Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-014
RECEIVED • STATE OF ALASKA OCT 3 0 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO - GGC la. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other ®Abandoned ❑Suspended 1b. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ ❑WAG ID WDSPL ❑Other No. of Completions , Zero • ® Development ❑Service 2. Operator Name: 15. Date Comp.,Susp.,Of Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 9/30/2014 • 200-014 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 3/20/2000 50-029-20803-01-00 ' 4a. Location of Well(Governmental Section): '7. Date T.D. Reached: 14. Well Name and Number Surface: 5/5/2000 PBU 18-07A 719' FNL, 282 FEL, Sec. 24, T11N, R14E, UM • 8. KB(ft above MSL): 46 15. Field/Pool(s) Top of Productive Horizon: 958' FNL, 2315' FEL, Sec. 23, T11N, R14E, UM GL(ft above MSL): 16.41' - Prudhoe Bay/Prudhoe Bay • Total Depth: 9. Plug Back Depth(MD+TVD) 689' FNL, 3091' FEL, Sec.23, T11N, R14E, UM 11930' - 8439' • 4b. Location of Well(State Base Plane Coordinates, NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 691473 • y- 5961142 - Zone- ASP4 13300' • 8834' • ADL 028307 • TPI: x- 684168 y- 5960721 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 683385 y- 5960971 Zone- ASP4 None 18. Directional Survey: ❑Yes 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): ® No N/A ft MSL 1900' (Approx.) (Submit electronic and printed information per 20 AAC 25.050) ( pp ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD& GR, Mem CNL/GR/CCL 12440' - 8780' • 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 31' 101' 31' 110' 30" 1900#Poleset 13-3/8" 72# L-80 30' 2497' 30' 2497' , 17-1/2" 1670 sx Fondu,400 sx Permafrost C 9-5/8" 47# L-80/S00-95 28' 11531' 28' 8190' 12-1/4" 500 sx Class'G', 300 sx Permafrost C _ 7" _ 29# L-80 11206' 12440' 7995' 8780 8-1/2" 400 sx Class'G' 2-3/8" 4.43# L-80 12065' 13152' 8525' 8846' 3" 12.5 Bbls Class'G' I 24. Open to production or injection? ❑Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom; Perforation Size and Number): 4-1/2", 12.6#x3-l/2",9.2#, L-80 12430' 11068'/7913'.11173'17975' iiiiiii4444;04 12403'/8754' 3..U�( 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. j V_ ([n' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No 4 - SGANNED FEB 2 0 2015 "`^`"` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached • 27. PRODUCTION TEST Date First Production Method of Operation(Flowing, Gas Lift,etc Not on Production 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(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No• Sidewall Core(s)Acquired? 0 Yes ® No If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 vTG Z/4,/j S CONTINUED ON REVERSES / Submit Original Only �49- • RBDIMAS>)�i JAN - 4 2015./ 29 GEOLOGIC MARKERS(List all formations ar rkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? ij Yes 0 No . Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 11541' 8197' None Shublik 11627' 8250' Sadlerochit 11756' 8330' Zone 1B 12450' 8787' Zone 1A 12730' 8810' Formation at Total Depth: 31 List of Attachment Summary of Pre Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: David.Johnston@@bp.com David Johnston,564-5985 Title: Drilling Technologist Printed Name: Joe Lastufka Signature. ,� Phone 564-4091 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 and Ground Level elevation 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 13: 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 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 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 Form 10-407 Revised 10/2012 Submit Original Only WELL NAME: 18-07A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 12390' Set CIBP 11465' - 11471' Tubing Punch 12310' - 12320' Tubing Punch 12200' Set CIBP 11495' Set CIBP (Milled) Squeeze 27.4 Bbls Class 'G' 12040' Fish: Milled CIBP (11495') 11930' Set Whipstock 18-07A, Well History (Pre-Rig Sidetrack) Date Summary 07/15/14 INITIAL T/I/O =2500/300/0. WAIT FOR SSV TO BE SERVICED. MIRU. PT. LRS LOAD AND KILL WELL. RIH WITH HEAD/ERS/2x1-11/16"WB/GR/CCL/FH/SETTING TOOL/BAKER CIBP. MAX OD = 1.76", FN = 1.375",TOTAL LENGTH =35'. CCL TO PLUG ME = 10.75', CCL STOP DEPTH = 12379.25' ELM, PLUG ME SET DEPTH = 12390' ELM. PLUG TOP TO ME= 1.5". POOH. 07/16/14 Assist E-Line. MIT TBG 2500 psi (CTD Prep) Pumped 57 bbls of 45*diesel down TBG to reach 2100 psi for MIT TBG ran out of fluid before reaching test psi Conclusion E-line bleed gas from TBG because of high starting TP Bleed TP till fluid to service (Energized fluid) Pumped 33 bbls of 45*diesel in attempt to MIT TBG Pumped 6 bbls @ .90 bbls @ 2525 psi to attempt to LLR but TP jumped up aprox.100 psi to 2625 shut down & monitor lost 617 psi in 3 min Pumped 5 bbls of diesel in attempt to MIT TBG monitor for 3 min& lost 532 psi in 3 min Pumped 5 bbls to reach 2500 psi and attempt LLR for 3 bbls © .50 bpm @ 2525 psi shut down and monitor for 3 min & lost 582 psi in 3 min. Pumped 42 bbs, 45*, diesel and 23 bbls, 60*, crude down TBG at 0.6 BPM while E-Line performed a LDL. Job postponed. FWHP's= 400/317/07, Valve positions = E-Line on well at LRS detarture, casing valves OTG's.Tag Hung. 07/16/14 RS MIT-T TO 2500 PSI. MIT NOT PASSING. BLEED DOWN GAS AND TRY TO MIT AGAIN. STILL NOT PASSING. DECISION MADE TO RUN LEAK DETECT TO DETERMINE WHERE THE FLUID IS GOING. OP CHECK LEAK DETECT TOOLSTRING. ISSUES WITH ERS. TORUBLESHOOT. REMOVE ERS FROM TOOLSTRING. RIH WITH LEAK DETECT TOOLSTRING. LOG STATIC AND DYNAMIC UP/DOWN PASSES AT 60 FPM. LEAK LOCATED— 11180'. POOH. RD. FINAL T/I/O =450/350/0 PSI. WELL SHUT IN UPON DEPARTURE. DSO NOTIFIED. 07/18/14 T/I/O = SSV/340/50, Temp:SI, PPPOT-T(PASS) Eval Comms TxIA. PPPOT-T: Opened SBS to verify 0 psi in test void, unable to bleed void to 0 psi. Torqued LDS to 500 ft/lbs. Bled void to 0 psi. Removed 1" pipe plug and installed 1"alemite fitting. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. Removed internal check and installed 1"alemite fitting. PT to 5,000, no leaks. 08/05/14 INITIAL T/I/O =600/400/0. ATTEMPT TO PUNCH TUBING FROM 11465'- 11471'WITH 2"4 SPF 0 DEG PHASED TUBING PUNCH GUN. WHEN LAYING GUN DOWN NOTICED THAT DECENTRILIZERS HAD BEEN PUT ON 180 DEG OUT OF PHASE WITH SHOTS. WILL NEED TO RE- PUNCH. 08/06/14 PUNCH TUBING FROM 11465'- 11471'WITH 2"4 SPF 0 DEG PHASED TUBING PUNCH GUN LEAK DETECT BASELINE TEMPERATURE PASS FROM 875'TO 12390'. TOOLS SHORTED OUT. POOH TO INVESTIGATE. 08/06/14 T/I/0=443/303/0 Temp= SI Assist E-line w/injectivity test. (CTD) Spear in to TBG w/5 bbls of 40*60/40 meth H2o followed by 40 bbls of 40"diesel to perform injectivity test resulting in 1.7 bpm @ approximately 3450 psi E-line on well on dep. Wing shut swa shut ssv shut master open casing valves open to gauges Final Whp"s=650/312/0. 08/06/14 T/I/0=316/296/01 Temp=SI Assist E-Line (CTD) Pumped 40 bbls of 40*diesel down TBG for injectivity test @ .60 bpm TP stabilized after 14 bbls @ approximately 2050 psi. Called to another job. Halliburton EL in control of well upon departure. IA OA=OTG. FWHPS=2000/295/1. 08/07/14 T/I/O 342/276/2 temp=SI Assist E-line (LDL) Pump 261 bbls diesel down tbg while E-line logs. Job continued on 8-8-14 WSR. Page 1 of 4 18-07A, Well History (Pre-Rig Sidetrack) Date Summary 08/07/14 PERFORM LEAK DETECTION LOG FROM 12390'TO 10000'. SPINNER WORKING ON AND OFF. DECISION MADE TO POOH AND CHANGE SPINNER. AT SURFACE STANDBY FOR HIGH WINDS 35- 49 MPH. 08/08/14 Pump 148 (409 total) bbls 40*f diesel down tubing while E-line logs. FWHP 266/243/40 HES on well at departure. 08/08/14 STANDBY FOR HIGH WINDS 35-49 MPH. UNSTAB FROM WELL AND CHANGE OUT TOOL STRING TO(7'x 1.69"WB/5'x 1.69"WB/1.69" PRODUCTION KJ/1.69" PRODUCTION KJ/2"CENT/1.69" XTU/ 1.69" PGR/1.69" PRESSURE TOOL/2.13" IN LINE SPINNER/2"CENT/ 1.69" CAPACITANCE AND TEMP/2.13" SPINNER. OVERALL LENGTH 27.7'. PRIMARY BARRIERS ARE LUBRICATOR AND GREASEHEAD. SECONDARY BARRIERS ARE SSV AND SWAB. TAG BTM @12076 ELMD. LRS PUMP FOR 30 MIN @ 1.5BBLS/MIN, 3500PSI WHP. UP LOG FROM 12070' ELMD TO 10200' ELMD, LRS PUMPING @ 1.5BBLS/MIN. DOWN LOG FROM 10200' ELMD TO 12070' ELMD, LRS PUMPING @ 1.5BBLS/MIN. LRS LOWER PUMP RATE TO 1.0BLLS/MIN. LOG 1ST STOP COUNT @ 11700' ELMD, BELOW TUBING PUNCH. LOG 2ND STOP COUNT @ 11300' ELMD,ABOVE TUBING PUNCH. LOG 3RD STOP COUNT @ 10948' ELMD, ABOVE LDL LEAK STANDBY FOR HIGH WINDS. 08/09/14 T/I/O =0/245/5 Temp=Sl MIT-IA to 3000 PSI **PASSED**, MIT-OA to 2000 PSI **PASSED**(CTD) Pumped 15.18 bbls crude for MIT-IA. 1st 15 min IAP lost 120&2nd 15 min IAP lost 36 for a total IAP loss of 156 in 30 min. Bled back—8 bbls. Pumped 2.28 bbls crude for MIT-OA. 1st 15 min OAP lost 109&2nd 15 min OAP lost 42 for a total OAP loss of 151 in 30 min. Bled back 2 bbls. FWHP's=0/698/39 Upon departure DSO notified of WV,SWV,SSV=S/I IAV,OAV=OTG Tags hung on casing VLV's&WV**Fluid packed watch for thermal expansion**. 08/25/14 INITIAL T/I/O = 150/725/100. LRS PERFORMED INJECTIVITY TEST, RIH WITH POWERJET 1606, HMX GUNS (10'). SHOT INTERVAL AT 12310'-12320'. POOH. RIH WITH 2-7/8" BAKER CIBP. SAT DOWN ON LINER TOP SY 12065'. MADE MULTIPLE ATTEMPTS AT 12,15,20 AND 25 FPM. NOT ABLE TO GET THROUGH. DECISION MADE TO POOH AND LOOK AT PLUG ON SURFACE. 08/26/14 EL couldn't get past LNR to set plug,job postponed. Pumped 83 bbls of 1% kcl down TBG to empty transport. Freeze protect TBG w/38 bbls of 50/50 meth/water. Hung FP tag on wing, SV WV SSV= closed. MV IA OA=open. DSO notified upon departure. FWHPS=0/800/100. 08/26/14 POOH. OTHER THAN SCRATCHES ON THE BULL NOSE, PLUG LOOKED GOOD. DECISION MADE TO RIG DOWN AND MAKE ANOTHER ATTEMPT AT A LATER DATE. RDMO. WELL SHUT IN AND HANDED OVER TO DSO ON DEPARTURE. FINIAL TWO =VAC/840/50. 08/29/14 INITIAL T/I/O = 100/700/0. RIH W/2 3/8" BAKER CIBP. WEIGHT=300 LBS; MAX OD = 1.75"; FN = 1.38"; LENGTH =34 FT. SET ME OF CIBP AT 12200'. TOP OF PLUG @ 12199.5'. FINAL T/I/O = 280/700/0. 08/30/14 T/I/0=338/693/0 Injection test Pumped 5 bbls neat meth followed by 62 bbls dsl down tbg at 2 bpm pumped for 29 min between 2800 and 3100 psi to get injection rate rig down (swab closed wing closed ssv open master open annulus valves open to gauges) FWHP=516/461/0. 09/03/14 CTU#6- 1.75" CT(CTV= 34 bbls)Job Objective: Set CBP, Cement squeeze, Mill CBP MIRU CTU. Make up 2-7/8"GR/CCI carrier with 3.70" CIBP drift and RIH. Tag LIP at 12073'ctm. Log 40 fpm up to 10900'. Flagged pipe at 11450'. Pooh. Receive good data. MU WFT CBP. Page 2 of 4 18-07A, Well History (Pre-Rig Sidetrack) Date Summary 09/04/14 CTU#6- 1.75" CT(CTV= 34 bbls)Job Objective: Set CBP/Cement Sqz/Mill CBP. Rih w/WFT 4-1/2" Composite Bridge Plug. Correct Depth at flag. Set plug middle element at 11,495'. Pooh. MU Cement bha. Rih w/2.44" BDJSN.Tag CBP at 11495'and pick up to 11485'. Circulate well to 1% KCI to remove gas and fluid pack though unable to maintain 1:1 returns. Pump 100 bbls diesel down backside to lighten column. Injectivity rate of 2bpm at—2500psi. Pump 27.4 bbls of 15.8 ppg unislurry laying above the CBP, however were unable to maintain 1:1 returns. Have 3.4 bbls of losses. After cement laid in, online with 1% KCL down backside at max rate to push a total of 23.0 bbls through the punched holes into the annulus. Shut down pump and—1700 psi of squeeze pressure remained. Wait 1 hour for cement to build gel strength and then drop ball and contaminate with Powervis. Chase ooh at 80%. FP Coil &Tbg to 500'. At surface, standby for cement to reach 500psi compressive strength before milling plug. 09/05/14 CTU#6- 1.75" CT(CTV= 34 bbls)Job Objective: Set CBP/Cement Sqz/Mill CBP. Wait for cement to reach 500psi compressive strength. Rih w/WFT 2-7/8" motor&3.795" mill. Mill small cement stringers and pump gel sweep. Begin milling CBP at 11501' CTMD. Push mill to Liner top at 12040' CTMD. Open Circ sub and pump final gel sweep to clear plug debris and chase OOH at 80%. FP well to 2500'with 50/50 meth. RDMO CTU. 09/07/14 RAN 3.70" DUMMY WHIP STOCK, S/D @ 11,975'SLM. RAN 4-1/2"X-LINE LOC X NIPPLE © 11,110' SLM, 11,102'MD, -8' CORRECTION. 09/09/14 T/I/O- 110/700/0 Temp. SI . MITT PASSED to 2500 psi. (on 1st attempt) Pumped 2.5 bbls of 60*F meth to reach test pressure. Tubing lost 60 psi. in the 1st 15 min. and 28 psi. in the 2nd 15 min. for a total loss of 88 psi. in a 30 min. test. Bled back—2.5 bbls to Final WHP- 115/700/0. Tags hung, SV,WV,SSV- closed MV,IA,OA-open. 09/09/14 INITIAL T/I/O = 150/700/0 PSI. RIH W/SCMT, LOGGED REPEAT PASS FROM 12065'TO 11760', LOGGED MAIN PASS FROM 12065'TO 11060' (CEMENT LOOKED QUESTIONABLE, INFORMED WSL- DECISION TO BLEED OFF AND DO ANOTHER PASS), LOGGED LOWER PRESSURE PASS FROM 12065'- 11310' (CEMENT IS QUESTIONABLE AT THE ZONE OF INTEREST), WILL SEND LOGS TO TOWN TO CONFIRM REQUIREMENTS PRIOR TO SETTING WHIPSTOCK, RD AND LEAVE EQUIPMENT ON LOCATION. 09/10/14 RIH W/ELINE TOOLSTRING W/BAKER 4-1/2" MONOBORE WHIPSTOCK. SET TOP OF WHIPSTOCK @ 11930'W/32 DEG ROHS ORIENTATION-- (PIP TAGS INSTALLED 8' BELOW TOP OF WHIPSTOCK- DEPTH FOR PIP TAGS = 11938). TIED INTO SLB MEMORY MCNL/GR/CCL DATED JULY 7, 2000. FINAL T/I/O=0/700/0 PSI. 09/23/14 T/I/O=0/700/0. Removed Tree cap and installed BOP test spool#2. Torqued and Pt'd. Set 4"CIW H- TWC#425. Torqued tree and Pt'd. (Pre- CTD).Pt'd both sides of SV. Pulled TWC. Final T/I/O=0 700/0. (See log). RDMO. 09/24/14 T/I/O= SSV/680Nac. Temp= SI. Bleed IAP to 0 psi (pre CTD). Wellhouse and flowline removed. IA FL near surface. Bled IAP to 30 psi in 3 hrs(gas/fluid 4 bbls). Rigged down end of shift. Job incomplete. FWHPs= SSV/30/0. SSV=C. MV= O. IA, OA=OTG. 17:00 hrs. 09/25/14 T/I/O = SSV/65/vac. Temp= SI. (pre CTD). No well house, Flow line. Rig scaffolding on well. IA increased 35 psi in 24 hrs. Bled IAP to bleed tank from 65 psi to 16 psi in 20 mins. During 1 hr monitor IAP increased 17 psi. Job complete. See log for details. Final WHPs SSV/33/vac. Page 3 of 4 18-07A, Well History (Pre-Rig Sidetrack) Date Summary 09/26/14 T/I/0 = SSV/40NAC. Temp= SI. WHP's (pre CTD). No well house, Flowline. IAP increases 7 psi overnight. SV, WV, SSV=C. MV= O. IA, OA = OTG. NOVP. 1645. 09/27/14 T/I/O = SSV/56NAC.Temp = SI. Bleed IAP to 0 psi (pre CTD). Wellhouse, flowline, tree scaffold railings removed. IA FL near surface. Bled IAP to 0+ psi in 30 min. Monitored for 10 min. IAP increased 8 psi. Final WHPs=SSV/8NAC. SSV= C. MV= O. IA, OA=OTG. 0500. Page 4 of 4 North America-ALASKA-BP Page t,sta- Operation Summary Report Common Well Name:18-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/27/2014 End Date:10/4/2014 X3-014PV-C:(3,898,838.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:9/13/1982 12:00:00AM Rig Release:10/5/2014 Rig Contractor:NORDIC CALISTA UWI:500292080300 Active datum:1 :01 6/8/1982 00:00 @46.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/27/2014 10:00 - 11:00 1.00 MOB P PRE MOVE RIG OFF Y PAD. 11:00 - 19:00 8.00 MOB P PRE MOVE RIG FROM Y PAD TO GC2 ENTRANCE ON SPINE.MOVE RIG MATS IN FRONT OF RIG AS NEEDED. 19:00 - 00:00 5.00 MOB P PRE MOVE RIG FROM GC2 SPINE ROAD ACCESS POINT TO OXBOW ROAD. -GREASE CHOKE&REEL VALVES. -SWAP INJECTOR BLOCKS FROM 2"TO 2-3/8". -SWAP GOOSENECK ROLLERS FROM 2"TO 2-3/8". -SWAP INJECTOR STUFFING BOX BRASS& PACKOFFS FROM 2"TO 2-3/8". -INSPECT PITS. -RIG IS NEXT TO PS 1 AT MIDNIGHT 9/28/2014 00:00 - 03:50 3.83 MOB P PRE ,CONTINUE TO MOVE RIG FROM NEXT TO PS 1TO DS 18. 03:50 - 06:00 2.17 MOB P PRE TURN OFF OF OXBOW&ONTO WEST DOCK ROAD. -RIG ON LOCATION 06:00 06:00 - 08:00 2.00 MOB P PRE SPOT RIG MATS AROUND WELL -CHECK IA/OA PRESSURE:0 PSI/0 PSI 08:00 - 08:30 0.50 MOB P PRE HELD PJSM FOR PULLING OVER WELL NOTIFIED PAD OPERATOR FOR PULLING OVER WELL PULL OVER WELL WITH WSL,NORDIC SUPERINTENDENT,RIG MANAGER -ACCEPT RIG @ 08:30 HRS 09/28/2014 08:30 - 14:00 5.50 MOB P PRE BEGIN RIG-UP OPERATIONS -SPOT ANCILLARY EQUIPMENT -CONFIRM 2 BARRIERS-ND TREE CAP -NIPPLE UP BOPE -SPOT CUTTINGS BOX,TRASH BINS,TIGER TANK -SPOT PARTS TRAILER,WELDING SHACK, SAT OFFICE 14:00 - 15:00 1.00 MOB P PRE HELD PJSM FOR PICKING UP REEL -SPOT TRUCK UNDER REEL HOUSE -PU REEL AND SECURE INSIDE REEL HOUSE 15:00 - 17.00 2.00 MOB P PRE SHELL TEST BOP -FILL STACK WITH WATER -SHELL TEST 250 PSI/3500 PSI 17:00 - 19:30 2.50 BOPSUR P PRE STATE GIVEN NOTIFICATION OF BOP TEST 09/27/2014 18:30 STATE INSPECTOR BOB NOBLE WAIVE WITNESS 09/27/2014 18:59 PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,SUNDRY#200-014,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER Printed 10/13/2014 1:12:11 PM North America-ALASKA-BP Page 249 Operation Summary Report Common Well Name:18-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/27/2014 End Date:10/4/2014 X3-014PV-C:(3,898,838.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:9/13/1982 12:00:00AM Rig Release:10/5/2014 Rig Contractor:NORDIC CALISTA UWI:500292080300 Active datum:1 :01 6/8/1982 00:00 @46.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 22:30 3.00 BOPSUR N HMAN -16.00 PRE ACCIDENTIALLY SHEAR 2-3/8"TEST JOINT. SEE TRACTION REPORT 2014-IR-4827003. PJSM FOR REMOVING TEST JOINT. LOTO ON KOOMEY UNIT. SUCK DOWN STACK. OPEN RAM DOORS ON BLIND SHEAR RAMS- INSPECT SAME-NO ISSUES. PULL JOINT FROM WELL. REPLACE BLIND RAM SEALS AS A PRECAUTION. INSTALL&BUTTON UP DOORS. REMOVE LOTO. FILL STACK. SHELL TEST,250PSI/3500PSI FOR 5 MIN- PASS. PRESSURE TEST BLIND RAMS, 250PSI/3500PSI FOR 5 MIN-PASS. 22:30 - 00:00 1.50 BOPSUR P PRE CONTINUE TO TEST BOPE. -LOWER 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -VBR TESTED WITH BOTH 2-3/8"AND 3-1/2" TEST JOINT -UPPPER 2-3/8"PIPE RAMS TESTED WITH •2-3/8"TEST JOINT -ANNULAR TESTED WITH BOTH 2-3/8"AND 3-1/2"TEST JOINT 9/29/2014 00:00 - 05:00 5.00 BOPSUR P PRE CONTINUE TO TEST BOPE. -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS -PERFORM DRAW DOWN TEST OF ACCUMULATOR -ALL TESTS WITNESSED BY TOOLPUSHER AND WSL -NO FAILURES 05:00 - 05:30 0.50 BOPSUR P PRE PERFORM RIG EVAC DRILL&CONDUCT AAR. 05:30 - 08:30 3.00 BOPSUR P PRE PU INJECTOR AND RE-ASSEMBLE FOR PRESSURE TEST. -PREPARE INJECTOR TO RECEIVE COIL. 08:30 - 10:30 2.00 BOPSUR P PRE PULL COIL ACROSS TO INJECTOR -HELD PJSM FOR PULLING COIL ACROSS -PULL COIL ACROSS TO INJECTOR CATTLE SHOOT -COIL OFF TRACK(STOP FOR CHANGE OF SCOPE PJSM) -RE-POSITION COIL ONTO CATTLE SHOOT -STABBED COIL INTO INJECTOR -HELD AAR FOR CHANGE OF SCOPE OPERATIONS 10:30 - 13:30 3.00 BOPSUR P PRE PREPARE COIL TO RECEIVE WATER -TEST E-LINE CONNECTIVITY(OHM TEST) -INSTALL BOOT ONTO END OF E-LINE -FILL REEL WITH 1%KCL -PUMP FORWARD 1 REEL VOLUME 13:30 - 14:00 0.50 BOPSUR P PRE PRESSURE TEST ALL REEL HOUSE IRON 250 PSI/3500 PSI Printed 10/13/2014 1:12:11PM North America-ALASKA-BP Page 3 cite- Operation Summary Report Common Well Name:18-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/27/2014 End Date:10/4/2014 X3-014PV-C:(3,898,838.