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200-098
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 Organization {done) h or items: Grayscale items: [] Poor Quality Originals: Other: D I G..~,,~T A Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds TOTAL PAG ES'~.~ NOTES' ORGANIZED BY; BEVERLY BREkc~;~SHERYL MARIA LOWELL [] Other Project Proofing PROOFED BY' , BEVERLY' BRE~SHERYL MARIA LOWELL DATE:/~'~/ [] Staff Proof By: Date: Is~ ~~"' Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BREN VINCEN~ARIA LOWELL BEVERLY DATE Is~ ReScanned (done) RESCANNED BY: BEVERLY BRE~ SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES' ~ Quality Checked (done) Rev1 NOTScanned.wpd MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc K~ STATE OF ALASKA ~'" ALAS , ,.)IL AND GAS CONSERVATION CO,v,,~,,SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack ,_ la. Well Status: [] Oil [] Gas [] Plugged [] Abandoned [] Suspended [] WAG lb. Well Class: 20AAC2S.105 20AAC25.110 [] Development [] Exploratory [] GINJ [] WlNJ [] WDSPL No. of Completions Zero Other [] Stratigraphic [] Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 6/10/2003 200-098 303-158 3. Address: 6. Date Spudded 13. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/5/2000 50-029-21166-02 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 8/12/2000 PBU 15-07B 1527' SNL, 1354' EWL, SEC. 22, T11N, R14E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: KBE - 66.52' Prudhoe Bay Field / Prudhoe Bay 2993' NSL, 1266' EWL, SEC. 14, T11N, R14E, UM Pool Total Depth: 9. Plug Back Depth (MD+TVD) 4351' NSL, 2059' EWL, SEC. 14, T11N, R14E, UM 13838 + 8730 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation'and Serial No. Surface: x- 677294 y- 5959986 Zone- ASP4 13875 + 8729 Ft ADL028307 TPI: x- 682369 Y' 5964628 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 683127 Y- 5966005 Zone- ASP4 N/A MD ...... 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey [] Yes [] No N/A MSL 1900' (Approx.) ,,, 21. Logs Run: MWD, Memory GR, CNL 22. CASING, LINER AND CEMENTING RECORD CASING . .. 'SETTING DEPTH HOLE . .. SIZE ' WT. PER' FT. ..(~RADE' ' 'TOP'" ~ ..BOTTOM. SIZE.. '" CEMENTING' REC°RD ...... AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 2000 sx Poleset 13-3/8" 72# L-80 Surface 2395' 17-1/2" 1850 sx PF 'E', 400 sx PF 'C' 9-5/8" 47# L-80 Surface 10193' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 7" 26# NT-80 10014' 12114' 8-1/2" 305 sx Class 'G' 2-3/8" 4.6# L-80 11854' 13875' 3" 66 sx LARC (Approx.) ,, , 123. Perforations open to Production (MD + TVD of Top and 24. .TUBING· RECORD : Bottom Interval, Size and Number; if none, state "none"): · SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2#, L-80 11724'- 12002' 11946' , , , ....... , .... MD TVD MD TVD 25. · . ~ ACID, FRACTURE,CEMENT SQuEEzE, ETC. .. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATER~AL USED, 11724' P&A with 15 Bbls Class 'G' Sqzd to 1000 psi 11724' Set Whipstock ........... , ,,, 26. PRODUCTION TEST Date First Pro~l'uction: 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 ICHOKE SIZE I GAS-OIL RATIO TEST PERIOD i~ I Flow Tubing Casing Pressure CALCULATED ~. OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-Hour RATE--~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atta'ch separate sheet; if necessary). Submit core chips; if none, state "none". None .;.. Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKEi.' 29. { FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 11322' 8232' None Shublik 11381' 8270' Sadlerochit 11476' 8332' Zone lB 12130' 8713' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble "~~_ _~~_~ Title TechnicalAssistant Date PBU 15-07B 200-098 303-158 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Phil Smith, 564-4897 GENERAL: iNSTRUCTIONS 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 la: ITEM 4b: 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. TPI (Top of Producing Interval). ITEM 8: ITEM 13: ITEM 20: The Kelly Bushing elevation in feet above mean Iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. ITEM 22: ITEM 23: ITEM 26: ITEM 27: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Well: 15-07C Accept: 06/24/03 Field: Prudhoe Bay Unit Spud: 06/28/03 APl: 50-029-21166-03 Release: 07/08/03 Permit: 203-097 Rig' Nabors 2ES Date PRE-RIG WORK 06/09/03 KILL WELL WITH 1% KCL AT 4 B/M. RIH WITH 1.5" BD NOZZLE. UNABLE TO GET PAST GLM AT 11581. P©H. 06/10/03 RIH WITH 1.5" BD NOZZLE. TAG UP AT 12963. MIX AND PUMP 15 BBLS 15.8 PPG CLASS G CEMENT. LAYIN /~'' AND SQUEEZE WITH 1000 PSI SURFACE PRESSURE. ESTIMATE 1.5 BBLS CEMENT BEHIND PIPE. HOLD SQUEEZE PRESSURE FOR 30 MINUTES WHILE CIRCULATING WITH 1 FOR ONE RETURNS. / CONTAMINATE AND CLEAN OUT TO 11825 HOLDING 500 PSI. POH AT 80 % JETTING ALL JEWELRY. BLOW DOWN COIL WITH N2 FOR PIPE SWAP. 06/12/O3 T/I/O=100/500/0. MIT IA PASSED TO 3500 PSI. MIT-T PASSED TO 3500 PSI. (PREP FOR RWO). PRESSURED IA TO 3500 PSI WITH 14.7 BBLS CRUDE. IA LOST 100 PSI IN FIRST 15 MINUTES AND 25 PSI IN SECOND 15 MINUTES FOR TOTAL OF 125 PSI IN 30 MINUTES. BLED IA DOWN TO 640 PSI. PRESSURED TBG TO 3500 PSI WITH 2.2 BBLS OF CRUDE. TBG LOST 190 PSI IN 15 MINUTES. BUMPED TBG BACK UP TO 3500 PSI. TBG LOST 50 PSI IN 15 MINUTES AND 75 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 125 PSI IN 30 MINUTES. PRESSURED TBG UP TO 3500 PSI. TBG LOST 50 PSI IN FIRST 15 MINUTES AND 20 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 70 PSI IN 30 MINUTES. BLED TBG TO 0 PSI. FINAL WHP'S=0/640/0. 06/14~03 DRIFT TO SSSV @ 2088' WLM. UNABLE TO PASS THRU - BACK FLOWED TO ASSIST OPENING TRSSSV. RIH W/2.52" CENT, S. BAILER. TAGGED BOTTOM @ 11797' SLM -- LOST TOOLS, WIRE SNIPPED ON TRSSSV WHILE PULLING OUT OF HOLE. RUNNING IN HOLE W/3.87" CENT, 10' STEM W/FLAPPER CHECKER TO TRSSSV. 06/15/03 RAN FLAPPER CHECKER TO TRSSSV @ 2082' (FLAPPER OPEN ALL THE WAY). RUN 2.68" CENT W/2-1/2" RB TO FISH @ 11772' SLM. FISH OUT OF HOLE. 2.375 CHEMICAL CUT TUBING AT 11745' - IN MIDDLE OF SIXTH FULL JOINT ABOVE PACKER. DEPTH REFERENCED TO TUBING TALLY. TAG TD AT 11807'. PUNCH TUBING FROM 11721'-11723' AND SHOOT STRINGSHOT FROM 11733'-11747' PRIOR TO CUT. ON SURFACE- SEVERING HEAD APPEARED TO HAVE NORMAL CHEMICAL WEAR. 06/16/03 T/IA/OA = 500/550/0. (PRE RWO). CIRCULATE OUT TUBING & IA. PUMPED 10 BBL NEAT MEOH SPEAR, 1258 BBLS SEAWATER DOWN THE TBG WHILE TAKING RETURNS UP THE IA TO THE FLOW LINE. PUMP 175 BBLS DIESEL DOWN IA, U-TUBE DIIESEL TO FREEZE PROTECT. FREEZE PROTECT FLOWLINE: 5 NEAT MEOH, 33 CRUDE, 5 NEAT MEOH. FINAL WHP'S- 0/0/0. 06/17/03 SET 3.81 HOLD-OPEN SLV IN TRDP SSSV. (TAKES 4 1/2 PRS TO PULL) (OAL = 92"). Z-6 SETTING TOOL INDICATED GOOD SET. LEFT WELL SI. BP EXPLORATION Page 1 ~ Operations Surnma Report Legal Well Name: 15-07 ,Common Well Name: 15-07C Spud Date: 8/16/1984 Event Name: REENTER+COMPLETE Start: 6/24/2003 End: 7/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/8/2003 Rig Name: NABORS 2ES Rig Number: Date From -To 'Hours Task Code NPT Phase Description of Operations 6~23~2003 10:00 - 12:00 2.00 MOB P PRE Held PJSM - Rig Down Rig Floor And Can-Rig Top Drive - Load Up Camp Shop And Mud Pit Pump Room Complex 12:00 - 13:30 1.50 MOB P PRE Held PJSM - Bridle Up Traveling Blocks - Lower Cattle Shoot 13:30 - 14:30 1.001 MOB P PRE Held PJSM - Remove Pins From A-Legs And Lower Mast 14:30 - 15:30 1.00 MOB P PRE Held PJSM - Move Sub Base Off DS 18-03B And Stage At End Of Pad 15:30 - 18:30 3.00 MOB P PRE Held PJSM With Security And Peak - Take Camp, Shop, And Mud Pit Complex To DS-18 Road Sub Base To DS-15 18:30 - 21:00 2.50 RIGU P PRE Held PJSM - Lay Matting Boards And Herculite Around Well Cellar - Attempt To Position Rig Had To Remove Needle Valve Connections, And Flange - Reposition BOP Stack - Spot Sub Base Over Well 21:00 - 22:00 1.00 RIGU P PRE Held PJSM - Raise Mast And Pin - Raise Cattle Shoot 22:00 - 23:00 1.00 RIGU P PRE Held PJSM - Lay Herculite - Position Mud Pit Pump Room Complex 23:00 - 00:00 1.00 RIGU P PRE Held PJSM - Position Camp Unit - Connect Service Lines 6/24/2003 00:00 - 01:00 1.00 RIGU P PRE Held PJSM - Lay Herculite For Cuttings Tank - Position Tank And Berm - Remove Bridal Lines From Traveling Blocks And Secure In Mast - Hook Up Utilities Between Pit Complex And Sub Base - Rig Up Floor^rea And Can-Rig Top Drive - Spot Mud Lab And Geologist Unit 01:00 - 01:30 0.50 WHSUR P DECOMP Hold Pre-Spud Meeting With All Personal Regarding Operations For Well Work Rig Accepted For Well Work On DS 15-07C At 01:00 Hours On 06/24/2003 01:30 - 02:00 0.50 WHSUR P DECOMP Held PJSM - Take On Sea Water In Pit System - Install Secondary Annulus Valve On Well Head - Record Tubing Pressure At 15 Psi. And Annulus Pressure At 0 Psi. 02:00 - 03:30 1.50 WHSUR P DECOMP Held PJSM - Rig Up DSM Lubricator And Pull BPV - Rig Up To Tree And Well Head To Circulate Out Freeze Protection. 03:30 - 08:30 5.00 WHSUR P DECOMP ~Held PJSM - Test Surface Lines To 3,500 Psi. (Test Good) - ~Circulate Out Freeze Protection Thru Choke Taking Returns To ~Cuttings Tank - Fluids Out Of Balance - Circulate To Balance Out Fluid. CBU at 5 bpm and 650 psi. O psi on tubing and annulus. 08:30 - 11:00 2.50 WHSUR P DECOMP Dry rod TWC. Test from below to 1,000 psi. Blow down surface equipment. PJD circulation lines. N/D tree and adapter flange. Verify 4 1/2" NSCT threads. Required 7 1/2 turns to M/U. No galling apparent. 11:00 - 14:30 3.50 BOPSUF. P DECOMP N/U BOPE. Install flow riser, turnbuckles, and mousehole. 14:30 - 17:30 3.00 BOPSUF P DECOMP Test BOPE to 250 psi Iow and 3,500 psi high. Test witnessed by Lou Grimaldi of the AOGCC. 17:30 - 18:30 1.00 WHSUR P DECOMP PJU DSM and pull TWC with lubricator. 18:30-20:30 2.00 WHSUR P DECOMP M/U landing joint and screw into tubing hanger. BOLDS. Pull tubing hanger to floor with 125K up weight. 20:30 - 21:30 1.00 PULL P DECOMP PJU casing equipment. L/D tubing hanger. R/U control line spooler. 21:30 - 23:00 1.50 PULL P DECOMP L/D 4 1/2", 12.6#, L-80, NSCT tubing to the SCSSV (52 joints). 23:00 - 23:30 0.50 PULL P DECOMP L/D SCSSV, R/D control line spooler. Recovered 51 SS control line bands. 23:30 - 00:00 0.50 PULL P ~DECOMP Continue L/D 4 1/2" tubing. 6/25/2003 00:00 - 01:00 1.00 PULL P DECOMP POOH, L/D 4 1/2" tubing from 9,623' to 7,730'. Printed: 7/2212003 8:48:44 AM BP EXPLORATION Page 2 ~ Operations Summary Report Legal Well Name: 15-07 Common Well Name: 15-07C Spud Date: 8/16/1984 Event Name: REENTER+COMPLETE Start: 6/24/2003 End: 7/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/8/2003 Rig Name: NABORS 2ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 612512003 01:00 - 09:00 8.00 PULL P DECOMP CIO handling equipment. L/D 3 1/2", 9.2#, L-80, NSCT tubing from 7,730'. ' PJD 3 1/2" handling equipment. Clear and clean rig floor. Install wear bushing. 09:00 - 11:00 2.00 STWHIP P WEXlT PJSM. P/U and M/U BHA#1 to 1,049'. 11:00 - 13:00 2.00 STWHIP P WEXlT Service top drive. Cut and slip 107' drilling line. 13:00 - 20:00 7.00 STWHIP, P WEXlT P/U 4" drill pipe from 1,049' to 11,742', (344 joints). Break circulation every 4,000'. 20:00 - 21:30 1.50 STWHIP P WEXlT Circulate. Pressure test the 9 5~8" x 7" to 3,500 psi for 30 minutes. Record test. 21:30 - 23:00 1.50 STWHIP ~ WEXlT Displace well to 8.5 ppg QuickDrilN fluid at 13 bpm and 2,350 psi. Clean out under shakers. 23:00 - 00:00 1.00 STWHIP ~ WEXlT Pump dry job. POOH with drill pipe from 11,742' to 10,484'. P/U weight 190K, S/O weight 145K, Rot weight 165K Torque 6K 612612003 00:00 - 04:30 4.50 STWHIP ~ WEXlT POH w/drill pipe from 10,484' to 1,049'. Stand back assembly from 1,049' to 35'. Caliper and L/D mills. Clear and clean rig floor. 04:30 - 06:00 1.50 STWHIP ~ WEXIT ~JSM. M/U Whip Stock assembly (BHA #2) to 110'. 06:00 - 06:30 0.50 STWHIP ~ WEXIT Upload MWD. 06:30 - 07:00 0.50 STWHIP ~ WEXIT RIH from 110' to 1,133'. Shallow test MWD tools at 486' at 250 gpm and 350 psi. CIO elevators. 07:00 - 13:00 6.00 STWHIP P WEXIT RIH with drill pipe from 1,133' to 11,742'. Running speed 1 1/2 minutes per stand. Fill pipe at 4,400' and 7,671'. 13:00 - 13:30 0.50 STWHIP P WEXIT Orient whip stock at 20 degrees RHS and set. 13:30 - 00:00 10.50 S'I'WHIP P WEXIT Mill window in 7", 26# casing from 11,724' to 11,743'. P/U weight 190K, S/O weight 145K, Torque 6 -7K. = TOW at 11,724', BOW at 11,736'. Recovered approximately 50 lbs metal cuttings.. 6/27/2003 00:00 - 07:30 7.50 STWHIP P WEXIT Mill window / formation from 11,743' to 11,748'. 07:30 - 08:00 0.50 STWHIP P .VVEXIT Work window. Clean. 08:00 - 09:00 1.00 STVVHIP P WEXIT Drop dart and open circ sub. Pump sweep and circulate hole at 12 bpm and 2,100 psi. 09:00 ~ 09:30 0.50 STWHIPi P WEXIT Perform FIT with 8.5 ppg mud to 675 psi surface pressure at 11,720', (8,500' tvd). EMW 10.0 ppg. 09:30 - 13:30 4.00 STWHIP P WEXlT Observe well and pump dry job. POOH from 11,748' to 1,115'. 13:30 - 15:30 2.00 STWHIP P WEXIT LID BHA from 1,115'. Caliper mills and LID same. Clear rig floor. 15:30 - 16:30 1.00 DRILL P PROD1 Flush stack and surface equipment. Service wear bushing. 16:30- 19:00 2.50 DRILL P PROD1 PJSM. M/U BHA #3 to 107'. Upload MWD tools. Shallow test MWD. O.K. Load nuclear sources. Continue M/U BHA to 236'. 19:00 - 20:30 1.50 DRILL P PROD1 P/U drill pipe from 236' to 1,823'. RIH with drill pipe from 1,823' to 2,756'. 20:30 - 21:30 1.00 DRILL P PROD1 Service top drive. 21:30 - 23:00 1.50 DRILL P PROD1 RIH with drill pipe from 2,756' to 6,311'. Fill pipe every 3,000'. 23:00 - 00:00 1.00 DRILL P PROD1 Cut and slip drilling line. 6~28~2003 00:00 - 02:30 2.50 DRILL P PROD1 RIH from 6,311' to 11,675'. Break circulation at 9,110'. MWD functioning O.K. RIH to top of window. Break circulation. No response from MWD. ,,, Printed: 712212003 8:48:44AM BP EXPLORATION Page 3 Operations Surnma Report Legal Well Name: 15-07 Common Well Name: 15-07C Spud Date: 8/16/1984 Event Name: REENTER+COMPLETE Start: 6/24/2003 End: 7/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/8/2003 Rig Name: NABORS 2ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations '6~28~2003 02:30 - 04:00 1.50 DRILL N DFAL PROD1 Work with MWD. Work pipe, rotate, pump 20 bbl water sweep, check and confirm all surface equipment functioning. No success reviving MWD. 04:00 - 05:00 1.00 DRILL N DFAL PROD1 POOH from 11,724' to 10,300'. Circulate and test MWD. No success. Drop dart to circ sub, pump dry job. 05:00 - 09:30 4.50 DRILL N DFAL PROD1 POOH with drill pipe from 10,300' to 237'. 09:30 - 11:00 1.50 DRILL N DFAL PROD1 POH with BHA from 237' to 138'. Function test MWD. No response. Flush tools with water. Remove RAS, download MWD. 11:00 - 12:00 1.00 DRILL N DFAL PROD1 L/D MWD. P/U new MWD tools to 46' and orient. 12:00 - 12:30 0.50 DRILL N DFAL PROD1 M/U BHA from 46' to 107'. 12:30 - 14:00 1.50 DRILL N DFAL PROD1 Upload MWD. Shallow test MWD tools. M/U BHA to 138'. PJSM. Load RAS in MWD tool. M/U BHA to 237'. 14:00 - 16:00 2.00 DRILL N DFAL PROD1 RIH with drill pipe from 237' to 6,778'. Fill pipe every 3,000'. 16:00 - 17:00 1.00 DRILL ~ PROD1 Service top drive. 17:00 - 18:30 1.50 DRILL N DFAL PROD1 RIH with drill pipe from 6,778' to 11,539'. 18:30 - 19:00 0.50 DRILL N DFAL PROD1 Install blower hose. Orient to 20 degrees RHS. 19:00 - 19:30 0.50 DRILL ~ PROD1 RIH from 11,539'. Slide through window, no problems. Ream under,laurie hole from 11 ~738' to 11 ~748'. Obtain SPR. Directional drill from 11,748' to 11,910'. 19:30 - 00:00 4.50 DRILL .... PROD1 ART = 0.59 hrs, AST = 2.05 hrs, ADT = 2.64 hrs P/U weight 180K, S/O weight 140K, Rot w~K. Slide/Rotate 162' (11,748' - 11,91~,,/' Slide at TF 20 to initiate build/.~,Kturn Flow rate 267 gpm, on btm,,.~,¢1'00 psi, off btm 2,000 psi. WeB 5 - 15 K, ROP.~SO fph Rotate at 30 RP~r Flow rate.~T'gpm~ psi, off btm 2,000 psi. Torqu~ btm 7,000; Torque offbtm 4,000 Wj~;~. 5-1.5K~ ReP 40 : 67 fPh irectional drill from 11,910' to 12,375'. 612912003 00:00 - 12:00 12.00 DRILL P PRO~,~ ART = 3.08 hrs, AST = 5.73 hrs, ADT = 8.81 hrs j, P/U weight 185K, S/O weight 140K, Rot weight 160K. j Slide / Rotate 465' (11,910' - 12,375') j Slide at TF 0 to 20 RHS to continue build / RH turn Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. WeB 15 - 20 K, ReP 50-60 fph J Rotate at 60 RPM Flow rate 267 gpm, on btm 2,100 psi, off btm 2,000 psi. Torque on btm 7,000; Torque off btm 5,000 WeB 15 -20K, ReP 70 - 100 fph 3.00 DRILL P PROD1 Directional drill from 12,375' to 12,562'. ART = 1.0 hrs, AST = 1.14 hrs, ADT = 2.14 hrs Printed: 7/22/2003 8:48:44 AM To: Winton Aubert -AOGCC Date: June 9, 2003 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: Revised DS15-07B Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-21166-02 Approval is requested for the proposed P&A of PBU well DS15-07B, a Z1B horizontal well drilled and completed by CTD in. 2000. The well came on at 2500 BOPD and 2000 GOR. Within a year, production had declined to 500 BOPD at a 25,000 GOR. No wellwork opportunities are available for 15-07B. The DS15-07C sidetrack is currently scheduled for Nabors 2ES beginning approximately June 25th 2003, after completing the 18-03A sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Scope Pre-ri.q Operations: In preparation for the sidetrack the following pre-work has been performed: Tested the OA to 2000 psi - passed 4/16/03 Changed the uppermost two GLMs to dummy valves 5/02/03 Loaded the IA with 386 bbls dead crude 5/02/03 Tested the FMC Gen III 9-5/8" mandrel pack-off and tubing hanger seals - passed 5/11/03 Cycled tubing hanger and inner casing LDS 5/11/03. Remaining Work: 1. Lock open the SSSV, drift & tag top of 2 3/8" liner. 2. RIH 1%" coiled tubing to PBTD at ~13,838' MD. Pump and squeeze 10-bbls cement (full liner volume + 3 bbls) while POH to above the 2 3/8" liner top at 11,854. Dress off the top of cement to 11,850'. 3. Pressure test the well to 3500 psi for 30 minutes. 4. Chemical cut the 3 %" tubing at 11,745' (13' up from the bottom of the 6th full joint above the packer, ref tally 2/24/94)..This depth accounts for the tally being 6' deep to the 5/30/2003 corrected tie-in log in which the KOP is based. The depth of the cut _+5' is critical to ensure proper whipstock setting location. 5. Circulate the well to seawater and freeze protect to 2100' with diesel. Bleed well pressures to zero. Set a BPV. 6. Remove the well house. If necessary, level the pad. DS15-07B Application for Sundry JUN 0 9 2BD3 Ri~ 1. 2. Operations: MIRU Nabors 2ES. Pull BPV, circulate out freeze protection with seawater and reverse circulate the well with seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 %" x 3 %" tubing from the cut at 11,750'. 5. MU window milling BHA and drift the the casing to the top of fish. Test casing to 3500 psi. Change the well over to 8.4 ppg drill-in mud, POH. 6. RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on tubing stub. Mill window in 7" casing at +_11,735' MD plus 20' minimum open hole below the window top. Perform FIT to 10.0 ppg EMW. 7. RIH with 6 1/8" directional assembly. Drill the 6 1/8" production section as per directional plan to an estimated TD of 15,250' MD. CBU, POH. 8. Run a 4 %", 12.6# L-80 solid production liner. Cement the liner in place, and displace well to clean seawater above liner top. POH LD DP. 9. R/U and RIH with Halliburton 2 %" dpc perforating guns. Perforate per Halliburton recommendation. POOH. 10. Run 4-1/2", 12.6# L-80 completion tying into the 4-1/2" liner top. 11. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -2200' and secure the well. 14. Rig down and move off. Post-Rig Work: 1. Install wellhouse and flow lines. 2. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. Run slickline-conveyed CNL to determine GOC. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 06/10/03 06/25/03 JUN 0 9 200 ] DS15-07B Application for Sundry STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1527' SNL, 1354' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 2993' NSL, 1266' EWL, SEC. 14, T11N, R14E, UM At effective depth 4327' NSL, 2031' EWL, SEC. 14, T11N, R14E, UM At total depth 4351' NSL, 2059' EWL, SEC. 14, T11N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 677294, Y = 5959986 X = 682369, Y = 5964628 X = 683099, Y = 5965981 X = 683127, Y = 5966005 6. Datum Elevation (DF or KB) KBE = 66.52' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ,,,,... 15-07B 9. Permit Num,.ber 200-098" 10. APl Number 50-029-21166-02 '/" 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13875 feet true vertical 8729 feet Effective depth: measured 13838 feet true vertical 8730 feet Casing Length Size Structural Conductor 80' 20" Surface 2395' 13-3/8" Intermediate 9-5/8" Production Liner 2100' 7" Liner 2021' 2-3/8" Plugs (measured) Junk (measured) Cemented 2000 sx Poleset 1850 sx PF'E',400 sx PF'C' 500 sx Class'G', 300 sx PF'C' 305 sx Class 'G' 66 sx LARC (Approx.) MD TVD 80' 80' 2395' 2395' 1O193' 7556' 10014'-12114' 7466'-8708' 11854'-13857' 8575'-8729' Pefforationdepth:measured Open: 13158'-13360', 13400'-13558', 13640'-13835' RECEIVED Sqzd: 12950'-13100',13156'-13158' truevertical Open: 8735'-8727', 8726'-8730', 8732'-8730' JUN 0 2 2003 Sqzd: 8735'-8735', 8735'-8735' &Gas Tubing (size, grade, andmeasureddepth) 4-1/2",12.6#,L-80to4020'; 3-1/2",9.2#, L-80~o~~l Anchorage Packers and SSSV (type and measured depth) 4-1/2" Baker 'SABL-3' packer at 11946'; 4-1/2" Camco TRDP SSSV Nipple at 2106' 13. Attachments [] Description Summary of Proposal 14. Estimated date for comm~en'~ing,operation ~l~ne 5~003 16. If proposal was verbaf~::rtoved [] Detailed Operations Program [] BOP Sketch 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Bill Isaacson . ^~o,---...-- Title Senior Drilling Engineer Date "~'v~,t[ ~, ~ :.:~'..': :! ,,": ." ~:.,'..... i :. !i:' :;' :,"...,:!:~ ':,!!'::..: '.. ;::?.!.' :.':..:,~:::::: ..!..',:'..::'::':.'.~',,':::::,'..;::,.',.'.'ii.:.:,.';.:.'..ii'; ::!?i::,:.'.',;,.:i:...~;i.'f..;,,,~:.: ::';'?.':.i': ':~;':C~',',m. :m."is~iOil.:.,.:u$e ,.Oii.iyi::.:~:.:;'.?'~:;=. ;'i'::~:':!':.!.i.'.?i.:,/.,'.' "!.;:,,:;'i.:.":: ::".:.::!;':':!;'.' ::;~.'.': ... :..:':.', ::'..':. :';,"';:::;~';'.::"':':~' ':: .'",.:, ':.:" ;:" "::'? "' :',,:'.:.:.' ::: '" Conditions of Approval: Notify Commission so representative may,witness Plug integrity BOP Test Z% Location clearance ~ Mechanical Integrity Test /~ Subsequent form required 10- l~O'~ Approved by order of the Commission ~ .~'~ /~7~~-~ ~ ~i r -4 NRe2 zIju.UK I L I Approval No. ~.%~:~. 1~3~'~ Commissioner Date Submit In/Triplicate 0 bp G To: Winton Aubert - AOGCC Date: June 2, 2003 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: DS15-07B Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-21166-02 Approval is requested for the proposed P&A of P~I DS15-07B, a Z1B horizontal well drilled and completed by CT/D~2000. The well came on a~0_.0..B'OPD and 2000 GOR. Within a year, production had declined t ~~_OPD at a 25,000 GOR. No ~ll'work opportunities are available for 15-07B. -" The DS15-07C sidetrack is currently scheduled for Nabors 2ES beginning approximately June 20th 2003, after completing the 18-03A sidetrack. The pre-rig work.,~.r this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Scope Pre-rig Operations: In preparation for the sidetrack the following pre-work has been performed: Tested the OA to 2000 psi- passed 4/16/03 ,/ Changed the uppermost two GLMs to dummy valves 5/02/03 Loaded the IA with 386 bbls dead crude 5/02/03 Tested the FMC Gen III 9-5/8" mandrel pack-off and tubing hanger seals - passed 5/11/03 Cycled tubing hanger and inner casing LDS 5/11/03. Remaining Work: 1. Lock open th,~.-S~SSV, drift & tag top of 2 3/8" liner. .~-. /' I " 2. RIH with~ '3/~ Weatherford FH cement retainer on coiled tubing. Set retainer at 11,825' and squeezg/10;~ls cement (full liner volume + 3 bbls) to abandon the perforations and the 2 3/8" liner. 3. Pressur~t~t the well to 3500 psi for 30 minutes. ' 4. Chemical cut the 3 Y2" tubing at 11,745' (13' up from the bottom of the 6th full joint above the packer, ref tally 2/24/94). This depth accounts for the tally being 6' deep to the 5/30/2003 corrected tie-in log in which the KOP is based. The depth of the cut +_5' is critical to ensure proper whipstock setting location. 5. Circulate the well to seawater and freeze protect to 2100' with diesel. Bleed well pressures to zero. Set a BPV. 6. Remove the well house. If necessary, level the pad. DS15-07B Application for Sundry Ri.q 1. 2. Operations: MIRU Nabors 2ES. Pull BPV, circulate out freeze protection with seawater and reverse circulate the well with seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 Y2" x 3 YW' tubing from the cut at 11,750'. 5. MU window milling BHA and drift the the casing to the top of fish. Test casing to 3500 psi. Change the well over to 8.4 ppg drill-in mud, POH. 6. RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on tubing stub. Mill window in 7" casing at +_11,735' MD plus 20' minimum open hole below the window top. Perform FIT to 10.0 ppg EMW. 7. RIH with 6 1/8" directional assembly. Drill the 6 1/8" production section as per directional plan to an estimated TD of 15,250' MD. CBU, POH. 8. Run a 4 YW', 12.6# L-80 solid production liner. Cement the liner in place, and displace well to clean seawater above liner top. POH LD DP. 9. R/U and RIH with Halliburton 2 YW' dpc perforating guns. Perforate per Halliburton recommendation. POOH. 10. Run 4-1/2", 12.6# L-80 completion tying into the 4-1/2" liner top. 11. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -2200' and secure the well. 14. Rig down and move off. Post-Riq Work: 1. Install wellhouse and flow lines. 2. MIRU siickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. Run slickline-conveyed CNL to determine GOC. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 06/07/03 06/20/03 ;ANNE© JUN 0 9 2.003 DSlS-07B Application for Sundry 'FREE = , FMC GEN 3 WELLHEAD = CIW A CTUA TOR= BAKER ~,B. ELEV = 67' BF. ELEV = KOP -- 2796' Max Angle -- 98 @ 12619' Datum MD = 12317' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2395' Minimum ID = 1.995" @ 11854' TOP OF 2-3/8" LNR I 4-1/2"TBG, 12.6#,L-80,0.0152bpf, ID=3.958" Id 4020' I TOP OF 3-1/2" TBG Id 4020' TOPOF 7" LNR Id 10014' 10193' I TOPOF 2-3/8" LNR, 4.6# Id 11854' 12002' I 7" LNR, 26#, NT-80 Id 12452' PERFORATION SUMMARY REF LOG: MWD-RESISTIVITY ON 02/20/94 ANGLEATTOP PERF: 84 @ 12950' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 12950-13100 S 08/14/00 1-11/16" 4 13156-13158 S 08/14/00 1-11/16" 4 13158-13160 O 08/14/00 1-11/16" 4 13400-13558 O 08/14/00 1-11/16" 4 13640-13835 O 08/14/00 15-07B SAFETY NOTES: 71)° @ 12127' AND 90° @ 12230' 2106' [-~ 4-1/2"CAMCOTRDPSSSV NIP, ID:3.812" I GAS LIFT MANDRELS 4018' I~ 4'1/2"X3'l/2"x°l 11854' 11894' 11946' 11968' 11989' 12002' Id BAKER DEPLOYMENT SLEEVE I 1-13-1/2" OTIS X NIP, ID: 2.813" (BEH. LNR) I 13-1/2" PARKER SWN NIP, ID = 2.76" I I (BEH. LNR)- MILLED OUT 3-1/2" TUBING TAIL WLEG [ 12013' I-'1 ELMD'FI' LOGGED 04/10/94 7" WINDOW 12114 '- 12118' ~-~ 13838' ]2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID= 1.995" Id 13875' DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 05/29/03 PGS Corrections (pre-rig) 09/25/00 SlS-Isl CONVERTEDTO CANVAS 01/23/01 SIS-MD FINAL 08/15/00 B SIDETRACK 02/10/02 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: 15-07B PERMIT No: 200-0980 AP1 No: 50-029-21166-02 SEC 22, T11N, R14E BP Exploration (Alas ka) Permit to Drill 2000980 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 15-07B Operator BP EXPLORATION (ALASKA) INC MD 13875 TVD 8730 Completion Dat 8/14/2000~'''~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-21166-02-00 UIC N REQUIRED INFORMATION Mud Log N.._9 Sample N__9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret Name k ~_k~~''~ Log Log Scale Media (data taken from Logs Portion of Master Well Data Maint) MWD Survey Report MWD Survey Report MCNL 2 9753 9999 MD GR 5 TVD GR 1 LIS Verification Interval Run OH I No Start Stop CH Dataset Received Number Comments 11718 13815 Case 12100 13880 Open FINAL FINAL 12080 13875 FINAL 13815 11718 CH 1 CH FINAL 12100 13880 oh FINAL 12133 12875 oh FINAL 12133 13875 oh FINAL oh 10/3/2000 09753.---'1'~718-13815 4/20/2001 09999 ~r2'1'00-13880 2/2/2001 Digital Data 2/2/2001 12080-13875 Paper Copy 10/3/2000 13815-11718 5/10/2001 999~r'"'~100-13880 Digital Data 5/10/2001 12133-12875 BL, Sepia 5/10/2001 12133-13875 BL, Sepia 5/10/2001 LIS Verification Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Chips Received? Analysis R ~.c.~.iv~d ? Daily History Received? l~r~. / N Formation Tops ~_~/N Comments: Permit to Drill 2000980 DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Well Name/No. PRUDHOE BAY UNIT 15-07B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21166-02-00 MD 13875 TVD 8730 Completion Dar 8/14/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N Date: 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 99501 Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska 15-07B Contains the following: I/LAS Format disk VFilm q/Measured Depth GR print q/TVD-GR print Sent By: JosefBerg Receive d B~"~~c~/'_'~_~12t~ txO~ Date: April 20, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED I-iAY 10 2001 Alaska Oil & Gas Cons. Commissior~ Ancflomge 9~25~00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'n'N: Sherrie NO. 544 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-23A 20279 MCNL (PDC) ~ ~<~q,- 000623 I I 1 D.$. 5-10B 20330 MCNL '1~ ~1 ~' I 000728 I I 1 D.S. 7-35 20309 RST ~ c~-O 000712 I I 1 D.S. 15-07B 20353 UCNL ~ 4~,...t ,<~'"~ 000813 I I 1 K t. Cl v SlGNE~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. OCT ~[0il& Gas [,'0ns. ~u.,,,,,~.--- '' Anchorage - STA'T'E OF ALASKA ALAS. . OIL AND GAS CONSERVATION COMk .;ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well o, FI Gas I--I Suspended F'i Abandoned I--I Service I--I.______ 2. Name of Operator ~]'~ 7. Permit Number BP Exploration (Alaska), Inc. ~~/~/_ 200-098 3. Address ~ 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612 B,~o~ 50-029-21166-02 4. Location of well at sudace ........... ~" 9. Unit or Lease Name 1526' FNL, 3922' FEL, Sec. 22, T11N, R14E, UM (asp's 677294, 5959985) ; ;~' ' ,:;-~ :.:' · Prudhoe Bay Unit ~ :i.:.. 10. Well Number At Top Producing Interval~ 2289' FNL, 4014' FEL, SEC 14, T11N, R14E, UM (asp's 682368, 5964626) i 15-07B At Total Depth i ~" :. :11. Field and Pool 930' FNL, 3220' FEL, SEC 14, T11N, R14E, UM (asp's 683127, 5966004) ;, ............ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 67 feetI ADL 28307 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp. Susp. Or Aband. 115. Water Depth, it offshore 16. No. of Completions August 5, 2000 August 12, 2000 August_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 21. Thickness of Permafrost 13875' MD /8730' TVD 13838' MD /8731' TVD YES r~ No E]I 2106' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & Mere GR/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 80 30" 2000 Sx Poleset 13-3/8" 72# L-80 Surface 2395' 17-1/2" 1850 Sx PF E &400 Sx PFC 9-5/8" 47# L-80 Surface 10193 12-1/4" 500 Sx Class G & 300 Sx PFC 7" 26# UT-80 10014' 12114' 8-1/2" 305 Sx Class G 2-3/8" 4.6# L-80 11854' 13875' 3.0" 14 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING REC® interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 4020' 12326' 3-1/2" 12002' 11946' 12950' - 13100' MD; 8736' - 8737' TVD; @ 4 SPF 13156' - 13360' MD; 8736' - 8728' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13400' - 13558' MD; 8727' - 8731' TVD; @ 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13640' - 13835' MD; 8734' - 8732' TVD; @ 4 SPF (See Sidetrack Summary for details) 27. ~.J I \ i ~J i I ~/'1. L,,, PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 24, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/27/2000 3.3 Test Pedod >I 2644 Flow Tubing Casing Pressure Calculated OIL-BBL :GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -299 psi 24-Hour Rate > 2079 5496 0 28. CORE DATA Brief description of lithology, porosity, lractures, 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 July 12, 2000 (Permit #200-098) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAM E Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone lB GEOLOGIC MARKERS MEAS. DEPTH 11322' 11381' 11476' 12130' 31. LIST OF A'FrACHMENTS Summary of 15-07B CT Sidetrack Drilling Operations + Survey. TRUE VERT. DEPTH 8234' 8271' 8333' 8715' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~¢~.~ ,~ ' ~Title Coil Tubing Drillin,q Engineer Larnar L. Gantt Date INSTRUCTIONS Prepared by Paul Rauf 564-5799. 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 repoded in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21-' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27." Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ~ ~,.~_,,,%:?-.[..~ ,., ~ ~ .... Form 10-407 15-07B DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 7/28/2000: 7/29/2000: 7/30/2000: 7/31/2000: 8/03/2000: 8/04/2000: 8/05/2000: 8/06/2000: 8/07/2000: 8/08/2000: 8/09/2000: 8/10/2000: 8/11/2000: 8/12/2000: 8/13/2000: 8/14~2000: 8/15/2000: 8/19/2000: MIRU CTU (service unit). PT BOPE. RIH & milled X Nipple. Milled cement to 12080' MD & POOH. RIH & milled pilot hole to 12112'. POOH. RIH & commenced window milling operations through the 7" casing. Drilled to 12128'. Verified casing was penetrated. TOW = 12114', BOW = 12118', Pumped Biozan sweep. POOH. RIH & dressed window. Drilled OH to 12133'. Pumped Biozan & POOH. RD. MIRU Nabors CDR1. Rig accepted 8/02/2000 @ 2100 hrs. NU BOP. Continued RU. PT'd BOPE. Performed rig maintenance. RIH & tagged 12133'. New mud. Performed LOT to EMW of 9.17 ppg. Drilled to 12272'. Drilled to 12550' & POOH. RIH & drilled to 12647'. Drilled to 12954' & POOH. RIH & drilled to 13240' - became stuck. Freed CT w/Crude. Drilled to 13660'. POOH. RIH & drilled to 13799'. Drilled to 113829' & POOH. PT'd BOPE. RIH & logged well for correlation. Drilled to TD @ 13875' MD. Cleaned OH & spotted new mud. POOH. MU liner. RIH w/2-3/8" FL4S liner & landed it @ 11875'. TOL = 11854'. Sheared f/liner - verified release. Pumped 14 bbls of 15.8 ppg LARC to cement liner in place. Unstung f/flapper valve & contaminated cement w/Biozan. Jetted contaminated cement f/wellbore. POOH. RIH w/Mere CNL logging tools & logged well f/11750' to PBTD @ 13838'. Spotted new mud. POOH. PT'd liner to 2000 psi - lost 180 psi in 30 min. RIH w/CT conveyed perf guns & shot 707' of initial perforations f/: 12950' - 13100' MD (Zone 1) 13156'- 13360' MD (Zone 1) 13400'- 13558' MD (Zone 1) 13640'- 13835' MD (Zone 1) Used 1-11/16" carriers & shot all perfs @ 4 SPF. POOH w/guns. ASF. FP'd well. Set BPV. ND BOP. RDMOL. Rig released 2230 hrs 8/14/2000. Installed GLV's. Placed well 15-07B on initial production & obtained a valid well test. Sidetrack Summary Page 1 J~'~" * ' '" LEGEND T Wcll~x~[h: (15.07115~070) BP Amoco BPAmoco BAKER I :' { .? ii.: ~.i" ~ I ...... 15-07(1( ..... 5-07A)) WELLPATH DETAILS ~ '~' ~ '~ .:.'"'/....~'~".' .' ':~, Dip Angle: 80.79 15.070 r' .... ~ ~'~y~::'.~?]~[' .:~ ~.:.'~......~ :::..:'..[.~- Parent Wellpath: 15-07A Tie on MD:12080.00 V~lcal Section Origin: Slot - (0.00,0.~) Ve~lcal Section Angle: 45.40' ' ......... j .......................... ~ ..................... ~ ................................................ ~ .............................................. Rig: CDR I " ~ ~ / 15-~07,15-07071an ~1 J : Depth Reference: 10: 07 ~994 ~:00 66.52fl ~ ~ ~ REFERENCE INFORMATI~ ~ ~ ~ co.o~l.~,o (~),o,~,~: w~, c~,,,~o: ,s.o7 Tru~ N~ 6000 ................................................................................. ~ ........................................................... ~ ........................................................ Vor ca (TVD) Roforonce: FIold - Moae Soa L~vol ~ } 15-07B T1,2 [ Secton(VS)Roferonce: Slot. 000,0~) } ~ ~ / /~ Measured Depth Rolerence: 10: O72/4/1994 ~ ~ 665 a~ve Mean Sea Love } ~ ~ ~ ~ ~1 I b-O / ~ J '. Calculalion Method: Mini .... C ....... ~ ~ ~ ~ No TVD MD Anno~ o~No TVO +N-8 +E W T~ ge ~ : -_ ~ ~ I/ ~ / ooo ............................................................................................................ ............ ~oo ~. ~ II / ~ ... ~ [ .............. ~ ~ .......... , , ............................. y.. ~ "' 4500' ' "'"'r '' ........... :. ........... , ........... .......................................................................................... , ................ = '~3 ' ~ ~X = 4500 5000 5500 6000 6500 7000 7500 . ..~ ~ [ ~ W~s,(-),~s,(+)[~OO~n] · 8500 ..... ~ · ~ ~ ~ ~ ~ ) Kick-o~ Point I I ...... : _ [1~07BT1.1 I I I~07(15~7A) ] [~ ] , 115-07 (1S~7) I 9000" · .~: ~ 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Ve~icalSection at45.40°[500ft/in] Prepared by Baker Hughes INTEQ I nd of Well Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: BP Exploration Alaska, Inc. Rig: CDR 1 Field: Prudhoe Bay Unit RKB H~ght: 66~20 Well: 15-07B (Drilled ~om 15-07A) Vertic~ Sect. Plane: 37.920 Job No: 68153 Mag. Declination: 27.115 AFE No: AP-1561 GAd Correction: 1.340 API No: 50-029-21166-02 Job Start Date: ................ Bm Rep: ii~iii~~ii~iiMh~(~iiiii: Job End Date: Survey Date: Survey Type: Meas. Incl. TRUE TRUE Subsea Coords. - True Coords. - ASP Dogleg Verfic~ Depth Angle Azi. V. Depth TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section (R) (deg) (deg) (n) (n) (a) (a) Lat. (Y) Dep. (X) (°/100n) (ft) 12080.00 63.43 48.35 8691.44 8624.92 4496.46 5146.61 5964602.35 682332.83 0.00 6821.69 12127.22 74.40 43.00 8708.41 8641.89 4527.23 5178.01 5964633.85 682363.50 25.51 6865.66 12154.00 81.50 35.20 8714.00 8647.48 4547.54 5194.49 5964654.54 682379.49 38.90 6891.65 12185.09 86.30 34.89 8717.31 8650.79 4572.85 5212.23 5964680.26 682396.63 15.47 6922.06 12230.12 90.43 24.34 8718.59 8652.07 4611.92 5234.44 5964719.84 682417.91 25.15 6965.30 12268.00 88.20 18.40 8719.05 8652.53 4647.17 5248.23 5964755.41 682430.86 16.75 6999.88 12301.00 87.01 10.60 8720.43 8653.91 4679.07 5256.48 5964787.48 682438.36 23.89 7028.15 12343.00 86.00 1.49 8722.99 8656.47 4720.71 5260.89 5964829.22 682441.79 21.78 7060.53 12379.00 87.40 352.40' 8725.07 8658.55 4756.56 5258.98 5964865.01 682439.03 25.51 7084.34 12407.00 91.60 347.00; 8725.31 8658.79 4784.09 5253.97 5964892.41 682433.38 24.43 7100.11 12438.00 89.90 341.50 8724.91 8658.39 4813.91 5245.56 5964922.03 682424.26 18.57 7115.06 12469.00 88.40 346.00 8725.37 8658.85 4843.66 5236.89 5964951.56 682414.89 15.30 7129.78 12494.00 88.40 352.00 8726.07 8659.55 4868.18 5232.13 5964975.96 682409.55 23.99 7143.60 12514.00 89.03 355.87 8726.52 8660.00 4888.06 5230.01 5964995.78 682406.97 19.60 7156.06 12563.00 93.33 2.20 8725.51 8658.99 4937.01 5229.19 5965044.69 682404.99 15.61 7189.84 12587.00 97.40 7.12 8723.26 8656.74 4960.81 5231.12 5965068.53 682406.36 26.53 7207.94 12619.00 97.70 10.30 8719.06 8652.54 4992.16 5235.93 5965099.99 682410.43 9.90 7233.37 12651.00 96.06 13.80 8715.22 8648.70 5023.23 5242.56 5965131.20 682416.32 12.01 7259.91 12689.00 93.50 16.10 8712.05 8645.53 5059.81 5252.33 5965168.00 682425.23 9.04 7292.55 12718.00 90.90 18.39 8710.94 8644.42 5087.48 5260.92 5965195.86 682433.16 11.94 7318.09 12748.00 87.70 20.10 8711.31 8644.79 5115.80 5270.80 5965224.40 682442.38 12.09 7345.02' 12780.00 86.00 23.60 8713.07 8646.55~ 5145.45 5282.69 5965254.32 682453.56 12.14 7374.30 12831.00 84.90 19.10 8717.111 8650.59 5192.78 5301.20 5965302.08 682470.94 9.06 7420.72 12873.00 83.40 15.60 8721.40 8654.88 5232.66 5313.66 5965342.23 682482.46 9.03 7457.59 12912.00 82.40 12.00 8726.22 8659.70 5270.23 5322.89 5965380.01 682490.80 9.51 7490.55 12948.00: 84.40 10.30 8730.36 8663.84 5305.32 5329.80 5965415.25 682496.88 7.27 7520.10 12982.00] 90.50 10.30 8731.87 8665.35 5338.72 5335.87 5965448.78 682502.16 17.94 7547.88 13009.00 90.40 8.19 8731.66 8665.14 5365.37 5340.21 5965475.52 682505.87 7.82 7569.68 13037.00 89.50 12.39 8731.68 8665.16 5392.91 5345.21 5965503.18 682510.22 15.34 7592.58 13072.00 91.20 17.30 8731.47 8664.95 5426.73 5354.17 5965537.19 682518.38 14.84 7622.71 13105.00 90.10 22.90 8731.09 8664.57 5457.70 5365.51 5965568.43 682528.98 17.29 7652.53 13174.00 90.40 26.80 8730.79 8664.27 5520.30 5394.50 5965631.69 682556.49 5.67 7717.13 13201.00 91.10 31.00 8730.44 8663.92 5543.93 5407.54 5965655.62 682568.97 15.77 7743.01 13229.00 92.10 34.90 8729.66 8663.14 5567.41 5422.76 5965679.45 682583.63 14.37 7770.34 13272.00 92.10 40.89 8728.08 8661.56 5601.31 5449.15 5965713.96 682609.20 13.92 7812.92 13307.00 95.09 47.60 8725.88 8659.36 5626.32 5473.50 5965739.53 682632.96 20.95 7847.82 13335.00 93.40 50.00 8723.81 8657.29 5644.71 5494.51 5965758.41 682653.53 10.46 7875.69 13360.00 91.75 51.77 8722.69 8656.17 5660.46 5513.88 5965774.62 682672.52 9.67 7900.55 13410.00 90.80 59.90 8721.57 8655.05 5688.51 5555.21 5965803.63 682713.17 16.37 7949.67 13438.00 89.20 64.40 8721.57 8655.05 5701.59 5579.96 5965817.28 682737.61 17.06 7976.47 13457.00 87.70 68.30 8722.09 8655.57 5709.20 5597.35 5965825.31 682754.82 21.98 7994.21 13490.00 86.30 71.80 8723.81 8657.29 5720.45 5628.32 5965837.28 682785.51 11.41 8024.15 13535.00 89.40 68.70 8725.50 8658.98 5735.64 5670.64 5965853.47 682827.45 9.74 8064.95 13570.00 88.70 72.90 8726.08 8659.56 5747.15 5703.68 5965865.75 682860.21 12.16 8096.55 13596.00 88.90 72.50 8726.63 8660.11 5754.88 5728.50 5965874.06 682884.84 1.72 8119.65 13655.00 86.70 68.30 8728.89 8662.37 5774.65 5784.02 5965895.13 682939.88 8.03 8173.06 Meas. Incl. TRUE TRW ~ Subsea Coords. - True 9ords. - ASP Dogleg Vertical Depth Angle Azi. ¥. Dept. TVD N(+)/S(-) E(+)/W(-) N(~. ~-) E(+)/W(-) Severity Section (~) (deg) (deg) (fO (~) (R) (~) Lat. (Y) De~. (X) (°/IOOf t) (ft) 13690.00 87.90 67.90 8730.54 8664.02 5787.69 5816.46 5965908.93 682971.99 3.61 8205.31 13715.00 91.10 63.00 8730.76 8664.24 5798.07 5839.19 5965919.85 682994.47 23.41 8228.79 13746.00 93.10 60.90 8729.62 8663.10 5812.63 5866.53 5965935.05 683021.46' 9.35 8258.48 13772.00 91.80 58.50 8728.51 8661.99 5825.74 5888.95 5965948.68 683043.56 10.49 8283.65 13808.00 92.46 52.48 8727.17 8660.65 5846.11 5918.58 5965969.75 683072.70 16.81 8319.05 13839.00 92.30 50.36 8725.88 8659.36 5865.42 5942.79 5965989.63 683096.45 6.85 8349.851 13875.00 92.30 50.36 8724.44 8657.92 5888.37 5970.49 5966013.22 683123.60 0.00 8385.69 BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco F'~ld: Prudhoe Bay Site: PB DS 15 i WeH: 15-07 ~ Weapath: 15-O7B Date: 1/2212001 Time: 15:14:24 Page: 1 Co-ordinate(NE) Reference: Well: 15-07, True North Vertical (TVD) Reference: 10: 07 2/4/1994 00:00 66.5 Section (VS) Reference: Well (0.00E,0.00N,45.40Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 ft Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1.34 deg Well: 15-07 Slot Name: 1 5-07 Well Position: +N/-S 1125.04 ft Northing: 5959986.03 ft Latitude: 70 17 46.300 N +E/-W 1023.80 ft Easting: 677294.05 ft Longitude: 148 33 51.372 W Position Uncertainty: 0.00 ft Weilpath: 15-07B Drilled From: 1 5.07A 500292116602 Tie-on Depth: 12080.00 ft Current Datum: 10: 07 2/4/1994 00:00 Height 66.52 ft Above System Datum: Mean Sea Level Magnetic Data: 9/11/2000 Declination: 26.96 deg Field Strength: 57481 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 45.40 Survey: MWD Start Date: 8/11/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD ~ :: :~ 12080.00 8695.81 Kick-off Point 13875.00 8728.74 Projected to TD Survey MD Incl Azim TVD~ SSTVD i~ N/S E/W MapN MapE DLS VS ff deg deg ff ff : ff ff ff ff deg/lOOff 12080.00 63.61 48.19 8695.81 8629.29 4487.39 5149.99 5964593.36 682336.42 0.00 6817.73 12127.22 74.40 43.00 8712.71 8646.19 4518.23 5181.37 5964624.93 682367.07 25.04 6861.73 12164.00 81.50 35.20 8718.31 8651.79 4538.53 5197.85 5964645.62 682383.06 38.90 6887.72 12185.09 86.30 34.89 8721.61 8655.09 4563.84 5215.59 5964671.33 682400.20 15.47 6918.12 12230.12 90.43 24.34 8722.90 8656.38 4602.91 5237.80 5964710.91 682421.48 25.15 6961.36 12268.00 88.20 18.40 8723.35 8656.83 4638.16 5251.59 5964746.48 682434.44 16.75 6995.94 12301.00 87.01 10.60 8724.73 8658.21 4670.06 5259.64 5964778.56 682441.93 23.89 7024.21 12343.00 86.00 1.49 8727.30 8660.78 4711.70 5264.25 5964820.29 682445.36 21.78 7056.60 12379.00 87.40 352.40 8729.38 8662.86 4747.55 5262.34 5964856.08 082442.60 25.51 7080.41 12407.00 91.60 347.00 8729.62 8663.10 4775.08 5257.33 5964883.49 682436.95 24.43 7096.18 12438.00 89.90 341.50 8729.21 8662.69 4804.90 5248.92 5964913.10 682427.84 18.57 7111.13 12469.00 88.40 346.00 8729.67 8663.15 4834.65 5240.25 5964942.64 682418.46 15.30 7125.85 12494.00 88.40 352.00 8730.37 8663.85 4859.17 5235.49 5964967.03 682413.12 23.99 7139.67 12514.00 89.03 355.87 8730.82 8664.30 4879.05 5233.37 5964986.86 682410.54 19.60 7152.13 12563.00 93.33 2.20 8729.81 8663.29 4928.00 5232.55 5965035.77 682408.56 15.61 7185.91 12587.00 97.40 7.12 8727.57 8661.05 4951.80 5234.48 5965059.61 682409.94 26.53 7204.00 12619.00 97.70 10.30 8723.36 8656.84 4983.16 5239.29 5965091.06 682414.00 9.90 7229.44 12651.00 96.06 13.80 8719.53 8653.01 5014.22 5245.92 5965122.27 682419.90 12.01 7255.97 BP Amoco Baker Hughes INTEQ Survey Repo~ Company:~ BP ~ Fk4d: Prudho~ Bay Site: PB DS 15 Well: ~ ~ 1,5-07 wetlpath: ~ 15-07B ii ~i ~ ~ Survey ~ MD? ~ ~ ~ ~ Incl ~ ~ ~ Azim ~ TVD SSTVD ~NiS ~ E/W MapN MapE DLS VS Date: 1/22/2001 Tbne: 15:14:24 Page: 2 Ce~rdiaate(NE) Reference: Well: 15-07, True Norlh Vertical (TVD) Reference: 10: 07 2/4/1994 00:00 66.5 Section (VS) Reference: Well (0.00E,0.00N,45.40Azi) Sar~ey Calculation Method: Minimum Curvature Db: Oracle 12689.00 93.50 16.10 8716.36 8649.84 5050.80 5255.69 5965159.07 682428.80 9.04 7268.61 12718.00 90.90 18.39 8715.25 8648.73 5078.47 5264.28 5965186.94 682436.73 11.94 7314.16 12748.00 87.70 20.10 8715.61 8649.09 5106.79 5274.16 5965215.48 682445.95 12.09 7341.08 12780.00 86.00 23.60 8717.37 8650.85 5136.44 5286.05 5965245,40 682457.13 12.14 7370.37 12831.00 64.90 19.10 8721.42 8654.90 5183.77 5304.56 5965293.15 682474.51 9.06 7416.78 12873.00 83.40 15.60 8725.70 8659.18 5223.65 5317.02 5965333.31 682486.03 9.03 7453.65 12912.00 82.40 12.00 8730.52 8664.00 5261.22 5326.25 5965371.09 682494.37 9.51 7486.61 12948.00 64.40 10.30 8734.66 8668.14 5296.31 5333.16 5965406.32 682500.45 7.27 7516.17 12982.00 90.50 10.30 8736.17 8669.65 5329.71 5339.23 5965439.86 682505.73 17.94 7543.95 13009.00 90.40 8.19 8735.96 8669.44 5356.36 5343.57 5965466.60 682509.44 7.82 7565.75 13037.00 89.50 12.39 8735.99 8669.47 5383.90 5348.57 5965494.25 682513.79 15.34 7588.65 13072.00 91.20 17.30 8735.77 8669.25 5417.72 5357.53 5965528.27 682521.95 14.84 7618.78 13105.00 90.10 22.90 8735.40 8668.88 5448.69 5368.87 5965559.50 682532.55 17.29 7648.60 13174.00 90.40 26.80 8735.10 8668.58 5511.29 5397.86 5965622.76 682560.06 5.67 7713.20 13201.00 91.10 31.00 8734.74 8668.22 5534.92 5410.90 5965646.69 682572.54 15.77 7739.08 13229.00 92.10 34.90 8733.96 8667.44 5558.41 5426.12 5965670.52 682587.20 14.37 7766.40 13272.00 92.10 40.89 8732.38 8665.86 5592.30 5452.51 5965705.03 682612.77 13.92 7808.99 13307.00 95.09 47.60 8730.19 8663.67 5617.31 5476.86 5965730.60 682636.53 20.95 7843.89 13335.00 93.40 50.00 8728.11 8661.59 5635.70 5497.87 5965749.48 682657.10 10.46 7871.76 13360.00 91.75 51.77 8726.99 8660.47 5651.45 5517.24 5965765.69 682676.09 9.67 7896.62 13410.00 90.80 59.90 8725.88 8659.36 5679.50 5558.57 5985794.70 682716.75 16.37 7945.73 13438.00 89.20 64.40 8725.68 8659.36 5692.58 5583.32 5965808.36 682741,18 17.06 7972.54 13457.00 87.70 68.30 8726.39 8659.87 5700.20 5600.71 5965816.38 682758.39 21.98 7990.27 13490.00 86.30 71.80 8728.12 8661.60 5711.44 5631.68 5965828.35 682789.08 11.41 8020.22 13535.00 89.40 68.70 8729.81 8663.29 5726.63 5674.00 5965844.54 682831.02 9,74 8061.01 13570.00 88.70 72.90 8730.39 8663.87 5738.14 5707.04 5965856.82 682863.78 12.16 8092.62 13596.00 88.90 72.50 8730.93 8664.41 5745.87 5731.86 5965865,13 682888.41 1.72 8115.71 13655.00 86.70 68.30 8733.20 8666.68 5765.64 5787.38 5965886.21 682943.45 8.03 8169.13 13690.00 87.90 67.90 8734.85 8668.33 5778.68 5819.82 5965900.01 682975.57 3.61 8201.38 13715.00 91,10 63.00 8735.06 8668.54 5789.06 5842.55 5965910.92 682998.04 23.41 8224.85 13746.00 93.10 60.90 8733.93 8667.41 5803.63 5869.88 5965926.13 683025.03 9.35 8254.55 13772.00 91.80 58.50 8732.82 8666.30 5816.73 5892.31 5965939.76 683047.14 10.49 8279.71 13808.00 92.46 52.48 8731.48 8664.96 5837.10 5921.94 5965960.82 683076.28 16,81 8315.12 13639.00 92.30 50.36 8730.19 8663.67 5856.42 5946.15 5965980.70 683100.02 6.85 8345.92 13875.00 92.30 50.36 8728.74 8662.22 5879.36 5973.85 5966004.29 683127.17 0.00 8381.75 BP Amoco 45O0 5O0O West(.)/East(+) [5001tlin] 7000 7500 7500 8000 8500 Vertical Section at 45.40* [500ft/in] 95OO 1O00O 1/22/2001 3:15 PE ALASKA OIL AND GAS CONSERVATION COI~ilSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar L. Gantt PAI Coil Tubing Drilling Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 15-07B Phillips Alaska, Inc. Permit No: 200-098 Sur Loc: 1526'FNL, 3922'FEL, Sec. 22, T11N, R14E, UM Btmhole Loc. 706'FNL, 2805'FEL, Sec. 14, T11N, R14E, UM Dear Mr. Gantt: 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE CQlylMISSION DATED this ] 2."m day of July, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill J'--J Redrill J~] I lb. Type ofwell. Exploratory r-J Stratigraphic Test J~J Re-entry J--J Deepen J~J I Service J~J Development Gas J~J Single Zone r~J 2. Name of Operator 5. Datum elevation (DF or KB) Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1526' FNL, 3922' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 2588' FNL, 4456' FEL, Sec. 14, T11N, R14E, UM At total depth 706' FNL, 2805' FEL, Sec 14, T11 N, R14E, UM RKB 67 feet Property Designation ADL 28307 16. To be completed for deviated wells Kickoff depth: 12095' MD Maximum hole angle 7. Unit or property Name Prudhoe Bay Unit 8. Well number 15-07B 9. Approximate spud date July 31, 2OOO Development Oil J~] Multiple Zone r-J 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 11. Type Bond (see 20AAC 25.0251) Statewide Number #U-630610 Amount $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 28302, 706' @ TD feet No Close Approach feet 2560 14350 MD / 8746 TVD 17. Anticipated pressure (see 20 AAC 25.035 91.4° Maximum surface 2459 psig e)(2)) Attotal depth (TVD) 3339 psig @ 8800' 18. Casing program I Setting Depth size )ecifications Bo' Hole MD 3" 2-3/8" 14350' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 13545 feet Plugs (measured) tree vedical 8769 feet :om 8746' Quant~ of Cement (include stave data) 13 bbls 15.8 ppg Cement o 9 2000 Effective Depth: measured 13545 feet tree vertical 8763 feet Casing Length Size Cemented Conductor 80' 20" 2000 Sx Poleset Surface 2328' 13-3/8" 1850 Sx PF E & 400 Sx PFC Production 10176' 9-5/8" 500 Sx Class G & 300 Sx PFC Liner 2438' 7" 305 Sx Class G Slotted Liner 140' 4-1/2" uncernented Junk (measured) Measured depth True Ve~icaldepth 80' 80' 2395' 2395' 10193' 7558' 12452' 8763' 13545' 8763' Pedoration depth: measured tree vertical 12214'- 12234'; 12272' - 12292'; (slotted liner interval @ 12453'- 13521'). 8763'- 8763'; 8758'- 8761'; (slotted liner interval @ 8763'- 8763'). 20. Attachments Filing fee ~] Property Plat D BOP Sketch I~1 Diverter Sketch D Drilling program r~ Drilling fluid program Time vs depth plot [--] Refraction analysis D Seabed report D 20AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my k~owledg~ Signed L~ {~'~ Title: PAI CoilTubing Drilling Supervisor Commission Use Only Questions? Call Stephen Ward @ 265-1305. Date ~t~/~--~/~ O I~repared b)/ Pau/ Rauf 263-4990 Permit Number Conditions of approval Samples required Hydrogen sulfide measures ,J~ Yes Required working pressure for BOPE J~J 2M; 50- 02---~ '- ,~///r~ ~ ~ / ~1,~ ~) i,or other requirements ~ Yes ~ No Mud logrequired ~ Yes ~ No D No Dire~io~alsu~eyrequired ~ Yes D No ~ 3U; ~ 5U; ~ 10U;D ~3500psiforCTU Other:. Approved by ORIGINAL SIGNED BY D Taylor Seamount by order ol '~*/C~ Commissioner the commission Date ~ 0 ~ Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 15-07B CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Intended Procedure: Service CTU: Cement squeeze the current perforations and plugback the existing completion to - 12000' md. Mill cement from 3-1/2" TT, Mill pilot hole in 7" from - 12000' - 12080' and mill window in 7" casing at -12080' md. CT Drilling Rig · Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. · Directionally drill 3" x 1700' horizontal well to access Zone 1 reserves. · Run memory CNL log. · Run and cement 2-3/8" liner to TD. · Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. June 28, 2000 DS 15-07B Potential Drilling Hazards POST ON RIG H2S was measured at 3 ppm back in 9/96. Insure that all H2S monitoring equipment is operational. BHP: 3339 psi @ 8800' ss (7.3 ppg EMW) based on offset well. Plans are to drill with 8.5 ppg Flopro. This will provide an overbalance on the formation of approximately 549 psi. Maximum anticipated WHP w/ full column of gas: -2459 psi assuming 0.1 psi/ft gas gradient. GOC is currently at - 11917' md. June 28, 2000 DS 15-07B. ,'OPOSED CT HORIZONTAL 3MPLETION Camco TRDP SSSV @ 2106' ~- 4-1/2", 12.6#, L-80 Production Tubing to 4018' 3-1/2", 9.3#, L-80 Production Tubing: 4018' - 12002' 7" Liner Top @ 10014' · 9-5/8" Shoe @ 10243' Behind liner: X NPL @ 1 SWN @ 11989' Top of 2-3/8" liner @ -11850' 7" Baker SABL Packer @ 11946' 3-1/2" TT @ 12002' WindoTM cut in 7" @ ~ 12095' 7"x 4-1/2" TIW SS Packer @ 12326' 7" Shoe @ 12452 3" Open hole 2-3/8" Liner Cemented & Perf'd I Existing 4-1/2" Slotted Liner Isolated w/Cement TD @ 14350 4-1/2" shoe at 13545' PHILLIPS Alaska, Inc. WELLPATH DETAILS Plan 500292116602 Parent Wellpnth: 15-07A Tleon MD: 12080.~0 VarflcalSectlonOrlgln: UeerDeflned(5081.60,4430.50) VartlcMSectlonAngle: 37.92° Rig: CDR Depth Reference: 15-07A 67.0Oft ANNOTATIONS No, TVD MO Annotation 21 8583,83 11981,00 Tl(~-In Point 8030,14 12080,00 1Kick-off Point 3 8070.00 12242,50 8870.62 12442,20 8879,2~ 12542,00 32 8086.00 13090,40 98 8877,86 13480,00 8870,00 13781.40 ~ 10 8{378.0O 14346,30 TD BAKER HUGHES INTEQ LEGEND ........ 15-07 (15-07) 15-07 (15-07A) Plan 15-07B Wetlp~,O~: ( 15-071Phm 15-070) All Anglc~ Relative [ To Tmc Nt~flh CO~T~m't Ihh~rm:~tlqn' Tmc No~h: 0.(X) Magnetic Nt Jaker, u~j REFERENCE INFORMATION Co-ordinate (N/E) Reference: Wellhead: 15-07, True North 6000 .... Vertical (TVD) Reference: Field- Mean Sea Level Section (VS) Reference: User Defined (5081.60,4430,50) , Measured Depth Reference: 1 5-07A 67.0 above Mean Sea Level Calculation Method: Minimum Curvature ..~ 1 8070.0D 6848,~2 §737,68 15-07BT2I~. ..] J15 07 (15 07A} I 2 8o7§.oo 8o71,61 6388,34 15-07B T3eTD 3 50e$.oo 1~420,28 6374,62 15-07B T1 55oo-! ..! .?.m I / :: i :: ,.,i .............................. : ................................ , ......................... 5000 ........................................................................... I i i ~ ~-~ ~./ , !i i i i i' ........... ~: .................... i ::' ........... ~:i ........... ::' ................................ i~ ........ ? .......... ~ ........... [~ ........... ::~ .......... ' .......... ~ i ......... :~'" : ~ i ~6.o~s.o~i L :~ i i ~ i i ' { ....... ~ : ..J. [ ................................... ~~-~ .....................! ................... ; ...................... =: ........ i ...... ~ ................. ! ...... ~ ..... ~ ......... : ........ ~. ~. ~ ...... "'. ....... .'"~'. · '"j ' : 45oo,.,,i ~ ! ~ ~ ' ~" ~"'~ ............................... ~ ........... ' ........... f ................................. ~ ...................... ~ ...................... ~ ................................. 1 ....................................................... } ............................................ : .......... I ............................................... ! ............. ~ [ ~.X 4500 5000 5500 6000 6500 7000 7500 "'_~ 8000 ...~ ----~,,~ West(-)/East(+) [500ft/in] '"i : ! : 8500 .................................................................................................. ~ ............... i ............................................... '"i '"i I 15-07 (iS-07) oooo .-! ......... i ........... ~ ........... ~ ........... 1 ........... 1 .......... ~ ........... ~ ........... ~ ........... I ........... -1000 -500 0 500 1000 1500 2000 2500 3000 Vertical Section at 37.92° [500ft~n] Prepared by Baker Hughes INTEQ Proposal Calculations E~G~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: PHILLIPS Alaskaz Inc. Vertical Sect. Plane: 37.920 TRUE Job No: 0 Field: Prudhoe Bay Unit Mag. Declination: 27.162 AFE No: 0 Well: 15-07B Plan #1 Grid Correction: 1.340 API No: 50-029-21166-02 Rig: CDR Total Correction: 25.822 BHI Rep: Surface Location Dip: 80.724 Job Start Date: 00-Jan-00 X: 677294.4 RKB Height: 67.000 Job End Date: 00-Jan-00 Y: 5959985.5 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 (det~) (de~) (ft) Lat. (Y) Dep. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 11981.00 59.44 52.54 8583.83 4430.47 5081.61 5964533.59 682271.01 0.00 -0.02 0.00 0.00 0.00 Tie-in Point 12000.00 60.96 51.19 8593.27 4440.65 5094.57 5964544.08 682283.73 10.10 15.98 -38.12 7.98 -7.13 12011.00 61.84 50.42 8598.54! 4446.76 5102.06 5964550.35 682291.07 10.10 25.40 -37.44 8.04 -6.96 12046.00 62.84 49.07 8614.79: 4466.79 5125.71 5964570.93 682314.26 4.45 55.74 -50.41 2.86 -3.86 12078.00 63.43 48.35 8629.25' 4485.63 5147.16 5964590.27 682335.26 2.73 83.78 -47.59 1.84 -2.25 12080.00 63.59 48.21 8630.14' 4486.82 5148.50 5964591.49 682336.57 10.16 85.54 -38.10 8.00 -7.00 Kick-off Point 12100.00 66.51 45.83 8638.58 4499.18 5161.76 5964604.16 682349.53 18.14 103.44 -36.93 14.60 -11.88 12125.00 70.21 43.01 8647.80 4515.78 5178.01 5964621.13 682365.40 18.14 126.53 -35.93 14.79 -11.31 12150.00 73.95 40.31 8655.49 4533.55 5193.82 5964639.27 682380.78 18.14 150.26 -34.89 14.96 -10.79 12175.00 77.72 37.71 8661.61 4552.38 5209.07 5964658.45 682395.58 18.14 174.48 -34.06 15.09 -10.39 12200.00 81.51 35.19 8666.12 4572.16 5223.67 5964678.56 682409.72 18.i4 199.06 -33.42 15.18 -10.09 12225.00 85.32 32.721 8668.98 4592.75 5237.54 5964699.48 682423.10 18.14 223.83 -32.96 15.25 -9.90 12242.51 88.00 31.001 8670.00 4607.60 5246.76 5964714.54 682431.98 18.14 241.21 -32.68 15.28 -9.80 1 12250.00 88.00 29.65 8670.26 4614.06 5250.54 5964721.081 682435.60 18.00 248.63 -90.00 0.01 -18.01 12275.00 88.01 25.15 8671.13 4636.23 5262.04 5964743.5T 682446.58 18.00 273.19 -89.95 0.04 -18.01 12300.00 88.03 20.65 8672.00 4659.25 5271.75 5964766.75 682455.75 18.00 297.31 -89.80 0.09 -18.01 12325.00 88.07 16.14 8672.85 4682.95 5279.64 5964790.63 682463.08 18.00 320.85 -89.64 0.14 -18.01 12350.00 88.11 11.64 8673.68 4707.20 5285.63 5964815.02 682468.51 18.00 343.67 -89.49 0.18 -18.01 12375.00 88.17 7.14 8674.49 4731.84 5289.71 5964839.75 682472.01 18.00 365.61 -89.34 0.23 -18.01 12400.00 88.24 2.64 8675.27 4756.73 5291.84 5964864.68 682473.55 18.00 386.56 -89.19 0.28 -18.01 12425.00 88.32 358.14 8676.03 4781.71 5292.01 5964889.66 682473.14 i8.00 406.37 -89.05 0.32 -18.01 12442.19 88.38 355.04 8676.52 4798.87 5290.99 5964906.78 682471.72 18.00 419.27 -88.91 0.35 -18.013 "~"~ ~'''' 12450.00 88.38 353.64 8676.74 4806.63 5290.21 5964914.53 682470.76 18.00 424.92 -90.00 0.01 -18.01 12475.00 88.39 349.13 8677.45 4831.34 5286.47 5964939.14 682466.44 18.00 442.11 -89.96 0.03 -18.01 12500.00 88.41 344.63 8678.14 4855.67 5280.80 5964963.33 682460.21 18.00 457.82 -89.83 0.07 -18.01 12525.00 88.44 340.13 8678.83 4879.48 5273.24 5964986.96 682452.09 18.00 471.95 -89.71 0.11 -18.01 12542.00 88.46 337.07 8679.29 4895.30 5267.04 5965002.63 682445.52 18.00 480.62 -89.58 0.14 -18.01 3 12550.00 88.46 338.51 8679.51 4902.70 5264.02 5965009.96 682442.33 18.00 484.60 90.00 0.01 18.01 12575.00 88.47 343.01 8680.18 4926.29 5255.78 5965033.35 682433.54 18.00 498.15 89.96 0.03 18.01 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~) (det~) (ft) Lat. (Y) Dei~. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 12600.00 88.49 347.51 8680.84 4950.45 5249.43 5965057.36 682426.62 18.00 513.30 89.84 0.07 18.01 12625.00 88.51 352.01 8681.50 4975.04 5244.99 5965081.84 682421.61 18.00 529.97 89.72 0.11 18.01 12650.00 88.55 356.52 8682.14 4999.90 5242.49 5965106.63 682418.53 18.00 548.04 89.60 0.14 18.01 12675.00 88.59 1.02 8682.77 5024.88 5241.95 5965131.59 682417.41 18.00 567.42 89.49 0.18 18.00 12680.00 88.60 1.92 8682.89 5029.88 5242.08 5965136.59 682417.42 18.00 571.44 89.37 0.20 18.00 4 12700.00 88.70 3.53 8683.36 5049.85 5243.03 5965156.58 682417.90 8.07 587.78 86.40 0.51 8.06 12750.00 88.96 7.56 8684.38 5099.60 5247.86 5965206.42 682421.57 8.07 629.99 86.37 0.52 8.06 12800.00 89.23 11.59 8685.17 5148.88 5256.17 5965255.89 682428.73 8.07 673.97 86.28 0.53 8.06 12850.00 89.49 15.62 8685.72 5197.47 5267.93 5965304.74 682439.34 8.07 719.52~ 86122 0.54 8.06 12900.00 89.77 19.64 8686.05 5245.11 5283.07 5965352.72 682453.37 8.07 766.411 86.18 0.54 8.06 12950.00 90.04 23.67 8686.13 5291.57 5301.52 5965399.60 682470.72 8.07 814.40 86.15 0.54 8.06 13000.00 90.31 27.70 8685.98 5336.62 5323.19 5965445.14 682491.33 8.07 863.25 86.14 0.54 8.06 13050.00 90.58 31.73 8685.60 5380.03 5347.97 5965489.12 682515.09 8.07 912.73 86.15 0.54 8.06 13098.40 90.84 35.63 8685.00 5420.30 537&80 5965530.01 682540.97 8.07 960.98 86.19 0.53 8.06 5 13100.00 90.84 35.76 8684.98 5421.60 5375.73 5965531.33 682541.88 8.12 962.58! 88.67 0.19 8.12 13150.00 90.93 39.82 8684.20 5461.10 5406.36 5965571.53 682571.57 8.12 1012.56 88.67 0.18 8.12 13200.00 91.02 43.88 8683.35 5498.33 5439.71 5965609.53 682604.04 8.12 1062.43 88.74 0.17 8.12 13250.00 91.10 47.94 8682.43 5533.10 5475.61 5965645.14 682639.12 8.12 1111.92 88.81 0.16 8.12 13300.00 91.18 52.00 8681.44 5565.25 5513.88 5965678.17 682676.63 8.12 1160.801 88.88 0.15 8.12 13350.00 91.25 56.06 8680.38 5594.60 5554.33 5965708.46 682716.38 8.12 1208.821 88.96 0.14 8.12 13400.00 91.31 60.13 8679.26 5621.02 5596.76 5965735.86 682758.18 8.12 1255.73 89.05 0.13 8.12 13450.00 91.37 64.19 8678.09 5644.36 5640.95 5965760.23 682801.81 8.12 1301.30 89.14 0.12 8.12 13460.00 91.38 65.00 8677.85 5648.65 5649.98 5965764.73 682810.74 8.12 1310.24 89.23 0.11 8.12 6 13500.00 91.40 61.70 8676.88 5666.58 5685.71 5965783.49 682846.04 8.26 1346.35 -89.70 0.04 -8.26 13550.00 91.41 57.57 8675.66 5691.84 5728.83 5965809.76 682888.56 8.26 1392.78 -89.78 0.02 -8.26 13600.00 91.41 53.44 8674.43 5720.15 5770.01 5965839.02 682929.07 8.26 1440.42 -89.88 0.01 -8.26 13650.00 91.41 49.31 8673.20 5751.34 5809.06 5965871.12 682967.37 8.26 1489.02 -89.98 0.00 -8.26 13700.00 91.40 45.18 8671.97 5785127 5845.75 5965905.89 683003.26 8.26 1538.34 -90.08 -0.02 -8.26 13750.00 91.38 41.05 8670.75 5821.75 5879.91 5965943.16 683036.56 8.26 1588.10 -90.19 -0.03 -8.26 13781.43 91.37 38.46 8670.00 5845.90 5900.00 5965967.77 683056.08 8.26 1619.51 -90.29 -0.05 -8.26 7 13800.00 91.25 40.00 8669.58 5860.28 5911.74 5965982.43 683067.48 8.31 1638.07 94.44 -0.65 8.29 13850.00 90.92 44.14 8668.63 5897.38 5945.23 5966020'.30 683100.09 8.31 1687.92 94.48 -0.66 8.29 13900.00 90.59 48.29 8667.97 5931.97 5981.32 5966055.72 683135.36 8.31 1737.38 94.56 -0.66 8.29 13950.00 90.25 52.43 8667.60 5963.86 6019.81 5966088.51 683173.10 8.31 1786.19 94.61 -0.67 8.29 · 14000.00 89.92 56.57 8667.53 5992.89 6060.51 5966118.48 683213.10 8.31 1834.10 94.64 -0.67 8.29 14050.00 89.58 60.72 8667.75 6018.90 6103.20 5966145.48 683255.17 8.31 1880.86 94.65 -0.67 8.29 14100.00 89.25 64.86 8668.26 6041.75 6147.65 5966169.37 683299.08 8.31 1926.21 94.63 -0.67 8.29 14150.00 88.92 69.01 8669.06 6061.34 6193.64 5966190.02 683344.60 8.31 1969.92 94.59 -0.66 8.29 14200.00 88.59 73.15 8670.15 6077.54 6240.92 5966207.32 683391.48 8.31 2011.76 94.52 -0.65 8.29 ,~. :...:~ ... ,..,. 14250.00 88.27 77.30 8671.52 6090.28 6289.23 5966221.19 683439.49 8.31 2051.51 94.43 -0.63 8.29 , ~. '.....5 L:':~. i~.~. 14300.00 87.97 81.45 8673.16 6099.50 6338.34 5966231.55 6834'88.37 8.31 2088.96 94.32 -0.62 8.30 14348.32 87.68 85.46 8675.00 6i05.00 6386.30 5966238.18 683536.19 8.31 2122.78 94.18 -0.60 8.30 TD CDR1 Drilling Wellhead Detail ~ CT Injector Head Annular BOP (Hydril),7-1/16" ID i' I ~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Ram Type Dual Gate BOPE 7-1/16" ID with ~ Pipe& Blind/Shear Rams Choke Line to dual Choke Manifold,,, HCR Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M 5,000 psi working pressure Ram Type Dual Gate BOPE 7-1/16" ID with Slip & PipeRams, Kill Line XO spool as necessary Manual Master Valve Hanger 9-5/8" Annulus 13-3/8" Annulus :J ,r ;:.,,:~, ;:, "' .'::,,.:, .~ ..~,/ CDR Rig #1 Alaska LAYOUT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,,, 1. Type of request: Abandon_X 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 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 67 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1526' FNL, 3922' FEL, Sec. 22, T11N, R14E, UM (asp's 677294, 5959985) 15-07A At top of productive interval 9. Permit number / approval number 2588' FNL, 4456' FEL, Sec. 14, T11N, R14E, UM (asp's 681933, 5964317) 194-011 At effective depth 10. APl number 50-029-21166-01 At total depth 11. Field / Pool 1208' FNL, 3110' FEL, Sec. 14, T11 N, R14E, UM (asp's 683243, 5965727) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13545 feet Plugs (measured) ORIGINAL Effective depth: measured 13545 feet Junk (measured) true vertical 8763 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20' 2000 Sx Poleset 80' 80' Surface 2328' 13-3/8' 185o sx PF E & 400 Sx PFC 2395' 2395' Production 10176' 9-5/8' 500 Sx Class G & 300 Sx PFC 10193' 7558' Uner 2438' 7' 305 Sx Cass G 12452' 8763' Slotted Liner 140' 4-1/2' uncemented 13545' 8763' RECEiv,. D Perforation depth: measured 12214' - 12234'; 12272'- 12292'; (slotted liner interval @ 12453' - 13521'). 29 2000 true vertical 8763' - 8763'; 8758' - 8761'; (slotted liner interval @ 8763' - 8763'). Ala~a Oil & Gas Cons, Commission Tubing (size, grade, and measured depth 4-1/2', 12.6~, L-80 Tbg @ 4020' MD; 3-1/2", 9.2#, L-80 Tbg @ 12002' MD. Packers & SSSV (type & measured depth) 4-1/2' TlW SS PACKER W/SCOOP GUIDE SHOE @ 12326' MD; 7' X4-1/2' BAKERSABL-3 PACKER @ 11946' MD. 4-1/2' CAMCO TRDP SSSV @ 2106' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: July 18, 2000 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service , 17. I hereby certify that the loregoing is true and correct to the best of my k~owledge. Questions? Call Stephen Ward @ 265-1305. Signed ar~~ (~' ~ Titie: PAl CoilTubing Drilling Supervisor Date L Prepared b~/Paul Raur263.4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Appr.o.v. al no. Plug integrity__ BOP Test__ Location c,.a.a, ce_ / 7 i Mechanical Integrity Test__ Subsequent form required lO- ApprOved by order of the Commission "~ T'"'~ Commissioner Date 7 Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPUCATE 107 82-~0/~ 02 ~ j Eng~wo~, Colo~o.~ :: ;,, : ,~NOT~V~ FOR AMOUNT OVER $1~0 ~ z~~:"~;~° >~?~-~ _/~~::,'.-~~ COMPANY WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. 2. WELL NAME ,/'.~,'-~O?D~ PROGRAM: exp_ . 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. Permit fee attached .......... ,~,d .~ ........... Lease number appropriate.=~.' ~4~..'~.'~/..." .~ .'¢T/ Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE GEOL AREA Y N Y N Y N Y N N N N N N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to "~:..'~Q~ 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 ................. dev ~ redrll ~ l serv~wellbore seg ann. disposal para req__ ~_~)~c/]) UNIT# ~/"/"~-r~ ~"~ ON/OFF SHORE (L..."'~,/'"( GEOLOGY 30. 31. 32. A/.~ .DATE 33. ~ ~,~O' ~¢~ 34. Permit can be issued w/o hydrogen sulfide measures ..... ,Y,~ Data presented on potential overpressure zones ....... ....4~ ~,~ "¢ Seismic analysis of shallow gas zones .......... _/,,/';~. "~"~ Y N Seabed condition survey (if off-shore) ....... ./...-¢'.... Y N Contact name/phone for weekly progress report~/[exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. -,. · ., **** REEL HEADER **** MWD Ol/O5/O8 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD Ol/O5/O8 64879 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** 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 12100.000: STOP.FT 13880.000: STEP.FT 0.5000: NULL, -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COLrNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE, LOG DATE: API , API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE, F OS1 -Remarks CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ............................... Starting Depth Ending Depth Level Spacing Absent Value PHILLIPS Alaska, Inc. 15-07B Prudhoe Bay Unit 1526' FNL 3922' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray il-AUG-00 500292116602 Value 22 : llN : 14E : MSL : 0 : RKB : 67 : KB : 67 : N/A : N/A : N/A : DIRECTIONAL : Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-07B was drilled to TD @ 13875' MD (8663' SSTVD) on Run 5. (5) The well 15-07B was kicked off at 12080' MD (8630' SSTVD) on Run 1. (6) The interval from 13858' MD (8664' SSTVD) to 13875' MD (8663' 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 (SWS,13-08-00) (8) A Magnetic Declination correction of 27.16 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 17.26 ft. 22.21 ft. 2 17.44 ft. 22.39 ft. 3 18.11 ft. 23.06 ft. 4 18.25 ft. 23.21 ft. 5 17.21 ft. 22.16 ft. CURVE SHIFT DATA BASELINE 12118.8 12129.9 12219.5 12302.6 12316.7 12343.4 12353.3 12407.4 12447.1 12482.4 12524.5 12548.0, 12604.7, 12676.3, 12714.4, 12732.8, 12743.4, 12798 9, 12837 0, 12850 5, 12879 6, 12893 2, 12919 7, 12947 4, 13007 6, 13070 4, 13094 7, 13149 2, 13201 6, 13296 3, MEASURED, 12119 4 12130 7 12220 2 12304 0 12317 9 12344 5 12354 5 12408 4 12448 6 12486 1 12524 5 12547 0 12604 3 12678 3 12715 7 12732.4 12742.0 12795.7 12836.2 12850.7 12879.8 12893.8 12920.7 12953.1 13005.0 13065.9, 13092.0, 13146.9, 13198.1, 13297.5, DISPLACEMENT 0 586914 0 782227 0 783203 1 37012 1 17383 1 17285 1 17383 0 978516 1 56543 3 7168 0 -0.978516 -0.391602 1.95605 1.36914 -0.391602 -1.37012 -3.12988 -0.782227 0.195312 0.196289 0.586914 0.977539 5.67285 -2.54297 -4.49902 -2.73926 -2.34766 -3.52148 1.17383 13311 8 13311 13352 8 13353 13394 9 13389 13476 7 13485 13501 6 13509 13513 2 13521 13527 5 13536 13548 5 13558 13601 9 13601 13682 0 13675 13714.1 13719 13799.8 13800 -0.782227 0.195312 -5.86816 8.41113 8.21582 8.41211 8.60742 10.3672 0 -6.8457 4.88965 0.977539 Tape Subfile: 1 121 records... Minimum record length: 8 Maximum record length: 132 **** FILE HEADER **** MWD .001 bytes bytes 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska, Inc. WN 15-07B FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! 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 13-AUg-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX11 0.0 2 ROP ROPSll 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Size 4 4 Total Data Records: 43 Tape File Start Depth = 12100.000000 Tape File End Depth = 13880.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 Length 4 4 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska, Inc. WN 15-07B FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!! !!!!!!!!!!!!!!!! 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) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR3LX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Total Data Records: 43 Size Length 4 4 4 4 8 Tape File Start Depth = 12100.000000 Tape File End Depth = 13880.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/05/08 64879 01 **** REEL TRAILER **** MWD 01/05/08 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH 12100 12100 12200 12300 12400 12500 12600 12700 12800 12900 13000 13100 13200 13300 13400 13500 13600 13700 13800 13880 0000 5000 0000 0000 0000 0000 0000 0000 .0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GR -999.2500 -999.2500 27.4747 48.9551 37.3592 52.4656 59.0400 20 3229 22 9232 47 5499 27 9858 113 6171 66 6920 69 0240 38 8393 71 9842 64 8429 61 6401 82 9772 -999 2500 ROP -999 -999 77 62 39 34 67 49 86 10 87 16 80 72 19 97 82 58 4 -999 .2500 .2500 5146 7787 9583 1221 8659 6035 7988 2676 4724 2594 5528 4105 4123 7227 5015 7477 7024 2500 Tape Tape File Start Depth = 12100.000000 Tape File End Depth = 13880.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Subfile 3 is type: LIS DEPTH 12100.0000 12100.5000 12200 0000 12300 0000 12400 0000 12500 0000 12600 0000 12700 0000 12800 0000 12900 0000 13000 0000 13100 0000 13200 0000 13300 0000 13400.0000 13500.0000 13600.0000 13700.0000 13800.0000 13880.0000 GRAX -999 2500 -999 2500 30 4340 67 4590 35 3220 43 6510 59 0400 21.7430 23 7580 48 5360 28 5930 103 8420 71 8640 83 8980 38 4000 39 6910 67 0060 61 8110 75.1500 -999.2500 ROPS -999 -999 78 52 49 65 90 50 87 7 90 18 95 72 90 43 93 63 34 -999 2500 2500 5350 3630 0950 5160 5850 7040 5710 6210 2700 9480 9080 2590 .0920 .3910 .3850 .4470 .0000 .2500 Tape File Start Depth = 12100.000000 Tape File End Depth = 13880.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
