Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-152
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG =SCI V CLL MAY 0 9 ?n±g la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 ° Suspended ❑ 1b. Well Class. 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions. Zero Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6, Date Comp., Sull or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 4/17/2019 200-152 ' 319-063 3. Address: 7, Date Spudded: 15, API Number. ' P.O. Box 196612 Anchorage, AK 99519-6612 10/25/2000 50-029.22977-00-00 4a. Location of Well (Governmental Section): e. Date TO Reached: 16. Well Name and Number: 11/3/2000 PBU 5-105 ° Surface: 4631' FSL, 4496' FEL Sec. 35, T12N, R12E, UM r 9 Ref Elevations KB 65 oB 17. Field/Pool(s): I Top of Productive Interval: 2491' FSL, 4344' FEL, Sec. 26, T12N, R12E, UM r GL 36 BF 37.91 PRUDHOE BAY, AURORA OIL 10, Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 2695' FSL, 4320' FEL, Sec. 26, T1214, R12E, UM 7693'/ 6816' ADL 028257 ' 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 618930 y- 5980835 Zone - ASP 4 8120'17203' 83-07 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MDRVD: TPI: x- 619027 y- 5983977 Zone - ASP Total Depth: x- 619047 y- 5984181 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13, Water Depth, if Offshore: 21. Re-dnMLareral Top Window MD/IVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit ail 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 my. caliper, resistivity, porosity, magnetic resonance, tlipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perfora0on record. Acronyms may be used. Attach a separate page if necessary MWD, GR, RES, NEU, DEN, PWD 23' CASING, LINER AND CEMENTING RECORD CASING WT PERGRADE FT. SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 28' 107' 28' 107' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-90 28' 2996' 28' 2833' 12-1/4" 405 six AS Lite III, 240 ax Clasa'G' 7" 26# L-90 26' 8103' 26' 7188' 8-34' 497 sic Class 'G' 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/IVD of Top and Bottom; Perforation Size and Number; Date Perftl): GRADE I DEPTH SET (MD) PACKER SET (MD/TV 3-1/Z'9,2# L-80 1 7631' 7593'/ 6726' No. A _ _ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Wq*�/1 ',DATE ��5 Was hydmulicfmcturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MDI AMOUNT AND KIND OF MATERIAL USED ``r^r(�G Vyj 7648' Set Whipstock 7648' 12 Bbls Claw 'G' 27. PRODUCTION TEST Date First Production: Not on Produtlior, Method M Operation (Flowing, gas lift, etc.): WA est:Production Date of Test-::: Hours Tested for Dill Gas -MCF: Water -Bbl: Choke Size Ga Oil Ratio: Test Period! y Flow Tubing Casina Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Grauitv- API (cor1: Press 24 Hour Rate Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only i)Lj 6/23//q 46��y maP-► " RBDMSZ---'MAY 10 2019 I& 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sidewall Cores Yes ❑ 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 ❑ No 0 Permafrost - Base 1 If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 7632' 6781, separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071, Ugnu 3901' 3585' Schrader 5350' 4788' West Sak 5609' 5004' Kuparuk 7632' 6751' Miluveach 7960' 7057' Formation at total depth: Miluveach 7960' 7057' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore 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. 1 hereby cerify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: SIMS is t Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: Datelsj/1 /) &I Contact Phone: +1 907 564 5977 INSTRUCTIONS General: This form is designed for submitting a complete and correctwell completion reportand log on all types of lands antl 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 1a. 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 tb. 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 feel 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 ocours 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 comesponding 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 5/2017 Submit ORIGINAL Only Daily Report of Well Operations S-105 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL` PULLED GUAGES FROM X -NIPPLE AT 7619' MD. 3/12/2019 ***END AWGRS. MOVE TO ANOTHER AFE*** ***CONT FROM 3-12-19 WSR ON NEW AFE & SOR***(CTD) DRIFTED W/ 20'x 2.70" DUMMY WHIPSTOCK TO TD @ 7665' SLM. RAN 24 ARM(Ext Finger) FROM TD TO SURFACE.(good data) PULLED RK-LGLV & SET RK-DGLV IN ST#2 @ 6631' MD. PULLED RK-LGLV & SET RK-DGLV IN ST#3 @ 4129' MD. PULLED S/O GLV FROM STA#1. 3/13/2019 ***CONT ON 3-14-19 WSR*** T/1/0= 1710/1865/187 LRS unit 72 Assist Slickline (PRE CTD) Pumped 5 bbls 60/40 down 3/13/2019 IA, Have heater on tran ort plumbing ***WSR Continued on 03-14-19*** ***CONT FROM 3-13-19 WSR***(CTD) LRS LOADED IA WITH 240 BBLS OF CRUDE. SET RK-DGLV IN STA#1. LRS PERFORMED PASSING MIT -IA TO 2500#. PULL—ED 2.75" WHIDDON CATCHER SUB FROM 7549' LM.(empty) 3/14/2019 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** **"WSR Continued from 03-13-19*°" Temp= S/I Assist SSL MIT- IA PASSED at 2611 psi, Max Applied Pressure= 2750 psi, Target Pressure= 2500 psi (CTD) Pumped 240 bbls 100* crude down IA to load, MIT- IA= Pumped 2.65 bbls IA to reach test pressure, IA lost 91 psi in 1st 15 min and 31 psi in 2nd 15 min for a total loss of 122 psi in 30 min test, Bleed IA pressure, Bled back 2.5 bbls, AFE sign & tags hung on tree, SSL in control of well at 3/14/2019 departure- FWHP= 1982/450/211 CTU#8 1.75" CT. Job Scope: Underream / Caliper - Pre CTD Wait for Pad Prep & Well Support rig up to finish. 4/2/2019 ***Continue Job on 4/3/19 WSR*** CTU#8 1.75" CT. Job Scope: Underream / Caliper - Pre CTD MIRU CTU. Perform Weekly BOP Test. MU & RIH HES 2.375" Logging Carrier w/ 2.50" JSN. Tag TD at 7682'. Log from compression up to 7300'. Flagged pipe at 7600.59'. Pooh. 4/3/2019 CTU#8 1.75" CT. Job Scope: Underream / Caliper - Pre CTD MIRU CTU. Perform Weekly BOP Test. MU & RIH with memory GR/CCL with 2.4" carrier/2.49" nozzle. 4/3/2019 ***In Progress*** CTU#8 1.75" CT. Job Scope: Underream / Caliper - Pre CTD MIRU CTU. Perform Weekly BOP Test. 4/3/2019 **`Continue Job on 4/4/19 WSR*** CTU#8 1.75" CT. Job Scope: Depth Log / Underream / Caliper - Pre CTD Pooh w/ Logging BHA. Receive good data (+2' Correction). Correlate to Sib Jewelry Log 9 - March -2001. Corrected TD at 7686.73'. MU & RIH w/ Baker 2-5/8" DB Underreamer w/ 6.12" Blades. Correct depth at Flag to UR blades. Displace methanol to Slick KCL. Underream from 7667'- 7621'. POOH. UR came back with all blades intact. RIH w/ PDS 24 arm extended reach caliper. Caliper from 7667' - 7300. POOH. 4/4/2019 ***In Progress*** Daily Report of Well Operations S-105 CTU#8 1.75" CT Job Scope: Depth Log / Underream / Caliper - Pre CTD Pooh w/ Logging BHA. Receive good data (+2' Correction). Correlate to Sib Jewelry Log 9 - March -2001. Corrected TD at 7686.73'. MU & RIH w/ Baker 2-5/8" DB Underreamer w/ 6.12" Blades. Correct depth at Flag to UR blades. Displace methanol to Slick KCL. Underream from 7667'- 7621'. POOH. UR came back with all blades intact. RIH w/ PDS 24 arm extended reach caliper. Caliper from 7667'- 7300. POOH. Freeze protect well w/ 24 bbls of 60/40 methanol. Town analyzed data and determined the underreaming in the casing to be sufficient for the whipstock. Start rigging down. 4/4/2019 ***Continued on 04/05/19*** TWO = TWC/10/210. Temp = Si. Bleed WHPs (Pre RIG). No wellhouse, scaffolding, AL or flowline. Tree configuration set up for CDR2. IA and OA FL @ near surface. Bled IAP from 10 psi to 0 psi in 1 minute to BT.(all gas). Bled OAP from 210 psi to 0 psi in 1 hour and 30 minutes to BT. (0.25 bbl). Held open bleed on OA for 30 minutes. Monitored for 30 minutes, IAP and OAP unchanged. Final WHPs = TWC/0/0. 4/5/2019 SV, WV = C. MV = O. IA, OA = OTG. 23:59 TWO = 50/0/200. Set 4" H TWC #438 @ 125" w/ Lubricator 840, Performed LTT on TWC 4/5/2019 (Pass). RD Upper most tree. Change out with night crew. ***Job In ro ress***. CTU#8 1.75" CT. Job Scope: Depth Log / Underream / Caliper - Pre CTD Rig down complete. Leave location and travel to W -pad. 4/5/2019 ***Job Complete*** T/1/0=50/0/200 PRE CDR2 CONTINUED FROM NIGHT SHIFT. Continued from night shift. R/D ME 60 SSV. R/U CDR tree # 6. Torqued MV x CDR tree to 573 ft lbs. R/U CDR target 90 #3. Torqued target 90 x FC to 573 ft lbs. Torqued MV x THA to 553 ft ibs. Installed CDR platform. PT'd CDR upper tree & target 90 against MV Low 300psi, High 5000psi. PT'd TWC loww 300psi, High 3500psi. Drained 3 buckets of hydo from tree for 4/5/2019 themal expansion. RDMO '**JOB COMPLETE' FWHP= TWC/0/200 See log for details. TWO = TWC/1/6. Temp = SI. WHPs (pre RIG). No welhouse, scaffolding, AL, or flowline. CDR2 tree configuration. IAP increased 1 psi and OAP increased 6 psi overnight. 4/6/2019 SV, WV = C. MV = O. IA, OA = OTG. 20:30 Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 18W Operation Summary Report Common Well Name'. 5-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Dale'. 4/14/2019 End Dale: 4/21/2019 X3 -019C6 -C: (2,416,770.00 ) Project: PBU Site: S Rig Name/No.: CDR -2 I Spud Dale/Time: 1025/2000 12:00:OOAM Rig Release: 4/27/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.O8usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 4/14/2019 0400 - 21:30 17.50 RIGU P PRE MOVE RIG FROM 1_2-07B TO 5-105A - PJSM FOR MOVING RIG WITH PEAKAND NABORSCREWS. - MOVE RIG OFF WELL L2 -07B -INSTALL JEEPS - MOVE RIG TO 5-105A -TAKE OFF JEEPS ISI -SPOT STOP BLOCK - VERIFY TREE VALVES CLOSED - SPOT SUB OVER WELLAND SET DOWN - SPOT PIT MODULE AND SET DOWN RIGACCEPTEDT 2130 NOTE: INSTALLED LOCKS AND TAGS ON LOCK— WINGS AND SWABS ON S PAD WELLS 104 _ AND 124 21:30 - 00:00 2.50 RIGU P RE RIG UP - WORK THROUGH RIG UP CHECKLISTS - HOOK UP STEAM AND PIPING, ELECTRICAL ONES INTERCONNECT - VERIFY STEAM HEAT THROUGHOUT THE RIG - SPOT AUXILIARY EQUIPMENT - RIG UP MP LINE 4/15/2019 00:00 - 02:00 2.00 RIGU P PRE RIG UP - COMPLETE RIG UP CHECKLISTS - LEAK TIGHT TEST SWAB AND MASTER _ _ VALVES, GOOD. _ 02:00 - 07:00 5.00 RIGU P PRE NIPPLE UP BOP -REMOVE TREE CAP -INSTALL BOPS. -INSTALL TURNBUCKLES ON BOPS. -MU TEST JOINTASSEMBLY -FILL COIL WITH FRESH WATER - CHECK IN AND OUT MM RATESAND • DENSITIES, CALIBRATE AND ZERO. AOGCC INSPECTOR BOB NOBLE CALLS AT 0650 AND GIVES PERMISSION TO PROCEED WITH BOP TEST. Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 5-105 Event Typer RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Dale. 4/21/2019 Project: PBU Site: S Rig Name/No.: CDR -2 Spud DateTme'. 10/25/2000 12:00 OOAM Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase (hr) _ (usft) _ 07:00 - 14:00 7.00 BOPSUR P PRE 14:00 - 15:00 1.00 BOPSUR P 15.00 - 15.30 0.50 BOPSUR P 15:30 - 17:00 1.50 1700 - 21:00 4.00 RIGU P RIGU P PRE PRE PRE PRE Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" Page 2A013 AFE No 0 -019C8 -C: (2,416 770 00 ) BPUOI: USA00000133 Description of Operations FLUSH LINES FOR BOP SHELL TEST. GOOD SHELL TEST TO 4500 PSI. TEST WITNESS WAIVED BY BOB NOBLE. ALL TESTS TO 250 / 3500 PSI. TEST 1: IRV, PACKOFF, C9, C10 BACKWARDS - PASS TEST2: BLIND/ SHEARS, RI, BLIA, BI, B4 - PASS INSTALL TEST JOINT WITH SAVER SUB REMOVED. TEST 3: ANNULAR (2"), TIW#2, B3, B2, BL1 - PASS TEST 4: UPPER 2-3/8" PIPE/ SLIPS, TIW #2, BL2, R2, T2, C15- PASS TEST 5: C16, T1, C11 - FAIL ON VALVE C4, LEAKING PAST THE GREASE PORT. TIGHTEN UP THE GREASE CAP AND RE -TEST -PASS TEST 6: LOWER 2" PIPE / SLIPS, C7, C9, C10. TV2-PASS TEST 7: C5, C6, C8, TV1 -PASS TEST B: CHOKE A, CHOKE C - PASS ACCUMULATOR TEST -PASS, TIMES RECORDED TAKE OUT TEST JOINT AND INSTALL SUB TO MOVE 2-3/8" ACROSS ANNULAR AND VBR TEST 9: ANNULAR (2-3/8"), C1, C4 - PASS TEST 10: VARIABLES (2-3/811 C2, C3 - PASS RIG DOWN BOP TEST EQUIPMENT - REMOVE TEST RISERS AND INSTALL DRILLING RISERS -PUT INJECTOR ONAND CHECKTORQUE ON TREE BOLTS 142S RIG EVAC EXERCISE WITH ROY CREW ALL PERSONS MUSTER AND ACCOUNTED FOR IN 3 MIN. CONDUCTAAR. PRESSURE TEST RISER CONNECTION TO 250 / 4200 PSI, GOOD. INSTALL BHI FLOATS. PRESSURE TEST FLOATS TO 3500 PSI, GOOD FLUID PACK STACK TO PT VC LUBRICATOR - WORK THROUGH COMMAND AND CONTROL VALVE CHECKLIST -PRESSURE UP TO 250 FOR VISUAL LTT - GOOD LOW GO TO 3700 HIGH PT - GOOD PT, BLEED OFF AND OPEN UP TO TWC -TWC PULLED, 0 PSI ON WELL - CLOSE M 8 S VALVES, LTT 3500 PSI CONFIRMED -BLOW DOWN RISER AND REMOVE LUBRICATOR - LD TWC, BODY SEAL IS NOT ON PLUG, _LOAD OUT North America - ALASKA - BP Operation Summary Report Common Well Name: $-105 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 Project: PBU Site. S AFE No End Date: 4/21/2019 X3 -019C8 -C (2,416,77000) Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 21:00 - 22:30 1.50 RIGU P PRE BOTTOM HOLE KILL -HOLD PJSM WITH CREW -MAKEUP NOZZLE BHA WITH CHECKS -MAKE UP INJECTOR AND TEST LUBRICATOR • QTS TO 3500 PSI -GOOD TEST -DISPLACE FRESH WATER FROM COIL WITH 13 BBL MEOH SPEAR FOLLOWED BY 9.0 PPG SLICK KCL -LINE UP TO TAKE RETURNS TO TIGER TANK -OPEN MASTER AND SWAB VALVE -0 PSI ON 2230 - 00'.00 1.50 RIGU P 7,693.00 PRE _'WELL__ RIH FROM SURFACE TO 4200' -PUMP 0.25 BPM IN BUILDING UP TO 100 PSI CHOKE PRESSURE THEN 0.45 OUT. -OBSERVE DROP IN OUT RATE, REDUCE CHOKE PRESSURE TOO PSI /WELL HEAD PRESSURE 35 PSI -DISCUSS WITH ODE AND DECIDE TO CONTINUE OPERATIONS. 4/16/2019 0000 - 01:45 1.75 RIGU P 7,693.00 PRE RIH FROM 4200 TO 7665' -PUMP 0.74 BPM IN 0.17 OUT. UPWT35K DWWT21KAT7650' TAKE 2K WOB AT 7686' NOTE: OBSERVES DROP IN OUT RATE, REDUCE CHOKE PRESSURE TOO PSI, DISCUSS WITH ODE AND DECIDE TO CONTINUE OPERATIONS. MAINTAINING RETURNS NOTE: STOP TRIPPING FOR 15 MINUTES TO REMAKE CONNECTION ON INJECTOR _ WEIGHT INDICATOR. 01:45 - 0300 1.25 RIGU P 7,693.00 PRE BOTTOM KILLTAKING RETURNSTOTIGER TANK -DISCUSS FLUID VOLUMES WITH ODE AND DECIDE TO START BOTTOM KILL —SHUT DOWN TO SWAP PITS AND UNABLE TO REGAIN CIRCULATION. -LINE UP DOWN THE BACKSIDE WITH CHARGE PUMP TO FILL WHILE PUMPING DOWN THE COIL AT 0.3 BPM -TOOK 6 BELS TO FILL. -SWAP BACK OVER TO PUMPING JUST DOWN THE COIL ESTABLISH CIRCULATION AT 0.4 BPM SLOWLY INCREASE PUMP RATE IN INCREMENTS TO CHECK LOSS RATE.AT 2.5 BPM IN AT 2550 PSI, OUT RATE AT 1.15-DICUSS RESULTS WITH ODE -DECIDE TO _ WAIT FOR MUD COMING FROM MUD PLANT. 03:00 - 0430 1.50 RIGU N 7,693.00 PRE WAIT ON 9.0 PPG KCL / NACL BRINE FROM MUD PLANT PUMP DOWN COIL TO MAINTAIN FULL FLUID COLUMN TAKING RETURNS TO TIGER TANK UNABLE TO MAINTAIN RETURNS, PULL UP HOLE ABOVE PERFS TO 7500' MD PUMPING DOWN COIL TO MAINTAIN WELLHEAD PRESSURE WITH CHOKE CLOSED.DISCUSS STATUS WITH WSUP AND ETL AND AGREE ON PLAN FORWARD. Printed 5/9/2019 8:49:06AM ••AII depths reported in Drillers Depths" Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" North America - ALASKA- BP Page 4 0164 Operation Summary Report Common Well Name: 5-105 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 End Date: 4/21/2019 X3-019CB-C'. (2.416,770 00 ) Project: PBU Site: S Rig NamelI CDR -2 Spud DateMme: 10/25/2000 12:00:OOAM Rig Release: 4/2712019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI. USA00000133 Active datum: KB @65.08usR (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (us8) 04:30 - 08:00 3.50 RIGU P 7,693.00 PRE MIX HI VIS QUICK DRILL N PILL 15 BBLS PUMPAT 2 BPM IN AND 1 TO 1 BPM OUT. WITH PILL AT NOZZLE SHUT IN AND BULLHEAD 10 BBLS AT 0.5 BPM AFTER 10 BBLS SQUEEZED OPEN CHOKE, CIRCULATE 0.52 / 0.35 BPM. BRING RATE UP TO 1.05 / 0.74 BPM BRING RATE UP SLOWLY 7O 1.5 / 0.97 BPM, PUMP B/U FROM 7680'. 08:00 - 10:30 2.50 RIGU P 7,693.00 PRE PURGE CT RISER WITH BRINE OUT TO TIGER TANK. BRING RETURNS INSIDE, ESTABLISH 10 MIN " LOSS RATE. PUMP 1.01 10.63 BPM. LOSS OF 4 BBLS OVER 10 MIN. POOH. AT 10:00 SWAP POWER TO_ H_IGHL_INE. 10:30 - 11:30 1.00 RIGU P 7,693.00 PRE TAG STRIPPER. PUMP 1.0 10.67 BPM FOR 10 MIN TO ESTABLISH LOSS RATE. M/U COILTRAK WHILE WAITING. WITH BHA HANGING MOVE INJECTOR OFF WELL. INJECTOR OFF AT 11:00 ATTACH NS WHIPSTOCKAND RUN WHIPSTOCK BHA IN. FILL WELL2 TIMES WHILE INJECTOR IS OFF. INJECTOR_ ONAT 11:20. 11:30 - 15:00 3.50 WHIP P 7,693.00 WEXIT RIH WITH BHA#? WHIPSTOCK BHA. CIRC THROUGH OPEN EDC, SET PUMP TRIPS LOW. ON LOSSES WHILE RIH, 0.52 / 0.42 BPM @ 330 PSI. LOG GR DOWN FROM 7250', CORRECT -9'. CONTINUE RIH TO 7660'. FLAG PIPE HERE (EOP = 7590.5') LOG CCL UP FROM 7660'. BHI CCL MATCHES THE ONE IN THE OCN. DISCUSS RESULTS WITH ODE. NO CORRECTION BASED ON CCL. 1500 - 1700 2.00 WHIP P 7,693.00 WEXIT RIH TO DEPTH OF 7654.8' AND OLTF, PLACES TOP WHIPSTOCKAT 7646' AND PINCH POINT AT 7650', CLOSE EDC AND PRESSURE UP TO 2200 PSI TO SET WHIPSTOCK. FOLLOWING SET, OPEN EDC. POOH, PUMP 1.00 / 0.38 BPM WHILE POOH. Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" Pnnted 5/9/2019 8.49.06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 5 6�6 Operation Summary Report Common Well Name. S-105 APE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Date: 4/21/2019 X3 -019C8 -C: (2,416,770.00) Project: PBU Site: S Rig Name/No.: CDR -2 Spud DateTme: 10/25/2000 12:00:00AM Rig Release: 4/27/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOi: USA00000133 Active datum: KB Q65.08usR (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _(usft) 17.00 - 18'.30 1.50 WHIP P 7,693.00 WEXIT AT SURFACE, PUMP 0.79/0.43 BPM FOR 10 MIN TO ESTABLISH LOSS RATE. LOSE 3.3 BBLS IN 10 MIN. MOVE INJECTOR OFF, TAKE OUT BHA IN ONE PICK. FILL WELL WITH 3.2 BBLS. BREAK DOWN WHIPSTOCK SETTING TOOL, STAND BACK COILTRACK REMOVE FLOATS FROM UQC. FILL WELL EVERY 10 MIN WITH 2-3 BBLS. LEAK TIGHT TEST UQC TO 3500 PSI FOR 5 MINUTES -GOOD TEST MAKE UP BHA #4 MAKE UP INJECTOR AT 1820 HOURS SET DEPTH AND TEST OTC TO 3500 PSI GOOD TEST. NOTE:FILLING HOLE EVERY 10 MINUTES _TAKING 3 BBLS TO FILL. 18.30 - 21 15 2.75 WHIP P 7,693.00 WEXIT RIH RIH AT 60 FPM, PUMP RATE .44 IN 1.38 OUT AT 202 PSI STOPAT EOP FLAG AND CORRECT -13 FEET TO 7599.53 BIT DEPTH RIH TO 7636' AND PAINT YELLOW FLAG NOTE: SLB PRESSURE TEST TO 3800 PSI OFFLINE -GOOD TEST. 21.15 - 00'.00 2.75 WHIP P 7,693.00 WEXIT CEMENT WHIPSTOCK -HOLD PJSM WITH ALL INVOLVED CREWS. -SLB BATCH UP 12 BBLS OF 15.8 PPG CEMENT, CEMENT BATCHED UP AT 2156 HRS -PUMP 5 BBLS OF SPACER -PUMP 12 BBLS OF CEMENTAT 1.5 BPM IN / 0.7 OUT 1750 PSI -PUMP 28 BBLS OF SPACER LEAVING 1 BBL OF CEMENT OUT SIDE OF COIL. AT 1.42 BPM IN / 0.76 BPM OUT 2300 PSI -POOH PUMPING CEMENTAT 1 TO 1 CEMENT OUT OF PIPE AT 6920' -POOH TO 6612' -BULL HEAD DOWN COIL 3 BBLS WITH 1200 PSI PUMP PRESSURE/WELLHEAD PRESSURE 100 PSI. AWAYAND HESITATE FOR 15 MINUTES. Pnnted 5/9/2019 8.49.06AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name. S-105 Event Type.- RE-ENTER- ONSHORE (RON) Start Date: 4/14/2019 PBU Site: S Active datum: KB @65.08usft (above Mean Sea Level) Date From - To Hrs _ (hr) 00: 4/17/2019 00 - 02:30 2.50 End Date: 4/21/2019 Task Code NPT Total Depth (usft) WHIP P- _ -- -i 7,693.00 02:30 - 06:00 3.50 WHIP P 7,693.00 06:00 - 07:30 1.50 WHIP P 7,693.00 07:30 - 09:00 1.50 WHIP P 7,693.00 AFE No X3 -019C8 -C (2,416,770.00) BPUOI: USA00000133 Phase Description of Operations Page 6 WEXIT CEMENT WHIPSTOCK -HOLD PJSM WITH ALL INVOLVED CREWS. -BULL HEAD DOWN COIL 3 BBLS FOR A TOTAL OF 6 BBLS WITH 1600 PSI PUMP PRESSURE / WELL HEAD PRESSURE 350 PSI. AWAY AND HESITATE FOR 15 MINUTES. -BULL HEAD DOWN COIL .5 BBLS FOR A TOTAL OF 6.5 BBLS WITH 1500 PSI PUMP PRESSURE/ WELL HEAD PRESSURE 300 PSI. LEAVING TOP OF CEMENT AT 7636' (10' ABOVE TOP OF WHIPSTOCK) -SLOWLY BLEED PRESSURE OFF AND OPEN CHOKE. -BRING PUMPS ON TO 1.5 BPM IN / 1.38 BPM OUTAT 2680 PSI -RIH TO 7086' OBSERVE INCREASE IN LOSS RATE, REDUCE PUMP RATEAND CALL ODE TO DISCUSS, PULL BACK TO 6600' AT MINIMUM RATE AND WAIT AN ADDITIONAL 15 MINUTES. AGREED PLAN TO CONTAMINATE :RIH AT MINIMUM RATE TO STIR CONTAM PILL THROUGH WHERE TOP OF CEMENT WAS LEFT PRIOR TO SQUEEZING TO TUBING TAIL, POOH AT PIPE DISPLACEMENT PLUS 0.1 TO 0 2 BPM. -RIH FROM 6600' TO 7590' PUMPING AT 0.2 BPM IN / 0.15 BPM OUT AT 40' PER MINUTE WITH CONTAMINATE STILL COMING OUT PIPE. -AT 7590' LOSE RETURNS INCREASE PUMP RATE TO 0.5 BPM IN TO REGAIN OUT RATE OF .15 BPM CONTINUE TO RIH TO 7624' AT 20 FPM. WEXIT POOH FROM 7624' TO 9' AT 7624' POOH PUMPING AT .65 BPM IN /.18 BPM OUT AT 20 FPM WITH CONTAMINATE COMING OUT OF PIPE UNTIL 7200' THEN FOLLWED BY 9.0 PPG BRINE. INCREASE PULLING SPEED AND DECREASE PUMP RATE AS LOSS RATE DECREASES MAINTIANING 0.1 BPM OVER PIPE DISPLACEMENT. AT 5000' SHOWING NO LOSSES INCREASE PUMP RATE SLOWLY TO ATTEMPT TO MOVE CONTAMINATES UPHOLE WITH BETTER ANNULAR VELOCITY. PUMPING AT 1 BPM IN / 0.78 OUT AT 60 FPM 7.6 BBLS LOST ON TRIP. -CHECK FOR LOSS RATE / FLOW CHECK -RETURNS 1 FOR 1, CHECK FLOW NO FLOW. WEXIT INSTALL FLOATS IN UQC. _ PRESSURE TEST UQC AND FLOATS, GOOD WEXIT Mi BHA #4 MAKE UP 2.74" MILLING BHA #4 - PICK UP 1 DEG FIXED BEND WFT MOTOR AND 2-3/8° COILTRAK TOOLS - SURFACE TESTED COILTRAK TOOL. GOOD TEST. - PRESSURE TEST QTS TO 3,500 PSI HIGH FOR 5 MINUTES -INJECTOR ON: 08:45 Printed 5/9/2019 8:49:06AM **All depths reported in Drillers Depths" Printed 5/9/2019 8:49:06AM '"All depths reported in Drillers Depths" North America - ALASKA - BP Page 7 Operation Summary Report Common Well Name: 5-105 APE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 4/14/2019 End Date. 421/2019 X3 -019C8 -C: (2,416,770.00) Project: PBU Site: S Rig Name/No.: CDR -2 Spud DateRme: 10/25/2000 12:00 OOAM Rig Release: 4/27/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000133 Active datum: KB @65.08us6 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _ (usft)__ 0900 - 11:30 2.50 WHIP P 7,693.00 WEXIT RIH RIH WITH 2.74" MILLING BHA #4 - RATE: 0.29 BPM IN, 0.59 BPM OUT. CIRC PRESSURE: 160 PSI -MUD WEIGHT: 9.03 PPG IN, 9.04 PPG OUT -WEIGHT CHECKAT 6600'IS 30K. - LOG DOWN FOR TIE-IN FROM 7300' WITH -11'CORRECTION RIH TO 7636'NO SIGN OF CEMENT. _ 11:30 - 13:00 1.50 WHIP P 7,693.00 WEXIT SWAP WELL TO DRILLING MUD. WAIT FOR 13:00 FOR CEMENT TO REACH 1000 PSI COMPRESSIVE TO START MILLING. 13:00 - 20:15 7.25 WHIP P 7,664.00 WEXIT CLOSE EDC. LIGHT TAG AT MIN RATE AT 7650'. PICK UPAND GO TO 1.82 /1.47 BPM /G i CEASE DOWNAND STARTMILLING WINDOW FREE SPIN = 3200 PSI IN RATE = 1.81 BPM OUT RATE = 1.68 BPM IAP = 317 PSI OAP = 36 PSI WOB = 1.38K TO 1.64K WOB DROPPED OFF AT 7653'BOW -MILL RAT HOLE TO 7654 - RAT HOLE MILLED,- PUMP 5 BBL HI VIS SWEEP PU AND START REAMING PASSES AT 0', 30° L, 30° RAND 1so- - DRY DRIFT WINDOW. - PAINT FLAG FOR BOTTOM OF RATHOLE (10260.26 EDP) NOTE:: AT BOTTOMS UP FOR 7654' SAMPLE SHOWED 90% FORMATION _ 20.15 - 22:30 2.25 WHIP P 7,664.00 WEXIT POOH - OPEN EDC -MONITOR WELL FOR 10 MINUTES: LOSSES 6 BPH AT.22 BPM - MUD WEIGHT: 9.12 PPG IN ,9.04 PPG OUT - RATE: 2.0 BPM IN,1.7 BPM OUT PRESSURE 2820 PSI 22'.30 - 23:15 0.75 WHIP P 7,664.00 WEXIT LD WINDOW MILLING BHA #4 -MONITOR WELL FOR 10 MINUTES AT BHA. STATIC -HOLD PJSM WHILE MONITORING WELL -CLOSE EDC, POWER DOWN - INJECTOR OFF 2245 - 2.74" GO / 2.73" NOGO ON WINDOW MILL. REAMER 2.74"GO/2.73"NOGO ',2315 - 00:00 0.75 DRILL P 7,664.00 PROD1 MAKE UP 3-1/4'BUILD BHA #5 - HOLD PJSM - PICK UP 2-3/8' ILLS MOTOR (1.8 DEG AKO) AND 2 3/8' COILTRAK TOOLS MAKE UP HYCALOG 3-1/4' BICENTER BIT 4/18/2019 00:00 - 00:30 0.50 DRILL P 7,664.00 PROD1 - SURFACE TESTED TOOL. GOOD TEST. - PRESSURE TEST OTS TO 250 PSI LOW FOR j 5 MINUTES 13500 PSI HIGH FOR 5 MINUTES - CHECK TORQUE ON SADDLE CLAMPS ON REEL - INJECTOR ON:000OHRS Printed 5/9/2019 8:49:06AM '"All depths reported in Drillers Depths" 4-1/8" CPNFLS S-105 _1OC SAFETY NOTES: .01522 bpf, D = 3.958" 3-12' TBG. D = 2.992" Minimum ID = 2.75" @ 2106' HES X NIPPLE ' TBG, 9.2#, L -90 -EVE, BRD, — 7630 bpf, D=2.992' HIGH EXPANSION WEDGE 7648' A TAG (04/16/19) PERFORAIION SUMMITY REF LOG SPERRY DGR MWD ON 1025100 ANGLEATTOPPERF: 25" @ 7650' Note: Fdefer to Production OB for historical pert data SIZE SPF TNTHT.VAL OpnlSgz DATE 2-12" 6 7650-7670 S 04/17/19 2-12" 6 7665-7685 S 04/17/19 2-12' 6 7662-7702 C 05/12/02 2-12" 6 7712-7722 C 05/12/02 GAS LFT MANDRELS ST I MD I ND I DEV/ I TYPE I VLV LATCH PORT DATE 3 0328/19 JMG/JMD PULLED FLOWTFRUSUB &GUAGES 32 RCT/JAD SETPXPLUG 11/19115 DMY RK 0 03/13/19 2 �4129�3775� 6631 5877 29 �CAAWW=� C DMY RK 0 03/13/19 1 7475 6620 27 CAM -MMM DMY RK 0 03/13/19 HES X NP. D = 2.750' 7692 1-13-12- X 4-12" XO, D = 2.992" w /XO RIPS to 3-12', D = 3.875' 759—{ 4-12' X.3-12' XO, D = 2992- I 761W 1--13-1/2' FES X NP, D=2.750' 1 7763 -13-12'WLEG,13=2.992' 7620" CTMDTr94104/19 DATE 11MOAq WVBYj COMMENTS I JORIGINALCOMPLETION DATE 02/19/19 REV BY COMMENTS I GIB/JMD SETX-LOCKwrFLOWfPRUSU3&GAlK1E 12/17/06 JCWPJC GLVCl0 12/12406 0220/19 GIB/JMD ADDED XO's ABOVE&BELOWPKR 0531N9 PJCfrLH ONE FSH REMOVEDW271M 0328/19 JMG/JMD PULLED FLOWTFRUSUB &GUAGES 1125/15 RCT/JAD SETPXPLUG 11/19115 032BA9 GIB/JMD GLVC/OMM4/19) 12/10115 DIYJMD TREE C/O 12N3/1 04/10/19 TFAM ELMD L FSH DE SG BBLS 0127/16 GrWJMD PULLED PX PLUG(01/10116) AURORA UNfT 5 WELL: 5705 PERMfT No: 2001520 API No: 50-029-22977-00 SEC 35, T12N, R12, 19) BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-105 Permit to Drill Number: 200-152 Sundry Number: 319-063 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. eamount, Jr. Commissioner DATED thisL Stof February, 2019. RBDMS01b 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 EGENLU rTQ P P 'i 19 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill 0 • Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 200-152 3. Addmss: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-22977-00-00 99519-6812 Stratigrephic ❑ Service ❑ 7, If perforating: 8. Well Name and Number'. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No El PBU S-105 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028257 • PRUDHOE BAY. AURORA OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (6): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8120• 7203 7693 6816 2382 7693 7631 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 28-107 28-107 1490 470 Surface 2969 9-5/8" 28-2996 28-2833 5750 3090 Intermediate Production 8077 7" 26-8103 26-7188 7240' 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MO (ft): 7650- 7722 6777-6842 Packers and SSSV Type: 4-1/2• Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (ft): 7593/6726 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ Stratigraphic ❑ Development El Service 14. Estimated Date for Commencing Operations: February 20, 2019 /❑ 15. We1I SStatus ait ro ed work ONJ11WDSPL Suspended 16. Verbal Approval: Date: GAS ❑ �'S((_X WAG ❑ GSTOR ❑ SPLUG rl Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz, Ryan R be deviated from without prior written approval. Contact Email: Ryan.Ciolkosz(Mbp.com Authorized Name: Mdaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Engineering Team Lead - CTD 8 RWO Authorized Signature: / Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n n Plug Integrity ❑ BOP Test C3' Mechanical Integrity Test ❑ Clearance ❑ nLocation Other: S'��EST 0 3���V5 i 1�tJftl3uk�.rd a�SV` ��S A�b 11 �`4rv� -P 1� P �dG—C�-s^'l.a w -V O- f-6J-�-oyC e ✓' �� � /�7��� Post Initial Injection MIT Req'd? Yes ❑ No ❑J/ Spacing Exception Required? Yes ❑ No <9A Subsequent Form Required: APPROVED BYTHE Approved by COMMISSIONER COMMISSION Date: �J1 J r/ \y IV Form 10-403 Revised 04/2017 MCIMS6 `FEB 19 2019 ORIGINAL mr,P, Submit Form and Approved application is valid for 12 months from the date of approval. O� AttacIn is in Duplicate �4 2'/( /I Z, lco( To: Alaska Oil & Gas Conservation Commission From: Ryang CTD Engineer I I bp ineer Date: February 7, 2019 Re: 5-105 Sundry Approval Sundry approval is requested to plug the 5-105 wellbore as part of the drilling and completion of the proposed S - 105A CTD sidetrack. Parent well, S-105, is a Kuparuk Zone C producer completed in 2000. It currently has 40' of open perfs in the Kuparuk Zone C. The intent of the S -105A wellbore is to access reserves outside the parent wellbore's 500' drainage radius. The parent reserves will be accessed via frac job near parent in the S -105A wellbore._ i Co Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around May 6th. 2019. E -line unit will set a CTD whipstock. CDR 2 will mill a 2.74" window in the 7" liner and drill an Kuparuk well to -10,341 'MD. The lateral will be completed with a 2-3/8" 4.7# L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing S-105 perforations via the S -105A liner cement iob or liner top packer set post -rig (alternate plug placement per 20 AAC 25.112(i11 and viaposi-set plug. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Start Date: February 20th, 2019 P rme Ig Work 1 F MIT - IA 2 S Drift for whi stock & caliper to whipstock setting depth 3 E Set NS Whipstock wedge 4 V Pre CTD Tree Work/set TWC Rig Work: Z Y L. rllo ' c e-�' 4 -0G -",C- 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 2. Mill 2.74" window plus 10' of rathole. Swap the well to 8.7-9.5 ppg drilling fli 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD at -10,341 MD 5. Run 2-3/8" L-80 liner. to surface is 2,382 psi. 6. Pump primary cement bringing TOC to TOL, 20 bbls of 15.3 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work, pull TWC/BPV as necessary 2. SL: Set LGLVs, set LTP (if fail lap); 3.5" WFD widepak LTP with PTSA stinger. Regulatory compliance SBHPS (review state requirements, as there is an effort to drop this requirement in the CO) 3. F: assist SL: PT LTP 4. T: Portable is flowback (plan to perf 1300 ft) 5. F: SIT 6. C: Set CBP/CIBP such that heel perfs are the only thing flowing. 7. C: mill plug to bottom (so we can produce well until frac is ready to execute) 8. S: Dummy GLVs 9. C: set CBP. Perf if necessary 10. Special projects: Frac (1 stage) 11. C: Clean out, mill CBP to bottom 12. S: Set LGLVs, regulatory compliance SBHPS. 13. T: Post frac flowback 14. F: SIT post frac * Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka WELLHEAD = 11' - 5m f= Uba SH Gen 5 ACTLATOR= - - awmE-66 KB. ELEV =- 66 BF. 2XV = — KOP = 15W Max Angle = 37° @4436' Datum WD= 763T L>BtumTVD= 67W SS , .01522 bpf, D = 3.958' 3-1/2' TBG, D = 2.992' L460-MRTC In = R Ai5 I 2996' I Minimum ID = 2.75" @ 2106' HES X Nipple 3-1/2' TBG, 9.2M, L -80 -EV E, 8RD, .0087 bof, D = 2.992' PERFOPA11ON SlJMW RY MD REF LOG: SFEFW DGR MND ON 10/25/00 ANGLE AT TOP PUWF. 25 @ 7650' Note: Refer to Production DS for listorical pert data SIZE SFF INTERVAL OprVSgz DATE 2-10 6 7650-7670 O 03/09/01 2-1/2' 6 7665-7685 O 08/07106 2-1/2' 6 7682-7702 c 05/12/02 2-1/2" 6 7712-7722 c 05/12102 3to,' 7- FLOAT SHOE H 8103' S-105 SAFETY NOTES: 69' 4-1/2'X3-12'XO, D=2.997 994' TAM PDRT COLLAR 2106' 3-12'FESX NP, D=2.750' GAS LFT MANDRELS ST MD I ND I DEV I TYPE I VLV I LATCH PDRi DATE 3 4129 3775 32 CAM -LOAM DOME RK i6 1122/06 2 6631 5877 29 CAM -MMA DOME R( 16 12/12106 1 7475 6620 27 CAM -MMM SO RIC 20 12/12/06 FES X NP, D = 2.750' 7594' JI T z 4-12' BAKER S-3 FKR Vffl H XO PUPS to 3-12', D = 3.875' 7631' —RW- VN.EG, D = 2.997 7620' H.LDTTNOTAVALABLE 7693' DATE REV BY OOMENTS DATE REV BY (DOM434lS 11/10100 ORUNALCOMPLErION 12/17/06 JCANPJC GLV CJO (12J12/O6) 05131/09 PJC/1LH ONE FISH REMDV ®11/27/06 11125115 RCTIJ A) SET PX PLUG (11/19/15) 12/10/15 DUJMJ Trill C/O(12/03/15) 01/27/16 GTW/J RJLLEDPXPLUG(01/10/16) AURORA LINT WELL: S-105 PEFMT No: °1001520 API No: 50-029-22977-00 SEC 35, T12NL R12, BP E ploration (Alaska) VAaJMAD = 11' - 5mfrlc Uha SH Gen 5 ACFMT40R= CNV" KB. BEV = BS BF. BEV = SQE SPF 31 TER Vat Opa/•0• KOP= 1506' Mix Angle = 37- @ 4438 DawmkD= 783T DatumwD= 6708 SS r CSG, 40#, L -80 -MM, D = 8-8351—L 2996' Minimum ID = 2.75" 2106' HES X Nipple 312 -TBG, 9.2#, L-80-EVF BRD, 7630' .0087 bpf, D = 2.992- 1 7650' 1 I FISH 2.75"KEY (08/10/06) 1 PERFO RATON SUMMARY I MD I ND REF LOO: SPERRY DOR MND ON +023/00 ANGLEATTOPPER F: 250 ]•S•' I VLV Note: Re ler to Prod malloo OR+or SMlertalp_a_rl data SQE SPF 31 TER Vat Opa/•0• i DATE 2-12• • 7.50- ]•]S O 0)/03101 2-12- • 70.5 - ]••5 O 0•/0]/0• 2 -+2 • 722 O2 17.2 c 03112/02 3-+2•• 0 )T+2-Ttt2 c 03/12M2 IT FLOAT COLLAR -PBTD 7' CSG, 28#, L-80-8TC, MOD, D = 6.276' SE -1 05A SAFETY NOTES: 88' 412' X 3-12' XO, D= 2.992' 21W —13-12- HES X NP, D = 2.750' GAS LFT MANDRELS ST I MD I ND I DEV I TYPE I VLV LATCH I FORT DATE 3 7618' 7631' 3-12' VkLBG, D = 2.992' CAM-AMM DMY RK 16 1122/06 2 �4129�377532 6631 5877 29 �CAFA DMY RK 16 12/12/06 1 7475 6620 27 CAM -MMM DW RK 20 12/12/06 7568' H 3-12' H6 X NP, D = 2.750' 7594' 7' x 4-12' BAKER S-3 PKR 11110100 ORIGINAL COMPLETION WITH XO RPS to 312', D = 3.875' 7608' H2.70' DER-OYMENT SLFEVF D=2.250' 05/31/09 PJC/TLH ONE FISH RHaDV ®1127/06 3-12' HES X NP, D = 2.750' 7618' 7631' 3-12' VkLBG, D = 2.992' 7620' E METTNOTAVALABLE 2-31W LW 4.7#, 140-HYD511 D=1.995 10341' DATE REV BY CONNA34TS DATE REV BY COMMENTS 11110100 ORIGINAL COMPLETION 12/17/06 JCMPJC GLV C/O (12112106) 05/31/09 PJC/TLH ONE FISH RHaDV ®1127/06 1125/15 RCT/JMD SET P)CPLl1G(11/19/15) 12/10/15 DUJND TREEC10(12/03+15) 0127/16 GTWJKU Pl1LLEO P)(R-LIG(01/10116) AU C)RA IHT WELL 5105 FERNT ND- 02001520 AH No: 50-029-22977-00 SEC 35, T12K Rig, BP Exploration (Alaska) Well Slimhole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis Top of 7" Otis O.Ok —. — — -- -- — — ------ �C082 Rig's Drip Pan Distances from top of riser Excluding quick -test sub F— 7.1116' 6k Flange X T' Otis Box Top of Annular 6.0 ft Hydril 7 1116' Top of Annular Element.Annular Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 81 B2 B3 84 Choke Line Kill Line r_irT_f CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft CL of Flow Cross 17.4 ft CL of Master 18.6 ft LDS LDS Ground Level 0 �-- Swab a, T1 �e T2 Master IA I*n Test Pump Hose 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 Res onsib e 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left comer 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 Geologist L� work) the initial reviewer will cross out that erroneous entry and initial then / it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer 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 Stat Tech for Redrill" box, they 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, they will check the Stat Tech History tab 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, they 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 Stat Tech change 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 Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in 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. BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UN AURO S-105 (200-152) PRUDHOE BAY, AURORA OIL Monthly Production Rates 10,000,000 1,000,000 t 0 a Q 100,000 V O N M 10,000 (D _ o O H LL `0 1,000 3 V >3 vOro 100 3 O F- F 10 i 11 1 a��1 - iilli�Laa�t�aiiii�lr��>♦ ��d/ilt`�IIIIII�C�RJhAIw I"�7i1■11�� I ■ • "' �� n I r.'aiT�.rPiiAi �' i"�iT„'.s�iC'i��i'•`C• c'-. Irs.�� rir Jan -2005 Jan -2010 Jan -2015 —�— Produced Gas (MCFM) • GOR - Produced Water (BOPM) -- Produced Oil (BOPM) 10,000,000 1,000,000 ID0 100,000 O 3 S 10,000 0 1 Jan -2020 SPREADSHEET _Prod-Inject_Cu"es_W el I_V117_2001520_PBU_5-105_20190211.xlsx 2/11/2019 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate I1 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: HCL Acid Stimulation WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-152 3. Address: P.O.Box 196612 Anchorage, Development EI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22977-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PBU S-105 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL r 11.Present Well Condition Summary: RECEIVED IVE Total Depth: measured 8120 feet Plugs measured 7693 feet true vertical 7203 feet Junk measured_ 7631 feet OCT 19 2017 Effective Depth: measured 7693 feet Packer measured 7595 feet true vertical 6816 feet Packer true vertical 6727 feet e AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 107 20"91.5#H-40 29-136 29-136 1490 470 Surface 2969 9-5/8"40#L-80 28-2997 28-2834 5750 3090 Intermediate Production 8072 7"26#L-80 27-8099 27-7184 7240 5410 Liner Perforation Depth: Measured depth: 7650-7665 feet feet 7665-7670 feet 7670-7682 feet 7682-7685 feet 7685-7693 feet 7693-7702 feet 7712-7722 feet True vertical depth: 6777-6791 feet feet 6791-6795 feet 6795-6806 feet 6806-6809 feet 6809-6816 feet 6816-6824 feet 6833-6842 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 7595 6727 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7650'-7702',7712'-7722'. scANNE® DEC � a�f Treatment descriptions including volumes used and final pressure: 40 Bbls 60/40 Methanol/Water,3 Bbls 2%Slick KCL,164 Bbls 2%Slick KCL+F203,41 Bbls 7.5%HCL Acid,1030 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 37 1299 192 1248 225 Subsequent to operation: 257 3145 867 1432 203 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations EI Exploratory 0 Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil EJ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt: N/A Authorized Name: Youngmun,Alex Contact Name: Youngmun,Alex Authorized Title: paruk&Schrader Bluff PE Contact Email: younak©BP.com Authorized Signature: y ...-1,.....,...-1,....., Date: /6/C/ 1 1-7 Contact Phone: +1 907 564 4864 RBD S 1k/ � Form 10404Revised 04/2017 �" 2- 11117- L .j •LU i7 Submit Original Only offr #�� /, • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 18, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Acid Stimulation of Well S-105, PTD # 200-152. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • CD m0000200-9 C)) r O O Lo LP � O C`7 Lf) I� O� f� U MOO 0 0 0 0 0 L CA LC) 'Cr c) O M CO • N- N O c- O m I"- 00 CO Ct CY LC) M CO CO O N CO C0 CO N- N- N- N N- CO CO CO F- LO CA 00 f� LI) O N CO N N N N N- 1 r-- CO `CO O 4.0 CD CON C) CO N co O) CA O O) 6) C7 6) O LC) LC) CO N CO C.) COi i i i i u) < C CO CO t 0) CO N- LC) O O) CA C) INNNN N- LO LC) C Cf) N- • 03 I-- I'_ a O O O O Q co (b CO 0J 0 J ' J J N p O N ( •� '1' N C5) C3) U °° zr N N N O) c� c� ct+' CA N N Cfl L(7 N rf C O 0) O V Lc) O co 4) N CO N- J Z cs)O _O C W Q• Oci: OZZZZ Z c O m CO m ODCCDDDD UU) 0 — F— F— F— • • . --(5 E 0) ° a-a c ° � H 0m am NtT° Tc � ? = w U) EH ° • D • a c o V pOU ' OL - O Q O N u) ° -aOU) N c O_ N Y O LO QO r- °O . +. 3 O Q N Q LY •QO , LL _ c Q N- U O C p U O < LU O m 0,- E U) N E a) 7O_ ON QCO CO U o a) Q m Q C Q O n NU = "Q O t` c .. p N z aoo cn 3 N S �? v cu W o c o- O O C"= Y 2 C O U CC O 7 U O N o QoEt .0 Osa _ Urn ° ° a) 30 ' > ami (n O)H ii n co o� O LO J o O p a) c -C-1.--1 C II to CU >� O F- N- a)) < o O_ o__C _ > "Ta_ > N N C 0 O o cn 20 a .EH C L . N ,- F- Q_j O co L00a) O c C = *k W0 O o) TC) 7 cn .N t -. p - a) Cl) L Z J - in > U al a) O C '5 N •v) _ c o rn 1- c 3 o_ a aa)) 1- o i- U z Eo v) (n L — O a) a) - 2 o cU ,-- r .Sto 7 E Qo 0 a) !3 Q � in r�i 3 ° 3 E o U O 1._ •• ° cn -- CL 2 C � C- 2 4t a) - o c 7 ° ` coo y 3 `r C U) E Q Q c a) a D m C� >, Q� � � o >, L Q.- o c,N c E) �c m mU) o � � ° ° O O in � � � 00 oa aa_ _ Q3w a- 0 a) r-- 0 U � O , (n ..i LJL. = II N N .U) 0 t Q) N '" Cl I U U (UO \ O j U �O Ch *a) ,r, CUQ -a Nn a) 63 o ° -° 3Q 3 Cl) amiciU CL Cl) _0On O ' o Q O - ai - 3 rn o a Q c,Ja N °a -0 Cr_ • o a cU o - m a°) Ev) > - - m _ Q)1° - O - 3 `o)2 °~ �'') - o.._ : LL O d v) O0 II ao O Cl E o) a . La C o H � 5 N N- cU m rx o a) Q. � . Q CU Cl Q > O 0 Cl c . I,- a- ,., c0 0 C))OD Q O Cl) o E in II N U `) C Q) N L O N C .0 N Q) aO Q O N •to (/) p-, D (LO 0 L- Q F3 CU a) _ > . Q A c * ~ LU a cU Q. _ ~ Ucp - 0 CU LU a) H , E2rn N- . O o On 3 E u) >, Q On )) w z c Q O CU 3 ,H a) - � < °) CU D2ooU o mao 0 o n.- oo c ' a) - w � a) - N •-(5 is co op°)o -) C U) r U = a) LU CU ate) to 3a _ o `. c) 0 o O to O O NLO to i..:..),- m C N. 4) I N a) O J F- poo rn0 ©0) UooF- o < N � � = U � E o - cc ` N. a) N ° 0oJ %c) ° C a)°) E ....... o 3 E o ` -o c 2 0o m � W N. c O . ..C = D o U N. CU _ D C ° 3 3 = U in o Q N m c in 't p) . I () = o c .«- L , j Q U) II > co c >,.E ;- a) a) c E in ° 3 L c a) II a) Y v cHa_ 7 O = cU - c F- - H Oai On i* C a) O __ cn * ots a) c - o a) _ O I > H N N _C U U C C co D c°)c) cCa o 00 _0 - Q U F- O_ H > U) U25 3OnI -I < 0 - 0 -0a. o2 -o < .S + Jv) w F- < N- N- N- N- N- N� } Q 0 0 0 0 0 H N N N (N N (N1 CO O) 0) O O > - '- x- N- N N H rn rn Er) a am o) 0 Q • • ) o = m / / E# ± \ / � U / / § \ o \y _ # o w ± - \ \ £ / \ / s)E _C (0 0 / \ % 0 \ $ � _ - a) - a o = -0 ® u o n o cp/ • ) N- § 0 \ % o < § / / co r, ®© 2 E o co ¥ .g - � ® = a O. / \ 2 ƒ \ \ � O �� ® $ $ « _ - c \ _ 2 \ \\ \ \ ---.. E m ! OI \ \ a o / f 9 o n .» E / aCOco = $ / & \ 2 •- •-, o CL / 2 / 2 —o c 0. w > / O2 / E 0 11 7 k< % § \ § o .• \ / f \ f \ . e± z n m @ CO a \ \ / \ / / /\ i \ > \ m@ 2 I / @ 2 ± 2 _1 � S a ,_ 12 0 0 0 5 � k e = = u o -J \ \ \ 0 \ O .g E f ' R ± £ J I \ o ) ® f / ym = # / ± y / � � 2 9'I' o k m A 4 U r a\ 0 7 $ o e g /. i / / / ± / / § / / 0 - o \ e e } O < R ± & o , - co a 2 E O % w N- ,-- mor of g # c \ r o \ \ coI A # m A a TREE= 4-1/8'OW FLS • k11_L 1- AD= 11'-5m fmc Ultra SH Gen 5 • S-1 0 5 SAFETY NOTES: +ACTUATOR= CNV ME-60 KB.ELEV- 65' BF.REV KOP= 1500' Max Angle- 37°t. 4438' / 69' —4-1/ X 3-1/T XO,D=2.997 Datum MD= 7637' Datum IVO= 6700'SS 1 884' TAM PORT COLLAR 4-1/7 TBG,12.61,L-80, .01522 bpf,D=3.958' — 69' 1 2106' —13-1/2-HES X P13,D=2.750' TOP OF 3-1/2'TBG,E)=2.997 H I 71' GAS LFT MANDRELS 9-5/8'CSG,40#,L-80-M-BTC,D=8.835'— 2996' , ST IVO ND DEV TYPE VLV LATCH FORT DATE 3 4129 3775 32 CAM-MMM DOME RK 16 11/22/06 2 6631 5877 29 CAM-MMM DOME RK 16 12/12/06 1 7475 6620 27 CAII4-MMM SO RK 20 12/12/06 Minimum ID =2.75" @ 2106' HES X Nipple 1 1 7668' —3-1/7 HES X NP,D=2.750' g g 7594' — r x 4-1/7 BAKER S-3 FKR WITH XO PUPS to 3-1/7,D=3.875' 1 1 7619' —{3-1/2'HES X NP,D=2.750' 3-1/7 TBG,9.2#,L-80-EVE,8RD,H 7630' / 7631' {3-1/2"ACM,D=2.997 .0087 bpf,13=2.992' 7620' --{ECMO TT NOT AVAL.ABLE ?? - 1FISH-2.75'X KEY (08/10/06) PERFORATK)N SUN./ARV REF LOG: SPERRY DGR NM ON 10/25M0 ANGLE AT TOP FERE: 25 7650' Note:Refer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sgz DATE 7693' —TOP OF SAND(8/07/06) 2-1/7 6 7650-7670 0 03/09/01 2-1/2' 6 7665-7685 0 08/07/06 2-1/7 6 7682-7702 C 05/12/02 1 2-1/2' 6 7712-7722 C 05/12/02 T 7'FLOAT COLLAR-PB1D H 8017' v1v1Y1v1v1v1W11 111111111111111111111 1111111111111111111111 1111111111 r CSG,26#,L-80-BTC,MOD,D=6.276-H 8103' X11111111111 r FLOAT SHOE — 8103' DATE REV BY COMNE fTS DATE FEV BY COMIENTS AURORA INT 11110/00 ORIGINAL COMPLETION WELL: S-105 12/17/06 JCV/PJC GLV C/O(12/12/06) FERNT No:1'2001520 05/31/09 PJC/TLH ONE FISH RHNOVED 11/27/06 : AFS No: 50-029-22977-00 11/25/15 RCT/A11) SET PX FFUG(11/19/15) SEC 35,T12N,R12, 12/10/15 DIXJMD TREE CYO(12/03/15) - 01/27/16 I GTW/JMD PULLED PX RUG(01/10/16) BP Exploration(Alaska) ` • THE STATE Alaska Oil and Gas �_�►.��� ofLAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O`F'fA SSP Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov April 28, 2016 d00— 150. Ms. Mary Cocklan-Vendl Pipeline Compliance& Conformance Mgr BP Exploration(Alaska) Inc. 900 E. Benson Boulevand Anchorage, AK 99508 Re: Docket Number: OTH-16-006 Unapproved Delay for Testing SVS %MO MAI 0 2 2-01 PBU S-105 (PTD 2001520) Dear Ms. Cocklan-Vendel: The Alaska Oil and Gas Conservation Commission(AOGCC)reviewed BP Exploration(Alaska) Inc. (BPXA)'s April 19, 2016 explanation regarding the failure to properly test the well safety valve system on Prudhoe Bay Unit S-105. The corrective actions initiated by BPXA address the procedural concerns identified in the violation as discussed during your March 10, 2016 meeting with AOGCC staff and as further detailed in the April 19, 2016 letter. The AOGCC does not intend to pursue any further enforcement action regarding the Prudhoe Bay Unit S-105 safety valve system testing violation. Sincerely, aht;Cathy Foerster Chair cc: AOGCC Inspectors (via email) 0-r4 -1(10.0o 6 • byRECEIVE® APR 2 1 2016 AOGCCBP Exploration(Alaska) Inc. (� 900 E. Benson Boulevard Mary E. Cocklan-Vend) Anchorage,Alaska 99508 Pipeline Compliance&Conformance Manager Tel: (907)564-4766 Fax: (907)564-5706 Email: mary.cocklanvendl@bp.com April 19, 2016 James Regg Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Notice of Violation—Unapproved Delay for Testing SVS PBU S-105 (PTD 2001520) Dear Mr. Regg: On March 1, 2016, AOGCC issued a Notice of Violation (NOV)to BPXA for an unapproved delay for Testing SVS PBU S-105. Specifically, the well was returned to production on January 14, 2016 after replacing a tree, steady flowing conditions were estimated to occur on January 15, 2016. AOGCC requires a Miscellaneous Test no greater than 5 days after stabilized flow after replacing a tree. Performance tests of S-105 well SVS were witnessed by an AOGCC Inspector on February 1, 2016 (17 days after stabilized flow)resulting in a failed low pressure sensor. The well was shut in pending repairs. Per 20 AAC 25.300, AOGCC requested BPXA provide an overview of its tracking system used to ensure regulatory obligations are met. The response was to include the specific corrective actions taken to prevent recurrence of missed well SVS tests in BPXA-operated fields. AOGCC also requested BPXA discuss the improvements to its compliance tracking capabilities that have been implemented to address missed regulatory obligations. BPXA met with AOGCC on March 10, 2016 to provide an overview of our tracking system and the following corrective actions to prevent recurrence of missed well SVS tests in BPXA-operated fields: • Valve Shop to install tag on Wing Valve after Tree or SSV Actuator is replaced. o CH2M Oil, Gas &Chemicals Work Instruction for Surface Safety Valve Replacement revised to include instruction to"Install tag on wing valve stating Alaska Oil and Gas Conservation Commission (AOGCC) test required within five days of Put On Production (POP) due to component changeout". • Field checked list of wells requiring a State Test due to SVS component change out and updated Compliance Advisor Tracker accordingly. • Update SVS Tool in Operator Tools to generate a Miscellaneous Test due to "Component Change Out" field that would trigger the need for a Miscellaneous AOGCC Test and populate AMR report to show up on SVS Tool. • Drill Site/Well Pad Operators to utilize TIO Status button to view or create a Miscellaneous AOGCC test with a direct link to the SVS Tool. • • • BPXA AOGCC State Test Production Wells Procedure to be revised to include detailed information on what activities trigger a Performance Test and a Function Test and what the requirements are for Routine Performance Testing, Miscellaneous Performance Testing, and Miscellaneous Function Testing. The Procedure will also require that anytime a LPP, SSV, or SSSV component is installed, repaired or replaced, a tag will be attached to the wing valve to alert that a performance test is due when the well is returned to operation. • Well Compliance Advisor to review AOGCC and WIOP requirements and tracking with Field Operations Team Leads. • 180 day clock between performance tests is being adjusted in SVS Tool to count from the date of last"Pass" Routine Test and not the last"Pass" Miscellaneous test. Please let me know if you have any questions. Sincerely, 74.7yZ, gLepee.ie Mary E. Cocklan-Vendl Pipeline Compliance & Conformance Manager BP Exploration (Alaska) Inc. Electronic cc: Glen Pomeroy, BPXA Storm Herring, BPXA Lee Hulme, BPXA Vince Pokryfki, BPXA AOGCC NOV— Unapproved Delay for Testing SVS PBU S-105 (PTD 2001520) 4/19/2016 Page 2 • S • Regg, James B (DOA) From: Cocklan-vend/, Mary E <mary.cocklan-vendl@bp.com> Sent: Tuesday, April 19, 2016 4:48 PM � 411fiIi 0 To: Regg, James B (DOA) Cc: Pomeroy, Glen; Herring, Storm;AK, OPS FF Well Ops Comp Rep Subject: BPXA Response to AOGCC NOV 0 Unapproved Delay for Testing SVS PBU S-105 (PTD 2001520) Attachments: BPXA Response - AOGCC NOV S-105.pdf Jim, Per our conversation and as a follow-up to our meeting on March 10, 2016, attached is a letter providing an overview of our tracking system and the following corrective actions to prevent recurrence of missed well SVS tests in BPXA- operated fields. I will be on vacation starting tomorrow, returning to the office on May 4th. If you have any questions on the information attached, please contact Vince/Lee at 907-659-5332 or Glen Pomeroy at 907-564-5921. Thanks, Mary Mary E Cocklan-Vend/ Pipeline Compliance & Conformance Manager Office Phone: 907-564-4766 COI Phone: 907-227-3464 Slope Phone: 907-670-7550 e-mail: Mary.Cocklan-Vend!