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198-168
STATE OF ALASKA WELAILASKA OIL AND GAS CONSERVATION COMM• N MPLETION OR RECOMPLETION REP AND LOG 1a. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 • Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development IZI Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/20/2015 198-168 . 315-637 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/31/1998 50-029-22531-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 9/8/1998 PBU K-19A Surface: 3100'FSL,4766'FEL,Sec.04,T11N,R14E,UM • 9 Ref Elevations KB 54.25 17. Field/Pool(s): Top of Productive Interval: 3503'FSL,486'FEL,Sec.05,T11N,R14E,UM GL 26.3 BF 28.42 PRUDHOE BAY,PRUDHOE OIL Total Depth: 3716'FSL,2561'FEL,Sec.05,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 3518'/3517' ' ADL 028303&028304 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 670788. y- 5975025' Zone - ASP 4 , 11795'/8963'' 95-001 TPI: x- 669778 y- 5975405 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 667699 y- 5975572 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No RI 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8426'/8419' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD,DIR,GR,RES r� jrr 23. 9 .•3 211 t CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 28' 108' 28' 108' 30" 260 sx Arctic Set(Approx.) 9-5/8" 47# NT-80 28' 3696' 28' 3695' 12-1/4" 882 sx PF'E',375 sx Class'G' 7" 26# NT-80 3640' 8426' 3639' 8419' 8-1/2" 276 sx Class'G' 3614' 4-1/2" 12.6# L-80 8240' 11795' 8238' 8963' 6" 386 sx Class'G' 24. Open to production or injection? Yes 0 No WI 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 8237' 8182'/8180' APAAVLOA.a 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DATE RECEIVED Was hydraulic fracturing used during completion? Yes ❑ No ,.L(2A(f Per 20 AAC 25.283(i)(2)attach electronic and printed 4 information VER!FIED JAN 14 2016 1.1.• DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AA^CC See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(con'): Press 24 Hour Rate ""Mil" Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only d �(u7j46 VP" I/76 l//1.° RBDMS LL JAN 2 2 2016 M. 2•-t6-,i4. ICI 28. CORE DATA • Conventional Core(s) Yes 0 No El • Sidewall Cores Yes 0 No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No RI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8414' 8407' Shublik A 8468' 8458' Shublik B 8497' 8485' Shublik C 8515' 8501' Sadlerochit-Zone 4B 8530' 8514' Zone 4A 8587' 8563' Zone 3 8645' 8609' Zone 2C 8703' 8652' Zone 2B 8780' 8704' Zone 2A 9137' 8813' Zone 1B 9678' 8865' • Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Drilling Reports,Well Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nocas,Noel Email: Noel.Nocas@bp.com Printed Name: Joe Lastufka�kN,----Ahone: Title: Drilling Technologist Signature: +1 907 564 4091 Date:i4/l(P INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • WELL NAME: K-19A / AL1 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8173' Set Cement Retainer 8163' 61 Bbls Class 'G' 4886' 101.6 Bbls Class 'G' 3815' Cut & Pull Tubing 3640' Cut & Pull 7" 3540' Set EZSV 3518' Set Whipstock . S K-19A /AL1, Well History (Pre-Rig Sidetrack) PULLED 4-1/2" PX-PLUG FROM 8,154' SLM /8,168' MD (Thick parifin from 1700' to 1300' SLM). DRIFTED W/3.70"WRP DRIFT TO DEVIATION @ 9,004' SLM (Tight spots from 11/14/2015 1300' to 2500' SLM). T/I/O= 920/481/43 Temp= shut in (Assist E-Line) Pumped 5 bbls of meth, 295 bbls of 1% 11/15/2015 KCL, 5 bbls of meth, followed by 70 bbls of DSL. INITIAL T/I/O = 900/675/50. LRS PERFORMED LOAD AND KILL W/290 BBLS 1% KCL & FRZ PROTECTED W/70 BBLS DIESEL. RIH W/ ELINE &4.5" HES SVB SQZ PACKER SET PLUG MID ELEMENT @ 8174' (TOP AT 8173') TIED INTO TBG TALLY DATED 13- SEPT-1998. WELL SI ON DEPARTURE - NOTIFIED PAD OP OF WELL STATUS 11/15/2015 FINAL T/I/O = 0/600/50. LRS ON LOCATION UPON DEPARTURE PERFORMING MIT-T. Assist E-Line ( MIT-T to 2500 ****PASS**** ) Pumped 7 bbls dsl down tbg to reach test psi. 15 min loss = 80 psi. 30 min. loss = 28 psi. Total loss = 108 psi. FWHP= 0/478/0 MV=open 11/16/2015 SV/WV/SSV= closed IA/OA= otg. CTU #8 w/ 1.5" CT (CTV=18.7). Objective-PxA slotted liner in prep for CTD. MIRU from E-20 - MU BTT MHA- MU HES Cmt Retainer Stinger- NU BOPs - Fnc Test BOPs- RIH Tag ST#3 GLM @ 5477' CTM - NOT make thru - POOH - Shinny on 3.71" Btm Centralizer, NO marks on 11/17/2015 Stinger Sec. CTU #8 w/ 1.5" CT (CTV=18.7). Objective-PxA slotted liner in prep for CTD. MU HES Stinger Assy w/3.56" bow spring btm Centralizer- RIH thru all GLM - Sting into HES Cmt Retainer 8174' EM - Press Up CT Annulus to 400 psi - Perform Inj. Test-SWS cementers pump 61 bbls 15.8 ppg G cement down CT. Displace to leave one bbl cement above retainer after unstinging. Reverse out excess cement to —10' above retainer. POH. FP well from 2000'w/ 11/18/2015 McOH. RDMO to K-09. 11/29/2015 T/I/O= 0/580/0. Assist with MIT T wait for wind to dir down 11/29/2015 RIG UP SWCP LL-09. STNADBY FOR WEATHER. 11/30/2015 Standby for wind to let so slickline can get on well 12/1/2015 Standby for wind to let so slickline can get on well TAG CEMENT @ 8163' SLM W/2.50" S.BAILER, STICKY BOTTOM. LRS PERFORMED PASSING MITI-T TO 2672psi. SET 4 1/2" S.S. CATCHER ( ss-42 ) @ 8152' SLM. PULL ST# 1 (1" btm-int-dmy) @ 8093' SLM/8100' MD ****NOTE: STA#1 LEFT OPEN POCKET****. 12/2/2015 PULL 4 1/2" S.S. CATCHER ( ss-42 ) @ 8152' SLM. T/1/0= 0/471/0 Assist slickline with MIT-T **PASSED**to 2500 psi. (Pre Rig) Pumped 2 bbls diesel down tbg to reach test pressure. 15 min T lost 59 psi. 30 min T lost 22 psi. Total loss of 81 psi in 30 mins. Bleed TP back to 1000 psi. Slickline to RIH and set catcher. 12/2/2015 FWHP=585/480/0 Casing valves OTG. S-Line on location upon departure 12/3/2015 Heat upright# H-06 of fresh water to 100*f 12/4/2015 Heat Diesel tanker#30018 to 90* for SLB Cement pumping crew** Job Scope: Balance Cement Plug T/I/O = 920/120/0. R/U SLB and spot all equipment. LPT to 300 psi and HPT to 4000 psi passed. Troubleshoot micro-motion and PJSM with all personnel. Circ-out well with fresh water. Incur difficulties with micro motion and accurate recording of tank returns. Decide to freeze protect the well with diesel and begin standby for 12/5/2015 more fluids and new micro motion. 12/5/2015 Assist SLB Cement crew(Pre Rig) Heated CH2 transport#30018 to 90* F. 12/5/2015 Heat Diesel tanker#30018 to 80* for SLB Cement pumping crew. Job Scope: Balanced Cement Plug. T/I/O = 454/50/0. Continued standby for third micro motion and second SLB pump truck. R/U, PJSM, LPT to 350 psi = pass, HPT to 4000 psi = pass. Pumped a total of 10 BBL's 60/40, 166 BBL's diesel, 323 BBL's fresh water, and 101.6 12/6/2015 BBL's of 15.8 ppg Class"G" cement into the well. Rigged down and ended ticket. 12/7/2015 BRUSHED BPV PROFILE w/ DOUBLE 4-1/2" BLB's. RIH w/3.70" CENT, 1.75" S-BLR. K-19A /AL1, Well History (Pre-Rig Sidetrack) T/I/O= 186/333/-16 Temp= SI CMIT-TxIA to 3000 psi ***PASSED*** (Pre Rig) Pumped 3 bbls of neat methanol, followed by 3 bbls of diesel down TBG/IA, using jumper hose, to achieve test pressure. Test results follow: Seventh 15 min T/IA lost 17/20 psi; Eighth 15 min T/IA lost 14/12 psi for a total loss of 31/32 psi in last 30 minutes of test. Bled back—3 bbls.Tags hung. SV WV SSV= closed. IA OA=OTG. Pad op notified. **AFE**sign hung on 12/8/2015 well. FWHPS=308/317/0. 12/8/2015 TAGGED TOC @ 4,886' SLM w/3.70" CENT, 1.75" S-BLR. (Sample of Cement). T/I/0=150/150/0 CMIT TxIA PASSED to 3000 (RWO) Pumped 2 bbls diesel down IA to reach 12/9/2015 test pressure. Loss of 73/73 bbls 1st 15 min, Loss of 32/33 psi 2nd 15 min. (ELINE JET CUT). WELL SI ON ARRIVAL. T/I/A= 250/500/200. CUT 4.5" TUBING AT 3815' USING POWERCUTTER; CCL TO MIDDLE OF CUTTER = 8.85'; CCL STOP DEPTH = 12/9/2015 3806.15'. WELL SI BEFORE DEPARTING SITE. T/I/O = 0/180/0. MIT-OA PASSED to 3000 psi Pumped 2 bbls diesel dowm OA to reach test pressure.Loss of 24 psi 1st 15 min. Loss of 11 psi 2nd 15 min FWHP=300/300/0 SV,WV,SSV closed. MV,IA,OA 12/10/2015 Open Tags hung, AFE Sign hung. T/I/O = 300/500/0. Installed drilling scaffolding. RU IA TEMP#74 . OA TEMP#11 Piggyback 12/13/2015 GV. Torqued and PT'd to API specs (PASS). RDMO. FWHP = 300/500/0. T/I/O = 300/500/60. Set TWC#431 @ 125", set good. Performed LTT On TWC. (Passed). Hung TWC Sing on MV. N/D 4" CIW Upper Tree w/ Baker act. N/U Dry Hole. Temp#12. 12/14/2015 Verrified O/A Comp. VR Plug. Bled TBG to 0 psi Through I/A. RDMO. FWHP's = 0/0/60. T/I/O = TWC/53/Vac. Temp= SI. WHPs. (Pre Rig). No wellhouse or flowline, dry hole tree installed. Crew on location pulling drilling scaffolding. Unable to access SV to verify position. 12/15/2015 MV= O. IA& OA= OTG. 01:30. • North America-ALASKA-BP Page t lot Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/15/2015 12:00 - 14:00 2.00 RIGD P PRE BEGIN RON EVENT WITH PARKER 272 AT 12:00 RIG DOWN AND PREPARE TO SKID FLOOR -PERFORM DERRICK INSPECTION -CHANGE OUT LIGHT IN DERRICK -RIG DOWN MAN RIDERS -DISCONNECT INTERCONNECTS BETWEEN MUD MOD AND DRILL MOD 14:00 - 15:00 1.00 RIGD P PRE SKID CATTLE CHUTE AND RIG FLOOR -PEFORM CHECKLISTS PRIOR TO SKIDDING FLOOR AND LOWERING MAST 15:00 - 16:00 1.00 RIGD P PRE LOWER MAST -380K MAX HOOKLOAD WHILE LOWERING MAST 16:00 - 18:30 2.50 RIGD P PRE GENERAL RIG DOWN IN PREPARATION FOR RIG MOVE -WARM UP COLUMBIA MOVING SYSTEM AND HOLD PJSM 18:30 - 21:30 3.00 RIGD P PRE SEPARATE MODULES,PULL OFF WELL AND STAGE ALL THREE AT ENTRANCE OF PAD SIMOPS: -PULL DUMMY WELLHOUSE WITH CRANE, SECURE ON TRUCK,AND SEND TO K PAD 21:30 - 00:00 2.50 MOB P PRE MOVE ALL 3 MODULES TOWARD K PAD -SET DUMMY WELLHOUSE OVER K-19 WITH CRANE 12/16/2015 00:00 - 04:00 4.00 MOB P PRE MOVE ALL 3 MODULES TOWARD K PAD(ALL THREE AT SAME TIME) -OBSERVE HYDRAULIC LINE LEAK ON MUD MOD DRIVE AXEL(NO FLUID ON GROUND) -ALL 3 MODULES STOP ONE MILE FROM WEST DOCK INTERSECTION(MUD MOD IN FRONT) 04:00 - 09:00 5.00 MOB N RREP 0.07 PRE IADC CODE 8:REPAIR HYDRAULIC LINE LEAK -RETRIEVE REPLACEMENT HYDRAULIC LINE FROM PARKER'S YARD 09:00 - 13:00 4.00 MOB P PRE MOVE AND STAGE ALL 3 MODULES TO EDGE OF K PAD 13:00 - 15:30 2.50 MOB P PRE SET DRILL MOD OVER WELL K-19 -RIG MANAGER TEST ESD PRIOR TO BACKING OVER WELL. -WSL CONFIRMS WELLHEAD PRESSURES T/I/O=0/50/0 PSI. CONFIRM BARRIERS TESTED PRE-RIG AND PRE-RIG WORK COMPLETE. -COMPLETE HANDOVER FROM WELLS GROUP. OPEN WWTP WITH PAD OPERATOR. -MONITOR TREE PRESSURE WITH STEAM ON WELLHOUSE -DOUBLE ANNULUS WORKING VALVES INSTALLED ON WELLHEAD PRE-RIG. -WELL K-06 SHUT-IN AND LOTO(WING& SWAB VALVES)FOR DRILLBY 15:30 - 16:30 1.00 MOB P PRE SET UTILITY MODULE NEXT TO DRILL MODULE AND LEVEL. Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP • Page 2 o Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 18:30 2.00 RIGU P PRE SET MUD MODULE NEXT TO DRILL MOD AND LEVEL. -PLUG IN ELECTRICAL INTERCONNECTS ON UM 18:30 - 20:00 1.50 MOB P PRE COMPLETE RIGGING UP INTERCONNECTS 20:00 - 21:00 1.00 RIGU P PRE RAISE DERRICK DERRICK PICKED OFF STAND AT 527 KLBS 21:00 - 22:00 1.00 RIGU P PRE SKID RIG FLOOR AND CATTLE CHUTE INTO PLACE. 22:00 - 23:00 1.00 RIGU P PRE GENERAL RIG UP ON RIG FLOOR -MAN RIDERS,STEAM HEATERS -RIG UP PIPE SHED -RIG UP DUMMY WELLHOUSE -TAKE ON 8.5PPG SEAWATER TO PITS 23:00 - 00:00 1.00 RIGU P PRE BRIDLE DOWN. RIG UP TOP DRIVE AND BLOCKS 12/17/2015 00:00 - 01:00 1.00 RIGU P PRE COMPLETE BRIDLING DOWN AND RIGGING UP TOP DRIVE -CALIBRATE BLOCKS -RAISE PIPE CAT 01:00 - 04:30 3.50 RIGU P PRE GENERAL RIG UP AND HOUSEKEEPING -RIG UP TOTESTTWC —CH2 RIG UP CREW SPOT TIGER TANKAND INSTALL HARDLINE(LEAKTIGHT PT TO 4000 PSI-PASS) -QUADCO TECHNICIAN ON LOCATION TO CHECK&CALIBRATE PVT SENSORS(SEE ATTACHED REPORT) -WSLAND RIG MANAGER COMPLETE WALKAROUND FOR RIG READINESS 04:30 - 05:30 1.00 RIGU P PRE RIG EVACUATION DRILL WITH MANDOWN SCENARIO+MR PRE-SPUD MEETING WITH YEAROUT CREW ***ACCEPT RIG AT 05:30 12/17/2015*** 05:30 - 08:00 2.50 DHB P PRE PRESSURE TEST TWC TO 250 PSI LOWAND 3500 PSI HIGH FOR FIVE MIN EACH FROM ABOVE AND BELOW WITH 6.8PPG DIESEL -PASSING TESTS(SEE ATTACHED CHART) 08:00 - 09:00 1.00 RIGU P PRE NIPPLE DOWN TREE AND ADAPTER -FMC REP ON LOCATION TO BLEED DOWN VOID PRESSURE BARRIERS TO NIPPLE DOWN: TUBING: CEMENT PLUG,KILL WEIGHT FLUID, TESTED TWC 09:00 - 10:00 1.00 RIGU P PRE INSPECT TUBING HANGER WITH FMC REP -MAKEUP HANGER THREAD XO(8.5 TURNS)- GOOD CONDITION -CHECK TUBING SPOOL LOCK DOWN SCREWS PER FMC 10:00 - 12:00 2.00 BOPSUR P PRE NIPPLE UP HIGH PRESSURE RISERS TO WELLHEAD -SET BOP STACK ONTO RISERS SIMOPS: -PRE-SPUD MEETING WITH MALLORY CREW -PERFORM DERRICK INSPECTION Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP Page 3 V Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 20:30 8.50 BOPSUR P PRE NIPPLE UP BOP STACK -CHECK TORQUE ON ALL BOP CONNECTIONS(QUARTERLY PER PARKER) -CHANGEOUT ALL DOOR SEALS -CHANGEOUT UPPER RAMS FROM 2-7/8"X VBR TO 7"FIXED -BUILD 7",4-1/2"&4"TEST JOINTS SET BELL NIPPLE -GREASE ALL VALVES -CHECK ACCUMULATOR BOTTLE PRE-CHARGE 13-5/8"5K SHAFFER STACK: -ANNULAR PREVENTER -7"FIXED BORE UPPER RAM -BLIND/SHEAR RAM -MUD CROSS -2-7/8"X 5-1/2"LOWER VBR 20:30 - 21:30 1.00 BOPSUR P PRE RIG UP TO TEST BOPE -FILL STACK WITH WATER AND PURGE AIR -FLUID PACK LINES -SHELL TEST BOP STACK 21:30 - 00:00 2.50 BOPSUR P PRE TEST BOPE TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH WITH 7"TEST JOINTS -TESTWITNESSED BY AOGCC REP JEFF JONES 12/18/2015 00:00 - 01:00 1.00 BOPSUR P PRE TEST BOPE TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH WITH 7"TEST JOINTS -ALL TESTS WITH 7"TEST JOINT PASS -TEST RAM LOCKS -TEST GAS AND PVT ALARMS -DOOR SEAL FAILURE ON LOWER PIPE RAMS DURING BLIND/SHEAR TEST 01:00 - 02:30 1.50 BOPSUR N RREP 0.07 PRE NON IADC CODE 8 NPT:CHANGEOUT DRILLERS SIDE LOWER PIPE RAM DOOR SEALS 02:30 - 04:30 2.00 BOPSUR P PRE TEST BOPE TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH WITH 4-1/2"&4"TEST JOINTS -RE-TEST BLIND/SHEAR RAMS(PASS) -ALL TESTS WITH 4-1/2"&4"TEST JOINTS PASS -CONDUCT DRAW DOWN TEST ON ACCUMULATOR -ALL TESTS CHARTED(SEE ATTACHED BOP TEST CHARTS) -TESTS WITNESSED BYAOGCC REP JEFF JONES 04:30 - 05:00 0.50 BOPSUR P PRE RIG DOWN BOPE TEST EQUIPMENT 05:00 - 07:30 2.50 DHB P PRE RIG UP DUTCH RISER AND LUBRICATOR WITH EXTENSION PIECES 07:30 - 08:00 0.50 DHB P PRE PRESSURE TEST LUBRICATOR TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN -TEST CHARTED(SEE ATTACHED) 08:00 - 09:00 1.00 DHB P DECOMP PULL TWC -VERIFY WELL IS DEAD -RDMO VALVE SHOP LUBRICATOR Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP Page 4 Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL(g73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:00 1.00 PULL P DECOMP DISPLACE DIESEL FREEZE PROTECT FROM WELLBORE WITH 300 BBL 8.5 PPG SEAWATER UNTIL CLEAN RETURNS -LINE UP IA VALVE TO FLOWBACK TANK AND STAGE PUMPS TO 10 BPM,1950 PSI -FLOWCHECK WELL FOR 10 MIN(STATIC) 10:00 - 11:00 1.00 PULL P DECOMP UNSEAT TUBING HANGER AND DISPLACE REMAINING DIESEL -RUN IN HOLE WITH XO ON LANDING JOINT AND ENGAGE TUBING HANGER WITH 8-1/2 TURNS -BACK OUT LOCK DOWN SCREWS -UNSEAT HANGER WITH 79 KLBS -PICKUP 5'TO TOOL JOINT TO VERIFY SPACEOUTAND CLOSE ANNULAR PREVENTER -LINE UP IA VALVE TO FLOWBACK TANK AND STAGE PUMPS TO 10 BPM,1950 PSI -CIRCULATE SURFACE TO SURFACE WITH 8.5 PPG SEAWATER TO CLEAR WELL OF REMAINING DIESEL 11:00 - 12:00 1.00 PULL P DECOMP PULL TUBING HANGER -FLOWCHECK WELL FOR 10 MIN(STATIC) -LAYDOWN HANGER AND PUP(HANGER IN GOOD CONDITION) CHANGEOUT ELEVATORS 12:00 - 16:30 4.50 PULL P DECOMP PULL AND LAYDOWN 4-1/2",12.6#,L-80 IBT-M COMPLETION TUBING FROM 3815'MD TO SURFACE(INSPECT ALL EQUIPMENT FOR NORM PRIOR TO LEAVING LOCATION) -2.1'TUBING HANGER/PUP -91 FULL JOINTS -10'PUP -28'GLM ASSY WITH PUPS -25'X-NIP ASSY WITH PUPS -CUT JOINT=3.05',FLARE OD=5"(GOOD CUT) -TUBING IN GOOD CONDITION(NO CLEANOUT RUN REQUIRED) -PUW=74K,SOW=74K SIMOPS:MI/RU SLB E-LINE UNIT AND LOAD TOOLS TO RIG FLOOR 16:30 - 17:00 0.50 EVAL P DECOMP INSTALL WEAR RING,ID=6-15/16" 17:00 - 18:00 1.00 EVAL P DECOMP RIG UP E-LINE AND LOGGING TOOLS -CONFIRM NO PRESSURE CONTROL WITH WTL(ONLY LINE WIPER WITH INTEGRAL CUTTER PER SOP) 18:00 - 19:30 1.50 EVAL P DECOMP RIG UP AND RUN GAUGE RING/JUNK BASKET TO 3815'MD(NO ISSUES) SIMOPS:PICK UP 4"DRILL PIPE OFFLINE 19:30 - 00:00 4.50 EVAL P DECOMP RIG UP AND RUN USIT LOGGING TOOLS IN PDC MODE FROM 3815'MD TO 2082'MD SIMOPS:PICK UP 4"DRILL PIPE OFFLINE 12/19/2015 00:00 - 01:00 1.00 EVAL P DECOMP RIG UP AND RUN USIT LOGGING TOOLS IN PDC MODE FROM 2082'MD TO SURFACE -LOG INDICATES TOP OF OA CEMENT AT —3700'MD(PER PETROPHYSICIST) SIMOPS:PICK UP 4"DRILL PIPE OFFLINE 01:00 - 02:30 1.50 EVAL P DECOMP RIG DOWN LOGGING TOOLS AND SLB E-LINE Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP • Page 5 Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 03:00 0.50 CUT P DECOMP MAKE UP BAKER 5-1/4"MULTI-STRING CUTTER BHA -6-1/8"STABILIZER 03:00 - 04:30 1.50 CUT P DECOMP RUN IN HOLE WITH CASING CUTTER ASSEMBLY FROM SURFACE TO 3640'MD -PICK UP 36 4"DP SINGLES AND THEN RUN 27 4"DP STANDS BUILT OFFLINE 04:30 - 06:00 1.50 CUT P DECOMP CUT 7"CASING AT 3640'MD —ATTEMPT TO LOCATE COLLARS WITH BLADES AT 3660'MD AND 3700'MD:CANNOT LOCATE DUE TO METAL TO METAL SEAL OF IJ4S CONNECTION -OA PRESSURE BLED TO ZERO PRIOR TO CUTTING -PUW=85 KLBS,SOW=90 KLBS,ROT=89 KLBS AT 3640'MD -100 RPM,1.5-2K FT-LBS TQ -4 BPM,600 PSI -LOSS OF 440 PSI CIRC PRESSURE INDICATES GOOD CUT -OA PRESSURE INCREASE FROM 0 PSI TO 175 PSI 06:00 - 06:30 0.50 CUT P DECOMP CIRCULATE OUT OA FREEZE PROTECT THROUGH OA VALVES TO FLOWBACK TANK -BEGIN TO SPOT 100 BBL 8.5 PPG BARAKLEAN IN OAAT 2 BPM,120 PSI -OBSERVE LEAKS FROM 2 TUBING SPOOL LOCKDOWN SCREWS DURING CIRCULATION AND SHUT DOWN 06:30 - 08:30 2.00 CUT N SFAL 0.07 DECOMP TROUBLESHOOT LEAKING TUBING SPOOL LOCKDOWN SCREWS -ENGAGE DIFFERENT LOCKDOWN SCREWS ON THE WEAR RING AND RESUME CIRCULATION -DIFFERENT LOCKDOWN SCREW LEAKING AND SHUT DOWN -CALLOUT FMC REP TO DIAGNOSE AND CONTACT DRILLING SUPTAND ODE TO DISCUSS POSSIBLE PLAN FORWARD -FMC REP CHECKS AND RE-TORQUES ALL GLAND NUTS AND ENGAGED SCREWS -GLAND NUTS HAD NOT BEEN TORQUED TO MARKED 12-0-CLOCK POSITION -PRESSURE TEST WELLBORE TO 500 PSI FOR 5 MIN TO VERIFY LEAK-TIGHT LDS PER OPS NOTE(PASS-NO LEAKS) SIMOPS:BUILD 4"DP STANDS OFFLINE 08:30 - 10:30 2.00 CUT P DECOMP CIRCULATE OUT OA FREEZE PROTECT THROUGH OA VALVES TO FLOWBACK TANK -SPOT 100 BBL 8.5 PPG BARAKLEAN IN OAAT 2 BPM,140 PSI(SOAK ANNULUS FOR 20 MIN) -CIRCULATE 200 BBL 8.5 PPG SEAWATER AT 6 BPM,1080 PSI UNTIL CLEAN RETURNS -SEND 134 BBL DISPLACED CRUDE TO HYDROCARBON RECYCLE 10:30 - 12:30 2.00 CUT P DECOMP POOH ON ELEVATORS FROM 3640'MD TO SURFACE -FLOWCHECK FOR 10 MIN(STATIC) Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP Page e Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud DateRme:12/14/1994 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. U M:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 13:00 0.50 CUT P DECOMP LAYDOWN BAKER 5-1/4"MULTI-STRING CUTTER ASSEMBLY -CUTTERS IN GOOD CONDITION,ALL PARTS RECOVERED 13:00 - 13:30 0.50 PULL P DECOMP PULL WEAR RING 13:30 - 14:30 1.00 PULL P DECOMP MAKE UP BAKER CASING SPEAR ASSEMBLY AND RUN IN HOLE TO ENGAGE 7"CASING -FMC REP DISENGAGES LOCKDOWN SCREWS SIMOPS:RIG UP DOYON CASING TOOLS 14:30 - 15:30 1.00 PULL P DECOMP PULL 7"CASING HANGER TO RIG FLOOR -UNSEAT HANGER WITH 134 KLBS -PU/SO FREE WEIGHTS=117 KLBS -REMOVE PACKOFF AND LAYDOWN HANGER WITH PUP 15:30 - 16:00 0.50 PULL P DECOMP CIRCULATE 100 BBL BOTTOMS-UP WHILE RECIPROCATING -8 BPM,150 PSI WITH CLEAN RETURNS 16:00 - 21:00 5.00 PULL P DECOMP PULL AND LAYDOWN 7",26#,NT-80,IJ4S CASING FROM MECHANICAL CUT AT 3640'MD TO SURFACE(INSPECTALL EQUIPMENT FOR NORM PRIOR TO LEAVING LOCATION) -10'PUP -92 FULL JOINTS -CUT JOINT=21.30',NO FLARE(GOOD CUT) -CASING IN GOOD CONDITION 21:00 - 22:00 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -RIG DOWN DOYON CASING TOOLS 22:00 - 22:30 0.50 CLEAN P DECOMP SET WEAR RING,ID=12.5" 22:30 - 23:00 0.50 CLEAN P DECOMP RIG SERVICE:GREASE TOP DRIVE,BLOCKS &WASH PIPE 23:00 - 00:00 1.00 CLEAN P WEXIT MAKE UP BAKER 9-5/8"CASING CLEANOUT ASSEMBLY 12/20/2015 00:00 - 02:00 2.00 CLEAN P WEXIT MAKE UP BAKER 9-5/8"CASING CLEANOUT ASSEMBLY FROM SURFACE TO 791'MD -8-1/2"MILL TOOTH BIT WITH WATERMELON MILL -SINGLE IN 9 JT 6-1/2"DRILL COLLARS -SINGLE IN 15 JT 5"HWDP 02:00 - 03:00 1.00 CLEAN P WEXIT RUN IN HOLE WITH 4"DP ON ELEVATORS FROM 791'MD TO 3525'MD(NO ISSUES) 03:00 - 03:30 0.50 CLEAN P WEXIT REAM PROPOSED WHIPSTOCK SETTING DEPTH 3 TIMES WITH WATERMELON MILL FROM 3510'MD TO 3560'MD(NO ISSUES) -500 GPM,1100 PSI -40 RPM,1K FT-LBS TAG 7"CASING STUB ON DEPTH AT 3640'MD 03:30 - 04:00 0.50 CLEAN P WEXIT CIRCULATE BOTTOMS-UP WHILE RECIPROCATING PIPE -700 GPM,1900 PSI -PUMP 20 BBL HI-VIS SWEEP:NO SPECIAL RETURNS 04:00 - 05:00 1.00 CLEAN P WEXIT PULL OUT OF HOLE ON ELEVATORS FROM 3575'MD TO BHAAT 791'MD Printed 1/6/2016 5:42:44PM • North America-ALASKA-BP • Page 7 Operation.Summary Report Common Well Name:K-19 AFE Na Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-198 ACTUAL l73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 06:00 1.00 CLEAN P WEXIT LAYDOWN BAKER 9-5/8"CASING CLEANOUT ASSEMBLY FROM 791'MD TO SURFACE -RACK BACK 5"HWDP AND 6-1/2"DRILL COLLARS -LAYDOWN BAKER CLEANOUT TOOLS (NOTHING TO NOTE IN BOOT BASKETS) 06:00 - 06:30 0.50 CLEAN P WEXIT CLEAR AND CLEAN RIG FLOOR 06:30 - 08:00 1.50 DHB P WEXIT RIG UP SLB E-LINE AND TOOLS RIG UP SHEAVES -PICK UP GR/CCL AND EZSV 08:00 - 09:30 1.50 DHB P WEXIT RUN IN HOLE WITH EZSV ON E-LINE AND SET TOP AT 3540'MD(6'ABOVE COLLAR AT 3546' MD) -LOG 9-5/8"CSG COLLARS ACROSS PROPOSED WHIPSTOCK SETTING DEPTH -GOOD SET AND POOH WITH E-LINE SIMOPS:MAKE UP MILLING ASSEMBLY OFF-LINE 09:30 - 10:00 0.50 DHB P WEXIT PARTIALLY RIG DOWN SLB E-LINE AND STANDBY FOR PASSING CASING TEST 10:00 - 11:00 1.00 DHB P WEXIT PRESSURE TEST 9-5/8"SURFACE CASING AND EZSV PLUG TO 250 PSI LOW FOR 5 MIN/ 3000 PSI HIGH FOR 30 MIN EACH -PASS PER BP INTEGRITY TESTING CRITERIA(SEE ATTACHED CHART) -19 PSI LOST IN FIRST 15 MIN/9 PSI LOST IN SECOND 15 MIN -TEST APPROVED BY WTL -TEST CONFIRMS INTEGRITY OF LOCK DOWN SCREWS AND GLAND NUTS 11:00 - 11:30 0.50 DHB P WEXIT COMPLETE RIG DOWN SLB E-LINE AND TOOLS 11:30 - 14:30 3.00 STWHIP P WEXIT MAKE UP WHIPSTOCK/STIFF MILLING ASSEMBLY FROM SURFACE TO 831'MD -MAKE UP LOWER MILLING ASSEMBLY(MILL, 3 WATERMELON MILLS,HWDP,FLOAT,UBHO) -ATTACH MILL TO WHIPSTOCK WITH SHEAR PIN -SCRIBE IN HOLE WITH BAKER 9-5/8"GEN II ONE-RUN WHIPSTOCK/MILLING ASSEMBLY (DD AND GYRODATA REP CONFIRM TRAY FACE SCRIBE TO UBHO) -RUN IN HOLE WITH 3 STANDS 6-1/2"DRILL COLLARS AND 5 STANDS 5"HWDP SIMOPS:RIG UP SPERRY E-LINE/GYRODATA 14:30 - 16:00 1.50 STWHIP P WEXIT RUN IN HOLE WITH WHIPSTOCK/MILLING ASSEMBLY FROM 831'MD TO 3482'ON ELEVATORS Printed 1/6/2016 5:42:44PM • North Attterica-ALASKA.-BP II Page a oat Operation Summary Report Common Well Name:K-19 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/15/2015 End Date: X3-017G9-C:(9,909,516.