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Home My WebLink About204-053STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG APR 2 3 2019 la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ Well Class:. 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 11b. Developml ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 3/26/2019 204-053 • 318486 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 5/24/2004 50-029.22910-01-00 4a. Location of Well (Governmental Section): 8, Date TD Reached: 16. Well Name and Number: 5/29/2004 PBU 1-2-07A Surface 1315-FSL, 3802' FEL, Sec. 18, Tl IN. R1 5E. UM ' 9 Ref Elevations - KB 39.30 17. Field/Pool(s): Top of Productive Interval: 820 FSL, 3388' FEL, Sec. 12, T11 N, R14E, UM GL 11.80 • BF 14.43 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MDrrVD): 18. Property Designation: , Total Depth: 343' FSL, 4815' FEL, Sec. 12, T11N, R14E, UM • 10924' / 8920' ADL 028321. 028307 6 028302 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface. x- 692844 • y- 5963212 • Zone - ASP 4 •12956'18657' ' 84-62 TPI: x- 688198 y- 5967680 Zone - ASP 4 12, SSSV Depth (MDr VD): 20 Thickness of Permafrost MDRVD: Total Depth: x- 686779 y- 5967367 Zone - ASP 4 None .1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No RI 13. Water Depth, if Offshore: 21. Re-ddll/Lateral Top Wndow MDrrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 11035'!8519' 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/GR/ROP/PRESS, GR/CCL /CNL 23. CASING, LINER AND CEMENTING RECORD CASING Wf. PER FT. GRADE SETTING DEPTH MD SETTINGDEPTHTVD HOLESIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 27' 107' 27' 107' 30" 260 sx Arctic Set (Approx.) 9-5/8" 9-5/8" 40# 40# L-80 L-80 2T 27' - 7�� 2T 3734' 12-1/4" 350 ssx x PF'E', 210 Class'G', 1848 sx PF 'E', 200 sx PF'C' 7„ 26# Lao 25' 10785'• 5' 8293' 8-1/2" 552 sx Cless'G' 4-1/2" 12.6# L -m 10590' 11035' 8120' 8519' 6" 143 sx Class'G' 3-1/7x3-3116" 9.3#/6.6# L-80 1 10954' 12956'. 8447' 8657' 41/8"x3-3/4' 189 sx Class'G' x2-7/8" /6.5# 24. Open to production or injection? Yes ❑ No a 25. TUBING RECORD If Yes, list each interval open (MDrtVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (li 4-1/2" 12.6# L-80 10605' 10550' / 8084- AA 4 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (E Was hydraulic fracturing used during completion? Yes ❑ No 10 Per 20 AAC 25.283 (i)(2) attach electronic and panted Z G information VE/R�IFFIIE�D� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10924' Set Whipstock 10938' Set CIBP 10957' Fish: Milled Cement Retainer 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flouring, gas II6, etc.): N/A Date of Test: Hours Tested: Production for Oil -8131: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Test Period Flow Tubing Press Casing Press: Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Grii- API(cum: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ,0 ll dn6.R2S9P"9RBDMSILS/APR 2 4 2019 s 3'y 28. CORE DATA Conventional Corals) Yes ❑ NO 0 Sidewall Cores Yes ❑ NO 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 11407' 8635' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 22TS 11174' 8617' TDV - Zone 1A 11407' 8635' Formation at total depth: Zone 1A 11407' 8635' 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: Ciolkosz, Ryan R Authorized Title: SIMS alis Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: e: 2 2 JII Contact Phone: +1 907 564 5977 INSTRUCTIONS General: This forth is designed for submitting a complete and correct well completion report and log on ail 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. Mulfiple 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days Of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cored and the coresponding 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 forn: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to. care analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Daily Report of Well Operations L2 -07A ACTIVITYnATF RI IUKAAPV 'WELL SHUT IN ON ARRIVAL***(ctd) PULL PRONG FROM 10,563' SLM PULL 4-1/2" PX -PLUG BODY FROM 10,583' MD **"WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS UPON 10/25/2018 DEPARTURE*** T/I/0 = 2540/670/230. Temp = SI. TBG & IA FL (Eline Request). No AL. TBG FL @ 8170' ( 124 bbls). IA FL @ near surface. 11/1/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00- T/1/0=2522/668/237 (LRS Unit 70 - Assist E -line: Load &Test) Pumped a 2 bbl 60/40 spear and 210 bbls 110* cude to load tbg. Called off job to assist slickline unit. E -line in control of well upon LRS departure. 11/2/2018 FWHP=121/683/940 ***WELL SHUT-IN ON ARRIVAL*** (SLB E -LINE CBP AND CMT RETAINER SETTING) RIG UP, PT LUBRICATOR TO 3350 PSI. LRS LOAD TUBING WITH 205 BBLS CRUDE AT 5 BPM RIH W/ BKR 10/HAL CBP. OAL = 23', CAW = 250 LBS, MAX OD = 3.60". CBP SETTING DEPTH = 10425' ME, TOP OF PLUG @ 10424, CCL TO MID ELEMENT = 7.8', CCL STOP DEPTH = 10417.2'. TIED INTO TUBING SUMMARY DATED 12/1/98 FINAL T/l/0 = 140/650/80 PSI 11/2/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** T/I/0= 100/675/35 Temp= S/I (LRS Unit 70 - Pressure Test Post Eline CBP) Pressure Test Tubing **PASSED** to 2728 (Target=2500 psi, Max Applied 2750 psi) Pressured up with 2.6 bbls crude. Tbg lost 110 psi 1st 15 min and 42 psi 2nd 15 min for a total loss of 152 psi in 30 min test. Bled back —2bbls SV,WV,SSV=closed MV,IA,OA=open DSO notified on departure 11/3/2018 Final WHP's 100/662/28 "*WELL SHUT IN ON ARRIVAL***(pre ctd) SET 4 1/2" WHIDDON ON CBP @ 10,407' SLM MADE 2 UNSUCCESSFUL ATTEMPTS TO PULL INT-DGLV FROM STA #3 @ 10,401' 11/11/2018 IMD 11/11/2018 Assist Sline w/ Circ Out (CTD) SU/PJSM Start RU ***Job Cont to 11-12-2018 WSR*** ***CONT WSR FROM 11/11/18*** (ctd) PULLED INT-DGLV FROM STA#3 @ 10,401' MD PULLED EMPTY 4 1/2" WHIDDON FROM 10,400' SLM LRS CIRC OUT WELL WITH 355bbls OF DIESEL. DRIFT TUBING WITH 10' x 2 7/8" DUMMY GUN, 3.69" DRIFT AND 3.25" LIB TO 10,424' SLM (no impression) SET HES 4 1/2" FAST DRILL SVB CEMENT RETAINER PLUG @ 10375' MD. PERFORMED PASSING MIT -T TO 2595psi. (see log for details) 11/12/2018 *'*WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** *'*Job Cont from 11-11-2018 WSR*** Pumped 4 bbl 60/40 spear down TBG up IA, returns to 1-2-11 fl. Pumped 355 bbls DSL to circ out well. Released from Job. SLB on well upon 11/12/2018 departure. FWHP's 740/743/290. Daily Report of Well Operations L2 -07A CTU#8 1.75" CT. Job Scope: IA Sqz / Mill Plugs MIRU CTU. Drift Coil w/ 1-3/16" ball. Perform Weekly BOP Test. MU & RIH w/ HES Stinger BHA. Take diesel pipe displacement returns while RIH. Sting into HES Cmt Retainer at 10383'. Pump 5 bbls of diesel to verify we can circulate up the IA. Pump 10 bbls of chemwash, 2 bbls of FW & 72 bbls of 15.8ppg Class G Cement. Circulate 71 bbls cement into IA. Unsling and lay in 1 bbl of cement on top of retainer. Close choke & pump pipe displacement to surface. Estimated TOC - 6624'. 11/15/2018 ***Continue on 11/16/18*** CTU#8 1.75" CT Job Scope: IA Sqz / Mill Plugs Lay down Stinger BHA. Pump 1-3/16" drift ball w/ 10 bbl gel sweep to open top tanks. Wait on 500psi Compressive Strength. MU & RIH w/ Baker 3.80" Milling BHA. Tag TOC at 10387' (-5-8' of cement on top of retainer). Mill up retainer and cement to 10433'. Circulate bottoms up w/ 25 bbl gel sweep. Mill CBP.. 11/16/2018 `*Continued on 11/17/18** CTU#8 1.75" CT. Job Scope: IA Sqz / Mill Plugs MITI CBP & push to TOL at 10984' uncorrected. Pump 20 bbl gel sweep and chase ooh at 80%. Re -run 3.80" Milling BHA due to counter slippage from previous run. Dry drift from surface to TOL at 10962' down / 10957' up. Clean dry drift achieved. Pooh. Lay in 60/40 Freeze Protect from 2500' tvd. Break down tools. Rig Down CTU. 11/17/2018 ***Job Complete*** TWO= vac/vac/190. MIT -IA to 3000 psi. (CTD) Failed 4 attempts to 3250 psi max applied pressure. Lost 99 psi during the first 15 minutes and lost 83 psi during the second 15 minutes of the last test. Lost 182 psi during the 30 minute test. Pumped 2.4 bbis of 30* F diesel to achieve test pressure. Pumped 0.1 bbls to reestablish test pressure before each of the last 3 tests. Bled back 2.3 bbls to Final T/1/0= vac/6/157. DSO notified of well status 11/21/2018 upon departure. SV, SSV, WV closed. MV open. IA/OA OTG. ***WELL SHUT IN ON ARRIVAL*** (CTD) DRIFT FREELY W120' x 3.70" DMY WHIPSTOCK TO 10,945' SLM LRS PUMPED 180 BBLS CRUDE DOWN TBG 11/24/2018 ***CONT. ON 11/25/2018 WSR*** T/I/O=Vac/40/225 Temp=S/I (LRS nit 70- Assist Slickline: SCMT log/ CTD) Pumped 170 bbls 100* crude down TBG to load, TBG pressures and rates varried during load from possible CBP debris in LTP. IA gained and lost pressure based on TBG pressures,OA 11/24/2018 pressures slowly gained and had to be bled down. ***Continued on 11-25-18 WSR*** TWO = VAC/40/220. Temp = SI. T FL (SL REQ). No AL. Well is disconnected from the system, no well house or flow line. T FL @ 430'. 11124/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 ***CONT. FROM 11/24/2018 WSR*** (CTD) LOGGED SCMT (2 passes) FROM 10,550' SLM TO SURFACE @ 30 FPM ... GOOD 11/25/2018 DATA ***Continued from 11-24-18 WSR*** (LRS nit 70- Assist Slickline: SCMT log/ CTD) Pumped 10 bbls (180 bbls total) crude down TBG to load. Pump 121 bbls crude down TBG 11/25/2018 as needed to maintain fluid column. 301 total pump job) Final WHP's 200/27/70 SL on ****WELL S/I UPON ARRIVAL**** (Pre CTD) R/U SLICKLINE SWCP #4522 TO SET PLUG 11/28/2018 ****CONT JOB ON 11/29/18**** Daily Report of Well Operations L2 -07A T/I/0= 265/75/230 Temp= S/I (LRS Unit 70 -Assist Slickline: Load & Test) Pumped 250 bbls of 92*F crude to fluid pack TBG. MIT -T PASSED 2nd attempt to 3200 psi. Target Pressure = 3000 psi, Max Applied Pressure = 3250 psi. Reached test pressure with 3.31 bbls 15*F diesel. TBG lost 32 psi in 1 st 15 minutes and 14 psi in 2nd 15 minutes. Bled pressure into IA for CMIT. CMIT-TxIA PASSED on 7th attempt to 3179/3027 psi. Target Pressure= 3000 psi, Max Applied Pressure = 3250 psi. Reached test pressure with 6 bbls of 15*F diesel. TBG/IA lost 23/150 psi in 1st 15 minutes and 14/69 psi in 2nd 15 minutes. Bled back to 200 psi, returned - 4 bbl (See log for details) Slickline on well upon LRS departure. 11/29/2018 FWHP's 200/215/30 ****CONT. JOB FROM 11/28/18**** (Pre CTD) DRIFTED W/ 4-1/2" BRUSH, 3.80" G -RING TO 10,610' SLM (No issues) LRS LOADED TBG W/ 250 BBLS CRUDE (See LRS log) SET 4-1/2" XX -PLUG @ 10,583' MD LRS PERFORMED PASSING MIT -T TO 3,000 psi (See LRS log) LRS PERFORMED PASSING CMIT-TxIA TO 3,000 psi (See LRS log) PULLED 4-1/2" XX -PLUG FROM 10,583' MD 11/29/2018 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** T/1/0=400/320/215 Temp=Sl (LRS Unit 46 - MIT -IA) MIT IA to 3147 psi ***PASSED*** Target pressure=3000 psi Max applied=3250 psi Initially Pumped 2.28 bbls DSL down IA to achieve test pressure of 3245 psi. 15 mi loss of 67 psi, 30 min loss of 31 psi, for total loss of 98 psi in 30 mins. Bled IAP to 230 psi (2.3 bbls). DSO/WSL notified Tags hung on IA/WV AFE sign hung on MV ***FLUID PACKED ANNULUS*** Valve positions=SV WV SSV closed MV open CVs OTG AL closed 12/4/2018 FWHP=400/320/175 ***WELL SHUT-IN ON ARRIVAL*** (SLB ELINE CIBP AND WHIPSTOCK SETTING) INITIAL T/I/O = 500/475/200 PSI RIG UP, PT LUBRICATOR TO 3600 PSI LRS LOAD WELL WITH 200 BBLS 1% KCLAND 38 BBL DIESEL FP RIH W/ 4-1/2" BAKER CIBP. SET CIBP AT 10938' TOP OF PLUG. ALL LOGS CORRELATED TO 11 -APR -2018. LRS PRESSURE TEST PLUG, PASSED. LAY DOWN LUBRICATOR TO RETURN IN THE MORNING 12/5/2018 ***JOB CONTINUED ON 06 -DEC -2018*** T/1/0=453/477/200 Assist E -line (load and secure) Pumped 5 bbls 60/40 meth down TBG, followed by 201 bbls KCL. Pumped 5 bbls Meth down TBG followed by 38 bbls Diesel for FP. Set test CIBP to 2700 psi, with 5.3 bbls 60/40. bled back 3 bbls 60/40. ***Job 12/5/2018 continued on 12/06/2018*** ***Job continued from 12/05/2018*** Assist E -line (Secure well) Pressure test CIBP with max applied 2600 psi. pressured up to 2579 psi with 1.7 bbls 60/40. 1st 15 min TBG lost 40 psi, 2nd 15 min TBG lost 26 psi for total loss of 66 psi 30 min. bled back 1.8 bbls 60/40. 12/6/2018 Valve position= SV, SSV WV=Closed, IAC, OAC=OTG FWHP= 0/531/12 ***CONTINUED FROM 05 -DEC -2018*** (SLB E -LINE WHIPSTOCK SETTING) PICK UP TOOLS, PT LUBRICATOR TO 3600 PSI RUN 1: RIH W/ BAKER 3.63" WHIPSTOCK. TOOLS WILL NOT TURN ON. RETURN TO SURFACE TO TROUBLESHOOT RUN 2: RIH W/ BAKER 3.63" WHIPSTOCK. REPLACE WPPTTOOLSTRING SET TOWS AT 10924'. WHIPSTOCK ORIENTED TO 23 DEG ROHS. ALL LOGS CORRELATED TO PDCL LOG DATED 11 -APR -2018. 12/6/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** Daily Report of Well Operations L2-07A T/I/O = VAC/500/200. Set TWC For Pre CDR2 Tree work. RU CIW lubricator #68-840 with 4" CIW 'H' TWC #432. PT to 350/3500psi (PASS). Run down and set at 120". LTT (PASS) RD lubricator and install tree cap. PT to 500psi. (PASS). RDMO ***Job Complete*** SEE 12/28/2018 LOG FOR DETAILS Final T/l/O = TWC/500/200. Note: TWC sign hung on wellhead. T/I/0=TWC/500/150.ND 4" Cameron upper tree. Install 4" CDR2 tree #3. PT CDR2 tree to 350 low and 5000psi high for 5min. each Passed. See log. Final WHP's TWC/500/150. 12/29/2018 *** Kill line still needs to be installed** T/I/O=TWC/0/0 Pulled 4" CIW "H" TWC #432 through CDR 2 tree for upcoming MIT. 1/24/2019 FWP's 0/0/0 see log for details. T/l/O = 3/428/228. Temp = SI. AOGCC MIT-T to 2691 psi PASSED. Max = 2750 psi, target = 2500 psi & MIT-IA to 3053 psi PASSED. Max = 3250 psi, target = 3000 psi. Witnessed by Jeff Jones (reg compliance). Wellhouse, Flowline, SSV, scaffold removed. Rig scaffold installed. T FL @ near surface. IA FL @ surface. Used 2.1 bbls to increase IAP to 3249 psi. IAP lost 153 psi in the 1st 15 min & 43 psi in the 2nd 15 min for a total loss of 196 psi in 30 min. Used 1 bbl of diesel to increase TP to 2748 psi. TP lost 42 psi in the 1 st 15 min & 15 psi in the 2nd 15 min for a total loss of 57 psi in 30 min. Bled TP & IAP to 0 psi (2.2 bbls). Tags hung. Final WHPs = 0/0/160. 1/25/2019 1 SV, WV = C. MV = O. IA, OA = OTG. 13:00 Wireless install (WOLP). Installed and pressure tested wireless pressure gauges on annuli. 2/4/2019 FCO complete and ready to turn over to Operations. T/1/0=0/0/0. Set 4" H TWC #439 @100" w/ Lubricator 840. RU Target 90 CTU #02. PT'd against TWC 350/5000 PSI (Pass) Charted and Retained. Pulled 4" H TWC #439 @100". 3/6/2019 RDMO. ***Job Complete***. T/I/O = 0/30/230. Temp = SI. Bleed WHPs to 0 psi (Pre RIG). No AL, SSV, flowline, scaffold or well house. TBG FL @ Surface. IA FL @ Surface. OA FL @ Surface. Bled IAP to BT from 30 psi to 0 psi in <1 min. Bled OAP to BT from 230 psi to 100 psi in 1.5 hrs (Fluid, 15 bbls). OA would not bleed below 100 psi. SI bleed for 45 min. (See log for details). IAP increased 2 psi and OAP increased 70 psi. Continued with OA bleed. Bled OAP from 170 psi to 110 psi in 1 hr (fluid 7.5 bbls, 22.5 bbls total). Monitored for 30 min. Final WHP's = 0/10/135. 3/21/2019 SV, WV = C. MV=O. IA, OA = OTG. 04:30 Printed 4/8/2019 114.05PM "All depths reported in Drillers Depths" North Amenra - ALASKA - BP Page 1 of 15 Operation Summary Report Common Weil Name: 1-2-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/24/2019 End Date: 4/2/2019 X3 -0198F -C: (3,063,038.00 ) Project: Lisburne Site: L2 Rig Name/No.: CDR -2 Spud Date/Time: 8/28/1998 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001105 Active datum: KB @39.30usft (above Mean Sea Level) Dale From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 3/24/2019 04:30 - 17:30 13.00 MOB P PRE MOVE RIG FROM 09-28B TO L2-078 - PJSM FOR MOVING RIG WITH PEAK AND NABORS CREWS. - MOVE RIG OFF WELL 09-28B. -INSTALL JEEPS - MOVE RIG TO 12-078 -TAKE OFF JEEPS -SPOT STOP BLOCK - VERIFY TREE VALVES CLOSED -SPOT SUB OVER WELLAND SET DOWN - SPOT PIT MODULE AND SET DOWN --RIG ACCEPTED AT 1730 1730 - 20:30 3.00 RIGU P PRE RIG UP - COMPLETE RIG UP CHECKLISTS - HOOK UP STEAM AND PIPING, ELECTRICAL LINES INTERCONNECT - VERIFY STEAM HEAT THROUGHOUT THE RIG j - SPOTAUXILIARY EQUIPMENT - RIG UP MP LINE LEAK TIGHT TEST SWAB AND MASTER 'VALVES, GOOD. NOTE: INSTALLED LOCKS AND TAGS ON WINGS AND SWABS ON NGI WELLS 1 AND 12 -ALREADY SHUT IN AND LOCKED OUT BY i PAD OPERATOR ON 3-19-2019 2030 - O000 3.50 RIGU P PRE REMOVE TREE CAP, INSTALL BOPS. 'RIG UP -INSTALL TURNBUCKLES ON BOPS. _-MU TEST JOINT ASSEMBLY 3/25/2019 00:00 - 06:00 6.00 i 8OPSUR P PRE PREP BOPE TEST -GREASE TREE, T1, T2 AND CHECK TORQUE ON TREE FLANGE -GOOD -FILL COIL WITH FRESHWATER -PREP RIG FLOOR FOR BOP TEST -CALIBRATE MICROMOTIONS -PURGE AIR FROM SYSTEM. Printed 4/8/2019 114.05PM "All depths reported in Drillers Depths" Common Well Name: 12-07 Event Type: RE-ENTER- ONSHORE(RON) Project: Lisburne North America - ALASKA - BP Operation Summary Report AFE No Start Dale: 3/24/2019 End Date: 4/2/2019 X3 -0198F -C: (3,063,038.00 ) Site'. L2 Page 2 of 15 Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @39.30usft (above Mean Sea Level) BPUOI: USAD0001105 Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (hr)_ i (usft) 06'.00 - 1400 8.00 BOPSUR P PRE TEST BOPS AS PER AOGCC AND BP REGULATIONS. 7-1/16" 5K STACK: ANNULAR, BLIND/SHEAR RAM, 2-3/8" PIPE/SLIP, 2-3/8" x 3-1/2" VARIABLE RAM, 2-3/8" PIPEISLIP RAM AOGCC WITNESSED WAIVED BY BOB NOBLE ALL TESTS TO 250 / 3500 PSI. TEST 1: IRV, STRIPPER, C9, C70 'BACKWARDS - PASS TEST2: BLIND /SHEARS,R1,BL1A,all, B4— PASS REMOVE INJECTOR TEST 3: ANNULAR (2-3/8"), TIW1, B3, B2, BL1 - PASS TEST 4: REDO, SMALL INCREASE IN PRESSURE HALFWAY THROUGH TEST 4: UPPER P/S, TIW2, BL2, R2, T2, C15 - "'T2 FAIL/FAIL"' TEST 4 PASS USING T1 TEST 5: C16, T1, C 11 -PASS TEST 6: VARIABLES (2-3/8"), C7, C9, C10, TV2 -PASS TEST 7: LOWER 2-3/8" P/S, C5, C6, C8, TV1 - PASS TEST 8: CHOKE A, CHOKE C - PASS HOLD PRE -SPUD & RIG EVAC DRILL WITH DAY CREW COMING ON TOUR CONDUCT DRAWDOWN TEST -PASS '. REMOVE BOP TEST JOINTAND INSTALL 0.9' SAVER SUB TO SPACE 3-1/2" SECTION ACROSS ANNULAR AND VERS. REINSTALL TEST JOINT. TEST 9: ANNULAR (3-1/2"), Cl, C4. - FAWPASS TEST 10: VARIABLES (3-1/2"), C2, C3 - PASS FAILURES - T2 VALVE ON MPD LINE (BP VALVE) 14:00 - 17:00 3.00 BOPSUR N PRE BOP TEST COMPLETED, HOLD A PJSM TO REPLACE T2 VALVE - REMOVE TEST JOINT - SUCK OUT STACK SIMOPS - INSTALL BHI FLOATS WHILE CHANGING OUT T2 VALVE - RD MPLAND REMOVE T2 VALVE - MU NEW VALVE & TORQUE -SWAP OUT LUBRICATORS -TEST DRILLING LUBRICATOR AND T2 VALVE 17.00 - 1745 0.75 BOPSUR P PRE GOOD PT ON DRILLING LUBRICATORAND T2 VALVE - REMOVE NIGHT CAP AND INSTALL QTS - STAB INJECTOR AND PT QTS AND BHI FLOATS Printed 4/8/2019 1.14:05PM **All depths reported in Drillers Depths— North America - ALASKA - BP Page 3 of 15 Operation Summary Report Common Well Name: 1.2-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/24/2019 End Date: 42/2019 X3-0198F-C: (3,063,038.00) Project: Lisburne Site: L2 Rig Name/No.: CDR-2 Spud Date/Time: 8/28/1998 12:00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001105 Active datum: KB @39.30usft (above Mean Sea Level) Date From -To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ Milt) _ 17:45 - 18:30 0.75 BOPSUR P PRE OPEN TO WELLAND FLOW CHECK -PUMP METHANOL DOWN MPD LINEAND FLUSH TREEAND STACK TAKING RETURNS TO TIGER TANK UNTIL WE HAVE GOOD 'METHANOL. -OPEN MASTER VALVE WITH CLOSED CHOKE AND MONITOR FOR PRESSURE-0 PSI. •-PUMP METHANOL DOWN MPD LINE AND CHECK FOR LOSSES TAKING RETURNS TO TIGER TANK., NO LOSSES -MONITOR WELL FOR TEN MINUTES-STATIC -BREAK OFF INJECTOR.. 18 30 - 1990 1.00 STWHIP P WEXIT MAKE UP MILLING BHA -HOLD PJSM -MAKE UP MILLING BHA -MAKE UP INJECTOR AT 1915 HOURS -TEST OTS TO 3500 PSI -GOOD TEST. 19 30 - 00:00 4.50 STWHIP P 10,900.00 WEXIT RIP -PUMP RATE 0.4 BPM IN, 0.8 BPM OUTAT 40 PSI. -AT 3000' STOP AND FLUSH SURFACE LINES 'OF METHANOL -CONTINUE RUN IN HOLE ATABOVE 'PARAMETERS • -AT 4600' OBSERVE OUT RATE INCREASE AND DENSITY ON OUT MICROMOTION GO TO 6 PPG. STOP AND FLOW CHECK-DISCUSS WITH WELL SUPERINTENDENT AND CONTINUE IN HOLE HOLDING ONE TO ONE RETURNS WITH CHOKE. -TIE IN TO FORMATION (PDC) FROM 10750' TO 10850' SENSOR DEPTH, -13' CORRECTION -CIRCULATE KCLAT 4.25 BPM IN AND OUT TAKING RETURNS TO TIGER TANK NOTE BLED OFF IA FROM 1400 TO 800 PSI, BLED OFF OA FROM 600 TO 300 PSI NOTEAELD KICK WHILE TRIPPING DRILL WITH BEARD'S CREW. WELL SIMULATED SHUT IN IN 1 MINUTE 13 SECONDS. AAR HELD WITH CREW. _ 3/26/2019 0000 - 01:00 1.00 STWHIP P 10,900.00 WEXIT CONTINUE TO CIRCULATE WELL TO 8.6 PPG QUICK DRILL N PUMP AT 4.4 BPM AT 3226 PI 01:00 - 1000 9.00 STWHIP P 10,931.00 WEXIT MILL 3.8" WINDOW ( -DRY TAG @ 10924.9 , DRY PICK UP 52K, DRY {-7 DOWN WT 22K - RATE: 2.8 BPM IN, 2.33 BPM OUT -UP Wr 48K, DOWN WT 20K - MUD WEIGHT: 8.58 PPG IN, 8.52 PPG OUT - DADS: 0.5- 3.7 KLBS - CIRC PRESSURE: 2418 PSI 10.00 - 10.15 0.25 STWHIP P 10,931.00 WEXIT PU OFF WINDOW TO SWAP RIG OVER TO HIGHLINE POWER ""HOLD KWD DRILL"" SIMULATED INCREASED OUT RATE, PU OFF BOTTOM AND FLOW CHECKED WELL, SIMULATED WELL WAS STILL FLOWING AND WELL WAS SHUT IN FOLLOWING OUR STANDING ORDERS. MORE INFO ON COMPLEX DRILL IN THE SAFETY COMMENTS Printed 4/82019 1'.14:05PM "All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: L2-07 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/242019 End Date: 4/2/2019 Project Lisburne Site: L2 -�-- AFE No t3 -0198F -C: (3,063,038.00 ) Page 4 of 15 Rig Name/No.: CDR -2 Spud Date/Time: 8/28/1998 12:00:00AM Rig Release: Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00001105 Active datum: KB @39.30us8 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ _ (usft) _ 10:15 - 12:30 2.25 STWHIP P 10,934.00 WEXIT CONTINUE MILLING 3.8" WINDOW - RATE: 2.7 BPM IN, 2.7 BPM OUT - UP WT 48K, DOWN WT 20K - MUD WEIGHT: 8.58 PPG IN, 8.52 PPG OUT - DWOB: 0.5- 3.2 KLBS - CIRC PRESSURE: 2360 PSI WE ARE NOT SEING ANYTHING THAT INDICATES WE HAVE EXITED THE WINDOW, BOT HAND THINKS THEY STARTED 1' EARLY. WE ARE GOING TO CONTINUE AT VHR UNTIL WE SEE OUR WOB DROP OFF 12'.30 - 17:00 4.50 STWHIP P 10,944.00 WEXIT GOOD INDICATION WE HAVE EXITED THE BOTTOM OF THE WINDOW AT 10933.7, CONTINUE MILLING AT 1'/HR FOR T THEN START MILLING RAT HOLE - 10938' PUMPA 10X10 LOW/HI-VIS PILLS - DRILLED TO 10944' START REAMING PASSES DRY DRIFT IN BOTH DIRECTIONS CLEAN 1700 - 1900 2.00 STWHIP P 10,944.00 WE POH -MONITOR WELL FOR 10 MINUTES: STATIC -OPEN EDC, POH - MUD WEIGHT: 8.6 PPG IN, 8.55 PPG OUT RATE: 2.5 BPM IN, 2 BPM OUT .1900 - 20:00 1.00 STWHP P 10,944.00 WEXIT LD BHA MONITOR WELL FOR 10 MINUTES AT BHA: ,STATIC -HOLD PJSM -CLOSE EDC, POWER DOWN - INJECTOR OFF: 19:20 i- MILL IS 3.79" GO, 3.78" NO-GO. REAMER IS 13.79" GO, 3.78" NO-GO 2000'. - 2045 0.75 DRILL P 10,944.00 PROD1 'MU BHA -HOLD PJSM -MAKE UP BUILD BHA WITH 2.1 DEGREE MOTOR -INJECTOR ON AT 2030 HRS -TEST QTS TO 250/3500 PSI -GOOD TEST -SURFACE TEST MWD TOOLS -GOOD 2045'. - 23.30 275 DRILL _ P 10,944.00 PROD? RIH WITH 4-1/4° BUILD BHA#2 - RATE: 1.13 SPM IN, 1.59 BPM OUT. CIRC PRESSURE: 1010 PSI - MUD WEIGHT: 8.54 PPG IN, 8.51 PPG OUT -TIE INTO FORMATION (PDC) FROM 10800' TO 10826' BIT DEPTH, -13' CORRECTION WT CHECK PUMPS ON -UP WT 47K, DOWN WT 20K -CLOSE EDC -RIH THIRD WINDOW WITH NO PUMPS AT 25 DEGREES RIGHT -NO ISSUES 23:30 - 00:00 0.50 DRILL P 10,950 00 PROD1 DRILL 4.25' BUILD FROM 10944' MD TO 10950' MD - FREE SPIN: 2500 PSI, 2.78 BPM - RATE: 2.78 BPM IN, 2.78 BPM OUT. CIRC PRESSURE: 2600-2900 PSI -MUD WEIGHT: 8.58 PPG IN, 8.51 PPG OUT, ECD: 10.3 PPG -ROP 30-70 FT/HR WOB 2- 3KLBS Printed 4/812019 1:14:05PM "All depths reported in Drillers Depths" TfEE= 4-1/16'CAN VVELLFEAD= FMC ACTUATOR= BAKHtC KB. ELEV= 39.3' � aEV = _ 39.3' BF. E LEV = 14.43 KOP= 1985' Max Angle = 96' @ 12630' Datum KU = 489T Datum TVD= 88W SS 9-5/8' CSG, 40#, L-80, D = 8.835 4430' BT N TOC M 1/15/18) Minimum ID = 2.372' @ 10954• 3.7" BKR KB LNR TOP PKR 4-12• MONOBORE WFIFSTOCK w/ 10924• 2 RA FPTAGS @ 10933' (12106118) 4-1/2' BKR CBP(12105/18) 10938' PERFORATION SL*jMRY FEF LOG: SLB C7•L ON 05/31/04 ANGLEATTOPPHW: 86' @ 11575' Atte: Fbfer to Production DO for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2' 6 11575-11606 O 03/13/18 2' 6 11619-11650 O 03/13/18 2' 6 11855-12055 C 05/31/04 2" 6 12100 - 12170 C 05/31/04 2' 6 12195-12245 C 05/31/04 Y 6 12325 - 12405 C 05/31/04 2 6 12445-12495 C 05/31/04 2' 6 12585 - 12635 C 05/31/04 2' 6 12700 - 12680 C 05/31/04 4-1/2' LNR 12.6#, L-80, .0152 bpf, D = 3.958' 11556• L2 -07A SAFETY NOTES: WELL ANGLE> -70' @ 11208. PRUDHOE BAY 2170' 4-1 /2' CAMCO BAL-O SSSV NIP, D = 3.813' [efa69II a11,T M1 5o69 ISTI AID 1TVDIDEVI D = 4.4375' TYPE I VLV LATCH FDRr DATE 1 4089 12(18118 44 KBG2LS DAM M 0 04/21/18 '2 7758 1 13498 6094 45 KBG2LS DAM M 0 0421/18 '3 10401 7958 34 KBG2LS BMPIY - - 11/12118 10660' 7- X 4-1/2' BAKER S-3 PKR D = 395Fr 10683' H4-112* HES X NP, D = 3.813' 10590' 4- U2" 7' X 4-1/2' BKR ZXP PKR w /BKR HMC HGR DATE D = 4.4375' 10606' 4-1/2'WLEG, D=3.958' 106 5'X4-1/2'XO. D=3.9375- .9375' 7VUtl7 —jb-lIL'T}:1/lO JIU,U=Z/8ti LI.LOL)T WIDOW 11035':11041' LNR 6.2#, L-80, .0076 bpf, D = 2.80' 1-1 11906' Iwr/ exi rwrn.e utr luml-snet 11906• x-13-3/16^ X 2-7/8' XO, D = 2.372' LNR 6.5#, L-80, .0058 bpf, D = 2.441' H 12966' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/11/98 ORIGINAL COMPLETION 1127/18 TFA/AU CMT N IA/t&LEDRET& CBPYSE7 06/02/04 JLMIKAK CTD SIDETRACK (1-2-07A) 12(18118 KFM/ AID SET CBP& MDNOBOFP WFPSTOC( 10129/18 JBJJJM)ADO®Rff,BF,& 12/19/18 JM) MNDR CORRECTONS 1029118 ZV/JAD FILL®PXPLLIG(1(I/25/18) 11/06/18 NXW/J SETCBP(11/02/18) 1127/18 CJFYJM) GLVCO(11N2118) 1 12921' 1 PFADFDE BAY LUT VVE-L: L2 -07A PBtMT No: "2040530 AP No: 50-029-22910-01 SEC 18. T1 1N. RI 5E 3511.01' FE_ & 4478.57' FNL BP Exploration (Alaska) MEMORANDUM TO: Jim Regg � 2� 15�tq P.I. Supervisor 'il FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 11, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. L2 -07A PRUDHOE BAY UN PBU L2 -07A See: Inspector Reviewed By: P.I. Supry J�`-- Comm Well Name PRUDHOE BAY UN PBU L2 -07A API Well Number 50-029-22910-01-00 Inspector Name: Jeff Jones Permit Number: 204-053-0 Inspection Date: 1/25/2019 Insp Num: miUJ19012709034I Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L2 -07A -]Type Inj N TVD 6625 Tubing 1365 2748 2706 - 2691 1 PTD zo4os3o Type Test SPT Test psi 1656 IA 62 225 254 - 259 _ BBL Pumped: BBL Returned: I - OA 167 189 - 197 201 -- Interval OTHER P/F P — Notes: Post production casing repair MIT -T. Whipstock set @ 10924' MD to facilitate test. I well inspected, no exceptions noted. Su it 316-3b(, tuii t -z; 1--04 fnxt tc, Monday, February 11, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggj�� p (_J/ 6 DATE: Monday, February 11, 2019 1 P.I. Supervisor (q F SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. L2 -07A FROM: Jeff Jones PRUDHOE BAY UN PBU 1,247A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PBU L2 -07A API Well Number 50-029-22910-01-00 Inspector Name: Jeff Jones Permit Number: 204-053-0 Inspection Date: 1/25/2019 - Insp Num: miUJI90127085026 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L2-o7A 'Typelnj N TVD 6625 "Tubing ? 151 u,, ,ao PTD 2040530 'Type Test SPT Test psi 1656 IA 428 3249 - 1096 �osz BBL Pumped: 2.1 'BBL Returned: ?_1 - OA 228 eos - 583 _ n4 - �_ Intervale, OTHER P/F P Notes: Post prrond�uctum casing repair MIT -IA. 1 well inspected, no exceptions noted. 0—yQ (S FrDltcer 43tw)- 31 it --M& Monday, February 11, 2019 Page 1 of I 20 4053 WELL LOG 2 9 3 1 8 TRANSMITTAL EC ' ' PROACTIVE DIAGNOSTIC SERVICES, INC. MAY 19 2018 AOGCC To: AOGCC Natural Resources Technician II 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2— 1 900 Benson Blvd. Anchorage, AK 99508 GANCPDC@USAANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. same JUN L 5 LW Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 22-Apr-18 Run2 L2-07A Color Log /CD 50-029-22910-01 2) i Signed : A�_ Date : L2/10P- ei Print Name: MINA__Ma A. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE: D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • ` 20 4053 WELL LOG 2 9 3 1 9 TRANSMITTAL RECEIVED PROACTIVE DIACINOSTIC SERVICES, INC. MAY 292018 AOGCC To: AOGCC Natural Resources Technician II 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2– 1 900 Benson Blvd. Anchorage, AK 99508 GANCPDC(a,USAANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe SCANJUN 2 ant) 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 21-Apr-18 Runt L2-07A ((1-47c_ /CD 50-029-22910-01 2) 11 n Signed : I . nry Date : V1ox` ' Print Name: `';-1 ► 1i �� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTempl ateFi I e s\Templ ates\Di stribution\TransmittalSheets\BP_Transmit.docx '411‘° _ , . 204053 Archer LeakPointTM 2 9 3 1 9 Final job report BP Alaska L2-07A Prudhoe Bay 04-23-2018 Rev. 1 Here's the Point Bringing clarity to well integrity management mmor 1111 Archer The well company Innovative, hich cefinition, ultrasounc technology for fast, accurate fault location anc creater operator conficence. .ti► • • r ^ kks,. Archer LeakPointTM Finaljob report Client: BP Alaska Well: L2-07A Field: Prudhoe Bay Country: USA Survey date: 04/23/2018 Report date: 04/26/2018 Reference number: Field Engineer/Log analyst: Joel Johns Reviewed by: Revision: 1 III Legal Notice All interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretations.Archer shall not except in the case of gross or wilful negligence on our part be liable or responsible for any loss costs damages or expenses incurred or sustained by any party resulting from any interpretation made by any of our officers agents or employees.These interpretations are also subject to Archer's general terms and conditions of trade Submitted by(Analyst sign) Approved by(Reviewer sign) Print name Print name Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 3 of 15 • •r? r �r L Table of contents Page 1 Introduction 5 2 Executive summary 5 3 Data acquisition,presentation and analysis 5 4 Interpretation of data 5 4.1 Summary of Results 5 4.2 Suspected PC Leal—7,394' MD 6 4.3 Confirmed PC Leak—7,394' MD 7 5 Conclusion 8 Appendix 1 —Operations summary 9 Appendix 2—Pressure Data 11 Appendix 3—Well Schematic 14 Appendix 4—Sensor Configuration 15 Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 4 of 15 • cp c' cpES 0164-S 1 Introduction A LeakPoint Survey in memory mode was run with the objective • Determine location of leak causing failure of MITIA. This report details the results of that survey. 2 Executive summary A leak was first established by pressuring the IA to 1700 psi and taking returns to the formation. A rate of about 0.31 bpm was reported under these conditions. A suspect signal was noted at 7,394' MD. A second pass was taken with 2,800 psi on the IA and taking returns to the formation. A rate of about 0.44 bpm was reported under these conditions. A definite leak signature was located at 7,394 MD. 3 Data acquisition, presentation and analysis Logging Summary Run1 Program Phase Tubing!Well Status A-annulus B-annulus Comment Run 1 —225 —1700 250-380(build) .31 BPM on IA(pressures are average) Run 2 —200 —2800 250-566(build) .44 BPM on IA(pressures are average) 4 Interpretation of data 4.1 Summary of Results Depth ft. Comment 7394' PC Leak Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 5 of 15 • 4011 s ors WIRfLINf LLC 4.2 Suspected PC Leak—7,394' MD 6000 CCL -665 160 Temperature(degF) 180 0 Line Speed(ftlmin) -200 -3 Differential Temperature(degF) 1 0 Temperature(degF) 200 0 LeakPoint -A(Upper Tool) 150000 0 TEMP2(degF) 200 0 LeakPoint"'-B(Upper Tool) 150000 0 LeakPoint" -C(Upper Tool) 150000 160 TEMP2(degF) 1801 rr ' r ' OH 't1 t i 7300 + ' c a. .... _-- ( Temperature—►". ' ` LeakPolntTM-A(Upper Tool) _ t eakPointTM-B(Upper Tool) — ( ) Tempera ureBL LeakPointT"-C(Upper Tool), III r Diff Temp(LA) _. - - -.- __ i - .:+11--Line Speed 1 ` --lefrlpefttlre 1 {• 1 - t i r- - —4- -4- Z CCL--I. _�r--_- -r-- p _. --- __-rrl Temperture(BL) I } Till CC l h-Suspected Leak 0.31 bbl/min 7400 1 gni , 11111 11 EMI — — — t — , ■ari i 1 --tr Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay survey date 04/23/2018 Report date 04/26/2018 Page 6 of 15 • •1------) r Ot11VlRI,J1V1 t[{ 4.3 Confirmed PC Leak—7,394' MD 6000 CCL -665 160 Temperature(degF) 180 O Line Speed(ft/min) -200 -3 Differential Temperature(degF) 1 O Temperature(degF) 200 0 LeakPointTM-A(Lower Tool)50000 1500CLeakPoint",-A(Upper Tool) 0 O TEMP2(degF) 200 0 LeakPoint -B(Lower Tool)50000 1500(LeakPoint""-B(Upper Tool) 0 0 LeakPointTM-C(Lower Tool)50000 1500(LeakPoint"'-C(Upper Tool) 0 160 Temperature(BL)(degF) 180 2 ��tr/r. s INA ' --CCL 7300 --4---Temperature--1- i M--Line Speed Differential Temperature—4. 4—Temperature— LeakPointTM-A(upper Toot)__I i i _ '------- it--Base-Line Temp LeakPoint""-B(Upper Tool) 1 i t- 7t LeakPointTM-C(Upper Tool) r __111.1111111111 R■_ _ .1 LeakPomtr. A(Lower Tooq--i i t. f I r rLeakPoint'"-B(Lower TooTool). _ 1 4.1.Base-Line Temp--i 11111111111111111A . .. .. ........................Leaki -C(LowerTool)------- MI H;r , mu 1 Ell 5 If " 5 T 1 I r y Leak Signature r I '.t I 7400 t —1- o• { t p C t y NFA t ik i t L r KAt "ILA r • i 1T I yy , Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 7 of 15 • • C.; L. CFRS 5 Conclusion • A leak was first established by pressuring the IA to -1700 psi and taking returns to the formation. A rate of about 0.31 bpm was reported under these conditions. A suspect signal was noted at 7,394' MD. (Figure 4.2) • In an effort to confirm the leak, a second pass was taken with a higher pressure applied to the IA in an attempt to increase the signal strength. A pressure of-2,800 psi was applied to the IA and while taking returns to the formation. A rate of about 0.44 bpm was reported under these conditions.A definite leak signature was located at 7,394 MD. (Figure 4.3) • No other leaks were found during the course of the log. Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 8 of 15 O r L. ,SFS !N(Il Appendix 1 —Operations summary Date Time Description 21-Apr-18 21:00 Travel 21:30 Arrive-On Location 23:00 Program tools 23:23 Start battery 00:23 on DTR Stab on Lubricator- Run 1 RIH 22-Apr-18 01:13 On bottom 01:18 LRS start pumping 09:00 Break Off Lubricator-Run 1 Download Data 1 of the 2 tools didn't record 22-Apr-18 10:00 BP Opted to make 2nd run (Asked to increase pump pressure) Call out to relieve Brandon Travel Arrive-On Location 12:00 Programed Tools for Run 2 12:00 Standby for OA Test and rig down and rig up for IA Pumping Connected tools, and tools didn't initiate as they should Re-Re-program tools Connected tools to battery and didn't operate again as should, so decided to go to Shop and get new memory. 17:30 Program new memory Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 9 of 15 • • r? Cc �r► Law ..i Li OI 17:40 Connect Battery 17:50 Stab on Lubricator- Run 1 17:55 RIH @ 120'/min 23-Apr-18 00:32 Stop Logging for Safety meeting w/pad and WSL/Safety Coordinator Start pumping again 23-Apr-18 01:42 Start logging again 04:40 Bumped up 04:45 Bleed off Lube 04:48 Download DTR 04:55 Break Off Lubricator-Run 1 05:09 Download UMT 05:15 Data looks good(just need to see if I can find a leak now) 05:55 Leak found at 7380'uncorrected 06:00 Sent in to Houston for confirmation 06:15 Travel 06:45 Arrive-Not On Location 07:00 End Ticket Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 10 of 15 II II • ! r Ct Appendix 2—Pressure Data Date Time Tubing IA OA Leak Rate(gpm) Comments 22-Apr-18 0:52 220 668 29 1:18 235 2300 350 1:19 224 2294 346 1:35 230 1770 274 1:40 1712 1:44 229 1700 263 10 bbls gone 1:50 228 1697 262 2:05 227 1699 262 2:20 225 1703 264 2:35 224 1705 266 2:50 223 1707 269 3:05 223 1709 272 3:20 220 1711 275 3:35 219 1712 278 41 bbls gone 3:50 220 1715 280 4:05 219 1714 282 4:20 218 1714 285 4:45 216 1716 288 62 bbls gone 5:30 215 1716 291 5:45 215 1719 293 6:00 216 1718 294 6:15 216 1719 297 87 bbls gone 6:30 216 1714 297 7:00 220 1703 316 Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 11 of 15 • • r., „b. 7:30 225 1700 340 8:00 226 1705 355 8:30 230 1706 371 9:00 231 1708 382 RUN 2 RUN2 RUN2 RUN2 RUN2 RUN2 RUN2 22-Apr-18 19:22 194 664 35 .4bbl/min bring pumps on line 19:38 213 2515 248 70deg fluid 19:43 213 2598 263 19:59 213 2654 284 20:30 210 2654 314 85deg fluid 20:57 209 2701 351 21:20 208 2698 377 .4bbl/min 48bb1 away 21:44 206 2692 405 58bb1, 94 deg 21:54 206 2691 416 22:20 204 2671 440 203 2662 461 98deg 203 5666 479 23:24 202 2679 494 23:40 202 2680 506 0:00 202 2680 518 100deg, 112bbl away 0:20 200 2672 529 safety meeting. Shut down 1:42 197 2623 464 97deg, 132bbl away 2:04 199 2666 482 .4bbl/min 2:20 199 2684 485 Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 12 of 15 • • • r. c-D cPSL. ;es mraWMt Uc 2:40 198 2701 510 3:00 197 2710 523 164bb1 away 3:22 196 2713 525 3:43 196 2712 525 195 2711 550 190 away 4:21 194 2713 561 4:41 197 2712 566 206 away 96deg Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 13 of 15 • r • _......._......._..-- Appendix 3 —Well Schematic TREE R; CNV WELLHEAD- FMC L2-078 SAFETY NOTES: ACTUATOR- BAKERC KB ELEV asa PRUDHOE BAY BF ELEV KOP- 1985' Vex Angle- 96-471-26,30T Datum NO- 4893' ( 2170' 4-1R"CAMCO BAL-O SSSV r8.0=3813" Datum TVD- 8800'SS 0.5:8"CSG,408,L-80,ID=8.835" 4429 , GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE Minimum ID=2.372"@ 10954' — 1 e088 3498 44 KBG2LS DMY 94T 0 12/19/09 3.7"BKR KB LNR TOP PKR 2 7758 6094 45 KBG2LS D 8' 0 INT 0 01/161 IM 3 10401 7958 34 KBG2LS DM 0 12104/99 -,--- 10550' 7"X 4-12"BAKER 5-3 PKR ID-3.958"' I 10583' 1-14-112'HES X NIP.D-3.813"I /14 10604r X 4.112"BKR ZXP PKR.ID-4.375"I 14-1/Y TBG,12.69..L-80..0152 bpf,D=3.958" 10605' 10605" 4.1/2'WLEG.0-3.958" MMUS EEC= 17"CSG 268 L-80 ID-5 275" 10785' ==:HELMO NOT LOGGED I PB6FORATON SUMMARY 3.7"BKR INR TOP RCR 0",2.372" REF LOG, 111 10961" 3.7"BKR DEPLOYMENT SLV.0-3 0" I ANGLE AT TOP PERF-88 ek 11855' Note:Refer to Production OB for historical pert data 3-1/2"HES X NP 0-2.812"I SIZE SFF INTERVAL OpNSgz DATE 2" B 11855-12055 0 05131/04 10991" 3-1/2"X 3-3/16"X0.0-2 786"I 2" 6 12100.12170 0 05/31/04 2" 6 12195-12245 0 05131/04 1/CLOUT WINDOW 11035'-11041' 2" 6 12325.12405 C 05/31104 2" 8 12445-12495 C 05/31/04 2" 6 12585-12635 C 05/31/04 4` ®i. 3-3116"X 2-7/8"XO.D-2.372"I 2" 6 12700-12880 C 05131/04 �Ie1�4�1�4�1a MEER 's°tPD r78P(4/3106) I I 1-1,2`LNR 12.68,LOU- 0152 opt.ID-3.953" .1,1,4,1,11"i ` mem BKR CBP(1/05/061I 13-3/16"LNR,6.28.L-80.0076 npf ID-2 AD" 11906' +' 12921' EN 4i. I2-7/8"Llai.6.511.L-80..0058 bpi,JD-,2.441" NiEni DATE REV BY COSMENTS DATE REV BY COMMENTS FRLOHOE BAY UNIT 12/11/98 ORIGINAL COMPLETION 01/16/07 DAV/PAG GLV C/0 WELL L2-07A 06/02/04 JLM/KAK CTO SIDETRACK(L2.07A) 01/01/10 JJ/RPC GLV UPDATE(12/19/09) PERMIT N0,1'2040530 06/08/04 JLJ/KAK GLV 5J0 AR No 50-029-22910-01 12113/05 AS/TLH CORRECTION(PRUDHOE WELL SEC 18.T11N.1915E,3511.01'FR,8 4478.57'FN. 01/05106 BbtN/PJC SET CIBP(fp 12550' 04/0303 SGS/PJC SET WFD CBP@12285' BP Etc lorat Ion(Alaska) Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 14 of 15 •r?IcR pr �. .s 411-14r_ AES*MUM,.( Appendix 4-Sensor Configuration Sensor Offset(ft)i Schematic __ Description Len(ft) OD(in) Wt(lb) 1 MBH-025(1012) 2.33 1.69 11.60 Memory cattery Houses(5CC) I 1 1 UMT-003(210975) 2.14 1.69 10.60 Ultras/ire Memory Tod(12811413) ICCL-015(214103) 1.54 1.69 9.00 CCL 9.59 ; Casing CollarLocator ■ ■ ii F I PRC-001(21269) 1.92 1.69 7.00 Production Roger Centrattser(3 Arm) ' M ■ LEAKA2 5.24 ` _ LEAK2-002t 1.98 1.69 9.20 e5a Leakproof _ LEAKB2 5.24 LEAKC2 5.24 - PRT-016(214960) 1.04 1.69 6.00 LEAKD2 5.24 Platinum Resistance Thermometer TEMP 4.26 = - ■ am 1_111 - PRC-001(95516) 1.92 1.69 7.00 Production Rohr Centragser(3 Arm) , 4. aL �LEAK1-002(215233) 1.97 1.69 9.20 LEAKA1 0.30 est LeakPdm LEAKBI 0.30 LEAKC1 0.30 BUL-006(219226) 0.22 1.69 1.20 LEAKDI 0.30 NI -&anose Terminator Dataset: 1657012-07a Id)run2(dh).db.field/well/run1/Merge2 Total Length: 15.06 ft Total Weight: 79.80 lb O.D. 1.69 in Document number Document title LeakPoint Survey Revision number 1 Well name L2-07A Responsible analyst Joel Johns Field name Prudhoe Bay Survey date 04/23/2018 Report date 04/26/2018 Page 15 of 15 , STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION CO ION APR 0 9 2018 REPORT OF SUNDRY WELL OPE NS 1. Operations Performed (�/�yy,,�, Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 OperatiorA1OiG C OD Suspend 0 Perforate Ei Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill O. Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP Plug H 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-053 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 ' AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22910-01-00 7. Property Designation(Lease Number): ADL 028321,028302 8. Well Name and Number: PBU L2-07A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12956 feet Plugs measured 11764 feet true vertical 8657 feet Junk measured 12920 feet Effective Depth: measured 11764 feet Packer measured 10551 feet true vertical 8650 feet Packer true vertical 8085 feet Casing: Length: Size: MO: ND: Burst: Collapse: Structural Conductor 80 20" 27-107 27-107 Surface 4395 9-5/8" 26-4421 26-3733 5750 3090 Intermediate 10762 7" 25-10787 25-8295 7240 5410 Liner 443 4-1/2" 10592-11035 8122-8519 8430 7500 Liner 2002 3-1/2"x 3-3/16"x 2-7/8" 10954-12956 8447-8657 10160/10570 10530/11160 Perforation Depth: Measured depth: 11575-12880 feet True vertical depth: 8639-8659 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10606 23-8135 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 10551 8085 true vertical depth) - No SSSV • 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED 1 ,w Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 4548 4451 0 571 Subsequent to operation: 2 24625 4143 0 665 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil EL Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: GPMA/Lisbume Lead PE Contact Email: Mark.Sauve@bp.com Authorized Signature: , /,..L.,t4: Date: C//V/j/ Contact Phone: +1 907 564 4660 L' f Form 10-404 Revised 04/2017 VTL 4/26 Pe RBDMSTSV If1PR 1 1 2018 Submit Original Only ,;(,?-,!V /it ?VAT,/ 111111WWW • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) April 9, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Plug Perforations (Set CIBP) and Perforate for Well LISB L2-07A, PTD #204-053. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 i i Daily Report of Well Operations LISB L2-07A ACTIVITYDATE SUMMARY CTU#9- 1.75"Coil 0.156WT Job Objective: Set CIBP,AddPerf MIRU CTU. Pump 1.188"drift ball. Perform partial bop test. MU HES memory GR/CCL in 2.2" carrier+2.30" DJN. Drift to 12,200'and log up to 10,900' painting tie in flag at 11,700'. POOH. Lay down logging tools and confirm good data. 3/12/2018 ....Continued on WSR 3-13-18... CTU#9- 1.75" Coil***Cont. from WSR 3-12-18*** Job Objective:AddPerf, Set CIBP Confirm correction of+4'. Make up perf gun run#1 with 31'x 2" Millenium Perf guns, 6 spf. RIH and Tie in at white/blue flag. Perforate 11619'-11650', POOH. Confirmed shots fired. RD gun#1, Make up pert gun run#2 with 31'x 2" Millenium Perf guns, 6 spf. RIH and Tie in at white/blue flag. Perforate 11575'-11606'. Confirmed shots fired. MU/RIH with 2.281"extended range WFD CIBP. RIH and tie into flag. Set Ext. Range CIBP 11765 middle element (11764' CIBP Top). POOH. RDMO CTU. 3/13/2018 ***Job Complete**** Fluids Summary Bbls Type 230 60/40 Methanol TREE= '4-1/16"CM/ • WB LHEAD= L2-0 7A [igETY Moms: ACTUATOR= BAKER C KB.ELEv= 39.3' PRUDHOE BAY BF.BEV= KOP= 1985' Max Angie= 96"(4 12630' Datum MD= 4893' Datum TVD= 8800 SS I 2170' H4-1/2"CAMCO BAL-0 SSSV NP,D=3.813' 9-5/8'CSG, 40#,L-80,D=8.835" --{ 4425' f---4 I GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT TE Mlnkt'tum ID _2.372" ' 10954' 1 4088 3498 44 KBG2LS DOME t1T 16 1 1/17 2 7758 6094 45 KBG2LS SO NT 20 1 1/17 3.7" BKR KB LNR TOP PKR 3 10401 7958 34 KBG2LS DMY Hr 0 1 Z C 10660' Hi"X 4-1/2"BAKER S-3 PKR,I3=3.958 1 10683' H--14-1/2"HES X NP.ID=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpi,D=3.958" H 10606' k ►7.4 10604' H 7 X 4 1,r BKR ZXP PKR D=4.375' I 10606' H4-1/2"WLEG,D=3.958" 10612' _-15'X 4-1/2"XO 7'CSG,26#,L-8),D=6.276" ---i 10786' 1-41 H EtA0 NOT LOGGED PERFORATION StL*44RY REF LOG:SLB Mt.ON 05/31/04 g e 10564' H 3.7"BKR LINIR TOP PKR,D=2.372" ANGLE AT TOP PERF: 86"@ 11575' II 10961' H3.7"BKR DEPLOY Mt3YT SLV,ID=3 0' Skate:Refer to Reduction DB for historical perf data SIZE SPF P TSA/AL Opn/Sgz DATE I 10980' —13-1/2"HES X SP,D=2.812" 2" 6 11575-11606 0 03/13/18 2" 6 11619-11650 0 03/13/18 10991' H3-12'x3-3/16'x0,D=2.786 1 2" 6 11855-12055 C 05/31/04 2" 6 12100-12170 C 05/31/04 . MLLOUT WTOOW 11035'-11041' 2" 6 12195-12245 C 05/31/04 2" 6 12325-12405 C 05/31-04 � 117W —I EXT RANGE C33P(03/13/18) 2" 6 12445-12495 C 05/31X}4 % - 2" 6 12585-12635 C 05/31/04 � 11906' H3 3/16"X 2-7/8"XO.D=2.372' 2" 6 12700-12880 C 05/31/04 / •••••• 4-12" NR,12.6#,L-80,.0152 bpf,ID=3.953" 1-1 11566' .......0.0.• 4 , 12931'CTM —FISH:MLLE D S CEPS(10/16/17) 3-3/16"LNR,6.2#,L-80,.0076 bpf,D=2.80" 11906' 12921' --IPBTD 2-7/8"LNR,6.5#,L-80,.0058 bpf,D=2A41" 12966' DATE REV BY COMMENTS DATE REV BY COS/SOWS PRUCHOE BAY UM' 12/11198 OliIGlNAL COMPLETiON 03/19/18 JCF/,SD ACFEFFS&SET COP WELL: L2-07A 06102/04 JLM/KAKKCTD 88/MACK(12-07A) F F 4T No:`1040530 01/01/10 JJ/RPC GLV UPDATE(12/19/09) API No: 50-029-22910-01 08/15/17 JL/JM) CORRECTED CSP DIB'f}-t TYPO SEC 18,T11 N,R15E,3511.01'Fa&4478.57'FN 10/17/17 JOM JND MLLE)&PUSHED CEPS 11/06/17 CJWJMD GLV 00(10/31/17) BP 6clloratton(Alaska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill CIBP's Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-053 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22910-01-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU L2-07A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: RECEIVED IV E PRUDHOE BAY,PRUDHOE OIL C 11.Present Well Condition Summary: Total Depth: measured 12956 feet Plugs measured feet NOV 0 9 2017 true vertical 8657 feet Junk measured 12920 feet Effective Depth: measured 12921 feet Packer measured 10551 feet AOGCC true vertical 8657 feet Packer true vertical 8085 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 27-107 27-107 Surface 4395 9-5/8"40#L-80 26-4421 26-3733 5750 3090 Intermediate 10762 7"26#L-80 25-10787 25-8295 7240 5410 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11855-12055 feet 12100-12170 feet 12195-12245 feet 12325-12405 feet 12445-12495 feet 12585-12635 feet 12700-12880 feet True vertical depth: 8654-8663 feet feet 8668-8673 feet 8675-8677 feet 8677-8673 feet 8673-8674 feet 8668-8664 feet 8662-8659 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10606 23-8135 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 2 n Treatment descriptions including volumes used and final pressure: scoop IDE C 2 2 01 r 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2330 620 500 Subsequent to operation: Shut-In 200 2600 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.2831 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Sauve,Mark A Contact Name: Sauve,Mark A Authorized Title: / LEGPMAA/ / /// Contact Email: Mark.Sauve@bp.com Authorized Signature: // Date:///f Contact Phone: +1 907 564 4660 Form 10-404 Revised 04/2017 it T 1Z/ -/` `��'/ I r F v i2}9 - 6 21317 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 8, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Milling of two Cast Iron Bridge Plugs for Well L2-07A, PTD # 204-053. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • m a 0 0 0 (0 O 273 o n r O LO oO r N- L0 0 o O LO CI-I- N CO0 m Lo N- CO CO CO LO 6) O Cfl N- Ln co O) r CO Ln LC) co O N- N LC) V CO CO c- r C) Cb 00 Cb CO CO CO I— N N- O CO N- CO LO N V CO LO C) N N N r ct V CO N CO CO CO CO C O CO CCO CO CO O CO r COOO 0) O LO O O N- O O O O CO r O r O r N o r r r r r o oC Q C i i t i I I ♦+ C Q � N V •-- CO O N- O Cn CA LO CS) O C) N N N LO Cn CA O N O O O = J r r r r .Q M m ! O o O a) U J 00 J C J Cfl N LSC) (D O N 65 O *k N (A O N Rf U N _ ( o N N N i r • o 4 ch N Lo N O C) d Cb O 'sr a) O J CCW C)0 Q CO W U U u C o c o Z Z 0 W W W W W �p Q D H Z_ Z_ Z Z_ j U (n Z J J J J I- • S Packers and SSV's Attachment PBU L2-07A SW Name Type MD TVD Depscription L2-07A TBG PACKER 10551.06 8085.36 4-1/2" Baker S-3 Perm Packer L2-07A PACKER 10599.57 8128.7 5" Baker ZXP Top Packer L2-07A PACKER 10953.81 8446.69 3-1/2" Baker Liner Top Packer • • O O = O Y a) a) o Q (p 3 ) -0 O co N E — - c o ca c a) cLn > ,O L L a O U - + a (a U a) co .O •O 3 oowE3cQ - = m� .L 7, a) Eth Lo 3 �o a ca tea. O y - a al rx ❑ 2 c a) -° O O ci c N O O o M a ° a) co C7 c N -O E •- O o)-o 0 •!n .Q N c +. > In ° o E c O fn .� Q) •a) p a) v) � N O N O -0 Q 7 O N U) Y 7 a) n a) oE .c � •— cEaa) rn - m o ° m3a -0 7 -0 a) 2 7 c cn ami o 00).5 0) 3 o ° -o c}a • ca O Q o 2 -c a) I o ca a) E t ccca a) co co E 0 vi vS cLi c vi "3 Y T= Ca > c a) o a) N.. .` cl n c E m a ca ca .o O -, ° _c c Q N ° cn a) m_ E a) E O o co o a) E M 04 CL o) E ac) Y o ° a) N U L+ ° E �' a U (Ni o@ a) N > .- c L a) c Zo a) c -c N L • ❑ c z > co ca N Q= � 0 � p� o_ — � Y C co 0).0 Q � 3 0) o 0 - a 2 cn C co EU) c -0c ❑ ° -O 0 _ u) c0 U C a > ° � ° Cm O C o Oa ° 4(-0 To• >- )0) o) a oID -N co Q N L a) a H to a`) o a O a`� a) a) a) L N a) a) 2 a a) -a .S (0L co CD > m >:, Q°)- .0 co Q °- :- --, -ooa) oo 33 e) 0 12 cn o o' ow O• < .a � ID_- c0 o aa0) a.) aa) aa) O m N L ." > •a) ca ca O o 0 C (1) ,`i ca rn C7 0) c m O E. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q It- - 05 ß Well History File Identifier Organizing (done) o Two-sided 111111/11111111111I o Rescan Needed '"" 1/1111 II 11I111 R~CAN .y6 ~olor Items: ~reYSCale Items: \ ~ o Poor Quality Originals: DIGITAL DATA ~skettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Dale 71N/ Db Dale7jll4:/ob -'-- X 30 = 30 Date: h /5/ Mf Project Proofing '11111111111111111I Mf BY: ~ /5/ BY: +.2'6 = TOTAL PAGES b~ (Count does not include cover sheet) /5/ Scanning Preparation '" 111111111111111I Production Scanning Stage 1 Page Count from Scanned File: -.:5!l- (Counl does ;nClu~ sheel) Page Count Matches Number in Scanning p¡eparation: YES BY: ~ Date:7/J4-/Ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /5/ VVlp NO BY: Maria Date: /5/ 11/111/1111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned II/ "'111111111111I BY: Maria Date: /5/ Comments about this file: Quality Checked III "1/111/1" II1II 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 a RECEIVED An31 August 22, 2011 rn+missiorr * t1I1 & Go> ,CowCo Anthcolgo o Mr. Tom Maunder ),5) , 0 7 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 ' :f' g S E P 1 9 20 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 02 Date: 7/7/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 L2 -13A 1980780 500292144001 Top Plate NA NA NA NA NA L2 -14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA 11/24/10 SCMM" W NO. 5648 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shart2er ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD OWDW -SE BBSK -00030 RST REDO 09123110 1 1 OWDWSW BBSK -00034 RST 09124/10 1 1 1-2 -0711 BG27 -00008 RST -3,6 — 09128/10 1 i 1-2 -16 BG27 -D0007 RST 09127110 1 1 15 -37C BAUJ -00031 MCNL 06130110 1 1 C -37B AWJI -00107 MCNL 09110/10 1 1 05 -OBA AWJI -00108 MCNL 09111110 1 1 18 -10C SCUE -00078 MCNL 09128110 1 1 04-03 BCRO -00059 RST s 09128110 1 1 1-2.33 B9RH -00036 RST 09130110 1 1 • 1-3 -19 BCRJ -00043 RST — 10102110 1 1 1-3 -08 B3SO -00094 RST 10101110 1 1 1-2 -28 BGZ7 -00009 RST 09129/10 1 1 1-3 -05 BCRJ -00042 RST 10101110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 995012838 WNW • 'EC. 2011 0 rt e,,-- schlumberver NO. 5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job k Log Description Date 8L Color CD OWDW -SW 83SO -00032 RST/WFL 11/07/09 1 1 L -223 858M00014 USIT 10/21/09 1 1 S -218 BSJN -00018 USIT 10/21/09 1 1 L -222 B3SO -00031 USIT 11107/09 1 1 L2 -24 8148 -00079 RST 10/31/09 1 1 11-2 -32 014B -00078 RST 10/30/09 1 1 L1 -14 AV1M -00029 RST 10/27/09 1 1 L2 -18A 8148 -00077 RST 10/30/09 1 1 0488 UBD -00053 MCNL 10/02/09 1 1 S -228 BSK5 -00008 RST 1 10/27/09 1 1 D -24 AWLS -00038 RST 09/27/09 1 1 18 -158 AYS4 -00107 RST 10/31109 1 1 04 -21 AMY-00115 RST 1 W27109 1 1 L2 -07A AYOO -00047 RST 10/29/09 1 1 OWDW -SW B3SO-00032 RST 11107/09 1 12- 05APB1 40015441 OH MWD/LWD EDIT _ 07101/07 2 1 06-218 08AKA0016 OH MWD/LWD EDIT 07/28/08 2 1 D-1 6A 08AKA0175 OH MWD/LWD EDIT 09/07/09 2 1 L -223 09AKA0081 OH MWD/LWD EDIT 10/10/09 2 1 L -223 8581 -00014 CH EDIT PDC (USIT) 10/21/09 1 S -218 BSJN -00018 CH EDIT PDC (USIT) 10121/09 1 L -222 83SO -00031 CH EDIT PDC (USIT) 11/07/09 1 04 -33A 09AKA0075 OH MWO /LWD EDIT 09/19109 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 • s ~m~ ~~ • ~. ,1 o3io~ ~ZOOs DO NOT PLACE ''. ,, ~~ ~~ ~~ ,. ~- ~~ ANY NEW MATERIAL UNDER THIS PAGE F:U.aserFiche\C~nPgs_InsertstMicrofilm Marker.doc ~u&u@ @~ &~~~ DIVISION OF OIL & GAS . SARAH PAL/N, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH AVENUE, SUITE BOO ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX: (907) 269-8938 CERTIFIED MAIL RETURN RECEIPT REQUESTED April 12, 2007 SGJiNNED NOV"O 1 2007 Mark C. Weggeland GPMA Resource Manager BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AK 99519-6612 Re: Request to Commingle Production from the Initial Participating Area with Lisburne Participating Area Production ~<ë.~ ý"'\c..a <:'OS<Oð-~.~C~ <>t.Q:. ~\ ~C} c..a ~'-\ \ E . O\)~ Dear Mr. Weggeland: By letter dated April 2, 2007, BP Exploration (Alaska) Inc. (BPXA), as Operator of the Initial Participating Area (IP A) within the Prudhoe Bay Unit (PBU), requested authorization to commingle a portion of the production from the IPA of the PBU with production from the Lisburne Participating Area (LP A) that is processed through the Lisburne Production Center (LPC). r 304-053> Six IPA wells (L2-03A, L2-07A, L2-08A, L2-11, L2-13A, and L2-18A) located on the Lisburne L2 pad are currently connected to DS-18 by a pipeline and processed at FS-l. These six wells are currently cycled on and off, depending on whether their marginal gas oil ratio (GOR) is competitive with lower GOR production at the FS-l processing facility. Because the LPC is not currently gas- constrained, BPXA proposes to re-route this partially shut-in production through the L2 pad to the LPC processing facility and maintain full-time production from these wells. The Division of Oil and Gas (Division) approves BPXA's request to commingle production trom the IPA with production :trom the LPA with the following conditions: (a) BPXA shall report production from the six IP A wells at the LPC as IP A production and include it on the IP A production reports; (b) BPXA shall report these volumes to the Division using selling arrangement number 207002FOOO on the PRUD and PGAS accounting unit oil operator reports (01); (c) production :trom PBU IPA wells to the LPC shall be determined and allocated in accordance with the GPMA metering and allocation procedures; (d) NGLs removed :trom gas produced by these PBU IP A wells at the LPC shall be accounted for and reported as IP A NGLs; (e) BPXA shall provide the Division the appropriate NGL yield for IP A NGLs produced at the LPC within 10 days of the determination and provide the Division with the alUmaI GPMA NGL allocation update; and (t) the updated Lisburne POD, due in June 2007, shall incorporate a description of operations associated with these SL'( wells. «Develop, COllserve, alld Ell¡ulIIce Natural Resources for Presellt alld Future Alaskalls. " . . Division of Oil & Gas 4/13/07 ~age 2 of2 A person affected by this decision may appeal it, in accordance with 1 I AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" of this decision, as defined in 1 I AAC 02.040 (c) and (d), and may be mailed or delivered to Tom Irwin, Commissioner, DNR 550 W. th avenue, Suite 1400, Anchorage, Alaska 99501; faxed to 1 -907-269-8918, or sent by electronic mail to dnrappeals@dnr.state.ak.us . This decision takes effect immediately. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained ITom any regional information office of the Department of Natural Resources. If you have any questions regarding this decision, contact Cammy Taylor with the Division at 907- 269-8817. Sincerely, ? Kevin R. Banks Acting Director cc: Sherri Gould, BPXA Sam French, BPXA Gary Benson, BPXA Ted Cahalane, BPXA Tim Verseput, BPXA Eric Reinbold, ConocoPhillips Gary Forsthoff, Chevron Hank BensmiIIer, ExxonMobi] John Norman, AOGCC Dave Roby, AOGCC Tom Maunder, AOGCC John Iversen, DOR Cammy Taylor, DNR Jim Stouffer, DNR Jeff Landry, DOL L2-07 A (PTD 2040530) Classified as probleWll All, Well L2-07 A (PTD #2040530) has been found to have sustained casing pressure on the IA. The TIOs on 01/11/07 were 2390/2240/260 psi. A subsequent TIFL failed on 01/12/07. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: c/o OGL V @ 7758' MD 3. DHD: Re-TIFL SCANNED FEB 2 6 2007 A well bore schematic has been included for reference. «L2-07 A. pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Andrea Hughes Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: L2-07 A.pdf L2-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 .J.A ~ ~ s<f 2Z4<Cpsí % M:v-t-P - 3o,("t~ ---. 61:- f&- CÐ 41 'L SRercr I( J 1o{07 1 of! 1/16/20074:01 PM TREE = 4-1/16"C~N WELL.HEAD = FMC KOP = Î 985' Max Angle = 9? @ 1~630' Datum MD = 4893' _".,.".,.,.,.......'.,..,>=_m;O>"="= Datum NO = 8800' SS L2-07 A PRUDHOE BAY . 2170' -14-112" CAMCO BAL.-O SSSV NIP, 10 = 3.813" I I 9-5/8" CSG, 40#, L.-80, 10 = 8,835" I 14-1/2" TBG, 12,6#, L.-80. ,0152 bpf, 10 = 3,958" H 10605' f-- Minimum ID = 2.372" @ 10954' 3.1" BKR KB LNR TOP PKR I 7" CSG, 26#, L.-80. 10 = 6,276" H PF..RFORA 1l0N SUMMARY REF L.OG: ANGL.EAT TOP PERF: 88 @ 11855' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" H 11855-12055 0 05/31í04 2" 6 12100 - 12170 0 05/31104 2" 6 12195 - 12245 0 05/31/04 2" 6 12325 - 12405 C 05/31/04 2" 6 12445 - 12495 C 05/31/04 2" 6 12585 - 12635 C 05/31/04 2" 6 12700 - 12880 C 05/31/04 14-1/2" LNR, 12,6#, L-80, ,0152 bpf, 10 = 3,953" I 11556' ST MD 1 4088 2 7758 3 10401 GAS LIFT MANDRELS DEV TYPE ATCH 44 KBG2lS INT 45 KBG2LS SO INT 34 KBG2LS OMY INT PORT DATE 16 06/08/04 24 06/08/04 o NO 3498 6094 7958 10550' -17" X 4-1/2" BAKER S-3 PKR, 10 - 3.958" I 10583' -14-1/2"HESXNIP,ID=3,813" I -17" X 4-1/2" BKR ZXP PKR. 10 - 4.375" -14-1/2" WLEG. 10 = 3,958" I -15" X 4-1/2" XO I H ELMO NOT LOGGED I 10954' -13.7" BKR L.NR TOP PKR, ID - 2,372" 10961' -13,7" BKR DEPLOYMENT SLV, 10 - 3.0" 10980' -13-1/2" HES X NIP, 10 = 2,812" I 10991' -j 3-1 /2" X 3-3/16" XO, 10 - 2.786" I I MllLOUT WINDOW 11035' - 11041' -1 WFO CIBP (4/3/06) I -1 BKR ClBP (1i05/06) I 13-3/16" LNR, 6.2#, L-80. ,0076 bpf. tD = 2,80" H v CiO CORRECTION (PRUDHOE WEL SE:.ì CIBP @ 12550' SET WFD CIBP @ 12285' 12-7/8" LNR, 6,5#, L-80, ,0058 bpf, ID - 2.441" I DA TE REV BY COMMENTS PRUDHOE BA Y UNrf WELL: l2-07A ÆRMrf No: '2040530 API No: 50-029-22910-01 SEC 18. T11 N, R15E, 3511,01' FEL & 4478.57' FNL BP Exploration (Alaska) ~j~\ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040530 MD 12956 UIC N Well Name/No. PRUDHOE BAY UN PBU L2-07A Operator BP EXPLORATION (ALASKA) INC >~ ~'t~ ~'( API No. 50-029-22910-01-00 / 1-01L Current Status 1-01L Completion Date 6/2/2004 /" 8656 ,.- TVD Completion Status REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD GR, ROP, TVD, PRESS, GR, CNL, CCL Well Log Information: C Lis C Lis (data taken from Logs Portion of Master Well Data Maint Received Comments 9/3/2004 MWD 9/3/2004 MWD 11/20/2004 COMPENSATED NEUTRON/MEMORY GRlCCUCNL COMPENSATED NEUTRON/MEMORY GRlCCUCNL MWD-GR DIRECTIONAL GRAPHIC IMAGE FILES GR, MWD GR,DIR GR, MWD GRlPB1 GR/PB1 PB 1 GR plus Graphics PB 1 GR Log Log Run Interval OH/ Scale Media No Start Stop CH 11114 12956 Open 11114 12956 Open 1 0400 12840 Case Blu 10400 12840 Case 11/20/2004 11 035 12956 Open 1/18/2005 11035 12956 Open 1/18/2005 11035 12956 Open 1/18/2005 11035 12956 Open 1/18/2005 11035 11700 Open 11035 11700 Open 11035 11700 Open 11035 11700 Open Sample Set Number Comments Log/ Electr Data Digital Dataset Type Med/Frmt Number Name )žÐ D Asc Directional Survey Rpt Directional Survey µ C Lis 12859 Neutron Neutron 12931 Gamma Ray Gamma Ray ~~ Blu Gamma Ray 'tVb Blu 12931 LIS Verification Gamma Ray Mf:) 25 Blu Gamma Ray 'tv b 25 Blu 12996 Gamma Ray 12996 LIS Verification Well Cores/Samples Information: Name Interval Start Stop Received Sent . . Permit to Drill 2040530 MD 12956 TVD 8656 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. PRUDHOE BAY UN PBU L2-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22910-01-00 UIC N Comments: Compliance Reviewed By: Completion Date 6/2/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? GIN ~/N Formation Tops ~ Date: ~ ~ j-.,w... ~~ . . # . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Kt:vt:IV I-.U ..; FEB 0 2 2UUb Alaska Oil & Gas Cons. Commission 1 . Operations Abandon D Repair Well D Plug Perforations [] Stimulate D Other D Anchorage Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development M Exploratory 204-0530 3. Address: P.O. Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-22910-01-00 7. KB Elevation (ft): 9. Well Name and Number: 39.3 KB L2-07A 8. Property Designation: 10. Field/Pool(s): ADL-028302 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12956 feet Plugs (measured) 12550 true vertical 8656.42 feet Junk (measured) None Effective Depth measured 12921 feet true vertical 8657.22 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" x 30" 30 - 110 30 - 110 Surface 4401 9-5/8" 40# L-80 28 - 4429 28 - 3739.59 5750 3090 Production 10759 7" 26# L-80 26 - 10785 26 - 8292.83 7240 5410 Liner 951 4-1/2" 12.6# L-80 10605 - 11556 8133.3 - 8637.65 8430 7500 Liner 915 3-3/16" 6.2# L-80 10991 - 11906 8479.86 - 8656.21 Liner 1050 2-7/8" 6.5# L-80 11906 - 12956 8656.21 - 8656.42 10570 11160 Perforation depth: Measured depth: 11855 -12055 12100 - 12170 12195 - 12245 12325 - 12405 12445 - 12495 Closed 12585 - 12635 12700 - 12880 True Vertical depth: 8653.82 - 8662.73 8667.55 - 8672.78 8674.34 - 8676.4 8677.09 - 8672.3 8672.75 - 8673.96 Closed 8668.21 - 8663.96 8661.43 - 8658.43 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 21 - 10605 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Packer 10550 4-1/2" Baker ZXP Packer 10604 3-1/2" Baker KB Top Packer 10954 12. Stimulation or cement squeeze summary: RBDMS BFl FEB {) 6 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 555 26457 0 0 2043 Subsequent to operation: 997 46763 0 0 1301 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development M Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil M Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal l Title Data Mgmt Engr - / Signatu~1?~¿ 7v~.Q Phone 564-4424 Date 1/27/2006 Form 10-404 Revised 04/2004 ¡ I '-. Submit Original Only ., . . . L2-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I 1/2/2006 ***CONT. FROM 01-01-06*** PULLED WRDP-2 (SER # HKS-47 3 SETS OVER SIZE PACKING) DRIFT W/2.250" CENT. W/ SB TO 11203' SLM ***TURNED WELL OVER TO DSO*** 1/4/2006 CTU #9 Set CIBP: MIRU. MU/RIH w/ 2.25" JSN. Partial kill w/ KCL. RIH. Hard tag at 12445' ctmd. 11 K overpull to get pipe moving. POOH to pick up motor and mill. ... Job in Progress - Cant' on WSR 01/05/2006... 1/5/2006 CTU #9, Set CIBP; ... Cant' from WSR 01/04/2006... RIH with BKR 2.31" 3- bladed mill. Kill well with 1% KCL. Mill to 12580', POOH. MU/RIH w/2-7/8" CIBP. Set CIBP @ 12550'. POOH, FP tbg. RDMO. *** Job Complete *** ;,'$'i:S<,.< 'L<; 'lí SUMMAR¥ FLUIDS PUMPED BBLS 231 1 % KCL 112 60/40 Meth 343 TOTAL · Transmittal Form .';<Oc/-053 r'ill BAKER HUGHES I--~-~~::-~:"l--l , ' ';;ì;:'~'::;i';';:w'--'m\ INTEQ :~~~;··t~ ,~:-!___~:,C'_-'~'" _. j .....'''.... ..,....~~ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Jh.,bln Deasun ----.J Reference: L2-07APBl Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log LAC Job#: 680720 .a..v----- Dale: Jï~ ~_ Date: ~ :f. 05 / I L/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -." : ª§g' ! :;~~7::<7~;:-;-;;:;~--~---'! ;~'" :'.;~-"\-;>-' -..-:..1 ;;".. -;;:-·'7_":' u:=::1 ....... .... I .----------.----------------- ~¡."... k~'<;·/ i/ ! .. \:,'.:: , . ii' :' -, Ul~: ~_g~~ \. ¡.:ct' !r~~ .u( I I', :.., : ~.':' ,I' -" ¡it F~:, f)l"; t--~. ,,¡ f",:_.I, '.._',,:, I:::,';' . ~~-- .. (~-'.,.¡ : , >:,' ~:"; ? i-";::~"'~' ..,:_-.-~... '- "'H: "'~ , '.-.'..- ~i.IIIIMiIò.::':;!iIIIiìIâ ~'~i..;:;:_2..~'0 ¡ ~,,-_.~ - i'::> ... . . . dO cf-05 3 Transmittal Form r~i_ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: -B.o.l1iD-Deasou Reference: L2-07 A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/DirectÍonal TVD Log LAC Job#: 680720 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 r~~~~ - ';;;¡:;-;;:',,"--,..,'-'" ---~·I ;-" ;: ~"~: ~:-.: I ~R E':::.~E';;'} -., ¡ I : ¡ -- ª§~ ¡ i...." :<~ ~ _:1 ..-..:.;,···,,'-.---;--·-....",;.,;,1 at-:....,..·,·,... ! :::";1.··~;¿.·:'.:n~·:'·:.1 ~~~"""~ j"-"~~'-'---- I i ., ~", i~ ' , i r-'" i " \ i; ! \' ¡, Ii) j¡S~ tL. ,.,;1 ~. ¡;1~ :: - l:~::~'~ : ",:,>.' L...._ )..._. . , ," . ': ('n n; , u~~ ¡ :\. ' 1¡~li~~i ~-~~-~- !._--~-~----:~_...:.~.~-:- ~."dI! i~_ ~":~X~,J'4 ! ~._._------._~ I I, r'O '-.- , ~_____________l+______________+. . STATE OF ALASKA I ALASKA~IL AND GAS CONSERVATION COM I$SION WELL COMPLETION OR REcOMPLETION REPORT AND LOG / ',{¡in. ";. 1a. Well Status: 1m Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 1m Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/2/2004 2()4.()53 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/24/2004 50- 029-2291 0-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 5/29/2004 PBU L2-07 A 1315' NSL, 3802' WEL, SEC. 18, T11N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 522' NSL, 3496' WEL, SEC. 12, T11N, R14E, UM 39.3' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 245' NSL, 4922' WEL, SEC. 12, T11N, R14E, UM 12921 + 8657 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692844 y- 5963212 Zone- ASP4 12956 + 8656 Ft ADL 028302 TPI: x- 688093 y- 5967579 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 686674 y- 5967267 Zone- ASP4 (Nipple) 2170' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 1m Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD GR / ROP / TVD / PRESS, GR / CNL / CCL 2. CASING, LINER AND CEMENTING RECORD - A,,"',...r: ii ~Emlll~pI;RTH MD SETTING! )f¡P'rli1'VP i~?f~ 2$ìž~ . "YT;....ER FT. G~bl; TopiBoTTOM lOP itsOTTOM RECORD 20" Insulated Conductor Surface 110' Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 35' 4430' 35' 3743' 12-1/4" 350 sx PF E, 210 sx G, 1848 sx PF E, 200 sx PF C 7" 26# L-80 23' 10785' 23' 8296' 8-1/2" 552 sx Class 'G' 4-1/2" 12.6# L-80 10590' 11035' 8123' 8519' 6" 143 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 9.3# /6.2# /6.5# L-80 10954 ' 12956' 8447' 8656' 4-1/8" x 3-3/4" 189 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. T J81NG Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10605' 10550' MD TVD MD TVD 11855' - 12055' 8654' - 8663' g5' AbI9,' ;. ""I:Mt:N, . 12100' -12170' 8668' - 8673' 12195' -12245' 8674' - 8676' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12325' - 12405' 8677' - 8672' 12445' - 12495' 8673' - 8674' 2000' Freeze protected with MeOH 12585' - 12635' 8668' - 8664' 12700' - 12880' 8661' - 8658' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 14, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oil-Bel GAs-McF WATER-Bel CHOKE SIZE I GAS-Oil RATIO 6/28/2004 8 TEST PERIOD + 521 3,613 2 45 6,932 Flow Tubing Casing Pressure CALCULATED + Oil-Bel GAs-McF WATER-Bel Oil GRAVITY-API (CORR) Press. 409 10 24-HoUR RATE 1,563 10,838 7 27. CORE DATA Brief descnpllon of UlhoIogy, poros;ty, tractures, apparent dips and presence of 00, [ or water (attach sepa_ sheet, . necessary). SUbmit~~~~illl one, state "none". 0 R \ G \ N A None ~~ <7 I ,j}\jL 1 ~ . ~IED .~~ ~ .+Øt.~ . . g~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ l.9t: (; 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 22TS 11174' 8617' None TDF / Zone 1A 11407' 8634' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Signed / Terrie Hubble ~ IO}., Title Technical Assistant Date () '1-0;)" ·0 PBU L2-07 A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Thomas McCarty, 564-4378 204-053 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/20/2004 6/2/2004 Spud Date: 5/20/2004 End: 6/2/2004 5/21/2004 12:00 - 13:30 1.50 MOB P PRE Prepare and move rig off DS 14-06A. 13:30 - 14:00 0.50 MOB P PRE Finalize for move. Hold safety meeting with crews and security personnel. 14:00 - 22:00 8.00 MOB P PRE Move from 14-06A to L2-07. 8 hours in route. The rig crossed 4 of the new burried powerlines. Time time/cost savings for doing a derrick up move is 12 hours and $50,000.00. Rig accepted at 2100 hrs 5-21-2004 22:00 - 22: 15 0.25 MOB N WAIT PRE Arrive on L2 pad. Spot rig. Wait for pad operator to show up for pad inspection. 22:15 - 22:45 0.50 MOB P PRE Inspect pad with L2 pad operator, Ron White. Slight sheen on 3 puddles. Rig hands will clean up. Tree out of plumb by 3" to 4". Hold PJSM prior to backing over well with rig hands. 22:45 - 23:15 0.50 MOB P PRE Back rig over well L2-07. 23:15 - 23:30 0.25 RIGU P PRE Set rig down, nipple down tree cap. 23:30 - 00:00 0.50 BOPSU P PRE Begin NU BOP stack. 5/22/2004 00:00 - 02:30 2.50 BOPSU P PRE Nipple up BOP stack. Fighting tree that is out of plumb by 3". 02:30 - 03:30 1.00 BOPSU P PRE Initial BOP test. Master and Swab valves leaking. Call for valve crew to grease valves. Resume BOP test. Witness waived by AOGCC, Jeff Jones. 03:30 - 07:00 3.50 RIGU P PRE Pickup Eline coil into reel house. Continue with BOP test 250/3500psi. Check accumulator bottle pressures and function test accumulator. 07:00 - 07:20 0.33 RIGU P PRE PJSM. Stabbing coil to injector. Review plan forward for next 24hrs. (TL shack being overhauled at Tool Sevices) 07:20 - 08:45 1.42 RIGU P PRE Stab coil from reel #1 0592E to injector. (Same time installing hardline and Tiger Tank) 08:45 - 11 :30 2.75 WHIP P WEXIT MU BHi CTC (same time r/u Tiger Tank and hardline. Install 3 pip tags in WE whipstock) 11 :30 - 11 :45 0.25 WHIP P WEXIT Check tubing pressure.. on vacuum 11 :45 - 12:50 1.08 WHIP P WEXIT P/U BHA #1 (108.48'). Check that whipstock tray alignment is set for 30L. Pip tags installed and are 7.77' from top of tray. 12:50 - 13:10 0.33 WHIP P WEXIT Stab-on injector. Check BHi elec connections ...ok. Line-up to take returns to Tiger Tank. 13:10 - 15:00 1.83 WHIP P WEXIT RIH to 2500'. Displace freeze protect from well 15:00 - 15:40 0.67 WHIP P WEXIT Log CCL 1 0600-1 0850' -18' correction. 15:40 . 15:50 0.17 WHIP P WEXIT RIH wt check 48k up 22k dwn tagged at 11041'. Setdown 4k pull to neutral setdown 6k pull to 61k and sheared off whipstock. TO tray = 11 030' Pip tag = 11037.77' BO tray = 11 039' 15:50 - 18:00 2.17 WHIP P WEXIT TOH paint EOP flag at 10500' continue TOH 18:00 - 18:40 0.67 REMCM P WEXIT Tag up at surface. Hold PJ Safety meeting with rig crews to discuss plan forward with experimental cement job. 18:40 - 19:25 0.75 WHIP P WEXIT Lay down WS BHA. All recovered ok. 19:25 - 23:00 3.58 REMCM P WEXIT Check eline for insulation, getting 12 megohms insulation which is marginal. Cut back coil, retest. Getting 7 megohms insulation. Check Jupiter plug, and found corrosion on the plug. Remove the plug and corroded end of cable. Check insulation on raw end of wire. Got insulation of 50 megohms. Hurray! Make up jupiter connection again (15 minutes). Recheck insulation. Megged at 62 meghoms. good to go. Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/20/2004 6/2/2004 Spud Date: 5/20/2004 End: 6/2/2004 5/22/2004 23:00 - 00:00 1.00 REMCM P WEXIT Make up new CTC. Epoxy the end of coil. 5/23/2004 00:00 - 02:00 2.00 REMCM P WEXIT Continue epoxying end of eline. MU cementing BHA - 3" cement dump/JSN nozzle, 12 joints of 1-1/4" CSH, straight pull disconnect and swivel, CTC. Pull test CTC to 10 klbs. PT CTC to 3500 psi. Stab injector. 02:00 - 03:50 1.83 REMCM P WEXIT RIH with BHA #2 to test the eline coil cementing system. Pumping minimum rate while RIH. Stop at flag, make a -22' correction. Continue RIH. Tag top of WS, 03:50 - 04:05 0.25 REMCM P WEXIT Safety meeting prior to cement job with all hands on location. Hazards and mitigations discussed. 04:05 - 04:55 0.83 REMCM P WEXIT Circulate 10' above whipstock while waiting on cementers to batch up. 04:55 - 05:35 0.67 REMCM P WEXIT Cement up to weight. Line up to pump cement. Pump 5 bbls water to warm lines. SD, PT lines to 4000 psi. Open up to coil. On line with cement. Begin pumping; o bbls away, 2.4 bpm, 2400 psi, weight=15.75 ppg. 10 bbls away, 2.4 bpm, 2600 psi, 15.75 ppg 20 bbls away, 2.45 bpm, 2690 psi, 15.75 ppg. 30 bbls away, 2.49 bpm, 2690 psi, 15.67 ppg. Got total of 30.8 bbls of cement away. Pump 5 bbls of water. Swap to rig pumps. Displace cement with biozan. 05:35 - 10:00 4.42 REMCM P WEXIT POH 1.1 bpm, 75 fpm, 180 psi pump pressure. PU weight=48 klbs. Pull to safety at 8800'. RIH washing back thru cement in 300' steps back to whipstock tray. Taking cement returns to cuttings tank, adding citric acid at the possum belly. Washing tbg jewelry on the way out. 10:00 - 10:45 0.75 REMCM P WEXIT Unstab injector. Strip out 260' of e-line from 1-1/4" hydril. Test e-line: Continutiy 62.5 meg ohms Insulation 45.2 ohms Test good. Re-dress and seal end of e-line. Setback injector. 10:45 - 11 :20 0.58 REMCM P WEXIT Standback hydril. 11 :20 - 14:00 2.67 REMCM P WEXIT Slack management. Cut 186' coil and found e-line. 14:00 - 15:10 1.17 STWHIP P WEXIT Install SLB dimple connector pull test to 35k. Make-up BHi upper quick connect 15:10-16:00 0.83 STWHIP P WEXIT Install swizzle stick and cleanout BOP stack. PT CTC 2000psi. 16:00 - 17:00 1.00 STWHIP P WEXIT PU Window Milling assy BHA #3 (45.12') Stab on well. Test tools 17:00 - 19:35 2.58 STWHIP P WEXIT RIH 19:35 - 21 :00 1.42 STWHIP P WEXIT Tag pinch point on WS. Check free spin, 2750 psi at 2.6 bpm. Begin milling. Milling at 2.6/2.6/3090 psi. Ditch magnets in. Milling with used Flo-pro drilling mud. 21 :00 - 22:00 1.00 STWHIP P WEXIT 11036.0', 2.6/2.6/3100 psi. Pit volume=302 bbls. IAP=220 psi, OAP=286 psi. WOB=1700 Ibs. 22:00 - 23:00 1.00 STWHIP P WEXIT 11037.1', 2.6/2.6/3200 psi. Pit volume=301 bbls. IAP=250 psi, OAP=289 psi. WOB=4200 Ibs. 23:00 - 00:00 1.00 STWHIP P WEXIT 11038.1', 2.62/2.60/3250 psi. Pit volume=301 bbls. IAP=260 psi, OAP=290 psi. WOB=4600 Ibs. Getting some steel back on ditch magnets. Printed: 617/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/20/2004 6/2/2004 Spud Date: 5/20/2004 End: 6/2/2004 5/24/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT 11039.0', 2.6/2.6/3100 psi. IAP=280 psi, OAP=288 psi. Pit Volume=304 bbls. WOB=2560 Ibs. 01 :00 - 02:00 1.00 STWHIP P WEXIT 11040.0', 2.56/2.59/3050 psi. IAP=280, OAP=288 psi. Pit Volume=302 bbls. WOB=3670 Ibs. Getting good metal accross shaker screens. 02:00 - 03:00 1.00 STWHIP P WEXIT 11041.0',2.57/2.6/3200 psi. IAP=300 psi, OAP=288 psi. Pit volume=304 bbls. WOB=5400 Ibs. Getting some ratty milling. May be getting ready to exit. 03:00 - 03:40 0.67 STWHIP P WEXIT 11042.0',2.57/2.6/3200 psi. IAP=320 psi, OAP=289 psi. Pit volume=307 bbls. WOB=4000 Ibs. Stall at 11042.0'. May be string mill exiting. 03:40 - 05:00 1.33 STWHIP P WEXIT 11042.3', 2.5/2.5/3400 psi. Drilling break. Probably exited window. Drill ahead formation. ROP=10 fph. Window Depth 11035.0'-11041.0' 05:00 - 06:20 1.33 STWHIP P WEXIT Backream window. PUH above window RIH dry tag on bottom. No problems running thru window area. 06:20 - 08:10 1.83 STWHIP P WEXIT TOH 08:10 - 09:00 0.83 DRILL P PROD1 UD Weatherford window milling assembly. (Window mill 3.79" no-go, string mill 3.79" go, 3.78" no/go) P/U BHi build assembly (65.14'). Surface test tools -ok. 09:00 - 11 :00 2.00 DRILL P PROD1 RIH to 580' stop open EDC. Continue RIH to 10920' 11 :00 - 11 :35 0.58 DRILL P PROD1 Log Gr tie-in. -20' correction 11 :35 - 11 :40 0.08 DRILL P PROD1 RIH to window. 11 :40 - 12:15 0.58 DRILL P PROD1 Ream from 11044' to 11051'. 12:15 - 15:00 2.75 DRILL P PROD1 Directionally drill f/11 051' 2.50/2730 free-spin 3-400psi mw 2-3k wob 50-60'/hr. IAlOA 260/305 Seen RA tags at 11037'. Drilled to 11200'. 15:00-15:15 0.25 DRILL P PROD1 Wiper trip to window. 15:15 - 17:50 2.58 DRILL P PROD1 Continue drilling ahead f/ 11200' 2.5/2700 FS 2-400psi mw IAlOA 340/300psi 3-4k wob 30-50'/hr 17:50 - 20:30 2.67 DRILL P PROD1 Well landed at 80 deg, 11315'. POH to change motor AKO. IAP=390 psi, OAP=290 psi. Pit vol 300 bbls. MWD tool not working. Electrical noise from rig power interfering with tool telemetry. 20:30-21:15 0.75 DRILL P PROD1 Tag up with BHA #4. Bit rung out on nose. Chipped cutters on wing. Graded 8,2, rung out. Geo indicates significant chert pebbles in cuttings. Lay down MWD tool, change coms section. Adjust motor to 1.5 deg AKO. Can't get MWD tool to work due to electrical noise. Try different baud rate coms section. 21:15 - 00:00 2.75 DRILL N DPRB PROD1 Reload MWD software to work with higher baud rate telemetry package. 5/25/2004 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Continue troubleshooting MWD tool. Can't get higher baud rate tool to work properly. Get new software emailed over from Germany. 00:30 - 01:10 0.67 DRILL P PROD1 MWD problems solved. PU BHA #5. 01:10 - 03:00 1.83 DRILL P PROD1 Stab on injector, test BHA. Confirmed MWD is still working. Begin RIH with BHA #5. New Hughes bi center bit, 1.5 deg motor. 03:00 - 03:40 0.67 DRILL P PROD1 Log tie in pass down over Gamma profile at 10910'. Make a correction of -16'. Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/20/2004 6/2/2004 Spud Date: 5/20/2004 End: 6/2/2004 5/25/2004 03:40 - 07: 10 3.50 DRILL P PROD1 Tag bottom, begin drilling lateral section. IAP=150 psi, OAP=281 psi. Pit vol=312 bbls. TF=55L, WOB=4000 Ibs. ROP=90 fph. Free spin 3150 @ 2.65 bpm. Drilling at 2.65/2.65/3450 psi. Current thinking is we are in the base of Zone 1. Turning up. Drilled to 11448' 87deg at bit. 07:10 - 08:10 1.00 DRILL P PROD1 Wiper trip back to window. 08:10 - 09:25 1.25 DRILL P PROD1 Several stalls getting started. Drilling ahead f/11448' 2.65/3130 FS 2-300psi mw 2-3k wob 20-30'/hr frequent stalls 11060-70'. Drilled to 11480'. (ordered out new mud system) 09:25 - 09:40 0.25 DRILL P PROD1 Make 100' wiper trip. 09:40 - 11 :45 2.08 DRILL P PROD1 Drill ahead 1/11480' 2.6/3000fs 2-300psi mw 2.6/2.6 IA/OA 490/322 looks to be 100% shale. Drill to 11504' 96deg at bit. Numerous stalls drilled to 11509'. 11 :45 - 13:00 1.25 DRILL P PROD1 Wiper trip back to window. Sticky spots at 11420',11443', 11449', 11470', 11509'. 13:00 - 13:40 0.67 DRILL P PROD1 Resume drilling. Mud swap to new mud in progress. New mud has 8.7 ppg, 12 ppb claygard. 13:40 - 14:00 0.33 DRILL P PROD1 Attempt PU, heavy overpull. Normal up weight=40 klbs. PU at 58 klbs. PU until clean. RIH 11423', stacking out with no motor work. PU at 56 klbs. Pull up hole 100'. Attempt to ream back to bottom. 14:00 - 14:30 0.50 DRILL P PROD1 Resume drilling. INC=98 deg. Trying to drill up out of the Kavik. Free spin 2530 psi at 2.5 bpm. Drilling at 2.5/2.5/2630 psi. Taking on new mud. IAP=420 psi, OAP=280 psi. 14:30 - 15:45 1.25 DRILL P PROD1 Con/ir with town. Shales in the heel are bad and will probably get worse. Plan forward is to drill straight up and get a pilot hole thru the target sand, then set and OH whipstock to sidetrack, and avoid the Kavik altogether. Continue drilling ahead. 15:45 - 16:35 0.83 DRILL P PROD1 Stacking weight, and can't drill. PU at 60 klbs. Wiper trip to window. Motor work as we ream the last 50' to bottom. 16:35 - 19:00 2.42 DRILL P PROD1 Resume drilling. Encounter "clean sand" at +/-11600' 19:00 - 21 :00 2.00 STWHIP C PROD1 POOH to pick up aluminum billet assembly. Hold PJSM with crew prior to reaching surface. 21 :00 - 22:00 1.00 STWHIP C PROD1 LD motor & bit. MU Weatherford WS assembly. 22:00 - 00:00 2.00 STWHIP C PROD1 RIH. 5/26/2004 00:00 - 00:30 0.50 STWHIP C PROD1 Continue to RIH with billet. Continue to revise directional plan with geo & DD. 00:30 - 00:50 0.33 STWHIP C PROD1 Log gr tie in from 10920'. Subtract 19' correction. 00:50 - 01 :30 0.67 STWHIP C PROD1 RIH to 11130'. Through window smooth, slight bobble. 43k# up, 16k# dn wt. Stop with top of billet at 11115'. Close EDC and pressure up to 4350 psi. Set down 3K#. Seems to be set. Pull up, no over pull. 01 :30 - 03:30 2.00 STWHIP C PROD1 POOH, circulating through EDC. 03:30 - 04:30 1.00 STWHIP C PROD1 LD BHA. Recovered all running tools etc. 04:30 - 06:30 2.00 STWHIP X DFAL PROD1 MU sidetrack assembly. Trouble shoot comms problem with mwd at surface. 06:30 - 07:00 0.50 STWHIP C PROD1 COMS problems resolved, MU BHA #7. 2.70 deg motor, Hughes R335C bit, to sidetrack off of OH whipstock. 07:00 - 09:10 2.17 STWHIP C PROD1 RIH with BHA #7. Printed: 6/7/2004 9:02:35 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 5/26/2004 09: 1 0 - 09:35 0.42 STWHIP C PROD1 09:35 - 10:00 0.42 STWHIP C PROD1 10:00 - 10:40 0.67 STWHIP C PROD1 10:40 - 10:55 0.25 STWHIP C PROD1 10:55 - 11 :35 0.67 STWHIP C PROD1 11 :35 - 12:00 0.42 STWHIP C PROD1 12:00-14:10 2.17 STWHIP C PROD1 14:10 - 15:00 0.83 STWHIP C PROD1 15:00 - 17:00 2.00 STWHIP C PROD1 17:00 - 17:20 0.33 STWHIP C PROD1 17:20 - 21 :30 4.17 STWHIP C PROD1 21 :30 - 23:30 2.00 STWHIP C PROD1 23:30 - 00:00 0.50 STWHIP C PROD1 5/27/2004 00:00 - 00:45 0.75 STWHIP C PROD1 00:45 - 02:45 2.00 STWHIP C PROD1 02:45 - 03: 15 0.50 STWHIP C PROD1 03:15 - 04:15 1.00 STWHIP X DFAL PROD1 04:15 - 06:00 1.75 STWHIP X DFAL PROD1 06:00 - 07: 15 1.25 STWHIP X DFAL PROD1 07:15 - 09:10 1.92 STWHIP X DFAL PROD1 09: 10 - 09:25 0.25 STWHIP X DFAL PROD1 09:25 - 11 :15 1.83 STWHIP X DPRB PROD1 11 : 15 - 12:30 1.25 STWHIP X DPRB PROD1 12:30 - 15:00 2.50 STWHIP C PROD1 15:00 - 15:40 0.67 STWHIP C PROD1 Log time in pass down from 10940'. Make -21' correction. Tag top of WS at 11118.5' with pumps on. PU, RIH to 11118'. Begin time milling from here at TF=60R, 6 fph. Continue drilling off the whipstock to sidetrack the well at 6 fph. TF=55R. Appear to be off whipstock. Begin drilling ahead 15-20 fph. Free spin 2730 psi at 2.65 bpm. Drilling at 2.65/2.7/3000 psi. Pit vol=420 bbls. IAP=320 psi, OAP=338 psi. TF=45R. Drill ahead 70 fph. 2.7/2.7/2900 psi. MWD confirms we are off the whipstock, and have a new hole. Backream whipstock at 0 deg TF to open up hole. Dry drift down thru whipstock with no problems. POOH to change bit to a 4.125" bi center. Tag up at surface with BHA #7. Stand back injector. Swap out R335C bit for a Hughes bicenter. Recovered R335C bit recovered 2,1, Chipped. RIH with BHA #8, Hughes bi center bit and 2.7 deg motor to finish build section. Log tie in pass, make -19' correction. RIH smooth thru the whipstock. Tag bottom and resume drilling the build section. 2.6/2.6/3100 psi. Free spin 2790 psi at 2.6 bpm. Drill to 11350'. ECD: 10.4 ppg. POOH for planned motor angle change. At surface. Get off well. Unstab coil. Change out bit and lower motor AKO to 1.5 deg. Bit cored out, 8 broken cutters on nose and reamer blades. Stab coil. Get on well. RIH Log gr tie in from 10930'. Subtract 18' correction. Lost signal from mwd DGS tool. Unable to get GR or directional info. Trouble shoot same. Clean up shale from 11220' to 11260' while truble shooting tools. Hole very sticky. Over pulls up to 80k# at 11250'. POOH to repair mwd tools. Tag up at surface. Stand back injector, lay down BHA #8. Troubleshoot DGS tool. Fix problem. Make BHA Back up. RIH with BHA #10, 1.5 deg AKO, and Hycalog bicenter bit. Log tie in pass down over GR charecter at 10940'. Make -21' correction. RIH thru window and OH whipstock with no problems. IAP=200 psi, OAP=293 psi. Pit vol=406 bbls. RIH to 11250', back ream to 11130'. Motor work in shales while backreaming. Continue taking 20' bites and backreaming to clean up shale. Continue trying to clean up hole. Seeing motor work in shales from 11240-11246, 11256', 11282', 11323'. Hard tag at 11323', and we have not been deeper than this depth as yet. Tight spots are better. Not perfect, but reasonably clean. Tag bottom and begin drilling. Free spin 2760 psi at 2.6 bpm. Drilling at 2.6/2.6/ 3000 psi. Pit vol=399 bbls. Wiper trip to shoe. Overpull at 11360'. Overpull and motor work at 11312', 11296', 11260'. Clean thru the open hole sidetrack, and the rest of the way to the window. Clean back to bottom! Printed: 6/7/2004 9:02:35 AM It Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 5/27/2004 15:40 - 18:00 2.33 STWHIP C PROD1 Resume drilling. 2.5/2.5/3180 psi. Pit vol=397 bbls. IAP=504 psi, OAP=320 psi. 18:00 - 18:40 0.67 STWHIP C PROD1 Short trip to window. Some tight spots from 11360' to 11220'. Hole seems to have cleaned up, but will increase frequency of short trips to monitor shales closely. 18:40 - 22:00 3.33 DRILL P PROD1 Drilling ahead. 2975 psi @ 2.53 bpm in/out. 2700 dpsi fs. 2K-3K# WOB ROP:50-70 fph. ECD: 10.55 ppg. Start new mud down hole at 1930 hrs. 22:00 - 22:50 0.83 DRILL P PROD1 Wiper trip to window. Hole cleaning up nicely from 11220 to 11360'. No sign of billet, shuting down pumps when passing billet both in and out of hole. 22:50 - 00:00 1.17 DRILL P PROD1 Drilling ahead. 2950 psi @ 2.57 bpm in/out. 2600 dpsi fs. 2K-3K# WOB ROP:50-70 fph. ECD: 10.4 ppg. Not much change in pump pressures with new mud around. 5/28/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drilling ahead. 2950 psi @ 2.57 bpm in/out. 2600 dpsi fs. 2K-3K# WOB ROP:50-70 fph. ECD: 10.4 ppg 00:30 - 02: 15 1.75 DRILL P PROD1 Wiper trip to window. 10k# over pull at 11365. Smaller over pulls up to 11224. Some mtr work from 11224' to 11200'. Smooth running in hole. 02:15 - 04:15 2.00 DRILL P PROD1 Drilling ahead. 3050 psi @ 2.51 bpm in/out. 2730 dpsi fs. 2K-3K# WOB ROP:70-100 fph. ECD: 10.5 ppg 04:15 - 06:20 2.08 DRILL P PROD1 Wiper trip to window. Clean up and down. No problems. 06:20 - 08:15 1.92 DRILL P PROD1 Resume drillng. Free spin 3050 @ 2.7 bpm. 08:15 - 09:45 1.50 DRILL P PROD1 Clean PU off bottom, thru the shales and OH sidetrack. 09:45 - 10:05 0.33 DRILL P PROD1 Log tie in pass. Made a + 12' correction. 10:05 - 10:55 0.83 DRILL P PROD1 Continue wiper trip back in hole. No problems at OH whipstock or shales in the heel of well. 10:55 - 11 :45 0.83 DRILL P PROD1 Resume drilling. Free spin=2800 psi at 2.6 bpm. Drilling at 2.6/2.6/3200 psi. Pit vol=356 bbls. IAP=475 psi, OAP=292 psi. ECD=10.57 ppg, (4730 psi). TF=75R, INC 87 deg. 11:45 -12:15 0.50 DRILL N DPRB PROD1 Getting differentially stuck. Saw loss of motor work and loss of weight as we drilled ahead. Attempt to pick up with pumps on. Pull 74 klbs. Can't get free. SD pumps and attempt the "relax" method. Wait 15 mintues at neutral wt, pull 80 klbs. Still stuck. Wait 15 more minutes with stacked weight. Picked up to 85 klbs, and popped free. 12:15 - 13:15 1.00 DRILL P PROD1 Maker short wiper up to 11500' to condition hole. Back smooth to bottom. 13:15 -15:40 2.42 DRILL P PROD1 Resume drilling. Constant differential sticking. Having to be very careful to keep BHA moving. Free spin 2790 psi at 2.6 bpm. Drilling at 2.6/2.6/3200 15:40 - 16:35 0.92 DRILL P PROD1 ROP has improved a bit, so our differential sticking has gotten somewhat better. Drilling at 50 fph with only 2000 Ibs string weight. Swap to clean 40 bbls of new mud in pill pit to see if it improves weight transfer. 16:35 - 18:30 1.92 DRILL P PROD1 Wiper trip to shoe. Clean PU off bottom at 50 klbs. ECD 10.55 ppg, 4727 psi. Very slow drilling. Continue to stack out after PU off bt. Start new mud down hole. 18:30 - 21 :00 2.50 DRILL P PROD1 Drilling ahead. 3500 psi @ 2.70 bpm in/out. 3100 dpsi fs. 4K-5K# WOB ROP:70-100 fph. ECD: 10.6 ppg. Drilling improved greatly with new mud around. 21 :00 - 21 :45 0.75 DRILL P PROD1 Wiper trip to window. Stuck at 12365' for 15 minutes (near Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 5/28/2004 21 :00 - 21 :45 0.75 DRILL P PROD1 fault). Continued to CBU before resting hole. Popped free after orienting. A few minor tight spots from 11350' to 11220'. 21 :45 - 22:00 0.25 DRILL P PROD1 Log gr tie in from 10930'. Add 12' correction. 22:00 - 22:30 0.50 DRILL P PROD1 RIH. Smooth going in hole. 22:30 - 00:00 1.50 DRILL P PROD1 Drilling ahead. Excellent weight transfer after wiper trip & new mud. ROP 100 fph +. 5/29/2004 00:00 - 00:45 0.75 DRILL P PROD1 Drilling ahead. 3500 psi @ 2.70 bpm in/2.200ut. 3100 dpsi fs. WOB: 2-3K# ROP:70-100 fph. ECD: 10.6 ppg. Drilling very clean sand, hope partial losses are tempory. Ops cab computer locked up. 00:45 - 03:00 2.25 DRILL P PROD1 Order more mud. Short trip to inside window to shut down and re-boot ops cab computer. Hve lost 65 bbls in 90 minutes. 03:00 - 04:00 1.00 DRILL P PROD1 Drilling ahead. 3650 psi @ 2.43 bpm in/1.90 out. 3100 dpsi fs. WOB: 4-5K# ROP:80-120 fph. ECD: 10.55 ppg. Drilling in clean sand. Losses remain at 0.5 bpm. 04:00 - 05:00 1.00 DRILL P PROD1 Lose all returns. Still waiting on mud from MI. Reduce rate to 1 bpm. POOH at 30 fpm. Mud on location (290 bbls). Head back in hole to drill ahead. 05:00 - 06:10 1.17 DRILL P PROD1 Drilling ahead. 3060 psi @ 2.47 bpm in/ 0.4 out. 2700 dpsi fs. WOB: 4-5K# ROP:80-120 fph. ECD: 10.17 ppg. 06:10 - 07:25 1.25 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 47 klbs. IAP=65 psi, OAP=280 psi, Pit vol=190 bbls. 2.47/0.73/2600 psi. ECD=10.26 psi, 4592 psi. Round tripping vac truck to keep the hole full. No overpulls or ratty hole on wiper trip up to the window. 07:25 - 07:50 0.42 DRILL P PROD1 Log tie in pass. Make -5' correction. 07:50 - 08:55 1.08 DRILL P PROD1 Continue wiper back in the hole. No problems on trip back in hole. The hole is in good shape. 12650', Started seeing increased returns momentarily. Might have been washing some cuttings down to the loss zone. 08:55 - 12:15 3.33 DRILL P PROD1 Resume drilling. Free spin 2747 psi at 2.65 bpm. Drilling at 2.62/0.95/3250 psi. Pit volume=250 bbls. ROP=100 fph. 12:15 - 13:20 1.08 DRILL P PROD1 Geo has called this TD. Wiper trip to window to condition hole and tie in. 13:20 - 13:35 0.25 DRILL P PROD1 Log tie in point. Make a +4' correction. 13:35 - 14:40 1.08 DRILL P PROD1 Continue wiper trip back in hole. Returns improving as we head back in. 2.6/1.5/2780 psi. (Pipe displacement?) Clean thru shale in toe of well. No motor work or weight loss. Check returns on bottom with pipe stationary. 2.6/1.44/2770 psi. 14:40 - 15:10 0.50 DRILL P PROD1 Tag TD at corrected depth of 12956'. POOH. Pickup clean at 45 klbs. No problems in lower shale. Had some drag at 12380', and a slight amount of motor work. First time we have seen anything at this depth recently. 15:10-15:30 0.33 DRILL P PROD1 Ream shale at 12380'. 15:30 - 15:50 0.33 DRILL P PROD1 RIH all the way back to TD. 15:50 - 19:00 3.17 DRILL P PROD1 POOH. Clean PU off bottom at 45 klbs. Weight bobbles, but no motor work at 12350', continue POOH, clean to window. POOH pumping all the way. 2.65/1.3/2790 psi. Continuing to round trip vac trucks to keep the hole full. Shut down circ at 1000' to leave void for liner displacement. 19:00 - 20:30 1.50 RUNCO RUNCMP RU SLB N2 unit. Hold PJSM with crews. Blow down coil with nitrogen. Take returns to tiger tank. 20:30 - 23:00 2.50 RUNCO RUNCMP Prep to remove e-coil reel. Unstab coil and secure on reel. Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 5/20/2004 6/2/2004 Spud Date: 5/20/2004 End: 6/2/2004 Start: Rig Release: Rig Number: 0.33 Release reel from mounts. Lower reel on to trailer. Fill hole. Function BOP rams. Install completion reel. RU floor to mu liner. Prep safety floor valve. Fill hole. Took +/- 10 bbls. PJSM with crews to discuss handling liner. MU 2-7/8" liner assy (32 jts). Change elevators & slip dies. Fill back side and liner with KCL water. MU hard line inside reel. MU 3-3/16" liner ( 29 jts). All liner in the hole. Fill backside, took 8 bbls. Fill liner. Hold PJSM with day tour to discuss well control and stabbing pipe. PU BTT 3-1/2" pup joints and deployment sleeve. Hang in slips. Lay down elevators. Pick up injector and position over hole on legs. Stab coil into injector using stabbing line. Change out packoffs, MU CTC. Pull test CTC to 35 klbs. Pump 2 bbls of mud into the reel. Launch a dart. Chase with mud. Land dart at 53.5 bbls. Remove CTC, retrieve dart. There was a very small amount of rust particles along with dart. Circulate an additional coil vol. PT coil connector to 3500 psi. 5/30/2004 01 :00 - 01 :15 0.25 RUNCMP 01:15-04:45 3.50 RUNCMP 04:45 - 06:30 1.75 RUNCMP 06:30 - 07:00 0.50 RUNCMP 07:00 - 08:00 1.00 RUNCMP 08:00 - 10:00 2.00 RUNCMP 10:00 - 11 :20 RUNCMP 11 :20 - 11 :40 11 :40 - 14:05 14:05 - 14:45 14:45 - 16:45 16:45 - 17:05 17:05 - 17:40 17:40-18:10 18:10 - 18:40 2.42 RUNCMP Bleed off coil pressure. Make up coil to liner BHA. Make up injector. RUNCMP RIH with BHA #11, 2-7/8" x 3-3/16" liner. Weight check at the window = 45 klbs. Continue RIH. Slick thru window and OH whipstock. Slick to 12121', tagged up. PU, bring pumps up to 1 bpm, RIH and got thru. Slick to 12650', ratty to 12766', tagged up, PU and fell thru. Ratty to TD. Tagged up at 12976' CTM. (Typical correction has been -20', which would put us on depth at 12956'.) RUNCMP PU to drop 5/8" ball to release from liner at 62 klbs. Chase with mud. Run back to TD ok. Ball on seat at 45.8 bbls away. (Coil vol=53.5). Good indication of shear at 3944 psi. PU at 27 klbs, confirming liner released. RUNCMP Swap to 4% KCL brine and circulate well out. Pumping brine initially at 2.87/1.22/2200 psi. Returns improved to 2.9/1.8/2430 psi at end of circ out. Possibly due to reduced ECD's with brine. RUNCMP Safety meeting prior to pumping cement. RUNCMP Circulate while waiting for cementers to get up to weight. RUNCMP Cement up to weight at 17:40. Down on pumps. Line up to cementers. Pump 2 bbls of water. PT cementers hard lines to 4000 psi. Passed ok. On line with cement. 3.0/1.6/1800 psi. Pumping 15.8 ppg class G as per proceedure. 4:30 hrs thickening time. Pump 38.8 bbls, shut down and launch dart. RUNCMP Displace cement at 3.05 bpm @ 750 psi with 2# biozan. Caught cement after 16 bbls. Dart landed at 53.7 bbls (53.5 calc). Sheared at 3450 psi (pinned for 2800). Plug bumped at 66.8 bbls @ 1100 psi (66.6 calc). Bleed back to 500 psi. Unsting. 39K# up wt. CI P at 1840. Pumped 38.8 bbls of cement. Calculated hole vol +40%=23.5 bbls. Got back 26.7 bbls of cement. Lost 12.1 bbls of cement to formation. 0.33 0.58 0.50 Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 Got 3.2 bbls of cement over top of liner. POOH laying in biozan, coil voidage only. 45 fpm @ 0.25 bpm. Pit vol is 125 bbls at start of trip out of hole. Hole staying full at this rate & pipe speed. Lost track of exact hole fill due to problems with fluid transfers in pits while POOH. Estimate we lost 2-4 bbls while POOH. 21:30 - 22:15 RUNCMP At surface. Get off well. Unstab from coil. LD liner running tools. Mix 1.5# biozan clean out pill, and 1.5# flo pro pill for perfing. 22:15 - 23:00 0.75 RUNCMP MU CNUGR clean out assembly including two joints of CSH between motor & logging tools. 23:00 - 23:15 0.25 RUNCMP Hold PJSM with SLB & Nordic crews. Discuss roles & responsibilties, assignments, source control, logging procedure. 23:15 - 00:00 0.75 RUNCMP Continue to MU logging/FCO BHA. PU 54 single 1.25" CSH from pipe shed. Drift while picking up. 5/31/2004 00:00 - 03:00 3.00 RUNCMP Continue to MU CSH with CNUGR and FCO clean out assembly. Stab coil. Get on well. 03:00 - 05:00 2.00 RUNCMP RIH. Mix 75 bbls 1 # biozan. Pump bio down coil at 1.0 bpm. 05:00 - 06:30 1.50 RUNCMP Begin logging down pass from 10800'. Take weight at 11191 '. Hitting cement. Logging pass aborted. Mill ahead at varying ROP's 1950 psi @ 1.67 bpm. 42k# up, 15k# dn wt. 06:30 - 07: 15 RUNCMP Tagged hard bottom at 12941 '. Expected landing collar depth was 12920'. Typical correction for this well has been -20', so we appear to exactly on depth. Begin logging pass up at 60 fpm, 0.5 bpm. 07: 15 - 07:35 0.33 RUNCMP Log down at 30 fpm, 0.5 bpm pump rate. 07:35 - 09:30 1.92 RUNCMP Pin hole at 11127'. Abort further logging. SD pumps, fill across the hole POOH. Total running footage on this reel 435,234'. Coil life at pinhole was 35%. 09:30 - 09:45 RUNCMP Safety meeting while POOH to discuss mazards and mitigation of tripping drillpipe. 09:45 - 10:00 0.25 RUNCO RUNCMP Tag up at surface, stand back injector. 10:00 - 11 :45 1.75 RUNCO RUNCMP Trip OOH, standing back 1-1/4" CS Hydril work string. 11 :45 - 12:00 0.25 RUNCO RUNCMP Safety meeting prior to laying out SWS radioactive source. 12:00 - 12:30 0.50 RUNCO RUNCMP Lay down SWS memory logging tools. 12:30 - 13:00 0.50 RUNCO DFAL RUNCMP Safety meeting prior to pumping nitrogen. 13:00 - 14:40 1.92 RUNCO DFAL RUNCMP Pump N2 to blow down reel. Take returns to pits. 14:40 - 16:30 1.83 RUNCO DFAL RUNCMP Unstab injector. Unstab coil and secure to reel. 16:30 - 18:30 2.00 RUNCO DFAL RUNCMP Remove pin holed reel from rig. Lift replacement reel and secure. Bushings ok. 18:30 - 20:30 2.00 DFAL RUNCMP Unsecure coil from reel. Pull across pipe shed with tugger. Stab coil into injector. 20:30 - 22:00 1.50 RUNCMP Pressure tbg to 1500 psi. Pressure IA to 750 psi. Pressure tbg to 1750 and bled off to 1350 in 5 minutes. Lap not holding. Initial test to 2000 psi was performed with master valve closed - invalid test. 22:00 - 00:00 2.00 RUNCMP MU 50 perf guns on 32 jts 1.25" CSH. (2.125" HSD 6 spf PJ006) 6/1/2004 00:00 - 03:30 3.50 RUNCMP Continue to MU 50 2" perf guns on 32 jts CSH pipe. Stab coil. Get on well. 03:30 - 06:00 2.50 RUNCMP RIH with perf assy. 52k# up, 17k# dn wt at top of liner Printed: 6/7/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 07:30 - 10:15 RUNCMP 10:15 -11:15 1.00 RUNCMP 11: 15 - 11 :30 0.25 RUNCMP 11 :30 - 12:30 1.00 WAIT RUNCMP 12:30 - 16:30 4.00 RUNCMP 16:30 - 18:30 2.00 RUNCO RUNCMP 18:30 - 20:15 1.75 RUNCO RUNCMP 20:15 - 20:35 0.33 RUNCO RUNCMP 20:35 - 22:45 2.17 RUNCO RUNCMP (10,960') Tag bottom at 12925'. ELM PBTD=12918'. PU, set depth at pickup at 12918'. PU with pumps down at weight=62 klbs. Pump 10 bbls of flopro, drop 5/8" ball to fire guns. Chase with 10 bbls of flopro, then KCL. Confirmed ball rolling. Reposition coil l' below firing depth. Pumping at 2.5/2.5/2240 psi. Pump ball on seat at 1 bpm, 600 psi, and 58 bbls away (Coil volume=60.9 bbls). Shoot guns with BHA moving. Heavy overpull at 74klbs overpull after firing guns. Overpull improved as we came up hole. IAP=940 psi, OAP=334 psi. 1 for 1 returns at 1 bpm. Note SLB sonic shot detection gave a false indication of fire as we started the BHA moving. The coil "popped" just as we began moving. The shot detection indicated firing at this point. CTP was only 1000 psi at this time. We continued pumping. The pressure built up to 3200 psi, and broke over as normal indicating the guns firing. Also Note - Contaminated cement returns when circulating the ball on seat. Need to pump while POH after setting liner top packer to clean hole. POOH with perf guns. Lay in remainder of perf pill. Pull OOH pumping across the top holding 200 psi on the WHP with the choke. 1 for 1 returns while POOH. Tag up, stand back injector. Trip OOH with 1-1/4" CS hydril work string. Safety meeting to discuss laying down perf guns. SLB does not have the proper PU elevators on location. Wait while SLB hand goes to PU proper elevators for laying down guns. It is at a job on another rig. LD perf guns. All shots fired. Pressured up blanks really slow down operation. Perforated 11855-12055' 12100-12170' 12195-12245' 12325-12405' 12445-12495' 12585-12635' 12700-12880' w/ SWS PJ guns at 6 spf MU Baker liner top pkr running assembly. Load out perf guns from pipe shed. RIH w/ L TP assy to 10800' 51k wo pump, 15k RIH Tag TOL at 10971' and see press incr. RIH to set down at 10976.5'. Stack 10k to 10980.5'. Bleed off 230 psi. PUH and PU wt 53k at 10971.1'. PUH to ball drop Load 518" steel ball and circ to seat 2.1/900 at 51.3 bbls. Bleed off 100 psi. RI H 15k and see TOL at 10972'. Set down at 10977', stack 10k at 10980'. PUH to 54k at 10970.4' then park 2' above at 10968.5' 45k. Pressure up to set packer at 2100 psi. Stack 10k to 10977.5'. PU to 50k at 10969.6'. IA 860, OA 320. Pressure BS to 2000 psi w/ 2058 psi on CT. Printed: Sn/2004 9:02:35 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-07 L2-07 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/20/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/20/2004 End: 6/2/2004 22:45 - 00:00 1.25 RUNCO Initial press WHP 1985, IA 980, OA 330, CTP 2250 After 30 min WHP 1760, IA 910, OA 292 After 40 min WHP 1655, IA 895, OA 284, CTP 2250 Discuss. Found a small leak on packoff. Repressure BS to 2000 psi Initial WHP 1990, IA 916, OA 284, CTP 2278 After 30 min WHP 1974, IA 889, OA 271, CTP 2278 Bleed off press WHP 0, IA 752, OA 271 Note: Top of LTP is at 10953.81' CTD and passed 2000 psi pressure test RUNCMP Slack off to 8k. Pressure up from 2170 psi to shear seat at 3765 psi. Slack off to 4k at 10978.2'. PUH and released at 58k. POOH jetting 2.6/1500 and dump 100 bbls KCUcement returns Fin POOH w/ L TP setting tools. FP wellbore from 2000' w/ MeOH LD/load out L TP tools CDL (50') ND BOPE while fin vac pits. NU tree cap and PT @ 5000 General preps to move (time allowed to move rig mats) RREL at 0500 hrs 6/2/04 6/2/2004 00:00 - 01 :00 1.00 P RUNCMP 01 :00 - 01 :30 0.50 RUNCO RUNCMP 01 :30 - 02:30 1.00 BOPSU P RUNCMP 02:30 - 04:00 1.50 BOPSU P RUNCMP 04:00 - 05:00 1.00 RIGD P POST Printed: Sn/2004 9:02:35 AM tit e --= oos,Q Obp BP-GDB Baker Hughes INTEQ Survey Report Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-07 Slot Name: 07 L2-07 Well Position: +N/-S 5715.56 ft Northing: 5963211.65 ft Latitude: 70 18 14.250 N +E/-W 3666.75 ft Easting : 692843.82 ft Longitude: 148 26 15.842 W Position Uncertainty: 0.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-07APB1 11117.73 ft Mean Sea Level 25.37 deg 80.88 deg Direction deg 256.00 Wellpath: L2-07A 500292291001 Current Datum: L2-07:39.3 (Doyon 16) Magnetic Data: 5/19/2004 Field Strength: 57602 nT Vertical Section: Depth From (TVO) ft 27.50 Height 39.30 ft Survey Program for Definitive Wellpath Date: 6/23/2004 Validated: Yes Actual From To Survey ft ft 180.03 4366.93 4516.64 11029.49 11035.00 11114.08 11117.73 12956.00 Version: Toolcode 4 Tool Name 2: MWD - Standard (180.03-4366.93) (0) MWD 3: MWD + IFR [Alaska] (4516.64-11572.00NØYD+IFRAK MWD (11035.00-11700.00) (2) MWD MWD (11117.73-12956.00) MWD MWD - Standard MWD + IFR [Alaska] MWD - Standard MWD - Standard Annotation 11114.08 11117.73 12956.00 8581.89 8584.41 8656.43 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 5/29/2004 Engineer: Tied-to: From: Definitive Path It BP-GDB Baker Hughes INTEQ Survey Report e ... ..... INTEQ Obp 11114.08 45.85 255.69 8581.89 8542.59 4633.08 -4415.21 5967729.60 688311.39 3163.21 0.00 11117.73 46.43 254.49 8584.41 8545.11 4632.40 -4417.75 5967728.86 688308.87 3165.85 28.54 11132.74 50.72 258.00 8594.35 8555.05 4629.74 -4428.68 5967725.92 688298.01 3177.10 33.52 11163.10 60.23 255.01 8611.54 8572.24 4623.87 -4452.96 5967719.43 688273.89 3202.07 32.35 11189.01 66.00 250.35 8623.25 8583.95 4616.97 -4475.00 5967711.97 688252.04 3225.12 27.44 11226.28 77.09 246.85 8635.04 8595.74 4604.06 -4507.84 5967698.22 688219.54 3260.12 31.06 11251.62 83.37 242.70 8639.34 8600.04 4593.42 -4530.41 5967687.01 688197.25 3284.59 29.57 11281.74 90.44 236.48 8640.96 8601.66 4578.21 -4556.32 5967671.13 688171.74 3313.41 31.24 11312.64 91.70 230.02 8640.38 8601.08 4559.73 -4581.06 5967652.03 688147.49 3341.89 21.30 11351.59 93.95 218.59 8638.46 8599.16 4531.95 -4608.19 5967623.56 688121.08 3374.93 29.87 11389.74 94.98 214.15 8635.49 8596.19 4501.33 -4630.74 5967592.37 688099.33 3404.22 11.91 11443.08 90.08 209.53 8633.13 8593.83 4456.08 -4658.83 5967546.42 688072.41 3442.42 12.62 11477.06 88.70 216.65 8633.49 8594.19 4427.63 -4677.37 5967517.51 688054.61 3467.29 21.34 11507.86 87.50 217.85 8634.52 8595.22 4403.13 -4696.00 5967492.54 688036.61 3491.30 5.51 11539.49 85.66 223.69 8636.40 8597.10 4379.23 -4716.61 5967468.12 688016.63 3517.07 19.33 11578.09 85.64 229.04 8639.33 8600.03 4352.68 -4744.46 5967440.86 687989.47 3550.52 13.82 11608.68 86.47 233.42 8641.44 8602.14 4333.58 -4768.24 5967421.16 687966.18 3578.22 14.54 11642.38 87.78 239.78 8643.13 8603.83 4315.06 -4796.33 5967401.93 687938.59 3609.95 19.24 11662.55 87.37 242.23 8643.98 8604.68 4305.29 -4813.95 5967391.71 687921.22 3629.41 12.30 11700.80 87.37 250.20 8645.74 8606.44 4289.89 -4848.89 5967375.42 687886.69 3667.04 20.81 11729.87 86.05 253.73 8647.41 8608.11 4280.91 -4876.48 5967365.73 687859.34 3695.98 12.95 11769.37 86.38 259.31 8650.02 8610.72 4271.73 -4914.79 5967355.57 687821.28 3735.38 14.12 11805.00 87.01 268.46 8652.08 8612.78 4267.94 -4950.12 5967350.88 687786.06 3770.57 25.70 11831.76 88.26 264.22 8653.18 8613.88 4266.24 -4976.80 5967348.49 687759.44 3796.87 16.51 11862.35 88.63 264.81 8654.01 8614.71 4263.31 -5007.24 5967344.79 687729.09 3827.11 2.28 11889.29 86.32 260.38 8655.20 8615.90 4259.85 -5033.92 5967340.64 687702.50 3853.84 18.53 11912.26 86.82 259.55 8656.58 8617.28 4255.85 -5056.50 5967336.06 687680.04 3876.71 4.21 11963.11 89.86 246.16 8658.06 8618.76 4240.90 -5104.95 5967319.87 687631.99 3927.34 26.99 12003.33 87.33 249.59 8659.04 8619.74 4225.76 -5142.19 5967303.78 687595.15 3967.14 10.59 12030.10 85.64 244.67 8660.68 8621.38 4215.38 -5166.80 5967292.77 687570.82 3993.53 19.40 12051.34 85.02 244.80 8662.41 8623.11 4206.34 -5185.94 5967283.25 687551.91 4014.29 2.98 12086.77 83.11 240.73 8666.08 8626.78 4190.22 -5217.27 5967266.33 687521.01 4048.59 12.63 12121.59 85.60 244.08 8669.50 8630.20 4174.18 -5247.97 5967249.50 687490.73 4082.26 11.95 12160.59 86.46 250.58 8672.21 8632.91 4159.19 -5283.85 5967233.60 687455.25 4120.70 16.77 12194.18 86.41 256.22 8674.30 8635.00 4149.62 -5315.97 5967223.21 687423.39 4154.18 16.76 12232.54 88.33 262.32 8676.06 8636.76 4142.49 -5353.60 5967215.12 687385.96 4192.41 16.65 12265.73 88.73 267.45 8676.91 8637.61 4139.53 -5386.63 5967211.31 687353.01 4225.18 15.50 12298.25 88.88 269.86 8677.59 8638.29 4138.77 -5419.14 5967209.72 687320.54 4256.91 7.42 12335.50 94.91 270.55 8676.36 8637.06 4138.90 -5456.35 5967208.89 687283.34 4292.98 16.29 12367.50 93.75 277.73 8673.94 8634.64 4141.20 -5488.15 5967210.38 687251.49 4323.28 22.66 12401.37 91.47 283.40 8672.40 8633.10 4147.41 -5521.40 5967215.73 687218.10 4354.04 18.03 12436.13 88.29 287.46 8672.47 8633.17 4156.65 -5554.89 5967224.11 687184.38 4384.30 14.84 12462.55 87.43 284.98 8673.46 8634.16 4164.02 -5580.24 5967230.83 687158.85 4407.11 9.93 12499.19 91.19 284.69 8673.90 8634.60 4173.40 -5615.65 5967239.29 687123.22 4439.20 10.29 12535.07 94.97 280.44 8671.97 8632.67 4181.20 -5650.61 5967246.19 687088.08 4471.23 15.84 12567.74 93.90 276.41 8669.44 8630.14 4185.97 -5682.82 5967250.13 687055.75 4501.34 12.73 12599.01 94.52 270.42 8667.14 8627.84 4187.82 -5713.93 5967251.19 687024.60 4531.08 19.21 12630.13 95.52 266.07 8664.42 8625.12 4186.88 -5744.91 5967249.44 686993.66 4561.37 14.29 12671.57 91.61 263.50 8661.84 8622.54 4183.12 -5786.09 5967244.63 686952.59 4602.23 11.28 12713.54 89.28 265.17 8661.52 8622.22 4178.97 -5827.85 5967239.42 686910.96 4643.75 6.83 12742.87 87.72 268.83 8662.28 8622.98 4177.44 -5857.12 5967237.13 686881.73 4672.53 13.56 12782.96 93.67 274.95 8661.80 8622.50 4178.76 -5897.15 5967237.42 686841.69 4711.05 21.29 12819.80 92.04 281.04 8659.96 8620.66 4183.87 -5933.57 5967241.60 686805.15 4745.15 17.09 e e ..a: INTEQ Obp BP-GDB Baker Hughes INTEQ Survey Report 12851.61 90.88 288.06 8659.15 8619.85 4191.86 -5964.33 5967248.79 686774.20 4773.06 22.36 12883.25 92.10 283.50 8658.33 8619.03 4200.46 -5994.76 5967256.61 686743.56 4800.50 14.91 12917.87 91.30 275.75 8657.30 8618.00 4206.24 -6028.85 5967261.51 686709.34 4832.18 22.49 12956.00 91.30 275.75 8656.43 8617.13 4210.06 -6066.78 5967264.36 686671.32 4868.06 0.00 Survey: MWD (L2-071l2-07A) Created By: Digital Business CHent UserDate: 7/1/2004 BP Amoco WELLPATH DETAILS L2.o7A 500292291001 Parent Wellpath: L2.o7APB1 Tie on MD: 11117.73 Rig: Nordic 2 Ref. Datum: L2-07:39.3 (Doyon 16) 39.3011 V.Section Origin Origin Starting Anglo +NI·S +EJ·W From TVD 256.00° 0.00 0.00 21.50 REFERENCE INFORMATION e BP-GDB Baker Hughes INTEQ Survey Report e ..IC INTRQ Obp Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 GeoDatum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Lon~tude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-07 Slot Name: 07 L2-07 Well Position: +N/-S 5715.56 ft Northing: 5963211.65 ft Latitude: 70 18 14.250 N +E/-W 3666.75 ft Easting : 692843.82 ft Longitude: 148 26 15.842 W Position Uncertainty: 0.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-07 11035.00 ft Mean Sea Level 25.37 deg 80.88 deg Direction deg 311.66 Wellpath: L2-07APB1 500292291070 Current Datum: L2-07:39.3 (Doyon 16) Magnetic Data: 5/19/2004 Field Strength: 57602 nT Vertical Section: Depth From (TVD) ft 27.50 Height 39.30 ft Survey Program for Definitive Wellpath Date: 6/23/2004 Validated: Yes Actual From To Survey ft ft 180.03 4366.93 4516.64 11029.49 11035.00 11700.00 Version: Toolcode Tool Name 2: MWD - Standard (180.03-4366.93) (0) MWD 3: MWD + IFR [Alaska] (4516.64-11572.00NU)'D+IFR:AK MWD (11035.00-11700.00) MWD MWD - Standard MWD + IFR [Alaska] MWD - Standard Annotation Survey: MWD CoilT rak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 5/25/2004 Engineer: Tied-to: From: Definitive Path e Obp BP-GDB Baker Hughes INTEQ Survey Report e -. !fI1JI. 11029.49 28.86 286.50 8514.14 8474.84 4632.60 -4366.03 5967730.39 688360.57 6341.16 0.00 11035.00 29.45 286.02 8518.95 8479.65 4633.35 -4368.61 5967731.08 688357.97 6343.58 11.51 11051.69 31.26 284.30 8533.35 8494.05 4635.56 -4376.75 5967733.07 688349.78 6351.13 12.03 11082.95 39.23 265.00 8558.94 8519.64 4636.70 -4394.54 5967733.76 688331.97 6365.18 43.56 11114.08 45.85 255.69 8581.89 8542.59 4633.08 -4415.21 5967729.60 688311.39 6378.22 29.30 11152.04 52.45 244.30 8606.75 8567.45 4623.16 -4442.04 5967719.00 688284.82 6391.67 28.55 11188.50 63.56 240.02 8626.04 8586.74 4608.68 -4469.30 5967703.83 688257.95 6402.42 32.05 11223.25 71.85 229.68 8639.24 8599.94 4590.15 -4495.47 5967684.63 688232.26 6409.65 36.40 11250.83 73.96 219.65 8647.37 8608.07 4571.42 -4513.96 5967665.43 688214.26 6411.02 35.59 11277.95 77.44 214.36 8654.07 8614.77 4550.44 -4529.77 5967644.06 688199.00 6408.88 22.84 11326.05 80.67 188.58 8663.36 8624.06 4506.87 -4546.84 5967600.07 688183.06 6392.68 53.02 11356.30 85.63 186.28 8666.96 8627.66 4477.10 -4550.72 5967570.21 688179.94 6375.79 18.05 11383.61 87.28 190.15 8668.65 8629.35 4450.13 -4554.61 5967543.15 688176.74 6360.78 15.38 11414.15 88.60 194.74 8669.75 8630.45 4420.33 -4561.19 5967513.20 688170.93 6345.89 15.63 11444.79 90.44 199.29 8670.01 8630.71 4391.05 -4570.15 5967483.69 688162.73 6333.12 16.02 11474.18 95.49 202.25 8668.49 8629.19 4363.61 -4580.55 5967456.00 688153.03 6322.66 19.91 11504.00 97.66 203.89 8665.07 8625.77 4336.36 -4592.16 5967428.46 688142.13 6313.22 9.10 11549.54 97.58 209.92 8659.03 8619.73 4296.13 -4612.57 5967387.72 688122.75 6301.73 13.13 11607.99 104.64 219.48 8647.75 8608.45 4249.03 -4645.12 5967339.80 688091.43 6294.74 20.08 11637.24 107.79 223.12 8639.58 8600.28 4227.93 -4663.64 5967318.24 688073.46 6294.56 16.08 11659.37 109.22 225.04 8632.55 8593.25 4212.86 -4678.24 5967302.79 688059.25 6295.44 10.46 11700.00 109.22 225.04 8619.18 8579.88 4185.75 -4705.39 5967275.00 688032.81 6297.71 0.00 Survey: MWD (L2-o7lL2~07A) Created By: Digita! Busíness CHent UserOate; 7/112004 l2~07,L2~07A,P¡al1 l2~07 (L2-07) L2-Q7 (L2~07APB1) L2-07A MWD BP Amoco WELLPAm DETAilS L2'(1A 500292291001 NordÎc2 Ref. L2'(7:39.3 {Doyon V,Section Origin Origin S Angle +I"'·S +EI·W F 256.00· 0.00 0.00 27.50 REFERENCE INFORMATION "NO TREE = WB..U-EAO = A crUA TOR = KB. ELEV = BF. ELEV- KOP- Max An Ie = Oatum MO = OatumTVO = 4-1/16" OW FMC BAKERC 39.3' L2-07A 1985' 12630' 4893' 8800' SS 2170' 4-1/2"CAMCOBAL-OSSSV NP, 10- 3.813" . 9-518" CSG, 40#, L-BO, 10 = 8.835" I Minimum ID = 2.372" @ 10954' 3.7" BKR KB LNR TOP PKR ST MO 1 4088 2 7758 3 10401 TVO 3498 6094 7958 GAS LIFT MA NORELS OEV TYPE VL V LA T01 44 KBG2LS DOME INT 45 KBG2LS SO INT 34 KBG2LS DllAY INT PORT OA TE 16 06108/04 24 06108/04 o 1 0550' T' X 4-1/2" BAKERS-3 PKR, 10 = 3.958" I 10583' 4-112" HES X NIP, 10 = 3.813" 2-7/8" LNR, 6.5#, L-BO, .0058 bpf, D = 2.441" T' X 4-1/2" BKRZXP A<R, 10 = 4.375" 7" CSG, 26#, L-80, 10 = 6.276" 4-112" WLEG, D =3.958"1 5" x 4-1/2" XO 4-1/2" 1BG, 12.6#, L-BO, .0152 bpf, D =3.958" ELMO NOT LOGGEO ÆRFORA TON SUMV1ARY REF LOG: ANGLE AT TOP PERF: 88@11855' Note: Refer to Production OB for hstorical perf data SIZE SA" INTERVAL Opn/Sqz OATE 2" 6 11855 - 12055 0 05/31/04 2" 6 12100 - 12170 0 05/31/04 2" 6 12195 - 12245 0 05/31/04 2" 6 12325 - 12405 0 05/31/04 2" 6 12445 - 12495 0 05/31/04 2" 6 12585 - 12635 0 05/31/04 2" 6 12700 - 128BO 0 05/31/04 10961' 3.7" BKROEA...OYrvENTSLV, D -3.0" 10980' 3-1/2" HES X NIP, 10 = 2.812" 10991' 3-1/2"X 3-3/16"XO, 10= 2.786" I 1 MLLOUTWNOOW 11035'-11041' -1 3-3116" X 2-718" XO, 10 = 2.372" 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.953" 11556' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" OA TE REV BY 12/11/98 06/02/04 JLM/KA 06/08/04 JLJ/KAK co MV18\JTS ORIGINAL COMPLETION CTDSIDETRACK L2-07A GL V C/O DA1E REV BY COMrvENTS PRLDI-OE BA Y UNIT WELL: L2-07 A PERfv11T No: 2040530 A A No: 50-029-22910-01 SEC18, T11N, R15E, 3511.01' FB.. &4478.57' FNL BP Exploration (Alaska) . [ill . 11 L FRANK H. MURKOWSKI, GOVERNOR A.,ASIiA. OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay L2-07 A BP Exploration (Alaska) Inc. Permit No: 204-053 Surface Location: 1315' NSL, 3802' WEL, SEC. 18, TllN, RI5E, UM Bottomhole Location: 221' NSL, 4929' WEL, SEC. 12, TIIN, RI4E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development welL This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission ·tness any required test. Contact the Commission's North Slope petroleum field ins ecto -3607 (pager). S' ce I, BY ORDERJ& THE COMMISSION DATED thi day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \AlGI\- '3/2 S/Z.OO'¡' . STATE OF ALASKA I ALAS~OIL AND GAS CONSERVATION C MMISSION PERMIT TO DRILL 20 AAC 25.005 ! Ií 1a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory II Development Oil (D Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas 0 Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 Lisburne L2-07 A /' 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 13050 TVD 8646 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028302 1315' NSL, 3802'WEL, SEC. 18, T11N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 795' NSL, 3278' WEL, SEC. 12, T11N, R14E, UM May 1, 2004 '" Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 221' NSL, 4929' WEL, SEC. 12, T11N, R14E, UM 2560 30,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 692844 y- 5963212 Zone- ASP4 (Height above GL): 39.3' feet L 1-01 is 775' away at 12250' MD 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Kickoff Depth 11015' ft Maximum Hole Angle 92 0 Downhole: 3392 psig Surface: 2512 psig 18.CøsingProgram iT._;······· ~i(c;f;_ Size /< i Q""""" Hole Casino WeiQht Grade CouplinQ LenQth MD TVD MD TVD (includino staoe data) 3-3/4" 3-3/16" x 2-7/8" 6.2# / 6.5# L-80 TCII/ STL 2080' 10970 8425' 13050' 8646' S2 sx Class 'G' 19: PRES~NTWELL·CØNDITIØN$I...!~MARY··(T()··~ Corl'lpletedfor'RedriIlANI¡)·Re:.el"ltrY ØPØ~~ti9l'1s) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): 11572 8870 None 11472 8810 None ii ·ii i:.) '.i\,·.c¡;nfflhii·, iii. 5.iZ~i i iiii .¡¡ c', '\i ~/i Structural t r 110' 20" 260 sx Arcticset (Approx.) 110' 110' 4395' 9-5/8" 350 sx PF E. 210 sx G. 1848 sx PF E, 200 sx PF c 4430' 3743' 10762' 7" 552 sx Class 'G' 10785' 8296' Production Liner 966' 4-1/2" 143 sx Class 'G' 10590' - 11556' 8123' - 8861' Perforation Depth MD (ft): 11286' - 11440' /perfOration Depth TVD (ft): 8706' - 8792' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer /~..-;? Date 7ðl/l17 Prepared By Name/Number: .."",~. 564-4378 Terrie Hubble, 564-4628 SiQnatureA ~......~ /e;e ....... / Phone ·······.i/ /0 'ii iii.·····.·..·.·.·.··.... ·.'iH·i .~.... ~I"I'~ ii' (0)::1i:: ..i/.¡··/.i' /,'(// ........... Permit To Drill API Number: Permit A~al . k I See cover letter for Number: .2ð C;; - ð. ~~ 50- 029-2291 0-01-00 Date: ';;2.c" oc/ other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required I DYes ~NO Hydr Sulfide Measures -::NYes DNo Directional Survey Required ~es D No Other: Te <; t !5D - ~SDD fJS e' , - ~~ ii\. j ,\ ii BY ORDER OF a~/~f Approved r'\ r'\ \ ( THE COMMISSION Date 'j I Form 1 0-40~evised~2003 -- U0\U\~'\.1 \..... Submit In Duplicate . . BP L2-07 A Sidetrack Summary of Operations: Well L2-07 is scheduled for a through tubing sidetrack with the SLB/Nordic 1 CTD rig. The sidetrack, L2- 07 A, will exit~~ the existing 4-112" liner from a mechanical whipstock and target Zone 1 reserves. The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (Dhase 1) 1) Slickline -Drift tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. 2) E-line - Set packer and whipstock tray at approx 11015'md / CTD Sidetrack Summary (Dhase 2) 1) MIRU CTD rig. 2) Mill 3.8" OD window at approx 11015' md. 3) Drill sidetrack to -13050' TD with MWD/gamma ray. , 4) Run 3-3/16" x 2-7/ " III r completion. Top of liner will be at approx 10970' md in 4 Y2"liner ,,/ 5) Cement liner wi 19 Is of 15.8 ppg cement. 6) Run memory C CL/GR 7) Perforate. 8) RDMO. Mud Program: . Phase 1: 8.4 ppg seawater · Phase 2: 8,6 ppg used PIo Pro or biozan for milling, new PIo Pro for drilling. / Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · A 3-3/16"x 2 7/8" solid cemented liner completion from 10970' to TD at 13050'. The liner cement volume is planned to be -19 bbls of 15.8 ppg class G. Perforate liner as per Asset instructions. /' Parent Well CasinQs Burst (psi) Collapse (psi) 9%" 40#, L-80 5750 / 3090 7" 26#, L-80 7240 5410 4-1/2", 12.6# L-80 8440 7500 Sidetrack CasinQs 3-3/16" 6.2#, L-80, TCII- Prod LNR 8520 7660 2Ys" 6,5#, L-80, STL - Prod LNR 10570 11170 Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. .' · The annular preventer will be tested to 400 psi and 2500 psL Directional · See attached directional plan. Max. planned hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Ll-07A will be approx 775' ctr-ctr away from well Ll-01 at 12250'md · L2-07 A will be approx 30,000' from the unit boundary, (Prudhoe Bay Unit) . . Logging · MWD Gamma Ray log will be run over all of the open hole section. · A memory CNLlGRlCCL cased hole log is planned after the liner has been run and cemented. Hazards ".- · L2 pad is not an H2S pad. No H2S measurements have been taken for well L2-07 A. The nearest bottom hole location,T8-26A had a IOppm sample in 1999. The nearest surface location, L2-13A, had a sample of IOppm taken in 2001. All H2S monitoring equipment will be operational. · Two fault crossings are predicted. Geologic risk is relatively high due to these faults. Lost circulation risk is considered "medium" so LCM material will be on location as a contingency. Reservoir Pressure ~ · Res. press. is estimated to be 3392 psi at 8800'~g EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2512 psi. .-/ . TREE = W8..LI-EAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max An Ie = Datum MD = DatumTVD = 4-1116" CNV Ftv1C BAKERC 39.3' . L2-07 I SAFETY NOTES: ? 11351 ' 11520' 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" Minimum ID = 3.813" @ 10583' 4-1/2" HES X-NIPPLE TOP OF 4-1/2" LNR 4-112" lBG, 12.6#, L-80, .0152 bpf, D = 3.958" 7" CSG, 26#, L-80, ID = 6.276" PERFORATION SUI'vfv1ARY REF LOG: SWS JEW8..RY LOG ON 12/11/98 ANGLE AT TOP ÆRF: 55 @ 11290' Note: Refer to Production DB for historcal perf data SIZ E SPF INTERV AL Opn/Sqz DA 1E 2-1/8" 6 11286-11304 0 04115/99 2-7/8" 6 11340- 11360 0 12/11/98 2-1/8" 6 11340 - 11360 0 02/20/99 2-7/8" 6 11404 - 11412 0 12/11/98 2-1/8" 6 11404-11412 0 02/20/99 2-7/8" 6 11420 - 11440 0 12/11/98 2-1/8" 6 11420 - 11440 0 02/20/99 3-1/2" 4 11430-11440 0 01/29/99 11556' 11572' DATE 12/11/98 10/21/00 04/23/01 07/13/02 02/04/04 02/27/04 REV BY COI'vfv1I3'JTS ORIGINAL COM PLETION DA V / FULL WRCf', OPER SSSV Rf\VTP CORRECTIONS GClKAK ÆRF CORRECTIONS CMOITLP ÆRF Q-IANGE A TCVTLP WELL I-EA D DATA CORREC110 OA. 1E RBI BY . 2170' 4-1/2" CAtv1CO BAL-O SSSV NP, ID - 3.813" GAS LIFT IINHÐRB...S ST MD TVD DEV TYÆ VLC LATCH PORT 0A.1E 1 4088 3498 44 KBG2LS DK11NT 2 7758 6094 45 KBG2LS DK11NT 3 10401 7958 34 KBG2LS DK11NT 1 0550· 10583' 4-1(2" I-ESX NlP,ID -3.813" T' X 4-1/2" BAKERZXP A<R, ID = 4.375" 4-1(2" TT W/WLEG, ID= 3.958" 8..M) NOT LOGGED 5" X 4-1/2" XO COM~TS FRLDHOE BA Y UNIT WELL: L2-07 PERIVIIT No: 1981650 A A No: 50-029-22910-00 SEC 18, T11N, R15E, 3511.01' FB... & 4478.57' FNL BP Exploration (Alaska) NIPPLE, ID =3.813" PERFORA TICN SUMMARY REF LOG SWS JEWELRY LOG 12/11/98 ANGLE AT TOP PERF: @ 11290' Note: Refer to Production D8 for histo 11286-11304 11290-11308 11340-11360 11340-1 11404-11412 11404-11412 11420-11440 11420-11440 11430-11440 1/2" LNR, 12.6#, L-80, 0.0152 bpf, SEe 18, T1 M 5200 5100 ^ ^ , 5000 . 4900 ^ , ^ ^ , 'vv ;;. _vvv ... J,- --- -- ~vVV i 4- .~LVV tm 'œ rEJ- ^ Lc :Q¡µ'dJ 'U9= tID 4100 ^ ^ ^ ^ , 4000 ^ ^ ; : - VvVV : ^^ , vuw : ^ ",w ^ , ' ^ vuvv j , 3500 M C:C:A(', "' BP Amoco WELL PATH DETAJLS PIaI'l#J:L2-Ð1A 500"2"92291001 L2·1)7 11015.(\(1 Tars, 9.30 L2'(}7:39.3 (Doyon 16) o+~,~ c;~l:i ~::~D 0.0.0' 0,1).0' 27.50. DLe!! T;il<::~ SECTION ttlITAI1..S Pareht W.U~th¡ 11"<1011 M{)~ Rig: Ref. DatUM: V.S$cfiotli liltgl. 256.6(), ." ~ , , , , , f! ~ 81 ObP . BP-GDB Baker Hughes INTEQ Planning Report . II.. BAKDt IUGIIU ----'-""'"-,-"-_.,.,-""""~,,- IN'TEQ UNITED Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis DS 02 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957405.92 ft 689322.35 ft Latitude: 70 17 Longitude: 148 28 North Reference: Grid Convergence: 18.046 N 2.759 W True 1.44 deg Well: L2-07 Slot Name: 07 L2-07 Well Position: +N/-S 5715.56 ft Northing: 5963211.65 ft Latitude: 70 18 14.250 N +E/-W 3666.75 ft Easting : 692843.82 ft Longitude: 148 26 15.842 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 L2-07 A Drilled From: L2-07 500292291001 Tie-on Depth: 11015.00 ft Current Datum: L2-07:39.3 (Doyon 16) Height 39.30 ft Above System Datum: Mean Sea Level Magnetic Data: 2/4/2004 Declination: 25.49 deg Fietd Strength: 57594 nT Mag Dip Angte: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.50 0.00 0.00 256.00 Targets ft L2-07A Polygon3.1 0.00 4240.25 -6243.41 5967290.00 686493.99 70 18 55.927 N 148 29 17.994 W -Polygon 1 0.00 4240.25 -6243.41 5967290.00 686493.99 70 18 55.927 N 148 29 17.994 W -Polygon 2 0.00 4260.77 -5834.72 5967321.00 686901.99 70 18 56.132 N 148 29 6.071 W -Polygon 3 0.00 4279.34 -5506.12 5967348.00 687229.99 70 18 56.317 N 148 28 56.484 W -Polygon 4 0.00 4297.45 -5159.52 5967375.00 687575.99 70 18 56.498 N 148 2846.372 W -Polygon 5 0.00 4321.59 -4891.79 5967406.00 687842.99 70 18 56.737 N 148 28 38.562 W -Polygon 6 0.00 4452.65 -4658.34 5967543.00 688072.99 70 18 58.027 N 148 28 31.753 W ·Polygon 7 0.00 4310.09 -4443.92 5967406.00 688290.99 70 18 56.626 N 148 2825.495 W ·Polygon 8 0.00 4120.73 -4510.80 5967215.00 688228.99 70 18 54.764 N 148 28 27.443 W -Polygon 9 0.00 3940.02 -4719.52 5967029.00 688024.99 70 18 52.985 N 148 28 33.529 W -Polygon 10 0.00 3916.47 -5049.25 5966997.00 687695.99 70 18 52.751 N 148 2843.148 W ·Polygon 11 0.00 3934.35 -5394.93 5967006.00 687349.99 70 18 52.925 N 148 28 53.233 W ·Polygon 12 0.00 3968.05 -5811.23 5967029.00 686932.99 70 18 53.253 N 148 29 5.379 W ·Polygon 13 0.00 3970.45 -6255.34 5967020.00 686488.99 70 18 53.273 N 148 29 18.335 W L2·07A Fault 1 0.00 4395.97 -6775.62 5967432.00 685957.99 70 18 57.454 N 148 2933.525 W ·Polygon 1 0.00 4395.97 -6775.62 5967432.00 685957.99 70 18 57.454 N 148 29 33.525 W ·Polygon 2 0.00 4388.57 -5474.30 5967458.00 687258.99 70 18 57.391 N 148 28 55.558 W ·Polygon 3 0.00 4568.25 -4524.32 5967662.00 688203.99 70 18 59.165 N 148 28 27.845 W ·Polygon 4 0.00 4359.62 -3840.41 5967471.00 688892.99 70 1857.117 N 148 28 7.888 W ·Polygon 5 0.00 4568.25 -4524.32 5967662.00 688203.99 70 1859.165N 148 28 27.845 W ·Polygon 6 0.00 4388.57 -5474.30 5967458.00 687258.99 70 18 57.391 N 148 28 55.558 W L2-07 A Fault 2 0.00 4455.54 -5238.49 5967531.00 687492.99 70 18 58.052 N 148 2848.680 W -Polygon 1 0.00 4455.54 -5238.49 5967531.00 687492.99 70 18 58.052 N 148 28 48.680 W -Polygon 2 0.00 3800.41 -5282.32 5966875.00 687465.99 70 1851.608N 148 28 49.945 W L2-07A T3.1 8644.00 4201.90 -4827.84 5967288.00 687909.99 70 18 55.560 N 148 28 36.694 W L2-07A T3.3 8646.00 4192.00 -6078.58 5967246.00 686659.99 70 18 55.454 N 148 2913.184 W L2-07A T3.2 8660.00 4248.28 -5581.94 5967315.00 687154.99 70 18 56.011 N 148 28 58.696 W Company: Field: Site: Well: Wellpath: Targets Annotation MÐ ft 10999.92 11015.00 11035.00 11135.00 11340.93 11405.93 11713.36 12088.36 12338.36 12538.36 12788.36 13050.00 ObP BP Amoco Lisburne Lis DS 02 L2-07 Plan#3 L2-07 A Name TVD ft 8448.58 8462.05 8479.66 8548.06 8618.49 8626.55 8644.11 8650.33 8657.42 8658.47 8652.88 8645.85 . . B.. ØAKI:II: ...... -,,--,,--,-.-".,..;.-.--.- IN'fEQ BP-GDB Baker Hughes INTEQ Planning Report Date: 2/412004 Time: 17:29:36 Page: Co-ordinate(NE) Reference: Well: L2-07, True North Vertical (F'VD) Reference: System: Mean Sea Level Section (VS) Reference: wen (0.00N,0.00E.256.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Description Dip. Dir. Map Northing ft Map Easting ft <-- Latitude -> <.- Longitude --> Deg Min See Deg Min See +E/-W ft TIP KOP 3 4 5 6 7 8 9 10 11 TO ptan: Plan #3 Identical to Lamar's Plan #3 Principal: Yes Date Composed: Version: Tied-to: 2/4/2004 1 From: Definitive Path Plan Section Information MD Ind ft deg 10999.92 25.93 289.02 8448.58 4628.47 -4353.07 0.00 0.00 0.00 0.00 11015.00 27.42 287.67 8462.05 4630.60 -4359.50 10.66 9.88 -8.94 337.29 11035.00 29.19 287.03 8479.66 4633.43 -4368.55 9.00 8.87 -3.20 350.00 11135.00 63.12 274.32 8548.06 4644.27 -4438.53 35.00 33.92 -12.71 340.00 11340.93 82.00 200.42 8618.49 4541.75 -4585.60 35.00 9.17 -35.89 270.00 11405.93 83.80 190.76 8626.55 4479.69 -4602.90 15.00 2.77 -14.86 280.00 11713.36 90.00 236.55 8644.11 4231.27 -4768.74 15.00 2.02 14.89 84.00 12088.36 88.25 292.78 8650.33 4197.75 -5127.24 15.00 -0.47 15.00 92.10 12338.36 88.61 255.27 8657.42 4214.97 -5372.09 15.00 0.14 -15.01 270.00 12538.36 90.80 285.19 8658.47 4215.77 -5569.81 15.00 1.09 14.96 86.00 12788.36 91.67 247.69 8652.88 4200.55 -5814.84 15.00 0.35 -15.00 271.70 13050.00 91.29 286.95 8645.85 4188.57 -6071.01 15.00 -0.14 15.00 90.00 Survey MD Map!'; MapE ft ft ft 10999.92 25.93 289.02 8448.58 4628.47 -4353.07 5967726.59 688373.62 3104.04 0.00 0.00 TIP 11000.00 25.93 289.02 8448.65 4628.48 -4353.11 5967726.61 688373.59 3104.07 0.00 0.00 MWD 11015.00 27.42 287.67 8462.05 4630.60 -4359.50 5967728.56 688367.14 3109.76 10.72 337.29 KOP 11025.00 28.31 287.34 8470.89 4632.01 -4363.96 5967729.85 688362.65 3113.75 9.00 350.00 MWD 11035.00 29.19 287.03 8479.66 4633.43 -4368.55 5967731.15 688358.02 3117.86 9.00 350.29 3 11050.00 34.17 283.84 8492.42 4635.51 -4376.15 5967733.03 688350.38 3124.73 35.00 340.00 MWD 11075.00 42.60 280.01 8512.01 4638.66 -4391.32 5967735.80 688335.13 3138.69 35.00 342.72 MWD 11100.00 51.11 277.25 8529.09 4641.36 -4409.34 5967738.04 688317.05 3155.52 35.00 345.73 MWD 11125.00 59.68 275.08 8543.27 4643.55 -4429.78 5967739.70 688296.56 3174.82 35.00 347.62 MWD 11135.00 63.12 274.32 8548.06 4644.27 -4438.53 5967740.19 688287.79 3183.14 35.00 348.86 4 11150.00 63.24 268.44 8554.83 4644.59 -4451.90 5967740.17 688274.42 3196.04 35.00 270.00 MWD 11175.00 63.98 258.71 8565.97 4642.08 -4474.12 5967737.10 688252.28 3218.20 35.00 272.66 MWD 11200.00 65.35 249.14 8576.69 4635.83 -4495.79 5967730.28 688230.77 3240.74 35.00 276.99 MWD 11225.00 67.32 239.83 8586.74 4625.97 -4516.42 5967719.90 688210.40 3263.14 35.00 281.09 MWD 11250.00 69.81 230.82 8595.89 4612.73 -4535.52 5967706.18 688191.65 3284.88 35.00 284.84 MWD 11275.00 72.74 222.11 8603.93 4596.43 -4552.66 5967689.45 688174.94 3305.44 35.00 288.14 MWD . BP-GDB . Ba. ObP ..... Baker Hughes INTEQ Planning Report --"-"'","",,,--,--.".-- .. INfEQ Company: BP Amoco Da~:. ~/4/2004.. > Time: 1'7:.29:36 Page: 3 Field: Lisburne Co"'Ordinate(Nt11~eference: Well: L2-07, True\,orth Site: Lis DS02 Ver.tIcal (TVP) R.eferece: SY$t~rn:MeanSeaLevel Wen: L2-07 Section(VS) Refer"nce: VVell..(0.00N.,O.00E,256.00Azi) Wellpath: Plan#3 L2c07A Survey Calculation Method: MinimurnCurvature Db: Oracle Survey MD Inct Azim Sys TVD N/S MapE DLS Tool ft døg deg ft ft ft degl100ft 11300.00 76.04 213.69 8610.67 4577.45 -4567.42 5967670.09 688160.67 3324.36 35.00 290.94 MWD 11325.00 79.61 205.52 8615.95 4556.22 -4579.47 5967648.56 688149.17 3341.19 35.00 293.21 MWD 11340.93 82.00 20Q.42 8618.49 4541.75 -4585.60 5967633.93 688143.41 3350.64 35.00 294.94 5 11350.00 82.24 199.06 8619.74 4533.29 -4588.63 5967625.40 688140.60 3355.63 15.00 280.00 MWD 11375.00 82.92 195.35 8622.97 4509.61 -4595.97 5967601.55 688133.88 3368.47 15.00 280.19 MWD 11400.00 83.63 191.64 8625.90 4485.47 -4601.76 5967577.27 688128.71 3379.93 15.00 280.67 MWD 11405.93 83.80 190.76 8626.55 4479.69 -4602.90 5967571.46 688127.71 3382.44 15.00 281.10 6 11425.00 84.10 193.62 8628.56 4461.16 -4606.90 5967552.83 688124.19 3390.81 15.00 84.00 MWD 11450.00 84.53 197.36 8631.03 4437.19 -4613.55 5967528.70 688118.16 3403.05 15.00 83.70 MWD 11475.00 84.97 201.10 8633.32 4413.69 -4621.75 5967505.00 688110.57 3416.69 15.00 83.33 MWD 11500.00 85.44 204.84 8635.41 4390.75 -4631.47 5967481.82 688101.44 3431.67 15.00 82.99 MWD 11525.00 85.93 208.57 8637.29 4368.49 -4642.67 5967459.28 688090.81 3447.93 15.00 82.67 MWD 11550.00 86.44 212.29 8638.96 4346.98 -4655.30 5967437.46 688078.74 3465.39 15.00 82.39 MWD 11575.00 86.95 216.01 8640.40 4326.33 -4669.31 5967416.45 688065.27 3483.98 15.00 82.14 MWD 11600.00 87.49 219.73 8641.61 4306.62 -4684.63 5967396.36 688050.45 3503.61 15.00 81.93 MWD 11625.00 88.03 223.44 8642.59 4287.94 -4701.21 5967377.26 688034.36 3524.22 15.00 81.75 MWD 11650.00 88.58 227.15 8643.33 4270.36 -4718.97 5967359.23 688017.06 3545.70 15.00 81.60 MWD 11675.00 89.14 230.86 8643.82 4253.97 -4737.83 5967342.36 687998.63 3567.97 15.00 81.50 MWD 11700.00 89.70 234.57 8644.08 4238.83 -4757.72 5967326.72 687979.14 3590.93 15.00 81.42 MWD 11713.36 90.00 236.55 8644.11 4231.27 -4768.74 5967318.88 687968.32 3603.45 15.00 81.38 7 11725.00 89.94 238.29 8644.12 4225.01 -4778.54 5967312.36 687958.68 3614.48 15.00 92.10 MWD 11750.00 89.80 242.04 8644.18 4212.57 -4800.22 5967299.38 687937.32 3638.52 15.00 92.10 MWD 11775.00 89.66 245.79 8644.29 4201.58 -4822.67 5967287.82 687915.16 3662.96 15.00 92.09 MWD 11800.00 89.53 249.54 8644.47 4192.08 -4845.79 5967277.73 687892.30 3687.70 15.00 92.07 MWD 11825.00 89.40 253.28 8644.71 4184.11 -4869.48 5967269.15 687868.82 3712.61 15.00 92.05 MWD 11850.00 89.26 257.03 8645.00 4177.71 -4893.64 5967262.13 687844.83 3737.60 15.00 92.01 MWD 11875.00 89.14 260.78 8645.35 4172.90 -4918.17 5967256.70 687820.44 3762.56 15.00 91.97 MWD 11900.00 89.01 264.53 8645.75 4169.71 -4942.96 5967252.87 687795.74 3787.39 15.00 91.91 MWD 11925.00 88.90 268.28 8646.21 4168.14 -4967.90 5967250.66 687770.85 3811.97 15.00 91.85 MWD 11950.00 88.78 272.03 8646.71 4168.21 -4992.89 5967250.08 687745.87 3836.20 15.00 91.79 MWD 11975.00 88.67 275.78 8647.27 4169.91 -5017.82 5967251.14 687720.90 3859.98 15.00 91.71 MWD 12000.00 88.57 279.53 8647.87 4173.23 -5042.59 5967253.83 687696.06 3883.20 15.00 91.63 MWD 12025.00 88.47 283.28 8648.52 4178.17 -5067.08 5967258.14 687671.45 3905.78 15.00 91.54 MWD 12050.00 88.38 287.03 8649.21 4184.70 -5091.20 5967264.05 687647.18 3927.60 15.00 91.44 MWD 12075.00 88.30 290.78 8649.93 4192.80 -5114.84 5967271.53 687623.34 3948.57 15.00 91.34 MWD 12088.36 88.25 292.78 8650.33 4197.75 -5127.24 5967276.17 687610.81 3959.41 15.00 91.23 8 12100.00 88.25 291.03 8650.69 4202.09 -5138.03 5967280.23 687599.92 3968.83 15.00 270.00 MWD 12125.00 88.26 287.28 8651 .45 4210.29 -5161.63 5967287.82 687576.11 3989.75 15.00 270.05 MWD 12150.00 88.28 283.53 8652.20 4216.93 -5185.72 5967293.84 687551.87 4011.51 15.00 270.17 MWD 12175.00 88.30 279.78 8652.95 4221.98 -5210.19 5967298.26 687527.28 4034.03 15.00 270.28 MWD 12200.00 88.33 276.03 8653.69 4225.41 -5234.93 5967301.06 687502.45 4057.21 15.00 270.39 MWD 12225.00 88.36 272.28 8654.41 4227.22 -5259.85 5967302.22 687477.50 4080.95 15.00 270.50 MWD 12250.00 88.41 268.53 8655.11 4227.40 -5284.84 5967301.76 687452.52 4105.16 15.00 270.61 MWD 12275.00 88.46 264.77 8655.80 4225.94 -5309.78 5967299.66 687427.62 4129.71 15.00 270.72 MWD 12300.00 88.52 261.02 8656.46 4222.85 -5334.58 5967295.93 687402.91 4154.52 15.00 270.82 MWD 12325.00 88.58 257.27 8657.09 4218.14 -5359.12 5967290.60 687378.50 4179.47 15.00 270.92 MWD 12338.36 88.61 255.27 8657.42 4214.97 -5372.09 5967287.10 687365.61 4192.82 15.00 271.01 9 12350.00 88.74 257.01 8657.69 4212.19 -5383.39 5967284.02 687354.39 4204.46 15.00 86.00 MWD 12375.00 89.00 260.75 8658.18 4207.37 -5407.91 5967278.58 687330.01 4229.42 15.00 85.96 MWD 12400.00 89.27 264.49 8658.56 4204.16 -5432.70 5967274.73 687305.31 4254.24 15.00 85.89 MWD 12425.00 89.55 268.23 8658.81 4202.57 -5457.64 5967272.51 687280.42 4278.83 15.00 85.83 MWD 12450.00 89.82 271.97 8658.95 4202.62 -5482.63 5967271.91 687255.43 4303.07 15.00 85.79 MWD 12475.00 90.10 275.71 8658.97 4204.29 -5507.57 5967272.94 687230.46 4326.87 15.00 85.77 MWD . . II~. ObP BP-GDB IIAICd ...... Baker Hughes INTEQ Planning Report --',,_.-'""--;.._---"",- INTEQ Company; BPAmoco Date:. .... 2/4/2004 . ...... .... Time: 17:29:36 Page: Fietd: Lisburne Co--ordinate(NE),Referenee: WeltL2-07.TI'LIErNorth Site; Lis DS02 Verti¡:al <'l'VD) Rc:fereJce: S}istem: M~n~ea Level Well; L2-07 Section(VS~.~eference: \N~"(O. DON ,0.00E,256.00Azi) Wellpath: Plan#3 L2-07A SurveyCalcnlatiOn Method: Minimum Curvature Db: Survey MD Ine! Azilll Sys TVD N/S E/W VS DLS TFO Tool ft deg d(Q ft ft ft ft d¢9l100ft d¢9 12500.00 90.38 279.45 8658.86 4207.59 -5532.35 5967275.61 687205.61 4350.11 15.00 85.77 MWD 12525.00 90.65 283.19 8658.64 4212.50 -5556.86 5967279.88 687180.98 4372.70 15.00 85.78 MWD 12538.36 90.80 285.19 8658.47 4215.77 -5569.81 5967282.82 687167.95 4384.48 15.00 85.82 10 12550.00 90.85 283.45 8658.30 4218.65 -5581.09 5967285.41 687156.61 4394.72 15.00 271.70 MWD 12575.00 90.96 279.70 8657.90 4223.66 -5605.57 5967289.79 687132.00 4417.26 15.00 271.67 MWD 12600.00 91.06 275.95 8657.46 4227.06 -5630.33 5967292.56 687107.17 4440.47 15.00 271.62 MWD 12625.00 91.16 272.20 8656.98 4228.84 -5655.26 5967293.69 687082.20 4464.22 15.00 271.55 MWD 12650.00 91.25 268.45 8656.45 4228.98 -5680.25 5967293.19 687057.22 4488.44 15.00 271 .48 MWD 12675.00 91.34 264.70 8655.89 4227.49 -5705.19 5967291.06 687032.32 4513.00 15.00 271 .40 MWD 12700.00 91.43 260.95 8655.28 4224.37 -5729.98 5967287.30 687007.62 4537.81 15.00 271.31 MWD 12725.00 91.50 257.20 8654.64 4219.63 -5754.52 5967281.94 686983.22 4562.76 15.00 271.22 MWD 12750.00 91.57 253.45 8653.97 4213.30 -5778.69 5967274.99 686959.22 4587.75 15.00 271.13 MWD 12775.00 91.64 249.70 8653.27 4205.40 -5802.39 5967266.49 686935.72 4612.66 15.00 271.03 MWD 12788.36 91.67 247.69 8652.88 4200.55 -5814.84 5967261.32 686923.41 4625.91 15.00 270.92 11 12800.00 91.67 249.44 8652.55 4196.30 -5825.67 5967256.79 686912.70 4637.44 15.00 90.00 MWD 12825.00 91.66 253.19 8651.82 4188.29 -5849.33 5967248.18 686889.24 4662.34 15.00 90.05 MWD 12850.00 91.65 256.94 8651.10 4181.85 -5873.47 5967241.12 686865.28 4687.32 15.00 90.16 MWD 12875.00 91.63 260.69 8650.38 4177.01 -5897.99 5967235.65 686840.90 4712.28 15.00 90.27 MWD 12900.00 91.60 264.44 8649.68 4173.78 -5922.76 5967231.78 686816.22 4737.10 15.00 90.38 MWD 12925.00 91.56 268.20 8648.99 4172.17 -5947.70 5967229.54 686791.33 4761.68 15.00 90.48 MWD 12950.00 91.52 271.95 8648.32 4172.20 -5972.68 5967228.93 686766.35 4785.92 15.00 90.58 MWD 12975.00 91.47 275.70 8647.66 4173.87 -5997.61 5967229.96 686741.39 4809.71 15.00 90.69 MWD 13000.00 91.42 279.45 8647.03 4177.16 -6022.38 5967232.61 686716.55 4832.95 15.00 90.78 MWD 13025.00 /91.36 283.20 8646.43 4182.07 -6046.88 5967236.89 686691.93 4855.53 15.00 90.88 MWD 13050.00 91.29 286.95 8645.85 4188.57 -6071.01 5967242.76 686667.64 4877.37 15.00 90.97 TO Nordic 1 bighole All Measurements are from top of Riser 3/17/2004 ~ Q) (/) a- ce bttm of bag BAG 71/16" 5000psi top of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ./ ·······71/16" 5000 . ............ pSI .............. middle of flow cross Mud Cross 71/16" 5000psi middle of blind/shears TOTs 71/16" 5000psi middle of pipe/slips Flow Tee . -- I"'" U\J\JL;JO DATE INVOICE 1 CREDIT MEMO DESCRIPTION GROSS - 3/2/2004 PR022604 PERMIT TO DRILL PPLlCA TIONS POUCH TO TERRI UBBLE MB7-5 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. NATIONAL CITY BANK Ashland, Ohio PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: [f. "/'" ,IIU, : ~..[. tn) TO THE STATE OF ALASKA ORDER AOGCC OF 333 WEST 7TH AVENUE SUITE 1 ANCHORAGE AK 99501 110 5 5 2 5 8 III ~:O~ ¡. 20:l8iìS.: o ¡. 2 ? 8 iì b III ¡., ~V". . . .. ." :.::..:.::::..:.::::.:. . " .'. '" .--- 56-389 412 VENDOR DISCOUNT ,;)1 L.I L.UU<+ AMOUNT ............$100.00.......... Nö.P CÖNSOLlDATE;D COMMERCIAL ACCOUNT I 055258 NET U:J:J;¿:Jö H . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME;;~/-r/c ¿:2 -'o7H PTD# ?n 5/ - OS--3 -----Z- Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlboresegment of LATERAL existing well . Permit No, API No. . (If API num ber Production should continue to be reported as last two (2) digits a function· of the original API number. stated are between 60-69) above. PILOT BOLE In accordance witb 20 AAC 25.005(t), an (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for wen (name on permit). SPACING The permit is approved subject ·to full EXCEPTION compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrougb target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#: 2040530 Company BP EXPLORATION (ALASKA) INC Initial ClasslType 1 P.ß(mitfee attacheø. . . . . . .. ............... Yes. 2 Leas.ßnumberapprORriate. ................. . .Y.ßs . 3 .U.n[que well.n.am.ß.and ou.mb.e( . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y.ßs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WelUocat.ßd inadefineø .pool . . . . . . . . . . . . . . . . . . . . . . . . . Yes. 5 WelUocat.ßd proper .d[stance. from driJling unitbound.al)' . . . . . . . . . . . . .. ........ Y.ßs. 6 WelUocat.ßd pr.operd[stance. from otber w~IJs. . . . . . . . . Y.ßs . 7 .S.ufficientacr~aQ.e.aYailable indrillioQ. unjt . . . . . . . . . Yes. 8 Jtd.ßviélted. js weJlbore pléltincJuded . . . . . . . . . . . . . .. ................ Y.ßs . 9 .Ope(ator Onl}' aftect~d party. . . . . . . . . . . . . . .. . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator bas.appropr[ate.bond [nJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . Y.ßs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P.ß(mit can be iSSl.!ed wjtbout conservation order. . . Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....................... Appr Date 12 P.ß(mit can be [sSl.!ed witbout éldmini$t(atil.'e.approvaJ . . . . . . .. .............. _ . Yes. . . . . . . . . . . . . RPC 3/22/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocat.ßd within élrea élndstrata .authorized by-'njectioo OrdeUI (putlO# in. comments) (For NA . . . . .. ........ . . . . . . 15 AJI weIJs.withLnJL4.n::lile.area.of (eyieW id.ßntlfied (FO( $ervjc.ew.ell Onl}'>- . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-produced injector; øurationof pre-proøuc!ioo l.ßs$ than 3 mOnths (For.seJ:Vlce well on)y) . .NA . . . . . . . . . . . . . 17 AÇMPJ=indingofCon.slstenGyhas bee.nJ$sued.fortbis project . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . Administration Engineering Appr Date WGA 3/23/2004 Geology Appr RPC Date 3/22/2004 Geologic Commissioner: Þ)'S Well Name: PRUDHOE BAY UN PBU L2-07A DEV /1-0IL GeoArea 890 Unit _ Program DEV On/Off Shore On Well bore seg Annular Disposal 11650 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 .C.ondu.ct.or $t(ingprovided . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA 19 .S.ud'ac.ß.ca$ingprotects allkl10wn USQWs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA 20 .CMTvoladeQl.!ateto circulateo.n.cOnductor& surf.C$g . . . . . . . . NA . . 21 .CMT vol adeQu.ateto tie-lnJongstring tOS!.lr1 C$g. . . . . . . .. ............... .NA 22CMTwil] Goyera]l koown.pro.ductiye bori~ons. . . . . . . . . . . . . . . . . _Yes.. . . . . . . . . . . . . _ . 23 .Casing designs éld.equa.te fo( C,l", B.&.permafrost . . . . . . . . . . . . . . . .. . Y.ßs. . . . . .. ......... 24 .Mequate.tan.kélge.oJ reserve pit. . . . . . . . . . . . . . . . . . . . . . . . . Y.ßs. . . CTQU.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 JtaJe-d(ilt bas.a. to-403 for abandonment be.ßn apPJoved. . . . . . . . . Y.ßs. . 3/19/20.0~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... 26 Aøequatewellbore $eparatjo.n.proposed. . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . .Y.ßs. . _ . . . . . . . . . . . . . _ . _ . . . _ _ . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . _ . . . . . _ . 27 Jtdiver:ter req.uired. does it meet reguJations. . . _ _ . . . . . . . . . . _ . . .NA _ . Sidet(ack. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28 DJilliog fJuid.program schematic.& eq!.lipJistadequat.ß . . . . . _ _ . Y.ßs. . Max MW.8,Q ppg.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . 29 .BOPEs,.dothey meet reguJation . . . . . . . . . . . . . . . . . . . . . .. . Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BOPEpre.ss ra!ing app(Op(iatEUest to (pu.t psig Lncomments) . . . . . . . Y.ßs . . . . Test to .3500. psi. .MSF' 25.12 psi. . . . . . . . . . . . .. ............... 31 Choke. manifold compJie$ w/API RF'-53 (May 84) . . . . . . . . . _ . . . . . . . Y.ßS. . . . . .. ..... _ . . . . . . . . 32 Work will OGCU( withoyt.operatiol1sbutdown . . . . . . . . . . . . . . . . . . .. ......... Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . 33 Js presence of H2S gas probable. . . . . . . . _ . _ _ . . . . .. ...... ....... No . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . 34 Mecba.nicalcoodJtlon of wells within ,ð.Oß verified (For.s.ervice wel) only). _ _ . . . . . . .NA . . . . .. ...... ...... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 P.ß(mit ~an be [sSijed w/Q hyd(ogen. s.ulfide measjJ(e~. . . . . . . . . . . . . . . . . 36 .D.atapreseoted on. potential overpre~suœ .ZOne~. . . . . . . 37 .S.ßi.smic.al1é1lysjs of shaJlow gas zones. . . . . . . _ ............._ 38S.ßabed .condjtioo survey.(if off-shoœ) . . . . . . . . . . . . . . . . . . . . . 39 . CQntact nameLphoneJor.we.ßlsly progress. reports [exploratol)'only] . No. - - - - - - - - - - - - - - - - - - - - - - - - . NA .NA ........ NA .... NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Ø/~ Date 3123};" o o . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e e d.f)cf -ð53 **** REEL HEADER **** MWD 05/01/05 #/~';,1 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/05/29 680720 01 3.125" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11035.0000: STOP.FT 12956.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 18 TOWN.N 11N RANG. 15E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 39.3 DMF KB EKB .F 39.3 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. Remark File Version 1.000 Extract File: Idwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. L2-07A Prudhoe Bay 70deg 18'14.250" N, 148deg 26'15.842" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - Gamma Ray 29-May-04 500292291001 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 e e (5) Tools run in the string included Casing Coil Locator, Electric Disconnect and Circulating sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and was depth shifted to a PDC (Primary Depth Control) logged by SWS on May 31, 2004. (7) The sidetrack was drilled from milled window in 7 inch liner. Top of window: 11035' MD (8480' SSTVD). Bottom of window: 11041' MD (8485' SSTVD). (8) The interval from 12922' (8618' SSTVD) to 12956' MD (8617' SSTVD) was not logged due to bit to sensor offset. (9) Tied in to L2-07 at 10900'MD (8358' SSTVD). (10) Open hole sidetrack from L2-07APB1 at 11118'MD (8545' SSTVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 11035.6, 11036.5, 11038, 11040.7, 11043.5, 11046.2, 11047.7, 11048.8, 11049.7, 11051.5, 11059.4, 11061.2, 11062.5, 11064.5, 11080.1, 11082.5, 11083.9,11085.4, 11097.9, 11098.8, 11127.2,11127, 11166.5,11166.1, 11169.6, 11169.9, 11173.8, 11173.4, 11176.7, 11176.5, 11184.6, 11185.3, 11195.7, 11196.5, 11199.4,11199.6, 11221.7, 11219.5, 11222.2, 11222.2, 11224.3, 11221.7, 11228.1, 11229.6, 11229.6, 11229.6, 11235.6, 11234, 11237.2, 11235.2, 11240.3, 11239.6, 11246.7, 11246.5, 11292.6, 11288.6, 11303.6, 11298.3, 11327.1, 11326.9, 11328.2, 11332.2, 11338.4,11341.9, 11339.2, 11339, 11352, 11354, 11361.5, 11364.8, 11393.6, 11394.8, 11398.1, 11400.1, 11406.2, 11407.8, 11409.1, 11411.8, 11482.2, 11484.2, 11501.2, 11501.6, 11529.2, 11537.4, 11546.6, 11549.9, 11558.9, 11559.6, 11563.3, 11564, 11569.5, 11570.1, 11573.2, 11575.4, 11592.4, 11595.1, 11606.3,11605.9, 11608.1, 11609.4, 11651,11651.9, 11658.8, 11663.2, DISPLACEMENT 0.881836 2.64551 2.64551 1.10254 1. 76367 1. 76367 1. 98438 2.4248 1. 54297 0.881836 -0.219727 -0.44043 0.219727 -0.441406 -0.220703 0.661133 0.881836 0.220703 -2.2041 o -2.64551 1. 54297 o -1.54297 -1. 9834 -0.661133 -0.220703 -3.96875 -5.29102 ~0.220703 3.96777 3.52734 -0.220703 1.9834 3.30664 1.10254 1.98438 1.54297 2.64551 1. 98438 0.44043 8.15723 3.30762 0.661133 0.661133 0.661133 2.2041 2.64551 -0.44043 1. 32324 0.881836 4.40918 11674.3, 11675.6, 11688.6, 11689, 11696.1, 11699.8, 11710.1, 11712.5, 11717.4, 11720.2, 11723.3, 11725.7, 11732.3, 11733.4, 11742, 11744.2, 11746, 11747.8, 11753.5, 11756.4, 11759.8, 11762.4, 11769.9, 11773, 11796.3, 11797.2, 11808, 11811.5, 11811.3, 11813.5, 11823.2, 11825.6, 11840.4, 11843.1, 11850.4, 11851, 11855.2, 11855.9, 11891.1, 11894.4, 11896, 11897.7, 11954.9, 11956.9, 11959.3, 11964.6, 11964.8, 11970.4, 11981.2, 11983.1, 11988.9, 11988.7, 11998.1, 12003.2, 12021,12021.3, 12030.1, 12031.8, 12040.7, 12040.9, 12051, 12052.1, 12064.2, 12070.9, 12087.8, 12091.3, 12101.4, 12105.2, 12142.1, 12144, 12167.3, 12168, 12175.7, 12175.3, 12178.3, 12179.7, 12190,12190.9, 12196, 12200.8, 12277, 12275.6, 12284.7, 12287.5, 12323.2, 12328.5, 12341.7, 12347.9, 12355.8, 12365.7, 12360.8, 12367.9, 12366.4, 12376.3, 12385.4, 12387.8, 12394.2, 12395.7, 12405, 12413.6, 12444.3, 12452.9, 12487.1, 12491. 8, 12514.9, 12518.7, 12519.3, 12522.4, 12527.9, 12529.9, 12539.8, 12537.6, 12558.3, 12559.4, 12573.5, 12571.3, 12579.9,12577.1, 12631.8, 12622.8, 12698.6, 12699.1, 12701.9, 12704.4, 12707.6, 12708.4, 12711.1, 12710.4, 12712.7, 12714.9, 12714.2, 12717.5, 12716.9, 12719.8, 12718.5, 12721.3, 12726.4, 12726.2, 12732.6, 12731.5, 12737, 12737.2, e e 1. 32324 0.441406 3.74707 2.4248 2.86621 2.4248 1.10254 2.2041 1. 76367 2.86523 2.64551 3.08594 0.881836 3.52734 2.20508 2.4248 2.64551 0.661133 0.661133 3.30664 1. 76367 1. 9834 5.29102 5.51172 1. 98438 -0.220703 5.07129 0.219727 1. 76367 0.220703 1.10254 6.61426 3.52734 3.74707 1.98438 0.662109 -0.441406 1. 32227 0.881836 4.84961 -1. 32227 2.86621 5.29102 6.17285 9.9209 7.05469 9.9209 2.42578 1. 54395 8.59766 8.59766 4.62988 3.74805 3.08594 1.98438 -2.2041 1.10254 -2.20508 -2.86621 -9.03809 0.441406 2.4248 0.881836 -0.661133 2.20508 3.30664 2.86621 2.86523 -0.220703 -1.10254 0.220703 e e 12740.1, 12740.7, 12749.1, 12745.1, 12751.5, 12748, 12754.2, 12753.7, 12757.5, 12755.3, 12758.8, 12759.2, 12760.3, 12764.1, 12765.9, 12767, 12769.2,12771.6, 12774.7, 12775.6, 12779.3, 12780.6, 12783.1,12788.1, 12791,12792.1, 12796.5, 12798.5, 12801.8, 12802, 12806.4, 12806.8, 12816.8,12818.1, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subtile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU 0.661133 -3.96875 -3.52734 -0.441406 -2.2041 0.44043 3.74805 1.10156 2.4248 0.881836 1. 32324 5.07031 1.10254 1. 98438 0.220703 0.44043 1.32324 208 records... 10 bytes 132 bytes ------------------------------------ WDFN LCC CN WN FN COUN STAT L2-07A 5.xtf 150 BP Exploration (Alaska) Inc. L2-07A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 31-May-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP GR ROP ---------------------------------------------------- GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 e e Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 1 1 GR ROP 4 4 4 4 MWD MWD AAPI F/HR ------- 8 Total Data Records: 46 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11035.000000 12956.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 55 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT L2-07A.xtf 150 BP Exploration (Alaska) L2-07A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX ROPS ---------------------------------------------------- GRAX ROPA GRAX ROPS 0.0 0.0 e e * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 92 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11035.000000 12955.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 101 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/05/29 680720 01 **** REEL TRAILER **** MWD 05/01/05 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes rape Subfile 2 is type: LIS DEPTH 11035.0000 11035.5000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 12956.0000 GR -999.2500 -999.2500 39.1809 31. 2704 155.7361 45.5280 118.2845 34.3747 47.7257 63.8666 36.4392 37.5500 182.6299 95.9331 123.1910 46.0462 83.8859 43.7572 58.8103 49.0953 280.9536 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units e e ROP -999.2500 -999.2500 61.0819 90.6432 29.9826 59.5146 73.3484 83.5372 57.0400 53.8792 106.7566 48.0000 13.8754 53.7628 51.0576 87.6216 100.4709 97.0279 146.9352 112.2748 40.6141 41.8213 11035.000000 12956.000000 0.500000 feet ".f .. e e Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11035.0000 21.8300 -999.2500 11035.2500 23.9900 -999.2500 11100.0000 35.4600 60.0100 11200.0000 31. 0900 89.1600 11300.0000 156.7000 34.7100 11400.0000 28.6900 69.6400 11500.0000 118.5400 73.7400 11600.0000 33.1750 83.5700 11700.0000 56.4300 54.9000 11800.0000 67.7900 54.6700 11900.0000 36.0500 63.9400 12000.0000 38.3700 46.6100 12100.0000 139.7700 34.1500 12200.0000 59.3700 37.7300 12300.0000 121.9600 93.3400 12400.0000 38.5400 82.7000 12500.0000 81. 2850 97.7100 12600.0000 43.6250 92.6000 12700.0000 57.2000 147.8500 12800.0000 51. 2100 111.8500 12900.0000 268.7600 62.6800 12955.7500 -999.2500 -999.2500 Tape File Start Depth 11035.000000 Tape File End Depth 12955.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet e e **** REEL HEADER **** MWD 05/01/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/05/25 680720 01 3.125" CTK *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11035.0000: STOP.FT 11700.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 18 TOWN.N 11N RANG. 15E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 39.3 DMF KB EKB .F 39.3 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. L2-07APB1 Prudhoe Bay 70deg 18'14.250" N, 148deg 26'15.842" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - Gamma Ray 25-May-04 500292291070 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 if v2oLfo53 J~CjC¡~ e e (5) Tools run in the string included Casing Coil Locator, Electric Disconnect and Circulating sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and was depth shifted to a PDC (Primary Depth Control) logged by SWS on May 31, 2004,run in wellbore L2-07A. (7) The sidetrack was drilled from milled window in 7 inch liner. Top of window: 11035' MD (8480' SSTVD). Bottom of window: 11041' MD (8485' SSTVD). (8) The interval from 11666' (8591' SSTVD) to 11700' MD (8580' SSTVD) was not logged due to bit to sensor offset. (9) Tied in to L2-07 at 10900'MD (8358' SSTVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 11035.6, 11036.5, 11038, 11040.7, 11043.5, 11046.2, 11047.7, 11048.8, 11049.7, 11051.5, 11059.4, 11061.2, 11062.5, 11064.5, 11080.1,11082.5, 11083.9, 11085.4, 11097.9, 11098.8, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX DISPLACEMENT 0.881836 2.64551 2.64551 1.10254 1. 76367 1. 76367 1. 98438 2.4248 1. 54297 0.881836 Tape Subtile: 1 77 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT L2-07APB1 5.xtf 150 BP Exploration (Alaska) Inc. L2-07APB1 Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 31-May-04 run in wellbore L2-07A/ *** INFORMATION TABLE: CIFO e e MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (va1ue= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 16 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11036.000000 11700.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 25 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT L2-07APB1.xtf 150 BP Exploration (Alaska) L2-07APB1 Prudhoe Bay North Slope Alaska e e *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Speci£ication Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX MWD ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 32 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11035.000000 11700.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 41 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/05/25 680720 01 **** REEL TRAILER **** MWD 05/01/17 BHI 01 Tape Subtile: 4 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes e e Tape Sub file 2 is type: LIS DEPTH GR ROP 11036.0000 21. 8300 -999.2500 11036.5000 52.2168 -999.2500 11100.0000 39.1809 61.0819 11200.0000 47.8400 64.3500 11300.0000 53.2300 80.7600 11400.0000 143.7500 69.6800 11500.0000 72.7200 42.2000 11600.0000 121. 8300 81. 9100 11700.0000 -999.2500 94.8300 Tape File Start Depth 11036.000000 Tape File End Depth 11700.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet e e Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11035.0000 19.8800 -999.2500 11035.2500 22.4400 -999.2500 11100.0000 34.0700 60.0100 11200.0000 37.6300 53.1500 11300.0000 46.2400 74.3000 11400.0000 149.6900 70.1900 11500.0000 74.4600 57.4800 11600.0000 120.4300 73.3800 11700.0000 -999.2500 -999.2500 Tape File Start Depth 11035.000000 Tape File End Depth 11700.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet