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204-095
- r1"-Cr 6� i t Via,'" STATE OF ALASKA �& - ��' ALASKA OIL AND GAS CONSERVATION COM ION W2018U E�OMPLETION OR RECOMPLETION RE T AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG 0 Other 0 Abandoned la • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development l pppwww...IJ GINJ 0 WINJ ❑ WAG 0 WDSPL 0 No.of Completions: Zero Service a Stratigraphic Test E 2. Operator Name: 6. Date Comp.,Susp., rAband.• 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc �/a I g TM 204-095 ' 318-100 - 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 6/5/2004 50-029-21758-02-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 6/9/2004 PBU L2-14B ' Surface: 1556'FSL,1272'FWL,Sec.18,T11N,R15E,UM • 9 Ref Elevations KB 45.00 • 17. Field/Pool(s): Top of Productive Interval: 1308'FSL,3749'FWL,Sec.18,T11N,R15E,UM GL 12.30 • BF 14.64 . PRUDHOE BAY,LISBURNE OIL • Total Depth: 1919'FSL,3677'FWL,Sec.18,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9003'/8420' ADL 028321 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 692967 • y- 5963456 • Zone - ASP 4 . 10598'/8917' ' 84-62 TPI: x- 695450 y- 5963272 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 695362 y- 5963882 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ® 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9515'/8868' 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 GR/ROP/WOB/PRESS,Quad Combo 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLEp TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 33' 113' 33' 113' 30" 2100#Poleset 10-3/4" 45.5# J-55/L-80 32' 3897' 32' 3897' 13-1/2" 1500 sx AS III,325 sx Class'G',150 sx AS I 7-5/8" 29.7# L-80 30' 9411' 30' 8776' 9-7/8" 610 sx Class'G' 5-1/2" 17# L-80 9207' 9515' 8596' 8868' 6-3/4" 200sxClass'G' 3-3/16" 6.2# L-80 9072' 10493' 8479' 8919' 3-3/4"x4-1/8" Uncemented Slotted Liner 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number;Date Perfd): 4-1/2"12.6#13Cr80 9226' 9068'/8476' Ap Ct#Ae.14 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No 1 I Per 20 AAC 25.283(i)(2)attach electronic and printed s, f information SCANJUN 1 9 LlJ 1 I . DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED J- '---a See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size_ Gas-Oil Ratio: Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(con-1: Press 24 Hour Rate �. Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only r Iei(f ' ►gyri- 6/6/e� RBDMS -JUN 012018 0. 1".-5..4l� • 28. CORE DATA Conventional Core(s) Yes 0 No D Sidewall Cores Yes 0 No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summa a lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No I Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9513' 8867 separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Wahoo Zone 6.3 9513' 8867' Kicked off from Parent Well L2-14A 9515' 8868' Wahoo Zone 6.2 9550' 8899' Wahoo Zone 6.1.2 9609' 8941' Wahoo Zone 6.2(Invert) 9897' 8941' Formation at total depth: Wahoo Zone 6.2(From Base) 9897' 8941' 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.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Browning,Zachary H Authorized Title: SI ecialist I Contact Email: Zachary.Browning©bp.com Authorized Signature: \ Date: C�/31/'Q Contact Phone: +1 907 564 5220 •••/// INSTRUCTIONSV General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only S • WELL NAME: L2-14B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount& Kind of Material Used 9050' Set Cement Retainer 9072' 31.6 Bbls Class 'G' 9036'-9041' Tubing Punch 9026' Set Inflatable Cement Retainer 9022' 16 Bbls Class 'G' 9003' Set Whipstock • • • Daily Report of Well Operations L2-14B ACTIVITYDATE SUMMARY 4/7/2018 Assist SSL L&T (Pre-CTD) Job Delayed ***CONT WSR FROM 4/6/18***(ctd) RAN 10'x 2.70" DUMMY WHIPSTOCK, 1 1/2" SAMPLE BAILER, STOP @ 9,060' SLM (no issues) RAN HES CALIPER AS PER PROGRAM (good data) ATTEMPTED TO SET 3 1/2"SLIP STOP CATCHER IN LINER, BOBBLE OF LINER TOP & DROP SLIP STOP. FISH SLIP STOP CATCHER FROM DEVIATION @ 9656' SLM. SET 3 1/2"SLIP STOP CATCHER @ 9,048' SLM PULLED BK-S/O FROM STA#3 @ 6,227' MD PULLED BK-LGLV FROM STA#4 @ 4,793' MD 4/7/2018 ***CONT WSR ON 4/8/18*** T/I/0=600/1500/0 Temp= 80* Freeze protect TBG/FL (Pre Slickline/CTD) Pumped 1 bbl 60/40 and 5 bbls crude down FL. Pumped 2 bbls 60/40 and 38 bbls crude down TBG. Tags 4/7/2018 hung. Slickline on well upon departure. IA OA= OTG FWHPS=100/1500/0 ***CONT WSR FROM 4/7/18***(ctd) SET BK-DGLV IN STA#4 @ 4,793' MD LRS LOADED IA W/200bbts OF CRUDE SET BK-DGLV IN STA#3 @ 6,227' MD LRS ATTEMPT TO MIT-IA(unable to catch pressure) PULL/RESET BK-DGLV IN STA#3 @ 6,227' MD PULLED 3 1/2"SS-CATCHER FROM 9,048' SLM LRS PERFORMED PASSING MIT-IA TO 1547psi 4/8/2018 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/I/0=1000/1000/0 Temp= S/I Assist Slickline (CTD) MIT-IA Passed to 1547 psi. Max applied=1750 psi. Target pressure=1500 psi. Pumped 37 bbls crude down IA,SL R&R station#3. bled psi to 0 Pumped 62.5 bbls and 3 attempts to MIT-IA bled IA to 285 psi , Pressured up IA to 1601 psi with 52.3 bbls crude. 1st 15 min IA lost 49 psi. 2nd 15 min IA lost 5 psi for a total loss of 54 psi in 30 min. Bled IA to 1450 psi. Bled back'-1 bbl (Gas) Loaded IA with 200 bbls crude. Tags hung. **AFE"* sign hung on well. Slickline in control of well upon departure. DSO 4/8/2018 notified. FWHPS=1137/1450/vac CTU #9. 2.0"tapered string (.204-.175) Objective: Pre rig cement sqz MIRU. Pump 1.375"drift ball, perform partial bop test. MU/RIH with HES memory logging GR/CCL+2.5" DJN. Drifted cleanly to 9200'. Logged up from 9180' to 8800'. Painted ORANGE flag @ 9050'. POOH. Good data on log, +9' correction. Swap coil to diesel 4/9/2018 ***In progress*** CTU 9 2"tapered string (.204-.175) Objective: Pre rig cement sqz MIRU. Pump 1.375"drift ball, perform partial bop test. 4/9/2018 ***In progress*** CTU 9 2"tapered string (.204-.175) Objective: Pre rig cement sqz MIRU. Pump 1.375"drift ball, perform partial bop test. MU/RIH with HES memory logging GR/CCL+2.5" DJN. 4/9/2018 ***I n progress*** S • • Daily Report of Well Operations L2-14B CTU#9. 2.0"tapered string (.204-.175) **Continue from 4/9/18** Loaded well with 280 bbls Slick 1% KCL followed by 164 bbls diesel. Make up & RIH w/ Baker cement retainer at 9054'ME Top of plug=9049.85'. Set/sheared inflate plug at 1600psi. Applied —500psi on well head to verify isolation. Perform injectivity test with diesel at 1 bpm=-350psi. Pump 31.6bbls 15.8 class G cement into 3-3/16" liner, never had a pressure bump, unsting from inflate retainer with 1.4bbls left in coil. Pickup/release from retainer, pull additional 5' up from weight back. Reverse entire coil volume with diesel before POOH pumping displacement. See log for details. Pump coil displacement using 60/40 while POOH. Tag up. RDMO. 4/10/2018 ***Job complete*** T/I/O= 365/565/-11. Temp= SI. MIT-T PASSED to 2648 psi (Pre-CTD). Max pressure= 2750 psi, Target pressure = 2500 psi. ALP = 1250 psi, SI @ CV. T FL @ surface, IA FL near surface. Grease crew serviced WV and IA AL CV. Bled IAP from 565 psi to 200 psi, gas then FTS. Used 1.5 bbls of diesel to pressure TBG from 280 psi to 2754 psi. Started MIT-T, Loss 84 psi in 1st 15 min, loss 22 psi for a total loss of 106 psi. Bled TP to 90 psi to OT. Monitor for 30 min. Hung tags. Final WHPs= 90/350Nac. 4/16/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 14:30 CTU#8 1,50" CT Job Scope: Tbg punch, Cement IA, Drift for WS MIRU CTU. 4/22/2018 ** In progress** (LRS Unit 76-Assist Coiled Tubing: Heat Upright, Heat Diesel) Heat UR 077 to 110*F. 4/22/2018 Heat Vac truck of DSL w/Safelube to 80*. ***Job continued on 04/22/18 **** CTU#8 1,50"CT Job Scope: Tbg punch, Cement IA, Drift for WS MIRU CTU. MU & RIH w/HES 2.2" Logging Carrier&2.5" Nozzle. 4/22/2018 ***In Progress*** CTU#8 1,50"CT Job Scope: Tbg punch, Cement IA, Drift for WS MIRU CTU. MU & RIH w/ HES 2.2" Logging Carrier&2.5" Nozzle. Tag plug 9055'down/ 9050' up. Log up to 8800'. Flag pipe at 9000'. Pooh. Tie in to SLB PPROF log dated 20-Aug- 2004, (-6' correction Corrected TD = 9053.06'). RIH with HES 2"x 10' (5' loaded 4spf)tubing punch. 4/22/2018 ***Continue on 04/23/18*** CTU#8 1,50"CT Job Scope: Tbg punch, Cement IA, Drift for WS MIRU CTU. MU & RIH w/HES 2.2" Logging Carrier&2.5" Nozzle. Tag plug 9055'down/ 9050' up. Log up to 8800'. Flag pipe at 9000'. Pooh. Tie in to SLB PPROF log dated 20-Aug- 2004, (-6' correction Corrected TD = 9053.06'). RIH with HES 2"x 10' (5' loaded 4spf) tubing punch. 4/22/2018 ***Continue on 04/23/18*** CTU#8 1,50" CT Job Scope: Tbg punch, Cement IA, Drift for WS RIH with HES tubing punch. Tag Inflate plug, correct depth. Tubing punch 9036'-9041'. Pooh. Attempt to circulate diesel down IA taking returns up the tubing at 5 bpm. IA pressured up quickly with slow response on tubing. There is Tbg x IA communication but unable to circulate at high rate. Discuss w/APE. Run 2nd Tbg Punch Gun (5' loaded 4spf) Tag Baker Inflate Plug. Correct depth. Puh &Tbg Punch from 9036' -9041'. Pooh. All shots fired, ball recovered. Coil unit swapped out Tractors. Stab back on well. Circ-out IA &Tbg w/400 bbls diesel pumping down IA&taking Tubing Returns. MU & RIH w/Baker Inflatable Cement Retainer. Tag Plug, correct depth. Set Baker Inflate Cement Retainer 9026' ME Top of plug = 9025.85'. Inflate plug sheared at 2650psi. Applied 500 psi on well head to verify isolation. Perform injectivity test with diesel at 1 bpm at 2800 psi. 4/23/2018 ***Continued on 04/24/18*** • Daily Report of Well Operations L2-14B CTU#8 1,50" CT Job Scope: Tbg punch, Cement IA, Drift for WS Pump 16 bbls of 15.8 ppg Glass G cement. Circulate 15 bbls into IA. Est. TOC at 8483' in IA .Unsting from inflate retainer with 1.2bbls left in coil. Get weight back and pull additional 5' up from top of plug. Reverse entire coil volume with diesel at 9021'. Pooh reverse circulating with diesel. Pump gel sweep through Coil at surface to tanks. MU & RIH w/Baker Dummy Whipstock BHA(Max OD=2.77"). Tag TOC at 9022'ctm/9018'm. Weight back at 9021 ctm'. Good drift. Pooh pumping pipe displacement w/diesel down backside. Tbg &IA are full of diesel. Rig Down CTU. 4/24/2018 ***Job Complete*** T/I/0=50/1900/0 Temp=S/I Post cement MIT's (CTD) Bleed gas cap off IA from 1900 to 0 4/25/2018 psi. Gas swapped to fluid near 0 psi. **Continued on 4/26/18 WSR** ***WELL S/I ON ARRIVAL***(CTD) DRIFTED FREELY w/20'x 2.70" DUMMY WHIPSTOCK, 1.75" S-BLR TO TAG TOC @ 9,018' SLM. (Sample of Cement) 4/25/2018 ***JOB COMPLETED,WELL LEFT S/I*** **WSR continued from 4/25/18** (CTD) MIT-T**PASSED**to 2658 psi, Max applied 2750 psi, target 2500 psi. MIT-IA**PASSED**to 2679 psi, max applied 2750 psi, target 2500 psi. MIT-T Pumped 2.4 bbls diesel down TBG to achieve test pressure. 1st 15 min TBG lost 61 psi. 2nd 15 min TBG lost 28 psi for total loss of 89 psi in 30 min. Bled TBGP into IA. Bled remaining TBGP to truck, bled back—0.6 bbls. MIT-IA pumped 3.2 bbls diesel down IA to achieve test pressure. 1st 15 min IA lost 48 psi. 2nd 15 min IA lost 20 psi, for a total loss of 68 psi in 30 min. Bled IAP. Bled back 4 bbls. RDMO. Hung info tags on IA and WV. SSV/Swab/WV=Closed. AL=closed. MV=Open IA/OA=OTG. FWHP's=0/8/0. DSO notified 4/26/2018 of LRS departure. ***WELL SHUT IN ON ARRIVAL***(SLB E-LINE CEMENT BOND LOG/WHIPSTOCK) INITIAL T/I/O= 0/500/0 PSI RIH W/ MH-22 (1.375" FN)/SWIVEL/WIEGHT/SCMT. LOG MAIN PASS UP AT 30 FPM FROM TAG DEPTH OF 9018'TO 8000' LOG REPEAT PASS UP AT 30 FPM FROM 8700'-8400'. TOP OF CEMENT FOUND AT 8543'. RIH W/WPST/BKR 10/BKR GEN II DELTA WHIPSTOCK. OAL =48.3', OAW= 380 LBS, MAX OD= 2.69". TOWS @ 8998'. CCL TO TOW= 14.9', CCL STOP DEPTH = 8983.1'. WHIPSTOCK ORIENTED TO 1.9 DEG LOHS (-1.9 DEG ROHS). TIE INTO SLB PRODUCTION PROFILE DATED 20-AUG-2004. FINAL T/I/O = 20/550/0 PSI. 4/27/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** T/I/O = 0+/520NAC. Temp= SI. Bleed WHPs to 0 psi(pre CTD). Wellhouse,scaffold, flowline, and AL disconnected. Fusible cap installed on SSV. IA FL near surface. Bled IAP to BT from 520 psi to 0+ psi (gas to fluid, 0.1 bbls). During bleed TP went on VAC. No monitor due to active pad site prep. Final WHPs=VAC/O+NAC. 4/28/2018 SV, WV, MV= C. SSV=0. IA, OA= OTG. 21:30 T/I/O= 0/550/0. Pre CDR2 Tree work. Removed 4"tree cap assembly and replaced with 4" tapped blind flange. Torqued to API specs. Removed 4" tapped blind flange off FC companion side and replaced with CDR KL1. Torqued to API specs. PT to 350psi low and 5000psi high for 5 minutes each. (PASS). RDMO***Job Complete*** Final T/I/O = 0/550/0. 4/28/2018 SEE LOG FOR DETAILS T/I/O = MV/20NAC. Temp= SI. WHPs (Pre RIG). Wellhouse,flowline,scaffold and AL line removed. Fusible cap installed on SSV. 4/30/2018 SV, WV, MV= C. SSV=0. IA, OA = OTG. 16:00 • • • ,FF, "Page 1.a�: V�or'th i�meriea-ALASKA BP ;"'" �„ Operation Summary Report1� Common Well Name L2-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2018 End Date 5/5/2018 X3-01912-C:(1,887,997.00) Project:Lisburne Site:L2 Rig Name/No.:CDR-2 Spud Date/Time.10/8/1987 12:00:00AM !Rig Release:5/8/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001099 Active datum:KB @45.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT Total Depth I Phase Description of Operations (hr) (usft) 4/30/2018 12:00 - 12:15 0.25 MOB P PRE TREE CAP TESTED,RIG RELEASED 12:15 12:30 0.25 MOB P PRE I PJSM W/CREW AND TRUCK DRIVERS -EMPHASIS ON USING GOOD COMMUNICATION -STOP COMMAND AGREED UPON -STOP BLOCK IN PLACE ON SUB -ANNULUS PRESSURES CHECKED WITH 0 PSI ON IA/OA -WELL SECURED WITH VALVES SHUT IN -DRILL SITE OPERATOR NOTIFIED,WAIVED WITNESSING. 12:30 13:00 0.50 MOB P PRE -JACK UP PIT MODULE AND SPOT ON ACCESS ROAD TO BACKSIDE OF PAD JACK UP SUB AND PULL OFF OF WELL -NABORS TOOLPUSHER AND BP WSL WITNESSED SUB PULLING OFF OF THE WELL 13:00 - 13:40 0.67 MOB P ® PRE STAGE DOWN THE PAD AND INSTALL JEEPS FOR MOVE 13:40 - 18:30 4.83 MOB P PRE MOVE RIG TO L2-PAD 18:30 - 20:30 2.00 MOB P PRE !SPOT MODULES OVER L2-14C AND ACCEPT RIG AT 20:30 ON 4/30/18 - HOLD PJSM PRIOR TO PULLING OVER _WELL:EMPHASIS ON USING GOOD COMMUNICATION,STOP COMMAND AGREED UPON -STOP BLOCK IN PLACE ON SUB -ANNULUS PRESSURES CHECKED WITH 0 PSI ON IA/OA -WELL SECURED WITH VALVES SHUT IN -DRILL SITE OPERATOR NOTIFIED(WITNESS 1 PULLING OVER WELL) 20:30 - 00:00 3.50 RIGU P PRE GENERAL RIG UP OPERATIONS -MATE UP INTERCONNECTS -SPOT TIGER TANK AND RUN HARD LINE -PRESSURE TEST HIGH PRESSURE LINES ON RIG -ENERGIZE RIG STEAM SYSTEM -CYCLE TREE VALVES TO PREVENT THERMAL EXPANSION -RIG UP MANAGED PRESSURE LINE ON TREE PRE-SPUD WITH COYNE CREW (MIDNIGHT-NOON) 5/1/2018 00 00 - 04:00 4.00 RIGU P PRE NIPPLE UP BOPE IN THE FOLLOWING CONFIGURATION: -ANNULAR PREVENTER -TOT DOUBLE GATE:BLIND/SHEAR RAMS (UPPER),2"PIPE/SLIP RAMS(LOWER) -MUD CROSS -TOT DOUBLE GATE:2-3/8"PIPE/SLIP RAMS (UPPER),2"PIPE/SLIP RAMS(LOWER) -ADAPTER FLANGE FROM 7-1/16"BOPE TO 4-1/16"TREE 04:00 - 04:50 0.83 RIGU P PRE RIG UP AND SHELL TEST BOPE TO 3500 PSI (PASS) Printed 5/18/2018 4.36:36PM *All depths reported in Drillers Depths* 1111 North America ALASKA BP • T , Page 2 Operation Summary Report Common Well Name:L2-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2018 End Date:5/5/2018 X3-01912-C:(1,887,997 00) Project:Lisbume Site:L2 Rig Name/No.:CDR-2 Spud Date/Time.10/8/1987 12:00:00AM Rig Release:5/8/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001099 Active datum:KB©45.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04:50 - 09:00 4.17 RIGU P PRE j PRESSURE TEST BOP EQUIPMENT TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH ACCORDING TO AOGCC,BP,AND NABORS PROCEDURES TEST 2"RAMS WITH 2"TEST JOINT,2-3/8" RAMS WITH 2-3/8"TEST JOINT,ANNULAR WITH 2"AND 2-3/8"TEST JOINTS -ALL TESTS CHARTED -FAIUPASS ON R1 VALVE(REMOVE VALVE ON MANAGED PRESSURE LINE),RE-GREASE AND TEST PASSES -ALL OTHER TESTS PASS -FUNCTION RAMS FROM DRILLERS CONSOLE DURING PRESSURE TESTING -INNER REEL IRON,INNER REEL VALVE AND PACKOFFS WERE TESTED AND CHARTED TO 250 PSI LOW/3500 PSI HIGH -WITNESS WAIVED BYAOGCC REP JEFF JONES 09:00 - 10:00 1.00 RIGU P PRE CALL OUT GREASE CREW TO CHECK TREE BOLTS 10:00 - 11:35 1.58 RIGU P PRE BOP TEST COMPLETED,RD TEST EQUIPMENT,INSTALL LUBRICATOR&LOWER QTS AND TEST 11:35 - 12:00 0.42 RIGU P PRE PJSM WITH GREASE CREW TO CHECK TREE BOLTS. CHECK TREE BOLTS. 12:00 - 15:00 3.00 RIGU P PRE DISPLACE REEL WITH KCL WATER AND PUMP SLACK FORWARD. PUSH MEOH SPEAR TO FRONT OF REEL. PRESSURE TEST LUBRICATOR CONNECTION. OPEN WELL AND CHECK FOR PRESSURE, NONE. FLOW TEST WELL,GOOD. 15:00 - 16:00 1.00 RIGU P PRE RISER 0-RING IS SEEN LEAKING SLIGHTLY, SHUT IN SWAB AND CHANGE IT OUT, RE-TEST IS GOOD. OPEN SWAB,10 MIN FLOW CHECK WHILE PJSM FOR P/U BHA. GOOD NO FLOW. 16:00 - 17:30 1.50 RIGU P PRE OPEN CT RISER AND SLIDE BACK,OBSERVE FLUID LEVEL IS STATIC. START M/U MILLING BHA. MILL AND REAMER ARE 2.74"GO,2.73" NO-GO. AFTER 2ND JT OF 2-1/16"CSH DRILLER ACTIVATES BOP ALARM TO START KICK DRILL. TUGGER IS BOUGHT TO RIG FLOOR AND BHA THAT IS IN THE WELL IS PULLED OUT ABOVE BLINDS,AS PER STANDING ORDERS. DRILLER SIMULATES WELL SHUT IN,ALL HANDS REPORT TO STATIONS. TOTAL ELAPSED TIME 2 MIN 30 SEC. CONDUCT AAR FOR KICK DRILL THEN CONTINUE M/U BHA. INJECTOR ON AT 17:30. 17:30 18:00 0.50 STWHIP P WEXIT PUMP 5 BBL MEOH AHEAD FOLLOWED BY KCL TO PLACE THE MEOH AT THE LEADING EDGE. Printed 5/18/2018 4 36.36PM *AII depths reported in Drillers Depths* North America ALASKA BP • `" Page 3(014. Operation Summary Report "'"/' "` Common Well Name:L2-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2018 End Date:5/5/2018 X3-01912-C:(1,887,997 00) Project:Lisburne Site:L2 Rig Name/No.:CDR-2 Spud Date/Time:10/8/1987 12:00.00AM Rig Release:5/8/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001099 Active datum:KB @45.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 - 18:30 0.50 STWHIP P WEXIT PERFORM RIG EVAC DRILL WITH YEAROUT CREW.ALL PARTIES ACCOUNTED FOR IN PROPER MUSTER AREA IN 04:00 MINUTES, WELL SECURED PER STANDING ORDERS. AAR HELD IN CONFERENCE ROOM. 18:30 - 19:30 1.00 STWHIP P 9,000.00 WEXIT RUN IN THE HOLE PUMPING 5 BBLS METHANOL AND KCLAT0.5 BPM,250 PSI,60 FT/MIN FROM SURFACE TO 2320'MD TO ALLOW ENTIRE BHA TO PASS THROUGH THE SLEEVE(TOP OF SSV HOLD OPEN SLEEVE AT 2194'MD). -PUMPING THROUGH OPEN EDC -SLOWDOWN TO 10 FT/MIN THROUGH HOLD OPEN SLEEVE -OBSERVE SLIGHT BOBBLE-0.2 KLBS AT 2225'MD(31'BACK ON BHA, CORRESPONDING TO BOTTOM CSH 2-1/16" JNT) 19:30 - 21:00 1.50 STWHIP P 9,006.00 WEXIT CONTINUE TO RUN IN THE HOLE WITH MILLING BHA FROM 2250'MD TO TOP OF 1 1 'WHIPSTOCK AT 9005.78'MD -RUN IN THE HOLE AT 60 FT/MIN -PUMP HOT KCL FROM TRUCK AT 1.25 BPM, THROUGH OPEN EDC OUT TO THE TIGER TANK ©3100'MD 1350 PSI @ 5600'MD 2300 PSI @ 8600'MD 3350 PSI 11 -TIE IN ON THE WAY DOWN AT 8750'MD AT 5 FT/MIN(-29'CORRECTION) -TAG TOP OF WHIPSTOCK AT 9005.78'MD WITH 3 KLBS DOWN 21:00 - 23:00 2.00 STWHIP P 9,006.00 WEXIT BEGIN DISPLACEMENT FROM KCL TO 8.6 PPG MILLING FLUID -STAGE UP PUMP RATE TO 2.5 BPM,3900 PSI -TAKING RETURNS OUT TO THE TIGER TANK 23:00 - 23:30 0.50 STWHIP P 9,006.00 WEXIT SHUT DOWN PUMPS AND PERFORM FLOW CHECK THROUGH WHITEY VALVE AT SURFACE:WELL STATIC -1:36 MINS FOR FLOW OUT TO GO TO ZERO FROM PUMPS OFF 1-CLOSE EDC 23:30 - 00:00 0.50 STWHIP P 9,006.00 WEXIT TAG PINCH POINT AT 9005.4'MD.PICK UP AND START MOTOR. -1.8 BPM,3520 PSI OFF BOTTOM -FREE SPIN DIFFERENTIAL=650 PSI -PU=40 KLBS,SO=25 KLBS SIMOPS:HELD TABLE TOP RIG EVACUATION DRILL WITH COYNE CREW 5/2/2018 00:00 - 07:00 7.00 STWHIP P 9,012.00 WEXIT MILL 2.74"WINDOW FROM 9006'MD AT �Q�lA MIDNIGHT TO 9012.5'MD(DUAL STRING EXIT 'r`IVl 4-1/2"X 7-5/8") -MILL AT 1 FPH PER WEATHERFORDAND �/2 �g� BOT REPS ON LOCATION -1.8 BPM IN/OUT,3600-3900 PSI ON BOTTOM,0.3-2.6 KLBS WOB -MUD WEIGHT 8.8 PPG IN/OUT • Printed 5/18/2018 4.36.36PM 'All depths reported in Drillers Depths* 11110 North America-ALASKA-BP Page 4 amt. f" Operation Summary Repo" r °' A 014,� • Common Well Name:L2-14 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/30/2018 End Date:5/5/2018 X3-01912-C:(1,887,997.00) Project:Lisburne Site:L2 Rig Name/No.:CDR-2 Spud Date/Time:10/8/1987 12:00:00AM Rig Release:5/8/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001099 Active datum:KB @45.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 07:00 - 10:45 3.75 STWHIP P 9,012.00 WEXIT MILL 2.74"WINDOW FROM 9012.5'MD TO 9015.5 MD(DUAL STRING EXIT 4-1/2"X 7-5/8") -MILL AT 0.5 FPH PER BOT REP ON LOCATION,LIKELY ON THE 7-5/8". -CONTINUE FOLLOWING TIME DRILLING SCHEDULE. -1.83 BPM IN/OUT,3650-3,850 PSI ON BOTTOM,1.0-2.6 KLBS WOB -MUD WEIGHT 8.77 PPG IN/8.81 PPG OUT 10:45 - 12:20 1.58 STWHIP P 9,023.00 WEXIT MILL 10'RATHOLE TO 9,023'AT 15-20 FT/HR. FIRST BACKREAM AT OL TF,1 FT/MIN. SECOND BACKREAM AT 15R TF,1 FT/MIN. SLIGHT MOTOR WORK SEEN AT TOP OF WINDOW. 'THIRD BACKREAM AT 15L,1 FT/MIN. SLIGHT MOTOR WORK SEEN AT TOP OF WINDOW. DRY DRIFT IS CLEAN THROUGH WINDOW, TAG AT TD OF RATHOLE. 12:20 - 15:00 2.67 STWHIP P 9,023.00 WEXIT PICK UP ABOVE WINDOW. DYNAMIC FLOW CHECK FOR 10 MIN,GOOD. LOSS OF 0.3 BBLS. OPEN EDC. PICK UP AND TIE-IN DEPTH,NO CORRECTION. LOG CCL ACROSS LINER TOP SETTING AREA. POOH,PUMP 2.3 BPM/3,800 PSI. 15:00 - 16:30 1.50 STWHIP P 9,023.00 WEXIT MONITOR WELL FOR 10 MINUTES AT BHA: STATIC 1-CLOSE EDC,POWER DOWN -INJECTOR OFF:15:20 -OPEN CT RISER AND INSPECT LAST 50'OF CT FOR CHROME RELATED DAMAGE, NOTHING SEEN. -L/D BHA#1. MILL IS 2.73"GO,2.72"NO-GO. REAMER IS 2.74"GO,2.73"NO-GO. 16:30 - 17:30 1.00 STWHIP N 9,023.00 WEXIT CONDUCT PJSM AND REVIEW RISK ASSESSMENT FOR MIT-IA. CLOSE BLIND SHEARS. RIG UP IA LINE AND BLEED LINE. CONDUCT PRESSURE CROSSCHECK VERIFICATION IN CELLAR AND OPS CAB. EQUALIZE PRESSURE AND OPEN UP TO THE IA. PUMP IA UP TO 2,650 PSI • 17:30 - 18:30 1.00 STWHIP N 9,023.00 WEXIT PERFORM MIT-IA TO 2500 PSI FOR 30 MINUTES -63 PSI LOST IN FIRST 15 MINUTES -40 PSI LOST IN SECOND 15 MINUTES: FAILING RESULT -HOLD OUT FOR 15 ADDITIONAL MINUTES,30 PSI PRESSURE LOST IN THIRD 15 MINUTES: FAILING RESULT -CALL AND DISCUSS WITH WSUP AND SWSL. ELECT TO RETEST WITH LITTLE RED PUMPING SERVICES -BLEED DOWN IA TO 500 PSI(ORIGINAL PRESSURE BEFORE INITIATING MIT-IA) 18:30 - 19:30 1.00 STWHIP P 9,023.00 WEXIT RIG UP LITTLE RED PUMPING SERVICES AND PREPARE TO PERFORM MIT-IA TO 2500 PSI -CIRCULATE OVER THE TOP,0.3 BBLS TO FILL THE HOLE 1 Printed 5/18/2018 4:36.36PM *AII depths reported in Drillers Depths* TRII= ' 4-1116"CNV VVELLHEAD= FMC L2-14B NOTES: WELL ANGLE ACTUATOR= BAKER C - "CHROE TBG* INITIAL&L2-14A KB.BEV= 45.0' W ELLBORE'S NOT SHOWN ON DIAGRAM*** BF.B-EV I XI KOP= 4400' 10-3/4"CSG, — 6T "---->G Max Angle= 102"@ 9929' 45.5#,J-55 BTC, \ 2194' H4-1/2"HES WELLSTAR TRSSSV,ID=3.813" Datum MD= 9617' ID=9.950" 2194' —I4 1/2"HOLD OPEN SLV,D=2.8"(08/22/15) Datum ND= 8900'SS GAS LFT MANS 10-3/4"CSG,45.5#,L-80 VAM,ID=9.950" H 3897' --A , ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3014 3014 1 KBG-2 DMY BK 0 01/13/04 7-5/8"CSG,29.7#,L-80 NSCC XO TO BTC H 4482' -------x �-G 4 4793 4774 22 KBG-2 DMY BK 0 04/08/18 3 6227 6014 32 KBG-2 DMY BK 0 04/08/18 2 7660 7231 29 KBG-2 DMY BK 0 08/23/15 TOC IN IA(04!24/18) -8483' 1.16 111 8975 8396 30 KBG-2 DMY BK 0 10/06/15 2-5/8"GEN 2 DELTA W5 w/RA TAG(04127118) H 9043' 0A •�1� 9022' H4-1/2"BKR INFLATABLE PLUG(04/23/18) TOC IN TBG(04/24/18) — ^-9021' .�+�i 474y.... TBG PUNCH(04/23/18) — 9036'-9041' � ������� ��' 9044' H4-1/2"HES X NIP,D=3.813" Minimum ID =2.8" @ 2194' 11);1'1- .111111 11 44 9050' (BOT INFLATE PLUG(04/10/18) 4-1/2" HOLD OPEN SLEEVE 9065' H7-5/8"X 4-112"S-3 PKR,ID-3.875" TOP OF DOWNSQUH- E CMT(04/10/18) —1 9072' ,E- 9072' --I 3.7"BTT DEPLOY SLV,0=3.0" re 9076' —I3-1/2"X 3-3/16"XO,D=2.80" IC ' #, I 9131' —14-1/2"HES X NIP,D=3.813" BEHIND 4 i........... 9207' HBOT SETTING SLV,ID=5.75" CT LINER • 110 i 9214' H7-5/8"X 5-1/2"BOT HMC HYD HGR,D=4.892" 1 4-1/2"TBG,12.6#,13CR 80 VAM TOP, —I 9223' / 0 9223' —14-112"TT W/MULE SHOE D=3.958" 41 .0152 bpf,ID=3.958" •4 • 7-5/8"CSG,29.7#,L-80 BTC,D=6.875" —I 9411' , IV MILLOUT WINDOW (L2-14B)9515'-9526' 1 I —9500 H ESTIMATED TOC 06/03/04) 5-1/2"WHIPSTOCK(05/28/04) —I 9515 5-112"LNR,17#,L-80 FL4S,.0232 bpf,ID=4.892" —9515' .vgAvvvAAT BKR INFLATABLE STANDING VLV(05/28/04) —I 9620' ��=4,r'ile•4 1.4i...4%** 5-112"WHIPSTOCK(01/18/04) —{ 9655' 4�.�.�.�.�.�• 4.��� ,YVrVYY ov.v0v0v0 4,41,41* ..'.�..'.'.' ' .'1".'1'1'1' PERFORATION SUN VIARY Rff LOG: / ANGLE AT TOP PERF:N/A PBTD J 10460' Note:Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/16"LNR,6.2#,L-80 TCU,.0076 bpf,D=2.80" —j 10493' 4-1/2" SLID 9387-10460 C 06/11/04 2" 1 9495-9555 C 10/28/15 BTM OF OPEN HOLE,MILLED SHOE w/2.74"MILL(12/06/04) —I 10594' DATE REV BY CONVENTS DATE REV BY CONMAENTS LISBLIRNEUNIT 11/18/87 N28E INITIAL COMPLETION 09/13/17 JMG/JMD GLV C/O(09/12/17) WELL: L2-14B 01113/04 N2ES RWO 04/12/18 DG/J1413 GLV CIO(04/08/18) PERMIT No:"2040950 01/27104 NORDIC 2 CTD ST(L2-14A)-OPE/IOL 04/12/18 JTC/JMD DVVNSQZ CMT&SET RETAINS? AR No: 50-029-21758-02 06/12/04 NORDIC 2 CTD SIDETRACK(L2-148) 04/25/18 TFA/JMO TBG PUNCWBP/CMT IN IA&TBG SEC 18,T11 N,R15E,1557'FSL&1273'FM. 03/01/17 MAS/JND SET HO SLEEVE(08/22/15) 04/30/18 NXW/JMD SET WS w/RA TAG(04/27/18) 05/03/17 CJWJND GLV C/O(05/02/17) BP Exploration(Alaska) u1 o • 0_______ CT/ TCI x ro a) ,r,o _ _C CNI N Cil N w M O CO II Sg. _ ul a co o c 0.) o CO ., ( •� . , +-, 0 -o 0- - r0 0 a > < LU ro 00 a) E o m O uui N a u o N m` a — of H` in o . C U r aJ N Z N N N O f6 p Z a) E u QJ > -6 4J co au' o 0 o C v -6 N u o Q Q c v 0 J J J - C y_ V p W_ w w • CIO LL LL LL aJ J J J Y_ c a1 C Z Z Z al 0 C .o ,A-. Z Z Z u a p r0 +u. > v C C u C Zi sn a u v 0 c o co E - v u L E' co . U a) N E a z Q C a a O O _ V U t C W CL LL f- U o Q O Jg 1- �+ w a o u u v '-+ a, ON 0 al J: (1.1 VIa Q ai C a° 10 0 t9 _ �.. 00 z ZO h aL a, V . C W 0 E 00 V ...co V a. ` s 0 a° < a m Q w O 3 Z �4p11111:)...ylif W E E ♦ ›.- ��s w m w 0 Q 2 Z Z / 0 a cc w W. Z Z = _ « I- W m = m 0 w Zi 0 . v as T _Z O J J Q 5 N 0 a mom M 'w ' 00 M (-7X 17) — Q LUeV V O O czcz �[ O c o o 3 W `_' = oD > 0 0 0 m y�j 0 0 0 C x ,n5 c w u O O N 0 LO O O O v CO r- w •N E M yk et N h L p I� ilN Q U N N N N L _ 0 N N NQ! s7 Qs O O O •L O O O in - In .n v) a 0 cu Es '01 ro .4.4. y f0 aJ L Z rn E u Y c, w Y 0o cu = V a n0 2 L -a a F- . ai N Q m a I z m Z r' �E v a Q p r^,i J a- N E Z d c_ W J H a) •00 2 O 4-1 u r C/1' rts C 10 �n 0 CO. a Q 1- a 0 Q • PTD at,4 -a Loepp, Victoria T (DOA) From: Browning,Zachary H <Zachary.Browning@bp.com> Sent: Thursday, May 10, 2018 4:44 PM To: Loepp,Victoria T(DOA) Subject: RE: L2-14C IA Test Results Attachments: L2-14B Appr Sundry 3-22-18.pdf; MIT-IA Calculator L2-14C Little Red.xls Follow Up Flag: Follow up Flag Status: Flagged Victoria, The L2-14C MIT-IA results from the pressure test following the window milling run are attached.This test verified the integrity of the IA cement packer after the window was cut. Starting Pressure: 2661 psi 15 min: 2596 psi Final Pressure: 2570 psi SCANNED JUN j 5 2018 Test Result: PASS Thanks,Zach From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,April 30,2018 10:45 AM To: Browning,Zachary H <Zachary.Browning@bp.com> Subject: Re: L2-14C SCMT Results Thanx for the SCMT IA TOC log and MIT-IA results.Approval is granted to proceed as planned with sidetrack operations. Victoria Sent from my iPhone On Apr 30,2018,at 10:37 AM, Browning,Zachary H<Zachary.Browning@bp.com>wrote: Victoria, See the SCMT log attached,which was ran on L2-14B on 4-27-18 to evaluate the IA cement job (performed under Sundry 318-100).The log shows cement has been successfully placed in the IA with a TOC at^'8543' MD(planned for 8500'). MIT-IA passed to 2679 psi on 4-26-18.We plan to carry on with rig sidetrack operations as planned. Let me know if you have any questions. Thanks, Zach Browning 1/1 CTD&RWO Engineer BP Alaska 0:(907)564-5220 1 C:(907)351-7941 410 • Zachary.browning@bp.com All men are created equal, some work harder in pre-season.