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:9/13/1982 12:00:OOAM Rig Release:10/5/2014 Rig Contractor:NORDIC CALISTA UWI:500292080300 Active datum:1 :01 6/8/1982 00:00 @46.00usft(above Mean Sea Level) ._.. ._ _. .... Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 15:45 1.75 BOPSUR N SFAL -16.00 PRE PRESSURE TEST INNER REEL/PACK-OFF VALVES -SLOW BLEED OFF DURING LOW PRESSURE TEST(FAIL) -CHANGE OUT INNER REEL VALVE AND RE-TEST -PRESSURE TEST 250 PSI/3500 PSI (PASSED) 15:45 - 17:00 1.25 BOPSUR P PRE PERFORM SLACK MANAGEMENT -PUMP SLACK INTO REEL -CUT 50'OF COIL -CHANGE OUT SLB COMPUTER 17:00 - 17:30 0.50 BOPSUR P PRE PERFORMED RIG EVAC DRILL -CONDUCT AAR WITH CREW 17:30 - 22:30 5.00 BOPSUR P PRE PSJM WITH CREW REGARDING COIL 'MANAGEMENT CONTINUE SLACK MANAGEMENT -MU COIL CUTTER -CUT 265'OF COIL -RD COIL CUTTER -PUMP SLACK FORWARD -CUT 10'E-LINE -INSTALL SLB COIL CONNECTOR -PULL TEST TO 35K/PRESSURE TEST COIL CONNECTOR TO 250PSI/4000PSI FOR 5 MIN. -HEAD UP WITH BHI 22:30 - 23:00 0.50 BOPSUR P PRE STAB INJECTOR ONTO WELL WITH BLIND SUB ON BHI UQC. TEST LUBRICATOR CONNECTON ABOVE QTS, 25OPSI/3500PSI. 23:00 - 23:30 0.50 STMILL P WEXIT PJSM FOR HANDLING MILLING BHA. -OPEN WELL-OPSI WHP -FLOW CHECK WELL-NO FLOW. -POP OFF WELL. -PUMP 1 COIL VOLUME FORWARD WITH INJECTOR OVER BUNG HOLE. 23:30 - 00:00 0.50 STMILL P WEXIT -CHECK TREE BOLTS. -SIMULTANEOUSLY,MU MILLING BHA. 9/30/2014 00:00 - 01:00 1.00 STMILL P WEXIT CONTINUE TO MU MILLING BHA -PU INJECTOR -MU COIL TO BHA. -STAB ONTO WELL. -TEST QTS 250/PSI/3500PSI FOR 5 MIN 01:00 - 03:15 2.25 STMILL P WEXIT RIH WITH BHA#1 PUMPING 1%KCL THRU EDC(FOR SLACK MANAGEMENT). 1.75BPM IN/VARIOUS OUT 8.4PPG IN /VARIOUS OUT 79DEGF IN/70 DEGF OUT CTP=500PSI,IAP=51 PSI,OAP=OPSI. PVT=270BBLS -TAKE FREEZE PROTECT FLUID TO TIGER TANK -TAG FIRST GLM,PUH,WENT PAST SMOOTH Printed 10/13/2014 1:12:11 PM • ` ' Page 4efV North America-ALASKA-BP Operation Summary Report Common Well Name:18-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/27/2014 End Date:10/4/2014 X3-014PV-C:(3,898,838.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:9/13/1982 12:00:00AM Rig Release:10/5/2014 Rig Contractor:NORDIC CALISTA UWI:500292080300 Active datum:1 :01 6/8/1982 00:00©46.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:15 - 03:40 0.42 STMILL P WEXIT LOG TIE-IN FROM 11600' SWAP TO PUMPING USED 9.5PPG POWER PRO MUD WHILE LOGGING DOWN WITH FLUIDS FROM THE TRUCK 2.2BPM IN/2.2BPM OUT 9.4PPG IN /8.38PPG OUT 76DEGF IN/72 DEGF OUT CTP=872PSI,IAP=70PSI,OAP=4PSI. MINUS 4'CORRECTION. 03:40 - 03:45 0.08 STMILL P WEXIT CONTINUE TO RIH WITH MILLING BHA. PUMPING 9.4PPG USED POWER PRO MUD AT 2.2BPM THRU OPEN EDC. CTP=956PSI,IAP=72PSI,OAP=6PSI. 03:45 - 04:30 0.75 STMILL P WEXIT SWAP WELL TO 9.4PPG USED MUD PUMP 3.4BPM IN/OUT THRU THE EDC. -FILL PITS WITH MUD. 04:30 - 04:45 0.25 STMILL P WEXIT -CLOSE EDC. -GET SPR'S PUMP 1 0.5BPM=967PSI 1 BPM=1156PSI 1.5BPM=1443PSI -GET SPR'S PUMP 2 0.5BPM=945PSI 1 BPM=1159PSI 1.5BPM=1417PSI RIH&DRY TAG PINCH POINT AT 11931'. 04:45 - 06:25 1.67 STMILL P WEXIT MILL WINDOW FROM 11931' ✓ 56v14-L PUW=46K,SOW=19K PUMPING 9.5PPG USED POWER PRO THRU I -01- 13 THE MILL. 2.72BPM IN/2.72BPM OUT 9.5PPG IN /9.43PPG OUT 77DEGF IN/71 DEGF OUT CTP=2534PSI,IAP=117PSI,OAP=21PSI. EDC=10.67PPG WOB=0.64K PVT=23BBLS(FILLING PITS) 06:25 - 07:30 1.08 STMILL P WEXIT WOB SUB FAILED. CONTINUE TO MILL AHEAD. MILL WINDOW FROM 11931.9' PUMPING 9.5PPG USED POWER PRO THRU THE MILL. 2.72BPM IN/2.72BPM OUT 9.4PPG IN /9.4PPG OUT 81 DEGF IN/79 DEGF OUT CTP=2534PSI(200-300PSI MVV),IAP=166PSI, OAP=87PSI. EDC=10.58PPG PVT=71BBLS 07:30 - 18:00 10.50 STMILL P WEXIT MILL 3.80"WINDOW F/11,931.9'-11,939.5'MD. -BPM IN/OUT:2.72/2.71 -CIRC PSI:2560 -ECD:10.57 -MW IN/OUT:9.51 PPG/9.42 PPG -IA/OA/PVT:290 PSI/701 PSI/317 BBLS -WOB:1.61 K#(WOB SUB NOW WORKING) -NO STALLS,NO PICK UPS Printed 10/13/2014 1:12:11 PM North America-ALASKA-BP Page 549' Operation Summary Report Common Well Name:18-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/27/2014 End Date:10/4/2014 X3-014PV-C:(3,898,838.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:9/13/1982 12:00:00AM Rig Release 10/5/2014 Rig Contractor:NORDIC CALISTA UWI:500292080300 Active datum:1:01 6/8/1982 00:00©46.00usft(above Mean Sea Level) Date From-To Hrs ! Task Code NPT NPT Depth Phase Description of Operations (hr) j (usft) 18:00 - 00:00 6.00 STMILL P WEXIT I MILL 3.80"WINDOW F/11,939.5'-11,941.1'MD. -BPM IN/OUT:2.71/2.70 -CIRC PSI:2610 -ECD:10.59 -MW IN/OUT:9.45 PPG/9.42 PPG -IA/OA/PVT:295 PSI/134 PSI/317 BBLS -WOB:3.25K# NO STALLS,NO PICK UPS 10/1/2014 00:00 - 06:00 6.00 STMILL P WEXIT MILL 3.80"WINDOW F/11,941.1'-11,942.2'MD. BPM IN/OUT:2.71/2.70 -CIRC PSI:2600 -ECD:10.58 PPG -MW IN/OUT:9.45 PPG/9.42 PPG -IA/OA/PVT:315 PSI/200 PSI/317 BBLS -WOB:4.25K# NO STALLS,NO PICK UPS 1-SEE TRACE AMOUNT OF SAND IN SAMPLES 06:00 - 09:00 3.00 STMILL P WEXIT POOH TO INSPECT MILLING ASSEMBLY 09:00 - 10:00 1.00 STMILL P WEXIT HELD PJSM FOR LD MILLING BHA -FLOW CHECK(NO FLOW) -STAND INJECTOR BACK LD MILLING BHA GAUGE MILL 3.80 GO 3.79 NOGO -GAUGE STRING MILL 3.79 GO 3.78 NOGG 10:00 - 11:00 1.00 STMILL P WEXIT HELD PJSM FOR PU MILLING BHA MU NEW MILL 3.81 GO 3.80 NOGO -NEW STRING MILL 3.80 GO 3.79 NOGO -PU NEW STRAIGHT MOTOR AND BHA -GET ONTO WELL WITH INJECTOR 11:00 - 11:30 0.50 STMILL P WEXIT PRESSURE TEST QTS -250 PSI/3500 PSI(PASSED) -_ 11:30 - 15:30 4.00 STMILL P WEXIT RIH WITH MILLING BHA#2 -BPM IN/OUT:0.35/0.87 MW IN/OUT:9.36 PPG/9.42 PPG -LOG TIE-IN WITH(-6.5')DEPTH CORRECTION -RIH DRY TAG BOTTOM @ 11,942.2'MD 15:30 - 19:00 3.50 STMILL P WEXIT !MILL 3.80"WINDOW F/11,941.2'-11,944.0'MD. -BPM IN/OUT:2.75/2.74 -CIRC PSI:2585 -ECD:10.56 PPG !-MW IN/OUT:9.45 PPG/9.42 PPG '-1A/0A/PVT:295 PSI/167 PSI/321 BBLS WOB:2.25-3.50K# -NO STALLS,NO PICK UPS 19 00 - 00:00 5.00 STMILL P WEXIT MILL RATHOLE F/11,944'-11,953'MD. -BPM IN/OUT:2.74/2.73 -CIRC PSI:2728 -ECD:10.55 PPG I -MW IN/OUT:9.44 PPG/9.41 PPG !-IA/0A/PVT:322 PSI/247 PSI/321 BBLS WOB:3.00-3.75K# 10/2/2014 00:00 - 00:30 0.50 STMILL P WEXIT MILL RATHOLE F/11,953'-11,954'MD. -BPM IN/OUT:2.75/2.74 -CIRC PSI:2677 -ECD:10.55 PPG -MW IN/OUT:9.45 PPG/9.42 PPG -IA/OA/PVT:338 PSI/284 PSI/350 BBLS -WOB:2.25-3.50K# PUMP 10 BBL LO-VIS,20 BBL HI-VIS SWEEP 00 30 - 02:30 2.00 STMILL P WEXIT DRESS WINDOW -REAM UP AND DOWN 3X AT 1'/MIN -DRY DRIFT WINDOW,WINDOW SMOOTH Printed 10/13/2014 1:12 11 PM TREE= CNV 18-07A WELLHEAD=__ McEVOY Si NOTES: WELL ANGLE>70°@ 12472'*** ACTUATOR= BAKER C 2-310 CT LNR IS—133'SHALLOWER THAN Isif AL KB.ELEl/ 67 I 1 1 DEPTHS ON TALLY(05/06/00)*** BF.REV= NA KOP= 2950 Max Angle= 97°@ 13261' / L 2249' –i4-1/2"GAS CA MCOLFT BAL-OMANDRELS SV LN 13=3.812" Datum AD= 13050' �•J Datum TVD= 8800'SS 20"CONDUCTOR,91.5#,11-40,D=19.124" –I –80' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3608 3561 32 KBG-2 DMY BK 0 06/24/13 13-3/8"CSG,72#,L-80,D=12.347" H 2497' n 2 8768 6565 56 KBG-2 DMY BK 0 06/24/13 9-5/8"CSG,47#,L-80 BTC,13=8.681" H 10633' 1— m X 3 11000 7866 54 KBG-2 DMY BK 0 10/25/06 " Minimum ID = 1.83" @ 12065' 11068' –I9-5/8"X4-1/2"BKR S-3PKR,ID=3.875" 45 KB LINER TOP PACKER I I 11102' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,13=3.958" –I 11129' {----- l 11136' 9-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TUBING STUB(11133'ELMO) –I 11133' TBG LEAK(LDL 07/16/14) – 11180' 5Z 11173' –J9 5/8"X 4-1/2"BKR F-1 PROD PKR,D-? 011206' H9-5/8"X 7"BKR LTP&HGR D=? TOP OF 7"LNR –I 11206' 11465'-12320' H CEMENT N ANNULUS(09/05/14) r _11465'-11471' –I TUBING PUNCH(08/06/14) 9-5/8"CSG,47#,SO0 BTC,D=8.681" –I 11531' I ...4I. 4-1/2"BKR MONOBORE WHIPSTOCK(09/10/14) –1 11930' \ 12065' H45 BKR KB LTP,D=1.83"(07/11/13) FISH-MLLED 4-1/2"WFT CBP(09//05/14) H 12040'CTMD 12076' 3.71"BKR DEPLOY SLV w/2.25"SEAL BORE, TOP OF 2-3/8"LNR –I 12076' -- -- 13=1.969"(TAGGED HIGH ON 05/30/00) C; 2-3/8"BKR CBP(08/29/14) –I 12200' 12215' –i4-1/2"X 3-1/2"XO,D=2.992" BEHIND ? GAS LFT MANDRELS CT LNR 4-1/2"TBG-PC,12.6#,L-80,_0152 bpf,D=3.958" –I 12214' --- *. ST M3 TVD DEV TYPE VLV LATCH PORT DATE TBG PUNCH(08/25/14) H 12310'-12320' gi 1 1 12280 8610 47 *KBUG DMY BK 0 11/30/99 2 12318 8637 46 `KBUG DM' BKP 0 08/31/93 GLMS FROM INITIAL COMPLETION 09/1982(CM T'D 09/04/14) 3-1/2"TBG,9.2#,L-80,.0087 bpf,D=2.992" – 12429' I I ' 12366'-12398' --I4-1/2"BLASTJONTS 7"LNR,29#,L-80 BTC,_0371 bpf,D=6.184" –I -"12440' 12390' H2-3/8"BKR CEP(07!15/14) BEHIND PERFORATION SLAW RY 12403" H "X 3-1/2"BKR F1 PKR 12418' –3-112"CA MCO D NP,D=2.80" CT LNR RIEF LOG: SWS MCMJGR/CCL ON 07/07/00 / 11 ANGLE AT TOP PUT:46°@ 12310' 12430' H3-1/2'WLEG,D=2.992" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 7"MILLOUT WINDOW(18-07A)12440'-12444' 4" 4 12370-12390 S 10/04/82 02/24/00 1.56" 6 12465-12515 C 06/17/04 1.56" 6 12525-12770 C 08/10/08 1.9/16" 4 12569-12600 C 07/07/00 1.9/16" 4 12689-12740 C 07/07/00 1.56" 6 12875- 12925 C 08/10/08 OA 12977' HFISH-3-1/2"CBP(1/30106) PBTD(O-RING SUB,D=1.00") H 13115' TD H 13300' 2-3/8"LNR,4.43#,L-80 FL4S,.0039 bpf,0=1.941" -II 13152' DATE REV BY CONVENTS ' DATE REV BY COMAENTS PRUDHOE BAY UNIT 09/12/82 PKR 176 INITIAL COMPLETION 09/05/14 JCF/PJC TBG LEAK(LDL 07/16/14) WELL: 18-07A 03/11/00 N3ES RWO 09/05/14 JCF/PJC MLUFUSH CBP/CMT N ANNULUS F 9 MTT No:'2000140 05/07/00 N3E5 CTD SIDETRACK(18-07A) 09/10/14 GTW/PJC SET%M-IIPSTOCK AR No: 50-029-20803-01 08/29/14 AOG/JIVE SET CIBP 09/11/14 PJC PURF SQZ CORRECTION(09/04/14) SEC 24,T11 N,R14E,719'FNL&282'FEL 09/03/14 PJC PERF CORRECTION(8/25/14) 10/23/14 JNJJMI)CORRECTED PERF TO F1JNCH 09/04/14 JMD PUT CORRECTION(02/24/00) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~- ~/_¢ Well History File Identifier RESC~,/ m/Color items: I~ Grayscale items: Poor Quality Originals: o Other: DIGITAL DATA OVERSIZED (Scannable) Diskettes, No. [] Maps: Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ;~ NOTES: ORGANIZED BY: BEVERLY BRE~ERYL MARia LOWELL Project Proofing PROOFED BY: BEVERLY BR~HERYL MARIA LOWELL [] Other DATE¢~.,~ ID Staff Proof By: Date: Scanned (done) PAGES: (at the time of scanning) SCANNED BY'. BEVERLY BREN VINCENT ,~ARIA LOWELL DATE Is/ RESCANNEDBY; BEVERLY BREN ~'I~RYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done} e;cv I%j%4a, 1 HE STATE 1,_.(,,,-,, (-,. �i �;_� 4 ___, - i i {I / , E„- ,__,..1-2'./: L ,.,' J\.moi' ._ - } , y 4 333 West Seventh Avenue """%' 1 GOVERNOR SEAN P3 RNE3_I. Anchorage, Alaska 99501 3572 017. �� l'Og,n 9n7 279 1432 kW v�A. tviY 201 y^ SC.�►NNE© 4. John McMullen Engineering Team Leader / BP Exploration(Alaska), Inc. C)________------- j Li- P.O. Box 196612 Anchorage, AK 99519-6612 63:,--- Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-07A Sundry Number: 314-053 Dear Mr. McMullen: 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, _v_64. P ,„,y,__, Cathy . Foerster Chair DATED this 7 day of February, 2014. Encl. • STATE OF ALASKA t ALASIw OIL AND GAS CONSERVATION COMMISSION REC ENED APPLICATION FOR SUNDRY APPROVAL JAN 2 2 2014 20 AAC 25.280 1. Type of Request: O OGCC ❑Abandon ®Plug for Redrill . 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ❑Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well 0 Stimulate 0 Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑Exploratory 0 Stratigraphic 200-014 • 3. Address: 6. API Number: 0 Development 0 Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20803-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 18-07A Will planned perforations require a Spacing Exception? ❑Yes ® No • 9. Property Designatior 10.Field/Pool(s): ADL 028307 • Prudhoe Bay/Prudhoe Bay ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13300' • 8829' • 13115' 8843' None 12977' Casing Length _ Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2497' 13-3/8" .. 2497' 2497' 4930 2670 Intermediate 11531' 9-5/8" _ 11531' 8184' 6870/8150 4760/5080 Production Liner 1234' 7" 11206'- 12440' 7988'-8775' 8160 7020 Liner 1087' 2-3/8" 12065'- 13152' 8519'-8841' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12465'- 12925' 8790'-8826' 4-1/2", 12.6#x 3-1/2",9.2# L-80 12430' Packers and SSSV Type: 9-5/8"x 4-1/2" Baker S-3 Packer; Packers and SSSV 11068'/7906'; 9-5/8"x 4-1/2"Baker F-1 Production Packer; MD(ft)and ND(ft): 11173'/7968'; 7"x 3-1/2" Baker F-1 Packer 12403'/8749' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program ElExploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation' March 1,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended • 17. I hereby certify that the for-going is true and correct to the best of my knowledge. Contact: David Johnston,564-5985 Printed Name: Johrfa�t Title: Engineering Team Leader mail: avid.Johnston2@bp.com Signatur= / v Phone: 564-4711 Date: /7222 Commission Use Only Conditi. s of approval: Notify Commission so that a representative may witness _ 0 Sundry Number: ❑Plug Integrity BOP Test El Mechanical Integrity Test 0 Location Clearance Other: •-h--5 f --t-t, 35-0 5 , RBDM�MAY 0 9 2014 ,%/ tern a IC p/Uy %ol aecvv-,-er-,1- approVcd per 2e4 25-. /12-(L Spacing Exception Required? 0 Yes [.1 No Subsequent Form Required: /0 _ 46.? APPROVED BY Approved By:(--1 p4THE L- COMMISSION Date: P-7 �Form 10 403 Revised 10 012Appro a RiatieniNdi10...MMISSIONER 2 months from the date of approval Submit In Duplicate it VLF 4- ��`` ��J —.5�� iIA5 u 1 '� ti • To: Alaska Oil & Gas Conservation Commission b From: David Johnston p CTD Engineer Date: January 14, 2014 Re: 1 8-07A Sundry Approval Sundry approval is requested to plug the 18-07A perforations as part of the drilling and completion of proposed 18-07B coiled tubing sidetrack. - History and current status: 18-07 was originally completed in 1982. In 2000 the tubing was replaced by RWO. A CTD sidetrack to 18-07A was completed. The well reached MGOR and while it showed some • recharge, the last cycle lasted only 4 days before testing at MGOR. In July 2013, the liner top packer was re-set in an attempt to reduce gas production. The liner top packer re-set was unsuccessful in changing the production trend. The lack of recharge and high GOR leave 18- . 07A with no significant remaining value. Proposed plan: Sidetrack 18-07A to the 18-07B location using Nordic 1 Coiled Tubing Drilling rig on or around July 1, 2014. The 18-07B sidetrack will be a dual string exit through the existing 4-1/2" and 7" liner and kick off in the Ivishak Zone 4, to target a Zone 1 lateral. The proposed sidetrack is a -2,783' horizontal Ivishak Zone 1 producer, which will access a -35 acre reserves target in southwestern Drill Site 18. The lateral will be completed with a 3- 1/2" X 3-1/4" X 2-7/8" L-80 liner which will be cemented to -12,300ft (cement outside window). A liner top packer will be set post rig with Slickline. This Sundry covers plugging the existing 18-07A perforations via the liner top packer set post rig with slick line. (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. 1- CO/'cv�. l 4. t,,.P I, PocAC f 'r 030 1- f% God Q000 5 404,4 /,•rile ;F G 7 c 4 e "4" Cle°/‘ 4.1 10 /If loll #%.04/.-o►cKeo/ 401141 0 ye/ /e cog,er ArjoiL Thu t i`on 0,- Toe foo 1. ,o i� f Pre-Rig Work (scheduled to begin March 1st, 2014) 1. E Set a 4-1/2" CIBP at 12,072' ELMD and MIT 2. E Punch tubing at 12,064' -12070 ' and MIT 3. E Punch tubing at 11,300'-11,306' and MIT 4. E Set Cement retainer at 12,060' 5. C Cement squeeze cement into IA for dual string exit TOC 11,300' MD 6. E MIT-T to 2,500 psi 7. E Set 4-1/2" Monobore Whipstock at 11,930' ELMD and HSTF 8. V PT MV, SV, WV. 9. 0 Remove wellhouse and level pad. Rig Work (scheduled to begin July 1st, 2014) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,460 psi) A 5 vv, d f-'-1 2. Mill 3.80" dual string window and 10' of rathole. J 3. Drill build: 4.25" OH, 727' (20 deg DLS planned). 4. Drill lateral: 4.25" OH, 2,011' (12 deg DLS planned). prP 5. Run 3-1/2" X 3-1/4" X 2-7/8" L-80 liner leaving TOL at 11,120". 6. Pump primary cement job: 24 bbls, 15.8 ppg, TOC at -12,300'MD. 7. Perform liner cleanout and MCNL/GR/CCL log. 8. Perform liner lap Injectivity test 9. Perforate liner based on log interpretation (-200'). 10. Freeze protect well to 2,500' MD. 11. Set TWC, RDMO. Post-Rig Work 1. 0 Re-install Wellhouse, and flow line 2. V Pull TWC 2. S Set Liner Top packer and MIT to 2,500 Psi * 3. S Set Generic GLV's *Approved alternate plug placement per 20 AAC 25.112(i) David E. Johnston CTD Engineer 564-5985 CC: Well File Joe Lastufka TREE= 4-1/16"CNV VyELLHEAD= McEVOY 1 8-07A S F CNOTES: WELL SANGLE >70°@12472'*** ACTUATOR= BAKER C IVTIAL KB.ELEv 62' ( 1 I DEPTHS ON TALLY(05/06/00)*** BF.E LEV=-- NA KOP_____ X50; Max Angle=—.---97°@ 13261' 2249' —14-1/2"CAMCO BAL-O SVLN,D=3.812" / _Datum M)= - 13050' I v Datum ND= 8800'SS GAS LIFT MANDRELS 20"CONDUCTOR,91.5#,H-40,13=19.124" H —80• ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3608 3561 32 KBG-2 DMY BK 0 06/24/13 13-3/8"CSG,72#,L-80,13=12.347" H 2497' L' I 2 8768 6565 56 KBG-2 DMY BK 0 06/24/13 9-5/8"CSG,47#,L-80 BTC,D=8.681" H 10633' 1-->c x 3 11000 7866 54 KBG-2 DMY BK 0 10/25/06 Minimum ID = 1.83" @ 12065' g 'X I 11068' —I9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 45 KB LINER TOP PACKER 11102' H 4-1/2"HES X NIP,D=3-813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 11129' 11136' H9-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TUBING STUB(11133'ELM)) —I 11133' -� x 11173' 9-518"X 4-112"BKR F-1 PROD PKR D-? TOP OF 7"LNR — 11206' Y 11206' H 9-5/8"X 7"BKR LW&HGR D=? 9-5/8"CSG,47#,S00 BTC,D=8.681" --I 11531' I lk 12065' —145 BKR KB LIP,D=1.83"(07/11/13) 12076' 3.71"BKR DEPLOY SLV w/225"SEAL BORE, TOP OF 2-3/8"LNR I-1 12076' D=1.969"(TAGGED HIGH ON 05/30100) 12215' --I4-112"X 3-1/2"XO,ID=2.992" BEHIND CT LNR GAS LFT MANDRILS 4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,D=3-958" —I 12214' I---• i ST MD ND DEV TYPE VLV LATCH PORT DATE 1 12280 8610 47 *KBUG DMY BK 0 11/30/99 2 12318 8637 46 *KBUG DMY BKP 0 08/31/93 GLMS FROM INITIAL COMPLETION 09/1982 II—r--I 12356'-12398' H4-1/2"BLAST Jouvrs cg--- 12403' —17"x 3-1/2"BKR F1 PKR BEHIND 3-1/2"TBG,9.2#,L-80,.0087 bpf,D=2.992" —I 12429' 1 I 12418' —3-1/2"CA MCO D Nom,D=2.80" CT LNR 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" H ^-12440' / , 12430' —I3-1/2'WLEG,D=2.992" PERFORATION SUMMARY REF LOG: SWS MCNUGR/CCL ON 07/07/00 7"ML LOUT WINDOW(18-07A)12440'-12444' ANGLE AT TOP PERF:45°@ 12370' ' Note:Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1 4" 4 12370-12390 S 10!04/82 02/24/00 ' 1.56" 6 12465-12515 0 06/17/04 1.56" 6 12525- 12770 0 08/10/08 1.9/16" 4 12569-12600 0 07/07/00 ' 1.9/16" 4 12689-12740 0 07/07/00 1.56" 6 12875- 12925 0 08/10/08 ,l 12977' H FISH-3-1/2"CIBP(1/30/06) PBTD(O-RI'JG SUB,D=1.00") H 13115' TO —1 13300' IA 2-3/8"LNR,4.43#,L-80 FL4S,.0039 bpf,ID=1.941" —I 13152' ISO ogI DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/12/82 PKR 176 IMTIAL COMPLETION 07/14/13 PJC REFORMAT WBS WELL: 18-07A 03/11/00 N3ES RWO 08/29/13 SG/PJC ADD PKR @ 11173' PERMIT No:2000140 05/07/00 N3ES CTD SIDETRACK(18-07A) API No: 50-029-20803-01 12/20/12 JF/JMD REPERFS(08/10/08) SEC 24,T11 N,R14E,719'FNL 8 282'FEL 07/13/13 CJW PJC GLV CJO(06/24/13_ 07/13/13 ALMc/PJC 45 KB LIP SET(7/11/13) BP Exploration(Alaska) f IKE= McEVOY 4-1/16"CNV a'J�LI- 18-07B 8_07B SAFETY NOTES: WELL ANGLE>70°@ 12472'*** ACTUATOR= BAKER C proposed CTD sidetrack 2-3/8"CT LNR IS--133'SHALLOWER THAN NJITIAL KB.ELEV 62' I 1 I DEPTHS ON TALLY(05/06/00)*** BF.ELEV= NA KOP= 2950' Max Angle= 97°@ 13261' ( 0 2249' -14-1/2"CA MCO BAL-O SVLN,ID=3.812" / Datum MD= 13050' Datum ND= 8800'SS GAS LFT MANDRELS 20"CONDUCTOR,91.5#,1-40,D=19.124" H -Mr N ST MD D DEV TYPE V LV LATCH PORT DATE L I 1 3608 3561 32 KBG-2 DMY BK 0 06/24/13 13-3/8"CSG,72#,L-80,D=12.347" H 2497' 2 8768 6565 56 KBG-2 DMY BK 0 06/24/13 9-518"CSG,47#,L-80 BTC,D=8.681" -1 10633' (—x x 3 11000 7866 54 KBG-2 DMY BK 0 10/25/06 Minimum ID = 1.83" @ 12065' 7 ' >< 11068' HI9-5/8"X 4-112"BKR S-3 PKR,ID=3.875" 45 KB LINER TOP PACKER ' • 11102' 4-112"HES X NP,D=3.813" c .=, 1 3-1/2"x 2-7/8"TOL Liner-11 120' MD/LTP 11.010'MD 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 11129' I 11136' -19-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TUBING STUB(11133'ELMD) -1 11133' 261 ►=, 11173' H 9-5/8"X 4-1/2"BKR F-1 PROD PKR D-? TOP OF 7"LNR -I 11206' 11206' -19-5/8"X 7"BKR LTP&HGR,D=? 'ubing Punch 11,300' • TOO Packer 11,300 MD 9-5/8"CSG,47#,SOO BTC,D=8.681" H 11531' A TSAD 11,543' MD 4 itc iI 1 4-112"TBG-PC,12.6#,L-80,.0152 bpf,D=3.958" H 12214' I 53°Inc / TOWS 4-1/2" Monobore @–11,930' MD • TOC —12,300' MD 2-7/8"13-114" x3-112" L-80 x liner' \ Cement Retainer Tubing Punch —C/BP 1lzoss — .4zi 1I `-i 12430' H 3-1/2'WLEG,ID=2.992" 4-1/4" Open Hole TD —14,713' • a 12215' -14-1/2"X 3-1/2"XO,D=2.992" TOP OF 2-3/8"LNR H 12076' 12076' -3.71"BKR DEPLOY SLV W I 225"SEAL BORE, 12418 -3-1/2"CA MCO D NP,D=2.60" D=1.969"(TAGGED HIGH ON 05130/00) I - 12356'-12398' -4-1/2"BLAST JOINTS 12403' -17"X 3-1/2"BKR F1 PKR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE I 1 12280 8610 47 *KBUG DMY BK 0 11/30/99 2 12318 8637 46 *KBUG DMY BKP 0 08/31/93 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" -1 --12444 ' GLMS FROM INTIAL COMPLETION 09/1982 H 7"MLLOUT WIDOW(18-07A)12440'-12444' 3-1/2"TBG,9.2#,L-80,.0087 bpf,D=2.992" 12429' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY LINT 09/12/82 PKR 176 IMTIAL COMPLETION 07/14/13 PJC REFORMAT WBS WELL: 18-07A 03/11/00 N3ES RWO 08/29/13 SG/PJC ADD PKR @ 11173' PERMT No:"2000140 05/07/00 N3ES CTD SIDETRACK(18-07A) API No: 50-029-20803-01 12/20/12 JF/JM) REPERFS(08/10/08) SEC 24,T11N,R14E,719'FN_&282'FEL 07/13/13 CJNI PJC GLV CIO(06/24/13_ 07/13/13 ALM./PJC 45 KB LW SET(7/11/13) BP Exploration(Alaska) : 01 ";— 8 a i—I a 11 6 E m LL LL~ s a 2 i 0 1 a f Y� T t:I'.!1 I 1212 I u f u m g 10233 n a .� . _ 2 = f m V M l • a I� II 11:04:2 _NM 1 1 1- kin Eli� r�1I�� Im wool) Vg s ngd 2m09 O 2 g m 11; cc a. t9 Q m m I Q cm; , g 1 0 .. c li $ I ui Ci -III S i II C 1=--1 I C Ii . O 0/1 ,7.. I 1111 III u- iii 8 1 0 — o Z 11 _ 11 . C [II2 ' i 1 3 -i 1- .... (II a 111 a Z I I ill I�I i > NI% ' I 111 I11 J 0 e 10 111 Mk '"'EL vl ..1 —SW ILII' . : „ Ia! I ! • Ice ii g ..- ig ..._ HIll U 1 ViI Q I & m I m O El I ' o al MI Z 1 S — ) c 1 I N b I.1 a 1 rc mw I ] I 0 ri1 Imo. I'1II=1®I i I��II 1 — O STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMOON AUG 0 2 20 1', REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LJ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.ShutdownD Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Ell Exploratory ❑ 200-014-0 w 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20803-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028307 PBU 18-07A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: • Total Depth measured 13300 feet Plugs measured None feet true vertical 8829.48 feet Junk measured 12977 feet Effective Depth measured 13115 feet Packer measured See Attachment feet true vertical 8843.28 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2469 13-3/8"72#L-80 28-2497 28-2496.96 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12370-12390 feet_12465-12515 feet 12525-12545 feet 12545-12569 feet 12569-12600 feet 12600-12689 feet 12689-12740 feet 12740-12770 feet 12875-12925 feet True Vertical depth 8725.91-8739.97 feet 8789.78-8800.48 feet 8801.67-8803.84 feet 8803.84-8805.75 feet 8805.75-8806.92 feet 8806.92-8805.31 feet 8805.31-8806.3 feet 8806.3-8809.43 feet 8821.12-8825.6 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NOV a iF 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 493 39149 18 0 982 Subsequent to operation: 757 37191 17 0 1024 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U• Gas U WDSPL[J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(ilBP.com Printed Name Nita Summerh- s Title Petrotechnical Data Technician signature ,12 Phone 564 4035 Date 8/2/2013 * 1 -------,,,,,,,. ' -Z RBDMS AUG - 8 2u,o`--/ Form 10-404 Revised 10/2012 (5%j Submit Original Only • • Daily Report of Well Operations ADL0028307 ACTIVITYDATE ( SUMMARY se finer op pac er. •umpe• bbls 60/40 Methanol followed by 240 bbls Dead Crude down TBG as directed by 7/10/2013 SSL. ***WSR continued to 7-11-13*** VT • ' .A pole-mo• RAN 10' 3.70" DMY WHIPSTOCK, 3.50" LIB, TAG 3.71" BKR DEPLOYMENT SLV @ 12,073' SLM ( 12,076' MD). RAN 10' 3.70" DMY WHIPSTOCK, 2.25" DMY STINGER INTO DEPLOY SLV @ 12,073' SLM (see wsr). LRS LOADS TBG W/220 BBL OF CRUDE. BRUSH DEPLOY SLV W/ LOOSE 2-7/8" BRUSH WHILE LRS PUMPS 20 BBLS OF CRUDE. RAN 10' 3.70" DMY WHIPSTOCK, 2.25" DMY STINGER INTO DEPLOY SLV @ 12,073' SLM (see wsr). 7/10/2013 ***CONT ON 7/11/13 WSR*** •1 -• , I proie-mo• SET BAKER 45 KB PKR W/2.25" STINGER (oal 11.55') @ 12,076 MD. LOG FROM 12,300' SLM TO 11,700' SLM W/ PDS 24 ARM CALIPER. (Good data) 7/11/2013 ****WELL S/I ON DEPARTURE**** - VT ' con inue. rom - I- 'ump a•.1 iona • •• s •S cruse •own BG. 7/11/2013 I • • I/1 5/ S li .I' - • a, -II •• •-•_• - ' _• FLUIDS PUMPED BBLS 5 60/40 METH 249 CRUDE 1 DIESEL 255 TOTAL Casing / Tubing Attachment ADL0028307 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5#H-40 29 - 109 29 - 109 1490 470 LINER 1234 7"29# L-80 11206 - 12440 7988.03 - 8775.27 8160 7020 LINER 938 2-3/8"4.7# L-80 12214 - 13152 8618.59 - 8841.33 11200 11780 PRODUCTION 10606 9-5/8"47# L-80 27 - 10633 27 - 7656.92 6870 4760 PRODUCTION 898 9-5/8"47#S00-95 10633 - 11531 7656.92 - 8184.16 8150 5080 SURFACE 2469 13-3/8" 72# L-80 28 - 2497 28 - 2496.96 4930 2670 TUBING 12190 4-1/2" 12.6# L-80 25 - 12215 25 - 8619.27 8430 7500 • TUBING 215 3-1/2" 9.3#L-80 12215 - 12430 8619.27 - 8768.19 10160 10530 • • • Packers and SSV's Attachment ADL0028307 SW Name Type MD TVD Depscription 18-07A _ PACKER 11068 7860.33 4-1/2" BAKER S-3 PERM PACKER 18-07A PACKER 11206 7942.03 7" Baker ZXP PKR/HGR 18-07A PACKER 12065 8473.45 2-7/8" Baker KB Packer 18-07A 1 PACKER 12403 8703.13 3-1/2" FB-1 PACKER ■ •VH�LFEAD= 41 McB/OY 1 8_O 7A S NOTES: WELL ANGLE>70°fa 12472'*** ACTUATOR= BAKE R C 2-318"CT LNR IS -133'SHALLOWER THAN NT AL KB.ELEV 62' 1 - I DEPTHS ON TALLY(05106100)*** BF.e.EV= NA KOP= 2950' I fig' H4-1/2"CAMCO BAL-O SVLN,D=3.812" Max Angle= 97°@ 13261' Datum MD= 13050' DatumTVD= _ 8800'SS GAS LFT MANDRELS 120"CONDUCTOR 91.5#,H-40,D=19.124" I —80' ST MD WI) DEV TYPE VLV LATCH FORT DATE 1 3608 3561 32 KBG-2 DMY BK 0 06/24/13 H 2 87 8 6565 56 KBG-2 DMY BK 0 06/24/13 13-3/8"CSG,72#,L-80,D=12.347" 2497' LI 1 9-5/8"CSG,47#,L-80 BTC,D=8.681" H 10633' I--->.< x 3 11000 7866 54 KBG-2 DMY BK 0 10/25/06 Minimum ID =1.83" @ 12065' I 11068' H9-5/8"X 41/2"BKR S-3 PKR,D=3.875" I 45 KB LINER TOP PACKER I 11102' H4-1/rHESX NP,D=3.813" I 14-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 11129' I 14-1/2"TUBING STUB(11133'B.MD) --I. 11133' 1 L11136' H9-5/8"X 4-1/2"LNIQLEOVERSHOT I TOP OF r LNR __i__1 1206' I•-- I 11206' H9-5/8"X 7"BKR LW&HGR,D=? I 19-5/8"CSG,47#,S00 BTC,D=8.681" —I 11533' I. L 12065' I--I45 BKR KB LIP,D=1.83"(07/11/13) I 12076' 3.71'BKR DEPLOY SLV w/2.25"SEAL BORE, TOP OF 2-318°LNR H 12076' I D=1.969'(TAGGE37 IUGH ON 05/30/00) 12215' —14-1/2"X 3-112"XO,D=2.992" I BEHIND CT LNR GAS LFT MANDRELS I4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,D=3.958' H 12214' I•— ■ ST MD ND DEV TYFE VLV LATCH FORT GATE 1 12280 8610 47 "KBUG DMY BK 0 11/30/99 2 12318 8637 46 'KBt1G DMY BKP _ 0 08/31/93 GLMS FIEDM INITIAL COMPLETION 09/1982 I [1 12366'-12398'Ha-1/2-BLAST JOTS I x 12403' HrX3-1/2"BKR F1PKRI BEHIND 13-1/2"TBG,9.2#,L-80,.0087 bpf,0=2.992' IH 12429' I\ I i I 12418' H3-1/2"CAMCO D NP,D=2.80" I CT LNR 17"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" H —12444 \\, ,,---) 12430' I--0-112'WLEG,D=2.992" I PERFORATION SUMMARY I REF LOG: SWS MCNJGR/CCL ON 07/07/00 7"MLLOUT 1AV DOW(18-07A)12440'-12444' ANGLE AT TOP PHRF:45°@ 12370' I Note:Refer to Aoduction DB for historical pert data ' SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 4" 4 12370-12390 C 03/11/00 ' 1.56" 6 12465-12515 0 06/17/04 I 1.56' 6 12525-12770 0 08/10/08 1.9/16" 4 12569-12600 0 07/07/00 ' 1.9/16" 4 12689-12740 0 07/07/00 1.56" 6 12875-12925 0 08/10/08 41/I I 12977' H FISH-3-1/2°CBP(1/30/06) I IPBTD(O-RING SUB,D=1.00")H 13115' I ... 13300' sA 12-3/8"LNR,4.43#,L-80 FL4S,.0039 bpf,D=1.941' H 13151' wr// DATE REV BY COM6B'TTS DATE REV BY SITS PR DHOE BAY UNIT 09/12/82 PHR 176 INITIAL COMPLETION 09/05/08 GJF/PJC GLV C/O(08/30/08) WELL 18-07A 031/1100 N3E5 MO 12/20/12 JF/JbD RCS(08/10/08) PEWIT Pb:"2000140 06107/00 N3E8 CTD SIDETRACK(18-07A) 07/13/13 CJW PJC GLV C/O(06/24/13 AR No: 50-029-20803-01 01/30/06 A/C/PJC FUSH CEP BOTTOM 07/13/13 ALMc/PJC 45 KB LTP SET(7/11/13) SEC 24,T11N,R14E,719 FNL&282'FE. 1025/06 DTR/PAG GLV co 07/14/13 PJC REFORMAT WBS 09/05/08 JKC/PJC F RFS(08/09/08) BP Exploration(Alaska) _ .. .::.. STATE OF ALASKA ~ r_ ~ , _; ~'~ ALA OIL AND GAS CONSERVATION COMt~IC'I~ ~_: REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0, Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~` i Exploratory ~ 200-0140 3. Address: P.O. Box 196612 Stratigraphic Service ~-~ 6. API Number: Anchorage, AK 99519-6612 50-029-20803-01-00 7. KB Elevation (ft): 9. Well Name and Number: 46 KB - PBU 18-07A ' 8. Property Designation: 10. Field/Pool(s): _ ADLO-028307 < PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13300 ~ feet Plugs (measured) None true vertical 8828.91 ~ feet Junk (measured) 12977' Effective Depth measured 13115 feet true vertical 8843 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2469 13-3/8" 72# L-80 28 - 2497 28 - 2497 4930 2670 Production 11504 9-5/8" 47# L-80 27 - 11531 27 - 8184 6870 4760 Liner 1234 7" 29# L-80 11206 - 12440 7988 - 8775 8160 7020 Liner 942 2-3/8" 4.43# L-80 12209 - 13151 8615 - 8841 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 25 - 12215 3-1/2" 9.3# L-80 12215 - 12430 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 11068 3-1/2" FB-1 Packer 12403 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): pp,,~~~q ^, ~ ~~D 4ryc.~~i1~~~ ~ "'' t1 ~ 7 O 0 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 352 17429 0 1809 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development +~'' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG !! GINJ ~' WINJ `~ WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Si nature Phone 564-4944 Date 8/11/2008 ~~/ g t Form 10-404 Revi d 6) -, ~ "' ~ ~ e ~_ ~O~ ~ ~ ZQOS Submit Original Only 18-07A 200-0140 PFRF ATT~C`HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-07A 7/7/00 PER 12,569. 12,600. 8,805.19 8,806.35 18-07A 7/7/00 PER 12,689. 12,740. 8,804.74 8,805.73 18-07A 6/17/04 APF 12,465. 12,515. 8,789.52 8,799.92 18-07A 4/14/05 BPS 12,545. 12,740. 8,803.27 8,805.73 18-07A 1/29/06 BPP 12,545. 12,740. 8,803.27 8,805.73 18-07A 8/10/08 APF 12,525. 12,770. ~ 8,801.11 8,808.86 18-07A 8/10/08 APF 12,875. 12,925. 8,820.55 8,825.03 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE . • • 18-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/9/2008':: T/I/0=2400/1000/150. Pull 4-1/16 CIW "H" BPV #130 thru stack for Klondike. RKB' 20.75'.15' ext used, tagged @ 76". No problems. 8/9/2008':CTU #9 1.5" CT (Extended Perforating) Continued from 8/8/08 WSR RIH for drift ',tagged TD at 12995' PUH to 12965' paint flag POOH At surface M/U logging tools 'IOG FROM 12975' to12400' Paint yellow & white flag ~ 12800'. OOH ck for flow. No flow L/D logging tools ck for data. Confirmed good data 0 correction RIH w gun ''run #1 12875 to 12925 w/1.56" HSD Gun PJ 1606 6 s f 60 de ree. POOH uns `, ire aint flag at 12450' for next gun run. At surface break down guns and M/U ;.guns for next run. *"""***** Continued on 8/10/08 WSR *****"*" 8/10/2008'''CTU #9 1.5"CT (Extended Perforating) Continued from 8/9/08 WSR M/U guns for !'2nd run RIH with guns to 12525'. Perf from 12525' to 12770' w/1.56" HSD Gun ''PJ1606 6 spf 60 degree POOH. Recovered 1/2" ball all shots fired P/U 1.75" 'nozzle RIH and clean out Flo Pro. Freeze protect well w/45 bbls Diesel. RDMO 'j Road to shop to change to 1.75" pipe. "**"**** Job Complete'`******'* 8/11/2008: T/I/O=Vac/0/0. Set 4-1/16" CIW "H" BPV # 251 thru dry hole tree & partial stack, Klondike move off. 5' ext used, tagged @ 76". No problems. FLUIDS PUMPED BBLS 1 diesel 1 Total 18-07A (PTD #2000140) Classified as PrOb,well . All, Well 18-07A (PTD #2000140) has been found to have sustained casing pressure on the fA. The TIOs on 10/18/06 were 2280/2280/90. A subsequent TfFL failed on 10/19/06. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGL Vs 3. DHD: Re-TIFL ,i.; A wellbore schematic has been included for reference. «18-07 A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, Andrea Hughes Well Integrity Engineer Office: (907) 659-5766 Pager: (907) 659-5100 x1242 Content-Description: 18-07 A.pdf Content- Type: application/octet-stream Content-Encoding: base64 1 of 1 10/23/2006 4:31 PM TREE = 4-1/16" CfIN ~NOTES: WELLANGlE>700@12472'& WaLHEAD= McEVOY 18-07 A ACTUA TOR = BAKER C >900 @ 12617'. * GlM #4 & 5 ARE PRE-RWO KB. aEV - 46.0' JEWELRY (WERE #1 & #2 PRE-RWO} & ARE BF. aEV - NA BEHIND 2-3/8" LNR. KOP= 2950' Max Angle = 97 @ 13261' . 2249' 1-14-1/2" CAMCO BAL-O SVLN, ID = 3.812" ¡ Datum MD = 13050' Datum TVD = 8800'SŠ GAS LIFT MANDRaS ST MD TVO OEV TYÆ VLV LATCH PORT DATE ~ 1 3608 3564 31 KBG-2 DOME BK 16 07/22/00 113-3/8" CSG, 72#, L-80, 10 = 12.347" I 2497' L .. 2 8768 6572 57 KBG-2 DOME BK 16 07123/00 3 11000 7873 54 KBG-2 S/O BK 24 07/23/00 *4 12280 8610 47 . KBUG OV BK-2 0 11130/99 Minimum 10 = 1.941" @ 12214' *5 12318 8637 46 * KBUG EKED BKP 0 08131193 2-3/8" LINER TOP *GLMS #4 & #5 BEHIND CT LINER 05/07/00 ~ I..--, 11068' H9-5/8" x 4-1/2" BKR 8-3 PKR, ID =: 3.875" I /2S I 11102' 1-14-112" HES x NIP, 10 = 3.813" I 14-1/2" TBG, 12.6#, L-BO, .0152 bpf,ID= 3.958" 1-1 11129' I i IÌ' I 11129' 1-14-1/2" UNIQUE OVERSHOT I Ñ 11133' H4-1/2" TBG STUB (11126'aM) I . Ii 11206' H 9-5/8" x 7" BKR LNR HGR I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 11531 ' "}-----..4 ... 