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:PARKER 272 Spud Date/Time:12/14/1994 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292253100 Active datum:K-19B ACTUAL @73.32usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 19:00 3.00 STWHIP P WEXIT SET WHIPSTOCK TOP AT 3518'MD WITH 109 DEG GYRO TOOLFACE(VERTICAL HOLE)AS FOLLOWS: -RUN GYRO SURVEY TO ORIENT WHIPSTOCK AND RUN IN HOLE TO 3514'MD -RUN GYRO SURVEY TO CONFIRM WHIPSTOCK ORIENTATION AND RUN IN HOLE TO TAG EZSV ON DEPTH AT 3540'MD -SET DOWN 21 KLBS PER BAKER REP TO SHEAR AND SET ANCHOR(CONFIRM GOOD SET WITH 10 KLB OVERPULL) -SHEAR TRAY PIN DOWN WITH 50 KLBS -PICK UP 5'ABOVE TOP WHIPSTOCK TO BEGIN DISPLACEMENT 19:00 - 20:00 1.00 STWHIP P WEXIT DISPLACE WELL FROM 8.5 PPG SEAWATER TO 9.4 PPG LSND MILLING FLUID -600 GPM,1300 PSI -OBTAIN NEW SPR'S cipitir 20:00 - 00:00 4.00 STWHIP P WEXIT MILL 8-1/2"WINDOW IN 9-5/8",47#SURFACE J CASING PER BAKER REP FROM 3518'MD TO 1°01) 3534'MD AT MIDNIGHT -400 GPM,720 PSI -80-100 RPM,2-9 KFT-LBS TQ STAGE UP WOB(1-9 KLBS) -GOOD CEMENT AND METAL SHAVINGS IN RETURNS PUMP 40 BBL HI-VIS SWEEP AT 3526'MD:NO INCREASE OVER BASELINE METAL SHAVINGS SIMOPS:MAKE UP 8-1/2"DRILLING ASSEMBLY AND 4"DP STANDS OFFLINE 12/21/2015 00:00 - 01:30 1.50 STWHIP P WEXIT MILL 8-1/2"WINDOW IN 9-5/8",47#SURFACE CASING PER BAKER REP FROM 3534'MD AT MIDNIGHT TO BOTTOM OF WHIPSTOCK TRAY AT 3535'MD AND DRILL 20'NEW FORMATION (AS MEASURED FROM MID WHIPSTOCK TRAY AT 3526'MD)TO 3546'MD -400 GPM,720 PSI -100 RPM,1-2 KFT-LBS TQ -2-6 KLBS WOB -FORMATION SAMPLE CONFIRMED 01:30 - 02:30 1.00 STWHIP P WEXIT CIRCULATE 1-1/2 BOTTOMS-UP -DRIFT WINDOW(NO ISSUES) -PUMP 40 BBL HI-VIS SWEEP:NO SPECIAL RETURNS -CONFIRM MUD WEIGHT IN/OUT=9.4 PPG FLOW CHECK FOR 10 MIN:STATIC 02:30 - 03:00 0.50 STWHIP P WEXIT PERFORM LOT -MUD WEIGHT:9.4 PPG,3526'TVD,3526'MD -BBL IN/OUT:1.5 BBL -LOT EMW=14.58 PPG(950 PSI LEAKOFF PRESSURE) -KICK TOLERANCE>25 BBL WITH EMW>12.5 PPG -LOT APPROVED BY ODE 03:00 - 03:30 0.50 DRILL P INTI MILL ADDITIONAL 6'NEW FORMATION TO 3552'MD TO ENSURE UPPER WATERMELLON MILL PASSES FULLY THROUGH WINDOW -PERFORM FINAL DRY DRIFT(NO ISSUES) Printed 1/6/2016 5:42:44PM NOTES 'IACTUATOR= 4-1/16"'� BAKI32 T-19A L 1 EDL 1'0 44'PSTOCK8�PACKER 4_.:_ _` KB.E LEV= 54.25' BF.ELEV= 25.5' K_OP= _ __ 8279' Max Angle_= 93 @ 10713' WS(12/20/15) — 3618' Datum = —.�. 9615' DatuV = ---.-8850'SS EZSV(12/20/15) H 3640' -------------../u---- 3640' H 7"CSG CUT(12/19/15) rAz 9-5/8"CSG,47#,NT80 NSCC/BTC,13=8.681" —I 3704' TBG CUT(12/09/15) —1 3815' •�•1,1"•1�s•irs• TOC(12/06/15) — 4886' 444.6.4.41.4.AVA =INIENI TOC(11/18/15) -i —8163' 4.4.....4A 8173' ELM—j4-1/2^CMT REfA1'JB (11/15/15) 8168' H4-1/2"HES X NP,D=3.813" K-19A Minimum ID =3.8" 8222' II*. 114. Myk. 8179' H7"X 4-1/2"BKR PROD PKR,b=3.875" 4-1/2" HES XN MILLED NIPPLE 41P44Ill 411P 4soi■ 8202' H4-1/2"HES X NP,ID=3.813" K-19A L1 Minimum ID =2.372" @ 10060' .4 3-1/2" X 2-7/8" XO 8222' —14-1/2"HES XN NP,MILLED ID=3.8 .11 8231' H 7"x 4-1/2"BKR TP BACK SLV if i 8234' —14-1/2"WLEG,D=3.958" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ND=3.958" — 8234' 1Iltfl 8244' —I SMD TT LOGGED 09/18/98 j j 8240' 7"X 5"BKR ZXP PKR Iw/HMCLNRHGR,D=4-375" if*: 8261' --15"X 4-1/2"X0,ID=3.980^ i44 hit?. ilii 7"CSG,26#,NT80 U4S,ID=6276 — 9246' earmsl i, 7"MLLOUT WINDOW(K 19A) 8426'-8440' • A PERFORATION SUMMARY Y WN, taiek44)4 RB LOG:SPERRY M ID/GR/RES ON 09/09-10/98 4-1/2"MLLOUT VIANDOW(K-19A L1) 10034'-10040' ANGLE AT TOP FERE:86 @ 10100' ilk* 1 Note:Refer to Production DB for historical perf data 10057' —13.7"BKR DEPLOYMENT SLV,O=3.0" SIZE SPF 1NT RVAL Opn/Sqz DATE K-19A 10060' —I3-1/2"X 2-7/8^XO,ID=2.372" 2-7/8" 4 10100-10300 C 09/24/99 2-3/4" 4 10300-10400 C 09/14/98 :OA ir Att.- N. I 3-3/4"OPEN HOLE 2-3/4" 4 10440-10700 C 09/13/98 2-3/4" 4 10750-10800 C 09/14/98 le 2-3/4" 4 11100-11330 C 09/14/98 2-3/4" 4 11400-11590 C 09/14/98 `�`, PBTD -I 11547 2-3/4" 4 11640-11690 C 09/14/98 � ' K-19A L1 SLOTTED LlNB2 10960'CTM —4-1/132; "FES EZ DRLL 2-7/8" SLOT 10061-10368 C 12/15/03 01115/06 10533-11541 12/15/03 11680'CTM H BKR GBP(PUSHED PBTD — 11705' LA� TO BTM 06/04/05) /���1;W, 4-1/2"LNR,12.6#,L-80,-0152 bpf,13=3.953" —IJ 11795' 2-7/8"LNR,6.16#,L-80, ®=2.377" — 11575' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/03/95 ORIGINAL COMPLETION 06/28/09 SEW/TLH GLV CIO&PX PLUG SET(06/14/09) WELL: K 19AL1 09/14/98 SIDETRACK(K-19A) 07/29/09 CJN/PJC PULURESET PX PLUG(07/25/09) PERMf No: 2031900 12/16/03 TMNIKK CTD LATERAL(K-19A Li) 11/16/15 GTW/JMD PULLED PX PLUG(11/14/15) AR No: 50-029-22531-06 01/03/04 RM-YKK GLV GO 11/16/15 JCMJMD SET ELMD CBP(11/15/15) SEC4,T11N,R14E,504'NSL 8 4760'VVEL 06/07/05 BMcN/TLH CEP PUSH TO BTM 01/13/16 TR/J1\13 PRE-RIG EDITS 01/21/06 KCF/PAG CEP(01/15/06) BP Exploration(Alaska) ti ofd • • cI%7,cs• THE STATE Alaska Oil and Gas of AsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov SC POE OED Mary Endacott Engineering Team Lead 198 — I6•c3 q BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-19A Sundry Number: 315-637 Dear Ms. Endacott: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �r7c Cathy P Foerster Chair DATED this 4 day of October, 2015 Encl. RBDMS OCT 2 3 2015 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROV LS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill IA • Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 198-168 • 3. Address: P.O.Box 196612.Anchorage,AK Exploratory 0 Development Q 99519-6612Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22531-01-00 • 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECEIVED Will planned perforations require a spacing exception? Yes ❑ No m PBU K-19A • 9. Property Designation(Lease Number): 10. Field/Pools: OCT 2015 ADL 028303&028304• PRUDHOE BAY,PRUDHOE OIL• f' /J/ 11. PRESENT WELL CONDITION SUMMARY / �y Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk n are 11795 • 8963 • 8168 8166 8168,10960 11680 Casing Length Size MD ND Burst collapse Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 3668 9-5/8" 28-3696 28-3695 6870 4760 Intermediate 8400 7" 26-8426 26-8419 8160 7020 Production Liner 3555 4-1/2" 8240-11795 8238-8963 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10100-11690 8951 -8960 4-1/2"12.6# L-80 24-8237 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 8182/8180 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal RI 13.Well Class after proposed work: BOP Sketch a Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development El ' Service 0 14.Estimated Date for Commencing Operations: November 1,2015 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended VI 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned o Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Nocas,Noel Email Noel.Nocas@bp.com Printed Name Mary Endacott Title Engineering Team Lead Signature -'11 . , • , - Phone +1 907 564 4388 Date ,,,,,pA, COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP TestV-- Mechanical Integrity Test 0 Location Clearance 0 Other: 130P firs 71- to 3 50V 1,5,1i (NA p 5 1-) is 24 7_0 p 5/5 A V)k1( 14✓pY—z'vev. t-Zre-- -J- to ZSvo iii.ii.),-1.,i Spacing Exception Required? Yes 0 No 12'/ Subsequent Form Required: /61 — Lf 6 ati% `! Approved by: "12u4......1 APPROVED BYTHE COMMISSIONER COMMISSION Date:/0--2/—/S-- ORIGINAL ate`-u_/S--ORIGINAL RBDMS3t, 1.3 1015 ,01io434, Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,,,,,, Z> lit.,•/3-i-.s' • • • GP 6pediff...tfreigy K-19A Sundry Application Well Type: Producer Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of Prudhoe Bay well K-19A to sidetrack and complete K- 19B. MIT-IA Fails- LLR 3BPM at 1600psi (Leak @-5630'MD) MIT-OA Passed to 2000psi (6/23/2015) PPPOT-T Passed to 5000 psi(6/20/2015) PPPOT-IC Passed to 3500 psi(6/20/2015) Well History: Well K-19A was drilled in September 1998 as a horizontal rig sidetrack targeting the lower Ivishak Zone 1 mouth bar sands in southern K Pad GD. By March of 1999 the GOR had climbed to MGOR • and K-19A went on intermittent production. The gas mechanism appeared to be high perm sands in the toe of the well. A CIBP was set to isolate the toe. A CTD lateral was added to the rate stream in 2003. In 2009 a cretaceous leak was found and evaluated to be at 5630'MD and the well was shut in. The best use for this wellbore-IS-a sidetrack to a new location. . 1.kt t ,;,<s�c''e- A62 ze- . & r" 2ce-= / 44.. 'aL&c'e-a 339 50&b 4/$4.-P Scope of Work: C 3-57 / /5 Prior to rig operations the lower perforations and slotted liner will be plugged and abandoned per • AOGCC regulations. A lateral cement plug will be placed in the wellbore above the production packer • from -5,100' to 8,150'MD. The cement plug will be tested after the cement sets up and TOC will be confirmed with E-line. Afterwards the wellbore will be tested and the OA will be tested in attempt to understand if the shoe is open as it currently passes pressure tests to 2000psi. During rig operations, the tubing will be pulled and the 7" casing will be cut above the surface casing shoe and pulled out of the hole. An EZSV will be set above the casing stub and a pressure test will be performed. A whipstock will be set at approximately 3500' and the 9-5/8" casing will be milled to provide a window for drilling operations. The planned sidetrack will utilize an ultra-slim hole design by drilling 8.5" hole to the top of the Sag River and replacing the current 7" casing. From the 7" casing point, a 6-1/8 " pilot hole will be drilled to BSAD. Upon drilling the pilot hole, fluid samples will be retrieved to determine the NLOC (Net Light Oil Column). Based on sampling results the well will be drilled to TD in Zone 1, maximizing footage within pay. The 6-1/8" hole will be cased and cemented with 4-1/2" production liner. MASP: 2,470 psi -Sag River pore pressure with 0.1 psi/ft gas gradie t to surface P Estimated Start,Dat November 1st, 2714, it (iG� fO „/� 70 wheeli/ A&A/44A 1." ,17-‘ frP Whey t be_ fad avtiaye -fi' Q�f"'�q/e% • �,S' �j0 �rG%�T/�• vcj arteste qr /in bwel1,` (e 'r .0,y- kite eivy�r�Ky T4 We r,�y 4-or red' ill clou al/ow 16r )r"er°1 f eeOve(y ill's Hyl / o iG e pool, K-19B Sundry1 10/6/2015 • • Pre-Rig Prep Work: 1. PA slotted liner and perfs per AOGCC with —60bbls class G cement 2. Tubing punch at—8170 MD 3. Circulate lateral cement plug into TBG and IA with—104bbIs of 15.8ppg Class G cement. TOC at least 5300'MD but no more than 5000'MD 7 e� To C.. 4. MIT-IA to 3000psi, MIT-T to 3000psi 5. Jet Cut tubing at—3800' 6. CMIT-TxIA to 3000 psi (verify no PC leak). Hold pressure on tubing and IA and MIT-OA to 3000 psi. 7. Freeze protect the well to 2200' MD with diesel. 8. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi,function LDS. 9. Install TWC, NU Dryhole tree and test. Install wellhead valves for workover Proposed Drilling Rig Sundry Operations: 1. MIRU Parker 272. 2. Test TWC from below to 3,000 psi for 30 minutes. 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. 4. Pull TWC with lubricator. 5. RU hard lines to BOP. Circulate out diesel freeze protection through choke to tiger tank with clean 8.5 ppg seawater. 6. RU and pull the 4-1/2"tubing from the pre-rig jet cut. 7. Cut 7" casing at—3,600' MD (mechanical Cutter on DP.) Circulate out OA freeze protect 8. RU and pull 7"casing from rig jet cut. 9. RIH with 9-5/8"clean out assembly down to the top of casing stub. 10. RU E-line w/GR/CCL log and set EZSV at—2,768 MD and pressure test to 3,500 psi for 30 min. Chart test. 11. PU 9-5/8"whipstock, bottom trip anchor and 8.5"window milling assembly(to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. 12. Swap the well over to 9.0 ppg fresh water LSND milling fluid. 13. Mill window+20' of new hole and perform LOT. End of Sundry: Start of Permit to Drill (See K-19B PTD application) Project Contacts: Drilling Engineer: Noel Nocas (907)564-5027 (907)229-9532 Production Engineer: Ryan Rupert (907) 564-4238 Geologist: Katherine Cunha (907) 564-5574 K-19B Sundry 2 10/5/2015 0 0 r — ITCE. 4-VIC OW5111 ' SAFETY NOTES:WHIPSTOCK&PACKER AELLICAO= 13-3W RC K-19A L1 1 REIRTEVED fg 10044' ACTUATOR m BAKER KS ELEV= SI 25' 1W ELEV- 25.3 AM. 077.7 IA - 1330p10/iX Colum TAD- 9615' —{ MT__.1---4L1/:7_0035%PP.a.a.sir I Nam tvu- tow ss I 11---- GAS LIT PAUCITELS i 4-1Th0 LTViiTiFey_r TT IT VW LAM-I Karr CA1E -- -:a'Ffigii T-2001-70-71,23c-21.3 LW HT 0 CIW1 •• iiii-J-41 l em. 3 15603155X!I I I,03G-2LS corr.l'i INI 0 .. 2!,7146,r0451 i 1 xaGas our , ea r; K-19A Minimum ID=3.8"@ 8222" ; ---.1 } 11ao,sossi 1 Lo3.6-45, Caff ' ea -STA TERM IRS OTTEICIED PAGANO OANONIGN 4-1/2"HES XN MILLED NPPLE ! 1114it_ Bier -14-trepesxNr 0.3.etri *-------1-"iiiir-'''-fiSiir orx Px PI UG;07/15021 1 K-19A L1 Minimum ID=2.372 0 10060 __. _ 3-1/2"X 2-7/8"X0 iiim 2c--:, tint i---Lr A 4 17 SKR PRCO F1KR,0.3 1/75- 1 L sm j I li 0 1 [ Ir--Er—rr Hff,xmmp miL i eo 10-3 I' .1---a ;- 1 ri..-47-07ViokTFT*ii.x-cx-eiv"j tor 4-0.77 ALM 0=3 Mc , 4-ti7 TOG izak L-00,.0102 WID*3.ser -{ 0264• } . ' 1::-144-1.-111:5-45-ii-L-0011;1M811 % 474 OW i--;r x s-arm ZAP Arti-a1C OR Poi,V'4 ,..,.., _-..., q saw r x 4-1Pe X0,D.3 eR1,1 1 r ca0,2s0,PcSo ugs,0-6.275 111240' 44,/.74. 7:WU ry TT Alen*0*-144) UV',hurt 1'9112 reil.. REFF-00ATEHauwAR, ilafA REF LOG SHERRY MAIICHIREE(I4 =-1008 , [--- ANGLE AT TCP FEW-OS 0101W It. , Relo.ID Nixtieston re to.himorica pve isis % g*t NTERVAL OirgSq z OA TE : 4-ter MI[Mit vdoti.:fiA,socteit k$t itaw to44•3 100MT 1.-.1„r 8/04 001.OY LEW SLW,13 --; • IOW;{to rr x 2,rtr xo,0.2 377 1110=.111 , 2-7w I 4 WOO KM C 00`.-,..4,94 • ' - - 2-3W 4 IDDC0-I0.0074 C C0.0,"0-47303 3-30C OREN kica.€ I 2-34r 1 4 I 1141-t07(X) C C10 1,9e I ...."‹.1,,,•••..,.. _ 2-air i 4 , 10750-100IM C 010404 3-3/4' 1 1 ". 111CC-11330 C 01P1-109C 2-3ir 1 4 i I14'00 11500 C i low cr [ 00./14090 ••• im 2- ' 4 : 110340-IT0110 C 043/141118 K.111A L 1 SLOTTED LINER 2-74` :SLOT% 10051-10388 C 12115413 [ ' loan 11541 i L „ trisi co_ - 30C ........ .., , , Fir11112:111 i 4.vr msa(ml .., ....., IIII icaParvii.ne ! L --.-- —tilimirenii;,--67t COP i'R.Sii19) -.AM..- f_ir-r113 -,__11 7-r/6:1_,' TO 8 IL 08,24,23) Mlill...11 Mr. LIP.12 ea,L-ao, Di 32 tyl,0.1153' ,--I 11 7,16' ' . • ,2,,ir u4t,-ii re.i.-80, 13-2 3 F1-71-M110-1r _ LA 1 P ' PV 131' 1.-Lowtor, - taA0- i HY i o) 44rs FELICI7CE BAY UPC 41143316 ORIGINAL COMPLETION oene.o 1 SENTo/C.'O&PA FILLIG SET(Q6140) wa... is-niALI lanais t, MCETRACK(Kr ISA) I''i 07/2409 CJN-P3C tRI.LT/RESorIN R,UG031128430) I Funin to 'h331003 >121111803: TYPO( CM LATERAL(1-1M LI) AP It 504LN-2253144 ;OL412/04 WOW 'CAN 00 SEC 4,TI IN R141.504 NSL 14760'Y - -- ---4 osxiiies,exxX-iiiiiirciieTusirrlisfii ; _ow tido I,KCF/14Cdr-Ci3-Fialii5a131- j - OP EqNoraMo4(Alaska, --------• K-19B Sundry 3 10/5/2015 S • Ma- 4-to lir OW SU I vdairEAD.= 13-ifer RC K-19AL1 Pre-Rig ACTUATOR BAK/31 X.13 BEY• 54,22/ , ;BF.ELEV= 25.5' SAKTI'moITS:Wilre10124111 PAMIR ricip= am RY TRTCYf 0 00 10•44'. Iiin more• 3s1071.3' I ai 72-41*---H 4-aff 1121 x NP.0-3 sir 1 -13mikaelTVO= SNOB SS ..m,..............---_ .., 0-sir csa,4711,NM PSCOITIO 0•i3„6.0. l• , 3204' Eit GAS LFT LANCRELS K-1SA Minimum ID•3.8-ofa 8222' ; sr to I Ivo'mai Trm VW LATCH PORF-Tr—e".tir" 4-1/2'HES XM IIIII.LED NIPPLE 1 - i 4 3281-3260• 1 Ken-as Ow wr r 0 08/14.4311 A 3 5503 5002 I i 11316-2L8 CST* NI r 0 ..... ,K-19A1.1 Minimum ID=2 372-fp 10060' 2 rose /045 1 1,06.2ts cow C NT : , 1 1 $100 ow i 106-as MN ea i 3-1/2~X 2-7M"XO i ' —7 ••11TATKX1S3 MS TEKED MOOG SAIINIIICI4 Tubmg C ut'e -.i7t4 ,• Mir ...1--L-1__Jr0415 1t0Ve1111/1.1 __...,_ L.aten1CementP lig-5100 4i1.7!,!•,_ c, '' • Tubtrg Punch-al 75 14 D —---‘...'21 Y.Y.9...: -...< - ritiff-Fir____•."4-irr IMOR PlIODRIR,0 ..... I _ azor 4-1/7 HS X NP,V.1 rir Cern entRetatrer-8210MIL — - •$•••••••ir 9 0 il 0 -szEr-1--4F-TrFtaa Zit NiR4IFILC.11-0 032.11-1 414.4 1w .0 4,11,• /0 41N sz,i' 1--7-.4-iir locR mtukcx sty j %04M / ' • y* ••i . war s-4-1i0"BALM 0• 4 vi L- rea.12111 40 32 W.D I-•ailsr 11:23C..__r - ,, ii L'4 ist MC - .71 L0001006,15isj f:: - li_L__40rr_i-,r x r elm no.PRI w 441C LAP NOLO-4 ITV .......... i Mi. .1-1:x 4-lir Jrck iu••ler",. F.--090,no,woo maim=tan H OW 'FS trA fla , l'ict roil'woo*ilL44,A I Id174, Raw 1 MIMI. R3IFORA TOM 3LAW/B. faer It T l i 4-,,r uu_our 44414410/1(WPM LB OW -wow REF LOQ SFEFIFY 11,630113PRES OM OROS-tOVE ., , ANGLE AT TOP RN 81.i0102 AM.We;lo IR00.400,,CB sx Pist".41 pee Sok ' - *-171 -fi-7-Mt OfflOY RENT SLY,0•3 0' , WE. '5C4' ertERvA.L. i opwscia Can P' ' , MEMO w..,, I 1c-;----rf-aaio-T-fil72,--iiiziiiFiaii=iiir: to. 2-71W i 4 moo-laxo C Maw A • 4 4• 2-304- i 4 10000 1003) C WWII , 0.44.•, raw i 4 101,40-10200 C MI 3,001 , I .4.4•. 4,41.44.• X 344-OEN PO.E 2-likr ' 1 NM-10100 C i ' , 4 • 4 is •A. '•OA. MOD-MOO C •••••'- .- ,+, • ""•••. • RIM 2-314 4 I 3400 11500 C MANS 1 -.1.- J •i. .. itea 4 ' 4 11603-IM49.•O C CIVIs 1 •,. 1 112=1511 I 10•10'CM -14-u2"PCS GE mit Vs. '14 , 2-7., 9 11 ',1w. 'O'N.P , ' '',' L ,.. ,....p3i risco '11iiii-eiii ino•carreutp4 • .,., . , I 4-1/2•LIP.424, , :., : 14. A: ' ' ,1,4 ___11. p.., ,,,,,, ,,,,c 0.,2 3/7" 1157r I K-19B Sundry 4 10/5/2015 • • PARKER 272 BOP STACK RAN TyPE RCP OLTCH LOCK VAN FLA 1 SHAFFER LxT XX. BCP 13 5/9--51x I I 1 13 5./9.-9. STUDDED TOP L3 5,4V-9.1 FLAKE) RoTTCAA "' • ''' •(--_• It..--"-- 74-...0 OPERATOR.UPPER:AxITY or. .\.5) ANNLILAR Rop 1 1•40(2; 14-PSLk w/BsTR DpERAT0B, Merin(KA rii ripriihir•K SHAFFER Ln is 0/K-9,4 LOWER CAVITY '3- /5. 51. STUMM T3-, 0 13-5,1-9A FLAKE.BOTTON I 0 , 1 1 WILK ORM. _ 13 5,1r-51.4 FLANGED TI' :I 1111IIME ,..i .....joilio.r. !..3 5/Er-94 FLAKED RoTTUA : . .........., • ...111, • . IIIIM xi(2) 3 - ',/5-9•4 SICE OUTLETS -7 ___ --:. vtr•u- . um : im.• 1 _ • KILL UNE I,_ 41111i, •,011%, . 2-1/1A- ski FLEx KSE -----i/JOrAT -.:• .-,H-•H __4 1,. . lar,...IN I.— 1– ,-.'. e,m-,.?,,Iiil 11500.1—"--2-I/16" 9.1 x 3-1,,ir sm Bs A '14%'W' 11P-441/' .3-'/V Sho FLANC.0 IdAmiAL CATE VALE ••— FLAKED HYDRAuLID GATE yALiE - AS •-i . . . CHOKE LINE RAM TYPE BOP' .3—'/8- 5.101 FLANGE", VAN:,AL SATE VALVE SHAFFER LXT SINGLE '3 5/1- Shi 3-78' 5M FLANCES HYDRALLIC GATE VALdE 13 5/B--9A STWOED TCAR 13 5fif- 5)A FLAKED BOTM 3—'/3. 5M FLEX HOSE ri/(2)'4'UL2 OPERATOR K-19B PTD 14 10/5/2015 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then / check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~'~" - / ~ ~ File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Damth~well n TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ ) STATE OF ALASKA ) RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION AUG 0 2 REPORT OF SUNDRY WELL OPERATIOlii~ Oil & 3 005 . 1. Operations Performed: Gas CUllS. Comm,ssI Ji AbandonD Repair WellD PluÇJ PerforationsD Stimulate D Armfuw'ijlMILL CIBP Alter CasingD Pull TubingD Perlorate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perlorate 0 Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 198-1680 6. API Number 50-029-22531-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.25 8. Property Designation: ADL-028304 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: K-19A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 11795 feet true vertical 8963.0 feet Effective Depth measured 11705 feet true vertical 8960.6 feet Plugs (measured) Junk (measured) None Milled CIBP pushed to Bottom @ 11680 (06/04/05) Casing CONDUCTOR SURFACE PRODUCTION LINER Perloration depth: Length 80 3675 8398 3555 Size 20" 91.5# H-40 9-5/8" 47# L-80 7" 29# L-80 4-1/2" 12.6# L-80 MD TVD Burst Collapse 30 110 30.0 110.0 1490 470 29 3704 29.0 3703.0 6870 4760 28 8426 28.0 8419.0 8160 7020 8240 11795 8238.0 8963.0 8430 7500 Measured depth: 10100 -10300,10300 -10400,10440 -10700,10750 -10800,11100 -11330,11400 -11590,11640 -11690 True vertical depth: 8951 - 8955, 8955 - 8955, 8955 - 8951, 8949 - 8948, 8950 - 8952, 8953 - 8958, 8959 - 8960 TubinÇJ ( size, ÇJrade, and measured depth): 4-1/2" 12.6# L-80 @ 26 8234 Packers & SSSV (type & measured depth): 4-1/2" Baker Production PKR 4-1/2" Baker ZXP Packer 4-1/2" Baker HMC LNR HGR 4-1/2" HES X Nipple @ 8179 @ 8240 @ 8240 @ 2010 ~Q'.'l." NNED r~UG 0 B (.DOS ~~¡)~ (: 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl 450 1110 Representative Dailv Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 13642 30245 30 20 Tubing Pressure 186 1803 14. Attachments: ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development ŒI Service D Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature A4g- -ØfJc,~ Title Petroleum Engineer ORIG!NJ~r 564-5174 Date 7/29/05 RBDMS BFl AUG 0 4 2005 Form 10-404 Revised 4/2004 ) ) K-19AL 1 (WORK DONE IN WELLBORE K-19A) DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/16/05 ***WELL WAS FLOWING UPON ARRIVAL*** (PRE CTU MILL CIBP IN WELLBORE K- 19A) DRIFTED WITH 3.51" CENT., AND SAMPLE BAILER TO 8,9361 SLM. STOPPED DUE TO DEVIATION. (SAMPLE BAILER WAS EMPTY) ****BROUGHT WELL BACK ON PRODUCTION**** 06/03/05 CTU #4 MILL CIBP: WELL FLOWING ON ARRIVAL. MIRU. MU 2-7/8" MOTOR & 3.75" JUNK MILL. *** CONTINUED ON 06/04/2005 WSR*** 06/04/05 CTU #4 Mill CIBP: CONTINUED FROM 06/03/2005 WSR. RIH WITH MOTOR & 3.75" MILL. TAGGED CIBP @ 11030'. DISLODGE cibp WITH MILL, MOVES UPHOLE WITH COIL, CAN NOT PUSH DOWN, PISTON EFFECT. MILLED UP CIBP IN PERF ZONE, PUSH TO 11680'. POOH. RDMO. REQUEST PCC TEST WELL IN A COUPLE OF DAYS. FLUIDS PUMPED BBLS 117 50/50 METHANOL WATER 255 EXTRA SLICK 1 % KCL WATER 170 1 % KCL WATER W / 1.5% LUBETEX & 0.25 PPB FLOVIS 372 TOTAL Page 1 TREE = 4-1/16" CrN 5M WELLHEAD = 13-3/8" FMC Ä'ërüÄ'rO'R";' "."" . . .. ""sÄ'k'ER KB. ELEV = 54.25' i3F.ECEV·; ..... '2'i~r5ï KOP = 8279' "ïÌ¡1.iI·x ·Ängl~~.~_~··93··@·1Ói1ài Datum MD = 9615' 'bäiÙm"TVtj";"'" ."" ,.. ." ''''''''ä'só'òï''SS' ') K-19A L 1 SAA..~OTES: WHIPSTOCK & PACKER RETRIEVED @ 10044'. 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 3704' ~ K-19A Minimum ID = 3.8" @ 8222' 4-1/2" HES XN MILLED NIPPLE K-19A L 1 Minimum ID = 2.372" @ 10060' 3-1/2" X 2-7/8" XO 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 8234' 17" CSG, 29#, L-80, ID = 6.184" l-i 9246' PERFORA TION SUMMA RY REF LOG: SPERRY MWD/GR/RES ON 09109 - 10/98 ANGLE AT TOP PERF: 86 @ 10100' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE K-19A 4 10100 - 10300 0 4 10300 - 10400 0 4 10440 - 10700 0 4 10750 - 10800 0 4 11100 - 11330 0 4 11400 - 11590 0 4 11640 - 11690 0 K-19A L 1 SLOTTED LINER 10061 -10368 0 10533-11541 0 2-7/8" 2-3/4" 2-3/4" 2-3/4" 2-3/4" 2-3/4" 2-3/4" 09/24/99 09/14/98 09/13/98 09/14/98 09/14/98 09/14/98 09/14/98 12/15/03 12/15/03 I PSTD l-i 11705' \4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" l-i 11795' DATE 01/03/95 09/14/98 12/16/03 01/03/04 06/07/05 REV BY COMMENTS DA TE ORJGINAL COM PLETION SIDETRACK COM PLETION (K-19A) TMNlKK CTD LATERAL (K-19A L 1) RMH/KK GL V C/O BMcN/TLH CIBP PUSH TO BTM I I 2010' 1-i4-1/2" HES X NIP, ID = 3.813" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LA TCH PORT DATE 4 3261 3260 1 KBG-2LS DOME INT 16 01/03/04 3 5503 5502 1 KBG-2LS SO INT 20 01/03/04 L 2 7046 7045 1 KBG-2LS DMY INT 1 8100 8098 1 KBG-2LS DMY INT I I I 8168' 1-i4-1/2" HES X NIP, ID = 3.813" 1 :8: :8: I 8179' l-i 7" X 4-1/2" BKR PROD PKR, ID = 3.875" ~ ~ I 8202' 1-i4-1/2" HES X NIP, ID = 3.813" I I 8222' 1-i4-1/2" HES XN NIP, MILLED ID = 3.8" 1 ~! 8231' - TIE BACK SLV 1 8234' - 4-1/2" WLEG, ID = 3.958" 1 ~ 8244' l-i ELMD TT LOGGED 09/18/98 8240' 1- 7" X 4-1/2" BKR ZXP LNR 1 PKR & HMC LNR HGR /' MILLOUT WINDOW (K-19A) 8426' - 8440' ø EXIT WINDOW (K-19A L 1) 10034' - 10040' ~ , '- ~ PBTD l-i 11542' 1 111680' CTM 1- BKR CIBP (PUSHED TO BTM 06/04/05) \2-7/8" LNR, 6.16#, L-80, ID = 2.377" 1-1 11575' REV BY COMMENTS PRUDHOE BA Y UNIT WB..L: K-19A L 1 PERMIT No: "2031900 API No: 50-029-22531-06 SEe 4, T11 N, R14E, 504' NSL & 4760' WEL BP Exploration (Alaska) e3i:c°mpiiance Report File on Left side of folder 198-168-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 1179_5_ TVD 08963 Completion Date: K-19A 50- 029-22531-01 Start Stop 9/14/98 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: Name Interval D 8808 2-5 SPERRY GR/EWR4 D 9266 1 PDS PROD L CHEMCTTR FINAL 8610 L DGR/EWR4-MD FINAL 8447-11795 L DGR/EWR4-TVD FINAL 8431-8963 L 1NJQ FINAL 10080-10880 7/27/99 L MCNL FINAL 8008-11703 L PROD PROF 1 8105-11701 T 8946 1 SCHLUM MCNL Daily Well Ops __ -- __ Was the well cored? yes (n~ Comments: OH CH CH 5 OH OH CH 5 CH 2 CH 1 CH Sent Received T/C/D .. 12/30/98 12/30/98 8/4/99 8/4/99 9/22/98 9/24/98 1/6/99 1/6/99 1/6/99 1/6/99 8/4/99 8/4/99 D 11/30/98 12/3/98 T 11/4/98 11/5/98 11/30/98 12/3/98 Are Dry Ditch Samples Required? yeseS) Analysis Description Received? yes ~ And Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, .- Commissioner Tom Maunder, P. I. Supervisor FROM' Chuck Scheve; SUBJECT' Petroleum Inspector DATE: APril 20, 2001 Safety Valve Tests Prudhoe Bay Unit K pad-~ Friday, A~)ril 20, 2001; I traveled to BPXs K Pad and witnessed the 30-day retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with 3 failures. The pilots on wells K-06, K- 07 and K-09 tripped below the required set point. The pilot on well K-09 was retested and operated properly. Wells K-06 and K-07 normally flow into the Iow- pressure system (at 200 to 300 psi) but were recently switched into the high- pressure system. The pilots on these two wells were left in'the Iow pressure setting (125 psi) and tdpped near this set point but were failed on this test due to the: higher flowing tubing pressure required to produce into the high pressure system. These two pilots were adjusted to the higher set pressure (550 psi) and retested at this time. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in fair conditions. Summary' I witnessed the 30-day retest of the safety valve systems at BPXs K- Pad in the Prudhoe Bay Field. PBU K Pad, 11 wells, 22 components, 3 failure 13,6% failure rate 16 welihouse inspections Attachment: SVS PBU K Pad 4-20-01 CS . X.. Unclassified Confidential (Unclassified if doc. removed ) SVS PBU K Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / K Pad Separator psi: LPS 154 Date: 4/20/01 HPS 670 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE K-01 1831210! 670 550 525 P P OIL K-02B 1941350 670 550 525 P P OIL K-03A 1990030 154 125 100 P P OIL K-04A 1970210 K-05A 1931560 K-06A 1981360 670 550 100 3 P 4/20/01 OIL K-07C 1991090 670 550 100 3 P 4/20/01 OIL K-08 1851790 670 550 525 P P OIL K-09B 1970860 670 550 100 3 P 4/20/01 OIL K-10 1871140 K-11 1871170 K-12 1871040 1541 125 110~ P P OIL K-13 1871010 K-14 1870950 K-16A 1981800 154 125 120 P P OIL K-17A 1980610 K-19A 1981680 154 125! 125 P P OIL K-20A 1981500 154 125 150 P P OIL Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.64°/~ 90 Day Remarks: The pilot on well K-09 tripped below the set point it was retested and worked properly Wells K-06 & K-07 were recently switched from the low pressure to high pressure oi train but the pilots were left at the low pressure setting. These pilots were adjusted an retested. RJF 1/16/01 Page 1 of 1 SVS PBU K Pad 4-20-01 CS STATE OF ALASKA ALASKA.-__,,_ AND GAS CONSERVATION COb,-. .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [~Stimulate [] Plugging I~ Perforate I--~ Pull Tubing []Alter Casing []Repair Well []Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3100' NSL, 4766' WEL, SEC. 04, T11N, R14E, UM At top of productive interval 3503' NSL, 487' WEL, SEC. 05, T11N, R14E, UM At effective depth At total depth 3717' NSL, 2562' WEL, SEC. 05, T11N, R14E, UM 5. Type of well: J~ Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 54.25' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number K-19A 9. Permit Number / Approval No. 98-168 10. APl Number 50-029-22531-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11795 feet true vertical 8963 feet Effective depth: measured 11705 feet true vertical 8961 feet Casing Size Structural Conductor 80' 20" Surface 3669' 9-5/8" Intermediate Production 9211' 7" Liner 1508' 4-1/2" Plugs (measured) Junk (measured) Length Cemented 260 sx Arcticset (Approx.) 882 sx PF 'E', 375 sx Class 'G' 276 sx Class 'G' Uncemented Slotted liner MD TVD 110' 110' 3704' 3703' 9246' 8973' 9122'-10630' 8948'-8946' Perforation depth: measured Slotted Liner: 9207' - 10607' true vertical Slotted Liner: 8968' - 8946' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIG!I AL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments I 16. Status of well classifications as: ~ CDa°ilPCe~ e°~°Lr~.? ~vnedl I/SoUpr~re~sn I ~O,I [] Gas [] Suspended 7. I hereby.cel~. ~hat.t~ fore~giflg.~s true arid correct to the best of my knowledge Sig.¢:/~ T IV ~/~, c.-~r~, a~'~~ ~~~ Title Techn,cal Ass,stent Prepared By Name/Number: Service Sub-mit In Duplicat Form 10-404 Rev. 06/15/88 K-19A DESCRIPTION OF WORK COMPLETED ADDPERF O9/24/99 SUMMARY The following additional interval were perforated using 2 7/8" guns, 4 SPF, random orientation and 60° phasing. 10100' - 10300' MD RECEIVED LOV 3 2. ~999 Alaska Oil & Gas Cons. Commission Anchorage TRANStV/ITTAL ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petr~Technical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT(S) Open Hole I I 1 K-1 9Al July 27, 1999 es. Eval. CH __~-~ I I 1 -2.~ ~:..~ ~,? ': :" ', ,~,.-r rr':~ Signed · Date Print Name: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, kK 99734 PhoneQ907) 659-2307 FaxQ907) 659-2314 E-mail: pdsprudhoe@NA800 .net Website: w~v.memo~iog.com C :hVly Documents\Excel_Word_DocumentsXDistribution_Forms~p_pb_form.doc 0 F! I I--I--I IM IS To: WELL LOG TRANSM1Tr~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs K-19A, AK-MW-80353 January 6, 1999 K-19A: 2"x 5"MD Resistivity & Gamma Ray Logs: 50-029-22531-01 1 Blueline 1 Rolled Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22531-01 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE AI'rACHED COPIES OF THE TRANSMITYAL LETTER TO ~ ATYENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Da~N 0 6 1999 Alaska Oil & C~s Cons. Commi~ion BP Exploration (Alaska) Inc. Petro-technical Data Cemer, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Olql I--I_1N 13 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs K- 19A December 30, 1998 AK-MW-80353 1 LDWG formatted Disc with verification listing. API#: 50-029-22531-01 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATFACHFJ~ COPIES OF THE TRANSMITFAL LETYER TO THE A'ITENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 995! 8 RECEIVED DEC 50 1998 Date: Ala¢~ Oii& G~ ~n~. Gommi~;~n BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Si GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12108 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) 11/30/98 Well Job # Log Description Date BL Sepia LIS Tape C-03A ~ ~/~ ~ 98609 MCNL 981013 1 1 1 J-15A '1~ ~<~ ~ q 98610 MCNL 981020 1 1 1 K-19A ,.~ ~ ~ ~;; 98606 MCNL 980918 1 1 1 Z-01 '-~::L-[~'~ 98612 RST-SIGMA 981022 ! 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center M83-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99,503 ATrN: Sherrii~i/~~.., Received l:::~'. ~X, ~./~ BP EXPLORATION Date: 11-4-98 Trans# 89809 BP/PBU CASED HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166. ISw Name IRec Type Rec Date ICompany Code IComments K-19A ICH 01-Nov-98IPDS I PRODUCTION PROFILE Please sign and return one copy of this transmittal. Thank-you, Carla H. Mclntosh Petrotechnical Data Center CH LOGS Becky Clark MB9-3 AOG-~.C; Exxon Phillips Lori Taylor Susan Nisbet Info. Management I blueline I blueline/1 RS I blueline I blueline RECEIVED NOV ~,.~:; 1998 ~as~a 0,, & Gas Cons. Commission Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 11503 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 9/22/98 Well Job # Log Description Date BL RF Sepia LIS Tape A- 32 PERFORATING RECORD 9 8 0 812 I 1 B- 16 PERFORATING RECORD 9 8 0 819 I 1 C-06 PERFORATION RECORD 9 8 0 818 1 1 C-06 CI BRIDGE PLUG RECORD 9 80 819 I 1 C-26 PLUG SETTING RECORD 9 8 0 8 04 I 1 C-26 PACKER SE'ri'lNG RECORD 9 8 0 8 0 7 1 1 D-20 PERFORATION RECORD 9 8 0 815 1 1 E-32 JEWELRY LOG 9 8 0 8 01 I 1 F-04 PERFORATING RECORD 9 80 8 0 6 I 1 G-26 PRE RIG TUBING CUT 9 8 0 8 05 I 1 K- 19 PERFORATION RECORD 9 8 0 5 2 7 1 1 K- 19 A CHEMICAL cu'rrER RECORD 9 80 8 2 0 I 1 K-20 JET CUTrER RECORD 9 80 8 04 I 1 Y-24 'U.t (__. LEAK DETECTION 980808 1 1 Z- 25 PERFORATING RECORD 9 8 0 8 02 1 1 Z- 25 PERFORATING RECORD 9 80 817 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 .e e,ve ~,, STATE OF ALASKA .~_-~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [--I Gas [] Suspended i--] Abandoned E~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-168 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22531-01 4. Location of well at surface ~~!. 9. Unit or Lease Name 3100' NSL, 4766' WEL, SEC. 04, T11N R14E, UM, q~/~ }~' ""-'~ " ~1~4~~~ Prudhoe Bay Unit At top of productive interval ~/~ . 10. Well Number 3503' NSL, 487' WEL, SEC. 05, T11N, R14E, UM r '.~¢:;i;_i.¢~ ! K-leA At total depth ..... ~ 11. Field and Pool 3717' NSL, 2562' WEL, SEC. 05, T11N, R14E, UM ; ..... ' ........... '-" Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 54.25'I ADL 028304 12. Date Spudded8/31/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l 15' Water depth' if °ffsh°re I16' N°' °f c°mpleti°ns9/8/98 9/14/98 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)llS. DirectionalSurvey120. DepthwhereSSSVset121. Thickness of Permafrost 11795 8963 FT 11705 8961 FTI [~Yes [--]No (Nipple) 2010' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES 23. CASING, LINER AND CEMENTING RECORD ~CASlNG SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 47# NT-80 35' 3704' 12-1/4" 882 sx PF 'E', 375 sx Class 'G' 7" 26# NT-80 35' 8426' 8-1/2" 276 sx Class 'G' 4-1/2" 12.6# L-80 8240' 11795' 6" 386 sx Class 'G' ~24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8234' 8179' MD TVD MD TVD 10300' - 10400' 8955' - 8955' 10440' - 10700' 8955' - 8951' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10750' - 10800' 8949' - 8948' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11100' - 11330' 8950' - 8952' 11400' - 11590' 8953' - 8958' Freeze Protect with 72 Bbls of Diesel 11640' - 11690' 8959' - 8906' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) September 21, 1998I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 ~L'~lC~,~t In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 8414' 8407' Shublik 'A' 8468' 8458' Shublik 'B' 8497' 8484' Shublik 'C' 8515' 8501' Sadlerochit / Zone 4B 8530' 8514' Zone 4A 8587' 8554' i Zone 3 8645' 8609' Zone 2C 8703' 8652' Zone 2B 8780' 8704' Zone 2A 9137' 8813' i Zone 1 B 9678' 8865' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing~strue and correct to the best of my knowledge Signed ~_.....~,,-~. ~ DanStone Title Engineering Supervisor Date ~.8, K-19A 98-168 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 27 Aug 98 28 Aug 98 29 Aug 98 30 Aug 98 31 Aug 98 01 Sep 98 Progress Report PB K Pad Well K- 19A Rig Doyon 16 Page 1 Date 07 October 98 12:00-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-02:00 02:00-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-10:00 10:00-13:00 13:00-14:00 14:00-14:30 14:30-15:30 15:30-01:30 01:30-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-16:30 16:30-17:30 17:30-18:00 18:00-06:00 06:00-06:45 06:45-09:15 09:15-10:30 10:30-11:00 11:00-11:45 11:45-12:30 12:30-16:00 16:00-17:00 17:00-18:00 18:00-00:00 00:00-01:00 01:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:15 07:15-07:45 07:45-11:45 11:45-18:00 18:00-18:30 18:30-06:00 06:00-08:00 08:00-08:45 08:45-09:15 09:15-09:30 09:30-18:00 18:00-22:30 22:30-23:30 Duration 6hr 1/2 hr 2hr 1-1/2 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 4 hr 3 hr 1 hr 1/2 hr lhr 10hr lhr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 4hr 1 hr 5 hr lhr 1/2 hr 12hr 3/4 hr 2-1/2 hr 1-1/4 hr 1/2 hr 3/4 hr 3/4 hr 3-1/2 hr 1 hr lhr 6hr lhr 3-1/2 hr lhr 1/2 hr 1/2 hr 3/4 hr 1/2 hr 4hr 6-1/4 hr 1/2 hr 11-1/2 hr 2hr 3/4 hr 1/2 hr 1/4 hr 8-1/2 hr 4-1/2 hr 1 hr Activity Rig moved 85.00 % Held safety meeting Serviced Fluid system Rig moved 100.00 % Retrieved BOP test plug assembly Held safety meeting Circulated at 8460.0 ft Installed BOP test plug assembly Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Retrieved BOP test plug assembly Installed Drillpipe retrieval string Circulated at 8460.0 ft Laid down 8460.0 ft of Tubing Rigged up Tubing handling equipment Tested Bottom ram Installed B ore protector Made up BHA no. 1 Held safety meeting Singled in drill pipe to 3934.0 ft Rigged up Kelly Singled in drill pipe to 8397.0 ft Set tool face Functioned downhole tools at 8426.0 ft Milled Casing at 8426.0 ft Circulated at 8440.0 ft Pulled out of hole to 912.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Made up BHA no. %s R.I.H. to %s Serviced %s Reamed to %s Milled %s at %s Circulated at %s Pulled out of hole to %s Pulled BHA Made up BHA no. 2 Held safety meeting Made up BHA no. 3 Tested M.W.D. tool - Via string R.I.H. to 8400.0 ft Drilled to 8546.0 ft Held safety meeting Drilled to 8802.0 ft Drilled to 8802.0 ft (cont...) Circulated at 8800.0 ft Pulled out of hole to 8450.0 ft R.I.H. to 8802.0 ft Drilled to 8961.0 ft Drilled to 9088.0 ft Circulated at 9085.0 ft Facility Date/Time 02 Sep 98 03 Sep 98 04 Sep 98 05 Sep 98 06 Sep 98 07 Sep 98 08 Sep 98 PB K Pad 23:30-03:00 03:00-04:15 04:15-06:00 06:00-06:30 06:30-07:00 07:00-11:30 11:30-18:00 18:00-18:15 18:15-06:00 06:00-09:30 09:30-13:30 13:30-14:15 14:15-15:00 15:00-15:30 15:30-16:00 16:00-16:15 16:15-18:00 18:00-18:15 18:15-20:30 20:30-21:15 21:15-06:00 06:00-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-21:00 21:00-23:15 23:15-23:45 23:45-02:45 02:45-03:15 03:15-04:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-18:00 18:00-18:15 18:15-06:00 06:00-18:00 18:00-19:30 19:30-20:30 20:30-21:30 21:30-02:30 02:30-06:00 06:00-18:00 18:00-18:15 18:15-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-07:30 07:30-18:00 18:00-18:15 Duration 3-1/2 hr 1-1/4 hr 1-3/4 hr 1/2 hr 1/2 hr 4-1/2 hr 6-1/2 hr 1/4 hr 11-3/4 hr 3-1/2 hr 4hr 3/4 hr 3/4 hr 1/2 hr 1/2 hr 1/4 hr 1-3/4 hr 1/4 hr 2-1/4 hr 3/4 hr 8-3/4 hr 8-1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 2-1/2 hr 2-1/4 hr 1/2 hr 3 hr 1/2 hr 3/4 hr 1/2 hr 1-1/2 hr lhr lhr 8 hr 1/4 hr 11-3/4 hr 12 hr 1-1/2 hr lhr lhr 5hr 3-1/2 hr 12hr 1/4 hr 9-1/4 hr 1~ 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 10-1/2 hr 1/4 hr Progress Report Well K-19A Rig Doyon 16 Activity Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 3 Tested M.W.D. tool - Via string Held safety meeting R.I.H. to 9088.0 ft Drilled to 9210.0 ft Held safety meeting Drilled to 9448.0 ft Drilled to 9456.0 ft Pulled out of hole to 220.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Made up BHA no. 4 Tested M.W.D. tool - Via string R.I.H. to 4800.0 ft Held safety meeting R.I.H. to 9370.0 ft Reamed to 9456.0 ft Drilled to 9753.0 ft Drilled to 9753.0 ft (cont...) Investigated pressure change Circulated at 9893.0 ft Pulled out of hole to 4000.0 ft Held safety meeting Pulled out of hole to 220.0 ft Pulled BHA Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Made up BHA no. 5 Held safety meeting R.I.H. to 8495.0 ft Serviced Block line R.I.H. to 9893.0 ft Drilled to 10040.0 ft Held safety meeting Drilled to 10265.0 fi Drilled to 10487.0 fi (cont...) Circulated at 10487.0 ft Pulled out of hole to 8426.0 ft R.I.H. to 10487.0 ft Circulated at 10487.0 ft Drilled to 10646.0 ft Drilled to 10966.0 ft (cont...) Held safety meeting Drilled to 11248.0 ft Pulled out of hole to 8426.0 fi Serviced Swivel R.I.H. to 8800.0 ft R.I.H. to 11248.0 ft Drilled to 11604.0 ft Held safety meeting Page Date 2 07 October 98 Facility Date/Time 09 Sep 98 10 Sep 98 11 Sep 98 12 Sep 98 Progress Report PB K Pad Well K-19A Page 3 Rig Doyon 16 Date 07 October 98 18:15-23:45 23:45-01:00 01:00-04:45 04:45-05:30 05:30-06:00 06:00-07:00 07:00-08:15 08:15-09:30 09:30-09:45 09:45-10:00 10:00-12:00 12:00-17:00 17:00-18:00 18:00-18:15 18:15-20:00 20:00-20:15 20:15-01:15 01:15-01:45 01:45-04:45 04:45-05:15 05:15-06:00 06:00-07:00 07:00-07:30 07:30-09:30 09:30-09:45 09:45-10:15 10:15-10:45 10:45-11:00 11:00-12:00 12:00-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-19:15 19:15-19:45 19:45-20:45 20:45-05:30 05:30-06:00 06:00-09:45 09:45-10:30 10:30-11:00 11:00-14:45 14:45-15:00 15:00-16:00 16:00-23:00 23:00-23:15 23:15-00:15 00:15-00:30 00:30-02:30 02:30-04:00 04:00-04:45 04:45-06:00 06:00-10:15 Duration 5-1/2 hr 1-1/4 hr 3-3/4 hr 3/4 hr 1/2 hr 1 hr 1-1/4 hr 1-1/4 hr 1/4 hr 1/4 hr 2 hr 5hr lhr 1/4 hr 1-3/4 hr 1/4 hr 5 hr 1/2 hr 3hr 1/2 hr 3/4 hr 1 hr 1/2 hr 2 hr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1 hr 1 hr 1/2 hr 4-1/2 hr 1/2 hr 3/4 hr 1/2 hr lhr 8-3/4 hr 1/2 hr 3-3/4 hr 3/4 hr 1/2 hr 3-3/4 hr 1/4hr lhr 7hr 1/4 hr 1 hr 1/4 hr 2hr 1-1/2 hr 3/4 hr 1-1/4 hr 4-1/4 hr Activity Drilled to 11795.0 ft Circulated at 11795.0 ft Logged hole with LWD: Formation evaluation (FE) from 11795.0 ft to 10000.0 ft Pulled out of hole to 8426.0 ft R.I.H. to 8800.0 ft R.I.H. to 11749.0 ft (cont...) Reamed to 11795.0 ft Circulated at 11795.0 ft Pulled out of hole to 11439.0 ft R.I.H. to 11795.0 ft Circulated at 11795.0 ft Pulled out of hole to 220.0 ft Pulled BHA Held safety meeting Downloaded MWD tool Held safety meeting Ran Liner to 3541.0 ft (4-1/2in OD) Circulated at 3630.0 ft Ran Liner in stands to 8426.0 ft Circulated at 8426.0 ft Ran Liner in stands to 9200.0 ft Ran Liner in stands to 11770.0 ft (cont...) Rigged up Cement head Circulated at 11795.0 ft Held safety meeting Mixed and pumped slurry - 82.000 bbl Displaced slurry - 113.000 bbl Functioned Liner hanger Circulated at 8240.0 ft Circulated at 8240.0 ft Rigged down Cement head Laid down 2496.0 ft of 3-1/2in OD drill pipe Held safety meeting Pulled Drillpipe in stands to 0.0 ft Rigged down sub-surface equipment - Setting tools Laid down 905.0 ft of 3.400 in OD drill pipe Made up BHA no. 6 R.I.H. to 3800.0 ft R.I.H. to 11690.0 ft (cont...) Tested Liner - Via annulus and string Washed to 11705.0 ft Circulated at 11705.0 ft Tested Liner - Via annulus and string Circulated at 11705.0 ft Pulled out of hole to 56.0 ft Pulled BHA Rigged up Tubing handling equipment Held safety meeting Installed Gun assembly Ran Tubing in stands to 3885.0 ft Installed Retrievable packer Ran Drillpipe in stands to 5100.0 ft Ran Drillpipe in stands to 11691.0 ft (cont...) Facility Datefrime 13 Sep 98 14 Sep 98 PB K Pad 10:15-10:30 10:30-10:45 10:45-11:00 11:00-11:15 11:15-12:00 12:00-12:15 12:15-12:30 12:30-20:45 20:45-21:30 21:30-21:45 21:45-01:15 01:15-01:30 01:30-05:00 05:00-05:15 05:15-06:00 06:00-06:30 06:30-15:00 15:00-16:30 16:30-19:00 19:00-19:15 19:15-19:45 19:45-20:15 20:15-20:30 20:30-21:00 21:00-21:15 21:15-00:00 00:00-01:30 01:30-02:15 02:15-03:15 03:15-04:15 04:15-06:00 Duration 1/4 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 1/4 hr 1/4 hr 8-1/4 hr 3/4 hr 1/4 hr 3-1/2 hr 1/4 hr 3-1/2 hr 1/4 hr 3/4 hr 1/2 hr 8-1/2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/4 hr 2-3/4 hr 1-1/2 hr 3/4 hr 1 hr lhr 1-3/4 hr Progress Report Well K- 19A Page Rig Doyon 16 Date Activity Rigged up Circulating head Functioned Retrievable packer Held safety meeting Perforated Reverse circulated at 8071.0 ft Functioned Retrievable packer Rigged down Circulating head Laid down 8060.0 ft of 3-1/2in OD drill pipe Retrieved Retrievable packer Rigged up Tubing handling equipment Laid down 2196.0 ft of Tubing Held safety meeting Rigged down sub-surface equipment - TCP Removed Bore protector Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 8234.5 ft (4-1/2in OD) Space out tubulars Reverse circulated at 8234.5 ft Set Production packer at 8179.0 ft with 3500.0 psi Tested Tubing Tested Permanent packer Bleed down well Installed BOP test plug assembly Held safety meeting Removed BOP stack Installed Xmas tree Tested Xmas tree Removed BOP test plug assembly Circulated at 3261.0 ft Rigged down Completion string handling equipment 4 07 October 98 ~ALASKA4~ leare,d rvlc(~s rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: October 8, 1998 From: Terrie Hubble Technical Assistant Subject: Permit To Drill ~¢98-168, K-19A The location of this well at total depth was listed incorrectly on the original Permit To Drill. This was discovered while computing the bottom hole location for the Completion Report. Originally Permitted (Incorrectly) Should Have Been Permitted Location of well at total depth Location of well at total depth 3297' NSL, 2679' WEL, SEC. 05, T11N, R14E 3694' NSL, 2554' WEL, SEC. 05, T11N, R14E This information was listed correctly on the directional attachments to the Permit to Drill, but not translated correctly. I apologize for any inconvenience this may have caused. Please let me know if there are any further action required. Thank you for your assistance and patience in this matter. /tlh Prudhoe Bay Unit Alaska State Plane Zone 4 PBU WOA K Pad K-19A RECEIVED oct 0 7 1998 BPXA PDC SURVEY REPORT 25 September, 1998 Your Reft API-500292253101 Last Survey Date 08-September-98 Job# AKMW80353 KBE- 54.25' si:3,=,r-,r-,~-sum DRILLING C;ERVICE$ Survey Ref: svy3830 Prudhoe Bay Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 8409.61 17.560 286.244 8348.71 8402.96 8427.00 18.010 282.400 8365.26 8419.51 8454.14 20.780 284.750 8390.86 8445.11 8487.57 24.450 286.920 8421.72 8475.97 8518.34 27.810 288.460 8449.36 8503.61 8553.82 30.800 295.750 8480.34 8534.59 8581.74 33.560 300.570 8503.97 8558.22 8613,60 36.660 300.530 8530.03 8584,28 8645.34 39.530 296.500 8555,01 8609.26 8676.79 41.640 295.890 8578.89 8633.14 8708.50 44.340 295.550 8602.09 8656.34 8737.83 47.270 295.510 8622.53 8676.78 8774.13 51,680 294.450 8646.11 8700.36 8805.83 55.450 294.880 8664.94 8719.19 8837.59 59.570 293.770 8681.99 8736.24 8869.36 63.340 293.510 8697.17 8751.42 8901.21 66.660 292.640 8710.63 8764.88 8932.33 70.340 292.050 8722.03 8776.28 8964.17 74.220 291.770 8731.72 8785.97 8996.13 78,500 292.540 8739.26 8793.51 9030.60 82.410 292.880 8744.97 8799.22 9053.98 82.800 296.500 8747.98 8802.23 9085.87 82.270 296.820 8752.13 8806.38 9117.89 81.950 297.080 8756.52 8810.77 9149.52 82.090 297.700 8760.91 8815.16 9181.66 81.800 297.310 8765.42 8819.67 9213.59 83.620 294.790 8769.47 8823.72 9245.49 85.700 292.690 8772.44 8826.69 9277.47 85.790 292,820 8774.81 8829.06 9309.36 87.680 293.960 8776.63 8830.88 Sperry-Sun Drilling Services Survey Report for K-19A Your Ref: API-500292253101 Local Coordinates Northings (ft) 19.11 S 17.80 S 15.67 S 12,15 S 8.O4 S 1.48 S 5.55 N 14.86 N 24.18 N 33.21 N 42.60 N 51.66 N 63.30 N 73.94 N 84.97 N 96.16 N 107.47 N 118.47 N 129.78 N 141.5O N 154.62 N 164.30 N 178.49 N 192.86 N 207.27 N 221.97 N 235.88 N 248.66 N 261.00 N 273,63 N Global Coordinates Dogleg VeKical Eastings Nothings Eastings Rate Section (~) (~) (~) (°/t00~) (~) 10.63W 5975005.90 N 670777.70 E 6,67 15.78W 5975007.09 N 670772.53 E 7.229 11.97 24.53W 5975009.02 N 670763.73 E 10.602 20.97 36.89W 5975012.26 N 670751.29 E 11.256 33.78 49.75W 5975016.08 N 670738.35 E 10.501 47.20 65.74W 5975022.27 N 670722.21 E 13.452 64.16 78.83W 5975029.00 N 670708.97 E 13.494 78.38 94.61W 5975037,95 N 670692.98 E 9.731 95.68 111.81W 5975046.88 N 670675.56 E 11.960 114.39 130.17W 5975055.49 N 670657.00 E 6.827 134.16 149.65W 5975064.43 N 670637.32 E 8.546 155.11 168.63W 5975073.05 N 670618.14 E 9.990 175.49 193.63W 5975084.12 N 670592.87 E 12.350 202.30 216.81W 5975094.23 N 670569.47 E 11.943 227.12 241.21W 5975104.70 N 670544.81 E 13.303 253.21 266.78W 5975115.31 N 670519.00 E 11.888 280,48 293.33W 5975126,01 N 670492.20 E 10.714 308.74 320.10W 5975136.40 N 670465.18 E 11.956 337.16 348.24W 5975147.07 N 670436.80 E 12.215 366.97 377.00W 5975158.12 N 670407.78 E 13.595 397.47 408.35W 5975170.53 N 670376.14 E 11.385 430.78 429.41W 5975179.73 N 670354.86 E 15.444 453.34 457.67W 5975193.27 N 670326.29 E 1.937 483.84 485.94W 5975206,99 N 670297.69 E 1.283 514.39 513.75W 5975220.77 N 670269.56 E 1.991 544.49 541.98W 5975234.82 N 670241.01 E 1.503 575.05 570.43W 5975248.07 N 670212,25 E 9,684 605.69 599.50W 5975260.19 N 670182.89 E 9.245 636.70 628.91W 5975271.85 N 670153.21 E 0.494 667.97 658.13W 5975283.82 N 670123.71 E 6.918 699.10 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 PBU WOA K Pad Continued... 25 September, 1998 - 15:46 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for K-19A Your Ref: API-500292253101 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim, Depth Depth Northings (rt) (rt) (ft) (ft) 9341.33 88.430 293.710 8777,71 8831.96 286,55 N 9373.22 88.390 293.450 8778.60 8832.85 299.30 N 9405.11 87.790 291.660 8779.66 8833.91 311.52 N 9437.83 86,460 289.770 8781.30 8835.55 323.08 N 9469.18 85.110 290.310 8783.61 8837.86 333.79 N 9501.25 84.410 289.570 8786.53 8840.78 344.69 N 9533.13 84.730 289.430 8789.55 8843.80 355.28 N 9565.13 83.610 289.530 8792.80 8847.05 365.90 N 9597.22 81.010 289.910 8797.10 8851.35 376.62 N 9629.28 79.990 289.020 8802.39 8856.64 387.16 N 9661.39 79.600 289.490 8808.08 8862.33 397.58 N 9693.58 79.030 289.660 8814.04 8868.29 408.18 N 9725.71 78.100 289.860 8820.41 8874.66 418.83 N 9757.75 76.980 289,730 8827.33 8881.58 429.42 N 9788.73 76.950 289.250 8834.31 8888,56 439.49 N 9820.82 77.220 287.650 8841.49 8895.74 449.39 N 9851.32 76.950 286.580 8848.30 8902.55 458.14 N 9883.25 76.820 287,170 8855.55 8909.80 467.17 N 9915.19 77.030 287.390 8862.77 8917.02 476.41 N 9947.10 77.490 287.620 8869.81 8924.06 485.77 N 9979.18 77.370 287.980 8876.79 8931,04 495.34 N 10011.12 78.050 287.890 8883.59 8937.84 504.95 N 10043.16 80.650 286.910 8889.51 8943.76 514.37 N 10075.26 83.100 285.920 8894.05 8948.30 523.34 N 10107.15 86.310 284.900 8896.99 8951.24 531.78 N 10139.17 88.400 284.770 8898.47 8952.72 539.97 N 10171.25 88.990 284.870 8899.20 8953.45 548.17 N 10203.22 89.110 285.350 8899.73 8953.98 556.51 N 10235.15 89,010 285.060 8900.25 8954,50 564.88 N 10266.88 88.980 284.790 8900,81 8955.06 573.05 N Local Coordinates Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (~) (~) (~) (°/100~) (~) 687.36W 5975296.07 N 670094.20 E 2.473 730.30 716.57W 5975308.15 N 670064.70 E 0.825 761.45 746.01W 5975319.70 N 670034.99 E 5,917 792.71 776.57W 5975330.56 N 670004.17 E 7.057 824.95 805.94W 5975340,60 N 669974.57 E 4.636 855.86 835.96W 5975350.81 N 669944.30 E 3.169 887.44 865.88W 5975360.72 N 669914.16 E 1.095 918.85 895.89W 5975370.65 N 669883.91 E 3.514 950.37 925.82W 5975380.69 N 669853.74 E 8.187 981.82 955.64W 5975390.55 N 669823.69 E 4,197 1013.13 985.47W 5975400.29 N 669793.63 E 1.884 1044.43 1015.27W 5975410.20 N 669763.59 E 1.845 1075.74 1044.91W 5975420.17 N 669733.72 E 2.958 1106.89 1074,35W 5975430,09 N 669704.05 E 3.518 1137.83 1102.80W 5975439.51 N 669675,38 E 1.513 1167.71 1132.47W 5975448.73 N 669645.49 E 4.932 1198.75 1160.88W 5975456.83 N 669616.89 E 3.532 1228.33 1190.64W 5975465.18 N 669586.93 E 1,845 1259.28 1220,35W 5975473.74 N 669557.02 E 0.939 1290.22 1250.03W 5975482,42 N 669527.13 E 1.604 1321.17 1279.84W 5975491.31 N 669497.11E 1.157 1352.28 1309.53W 5975500.25 N 669467.21E 2.147 1383.28 1339.58W 5975508.97 N 669436.96E 8.654 1414.59 1370.06W 5975517,25 N 669406.28 E 8.220 1446.24 1400.67W 5975524.99 N 669375.49 E 10.557 1477.91 1431.58W 5975532.47 N 669344.39 E 6.540 1509.84 1462.59W 5975539.97 N 669313.21 E 1.865 1541.85 1493.45W 5975547.60 N 669282.16 E 1.547 1573,74 1524.26W 5975555.27 N 669251.17 E 0,961 1605.60 1554.91W 5975562.74 N 669220.34 E 0.856 1637.26 Comment Alaska State Plane Zone 4 PBU WOA K Pad Continued... 25 September, 1998 - 15:46 - 3 - DrillQuest Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (ft) (ft) 10298.94 89.720 285.460 8901.17 8955.42 581.41 N 10330.95 90.120 285.530 8901.22 8955.47 589.97 N 10362.97 90.250 285.060 8901.12 8955.37 598.41 N 10394.96 90.370 283.680 8900.94 8955.19 606.35 N 10428.29 89.290 281.550 8901,04 8955.29 613.63 N 10459.28 88.830 279.210 8901.55 8955.80 619.21 N 10489.95 88.490 276.530 8902.27 8956.52 623.41 N 10521.28 89,600 273,440 8902.79 8957.04 626.13 N 10553.45 90.770 270,430 8902.69 8956.94 627.22 N 10585.22 91.600 268,770 8902.03 8956.28 627.00 N 10617.16 92.270 267.930 8900.95 8955.20 626.08 N 10649.12 92,670 268.000 8899.57 8953.82 624.94 N 10681,21 92.740 266,930 8898.06 8952.31 623.53 N 10713.29 92.860 268,070 8896.49 8950.74 622.13 N 10745.33 92.310 267.540 8895.05 8949.30 620.90 N 10777.27 91.350 268,470 8894.03 8948.28 619.79 N 10809.33 91.350 268,810 8893.27 8947.52 619.03 N 10841.34 89.600 269,540 8893.01 8947.26 618.57 N 10873.38 89.630 269.720 8893,22 8947.47 618.36 N 10905.39 89.170 269,890 8893.56 8947.81 618.25 N 10937.33 88,920 270.530 8894.09 8948.34 618.37 N 10969.30 88.740 272,070 8894.74 8948.99 619.10 N 11 O01.37 88.770 270.390 8895.44 8949.69 619.78 N 11032.34 89,450 269.150 8895.92 8950.17 619.66 N 11064.27 89,780 268.280 8896.13 8950.38 618.94 N 11096.41 89.880 268.320 8896.23 8950.48 617.99 N 11128.46 89.880 268.660 8896.30 8950.55 617.15 N 11160.43 89.820 268.780 8896.38 8950.63 616.43 N 11192.48 89.790 268.060 8896.49 8950.74 615.55 N 11224.56 89,630 267.490 8896.65 8950.90 614.30 N Sperry-Sun Drilling Services Survey Report for K-19A Your Ref: API-500292253101 Local Coordinates Global Coordinates Eastings Northings Eastings (fi) (fi) (fi) 1585.S6W 5975570.39N 669189.21E 1616.70W 5975578.24 N 669158.18 E 1647.59W 5975585.98 N 669127.11E 1678.58W 5975593.21N 669095.95 E 1711.10W 5975599.75 N 669063.27 E 1741.58W 5975604.64 N 669032.67 E 1771.95W 5975608,14 N 669002.21 E 1803.15W 5975610.15 N 668970.96 E 1835.30W 5975610.51N 668938.79 E 1867.06W 5975609.56 N 668907.05 E 1898.97W 5975607.91 N 668875.17 E 1930.88W 5975606.05 N 668843.29 E 1962.90W 5975603.91N 668811.31E 1994.91W 5975601.78 N 668779.34 E 2026.89W 5975599.83 N 668747.39 E 2058.80W 5975597.99 N 668715.52 E 2090.84W 5975596.50 N 668683.50 E 2122.84W 5975595.31N 668651.52 E 2154.88W 5975594.37 N 668619.49 E 2186.89W 5975593.54N 668587.50 E 2218.83W 5975592.93 N 668555.57 E 2250.78W 5975592.92 N 668523.60 E 2282.83W 5975592.88 N 668491.54E 2313,80W 5975592.05 N 668460.59 E 2345.72W 5975590.61N 668428.69 E 2377.85W 5975588.92 N 668396.60 E 2409.88W 5975587.35 N 668364.59 E 2441.85W 5975585.91 N 668332.65 E 2473.88W 5975584.29 N 668300.64E 2505.94W 5975582,32 N 668268.62 E Dogleg Vertical Rate Section (°/100fi) (~) 3.114 1669.25 1.269 1701.18 1.523 1733.12 4.330 1765.06 7.165 1798.38 7.694 1829.36 8.806 1859.96 10.478 1891.09 10.038 1922.83 5.841 1953,92 3.363 1985.03 1.271 2016.09 3.338 2047.21 3.569 2078.32 2.383 2109.43 4.184 2140.50 1.060 2171,76 5.924 2203.05 0.570 2234.42 1.532 2265.78 2.151 2297.12 4.849 2328.59 5.238 2360.15 4.566 2390.49 2.914 2421.64 0.335 2452.95 1.061 2484.20 0.420 2515.40 2.248 2546.64 1.846 2577.82 Comment Alaska State Plane Zone 4 PBU WOA K Pad Continued.., 25 September, 1998 - 15:46 - 4, DrillQuest Sperry-Sun Drilling Services Survey Report for K-19A Your Ref: API-500292253101 Prudhoe Bay Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (fi) (fi) (fi) 11258.39 89.540 268.620 8896.90 8951.15 613.15 N 11289.34 89.450 268.650 8897.17 8951.42 612.42 N 11319.42 89.320 268.440 8897.49 8951.74 611.65 N 11351.44 89.140 268.040 8897.92 8952.17 610.67 N 11383.58 89.110 268.730 8898.41 8952.66 609.76 N 11415.61 88.800 269.760 8899.00 8953.25 609.34 N 11447.73 88.550 269.650 8899.74 8953.99 609.18 N 11479.96 88.530 270.380 8900.56 8954.81 609.19 N 11512.04 88.560 270.640 8901.38 8955.63 609.47 N 11543.77 88.400 271.150 8902.22 8956.47 609.97 N 11575.57 88.340 271.790 8903.12 8957.37 610.78 N 11607.15 88.400 271.590 8904.02 8958.27 611.71N 11639.21 88.650 271.540 8904.85 8959.10 612.59 N 11671.42 88.710 271.180 8905.59 8959.84 613.35 N 11704.76 88.580 272.110 8906.38 8960.63 614.31N 11736.63 88.490 271.800 8907.19 8961.44 615.40 N 11795.00 88.490 271.800 8908.73 8962.98 617.23 N Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (~) (~) (fi) (°/100fi) (fi) 2539.75W 5975580.40 N 668234.85E 3.351 2610.74 2570.69W 5975578.96 N 668203.93 E 0.307 2640.93 2600.76W 5975577.51N 668173.89 E 0.821 2670.26 2632.76W 5975575.80 N 668141.92 E 1.370 2701.45 2664.88W 5975574.16 N 668109.82 E 2,149 2732.76 2696.90W 5975573.01N 668077.82 E 3.358 2764.08 2729.01W 5975572.11N 668045.72 E 0.850 2795.53 2761.23W 5975571.39 N 668013.51E 2.265 2827.12 2793.30W 5975570.94 N 667981.44 E 0.816 2858.61 2825.02W 5975570.72 N 667949.73 E 1,684 2889.81 2856.79W 5975570.81 N 667917.94 E 2,021 2921.12 2888.35W 5975571.02 N 667886.37 E 0.661 2952.24 2920.38W 5975571.17 N 667854.32 E 0,795 2983.83 2952.58W 5975571.20 N 667822.12 E 1.133 3015.54 2985.89W 5975571,39 N 667788.79 E 2.816 3048.39 3017.73W 5975571.76 N 667756.93 E 1.013 3079.83 3076.05W 5975572.26 N 667698.59 E 0.000 3137.37 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 281.346° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11795.00ft., The Bottom Hole Displacement is 3137.37ft., in the Direction of 281.346° (True). Comment Projected Survey Alaska State Plane Zone 4 PBU WOA K Pad Continued... 25 September, 1998 - 15:46 - 5 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for K-19A Your Ref: API-500292253101 Alaska State Plane Zone 4 PBU WOA K Pad Comments Measured Depth (fi) 8409,61 8427.00 11795.00 Station Coordinates TVD Nothings Eastings (fi) (~) (fi) 8402.96 19.11S 10.63W 8419.51 17.80 S 15,78W 8962.98 617.23 N 3076.05W Comment Tie-on Survey Window Point Projected Survey 25 September, 1998 - 15:46 - 6 - DrillQuest MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst~ DATE: 9~4~98 Chairman THRU' Blair Wondzell, ,~~ FILE NO: .DOC P. I. Supervisor '~/~'=)~ FROM' Larry Wade,;~ SUBJECT: Petroleum Inspect~~ BOP Test Doyon 16 BPX PBU K-19A PTD 98-168 September 4,1998: I traveled to PBU K-pad to witness a BOP test on Doyon 16. As usual everything went smooth and the test was done expeditiously with no suprises. SUMMARY: I witnessed a BOP test on Doyon 16, 0 failures, 3 hours. Attachments: ahigidfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X SSD K-19A 7" Set @ Weekly Workover: DATE: Doyon Rig No. 16 PTD # 98-168 Rig Ph.# Re p.: Phil Smith Rig Rep.: 9,246 Location: Sec. X' Other 9/5/98 659-46'I0 Scott Heirn 5 T. 11N R. 14E Meridian Urniat Test Pressures 250/5000 TEST MISC. INSPECTIONS: Location Gen.' ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X ~ BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign X Drl. Rig X Hazard Sec. X Quan. 1 Test Press. P/F P 1 250/5000 P 1 250/5000 P 1 250/5000 P I 250/5000 P 2 250/5000 P 1 250/5000 P 250/5000 MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X' / H2S Gas Detector X X . FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F 250/5000 250/5000 250/5000 250/5000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 13 25O/5OOO P 26 250/5000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Masl:er: Nitgn. Btl's: 6 @ 1900 3,000 1,500 minutes ?8 sec. minutes ?0 sec. x Remo~:e: x Psig. TEST RESU LTS~ Number of Failures: 0 ,Test Time: 3.5 Hours. NumDer of valves tested 15 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOCCC Commission Office a~:: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade FI-021L (Rev.12/94) Ahigidfe.xls -CNY KNOWLE$, GOVERNOR .~LASKA OIL A~NII GAS ~ONSERVATION CO~DIISSION :001 PORCUPINE DRIVE ,:.,"-,I'CHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 ',907) 276-7542 Au~,ust ~ 1. 1998 Dan Stone Engineering Supervisor BP Exploration (Alaska)Inc. POBox 196612 Anchorage. AK 99519-6612 Re,: Pmdhoe Bay Unit K- l 9A BP Exploration I Alaska) inc. Permit No. ~8-168 Sur. Loc. 3100'NSL. 4766'WEL. Sec. ,.5.,4. T1 IN. R14E. UM Btmnhole Loc. 5297'NSL. 2679'WEL. Sec. 05. T1 IN. R14E. UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. Thc permit to rcdrill does not exempt you from obtaining additional permits required bx- lax',' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficicnt notice (approxirnatcly 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling ney,' hole. Notice max' bc given bx' contacting the Commission petroleum ficld inspector on thc Norti~ Slope pager at 659-3607. Sine ' / / Robcrt N. Christcnson. P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Dcpartmcnt of Fish & Gatnc. Habitat Section w/o cncl. Department of Environmcntal Conscrx'ation xv/o cnci. STATE OF ALASKA ALASKA'-<,viL AND GAS CONSERVATION COI,-¢.,ilSSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I--IDrill I~Redrill Ilb. Typeofwell Ij--lExploratory I-]StratigraphicTest [~ Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 25.50' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304--' 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3100' NSL, 4766' WEL, SEC. 04, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3736' NSL, 1108' WEL, SEC. 05, T11N, R14E, UM K-19A At total depth 9. Approximate spud date Amount $200,000.00 3297' NSL, 2679' WEL, SEC. 05, T11N, R14E, UM 08/22/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028299, 1983'I E-09, 544' away at 10178' 2560 11808' MD / 8920' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8450' Maximum Hole Angle 93° Maximum surface 2624 psig, At total depth (TVD) 8800' / 3523 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 BTC-Mod 3507' 8300' 8290' 11807' 8920' 379 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10630 feet Plugs(measured)ORIGINAL true vertical 8946 feet Effective depth: measured 10630 feet Junk (measured) true vertical 8946 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3669' 9-5/8" 882 sx PF 'E', 375 sx Class 'G' 3704' 3703' Intermediate Production 9211' 7" 276 sx Class 'G' 9246' 8973' Liner 1508' 4-1/2" Uncemented Slotted Liner 9122' - 10630' 8948' - 8946' Perforation depth' measured Slotted Liner: 9207' - 10607' ~ ;¢-~ ~:/ ¢~- ~ .; true vertical Slotted Liner: 8968' - 8946' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis ;~:~..$e.a.b.~¢}~.R~gri¢0:.~2.'_~-~¢L25.;_O50 Requirements Contact Engineer Name/Number John Powell, 564-5480 Prepared By Na~i~'/~¢r~:~ Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Dan Stone Title Engineering Supervisor Date Commission Use Only Permit Number APl Number Ai3pro_val D.a, te~ I See cover letter ~ ~- ~(,.o ~ 50-029-22531-01 ~'~--~/'~ ~¢I for other requirements Conditions of Approval: Samples Required I--lYes [~ No Mud Log Required []Yes [~No Hydrogen Sulfide Measures [~Yes []No Directional Survey Required [~Yes []No Required Working Pressure for BOPE [--12M; [--13M; 1~5M; I--I10M; [-115M Other: ORIGINAL SIGNED BY by order of Approved By Robert N. Chdstenson Commissioner the commission Date ~'~ ~'c:~/"'/~'~ Form 10-401 Rev. 12-01-85 Submit In Triplicate . ' STATE OF ALASKA . . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work E] Drill [~;;i~Redrill Ilb. Type ~)f well [--I Exploratory I--]StratigraphicTest ~:] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone ..... 2. Name of Operator 5. Datum Elevation (DF or KB) I10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 25.50' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3100' NSL, 4766' WEL, SEC. 04, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3736' NSL, 1108' WEL, SEC. 05, T11N, R14E, UM K-19A At total depth 9. Approximate spud date Amount $200,000.00 3297' NSL, 2679' WEL, SEC. 05, T11N, R14E, UM 08/22/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028299, 1983'I E-09,544' away at 10178' 2560 11808' MD / 8920' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 2'5.035 (e) (2)} Kick Off Depth 8450' Maximum Hole Angle 93 ° Maximum surface 2624 psig, At total depth (TVD) 8800' / 3523 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casin'g Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 BTC-Mod 3507' 8300' 8290' 11807' 8920' 379 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10630 feet Plugs (measured) true vertical 8946 feet Effective depth: measured 10630 feet Junk (measured) true vertical 8946 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3669' 9-5/8" 882 sx PF 'E', 375 sx Class 'G' 3704' 3703' Intermediate Production 9211' 7" 276 sx Class 'G' 9246' 8973' Liner 1508' 4-1/2" Uncemented Slotted Liner 9122' - 10630' 8948' - 8946' . Perforation depth: measured Slotted Liner: 9207' - 10607' · true vertical Slotted Liner: 8968' - 8946' .... 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: John Powell, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby Certify that the foregoing is true and correct to the best of my knowledge Signed ,_.~"._: ~-'-~.~ .~-..~ . ~ c~J ,'8! Da, Stone Title Engineering Supervi.sor' Date Commission Use Only Permit Number APINumber I ApprovalDate I Seecoverletter ~o¢ - !/¢ (~ 50-029-22531-01 t'~ ~',:~//- ,~2 for other requirements Conditions of Approval: Samples Required [] Yes C~ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE I--]2M; •3M; ~ii~5M; []10M; []15M Other: ,ORiGiNAL SIGNED BY by order of Approved By Robert N. Chdstenson Commissioner the commission Date ]Well Name: I K-19A Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: 3100' NSL, 4766' WEL, Sec. 4, TllN, R14E, UM X = 670,788 Y = 5,975,025 Target Start: X = 669,150 Y = 5,975,625 Z -- 8,920' TVDss 3736' NSL, 1108' WEL, Sec 5, T1 iN, R14E Intermediate Target End: X = 673,004 Y = 5,969,993 Z = 8,735 TVDss 3297' NSL, 2679' WEL, Sec 5, T1 iN, R14E I AFE Number: 14P1189 Estimated Start Date: I 08/22/98I ]Rig: I Doyon 16 Operating days to complete: I MD [11,8o8' [ I TVD: 18,920ss [ 23 Well Design (conventional, slim hole, Extended Horizontal Sidetrack >3000' etc.): (3357') Objective: Sidetrack out of existing 7" csg into the base of SGR, directionally drill and geosteer 6" hole to 4.5" liner TD @ 11,808 in base of Zone 1 (8,920 TVDss). Run and cmt 4.5" liner. Complete with 4 ½", L-80 tbg, (4) GLM's and WOA tail assy. Formation Markers Formation Tops MD TVD(ss) Begin sidetrack 8,460 8,400 Sidetrack from Whipstock out of 7 "csg base of SGR into SHU. (TSHU 8406ss) SHU 8,468 8,406 TSAD 8,530 8,463 TZ3 8,655 8,567 TZ2C 8,718 8,612 GOC 9,596 8,825 (est) PGOC -TBD by Neutron Density Logs TZIB 9,742 8,850 T1 (Geological) 10,360 8,920 13P T2 New 10,810 8,910 13P T3 New 11,210 8,910 13P T4 New 11,410 8,900 13P TD Target 11,808 8,920 13P Target TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MDfrVD MD/TVD O.D. 6" 4 V2" 12.6# L-80 Mod 3,507' 8300' MD 11,807'/8,920' liner BTC 8290' TVD Logging Program: Open Hole Logs: Reference Logging/Bit/Directional/BHA Attachments Drilling section: BHA #1 (6" STR-09D Insert Tri-Cone Sidetrack/Build/Turn Assy): MWD/DIR/GR for first bit run. BHA #2: (6" STR-09D Insert Tri-Cone Lateral Assy): MWD/Dir/GR/Res for second bit run. GR will be used for correlating K-19A to offset wells. Res will be used to determine fractures, rock quality and fluid influx. Post Rig: CTU Memory CNL (prior to POP) CNL will be used to determine the GOC. Mud Program: Detailed vendor fluid program is as run on K-20A and will be kept optimized. I Special design ] Use 6% KC1 Quickdril-N fluid with elevated low end [ considerations rheology, ontinue Trend Line Charting major properties. Record LSRV at 1,2,3 minutes: Make certain they are elevated and flat KCI 6 % LSRV >60,000cps I Density 8.6-8.8 pH 9.0-9.5 PV <15 (expect Lubetex 5% Sweeps 150,000cps w/60-80 rpm & 8-12) Add only (fresh active, not reciprocation (follow RP for BHA for Clarified Xanthan coated out on drilled max rpms) / stand back singles to per Quickdril-N solids avoid extended CBU over same 30' 10 sec Gel > 18, 10 min >20 Follow the same detailed fluids/displacement/spacer/cementing/cleanout program from K-06A & K-20A (reviewed, edited, and attached). Directional: Reference Following Logging/Bit~irectional/BHA attachments KOP: 1) 8450' MD, drill out of 7 "csg via whipstock window at 19© inclination, build angle to 90© inclination at 10,300MD in Z1 13P. PU BHA#2 and geosteer to 11,807'MD @ TD and 8,920 TVDss). Maximum Hole Angle: 93+© in horizontal section Close Approach Well: Point to point separation None identified by Asset for shut-ins, E-09 · 544' @10,178' MD; E-09A: 617' @ 10,213' @ MD Surface Shut Ins K-06A 35' NW, Shut in: MIRU & RDMO Cement Data: Casing/Liner P&A of original well 4.5", 12.6#, L-80 liner set in 7" 29# csg @ 8300'. Lead: Sxs/Wt/Yield Volume as needed Volume: 451.3 cu. Ft. 80.44 bbls Tail: Sxs/Wt/Yield as needed/15.8/1.16 (pump w/CTU) 379/15.7/1.19 Comments "G" at 15.8 ppg Class "G", 40%+ for OH, +80' shoe, + 150' lap, +200' ann See Detailed BJ Cementing Procedure & Attached MC4-D Viscosified Spacer w/1.75 ppb xanthan (Follow the detailed Conventional Cement/Displacement/Spacer Program from K-O6A (reviewed, edited, and attached) Well Control: Fluid Overbalance Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. NO ANNULAR INJECTION IN THIS WELL. K-19A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Bottom hole pressure in the target sand is 3,523 psi at 8,800' TVDss (estimated) or 7.7 EMW. The overbalance with 8.8 QuickdrilN is 500 psi, or 1.1 PPG. This is the highest bottom hole pressure expected in the wellbore trajectory. Maximum shut-in casing pressure is 2,624 psi (assumes 0.1 psi/ft gas gradient to surface). Drilling Discussion Well Obiective The Pad K development seeks to exploit the target Gravity Drainage in the base of Zone 1 with well K- 19A and to leave the well set up for additional sidetracks into the surrounding area. The trajectory of the well is to expose as many basal mouth bar deposits, allowing gravity drainage from fluvial and distributory channels above. Recoverable OIP in place is estimated at 1.058 MMSTB, with an initial recovery 3000 BOPD. The objective of the well is to drill an essentially horizontal section through Zone 1 basal 13P sand and follow the structure, optimizing standoff from gas, and Kavik. This well path optimizes exposure to the base of Zone 1 above the Kavik, standoff from GOC and faults for good cement zonal isolation. The cement program has been extensively modified to successfully run 2 RH turbulators/jt, eliminate the inner string & improve liner flexibility. Additionally, the program developed with the Asset, the Fluids Company, The Rig Team, Baker, B J, and Halliburton allowed full reciprocation while cementing in K- 06A. Excess cement was circulated out the long way to eliminate liner top/tool release problems. The well path of K-06A crossed 3 major faults without losses, K-20A has small faults which also present some potential loss at- 10,750, 11,200, 11,750 MD, so stay alert. Drilling Objective The objective is to chemically cut and pull the existing 3 V2" completion tubing at 8460 MD. The 6" whipstock sidetrack will exit the 7" casing at this point, into the SHU @8406 TVDss, landing into the base of Z1 @8920 TVDss (10,360'MD), with TD of the 6" hole section in the base of Zone 1 at 8920 TVDss and 11,808 MD. Directionally drill with first Build&Turn Tri-Cone Assy BHA equipped with MWD/GR/Dir from 8460 MD to run out of bit or 10360' MD. The Second Lateral B HA will add Res and will build from 90-93+ degrees, and TD @ 11,808'MD @ 86 degrees. It will utilize the same full suite of Real Time MWD/DIR/GR/Res for geosteering 6" hole to maximize well placement, measure rock quality, fluid influx, and presence of faults. Dog legs in the lateral section have been minimized in plan to be 10 degrees or less. A CTU memory CNL will be run after the rig moves off the well and prior to putting the well on production to determine the GOC. The target risk is low and confined mainly to structurally small faults and uncertainty of exact GOC. A high quality cement job, obtainable with a modified conventional 2 RH turbolators/jt, cementing program developed on K-06A/K-20A and continued here on K-19A, has obtained good isolation. Better standoff/centralization with engineered displacements & sweeps, with in-guage wellbore improve bonding, minimize channels which cause premature coning, and the use of clean & non- damaging perforating pills eliminates damage during perforation and subsequent protection from seawater/brines containing corrosion inhibitors. Eliminating the inner string increases flexibility of liner w/2 turb/jt, and has shown promise of eliminating cleanout runs, and improving perf gun placement. The K-19A well will be completed as a Zone 1 producer with a 4 lA", L-80, 12.6# liner, (4) GLM's and WOA tailpipe assy. The GLM's will be run at the MDs to be determined by the Asset/Pad Engineer. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is one well, K-06A, 35' NW which will need to be shut in during MIRU and RDMO. This has been identified via Shut In Memo, Pre-Rig, and this Well Plan. DRILLING CLOSE APPROACH WELL SHUT-INS No downhole shut-ins identified on Sperry Sun directional well plans or by Asset due to close approach requirements. HOLE PROBLEMS This well will cross small known faults, with a small predicted possibility for lost circulation, or gas cut mud and gas kicks after crossing any of the faults. The faults are not prognosed to be problematic, however, their depths were identified earlier, and normal precautionary measures will be taken. Lost circulation, if it occurs, will be handled using a comprehensive lost circulation decision tree. All rig personnel should be aware and ready to effectively react to any gas kick potential. Ready to shut in any kicks and weight-up and safely circulate-out the kick. Differential sticking is a possibility while drilling across any of the faults. However, fluid design is such that differential sticking has not been a problem, even when drilling and completing with >2000 psi overbalance. Casing Shoe Kick Tolerance The smallest kick tolerance for the kick off window is calculated as infinite of influx assuming a swabbed gas influx at the top of the Sag River along the planned directional path. Based on 8.7 ppg MW (SAD 13P 8,800' TVD 7.7 ppg reservoir pore pressure), and min. frac at the window 10.0 ppg. The casing window will withstand complete (gas) evacuation to surface based on predicted pressures. Pre-Rig / Pre-Drill Work 1. RU wireline and retrieve the 3.5" HES SSSV. Valve nipple is set at 2176'MD. Test 7" packoff and tubing hanger packoff to 5000 psi and carefully cycle LDS. 2. Circulate Seawater as needed to prepare well for perforation squeeze abandonment. 3. Drift 3 V2"tubing to top of 4.5" slotted liner at 9122'MD (67 degrees). 4. Perf interval above slotted liner is 9090-9120 MD inside the 7" liner. 5. P&A slotted liner, and perfs, with cement top at 8800'MD (290' above perfs). Lay in cement with CTU, WOC, cleanout to 8800 (41 degrees) and test for 30 minutes at 3000 psi. 6. Cut the 3.5" tbg in the middle of a full joint of tubing at ~8460'MD for setting whipstock. 7. Test 7" to 3000 psi before cut or retest both IA and tubing after cut. 8. If a chemical cut, follow recommended practices for successful chemical cuts, including double anchors, and balanced IA/tubing hydrostatic. 9. Displace the tubing and wellbore to 8.5 ppg seawater 10. Freeze protect top 2200'MD with diesel. 11. Bleed tubing and annuli pressures to zero. 12. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure the well 13.Remove the well house and flowlines. If necessary, level the pad. K-06A is within 35' of the K-19 wellhead. Ensure that well is shut-in during MIRU and during RDMO operations with as little shut- in time as possible. Please provide total well preparation cost on the handover form. Rig Sidetrack Procedure o MIRU. Coordinate with Pad Engineer prior to MIRU D-16 that surface close approach well K-06A is shut in. Minimize shut in times during MIRU and RDMO with Pad Engineer. Obtain PE handover notes, completed, confirming well status before completing handover. Test packoffs to 5000 psi if not confirmed in pre-rig work.. 2. Bleed off pressures to zero. Pull BPV. Circulate out freeze protection (if required) and circulate well with seawater. Install TWCV and test to 1000 psi. 3. ND tree and send to DSM for refurbishing. NU BOP and notify AOGCC to witness or obtain waiver. Perform a full BOP test- 250/5000, annular 250/3500. 4. Pull the 3 i/~?, tubing completion from cut at 8460'. Call DSM for Norm readings if scale is present. Inspect quality of cut and report to SLB for database. . Because of the problem with casing scale plugging our MWD tools on K-06A, consider PU DP with bit and scraper to clean casing to top of tubing cut. Viscosify seawater with 2 PPB XC polymer and note scale recovered while circulating. Reuse this fluid as milling fluid. . PU Baker Bottom Set WindowMaster One-Trip Mill and RIH to Set and orient on tubing stub @ --8460'. Mill window with Baker window master mill per representatives confirmation that the top full guage string mill has exited the window and that the window is well dressed prior to POOH. Inspect mill for confirmation of window integrity. Use ditch magnets and keep them clean. Clean pits and take on new 60,000 LSRV 4% KCL / 5% Lubetex drill-in fluid. , PU STR-09D 6" insert bit and Sperry BHA#1 (See BI-IA Attachment) Sidetrack/Build/Turn assembly with MWD/Dir/GR/tools and kick-off directionally drilling 6" hole from SHU to BHA#1 landing pt @ 10,360'MD (8920 TVDss) in base of Zone 1. 8. PU BHA #2 Lateral Tri-Cone Assembly with second STR-09D 6" insert bit with MWD/Dir/GR/Res tools. Continue with this assembly to lateral TD at 11,808'MD (8920'TVDss). 9. Optimize gas standoff and Kavik basal standoff, while crossing a series of small faults. Prepare for losses associated with faults, though not expected as highly probable or likely. 10. Keep Fluid specs maintained at all times for optimum performance. If there are any ROP/sliding problems, call to discuss. Keep active Lubetex concentration at 5 % and utilize Lubetex spotting pills (and beads if necessary) if drilling hard, or sticky formation. 11. At TD circulate and condition the wellbore as in K-06A/K-20A "Conventional Production Cementing Pump Down Job, Modified Procedure" for optimum wellbore conditions for running and cementing liner, conventionally, with 2 RH turbulators/jt to just above GOC. 12. We will be repeating all steps (though some will be deleted as K-06A/K-20A results confirm) except where the attached document has been modified. We may not run tandem scraper/bit run to top of float shoe based on results of prior wells. One objective of this cement technique is to eliminate the cleanout run. 13. Run and cement 4.5" liner with the modified conventional program from K-06A/K-20A (attached). Displace cement with 150,000 cps/5% Lubetex/6% KC1 perf pill = to liner volume plus 30 bbls excess pill for cement pusher pill. Displace pills with clean filtered seawater. Reference procedure for rig floor cement manifold setup to divert cement wash water to slop tank, avoiding cement shoe contamination or contamination to perf pill, and minimizing shut down to a few minutes. After plug bumps, and liner hanger and liner top packer are set, keep 1000 psi on drillpipe/liner. When you rotate 6 turns to the right and release from setting tool, the 1000 psi and the 30 bbl 150,000 LSRV/5% Lubetex lead fluid will act as a pusher pill to start moving the excess cement up the annulus. Pump at max rate set back down on liner top with slack weight of 40K to confirm liner top packer set, while circulating at max rate (with C-2 running tool only) Test liner lap to 3000 psi. Follow recommended practice for liner top 150' inside 7". 14. 150,000 cps 5% clarified Xanthan 6% KC1 perf pill inside liner is to prevent sticking perf guns during 100 psi underbalanced perforation on K-19A and to minimize formation damage, especially from fluid loss of inhibitor-treated brines, and to avoid sticking guns in influx of perf debris. POOH for perf guns. Run DPC Halliburton 2-3/4" RDX DP (12.5 gm), 4 spf, random orientation, 60 degree phasing perforating guns with Champ Perf packer. Perforate 100 psi underbalance. (Perforating memo will be distributed after logs, identifying intervals and procedures.) Reshoot fluid level to determine gains/losses. POOH & lay down guns. 15. Complete well with 4 1/2", L-80 tubing, Baker 4.5x7" S-3 packer set at 8280 MD (150' inside of window of 7" at 8460'. Completion string will include (4) GLM's and WOA tailpipe assembly, WLEG spaced & stung into top of liner tieback sleeve, and modified X nipple profile instead of SSSV. (Note: Have Camco pin the RP for 2400 psi nominal instead of 2900 and paint with white stripes to denote change. When testing tubing to 3500, only bleed tubing to 2000 psi prior to testing IA to 3000 to leave a 1000 psi differential across RP and prevent shear. Carefully bleed off IA & tubing pressures to avoid shearing RP. Contact ODE and Camco for details when you get to this step or reference attached document (also in rig files). This is our fifth well on which we have utilized this modified procedure with solid success. Space WLEG to place inside of 4.5" liner tieback sleeve when tubing is landed. Pull up and reverse circulate filtered seawater with Corexit @ 25 gal/100 bbls. 16. Position WLEG inside 4.5" tieback sleeve and drop packer setting ball. Set the packer and test the tubing to 3500 psi for 30 min. Only bleed to 2000 psi. Test annulus to 3000 for 30 min. Slowly bleed tubing and record pressure differential when RP shears. Do not freeze protect yet. 17. Install TWCV in the tubing hanger and test from the annulus to 1000 psi. 18. Install BPV & nipple down BOP equipment. 19. NU and test tree to 5000 psi. (Notify AOGCC in advance to witness or waiver) Pull TWCV and BPV. 20. Displace the annulus with diesel to 2000', overdisplacing sufficient volume through top GLM to freeze protect tubing to 2000', chasing with seawater. Install BPV, test from below, and secure the tree. 21. RDMO, pick up matting boards and herculite, clean area, perform a post rig site inspection with Pad Operator, and handover/release rig to Production. 22. Notify PE's that tie-in will require dual P-Pilot to complete and put well on production. Minimize shut-in time of K- 17A. John Powell, ODE Doyon 16 ,anc, Ops. Drlg. Superintendent TREE: 4' ClW 5M '-- :" WELLHEAD: FMC 13-5/8" Slimhole 9-5/8", 47 #/f~, 137041 I 7"29# L-80 BUTT CSG I KOP: 8200' K-19 GL ELEV = 26.30 KB ELEV = 64.50 3.5"HES"XDB'SSSVN I 2176' I MCMurray Gas Lift Mandrels !o 3-1/2", 9.2#/ft, L-80, Mod TUBING ID: 2.992' CAPACITY:.0087 BBL/FT Top of 4-1/2" slotted liner I 7" x 4-1/2" TIW SS Packer 9122 7" 29 #/ft L-80, Butt Casing I 9246 ! NOTE: 2 joints of blank 4-1/2" casing below TIW SS packer 3 1/2" HES "X" NIPPLE ( 2.75" ID) I 7" x 3-1/2" Baker "SABL-3" i Packer Baker KBH-22 Seal Assy. 3 1/2" HES "X' NIPPLE (2.75" ID) I 3 1/2" HES "X" NIPPLE ( 2.75" ID) I 8925 ! 8939 I 8964 I 1 8975'I I so o'l CT-GR/CCL MD f1%31/2"WLEG I 8987' I Eb D II Open Perforations (9090' - 9120' MD ) 4-1/2" 12.6#/ft, L-80, NSCT Slotted Liner DATE 1-03-95 9/28/95 5/27/98 REV. BY MDO COMMENTS Completion PPA CT Jewelry log update JDR ADD PERF 9090-9120' PRUDHOE BAY UNIT WELL: K-19 APl NO: SEC 4; TN 11N; RGE 14E BP Exploration (Alaska) ii . , ii TREE: 4" ClW 5M ' WELLHEAD: FMC 13-5/8' Slimhole ACTUATOR: BAKER i I GL ELEV = KB ELEV = 9'5/8"' 47 #/fl' I L-80, NSCT 3704' KOP: MAX ANGLE: 4-1/2" X Nipple I ! Camco Gas Lift Mandrels 4.5' x 1 · Latch Nol MD I TVD ~n~] 41 1325°', / 3l 155°° / 2I 17000' ! 11 18000' / 4-1/2", 12.6#/ft, L-80, IBT TUBING TUBING ID: 3.958 · CAPACITY:.0152 BBL/FT 7"x 4-1/2" Production Packer @ 8280' MD Top of 4-1/2" Liner @ 8300' MD 7" Whipstock @ 8450' MD Tubing Cut @ 8460' MD Top of Cement Plug @ 8800' MD Top of 4-1/2" slotted liner I 7" x 4-1/2" TIW SS PackerI 9122' 7" 29 #/ft L-80, Butt Casing NOTE: 2 joints of blank 4-1/2" casing below 4-1/2" 12.6# IBT Liner @ 11,807' MD 3-1/2' WLEG @ 8987' MD Perforations (9090' - 9120' MD) 4-1/2" IBP @ 9140' MD 4-1/2" 12.6~/ft, L-80, NSCT DATE REV. BY COMMENTS Proposed Completion PRUDHOE BAY UNIT WELL:K-19 BP Exploration (Alaska) =narea =erv/ce~ ~rm/n,g Well · K-19A Wp3 [ Drtll uest Proposal Data for K-19A Wp3 Vertical Origin: Well Horizontal Origin: Well MeasurementUnits: ft North Reference: True North Dogleg severity: Degrees per 100ff Vertical Section Azimuth: 281.353° Vertical Section Description: Well Vertical Section Origin:0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogle~ Depth Depth Section Rate 8450.00 18.743 277.368 8441.22 i 6.44 S 23:.69'W· 19.99 8490.00 22.294 282.643 8478.68 ! 3.96 S 37.47 W 33.99 10.(X2C' 8656.09 41.837 290.343 8618.80 12.46 N -- 120.99 W 121.07 8720.91 45.700 291.000 8665.61 28.29 N 162.93 W 165.32 6.0(~ 9021.92 81.629 295.269 8797.01 133.98 N 406.26 W 424.68 12.0~) 10079,19 81.629 295.269 8950.92 580.48 N 1352.18 W 1439.99 0.0C~, 10360.22 90.000 268.344 8971.80 636.90 N 1623.82 W 1717.42 10373.14 91.292 268.344 8971.65 636.53 N 1636.73 W 1730.00 10.CO~ 10810.18 91.292 268.344 8961.80 623.90 N 2073.48 W 2155.73 0. 10826.67 89.973 268.344 8961.62 623.42 N 2089.96 W 2171.79 I 1210.05 89.973 268.344 8961.80 612.34 N 2473.18 W 2545.33 I 1266.25 93.345 268.344 8960.17 610.72 N 2529.32 W 2600.05 11409.78 93.345 268,344 8951.80 606.58 N 2672.55 W 2739.66 0.0(~ 11532.52 85.980 268.344 8952.52 603,03 N 2795.15 W 2859.17 6. 11807.51 85.980 268.344 8971.80 595. I I N 3069.35 W 3126.44 0.0C~ SURFACE LOCATION J~ [ PLOT DATE: 12-Aug-98 t~?=cmta/Coordinate~: 5975025.25 N 670787.90 E J/ ~J / . ;:l(.~3Ele,v-al:~n: 25.50~ Rig(EST)I/ l~ /JCreatedBy: C.,x~'dinate System · NAD27 Alaska State Planes' ' - - · Zone 4. US Fooi/~/ Approved By:~/.~.~,~,~..~, Proposal Target Summary Target Name: TVDss: TVDrkb Wellhead Offsets: .G._/o~.,~ C. ~on:linatcs: K-19A TI 8920.00 8971.80 636.90 N, 1623.82 W5975625.00 N, 669150.00 E K-I9A T2Ncw 8910.1108961.80 623.90 N, 2073.48 W5975601.76 N, 668700.75 E K-19A T3New 8910.00 8961.80 612.34 N, 2473.18 W5975581.11 N, 668301.41 E K-19A T4New 8900,00 8951.80 606.58 N, 2672.55 W5975570.80 N, 668102.23 E K-19A TSNew 8920.00 8971.80 595.11 N, 3069.35 W5975550.30 N. 667705.79 E ~o, 8200 .~o ~ '.~ o'~ ~ '~o~' ~ ~oo ........ ~ ~ ~' _~ .~<- ~;~,,.' $~," ~o"' ~x.~~ 6o"'.,~~ o~O"' .o~ ~ --_-- ~ ~ ~.~~ L ~' ~. ,"~,- ~'/ ; -- -$~ ~ ~ -- ~ ._ ooo I I I I I I 0 400 800 1200 t 600 2C~00 2400 2800 3200 ' 3600 Scale: linch = 400ft Vertical S~-ction Section Azimuth: 281.353' (True North) c~nareo c, erv/ces ur/rang Well · K-19A Wp3 ] lJrtll gZuest Proposal Data for K-19A Wp3 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: True North Dogleg severity' Degrees per 10Oft Vertical Section ~zimuth: 281.353° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 8450.00 18.743 277.368 8441.22 16.44 $ 23.69 W 19.99 8490.00 22.294 282.643 8478.68 13.96 S 37.47 W -33~99' ' ' 10,000 ' 8656.09 41.837 290.343 8618,80 12.46 N 120.99 W 121.07 12.000 ,_ 8720.91 45.700 291.000 8665.61 28.29 N 162.93 W 165.32 6.000 9021.92 81.629 295,269 8797.01 133.98 N 406.26 W 424.68 12.000 10079.19 81.629 295.269 8950.92 580.48 N 1352.18 W 1439.99 0.000 10360.22 90,000 268.344 8971.80 636.90 N 1623.82 W 1717.42 10.000 10373.14 91.292 268.344 8971.65 636.53 N 1636.73 W 1730.00 10.000 10810.18 91.292 268,344 8961.80 623.90 N 2073.48 W 2155.73 0.000 10826.67 89.973 268.344 8961.62 623.42 N 2089.96 W 2171.79 8.000 11210.05 89.973 268,344 8961.80 612.34 N 2473.18 W 2545.33 0.000 11266.25 93.345 268.344 8960.17 610.72 N 2529.32 W 2600.05 6.000 11409.78 93.345 268,344 8951.80 606.58 N 2672.55 W 2739.66 0.000 11532.52 85.980 268.344 8952.52 603.03 N 2795.15 W 2859.17 6.000 11807.51 85.980 268.344 8971.80 595.1 i N 3069.35 W 3126.44 0.000 Horizontal Coordinates: 5975025.25 N, 670787.90 E RKB Elevation: 25.50 ft Rig (EST) 26.30 fl Well (CBE)l 5,.80 . ..8 . ,,st\ Coordinate System: NAD27 Alaska State Plane$,l zoo4. us PLOT' DATE: 12j-Aug-98 cr.,~.y: Checked By: Approved By~..~~-.~,.~ Proposal Target Summary Target Name: TVDss: TVDrkb Wcllhcad Offsets: Global Coordinates: K-19A TI 8920.00 8971.80 636.90 N, 1623.82 W 5975625.00.~I~ .~,ISD.O0 E K-19A T'2New 8910.00 8961.80 623.90 N. 2073.48 W 5975601.76 N, 668700.75 E K-19A T3Ncw 8910.00 8961.80 612.34 N, 2473.18 W 5975581.11 N. 668301,41 E K-19A T4New 8900.00 8951.80 606.58 N, 2672.55 W 5975570.80 N. 668102.23 E K-19A T5New 8920.00 8971.80 595,11 N, 3069.35 W 5975550.30 N, 667705.79 E .APPRO¥ D 800 400 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 Scale: linch = 40Oft Eastings Reference is True North 800 400 Prudhoe Bay Unit Sperry-Sun Drilling Services Proposal Report for K-19A Wp3 Alaska State Plane Zone 4 PBU_WOA K Pad Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates ....... Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100fi) Vertical Section (ft) Comment 8450.00 18.743 277.368 8389.42 8441.22 8467.59 20.285 279.906 8406.00 8457.80 8490.00 22.294 282.643 8426.88 8478.68 8500.00 23.454 283.433 8436.09 8487.89 8529.74 26.923 285.402 8463.00 8514.8o 860o.0o 35.193 288.605 8523.14 8574.94 8654.75 41.678 290.307 8566.00 8617.8o 8656.09 41.837 290.343 8567.00 8618.8o 8700.00 44.453 290.798 8599.04 8650.84 8718.33 45.546 290.976 8612.0o 8663.80 8720.91 45.700 291.00o 8613.81 8665.61 8779.38 52.667 292.1oo 8652.o0 8703.80 8800.00 55.126 292.439 8664.15 8715.95 8810.40 56.366 292.602 8670.00 8721.80 8853.01 61.452 293.226 8692.00 8743.80 8900.00 67.062 293.848 8712.40 8764.20 9000.00 79.o10 295.027 8741.52 8793.32 9021.92 81.629 295.269 8745.21 8797.Ol 9100.00 81.629 295.269 8756.58 8808.38 9200.00 81.629 295.269 8771.13 8822.93 9300.00 81.629 295.269 8785.69 8837.49 9400.00 81.629 295.269 8800.25 8852.05 9460.11 81.629 295.269 8809.00 8860.80 9500.00 81.629 295.269 8814.81 8866.61 96oo.00 81.629 295.269 8829.37 8881.17 9700.00 81.629 295.269 8843.92 8895.72 9741.75 81.629 295.269 8850.00 8901.80 9800.00 81.629 295.269 8858.48 891o.28 9900.00 81.629 295.269 8873.04 8924.84 10000.00 81.629 295.269 8887.60 8939.40 16.44s 23.69w 5975008.27 N 670764.59 E 15.56 S 29.49W 5975009.02 N 670758.77 E 13.96 S 37.47W 5975010.44N 670750.76 E 13.08 S 41.26W 5975011.23 N 670746.95 E 9.92 S 53.51W 5975014.12 N 670734.63 E 0.79 N 88.09W 5975024.03 N 670699.81 E 12.15 N 120.15W 5975034.66 N 670667.50 E 12.46 N 120.99W 5975034.95 N 670666.66 E 23.01 N 149.10W 5975044.86 N 670638.32 E 27.63 N 161.21W 5975049.21 N 670626.10 E 28.29 N 162.93W 5975049.83 N 670624.36 E 44.56 N 204.05W 5975065.15 N 670582.88 E 50.87 N 219.47W 5975071.11N 670567.33 E 54.16 N 227.41W 5975074.22 N 670559.32 E 68.37 N 261.01W 5975087.66 N 670525.40 E 85.27 N 299.79W 5975103.67 N 670486.24 E 124.80 N 386.70W 5975141.21 N 670398.46 E 133.98 N 406.26W 5975149.94 N 670378.70 E 166.95 N 476.11W 5975181.32 N 670308.11 E 209.19 N 565.58W 5975221.50 N 670217.70 E 251.42 N 655.05W 5975261.68 N 670127.29 E 293.65 N 744.52W 5975301.87 N 670036.89 E 319.03 N 798.30W 5975326.02 N 669982.55 E 335.88 N 833.99W 5975342.05 N 669946.48 E 378.11 N 923.45W 5975382.23 N 669856.07 E 420.34 N 1012.92W 5975422.42 N 669765.67 E 437.97 N 1050.27W 5975439.19 N 669727.93 E 462.58 N 1102.39W 5975462.60 N 669675.26 E 504.81 N 1191.86W 5975502.78 N 669584.85 E 547.04 N 1281.33W 5975542.96 N 669494.45 E 10.000 10.000 12.000 12.000 12.000 12.000 12.000 6.000 6.000 6.000 12.000 12.000 12.000 12.000 12.000 12.000 12.000 0.000' 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 19.99 25.86 33.99 37.87 50.51 86.52 120.19 121.07 150.71 163.50 165.32 208.83 225.19 233.62 269.36 310.71 4O3.70 424.68 499.66 595.69 691.73 787.76 845.48 883.79 979.82 1075.85 1115.94 1171.88 1267.91 1363.94 KOP · Start Dir @ 10.000°/100ft' 8450.00ft MD, 8441.22ft TVD TSHUB Dir Rate Increase @ 12.000°/100ft · 8490.00ft MD, 8478.68ft TVD TSAD TZ3 Dir Rate Decrease @ 6.000°/100ft- 8656.09ft MD; 8618.80ft TVD TZ2C Dir Rate Increase @ 12.000°/100ft· 8720.91ft MD, 8665.61ft TVD 26N 25N 24N End Dir, Sail @ 81.629°-9021.92fi MD, 8797.01fiTVD 21N TZ1B Continued... 13 August, 1998 - 11:08 - I - DrillQuest -; Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10016.51 81.629 295.269 8890.00 8941.80 10079.19 81.629 295.269 8899.12 8950.92 10100.00 82.208 293.250 8902.05 8953.85 10200.00 85.107 283.619 8913.12 8964.92 10300.00 88.142 274.073 8919.02 8970.82 10360.22 90.000 268.344 8920.00 8971.80 10373.14 91.292 268.344 8919.85 8971.65 10400.00 91.292 268.344 8919.25 8971.05 10500.00 91.292 268.344 8916.99 8968.79 10600.00 91.292 268.344 8914.74 8966.54 10700.00 91.292 268.344 8912.48 8964.28 10800.00 91.292 268.344 8910.23 8962.03 10810.18 91.292 268.344 8910.00 8961.80 10826.67 89.973 268.344 8909.82 8961.62 10900.00 89.973 268.344 8909.85 8961.65 11000.00 89.973 268.344 8909.90 8961.70 11100.00 89.973 268.344 8909.95 8961.75 11200.00 89.973 268.344 8910.00 8961.80 11210.05 89.973 268.344 8910.00 8961.80 11266.25 93.345 268.344 8908.37 8960.17 11300.00 93.345 268.344 8906.40 8958.20 11400.00 93.345 268.344 8900.57 8952.37 11409.78 93.345 268.344 8900.00 8951.80 11500.00 87.931 268.344 8899.00 8950.80 11532.52 85.980 268.344 8900.72 8952.52 Sperry-Sun Drilling Services Proposal Report for K-19A Wp3 Alaska State Plane Zone 4 PBU_WOA K Pad Local Coordinates --- Northings Eastings (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°/100ft) (ft) Comment 554.01 N 1296.10W 580.48 N 1352.18W 588.95 N 1370.96W 620.31 N 1465.13W 635.63 N 1563.65W 636.90 N 1623.82W 636.53 N. 1636.73W 635.75 N 1663.57W 632.86 N 1763.51W 629.97 N 1863.44W 627.08 N 1963.37W 624.19 N 2063.30W 623.90 N 2073.48W 623.42 N 2089.96W 621.30 N 2163.26W 618.41 N 2263.22W 615.52 N 2363.18W 612.63 N 2463.13W 612.34 N 2473.18W 610.72 N 2529.32W 609.75 N 2563.00W 606.86 N 2662.79W 606.58 N 2672.55W 603.97 N 2762.69W 603.03 N 2795.15W 5975549.60 N 669479.52 E 0.000 1379.80 5975574.78 N 669422.85 E 0.000 1439.99 5975582.82 N 669403.88 E 10.000 1460.07 5975612.03 N 669309.02 E 10.000 1558.57 5975625.10 N 669210.18 E 10.000 1658.18 5975625.00 N 669150.00 E 10.000 1717.42 5975624.33 N 669137.10 E 10.000 1730.00 5975622.95 N 669110.28 E 0.000 1756.17 5975617.78 N 669010.44 E 0.000 1853.58 5975612.62 N 668910.60 E 0.000 1950.99 5975607.45 N 668810.76 E 0.000 2048.40 5975602.29 N 668710.91E 0.000 2145.81 5975601.76 N 668700.75 E 0.000 2155.73 5975600.91 N 668684.28 E 8.000 2171.79 5975597.12 N 668611.05 E 0.000 2243.24 5975591.96 N 668511.19 E 0.000 2340.67 5975586.79 N 668411.32 E 0.000 2438.10 5975581.63 N 668311.45 E 0.000 2535.54 5975581.11N 668301.41E 0.000 2545.33 5975578.20 N 668245.32 E 6.000 2600.05 5975576.46 N 668211.67 E 0.000 2632.88 5975571.31 N 668111.98 E 0.000 2730.15 5975570.80 N 668102.23 E 0.000 2739.66 5975566.14 N 668012.17 E 6.000 2827.53 5975564.47 N 667979.74 E 6.000 2859.17 13N Start Dir @ 10.000°/100ft: 10079.19ft MD, 8950.92ft TVD Continue Dir @ 10.000°/100ft: 10360.22ft MD, 8971.80ft TVD 13P Target: K-19A T1, Geological End Dir, Sail @ 91.292°: 10373.14ft MD, 8971.65ft TVD Start Dir @ 8.000°/100ft: 10810.18ft MD, 8961.80ft 'I'VD Target: K-19A T2New, Geological End Dir, Sail @ 89.973°: 10826.67ft MD, 8961.62ft TVD Start Dir @ 6.000°/100ft: 11210.05ft MD, 8961.80ft 'I'VD Target: K-19A T3New, Geological End Dir, Sail @ 93.345°: 11266.25ft MD, 8960.17ft TVD Stad Dir @ 6.000°/100ft: 11409.78ft MD, 8951.80ft TVD Target: K-19A T4New, Geological End Dir, Sail @ 85.980°: 11532.52ft MD, 8952.52ft TVD Continued... ,., 13 August, 1998 - 11:08 - 2 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Proposal Report for K-19A Wp3 Alaska State Plane Zone 4 PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (ft) (°ll00ft) (ft) Comment 11600.00 85.980 268.344 8905.45 8957.25 601.09 N 2862.44W 11700.00 85.980 268.344 8912.46 8964.26 598.21 N 2962.15W 11800.00 85.980 268.344 8919.47 8971.27 595.32 N 3061.86W 11807.51 85.980 268.344 8920.00 8971.80 595.11 N 3069.35W 5975560.99 N 667912.51 E 0.000 2924.75 5975555.84 N 667812.89 E 0.000 3021.95 5975550.68 N 667713.27 E 0.000 3119.14 5975550.30 N 667705.79 E 0.000 3126.44 Total Depth · 11807.51ft MD, 8971.80ft 'i'VD 4 1/2' Lifter 13P Target: K-19A T5New, Geological All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 281.353° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11807.51ft., The Bottom Hole Displacement is 3126.51ft., in the Direction of 280.973° (True). 13 August, 1998 - 11:08 3 DrillQuest 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Ddlling ¢ ~'~; ~; ~.:~. ~::x~ ~..., ~ ~.$Approved...~> Well Close Approach Review John Powell ,, , PBU / K-19A Wp3 John, ~e abova mention~ well h~ b~en seined ~ing s~d~d ~ti-~llision me~ via D~. The scan was performed with the following parameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (per lOOO~) 8,493.00' 11,807.51 ' 1,100.00 ' 100.00' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 575.35' larger than DEAP's default settings of 100' Start Scan Radius increash~g at 50' per I000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 524.65' at the Start Scan Inspection Zone as stated above. These numbers are used to produce a final scan radius of 1431.451' which is 741.0755' larger than DEAF's default value of 690.3755' Scan Parameters Comments: At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation from Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Comparison Sublect Well Planned Well ~RCat~v9 Allowable W¢I; Denth Se~eratlon Azimuth Deviation ('. F~btint, SuresT} ('. W~ll PI~ MD) (Point to Poinfl t'l'C Direction) [Am~ro~: TL Dist) E-09 10177.74'MD 544.29 ' 19.20 ° 178.15 E-09A 10212.98 'MD 617.42 ' 357.00 ° 271.00 ' K-19 8499.85'MD 2.55 ' 151.40 o -32.57 K-19 8594.54'MD 26.45 ' 149.00 o -10.06 K-19 8678.98 'MD 69.46 ' 153.00 ° 29.61 ' K-19 8760.32'MD 111.00 ' 157.30 o 65.31 ' ,, Shut-In Required? (Seoeration no~s) Status as TeJted Maior Major Same Well Same Well Same Well Same Well Minor Minor Minor Minor Tolerance Plot required: Yes Close Approach Comments: Checked by: ~~ Approved by: ~~..~...~.~ .... ..- Date: Date: /7 '- Date: Shared Services Approval: Date: K-19Awp3_ AWD Proximity Review 8/13/98 Alaska hared · ervlces tilling WELL NAME DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT Permit ~gc/u~tatio~ Prepared: O DE:'~h~t4~ '/~~ Date: Perinit A~_ ~on~~wed: ~ Ce~-~n~? ~plication Submitted:Date: ~~ TA: Date: ! r-] PRE-RIG WORK SUNDRY NOTICE [-'] Sundry Documentation Prepared: ODE: Date: r-] Sundry Application Reviewed: SDE/ES: Date: r-] Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received Approval to Commence Operations TA: SDE/ES: Date: Date: I wen Name: I K-19A Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 3100' NSL, 4766' WEL, Sec. 4, T1 IN, R14E, UM X = 670,788 Y = 5,975,025 Target Start: X = 669,150 Y = 5,975,625 Z = 8,920' TVDss 3736' NSL, 1108' WEL, Sec 5, Ti iN, R14E Intermediate Target End: X = 673,004 Y = 5,969,993 Z = 8,735 TVDss 3297' NSL, 2679' WEL, Sec 5, TllN, R14E I AFE Number: 14P1189 IEstimated Start Date: ] 08/22/98 I MD 1~1,808' [ I R~g= [ Doyon 16 Operating days to 123 complete: I TVD: [8,920 ss I KBE: 125.50' I Well Design (conventional, slim hole, Extended Horizontal Sidetrack >3000' etc.): (3357') Objective: Sidetrack out of existing 7" csg into the base of SGR, directionally drill and geosteer 6" hole to 4.5" liner TD @ 11,808 in base of Zone 1 (8,920 TVDss). Run and cmt 4.5" liner. Complete with 4 V2", L-80 tbg, (4) GLM's and WOA tail assy. Formation Markers Formation Tops MD TVD(ss) Begin sidetrack 8,460 8,400 Sidetrack from Whipstock out of 7 "csg base of SGR into SHU. (TSHU 8406ss) SHU 8,468 8,406 TSAD 8,530 8,463 i ~ "~:~,~ ! ~.~. ~: TZ3 8,655 8,567 :~ ~' ~- :~ :: TZ2C 8,718 8,612 .~ :., -~:: GOC 9,596 8,825 (est) PGOC -TBD by Neutron Density Logs TZ1B 9,742 8,850 TI (Geological) 10,360 8,920 13P T2 New 10,810 8,910 13P T3 New 11,210 8,910 13P T4 New 11,410 8,900 13P TD Target 11,808 8,920 13P Target TD Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MDfrVD MDfrVD O.D. 6" 4 V2" 12.6# L-80 Mod 3,507' 8300' MD 11,807'/8,920' liner BTC 8290' TVD Logging Program: Open Hole Logs: Reference Logging/Bit/Directional/BI-IA Attachments Drilling section: BHA #1 (6" STR-09D Insert Tri-Cone Sidetrack/Build/Turn Assy): MWD/DIR/GR for first bit run. BHA #2: (6" STR-09D Insert Tri-Cone Lateral Assy): MWD/Dir/GR/Res for second bit run. GR will be used for correlating K-19A to offset wells. Res will be used to determine fractures, rock quality and fluid influx. Post Rig: CTU Memory CNL (prior to POP) CNL will be used to determine the GOC. Mud Program: Detailed vendor fluid program is as run on K-20A and will be kept optimized. Special design Use 6% KC1 Quickdril-N fluid with elevated low end I considerations rheology, ontinue Trend Line Charting major properties. Record LSRV at 1,2,3 minutes: Make certain they are elevated and flat KCI 6% LSRV>60,000c~s ] Density8.6-8.8 I pH 9.0-9.5 PV <15 (expect Lubetex 5% Sweeps 150,000cps w/60-80 rpm & 8-12) Add only (fresh active, not reciprocation (follow RP for BHA for Clarified Xanthan coated out on drilled max rpms) / stand back singles to per Quickdril-N solids avoid extended CBU over same 30' 10 sec Gel > 18, 10 rain >20 Follow the same detailed fluids/displacement/spacer/cementing/cleanout program from K-06A & K-20A (reviewed, edited, and attached). Directional: Reference Following Logging/Bit~irectional/BHA attachments KOP: 1) 8450' MD, drill out of 7 "csg via whipstock window at 19° inclination, build angle to 90° inclination at 10,300MD in Z1 13P. PU BHA#2 and g¢osteer to 11,807'MD @ TD and 8,920 TVDss). Maximum Hole Angle: Close Approach Well: Point to point separation 93+© in horizontal section None identified by Asset for shut-ins, E-09 '544' @10,178' MD; E-09A: 617' @ 10,213' @ MD Surface Shut Ins K-06A 35' NW, Shut in: MIRU & RDMO Cement Data: Casing/Liner P&A of original well 4.5", 12.6#, L-80 liner set in 7" 29# csg @ 8300'. Lead: Sxs/Wt/Yield Volume as needed Volume: 451.3 cu. Ft. 80.44 bbls Tail: Sxs/Wt~ield as needed/15.8/1.16 (pump w/CTU) 379/15.7/1.19 Comments "G" at 15.8 ppg Class "G", 40%+ for OH, +80' shoe, +150' lap, +200' ann See Detailed BJ Cementing Procedure & Attached MC4-D Viscosified Spacer w/1.75 ppb xanthan (Follow the detailed Conventional Cement/Displacement/Spacer Program from K. O6A (reviewed, edited, and attached) Well Control: Fluid Overbalance Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. NO ANNULAR INJECTION IN THIS WELL. K-19A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Bottom hole pressure in the target sand is 3,523 psi at 8,800' TVDss (estimated) or 7.7 EMW. The overbalance with 8.8 QuickdrilN is 500 psi, or 1.1 PPG. This is the highest bottom hole pressure expected in the wellbore trajectory. ? ;~-' ~C i~"~-~ ~'~ ~' ~5 ~'~'-- Maximum shut-in casing pressure is 2,624 psi (assumes 0.1 psi/ft gas gradient to surface) .... Drilling Discussion Well Obiective The Pad K development seeks to exploit the target Gravity Drainage in the base of Zone 1 with well K- 19A and to leave the well set up for additional sidetracks into the surrounding area. The trajectory of the well is to expose as many basal mouth bar deposits, allowing gravity drainage from fluvial and distributory channels above. Recoverable OIP in place is estimated at 1.058 MMSTB, with an initial recovery 3000 BOPD. The objective of the well is to drill an essentially horizontal section through Zone 1 basal 13P sand and follow the structure, optimizing standoff from gas, and Kavik. This well path optimizes exposure to the base of Zone 1 above the Kavik, standoff from GOC and faults for good cement zonal isolation. The cement program has been extensively modified to successfully run 2 RH turbulators/jt, eliminate the inner string & improve liner flexibility. Additionally, the program developed with the Asset, the Fluids Company, The Rig Team, Baker, B J, and Halliburton allowed full reciprocation while cementing in K- 06A. Excess cement was circulated out the long way to eliminate liner top/tool release problems. The well path of K-06A crossed 3 major faults without losses, K-20A has small faults which also present some potential loss at- 10,750, 11,200, 11,750 MD, so stay alert. Drilling Objective The objective is to chemically cut and pull the existing 3 V2" completion tubing at 8460 MD. The 6" whipstock sidetrack will exit the 7" casing at this point, into the SHU @8406 TVDss, landing into the base of Z1 @8920 TVDss (10,360'MD), with TD of the 6" hole section in the base of Zone 1 at 8920 TVDss and 11,808 MD. Directionally drill with first Build&Turn Th-Cone Assy BHA equipped with MWD/GR/Dir from 8460 MD to run out of bit or 10360' MD. The Second Lateral BHA will add Res and will build from 90-93+ degrees, and TD @ 11,808'MD @ 86 degrees. It will utilize the same full suite of Real Time MWD/DIR/GR/Res for geosteering 6" hole to maximize well placement, measure rock quality, fluid influx, and presence of faults. Dog legs in the lateral section have been minimized in plan to be 10 degrees or less. A CTU memory CNL will be run after the rig moves off the well and prior to putting the well on production to determine the GOC. The target risk is low and confined mainly to structurally small faults and uncertainty of exact GOC. A high quality cement job, obtainable with a modified conventional 2 RH turbolators/jt, cementing program developed on K-06A/K-20A and continued here on K-19A, has obtained good isolation. Better standoff/centralization with engineered displacements & sweeps, with in-guage wellbore improve bonding, minimize channels which cause premature coning, and the use of clean & non- damaging perforating pills eliminates damage during perforation and subsequent protection from seawater/brines containing corrosion inhibitors. Eliminating the inner string increases flexibility of liner w/2 turb/jt, and has shown promise of eliminating cleanout runs, and improving perf gun placement. The K-19A well will be completed as a Zone 1 producer with a 4 V2", L-80, 12.6# liner, (4) GLM's and WOA tailpipe assy. The GLM's will be run at the MDs to be determined by the Asset/Pad Engineer. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is one well, K-06A, 35' NW which will need to be shut in during MIRU and RDMO. This has been identified via Shut In Memo, Pre-Rig, and this Well Plan. DRILLING CLOSE APPROACH WELL SHUT-INS No downhole shut-ins identified on Sperry Sun directional well plans or by Asset due to close approach requirements. HOLE PROBLEMS This well will cross small known faults, with a small predicted possibility for lost circulation, or gas cut mud and gas kicks after crossing any of the faults. The faults are not prognosed to be problematic, however, their depths were identified earlier, and normal precautionary measures will be taken. Lost circulation, if it occurs, will be handled using a comprehensive lost circulation decision tree. All rig personnel should be aware and ready to effectively react to any gas kick potential. Ready to shut in any kicks and weight-up and safely circulate-out the kick. Differential sticking is a possibility while drilling across any of the faults. However, fluid design is such that differential sticking has not been a problem, even when drilling and completing with >2000 psi overbalance. Casing Shoe Kick Tolerance The smallest kick tolerance for the kick off window is calculated as infinite of influx assuming a swabbed gas influx at the top of the Sag River along the planned directional path. Based on 8.7 ppg MW (SAD 13P 8,800' TVD 7.7 ppg reservoir pore pressure), and min. frac at the window 10.0 ppg. The casing window will withstand complete (gas) evacuation to surface based on predicted pressures. Pre-Rig / Pre-Drill Work 1. RU wireline and retrieve the 3.5" HES SSSV. Valve nipple is set at 2176'MD. Test 7" packoff and tubing hanger packoff to 5000 psi and carefully cycle LDS. 2. Circulate Seawater as needed to prepare well for perforation squeeze abandonment. 3. Drift 3 V2"tubing to top of 4.5" slotted liner at 9122'MD (67 degrees). 4. Perf interval above slotted liner is 9090-9120 MD inside the 7" liner. 5. P&A slotted liner, and perfs, with cement top at 8800'MD (290' above perfs). Lay in cement with CTU, WOC, cleanout to 8800 (41 degrees) and test for 30 minutes at 3000 psi. 6. Cut the 3.5" tbg in the middle of a full joint of tubing at -8460'MD for setting whipstock. 7. Test 7" to 3000 psi before cut or retest both IA and tubing after cut. 8. If a chemical cut, follow recommended practices for successful chemical cuts, including double anchors, and balanced IA/tubing hydrostatic. 9. Displace the tubing and wellbore to 8.5 ppg seawater 10. Freeze protect top 2200'MD with diesel. 11. Bleed tubing and annuli pressures to zero. 12. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure the well 13. Remove the well house and flowlines. If necessary, level the pad. K-06A is within 35' of the K-19 wellhead. Ensure that well is shut-in during MIRU and during RDMO operations with as little shut- in time as possible. Please provide total well preparation cost on the handover form. Rig Sidetrack Procedure MIRU. Coordinate with Pad Engineer prior to MIRU D-16 that surface close approach well K-06A is shut in. Minimize shut in times during MIRU and RDMO with Pad Engineer. Obtain PE handover notes, completed, confirming well status before completing handover. Test packoffs to 5000 psi if not confirmed in pre-rig work.. . Bleed off pressures to zero. Pull B PV. Circulate out freeze protection (if required) and circulate well with seawater. Install TWCV and test to 1000 psi. 3. ND tree and send to DSM for refurbishing. NU BOP and notify AOGCC to witness or obtain waiver. Perform a full BOP test- 250/5000, annular 250/3500. . Pull the 3 V2" tubing completion from cut at 8460'. Call DSM for Norm readings if scale is present. Inspect quality of cut and report to SLB for database. o Because of the problem with casing scale plugging our MWD tools on K-06A, consider PU DP with bit and scraper to clean casing to top of tubing cut. Viscosify seawater with 2 PPB XC polymer and note scale recovered while circulating. Reuse this fluid as milling fluid. . PU Baker Bottom Set WindowMaster One-Trip Mill and RIH to Set and orient on tubing stub @ -8460'. Mill window with Baker window master mill per representatives confirmation that the top full guage string mill has exited the window and that the window is well dressed prior to POOH. Inspect mill for confirmation of window integrity. Use ditch magnets and keep them clean. Clean pits and take on new 60,000 LSRV 4% KCL / 5% Lubetex drill-in fluid. . PU STR-09D 6" insert bit and Sperry BHA#1 (See BHA Attachment) Sidetrack/Build/Turn assembly with MWD/Dir/GR/tools and kick-off directionally drilling 6" hole from SHU to BHA#1 landing pt @ 10,360'MD (8920 TVDss) in base of Zone 1. 8. PU BHA #2 Lateral Tri-Cone Assembly with second STR-09D 6" insert bit with MWD/Dir/GR/Res tools. Continue with this assembly to lateral TD at 11,808'MD (8920'TVDss). 9. Optimize gas standoff and Kavik basal standoff, while crossing a series of small faults. Prepare for losses associated with faults, though not expected as highly probable or likely. 10. Keep Fluid specs maintained at all times for optimum performance. If there are any ROP/sliding problems, call to discuss. Keep active Lubetex concentration at 5 % and utilize Lubetex spotting pills (and beads if necessary) if drilling hard, or sticky formation. 11. At TD circulate and condition the wellbore as in K-06A/K-20A "Conventional Production Cementing Pump Down Job, Modified Procedure" for optimum wellbore conditions for running and cementing liner, conventionally, with 2 RH turbulators/jt to just above GOC. 12. We will be repeating all steps (though some will be deleted as K-06A/K-20A results confirm) except where the attached document has been modified. We may not run tandem scraper/bit run to top of float shoe based on results of prior wells. One objective of this cement technique is to eliminate the cleanout run. 13. Run and cement 4.5" liner with the modified conventional program from K-06A/K-20A (attached). Displace cement with 150,000 cps/5% Lubetex/6% KC1 perf pill = to liner volume plus 30 bbls excess pill for cement pusher pill. Displace pills with clean filtered seawater. Reference procedure for rig floor cement manifold setup to divert cement wash water to slop tank, avoiding cement shoe contamination or contamination to perf pill, and minim/zing shut down to a few m/nutes. After plug bumps, and liner hanger and liner top packer are set, keep 1000 psi on drillpipe/liner. When you rotate 6 turns to the right and release from setting tool, the 1000 psi and the 30 bbl 150,000 LSRV/5 % Lubetex lead fluid will act as a pusher pill to start moving the excess cement up the annulus. Pump at max rate set back down on liner top with slack weight of 40K to confirm liner top packer set, while circulating at max rate (with C-2 running tool only) Test liner lap to 3000 psi. Follow recommended practice for liner top 150' inside 7". 14. 150,000 cps 5% clarified Xanthan 6% KC1 perf pill inside liner is to prevent sticking perf guns during 100 psi underbalanced perforation on K-19A and to m/nim/ze formation damage, especially from fluid loss of inhibitor-treated brines, and to avoid sticking guns in influx of perf debris. POOH for perf guns. Run DPC Halliburton 2-3/4" RDX DP (12.5 gm), 4 spf, random orientation, 60 degree phasing perforating guns with Champ Perf packer. Perforate 100 psi underbalance. (Perforating memo will be distributed after logs, identifying intervals and procedures.) Reshoot fluid level to determine gains/losses. POOH & lay down guns. 15. Complete well with 4 1/2", L-80 tubing, Baker 4.5x7" S-3 packer set at 8280 MD (150' inside of window of 7" at 8460'. Completion string will include (4) GLM' s and WOA tailpipe assembly, WLEG spaced & stung into top of liner tieback sleeve, and modified X nipple profile instead of SSSV. (Note: Have Camco pin the RP for 2400 psi nominal instead of 2900 and paint with white stripes to denote change. When testing tubing to 3500, only bleed tubing to 2000 psi prior to testing IA to 3000 to leave a 1000 psi differential across RP and prevent shear. Carefully bleed off IA & tubing pressures to avoid shearing RP. Contact ODE and Camco for details when you get to this step or reference attached document (also in rig files). This is our fifth well on which we have utilized this modified procedure with solid success. Space WLEG to place inside of 4.5" liner tieback sleeve when tubing is landed. Pull up and reverse circulate filtered seawater with Corexit @ 25 gal/100 bbls. 16. Position WLEG inside 4.5" tieback sleeve and drop packer setting ball. Set the packer and test the tubing to 3500 psi for 30 min. Only bleed to 2000 psi. Test annulus to 3000 for 30 min. Slowly bleed tubing and record pressure differential when RP shears. Do not freeze protect yet. 17. Install TWCV in the tubing hanger and test from the annulus to 1000 psi. 18. Install BPV & nipple down BOP equipment. 19. NU and test tree to 5000 psi. (Notify AOGCC in advance to witness or waiver) Pull TWCV and BPV. 20. Displace the annulus with diesel to 2000', overdisplacing sufficient volume through top GLM to freeze protect tubing to 2000', chasing with seawater. Install BPV, test from below, and secure the tree. 21. RDMO, pick up matting boards and herculite, clean area, perform a post rig site inspection with Pad Operator, and handover/release rig to Production. 22. Notify PE's that tie-in will require dual P-Pilot to complete and put well on production. Minimize shut-in time of K-17A. John Powell, ODE Doyon 16 Superintendent T.EE: 4' C,W 5M K'I 9 O~ ELEV = 26.30 WELLHEAD: FMc, 73-5/8" Slimhole ~ ...... KB ELEV -- 64.50 I , 9-5/8', 47 #/ft, 13704 ~ MCMurmy Gas Lift Mandrels I-- i No ~,ng MD TVD 7"29# L-gO Bu'Fr O$G ~ 3 4190' 4189' 0 ! ~ 679?' :~79§' 0 KO~: 8200' ~-112', 0.2#1ft, L-80, Mod : TUBING ID: 2.992' ; ,.,, I Packer Baker KBH-22 Seal Assy. 8939 ! I 31/2" HES "X" NIPPLE ( 2.7S" ! ! ! 3 lZ2" HES"X" NIPPrE , , CT-GR/OCL MD I 8~70' I ~iner TOP7. x 4-1/2" TIW SS Packer°f 4-1/2" slotted I 9122 £LMD 8978' 7" 29 #/ft L-80, Butt Casing I 9246 IJ / NOTE: I ! Open Perforations (9090' - 9120' MD 2 joints of blank 4-1/2" casing below TIW SS packer I I I I I I I ! I I 4-1/2" 12.6#/ft, L-80, NSCT Slotted Liner I 10,630 I D^TE ~E¥. BY COMUEm'S PFIHDHO~ BAY HNIT 1-08-95 MIX~ Completion W£LL: K-19 0/2~/~5 PP^ ~1 ,Jewelry log update ~! NO: $£C 4 5/27/98 JDR ^DD PI::RF 9090-9120' BP fixploration (Alaska) FREE: 4' ClW 5M <AL ELEV ~NELLHEAD: FM 5/8" Slimhole .~.-] ~1 .... KB ELEV = ACTUATOR: BAkl:-,i~ i I i I I 4-1/2"X Nipple I I L-80, NSCT Camco Gas Lift Mandrels 4.5' xl" Latch No MD iTvD Ang 4 , ! 3250' 3 ! S500' I 2 {7000' 1; 8000' KOP: MAX ANGLE: 4-1/2", 12.6#/ft, L-80, IBT TUBING TUBING ID: 3.958" I m CAPACITY:.0152 BBL/FT :~ ~ 7"x 4-1/2" Production Packer m m @ 8280' MD I m Top of 4-1/2" slotted linerT°P@ 8300'of 4-1/2"MD Liner9122, ' , ' ' ' 7" Whipstock @ 8450' MD ~..~ :~:_.-:_::~::- Tubing Cut @ 8460' MD ~ Top of Cement Plug@ 8800' MD ~ !i~: 3 1/2' WLI=G @ 8 ,MD 7" x 4-1/2" TIW SS Packer I I Perforat{ons (9090 9120 MD) 7" 29 #/ft L-80, Butt Casing ~ ::.':..-'~ii~iiiii ~ I I x4-1/2" IBP @ 9140' MD NOTE: 2 joints of blank 4-1/2" casing below I I I I I I I I I 4-1/2" 12.6#/ft, L-80, NSCT DATE REV. BY COMMENTS PRUDHOE BAY UNIT Proposed Completion WELL:K-lO BP Exploration (Alaska) !~-~l~--i~-Sl-ln Shared Services Drilling °""k',~".~.,~sZ"~vJ.c'=s Well: K-1gA Wp3 Proposal Data for K-19A Wp3 SURF~ACE LOCATION ~' PLOT DATE :.._~._~._~.~..._~.12-AuTd/-98 we,, Ho~ontal Origin: Well RKB ~: 25~ ~ R~ (ES~ Cma~ By: M~summentU~: ff 26.~ ff Well (CBE) Check~ By: ' ' No~h Referen~: Tree No~h I 51.80 fl RKB- ~SI D~leg seved~: D~ ~r 1~ ~ ~m: NAD27 ~ State Pla~, Venial S~fion ~imuth: 281 .~3° Z~ 4, US F~t A~roved By:~~~. Veffi~ ~i~ ~sc~pfion: Well Ve~i~ ~i~ Origin: 0.~ N,0.~ E , ' U.~r~ ,.~. ~. V~.~.~ .o~ ~.~ W.~.~ ~,~ Proposal Target Summa~ ~p~ ~p~ ~on R~e 8450.~ 18.743 277.3~ 8~1.22 16.~ S 2~-W ' ' ' 19.~ , .. T~ct 84~.~ 22.~4 282.~3 8478.68 13.96 S 37.47 W 33.~ 10.~ 8656.~ 41.837 2~.~3 8618.80 12.46 N .- 120.~ W 121.07 12.~ K-19ATI 8920.~ g971.80 636.~ N, 16~.82 W 59756~.~ N, ~9150.~ E 8720.91 45.7~ 291.~ 8665.61 28.~ N 162.93 W 165.32 6.~ K-19A ~New 8910.~ 8~1.80 623.~ N, 2073.~ W 5975~1.76 N, ~7~.75 E ~21.92 81.629 295.269 8797.01 133.98 N ~.26 W 424.68 12.~ K-19A ~New 8910.~ 8961.g0 612.~ N, 2473.18 W 5975581.~ ] N, ~301.4] E 1~79.19 81.629 295.269 8950.92 580.~ N 1352.18 W 1439.~ 0.~ K-19A T4New 8~.~ 8951.80 ~.Sg N, 2672.55 W 5975570.80 N, ~81~.23 E 10360.22 ~.~ 268.~ 8971.80 636.~ N 1623.82 W 1717.42 10.~ 10373.14 91 .~2 268.~ 8971.65 636.53 N 1636.73 W 1730.~ 10.~ [ K-IgA TSNew 8~0.~ 8971.80 595.11 N. 3~9.35 W 5975550.30 N. ~7705.79 E I0810.18 91.~2 268.~ 8961.80 623.~ N 2073.48 W 2155.73 0.~ 10826.67 89.973 268.~ 8961.62 623.42 N 2089.96 W 2 ! 71.79 8.~ 11210.05 89.973 268.~ 8961.80 612.~ N 2473.18 W 2545.33 0.~ 11266.25 93.~5 268.~ 89~.17 610.72 N ~29.32 W 2~.05 6.~ 114~.78 93.~5 2~.~ 89~ 1.80 ~.58 N 2672.55 W 2739.66 0.~ ,. : 11532.52 85.980 268.~ 8952.52 ~3.03 N 2795.15 ~ 2859.17 6.~ 11807.51 85.980 268.~ 8971.80 595. I 1 N 3~9.35 W 3126.~ 0. ,: RPPROVED :,..~ .., 8200 - ~ ~ ~ ~ -~ ~ ~ .... ~ ~-~v ~_~ __ _ ~,.~,-_~,~-~ ~ 8600- r~~ ~ ~" _~...~. ~ - ~l~.~~ ~ ~~~-~ ' ~' K-9~ccR~ ~~ - '~ F ~ :~ ~ -" ~ ~ ~ ~ ~ 13~'8941aO~D .~ 9000-- fl~D.' SD86.80 ~D ~ I I I i I I I I I 0 ~0 800 t 200 t 600 2000 2~0 2800 3200 3600 Scale: t inch = ~0~ Ve~ical Section Section ~imuth: 28t.353' (True No~h) ID illQuest' S~--I~I~L~'SLJI-I Shared Services Drilling r =.,--,n- s,=.v,cEs Well: K-19A Wp3 Proposal Data for K-19A Wp3 SURFACE LOCATION PLOT DATE: 12-Aug-98 Vertical Origin: Well ! Horizontal Coordinate~: 5975025.25 N, 670787.90 E Horizontal Origin: Well ' RKB Elevation: 25.50 ft Rig (EST) Created By: Measurement Units: ft 26.30 ft Well (CBE) L North Reference: True North 51.80 ft RKB Checked By: Dogleg severity' Degrees per 100ft Coordinate System: NAD27 Alaska State Planes, Vertical Section ~.imuth: 281.353° Zone 4, US Foot Approved By: Vertical Section Description: Well ' Vertical Section Origin: 0.00 N,0.00 E Proposal Target Summary Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate Target Nam~: TVDss: TVDflcb Wellhead Offsets: Global Cooz~nat~: 8450.00 18.743 277.368 8441.22 16.44 $ 23.69 W 19.99 K-19A T1 8920.00 8971.80 636.90 N, 1623.82 W 5975625.00.[% (t09150.00 E 8490.00 22.294 282.643 8478.68 13.96 S 37.47 W -33~99 ' '10.000 ' K-19A T2New 8910.00 8961.80 623.90 N, 2073.48 W 5975601.76 N, 668700.75 E 8656.09 41.837 290.343 8618.80 12.46 N 120.99 W 121.07 12.000 K-19A T3Ncw 8910.00 8961.80 612.34 N, 2473.18 W 5975581.11 N, 668301.41 E i 8720.91 45.700 291.000 8665.61 28.29 N 162.93 W -- 165.32 6.000 K-19A T4Ncw 8900.00 8951.80 606.58 N, 2672.55 W 5975570.80 N, 668102.23 E 9021.92 81.629 295.269 8797.01 133.98 N 406.26 W 424.68 12.000 K-19A T5Ncw 8920.00 8971.80 595.11 N, 3069.35 W 5975550.30 N. 667705.79 E 10079.19 81.629 295.269 8950.92 580.48 N 1352.18 W 1439.99 0.000 10360.22 90.000 268.344 8971.80 636.90 N 1623.82 W 1717.42 10.000 , 10373.14 91.292 268.344 8971.65 636.53 N 1636.73 W 1730.00 10.000 10810.18 91.292 268.344 8961.80 623.90 N 2073.48 W 2155.73 0.000 10826.67 89.973 268.344 8961.62 623.42 N 2089.96 W 2171.79 8.000 11210.05 89.973 268.344 8961.80 612.34 N 2473.18 W 2545.33 0.000 11266.25 93.345 268.344 8960.17 610.72 N 2529.32 W 2600.05 6.000 11409.78 93.345 268.344 8951.80 606.58 N 2672.55 W 2739.66 0.000 11532.52 85.980 268.344 8952.52 603.03 N 2795.15 W 2859.17 6.000 11807.51 85.980 268.344 8971.80 595.11N o.o. APPROVED .=ioo . 9oo .,9oo ., ioo .5oo Total Depth: 11807.51ff MD, 8971.80ft TVD End DIr, Sail O 85.980°: 11532.52tl MD, 8952.52ft TVD ~ / Start Dir 0 6.000°/100fi: 11409.78ft MD, 8951.80ft TVD \ / / End Dir, Sail ~ 93,345°: 11266.25ft MD, 8960.17ft TVD ~ / / /! Start Oir ' 6'000°/10Off: 11210'05fl MD' $961'80ff TVD \ / / / / End Oir, Sail e 89,973°: 10826.67lt MD, 8961.62lt TVD 800 -'~ \ / / / / / Start Dire 8,000°1100fl: 10610.18ff MO, S961.S0ft 'I'VD -- 800 i , ~, / / / / / / End Dir, Sail O 91.292°: 10373.141t MD, 8971.65ft TVD ~4 ~8/~7 L~ei~iD \ / / ! / / / , Oonfiflue Dir ~ 10.000°/100fl: 10:~o0.22fl MD. 8971.80fl TVD 8971.8OTVD ~ ~ ~ Start DIr ~ 10.000°/10Oft: 10079,19ff MD, 8950.g2ft TVD .E -~ ti-tM .00 400 - ~s.r - 400 ~12.34 ti. 2'i73.18 W End Dir, Sail @ 81.629°: 9021 .g2ft MD, 8797.01ft TVD ~_~U.UU II~ 0 .E 0 ./ 0 '~ Dir Rate Increase ~ 12,000°/100ft: 8490.00ft MD, 8478.68ft TVD ~ I KOP: Staff Dir O 10.O00°/100ft; 8450.00ft MD, 8441.22fl 'TVD I I I I I I I I -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 Scale: linch = 40Oft Eastings Reference is True North .=ioo .,,,ioo .,,?o . 9oo ..,,ioo ..,=ioo .8?0 .,,fo Total Depth: 11807.51ff MD, 8971.80ft TVD End DIr, Sail ~ 85.980°: 11532.52tl MD, 8952.52ft TVD ~ / Start Dir 0 6.000°/100fi: 11409.78ft MD, 8951.80ft TVD \ / / End Dir, Sail ~ 93,345°: 11266.25ft MD, 8960.17ft TVD ~ / / /, Staff Dir ' 6'000°/100fl: 11210'05ff MD' $961'80~ '~/D \ / / / / End Oir, Sail O 89,973°: 10826.67lt MD, 8961.62lt TVD \ / / / / / Start Dir ~ 8,000°/100fl: 10610.18ff MD, 8961.80ft TVD -- · ~, / / I / / / End Dir, Sail ~ 91.292°: 10373.141t MD, 8971.65ft TVD ~4 ~8/~7 L~ei~iD \ / / / / / / , 8971.8OTVD ~ ~ ~ Start DIr ~ 10.000°/10Oft: 10079,19ff MO, 8950.g2ft TVD K 19A Wp3 ti- tM .00 End Dir, Sail @ 81.629°: 9021.92ft MD, 8797.01ft TVD 0 Dir Rate increase @ 12,000°/100ft: 8490.00ft MD, 8478.68ft TVD KOP: Staff Dir ~ 10.O00°/100ft; 8450.00ft MD, 8441.22ff 'TVD I I I I I I I I Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8450.00 18.743 277.368 8389.42 8441.22 8467.59 20.285 279.906 8406.00 8457.80 8490.00 22.294 282.643 8426.88 8478.68 8500.00 23.454 283.433 8436.09 8487.89 8529.74 26.923 285.402 8463.00 8514.80 8600.00 35.193 288.605 8523.14 8574.94 8654.75 41.678 290.307 8566.00 8617.80 8656.09 41.837 290.343 8567.00 8618.80 8700.00 44.453 290.798 8599.04 8650.84 8718.33 45.546 290.976 8612.00 8663.80 8720.91 45.700 291.000 8613.81 8665.61 8779.38 52.667 292.100 8652.00 8703.80 8800.00 55.126 292.439 8664.15 8715.95 8810.40 56.366 292.602 8670.00 8721.80 8853.01 61.452 293.226 8692.00 8743.80 8900.00 67.062 293.848 8712.40 8764.20 9000.00 79.010 295.027 8741.52 8793.32 9021.92 81.629 295.269 8745.21 8797.01 9100.00 81.629 295.269 8756.58 8808.38 9200.00 81.629 295.269 8771.13 8822.93 9300.00 81.629 295.269 8785.69 8837.49 9400.00 81.629 295.269 8800.25 8852.05 9460.11 81.629 295.269 8809.00 8860.80 9500.00 81.629 295.269 8814.81 8866.61 9600.00 81.629 295.269 8829.37 8881.17 9700.00 81.629 295.269 8843.92 8895.72 9741.75 81.629 295.269 8850.00 8901.80 9800.00 81.629 295.269 8858.48 8910.28 9900.00 81.629 295.269 8873.04 8924.84 10000.00 81.629 295.269 8887.60 8939.40 Sperry-Sun Drilling Services Proposal Report for K-19A Wp3 APPROVED Alaska State Plane Zone 4 PBU_WOA K Pad Local Coordinates ...... Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100fi) Vertical Section (ft) Comment 16.44 S 23.69 W 5975008.27 N 670764.59 E 15.56 S 29.49 W 5975009.02 N 670758.77 E 13.96 S 37.47 W 5975010.44 N 670750.76 E 13.08 S 41.26 W 5975011.23 N 670746.95 E 9.92 S 53.51 W 5975014.12 N 670734.63 E 0.79 N 88.09 W 5975024.03 N 670699.81 E 12.15 N 120.15 W 5975034.66 N 670667.50 E 12.46 N 120.99 W 5975034.95 N 670666.66 E 23.01 N 149.10 W 5975044.86 N 670638.32 E 27.63 N 161.21 W 5975049.21 N 670626.10 E 28.29 N 162.93 W 5975049.83 N 670624.36 E 44.56 N 204.05 W 5975065.15 N 670582.88 E 50.87 N 219.47 W 5975071.11 N 670567.33 E 54.16 N 227.41 W 5975074.22 N 670559.32 E 68.37 N 261.01 W 5975087.66 N 670525.40 E 85.27 N 299.79 W 5975103.67 N 670486.24 E 124.80 N 386.70 W 5975141.21 N 670398.46 E 133.98 N 406.26 W 5975149.94 N 670378.70 E 166.95 N 476.11 W 5975181.32 N 670308.11 E 209.19 N 565.58 W 5975221.50 N 670217.70 E 251.42 N 655.05 W 5975261.68 N 670127.29 E 293.65 N 744.52 W 5975301.87 N 670036.89 E 319.03 N 798.30 W 5975326.02 N 669982.55 E 335.88 N 833.99 W 5975342.05 N 669946.48 E 378.11 N 923.45 W 5975382.23 N 669856.07 E 420.34 N 1012.92 W 5975422.42 N 669765.67 E 437.97 N 1050.27 W 5975439.19 N 669727.93 E 462.58 N 1102.39 W 5975462.60 N 669675.26 E 504.81 N 1191.86 W 5975502.78 N 669584.85 E 547.04 N 1281.33 W 5975542.96 N 669494.45 E 10.000 10.000 12.000 12.000 12.000 12.000 12.000 6.000 6.000 6.000 12.000 12.000 12.000 12.000 12.000 12.000 12.000 0.000' 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 19.99 25.86 33.99 37.87 50.51 86.52 120.19 121.07 150.71 163.50 165.32 208.83 225.19 233.62 269.36 310.71 403.70 424.68 499.66 595.69 691.73 787.76 845.48 883.79 979.82 1075.85 1115.94 1171.88 1267.91 1363.94 KOP: Start Dir @ 10.000°/100ft: 8450.00ft MD, 8441.22ft TVD TSHUB Dir Rate Increase @ 12.000°/100ft: 8490.00ft MD, 8478.68ft TVD TSAD TZ3 Dir Rate Decrease @ 6.000°/100ft: 8656.09ft MD,. 8618.80ft TVD TZ2C Dir Rate Increase @ 12.000°/100ft: 8720.91ft MD, 8665.61ft TVD 26N 25N 24N End Dir, Sail @ 81.629°: 9021.92ft MD, 8797.01ft TVD 21N TZ1B Continued... 13 August, 1998- 11:08 - I- DrillQuest Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10016.51 81.629 295.269 8890.00 8941.80 10079.19 81.629 295.269 8899.12 8950.92 10100.00 82.208 293.250 8902.05 8953.85 10200.00 85.107 283.619 8913.12 8964.92 10300.00 88.142 274.073 8919.02 8970.82 10360.22 90.000 268.344 8920.00 8971.80 10373.14 91.292 268.344 8919.85 8971.65 10400.00 91.292 268.344 8919.25 8971.05 10500.00 91.292 268.344 8916.99 8968.79 10600.00 91.292 268.344 8914.74 8966.54 10700.00 91.292 268.344 8912.48 8964.28 10800.00 91.292 268.344 8910.23 8962.03 10810.18 91.292 268.344 8910.00 8961.80 10826.67 89.973 268.344 8909.82 8961.62 10900.00 89.973 268.344 8909.85 8961.65 11000.00 89.973 268.344 8909.90 8961.70 11100.00 89.973 268.344 8909.95 8961.75 11200.00 89.973 268.344 8910.00 8961.80 11210.05 89.973 268.344 8910.00 8961.80 11266.25 93.345 268.344 8908.37 8960.17 11300.00 93.345 268.344 8906.40 8958.20 11400.00 93.345 268.344 8900.57 8952.37 11409.78 93.345 268.344 8900.00 8951.80 11500.00 87.931 268.344 8899.00 8950.80 11532.52 85.980 268.344 8900.72 8952.52 Sperry-Sun Drilling Services Proposal Report for K- 19A Wp3 APPEOVED Alaska State Plane Zone 4 PBU_WOA K Pad Local Coordinates ....... Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100ft) Vertical Section (ft) Comment 554.01 N 1296.10 W 5975549.60 N 669479.52 E 580.48 N 1352.18 W 5975574.78 N 669422.85 E 588.95 N 1370.96 W 5975582.82 N 669403.88 E 620.31 N 1465.13 W 5975612.03 N 669309.02 E 635.63 N 1563.65 W 5975625.10 N 669210.18 E 636.90 N 1623.82 W 5975625.00 N 669150.00 E 636.53 N 1636.73 W 5975624.33 N 669137.10 E 635.75 N 1663.57 W 5975622.95 N 669110.28 E 632.86 N 1763.51 W 5975617.78 N 669010.44 E 629.97 N 1863.44 W 5975612.62 N 668910.60 E 627.08 N 1963.37 W 5975607.45 N 668810.76 E 624.19 N 2063.30 W 5975602.29 N 668710.91 E 623.90 N 2073.48 W 5975601.76 N 668700.75 E 623.42 N 2089.96 W 5975600.91 N 668684.28 E 621.30 N 2163.26 W 5975597.12 N 668611.05 E 618.41 N 2263.22 W 5975591.96 N 668511.19 E 615.52 N 2363.18 W 5975586.79 N 668411.32 E 612.63 N 2463.13 W 5975581.63 N 668311.45 E 612.34 N 2473.18 W 5975581.11 N 668301.41 E 610.72 N 2529.32 W 5975578.20 N 668245.32 E 609.75 N 2563.00 W 5975576.46 N 668211.67 E 606.86 N 2662.79 W 5975571.31 N 668111.98 E 606.58 N 2672.55 W 5975570.80 N 668102.23 E 603.97 N 2762.69 W 5975566.14 N 668012.17 E 603.03 N 2795.15 W 5975564.47 N 667979.74 E 0.000 0.000 10.000 10.000 10.000 10.000 10.000 0.000 0.000 0.000 0.000 0.000 0.000 8.000 0.000 0.000 0.000 0.000 0.000 6.000 0.000 0.000 0.000 6.000 6.000 1379.80 1439.99 1460.07 1558.57 1658.18 1717.42 1730.00 1756.17 1853.58 1950.99 2048.40 2145.81 2155.73 2171.79 2243.24 2340.67 2438.10 2535.54 2545.33 2600.05 2632.88 2730.15 2739.66 2827.53 2859.17 13N Start Dir @ 10.000°/100ft: 10079.19ft MD, 8950.92ft TVD Continue Dir @ 10.000°/100ft: 10360.22ft MD, 8971.80ft 'I'VD 13P Target: K-19A T1, Geological End Dir, Sail @ 91.292°: 10373.14ft MD, 8971.65ft TVD Start Dir @ 8.000°/100ft: 10810.18ft MD, 8961.80ft 'I'VD Target: K-19A T2New, Geological End Dir, Sail @ 89.973°: 10826.67ft MD, 8961.62ft TVD Start Dir @ 6.000°/100ft: 11210.05ft MD, 8961.80ft TVD Target: K-19A T3New, Geological End Dir, Sail @ 93.345°: 11266.25ft MD, 8960.17ft TVD Start Dir @ 6.000°/100ft: 11409.78ft MD, 8951.80ft TVD Target: K-19A T4New, Geological End Dir, Sail @ 85.980°: 11532.52ft MD, 8952.52ft TVD Continued... 13 August, 1998 - 11:08 - 2 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Proposal Report for K-1gA Wp3 APPROVED Alaska State Plane Zone 4 PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) ........ Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) Vertical Section (ft) Comment 11600.00 85.980 268.344 8905.45 8957.25 601.09 N 2862.44 W 11700.00 85.980 268.344 8912.46 8964.26 598.21 N 2962.15 W 11800.00 85.980 268.344 8919.47 8971.27 595.32 N 3061.86 W 11807.51 85.980 268.344 8920.00 8971.80 595.11 N 3069.35 W 5975560.99 N 667912.51 E 0.000 5975555.84 N 667812.89 E 0.000 5975550.68 N 667713.27 E 0.000 5975550.30 N 667705.79 E 0.000 2924.75 3021.95 3119.14 3126.44 Total Depth · 11807.51ft MD, 8971.80ft TVD 4 1/2' Lifter 13P Target: K-19A T5New, Geological All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 281.353° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11807.51ft., The Bottom Hole Displacement is 3126.51ft., in the Direction of 280.973° (True). 13 August, 1998 - 11:08 - 3 - DrillQuest A E~I~R mBiUI'TI~K I ~C. C Ol~A,q! 5631 SJlverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Ddlling APPPt0VE[ pprowd John Powell ,, : John, The above mentioned well has been scanned using standard anti-collision methods via DEAP. Well Close Approach Review PBU / K-19A Wp3 The scan was performed with thc following parameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (p~r 1000~ 8,493.00 ' 11,807.51 ' 1,100.00' 100.00' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 575.35' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 524.65' at the Start Scan Inspection Zone as stated above. These numbers axe used to produce a final scan radius of 1431.451' which is 741.0755' larger than DEAP's default value of 690.3755' Scan Parameters Comments: At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation from Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Comparison Sublect Well Planned Well ~elatlve ~llowable Weft: Denth ~;~peratlon Azimuth Deviation ('= F~lJtint Surly) I'- Wall Plan MD) /Point ~o Point) I'I'C Direction) IArmro~: 1'L Dbt) E-09 10177.74 WID 544.29 ' 19.20 ° 178.15 ' E-09A 10212.98'MD 617.42' 357.00 o 271.00 ' K-19 8499.85 'MD 2.55 ' 151.40 ° -32.57 ' K- 19 8594.54 'MD 26.45 ' 149.00 o -10.06 ' K-19 8678.98"MD 69.46 ' 153.00 o 29.61 ' K-19 8760.32'MD 111.00 ' 157.30 ° 65.31 ' Shut-in Reeulred? (Seoeration notes~ ,Status as T~ted Major Maior Same Well Same Well Same Well Same Well Minor Minor Minor Minor Tolerance Plot required: Yes Close Approach Comments: Approved by: Date: Date: Shared Services Approval: Date: K-19Awp3_ AWD Proximity Review 8/13/98 H 141161 I °~'"°~;~' ~1 I ~'~'~" VEN~O. ALASKAST 1 ~ OO DATE INVOICE / CRED~ MEMO DESCRIPTION GRO~ DI~OUNT NET , 073198 CK073198 100. O0 100. O0 HANDLINQ INST: S/H TERRIE HUBBI_~ X4628 ............... u ~UE~ FOR ~US DE~RIBED ABOVE. ~ 1 OO. OO ! dO_ OO · WELL PERMIT CHECKLIST COMPANY ~'~ ~' FIELD & POOL INIT CLASS _[~') ~,,.~ ~'"' C);I WELL NAME ~ ~U~ ~ "' ~,~ PROGRAM: exp [] dev I~ redrll ~ serv [] wellbore seg 13 ann. disposal para req [] GEOL AREA ~ ~0 UNIT# I ~ (J j'"'0 ON/OFF SHORE 0 ~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~4;~OO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ~ Y N 32. Seismic analysis of sh~ ............. Y N 33. Seabed~y (if off-shore) ............. Y N 34. Con. tact.nam, e/phone for weekly progress reports ....... Y N lexplorarory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOII(~_GY: ENGINEERING: UlC/Annular RPC~ B E~l~J~Ir~l~ WM JDH COMMISSION: DWJ RNC CO (..O /Iq' Commentsllnstructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist 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 Mon Dec 28 15:51:17 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/28 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 ..................... 98/12/28 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 UNIT ~n/~t~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: K-19A 500292253101 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 28-DEC-98 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MW-80353 AK-MW-80353 AK-MW-80353 J. SACK J. SACK J. SACK P. SMITH P. SMITH P. SMITH JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 5 AK-MW-80353 J. SACK P. SMITH MWD RUN 5 AK-MW- 80353 J. SACK P. SMITH 4 liN 14E 3100 DEC $0 19-98 FEL: 4766 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 54.30 DERRICK FLOOR: 52.80 GROUND LEVEL: 26.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 8427.0 PRODUCTION STRING 6.000 11795.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 3 THROUGH 5 ARE DIRECTIONAL WITH DUAL GAMMA RJkY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PH3kSE-4 (EWR-4) . 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 9030'MD, 8799'TVD. 6. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED AFTER MWD RUN 5. THIS DATA IS PRESENTED A TAIL TO THIS LOG. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM TRACY LOVE OF BP EXPLORATION (ALASKA), INC. ON 09 OCTOBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL K-19A. 8. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11795'MD, 8963'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISITVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING (MAD). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8385.5 11750 0 ROP 8447 5 11796 0 FET 9049 0 11757 0 RPD 9049 0 11757 0 RPM 9049 0 11757 0 RPS 9049 0 11757 0 RPX 9049 0 11757 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 8447.0 9088.0 3 9088.0 9456.0 4 9456.0 9893.0 5 9893.0 11795.0 MERGED MAIN PASS. $ 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 .liN Max frames per record ............. Undefined ~ubsent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHM_M RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR 1 68 1 68 1 68 1 68 1 68 12 16 20 24 28 Name Min Max DEPT 8385.5 11796 GR 15.7942 590.914 ROP 1.8514 302.344 RPX 2.3942 52.7743 RPS 3.8239 2000 RPM 6.4227 2000 RPD 10.1961 635.968 FET 0.6325 22.1796 Mean Nsam 10090.8 6822 53 8976 6730 46 4168 6698 20 2777 5417 28 7086 5417 30 5948 5417 31 7332 5417 2.44316 5417 First Reading 8385.5 8385.5 8447.5 9049 9049 9049 9049 9049 Last Reading 11796 11750 11796 11757 11757 11757 11757 11757 First Reading For Entire File .......... 8385.5 Last Reading For Entire File ........... 11796 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 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 ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 9999.0 11756.5 RPD 9999.0 11756.5 RPM RPS RPX GR P~AT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 9999.0 11756.5 9999.0 11756.5 9999.0 11756.5 9999.0 11749.5 9999.0 11795.0 M/ID RLIN NO. MAD PASS NO. 5 MERGED MAD PASS. $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 9893.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 MERGE BASE 11795.0 Name Min Max DEPT 9999 11795 RAT 96.4938 17436.3 GR 15.5172 215.622 RPX 3.7129 85.8623 RPS 5.7966 50.4329 RPM 9.7868 49.0614 RPD 12.617 52.5836 FET 2.4536 85.2591 Mean 10897 612.477 62 3377 10 3096 16 0819 21 2987 25 1505 39 1224 Nsam 3593 3566 3473 3488 3488 3488 3489 3488 First Reading 9999 9999 9999 9999 9999 9999 9999 9999 Last Reading 11795 11795 11749.5 11756.5 11756.5 11756.5 11756.5 11756.5 First Reading For Entire File .......... 9999 Last Reading For Entire File ........... 11795 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 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 ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NI/MBER: 3 tlAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8385.5 9025.5 ROP 8447.5 9087.5 $ LOG HEADER DATA DATE LOGGED: 02-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: VARIOUS DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9088.0 TOP LOG INTERVAL (FT) : 8447.0 BOTTOM LOG INTERVAL (FT) : 9088.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 17.6 MAXIMUM ANGLE: 82.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : TOOL NI3MBER NGP SPC 289 6.000 6.0 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: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REM3~RKS: $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6%KCL QUIKDRIL 8.60 65.0 8.8 29000 6.3 .000 .000 .000 .000 51.6 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8385.5 9087'.5 8736.5 1405 8385.5 GR 17.9241 590.914 54.5677 1281 8385.5 ROP 3.5744 247.402 36.7338 1281 8447.5 Last Reading 9087.5 9025.5 9087.5 First Reading For Entire File .......... 8385.5 Last Reading For Entire File ........... 9087.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 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 ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9042.5 9411.0 FET 9049.0 9418.0 RPD 9049.0 9418.0 RPM 9049.0 9418.0 RPS 9049.0 9418.0 RPX 9049.0 9418.0 ROP 9087.5 9456.0 $ LOG HEADER DATA DATE LOGGED: 03-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: VARIOUS DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9456.0 TOP LOG INTERVAL (FT) : 9088.0 BOTTOM LOG INTERVAL (FT) : 9456.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 MAXIMUM ANGLE: 88.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1084GR4 EWR4 ELECTROMAG. RESIS. 4 P1084GR4 $ 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 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 6% KCL QUIKDRIL 8.60 60.0 9.3 28000 5.0 .300 .182 .200 .420 53.9 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 9042.5 9456 9249.25 828 9042.5 GR 15.7942 86.5999 31.4559 738 9042.5 Last Reading 9456 9411 RPX RPS RPM RPD ROP FET 2 8642 5 0517 9 1653 13 9893 1 8514 0 7291 50.6178 16.2554 739 2000 31.0263 739 2000 41.169 739 635.968 44.3053 739 317.372 52.8273 738 16.2358 3.28548 739 9049 9049 9049 9049 9087.5 9049 9418 9418 9418 9418 9456 9418 First Reading For Entire File .......... 9042.5 Last Reading For Entire File ........... 9456 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9408 5 9415 5 9415 5 9415 5 9415 5 9415 5 9454 0 STOP DEPTH 9847.5 9854.5 9854.5 9854.5 9854.5 9854.5 9893.0 04-SEP-98 SURFACE SOFTWARE VERSION: ISC 5.07 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 VARIOUS MEMORY 9893.0 9456.0 9893.0 77.2 87.8 TOOL NUMBER P1084GR4 P1084GR4 6.000 6.0 6% KCL QUIKDRIL 8.60 58.0 9.3 29000 4.0 .130 .075 .120 .130 56.3 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 4 API 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 0 4 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 9408.5 9893 9650.75 970 GR 18.3857 107.865 37.3962 879 RPX 2.2247 52.7743 19.3744 879 RPS 3.6924 73.5613 30.481 879 RPM 6.4227 100.699 34.818 879 RPD 10.1961 99.2114 36.5629 879 ROP 7.2601 200.391 48.5025 879 FET 0.6325 18.1607 2.92492 879 First Reading 9408.5 9408.5 9415.5 9415.5 9415.5 9415.5 9454 9415.5 Last Reading 9893 9847.5 9854.5 9854.5 9854.5 9854.5 9893 9854.5 First Reading For Entire File .......... 9408.5 Last Reading For Entire File ........... 9893 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9848.5 11750.0 FET 9855.0 11757.0 RPD 9855.0 11757.0 RPX 9855.0 11757.0 RPM 9855.5 11757.0 RPS 9855.5 11757.0 ROP 9895.0 11796.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A/gI) 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 TEMDEP~ATURE (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: 08-SEP-98 ISC 5.07 VARIOUS MEMORY 11795.0 9893.0 11795.0 77.0 92.9 TOOL NUMBER P1084GR4 P1084GR4 6.000 6.0 6% KCL QUIKDRIL 8.80 57.0 9.0 30000 5.0 .130 .047 .120 .130 80.5 .0 $ 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 .liN Max frames per record ............. Undefined A~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 FET MWD 5 HOUR 4 1 68 GR MWD 5 API 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMM 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT FET GR RPX RPS RPM RPD ROP Min 9848.5 0 7158 22 1565 6 6213 9 1883 10 0888 13 8985 4 9745 Max Mean Nsam 11796 10822.2 3896 22.1796 2.19245 3805 208.868 62.0443 3804 46.9102 21.2393 3805 49.086 27.8109 3804 51.9831 27.5278 3804 58.44 28.1468 3805 302.344 48.038 3803 First Reading 9848.5 9855 9848.5 9855 9855.5 9855.5 9855 9895 Last Reading 11796 11757 11750 11757 11757 11757 11757 11796 First Reading For Entire File .......... 9848.5 Last Reading For Entire File ........... 11796 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9999 0 9999 0 9999 0 9999 0 9999 0 9999 0 9999 0 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: STOP DEPTH 11756 5 11756 5 11756 5 11756 5 11756 11749 11795 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 08-SEP-98 ISC 5.07 VARIOUS MEMORY 11795.0 9893.0 11795.0 77.0 92.9 TOOL NUMBER P1084GR4 P1084GR4 6.000 6.0 6% KCL QUIKDRIL 8.80 57.0 9.0 30000 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 M3~TRIX: 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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.0 .130 .047 .120 .130 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 5 API 4 1 68 RPX MAI) 5 OHMM 4 1 68 RPS MAD 5 OHStM 4 1 68 RPM MAD 5 OHMM 4 1 68 RPD MAD 5 OHMS4 4 1 68 RAT MAD 5 FT/H 4 1 68 FET MAD 5 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 80.5 Name Min Max Mean DEPT 9999 11795 10897 GR 15.5172 215.622 62.3377 RPX 3.7129 85.8623 10.3096 RPS 5.7966 50.4329 16.0819 RPM 9.7868 49.0614 21.2987 RPD 12.617 52.5836 25.1505 R-AT 96.4938 17436.3 612.477 FET 2.4536 85.2591 39.1224 Nsam 3593 3473 3488 3488 3488 3489 3566 3488 First Reading 9999 9999 9999 9999 9999 9999 9999 9999 Last Reading 11795 11749.5 11756.5 11756.5 11756.5 11756.5 11795 11756.5 First Reading For Entire File .......... 9999 Last Reading For Entire File ........... 11795 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/12/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/12/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER . .~********~****************** . ............................ ....... SCHLUI~BERGER ....... . ............................ ****************************** COMPANY NAlVIE : BP EXPLORATION WELL NAME : K-19A FIELD NAFiE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NURIBER : 500292253101 REFERENCE NO : 98606 DEC 1998 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC REEL NAME : 98606 CONTINUATION # : PREVIOUS REEL : COf4~ENT ' BP EXPLORATION, PRUDHOE BAY, K-19A, API #50-029-22531-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC TAPE NAME : 98606 CONTINUATION # : 1 PREVIOUS TAPE : CO~E4ENT : BP EXPLORATION, PRUDHOE BAY, K-19A, API #50-029-22531-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: K-19A API NUMBER: 5002922531 O1 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-NOV-98 JOB NUMBER: 98606 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: S. BUNDY SURFACE LOCATION SEC TI ON: 4 TOWNSHIP: 1 iN RANGE: 14E FNL: FSL: 3100 FEL: 4760 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 54.25 DERRICK FLOOR: 52.75 GROUND LEVEL: 26.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 8440.0 29. O0 2ND STRING 4. 500 11795.0 12.60 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASUR3F~ DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 11682.0 11666.5 11642.5 11635.0 11608.0 11596.5 11579 5 11521 0 11348 0 11305 0 11218 5 11103 0 11043 0 11013 5 10864 5 10735 0 10502 0 10485 5 10427 5 10422 5 10407 0 10048 0 9964 0 9947 5 9888 0 9874 5 9863 5 9823 0 9784 5 9775 5 9747 5 9726 5 9706 5 9694 5 9640 0 9459 0 9420 0 9130 5 9115 0 9079 0 9003 0 8911 0 8871 0 8844 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88888.5 11682.5 11667.0 11642.0 11635.0 11609.5 11596.0 11579.0 11520.5 11348.0 11304.0 11219.0 11103.0 11043.5 11014.5 10863.0 10733.0 10504.5 10487.5 10426.5 10421.5 10408.0 10049.0 9965.0 9947 5 9888 0 9875 5 9863 0 9824 0 9786 5 9778 0 9749 5 9726.5 9708.0 9696.5 9642.0 9460.5 9421.5 9133.0 9116.0 9078.0 9002.0 8911.5 8872.0 8845.0 MCNL 88888 5 11682 5 11667 0 11642 0 11635 0 11609 5 11596 0 11579 0 11520 5 11348 0 11304 0 11219.0 11103.0 11043.5 11014.5 10863.0 10733.0 10504.5 10487.5 10426.5 10421.5 10408.0 10049.0 9965.0 9947.5 9888.0 9875.5 9863.0 9824.0 9786.5 9778.0 9749.5 9726.5 9708.0 9696.5 9642.0 9460.5 9421.5 9133.0 9116.0 9078.0 9002.0 8911.5 8872.0 8845.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 8835.0 8835.5 8796.0 8796.5 8792.0 8792.0 8788.0 8788.5 8765.0 8765.0 8739.0 8738.0 8696.5 8695.5 8667.5 8667.5 8605.5 8603.5 8588.5 8586.0 8570.0 8567.0 8561.5 8558.5 8529.5 8527.0 8515.5 8514.0 8503.5 8502.0 8498.0 8496.5 8488.5 8487.5 8468.0 8468.5 8445.0 8446.5 8422.5 8424.0 8413.0 8414.0 8408.0 8406.5 100.0 98.5 REMARKS: 8835.5 8796.5 8792.0 8788.5 8765 0 8738 0 8695 5 8667 5 8603 5 85860 85670 8558,5 85270 8514,0 8502.0 8496.5 8487.5 8468.5 8446.5 8424.0 8414.0 8406.5 98.5 CONTAINED HEREIN IS THE MCNLDATA ACQUIRED ON BP EXPLORATION WELL K-19A ON 18-SEP-98. THE DEPTH SHIFTS SHOWN ABOVEREFLECT MCNL PASS #1 GRCH TO THE BASELIAUEGAM~4ARAY PROVIDED BYTHE CLIENT (GR.MWD); AND MCNL PASS #1 NRAT TO GR.MWD. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTgM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12: O0 PAGE: GRCH 11690.0 8300.0 MCNL 11698.0 8300.0 $ CURVE SHIFT DATA - PASS TO PASS (~!EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH MCNL ~S: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR MCNL PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELM CODE (HEX) NCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CArT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11698.400 GRCH. CNT -999.250 ArRAT. CNT 19.528 CCL. CNT -999.250 DEPT. 8299.400 GRCH. CNT 82.324 NRAT. CNT 45.959 CCL. CNT 85.000 NCNT. CNT 4806.480 FCNT. CNT 235.757 NCNT. CNT 2413.844 FCNT. CNT 67.580 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMFJ~f: 0.5000 FILE SUM~z~gY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: GRCH 11696.0 8304.0 MCNL 11704.0 8304.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER : 1 BASELINE DEPTH 88888.0 11685.0 11684.5 11670.0 11668.0 11638.0 11627.0 11613.5 11610.0 11583.5 11582.5 11558.0 11511.5 11467.5 11420.0 11419.0 11361 5 11284 0 11229 0 11216 0 11208 0 11132 5 11105 5 11092 5 11055 0 11024 0 11017.5 10998.0 10969.0 10951.0 10939.5 10916.5 10886.0 10845.0 10808.0 10797.0 10762.5 10735.0 10723.5 10678.5 10664.0 10606.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH MCNL 88886.0 88886.0 11683.0 11682.5 11609.5 11583.0 11556.0 11415.5 11358.5 11214.0 11103.5 11054.0 11017.5 10843.0 10805.5 10724.5 10665.0 11669.5 11666.5 11635.5 11625.5 11613.0 11581.0 11508.5 11465.0 11417.5 11282.5 11229.0 11207.5 11131.5 11092.0 11024.0 10997.5 10969.5 10953.0 10938.0 10914.5 10885.0 10796.5 10760.0 10734.0 10677.5 10604.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 10517.0 10499.0 10490.5 10476.5 10431.0 10427.5 10406.0 10404.0 10392 0 10352 5 10331 5 10315 0 10298 5 10293 0 10292 0 10174 5 10145 5 10139 5 10097 0 10094 0 10050 5 10029 5 10026 0 10006 5 10002 0 9972 0 9964 0 9956.0 9948.0 9925.5 9902.5 9892.0 9888.5 9879.5 9863.5 9854.5 9829.0 9823.0 9780.0 9776.0 9748.0 9747.5 9738.0 9722.0 9717.5 9697.0 9695.5 9692.0 9640.0 9639.5 9583.5 9572.0 9556.5 9501.5 9491.5 10517.0 10491.5 10426.5 10405.0 10294.0 10144.5 10096.0 10051.5 10031.5 10007.5 9964.5 9947.5 9925.0 9892.5 9863.0 9830.0 9778.0 9749.5 9697.0 9641.5 10500.5 10477.0 10431.0 10406.5 10391.0 10353.0 10332.0 10316.5 10298.5 10293.0 10175.5 10141.5 10100.0 10026.0 10007.0 10004.0 9972.5 9956.0 9902.0 9889.0 9878.5 9853.5 9821.5 9776.0 9749.5 9739.0 9725.5 9719.0 9698.5 9694.5 9640.0 9584.0 9573.0 9558.0 9502.5 9493.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 9467.5 9462.0 9459.0 9435.5 9422.5 9404.5 9395.5 9370.0 9345.5 9329.0 9311.0 9289.5 9276.5 9242.5 9225.5 9207.5 9182.5 9171.0 9147.0 9130.0 9126.5 9119.5 9106.0 91 O1.5 9079 5 9047 0 9041 0 9024 0 9018 5 9004 0 9003 5 8987 5 8967 0 8955.5 893 O. 5 8913.0 8911.0 8905.0 8878.0 8846.5 8835.0 8833.5 8812.0 8805.0 8797.5 8794.5 8790.0 8784.0 8775.5 8773.5 8770.0 8756.5 8740.0 8734.5 8730.5 9460.5 9275.0 9227.0 9184.0 9148.0 9120.0 9078.0 9002.0 8911.0 8845.5 8835.5 8813.0 8796.5 8794.5 8773.5 8754.5 8738.5 8729.0 9469.0 9463.0 9435.5 9422.5 9406.0 9396.0 9371.5 9346.0 9329.0 9312.5 9291.5 9244.5 9209.5 9173.0 9132.5 9129.5 9106.5 9100.5 9079.0 9045.5 9040.0 9022.0 9017.5 9002.5 8986.5 8966.5 8954.0 8930.0 8913.5 8905.5 8878.5 8834.0 8806.0 8790.0 8784.0 8776.0 8769.5 8734.5 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Cent er 25-NOV-1998 12:00 PAGE: 8726.0 8709 0 8697 0 8696 5 8679 0 8668 0 8654 0 8649.0 8643.0 8636.0 8605.5 8601.0 8589.0 8588.0 8570.5 8561.5 8554.0 8546.0 8533.5 8529.5 8526.5 8516.0 8513.0 8509.0 8498.0 8488.5 8480.0 8472.0 8471.5 8468.5 8429.5 8424 5 8423 0 8413 5 8404 5 8397 5 8375 0 8372 5 8358.5 8329.0 8311.5 8310.0 100.0 8695.5 8667.5 8642.0 8603.5 8586.0 8566.5 8558.0 8527.0 8514.0 8496.0 8487.5 8471.0 8468.5 8431.0 8424.0 8414.0 8403.0 8369.5 8354.0 8308.5 97.0 8725.0 8708.0 8695.5 8678.5 8653.0 8648.5 8635.0 8599.0 8585.5 8550.0 8544.0 8530.5 8523.5 8511.0 8507.0 8479.0 8471.5 8425.5 8397.0 8374.0 8326.0 8307.0 97.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR MCNL PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 NRAT TO PASS #1 NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUA~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11701 . 701 GRCH. CNT -999. 250 NCNT. CNT 4964 . 778 FCNT. CNT NRAT. CNT 18. 561 CCL. CNT -999. 250 DEPT. 8301.201 GRCH. CNT NRAT. CNT 51.547 CCL.CNT 84.578 NCNT. CNT 2374.000 FCNT. CNT 85.000 248.257 59.145 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCRE~IENT : O . 5000 FILE SD?4~zARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11696.0 8012.0 MCNL 11704.0 8012.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH MCNL 88888.0 88887.5 88888.5 11687.5 11688.0 11683.0 11682.5 11681.0 11680.5 11664.0 11664.5 11637.0 11635.5 11628.5 11628.5 11626.0 11625.5 11612.5 11613.0 11584.0 11583.0 11582.0 11580.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 12 11533.0 11513.5 11510.0 11503.5 11494.5 11485.0 11413.5 11387.5 11384.5 11358.5 11357.5 11353.0 11349.5 11304.0 11265.5 11258.0 11255.0 11222.0 11221.0 11189.0 11172.0 11165.5 11140.0 11123.5 11108.5 11093.5 11081.5 11022.5 11021.0 11009.0 10998.0 10969.0 1O959 5 10925 0 10889 0 10885 0 10844 5 1O808 0 10787.5 10762.0 10760.5 10726.0 10689.0 10676.0 10655.5 10647.5 10631.5 10621.5 10612.0 10603.0 10596.5 10578.0 10575.5 10563.5 10551.5 11510.0 11505.0 11415.5 11358.0 11256.5 11220.0 11173.5 11093.5 11023.0 11020.5 11010.0 10959.5 10924.5 10884.0 10843.0 10787.5 10760.5 10724.5 10691.0 10656.5 10623.0 10612.5 10597.0 10577.0 11531.5 11512.5 11492.0 11482.0 11386.5 11383.0 11355.0 11351.5 11348.0 11302.0 11263.5 11253.0 11220.5 11186.0 11164.0 11138.5 11121.5 11107.5 11080.5 10998.0 10969.5 10888.5 10807.0 10760.0 10675.0 10645.5 10630.5 10602.5 10579.0 10563.0 10553.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 13 10544.0 10546.5 10535.0 10535.0 10530.5 10532.5 10498.0 10501.0 10489.5 10491.5 10489.0 10491.5 10475.0 10476.5 10477.0 10463.5 10465.0 10461.5 10461.5 10443.0 10446.0 10426.5 10426.0 10419.0 10421.0 10413.0 10414.0 10403.0 10405.5 10384.0 10386.5 10331.0 10332.0 10319.5 10321.0 10310.0 10311.5 10288.5 10290 . 5 10268.5 10270.0 10254.0 10258.0 10230.5 10234.0 10229.0 10231.5 10211.5 10217.0 10177.5 10182.5 10173.5 10175.5 10167.5 10169.0 10161 . 0 10163.0 10147.0 10149.0 10146.5 10148.0 10141.0 10141.5 10137.5 10138.0 10135.5 10137.0 10107.0 10108.5 10092.0 10094.0 10082.5 10086.5 10068.0 10068.5 10058.5 10061.5 10028.0 10029.5 9991.0 9992.0 9988.0 9989.5 9970.5 9972.0 9947.0 9947.5 9946.5 9948.5 9910.5 9911.0 9904.0 9903.5 9902.0 9902.0 9892.5 9893.0 9890.5 9889.0 9878.5 9879.5 9868.5 9865.5 9862.0 9862.5 9858.5 9857.0 9840.0 9843.0 9823.0 9824.0 9821.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 ~AGE: 14 9798.5 9792.5 9789.5 9784.0 9775.5 9775.0 9772.5 9767.0 9747.5 9747.0 9737.5 9725.5 9707.0 9695.5 9695.0 9675.5 9663.5 9654.5 9641.0 9640.0 9624.0 9611.5 9581.5 9570.5 9568.5 9535.5 9509.5 9507.5 9499.0 9491.0 9484.5 9467.0 9461.0 9456.5 9433 0 9428 0 9420 0 9407 5 9388 0 9343 5 9338.5 9333.5 9321.0 9309.5 9300.5 9288.5 9282.5 9255.5 9245.0 9242.0 9214.0 9197.0 9194.0 9182.0 9170.5 9797.5 9794.0 9786.5 9778.0 9775.5 9770.0 9749.5 9727.0 9708.5 9697.5 9668.0 9642.5 9573.5 9507.0 9484.5 9458.5 9433.0 9340.5 9302.5 9247.5 9197.5 9184.5 9800.0 9776.0 9749.5 9739.0 9698.5 9678.0 9657.5 9643.5 9626.5 9614.5 9583.5 9570.5 9538.0 9513.5 9502.5 9493.0 9469.0 9463.0 9426.0 9419.5 9406.0 9389.0 9346.0 9339.0 9325.0 9312.5 9291.5 9286.0 9259.0 9244.0 9218.0 9201.0 9173.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 15 9161 9146 9127 9124 9100 9079 9078 9065 9062 9040 9038 9033 9017 9003 9002 8986 8958 8942 8918 8873 8870 8840 8836 8834 8819 8816 8805 8796 8791 8789 8769 8764 8752 8734 8723 8711 8708 8697 8679 8671 8667 8653 8636 8633 8613 8605 8598 8588 8588 8575 8569 8549 8538 8535 8529 5 9163.5 5 9150.5 5 9130.0 0 9127.5 0 9100.5 0 9079.0 5 9077.5 0 9064.0 5 9062.0 0 9039.5 5 9038.0 0 9032.5 0 9017.5 0 9001.5 5 9002.5 0 8986.0 0 8957.5 0 8941.5 0 8919.0 5 8872.5 0 8871.0 0 8841.5 5 8837.5 5 8835.5 0 8819.0 5 8817.0 0 8806.0 0 8796.5 5 8792.0 5 8790.0 5 8770.0 0 8764.5 5 8752.5 5 8734.5 0 8722.5 0 871 O. 5 5 87O8.O 0 8695.5 0 8678.5 5 8672.0 0 8667.0 0 8653.0 5 8635.5 0 8632.5 0 8611.0 0 8603.5 0 8596.5 5 8586.0 0 8585.5 0 8572.5 0 8566.5 5 8546.5 0 8535.5 5 8533.0 5 8527.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 16 8526.0 8523.5 8515.5 8514.0 8514.5 8508.5 8507.0 8505.5 8504.0 8497.5 8496.0 8488.5 8487.5 8480.0 8479.5 8471.0 8471.5 8468.0 8468.5 8429.5 8431.0 8424.0 8425.5 8422.5 8424.0 8413.0 8414.5 8410.5 8410.5 8404.0 8402.5 8400.0 8397.0 8398.5 8401.0 8374.5 8373.5 8370.0 8368.0 8358.0 8356.5 8357.0 8354.5 8340.0 8338.0 8333.5 8327.5 8321.0 8312.0 8307.0 8311.5 8310.0 8306.0 8305.5 8304.5 8303.0 100.0 99.5 98.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR MCNL PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NRAT TO PASS #1 NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 17 TYPE REPR CODE VALUE .............................. 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NR~T CArT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11704.400 GRCH. CNT -999.250 NCNT. CNT 4940.647 FCNT. CNT NRAT. CNT 17.976 CCL.CNT -999.250 DEPT. NRAT. CNT 8011.400 GRCH. CNT -999.250 NCNT. CNT 2401.813 FCNT. CNT 32.910 CCL.CNT 85.000 252.377 81. 773 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUFiBERS 1, 2, 3, MCNL $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AN DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 19 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB N73M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNAV GAPI 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11698.400 NRAT. CNAV 18.867 DEPT. 8299.400 NRAT. CNAV -999.250 GRCH. CNAV -999. 250 NCNT. CNAV GRCH. CNAV 82. 324 NCNT. CNAV 4949. 249 FCNT. CNAV -999.250 FCNT. CNAV 243.106 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE . 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE · 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRE~fENT: 0.1000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 2O FILE SUMMARY VENDOR TOOL CODE START DEPTH MCNL 11705.9 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~4A RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH 8285.4 18-SEP-98 0033A 1929 18-SEP-98 11705.0 11706.0 8008.0 11703.0 1800.0 NO TOOL NUMBER ........... MGR-123 LTTN-A13 8440.0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (?T) : BLUELINUE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -20 FAR COUNT RATE HIGH SCALE (CPS): 1080 NEAR COUNT RATE LOW SCALE (CPS): 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 21 NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 22000 REMARKS: TOOL NUFfl3ERS ARE LISTED ON TOOLSTRING DIAGRAM. WELL WAS FULL OF OIL AND COMPLETION FLUIDS. WHP=O PSI. DID NOT PUMP PRIOR TO LOGGING. DEPTH CORRELATED TO SPERRY SUN MWD LOG DATED 2-SEPT TO 9-SEPT-98. DEPTH OFFSET PASS #1 = 0.0 FEET DEPTH OFFSET PASS #2 = 6.0 FEET ADDED. DEPTH OFFSET PASS #3 = 10.0 FEET ADDED. NOTE: THIS TIE-IN LOG (SPERRY SUN OF SEPT-98) IS 9 FEET SHALLOW COMPARED TO SPERRY SUN MWD DATED 15-DEC-94 TO 1-JAN-95. (THE ORIGINAL WELLBORE). TAGGED TD AT 11706 FT FiD. FIELD PICKED GOC AT 9668 FT FID. LOGGED UP ABOVE GLM #1 ON PASS #3 FOR JEWELRY LOG. THIS FILE CONTAINS THE RAW MCNL DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 22 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 0000000 CVEL PSl F/HR 0000000 GR PSl GAPI 0000000 RCAFf PS1 CPS 0000000 RCFT PS1 CPS 0000000 RTNR PSl 0000000 CCL PS1 V 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11705.900 CVEL.PS1 -999.250 GR.PS1 -999.250 RCNT. PS1 RCFT. PS1 -999.250 RTN-R.PS1 -999.250 CCL.PS1 -999.250 DEPT. 8285.400 CVEL.PS1 -999.250 GR.PS1 -999.250 RCNT. PS1 RCFT. PSl -999.250 RTNR.PS1 -999.250 CCL.PS1 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 1~: O0 PAGE: 23 MCNL $ LOG HEADER DATA DATE LOGGED: DEPTH INCREMENT: 0.1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH 11712.2 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMPIA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BORBHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH 8286.2 18-SEP-98 0033A 1929 18-SEP-98 11705.0 11706.0 8008.0 11703.0 1800.0 NO TOOL NUMBER MGR-123 LTTN-A13 8440.0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -20 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 24 FAR COUNT RATE HIGH SCALE (CPS): 1080 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REMARKS: TOOL NUMBERS ARE LISTED ON TOOLSTRING DIAGRAM. WELL WAS FULL OF OIL AND COMPLETION FLUIDS.WHP=O PSI. DID NOT PUMP PRIOR TO LOGGING. DEPTH CORRELATED TO SPERRY SUN MWD LOG DATED 2-SEPT TO 9- SEPT- 98. DEPTH OFFSET PASS #1 = 0.0 FEET DEPTH OFFSET PASS #2 = 6.0 FEET ADDED. DEPTH OFFSET PASS #3 = 10.0 FEET ADDED. NOTE: THIS TIE-IN LOG (SPERRY SUN OF SEPT~98) IS 9 FEET SHALLOW COMPARED TO SPERRY SUN MWD DATED 15-DEC-94 TO 1-JAN-95. (THE ORIGINAL WELLBORE) . TAGGED TD AT 11706 FT RID. FIELD PICKED GOC AT 9668 FT FID. LOGGED UP ABOVE GLM #1 ON PASS #3 FOR JEWELRY LOG. THIS FILE CONTAINS THE RAW MCNL DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12: O0 PAGE: 25 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUI4B SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 0000000 CVEL PS2 F/HR 0000000 GR PS2 GAPI 0000000 RCNT PS2 CPS 0000000 RCFT PS~ CPS 0000000 RTNR PS2 0000000 CCL PS2 V 0000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11712.201 CVEL.PS2 -999.250 GR.PS2 -999.250 RCNT. PS2 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 -999.250 DEPT. 8286.201 CVEL.PS2 -999.250 GR.PS2 -999.250 RCNT. PS2 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 26 DEPTH INCREMENT: O. 1000 FILE SUN~fA~Y VENDOR TOOL CODE START DEPTH 11713.4 MCNL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH 7995.4 18-SEP-98 0033A 1929 18-SEP-98 11705.0 11706.0 8008.0 11703.0 1800.0 NO TOOL ~ER MGR-123 LTTN-A13 8440.0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : -20 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 27 FAR COUNT RATE HIGH SCALE (CPS): 1080 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REFLARKS: TOOL NUMBERS ARE LISTED ON TOOLSTRING DIAGRAM. WELL WAS FULL OF OIL AND COMPLETION FLUIDS. WHP=O PSI. DID NOT PUMP PRIOR TO LOGGING. DEPTH CORRELATED TO SPERRY SUN MWD LOG DATED 2-SEPT TO 9-SEPT-98. DEPTH OFFSET PASS #1 = 0.0 FEET DEPTH OFFSET PASS #2 = 6.0 FEET ADDED. DEPTH OFFSET PASS #3 = 10.0 FEET ADDED. NOTE: THIS TIE-IN LOG (SPERRY SUN OF SEPT-98) IS 9 FEET SHALLOW COMPARED TO SPERRY SUN MWD DATED 15-DEC-94 TO 1-JAN-95. (THE ORIGINAL WELLBORE). TAGGED TD AT 11706 FT MD. FIELD PICKED GOC AT 9668 FT MD. LOGGED UP ABOVE GLM #1 ON PASS #3 FOR JEWELRY LOG. THIS FILE CONTAINS THE RAW MCNL DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 28 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 CVEL PS3 F/HR 0000000 O0 000 O0 0 7 I 1 4 68 0000000000 GR PS3 GAPI 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 0000000 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11713.400 CVEL.PS3 -999.250 GR.PS3 -999.250 RCNT. PS3 -999.250 RCFT. PS3 -999.250 RTNR.PS3 -999.250 CCL.PS3 -999.250 DEPT. 7995.400 CVEL.PS3 RCFT. PS3 -999.250 RTNR.PS3 -999.250 GR.PS3 -999.250 RCNT. PS3 -999.250 -999.250 CCL.PS3 85.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC TAPE NAME : 98606 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, K-19A, API #50-029-22531-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 12:00 PAGE: 29 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC REEL NAME : 98606 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, PRUDHOE BAY, K-19A, API #50-029-22531-01