(d7bp.com 1 • • RECORD OF MEETING Date: March 10, 2016 (6-1( Subject: Notice of Violation Unapproved Delay for Testing SVS PBU S-105 (PTD 2001520) AOGCC Docket OTH 16-006 I met with BPXA representatives Mary Cocklan-Vendl and Vince Pokryfki regarding the failure to test the well safety valve system (SVS) on PBU S-105 within the required timeframe after returning the well to production. This plus several recently-missed SVS obligations (missed tests; failure to obtain approval for installation of an alternate subsurface safety valve) let to issuance of a notice of violation dated March 1, 2016 requiring BPXA to provide the following within 14 days of receipt of the notice of violation: - Overview of BPXA's tracking system used to ensure regulatory obligations are met; - Discussion improvements made to BPXA's compliance tracking capabilities that have been implemented to address missed regulatory obligations. This meeting was held at BPXA's request to address the obligations of the notice of violation. Tracking System- - Lists are maintained by facility operators that include "wells to watch". Data records are manually entered into a spreadsheet and updated as needed. Examples of wells include SVS component changes that trigger a new test. Replacement of the entire production tree is another example. - BPXA acknowledged the limitations of this current tracking system—including inconsistencies between different facility lists and reliance only on people to update the "wells to watch" list. The longer a well remains on the list, the more likely it is to miss a required test. - The BPXA representatives stated work as commenced with the facilities and also with their IT group to develop a more reliable automated tracking system (generate a test notice based on a well's start of production; links to existing well-related databases; emails; alerts for test approach and those that exceed the required test due date). Procedural Changes- - After changing a SVS component or the production (or injection) tree, a tag is hung on the affected SVS component with"test required"; this is a change that has been made in procedures and communicated to field staff. - BPXA is performing periodic audits to ensure wells are tagged after SVS component changes - Added to SVS Testing Procedure actions triggering different types of SVS tests I requested BPXA provide a written summary as required by the notice of violation. The information is required to close out the enforcement action. v®F •7' • (9.&��\I1/ THE STATE Alaska Oil and Gas te, n Conservation Commission t2 = CP' 333 West Seventh Avenue ^.,P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 15LA6� Fax 907.276.7542 www.aogcc.alaska.gov March 1, 2016 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7104 Ms. Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Subject: Docket Number: OTH-16-006 Notice of Violation Unapproved Delay for Testing SVS PBU S-105 (PTD 2001520) Dear Ms. Cocklan-Vendl: On February 2, 2016 BP Exploration (Alaska) Inc (BPXA) reported it had surpassed the time limit for completing the required well safety valve system performance test on Prudhoe Bay Unit S-105.1 According to BPXA the well was returned to production on January 14, 2016 after replacing the production tree, and steady flowing conditions were estimated to occur on January 15, 2016. Performance tests of the Prudhoe Bay Unit S-105 well safety valve system were witnessed by an Alaska Oil and Gas Conservation Commission(AOGCC) Inspector on February 1, 2016 resulting in a failed low pressure sensor. The well was shut in pending repairs. AOGCC records indicate there were no safety valve system performance tests between the occurrence of stabilized production from Prudhoe Bay S-105 and the AOGCC-witnessed test. Details reported to AOGCC indicate BPXA failed to properly test the well safety valve system, which would be a violation of State regulations. The recent occurrence of several missed regulatory obligations has raised AOGCC concerns about the adequacy of BPXA's compliance tracking capabilities.2'3 Within 14 days of receipt of this letter, BPXA is requested to provide AOGCC with an overview of its tracking system used to ensure regulatory obligations are met. BPXA's response should include the specific corrective actions taken to prevent recurrence of missed well safety valve system tests in BPXA-operated ' February 2,2016 email"S-105 Miscellaneous Test greater than 5 days of stabilized flow test" 2 January 20,2016 email "13-03 SVS Deferral Request";missing approval for subsurface controlled subsurface safety valve 3 January 21,2016 email`BPXA clarification request for Wells with K-Valve or PB valves Installed...Guidance Bulletin 10-004" • • Docket Number: OTH-16-006 March 1,2016 Page 2 of 2 fields. AOGCC also requests BPXA discuss the improvements to its compliance tracking capabilities that have been implemented to address missed regulatory obligations. This information request is made pursuant to 20 AAC 25.300. Failure to comply with this request is itself a violation subject to enforcement in accordance with 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Cathy Foerster Chair RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. . U.S. Postal ServicetM 9 CERTIFIED MAIL° RECEIPT .1" Domestic Mail Only L7 rq For delivery information,visit our website at www.usps.com". f- f., to t< coCertified Mail Fee '".. $ 1-1 Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ CI ❑Return Receipt(electronic) $ Postmark O ❑Certified Mail Restricted Delivery $ Here 0 ❑Adult Signature Required $ ❑Adult Signature Restricted Delivery$ 0 Postage ...0 $ .11 Total Postage an r-q $ Ms. Mary Cocklan-Vend) Li) Sent To Pipeline Compliance and Conformance Mgr. `qoration Alaska O Street end Apt.Al, BP Exploration (Alaska), Inc. r` P.O. Box 196612 City,State,zIP+4 Anchorage,AK 99519-6612 _i PS Form 3800, • • SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION OM DELIVERY , • Complete items 1,2,and 3. A. Signature f / P'Agent • Print your name and address on the reverse X _/ / / ...„....4...,,,, / --❑Addressee so that we can return the card to you. B. Received by(Pri-%•lirfne)/ C. Date of Delivery • Attach this card to the back of the mailpiece, r 3^ or on the front if space permits. D. Is delivery address different from item 1? 0 Yes If YES,enter delivery address below: p No Ms. Mary Cocklan-Vend) P line impliance arid-eoWTRran MAR 0 BP Exploration (Alaska), Inc. — _ P.O. Box 196612 Anchorage,AK 99519-6612 III III III 3. Service Type 0 Priority Mail Express® 111111111 111111111111111111111111111100 Adult Signature 0 Registered Mail T" ,Adult Signature Restricted Delivery 0 Registered Mail Restricted fre Certified Mail® Delivery 9590 9403 0910 5223 5231 26 0 Certified Mail Restricted Delivery IiirReturn Re seipt for 0 Collect on Delivery 0MerchanSi nature Confirmation"'Collect on Delivery Restricted Delivery9 2. .articia Number(Transfer from service label) red Mail 0 Signature Confirmation 7 015 1660 0000 1487 7104 red Mail Restricted Delivery Restricted Delivery r$500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • Prb 7-601S-249 Regg, James B (DOA) From: Cocklan-vendl, Mary E <mary.cocklan-vendl@bp.com> �Z'S� Sent: Tuesday, February 02, 2016 2:08 PMq To: Regg, James B (DOA) I 1 Cc: AK, OPS FF Well Ops Comp Rep; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead Subject: S-105 Miscellaneous Test greater than 5 days of stabilized flow test Jim, It was discovered on Sunday that S-105 was online following a tree replacement and had surpassed the AOGCC "5 days of stabilized flow to test" rule. Details around this well are as follows: • The SSV failed to hold DP 9/1/15 2e44c_t>.z6.50iL) (,) • SSV serviced and successfully retested 9/2/15 • Well last SI prior to tree replacement on 10/18 • Tree replacement completed on 12/4/15 >• Well was put on production 1/14/16, estimated steady flow on 1/15/16 • Overdue status found 1/31/16 • Notification by phone to GC2 FLT and SVST alert entry made 1/31/16 • Notification sent by GC2 FLT to AOGCC to test 1/31/16 • Well tested on 2/1/16 with AOGCC Inspector. Pilot failed and well was SI. Performance test will be redone once repair is complete. Please let me know if you need any additional information. Thanks, Mary Mary E Cocklan-Vend! Pipeline Compliance & Conformance Manager Office Phone: 907-564,4766 Ce!!Phone: 907-227-3464 Slope Phone: 907-670-7550 e-mail: Mary.Cocklan-Vendl(&,bp.com 2°444-z-21°C(w)(kG - a- l ‘s)kW 4 Ns - rine o- 04 - erZ7 .,;‘ c ke Aivec.Ea,,,uS ti ileeck not w_ 4es,4ed a+ qie _1‘tile L Tactic r� 1e rx-�a''Azy—49-s t- s�,, .i n S sG,�cec (x,�1—`! I e 1 \Ja Put 4 pe pmetAce_- l a1 - .. �t�►t o�i� S tA1e i s ry,A-vt r . Z Prole etc, ; of- l n j ecff r i Project Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~N0OO ,] ,,~ _o~_ We,, History Fi,e ,dentifier RESCAN DIGITAL DATA Color items: [] Diskettes, No. D GrayscaJe items: [] Other, No/Type [3 Poor Quality Originals: E] Other: NOTES' BY: BEVERLY ROBIN VINCENT SHERYL~WINDY OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYI..~WINDY sca'nning Preparation x30= BY: BEVERLY ROBIN VINCENT SHERY~W1NDY TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FLEE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~YES NO Stage2 IF NO IN STAGE 1~ PAGE(S) DISCREPA~,~ERE FOUND: YES NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA W'INDY DATE: General Notes or Comments about this file: /si Quality Checked 12/10/02Rev3N OTScannedwpd ~ • ~p BP Exploration (Alaska) Ina ~ ~ Attn: Well Iniegrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~ Subject: Corrosion Inhibitor Treatments of S-Pad a,~ ~"~~°~" ~ _ 1 ~-~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wel~s from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~,, n ~ w. F~~ ,~~ ~ ~~ ~ ~ 2.~~:; ;y~'aora'~T~: E~+ti~ w Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad \ ~ Date fi/25/2009 W ell Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top oft date Conosion inhibitor Corrosion inhibirod sealant date ft bbls ft na al S-01B 1952020 025 NA 025 NA 2.6 5/30I2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.85 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26I2009 S-O6 1827650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-08B 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/37/2009 S-10A 1971230 0.5 NA 0.5 NA 3.4 5/3t12009 S-11B 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 7.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 7840170 025 NA 025 NA 3 6J2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-t9 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 025 NA 1.3 5/19/2009 S-2i t900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.~5 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL1 7960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 1.25 NA 125 NA 11.9 5/27/2009 S38 i921270 025 NA 025 NA 10.2 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-a2 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA Y.7 5/28/2009 S-a4 1970070 025 NA 025 NA 7.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-~07 2001150 125 NA 1.25 NA 11.9 5/29/2009 5-702Lt 2031560 125 NA 125 NA 11.7 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 17.9 5/18l2009 5-164 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5•705 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 1625 NA 174.3 6/2/2009 5-707 2011130 2.25 NA 2.25 NA 28.9 5/18/2009 5-108 2011 WO 3.5 NA 3.5 NA 40 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5l30/2009 5-710 2071290 11.75 NA 11.75 NA 98.6 5/30/2009 S-11t 2050510 2 NA 2 NA 79.6 5/30/2009 5-712 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1 J5 NA 1.75 NA 22.1 5/18I2009 S-naA 2021980 125 NA 125 NA 102 5/30I2009 S-715 2Q22300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/'1009 577~ 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-7~8 2032000 5 NA 5 NA 76.5 5/28I2009 S-119 2041620 1 NA t NA 5.2 5/30I2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-12~ 2060410 4.5 NA 4.5 NA 53.6 5/28/'L009 S-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA t 1.9 5/26I2009 S-t25 2070830 225 NA 225 NA 20.a 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 1.25 NA 125 NA t4.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 7a.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 5t 5/29l2009 5-217 2070950 025 NA 025 NA 17 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 P.l. Suprv ~ ` Z Z~ f~ Safety Valve & Well Pressures Test Report Reviewed B~ l Comm Pad: PB~_s InspDt: 2/18/2008 Inspected by John Crisp Interval InspNo svsJCi•080221140934 Related Insp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Rich Vincent Reason 180-Day `~ _ Src: Inspector Well Data ~- -__ Pilots - - E SSV ; SSSV S{zutln Dt Well Type_ Well Pressures ~ Gas Lift Waiver i Comments -- - -1 ~ ~ ---~---~-- Well Permit Separ Set L/P Test Test 'Pest Date SI OiI,WAG,GINJ, Inner Outer Tubing Number Number PSl PSI Trip Code Code Code GAS,CYCLE, SI PSl PSI PSl Yes/No Yes/No - _- S-100 S-103 ~~ 5-105 5-106 ' S-108 S-109 S-113 S-I l5 S-117 S-l2l 5-122 S-125 S-17C S- l 8A S 213 ~ S _44 2000780 _ 2001680 ~ - --- 2001520 !! 153 - _ 153 I~ 153 125 ~ - 125 ' - 125 ,i 125 ~ 120 - -- ~ 1i01 p ~ -Y i - ._ P -- - P i -P --- - P - - ~ --- ~ -- ~- ~ - - ---- - -- - ~ - -- 1-OlL - -- ~ -- - 1-OIL - - - 1-OlL - -- --~- -- - ~ - -- ---~ - - --- - - I -- -- - - - --- -- - ~ _ - - - - - - - -- _.-- ----- 2010120 i - -- -- F-- 153 125 ~ 40 - i 30 ~ - P - - ---- - ---- --- --- l-OIL ---i - - ' _.- - -_-_ ---- --- r 2011000 2022450 -- -------- ------ 53 ~ 153 - - 125 125 ~ 25 l25 - P P - P ( P ------ ---- -OIL - --.._ 1-OIL i - - I L_ -- - !- -- i . _ r-. - -- ----- 2021430 153 125 ~ l25 P P 1O1L - - 1 - ~ i --- ~ -- _ 1 i ~ 20301020 201i041U ---- 153 ? __-~ l53 j ~ '-- i 125 ---- 125 - 139 - 125 T -- P _ _ P - - -- i P -- P ----- - -- - ~ - -_ - -- - ____ -- - 1 OIL - _ -- - t-0lL -' - -- - ~ ~ - ' ~ ~ - ---- _ - ~ I -- - - - - -- - _--I - -_ -- _- T --~ - - - ~ _- rt -- - - ' - --- 1 -- - 2050810 I ~ _ .2070830 2020070 ~ 153 r~ 153 153 125 T125~ 125 ! l10 l I S l10 P -P- P P -P- P --- - -- - - I }- 1-O[L _ 1-OIL- 1-OIL ~ ~ --.._~ -- - ~ - -- - I - --__- -- _- - - - - - 2021630 ~ 2042130 153 153 - +- 125 125 - -- 100 125 -- P P P P ---- - - -- 1-O1L 1 OIL - -~ - - - r-- - -, __ _- . -_j- 1970060.., y 53 ---- 25 ~ -- 100 1-~ P - ~- P -- -- I - i ------~ 1-OIL I I - T- --- ._ -~ ---~ rz~ - ___ _ ~ ----- ~--- B A --- - __ -- - -- -, - - -~ -- --- { -- - -- -~ _ _ _ _ -_ - -.. I -- --- - - - --_..- -- -.-1 comments Performance ~~~ s ~ P( ~ ~ ~ ~ Wells Components Failures Failure Rate ~ (~rrN~u~ ~v~~~~,- , .~ I ~~- ~re~s~~e . ~ - 16 ---- 32 -- - --1- - ---- 3.12%-- - ~~%~~~€~ MAR ~ 9 200 Monday, February 25, 2008 ! /I. . 1. Operations Perfonned: :" Abandon 0 Repair WelllE PluQ PerforationsD Stimulate 00 OtherD Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 00 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Pennit to Drill Number: Name: Development Œ] ExploratoryD 200-1520 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22977-00-00 7. KB Elevation (ft): 9. Well Name and Number: 65.08 5-105 8. Property Designation: 10. Field/Pool(s): ADL-028257 Prudhoe Bay Field I Aurora Pool 11. Present Well Condition Summary: Total Depth measured 8120 feet true vertical 7203.0 feet Plugs (measured) Effective Depth measured 7693 feet Junk (measured) Fish --- 2.75" X Key --- Depth = ?? (08/10/2006) true vertical 6816.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 107 20" 91.5# H-40 34 - 141 34.0 - 141.0 1490 470 SURFACE 2963 9-5/8" 40# L-80 33 - 2996 33.0 - 2833.0 5750 3090 PRODUCTION 8071 7" 26# L-80 32 - 8103 32.0 - 7188.0 7240 5410 Perforation depth: ~ ~ ,f."t.:t- C c ij" Measured depth: 7650-7670,7665-7685 :s~¡¡ "' True vertical depth: 6777-6795, 6791-6809 TubinQ (size, Qrade, and measured depth): 4-1/2" 12.6# L-80 @ 28 - 69. .' 3-1/2" 9.2# L-80 @ 'ê9 " - 7630 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 7594 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft OCT 042006 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 193 131 158 --- 261 Subsequent to operation: SI 0 0 --- --- 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ Oil I]] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr " ^ Title Petroleum Engineer Signature h~-- R ~t! ./ Phone 564-5174 Date 9/29/06 rJ . . CEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION r: T 0 4 2006 REPORT OF SUNDRY WELL OPERA TIOYtS Oil & Gas Cons. Commission Form 10-404 Revised 4/2004 U t"\ IV \ \ \¡ r\ L . . 5-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/10/2006 (gl to dmy) SET 1.5" DMY GL V IN ST A # 1 @ 7442' SLM. PULL 3.5 X-LINE CATCHER FROM 7539' SLM. ONE KEY MISSING. DRIFT OUT TUBING TAIL WIBL BRUSH & 2.50" GAUGE RING FOR MISSING 2.75" KEY. *** RIG DOWN COMPLETE, WELL S/I ON DEPARTURE *** NOTE: ONE 2.75" X KEY LEFT IN HOLE. 08/09/2006 (gl to dmy) PULLED OGLV & RK FROM STA #1 @ 7448' SLM. SET DMY GLV & RA IN STA #3 (4101' SLM), STA #2 (6603' SLM), & STA #1 (7448' SLM). UNABLE TO LATCH CATCHER. RAN BELL GDE & 1 5/8" JD TO PICK UP PROBABLE DROPPED VALVE. IN PROGRESS. 08/08/2006 ***WELL S/I ON ARRIVAL*** (gl to dmy) SET 2.75 X LOCK CATCHER @ 7534' SLM. PULL 1 1/2" LGLV & RK FROM STA #2 @ 6602' SLM & STA #3 @ 4102' SLM. 08/07/2006 CTU #5. Log for Depth Control I Perforate. RIH with 2.18" Weatherford MHA and PDS memory logging tools. Log from 7715' to 7400' at 40fpm. POOH. Good data, call TCP hand for perforating gun. Corrected tag at 7693' (-24' correction). RIH with gun #1, 2.5" x 20' PF HMX 6 SPF. Perforate from 7665' - 7685' corrected depth. Freeze protect to 2500' with 50:50 methanol while pulling out of hole. RD. Road unit to shop for standby. ***Job Complete *** 08/06/2006 CTU #5...Continue circulating well..Pump .7bbI15.8ppg cement into reel. Launch 7/8" ball behind cement. No confirmation of ball rolling. Recover ball in standing iron. Abort cement job after 15bbl cement. POOH. Contaminate cement at surface and pump to return tanks. Inspect "Pigs Ear" nozzle. RIH and tag bottom at 7696' corrected. Meter 0.6 bbls of 15.8 ppg cement into reel. Launch 7/8" ball behind the cement. Ball landed on seat at 33.1 bbls displaced with CT 5' off bottom. PUH at 1 fpm to 7670'. Sheared out nozzle. Allowed fluids to stabilize, then POOH pumping CT displacment to maintain static pressure at 410 psi. Perform weekly BOP test while waiting on cement. 08/05/2006 CTU #5 Continue RIH with 2.25" DJN..Tag 7723'. POOH. M/U BHA #2: Weatherford 2.188" MHA w/PDS memory CCUGamma tool. Tag 7713'. Log up hole to 7400'. POOH. PDS data was good and correlated to Jewelry Log (9-Mar-2001). Corrected tag depth (-24') at 7691.0'. RIH with BHA #3: 2.5" BON for Reverse Clean Out. Tagged bottom and corrected depth to flag, washed down to hard bottom at 7702' corrected depth. Loaded well with 2% filtered KCI and reverse circulated to 7702' corrected depth. Heavy sand returns were seen at surface with bottoms up. Pump 20 bbl Biozan pill to sweep CT. MU "Pigs Ear" nozzle and RIH. Correct depth at flag (-24'). Circulate 105 bbls of 2% KCI. 08/05/2006 Assist CTU #5 - Hot Oil Treatment - Pumped 223 (433 total) bbls 140* diesel down coil tubing to remove Asphaltene from tubing. FWP's = 300/1450/200 08104/2006 CTU #5. Hot Diesel Tubing Wash. MIRU CTU and LRS. RIH w/2.25" DJN jetting hot diesel to flowline. 08/04/2006 T/I/O=300/1950/180 Assist CTU 5 [ Hot Oil Treatment] Pumped 210 bbls diesel heated to 140* down Coil Tubing to remove Asphaltenes in Tubing. Page 1 . . 5-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/01/2006 T/I/O= 700/1930/320 Assist slickline wI Brush & Flush (Pre-Frac) Spear in WI 3 bbls neat, well pressured to 2500 psi, bleed WHP down FL, pressure up to 3000 W/2 bbls Diesel, TP holding steady Final WHP's=320/1920/120 08/01/2006 (pre frac) RAN 2.79 GAUGE RING, UNABLE TO GET PAST 600'SLM. TOOLS COVERED W/HARD PARAFFIN. LRS PUMPED 2 BBLS DIESEL AND TUBING LOCKED UP. PAD OPERATOR ATTEMTED TO FLOW WELL ,NO LUCK. RDMO . *** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER.*** 07/31/2006 ***WELL FLOWING ON ARRIVAL*** (pre frac) RIH WI 3.5 X CATCHER SUB, RAN INTO PARAFFIN @ 579' SLM, POOH. 07/10/2006 TestEvent --- BOPD: 207 BWPD: 162 MCFPD: 2,660 AL Rate: 2,590 FLUIDS PUMPED BBLS 3 Diesel --- PT Surface Equipment 3 Methanol 60 50/50 Methanol Water 654 Diesel 622 2% KCL Water 27 1.5# Biozan 1.2 15.8 PPG Class "G" Cement 1370.2 TOTAL Page 2 TREE = 4-1/16"-5M CIW Stainless WELLHEAD = 11" - 5mfmc Ultra SH Gen 5 ACTUA TOR = LEO . KB. ELEV = 65' BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 1500' 37° @ 4438' 7637' 6700' SS 14-1/2" TBG, 12.6#, L-80, .01522 bpf, ID:= 3.958" I TOP OF 3_1/2" TBG, ID = 2.992" H 19-5/8" CSG, 40#, L-80-M-BTC, ID = 8.835'1 Minimum ID = 2.75" @ 2106' HES X Nipple 3-1/2" TBG, 9.2#, L-80-EVE, 8RD, --i 7630' .0087 bpf, 10 = 2.992" ÆRFORA TION SUMMARY REF LOG: SÆRRY DGR MIND ON 10/25/00 A NGLE AT TOP ÆRF: 25 @ 7650' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 7650 - 7670 0 03/09/01 2-1/2" 6 7665 - 7685 0 08/07/06 2-1/2" 6 7682 - 7702 C 05/12/02 2-1/2" 6 7712 - 7722 C 05/12/02 17" FLOAT COLLA R - PBTD I 801 T 17" CSG, 26#, L-80-BTC, MOD. 10 = 6.276"1-1 8103' 17" FLOAT SHOE H 8103' DATE 11/10/00 03/17/01 05/12/02 04/09/03 1 0/22/05 02/20/06 REV BY COMMENTS ORIGINAL COMPLETION CHlTP ADD ÆRFS CJS/KK SANOBACK ORSITP TVD/MD CORRECTIONS RCc/PJC A CTUA TOR CORRECTION LWB/TLH GLV CORRECTION (2001 C/O) SAFETY NOTES: 8-105 69' -14-112" X 3-1/2" XO, ID = 2.992" I --J TAM PORT COLLAR -13-1/2" HES X NIP, 10 = 2.750" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH 3 4129 3775 32 CAM-MMM DMY RK 2 6631 5877 29 CAM-MMM DMY RK 1 7475 6620 27 CAM-MMM DMY RK PORT DATE o 08/10/06 o 08/10/06 o 08/10/06 7568' -13-1/2"HESXNIP, 10-2.750" I 7594' 7" x 4-1/2" BAKER S-3 PKR WrrH XO PUPS to 3-1/2",10 = 3.875" 7619' - 3-1/2" HES X NIP, 10 = 2.750" I 7631' -i 3-1/2" WLEG, 10 = 2.992" I 7620' H ELMO IT NOT A V AILABLE I ?? -i FISH-2.75" X KEY (08/10/06) I 7693' -i TOP OF SAND (8/07/06) OA TE REV BY COMMENTS 08/07/06 GUNPJV CEMENT & ÆRFORA TE 08/10/06 RCT/PJC GL V C/O & FISH AURORA UNrr WELL: S-105 ÆRMrr No: ~2001520 API No: 50-029-22977-00 SEC 35, T12N, R12, BP Exploration (Alaska) . . RECEIVED WELL LOG TRANSMITTAL AUG 2 9 2006 4laska Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection[Caliper / MTT] 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 : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1] EDE Disk 2] EDE Disk 3] 4] 5] 6] 7J Signed : Print Name: S - 1 05 05-Aug-06 07-Aug-06 Coil Flag #2 Coil Flag #1 S - 1 05 dOO - 15d =t /i../ 07 d 4- J4073 ~<;ANNED AUG 3 0 2006 Œ,-lL--- Q~_r~{1{A-e - OJf\lA~€e(.t Date: 9/r!A/00 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM C:lDocuments and SettingslPDS AnchOI1lge - MPLlDesktopITransmit_Original.doc F: \LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~......, ~ ._~ . . -~ Permit to Drill 200t520 MD 8120 TVD DATA SUBMITTAL COMPLIANCE REPORT 4~9~2003 Well Name/No. PRUDHOE BAY UN AURO S-J05 Operator BP EXPLORATION (ALASKA) 7203 Completion Dat 3/9/2001 Completion Statu l-OIL Current Status l-OIL APl No. 50-029-22977-00-00 UIC N REQUIRED INFORMATION Mud Log N_.qo Sample N._gq Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media D Digital Fmt D Log Log Run Name Scale Media No Interval Start Stop 9830 LIS Verification LDWG LIS Usfing LDWG LIS Listing MWD/IIFR Survey MWD/IIFR Survey MWD Survey Report MWD Survey Report ~R~ees/GR MD 2/5 cJ;;~-~/GR TVD 2/5 t. Nea/Den MD 2/5 C~a/Den 'I'VD 2/5 c CMT Bond Log GR 5 ollar MT Bond Log GR 5 Collar ..,.