-Emmitt Smith <BPXA_L2-14B_SCMT_27APR 18_Pri nt.pdf> <L2-14B Appr Sundry 3-22-18.pdf> 2 ' • 0 Z 0 ._ -� c„ D �2 ? 'Om a v i3' C cam o :1 „'' Hsk a a $m•'� T • ° '1`5 R�.y' v 3 ;'it m o f w F m .°23. o s: «_ •o m `a ;-4 o 'a H a F,'ai ° o am o »o 'wo D ,,57 l E !, yQ ;.i i 3d ,'? ' u c_ ' 3 _v '7 Io: a. _ _G • mmm n_ 0 : a '• u, : n° IA n• _ g m A $Ca � • � b a I n $ o n a — 'i w w. a �o m3 �� �g 'fig d ? 'w _ D y v m o m r7; i• m • m _ ;a h w ¢ . A o2 . 50 E2 °o ?;2,, Q a a m 7 m A m p c m o a Tf a �� 1 .'..°_. • ti.e 5 3 m 3 c w d m I ¢ . a ¢c 3. m m a g ° 21 1 ' $ 3 ' z S o o D 3 m c 3 ' s y a' 'c a m m m m m o o S • • m iifia i ny m • R �T 3' n° » N y .=" I• a c $ t y! m n $ m 7°. » �w h o $ '' 2, %'"E- - y v H o - m a. m m ° a a • •" c n • 3 a ' % s a a _ 'o rt ' c N 7 az g _ca N N �IA o' n " N 3 E f N R .- w 9 n C W r Fa D : :,1.14,F7 E III • S PTD 62 Of- - Loepp, Victoria T (DOA) From: Browning,Zachary H <Zachary.Browning@bp.com> Sent: Monday,April 30, 2018 10:48 AM To: Loepp,Victoria T(DOA) Subject: RE: L2-14C SCMT Results Follow Up Flag: Follow up Flag Status: Flagged Thank you! 0 46 From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday,April 30,2018 10:45 AM To: Browning,Zachary H<Zachary.Browning@bp.com> Subject: Re: L2-14C SCMT Results Thanx for the SCMT IA TOC log and MIT-IA results.Approval is granted to proceed as planned with sidetrack operations. Victoria Sent from my iPhone On Apr 30, 2018,at 10:37 AM, Browning,Zachary H<Zachary.Browning@bp.com>wrote: Victoria, See the SCMT log attached,which was ran on L2-14B on 4-27-18 to evaluate the IA cement job (performed under Sundry 318-100).The log shows cement has been successfully placed in the IA with a TOC at^'8543' MD(planned for 8500'). MIT-IA passed to 2679 psi on 4-26-18.We plan to carry on with rig sidetrack operations as planned. Let me know if you have any questions. Thanks, Zach Browning$i CTD&RWO Engineer BP Alaska 0:(907)564-5220 C:(907)351-7941 Zachary.browning@bp.com All men are created equal, some work harder in pre-season. -Emmitt Smith <BPXA_L2-14B_SCMT_27APR18_Print.pdf> <L2-14B Appr Sundry 3-22-18.pdf> 1 �of Thl • ti, gw���\�y/� s THE STAT Alaska Oil and Gas ti�''►�t''d�iA� ofJ L 1V Conservation Commission :__ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F e. Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Leader SCOViel BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L2-14B Permit to Drill Number: 204-095 Sundry Number: 318-100 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1SL /044,44..._ Cathy P oerster Commissioner DATED this day of March, 2018. RBDMS d.L NAg 2 3 29JJ STATE OF ALASKA 4101LASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVO ," R 0 9 201 20 AAC 25.280 .3 2j 1 i 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0' MCC Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0, Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Packer `(0 • C� , c/l r 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-095' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p, 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21758-02-00, 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU L2-14B 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028321 PRUDHOE BAY,LISBURNE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓ Plugs(MD): Junk(MD): ` 10598 • 8917 • 10598 i 8917 2450 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 33-113 33-113 1490 470 Surface 3865 13-3/8" 32-3897 32-3897 3580/5210 2090/2480 Intermediate 9411 7-5/8" 30-9411 30-8776 6890 4790 Liner 308 5-1/2" 9207-9515 8596-8868 7740 6280 Liner 1421 3-3/16" 9072-10493 8479-8919 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Cpa 9/45-10460 0 8851-8919 4-1/2"12.6# 13Cr80 28-9226 / Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 9068/8476 No SSSV Installed No S installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch RI Exploratory 0 Stratigraphic 0 Development RI ' Service 0 14.Estimated Date for Commencing Operations: March 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 ' 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning,Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browning©bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5220 Authorized Title: Engineering Team Leader-CTD&RWO / Authorized Signature: 70 Date: /e,R o/.6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Cir'' ' � 31� - Io0 Plug Integrity 0 BOP Test L9' Mechanical Integrity Test 0 Location Clearance 0 Other: L30P ic,5f *a 35-00 p51- ,5-1Ob1 vi1i`. 1 At Gr C✓-C'✓1t C–✓4 ) *v it06-eC �r7hviat1' p/'—cVw-71r it f 2 57./0/3$l - - Post Initial Injection MIT Req'd? Yes 0 No � �y z'G (� �� Spacing Exception Required? Yes 0 No Subsequent Form Requi d: y t ' 4 0 7" 17 APPROVED BYTHE Approved�b}y: iiii- COMMISSIONER COMMISSION Date: 3 ..22_,_ /8 11' / /1)-0 -14/4--- V / L-- 3/:01l 51,n, RBDMS � MAR 2 3 2018 aR1G1NAL .42 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • To: Alaska Oil & Gas Conservation Commission From: Zach Browning h CTD Engineer 0 �J p Date: March 8, 2018 Re: L2-14B Sundry Approval Request Sundry approval is requested to plug the L2-14B perforations as part of the preparation, drilling and completing the proposed L2-14C coiled tubing sidetrack. History of L2-14B: L2-14B was completed as a CTD sidetrack in 2004. It produced from the Lisburne reservoir as a cycle well. Recently, the well only maintains a few days of positive IOR production in this cycling regime, and only has a 5% on time. The well is no longer competitive and has no future wellwork options. The well passed integrity screening and is fit for a sidetrack. Proposed plan for abandoning Lisburne: During pre-rig operations an inflatable cement retainer will be set in the 4-1/2" tubing above the production liner and cement will be down squeezed through the retainer to fill the liner, annulus and open hole in the Lisburne. A minimum of the total liner+ open hole + cased hole volume will be pumped or until squeeze pressure is reached. After cementing, an MIT-T will be performed to verify cement/retainer integrity. Proposed plan for Packer Squeeze: After the Lisburne is abandoned, the tubing will be punched above the first cement retainer and a second cement retainer will be set to allow cement to be circulated into the IA above the production packer./TOC is planned for 8500' MD, giving a minimum of 500' of cement in the 4- 1/2" tubing X 7-5/8" annulus above the planned dual string exit. There are no current integrity concerns (Passing MIT-IA to 2620 psi on 5/2/17, passing MIT-OA to 1122 psi on 5/2/17). This cement is needed to provide cement in the annulus for the dual string exit and to provide the annular barrier (cement packer) above the sidetrack point. Tubing and IA will be pressure tested to 2500 psi following cemen job and TOC will be logged. The IA will be tested again after the window is cut. Proposed plan for L2-14C: Drill a through tubing sidetrack with the Nabors CDR2 Coiled Tubing Drilling rig on or around May 1st, 2017. During pre-rig operations, the Lisburne will be abandoned and -500' of the IA will be cemented as outlined above. A thru-tubing whipstock will then be set on E-line. The rig will mill a 2.74" window and kick-off in the Ivishak Zone 2 below the Base of the conglomerates. The well is planned to target reserves in Zone 1A. This target is a FURY target in eastern DS18 that will be accessed from L2. The proposed sidetrack is a 1148' horizontal Ivishak producer to be completed with a 2-3/8" L-80 solid x slotted liner with a modified bonsai cement job. If losses or faults/fractures are seen in the last 600', solid pipe is planned as a contingency and will be cemented and selectively perforated. This Sundry covers plugging the existing L2-14B perforations and abandoning the Lisburne formation via the cement retainer and cement placed pre rig, and the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). 1 co cur Wei i f ��lO w�Ajr /,'rr/e IC 47 e N. 4 e" Ciicte G� Ad/ kqf a�l vice./ (e ff � IA) ci�a�> d r.e. Ili 1046 2-74foxP��l►'i r�� '-e�� {,,, re c/- / 1.„0 0ve/ re cove," fief of T-44f etrt Of 1 € 7 /'2fal • • The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin March 15th, 2018) 1. S Dummy GLVs 2. F Load IA. Set Inflatable cement retainer at-9060' MD and down squeeze production liner to abandon Lisburne. Pump a minimum of liner+ CH annulus + OH annulus volume = 31.1 bbls, 15.8 ppg, Class G cement. 3. C MIT-T to 2500 psi. Tubing Punch at-9055' MD. Set second retainer at-9050' MD. Cement IA through cement 4. C retainer. Pump 21.2 bbls, 15.8 ppg Class G, TOC -500' above planned window(8500' MD). 5. S Drift for WS. Log IA cement with SCMT. wb'm f r'cSt] yet tr� tom► �z�, 6. F Assist SL as needed. MIT-IA to 2500 psi. MIT-T to 2500 psi. ,'(z 7. E Set Thru tubing Whipstock 8. V Pre-CTD tree work. " 1/5 Rig Work(scheduled to begin May 1st, 2018) 1. MIRU and fest BOPE 250 psi low and 3,500 psi high (MASP 2450 psi). 2. Mill 2.74"window+ 10' of rathole. MIT-IA to 2500 psi. _ 3. Drill Build: 3.25" OH, 834' (22 deg DLS planned) IVc w P-7-43 4. Drill Lateral: 3.25" OH, 314' (12 deg DLS planned) Run 2-3/8" L-80 solid by slotted liner leaving TOL at-8300' MD. (Contingency to run all solid pipe if 5. fault or losses are seen near the toe.) Pump primary bonsai cement job: 14.5 bbls, 15.3 ppg Class G, TOC at TOL (8300' MD).* 6. (Contingency extra 3.5 bbls of cement will be required if solid pipe is ran). 7. (Contingency- Perforate -500') 8. Freeze protect well to a min 2,200' TVDss. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. 0: Re-install wellhouse, and flowline if needed. 2. V: Tree work as necessary. 3. F: Liner Lap Test 4. S: Set GLVs. LTP set post rig if needed and test.* 5. C: Memory Neutron/Density Log Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 TREE= 4-1/16"CIW • ---A — VL}-EAD= FMC 1.2-14B .- NOTES: WELL ANGLE>70°@ 9659'. ACTUATOR= BAKER C ***4-1/2"CHROME TBG***IMTIAL&L2-14A KB.ELEV= 45.0' WELLBORES NOT SHOWN ON DIAGRAM *** BF.ELEV= 1 I x KOP= 4400' 10-3/4'CSG, - 67' Mx Angie Angle= 102°@ 9929' 45.5#,J-55 BTC, 2194' AH4-1/2"HES WELLSTAR TRSSSV,ID=3,813" Datum MD= 9617' 1 ------1 2194' j-4-1/2-HOLD OPEN SLV,0=2,8"(08/22/15) I ID=9.950" Datum TVD= 8900'SS GAS LFT MANDRELS k ST MD TVD DEV TY FE VLV LATCH FORT DATE 110-3/4"CSG,45.5#,L-80 VAM,0=9.950" H 3897' ---4 • . 5 3014 3014 1 KBG-2 DAY BK 0 01/13/04 _ _ 4 4793 4774 22 KBG-2 DOME BK 16 09/12/17 . [7-5/8"CSG,29.7#,L-80 NSCC XO TO BTC1-1 4482' 1------>c 3 6227 6014 32 KBG-2 SO BK 20 09/12/17 2 7660 7231 29 KBG-2 DMY BK 0 08/23/15 1 8975 8396 30 KBG-2 DMY BK 0 10/06/15 Minimum ID =2.8" @ 2194' 4-1/2" HOLD OPEN SLEEVE I 9044' --I4-1/2"HES X 11P,ID=3.813" ,‹ 110-11 = 9065' H 7-5/8"X 4-1/2"S-3 PKR,0-3.875" 9072' 1--3.7"BTT DEPLOY SLV,ID=arcr 9076' -13-1/2"X 3-3/16"XO,0=2.80" I 9131' H4-1/2"I-ES X NP,V=3.813' BEHIND 1 9207' --I BOT SETTING SLV,03=5.75" CT LINER Xi 1 9214' H7-5/8"X 5-1/2"ROT MAC HY D NUR,0=4.892" 4-1/2"TBG,12,6#,13CR-80 VAM TOP, H 9223' / \ , 9223' -{4-1/2"TT W/MULE SHOE,0=3.958' .0152 bpf,0=3.958' [7-5/8"CSG,29.7#,L-80 BTC,0=6.875- - 9411' i I MILLOUT VVINDOW (L2-148)9515'-9526' I. -9500 E- STIMATED TOC 06/03/04) I5-1/2"VVHPSTOCK(05/28/04) I-I_ 9615' i °WC. " . - 15-1/2"LNR,17#,L-80 FL4S,.0232 bpf,13=4.892" H -9616 ... , _ ,t•-•,,•A•A•.•.•.• - , - KKR INFLATABLE STANDING VLV(05/28/04) j 9620' .;74'ovs'r 67:4 - , --— ---- 40••i' , 5-1/2"WHIPSTOCK(01/18/04) H 9666' ..v,41.................... . , - • , „. 4,4 IF.7.747.•#.... , ' ' 1.....0. ... V , „ I :- V i4.4.0.41.67.*At , , PERFORATION SLIAMARY 5 5 REF LOG: - . ANGLE AT TOP PERE:N/A Note:Refer to Production DB for historical perf data [ PSTD j.--1_ 10460. I SIZE SFF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 9387-10460 06/11/04 1.3-3/16"LIV2,6.2#,L-80 TCH,_0076 bpf,ID=2.80" 10493' 7 0 — 2" 1 9495-9555 0 10/28/15 I BIM OF Of HOLE,MLLE)SHOE w/2.74"MLL(12/06/04) --[. 10694' I DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 11/18187 N28E IMTIAL COMPLETION 11/18/15 GJB/JMD FULLED BP(11/16/15) VVELL: L2-14B 01/13/04 N2ES RWO 02/02/16 OJ-/JM) GLV CIO(01/05/16) PERMIT No:t040950 01/27/04 NORDIC 2 CTD ST(L2-14A)-OPEN HOL 03/01/17 MAS/JM)SET HO SLEEVE(08/22/15) API No: 50-029-21758-02 06/12/04 NORDIC 2 CTD SIDETRACK(12-14B) 05/03/17 CJN/JMD GLV 00(05/02/17) SEC 18,T1114,R15E, 1557'FSL&1273'FWL 11/04/15 MREY.MD ADPERFS(10/28/15) 09/13/17 JMG/J11,43 GLV C/O(09/12/17) 11/04/15 JCIWJAD SET BP(11/03/15) BP Exploration(Alaska) TREE., III V AD= RC PROPOSED L2 SA NCHRO KB.ELEV= 45.0'— REV 3 14 •**4-112"CHROME TBG*** BF.ELEV= IxI KOP= 4400' 10-3/4"CSG, ---I 67' — MaX Angle= _"@______ 45.5#,J-55 BTC, l / 2194' H4-1/2"HES WELLSTAR TRSSSV,D=3.813" Datum MD= D=9.950" L!O 2194' H4-1/2"HOLD OPEN SLV,D=2.8"(08/22/15) Datum TVD= 8900'SS GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,L-80 VARA,ID=9.950" H 3897' , 5 3014 3014 1 KBG-2 DMY BK 0 01/13/04 7-5/8"CSG,29.7#,L-80 NSCC XO TO BTCH 4482' X 4 4793 4774 22 KBG-2 DOME BK 16 01/05/16 r _nV 3 6227 6014 32 KBG-2 SO BK 20 01/05/16 Cl 2 7660 7231 29 KBG-2 DMY BK 0 08/23/15 Minimum ID = " QC _ )��� 1 8975 8396 30 KBG-2 DMY BK 0 10/06/15 TOC 8600' H2.70"DEPLOY SLV,ID=3.Oc" �*/4 *•1•; t 5 G a d J 1*4 44. 44 '*'4 444 MLLOUT DOW(L2-14C) -9022'- 44 44 444 4-1/2"WHPSTOCK(_1__/_ —I 9022' 1 ��4 ' S1, I 4-1/2"HES X NP,D=3.813" — 9044' �'�� .�♦�� q D 22 l 9660' H2-3/8"sold x slotted crossover ICMT RETAINER(_/ 1_) — ;...'l ,41�;� 1 TBG PUNCH,4 SPF(_I 1_) H ve� '�'�' 11 14 7-5/8"X 4-1/2"S-3 PKR,D=3.875" —I 9066' . . 1 3.70"BTT DEPLOY SLV,D=3.0" —I 9072' - • .: . . .\ . I3-1/2"X 3-3/16"XO,ID=2.80" —I 9076' ` : t;j` -: •. fir *+ � FBTD I— K M -3/8"SLTD LNR, #,L-80,. bpf,D= " • 10170' 'g. 7 9131' _H4-1/2"HES XNP,D=3.813" . BEHIND 9207' H BOT SETTING SLV,D=5.75" CT LINER : • 4 t 9214' H 7-5/8"X5-1/2"BOT HMC HYD HGR,D=4.892" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 9223' / 9223' H4-1/2"TT W/MULE SHOE,D=3.958" .0152 bpf,ID=3.958' •x ,, 9 7-5/8"CSG,29.7#,L-80 BTC,13=6.875" —I 941 V --A ••,•••,• . PERFORATION SUMMARY REF LOG: ON / / �4 h ~9500 —I ESTIMAT®TOC 06/03/04) ANGLE AT TOP PERE: ( -•1. Note:Refer to Production DB for historical pert data •i MLLOUT WINDOW (L2-14B)9515'-9526' SIZE SPF INTERVAL Opn/Sqz DATE .❖�t:t-t� `NI NIP*4 ::::.::iii Vii♦ -114-441 DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE LW 11/18/87 N28E IMTIAL COMPLETION 04/18/17 ZB/JMD BOLT PROPOSED REV 1 WELL: L2-14 01/13/04 N2ES RIO °)4/20/17 ZB/JbD BUILT PROPOSED REV 7 PBRMf No: 01/27/04 NORDIC 2 CTD ST(L2-14A)-OPEN HOLE AR No: 50-029-21758-0 06/12104 NORDIC 2 CTD SIDETRACK(L2-14B) . SEC 18,T11 N,R15E, 1557'FSL&1273'FVVL / 1 CTD SIDETRACK(L2-14C) 04/18/1: JM.) SILT PROPOSED BP Exploration(Alaska) • • Well siitt,hol CDR2-AC 4 Ram BOP Schematic Date 21-Nod-17 Quick Test Sub to Otis 1.1 ft — ;; Top of 7"Otis I j. ,' CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub e 7-1/16"5k Flange X 7"Otis Box Top of Annular I 6.0 ft C o ma_ 1 Hydril 7 1/16" Top of Annular Element I 6.7 ft I Annular Bottom Annular I 8.0 ft I `' Blind/Shear CL Blind/Shears 9.3 ft r 2"Pipe/Slips ��99 CL 2"Pipe/Slips 10.1 ft . B1 B2 B3 ' B4 Kill Line WP NIP ,�, Rrs 7-1116• AIR; iii, . Y@ 'fah.-1/x.10 ,64 ScrossMudWill' Off•)-YrI r ' 11 III III 2-3 8"Pipe/Slips CL 2-3/8"Pipe/Slips I 12.6 ft I ► 2"Pipe/Slips CL 2"Pipe/Slips 13.4 ft e l Ili CL of Top Swab 16.0 ft IIIP ISwab Test Pump Hose 1 T1 " T2 CL of Flow Cross 17.4 ft .` :, IV ", ` Master CL of Master 18.8 ft . . . „ LDS 10:4 .,. • IA I II II I t 0 €n: OA I II II I it LDS I I - - Ground Level • • Loepp, Victoria T (DOA) From: Browning,Zachary H <Zachary.Browning@bp.com> Sent: Monday, March 19,2018 3:39 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU 12-14B(PTD 204-095, Sundry 318-100)IA Packer Squeeze w/Plug for Redrill Follow Up Flag: Follow up Flag Status: Flagged Victoria, 9-7/8"OH x 7-5/8"casing cement iob= DPZ 3-DPZ 4 intra-zonal annulus was cased and cemented by 7=5/8" intermediate casing on 10/19/1985.The records of the original cement job indicate that the planned primary cement job consisted of 65 bbls of Lead cement(12 ppg)and 96 bbls of Tail class G (15.8 ppg). No losses recorded during the job and the plug bumped. Using 30%washout, 161 bbls achieves 3161'of cement.This places calculated TOC at 625 .A Cement bond log was run prior to the completion in 1987.The SLB CBT run 28-OCT-87 logged a TOC at 7070'MD. Let me know if you need any other information. Thanks,Zach From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent: Friday, March 16,2018 10:26 AM To: Browning,Zachary H<Zachary.Browning@bp.com> Subject:PBU L2-14B(PTD 204-095,Sundry 318-100) IA Packer Squeeze w/Plug for Redrill Zach, Please provide cementing information for 7-5/8" intermediate casing;was a cement evaluation log run?What was the TOC from log and/or from calculation? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • +• Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist sible in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial ✓ then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling The drilling engineers will serve as quality control for steps 1 and 2. (QEnCineer C) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, they will enter the Typ_Work code"IPBRD"into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ECE1VEC STATE OF ALASKA 4 2 6 93 ALASKA OIL AND GAS CONSERVATION COMMIS, JAN 1 9 2016 L. J REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed OCC Abandon 0 Plug Perforations 0 Fracture Stimulate p Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-095 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21758-02-00 7. Property Designation(Lease Number): ADL 0028321 8. Well Name and Number: LISB L2-14B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 10598 feet Plugs measured feet true vertical 8917 Leet Junk measured feet Effective Depth: measured 10598 feet Packer measured 9068 feet true vertical 8917 feet Packer true vertical 8475,79 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9411 7-5/8"29.7#L-80 30-9441 30-8803 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9387-9495 feet 9495-9555 feet 9555-10460 feet True vertical depth: 8755-8851 feet 8851-8903 feet 8903-8919 feet {'F" A I R 0 8 26161 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 28-9226 28-8613 Packers and SSSV(type,measured and 4-1/2"12.6#13Cr80 9068 8475.79 true vertical depth) 4-1/2"HES TRSSSV 2197 2197.15 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9387'-10460'. Treatment descriptions including volumes used and final pressure: Please see Schlumberger FracCAT Treatment Report. 21(.2. pii ++ 1ct Yv' 414/ir w'/ 0 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 154 9358 20 943 574 Subsequent to operation: 343 1833 363 900 576 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 "VJ ` 16.Well Status after work: Oil p Gas 0 WDSPL " ❑ Printed and Electronic Fracture Stimulation Data II GSTOR o 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: 315-298 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature igG(/14.,✓` C Phone +1 907 564 4424 Date 1/19/16 Form 10-404 Revised 5/2015 C RBDMS �� JAN 2 11 20160 t L 3`� / ItccM' Submit Original Only it 3/ir,�' 001nl 31IVAJDI • S m .0 0 0 0 01 0 0 � CO0rn 00 C) -- O tt ti 00 N O N N V CO U N 0 0 0 0 00 0 1,- 0) CO v- 0) 0 V 00 7 �t 0 N OO `, N- m C`') 0 CD Or h OD O M Ch OO M 0) N O 0 CO O 0) 00 co 0 00 00 00 CO 0 F- CD M N 0) O 00) OO 00 00 0) 01 V 0 N 0 0 4.0 co CD N r 0 N c- 0) 0) V 0 0 N L M 07 0) 0) 0) v03 AM E o 4.0 Q CV r C'') N 0) 0 0 0 N 01 00 0) 00 O N N C MMJ 0) CD W 0 O O 0 J oin (bOD0o J J CO COM 10) J J CD in (j cD T- 03 - N U 0) � v �oNNr O 01 Ch C) N O O M Cn S- L O r- 0 CD CD N- r) v- 0 CD C 0 CD 0 tt O M 0) C7 0) W _- c O W W O w O O LL u_ c a z z c w w w m 0ppl' zzD • 0 • ❑ 00 Et aO m m 0 W w N J F ❑ H Co W Q W • N o w LL z U co _I U) O O a) w 0.5 F7- W Z j o f 0 O NU Z = Q NN, J 00 (n -a m .=-- l...) 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LU > Z a) UZYWJ ~ w . - 0 ai , a) a aUi ODOWL" < '- L1_14, 0000m mOco H -1 > ZW Nom ~ NO np c a ~ * Z U f H 2 LU D * * Ce0 C Uma O o 0 W O * a_ acnowErI * Jv) a * cna * * J of cN- F- ,= 1:1"0J [t CO (0 CO CO CO CO CO r T- r r ,- r A.- CD 0 0 0 0 0 0 0 CV CVLU `N N N N N r r r r r r r • i 0 0 (0 L 0) L Cl) 0 O E a 4' E a E d C. u) ~ u) O CO P _ .- u J O m o Q a) 0 J Q. a) m >, Ca z a� •� L N a) ~ al RI U U 0 O C L Y a) CO 0 a) co6 o D2UZai � co � c O �t (3) O N N CO N N CO N N pp CO I • Schlumberger FracCAT Treatment Report Well :L2-14 Field :Lisburne Formation :Wahoo 6 County :Prudhoe Bay State :Alaska Prepared for Client :BP Exploration Alaska Client Rep :Jack Lau Date Prepared :12/17/2015 Prepared by Name :Michael Hyatt Division :Schlumberger Phone :7705976685 Pressures ' Initial Wellhead Pressure(psi) 1,832 Maximum Treating Pressure(psi) 2,262 Final Surface ISIP(psi) 1,701 DataFRAC ISIP n/a Surface Shut in Pressure(psi) 1,108 Treatment Totals Total Slurry Pumped 2 188 Total Proppant Pumped(lb.);From Load 62,600 (Water+Adds+Proppant)(bbl) Tickets Total WF128 Past Wellhead(bbl) 606.6 Total Proppant in Formation(Ib) 61,052 Total YF128FIexD Past Wellhead(bbl) 1,506.4 Total 40/70 Pumped(Ib) 28,800 Total Freeze Protect Past Wellhead(bbl) 30.3 Total 20/40 Pumped(Ib) 33,800 Total Chemical Additives Invoiced Past WH Invoiced Past WH J957(mgal) 63,268 63,268 J475(Ib) 138 138 F103(gal) 82 82 J134(lb) 10 0 L065(gal) 91 91 M002(Ib) 64 64 L071 (gal) 177 177 J604(gal) 212 212 M275(Ib) 30 30 Freeze Protect 0 30.3 B882(gal) 530 513 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,nd material ultimately required to perform these services.Freedom from infringement of patents of Schlumberger or others is not to be nferred. • a Schiomberger Client:BP Exploration Alaska Well:L2-14 Formation Wahoo 6 District:Prudhoe Bay Country:United States Executive Summary The prop frac treatment for Lisburne 2-14 was performed on 12/16/2015. The treatment consisted of two Data FRAC attempts and the main treatment itself. Throughout the DataFRAC pressure were extremely low and declined throughout the pump time. Once we shutdown, the well was on a vac. As a result, we attempted another DataFRAC, but at higher rates of 30 and 40 bpm. Once the client called for shutdown, the well went again on a vac. After a few phone calls, the decision was made to move forward under the following conditions. 1. We had to be treating at a positive pressure 2. Sand had to be placed in formation at 20bpm Once the main treatment was started,the well started to show pressure gains and we were able to pump the entire schedule without any issues. The only deviation, from the schedule occurred when the BP engineer made the decision to shut down after we had pumped 130 bbl of flush. This was done to prevent the loss of proppant if the well showed signs of being on a vac. The final ISIP was 1,701 and the well was shut in at 1,108 psi. A total of 62,600 lbs of proppant was pumped with a total of 61,052 lbs placed into formation. • • Schiumberger Client:BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Section 1 : Dia. nostic, As Measured Pum • Schedule As Measured Pump Schedule Step Slurry Slurry Rate Pump Time Fluid MaxrProp Prop if Step Name Volume ) (min) Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min (gal) (PPA) (PPA) (Ib) 1 Load hole 102.0 14.2 16.9 WF128 5140 0.0 0.0 0 2 DataFRAC 50.0 20.8 2.4 YF128FIexD 2100 0.0 0.0 0 3 Displacement 141.0 20.3 7.0 WF128 5936 0.0 0.0 0 4 Shut down 0.0 20.3 0.0 WF128 0 0.0 0.0 0 5 Load hole 143.7 32.4 4.8 WF128 6035 0.0 0.0 0 6 DataFRAC 50.0 40.3 1.2 YF128FIexD 2100 0.0 0.0 0 7 Displacement 2.4 40.2 0.1 WF128 99 0.0 0.0 0 8 DataFRAC 183.4 33.2 7.4 YF128FIexD 7704 0.0 0.0 0 9 Displacement 142.4 24.3 10.2 WF128 5982 0.0 0.0 0 10 Displacement 3.1 14.4 0.2 WF128 132 0.0 0.0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Load hole 14.2 20.7 1114 2566 366 2 Data Frac 20.8 21.0 103 363 36 3 Displacement 20.3 21.0 39 45 35 4 Shut down 20.3 21.0 39 45 35 5 Load hole 32.4 41.5 688 1429 15 6 Data Frac 40.3 40.3 1567 1722 1433 7 Displacement 40.2 40.2 1731 1733 1729 8 Data Frac 33.2 40.2 1488 2103 3 9 Displacement 24.3 30.5 981 2564 10 10 Displacement 14.4 14.5 24 24 23 Average Treating Pressure: 1133 psi Maximum Treating Pressure: 2566 psi Minimum Treating Pressure: 3 psi Average Injection Rate: 31.1 bbl/min Maximum Injection Rate: 41.5 bbl/min Average Horsepower: 1017.5 hhp Maximum Horsepower: 2066.9 hhp Maximum Prop Concentration: 0.0 PPA • • Schlumberger Client:BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Section 2: Pro. sed Frac, As Measured Pum . Schedule 1 As Measured Pump Schedule Step Step Slurry Slurry Pump Fluid Max Prop Prop Name Volume Rate Time Fluid Name Volume Proppant Name Copp Conc Mass (bbl) (bbl/min) (min) (gal) (PPA) (Ib) (PPA) 1 PAD 191.5 28.2 6.8 YF128FIexD 8036 0 0 0 2 1.0 PPA 39.7 40.2 1 YF128FIexD 1611 40/70 CarboLite 1 0.3 1567 3 PAD 50 34.2 1.6 YF128FIexD 2086 40/70 CarboLite 1 0.1 0 4 1-2 PPA 20.2 20.2 1 YF128FIexD 811 40/70 CarboLite 1.5 0.7 1147 5 2.0 PPA 40.3 20.1 2 YF128FIexD 1556 40/70 CarboLite 2.1 0.6 3066 6 PAD 50 20.2 2.5 YF128FIexD 2085 0 7 1-3PPA 30.2 20.2 1.6 YF128FIexD 1195 40/70 CarboLite 2.4 1.1 2142 8 3.0 PPA 29.5 19.9 1.5 YF128FIexD 1095 40/70 CarboLite 3.1 2.6 3207 9 PAD 50 20.3 2,5 YF128FIexD 2079 0 0 0 10 1-4 PPA 39.6 20.2 1.8 YF128FIexD 1535 40/70 CarboLite 3.3 1.05 3484 11 4.0 PPA 29.4 20.1 1.5 YF128FIexD 1054 40/70 CarboLite 4 0.8 4105 12 PAD 50 20.4 2.4 YF128FIexD 2074 0 0 0 13 1-5 PPA 49.4 20.2 2.4 YF128FIexD 1880 40/70 CarboLite 4.2 0.875 4822 14 5.0 PPA 32.7 20 1.6 YF128FIexD 1125 40/70 CarboLite 5.3 0 5587 ' 15 PAD 50 20.3 2.5 YF128FIexD 2077 40/70 CarboLite 0 0 0 16 1-2 PPA 21.2 20.3 1.2 YF128FIexD 852 CarboLite 20/40 1.7 0.4 1275 17 2.0 PPA 40.2 20 2 YF128FIexD 1556 CarboLite 20/40 2.1 1.4 3063 18 PAD 50 20.3 2.5 YF128FIexD 2083 0 0 0 19 1-3 PPA 30.2 20.1 1.6 YF128FIexD 1192 CarboLite 20/40 2.4 0.6 2167 20 3.0 PPA 39.6 20 2 YF128FIexD 1473 CarboLite 20/40 3 0.1 4331 21 PAD 50 20.3 2.5 YF128FIexD 2078 0 0 0 22 1-4 PPA 39.6 20 1,8 YF128FIexD 1534 CarboLite 20/40 3.4 1.4 3516 23 4.0 PPA 40 20 2 YF128FIexD 1432 CarboLite 20/40 4 0.1 5616 24 PAD 50 20.2 2.5 YF128FIexD 2073 CarboLite 20/40 4 0.2 0 25 1.0 PPA 49.3 160.6 2.4 YF128FIexD 1877 CarboLite 20/40 4.3 1 4389 26 5.0 PPA 77.8 19.9 3.9 YF128FIexD 2775 CarboLite 20/40 5.1 0 11387 27 Flush 51 20.4 2.5 YF128FIexD 2140 0 0 0 28 Flush 51 20.3 2.5 WF128 2152 0 0 0 29 Flush 30.3 12.5 2.4 Freezeprotect 1318 0 0 0 • • Schiumberger Client:BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District Prudhoe Bay Country:United States Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 28.2 41 1450 2199 15 2 1.0 PPA 40.2 40.3 2223 2247 2203 3 PAD 34.2 40.3 1741 2262 942 4 1-2 PPA 20.2 20.8 932 942 928 5 2.0 PPA 20.1 20.1 911 928 874 6 PAD 20.2 20.2 889 968 846 7 1-3 PPA 20.1 20.2 1002 1016 971 8 3.0 PPA 19.9 20.1 972 1011 938 9 PAD 20.3 20.5 1015 1098 949 10 1-4 PPA 20.2 20.5 1120 1138 1100 11 4.0 PPA 20.1 20.3 1065 1098 1037 12 PAD 20.4 20.5 1088 1182 1027 13 1-5 PPA 20.2 20.5 1193 1225 1183 14 5.0 PPA 20 20.3 1122 1142 1076 15 PAD 20,3 20.5 1155 1288 1069 16 1-2 PPA 20.3 20.5 1329 1351 1288 17 2.0 PPA 20 20.1 1371 1391 1348 18 PAD 20.3 20.4 1511 1665 1389 19 1.0 PPA 20.1 20.4 1696 1710 1667 20 3.0 PPA 20 201 1659 1699 1624 21 PAD 20.3 20.6 1670 1728 1613 22 1.0 PPA 20 20.4 1702 1730 1669 23 4.0 PPA 20 20.2 1630 1667 1598 24 PAD 20.2 20.4 1671 1737 1613 25 1.0 PPA 20.1 20.4 1672 1726 1645 26 5.0 PPA 19.9 20.2 1655 1689 1633 27 Flush 20.4 20.4 1699 1808 1635 28 Flush 20.3 20,4 1940 2098 1812 29 Flush 12.5 19.5 1980 2139 1542 Average Treating Pressure: 1433 psi Maximum Treating Pressure: 2262 psi Minimum Treating Pressure: 15 psi Average Injection Rate: 23.1 bbl/min Maximum Injection Rate: 41.0 bbl/min Average Horsepower: 836.5 hhp Maximum Horsepower: 2229.0 hhp Maximum Prop Concentration: 5.3 PPA • is SchIumbeger Client:BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Section 4: Job Messa•es Message Log Message Treating Annulus ;t Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 Reset Executed Steps 0 0 0.0 0.0 0.0 4 6:30:44 Arrived Location 0 0 0.0 0.0 0.0 5 7:30:08 crank pumps 0 0 0.0 0.0 0.0 6 10:30:09 prejob prime up and pressure test meeting 0 0 0.0 0.0 0.0 7 11:21:31 warming lines 32 1186 0.0 0.0 0.0 8 11:30:31 pump 1 primed up and trip tested 34 0 0.0 4.3 0.0 9 11:30:48 pump 2 primed up and trip tested 35 -0 0.0 2.7 0.0 10 11:33:52 pump 3 primed up and trip test 37 0 0.0 4.3 0.0 11 11:3619 pump 4 primed up and trip tested 37 0 0.0 2.2 0.0 12 11:39:57 pump 5 primed up and trip tested 47 0 0.0 2.1 0.0 13 11:51:05 pump 6 primed up and trip tested 52 2 0.0 1.5 0.0 14 11:54:58 Low pressure stall 1520 2 0.0 0.0 0.0 15 12:05:38 low pressure leak 26 2 0.0 0.0 0.0 16 12:20:33 leak repaired Low pressure stall 834 3 0.0 0.0 0.0 17 12:48:29 Low PT good loss 20 psi 5 mins 296 3 0.0 0.0 0.0 18 12:50:30 Check valve test good 4195 3 0.0 0.0 0.0 19 12:52:33 Global trip tested 7,000 psi good 7270 3 0.0 0.4 0.0 20 13:07:14 High PT good lost 199 psi 5 min 7622 3 0.0 0.0 0.0 21 13:28:16 Inputing final pump schedule into FracCat 1552 3 0.0 0.0 0.0 22 14:58:12 mixing gel 1408 2 0.0 0.0 0.0 23 15:50:17 Start Load hole Automatically 1340 945 0.0 0.0 0.0 24 15:50:17 Start Diagnostic Automatically 1340 945 0.0 0.0 0.0 25 15:50:17 Start Prop Frac sw Automatically 1340 945 0.0 0.0 0.0 26 15:50:17 Started Pumping 1340 945 0.0 0.0 0.0 27 15:57:57 Wellhead Open 1832 945 0.0 0.0 0.0 28 15:59:15 2 bpm for 1 min as per client to check ssv 1841 945 0.5 2.1 0.0 29 16:04:31 wellhead closed as per client to reset over pressure for job 1711 2744 4.6 0.0 0.0 30 16:17:32 Equalizing wellhead 2567 2966 4.6 0.2 0.0 31 16:18:26 Wellhead Open 1782 2963 4.6 0.0 0.0 32 16:23:10 shutdown pump check 902 2996 48.4 0.0 0.0 33 16:36:03 client wants to pump WF fluid to pack off SSV control line 1 bp 868 3080 48.4 -0.0 0.0 34 16:41:40 start pumping to gel off control line 868 3004 49.8 2.2 0.0 35 16:45:57 cut pcm adds to stop LAS Pump surge 690 3019 58.6 2.0 0.0 36 16:52:39 Activated Extend Stage 715 3086 80.5 20.3 0.0 37 16:53:40 good xl sample 10.5 391 2972 101.4 20.5 0.0 38 16:53:42 Deactivated Extend Stage 381 2973 102.0 20.6 0.0 39 16:53:42 Start Data Frac Manually 381 2973 102.0 20.6 0.0 40 16:54:59 Stage at Perfs:Load hole 45 2954 128.5 20.9 0.0 41 16:56:07 Start Displacement Automatically 43 2991 152.2 20.9 0.0 42 17:00:58 Stage at Perfs:Data Frac 42 3068 251.0 20.0 0.0 43 17:03:05 Start Shut down Automatically 29 3023 293.3 20.0 0.0 44 17:03:06 Start PAD Automatically 22 3022 0.0 20.0 0.0 45 17:03:06 Start Propped Frac Automatically 22 3022 0.0 20.0 0.0 • S Schiumberger Client BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Message Log Message Treating Annulus it Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 46 17:03:34 Stage at Perfs:Displacement 15 3034 7.5 14.5 0.0 47 17:04:35 shutdown well on vac 15 3044 22.1 14.4 0.0 48 17:05:21 Start Load hole Manually 15 3050 33.2 14.4 0.0 49 17:05:21 Start Propped Frac Manually 15 3050 33.2 14.4 0.0 50 17:06:14 start new DataFRAC 30bpm 27 3057 13.7 17.5 0.0 51 17:06:28 Activated Extend Stage 59 3062 18.0 20.8 0.0 52 17:09:29 Stage at Perfs:Load hole 1432 3061 115.8 41.2 0.0 53 17:10:10 Deactivated Extend Stage 1448 2985 143.7 40.3 0.0 54 17:10:10 Start Data Frac Manually 1448 2985 143.7 40.3 0.0 55 17:10:18 Stage at Perfs:Load hole 1474 2984 149.1 40.3 0.0 56 17:11:25 Start Displacement Automatically 1742 2999 194.1 40.2 0.0 57 17:11:26 Activated Extend Stage 1742 2999 194.7 40.2 0.0 58 17:11:28 Deactivated Extend Stage 1755 2999 196.1 40.2 0.0 59 17:11:28 Start Data Frac Manually 1755 2999 196.1 40.2 0.0 60 17:13:53 Stage at Perfs:Data Frac 2056 2968 293.1 40.2 0.0 61 17:15:00 shutdown as per client 53 2800 332.8 10.4 0.0 62 17:16:10 Stage at Perfs:Displacement 42 2815 343.1 10.9 0.0 63 17:16:21 Stage at Perfs:Data Frac 48 2810 345.1 10.9 0.0 64 17:18:37 displace well down 695 with linear gel 848 2807 372.9 23.4 0.0 65 17:18:52 Start Displacement Manually 1311 2820 379.5 29.0 0.0 66 17:19:54 client calls to flush crosslink fluid with LG top perfs 1324 2794 410.7 30.1 0.0 67 17:21:36 Activated Extend Stage 845 2728 461.9 29.3 0.0 68 17:23:47 pumps down pod discharge down the well 5.3 bpm 73 2643 500.3 5.9 0.0 69 17:25:56 30 min 94 2606 514.1 0.0 0.0 70 17:26:05 wellhead closed 94 2603 514.1 -0.0 0.0 71 17:47:16 equalize wellhead 2569 2974 514.2 0,2 0.0 72 17:51:13 wellhead open 10 2944 514,7 6.6 0.0 73 17:51:49 Deactivated Extend Stage 24 2951 521.9 14.2 0.0 74 17:51:49 Start Displacement Manually 24 2951 521.9 14.2 0.0 75 17:03:05 Start Shut down Automatically 29 3023 293.3 20.0 0.0 76 17:03:06 Start PAD Automatically 22 3022 0.0 20.0 0.0 77 17:03:06 Start Propped Frac Automatically 22 3022 0.0 20.0 0.0 78 17:03:34 Stage at Perfs:Displacement 15 3034 7.5 14.5 0.0 79 17:04:35 shutdown well on vac 15 3044 22,1 14,4 0.0 80 17:05:21 Start Load hole Manually 15 3050 33.2 14.4 0.0 81 17:05:21 Start Propped Frac Manually 15 3050 33.2 14.4 0.0 82 17:06:14 start new DataFRAC 30bpm 27 3057 13.7 17.5 0.0 83 17:06:28 Activated Extend Stage 59 3062 18.0 20.8 0.0 84 17:09:29 Stage at Perfs:Load hole 1432 3061 115.8 41.2 0.0 85 17:10:10 Deactivated Extend Stage 1448 2985 143.7 40.3 0.0 86 17:10:10 Start Data Frac Manually 1448 2985 143.7 40.3 0.0 87 17:10:18 Stage at Perfs:Load hole 1474 2984 149.1 40.3 0.0 88 17:11:25 Start Displacement Automatically 1742 2999 194.1 40.2 0.0 89 17:11:26 Activated Extend Stage 1742 2999 194.7 40.2 0.0 90 17:11:28 Deactivated Extend Stage 1755 2999 196.1 40.2 0.0 91 17:11:28 Start Data Frac Manually 1755 2999 196.1 40.2 0.0 92 17:13:53 Stage at Perfs:Data Frac 2056 2968 293.1 40.2 0.0 93 17:15:00 shutdown as per client 53 2800 332.8 10.4 0,0 94 17:16:10 Stage at Perfs:Displacement 42 2815 343.1 10.9 0.0 • • Schoenberger Client:BP Exploration Alaska Well L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country.United States Message Log Message Treating Annulus I Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 95 17:16:21 Stage at Perfs:Data Frac 48 2810 345.1 10.9 0.0 96 17:18:37 displace well down 695 with linear gel 848 2807 372.9 23.4 0.0 97 17:18:52 Start Displacement Manually 1311 2820 379.5 29,0 0.0 98 17:19:54 client calls to flush crosslink fluid with LG top perfs 1324 2794 410.7 30.1 0.0 99 17:21:36 Activated Extend Stage 845 2728 461.9 29.3 0.0 100 17:23:47 pumps down pod discharge down the well 5.3 bpm 73 2643 500.3 5.9 0.0 101 17:25:56 30 min 94 2606 514.1 0.0 0.0 102 17:26:05 wellhead closed 94 2603 514.1 -0.0 0.0 103 17:47:16 equalize wellhead 2569 2974 514.2 0.2 0.0 104 17:51:13 wellhead open 10 2944 514.7 6.6 0.0 105 17:51:49 Deactivated Extend Stage 24 2951 521.9 14.2 0.0 106 17:51:49 Start Displacement Manually 24 2951 521.9 14.2 0.0 107 17:52:02 Start PAD Manually 25 2957 525.1 14.6 0.0 108 17:52:02 Start Propped Frac Manually 25 2957 525.1 14.6 0.0 109 17:52:16 Stage at Perfs:Displacement 36 2958 3.5 15.9 0.0 110 17:52:30 Start PAD Manually 49 2969 7.7 19.5 0.0 111 17:54:00 good lip on pad 1473 3010 57.6 38.8 0.0 112 17:56:12 Stage at Perfs:Displacement 2095 2999 146.0 40.2 0.0 113 17:56:17 Stage at Perfs:Load hole 2121 3003 149.4 40.3 0.0 114 17:56:28 Stage at Perfs:Load hole 2215 3013 156.8 40.3 0.0 115 17:56:30 Start 1.0 PPA Automatically 2204 3016 158.1 40.3 0.0 116 17:56:30 Started Pumping Prop 2204 3016 158.1 40.3 0.0 117 17:57:29 Start PAD Automatically 2244 3048 197.6 40.2 1.1 118 17:59:04 Start 1.0 PPA Automatically 928 2961 247.5 20.5 0.0 119 17:59:19 Start 1.25 PPA Automatically 931 2964 252.6 20.2 0.8 120 17:59:34 Start 1.5 PPA Automatically 925 2967 257.6 20.2 1.2 121 17:59:49 Start 1.75 PPA Automatically 932 2970 262.7 20.1 1.4 122 18:00:04 Start 2.0 PPA Automatically 928 2973 267,7 20.1 1.6 123 18:02:02 Stage at Perfs:Data Frac 868 2985 307.2 20.1 2.0 124 18:02:04 Start PAD Automatically 869 2985 307.9 20.1 2.0 125 18:04:00 Stage at Perfs:Displacement 935 2991 346.9 20.2 0.0 126 18:04:33 Start 1.0 PPA Automatically 975 2992 358.0 20.2 0.0 127 18:04:55 Start 1.5 PPA Automatically 995 2993 365.4 20.1 1.0 128 18:05:17 Start 2 PPA Automatically 1011 2995 372.8 20.1 1,5 129 18:05:40 Start 2.5 PPA Automatically 1019 2996 380.5 20.1 2.0 130 18:06:03 Start 3.0 PPA Automatically 1007 2996 388.2 20.1 2.5 131 18:06:28 Stage at Perfs:Data Frac 990 2996 396.6 20.1 3.1 132 18:06:43 Stage at Perfs:Displacement 968 2995 401.6 19.9 3.1 133 18:06:59 Stage at Perfs:Displacement 947 2994 406.9 19.7 3.0 134 18:07:14 Stage at Perfs:PAD 938 2994 411.8 19.7 3.0 135 18:07:29 Stage at Perfs:PAD 949 2995 416.7 19.9 3.0 136 18:07:32 Start PAD Automatically 949 2995 417.7 19.8 3.0 137 18:09:28 Stage at Perfs:PAD 1069 2989 457.0 20.5 0.0 138 18:09:59 Start 1.0 PPA Automatically 1106 2987 467.5 20.4 0.1 139 18:10:17 Start 1.5 PPA Automatically 1120 2984 473.7 20.5 1.0 140 18:10:36 Start 2 PPA Automatically 1130 2981 480.2 20.4 1.4 141 18:10:56 Start 2.5 PPA Automatically 1128 2979 486.9 20.3 2.0 142 18:11:15 Start 3 PA Automatically 1130 2978 493.3 20.1 2.4 143 18:11:36 Start 3.5 PPA Automatically 1111 2974 500.3 19.8 3.0 • • Sclilumb ger Client:BP Exploration Alaska Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. it Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 144 18:11:57 Stage at Perfs:1.0 PPA 1092 2969 507.3 19.9 3.5 145 18:11:57 Start 4.0 PPA Automatically 1092 2969 507.3 19.9 3.5 146 18:12:19 Stage at Perfs:PAD 1075 2966 514.6 19.9 3.9 147 18:12:41 Stage at Perfs:1.0 PPA 1078 2968 522.0 20.2 4.0 148 18:13:04 Stage at Perfs:1.25 PPA 1045 2958 529.8 20.3 4.0 149 18:13:24 Start PAD Automatically 1035 2955 536.5 20.3 4.0 150 18:13:26 Stage at Perfs:1.5 PPA 1033 2954 537.2 20.3 4.0 151 18:14:53 Stage at Perfs:1.75 PPA 1117 2936 566.8 20.5 0.1 152 18:15:51 Start 1,0 PPA Automatically 1187 2923 586.6 20.5 0.0 153 18:16:08 Start 1.5 PPA Automatically 1200 2919 592.4 20.5 0.9 154 18:16:25 Start 2 PPA Automatically 1207 2915 598.1 20.4 1.4 155 18:16:43 Start 2.5 PPA Automatically 1219 2912 604.3 20.4 1.9 156 18:17:01 Start 3 PA Automatically 1224 2908 610.4 20.4 2.5 157 18:17:19 Start 3.5 PPA Automatically 1186 2903 616.4 20.0 3.0 158 18:17:20 Stage at Perfs:2.0 PPA 1184 2903 616.8 19.9 3.0 159 18:17:38 Stage at Perfs:PAD 1173 2900 622.7 19.7 3.4 160 18:17:39 Start 4 PPA Automatically 1175 2899 623.0 19.7 3.4 161 18:17:58 Stage at Perfs:1.0 PPA 1156 2895 629.3 19.8 3.8 162 18:17:58 Start 4.5 PPA Automatically 1156 2895 629.3 19.8 3.8 163 18:18:18 Start 5.0 PPA Automatically 1138 2891 635.9 19.7 4.4 164 18:18:19 Stage at Perfs:1.5 PPA 1142 2891 636.2 19.7 4.4 165 18:18:36 Activated Extend Stage 1134 2889 641.8 19.8 5.0 166 18:18:38 Stage at Perfs:2 PPA 1131 2888 642.4 19,8 5.0 167 18:18:59 Stage at Perfs:2.5 PPA 1126 2884 649.4 19.9 5.0 168 18:19:20 Stage at Perfs:3.0 PPA 1117 2881 656.4 20.3 5.0 169 18:19:56 Deactivated Extend Stage 1073 2874 668.5 19.9 4.9 170 18:19:56 Start PAD Manually 1073 2874 668.5 19.9 4.9 171 18:20:05 Stopped Pumping Prop 1066 2872 671.5 19.6 3.0 172 18:20:48 Stage at Perfs:PAD 1115 2867 685.8 20.4 0.0 173 18:22:24 Start 1.0 PPA Automatically 1297 2846 718.6 20.4 0.0 174 18:22:33 Started Pumping Prop 1315 2845 721.6 20.5 0.0 175 18:22:40 Start 1.25 PPA Automatically 1325 2844 724.0 20.4 0.9 176 18:22:55 Start 1.5 PPA Automatically 1330 2841 729.1 20.4 1.3 177 18:23:11 Start 1.75 PPA Automatically 1344 2896 734.5 20.2 1.5 178 18:23:14 Stage at Perfs:1,0 PPA 1346 2931 735.5 20.1 1.5 179 18:23:27 Start 2.0 PPA Automatically 1350 2989 739.9 20.1 1.7 180 18:23:32 Stage at Perfs:1.5 PPA 1348 2987 741.6 20.1 1.8 181 18:23:49 Stage at Perfs:2 PPA 1360 2981 747.2 20.1 2.0 182 18:24:07 Stage at Perfs:2.5 PPA 1369 2979 753.2 20.0 2.0 183 18:24:26 Stage at Perfs:3 PA 1374 2977 759.6 20.0 1.9 184 18:24:44 Stage at Perfs:3.5 PPA 1384 2975 765.6 20.0 2.0 185 18:25:04 Stage at Perfs:4.0 PPA 1384 2972 772.2 20.0 2.0 186 18:25:22 Stage at Perfs:PAD 1391 2970 778.2 20.0 2.0 187 18:25:28 Start PAD Automatically 1387 2970 780.2 19.8 2.0 188 18:25:42 Stage at Perfs:1.0 PPA 1399 2969 784.9 20.0 0.3 189 18:27:19 Stage at Perfs:1.5 PPA 1602 2969 817.7 20.3 0.0 190 18:27:56 Start 1.0 PPA Automatically 1673 2969 830.2 20.3 0.1 191 18:28:17 Start 1.5 PPA Automatically 1692 2968 837.4 20.3 1.0 192 18:28:39 Start 2 PPA Automatically 1701 2967 844.8 20.0 1.5 • . SChi II Illb(1.11 8 r Client:BP Exploration Alaska Well:L2-14 Formation Wahoo 6 District:Prudhoe Bay Country.United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. I Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 193 18:29:02 Start 2.5 PPA Automatically 1707 2966 852.4 19.9 2.0 194 18:29:26 Start 3.0 PPA Automatically 1700 2964 860.4 20.0 2.5 195 18:29:48 Stage at Perfs:2 PPA 1687 2964 867.7 20.0 3.0 196 18:30:04 Stage at Perfs:2.5 PPA 1671 2963 873.1 20.0 3.0 197 18:30:20 Stage at Perfs:3 PA 1659 2962 878.4 20.0 3.0 198 18:30:36 Stage at Perfs:3.5 PPA 1650 2962 883.8 20.0 3.0 199 18:30:52 Stage at Perfs:4 PPA 1633 2960 889.1 19.9 3.0 200 18:31:24 Start PAD Automatically 1623 2959 899.7 20.0 2.9 201 18:32:52 Stage at Perfs:4.5 PPA 1699 2953 929.4 20.5 0.1 202 18:33:52 Start 1.0 PPA Automatically 1726 2947 949.7 20.3 0.0 203 18:34:11 Start 1.5 PPA Automatically 1730 2945 956.2 20.3 0.9 204 18:34:30 Start 2 PPA Automatically 1705 2941 962.6 20.0 1.4 205 18:34:50 Start 2.5 PPA Automatically 1700 2940 969.2 20.0 1.8 206 18:35:10 Start 3 PPA Automatically 1691 2938 975.9 20.0 2.5 207 18:35:11 ph 10.2 1688 2939 976.2 19.9 2.4 208 18:35:21 Stage at Perfs:5.0 PPA 1688 2938 979.5 20.0 2.8 209 18:35:30 Start 3.5 PPA Automatically 1681 2939 982.5 19.8 3.0 210 18:35:42 Stage at Perfs:PAD 1672 2938 986.5 19.9 3.4 211 18:35:51 Start 4.0 PPA Automatically 1665 2938 989.5 20.0 3.5 212 18:36:04 Stage at Perfs:1.0 PPA 1654 2937 993.8 20.0 3.8 213 18:36:27 Stage at Perfs:1.25 PPA 1640 2936 1001.5 20.0 4.0 214 18:36:51 Stage at Perfs:1.5 PPA 1614 2936 1009.6 20.2 4.0 215 18:37:50 Start PAD Automatically 1617 2936 1029.2 20.0 3.9 1 216 18:38:49 Stage at Perfs:1.75 PPA 1667 2937 1048.9 20.3 0.0 217 18:40:19 Start 1.0 PPA Automatically 1723 2926 1079.5 20.4 0.0 218 18:40:36 Start 1.5 PPA Automatically 1706 2922 1085.3 20.4 0.9 219 18:40:53 Start 2 PPA Automatically 1683 2919 1091.0 20.1 1.5 220 18:41:11 Start 2.5 PPA Automatically 1665 2917 1097.0 19.9 1.9 221 18:41:17 Stage at Perfs:2.0 PPA 1663 2917 1099.0 20.0 2.0 222 18:41:29 Start 3 PPA Automatically 1659 2916 1103.0 20.0 2.4 223 18:41:36 Stage at Perfs:PAD 1658 2915 1105.3 19.9 2.5 224 18:41:48 Start 3.5 PPA Automatically 1657 2917 1109.3 19.9 3.0 225 18:41:55 Stage at Perfs:1.0 PPA 1656 2918 1111.6 19.9 3.1 226 18:42:07 Start 4 PPA Automatically 1653 2919 1115.6 20.0 3.5 227 18:42:15 Stage at Perfs:1.5 PPA 1655 2918 1118.3 20.1 3.7 228 18:42:26 Start 4.5 PPA Automatically 1644 2919 1122.0 19.9 3.9 229 18:42:35 Stage at Perfs:2 PPA 1648 2920 1125.0 19.9 4.1 230 18:42:46 Start 5.0 PPA Automatically 1645 2921 1128.6 20.0 4.4 231 18:42:55 Stage at Perfs:2.5 PPA 1634 2920 1131.6 19.9 4.7 232 18:42:57 Activated Extend Stage 1636 2923 1132.3 19.9 4.9 233 18:43:16 Stage at Perfs:3.0 PPA 1633 2923 1138.6 20.0 5.0 234 18:45:16 Stage at Perfs:PAD 1688 2933 1178.4 19.8 4.9 235 18:46:40 Deactivated Extend Stage 1635 2920 1206.3 20.2 0.0 236 18:46:40 Start Flush Manually 1635 2920 1206.3 20.2 0.0 237 18:47:46 Stage at Perfs:1.0 PPA 1676 2912 1228.7 20.4 -0.0 238 18:48:03 Stage at Perfs:1.5 PPA 1700 2911 1234.4 20.4 0.0 239 18:48:20 Stage at Perfs:2 PPA 1728 2910 1240.2 20.4 0.0 240 18:48:37 Stage at Perfs:2.5 PPA 1759 2910 1246.0 20.4 0.0 241 18:48:55 Stage at Perfs:3 PPA 1789 2911 1252.1 20.4 -0.0 0 • Scliluiiiberger Client,BP Exploration Alaska Well:L2-14 Formation Wahoo 6 District Prudhoe Bay Country.United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. I Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 242 18:49:11 Start Flush Automatically 1818 2912 1257.5 20.3 -0.0 243 18:49:14 Stage at Perfs:3.5 PPA 1824 2913 1258.5 20.4 0.0 244 18:49:32 Stage at Perfs:4.0 PPA 1842 2912 1264.7 20.3 -0.0 • 245 18:49:51 Stage at Perfs:PAD 1865 2914 1271.1 20.3 0.0 246 18:50:11 Stage at Perfs:1.0 PPA 1902 2919 1277.9 20.4 0.0 247 18:51:42 Start Flush Automatically 1800 2924 1308.5 16.9 -1.6 248 18:55:24 Stopped Pumping Prop 1535 2935 1336.5 0.0 -2.4 249 19:09:18 well head 1109 2840 1336.5 0.0 0.0 250 19:49:30 ice plug on bleed off line 1174 -7 1336.5 0.0 0.0 251 20:10:30 pumps fanned out Job Complete 56 -6 1336.5 0.0 0.0 • • Schlumberger Client:BP Exploration Alaska L2 Well:L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States Section: Treatment Plots Treating Pressure Pressure Test BP Exploration Alaska — Annulus Pressure Lisburne 2-14 — Slurry Rate 12-16-2015 — Prop Con — BH Prop Con 10000 . , • , 45 -10 9000- -9 8000. _._–_ _.._ _._.__ _— ___ -36 -8 7000- -7 6000 .. _.._ .__ _ 2. @ 5000. n -5 ir 1 r 3 D 4000 - _ __ 18 ' -4 3000- -3 2000-._____– .. __._. _._ - 1000 -1 0 0 0 11'.50:38 12'.11 28 12:32:18 12:53:08 13 13.58 Time-hh:mm:e3 ©Schlumberger 1994-2012 Schlumberger • • Schiomberger Client:BP Exploration Alaska Well L2-14 Formation:Wahoo 6 District:Prudhoe Bay Country:United States - Treating Pressure BP Exploration Alaska — Annulus Pressure DataFRAC Lisburne 2-14 — Slurry Rate 12-16-2015 — Prop Con - BH Prop Con 4500 , 45 -10 4000- -0 -36 -8 3500- 3000 f� 1ANIP .' 7 12000 A 3 a 1500- ' -3 ii ' ---[,.__ 1000- ___. —.-g -2 500- .1 0 0 17'.00:17 17:08:37 17:16:57 17:25:17 17'.33:37 Time-hh:mm:es Treating Pressure Main Treatment BP Exploration Alaska -- Annulus Pressure Lisbume 2-14 — Slurry Rate 12-16-2015 — Prop Con 4500 °^ BH Prop Con 45 -10 4000 lir --- 40 s 3500— 8 3000- 840A _ 30 -6 ii 2500 ` - 125 . a a 5S. g 2000- - ro_ NLI __. T VI I,500 1 ....-5 ( 1( 500 1?r. 5 •1 e It 1 17:39:44 18:04:44 18:29:44 18:54:44 19:19:44 Time-hh:mm:es • • Scab er Client,BP Exploration Alaska Welt L2-14 Formation:Wahoo 6 • District:Prudhoe Bay Country:United States — F103 Concentration PCM Additives BP Exploration Alaska — L065 Concentration Lisburne 2-14 — L071 Concentration 12-16-2015 — Clean Fluid Rate - Slurry Rate 5 . r 50 -40 4- irT e IT E -30 m rn 3- O • N ti Ci .8 III 41111 Nilll Nii le IQ INJI cr 0ok 3 0 U 2- r 7 > F� D -10 Q y/ 1 • r 0 ° -10 17:23'.57 17:53:07 18:2217 18:51:27 19'20'.37 Time-hh:mm:ss — Prop Con — BH Prop Con POD Additives BP Exploration Alaska — J475 Concentration Usburne2-14 — U028 Concentration 12-16-2015 — J604 Concentration Slurry Rate 10 r r - r Clean Fluid Rat 45 -70 — Gate Posti on O. 9- U CL U -40 60 LI 0 8- U -35 co 2 7- -50 m -30 m G) m a E 6- S RI I ao m 7 23 m J s- yy 2 rj ■ 17 e i �� rr' r 19 20 3 30 A a a- I e 01 a 3 ,�u Co- 16�t1IW1i WOOlr+wb� -20 z •— — — ; • o IIli -10 g.4 -1- s0 . 1111111111 0 0 17.39:44 18'.04'.44 18:29:44 18'.54:44 19'.19:44 Time-hh:mm:ss • • co c a) E E :s, o w 0 0 O O V V CO 0) N O CO LU CO * Ln CO N Cr V CO V r CO CO O 0 u.. 1,4 * O N C) C [O LU Ln V Q) C Q W Q C) Ln 00 N a) E C O -0 r N N r r O 0 O O O a) 'c '� "07.)'- 0 0 0 0 0 0 0 0 0 go, E � wLLE '' cot,,, a, u_ i, Q (O CO (D f� a CO CO Ln * I� CO O N r CO CO O co _ co co O) N O CO CO O) O _.C5 "•P E C C C) O) LO O) V T T Ln O a) C] C) m r N Q) N U C `.— 3. C -o ., CO N r r O O O O O Uno -c G .0._, O F F () U L a) U Q o r O z 0 (00 7 O r C) T CV O '� U � N N M o0 C) N O) C N- co -fl Q o N O 7 O) N O) C) Q (O 7 O N- co O T n V Z (o co O) CO CO r CO }, L -0 Cui -Op -.. m a) m O 3 ca a) N T C Cl) $ t o O in in cc r- O >, O O r--- 0 O (h O C E T \ TN 0.1 x^2 c .-n 0. _OO 0 c6 m O O f� . _ ci O J Qf� o)aioL Z E U) aL o0 CO Q . O Z 0 N ca a _ O r L LIU op O C 7 > N 0_ Z L TC _ y r 0 CO E v a) cEo N N E •-• I)r r 00O c� U U a) N 7m>. O CN O N O d � i c m ° o °++ m OU O - NOO) am E °� > oo 0V N0 m z a)LN�= L E o L a ( o a o c/ 0 a E_c_„07 (' W NO N Q 73 Ln c N a) a) O CUco A N U O 6 Oa ° O EUaoQ d > EY -o o a) C --< 5 = m N aca �� c ° c O == ° mLL, -c 0, o 0cnc)SQma. o i i i- a) a) a) �+ a) — L i O O O 6 E O c0 N 'C O ft as C '— �L io E � n E _ .� 7 7 I •W 't -a 0 D Z = La ca m a ° o Li =' a`) CQ CZ C Z o Z o f E > (a LLJ a —'Ei2 -0 J -4° C )7.; C -SD 1 9 O ¢Q a) c0 > > > Z N L V O 3 a) a) c U Z LL ?) 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Li) N. l) U a u ' w co N n O1 M o m LO O) N (O in V V O N O CO cD (O N O O) O) O) M CON CONNN 0 0 0 0 0 0 0 0 CO O) CO N N V V (-0 N N N N N O O O O 0 0 0 0 0 0 0 0 0 0 O O O O 000 00000000000 0000000000 00000 000 00000000000 0000000000 O O O O O O O O O O O O O O O O O O O O O O O O O O O O O 0 _ U) O in in N CO O M N N LO O) - N ,- M N 0) N N LO in Co O) N N V in 0) 2 co V O LU V LO V O) O) O) LO in Q) N CO LO N CO O N- CO LO 7 V V O c0 LO r CO M CO CO V N N N CO V .- CO 7 CO N N N LO O O) Co CO u") .71- CO M LU M N N N O O O O 0 0 0 0 0 0 0 0 0 0 0 ,- ,- 000 000 00000000000 CDCCCCCCCC a) O O O O O O O O O O O O O O O O O O O O O O O O O O O O O L co coa T a) ca Ca -c a) o 0 O .5 2 I LO N (D M (`� M O co \O N r LO O NC , 0, Lr) N N m LO O O O O CO O r7Np Oc'. 1 NV M M co (D n coco co in M O cO LO O ,..h 0) O O V CO 7 ^InV r. _ () MrOD MV CO V N CO C rM M CO N M N O N OV CO , O C a) O.O O CO LO r NCO V 7 LO N O N 0 0 O N N CO O N T O- N CO r 0) CO V O OOOCOOOM r VCONVCOO _0 7NMCMMCO OcOLO N- OOOT0MNNV N7VO0 NN r r CO M N N N N r r .- ,- O r r CO r co ,- r ^ Nr r ,- O) M a n O L° E a) T ° O L O f° _ L -O N C`- d T p O C C T O .'T' C �, a •C _� (0 .T. C > N m w Ca O U c� 0 p co T O C 0_ X Q) N U a) _0 M N Y m N (° m _ O O 0 a) 0 C - a T E 0 o C N L o L x0 pC �, .L-. U a) ,_-_-_•• N 7 T C N L (a O a) 0 N -0 0 a) a) .N E T -0 0 a) N -0 a) -,-. O UE x N c6 a) 76 ' m :c- L C a) CL 0 .x �° C °) i°0 5, 7 0 -O a) N L C U L ca Ca a) 3 r_.-t° E ° 2 o ��_0 _ E -o o o c m L CD(°0 'm t -(o-' o_ " o E 0 0 a )< 0 -o 0 ° E o L a) - _ s o o E E U L Ln o . •• ° o-).c ° ac m E o 0 0 >, E m (0J .N m o °.� o) .3 N 0 = a) m p u) a) 7 r 'O p _O'o p 0 c6 U N . EO "06 C C O o.° C c a) -c-,•,-; U LO 0.) Q) U a '' o a _0 _0 N U -0 T o C U C 0) - L L 01 O) f° to I°Y (/)Q v o p -cE- p CL o° 0 .... E ci m o m E N U 5 l° = a) o E 0 .N o -� �-6 El (n (n U E a)(n (n > U U 2 u. co 4 U o r 2 Q N_6_. 2_E 2 o_ N 0 0 0 ¢ a) c c N ca 0- ao 0-o c0) (° L N oma .30 -6 C oa) c U m [1 CO N U L cc ca Oc 0 _ 3 � U _c N cc)RI - 0 j O a) O O U O E o_ _) = u) p .- E U a x -6 t° E 2 O U ° O E a) O U.L.. CL CD U • 0 E O O n o 0 °a)O C E m > 0 0..0 a) m 0 o E • - -0 O • C a) O E,a,.,_ N LL E o a°) o O l..-0 O C 0 N F-- O m Z TREE= 4-1/16.CMV • -- WEL LFEA D FMC L2-14B 2-1 /� B S/ 1y NOTES: WELL ANGLE>70"@ 9659'. ACTUATOR- BAKER C '7' 4-1/2 CHROME TBG INITIAL 8 L2-14A KB.H EV= 45.0' WELLBORES NOT SHOWN ON DIAGRAM ,ti" BF.ELEV= I I KOP= 4400' Max Angle= 102°Q 9929' 10-3/4"CSG67' ----->< X Datum = 9617' 45.5#,J-55 BTC, 2194 —4-1/2"FES WE LSTAR TRCSSV,D=3.813" Datum TVD= 8900"SS D=9.953" LOCKED OUT(12113/04) GAS LFT MANDRILS 10-314"CSG,45.5#,L-80 VAM D=9.953" —j 3897" , , ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3014 3014 1 KBG-2 DMY BK 0 01/13/04 4 4793 4774 22 KBG-2 DRY BK 0 08/23/15 [7-5/8"CSG,29.7#,L-80 NSCC XO TO BTC --i 4482' — 3 6227 6014 32 KBG-2 [MY BK 0 08/23/15 2 7660 7231 29 KBG-2 MY BK 0 08/23/15 — - 1 8975 8396 30 KBG-2 OMY BK 0 10/06/15 Minimum ID =2.74" @ 10496' MILLED SHOE I 1 9044'-1-14-1/2"HES XNIP,ID=3.813" - . 11,-...-44 9065' H7-5/8"X 4-1/2"S-3 PKR,O-3.875" ill 9072' —13.7"BIT DEPLOY SLV,C=3.0" 1111 9076" (-{3-1/2"X 3-3/16"X0,13=2.80" I 9131' —14-1/2"HES X NP,ID=3.813"-I BEHIND 9207' HBOT SETTING SLV,D=5.75" CT LINER 9214' I—7-5/8"x 5-1/2"BOT HMG HY D HGR,ID=4.892" 4-1/2"1BG,12.6#,13CR-80 VAMTOP, H 9223' / \ ' 9223' H4-1/2"TT W/MLLE SHOE C=3.958" 0152 bpf,ID=3.958" 7-5/8"CSG,29.7#,L-80 BTC,13=6.875"1-1 9411' al MI.LOUT WINDOW (2-148)9515'-9526' 5-1/T WHIPSTOCK(05!28104) H 9515' —9500 H ESTVIATED TOC 06/03/04) 41 5.1/2"LW, 17#,L-80 FL4S,.0232 bpf,ID=4.892" I— —9515 V41 .VVT•44.e, . BKR NFI.ATABLE STANDING VLV(05/28104) 1--[ 9620' ,: 4.1j0(�►,,4 ♦t,011.ii 01111/411 5-1/2"W -- HIPSTOCK(01/18/04) H 9655' J11.111111111111 �.1*141111 11111111111111 111 111/1111 111*.C.�1111� . e'.e.V. 4.4 e PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF:WA Note:Refer to FFoductian DB for historical pert data PBTD 1— 10460'// SIZE SFE INTERVAL Opn1Sgz DATE 4-1/2" SLID 9387-10460 O 06/11/04 33116"LNR 6.2#,L-80 TO,.0076 bpf,ID=2.80" H 10493' 2" 1 9495-9555 0 10/28/15 BTM OF OFEN HOLE MLLB)SHOE w/2.74"MILL(12/06/04) —I 10594' I DATE REV BY COI M3irS DATE REV BY COMMENTS LISBURNE INT 11/18/87 128E INITIAL COM PLERON 11/18/15 GB/JMD PULLED BP(11/16/15) WBL: L2-14B 01/13/04— N2ES RWO PERMIT No: 2040950 01/27/04 NORDIC 2_CTD ST(L2-14A)-OPEN HOLE _ API No: 50-029-21758-02 06/12/04 NORDIC 2 CTD SIDETRACK(L2-14B) SEC 18,T11N,R15E, 1557'FSL&1273'FWL 11/04/15 NIC/AC/ ADFB S(10/28/15) 11/04/15 JONJMD SET BP(11/03/15) 8P Exploration(Alaska) Lo • O O a, el N U > 0 " U a) CO N X f6 -C N - d O Q aJ Q O a) O VI K I- a) t _c Z c 0 ti4 '_' H >- Z to CO O a v) u y o r c o c :5 0 0 aj co > °- Q www C LU in N N in in N L O w E co ca v hoz 0 ,- 44 r U t N '"' a) O Y y C/) \m O V o > > > > 0 `n L C E 0 H Q Y W 0 Z Z Z Z Z Z 7 'p 0 Q > C Z _ Q N O O l44 (IS N N C c0 a) >' a) Q i Q.) va °' > 0 0 0 0 0 0 0 C v Y - , a W W W W W W W c a Q o H LL LL LL LL LL LL LL .1 a) E 0 C. D L",i C Q J J J J J J J Q p C Z• CM a Z Z Z Z Z Z Z u v -0 o a 2-4 LL LL LL LL LL LL LL CICO tz L.= U au . _ Q 4--, cu W o a O Z w O_ v -0 V ti O C O - C a) ." [ o v a r d F- > >c O v .0 t0• < N E LL LL LL LL ;•• , O _10000 teO V a0cnnOOCe 4,1 J J J C40IC iy — 0- 0- O.03 C E. O 2 vcr c� MI UtriLY I•I rj) . <. WV > ro0 IiiCCO a O c' 0 z`•. p9o' P `v on T T T T T T CU CU 2' m m m Z m m m L Z• o o o D Ce o o O _= O L L L m L L L \ L w 3 3 Z .-(n - 3 3 3 4J U U Cr. a a` LLQ a cm0 C4-. r J Oa X Q0 4....." �"'' Ir.j. w QO oina n uN coC'bij 'ti-' 0 cc O N O O ,- N O O WO 0 0 O O O p O O O O O Oro U it = T- E • NcoO m N > CD w V U V 0 0 c w N as 9e4 g ra in N N OrQI N N 0 0 0 u p7ON ONNr O Or) Co O0 O OD E 71 0 L v C VI N N N N N N N y p10 0 0 0 0 0 O •` O O O O O O O7-- U) U) U) U) U) U) N Q1 L CO e Q O� C N az K U1 fa a) @ a) ice! w C E v •> U 8 a m o1 CO a M M :° E 13+ N Ih��p R7 Z M O O r9CU I— d .. = E N L N LL O LL J Z O O E Z vii Y C = C' w C CO vl '▪� N. 3 ._ ai co vOF ry I1/j, 4, THE STATE Alaska Oil and Gas o fALS► <. Conservation Commission _� � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OFALASI-� Fax. 907.276 7542 www aogcc.alaska.gov David WagesNSE© �, ''y 1 8 2 "�i Well Interventions Engineer Sa BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, LISB L2-14B Sundry Number: 315-298 Dear Mr. Wages: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Ay of June, 2015 Encl. RECEIVED STATE OF ALASKA v1AY 14 20 5 ALASKA OIL AND GAS CONSERVATION COMMISSION piS (/S /5 APPLICATION FOR SUNDRY APPROVALS AOGC 20 MC 25.280 1.Type of Request: Abandon Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ 4.411— i5 Perforate❑ Pull Tubing❑ Time Extension[2] Operations Shutdown❑ Re-enter Susp.Well LJ r ,��L r r Stimulate 0 • Alter Casing❑ Other of C CJ 2.Operator Name: 4 Current Well Class: 5 Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 • 204-095-0 • • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P O Box 196612,Anchorage,AK 99519-6612 50-029-21758-02-00 . 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? LI SB L2-14B • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028321 - PRUDHOE BAY, LISBURNE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured). Junk(measured). 10598 • 8917 • 10598 8917 • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 32.66-112 66 32.66-112.66 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9411 7-5/8"29.7#L-80 30.36-9441.2 30 36-8802.87 6890 4790 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft): 9387-10460 8754.5-8919.2 4-1/2"12.6#13Cr80 13Cr80 28-9225 99 Packers and SSSV Type. 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 9067.95,8475.79 4-1/2"HES TRSSSV 2197 18',2197.15' 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Development E ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil E' Gas ❑ WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date. WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Wages ' Email David.Wages@BP.Com Printed Name David Wages Title Well Intervetions Engineer Signature �C/ /V// / f Phone 564-5669 � Dat5 Prepared by Garry Catron 564-4424 � COMMISSION USE'ON Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 5- Z \ O Plug Integrity ❑ BOP Test ❑ Mechanicalif-a. Integrity Test ❑ Location Clearance ❑1. Other: POST infCiv► (eQUdA +o `a. P Foc-01 C�i,Pi�'+�tt.. 4 JlkiO.Iure R.Q�/t/ Www. Fc0.c�pGVY, or ()los a t&a u,ce-0-re,, -s 4 .20 /l- C, 2S 2,9 v 2,-,,,,,,�JiasS �lJl�l✓, fl GtGtom/ ir'c G/7Cra i`o 'i5 I. re -r"c iv), v-7ifc,# ,",—,: sl-, ,.< _,_5 rah o >,45 Shall lfr"�td a1 I7 erase c« cj p 5/—p' ac pn5 shy l/ �� � " Spacing Exception Required? Yes U No 12 Subsequent Form Required: 0 QrcD 4- APPROVED BY / Approved by: P�e 1. COMMISSIONER THE COMMISSION Date: ‘ _ C— /S--- I/TL 6 /5-7 i,r. ,172/4-- ,, � 6 / / 0Ripeel At� _�n A F,z Form 10-403 Revised 10/2012 c is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate c.-b1--,1 S—/z1//j RBDMJUN 1 1 2015 -000001.) O02 v CO CO CO in CO CD I J J -3 J co a) Q O 0 0 0 0 (U f� 6) O co 0) CO O I� O N O V O CO N N N- U o 0 0 0 0 C. 0 � Cr) 0) tCO CO D - co - f- O N v CO N- CO O CO a) Cn • co co co O) co m O 00 CO CT N CO r CO CT O - CO 00 00 CO 00 I- C2 O O CO CO CD N- O) N 0) CO QCO CO O CO 0) N CO CO (13E N M n -- CO LO rn co 00 CO VN- r 0) N N Q CA C7) O c) 6N) O � J ' C Q Q 0� F— M O � CD N 0) CO 0 Q CO CO O NCO CA N O) CA O O co CD co O O O CO rCC) CO i J J Cr) • IO Ch NO O U) N CA CN N N 751- co M M N N A 0 66 �- O co O O I-- co CA co V co co J 0) CO 0) CCw CT L D .� Uw ww U Q CC CC w u_ Z Z w w w [Yl Q F Z_ Z_ J D U Z J J (n (n TREE= 7 I SAF. JOTES: WELL ANGLE>-70"c 9657'. WELLHEAD= FMC L2-14B """ ACTUATOR= AXELSON4-12"CHROME TBG—L2-14A WELLBORE KB ELEV= 45.0' I NOT SHOWN ON DIAGRAM. BF. ELEV= KOP= 4400' Man Angle= 100°@ 9775' Datum MD= 9617' 0 2194' -4-1/2"HES WELLSTAR TRSSSV,ID=3.813" Datum TVD= 8900'SS LOCKED OUT(12/13/04) GAS LIFT MANDRELS 10-3/4"CSG,45.5#, L-80, ID=9.953" H 3897' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3014 3014 1 KBG-2 DMY BK 0 01/13/04 WI 4 4794 4774 22 KBG-2 DONE BK 16 07/11/04 3 6227 6014 32 KBG-2 DOAK BK 16 0727/04 2 7660 7231 29 KBG-2 DOME BK 16 07/11/04 Minimum ID = 2.74" 10495' 1 8975 8396 30 KBG-2 SO BK 22 0727/04 MILLED SHOE I I 9044' -14-1/2"HES X NIP,ID=3.813" `; >< ><\— 9065' -17-518"X 4-1/2"S-3 PKR, ID-3.875" 9072' H3.7 BTT DEPLOYMENT SLV,ID=3.0" 9076' -3-1/2"X 3-3/16"XO,ID=2.80" I I 9131' H4-112"HES X NIP,ID=3.813'•(BEHIND CT LNR) 4-1/2"TBG,12.6#, 13 CR, .0152 bpf, ID=3.958" H 9223' —j 9223' H41/2"TT W/MJLE SHOE BEHIND CT LNR) 3-3/16"SOLID LNR,6.2#,L-80, .0076 bpf, ID=2.80" H 9387' 1 7-5/8"CSG,29.7#,L-80,ID=6.875" - I 9411' 1--4 ' ' ' MLLOUT W NDOW 9515'-9526' TOP OF WHIPSTOCK '- 9515' \` BKR INFLATABLE STANDING VLV -{ 9620' MAW* 111111111111111 111111111111111 111111111111111 111111111111111 111111111111 **III*** 11�t 4�11111 5-1/2"LNR,17#, L-80, 0232 bpf,ID=4.892" -1 9976' PERFORATION SUMMARY PBTD --I 10460' 77 REF LOG: ANGLE AT TOP PERF: TOP OF SLTD LNR @ 9387' 3-3/16"SLTD/SOLID LNR,6.2#, L-80, .0076 bpf,ID=2.80" -i 10493' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE BTM OF OPEN HOLE,MILLED SHOE w/2.74"MILL(12/06/04) --1 10594' L2-14B SLOTTED LNR SLTD 9387- 10460 0 06/11/04 DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 10/31/87 ORIGINAL COMPLETION 02/08/05 KEY/TLH MLL SHOE CORRECTION WELL: L2-14B 01/16/04 JLM/TLH RWO 12/03/05 RW/TLH CORRECTIONS(11/17/05) PERMIT No: 2040950 01/28104 TM NITLP CTDST-OPEN HOLE 03/01/07 RL DATUM MD API No: 50-029-21758-02 06/12/04 JOM/KAK CTDST(L2-14B) 07/03/07 SWC/SV TRSSSV UO(12/13/04) SEC 18,T11 N, R15E,979.09'FEL&4005.15'FNL 07/11/04 JLJ/KAK GLV C/O 05/14/12 CJWJMD REMVD H2S NOTE(05/10/12) 07/27/04 SS/KAK GLV C/O 05/14/12 JMD GLM CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS Before me, the undersigned authority, on this day personally appeared A C)-(CI LIC1 t) , who being duly sworn states: ,� 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the L2-14B Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On April 2, 2015, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 7th day of May,2015. ti V (Signature) /61- STATE OF ALASKA THIRD JUDICIAL DISTRICT f4+— Subscribed and sworn to or affirmed before me at Citf.frft ,e / At on the day of 17 , 20 Si ature of Officer/ \1166661{lFlf3/j//f Aid lin P�E L. d0,9`�Qr� Title of Officer I' Pulp C �of AI.P`��- O x/11111111% Date. March 30, 2015 Subject: L2-14B Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Wahoo Zones of well L2-14B. L2-14B is a 2004 CTD sidetrack well completed almost entirely in Wahoo Zone 6. It never fully lived • up to expectations for productivity and has been a short-cycle well for the past ten years. Although producing GOR and WC have remained low throughout the wells history it has only cumulated 280,000 total barrels of oil. Reservoir pressure has been reasonably good in the area ranging from 2250 to 2600 psi in L2-14B and its offsets. It is thought that low rock quality is primarily to blame for • L2-14B's productivity problems. Opening up a much larger area to flow via a propped hydraulic fracture treatment may allow for better cycle time or perhaps full time production We are requesting a variance to sections 20 AAC 25 283, a, 3-4 which require identification of fresh water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages Affidavit of Notification (20 AAC 25.283,a, 1) Partners notified: ConocoPhillips Exxon Mobil Chevron Department of Natural Resources Plat Identifying Wells(20 AAC 25.283, a,2,A-C) and Faults(20 AAC 25.283,a, 11) 4- 4'. 1 -•580' # T 4 4 4 1 mile Wells within 'h mile of L4-14B: L2-06 L2-24 L2-16 Per the plat above, there are no water wells within 'h mile of the subject well. The primary stress is thought to be in the N-S to NNE-SSW based on image logs as well as core data. This means the frac will grow almost perpendicular towards faults 1, 2 and 3 and will most likely result in the loss of some of our frac fluid to the faults. Fault Throw Magnitude and Direction 1 40-45' N 2 35-40' NW 3 20-25' S 4 10-15'WSW Faults 1,2 and 4 extend up into the HRZ and down into the Alapah. Fault 3 extends down to the Alapah but only up into the Ivishak set of faults. These faults could be open or partially open. If that is the case, there is a possibility that the injected fluids are not going to remain in the Whaoo. However, it is in our interest to keep fracturing fluids within the producing interval. If we see a pressure indication that the fluid has intercepted a fault (sudden, unexpected/non-predicted drop in treating pressure), we will evaluate the issue and possibly go to flush early. Prior to pumping the frac ✓ treatment, the frac geologic model will be re-calibrated based on the injection test. Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well L2-14B is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within ' mile radius per 20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) L2-14 Parent Well- The surface casing hole was drilled where 10-3/4" 45.5#, L-80 csg was run and cemented in place with 325 sx of 15.8 ppg Class G cmt. After plug was dropped, the casing was tested to 2500 psi for 30 min for a good test. A LOT to 14.2 ppg was performed after the shoe was drilled. The intermediate hole was drilled to 9411'. Once past casing set point, 7-5/8", 29.7# L-80 NSCC and BTC csg was run and cemented @ 9411' with 150 sx in the first stage and 460 sx of Class G in the second. Bumped plug and pressured tested to 2000 psi. A LOT to 12.5 ppg was performed after the shoe was drilled. A 6-3/4" hole was drilled to 9976 and 5-1/2" 17# L-80 csg cemented with 200 sks 35/65 Class G; 50bbls slurry @ 14 ppg, 25 bbls CW100 CW100 & 25 bbls spacer 3000 (9.5ppg). Bumped plug and pressure tested to 3000 psi. Cleaned out cement in liner to 9926' MD and tested again to 3000 psi. L2-14B Coil Sidetrack- A 3-3/4" hole was drilled to TD of 10,594'. 3-3-16" 6.2# L-80 TC11 solid and slotted liner was run to 10,493'. The first two years of production were relatively sustained at —400 bopd, since then, L2-14B has been an intermittent producer whose production rates quickly decline. Original logs indicated that invasion of drilling fluids may be a prime suspect for low production rates, thus a frac is planned to get beyond near wellbore damage. Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283,a,8) Tia ' SAFETYNCH9 WELL ANGILo -70" 9887'. WELLIEAD= ,-VC L2-14B ---4,10"CHHOMFTBG••'L2.14AWELLBORE AC't„ATpR- AXE-SONNOT SHOWN ON DIAGRAM. KH F.^V- 4S 0 8F F-EV= KOt'= 4400 Wax Argle= '06"@ 5775 OWL-IMO= 961T Co ----- 2104' 4!t2"t#$4YE1lS'RatIiSSSV J 36!5 Calt,'iWD- 990055 I0t:ROLX;1t71'/'04, GAS LFT WA'43%.,....8 13.11,4_SGr,554 L-80 0=4.059' 3897 51 !6T) 1V0 11;V IYij= '. V'.V ;A`:bi POW ITA TE 5 3014 3014, 1 KBG2 -DOT- 8K 0 017'-3'1541 111 4 4794 4774 22 K60-2 'DOME BK 116 077'1,134 3 9227 6014,. 32 KB0-2 DONE BK 16 07'27104 i 2 7860 7231' 29 KBG2 .DOME BK 16 07/11104' [Minimum!D=2.74"0 10495' 1 6975 8396 KI1C 2 s0 BM 22 01/27/04 MILLED SHOE L Soca' H4-1?»ES%'4'IO=3.5.3' ►� 9085' '0-818-x4.1!2"6-3tSN,10-3aF5 -----I 9072' I- 3!'I1 )i%sit cYA4N SIV in-;Iv .- 9076' -J3-'7 X 3-3115•K0 0=2 90•- 9131' . 4.1x2"ESXRN.ID=3.813'tBERNDCYLNRI , I t 1i7' 440.'2E:1 11 CR ,:It 54'me Y:•3950' t 9229' f 922J' •.I4 1)2'TT1M'Via- SiKk. 941W4DCTI (3.]".6 SOI D'.KR,6 2e.x-110 007E epr 0=2 ID' {~_ 9387' 1 (7.5,E CSG.29711-80.0=6075• H 9411' FA , , ik _ _. _ - t V UJLI Wl.DCM,95.1' %.•26' (T�OFWHPSTOCK 9H—FDF--1 I 1BKM n*LA IABLE S'PALING VLV -•( 9620' -4 $.4`- ALIVataflrlt1W 110011111 11111111/11111.1! 11111/1111111.11 1111111111111111 1/,.f1l•1111111a 811.1'1.4-8111 'b 1 V' 44 1.q 100. 0242 bat I'e 4 SW • 9976' -71, RE LOG l`__ 1 104160' I M.G.i-A•'08/4}8- tt)P01513'i NR@93137' 3.316'3'.1TXS0L16I.NR,i374•16Z, 0076 bpi..':)'280' I-f Y19819.3'_� i Note Rete,to Roduotcr'a9 for h,Btarieal serf:eta SIZE Sri' 'ITU `AL Dparmw CATE BTN 07 OPEN-7931..0 MLLED-5.-.OE w 2 74'KY,.I I O12 j 10594' 51 it➢ 5'1Ir-104E0 0 I Ll5lI44)4 DTE REV BY 1 COATI'_N75 GATE ;REV BY COMMENTS LISB,, r E UNIT 10731/87 iORIGINAL COMPLETIOY 02703105,KCYrLH';M._5-0t xRECTION WCL 12-143 01!16!04 JLM/TLH ;RIO '2/03/05 RM r u-;0012=.^.T0MS f'1717105; PERMIT No 21340950 01128/0TMWWTLP JCTDST-OPEMHOLE 03'0'707- RL ';r4ATUMMO • AP 1w 50-02=-775£-02 0411270_ JOMIKAK ,CTDST(L2-146) 07/03,07 SWOSV;TRSSSVL70(12.13/04) SEC'8 '•^N,R15E.979C8 TEL 5400515'=N- Nit1704 rJMAK IGLVCIO -- 05/14/12G.`YJNC:RGV0125NOT I(0671Q712) ' 3//77104 557KAK let'00 05'14112- .M) .0,.M CORRFC'IOtr5 J BP Etploratlan(Alaska) Name/Size Weight Grade ID Burst,psi Collapse,psi 10-3/4" Surface 45.5# L-80 9.953" 5210 2470 7-5/8" Production 29.7# L-80 6.875" 6890 4790 5-1/2" Liner 17# L-80 4.892" 7740 6290 4-1/2" Tubing 12.6# 13Cr80 3.958" 8430 7500 3-3/16" Slotted Liner 6.2# L-80 2.80" N/A N/A Wellhead: 4 t; F .4ii >it , 4 lib L.,..,,- it : , 4r,;':',,,,,,,y: . -114 :', . .-ii..-.1'1;‘,:: 4' ''-b-i::'!‘".- S'i : .'' ek- _,.�- .14 Ir. ":' 41,004. . , .4:,..U44. r}4,)4 ' ....., II) r y� ��imak- t y la -1111pr ! . 1. {yv FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 5,000psi Tubing head adaptor: 11" 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11" 5,000psi w/2-1/16" side outlets Casing Spool: 11" 5,000psi w/2-1/16" side outlets Tree saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" The treesaver is rated to 10,000 psi. wayazi ,. L . ' '0 i _ , ei.. ..,. , .... ::_., .• Fi..... ... , f,„ ....„ le 1 . . , • 33 4 I I � 1 9 . i E, { ------jjiib� !� J K_______ir.. ._ i ...L.—'2.._,.::,:;:!.i...11. ffim i, C♦ Geological Frac Information (20 AAC 25.283,a,9) Most geological information was taken from logs obtained from L2-14 (the parent well). The depths of the logs were simply shifted in order to match the depths of the welipath of L2-14B. It is important to note that the values for stress and leakoff are estimated at this time and will be corrected •' following an injection test that will be performed —1 week prior to the hydraulic fracture treatment. ND Depth Stress Stress✓t Stress at Fluid Loss 1 fZone 011 Stress Graded Top d Grade Dltarence t3Bottom d Coeffiasrt Sprat Propped from Surface Zana Zone Modulus Poisson's (Mod Loss Embedment Layer T .. (pee - (post!) Meese) R2t'o K-to mn •- 100ft"2 • 2 1 8740.0 0 ''® '® cm= 0.700 mmi2.500000 =En 2000.0 0.001170 ifzum 0.20000 2 1 0 3 8808.0 e y p Mall 0.700 MM. 0.700 6168.4 2.500000 MEM 2000.0 0.001170 9.00000 .20000 5 8924.0 Y O 1690.8 0.690 li1-v&m0.700 6163.9 2.500000 cum 2000.0 0.001170 9.00000 0.20000 6 8933.0 '- ••• 0lizzia az= ml. 0.700 II= 3-000000 MEM 2000.0 0.002790 .300000 '.20000 MD for each zone: TVD for each zone (from the table above): Kavik: —8700' Kavik: —9320' Wahoo 7: 9433' Wahoo 7: 9433' r Wahoo 6: 9452' Wahoo 6: 8794' Wahoo 5: 9595' Wahoo 5: 8959' 49326MDtt L2-148 10598 MID O n I • ; • 0 0 0 0 0 7 " I 8 MS 0.0 1800 2200 t).30a 0 360 en Pc! E K-Ic Poisson s ratio Coe$ Thermal (psi) (MMpsi) Expansion All the above data for each formation will be verified and corrected via an injection test to be performed prior to the fracture stimulation, this is where formation stresses and leak-off coefficient will be adjusted to match the pressure trend seen. Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Per plat above, the following wells have been reviewed for casing and cement information. L2-24: 9-5/8" 47#/ft L-80 casing set @ 9802' MD cemented with 638 sx Class G and 600 sx AS I 7" 29#/ft L-80 liner set from 9584' MD to 10600' MD cemented with 300 sx Class G Cement bond log run in 7" casing liner on 6-21-85 indicated TOC @ 9890' MD, fair to poor bond 9890'-10545' MD. L2-16: 7-5/8" 29.7#/ft L-80 casing set© 10571' MD cemented with 610 sx Class G and 200 sx CS I 5-1/2" 16.9#/ft L-80 casing liner set from 10353' MD to 11188' MD cemented with 171 sx Class G Cement bond log run in 7-5/8" casing on 10-2-87 indicated fair to poor bond 9600'-10550' MD. Cement bond log run in 5-1/2" casing on 10-13-87 indicated fair to good bond 10630'-11136' MD and good to excellent bond 10550'-10630' MD L2-06: 9-5/8" 47#/ft L-80 casing set®8076' MD cemented with 500 sx Class G 7-5/8" 33.7#/ft S-95 casing liner set from 7712' MD to 8788' MD cemented with 448 sx Class G 5" 18#/ft S-140 casing liner set from 8484' to 10150' MD cemented with 584 sx Class G (includes three cement squeezes after primary) Cement bond logs run in 5" casing liner on 7-16-93 and 7-28-83 indicated fair to good bond 8788'- 9400' MD andP oor bond 8460'-8788' MD. Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program included) Pump Schedule: Sage Stag. fluid Type Claalt Ct. Clean Con Mee, Crr 91vey Con Prnpprw Type Ran Rap/ Cm R.. Ramping Con O.ses.p.an 1Ia . 8(na Volume Clean Vir Sly Volume Slimy Cane. Sag. Roo (heal Time P.wtp tW IMM 01.11 Mel (pall III WA) 1535311 boa) (66) Pb.) T1a.. 0 PT estlds 107200 0 0 1 Load hole 143127 5980 5.1530 140.0 1000 5,880 5,880 1100 1000 NA 0 0 5 28.00 28.00 2 31.-e 0 5,880 0.0 1400 0 5030 00 100.0 NA 0 0 0 30.00 58.00 3 Pae-ead YF12751.0 0.100 7000 50.0 190.0 2,100 7380 500 190.0 NA 0 0 20 250 60.50 4 Pad 4F127F1.0 10500 11400 2500 440.0 5,500 18.400 2500 4e00 NA 0 0 40 6.25 86.75 5 553 43127314.0 2059 20.570 500 490.0 2.95 20,875 523 4923 201/0Cab8.. 2099 2,099 40 131 68.06 6 SS ',312731n0 2.0519 52.066 50.0 539.9 2.385 39.401 568 519.1 20/40 Cab... 6255 8.394 40 142 6348 7 9.3 3131273140 2.857 24,175 41.9 5899 2,578 25638 613 654 20103a68.. 9,487 18082 40 153 7101 8 540 31F1277140 2051 20.82 49.9 639.8 2.706 29402 409 6762 2090Carb.k. 14677 33.558 40 165 7266 9 SLF 0312731.0 4.112 31884 998 731.6 1.961 31,33 1408 8170 208803a5,8. 37728 71.286 40 3.52 78.9 10 Flats 031273..0 1092 *me 26.0 7656 1,090 35.406 26.0 8430 NA 0 0 40 085 76.83 11 Ruth 143127 Isle 318(8 26.0 7916 1,1392 38.498 70.0 869.0 NA 0 0 40 0.65 7748 12 Flush 101200 2.034 59918 50.0 8416 2.10 368% 500 990 NA 0 0 20 250 79.98 Clean Volua.Rano 3312731.40..44.8.. Hydration Curves for 3887 @ 511 1 1 Pad 12600.0 443% 880214.0.2.9.l 6.50 gal6e.mgal 51.9 15.8345 55.7% J6041oost8.,l 220 504P.ng01 L-1 i I Taal 204345 677 dols 14002 McNeal 170 gal Prngd J511 10.1.100 Agrel 400 Galpwmgal 3133450 VII W41 uaI It q.1005 aai Noonan.Cawnesalen Ratio F113315.1 octane 1.00 galprmgd *NM 100100844! Ropers l-6 9082 26.5% L0641C4y 9tabera0 2.00 gdpwmgal Reapers>13ppg 52,405 73.5% L0651Se.Metal 1.00 galpes gal 1.31.01,1.d•y.. Taal 71288 #275(31,04.) 030 Opel regal 4 IJ it 01 70 131 as l: 4, 151391Er..pWr.dorale04 0.5-60 bP..g1 Fluid I Regnant pet Re.088 8neas Net Pay Treat. 111 VF727 DontaYn: .1 Ruppan 14051 642 68821ge1a.9.ganl 650 gal Pr 051A Fluid 00•801 256 F10315od.o.,,l 100 9.1P...901 L0641CIay Stab/awl 200 g9Pnng1 Material Requite.... 108515.8.6.540,1 100 pionsAcid Requirement 0 M275(Rock. 0 30 Mar Reaerc ene. 842 Ws J56916apoJr8, ed .aktel 05-.0 6pe: eget 0 rugal a %p.m Requiems. 71286 lbs 66%da.pera 47,019 I moi• le Si ee h a. M 100 114 I:0 7.:eP•talur A•1F '. Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 5500 psi Anticipated half length: -200' TVD Frac top: 8795' • MD Frac top: 9432' . TVD Frac bottom: 8933' MD Frac bottom: 9597' The above values were calculated using modeling software. � Surface pressure is calculated based on a closure pressure of -0.5 psi/ft or -4400 psi, this combined with hydrostatic loss, the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the cleaner Wahoo formations and the shales/Kavik formation and the softer confining layers. Average confining layer stress is -0.69 psi/ft. ✓ Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values we used, a half length of 200' is expected. Pressure Test Information (20 AAC 25.283,a,7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 5000 psi and the tubing will be tested to 4500 psi (110% of max differential of 4090 psi). PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 6400 psi Stagger Pump Kickouts between: 6080 psi and 5760 psi (95%to 90%of MATP) Global Kickout: 5760 psi (95%of MATP) IA pop-off set pressure: 3375 psi (75%of MIT-IA) Treating line test pressure: 7400 psi Sand Requirement 100,000#20/40 Carbolite Minimum Water Requirement 750 bbls(pump schedule: 550 bbls) IA Hold Pressure 3000-3250 psi OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r L2-14 Rig Upornmpenunn 1 vat,*has Traeava mounted on even 721 Inner Annulus Line t 411 aiBomElCl ontre�g lie pump forlApcoonno control Boom Truck t r Prop Fad Dump i L _ J Chemical Disclosure (20 AAC 25.283,a, 12) Fluid Description(s) YF125FIexD:WF125 51,198 Gal Contains:Water,Guar Polymer Slurry,Surfactant,Breaker,Crosslinker,Scale Inhibitor,Clay Control Agent,Additive, Bactericide,Propping Agent The total volume listed on the nobles above represenn the summation of water and additives.Water a supphed by chant CAS Number Chemical Name Mass Fraction _ - - Water(Including Mix Water Supplied by Client)* • "85% 66402.68.4 Ceramic materials and wares,chemicals -14% 64742-47-8 Distillates(petroleum),hydrotreated light I <1% 9000-30-0 Guar gum <1% 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride <1% 107-21-1 - Ethylene Glycol ! <0.1% 7727-54-0 Diammonium peroxodisulphate <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphlnate <0.1% 111-76.2 2-butoxyethanol----- <0.1%_--- 67-63-0 Propan-2-ol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 1310-73-2 Sodium hydroxide(impurity) <01% 11138-66-2 Gum,xanthan <0.01% 34398-01-1(3E0) Linear C11 akohol ethoxylate(3eo) <0.01% 68131-39-5 C12-15 alcohol ethyoxylated _ - <0.01% 34398701-1(7E0) Linear C11 alcohol ethoxylate[leo) <0.01% 68953-58-2 _ _ Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 1330-43-4 Sodium tetraborate <0.01% 7631-86-9 Silicon Dioxide <0.01% 7647-14-5 Sodium chloride <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 10043-52-4 Calcium Chloride <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 14807-96-6 Magnesium silicate hydrate(tale) <0.001% 10377-60-3 Magnesium nitrate <0.001% 68153-30-0 Amine treated smectite clay <0.001% _ - - 111-46-6 2,2-oxydiethanol(impurity) <0.001% 9002-84-0 poly(tetrafuoroethylene) <0.001% 26172-55-4 5-chloro-2-methyl-2h-isothiazobt-3-one <0.001% 7786-30-3 Magnesium chloride <0.001% 7447.40-7 Potassium chloride(impurity) <0.0001% • 2682-20-4 2-meth -2h-isotia2o1-3-one <0.0001% 14808-60-7 Crystalline silica(imPAY) <0.0001% --- - _ ----- --- 14464-46-1 Cristobalite <0.0001% Total 100% Wellwork Procedure Request To: Well Services Operations Team Lead Date: 4/15/2015 Wireline Operations Team Lead VER1 AFE: APBFRACS From: David Wages -Well Intervention Engineer IOR: 100 Est. Cost: 800K Subject: L2-14 - Pre and Post Frac Procedure Please perform the following steps 1. S Load TBG/IA, D&T, Install plug, CMIT TxIA, dummy GLMs 2-5, circ packer fluid, dummy Sta 1, MIT-T, MIT-IA, Pull plug 2 F Assist SL w/ CMIT, Circ packer fluid 3 E Perforate 4 S Run memory Spin/Temp/Pressure tools (pressure sensors set to record on 1 second interval) 5. F Injection Test 6. F Hydraulic Fracture Treatment 7. C Post frac FCO 8. S D&T, Install GLVs 9. T Post frac flowback Current Status: Operable Minimum ID: 3-3/16" Slotted liner, ID: 2.80" Max Deviation: 102 deg at 9929' MD Top Perf Deviation: 27 deg at 9387' MD Last TD Tag: NA well angle > 70deg at 9688' MD. Last Downhole Op: 5/10/12: SBHPS and pull QOS SSSV from TRSV SBHP/SBHT: 5/10/2012: 2246 psi and 184F at 8900' TVDss datum. Latest H2S: 40 ppm, 5/2/2005 Program Contacts Contact Phone -Work Phone -Mobile/Home Interventions Engineer David Wages 907-564-5669 713-380-9836 Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Page 11 of 8 L2-14B is a 2004 CTD sidetrack well completed almost entirely in Wahoo Zone 6. It never fully lived up to expectations for productivity and has been a short-cycle well for the past ten years. Although producing GOR and WC have remained low throughout the well's history, it has only cumed 280,000 total bbls of oil. Reservoir pressure has been reasonably good in the area ranging from 2250-2600 psi in L2-14B and its offsets. It is thought that low rock quality is primarily to blame for L2-14B's productivity issues. Opening up a much larger area to flow via a propped hydraulic fracture treatment may allow for better cycle time or perhaps full time production. >5/2012: Drift to deviation @ 9688' w/ 1.75" bailer (no sample), Ran SBHPS Drift w/ 3.84" no-go cent to 4-1/2" QOS SSSV @ 2178' SLM, pulled QOS SSSV >11/2007: Ran 1.90" cent and S-bailer to 9710' SLM, stop due to deviation. Ran SBHPs as per program SlicklineLoad TBG/IA, D&T, Install plug, CMIT TxIA, dummy GLMs 2-5, circ packer fluid, dummy Sta 1, MIT-T, MIT-IA, Pull plug 1. Drift to deviation 2. Load IA and TBG with crude • 1.2x tbg vol to top slot: 170 bbls • 1.2x IA volume to orifice: 285 bbls 3. Install plug in X-nipple at 9044' 4. CMIT TxIA to 4500 psi 5. Dummy off stations 2-5 6. Install circ valve in station 1 7. Circulate 9.8 ppg NaCI, freeze protect with dead crude. • See attached fullbore pump template 8. Pull circ valve and install dummy 9. MIT-T to 4500 psi 10. MIT-IA to 4500 psi • Hold 2000 psi on tubing during MIT-IA 11. Pull plug in X-nipple at 9044' 12. RDMO Fulfbore Assist SL w/ load, CMIT, Circ packer fluid Total volume for IA &Tbg from Sta #1 is 375 bbls Freeze protect to 500' (-21 bbls crude) 354 bbls 9.8 ppg NaCI with MI KI-3869 corrosion inhibitor/0.45% v/v • Pump down IA and up tubing • Use methanol spear as required • See attached Fullbore template E-line Perforate 13. Perforate from 9495'-9555'. • Use 2" guns with 2006 PowerJet, HMX charges (Bighole charges) • 1 spf, 60 deg phasing • See Attached tie in log. Slickline RIH with memory STP tools, pump injectivity test, Page 12 of 8 14. RIH to deviation with Spin/Temp/Pressure (pressure gauges recording every 1 second) memory tools 15. With tools at deepest point, pump water injectivity test as stipulated below. 16. When done with water injection test allow tools to soak for 1 hour. 17. PUH to 9300 MD. Pump 2nd injectivity test with crude oil. 18. When done with 2nd injecivity test allow tool to sit for additional 10 minutes and then POOH. 19. RDMO. Fulibore Injection Test • Please call David Wages prior to pumping injection test. 20. Pump the following down the TBG at max rate (8 bpm) not to exceed 4500 psi. Please attempt to keep a stable rate if possible. 1. 5 bbls neat meth (if necessary) 2. -190 bbls Crude • 8 BPM is important, please RU hardline. • Record surface pressure and rate at 1 second intervals. • Work with SLB to obtain BH gauge data at 1 second intervals. • Perform hard shut down of pumps (do not operate tree valves) and monitor pressure decline for 1 hour. • When memory tools logging tools have been moved up hole 9300' MD, bring pumps on line and inject crude oil at maximum rate for 10 minutes. Then shut well in and RD. • Send pump rate and pressure data to David Wages Fuilbore Hydraulic Fracture Treatment 21. Frac treatment per pump schedule. Pressure testing Maximum Allowable Treating Pressure: 6400 psi Stagger Pump Kickouts between: 6080 psi and 5760 psi (95% to 90% of MATP) Global Kickout 6080 psi (95% of MATP) IA pop-off set pressure 3375 psi (75% of MIT-IA) Treating Line Test Pressure 7400 psi Sand Requirement 100,000# 24/40 Carbolite Minimum Water Requirement 750 bbls (pump schedule: 550 bbls) IA Hold Pressure 3000-3250 psi (IA pop off set at 3375 psi) OA Monitor and maintain open to atmosphere Coiled Tubing Post frac FCO See Appendix B for FCO procedure Slioklne D&T, Install GLVs Page 3 of 8 22. Drift and tag fill. • Previous SL runs have deviated out around 9000' 23. Install Deep GL design Testers Post frac flowback 24. Post frac flowback Page 14 of 8 Appendix A - CT FCO Procedure Notes: • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate post frac well test. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA. 3. RIH down to estimated sand top and begin cleaning out with slick 1% KCL. 4. Continue down to 9387' CTMD. At this point we are at the slotted liner. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the slots. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 5. Slowly continue to clean out until returns fall off to -80%. If returns are still good even after the nozzle is past the slots (not likely but possible), continue to clean out until returns show trace amount of Carbolite. 6. FP to 2500'. 7. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 8. RDMO. Page I 5 of 8 Appendix B -Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 16 of 8 TREE= _ _ i j 41&_LEAD- -FMC L2-14B SAFETY NOTES: WELL ANGLE>-70'@ 9657'. ACTU4T.^,? AXE15f{J '"'4-112"CHROME T9G'."L2-14A WELLBORE KH FL-V- at;0 NOT SHOWN ON DIAGRAM. OFEEV= KOP c . 44;X7 Max Angle= 100*0 9775 Datum MON 95'7 {� 2194', }-4 l!7'? .SWFl191AR Ik$SSV,IU 381L1 Datum TVD- 8900 SS I CC.KED OUT 02, .t.n4) GAS LET W ORTIS ST_MD `v_ DEV TV VLV LATCH 15131111 CA-7C: 10-34';SG.45 50,L-80, D=q 1,T f 1 3697' 5 3014 301 a 1 K9 2 OMY OK 0 401 f 35541 4 14794 4774 22 KB0-2 D04E BK , IS 107/11/041 3 16227 61314 32 '696.2 OCHE OK 16 0727VO4 2 (7660 ?23f 29 K8G-2 004E 13K 16 011'1104 Minimum ID=2.74" @ 10496' 1 18975 8396 33 K8G-2 SO BK 22 0712'7/.4" MILLED SHOE I { 9044' j-44-11,2'HESX MP,ID=3.813' { 9065' -1 li 9+1J x i.14'6 3 I.4.-{ r„ 3 an i ril _.. -. 9072' i-�3 r H DEPL.OYMLNL S.V 1L`=3.0'J .R.1 9076' -I 3.112"X 3-3)16'X0 ID=25,0 I I I w `9131' 1--94 11,. 'HFS X%IP 10.3 81 MERINO CT L188 i 4-112'1'9c 12.64 13-C R. { ID-3:6�a8' )-i 9225• , 0 • 9229 44 t12'TtNUMUlF.9HCC1lINt5C1 LNM' 13-,y18'SOL n t Nfl 6?X SC, 0076 W, =t 80" !-! 938 77-54'CSt;,29.7N 83 O=8 875" ll� 941L. 1' ' — MLLOLT 14140044 9515-5625' TOP OFW.IPSTOCK 9616' + ` 19/04114-;A 1A BLE 6rAr+471Nc1 VLV J--{ 9620' 1 -,<,,,- ik•l 14 9 Mr 44449 �j04 511241.149-174-i.60 0532 bp.I ID-ti[+07" 99/8' KM-ORATION SL MAANY rP[1TU}I 104 J-77-7.- ��j REF LOQ. ANLL EAT TCP!PRF TOP OF St TO I MR ft 9367' L3-311O'SLTtDSSOLID LNR 6 20,L-80, 0078 t1pr D 2 8L"' j-t 10493' ' Note:Refer to Roauclion DEI for^stIzak perf:eta i Sit 1' . SPF IN?FRJA Ovu qz 117E 9-1.1 OF OPEN HOLE WILLED SHOE w1174'mi.; .17.'09,04) I-{ 10694' 1, t L2-14B SLOTT ED L NFIr :SLID; 9001-"0460 0 06,11/74 i ' DATE ( REV BY COMMENTS DATE REV 9Y COMMENTS LIS3J3NE UNT 10131147 ( ORIGINAL COMPLETION 02001135 I(EYrtH W.I.SHOE CORRECTION WELL L2-148 } 01116/04 ! JLMITLH FM) 1210105 RIN(TLH CORCTONS 1,11117X.15! PERMIT No 2040950 01123104 1 TM MTLP CT DST-OPt3N HOLE C.3f011D7 RI 7147,113 6+:7 AP N= 5C-029-2175.402 06112104 JOMIKAK MST ST(L2-'148) 1)7/03/07 S.IIJSV TRSSS,.L O 12+13104) SEC'0 Tl 1M R1 5E,979 OR FELE 4006 15 FNL 07111/04 I J1.J'±4AK GLV C/0 0511-4112 CiWJ!1) RIANNO1-fcSNOTE(05110/12;s 07/17/04 r SSIKAK CLV 6a .. C6114112 .11.6) GLA!CORREC'r1C)4S I 9P Exploration(Alaska) i Page 17of8 TubeMove Calculations Force(1b0(+Tensile) o m m o o 0 0 0 0 0 0 L. 0 m CO o o 0 0 0 0 0 0 0 0 0 CD No 0 0 0 0 0 0 0 0 0 0 m 3 o 1 I I I e y 0 7 n m (o o 0 0 m m 01 AO O 40 4.0 40 0 W O A j j 0 0 0 CO O -• 10 00 0 Ol t0 O RI (J 0 _. V o N t1 7 O O o 0 O O 0 C ♦ .' a l a 3 0 .7 N 0 O 0 C ari o g N 7 ,11 v m F w d Ammo. �1 m o- o - 0 to �� i• W 0 0 ,, w (a to -( 1 3 0 (, 0 13mr- 1- 0 O °D P to v ° v, 0 3 c 10 o C C C W o T C O 7 7 LT. a S 7 r - o, A o rn D 1 d A H . n ; 05 m e • O 7 o H _. o 7 o N O Effective Differential Pressure(psi) p MD(tl) 1 m W N 0 (0 .I 0, A W E. O OD T A N ro A 01 OD O 7 0 0 0 0 0 0 0 0 0 N r o 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 o 0 0 3 O to o m; oO Z O T O CO N A 0 Q tJ _ ,, , O N r �; o N 3 -o O 'A CD-a A A m o 0 y o o c n o c y v o ii $ o_ 'O V N N C O p 0 0 1D o 0 O-0..-• ... • •.._._._N. 0 -, 0 3 0 • ' io w co• — .. 44 o co 0 0 $ J�'" O : : : D I .r�. in 0 N • _, A {tr[` 1. -ncn N • , • FS 0 0 �• ; • 0 O *47 JO o • d o— •i a O -1 - 1,-.. /yI 0- - , 1711 O W / ''. 0 0• 0 Si 0 '0 _ A• • • • x + o T+ Mss 1 N y tKJ oo 8 N a. a y D 1 d o- - n A t 7 o c o m o_ m m 7 o 2 T 5 m 0 0 0 W m N =( 1 a 0 'p, 7 7 CD . 0 D -i d NYT to 7 nlet 0. 1 O (p 0 c !o o 0 0 O O Page I8of8 PBU 12-14B (PTD 204-095) Proposed Hydraulic Fracturing Operations Note to File Recommendation Allow fracturing operations within PBU L2-14B according to BP's proposed plan (Sundry 315-298), with the following stipulation: During fracturing operations, if pressure monitoring suggests fluid loss to a nearby fault,fracturing operations shall cease immediately and post fracturing operations shall begin. Discussion BP proposes to hydraulically fracture the uppermost portion of the Wahoo limestone within the PBU L2- 14B well,which is located in the east-central portion of the Prudhoe Bay Field. There are few wells near the proposed interval for fracturing operations(Figure 1; note that wells L2-14 and L2-14A are plugged and abandoned). There are no freshwater aquifers in the Eastern Operating Area of Prudhoe Bay (see Aquifer Exemption Order No.4). The proposed fracture that will be generated in PBU L2-14B will likely intersect a nearby east-trending, down-to-the-south, normal fault(termed Fault 3 in Figure 1)that has an estimated 20' to 25'of vertical s000 -MOW* ---- \ soon L2-20 ` \\ \-8000 \-8000 \ \ \` 0\ L2-1 \_�000 \�000 i - -.---, _ --\-7000 \\-8000 \ 1` -7C -woo X3000 ------ --- 1 8-33A -7000-4000 \ \ . . \ -soon r000— , \\ \ \ 6000 6000 -2000 $� \ 1 )00 \ \ -5000 -7000 ., -8000 \ L2-14B -3001f-5860 \ -40003000 N ,oQ a000k 7 1 I I �2 14A �e;°� 7°S-:cis j�OQ°,.,— Fai 3��a` so0o I I -7..0 I 1 soon I I -woo 1 ,o or_ — N-4000-- -4600 L2-14 N V 5000 z —.400p N -/ 5000 III :000 — 18-4 -50D0"-4'' '• 8of1�00 / 1 -t- on�ncn n /.7nnn , Figure 1. Index Map displacement. This fault juxtaposes the Wahoo 7 interval and uppermost Wahoo 6 interval (in descending stratigraphic order) against the lower portion of the 55-foot thick, laterally extensive Kavik shale,which is expected to provide upper confinement for the fracture fluids (Figure 2). As modeled, BP expects the hydraulic fracture to propagate only within the lower pressured Wahoo 6 reservoir, with some possible fluid loss and fracture growth into the overlying Wahoo 7 reservoir interval. BP does not expect the fracture to grow upwards into the Kavik shale; however, nearby Fault 3 may provide a conduit for out-of-zone fluid migration. BP's application states that some of the fracture fluid may not remain in the Wahoo. However,while monitoring pressures during fracturing operations, if BP detects signs that the fracturing fluid has intercepted a fault(e.g., a sudden, unexpected drop in treating pressure), BP's application states that they will evaluate the situation and "...possibly go to flush early." Summary Prudhoe Bay is a mature field,with few wells near the proposed fracturing operations. Freshwater aquifers will not be impacted by the proposed operations. Correlative rights are not an issue within the field. The proposed operations will create a fracture that is expected to remain within the uppermost portion of the Wahoo limestone. The Kavik shale is expected to be a competent upper confining interval; however, nearby Fault 3 may provide a conduit for fluid migration out of the intended fracture interval. BP will monitor injection operations for indications of out-of-interval fluid migration, evaluate, and possibly terminate operations early, if warranted. 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U N Q C NI- a U 0. 0 o > U 'a QJ ---..4- " Oa EC t ..• vvi 0 Q TRFF.= v W3LhEAD= FMCL2-1 4 SAFETY NOTES: CAT l-SSSV,1125 250 (PPM) ACTUATOR= AX'_LSON KB.ELEV= 45.0' BF.ELEV= KOPMax 4400' D 2148' 'LOCKED 2-7/8"CAMTRDP-1A SSSV, D=2.313" Max Angle= 33 @ 6900' Datum MD= 9488' Datum TV D= 8800'SS CHEMICAL MANDRELS El ST MD TV D DEV TY FE VLV LATCH PORT DATE 1 2214 2214 0 JR-CJ-IZ DONE BK 12 07/03/91 110-314"CSG,45.5#, L-80,ID=9.953" H 389T I---A ' GAS LIFT MANDRELS El ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 2708' 2708 1 MC-FM-I0 DMY BK 3 5063 5019 28 MGFMHO DMY BK 4 7026 6687 32 MC-FMHO DMY BK ><" ,>C 5 8420 7908 27 HN PTY 09/16/03 6 9060 8469 30 MC-FMHO S/O RK* \I 9158' H7-5/8"X 2-718"H-B FKR I TOP OF 5-1/2"LNR H 9207' 1— °"' Minimum ID = 2.25" @ 9297' 2-7/8" CAMCO D NIPPLE 929T H2-7/8"CA MCO D NIP,ID=225" ili 2-7/8"TBG,6.5#,L-80, .00579 bpf,ID=2.441" 1- 9308' I 9308' —12-7/8"TUBING TAIL W/SHEAR SUB 9308' —ITT ELMD LOGGED 11/26/87 7-5/8"CSG,29.7#, L-80,ID=6.875" H 9411' I---A , FERFORATON SUMMARY REF LOG:LDT/CNL ON 10/27/87 9466' (—jTOP OF CEMENT 111111111111111 ANGLE AT TOP PERF:27 @ 9464' 11/1111/1111111 Note: Refer to Production DB for historical perf data 1111/111111 SIZE SPF INTERVAL Opn/Sqz DATE 11/1111/1111114 2-1/8" 1 9464-9490 S 01/12/90 1111111111111 111111111 44 11 / / 2-118" "S 9490-9511 S 02/26/89 11111111 2-1/8" 'S 9515-9559 S 04/22/91111111111111' 2-1/8" *S 9534-9588 S 11/25/87 11111111111111 2-1/8" "S 9534-9589 S 05/08/88 1111/1111111111 2-1/8" *S 9607-9688 S 11/25/87 11111111111111 1/1/11111/1• 2-1/8" `S 9610-9689 S 05/08/88 111111/11/111/1 2-1/8" "S 9705-9771 S 11/25/87 11111111111/11 2-1/8" "S 9717-9773 S 05/08/88 11111111111111 2-1/8" *S 9729-9796 S 04/22/91 1111111/111/i1., 2-1/8" "S 9804-9816 S 04/22/91 111/111111111 2-1/8" 'S 9827-9890 S 04/22/91 111111111111 2-1/8" "S 9652 S 04/22/91 '�1�11 1 SelectveShots • �1 9900' GLV RETREVINGTOOL;FINGER 1111 1/1, FROM TRDR1A SHIF11NGTOOL 11 1 PBTD 9914' I 111111111111,111111 040 44. 4144 44 1/11111111111111 5-1/2"LNR,17#, L-80,.0232 bpf, ID=4.892" —1 9976' .1.1.1.1.1.1.1.1. DATE REV BY COMMENTS DATE REV BY- COMMENTS LISBURNEUNIT 10/31/87 ORIGINAL COMPLETION WELL: L2-14 09/29/01 RN/TP CORRECTIONS _ PERMT No: 1871020 05/26/02 GRCRIh PERF CORRECTIONS API Nb: 50-029-21758-00 06/16/03 CMO/TLP KB ELEVATION CORRECTION SEC 18,T11 N, R15E,979.09'FEL&4005.15'FNL 09/16/03 JCM/TLP GLV C/O - 08/20/03 SRB/KK DUMP CEMENT;CORRECTIONS BP Exploration(Alaska) Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Friday, May 22, 2015 11:17 AM To: Davies, Stephen F (DOA) Subject: RE: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions Please see responses below in k i\ (el.IIIIIIIIIIIallill'illNiz' � ! A 'tom °� I t I- 14 // \tc\- \\:\.\ \N [. { s.. . 4 411 1 mile David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, May 18, 2015 2:21 PM To: Wages, David Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, I need more information concerning this sundry application: 1. Per 20 AAC 25.283(9), please provide a lithologic description for each fracturing and confining zone. 1 2. Within the application, BP provided a plat that identifies the L2-14, L2-14A,or L2-14B wells with respect to known faults. What geologic horizon is represented by this map? Top of Lisburne (top of Wahoo 7/bottom of Kavik) 3. At this geologic horizon, how far away are faults 1, 2, 3, and 4 from the ends of the fracture generated by the proposed operations? Fault 1: ^'1000' Fault 2: 400' Fault 3:The created frac will most likely cross this fault. Fault 4: Due to the expected length and direction of the frac, we would expect the frac would avoid this fault by' 250' 4. For faults 1 through 4, per 20 AAC 25.283(11), please provide "...information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius...". Faults 1, 2 and 4 will most likely avoid the fault due to frac orientation and length. Fault 3 will most likely be crossed by the frac, however, there are several things working in our favor: 1) The fault throw of 20-25' means that the Ivishak (above the Kavik) is not juxtaposed across the Wahoo 7. 2) We do not expect the induced frac to grow into the Kavik, in fact, the majority of the frac fluid should remain in the Wahoo 6 (as modeled) 3) The high viscosity of the frac fluid (^'600 cp) promotes a single wing frac oriented along the primary horizontal stress.The fault is oriented along the minimum stress.This means that the frac would have to overcome both the tendency to remain a single wing and the difference between the maximum and minimum stress. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 12:51 PM To: david.wages©bp.com Subject: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, Could you please check the "Geological Frac Information" section of BP sundry application to hydraulically fracture the PBU L2-14B wellbore? Comments: 1. the MD and TVD data provided in the two short lists aren't correct (approximate values for Kavik MD and TVD are switched; the same value is listed for the MD and TVD of the Wahoo 7); 2. the red-colored interval in the chart below the two short lists appears to be Wahoo 7, but the TVD depth on the chart doesn't match that given in the short list of TVDs; and 3. the orange- and yellow-colored intervals in the chart are labeled Wahoo 6 and Wahoo 5, but the TVD depths on the chart don't match those given in the short list of TVDs. 2 The introductory text of this section mentions the depths taken from the logs of the parent wellbore L2-14 were shifted. What shift values were applied? How were those shift values derived? Please re-submit this section of the application with corrections. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, May 19, 2015 4:15 PM To: Davies, Stephen F (DOA) Subject: RE: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions Steve, For two reasons, we expect the frac to only propagate in the Wahoo 6: we intend to perforate the Wahoo 6 in order to ensure that the wellbore is sufficiently connected to the wellbore at that point and the Wahoo 6 is where the majority of our production has come from. This means that the Wahoo 6 will have the lowest reservoir pressure and as a result,the lowest frac gradient. I would expect some of the frac fluid to go into zones 7 and 5, however,Zone 6 should receive the vast majority of the sand. Stress Stress at Stress at Fluid L, 'ND Depth gess Gradient Top d Stress Bcttom d Gothic to Top d Dill erence Gradient Modal Poison's �c from Surface Zone Zone Layer Zone fn1 Type fPs1} (ps,t) (Pal) (psi ftp {MMpa� ftetio K-Ic (min) 1 674a 0, Ka'ik Q 0.0 0.713 6231.6 0.700 6270.1 2.500000 0.85 2000.0 0.0011' 2 8795.0 Wahoo 7 0 -1292.1 0.588 8-0 0300 L 3 660E.0 E t, 0 117 6.5. 0.7 00 6165.6 0.700 6168.4 2.500000 0.35 2000.0 0.0011: 4 8812.0 Wahoo 6 0 -1780.0 0.498 4388.4 0.700 1=32111 3.000000 0.31 2000.0 0.0027: 5 6924.0 Sr CI 166,0.6 0.690 6157.6 0.700 13131= 2.500000 0.35 2000.0 O.0011 6 6633.0 Wel-005 E -1536.6 0.516 4627.3 0.700 0.0 3.000000 0.31 2000.0 0.0027: Zore MD for MD TVD for each zore (from TVD Lithological Name each zore: Thickness the table above): _ Thickness Descriptior Kavik: 9371" 61 8740' 55' Shale Wahoo 7: 9432' 14 8795' 12' Limestore/Dolomite Silty 9446' 5 8807' - 5' Shale Wahoo 6: 9451' 30 8812' 111' Limestone/Dolomite Silty 9581' 16 8923 10' Shale Wahoo 5: 9597' NIA 8933' ' 92' Limestone/Dolomite The Kavik will be the primary barrier that will prevent fracturing fluids from flowing up out of the Wahoo formations, it's stress gradient is currently listed at 0.71 psi/ft. The barrier to flow below the Wahoo 6 will be the silty/shaley layer between the Wahoo 6 and 5. Even though it is only listed as 9'TVD thickness, it should provide the confining stress necessary to contain the frac. At this time, BP does not name the shale barriers between the Wahoo formations. However, I do know that they will affect the way our frac grows due to the different lithology. Shales typically have higher Poisson's Ratio which translates to higher closing stresses, as a result they tend to be the primary barrier to height growth when fracturing. Once again, the values for stress and fluid loss coefficient will be adjusted based on an injection test performed prior to the frac. r.. I will answer the remaining emails as soon as possible. Thanks again for looking at this so quickly for us. David Wages o. 907.564.5669 c. 713.380.9836 1 W I E-AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, May 18, 2015 2:59 PM To: Wages, David Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, For the lower confining interval for the proposed fracturing operation, please provide:geologic name, lithologic description, measured and true vertical depth, measured and true vertical thicknesses, and fracture pressure. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 2:21 PM To: david.wages(abp.com Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, I need more information concerning this sundry application: 1. Per 20 AAC 25.283(9), please provide a lithologic description for each fracturing and confining zone. 2. Within the application, BP provided a plat that identifies the L2-14, L2-14A, or L2-14B wells with respect to known faults. What geologic horizon is represented by this map? 3. At this geologic horizon, how far away are faults 1, 2, 3, and 4 from the ends of the fracture generated by the proposed operations? 4. For faults 1 through 4, per 20 AAC 25.283(11), please provide "...information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius...". Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 2 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 12:51 PM To: david.wages@ba.com Subject: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, Could you please check the "Geological Frac Information" section of BP sundry application to hydraulically fracture the PBU L2-14B wellbore? Comments: 1. the MD and ND data provided in the two short lists aren't correct (approximate values for Kavik MD and TVD are switched;the same value is listed for the MD and TVD of the Wahoo 7); 2. the red-colored interval in the chart below the two short lists appears to be Wahoo 7, but the TVD depth on the chart doesn't match that given in the short list of TVDs; and 3. the orange-and yellow-colored intervals in the chart are labeled Wahoo 6 and Wahoo 5, but the TVD depths on the chart don't match those given in the short list of TVDs. The introductory text of this section mentions the depths taken from the logs of the parent wellbore L2-14 were shifted. What shift values were applied? How were those shift values derived? Please re-submit this section of the application with corrections. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, May 19, 2015 3:37 PM To: Davies, Stephen F (DOA) Subject: RE: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions Attachments: L2-14 WIRE CORP.las Steve, Using typical cement yield calculations and washout volumes I calculate a fully cemented 7-5/8" production casing: 7-5/8 cemented with 150+460 sx of cement 610 sx at 1.16 cu.ft./sk=708 cu ft= 126 bbls of cement Annular capacity with 30%excess: (8.25^2-7.625^2)/1029.4*1.3=0.01253 bbls/ft 126 bbls pumped/0.01263 bbl/ft=10,056 ft of annular footage covered by the cement. This means they should have received approx. 8 bbls of cement at surface. Due to the excess volume pumped, we would expect good cement coverage throughout the producing interval including up to the Ivishak or SAG. Logs for your reference attached in .las form, please advise if you would like a different format David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, May 18, 2015 4:04 PM To: Wages, David Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, Could BP please provide a current wellbore schematic drawing for PBU L2-14/14A/14B that displays all casing strings from surface to TD along with BP's estimate for top of cement outside each string? Does BP have a cased-hole gamma ray log in PBU L2-14 over the interval from 9400' MD to the surface? If so, could BP provide the digital data for that log to the AOGCC? These will allow AOGCC to verify that casing is cemented in accordance with 20 AAC 25.030 and that each hydrocarbon- bearing zone penetrated by the well is isolated. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 1 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 2:21 PM To: david.wages@ibD.com Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, I need more information concerning this sundry application: 1. Per 20 AAC 25.283(9), please provide a lithologic description for each fracturing and confining zone. 2. Within the application, BP provided a plat that identifies the L2-14, L2-14A, or L2-14B wells with respect to known faults. What geologic horizon is represented by this map? 3. At this geologic horizon, how far away are faults 1, 2, 3, and 4 from the ends of the fracture generated by the proposed operations? 4. For faults 1 through 4, per 20 AAC 25.283(11), please provide "...information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius...". Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 12:51 PM To: david.wages@bp.com Subject: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, Could you please check the "Geological Frac Information" section of BP sundry application to hydraulically fracture the PBU L2-14B wellbore? Comments: 1. the MD and TVD data provided in the two short lists aren't correct (approximate values for Kavik MD and TVD are switched; the same value is listed for the MD and TVD of the Wahoo 7); 2 2. the red-colored interval in the chart below the two short lists appears to be Wahoo 7, but the TVD depth on the chart doesn't match that given in the short list of TVDs; and 3. the orange-and yellow-colored intervals in the chart are labeled Wahoo 6 and Wahoo 5, but the TVD depths on the chart don't match those given in the short list of TVDs. The introductory text of this section mentions the depths taken from the logs of the parent wellbore L2-14 were shifted. What shift values were applied? How were those shift values derived? Please re-submit this section of the application with corrections. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 4:04 PM To: david.wages@bp.com Subject: FW: Sundry Application - PBU USB L2-14B (PTD 204-095) - Questions David, Could BP please provide a current wellbore schematic drawing for PBU L2-14/14A/14B that displays all casing strings from surface to TD along with BP's estimate for top of cement outside each string? Does BP have a cased-hole gamma ray log in PBU L2-14 over the interval from 9400' MD to the surface? If so, could BP provide the digital data for that log to the AOGCC? These will allow AOGCC to verify that casing is cemented in accordance with 20 AAC 25.030 and that each hydrocarbon- bearing zone penetrated by the well is isolated. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 2:21 PM To: david.wages@bp.com Subject: FW: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, I need more information concerning this sundry application: 1. Per 20 AAC 25.283(9), please provide a lithologic description for each fracturing and confining zone. 2. Within the application, BP provided a plat that identifies the L2-14, L2-14A, or L2-14B wells with respect to known faults. What geologic horizon is represented by this map? 3. At this geologic horizon, how far away are faults 1, 2, 3, and 4 from the ends of the fracture generated by the proposed operations? 4. For faults 1 through 4, per 20 AAC 25.283(11), please provide "...information sufficient to support a determination that the known or suspected fault or fracture will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius...". 1 Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Monday, May 18, 2015 12:51 PM To: david.wages@bp.com Subject: Sundry Application - PBU LISB L2-14B (PTD 204-095) - Questions David, Could you please check the "Geological Frac Information" section of BP sundry application to hydraulically fracture the PBU L2-14B wellbore? Comments: 1. the MD and TVD data provided in the two short lists aren't correct (approximate values for Kavik MD and TVD are switched; the same value is listed for the MD and TVD of the Wahoo 7); 2. the red-colored interval in the chart below the two short lists appears to be Wahoo 7, but the TVD depth on the chart doesn't match that given in the short list of TVDs; and 3. the orange-and yellow-colored intervals in the chart are labeled Wahoo 6 and Wahoo 5, but the ND depths on the chart don't match those given in the short list of TVDs. The introductory text of this section mentions the depths taken from the logs of the parent wellbore L2-14 were shifted. What shift values were applied? How were those shift values derived? Please re-submit this section of the application with corrections. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 e e Image Project Well History File Cover Page XHVlE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c:2 Q L} - () 0/ .s- Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 1111111111111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~ískettes, No. f o Other, NofType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 7þlf/Qfo Date 7 J¡ if ill (¿, I I 30 o Other:: BY: ~ 151 mP Project Proofing 111/111111111111111 BY: ~ 151 mp Scanning Preparation + J r¡ = TOTAL PAGES ~ 7 ~nt does not include cove~ /5/ p BY: Date: 11/11111111111 111/1 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:7!14-!Db Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /51 mr NO BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 111/111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 11I111111I11" 111/1 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. AI Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 SCj� August 22, 2011 g otas Mr. Tom Maunder i - 0 75 Alaska Oil and Gas Conservation Commission 8 I 1 4 333 West 7 Avenue ° �.,, Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 I °L O '► 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 r). 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 1 • • -,4. MICROFILMED 03!01 /2008 DO NOT PLACE -, .: ,~ __:, ANY NEW MATERIAL UNDER THiS PAGE F:\LaserFiche\C~rPgs_InsertslMicrofilm Marker.doc 2 .)~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040950 Well Name/No. PRUDHOE BAY UN LIS L2-14B Operator BP EXPLORATION (ALASKA) INC J ,,~J.. f,,- J __ Ab-tJ '1 API Jf o. 50-029-21758-02-00 MD 10598,/" TVD 8917.- Completion Date 6/12/2004--- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR, ROP, WOB, PRESS, QUAD COMBO Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type Electr Digital Dataset Med/Frmt Number D Asc . Directional Survey Production \)~ "', -!t) 12 Blu Interval Start Stop 9487 10598 9487 10598 8909 10456 OH/ CH Received Comments 9/3/2004 MWD 9/3/2004 MWD Case 11/24/2004 PRODUCTION PROFILE/CCUGRlSTPDE FT/GHOST GR/MWD GRlMWD GRlMWD GRlMWD PRODUCTION PROFILE CCUGRlSTP/DEFT/GHOS T Name Directional Survey Log Log Run Scale Media No C 13004 Gamma Ray 13004 Gamma Ray MD 13004 Gamma Ray Ï""~ 13004 LIS Verification Production 9534 10598 2/1112005 9534 10598 2/1112005 9534 10598 2/1112005 9534 10598 2/11/2005 5 Blu 9076 10493 Case 12/20/2005 Name Interval Start Stop Sent Received Sample Set Number Comments . Well Cores/Samples Information: ADDITIONAL INFOR~ION Well Cored? -t ~ Chips Received? ~ Daily History Received? '0 N Formation Tops ~ N Analysis Received? -'<J' Comments: Permit to Drill 2040950 MD 10598 TVD 8917 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. PRUDHOE BAY UN LIS L2-14B Operator BP EXPLORATION (ALASKA) INC Completion Date 6/12/2004 Completion Status 1-01L Current Status 1-01L }k API No. 50-029-21758-02-00 UIC N Date: ~j~ j...~ ~ 4.K) L . 'V r . . 01/04/06 Schlumberger NO. 3642 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. WII J b # L D 'f BL CI CD D e 0 og escrlptlon ate o or Z-01 11087166 LDL 08/05/05 1 Y-13 N/A PRODUCTION LOG 05/01/05 1 L2-14B ~O+-O~5" 10670029 PROD PROFILE 08/20/04 1 Y-OBA 11047356 MEMORY/SENSA LDL 10/15/05 1 X-36 11075908 MEMORY INJECTION PROFILE 08/17/05 1 X-30 10662973 GLS 12/02/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 P2-01 11072880 LDL 08/06/05 1 DS 12-08C 11087208 SBHP SURVEY 12/24/05 1 D.S. 09-2BA 11094347 LDL 12/28/05 1 P2-34 N/A INJECTION PROFILE 06/02/05 1 Q-05A 11087203 SBHP SURVEY 11/27/05 1 NK-09 11062632 PROD PROFILE W/DEFT 07/01/05 1 NK-38A 11075902 MEMORYPRODPROALE 07/27/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN B.,"~ Received b . t1"J Date Delivered: . . . Transmittal Form ;(t!J tf- () ?S- . r&i_ BAKER HUGHES I._~~~~.:"'~~.~:.~J _~~m~···s ~::',~~; '" - I ~~~ft: ;~~I INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: L2-14B Anchorage GEOScience Center Contains the following: 1 LDWO Compact Disc (Includes Oraphic Image files) I LDWO lister summary 1 blueline - OR/Directional Measured Depth Log I blueline - OR/Directional TVD Log LAC Job#: 696246 Received Date: Feb 7, 2005 Date: J..ll Ios t J 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) 267-66]2 FAX: (907) 267-6623 . . -- --- , --- , --=--~ ~ ;~~0~-~···::~ ~.¡~-".' .~ k~~:: ',;>¡.l ¡ j.. . ," i-, U--l_~_ , L~-:-.__~__ ¡t~,~ ;-",:~' (p"!_ ¡,.J; ~;~' 'ff~,t¡ ¡~L~ :~ '--'"T ~J: ~\V'i. ¡.: ltt. ,JJ~:S;·".¡; ~-' .' ,.- ',:.) ."-, -;-,;.-( .. ",,". ¡':'7~~- !~':---'~-"~~~~ þ:': ..- .,..__._ ..·.u , -~------ .. STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION ~MISSION REPORT OF SUNDRY WELL OPERATIONS ... 1, Operations Performed: Abandon 0 Alter Casing 0 Change Approved ProgramO 2, Operator Name: 3, Address: Repair Well 0 Pull Tubing 0 Operation Shutdown 0 PluQ PerforationsD Perforate New Pool D Perforate D Stimulate 00 WaiverO 4. Current Well Class: Development ŒJ BP Exploration (Alaska), Inc. ExploratoryO P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 45.00 8, Property Designation: ADL-028321 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: L2-14B 10. Field/Pool(s): Prudhoe Bay Field I Lisburne Oil Pool Total Depth measured 10598 feet true vertical 8916.6 feet Effective Depth measured 10598 feet true vertical 8916.6 feet Casing Conductor Production Surface Length 80 9411 3897 Perforation depth: Measured depth: 9387 - 10460 Plugs (measured) Junk (measured) Size 20" 91.5# H-40 7·5/8" 29.7# L-80 10-3/4" 45.5# L-80 MD 32 112 30 - 9441 31 - 3928 TVD 32.0 112.0 30.0 - 8802.7 31.0 - 3927.9 True vertical depth: 8754.5 - 8919.2 TubinQ ( size, Qrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 29 9189 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4·1/2" HES Wellstar SSSV @ 10539 @ 10604 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Signature Form 1 0-404 Revised 4/2004 OtherD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 204-0950 6. API Number 50-029-21758-02-00 None None Burst Collapse 470 4790 2480 1490 6890 5210 Oil-Bbl 317 541 Reoresentative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 13.8 505 1375 13.3 307 810 Tubing Pressure 536 529 ! 15. Well Class after proposed work: ExploratoryD 16, Well Status after proposed work: OilŒJ GasD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Garry Catron Printed Name Garry Catron J.1~ C~ DevelopmentŒ ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Phone 564-4657 Production Technical Assistant 1/26/05 Title Date RBDMS 8Ft FEB () 4. 2005 . . L2-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/03/04 CTU # 9 W/1.75" CT. MILL SHOElN2 FOAM DIVERTER ACID STIM. MIRU, PERFORM BOP TEST. «< CONTINUED ON WSR 04-DEC-04 >>> 12/04/04 CTU #9 W/1.75" CT, MILL SHOE/N2 FOAM DIVERTER ACID STIM. «< CONTINUED FROM WSR 03-DEC-04 »> MU BOT PDM W/2.74" MILL, KILL WELL AND RIH. MILL THROUGH BIT 0 - RING SUB AND TAPERED GUIDE SHOE. TAG TD 10594' CTM. RIH W/ 2.00" JSN W/GOOD SIDE JETS. «< CONTINUED ON WSR 05-DEC-04 »> 12/05/04 RIH AND TAG TD AT 10,594' CTM. MAKE CHECK RUN THROUGH NEWLY MILLED SEAL ASSY AND SHOE W/O PROBLEM, LINE UP AND START STAGE #1 W/35 BBLS 2% KCL SPEAR, FOLLOWED BY FOAM STAGE. COIL HANGING UP AT 10,468', ULTIMATELY LOST CIRCULATION, COIL RAPIDLY PRESSURED TO 4000 PSI, SD, BLED DOWN COIL AND FREEZE PROTECTED COIL W 60/40 METHANOL WATER. REGAINED ABILITY TO PUMP DOWN THE COIL, FREEZE PROTECTED, PUMPED 20 BBL CRUDE DOWN COIL. COULD NOT MOVE COIL. PUMP 20 BBLS 15% HCL DOWN COIL, ABLE TO EXTRACT COIL AND POOH. RIH W/1.75 JSN FOR SECOND TRY. FLUID PACK TUBING WITH 80 BBLS DEAD CRUDE FOLLOWED BY 5 BBLS 60/40, RIH TO 10,200' CLEAN PICKUPS FROM THIS DEPTH. INITIAL INJECTIVITY 31 PSI @ 2,0 BPM. PUMPED 15 BBL 2% KCL W/F103 PRE-FLUSH. MADE FIRST UP/DN PASS FROM 10,125' TO 10,595' WHILE JETTING W/60 BBLS 15% HCL, STILL SAW TIGHTS SPOTS AT 10,412', 10,450' BUT BOBBLED THROUGH. PUMPED 40 BBL FOAM STAGE WHILE JETTING DN/UP FROM 10,200' TO 10,450', PUMPED 50 BBLS 15% HCL WHILE JETTING FROM 10,300' TO 10,600' JETTED UP AT 7 FT/MIN TO 10,450'. JETTED W/FOAM FROM 10,450' TO 10,200' AND THEN BACK DOWN TO 10,560', JETTED W/50 BBLS 15% HCL FROM 10,560' TO 10,1300', 10,600' TO 10,510', AND BACK DOWN TO 10,590', 12/06/04 CTU #9 W/1.75" CT. MILL SHOE/N2 FOAM DIVERTER ACID STIM,JET INTERVAL W/35 BBLS OF FOAM FROM 10,590' TO 10,600',10,600' TO 10,300' AND BACK DOWN TO 10,475. JET INTERVAL FROM 10,494' TO 10,410' W/35 BBL 15% HCL. PUMP 30 BBL FOAM STAGE AND JET INTERVAL FROM 10,411' TO 10,300' W/30 BBLS 15% HCL. OVER DISPLACE WITH 21 BBLS 1% KCL AND POOH. FINAL INJECTIVITY AT END OF JOB 2.0 BPM AT 232 PSI. POOH, PUMP 5 BBLS NEAT METHANOL DOWN IA IN PREPARATION FOR FLOW BACK. FLUlIDS PUMPED BBlS 387 60/40 Methonal 747 1 % KCl XSlK 12 Flo Pro 150,000 LSRV 30 2% KCL wi 0.2% F103, 0.2% W054 75 2% KCL w/1.5% J259 180 15% HCL w/additives 105 Crude 20 2% HCL w/F1 03 ~,,; ) "Ie . F " .~. /" I, 65 15% HCL 74 Liquid N2 r-!::ö u-¡, j i:L ' ~ U t_~_i ' 1695 TOTAL r'L U > ..,. ,,". 'C,'. Page 1 ~ TREE = -- ? SAFETY NOTES: *** 4-1/2" CHROMETBG *** WB...LI..EAD - FMC L2-14B AcrUATOR = AXELSON H;3S 250 (PPM) L2·14A WELLBORE NOT KB. ELEV = 45.0' SHOWN ON DIAGRAM. BF. ELEV = KOP= 4400' Max Angle = 33 @ 6900' ......--, I 4-1/Z'I-ES WB...LSTARTRSSSV, ID= 3.813" I Datum MD- 9489' . 2194' Datum TV D= 8800' SS 10.......oooO GAS LFT Mt\NDRELS ~ ~ ST MD lVD DB' lYÆ VLV LATOi PORT I)ð. TE 110-314" CSG, 45.5#, L-80, ID = 9.953" 389T 5 3014 3013 1 KBG-2 D\1Y BK 0 01/12/04 ~ 4 4793 4773 22 KBG-2 DOME BK 16 07/11/04 3 6227 6014 32 KBG-2 DOME BK 16 07f27/04 2 7660 7231 30 KBG-2 DOME BK 16 07/11/04 1 8975 8396 30 KBG-2 SlO BK 22 07f27/04 Minimum ID = 2.80" @ 9076' 3-112" X 3-3/13" XO 9044' 4-1/2" HES X NP, ID = 3.813" I :8: ..,........" 9065' f-- 7-518" X 4-1/Z' S-3 A<R,ID - 3.875" I ..:::;.;::, I. . - 9072' f-- 3.7" BIT ŒPLOYMENf SLV, ID= 3.0" I Ir 9076' I- 3-1/2" X 3-3/16" XO, ID = 2.80" I . 9131' f- 4-1/2" HES X NlP,ID = 3.813" (BEHIND cr LNR) I I 14-1/2"TBG, 12.6#, 13-CR, .0152 bpf, D =3.958" 9223' I 9223' 4-1/2" TT W/ MJLE SHOE (BEHIND cr LNR) I I I HEUVÐ IT NOTLOGGID I µ I I ~ I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 9411' I I I I I I I I MLLOur WINDOW 9515' - 9526' ITOPOFWHPSTOCK 9515' t-- I .. .. , , , , , , , , , -. , -. -. BKR INFLA TABLESTANONG VLV 9620' I /.> , -. , -. , -. , , , , , , , , -. - , , -. , , -. , -. , - , , 10460' FBTD , , , , -. - , , -. . , , , , , - -. , I 5-1/2" LNR. 17#, L-80, .0232 bpf, D = 4.892" 9976' ~ -. , .. I , , -. , - -. , , , , , PffiFORA TION SUr-.tv1ARY REF LOG: 13-3/16" LNR. 6.2#, L-80, .0076 bpf, D = 2.80" H 10493' I ANGLEA TTOP ÆRF: 27 @ 9387' , .." /lbte: Refer to A'oduction DB for historical perf data SIZE SPF INlERV AL Opn/Sqz I)ð. TE L2-148 SLOTTED LNA 9387 - 1 0460 0 06/11104 DATE REV BY COr-.tv1ENfS I)ð.lE RB' BY COr-.tv1ENTS LSBLRI'E lJ'.JIT 10/31/87 ORIGINAL COMPLETION WELL: L2-14B 01/16/04 JLM/TLH RWO PERMIT No: 2040950 01/28/04 TM tflLP CTDsDTRK- OP811 HOLE AA No: 50-029-21758-02 06/12/04 JDM/KAI< CTD SIDETRACK (L2-14B) SEC18, T11N, R15E, 979.09'FEL& 4005.15' Ft-t. 07/11/04 JLJiKAK GL V C/O 07/27/04 SSiKA K GLV C/O BP Exploration (Alaska) 11/16/04 Schlumberger NO. 3256 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Color Well Job # Log Description Date Blueline Prints CD ~O fJ; E-39A 10715430 MEMORY IPROF & WARMBACK 09/13/04 1 K:f'1..o2 ¡,.. D,S, 15-25A 10715428 MEMORY PPROF & IPROF 09/11/04 1 cØ'qj, C-25A 10928596 MEMORY LDL 09/27/04 1 C-25A 10928598 MEMORY LDLlIPROF 10/04/08 1 1 .,~ L2-14B 10670029 PRODUCTION PROFILE 08/20/04 1 "'-. F-11 B 10928600 MCNL 10/20/04 1 1 ~ð'f." ~ L2-07 A 10861911 MCNL 05/31/04 1 1 1.E-07 A 10715409 MCNL 06/07/04 1 1 F-28A 10670015 MCNL OS/22/04 1 1 ~¡/ L3-05 10724368 RST-SIGMA 04/02/04 1 1 L3-05 10662981 RST-SIGMA 01/08/04 1 1 ~'~ L3-05 10866588 RST-SIGMA 09/03/04 1 1 ~ \. L3-05 10672320 RST-SIGMA 09/28/03 1 1 {1£. ~ /54 L3-02 10560313 RST-SIGMA 10/16/03 1 1 (Ðf)' < OWDW-NW 10563037 RST-SIGMA & BORAX 03/29/03 1 1 OWDW-NW 10672361 RST -BORAX 03/28/04 1 1 1,: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, 99503-2838 ATTN: Bet Date Delivered: /(-;).c{- oLf f'../ . " . STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATION~E("- , \.,p 1:::1' lit: '" 1. Operations Performed: "W"''Jf~ ~_;' Abandon D Repair Well 0 PluQ PerforationsD Stimulate Œ] other(ì('TO 5 2004 Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Tim~1}filYi¡ÇJ G:l':! r Change Approved Program D Operation ShutdownD Perforate 0 Re-enter Suspended Well~!1i"¡J¡¡"''''~ ~" 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number~ Name: Development 00 ExploratoryD 204-0950 3, Address: P,O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-21758-02-00 7, KB Elevation (ft): 9, Well Name and Number: 45.00 L2-14B 8. Property Designation: 10. Field/Pool(s): ADL-028321 Prudhoe Bay Field / Lisburne Oil Pool 11. Present Well Condition Summary: Total Depth measured 10598 feet true vertical 8916.6 feet Plugs (measured) None Effective Depth measured 10598 feet Junk (measured) None true vertical 8916.6 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 32 - 112 32.0 - 112.0 1490 470 Liner 6 3-1/2" 9.3# L-80 9072 - 9078 8479.3 - 8484.5 10160 10530 Liner 1415 3-3/16" 6.2# L-80 9078 - 10493 8484.5 - 8919.1 Liner 308 5-1/2" 17# L-80 9207 - 9515 8596.5 - 8868.5 7740 6280 Production 9411 7-5/8" 29.7# L-80 30 - 9441 30.0 - 8802.7 6890 4790 Surface 3897 10-3/4" 45.5# L-80 31 - 3928 31.0 - 3927,9 5210 2480 Perforation depth: Measured depth: 9387 - 10460 True vertical depth: 8754.5 - 8919.2 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 29 - 9189 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 9069 4-1/2" HES Wellstar SSSV @ 9198 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9387 - 10460 Treatment descriptions including volumes used and final pressure: 298 Bbls 15% HCL @ 1709 psig 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 97 0.5 41 830 546 Subsequent to operation: 1218 11.9 336 865 523 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16, Well Status after proposed work: Daily Report of Well Operations_ ! OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature 9{/'J r·,r;· Phone 564-4657 Date 10/1/04 ~ .,.-. - .J ! ì 1\ î "\ I Form 10-404 Revised 4/2004 RBDMSBfL OCT u ~ " . t. L2-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/07/04 CTU#5: ACID STIMULATION. RU WI ASRC FLOWBACK UNIT. KILL WELL WI 114 BBLS FILTERED KCL AND TOPPED OFF WI 110 BBLS CRUDE (TO ASSIST WI FLOWBACK). JET 298 BBLS OF 15% HCL ACROSS SLOTTED LINER FROM 9965' TO TD @ 10455' CTMD. MAKE ADDITIONAL PASSES ACROSS FRACTURE ZONES 10050'-10090',10110'- 10135', AND 10310'-10340'. OVER FLUSH ACID TO FORMATION WITH 143 BBLS 2% KCL (WI 0,2% F103 AND 0.2% W54). POOH, INITIAL WH TREATMENT PRESSURE = 1540 PSIG @ 2,0 BPM, FINAL WH TREATMENT PRESSURE (AFTER ACID) = 375 PSIG @ 2 BPM, WH TREATMENT PRESSURE (AT END OF OVERFLUSH) = 315 PSIG @ 2 BPM, RD DS CTU #5, TURN WELL OVER TO ASRC WELL TESTERS TO POP, *** JOB COMPLETE *** FLUIDS PUMPED BBLS 223 2% KCL 110 Crude 298 15% HCL 143 2% KCL w/0.2% F103 and 0.2% W54 774 TOTAL Page 1 , ¡, TREE = WB.U-EAD = AcrUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD- DatumTVD= ? FMC AXELSON 45.0' 1"/' 4400' 33 @ 6900' 9489' 8800' SS L2-14B 10-314" CSG, 45.5#, L-80, ID = 9.953" Minimum ID = 2.80"@ 9076' 3-112" X 3-3113" XO 4-1/2"TBG, 12.6#, 13-CR, .0152 bpf, D =3.958" 9223' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" I I I I ... TOPOFWHPSTOCK BKR INFLA TABLESTAN[)NG VLV 9620' 5-1/2" LNR, 17#, L-80, .0232 bpf, D =4.892" 9976' DATE REV BY COM\1ENfS 10/31/87 ORIGINAL COMPLETION 01/16/04 JLM/TLH RWO 01/28/04 TMN'TLP CTDSDTRK- OPe.! HOLE 06/12/04 JDM/KA CTDSIŒTRACK(L2-14B) 07/11/04 JLJiKAK GLV C/O 07/27/04 SSiKA K GL V C/O )A. TE RBI BY COM\1ENTS SAFETY TES: *** 4·1/2" CHROMETBG *** H2S 250 lPPMl L2-14A WELLBORE NOT SHOWN ON DIAGRAM. 2194' 4-1/2"I-ES WB.LSTARTRSSSV, ID= 3.813" ST MD TVD 5 3014 3013 4 4793 4773 3 6227 6014 2 7660 7231 1 8975 8396 GAS LFT Mð.J\DRELS DBI 1Y Æ VL V LA TŒ! 1 KBG-2 O'IAY BK 22 KBG-2 DOME BK 32 KBG-2 DOME BK 30 KBG-2 DOME BK 30 KBG-2 510 BK PORT )A. TE o 01/12/04 16 07/11/04 16 o 7f2. 7/04 16 07/11/04 22 07(27/04 9044' 4-1/2" HES X NIP, ID = 3.813" 9065' 7-518" X 4-1/2" S-3 R<R,ID - 3.875" 9072' 3.7" BTT DEPLOYMENT SLV, ID= 3.0" 9076' 3-1/2" x 3-3/16" XO, ID = 2.80" 9131' 4-1/2" HES X NIP, ID = 3.813" (BEHIND cr LNR) 9223' 4-1/2" IT W/ MJLE SHOE (BEHIND cr LNR) HELM::> TT NOTLOGGBJ I MLLOUT WINDOW 9515' - 9526' I 3-3/16" LNR, 62#, L-80, .0076 bpf, D = 2.80" L6BLRNE U\lfT WELL: L2-148 PERMfT No: 2040950 AA No: 50-029-21758-02 SEC 18, T11N, R15E, 979.09' FEL & 4005.15' FNI... BP Exploration (Alaska) .. STATE OF ALASKA . ALASKAII!JIL AND GAS CONSERVATION COM ClSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , 1a. Well Status: IBI Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IBI Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5, Date Comp., Susp" or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/12/2004 204-095 3. Address: 6, Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/5/2004 50- 029-21758-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/9/2004 PBU L2-14B 1556' NSL, 1272' EWL, SEC, 18, T11N, R15E, UM 8, KB Elevation (ft): 15, Field / Pool(s): Top of Productive Horizon: 1309' NSL, 3750' EWL, SEC. 18, T11N, R15E, UM 45' Prudhoe Bay Field I Lisburne Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1921' NSL, 3678' EWL, SEC, 18, T11N, R15E, UM 10598 + 8917 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692968 y- 5963457 Zone- ASP4 10598 + 8917 Ft ADL 028321 TPI: x- 695451 y- 5963273 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 695363 y- 5963883 Zone- ASP4 2194' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: GR I ROP I WOB I PRESS, Quad Combo 22. CASING, LINER AND CEMENTING RECORD ~~;~ ::;ETTING EF>" 'HMP::;ETTING' EPTHT\ID ~~~i/ / >.,. AMoUNT Wr. . PER ~T, GRAPE. ·.·IoP tsOTTOM lOP Itso"I"ToM >.» PULLED 20" 91.5# H-40 Surface 112' Surface 112' 30" 2100# Poleset 10-3/4" 45.5# L-80 / J-55 Surface 3897' Surface 3897' 13-1/2" 1500 sx AS 111,325 sx 'G', Top Job: 150 sx AS I 7-518" 29,7# L-80 Surface 9411' Surface 8776' 9-7/8" 610 sx Class 'G' 5-1/2" 17# L-80 9207' 9515' 8596' 8868' 6-3/4" 200 sx Class 'G' 3-3/16" 6,2# L-80 9072' 10493' 8479' 8919' 3-3/4" x 4-1/8" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of To,e and 24, >.......... ..,'..... ,> '>.. / Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/16" Slotted Section 4-1/2", 12,6#,13Cr80 9223' 9065' MD TVD MD TVD 9387' - 10460' 8755' - 8919' ?5, iðç:lb. ' ,'SI'-'. ..,...>i '" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9072' Freeze Protected with Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 13, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF W A TER-BSl CHOKE SIZE I GAS-Oil RATIO 6/30/2004 4 TEST PERIOD ... 17 101 7 104 5,870 Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 50 2,250 24-HoUR RATE 103 605 40 27. CORE DATA Brief description of lithology. porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". [i'C' UH';1-L.Ci d,..\I; -i None ~I OR\G\NAL ~ t ,~...- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ G G¡=; 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". Wahoo Zone 6.3 (above window) 9513' 8867' None Wahoo Zone 6.2 9550' 8899' 8941' Wahoo Zone 6.1.2 9609' Base Wahoo Zone 6.2 9897' 8941' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ T'tl T h· I A . t t Date " Terrie Hubble ~ J 0, I e ec nlca SSIS an U PBU L2-14B 204-095 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No, I A roval No. Drilling Engineer: Ted Stagg, 564-4694 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments, ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 61212004 05:00 - 06:00 1.00 MOB P PRE Move rig off L2-07. 06:00 - 09:00 3.00 MOB P PRE Begin Stand by Rate while additional location prep is performed. 09:00 - 11 :30 2.50 MOB N WAIT PRE Add additional gravel, grade around well head. This is the third time pad has been graded, and 2nd time extra gravel has been brought in. Snow melt from reserve pit keeps on "soaking" new gravel. Decide to get extra rig mats, 11 :30 - 15:30 4.00 MOB N WAIT PRE Double mat under rig. (34 mats total), 15:30 - 16:00 0.50 MOB P PRE Move rig over well. Align with tree. Accept rig at full rate at 1600 Hrs, 16:00 - 18:00 2,00 RIGU P PRE NU BOPS, Spot cuttings tank, RU hardline to flow back tank, 18:00 - 23:45 5,75 BOPSU P PRE Intiial BOPE test. Witness waived by AOGCC, Add 290 bbls 2% KCI to pits 23:45 - 00:00 0.25 EVAL P WEXIT Install tree cap. Check well for pressure and on a vac. Fill hole with 10 bbls KCI and on sli vac. Pressure to 300 psi w/ 3.4 bbls and bled to zero in 3 min 6/3/2004 00:00 - 00:15 0.25 EVAL P WEXIT I DSO pump up TRSSSV from 1100 psi to 4000 psi. IAO,OA 23. Check well and still on sli vac. SI swab 00:15 - 01:00 0.75 STWHIP P WEXIT PU injector. MU cement nozzle assy on stinger 01 :00 - 01 :40 0,67 STWHIP P WEXIT RIH wI BHA #1 taking diesel returns to cuttings box 01 :40 - 02:00 0,33 STWHIP P WEXIT Park at 4000', Circ test 1.0/0.8/185, 2,0/1,75/770, 3.0/2,65/2060. Discuss. Standing valve is not holding so will cement thru it and abandon open hole completion of L2-14a, Note: this requires name change of new well from L2-14aL 1 to L2-14b, Call for cementers. Switch back to taking returns of clean KCI 02:00 - 03:00 1,00 STWHIP P WEXIT Resume RIH to tag of WS at 9532' and set 5k down. PUH 39k wI mini overpull. Retag at 9531,5'. Corr to 9515'. PUH 38.5k to 9500' 03:00 - 03:30 0,50 STWHIP P WEXIT Park at 9500' and flag CT. Circ 1.1/0.8/100 Resume getting diesel back and resume dumping retums, MIRU OS cementers 03:30 - 04:40 1.17 STWHIP P WEXIT Prep for safety mtg and return rate and WHP started increasing. SI at choke to 175 psi while bull heading dn CT @ 0,6 bpm, Line up to flowback tank, Bleed 200 psi to flowback tank and hold 100 psi BP, Circ annular volume under choke 1,6/740 wI 100 psi BP and remove gas from wellbore, Assume gas came from 100' of tailpipe in 7-5/8" liner. Chk IA and on vac, Open choke after CBU and retum to circ from pits w/ clean KCI 04:40 - 05:30 0.83 STWHIP P WEXIT Safety mtg re: cementing Circ 1.6/1,3/620 wI open choke Cementers take on water and prep to mix on the fly 05:30 - 06:10 0.67 STWHIP P WEXIT PT DS @ 3500 psi. Load CT w/10 bbls neat, 10 bbls wI 12 ppb aggregate, 5 bbls neat 15,8 G cement wI TT 2:30, 100 ml FL 1,7/1.5/1000 06:10 - 07:05 0,92 STWHIP P WEXIT Displace wI 52 bbls hi vis pill followed by KCI at 1,5 bpm, PUH 44k from 9510' w/2 bbls out nozzle 4'/min. Close choke after 4 bbls out and noz at 9500' and hold 250 psi bp 1.0/0.7/200. After 5 bbls aggregate by SV, got full returns w/ 300 psi bp-incr PUH speed to 40'/min at 9430'. Last bbl out at 9000', Hole took 7 bbls. PUH to safety 0.5/740. CIP at 0645. 07:05 - 07:45 0,67 STWHIP P WEXIT Park at 7800' and circ 0.5/0.5/360. Shut in well and apply 500 Printed; 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/3/2004 07:05 - 07:45 0.67 STWHIP P WEXIT psi WHP, Very slow bleed off. Cement appears to be holding, 1:1 rtns. 07:45 - 08:30 0.75 STWHIP P WEXIT RIH circulating at 3 bpm, Wash to 9505' (10' above whipstock) 2: 1 with biozan, 08:30 - 10:30 2,00 STWHIP P WEXIT Circulate out of hole. Get flopro. bio & cmt retums to surface. 1: 1 rtns the whole way 10:30 - 11 :30 1,00 STWHIP P WEXIT At surface. Unstab. MU swirl nozzle, Get on well, Jet BOP satcke several times. Get off well. 11 :30 - 12:15 0.75 STWHIP P WEXIT LD nozzle assy, MU Baker motor with string reamer & one step speed mill. Stab coil. Get on well. 12:15 - 14:00 1.75 STWHIP P WEXIT RIH. Tag cement at +1-9500'. 14:00 - 18:00 4.00 STWHIP P WEXIT Mill cement. Slight bit of gas to surface. 1900 psi fs @ 2.75 bpm in/out 150 psi dpsi. 42k# up, 19k# dn wt. Contact top of tray at 9527' (uncorrected), Two stalls. Begin time milling, Some metal noted on ditch magnets, 18:00 - 22:00 4,00 STWHIP P WEXIT 9529,6' 2.75/2450 wI 50-100 psi diff and 0-500# wob Time mill by BTT instructions, . . 22:00 - 00:00 2.00 STWHIP P WEXIT 9532.0' 2,75/2400 w/ 50-100 psi diff and 0-500# wob. Time mill to 9533.8' 6/4/2004 00:00 - 04:30 4,50 STWHIP P WEXIT Continue time milling window from 9533.8' 2,75/2500 per BTT instructions 04:30 - 05:40 1.17 STWHIP P WEXIT 9538.4' This is 11.1' which is the calc length of the window. BTT start allowing steady progress at 0.1 '/min 2,75/2600 w/ 100# diff and 500# wob. Drill open hole to 9546.0' No stalls entire window except inital two 05:40 - 06:30 0.83 STWHIP P WEXIT Ream and backream window area. Window smooth, up and down, 06:30 - 11 :00 4.50 STWHIP N SFAL WEXIT POOH to 9320'. Reel stopped turning, unable to RIH or POH. Call mechanics. Slow pump to min rate. Detemine that bolts securing reel drive plate have sheared (all 15 of them!) Not sure why. Install replacements, Reel motor & planetary gears seem to be ok, 11:00-13:00 2.00 STWHIP P WEXIT POOH to surface. Unstab coil. Get off well. 13:00 - 13:30 0,50 STWHIP P WEXIT LD BHA. 13:30 - 15:00 1,50 DRILL P PROD1 Blow down reel with N2. 15:00 - 16:00 1,00 DRILL P PROD1 Unstab coil. Secure on reel. 16:00 - 18:30 2,50 DRILL P PROD1 Lower reel onto truck. Load E-CT reel into reelhouse, Prep reel. Install internal grapple, PJSM 18:30 - 20:00 1,50 DRILL P PROD1 Pull CT to injector and stab onto well. Displace MeOH from CT while reverse slack management 20:00 - 22:00 2.00 DRILL P PROD1 Install CTC and wet connect. PT 42k, Find short at jupiter connection 22:00 - 23:00 1.00 DRILL N SFAL PROD1 WO OS tech to fix jupiter connector 23:00 - 23:50 0,83 DRILL P PROD1 PT CTC at 3600 psi. Circ CT vol 3,1/2700 while MU build BHA 23:50 - 00:00 0,17 DRILL P PROD1 RIH wI BHA #3 (SP3BBM, 2,7 deg) 2.5/1950 thru EDC 6/5/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Continue RIH wI BHA #3 01 :30 - 01 :55 0.42 DRILL P PROD1 Log tie-in down from 9465' to 9522' and corr -15' to 9464' PDC 01 :55 - 02:25 0.50 DRILL P PROD1 RIH thru window, clean at 15L and tag at 9534', PUH 44k. Start motor 2,6/2620/1 OL ease in hole to first motor work at 9534' and stall, Repeat and break in bit 02:25 - 02:40 0,25 DRILL P PROD1 Start Flo Pro mud wI 6% KCI, 1 % DZ, 1 % Uhib, 3% L T down CT. PUH thru window to check high GR (291 api) and returned to normal Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/512004 02:40 - 03:40 1,00 DRILL P PROD1 Resume drilling from 9535' 2,7/3100/5L 100 psi diff, 6k wob, ECD 10,1 and go nowhere fast 03:40 - 05:40 2,00 DRILL P PROD1 9537,0' 05:40 - 07:30 1.83 DRILL P PROD1 Drilling at 9540' 3100 psi fs @ 2.62 bpm 700-800 dpsi. WOB: 5-7K#. ECD: 10,06. ROP: 1- 2 fph Very hard drilling, Able to stall if we push too hard, 07:30 - 12:30 5,00 DRILL P PROD1 Drilling at 9549'. ROP pretty much at zero, 12:30 - 14:00 1.50 DRILL P PROD1 POOH for bit change, 14:00 - 15:00 1,00 DRILL P PROD1 At surface, Get off well. Unstab coil. Change out bit from SP3BBM to M-07. SP3BBM completely worn out. Ash trayed nose, all cutters gone, bit face gone. Slighly undergauge (1/32"), gauge cutters intact. 15:00 - 16:45 1,75 DRILL P PROD1 Stab coil. Get on well. RIH, MWD working ok. 16:45 -17:00 0,25 DRILL P PROD1 Log gr tie in from 9475'. -16' correction, Orient to highside, 17:00 - 19:00 2.00 DRILL P PROD1 Drill ahead 3420 psi @ 2,6 bpm fs. 300-400 dpsi. WOB:5-7K#, TF:5R. ECD: 10.2 ppg 19:00 - 20:00 1.00 DRILL P PROD1 Drill from 9554.0' 2.7/3360/10L wI 100-300 diff, 3-6kwob, ECD 10.0, PVT 382 See RA pip at 9526' 20:00 - 21 :00 1.00 DRILL P PROD1 9561.0' 21 :00 - 22:00 1,00 DRILL P PROD1 9568,0' 4-7k wob and nearing the end for this bit 22:00 - 00:00 2.00 DRILL P PROD1 9570.0' 7-9k wob wI 400-500 diff, Drill to 9578' and stall 6/6/2004 00:00 - 01 :00 1,00 DRILL P PROD1 Several stalls at 9578'. Spend 30 min to be able to add wt wlo stalling 2,6/3180/10L, then, no drilloff PVT 380 01 :00 - 02:30 1.50 DRILL P PROD1 POOH for bit. Chk last 200' CT (for Graham), ok 02:30 - 02:50 0.33 DRILL P PROD1 Change bit, chk motor, ok. Bit was 1-8-1/16" and RO on first 1" of gauge 02:50 - 04:25 1.58 DRILL P PROD1 RIH w/ BHA #5 (2,7 deg, M09X) 04:25 - 04:50 0.42 DRILL P PROD1 Log tie-in down from 9465'. Corr -18' 04:50 - 05:20 0,50 DRILL P PROD1 RIH thru window at 10L. Precautionary ream 5'/min and stalled at 9550' 2,613230/1 OR Precautionary ream 1,5'/min to TO, clean, Tagged at 9579' 05:20 - 07:00 1.67 DRILL P PROD1 Drill from 9579' 2,65/3250/10L wI 0-50 psi diff, <1k wob, ECD 10.0, PVT 376 and start initially at 20'/hr while break in bit 07:00 - 08:15 1.25 DRILL P PROD1 Drill ahead from 9592', 3200 psi @ 2.66 bpm fs 150 dpsi. WOB:O,5K#, ROP: 15 fph. TF:15L. ECD:10,O ppg, 08:15 - 10:45 2.50 DRILL P PROD1 Drilling, Begin losing 0.2 to 0.5 bpm, ROP: 10-20 fph, PVT:365 bbls Losses healed to 2,66 in/2.40 out. Not getting enough build, Were getting 36-38/100 d-Ieg, dropped off to 26-28/100, 10:45 - 12:30 1,75 DRILL P PROD1 Flag EOP. POOH for bit & AKO motor adjustment. Slow pump rate to 0,9 bpm while passing mudstones. At surface. Get off well. Unstab from coil. 12:30 - 13:15 0.75 DRILL P PROD1 Remove M-09 (bit #3). In very good condition, 1/21in gauge, Slight wearlchipping on radius cutters, MU M-07 (bit #4). Adjust motor AKO from 2.7 to 3.2 deg, 13:15 - 15:00 1.75 DRILL P PROD1 Stab coil. Get on well. Test MWD. RIH. Tag SSSV. Reduce running speed and hydraulics for rest of trip (75 fpm vs the usual 100 fpm) 15:00 - 15:10 0.17 DRILL P PROD1 Correct to EOP flag at 9300 (-16,4' correction), Log gr tie in. No correction. 15:10 - 15:15 0.08 DRILL P PROD1 RIH to TD at min pump rate, 15:15 - 16:30 1.25 DRILL P PROD1 Drill ahead, 3200 psi fs at 2.63 in/2,26 bpm out. 400-600 dpsi. TF:05R. WOB: 4-5K#. PVT:336 bbls ECD: 10.13 ppg Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/612004 15:15 - 16:30 1.25 DRILL P PROD1 ROP: 40-60 fph D-Ieg: 40-45/100 16:30 - 18:20 1.83 DRILL P PROD1 Drilling ahead. Reduce WOB to 2-3K# to reduce build rate, TF: 300L. Begin tum to left. 2.59 inl2,53 out. Drill to 9780' and back on track. Landed at 9705' (8928' TVD) and are 102 deg at bit PVT 306 18:20 - 19:50 1.50 DRILL P PROD1 POOH for motor bend 19:50 - 20:40 0.83 DRILL P PROD1 Chg bit, adj motor to 2,0 deg, Bit was 1-8-1/16" wI L Ton gauge 20:40 - 22:20 1.67 DRILL P PROD1 RIH wI BHA #7 (2,0 deg, 05100) 22:20 - 22:35 0.25 DRILL P PROD1 Log tie-in down from 9490', Corr -20' 22:35 - 23:30 0.92 DRILL P PROD1 RIH thru window, clean. Precautionary ream 4-5'/min from 9545' 2,65/2,5/3280 MW from 9660' and stalled at 9670' (3 times) w/overpulls, Ream from 9670' 2-5'/min wI minor MW at times to TO tagged at 9780' 23:30 - 00:00 0.50 DRILL P PROD1 Drill from 9780' 2,62/2.45/3280/80L PVT 270 6/7/2004 00:00 - 01:15 1,25 DRILL P PROD1 Continue drilling invert from 9783' 2,6/2.4/3270/90L wI 500 psi diff, 3.5k wob 30'/hr to 9812' 01:15 - 01:35 0,33 DRILL P PROD1 60' wiper to smooth DLS reflected in stacking 01 :35 - 03:00 1.42 DRILL P PROD1 Drill from 9812' 2.6/2,5/3270/80L w/400 psi diff 3-4k wob, ECD 10.18, ROP 20-30 holding 100 deg PVT 234 03:00 - 03:30 0.50 DRILL P PROD1 Wiper to window, clean 03:30 - 05:00 1.50 DRILL P PROD1 Drill from 9850' 2.6/2,5/3280170L w/ 350-500 psi diff, 3-5k wob, ECD 10,24, ROP 10-25 holding 100 deg PVT 229 Geo says structure is flatter than thought so may level out sooner 05:00 - 05:40 0,67 DRILL P PROD1 Progress slowed from rather slow to real slow at 9873', Assume bit is dull from early digging and may be in mudstone. ,. No further progress past 9873' PVT 214 05:40 - 05:50 0.17 DRILL P PROD1 Wiper to window, clean 05:50 - 07:15 1.42 DRILL P PROD1 POOH for bit. At surface. Get off well. Unstab coil. 07:15 - 09:00 1,75 DRILL P PROD1 LD MWD tools, PU replacement tool string. DS100 had several chipped cutters on nose, several slightly chipped cutters on reamer blade. Overall 2-3-1/32. PU HTC RWD2ST bi-center with super duper new "2" cutters. Scribe mtr, Stab coil. Get on well. MWD tests ok, 09:00 - 10:45 1,75 DRILL P PROD1 RIH, 10:45 -11:00 0.25 DRILL P PROD1 Log gr tie in from 9480', -19' correction, 11:00 -11:15 0.25 DRILL P PROD1 Run through open hole slow, maintaining drilled TF through build section. 11 :15 - 15:00 3,75 DRILL P PROD1 Drill ahead. 3320 psi @ 2.61 bpm 15. 300-400 dpsi WOB: 1,5-3.0K# 2,6 in/2,5 bbl out. TF: 265L PVT: 189 bbls ECD: 10,2 ppg ROP: 10-12 fph. Fairly hard drilling, numerous stalls. Stall if more than 2K# wob is applied, Losses up to 0.5 bpm for a few minutes, then back to 0.1-0,2 bpm loss, 15:00 - 17:00 2,00 DRILL P PROD1 Continue drilling ahead, PVT: 184 bbls. TF:270L. 17:00 - 18:05 1,08 DRILL P PROD1 Drill ahead, 3320 psi @ 2,61 bpm 15. 400-700 dpsi WOB: 1.5-3,OK# 2.6 inl2,5 bbl out. TF: 225L Adding 290 bbls to pits ECD: 10.2 ppg ROP increased to 20-25 fph, Drilled up through lower mudstone at 9894'. Begin to roll over to level out TVD, 18:05 - 18:50 0.75 DRILL P PROD1 Wiper to window, clean PVT 450 18:50 - 20:00 1.17 DRILL P PROD1 Drill from 9972' 2,6/2,5/3180/140L-179L 300-500 psi diff, 1-3k wob, ECD 10,17 attempting to drop angle from 102 to 90 deg, ROP 20-40 wI occasional stalls at higher wt PVT 445. Not Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/712004 18:50 - 20:00 1.17 DRILL P PROD1 getting required drop and also need more tum 20:00 - 20:15 0.25 DRILL P PROD1 Wiper to window, clean. Red pump rate to <1.0 bpm over mudstone 9870-9905' 20:15 - 20:45 0,50 DRILL P PROD1 POOH for motor bend, Inspect last 200' CT for wear 20:45 - 22:20 1,58 DRILL P PROD1 LD flex sub assy. Change motor and bit (Z nose cutters were trashed, ,,). Bit inner nose cutters were chipped bad and starting to ring, 6-0-1 22:20 - 23:50 1.50 DRILL P PROD1 RIH wI BHA #9 (3,0 deg, M09X) 23:50 - 00:00 0.17 DRILL P PROD1 Log tie-in down from 9490' 6/8/2004 00:00 - 00:05 0.08 DRILL P PROD1 Tie-in, corr -17' 00:05 - 00:30 0.42 DRILL P PROD1 Wiper to TO slowing rate by mudstone, clean, Tag 10003' PVT 430 00:30 - 01 :45 1.25 DRILL P PROD1 Drill from 10003' 2,6/2,5/3130/170L w/200-500 psi diff, 1-3k wob, ECD 10.0, 24'/hr and drop angle from 101 deg to 92 deg on near bit incl 01:45 - 02:10 0.42 DRILL P PROD1 Several 50' wipers after sticky hole encountered probably due to TF change 02:10 - 03:45 1,58 DRILL P PROD1 Drill from 10033' 2,6/2,5/3150/100L wI 200-400 psi diff, 3-5k wob, ECD 10,1, 30'/hr and peaked at 8873' TVD at 10025', Level out at 8876' TVD in the Wahoo 6,2 and put everything into turn, Start stacking and have trouble making headway at 10072' 03:45 - 04:25 0,67 DRILL P PROD1 Wiper to window, clean PVT 415 04:25 - 05:30 1.08 DRILL P PROD1 Drill from 10072' 2.6/2.5/3200/80L wI 200-500 psi diff, 3-6k wob, ECD 10,1, 20'/hr. P-rate picking up at 10090'. Drill to 10100' Good oil stain in Wahoo samples 05:30 - 05:50 0,33 DRILL P PROD1 Wiper to window 05:50 - 07:15 1.42 DRILL P PROD1 POOH for lateral/tum BHA. At surface, Get off well, Unstab coil. 07:15 - 08:00 0.75 DRILL P PROD1 Remove M-09 bit. In good condition, 1-1-0. PU a new M-09 on 1.4 AKO mtr. 08:00 - 10:00 2.00 DRILL P PROD1 Stab coil. Get on well. MWD test ok. RIH. 10:00 - 10:15 0,25 DRILL P PROD1 Log gr tie in from 9475', -17' correction, PVT: 400 bbls. 10:15 -11:00 0,75 DRILL N DFAL PROD1 Adjust TF to run through window. Orienter not responding. Trouble shoot same from surface. Unable to get it working, 11 :00 - 12:20 1.33 DRILL N DFAL PROD1 POOH to replacelrepair orienter, At surface, Get off well, Unstab coil 12:20 - 13:25 1,08 DRILL N DFAL PROD1 Change orientor, add flex assy 13:25 - 15:00 1,58 DRILL N DFAL PROD1 RIH w/ BHA#11 (1.4/M09) 15:00 -15:15 0,25 DRILL N DFAL PROD1 Corr to flag -16', Log tie-in down from 9485', corr -2' 15:15 - 15:40 0.42 DRILL P PROD1 RIH thru window, clean. Wiper to TO, slowing pump rate for mudstone 9875-9900', Tag at 10099' PVT 392 15:40 -18:15 2,58 DRILL P PROD1 Drill from 10099' 2,6/2.5/3190/95L wI 200-400 psi diff, 1-3k wOb, ECD 10,1 at 8876' TVD and begin slow drop to 8880' TVD. Drill to 10203'. 18:15 - 18:50 0.58 DRILL P PROD1 Wiper trip to window. Slow pump rates at mudstone intervals, 18:50 - 22:10 3,33 DRILL P PROD1 Directionally drill f/10203' to 10310'. 2,58/2.553170 psi/fs 3630 psilbtm 3-5k wob 30'-50'/hr 22: 1 0 - 22:50 0,67 DRILL P PROD1 Wiper trip to window 22:50 - 00:00 1,17 DRILL P PROD1 Drill ahead f/10310' to 10362'. 2.62/2.60 3200psi 15 3750 on bottom, 3-4k wob 30'/hr 6/9/2004 00:00 - 01 :55 1.92 DRILL P PROD1 Directionally drill f/1 0362' to 10398'. 01 :55 - 02:30 0,58 DRILL P PROD1 Wiper trip to window, Slow pump rate while tripping through Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/912004 01 :55 - 02:30 0.58 DRILL P PROD1 mudstone areas with BHA. 02:30 - 04:45 2.25 DRILL P PROD1 Drill ahead f/10398', 2,6/2.6 3180 spi/fs 3860 psi/btm 4-5k wob 20-30'/hr. Drilled to 10468', 04:45 - 05:15 0.50 DRILL P PROD1 Wiper trip to window, 05:15 - 05:30 0,25 DRILL P PROD1 Log tie-in, add 3.0' 05:30 - 06:10 0,67 DRILL P PROD1 Wiper to TO, clean PVT 342 06:10 - 07:50 1,67 DRILL P PROD1 Drill from 10470' 2.6/2,55/3280/120L wI 400 psi, 3-5k wob, ECD 10,22 at 8874' TVD @ 90 deg 07:50 - 08:00 0,17 DRILL P PROD1 100' wiper after stacking 08:00 - 08:15 0.25 DRILL P PROD1 Drill to 10540' and can't make headway. Get 5k to bit and won't drill or get diff, TD will probably be extended by 200' PVT 336 08:15 - 08:40 0.42 DRILL P PROD1 Wiper to window. Red rate for mudstones 08:40 - 10:20 1.67 DRILL P PROD1 Flag CT. POOH to chk bit while wo logging tools to arrive at rig by 2200 hrs 10:20 - 11 :05 0.75 DRILL P PROD1 Change bit, grease blocks, M09X had little wear and minor chipped cutters, 1-1-1. TO will remain as in original plan as 10598' 11 :05 - 13:00 1,92 DRILL P PROD1 RIH wI BHA #12 (1.4/DS111) 13:00 - 13:15 0.25 DRILL P PROD1 Log tie-in down from 9480', corr -18,9' 13:15 - 14:00 0,75 DRILL P PROD1 RIH thru window, clean, Precautionary ream to TO and tag at 10538' PVT 326 14:00 - 15:10 1,17 DRILL P PROD1 Drill from 10538' 2.6/2.55/3300/100L wI 200-500 psi diff, 2-4k wob, 30-80'/hr, ECD 10,24. Drill to preliminary TO at 10595' 15:10 - 15:45 0.58 DRILL P PROD1 Wiper to window, clean 15:45 - 16:00 0.25 DRILL P PROD1 Log tie-in, corr 0.4' 16:00 - 16:40 0.67 DRILL P PROD1 Wiper to TO 16:40 - 16:50 0.17 DRILL P PROD1 Drill 3' to TO at 10598' and let it drill off PVT 322 16:50 - 17:40 0,83 DRILL P PROD1 Wiper to window 38k, 17k was clean 2,6/2.6/3200 Wiper in 5-1/2" to EOT was clean 17:40 - 22:10 4,50 DRILL N WAIT PROD1 Park at 9400' and circ at min rate while wo Reeves loggers and tools, Tools coming by road from Fairbanks, personnel arrived Slope this pm Change packoff 22:10 - 22:35 0.42 DRILL P PROD1 RIH to bottom, No problems, 22:35 - 00:00 1.42 DRILL P PROD1 TOH 6/10/2004 00:00 - 00:45 0,75 DRILL P PROD1 Continue TOH, Check last 200' of coil for wear from Cr tubing. Okay. 00:45 - 01 :00 0.25 DRILL P PROD1 LD BHi BHA 01 :00 - 05:30 4.50 EVAL N WAIT PROD1 Wait on Reeves logging tools. Truck arrived in Deadhorse at 0430 hrs, Change drivers and will deliver tools to rig. 05:30 - 09:00 3.50 EV AL P PROD1 Unload logging tools and surface test. 09:00 - 09:15 0,25 EVAL P PROD1 Safety mtg re: handle logging toolslsource 09:15 - 10:55 1.67 EVAL P PROD1 Load logging tools up beaver slide and MU logging assy. Check caliper arm, load source, Install BHI shorty assy. Stab CT 10:55 - 12:45 1,83 EVAL P PROD1 RIH wI BHA #13 (Reeves Full Suite wI BHI wob=180.4' OAL) wI EDC open 0,3/1000 12:45 - 13:25 0.67 EVAL P PROD1 Tie-in to flag at 9300' EOP and corr -18', RIH 30'/min logging down 21,7k 0.3/1230 to 10590', clean and Reeves didn't want to tag TO 13:25 - 13:50 0.42 EVAL P PROD1 Move CT while waiting for caliper to open at 1345 hrs, Park at 10590' 0.4/1150 Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/10/2004 13:50 - 14:40 0,83 EVAL P PROD1 PUH 38k logging up at 30'/min to 9180'. Flag at 9000' EOP 14:40 - 16:10 1,50 EVAL P PROD1 POOH wI logging tools 16:10 - 18:00 1,83 EVAL P PROD1 Set injector on legs, LD BHI tools, Check for logging data and have 6:17, LD/load out logging tools 18:00 - 18:30 0,50 CASE P PROD1 RlU to run liner. 18:30 - 18:45 0,25 CASE P PROD1 PSJM review procedures and hazards for running liner, 18:45 - 22:10 3,42 CASE P PROD1 PIU 45 jts 3-3/16" 6.2# L-80 TCllliner solid & slotted. PIU 1.25" CSH inner string, MU Baker CTRL T, 22:10 - 00:00 1.83 CASE P PROD1 MU BHi's ECD stab on injector. Test BHi tools. EDC has lost it's calibration, Need to LD, 6/11/2004 00:00 - 01 :00 1.00 CASE N SFAL PROD1 Setback injector, MU elevators. Swap out EDC tools, Retest good. 01 :00 - 02:45 1.75 CASE P PROD1 RIH with liner. Up wt check at 9460' 42K RIH stopped at 10270' . 02:45 - 04:30 1.75 CASE N DPRB PROD1 PU to 10200' RIH stopped at 10236' bring on pump to 2 bpm set for 5 min shut down pump PU to 10100' pump and RIH stopped at 10167' SO pump PU to 10100' RIH 1.7bpm stopped at 10233', Set down and pumped at 2bpm for 10min, SO pump RIH to 10301', PU free RIH to 10362', Pump 2,2 for 5min SO PU 57k RIH no-go. PU to 10310 pump 1,5 taking wt 10335' cont pumping 2,211,7 SO pump PU RIH to 10395'. Work at 10395 PU's tight. Pump 2,211,9 for 10 min SO pump PU RIH to 10427' Pump at 2.2 10 min (looking like cementrilizer hang-ups or pushing cuttings beds) SO pump pu RIH to 10455'. Pump 2.210 min SO pump pu RIH stopped at 10455'. Pump again 2.24/2.03 RIH to 10463'. Working this area wo much success, 04:30 - 06:00 1,50 CASE N DPRB PROD1 Continue working liner to bottom, Pumping 2,2bpm at 10459'. RIH to 10471, Continue cycle of pumping and attempting to RIH, 10484' at 0530 hrs 06:00 - 07:00 1.00 CASE N DPRB PROD1 Continue working liner 10-12 cyles, then pumping 1,9/1.9/3200 for 10-15 min wI stacked wt. Acts like metal to metal or more likely metal to hard rock-the 3,6" cementralizers just don't want to go past undergauge hole at 10020' and we don't have enough push left, Up wt 57k is clean for 20'. On wt is 13k. No further progress past 10488' at shoe which is 10470' ELMO verified by flag strategically placed not too far away (coil life is good) 07:00 - 08:30 1,50 CASE N DPRB PROD1 Circ while wo discussions in am call. 18-33 wellhouse is not pulled due to wind-will run agitator in the meantime, Circ 25 bbllubetex pill to shoe and circ 10 bbls out shoe 08:30 - 08:50 0,33 CASE N DPRB PROD1 Took 5 cycles up to 80k to move freely uphole at 55k. Try going downhole and still solid after 5 cycles at same spot 08:50 - 10:30 1,67 CASE N DPRB PROD1 Pump 1,8/2870 while hanging 8.4k wt and release GS from liner at 33.8k. POOH wI CT and inner string. ELMD of TOL is 9049' Crane MIRU on OS 18, Crews start working on installing L2-07 flowline, TS start laying plywood on access road to OS 18 10:30 - 11:30 1.00 CASE N DPRB PROD1 Tag up wI CT. Add Andergauge agitator and BTT accelerators above GS 11 :30 - 13:30 2.00 CASE N DPRB PROD1 RIH wI BHA #15 (1-1/4" CSH, BTT hyd GS, agitator, accel). Enter TOL, clean. RIH at 50'/min to tag at 10457' CTD (depth difference due to input depth of additional tools and referenced to bottom of BTT stinger). PUH 49k and GS had latched, Printed: 6/14/2004 9:15:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-14 L2-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/2/2004 Rig Release: 6/12/2004 Rig Number: N2 Spud Date: 6/2/2004 End: 6/12/2004 6/11/2004 11:30-13:30 2,00 CASE N DPRB PROD1 Slack off to neutral at 11,Sk and start pump 13:30 - 14:40 1.17 CASE N DPRB PROD1 1.7/1,7/3200/11.5k, 1.8/1,8/3440/5k, 1.8/1,8/3440,-1 k, 1 ,8/1 ,8/34201-3k at 10461' and no progress, Discuss 14:40 - 15:45 1,08 CASE P PROD1 Displace mud to 2% KCI while continuing to use agitator 1.9/1.9/32001-9k on TOL 1.8/1.8/3300 15:45 - 16:30 0.75 CASE P PROD1 With KCI halfway up annulus, and stacking -9k on TOL, liner moved downhole 23' to 10485' and stopped. Continue displacement wI -9k, Based on 10470' ELMO of prior depth, this should put shoe at 10493' and TOL at 9072' 16:30 - 17:30 1.00 CASE N DPRB PROD1 Fin displacement and continue agitating wI -10k 1,55/2000 17:30 - 19:00 1.50 CASE P PROD1 No further progress, Release from liner at 38k. POOH filling from BS 19:00 - 21:00 2,00 CASE P PROD1 Setback injector, RlU false RT and evelvators, UD BTT & BHi tools. Stand back hydril. 21:00 -21:15 0,25 CASE P PROD1 PIU nozzle and check valves, 21:15 - 22:30 1.25 CASE P PROD1 RIH to 9000'. 22:30 - 23:45 1.25 CASE P PROD1 TOH displacing tubing with diesel back to surface. Maintaining back pressure thnu choke. Trap 750 psi at surface. Close masterlswab valves, 23:45 - 00:00 0,25 CASE P PROD1 Washout stack, UD nozzle, 6/12/2004 00:00 - 02:30 2,50 DEMOB P POST Cut off BHi CTC, Dress coil and install SLB dimple connector. Pump slack management. Cut off 100' coil. Rehead with BHi connector. 02:30 - 04:30 2.00 BOPSU P POST NO BOPE, Install tree cap and test to 4k, 04:30 - 06:00 1,50 DE MOB P POST Rig released at 0600 hrs 6/12/04 (time allowed to move rig mats) Move rig off well and park for crew change. Prep to move to 18-33 Printed: 6/14/2004 9:15:41 AM It e L2-14B Prudhoe Bay Unit 50-029-21758-02-00 204-095 Accept: Spud: Release: Ri: POST RIG WORK 06/29/04 MUIRIH WI 2" JSN, JET TBG FROM 1200' WI HOT KCL TO TD @ 10452' (UP), PUMPED 82 BBLS 6 PPB BLEACH, MAKING 3 JETTING PASSES ACROSS SLOTTED LINER FROM 9200'-TD AND LAYING IN BLEACH ACROSS LINER, SOAK. TRY TO POP WELL WI AL. JET LINER @ MAX RATE WI KCL. CIRC KILL FROM TD TO FLUID PACK WELLBORE. CLOSE WING, PRE-INJECTIVITY = 1.3 BPM @ 570 PSI WHP, JET 81 BBLS 6 PPB BLEACH IN MULTIPLE PASSES ACROSS SLOTTED LINER TO TD, BEGIN SOAK. 06/30/04 SOAK 81 BBLS OF 6 PPB BLEACH JETTED INTO SLOTTED LINER. PERFORM POST BLEACH (BATCH #2) INJECTIVITY TEST. INJ 1.3 BPM @ 600 PSI WHP. POOH. TRY TO POP WELL WITH AL. RIH LIFTING WITH N2, JET LINER TO PBTD WITH N2. POOH LIFTING WITH N2. MONITOR WELL FOR SUSTAINED FLOW WHILE ON AL. WELL SLUGGED A FEW TIMES AND THEN APPEARED TO CYCLE AL GAS. RIH WI 2,5" JSN TO RESUME LIFTING WI N2. HIT OBSTRUCTION @ 6244' CTMD (GLM #3), SUSPECT HYDRATES, BEGIN JETTING 50/50 MEOH ON OBSTRUCTION, 07/01/04 RIH WI 2,5" JSN AND TAG UP @ 6244' CTMD. JET 50/50 MEOH ON OBSTRUCTION. UNABLE TO MAKE DOWNWARD PROGRESS (POSSIBLY TAGGING IN GLM). TRIP OUT OF HOLE FOR DJN, RIH WI 2" DJN, PASS THROUGH 6244' CTMD WITH NO PROBLEM, BEGIN PUMPING N2. MADE SEVERAL TRIPS TO PBTD. SURGED WELL TO TANK. WELL IS NOT CONTRIBUTING ANY SIGNIFICANT AMOUNT OF FLUID. CALLED TOWN, ELECTED TO TERMINATE N2 LIFT AND CANCEL LOGGING PROGRAM. FREEZE PROTECTED WELL TO 2500' WITH 50/50 METHANOL. WELL LEFT SHUT IN. DSO NOTIFIED. JOB COMPLETE. Obp e e ..a: INTEQ BP-GDB Baker Hughes INTEQ Survey Report Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre 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: L2-14 Slot Name: 14 L2-14 Well Position: +N/-S 5956.47 ft Northing: 5963455.72 ft Latitude: 70 18 16.618 N +E/-W 3796,09 ft Easting : 692967.04 ft Longitude: 148 26 12.067 W Position Uncertainty: 0.00 ft Wellpath: L2-14B 500292175802 Current Datum: 12: 14 10/8/198700:00 Magnetic Data: 5/26/2004 Field Strength: 57603 nT Vertical Section: Depth From (TVD) ft 32.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-14 9515.00 ft Mean Sea Level 25.36 deg 80.88 deg Direction deg 352.00 Height 45,00 ft Survey Program for Definitive Wellpath Date: 7/8/2004 Validated: Yes Version: 9 Actual From To Survey Toolcode ft ft 40.00 9487.45 1 : Schlumberger GeT multishot (40.oo-997&00)~ 9515.00 10598.00 MWd (9515.00-10598.00) MWD Tool Name Schlumberger GeT multishot MWD - Standard Annotation 9487.45 8844.04 TIP 9515,00 8868.48 KOP 10598.00 8916.56 TO Survey: MWd Start Date: 6/9/2004 CoilTrak Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 9487.45 27.38 98.13 8844.04 8799.04 -246.15 2465.87 5963273.00 695438.28 -586.94 0.00 9515.00 27.56 98.36 8868.48 8823.48 -247.97 2478.45 5963271.50 695450.90 -590.49 0.76 9534.37 29.41 98.36 8885.51 8840,51 -249.32 2487.59 5963270.40 695460,07 -593.10 9.55 9565.54 39,59 96.00 8911.16 8866.16 -251.47 2505.09 5963268.69 695477.61 -597.67 32.93 9596.28 50.70 91.00 8932.82 8887.82 -252.71 2526.79 5963268.01 695499.34 -601.91 37.91 9627.44 59.31 86,00 8950.68 8905,68 -251.98 2552.27 5963269.39 695524.79 -604,74 30.59 9657.33 68.38 81.00 8963.85 8918.85 -248,91 2578.88 5963273.15 695551.32 -605.40 33.84 9687.89 82.51 76.00 8971.51 8926,51 -242,99 2607.78 5963279.81 695580.05 -603,55 48.86 9707.89 92.44 72.73 8972.39 8927.39 -237,61 2626.99 5963285.68 695599.11 -600.90 52.26 9739.89 100.05 62.97 8968.91 8923.91 -225.65 2656.40 5963298.39 695628,21 -593.16 38.51 9774.66 99.92 47.91 8962.84 8917,84 -206.29 2684.52 5963318.47 695655.81 -577.89 42.66 Obp e BP-GDB Baker Hughes INTEQ Survey Report e -tIC INTEQ 9803.28 99.00 37.86 8958.13 8913.13 -185.63 2703.70 5963339.61 695674.46 -560.10 34.78 9834.41 100.45 31.03 8952.86 8907.86 -160.34 2721.05 5963365,33 695691.15 -537.48 22.12 9866.30 101.40 29.82 8946.82 8901,82 -133.34 2736.90 5963392.73 695706.31 -512.95 4.77 9897.80 101.48 24.96 8940.57 8895.57 -105.94 2751.10 5963420.49 695719.80 -487.79 15.12 9929.34 102.22 19.77 8934.09 8889.09 -77.41 2762.85 5963449.31 695730.80 -461.17 16.27 9959.63 101.06 13.95 8927.97 8882.97 -49.03 2771.44 5963477.90 695738.67 -434.26 19.20 9996.18 100.88 15.25 8921.02 8876.02 -14.30 2780.49 5963512.84 695746.81 -401.13 3.53 10026.24 90.17 9.40 8918.12 8873.12 14.87 2786.85 5963542.17 695752.42 -373,13 40.54 10055.83 86.63 358.73 8918.95 8873.95 44.33 2788.95 5963571.67 695753.76 -344.25 37.97 10086.97 89.46 346.45 8920,02 8875.02 75.13 2784.94 5963602.35 695748.96 -313.19 40.44 10117.59 86.02 338.12 8921.23 8876.23 104.25 2775.64 5963631.22 695738.92 -283.06 29.41 10149.18 86.85 332.65 8923.19 8878,19 132.90 2762.51 5963659.52 695725.06 -252.86 17.48 10180.39 90.91 331.60 8923.80 8878.80 160.48 2747.92 5963686.72 695709.77 -223.52 13.44 10209.83 90.57 327.73 8923.42 8878.42 185.88 2733,06 5963711.73 695694.26 -196.30 13.19 10242.43 90,90 320.60 8923.00 8878.00 212.29 2713.99 5963737.64 695674,52 -167.49 21.89 10270.19 88.76 317.89 8923.09 8878.09 233.31 2695.87 5963758.19 695655,87 -144.15 12.44 10311.59 89.00 312.13 8923.90 8878.90 262,57 2666.62 5963786.69 695625.88 -111.10 13.92 10340.42 91.64 308.60 8923.74 8878.74 281.24 2644.66 5963804.78 695603.44 -89.56 15,29 10371.20 90.72 303.66 8923.10 8878.10 299.38 2619.81 5963822.28 695578.14 -68.14 16.32 10400.74 93.82 299.40 8921,93 8876.93 314.81 2594.66 5963837.06 695552.60 -49.36 17.82 10433.18 92.81 294.65 8920.05 8875.05 329.52 2565.82 5963851.02 695523.40 -30.78 14.95 10472.44 89.89 287.79 8919.13 8874.13 343.72 2529.26 5963864.27 695486.48 -11.63 18.98 10502.67 90.11 282.77 8919.13 8874.13 351.68 2500.10 5963871.48 695457.14 0.31 16.62 10534.96 92.04 277.63 8918.52 8873.52 357.40 2468.34 5963876.38 695425.24 10.39 17.00 10556.52 91.73 275.65 8917.81 8872.81 359.89 2446.94 5963878,32 695403.78 15.84 9,29 10598.00 91.73 275.65 8916,56 8871.56 363.97 2405.68 5963881.34 695362.44 25.62 0.00 Survey: MWd (l2-141L2-148) DígUal Busìn$ss CHent UserDate: 7/8f2004 BP Amoco Parent WeUpath: 1.2-14 Tie on MD: 9515.00 I 2 1018 ~ 45.00fI Starting From TIID 352.00' 0.00 0.00 32.50 . TREE = ? SAFETY NOTES: *** 4-1/2" CHROM E TBG *** WElLl-EAD - FMC L2-14B Hß 250 lPPM) L2-14A WELLBORE NOT AcrUATOR = AXELSON KB. ELEV = 45.0' SHOWN ON DIAGRAM. BF. ELEV = KOP= 4400' Max Angle = 33 @ 6900' - 4-1/2" I-ES WElLSTAR TRSSSV, ID = 3.813" I Datum MD- 9489' . 2194' DatumTVD= 8800' SS L.o-.. GAS LFT MA.NDRELS ST MD lVD DEV lYÆ VLV LATa-! PORT DATE 110-314" CSG, 45.5#, L-80, ID = 9.953" 3897' ~ ~ 5 3014 3013 1 KBG-2 D'vtY BK 0 01/12/04 - 4 4793 4773 22 KBG-2 OOME BK 16 07/11/04 W 3 6227 6014 32 KBG-2 OOME BK 16 07/11/04 2 7660 7231 30 KBG-2 OOME BK 16 07/11/04 1 8975 8396 30 KBG-2 SlO BK 22 07/11/04 Minimum ID = 2.80" @ 9076' 3-112" X 3-3/13" XO I . I 9044' 4-1/2" HES X NIP, ID - 3.813" I 8 ~ 9065' - 7-5/8" X 4-112" S-3 A<R, ID - 3.875" I ~ II I-- 9072' r- 3.7" BTT DEPLOYMENT SLV, ID= 3.0" I ,..... r- 3-1/2"X 3-3/16" XO, ID-2.80" I 9076' 9131' - 4-1/2" HES X NIP, ID = 3.813" (BEHIND cr LNR) I . ,. 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, [) = 3.958" 9223' I 9223' 4-1/2" TT W/ MJLE SHOE (BEHIND cr LNR) I I HEUVI) TT NOTLOGGED I I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" I 9411' µ ~ I MLLOUT WINOOW 9515' - 9526' I I TOP OF WHPSTOCK 9515' -- ~ IBKR INFLA TABLE STANDING VLV 9620' I /, > I 10460' FBTD 5-1/2"LNR, 17#, L-80, .0232 bpf, [) =4.892" I 9976' . I PERFORATION SUMrvlARY REF LOG: 13-3/16" LNR, 6.2#, L-80, .0076 bpf, [) = 2.80" 10493' I ANGLEATTOPÆRF: 27@9387' f\bte: Refer to A-oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE L2-148 SLOTTED LNR 9387 - 10460 0 06/11/04 DATE REV BY COI'lltv'1ENTS DATE REV BY COMMENTS LlSBLRNE LNrr 10/31/87 ORIGINAL COMPLETION WELL: L2-14B 01/16/04 JLM/TlH RlNO PERMrr No: 2040950 01/28/04 TM l¡TLP CTDSI1TRK- OPEN HOLE AR No: 50-029-21758-02 06/12/04 JDM/KAK CTD SIŒTRACK (l2-14B) SEC 18, T11 N, R15E, 979.09' FEL & 4005.15' Ff\J... 07/11/04 JLJA<AK GL V C/O BP Exploration (Alaska) . . , I , ¡ FRANK H. MURKOWSK/, GOVERNOR I AI,ASIiA OIL AlQ) GAS CONSERVATION COMMISSION / / 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. box 196612 Anchorage, Alaska 995119-6612 Re: Prudhoe Bay L2-14B BP Exploration (Alaska) Inc. Permit No: 204-095 Surface Location: 1556' NSL, 1272' EWL, SEC.18. TI1N, RI5E, UM Bottomhole Location: 1914' NSL, 3677' EWL, SEe. 18, TIIN, RI5E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ffom obtaining additional permits or approvals required by law ffom 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 to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 07 (pager). BY ORDER r.'¿'~ COMMISSION DATED this ~f June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. R . STATE OF ALASKA .' ALASKA~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 (~ttËtt /z-cc4 N (1:J '¿¡:J04 Revised 06/03/0fin~ API Change /' 1a, Type of work o Drill RRedrill rb. Current Well Class o Exploratory R Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 1 00302630-277 PBU L2-14B "..- 3. Address: 6, Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10598 TVD 8869ss Prudhoe Bay Field I Lisburne 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028321 1556' NSL, 1272' EWL, SEC. 18, T11N, R15E. UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: June 3, 2004 r 1296' NSL, 3831' EWL, SEC. 18, T11N, R15E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1914' NSL, 3677' EWL, SEC. 18, T11N. R15E, UM 2560 15,840' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 692968 y- 5963457 Zone- ASP4 (Height above GL): 45' feet 18-16B is 855' away 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Kickoff Depth 9515 ft Maximum Hole Angle 102 0 Downhole: 3700 psig Surface: 2810 psig 18;G¡:¡sjr'l~·· Progrªm $~!t¡!,!g pepth .:.(c,f;:ar:"'§acks) Size ....... ....... Top < >.Bottom <.< ............ Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD (includino staoe data) 3-3/4" x 4-1/8" 3-3/16" 6.2# L-80 TCII 1318' 9280' 8616' 10598' 8869' Uncemented Slotted Liner / 19, PRE$E.NT WELL CONDITION. $l.!MMARY (To'be cqrnplétéQ for RêdriU ANP Re~~mtryOperª1iol'J~) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): 10400 9148 9515 9515 8868 None Gª$¡I'lgi ....... ·L.êr'l!'.lth ISizés. >; .< ....... . i.; .i < :M/¡)F :;;i;< . TV/¡) Structural Conductor 112' 20" 2100# Poleset 112' 112' 3897' 10-3/4" 1500 sX AS '". 325 sx Class 'G', Top Job: 150 sx AS' 3897' 3897' Inter 9411' 7-5/8" 610 sx Class 'G' 9411' 8776' Prnri, ,dinn Liner 449' 5-1/2" 200 sx Class 'G' 9207' - 9656' 8596' - 8993' Perforation Depth MD (ft): 3-3/16" Open Hole: 9656' - 10400' perfOration Depth TVD (ft): Open Hole: 8993' - 9148' 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 18120 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 Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer z.ß d' ~ Date "h-;{, J Prepared By Name/Number: SiQnature Phone 564-4694 Terrie Hubble. 564-4628 i.· :.<p ..... <fi) i)f, « .~ ;~X 0'.'·· </i> ·i:.< .. .' .. .··i·ii .i Permit To Drill 204-095 API Number: Permit APprrl1 OL 1~ee cover letter for Number: 50- 029-21758-02-00 Date: other requirements Conditions of Approval: Samples Required DYes ,Q(No Mud Log Requíred I jYes J8No Hydrogen Sulfide Measures $,Yes 0 No Directional Survey Required Yes 0 No Other: -res{- l~ot)E ·~SOC pU e e~v C c:::: 5/1.00e ~ ~ >',. ""/i 1A~ ('. '4 r í !.0";.1\1 BY ORDER OF Date b-f/~cI ADDroved THE COMMISSION Form 10-401 ~e ~u03 .......-- .... ¡ \ ! <J i I \f /~i' ,.8ub~ In DuPlicate . . BP L2-14B CTD Sidetrack Summary of Operations: A sidetrack ofL2-14A is underway with coiled tubing. The sidetrack, initially permitted as L2-14AL1, will ,...- kick off from a window milled from a mechanical whipstock set above the existing L2-14A window. A standing valve was set between the L2-14A window and the proposed L2-14AL1 window to permit flow from the L2-14A open hole while preventing flow into the L2-14A open hole. However, the standing valve failed to hold pressure from above just as the rig operations were about to begin. It was decided to abandon the relatively low value L2-14A lateral rather than attempt repair of the failed standing valve. The sidetrack planned as L2-14ALl will now be drilled as L2-14B. Approximately 1,362 ft of3,75"-41/8" open hole is planned to access the L2-14B target. This sidetrack will be completed with a slotted, un-cemented liner. The slotted liner top will be placed just inside the 4 Yí" tubing tail at approx, 9280'MD (8616ss), Pre-rig work: (completed) 1. Tubing integrity was re-confirmed via a tubing inflow test. 2. A standing valve was installed on an inflatable packer at approx. 9620' MD (8917ss). 3. A mech. whipstock was set at 9515' MD (8824ss). Nordic 2 CTD - Mill window, Drill and Complete sidetrack: 1. NU ~-1 Hi" ,CTD BOPE. Test. . 2. Pum 25 < Is cement to abandon the L2-14A lateral due to failure of the standing valve, / 3. MilI window through the 5 1/2" liner. 4. Directionally drill -1362' of 3.75"-4 1/8" open hole. 5. Log open hole with GRJResistivity/Density/NeutronlSonic (Reeves), 7. Run 3 3/16" slotted & solid liner from TD to approx. 9280'MD (8616ss), 8. Displace well to diesel. RD Nordic 2. Mud Program: · PIo-Pro (8,6 - 8,7 ppg), If lost circulation is severe, the Flo-Pro drilling fluid will be diluted with 8.6 ppg brine to reduce the cost of fluids that will be lost. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 1,318 ft of 33/16",6.2 #/ft, L-80, TC II slotted and solid un-cemented liner. Well Control: · BOP diagrams are attached, · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is approx. -102 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run, Logging · An MWD Gamma Ray will be run over the entire open hole section. A full suite of memory open hole logs will be run at TD consisting of GRJResistivity/Sonic/Density/Neutron. DLL will also be run if hole conditions are favorable. . . Hazards · L2 i~~~2S Pad. Most wells on L2 Pad measure between 25 and 50 ppm H2S in produced fluids. · Lost circulation risk is considered high. Drilling will be done with watered down Plo-Pro if losses are near total. · Mudstones drilled at high inclination are a hazard to hole stability. All drilling fluids will be enhanced for mudstone inhibition. Reservoir Pressure · Pore pressure is estimated to be 3700 psi at 8900'TVDss (8.0 ppg emw). · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2810 psi. / ? N COMMENTS Plan: Plan #119 (L2-14/Plan#119 L2-14B) Created By: James Ohlinger Date: 6/3/2004 Contz.¡c1 ¡nforfn<1~ior t.om Baker H;JgfH::'j. Azimuths to True North Magnetic North: 25.36' Magnetic Field Strength: 57603nT Dip Angle: 80.88' Date: 5/26/2004 Modei: bggm2003 T tl ~ L2-14 (L2·14) l2-14 (L2-14A) Plan#119 L2-14B Plan#119 . 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 . West(-)/East(+) [50ft/in] Vertical Section at 352,00· [10ft/in] AM .... C 250 æ CI II) .... -- + -- .c 1:: o z ;::;., ...:,.. .c .. ~ o en Shape Po/vgon Pctvgon Polygon ~~~~ Point PoiO! BP Amoco WELLPATH DETAILS ,1_n"119 L2-148 500292175802 '.rent Wellp.th: L2·14 Tie on MD: 9487.45 Rig: MonIle 2 Ref.D.tum: 12: 14101811987 00:00 45.00ft V.Section ~~~ ~~= ::::t\D Anllle 352.00' 0.00 0.00 32.50 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: l2-14, True North Vertical (TVD) Reference: System: Mean Sea Level Mea~~~d1>z;,~~ ~~~:~:~~:~ ~~o~ 11~ð~å~f~a~·gg:~b 45.00 Calculation Method: Minimum Curvature ANNOTAnONS TVO MD Annowtion ,- L2·14AFault115.A 1798.04 8487.45 TIP ~:m~:~~11~:g 8823.48 9515.00 KOP 8841.07 . 3 L2-14APolygon11g. 8822.58 · tt1:~ ~~~: ¡15_C 8....80 · L2-14AT11g,2 "63.04 · "'2.96 7 "'3.9S · "68.63 TD - 8660 ....8720 C ~ 8740 ~8760 .c 'S. 8780 GI ,l;j 8800 Glii en U 8820 ~.- Jri 8840 > GI 8860 ë to- 8880 896 8900 8920 eaker Hughes Incorpor. BHI Planning Report Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: Lis OS 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 L2-14 L2-14 Well Position: Slot Name: 14 ft Northing: 5963455.72 ft Latitude: 70 18 16.618 N ft Easting : 692967.04 ft Longitude: 148 26 12.067 W ft -~~-~ Well: +N/-S 5956.47 +E/-W 3796.09 Position Uncertainty: 0.00 .._.~_._--.._-~._-~ Wellpath: Plan#119 L2-14B 500292175802 Current Datum: 12 : 14 10/8/1987 00:00 Magnetic Data: 5/26/2004 Field Strength: 57603 nT Vertical Section: Depth From (TVD) ft 32.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L2-14 9487.45 ft Mean Sea Level 25.36 deg 80.88 deg Direction deg 352.00 Height 45.00 ft Plan: Plan #119 Similar to Ted's Case 119 Principal: Yes Date Composed: Version: Tied-to: 5/26/2004 2 From: Definitive Path Targets L2-14A Fault 115.A 45.00 853.31 1841.60 5964356.00 694786.00 70 18 25.008 N 148 25 18.361 W -Polygon 1 45.00 853.31 1841.60 5964356.00 694786.00 70 18 25.008 N 148 25 18.361 W -Polygon 2 45.00 856.14 2120.78 5964366.00 695065.00 70 18 25.036 N 148 25 10.219 W -Polygon 3 45.00 913.24 2390.35 5964430.00 695333.00 70 18 25.596 N 148 25 2.357 W -Polygon 4 45.00 918.02 2671.58 5964442.00 695614.00 70 18 25.642 N 148 2454.155 W -Polygon 5 45.00 920.82 2951.76 5964452.00 695894.00 70 18 25.669 N 148 24 45.985 W -Polygon 6 45.00 918.02 2671.58 5964442.00 695614.00 70 18 25.642 N 148 2454.155 W -Polygon 7 45.00 913.24 2390.35 5964430.00 695333.00 70 18 25.596 N 148 25 2.357 W -Polygon 8 45.00 856.14 2120.78 5964366.00 695065.00 70 18 25,036 N 148 25 10.219 W L2-14A Fault 115.B 45.00 425.61 2212.76 5963938.00 695168.00 70 18 20.801 N 148 25 7.540 W -Polygon 1 45.00 425.61 2212.76 5963938.00 695168.00 70 18 20.801 N 148 25 7.540 W -Polygon 2 45.00 590.32 2460.08 5964109.00 695411.00 70 18 22.420 N 148 25 0.327 W -Polygon 3 45.00 647.44 2728.65 5964173.00 695678.00 70 18 22.981 N 148 24 52.494 W -Polygon 4 45.00 705.57 2997.25 5964238.00 695945.00 70 18 23.552 N 148 24 44.660 W -Polygon 5 45.00 647.44 2728.65 5964173.00 695678.00 70 18 22.981 N 148 24 52.494 W -Polygon 6 45.00 590.32 2460.08 5964109.00 695411,00 70 18 22.420 N 148 25 0.327 W L2-14A Fault 115.0 45.00 -222.00 2071.07 5963287.00 695043.00 70 18 14.432 N 148 25 11.677 W -Polygon 1 45.00 -222.00 2071.07 5963287.00 695043.00 70 18 14.432 N 148 25 11.677 W -Polygon 2 45.00 -326.84 2374.49 5963190.00 695349.00 70 18 13.400 N 148 25 2.831 W -Polygon 3 45.00 -216.37 2630.43 5963307.00 695602.00 70 18 14.486 N 148 24 55.367 W -Polygon 4 45.00 -159.30 2901.00 5963371.00 695871.00 70 18 15.046 N 148 24 47.477 W -Polygon 5 45.00 -156.49 3181.18 5963381.00 696151.00 70 18 15.073 N 148 24 39.307 W -Polygon 6 45.00 -159.30 2901.00 5963371.00 695871.00 70 18 15.046 N 148 24 47.477 W -Polygon 7 45.00 -216.37 2630.43 5963307.00 695602.00 70 18 14.486 N 148 24 55.367 W -Polygon 8 45.00 -326.84 2374.49 5963190.00 695349.00 70 18 13.400 N 148 25 2.831 W eaker Hughes Incorpor. BHI Planning Report lNTEQ L2-14A Polygon119.1 695413.00 148 25 0.800 W -Polygon 1 5963408.00 695413.00 148 25 0.800 W -Polygon 2 5963558.00 695932.00 148 24 45.557 W -Polygon 3 5963974.00 695695.00 148 2452.149 W -Polygon 4 5963830.00 695192.00 148 25 6.923 W L2-14A Fault 115.C 45.00 321.78 2516.21 5963842.00 695474.00 70 18 19.779 N 148 24 58.692 W -Polygon 1 45.00 321.78 2516.21 5963842.00 695474.00 70 18 19.779 N 148 24 58.692 W -Polygon 2 45.00 378.90 2784.78 5963906.00 695741.00 70 18 20.340 N 148 24 50.860 W -Polygon 3 45.00 437.00 3054.38 5963971.00 696009.00 70 18 20.910 N 148 24 42.998 W -Polygon 4 45.00 378.90 2784.78 5963906.00 695741.00 70 18 20.340 N 148 24 50.860 W L2-14A T119.1 8869.00 -248.51 2479.55 5963271.00 695452.00 70 1814.170N 148 24 59.767 W L2-14A T119.2 8913.60 357.21 2422.08 5963875.00 695379.00 70 18 20.128 N 148 25 1.437 W Annotation 9487.45 8844.04 TIP 9515.00 8868.48 KOP 9535.00 8886.07 3 9745.00 8967.59 4 10030.00 8911.80 5 10073.00 8908.04 6 10253.00 8907.96 7 I 10403.00 8908.98 8 I 10598.00 8913.63 TO _____J Plan Section Information 9487.45 27.38 98.13 8844.04 -246.15 2465.87 0.00 0.00 0.00 0.00 9515.00 27.56 98.36 8868.48 -247.97 2478.45 0.76 0.65 0.83 30.62 9535.00 29.36 98.36 8886.07 -249.36 2487.88 9.00 9.00 0.00 0,00 9745.00 101.79 83.59 8967.59 -244.72 2665.99 34.94 34.49 -7.03 344.90 9840.00 101.00 49.65 8948.27 -208.31 2750.11 35.01 -0.83 -35.73 272,13 9935.00 101.00 15.76 8929.62 -131.07 2799.71 35.00 0.00 -35.67 273.33 10030.00 100.00 341.91 8911.80 -39.12 2797.80 35.03 -1,05 -35.63 271.50 10073.00 90.02 331.06 8908.04 0.03 2780.72 34.19 -23.21 -25.23 227.88 10253.00 90.03 302.26 8907.96 129.57 2658.48 16.00 0.01 -16.00 270.03 10403.00 89.20 326.27 8908.98 233.50 2551.85 16.02 -0.55 16.01 92.03 10598.00 88.14 295.04 8913.63 358.95 2405.79 16.02 -0.54 -16.02 267.73 eaker Hughes Incorpor. BHI Planning Report lNTEQ 9487.45 27.38 98.13 8799.04 -246.15 2465.87 5963273.00 695438.28 0.00 -586.94 0.00 TIP 9500.00 27.46 98.24 8810.18 -246.97 2471.59 5963272.33 695444.02 0.76 -588.55 30,62 MWD 9515.00 27.56 98.36 8823.48 -247.97 2478.45 5963271.50 695450.90 0,76 -590.49 30.52 KOP 9515.58 27.61 98.36 8824.00 -248.01 2478.72 5963271.4 7 695451.16 9.00 -590.57 360.00 L2-14A 9535.00 29.36 98.36 8841.07 -249.36 2487.88 5963270.36 695460.36 9.00 -593.18 0.00 3 9540.00 31.05 97.48 8845.39 -249.71 2490.37 5963270.08 695462.86 34.94 -593.87 344.90 MWD 9550.00 34.45 95.95 8853.80 -250.33 2495.74 5963269.59 695468.24 34.94 -595,24 345.67 MWD 9560.00 37.86 94.66 8861.87 -250.88 2501.61 5963269.20 695474.13 34.94 -596.59 346.95 MWD 9568.70 40.83 93.70 8868.60 -251.28 2507.12 5963268.94 695479.64 34.94 -597,76 347.99 L2-14A 9570.00 41.28 93.56 8869.58 -251.33 2507.97 5963268.91 695480.49 34,94 -597.93 348.74 MWD 9580.00 44.71 92.60 8876.89 -251.70 2514.78 5963268.72 695487.30 34.94 -599.24 348.84 MWD 9590.00 48.15 91.75 8883.78 -251.97 2522.01 5963268.63 695494.55 34.94 -600.52 349.54 MWD 9600.00 51.60 90.99 8890.23 -252.15 2529.66 5963268.64 695502.19 34.94 -601,76 350.13 MWD 9610.00 55.05 90.29 8896.20 -252.24 2537.68 5963268.76 695510.21 34.94 -602.96 350.62 MWD 9620.00 58.50 89.66 8901.68 -252.24 2546.04 5963268.98 695518.57 34.94 -604.12 351.04 MWD 9630.00 61.96 89.06 8906.64 -252.14 2554.72 5963269.30 695527.24 34.94 -605.23 351.39 MWD 9640.00 65.41 88.51 8911.08 -251.95 2563.68 5963269.72 695536.19 34.94 -606.29 351.68 MWD 9650.00 68.88 87.98 8914.96 -251.66 2572.89 5963270.24 695545.39 34.94 -607.29 351.93 MWD 9660.00 72.34 87.48 8918.28 -251.29 2582.31 5963270.86 695554.80 34.94 -608.23 352.13 MWD 9670.00 75.80 87.00 8921.02 -250.83 2591.91 5963271.57 695564.39 34.94 -609.11 352.30 MWD 9680.00 79.27 86.53 8923.18 -250.28 2601.66 5963272.37 695574.12 34.94 -609.92 352.43 MWD 9690.00 82.73 86.07 8924.75 -249.64 2611.52 5963273.26 695583.95 34.94 -610.66 352.53 MWD 9700.00 86.20 85.62 8925.71 -248.92 2621.44 5963274.23 695593.86 34.94 -611.33 352.60 MWD 9710.00 89.66 85.17 8926.07 -248.11 2631.40 5963275.29 695603.79 34.94 -611.92 352.65 MWD 9720.00 93.13 84.73 8925.83 -247.24 2641.36 5963276.43 695613.72 34.94 -612.44 352.66 MWD 9730.00 96.59 84.28 8924.98 -246.28 2651.27 5963277.64 695623.61 34.94 -612.87 352.65 MWD 9740.00 100.06 83.82 8923.53 -245.26 2661.11 5963278.91 695633.42 34.94 -613.22 352.61 MWD 9745.00 101.79 83.59 8922.59 -244.72 2665.99 5963279.58 695638.28 34.94 -613.37 352.55 4 9750.00 101.85 81.80 8921.56 -244.09 2670.85 5963280.32 695643.12 35.01 -613.43 272.13 MWD 9760.00 101.93 78.23 8919.50 -242.40 2680.48 5963282.27 695652.71 35.01 -613.09 271.76 MWD 9770.00 101.97 74.65 8917.43 -240,10 2689.99 5963284.80 695662.15 35.01 -612.14 271.03 MWD 9780.00 101.97 71.07 8915.35 -237.22 2699.34 5963287.93 695671.42 35.01 -610.59 270.29 MWD 9790.00 101.92 67.49 8913.28 -233,76 2708.49 5963291.62 695680.48 35.01 -608.43 269.54 MWD 9800.00 101.82 63.91 8911.23 -229,73 2717.41 5963295.87 695689.29 35.01 -605.69 268.80 MWD 9810.00 101.68 60.34 8909,19 -225.16 2726.06 5963300.67 695697.82 35.01 -602.36 268.07 MWD 9820.00 101.50 56.77 8907,18 -220.05 2734.41 5963305.99 695706.04 35.01 -598.46 267.34 MWD 9830.00 101.27 53.21 8905.20 -214.43 2742.44 5963311.82 695713.92 35.01 -594.01 266.62 MWD 9840.00 101.00 49.65 8903.27 -208.31 2750.11 5963318.13 695721.43 35.01 -589.02 265.92 MWD 9850.00 101.18 46.09 8901.35 -201.73 2757.39 5963324.90 695728.54 35.00 -583.52 273.33 MWD 9860.00 101.32 42.52 8899.40 -194.71 2764.24 5963332.09 695735.20 35.00 -577.52 272.64 MWD 9870.00 101.42 38.95 8897.42 -187.28 2770.63 5963339.68 695741.41 35.00 -571.06 271.95 MWD 9880.00 101.47 35.38 8895.44 -179.47 2776.56 5963347.63 695747,13 35.00 -564.15 271.24 MWD 9890.00 101.48 31.81 8893.45 -171.31 2781.98 5963355.93 695752.34 35.00 -556.82 270.53 MWD 9900.00 101.45 28.24 8891.46 -162.83 2786.88 5963364.54 695757,02 35.00 -549.10 269.82 MWD 9910.00 101.38 24.67 8889.48 -154.05 2791.25 5963373.42 695761.16 35.00 -541.02 269.11 MWD 9920.00 101.26 21.10 8887.52 -145.02 2795.06 5963382.55 695764.74 35.00 -532.61 268.41 MWD 9930.00 101.10 17.54 8885.58 -135.77 2798.30 5963391.88 695767.74 35.00 -523.89 267.71 MWD 9935.00 101.00 15.76 8884.62 -131,07 2799.71 5963396.62 695769.03 35.00 -519.43 267.01 MWD 9940.00 101.04 13.98 8883.66 -126.32 2800.97 5963401.39 695770.17 35.03 -514.91 271.50 MWD 9950.00 101.09 10.41 8881.74 -116.73 2803.04 5963411.03 695771.99 35.03 -505.70 271.16 MWD 9960.00 101.10 6.84 8879.82 -107.03 2804.51 5963420.77 695773.21 35.03 -496.30 270.48 MWD 9970.00 101.07 3.27 8877.90 -97.26 2805.38 5963430.56 695773.82 35.03 -486.74 269,79 MWD 9980.00 100.99 359.70 8875.98 -87.45 2805.63 5963440.37 695773.83 35.03 -477,06 269.10 MWD .aker Hughes Incorpor. BHI Planning Report 9990.00 100.87 356.13 8874.08 -77.64 2805.27 5963450.17 695773.22 35.03 -467.30 268.42 MWD 10000.00 100.71 352.57 8872.21 -67.86 2804.31 5963459.92 695772.00 35.03 -457.49 267.74 MWD 10010.00 100.52 349.01 8870.37 -58.16 2802.73 5963469,57 695770.18 35.03 -447.66 267.08 MWD 10020.00 100.28 345.46 8868.56 -48.57 2800.56 5963479.10 695767.76 35.03 -437.86 266.42 MWD 10030.00 100.00 341.91 8866.80 -39.12 2797.80 5963488.47 695764.75 35.03 -428.12 265.78 5 10040.00 97.70 339.35 8865.26 -29.80 2794.52 5963497.71 695761.24 34.19 -418.44 227.88 MWD 10050.00 95.38 336.82 8864.13 -20.59 2790.81 5963506.82 695757.30 34.19 -408.79 227.49 MWD 10060.00 93.05 334.31 8863.39 -11.51 2786.69 5963515.79 695752.94 34.19 -399.23 227.20 MWD 10070,00 90.72 331.81 8863.06 -2.60 2782.16 5963524.58 695748.18 34.19 -389.78 227.01 MWD 10073.00 90.02 331.06 8863.04 0.03 2780.72 5963527.18 695746.68 34.19 -386.97 226.93 6 10075,00 90.02 330.74 8863.04 1,78 2779.75 5963528.90 695745.66 16.00 -385.10 270.03 MWD 10100.00 90.02 326.74 8863.03 23.15 2766.78 5963549.92 695732.15 16.00 -362.14 270.03 MWD 10125.00 90.02 322.74 8863.02 43.56 2752.35 5963569.96 695717.20 16.00 -339.92 270.02 MWD 10150.00 90.03 318.74 8863.01 62.91 2736.53 5963588.90 695700.89 16.00 -318.56 270.02 MWD 10175.00 90.03 314.74 8863.00 81.11 2719.40 5963606.65 695683.30 16.00 -298.15 270.02 MWD 10200.00 90.03 310.74 8862.99 98.07 2701.05 5963623.14 695664.52 16.00 -278.79 270.02 MWD 10225.00 90.03 306.74 8862.98 113.72 2681.55 5963638.27 695644.63 16.00 -260.59 270.02 MWD 10250.00 90.03 302.74 8862.96 127.96 2661.01 5963651.98 695623.73 16.00 -243.63 270.02 MWD 10253.00 90.03 302.26 8862.96 129.57 2658.48 5963653.53 695621.16 16.00 -241.68 270.01 7 10275.00 89.91 305.78 8862.97 141.88 2640.25 5963665.36 695602.62 16.02 -226.95 92.03 MWD 10300.00 89.76 309.78 8863.05 157.19 2620.50 5963680.16 695582.48 16.02 -209.04 92.03 MWD 10325.00 89.62 313.78 8863.18 173.85 2601.86 5963696,33 695563.42 16.02 -189.95 92.02 MWD 10350.00 89.48 317.79 8863.37 191.76 2584.43 5963713.79 695545.54 16.02 -169.79 92.00 MWD 10375.00 89.35 321.79 8863.63 210.85 2568.29 5963732.45 695528.92 16.02 -148.64 91.97 MWD 10400.00 89.22 325.79 8863.94 231.01 2553.53 5963752.23 695513.64 16.02 -126.62 91.93 MWD 10403.00 89.20 326.27 8863.98 233.50 2551.85 5963754.68 695511.90 16.02 -123.92 91.88 8 10425.00 89.06 322.75 8864.32 251.41 2539.08 5963772,25 695498.68 16.02 -104.41 267.73 MWD 10450.00 88.91 318.75 8864.76 270.76 2523.27 5963791.19 695482.37 16.02 -83.05 267.79 MWD 10475.00 88.76 314.74 8865.27 288.96 2506.14 5963808.94 695464.79 16.02 -62.64 267.86 MWD 10500.00 88.62 310.74 8865.84 305.92 2487.79 5963825.42 695446.01 16.02 -43.29 267.94 MWD 10525.00 88.49 306.73 8866.47 321.55 2468.30 5963840.55 695426.12 16.02 -25,10 268.03 MWD 10550.00 88.36 302.73 8867.16 335.79 2447.77 5963854.25 695405.23 16.02 -8.14 268.13 MWD 10575.00 88.24 298.73 8867.90 348,55 2426.29 5963866.46 695383.43 16.02 7.49 268.24 MWD 10598.00 88.14 295.04 8868.63 358.95 2405.79 5963876.32 695362.67 16.02 20.63 268.36 TO TERRIE L HUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 First National ank Alaska Anchorage, AK 99501 MEMO L"./~6 89-6/1252 11 0 DATE 00 -03 - O<j $ 100.00 -- DOLLARS -1øW-~ ¿yf ki~ð~ . I: ~ 25 2000bOI:1111 ~~'"b 2 2 7"1 ~ 55b"- 0 ~ ~O . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME/'ì>('4 L-/~~ PTD# 201.j-ð 75 >< Development Service Exploration Stratigraphic CHECK WBA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI Tbe permit is for a new weJlbore segment of LATERAL existing well , Permit No, API No. . (If API number Production sbould continue to be reported as last two (2) digits a function' of tbe original API number, stated are between 60-69) above. PILOT BOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) " and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ,to fuD EX CEPTJ ON compliance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e~ ception. (Company Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. DRY DITCH An dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample bjtervals through target zones. . . o o Well bore seg Annular Disposal Field & Pool PRUDHOE BAY, LISBURNE OIL - 640144 Well Name: PRUDHOE BAY UN US L2-14B _ Program PLORA TION (ALASKA) INC Initial ClasslType ------Lj-OIL GeoArea 890 Unit j 1650 _ On/Off Shore On Administration P~rmit fee attachep. . - - - - - Yes 2 Lease .number appropriate. Y.es. 3 .U.nlque weltn.ame.and oumb.er . . . . . . . . . . . . . . . . . . . . . _ .' . .... . .Yes - - - - - - - - - - - - - - - - - - - - 4 Well JQcated in.a ci.efinepPool. . - - - - - Yes 5 WeJUQcated proper .distance. from driJling unitbounda(}'. . . Yes 6 Well JQcated proper .dlstance from Qtoer welJs. . . Yes - - -- 7 .S.utficient .acreag.eayailable In. dJil\iog unjt. Yes 8 Jf.devi<lted, js weJlbore pl<lUncluped . - - - - Y~s 9 .Operator onl}' affected party. . . Y~s 10 .Operator bas.approprlate-'~_ond lnJorce . . . . . . . . . . . . . . . . . ........ Y~s - - - - - . - - - - - - - - - - - - -- 11 Permit c.an be lssued witlJQut conserva.tion order. . Y~s Appr Date 12 Permit. can be lssued witoQut <ld.ministratilleapprovaJ . . . . . . Y~s RPC 6/4/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcat~d wlthin area <In.dstrata .authorlzed by.lojectioo Ord~r # (puUO# in.c.om[11~ots) (For .NA - - - - - - - 15 .AJI wells.withtn.1l4.roite.area.of reyiew id~otlfied (F.or servjc.ewe!l only). . . . . . . . . . . . . NA - - - - - - - - - - - - - - - - - - - - 16 PJe-produced injector; puration.of pre-propuctioo I~ss than.:3 montos. (Forservtce well only) NA 17 ACMP finding.of Consi.stencyhas bee.n issued. for. tbis pr.oject . NA - Engineering 18 .C.onductor stringpJQvided . . . - - - - NA 19 .S!Jrface.GasingpJotects alLknown. USDWs . NA 20 .CMT v.ol. adequate. to circ!Jl.ate. on conductor & sUIt csg . NA 21 .CMT vol. adequate.!o tie-in JQng .string to .surf csg . NA - - - - 22 .CMTwill coyer.aJ/ J<oownpro.ductiye bQri;1:on.s. . No Slotted, 23 .C.asing designs adeç¡ua.te f.or C..l:, B&.perroafrost . . . Yes 24 Apequatetan.k<lgeor re.serve pit. Y~s CTDU. 25 Jf.a.re-prill~ basa 10-403 for abandonme.nt be~n apPJQved . . . . . Y~s * 26 .Apequat.e .w.e!lbore separ¡:¡tio.n .proposed. . . . . _ . . _ . . _ . _ . . _ . . Y~s - - - - - - - - - - - - - - - - ~ - - - 27 Jf.diverter Jeq.uired, dQes it meet. reguJa.tions . . . .NA Sidetrack.. . . . . . Appr Date 28 .DriUiog fluid program sc.hematic.& eq.uipJistadequate. . . . .Y~s M<lx MW.8,7. ppg.. WGA 6/4/2004 29 .BOPEs,d.o.they meetreguJation . . . - - - - - - - - - - - - - - .Y~s - - -- 30 B.OPE.press rati[lg appropriate; .testto (put psig in .comments) . . Yes Test to.3500. psi. .MSF' 28.10 psi.. 31 .C.hoke.manifold cQmpJies w/APtRF'-5:3 (May 84). . .Yes 32 Work will occur withoutoperatjonsbutdown. . .Y~s 3~ .Is presence. Qf H2S g<ls. prob.able. . - - - - No. 34 MecOa.nlcaLcoodjtion .of wells wi.thin AOR verified (for. s.ervice well onJy) NA Geology 35 P~rmit c.a[l be i.ssued w/Q hydrogen. sulfide meas.uœs No 36 .D.ata.PJeseoted on pote.ntial overpressure .zones. NA Appr Date 37 S~ìsmican<llysjs. Qf soaJlow gaszooes NA RPC 6/4/2004 38 .Se<lbep .conditi.oo $urvey(if off-shore) NA 39 . CQntact oam.elphooefor.....eeIs1y pro )rls [I - Geologic Date: Engineering Date Commissioner: Commissioner Dr~ 6(7/"(-. 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 ;1or- 09S- **** REEL HEADER **** MWD 05/02/02 # {3 () ,-1 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/02/28 696246 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 9506.0000: STOP.FT 10598.0000: 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 NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 18 TOWN, N 11 RANG. 15 PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 45 DMF KB EKB .F 45 EDF .F N/A EGL . F 0 CASE.F 9526.6 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 (5) Tools run in the string included Casing Collar Locator, Electrical Disconnect and 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. L2-14B Prudhoe Bay Unit 70 deg 18' 16.046" N 148 deg 26' 12.067" W North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 09-June-04 500292175802 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 Circulating sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and a Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on Jun 11, 2004. (7) The sidetrack was drilled from milled window in 5 1/2" Liner. Top of the window. 9515.5 ft. MD (8823.9 ft. TVD) Bottom of window. 9526.6 ft. MD (8833.7 ft. TVD) (8) The interval from 10559 ft. to 10598 ft. MD (8872 ft. to 8871 ft. TVD) was not logged due to bit to sensor offset. (9) Tied in to L2-14A at 9462 ft. MD (8777 ft. TVD). 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, 9512.12, 9511.91, 9526.88, 9526.04, 9547.86, 9547.24, 9560.33, 9559.29, 9564.9, 9564.7, 9566.77, 9566.98, 9570.52, 9569.48, 9574.46, 9574,26, 9584.23, 9583.61, 9592.69, 9592.28, 9607.45, 9606.82, 9634.26, 9633.42, 9640.03, 9638.99, 9650.42, 9645.44, 9654.46, 9651.76, 9662.95, 9661.7, 9711.42, 9707.27, 9724.31,9718.28, 9737.81,9738.85, 9750.49, 9749.87, 9762.04, 9761.84, 9771. 6, 9770.77, 9793.84, 9792.8, 9806.2, 9806.62, 9816.38, 9816.59, 9822,9823.03, 9858.44,9859.06, 9866.33, 9865.71, 9890.31, 9890.52, 9898.2, 9898.62, 9909.76, 9908.51, 9943.32, 9944.56, 9986.96, 9986.33, 10069.3, 10068.4, 10076.8, 10076.3, 10123.9, 10124.5, 10135.5, 10134.7, 10143.9, 10141.4, 10164.5, 10166.2, 10173.6,10173.8, 10207.1, 10205.2, 10293.2, 10292.2, 10313, 10313, 10331.9, 10330.9, 10369.9,10369.9, 10377.4, 10378, 10406.5, 10410, 10443,10442.4, 10462.8, 10460.7, 10465.5, 10463, EOZ END ! BASE CURVE: GRCH, OFFSET CURVE: GRAX e e DISPLACEMENT -0.208008 -0.832031 -0.623047 -1.03906 -0.208008 0.208008 -1.03906 -0.208008 -0.623047 -0.416016 -0.624023 -0.831055 -1.03906 -4.9873 -2.70215 -1.24707 -4.15625 -6.02637 1. 03906 -0.623047 -0.208008 -0.831055 -1.03906 0.416016 0.208008 1. 03906 0.623047 -0.623047 0,208008 0.416016 -1.24707 1.24707 -0.623047 -0.831055 -0.416016 0.623047 -0.831055 -2.49316 1. 66309 0.207031 -1.87012 -1.03906 o -1.03906 o 0.623047 3.5332 -0.623047 -2.07812 -2.49316 e e Tape Subfile: 1 115 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 L2-14B.xtf 150 BP Exploration (Alaska) Inc. L2-14B Prudhoe Bay Unit 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, 11-Jun-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAXO 1 ROPA01 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 (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 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 27 e e Tape File start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9506.000000 10598.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 36 records... Minimum record length: Maximum record length: 18 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska) L2-14B Prudhoe Bay Unit 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 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 Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 2 Curves: e e 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: 53 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9506.000000 10598.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 62 records... Minimum record length: Maximum record length: 18 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/02/28 696246 01 **** REEL TRAILER **** MWD 05/02/02 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes /I e e Tape Subfile 2 is type: LIS DEPTH GR ROP 9506.0000 -999.2500 -999.2500 9506.5000 38.1803 -999.2500 9600.0000 46.8830 21.2117 9700.0000 20.3114 47.7400 9800.0000 30.4250 21. 8691 9900.0000 43.2697 12.0309 10000.0000 25.6684 37.0490 10100.0000 36.7113 50.6677 10200.0000 45.9613 95.8390 10300.0000 37.3924 30.0850 10400.0000 22.7295 28.4590 10500.0000 46.5400 52.8100 10598.0000 -999.2500 -999.2500 Tape File Start Depth 9506.000000 Tape File End Depth 10598.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet · \ ,. e e Tape Sub file 3 is type: LIS DEPTH GRAX ROPS 9506.0000 -999.2500 -999.2500 9506.2500 37.9000 -999.2500 9600.0000 44.7400 20.4100 9700.0000 21.2100 50.1800 9800.0000 29.1900 21. 4500 9900.0000 41. 7650 11. 9300 10000.0000 24.9675 32.9200 10100.0000 36.7300 50,6400 10200.0000 46.5000 95.8200 10300.0000 37.2400 27.9800 10400.0000 24.3300 32.3000 10500.0000 49.5700 52.0200 10598.0000 -999.2500 31. 9400 Tape File Start Depth 9506.000000 Tape File End Depth 10598.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet
