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200-184
STATE OF ALASKA F 77g , - ALASKA OIL AND GAS CONSERVATION COMMISSION`'a WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned d 0 • Suspended❑ 1b. Well CAN 13 2020 22. GINJ ❑ WINJ ❑ WAG 11WDSPL ElNo. of Completions: Zero Development m Exploratory El Service t Ic s ❑ 2. Operator Name: 6. Date Comp., Susp., or Abantl.: 14. Permit to DNI Number/Sundry BP Exploration (Alaska), Inc 12/31/2019 200-184 • 319-169 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 11/22/2000 50-029-22987-00-00 4a. Location of Well (Governmental Section): B. Date TD Reached: 16. Well Name and Number: 12/2/2000 PBU S-201 Surface: 4587' FSL, 4496' FEL, Sec. 35, T12N, R12E, UM 9 Ref Elevations KB 64.42 17. Field/Pool(s): Top of Productive Interval: 2388' FSL, 719' FEL, Sec. 27, T12N, R12E, UM GL 35.90 BF 37.68 PRUDHOE BAY, POLARIS OIL Total Depth: 2574' FSL, 830' FEL, Sec. 27, T12N, R12E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 5767'14311' ADL 028257 & 028258 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 618930 y- 5980790 Zone - ASP 4 r • 7245'15613' • 83-47 TPI: x- 617374 y- 5983847 Zone- ASP4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MDrrVD: Total Depth: x- 617260 y- 5984032 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drillg ateral Top Wndcw Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/ND: N/A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD, NEU, DEN, PWD, RES /AIT, DT/ BHC, CNL, LOL, OR, Caliper, SP, MRES, USIT 23. CASING, LINER AND CEMENTING RECORD CASING Wf. PER FT. GRADE SETTING DEPTH MO SETTING DEPTHTVO TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 29' 109' 29' 109' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# Lao 29' 3190' 29' 2846' 12-1/4" 385 sx AS Lite III, 280 sx Class'G' 7" 26# L-80 26' 7233' 26' 5602' 8-3/4" 421 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 r 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADEDEPTH SET (MD) PACKER SET MD/TVD) 3-1/2" 9.2# L-80 5793' - 6214' 6157'/ 4614' Aba71�a� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, .••.,..,�.! Ai ' 3� fir' Was hydraulic fracturing used during completion? Yes ❑ No m Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Ofid See Attached 27. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, pas lift. etc.): WA Date of Test: Hours Tested: Production for Test Period -► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press Casing Press: Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corn : Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 0`&M"tea AMS �IAN 16 2020 � S � V h 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sidewall Cores Yes ❑ No H If Yes to either question, list formations and intervals cared (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 If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 6636' 5044' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071, Ugnu 4554' 3562' Schrader Bluff NA 6516' 4933' Schrader Bluff N6 6533' 4949' Schrader Bluff NC 6560' 4974' Schrader Bluff NE 6570' 4983' Schrader Bluff NF 6606' 5016' Schrader Bluff OA 6636' 5044' Schrader Bluff OBa 6680' 5085' Schrader Bluff OBc 6766' 5167' Schrader Bluff OBd 6816' 5213' Schrader Bluff OBe 6873' 5264' Schrader Bluff OBf 6921' 5309' Schrader Bluff OBf Base 6962' 5336' Formation at total depth: OBf Base 6982' 5338' 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 certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Nocas, Noel Authorized Title: S1,M.6%cialist Contact Email: Noel.Nocas@bp.com Authorized Signature: Date: 2.0 Contact Phone: +1 9075645027 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Ia. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this forth and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate forth for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: S-201 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 6150' 16.1 bbls Class'G' 6140' Fish; Cement Retainer 6060' Set Cement Retainer 5894' 5 Bbls Class'G' 5793' Cut & Pull Tubing 5767' Set Whipstock T/I/O = SSV/500/100 TEMP = SI, PPPOT-T (PASS) PPPOT- IC (PASS) DRLG Sreen PPPOT-T: Stung into test void 20 psi, bled to 0 psi. Monitored for 15 min, no change in pressure. Function all LDS, all moved freely. Torque all LDS to 400 ft/lbs. R/U test equipment pump though test void, good returns. Pressure test void to 5,000 psi for 30 min test. Lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bleed test void to 0 psi. PPPOT-IC: Stung into test void 10 psi, bled to 0 psi. Monitored for 15 min, no change in pressure. Function all LDS, all moved freely. Torque all LDS to 400 ft/lbs. R/U test equipment. Pump though test void, good returns. Pressure test void to 3,500 psi for 30 min. 10/23/2019 Lost 50 psi in 15 min, lost 0 psi in second 15 min(PASS). Bleed test void to 0 psi. CTU#8 1.75" CT. Job Scope: Reservoir P&A Cement Plug MIRU CTU. RIH w/ 2" BDJSN. 11/2/2019 ***Job continued on 11/3/19 WSR*** CTU#8 1.75" CT. Job Scope: Reservoir P&A Cement Plug Tag IBP at 6610' CTM. 11/3/2019 ***Daylight savings time, job continued on 11/3/19 WSR*** CTU#8 1.75" CT. Job Scope: Reservoir P&A Cement Plug Job continued from daylight savings. Lay in 15.8 ppg cement from 6601' to 6000', pump 16.1 bbls cement. Drop 5/8" ball and contaminate to 6145'. Estimated TOC = 6145'. hase OOH at 80%, jet jewelry while POOH. Lay in 60/40 Methanol Freeze Protect from 2500'. Rig Down CTU. 11/3/2019 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (Sidetrack) RAN 2.70" CENT & 1.75" S-BLR TO TAG TOC @ - 6160' SLM (recovered cement sample). 11/6/2019 ***JOB CONTINUED ON 07-NOV-2019*** ***JOB CONTINUED FROM 07-NOV-2019*** (Sidetrack) RAN READ MTT LOG FROM 6160' SLM - 5500' SLM (good data). RAN 2.70" CENT & 1.75" SAMPLE BAILER, TAGGED TOC @ 6150' SLM (AOGCC witnessed, cement sample recovered). 11/7/2019 ***WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF WELL STATUS*** T/1/0=160/479/149 temp=Sl. (LRS Unit 46 - Injectivity Test) Pumped 20 bbls diesel down TBG to establish an injectivity rate of 1 bpm @ -1250 psi. Pressures trending up. (SEE LOG FOR DETAILS). SV/WV/SSV= C MV=O CV's=OTG Tags hung on MV 11/13/2019 FWHP's=1000/900/190 ***WELL SHUT IN ON ARRIVAL*** (drift, set cement retainer) DRIFT 2.75" GAUGE RING TO 6,110' ELMD. SET 3-1/2" BAKER MAGNUM COMPOSITE CEMENT RETAINER AT 6,080' ELMD. OP OF CEMENT RETAINER @ 6,079'. 11/15/2019 ***CONT ON 11/16/2019 WSR*** ***CONTINUE FROM 11/15/2019 WSR***(drift, cement retainer) RIG DOWN HES ELINE UNIT 4863 11/16/2019 ***WELL SHUT IN ON DEPARTURE*** Daily Report of Well Operations PBU S-201 T/I/0= 344/473/153 Temp= S/I (LRS Unit 72 - Tubing & IA Injectivity Test Post Cement Retainer) MIT -T to 1500psi (1750 psi max applied FAILED, IAP tracked Establish TBG LLR of 1 bpm (0—) 14UU psi with s uiesei Lower rate to compare LLR with Pre -Cement Retainer results. Establish TBG LLR of 0.65 bpm @ 1250 psi with 2 bbls Diesel. Establish IA LLR of 1.0 bpm @ 1340 psi with 15 bbls Diesel. 11/16/2019 Well shut in upon departureSV,SSV,WV=closed MV=open, IA,OA=open. T/1/0=520/530/180 Temp=S/I (LRS Unit 76 - Assist E -line: Leak Detect Log, LDL) Pump total of 172 bbls Diesel down Tbg while E -Line ran LDL. LLR=1 BPM @ 1600 PSI Casing valves OTG, E -Line on location upon departure 11/17/2019 FWHP=1220/1210/130 ***WELL SHUT IN ON ARRIVAL***(leak detect log) PERFORM S/P/T LDLJEAK DETECTED PAST CEMENT RETAINER SET 6 080' WHILE PUMPING 1 BPM AT 1,400 PSI. 11/17/2019 ***JOB COMPLETE, WELL SECURE TURNED OVER TO DSO*** CTU#8 1.75" CT. Job Scope: Mill failed retainer / Cement IA MI RU. MU & RI w/ 2.79" mill. Mill retainer from 6057.1ft to 6058.2ft. 11/21/2019 ***In Progress*** CTU#8 1.75" CT. Job Scope: Mill failed retainer / Set Retainer / Cement IA Continue to mill retainer from 6058.2ft & push to 6140ft. POH. Run GR/CCL for tie-in. Set ne trip retainer at 6060ft. Pump 5bbls of 15.8ppg class 'G' into IA. POH. RDMO. ***EST TOC in IA 5894ft*** 11/22/2019 ***Complete*** ***WELL S/I ON ARRIVAL*** (sidetrack) STATE WITNESS MIT -T & MIT -IA PASSED, RAN 2.75" CENT, & 1.75" SAMPLE BAILER TO 6,033' SLM (no cement sample). RAN 5'x 2.25" BAILER TO 6,033' SLM (no sample). RAN 2.70" LIB AND TAG CEMENT RETAINER AT 6,035' SLM. 11/25/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/I/0= 1111/562/160, LRS Unit 46, (Assist HES/SL) ***MIT-T/MIT-IA *** (AOGCC Witnessed test) Pretest MIT -T. Pumped .6 BBLS DSL down Tbg to take Tbg to 2685 psi. Tbg lost 59 psi in 1st 15 mins and 22 psi in 2nd 15 mins for a total loss of 81 psi in 30 minute test ***PASS*** . Pre Test MIT -IA. Took IA to 3999 psi w/ 2 bbls DSL. IA lost 134 psi in 1st 15 mins and 60 psi in 2nd 15 mins for a total loss of 194 psi in 30 min test. ***PASS***. Bled IA to 1000 psi. SLine bled Tbg to 1000 psi. AOGCC MIT -T to 2773 psi ***PASS*** Took Tbg to 2773 psi w/ 1.29 bbls DSL. Tbg lost 160 psi in 1st 15 mins and 35 psi in 2nd 15 mins for a total loss of 195 psi in 30 min test. ***PASS***. Bled Tbg to 2200 psi and got back —.1 bbls. AOGCC MIT -IA to 4003 psi. ***PASS*** Took IA to 4003 psi w/ 2.38 bbls DSL. IA lost 172 psi in 1st 15 mins and 62 psi in 2nd 15 mins for a total loss of 234 psi in 30 min test. ***PASS*** Bled IA to 1000 psi and got back — 2.2 bbls. SLick Line in control of well per LRS departure. FWHP's= IA,OA=OTG **Tags hung on 11/25/2019 lWing, MV, IA Daily Report of Well Operations PBU S-201 ***WELL SHUT IN ON ARRIVAL*** (SLB ELINE TUBING CUT) CUT TUBING AT 5,793' MD WITH 2.75" JET CUTTER. GOOD INDICATION OF CUT WITH IMMEDIATE PRESSURE RESPONSE ON IA 11/26/2019 ***JOB COMPLETE ON 26 -NOVEMBER -2019*** Intial T/I/O= 80/100/100 Temp=Sl, LRS Unit 46 pump CMIT-TxIA and Circout (SIDETRACK), CMIT-TxIA to 3805 psi ***PASSED*** Target psi=3800 Max Applied psi=4000. Pumped 4.63 bbls crude on 5 CMIT-TxIA attempts. Last 30 mins of last test (SEE LOG) Tbg/IA lost 20/20 psi in 3rd 15 mins and 19/19 psi in 4th 15 mins. Pass per WSL Spiller Pumped 5 bbls 60/40 meth, 283 bbls of 120* fresh water down Tbg up IA and to S-103 FL for Circ out. Pumped 88 bbls of 90* DSL down IA and let IA and Tbg U -Tube for half an hour 11/29/2019 for FP. DSO notified of well status per LRS departure. FWHP's=300/320/100 T/I/O = SSV/Vac/120. Temp = SI. IA FL (API call in). No AL or flowline. IA FL @ near surface. Master valve is locked open. 12/14/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40. T/I/O=BPV/0/0 PRE PARKER. Continued on from day shift. R/D SV & WV platforms. R/D CIW production upper tree. R/U CIW HWO Temp #40 on top of MV. Torqued MV x SV to 752 ft lbs. PT'd against BPV low 300psi, high 3500psi. PT'd Dry hole against MV gate, 12/15/2019 High 5000psi. Evacuated fluid down to MV gate. RDMO ***Job Complete*** FWHP= T/I/O=SI/0/0. Pre Parker 272. Set CIW HBPV #4-2 at 120". PT'd below plug to 3500 psi. (PASSED). See log for details. Final WHP's=HPBPV and dart/0/0. ***JOB IN 12/15/2019 PROGRESS***. Turned over to night shift. T/I/O=HPBPV and test dart/0/0. Pre Parker 272. RU temp valve #3 on IA and #30 on OA. Torqued to API specs. 253 FT/LBS. PT' 300 psi low and 3500 psi high. (PASSED) ***JOB 12/16/2019 COMPLETE***. See log for details. Final WHP's= HPBPV and test dart/0/0. T/I/O = BPV/3/120. Temp = SI. Bleed WHPs to 0 psi. (pre RIG). No wellhouse, flowline or scaffolding. Dryhole tree installed. SV, MV = LOTO. OA FL @ near surface. Bled OAP from 120 psi to 0 psi in 3 hours and 15 minutes to BT. Brought fluid to surface and OAP started to increase during bleed, shut in and let gas break out, then returned to slowly bleeding. During bleed IAP decreased 1 psi. Monitored for 30 minutes IAP unchanged, and OAP increased 3 psi. Final WHPs = BPV/2/3. 12/18/2019 SV, MV = LOTO. IA, OA = OTG. 23:59. T/I/O = BPV/2/15. Temp = SI. WHPs (pre RIG). No wellhouse, flowline, or scaffolding. Dryhole tree installed. IAP unchanged and OAP increased 12 psi overnight. 12/19/2019 SV, MV = LOTO. IA, OA = OTG. 21:30 T/I/O = LOTO/0/20. Temp = SI. WHPs (Pre Rig). Dry hole tree. BPV and test dart in hole. IAP unchanged, OAP increased 5 psi since 12/19. 12/21/2019 SV = C. MV = O. IA, OA = OTG. 9:30 T/I/O = LOTO/0/34. Temp = SI. WHPs (Post bleed). Dry hole tree. BPV and test dart in hole. IAP unchanged, OAP increased 14 psi since 12/21/19. 12/27/2019 SV = C. MV = O. IA, OA = OTG. 09:30 NorthAmerica-ALASKA - BP Pagee140( Operation Summary Report Common Well Name: S-201 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/29/2019 End Date: Project: PBU Site: S Rig Name/No.: PARKER 272 Spud Date/Time: 11/21/2000 12:00:00AM Rig Release: Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000173 _ Active datum: ACTUAL KB P272 @82.64usft (above Mean Sea Level) Date _ From - To Him (hr) Task - Code NPT Total Depth (usit) Phase Description of Operations 12/29/2019 00:00 - 03:30 3.50 RIGID P -0.41 PRE GENERAL RIG DOWN SKID RIG FLOOR - PREFORM PRE SKID CHECK LIST LAY DERRICK OVER 1 -PREFORM DERRICK INSPECTION - SET UP BARRICADES IN FRONT OF RIG LAY MAST OVER =380K ON RACK 03:30 - 0fi90 2.50 MOB P 0.41 PRE DISCONNECT INTERCONNECTS MOVE RIG FROM S-210 TO S -201A - WARM HYDRAULICS MODULES --_. -SPLIT -MOVE MODULES TO S -201A O6'.00 - 08:30 2.50 MOB P -0.41 _ PRE SPOTMODULES -FUNCTION E -STOPS PRIOR TO SPOTTING OVER WELL I- RIG UP UTILITY MOD PIPE SHED AND INTER (CONNECT I I I - RIG UP MUD MOD PIPE SHED AND INTER j :CONNECT P -0.41 08:30 - 12:00 3.50 RIGU PRE GENERAL RIG UP i i i - RAISE DERRICK, MAX WEIGHT 525 KLBS i- SKID RIG FLOOR TO DRILLING POSITION j j-SKIDHAUNCH - RIG UP RIG FLOOR EQUIPMENT - RECONNECT INTERCONNECTS - PERFORM OPERATIONS ON RIG 'ACCEPTANCE CHECKLIST "'RIG ACCEPTED AT 12:00" 12.00 - 1500 3.00 , RIGUP T -041 PRE CONNECT SAFETY SHOWER/EYE WASH LINE & VERIFY FUNCTION - PERFORM DERRICK INSPECTION - CHECK CHOKE MANIFOLD VALVES AND FUNCTION - LOWER BRIDLE LINES TO THE RIG FLOOR AND REMOVE FROM BLOCKS '- HANG LINES IN HOLDERS & SECURE - PIN BLOCKS TO TO 15:00 - 15:30 0.50 RIGU P ! 0.41 PRE HOLD RIG EVAC / H2S DRILL 15:30 - 18:00 2.50 WHSUR P -0.41 PRE NIPPLE DOWN TREE iFMC WELLHEAD -BLEEDADAPTER VOID AND EVACUATE TREE I- NIPPLE DOWN TREE AND REMOVE FROM WELLOUSE -DRY RUN 4 1/2"NSCTx 4 1/2" IF XO: BTURNS (1 1/4" SWALLOW) - NIPPLE UP ADAPTER FLANGE ON j WELLHEAD TUBING SPOOL SIMOPS -CALIBRATE TOTCO SENSORS, CALIBRATE DRAW WORKS AMPHION Printed 1/10/2020 10:05:46AM **All depths reported in Drillers Depths" North America -ALASKA - BP Paget Operation Summary Report Common Well Name: 5-201 - - - -- Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/29/2019 End Date. _ Project: PBUSite— Rig Name/No.. PARKER 272 Spud Date/Time: 11/21/2000 12:00:OOAM Rig Release: Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000173 Active datum: ACTUAL KB P272 @82.64usft (above Mean Sea Level) Date From - To Hrs Task Code NPT TotalII Depth Phase Description of Operations (hr) (usft) 18:00 - 19:30 1.50 BOPSUR P -0.41 PRE NIPPLE UP RISERS AND BOP STACK SOPA STKON RISER AN D TO FLANGE ! -SET NST -TORQUE FLANGES 19:30 - 21:00 1.50 BOPSUR P -0.41 _ PRE RIG UP TO TEST BOP AND CKOKE - RIG UP 4" TJ AND WELL CONTROL VALVES PERTESTPROCEDURE -MU FOSV&DART j- GREASE CHOKE MANIFOLD & BOP VALVES —� __ - FILL LINES AND PURGE AIR 121:00 - 00:00 3.00 BOPSUR P -0.41 PRE 1TEST BOPE TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH I - TEST WITH 4 -AND 31/2" TEST JOINTS j I- TESTED ALARMS,PVT AND FLOW SHOW –TEST WITNESS WAIVED BY AOGCC REP ! BRIAN BIXBY 12/30/2019 :00:00 - 03:30 3.50 1 BOPSUR P -0.41 PRE TEST BOPE TO 250 PSI LOW, 4000 PSI HIGH FOR 5 MINUTES EACH - TEST WITH 4"AND 3 1/2" TEST JOINTS - PREFORM BLACK OUT AND ACCUMULATOR 03:30 04:00 0.50 BOPSUR TEST _. P -0.41 PRE RIG DOWN TEST EQUIPMENT –, 04:00 - 06:30 2.50 WHSUR P -0.41 DECOMP "RIG UP TO PULL HIGH PRESSURE SPV WITH T -BAR PJSM ! - DRAIN STACK - PULL BPVAND DARTAS PER FMC REP WITH �jTBAR 08:30 - 08:00 1.50 WHSUR P 0.41 DECOMP ROCK OUT FREEZE PROTECT - PUMP 20 BELS DOWN THE IA @ 5 BPM W/ 1800 PSI - PUMP 120 BELS DOWN THE TUBING @5-8 j BPM W/ 2300 PSI ` - TAKING ALL RETURNS TO THE TIGER TANK CASING P -0.41 DECOMP PULL 3 1/2" TBO FROM TUBING CUT @ 5793' 08:00 - 09:30 1.50 (WLM) - M/U LANDING JTAND SCREW INTO HANGER - BACK OUT LOCK DOWN SCREWS - PULL HANGER TO RIG FLOOR = PULLED @ 73K i I - PUMP SOAP PILLAROUND @ 10 BPM 1000 PSI 09.30 - 18:00 8.50 CASING IP } -0.41 DECOMP I PULL & LAY DOWN 3 1/2" TBG -BREAKOUT HANGER ISI - CHANGE ELEVATORS _ RECOVER 180 JTS 3 1/2 TBG, PLUS 1 CUT j JT -28.89,1-4.5 TBG, 2 -GLM, 1 X -NIPPLE, HANGAR. SIMOPS- BUILD 4" DP STANDS OFFLINE —_ 1876 0 19:00 I 1.00 I CASING P -0.41 i DECOMP RD DOYON TUBING EQUIPMENT CLEAN &CLEAR RIG FLOOR 19'00 19:30 0.50 WHSUB P 0.41 WEXIT INSTALL WEAR BUSHING IN TUBING SPOOL ___ IID 7,25" ------ 119 30 - 20.00 0.50 WHIP -04-1 P � I 0,41 WEXIT MAKEUP WHIPSTOCK AND SHALLOW TEST 20.00 00:00 4.00 MWD (OK) WHIP I P j 751.00 1 WEXIT I RUN IN THE HOLE WITH WHIPSTOCK/MILLING j 'ASSEMBLY WHILE PICKING UP DRILL PIPE TO 751' 1- FILL PIPE EVERY 20 STANDS Printed 1/10/2020 10:05:46AM "All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 qbi. Operation Summary Report Common Well Name: S-201 - - -' Event Type: RE-ENTER- ONSHORE (RON) Start Date. 12/29/2019 End Date: Project: PBU Site: S Rig Name/No.: PARKER 272 Spud Date/rime: 11/21/2000 12 do ooAM Rig Release:. Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000173 Active datum: ACTUAL KB P272 @82.64usft (above Mean Sea Level) _ Date From - To Him (hr) Task Code NPT Total Depth (usft) Phase Description of Operations WEXIT i RUN IN THE HOLE WITH WHIPSTOCK/MILLING 12/31/2019 00:00 - 02:30 2.50 STWHIP . P 2,180.00 ASSEMBLY WHILE PICKING UP DRILL PIPE TO 2180' - FILL PIPE EVERY 20 STANDS I- D1 TRIP DRILL WITH BEN'S CREW 71 SECS TO SECURE THE WELL 102:30 - 05:00 1 2.50 STWHIP P 5,674.00 WEXIT f RUN IN THE HOLE WITH WHIPSTOCK/MILLING I ASSEMBLY ON DRILL PIPE TO 5674' -- --- FILL PIPE EVERY 20 STANDS 0500 - 06:00 1.00 STWHIP P 5,674.00 WEXIT SET WHIPSTOCK -ORIENT WHIPSTOCK - TAG 5798 DRILLERS DEPTH - PU iSET BTTM $F WHIPSTOCK @5787 MD WWI / STRETCH - TOW 5767 MD 4317 TVD - — - BOW 5778 MD 4325 TVD 06:00 - 07:00 1.00 STWHIP P i 5,674.00 WEXIT _ DISPLACE WELL WITH 9.4 LSND MILLING FLUID, - 300 GPM, 1682 PSI - MONITOR WELL FOR 10 MIN - STATIC 07:00 - 18:00 J tr �JQ� 11.00 STWHIP P 5,798.00 WEXIT MILL 6.125" WINDOW PER SLB FISHING REP FROM 5767' MD TO 5778' MD, 4317.27 TVD TO 1VD. (RAT HOLE FROM 5778' MD TO 5796' MD) - 200 GPM, 1000 PSI ON, 1000 PSI OFF BTM, - 120 RPM, 5 KFT-LBS To ON BOTTOM 4 KFT-LBS To OFF BTM, 2-6 KLBS WOB - - PU 114 KLBS, SO 92 KLBS, ROT 94 KLBS -MUD WEIGHT IN/OUT=9.4 PPG - PUMP HIGH VIS SWEEP -PUMP 5% EP SWEEP AND ISOLATE AT SURFACE - WORK MILLS THROUGH WINDOW SEVERAL TIMES WITH AND WITHOUT ROTARY - NO ISSUES I '. 18:00 - 18:30 0.50 STWHIP P 5,798.00 - NO CEMENT OBSERVED WITH WINDOW EXIT -CHECK FLOW -10 MIN STATIC WEXIT PERFORM FIT I - TOP OF WINDOW 5767' MD 4317.27 TVD - MUD WT- 9.4 PPG - PUMPED 1.6 BBLS BLED BACK 1.6 BBLS -ACHIEVED AN EOUIV MUD WT OF 12.4 PPG WITH ATEST PRESS URE OF 685 PSI 18:30 - 21:30 I0 1 3.00— STWHIP �— P 5,78&00 RECIEVED APPROVAL OF TEST FROM ODE WEXIT PULL OUT OF THE HOLE ON ELEVATORS WITH WINDOW MILLING ASSEMBLY FROM 5700' MD TO 770' MD - MONITOR WELL WITH BHA BELOW THE BOPS FOR 10 MINUTES: STATIC - PU 114 KLBS, SO 92 KLBS AT 5700' MD - MUD WEIGHT IN/OUT = 9.4 PPG - MONITOR WELL WITH HOLE FILLAND TRIP TANK WHILE PULLING: GOOD FILL 21:30 - 23:00 1.50 STWHIP P 5,798.00 _ WEXIT LAY DOWN WINDOW MILLING ASSEMBLY PER SLB FISHING REP/ BAKER MWD - MILLS LOOK GOOD --i I - UPPER MILL (MELON) IN GAUGE, LEAD AND FOLLOW MILL 1/16" UNDER Printed 1/10/2020 10:05:46AM **All depths reported in Drillers Depths— TRFF = rw WELLHEAD = FMC ACTUATOR= BAKER OKB. ELEV = 64.42' REF ELEV = 64A2' BF. ELEV = 37.68' KOP = 1800' Max Angle= 570 Q 4414' Datum MD = 6658' Da51m TVD = 5000' SS 19 -5/8'r -SG, 40#, L -80 -BTC, D = B.835' 3190' Minimum ID = 2.813" @ 6181' 3-1/2" HES X NIPPLE 17'X 10' SHORT JOINT W/RA TAG I 1 6214' 1 .0087 Spf, D = 2.992' PERFORATION SUMMARY REF LOG: ??? ANGLE ATTOP PERF: 21 @ 6640' Nate: Refer to Production DB for historical perfdata SIZE ISPFI INTERVAL 10prdSqzl DATE I DATE 2-1/2-1 4 16640-6730 1 C 10/02101110/02101 2-12' 1 4 1 6833-6841 1 C 0326/01 0326/01 17'X 20' SHORT JOINT W/RA 7AG 6797- I PBTD I S-201 wO SAFETY NOTES: 5793'-cuTTBG(T72611s 5894' ESTIA TOC(1122/1S 6050' EST TBG TOC (11/22 6050' ONE TRIP RETAINER 6140' HFisH: MILLED Cur R HES X NIP. ID = 2.813- 1/2' XO, D = 2.992' BAKER S-3 PROD F 13-12'WLLG.D=2.992' I ?? 1-1 FISH - B -B M34T FROM JET RUMP (0829/10) ?? F6H - 1'X3' SLP & EI-B43lr FROM Ht DATE REV BY COMMENTS DATE REV BY COMMENTS 12113100 PGS ORIGINAL COMPLETION 11/04/19 TFA/JMD CEMENT PLUG 11/03/19 0129/18 MS/JMD SETIBP 0128118 12/12/19 BTNIJMD SETCMT RETAINER 11/15/19 02/19/18 CJWJMD PULLED IBP 02U15118 12/12/19 MORUMD MILLED RET SET RET IA&TBG CMT1122/19 0227118 JCF/JMD SET IBP 0227118) 12112/'19 RT NIJMD CUT TBG (1126/19 0321118 JMG/JMD REMOVED SAFETY NOTE 04/01/19 JNUJMD ADDED BF ELEV POLARIS UNIT WELL: S-201 PERM1TNo: 2001840 API No: 50-029-22987-00 T12N. R12E. 4586' FSL & 4495' FEL BP Exploration (Abska) MEMORANDUM TO: Jim Regg P.I. Supervisor (( I FROM: Lou Laubenstein Petroleum Inspector Section: 35 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Eric Dickerman Casing/Tubing Data (depths are MD) Conductor: 20" 0. D. Shoe@ Surface: 95/81, 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: 7" O.D. Shoe@ Liner: 0. D. Shoe@ Tubing: 3.5" 0. D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 25, 2019 SUBJECT: Plug Verification PBU S-201 - BP Exploration Alaska PTD 2001840; Sundry 319-169 12N Range: 12E Meridian: Umiat NA Total Depth: 7245 ft MD Lease No.: Suspend: P&A: X 109 ' Feet 3190 Feet Feet 7233 Feet Feet 6214 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore ; 6033 ft MD .. Wireline tag Initial 15 min 30 min 45 min Result Tubing 2773 2613 2578 IA 1129 1150 - 1152 P OA 213 216 218 Initial 15 min 30 min 45 min Raailt Tubing 2512 2556 - 2544 - IA 4003 - 3832 3770 P OA 587 574 567 - See - (OBJ Remarks: Abandonment plug for redrill of S -201A. I witnessed a good MIT -T and MIT -IA on this well with no issues during these tests. I was told that there was a tag of the top of the cement plug also to be completed at the same time. Wireline ran into the hole tagging something @ 6033 ft MD, after getting the tool to surface no cement was witnessed and there was marks in the end of the tool. The operator rigged up a larger tool to drift again and hoping in tagging TOC, the tool once again tagged @ 6033 ft MD. The Well schematic did not show anything at that depth. There was nothing approved in their procedure for a plug at this depth. I was later contacted by Eric Dickerman "BP" that's informed me that a Coil tubing until had installed a sting -in plug at that depth that was used to squeeze cement into the IA. Austin Mcleod witnessed the TOC tag @ 6145 ft prior to the second cement ✓ squeeze. Attachments: none rev. 11-28-18 2019-1125_Plug_Verification PBU_S-201 MEMORANDUM TO: Jim Regg P. I. Supervisor ((( FROM: Austin McLeod Petroleum Inspector Section: 35 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Miles Shaw Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 9-5/8" O.D. Shoe@ Intermediate: NA O.D. Shoe@ Production: 7" O.D. Shoe@ Liner: NA O.D. Shoe@ Tubing: 3-1/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 7, 2019 SUBJECT: Plug Verification Prudhoe Bay Unit S-201 BPXA PTD 2001840; Sundry 319-169 12N Range: 12E Meridian: Umiat NA Total Depth: 7245 ft MD Lease No.: ADL 028257 Suspend: NA - P&A: X '1 109 Feet 3,190 Feet NA Feet 7,233 Feet NA Feet 6,214 Feet Type Plug Casing Removal: Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Csg Cut@ NA Feet Tbg Cut@ NA Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Bridge plug 6,610 ft MD' 6,150 ft WLM 8.4/7.3ppg'l Wireline tag initial 15 min W min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I traveled to PBU S-201 to witness the tag of a cement plug inside the tubing that was pumped via coil tubing on 11/2/19 after a tubing and production casing leak was determined. A 1 -3/4 -inch sample bailer string weighing approximately 200 pounds was used for the tag. It appeared stringers were encountered around 6,140 ft WLM with three good tags made at 6,150 ft WLM Y (inclination —35 degrees). Pulling the string to surface we did see good cement in the bailer once broke down. No pressure test was done at this time due to the leak in the tubing just below gas lift station #1 (-6,084 ft MD). Attachments rev. 11-28-18 2019-1107_Plug_Verification_PBU_S-201_am THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-201 Permit to Drill Number: 200-184 Sundry Number: 319-169 Dear Mr. Allen: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.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, nssieL. ielowski Commissioner DATED this l2, day of April, 2019. R13DMS141E`' APR 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 HLGEIVED APR 0 3 019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ epl6vetYPh llpp�I)p)p� Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Chan a 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. 200-184 - 3_ Address: P.O. Box 196612 Anchorage, AK 99519-6612S[re[igrephic ❑ Service ❑ 6. API Number: 50-029-22987-00-00 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 5-201 9. Property Designation (Lease Number): 10. Field/Pools: ADL 026257 8 028258 PRUDHOE BAY. POLARIS OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD' Effective Depth TVD: MPSP (psi: Plugs (MD): Junk (MD): 7245 5613 6610 5020 1836 8810 Unknown x 2 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 29-109 29-109 1490 470 Surface 3162 9-5/8" 29-3190 29-2846 5750 3090 Intermediate Production 7207 7" 26-7233 26-5602 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6640-6841 5048 - 5235 3-1/2" 9.3p L-60 23-6214 Packers and SSSV Type: 412• Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 6157/4614 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Clan after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: June 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 - 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Gorham, Bradley M be deviated from without prior written approval. Contact Email: Bradley.Gorham(rtbp.ccm Authorized Name: Allen, Kenneth W Contact Phone: 907-564-4649 Authorized Title: Engineenng Team Lead Authorized Signature: �-�__ Date: COMMISSION USE 6NILY Conditions of approval: Notify Commission so thattaa representative may witness Sundry Number: n _ I /► I Plug Integriity� 111/BOP Test 0e Mechanical Integrity Test @� Location Clearance ❑ Other: /4© allI Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required. /� .. 41I 7 HE 71 1 /'q APPROVED COMMISSION Approved by COMMISSIONER COMMISSION Date: _` `7Jl ORIGINAL RBDMSKE" APR 15 2019 y�sl MG/Q/��lPIQ/q Submit Form and Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Atte ents in Duplicate > S by S-201 Sundry Application Well Type: Injector Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of Prudhoe Bay well 5-201 to sidetrack and complete S - 201A. CMIT-IAxT Passed to 3500 psi (1/30/2018) MIT -OA Passed to 1100 psi (10/10/2018) PPPOT-T Passed to 5000 psi (10/16/2018) PPPOT-IC Passed to 3500 psi (10/16/2018) Well History: S-201 was originally drilled and completed in 2000. The well was brought online in 2001 and produced until 2016. In 2016 it was determined that there was a leak in both the production r nd the tubing. The we een s u -in since 2016. S- has no remaining va v rs actions —to-r-e-7hediate performance have been exhausted. Scope of Work: The sidetrack plan for the S-201 A well includes the following operations. Pre -rig, the well will be P&A'd with cement being dump bailed onto the existing IBP. Then cement will be placed in an attempt to remedy the production casing leak. Once the cement has setup, the final top of cement will be determined with a drift run. This will be followed by an MTT log and integrity testing which will be followed by a jet cut. The well will be sidetracked and drilled into the Schrader Bluff formation. A 3-1/2" monobore completion with cement through mandrels will then be run, bringing cement 500' inside the 7" casing window. MASP: 1,836 psi Estimated Start Date: June 15, 2019 1 CP^«r. q4111 S-201 Sundry 1 4/2/2019 Pre -Rig Prep Work: Step Service Line Description of Work 1 W PPPOT-T and IC.cfon LDS. 2 E Dum bail semen cement lu on IBP 3 C Cement PC Leak — set retainer and cement through station #1 4 S D&T TOC. Drift for Jet Cut. MTT log. 5 F CMIT-TxIA. Inflow test. OA integrity test. 6 E Jet Cut TBG at —5900' MD. Confirm depth of cut with ODE prior to cut 7 F 74*6 CMIT-TxIA. 8 V Pre Rig Tree Work. Set BPV/TWC 125���rof,e� 7f'6 /IV14. Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test BPV/TWC from below to 3,500 psi psi for 5 minutes. 3. Nipple down tree and nipple up BOPE and test to 4,000 psi. (Configured from top to bottom: 13-5/8" annular preventer 2-7/8" x 5" VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5" VBRs in the lower cavity). a. Notify AOGCC 24 hrs in advance of full test. 4. Rig up lubricator and pressure test. 5. Pull BPV/TWC with pressure tested lubricator. 6. RU hard lines to BOP. Circulate out diesel freeze protection. 7. Pull 3-1/2" tubing from the pre -rig cut. 8. Perform 9-5/8" cleanout run to tubing stub. Perform only if deemed necessary. 9. PU and RIH with EZSV. Set and perform assurance integrity test on existing 7" casing. Only necessary if PC leak is not isolated pre -rig. 10. PU 7" whipstock, bottom trip anchor, and 6-1/8" window milling assembly (to include full gauge string mills). RIH to top of tubing stub, orient and set whipstock. 11. Swap wellbore over to 9.5 ppg milling fluid. ------------------------------------End--End oma: Start of Permit to Drill ------------- --------------------- 12. Mill window and 20' of new formation. Pull back into casing and perform FIT. 13. MU and RIH with 6-1/8" drilling assembly. 14. Drill ahead to TD at 7,087' MD. Circulate and condition the hole as necessary. 15. POOH and lay down drilling assembly. 16. RU and run 3-1/2" completion to TD. 17. Cement tubing, bringing cement 500' inside 7" window. a. CBL and integrity testing to be conducted post rig. 18. Reverse circulate completion brine with corrosion inhibitor through shear valve. (may be post rig) 19. Circulate diesel freeze protect. Set TWC and test. 20. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 4500 psi. 21. RDMO Parker 272. S-201 Sundry 2 4/2/2019 Post -Rig Operations 1. V: Tree work/pull BPV 2. E: RU and run CBL to confirm TOC. 3. S: CMIT-TxIA to 3,800 psi. Pull shear valve. Set dummy. MIT -T to 3,800 psi WFRV work/breakdown cement to allow for reservoir communication 4. F: Assist SL with WFRV work and breaking down cement Drilling Engineer: Brad Gorham (907) 564-4649 Production Engineer: Alex Youngmun (907) 564-4864 Geologist: Priya Maraj (907) 564-4181 5-201 Sundry 3 4/2/2019 TREE= CNV WELLHEAD= EKE ACTUATOR= BAKER OKB. BE/ = 64.42' REF ELEf = 64A2' BE. ELEV = 37.68' KOP= 1800' Max Angle = SP @ 4414' Dahan MD= 6658' Oalxan TVD= 5000'SS S-201 19-5/8' CSG. 409. L -80 -BTC. D = 8.835' 1 Minimum ID = 2.813" @ 6181' 3-1/2" HES X NIPPLE 17'X 10' SHORT JONT W/RA TAG I 3-1/2' TBG, 9.2#, L-80-BJE-BRD, 6214- .0087 bpf, D = 2.992' PERFORATION SLAW ARY RE' LOG: ??? ANGLE AT TOP PERF: 21 @ 6640' We: Refer to Roduction DB for historical perf data SIZE I SPF I METALOpn/Sgz I DATE I DATE 2-1/2' 4 6640 - 67301 O 10/02/01 10/02/01 2-12' 4 6833-68411 O 10M26/01 0326/01 17" X 20' SHORT JOINT W/RA TAG I I PBTD I SAFETY NOTES: GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORI112r2am 0227/18 JCF/JMD SET BE (02/27/18) 4 2752 2536 57 MMM OW RK 0 3 4618 3568 54 AMM DMY RK 0 2 6024 4442 35 MMA OMY RK 0 1 6084 4491 35 MMM 'STA #1 = LEFT BVPRY FOR R(R REPAIR HES X X 3-12' BAKER S-3 PROD f 1/2' X 3-1/2' XO, D = 2.992" t/2" HES X NIP. ID = 2.813" 1 6202' 1-13-1/2' HES X NIP. ID = 2.813' 1 6196' ELMD TT LOGGED 0326/01 ?-p FISH- ELE3141ENI FROM JET RJAVP(0829/10) ?? FISH -1'X3' SLP & ELBVElIf FROM E2 R(R(05/05/15) DATE RE/ BY OOM ENTS DATE REV BY CONVENTS 12MMI) POS ORIGINAL COMPLETION 0129/18 MSIJMD SETBP(0128/18) 03/16/01 CWIP CORIRECT)ON6. 02/19/18 CJWJMD RiJLLED BE (02115/18) 0326/01 GNf LP MNL PERES 0227/18 JCF/JMD SET BE (02/27/18) 03AW16 GC/JMD ADDED Rff ELEV 0321118 JMJMD REMOVEDSAFETY NOTE 11/16/16 rrC/JMD Fi1LLED FIX PLUG (11/15/16) 04/01/19 JNJJMD ADDED BE B -EV 0124/18 RC8/ GLV CJO(0MV18) POLARIS UNIT VWLL: 5-201 PEFUT W: 1001840 AR No: 50-029-22987-00 SBC 35, T12K R12E, 4586' FSL & 4495' FE. SIR Exploration (Alaska) TREE= CNV WELLHEAD= ACTUATOR= OKB. E -B/ = REF AQIf = FKC BAKER 64A7 64.42' BF. HEV = 37.84' KOP= 1800' Max Angle = 57° @ 4414' Datum MD= 86 Datum TVD= 5000' P&A s-201 19-5/8- CSG, 409, L -80 -BTC, D = 8.835-�-J 3180' �- Imnuwuw tv — c.v ry v Wiwi 3-1/2" HES X NIPPLE Top of P&A Cement plug 1, F-5,900 SPC leak at-6,100'MD Top of Quality Cement I Top DPZ 1 = - 6,508'MD I 25' of dump bailed cement 7- X 20' SHORT JOINT W/RA TAG 6787' 1.5i�7 SAFETY NOTES: GAS LFT MAMIZLS ST MD TVD DEV TYPE VLV LATCH PORF DATE 4 27522536 57 MMM DMY RK 0 17128!00 3 4618 3568 54 MMM DAtY FaC 0 12/28/00 2 6024 4442 35 MMM DW RK 0 12/28100 1 6084 4491 35 MMM IWTY - - 01122/18 3-1/2' X 4-112' XO. D = 2.992' 13-1/2' HES X NP. D = 2.813' 1 6202' 3-1/2' HES X NP, 10= 2.813' VVI -EG, D = 2.992- ?? M FISH - ELBOIENT FROM JET R" (08129/10) TT FISH- 1'X3- SLP 8 ELBOIE lT FROM ER PERFORATION SUMMARY REF LOG ??? ANGLE AT TOP FEW: 21 @ 6640' Note: Refer to Product on OB for historical perf data SIZE I SPF I INTERVAL I OprVSgz I DATE I DATE 2-12' 1 4 16M - 67301 O 10/02!01 10102101 2-11ZI 4 IGM-%411 O 0326101 0326101 DATE REV BY COWENTS DATE RLV BY COM`BJTS 12/13/00 PGS ORIGINALCOMPLETION 01129/18 MS/JMD SETBP(0128118) 03/16/01 Off CORfiFS:TIONS 02/19/18 CJWJMD PILLIDBP(02115118) 03/26101 GNTLP INITIAL FRES 0227/18 JCFIJMD SET IBP (02J27118) 03104/16 GGUMD ADDED REF B -EV 03/21/18 AIGIJKU FEMMED SAFETY NDTE 11/16/16 JTG/JMD PULLED PX PLUG (11/15116) 0124118 RcwAc GLV CJO (0122/18) POLARS LINIT WELL: S-201 PEFaU No: `1001840 AR No: 50.029-22987-00 Tl 2N, R12E, 4586' FSL 8 4495' FEL BP FxploraWn (Alaska) TREE = WELLHEAD = CNV FMC ACTUATOR= BAKERC OKB. ELEV = 64.42' REF ELEV = 1". BF. ELEV = 37.84' KOP = 1800' Max Angle= Dahm MD = _°@_' Dahm TVD = 5000' SS PROPOSED 0=6.276' H —6767' �EZSVL� i—) �6766' f Minimum ID = "@ S-201 !-, DATE I 12(73100 REV BY PGS COMMENTS ORIGINAL COMPLETION DATE REV BY I I SIDETRACK -201A OV21/191 JMD IBULTPROPOSED SAFETY NOTES: MLLOUT WNDOW (S -201A) 5757'-00000' COMMENTS ISUIiESBVSSPWC,AUAGEMANDRFL.ID=2.875" I 13112"FES X NIP. D=2.813' 1 POLARIS UNIT WELL: S -201A PERMIT No: ' API No: 50-029-22987-01 SEC 35, T12N, R12E,4586' FSL & 4495' FEL BP Exploration (Alaska) CHORE UNE 3-1/8' 5M FUN D MMI WL ME V A 3 I/8• w FV81Gm Nf9RAWt G m Y w 3-I/C w RIX 1 CEUAR AND WELL NGD CONFIOURAINM ME FOR REFERENCE ORLY & ARE DEPENDWT W OPER.SRIRS REOURWENTS 6012 BOP ftc B BELL NIPPLE ST CK PBY SEA& W El) TO NE EOTTtlM OF 111E RO X 3 3/B• INNER OM TRIPLE INfU1A RUBBER SEAL WELL BELL Nff P 18' W UPPER, 1B' W LOWER 3' CeSR1G FILL OIIRET ((tt OF 2) 13 5/B' 5M BOTTW 111E FIANCE 16' REIRER SFAL RIP (1 FA.) 3' M M. OUREI (1 G) 2' DM M. OU BUTCH = OOWN Fl E ANNULAR BOP. 13-s/e• w slwsvE In 13-5/0• w SRI88m IOP 13-5/8• SM F1NIGm mifOM R/L TYPE BOP: 13 5/8' w NOY 8012 OOIIBIE BOP 13 5/B' w SIUDm BOlEC 13 5/B' FTTOY N/ Y1/2'2' LWlGED LLVlWL LOCIfS W/ tt' BOOSTER DR0ER8E CREW: 13 5/8' 59 mom IOP 13 5/8• w RANGm E0FTW W (2) 3 I/e IN 510E OMElS MILL U18: 2-1/18' w FLEX NOSE 3-1/8' w FLWGED WNUAL GlE 3-1/B' w FIANGm XYDRWLR: WlIEE VALVE w 1WE BOP: 13 5/8' w NOV 6012 MRGIE BOP 13 5/8' SM SIUDOED TOP 13 5/8' 5M F1ANGm miIOM RWPLE W. SPACER SPOOL 13 5/8' w RANGE TOP 13 5/B' w F w BOTTOM SPACER SPOOL 13 5/8' W RANGE TOP 13 5/8' w F m BOTTOM DOUBLE MODm AOIPIFR 13 5/e' w RANGED TOP 11' w RM1Eh0 BOTTOM C8910 SPWL ASSEIIMY It' 5M RANGED TOP II' 5M M m BOTTOM CASING NFAD A EMBLY 11•wF mTOP STACK (DRAFT 8.3.17 L. C.) BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UN POL S-201 (200-184) PRUDHOE BAY, POLARIS OIL Monthly Production Rates 1,000,000 1,000,000 L 100,000 C O a :s 10,000 LL V �o o 0: o N 1,000 ro v (7 LL 0 u 3 V 100 m 0 0 s 10 aMmmmmmu � Iii----�-------�--- �r!�i�■wiwwww�wwwwwww i WPM t„r '����i3'lliRanh �F�Pa ;r.f '�� 102mm nl�l�Iu)rr�L.+rF�llllllll�lllllll�lllllll�lllllll�lllllll��� w�lll� I!!1 WEIINS. ���i��i■�iw■�����w���iwwwwwww -�7, Lim-!i-IFY1�—F�Fs♦� ®��---Bn� �w'liww� iawwwwwwiwww wwwwwwwwwwwwwww _ - -------------- wwwwwwwwwwwww Jan -2005 Jan -2010 Jan -2015 —� Produced Gas (MCFM) . GGR —•— Produced Water (BOPM) Produced Oil (BOPM) w m 100,000 D N 0 1,000 0 i O 100 m 0 0 10 s 1 Jan -2020 SPREADSHEET_2001840_PBU_5-201_Prod-I nject_Cu"es_W ell_Oil_V 120_20190402.x1sx 4/5/2019 • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,June 20, 2018 10:14 AM To: Lastufka,Joseph N; mel.rixse@alaska.gov;Carlisle, Samantha J (DOA) Cc: Youngmun, Alex; Douglas, David (Wipro Technologies) Subject: RE:Withdraw sundry#317-373 S-201 (PTD#200-184) Joe, The AOGCC will withdraw sundry 317-373 as requested. Guy Schwartz Sr. Petroleum EngineerJUN 4 2 LJ)� AAOGCC SGANH� 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservati n Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.aov). From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Tuesday,June 19, 2018 9:58 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; mel.rixse@alaska.gov Cc:Youngmun,Alex<younak@BP.com>; Douglas, David (Wipro Technologies)<David.Douglas@bp.com> Subject:Withdraw sundry#317-373 S-201 (PTD#200-184) Guy/Mel, Please withdraw sundry#317-373 for S-201 (PTD#200-184),the job has been cancelled and if the work is to be done in the future, a new sundry will be submitted. If you have any questions, please let me know.Thanks! Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 1 Subsurf ne&Wells treoflrtfolo-•Ki Fxi w-0--sn BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK 1 RBDMk JUN 2 0 2018 • • 20 0 X1184 WELL LOG TRANSMITTAL# 2 9 3 1 3 To: Alaska Oil and Gas Conservation Comm. June 1, 2018 Attn.: Makana Bender RECENED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUN 12. 2018 RE: Leak Detect Log: S-201 Run Date: 3/12/2018 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 S-201 Digital Log Image files 1 CD Rom 50-029-22987-00 Leak Detection Log SCANNED J l N 2 1 -Mb 1 Color Log 50-029-22987-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRSANC@halliburton.com& AKGDMINTERNAL@bp.com Date: //Lai iU Si ned: • V OF 7.4 • w\ //jys� THE STATE Alaska Oil and Gas �►;," 40„, 7 °fA T Conservation Commission s ' � __-- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.9 433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Josh Allely • Well Intervention Engineer BP Exploration(Alaska), Inc. CANNE FB 0 P . PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-201 Permit to Drill Number: 200-184 Sundry Number: 317-515 Dear Mr. Allely: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French 4L Chair DATED this�day of January, 2018. R 13 - 12118 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 3 0 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 p TS fat �T 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well H • A@down 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Channa n�^.--d Program 0 t-001 Ck •i--- t1 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other I _raw �a; f'errrp.4 r V VcV 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-184 3. Address. P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0•• 6. API Number 50-029-22987-00-00 - 99519-6612 Stratigraphic 0 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 0 No 0 PBU S-201 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028258 / "fr.)I_ C--Y-:--'452-97 's6 if•(, 17 PRUDHOE BAY,POLARIS OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 7245 • 5613 . 7149 5523 2200/6094 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 ▪ 30-110 30-110 1490 470 Surface 3162 9-5/8"40#L-80 ▪ 29-3190 29-2846 5750 3090 Intermediate Production 7207 7"26#L-80 • 27-7234 27-5602 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and ND(ft): 6158, 4614.42 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program I1 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Allely,Josh be deviated from without prior written approval. Contact Email: Josh.Allelyi bp.com Authorized Name: Allely,Josh Contact Phone: +1 907 564 5732 Authorized Title: Well Intervention Engineer Authorized Signature: �__,•7 __� Date: to/;o , i 7 4„,...„..s.,/e" COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 3 ' ' Other Post Initial Injection MIT Req'd? Yes 0 No fit`/ Spacing Exception Required? Yes 0 No I3 Subsequent Form Required: /C —40/! APPROVED BYTHE c� Approved by: COMMISSIONER COMMISSION Date: I 1t VTL 1/2b// e ORIGINAL F: trS LL,`:�D - 1 21s _ //'17 ir.(.r7 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. 1110 • 0440if• if lit Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) October 30, 2017 To Whom it May Concern: Attached please find the Sundry Application for Change to Approved Program under Sundry Approval # 317-373 to use New Techrialog-i-of B 4-mal Sen-the Inner Annulus to Repair the Packer to using Cement to do the Packer Repair for Well S-201, PTD # 200-184. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • a) N cc m �N s" • r d CO N O in in in> I.- 0 I- N- LC) L 0) x- 0- 0 O• O CV LJJ N > O LO In 0 > I- w a CC L1.1 Z 0 0 o w1.11 0 El F-- E- J W co.)a) Q Q Y U O > 0 m O O W Y Y H g J U 0 w w r 0 J J J d d Z c[ ++ a CO Q Q Q w 0 - O 0 (0 00 U2220 ---1 -1 -10 --J U_ U_ -1 LIJ 111 J J D a) Z Z Z 0 0 0 J 0 J E aas s 2 2 2 Z O O 0 0 t * W W W W ae CeH Z 0 Z (. r 2 2 2 0 (I) Cl) Cl) Cl) (l) cof QN a o C = O co O m 0 co cco co ca a L a) i - = J = HHaJa 2 z 2 O w w ci) cn w a) a 0 0 0 c .2 u is d Cl. 0. 0 t 0 d 0 LU J J H D W 0 d a (n I- L11 D _J 0 0 0 0 D j U Q c 0 0 W J J Z L- o N N Z LL a a < W W .4-1.., O W N N w N a uJ W W J W W CC `y 0 0 Z a U` C7 U W W W W a .- N- Q a D O J J D D Irt a J_ J_ Q Q m m w w O O a cc a) E m z ,- O O N m Li_ Cl_ d 0 J w0 NO w d U) U) < < m m w 1 w cn a s • Wellwork Procedure Request To: GWO AK NS Superintendents Date: 10/11/17 From: Josh Allely - Well Intervention Engineer Alex Youngmun — Pad Engineer Subject: S-201 packer repair, tubing punch and straddle packer JP installation Please perform the following steps: 1. S D&T, SBHPS, Pull DGLV. 2. E Set IBP. 3. F A/EL: Load TBG. CMIT-TxIA. 4. C Packer Repair. MIT-IA. Mill Cement. Pull IBP. 5. S Contingent SL step to pull IBP if CT is unsuccessful. 6. F MIT-IA (WOC 5 days). MIT-IA after IBP is pulled. 7. E TBG Punch. Set Lower Packer 8. F A/EL: Verify TxIA post punch. 9. S Test Lower Packer. Set Upper Packer. Test Upper Packer. 10. F A/SL: MIT-Ts Notes: • IA volume to packer is 143 bbls. Annulus capacity of 7" x 3-1/2" is 0.0232 bbls/ft. • Packer LLR: o 11/19/16 WSR: 0.5 bpm @ 1050 psi, 1 bpm @ 1100 psi, 2 bpm @ 1300 psi and 5 bpm @ 1800 psi • Tubing LLR at pup joint below the lowermost GLM #1: o 2/10/16 WSR: 0.25 bpm @ 1475 psi, 0.65 bpm @ 2050 and 0.75 bpm at 2485 psi Program Contacts Contact Phone-Work Phone - Mobile/Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Pad Engineer Alex Youngmun 907-564-4864 907-250-1228 Page l 1 of 6 • • Slickline D&T, SBHPS, Pull DGLV 1. D&T TD with sample bailer and TEL. Note if any sample is recovered. 2. Run SBHPS per attached SBHP sheet (see SOR). 3. Pull DGLV from Sta #1 at 6084' MD and leave pocket open. E-Line Set IBP 4. Load TBG with 120 bbls of 1% KCI followed by 22 bbls of diesel for freeze protect. • Water temp when pumped should be no hotter than 100deg F. Preferably between 90- 100degF. • Pump at -5 bpm or 2000 psi. 5. RIH with 2.5" OD Baker IBP and set mid-joint at -6620' MD. • Tie-in with attached SLB RST dated 03-27-01. 6. LRS to perform CMIT-TxIA to 1500 psi after IBP is set. • Max applied pressure is 1500 psi. • Target pressure is 1300 psi. Coiled Tubing Packer Repair 1. See detailed CT procedure below. EL and SL Install Jet Pump Straddle. 1. See detailed EL and SL procedure below. Page l 2 of 6 • CT Packer Repair Operation for S-201 From: Josh Allely - Intervention Engineer Contact: 907-350-7362 Objective: The objective of this procedure is to fix the leaking packer by repairing it with cement. Planned TOC in the IA is 5884' MD. TOC will also cover the tubing leak just below GLM#1. Notes • The 2.5" IBP has a differential pressure rating of 2300 psi. Based on reservoir pressure, ECDs, and mud /cement hydrostatic pressure, do not exceed 700 psi WHP at any point in the procedure. This should keep the IBP well within its pressure envelope for all conditions in the procedure. • Please confirm BHP with APE prior to job. If BHP is less than 2000 psi, adjustments to max pressure will need to be made. Cement Design: MD: 6155 /TVD: 5300 Estimated temperature at packer is 83 degF / Estimated temperature at TOC is 78 degF SBHP: 2400 psi / BHCT: 90 deg F Cement: Class G Unislurry cement. Batch Mix. Density: 15.8 ppg Thickening time: 4 to 6 hrs. API Fluid Loss: 50-80 cc/30 min Free Water: 0 Compressive Strength: Minimum of 2000 psi (Pre Job UCA) Pump time: 40 minutes at assumed rate of 1 bpm Requested Volume: 7.0 bbls (pumpable). Planned Procedure 1. MIRU 1.75" CT. 2. RIH down to 6600' MD. 3. Pump 17 bbls of a 17 ppg barite mud pill. a. When circulating mud to nozzle, place sufficient choke pressure (-100 psi) to ensure mud does not "fall" out of the CT. b. Displace mud with slick 1% KCI 4. When mud reaches the nozzle, allow -2 bbls to get above nozzle and begin laying in 1:1. 5. After all of the mud is out of the nozzle, nozzle depth should be roughly 6000' MD. Jet back in the hole with slick 1% KCI down to 6100' MD and perform a bottoms up and verify clean 1% KCI at surface. 6. Pump the following down the CT taking returns up the CTxTBG annulus to tanks. a. 5 bbl freshwater spacer. b. 7.0 bbls of 15.8 ppg cement. c. CT volume to displace cement to nozzle. 7. As cement exits the nozzle, allow -100' (about 0.6 bbls) of cement to get above the nozzle and lay in cement 1:1 to -5350' MD (approx. 800'). 8. Position nozzle at cement top just as last barrel of cement reaches nozzle. Pull up hole to safety -300' above WCTOC. 9. While at safety, circulate 5.0 bbls of cement into the IA. 10. After placing the 5.0 bbls, shut in IA and take returns from the CTxTBG annulus for the remainder of the job. Page 13 of 6 • • 11. Swap to powervis (1.25 ppb mixed in fresh water) to contaminate cement. Pump 5 bbls, drop ball, and continue pumping powervis. Cleanout cement down to 6200' and lay in powervis from 6200' up to —5000' MD (10.5 bbls). This will help contaminate any cement that leaks back into the tubing. a. Maintain —100 psi on the choke for the entire clean out. Do not exceed 700 psi WHP. 12. Chase OOH at 80% with slick 1% KCI, slowing down to wash the GLMs. Wash BOP stack. 13. At surface, make up a 2-1/8" milling assembly with 2.80" DSM and 2.80" stringreamer. 14. Wait on cement to build at least 500 psi compressive strength based on field blend testing results. a. Do not RIH until 500 psi compressive strength is reached. 15. Prior to RIH, perform a MIT-IA to 1500 psi. If test fails, contact town for guidance. 16. Mill cement down past the TBG tail at 6214' MD and into the mud. Make 3 reciprocations (down, up, down) over the interval 5350-6250' MD to ensure all residual cement has been removed. 17. Keep cleaning out in the liner with the milling assembly until the BHA is around 6500' MD. The mud should clean out easily but it should be treated somewhat like fill (minus needing to use gel sweeps); take 50' bites and chase back up hole into the tail. 18. Chase last bite up hole to 5350' MD and park CT. Once clean returns are observed at surface, shut down pumps and perform a dry drift down to 6250' MD. 19. At 6250' MD, resume pumping and chase returns to surface at 80%. 20. POOH. 21. MU and RIH with 2.5" OD JSN. RIH and continue with FCO down to top of IBP. When cleaning down to the IBP, lightly tag IBP and jet on fish neck to ensure it is clean for the fishing run. 22. POOH chasing returns at 80%. 23. MU and RIH with hydraulic JDC pulling tool with jars. Please run 2 hydraulic centralizers in the fishing string to help CT latch. 24. Latch and pull IBP. 25. RDMO. Page 1 4 of 6 • • Jet Pump Installation Operation for S-201 From: Josh Allely - Intervention Engineer Contact: 907-350-7362 Notes • Reference the WFD post-incident report for explanation of why the previous packer slid downhole. • S-201 should be fluid packed from packer repair. MIT testing may be possible with a triplex pump. Planned Procedure Eline and Fullbore: Punch holes, install lower jet pump straddle packer 1. Punch tubing holes at 5740'-5742' with SLB 1606S HNS tubing punches for 3-1/2" L-80 tubing with 0 deg phasing. This corresponds to 2' - 3' below the collar at 5738'. • Follow RP: Tubing Punch for Circulation. • Tie-in with attached SLB Memory LDL dated 02-10-16. 2. Establish TxIA communication through tubing holes per EL assist pumping template. • Circulate down the IA up the tubing. For freeze protect, U-tube IA and tubing until pressures are equal. 3. MU tool string that includes CCL, lower 3-1/2" packer, setting adapter, and setting tool. 4. Measure and record distance from the CCL to mid-packer element. 5. RIH at moderate speed, - 100 fpm, slowing down at all ID restrictions. 6. Tie-in with attached SLB Memory LDL dated 02-10-16. 7. Pull-up into position and set packer with center of element at 5753' MD. This will put the element - 16' above the collar at 5769' MD (ref. tie-log) and -11' below the deepest tubing holes 5742' MD. 8. After the setting adapter shears, pick up to verify packer is released, RIH and tag packer, then finish the log up. POOH, RDMO. Slickline and Fullbore: Test lower packer, set top packer/jet pump, test upper packer 9. MU liner top test tool (LTTT) appropriate for the Weatherford packer. 10. RIH and set LTTT in the top of the lower packer. Perform CMIT per pumping template. • IA and TBG will communicate through the tubing holes. 11. If test passes, pull LTTT. If fails, diagnose, retest, pull and re-set LTTT. 12. MU wireline DPU or E-Fire packer setting tool. 13. MU top packer and jet pump assembly. 2-1/2" RC 8B Jet Pump is to be installed. Confirm assembly lengths and ensure space out will allow for the top packer element to be set mid-joint. 14. RIH at moderate speed to allow fluid bypass, -100 fpm, slowing down at all ID restrictions and stab snap latch into lower packer. Tap down with spang jars until landed. Page 15 of 6 • • 15. PU to check snap latch engagement. Pull up 800 pounds over pick up weight to ensure snap latch is fully engaged in the lower packer. Repeat stab-in / pull as necessary until latch is engaged and an 800 pound over-pull is achieved. 16. Relax wire back to neutral hanging weight. Wait for setting tool to set packer. 17. Once packer is set, pick up to verify packer is released, RIH and tag packer. POOH. 18. RIH w/ LTTT appropriate for the Weatherford upper packer. 19. Engage packer top w/ LTTT, perform MIT-T per pumping template. • If packer is holding, the tubing should be sealed above as packer assembly is set above the tubing holes. 20. If test passes, pull LTTT and POOH. If fails, diagnose, retest, pull and re-set LTTT. 21. RDMO. Page16of6 • • m orn0000 o v �n M Ln C.) N o 0 0 o 0 i 6) U) M 3 �fr- N O m O f� CO O CO C\I cf O 6) O 00 CO CO O N U) - I O C) N cr6) M N N N CO I. M 6) U) N O N CO r-- (0 ✓ Q I I I 4 Q 0 ornr� vrn M N N N CO C I-• aO CD O co O1- coa II 00 _ 2.1 CO J C 0) J 0 O N .N c O V co U - n cNiN o C M L a• )O (0 O O Vt C 00 - (N d M r O J Z 0)O O C H W H O D LL D Z_ Z Z0 (0 O D CC D D O U) O H H • TRIS= aw S VVELLHEAD= FMC S-201 _201 SAFETY NOTES: SEE WELL ALE FOR JET PUMP ACTUATOR= BAKER C INFO OKB.ELEV= 6442' REF BM/= 64.42` BF.ELEV= 37.84' KOP= 1800' ' ' 2200' H3-1/2"FES X NP,MLLEOTO 2.92"(05/03/15) Max Angle= 57°Q4414' Datum MD= 6658' GAS LFT MANDRELS Datum TVD= 5000'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 9-5/8'CSG,40#,L-80-BTC,D=8.835" H 3190' 4 2752 2536 57 MMM DMY RK 0 12/28/00 3 4618 3568 54 MMM DMfi RK 0 12/28/00 2 6024 4442 35 MuM DMY RK 0 12/28/00 1 6084 4491 35 MMM 'DMY RK 0 02/10/16 "STA#1=EXTBIDED PACKING Minimum ID =2.813" @ 6181' 3-1/2" HES X NIPPLE I , 6144' H 3-1/2"FES X NNP,D=2.813" __.6155' —13-112"x4-1C2'X0,0=2.992" I 6157' H7"X 3-1/2"BAKER S-3 FROD PKR 1 6160' H4-1/2"X 3-1/2"XO,D=2.992" 6181' H3-1/2"FSS X NP,D=2.813" 7'X 10'SHORT JOINT W/RA TAG 1-fi........_6182' I I 6202' H 3-1/2"HES X NP,D=2.813" 3-1/2"TBG,9.2#,L-80-EI JE$RD, —j 6214' \—I 6214' H3-I/2"WLEG,13=2.992" .0087 bpf,D=2.992" 6195' —1 aMO TT LOGGED 03/26/01 PERFORATION SUI MARY ?? FISH-ELEMENT FROM JET RAP(08/29/10) PEE LOG: : 2 ?? —FISH-1"X3^SLP&ELEMENT FROM ER T ANGLE AT TOP PERF: 21 • 6640' PKR(05/G5t15) Note:Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE DATE 2-1/2' 4 6640-6730 0 10/02/01 10/02/01' 2-1/2" 4 6833-6841 0 03/26/01 03/26/01 — 7"X 20'SHORT JOINT W/RA TAG —{ 6797' /11 PBTD —' 7100' ••••••••11'1,••••1,•1 .11111111/11111111111 7"CSG,26#,L-80,BTC-M,.0383 bpf,D=6.276" —I 7233' DATE REV BY COMMENTS DATE REV BY COI/INDIES POLARIS UNIT 12/13/00 PGS ORIGINAL COMPLETION 02/12/16 JMIG/JMD PULLED PKR/SET PLUG(02/10/16) WELL: S-201 03/16/01 CHIP CORRECTIONS 02/12/16,MAG/JMD GLV CJO(02/10/16) PERMIT No: 2001840 03/26/01 GWTLP WEAL PE ES 03/04/16 GC/JMD ADDED REF ELEV API No: 50-029-22987-00 09/10/15 JC MJMD SET LWR E2 PKR ASSY (08/05/15) 11/16/16 JTG/JMD RJLLED PX FUJG(11/15/16) SEC 35,T12N,R12E,4586'FSL&4495'Fa 12/11/15 MGS/JMD PULLED WFD LWR PKR(09/20/15) 01/28/16 lI&1YJMD SET LWR WDEPAK LE PR((01/27/16) BP Exploration(Alaska) ti OF Tit, • ofr,\\/7,—",s. THE STATE Alaska Oil and Gas —s--Q� a o Conservation Commission t, 11sKA- ::,16,,,,,,7 litt. _ 333 West Seventh Avenue " ' t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F pv ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Beau Obrigewitchsoli 'ED �-p 0 Well Integrity Engineer BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-201 Permit to Drill Number: 200-184 Sundry Number: 317-373 Dear Mr. Obrigewitch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ' 51-8. Cathy 7Foerster Commissioner DATED this 6 day of September, 2017. RBDMS Lt-SEP - 8 2017 IIISTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0, Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other New Tech BiSN Seal 0 ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-184 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 6. API Number: 50-029-22987-00-00 ' 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and fiEGFIVED What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I3 PBU S-201 • AUG0 7 2017 9. Property Designation(Lease Number): 10. Field/Pools:c. Y1 t-+s �41 f /,E ADL 0028258 i , j� —GG)z z T T,to, t 1 PRUDHOE BAY,POLARIS OIL ' ,✓ AOGCCF 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 7245 • 5613 • 7149 5523 2200/6094 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 3162 9-5/8"40#L-80 29-3190 29-2846 5750 3090 Intermediate Production 7207 7"26#L-80 27-7234 27-5602 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and TVD(ft): 6158, 4614.42 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development RI Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil IRI WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch,Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH©bp.com Authorized Name: Obrigewitch,Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity ngineer /JJ/ �j p Authorized Signature: a/all, L4[4'4 Date: '7/ ( Z(7 • COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number 3 rt-3.7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No It' Spacing Exception Required? Yes 0 No Irl Subsequent Form Required: / 0 APPROVED BYTHE Approved by: a_))..e.44,...____ COMMISSIONER COMMISSION Date:?6—('7 VTL /5/lam ORIGINAL RBDMS (.,L SEP - 82017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED AUG 0 7 2017 AOGCC • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) August 4, 2017 To Whom it May Concern: Attached please find the Sundry Application for proving up new technology of injecting a BiSN Metal to provide a Metal to Metal Seal of the Packer Leak in Well S-201, PTD # 200-184. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 bp • i 04.0 • At Well: S-201 S-201 Packer Repair with BiSN Metal to Metal Seal Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Alex Youngmun (907) 564-4864 History S-201 is a vertical Polaris producer completed and frac'd in the OA, OBa, OBb and OBd sands with a total of 250K#'s of proppant pumped in 2001. S-201 was brought online as a gas lift producer, but due to it being low rate, suffered from hydrate issues and low up-time. S-201 was converted to a jet pump (JP) producer in early 2002 by installing a straddle patch with a JP across the lower most gas lift mandrel. S-201's JP has historically needed to be pulled and replaced every 2 years. S-201 had good up-time post JP conversion until late 2012 when a JP change-out was needed. The well has been S/I since October 2012 after SL had trouble pulling the pump set in 2010 due to a straddle packer failure allowing power fluid to be injected downhole. Multiple slickline and coiled tubing operations were conducted to retrieve the JP. The JP was finally pulled with CT in 2015. When SL installed a new JP in January 2016, S-201 failed a CMIT-TxIA. After setting a DGLV in ST#1, the well also failed a MIT-T. A follow-up LDL confirmed a tubing leak in the pup below ST#1 - and a large packer leak. A LLR down the IA of 5 bpm at 1800 psi was established. Objective This well has been selected for the BiSN technology because it is a great candidate to prove up this technology, has the potential for future cost savings on other wells, and preserves ST#1. This will be the first trial of the technology for a packer repair of this type. Inclination at the packer is 35 degrees and estimated temperature is 83F. Procedural Steps Slickline 1. Obtain Static Bottom Hole Pressure Survey; Drift to TD; Set PX Plug with prong in lower X-Nipple at 6,202' MD. Eline & Fullbore 2. Schlumberger pumpers rig up to IA and pump BiSN bead/HEC Slurry; LRS rig up to tubing to maintain positive wellhead pressure 3. Eline run BiSN Heater, melting beads in place; Contingent USIT if necessary 4. LRS perform CMIT-TxIA to 3,200 psi Slickline 5. Pull PX Plug from 6,202' if CMIT-TxIA passes 6. Pull DGLV in ST#1 at 6084' MD. 7. Set Flow Sleeve in ST#1 at 6084' MD. • • Eline 8. Set lower jet pump straddle packer Slickline & Fullbore 9. Test lower packer; Set top packer/jet pump; Test upper packer 10. Fullbore to perform testing for Slickline as required 2 . 0 Pre Job Schematic ii- E, civy , 1AELLHEAD r RAC- 201 INFO SAFFTY NOTFS SFF%NH I 1,11.F. FOR J FT PUMP ACTUATOR= BA Kfft C' C10.B_EV- 64.42' REF E3_EV= 64.42' BF EIEV - 37 84'' KOP= lawy' L 2200' 1H 3-112',-.ES X NF' MLLE/10 292 (058)3/15)1 I Max Angle- 57"0 4414' [alum AJD= 6658GAS LFT MI-PLS Odium TVD- 5000'SS ST 14) ND DEV Tr FE VLV LATCH PORT DATE 9-5/8'CSG,,AUX,L-80-STC,0=84135' — 3110' Ur 4 2752 2536 57 PAW 1W FI( 0 12/28/00 3 4618 3568 54 MMM COAY FE 0 12/28/00 2 6024 4442 35 WA DI& PK 0 12/28/00 1 6084 4491 35 MIN, 'MY FE 0 02/10/16 'STA 011-MENDED PArxirs3 Minimum ID=2.813"@ 6181' . 3-1/2" HES X NIPPLE L6114*_J-1_3_1/2'HES X NP,_D 2.813' I _- _ ___-- 6156' j—i3 irr x 4 1;2"x0,D 2.992'I 3.1 6167' =..--i 7-X 3-1/2'BAKER 6-3 PROD PKR I ----------1 6180' —Esilfr x 3-1/2X0.ID=2.962' I '/"'X10' ',40-4iiiiii'vvii:ip, i'AGI—L iiiii- :--------* I F 11181' I FT 1.--- li- . NI II 1 6202' H3-1/2.'FX NP,L)=Z813' ., 3-1/2"TEG,8.2k.L-80 EUE-8RD, H 6214' 1 11\ IES 1 6214' ...---13-1/2"WLE-G.ID=2 992" DOC(bp',1) 2 992' 6196' —1E:i.1410 IT LOGGLD 01126/01 I FTERFORAT1ON&WARY ilk 7? -Iv ISA fiieirrhr1---FROM Jur RAS,(o1v2enc•FI FEF LOG 777 ANGLE AT TOP%FF. 21©6644Y lir I ?? li .-.FISIFI 110"SIP&FLE&IFET FROM ER FR(95/06/l5) Nate Refer to Procuchon I-13 for hslancol perf data SIZE SPE' INTERVAL Opn/Sqz DATE DATE I 2-1/7 4 -6640-6730 0 10/02/01 10/02I01 2-1•71 4 8833-6841 0 026/01 03/26/01 i • I /8 It-X„,0 ;iHull Jori'ho-tA IN; ' I 6797' r LPB-iqD --{ 71130' I- V9 949.9WM 4419Y.9.29*.AN r CSG,2es,L-eo,8TG4A 0383 bpi,08276- H 7233' DATE 1 RP/BY 1 efidvirENTS T co,TE REV 3Y' CENTS POLARS UHT i 12/13/00 PGSORIGINAL COMPLETION .02/12/16.1MG/JND FULLED FKRISEr rtuG(62/la 16) %Mal S 201 03/16r01 arrt. awsycnrsts '07/12/16 JiAGt.m)GLV 00402110/1C PERMT No 2001340 03/26/01 GNTLP MAL PER ,.,FS 03/04116 GUJAA3:ADDED REF ELEV API No. 50-029-22987-00 , 09/10/15 JC14.11.11.)SET LVVR ER FM ASSY (0685i15) '11/16/16.fTG1.1543I MUSD IN PLUG(11/15/16) SEC 35.T12N,R12E 4586'f-SL&4495'FEL 1 .2/11/1bViS'..11/DR/111=1.3 'A-1.)OW PK R C.19/20115) q 01/28116 1.11DJA1E1SET OAR VADEPAK LC PIE.(0127/16) li f3P Exploration(Alas li al 3 Post Job Schematic Fmc PROPOSED S-2 0 1 SAFETY NOTES SEE WELL FILE FOR JET PUMP INFO OK3 EL EV- 5442 R BEV= 6442' EF ELEV= 37 84 KDP 18/00 I I futax Angle 57'6ft 4414 Dater FAD. 43558' DeUrn - 5000"SS F9 5,8050 40* 4.SO BFC,117-8 836 f 3190' I GAS LET1/14NDPF1 II t,1- DEV TY FE V LV _ _ L _ 2752 2536 57 1/6/144T DAY C 3 4616 3568 54 Yhita1 Cf1 RI< 0 - I 2 6024 4442 35 VW 46 0 112r243/.._ Minimum ID=2.813" 6181' -',,CF4 4491 RK o 102/10,4- 3-1/2" HES X NIPPLE 2k.V2- 'E"91_,1 =71- - 11111 ei I VPPKP I 6'44' 1-0.1/2" HES X NP 3 I 1-07'6;'sVkli—Fth=—A"-Fil-{_6147' 6155' illy X4 1 2"X0 -2 992" I et#: 6157' 7-X 3-1/7 BARER S-3 PROD F1i,P. 6160' 1-44 12"X 3-1 2"X0 =2 992"] I 6181° 11'.1-1ES X NC' J SHORT JOINT V11/RA TAG 6182 .1111 6702' 2—p-1,7 HES X NIP,ID'- 3-1,2"TEG 92# L-812-EUE-BREIH 6214' F. 0967 bpt ID=2992" 6195" I , i PERFORATION SAMAR"( t REF LOG 77? ANGLE AT TOP PERF 21 a 6640' ,4 Note Refer ta Production LE tor nistoncalperl dat, - ES:1 SPF INTERVAL Opn/Sqz DATE C 2-1/7 4 6540-6730 0 10402101 10/r07 2-112' 4 6933-8841 0 03/26101 C3/2_, ' • A McP, A 1 6797' 1'. PeTD — 7100' 4 9' 91"6.4.1t. 4.f9§4. Cr CSC.; 2E4 --C Y 33a3 bpi 0'S 276' 7233' rtn't, .7.Crvoiebtr,5 CATE RP/ V COMMENTS POLARIS 12/131130 PGS ,ORIGINAL COM PLErION 02/12/16 JAC...QM)PULLED P<R,SET PLUG 10 16) WELL 5-201 -3-.3)"61V1* CHITP TCORRECTONS 02/12/16 JOV1a1,04131OLV 0/0 I 02/10/18) PERMT Nb 2C01840 03/26/01 GNITLP INfTAL F-ERFS 03/04/16 GC ) A DOE)REF ELEV API kb 50,029 22987 00 09110/116P.ICLCh SF' 1NR FR FI14R ASSY 08/05115 11/15/116 JIG/JK)RILED PX RUG 01/15116) SEC 35,T12N R12E,4596 Fa&4495 -71 '2P11/15kAGSLM PULLED WFD LAIR W.(2109120/15 1 01128,16 M71Y.M 3E7 11R WiCEPAK LE Plitc 01/271 61 BP Exploration(Alaska} 4 a) • y m CV co ty CO (NI O LU LO H 0- 0 t 0) r- CV • O O to in H 0 03 m CO . C — Q ( c' 0 CO CO CDfa aI 2 C) r RS O QN o C L o ch O m o coo co c° (0 (0 a) O 2 I CD a 0 0 .2 u. m 0_ W `0 Q CL a 0 a) a) a a) m ' v- O O O coo O N N N y O a . O a) E Ca z y- 0 N N N U) U) • • a) Ili U o 0 0 0 i O LU V M CO 7 V r- N V m LU I. CO O CO CN O) CO CO 0 M CO ` N LO - CI H O O) N- O) CO N N N CO C O O LU O CO O7 M f� O NI CO o p I I I I No 0) N- v o) CD I CO N N N CO • CCI F- Q. O O c) OJO O J CS) _ J IA N _ (r) r o) CO _ _ N N N N co .c �O NCO O Lo d- C CO - N a) M r-- -J �J Z O O• CIO Z_ Z_ ZOmCO c) d H • . Loepp, Victoria T (DOA) From: Julian,Jennifer Y <Jennifer.Julian@bp.com> Sent: Wednesday,August 30,2017 8:43 AM To: Loepp,Victoria T(DOA) Cc: Peru, Cale; Robertson, Daniel B(Alaska) Subject: FW: PBU S-201(PTD 200-184, Sundry 317-373), PBU W-30(PTD 188-136, 317-388) IA BiSN Metal Seal for Packer repair Attachments: PRT Beads Test Summary vl.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria! I hope you had a good summer. Attached please find the report of the testing I witnessed in Houston a little over a month ago. I would absolutely love to stop by with the bismuth tin beads and go over the testing and what we have planned. I am completely free today except for a United Way luncheon from 11 to 1. Warmest regards, Jennifer From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Friday,August 25, 2017 8:47 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com>; Peru,Cale<Cale.PeruPbp.com> Subject: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136,317-388) IA BiSN Metal Seal for Packer repair Beau&Cale, Could you please include more technical description/information on the BiSN technology and the application for packer repair. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 From:Sylvain Bedouet [mailto:sylvain.bedouet@bisn.com] Sent:Tuesday,August 29,2017 4:22 PM To:Julian,Jennifer Y<Jennifer.Julian@bp.com> Cc:Paul Carragher<pauLcarragher@bisn.com>;Jake Dearmon<jake.dearmon@bisn.com>; Didhiti Talapatra <didhiti.talapatra@bisn.com> Subject: RE: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136,317-388) IA BiSN Metal Seal for Packer repair Jennifer, I attached the report from the beads testing test#1.Test#2 with HEC polymer is underway and was shot last week. It passed 4,000 PSI at ambient,we are going to continue testing as soon as possible. The current situation in Houston does not allow to make any prevision yet on when we will be fully back up and running in Houston. We'll keep you posted,don't hesitate to check back with us. Best regards, Sylvain From:Julian,Jennifer Y[mailto:Jennifer.Julian@bp.com] Sent: Monday,August 28,2017 3:36 PM To:Sylvain Bedouet<sylvain.bedouet@bisn.com> Cc:Paul Carragher<paul.carragher@bisn.com>;Jake Dearmon<jake.dearmon@bisn.com> Subject:Re: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136, 317-388) IA BiSN Metal Seal for Packer repair Thank you! Jennifer Julian Senior Well Intervention Advisor BP Alaska On Aug 28,2017, at 12:16 PM,Sylvain Bedouet<sylvain.bedouet@bisn.com>wrote: Jennifer, We are going to send you a summary report as soon as we can. Best regards, Sylvain From:Julian,Jennifer Y [mailto:Jennifer.Julian@bp.com] Sent: Monday,August 28,2017 12:23 PM To: Paul Carragher<paul.carragher@bisn.com>;Sylvain Bedouet<svlvain.bedouet@tbisn.com> Subject: FW: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136,317-388) IA BiSN Metal Seal for Packer repair 2 • • fy From: Robertson, Daniel B(Alaska) Sent: Monday,August 28,2017 9:14 AM To:Gracia,Jesse<lesse.Gracia@bp.com>; Galvan Amaya,Jeanine<Jeanine.GalvanAmaya@bp.com> Cc:Julian,Jennifer Y<Jennifer.Julian@bp.com>;Youngmun,Alex<younak@BP.com>; Peru,Cale <Cale.Peru@bp.com>; Obrigewitch,Beau<BEAU.OBRIGEWITCH@bp.com> Subject: FW: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136,317-388) IA BiSN Metal Seal for Packer repair Jesse,Jeanine, Do we have a written report from BiSn regarding the testing they have done for packer repairs? If so, can we forward this report,or excerpts from it, to the Alaska Oil and Gas Conservation Commission? Thanks, Dan Daniel B. Robertson, PE Petroleum Engineering Advisor, Alaska Well Management Advisor BP Reservoir Development 900 E. Benson Blvd PO Box 196612 Anchorage Alaska 99519-6619 +1 907 564-5546 office +1 907 529-5818 mobile This communication contains information from BP p.l.c or its affiliates and is intended only for the use of the addressee(s)named above. This communication may be confidential and/or privileged. Access to this electronic transmission by anyone other than the intended recipients is unauthorized. If you received it in error please notify the sender immediately. Please then delete the email and do not disclose it contents to any person. From: Peru,Cale Sent: Friday,August 25, 2017 11:39 AM To: Robertson, Daniel B(Alaska)<Daniel.B.Robertson@bp.com>;Youngmun,Alex<younak@BP.com> Subject: FW: PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-136,317-388) IA BiSN Metal Seal for Packer repair fyi Cale Peru I Production Engineer I EWE/NWE I BP Exploration Alaska Wt 907.564.4522 I c 832.316.5774 ( e cale.peru@bp.com 900 East Benson Blvd PO Box 196612 I Anchorage I AK 199508 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent: Friday,August 25,2017 8:47 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com>; Peru,Cale<Cale.Peru@bp.com> 3 • Subject:PBU S-201(PTD 200-184,Sundry 317-373), PBU W-30(PTD 188-19,317-388) IA BiSN Metal Seal for Packer repair Beau&Cale, Could you please include more technical description/information on the BiSN technology and the application for packer repair. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a7alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793- 1247 or Victoria.LoeOO@alaska.Qov This e-mail contains confidential information belonging to the sender and is intended for use by the addressee only.If you are not the intended recipient please return the message to the sender and delete it from your computer.The unauthorised disclosure of this e-mail message,its contents or attachments is strictly prohibited.Whilst all reasonable care has been taken to avoid the transmission of viruses,it is the responsibility of the recipient to ensure the content or any attachments does not adversely affect their systems or data.No responsibility is accepted by BiSN,for any loss or damage so caused.BiSN is the trading name for BiSN Holdings LTD Company No:07735255&BiSN Laboratory Services LTD.Company No:08311009. 4 • . Engineering Test Summary BiSN Packer Repair Tool Beads—Feasibility Test Summary ENGINEERING TEST REPORT Test Name: Packer Repair Tool Beads Project Title: PRT- Beads Report Compiled for: BP Report Written by: Didhiti Talapatra SCANNED MAR 1 5 2018 Report Date 8/29/2017 Revision Rev 01 Project# 0030 EPDM# EPDM#:0030-001Report The information in this report is to be treated as confidential and not distributed to any 3'd party without BiSN's permission Page 1 of 9 S • • , Engineering Test Summary Packer Repair Tool Beads—Feasibility Test Summary B i S N Contents: 1 Aims and Objectives: 3 2 Results Summary. 3 3 Validation Tests in Fluid. 3 Tables and Figures: Figure 1: Test Vessel Setup 4 Figure 2: Test A, closeup of the plug 6 Figure 3: Test A Firing Data 7 Figure 4: Test A Pressure Test Ambient 8 Figure 5: Test A Pressure Test at Temp 8 The information in this report is to be treated as confidential and not distributed to any 3'd party without BiSN's permission Page 2 of 9 • • Engineering Test Summary Packer Repair Tool Beads—Feasibility Test Summary BiSN 1 Aims and Objectives: The objective of the test is conduct a feasibility test to validate the design and ability of the 3.50"OD heater to successfully form a seal in the annulus by melting the alloy beads which are to be dropped into the annulus from the surface.The test will be conducted using the W-30 well parameters in an 8.50"ID vessel at a 22°deviation from vertical and temperature of 93°C.The initial feasibility test will be carried out using a 10 ft long 3.50"OD heater placed inside a 4.50" OD X 3.958" ID X 12.6#tubing to simulate the well conditions. 10 ft of BiSN-138 alloy beads will then be dropped into the annulus between the 4.50"tubing and the 8.50"ID casing.A pressure test is to be conducted once the plug has solidified to determine the pressure rating of the seal.The aim is to hold at least 3500 PSI across the seal at 93 C. 2 Results Summary: BiSN Oil Tools has successfully qualified the 3.50"OD PRT—Beads Tool to create a 74"long seal in the annulus that was pressure qualified to 3500 PSI from both top and bottom at the desired temperature of 93°C. 3 Validation Tests in Fluid: To validate the design of the tool,a 10 ft long 3.50"OD heater was shot inside a pressurized vessel to determine the quality of the seal it would make in the annulus.The heater was shot inside a customer specified 4.50" OD X 3.958" ID X 12.6#tubing with BiSN-138 alloy beads in the annulus between the tubing and the 8.50" ID casing.The vessel was then filled with water and heated to a temperature of 93°C and raised to an angle of 68°(22°deviation from vertical)from the ground to simulate the well condition.The results from the test has been summarized in the table below. The information in this report is to be treated as confidential and not distributed to any 3'd party without BiSN's permission Page 3 of 9 • • Engineering Test Summary Packer Repair Tool Beads—Feasibility Test Summary BUSN ' 13'Vessel(8.500"ID) ► 12'X 4.5"12.6#Casing I. Alloy Shot Top Packer * *o s•• 000 000 10'138C Shot Bed(9901b) —4•0 0„x_; 0 0 000' 000`x, 000 000.`.; 000 000 <. 10'Thermite Heater . • a 000 1 O00' ' , 000 000 000 -: 000 's ' 000' II o00 000 000 000 000 000 000 000' F. 000 000 000' 000,5 000 00* ` 000 000 000 000 o00 1000 000 000 000 000 120" T6 4 ► oo0 • 000 A Os T1 o 000 00 000 00 000 00 12 T7 I 00000 000 T2 000 000 000 000 000 000 12„ 00o `r 000 000 000 T8 4 11* T3 000 000 ,.. 0 00 000 ' ` 000 000 12' 000 000 000 . 000 T9 I 000 . 000 T4 000 = 000 ' 000 000 000 000 - 000 000 T10 ` 000 000 T5 000 000,5'' 000 0 000` 000 000 12" 000 000 000 000 i V Alloy Shot Bottom Packer 1111 12"3.5"00 Heater Skirt III 14" Figure 1:Test Vessel Setup The information in this report is to be treated as confidential and not distributed to any 3rd party without BiSN's permission Page 4 of 9 0 0 � j \ C •i, .-4 a .2 z ; N ° al :t4 © ® a a E C k .0 2 § - E ■ 2 v © ; a E § 2 -0 5 — 0 - E a) _ in Q k g 3 al al co • U w J0 - 0. 0 t » 7 o e - 24. Lu k a • 2 03 Tik § m e >. 3 / C3 CO m § k 013 0 = # 0 ` � K k 2 f § X / o % CO ) el Z $ m = ff } $ . 2 m a, � . \ ƒ _ � in % 2 m Q u U E q \ % 7 / \ e-, / _ / 2 \ en \ x / # 2 / _ \ S _ f ) • 3 = o ® � o ® E 777 / \ E 2 cc co t 2 ƒ � � / \ \ . k \ ~ ~ a) j y ) m m < 5 / 7 / 7 lc'4.--- ' r < . 0 a 0 m 0 E e u \ $> / \ 0\ 15 al k QJ Ea - co 3 3 % \ ro a) ' 25 gs /\ /\ a m = 7k sok /& � § 1 \ ƒ � E \ ■ d - c ) 2 ` � Lu m m « m ! • tr Engineering Test Summary Packer Repair Tool Beads—Feasibility Test Summary \....•#e" Test A: Test was conducted using a 10 ft 3.50"OD heater with BiSN-138 alloy beads in the annulus.The height of the alloy beads was matched with the length of the heater resulting in approx 1000 lbs.of alloy in the annulus.The heater was loaded with Mix 1.5 crumble to a density of around 30 gms/in3 resulting in a total of 17.5 kg thermite in the heater. The setup was heated to 93°C and raised to an angle of 68' (22°deviation from vertical)from the ground to simulate the well condition.The heater was fired at a pressure of around 1800 PSI, max recorded pressure was 2500 PSI.Once the heater had stopped burning the pressure in the vessel was regulated at 2000 PSI. A pressure test was then conducted at 93°C and the seal was qualified to 3500 PSI from both top and bottom. The test successfully demonstrated the use of Mix 1.5 crumble in a 3.50"OD heater in order to generate a competent annular seal between the 4.50"tubing and the 8.50 ID casing by melting alloy beads which were dropped into the annulus from the surface. Test will be repeated using HEC polymer gel as the testing fluid instead of water to determine the effect of the polymer on the quality of the seal. Note:The gradual drop/rise in pressure during the seal qualification at temperature(Fig.5)is because of difficulty to maintain a steady temperature of 93°C during the short term hold. It must be noted that no communication was seen between the top and the bottom during the test.Long term temperature stabilization and hold is necessary to get the desired graph.Test B is planned to incorporate such a long term hold. tif s v 1 *4 Figure 2:Test A,closeup of the plug The information in this report is to be treated as confidential and not distributed to any 3`d party without BiSN's permission Page 6 of 9 Engineering Test Summary B i t Packer Repair Tool Beads—Feasibility Test Summary (Isd)ainssaid I § § s 0s + fa P Y Y w ' SN % i uUF t I T I I aIIV_VF1I 1 1 \ .. \ C co - Yfoo A no 0 LW 1 cp O !♦ m x r Lis.r.‘ ✓ ._N• n � .► 4 \ v — p c u tumucI , ry 6 cI IC E._ 7 gU _ u ��tir W Ti r►S� ... r a 2 3 u 11 6 / • H • • • • I 8 f p 8 op O ry 8 $ S 8 go, D N (j)ajnieJadwaj Figure 3:Test A Firing Data The information in this report is to be treated as confidential and not distributed to any 3'd party without BiSN's permission Page 7 of 9 • . Engineering Test Summary Packer Repair Tool Beads—Feasibility Test Summary BiSN Test 0030-001 Ambient Pressure Test 4000 3500 3000 2500 ^+ 12000 1500 1000 500 0 t--1- 0 5000 10000 15000 20000 2500. Time(Sec) -Top Pressure pe -Bottom Pressure psi -TOP WATER TEMP CH 14'C Figure 4:Test A Pressure Test Ambient Test 0030-001 Pressure Test 2 @ 90C 4030 3500 3000 .. rrrr___---- 60 -,2500 5 1000 60 r— .n0 40 1030 20 3 0 2000 4000 6000 8000 10000 12000 14000 16000 16000 20000 lime(Seo) —.Top P6 essure Bottom Presswe Top Wale, -.:ttam Water Figure 5:Test A Pressure Test at Temp The information in this report is to be treated as confidential and not distributed to any 3rd party without BiSN's permission Page 8 of 9 S • "! Engineering Test Summary BiSN Packer Repair Tool Beads—Feasibility Test Summary Report Written by: Didhiti Talapatra Date: 8/29/2017 Report Approved by: Sylvain Bedouet Date: 8/29/2017 The information in this report is to be treated as confidential and not distributed to any 3'd party without BiSN's permission Page 9 of 9 T 0Er goo L)� O LL I a- x (0a .0 ca A O a _ f Y -CI— 1 ' -J z a o > 0 FE - o LJ a u vi j Y �,_, (V c O c -a w r0 Y _cp T 0- Q Q0 -0 co m CO o m co m 0 0CI) —" m ❑ �p Y u Y L J V Y N JY Q O C C C C a d C N a) OC C H J -) ) 16 , a1 a1 ") co f0 H ..I M '� LL LL Y N M N M r E C a1 Q (11 _N Z 0 Ou -0 u O T ix v > a1 "a > t COY M3 0 ❑ ❑ O ❑ ❑ ❑ O li• '. to 0 O H' WLI. CD u W WWW W W DA C y vl _ Q J J J J J J J OC 65 1" Q Q Q Q Q Q Q O_ YC 0 O O u o p cc •� LL LL LL U LL LL LL C w U ` coO O M Y > Y u Y W C ,....... 'E v � O O Gtn , Q CD +-, -0 ✓ H zv 0 Z.0 ets c o - v a c0 Z 2• V 2 f- F- F- ¢ C ft-CO aR1 vV) o o C11 yy W o U U U J J ~ Yr 4c O CI co co ❑ N ❑ ,, C CO O* J J J J J C� "CI 0m m m CO LD = E. O < U U0 N ao U w, 1:11 Q tl: J v Or� r p =LIJ t0 00 X04 )_ g G a O , z dtC v a 0 0 0 0 J O Jva L. w ci2_914P I CO COm m co 03 ZL11 L.11 W LU w 0 0 0 Y 0 Q 0 O o 0 a 0 0 0 LAJDnDE ® LL O d 0 a a a a 0. c � Y co 11 x In v `J ,o 0 LU coN0000 c.0 O O Lo 0, CJ.. 00 • C'V 0 0 0 C. 0 0 0 C O 0 o 0 0 0 0 0 o O la G•4 arn 0 0 0 0 rn w a > o) v N c0 > .- V 00 N N 00 j R �1 > co co ›- OCC-) 0 cu ¢ v W N V co a _ m iii u_ a iti Cr S O O O O m u (D 0 0 0 0 0 0 O Q C N • a M ° u) � N co ++ ¢ U) � 00 CO N u 'cf 0 N CO O M f0 -0- N _ n O N O N a+ N p, N N N N N N N m I:^ Q 6 6N N N N N N N & O V' 0 0 0 0 0 0 0 C '^ — o O O O O O O f v U) U) N U) in U) U) y, a' m CO C 2 'Oa) w Q2 in E u OCD O gj a) O Q) CZ Q w OC n u c� p Q7 �L 1� CO csi Q CO !A)CZ b ~) m Z N O N N M a-+ = N : ++ D'2 H J Y N v E Z ars V R �_ a Q pN o o z o C � o i al O M- M.a a m Imj~ '9 Project Well History File Cov{ Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Rt=~CAN DIGITAL D~R~ OVERSIZED (Scannable) ~. Color items: ~~Diskettes, No. )(~) [] Maps: ~ Grayscale items: [] Other, No/Type [] Other items scannable by large scanner -', Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~ x 30 = BY: BEVERLY ROBIN VINCENT SHERYI,~~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE:~-?J ~..~.. ~1/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES / Stage 2 IF NO IN STAGE '~, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is~ Quality Checked 12110/02Rev3NOTScanned,wpd • • June 25, 2009 u . P- F r~=-~~ ~ ~~~=~=~~'~tf~: ~_> Mr. Tom Maunder JUL ~~ 2009 Alaska Oil and Gas Conservation Commission ~~~~~~~~ ~e~ ~_ ~~~ ~~r~~~ ~~~r~i~~i~r 333 West 7th Avenue ~~r~~~~~e~~~R Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad p~,~ Q"" ~~ ~ ~ '~-~ ,~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells 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, _ ~~ ~~~~`* :J ~;~~ ~` ~ 20C~'` ~~ ~.~: ~- 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) &pad ~ Date s/25/2009 Well Name PTD X , Initial top oi cement Vol. 01 cement um ed Final top of cement Cemem top off date Cortosion inhibitor Corcosion inhibitod sealant date ft bb~s ft na al S-O18 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 5-03 1811900 7325 NA 1325 NA 92.65 5/20/2009 S-oa 1830790 0 NA 0 NA o.9 5/25/2009 S-OSA 1957890 0 NA 0 NA 0.9 5/26I2009 5-06 1821650 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 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.a 5/31/2009 5-118 1990530 025 NA 025 NA t.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1I2009 5-73 1821350 6 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 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 5-19 1867760 0.75 NA 0.75 NA 2.2 5/19/2009 S-20A 2010450 0.25 NA 025 NA 1.3 5/19/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 7970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 NA 0.25 NA 7.7 5/25/2W9 S-24B 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 0.75 NA 3.4 5/26l2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/37/2009 S-29AL1 1960120 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 S33 7921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1927360 0.5 NA 0.5 NA 3.4 5/37/2009 S35 1921480 0 NA 0 NA .e5in 5/31/2009 S36 1921760 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 0.25 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 7970530 0.5 NA 0.5 NA 1.7 5/28/2~9 5-44 1970070 025 NA 025 NA 1.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001750 125 NA 125 NA 11.9 5/29/2009 S-102L1 2031560 725 NA 125 NA ~t.7 5/31/2009 5403 2001680 1.5 NA 1.5 NA 77.5 5/18/2009 S-7aa 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-705 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010720 1625 NA 1625 NA 174.3 6/2/'2009 S-107 2077130 2.25 NA 225 NA 28.9 5/78/2009 S-~oe 2071000 3.5 NA 3.5 NA ao 5/30/2009 S•109 2022450 2 NA 2 NA 21.3 5/30/2009 5-1~0 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-11t 2050510 2 NA 2 NA 79.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA Y2.1 5/18/2009 S-t~4A 2021980 125 NA 125 NA 102 5/30/2009 S-715 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-717 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28J2009 S-it9 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-722 2050810 3 NA 3 NA 21.3 5/29/2009 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 7.75 NA 1.75 NA 11.9 5/26l2009 5-125 2070830 225 NA 225 NA 20.4 5/2&2009 S-t26 20710970 125 NA 125 NA 15.3 6/1/2009 5200 1972390 125 NA 125 NA 14.5 5/28/2009 5-207 2001&40 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 73.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-2ts 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/t/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA i6 NA 99.5 6/2l2009 5-504 0 NA 0 NA 0.&S 5/28/2009 Sehlamherger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth :~:l;s~.~~9~ NOV L ~ 2007 Well Job # Log Description Date 5-201 11676972 LDL 11I07I07 5-126 11594528 ISOLATION SCANNER 11/01107 1 V-205 40014729 OH MWD/LWD EDIT / 01/29107 2 1 V-205L1 40014729 OH MWDILWD EDIT ~ 02/03107 1 1 V-205L2 40014729 OH MWDILWD EDIT 02112/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH l'O: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 ! 1 Date Delivered- NO. 4487 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris ~~ Aurora Orion ~/1 ~ ...~~ BL Color CD ~~,,JJ ~ .,F~1/f 1 ` N' Schlumberger-DCS 2525 Gambell St Srrite'40~ ~ ~ -' Anchorage, AK 99503-28t38'" ~~ }',I ATTN: Beth - ~ '~ Received by. __.. .~ _/'. `~) "(I" r 11/08/07 C: • MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0 7/"/ P.I. Supervisor 1"-.<1' fP. ð? DATE: Wednesday, January 31, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-201 PRUDHOE BA Y UN POL S-20 I FROM: Lou Grimaldi Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Suprv :JB.f2-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UN POL S-201 API Well Number 50-029-22987-00-00 Insp Num: mitLG070130185304 Permit Number: 200-184-0 Rellnsp Num Inspector Name: Lou Grimaldi Inspection Date: 1/30/2007 Packer Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well is ajet pump producer, te~t is for application to increase MASP on IA. ~ i-ox- ~~pt~ sc.ANNED FEB 0 7 2007 Wednesday, January 31,2007 Page I of I MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001840 MD 7245 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UN SHB S-201 Operator BP EXPLORATION (ALASKA) INC 5613 ,,,'/ Completion Dat 12/2/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22987-00-00 UIC N ._ REQUIRED INFORMATION Mud Log Nc) Sample Nc) Directional Survey Nc) DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No L L ~/GR ,l~=R'S-~rvey Report ~y Report ~ey Report ~urvey Report ,.~rvey Report Suey Report y Report ~FU NEU/DEN 2/5 ~.~:V~ GR/ROP/RES 2/5 .J~ROP/RES 2/5 LIS Verification ~,flf~'"'DD"Su rvey Report .,., RS ~gma, WFL, 5 (data taken from Logs Portion of Master Well Data Maint Interval Start Stop OH I Dataset CH Received Number FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 3750 225 197 6150 197 197 225 225 225 225 6150 6150 7043 7245 4739 7050 7211 7211 7245 4769 4769 4769 7050 7050 CH 1/10/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 1/9/2001 Open 7/18/2001 Open 7/26/2001 Case 5/29/2001 Open 7/26/2001 OH 6/27/2001 oh 7/18/2001 OH 7/2/2001 OH 7/2/2001 OH 7/2/2001 CH 6/27/2001 1/9/2001 ch 6/112001 ch 6/1/2001 C H 6/14/2001 Comments 3750-7(~4~3'~'~- Print ..... Survey Report Digital Data Survey Report Paper Copy Survey Report Digital Data Survey Report Paper Copy Survey Report Digital Data Survey Report Paper Copy S.~ey Report Digitall.,Data 10190/.,,E'25-7245 (3 ,~lnJN ~~-4739 ~'1~21;~7-7211 10190~'225-7245 Digital Data ., 225-4769 BL, Sepia 225-4769 BL, Sepia 225-4769 BL, Sepia LIS Verification, Paper Copy Survey Report Paper Copy ; /~ ' 100~0-7050 Digital Data 6150-7050 BL, Sepia LIS Verification, Paper Copy: DATA SUBMITTAL COMPLIANCE REPORT 1/16/2003 Permit to Drill 2001840 Well Name/No. PRUDHOE BAY UN SHB S-20t Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22987-00-00 MD 7245 TVD 5613 iD D Completion Dat 12/2/2000 ~G~ NEU/DEN 2/5 Completion Statu 1-OIL FI NAL 197 4739 FINAL 225 4769 Current Status 1-OIL UIC N OH 6/14/2001.~~'~'~-~ 3~-~i-gita i Data' OH 712/2001 225-4769 BL, Sepia Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ ChipS...~~ Analysis ~ ',' /" - · R ~.c~.iv~.~. Start Interval Stop Sent Received Daily History Received? Formation Tops Dataset Number Comments ~N Comments: Compliance Reviewed By: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ INSTALL JET PUMP Pull tubing _ Alter casing _ Repair well _ 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_ Service_ 4. Location of well at surface 693' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2704' FNL, 700' FEL, Sec. 27, T12N, R12E, UM At effective depth 2747' FNL, 804' FEL, Sec. 27, T12N, R12E, UM At total depth 2704' FNL, 830' FEL, Sec. 27, T12N, R12E, UM (asp's 618931, 5980790) (asp's 617394, 5983813) (asp's 617286, 5983990) (asp's 617260, 5984032) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-201 9. Permit number / approval number 200-184 / 302-126 10. APl number 50-029-22987-00 11. Field / Pool Polaris Field / Schrader Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 104' Surface 3161' Production 7207' 7245 feet Plugs (measured) 5613 feet 7100 feet Junk (measured) 5477 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arctic Set (Approx 133' 133' 9-5/8" 385 sx AS Lite 3, 280 sx Class 'G' 3190' 2845' 7" 421 sx Class 'G' 7233' 5602' Perforation depth: measured OpenPerfs 6640'-6730', 6833'-6841' ~;~[~,~lV~'L~ true vertical Open Perfs 5047'-5052', 5227'-5235' NOV 0 2002 Tubing (size, grade, and measured depth) 3-1/2" 9.3#, L-80 TBG @ 6157'. 3-1/2" 9.3# Tubing Tail to~l~.0il & Gas ~ns. CommJmi01~ Anchorage Packers & SSSV (type & measured depth) 7" x 3-1/2" Packer @ 6157'. 3-1/2" HES 'X' Nipple @ 2200'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Pdor to well operation Shut-In Subsequent to operation 05/08/2002 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 292 192 202 Casing Pressure Tubing Pressure 299 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. ~ R.~Schn orr~,'~~~. Title: Technical Assistant Form 10-404 Rev 06/15/88 · Date October 23, 2002 Prepered by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 02/24/2OO2 02/25/2002 02/25/2002 02/26/2002 03/14/2002 03/15/2002 O3/23/20O2 03/24/2002 03/25/20O2 03/26/20O2 04/11/2002 04/12/2002 04/13/2002 04/23/2002 04/25/2002 04/29/2002 10/04/2002 02/24/02 O2/25/O2 02/25/02 02/26/02 03/14/02 03/15/02 03/23/02 S-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 3ET PUMP ]ET PUMP ]ET PUMP ]ET PUMP ]ET PUMP 3ET PUMP .1ET PUMP .lET PUMP .lET PUMP .1ET PUMP .lET PUMP REMOVAL .lET PUMP .lET PUMP .lET PUMP .lET PUMP / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: / ESP: GAS LIFT--TO DUMMY VALVES GAS LIFT--TO DUMMY VALVES AC-MITIA GAS LIFT--TO DUMMY VALVES JET PUMP / ESP JET PUMP / ESP JET PUMP / ESP JET PUMP / ESP .lET PUMP / ESP .lET PUMP / ESP HOT OIL TREATMENT; PARAFFIN / ASPHALTENE / ESP: JET PUMP / ESP / ESP: .lET PUMP / ESP / ESP: JET PUMP / ESP / ESP: FISH; .lET PUMP / ESP .lET PUMP / ESP: .lET PUMP / ESP TESTEVENT--- BOPD: 276, BWPD: 1,776, MCFPD: 201, AL RATE: 0 EVENT SUMMARY BRUSH & FLUSH TBG W/180' DIESEL (IN PROGRESS). COMPLETE BRUSH & FLUSH. TAG TD W/2.8" GAUGE RING @ 6890' SLM (TARGET DEPTH = 6841' MD). SET 2.813" XX PLUG @ 6120' SLM. SET 3 1/2" WHIDDON C-SUB. PULLED STA# 1 RK-OGLV; STA# 3 RK-LGLV. SET STA# 3 RK-DGLV. SWEEP IA W/200 BBLS DIESEL TAKING RETURNS DOWN FLOWLINE. SET STA# 1 DGLV. MITIA TO 2500 PSI---PASSED. PULLED STA# 1 RK-DGLV. SET STA# 1 RK-FLOW SLEEVE. PUMPED 5 BBLS DIESEL THROUGH FLOW SLEEVE TO CONFIRM COMMUNICATION. PULLED C-SUB. PULL XX PLUG (IN PROGRESS). LOAD AND TEST IA. PULLED 2.813" XX PLUG. RDMO. LEFT WELL SHUT-IN. DRIFT AND LOCATE END OF TUBING - CORRECT TO RKB. SET SLIP STOP @ 6069' SLM. START CCL LOG FROM 6069' TO 0' IN PROGRESS. SET BOTTOM SEAL ASSEMBLY 25" LONG. SET PUMP ASSEMBLY. 21' LONG W/UPPER SEAL MANDREL. SET UPPER SLIP STOP.RDMO NOTIFY DSO PULLED TOP 3 1/2" SLIP STOP @ 6047.2' AMS --- LATCH 21' PUMP ASSEMBLY @ 6048' AMS, MOVE 40' UP HOLE. Page 1 03/24/02 03/25/02 03/26/02 S-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PULLED 3 1/2" JET PUMP ASSEMBLY 21' LONG AND LOWER SEAL ASSEMBLY - -- RAN 2.79" CENT & 2.74" LIB TO TOP OF SLIP STOP (IMPRESSION OF CLEAN F-NECK ON LOCK) (PULLED UPPER AND LOWER SEALS OFF OF TOOLS WHILE PULLING, BUT WAS ABLE TO RECOVER ONLY 1/2 OF 1, THERE STILL IS 1 & 1/2 MISSING DOWN HOLE) ****NOTIFY DSO TO LEAVE WELL SHUT- IN**** PULLED LOWER SLIP STOP FROM 6071.5 AMS --- DRIFT W/3 PRONG WIRE GRAB AND BRUSH. FISHED LOWER PACKOFF ELEMENT, TAG TD @ 6890' SLM -- SET JET PUMP ASSEMBLY (ALL DEPTHS FROM AMS) (NOTE: HALF OF PREVIOUS UPPER PACKOFF ELEMENT STILL IN HOLE) RDMO **** NOTIFY DSO TO POP WELL 04/11/02 04/12/02 DRIFT TO 4500' SLM UNABLE TO GET DOWN HOLE DUE TO TO PARAFFIN RDMO. HOT OIL TBG WITH 108 BBLS OF 190' F DIESEL. D/T TOP Of JET PUMP ASSEM. PULL UPPER SLIP STOP, PULL UPPER PACKOFF & JET PUMP, PULL LOWER PACKOFF ASSEM. ( LOWER PACKOFF RUBBER ELEMENT IN HOLE ) RDMO. FOR RIG JOB ( WELL SHUT IN ) 04/13/02 04/23/02 04/25/02 04/29/O2 10/04/02 FISH LOWER PACKING ELEMENT & AD2 SLIP STOP ( JET PUMP & ALL RELATED EQUIP. CCH ) RDMO ( LEFT WELL SHUT IN, NOTIFY DSO OF WELL STATUS) ATTEMPTED TO SET PACKER AND JET PUMP. BOTTOM PACKER FAILED TO SET @ 6095' AND DROPPED DOWN HOLE. USED SLOW BURN SETTING CHARGE BUT BURN TIME WAS VERY QUICK (10 SECONDS) LEFT WELL SI, NOTIFIED DSO OF STATUS. RAN 2 7/8" GS & 3 1/2" ECLIPSE SL ADAPTER TO 6112' WLM. PULLED 3 1/2" ECLIPSE LOWER PACKER ASSEMBLY. RDMO. LEFT WELL SHUT IN. NOTIFIED OPER. MIRU #2158, NOTIFY OPERATOR OF JOB SCOPE, RIH WITH LOWER JET PUMP PACKER, SET THE PACKER W/MID-ELEMENT AT 6095', APPROX 3' BELOW BOTTOM GLM, POOH, RIG UP UPPER PACKER ASSEMBLY, RIH AND STING INTO LOWER PACKER, SET UPPER PACKER & POOH, RDMO, NOTIFY PAD OP WELL STATUS IS SHUT IN TESTEVENT--- BOPD: 276, BWPD: 1,776, MCFPD: 201, AL RATE: 0 Page 2 S-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 3 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, 13 TESTS) 348 DIESEL 351 TOTAL Page 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: INSTALL JET PUMP Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ INSTALL JET PUMP 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 _ Service_ 4. Location of well at surface 693' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2704' FNL, 700' FEL, SEC 27, T12N, R12E, UM At effective depth 2747' FNL, 804' FEL, Sec. 27, T12N, R12E, UM At total depth 2704' FNL, 830' FEL, Sec 27 T12N, R12E, UM (asp's 618931,5980790) (asp's 617394, 5983813) (asp's 617286, 5983990) (asp's 617260, 5984032) 6. Datum elevation (DF or KB feet) RKB 64.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-201 9. Permit number / approval number 200-184 10. APl number 50-029-22987-00 11. Field / Pool Polaris Field / Schrader Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 104' 20" Surface 3161' 9-5/8" Production 7207' 7" 7245 feet 5613 feet Plugs (measured) 7100 feet 5477 feet Junk (measured) ',, Cemented Measured Depth 260 sx ArcticSet (Approx) 133' 385 sx AS Lite3, 280 sx Class 'G' 3190' 421 sx Class 'G' 7233' True vertical Depth 133' 2845' 5602' Perforation depth: measured Open Perfs 6640' - 6730', 6833' - 6841' true vertical Open Perfs 5047' - 5052', 5227' - 5235' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) RECEIVED 3-1/2", 9.3#, L-80 TBG @ 6157' MD. 3-1/2" 9.3# Tubing Tail to 6214'. 7"x 3-1/2" Baker S-3 Production Packer @ 6157. 3-1/2" HES 'X' Nipple @ 2200'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation April 18, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ....... ' Title: Polaris Lead Engineer Don Schmohr FOR COMMISSION USE ONLY Questions? Call Don Schmohr @ 564-5494. Date April 11,2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance _ ol .I Mechanical Integrity Test_ Subsequent form required 10-~'~ O Approved by order of the Commission Form 10-403 Rev 06/15/88 · J Approval no~.~Oa,~.. ~, Original Signed By ORIGINAL Commissioner Date SUBMIT IN TRIPLICATE bp ( April 11,2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice to Install Jet Pump in well S-201 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) S61.Sl 11 BP Exploration Alaska, Inc. proposes to install a jet pump on well S-201. The objectives are: · To prove up the design of a permanent jet pump installation for the Polaris prior to a permanent installation. · Reduce operating costs and improve downtime of Polaris wells. Contacts Office Home Mobile Donn Schmohr 564-5494 Brit Agler-Weatherford 248-1005 Joe Simpson-Downhole Solutions Wellwork Backl09 Sieps Step Category IOR Job Description 345-4861 529-8796 244-4157 1 S 300 2 E 300 Remove Jet Pump, packoffs and tubing stop Run Eclipse Pkr-Jet pump assembly across bottom GLM Well Parameters Last Test: Well Status: Max Deviation: Min ID: Last TD Tag: Last Downhole Operation: Latest H2S Value: Reference Log: BHT & BHP: 338 BOPD, 2573 MSCFPD, 114 BWPD with 2460 MSCF lift gas on 12/27/01. Shut-in & freeze protected 57° at 4414' MD 2.813" X Nipples - see well bore diagram 11/16/01 at 6922' CTU Cleanout Not available. Offset S-200 measured 10ppm 8/14/00 Sperry EWR12/3/00 100°F & 2200 psi Don Schmohr Polaris Field / Schrader Pool Polaris Lead Engineer Procedure for --- Slickline Work To pull the pack-off assembly 1) Equalize the tubing and casing. Go in hole with GS pulling tool, latch and jar up to release the AA tubing stop. POOH. 2) Run in hole with GS pulling tool, latch and jar up to shear the upper pack-off assembly, releasing the rubber element. Pull upper assembly, top spacer pipe, jet pump, lower spacer pipe and stinger out of hole. 3) Run in hole with GS pulling tool, latch and jar up to shear the lower pack-off assembly, releasing the rubber element. POOH. 4) Run in hole with GS pulling tool, latch the AD-2 tubing stop, jarring up to release the stop. POOH. 5) Take AKE jet pump to Weatherford at Deadhorse and ask them to ship (as previously arranged) to Weathorford in Anchorage, ATTN. Brit Agler. E-Line Work 1) The jet pump, two 3-1/2" eclipse packers, seal assembly and x-overs have been inspected in Anchorage and laid out to insure all connections are compatable. Joe Simpson with eclipse will be on location during the running of the assembly. It is not necessary to have a Weatherford service hand on location. 2) Rig up E-line and set the packer/jet pump assembly across the bottom gas lift mandrel per the attached procedure. Jet pump Startup: 1) Open power fluid (produced water) valves to the inner annulus by opening all block valves and opening the choke until the downstream pressure stabilizes at 1200 psi. 2) At approximately 1-2 hour increments open the choke at 100-200 psi increments until the power fluid choke is full open. 3) Expected power fluid rate with a full open choke is 1500-1800 bpd. Stable well head temperature will be 100F-105F. Note: Failure of the jet pump or packer seals across the gas lift mandrel will be indicated by a rapid rise in WHT to -115F to 120F and possibly a rapid decrease in annulus pressure. If this happens immediately shut in and freeze protect the well. If it is left on line it will result in flooding the formation with power fluid at a very high rate. TREE = 4-1116" - 5M CIW L-80 WF! LI-r=AD= 11"- 5M FMC G5~, ~ ~m, ~ SAFETY NOTES: Sm=WELL FILEFOR ACTUATOR= ...... ~ _~11~ .'~.I , PULLING PROC EDURE OF JET PUMP. KB. ELEV = 64.4' , ;BF. FI EV = ' .... ~ KOP = 1800' Max Angle = 57= @ 4414' Dalum TV D= 5466' SS ' GAS LIFT MANDRELS J ST IVD TVD DEV TYI~ VLV LATCH FORT, DATE 3 4618 3568 54 CAM-NIVlM RK Minimum ID = 2.813"" (~ 2200" 2 6024 4442 35 CAM-MVIM RK Nipple , ,1 6084 4491 35 CAM-IVlVIM RK 3-112" HES I I t ~*~' I-'1 ~-'~""~"~'~,'~=~'*'~" I ~ 7" X 10' SHORT ~OIIgr W/I~ TAO I PERFORATION S UtvlVlARY RB= LOG: ANGLEAT TOPPERF: 21 @ 6640' ' ' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE ~-~,~'~' ~' ~o-~o~.~.~ o° o~o~°~°~°~ i ~ .t,?. lq ~..×~0.~.o~o.~~^~ I , I ' 7" CSG, 26#, L-80-BTC-M, ID = 6.276" I 12/13/00 I:~$ ORIGHAL COMFt. EI1ON 081~0101 DAGttlh ELM DEF~'H,~KR GORFt~T ~r_.Ll.: 8-201 12/14/00 $15-$LT GONYERTED TO CANYA$ 10102/0'1 SRB/tlh ADD ~EI~:$ PEI~II No: 200-184 01120101 Sl$-I.O RB/I$10~ 0~115102 CJS/KK SEI'JE'I'~UM~ Alt No: 50-020-22~87-00 03/16/01 CH/'rP CORRECTIONS SEC35,T12N,R12E 03/26/01 GN/'rLP II~TIAL PB=,FS BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 2-11Z' 4 6640- 6730 O 10/02/01 2-11Z' 4 6833- 6841 O 03/26/01 bp BP Exploration (Alaska) Inc. 900 East Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 November 05, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501 Re: S-201 Prudhoe Bay Field / Polaris Pool Dear Mr. Maunder, Well S-201 was perforated and fraced without the Form 10-403 being submitted to the AOGCC before the work was done. This was an over slight on my part. I have completed and included the Form 10-404 that details the work that was done on this well. Please accept my apology for not submitting the 10-403 on time. I will do better in the future. Sincerely, DeWayne R. Schnorr Technical Assistant RECEIVED NOV 0 ? 2001 .A~asI~, 0i~ & G~s Co~s. Co,'nr,~issior;, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Sandbacld AdPerfl Frac Pull tubing _ Alter casing _ Repair well _ Other_X SANDBACK 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development mX Exploratory__ Stratigraphicm Service__ 4. Location of well at surface 693' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2704' FNL, 700' FEL, Sec. 27, T12N, R12E, UM At effective depth 2732' FNL, 813' FEL, Sec. 27, T12N, R12E, UM At total depth 2704' FNL, 830' FEL, Sec. 27, T12N, R12E, UM (asp's 618931, 5980790) (asp's 617394, 5983813) (asp's 617277, 5984005) (asp's 617260, 5984032) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-201 9. Permit number / approval number 200-184 10. APl number 50-029-22987-00 11. Field / Pool Polaris Field / Schrader Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 104' Surface 3161' Production 7207' 7245 feet Plugs (measured) 5613 feet 7149 feet Junk (measured) 5523 feet Size Cemented Measured Depth 20" ' 260 sx Arctic Set (Approx 133' 9-5/8" 385 sx AS Lite 3, 280 sx 3190' Class 'G' 7" 421 sx Class 'G' 7233' True Ve~ical Depth 133' 2845' 5602' Perforation depth: measured Open Perfs 6640'- 6730', 6833'- 6841' true vertical Open Perfs 5047'- 5052', 5227'- 5235' Tubing (size, grade, and measured depth) 3-1/2" 9.3#, L-80 TBG @ 6157'. F EC :: VED NOV 0 7 00! Alaska 0il & Gas Cons. Commission 3-1/2" 9.3# Tubing Tail to 6214', Anchorage Packers & SSSV (type & measured depth) 7" x 3-1/2" Packer @ 6157'. 3-1/2" HES 'X' Nipple @ 2200'. 5-1/2" SSSV Landing Nipple @ 2991'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 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. ~ Title: Polaris Lead Engineer Donn Schmohr Date October 31. 2001 Prepared b~/DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORlgiixlAL,. SUBMIT IN DUPLICATE 08/20/2001 09/06/2001 09/06/2001 09/13/2001 09/25/2001 09/29/2001 09/30/2001 10/01/2001 10/02/2001 10/03/2001 10/04/2001 10/04/2001 10/06/2001 10/08/2001 10/09/2001 10/22/2001 10/23/2001 10/24/2001 08/20/01 09/06/01 09/06/01 09/13/01 09/25/01 09/29/01 09/30/01 S-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS HOT OIL TBG WASH: HOT OIL TREATMENT HOT OIL TBG WASH: JET ICE PLUG/DRIFT TUBING HOT OIL TBG WASH: HOT OIL IA HOT OIL TBG WASH: HOT OIL TUBING & FLOWLINE TREATMENT HOT OIL TBG WASH: HOT OIL TREATMENT FRACTURING.: GLV C/OUT FRACTURING.: DRIFT & TAG / GLV C/OUT FRACTURING.: SAND BACK/PERF FRACTURING.: SAND DUMP/MEM LOG/TCP/PRE FRAC HOT OIL TBG WASH: SET SPMG IN STA# 1 FRACTURING.: SET SPMG FRACTURING.: LOAD & TEST IA W/CRUDE FRACTURING.: OA-OAB FRAC FRACTURING.: PULL SPMG / INSTALL GL DESIGN (IN PROGRESS) FRACTURING.: INSTALL GL DESIGN FRACTURING.: FCO FRACTURING.: FCO HOT OIL TBG WASH: HOT OIL TUBING WASH EVENT SUMMARY RU HB&R TO TREECAP. PUMP 19 BBLS HOT CRUDE AND WELL LOCKS UP 3,000 PSI.---ESTIMATE PLUG DEPTH -2200' . SWAP TO FLOWINE AND PUMP REMAINING 95 BBLS HOT CRUDE TO SYSTEM. ***NOTIFY OPERATOR TO LEAVE WELL SI PENDING FURTHER WELL WORK.*** MIRU CTU #3. RIH W/2.5" DOWN JET NOZZLE. TAG ICE PLUG AT 1420' CTM. JET THRU 10' BRIDGE AND CONTINUE RIH PAST TBG TAIL TO 6250' CTM W/O ENCOUNTERING ANY ADD'L ICE PLUGS. POOH AND TURN WELL OVER TO PAD OPERATOR/PCC TO LEAVE SHUT-IN PENDING GL INSTALLATION. LOAD IA WITH 100 BBLS OF 190' F CRUDE. HOT OIL TUBING & FLOWLINE TREATMENT HOT OIL TREATMENT TAGGED PBTD AT 6925'SLM W/2.31"DRIFT. APPRX 84' OF RATHOLE. BOTTOM PERF=6841' TAGGED PBTD AT 6938' ELM W/2.5" DG. PULL STA #4, 1.5" OGLV RK. PULL STA #1, 1.5 LGLV RK. SET STA #4 AND STA #1, 1.5 DGLV RK. WELL SHUT IN ON DEPARTURE. NOTIFY DSO. Page I 10/01/01 10/02/01 10/03/01 I O/O4/O 1 10/04/01 10/06/01 10/08/01 10/09/01 10/22/01 10/23/01 10/24/01 $-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS MIRU DS CTU #5. RU DS CEMENTERS. RIH, TAG TD AND CORRECT DEPTH TO 6938' ELMD. LAY IN 3700# OF RIVER SAND. TAGGED TOP HIGH AT 6735' ELMD. REVERSE OUT AND CLEAN SAND TOP TO 6780' ELMD. TAG AND CONFIRM SAND TOP AT 6787' CTD. HOLD 1500 PSI WHP FOR 15 MIN, GOOD TEST. POOH. MU SWS MEM LOG CCL/GR TOOLS, RIH. RIH WITH SWS MEM CCL/GR TO LOG FROM 6100' TO SAND TOP TAG. PLACE TIE IN FLAG, POOH. GOOD MEM DATA SHOWS SAND TOP TAG AT 6794' CORRECTED, FLAG DEPTH IS 6576' CORRECTED. RIH WITH TCP GUN #1, (2.5", 4 SPF, 35B, UP, RDX, 0.62" EH, 5.8" PEN), SHOOT FROM 6730'--6710'; GUN #2, 6710'-6690'; GUN #3, 6690'-6665'; GUN #4, 6665'-6640'. ALL SHOTS FIRED. WELL AND FLOW LINE FREEZE PROTECTED WITH 50/50 METH. *** WELL SHUT IN *** SET 3 1/2" X-LOCK C-SUB. PULLED STA# 1 RK-DGLV. SET sta# 1 RK-SPMG. PULL 3 1/2" X-LOCK C-SUB. *** GAVE WELL BACK TO PAD OP. LEAVE SHUT IN FOR FRAC JOB *** LOAD AND TEST IA TO 3500# - PASSED MIT. FRAC'D OA-OAB SANDS WITH YF130LG & 3K# 20/40, 156K# 16/20, 39K# 16/20 RCP (197.5K# BEHIND PIPE, 1.3K# LEFT IN CSG). EST. TOS-6690'. INTENTIONALLY UNDERFLUSHED BY 5 BBLS, TBG FREEZE PROTECTED WITH DIESEL TO 3220'. AVG TREAT 3740 PSI, MAX TREAT-4960 PSI. LOAD TO RECOVER-1513 BBLS. TREESAVER CUPS RECOVERED. TAG TD W/2.6" CENT @ '6645' MD(RKB). SET 3 1/2" X-LOCK C-SUB. PULLED STA# 1 RK-SPMG: STA# 3 RK-DGLV. SET STA# 3 RK-LGLV; STA# 1 RK-OGLV. PULLED C-SUB. RDMO. LEFT WELL SHUT-IN. MIRU CTU #8. LINE WELL UP F/RETURNS TO FACILITY ON GAS-LIFT ASSIST. JET THRU MULTIPLE ICE/HYDRATE BRIDGES FROM 1973' TO 3700'. CLEANOUT CARBOLITE TO 6787'. HIT CRUST. SPUD THROUGH. CLEAN RIVER SAND OUT TO 7080'. HARD BTM @ 7080'. PUMP FINAL GEL SWEEP. CHASE TO SURFACE @ 80% LINER/65% TBG. CONTINUE POH. FREEZE PROTECT COIL. ON SURFACE. RIG DOWN. PUMP 13 BBLS OF 180 DEG CRUDE DOWN THE TUBING @ 2 BPM. WELL LOCKED UP AFTER 13 BBLS. Page 2 (, S-201 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 4 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (4 TESTS) 5 METHANOL WATER 65 60/40 METHANOL WATER 357 50/50 METHANOL WATER 767 DEAD CRUDE 110 DIESEL 1855 2% KCL WATER 490 SLICK 2% KCL WATER 52 EXTRA SLICK 2% KCL WATER 140 30 PPT HEC GEL 3845 TOTAL ADD PERFS 10/02/20O 1 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-1/2" ULTRA-PACK 4SPF, RANDOM ORIENTATION. 6640' - 6730' Page 3 TRR: = 4-1/16" - 5M CIVV L-80 " WELLI-EAD= 11" - 5M FMC G5 I SAFETY NOTES I ? S-201 KB. FIEV = 64.4' BF. ELEV = ? KOP = 1800' I Max Angle = 57° @ 4414' Datum MD = 6894' I =" I 2200' H 3-112" HES 'X' NIP' ID = 2'813" I Datum TV D= 6466' SS I.,~" c~,~o~,.-~TC,,==~.~,, H =~o. i-~ GAS LIFT MANDRELS ST IVD '[VD DEV TYPE VLV. LATCH FORT DATE 4 2752 2536 57 CAM-IVIVIM RK 3 4618 3568 54 CAM-IVIVIM RK Minimum ID = 2,813" @ 2200' 2 6024 4442 35 CAM-IVlVlM RE 3-1/2" HES 'X' Nipple ~ 6084 4491 35 CAM-IVlVlM RE ,. I -' I I 6144' H ~-~'~""~s'~"'",'~:~."~" I ~ ><~--~]~~" x ~,,~, BA~. ~..o~.<.I I ~ · ~ ' 3-112" HES 'X' NIP, ID = 2.813" · I 7" x 1°' SHORT JOINT W/RA TAOI ' 'l I ~' Iq ~-'°~°~°' I " PERFORATION SUMMARY RB: LOG: : ANGLE AT TOP PERF: '1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/Z' 4 6833- 6841 O 03/26/01 I I 7" CSG, 26#, L-80-BTC-M, ID = 6.276" I I PB'rD 7100' I I7" SHOE H 7233'I' ~ ~ ~' DATE REV BY COMMENTS DATE REV BY COMrvENTS POLARIS UNIT 12/13/00 PGS OI~GNAL COMPLETION 09/30/01 DAC/tlh ELM DEI:q'~PKRCORRECT WELI~ S-201 12/14/00 SIS-SLT CONV~-t~P-D TO CANVAS 10102/01 SRB/tlh ADD PEI~S PERMIT No: 200-184 01/29/01 SIS-LG REVISION APl No: 50-029-22987-00 03/16/01 CH/11:' CORRECllONS SEC35,T12N, R12E 03/26/01 GN/'rLP II~ITIAL P~,FS BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 2-1/Z' 4 6640- 6730 O 10/02/01 2-1/Z' 4 6833- 6841 O 03/26/01 DEPARTMENT OF NATURAL RESOURCF_~ DIVISION OF OIL AND GAS TONY KNO WLES, GO VERNOI~ 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 September 6, 2001 BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612. Anchorage, Alaska 99519-6612 RECEIVED 2001 Alaska Oil & 6as Cons. Commission Anchorage Via Fax (564-4637) and Mail Attention: C-il Beuhler Central New Developments Manager Subject: Pmdhoe Bay Unit Tract Operations for Wells S-200, S-201 and S-213 on ADL 28258, W-200 (ADL 28263), S-216 (ADL 28261), and W-201 (ADL 28282) Dear Mr. Beuhler: Reference is made to your letter of August 31, 2001 regarding a request to continue Tract Operations for PBU Wells S-200, S-201 and S-213 on ADL 28258, Wi200 on ADL 28263, S-216 on ADL 2826.1, and W-201 on ADL 28263-1.. The Division approves your request to extend the Tract Operations. for the six wells' 'from September 1, 2001 until the first of the month following the issuance of the Polaris Participating Area final decision, but in no case, later than November 1, 2001. Sincerely, Mark D. Myers Director cc: Cammy Taylor- AOGCC Wade Fennel- Chevron PBU.PolarisWELLS.TOExtension. doc "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7m Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs: S-201 Polaris July 16, 2001 AK-MM-00275 A-201 Polaris: igital Log Images: 50-029-22987-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATI'ACm~D COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED 'JtL 18 ZOO1 . z'ONY KNOWLES, GOVERNOR 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 July 11,2001 RECEIVED JUL 7,.3 2001 Alaska 0i! & Gas Cons. Commission ~chorage BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 Via Fax (564.4637) and Mail Attention: Gil Beuhler Central New Developments Manager Subject: Prudhoe Ba.y Unit Tract Operations for Wells S2201" and S-213 on ADL 28258, and S-216 on ADL 28261 Dear Mr. Beuhler: Reference is made to your letter of July 10, 2001 regarding a request to continue Tract Operations for PBU Wells S-201 and S-213 on ADL 28258, and S-216 on ADL 28261. The Division approves your request to extend the Tract Operations for the three wells from July 11, 2001 until the first of the month following the issuance of the Polaris Participating Area final decision, but in no case, later than September 1,, 2001. Sincerely, Mark D. Myers Director cc: Cammy Taylor- AOGCC Wade Fennel- Chevron PBU.PolarisWELLS.TOExtension.doc CO~¥i!',~ ~1 : · COMM I~?~ COMM SR RES,ENG RES ENG , , SI:{ ENG _ ENG _ NRO SR GEOL GEOL GEOL A~ST . STAT TECH , STAT TECH , . . 'J~ILE "Develop, Conserve, attd Enhance Natural Resources for Present and Future Alaskans." WELL LOG TRANSMITTAL To: State of Alaska June 27, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs' S-201 PB1 POLARIS, AK-MM-00275 S-201 PB1 POLARIS: 2" x 5" MD Gamma Ray Logs' 50-029-22987-70 2" x 5" TVD Gamma Ray Logs' 50-029-22987-70 2"x 5" MD Neutron & Density Logs: 50-029-22987-70 2"x 5" TVD NeUtron & Density Logs: 50-029-22987-70 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline ' 1 Rolled Sepia ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING.AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun. Drilling ServiCes Attn: Jim Galvin. 6900 ArCtic Blvd. Anchorage, Alaska 99518 Bp Exploration (Alaska)Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED "JUL 0 2 20'01 Ala~Oil & GasCons.~ WELL LOG TRANSMITTAL To: State of Alaska June 22, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S-201, AK-MM-00275 1 LDWG formatted Disc with verification listing. API#: 50-029-22987-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING.AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: .Sperry-Sun Drilling Services Attn: Jim Galvin 6900'Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED, JUN 2 7 2001 AlalkaOil a Gas Cans. C~ WEIJ~ LOG TRANSMII~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs S-201 PB 1, June 13,2001 AK-MM-00275 1 LDWG formatted Disc with verification listing. API#: 50-029-22987-70 PLEASE ACKNO~EDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE THANSMI'I'I'AL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jan Gal~ 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED JUN 1 ZOO1. 512912001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99603-6711 ATTN: Sherrie NO. 1167 CompanY: Alaska Oil & Gas Cons Comm At'm: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Well Job # Log Description Date BL Sepia CD' S-213 ~ (')/') ~}/.~;_;~ . PRESS/TEMP SURVEY 05117101 1 S-201 ,-~¢')O" I~)'(~ 21167 RST 03127101 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 JUN 0 1 2001 ~adm (~! & 6,~ Cons. Commmion Schlumberger Dcs 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A'I-rN: Sherrie . CO SI RYATIO CO I HSSIO May 24, 2001 Gil Beuhler Central New Development Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Subject: Application for Extension of Pilot Production Operations Well S-200; and Initial Production Operations at S-201, 213, and S-216 Prudhoe Bay Unit, Polaris Accumulation (Schrader Bluff Formation), ADL-028258 & 028261 File: Prudhoe Bay Field - Polaris Pool Dear Mr. Beuhler: ., The AOGCC has received an application from BP Exploration (Alaska) Inc.. "(BP)" to extend pilot production operations at the Polaris prospect, Prudhoe Bay Unit, at Well S-200 through July 3 l, 2001 and to initiate pilot production operations at wells S;201, S-213, and S-216 for a period .of six months from the start of production. The request is based on the need for additional information to evaluate primary development and establish a depletion plan. On February 22, 2001, BP provided additional information to Jack Hartz, AOGCC Sr. Reservoir Engineer, regarding primary production and the anticipated pressure. response during the extended production period. The AOGCC approved the original request for a waiver of the GOR limitations of 20 AAC 25.240 for production operations on S-200. The waiver of the GOR limitations is necessary to continue tract and production operations at S-200, and for the initial tract and production operations at S-201, .213 and 216. Prior production reporting and allocation procedures are still applicable. Production should be reported to the Polaris Undefined Pool, number 640160. Your commitment to gather pressure data 'and maintain reservoir pressure above bubble point will ensure reservoir energy is not diminished prematurely. 'The .evaluatiOn work done, in progress, and planned surveillance Will be sufficient to monitor well and reservoir performance for any adverse behavior. We anticipate you will keep the Commission informed about any significant developments. Therefore the Commission approves an extension of the Gas-Oil ratio variance through the end of July 2001 for well s-200, and for a period of six months.from the start of production at wells S-201,213 and. 216, conditioned on reservoir pressure performance.. AOGCC approval is coincident with any restrictions imposed by The Division of Oil & Gas on Tract or PA operations. Pressure data should be forwarded to the AOGCC after each survey or pressure test. If there are any questions Please contact Jack Hartz at 279- 143'3 ext. 232. Sincerely, Copy: Mark Myers, DNR/DOG D.E. Dickinson, DOR Oil & Gas Audit PbuPolarisPilotOperations-RenewalSPad.doc STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMi,SSION WELL COMPLETION OR REOOMPLETION 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. 200-184 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22987-00 4. Location of well at surfacei: ?.:..C'.' T ~ '.'..,"' . 9. Unit or Lease Name 4586' NSL, 4495' WEL, SEC. 35, T12N, R12E, UM .~" Prudhoe Bay Unit 2354' NSL, 700' WEL, SEC. 27, T12N, R12E, UM ! -~--' ' (--~.' ; At total depth ~ ~,,-i.' ' 10. Well Number 2574' NSL, 830' WEL, SEC. 27, T12N, R12E, UM i._¢_.:.-- ._.._~..._-. ~ .i 8. ~,~-., S-201 ¥~";' ........ ~ ...... ~-'""' "--'~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Polads Field / Schrader Pool KBE = 64.42' ADL 028258 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSVset121. Thickness of Permafrost 7245 5613 FTI 7149 5523 FTI [] Yes [] NoI (Nipple) 2200' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, NEU, DEN, PWD, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 104' 30" ;)60 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 3190' 12-1/4" 385 sx AS Lite 3, 280 sx Class 'G' 7" 26# L-80 26' 7233' 8-3/4" ¢218x Class 'G' 24. Perforations pp. en to. Producti.on (M.D+,TVD of Top and 25. TUE~NG RECORD Bottom and ~merva~, s~ze an(] numDer) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 3-1/2", 9.2#, L-80 6214' 6157' MD TVD MD TVD 6833' - 6841' 5227' - 5235' RECEIV[[) ^o,o, ..^c.u.., ou.z , .c. . , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 bbls diesel ~!'if~Y '1 8 ~.00'l 6833'-6841' Frac'd w/51,660# of 16/20 RCP An~;l~nrao¢, 27. PRODUCTION TEST Date First Production ;Method of Operation (Flowing, gas lift, etc.) 04/30/01 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 4/28/2001 4 TEST PERIOD 80 2281 20 176I 28512 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Top of Ugnu Ma Sands 6283' 4721' Na 6516' 4933' Nb 6533' 4949' Nc 6570' 4983' OA 6630' 5039' OBa 6680' 5085' OBf Base 6962' 5348' R[C[ VF_D '/8 200 Alaska 0ii & Gas Cons. Commission, Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,errieHubble.~~.,~. ~ Title *echnicalAssistan, Date S-201 200-184 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL ,:," , '= ..... "' , .... , ..... ,=,,,Eeak,Off Test, Summa Legal Name: S-201 Common Name: S-201 !~i~?~'Date" ' TeSt'TY~:'':':'? i":, i...i'Test'De~th'i,(,T,~'~)'':'':'::,' ':'!:,;:,'TestD~:pth,'!:'(~~):'''' ,:,,',,,,,i 'i,, 'AM,W" ' Surface Pressure Leak Off Pressure (BHP) EMW 11/27/2000 FIT 3,190.0 (fl:) 2,850.0 (ft) 10.50 (ppg) 300 (psi) 1,855 (psi) 12.53 (ppg) · Printed: 51112001 1:41:27 PM BP EXPLORATION Page 1 of'6 Operations Summa Report Legal Well Name: 8-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRI LL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From - To Hours Task Code , Phase Description of Operations 11/21/2000 19:00 - 00:00 5.00 MOB PRE Prepare rig for move. Move pit module and sub module off S-103. Install 20" diverter on S-201. Move in sub base and pit modules. Accept rig at 00:00 hrs 22 Nov 00 11/22/2000 00:00 - 02:30 2.50 MOB PRE Spot pit module over S-201 cellar. Hook up mud and electric lines. 02:30 - 04:30 2.00 RIGU PRE Install flow line and riser and continue nippling up 20" diverter. Taking on fresh water. 04:30 - 08:30 2.00 RIGU PRE Mix spud mud. Load BHA into pipe shed. 06:30 - 07:30 1.00 RIGU PRE Clean rig. Put away tools and tidy up. 07:30 - 10:30 3.00 RIGU PRE PJSM and prespud meeting with drilling crew and all service companies. Make up BHA # 1. Adjust mud motor housing to 1.157 10:30 - 11 ;30 1.00 RIGU PRE Functoin test 20" diverter. AOGCC rep. Jeff Jones waived witnessing test. 11:30 - 12:00 0.50 DRILL SURF Break circ., C/O to 4" elevators 12:00 - 13:00 1.00 DRILL SURF Tag Btm @ 104', Drill from 104' to 225'. WOB=10K. PS1=630. GPM=500. 13:00 - 13:30 0.50 DRILL SURF CBU - POH 13:30 - 18:00 2.50 DRILL SURF M/U BHA # 2 W/MWD & UBHO RIH to 225' 18:00 - 17:30 1.50 DRILL SURF Circ. - reciprocate pipe while rigging up Wireline for SS Gyro. 17:30 - 00:00 8.50 DRILL SURF Drill Directionaly and survey from 225' to 489" AST -2 ART-1. WOB=10-20K. PS1=1950. GPM=600. 11/23/2000 00:00 - 07:30 7.50 DRILL SURF Drill Directionaly and survey from 489' to 1041" AST=5.1/4 ART=l/2. WOB=10-20K. PS1=1950. GPM=600. Difficulty building angle and holding azimuth. 07:30 - 08:00 0.50 DRILL SURF Circulate prior to trip. 08:00 - 10:00 2.00 DRILL SURF POH to change mud motor bent housing angle. 10:00 - 11:30 1.50 DRILL SURF Change mud motor bent housing setting to 1.5?, down load MWD and change bit. 11:30 - 12:30 1.00 DRILL SURF RIH to 950'. Wash down to btm @ 1041' - no fill. 12:30 - 00:00 11.50 DRILL SURF Directional Drill 12 1/4" Hole from 1041' to 1879'.Sliding all but 30 ft. ART = 1/4 AST =7 3/4 hrs. Avg.- 73 ft / hr..No Drilling problems. 11/24/2000 00:00 - 16:30 16.50 DRILL SURF Drill directional 12 1/4" hole from 1879' to 3205'.TD-Casing point, build angle to 55? and holding azimuth. ART- 4.5 hrs. AST- 6.5 hrs.WOB=20-30K PS1=3090 GPM--575 16:30 - 18:00 1.50 DRILL SURF Circulate. Recover sample. Pump high vis sweep. 18:00 - 20:00 2.00 DRILL SURF Wiper Trip to 1040'. NO OVERPULL. NO FILL 20:00 - 22:00 2.00 DRILL SURF Circ. & Cond. Mud for Casing.Pump HI - VIS sweep Drop ESS. Pump slug. 22:00 - 00:00 2.00 DRILL SURF POH. Taking multi-shot (ESS) surveys per JORPs requirements. Stand back all DP & HWDP. Again: very smooth, no overpull. 11/25/2000 00:00 - 02:30 2.50 DRILL SURF POH lay down BHA. 02:30 - 04:30 2.00 DRILL SURF Rig up 9 5/8" casing running tools and fill up tool. Pick up casing hanger and running tool and make dummy landing run to mark landing joint. PJSM 04:30 - 13:00 8.50 CASE SURF Run 78 jts 9 5/8" 40~ L-80 casing to 2388'. Circulate and work casing to 2810'. Run casing to 3190' and land on casing hanger. 13:00 - 13:30 0.50 DRILL SURF Rig down fill up tool and rig up cementing head and lines. 13:30 - 15:00 1.50 DRILL SURF Circulate and condition mud. PJSM with rig crews and service Printed: 1/26/2001 4:31:21 PM BP EXPLORATION Page 2 of 6 Operations Summa Report Legal Well Name: 8-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRILL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From - To Hours Task Sub Code Phase Description of Operations 11/25/2000 13:30 - 15:00 1.50 DRILL SURF company personnel. R/U Dowell. 15:00 - 18:00 3.00 CEMT SURF Test Dowell lines to 3500 psi. Mix & Pump: 67 bbls, 10.4 ppb MudPUSH Spacer, 312 bbls - 10.7 ppb. ArcticSet 3-Lite Lead Slurry and 69 bbls. - 15.8 ppg Class G Tail Slurry. Displaced with Total 237 bbls. Bumped plug w/3000 psi. Full Returns. No Cement to Surface. 18:00 - 19:00 1.00 REMCM; SURF R/D Upper Section of Landing Jt.. R/U to run 4' HWDP and TAM Combo Tool 19:00 - 20:00 1.00 REMCM'~ SURF 'Make up Tam Combo Tool and RIH with 4" HWDP to Tam Port Collar at 1002'. Drop ball and latch into collar. Test tool to 1000 psi. Slack off 12,000 lbs and open collar. 20:00 - 00:00 4.00 REMCM" SURF Circ and clean 9 5/8" annulus. After pumping 110 bbl mud, cement (5 bbl) was observed at surface. Continued pumping to clean mud. Pump 50 bbl treated mud spacer followed by10 bbls water followed by 110 bbl ArcticSet 3 Lite Cmt. Full, clean cement returns to surface. Displace lines and HWDP with 14 bbls water. Close Port collar and test to 1000 psi. 11/26/2000 00:00 - 00:30 0.50 REMCM" SURF Close Tam Port Collar and test to 1000 psi. OK. 00:30 - 01:00 0.50 REMCM" SURF Circulate HWDP and 9 5/8" casing annulus. 01:00 - 02:00 1.00 REMCM'; SURF POH with HWDP stand in derrick, lay down Tam Combo Tool. 02:00 - 04:30 2.50 REMCM' SURF Pump through all lines. Clean out flow line and shaker box, riser and diverter. 04:30 - 07:30 3.00 BOPSUF SURF Nipple down 20" diverter, riser and flow line. 07:30 - 08:30 1.00 WHSUR SURF Install FMC GEN 5 Unihead casing spool on 9 5/8" casing hanger and test 1000 psi. OK. 08:30 - 13:00 4.50 BOPSUI; PROD1 Install 13 5/8" 5000 psi BOP 13:00 - 17:00 4.00 BOPSUF PROD1 Test BOP'S. Test all rams, Hydril, choke and kill lines & valves to 250/3500 psi. Test Top-Drive & all surface related equipment to 250/3500 psi. Function test rig H2S alarms. Install Wear bushing. Note: John Spaulding with the AOGCC witnessed the 13 5/8" BOP and alarm tests. 17:00 - 20:30 3.50 DRILL PROD1 P/U & M/U 8 3/4" Steerable BHA with 17 fixed bent housing. Held PJSM prior to Sperry installing nuclear source in LWD. 20:30 - 23:00 2.50 DRILL PROD1 Pick Up 4" DP singles and stand back 5 stds. RIH to 2995'. Fill DP. Note: Took wt at Tam port collar @ 1002'. Circulated through it ok. 23:00 - 00:00 1.00 DRILL PROD1 Slip and cut Drilling Line. 11/27/2000 00:00 - 01:00 1.00 DRILL PROD1 RIH to 2995'. Wash down to 3098'. Drill medium to hard cement to 3107'. Top of float collar. 01:00 - 02:30 1.50 DRILL i PROD1 Circulate. Test casing with 3500 psi for 30 minutes. OK. Held pre-reservoir meeting with crew. 02:30 - 03:30 1.00 DRILL PROD1 Drill float collar, medium to hard cement and float shoe at 3190'. 03:30 - 04:00 0.50 DRILL PROD1 Drill cement in rat hole and 20' of new formation to 3225'. 04:00 - 05:30 1.50 DRILL PROD1 Circulate and change mud over to new LSND 10.5 ppg with bit at 9 5/8" shoe. 05:30 - 06:30 1.00 DRILL PROD1 Perform FIT at 9 5/8" casing shoe at 3190' MD 2850' TVD with EMW 12.5 ppg. 06:30 - 22:30 16.00 DRILL PROD1 Drill 8 3/4" directional hole from 3225' to 4769' WOB=10K RPM=100 GPM=500 PS1=2500. Rotate and slide, pump 30 bbl weighted high Vis pills every 300' drilled. ART=8.5 AST=2.5 22:30 - 00:00 1.50 DRILL PROD1 Circulate and pump around hi vis sweep prior to wiper trip. Work pipe and rotate while circulating. 11/28/2000 00:00 - 03:00 3.00 PROD1 Wiper trip to 9 5/8" casing shoe. Pull tight between 4500' and 3800'. Printed: 1/2612001 4:31:21 PM BP EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: S-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRILL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 11/28/2000 00:00 - 03:00 3.00 PROD1 Max over pull 40K. Work pipe up with pumps on from 3800' to casing shoe. 03:00 - 03:30 0.50 DRILL PROD1 Circulate. Rotate and work pipe, pump 30 bbl weighted hi vis sweep. 03:30 - 07:30 4.00 DRILL DIR PROD1 RIH. Held up at 3275' Rotate and work pipe from 3368' down to 3648'. Pump hi vis sweep. Take survey, directional survey indicates well is side tracked. New hole high and to the lee of original hole. 07:30 - 09:00 1.50 DRILL DIR PROD1 POH to shoe. Re-survey on every stand to verify original surveys. 09:00 - 10:30 1.50 DRILL DIR PROD1 RIH to 3550' orient tool face to Iow side of hole, continue in and held up at 3648'. Wash and resam with 325 gpm and rotating at 35 rpm. Bit taking weight, fluctuating from 0 to 10K and gradually increasing to 20K. Wash and ream to 3710'. Take survey at 3634' 62.19 deg indicating new hole drilled. 10:30 - 12:30 2.00 DRILL :DIR PROD1 Circulate, rotate & work pipe from 3648' to 3555'. 12:30 - 15:30 3.00 DRILL I DIR PROD1 Received orders from BPX drilling department to drill ahead. Continue drilling 8 3/4" directional hole from 3710' to 4022'. WOB -- 6-8K, RPM = 110, GPM = 550-575 with 2530 PSI. 15:30 - 16:00 0.50 DRILL DIR PROD1 Pump 35 bbl Hi-vis sweep & circulate hole clean from 4022' with 550 gpm. Rotate & work pipe while circulating. 16:00 - 17:00 1.00 DRILL DIR PROD1 Made wiper trip to 9 5/8" casing shoe with no problems encountered. Tagged bottom @ 4022'. 17:00 - 00:00 7.00 DRILL DIR PROD1 Drill 8 3/4" directional hole from 4022' to 4676'. WOB = 8K, RPM = 110 with 6K fi/lb torque, GPM = 550 - 575 with 2900 psi. AST = 1 hr. ART = 5 hrs. 11/29/2000 00:00 - 06:00 6.00 DRILL PROD1 Drill 8 3/4" directional hole from 4676' to 5140'. WOB = 8K, RPM = 110 with 6K fi/lb torque, GPM = 550 - 575 with 2900 psi. AST = 2 hrs. ART = 2.75 hrs. 06:00 - 07:00 1.00 DRILL PROD1 Circulate prior to short trip. 07:00 - 08:30 1.50 DRILL PROD1 POH for short trip. Tight hole from 4350' to 4338', max over pull 25K. Hole swabbing. Back ream with pumps on from 4370' to 4022'. BHA pulling tight through clay at 4230' to 4100'. 08:30 - 10:00 1.50 DRILL PROD1 RIH. No problem, wash last 90' to bottom as precaution. 10:00 - 00:00 14.00 DRILL PROD1 Drill 8 3/4" directional hole from 5140' to 5887'. WOB = 5-30K, RPM = 110 with 6-8K fi/lb torque, GPM = 550 - 575 with 3380 psi. AST = 1.5hrs. ART = 6hrs. 11/30/2000 00:00 - 06:00 6.00 DRILL PROD1 Drill 8 3/4" directional hole from 5887' to 6187'. WOB = 5-20K, RPM -- 110 with 6-8K fi/lb torque, GPM -- 550 - 575 with 2900 psi. ^ST = 2.25 hrs. ART = 3 hrs. 06:00 - 07:00 1.00 DRILL ClRC PROD1 Rig repair. Change 1 swab and 1 liner in #1 mud pump. Circulate and move pipe. 07:00 - 11:00 4.00 DRILL PROD1 Drill 8 3~4" directional hole from 6187' to 6280'. WOB -- 5-25K, RPM -- 110 with 6-8K fi/lb torque, GPM -- 550 - 575 with 3000 psi. AST -- 2.25hrs. ART = .5 hrs. 11:00 - 11:30 0.50 DRILL TDRV PROD1 Hydraulic oil filter seal gasket leaking on Top-drive. Replace filter & seal. 11:30 - 22:30 11.00 DRILL PROD1 Drill 8 3~4" directional hole from 6280' to 6483'. WOB = 10-30K, RPM = 110, GPM = 565 with 3000 psi DPP. ROP decreased from 60 fph to 8 fph. Adjust bit parameters in an attempt to increase ROP with no SUCceSS. 22:30 - 23:00 0.50, DRILL PROD1 CBU from 6483'. 23:00 - 00:00 1.00 DRILL PROD1 POOH for bit change ( 5735' @ midni§ht ) with 30-50K dra§. 12/1/2000 00:00 - 01:00 1.00' DRILL PROD1 POH to 4022' for bit change. Printed: 1/26/2001 4:31:21 PM BP EXPLORATION Page 4 of 6 Operations Summa Report Legal Well Name: 8-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRILL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 12/112000 01:00 - 06:00 5.00 DRILL PROD1 POH. Run MWD DAD pass log from 4022" to 9 5/8" casing shoe at 150-200 fi/hr to log section of hole that was not logged during wash and ream and side track operations. 06:00 - 07:00 1.00~ DRILL PROD1 Service rig. 07:00 - 08:30 1.50 DRILL PROD1 POH stand back HWDP. 08:30 - 09:00 0.50 DRILL PROD1 PJSM prior to removing RA sources from MWD. 09:00 - 10:30 1.50 DRILL PROD1 POH. Stand back BHA. Remove source from MWD tool. Download MWD data. Change out mud motor, bit and orient same. 10:30 - 13:00 2.50 DRILL PROD1 Finish making up BH^. 13:00 - 17:30 4.50 DRILL PROD1 TIH with 8 3/4" steerable drilling assembly on 4" dp. Encountered tight hole from 3600' to 3980' and 6125'. Work bit past same. Continue TIH to 6393'. Wash 90' to bottom at 6483'. 17:30 - 0.00 DRILL ! PROD1 Drill 8 3/4" directional hole from 6483' to 6637 WOB -- 5-15K, RPM = 80 - 110, GPM = 440 to 490. 12/2/2000 00:00 - 08:30 8.50 DRILL PROD1 Drill 8 3~4" directional hole from 6637' to 7245 WOB -- 5-15K, RPM = 80 - 110, GPM = 440 to 503 w/3450 psi. 08:30 - 10:00 1.50 DRILL PROD1 Circulate and pump sweep. 10:00 - 11:00 1.00 DRILL PROD1 POOH wiper trip to 6400'. Normal drag. RIH to bottom with no = problems. 11:00 - 12:30 1.50 DRILL PROD1 , Circulate hole clean from 7245'. 12:30 - 17:30 5.00 DRILL PROD1 I POOH for logs. Drop ESS survey tool. No hole problems encountered while POOH. 17:30 - 21:30 4.00 DRILL PROD1 . Rack back 4" HWDP in derrick. Held PJSM with Sperry-Sun. Remove radioactive source from MWD & download MWD data. L/D MWD, Mud-motor & bit. 21:30 - 22:00 0.50 DRILL PROD1 Held PJSM with Schlumberger concerning DPC logging operations. 22:00 - 22:30 0.50 DRILL PROD1 Schlumberger M/U RFT logging tool to 4" HWDP. 22:30 - 00:00 1.50 DRILL PROD1 TIH with RFT tool on 4" DP ( 1500' @ midnight ). 12/3/2000 00:00 - 01:00 1.00 EVAL PROD1 Circlate at 1500'. RIH to 9 5/8" casing shoe at 3190' 01:00 - 02:00 1.00 EVAL PROD1 Rig up Schlumberger logging unit and E-line. Circulate at shoe. PJSM. 02:00 - 02:30 0.50 EV^L PROD1 RIH with drill pipe to 3900' 02:30 - 04:30 2.00 EV^L PROD1 Make up Side Door Entry Sub (SDES) on drill pipe and install line packing. Run in with E-line to Down Hole Wet Connect head (DHWC). Check tools. Functioning OK. 04:30 - 22:00 17.50 EVAL PROD1 ! Run RFT logs on 4" drill pipe. Taking 49 presure readings from 3966' lin SV1 sand to 6934' in OBf sand. 22:00 - 00:00 2.00 EVAL PROD1 , POOH with RFT tool & 4" drill pipe to 6465'. Take fluid sample from the ~ Mc sand. 12/4/2000 00:00 - 00:30 0.50 EVAL PROD1 Take formation sample at 6465' in MC sand with RFT 00:30 - 03:30 3.00 EVAL PROD1 POH with drill pipe and RFT tools to SDES. 03:30 - 05:00 1.50 EVAL PROD1 Remove packing from SDES. Unlatch e-line from DHWC. POH with e-line to surface. Rig down SDES, pullys and logging unit. 05:00 - 07:00 2.00 EVAL PROD1 POH with RFT tools and lay down. Test choke and kill lines and choke manifold while POH. 07:00 - 08:00 1.00 BOPSUR PROD1 Pull wear bushing. 08:00 - 11:00 3.00 BOPSUF~ PROD1 Test BOP 250 psi and 3500 psi. AOGCC rep. John Chrisp waived witnessing test. 11:00 - 12:00 1.00 DRILL PROD1 Pick up clean out BHA with bull nose on 8 3~4" stablizer. 12:00 - 14:00 2.00 DRILL PROD1 RIH with clean out BH^ to casing shoe. 14:00 - 15:30 1.50 DRILL PROD1 Slip and cut drilling line. Service Top-drive. 15:30 - 17:30 2.00 DRILL PROD1 RIH 4 "drill pipe to 7088'. Wash to bottom @ 7245'. No hole problems encountered. Printed: 1/26/2001 4:31:21 PM BP EXPLORATION Page 5 of 6 Operations Summa Report Legal Well Name: 8-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRILL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations , 12/4/2000 17:30 - 20:00 2.50 DRILL PROD1 Circulate and condition mud/hole at 7245'. GPM = 503 W/2800 psi. Spot liner running pill. 20:00 - 00:00 4.00 DRILL PROD1 POOH. L/D 4" drill pipe. ( 3900' @ midnight ). 12/5/2000 00:00 - 03:30 3.50 DRILL PROD1 POOH. L/D 4" drill pipe, HWDP and BHA. 03:30 - 04:00 0.50 DRILL PROD1 Pull wear bushing. 04:00 - 07:00 3.00 CASE PROD1 ~Rig up to run 7" casing. Change top rams to 7"and test ram bonnets to ;3500 psi. 07:00 - 11:30 4.50 CASE PROD1 I PJSM. M/U 7" Shoetrack and check float equipment. Run 7", 26 lb/fi, L-80 casing ( 77 Jts ) to 3172' with full returns. 11:30 - 12:30 1.00 CASE PROD1 Break circulation @ 9 5/8" shoe. Circulate with 4 bpm @ 350 psi. Had full returns. P/U = 110K, S/O = 94K. 12:30 - 18:00 5.50 CASE PROD1 Continue RIH with 176 joints total ( 7204' ) of 7" 28 ppf L-80 BTCM Production casing ( lost 38 bbl mud ). P/U FMC hanger & landing joint. 18:00 - 19:30 1.50 CASE PROD1 Establish circulation ( lost 19 bbl mud ). Wash down to 7233'- shoe depth. Land hanger -OK. Reciprocate pipe 15' while circulating. P/U = 225-245K, S/O 110K. Stage pumps up to 6.4 bpm w/970 psi. Circulate a total of 473 bbl with full returns. 19:30 - 20:30 1.00 CASE PROD1 R/D Franks fill-up tool. Install Dowell 7" cement head. 20:30 - 21:30 1.00 CASE WTHR PROD1 Continue circulating @ 6.4 bpm w/970 psi with full returns. Waiting on Peak water trucks to arrive at location. ( Phase II weather ). 21:30 - 23:30 2.00 CASE PROD1 PJSM. Dowell test cement lines to 3500 psi. Pump 50 bbl 11.5# spacer. Release bottom plug. Mix & pump cement as follows: Lead -- 45 bbl of class "G" @ 11.5 ppg. Yield 2.79 fi3/sk. Tail = 75 bbl of class "G" @ 15.8 ppg. Yield 1.17 fi3/sk. Release Top plug. Chase with 10 bbl water. Switch over to rig pumps. Displace cement with 264 bbl seawater @ 7 bpm with 1610 psi for the first 260 bbl. Reduce pump rate to 2 bpm w/1370 psi. Bump plug w/3500 psi-ok. Cement in place @ 23:05 hrs. Release pressure, floats held. Note: Lost partial returns after pumping 210 bbl into the displacement. Estimated mud lost while displacing = 55 bbl. 23:30 - 00:00 0.50 CASE PROD1 PJD Dowell cement head & related equipment. 12/6/2000 00:00 - 01:00 1.00 CASE PROD1 I_/D 7" Landing Joint. Flush BOP'S. R/D 7" casing equipment. 01:00 - 02:00 1.00 CASE PROD1 Run FMC 7" Hanger/pack-off seal assembly. Test same to 5000 psi. ~Test was APl. 02:00 - 03:30 1.50 CASE PROD1 'PJU chicksan line to 7" x 9 5/8" annulus valve. Test lines to 3500 psi. Inject 93 bbl of 10.5# mud. Stage as follows: 1 bpm = 700 psi, 2 bpm -- '800 psi, 3 bpm = 830 psi, 4 bpm = 850 psi FCP. 03:30 - 04:00 0.50 CASE PROD1 Freeze Protect 7" x 9 5/8" annulus with 56 bbl of crude oil to 2115'. Pump @ 2.5 bpm with 2000 psi. Stop pumps with 1000 psi differential pressure. Shut-in & secure annulus valve. R/D Hot Oil truck. 04:00 - 05:00 1.00 CASE PROD1 Change top rams from 7" casing rams to 3.5" x 6" VBR. Test Ram Bonnets to 3500 psi. 05:00 - 06:30 1.50 CASE . PROD1 Run wearbushing. Test 7" casing to 3500 psi for 30 minutes on chart. Test was APl. 06:30 - 07:00 0.50 CASE PROD1 IJD 3 joints of 4" HWDP. 07:00 - 07:30 0.50 CLEAN i COMP R/U 3.5" Tubing Handling equipment. 07:30 - 14:00 6.50 CLEAN 'COMP P/U & TIH w/190 joints of 3.5" 9.2# L-80 EUE tubing to 5950'. 14:00 - 15:00 1.00 CLEAN COMP Circulate hole with clean seawater from 5950' w/550 gpm @ 2500 psi. 15:00 - 18:00 3.00 CLEAN COMP POOH. Rack 183 joints of 3.5" production tubing in derrick. L/D 7 joints 3.5" tubing. Printed: 1/2612001 4:31:21 PM BP EXPLORATION Page 6 of 6 Operations Summa Report Legal Well Name: 8-201 Common Well Name: S-201 Spud Date: 11/21/2000 Event Name: DRILL+COMPLETE Start: 11/21/2000 End: 12/4/2000 Contractor Name: NABORS Rig Release: 12/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Sub Date From-To Hours Task Code Phase Description of Operations 12/612000 18:00 - 20:30 2.50 EVAL COMP PJSM. R/U Schlumberger cased hole logging equipment in preparation for running USIT log. 20:30 - 23:00 2.50 EVAL COMP Schlumberger M/U & RIH with USlT logging tool to 7072', tagged-up. Log 7" casing up to 6472'. Experienced failure with USIT tool. Not receiving data from tool. 23:00 - 00:00 1.00 EVAL REEL COMP POOH with E-line. Cut off 500' of e-line & rehead same. This did not rectify the problem. Continue to trouble shoot e-line problem. USIT tool checked out OK. 12/7/2000 '00:00 - 02:30 2.50 EVAL REEL COMP Trouble shoot e-line problem. Found e-line data collector on hoisting drum to have moisture inside same which caused e-line to ground out. Dry out data collector & reterminate to drum. Ran surface checks-OK. 02:30 - 04:30 2.00 EVAL REEL COMP RIH with USlT tool to 7072'. Log up 20' to 7052'. USIT tool not receiving data. Data collector grounded out again. POOH with e-line. R/D Schlumberger e-line unit & release same. 04:30 - 05:30 1.00 EVAL OTHR COMP ~Waiting on another Schlumberger e-line logging truck to arrive at location. Truck arrived @ 05:20 hrs. 05:30 - 06:30 1.00 EVAL OTHR COMP Spot Schlumberger e-line truck. R/U e-line to rig floor. 06:30 - 12:30 6.00 EVAL COMP Schlumberger RIH with USlT logging tool to 7050'. Log up to 3750'. Log indicated poor cement quaility around 7" casing. Pressure up on 7" casing to 1000 psi. RIH to 7050'. Re-log 7" casing under pressure up to 3750'. Bleed off pressure. POOH and R/D Schlumberger e-line equipment. 12:30 - 13:00 0.50 RUNCOI~ COMP R/U 3.5" tubing handling tools and related equipment. 13:00 - 14:00 1.00 EVAL COMP Wait on orders while BPX drilling department evaluates USlT log. 14:00 - 15:00 1.00 RUNCOI~ COMP Pull wearbushing. Held PJSM prior to running 3.5" production tubing. 15:00 - 20:30 5.50:RUNCOI~ COMP Run 3.5" 9.2# L-80 EUE 8rd completion string as per program w/190 jts tubing. 4 GLM, 3 X-nipples. Baker "S-3" production packer. 20:30 - 21:30 1.00 RUNCOI~ COMP P/U FMC 4.5" x 11" tubing hanger with onejt of 4.5" 12.6~ L-80 MBTC tubing below hanger wi XO to 3.5" EUE 8rd. M/U in 3.5" tubing string. Land hanger w/WLIG @ 6214', top of Baker "S-3" packer @ 6156' RKB. RILDS. 21:30 - 00:00 2.50 RUNCOI~ ~ COMP Reverce circulate Seawater @ 3 bpm w/200 psi. Pump 200 bbl clean SW + 91 bbl corexit treated SW + 72 bbl clean SW. Initial returns 142 NTU. Final 63 NTU. 12/8/2000 00:00 - 01:00 1.00 RUNCOI~I COMP L/D Tubing landing joint. Install TWC in Tubing hanger. Test to 500 psi above & 1000 psi below with no problems. 01:00 - 04:00 3.00 RUNCOI~I COMP N/D 13 5/8" 10M BOP & DSA flange. 04:00 - 06:00 2.00 RUNCO~I COMP N/U FMC 4 1/16" 5M Production Tree assembly. Test void to 5000 psi. Shell test tree with water to 5000 psi. All test were APl. 06:00 - 07:30 1.50 RUNCO~ COMP Pull TWC. Drop packer setting ball-rod down 3.5" tubing. R/U Hot Oil line to 3.5" x 7" casing annulus valve. R/U Rig pumps to pump down 3.5" tubing & 3.5" x 7" annulus. Pressure up on 3.5" tubing to 3500 psi & set BOT "S-3" 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 1200 psi. Bleed-off remaining pressure from tubing & annulus to 0 psi. 07:30 - 08:30 1.00 RUNCO~ COMP Freeze protest 3.5" x 7" annulus. Reverce circulate 75 bbl of diesel down annulus @ 2.5 bpm. Stop pumping. Had 300 psi differential pressure. Let well U-Tube & equalize. R/D Hot oil line. 08:30 - 12:00 3.50 RUNCO~ COMP Set BPV in tubing hanger. Secure well. R/D & prepare for rig move. Released Nabors Rig 9ES from well #S-201 at 12:00 hrs on 12/08/2000. Printed: 1126/2001 4:31:21 PM Original Well: Field: APl: Permit: S-201 Prudhoe Bay Field / Polaris Pool / Schrader Pool 50-029-22987-00 200-184 Date POST-RIG SUMMARY WORK 03/05101 Set catcher sub, pulled STA #1 RP Shear valve, set RK latch w/1.5 DGLV at 2744' SLM, and pulled Catcher sub. 03/06/01 Pulled B&R Mit tubing and IA both to 3500 PSI (Passed) and Bleed back down to 0 PSI. Pulled RHC plug at 6189' SLM. Drift and tag with 2.5" Dummy gun and TEL. T.T. at 6199' SLM and Tag TD at 7085' SLM. (No E-line measurements available for correction) left well shut in. 03/26/01 Perforate 6833' - 6841' using 2.5" HSD 35B up RDX (Big hole charges), 4 spf, reference log Sperry EWR 12/03/O0. 03/27101 RST SIGMA, BORAX and WFL logging. WFL log did not show up flow at 6801. Borax logging showed channel down to 6930 and a channel up to 6820 with other'unexplained anomalies up to 6680. Tried to initiate FRAC, pump limited to 5.0 BPM at 1900 WHP, RP 3430, when pump heated up, reduced to 3.0 BPM. Flushed BORAX with 50 BBLS, but BORAX was still apparent in formation. Freeze protected tubing with 30 BBLS Diesel. 04/04/01 Set 2.81" X-Lock catcher sub at 6121' WLM, pull Dummy valve from STA #1 at 6067' WLM, set Petredat side pocket gauge in STA #1 at 6067' WLM, pull Catcher sub. Pressure test IA to 3000 PSI from 0 PSI hold 30 minutes. (Lost 40 PSI in 30 minutes Good test) Left well shut in. 04/06/01 Fractured OBD sand perforations 6833' - 6841' with 51.66 K# of 16/20 RCP behind pipe using YF-140D GW system, 1500# left in casing EST TOS = 7018' MD for 177' RH. Max treat = 4499 RSI, AVG TREAT= 1363 PSI. Load to recover is 1089 Bbls, all ISO cups recovered. Well freeze protected to 3700' with diesel. 04/07/01 - 04/06/01 Tab PBTD at 6960' SLM with 2.45" drift (Rat hole= 119'). Set 3-1/2" X-lock C-Sub at 6144' MD. Pulled SP gauge (Petredat) from ST #1. Set RKDGLV at ST #1. Pulled RK-DGLV from ST #4. Attempted to set RK-OGLV at ST #4. Set RK-OGLV at ST #4 (5/16" Orifice, dual check). Pulled 3-1/2" X-Lock cub, Hung up in X-Nipple at 2200' MD (See log entries: Packing Bore may now be damaged). Well returned to DSO ready to pop. 04/11101 Attempt to set 2.81 Catcher sub with key, couldn't get past X nipple at 2178' SLM. LDFN 04/12/01 Set Catcher with keys at 6156' SLM, pulled DGLV at GLM #1 at 6064' SLM and OGLV at GLM #4 at 2734' SLM. 04/1 3/01 Set 1500# TRO LGLV in GLM #$ and 20/64" Port OGLV in GLM #1. Pulled Catcher sub note: Chunk of metal that caused trouble at GLM #4 was retrieved in Catcher sub. Well left shut in for flow back unit. 04/1 6/01 Pump Neat Methanol down IA. North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-20~ S-201 Surveyed: 2 December, 2000 DEFINITIVE SURVEY REPORT December, 2000 Your Reft AP!500292298700 Surface Coordinates: 5980789.92 N, 618929.93 E (70° 21' 22.2099" N, 149° 02' 02.8488" W) Kelly Bushing: 64.42ft above Mean Sea Level DRILLING SERVICES A Halliburton Company Survey Ref: svy10669 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for $-201 Your Ref: API500292298700 Surveyed: 2 December, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3199.82 54.200 330.226 2786.97 2851.39 3291.83 55.780 330.945 2839.76 2904.18 3385.32 57.650 330.472 2891.06 2955.48 3478.55 59.680 328.925 2939.55 3003.97 3573.76 61.190 328.723 2986.52 3050.94 3667.53 62.740 327.922 3030.60 3095.02 3760.55 62.810 328.153 3073.15 3137.57 3854.08 59.850 328.459 3118.02 3182.44 3946.92 57.770 330.375 3166.10 3230.52 4040.41 56.840 330.523 3216.60 3281.02 4133.30 56.160 331.170 3267.87 3332.29 4228.18 56.430 333.679 3320.52 3384.94 4321.36 57.220 336.075 3371.52 3435.94 4413.61 57.120 335.762 3421.53 3485.95 4507.41 56.320 336.307 3473.00 3537.42 4600.05 55.640 336.837 3524.83 3589.25 4693.89 54.460 337.274 3578.59 3643.01 4786.26 51.350 338.315 3634.29 3698.71 4878.20 50.290 337.747 3692.38 3756.80 4971.74 51.200 336.169 3751.57 3815.99 Alaska Drilling & Wells PBU WOA S Pad 5064.87 51.290 335.917 3809.87 3874.29 5157.42 54.900 336.473 3865.43 3929.85 5252.77 54.050 334.793 3920.84 3985.26 5347.04 53.840 336.623 3976.33 4040.75 5440.45 53.360 336.341 4031.76 4096.18 801.55 N 362.60W 867.20 N 399.61W 935.35 N 437.84W 1004.09 N 478.03W 1074.94 N 520.90W 1145.38 N 564.36W 1215.55 N 608.15W 1285.37 N 651.26W 1353.72 N 691.68W 1422.16 N 730.48W 1489.81N 768.22W 1559.77 N 804.75W 1630.37 N 837.85W 1701.14 N 869.48W 1772.80 N 901.33W 1843.25 N 931.86W 1914.08 N 961.85W 1982.28 N 989.70W 2048.37 N 1016.36W 2115.01N 1044.72W 2181.38 N 1074.21W 2249.09 N 1104.07W 2319.77 N 1136.08W 2389.23 N 1167.43W 2458.17 N 1197.43W 5981585.62 N 618554.65 E 5981650.66 N 618516.61E 5981718.20 N 618477.29 E 5981786.30 N 618436.02 E 5981856.46 N 618392.03 E 5981926.19 N 618347.45 E 5981995.66 N 618302.56 E 5982064.78 N 618258.34 E 5982132.49 N 618216.85 E 5982200.31N 618176.96 E 5982267.34 N 618138.16 E 5982336.71N 618100.52 E 5982406.79 N 618066.30 E 5982477.04 N 618033.55 E 5982548.18 N 618000.56 E 5982618.14 N 617968.92 E 5982688.49 N 617937.81 E 5982756.23 N 617908.88 E 5982821.90 N 617881.17 E 5982888.08 N 617851.77 E 5982953.97 N 617821.23 E 5983021.19 N 617790.30 E 5983091.36 N 617757.17 E 5983160.32 N 617724.72 E 5983228.77 N 617693.63 E Dogleg Rate (°/100ft) 1.83 2.04 2.60 1.60 1.82 0.23 3.18 2.85 1.00 0.93 2.22 2.31 0.31 0.98 0.87 1.31 3.48 1.25 1.63 0.23 3.93 1.69 1.59 O.57 Vertical Section Comment 879.38 954.60 1032.62 1112.02 1194.50 1276.86 1359.13 1440.78 1519.94 1598.47 1675.81 1754.70 1832.67 1910.14 1988.51 2065.21 2142.02 2215.52 2286.61 2358.94 2431.52 2505.46 2583.02 2659.19 2734.31 Tie on Survey Continued... DrillQuest 2.00.05 13 December, 2000 - 7:21 - 2 - Sperry-Sun Drilling Services Survey Report for $-201 Your Ref: APi500292298700 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5533.02 51.750 335.574 4088.04 4152.46 5626.16 46.770 335.344 4148.81 4213.23 5719.34 44.870 333.613 4213.74 4278.16 5812.73 44.530 334.114 4280.13 4344.55 5904.76 40.150 333.374 4348.13 4412.55 5997.76 36.020 331.884 4421.32 4485.74 6090.39 35.650 332.519 4496.42 4560.84 6184.39 34.320 333.011 4573.43 4637.85 6277.24 28.370 333.023 4652.69 4717.11 6338.89 26.050 332.285 4707.52 4771.94 6370.46 24.210 333.158 4736.10 4800.52 6428.60 22.530 331.483 4789.47 4853.89 6459.61 22.640 330.968 4818.10 4882.52 6558.44 22.360 331.016 4909.40 4973.82 6652.82 22.080 329.932 4996.78 5061.20 6745.04 21.830 329.666 5082.31 5146.73 6838.09 21.380 329.623 5168.82 5233.24 6931.40 20.890 329.426 5255.85 5320.27 7024.12 20.630 328.853 5342.55 5406.97 7118.19 20.050 328.604 5430.76 5495.18 7162.98 19.770 328.585 5472.87 5537.29 7245.00 19.770 328.585 5550.06 5614.48 2525.29 N 1227.37W 5983295.40 N 617662.63 E 2589.47 N 1256.66W 5983359.11 N 617632.31 E 2649.77 N 1285.44W 5983418.95 N 617602.59 E 2708.74 N 1314.37W 5983477.45 N 617572.72 E 2764.32 N 1341.77W 5983532.59 N 617544.44 E 2815.27 N 1368.11W 5983583.11N 617517.30 E 2863.24 N 1393.40W 5983630.68 N 617491.25 E 2911.16 N 1418.07W 5983678.20 N 617465.82 E 2954.18 N 1439.97W 5983720.87 N 617443.24 E 2979.22 N 1452.92W 5983745.70 N 617429.90 E 2991.13 N 1459.06W 5983757.51 N 617423.56 E 3011.56 N 1469.76W 5983777.76 N 617412.54 E 3022.00 N 1475.50W 5983788.11N 617406.64 E 3055.07 N 1493.84W 5983820.89 N 617387.78 E 3086.13 N 1511.42W 5983851.66 N 617369.70 E 3115.93 N 1528.77W 5983881.18 N 617351.89 E 3145.49 N 1546.08W 5983910.47 N 617334.10 E 3174.49 N 1563.14W 5983939.19 N 617316.58 E 3202.70 N 1580,00W 5983967.13 N 617299.28 E 3230.65 N 1596.97W 5983994.81 N 617281.87 E 3243.67 N 1604.92W 5984007.70 N 617273.71E 3267.34 N 1619.38W 5984031.14 N 617258.88 E Dogleg Rate (°/lOOft) 1.86 5.35 2.44 0.52 4.79 4.55 0.57 1.45 6.41 3.80 5.95 3.11 0.73 0.28 0.53 0.29 0.48 0.53 0.36 0.62 0.63 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 2807.75 2878.28 2945.09 3010.78 3072.75 3130.08 3184.29 3238.17 3286.44 3314.62 3328.02 3351.07 3362.97 3400.74 3436.36 3470.75 3504.91 3538.45 3571.20 3603.76 3618.95 3646.57 Projected Survey Continued... DrillQuest 2.00.05 13 Decembe~ 2000.7:21 -3- Sperry-Sun Drilling Services Survey Report for $-201 Your Ref: API500292298700 Surveyed: 2 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.670° (22-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 333.980° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7245.00ft., The Bottom Hole Displacement is 3646.63ft., in the Direction of 333.636° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings {ft) {ft) (ft) (ft) 3199.82 2851.39 801.55 N 362.60 W 7245.00 5614.48 3267.34 N 1619.38 W Comment Tie on Survey Projected Survey Continued... 13 December, 2000.7:21 .4. DrillQuest 2.00.0,5 North Slope Alaska Sperry-Sun Drilling Services Survey Report for $-201 Your Ref: API5002922987'00 Surveyed: 2 December, 2000 Alaska Drilling & Wells PBU WOA S Pad Survey tool program for S-201 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 7245.00 Vertical Depth (ft) 5614.48 Survey Tool Description AK-6 BP_IFR-AK 13 December, 2000.7:22 - 5 - DrillQuest 2.00.05 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-201 S-20~ MWD Surveyed: 2 December, 2000 SURVEY REPORT December, 2000 Your Ref: APl 500292298700 Surface Coordinates: 5980789.92 N, 618929.93 E (70° 21' 22.2099" N, Kelly Bushing: 64.42ft above Mean Sea Level DRICLINI; SERVICES A Halliburton Company 149° 02' 02.8488" HO Survey Reft svy10663 Sperry-Sun Drilling Services Survey Report for $-201 MWD Your Ref: AP1500292298700 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. 3199.82 54.200 330.510 3291.83 55.780 330.870 3385.32 57.650 330.300 3478.55 59.680 328.720 3573.76 61.190 328.440 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 2786.97 2839.75 2891.06 2939.54 2986.52 2851.39 2904.17 2955.48 3003.96 3050.94 3667.53 62.740 327.870 3030.59 3095.01 3760.55 62.810 329.240 3073.15 3137.57 3854.08 59.850 328.910 3118.02 3182.44 3946.92 57.770 330.410 3166.10 3230.52 4040.41 56.840 330.620 3216.60 3281.02 4133.30 56.160 331.070 3267.86 3332.28 4228.18 56.430 334.370 3320.53 3384.95 4321.36 57.220 337.010 3371.52 3435.94 4413.61 57.120 336.860 3421.53 3485.95 4507.41 56.320 337.010 3473.00 3537.42 4600.05 55.640 337.370 3524.83 3589.25 4693.89 54.460 336.690 3578.59 3643.01 4786.26 51.350 338.900 3634.30 3698.72 4878.20 50.290 337.880 3692.38 3756.80 4971.74 51.200 335.230 3751.58 3816.00 5064.87 51.290 333.970 3809.88 3874.30 5157.42 54.900 336.190 3865.45 3929.87 5252.77 54.050 334.160 3920.86 3985.28 5347.04 53.840 336.050 3976.34 4040.76 5440.45 53.360 335.800 4031.77 4096.19 802.09 N 362.08W 867.81N 398.97W 935.88 N 437.35W 1004.49 N 477.76W 1075.15 N 520.93W 1145.46 N 564.60W 1216.02 N 607.75W 1286.41 N 649.92W 1354.94 N 690.04W 1423.43 N 728.77W 1491.08 N 766.50W 1561.21N 802.67W 1632.28 N 834.77W 1703.60 N 865.13W 1775.75 N 895.86W 1846.53 N 925.62W 1917.34 N 955.64W 1985.53 N 983.50W 2051.79 N 1009.74W 2118.23 N 1038.57W 2183.83 N 1069.72W 2250.94 N 1100.86W 2321.37 N 1133.43W 2390.49 N 1165.51W 2459.14 N 1196.18W Global Coordinates Northings Eastings (ft) (ft) 5981586.16 N 618555.16 E 5981651.28 N 618517.24 E 5981718.74 N 618477.77 E 5981786.69 N 618436.28 E 5981856.67 N 618391.99 E 5981926.27 N 618347.21E 5981996.14 N 618302.95 E 5982065.85 N 618259.67 E 5982133.74 N 618218.46 E 5982201.60 N 618178.66 E 5982268.64 N 618139.85 E 5982338.19 N 618102.57 E 5982408.74 N 618069.36 E 5982479.57 N 618037.86 E 5982551.22 N 618005.99 E 5982621.52 N 617975.11E 5982691.85 N 617943.97 E 5982759.59 N 617915.03 E 5982825.42 N 617887.74 E 5982891.39 N 617857.86 E 5982956.49 N 617825.68 E 5983023.10 N 617793.47 E 5983093.00 N 617759.79 E 5983161.61N 617726.61E 5983229.76 N 617694.86 E Dogleg Rate (°/t00ft) Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 879.63 Tie on 1.75 954.87 2.06 1032.88 2.61 1112.26 1.61 1194.70 1.74 1.31 3.18 2.63 1.01 0.84 2.91 2.52 0.17 0.86 0.80 1.39 3.87 1.44 2.40 1.06 4.35 1.95 1.64 0,56 1277.04 1359.38 1441.13 1520.32 1598.85 1676.20 1755.09 1833.04 1910.45 1988.76 2O65.42 2142.23 2215.73 2286.78 2359.13 2431.75 2505.72 2583.30 2659.49 2734.63 Continued... DriliQuest 2.00.05 13 December, 2000 - 7:21 - 2 - Sperry-Sun Drilling Services Survey Report for $-201 MWD Your Ref: AP1 500292298700 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 5533.02 51.750 335.030 4088.06 4152.48 5626.16 46.770 334.950 4148.82 4213.24 5719.34 44.870 333.200 4213.76 4278.18 5812.73 44.530 333.600 4280.14 4344.56 5904.76 40.150 333.580 4348.15 4412.57 5997.76 36.020 331.510 4421.34 4485.76 6090.39 35.650 331.750 4496.43 4560.85 6184.39 34.320 332.400 4573.45 4637.87 6277.24 28.370 332.590 4652.71 4717.13 6338.89 26.050 331.750 4707.53 4771.95 6370.46 24.210 332.660 4736.11 4800.53 6428.60 22.530 330.740 4789.48 4853.90 6459.61 22.640 330.250 4818.11 4882.53 6558.44 22.360 330.260 4909.42 4973.84 6652.82 22.080 329.620 4996.79 5061.21 6745.04 21.830 329.280 5082.33 5146.75 6838.09 21.380 328.390 5168.84 5233.26 6931.40 20.890 328.400 5255.87 5320.29 7024.12 20.630 327.380 5342.57 5406.99 7118.19 20.050 327.610 5430.78 5495.20 7162.98 19.770 327.670 5472.89 5537.31 7245.00 19.770 327.670 5550.07 5614.49 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 2525.97 N 1226.75W 5983296.09 N 617663.23 E 2589.90 N 1256.58W 5983359.55 N 617632.39 E 2650.00 N 1285.78W 5983419.17 N 617602.24 E 2708.74N 1315.19W 5983477.44 N 617571.90 E 2764.24 N 1342.75W 5983532.49 N 617543.46 E 2815.15 N 1369.15W 5983582.98 N 617516.26 E 2862.87 N 1394.92W 5983630.28 N 617489.74 E 2910.48 N 1420.16W 5983677.49 N 617463.74 E 2953.30 N 1442.46W 5983719.95 N 617440.76 E 2978.23 N 1455.62W 5983744.67 N 617427.21E 2990.09 N 1461.87W 5983756.42 N 617420.77 E 3010.40 N 1472.79W 5983776.56 N 617409.53 E 3020.76 N 1478.66W 5983786.83 N 617403.50 E 3053.60 N 1497.42W 5983819.36 N 617384.22 E 3084.49 N 1515.30W 5983849.97 N 617365.85 E 3114.18 N 1532.82W 5983879.38 N 617347.86 E 3143.50 N 1550.55W 5983908.41 N 617329.67 E 3172.16 N 1568.18W 5983936.78 N 617311.58 E 3199.99 N 1585.65W 5983964.34 N 617293.68 E 3227.57 N 1603.22W 5983991.63 N 617275.67 E 3240.45 N 1611.38W 5984004.38 N 617267.30 E 3263.89 N 1626.22W 5984027.59 N 617252.10 E 1.86 5.35 2.44 0.47 4.76 4.65 0.43 1.47 6.41 3.81 5.96 3.17 0.70 0.28 0.39 0.30 0.60 0.53 0.48 0.62 0.63 0.00 Alaska Drilling & Wells PBU WOA $ Pad Vertical Section Comment 2808.10 2878.63 2945.45 3011.14 3073.11 3130.43 3184.62 3238.48 3286.74 3314.92 3328.32 3351.36 3363.25 34O0.99 3436.59 3470.96 3505.08 3538.57 3571.25 36O3.73 3618.89 3646.47 Projected Survey Continued... 13 December, 2000 - 7:21 .3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-201 MWD Your Ref: AP1500292298700 Surveyed: 2 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.670° (22-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 333.980° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7245.00ft., The Bottom Hole Displacement is 3646.59ft., in the Direction of 333.515" (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 3199.82 2851.39 802.09 N 362.08 W 7245.00 5614.49 3263.89 N 1626.22 W Comment Tie on Projected Survey Continued... 13 December, 2000.7:21 - 4. DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for $-201 MWD Your Ref: AP1 500292298700 Surveyed: 2 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Survey tool program for $-201 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 7245.00 5614.49 Survey Tool Description MWD Magnetic 13 December, 2000.7:21 -5- DrillQuest 2.00.05 North Slope Alaska Alaska Drilling & Wells PBU_WOA $ Pad, Slot S-20'/ S-201PB1 Surveyed: 2 December, 2000 SURVEY REPORT 'i9 December, 2000 o o Your Reft APl 500292298770 Surface Coordinates: 5980789.92 N, 618929.93'E (70' 2f' 22.2099"N, Kelly Bushing: 64.42fl above Mean Sea Level DRIL. LINI; SERV. ICI~S A Hellll~urton Company f49' 02' 02.8488"V10 Survey Reft svy10668 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -64.42 0.00 120.00 0.000 0.000 55.58 120.00 237.75 0.310 8.201 173.33 237.75 329.76 2.160 3.432 265.31 329.73 421.49 2.580 357.173 356.97 421.39 514.35 2.180 5.129 449.75 514.17 605.42 2. 340 4.924 540.74 605.16 697.89 2. 330 15.041 633.14 697.56 745.88 2.580 18.384 681.08 745.50 789.53 2.460 17.527 724.69 789.11 882.13 2.350 31.456 817.21 881.63 930.12 2.140 37.494 865.16 929.58 974.52 2.040 36.101 909.53 973.95 1066.48 1.870 51.113 1001.44 1065.86 1129.45 2.020 65.987 1064.38 1128.80 1159.17 2.110 64.368 t094.08 1158.50 1253.52 1.520 56.133 1188.38 1252.80 1345.99 1.010 61.387 1280.83 1345.25 1408.69 0.980 25.910 1343.52 1407.94 1439.61 1.970 352.686 1374.43 1438.85 Sperry-Sun Drilling Services Survey Report for $.20f PBf Your Reft APl 500292298770 Surveyed: 2 December, 2000 DEFINITIVE Alaska Drilling & Wells PBU_WOA S Pad 1486.26 2.570 341.931 1421.04 1485.46 1532.68 2.590 342.533 1467.41 1531.83 1625.69 2.670 346.089 1560.33 1624.75 1676.03 4.290 338.463 1610.57 1674.99 1720.30 6.250 333.848 1654.65 1719.07 Local Coordinates Northings Eastings fit) fit) 0.00 N 0.00 E 0.00 N 0.00 E 0.32 N 0.05 E 2.29 N 0.18 E 6.08 N 0.19 E 9.93 N 0.24 E 13.50 N 0.56 E 17.20 N 1.21 E 19.17 N 1.80 E 20.99 N 2.39 E 24.51 N 3.98 E 26.06 N 5.04 E 27.35 N 6.01 E 29.62 N 8.14 E 30.72 N 9.96 E 31.16 N 10.93 E 32.61N 13.53 E 33.69 N 15.27 E 34.43 N 15.99 E 35.20 N 16.03 E 36.99 N 15.61E 38.98 N 14.97 E 43.09 N 13.82 E 45.98 N 12.84E 49.68 N 11.17 E Global Coordinates Northings Easflngs fit) (ft) 5980789.92 N 618929.93 E 5980789.92 N 618929.93 E 5980790.24 N 618929.97 E 5980792.22 N 618930.08 E 5980796.00 N 618930.02 E 5980799.85 N 618930.01E 5980803.43 N 618930.27 E 5980807.14 N 618930.86 E 5980809.11N 618931.42 E 5980810.95 N 618931.99 E 5980814.49 N 618933.52 E 5980816.05 N 618934.55 E 5980817.37 N 618935.50 E 5980819.66 N 618937.60 E 5980820.79 N 618939.40 E 5980821.25 N 618940.36 E 5980822.74N 618942.94 E 5980823.85 N 618944.66 E 5980824.60 N 618945.37 E 5980825.37 N 618945.40 E 5980827.15 N 618944.95 E 5980829.13 N 618944.28 E 5980833.22 N 618943.06E 5980836.09 N 618942.04 E 5980839.77 N 618940.31E Dogleg Vertical Rate Section (°/lOOft) 0.00 0.00 0.00 0.26 0.26 2.01 1.98 0.54 5.38 0.56 8.81 0.18 11.89 0.45 14.93 0.60 16.44 0.29 17.82 0.64 20.28 0.66 21.21 0.25 21.95 0.58 23.04 0.83 23.23 0.36 23.21 O.68 23.37 0.57 23.58 O.97 23.93 4.11 24.6O 1.57 26.39 O.O7 28.46 O.2O 32.66 3.34 35.68 4.53 39.74 Comment AK-6 BP_IFR-AK ConUnued. . . DrillQuest 2.00.05 December, 2000 - 11:10 - 2. Sperry-Sun Drilling Services Survey Report for S-201PBf Your Reft APl 500292298770 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1812.90 11.090 330.125 1746.17 1810.59 1907.24 12.330 329.289 1838.54 1902.96 2000.02 15.350 331.078 1928.62 1993.04 2094.70 20.310 338.338 2018.73 2083.15 2187.13 25.870 341.469 2103.73 2168.15 2280.09 26.730 342.535 2187.07 2251.49 2374.01 32.790 340.017 2268.56 2332.98 2467.33 38.230 338.620 2344.50 2408.92 2559.87 43.870 337.243 2414.26 2478.68 2652.79 50.580 332.548 2477.35 2541.77 2744.91 56.650 329.818 2531.98 2596.40 2838.56 56.620 330.217 2583.48 2647.90 2931.31 56.580 330.159 2634.54 2698.96 3024.67 56.170 329.887 2686.24 2750.66 3118.38 54.730 330.711 2739.38 2803.80 3140.60 54.140 330.380 2752.31 2816.73 3199.82 54.200 330.226 2786.97 2851.39 3292.69 56.770 331.391 2839.59 2904.01 3385.82 57.670 332.553 2890.01 2954.43 3478.73 55.520 332.369 2941.16 3005.58 3572.79 55.490 333.156 2994.43 3058.85 3666.23 59.410 333.554 3044.70 3109.12 3759.74 61.770 334.766 3090.61 3155.03 3854.08 53.220 336.610 3141.27 3205.69 3947.14 58.960 334.772 3193.16 3257.58 Local Coordinates Northings Eastings (ft) (ft) 61.93 N 4.51 E 78.46 N 5.15 W 97.73 N 16.15 W 123.99 N 28.29 W 158.05 N 40.63 W 197.22 N 53.35W 241.31N 68.39W 291.99 N 87.57W 348.26 N 110.43W 409.89 N 139.47W 474.80 N 175.26W 542.55 N 214.34W 609.73 N 252.84W 677.07 N 291.68W 744.11N 329.93W 759.85 N 338.81W 801.55 N 362.60W 868.36 N 399.91W 937.47 N 436.70W 1006.24 N 472.55W 1075.17 N 508.03W 1145.55 N 543.34W 1218.86N 578.84W 1291.27 N 611.61W 1361.61N 643.43W Global Coordinates Northings EastJngs (ft) (ft) 5980851.92 N 618933.46 E 5980868.29 N 618923.53 E 5980887.38 N 618912.23 E 5980913.45 N 618899.68 E 5980947.30 N 618886.80 E 5980986.27 N 618873.46 E 5981030.12 N 618857.71E 5981080.48 N 618837.74E 5981136.39 N 618813.98 E 5981197.55 N 618783.97 E 5981261.88 N 618747.16 E 5981328.99 N 618707.00 E 5981395.56 N 618667.44E 5981462.27 N 618627.54E 5981528.70 N 618588.23 E 5981544.29 N 618579.09 E 5981585.62 N 618554.65 E 5981651.82 N 618516.29 E 5981720.34 N 618478.41E 5981788.53 N 618441.46 E 5981856.89 N 618404.89 E 5981926.70 N 618368.47 E 5981999.44N 618331.82 E 5982071.32 N 618297.89 E 5982141.14 N 618264.96 E Alaska Drilling & Wells PBU_WOA S Pad Dogleg Vertical Rate Section Comment ('/100fi) 5.26 53.68 1.33 72.77 3.29 94.91 5.73 123.83 6.16 159.85 1.06 200.63 6.59 246.86 5.89 300.81 6.17 361.41 8.11 429.53 7.01 503.56 0.36 581.58 0.07 658.85 0.50 736.40 1.70 813.42 2.92 831.46 0.23 879.38 2.95 955.77 1.43 1034.02 2.32 1111.55 4.21 1267.80 2.77 1349.25 9.21 1428.70 6.38 1505.86 Continued... ............. DrillQuest 2.00.05 December, 2000 - fl:fO - 3 - Sperry-Sun Drilling Services Survey Report for S-20f PB1 Your Ref: APl 500292298770 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 4040.29 56.350 334.594 3243.00 3307.42 1432.74N 677.08W 5982211.73 N 618230.19 E 4133.41 56.620 333.788 3294.41 3358.83 1502.63 N 710.88W 5982281.08 N 618195.28 E 4226.92 55.660 333.580 3346.51 3410.93 1572.23 N 745.30W 5982350.12 N 618159.76E 4227.50 55.690 332.797 3346.84 3411.26 1572.66 N 745.52W 5982350.55 N 618159.54 E 4321.24 55.240 334.259 3399.98 3464.40 1641.78 N 779.94W 5982419.11N 618124.02 E 4412.91 55.800 333.368 3451.88 3516.30 1709.59N 813.29W 5982486.38 N 618089.60 E 4506.66 56.050 332.515 3504.41 3568.83 1778.74N 848.62W 5982554.96 N 618053.18 E 4570.28 55.650 333.500 3540.12 3604.54 1825.65 N 872.51W 5982601.49 N 618028.54E 4601.32 54.760 334.227 3557.84 3622.26 1848.54N 883.74W 5982624.19 N 618016.95 E 4693.45 53.230 335.130 3611.99 3676.41 1915.90 N 915.62W 5982691.04 N 617984.01E 4769.00 53.230 335.130 3657.22 3721.64 1970.81N 941.07W 5982745.54 N 617957.69 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.670" (22-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 333.980° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4769.00ft., The Bottom Hole Displacement is 2183.96ft., in the Direction of 334.475° (True). Dogleg Rate (°/'lOOft) 2.81 0.78 1.04 111.68 1.37 1.01 0.80 1.43 3.45 1.84 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 1584.54 1662.18 1739.83 1740.31 1817.52 1893.08 1970.72 2023.37 2048.86 2123.38 2183.88 Projected to TD 19 December, 2000 - 11:10 .4. Continued... DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-20fPBf Your Ref: APl 500292298770 Surveyed: 2 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU_WOA $ Pad Comments Measured Depth (ft) 4769.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3721.64 1970.81 N 941.07 W Comment Projected to TD Survey tool program for S-20fPBf From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 4769.00 3721.64 Survey Tool Description AK-6 BP_IFR-AK 19 December, 2000.11:10 -5- DrillQuest 2.00.05 North Slope Alaska Alaska Drilling & Wells PBU_WOA $ Pad, Slot S-20f S-2OfPBf MWD Surveyed: 2 December, 2000 SURVEY REPORT 19 December, 2000 Your Ref: APl 500292298770 Surface Coordinates: 5980789.92 N, 618929.93 E (70° 21' 22.2099"N, 149° 02' 02.8488" HO Kelly Bushing: 64.42fl above Mean Sea Level D R I I,. I,. ~1 N {] EER~JlC'E$ A Halliburton Company Survey Reft svy10662 Sperry-Sun Drilling Services. Survey Report for S-20fPBf MWD Your Ref: APl 500292298770 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -64.42 0.00 120.00 0.000 0.000 55.58 120.00 237.75 0.310 7.820 173.33 237.75 329.76 2.160 3.220 265.31 329.73 421.49 2.580 357.030 356.97 421.39 514.35 2.180 5.260 449.75 514.17 605.42 2.340 4.810 540.74 605.16 697.89 2.330 14.970 633.14 697.56 745.88 2.580 18.180 681.08 745.50 789.53 2.460 17.340 724.69 789.11 882.13 2.350 31.010 817.21 881.63 930.12 2.140 37.100 865.16 929.58 974.52 2.040 35.710 909.53 973.95 1066.48 1.870 50.950 1001.44 1065.86 1129.45 2.020 65.800 1064.38 1128.80 1159.17 2.110 64.180 1094.08 1158.50 1253.52 1.520 55.910 1188.38 1252.80 1345.99 1.010 61.150 1280.83 1345.25 1408.69 0.980 25.690 1343.52 1407.94 1439.61 1.970 352.440 1374.43 1438.85 1486.26 2.570 341.700 1421.04 1485.46 1532.68 2.590 342.280 1467.41 1531.83 1625.69 2.670 345.870 1560.33 1624.75 1676.03 4.290 338.320 1610.57 1674.99 1720.30 6.250 333.900 1654.65 1719.07 Local Coordinates Northings Easfings (ft) (ft) 0.00 N 0.00 E ' 0.00 N 0.00 E 0.32 N 0.04 E ' 2.29 N 0.17 E 6.08 N 0.16 E 9.93 N 0.22 E 13.50 N 0.53 E 17.20 N 1.18 E 19.17 N 1.77 E 21.00 N 2.35 E 24.52 N 3.92 E 26.08 N 4.97 E 27.38 N 5.93 E 29.66 N 8.05 E 30.76 N 9.86 E 31.21N 10.83 E 32.67 N 13.43 E 33.75 N 15.16 E 34.50 N 15.88 E 35.27 N 15.92 E 37.05 N 15.49 E 39.04N 14.84 E 43.14 N 13.67 E 46.03 N 12.69 E 49.73 N 11.02 E Global Coordinates Northings Eastings (ft) (ft) 5980789.92 N 618929.93 5980789.92 N 618929.93 5980790.24 N 618929.97 5980792.22 N 618930.07 5980796.00 N 618930.00 5980799.85 N 618929.99 5980803.43 N 618930.25 5980807.14 N 618930.83 5980809.12 N 618931.39 5980810.95 N 618931.95 5980814.50 N 618933.46 5980816.08 N 618934.48 5980817.39 N 618935.43 5980819.70 N 618937.51 5980820.83 N 618939.30 5980821.30 N 618940.26 5980822.80 N 618942.84 5980823.91N 618944.55 5980824.67 N 618945.26 5980825.43 N 618945.29 5980827.21N 618944.83 5980829.19 N 618944.15 5980833.28 N 618942.92 5980836.15 N 618941.89 5980839.82 N 618940.16 Dogleg Rate (°ll00ft) 0.00 0.26 2.01 0.54 0.57 0.18 0.45 0.59 0.29 0.63 0.66 0.25 0.59 0.83 0.36 0.68 0.56 0.97 4.11 1.57 0.07 0.20 3.34 4.52 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 0.00 0.00 0.26 1.98 5.39 8.83 11.90 14.94 16.45 17.84 20.32 21.26 22.01 23.12 23.32 23.30 23.47 23.68 24.04 24.71 26.50 28.57 32.77 35.80 39.86 MWD Magnetic Continued... 19 December, 2000- 11:10 -2- DrillQuest 2.00.05 · Sperry-Sun Drilling Services Survey Report for S-20fPBf MWD Your Ref: AP150029229877'0 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1812.90 11.090 330.240 t746.17 1810.59 1907.24 12.330 329.400 1838.54 1902.96 2000.02 15.350 331.280 1928.62 1993.04 2094.70 20.310 338.350 2018.73 2083.15 2187.13 25.870 341.540 2103.73 2168.15 2280.09 26.730 342.520 2187.07 2251.49 2374.01 32.790 339.900 2268.56 2332.98 2467.33 38.230 338.540 2344.50 2408.92 2559.87 43.870 336.740 2414.26 2478.68 2652.79 50.580 332.450 2477.35 2541.77 2744.91 56.650 329.880 2531.97 2596.39 2838.56 56.620 330.470 2583.48 2647.90 2931.31 56.580 330.410 2634.54 2698.96 3024.67 56.170 330.260 2686.23 2750.65 3118.38 54.730 330.840 2739.38 2803.80 3140.60 54.140 330.350 2752.30 2816.72 3199.82 54.200 330.510 2786.97 2851.39 3292.69 56.770 331.230 2839.59 2904.01 3385.82 57.670 332.620 2890.01 2954.43 3478.73 55.520 331.940 2941.16 3005.58 3572.79 55.490 332.960 2994.43 3058.85 3666.23 59.410 335.150 3044.70 3109.12 3759.74 61.770 334.830 3090.61 3155.03 3854.08 53.220 336.610 3141.27 3205.69 3947.14 58.960 334.580 3193.16 3257.58 Local Coordinates Global Coordinates Northings Eastings Northings Easfings (ft) (ft) (ft) (ft) 62.00 N 4.38 E 5980851.98 N 618933.32 E 78.55 N 5.25W 5980868.37 N 618923.43 E 97.85 N 16.20W 5980887.50 N 618912.18 E 124.13 N 28.29W 5980913.58 N 618899.67 E 158.19 N 40.61W 5980947.45 N 618886.82 E 197.37N 53.31W 5980986.42 N 618873.50 E 241.44N 68.41W 5981030.25 N 618857.70 E 292.09 N 87.67W 5981080.58 N 618837.63 E 348.24N 110.83W 5981136.36 N 618813.59 E 409.73 N 140.18W 5981197.37 N 618783.26 E 474.62 N 175.99W 5981261.69 N 618746.43 E 542.48 N 214.89W 5981328.92 N 618706.46E 609.83 N 253.09W 5981395.66 N 618667.19 E 677.38 N 291.56W 59.81462.59 N 618627.65 E 744.59 N 329.51W 5981529.18 N 618588.64 E 760.33 N 338.38W 5981544.79 N 618579.52 E 802.09 N 362.08W 5981586.16 N 618555.16 E 868.94 N 399.32W 5981652.41N 618516.87 E 938.02 N 436.16W 5981720.90 N 618478.93 E 1006.68 N 472.23W 5981788.97 N 618441.77 E 1075.41N 508.09W 5981857.13 N 618404.83 E 1146.23 N 542.51W 5981927.39 N 618369.29 E 1220.04 N 576.95W 5982000.65 N 618333.69 E 1292.47 N 609.68W 5982072.55 N 618299.80 E 1362.74N 641.62W 5982142.31N 618266.76 E Dogleg Rate (°/lOOft) 5.26 1.33 3.29 5.71 6.16 1.04 6.60 5.89 6.23 7.97 6.96 0.53 0.O7 O.46 1.62 3.20 0.24 2.84 1.58 2.39 0.89 4.64 2.54 9.20 6.43 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 53.79 72.89 95.O4 123.96 159.97 200.75 246.98 3O0.94 361.56 429.70 5O3.72 581.76 659.O5 736.63 813.67 831.71 879.63 956.04 1034.28 1111.80 1189.30 1268.04 1349.48 1428.92 1506.09 Continued... 19 Oecembe~ 2000.11:10 -3- DriliQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S.201PB1 MWD Your Ref: APl 500292298770 Surveyed: 2 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Easflngs Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 4040.29 56.350 334.150 3243.00 3307.42 1433.69 N 675.66 w ' 5982212.70 N 618231.59 E 4133.41 56.620 333.560 3294.41 3358.83 1503.38 N 709.87 W 5982281.84 N 618196.28 E 4226.92 55.660 333.580 3346.51 3410.93 1572.92 N 744.43 W 5982350.82 N 618160,62 E 4227.50 55.690 332.560 3346.84 3411.26 1573.35 N 744.65 W 5982351.24 N 618160.39 E 4321.24 55.240 333.880 3399.98 3464.40 1642.28 N 779.44 W 5982419.62 N 618124.51 E 4412.91 55.800 333.600 3451.88 3516.30 1710.05 N 812.88 W 5982486.85 N 618090.00 E 4506.66 56.050 332.790 3504.41 3568.83 1779.35 N 647.90 W 5982555.59 N 618053.89 E 4570.28 55.650 333.500 3540.12 3604.54 1826.33 N 871.68 W 5982602.18 N 618029.36 E 4601.32 54.760 335.280 3557.83 3622.25 1849.31 N 882.70 W 5982624.98 N 618017.98 E 4693.45 53.230 336.980 3612.00 3676.42 1917.45 N 912.87 W 5982692.64 N 617986.74 E 4769.00 53.230 336.980 3657.22 3721.64 1973.15 N 936.53 W 5982747.96 N 617962.19 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.670" (22-Nov-O0) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 333.980° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4769.00ft., The Bottom Hole Displacement is 2184.13ft., in the Direction of 334.609° (True). Dogleg Rate (o/100rt) 2.83 0.60 1.03 145.33 1.26 0.66 0.76 1.12 5.51 2.23 0.00 Alaska Drilling & Wells PBU WOA $ Pad Vertical Section Comment 1584.78 1662.41 1740.06 1740.54 1817.75 1893.32 1970.96 2023.60 2049.09 2123.56 2184.00 Projected to TD 19 December, 2000.11:f0 .4 - Continued... DrillQuest 2.00.05 Sperry-Sun Drilling Services Survey Report for S-201PBf MWD Your Ref: APl 6002922987;'0 Surveyed: 2 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Comments Measured Depth (ft) 4769.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3721.64 1973.15 N 936.53 W Comment Projected to TD Survey tool program for S.2OfPB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 4769.00 3721.64 Survey Tool Description MWD Magnetic 19 Decembec 2000.11:10 -5- DrillQuest 2.00.05 1/2/01 ,i5.o i/ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 837 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Color Well Job # Log Description Date Blueline Sepia Prints CD J-01A MEM PROD PROFILE 001226 I i M-30 LEAK DETECTION LOG 001227 1 ! D.S. 6-18 PRODUCTION PROFILE 001225 1 1 D.S. 14-08A PSP GAS LIFT SURVEY 001227 1 1 D.S. 18-28 :PSP PPROF/IPROF 001221 I 1 S-201 20521 USIT 001206 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, Alaska 99508 Date Delivered: 1 o/o/ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATrN: Sherrie RecE~ 19-Dec-00 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-201PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 4,769.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 13-Dec-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-201MWD Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,199.82' MD 'MD 7,245.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ALASKA OIL AND GAS CONSERVATION CO~L~ISSION TONY KNOWLES, 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 Prudhoe Bay Unit S-201 BP Exploration (Alaska) Inc. Permit No: 200-184 Sur Loc: 4586'NSL, 4495'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 2481'NSL, 761'WEL, Sec. 27, T12N, RI2E, 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. Your request for exception to the diverter requirements of 20 AAC 25.035(c) 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, J. M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this 7,07 day of November, 2000 dlf/Enclosures Department Of Fish & Game, Habitat Section w/o encl. Departmen! of Environmental Conservation w/o encl. STATE OF ALASKA ALASKI IL AND GAS CONSERVATION coa{' ~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.3' Polaris Field / Schrader Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 D2.~-~ A.~ 028258 4. Location of well at surface 7. Unit or PrOperty Name 11. Type Bond (See 20 A^C 25.025) 4586' NSL, 4495' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2315' NSL, 674' WEL, SEC. 27, T12N, R12E, UM S-201 Number 2S100302630-277 At total de~.th 9. Approximate spud date 2481'~,~[61' WEL, SEC. 27, T12N, R12E, UM 11/20/2000 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 028257, 761' MDI S-105 is 16' away at surface 2560 6894' MD / 5466' TVD 16. To be completed for deviated wells o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 700' MD Maximum Hole Angle 51 Maximum surface 1728 psig, At total depth (TVD) 5185' / 2246 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casina Weight Grade Couplin,q Len,qth MD TVD MD TVD (include stare 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 ~ ~C 3225' Surface Surface 3_P_~5' 2798' 346 AS Lite 3, 302 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 6894' Surface Surface 6894' 5466' 396 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 Intermediate RECEIVED Production Liner NOV 08 00O Perforation depth: measured ~ true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Nurnbec Allen Sherritt, 564-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed DanStone ~-------'~-~-~"'~* ~ Title Senior Drilling Engineer Date I~/%1~ '!':'!~C:{ i',!::"ii~ii:'~:'!;':': ;;~[ ',!:,' '"~',i~x~.~ I · a;""~,i~[';=;:~i~,~?;':~F;dii~',~i~;.'H 'l'~i~"'.',~'i:!I~[l~N','~t~[ ~'!iIE~j{~i ~R~'~ h,~i~'~.~j41.~,~..~!iI~'~#~ii=~,,~',:~[]~ ;.!, ~ ',,. ,i ~,; ;,,~,~ ,, ~,~,,~, 'tli~ "",'. ' ~"':""" 'rP '~,'; ~,,'.1'.,','.'.~,,.~,', ~ ~..,,,n...,,~, ~,*~i,~' . ~.' .... ,,.. ',..'.'..'.,.., ..,,.,~ , ,'~. Permit Num~.~ /~> ~..~l APl Number --, ~p/p. ro~D,.a~(...) I See cover letter ' ' -' 50- (3~..~ - ,?--~--"7'~:~7-"4~..~ - . for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes I~1 No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,~,3.5K psHc~ Other: by order of Approved By Commissioner the commission Date I ~ ii '~ i wi, i ~*- -,~ E a~ ~ ~. i Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate IWell Name: IS_201 RECEIVED NOV 08 Drill and Complete Plan Summa[~,a& G~c~, I Type of Well (service / producer / injector): I Producer ~-";'~'~ Surface Location: Target Location: Schrader M Sands Target Location: Schrader Ob Sands Bottom Hole Location: X = 618,929.93 Y = 5,980,789.92 4586' FSL (693' FNL), 4495' FEL (783' FWL), Sec. 35, T12N, R12E Umiat X = 617,420.00 Y = 5,983,775.00 2315' FSL (2964' FNL), 674' FEL (4604' FWL), Sec. 27, T12N, R12E Umiat X = 617,365.00 Y = 5,983,875.00 2415' FSL (2863' FNL), 727' FEL (4551' FWL), Sec. 27, T12N, R12E Umiat X = 617,330.00 Y = 5,983,940.00 2481' FSL (2798' FNL), 761' FEL (4517' FWL), Sec. 27, T12N, R12E Umiat I AFE Number: 15M1003 I Estimated Start Date:I 11/20/2000 I MD: 16,894'I TVD: 15466' I Rig: I Nabors 9ES I Operating days to complete: 114.2 leE/MS: 135.8' I IRKS: 164.3' I Well Design (conventional, slimhole, etc.): I Ultra Slimhole Longstring I Objective: I Schrader Formation Mud Program: 12-1/4" Surface Hole (0-3225'): Fresh Water Surface Hole Mud Interval Density' Viscosity YP PV -Gel~-~ ...... I~i;i~'-- (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" Lonqstring Production Hole (3225' - 6894'): Freshwater LSND Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.0 42-52 15-25 10-19 9.0-9.5 6cc <14 shoe to TD to <5 S-105 Permit to Drill Page I Directional: KOP: 1700' Maximum Hole Angle: Close Approach Wells: 51° at 2709' MD - Surface hole through Intermediate hole S-105 is located 45' North of surface location. Closest point will be at -1300' MD; 38.1' S-103 is located 15' South of surface location. Closest point is from surface to -800' MD; 16'. Gyro surveys will be used to mitigate the close approach issues in the surface hole. Logging Program: Surface Intermediate ! Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den + MAD pass Sample catchers Open Hole: RFT pressures and samples in both the Schrader and Ugnu intervals. Cased Hole: USIT CBL Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 2030 1875 SV3 / T5 3126 2670 8.64 ppg EMW (pore pressure = 1200) SV2 3382 2830 8.66 ppg EMW (pore pressure = 1275) SV1 3925 3170 9.43 ppg EMW (pore pressure = 1557) Ugnu top UG4 4484 3520 9.29 ppg EMW (pore pressure = 1727) UG4A 4572 3575 Unknown, (10.5 ppg MW required on SB-01) S-102 reduced hydrostatic to 9.0 ppg EMW with no indication of problems. UG3 5084 3895 8.84 ppg EMW (pore pressure = 1790) UG1 5939 4500 8.55 ppg EMW (pore pressure = 2001) Top Ugnu Ma Sand 6096 4640 8.54 ppg EMW (pore pressure = 2061) Base Mb2 sand / WS2 6266 4800 8.51 ppg EMW (pore pressure = 2124) Schrader Oa / WS1 6464 4950 8.43 ppg EMW (pore pressure = 2170) Schrader Ob 6623 5140 8.34 ppg EMW (pore pressure = 2230) CM3 6670 5185 8.33 ppg EMW (pore pressure = 2246) TD 6894 5400 TD S-105 Permit to Drill RECEIVED NOV 08 Alma~ &~lsCons. Cemmm Page 2 Casinq/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb9 O.D. MD/TVD MD/'rVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC 3225' GL 3225'/2798' 8-3/4" 7" 26# L-80 BTC-M ,,6894~'~ GL 6894'/5466' Tubing 3-1/2" 9.3# L-80 EUE~ GL 6046'/4661' 8rd 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 1920' of annulus in the permafrost @ 100% excess and 418' 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 -2448' MD (2298' TVDbkb). Lead 1274 bbl / 1536 ft~ / 346 sks of Dowell ARTICSET Lite 3 at 1 10.7 ppg and 4.44 cf/sk. Tail 62 bbl / 350 ft~ / 302 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. I Casin(. Size 17" Intermediate I Basis: Lead: to 500' MD above the Ugnu 4A Formation and 30% excess Lead TOC: 3984' MD Tail: Based on TOC 1000' above top of Schrader formation and 30% excess + shoe Tail TOC: 5095' MD, 3968' TVDbkb i Total Cement Volume: I Lead 139 bbls / 218 ft~/78 sks of Dowell Extended blend atI 11.5 ppg and 2.79 cf/sk. Tail 1 66 bbls / 369 ftc/318 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. S-105 Permit to Drill RECEIVED 08 000 Page 3 Well Control: Surface h01e will be drilled without diverter. Please refer to the AOGCC Diverter Dispensation granted, on 11-6-00, for surface holes drilled on Prudhoe Bay S-Pad. 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: 2246 psi @ 5185' TVDss - Kuparuk Target Top 1728 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: 8.4 ppg seawater / 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: The surface hole close approach issues will mitigated by utilizing a surveying with gyro surveying tools. SURFACE HOLE SECTION: · Directional control was an issue in the S-100 and $-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. The first three Aurora wells on S-pad experienced some degree of tight hole while drilling and casing the surface hole. Conditions have improved with 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. RECEIVED S-105 Permit to Drill 08 2000 Page 4 INTERMEDIATE/PRODUCTION HOLE SECTION: · 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 the surface casing to mitigate differential sticking hazards across the sand. The HRZ will not be penetrated, allowing for a lower mud weight while drilling the production interval, thus minimizing the risk of differential sticking. · The kick tolerance for the 8 3A,, open hole section would be 118 bbls assuming an influx from the Schrader interval at -6,894' MD. This is a worst case scenario based on a 8.33 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.0 ppg mud in the hole. Rig will perform FIT to 12.5 EMW after drilling 20ft of new formation. · The closest mapped fault is approximately >1000' away from the planned target coordinate at the top of Schrader formation. 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, S-101, S-102 and S- 105 have all contained 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. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: A 20" conductor has been set for this well. Costs associated with setting the conductor will be covered under a separate conductor AFE. 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig 1. 2. . Operations: MIRU Nabors 9ES. ~~' ,,~'t~[' ~,,~~~ ~'~~, ~,~I~ [ ~_~~ Nipple up Diverter ~ (dispensation from running Diverter for surface holes on S-Pad.) PU 5" DP as required and stand back in derrick. MU 12-1/4" drilling assembly with MWD and directionally drill surface hole to approximately 3225' MD / 2798' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV3 sands. Run and cement the 9-5/8", 40# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. I' tJP_..IV I S-105 Permit to Drill I 0V 08 2000 Page 5 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 8-3/4" drilling assembly with MWD/GR/Res and RIH to float collar. Test the 9-5/8" casing to 3000 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 FIT to 12.5 EMW. 8. Drill ahead to TD of well @ -6894' MD/5466' TVD approximately -200' rat hole below the base of the Schrader Ob sands as required for logging. Condition hole for logging and POOH. 9. RU Schlumberger E-line unit. Make one logging run across Schrader interval (RFT 40 pressure and 2 samples.) POOH and RD Schlumberger. 10. RIH with 8-3/4" cleanout assembly and condition hole for running the 7" casing. POOH laying down the 5" DP. 11. Run and cement the 7", 26# production casing as required to cover all significant hydrocarbon intervals. Displace the 7" casing with seawater completion fluid during cementing operations and freeze protect the 7" x 9-5/8" annulus as required. 12. RU Schlumberger E-line unit. Make run CBL USIT log, minimum of 12 hrs after cementing 7" production casing. Pressure casing to 1500 psi while running log to eliminate micro- annulus. POOH and RD Schlumberger. 13. Test the 7" casing to 3500 psi for 30 min. 14. Run the 3-1/2", 9.3#, L-80 8rd-Mod gas lift completion assembly. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect the well to -2200' and secure the well. 17. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug. 2. RU E-line and perforate Schrader interval with E-line conveyed guns. 3. Perform fracture stimulation on Schrader interval as required. Estimated Spud Date: 11/20/2000 Allen Sherritt BP Alaska Drilling and Wells 564-5204 sherrija@ BP.com RECEIVED I OV O8 S-105 Permit to Drill Page 6 Polaris S-201 Proposed Completion TREE: 4.1/16 "- 5M ClW L-80 WELLHEAD: 11" - 5M FMC G5 9-5/8", 40 #/ft, L-80, BTC Plug Back Depth 16,809' 7", 29 #/ft, L-80, BTC-Mod I ! I I I 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I 2200' Cellar Elevation = 35.9' Nabors 9ES RKB = 65.9' 3-1/2" x 1-1/2" Camco 'MMG' Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS 2 ~ 3500 1-1/2" DV 3 .... 45O01 1-1/2" DV 4 4600 1-1/2" DV 3-1/2" 9.3# L-80, EUE 8rd-Mod Tubing 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 3-1/2" Baker 'S-3' Production Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore and 2.725" No-Go ID. 3-1/2" 'X' Landing Nipple with 2.813" seal bore and 2.725" No-Go ID. 3-1/2" WireLine Entry Guide set at +/-6046' (-50' above the Schrader Ungu Ma Formation). RECEIVED 08 000 Date Rev By Comments 10/11/00 JAS Proposed Completion Polaris WELL: S-201 APl NO: 50-029-????? BP Alaska Drilling & Wells I S-201 Ri.site RECEtVED Summary of Drilling Hazards NOV OOO POST THIS NOTICE IN THE DOGHOUSBeaa~&~a~Cms' Expected formation pressure below the permafrost is 9.0 ppg EMW. The surface holes on the S-Pad Aurora wells 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. Surface hole will be drilled without Diverter system. Pre-spud and PJS meetings will include discussions about possible hazards and proper hole monitoring procedures while drilling surface hole. Lost circulation while drilling has not been a problem in the first three wells of the Aurora development, despite several fault crossings. S-102 experienced total losses while running the 7" intermediate casing to bottom, (11.5 ppg MW, hole would stand full with pipe static) and S-105 experienced 3 to 5 BPH losses while drilling the 8 3A" section. The S-S01 well bore trajectory will not cross any planned faults prior to TD of the production interval. The SSD Lost Circulation tree should be followed if losses are encountered. The Ugnu formation on all of the S-Pad Aurora wells, have contained hydrocarbons. LWD tools will be used to determine hydrocarbon presence in the Ugnu interval. Cement will need to be brought minimum 500 feet above the Ugnu formation. The surface casing will be set higher in the SV3 formation to minimize the possibility of cement across the surface shoe and production casing over lap. 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 1 rtl:Ill_LING Proposal Data for S-201 Wp 01 Vertical Origin: We~l HonZOntaIOdgln:Well Measurement Urflts: ft Noflh Reference: True Nor~ Dogleg severffy: Degrees per 10Oft Vefllcal Section Azmuth: 333.983' Vertical Section Desc dption: Wail Vefllcal Section Origin: 0.00 N,0.00 E Meeeured Incl. ,~lm. VerticalNorthlnga Depth Depth 0.~0 O.0000.ql0 ?(X~.O00.0000.gl0 9~0,00 2.0003.t4.159 8~.96 1100.O06,0003.~t. 159 1099.43 13t~.0012.000 334.159129638 1952.7031.581 3.Lt 159 19~0,00 205230 31,581 3,M. 150 I085,19 2708,7051.261 334.1582474.69 54l'k1.41 51.261 334.1584160.96 6245.5817.590 332,0t3~ fi252..~ 17.K60 332,02848.~;2.1~ &q~,46 17.860 332,0285109,24 fi6[g,26 15.Kq I 332,6095205.70 6893.5315.Kql 332,6095465.70 Single Well Target Data for S-201 WPS (EX 9) Measurement Units: ft Coordinate Target Point TVDrkI~TVDae Northlnge Eaatlnga Name Type Shared Services Drilling S-201 Wo 01 (ex9) Eastings Scale: I inch = 700ft 3500 Vail 0.00 N 0.130 I{0,~1 0.00 N 0.~ E 0.~ 0.~ 3.14 N 1,52 W K49 1.~ 15.~ N 7,~ W 17.~ 43.~ N 21.23 W ~,71 3.~ 2~.Kq N 126.33 W ~.83 3.~ 307.~ N I~. 16 W ~2.~ 0.~ ~.~ N 337.41 W 774.~ 3.~ [q88,~ N 1253.fi1 W 2875.~ .~.~ N 1~..~ W 3.~. 174.~ ~10.42 N 1~.35 W 3~7.[~ 4.~ ~,~.s,, ~sm.2o w ~.m o.~ 2800 31~.~ N 1515.78 W~q9.24 2.~ 3175.~ N 15~.75 W 3533,ffi 0.~ ~P Y ~P X Target C~ c~ O Z 1400 in Dir Bate ~ 2.000°/~ ~ft: O~.00ff MD, 899.06ft TVD in Dir 8ate ~ 3.O00°/lOOft: ~ lO0.OOft MD, 1099.43ft .700 Dir: ~952.70ft MD. 19~.OOft TVD Dir ~ 3.000°/lOOft: 2052.70ft MD, 1985.19ft TVD ................................................................... B Perm 1965. 7O 0 Dir' 2708.70ft MD, 2474.69ft IVD S-2111 M S~md ITl) Entvj P, int S-201 Obd Sand ('1'21 Entry Point I~mnd~y P,int C S-201 TD (T3) Entry 1000 20O0 3000 4845.704780.00 3038,60N 1462.38W 5983T75.00N 617420.00E 5205.705140,(X) 3109.46N 1515.78W 5983875.00N 617~5.00E 5205,705140.00 2893.45N lTFO.?qW 59831~qS.00N 617115,001'; 5205.705140.00 3397.04N 1676.24W 59841fiO,00N 617200.00E 5205 705140,00 3234.44 N 1.124.78 W 5984I)03.00 N 617554.00 5205.70514(I.00 2784,50N 1331.92W 5983553.00N 617~q4.(X)E 54~q,7054(Xl.00 3175.(X)N 1549.75W 5983940.00N 617330,00E in Dir @ 1.000°/100ft· 700.0Oft MD, 700.00ft TVD 4000 I DriHQuest 35O0 2800 2100 1400 7OO -1400 -700 0 { I ' -- 700.00 ~~0o0 9 5/8" Casing __ lOO.OO 1 v2) R I I -1400 -700 0 o Z $¥"3 .... 27-£5_ 7O.TVD ..................... SV2 9 5/8" Casing 2,S~.S. 7o TVD 4084.62 MD 3,335.70 TVD SVI 3235.70 7'VD UG4 ..................... ..LS,'t~. 70 TVI) UG4A ~?6dO, 70 TVI) in Oir @ 4.000~ MD, 416C Reference is True North Eastings Scale: linch = 700ft Current Well Properties Well: S-201 WPS (EX 9) Horizontal Coordinates: Ref. Gbbal Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: 100ft: 6t D '~o~h ;re~f/orenco: Units: 5980790.00 N, 618929.96 E 82.31 S, 1012.06 E 70° 21'22.2107" N, 149° 02' 02.8479" W 65.70ff above Mean Sea Level 65.70ft above Structure Reference True North Feet Top Scltr~ub'r M Srmd,v 4705, 70 TVI) 7'tq~ Ohd Satu/,v 5205.70 TV/) I 0 1000 Scale: linch = 1000ft ,':i~:!',l'al j!;'. y 19 'dr II.'? ,l~ .ii,1~,(11!)~.471~ ?,/, iI?:!L[J:;,?3[ ?1 ?:[,,,ik'il'[,~i'. ylql I I 2000 3000 Dil~ '." 6252.36ft MD, 4852.16ft TVD Dir @ 2.000°/100ft· 6522.46ft MD, 5109.24ft TVD : 6623.26ft MD, 5205.70ft TVD 7" Casing 6893.53 MD 5465.70 TVD Section Azimuth: 333.983° (Tree North) Vertical Section Prepared: rhecked: ~3Proved: Spe,. y-Sun Drilling vices Proposal Data - S-201 WPS (EX 9) - S-201 Wp 01 (ft) MD (ft) (°) (°) (ft) TVD (ft) (ft) (ft) (°/100ft) (°) (ft) ................. J I I..__ ...... J.._ ............... .L ........... _1 ................. I ................... i ................. I .................. -I 1 0.00 0.000, 0.000 O.OOi 0.00 ~; 0.001 : O.OOl i~"'"-: ....... F6~o- ....... i,~'i~': ...... '6;'~-~ ........... i~:'~ .... ~'i ......... ~,~t'~-' ......... ~i~'! ................. ~! ............ ~,"c~'! 4 1100.00, 200.00 6.000; 334.159 1099.43 199.47!: 15.69 Nt 7.60Wi 2.000 0.000 17.44~ 5 1300.00 200.00 12.0001 334.1591 1296.88!~ 197.45: 43.84 N~. 21.23W! 3.000 0.000: 48.71 6' 1952.70i 652.70' 31.5811 334.159 1900.001 603.12 260.85N! 126.33W! 3.000; 0.000 289.83i 7 2052.70 100.00 31.5811 334.159i 1985.19! 85.191 307.98N] 149.16Wi 0.0001 0.0001 342.20 8 2708.70 656.00 51.261 334.158 2474.69 489.50 696.66 N 337.41 W 3.000 359.998 774.07 9 5403.41 2694.71 51.261 334.158 4160.96 1686.27 2588.36 N 1253.61 W 0.000 0.000 2875.94 10 6245.58 842.17 17.590 332.099 4845.70 684.74 3008.60 N 1462.38W 4.000 181.122 3345.17 11 6252.36 6.78 17.860 332.028 4852.16 6.46 3010.42 N 1463.35 W 4.000 355.413 3347.23 12 6522.46 270.10 17.860 332.028 5109.24 257.08 3083.58 N 1502.20 W 0.000 0.000 3430.02 13 6623.26 100.80 15.851 332.609 5205.70 96.46 3109.46 N 1515.78W 2.000 175.486 3459.24 29 September, 2000 - 10:56 - 1 - Dri#Quest Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northinge Eestings Northinge Eaatinga (ft) (ft) Ut) (ft) (ft) (ft) (ft) 0.00 0.0(X) 0.000 -65.70 0.00 0.00 N 0.00 E 618929.96 E 100.00 0.000 0.000 34.30 100.00 0.00 N 0.00 E 618929.96 E 200.00 0.000 0.000 134.30 200.00 0.00 N 0.00 E 618929.96 E 300.00 0.000 0.000 234.30 300.00 0.00 N 0.00 E 618929.96 E 400.00 0.000 0.000 334.30 400.00 0.00 N 0.00 E 618929.96 E 500.00 0.000 0.000 434.30 500.00 0.00 N 0.00 618929.96 E 600.00 0.000 0.000 534.30 600.00 0.00 N 618929.96 E 700.00 0.000 0.000 634.30 700.00 0.00 N 0.00 618929.96 E 800.00 1.000 334.159 734.29 799.99 0.79 N 618929.57 E 900.00 2.000 334.159 834.26 899.96 3.14 N N 618928.39 E 1000.00 4.000 334.159 934.12 999.82 7.;__ W 5980797.79 N 618926.03 E 1100.00 6.000 334.159 1033.73 1099.43 15.~!11~ 7.60 W 5980805.57 N 618922.11 E 1200.00 9.000 334.159 1132.86 1198.56 27.44 NV 13.29 W 5980817.23 N 618916.24 E 13(X).00 12.000 334.159 1231.18 1296.88 43.84 N 21.23 W 5980833.50 N 618908.03 E 1400.00 15.000 334.159 1328.40 1394.10 64.65 N 31.41 W 5980854.34 N 618897.53 E 1500.00 18.000 334.159 1424.28 1489.98 90.41 N 43.78 W 5980879.70 N 618884.75 E 1600.00 21.000 334.159 1518.53 1584.23 120.45 N 56.33 W 5980909.50 N 618869.72 E 1700.00 24.000 334.159 1610.91 1676.61 154.88 N 75.01 W 5980943.67 N 618852.50 E 1800.00 27.000 334.159 1701.16 1766.86 193.63 N 93.77 W 5980982.11 N 618833.12 E 1900.00 30.000 334.159 1789.03 1854.73 236.57 N 114.57 W 5981024.72 N 618811.65 E 1952.70 31.581 334.159 1834.30 1900.00 260185 N 126.33 W 5981048.81 N 618799.50 E 20(X).00 31.581 334.159 1874.59 1940.29 283.14 N 137.13 W 5981070.93 N 618788.36 E 2029.63 31.581 334.159 19(X).00 1965.70 297.20 N 143.93 W 5981084.87 N 618781.33 E 2052.70 31.581 334.159 1919.49 1985.19 307.98 N 149.16 W 5981095.57 N 618775.93 E 2100.00 33.000 334.159 1959.47 2025.17 330.72 N 160.17 W 5981118.13 N 618764.56 E Dogleg Rate (°ilOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1.000 1.000 3.000 3.0(X) 3.000 3.000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 3.000 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 0.87 3.49 8.72 17.44 30.49 48.71 72.05 100.45 133.83 172.09 215.14 262.85 289.83 314.60 330.21 342.20 367.46 Comment 7El~.i~t ir O 1.000°/100ft: MD, 700.00ft TVD Increase in Dir Rate O 2.000°/100ft: 900.00ft MD, 899.98ft TVD Increase in Dir Rate ~ 3.000°/100ft: 1100.00ft MD, 1099.43ft TVD End Dir: 1952.70ft MD, 1900.00ft TVD B Perm 20B~2in Dir ~ 3.000°/100ff: .70ft MD, 1985.19ft TVD Continued... 29 September, 2000- 11:29 - 1 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 2200.05 36.000 334.158 2041.87 2107.57 2300.00 39.000 334.158 2121.20 2186.90 2400.00 42.030 334.158 2197.23 2262.93 2500.00 45.000 334.158 2269.76 2335.46 2600.03 48.030 334.158 2338.59 2404.29 2700.03 51.000 334.1 58 2403.53 2469.23 2708.70 51.261 334.158 2408.99 2474.69 2800.00 51.261 334.158 2466.12 2531.82 2900.00 51.261 334.1 58 2528.70 2594.40 3000.00 51.261 334.158 2591.27 2656.97 3100.00 51.261 334.158 2653.85 2719.55 3125.81 51.261 334.158 2670.00 2735.70 3200.00 51.261 334.158 2716.43 2782.13 3300.08 51.261 334.1 58 2779.08 2844.70 3381.49 51.261 334.158 2830.00 2895.70 3400.08 51.261 334.158 2841.58 2907.28 3500.00 51.261 334.158 2904.16 2969.86 3600.00 51.261 334.158 2966.74 3032.44 3700.08 51.261 334.158 3029.31 3095.01 3800.00 51.261 334.158 3091.89 3157.59 3900.08 51.261 334.1 58 3154.47 3220.17 3924.82 51.261 334.1 58 3170.00 3235.70 4(X)0.00 51.261 334.158 3217.05 3282.75 4084.62 51.261 334.158 3270.00 3335.70 4108.00 51.261 334.158 3279.62 3345.32 Local Coordinates Northings Eaetings (ft) (ft) 381.69 N 184.86 W 436.47 N 211.39 W 494.92 N 239.69 W 556.86 N 269.70 W 622.14 N 301.31 W 690.57 N 334.45 696.66 N 337.41 760.75 N 830.95 N 901.15 N 971.35 ~W 1 1168.96 N 1181.96 N 1252.16 N 1322.36 N 1392.58 N 1452.76 N 1532.96 N 1550.38 N 1603.16 N 1662.58 N 1673.36 N 572.45 W 606.45 W 640.45 W 674.45 W 708.45 W 742.45 W 750.89 W 776.45 W 805.22 W 810.45 W Global Coordinates Northinge (ft) 5981168.7~1~ N N N N 5981614.46 N 1N 5981753.76 N _ 5981771.74 N 5981823.42 N 5981893.07 N 5981949.83 N Eaetinge (ft) 618739.07 E 618711.67 E 618682.44 E -- 618651.46 E 618618.81 E 618584.59 E 618581.54 E 618549.48 E 618514.37 E 618479.26 E 618444.15 E 618435.08 E 618409.04 E 618373.93 E 618345.32 E 618338.82 E 618303.71 E 618268.60 E 616233.49 E 618198.38 E 618163.27 E 618154.55 E 618128.16 E 618098.44 E 618083.05 E 5981962.72 N 5982032.37 N 5982102.02 N 5982171.67 N 5982241.33 N 5982310.98 N 5982328.26 N 5982380.63 N 5982439.57 N 5982450.28 N Dogleg Rate (o/looft) 3.000 3.030 3.000 3.000 3.030 3.000 3.000 0.030 0.030 0.030 0.030 0.000 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.000 0.030 0.030 0.030 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 424.10 549.90 618.73 691.26 767.29 774.07 845.26 923.28 1001.28 1079.28 1099.41 1157.28 1235.28 1298.84 1313.28 1391.28 1469.28 1547.28 1625.28 1703.28 1722.64 1781.28 1647.29 1859.28 Comment 47nd Dir: 2708.70ft MD, 4.69ft TVD SV3 SV2 ~ Continued... 29 September, 2000 - 11:29 - 2 - DrlllQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 4200.00 51.261 334.158 3342.20 3407.90 4300.00 51.261 334.158 3404.78 3470.48 4400.00 51.261 334.158 3467.35 3533.05 4484.13 51.261 334.158 3520.00 3585.70 4500.00 51.261 334.158 3529.93 3595.63 4572.02 51.261 334.158 3575.00 3640.70 46(X).00 51.261 334.158 3592.51 3658.21 4700.00 51.261 334.158 3655.09 3720.79 4800.00 51.261 334.158 3717.66 3763.36 4900.00 51.261 334.158 3780.24 3845.94 5(XX).00 51.261 334.158 3842.82 3908.52 5100.00 51.261 334.158 3905.39 3971.09 5200.00 51.261 334.158 3967.97 4033.67 5300.00 51.261 334.1 58 4030.55 4096.25 5400.00 51.261 334.158 4093.13 4158.83 5403.41 51.261 334.1 58 4095.26 4160.96 5500.00 47.398 334.055 41 58.20 4223.90 5600.00 43.399 333.934 4228.40 4294.10 5700.00 39.4(X) 333.794 4303.39 4369.09 5800.00 35.402 333.628 4382.82 4448.52 5900.00 31.403 333.428 4466.28 4531.98 6(XX).00 27.405 333.172 4553.38 4619.08 6095.97 23.569 332.854 4540.00 4705.70 6100.00 23.408 332.838 4643.70 4709.40 6200.00 19.411 332.376 4735.78 4802.48 Local Coordinates Global Coordinates Northings Eeetinga Northinge Eeetinge (ft) (ft) (ft) (ft) 1743.58 N 844.45 W 5962519._~._~_~_~_~_~_~_~' 618057.94 E 1813.76 N 878.45 W 618022.62 E 1883.98 N 912.45 W 617987.71 E 1943.02 N 941.06 W 617958.18 E 1954.16 N 946.45 W 617952.60 E 2004.72 N 970.94 617927.32 E 2924.36 N 980.45 -- 617917.49 E 2094.56 N 1014.45 617982.38 E 2164.76 N 11 N 617847.27 E 2234.96 N 5983007.49 N 617812.16 E 2305.16 N 5983077.15 N 617777.05 E 2375.36 W~ 5963146.80 N 617741.94 E 2445J 5963216.45 N 617706.63 E 5983286.10 N 617671.72 E 5993355.75 N 617636.61 E 2588.35 N 1253.61 W 5983358.13 N 617635.41 E 2654.25 N 1285.60 W 5983423.50 N 617602.38 E 2718.23 N 1316.81 W 5983486.98 N 617570.16 E 2777.59 N 1345.93 W 5983545.87 N 617540.10 E 2632.04 N 1372.82 W 5963599.58 N 617512.35 E 2881.31 N 1397.35 W 5983648.76 N 617487.04 E 2925.16 N 1419.40 W 5983692.26 N 617454.30 E 2961.95 N 1438.13 W 5983728.75 N 617444.99 E 2983.39 N 1438.86 W 5983730.17 N 617444.23 E 2995.80 N 1455.64 W 5983762.31 N 617426.94 E Dogleg Rate (°/100ft) 0.0o0 0.00o 0.000 0.000 0.000 0.000 0.000 o.000 0.000 0.000 0.000 0.000 0.000 0.00o 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.(xx) 4.000 4.000 4.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section Comment (ft) 1937.28 2015.28 2171.28 2227.46 UG4A 2249.28 2327.28 2495.28 2463.28 2639.28 ~717.26 2795.28 2873.28 2875.94 ~in ~ir ~ 4.~/l~t: ffi3.41fl MD, 41~.~fl TVD 2949.19 ~.38 ~" ~.49 3147.22 ~.26 ~51 .~ ~.62 T~ Schr~ M S~s 32~.23 ~.72 Continued.., 29 September, 2000 - 11:29 - 3 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth fit) (ft) 6245.58 17.590 332.099 4780.00 6252.36 17.860 332.028 4786.46 6300.00 17.860 332.028 4631.80 6400.00 17.860 332.028 4926.98 6500.00 17.860 332.028 5022.16 6522.46 17.860 332.028 5043.54 6600.00 16.315 332.463 5117.66 6623.26 15.851 332.609 5140.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4845.70 3008.60 N 1462.38 W 617420.00 E 4852.16 3010.42 N 1463.35 W 617419.00 E 4897.50 3023.32 N 1470.20 W ~ E 4992.68 3050.41 N 1484.58 W N 617397.13 E 5087.86 3077.50 N 1498.97 W N 617382.32 E 5109.24 3083.58 N N 617378.99 E 5183.36 3103.74 N 1~ N 617368.06 E 5205.70 3109.46 N 5983875.00 N 617385.00 E Dogleg Rate (o/100ft) 4.000 4.000 0.000 0.000 0.000 0.000 2.000 2.000 6700.00 15.851 332.609 5213.83 5279.53 ; W 5983893.45 N 617355.06 E 6800.00 15.851 332.609 5310.02 5375.72 5983917.51 N 617342.11 E 6893.53 15.851 332.609 5400.00 5465.70 3175.00 5983940.00 N 617330.00 E 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 333.983° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6893.53ft., The Bottom Hole Displacement is 3533.04ft., in the Direction of 333.983° (True). Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) 3345.17 3347.23 3381.84 3392.49 3423.14 3430.02 3459.24 3480.19 3507.50 Comment 2T~.~- S-201 M Sand (T1), Radius., Geolog~al End Dir: 6252.36fl MD, 4852.16ff TVD End Dir: 6823.26ft MD, -~2~,5¢~b~i~tsT~ D Total Deoth: 6893.53ft MD, 5465.70ft TVD 7' Casing Tamer - S-201 TD (T3)~ . 200~.00 Radius., Gdolo~oa~ Continued... 29 September, 2000 - 11:29 - 4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured $ t a t i o n Depth TVD Northings (ft) (fi) (ft) 700.00 700.00 0.00 N 900.00 899.96 3.14 N 1100.00 1099.43 15.69 N 1952.70 1900.00 260.85 N 2052.70 1985.19 307.98 N 2708.70 2474.69 696.66 N 5403.41 4160.96 2588.36 N 6252.36 4852.16 3010.42 N 6522.46 5109.24 3083.58 N 6623.25 5205.70 3108.46 N Coordinates Eastings Comment (ft) 0.00 E Begin Dir ¢~ 1.000°/100ff: 1.52 W Increase in Dir Rate O 7.60 W Increase in Dir Rate O 126.33 W End Dir: 1952.70ft MD, 1!; 149.16 W Begin Dir ~ 3.000°/l(X)ff 337.41 W End Dir: 12,53.61 W Begin Dir ~ 1463.35 W End Dir: 1502.20 W Begin 1515.78 W End 6893.53 5465.70 3175.00 N 1549.75 W Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Easflngs (ft) (ft) (ft) (ft) (ft) 2029.83 1965.70 1900.00 297.20 N 143.93 W 3125.81 2735.70 2670.00 989.47 N 479.22 W 3381.49 2895.70 2830.00 1168.96 N 566.16 W 3924.82 3235.70 3170.00 1550.38 N 750.89 W 4484.13 3585.70 3520.00 1943.02 N 941.06 W 4572.02 3640.70 3575.00 2004.72 N 970.94 W 6095.97 4705.70 4640.05 2961.96 N 1438.13 W 6623.25 5205.70 5140.00 3109.46 N 1515.78 W MD, 899.96ft TVD MD, 1099.43ft TVD TVD MD, 4160.g6ft TVD :TVD MD, 5109.24ft TVD TVD 3ft MD, 5465.70ft TVD Formation Name B Perm SV3 SV2 SV1 UG4 UG4A Top Schrader M Sands Top Obd Sands Continued... 29 September, 2000 - 11:29 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (fi) (ft) (ft) (fi) <Surface> <Surface> 4084.62 3335.70 <Surface> <Surface> 6893.53 5465.70 Targets associated with this wellpath Target Name S-201 M Sand ('1'1) S-201 Obd Sand (3'2) Casing Detail 9 5/8' Casing 7' Casing Mean Sea Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundmy Point #1 Mean Sea LeveVGIobal Coordinates #1 #2 #3 #4 Target Entry Coordinates __q~" TVD Northinge Eaetinge (fi) (ft) (ft) 4845.70 3008.60 N 1462.38 W 4780.00 5983775.05 N 617420.00 E 70° 21' 51.8010' N 149° 02' 45.6183' W 5205.70 3105.46 N 1515.78 W 5140.05 5983875.00 N 617365.00 E 70° 21' 52.7929" N 149° 02' 47.1809" W 5205.70 2893.45 N 1769.25 W 5205.70 3397.04 N 1676.24 W 5205.70 3234.44 N 1324.78 W 5205.70 2734.50 N 1331.92 W 5140.00 5983655.00 N 617115.00 E 5140.00 5984160.00 N 617200.00 E 5140.00 5984003.00 N 617554.00 E 5140.00 5983553.00 N 617554.00 E Target Target 8hepe Type Circle Geological Polygon Geological Continued... 29 September, 2000 - 11:29 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-201 WPS (EX 9) - S-201 Wp 01 North Slope Alaska Target Name Targets associated with this wellpath (Continued) $-201 TD (T3) Mean Target Entry Coordinates TVD Northings Eaatings (ft) (ft) (ft) N 149° 02' 54.5925' W N 149° 02' 51.8757' W 70° 21' 54.0226' N 149° 02' 41.5950' W 70° 21' 49.5971' N 149° 02' 41.8016' W 3175.00 N 1549.75 W 5983940.00 N 617330.00 E 7(7' 21' 53.4376' N 149° 02' 48.1746' W Alaska State Plane 4 PBU_WOA S Pad Target Target Shape Type Circle Geological 29 September, 2000- 11:29 - 7- DrillQuest 1.05.05a VENOOR ALASKAST~T 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~0~500 CK102500 100. O0 100. O0 H/~NDLi[NG INST: S/H - TERRIE HUB]ILE X4628 AI'rACHED CHECK IS IN PAYMF. NT FOR ITEMS DESCRIBED ABovEL~d~~~ 100. O0 100. OO WELL PERMIT CHECKLIST FIELD & POOL ~;~ (7/0 / (,,o ~_...~ ADMINISTRATION DATE /I.'~. ~0 COMPANY INIT CLASS ,~-~'L,/ WELL NAME,~'-Z.~/ PROGRAM: exp dev .v/redrll serv wellbore sag ann. disposal para req GEOL AREA ~,~"~-~ UNIT# (~) / / ~ ~) ON/OFF SHORE ~--~/-~ 1. Permit fee attached .............. 2. Lease number appropriate~. ~'.~--...-~=.~.,-~"~. ~ ~'~P ~'~. / 3. Unique well name and number .................. 4. Well located in a defined pool.~'. ............ 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat in,~ded ............... 9. Operator only affected party. ~,.~ ................ 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. 27. 28. {[/1~'~ 29. I OEOLOGY '. 30, 31, 32, DA'r,I~ 33. /l.~, GO ~. If a re-drill, has a 10-403 for abandonment been approved... - ',' N ~51~. . .. _ ~ . Ada uatewellbore se aration roposed .......... Y N C,.\c3~e o,~_~e.~'~'~3e,.~',,~'~_ ....... _ ._~.c7',,. ; .~ .. '~:,, ,.,_ ____,.. .q · P · P ." ' \ .~.--~, If dtverter requ~recL does ~t meet regulations .......... ..Y,. N ~rilling fluid program schematic & equip list adequate ..... BOPEs. do they meet regulation ................ BOP E press rating appropriate; test to %$~ psig. (~ N ~l~.~' -_ \"~.~- ~:~, '~ [ ?~., ~'~,_,,.~%'~'c'~ ' · Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... ,Y{~, ~ Is presence of H2S gas probable ................. Y ~ . ' · Permit can be'issued wlo hydrogen sulfide measureS~' . . . Data presented on potential overpressUre zones · .'~--~.. .... Seismic analysis of shallow gas zones; ............ Seabed condition survey (if off-shore) ........... ~ ~Y N v o ' . v/ ~ u Contact name/phone for weekly progress reports~tory only] Y N . Y N Y N Y N GEOLOG'~: ENGINEERING:' UlClAnnular COMMISSION: ~_. ~ [_/!~. ~ JMH ..,i~. Comments/Instructions: Z -r- c:\msoffice\wOrdian\diana\checklist (rev. 111011100) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LiS Scan Utility SRevision: 3 $ LisLib SRevislon: 4 $ Mon Jun 1i 10:40:59 2001 Reel Header Service name ............. LiSTPE Da%e ..................... 0i/06/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Nunfoer ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/06/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ........ UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NARE: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: l~!qG E: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHiNS: DERRICK FLOOR: GROUN[ LEVEL: WELL CASING RECORi MWD RUN 1 AK-MM-00275 PHIL ROGER DUNCAN FERGU S-201 PB1 500292298770 BP Exploration (Alaska), Inc. Sperry Sun Drilling Services Il-JUN-01 MWD RUN 2 AK-MM-00275 PHIL ROGER DUNCAN FERGU MWD RUN 3 AK-MM-00275 PHIL ROGER DUNCAN FERGU 35 12N 12E 693 4495 64.42 ~. 9C ~F,i .- ROD1 ..... ~., STRING RE:,:ARKS: S?EK UOL-- CAS i .NC- _RiLLESS ' ALL .... ~ ARE MEASURED nr=~uS ~UD' :~N~rcS OTHERWISE NOTED. 2. MWD RUKS i & 2 WERE DIRECTIONAL WiTH DUAL G~M~. kAY (DSR) =E==uR-~iu~Lu=R TUBE DETECTORS. MWD RUN 3 WAS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 4. MWD GAMMA RAY IS CONSIDERED PDC, PER 12/03/00 E-MAIL FROM DEWAYNE SCHNOOR, QUOTING A PHONE CALL FROM GREG BERNASKI (BP EXPLORATION). 5. MWD RUNS 1-3 REPRESENT WELL S-201PB1 WITH API%:50-029-22987-70. THIS WELL .~EACHED A TOTAL DEPTH (TD) OF 4769~MD / 3720.19'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPS? = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ALSORPTION FACTOR ~LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 10.5 PPG MUD SALINITY: 160-400 PPM CHLORIDES FOk~TION WATER SALINITY: 23,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC L_- '_-'H'OL 3 2"_': ,,..,..... .......... £ Fiie Header S-r'-i-= , ~~= r. ame ............. STSLiB.~. Service Sub L.evei Name... Versicr. Number ........... !.0.0 Da~e cf Generation ....... 01/06/11 Ma::imum Fkysica! 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. .5000. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 197.5 4739.5 ROP 225.0 4768.5 FET 3149.5 4712.5 RPD 3149.5 4712.5 RPM 3149.5 4712.5 RPS 3149.5 4712.5 RPX 3149.5 4712.5 NCNT 3158.0 4720.0 FCNT 3158.0' 4720.0 NPHI 3158.0 4720.0 PEF 3167.0 4729.0 DRHO 3186.0 4729.0 RHOB 3186.0 4729.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: - EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 197.5 1041.5 2 989.5 3205.0 3 3149.5 4768.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .......... ' ........ 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin !,'ia:: =~a.-..es net rescrd ............. Undefined Absen- va-ue ...................... -999 ier5h Ur./~ ........................ 2atur. S_ue~ifiua~i_.. ~i,_k suk-uy.ue .... RPX RPS RPM R?D FET NPHi FCNT NCNT RHOB DRHO PEF ger--ice ~de~ Units Size Nsam ReT . F? 4 i 65 MWD FT/H 4 ~ 68 ~':WD ~HMM z ~ 68 MWD ~u,~ ~ I 68 MWD OHMM 4 i 68 MWD OHMM 4 ! 68 ,.,w~ HOUR 4 1 68 MWD PU-S 4 1 68 MWD CNTS 4 1 68 MWD CNTS 4 1 68 MWD G/CM 4 1 68 MWD G/CM 4 1 68 MWD BAR. N 4 1 68 Scde ~f=s^t ~hannel C _ 4 2 8 3 '2 4 i6 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 197.5' 4768.5 GR MWD API 19.05 126.48 ROP MWD FT/H 0 442.6 RPX MWD OHMM 0.06 1876.28 RPS MWD OHMM 0.06 1450.08 RPM MWD OHMM 0.11 2000 RPD MWD OHMM 0.23 2000 FET MWD HOUR 0.27 64.1 NPHI MWD PU-S 30.5 71.82 FCNT MWD CNTS 410 627 NCNT MWD CNTS 2080 3016 RHOB MWD G/CM 1.46 2.64 DRHO MWD G/CM -0.2 0.25 PEF MWD BARN 1.36 17.09 Mean 2483 63.4475 141.706 12.5649 13.0032 18.1891 50.986 2.85713 45.6594 523.736 2579.75 2.18594 0.0617395 4.80574 Nsam 9143 9085 9088 3127 3127 3127 3127 3127 3125 3125 3125 3087 3087 3125 First Reading 197.5 197.5 225 3149.5 3149.5 3149.5 3149.5 3149.5 3158 3158 3158 3186 3186 3167 Last Reading 4768.5 4739.5 4768.5 4712.5 4712.5 4712.5 4712.5 4712.5 4720 4720 4720 4729 4729 4729 First Reading For Entire File .......... 197.5 Last Reading For Entire File ........... 4768.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version NumDer ........... 1.0.0 Date of Generation ....... 01/06/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... ','erslcn '.,lumber ........... 1.3.$ _-'ate cf Genera%irn ....... .~l 36.Z1 . Frevicus _--iZe :~---.-..e ....... S_-SLii-..~.~ l Co.-.~.eL5 FiLE NU:,:~ER · kAW MWD Curves and log h-a~=~ '--a for each bi-_ run in separate files Bi~ ~ = RUN NUMSER: _ DEPTH T~n~TS'=?ZW . ............. : 5000 FILE SUMY~ARY VENDOR TOOL CODE START DEPTH GR 197.5 ROP 225.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 989.0 1041.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SiZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY <LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS ~C3): RESISTIVITY iOHMM) AT TEMPERATURE (DEGF) MUE'AT MEASURED TEMPERATURE (MT): MUD AT MA3[ CIRCULATING TERMPERATURE: MUD FILTkATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRI>[ EENSiTY: HOLE CORRECTION (IN): 23-NOV-00 Insite 5.46 Memory 1041.0 .3 2.6 TOOL NUMBER PB01738CG8 12.250 SPUD MUD 8.70 318.0 9.1 400 14.2 .000 .000 .000 .000 .0 69.4 .0 .0 ~-~- Format Ss-cificanicn Record Daza Reccrd Type .................. Data Speclfica'ion B'ock Type ..... Logging Direction ................. Down O~=_~=_ log depth units ........... Fee~ Data Reference Point .............. Undefined Frame Spacing ..................... 60 .ilk Max frames Der 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 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 197.5 1041.5 619.5 1689 GR MWD010 API 19.05 100.9 49.896 1584 ROP MWD010 FT/H 3 188.98 106.513 1634 First Reading 197.5 197.5 225 Last Reading 1041.5 989 1041.5 First Reading For Entire File .......... 197.5 Last Reading For Entire File ........... 1041.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/11 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 ....... 01/06/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: ~ ~ o~ Y. ea~e~ ~-~a for e-~h ~ ........... ~ - ..,..~ >;,U:.ZS='F: _ 3'-".--_"E _-:<CRE:,-E:;L7: . E-LE SUMMA..:.'." C-R ~S~.5 RC? ' $ LOG HEADER 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: 3152.~ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Forma% S?ecifica%ion Record Data Record Type .................. 0 Data Specification Block Type ..... 0 24-NOV-00 Insite 5.46 Memory 3205.0 1.0 56.6 TOOL NUMBER PB01738CG8 12.250 Water Based 9.10 339.0 8.9 160 14'.4 .000 .000 .000 .000 .0 101.0 .0 .0 "u~i-al -- deuzh unins ........... Fe-,~= i;=_-_a Re--e"ence Puinz .............. Undefined Erame Suarir..- ..................... 6~' .'-K i-'a.:, frar.-== '-=~ ~-sard= ............. Undefined :-h_-nc== :.'al ue ...................... -999 Da-_um S~.egific-~ion ~=~ck sub-type 0 Xame Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 i 68 0 l GR MWD020 APi 4 i 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 989.5 3205 2097.25 4432 GR. MWD020 API 23.54 126.48 68.7989 4327 ROP MWD020 FT/H 0 442.6 145.003 4327 First Reading 989.5 989.5 1042 Last Reading 3205 3152.5 3205 First Reading For Entire File .......... 989.5 Last Reading For Entire File ........... 3205 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/11 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 ....... 01/06/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3149.5 4712.5 RPD 3149.5 4712.5 _--2NT 315~. 2 4-22. ,-~T ~1~5 ~ ~ . PEF 3167.0 4729. i'RHO 31~ 6. '~ 4729. RHOB 3186. O 4729. ROP 32C5.; 4768. $ 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 (OHMS) 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: 27-NOV-00 Insite 65.44 Memory 4769..0 53.2 61.8 TOOL NUMBER PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 8.750 LSND 10.50 48.O 8.8 200 5.2 3.000 1.390 2.350 4.300 66.0 150.0 66.0 64.0 .. .- - ~ ~= ~-: OL ................. - . ' ~= ~- ~e~h units ........... Fee~ . Ref-=rence Pcin~ .............. Un~eflned Frame ST-- =rlng ..................... 6~ .iix - Max frar.~s c-r reccrd Un~eflned ~bsent value ...................... -999 Depnh Uniss ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 .16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 I 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 Name Service Unit DEPT FT GR MWD030 API ROP MWD030 FT/H RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR NPHI MWD030 PU-S FCNT MWD030 CNTS NCNT MWD030 CNTS RHOB MWD030 G/CM DRHO MWD030 G/CM PEF MWD030 BARN Min Max Mean Nsam 3149.5 4768.5 3959 3239 19.52 110.36 62.9151 3174 13.27 289.85 155.532 3127 0.06 1876.28 12.5649 3127 0.06 1450.08 13.0032 3127 0.11 2000 18.1891 3127 0.23 2000 50.986 .3127 0.27 64.1 '2.85713 3127 30.5 71.82 45.6594 3125 410 627 523.736 3125 2080 3016 2579.75 3125 1.46 2.64 2.18594 3087 -0.2 0.25 0.0617395 '3087 1.36 17.09 4.80574 3125 First Reading 3149.5 3153 3205.5 3149.5 3149.5 3149.5 3149.5 3149.5 3158 3158 3158 3186 3186 3167 Last Reading 4768.5 4739.5 4768.5 4712.5 4712.5 4712.5 4712.5 4712.5 4720 4720 4720 4729 4729 4729 First Reading Eor Entire File .......... 3149.5 Last Reading For Entire File ........... 4768.5 File Trailer' Service name ............. STSLIB.004 Service Sub Level Kame... Version NumDer ........... 1.0.0 Date of Generation ....... 01/06/11 Maximum ?hysical Record..65535 File Type ................ LO -ape T_-iler~= Set--ice- , r.a.-, e ....... ..... .-- ' -STPE l'ate ..................... 0"/06/11 C'ri~in ................... STS 7ape Nar, e ................ UNKNOWN Con~. ~uat- -- Number '~' Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/06/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 , Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services - --=- Utilinv . £Revisisn: 3 $ LisLi~ SRevision: 4 $ Thu Jun 21 14:27:56 2001 Reel Header Service name ............. LISTPE Date ..................... 01/06/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/06/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay (Polaris) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-00275 PHIL ROGER DUNCAN FERGU S-201 500292298700 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 20-JUN-01 MWD RUN 2 AK-MM-00275 PHIL ROGER DUNCAN FERGU MWD RUN 3 AK-MM-00275 PHIL ROGER DUNCAN FERGU JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-00275 J. SACK D. FERGUSON 35 12N 12E 693 4495 ELEVATION (FT FRO:'.':.~-:'"e' ~' KELLY _~USHiNG: DERRi CK -: GROUND LEVEL: WELL CASING RECORD OPE:.{ HOLE iST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 64.42 CAS iNG DRi LLERS SiZE (iN) SiZE iiK' DEPTH (FT', .~50 9.625 3190.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. THIS WELL WAS INADVERTENTLY SIDETRACKED JUST OUT OF THE SHOE, AFTER A SHORT TRIP. RUNS 1, 2, AND PART OF RUN 3 WERE RECORDED WHILE DRILLING THE ORIGINAL HOLE (S-201 PB1). PART OF RUN 3 AND ALL OF RUN 4 WERE RECORDED WHILE DRILLING THE SIDETRACK. DATA FROM THE SHOE TO 4024'MD / 3272'TVD WERE NOT RECORDED WHILE DRILLING, BUT WERE RECORDED DURING A SUBSEQUENT MAD PASS. SEPARATE MAD-PASS DATA ARE NOT PRESENTED. 3. MWD RUNS 1 & 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 3 & 4 WERE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD GAMMA RAY IS CONSIDERED PDC, PER 12/03/00 E-MAIL FROM DEWAYNE SCHNORR QUOTING A PHONE CALL FROM GREG BERNASKI (BP EXPLORATION). 6. MWD RUNS 1-4 REPRESENT WELL S-201 WITH API9:50-029-22987-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7245'MD / 5614.56'TVD. SROP = SMOOTHED RATE OF PENETRA?ION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERiVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERiVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DEK2VED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERiVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. FIXED HOLE SKFA = SMOC/HE? AVER_AGE CF SNKA SMOC/HE2 AVE~.GE OF NEAR DETECTOR'c COUNT FAZE S~22 = SMOC'H=~. BULK DENS SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN}. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ~ LOW-COUNT BIN). PAk~ETERS USED iN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 10.5 PPG MUD SALINITY: 160-400 PPM CHLORIDES FORMATION WATER SALINITY: 23,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 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: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 197.5 7211.5 ROP 225.0 7244.0 NPHI 3133.5 7192.0 FCNT 3134.0 7192.0 PEF 3144.0 7201.0 RPX 3149.5 7184.5 RPS 3149.5 7184.5 RPM 3149.5 7184.5 RPD 3149.5 7184.5 FET 3149.5 7184.5 NCNT 3157.5 7192.0 DRHO 3189.0 7201.0 RHOB 3189.0 7201.0 $ BASELINE CURVE FOR SH-FTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH ......... Y£?,C-E'-' DA?A SOURCE ?SU ?30L CODE !.':.'; Z S RE¥~RKS: _ _~,.~ 104~ .5 ~ '0" : 2-'23= ~ _' --. . ~.' ~ 3205.~ ~48~.$ ~ 6483. C -2zz ~'. MERGED !.LAIN PASS. # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Tk~e ..... 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 Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM ~fWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 197.5 7244 3720.75 14094 GR MWD API 8.28 137.44 67.6117 14029 ROP MWD FT/H 0 531.64 125.765 14039 RPX MWD OHMM 0.98 290.04 12.2415 8071 RPS MWD OHMM 0.63 1138.42 13.6778 8071 RPM MWD OHMM 0.84 2000 16.3525 8071 RPD MWD OHMM 0.75 2000 33.5768 8071 FET MWD HOUR 0.07 159.51 14.5356 8071 NPHI MWD PU-S 13.84 80.61 40.4134 8096 FCNT MWD CNTS 402 1067 570.119 8094 NCNT MWD CNTS 2008 3904 2686.96 8070 RHOB MWD G/CM 1.24 3.25 2.21613 8025 DRHO MWD G/CM -0.23 0.54 0.0504299 8025 PEF MWD BARN 0.07 13.93 2.80726 8115 First Reading 197.5 197.5 225 3149.5 3149.5 3149.5 3149.5 3149.5 3133.5 3134 3157.5 3189 3189 3144 Last Reading 7244 7211.5 7244 7184.5 7184.5 7184.5 7184.5 7184.5 7192 7192 7192 7201 7201 7201 First Reading For Entire File .......... 197.5 Last Readinc Err Entire File ........... 7244 File Trailer Service nar. e ............. $iSLi~.0Ci Service Suk Level flame... Version Kumber ' ~ 0 Date of g .... :-~cn ....... Cl.'06'21 Maximum Fkvsiga2 Aegcr~..65~35 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 ....... 01/06/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 COmment Record FILE HEADER FILE NUMBER: 2 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 GR 197.5 989.0 ROP 225.0 1041.5 $ LOG HEADER DATA DATE LOGGED: 23-NOV-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 1041.0 TOP LOG INTERVAL (FT): BOTTOM LOG iNTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 2.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SiZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER PB01738CG8 12.250 BOREHOLE ~ ~ '~- ~- ^~' c MUD TY?E: MUD DENS-TY {LB/Si': MUD ViSCOS!~v ~c' · MUD FH: MUD CHLCRiDES (FPI']): FLUID LOSS {C~): RESiSTiViTY 'CHi~'f~ AT TEMPEkATURE ~DEGF,~ MUD AT MEASURED TEMPE~TURE (MT): MUD AT M~ CiRCULATiNG TE~PE~TURE: MUD FILT~TE 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 SPUD MUD $. 70 3!$. C. 9.1 400 !4.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 .0 69.4 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 197.5 1041.5 619.5 1689 GR MWD010 API 19.05 100.9 49.896 1584 ROP MWD010 FT/H 3 188.98 106.513 1634 First Reading For Entire File .......... 197.5 Last Reading For Entire File ........... 1041.5 First Reading 197.5 197.5 225 Last Reading 1041.5 989 1041.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 Maximum Physical Record..65535 File Type ................ LO Nexz File Name ........... STSLiB.003 Physical ECF File Header Service name ............. STSLIB.003 Service Sub Level Kame... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 989.5 ROP 1042.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT).: BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 3153.5 3205.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 24-NOV-00 Insite 5.46 Memory 3205.0 1.0 56.6 TOOL NUMBER PB01738CG8 12.250 Water Based 9.10 339.0 8.9 160 14.4 MUD AU MEASURED TEMPEkATURE [MT': u':." .~.. .t~_X C RCULATiNG ~ r ...... .- ~:"12 EiLTkATE AT MT: :,:US CAKE AT :-fi: NEUTRON TOOL ~£ATRiX: M~TRiX DENSITY: HOLE CORRECT!OK (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 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 989.5 3205 2097.25 4432 GR MWD020 API 23.54 126.48 68.8031 4329 ROP MWD020 FT/H 0 442.6 145.015 4327 First Reading 989.5 989.5 1042 Last Reading 3205 3153.5 3205 First Reading For Entire File .......... 989.5 Last Reading For Entire File ........... 3205 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Suk level Name... Versicn Kum~er ........... i.e.0 Date of G=--n=~=-~on ....... 01/06/21. Maximum Ph\'sica' Reccrd..65535 . File Type ................ LO Previous File Name ....... STSLIB.0C3 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and icg header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS RPM FET RPX RPD PEF NCNT NPHI FCNT GR DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3102.5 3102.5 3102.5 3102.5 3102.5 3103.5 3113.0 3133.5 3134.0 3154.0 3189.0 3189.0 3205.5 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): STOP DEPTH 6427.0 6427.0 6427.0 6427.0 6427.0 6443.5 6434.5 6434.5 6434.5 6454.0 6443.5 6443.5 6483.0 27-NOV-00 Insite 65.44 Memory 6483.0 24.2 62.8 TOOL NUMBER PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 8.750 LSND 10.50 MUD ':~R~c-~x' b:UD FH: ., ~ "' - ES <F . FLUID LCSS :3~: R~c-c~-,--~v ,OH,ZU, ~ UEi,fFEkA!UAE ~DEGF) MUD AT MEASURED TEMPEkAIURE MUD A? M3~ CiRCUkATiNG TE~ZPEkATURE: MUD FiLTkATE 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 5.~ 5.2 3.000 !.i!0 2.350 4.300 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 66.0 150.0 66.0 64.0 Name Service Unit DEPT FT GR MWD030 API ROP MWD030 FT/H RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min Max Mean Nsam 3102.5 6483 4792.75 6762 8.28 130.87 66.1214 6601 0 531.64 128.059 6556 0.98 290.04 13.7791 6616 0.63. 1138.42 15.5867 6616 0.84 2000 18.9854 6616 0.75 2000 57.1417 6616 0.07 160.21 18.5611 6616 First Reading 3102.5 3154 3205.5 3102.5 3102.5 3102.5 3102.5 3102.5 Last Reading 6483 6454 6483 6427 6427 6427 6427 6427 !3.84 80.61 z_~,z C67 2008 3904 1.24 3.25 -C.23 0.54 0.07 '3.93 4 0. 6664 562.472 2675.1 2.:85 0.0452903 2.84628 6581 6579 6604 6510 6510 6604 3!34 3!13 3189 3189 3lC~.z 643-'..5 6434.5 6443.5 6443.5 6-~43.5 First Reading For Entire File .......... 3102.5 Last Reading For Entire File ........... 6483 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 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 ....... 01/06/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6424.0 7184.5 RPX 6424.0 7184.5 RPM 6427.5 7184.5 RPD 6427.5 7184.5 FET 6427.5 7184.5 NPHI 6435.0 7192.0 FCNT 6435.0 7192.0 NCNT 6435.0 7192.0 PEF 6444.0 7201.0 RHOB 6444.0 7201.0 DRHO 6444.0 7201.0 GR 6454.5 7211.5 ROP , 6483.5 7244.0 $ LOG HEADER DATA DATE LOGGED: 02-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: DOWKHOLE 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 CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G):, MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames Der record ............. Undefined . Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 insite 65.44 Memory 7245.0 19.8 22.6 TOOL NUMBER PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 PB01742HRNLG6 8.750 LSND 10.50 47.0 9.3 2O0 5.4 5.000 1.950 2.400 4.500 70.0 190.0 65.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel _~EPT -- .~D040 F, OP MWD04 C RPX MWD042 F, FS MWD040 RPM MWD04 0 RPD MWD040 FET MWD040 KPHI MWD040 FCNT MWD040 NCNT MWD040 RHOB MWD040 DRHO MWD040 PEF MWD040 nPi FT/H OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN i 68 0 ~ ! 68 4 2 i 68 $ 3 ! 65 12 4 i 68 !6 5 i 68 20 6 1 68 24 7 1 68 28 8 I 68 32 9 1 68 36 10 1 68 40 I1 1 68 44 12 1 68 48 13 1 68 52 14 Name Service Unit DEPT FT GR MWD040 API ROP MWD040 FT/H RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN Min 6424 45.63 0 2.03 1.74 2.21 2.24 0.56 32 504.15 2339.26 2.08 -0.04 1.14 Max Mean Nsam 7244 6834 1641 137.44 89.2231 1515 279.61 81.8221 1522 35.91 5.36174 1521 31.63 5.27547 1521 36.04 5.38317 1515 34.56 5.40957 1515 22.54 2.70882 1515 69.08 39.3142 1515 692.66 603.326 1515 3054.14 2730.21 1515 3.01 2.34991 1515 0.47 0.0725148 1515 7.78 2.66043 1515 First Reading 6424 6454.5 6483.5 6424 6424 6427.5 6427.5 6427.5 6435 6435 6435 6444 6444 6444 Last Reading 7244 7211.5 7244 7184.5 7184.5 7184.5 7184.5 7184.5 7192 7192 7192 7201 7201 7201 First Reading For Entire File .......... 6424 Last Reading For Entire File ........... 7244 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/06/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ...... ~ .... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/06/21 Origin ...... ~ ............ STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Da~e ..................... 01/06,,'2! Origin ................... STS Reel Name ................ UNKNOWN Ccntinua~ion N,~mber ...... 01 Next Reel Name ........... UNKNOWN Commen~s ................. STS LiS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
