 4.5 X-LINE TO X NIPPLE FOR CORR (SEE LOG). RAN 4 1/2" D&D HOLEFINDER. MADE MULTIPLE STOPS & MULTIPLE RUNS. ALL CMIT'S & MIT-T'S FAILED. SUSPECT TOOL FAILURE. 03/24/05 SET 4.5" XX TIP AT 8833' SLM. DEFINITI E Halliburton Sperry-Sun North Slope Alaska BPXA Y-10A . Job No. AKMW3530513, Surveyed: 15 February, 2005 Survey Report 1 March, 2005 Your Ref: API 500292058701 Surface Coordinates: 5948841.49 N, 644611.01 E (70016' 03.5907" N, 148049' 50.1394" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 85.70ft above Mean Sea Level 5peu-''-'y-5UI'''''! CRI,LL.tNG seRVices A Halliburton Company Survey Ref: svy4495 Halliburton Sperry-Sun Survey Report for Y-10A Your Ref: API 500292058701 Job No. AKMW3530513, Surveyed: 15 February, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (e/100ft) 9400.00 17.620 297.610 8702.90 8788.60 485.74 N 2564.33 W 5949277.88 N 642037.82 E -1917.27 Tie On Point MWD Magnetic 9503.00 16.820 296.260 8801.28 8886.98 499.56 N 2591.51 W 5949291.17 N 642010.38 E 0.868 -1933.00 Window Point 9532.68 22.410 313.000 8829.25 8914.95 505.33 N 2599.51 W 5949296.79 N 642002.27 E 26.533 -1936.73 9563.98 33.490 331.000 8856.90 8942.60 517.01 N 2608.11 W 5949308.30 N 641993.45 E 44.143 -1937.83 . 9593.11 42.100 347.000 8879.96 8965.66 533.62 N 2614.22 W 5949324.79 N 641987.02 E 44.602 -1934.21 9622.73 55.700 353.320 8899.39 8985.09 555.56 N 2617.90 W 5949346.66 N 641982.92 E 48.607 -1925.70 9654.22 68.640 359.320 8914.07 8999.77 583.28 N 2619.60 W 5949374.34 N 641980.69 E 44.387 -1912.45 9685.22 80.680 5.470 8922.27 9007.97 613.08 N 2618.30 W 5949404.15 N 641981.41 E 43.276 -1895.57 9719.68 91.050 16.370 8924.76 9010.46 646.72 N 2611.79 W 5949437.92 N 641987.28 E 43.567 -1872.21 9762.92 93.690 34.120 8922.95 9008.65 685.64 N 2593.45 W 5949477.19 N 642004.87 E 41 .463 -1836.03 9797.12 90.260 49.420 8921.77 9007.47 711.05 N 2570.75 W 5949503.03 N 642027.08 E 45.815 -1803.32 9834.23 86.310 61.720 8922.88 9008.58 731.98 N 2540.22 W 5949524.54 N 642057.20 E 34.791 -1766.33 9874.63 84.900 75.610 8925.99 9011.69 746.61 N 2502.79 W 5949539.88 N 642094.34 E 34.456 -1726.85 9907.02 87.010 80.180 8928.28 9013.98 753.38 N 2471.21 W 5949547.26 N 642125.78 E 15.508 -1696.48 9939.17 89.210 82.640 8929.34 9015.04 758.18 N 2439.44 W 5949552.66 N 642157.45 E 10.262 -1666.99 9970.58 90.970 89.490 8929.29 9014.99 760.33 N 2408.13 W 5949555.42 N 642188.72 E 22.516 -1639.29 10002.02 90.180 92.130 8928.98 9014.68 759.89 N 2376.69 W 5949555.58 N 642220.16 E 8.764 -1612.87 10036.66 88.590 87.210 8929.35 9015.05 760.09 N 2342.07 W 5949556.44 N 642254.77 E 14.925 -1583.40 10070.00 88.330 87.740 8930.24 9015.94 761.55 N 2308.77 W 5949558.55 N 642288.03 E 1.770 -1554.39 10110.30 89.030 80.700 8931.17 9016.87 765.61 N 2268.71 W 5949563.37 N 642328.01 E 17.550 -1518.27 10143.63 90.090 81.760 8931 .43 9017.13 770.69 N 2235.78 W 5949569.09 N 642360.84 E 4.498 -1487.64 . 10173.46 90.970 79.120 8931.15 9016.85 775.64 N 2206.36 W 5949574.61 N 642390.15 E 9.328 -1460.07 10203.73 90.610 75.780 8930.74 9016.44 782.22 N 2176.83 W 5949581.75 N 642419.56 E 11.097 -1431.54 10237.41 91.670 74.550 8930.07 9015.77 790.84 N 2144.28 W 5949590.99 N 642451.94 E 4.820 -1399.37 10268.44 87.890 73.670 8930.18 9015.88 799.34 N 2114.44 W 5949600.06 N 642481.61 E 12.507 -1369.56 10298.53 86.920 67.700 8931.55 9017.25 809.27 N 2086.08 W 5949610.54 N 642509.77 E 20.080 -1340.25 10329.97 87.270 68.220 8933.14 9018.84 821.06 N 2056.98 W 5949622.88 N 642538.64 E 1.992 -1309.32 10362.82 89.380 69.450 8934.10 9019.80 832.91 N 2026.36 W 5949635.32 N 642569.02 E 7.434 -1277.08 10393.47 90.530 66.820 8934.13 9019.83 844.32 N 1997.92 W 5949647.28 N 642597.24 E 9.365 -1246.91 10437.80 91.580 62.950 8933.31 9019.01 863.13 N 1957.79 W 5949666.85 N 642637.00 E 9.044 -1202.91 10468.91 91.670 58.560 8932.43 9018.13 878.32 N 1930.67 W 5949682.56 N 642663.83 E 14.109 -1171.86 1 0501.16 92.550 55.740 8931.24 9016.94 895.80 N 1903.59 W 5949700.56 N 642690.56 E 9.154 -1139.64 10534.85 92.720 52.580 8929.69 9015.39 915.50 N 1876.32 W 5949720.78 N 642717.45 E 9.383 -1106.06 10570.22 92.640 51.000 8928.04 9013.74 937.36 N 1848.55 W 5949743.16 N 642744.79 E 4.468 -1070.94 10610.79 91.850 48.360 8926.45 9012.15 963.58 N 1817.65 W 5949769.98 N 642775.19 E 6.788 -1030.83 1 March, 2005 - 16:56 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Y-10A Your Ref: API 500292058701 Job No. AKMW3530513, Surveyed: 15 February, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 10654.55 92.720 45.720 8924.70 9010.40 993.38 N 1785.65 W 5949800.38 N 642806.60 E 6.347 -987.91 10686.79 94.220 46.780 8922.75 9008.45 1015.63N 1762.41 W 5949823.08 N 642829.42 E 5.694 -956.40 10717.66 94.750 50.470 8920.34 9006.04 1035.97 N 1739.32 W 5949843.86 N 642852.11 E 12.040 -926.04 10764.22 95.980 52.930 8915.98 9001.68 1064.70 N 1702.94 W 5949873.28 N 642887.93 E 5.886 -879.97 10805.09 95.100 59.260 8912.03 8997.73 1087.38 N 1669.20 W 5949896.60 N 642921.23 E 15.565 -839.34 . 10838.37 94.130 63.130 8909.35 8995.05 1103.36 N 1640.14 W 5949913.14 N 642949.98 E 11.952 -806.22 10887.29 97.820 63.300 8904.26 8989.96 1125.28 N 1596.71 W 5949935.89 N 642992.98 E 7.551 -757.78 10915.30 98.440 69.450 8900.30 8986.00 1136.39 N 1571.32 W 5949947.48 N 643018.15 E 21.848 -730.36 10945.56 97.210 68.220 8896.18 8981.88 1147.21 N 1543.36 W 5949958.84 N 643045.89 E 5.722 -700.92 10974.91 96.330 69.810 8892.72 8978.42 1157.65N 1516.15 W 5949969.80 N 643072.90 E 6.159 -672.31 11006.05 96.850 75.610 8889.14 8974.84 1166.84 N 1486.63 W 5949979.55 N 643102.24 E 18.578 -642.40 11036.46 96.850 76.660 8885.51 8971.21 1174.07N 1457.32 W 5949987.35 N 643131.41 E 3.428 -613.71 11066.66 95.980 78.770 8882.14 8967.84 1180.46 N 1427.99 W 5949994.30 N 643160.60 E 7.517 -585.46 11087.30 93.340 80.530 8880.46 8966.16 1184.15 N 1407.76 W 5949998.38 N 643180.76 E 15.356 -566.34 11114.00 93.340 80.530 8878.91 8964.61 1188.54 N 1381.47W 5950003.27 N 643206.96 E 0.000 -541.72 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 58.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11114.00ft., The Bottom Hole Displacement is 1822.38ft., in the Direction of 310.7070 (True). . 1 March, 2005·16:56 Page 3 of 4 Dril/Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Y-10A Your Ref: API 500292058701 Job No. AKMW3530513, Surveyed: 15 February, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9400.00 9503.00 11114.00 8788.60 8886.98 8964.61 485.74 N 499.56 N 1188.54 N 2564.33 W 2591.51 W 1381.47 W Tie On Point Window Point Projected Survey . Survey toolproqram for Y-10A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9400.00 0.00 9400.00 8788.60 11114.00 8788.60 BP High Accuracy Gyro - Boss Gyro (Y-1 0) 8964.61 MWD Magnetic (Y-10A) . 1 March, 2005 - 16:56 Page 4 of 4 DrillQuest 3.03.06.008 72#, ID HES ..... ..... ..... .... .. I I COMMENTS NOTE MSE BMH BP ( ObP . Baker Hughes INTEQ . Baker Hughes INTEQ Survey Report _íi. BAKa IIIUGIIU INTEQ Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe E!ç¡y PB Y Pad Y-10 Y-10A Date: 3/18/2005 Time: 15:44:14 Page: 1 ClHlrdinate(NE) Referençe: Well: Y-10, True North Vertical (fVD) Referencè: 14: 107/5/1981 00:0085.7 Section (VS) Reference: Well (0.00N,0.00E,58.00Azi) Survey CaleulatiollMethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: 0.041 N 18.991 W True 1.12 deg Well: Y-10 Slot Name: 10 Y-10 Well Position: +N/-S 361.57 ft Northing: 5948841.49 ft Latitude: 70 16 3.591 N +E1-W-3131.46 ft Easting : 644611.01 ft Longitude: 148 49 50.139 W Position Uncertainty: 0.00 ft Wellpath: Y-10A 500292058701 Current Datum: 14: 107/5/1981 00:00 Magnetic Data: 12/9/2004 Field Strength: 57616 nT Vertical Section: Depth From (fVD) ft 36.70 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Y-10 9400.00 ft Mean Sea Level 24.89 deg 80.81 deg Direction deg 58.00 Height 85.70 ft Survey Program for Definitive Wellpath Date: 12/9/2004 Validated: Yes Actual From To Survey ft ft 100.00 9400.00 9503.00 11087.30 Version: Toolcode 4 Tool Name 1: Sperry-Sun BOSS gyro multi (100.00-10~YRO MWD (9503.00-11087.30) MWD Sperry-Sun BOSS gyro multishot MWD - Standard Annotation 9503.00 9532.68 9563.98 9593.11 11114.00 8886.98 8914.95 8942.60 8965.66 0.00 KOP- Top of Whipstock Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Projection to TD Survey: MWD Start Date: 2/12/2005 Company: Tool: MWD:MWD - Standard Engineer: Tied-to: From: Definitive Path ;z. () ,·-4 -  ~- (j . ObP . Baker Hughes INTEQ . Biíí. BAJCD IIIIGIIH Baker Hughes INTEQ Survey Report I.NTEQ Company: BP Amoco Date: 3/18/2005 Time: 15:44:14 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y.10, True North Site: PB Y Pad Vertical (TVD)Reference: 14 :10 7/5/1981 00:0085.7 Well: Y-10 Section (VS) Reference: Well (0.00N,O.00E,58.00Azi) Wellpath: Y-10A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/10Qft 9400.00 17.62 297.61 8788.60 8702.90 485.83 -2564.36 5949277.93 642037.98 -1917.25 0.00 MWD 9503.00 16.82 296.26 8886.98 8801.28 499.64 -2591.54 5949291.22 642010.54 -1932.98 0.87 MWD 9532.68 22.41 313.00 8914.95 8829.25 505.41 -2599.54 5949296.84 642002.43 -1936.71 26.53 MWD 9563.98 33.49 331.00 8942.60 8856.90 517.09 -2608.13 5949308.35 641993.62 -1937.81 44.14 MWD 9593.11 42.10 347.00 8965.66 8879.96 533.71 -2614.25 5949324.84 641987.18 -1934.19 44.60 MWD 9622.73 55.70 353.32 8985.09 8899.39 555.65 -2617.93 5949346.71 641983.09 -1925.68 48.61 MWD 9654.22 68.64 359.32 8999.77 8914.07 583.37 -2619.62 5949374.38 641980.86 -1912.43 44.39 MWD 9685.22 80.68 5.47 9007.97 8922.27 613.16 -2618.33 5949404.20 641981.58 -1895.55 43.28 MWD 9719.68 91.05 16.37 9010.46 8924.76 646.81 -2611.82 5949437.96 641987.45 -1872.19 43.57 MWD 9762.92 93.69 34.12 9008.65 8922.95 685.73 -2593.47 5949477.22 642005.04 -1836.01 41.46 MWD 9797.12 90.26 49.42 9007.47 8921.77 711.14 -2570.77 5949503.06 642027.24 -1803.29 45.81 MWD 9834.23 86.31 61.72 9008.58 8922.88 732.07 -2540.25 5949524.57 642057.36 -1766.31 34.79 MWD 9874.63 84.90 75.61 9011.69 8925.99 746.69 -2502.82 5949539.91 642094.50 -1726.83 34.46 MWD 9907.02 87.01 80.18 9013.98 8928.28 753.46 -2471.24 5949547.29 642125.94 -1696.46 15.51 MWD 9939.17 89.21 82.64 9015.04 8929.34 758.26 -2439.47 5949552.70 642157.61 -1666.97 10.26 MWD 9970.58 90.97 89.49 9014.99 8929.29 760.42 -2408.16 5949555.45 642188.87 -1639.27 22.52 MWD 10002.02 90.18 92.13 9014.68 8928.98 759.97 -2376.72 5949555.61 642220.31 -1612.85 8.76 MWD 10036.66 88.59 87.21 9015.05 8929.35 760.17 -2342.10 5949556.47 642254.92 -1583.38 14.93 MWD 10070.00 88.33 87.74 9015.94 8930.24 761.64 -2308.80 5949558.58 642288.18 -1554.37 1.77 MWD 10110.30 89.03 80.70 9016.87 8931.17 765.69 -2268.74 5949563.41 642328.15 -1518.25 17.55 MWD 10143.63 90.09 81.76 9017.13 8931.43 770.78 -2235.80 5949569.12 642360.98 -1487.62 4.50 MWD 10173.46 90.97 79.12 9016.85 8931.15 775.73 -2206.39 5949574.64 642390.29 -1460.05 9.33 MWD 10203.73 90.61 75.78 9016.44 8930.74 782.30 -2176.85 5949581.78 642419.69 -1431.52 11.10 MWD 10237.41 91.67 74.55 9015.77 8930.07 790.93 -2144.30 5949591.02 642452.07 -1399.35 4.82 MWD 10268.44 87.89 73.67 9015.88 8930.18 799.42 -2114.47 5949600.09 642481.74 -1369.54 12.51 MWD 10298.53 86.92 67.70 9017.25 8931.55 809.36 -2086.11 5949610.57 642509.89 -1340.23 20.08 MWD 10329.97 87.27 68.22 9018.84 8933.14 821.14 -2057.01 5949622.90 642538.76 -1309.30 1.99 MWD 10362.82 89.38 69.45 9019.80 8934.10 832.99 -2026.39 5949635.34 642569.15 -1277.05 7.43 MWD 10393.47 90.53 66.82 9019.83 8934.13 844.41 -1997.95 5949647.30 642597.36 -1246.89 9.37 MWD 10437.80 91.58 62.95 9019.01 8933.31 863.22 -1957.82 5949666.87 642637.12 -1202.89 9.04 MWD 10468.91 91.67 58.56 9018.13 8932.43 878.40 -1930.69 5949682.58 642663.94 -1171.84 14.11 MWD 10501.16 92.55 55.74 9016.94 8931.24 895.88 -1903.62 5949700.58 642690.67 -1139.62 9.15 MWD 10534.85 92.72 52.58 9015.39 8929.69 915.59 -1876.34 5949720.80 642717.57 -1106.04 9.38 MWD 10570.22 92.64 51.00 9013.74 8928.04 937.44 -1848.58 5949743.18 642744.90 -1070.92 4.47 MWD 10610.79 91.85 48.36 9012.15 8926.45 963.67 -1817.68 5949769.99 642775.29 -1030.81 6.79 MWD 10654.55 92.72 45.72 9010.40 8924.70 993.46 -1785.68 5949800.40 642806.71 -987.89 6.35 MWD 10686.79 94.22 46.78 9008.45 8922.75 1015.72 -1762.44 5949823.09 642829.52 -956.38 5.69 MWD 10717.66 94.75 50.47 9006.04 8920.34 1036.06 -1739.35 5949843.87 642852.21 -926.02 12.04 MWD 10764.22 95.98 52.93 9001.68 8915.98 1064.78 -1702.97 5949873.29 642888.03 -879.95 5.89 MWD 10805.09 95.10 59.26 8997.73 8912.03 1087.46 -1669.23 5949896.61 642921.33 -839.32 15.57 MWD 10838.37 94.13 63.13 8995.05 8909.35 1103.44 -1640.16 5949913.14 642950.07 -806.20 11.95 MWD 10887.29 97.82 63.30 8989.96 8904.26 1125.36 -1596.74 5949935.89 642993.07 -757.76 7.55 MWD 10915.30 98.44 69.45 8986.00 8900.30 1136.47 -1571.35 5949947.48 643018.24 -730.34 21.85 MWD 10945.56 97.21 68.22 8981.88 8896.18 1147.30 -1543.39 5949958.84 643045.98 -700.90 5.72 MWD 10974.91 96.33 69.81 8978.42 8892.72 1157.73 -1516.18 5949969.80 643072.98 -672.29 6.16 MWD 11006.05 96.85 75.61 8974.84 8889.14 1166.92 -1486.66 5949979.55 643102.32 -642.38 18.58 MWD 11036.46 96.85 76.66 8971.21 8885.51 1174.16 -1457.34 5949987.35 643131.49 -613.69 3.43 MWD 11066.66 95.98 78.77 8967.84 8882.14 1180.54 -1428.02 5949994.30 643160.68 -585.44 7.52 MWD 11087.30 93.34 80.53 8966.16 8880.46 1184.24 -1407.79 5949998.38 643180.84 -566.32 15.36 MWD . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well Y-10A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,400.00' MD 9,503.00' MD 11,114.00' MD (if applicable) 05-Mar-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date l c¡ ~ .tL~t;- Signed tlN-J ~j Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) é). ~4 - ^ ~._~ 23/8" TIW Valve Falilure on 2/4/05 BOP test on Y-lOa Have replaced valve and tested it to 300j3500psi. Regards Chuck «NORDIC 1 BOP 2-4-2005 .xls» Content-Description: NORDIC 1 BOP 2-4-2005 .xIs 1 BOP 2-4-2005 .xls Content-Type: appIication/vnd.ms-exceI Content-Encoding: base64 1 of 1 2/8/2005 10:34 AM · STATE OF ALASKA . OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: llL1J...r~.9iJ.@ªiJ.rni.Q.'.~Aª.t§!ÆLtUE~ aoncc _P¡lH:!hoe _ bay@admin.stale.ak.us bob_fleGkenst.e¡n@adrnir¡.state.ak.lJs Rig No.: 1 DATE: 2/4/05 Rig Phone: 659-4434 Rig Fax: 659-4434 Op. Phone: 659-4433 Op. Fax: 659-4266 E-Mail NSU,ADW Drlg.Nordic 1 Supervisor PTD # 204-250 Meridian: UM Township: 11 N Range: 13E Workover: Explor.: Weekly: Other: Annular: 250 1 2500 Valves: 250 I 3500 TEST DATA FLOOR SAFETY VALVES: P/F Quantity P/F P Upper Kelly N/A P Lower Kelly N/A P Ball Type 1 Inside BOP N/A Contractor: Nordic I SLB Rig Rep.: VANRAY/MUNIZ Operator: BPX Rep.: WHITLOW) LAULE Well Name: Y-10A Location: Section: 33 Operation: Drlg: X Test: Initial: X Test Pressure: Rams: 250 I 3500 MISC. INSPECTIONS: P/F P P P P Location Gen.: Housekeeping: PTD On Location Standing Order Posted Well Sign Dr!. Rig Hazard Sec. F/P BOP STACK: Quantity Size/Type P/F MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank N/A Annular Preventer 1 71/16 I 5000 P Pit Level Indicators Yes P #1 Rams 1 2 3/8comb P Flow Indicator N/A #2 Rams 1 blind/shear P Meth Gas Detector Yes P #3 Rams 1 2718 vari P H2S Gas Detector Yes P #4 Rams 1 2 3/8 comb P #5 Rams N/A Quantity P/F Choke Ln. Valves 1 3 1/8 I 5000 P Inside Reel valves 1 P HCR Valves 1 3 1/8 I 5000 P Kill Line Valves 2 21/16 I 5000 P ACCUMULATOR SYSTEM: Check Valve 1 21/16 I 5000 P Time/Pressure P/F System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1950 P Quantity P/F 200 psi Attained 23sec P No. Valves 15 P Full Pressure Attained 1 min56sec P Manual Chokes 1 P Blind Switch Covers: All stations P Hydraulic Chokes 1 P Nitgn. Bottles (avg): .;¿.@l.§.§.Q P Test Results Number of Failures: 1 Test Time: -ª Hours Components tested 32 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: llm...mJJiJ.@ªiJ.rnjn.'.~Aª-t.E:H!.h!.~t~~ remarks WILL REBUILD AND RETEST 2318 TIW VALVE Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector YES 24 HOUR NOTICE GIVEN YES NO Date Waived By CHUCK SHEVE 2/3/04 Time Witness Test start 1500 Finish 0130 Coil Tubing BFL 05/29/03 0900 2005-0204_BOP _Nordic1_PBU_ Y-1 OA.xls . ~~!Æ~E lIDF !Æ~!Æ~~~!Æ . ~",ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Y-I0A BP Exploration (Alaska) Inc. Permit No: 204-250 Surface Location: 1410' SNL, 205' WEL, SEe. 33, TIIN, R13E, UM Bottomhole Location: 159' SNL, 1531' WEL, SEC. 33, TIIN, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. P e provide at least twenty-four (24) hours notice for a representative of the Commissio 0 wit\ess any required test. Contact the Commission's petroleum field inspector a . ~. - , (pz-ger). mc/'/) ( '~A orm'át\... Chairman ,., DATED this~ day of December, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. o Drill IBI Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1410' SNL, 205' WEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 915' SNL, 2788' WEL, SEC. 33, T11 N, R13E, UM Total Depth: 159' SNL, 1531' WEL, SEC. 33, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-644611 y- 5948841 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 9520 feet Maximum Hole Angle: 95 degrees J . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory 0 Development Oil 0 Multiple Zone o Stratigraphic Test IBI Service /' 0 Development Gas 0 Single Zone 5. Bond: IHI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 Y-10A / I tho 6. Proposed Depth: 12. Field I Pool(s): MD 11180 TVD 8896ss Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028287 VJ 61\. /l··1 l. 7{2oo1 8. Land Use Permit: 9. Acres in Property: 2560 13. Approximate Spud Date: i January 4, 200/.) )~ 14. Distance to Nearest Property: 15400' 18. Casing Program: Size Casing 3-3/16" 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 86.59' feet 960' to Y-30 at 10958' 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3117 Surface: 2204 ~c Setting··~Þ~hi... QI..I~o~ity Top ...... . . ..·.·i·SottQrn (cJ. or MD TVD MD TVD (includinQ staQe data) 8990' 8315' 11180' 8896' 129 cu ft ~r..~G' .CtIVI:::D DEC 1 ¡ 20 , .. . . .. .. . . ..... Alask~pil&. ..iI .. 04 PRESENT WELLCöNDITION SUMMAf3.Y(To be completed for ReqrillANPRe"7entry oper~tic>nÞ~~ª",.110.· .. Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD (ftmiCh;,Ðb~me~§fon 10275 9638 None 10224 9588' I 10120 MD Hole 3-3/4" x WeiQht 6.2# Specifications Grade Coupling LenQth L-80 TCII 2190' Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2709' 13-3/8" 3720 cu ft Permafrost II 2709' 2709' Intermediate 9464' 9-5/8" 1270 cu ft Class 'G', 130 cu ft PF 'c' 9464' 8850' Production Liner 1285' 7" 336 cu ft Class 'G' 8985' - 10270' 8396' - 9633' 20. Attachments IHI Filing Fee, $100 IHI BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8859' - 9055' IHI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IHI Drilling Fluid Program 1H120 MC 25.050 Requirements Perforation Depth MD (ft): 9474' - 9678' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Title CT Drilling Engineer Date: Contact Mary Endacott, 564-4388 Phone 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Permit Approval / Number:.z.. <Y7 - 2..';0 50- 029-20587-01-00 Date: /..,;?¡;?-&/v' Conditions of APProV~I: Sam s Required 0 Yes )š"No Mud Log Req. uired. H rog n Sulfide Measures ~Yes [J t;Jo ,Directional Survey Required Other: T~ s t /SOP' ŠC;OO p{.; . MIT, UrvL't..·\.J· ~t,U,{ .'f¡ ¡vel rPttA.A..'N" J ' //:, J (/ r¡. APPROVED BY Approved v: 0 R I G I N A L THE COMMISSION Form 10-40 R · ! ,/{¡y (f<fj[JrlS See cover letter for other requirements o Yes ~NO ~Yes 0 No ~!s~~~~ ~'" '~'" . . BP Y-IOAi Sidetrack Mud Program: · Pre CTD: 813 8.9 ppg brine · CTD: 8.5 (~ ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3 3/16" cemented liner completion 8,990' }!?J.0' . · The l!ner c~ment volume!s planned to be~.yt>bls of 15.8 ppg class G for top of cement at top liner. Casm2ILmer Information '.J 33/16" L-80 TCII, 6.2#, Burst 8520 psi; collapse 7660 psi (Hole size 41/8") / Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. ~ · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 96deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property 15,400ft · Distance to nearest well within pool 950ft to Y -30Ll at 10,958' Logging · MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. Hazards · Y pad is 2!.Q!, designated as an H2S pad. Maximum recorded H2S on the pad was 120 ppm from Y- .....- 30L1 2/8/04. Y-lO is an injector, so H2S levels are not monitored. Based on high WC producers on Y Pad, H2S is likely present and will be assumed to be high by the drilling team. All H2S monitoring equipment will be operational. · Two fault crossings are anticipated. Lost circulation risk is considered "medium". KOP is in Sag River, Shublik will be drilled in which offset wells experienced manageable losses. Reservoir Pressure · Res. press. is estimated to be 3117 psi at 8873'ss (6.7 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2204 psi. / =--1 ~ ~ . TREE = WElLHEAD = Þ:CTUA. TÖR~~ " A_A'___'~ U KB. ELEV = , ^~~..,,', "" ~~"''',' un .0. .~,.~^'''_m .',A_A' BF ELEV = RöP:;;~-~m"~_" ^~M .__,,~~~"."'__ _F\i1~~ng.~:m. 33 Datum MD = Datum TVD = 4"0/11 GRAY ~ÃXËlSÓN ~.~om.~n" '" ~" 85.69' 51.59' 3360' 6800' 9502' 8800' SS Y-10 13-3/8" CSG, 72#, L-80, 10 = 12.347 H 2708' z I Minimum ID = 3.725" @ 9012' I 4-1/2" HES XN NIPPLE ::g I TOP OF 7" LNR H 8985' 'I - 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 9038' -- 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 9464' PERFORATION SUMMI\RY REF LOG: CBL ON 07/21/81 ANGLEATTOP ÆRF: 18 @ 9474' i'bte: Refer to A"oduction DB for historical perf data SIZE SA" NTERVAL Opn/Sqz DATE 3-318" 4 9474 - 9484 0 06/15/89 3-118" 4 9484-9494 0 10/10/86 3-318" 4 9494 - 9498 0 06/15/89 2-718" 4 9580- 9638 0 02/20/86 3-118" 4 9638-9658 0 10/10/86 3-318" 4 9658 - 9678 0 06/15/89 ---I ~ ---I . SAFETY NOTES: OVERSHOT GUIDE COVERS CUT STUB. SEETB..EX FOR DETAILS. ***T X IA COMM. (02107/03 WAIVER.)"* 2182' H4-1/2" HES X NIP, D = 3.813" I 2574' H9-Sl8" DV PKR I 8832' 8843' 8867' 8888' 1-14-1/2" HES X NP, ID = 3.813" I H9-5/8" x 4-1/2" TIW HBBP- T PKR, ID = 3.90" ~4-1/2" HES X NP, ID = 3.813" I H4-1/2" HES X NP, ID= 3.813" I ~: 8907' ~ OV ERSHOT GUIDE FOR ClJf STlJ3, ID = 4.55" 8915' HBAKER 1BG SEAL ASSY I Z"--I 8935' ~9-5/8" x 4-1/2" BKR PKR, ID = 4.000" I I 8979' ~4-1/2" HES X NP, ID = 3.813" I - ï. I 9012' H4-1/2" HES XN NIP, ID = 3.725" I I 9037' U ruT OFF TBG TA IL I I 9037' H ElMO TT LOGGED 02/17188 I ... ~ ~ 10224' -, ~ DATE REV BY COMMENTS 02/07/03 ?/KAK WAIVERSAFETY t\OlE 7" LNR, 29#, L-80, .0371 bpf, ID= 6.184" H 10270' [)ð,lE 07/22/81 11/05/95 03103/0 1 06124/0 1 10/31/01 02124/02 RBI BY OOIvtv1ENTS HOFF ORGINA.L COIWlETION RWO SS-MJ FINAL RNIlP CORRECTDNS WBIlP SURF LaC CORRECllONS A F/KAK PERF [)ð, TE CORRECllONS 9578' HMI\RKERJ01NT I ~7' OF 4-1/2" TAILPIPE- 12/16/88 I PRUDHOE BA Y UNIT WELL: Y-10 PERMIT No: 1810540 AA No: 50-029-20587-00 SEC33, T11N, R13E BP Exploration (Alaska) 13-3/8" CSG, 72#, L-80, iD '" 12.347 ::::: 12.6#, L-80, NSCT, 0.0152 bpi, iD '" 3.958" 2108' IIIIIí NOTES: OVERSHOT STUB. SEE TElex FOR œ.r AILS, -r X IA COMM. (02107/03 .. 2182' 3.813" 1 ...... ...... ...... ...... 2514' DV PKR I . I I 8915' TBG 8935' 9012' 4-1/2" TBG, 12.6#, L-80, .0152 bpi, iD 3.958" 9037' 9031' 9-5/8" CSG, 47#, L-60, ID '" 6.681" 9464' PERFORATION SUMMARY REF CBL ON 07/21181 ANGLE AT TOP PERF: 18 @ 9474' Note: Refer to Production DB for historical pari data SIZE SPF INTERV AL DATE 3-3/8" 4 9474 - 9484 3-1/8" 4 9484 9494 3-318" 4 9494 9498 2-7/8" 4 9560 - 9538 3-118" 4 9638 - 9658 3-3/6" 4 9658 9578 7" LNR, 29#, L-60, .0371 bpf, ID DATE 07/22./81 11105/95 03/03/01 06/24/01 10/31/01 02124/02 REV BY HOFF SIS-MD RNITP CORRECTIONS WBITP SURF LOC CORRECTIONS AF/KAK ÆRF DATE CORRECTIONS 10270' 4-1/2" TAilPIPE> DATE REV BY COMMENTS 02107/03 ?/KAK WMIER SAFETY NOTE 12/16/04 MSE PROPOSED cm SIDETRACK WElL: PERMIT No: API No: SEe Sf> · . BP-GDB Baker Hughes INTEQ Planning Report ObP company: Field: Site: WeD: WeDpath: Field: BPAmoco Prudhoe &iy PB Y Pad Y-10 PIàn#9Y-10A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Bit. 8A~ IIUGIIU lNTEQ Date: 1211612004 Time: 11 :43:28 Page: Co-ordinate(NE) R.eferenee: Well: Y-10. True Nort/'l Vertical (TVD) Reference: System: Mean Sea·lievel Section (VS) Reference: Well (O.OON,O.OOE.58,OOAzi) Survey Calculation Method: Minimum Curvature Db: Map Zone: Coordinate System: Geomagnetic Model: 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: 1 Alaska, Zone 4 Well Centre bggm2004 0.041 N 18.991 W True 1.12 deg Well: Y-10 Slot Name: 10 Y-10 Well Position: +N/-S 361.57 ft Northing: 5948841.49 ft Latitude: 70 16 3.591 N +EI-W-3131.46 ft Easting : 644611.01 ft Longitude: 148 49 50.139 W Position Uncertainty: 0.00 ft Wellpath: Plan#9 Y-10A 500292058701 Current Datum: 14: 107/5/1981 00:00 Magnetic Data: 1219/2004 Field Strength: 57616 nT Vertical Section: Depth From (TVD) ft 36.70 Targets Name D~ription Dip. Dir. Y -10A Polygon8.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Y-1OA Fault 1 -Polygon 1 -Polygon 2 Y-10A Fault 2 -Polygon 1 -Polygon 2 0.00 0.00 0.00 8895.00 8930.00 8960.00 Y-10A T8.3 Y-10A T8.1 Y-10A T8.2 Annotation MD TVD ft ft 9400.00 8702.90 TIP 9520.00 8817.48 KOP 9580.00 8870.91 3 9712.00 8929.51 4 9742.00 8929.78 5 9842.00 8933.81 6 9962.00 8941.85 7 Height 85.70 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Y-10 9400.00 ft Mean Sea Level 24.89 deg 80.81 deg Direction deg 58.00 Map Map <- Latitude........> <.-Longltude +N/-8 +EI-W Northing Easting Deg Min .. Sec DegMin ~ ft ft ft ft 679.37 -2638.64 5949469.99 641960.00 70 16 10.268 N 148 51 6.950 W 679.37 -2638.64 5949469.99 641960.00 70 16 10.268 N 148 51 6.950 W 1384.41 -1329.76 5950199.99 643255.00 70 16 17.205 N 148 50 28.852 W 1232.21 -1217.65 5950049.99 643370.00 70 16 15.709 N 148 5025.588 W 492.18 -2527.21 5949284.99 642075.00 70 16 8.427 N 148 51 3.704 W 1821.06 -3231.87 5950599.99 641345.00 70 1621.494 N 148 51 24.233 W 1821.06 -3231.87 5950599.99 641345.00 70 1621.494 N 148 51 24.233 W 397.09 -2524.04 5949189.99 642080.00 70 16 7.492 N 148 51 3.611 W 2403.99 -2335.44 5951199.99 642230.00 70 16 27.230 N 148 50 58.139 W 2403.99 -2335.44 5951199.99 642230.00 70 16 27.230 N 148 5058.139 W 774.65 -1871.62 5949579.99 642725.00 70 1611.207 N 148 50 44.623 W 1264.54 -1338.07 5950080.00 643249.00 70 16 16.026 N 148 50 29.093 W 616.68 -2551.83 5949408.99 642048.00 70 16 9.651 N 148 51 4.422 W 830.22 -2056.60 5949631.99 642539.00 70 1611.753 N 148 50 50.008 W . . Bit. IIA_ IUGIIH lNTEQ ObP BP-GDB Anticollision Report Company: BP Amoco Date: 1211612004 Time: 11:55:03 Page: 1 Field: PrudhoEt Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y~1 O,True North Reference WeD: Y-10 Vertieal (TVD) Reference: 14: 107/511981 00:00 85.7 Reference WeDpath: PIan#9 Y-10A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There arlßilI8lltèøells in thli'lIIdIFlan #9 & NOT PLANNED PROGRA 1.1 Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9400.00 to 11180.00 ft Scan Method: Trav Cytinder North Maximum Radius: 1314.33 ft Error Suñace: Ellipse + Casing Casing Points MD ft 2708.00 9464.00 9500.00 11180.00 TV» ft 2707.93 8849.68 8884.10 8981.50 13.375 9.625 7.000 2.875 17.500 12.250 8.500 3.750 13 3/8" 9 5/8" 7" 27/8" Diameter in Hole Size in Name Plan: Plan #9 Ok to swing north out of poly Principal: Yes Date Composed: Venion: Tied-to: 12/9/2004 2 From: Definitive Path Summary EX PR331113 PB Y Pad PB Y Pad PB Y Pad PB Y Pad PB Y Pad Offset Wellpath ,.. Reference Offset Ctr-Ctr No-Go Allowable WeD WeDpath MD MD Distance Area Deviation Wamiltg ft ft ft ft ft PR331113 PR331113 V1 9498.85 8900.00 478.41 391.89 86.52 Pass: Major Risk Y-10 Y-10 V1 9500.00 9500.00 0.00 0.00 0.00 FAIL: NOERRORS Y-19 Y-19 V1 Out of range Y-30 Y -30 V3 11041.00 9500.00 977.56 317.87 659.70 Pass: Major Risk Y-30 Y-30L 1 V3 10958.28 9500.00 949.55 368.02 581.53 Pass: Major Risk Y-31 Y-31 V1 9795.03 9900.00 1111.90 321.72 790.18 Pass: Major Risk .,. Site Site: EX PR331113 Well: PR331113 Rule Assigned: Major Risk Wellpatb: PR331113V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV» MD TV» Ref Offset TFO+AZI TFD-HS CaslnglHS)istanee. Area Deviation WlU'lÚllg ft ft ft ft ft ft deg deg in ft ft ft 9498.85 8883.01 8900.00 8899.19 113.91 7.23 189.11 252.88 478.41 391.89 86.52 Pass 9532.58 8915.04 9000.00 8999.18 111.93 8.10 186.84 231.42 491.76 388.12 103.64 Pass 9550.00 8931.04 9100.00 9099.18 107.91 9.42 185.12 214.79 520.43 380.76 139.67 Pass 9570.00 8948.43 9200.00 9199.16 100.73 11.29 184.15 202.79 562.38 365.08 197.30 Pass 9583.19 8959.13 9300.00 9299.14 94.59 12.62 183.33 196.48 615.51 350.81 264.69 Pass 9596.77 8969.44 9400.00 9399.13 87.35 13.89 183.39 190.93 677.67 334.40 343.27 Pass 9610.00 8978.71 9500.00 9499.12 79.43 15.13 183.95 186.95 747.09 316.36 430.73 Pass 9620.00 8985.13 9600.00 9599.10 72.87 16.09 184.52 184.55 822.19 301.35 520.84 Pass 9626.93 8989.27 9700.00 9699.10 68.04 16.79 184.94 183.09 901.50 290.37 611.14 Pass 9634.22 8993.34 9800.00 9799.10 62.82 17.50 185.53 181.84 984.26 278.32 705.95 Pass 9640.00 8996.33 9900.00 9899.10 58.60 18.09 186.08 181.01 1069.83 268.60 801.22 Pass 9645.90 8999.18 10000.00 9999.10 54.14 18.67 186.72 180.31 1157.46 258.19 899.27 Pass 9650.00 9001.04 10100.00 10099.10 51.04 19.13 187.21 179.90 1246.76 251.04 995.72 Pass Site: PB Y Pad Well: Y-10 Rule Assigned: NOERRORS Wellpatb: Y-10 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV» MD TV» Ref Offset TFO+AZI TFD-HS CasinglH~istance.. Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9400.00 8788.60 9400.00 8788.60 113.10 113.10 297.61 0.00 9.625 0.00 0.00 0.00 FAIL 9500.00 8884.10 9500.00 8884.10 113.92 114.62 296.21 0.00 7.000 0.00 0.00 0.00 FAIL 9590.35 8964.67 9600.00 8980.17 90.95 92.73 189.43 199.48 7.000 25.22 0.00 25.22 Pass 9639.84 8996.25 9700.00 9076.73 58.72 60.73 198.95 193.92 7.000 95.90 0.00 95.90 Pass 9663.77 9006.47 9800.00 9173.58 40.45 42.36 203.26 193.10 7.000 183.09 0.00 183.09 Pass 9677.02 9010.50 9900.00 9270.73 30.65 32.23 205.48 192.77 7.000 276.22 0.00 276.22 Pass 9685.39 9012.42 10000.00 9368.18 25.42 26.45 206.74 192.49 7.000 371.88 0.00 371.88 Pass Company: Field: Site: WeD: WeDpath: Annotation MD ft 10222.00 10422.00 10822.00 11180.00 I Plan: Principal: ObP BP Amoco Prudhoe Bay PB Y Pad Y-10 Plan#9 Y-10A TVD ft 8958.08 8954.88 8923.79 8895.80 '. . BP-GDB Baker Hughes INTEQ Planning Report 8 9 10 TD Plan #9 Ok to swing north out of poly Yes Plan Section Information MD ft 9400.00 9500.00 9520.00 9580.00 9712.00 9742.00 9842.00 9962.00 10222.00 10422.00 10822.00 11180.00 Survey MD ft 9400.00 9425.00 9450.00 9475.00 9500.00 9520.00 9525.00 9550.00 9575.00 9580.00 9600.00 9613.02 9625.00 9650.00 9675.00 9700.00 9712.00 9725.00 9742.00 9750.00 9775.00 9800.00 9825.00 9842.00 9850.00 9875.00 9900.00 9925.00 9950.00 Inci deg 17.62 16.87 18.19 37.06 89.49 89.50 86.12 86.24 86.78 95.03 93.36 95.18 Inci deg 17.62 17.43 17.24 17.06 16.87 18.19 19.07 25.99 35.11 37.06 44.27 49.23 53.92 63.94 74.18 84.51 89.49 89.49 89.50 89.19 88.24 87.36 86.57 86.12 86.12 86.13 86.14 86.17 86.21 Azim deg 297.61 296.21 300.29 345.36 18.95 32.45 77.37 91.80 60.54 37.98 86.09 43.04 ADm deg 297.61 297.27 296.92 296.57 296.21 300.29 306.77 330.33 343.45 345.36 353.64 357.93 1.34 7.31 12.33 16.85 18.95 24.80 32.45 36.04 47.25 58.48 69.71 77.37 78.33 81.34 84.34 87.35 90.35 TVD ft 8702.90 8798.40 8817.48 8870.91 8929.51 8929.78 8933.81 8941.85 8958.08 8954.88 8923.79 8895.80 SSTVD ft 8702.90 8726.74 8750.60 8774.49 8798.40 8817.48 8822.21 8845.34 8866.87 8870.91 8886.08 8895.00 8902.45 8915.34 8924.27 8928.89 8929.51 8929.63 8929.78 8929.87 8930.43 8931.39 8932.72 8933.81 8934.35 8936.04 8937.73 8939.40 8941.06 +N/-8 ft 485.83 499.25 502.11 524.74 635.77 662.74 718.75 730.02 791.30 920.82 1102.20 1251.75 NIS ft 485.83 489.30 492.69 496.01 499.25 502.11 502.99 510.22 521.90 524.74 537.53 546.98 556.37 577.67 600.63 624.37 635.77 647.83 662.74 669.35 687.99 703.05 713.94 718.75 720.43 724.83 727.94 729.75 730.25 II.. ..... INTEQ Date: 12/16/2004 Time: .·..11:43:28 Page: Co-ordinate(NE) Referenee: Well:Y-10. TrueNørth Vertieai (TVD) Referenee: $ystem:MearlSea LE!vel Section (VS) Reference: Well (O.OON.O.ooE.58,ooAzO Survey Caleulation Method: Minimum Curvature Db: +EI-W ft -2564.36 -2590.79 -2596.09 -2608.99 -2596.46 -2583.48 -2503.84 -2384.96 -2136.11 -1985.66 -1643.62 -1328.78 EIW ft -2564.36 -2571.04 -2577.68 -2584.26 -2590.79 -2596.09 -2597.42 -2603.42 -2608.20 -2608.99 -2611.29 -2611.97 -2612.02 -2610.35 -2606.34 -2600.14 -2596.46 -2591.62 -2583.48 -2578.98 -2562.40 -2542.52 -2520.10 -2503.84 -2496.04 -2471.49 -2446.74 -2421.87 -2396.93 Date Composed: Version: Tied-to: 12/9/2004 2 From: Definitive Path DLS BuDd Tum deg/10Qft deg/10Qft deg/10Oft 0.00 0.00 0.00 0.86 -0.75 -1.40 9.00 6.58 20.40 45.00 31.45 75.11 45.00 39.72 25.45 45.00 0.05 45.00 45.00 -3.39 44.91 12.00 0.10 12.03 12.00 0.21 -12.02 12.00 4.12 -11.28 12.00 -0.42 12.03 12.00 0.51 -12.02 TFO deg 0.00 208.29 45.00 70.00 40.00 90.00 95.00 90.00 -90.00 -70.00 90.00 -86.00 MapN ft 5949277.93 5949281.27 5949284.54 5949287.73 5949290.84 5949293.60 5949294.45 5949301.56 5949313.16 5949315.98 5949328.73 5949338.16 5949347.54 5949368.87 5949391.90 5949415.75 5949427.22 5949439.37 5949454.43 5949461.12 5949480.09 5949495.52 5949506.84 5949511.95 5949513.78 5949518.66 5949522.24 5949524.52 5949525.50 MaPE ft 642037.98 642031.24 642024.54 642017.90 642011.30 642005.95 642004.60 641998.46 641993.47 641992.62 641990.08 641989.21 641988.98 641990.24 641993.81 641999.55 642003.01 642007.62 642015.47 642019.84 642036.06 642055.65 642077.85 642094.02 642101.78 642126.24 642150.92 642175.75 642200.68 Target VS ft -1917.25 -1921.08 -1924.91 -1928.73 -1932.55 DLS Toolfaee deg/100ft deg 0.00 0.00 0.86 208.29 0.86 208.62 0.86 208.95 0.86 209.28 -1935.54 -1936.19 -1937.45 -1935.31 -1934.48 -1929.65 -1925.22 -1920.29 -1907.58 -1892.01 -1874.18 -1865.02 -1854.52 -1839.72 -1832.40 -1808.46 -1783.61 -1758.83 -1742.50 -1734.99 -1711.84 -1689.21 -1667.15 -1645.74 9.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 12.00 12.00 12.00 12.00 12.00 2 Tool TIP MWD MWD MWD MWD 45.00 70.00 63.86 42.01 30.66 40.00 33.70 30.76 28.64 25.54 23.74 22.90 90.00 89.95 95.00 94.96 94.71 94.27 93.68 90.00 89.93 89.73 89.53 89.33 KOP MWD MWD MWD 3 MWD Y-10A -~ MWD MWD MWD MWD 4 MWD 5 MWD MWD MWD MWD 6 MWD MWD MWD MWD MWD . . B.. ObP BP-GDB BA_ IUGIIH Baker Hughes INTEQ Planning Report INTEQ COInpany: BPAmoco Date: 12/1612004 Time: .11 :43:28 Page: 3 Field: Prudhoe. Bay Co-ordinate(NE) Referenee: Well: Y"10, True North Site: PB Y Pad Vertical (TVD) Reference: System: Mean Sea Level Well: Y-10 Section (VS) Referenee: Well (o.oON,O.OOE.58.00Azi) Wellpath: Plan#9 Y-10A Snrvey Calc:nlation Method: Minimum Curvature Db: Oracle Survey MD Incl Ázim SSTVD NIS EJW MapN MapE VS DLS Toolfaee Tooi ft deg deg ft ft ft ft ft ft deg/100ft deg 9962.00 86.24 91.80 8941.85 730.02 -2384.96 5949525.51 642212.65 -1635.71 12.00 89.13 7 9975.00 86.24 90.23 8942.70 729.79 -2371.99 5949525.53 642225.62 -1624.83 12.00 270.00 MWD 10000.00 86.25 87.23 8944.34 730.34 -2347.05 5949526.56 642250.54 -1603.39 12.00 270.10 MWD 10025.00 86.27 84.22 8945.97 732.20 -2322.18 5949528.90 642275.37 -1581.31 12.00 270.30 MWD 10050.00 86.30 81.22 8947.59 735.36 -2297.43 5949532.53 642300.05 -1558.65 12.00 270.50 MWD 10075.00 86.34 78.21 8949.20 739.82 -2272.89 5949537.46 642324.50 -1535.47 12.00 270.69 MWD 10100.00 86.39 75.20 8950.78 745.55 -2248.61 5949543.66 642348.66 -1511.85 12.00 270.88 MWD 10125.00 86.46 72.20 8952.34 752.56 -2224.66 5949551.12 642372.47 -1487.83 12.00 271.07 MWD 10150.00 86.53 69.19 8953.87 760.80 -2201.12 5949559.82 642395.85 -1463.49 12.00 271.26 MWD 10175.00 86.61 66.19 8955.37 770.28 -2178.03 5949569.73 642418.75 -1438.89 12.00 271.45 MWD 10200.00 86.70 63.19 8956.83 780.95 -2155.47 5949580.83 642441.09 -1414.11 12.00 271.63 MWD 10222.00 86.78 60.54 8958.08 791.30 -2136.11 5949591.55 642460.26 -1392.19 12.00 271.80 8 10225.00 86.91 60.20 8958.24 792.78 -2133.50 5949593.09 642462.83 -1389.20 12.00 290.00 MWD 10250.00 87.94 57.38 8959.37 805.72 -2112.14 5949606.43 642483.94 -1364.23 12.00 290.02 MWD 10275.00 88.97 54.57 8960.04 819.70 -2091.43 5949620.81 642504.37 -1339.26 12.00 290.15 MWD 10300.00 90.01 51.75 8960.27 834.69 -2071.43 5949636.17 642524.08 -1314.35 12.00 290.22 MWD 10325.00 91.05 48.94 8960.04 850.64 -2052.19 5949652.49 642543.02 -1289.58 12.00 290.25 MWD 10350.00 92.08 46.12 8959.35 867.51 -2033.75 5949669.71 642561.12 -1265.01 12.00 290.22 MWD 10375.00 93.11 43.30 8958.22 885.26 -2016.19 5949687.79 642578.34 -1240.71 12.00 290.14 MWD 10400.00 94.14 40.47 8956.64 903.83 -1999.53 5949706.68 642594.64 -1216.74 12.00 290.02 MWD 10422.00 95.03 37.98 8954.88 920.82 -1985.66 5949723.93 642608.18 -1195.98 12.00 289.84 9 10425.00 95.03 38.34 8954.62 923.17 -1983.82 5949726.31 642609.98 -1193.17 12.00 90.00 MWD 10450.00 95.02 41.35 8952.43 942.29 -1967.86 5949745.73 642625.56 -1169.50 12.00 90.03 MWD 10475.00 95.00 44.37 8950.25 960.54 -1950.92 5949764.31 642642.14 -1145.47 12.00 90.30 MWD 10500.00 94.96 47.38 8948.08 977.88 -1933.05 5949781.98 642659.68 -1121.12 12.00 90.56 MWD 10525.00 94.91 50.39 8945.93 994.26 -1914.29 5949798.72 642678.12 -1096.53 12.00 90.82 MWD 10550.00 94.85 53.40 8943.80 1009.63 -1894.69 5949814.46 642697.42 -1071.76 12.00 91.08 MWD 10575.00 94.77 56.41 8941.70 1023.95 -1874.31 5949829.17 642717.52 -1046.89 12.00 91.33 MWD 10600.00 94.68 59.42 8939.64 1037.18 -1853.20 5949842.81 642738.37 -1021.98 12.00 91.59 MWD 10625.00 94.58 62.42 8937.63 1049.29 -1831.43 5949855.33 642759.90 -997.10 12.00 91.83 MWD 10650.00 94.46 65.43 8935.65 1060.25 -1809.04 5949866.71 642782.07 -972.31 12.00 92.08 MWD 10675.00 94.34 68.44 8933.74 1070.01 -1786.11 5949876.91 642804.81 -947.69 12.00 92.31 MWD 10700.00 94.20 71.44 8931.88 1078.56 -1762.70 5949885.91 642828.05 -923.30 12.00 92.55 MWD 10725.00 94.05 74.45 8930.08 1085.87 -1738.86 5949893.68 642851.74 -899.21 12.00 92.77 MWD 10750.00 93.88 77.45 8928.35 1091.93 -1714.67 5949900.20 642875.81 -875.49 12.00 92.99 MWD 10775.00 93.71 80.45 8926.69 1096.71 -1690.19 5949905.45 642900.19 -852.20 12.00 93.19 MWD 10800.00 93.53 83.45 8925.11 1100.20 -1665.49 5949909.41 642924.82 -829.40 12.00 93.39 MWD 10822.00 93.36 86.09 8923.79 1102.20 -1643.62 5949911.83 642946.64 -809.79 12.00 93.58 10 10825.00 93.39 85.73 8923.62 1102.42 -1640.63 5949912.11 642949.63 -807.14 12.00 274.00 MWD 10850.00 93.59 82.73 8922.09 1104.92 -1615.81 5949915.09 642974.39 -784.76 12.00 273.98 MWD 10875.00 93.78 79.73 8920.49 1108.73 -1591.16 5949919.36 642998.97 -761.84 12.00 273.80 MWD 10900.00 93.97 76.73 8918.80 1113.81 -1566.74 5949924.92 643023.28 -738.44 12.00 273.60 MWD 10925.00 94.14 73.73 8917.03 1120.17 -1542.63 5949931.74 643047.26 -714.62 12.00 273.40 MWD 10950.00 94.30 70.72 8915.19 1127.78 -1518.89 5949939.80 643070.85 -690.46 12.00 273.19 MWD 10975.00 94.45 67.72 8913.28 1136.62 -1495.59 5949949.09 643093.98 -666.01 12.00 272.97 MWD 11000.00 94.59 64.71 8911.31 1146.67 -1472.78 5949959.57 643116.58 -641.35 12.00 272.74 MWD 11025.00 94.71 61.71 8909.28 1157.90 -1450.54 5949971.23 643138.60 -616.54 12.00 272.50 MWD 11050.00 94.82 58.70 8907.21 1170.28 -1428.93 5949984.02 643159.97 -591.64 12.00 272.26 MWD 11075.00 94.92 55.69 8905.08 1183.77 -1407.99 5949997.91 643180.64 -566.74 12.00 272.01 MWD 11100.00 95.01 52.68 8902.92 1198.35 -1387.80 5950012.87 643200.55 -541.89 12.00 271.75 MWD 11125.00 95.08 49.67 8900.72 1213.96 -1368.40 5950028.85 643219.65 -517.17 12.00 271.49 MWD 11150.00 95.13 46.66 8898.50 1230.57 -1349.85 5950045.81 643237.87 -492.64 12.00 271.23 MWD . . Biii. BA~ IUGIIIS lNTEQ ObP BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: WeD: WeDpath: BP Amoco Prudhoe Bay PB Y Pad Y-10 Plan#9 Y-10A Date: 12/16/2004 Time: 11:43:28 Page: 4 Co-.ordinate(NE) Referenee: Well: Y-10. Tl\le North Vertical (TVD) Referenee: System: Meal) SeaLevel Section (VS) Reference: Well (O.ooN.O.ooE.58.ooAzi) Survey Caicniation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SSTVD ft deg deg ft 11175.00 95.18 43.64 8896.25 11180.00 95.18 43.04 8895.80 N/S EIW MapN MapE VS DLS Toolfaee Tool ft ft ft ft ft degl100ft deg 1248.12 -1332.20 5950063.70 643255.18 -468.36 12.00 270.96 MWD 1251.75 -1328.78 5950067.39 643258.53 -463.55 12.00 270.69 TD BP 'llÆU.PATH HTAn.S ~'f·1M 5OU9au'f01 -- Y-iO ....-- ....... hf. .,.::t Nm\dic .3 14 "'0 Tf$f'f931 00,\1)0 ...- Y.- <¡¡r.,e =-~ - ...... .... .... ....... REFERENCE INFORMATION 85.70 $!OO'f~J;'IfWAW'ô .. ... ... .... ..... ..,... ~'fhI» -,- "" "" ... >iOO ... := "" ... ;I ... No. · · · · · · 1 · · i. " Plan: Plan#!! (Y-101P1an119 Y-10A) Created By: Brij PotnIs. Date: 12[16/2004 T LEGEND 6/2004 11.49 AM 12/1 1250 Nordic 1 big hole All Measurements are from top of Riser ######## ~ Q) W .- a: top of bag -" ¡"".,.". -~,j ~ - :--- BAG 71/16" 5000psi J1' . 1i bttm of bag middle of slips Blind/Shears ........................,. middle of pipes TOTs 23/811 combi ram/slips L..........·······"···71/16" 5000psi ........... ........... ""'-- Mud Cross I I I variable bore pipe 31/2"-2 1/8" I 23/811 combi ram/slips Mud Cross 7 1/16" 5000psi middle of flow cross '"--" middle of blind/shears I'· ......................., TOTs I..."..........".·····'·· 7 1/16" 5000psi middle of pipe/slips " ., Flow Tee III I 0' amies in NW Pad Area Y -1 OAi and Y -06Ai drilling permits . . «Y-10ALgeodisplays.ZIP» Bob Thanks for calling - let me know if you need anything else. Wells within 1/4mi of Y-10Ai map attached Y-19 1000ft Y -30 977ft Y -30L 1 950ft Y -31 1111 ft Wells within 1/4mi of Y-06Ai map attached Y-04 1125' Y-19 1895' Y-33 810' Y-31 1180' Mary S. Endacott Coil Tubing Drlg Engr 907-564-4388 741 endacoms@bp.com Content-Description: Y -1 OAi_geodisplays.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 1 of 1 12/21/20044:26 PM . . "':.,... ,." . '.. -' . c.' .,.., ..,' . :. _n·...__ --'" i -_,.._._~ . TERRIELHUBBLE.· . . BPEXPLORA TION AK INC PO BOX196612 MB7-5 . .. ANCHORAGE,:AK ß95,19-p612 , ,. . " ..'.,...,' ..,.-...--". "Mastercard Check" "" ", :.' -'., :, 89:611252 ... 167 ::.::, .. :~ :::::::,:,:: ~', :::.: :';:.: -::::::-::: :' ,. ::: --': ,-,::,:'~::-: '; < -, ,'. :"",:,·.,,'_:__:,,:'_,,.',,".,_.:,:_",,_f . DATE'\~ IloJö4. ..... .-."....--.:,..'....,--:".:--.---:".'-..;,.-' . . ." . -. : ,';, ',.' .. -_::.-:..-~'-..,- ' ::,,~",. ~j i1b6C!~,$ roo;~:: ' ~a:x(Ji5 .'. .' . . ".'.i .,Ò~C[A~S 2' to·'· . ~oø.~: .. ,.__..__.::.'___'. " ...."......n..·... . ,..... ......'.." ,..; ..,--.......,...,... , . ,', :' :-' '.. " -; .......,.".."...-..:.:.:...,.......,.:.'.-.......:. .-,,'_~' : .- """ ,.......- '. ·n_··.._'_, ".,,,__.-_. '.., ....... __... . .'" ..,,' .. . __ __'" . ......- . - I: ¡'2 52000 bOI:~ ~¡'I."I b 2 2 ?"I¡'S 5 buÍt OU;? . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fJ8?r Y-/ðA PTD# 2D~- 2.S·(') Development ,X Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE"· Tbe permit is for a new wellboresegment of existing well, ~ . Permit No, .' API No. Production. sbould continue to be reponed as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sampJe iIiter:vals tbrougb target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#: 2042500 Company BP EXPLORATION (ALASKA) INC Initial ClasslType 1 P.ermit fee attache.d. . . . . . . . Yes. 2 .Leas.e.nIJmber .appropriate. Yes. . . . . . . 3 .U.niqIJe weIlJlarn.e.and oumb.er . . . . . . . . . . . . . . . . . . . . .. ............... Yes. . . . . . . . . . . . . . . . . . . . . . 4 WelUQc.ated inadefilJe.d.ppol . . . . . . . . . . . . . . . . . . . . . Yes ,5 WellJQc.ated proper .distance from driJling IJlJit b.oIJlJdaryYes 6 WeIlJoc.at.ed pr.operdistance. from other welJs . . . . . . _ . . . . . . . . Yes. 7 .S.ufficielJt.acreage.aYailable in drilliog unJt. . . . . . . .Y.es ,8 Jfdeviated, Js wellbQre platilJcJuded . . . . . . . . Yes 9 Qperator olJly affected party. . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . 10 .Qperator has.apprppriate. ~ond inJorce . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ . . _ . . . . . _ _ _ _ _ _ _ _ . . _ _ . . . . _ _ _ _ _ . _ . . . . . . . 11 P.ermit Gan be issued .wJtbQut co.nservatiOIJ order. Yes.. . . . . . . . . . . . . . Appr Date 12 Permit Gan be issued .wJtbQut admilJistratille. appr.oval. ............. Yes. . . . .. . . . . . . . . _ . RPC 12/21/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQc.ated withilJ area and.str.ataaIJthorized by.lnjectiPIJ Ord.er # (PIJt lOti in.c.ornm.ents) (For. Yes. . .1\10:-3 . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . 15 AJlwelJs.withinJl4.mile_area.oJreyiewid.e[1tified(FprservJc.ewe[lç)l}lyL _. _.. _ _... _ _ _. .Y_es_ _. _.. _ Y-J9.Y:30"Y~30L1.Y-_3j..... _ _.... _ _ _. _ _ _ _ _. _ _ _. _.. _ _ _ _. _.. _ _..... _.. _ _.... _. 16 Pre-produced injector;dlJr.ationof pre-pro.ductiolJ less than 3 montbs (For.sel"Vice well QnJy). NA...... . . . . . . . . . . . . . . . . . . . 17 ACMP.F:indingof Con.sistencyhas ÞeenissIJed. forthis projectNA . . . . . . . . . . . . . . . . . . . . _ . Administration Appr WGA 18 19 20 21 22 23 24 25 26 27 Date 28 12/27/2004 29 30 31 32 33 34 Engineering Geology Appr RPC Date 12/21/2004 Geologic Commissioner: j)TS Well Name: PRUDHOE BAY UNIT Y-10A SER 11WINJ GeoArea 890 Unit 11650 Program SER On/Off Shore On Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - ~ - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- C.ondu.ctor stringprovid.ed . . . . . . . . . . . . . . . NA S.urfac.ec.asingprotects alLknown USDWs. ....... NA . .CMT. vol adequate to circulate. oncOlJductor 8. su.rf. csg . . .NA .CMT. vol adequ.ateto tie-in .long string to.SIJrf çsg. . . . . . .NA . . . . . . CMT. will cOYeraJI koown.prOductiye horizons. . . Yes .C.asing de.signs adeQua.te for C,. T. B& permafrost . Yes. Adequ.ate.tankage.or re.seI"Ve pit . . . . . . . Yes . . . CTDU. Jf.aJe-.drill, has.a to-403for .abandonme.nt be.e[1 .approved. Yes. . . .12/20/2004. . Adequate.wellbore. sep¡Uatio_n.proposed. . _ _ . _ _ . _ _ _ _ . . _ _ . . . _ . _ _ _ _ . _ _ _ _ _ . . .Y_es _ _ _ _ . . _ _ _ _ _ . . _ . . _ _ _ _ . _ _ _ _ . _ . JfdJverterreq.uired, does JLl11eet reguJa.tiOlJs. ....... . . . . . . . . . . . _ . . . . . .NA . . . Sidetrack.. . . . _ . . . . . . . . .DJilliog fJuJdprogram schematic & eq.uipJistadequate. ....... Yes. . . . Max MW8..9. ppg, . . . . B.QPEs.. d.o they meet reguJa.tiOIJ . Yes. .B.oPEpress rating appropriate; test to.(put psig in.commelJts). . . . . . . Yes. ,- .Choke manifold complies w/API RP-S3 (May 84). . Yes Work wi!1 occur withput.operatjo.n .shutdown. . . _ . . . . . . . Yes _ . .Is presence of H2S gas_ prob.aÞle. . . . . . . . Yes. Me~banic.aLcpodition .of wells withilJ .l\OR yeriJiecl (For service welJ only). . . . Yes . - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ r _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - . . . . Testt03500 psLMSF' 2204 psi. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . 120.ppm, . . . . . . . . . . . . _ . . . . . Cmtng records indiçate lTlech i!ltegrit~ Of all AOR w.eUs. . - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen s.ulfide measures. 36 .D.ata. PJeseoted on. pote.ntial 9veJpressIJre .zone.s. " 37S.eismic.analysJs of sha.llow gaszooes . . . . . . . . . 38 .S.eabepCOlJdjtip!l survey.(if off-shore) . . . . . _ . . 39 . Contact l)ame/p.honeJorwee~ly progress reports [exploratpryonlYl . No NA NA. . ..... NA NA.. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: (~~c W;ooe, Date /7Z-~y Date Jè/ <JYtCf- o . . . . 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 RECEIVED $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 17 16:24:19 2006 JAN 2 9 Z007 AllllcaOD & Gas Cons. eommiSSiOO Anchorage Reel Header Service name..... ....... .LISTPE Date........ ............ .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments..... . . . . . . . . . . . .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date.................... .06/11/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number. . . . . .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Y-10A 500292058701 BP Exploration (Alaska) Inc. Sperry Drilling Services 17-NOV-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 W-0003530513 S. LATZ R. WHITLOW/D MWDRUN 6 W-0003530513 S. LATZ R. WHITLOW/D MWD RUN 7 W-0003530513 S. LATZ R. WHITLOW/D # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 llN 13E 1410 205 85.69 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 9503.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE Y-03 WELLBORE BY MEANS OF A U:t:...C- ~o4 -d:$"Ó tt 14359 . . WHIPSTOCK, THE TOP OF WHICH WAS AT 9503'MD/8801'TVDSS. 4. NO DATA WERE ACQUIRED ON MWD RUNS 1,3-5. 5. MWD RUNS 2 AND 6 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY(PCG) UTILIZING SCINTILLATION DETECTORS. 6. MWD RUN 7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(GM)UTILIZING GEIGER-MUELLER TUBE DETECTORS,AND ELECTROMAGMETIC WAVE RESISTIVITY-PHASE 4 (EWR4) . THIS RUN WAS A MAD PASS FROM TD TO THE WINDOW TO ACQUIRE RESISTIVITY DATA. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN Y-10. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 16 NOVEMBER 2006. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1-7 REPRESENT WELL Y-10A WITH API#:50-029-20587-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11114'MD/8879'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD SMOOTHED NATURAL GAMMA RAY. 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. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....06/11/17 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPM RPS RPD FET RPX ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9432.0 9493.0 9493.0 9493.0 9493.0 9493.0 9521.5 STOP DEPTH 11081.0 11079.5 11079.5 11079.5 11079.5 11079.5 11111 . 0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9432.0 9476.0 9478.0 GR 9433.5 9477.5 9480.0 . . 9481.0 9487.0 9497.0 9500.0 9504.0 9506.0 11111.0 $ 9483.5 9489.5 9499.0 9501.5 9507.0 9508.5 11113.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 6 7 MERGE TOP 9433.5 9847.5 9495.0 MERGE BASE 9878.0 11113 . 5 11082.0 # REMARKS: MERGED MAIN PASS. $ # 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9432 11111 10271.5 3359 9432 11111 RPD MWD OHMM 0.06 2000 16.7379 3174 9493 11079.5 RPM MWD OHMM 0.13 2000 13.3621 3174 9493 11079.5 RPS MWD OHMM 0.38 2000 16.6324 3174 9493 11079.5 RPX MWD OHMM 0.43 2000 24.3526 3174 9493 11079.5 FET MWD HOUR 15.47 94.1 44.5206 3174 9493 11079.5 GR MWD API 20.45 943.56 44.7892 3299 9432 11081 ROP MWD FT/H 0.28 334.27 98.5703 3180 9521. 5 11111 First Reading For Entire File. ........ .9432 Last Reading For Entire File.. ........ .11111 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 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...... .06/11/17 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 GR ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 9433.5 9524.0 STOP DEPTH 9847.0 9878.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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... .......... .....0 Data Specification Block Type... ..0 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. . . . . . . . . . . . . . . . . . . . . . . 13 -FEB- 05 Insite 7.75 Memory 9878.0 9524.0 9878.0 22.4 93.7 TOOL NUMBER TLGOll 3.750 9503.0 Flo Pro 8.60 65.0 9.5 23000 10.0 .000 .000 .000 .000 .0 133.0 .0 .0 . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9433.5 9878 9655.75 890 9433.5 9878 GR MWD020 API 21.48 943.56 71.9487 828 9433.5 9847 ROP MWD020 FT/H 0.28 334.27 86.6341 709 9524 9878 First Reading For Entire File..... .....9433.5 Last Reading For Entire File.... ...... .9878 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......06/11/17 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....06/11/17 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 ROP $ 3 header data for each bit run in separate files. 6 .5000 START DEPTH 9847.5 9878.5 STOP DEPTH 11083.5 11113 .5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15-FEB-05 Insite 7.75 Memory 11114 . 0 9878.0 11114.0 87.0 98.4 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG011 # BOREHOLE AND CASING DATA . . OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9503.0 # 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: Flo Pro/KCL 8.60 65.0 9.5 23000 10.0 .000 .0 .000 129.0 .000 .0 .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ....... ...0 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 Service Order Units FT API FT/H Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT GR ROP MWD060 MWD060 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9847.5 11113 .5 10480.5 2533 9847.5 11113.5 GR MWD060 API 20.45 158.95 35.7589 2473 9847.5 11083.5 ROP MWD060 FT/H 3.9 206.12 101.995 2471 9878.5 11113.5 First Reading For Entire File......... .9847.5 Last Reading For Entire File.. ........ .11113.5 File Trailer Service name.. ...........STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name...........STSLIB.004 Physical EOF File Header Service name...... ...... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record..65535 . File Type.. .. . . . . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPS RPM $ 4 . header data for each bit run in separate files. 7 .5000 START DEPTH 9495.0 9495.0 9495.0 9495.0 9495.0 STOP DEPTH 11082.0 11082.0 11082.0 11082.0 11082.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM DGR $ BOTTOM) TOOL TYPE Dual GR DUAL GAMMA RAY # 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 16-FEB-05 Insite 4.3 Memory 11114.0 9524.0 11114.0 22.4 98.4 TOOL NUMBER 78005 171170 4.125 9503.0 Flo Pro!KCL 8.60 65.0 9.5 23000 10.0 .120 65.0 .062 133.0 .160 65.0 .110 65.0 . . Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9495 11082 10288.5 3175 9495 11082 RPD MWD070 OHMM 0.06 2000 17.6858 3175 9495 11082 RPM MWD070 OHMM 0.13 2000 13.5557 3175 9495 11082 RPS MWD070 OHMM 0.38 2000 16.1956 3175 9495 11082 RPX MWD070 OHMM 0.43 2000 24.7779 3175 9495 11082 FET MWD070 HOUR 15.47 94.1 44.5363 3175 9495 11082 First Reading For Entire File......... .9495 Last Reading For Entire File.......... .11082 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .06/11/17 Maximum Physical Record. .65535 File Type... .. . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date..... . . . . . . . . .. . . . .. .06/11/17 Origin.................. .STS Tape Name..... ......... ..UNKNOWN Continuation Number. . .. . .01 Next Tape Name. .. .. . . ... . UNKNOWN Comments...... ........ ...STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.. ...........LISTPE Date........ .............06/11/17 Origin. . . . . . ........... . .STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Next Reel Name... ....... .UNKNOWN Comments......... ....... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