~i'oduction Profile ~ ~ ~ ! 10185 7600 7760 216 8089 FINAL FINAL 216 8089 216 8089 FINAL 0 8120 FINAL 0 8120 FINAL 0 8120 FINAL 0 8120 FINAL_ 7400 7942 FINALj 7400 7942 FINAL 7600 7800 FINAL 7600 7760 FINAL 7600 7760 (data taken from Logs Portion of Master Well Data Maint OH I CH Received Case 7113/2001 Case 2/22/2001 2/22/2001 2/22/2001 1/9/2001 11912001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 ~ ~hL- 1/9/2001 ~ 1~ !'( 1/9/2001 ~d=,~ ,,t k 1/9/200t eH- 0 */~- 1/9/2001 eh~ t~- 4/6/2001 -~r ~. ! & 4/6/2001 4~h.~. t'~ 5/15/2001 CH 7/13/2001 CH 7/13/2001 Dataset Nu~. er, ,~,~Comments -~dlSS~600-7760 09830 216-8089 9830 LIS Verification Digital Data LIS Verification Paper Copy 216-8089 Digital Data 216-8089 Paper Report Surface to TD Digital Data Surface to TD Paper Report Surface to TD Digital Data Surface to TD Paper Report 0-8120 BL, Sepia 0-8120 BL, Sepia 0-8120 BL, Sepia 0-8120 BL, Sepia .~,~400-7942 Color Print 7400-7942 Color Print 7600-7800 BL, Sepia 7600-7760 BL, Sepia ~14~854'~600-7760, Digital Data Well Cores/Samples Information: Permit to Drill 200t 520 MD 8120 Name TVD 7203 DATA SUBMITTAL COMPLIANCE REPORT 4~9~2003 Well Name/No. PRUDHOE BAY UN AURO S-105 Operator BP EXPLORATION (ALASKA) INC Completion Dar 3/9/2001 Completion Statu 1-OIL Current Status 1-OIL Interval Dataset Start Stop Sent Received Number Comments APl No. 50-029-22977-00-00 UIC N ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Analysis R ~.c~.iv~.d ? Daily History Received? {~/N Formation Tops ~ N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WELLBORE PLUG BACK Pull tubing _ Alter casing _ Repair well _ Other_X PLUG BACK WELL 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development wX Exploratoryw Stratigraphic._ Servicew 4. Location of well at surface 648' FNL, 4493' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2788' FNL, 4344' FEL, Sec. 26, T12N, R12E, UM At effective depth 2757' FNL, 4340' FEL, Sec. 26, T12N, R12E, UM At total depth 2583' FNL, 4320' FEL, Sec. 26, T12N, R12E, UM (asp's 618931, 5980835) (asp°s 619027, 5983977)~ (asp's 619030, 5984008) (asp's 619047, 5984181) 12. Present well condition summary Total depth: measured true vertical 8120 feet Plugs (measured) 7203 feet Effective depth: measured true vertical 7705 feet Junk (measured) 6827 feet Casing Length Conductor '107' Surface 2962' Production 8069' 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-105 9. Permit number / approval number 200-152 / 302-160 10. APl number 50-029-22977-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool Tagged PBTD @ 7705' (05/18/2002) Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS 141' 141' 9-5/8" 405 sx AS Lite III, 240 sx 2996' 2833' Class 'G' 7" 497 sx Class 'G' 8103' 7188' Perforation depth: measured Open Perfs 7650'-7670', 7682'-7702', Open Perfs Below Sd Plug 7712'-7722' true vertical Open Perfs 6777'-6795', 6806'-6824', Open Perle Below Sd Plug 6833'-6842' Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 TaG @ 7594' MD. 3-1/2" 9.2# L-80 Tubing Tail @?~.~)'i!., J;;' ;, Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 7594' MD. 3-1/2" HES 'X' Nipple @ 2106' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 05/10/2002 Subsequent to operation 05/30/2002 OiI-Bbl 443 Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl 786 881 524 1003 72 Casing Pressure Tubing Pressure 317 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~~~~___v~.~.~ Title: Technical Assistant DeWayne R. Schnorr ' "'qnqs BFL Form 10-404 Rev 06/15/88 · Date. February 19, 2003 Prepared by DeWayne R, Schnorr 564-5174 SUBMIT IN DUPLICATE S-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/11/2002 05/12/2002 05/13/2002 05/18/2OO2 09/26/2OO2 02/03/2003 02/14/2003 SAND PLUG: DRIFT/TAG SAND PLUG: SAND PLUG SAND PLUG: SAND PLUG SAND PLUG: DRIFT/TAG ANNCOM --- T/I/O = 1980/2000/20. TBG, IA & CA FL's. (WELL TO BE POPed). TBG FL@ 7150'. IA FL @ 7220'. CA FL @ 36'. TESTEVENT --- BOPD: 382, BWPD: 66, MCFPD: 392, AL Rate: 0 HOT OIL TBG WASH: HOT OIL TREATMENT EVENT SUMMARY 05/11/02 DRIFT AND TAG W/2.25" DRIFT, TEL, SB TO 7904' CORRECTED DEPTH , SMALL SAMPLE OF SAND, HARD BOTTOM *** LEAVE WELL SHUT IN FOR COIL SAND / CEMENT PLUG *** RDMO 05/1 2/02 MIRU. KILL WELL WITH 2% KCL TOPPED WITH CRUDE. TAGGED TD, CORRECTION -2 FT. LAID IN 2500# 20/40 RIVER SAND PLUG (FIRST'BATCH). GOT 1 FOR I RETURNS. WAIT FOR SAND TO FALL. TAGGED SAND TOP @ 7724'. TAGGED A SECOND TIME AT SAME DEPTH. POOH. 05/13/02 MU 2.625" PIG'S EAR SHEAR NOZZLE. RIH. PUMPED 1.3 BBLS CLASS 'G' 15.8 PPG CEMENT. DID NOT SEE BALL SEAT ON SHEAR NOZZLE. POOH. BALL IN SHEARED NOZZLE AT SURFACE. ESTIMATE CEMENT TOP @ 7690'. FP WITH 23 BBLS CRUDE. <<< LEFT WELL SI & FP FOR SLICKLINE TO TAG CEMENT TIP IN 24 HOURS >>> 05/18/02 DRIFT AND TAG TO CEMENT TOP. CORRECTED DEPTH OF 7705'. <<< NOTIFY PAD OPERATOR, LEAVE WELL SHUT IN >>>. 09/26/02 ANNCOM --- T/:[/O = 1980/2000/20. TBG, ]:A & CA FL's. (WELL TO BE POPed3. TBG FL@ 7150'. ]:A FL @ 7220'. CA FL @ 36'. 02/03/03 TESTEVENT --- BOPD: 382, BWPD: 66, MCFPD: 392, AL Rate: 0 02/14/03 PUMP DOWN IA; 5 BBLS NEAT METHANOL, 100 BBLS CRUDE PUMPED @ 1800 DEGREES. LIFTED WELL ON PRODUCTION WHILE PUMPING. Fluids Pumped BBLS 62 CRUDE 59 2% KCL WATER 132 2% SLICK KCL WATER 12 CLEAN GEL 25 SAND SLURRY 1.3 CLASS 'G' 15.8 PPG CEMENT 291.3 TOTAL Page I I,. STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: WELLBORE PLUG BACK Abandon_ Suspend_ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ Re-enter suspended well _ PLUG BACK WELLBORE Time extension _ Stimulate_ Variance _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Sewice_ 4. Location of well at surface 648' FNL, 4493' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2788' FNL, 4344' FEL, SEC 26, T12N, R12E, UM At effective depth 2665' FNL, 4330' FEL, Sec. 26, T12N, R12E, UM At total depth 2583' FNL, 4320' FEL, Sec 26 T12N, R12E, UM (asp's 618931,5980835) (asp's 619027, 5983977) (asp's 619039, 5984100) (asp's 619047, 5984181) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 107' Surface 2962' Production 8069' 8120 feet Plugs (measured) 7203 feet 6. Datum elevation (DF or KB feet) RKB 65.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-105 9. Permit number / approval number 200-152 10. APl number 50-029-22977-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool Tagged PBTD @ 7921' (02/10/2002). 7943 feet Junk (measured) 7042 feet Size Cemented Measured Depth True vertical Depth 20" 260 sx AS 141' 141' 9-5/8" 405 sx AS Lite III, 240 sx 2996' 2833' Class 'G' 7" 497 sx Class 'G' 8103' 7188' Perforation depth: Tubing (size, grade, and measured depth RECE[VED measured Open Perf 7650'-7670', 7682't 7702', 7712't 7722' ,.,, ~v -~ 0 2002 true vertical Open Porf 6777' - 6795', 6806' - 6824', 6833' - 6842' ~..a~ 0il & Gas Cons. {~0a~issi01~ ohorag 3-112" 9.2#, 1_-80 IBG @ 7594'. 3-1/2" 9.2#, 1_-80, Tubing Tail to 7630'. Packers & $SSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 7594' MD. 3-1/2" HES 'X' Nipple @ 2106'. 13. Attachments Description summary of proposal _X Detailed operations program i BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation May 13, 2002 16. If proposal was verbally approved Name of approver Date approved Oil I X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ "~~,~~ Title:AuroraSurveillanceEngineer Jim Young _ Approved by order of the Commission FOR COMMISSION USE ONLY Questions? Call Jim Young @ 564-5754. Date May 09, 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representajjve may witness ~lug integrity _ BOP Test _L~ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- ~'~'O~'~ Onglnal Signed By Commissioner Form 10-403 Rev 06/15/88 · I Appr°val Date 5//,4-.'~/~ "~ SUBMIT IN TRIPLICATE bp ( ir'" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 09, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom' Re: Sundry Notice for S-105 Sand Back for Water Shutoff. BP Exploration Alaska, Inc. proposes to sand-back the lower most peforations with CTU and dump/bail a cement cap for water-shutoff (WSO) in development well $-105. If the WSO is successful, the sand-back would be the first step to a re-fracture treatment which may further increase rates from this well. The original treatment was the first frac completed at Aurora and was designed conservatively relative to recent developments'made in fracturing. It is proposed to test the well after the sand-back before decisioning the re-fracture treatment. The procedure includes the following major steps: Step Description Drift to PBTD, correct to ELMD SI the lift gas prior to the operation and bleed down the IA as necessary to prevent gas commune.cation to the tubing during the job. RU CT.'Bullhead kill with 1.5 tubing volumes of filtered 2% KCI. Cap with dead crude as necessary to stop the well from taking fluid on a vacuum. RIH with (pigs ear) shear nozzle (2.6V2" OD, 7/8" ball) and tag PBTD for depth control. Sand back with 20/40 sand to 7715' +/- 10'. Cap with 1 bbl of cement to 7690' +/- 10' (Class G with 4 hour thickening time @ 170°F BHCT.). Use the foam pigs/shear nozzle procedure to insure precise measurement and placement: POOH, taking care not to underbalance the well. Freeze protect as necessary. RDMO. WOC 24 hours and tag the plug with slickline. If cement top >7712' or <7685' ELMD, contact APE, may need to dump-bail cement or re-perf prior to POP. POP Well w/5bbls MeOH and 2mmcfd gas lift and obtain a production test. Please call O'im Young 564-5754, hm: 248-0133, cell: 440-8007) if there ate any questions. Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer Scklumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1910 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 3/20/2002 Field: Borealis Aurora . , Well Job it Log Description Date ColOr ' Sepia BL CD L-104 <:~C)/""c~,,~ <~ 22110 SCMT 02/11/02 2 L-106 ,~r~/:) ]'" .C~ C::~ ,.~ 22111 SCMT 02/10/02 2 S-105 ~ O/.) -J.~ ~ PROD PROFILE/DEFTIGLS 02/28102 1 1 L-120 22086 PP IMP DATA 02/09/02 1 L-120 <:~ O<:~ '" OO (o 22086 MD VISION RESISTIVI'i'Y 02/09/02 1 1 L-120 22086 TVD VISION RESISTIVITY 02/09102 1 1 ,, , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED NAR 2 £ 2002 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 Al'tN: Sherrie STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X(FRAC) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 648' FNL, 4493' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2788' FNL, 4344' FEL, SEC 26, T12N, R12E, UM At effective depth At total depth 2583' FNL, 4320' FEL, SEC 26, T12N, R12E, UM 5. Type of Well: Development _X Exploratoryw Stratigraphicm Service__ (asp's 618931, 5980835) (asp's 619027, 598;3977) (asp's 619047, 5984181) 6. Datum elevation (DF or KB feet) RKB 65.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-105 9. Permit number / approval number 200-152 / (301-155 signed 6/15/2001) lO. APl number 50-029-22977 11. Field / Pool Prudhoe Bay Oil Pool / Aurora Pool (undefined) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 107' Surface 2931' Production 8038' 8120 feet Plugs (measured) 7203 feet 7943 feet Junk (measured) 7042 feet Tagged PBTD @ 7943' MD on 6/25/2001. Size Cemented Measured Depth True Vertical Depth 20" 260 Sx AS 107' 107'. 9-5/8" 405 Sx AS Lite III & 240 Sx Class 2996' 2833' G 7" 497 Sx C~ass G 8103' 7188' Perforation depth: measured 7650' - 7670'; 7682' - 7702'; 7712' - 7722'. true vertical 6777' - 6795'; 6806' - 6824'; 6833' - 6842'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.2#, L-80 Tbg @ 7630' MD. 7" X 3-1/2" Baker S-3 Packer @ 7594' MD. 3-1/2" X HES X Nipple @ 2106' MD. RECEIVED JUL 2 7 2001 Alaska 0ii & 13as Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation(4~1~2001) Subsequent to operation(6~29~2001) OiI-Bbl 151 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 275 600 1391 839 1170 Casing Pressure Tubing Pressure 190 258 289 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas ~ Suspended Service 17. I hereby certify~he foreg~g is true and correct to the best of my knowledge. Signed ( /~1~ t/~.~_ ' Title: Aurora Surveillance Engineer Jim Young , /.I --/~'t,,~'~/,~ ~ Form 10-404 Rev 06/15/88 · ORI61NAL Prepared by Paul Rauf ,.=,64-57~ SUBMIT IN DUPLICATE S-105 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT Date 6/12/2001' 6/1612001' 611812001 - 611912001: 612412001: 6/25/2001: Event Summary Performed SBHPS. Completed Static Survey. Ran Borax RST - no evidence of channeling. Dummied GLV's. MITIA to 3500 psi - passed. MIRU Dowell FRAC Unit. PT'd equip. Performed a FB Hydraulic Fracture Treatment using 20/40 mesh ceramic proppant through the target perforations listed below: 7650'- 7670' MD (Kuparuk C Sand) Reference Log: Sperry MWD EWR 10/25/2000. 7682'- 7702' MD (Kuparuk C Sand) 7712'- 7722' MD (Kuparuk C Sand) Pumped: (a) 133.5 bbls 20# Gelled Pre-Pad @ 30 bpm, followed by shutdown. ISIP = 1528 psi. (b) 53 bbls 40# Crosslinked Gelled Pad @ 20 bpm, followed by (c) 83 bbls 1 ppg Scour Stage @ 20 bpm, followed by (d) 134 bbls Flush w/20# Liner Gel @ 30 bpm, followed by (e) Shutdown. ISIP @ 1541 psi. Resumed pumping Datafrac Treatment: (f) 60 bbls 40# Crosslinked Gel @ 30 bpm, followed by (g) 74 bbls 20# Linear Gel Flush @ 30 bpm, followed by (h) Shutdown. ISIP = 1891 psi. Resumed pumping Fmc Treatment: (i) 80 bbls 40# Crosslinked Pad @ 30 bpm, followed by (j) 424 bbls Crosslinked Slurry @ 30 bpm w/proppant stages @ 1-10 ppg, followed by (k) 63 bbls Flush @ 30 bpm, followed by (I) Shutdown. ISIP = 1677 psi. Placed a total of 79537 lbs of proppant into FM. Max proppant concentration placed was 10 ppg. Average treatment press was 3800 psi. RD Dowell FRAC equip. MIRU CTU. PT'd BOPE. MIRU CTU. RIH w/CT & tagged TOS @ 7700'. FCO'd to 7929' CTM. POOH w/CT. FP'd well to 2100' w/Methanol Water. RD CTU. MIRU SLU. RIH & pulled dummied GLV's. Installed live GLV's. Tagged PBTD @ 7943' MD. POOH. RD SLU. Placed well BOL. Performed production test. page 1 Schlumberger Alaska Data and Consulting Services 3040 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. t282 Company: Alaska Oil &.Gas Cone Comm Attn: Liea Weeple 333. West 7th'Ave, Suite 100. . Anchorage, AK 99501 07111101 Field: Aurora' _Polaris Well Job # Log DeScription - Date Color . Sepia BL CD S-108,~..~/4~[~ 21315 CNIR - '0S11910t 2 S-106 ~O~1~, 21317 RST 06116/01 t - t 1 w-201 ZO/-- O~;! 21293 usrr oe~03~o~ 2 . . . . . . . . . . . _ . . - . . . . i' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE cOPY EACH TO:. " BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: .. RECEIVED Schlumberger DCS -- -3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 'JUL 1 3 2001' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ (Cmt Sqz I Frae) Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 648' FNL, 4493' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2788' FNL, 4344' FEL, SEC 26, T12N, R12E, UM At effective depth At total depth 2583' FNL, 4320' FEL, SEC 26, T12N, R12E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic _ Service__ ' (asp's 618931,5980835) (asp's 619027, 5983977) (asp's 619047, 5984181) 6. Datum elevation (DF or KB feet) RKB 65.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-105 9. Permit number / approval number 200-152 ~''' 10. APl number 50-029-22977 '~' 11. Field / Pool Prudhoe Bay Field/Aurora Pool (undefined) 12. Present well condition summary Total depth: measured ..... 8120 feet Plugs (measured) true vertical ,~7203 feet Effective depth: measured 7944 feet Junk (measured) true vertical 7043 feet Casing Length Size Cemented Conductor 107' 20" 260 Sx AS Surface 2931' 9-5/8" 405 Sx AS Lite III & 240 Sx Class G Production 8038' 7" 497 sx Class G Tagged PBTD @ 7944' MD on 4/22/2001. Measured Depth True vertical Depth 107' 107' 2996' 2833' 8103' 7188' Perforation depth: measured 7650' - 7670'; 7682' - 7702'; 7712' - 7722'. true vertical6777'-6795'; 6806'-6824'; 6833'-6842'. Tubing (size, grade, and measured depth 3-1/2", 9.2#, L-80 Tbg @ 7630' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" Baker S-3 Packer @ 7594' MD. 3-1/2" X HES X Nipple @ 2106' MD. RECE VE[) .;i',,i tis ?.Or1 Anchorage 13. Attachments Description summary of proposal ._X Detailed operations program _ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation 16. If proposal was verbally appr(~ved Name of approver Date approved Oil ~ X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedJimYoun~~' ~/~'~ ~{,,ul,~:,~ Title: Aurora Petroleum Engineer FOR COMMISSION USE ONLY Questions? Call Jim Young {} 564-5754. Conditions of approval: Notify Commission so representat!ve may witness ~'~ ~.~,.~ ~ ~,~st~O ~-> [, Plug integrity _ BOP Test ~ Location clearance M Mechanical Integrity Test _ Subsequent form required 10- ~fO~-~ Date June 8, 2001 Prepared by Paul Rauf 564-5799 I Appr°va' {,! Approved by order of the Commission 'aR~GINAL SIGNED BY D Taylor Seamount Commissioner Form 10-403 Rev 06/15/88 · ORIGINAL, SUBMIT IN TRIPLICATE bp June 8, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: RE: Sundry Notice for S-105 Squeeze / FRAC (permit #200-152). BP requests approval for a potential cement squeeze and fracture stimulation of Aurora well S- 105. Below are the proposed series of events which could begin as early as Sunday Junel0, 2001. 1) Drift/tag, HOT/Jet hydrates as necessary. SBHP survey. 2) RIH with GR, spinner, press/temp, RST in upflow mode to determine water entry point. 3) Cement squeeze or sandback to 7670' depending on log results. 4) Fracture stimulate through perforations 7650'-7670'. If you have any questions, please,contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or by email at Youngj3@bp.com. Sincerel~r, Jim Young ~ Aurora Petroleum Engineer Page 1 (' PRELIMINARY SQUEEZE WORK: 1. Design a Latex cement slurry and perform lab tests as per Attachment A. 2. Drift to PBTD. Dummy off generic design. MIT IA. ACID AND CEMENT SQUEEZE: . RU CT. Bullhead kill with non-slick filtered 2% KC1. RIH with combo cement nozzle. Pump at 1 BPM while RIH to maintain BHCT. Tag PBTD for depth control and flag the pipe 10' off bottom. 4. Observe SIWHP. The formation is over pressured, and the S1WHP with a full column of water is expected to be -360 psi. Do not allow the WHP to drop below 500 psi when taking returns. . With the nozzle reciprocating at the bottom perf, pump 20 bbls 7.5% HC1 (with standard additives) at maximum rate. Maximum recommended WHP is 2000 psi. Over flush the acid with 50 bbls of filtered 2% KC1 while reciprocating across the sump. Place a field mix sample of cement in UCA at 150°F. Cement QC should include fluid loss, slurry density, slurry temperature, slurry rheology, and filter cake thickness and quality. Compare to design parameters. Place 2 samples in a hot water bath, lw/100% cement and 1 w/ 50/50 mix of cement and biozan. 6. Pump the following while holding 500 psi WHP: · 10 bbls fresh water spacer · 25 bbls of latex cement (Attachement A) · 10 bbls fresh water spacer · displace with filtered seawater The cement should be pumped at a high enough rate to prevent free fall (-1.5 BPM). 7. RIH to the flag as cement reaches the nozzle. Lay in cement after 2 bbls of cement are out the nozzle. Do not build squeeze pressure until the nozzle is above the perfs. Keep the coil moving at all times while laying in cement. . Once the nozzle is above the top peri, close the chokes and squeeze until a 1000 psi bump in WHP is observed. Continue to reciprocate the CT above the top perf' until squeeze pressure is obtained. Don't lay in remaining cement until initial squeez, e pressure is obtained. If squeeze pressure does not build then pump all but 5 bbls behind pipe and attempt a hesitation squeeze. Page 2 9. Gauge returns and lay in the remaining cement to WCTOC, adjusted for the amount of cement that was placed behind pipe. The cement volume to reach initial squeeze pressure minus the calculated volume to cover the sump and perfs (12 bbls) minus -0.5 bbl/1000 psi (ballooning) is a good estimate of the amount of cement behind pipe. If the perfs take no cement then the WCTOC will be -6154'. Timing should be that the nozzle pulls from the cement when water reaches the nozzle. 10. Pull the CT to safety. Attempt to build 3000 psi dP squeeze pressure (at the perfs) in ramps of approximately 500 psi per 5 minutes (based on a reservoir pressure of 3400 psi @ 6750' TVD). Hold the final squeeze pressure for 45 minutes, then bleed slowly to 500 psi dP to commence the contamination and cleanout. (Don't' allow WHP to drop below 500 psi). If final squeeze pressure cannot be obtained after several hesitations, then over displace and pump another batch of cement. Monitor the IAP during the squeeze pressure ramps. CEMENT CLEANOUT: 11. Drop the ball for jetting. Hold 500 psi dP and pump ~ 100 bbls of 1.5 ppb biozan cement contaminant. With the ball on seat, contaminate the cement to the flag making multiple passes. If the squeeze breaks down during the contamination passes then continue to pump with 500 WHP. Gauge returns and if possible chase the returns OOH. 12. Spot 5 bbls of 10% TEA solution on the final pass up across the perfs. 13. Displace with slick water and chase OOH at maximum pump rate. Perform additional jet passes across the jewelry while POOH. Thoroughly wash the tree and BOP stack. Freeze protect as necessary. Trap 500 psi dP on the well and RDMO. PERFORATING: 14. Monitor cement compressive strength in UCA and WOC as directed. 15. RU slickline. Drift. 16. Perforate with 2.5" power jet, 6 SPF, 60° phasing reference Sperry DGR MWD (10/25/00) from 7650' - 7670'. 17. Proceed with frac program as directed.. .~.... Page 3 TREE= 4-1116"-5M ClW Stainless WB_LHEAD= 11" - 5m fmc Utra SH Gert 5 :ACTUATOR= BAKER KB. ELEV = 65' BF. ELEV = KOP = 1500' Max Angb = 37° @ 4436' Datum MD = 8119' Datum'rVD= 8800' SS 4-1/2" 'I~G, 12.6#, L-80, .01522 bpf, ID=3.958 ~ 69' Top of 3-11Z' TBG, ID=2.992" I r i 3'1' 9-5/8" CSG, 40#, 2996' L-80-M-BTC, D = 8.835" / / S-105 .. r--~SAFETY NOT ES 994' ~-~ 2106' ~-~ 4-112" X 3-1/2" XO, ID = 2.992" I TAM FORT COLLAR I 3-112 HES 'X' NIP, ID= 2.75" GAS LIFT M~.NDRB. S IMinimum ID = 2.75" @ 2106' I HES 'X' Nipple I 3-1/2"TBG, 9.2#,L-80-EVE,~-----~ 7630' t 8RD, .00870 Bpf, ID: 2.992 PERFORATION SUMVlARY REF LOG: SPERRY DGR MWD ON 10125/00 ANGLEATTOPPERF: 25 @ 7610 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/Z' 6 7650-7670 O 03/09/01 2-11Z' 6 7652-7702 O 03/09/01 2-1/Z' 6 7712-7722 O 03/09/01 I 7" FLOAT COLLAR- FBTD~-~ 8017' 17" CSG, 26#, L-80-BTC, MOD, ID = 6.276" ~ 8103' 17" FLOATSHOE ~ 8103' 7568' 7594' 7619' 7631' 3-112" HES 'X' NIP, ID=2.75" I 7" x/1/2" BAKER 'S-3' FKR WITH XO PUPS to 3-1/2", ID= 3.875" 3-112" HES 'X' NIP, ID = 2.75" 3-1/2" WLEG,ID = 2.992" TT ELM NOT LOGGED DA'[E REV BY COMf,~ENTS 11/10/00 ORIGINAL COMR. ErlON 11/15/00 SIS-SLT CONVERTED TO CANVAS 01/26/01 SIS-MD FNAL 03/17/01 CH/I'P ADD PEI:~S AURORA UNIT WB.L: S-105 PERMIT No: 200-152 APl No: 50-029-22977-00 Sec35,T12N, RI 2 BP Exploration (Alas ka) 5/10/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1130 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-103 ~ ~)b"l~' 21174 SCMT 03/23/01 2 S-103 2t2t0 RST 04/2610t 1 t 1 S-106 ~-,~bO'"' i.,.~ PRODUCTION PROFILE/DEFTIGLS 04123/0t 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED HAY 1 5 2001 Schlumberger DC$ 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A'I-I'N: Sherrie ALASK oiL AND GAS CONSERVATION COM WELL C.OMPLETION OR RECOMPLETION REPORT AND LOG ,. · 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-152 3. Address 8. APl NUmber P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22977-00 4. Location of well at surface · 9. Unit or Lease Name 4631' NSL, 4494"WEL, SEC. 35, T12N, R12E, uM''';!:''~,?;'--.i-'.-i-'','''' ~ Prudhoe Bay Unit At top of productive interval .I'. 2491' NS L, 4344' WEE, SEC. 26, T12N, R12E, U .M ,,~/...//,_~_~Z. .... ; At total depth ' ,~'~JFi[~ ' 10. Well Number 2695' NSL, 4320' WEL, SEC. 26, T12N, R12E, UM ..... ,Z~'~;;~ ...... i S-105 '~,-~.'.~-~'T'~.''~''~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease ues~gnafion and Serial No. Prudhoe Bay Field / Aurora Pool KBE = 65.08' ADL 028257 (Undefined) 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore .16. Nc. of Completions 10/25/2000 11/3/2000 -~ ~/~//~ / N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 8120 7203 FTI 8017 7109 FTI [] Yes [] NoI (Nipple) 2106' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN, PWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 107' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 2996' 12-1/4" 405 sx AS Lite 3~ 240 sx Class 'G' 7" 26# L-80 26' 8103' 8-3/4" 497 sx Class 'G' 24. Perforations pp. en to. Production (M.D+.TVD of Top and 25. TUBING RECORD Bottom and m;erva~, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 7631' 7593' MD TVD MD TVD 7650' - 7670' 6777' - 6795' 7682' - 7702' 6806' - 6824' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7712' - 7722' 6833' - 6842' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 80 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 20, 2001 Flowing Date of Test Hours Tested !PRODUCTION FOR OIL-aBE GAS-MCF WATER-aBE CHOKE SIZE ~ ~'~S~.OIL RATIO 4/26/2001 4 TEST PERIOD 23 40 498 176I 1747 Flow Tubing Casing Pressure CALCULATED OIL-aBE GAS-MCF WATER-aBE O~L GRAWTY-API (CORR) Press. 24-Hour RATE .,,28. CORE DATA Brief description of lithology, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska Oil & Gas Cons.L;",,,,', ...... ,..~,~.,,.~ ..... ,~- Form 10-407 Rev. 07-01-80 O RJ.G NAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Ugnu 3901' 3585' Schrader 5350' 4788' West Sak 5609' 5004' Kuparuk 7632' 6761' Miluveach 7960' 7057' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~'~. ~j~, ,~ Title TechnicalAssistant Date S-105 · 200-152 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 ANe 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. .............. ~- .... ~ ' '!"..'~:"""~':':'~"'".i'..~!' ITEM 28: If no cores taken, indicate 'none'. i""""'~ Form 10-407 Rev. 07-01-80 .... t ...... , ~... '~..w ~! ,' 'm,',~.~ ! ~V.,l~q~?l i~ ',,'~ ~ ' ,,,,,:, ',,' .... ':'" ,' ,, ' ,,: , '",, '":!, , ':,,,, ,,?, , ,'i""Ii,,";,,,,i,~', ;.:~:;'..~!..''~'.''=..''~'~:':'~'~'~!~:'.~''..i~.~'~!~.'''.~i!~`:;'~ ¥1,~';~hi,'ll,i:i=,l,':"=:'~:il,il"'l,;l',ili!i',,;i='i,,l',,i,'l,,,;i?i, h'iui!',',!;i'?!l!,,~',",i;,'l!:=",:,,','k~llr'l;i,i;i,?,,?':ii,l,i',,,: il;?=:,'i'~"=:=~l:ii!=i,,,' :'=i?:' , , ,;,'=',' '=' ~ '",',',,i,,',.' ' ','., 7 ' .", . c' ,~ '; ,,' ,,,,:," '='' '~: ~;; , ":,~==',~;, ',:=Ii ',' ': ": , ' ', , , ' , ,,,l , ,, ,,',I ,, ', , ' ,, ,,' ,, .', ',,,, , ..' ....... . ,,,i, ,i,, '!r,,','' i,,i ...... I . ,,,,!,1,,., ,, ii ,, ~e,,,,l, ' ,,, ii, ,,,,i,,l,, ,i,i,lhl,,,,,,l, .',l"'l,' '1,,,,h Ii",,i,,,,,h,l,,i,,, '1 ....... ' h",/, ,, ,,'.,,,hh ,,I1,,, ,,i,., i'i' '... '" / '"".: :" .... '..' ;'. :...:."' ' ."..' ,:. "..:::~. ~' .: :ii' '.'.i.....'.? ~ ,i" i:..: "::'::'''' Ii ::.,i;'il?..'~:: II ?iii,:L;i'.;:.;ll l..i.'"iL~,~."iil! .'..,::: Li:~.~i:,l'~i..;~:'~i"." ~.'::'!!.i~;.~';:"i"~:.;'.ii~.':";~,~ i'.';?i:...:.:~ ..'I.," i":"iii'~'::: .':~":;!'.'II.'.:i.: ~l!::'r~::~', :!: ?'.-' !!~,:?!.'!' '? .i,_.. ! ,~-~:~.~,~ :~,~,,~;.:;:.~.~.., .,~.~ ..... .,i:" :.." ":..?' ' ~.: ....... " . ""' . .... .".'~' ." .:' .... :' :' '. ....... : ..... ' ..... ':.. ' ............ ' .:".'. ......... '"':~'....'~ ......... ." ............. .' "..'"..':" ":'."'. .......... ~ ~.... '~,'~'~'~Ul~.'"' !!l~l~'~.~.,i~l'mm~'~..... ' ..... ...,. .... .., . ..... ......~.. ......... . .............. . .......... :.. ........... .... ::.. ,..~,,...~ .................... ....:,.:.,.... :.~ ............. . .......... , ,,.,. ........ ~,,,,,,, ,'~¢',~.i ' a~,~,,~:~...,,~,.. ..... "~"~' ,7 ':':~: ...... ,,,,,', ", I,, ',, ,,,,,, ,, ,: , ;,,, ,,,: ,;" ,,,,,, :',: ,;, ,,,,i,,',I' ,: :, ,,,, , :l'l'l,i,l,,,', ':,!, ,' 'i'",U .... 'h',';, ,,,,,"lh,l',,',, 'l:'l';['I, ,h I/','llh' ,l'li'l~'; ~ll ',,,~ltl,!,~;;'ll I1'!:,',,',~;:' i,;;H'l;,I,'ilI' 'll"lll1%'rl;~!"q:;, i,:i~,,ihl ,i "h';';lll,;I,i ~',;';ll:~':h!'" I',111;lq ,l'll;;,,'lllll~l~ll:'ll'lll'l,;;,,,l'l Il'l! :" '1 '"'Il! 1% h!l' :;',,',i,',,i'l" ,,,'''''Il'' ,';, '~" ,,I,, "'", ':,! "' ': ' ,,,, ;,, ,'i'l",",,~:, ~, ':' ' : , Legal Name: S-105 Common Name: S-105 ,,,, ' '~'~,~',",",lI' hll",l~:,r I' ;~, · ,', - ,; ,:, , , ..... ,, , ,I , ,: ..... , , ................. , ................................. ,,, ...... ,,,:,,, ..... . .... ,, : ........... ,,, ...... T ' t ~(' ,M '~ ,Su~ce::p'ressure Off Pressure (BHP) EMW ............. :,,,.,.,==.,=,.~=f;,.,,~.P,,=..~,.,..~,,,,,,,,..:.,~) .......... }':.:'=;..:i,.;;Te.~:,:.P~.P~ii.(~),;.:;::,.;:..,;i,=i ,.,:'i.~i'.;':,:::::!:;.':=;""':'":?'AMW'''' .:' '::':"i'. ...: Leak 10124/2000 FIT 109.0 (ft) 109.0 (fi) 8.30 (ppg) 12 (psi) 59 (psi) 10.42 (ppg) 10/29/2000 FIT (ft) (ft) (ppg) (psi) (psi) 8.30 (ppg) 10/30/2000 LOT 2,996.0 (ft) 2,845.0 (ft) 10.20 (ppg) 689 (psi) 2,196 (psi) 14.86 (ppg) Printed: 4123/2001 3:34:05 PM BP EXPLORATION Page 1' of 5 Operations Summa Report .. . . Legal Well Name: 8-105 Common Well Name: S-105 Spud Date: 10/25/2000 Event Name: DRILL+COMPLETE Start: 10/24/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es .... . Date · From To Hours' 'Task SUb Phase · ' Description of Operations · . ': ' :. - . . . Code. . .... . . ' ...... ... ' ''.. ...."' 10/24/2000 21:00 - 00:00 3.00 MOB PRE Move pits. 10/25/2000 00:00 - 07:00 7.00 RIGU PRE Spot sub base over S-105 conductor. Lay herculite, set and level rig. Spot pit module, camp & cuttings tank. HU power,water, steam and mud lines. ACCEPT RIG at 07:00 07:00 - 10:30 3.50 RIGU 'PRE Take on FVV and mix spud mud. Mu flow nipple and function test diverter. Test witnessedby L. Grimaldi. AOGCC. Load BHA in pipe shed. Strap and calliper BHA. PU and stand back 21 jts. 5" HWDP. 10:30 - 12:30 2.00 DRILL SURF PU BHA # 1. Fill hole wi water and check surface system. 12:30 - 13:00 0.50 DRILL SURF Cont. to mix Spud mud 13:00 - 14:30 1.50 DRILL SURF IM/U BHA# 1 14:30 - 15:00 0.50 DRILL SURF Hold pre spud safety meeting with all rig hands and Service company personnel. 15:00 - 15:30 0,50 DRILL SURF H 2s False alarm investigate & Repair 15:30 - 17:30 2.00 DRILL SURF Tag Btm at 107' Drill to 279" 17:30 - 18:00 0.50 DRILL SURF POH & Std back Flex DC's 18:00 - 21:00 3,00 DRILL SURF M/U BHA # 2 RIH to 223' 21:00 - 00:00 3.00 DRILL OTHR SURF Attempted to break Circ. - String plugged. POH Found Bit completely plugged with formation gravel. Un-plugged bit RIH 10/26/2000 00:00 - 00:30 0.50 DRILL OTHR SURF RIH to 222'. Precautionary wash to TD. No fill or exess drag. 00:30 - 11:00 10.50 DRILL SURF Drill to 973', 10-20 K WOB, 60 RPM surf./150 RPM bit. w/1500 ftlb. torque. 1300 psi {~ 600 gpm, 50 -150 fph,No excess drag 11:00 - 12:00 1.00 DRILL SURF Circulate hole clean and survey. 12:00 - 13:00 1.00 DRILL SURF POOH for HWDP.Stand back DP 13:00 - 13:30 0.50 DRILL SURF RIH w/HWDP tag btm ~ 973 No Fill 13:30 - 00:00 10.50 DRILL SURF Cont, Drilling to 1398' AST= 6.5 hrs. ART=0.5hrs 10/27/2000 ,00:00 - 00:00 24.00 DRILL SURF Control Drill from 1398' to 2926'. AST- 12 Hrs., ART - 4.25 Hrs 10/28/2000 '00:00 - 01:00 1.00 DRILL SURF Drill to 3010'. ART = 1 hr. 60+90 RPM., 10-30 K WOB, 1970 psi. @ 600 gpm. 01:00 - 02:00 1.00 DRILL SURF CBU 02:00 - 03:30 1.50 DRILL SURF Short trip to 1700'. 10 - 15 K OP from TD to 2400'. 15 - 20 K Op to 1700', 03:30 - 04:30 1.00 DRILL SURF RIH to TD. No Excess drag or fill. 04:30 - 06:00 1.50 DRILL SURF CBU. Spot 1.5 % Lubtex casing running pill TD to 2000'. 06:00 - 07:00 1.00 DRILL SURF Drop ESS. Pull 5 std. Pump Slug. 07:00 - 07:45 0,75 DRILL OTHR SURF Repair 4" DP elevators. See Remarks. 07:45 - 09:00 1.25 DRILL SURF POOH to HWDP. Pulled 30 K OP @ 2030'. OthenNise no excess drag. Trip hole fill OK. 09:00 - 10:00 1.00 DRILL SURF XO to 5" elevators. PO and RB HWDP. 10:00 - 13:00 3.00 DRILL SURF LD jars & FDC. Download MWD/LWD data. LD tools, motor and bit. 13:00 - 15:00 2.00 CASE SURF Rig up power tongs, spider, 15' bales and elevators, MU fillup tool. PU hanger and Landing joint, Dummy land then lay out hanger 15:00 - 15:30 0,50 CASE SURF Pre-job safety meeting for casing running. Printed: 11/28/2000 8:49:14 AM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: 8-105 Common Well Name: S-105 Spud Date: 10/25/2000 Event Name: DRILL+COMPLETE Start: 10/24/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es · · .. .... ..... ........ .... ........... . ...... .: .... Date' 'Fr°m'"T°' HourS· 'Task·· Code'SUb Phase .. ' .'..~' ' ' Description .... of Operations .' .. 10/28/2000 15:30 - 18:45 1.25 CASE SURF MU shoe and float joints. Install centralizers and check floats. PU ~lup tool and BC. 16:45 - 21:00 4.25 CASE SURF RIH w/9 5/8" 40.0~ L-80 BTC Casing to 2530' - tag obstruction. 21:00 - 22:00 1.00 CASE SURF Work pipe with and without pumps from 2530' to 2590'. Hole cleared up. Normal Drag of 100 to 110. 22:00 - 23:00 1.00 CASE SURF Run total of 73 Jts 9 5/8" 40ppf, L-80, BT&C Csg. set shoe at 2998'. 23:00 - 00:00 1.00 CASE SURF M/U landing Jt.& Mandrel Hgr, Hang off casing in Head, M/U cement head. 10/2912000 00:00 - 01:30 1.50 CASE SURF Circulate and condition for casing job. Did not recriprocate casing due to hole problems encountered whle RIH. Hold PJSM while circulating. 01:30 - 03:30 2.00 CASE SURF Cemented 9 518" csg. @ 2996' wi 75 bbl. 10.4 ppg Viscosified spacer, 312 bbl 10.7 ppg ASL III lead slurry and 50 bbl 15.8 ppg Class G tail slurry.. Displaced with 222 bbl and bumped plugs to 3500 psi. Checked floats. Recovered 122 bb110.7 ppg cement returns to surface. Full returns throughout job. 03:30 - 04:30 1.00 CASE SURF ND Cmt Head & lines, BO landing JT.,Flush Div., LD csg tools, clear floor. 04:30 - 07:30 3.00 BOPSUF SURF Remove Sfc. Riser, ND Diverter, removed Sfc equip, from cellar 07:30 - 14:30 7.00 BOPSUF PROD1 Install Speed Head & adapter flange. NU BOP'S. 14:30 - 19:00 4.50 BOPSUF PROD1 RU, set test plug, Test BOPE per program 250 Iowl3500 ! High. Test witness waived by Lou Grimaldi, AOGCC. 19:00 - 00:00 5.00 DRILL PROD1 PU & MU BHA, Load source -MWD.RIH, very tight clearance - had to work down until drill collar wieght could "push". Eased through Tam port collar - No problem, took no wt., Cont. RIH to 1800'. 10/30/2000 00:00 - 00:30 0.50 DRILL 'PROD1 Function check MWD ~ 1700'. 00:30 - 01:30 1.00 DRILL ! PROD1 Cut drilling line 01:30 - 03:00 1.50 DRILL PROD1 Conduct stripping in hole drill/training. Strip 1700' to 1800' w/ psi taking returns through choke. :03:00 - 04:00 1.00 DRILL PROD1 RIH to 2700' Precautionary wash to top plug at 2914'. No cement on plug. 04:00 - 05:00 1.00 DRILL PROD1 CBU and condition for casing test. 05:00 - 06:00 1.00 DRILL PROD1 :Test casing to 3500 psi. wi 3.2 bbl pumped. Held 30 min. Lost 75 psi. Bleed back 3.2 bbl. 06:00 - 07:30 1.50 DRILL PROD1 !Drill out plugs & float collar in 15 min. Drill firm cement to 2994'. Milled ~ continuous swarf approx. 0.004" thick off ID of casing through entire shoe track. No exess or erratic torque noted. Drilled shoe in 2 min. 07:30 - 08:00 0.50 DRILL PROD1 Wash through rathole wi no cement to 3010'. Drill to 3030'. 08:00 - 09:30 1.50 DRILL PROD1 Pump sweep and displace well to 10.2 ppg LSND mud. 09:30 - 10:00 0.50 DRILL PROD1 Pull 1 std. and perform LOT. Pumped 1.5 bbl. to 888 psi. Breakover @ 1.1 bbl & 689 psi. Calculated LOT EMW = 14.86 ppg at breakover. Held 10 min. w! pressure still declining at 275 psi. Held 5 min. to 220 psi. Bleed back and recover 0.5 bbl. 10:00 - 11:30 1.50 DRILL PROD1 Retest. Pressure to 439 psi wi 0.6 bbl. Isolated at standpipe and checked for leaks. Bled to 275 psi. in 10. min. Bleed off & recover 0.2 bbl. Repressure to 477 psi w! 0.7 bbl. Isolate at pumps and check for leaks. Bled to 300 psi in 10. min. Hold pressure while confirm LOT results w/Drilling Superintendant. Bled to 180 psi after 30 min. Bleed back 0.1 bbl. 11:30 - 00:00 12.50 DRILL PROD1 RIH to 3030 and drill per directional plan to 4134 Experienced Background Gas of 40 to 70 units topping the Ugnu. Printed: 11/28/2000 8:49:14 AM BP EXPLORATION Page 3'of 5 Operations Summa Report Legal Well Name: $-105 Common Well Name: S-105 Spud Date: 10/25/2000 Event Name: DRILL+COMPLETE Start: 10/24/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: N^BORS 9ES Rig Number: 9es From_To .Hours iTask Sub ........ Phase"": .............. ... Date' .. code · ~,escripti,,n .,.,~,erations ' .. ... 10~30~2000 11:30 - 00:00 12.50 DRILL PROD1 Connection gas of 750 units and 1500 units with slight oil show in the fine sand cuttings. No flow nor increase. Allowed mud to climb to 10.3 ppg and continue to monitor all parameters. BG leveled out at 30-45 U., CG 250U. 10/31/2000 00:00 - 23:00 23.00' DRILL PROD1 Drill from 4134' to 6187'. AST = 3.25 hrs. ART = 13.0 hrs. PU -- 170K, SO -- 118K ROT = 138K. 8-9000 ftlb ~ 60 rpm. 3000 psi ~ 500 gpm. 23:00 - 00:00 1.00 DRILL PROD1 Pump 25 bbl Hi-Vis pill. Circulate hole clean. Flow Check-OK. Pump slug. 1111/2000 00:00 - 02:30 2.50 DRILL PROD1 Slug pipe and POOH to 5440'. 30 - 40 K OP 5560' to 5440' wi partial swabbing. Work pipe and POOH wi proper hole fill. Pulled 30- -50 Op 3760 to 3201'. Worked each std. and pulled to shoe. 02:30 - 03:30 1.00 DRILL PROD1 Service top drive and link tilt. Fill pipe and blow down kelly hose. 03:30 - 06:00 2.50 DRILL PROD1 RIH wi minor surge loss. Running drag = 10 - 15 K from 3201' to 3760' and 5440' to 5560'. Total loss of 8 bbl. 06:00 - 06:30 0.50 DRILL PROD1 CBU and clear heavy cuttings from shakers. Large blocky coal returns. BU Max Gas = 580 units. 06:30 - 23:00 16.50 DRILL PROD1 Orient and slide 60' for azimuth then rotate and drill to 7349'. Geologist called HRZ top. PU = 196K, SO = 126K, ROT -- 155K. Torque -- 10 to 11K at 60 RPM. 3350 psi ~} 500 gpm. AST = 1.75 ART -- 11 23:00 - 00:00 1.00 DRILL PROD1 Pump 25 bbl Hi-Vis sweep. Circulate hole clean from 7349' 11/2/2000 00:00 - 02:30 2.50 DRILL PROD1 . POOH to 9 5/8" casing shoe ~ 2994'. Had 5-10K drag ~ 3400'. Pulled =slow through this interval to avoid hole swabbing. 02:30 - 05:30 3.00 DRILL PROD1 . Drain & clean mud pits #2 & #3 in preparation for KCL/GEM mud . system. 05:30 - 07:30 2.00 DRILL PROD1 TIH to bottom @ 7349'. Had 5-10K running drag ~, 3400' with minor .surge loss. Lost 6 bbl. No other hole problems encountered. 07:30 - 10:00 2.50 DRILL PROD1 . CBU. Max trip gas -- 220 units. 10:00 - 10:30 0.50 DRILL i PROD1 Pump 50 bbl 10.5 ppg spacer. Displace drill pipe with KCL/GEM mud. 10:30 - 11:00 0.50 DRILL i PROD1 Drill from 7349' to 7374'. ART = 1/2 hrs. 11:00 - 12:00 1.00 DRILL PROD1 Finish displacing hole to KCI./GEM mud system. Clean #1 mud pit. Could not deliver from trucks fast enough to continue drilling. Top off pits with KCI_/GEM mud and clean out possum belly and shaker trays.. 12:00 - 00:00 12.00 DRILL PROD1 Drill from 7374' to 8052'. Geologist called top of the Miluveach ~ 7960' MD / 7057' TVD. PU = 200K, SO - 142K, ROT WT = 168K, Torque -- 8-10K at 70 RPM. 2890 psi @ 485 gpm. ART = 9.5 hrs, AST= I hr. 11/3/2000 00:00 - 02:00 2.00 DRILL PROD1 Drill to 8120' MDTD / 7203' TVD.PU -- 205K, SO -- 142K, ROT WT -- 168K, TORQUE = 8-10K at 70 RPM. 2890 psi ~ 485 gpm. ART -- 2 hrs. 02:00 - 03:00 1.00 DRILL PROD1 Pump Hi-vis sweep and circulate hole clean from 8120'. 03:00 - 04:00 1.00 DRILL PROD1 POOH. Short trip to 7301'. Encountered tight spot ~ 7684' to 7600' with 25-45K O.P. 04:00 - 06:30 2.50 DRILL PROD1 TIH. Perform MAD Pass from 7550' to 8000' @ 240'/hr +/-.Finish TIH to bottom. 06:30 - 08:30 2.00 DRILL PROD1 Pump Hi-vis sweep. Circulate hole clean. Spot Liner pill. Pump Slug. Dropp ESS. 08:30 - 11:30 3.00 DRILL PROD1 POOH ( SLM ). Take ESS check shots @ 7722', 5483' & 5390'. Record PU & SO weights every 10 stands while POOH.Rack a total of 63 stands of 4" drill pipe in derrick. 11:30 - 13:00 1.50 DRILL PROD1 Continue POOH to BHA. Layed down 51 jts of 4" drill pipe. 13:00 - 16:00 3.00 DRILL PROD1 Stand back HWDP. Down load MWD data. Held PJSM. Remove nuclear source from tool. L/D all directional drilling equipment. Printed: 11/28/2000 8:49:14 AM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: S-105 Common Well Name: S-105 Spud Date: 10/25/2000 Event Name: DRILL+COMPLETE Start: 10/24/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es .Date.. ' From - To HOurs .Task .Sub Phase .. . Description of Operations .. · ,'.. ' .. = . :.COde. : .. , .= .. · · ..... 11/312000 .16:00 - 20:00 4.00 DRILL PROD1 Pull wearbushing. Change out UDPR to 7" Casing rams. Test BOP bonnets to 3500 psi. .20:00 - 21:00 1.00 DRILL PROD1 Rig up 7" casing running equipment. Make dummy run with 7" casing hanger & landing joint. 21:00 - 00:00 3.00 DRILL PROD1 Run 7" 26 ppf L-80 BTCM Production casing to 2052' ( 50 joints). This was midnight depth. 111412000 00:00 - 01:30 1.50 CASE PROD1 Run 7", 26~, L-80, BTC csg to 2999'. PU = 109K, SO = 100K. 01:30 - 02:00 0.50 CASE PROD1 C & C 115 bbl w/full returns. 7 bpm {~470 psi. 02:00 - 08:30 6.50 CASE PROD1 RIH w/casing to 7600' wi no excess drag. Minor loss of returns ~ 45 sec. per jt. Slowed to 90 sec per joint and regained full returns. 08:30 - 09:30 1.00 CASE PROD1 Worked tight hole from 7600' to 7700' at 20' intervals w/jerky drag and stack out down and PU to 360K (150 K OP) Suspect mechanical hanging of centralizers. 09:30 - 10:00 0.50 CASE PROD1 RIH w no excess drag to 8070'. Full returns. PU = 260 K. SO = 140 K. 10:00 - 10:30 0.50 CASE PROD1 MU mandrel hanger and Landing joint· RIH to 8085'. Stacked out. Worked to TD wi 360 K PU and 80 K SO. Landed 197 its at 8103.46' RKB. 7188' TVD. Total mud loss to hole = 14 bbl. 10:30 - 12:00 1.50 CASE PROD1 RU cement head and lines. Break circ. w/320 psi {~ 1 bpm. Stage to 850 psi @ 5 bpm. Partial packoff to 2600 psi. Reduced rate to 2.5 bpm with pressure declining past 1600 psi. Staged back to 6 bpm at 800 psi · Bottoms up and cleaned up with no losses. 12:00 - 12:30 0·50 CASE PROD1 Held PJSM w/NAD, Peak, Baroid, and BPX personnel while continuing circulation. Final circulation 7 bpm & 1000 psi. 12:30 - 15:00 2.50 CASE PROD1 Cement casing. Flushed and tested lines to 3500 psi. Dropped bottom plug and pumped 50 bbl 11.5 ppg Visc. Spacer, 115 bbl 11.5 ppg lead slurry and 55 bbl 15·8 ppg tail· Started mix at 13:10. End Mix at 13:48. Average mix rate -- 5 bpm. Dropped top plug and displaced with 307.3 bbl sea water at 8.15 bpm. Bumped plug and pressured to 3500 psi. Held 5 min. CIP at 14:43. Bleed back 1 bbl and confirm floats holding· PBTD at float collar -- 8017' MD, 7109' TVD. 15:00 - 17:30 2.50 CASE PROD1 RD cement head ,and lines. LD running tool. Change elevator bales & install drill pipe elevators. Clear rig floor of excess equipment. 17:30 - 18:30 1.00 CASE PROD1 M/U 7" packoff seals. RIH & set packoff. R/U & test packoff to 5000 psi for 30 minutes with no problems. IJD Packoff setting tool. 18:30 - 20:30 2.00 CASE PROD1 Open top ram bonnets & change out 7" casing rams to 3 1/2" x 5" VBR. M/U test plug on 4" dp & RIH. Test top ram bonnets to 3500 psi. L/D test plug. 20:30 - 21:00 0·50 CASE PROD1 Inject 93 bbl of 10.5 ppg KCI/Gem mud down 7" x 9 5/8" annulus ~ 4 bpm with 800 psi final injection pressure. 21:00 - 22:00 1.00 CASE PROD1 Freeze protect 7" x 9 5/8"'annulus. PJU Hot oil line to 11" 5M casing valve. Inject 60 bbl of dead crude oil down annulus ~ 2 bpm with 1600 psi final injection pressure. Close casing valve & secure. R/D Hot oil line. 22:00 - 23:00 1.00 CASE PROD1 Test 7" casing to 3500 psi with 4 bbl of seawater. Test was APl. Bleed down and stabilized at 3415 psi.4 bbl pumped, 4 bbl returned· 23:00 - 00:00 1.00 CASE PROD1 I RJU 3 1/2" tubing running equipment. Held PJSM regarding 3 112" tubing running procedures. 11/5/2000 00:00 - 08:30 8.50 RUNCOI~ COMP PJSM. Run 3.5", 9.2#, L-80 EUE 8-RD completion string per program wi 236 jts, 3 X nipples, Baker S-3 packer and 3 GLM. 08:30 - 09:30 1.00 RUNCOI~ COMP XO to 4.5" tools and PU 4.5" X-O and tubing hanger. Land tubing at 7630.85' RILDS. 09:30 - 13:00 3.50 RUNCOI~ COMP Reverse circulate Seawater @ 3 bpm & 350 psi. Pumped 200 bbl, clean SW, 150 bbl corexit treated SW, and 50 bbl clean SW. Initial returns Printed: 11/28/2000 8:49:14 AM BP EXPLORATION Page 5 of 5 Operations Summa Report . . Legal Well Name: 8-105 Common Well Name: S-105 Spud Date: 10/25/2000 Event Name: DRILL+COMPLETE Start: 10/24/2000 End: 11/5/2000 Contractor Name: NABORS Rig Release: 11/5/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es SUb phase' '. · Description of Operations ....... .. ".. . ..Date... .~.From - To.Hours Task COde . .' . · .... ... .. : . .. . . 1115/2000 09:30 - 13:00 3.50 RUNCO~ COMP 285 NTU. Final 78 NTU. 13:00 - 14:30 1.50 RUNCO~ COMP L/D Landing joint. Install TWC in Tubing hanger. Test to 500 psi above & 1000 psi below with no problems. 14:30 - 18:30 4.00 RUNCO~ COMP N/D 13 5~8" 10M BOP. NIU FMC 2 9116" 5M Production Tree assembly. Shell test Tree to 5000 psi for 30 minutes & record on chart. 18:30 - 20:00 1.50 RUNCO~ COMP Pull TWC. Drop ball rod down tubing. FUU Hot oil line to 3.5" X 7" casing annulus valve. Test to 4000 psi. Pressure up tubing to 3500 psi & set BOT "83" production packer. Held 3500 psi on 3.5" tubing for 30 minutes-OK. Bleed tubing pressure to 1800 psi. Apply 3500 psi to 3.5" x 7" annulus. Bleed-off tubing pressure & sheared RP with 1750 psi. Bleed-off remaining pressure on tubing & annulus to 0 psi. 20:00 - 22:30 2.50 RUNCO! COMP Freeze protect 3.5" x 7" annulus. Reverse circulate 80 bbl of diesel down annulus with Little Red Hot oil pump truck @ 2 bpm. Stop pumping. Had 250 psi differential pressure. Let well U-Tube & equalize. PJD Hot oil line. 22:30 - 00:00 1.50 RUNCO~ COMP Set BPV in Tubing hanger. Secure well. R/D & prepare for rig move. Released Nabors Rig 9ES from well # S-105 at 24:00 hrs on 11/05/00. Printed: 11/28/2000 8:49:14 AM Page 1 of 2 Well Service Report IlWell II Job Scope Is-xo~ IIDgn~L-POST WORK IDate]lOaily Work Io3/o9/2oo 1 []Job Number IIDmLL-POST WORK: SCMT BOND LOG, ADD PERF 0000905.6 I lunit Number I]SWS 2158 IDlyIIOperation Complete IlSuc~! IlKey Person Ilsupervisor JACKSON False Il SWS-DECKERT II Field IIAFC# Ilcc# IIDaily Cost IIAccum Cost IIsig~ed I[ Init Tbg Press 0 IlFinal Tbg Press [lInit Inner Ann IlFinal Inner Ann IIlnit Outer Ann II ~oo II o II o II IIFinal Outer Ann o II o Daily Summary LOG SCMT 0 PSI FROM TD 7949-EOT 7620, JEWELRY LOG TO 7400. PERF Il 7650-7670, 7682-7702 & 7712-7722 WITH 2.5" POWERJET 6 SPF, 25.2 PENE, .32 II EH, 10.7 GMS. ***POP WELL*** Time 09:00 10:00 10:30 11:30 12:00 I 12:20 IILog Entry II~Ru sws 2158 SAFETY MTG, MUSTER AREA, WIND, SLIPS, TRIPS, FALLS, INO WELL HOUSE, BLEEDING GAS, JOB DETAILS, ICE & SNOW HARD IPACKED-SLICK IIPT LUB 500 LP, 3000 HP IImH W/SCMT-GR-CCL IILoo PASS ONE TD 7949, EOT 7620 ]ILOG PASS 2, 1500 PSI [ICOMPLETE LOG POOH 113:30 Iloo~ I 14:00 15:00 IImH W/20' 2.5" PJ 6 SPF IITIE IN, POSITION & SHOOT 7682-7702. NO PRESS CHANGE FROM ZERO, RUN IUP/DN HOLETO MINIMIZE BURRS. POOH I x6:oo IImH W/20' GUN 16:50 I 18:oo 18:45 IICORRELATE, SHOOT 7650-7670. WHP 500, OPEN WING 250g, SHOOT NO ICHANGE, RUN UP/DN W/GUN POOH ]IRIH W/10' GUN IICORRELATE, SHOOT 7712-7722. WHP 700, OPEN WING 300, SHOOT NO ICHANGE, RUN UP/DN W/GUN POOH 12o:3o Iloo" I 2~.'oo IIRDMO http://apps-a~aska.bpweb.bp.c~m/sst-dri~~ing-we~~s/we~~-event.../we~~event-awgs.asp?~D=S 105390110275 4/23/2001 .. Page 2 of 2 [Service Company - Service ISCHLUMBERGER SVCS - E LINE CONTRACT IFLUID - DIESEL NON RECVRBL ITotai Field Estimate IIDaily Cost IIAccum Total II 29,070'0011 Il 32'0011 II 29,102.001l IlFluid [Summary http://apps-a~aska.bpweb.bp.c~m/sst-dri~~ing-we~~s/we~~-event.../we~~event-awgs.asp?ID=S 1053901 !0275 4/23/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99603-5711 ATTN: Sherrie NO. T17 Company: Alaska Oil & Gas Cons Comm Afln: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 3/29/01 Field: Borealis Well Job # Log Description Date Color Sepia BL CD S-105 ,::~(O~)-L~'~ 21136 SCMT 03/09/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED APR 0 6 2001 Date Delivered: ALaeir,~ ('ill ,t, ~ f~J~ne f'.e~mmie, ei~m Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 AI-rN: Sherrie Recei~,~ 03/08/2001 15:43 FAX 907 564 4264 BP EXPLORATION bp March 7, 2001 BP Exploration (Ala~a) Inc. 900 Fast Benson Boulevm'd P.O. Box 196612 Anchora~ Alaska 99519-6612 (90?) 561-5111 ~ UU.I. Julie Heusser, Dan Seamount, & Cammy Occhsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7*~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & Lisburne Well Work This listing is provided as required under thc terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001' Well , 03-08 03-25A ' 03-27 03-28 06-18. 13-27A 16-05Ai 16-21 NK-22 S- 10l 8-103 Work Planned REPERFORATION REP~ORATION / HYD~~C ~~ ~A~ ~~~ON '" ~ ~cm wASS- ~ ~~~ sO~~ oSO ~ ~ ~~~UON W/WO~ C~ S~E~CK (N~OR~ 3~) ~~O~ON ~D P~~TION ~ PEtiTION ~ PEtiTION If additional data or scheduling infOrmation is needed, please call me at 564-5799 or E-mail me at t~/~o o s 2oo~ Alaska Oil & Gas Cons. Commission Anchorage FEB 26 '01 09:05PM BP MILME POIMT GROUP BP Exploration Endioott Well Operations P.2 Sunday_ .. Sliekline: E-line; ..... Other: 4-10 1-47 Dummy off GLV'e a'r{d drift tubir~l~, to 3.62.5" Leak detection water flow log.. Monday_ Ii$1iokline: 2/2.,6 3-25 Pull S$SV, drif{~)t_h dumrfi~ w.h.!pstoek 2-14 Water flow Tuesda), ~lickline: E-line: Other: 3-25...Run static pressure euwey 3-39 gas-lift survey & FSPL 1-05L2-12; 3-45! .4.10~ 5-01 & 5-02 MJ,T,'_s w/AOGCC witness Wednesday ISlickline: Other: 2/28 1-25 Brush;_Flush & pull ~ .~8Vi-~ii'ift'tubing Thursday [[lickline: that: 8/01 1-25 Caliper s~rvey tubi;l{t & liner,.. 2-56 PFO .Friday 3/02 ISlickline: lOth?r! .... 1-2S b'tatic pressure suWey. Saturday 3/04 1811ekllne: 1.21 ' lOth_er'.. ....... - C~lipi~r survey of tubing. I njectivity test To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.. Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 December 12, 2000 MWD Formation Evaluation Logs ' S-105, AK-MM-00241 S-105: ~" x 5" MD Resistivity & Gamma Ray Logs ' 50-029-22977-00 ~2" x 5" TVD Resistivity & Gamma Ray Logs · 50-029-22977-00 4"2" x 5" MD Neutron & Density Logs: 50-029-22977-00 42" x 5" TVD Neutron & Density Logs' 50-029-22977-00 Blueline Rolled Sepia ~,Blueline Rolled Sepia Blueline Rolled Sepia Blueline Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSMITTAL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-teclmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF Date: Signed:g~~~~~o_~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 300! Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs S-105, AK-MM-00241 November 21, 2000 v/' 1 LDWG formatted Disc with verification listing. API#: 50-029-22977-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSMITTAL LETTER TO TH'E ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Tectmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF THE Date: 14-Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Wel S-105 MWD Dear Lori Taylor: ',' Enclosed are two survey hard copies. ,t: ~ ~-~'~~. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 8,120.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-105 MWD Job No. AKMMO0241, Surveyed: $ November, 2000 SURVEY REPORT 14 November, 2000 Your Ref: API-500292297700 Surface Coordinates: 5980834.75 N, 618929.81 E (70° 21' 22.6508" N, 210° 57' 57.1685" E) Kelly Bushing: 65.08ft above Mean Sea Level ~ l.~lllburton CompIn¥ Survey Ref: svy10564 Sperry-Sun Drilling Services Survey Report for S-105 MWD Your Ref: API-500292297700 Job No. AKMM00241, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (fi) 0.00 0.000 0.000 -65.08 0.00 147.03 0.660 4.350 81.95 147.03 235.10 0.730 11.690 170.01 235.09 330.82 0.720 26.750 265.72 330.80 423.45 0.620 38.200 358.35 423.43 519.39 0.730 45.700 454.28 519.36 612.54 0.870 50.610 547.42 612.50 705.00 1.160 67.520 639.87 704.95 799.27 1.450 72.950 734.11 799.19 893.81 1.390 78.450 828.62 893.70 975.27 1.190 84.820 910.06 975.14 1071.68 0.870 83.800 1006.46 1071.54 1166.14 1.560 5.100 1100.90 1165.98 1258.82 3.870 349.480 1193.47 1258.55 1353.61 4.810 350.970 1287.99 1353.07 1444.26 8.630 353.430 1378.00 1443.08 1540.46 10.170 357.170 1472.90 1537.98 1633.36 12.290 1.860 1564.02 1629.10 1726.65 20.090 5.780 1653.55 1718.63 1757.71 20.970 6.250 1682.63 1747.71 1819.27 21.340 1915.30 21.080 2006.61 22.580 2098.79 25.300 2190.83 27.630 1740.05 1829.57 1914.33 1998.57 2080.96 3.860 2.440 3.460 4.040 3.780 1805.13 1894.65 1979.41 2063.65 2146.04 Local Coordinates Global Coordinates Northinga Eaatinga Northings Eastinga (ft) (fi) (ft) (ft) 0.00N 0.00E 5980834.75N 618929.81E 0.84 N 0.06 E 5980835.60 N 618929.86 E 1.90 N 0.22 E 5980836.65 N 618930.00 E 3.03N 0.61E 5980837.79 N 618930.37E 3.95 N 1.18 E 5980838.72N 618930.93 E 4.78 N 1.94 E 5980839.56 N 618931.67E 5.65 N 2.91 E 5980840.44N 618932.63 E 6.45 N 4.32 E 5980841.27N 618934.03E 7.16 N 6.34 E -5980842.01N 618936.04E 7.74N 8.61E 5980842.63N 618938.29 E 8.02N 10.42E 5980842.93 N 618940.10 E 8.19 N 12.14 E 5980843.13 N 618941.82E 9.55 N 12.97E 5980844.50 N 618942.63E 13.88 N 12.51E 5980848.82 N 618942.10 E 20.95 N 11.30E 5980855.87N 618940.78 E 31.46 N 9.93E 5980866.37N 618939.24E 47.12 N 8.68E 5980882.00N 618937.74E 65.19 N 8.60 E 5980900.07N 618937.37E 91.10 N 10.54 E 5980926.00 N 618938.90E 101.93 N 11.68 E 5980936.85 N 618939.87E 124.06 N 13.63E 5980959.01N 618941.47E 158.74N 15.55 E 5980993.72N 618942.83 E 192.65N 17.30E 5981027.65 N 618944.05 E 229.97 N 19.76E 5981065.00N. 618945.92E 270.89 N 22.55 E 5981105.96 N 618948.06E Dogleg Rate (°/100ft) 0.45 0.13 0.20 0.18 0.15 0.17 0.45 0.33 0.16 0.30 0.33 1.73 2.59 1.00 4.22 1.72 2.48 8.44 2.88 1.52 0.60 1.69 2.96 2.53 Alaska State Plane 4 PBU_WOA $ Pad Vertical Section Comment 0.00 0.85 1.91 3.06 4.00 4.87 5.78 6.66 7.47 8.17 8.53 8.79 10.19 14.49 21.49 31.92 47.49 65.54 91.51 102.39 124.58 159.32 193.28 230.67 271.68 MWD Magnetic Continued... 14 November, 2000 - 17:34 - 2 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-105 MWD Your Ref: API-500292297700 Job No. AKMM00241, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (ft) Incl. 2285.93 29.420 2378.87 30.420 2474.05 31.860 2565.92 30.820 2660.07 31.970 2754.91 33.140 2848.19 32.990 2930.77 32.670 3037.20 33.670 3131.32 34.450 3225.16 33.970 3318.67 33.400 3411.15 32.710 3504.47 31.880 3596.95 34.210 3690.84 35.080 3785.46 34.680 3879.39 33.740 3972.08 34.330 4065.41 33.190 4157.85 31.470 4250.67 32.760 4343.62 36.230 4438.05 36.520 4530.55 35.210 Azim. 1.920 2.140 2.250 2.700 3.020 1.680 1.380 1.330 1.650 2.320 1.390 2.910 2.080 2.140 0.890 1.500 0.730 0.630 2.250 3.160 4.100 5.080 4.190 4.650 5.370 Sub-Sea Depth (ft) 2164.52 2245.07 2326.53 2405.00 2485.36 2565.30 2643.47 2712.86 2801.95 2879.92 2957.53 3035.34 3112.85 3191.73 3269.25 3346.49 3424.11 3501.79 3578.60 3656.2O 3734.30 3812.92 3889.52 3965.55 4040.51 Vertical Depth (ft) 2229.60 2310.15 2391.61 2470.08 2550.44 2630.38 27O8.55 2777.94 2867.03 2945.00 3022.61 3100.42 3177.93 3256.81 3334.33 3411.57 3489.19 3566.87 3643.68 3721.28 3799.38 3878.00 3954.60 4030.63 4105.59 Local Coordinates Global Coordinates Northings Eaatings Northings Eaatinga (ft) (ft) (ft) (ft) 316.24 N 24.79 E 5981151.34 N 618949.57E 362.57 N 26.43E 5981197.69 N 618950.48E 411.75 N 28.32 E 5981246.90 N 618951.59 E 459.49 N 30.38 E 5981294.66 N 618952.89 E 508.47 N 32.83 E 5981343.68 N 618954.56 E 559.46 N 34.91E 5981394.69N 618955.83 E 610.34 N 36.27 E 5981445.58 N 618956.39 E 655.09 N 37.33 E 5981490.35 N 618956.73E 713.30 N 38.85 E 5981548.58 N 618957.33 E 765.98 N 40.67 E 5981601.28 N 618958.32E 818.71N 42.38 E 5981654.03N 618959.19 E 870.54 N 44.32E 5981705.88 N 618960.31E 920.93 N 46.52E 5981756.30 N 618961.71E 970.75 N 48.36 E '5981806.15N 618962.75 E 1021.16 N 49.68 E 5981856.57 N 618963.27 E 1074.52 N '50.79 E 5981909.94 N 618963.54 E 1128.62 N 51.85 E 5981964.05 N 618963.73E 1181.43N 52.47E 5982016.86 N 618963.52 E 1233.28 N 53.78 E 5982068.73N 618964.01E 1285.09 N 56.22 E 5982120.57N 618965.63 E 1334.42N 59.34E 5982169.95 N 618967.96E 1383.61N 63.30E 5982219.19 N 618971.14 E 1436.07N 67.54E 5982271.71N 618974.54 E 1491.91N 71.85 E 5982327.61N 618977.97E 1545.89 N 76.58 E 5982381.66N 618981.84 E Dogleg Rate (°ll00ft) 2.10 1.08 1.51 1.16 1.23 1.45 0.24 0.39 0.95 0.92 0.76 1.09 0.89 0.89 2.62 1.00 0.63 1.00 1.17 1.34 1.94 1.50 3.77 0.42 1.49 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment 317.09 363.44 412.65 460.44 509.48 560.51 611.39 656.14 714.35 767.06 819.81 871.66 922.10 971.96 1022.37 1075.72 1129.80 1182.57 1234.43 1286.29 1335.72 1385.04 1437.65 1493.63 1547.79 Continued... 14 November, 2000 - 17:34 .3 - DrillQueet 2.00.05 Sperry'Sun Drilling Services Survey Report for S-105 MWD Your Ref: API-5002§2297700 Job No. AKMMO0241, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (fi) Incl. 4624.09 34.610 4717.40 33.880 4812.11 33.380 4904.60 33.070 4997.49 32.990 5091.70 33.640 5186.57 33.350 5279.03 33.300 5371.02 33,110 5464.85 33.300 5557.45 33.680 5651.85 33.620 5745.53 33,190 5838.82 32.720 5931.72 32.210 Azim. 5.070 6.170 6.700 7.100 3.350 0.590 0.550 1.480 1.460 1.590 1.870 1.530 2.090 1.660 2.100 Sub-Sea Depth (ft) 4117.21 4194.35 4273.21 4350.58 4428.46 4507.19 4586.31 4663.57 4740.54 4819.05 4896.27 4974.85 5053.06 5131.34 5209.72 Vertical Depth (ft) 4182.29 4259.43 4338.29 4415.66 4493.54 4572.27 4651.39 4728.65 4805.62 4884.13 4961.35 5039.93 5118.14 5196.42 5274.80 6024.92 31.960 1.360 5288,68 5353.76 6117.54 31.440 1.030 5367,49 5432.57 6209.51 30.930 0.390 5446,17 5511.25 6305.44 30.180 359.160 5528.78 5593.86 6398.87 29.800 358.550 5609,70 5674.78 6490.55 29.640 1.790 5689.32 5754.40 6584.28 29.340 3.180 5770.91 5835.99 6678.69 28.760 3.110 5853.44 5918.52 6772.03 28.270 2.120 5935.46 6000.54 6863.77 27.870 1.240 6016.41 6081.49 Local Coordinates Global Coordinates ' Northings Eaatings Northings Fastings (ft) (ft) (ft) (ft) 1599.20 N 81.45E 5982435.04 N 618985.86 E 1651.45N 86.59 E 5982487.37N 618990.17 E 1703.58 N 92.47 E 5982539.58 N 618995.22 E 1753.89 N 98.55 E 5982589.98 N 619000.51E 1804.29 N 103.16 E 5982640.45N 619004.32E 1855.99 N 104.93 E 5982692.17 N 619005.26 E 1908.34N 105.45 E 5982744.53 N 619004.95 E 1959.13 N 106.35 E 5982795.32 N 619005.04E 2009.49 N 107.64 E 5982845.69 N 619005.54 E 2060.86 N 109.01 E 5982897.08 N 619006.09 E 2111.93 N 110.56 E 5982948.17 N 619006.82 E 2164.21N 112.11E 5983000.47N 619007.54 E 2215.76N 113.73 E 5983052.04 N 619008.35 E 2266.48 N 115.40 E 5983102.78 N 619009.21E 2316.32N 117.03E 5983152.64N 619010.05 E 2365.81N 118.53 E 5983202.14 N 619010.76E 2414.46N 119.54 E 5983250.81N 619011.00E 2462,08 N 120.13 E 5983298.43N 619010.84E 2510.85 N 119.95 E 5983347.18 N 619009.88 E 2557.54 N · 119.02 E 5983393.85 N 619008.21E 2602,97N 119.15 E 5983439.29 N 619007.62E 2649.07N 121.15 E 5983485.41N 619008.88 E 2694.84 N 123.66 E 5983531.21N 619010.67E 2739.35 N 125.70 E 5983575.75 N 619012o00E 2782,50 N 126.97E 5983618.92 N 619012.58 E Dogleg Rate (°/100ft) 0.67 1.03 0.61 0.41 2.20 1.75 0.31 0.56 0.21 0.22 0.44 0.21 0.56 0.56 0.60 0.50 0.59 0.66 1.02 0.52 1.76 0.80 0.62 0.73 0.63 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment 1601.27 1653.72 1706.07 1756.62 1807.19 1858.92 1911.23 1962.00 2012.36 2063.73 2114.82 2167.11 2218.68 2269.42 2319.28 2368.77 2417.42 2465.01 2513.70 2560.29 2605.67 2651.81 2697.65 2742.21 2?85.37 Continued... 14 November, 2000 - 17:34 - 4 - DrlllQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-105 MWD Your Ref: API,500292297700 Job No. AKMMO0241, Surveyed: 3 November, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (fi) (fi) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6957.09 27.560 0.370 6099.02 6164.10 2825.90 N 127.58 E 5983662.32 N 619012.51 E 7050.36 28.790 1.530 6181.24 6246.32 2869.93 N 128.32 E 5983706.35 N 619012.55 E 7144.00 29.680 2.600 6262.95 6328.03 2915.63 N 129.97 E .5983752.07 N 619013.47 E 7236.21 29.140 2.050 6343.28 6408.36 2960.87 N 131.81 E 5983797.34 N 619014.59 E 7329.59 27.690 3.070 6425.41 6490.49 3005.26 N 133.78 E 5983841.75 N 619015.86 E 7423.87 27.220 4.240 6509.07 6574.15 3048.64 N 136.55 E 5983885.17 N 619017.94 E 7517.03 26.430 5.750 6592.20 6657.28 3090.51 N 140.20 E 5983927.10 N 619020.93 E 7610.76 25.440 6.230 6676.49 6741.57 3131.28 N 144.48 E 5983967.93 N 619024.56 E 7703.69 25.390 6.550 6760.43 6825.51 3170.92 N 148.92 E 5984007.63'N 619028.37 E 7796.58 25.710 6.280 6844.24 6909.32 3210.73 N 153.39 E 5934047.51 N 619032.21 E 7890.74 25.170 6.380 6929.27 6994.35 3250.93 N 157.85 E '5984087.78 N 619036.03 E 7983.51 24.430 6.170 7013.48 7078.56 3289.61 N 162.11 E 5984126.52 N 619039.67 E 8050.31 23.820 6.600 7074.44 7139.52 3316.74 N 165.14 E 5984153.70 N 619042.27 E 8120.00 23.820 6.600 7138.20 7203.28 3344.70 N 168.38 E 5984181.70 N 619045.06 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to $-105. Northings and Eastings are relative to $-105. Magnetic Declination at Surface is 25.367° (09-Nov-04) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from $-105 and calculated along an Azimuth of 2.882° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8120.00ft., The Bottom Hole Displacement is 3348.94ft., in the Direction of 2.882° (True). Dogleg Rate (°llOOff) 0.55 1.44 1.10 0.65 1.64 0.76 1.12 1.08 0.16 0.37 0.58 0.80 0.95 0.00 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment 2828.74 2872.75 2918.47 2963.75 3008.18 3051.65 3093.65 3134.59 3174.39 3214.38 3254.76 3293.60 3320.85 3348.94 Projected Survey Continued... 14 November, 2000 - 17:34 - 5 - DrillQueet 2.00.05 Sperry-Sun Drilling Services Survey Report for S-105 MWD Your Ref: AP1-500292297700 Job No. AKMMO0241, Surveyed: 3 November, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured Depth (fi) 8120.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7203.28 3344.70 N 168.38 E Comment Projected Survey Survey tool program for S-105 MWD From To Measured Vertical Measured Depth Depth Depth (fi) (ft) (fi) 0.00 0.00 8120.00 Vertical Depth (ft) 7203.28 Survey Tool Description MWD Magnetic 14 November, 2000 - 17:34 - 6 - DrillQueet 2.00.05 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-105 Job No. AKZZ00269, Surveyed: 3 November, 2000 SURVEY'REPORT 14 November, 2000 Your Ref: API-500292297700 Surface Coordinates: 5980834.75 N, 618929.81 E (70° 21'22.6508" N, 210° 57' 57.1685" E) Kelly Bushing: 65.08fl above Mean Sea Level A I-MIIFour~on Company Survey Ref: svy10584 Sperry-Sun Drilling Services Survey Report for S-105 Your Ref: API.500292297700 Job No. AKZZO0269, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -65.08 0.00 147.03 0.660 4.140 81.95 147.03 235.10 0.730 11.240 170.01 235.09 330.82 0.720 26.250 265.72 330.80 423.45 0.620 38.430 358.35 423.43 519.39 0.730 46.020 454.28 519.36 612.54 0.870 50.520 547.42 612.50 705.00 1.160 67.430 639.87 704.95 799.27 1.450 73.090 734.11 799.19 893.81 1.390 78.430 828.62 893.70 975.27 1.190 84.610 910.06 975.14 1071.68 0.870 83.560 1006.46 1071.54 1166.14 1.560 4.830 1100.90 1165.98 1258.82 3.870 349.190 1193.47 1258.55 1353.61 4.810 350.700 1287.99 1353.07 1444.26 8.630 352.720 1378.00 1443.08 1540.46 10.170 357.070 1472.90 1537.98 1633.36 12.290 1.850 1564.02 1629.10 1726.65 20.090 5.710 1653.55 1718.63 1757.71 20.970 6.250 1682.63 1747.71 1819.27 21.340 1915.30 21.080 2006.61 22.580 2098.79 25.300 2190.83 27.630 1740.05 1829.57 1914.33 1998.57 2080.96 3.860 2.470 3.500 4.050 3.680 1805.13 1894.65 1979.41 2063.65 2146.04 Local Coordinates Global Coordinates Northings Fastings Northinga Eaetings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5980834.75 N 618929.81 0.84N 0.06 E 5980835.60 N 618929.86 1.90 N 0.21E 5980836.65 N 618929.99 3.04N 0.59 E 5980837.80 N 618930.35 3.95 N 1.16 E 5980838.72N 618930.91 4.78N 1.92E 5980839.56 N 618931.66 5.65N 2.90 E 5980840.44N 618932.62 6.45 N 4.30 E 5980841.27N 618934.01 7.16 N 6.32 E 5980842.01N 618936[02 7.74 N 8.59 E 5980842.63N 618938.28 8.02 N 10.40 E 5980842.93N 618940.08 8.20 N 12.13 E 5980843.14 N 618941.80 9.56 N 12.95E 5980844.51N 618942.60 13.89 N 12.47E 5980848.83 N 618942.05 20.95 N 11.22E 5980855.88 N 618940.70 31.45 N 9.75 E 5980866.35 N 618939.06 47.09 N 8.40 E 5980881.97N 618937.46 65.17 N 8.30 E 5980900.04 N 618937.07 91.08 N 10.22 E 5980925.98 N 618938.58 101.91N 11.35E 5980936.83 N 618939.54 124.04N 13.31E 5980958.98 N 618941.15 158.72N 15.23 E 5980993.70N 618942.51 192.63 N 17.00E 5981027.62N 618943.75 229.95 N 19.48 E 5981064.98 N 618945.63 270.87 N 22.24E 5981105.94N 618947.74 Dogleg Rate (°/100ft) Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment E 0.00 E 0.45 0.85 E 0.13 1.91 E 0.20 3.06 E 0.19 4.01 E 0.15 4.87 E 0.16 5.78 E 0.45 6.66 E O.34 7.47 E 0.15 8.17 E 0.30 8.53 E 0.33 -8.80 E 1.73 10.20 E 2.59 14.50 E 1.00 21.49 E 4.22 31.90 E 1.76 47.46 E 2.49 65.51 E 8.44 91.48 E 2.90 102.35 E 1.52 E 0.59 E 1.70 E 2.96 E 2.54 124.55 159.29 193.24 230.64 271.65 AK-6 BP_IFR-AK Continued... 14 November, 2000 - 17:34 - 2 - DrlllQueet 2.00.05 Sperry-Sun Drilling Services Survey Report for S-105 Your Reft API.500292297700 Job No. AKZZO0269, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (ft) Incl. 2285.93 29.420 2378.87 30.420 2474.05 31.860 2565.92 30.820 2660.07 31.970 2754.91 33.140 2848.19 32.990 2930.77 32.670 3037.20 33.670 3131.32 34.450 3225.16 33.970 3318.67 33.400 3411.15 32.710 3504.47 31.880 3596.95 34.210 3690.84 35.080 3785.46 34.680 3879.39 33.740 3972.08 34.330 4065.41 33.190 4157.85 31.470 4250.67 32.760 4343.62 36.230 4438.05 36.520 4530.55 35.210 Azim. 1.880 2.180 2.310 2.850 3.130 1.620 1.250 1.210 1.520 2.180 1.260 2.760 1.920 2.O40 0.810 1.400 0.610 0.470 2.090 2.740 3.810 4.890 4.45O 4.810 5.460 Sub-Sea Depth (ft) 2164.52 2245.07 2326.53 2405.00 2485.36 2565.30 2643.47 2712.86 2801.95 2879.92 2957.53 3035.34 3112.85 3191.73 3269.25 3346.49 3424.11 3501.79 3578.60 3656.20 3734.30 3812.92 3889.52 3965.55 4040.51 Vertical Depth (ft) 2229.60 2310.15 2391.61 2470.08 2550.44 2630.38 2708.55 2777.94 2867.03 2945.00 3022.61 3100.42 3177.93 3256.81 3334.33 3411.57 3489.19 3566.87 3643.68 3721.28 3799.38 3878.00 3954.60 4030.63 4105.59 Local Coordinatee Global Coordinates Northinga Eaetings Northings Eaatinga (ft) (ft) (ft) (fi) 316.23 N 24.42E 5981151.32N 618949.20 E 362.55 N 26.06 E 5981197.67N 618950.11E 411.73 N 27.99 E 5981246.88 N 618951.26 E 459.47N 30.14 E 5981294.64N 618952.65 E 508.45 N 32.70 E 5981343.65 N 618954.43E 559.43 N 34.80 E 5981394.66 N 618955.73E 610.31N 36.08 E 5981445.55 N. 618956.19 E 655.07N 37.04E 5981490.32 N 618956.44E 713.28 N 38.43E 5981548.55 N 618956.91E 765.97 N 40.13 E 5981601.26 N 618957.78 E 818.70N 41.72E 5981654.01N 618958.53 E 870.53 N 43.53 E 5981705.86 N 618959.52 E 920.93 N 45.60 E 5981756.28 N 618960.78E 970.76 N 47.32E 5981806.13 N 618961.71E 1021.16 N 48.55 E 5981856.56 N 618962.15 E 1074.53N 49.59 E 5981909.93N 618962.33E 1128.63N 50.54 E 5981964.04N 618962.42E 1181.44N 51.04E 5982016.85 N 618962.08 E 1233.30 N 52.20 E 5982068.72N 618962.42E 1285.11N 54.38 E 5982120.57N 618963.78E 1334.47N 57.19 E 5982169.96 N 618965.81E 1383.67N 60.95 E 5982219.21N 618968.78E 1436.12 N 65.22 E 5982271.73N 618972.22E 1491.94 N 69.74E 5982327.61N 618975.86 E 1545.92 N 74.59 E 5982381.66 N 618979.85 E Dogleg Rate (°/100ft) 2.09 1.09 1.51 1.17 1.23 1.50 0.27 0.39 0.95 0.92 0.75 1.08 0.90 0.89 2.62 0.99 0.64 1.00 1.17 1.28 1.96 1.52 3.74 0.38 1.47 Alaska State Plans 4 PBU_WOA S Pad Vertical Section Comment 317.05 363.41 412.62 460.40 5O9.45 560.48 611.35 656.10 714.31 767.02 819.76 871.62 922.05 971.91 1022.31 1075.66 1129.74 1182.51 1234.36 1286.22 1335.65 1384.98 1437.59 1493.56 1447.71 Continued... 14 November, 2000 - 17:34 - 3 - DrillOuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-105 Your Ref: AP1-500292297700 Job No. AKZZO0269, Surveyed: 3 November, 2000 North Slope Alaska Measured Depth (ft) Incl. 4624.09 34.610 4717.40 33.880 4812.11 33.380 4904.60 33.070 4997.49 32.990 5091.70 33.640 5186.57 33.350 5279.03 33.300 5371.02 33.110 5464.85 33.300 5557.45 33.680 5651.85 33.620 5745.53 33.190 5838.82 32.720 5931.72 32.210 Azim. 5.410 6.300 6.560 6.890 3.340 0.460 0.410 1.290 1.340 1.630 1.820 1.530 1~60 1.660 1.980 Sub-Sea Depth (ft) 4117.21 4194.35 4273.21 4350.58 4428.46 4507.19 4586.31 4663.57 4740.54 4819.04 4896.27 4974.85 5053.06 5131.34 5209.72 Vertical Depth (ft) 4182.29 4259.43 4338.29 4415.66 4493.54 4572.27 4651.39 4728.65 4805.62 4884.12 4961.35 5039.93 5118.14 5196.42 5274.80 6024.92 31.960 1.270 5288.68 5353.76 6117.54 31.440 0.960 5367.48 5432.56 6209.51 30.930 0.810 5446.16 5511.24 6305.44 30.180 359.880 5528.77 5593.85 6398.87 29.800 359.020 5609.69 5674.77 2.130 3.270 3.420 2.280 1.340 5689.32 5770.91 5853.44 5935.46 6016.41 6490.55 29.640 6584.28 29.340 6678.69 28.760 6772.03 28.270 6863.77 27.870 5754.40 5835~9 5918.52 6000.54 6081.49 Local Coordinates Global Coordinates Northinga Eaatlnga Northings Eastinge (ft) (ft) (ft) (ft) 1599.21N 79.66E 5982435.02 N 618984.07E 1651.44N 85.01.E 5982487.34N 618988.59 E 1703.57N 90.88 E 5982539.55 N 618993.64E 1753.90 N 96.82 E 5982589.96 N 618998.77E 1804.31 N 101.33 E 5982640.44N 619002.48 E 1856.01 N 103.04 E 5982692.16 N 619003.37 E 1908.36 N 1 03.43 E 5982744.52 N 619002.93 E 1959.15 N 104.19 E 5982795.31 N 619002.88 E 2009.52 N 105.34 E 5982845.69 N 619003.24 E 2060.88 N 106.68 E 5982897.07 N 619003.75 E 2111.96 N 108.21E 5982948.16 N 619004.48 E 2154.24N 109.74E 5983000.46 N 619005.18 E 2215.79 N 111.31E 5983052.03N 619005.93 E 2266.52 N 112.92E 5983102.77N 619006.73 E 2316.36 N 114.50 E 5983152.63 N 619007.52 E 2365.84 N 115.90 E 5983202.14 N 619008.14 E 2414.50 N 116.85 E 5983250.80 N 619008.31E 2462.12 N 117.59 E 5983298.43 N 619008.29 E 2510.88 N 117.89 E 5983347.19 N 619007.82 E 2557.58 N 117.44 E 5983393.87N 619006.63E 2603.02N 117.89 E 5983439.31N 619006.36 E 2549.10 N 120.06 E 5983485.43N 619007.80 E 2694.87N 122.74E 5983531.23N 619009.75E 2739.37N 124.96 E 5983575.76N 619011.26E 2782.52 N 126.32 E 5983618.92 N 619011.94E Dogleg Rate (°ll00ft) 0.54 0.95 0.55 0.39 2.08 1.82 0.31 0.53 0.21 O.26 0.43 0.18 0.52 0.53 0.58 0.49 0.59 0.56 0.92 0.61 1.69 0.68 0.62 0.78 0.65 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment 1601.19 1653.63 1705.98 1756.55 1807.12 1858.84 1911.15 1961.91 2012.27 2063.64 2114.73 2167.02 2218.59 2269.33 2319.19 2368.68 2417.32 2464.92 2513.64 2560.25 2605.65 2651.79 2697.63 2742.19 2'~85.35 Continued... 14 November, 2000 - 17:34 - 4 - DrlllQueet 2.00,05 Sperry-Sun Drilling Services Survey Report for S-105 Your Ref: AP1.500292297700 Job No. AKZZO0269, Surveyed: 3 November, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (fi) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eaatings (ft) (fi) (ft) (ft) 6957.09 27.560 0.550 6099.02 6164.10 2825.91 N 127.04 E 5983662.32 N 619011.97 E 7050.36 28.790 1.630 6181.24 6246.32 2869.94 N 127.89 E 5983706.36 N 619012.12 E 7144.00 29.680 2.700 6262.95 6328.03 2915.64 N 129.62 E 5983752.08 N 619013.12 E 7236.21 29.130 2.210 6343.28 6408.36 2960.87 N 131.56 E 5983797.33 N 619014.35 E 7329.59 27.650 3.340 6425.43 6490.51 3005.21 N 133.70 E 5983841.71 N 619015.78 E 7423.87 27.220 4.370 6509.10 6574.18 3048.55 N 136.62 E 5983885.09 N 619018.01 E 7517.03 26.430 5.870 6592.24 6657.32 3090.42 N 140.36 E 5983927.01 N 619021.09 E 7610.76 25.440 6.290 6676.53 6741.61 3131.18 N 144.70 E _5983967.84 N 619024.78 E 7703.69 25.390 6.630 6760.47 6825.55 3170.81 N 149.19 E 5984007.53 N 619028.64 E 7796.58 25.710 6.290 6844.27 6909.35 3210.62 N 153.69 E 5984047.41 N 619032.51 E 7890.74 25.170 6.340 6929.30 6994.38 3250.82 N 158.14 E 5984087.68 N 619036.32 E 7983.51 24.430 6.160 7013.52 7078.60 3289.51 N 162.38 E 5984126.42 N 619039.94 E 8050.31 23.820 6.690 7074.48 7139.56 3316.64 N 165.43 E 5984153.60 N 619042.57 E 8120.00 23.820 6.690 7138.23 7203.31 3344.59 N 168.71 E 5984181.60 N 619045.40 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-105. Northings and Eastings are relative to S-105. Magnetic Declination at Surface is 26.696° (24-Oct-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from $-105 and calculated along an Azimuth of 2.888° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8120.00ft., The Bottom Hole Displacement is 3348.84ft., in the Direction of 2.888° (True). Dogleg Rate (°ll00ft) 0.52 1.43 1.10 0.65 1.69 0.68 1.12 1.07 0.17 0.38 0.57 0.80 0.97 0.00 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment 2828.72 2872.74 2918.46 2963.74 3O08.13 3051.56 3093.57 3134.50 3174.30 3214.29 3254.66 3293.51 3320.76 3348.84 Projected Survey Continued... 14 November, 2000 - 17:34 - 5 - DrillQueet 2.00.05 Sperry-Sun Drilling Services- Survey Report for S.105 Your Ref: API-500292297700 Job No. AKZZO0269, Surveyed: 3 November, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured Depth (fi) 8120.00 Station Coordinates TVD Northings Esstings (ft) (ft) (ft) 7203.31 3344.59 N 168.71 E Comment Projected Survey Survey tool program for S-105 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 8120.00 Vertical Depth (ft) 7203.31 Survey Tool Description AK-6 BP_IFR-AK 14 November, 2000- 17:34 -6- DrillQuest 2.00.05 ALASKA OIL AND GAS CONSERVATION CO~I~IISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S- 105 BP Exploration (Alaska) Inc. Permit No: 200-152 Sur Loc: 463 I'NSL, 4494'WEL, Sec. 35, TI2N, R12E, UM Btmhole Loc. 2666'NSL, 4333'WEL, Sec. 26, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The request for a diverter waiver is denied. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION · DATED this 7__ ff e'/x day of October, 2000 dlf/Enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA .. ALASK("- IL AND GAS CONSERVATION COM~:"" ,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill 11 b. Type of well Re-Entry [] Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas [][] SingleStratigraphiCzone Test [][] MultipleDevel°pmentzone Oil I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.3' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool (Undefined) P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4631' NSL, 4494' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2514' NSL, 4340' WEL, SEC. 26, T12N, R12E, UM S-105 Number 2S100302630-277 At total depth 9. Approximate spud date 2666' NSL, 4333' WEL, SEC. 26, T12N, R12E, UM 10/16/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028258, 946' MDI No Close Approach 2560 8119' MD / 7190' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 1000' MD Maximum Hole Angle 35" Maximum surface 2765 psig, At total depth (TVD) 6700' / 3435 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Wei.clht Grade CouDline Lenqth MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3011' Surface Surface 3040' 2866' 317 sx AS Lite 3, 242 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 8090' Surface Surface 8119' 7190' 483 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface ~ECE/~ED Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program L. [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terde Hubble, 564-4628 21. I hereby certify that the foregoing is true and cjl~rrect to the best of my knowledge Signed Dan Stone ~~..,'"'J~.-,'"~==,'~-=- Title Senior Ddlling Engineer Date Ri ~,5 ~ Permit Number APl Number ADoroval Date_ See cover letter ~"/~.~'-2-- 50- (~2.-.c'1~ '- ,,7--;2-~'77-O~ ~-~--~-- ~)O forother requirements Conditions of Approval: Samples Required [] Yes IRI No Mud Log Required [] Yes [] No Lt,~. ~~ Hydrogen Sulfide Measures [] Yes ~ No Directional Survey Required [] Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K 1~3.5K psi Other: by order of ORIGINAL $IG~,~.~.;.. Commissioner the commission Date / 0 Approved By D T'~ulnr .~._= ..... Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IS-105 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: Target Location: Kuparuk Bottom Hole Location: X = 618,930.00 Y = 5,980,835.00 4631' FSL 4494' FEL S35 T12N R12E X = 619,030.00 Y = 5,984,000.00 2514' FSL 4340' FEL S26, T12N, R12E X = 619,034.79 Y = 5,984,151.68 2666' FSL 4333' FEL S26, T12N, R12E Umiat Umiat Umiat I AFE Number: 15M0004 I Estimated Start Date:110/16/2000 MD= 18,119' I I TVD: 17,190' I Rig: I Nabors 9ES I Operating days to complete: 114.1 I BF/MS: 135.8' I I RKB: 64.3' I Well Design (conventional, slimhole, etc.): I Ultra Slimhole Longstring I Objective: I Kuparuk Formation Mud Program: 12-1/4" Surface Hole (0-3040'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.1 300 75 12 12/25 NC Interval TD 9.1-9.6 65 20-25 22-25 19/55 NC 8-3/4" Upper Intermediate Hole (3040' - 7300'): Freshwater LSND Interv;~l' Density Viscosit~ YP 'PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 42-52 15-25 10-19 9.0-9.5 6cc <14 shoe to to by HRZ HRZ <5 8-3/4" Production Zone (7300' - 8119') GEM + 6% KCl Interval Density ~iscosity Y'P PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.5 40-50 18-25 12-18 9.0-9.5 <5 <9 Hole REC;EIVED S-105 Permit to Drill ~laaKa Oil & Gas CONS,, Anchorage Page 1 To: Blair Wondzell, AOGCC Date: September 25, 2000 From: Phil Smith Subject: Dispensation for 20 AAC 25.035 (c) on Aurora S-105 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent three Aurora wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first three surface holes for the Aurora development (S-100, S-101, and S-102) were drilled to the shale underlying the SV-1 sands; S-105 is planned to TD in the shallower SV-3 shale. The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is _+500' TVD above the Ugnu horizon. The shallowest RFT point recorded in the area is from SB-01, recording a pore pressure of 1,555 psi at 3,195' TVDss (9.36 ppg EMW). S-105 is planned to reach 9.6 ppg mud weight before TD at 2,800' TVDss: This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Your consideration of the waiver is appreciated. Sincerely, Phil G. Smith ADW Engineer 564-4897 RECEIVED SFP 000 Oil &' Gas C0~s. CommiJ~ion 0 5OO 1000 50O >~.,2000 250O 3OOO 3500 40OO Aurora Surface Hole Mud Weight MW (ppg) 8 8.5 9 9.5 10 -e"S'100 --a-S-101 -.=- S.105 Plan ~ Pore Pressure ! PGS 9/22/2000 S-105 Drilling Permit Directional: KOP: 11000' Maximum Hole Angle: Close Approach Wells: 35 2500' MD Intermediate hole at None (first well at north end of new S pad gravel) Logging Program: Surface Intermediate / Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD + MAD pass Kuparuk & Cuttings Gas & Samples Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 1800 SV3 / T5 2698 SV1 3195 Ugnu top (UG4A) 3583 Unknown, 10.5 ppg MW required on SB-01 Schrader (Mb1 Sand) 4788 8.96 ppg EMW (pore pressure = 2230) Schrader (Na Sand) 4934 9.40 ppg EMW (pore pressure = 2412) Schrader (Oa Sand) 5058 9.16 ppg EMW (pore pressure = 2410) Base Schrader (Obf) 5380 HRZ top 6533 . HRZ Base 6690 Kuparuk C4B 6707 Top Target 9.89 EMW (pore pressure = 3450) Kuparuk C4A 6730 Kuparuk C3B 6739 Kuparuk C3A 6777 Base Target Interval Kuparuk C2 6828 Kuparuk Cl 6838 Kuparuk B, LCU 6859 Kuparuk A 6919 Miluveach 6983 TD TD S-105 Permit to Drill Page 2 Casinq/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC-M 3011' GL 3040'/2866' 8-3/4" 7" 26# L-80 BTC-M 8090' GL 8119'/7190' Tubing 3-1/2" 9.3# 13-Cr Fox -8408' GL 7650'/6700' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casin(, Basis: Size 1 9-5/8" Surface I Lead: Based on 1900' of annulus in the permafrost @ 100% excess and 532' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2430' MD (2365' TVDbkb). Lead 251 bbl / 1409 ft~ / 317 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 50 bbl / 281 ft~ / 242 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Basis: Size 17" Intermediate I Lead: to 10 aA" surface casing shoe (above the Ugnu 4A Formation) and 30% excess Lead TOC: 3500' MD ITotal Cement Volume: Tail: Based on TOC 1000' above top of Kuparuk R. formation and 30% excess + shoe Tail TOC: 6675' MD, 5858' TVDbkb I Lead I 111 bbls / 623 ft~/223 sks of Dowell Extended blend at 1 11.5 ppg and 2.79 cf/sk. Tail 153.5 bbls / 300 ftc/260 sks of Dowell Premium 'G' at 1 15.8 ppg and 1.16 cf/sk. S-105 Permit to Drill Page 3 Well Control: 20" 1000 psi diverter employed on surface hole. Waiver request to drill the surface hole on S- 105 without diverter installed was submitted to the AOGCC on 9/25/2000. For intermediate hole drilling, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: 3435 psi @ 6700' TVDss - Kuparuk Target Top 2765 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 8.6 ppg KCI / seawater / NaBr Brine / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · S-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad has been 60 ppm (S-37, 12/2/98) DRILLING CLOSE APPROACH: Close approach issues are not expected at this time or will be mitigated in the final well plan. S-105 Permit to Drill Page 4 SURFACE HOLE SECTION: · Directional control was an issue in the S-100 and S-102 surface holes. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · The surface hole interval on S-Pad has been relatively problem free on most wells to date. Only one well (S-22, 1990) is recorded with lost circulation problems. S-22 experienced lost circulation while drilling and cementing both. · Some tight hole has been noted while running casing, in particular with 13-3/8" casing in 16" hole. All three Aurora wells on S-pad have experienced some degree of tight hole while drilling and casing the surface hole. Conditions have improved each well as mud and drilling parameters become fine-tuned. · No faults are mapped in the direction of the well plan · Heavy clays are reported in the 2000-3000' TVD area of S-pad. · .Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- 40 required 9.3 ppg mud to drill this interval. ~c~ c.\_ INTERMEDIATE/PRODUCTION HOLE SECTIONS: · The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8-3/4" hole. The first three Aurora wells covered the SV1 sand with he surface casing to mitigate differential sticking hazards across the sand. Due to the Iow hole angle through the HRZ, a lower mud weight will be required to provide well bore stability, thus minimizing the risk of differential sticking. · The closest mapped fault is approximately 600' away from the planned target coordinate at the top of Kuparuk, converging to 320' from the plan at TD. Adequate standoff will be maintained to avoid fault-related lost circulation problems and seismic uncertainty (_+100'). · Gas cut mud occurred in a relatively nearby well (S-03) at 5713' TVD. Mud weight was increased from 10.1 ppg to 10.3 ppg to handle the problem. S-100 experienced traces of oil at the top of the Ugnu. For this reason the 7" casing will be cemented to 500' above the UG4A. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-105 Permit to Drill Page 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is scheduled to be set Sept 2~h, 2000. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. Operations: MIRU Nabors 9ES. Nipple up diverter spool (with blinded outlet) and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 ~" drilling assembly and drill surface hole to approximately 3040' MD / 2866' TVD. The actual surface hole TD will be +/-100' TVD below the SV1 sand top (30' below the sand base). 4. Run and cement the 9 5/8", 40# surface casing back to surface. A TAM port collar will be positioned at +1000' as contingency in the event cement does no fully circulate to surface. 5. ND diverter spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 9 7/8" drilling assembly and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a LOT. 8. Drill per directional plan to top of Kuparuk and change mud system to 6% KCI GEM. Continue drilling 8 ~" hole to 150' below the base of Kuparuk A sands. TD: 8119' MD / 7190' TVDbkb. POOH, lay down 4" DP. 9. Run 7" 26#/ft long string casing to TD and cement to 500' above the Ugnu UG4A formation, set on mandrel hanger. Displace cement with clean Seawater. Bump plug to 3500 psi, check floats. 10. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000' TVD by bullhead method. 11. Run 3-1/2", 9.3# 13-Cr completion string. See attached completion schematic for details. 12. Freeze protect tubing and annulus with 2000' diesel. 13. Set production packer and test tubing and annulus to 3500 psi. 14. Install two-way check and test to 3500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Pull two-way check and Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 10/16/2000 Phil G. Smith Shared Services Drilling 564-4897 smithpgl@BP.com (Oct 1-15 contact Allen Sherritt 564-5204) S-105 Permit to Drill Page 6 S-105 Ri site Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Mud weights in excess of 10.4 ppg can be expected. The surface holes on S-100, 101 and 102 were drilled with 9.6- 9.7 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700' and 2850' TVDbkb, however there were no associated complications. Lost circulation while drilling has not been a problem in the first three wells of the Aurora development, despite several fault crossings. The closest known fault is 600' from the well plan near the top of the Kuparuk on S-105; lost circulation is not considered a likely hazard. Pipe sticking tendency is possible if the HRZ shale gives problems. S-100i and S-101i HRZ conditions where normal, back reaming at connections and good hole cleaning practices contributed to the good hole conditions. The 7" intermediate casing strings on S-100 and S-101 went to bottom without any difficulty. The Ugnu interval on S-100i and S-101 contained hydrocarbons. Triple combo LWD tools were used to mad pass the interval. Cement will need to be brought minimum 500 feet above the Ugnu formation. The surface casing will be set higher in this well than the previous three Aurora wells. The higher casing point will leave the SV1 sands exposed while drilling the 8-3/4" section, increasing the risk of differential sticking. pad is not a designated H2S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Aurora S-105 Hazards and Contingencies Page ]. of I sper',r', -sunI ORIL. LIN~, S~RVlC~=S Shared Services Drilling S-105 Wp 07 Prelx~,al Data for S-105 Wp 07 vertleN Odgln:S.1OS WPS (EX-12) I-le~l~nlal O~gln: 5-1 OS WPS (EX.12) Meaaummant Units: No;th Relstmnce: Trust North Dogleg seventy: Oegme~ per Vertical Sectlofl Azln'ul~: 2.720' Veflico] Sec~on Desct'~llon:$.l OS Wp O? Vmtlcal ~ectlofl Odgin: 0.00 N,O.00 E Idlll~rld I~cl. A]Jm, Vlrticll Nol~lllgl EiIIlflgl o.oo o.ooo o.91o o.oo o.oo N o. oo Eo.oo l(~0.oo 0.o0o 0.910 Io00.o0 o.00 N o.00 E 0.00 0.000 I 150.00 1.500 "720 1149.98 1.96 N 0.09 E 1.96 l.O00 1300.00 4.$00 2.720 1299.76 9.80 N 0.47 E 9.81 2.000 14~0.00 8.250 "720 1448.81 26.44 N 1.26 E °.6A7 I~q10.45 17.261"720 I S00.00 lOS.S:; N ~.03 E lOS.g7 1910,45 17.26t2.720 1st95.49 135.49 Iq 6.44 E 135.~4 0.000 2493.85 34.763'*720 ~17.76 3~0.07 N IR.$3 E390.:513.000 620O.92 ~.763 2.720 .';619.262609.62 N 123.9X F, ~12..';7 0.000 7375.14 20.0002.720 6490,79 30~0.53 N 145.41 E 3063,971.$00 7675.14 20.0002.730 67'/2.70 3163.01 N 150.28 E 3166.$80.000 7968.t~5 20.0002.730 7048.90 3265.36 N 155,04 E 3~67.040.000 8118.85 20.000~-730 7189.65 3314.60 N 157.48 E .~318.34 900 1800 2700 -~ 3600 ._ 4500 5400 6300 O O '- 7200 .. in Dir @ 1.000°/100ft: 1000.00ft MD, 1000.00ft TVD 3200 Dir Rate @ 2.000°/100ft: 1150.00ft MD, 1149.98ft TVD in Dir Rate @ 2.500°/100ft· 1300.00ft MD, 1299.76ft TVD in Dir Rate @ 2.500°/100ft· 1450.00ft MD, 1448.81ft TVD Dir: 1810.45ft MD, 1800.00ft TVD in..Dir.@. 3.000?/l.00ft.:.1910.45ft.M,,D.,!.1895.49ft TVD 2400 i,~6.q. 70 Oir .: 2493.85ft MD, 2417.76ft TVD .-- ............... 9 s/8" c~tg.g' ............................. ~0 1600 2866.39 ,~'W/I'~. Z 376&70 SV, I/Tit 3260.70 ............. ~'/t~k)o',~' ........... 800 36,'/3. 70 Begin Dir @ 3.000°/100ft: 1910.45ft MD End Dir: 1810.45ft MD, 1800.00ft Increase in Dir Rate @ 2.500°/1( 1450.00ft MD, 1448.81ft TVD Increase in Dir Rate 1300.00ft MD, 1299.76ft TVD ,..s~.~ ................................ ...... ................................................. 6',~ PZ'~:~'r;~ie ;:&} ......... 499~,.?o ........................ S;2& ?0 DrillQuest Current Well Properties Well: Horlz~nloJ Coordinates: Ref. Global Coordinates: Ref. Structtxe Reference: Ref. aeograpNoal Coordinates: RKB Elevation: S-los WPS (EX-12) 6980835.00 N, 618929.96 E 37,32 S, 1012.78 E 70' 21' 22.6533' N, 149° 02' 02,8270' W 65.701t above Mean Sea Level 65.701t abovo Structtre Roforeme North Reforemo: True North Ur,Its: Feat Eastings 0 7" Casing 8118.85 MD ./" 7189.65 TVD - . 3200 ~o~t~- Dir: 7375.14ft MD, 6490.79ft , ~E ~ Dir @ 1.500°/100ft' s, oo.~ (.~ MD, 5619.26ft TVD -- 2400 4g~ 0.O 430 h01 - 1600 1=: o Z STOO ~ 31oo 9 5/! r r 303,c .95 MD 286{ .39 TVD D~/D ~En( Dir: 2493.85ft MD, 2417.76ft TV ~ Increase in Dir Rate @ 2.000°/1 /~ 150.00ft MD, 1149.98ft TVD Begin ~ir @ 1.000°/100ff: lO00.OOff M 0 Scale: linch = 800ft Eastings ;, ....... _ egn Dtr@15 · . ..'4.,~.?o ~'~.6~320.92ft MD, ~6"1~9::~)~'~/D ,~ __...._ ~ ~b W., T... ~. ~r S-lO5 WPS (=.12) - ' ] ~ ~End Dir: 7375.14ft MD, ~6490.79ft TVD .... ~,s2~.~q ................................. ~ ;?.".'.':'. "'/." ::::::::::::::::::::::::::::::: ;;;~;~;~ff~:;:~:.::4~.~Z~:~::~5..;..:.,.~.~..;..:.;~ .:?:.. :. .' : :~. ~.:~..:...:.~,. ........................ . ......... ) ............ ~Sa .... ~t,.¢'9~ .............. ~¢g~ ................ ~X ........ . .................... ................. ~'] ....... Cv ........ ~: 2~.~0' '~Nc~.,e ....................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: g::::::::~9,:,~::~t~'~::z:::. _ _ /o;s.,,o ~04a~o ........... "'" ~ 8~nS. SSMD 71~.65 ~ I I I 0 900 1800 2700 Scale: linch = 900ft Section Azimuth: 2.720° (True North~ Vertical Section Prepared: ' rheoRed: rpproved: SpeL y-Sun Drilling S '.'vices Proposal Data - S-105 WPS (EX-12) - S-105 Wp 07 .= '-i:~-::(ft):;!.!'.::M.i~:(~t):-".I ,::.---{~i: ;; .-¢(.-~...--.:.:::::--(~t):::~;: TVD:(ff).! (ft).'i i,:,!. (ft): -(Oll'OOft) .... :(o)~--~--::~.'(fi):. : - _ , ,..::.. . ' ..-. . : . ~ .. - -:::'i';':;Io.oo ':'::'=::--'~i:-':?!: o.ooo .'.L:~.~o.ooo o.oo 'i ?-:.' o.ool o.oo ~-. ::::. :' ~":?': :!? .'-~. :. ---:': O.QO "'"~:::~ilOOO.OO -'mOO:OO .:. ~;o:i:~:)O i:.'<::!O'.oo0 :::!o0o:0o 'mOo,.=O~ . i': '-omo . "0.oo o.ooo - -- O:.OOe-!:':: ~. o.o0 ~ ,!3.. :i .~...1;1_50.~ _00 150.00 ~:;: il .500 :!,; ::'~:_2~-7_2Q, :i;.~1-i.4.9.9B, :-i '..1~9,_98 -,,-::~;. ;:1.96~N ;-' :::-. O.09..E 1.000 2.720 ......... 1.96 _ . . :' 4:!.i-i-:13~X).00 150.00 ::.4.5001'~: ;: 217.20. ;:..:1299:76 : ;-149;7.8 :' .:9'.80N : 0,47'E 2.000i 0.000 - 9.8~ :!$-:~i::--'1~150-:~ 150.00 ,~.:--j~:25~ ?' !-'2:-720'~ ?~44B'.81: :-;:L:1.49;~1~i -;:'::-.:.:26.44!N -:-::-: 1i'2~-E 2.500i 0.000 ~-.--:--. 2~.47 -:'.6'-!:';::18!0:_,i5 ~::3.60;45:,~17_~.61'~-.-'.::2.720' 1800.00 .:-'":35:1.i9 :::;-:~?I05.~:N !L!~:!:;.:': !9.10:45 100.00 ;'¥'1~;261 i?:i~'--'.2;720, ii'.1895i_49 ;:::.!.: 95~,;49 i !~:.135;49r-N ~ . . ,' RECEIVED Alaska Oil & Gas Cons. CommissiO~ Anchorage 21 September, 2000- 11:01 - 1 - Dr/I/Quest North Slope Alaska Alaska State Plane 4 PBU WOA S Pad S-105 WPS (EX-12)- 07 PROPOSAL T 21 Surface Coordinates: E (70° 21' 22.6533" N, 149° 02' 02.8270" W) Mean Sea Level Proposal Reft pro10430 Sperry-Sun Drilling Services Proposal Report for $-105 WPS (EX-12)- S-105 Wp 07 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) 0.00 0.000 0.000 -65.70 100.00 0.000 0.000 34.30 200.00 0.000 0.000 134.30 300.00 0.000 0.000 234.30 400.00 0.000 0.000 334.30 500.00 0.000 0.000 434.30 600.00 0.000 0.000 534.30 700.00 0.000 0.000 634.30 800.00 0.000 0.000 734.30 900.00 0.000 0.000 834.30 1000.00 0.000 0.000 934.30 1100.00 1.000 2.720 1034.29 1150.00 1.500 2.720 1084.28 1200.00 2.500 2.720 1134.25 1300.00 4.500 2.720 1234.06 1400.00 7.000 2.720 1333.55 1450.00 8.250 2.720 1383.11 1500.00 9.500 1600.00 12.000 1700.00 14.500 1800.00 17.000 1810.45 17.261 1879.25 17.261 1900.00 17.261 1910.45 17.261 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 1432.51 1530.74 1628.07 1724.31 1734.30 1800.00 1819.81 1829.79 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5980835. 618929.96 E 100.00 0.00 N 0.00 E 618929.96 E 200.00 0.00 N 0.00 E 618929.98 E 300.00 0.00 N 0.00 E 618929.96 E 400.00 0.00 N 0.00 E N 618929.96 E 500.00 0.00 N 0.00 5.00 N 618929.96 E 600.00 0.00 N N 618929.96 E 700.00 0.00 N 0.00 .00 N 618929.96 E 800.00 0.00 N 35.00 N 618929.96 E 900.00 0.00 N 5980835.00 N 618929.96 E 1000.00 0.00 N 5980835.00 N 618929.96 E 1099.99 E 5980835.87 N 618929.99 E 1149.98 E 5980836.96 N 618930.02 E 1199.95 3.70 N 0.18 E 5980838.71N 618930.08 E 1299.76 9.80 N 0.47E 5980844.81 N 618930.27 E 1399.25 19.81N 0.94 E 5980854.82 N 618930.59 E 1448.81 26.44 N 1.26 E 5980861.45 N 618930.80 E 1498.21 34.14 N 1.62 E 5980869.16 N 618931.04E 1596.44 52.77 N 2.51E 5980887.80 N 618931.63E 1693.77 75.66 N 3.59 E 5980910.71N 618932.35E 1790.01 102.77 N 4.88 E 5980937.84 N 618933.21 E 1800.00 105.85 N 5.03E 5980940.92N 618933.31E 1865.70 126.24 N 6.00E 5980961.32N 618933.95 E 1885.51 132.39 N 6.29 E 5980967.47N 618934.15 E 1895.49 135.49 N 6;44E 5980970.57 N 618934.25E Dogleg Rate (~100ff) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.000 1.000 2.000 2.000 2.500 2.500 2.500 2.500 2.500 2.500 2.500 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.87 1.96 3.71 9.81 19.83 26.47 34.18 52.83 75.75 102.89 105.97 126.38 132.54 135.64 Comment Be~in Dir @ 1.000°/100ft: 1000.00ft MD, 1000.00ft TVD Increase in Dir Rate @ 2.000°/100ft: 1150.00ft MD, 1149.98ft TVD Increase in Dir Rate @ 2.500°/100ft: 1300.00ft MD, 1299.76ft TVD Increase in Dir Rate @ 2.500°/100ft: 1450.00ft MD, 1448.81ft TVD End Dir' 1810.45ft MD, 1800.00ft TVD B Permafrost Be~in Dir @ 3.000°/100ft: 191'0.45ft MD, 1895.49ft TVD Continued,., 21 September, 2000 - 11:03 - 2 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for $-105 WPS (EX-12) - S-105 Wp 07 North Slope Alaska Measured Depth (ft) Incl. 2000.00 19.948 2100.00 22.948 2200.00 25.948 2300.00 28.948 2400.00 31.948 2493.85 34.763 2500.00 34.763 2600.00 34.763 2700.00 34.763 -2800.00 34.763 2900.00 34.763 2914.95 34.763 3> 3000.00 34.763 ~ 3039.95 34.763 '" ;;;1 oo.oo :.o rl oo.oo G3 -O · {[~00.00 34.763 I~1~00.00 34.763 oo.oo ~00.00 34.~a · ~00.00 ~.7~a ~' ~870.50 ~.7~ m ~000.00 ~.7~8 Azim. 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 Sub-Sea Depth (~) 1914.66 2007.72 2098.74 2187.48 2273.68 2352.06 2357.11 2439.26 2521.41 2603.57 2685.72 2698.00 2767.87 2800.69 2850.02 2932.17 3014.32 3096.47 3178.63 3195.00 3260.78 3342.93 3425.08 3483.00 3507.23 Vertical Depth (ft) 1980.36 2073.42 2164.44 2253.18 2339.38 2417.76 2422.81 2504.96 2587.11 2669.27 2751.42 2763.70 2833.57 2866.39 2915.72 2997.87 3080.02 3162.17 3244.33 3260.70 3326.48 3408.63 3490.78 3548.70 3572.93 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 164.02 N 7,79 E 5980999.~ 618935.15 E 200.54 N 9.53 E 59810~ 618936.30 E 241.88N 1-1.49E 59~.03ff~ 618937.61E 287.91N 13.68E 5~J~2~10N~618939.07E 338,53 N 16.08 E ~4 N ~ 618940.67 E 390.07N 18.53 598,~25.31N 618942.30 E 393.57 N 18.70 228.82 N 618942.41 E 450.52 N N 618944.21E 507.48 N N 618946.01E 564.43 N i981399.79N 618947,81E 5981456.78 N 618949.61E 5981465.30 N 618949.88 E 5981513.77 N 618951.41E 5981536.54 N 618952.13 E 5981570.76 N 618953.22 E 5981627.75N 618955.02E 5981684.74 N 618956.82E 5981741.73 N 618958.62 E 5981798.72N 618960.42 E 5981810.08 N 618960.78E 5981855.71N 618962.22 E 5981912.70 N 618964.02E 5981969.69 N 618965.83 E 5982009.87 N 618967.10 E 5982026.68 N 618967.63E E E 33.31 E 735.30 r 34.93 E 792.25 N 37.64 E 849.21N 40.35E 906.16 N 43.05E 963.11N 45.76E 974.47N 46.30 E 1020.07N 48.46 E 1077.02N 51.17 E 1133.98 N 53.88 E 1174.13 N 55.78 E 1190.93 N 56.58 E Dogleg Rate (~100ff) 3.000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad VeAical Section (fi) 164.21 200.77 242.15 288.24 338.91 390.51 394.01 451.03 508.05 565.07 622.09 630.61 679.11 701.89 736.13 793.14 850.16 907.18 964.20 975.57 1021.22 1078.24 1135.26 1175.46 1192.28 Comment End Dir: 2493.85ft MD, 2417.76ft TVD SV3/T5 9 5/8" Casing SVl/T3 UG4/K15 Continued,,, 21 September, 2000 - 11:03 - 3 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-105 WPS (EX-12) - S-105 Wp 07 North Slope Alaska Measured Depth Incl. (ft) 3992.23 34.763 4000.00 34.763 4100.00 34.763 4200.00 34.763 4300.00 34.763 4400.00 34.763 4500.00 34.763 4600.00 34.763 4700.00 34.763 4800.00 34.763 4900.00 34.763 5000.00 34.763 5100.00 34.763 5200.00 34.763 5300.00 34.763 5400.00 34.763 5459.03 34.763 5500.00 34.763 5600.00 34.763 5636.75 34.763 5700.00 34.763 5787.69 34.763 5800.00 34.763 5900.00 34.763 6000.00 34.763 6100.00 34.763 6179.65 34.763 6200.00 34.763 6300.00 34.763 6390.92 34.763 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 Sub-Sea Depth (ft) 3583.00 3589.38 3671.53 3753.69 3835.84 3917.99 4000.14 4082.29 4164.44 4246.59 4328.75 4410.90 4493.05 4575.20 4657.35 4739.50 4788.00 4821.65 4903.81 4934.00 4985.96 5058.00 5068.11 5150.26 5232.41 5314.56 5380.00 5396.71 5478.87 5553.56 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3648.70 1243,46 N 59,08 E 5982079, 618969.29 E 3655.08 1247,89 N 59.29 E 618969,43 E 3737.23 1304.84 N 61.99 E 618971.23 E 3819.39 1361,80 N 64.70 E 618973,03 E 3901.54 1418.75 N 67.41 E 618974.83 E 3983.69 1475.71 N 70.11 ~: ...... 1.63 N 618976.63 E 4065.84 1532.66 N 72.82,~',ilE'!i, N 618978.43 E 4147.99 1589.61 N 75.52 El; N 618980.24 E 4230.14 1646.57 N ,,,,,n,:;i:~,8~ ,2, 3 E 618982.04 E 4312.29 1703.52 N ,,,,,'~;I; ,:!,,i'"~8~B E 5982539.59 N 618983.84 E 4394.45 1760.48 N "'"="';="" ""'" 4476.60 1817.435 5982653.57 N 618987.44 E 4558.75 1874.~L/~ ; E 5982710.56 N 618989.24 E 4640.90 1931.3i~ 91.76 E 5982767.56 N 618991.04 E 4723.05 1988.301~ 94.46 E 5982824.55 N 618992.85 E 4805.20 2045.25 N 97.17 E 5982881.54 N 618994.65 E 4853.70 2078.87 N 98.77 E 5982915.18 N 618995.71 E 4887.35 2102.21 N 99.88 E 5982938.53 N 618996.45 E 4969.51 2159.16 N 102.58 E 5982995.52 N 618998.25 E 4999.70 2180.09 N 103.58 E 5983016.46 N 618998.91 E 5051.66 2216.11 N 105.29 E 5983052.51 N 619000.05 E 5123.70 2266.06 N 107.66 E 5983102.48 N 619001.63 E 5133.81 2273.07 N 107.99 E 5983109.50 N 619001.85 E 5215.96 2330.02 N 110.70 E 5983166.49 N 619003.65 E 5298.11 2386.98 N 113.41 E 5983223.48 N 619005.46 E 5380.26 2443.93 N 116.11 E 5983280.47 N 619007.26 E 5445.70 2489.30 N 118.27 E 5983325.86 N 619008.69 E 5462.41 2500.89 N 118.82 E 5983337.46 N 619009.06 E 5544.57 2557.84 N 121.52 E 5983394.45 N 619010.86 E 5619.26 2609.62 N 123.98 E 5983446.26 N 619012.50 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~) 1244.86 1249.29 1306.31 1363.33 1420.35 1477.37 1534.39 1591.41 1648.43 1705.44 1762.46 1819.46 1876.50 1933.52 1990.54 2047.56 2081.22 2104.58 2161.60 2182.55 2218.61 2268.62 2275.63 2332.65 2389.67 2446.69 2492.11 2503.71 2560.73 2612.57 Comment UG4A/Top Ugnu Top Schrader/MB1 WS2/Schrader Na WSl/Schrader Oa Base West SaldBase Obf Be_qin Dir @ 1.500°/100ft: 63~o.92ft M[~, 21 September, 2000 - 11:03 - 4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-105 WPS (EX-12) - S-105 Wp 07 North Slope Alaska Measured Depth Incl. (ft) 6400.00 34.627 6500.00 33.127 6600.00 31.627 6700.00 30.127 6800.00 28.627 6900.00 27.127 7000.00 25.627 7100.00 24.127 7200.00 22.627 7300.00 21.127 7375.14 20.000 7400.00 20.000 7489.97 20.000 7500.00 20.000 7600.00 20.000 7657.05 20.000 7675.14 20.000 7699.61 20.000 7700.00 20.000 7709.19 20.000 7749.63 20.000 7800.00 20.000 7803.90 20.000 7814.55 20.000 7836.89 20.000 Azim. 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 2.720 Sub-Sea Depth (~) 5561.02 5644.04 5728.50 5814.32 5901.46 5989.85 6079.44 6170.16 6261.95 6354.74 6425.09 6448.45 6533.00 6542.42 6636.39 6690.00 6707.00 6~0.00 6~0.36 6~9.00 6777.00 6~4.33 6~8.00 6838.00 6659.00 Vertical Depth (ft) 5626.72 5709.74 5794.20 5880.02 5967.16 6055.55 6145.14 6235.86 6327.65 6420.44 6490.79 6514.15 6598.70 6608.12 6702.09 6755.70 6772.70 6795.70 6796.06 6804.70 6542.70 6890.03 6893.70 6903.70 6924.70 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2614.79 N 124.23 I= 5983451., 619012.66 E 2670.46 N 126.87 E 619014.42 E 2723.95 N 129.42 E 619016.11 E 2775.21 N 131.85 E 111.96 N'"'?;;i;'.:~619017.73 E 2824.21 N 134.18 E N .... ~'....i. 619019.28 E 2870.91 N 136.40 N 619020.76 E 2915.29 N 138.51; N 619022.17 E 2957.31 N 140.50 N 619023.49 E 2996.94 N N 619024.75 E 3034.16 N 5963871.07 N 619025.92 E 3060.52 N 5983897.45 N 619026.76 E E 5983905.94 N 619027.03 E E 5963936.70 N 619028.00 E 3103.1 147.43 E 5983940.13 N 619028.11 E 3137.34 N 149.06 E 5963974.31 N 619029.19 E 3156.83 N 149.98 E 5963993.82 N 619029.80 E 3163.01N 150.28 E 5984000.00 N 61903~00E 3171.37 N 150.67E 5984008.37N 619030.26 E 3171.51N 150.68 E 5984008.50 N 619030.27 E 3174.65 N 150.83 E 5984011.64 N 619030.37 E 3188.46 N 151.48 E 5984025.47 N 619030.80 E 3205.67 N .152.30 E 5984042.68 N 619031.35 E 3207.00 N 152.37 E 5954044.02 N 619031.39 E 3210.64 N 152.54 E 5984047.66 N 619031.51 E 3218.27 N 152.90 E 5984055.30 N 619031.75 E Dogleg Rate (°llOOfl) 1.500 1.500 1.500 1.500 1.500 1.500 1.500 1.500 1.500 1.500 1.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~) 2617.74 2673.48 2727.02 2778.34 2827.40 2874,15 2918.58 2960.65 3000.32 3037.58 3063.97 3072.48 3103.25 3106.68 3140.88 3160.39 3166.58 3174.95 3175.08 3178.23 3192.06 3209.29 3210.62 3214.26 3221.90 Comment End Dir: 7375.14ft MD, 6490.79ft TVD THRZ BHRZ KUD C4B ~-1,0.5 9-~:00, T .arg,et, 150.00 Haolus., ~eologlcal C4A C3B C3A C2 C1 Kup B/LCU Continued... 21 September, 2000 - 11:03 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-105 WPS (EX-12) - S-105 Wp 07 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 7900.00 20.000 2.720 6918.30 7900.74 20.000 2.720 6919.00 7908.19 20.000 2.720 6926.00 7931.61 20.000 2.720 6948.00 7968.85 20.000 2.720 6983.00 8000.00 20.000 2.720 7012.27 8100.00 20.000 2.720 7106.24 8118.85 20.000 2.720 7123.95 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 6984.00 3239.83 N 153.93 E 5984076., 619032.43 E 6984.70 3240.09 N 153.94 E 619032.44 E 6991.70 3242.63 N 154.06 E 619032.52 E 7013.70 3250.63 N 154.44 E 619032.77 E 7048.70 3263.36 N 155.04 E N 619033.17 E 7077.97 3274.00 N 155.55 1.05 N 619033.51 E 7171.94 3308.16 N N 619034.59 E 7189.65 3314.60 N 157.48 .68 N 619034.79 E All data is in feet unless otherwise stated. Directions and coordinates are Vertical depths are relative to S-105 WPS (EX-12). Northings and orth. S-105 WPS (EX-12). Dogleg Rate (°ll00fl) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 3243.49 3243.74 3246.29 3254.30 3267.04 3277.69 3311.89 3318.34 Comment Kup A6 Kup A5 Kup A4 Miluveach/Bae Kuparuk Total Deoth: 8118.85ft MD, 7189.65ft TVD 7" Casing The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-105 Wp 07 and calculated along an Azimuth of 2.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8118.85ft., The Bottom Hole Dis~cement is 3318.34ft., in the Direction of 2.720° (True). Continued... 21 September, 2000 - 11:03 - 6 - DrillQuest 1.05.05a TREE: 4-1/16 "- 5M CIW Stainless WELLHEAD: 11" - 5M FMC Ultra SH Gert 5 9-5/8" TAM Port Collar S-105 Proposed Completion 4-1/2" 12.6# 13Cr-80, single joint Cellar Elevation = 35.8' Nabors 9ES Floor = 64.3' 3-1/2" 'X' Landing Nipple with 2.75" seal bom. I 2100' 3-1/2' Camco Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS # TVDss Size Valve Type -- 1 3700 1 1/2" RP Shear 2 5800 1 1/2" DV 3 2 jts above I 1/2" DV packer 3-1/2" 9.2# 13Cr-80, Fox Tubing 3-1/2" 'X' Landing Nipple with 2.75" seal bom. 7' x 4-1/2" Baker 'S-3' Production Packer with crossover pups to 3-1/2" 3-1/2" 'X' Landing Nipple with 2.75' seal bore. 3-1/2" WimLine Entry Guide 7", 26 #/ft, L80, BTC-Mod Date 9/22/2000 Rev By Comments PGS Proposed Completion AURORA WELL: S-105 APl NO: 50-029-22### BP Alaska Drilling & Wells Diverter Exception Request S-105 (200-152) f. Subject: Diverter Exception Request S-105 (200-152) Date: Fri, 13 Oct 2000 16:07:08 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Phil Smith <smithpgl@bp.com>, Dan, st CC: Blair Wondzell <blair._wondzell@admin.state.ak. us>, Bob Crandall <bob_crandall@admin.state.ak. us>, Steve Davies <steve_davies@admin.state.ak. us> Dan and Phil, Bob Crandall and I have been reviewing your request to drill surface hole on the subject well without a diverter system. In support of your request, you submitted mud weight information from the 3 recent Aurora wells. An RFT point from SB-01 (V-200) was also provided. In further discussions with Allen Sherritt, we requested copies of any surface hole mud logs from the S pad area. A copy of the SB-01 mud log was submitted. Unfortunately the mud log does not cover the surface hole of that well. No other mud logs from the S pad area have been found. After review of the above information and the caution concerning hydrate gas in the S-102 surface hole, we find that we do not have sufficient information to grant your request. In discussion with Allen, we were informed that you are taking continuous gas readings from your mid intermediate hole to TD. If it is possible to take such readings through the surface hole of S-105 and present that information versus depth in conjunction with the MVVD GR and ROP, it is likely that you will develop sufficient information to allow consideration of this request on subsequent Aurora wells. Please contact myself or Bob Crandall (793-1230) with any questions. Tom Maunder Petroleum Engineer t'"'"~om Maunder <tom maunder~,admin.state.ak, us> ! ~le--~m ~eer Alaska Oil and Gas Consentation Commission 1 of 1 10/13/00 4:07 PM / DATE / CHECK NO. ~0173373 · VENDOR i~LI~ ~l~i~l~l=i I ~ I i U DATE INVOKE I CRED~ MEMO DESCRI~ION G~ DIS;U; N~ )B2200 :KO~2200E 100. O0 100. O0 HANDL~ qO ZNST: TERR [E HUBBLE X4& ~B : ~-los ... IE *~ACHED CHECK · IN PAYME~ ~R ~m D~RIBED ABOVE, ~ X OO. OO 1 OO. OO i~!.;--:' :'""~;i::;'ii;~!:!.'-: :?i--ii:i~-:" :;'.~;;ili;i:;--'-;::i~: .... ,::/4? -"~'!~:;-:?:? ,i!"'-i!~. ,.. . . ~Ay:' . ;-;"-:'.::.'-': --':.::i" ..-:A~X~AT~.~." .. :-:~....'-"-Y-'-:..- · ' ..... ~':' '~;:::::i.-----::':--' ,.'.i.-,~,~c~:~,~,,~, -.:~'.-.:-:~ :~-.-.-.-'- - -.::.::-':"-.:.:;!-?.- _:QCEVEI,,~qD,-dRIO .?.::..:.- ::"?" :i;:;i;::.;;::.' ';"..~i;.'..-i~i~:~,:..,!:-i::-. :.:i!ii::(:::? ' ';;~'OX..7~:~3:.ii.ii-:ii, :~.i-:~-'.:!i:':;"" · 4:!~.' :- "' . . . - . . ::. ::;. -:~-..-:=: ~.::? . '~:i¢i~:i:.::' ~-:~::ii,:-.:.::?!i,::--:;i:.:~! ~-;;;i:;!;~i~'-'~: . [:,^~r,=.. ;::!:;i;::; '"-:::;:;:-:.?'~' :;";-:': "" .... '¥ ....... /' o.~.~o0..-. ['-':.' 'l"' .... ,,oo. ooI · ~r(¢:::' :F'.-'-'.::.; - ..-'-;:-:.'-~i:!'.. :!..(.C-r-N~.-N, adJo aFm~ ~o D~¥$ ;/- ,.::::'?.:'--'k 4?.": :'-:::::."..:..:~. '!?" :?- :i~i: :?il !'!?~'"" '. '"'!;~!~? ,;?-'ii:i;_ ::i-:i;:i: :-~: '?' '"'-::~:.~i::.:::-'-:.'~; . :. !.;;:.!; ::'"':i:.~/~?1. . '-'"::..; :"-:~tli:"'"'.i~:' ..-:--:;:!;i? .... . ........... iWELL PERM~IT FIELD & POOL ~ ~ CLASS .'~---, / /'//'~/! ~ ~_--:~T~ ~-'~'~'~ ~ ~ ~~,,,,. u,~pu=~a, para r_eq ....--_ ADMINISTRATION 1 Permit fee attached. N ' ~.E>; ON/OFF SHORE ~ . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. ENGINEERING 14. Lease number appropriate ................... Unique well name and'number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... N N 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 ............. II A4:~.RR__ .DAT. E ' 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet.regulation ................ 26. DOPE press rating appropriate; test to . "4.~'~<..~ psig. 27. Choke manifold complies w/APl RP-53'(May 8~,) .... ~... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... (~ N 31. Data presented on potential overpressure zones ....... d/'~ N 32. Seismic analysis of shallow gas zones ........... '.. N _DATE 33. Seabed condition survey (if off-shore) ....... .. ..... ,,v~ Y N _'~- Z.~,, z~D 34. Contact name/phone for weekly progress reports [exploratory o~ Y N ~A~NNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (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 GE( ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: 1:3 O :Z O --I .1> c:\msoffice\wordian~diana\checklist (rev. 02/17100) 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 {he roadability of the Well History file and to simp!ify finding information, informati~)n 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 SRevision: 3 $ LisLib SRevision: 4 $ Tue Nov 21 09:42:59 2000 bDO --/_~-~__ Reel Header Service name ............. LISTPE Date ..................... 00/11/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/11/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ..... ,.UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Aurora MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-00241 S. HUIBAN S. LEWIS S-105 500292297700 BP Exploration(Alaska), Sperry Sun 17-NOV-00 Inc. MWD RUN 2 MAD RUN 2 AK-MM-00241 AK-MM-00241 S. HUIBAN S. HUIBAN S. LEWIS S. LEWIS 35 12N 12E 4630 4495 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 65.08 36.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 109.0 8.750 9.625 2996.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY(EWR4) . 3. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR), ELECTROMAGNETIC WAVE RESISTIVITY(EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO DENSITY(SLD). 4. DATA FROM 7549'MD/6686'TVD AND 8108'MD/7192'TVD WERE OBTAINED ON A MEASUREMENT AFTER DRILLING(MAD) PASS PERFORMED WHILST RUNNING IN HOLE AFTER MWD RUN 2. 5. DEPTH SHIFTING WAIVED PER PHONE CONVERSATION BETWEEN J.COPEN OF BP EXPLORATION ALASKA, INC. AND R.KALISH OF SPERRY-SUN DRILLING SEVICES ON 11/09/00. 6. MWD RD-NS 1 AND 2 REPRESENT WELL S-105 WITH API# 50-029-22977 -00. THIS WELL REACHED A TOTAL DEPTH OF 8120'MD/7203'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA SHALLOW PHASE RESISTIVITY SESP = SMOOTHED SHALLOW PHASE RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE RESISTIVITY SEDP'= SMOOTHED DEEP PHASE RESISTIVITY SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY SANDSTONE MATRIX - FIXED HOLESIZE SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SNFA = SMOOTHED AVERAGE OF FAR DETECTOR' COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). CURVES WITH "M" SUFFIX DENOTE MEASUREMENT AFTER DRILLING DATA PARAMETERS USED FOR POROSITY LOG PROCESSING: HOLE SIZE: 8.75" LITHOLOGY: SANDSTONE MATRIX DENSITY: 2.65 G/CC FLUID DENSITY: 1.0 G/CC MUD WEIGHT: 10.3 - 10.5 ppg MUD SALINITY: 300 - 700 ppm FORMATION WATER SALINITY: 23,000 ppm $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 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: FILE SUMMARY PBU TOOL CODE ROP GR RPD RPX RPM FET RPS PEF NPHI FCNT RHOB DRHO NCNT $ .5000 START DEPTH .0 216.0 226 0 226 0 226 0 226 0 226 0 2996 0 2996 0 2996 0 2996 0 2996 0 2996 0 STOP DEPTH 8119.0 8089.5 8069.5 8069.5 8069.5 8069.5 8069.5 8078.5 8034.5 8034.5 8078.5 8078.5 8034.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 .0 3010.0 2 2945.0 8119.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification' Block Type ..... 0 Logging Direction ................. Down Optical 10g depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ................ ~ .... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 0 8119 4059.5 16239 0 ROP MWD FT/H 0 9234.83 177.768 16217 0 GR MWD API. 6.86 397.86 79.025 15748 216 RPX MWD OHMM 0.89 273'.27 12.6987 15625 226 RPS MWD OHMM 0.87 703.69 23.3641 15625 226 RPM MWD OHMM 0.81 2000 74.0656 15625 226 RPD MWD OHMM 0.88 2000 159.179 15625 226 FET MWD HOUR 0.29 107.22 6.97535 15688 226 NPHI MWD PU-S 21.99 76.93 36.4795 10078 2996 NCNT MWD CNTS 2008 3248 2711.06 10078 2996 Last Reading 8119 8119 8089.5 8069.5 8069.5 8069.5 8069.5 8069.5 8034.5 8034.5 FCNT MWD CNTS 402 1238 RHOB MWD G/CM 1.229 3.027 DRHO MWD G/CM -0.409 0.364 PEF MWD BARN 0.24 13.73 665.744 10078 2.2868 10166 0.0553494 10166 3.21271 10166 2996 2996 2996 2996 8034.5 8078.5 8078.5 8078.5 First Reading For Entire File .......... 0 Last Reading For Entire File ........... 8119 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 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 ....... 00/11/21 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 RPX FET RPD RPS RPM GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH STOP DEPTH 7501.0 8061.5' 7501.0 8061.5 7501.0 8061.5 7501.0 8061.5 7501.0 8061.5 7520.5 8081.5 7550.5 8111.5 MAD RUN NO. MAD PASS NO. 2 0 MERGED MAD PASS. $ MERGE TOP 2945.0 MERGE BASE 8119.0 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 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...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 Name Service Unit Min Max DEPT FT 7501 8111.5 RAT MAD FT/H 18 1951 GR MAD API 49.41 391.99 RPX MAD OHMM 0.99 17.92 RPS MAD OHMM 1.06 19.47 RPM MAD OHMM 1.07 16.75 RPD MAD OHMM 1.14 17.16 FET MAD HOUR 6.95 14.63 Mean 7806.25 315.507 123.034 4.07484 4.57059 4.70278 4.77942 11.726 Nsam 1222 1123 1123 1122 1122 1122 1122 1122 First Reading 7501 7550.5 7520.5 7501 7501 7501 7501 7501 Last Reading 8111.5 8111.5 8081.5 8061.5 8061.5 8061.5 8061.5 8061,5 First Reading For Entire File .......... 7501 Last Reading For Entire File ........... 8111.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 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 ....... 00/11/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP .0 3010.0 GR 216.0 2944.5 RPX 226.0 2954.5 RPS 226.0 2954.5 RPM 226.0 2954.5 RPD 226.0 2954.5 FET 226.0 2954.5 $ LOG HEADER DATA DATE LOGGED: 28-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): memory TD DRILLER (FT) : 3010.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .7 MAXIMUM ANGLE: 33.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01708CGVR8 EWR4 ELECTROMAG. RESIS. 4 PB01708CGVR8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT) : ' 109.0 BOREHOLE CONDITIONS MUD TYPE: Spud MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 70.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 8.2 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 Depth Units ....................... Datum Specification Block sub-type...0 9.000 6.963 1.600 1.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 65.0 86.0 65.0 65.0 Name Service Unit Min Max Mean Nsam DEPT FT '0 3010 1505 6021 ROP MWD010 FT/H 0 9234.83 273.439 5999 GR MWD010 API 18.48 130.22 62.02 5458 RPX MWD010 OHMM 0.89 141.44 23.5028 5458 RPS MWD010 OHMM 0.87 643.88 52.567 5458 RPM MWD010 OHMM 0.81 2000 195.771 5458 RPD MWD010 OHMM 0.88 2000 430.674 5458 FET MWD010 HOUR 0.31 46.9 17.2334 5458 First Reading 0 0 216 226 226 226 226 226 Last Reading 3010 3010 2944.5 2954.5 2954.5 2954.5 2954.5 2954.5 First Reading For Entire File .......... 0 Last Reading For Entire File ........... 3010 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 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 ....... 00/11/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPD RPS RPM PEF DRHO RHOB FCNT NCNT NPHI ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 START DEPTH STOP DEPTH 2945.0 8089.5 2955.0 8069.5 2986.5 8069.5 2986.5 8069.5 2986.5 8069.5 2986.5 8069.5 2996.0 8078.5 2996.0 8078.5 2996.0 8078.5 2996.0 8034.5 2996.0 8034.5 2996.0 8034.5 3010.5 8119.0 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 03-NOV-00 Insite 65.41 memory 8120.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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): RESISTIyITY (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 Depth Units ....................... Datum Specification Block sub-type...0 23.8 36.5 TOOL NUMBER PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 8.750 2996.0 Water Based 10.30 43.0 8.5 700 4.5 2.300 .978 2.200 3.000 62.0 155.0 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 NPHI MWD020 PU-S 4 1 68 NCNT MWD020 CNTS 4 1 68 FCNT MWD020 CNTS 4 1 68 RHOB MWD020 G/CM 4 1 68 DRHO MWD020 G/CM 4 1 68 PEF MWD020 BARN 4 1 68 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2945 8119 ROP MWD020 FT/H 0 236.19 GR MWD020 API 6.86 397.86 RPX MWD020 OHMM 0.94 273.27 RPS MWD020 OHMM 0.92 703.69 RPM MWD020 OHMM 0.87 1827.8 RPD MWD020 OHMM 0.91 2000 FET MWD020 HOUR 0.29 107.22 NPHI MWD020 PU-S 21.99 76.93 NCNT MWD020 CNTS 2008 3248 FCNT MWD020 CNTS 402 1238 RHOB MWD020 G/CM 1.229 3.027 DRHO MWD020 G/CM -0.409 0.364 PEF MWD020 BARN 0.24 13.73 .Mean Nsam 5532 10349 121.6 10218 88.0448 10290 6.89862 10167 7.68691 10167 8.73001 10167 13.4306 10167 1.50239 10230 36.4795 10078 2711.06 10078 665.744 10078 2.2868 10166 0.0553494 10166 3.21271 10166 First Reading 2945 3010.5 2945 2986.5 2986.5 2986.5 2986.5 2955 2996 2996 2996 2996 2996 2996 Last Reading 8119 8119 8089.5 8069.5 8069.5 8069.5 8069.5 8069.5 8034.5 8034.5 8034.5 8078.5 8078.5 8078.5 First Reading For Entire File .......... 2945 Last Reading For Entire File ........... 8119 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 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 ....... 00/11/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 2 MAD PASS NUMBER: 0 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7501.0 8061.5 RPD 7501.0 8061.5 RPM 7501.0 8061.5 RPS 7501.0 8061.5 RPX 7501.0 8061.5 GR 7520.5 8081.5 RAT 7550.5 8111.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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: 03-NOV-00 Insite 65.41 memory 8120.0 23.8 36.5 TOOL NUMBER PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 PB01711HRLG6 8.750 2996.0 Water Based 10.30 43.0 8.5 700 4.5 2.300 .978 2.200 3.000 62.0 155.0 62.0 62.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD020 FT/H 4 1 68 GR MAD020 API 4 1 68 RPX MAD020 OHMM 4 1 68 RPS MAD020 OHMM 4 1 68 RPM MAD020 OHMM 4 1 68 RPD MAD020 OHMM 4 1 68 FET MAD020 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 7501 8111.5 RAT MAD020 FT/H 18 1951 GR MAD020 API 49.41 391.99 RPX MAD020 OHMM 0.99 17.92 RPS MAD020 OHMM 1.06 19.47 RPM MAD020 OHMM 1.07 16.75 RPD MAD020 OHMM 1.14 17.16 FET MAD020 HOUR 6.95 14.63 Mean 7806.25 315.507 123.034 4.07484 4.57059 4.70278 4.77942 11.726 Nsam 1222 1123 1123 1122 1122 1122 1122 1122 First Reading 7501 7550.5 7520.5 7501 7501 7501 7501 7501 Last Reading 8111.5 8111.5 8081.5 8061.5 8061.5 8061.5 8061.5 8061.5 First Reading For Entire File .......... 7501 Last Reading For Entire File ........... 8111.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/11/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 00/11/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