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID= 3.958" I 12214' ~ ------t 12076' H3.71" BKR DEPLOYMENT SLV, 10 = 1.969" I ,- _J I TOP OF 2-3/8" LNR, 4.43#, ID = 1.941" I 12214' ~ ~ 12215' H4-1/2" x 3-112" XO (BHND LNR), ID = 2.992" I [ 12356' 1-1 TOP OF 4-1/2" BLA ST JTS (BEHIND LNR) I 12398' HBTM OF 4-1/2" BLAST JTS (BEHIND LNR) I :g ~ I 12403' H 7" X 3-1/2" BKR F1 PKR (BEHIND LNR) I 12418' I- 3-1/2" CAMCO D NIP (BHND LNR), 10" 2.80" I I 3-1/2" TTP. 9.2#, L-BO, 10" 2.992" (BHNO LNR) I 12429' I I 12430' H3-1/2" WLEG (BEHIND 2-3/8" LNR) I ÆRFORA TION SUMMARY ~ 7" SIDETRACK MILLOUT WINDOW REF LOG: SWS MCNLlGRlCCL ON 07/07/00 12440' - 12444' (OFF CMT RA MP ) ANGLE AT TOP PERF: 84 @ 12569' Note: Refer to Production DB for historical perf data SIZE SPF INTER V AL OpnlSqz DATE 4" 4 12370 - 12390 C 03/11/00 I 12977' -13-1/2" WRD CIBP (1/30/06) I 1.56" 6 12465 - 12515 0 06/17/04 1-9/16" 4 12569 - 12600 0 07/07/00 ~PBm -I 13115' I 1-9/16" 4 12689 - 12740 0 07/07/00 I 7" LNR. 29#, L-BO, ID" 6.184" I V ~¡ / TO l-t 13300' I 12646' I Ir I O-RING SUB, 10'" 1.00" I 13115' I 2-3/8" LNR, 4.43#, L-80, .0039 bpf, ID = 1.941" 13151' V DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE SA Y UNIT 09/12/82 ORIGINAL COMPLETION 05/03/05 JGMlPJC SET CIBP @ 12545 waL: 18-07A 03/11/00 RWO 10130/05 DAClPAG CIBP (4/4/05) CORRECTION PERMIT No: "2000140 05107100 CTD SIDETRACK 01/30/06 JMClPJC PUSH CIBP BOTTOM API No: 50-029-20803-01 11/05/01 SDFITLH OPL Y SL V DEPTH CORRECTIO/\ SEC 24, T11N, R14E, 719' FNL & 282' Fa 09/13/03 CMOITLP DATUM MO & ÆRF ANGLE 06/17104 JGIWKAK ADÆRFS BP Exploration (Alaska) · STATE OF ALASKA . AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Stimulate D Other 0 Mill CIBP Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: :I> ëD 200-0140 0 D 6. API Number: 50-029-20803-01-00 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development r;?' Stratigraphic D Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 5? s: 9. Well Name and Number: :I> == ("a 46 KB 18-07 A 8. Property Designation: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool ... I» CCI CD ADL-028307 11. Present Well Condition Summary: ~ ë;¡' o S' == Total Depth measured 13300 true vertical 8828.91 feet feet Plugs (measured) None Junk (measured) 12977 Effective Depth measured 13115 true vertical 8842.72 feet feet Casing Conductor Surface Production Liner Liner Length 80 2469 11504 1234 942 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 2-3/8" 4.7# L-80 Collapse 470 2670 4760 7020 11780 MD 29 - 109 28 - 2497 27 - 11531 11206 - 12440 12209 - 13151 TVD 29 - 109 28 - 2496.96 27 - 8184.16 7988.03 - 8775.14 8615.22 - 8840.82 Burst 1490 4930 6870 8160 11200 Perforation depth: Measured depth: 12465 - 12515 True Vertical depth: 8789.52 - 8799.92 12569 - 12600 8805.19 - 8806.35 12689 - 12740 8804.74 - 8805.73 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 3-1/2" 9.3# L-80 L-80 25-12215 12215 - 12430 Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 3-1/2" FB-1 Packer 11068 12403 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft MM) 0 :~ 7006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN 36551 0 0 1042 15. Well Class after Droposed work: Exploratory Development M Service 16. Well Status after proposed work: Oil M Gas D WAG WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 867 x Contact Sharmaine Vestal Printed Name Sharmaine Vestal I Signatu~-2J~l Title Data Mgmt Engr Phone 564-4424 Date 2/28/2006 Form 10-404 Revised 04/2004 Submit Original Only RBDMS BFl MAR 1 6 2006 e e . 18-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUf0I1.\ 1/29/2006 CTU 9 - 1 1/2" Coil - Mill CIBP - MIRU - Weld on connector - Kill well - RIH with 1 11/16" motor and 1.73" 3 blade concave mill- Tag at 12536' ctmd- Mill to 12562 - Pushing plug, stop at 12575'. Work down to 12617'. Tough time getting plug thru perfs. ***Continued on 1/30/06 WSR*** 1/30/2006 Mill CIBP. CTU #9. Continued from 1/29/04 WSR. Continue to work CIBP to bottom. Leave CIBP at 13001' ctmd. PUH with overpull's in liner. RBIH to bottom, try to spin plug off. POOH, still dragging thru areas in liner. At surface, LD tools ( heavy paraffins on tools and in stack). MU RIH drift tbg w/ 1.75" JSN. tag at 12977' - POH FP tbg to 2500'- RDMO to DS shop for maintenance **** Notify DSO of well SI status.**** **** Job Complete **** FLUIDS PUMPED BBLS 665 1 % x-SLK 206 60/40 Meth 305 1 % KCL 1176 TOTAL ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION ß.ECE,'VE[) REPORT OF SUNDRY WELL OPERATION~u ~,."".,,,,ð 1. Operations Performed: UN 0 8 2005 AbandonD Repair Well 0 PluÇJ PerforationslK! Stimulate ~~ . OtherD øiiiska O~~ &. 68 0 ~ \ . "'(1'~~ Alter CasingD Pull TubingD Perforate New Pool 0 Waiver Time ~xt~n~ðr"tf1mm¡"'~~l!.d·¡ D D 0 tmr:hom[J1¡~ D Change Approved Program Operation Shutdown Perforate Re-enter Suspended well ) 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ]] ExploratoryD 5. Permit to Drill Number: 200-0140 6. API Numbe 50-029-20803-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 46.00 8. Property Designation: ADL-028307 11. Present Well Condition Summary: Stratigraphic 0 Service D 9. Well Name and Number: 18-07 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 13300 feet true vertical 8828.9 feet Effective Depth measured 12602 feet true vertical 8806.4 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 29 109 29.0 109.0 1490 470 LINER 1234 7" 29# L-80 11206 - 12440 7988.0 - 8775.1 8160 7020 LINER 942 2-3/8" 4.7# L-80 12209 - 13151 8615.2 - 8840.8 11200 11780 PRODUCTION 11504 9-5/8" 47# L-80 27 - 11531 27.0 - 8184.2 6870 4760 SURFACE 2469 13-3/8" 72# L-80 28 - 2497 28.0 - 2497.0 4930 2670 Perforation depth: Measured depth: 12465 -12515 True vertical depth: 8789.52 - 8799.92 RBDMS ~L JUN 0 7 2005 TubinÇJ ( size, Qrade, and measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 @ 25 12215 @ 12215 12430 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 3-1/2" FB-1 Packer @ 11068 @ 12403 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: i)C.ANNcr JUN 1 4 ?G05 Prior to well operation: Subsequent to operation: Oil-Bbl 492 1028 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 19.5 0 38.9 0 Tubing Pressure 1720 650 13 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class atter proposed work: ExploratoryD 16. Well Status atter proposed work: OilŒJ GasD Development Œ] Service 0 14. Attachments: Signature Garry Catron Garry Catron ~ C -J-r-- .-....JC~. ~~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Form 10-404 Revised 4/2004 Phone U D , C ¡ i\r f~ L ,\IU~a\lj-"\ 564-4657 Date 6/2/05 ') ) 18-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/13/05 MIRU CTU 9 - MUIRIH AND DRIFT TBG WITH DUMMY CIBP DRIFT - NO OBSTRUCTIONS RIH OR POH OF LINER OR DL. RIH WI 1.75 CIBP........ 04/14/05 SET CIBP @ 125451 BBLS 105 Methanal 320 1 % KCL 270 Dead Crude 695 TOTAL FLUIDS PUMPED Page 1 TREE:;: 4-1/16" CWV WELLHEAD = McEVOY ÄCTUÄTÖR';' ... . BAKERC KB.··'ËLEV'·;;;····--4W ..."."".."...""....".". ..."..".... BF. ELEV = NA .,.....,.,.".~~~~ KOP = 2950' 'Max~·0Qi~;; ·9(~j~~~1; Datum MD = 13050' . "".""""""....""...",,, "",,,,,,,,,,,,. Datum ìVD = 8800' SS ') 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2497' Minimum ID = 1.941" @ 12214' 2·3/8" LINER TOP 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 11129' I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 11531' 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 12214' 1 TOP OF 2-3/8" LNR, 4.43#, ID = 1.941" I-J 12214' 3-1/2" TTP, 9.2#, L-80, ID = 2.992" (BHND LNR) l-i 12429' 1 ÆRFORA TION SUMMARY REF LOG: SWS MCNL/GR/CCL ON 07/07/00 ANGLEAT TOP ÆRF: 84 @ 12569' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 4 12370 - 12390 C 03/11/00 1.56" 6 12465-12515 0 06/17/04 1-9/16" 4 12569 - 12600 0 07/07/00 1-9/16" 4 12689 - 12740 0 07/07/00 7" LNR, 29#, L-80, ID = 6.184" l-i 12646' DATE 09/12/82 03/11/00 05/07/00 10/19/01 11/05/01 09/13/03 REV BY COMMENTS ORIGINAL COM PLETION RWO CTD SIDETRACK CH/KAK CORRECTIONS SDF/TLH DPL Y SL V DEPTH CORRECTION CMO/TLP DATUM MD & ÆRF ANGLE 18-07A ):ErYNOTES: WELL ANGLE >700 @ 12472' & >900 @ 12617'. * GLM #4 & 5 ARE PRE-RWO JEWELRY(WERE#1 & #2 PRE-RWO) & ARE BEHIND 2·3/8" LNR. - 2249' 1-1 4-1/2" CAMCO BAL-O SVLN, ID = 3.812" GAS LIFT MANDRELS ìVD DEV TYÆ VLV LATCH 3564 31 KBG-2 DaME BK 6572 57 KBG-2 DOME BK 7873 54 KBG-2 S/O BK 8610 47 * KBUG DV BK-2 8637 46 * KBUG EKED BKP ~ ST MD ~ 1 3608 a 2 8768 3 11000 *4 12280 *5 12318 PORT DATE 16 07/22/00 16 07/23/00 24 07/23/00 o 11/30/99 o 08/31/93 L z ~ ~ ~ *GLM'S #4 & #5 BEHIND CT LINER 05/07/00 11068' l-i 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 11102' l-i 4-1/2"HESXNIP,ID=3.813" 1 11129' 1-1 4-1/2" UNIQUE OVERSHaT 1 11133' l-i 4-1/2"TBGSTUB(11126'ELM)1 11206' l-i 9-5/8" x 7" BKR LNR HGR 1 , ~ r4 ~J I r .. 12076' l-i 3.71" BKRDEPLOYMENTSLV, ID= 1.969" 1 J ,_ 12215' l-i 4-1/2" x 3-1/2" XO (BHND LNR), ID = 2.992" 1 12356' l-i TOP OF 4-1/2" BLAST JTS (BEHIND LNR) 1 12398' l-i BTM OF 4-1/2" BLAST JTS (BEHIND LNR) 1 12403' l-i 7" x 3-1/2" BKR F1 PKR (BEHIND LNR) 1 o x ~ 12418' 1-13-1/2" CAMCO D NIP (BHND LNR), ID = 2.80" I 12430' l-i 3-1/2" WLEG (BEHIND 2-3/8" LNR) 7" SIDETRACK MILLOUT WINDOW 12440' - 12444' (OFF CMT RAMP) 112545'1-1 2-7/8"WFDCIBP(SET4/4/05) 13115' 1 l-i 13300' I O-RING SUB, ID = 1.00" l-i 13115' 2-3/8" LNR, 4.43#, L-80, .0039 bpf, ID = 1.941" l-i 13151' DA TE REV BY COMMENTS 06/17/04 JGIvVKAK ADÆRFS 05/03/05 JGIvVPJC SET CIBP @ 12545 PRUDHOE BA Y UNIT WELL: 18-07A ÆRMIT No: "'2000140 API No: 50-029-20803-01 SEC 24, T11N, R14E, 719' FNL & 282' FEL BP Exploration (Alaska) MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimulate 0 Other 0 Abandon 0 Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionO Change Approved ProgramD Operation Shutdown 0 Perforate I!] Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD ~141\ 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20803~1~0 7. KB Elevation (ft): 9. Well Name and Number: 46.00 18~7A 8. Property Designation: 10. Field/Pool(s): ADL~028307 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13300 feet true vertical 8828.9 feet Plugs (measured) None Effective Depth measured 13115 feet Junk (measured) None true vertical 8842.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29.0 - 109.0 1490 470 Liner 1234 7" 29# L-80 11206 - 12440 7988.0 - 8775.1 8160 7020 Liner 942 2-3/8" 4.7# L-80 12209 - 13151 8615.2 - 8840.8 11200 11780 Production 11504 9-5/8" 47# L-80 27 - 11531 27.0 - 8184.2 6870 4760 Surface 2469 13-3/8" 72# L-80 28 - 2497 28.0 - 2497.0 4930 2670 Perforation deDth: Measured depth: 12465 -12515,12569 -12600,12689 -12740 RECEIVED True vertical depth: 8789.52 - 8799.92,8805.19 - 8806.35,8804.74 - 8805.73 SEP - 3' 2004 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 .@ 25 12215 - 3-1/2" 9.3# L-80 @ 12215 - 12430 Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth): 3-112" FB-1 Packer @ 12403 Anchorage 4-112" Baker S-3 Perm Packer @ 11068 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Remesentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Waler-Bbl CasirlQ Pressure Tubing Pressure Prior to well operation: 1071 35.4 11 1330 458 Subsequent to operation: 928 10.4 13 1435 983 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development !J Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! OilŒJ GasD WAGD GlNJD 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. 1SUndry Number or NIA if C.O. Exempt: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature .11 ~/ ~ Phone 564-4657 Date 8/31/04 t'\ Form 10-404 Revised 4/2004 ORIGINAL IØIIS BF L SEP 0 3 1004 18-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/16/04 TRAVEL TO DS 18 - MIRU CTU # 9 - RIH TO 12600' NO PROBLEM POH. MU AND RIH WITH PDS LOGGING TOOLS. JOB IN PROGRESS. 06/17/04 CONTINUED FROM WSR OF 5/16/04. LOG FROM 12600 TO 12200 AT 40 FPM. FLAG PIPE AT 12200. POH. VERIFY DATA. MU AND RIH WITH GUN#1. (25') PERF INT 12490'- 12515'. POH - LD GUN #1- ALL SHOTS FIRED. MU/RIH W/ GUN # 2 (25') PERF INT 12465'. 12490', POH - LD GUN # 2 - ALL SHOTS FIRED - ALL GUNS 1.56" HSD - PJ1606 - 6 SPF- 60 DEG - RANDOM ORIENTATION - RDMO - NOTIFY DSO TO POP WELL- WELL LEFT SI **** JOB COMPLETE **** FLUIDS PUMPED BBLS 405 1 % KCL 20 50/50 Methonal 425 TOTAL Page 1 TREE = 4-1/16" CIN 18-07A SAFETY NOTES: WB.LANGLE>700@ 12472' & >900 @ 12617'. * GLM #4 & 5 ARE PRSRWO JEWB.RY(WERE#1 & #2 PRSRWO) & ARE BetIND2-3/8" LNR. WELLHEAD = MeBlOY ACn.l6.TOR= BAKERC KB. ELEV = 46.0' BF. ELEV = NA KOP= 2950' Max Angle = 97 @ 13261' DatumMD= 13050' DatumTVD = 8800' SS . 2249' ST MD 1 3608 2 8768 3 11000 *4 12280 *5 12318 13-318" CSG, 72#, L-80, ID = 12,347" Minimum ID = 1.941" @ 12214' 2-3/8" LINER TOP 4-112" TBG, 12.6#, L-80, .0152 bpt, D =3.958" 11129' 9-5/8" CSG,47#, L-80, ID =8.681" 4-112" TBG-PC, 12.6#, L-80, .0152 bpf, D =3.958" TOP OF 2-3/8" Lf\R, 4.43#, ID = 1.941" 12418' 3-1/2" TIP. 9.2#, L-80, D = 2.992" (BI-ND Lf\R) 12429' PERFORATION SUMMARY REF LOG: SWS MeNUGRlCa. ON 07/07/00 ANGLEATTOPÆRF: 84@ 12569' IIble: Refer 10 A"oduetion DB tor historieal ert data SIZE SPF INTERV AL Opn/Sqz OA. TE 4" 4 12370 - 12390 C 03111/00 1.56" 6 12465 -12515 0 06117/04 1-9/16" 4 12569 - 12600 0 07/07/00 1-9/16" 4 12689 - 12740 0 07/07/00 7' LNR, 29#, L-80,ID =6,184" 12646' O-RNG SUB, ID = 1.00" OA.TE RBI BY COMMß\JTS OA. TE REV BY COMMENTS 09/12/82 ORIGINAL COM PLETION 06117/04 JGMlKAK ArFERFS 03/11/00 RWO 05/07/00 CTDSDETRACK 10/19/01 CH'KAK CORRECTIONS 111\)5/01 SDF/TLH DPL Y SL V DEPrH CORRECllOt\ 09/13/03 CMOITLP DA lUM MD & ÆRF ANGLE 4-1/2" CAMeO BAL-O SVLN, ID = 3.812" GAS LIFT Mð.NffiELS TVD ŒV TYPE VLV LATCH 3564 31 KBG-2 DOME BK 6572 57 KBG-2 DOME BK 7873 54 KBG-2 SIO BK 8610 47 * KBoo DV BK-2 8637 46 * KBoo EKED BKP FORT DATE 16 07/22/00 16 07/23100 24 07/23100 0 11/30/99 0 08/31/93 *GLMS #4 & #5 BEHII'V cr LNER 05107,{J0 4-112" HES X I\IP, ID = 3.813" 4-1/2" \.NIQUEOVERSHOT 9-518" X 7" BKR LNR HGR 3.71" BKRDEROYMENTSLV, D =1.969" 4-1/2" X 3-1/2" XO(BHNDLf\R), ID= 2.992" TOPOF4-1/2" BLAST JTS (BEHNDLf\R) BTMOF4-1/2"BLAST JTS (BEHNDLf\R) 7"X3-1/2"BKRF1 R<R(BEHII'VLNR) 3-1/2" CAMeO D NIP (BI-ND LNR), D = 2.80" 3-112" WL83 (BEHND 2-3/8" LNR) 7" SIDErRACK MLLOUTWII'VOW 12440'-12444' (OFFCMTRAM') PRLOI-OEBAY \.NIT WELL: 18-07 A PERMIT No: 2000140 AA No: 50-029-20803-01 SEC24, T11N, R14E. 71g FI\I... &282' ÆL BP Exploration (Alaska) Permit to Drill 2000140 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 18-07A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20803-01-00 MD 13300 TVD 8834 Completion Dat 7/7/2000 ~'"' Completion Statu 1-OIL REQUIRED INFORMATION Mud Log N._~_o Sample No Current Status 1-OIL UIC N Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Interval Log Log Run Name Scale Media No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORM~ION Well Cored? Y/t~ Chips Received? ~ Analysis ~ Rec. P. ived? Daily History Received? Formation Tops ~ N Comments: Date: Transmittal Form B&KBR HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Prudhoe Bay North Slope, Alaska 18-07 APB2 '~i Contains the following: il 1 LAS Format disk !i 1 Film il 1 Measured Depth GR print !i 1 TVD-GR print Sent By: Josef Berg eive, Date: A ' , Date: APR 2 4 ZooJ .... ,~,k~l & Gas Cons. PLEASE ACKNOWLEDGE RECEIPT BY ~I~NING &~RNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 . :.. . Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To'. State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100' Anchorage, AK Phone: Attention: Lisa Weepie 99501 Reference: Pmdhoe Bay North Slope, Alaska 18-22A, & 18-07 APB1 Contains Prints Of.' 1 LAS Format disk · ' 1 Film. · 1 Measured Depth GR print 1 TVD-GR print · , Sent By: Glenn Horel Received By~~ ~_~ Date: April 19, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West .]th Avenue, Suite 100 Anchorage, AK 99501 Phone: Attention: Lisa Weepie Reference: Prudhoe Bay North Slope, Alaska 18-07A Contains Prints Of: 1 LAS Format disk 1 Film 1 Measured Depth GR Print 1 TVD-GR print Sent By: Glenn Horel Received By: ~ ~ Date: April 18, 2001 Date: RECEIVED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & ~~G OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Alaska Oil & 6as 6ons. Oommif, ei~ Anchorage 4~OO Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 514 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 i~,~. o~ ~' l~. 03oo ~,~ .oS'O Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-31A 20261 MCNL ~ ~.-j .~ 000608 1 I 1 D.S. 7-13A 20257 MCNL '[~ OL''~ 9,5" 000531 I I 1 D.S. 14-15 20253 EST ~ ~-~ ~ 000602 I I 1 D.S. 18-07A 20306 MCNL ~ ~m ~ 000707 I I 1 D.S. 18-~A 20244 MCNL(PDC) ~ ~~ 000525 I I I r..A. ]~,SR~ Oil & Gas Cons. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~,Ora~P~ STATE OF ALASKA ALA::,r,,A OIL AND GAS CONSERVATION COM~,,,,dSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas D Suspended D Abandoned E] Service D ~ 2. Name of Operator .. ~,m~ 7. Permit Number BP Exploration(Alaska), Inc. i~ 200-014 3. Address ~1~.~ 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612~ 50-029-20803-01 4. Location of well at surface ~'-i: ~';"" :"7; ;i'-I 9. Unit or Lease Name 717' FNL, 280' FEL, Sec. 24, T11 N, R14E, UM (asp's 691473, 5961142) ; '- "" -': i Prudhoe Bay Unit At Top Producing Interval i - ....... f 'Z--,---._. . 10. Well Number 942' FNL, 2589' FEL, SEC 23, T11 N, R14E, UM (asp's 683893, 5960732) i .T~ .... At Total Depth ~ --- 11. Field and Pool 696' FNL, 3091' FEL, Sec 23, T11 N, R14E, UM (asp's 683385, 5960965) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. I RKB 46 feet ADL 28307 Prudhoe Bay O/H' Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore / 1/6. No. of Completions March 20, 2000May 5, 2000 July7, .t~~ I N/A feet MSL-- / , 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set /, 2~li?T, hickness of Permafrost 13300'MD/8834"I'VD 13113' MD / 8848"rVD YES [~] No [~]I 2249' feetMD /~ 1900'(approx) 22. Type Electric or Other Logs Run / / MWD & GR, Mem CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDJ AMOUNT PULLED 20" 91.5# H-40 Surface 79' 30" 19oo# Poleset 13-3/8" 72# L-80 Surface 2497' 17-1/2" 1670 sx Fondu & 400 Sx PFC 9-5/8" 47# L-80/S00-95 Surface 11531' 12-1/4" 5oo Sx Class G & 3OO Sx PFC 7" 29# L-80 11206' 12440' 8-1/2" 400 Sx Class G 2-3/8" 4.43# L-80 12214' 13152' 3" 12.5 bbls 15.8 ppg Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 12215' 11173' 3-1/2" 12430' 12403' 12569'- 12600' MD; 8810'-8811'TVD; @ 4SPF 11068' 12689' o 12740' MD; 8810' - 8811' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary I'or details) 27. PRODUCTION TEST ;Date First Production Method of Operation (Flowing, gas lift, etc.) July 28, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL , GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/29/2000 6.6 Test Pedod >I 5466 Flow Tubing Casing Pressure Calculated OIL-BBL iGAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -944 psi 24-Hour Rate > 681 3723 101 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved March 2, 2000 (Permit #200-014) ,,' [ IF-, ,'", '.? ~ .... . ORIGINAL ?A~.p~',i~i --~¢ ~.-. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 1B Top of Zone lA GEOLOGIC MARKER; MEAS. DEPTH 11541' 11627' 11756' 12450' 1273O' TRUE VERT. DEPTH 8197' 8250' 8330' 8787' 8810' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time el each phase. 31. LIST OF ATTACHMENTS Summary of 18-07A CT Sidetrack Drilling Operations + Final Survey which includes 2 plugbacks. 32. I hereby cedify that the following is tree and correct to the best of my knowledge. Signed ~~ ~,~ Title PAl Coil Tubin.q Ddllin,q En.qineer Larnar L. Ganff INSTRUCTIONS Prepared by Paul Rauf 263-4990. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. !!:~,~:~:!.,. ~.~_~ ~i~,.,~,:~ ?:,~ ,: ..'/?'~ Item 28: If no cores taken, indicate "none". Form 10-407 ., 18-07A DESCRIPTION OF WORK COMPLETED PRODUCTION TUBING SWAP / COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/26/2000: 2/27/2000: 3/04/2000: 3/05/2000: 3/06/2000: 3/07/2000: 3/08/2000: 3/09/2000: 3/10/2000: 3/11/2000: 3/12/2000: 3/16/2000: 3/18/2000: 3/19/2000: 3/20/2000: 3/21/2000: 4/17/2000: PT'd IA to 1300 psi w/1000 psi on tubing - passed. RIH & tagged TOC @ 12344' MD. RIH & punched tubing f/11105' - 11109' @ 4 SPF. Shot string shot f/11117' -11128' to remove plastic coating on tubing. Cut tubing w/chemical cutter @ 11126'. MIRU Nabors 3S. Rig accepted 1530 hrs. Circulated well to Seawater. Continued RU. NU BOPE. PT'd BOPE. Spear hanger & pull to floor. Circulate Seawater. Pulled 3 4-1/2" joints. MU RTTS. Set @ 55' & tested it. ND BOPE. Changed out tubing spool. NU & tested BOP flanges that were broken. Pull RTTS. Circulated to warm wellbore. Verified well stable. POOH w/old 4-1/2" tubing. Retrieved all SS bands. LD SSSV. A total of 95 joints removed. POOH w/270 joints. Load pipeshed. RU SLU. RIH w/8.525" gauge ring but unable to get past 6500'. RIH w/8.465" junk basket to BTM. POOH. Cement in basket. Rerun 2nd time, got Cement & spring. RIH w/LIB & tagged stub @ 11127' MD. Prep rig floor. Ran 4-1/2" completion (custom overshot, SSSV Nipple Camco BAL-O @ 2249', Baker S-3 Hydraulic Production Packer @ 11068', 12.6# L-80 IBTM tubing, & 3 GLM's). Swallowed stub w/overshot @ 11126'. Prep for spaceout. Circulated Inhibited Seawater. Spaced out & landed hanger. RU SLU. RIH & pulled SSSV. Drifted tbg stub/overshot to 12000' - no bobbles. POOH. RIH w/RHC plug body. Set RHC plug & DSSSV. Set production packer. Good test on tubing & packer. Swapped out leaking DSSSV. FP'd well. ND BOP. RDMOL. 3S rig released 1700 hrs. Complete RDMOL. RIH w/SLU & tagged fill @ 12281' w/2.80". MIRU CTU#5 service unit. Work platform on location. Continued RU. PT'd BOPE (witnessed by AOGCC Rep). RIH & tagged BTM @ 12304'. Milled through junk / cement to 12428'. POOH w/BHA. RIH & milled pilot hole to 12442' & POOH. RIH & commenced milling window through the 7" liner. Milled window f/12440' - 12444'. Drilled FM to 12452'. POOH - indication of successful window milling. RIH w/Crayola mill & dressed window interval. Layed in FIo Pro. FP'd well. POOH. RDMOL service unit CTU. MIRU Nabors 3S. Rig accepted 1000 hrs. Sidetrack Summa~ Page I ,~ 18-07A DESCRIPTION OF WORK COMPLETED PRODUCTION TUBING SWAP / COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 4/18/2000: 4/19/2000: 4/20/2000: 4/21/2000: 4/22/2000: 4/23/2000: 4/24/2000: 4/25/2000 - 4/29/2000: 4/30/2000: 5/01/2000: 5/02/2000: 5/03/2000: 5/04/2000: 5/05/2000: 5/06/2000: Continued RU 3S. MIRU CTU#4, CTU on location 1100 hrs. RIH w/bi-centered bit & tagged BTM @ 12454' MD. Drilled to 12475' & performed LOT to EMW of 9.0 ppg. Drilled to 12503' & laid in LCM Pill. POOH. RIH w/lateral BHA & drilled to 12647' & lost all returns. Swapped over to Seawater & drilled ahead w/partial returns to 12927'. POOH. Circulated 30 bbl LCM pill down CT while RIH to BTM. Displaced pill w/FIo Pro mud & squeezed away 12 bbls into FM achieving 500-550 psi. POOH. RIH & cleaned out LCM pill. Survey indicates unexpected inclination @ 12600' - OH sidetracked @ +/- 12477', thereby leaving LCM plugback. Drilled to 12808'. Experienced 50% losses @ 12630' - swapped to KCL Water. Encountered fault @ 12780'. POOH. RIH w/CT nozzle & squeezed 20 bbl LCM plug. POOH w/CT. RIH & cleaned out LCM plug w/KCL Water. Began using FIo Pro & drilled to 12900' without losses. Drilled ahead using KCL Water to 12945' w/50% losses. POOH. RIH & squeezed LCM pill. POOH. RIH while cleaning out LCM pill & tagged 12603'. Reamed to 12932' w/severe sticking & packing off. POOH to plugback OH. RIH & spotted LCM pill into OH to 12250'. Squeezed 14 bbls into FM @ max press of 420 psi. Pumped 8 bbls Neat 17 ppg Class G Cement to plugback OH. Injector & reel stopped while laying in Cement @ 12280'. Adjusted controls & PUH to 11890' until lost all hydraulic power tc injector. Troubleshoot & attempted hydraulic repairs. Top drive failed internally. Cut coil & RD CTU#4 for repairs offsite. CTU off location 0600 hrs. CTU repairs. 3S on standby. CTU repairs. 3S on standby. MIRU CTU#4 (on location 2230 hrs). MU cold roll to existing pipe in hole. Began POOH w/CT. Completed POOH w/CT. Changed out CT reels. PT'd BOPE - AOGCC rep witnessed. RIH w/BHA & tagged up @ 12215'. Worked through to 12279' MD. RIH to window but unable to work through & POOH. RIH & milled to 12455' MD. POOH. RIH & drilled build section to 12495'. POOH. RIH & drilled to 12930'. Severe losses @ 12790'. Drilled w/KCL Water. Stuck & packing off @ 12920'. PUH to window. Conditioned OH. Drilled to 13019' & POOH. RIH & spotted LCM pill. POOH. RIH. Cleaned out LCM pill. Drilled to 13057' & POOH. RIH & drilled toTD @ 13300'. POOH. RIH w/nozzle & squeezed LCM pill f/13100' - 12750'. POOH holding 400 - 500 psi. RIH & cleaned out LCM pill & conditioned OH for liner run. POOH. MU 2-3/8" Liner. ~ .~.~.~. i~.,~..-, Sidetrack Summa~ Page 2 18-07A DESCRIPTION OF WORK COMPLETED PRODUCTION TUBING SWAP / COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 5/07/2000: 6/04/2000: 6/06/2000: 6/07/2000: 6/10~2000: 6/11/2000: 6/13/2000: 6/25/2000: 6/26/2000: 6/27/2000: 6/30/2000: 7/01/2000: 7/02/2000: RIH w/2-3/8" liner & landed it @ 13115'. TOL = 12214'. PBTD = 13113'. Circulated to establish rates. Dropped ball & released f/liner. Set back down on liner & cemented liner in place by pumping 12.5 bbls of 15.8 ppg Class G Cement. Unstung f/liner & contaminated cement w/Biozan. Jetted contaminated cement f/wellbore & cleaned out to PBTD. POOH. FP'd well. RDMOL. 3S released 0400 hrs. A Liner Top Cement Squeeze (attempt #1) was performed as follows: MIRU CTU & PT'd equip. Pumped 1% KCL Water & Crude down backside. RIH w/CT & stung into 2-3/8" Liner Top. Pumped 17 bbls of Class G Cement down backside of Liner & attained 1800 psi. Unstung f/Liner & contaminated remainig Cement w/Biozan, holding 650 psi. Cleaned out to the Liner Top. POOH w/CT. RD CTU. WOC. PT'd tubing to 1000 psi - bled to 0 psig in 15 min. Tubing leak rate test: 0.75 bpm @ 1000 psi. A 2nd Liner Top Cement Squeeze was performed as follows: MIRU CTU. PT'd equip. Performed injectivity test: 1.0 bpm @ 1100 psi, 1.5 bpm @ 1600 psi, & 2.0 bpm @ 1850 psi. RIH w/CT Cementing tool pumping 160° F 1% KCL Water. Stung into Liner Top. Pumped 23 bbls of Class G Cement down Liner backside. Attained 600 psi & placed 13 bbls of cement behind pipe. Unstung f/Liner & contaminated cement w/Biozan, cleaning out to 12060' in 3 passes. POOH. Left 400 psi on wellhead. RD CTU. WOC. MIT tubing failed. Tubing leak rate test: 0.5 bpm @ 1000 psi. A 3rd Liner Top Cement Squeeze was performed as follows: MIRU CTU. PT'd equip. Pumped 160° F 1% KCL Water down backside. RIH w/CT & Liner Top Cementing tool. Stung into Liner Top & pumped 28 bbls of 15.8 ppg Class G Cement. Saw small press increase then break back. Pumped an additional 26 bbls of Class G Cement & saw 100 psi increase before break back. Pumped 20 bbls of 13.8 ppg Class G Cement w/8% Bentonite & 0.59% D800 (lost circ plug). Saw 500 psi bump. Pumped Biozan & flushed remaining cement. Could not unsting f/liner. Pumped 10 bbls of Mud Acid but unable to unsting. Dropped ball, ball on seat, sheared disco but unable to pull CT free. Worked CT free by pumping Mud Acid and soaking. POOH & left stinger, flex joint, & bottom of HYD Disco in liner top as fish @ 12086'. RD. RIH & milled cement stringers to 12063'. RIH & milled cement to 12074'. Ran LIB - no impression. Attempted to retrieve fish. RIH w/overshot w/fishing motor & latched fish. POOH w/fish - all parts of liner top cementer tool recovered. PT'd liner to 1500 psi - lost 37 psi in 30 min. Sidetrack Summary Page 3 18-07A DESCRIPTION OF WORK COMPLETED PRODUCTION TUBING SWAP ! COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 7/06/2000: 7/07/2000: 7/2O~2OOO - 7/23~2000: MIRU CTU. PT'd equip. RIH & tagged obstruction @ 12475'. Milled to 12926'. Drifted to 12972' MD & POOH. RIH w/Mem CNL/GR/CCL logging tools. Logged f/11700' to 12475'. POOH w/logging tools. RIH w/Perf guns to PBTD & shot 82' of Initial Perforations f/: 12569'- 12600' MD (Zone lA) Reference Log: BHCS 9/29/1982. 12689' - 12740' MD (ZonelA) Used 1-9/16" carriers & shot all Perfs @ 4 SPF. POOH w/guns. ASF. FP'd well. RD. Performed GLV installation w/Slickline Unit. Placed well 18-07A on initial production & obtained a valid well test. Sidetrack Summary Page 4 8300 8400 8500 8600 8700 - 8800 89oo PHILLIPS Alaska, Inc. Structure : D.S. 18 Field : Prudhoe Boy Well : 18-07A, 50-029-20803-01 Location : North Slope, Alaska <- West (feet) Created by potnie Oote plotted ; 1-Jun-2000 Plot Refcrence is 18-07A. Coordlnotes ore in feet reference 1~,-07. True Vert[cel Oeptha ore reference RKR - klSL = 46 ft, Brij Potnis 267-6613 --- Baker Hu~hel INTEQ --- 10000 9800 9600 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 I I I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I '~ 18-07 T2 Projected to TO I 18-07A vii7 Plan ] 18-07 T3 TD- Projected to TD .~ Projected to lB ~ Projected to TO 18-07 T3 TD · 9000 I I i I I i i I I i I i I I I I i I I I I I I I t i I I i I I I i I I I i I I I i I i I 5800 5900 6000 61 O0 6200 6300 6400 6500 6600 6700 6800 6900 7000 71 O0 7200 7300 7400 7500 7600 7700 7800 7900 8000 Vertical Section (feet) -> Azimuth 302.00 with reference 0.00 N, 0.00 E from 18-.07 1200 1000 800 6o0 A I Z 400 0 200 --4- 0 200 400 600 PHILLIPS Alaska, Inc. D.S. 18 18-07A 18-07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-07A Our ref : svy353 License : 50-029-20803-01 Date printed : 1-Jun-2000 Date created : 1-Jun-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866' Reference North is True North PHILLIPS Alaska, Inc. D.S. 18,18-07A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 18-07A Last revised : 1-Jun-2000 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing- 12350.00 45.77 277.81 8670.72 12440.00 45.04 276.56 8733.91 12454.00 55.70 276.30 8742.83 12472.00 70.40 272.40 8750.96 12493.00 82.40 272.40 8755.89 248.23S 7242.72W 2.15 6010.63 684238.91 5960708.90 240.21S 7306.30W 1.28 6068.80 684175.15 5960715.29 239.01S 7317.00W 76.16 6078.51 684164.42 5960716.22 237.83S 7332.95W 83.90 6092.67 684148.44 5960716.99 236.97S 7353.31W 57.14 6110.38 684128.07 5960717.32 12532.00 83.50 272.70 8760.68 12571.00 86.50 268.50 8764.08 12617.00 91.10 270.30 8765.04 12666.00 91.40 278.40 8763.97 12704.00 90.60 285.00 8763.31 235.25S 7391.97W 2.92 6144.08 684089.38 5960718.06 234.85S 7430.81W 13.20 6177.23 684050.54 5960717.47 235.33S 7476.78W 10.74 6215.97 684004.60 5960715.82 231.62S 7525.59W 16.54 6259.32 683955.72 5960718.28 223.92S 7562.77W 17.49 6294.94 683918.35 5960725.03 12743.00 85.20 289.30 8764.74 12774.00 82.10 293.10 8768.17 12816.00 84.60 297.70 8773.03 12843.00 83.30 299.10 8775.88 12904.00 85.30 295.20 8781.94 212.43S 7599.99W 17.69 6332.59 683880.86 5960735.56 201.30S 7628.71W 15.76 6362.84 683851.87 5960745.96 183.41S 7666.38W 12.40 6404.27 683813.75 5960762.88 170.64S 7690.00W 7.05 6431.06 683789.82 5960775.05 142.95S 7743.99W 7.16 6491.53 683735.14 5960801.34 12940.00 84.00 291.00 8785.30 12975.00 79.50 287.50 8790.32 13026.00 83.50 284.00 8797.86 13067.00 86.80 285.00 8801.33 13117.00 93.07 291.37 8801.38 128.89S 7776.95W 12.16 6526.93 683701.83 5960814.56 117.47S 7809.64W 16.22 6560.70 683668.86 5960825.14 103.79S 7858.17W 10.37 6609.11 683620.00 5960837.58 93.56S 7897.72W 8.41 6648.06 683580.21 5960846.79 77.97S 7945.17W 17.87 6696.57 683532.38 5960861.16 13150.00 92.98 297.70 8799.64 13183.00 91.23 303.67 8798.43 13223.00 94.21 310.35 8796.53 13261.00 97.38 315.27 8792.69 13300.00 97.38 315.27 8787.68 64.30S 7975.13W 19.16 6729.23 683502.08 5960874.07 47.47S 8003.48W 18.84 6762.18 683473.31 5960890.16 23.44S 8035.36W 18.27 6801.95 683440.83 5960913.37 2.23N 8063.09W 15.35 6839.07 683412.46 5960938.33 29.71N 8090.31W 0.00 6876.72 683384.55 5960965.10 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 8090.36 on azimuth 270.21 degrees from wellhead. Vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. D.S. 18,18-07A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07A Last revised : 1-Jun-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 12350.00 8670.72 248.23S 7242.72W Tie-in Point 13300.00 8787.68 29.71N 8090.31W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 18-07 T1 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18-07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 PHILLIPS Alaska, Inc. D.S. 18 18-07APB2 18-07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes IN~fEQ Your ref : 18-07APB2 Our ref : s%q;338 License : 50-029-20803-71 Date printed : 1-Jun-2000 Date created : 28-Apr-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection tYlDe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North PHILLIPS Alaska, Inc. D.S. 18,18-07APB2 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 18-07APB2 Last revised : 1-Jun-2000 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing- 12350.00 45.77 277.81 8670.72 248.23S 7242.72W 2.15 6010.63 684238.91 5960708.90 12440.00 45.04 276.56 8733.91 240.21S 7306.30W 1.28 6068.80 684175.15 5960715.29 12449.00 51.60 276.56 8739.89 239.44S 7312.97W 72.89 6074.87 684168.45 5960715.89 12474.00 70.80 272.00 8751.88 237.90S 7334.71W 78.42 6094.13 684146.68 5960716.88 12500.00 83.10 282.60 8757.76 234.63S 7359.74W 61.71 6117.08 684121.58 5960719.50 12518.00 80.20 281.50 8760.37 230.91S 7377.16W 17.21 6133.82 684104.08 5960722.78 12558.00 74.30 281.20 8769.20 223.24S 7415.39W 14.77 6170.31 684065.66 5960729.47 12596.00 75.40 278.70 8779.13 216.90S 7451.51W 6.98 6204.30 684029.39 5960734.88 12617.00 78.40 278.70 8783.89 213.81S 7471.73W 14.29 6223.09 684009.10 5960737.46 12629.00 79.90 278.70 8786.15 212.03S 7483.38W 12.50 6233.91 683997.41 5960738.95 12664.00 84.20 278.70 8790.99 206.78S 7517.64W 12.29 6265.74 683963.03 5960743.31 12683.00 85.50 278.00 8792.69 204.04S 7536.36W 7.76 6283.07 683944.25 5960745.58 12714.00 87.40 284.30 8794.61 198.05S 7566.70W 21.19 6311.97 683913.77 5960750.79 12735.00 87.60 286.10 8795.53 192.55S 7586.94W 8.62 6332.06 683893.39 5960755.77 12754.00 88.20 287.50 8796.23 187.07S 7605.12W 8.01 6350.38 683875.08 5960760.79 12795.00 92.90 287.15 8795.83 174.86S 7644.25W 11.50 6390.03 683835.66 5960771.99 12825.00 92.60 290.30 8794.39 165.24S 7672.62W 10.54 6419.19 683807.05 5960780.88 12850.00 90.60 291.40 8793.69 156.35S 7695.97W 9.13 6443.71 683783.48 5960789.18 12884.00 87.50 289.30 8794.26 144.53S 7727.84W 11.01 6477.00 683751.32 5960800.18 12906.00 85.40 287.90 8795.62 137.52S 7748.65W 11.47 6498.35 683730.34 5960806.65 12948.00 85.40 287.90 8798.99 124.66S 7788.49W 0.00 6538.96 683690.19 5960818.50 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 7789.49 on azimuth 269.08 degrees from wellhead. Vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. D.S. 18,18-07APB2 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07APB2 Last revised : 1-Jun-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment ........................................................................................................... 12350.00 8670.72 248.23S 7242.72W Tie-in Point 12948.00 8798.99 124.66S 7788.49W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised ........................................................................................................... 18-07 TI 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18-07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 PHILLIPS Alaska, Inc. DoS. 18 18-07APB1 18-07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-07APB1 Our ref : svy337 License : 50-029-20803-70 Date printed : 1-Jun-2000 Date created : 28-Apr-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866' Reference North is True North PHILLIPS klaska, Inc. D.S. 18,18-07APB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 18-07APB1 Last revised : 1-Jun-2000 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 00 R D S C 00 R D I N A T E S Deg/100ft Sect Easting Northing- 12350.00 45.77 277.81 8670.72 12440.00 45.04 276.56 8733.91 12449.00 51.60 276.56 8739.89 12477.80 72.10 275.60 8753.41 12500.00 88.00 280.50 8757.23 248.23S 7242.72W 2.15 6010.63 684238.91 5960708.90 240.21S 7306.30W 1.28 6068.80 684175.15 5960715.29 239.44S 7312.97W 72.89 6074.87 684168.45 5960715.89 236.79S 7338.09W 71.24 6097.58 684143.28 5960717.90 233.71S 7359.66W 74.83 6117.'50 684121.64 5960720.42 12531.00 85.90 282.90 8758.88 12559.00 83.40 282.20 8761.49 12602.00 82.90 276.90 8766.62 12637.00 81.70 272.70 8771.32 12685.00 82.20 278.00 8778.04 227.44S 7389.97W 10.28 6146.53 684091.18 5960725.92 221.38S 7417.18W 9.27 6172.81 684063.83 5960731.28 214.30S 7459.26W 12.29 6212.26 684021.58 5960737.29 211.40S 7493.82W 12.38 6243.10 683986.96 5960739.31 206.96S 7541.12W 10.98 6285.56 683939.56 5960742.53 12707.00 81.10 281.00 8781.24 12762.00 80.90 282.20 8789.84 12791.00 82.80 280.10 8793.95 12813.00 86.20 280.50 8796.06 12866.00 92.00 281.50 8796.89 203.37S 7562.59W 14.39 6305.67 683918.01 5960745.57 192.45S 7615.80W 2.19 6356.58 683864.54 5960755.13 186.90S 7643.96W 9.71 6383.41 683836.25 5960759.96 182.99S 7665.50W 15.56 6403.75 683814.62 5960763.33 172.88S 7717.50W 11.10 6453.20 683762.38 5960772.10 12901.00 93.10 285.40 8795.34 164.75S 7751.50W 11.57 6486.34 683728.19 5960779.36 12925.00 93.10 285.40 8794.04 158.38S 7774.60W 0.00 6509.31 683704.93 5960785.14 Al/ data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 7776.22 on azimuth 268.83 degrees from wellhead. Vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. D.S. 18,18-07APB1 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07APB1 Last revised : 1-Jun-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 12350.00 8670.72 248.23S 7242.72W Tie-in Point 12925.00 8794.04 158.38S 7774.60W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 18-07 Ti 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18-07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 83O0 8400 8500 86o0 8700 8800 V 8900 PHILLIPS Alaska, Inc. Structure : D.S. 18 Field : Prudhoe Bay Well : 18-07A, 50-029-20803-01 Location : North Slope, Alaska <-- West (feet) Croci[ed by poilnla Dote plotted: 1-Jun-2000 Plot Reference is 11~-07A. Coordinates ore in feet reference 18-07. True Vcrt[col Depths are reference RKB - I'JSL = 46 ft. Brij Potnis 267-6613 --- Baker Hughes INT£Q 10000 9800 9600 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ORIGINAL 18-07 T3 TD. RECEIVED P,r°iectedt°TD I 18-07APB1 .~,x~ ~../ JUN 05 2000 . Projected to TO 18-07 T2 18-07 T1 Alaska Oil & Gas C0',qs. Commission Anchorage ~ __ ' Projected to TO Projected to · . TD ~ I.,a-OTA 18-07 T3 TD 9000 i i i i i i i i i i i i i i i i i i i t i i i i i i i i i i i i J i i i i i i i i i i 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 71 O0 7200 7300 7400 7500 7600 7700 7800 7900 8000 Vertical Section (feet) -> Azimuth 302.00 with reference 0,00 N, 0.00 E from 18-.07 1200 1000 800 6o0 A Z 400 0 200 ~ --4- 0 ~ 200 400 600 PHILLIPS Alaska, Inc. D.S. 18 18-07A 18-07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-07A Our ref : svy353 License : 50-029-20803-01 Date printed : 1-Jun-2000 Date created : 1-Jun-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866' Reference North is True North RECEIVED JUN 0 5 000 Alaska Oil & Gas CO'ns. Commission Anchorage PHILLIPS Alaska, Inc. D.S. 18,18-07A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 18-07A Last revised : 1-Jun-2000 Measured Inclin Azimuth Subsea Depth Degrees DeGrees Depth R E C T A N G U L A R DoGleG Vert G R I D C 00 R D S C 0 0 R D I N A T E S DeG/100ft Sect EastinG NorthinG- 12350.00 45.77 277.81 8670.72 12440.00 45.04 276.56 8733.91 12454.00 55.70 276.30 8742.83 12472.00 70.40 272.40 8750.96 12493.00 82.40 272.40 8755.89 248.23S 7242.72W 2.15 6010.63 684238.91 5960708.90 240.21S 7306.30W 1.28 6068.80 684175.15 5960715.29 239.01S 7317.00W 76.16 6078.51 684164.42 5960716.22 237.83S 7332.95W 83.90 6092.67 684148.44 5960716.99 236.97S 7353.31W 57.14 6110.38 684128.07 5960717.32 12532.00 83.50 272.70 8760.68 12571.00 86.50 268.50 8764.08 12617.00 91.10 270.30 8765.04 12666.00 91.40 278.40 8763.97 12704.00 90.60 285.00 8763.31 235.25S 7391.97W 2.92 6144.08 684089.38 5960718.06 234.85S 7430.81W 13.20 6177.23 684050.54 5960717.47 235.33S 7476.78W 10.74 6215.97 684004.60 5960715.82 231.62S 7525.59W 16.54 6259.32 683955.72 5960718.28 223.92S 7562.77W 17.49 6294.94 683918.35 5960725.03 12743.00 85.20 289.30 8764.74 12774.00 82.10 293.10 8768.17 12816.00 84.60 297.70 8773.03 12843.00 83.30 299.10 8775.88 12904.00 85.30 295.20 8781.94 212.43S 7599.99W 17.69 6332.59 683880.86 5960735.56 201.30S 7628.71W 15.76 6362.84 683851.87 5960745.96 183.41S 7666.38W 12.40 6404.27 683813.75 5960762.88 170.64S 7690.00W 7.05 6431.06 683789.82 5960775.05 142.95S 7743.99W 7.16 6491.53 683735.14 5960801.34 12940.00 84.00 291.00 8785.30 12975.00 79.50 287.50 8790.32 13026.00 83.50 284.00 8797.86 13067.00 86.80 285.00 8801.33 13117.00 93.07 291.37 8801.38 128.89S 7776.95W 12.16 6526.93 683701.83 5960814.56 117.47S 7809.64W 16.22 6560.70 683668.86 5960825.14 103.79S 7858.17W 10.37 6609.11 683620.00 5960837.58 93.56S 7897.72w 8.41 6648.06 683580.21 5960846.79 77.97S 7945.17W 17.87 6696.57 683532.38 5960861.16 13150.00 92.98 297.70 8799.64 13183.00 91.23 303.67 8798.43 13223.00 94.21 310.35 8796.53 13261.00 97.38 315.27 8792.69 13300.00 97.38 315.27 8787.68 64.30S 7975.13W 19.16 6729.23 683502.08 5960874.07 47.47S 8003.48W 18.84 6762.18 683473.31 5960890.16 23.44S 8035.36w 18.27 6801.95 683440.83 5960913.37 2.23N 8063.09W 15.35 6839.07 683412.46 5960938.33 29.71N 8090.31W 0.00 6876.72 683384.55 5960965.10 RECEIVED JUN 0 5 2000 Alaska Oil & Gas Cons. Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvatur~ method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 8090.36 on azimuth 270.21 degrees from wellhead. vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker HuGhes INTEQ PHILLIPS Alaska, Inc. D.S. 18,18-07A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07A Last revised : 1-Jun-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment ........................................................................................................... 12350.00 8670.72 248.23S 7242.72W Tie-in Point 13300.00 8787.68 29.71N 8090.31W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 18-07 TI 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18-07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 RECEIVED JUN 0 5 000 Aiask~ Oil & G~s Cons. Commission Anchorage PHILLIPS Alaska, Inc. D.S. 18 18-07APB2 18-07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-07APB2 Our ref : svy338 License : 50-029-20803-71 Date printed : 1-Jun-2000 Date created : 28-Apr-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection t~rpe: alaska - Zone 4, Spheroid: Clarke - 1866' Reference North is True North RECEIVED JUN 05 2000 Alaska 0il & 6as Cons. Commission Anchorage PHILLIPS Alaska, Inc. D.S. 18,18-07APB2 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 18-07APB2 Last revised : 1-Jun-2000 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing - 12350.00 45.77 277.81 8670.72 12440.00 45.04 276.56 8733.91 12449.00 51.60 276.56 8739.89 12474.00 70.80 272.00 8751.88 12500.00 83.10 282.60 8757.76 248.23S 7242.72W 2.15 6010.63 684238.91 5960708.90 240.21S 7306.30W 1.28 6068.80 684175.15 5960715.29 239.44S 7312.97W 72.89 6074.87 684168.45 5960715.89 237.90S 7334.71W 78.42 6094.13 684146.68 5960716.88 234.63S 7359.74W 61.71 6117.08 684121.58 5960719.50 12518.00 80.20 281.50 8760.37 12558.00 74.30 281.20 8769.20 12596.00 75.40 278.70 8779.13 12617.00 78.40 278.70 8783.89 12629.00 79.90 278.70 8786.15 230.91S 7377.16W 17.21 6133.82 684104.08 5960722.78 223.24S 7415.39W 14.77 6170.31 684065.66 5960729.47 216.90S 7451.51W 6.98 6204.30 684029.39 5960734.88 213.81S 7471.73W 14.29 6223.09 684009.10 5960737.46 212.03S 7483.38W 12.50 6233.91 683997.41 5960738.95 12664.00 84.20 278.70 8790.99 12683.00 85.50 278.00 8792.69 12714.00 87.40 284.30 8794.61 12735.00 87.60 286.10 8795.53 12754.00 88.20 287.50 8796.23 206.78S 7517.64W 12.29 6265.74 683963.03 5960743.31 204.04S 7536.36W 7.76 6283.07 683944.25 5960745.58 198.05S 7566.70W 21.19 6311.97 683913.77 5960750.79 192.55S 7586.94W 8.62 6332.06 683893.39 5960755.77 t87.07S 7605.12W 8.01 6350.38 683875.08 5960760.79 12795.00 92.90 287.15 8795.83 174.86S 7644.25W 11.50 6390.03 683835.66 5960771.99 12825.00 92.60 290.30 8794.39 165.24S 7672.62W 10.54 6419.19 683807.05 5960780.88 12850.00 90.60 291.40 8793.69 156.35S 7695.97W 9.13 6443.71 683783.48 5960789.18 12884.00 87.50 289.30 8794.26 144.53S 7727.84W 11.01 6477.00 683751.32 5960800.18 12906.00 85.40 287.90 8795.62 137.52S 7748.65W 11.47 6498.35 683730.34 5960806.65 12948.00 85.40 287.90 8798.99 124.66S 7788.49W 0.00 6538.96 683690.19 5960818.50 RECEIVED JUN 0 5 2000 Alaska Oil & Gas Cons. Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 7789.49 on azimuth 269.08 degrees from wellhead. Vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS A~aska, Inc. D.S. 18,18-07APB2 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07APB2 Last revised : 1-Jun~2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 12350.00 8670.72 248.23S 7242.72W Tie-in Point 12948.00 8798.99 124.66S 7788.49W Projected to TD Targets associated with this wellpath ======================= Target name Geographic Location SSTVD Rectangular Coordinates Revised 18-07 T1 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18~07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 RECEIVED JUN 0 5 000 Alaska Oil & G~s Cons. Oommission Anchorage PHILLIPS Alaska, Inc. D.S. 18 18 - 07APB1 18 -07 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 18-07APB1 Our ref : svy337 License : 50-029-20803-70 Date printed : 1-Jun-2000 Date created : 28-Apr-2000 Last revised : 1-Jun-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 691735.638,5961867.841,999.00000,N Slot location is n70 17 54.244,w148 26 57.354 Slot Grid coordinates are N 5961141.830, E 691472.509 Slot local coordinates are 719.10 S 281.58 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED JUN 0 5 Alaska Oil & (~as Cons. Commission Anchorage PHILLIPS Alaska, Inc. D.S. 18,18-07APB1 Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth RECTANG COORDIN 12350.00 45.77 277.81 8670.72 12440.00 45.04 276.56 8733.91 12449.00 51.60 276.56 8739.89 12477.80 72.10 275.60 8753.41 12500.00 88.00 280.50 8757.23 248.23S 240.21S 239.44S 236.79S 233.71S 12531.00 85.90 282.90 8758.88 12559.00 83.40 282.20 8761.49 12602.00 82.90 276.90 8766.62 12637.00 81.70 272.70 8771.32 12685.00 82.20 278.00 8778.04 227.44S 221.38S 214.30S 211.40S 206.96S 12707.00 81.10 281.00 8781.24 12762.00 80.90 282.20 8789.84 12791.00 82.80 280.10 8793.95 12813.00 86.20 280.50 8796.06 12866.00 92.00 281.50 8796.89 203.37S 192.45S 186.90S 182.99S 172.88S 12901.00 93.10 285.40 8795.34 12925.00 93.10 285.40 8794.04 164.75S 158.38S SURVEY LISTING Page 1 Your ref : 18-07APB1 Last revised : 1-Jun-2000 U L A R Dogleg Vert G R I D C O O R D S A T E S Deg/100ft Sect Easting Northing' 7242.72W 2.15 6010.63 684238.91 5960708.90 7306.30W 1.28 6068.80 684175.15 5960715.29 7312.97W 72.89 6074.87 684168.45 5960715.89 7338.09W 71.24 6097.58 684143.28 5960717.90 7359.66W 74.83 6117.50 684121.64 5960720.42 7389.97W 10.28 6146.53 684091.18 5960725.92 7417.18W 9.27 6172.81 684063.83 5960731.28 7459.26W 12.29 6212.26 684021.58 5960737.29 7493.82W 12.38 6243.10 683986.96 5960739.31 7541.12W 10.98 6285.56 683939.56 5960742.53 7562.59W 14.39 6305.67 683918.01 5960745.57 7615.80W 2.19 6356.58 683864.54 5960755.13 7643.96W 9.71 6383.41 683836.25 5960759.96 7665.50W 15.56 6403.75 683814.62 5960763.33 7717.50W 11.10 6453.20 683762.38 5960772.10 7751.50W 11.57 6486.34 683728.19 5960779.36 7774.60W 0.00 6509.31 683704.93 5960785.14 RECEIVED JUN 0 5 Alaska Oil & Gas Cons. Commission Anchorage data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 18-07 and SSTVD from RKB - MSL = 46 ft. Bottom hole distance is 7776.22 on azimuth 268.83 degrees from wellhead. Vertical section is from wellhead on azimuth 302.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS ~tlaska, Inc. D.S. 18,18-07APB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 18-07APB1 Last revised : 1-Jun-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 12350.00 8670.72 248.23S 7242.72W Tie-in Point 12925.00 8794.04 158.38S 7774.60W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 18-07 T1 683993.000,5960681.000,999.00 8790.00 269.84S 7489.27W 1-Feb-2000 18-07 T2 683760.000,5960777.000,999.00 8810.00 167.92S 7719.76W 1-Feb-2000 18-07 T3@TD 682790.000,5961550.000,999.00 8785.00 629.62N 8669.77W 1-Feb-2000 RECEIVED -JUN 0 5 000 A~aska Oil & G~s CoDs. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~,/~ Chairman DATE: May 1, 2000 THRU: Blair Wondzell, .~~ SUBJECT: P. I. Supervisor FROM: John H Spauldin~,~_ Petroleum Inspecfor BOPE Test Phillips Alaska Inc. Nabors 3S / DS4 PTD 200-014 May 1, 2000: I traveled this date to Phillips Alaska Inc well 18-07a to witness the BOPE test on Nabors 3S / DS4 coiled tubing drilling rig. The AOGCC BOPE test report is attached for reference. One of the hydraulic motors had failed 6 days prior to this date. The well was circulated the whole time that DS waited on parts. The unit was repaired and all items tested well. No failures were observed. SUMMARY: I witnessed the BOPE test on; Nabors 3S / DS4, o failures, 4 hours Attachment: BOP nabor 3s-ds4 5-1-00js STATE OF ALASKA OIL A,,O GAS CONSERVATION COMMI$olON Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors / DS Operator: Phillips Well Name: 18-07A Casing Size: Set @ Test: Initial Weekly DATE: 5/'1/00 Rig No. 3S/4 PTD# 200-014 Rig Ph,# 659-5514 Rep.: Steve Brad/ey Rig Rep,: Pau/Haynes Location: Sec, 24 T, 11N R, 14E Meridian UM X Other BOP STACK: Quan. Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Test Test Pressure P/F Pressure P/F 35O/35OO P 1 350/3500 P I 350/3500 P 250/2500 P slip rams P 35O/35OO P 350/35OO P 350/3500 P 350/3500 P CHOKE MANIFOLD: Quan. No. Valves 12 No. Flanges 32 Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: 35O/3500 P P Func~oned Func~oned Nitgn. Btl's: 4@2100 avg. 2,950 I P 1,800 P minutes 15 sec. minutes 47 sec. X Remote: X MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank ok ok Location Gen.: Pit Level Indicators ok ok Housekeeping: Meth Gas Detector ok ok Permit to drill: H2S Gas Detector ok ok Standing Order Posted Psig. ok Well Sign yes ok Drl, Rig ok Hazard Sec, Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested '/8 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES x NO 24 HOUR NOTICE GIVEN YES x NO Waived By: Witnessed By: Form Revised 2/20/97 L.G. BOP NABORS-DS 35-4 5-1-00JS1 5/3/00 Re: [F.v,,d: DS 15-13A & 18-07A change in Bop St .... ~.onfigumtion] Subject: Re: [Fwd: DS 15-13A & 18-07A change in Bop Stack configuration] Date: Tue, 22 Feb 2000 12:06:38 -0900 From: Tom Maunder <torn_maunder@admin.state.ak.us> Internal To: Bruce E Smith <BESMITH@mail.aai.arco.com>, Mark O Johnson <Mark O Johnson~mail.aai.arco.com>, 3S Supervisor PRB <P 1023@mail.aai.arco.com>, Stephen L Ward <SWARD@mail.aai.arco.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us>, AOGCC North Sope Office <aogcc__prudhoe_bay@admin.state.ak. us>, John Spaulding <john_spaulding@admin.state.ak.us> Gentlemen: Blair is presently out on vacation. I have looked at the files we have regarding these wells and have talked to the rig to determine the schedule of activities. I understand that 3S could be moving to 15-13 as early as late today and then on to 18-07. In each case, the only work planned for 3S will involve replacing the existing tubing string on each well. The actual sidetracks will take place at a later date. As such all work will be under the authority of the respective sundries 399-252 for 15-13 and 300-036 for 18-07. From talking to Steve at the rig, I understand that the service coil has plugged 15-13 so the rig will be essentially moving onto a dead well. From my reading of what we have received on 18-07, it will likewise be plugged and abandoned when 3S moves on. The work proposed is essentially a workover and the 3 preventer stack you plan is one used routinely by 4ES at Milne. The only difference is they run the blind rams on top of rather than below the spool. I understand from conversations with Steve and Mark that the preference is to run the blinds on the bottom so that the spool is available for circulation if the pipe rams are closed. Given the work planned, this stack change and arrangement is acceptable for pulling the tubing on 15-13 and 18-07. No open hole operations may be performed with this arrangement. Please contact me at 793-1250 if further information is needed. Tom Maunder Petroleum Engineer AOGCC Blair Wondzell wrote: Subject: Re: DS 15-13A & 18-07A change in Bop Stack configuration Date: Sat, 19 Feb 2000 10:13:32 -1000 From: "3S Supervisor PRB" <PlO23~mail.aai.arco.com> To: blair wondzell~admin.state.ak.us -- CC: "Bruce E Smith" <BESMITHSmail.aai.arco.com>, "Stephen L Ward" <SWARDSmail. aai. arco. com>, "Mark 0 Johnson" <Mark 0 Johnson~mail . aai . arco. com> Blair, As per Steve Ward's note below, we will be nippling up the 13-5/8" suack to do the workovers on Wells !5-13A and 18-07A. However, after measuring the wellhead heights, Nabors Rig 3S rig floor elevation, and the height of the BOP stack, we do not have enough distance under the rig floor to be able to rig up 2 sets of pipe rams. The configuration that we will have to nipple up is as follows: Annular Preventer Pipe Rams Mud Cross (kill and choke lines) 1 of 3 3/14/00 3:29 PM DS 157,3A & 18-07A change in Bop Stack config- .... ')n _-_ Subject: DS 15-13A & 18-07A change in Bop Stack configuration Date: Thu, 17 Feb 2000 11:03:55 -1000 From: "Stephen L Ward" <SWARD~mail.aai.arco.com> To: blair_wondzell~,admin, state.ak.us CC: "Bruce E Smith" <BESMITH@mail.aai.arco.com>, "Mark O. Johnson" <MOJ@mail.aai.arco.com> Blair-- As per the permit to drill, AAI is going to perform tubing changeout workovers on 15-13( Permit # 199-124) and 18-07(submitted 2/03/00) prior to sidetracking operations (Coiled Tubing Sidetracks). However, in order to perform this operation, the Nabors 3S rig will have to utilize a 13 5/8" BOP stack configured as follows: Annular Preventor Pipe & Blind dual rams Flow cross (kill and choke lines) pipe rams This BOP stack was not included in both permits to drill. Only a 7 1/16" drilling stack was included in the permit request. Can you approve the above mentioned BOP stack for the workover operations? For the subsequent sidetrack operations, the 7 1/16" stack will be utilized. If we can provide further information please call me (265-1305) or Mark O. Johnson 265-1661 . Thanks Steve Ward 1 of 1 2/17/00 1:29 PM Re; [F;.vd: DS 15-13A & 18-07A change in Bop S~---' configuration] Blind Rams Please let us know if this is acceptable. Thanks, Steve Bradley ARCO Rig Supervisor 659-5515 Bruce E Smith 02/19/2000 09:02 AM To: 3S Supervisor PRB/AAI/ARCO~ARCO cc: Subject: DS 15-13A & 18-07A change in Bop Stack configuration Forwarded by Bruce E Smith/AAI/ARCO on 02/19/2000 09:02 AM Stephen L Ward 02/1 7/2000 11:03 AM To: blair wondzell~admin.state.ak, us cc: Bruce E Smith/AAI/ARCOSARCO, Mark O. Johnson/AAI/ARCOSARCO Subject: DS 15-13A & 18-07A change in Bop Stack configuration Blair-- As per the permit to drill, AAI is going to perform tubing changeout workovers on 15-13( Permit # 199-124) and 18-07(submitted 2/03/00) prior to sidetracking operations (Coiled Tubing Sidetracks). However, in order to perform this operation, the Nabors 3S rig will have to utilize a 13 5/8" BOP stack configured as follows: Annular Preventor Pipe & Blind dual rams Flow cross (kill and choke lines) pipe rams This BOP stack was not included in both permits to drill. Only a 7 1/16" drilling stack was included in the permit request. Can you approve the above mentioned BOP stack for the workover operations? For the subsequent sidetrack operations, the 7 1/16" stack will be utilized. If we can provide further information please call me (265-1305) or Mark O. Johnson 265-1661 . Thanks Steve Ward Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 3 3/14/00 3:29 PM TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPlPlISSION 3001 PORCUPINF DRIVE ANCHORAGE. ALASKA 9950} -3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Bruce E. Smith, P.E. AAI Coil Tubing Drilling Supe~'isor ARCO Alaska, Inc. P O Box 100360 Anchorage, ,4142 99510-0360 Re: Prudhoe Bay Unit 18-07A ARCO Alaska, Inc. Permit No: 200-014 Sur Loc: 717'FNL, 280'FEL, Sec. 24, T11N, RI4E, UM Btmhole Loc. 97'FNL, 3676'FEL. Sec. 23, T11N, R14E. Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincy, r.e,ly, . // Robert N. Christenson. P.E. Chair BY ORDER OF TH OMMISSION DATED this 7-~ day of March, 2000 dlf/Enclosures Department of Fish & Gamc. Habitat Scction xv/o cncl. Department of Environmcntal Conservation ~v/o encl. ARCO Alaska, Post Office Anchorage, Alaska 99519-6105 · t-KD ~VIJK~. IJE. VEJ~VlTM February 29, 2000 Mr. Robert N. Christenson, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Mr. ChrJsten$on: ARCO Alaska, Inc. requests a short turnaround approval of the attached Permit to Drill for the Drill Site 18-07A sidetrack. The DS 18-07A permit was originally requested for March 31, 2000. Due to schedule constraints, we anticipate moving in and rigging up around March 8'". We request the permit be returned to us by March 7. Your immediate attention would be greatly appreciated. If you have any questions, please contact Bruce Smith at 263-4572. Sincerely, ~ Coiled Tubing Drilling Supevisor Arco Wells Group Cc: Paul Rau[ ATe-1509 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 i - I la. Type of work: Drill F! Redrill IvI lb. Type of well. Exploratory FI StratigraphicTest [-1 Development Oil I~l Re-entry D Deepen FI Service D Development Gas D Single Zone l~l Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 46 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28307 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAO 25.0251) 717' FNL, 280' FEL, Sec. 24, Tll N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1260' FNL, 1779' FEL, SEC. 23, T11 N, R14E, UM 18-07A #U-630610 At total depth 9. Approximate spud date Amount 97' FNL, 3676' FEL, Sec 23, T11N, R14E, UM March 31, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) ADL 028306, 1609' @ TD feetI No Close Approach feet 2560 14145 MD/883] TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 12442' MD Maximum hole angle 93° Maximum surface 2527 psig At total depth (TVD) 3407 psi~ @ 8800' 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~e data/ 3" 2-3/8" 4.6 L-80 FL4S 1844' 12301' 8683' 14145' 8831' 10 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 12646 feet Plugs (measured) Tagged PBTD @ 12509' MD on 11/15/1999. true vertical 8926 feet Effective Depth: measured 12509 feet Junk (measured) true vertical 8829 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 79' 20" 1900# Poleset 79' 79' Surface -2451' 13-3/8" 1670 Sx Fondu & 400 Sx PFC 2497' 2497' Production 11485' 9-5/8" 500 Sx Class G & 300 Sx PFC 11531' 8190' Liner 1440' 7" 400 Sx Class G 12646' 8926' Per/oration depth: measured 12370'- 12390'; 12420'- 12518'. truevertlcal 8731'-8745'; 8766'-8835'. 0 R I ~! NA L 20. Attachments Filing fee I~l Property Plat FI BOP Sketch D Diverter Sketch FI Drilling program [] Ddlling fluid program Time vs depth plot FI Refraction analysis l'-I Seabed report L--1 20 AAC 25.050 requirements I--I 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Johnson @ 265-1661. Signed BJ~~E~.E.~ /~L,~..~~ Title: AAl Coil Tubing Drilling Supervisor Date .... ' t'1¢ '~ Prepared by PaD/Rauf 263-4990 Commission Use Only Permit Number~ -_ I I JSee cover letter i~/V APl number Approval d~te 50- ~:~--~:~ '~ ~) ~(~ ~'- ~ jr j~'~ .-- I~)O Ifor other requirements Conditions of approval Samples required M Yes /~ .o Mud logrequired FI Yes ~ .o Hydrogen sulfide rneasures ~Yes FI No Directional survey required [~' Yes D Required working pressure for BOPE FI2M; FI 3M; ~ 5M; FI 10M;FI 1'~13500 psi for CTU''~'' Other. ORIGINAL SIGNED BY Robert N. Christenson by order of .[T,~ 0 ? ~000 Approved by Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 18-07A CT Sidetrack and Completion Intended Procedure Objective · Plug back existing wellbore. Mill window off of cement ramp. · Directionally drill a horizontal well from the existing wellbore. · Complete with 2 3/8" cemented liner. · Perforate and produce. Intended Procedure 1. P&A existing interval. 2. Replace 4 ½" production tubing from 11163' to surface due to corrosion. 3. Mill out 3 ½" XN nipple to 2.80". Mill 2.80" window off of cement ramp in 7" casing at 12442' with service coil tubing unit (ARCO work platform with drilling BOP stack) or with coiled tubing drilling rig. 4. Drill 2.75" x 3" build section + 100' to near horizontal. Drilling fluid will be 8.5 ppg FloPro. Leak off test to 9.0 ppg (0.5 ppg over mud weight). 5. Drill 2.75" x 3" horizontal section _+1600'. 6. Run and cement 2 3/8" FL4S liner. 7. Run CNL log. 8. Perforate -1000'. 9. Displace well with crude to top of liner. 10. RDMO. Drilling cuttings will be disposed of at G&I.. Drilling fluids will be injected into disposal wells at Pad 3 or G&I. MOJ 02/03/2000 REC£1VED Gas Cons. commission Anchorage DS 18-07a Potential Drilling Hazards Post on Rig · H2S production measured at 6 ppm in 12/96. Ensure all H2S monitoring equipment is operational. · BHP 3407 psi at 8800' SS (7.5 ppg EMW), BHT 190 °F (11/29/99 SBHPS). No over pressured zones are anticipated. · Maximum anticipated WHP with full column of gas: 2527 psi. · No major faults are anticipated in wellbore path. Two small faults (-20' throw) are planned to be crossed. Rig will have LCM on location for use if lost circulation occurs (not expected). The well will be drilled with 8.5 ppg mud. MOJ 02/02/2000 RECEIVED FE. 07 000 Naska Oil & Gas Cons. commiSSiOn Anchorage DS CT HORIZC ;IDETRACK Chem Cut @ 11163' 9-5/8" x 4-1/2" Baker SAB Packer @ 11173' 4-1/2",12.6#, L-80 Plastic Coated Tubing to Surface Top of 7" Liner @ 11206' 9-5/8" Shoe @ 11531' XO @ 12215' 3-1/2", 9.6#, L-80 Plastic Coated Tubing Top of 2-3/8" Liner @ t2301~ (proposed) 7", 29# L-80 Casing Straddled Perfs f/ 12370' - 12390' , @ , .W~ndow 12442 Baker F-1 Packer @ 12403' Zone 1 3" Open hole 3-1/2" Tubing Tail @ 12424' ELM 7" Liner & Perfs P&A'd with 17 ppg Cement 2-3/8 FL4S Liner Cemented & Perforated TD @ 14145' 7" Shoe @ 12646' ARCO Plan.xlt .. 8300 - - 8,100 - _ 8500 -- - 86O0- 880t) 8900 Structure : O.S. 18 Well : 18-07A Plan, 50-029-20803-01i Field Prudhoe Bay : Location : North Slope, Alaska <- West (feet) 9800 D,lO0 9200 9000 8800 BGO0 8,100 8200 8000 7800 7600 7400 Plut R,,t,,rnnc,~ i, Ift-07A V~uMon~2, Irun Vnrdcol D~l,thrl ¢~,~ r~.,.nc. RKB - MT;L *, 46 --- t~oker Hugh.l INI'[O --- j 7200 7000 680O 6600 64O0 Z--b.--I .... L-~---L,--2 ---J .... 'T'D b90o 00(I0(;100b200 630O b400 69OO 660O 67O0 6800 6900 1000 ?100 7200 730O 74O0 7L,00 7[;00770O 78O0 7900 8OO0 8100 Vertical Section (feet) -> Azimuth ,.302,00 with reference 0,00 N, 0,00 E from 18-07 4o0 A Z 200 0 0 ~ -,. 200 ~ Prepared by BHI 02/03/2000 Proposal Calculations ~G~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Alask% Inc. Vertical Sect. Plane: 302.000 TRUE Job No: 0 Field: Prudhoe Bay~ Alaska Mag. Declination: 27.350 AFE No: 0 Well: 18-07A Version#2 Grid Correction: 1.460 API No: 50-029-20803-01 Rig: Nabors 3S Total Correction: 25.890 BHI Rep: 0 Surface Location Dip: $0.740 Job Start Date: 00-Jan-00 X: 691472.5 RKB Height: 46.000 Job End Date: 00-Jan-00 Y: 5961141.8L,~ / Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. (Y) Dep. (X) Lat. (Y) Det~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 12350.00 45.77 277.81 8670.72 -248.23 -7242.72 5960708.90 684238.91 0.00 6010.63 140.00 0.00 0.00 Tie-in Point 12375.00 45.52 278.10 8688.20 -245.76 -7260.42 5960710.92 684221.15 1'.28 6026.96 139.00 -1.00 1.16 12400.00 45.28 278.39 8705.75 -243.20 -7278.04 5960713.02 684203.47 1.28 6043.25 -101.00 -0.96 1.16 12425.00 45.13 277.30 8723.36 -240.78 -7295.61 5960714.99 684185.84 3.15 6059.44 -100.00 -0.60 -4.36 12442.00 45.04 276.56 8735.37 -239.33 -7307.56 5960716.14 684173.86 3.15 6070.34 0.00 -0.53 -4.35 Kick-off Point 12450.00 48.64 276.56 8740.84 -238.66 -7313.36 5960716.66 684168.05 45.00 6075.61 0.00 45.00 0.00 12475.00 59.89 276.56 8755.42 -236.35 -7333.49 5960718.46 684147.87 45.00 6093.91 0.00 45.00 0.00 12500.00 71.14 276.56 8765.76, -233.76 -7356.05 5960720.47 684125.24 45.00 6114.42 0.00 45.00 0.00 12525.00 82.39 276.56 8771.48 -230.98 -7380.19 5960722.63 684101.04 45.00 6136.36 0.00 45.00 0.00 12530.80 85.00 276.56 8772.11 -230.32 -7385.92 5960723.14 684095.30 45.00 6141.56 -72.00 45.00 0.00 3 12550.00 85.82 273.981 8773.65 -228.57 -7404.98 5960724.41! 684076.21 14.04 ~158.65 -72.00 4.27 -13.44 12575.00 86.91 270.64~ 8775.23 -227.56 -7429.90 5960724.78 684051.27 14.04 6180.33 -71.00 4.36 -13.36 12600.00 88.00 267.30 8776.35 -228.01 -7454.87 5960723.69 684026.32 14.04 6201.26 90.00 4.36 -13.36 4 12625.00 88.00 270.83 8777.22 -228.42 -7479.85 5960722.65 684001.36! 14.09 6222.23 90.00 0.00 14.12 __ 12650.00 88.00 274.35 8778.09 -227.29 -7504.80 5960723.14 683976.39 14.09 6243.99 118.00 0.00 14.08 5 12675.00 86.32 277.43 8779.33 -224.73 -7529.63 5960725.06 683951.50 14.02 6266.40 118.00 -6.72 12.32 12700.00 84.64 280.52 8781.30 -220.85 -7554.25 5960728.32 683926.80 14.02 6289.34 118.00 -6.72 12.36 12725.00 82.99 283.63 8784.00 -215.65 -7578.55 5960732.89 683902.37 14.02 6312.70 118.00 -6.60 ~2.44 12740.001 82.00 285.50 8785.96 -211.91 -7592.94 5960736.26 683887.89 14.02 6326.89 180.00 -6.60 12.47 6 12750.00 80.60 285.50 8787.47 -209.27 -7602.47 5960738.66 683878.30 14.00 6336.36 180.00 -14.00 0.00 12775.00 77.10 285.50 8792.30 -202.72 -7626.10 5960744.61 683854.51 14.00 6359.88 180.00 -14.00 0.00 12790.00 75.00 285.50 8795.92 -198.83 -7640.13 5960748.14 683840.39 14.00 6373.84 13.00 -14.00 0.00 7 12800.00 76.36 285.84 8798.39 -196.21 -7649.46 5960750.52 683831.00 14.01 6383.13 13.00 13.60 3.40 12825.00 79.77 286.68 8803.56 -189.36 -7672.93 5960756.77 683807.35 14.01 6406.67 13.00 13.64 3.36 12850.00 83.18 287.49 8807.27 -182.10 -7696156 5960763.42 683783.55 14.01 6430.56 13.00 13.64 3.24 12875.00 86.59 288.30 8809.50 -174.45 -7720.25 5960770.47 683759.67 14.01 6454.71 13.00' 13.64 3.24 12900.00 90.00 289.10 8810.24 -166.44 -7743.92 5960777.87 683735.81 14.01 6479.02 88.00 13.64 3.20 8 12925.00 90.03 290.62 8810.24 -157.94 -7767.43 5960785.76 683712.09 6.08 6503.46 88.00 0.12 6.08 12950.00 90.06 292.14 8810.22 -148.83 -7790.71 5960794.28 683688.59 6.08 6528.03 88.00 0.12 6.08 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (~) Lat. (Y) Dep. (X) Lat. (Y) DeF. (X) (°/100ft) (Wellhead) (°/100ft) (°/100f0 12975.00 90.08 293.66 8810.19 -139.10 -7813.74 5960803.41 683665.32 6.08 6552.72 88.00, 0.08 6.08 13000.00 90.11 295.18 8810.14 -128.77 -7836.50 5960813.16 683642.30 6.08 6577.50 88.00 0.12 6.08 13025.00 90.14 296.70 8810.09 -117.83 -7858.98 5960823.52 683619.55 6.08 6602.36 88.00 0.12 6.08 13050.00 90.17 298.22 8810.02 -106.30 -7881.17 5960834.48 683597.08 6.08 6627.28 88.00 0.12 6.08 13075.00 90.20' 299.74 8809.94 -94.19 -7903.03 5960846.03 683574.91 6.08 6652.24 88.00 0.12 6.08 13100.00 90.22 301.26 8809.85 -81.50 -7924.57 5960858.16 683553.06! 6.08 6677.23 88.00 0.08 6.08 13125.00 90.25 302.78 8809.74 -68.25 -7945.77 5960870.87 683531.53: 6.08 6702.23 88.00 0.12 6.08 13150.00 90.28 304.30 8809.63 -54.44 -7966.61 5960884.15 683510.35 6.08 6727.22 88.00 0.12 6.08 13175.00 90.31 305.82 8809.50 -40.08 -7987.07 5960897.98 683489.53 6.08 6752.18 88.00 0.12 6.08 13200.00 90.33 307.34 8809.36 -25.18 -8007.14 5960912.36 683469.08 6.08 677~.10 88.00 0.08 6.08 13225.00 90.36 308.86 8809.21 -9.75 -8026.82 5960927.28 683449.02 6.08 6801.96 88.00 0.12 6.08 13250.00 90.39 310.38 8809.05 6.19 -8046.07 5960942.72 683429.37 6.08 6826.74 89.00 0.12 6.08 13275.00 90.41 311.90 8808.87 22.64 -8064.90 5960958.68 683410.13 6.08 6851.42 89.00 0.08 6.08 13300.00 90.44 313.42 8808.69 39.58 -8083.28 5960975.14 683391.32 6.08 6875.99 89.00 0.12 6.08 13325.00 90.46 314.94 8808.49 57.00 -8101.21 5960992.10 683372.95 6.08 6900.42 89.00 0.08 6.08 13350.00 90.49 316.46 8808.28 74.89 -8118.67 5961009.54 683355.04 6.08 6924.71 89.00 0.12 6.08 13375.00 90.52 317.98 8808.06 93.24 -8135.65 5961027.45 683337.60 6.08 6948.83 89.00 0.12 6.08 13400.00 90.54 319.50 8807.83 112.03 -8152.13 5961045.81 683320.65 6.08 6972.77 89.00 0.08 6.08 13425.00 90.56 321.02 8807.59 131.25 -8168.12 5961064.62 683304.18 6.08 6996.51 89.00 0.08 6.08 13450.00 90.59 322.54 8807.34 150.89 -8183.58 5961083.86 683288.22 6.08 7020.03 89.00 0.12 6.08 13475.00 90.61 324.06 8807.08 170.94 -8198.52 5961103.51 683272.77 6.08 7043.32 89.00 0.08 6.08 13500.00 90.63 325.58 8806.81 191.37 -8212.92 5961123.57 683257.86 6.08 7066.36 89.00 0.08 6.08 13525.00 90.'66 327.10 8806.52 212.17 -8226.7~ 5961144.01 683243.48 6.08 7089.14 89.00 0.12 6.08 13550.00 90.68 328.62 8806.23 233.34 -8240.07 5961164.83 683229.64 6.08 7111.63 89.00 0.08 6.08 13569.39 90.70 329.80 8806.00 250.00 -8250.00 5961181.23 683219.30 6.08 7128.88 -85.00 0.10 6.09 9 13575.00 90.72 329.46 8805.93 254.84 -8252.83 5961186.00 683216.34 6.16 7133.85 -85.00 0.36 -6.06 13600.00 90.85 327.92 8805.59 276.19 -8265.83 5961207.01 683202.81 6.16 7156.18 -85.00 0.52 -6.16 13625.00 90.98 326.39 8805.19 297.i9 -8279.38 5961227.66 683188.72 6.16 7178.80 -85.00 0.52 -6.12 13650.00 91.11 324.85 8804.73 317.82 -8293.50 5961247.92 683174.09 6.16 7201.71: -85.00 0.52 -6.16 13675.00 91.24 323.32 8804.22 338.06 -8308.16 5961267.78 683158.91 6.16 7224.87 -85.00 0.52 -6.12 13700.00 91.36 321.78 8803.65 357.91 -8323.36 5961287.23 683143.22 6.16 7248.27 -8~.00 0.48 ~6.16 13725.00 91.49 320.24 8803.03 377.33 -8339.08 5961306.24 683127.00 6.16 7271.90 -85.00 0.52 -6.16 13750.001 91.61 318.71 8802.3~ 396.33 -8355.32 5961324.82 683110.29 6.16 7295.73 -85.00 0.48 -6.12 13775.00 91.73 317.17 8801.63 414.88 -8372.06 5961342.94 683093.08 6.16 7319.76 -85.00 0.48 -6.16 13800.00 91.85 315.64 8800.85 432.98 -8389.29 5961360.59 683075.39 6.16 7343.96 -85.00 0.48 -6.12 13825.00 91.97 314.10 8800.01 450.60 -8406.99 5961377.75 683057.24 6.16 7368.32 -85.00 0.48 -6.1~ 13850.00 92.09 312.56 8799.12 467.75 -8425.17 5961394.43 683038.64 6.16 7392.82 ~85.00 0.48 -6.16 13875.00 92.21 311.03 8798.19 484.40 -8443.79 5961410.60 683019.60 6.16 7417.43 -85.00 0.48 -6.12 13900.00 92.32 309.49 8797.20 500.54 -8462.86 5961426.25 683000.13 6.16 7442.15 -85.00 0.44 -6.16 13925.00 92.44 307.95 8796.16 516.16 -8482.34 5961441.37 682980.25 6.16 7466.96 -85.00 0.48 -6.16 13950.00 92.55 306.41 8795.07 531.26 -8502.24 5961455.95 682959.98 6.16 7491.83 -85.00 0.44 -6.16 13975.00 92.66 304.88 8793.94 545.81 -8522.54 5961469.98 682939.32 6.16 7516.~6 -85.00 0.44 -6.12 14000.00 92.77 303.34 8792.75 559.81 -8543.21 5961483.45 682918.29 6.16 7541.71 -86.00 0.44 -6.16 14025.00 92.87 301.80 8791.52 573.26 -8564.25 5961496.35 682896.92 6.16 7566.68 -86.00 0.40 -6.16 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. (Y) De[~. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 14050.00 92.98 300.26 8790.25 586.13 -8585.65 5961508.67 682875.20 6.16 7591.64 -86.00 0.44 -6.16 14075.00 93.08 298.72 8788.92 598.42 -8607.38 5961520.40 682853.17 6.16 7616.58 -86.00 0.40 -6.16 14100.00 93.18 297.18 8787.56 610.12 -8629.43 5961531.53 682830.83 6.16 7641.48 -86.00 0.40 -6.16 14125.00 93.28 295.64 8786.15 621.22 -8651.78 5961542.06 682808.20 6.16 7666.32 -86.00 0.40 -6.16 14144.89 93.35 294.42 8785.00 629.62 -8669.77 5961550.00 682790.00' 6.16 7686.03 0.00 0.35 -6.13 TD C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I --" 7" Riser I I Otis 7" WL~ Quick I Connect ~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE' Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Combination CuttedBlinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Hydraulic over Electric 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") ri 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus ARCO Alaska, Inc. ,~f- ~-~. Check;'EFF#: 079~ oo o 100791 AAI PAYABLES Date:02/03/~ Page of N00072020221 P.O. Box 102776 p~y Entity: o2ol Vendor ~ Anchorage, AK 99510 100.00 02/01/, 0 V~020100SJD01 Y013P 0200 SJD FILING FEE FOR PERMIT TO D[ILL 18-07A ........................................................................................................................... -.,~: :.::::~.:-:;~-~:::~::-:~,=:,~.,.;;,:::-;::.:,:,.~:~ ........... ~,.;~.:.~,~;~iiS~i:W~i%?~'!ii.~iCiiii!i!;:i:i!~:!!%~iiii¥iiii:51!=!iiiiii!!i i:ii:?~!i!i!i;ili ?~;~<:<~:~:~: ~:?~:~ <;<~ ~ ~ ~ .......................... . .............. >:? ::::::::::::::::::::::: ............................. .:~;.~:;i~;>;.;~;~.~E~1:~..:~i.~>~:b~gJ.::~;~.:~3:;:.~'.~>~1?~5.~J~5~;~:;;~ ;~ : · ~ .~: .... :.'.7.'.wv :'.'......'.-..w. t'. ............................... ~:: ..... . ........ v.c....'.- -:'Z: t'-'=. ..?r'. '.'. vv'::.:.'..'?..'..'..'.:: v::::.'.v.'.'.":"': ]~':';:'::::: . · . .... L:~¢~:;~'~::-~(i~?~::~:'-~C:'~3'~;117-::-~0~ ............................................................................................. :~:~ ~::~;:~:~3::::~:::: :.:::~ ...................... ~t~: ~::~:'.~TJ~:J:"~J'].]~-:':~ 7~?~Jj:'~J:~::'JJ~5~SJ~j%~ jf~j~[~.'j~:J~J:~::~:.]}~]~j~2~ .......... ..... : ............ ' ...... ::::2~:~::::: ::: b ' i :; ': :" ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ...................................... ~ .... ~ :~ , .. ............................ ~ ............ . ............ ............................................. I ~ ......... ~ ............ . ................................................................................... :.:.:::.:.:;':::7~'~z.~::.~:.~:~:-~:7~::~::-?:~?~?.~;:~:~: ...... , ~gU.UU ~ .- 1- .1 - ._ ..... - . . Questions regarding this remittance can be made by calling or writing: FRT 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 MATLSg07/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 SVCS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 DIAL 907/263-4422 Detach check before depositing Pay ': 0100791 **************100 · 00' ("Amount Not To Exceed $23,000.00' ') 02 - 0 3 - 0 0 To the order of: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE AK 99501 D ale ANCHORAGE : Amount Void after 90 days r'O signatures required amounts over $~5,000.00 ""0000 ~O0?q ;i,,' i:02~Sq06 2Fo 2~: Oq qO000"" DO NOT WRITE IN THIS AREA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 717' FNL, 280' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 1260' FNL, 1779' FEL, SEC. 23, T11N, R14E, UM At effective depth At total depth 950' FNL, 2452' FEL, Sec. 23, T11N, R14E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service __ (asp's 691473, 5961142) (asp~ 684710, 5960439 (asp's 684030, 5960724) 6. Datum elevation (DF or KB feet) RKB 46 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-07 9. Permit number / approval number 182-128 10. APl number 50-229-20803 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 79' Surface 2451' Production 1 1485' Liner 1440' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 12646 feet Plugs (measured) Tagged PBTD @ 12509' MD on 11/15/1999. 8926 feet 12509 feet Junk (measured) 8829 feet Size Cemented Measured Depth True vertical Depth 20" 1900¢ Poleset 79' 79' 13-3/8" 167o sx Fondu & 400 Sx PFC 2497' 2497' 9-5/8" 500 Sx Class G & 300 Sx PFC 1 1 531' 81 90' 7" 4oo sx Class G 12646' 8926' RECEIVED 8731' -12370' -8745,;12390'; 8766' - 12420' -8835,.12518'. I" [.'_ f.2)--~F3 0 7 ~" "" ^ ^ ~' ~ ~ ~d ¢_.,0~l['giS,~i0 r' O~/~""~/~/~ Alaska 0il & Gas Cons. / Anchorage 4-1/2", 12.6¢, L-80 PCT @ 12215' MD; 3-1/2", 9.6¢, L-80 PCT @ 12430' MD. 9-5/8" X 4-1/2" BAKER SAB PACKER @ 11173' MD; 7" X 3-1/2" BAKER F-1 PACKER @ 12403' MD. 4-1/2' CAMCO BAL-O SSSV @ 2069' MD. 13. Attachments Description summary of proposal ~X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation February 17, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __.X Gas __ Suspended __ Service 17. I hereby certfly that the foregoing is true and correct to the best of my knowledge. Signed ' 1,11=-~-~0~-%~ ::~ Title: AAI Coil Tubing Drilling Supervisor FOR 6OMfvllSSION USE ONLY Conditions of approval: Notify Commission so representative may witness Questions? Call Mark Johnson @ 265-1661. Prepared b~/ Paul Rauf 263-4990 Plug integrity __ BOP Test __ Mechanical Integrity Test __ Location clearance __ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · II SUBMIT IN TRIPLICATE COMPANY /~/~C_.4:~ VVELL NAMEYZ~'.. /~-4:~7/z] PROGRAM: exp dev v/ redrtl v/ serv wellbore seg ann. disposal para req WELL PERMIT CHECKLIST FIELD & POOL INIT CLASS ~-~ 2/~)//-- ADMINISTRATION _R DATE ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... DATE 15. S~rface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long stdng to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Ddlling §uid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to %S[~"~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY GEOL AREA >N )N Y Y Y Y UNIT# _/_/_/_/~///_~ ~ ON/OFF SHORE 30. Permit can be issued w/o hydrogen sulfide measures ..... _A~ DATE ANNULAR D~POSAL APPR DATE 31. Data presented on potential overpressure zones ...... ./'/,~ Y N See'aS s ............ . 33. S " y(' - ) ............. ,~., N 34. Contact name/phone for weekly progress reports [exploratory only](._Y~ N 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater;, or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: RPCr' BEW~ WM ~ DWJ SFD~2 JDH~ RNC' CO Co Comments/Instructions: c:~msoffice\wordian\diana\checklist (rev. 09127199) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. [] Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 01/04/20 BHI 01 LIS Customer Fokmat Tape **** TAPE HEADER **** MWD 04/20/21 33243 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): ~234567890~234567890~23456789~~23456789~~23456789~~234567890~234567890~234567890 -- Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT.FT STOP.FT STEP.FT NULL. COMP. WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 12470.0000: Starting Depth 12948.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: ARCO Alaska, Inc. WELL: 18-07A PB2 FIELD: Prudhoe Bay Unit LOCATION: 717' FNL, 280' FEL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 22-Apr-00 API NYUMBER: 500292080371 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 24 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 46 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 46 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail 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) Well 18-07APB2 was sidetracked @ 12740' MD ( 8750' SSTVD)from the original wellbore of Well 18-07APB1. (5) Well 18-07APB2 was drilled to 12948' MD (8799' SSTVD) and later plugged back with cement. (6) The interval from 12925' MD (8797' SSTVD) to 12948' MD (8799' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here and the PDC (Primary Depth Control) supplied by BP Exploration (Schlumberger, 07/07/00) overlap on only 6 feet. The depth matching to PDC was not possible. (8) A Magnetic Declination correction of 27.29 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 4 17.25 ft. 22.22 ft. 5 17.25 ft. 22.22 ft. CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A N/A N/A ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 72 records... Minimum record length: 8 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth, feet **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN ARCO Alaska, Inc. WN 18-07APB2 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!! !! !!!!!!!!! !!!! Remark File Version 1.000 1. The data presented are the field raw data. 2. The data and the PDC supplied by BPX overlap on only 6 ft. 3. The PDC used is a Schlumberger Gamma Ray dated 07-Jul-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 0.0 2 ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 8 fndun a [F ] 1. 00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: API APi API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR MWD 68 1 API 4 4 99 995 99 1 2 ROP MWD 68 1 F/HR 4 4 99 995 99 1 *** Record Type (47) not decoded... *** Record Type ( 47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 12 Tape File Start Depth = 12470.000000 Tape File End Depth = 12948.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 2875 datums Rep Code: 79 2 datums Tape Subfile: 2 21 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER **** MWD 04/20/21 33243 01 **** REEL TRAILER **** MWD 01/04/20 BHI 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 20 APR ** 7:59a Elapsed execution time = 0.22 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GR ROP 12470.0000 19.7320 62.6480 12470.5000 18.3290 61.6290 12500.0000 24.0210 58.3370 12600.0000 194.4770 55.6020 12700.0000 99.5720 21.1810 12800.0000 68.6170 79.1030 12900.0000 25.7290 38.6410 12948.0000 -999.2500 -999.2500 Tape File Start Depth = 12470.000000 Tape File End Depth = 12948.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS [] Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 01/04/18 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/18/21 33243 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): ~23456789~~234567890~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ---- Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT.FT STOP.FT STEP.FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 12438.0000: Starting Depth 13300.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: ARCO Alaska, Inc. WELL: 18-07A FIELD: Prudhoe Bay Unit LOCATION: 717' FNL, 280' FEL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 05-MAY-00 API NYUMBER: 500292080301 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 24 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 46 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 46 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail 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) Well 18-07A was kicked off @ 12446' MD (8738' SSTVD) from the wellbore of Well 18-07. (5) Well 18-07A was drilled to 13300' MD (8788' SSTVD) on Run 12. (6) The interval from 13282' MD (8790' SSTVD) to 13300' MD (8788' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Exploration (Schlumnerger, 07/07/00) (8) A Magnetic Declination correction of 27.29 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 9 18.07 ft. 23.05 ft. 10 17.73 ft. 22.72 ft. 11 17.51 ft. 22.50 ft. 12 17.51 ft. 22.50 ft. CURVE SHIFT DATA BASELINE, MEASURED, 12446.0, 12441 12447.1, 12443 12452.5, 12450 12457.1, 12453 12461.5, 12457 12463.1, 12460 12466.6, 12466 12468.6, 12468 DISPLACEMENT 7, ! -4.31836 1, ! -4.03027 3, ! -2.15918 9, ! -3.16602 9, ! -3.59863 8, ! -2.30273 0, ! -0.576172 9, ! 0.288086 BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 80 records... Minimum record length: 8 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN ARCO Alaska, Inc. WN 18-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !! !! !!!!!! !!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 07-Jul-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXl2 0.0 2 ROP ROPS12 0.0 * FORMAT RECORD (TYPE% 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: IF ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a IF ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 B~TES * Total Data Records: 21 Tape File Start Depth = 12438,000000 Tape File End Depth = 13300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5179 datums Rep Code: 79 2 datums API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape Subfile: 2 30 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN ARCO Alaska, Inc. WN 18-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~23456789~~23456789~~234567890~234567890~23456789~~23456789~~23456789~ !!!!!!!!! !!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE% 64) Entry Type( 1) Size 1) Repcode 66) Data record type is: 0 Entry Type( 2) Size 1) Repcode 66) Datum Specification Block Type is: 0 Entry Type( 3) Size 2) Repcode 79) Datum Frame Size is: 12 bytes Entry Type( 4) Size 1) Repcode 66) Logging direction is down (value= 255) Entry Type( 5) Size 1) Repcode 66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size 4) Repcode 68) Frame spacing: 0.500000 Entry Type( 9) Size 4) Repcode 65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 fndun a [F ] [] FRAME SPACE = 8 8 1.00000000 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 21 Tape File Start Depth = 12438.000000 Tape File End Depth = 13300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5179 datums Rep Code: 79 2 datums Tape Subfile: 3 30 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 05/18/21 33243 01 **** REEL TRAILER **** MWD 01/04/18 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 18 APR ** 3:07a Elapsed execution time = 0.33 seconds. SYSTEM RETURN CODE = 0 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 I Tape [] Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH 12438 0000 12438 5000 12500 0000 12600 0000 12700 0000 12800 0000 12900 0000 13000 0000 13100 0000 13200 0000 13300 0000 Tape File Tape File Tape File Tape File Tape Subfile 3 DEPTH 12438.0000 12438.5000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13300.0000 Tape File Tape File Tape File Tape File Tape Subfile 4 GR 71 51 22 53 119 122 -999 19 7337 18 8808 25 8425 23,2467 5933 9602 ,2688 1245 0901 9740 .2500 ROP -999.2500 -999.2500 66.0792 33.5596 78.2682 24 6314 74 4583 68 9009 64 6293 2 3622 29 8693 Start Depth = 12438 End Depth = 13300 Level Spacing = 0 Depth Units = Feet is type: LIS .000000 .000000 .500000 Gl{AX ROPS -999.2500 -999.2500 -999.2500 -999.2500 25.4070 66.2140 22.7540 32.0070 67.6140 78.2610 38.5610 24.7120 21.9560 78.4130 52.3130 69.6210 121.0710 64.6510 120.8770 1.5080 -999.2500 29.7370 Start Depth = 12438.000000 End Depth = 13300.000000 Level Spacing = 0.500000 Depth Units = Feet is type: LIS [] Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 01/04/18 BHI 01 LIS Customer Format Tape ** TAPE HEADER **** MWD 04/18/21 33243 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): ~23456789~~234567890~234567890~234567890~234567890~234567890~23456789~~234567890 Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.FT 12450.0000: Starting Depth STOP.FT 12927.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ARCO Alaska, Inc. WELL. WELL: 18-07A PB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 717' FNL, 280' FEL CNTYo COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75'~ NaviGamma - Gamma Ray DATE. LOG DATE: 20-Apr-00 API . API NYUMBER: 500292080370 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 24 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 46 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 46 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail 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) Well 18-07APB1 was sidetracked from the original wellbore of Well 18-07. (5) Well 18-07A?B1 was drilled to 12927' MD (8794' SSTVD) on Run 3.An open hole sidetrack later made to drill 18-07A. (6) The interval from 12909' MD (8795' SSTVD) to 12927' MD (8794' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Exploration (Schlumberger, 07/07/00) (8) A Magnetic Declination correction of 27.29 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 18.33 ft. 23.99 ft. 2 18.00 ft'. 23.90 ft. CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 12456.3, 12453.9, ~ -2.44629 12460.6, 12458.0 ! -2.59082 12465.7, 12462.5, ! -3.16602 12479.5, 12472.4, ! -7.05273 ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 74 records... Minimum record length: 8 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN ARCO Alaska, Inc. WN 18-07APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 07-Jul-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX10 0.0 2 ROP ROPS10 0.0 * FORMAT RECORD (TYPE% 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode Frame spacing units: [F ] fndun c [F ] 1.00000000 Entry Type(11) Size( 4) Repcode Number of frames per record is: Entry Type(13) Size( 1) Repcode One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode 66) Datum Specification Block Sub-type is: 68) 65) 3 68) 84 66) Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 t 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR MWD 68 1 API 4 2 ROP MWD 68 i F/HR 4 4 99 995 99 1 4 99 995 99 1 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 12 Tape File Start Depth = 12450.000000 Tape File End Depth = 12927.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 2869 datums Rep Code: 79 2 datums Tape Subfile: 2 21 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN ARCO Alaska, Inc. WN 18-07APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~234567890~23456789~~23456789~~234567890~234567890~234567890~234567890 !! !! !!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE# 64 Entry Type( 1) Size( 1 Data record type is: Entry Type( 2) Size( 1 Datum Specification Block Entry Type( 3) Size( 2 Datum Frame Size is: Entry Type( 4) Size( 1 Logging direction is down Entry Type( 5) Size( 1 Repcode (66) 0 Repcode (66) Type is: 0 Repcode(79) 12 bytes Repcode(66) (value= 255) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 12 Tape File Start Depth = 12450.000000 Tape File End Depth = 12927.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 2869 datums Rep Code: 79 2 datums Tape Subfile: 3 21 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 04/18/21 33243 01 **** REEL TRAILER **** MWD Ol/O4/18 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Wed 18 APR ** 9:33p Elapsed execution time = 0.27 seconds. SYSTEM RETURN CODE = 0 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape [] Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH 12450 0000 12450 5000 12500 0000 12600 0000 12700 0000 12800 0000 12900 0000 12927 0000 GR ROP 21.4213 68.1294 49.8585 69.9189 25.1987 72.3575 26.5156 104.8151 31.9470 96.9240 49.0796 142.1966 81.8616 96.1261 -999.2500 -999.2500 [] Tape Tape File Start Depth = 12450.000000 Tape File End Depth = 12927.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Subfile 3 is type: LIS DEPTH GRAX ROPS 12450.0000 -999.2500 -999.2500 12450.5000 -999.2500 -999.2500 12500.0000 24.0210 58.3370 12600.0000 22.6890 55.6020 12700.0000 83.6390 19.1540 12800.0000 50.8380 74.6800 12900.0000 67.4200 95.5290 12927.0000 -999.2500 65.8420 Tape File Start Depth = 12450.000000 Tape File End Depth = 12927.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS
