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Home My WebLink About201-008 Imagff: 'oject Well History' File Cover Ri' je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (~0~_- O0? VVeI, History Fi,~ ,d~.tifi~r RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: / Diskettes, No. I [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHE~ WINDY Scanning Preparation / x 30 = ~ (~ BY: BEVERLY ROBIN VINCENT SHERYL~~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .;~'"~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/lO/02Rev3NOTScanned.wpd . STATE OF ALASKA e ALAS~OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LQGiu 1 a. Well Status: D Oil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC25.110 ~ Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/27/2006 201-008 306-012 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 02/18/2001 50- 029-20584-0 1-00 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 02/21/2001 PBU 16-06A 1893' FNL, 1121' FWL, SEC. 24, T10N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1671' FNL, 3736' FWL, SEC. 24, T10N, R15E, UM 72' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2240' FNL, 4939' FWL, SEC. 24, T10N, R15E, UM 11071 + 9027 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 719911 y- 5929055 Zone- ASP4 11132 + 9041 Ft ADL 028332 TPI: x- 722519 y- 5929354 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 723737 y- 5928820 Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost DYes ~No N/A MSL 1900' (Approx.) 21. Logs Run: MWD GR, GR / CNL, GR / RES a. 'JASING, INER AND EMENTING RECORD i'." ,t '32'''2 c.1!.i!i;; j,i"š.... 'i .iU, .·.1·····;.····,;,;:,;..';..····· .' ""j},i~¡4p" ......>i} } ,,>IZEì1/ ' i> ""..n, ii . ;.·,a 0"( BO f'l'OM iT! )P BOtToM }(;C,·. 20" 94# H-40 Surface 80' Surface 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2650' Surface 2650' 17-1/2" 3000 sx Fondu, 400 sx Permafrost 9-5/8" 47# L -80 / SOO-95 Surface 9536' Surface 8844' 12-1/4" 500 sx Class 'G' 7" 29# L-80 9237' 9653' 8569' 8950' 8-1/2" 350 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 9.3# /6.2# /6.5# L-80 9236' 11130' 8568' 9041' 3-3/4" 106 sx LARC 23. Perforations open to Production (MD + TVD of Top and 24·.·········'·//;;<·1I/,\1i>.... ".,e ii'Ci.i'?' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, L-80 7000' - 9207' 9184' MD TVD MD TVD 4-1/2", 12.6#, L-80 9207' - 9282' '~~~';;i'i;d·i};""'(" ii.i.." " i, '?' '¡i)·i.' ·/'·i'?i"i·.!; ,'. '" ;,:,,,.. . . ,- DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ;,~'J"..' C 9000' P&A w/ 21.5 Bbls and 13.5 Bbls of Cement 6734' Set EZSV with Whipstock on Top 26. 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-BsL GAs-McF W A TER-BSL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. OIL-BSL GAs-McF W A TER-BSL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8ft MAY 1 7 2U06 Form 10-407 Revised 12/2003 0 R \ G \ N~tUED ON REVERSE SIDE G 2'8. GEOLOGIC MARKE 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Zone 4 (From 16-06) 9639' 8938' None 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 Terrie Hubble ~ .. Title Technical Assistant Date 05!(';;..Jexo PBU 16-06A 201-008 306-012 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jeff Cutler, 564-4134 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e 16-06B Prudhoe Bay Unit 50-029-20584-02-00 206-011 Accept: Spud: Release: Ri: 03/06/06 03/11 /06 03/30/06 Nabors 2ES PRE-RIG WORK 02115/06 SET 5.5" WHIDDON AT 9208' SLM. PULLED LIVE VALVES FROM STA.1 AT 2876' (SLM), STA.2 AT 4880' (SLM) AND STAA AT 7503' (SLM). SET DUMMY GLV IN STA.1 AT 2876' (SLM), STA.2 AT 4880' (SLM). 02116/06 SET 1.5 DGLV IN STAA AT 7503' (SLM). PULLED 51/2" WHIDDON CATCHER AT 9208' (SLM). 02118/06 T/I/O = 260/220NAC. SI. TBG, IA AND OA FLS (PRE MIT-IA, MIT-OA) RIG ST PREP. TBG FL AT SURFACE, IA FL AT 2682', OA FL AT 36'. 02119/06 TII/O = 250/240/20 TEMP=SI MITIA TO 3000 FAILED. PUMPED 25BBLS DIESEL, IA PRESSURED UP TO 1800PSI, TUBING TRACKING, POSSIBLE VALVE OUT OF POCKET. MITOA TO 2000 PASSED. 3.2BBLS DIESEL TO PRESSURE UP. LOST 110 PSI 1 ST 15 MIN. LOST 30 PSI 2ND 15 MIN. BLED OA TO O. FWHP'S = 450/450/0. 02120/06 TII/O= 360/350/90. TEMP= SI. IA FL (POST-FAILED MIT-IA). IA FL AT SURFACE. AIL SPOOL REMOVED AND INTEGRAL INSTALLED ON IA. 02127/06 KILL WELL W/350 BBLS 1% KCL. CAP W/60 BBLS METH ON BACKSIDE. RIH W/2.25" BDN. STOP AT 9200', JUST ABOVE LINER TOP. PUMP 21.5 BBLS OF CEMENT. AFTER 12 BBLS OF CEMENT IN LINER GET 500 PSI INCREMENTAL PRESSURE BUMP. OPEN CHOKE AND LAY IN REMAINING CEMENT. CALCULATED 4 BBLS OF CEMENT BEHIND PIPE AFTER PULL TO SAFETY. CALCULATED CEMENT TOP 8980'. WOC. RIH TO 9200' AND NO TAG. LAY IN 13.5 BBLS OF CEMENT. GOOD 1:1 RETURNS. CALCULATED CEMENT TOP AT 8620'. PULL TO 7800'. PUMP 5 BBLS BIOZAN. DROP 7/8" BALL. PUMP 28 MORE BBLS OF BIOZAN. NOZZLE CLOGGED. REVERSE OUT WITH METH. POOH TO INSPECT. BALL RECOVERED ON XO, PU 2.325" JSN RIH TO 7800'. PUMP 20 BBLS BIOZAN AND CHASE OUT OF HOLE. 02128/06 W/2.235" JSN WHILE PUMPING 60/40 METHANOL. WELL IS FP TO 2500'. SI WELL WITH 1500 PSI. 03/01/06 DRIFT W/4.55" CENT W/ S-BAILER TAGGED OBSTRUCTION AT 7657' SLM, UNABLE TO WORK THROUGH. NO RECOVER SAMPLE. RAN 2.85 CENT W/ SB FIND TIGHT SPOT AT 7697' SLM, WORKED THROUGH. TAGGED AT 8318' SLM, WORKED TOOLS TO 8347' SLM. BOTTOM STICKY. RECOVERED CEMENT FROM SB. ATTEMPT TO PURGE CHEMICAL INJECTION LINE. LINE BLOCKED UNABLE TO PURGE. 03/04/06 RAN 4.15" JET CUTTER, CCL DEPTH = 6985.7, CCL TO CUTTER = 14.3, CUT DEPTH = 7000'. CIRCULATE DOWN TUBING TAKING RETURNS UP IA THROUGH LOOP TO FLOW LINE. W/5 BBLS METHANOL SPEAR, 707 BBLS 100° F 2% KCL AND 148 BBLS 80° F DIESEL. U-TUBE TXIA TO FREEZE PROTECT. FREEZE PROTECT FLOW LINE W/5 BBLS METHANOL AND 46 BBLS 80° F DIESEL. 03/05/06 CMIT-TXIA PASSED TO 2000 PSI. PRESSURED UP W/5.6 BBLS DIESEL. CMIT LOST 40 PSI IN 1ST 15 MIN AND 20 PSI IN 2ND 15 MIN FOR A TOTAL LOSS OF 60 PSI IN 30 MIN. BLED PRESSURES TO 0 PSI. FWP'S = 0/0/0. e . BP EXPLORATION Page 1 .. Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2006 12:30 - 00:00 11.50 MOB P PRE Move rig over well. 3/7/2006 00:00 - 01 :00 1.00 MOB P PRE Move rig over well and prepare for rig accept at 01 :00 hrs on 03/07/06. 01 :00 - 02:00 1.00 WHSUR P DECOMP Pre-Spud Meeting. Install 2nd annular valve 02:00 - 03:00 1.00 WHSUR P DECOMP Rig up lubricator. Pull back pressure valve Tubing = 50 psi Annulus = 10psi. 03:00 - 06:00 3.00 WHSUR P DECOMP Rig up circulating lines. Displace freeze protect with seawater through choke to cuttings tank. 06:00 - 07:30 1.50 WHSUR P DECOMP Dry rod BPV. Attempt to test from below to 1000psi, no test. Swap hoses and pump from the top to clean out debris. Swap hoses back and test from below to 1000psi. Good test 07:30 - 08:00 0.50 WHSUR P DECOMP Rig down circulating lines 08:00 - 12:00 4.00 WHSUR P DECOMP Nipple down Tree & adapter 12:00 - 14:00 2.00 WHSUR P DECOMP Nipple up BOP 14:00 - 15:30 1.50 WHSUR P DECOMP Rig up lubricator extension. Rig up DSM lubricator. Trouble pulling the BPV made 2 runs Rig down DSM lubricator and extension. Clear Floor 15:30 - 16:00 0.50 BOPSUF P DECOMP Dry rod tree test plug 16:00 - 16:30 0.50 BOPSUF P DECOMP Rig up test joint 16:30 - 00:00 7.50 BOPSUF P DECOMP Test BOPE 250psi low 3500psi high. Annular 2500psi. Test witnessed by AOGCC rep. Jeff Jones and BP Rep Blair Neufeld and NAD J. Henson. 3/8/2006 00:00 - 04:00 4.00 BOPSUF P DECOMP Test BOP 250psi low 3500psi high. Annular 2500psi. Test witnessed by AOGCC rep Jeff Jones & BP Rep Blair Neufeld and NAD J. Henson. 04:00 - 06:00 2.00 PULL P DECOMP Pull Tree test plug. PJSM Latch on to and pull tubing hanger. Purge chemical injection line with diesel. Difficult to purge line completely - could not pump freely thru line but may have got enough diesel in line to displace its capacity of -0.4 bbls. 06:00 - 07:00 1.00 PULL P DECOMP Circulate, Pump dry job.Rig up 5 1/2" tubing equipment & spooling unit. Lay down hanger and landing joint. 07:00 - 15:30 8.50 PULL P DECOMP Lay down 5 1/2" 17# tubing with injection line from 7000' to 2738' 15:30 -16:30 1.00 PULL P DECOMP PJSM Cut injection line. Change out control line spool. 16:30 - 20:30 4.00 PULL P DECOMP Lay down 51/2" 17# tubing with injection line from 2738' to surface 20:30 - 22:00 1.50 PULL P DECOMP Rig down spooling unit. Rig down 5 1/2" handling equipment. Clear and clean floor 22:00 - 22:30 0.50 CLEAN P DECOMP Make up test joint. Set test plug 22:30 - 00:00 1.50 CLEAN P DECOMP Test top and bottom rams & related valves with 4" test joint. 250psi low 3500psi high. Annular tested to 250psi low and 2500psi high. Test witnessed by BP Rep Blair Neufeld. NAD J. Henson 3/9/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Pull test plug. Install wear ring and blow down surface equipment 01:00 - 02:30 1.50 CLEAN P DECOMP Make up BHA #1 with mills, collars and HWDP 02:30 - 06:30 4.00 CLEAN P DECOMP Run in hole picking up drill pipe from pipe shed. 165k up 150k dn 06:30 - 08:00 1.50 CLEAN P DECOMP Circulate 2 x bottoms up @12 BPM 1650psi. Pump dry job 08:00 - 10:30 2.50 CLEAN P DECOMP POOH 6993'-963'. Change out handling equipment 10:30 - 11:30 1.00 CLEAN P DECOMP POOH with BHA from 963' 11:30-15:00 3.50 DHB P DECOMP PJSM Rig up E-line and run EZSV bridge plug with Gamma Printed: 4/14/2006 11 :09:17 AM e . BP EXPLORATION Page 2 _ Operations Summary Report Legal Well Name: 16-06A Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 3/6/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/30/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2006 11 :30 - 15:00 3.50 DHB P DECOMP and CCL log. Attempt to set EZSV - misfire. 15:00 - 19:00 4.00 DHB N DFAL DECOMP Pull out run #1. Troubleshoot at surface. Found short in GR tool. Change out tools and run in hole with EZSV and CCL log (no gamma ray) 19:00 - 20:30 1.50 DHB P DECOMP Set bridge plug with top at 6728' - 5' above coupling. 20:30 - 21 :30 1.00 DHB P DECOMP Stage up pump to 3500psi casing test. Hold and chart for 30 mintutes. Blow down surface equipment 21 :30 - 00:00 2.50 STWHIP P WEXIT PJSM MAke up BHA #2 Whipstock assembly with MWD. Orient and upload MWD tools. 3/10/2006 00:00 - 03:00 3.00 STWHIP P WEXIT Upload and pulse test MWD, Make up remainder of BHA 03:00 - 03:30 0.50 STWHIP P WEXIT Change out handling equipment. RIH 1029'-1688' 03:30 - 04:00 0.50 STWHIP N RREP WEXIT Repair blower motor on #1 SCR 04:00 - 06:30 2.50 STWHIP P WEXIT Run in hole with BHA #2,Whipstock assembly. Fill every 3000' 06:30 - 07:30 1.00 STWHIP P WEXIT Service top drive. Lubricate rig. Install blower hose. 07:30 - 08:30 1.00 STWHIP P WEXIT Orient whipstock to 50 deg left. 165k up 150k dn Tag EZSV @6734' Set bottom trip anchor with 15k dn. Pick up 10k over to verify. Set down and shear bolt with 25k dn. Pick up and work pipe free rotating weight 155k. Top of window 6712' bottom of window 6729' 08:30 - 09:30 1.00 STWHIP P WEXIT Pump 40 bbl his vis spacer then displace the system to 9.0ppg LSND milling mud. 550gpm @1300psi 160k up 150k dn 155k rotating. 5k ftjlbs off bottom and 7-11 k ftllbs.on bottom 09:30 - 14:00 4.50 STWHIP P WEXIT Milling from 6712'-6729' then formation to 6740'. 160k up 150k dn 155k rotating. 5k off bottom torque and 7k on bottom. 14:00 - 15:00 1.00 STWHIP P WEXIT Work window clean. Pump 20bbl hi-vis sweep. Circulate bottoms up with 510gpm @1250psi. Pull into casing Mud weight in and out 9.0ppg 15:00 - 16:00 1.00 STWHIP P WEXIT Perform FIT to 12.0 ppg equivalent mud weight. =1000psi@6383TVD Monitor well. Pump dry job 16:00 - 17:00 1.00 STWHIP P WEXIT Cut drilling line 17:00 - 19:00 2.00 STWHIP P WEXIT POOH 6695' to 1007' stand back BHA to 821' 19:00 - 22:00 3.00 STWHIP P WEXIT Monitor well @BHA. Lay down BHA from 821' to 76' Download MWD tool. Lay down MWD and mills. (mills in gauge) clear floor 22:00 - 22:30 0.50 STWHIP P WEXIT Service wear ring 22:30 - 23:30 1.00 STWHIP P WEXIT Rig up and flush stack. Install wear ring 23:30 - 00:00 0.50 STWHIP P WEXIT PJSM Make up BHA to 61' 3/11/2006 00:00 - 01 :30 1.50 STWHIP WEXIT Upload and shallow pulse test MWD. PWD failed test and required changing. 01 :30 - 05:30 4.00 STWHIP N DFAL WEXIT Touble shoot and change out PWD tool 05:30 - 06:00 0.50 STWHIP WEXIT Make up remaining BHA, Jars and HWDP. 06:00 - 10:30 4.50 STWHIP WEXIT Run in hole 342' to 5975' picking up pipe from pipeshed. Fill pipe every 3000'. 10:30-11:30 1.00 STWHIP WEXIT Service top drive, crown and drawworks. Install blower hose and fill pipe. 11:30 - 12:30 1.00 STWHIP WEXIT RIH 5975' to 6686' then orient toolface to 50deg left of highside. Slide through window at 6729' with no problems. Tag bottom @6740' and perform slow pump rates. 145k up 130k down 135k rotating. - uu:OO 11.:>0 LJRILL INT1 Drill 81/2" hole 6740' to 7104'. AST 4. 'Ah~ 145k un . --. UII DOttom 4k and on bottom 5-6k 1650psi Printed: 4114/2006 11 :09;17 AM e e r~ ~.,~~~t'~'i .~"-"'~ 1t!;k,,_ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _Illserts\Microfihn _ Marker. doc ) ) ~~' Q.J. .,. ïr~j8~r \ V' [Ir " f I I \ II 1:, I I I I , 'f I \ \ r ; I I...aii ,k.IGIIII. tn) l-~ ! f I! I L, lWlJ / /.,'& " ¡ FRANK H. MURKOWSKI, GOVERNOR AT,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 62DI-- 005 Re: Prudhoe Bay, 16-06A Sundry Number: 306-012 ~NED JAN 1 $ 'lotm Dear Mr. Wesley: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ DATED thisilday of January, 2006 Encl. CfJ:} I, 11..(ìþ w?<t:üE1VEB STATEOFALASKAbVS I, )7~ ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 1 2006 APPLICATION FOR SUNDRY APPROMt.PH&GasCons.Conmission 20 AAC 25.280 Anchorage ) 1. Type of Request: II Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension ---------,-~ 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well CI98S: IBI Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 201-008 -,' 6. API Number: / 50- 029-20584-01-00 99519-6612 721 9. Well Name and Number: PBU 16-06A ./ 8. Property Designation: ADL 028332 10. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool PRESENTWELLCONDITION·SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11071 9027 None MD / TVD Burst 11. Total Depth MD (ft): 11132 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9041 Length Size Junk (measured): None Collapse Liner 80' 20" 80' 80' 1530 520 2650' 13-3/8" 2650' 2650' 4930 2670 9536' 9-5/8" 9536' 8844' 6870 4760 416' 7" 9237' - 9653' 8569' - 8950' 8160 7020 18941 3-1/2" x 3-3116" x 2-7/8" 92361 - 11130' 8568' - 9041' 10160 10530 Perforation Depth MD ~): Perforation Depth TVD (ft): 9876' - 11066' 9042' - 9026' Packers and SSSV Type: 9-5/8" x 5-1/2" AVA 'PPB' packer Tubing Size: 5-1/2",17# x 4-1/2", 12.6# Tubing Grade: Tubing MD (ft): L-80 9282' Packers and SSSV MD (ft): 9184' /' 12. Attachments: IBI Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: / D Exploratory IBI Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam~ffve;/e/ Title Signature~ ~ ~ Phone 564-5153 Commission Use Only / January 20, 2006 Date: 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ IBI Abandoned D WDSPL Contact Jeff Cutler, 564-4134 Date / j¡1J/dfð Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance I Sundry Number: ê:Ð(O -0\ ~ It" - o{¡, 8. APPROVED BY THE COMMISSION Date 1-/r~()Þ Submit In Duplicate ) ) 0'·"."'."·".'.",'.':·:";'.·".','.':.'.·,··,·,..·:".·".,.b '. ,,:1 P 1'1, ~"', . 1',',_ ' " 'i" ,",I :' Ii:·';':": GI3J4I~! To: Winton Aubert - AOGCC Date: January 4, 2006 From: Jeff Cutler - BPXA GPB Rotary Drilling Subject: Reference: 16-06A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20584-02 Approval is requested for the proposed P&A of P8U well 16-06A. Well 16-06 was drilled as a Zulu producer in May 1981 and a RWO was done in May 1991. Pulse tests from 16-05 showed lack of transmissibility to 16-06 after 16-05 was converted to an injector in 1984. Thus 16-06 and 16-05 were sidetracked as an injector-producer pair in January 2001 in the southeast periphery. 16-06A was a horizontal sidetrack but it showed a slight production increase from the mud acid stim work done in May 2001. However, there was no positive response from the additional perforations in July 2001. Hot oil treatments were also unsuccessful. 16-06 was finally shut in for low rate in June 2003. A sidetrack to ("" access viable target reserves in the eastern periphery of drill site 16 is seen as the best way to maximize the value of the wellbore. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around February 15th 2006, after the completion of the 16-148 rotary sidetrack. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: ./ Currently 81 due to low productivity. ./ RWO, with new 5-1/2': 17#, L-80 tubing, completed 03/2004 ./ 9-5/8", 47#, L-80 casing landed at 9,536'. ./ 5-1/2", 17#, L -80 tubing landed in A V A seal assy. at 9, 183'. ./ 9-5/8" X 5-1/2" A VA PPB packer at 9, 184'. /' ./ Top of 3-3/16" CTD liner at 9,236'. ./ 5-1/8 FMC tree with 13-5/8", 5K FMC Gen II wellhead. Scope Pre-RiQ Operations: 1. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 2. RU SL and drift tbg to the 5-1/2" AVA locator seal as~mþly @ 9183" MD 3. RIH with CT and P&A the 16-06A well bore. Pump {!?pbls of 15.8 ppg cement, leaving TOC in the 5-1/2" tbg at -9,000' MD. Cement volume based on~ 1,346' of 2-7/8",6.5#, (cap. = 0.00578 bbl/ft), liner - volume = 7.8 bbls./ 489' of 3-3/16", 6.2#, (cap. = 0.0076 bbl/ft), liner - volume = 3.7 bbls./, 236' og 5-1/2",17#, (cap. = 0.0232 bbl/ft), tubing - volume = 5.5 bbls/ 4. RU SL, RIH and drift 5-1/2" tbg to below cut depth of 7,000 MD. If able continue RIH and tag cement to verify TOC depth. 5. RIH with the appropriate chemical cutter and cut the 5Y2" tubing at -7,000' MD. / 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock down screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. 16-06A Application for Sundry ) ) RiQ Operations: 1. MI I RU Nabors rig 2ES ,.AO) 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. /vc" \0 J 3. Nipple down tree. Nipple up and test BOPE to 3,500 psi. /" v'\9'Ú · 4 R/U. Pull 5%" tubing from the cut at ~7,000' MD and above. (~ \. t{,~ 5: R/U E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH and tag tubing stump. POH. V'" Å 6. RIH with HES ElSV on E-line. Set bridge plug at ~6,724', as required to avoid cutting a casing collar while milling the window. POH. RID E-line. 7. Pressure-test the 9-5/8" casing to 3,500psi for 30 minutes. Record test. r-/ 8. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly on 4" DP. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9-5/8" casing at ± 6,700' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POH. 12. M/U 8%" Dir/GR/PWD assembly. RIH, kick off and drill the 8%" intermediate section to ~1 00' above the HRl with 9.0 - 9.3 ppg LSND. 13. By ~ 11,600' MD (~150' above the top of the HRl) have the entire circulating system weighted up to 10.9 ppg with spike fluid from the MI plant. 14. Continue drilling ahead to the 7" liner point at top of the Ivashak, as per the directional plan. The Sag River is truncated by the LCU in this area so the liner pick will be done using an isopach data for the HRl. Circulate well clean, short trip to window. POH. 15. Run and cement a 7",26.0#, L-80 intermediate drilling liner. Test to 3,500 psi. 16. M/U 6-%" Dir/GR/Res assembly. RIH to the 7" liner landing collar. 17. Drill out the 7" liner float equipment and cement to the shoe. 18. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 19. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to TD per directional proposal. 20. Circulate well bore clean, short trip to shoe, circulate. POH. 21. Run and cement 4%", 12.6#, L-80, IBT-M solid production liner. During displacement spot a perf pill inside the 4-1/2" liner. POH. 22. RU and RIH with DPC perf gun. Planned perfs are 2-7/8" PowerJets at 6 spf 23. R/U and run a 4112", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4%" liner tie back sleeve. 24. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 25. Set a BPV. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 27. Freeze protect the well to ~2,200' TVD. Secure the well. 28. Rig down and move off. Post-RiQ Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. TiminQ: This sidetrack is scheduled for spud in mid February 2006. Estimated Pre-rig operations start date: Estimated Rig operations I spud date: 01/20106 02115/06 Jeff Cutler Operations Drilling Engineer 564-4134 16-06A Application for Sundry .!,REE = 5-1/8" FMC ) WELLHEAD = FMC ACTUA TOR = AXELSON KB. ELEV = 72.0' BF. ELEV = NA KOP = 4300' 'Max Angle = 99 @ 10190' ¡ Datum MD = 9567' i Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-f 2650' Minimum 10 = 2.377" @ 9726' 3-3/16" X 2-7/8" LNR XO I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 9183' I 3.75" BKR DEPLOY SLV, ID = 3.000" 1-1 9236' 9-5/8" X 7" BOT LNR HGR W/ TIEBACK SLV 1-1 9237' I 3-1/2" X 3-3/16" LNR XO, ID = 2.786" 1-1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9279' 9281' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9536' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" ÆRFORA TION SUMMARY REF LOG: SPERRY -SUN MWD/EWRlGR ON 02/22/01 ANGLE AT TOP PERF: 97 @ 9876' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9876 - 9940 0 07/07/01 2" 4 9972 - 10044 0 07/07/01 2" 4 10090-10112 0 07/07/01 2" 4 10150 - 10168 0 07/07/01 2" 6 1077 4 - 10804 0 02/24/01 2" 6 10838 - 10872 0 02/24/01 2" 6 11 000 - 11020 0 02/24/01 2" 6 11050 - 11066 0 02/24/01 7" LNR, 29#, L-80, ID = 6.184" 1-1 10261' DA TE REV BY 05/13/81 05/17/91 01/02/01 SIS-QAA 02/25/01 04/09/02 CI-VTP COMMB\ITS ORIGINA L COMPLETION RWO CONVERTED TO CANVAS CTDSIDETRACK (16-06A) CORRECTIONS DATE 16-06A ) SAFETY NOTES: WELL ANGLE> 70° @ 9775' & > 90° @ 9825'. ~ 2182' 1-1 5-1/2" CAMCO BAL-O SSSVN, ID = 4.562" 1 GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH 1 2887 2887 1 OT-LB DOME T2 2 4881 4854 21 OT-LB DOME T2 3 6407 6132 34 OT-LB DV T2 4 7499 7045 34 OT-LB S/O T2 5 8057 7515 31 OT-LB DV T2 6 8334 7756 29 OT-LB DV RA 7 8664 8049 27 OT-LB DV RA 8 8968 8323 25 OT-LB DV T2 CHEMICAL MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 9 9076 8421 25 MMG-L TS RK ~ PORT DATE 16 03/18/01 16 03/18/01 o 03/18/01 24 03/18/01 o 03/18/01 o 03/18/01 o 03/18/01 o 03/18/01 L Xl ~ 9183' IJ 5-1/2" AVA LOC. SEAL ASSY, ID = 4.750" 1 /" 9184' 1-1 9-5/8" X 5-1/2" A V A PPB PKR, ID = 6.000" 1 I 9200' IJ BTM A V A SEA L BORE EX1., ID = 6.000" 1 I I 9207' 1-1 5-1/2" X 4-1/2" XO, ID = 3.958" 1./ J . 9270' 1-1 4-1/2" OTIS XN NIP, ID = 3.80" (MILLED OUT) 1 \ 9282' 1-1 4-1/2" WLEG, ID = 3.958" 1 9280' 1-1 ELMD TT NOT LOGGED 1 ~ .... l ~ I .r--4 7" LNR MILLOUT WINDOW (16-06A) 9653' - 9659' (OFF WHIPSTOCK) TOP OF WHIPSTOCK @ 9650' RA PIP TAG @ 9661' 9725' 1-1 3-3/16" X 2-7/8" XO, ID = 2.377" 1 11071' I-IPBTD I 12-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.377" 1-1 11129' 1 REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 16-06A PERMIT No: 181-0510 API No: 50-029-20584-01 SEC. 24, T10N, R15E 1893' SNL & 1121' EWL BP Exploration (Alaska) ") 16-06B Proposed Completion TREE = 5-1/8" FMC W8...LHEAQ = FMC ACTUATOR = AXELSON KB. ELEV = 72.0' BF. 8...EV = NA KOP = 4300' Max Angle = 99 @ 10190' DatumMD= . 9567' 4-1/2" X Nipple (3.813" 10) - 2200' Datum ND = 8800' SS 13-3/8" 72#, L-80 (12.347" 10) - 2650'~ l 9-5/8" X 7" Baker Packer/Hanger (6/25" 10) - 6550' I!i 4-1/2" X Nipple (3.813" 10) - 114200' 7" X 4-1/2" Baker 53 Packer - 11440' 4-1/2" X Nipple (3.813" 10) - 11460' 4-1/2" X Nipple (3.813" 10) - 11480' 4-1/2" XN Nipple (3.725" 10) - 11500' 4-1/2" WLEG - 11520' t' X 4-1/2" BKR ZXP PKR/HGR - 11530' r", 26#, L-80, BTC-M Liner - 11680' 11,971' - 4-1/2",12.6#, L-80, IBT-M Liner PBTO PERFORA TION SUMMARY REF LOG: SPERRY -SUN MWD/EWR/GR ON 02/22/01 ANGLEATTOPPERF: 97 @ 9876' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9876 - 9940 0 07/07/01 2" 4 9972 - 10044 0 07/07/01 2" 4 10090 - 10112 0 07/07/01 2" 4 10150 - 10168 0 07/07/01 2" 6 1077 4 - 10804 0 02/24/01 2" 6 10838 - 10872 0 02/24/01 2" 6 11000 - 11020 0 02/24/01 2" 6 11050 - 11066 0 02/24/01 7" LNR, 29#, L-80, 10 = 6.184" - 10261' I . ') GAS LIFT MANDR8...S ST MD ND DEV TYPE VLV LATCH 5 3500 3500 MMG DMY 4 6004 5800 MMG DMY 3 8300 7295 MMG DMY 2 10000 8072 MMG DMY ~ 1 11745 8958 MMG DMY PORT DATE L ~. ,. "' l J ~.. . " \ ~ J Minimum 10 = 3.375" @ 11500' 4-1/2" XN Nipple ! 6700' - 9-5/8" Window ~ 7000' - 5-1/2",17#, L-80, tbg stub / ~ 9000' - Calculated TOC /' 9184" - 9-5/8" X 5-1/2" AVA PPB PKR, 10 = 6.0" ." .; - 9237' - 9-5/8" X 7" BOT LNR HGR W/ TIEBACK 5LV ..~it-- 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.786" ~ x x · · x · x · · x x · · · ~ ~ - y- 9725' - 3-3/16" X 2-7/8" XO ./ 2-7/8" LNR, 6.5#, L-80, - 11129' DA TE REV BY COMMENTS 12/05/05 JNC Proposed 16-06B Completion DATE REV BY COMMENTS 05/13/81 ORIGINAL COMPLEfION 05/17/91 RWO 01/02/01 SIS-QAA CONVERTED TO CANVAS 02125/01 CTD SIDEfRACK (16-06A) 04/09/02 CHlTP CORRECTIONS PRUDHOE BA Y UNIT W8...L: 16-06A PERMIT No: 181-0510 API No: 50-029-20584-01 SEC. 24, T10N, R15E 1893' SNL & 1121' EWL BP Exploration (Alaska) " 2 o o ~ ~ ¿¡ "2 '2 ;;; " " ¡.': COMPANY DHAILS REFERENCE INfORf\·1ATJON SURVEY PROGRAM Plan: 16-068 wp06 í lÚ,O{)/Plan ¡ 6-06B) UP Am<)~<J 'JmçNul1h ¡üü! Dcp!h Fill Ikpth r,) Sun'<.::y'!'bn Cr¢at\:d By Troy Jakabosky (jakatO(¿(b¡J.l:oik}þk: ! 2/¡ ~,/2005 67uo,OO J2U5655 Plmm"d: i6-()(,[j \\1106 V2() MWl)·!FR'MS CÌ\eded Datè; Reviewed: Date' WELL DETAiLS 5600 - CASINO DETAILS Nam,; NUr!híng Easting Lat!tud~ L.nllgitw.k 5101 TVD liH)Ú 151\5.!'! 719911.1') 7U'-¡2'JU.15N j4i:ì~!}t35.9ÜüW U6 - No. MD Name Size - - I I [(,80.3 I 7" 7.000 TARGET DFf A]lS - 2 913 12056.00 41:2" 4.500 Name TVD +N'·S +E/-W Northing Easting Shap" I r-~ 16·06B 1'1 90(¡6.50 2680.00 4830.00 593 1874A6 724660.88 Point - ~ .. SECTION DET A]LS - See MD lne AZI TVD +N/-S +E/·W Dl"g TFacc VSec Target - I 6700.00 6375.07 128.57 I 0.00 0.00 II07AO 2 6720.00 639164 129.79 12.00 ·46.00 1117.71 - 3 7578.15 62.11 696132 397.56 4.00 ·49.54 1740.95 4 I I 151.81 62. I I 8632.88 0.00 0.00 4872,0 I - ; , 5 I l304.61 56.00 53.26 87IIAI 4.00 ·179.95 5001.86 - 6 11939.61 56.00 53.26 9066.50 0.00 0.00 5523.69 16·06B TI - : 7 12056.55 56.00 53.26 913189 0.00 0.00 5619,79 - - iT - - - - ¡ . ' i> '"'' - - - , ¡ - '"'' '" ~ - ,51 ", - \ ~ - ¡ - \ "'" .. -. ~ - \ - .; - ~ -' , - FORMATION TOP DETAILS ~ ..... , , - No. TVDPath MDPath Fom1atÎon ] 9348.73 CM2 , - 2 10432.66 CMl ..- - 3 11308.35 THRZ 4 8921.50 11680.3] BHRZ TSAD 5 8921.50 11680.3] 45N / 45P : 44N /44P . 6 8931.50 11698,20 43N 11: 7 8934.50 11703.56 43P 'HRš 8 8941.50 11716.08 42N , 9 8956.50 1 1742.90 42P 10 8958.50 11746.48 41N '-::':' 11 8959.50 11748.27 4]P 12 8971.50 11769.73 31N ..... ~ 13 8972.50 1177 1.52 31P 12r ~~~~ - 14 9041.50 11894,91 27N 2P /' 15 9042.50 11896.70 27P HN ~ 16 9091.50 11984.32 26N V //j / / \ ¡\ \ - ]7 9094.50 11989,69 26P '31N 3 P - ]8 9076.50 11957.50 MHO/HOT r; r j - . . , :" . ' ,27 . . . , ¡P : ¡ : . ' , ' , : . , : ; ¡'! : , . : , ,':, ; , : : . : , : I : ! ' ¡ , ; ; , , , , , I ¡ t ¡ , , , , , , , , , , , , , , , , , 6300 7000 8400- 9100- I 2800 I 4200 I 4900 I 6300 5600 7000 VerticaJ Section at 60.84Q [700ft/in] ,8 2 '" '" 1800 ìS +' ~ õ z ? ~ 0 if> 1200 CÜMPANY DE! AILS HI' AfJl<I("O REFElŒNCE INFOR1\{ATION ClH~ckèd: SECTION DETAILS See MD lne Azi TVD +N/-S +E/-W DLcg TFace VScc Target 6700.00 33.21 85.32 6375,07 128.57 1196.35 0.00 0.00 1107.40 6720,00 82.30 6391.64 12Y,79 121J7.49 12.00 1117,71 7578.15 I 53,27 6961.32 397.56 1771.77 4,00 1740.95 11151.81 62.11 4303.16 0.00 0.00 4872.01 11304.61 56.00 4408.14 4.00 -179.95 5001.86 11939.61 56.00 53,26 9066.50 2680.00 4830.00 0.00 0.00 16-06B TI 12056.55 56,00 53,26 9131.89 2737.99 4907,69 0,00 0.00 ~ I - - - , , I . ' ! ! : ' [ ~ I:: [ [: : I ! ·"1 I ; I : , [ [ , i : , . r - - . . i .. ..- - , . .'. , .., .. , .. - ... , 7/ .. ,/ ! . - : .,. ¡ .. . , - : . , , : ! j , , , .. , - ¡/ - , ! , - : : I . .. FORMATION TOP DETAILS : No. TVDp",h MDp"lh Formation . i , i 1 7789.50 9348.73 CM2 . 2 8296.50 10432.66 CMI .. : 3 8713.50 11308.35 THRZ 4 8921.50 11680.31 BHRZ 5 8921.50 11680.31 45N I ¡ 44 - i 672( 6 11698.20 43N I }Jr- 7 11703.56 431' - 8 11716.08 42N - ! 9 ¡ ¡: 2"~ 42P wl( , .' ! 10 8958.50 41N 11 8959.50 ¡¡: F~ 41P - /1 ~ 12 8971.50 31N 13 8972.50 ¡ ¡; 4,:7 31P 14 9041.50 27N .. I i I 15 9042.50 ¡ ¡ 9~~~g 27P .. I{) 9091.50 26N .. -01(1 17 9094.50 11989.69 26P - .~. 18 9076.50 ll957.50 MHO/HOT - 750( I : r'9",· I j J ' , i : Iii , : ;6(10' . . . : : i : I , , , , , , , , , , , , , , , I , , , , , , I , , , , I , , , , I l200 1800 2400 3000 3600 4800 5400 3000 2400 600 SJ.lRVFY PRO(,\{AM Pl:m: J6-06B wp06 (16·06/PI¡¡n 16-06B) Ikp¡h Fw ¡krlh To Surn:y,l'hn ¡"ol fru¡: NUlih Cn:a1>:d By Tmy Jakabosky (iakntO(dbp,¡;o¡àilk: J 2...1;;/2005 670(),ÜO IJ.Ü5ú,55 PI;¡n¡¡"J: 16-U6B wpO(¡ V:W i\\Wf)'IFR,MS Wi~LL DETAiLS N,un¡: N()r!j¡jn¡c L<mgitudi.' Slü! L¡¡!imde IÚ~J{¡ 158},!9 5'!29Ü5}.Ü7 71991j,19 7lY¡:nl.J35N 14W'13'35.90l}\\i Ü6 TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape 16-06B TI 724660.HS Point 9066.50 2680.00 4830.00 5931874.46 CASING DETAILS No. TVD MD Name Size 11680.31 7" 1705600 4 117" 7.000 4500 WCsl(-)/EaSl(+) [600J\lin] "-~_..~ e Sperry-Sun BP Planning Report e Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 16 16-06 Plan 16-06B Date: 12/13/2005 Time: 12:37:13 Page: 1 Co-ordinate(NE) Reference: Well: 16-06, True North Vertical (TVD) Reference: 38+28.566.5 Section (VS) Reference: Well (0.00N,O.00E,60.84Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 16-06B wp06 Date Composed: Version: Tied-to: 8/31/2005 20 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2005 Site: PB DS 16 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5927441.99 ft 718969.88 ft Latitude: 70 12 Longitude: 148 14 North Reference: Grid Convergence: 15.545 N 4.567 W True 1.66 deg Well: 16-06 Slot Name: 06 16-06 Well Position: +N/-S 1585.19 ft Northing: 5929055.07 ft Latitude: 70 12 31.135 N +E/-W 987.72 ft Easting : 719911.19 ft Longitude: 148 13 35.900 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 11680.31 8921.50 7.000 8.500 7" 12056.00 9131.58 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 9348.73 7789.50 CM2 0.00 0.00 10432.66 8296.50 CM1 0.00 0.00 11308.35 8713.50 THRZ 0.00 0.00 11680.31 8921.50 BHRZ TSAD 0.00 0.00 11680.31 8921.50 45N 1 45P 1 44N 1 44P 0.00 0.00 11698.20 8931.50 43N 0.00 0.00 11703.56 8934.50 43P 0.00 0.00 11716.08 8941.50 42N 0.00 0.00 11742.90 8956.50 42P 0.00 0.00 11746.48 8958.50 41N 0.00 0.00 11748.27 8959.50 41P 0.00 0.00 11769.73 8971.50 31N 0.00 0.00 11771.52 8972.50 31P 0.00 0.00 11894.91 9041.50 27N 0.00 0.00 11896.70 9042.50 27P 0.00 0.00 11984.32 9091.50 26N 0.00 0.00 11989.69 9094.50 26P 0.00 0.00 11957.50 9076.50 MHO/HOT 0.00 0.00 Targets Map Map <--- Latitude ----> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 16-06B T1 9066.50 2680.00 4830.00 5931874.46 724660.88 70 12 57.478 N 148 11 15.665 W -Plan hit target e e Sperry-Sun BP Planning Report Company: BP Amoco Date: 12/13/2005 Time: 12:37:13 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-06, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.566.5 Well: 16-06 Section (VS) Reference: Well (0.00N,O.00E,60.84Azi) Wellpath: Plan 16-06B Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100f! deg/100f! deg/100f! deg 6700.00 33.21 85.32 6375.07 128.57 1196.35 0.00 0.00 0.00 0.00 6720.00 34.91 82.30 6391.64 129.79 1207.49 12.00 8.52 -15.08 -46.00 7578.15 62.11 53.27 6961.32 397.56 1771.77 4.00 3.17 -3.38 -49.54 11151.81 62.11 53.27 8632.88 2286.74 4303.16 0.00 0.00 0.00 0.00 11304.61 56.00 53.26 8711.41 2365.09 4408.14 4.00 -4.00 0.00 -179.95 11939.61 56.00 53.26 9066.50 2680.00 4830.00 0.00 0.00 0.00 0.00 16-06B T1 12056.55 56.00 53.26 9131.89 2737.99 4907.69 0.00 0.00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft ft deg/1 OOft ft ft 6700.00 33.21 85.32 6375.07 6308.57 1107.40 128.57 1196.35 0.00 5929218.43 721103.23 Start Dir 12/10 6720.00 34.91 82.30 6391.64 6325.14 1117.71 129.79 1207.49 12.00 5929219.96 721114.32 Start Dir 4/100 6800.00 37.06 78.26 6456.38 6389.88 1162.03 137.76 1253.79 4.00 5929229.28 721160.37 MWD+IFR+MS 6900.00 39.92 73.76 6534.66 6468.16 1222.08 152.87 1314.12 4.00 5929246.14 721220.24 MWD+IFR+MS 7000.00 42.93 69.77 6609.65 6543.15 1287.02 173.62 1376.90 4.00 5929268.71 721282.38 MWD+IFR+MS 7100.00 46.06 66.22 6680.99 6614.49 1356.53 199.92 1441.82 4.00 5929296.89 721346.51 MWD+IFR+MS 7200.00 49.29 63.03 6748.32 6681.82 1430.28 231.64 1508.57 4.00 5929330.54 721412.31 MWD+IFR+MS 7300.00 52.60 60.14 6811.33 6744.83 1507.90 268.62 1576.83 4.00 5929369.49 721479.45 MWD+IFR+MS 7400.00 55.98 57.49 6869.70 6803.20 1589.02 310.69 1646.25 4.00 5929413.55 721547.62 MWD+IFR+MS 7500.00 59.40 55.05 6923.15 6856.65 1673.24 357.63 1716.51 4.00 5929462.52 721616.47 MWD+IFR+MS 7578.15 62.11 53.27 6961.32 6894.82 1740.95 397.56 1771.77 4.00 5929504.04 721670.55 End Dir : 7578 7600.00 62.11 53.27 6971.54 6905.04 1760.10 409.11 1787.25 0.00 5929516.03 721685.68 MWD+IFR+MS 7700.00 62.11 53.27 7018.32 6951.82 1847.71 461.97 1858.08 0.00 5929570.94 721754.94 MWD+IFR+MS 7800.00 62.11 53.27 7065.09 6998.59 1935.33 514.84 1928.92 0.00 5929625.84 721824.21 MWD+IFR+MS 7900.00 62.11 53.27 7111.86 7045.36 2022.94 567.70 1999.75 0.00 5929680.74 721893.47 MWD+IFR+MS 8000.00 62.11 53.27 7158.64 7092.14 2110.56 620.57 2070.59 0.00 5929735.64 721962.73 MWD+IFR+MS 8100.00 62.11 53.27 7205.41 7138.91 2198.17 673.43 2141.42 0.00 5929790.54 722031.99 MWD+IFR+MS 8200.00 62.11 53.27 7252.19 7185.69 2285.79 726.29 2212.25 0.00 5929845.45 722101.25 MWD+IFR+MS 8300.00 62.11 53.27 7298.96 7232.46 2373.40 779.16 2283.09 0.00 5929900.35 722170.52 MWD+IFR+MS 8400.00 62.11 53.27 7345.74 7279.24 2461.02 832.02 2353.92 0.00 5929955.25 722239.78 MWD+IFR+MS 8500.00 62.11 53.27 7392.51 7326.01 2548.63 884.89 2424.76 0.00 5930010.15 722309.04 MWD+IFR+MS 8600.00 62.11 53.27 7439.29 7372.79 2636.25 937.75 2495.59 0.00 5930065.05 722378.30 MWD+IFR+MS 8700.00 62.11 53.27 7486.06 7419.56 2723.86 990.61 2566.43 0.00 5930119.96 722447.56 MWD+IFR+MS 8800.00 62.11 53.27 7532.83 7466.33 2811.48 1043.48 2637.26 0.00 5930174.86 722516.83 MWD+IFR+MS 8900.00 62.11 53.27 7579.61 7513.11 2899.09 1096.34 2708.10 0.00 5930229.76 722586.09 MWD+IFR+MS 9000.00 62.11 53.27 7626.38 7559.88 2986.71 1149.21 2778.93 0.00 5930284.66 722655.35 MWD+IFR+MS 9100.00 62.11 53.27 7673.16 7606.66 3074.32 1202.07 2849.77 0.00 5930339.56 722724.61 MWD+IFR+MS 9200.00 62.11 53.27 7719.93 7653.43 3161.93 1254.93 2920.60 0.00 5930394.47 722793.87 MWD+IFR+MS 9300.00 62.11 53.27 7766.71 7700.21 3249.55 1307.80 2991 .44 0.00 5930449.37 722863.14 MWD+IFR+MS 9348.73 62.11 53.27 7789.50 7723.00 3292.25 1333.56 302q.96 0.00 5930476.12 722896.89 CM2 9400.00 62.11 53.27 7813.48 7746.98 3337.16 1360.66 3062.27 0.00 5930504.27 722932.40 MWD+IFR+MS 9500.00 62.11 53.27 7860.25 7793.75 3424.78 1413.53 3133.10 0.00 5930559.17 723001.66 MWD+IFR+MS 9600.00 62.11 53.27 7907.03 7840.53 3512.39 1466.39 3203.94 0.00 5930614.07 723070.92 MWD+IFR+MS 9700.00 62.11 53.27 7953.80 7887.30 3600.01 1519.26 3274.77 0.00 5930668.97 723140.18 MWD+IFR+MS 9800.00 62.11 53.27 8000.58 7934.08 3687.62 1572.12 3345.61 0.00 5930723.88 723209.45 MWD+IFR+MS 9900.00 62.11 53.27 8047.35 7980.85 3775.24 1624.98 3416.44 0.00 5930778.78 723278.71 MWD+IFR+MS 10000.00 62.11 53.27 8094.13 8027.63 3862.85 1677.85 3487.28 0.00 5930833.68 723347.97 MWD+IFR+MS 10100.00 62.11 53.27 8140.90 8074.40 3950.47 1730.71 3558.11 0.00 5930888.58 723417.23 MWD+IFR+MS 10200.00 62.11 53.27 8187.67 8121.17 4038.08 1783.58 3628.95 0.00 5930943.48 723486.49 MWD+IFR+MS 10300.00 62.11 53.27 8234.45 8167.95 4125.70 1836.44 3699.78 0.00 5930998.39 723555.76 MWD+IFR+MS 10400.00 62.11 53.27 8281.22 8214.72 4213.31 1889.30 3770.62 0.00 5931053.29 723625.02 MWD+IFR+MS 10432.66 62.11 53.27 8296.50 8230.00 4241.93 1906.57 3793.75 0.00 5931071.22 723647.64 CM1 10500.00 62.11 53.27 8328.00 8261.50 4300.93 1942.17 3841.45 0.00 5931108.19 723694.28 MWD+IFR+MS .. e e Sperry-Sun BP Planning Report Company: 8P Amoco Date: 12/13/2005 Time: 12:37:13 Page: 3 Field: Prudhoe 8ay Co-ordinate(NE) Reference: Well: 16-06, True North Site: P8 DS 16 Vertical (TVD) Reference: 38+28.566.5 WeD: 16-06 Section (VS) Reference: Well (0.00N,0.00E,60.84Azi) WelIpath: Plan 16-068 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD IncI Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft ft deg/1 OOft ft ft 10600.00 62.11 53.27 8374.77 8308.27 4388.54 1995.03 3912.29 0.00 5931163.09 723763.54 MWD+IFR+MS 10700.00 62.11 53':27 8421.55 8355.05 4476.16 2047.90 3983.12 0.00 5931217.99 I 723832.80 MWD+IFR+MS 10800.00 62.11 53.27 8468.32 8401.82 4563.77 2100.76 4053.96 0.00 5931272.90 723902.07 MWD+IFR+MS 10900.00 62.11 53.27 8515.10 8448.60 4651.38 2153.62 4124.79 0.00 5931327.80 723971.33 MWD+IFR+MS 11000.00 62.11 53.27 8561.87 8495.37 4739.00 2206.49 4195.62 0.00 5931382.70 724040.59 MWD+IFR+MS 11100.00 62.11 53.27 8608.64 8542.14 4826.61 2259.35 4266.46 0.00 5931437.60 724109.85 MWD+IFR+MS 11151.81 62.11 53.27 8632.88 8566.38 4872.01 2286.74 4303.16 0.00 5931466.05 724145.74 Start Dir 4/100 11200.00 60.18 53.26 8656.13 8589.63 4913.84 2311.99 4336.98 4.00 5931492.26 724178.81 MWD+IFR+MS 11300.00 56.18 53.26 8708.84 8642.34 4998.06 2362.80 4405.07 4.00 5931545.04 724245.38 MWD+IFR+MS 11304.61 56.00 53.26 8711.41 8644.91 5001.86 2365.09 4408.14 4.00 5931547.42 724248.38 End Dir : 1130 11308.35 56.00 53.26 8713.50 8647.00 5004.92 2366.95 4410.62 0.00 5931549.34 724250.81 THRZ 11400.00 56.00 53.26 8764.75 8698.25 5080.24 2412.40 4471.51 0.00 5931596.55 724310.35 MWD+IFR+MS 11500.00 56.00 53.26 8820.67 8754.17 5162.42 2461.99 4537.94 0.00 5931648.05 724375.31 MWD+IFR+MS 11600.00 56.00 53.26 8876.59 8810.09 5244.60 2511.58 4604.38 0.00 5931699.55 724440.27 MWD+IFR+MS 11680.31 56.00 53.26 8921.50 8855.00 5310.60 2551.41 4657.73 0.00 5931740.92 724492.44 7" 11698.20 56.00 53.26 8931.50 8865.00 5325.30 2560.28 4669.61 0.00 5931750.13 724504.06 43N 11700.00 56.00 53.26 8932.51 8866.01 5326.78 2561.17 4670.81 0.00 5931751.06 724505.23 MWD+IFR+MS 11703.56 56.00 53.26 8934.50 8868.00 5329.70 2562.94 4673.18 0.00 5931752.89 724507.54 43P 11716.08 56.00 53.26 8941.50 8875.00 5339.99 2569.15 4681.49 0.00 5931759.34 724515.67 42N 11742.90 56.00 53.26 8956.50 8890.00 5362.04 2582.45 4699.31 0.00 5931773.15 724533.10 42P 11746.48 56.00 53.26 8958.50 8892.00 5364.97 2584.22 4701.69 0.00 5931774.99 724535.42 41N 11748.27 56.00 53.26 8959.50 8893.00 5366.44 2585.11 4702.88 0.00 5931775.91 724536.58 41P 11769.73 56.00 53.26 8971.50 8905.00 5384.08 2595.75 4717.14 0.00 5931786.97 724550.52 31N 11771.52 56.00 53.26 8972.50 8906.00 5385.55 2596.64 4718.32 0.00 5931787.89 724551.68 31P 11800.00 56.00 53.26 8988.43 8921.93 5408.96 2610.76 4737.25 0.00 5931802.56 724570.19 MWD+IFR+MS 11894.91 56.00 53.26 9041.50 8975.00 5486.95 2657.83 4800.30 0.00 5931851.44 724631.84 27N 11896.70 56.00 53.26 9042.50 8976.00 5488.42 2658.72 4801.49 0.00 5931852.36 724633.00 27P 11900.00 56.00 53.26 9044.35 8977.85 5491.14 2660.36 4803.68 0.00 5931854.06 724635.15 MWD+IFR+MS 11939.61 56.00 53.26 9066.50 9000.00 5523.69 2680.00 4830.00 0.00 5931874.46 724660.88 16-068 T1 11957.50 56.00 53.26 9076.50 9010.00 5538.39 2688.87 4841.88 0.00 5931883.67 724672.50 MHO/HOT 11984.32 56.00 53.26 9091.50 9025.00 5560.43 2702.17 4859.70 0.00 5931897.49 724689.92 26N 11989.69 56.00 53.26 9094.50 9028.00 5564.84 2704.83 4863.27 0.00 5931900.25 724693.41 26P 12000.00 56.00 53.26 9100.27 9033.77 5573.32 2709.95 4870.12 0.00 5931905.56 724700.11 MWD+IFR+MS 12056.00 56.00 53.26 9131.58 9065.08 5619.34 2737.72 4907.32 0.00 5931934.41 724736.49 41/2" 12056.55 56.00 53.26 9131.89 9065.39 5619.79 2737.99 4907.69 0.00 5931934.69 724736.84 MWD+IFR+MS I 90 50 10 0.5 01 005 0.01 0.008 PRUDHOE BAY, PRUDHOE OIL 5 16-06A Oil Rate (CD) (Mbblld ) -Water Rate (CD) (Mbblld ) Gas Rate (CD) ( M M dId) Cum Oil Prod (MMbbl) -Gas I Oil Ratìo (Mcflbbl) Water Cut (% ) 05 Date Permit to Drill 2010080 DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. PRUDHOE BAY UNIT 16-06A Operator BP EXPLORATION (ALASKA) INC MD 11132 ~ TVD 9041 ~' Completion Dar 5/26/2001 J Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log Nc) Sample Nc) Directional Survey Nc) APl No. 50-029-20584-01-00 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH ! Dataset Name Scale Media No Start Stop CH Received Number Comments ED~ ~r~LIS Verification jRpt Ver LIS Verification -- C 4C, w'~ee Notes 10100 10298 Case 7/16/2001 -"!"0193 10100-10298 9020 10092 Case 9/28/2001 ~-'113344 9020-10092 ~°nal Survey FINAL 3/27/2001 Directional Survey Digital Data ,,l~'~tional Survey FINAL 3/2712001 Directional Survey Paper Copy ~ FINAL 10100 10298 CH 7/16/2001 ~1'0193 10100-10298, Digital Data ,J.C~44 FINAL 9020 10992 CH 9/28/2001 ,,'r0344 9020-10992 Digital Data 1 9634 11082 Open 7/2/2002 ~1'0952 1 9634 11082 Open 7/212002 1 9631 11132 Case 1/21/2003 (.,1,.Y490 digital well logging data Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Daily History Received? (~ N Formation Tops ~__~/N Comments: Permit to Drill 2010080 DATA SUBMITTAL COMPLIANCE REPORT 6~3~2003 Well Name/No. PRUDHOE BAY UNIT 16-06A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20584-01-00 MD 11132 TVD 9041 Completion Dat 5/26/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 16, 2003 MWD Formation Evaluation Logs" 16-06A, AK-MW- 10050 16-06A: Digital Log Images 50-029-20584-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED JAN 2~ 1 200~ WELL LOG TRANSM1TFAL To: State of Alaska June 25, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 16-06A, AK-MW- 10050 1 LDWG formatted Disc with verification listing. APl#: 50-029-20584-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED ~ ~00~ Alaaa Oil & Gas Cons. Commis~on And~or~e 09/13/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1454 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 16-06A ¢-~Q/---O/')~/ 21371 MGR (PDC) 02/23/01 1 H-37A ~,~(') _(~o~ -'1 21368 MGR 09/01100 L-01 '~ ~,¢1 O"~ & 21375 FRAC ADVISOR TVD (KUPARUK SECTION) 06/19101 2 L-01 ~;:~tJ' -- 21378 FRAC ADVISOR TVD (SCHRADER BLUFF) 06119/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN~ " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ 4. Location of well at surface 1889' FNL, 4158' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1670' FNL, 1545' FEL, Sec. 24, T10N, R15E, UM At effective depth (asp's 719911, 5929055) (asp's 722519, 5929353) At total depth 2239' FNL, 341' FEL, SEC 24, T10N, R15E, UM (asp's 723738, 5928820) 12. Present well condition summary Total depth: measured true vertical 11132 feet Plugs (measured) 9041 feet Effective depth: measured 11058 feet Junk (measured) true vertical 9024 feet Perforate _X Other _ 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-06A 9. Permit number / approval number 201-008 10. APl number 50-029-20584-01 11. Field / Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Measured Depth Conductor 80' 20" 300 Sx PF 80' Surface 2578' 13-3/8" 3000 Sx Fondu & 400 Sx PF 2650' Production 9464' 9-5/8" 500 Sx Class G 9536' Liner 416' 7" 350 Sx Class G 9653' Liner 1383' 3-1/2"/3-3/16"/2-7/8" 22 bbls 15.8 ppg LARC 11130' True Vertical Depth 80' 2650' 8844' 8950' 9041' Perforation depth: measured 9876' - 9940'; 9972' - 10044'; 10090' - 10112'; 10150' - 10168'; 10774'- 10804'; 10838'- 10872'; 11000'- 11020'; 11050'- 11066'. true vertical 9042'- 9033'; 9029' - 9024'; 9021'- 9020'; 9016' - 9013'. 8992' - 8994'; 8996' - 8999'; 9014.5' - 9017'; 9023' - 9026'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 Tbg @ 9207' MD; 4-1/2", 12.6#, L-80 Tbg @ 9282' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" AVA PBR HYDR Set Packer @ 9184' MD. 5-1/2" CAMCO BAL-O SSSV @ 2182' MD. RECEIVED AUG 0 ?Z001 Alaska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 127 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 121 206 209 582 165 Casing Pressure - Tubing Pressure 229 284 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil _X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ i~~ Title: DS 16 Surveillance Engineer Jennifer Watso Form 10-404 Rev 06/15/88 · ORI, 61NAL Date ol Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE 16-06A DESCRIPTION OF WORK COMPLETED CT PERFORATING OPERATIONS Date Event Summary 6/15/2001' 7/05/2001 - 7/07/2001: Ran Static Survey. MIRU Work Platform & CTU. PT'd equip to 4000 psi. Loaded well w! 178 bbls of 2% KCI Water to reduce WHP. RIH w! Mem GR/CCL & logged well f/1030' to 9700'. POOH w/ logging tools. RIH w! CT conveyed perf guns & shot 176' of add perforations f!: 9876' - 9940' MD (Zone 4) Reference Log: Sperry MWD Log 2/22!2001. 9972' - 10044' MD (Zone 4) 10090' - 10112' MD (Zone 4) 10150' - 10168' MD (Zone 4) Used 2" PJ carriers & all shots @ 4 SPF, 60° phasing, random orientation, & underbalanced press. POOH w/guns - ASF. RD CTU & Work Platform. Placed well BOL & performed a representative welltest. Page 1 L L LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical date listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton/Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 13S9 Stafford, TX 77497 BP Exploration (Alaska}, Inc. Petrotechnical Data Center LRP-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole I I 1 Res. Eval. CH I I 1 Mech. CH 1 Caliper' Survey Print Name: RECEIVED JUL 1 6 2001 Aiaeka Oil & Gas Cons. CommJ~ion Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memorvlo~.com STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL [~] GAS D SUSPENDED D ABANDONED ~] SERVICE 2. Nameo, Operator ,~,...~.,~ 7. Permit Number BP Exploration (Alaska), Inc.t~~ 201-008 3. Address i "'~~ 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612~ ,~...~ ~ .$t~ 50-029-20584-01 4. Location of well at surlace ..... :' ~L~ 9. Unit or Lease Name .~,.. 1889' FNL, 4158' FEL, Sec. 24, T10N, R15E, UM (asp's 719911, 5929055). ..... · : Prudhoe Bay Unit At Top Producing Interval ' ~_~,_~,~.~,__~../~' 10. Well Number At 1670' FNL, 1545' FEL, Sec. 24, T10N, R15E, UMTotal Depth (asp's 722519' 5929353) i;~. .~_; ~i~' ~;£~ 11. Field16'06Aand Pool ~39' FNL, 341' FEL, SEC 24, T10N, R15E, UM (asp's 723738, 5928820) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 72 feetI ADL 28332 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115, Water Depth, if offshore 16. No. ot Completions February 18, 2001 Februa~ 21,2001 May 26, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey 12o. Depth where SSSV set 21. Thickne~ of Permafrost 11132' MD /9041' ~D 11058' MD /9024' TVD YES ~ No ~I 2182' feet MD 1900' (approx) 22. Type Ele~ric or Other Logs Run MWD GR, GR/CNL, GR/Resistivi~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEMENTING RECORD~ AMOUNT PULLED 20" 94~ H-40 Surface 80' 32" 300 Sx PF 13-3/8" 72~ L-80 Surface 2650' 17-1/2" 3000 Sx Fondu & 400 Sx PF 9-5/8" 47~ L-80 & S00-95 Surface 9536' 12-1/4" 500 Sx Class G 7" 29~ L-80 9237' 9653' 8-1/2" 35o Sx Class G 3-1/2" 3-3/16" 9.3~ / 6.2~ L-80 9238' 9747' 3-3/4" (see below) 2-7/8" 6.5~ L-80 9747' 11130' 3-3/4" 22 bbls 15.8 ppg LARC 24. Pedorations open to Pmdu~ion (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (al~ shots used2" carriers, 6 SPF, Zone 4) 5-1/2" 9207' 9184' 10774' - 10804' MD; 8992'- 8994' TVD; ~ 6 SPF 4-1/2" 9282' 10838' - 10872' MD; 8996' - 8999' TVD; ~ 6 SPF 11000' - 11020' MD; 9014.5' - 9017' TVD; ~ 6 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11050' - 11066' MD; 9023' - 9026' TVD; ~ 6 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2100' 60/40 Methanol Water for FP (See Sidetrack Summa~ for details) 27. PRODUCTION TEST Date First Produ~ion Method of Operation (Flowing, gas li~, etc.) May 29, 2001 gas lift Date of Test Hours Tested Productionlor OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/30/2001 6.5 Test Pedod >~ 951 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (co~) Press. -229 psi 24-Hour Rate > 127 121 206 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 January 30, 2001 (Permit Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Zone 4 9639' 8938' 31. LIST OF ATTACHMENTS Summary of 16-06A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signe Coil Tubin,q Drillin.q En.qineer Date May 29, 2001 Lamar Gan~_/ Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ~ ~;..~' ~... ~[~ I '~/' ~!~ ~/i?~ Form 10-407 .. i 16-06A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 1/28/2001: 1/29/2001: 1/30/2001: 2/12/2001 - 2/25/2001: 3/07/2001 - 3/08/2001: 3/28/2001: 5/25/2001: 5/26/2001 - 5/28/2001: 5/29/2001: MIRU CTU#8. PT'd equip. RIH w/CT nozzle & killed well w/351 bbls of 2% KCL Water. Tagged Whipstock Tray @ 9653' MD. P&A'd well with 25 bbls of 15.8 ppg Class G Cement (see P&A summary for details). Placed 10 bbls of cement behind pipe @ max squeeze press of 1200 psi. Contaminated cement w/ Biozan & cleaned out to the 9625'. POOH. WOC. PT'd BOPE. RIH w/BHA & PT'd cement plug to 1000 psi WHP - bled to 787 in 5 min & to 780 in 10 min. Milled XN Nipple @ 9270'. Tagged TOC @ 9625' & milled cement to 9651'. Milled window through the 7" Casing f/9653' - 9659' & POOH. RIH & dressed window interval. Drilled FM to 9665.5' MD. Backreamed window. Pumped Biozan sweep. POOH. FP'd well to 2000' w/Methanol Water. RD CTU#8. Performed CT Sidetrack w/Nabors 3S (see attached well event summary). Installed new GLV design. Performed SBHPS Survey. MIRU CTU. PT'd equip. RIH & jetted w/60/40 Methanol Water through ice plug @ 2437'. RIH to 6000'. Pumped 135 bbls of 150° F Crude down BS. POOH. RD CTU. Performed a CT Mud Acid Stimulation as follows: MIRU CTU & APC portable test separator. PT'd equip to 4000 psi. Killed well w/2% KCL Water. RIH w/CT & tagged PBTD @ 11058' MD. Reciprocated treatment fluids across the initial perforations f/: 10774' - 10804' MD (Zone 4) 10838' - 10872' MD (Zone 4) 11000' - 11020' MD (Zone 4) 11050'- 11066' MD (Zone 4) Pumped: (a) 40 bbls of 3% NH4CI w/additives @ 0.72 bpm, followed by (b) 103 bbls of 7.5% HCL @ 1.12 bpm, followed by (c) 50 bbls of 9% - 1% HCI - HF @ 0.8 bpm, followed by (d) 150 bbls overflush w/150 bbls of 3% NH4CI w/additives @ 0.9 bpm, followed by (e) displaced CT w/40 bbls of 3% NH4CI, followed by (f) shutdown. POOH w/CT. RD CTU. Acid flowback to APC test separator. Placed well 16-06A on initial production. Obtained a representative well test. Sidetrack Summary Page 1 BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: 16-06 'Common Well Name: 16-06A ;Event Name: REENTER+COMPLETE Start Date: 2/10/2001 End Date: 2/25/2001 DATE TMD 24 HOUR SUMMARY 2/12/2001 9,653.0 (ft) Move onto 16-06 from B-29a. Spot rig & rig up. Coil unit maintenance 2/13/2001 9,653.0 (ft) Continue rigging up. 2/14/2001 9,653.0 (ft) Attempted to PT BOPE w/o success. Several valves leaking 2/15/2001 9,653.0 (ft) PT BOPE. Replace leaking valves. Load cable in coil. 2/16/2001 9,653.0 (ft) Waiting on DS/t.4. work on rig alarms. Rig maintenance. 2/17/2001 9,653.0 (ft) RU ROC. RIH w/BHA#1 2/18/2001 9,836.0 (ft) Drill build to 9836'. 2/19/2001 10,572.0 (ft) Drill to 10572'. Tight spot @9830'-9750. Backream shale. 2/20/2001 11,070.0 (ft) Drill. Ream tight shales. 2/21/2001 11,132.0 (ft) Drill to TD. Make MAD pass. P/U 2 7/8" liner and RIH. 2/22/2001 11,132.0 (ft) RIH w/2 7~8" liner and cement. P/U log tools RIH 2/23/2001 11,132.0 (ft) TIH run memory GR-CCL. BOPE test. P/U cleanout BHA 2/24/2001 11,132.0 (ft) Clean out cmt f/liner to PBTD. P/U perf guns and peri. TOH 2/25/2001 11,132.0 (ft) LID perf guns. Freeze protect well. N/D BOP. N/U tree/test Rig Release Printed: 3/27/2001 9:24:20AM BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: 16-06 Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: 2/25/2001 Contractor Name: NABORS Rig Release: Group: COIL Rig Name: NABORS 3S Rig Number: DS~4 Sub Phase Description of Operations Date From-To Hours Task Code ~2/12/2001 08:30 - 12:00 3.50 MOB PRE Move rig and equipment from B-29a. 12:00 - 20:00 8.00 RIGU PRE Spot equipment and rig up 3S. 20:00 - 00:00 4.00 RIGU PRE Nipple up BOPE. Take on 1% KCL for testing. 2/13/2001 00:00 - 10:00 10.00 RIGU PRE Continue rigging up equipment. Back side tanks arriving from B-29A. Get Back side lines hooked up and close in dike. 10:00 - 00:00 14.00 RIGU PRE Continue rigging up equipment. Received Veco tank. Coordinate equipment to pump cable into coil reel. 2/14/2001 00:00 - 09:00 9.00 RIGU PRE Continue RU while loading cable in coil at Deadhorse. RU to test BOPE without coil using triplex pump. 09:00 - 14:30 5.50 BOPSUF TEST PROD1 PT BOPE. Inconsistent tests -- some flatline, some bleed-off. 14:30 - 17:00 2.50 BOPSUF TEST PROD1 AOGCC requests witness on remainder of test. Wait on inspector. 17:00 - 18:00 1.00 BOPSUF TEST PROD1 Continue PT BOPE. Test 2-3/8" pipes -- leak. Need to verify master is holding. Perform body test -- chase location of leak. 18:00 - 22:00 4.00 BOPSUF.TEST PROD1 Attempted several times to test BOPE w/o success. Call for greasers to service master valve.. 22:00 - 00:00 2.00 BOPSUF.TEST PROD1 Waiting on grease truck. Continue chasing leak. 2/15/2001 00:00 - 03:00 3.00 BOPSUF.TEST PROD1 Waiting on grease truck. Determined that both kill line valves leak. 03:00 - 04:30 1.50 BOPSUF.TEST PROD1 Grease crew on location. Service master. 04:30 - 06:30 2.00 BOPSUF.TEST PROD1 Wait on replacement valves from Veco. 06:30 - 10:00 3.50 BOPSUF.TEST PROD1 Replace the two manual kill valves. Pressure test good. Body test showed master leak. 10:00 - 13:00 3.00 BOPSUF.TEST PROD1 ~ Pull BPV. Set TWC. Replace a couple leaking valves on floor manifold. Finally got a flat line. 13:00 - 18:30 5.50 BOPSUF PROD1 PT BOPE with AOGCC witness Chuck Sheve. Need some work on LEL alarms. Blinds failed on Iow pressure test. 18:30 - 00:00 5.50 BOPSUF PROD1 Rebuild blinds. WOW to finish BOP test -- Phase 3. 2/16/2001 00:00 - 02:00 2.00 BOPSUF PROD1 Retest blinds, finish BOPE test. RD PT equipment. 02:00 - 00:00 22.00 RIGU PRE Wait on DS #4 to finish cable loading/pipe cutting in Deadhorse. Pull TWC. General rig maintenance. LEL and H2S alarm diagnostics and repair. 2/17/2001 00:00 - 01:30 1.50 RIGU PRE Waiting on DS#4. ROC maintenance/repair. 01:30 - 06:30 5.00 RIGU PRE CT unit on location. Spot unit. RU. 06:30 - 11:00 4.50 RIGU PRE Stab pipe. 11:00 - 13:30 2.50 DRILL PROD1 Install CTC. Pull test. Change packoff. 13:30 - 15:00 1.50. DRILL PROD1 Start filling coil with methanol. Started seeing pressure fluctuations after just a few bbls pumped, then pressured up. ROC is frozen. Able to work about 25 bbls of mehanol into coil, with several break-backs in pressure, before it locked up completely. 15:00 - 17:30 2.50 DRILL COIL PROD1 Tarp and heat the ROC. Surge pipe. Broke free. 17:30 - 18:15 0.75 DRILL PROD1 PT backside line, inner reel valve. Remove tarps. 18:15 - 18:45 0.50 DRILL PROD1 Safety meeting -- BHA and H2S. 18:45 - 20:45 2.00 DRILL PROD1 MU BHA. Ice plug on coil. 20:45 - 21:30 0.75 DRILL COIL PROD1 RIH to break ice plug. RIH to 1030'. establish circulation. POH 21:30 - 22:15 0.75 DRILL PROD1 P/T MHA. Mud on location 22:15 - 23:15 1.00 DRILL PROD1 Start pumping water. Stab onto well. 23:15-00:00 0.75 DRILL PROD1 RIH w/BHA #1. 2/18/2001 00:00- 01:20 1.33 DRILL PROD1 RIH. Shallow test. OK. 01:20 - 01:40 0.33 DRILL PROD1 Continue RIH. Dry tag. Tag bottom @ 9677'. Correct depth (-12'). Corrected depth 9665'. Orienting. 01:40 - 02:00 0.33 DRILL PROD1 Drill ahead. 02:00 - 03:30 1.50 DRILL PROD1 POH to cased hole. Shut in pumps. Observe well. Swap mud out of the hole. Observe well. 03:30 - 03:50 0.33 DRILL PROD1 Log tie in to RA PIP tag. 9664'. Correct -3'. Printed: 2/26/2001 3:09:40 PM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: 16-06 Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: 2/25/2001 Contractor Name: NABORS Rig Release: Group: COIL Rig Name: NABORS 3S Rig Number: DS~4 Date From -To Hours Task Sub Phase Description of Operations Code 2/18/2001 03:50 - 04:50 1.00 DRILL PROD1 Drill ahead. 2.4/3281/8R. Drill to 9725'. 04:50 - 06:30 1.67 DRILL PROD1 Getting just 33 deg/100' on the motor. Need 42/100'. POOH to readjust motor to 3.3. 06:30 - 07:00 0.50 DRILL PROD1 Safety meeting 07:00 - 08:15 1.25 DRILL PROD1 Readjust 2.8 SR motor to 3.3. 08:15 - 08:30 0.25 DRILL PROD1 RIH with BHA #2. 08:30 - 09:30 1.00 DRILL CIRC PROD1 Unable to get rig pump working. Gravel in suction filters and pump valves. Can't get it running again. Swap to DS pump. 09:30 - 11:30 2.00 DRILL PROD1 RIH. 11:30 - 11:45 0.25 DRILL PROD1 Orient TF above window. 11:45 - 12:30 0.75 DRILL PROD1 RIH and tag TD 9744' CTM. Correct depth (-19'). Log up (3' stretch). Tie into RA. No additional correction. 12:30 - 14:00 1.50 DRILL PROD1 Drill 2.4/3300/5R to 9776'. 14:00 - 14:45 0.75 DRILL PROD1 Unable to orient in OH. PUH to casing. 14:45 - 16:45 2.00 DRILL PROD1 Drill 2.4/3300/straight up to 9836'. Project 95 deg at bit. Got to 8975' SSTVD which is about 20' below the line. Drilled like shale on bottom. May have skimmed the biggy we were trying to avoid. 16:45 - 18:30 1.75 DRILL PROD1 POOH for smaller bend motor and resistivity tool. 18:30 - 22:00 3.50 DRILL PROD1 OOH. Change out motor to 1.37 bend. P/U resistivity tool. 22:00 - 22:35 0.58 DRILL PROD1 RIH w/BHA #3. Stop at 400'. Problems w/16-05 wellhead. 22:35 - 00:00 1.42 DRILL PROD1 RIH. TD @00:00 9836'. 2/19/2001 00:00 - 00:45 0.75 DRILL PROD1 Cont RIH. Orient to HS. 00:45 -01:20 0.58 DRILL PROD1 Tie in GR. Corrected -16'. 01:20 - 01:45 0.42 DRILL PROD1 Orient to 80 R. 01:45 - 03:15 1.50 DRILL PROD1 Drill 2.6/3600/66R. Drill to 9860'. 03:15 - 04:50 1.58 DRILL PROD1 Drill 2.6/3600/80R. Drill to 9918'. 04:50 - 05:35 0.75 DRILL PROD1 Orienting to 90R. 05:35 - 07:30 1.92 DRILL PROD1 Drill 2.6/3530. Drill to 10014' 07:30 - 08:30 1.00 DRILL PROD1 Orient around. Overshot. Do it again. 08:30 - 09:00 0.50 DRILL PROD1 Drill 2.5/3400/90R to 10080'. 09:00 - 09:30 0.50 DRILL PROD1 Wiper trip to window. Motor work in 9800' - 9880' shale and in shale stringers up to window. 09:30 - 10:30 1.00 DRILL STAB PROD1 Ream tight shales. 10:30 - 10:45 0.25 DRILL PROD1 Drill to 10103' 10:45 - 11:15 0.50 DRILL PROD1 Orient around. 11:15 - 12:45 1.50 DRILL PROD1 Drill to 10200'. 12:45 - 13:00 0.25 DRILL PROD1 Orient for left turn. 13:00 - 13:45 0.75 DRILL PROD1 Drill to 10232'. 13:45 - 14:45 1.00 DRILL PROD1 Wiper to window. Shales in good shape this time. 14:45 - 19:30 4.75 DRILL PROD1 Drill 2.5/3500/90L to 10410'. 19:30 - 20:40 1.17 DRILL PROD1 Wiper to the window. Tight spot. Backream shale @9830' - 9750'. 20:40 - 21:00 0.33 DRILL PROD1 Drill 2.6/3870/70R to 10426'. 21:00 - 23:45 2.75 DRILL PROD1 2.6/3800/137. Drill to 10572'. 23:45 - 00:00 0.25 DRILL PROD1 Wiper trip to the window. No problems passing through shales. 2/20/2001 00:00 - 01:40 1.67 DRILL PROD1 Continue w/wiper trip. 01:40 - 03:15 1.58 DRILL PROD1 Drill 2.6/3800/80L Drill to 10638'. 03:15 - 03:30 0.25 DRILL PROD1 Orienting 03:30- 04:00 0.50 DRILL PROD1 Drill 2.6/3800/85L to 10717 04:00 - 06:00 2.00 DRILL PROD1 Drill 2.6/3800/126L to 10768'. 06:00 - 08:00 2.00 DRILL PROD1 Wiper to window. Ream shales. 08:00 - 14:00 6.00 DRILL PROD1 Continue drilling left turn 2.5/3700. Slow drilling with negative wt trying to punch thru shales. Add 150 bbls new mud to the system. Should be past fault. Looking for oil. Drill to 10955'. Printed: 2/26/2001 3:09:40 PM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: 16-06 Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: 2/25/2001 Contractor Name: NABORS Rig Release: Group: COIL Rig Name: NABORS 3S Rig Number: DS~4 Sub Phase Description of Operations Date From-To Hours Task Code 2/20/2001 14:00 - 16:00 2.00 DRILL PROD1 Wiper trip to window. Work tight shales coming up. 16:00 - 17:00 1.00 DRILL PROD1 Log tie-in at RA. Correct depth (+26'). 17:00 - 19:00 2.00 DRILL STAB PROD1 RIH sat down 9852', work through to 9862'. No progress. PUH and orient high right. RIH and sat down at 9852'. Work pipe without pumps. Worked thru shale by setting down negative wt and waiting a minute or two and then got some wt back. Continue this, getting a foot or two at a time, to 9875' before falling thru clean. Continue RIH to TD. Multiple set downs in shale stringers. 19:00 - 19:30 0.50 DRILL PROD1 Orient TF. 19:30 - 21:00 1.50 DRILL PROD1 Drill 2.5/3600/110L to 11042'. 21:00 - 22:45 1.75 DRILL PROD1 Wiper to window. Shales a little better, but numerous set-downs RIH. 22:45 - 23:15 0.50 DRILL PROD1 Orient TF 23:15 - 00:00 0.75 DRILL PROD1 Drill to 11,070'. 2/21/2001 00:00 - 02:00 2.00 DRILL PROD1 Drill TD (end of polygon): 11128' MD, 8968' SSTVD. 02:00 - 04:15 2.25 DRILL PROD1 MAD pass from TD to window. 04:15 - 05:00 0.75 DRILL PROD1 Log tie-in at RA. Correct depth (+7'). 05:00 - 06:15 1.25 DRILL PROD1 TIH tagged at 11132'. No correction. 06:15 - 09:00 2.75 DRILL PROD1 TOH. Lay in 100 bbls new 9.1 ppg FIo-Pro 1 :lin openhole. Spot methanol from 800' to surface. POH to BHA monitor well for flow. 09:00 - 11:30 2.50 DRILL PROD1 LID BHA 11:30 - 13:00 1.50 CASE PROD1 Rig up to run liner. 13:00 - 13:30 0.50 CASE PROD1 Hold PJSM, job assigments, and well control ops on running liner. 13:30 - 14:00 0.50 CASE PROD1 P/U 2 7/8" shoe track and 2 jts. 14:00 - 14:30 0.50 CASE PROD1 Hold well control drill with the 3 1/2" tbg joint stood back in derrick. 14:30 - 18:30 4.00 CASE PROD1 Continue running liner. 18:30 - 18:50 0.33 CASE PROD1 PJSM to P/U LRT and 6 DC's. 18:50 - 19:40 0.83 CASE PROD1 M/U LRT and DC's. 19:40-20:10 0.50 CASE PROD1 M/U CT connector. PT to 4000 psi and pull test to 25K. 20:10 - 21:25 1.25 CASE PROD1 Displace methanol from CT and annulus. 21:25 - 23:59 2.57 CASE PROD1 RIH w/liner. 2/22/2001 00:00 - 00:30 0.50 CASE PROD1 Finish RIH w/liner. Landed at 11132'. Tight at 9880', 10440' and last 100'. 00:30 - 00:45 0.25 CASE PROD1 Circulate on bottom. 00:45 - 01:30 0.75 CASE PROD1 Drop and pump down .625" ball. Shear out at 4500 psi. P/U and confirm liner release. Call f/cementers. 01:30 - 05:30 4.00 CASE PROD1 Circulate and condition hole. R/U cementers. 05:30 - 06:30 1.00 CEMT PROD1 PJSM and cementing procedures held with both crews. (Crew change at 0600 hrs) 06:30 - 08:12 1.70 CEMT PROD1 Batch mix 26 bbls (22 pumpable) 15.85 ppb D-134 Latex cement. Pump 5 bbl 2% KCL ahead. PT lines to 5000 psi. Followed by 22 bbls cement. Pumped .5 bbl KCL behind then loaded and launched "dart". Continued displ w/10 bbl KCL, 20 bbl 2# Bio, then 27.4 bbl KCL. Reduced pump rate to 1.5 bpm. Dart sheared Liner Wiper Plug at 3200 psi (1700 psi over). Continued displ and bumped plug w/3300 psi (1000 psi over) as scheduled. Bleed off pressure, floats held okay. ClP @ 0810 hfs 2-22-01 08:12 - 10:45 2.55 CEMT PROD1 Pressure up to 500 psi and sting out of liner. POH and wash with Biozan to surface. No cement seen to surface. 10:45 - 12:00 1.25 CEMT PROD1 Make up swizzle stick above collars and wash out BOP stack. 12:00 - 14:00 2.00 CEMT PROD1 LID LRT's and 5 - 3/12" DC's. 14:00 - 17:00 3.00 EVAL . PROD1 Drift 1/14" CSH tubing and prep BHA for running GdCCL log. W@ Schlumbergr. 17:15 - 21:30 4.25 EVAL PROD1 P/U logging tools BHA #4. Printed: 2/26/2001 3:09:40 PM BP EXPLORATION Page 4 of 5 Operations Surnma Report Legal Well Name: 16-06 Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: 2/25/2001 Contractor Name: NABORS Rig Release: Group: COIL Rig Name: NABORS 3S Rig Number: DS~4 Sub Phase Description of Operations Date From-To Hours Task Code 2/22/2001 21:30 - 22:40 1.17 EVAL PROD1 P/U injector. Displace coil with KCL. '22:40 - 23:59 1.32 EVAL PROD1 TIH to 9170'. TIH w/logging tools 2/23/2001 00:00 - 01:25 1.42 EVAL PROD1 Finish TIH to 9170'. 01:25 - 02:00 0.58 EVAL PROD1 Log GR-CCL from 9170' to 11005' (uncorrected to PDC). (Tagged high to latch collar at 11068'. Unable to work down farther.) 02:00 - 02:30 0.50 EVAL PROD1 Displace liner with 150K LSRV FIo-Pro and log up. 02:30 - 04:40 2.17 EVAL PROD1 POH to 1 1/4" tubing. 04:40 - 06:00 1.33 EVAL PROD1 Set back injector and freeze protect coil. 06:00 - 09:30 3.50 EVAL PROD1 Stand back 1 1/4" CSH. LID logging tools. Log confirms high tag of 10998' corrected. 09:30 - 11:00 1.50' EVAL PROD1 Pressure test 2 7/8" liner. Communication with 5 1/2" x 9 5/8" inner annulus, suspect gas lift mandrels. Bleed off IA and check for fluid pack. Bleed small amount of gas then fluid to surface. Shut-in IA and perform combination test of liner lap and inner annulus. Initial: 2000 IA x 1400 tbg. Stabilized to 1975 IA x 1375 tbg and held for 30 min. 11:00 - 23:30 12.50 EVAL PROD1 Test BOPE. Notified AOGCC. Witnessing wavied by John Crisp. 23:30 - 23:59 0.48 EVAL PROD1 M/U BHA #5. 2/24/2001 00:00 - 01:05 1.08 PERF COMP Finish P/U BHA #5 and injector. 01:05 - 01:40 0.58 PERF COMP Displace methanol from coil with KCL water. 01:40 - 03:40 2.00 PERF COMP RIH. Tag up a 10986' make +12' correction to 10998' (corrected Gr-CCL log run tag). 03:40 - 04:45 1.08 PERF COMP Drill cement f/10998' to 11068'. Work pipe every 10'. 04:45 - 06:00 1.25 PERF COMP Circulate and wash liner top to bottom. Lay in 10 bbls 150k LSRV FIo-pro. 06:00 - 07:10 1.17 PERF COMP TOH to 1 1/4" tbg. 07:10 - 08:45 1.58 PERF COMP Fill coil w/60/40 methanol, set back injector. 08:45 - 11:00 2.25 PERF COMP Stand back 1 1/4" tbg and LID motor. 11:00 - 11:20 0.33 PERF COMP PJSM on picking up perf guns. 11:20- 14:00 2.67 PERF COMP P/U perf guns and BHA #6. 14:00 - 15:00 1.00 PERF COMP P/U injector displace to KCL water. 15:00 - 16:55 1.92 PERF COMP TIH tag TD at 11068'. Launch .625" ball. P/U 1' for bottom shot at 11066' 16:55 - 17:40 0.75 PERF COMP Pump 57 bbl KCL. Ball on seat and sheared at 2850 psi. No fluid losses noticed. Perf intervals 6 SPF as follows: 11066'-11050', 11020'-11000', 10872'-10838', 10804'-10774'. Flow check well. 17:40 - 18:50 1.17 PERF COMP TOH to 1 1/4" tbg. Flow check. 18:50 - 19:15 0.42 PERF COMP Fill coil w/60/40 methanol, set back injector. 19:15 - 23:30 4.25 PERF COMP LID 1 1/4" CSH tbg. 23:30 - 23:59 0.48 PERF COMP PJSM on LID of perf guns. 2/25/2001 00:00 - 01:50 1.83 PERF COMP L/D perf guns all shots fired. 01:50 - 03:10 1.33 PERF COMP P/U nozzle and checks RIH to 2200' and freeze protect well w/60-40 methanol. Well dead. TOH 03:10 - 04:00 0.83 RIGD COMP Install BPV. 04:00 - 08:00 4.00 RIGD COMP RID Schlumberger ROC and Coil Unit. N/D BOP's. 08:00 - 11:00 3.00 RIGD COMP N/U 7 1/16"x5K tree and test to 5000 psi. 11:00 - 11:01 0.02 RIGD COMP Rig Released 1100 hrs 02-25-2001 Printed: 2/26/2001 3:09:4(} PM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: 16-06 Common Well Name: 16-06A Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: 2/25/2001 Contractor Name: NABORS Rig Release: Group: Rig Name: NABORS 3S Rig Number: DS~4 Date From - To Hours Task Sub Phase Description of Operations Code 2/22/2001 17:00 - 17:150.25 EVAL PROD1 PJSM picking up logging tools, running CSH tubing. Printed: 2/26/2001 3:09:40 PM TREE = ? WR LHEAD= ? ACTUATOR= FMC AXEL KB. ELEV = 72 BF. ELEV = 72 KC)P= 9653' Max Angle = 99 @ 10190' Datum MD = 11130' Datum TVD= 8969' 113-3/8" CSG 72# L.-80, ID=12.347 I I 2650' 16-06A Minimum ID = 2.38" @ 9726' 3-3/16" x 2-7/8" Crossover TOPOF3-1/2" Liner H 9238' 5-1/2" TBG17# LB0 0.0232bpf ID=4.892 ~[ ITOPOF 4-1/2" TBG I"""~ 9207' 9207' ITOPOF 7"LNR ]----[ 9237' 4-1/2" TBG 12.6# L80 0.0152bpf D=3.958 '---I 9282' 9-5/8" CSG 47# L-80, ID=8.681 ~ 9536' SAFETY NOTES 2182' STA MD I TVD I 1 I 2887128871 2 1~81148~1 I 3 I ~°71 64321 I 4 I 7499 170,~ I I ~ I ~1 5-1/Z'CAM. BAL-O SSSV NIP, ID=4.562 I GAS LIFT MANDRELS DEV211 .~' TYPEoT_LBOT_LBMAN I LATCH I 34; OT-LB 341 OT-LB 31, OT-LB 29 OT-I_B OT-LB OT-LB OT-LB 5-1/2" AVA LOC SEAL ASSY I I 9183' I~1 9184' I-il 9-5/8"xs-1/2"AVA FI3RHYDRSETPKR [ 9207' [---I x°5'l/2"x4-1/2"l 9270' [~1 4-1/2" OTIS XN NIP, ID=3.725 9281' I--t ~,~"~.~o~ I 9282' [~1 4-1/2" TUBING TAIL 9~8o' I--I ~L~ I PERFORATION SUIVtvlARY REF LOG: BHCS on 5/7/1981 ANGLE AT TOP PERF: 186@40774' Note: Refer to R'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 10774-10804 O 2/24/2001 2 6 10838-10872 O 2/24/2001 2 6 11000-11020 O 2/24/2001 2 6 11050-11066 O 2/24/2001 9653' [ Mil Window off W/S 9726'I [ 3-3/46" x 2-7/8"XOI 3-3/4" Open Hole [7" LNR29#L-80 0.0371bpf D=6.184 N 10254' [ lo261' I i I2-7/8" Liner Cemented & Perforated PERFORATIONS P&A'd w/15.7 ppg CEMENT 1113o'I DATE REV BY COMIVENTS 05/12/81 ORIGINAL COIVPLErlON 05/18/91 LAST WORKOVER 01/02/01 SIS-QAA CONVERTED TO CANVAS 01/04/01 pcr proposed sidetrack 03/05/01 adk Actual CT sidetracks PRUDHOE BAY UNIT WELL: 16-06A ST PERMIT No: 181-051 AFl No: 50-029-20584-01 10N 15E24 1333.41 FB_ 1660.68 FNL BP Exploration (Alas ka) 15-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 16-06A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,600.00' MD 9,650.00' MD 11,132.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 2'7 Alaska Oil & 6as Cons. Commission Anchorage North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~ 6, Slot ~ 6-06 ~6-06A Job No. AKMWIO050, Surveyed: 2~ February, 2001 SURVEY REPORT March, 200~ Your Ref: 50029205840~ Surface Coordinates: 5929055.05 N, 7~99~.44 E (70° ~2' 3~.0~88" N, ~48° ~3' 35.9442" VIO Kelly Bushing: 72.0Oft above Mean Sea Level DRILLING 5~=RV II~E~5 A Halliburton Company Survey Reft svy'10778 Sperry-Sun Drilling Services Survey Report for 16-06A Your Ref: 500292058401 Job No. AKMWIO050, Surveyed: 21 February, 2001 North Slope Alaska Measure d Depth (ft) Incl. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) fit) (ft) (ft) (ft) (ft) 9600.00 25.270 92.500 8830.17 9650.00 23.790 90.660 8875.66 9659.82 25.230 90.700 8884.59 9703.02 37.710 104.650 8921.41 9734.82 49.830 88.650 8944.41 9768.82 64.770 87.950 8962.72 9797.42 77.520 84.430 8971.95 9812.42 84.730 82.150 8974.26 9838.77 95.330 81.230 8974.25 9868.57 97.180 86.510 8971.00 9904.54 98,150 93.030 8966.20 9936.97 98.590 99.550 8961.47 9966.77 97.270 105.010 8957.36 9992.77 94.800 110.120 8954.62 10021.90 92.070 115.590 8952.87 10053.10 92.950 121.230 8951.51 10085.90 93.300 128.980 8949.72 10113.30 94.630 133,740 8947.82 10138.90 97.360 138.140 8945.15 10159.10 98.240 142.720 8942.40 8902.17 223.27 N 2599.07 E 5929353.91N 8947.66 222.69 N 2619.81E 5929353.93 N 8956.59 222.64N 2623.89 E 5929354.00 N 8993.41 219.16 N 2645.99 E 5929351.17 N 9016.41 216.98 N 2667.70 E 5929349.62 N 9034.72 217.84N 2696.21E 5929351.31N 9043.95 219.66 N 2723.15 E 5929353.92 N 9046.26 221.40 N 2737.86 E 5929356.08 N 9046.25 225.20 N 2763.90 E 5929360.64N 9043.00 228.36 N 2793.34 E 5929364.66 N 9038.20 228.51 N 2828.97 E 5929365.84N 9033.47 225.00 N 2860.84E 5929363.26 N 9029.36 218.72 N 2889.67 E 5929357.82 N 9026.62 210.92 N 2914.31E 5929350.74 N 9024.87 199.63 N 2941.09 E 5929340.24 N 9023.51 184.80 N 2968.49 E 5929326.22 N 9021.72 165.98 N 2995.27 E 5929308.18 N 9019.82 147.93 N 3015.78 E 5929290.73 N 9017.15 129.64N 3033.48 E 5929272.97 N 9014.40 114.22 N 3046.22 E 5929257.92 N 9009.66 88.72 N 3063.90 E 5929232.95 N 9005.47 62.85 N 3081.19 E 5929207.60 N 9002.83 38.31N 3099.93 E 5929183.61N 9001.47 14.54N 3121.29 E 5929160.48 N 9001.07 2.93 S 3139.44 E 5929143.54N 10190.50 99.120 147.830 8937.66 10221.90 96.210 144,660 8933.47 10252.90 93.570 140.610 8930.83 10284.90 91.280 135.500 8929.47 10310.10 90.570 132.330 8929.07 722502.90 E 722523.66 E 722527.73 E 722549.93 E 722571.69 E 722600.17 E 722627.04 E 722641.69 E 722667.61E 722696.95 E 722732.55 E 722764.52 E 722793.51E 722818.37 E 722845.47 E 722873.29 E 722900.60 E 722921.63 E 722939.86 E 722953.05 E 722971.46 E 722989.49 E 723008.94 E 723030.99 E 723049.64E Alaska Drilling & Wells PBU_EOA DS 16 Dogleg Vertical Rate Section Comment (°/'~00ft) 3.33 14.66 33.28 51.39 43.97 46.O7 50.35 40.38 18.67 18.17 19.94 18.68 21.73 20.95 18.28 23.62 18.00 20.15 22.88 16.33 13.64 15.55 17.48 12.89 1847.49 1863.75 1866.91 1886.07 1904,10 1925,40 1944.86 1955.01 1972.51 1993.03 2020.23 2046.91 2073.02 2096.91 2124.69 2155.21 2187.82 2215.13 2240.45 2260.13 2290.06 2319.93 2350.06 2381.70 2406.84 Tie-on MWD Magnetic Window point March, 2001 - 17:05 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-06A Your Ref: 500292058401 Job No. AKMW10050, Surveyed: 21 February, 2001 North Slope Alaska Measure d Depth (ft) 10343.10 10371.70 10402.30 1O429.90 10461.50 Incl. 89,960 87.930 90.480 92.510 94.540 126.160 121.230 117.000 120.520 126.860 Sub-Sea Depth (ft) 8928.91 8929.44 8929.87 8929.15 8927.20 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 9000.91 23.80 S 3164.99 E 5929123.42 N 723075.78 E 9001.44 39.66 S 3188.77 E 5929108.26 N 723100.01E 9001.87 54.54S 3215.49 E 5929094.17 N 723127.16 E 9001.15 67.81S 3239.67 E 5929081.60 N 723151.72 E 8999.20 85.30 S 3265.90 E 5929064.89 N 723178.44 E 10492.20 95.330 131,620 8924.56 8996.56 10526.90 94,450 138.320 8921.60 8993.60 10552.50 93.130 141.840 8919.90 8991.90 10581.50 89.600 147.480 8919.21 8991.21 10611.50 90.040 146.420 8919.31 8991.31 10642.30 89.780 143.080 8919.36 8991.36 10673.70 90.220 138.490 8919.36 8991.36 10704.20 91.720 133.030 8918.84 8990.84 10734.10 88.990 127.750 8918.65 8990.65 10766.00 86.430 124.050 8919.93 8991.93 104.64S 3289.59 E 129.06 S 3314.03 E 148.65 S 3330.42 E 172.28 S 3347.18 E 197.43 S 3363.54E 10796.50 86.870 118.760 8921.71 8993.71 10833.90 86.340 113.470 8923.93 8995.93 10868.10 83.520 107.660 8926.95 8998.95 10896.70 83.260 103.600 8930.25 9002.25 10930.20 83.700 97.970 8934.05 9006.05 222.58 S 3381.31E 246.90 S 3401.16 E 268.74 S 3422.43 E 288.10 S 3445.19 E 306.79 S 3471.00 E 322.65 S 3496.98 E 339.08 S 3530.49 E 351.04 S 3562.37 E 358.69 S 3589.72 E 364.92S 3622.40 E 97.090 8937.25 9009.25 368.74S 3651.28 E 90.570 8941.25 9013.25 370.85 S 3682.74 E 84.930 8945.88 9017.88 369.61S 3714.16 E 78.760 8951.78 9023.78 364.99 S 3746.48 E 74.180 8958.26 9030.26 358.26 S 3774.45 E 10959.50 83.790 10991.30 81.760 11023.10 81.500 11056.30 78.060 11085.80 76.560 5929046.25 N 723202.68 E 5929022.55 N 723227,82 E 5929003.45 N 723244.78 E 5928980.31N 723262.22 E 5928955.65 N 723279.30 E 5928931.03 N 723297.80 E 5928907.30 N 723318.35 E 5928886.09 N 723340.24 E 5928867.39 N 723363.56 E 5928849.46 N 723389.90 E 5928834.37 N 723416.33 E 5928818.92 N 723450.31E 5928807.89 N 723482.52 E 5928801.04 N 723510.08 E 5928795.77 N 723542.93 E 5928792.79 N 723571.91E 5928791.60 N 723603.41E 5928793.75 N 723634.79 E 5928799.31N 723666.96 E 5928806.85 N 723694.73 E Dogleg Alaska Drilling & Wells PBU_EOA DS 16 Vertical Rate Section Comment (°/100fi) 18,79 2439.82 18.64 2468.23 16.14 2498.27 14.72 2525.32 21.o3 2556.65 15.66 19.40 14.66 22.94 3.83 10.88 14.68 18.56 19.88 14.10 17.37 14.19 18.82 14.13 16.75 3.00 21.32 17.57 21.02 15.98 2587,23 2621.65 2646.80 2674.83 2703.53 2733,31 2764.14 2794,47 2824.36 2856.14 2886.24 2922,47 2954,58 2980.45 3009.49 3034.06 3059.51 3082.79 3104.58 3121.69 15 March, 2001 - 17:05 Page 3 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-06A Your Ref: 500292058401 Job No. AKMWIO050, Surveyed: 21 February, 2001 North Slope Alaska Measure Sub-Sea d Depth Incl. Azim. Depth (~) (~) 11132.00 76.560 74.180 8969.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~) (~) (~) (~) (~) 9041.00 346.01 S 3817.69 E 5928820.35 N 723737.58 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 130.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11132.00ft., The Bottom Hole Displacement is 3833.34ft., in the Direction of 95.179° (True). Dogleg Rate (°~'~OOft) 0.00 Alaska Drilling & Wells PBU_EOA DS '16 Vertical Section Comment 3146.93 Projected survey Comments Measure Station Coordinates d Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment 9600.00 8902.17 223.27 N 2599.07 E Tie-on 9650.00 8947.66 222.69 N 2619.81 E Window point 11132.00 9041.00 346.01 S 3817.69 E Projected survey March, 200~ - ~7:05 Page 4 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-06A Your Ref: 500292058401 Job No. AKMWIO050, Surveyed: 21 February, 2001 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 16 Survey tool program for 16-06A From To Measure Vertical Measure Vertical d d Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 9600.00 8902.17 9600.00 8902.17 11132.00 9041.00 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gym (16-06) MWD Magnetic (16-06A) March, 2001. t7:05 Page 5 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services North Reference Sheet for 16-06 North Slope Alaska Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Grid Coordinates of Well: 5929055.05 N, 719911.44 E Geographical Coordinates of Well: 70° 12' 31.0188" N, 148° 13' 35.9442" W Grid Convergence at Surface is 1.669°. Magnetic Declination at Surface is 26.952° (17 February, 2001) True North .Gnd.North __ netic North Magnetic Model: · · .' .... - r Hole Direction Grid North is 1.669°. :East of True NOrth (Grid COnvergence) Magnetic NOrth is 26:952~ East of True NOrth (Magnetic Declination) Magnetic North is 25.283'''' East of Grid NOrth (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 1.669 degrees To convert a Magnetic Direction to a True DireCti°n,'Add 26.952 degrees To convert a Magnetic Direction to a Grid Direction, Add 25.283 degrees _ IGBGCF00 Date: 17-Feb-01 Declination: 26.952 Inclination/Dip: 80.775 Horizontal Component: 9217 nT Northerly Component: 8216 nT Eastedy Component: 4177 nT Vertical Component: 56753 nT Total Field Strength: 57496 nT Alaska Drilling & Wells PBU_EOA DS 16 March, 200~ - ~7:05 Page 6 of 6 DrillQuest 2.00.06 ALASKA OIL AN~D GAS CONSERYA~ION CO~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 16-06A BP Exploration (Alaska) Inc. Permit No: 201-008 SurLoc: 1893'SNL, l121'EWL, Sec. 24, T10N, R15E, UM Btmhole Loc. 2215'SNL, 4975'EWL, Sec. 24, T10N, R15E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you fi.om 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 COMMISSION , DATED this ~ o ~ day of January, 2001 dlffEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~, STATE OF ALASKA ~[ ~/~ ALASI~ 31LAND GAS CONSERVATION cory(" $SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work B Drill 511 Reddll 1 lb. TYpe of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen! [] Service [] Development Gas [] Single~7~ne [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 72' Prudhoe Bay Field / Prudhoe !3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028332 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1893' SNL, 1121' EWL, SEC. 24, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1670' SNL, 3736' EWL, SEC. 24, T10N, R15E, UM 16-06A Number 2S100302630-277 At total depth 9. Approximate spud date 2215' SNL, 4975' EWL, SEC. 24, T10N, R15E, UM 02/01/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028346, 304' MDI No Close Approach 2560 11115' MD / 8968' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9650' MD Maximum Hole Angle 93 o Maximum surface 3000 psig, At total depth (TVD) 8900' / 3880 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weiqht Grade Couplinq Length MD TVD MD TVD (include stage data) 3-3/4" 3-3/16./2-7/8. 6.2#/6.4# L-80 ST-L/FL4S 1915' 9200' 8463' 11115' 8968' 108 sx Class 'G' D r-. {\il-- JAN 19. To be completed for Redrill, Re-entry, and Deepen Operations. ' ' Present well condition summary Alaska Oil & Gas Cons. Commission Anchorage Total depth: measured 10261 feet Plugs (measured) PBTD tagged at 9939' (05/97) true vertical 9522 feet Effective depth: measured 9939 feet Junk (measured) true vertical 9217 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2650' 13-3/8" 3000 sx Fondu, 400 sx Permafrost 2650' 2650' Intermediate Production 9536' 9-5/8" 500 sx Class 'G' 9536' 8844' Liner 1024' 7" 350 sx Class 'G' 9237' - 10261' 8569' - 9522' Perforation depth: measured 9646' - 9686', 9696' - 9756', 9800' - 9810' true vertical 8944' - 8981', 8990' - 9046', 9087' - 9097' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements 'Contact Engineer Name/Number: Dan Kara, 564-566? ' ' Prepared By Name/Number: Terrie Hubble, 564-462B 21. I hereby certify thai the foregoing is true and ~0rreet to'the best of my knowledge ' Signed DanKara ~-..._,._...,-, Title CT Drilling Engineer Date 1/12./Z.~9o[ "'".: :.: ' ... '.'.' ".....:. :.'i:".':: "'?.' '. ':.i'.';' :'""'..':.'. :.': i:.'::' '" '!".. ;: .~.'. ::. ;.... :./' ?.':..' :.i ~:...'?!.:.:commissiOn.use oai¥.?! :':.' i:':. ::'?? :...:..: ! ~.':.':...!?."::.:..:' .. ':.. '.......::.'.....::: ::...:...?'i..:!...' ;? ::...:'.: '~'... i'. Permit Number I API Number I Appro~nl Date ..... i' 'See cover letter -"~/~'~::~'~I 50- 029-20584-01 .I (~2/'"' ~ "" g)/ I for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes !~] No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K '~.5K psi for' CTU Other: ORIGINAL SK.:;~'.,~,i'.-' by order of Approved By [,,) 'Tavtr,,r ~;,"',' ,~';.,, Commissioner the commission Date g~) / "- Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate BPX Prudhoe Bay Producer 16-06A Sidetrack Summary of Operations: 16-06 is being sidetracked to improve Zone 4 production. This sidetrack will be conducted in two phases. Phase 1 Prep Work: Install mechanical whipstock, P&A well, mill window Drift tubing, perform integrity test of inner annulus. · Run a caliper log in 7" liner. · Install mechanical whipstock at 9650' · RU service CTU, pump 15.8 ppg cement to isolate existing perfs. · Mill 3.80" window at 9650' (Zone 4 KOP) Phase 2: Drill and Complete sidetrack: Planned for Feb 01, 2001. Coiled tubing drilling will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Weighted brine (9.0 ppg) for window milling · Phase 2: Flo-Pro (9.0 ppg) for drilling operations. RECEIVED JAN 1 Alaska Oil & Gas Cons, Commission Disposal: Anchorage · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3-3/16", 6.2//STL L-80 x 2 7/8", 6.4//, L-80 FL4S liner will be run from TD to approx. 9200' MD (into tubing tail) and cemented with approximately 22 bbls. Top of cement is planned to be at the liner top. The liner will be pressure tested to 2000 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray and Resistivity log will be mn in the open hole section. · A Memory CNL may be mn in cased hole. Hazards · Lost circulation risk is low. Faults will be crossed and are expected to be sealing · Latest H2S was measured at 136 ppm on 3/26/99 Reservoir Pressure · Res. pressure is approx. 3880 psi @ 8900 tvd. · Max. surface pressure with gas (0.1 psi/ft) to surface is 3000 psi. RECEIVED JAN 1 2 ZOO] Alaska Oil & Gas Cons. Commission Anchor~e 16-06A Potential Drilling Hazards Post on Rig Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. Latest H2S was measured at 136 ppm on 3/26/99. Ensure H2S pit monitors and personal monitors are operational. DS 16 is designated as an H2S drillsite. 3. Reservoir pressure was measured at 3880 psi @ 8900 tvd (9/10/00), or -8.4 ppg EMW. 4. Maximum anticipated well head pressure w/full column of gas 3000 psi. . One mapped fault will be crossed. However, risk of lost circulation is low. Offset faults in this area are sealing faults. RECEIVED JIlN 1 2, 2001 Alaska Oil & Gas Cons. Commission Anchorage WSSSV Tubing Casing Gas Lift Mandrel/Valve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift MandrelNalve 5 Gas Lift Mandrel/Dummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 Gas Lift MandrelNalve 8 Chemical Mandrel/Valve 9 SEALASY PBR XO Tubing NOGO Liner SOSUB TTL' Ped .... ~ Perf..-" 16-06 ~i6.b~ ~ll'll il; :l i Il: i,~ Il ~l~( li~ llll ~ ~l~l~ ~ll ~ ~llll I:l~l ~':~ [ ~'~L~ T~i~,iI I':'' ;: :':'l' i Last:~ll ~ ~l~ l~ {11) I l~llTa~ ....... ~.~;..[~.~ ................ t .... ~[Lst U;~a:e. 4~16,'9~ Elevations KB 72. II ~ Cas FI.n.q ,-- . Grd I 0 ft Tub Head KB-Grd .I 72 ft [Ot!!er (pl~Jg'S: (~quJpl. etc.).- All Depth ID Type Description .. General Notes Date Note 9270 Min ID -- 3.725" ~4._-.1/2" Ot!s._X~ Oft --~,i.'. 07,'12ll~] p~{l~05 '~0 . i. TTL EL[`1~:~l~ll~l!!~l~llLt~l[lTll{ll[l`llll[j~.~:~l~ll[l¥l'~ill..l(?~9~(~p::~Z1Z;~i~l~[e|~l~; 19.~1-05-1'~" I ................... Grd Item Top Btm Wt (in) t ('tKB) I (ftKB) I { _13.375 in Cas{n_g ................ _0._0.0_.1 ..... 2~_0._9.~L ......... 72 O0 L-80 .c asl n ~..S_.t.r. Ln..tL_l_.Ni~ B ............................................................................................ Item Top Btm Wt Grd Ii (ftKB) (ftKB)....... 29.00. L-80 (in) 7.000 in Liner .......... 9.237.._0_0._. 1.~.0..2.61.00 Cas{qgl_S_t_rin[I- lelep0Z .~, I! .O.N Item ................. ToP .... g~{ ..... '~' ........... (~'rr~ ........ (in) (ftKB) I (ffKB) ?.7.~Q. _. L:.8.~., . 9 626 in Casir, c i 0.00I 9536.00: fi [ ~ ~ ~ l~Tl{~f~ l ~ ~T~il ~ ~ ~ ll~ll ; ~ l~ ll;~ ..... ~ I I I ~ I I I I ~ il ll ll~l ;ZTZll ill ~;liZl~ ...... Item Top Bottom Len Wt Grd l(in) I (ftKB) I (ftKB) (ft) .~ 12l~0 I 17,00 9207 5 500 in Tubing 0.00 9207.001 L-80 .... . m.. I .... ]~I~ ~ ~i~[ ~ ~ ~I r~i ~]I ~; ............................................................... 9 i ~76~.MMG.LT]! ! L MO I VRCH RK 0P~?~8 3620.0 816191 i ~]] T []~l[1]~ ~] ]]]i ~l]~ll i i I~ I~i I~ ~ i l~ Li i Iiii Ii II i ......... It ~I M D i M a ~ M fr i M ~ Type ¥1vMfr VlV Type L~ll=ll~Iv V~l~l~O VlVllR~l l ' Port i 2~87 OT-LB CA R-20 RK 0.250 1810.0 11t11/9, 2 4881 OT-LB OT RD-I.5 ~ I0.0001 0.01 1/1~60 3 6407 OT-LB CA R-20 RK 0.250 1,2Z01 11111/94 4 7499 OT-LB OT RD-I.5 RA 0.000I 0.01 111160 5 8057 OT-LB CA R-20 RK 0.250/ 1803.0 11II1/94 6 I 83341 OT-LB I I OT / RD-I.5 IRA t0.000/ 0.0[ 1/1/60 71 86641 OT-LB I I OT / RD-1.5 RA 0.000[ 0.0 1Ili60 8 / 89681 OT-LB CA I RDO RK 10.3751 9999.01 11/11/94 Interval Zone 9646 - 9651 ZONE 4 9651 - 9661 ZONE 4 9661 - 9671 ZONE 4 9671 - 9681 ZONE 4 9681 - 9686 ZONE 4 9696 - 9706 ZONE 4 9706 - 9716 ZONE 4 9716 - 9726 ZONE 4 9726 - 9736 ZONE 4 9736 - 9746 ZONE 4, HOT 9746 - 9756 ZONE 4,HOT 9800-9810 ZONE 4,HOT.OWC Statu~ Feet SPF Date Type I Comment O / 5 4 3/26/82 IPERF O ! 10 8 6/2/88 RPERF O ! 10 4 3/26/82 { IPERF I O I 10 8 6/2188 { RPERF I O / 5 4 3126/82 I IPERF o I 10 8 612188 RPERF o / lO/ 4{3/26/82 IPERF Io ! 10/ 8/e12/88 {RPERF IO I l°1 I O / 10] lO / lO/ 4/5/25/84 IAPERF I RECEIVED JAN 1 2, ZOO1 Alaska Oil & Gas Cons. Commission Anchorage WELLHEAD= ? ACTUATOR= FMC, AXEL KB. ELEV = 72 BF. ELEV = 72 KOP = __.? Max Angle = 35 @ 5400 Datum IVlD = '~ ~.* Datum TV 16-06A ( I SAFETY NOTES PROPOSED HORIZONTAL SIDETRACK 13-3/8" CSG 72# L-80 0.1481bpf ID=12.347 ~ 2650' IMinimum ID = 3.725" @ 9270' 4-1/2" OTIS XN NIPPLE 2182' 5-1/2"CAM. BAL-O SSSV NIP, ID= 4.562 GAS LIFT MANDRELS 2 14881148541 211OT-LBI RAI ~ I ~°Zl s~l ~10T-,~ I ~<I I" IZ"~l~°"Sl ~10T-L~ I ~ I I S IS0SZlZS~I ~10T-~ I~ I I ~ IS~6~IS0~I 2~10T-LB I ~ I I S IS~SlS~I ~10T-.B I ~ I 9183' [--~ 5-1/2" AVA LOC SEAL ASSY I PROPOSED TOP OF 3-3/16" Liner H 9200, ! 9184' I~ 9-5/8"X5-1/2"AVAPBRHYDRSETPKRI 15-1/2" TBG 17# L80 0.0232bpf ID=4.892 9207' 9207' ITOPOF 7'' LNR I'~ 9237' 14-1/2" 'TBG 12.6# L80 0.0152bpf ID:3.958 I---{ 19-5/8" CSG 47# L-80 0.0732bpf ID=8.681 9282' 9536' 9207' 927O' 9281' 9282' 9280' J.---J XO 5-1/2" X 4-1/2" J J---~ 4-1/2" OTIS XN NIP, ID=3.725 J J-~ 4-1/2" BKRS/O SUB J I---J 4-1/2" TUBING TAIL I RECEIVED JAN I 2 2001 PERFORATION SUMMARY REF LOG: BHCS on 5/7/1981 ANGLE AT TOP PERF: 124@9639 I Note: Refer to Production DB for historical )err data SIZE SPF INTERVAL Opn/Sqz DATE 4 9646-9686 O 03/26/1982 4 9651-9661 O 06/02/1988 4 9671-9681 O 06/02/1988 4 9696-9716 O 03/26/1982 4 9696-9706 O 06/02/1988 4 9716-9756 O 05/25/1984 4 9716-9726 O 06/02/1988 4 9736-9746 O 06/02/1988 4 9800-9810 O 07/06/1993 J 9650' J 9710' Alaska Oil & Gas Cons. Commission Anchora~ I Mill Window off WiS I 3-3/16" x 2-7/8" XO J 3-3/4" Open Hole J J2-7/8" Liner Cemented & Perforated J J 11115'J I~ I~1 J7" LNR29# L-80 0.0371bpf ID=6.184 J----~ 10254' J 10261' J PERFORATIONS P&A'd w/15.7 ppg CEMENT DATE REV BY COMMENTS 05/12/81 ORIGINAL COMPLETION 05/18/91 LAST WORKOVER 01/02/01 SlS-QAA CONVERTED TO CANVAS 01/04/01 pcr proposed sidetrack PRUDHOE BAY UNIT WELL: 16-06A Proposed ST PERMIT No: 181-051 APl No: 50-029-20584-01 10N 15E24 1333.41 FEL 1660.68 FNL BP Exploration (Alaska) BP Amoco Baker Hughes INTEQ Planning Report (.:ompauy: BP Ar'rloco Field: Pn:dhoe ~.qy ~il,:: PB DS 16 V¥eiI: ~,6-06 A'ellpath: P~an~l 16-06A ,, Field: Prudhoe Bay Nor~ Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Dat.m: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: !/9!209.1 'lime: 1.7:19:55 Pa~ze: I Co-ortlinate(Ni'h Refert:nee: WeT 16-(k3. True NO~'~ Vertical (l~ D) Referen~: Syst6m: Mean Sea Leve{ ~ection (~ ~)'Relk. rem'c: Well (0 00E,O.OON. 13C.O0Azi) Sm'~e~ Caleulalion Mt'Ih.d: Minimum CuP~atlJre Db: Crac~e ........... Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 16 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Positiou Uncertainty: 0.00 ft Ground 'Leveh 0.00 ft 5927441.99 fl Latit.de: 70 12 15.545 N 718969.88 ft Longitude: 148 14 4.567 W North Reference: True Grid Convergence: 1.66 deg Well: 16-06 Slot Name: 06 16-06 Well Position: +N/-S 1585.19 ft Northing: 5929055.07 ft Latitude: 70 12 3!.135 N +E/-W 987.72 ff E, asting: 719911.19 ft Lon~tude: 148 13 35.900 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 16-06A Drilled From: 16-06 500292058401 Tie-on Depth: 9650.00 ft Cra'rent Datum: 7: 06 4/22/1981 00:00 Height 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/9/2001 Declination: 26.98 deg Field Strength: 57495 nT Mag Dip Angle: 80.77 de9 Vertical Section: Depth From (TVD) +NAS +E/-W Direction ft ft ft deg 0,00 0.00 0.00 130.00 Plan: Plan #1 Date Composed: 1/9/2001 Lamar's Plan #12 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets : .Map Mqp X/amc l)e~crilnim~ TVI) -: N."-.~ ,--I,'/-~A NorHfi~g F;a.~t'ing .......................................... ,z ....l.atitm'h: .... :> ':'.~-- l.,ngiludc -~-> I)e,, Min Sec I'h:~ %1i. get- , ~ Annotation "'"' ............. RECEIVED ftfl .... b600.00 .... 8'~,:~J}17 ' ' Ti~'-'i'~"~'oint .................................................................................... 9650.00 8875.66 Kick-offPoint JAN I 2 ZO01 9660.00 88 4.62 1 9805.74 8955.34 2 10009,71 8949.10 3 Alaska Oil & Gas Cons. Commissi 10384.71 8927.99 4 10810,38 8917,28 5 /,ncnorage 11115.29 8968.21 TD Plan Section Infi}rmation ~11.) htcl Azim '!'% D ..~.-%.-S 4. E."'*~% I)1.% I{,ihl 'T.rn '1'!:(') f't d.~g ,.,,'"'~o~ 'f,' 'ft ft de...':l:' 100fl d~]'i..';0ft <leg.... or:,: dt-'.-',,] 9600.00 25.27 '" 92.50 '~830.'17 223.26 .... :~'599.04 0.00 0.00 0.00 0.00 9650.00 23.79 90.66 8875.66 222.68 2619.78 3.33 -2.96 -3.68 206.47 9660.00 28.79 90.66 8884.62 222.63 2624.21 50.00 50.00 0.00 0.00 9805.74 90.00 90.66 8955.34 221.25 2743.76 42.00 42.00 0.00 0.00 10009.71 93.47 110.77 8949.10 183.57 2943.03 10.00 1,70 9.86 80.00 10384.71 92.75 148.32 8927.99 -50.60 3226.56 10.00 -0.19 10.01 90.00 10810.38 90.00 105.83 8917.28 -301.21 3558.37 10.00 -0,65 -9.98 267.00 11115.29 70.96 81.55 8968.21 -322.10 3854.63 10.00 -6.24 -7.96 230.00 I"argel · ..... BP Amoco ~.~ Baker Hughes INTEQ Planning Report 'i~:~i:!ii'~:~ ............... (romp;in): BP Amoco I,)atc: t,'9'2001 I'ifll~: I'.z:19:55 Page: riehl: Prudhoo Bay Co-nrdinate(NE) Reference: 't~el!: i15-~3. True Noah ~i~t,: PB DS 16 Verlical ( i%' I')] Referen~: S'yst~m: Mean Sea LeVel ~x ell: '" ~" ,o-oa Section {¥g) Rt'i~rt'llcC: Well iD ' ~'~ ' '~ ' .... Wcllpath: Plan¢1 16-06A Sm',ey Cnlcsslatinn MclhmJ: Minimum Ca~iat~Jre Db: Oracle .................................. Surve}. ................................................................................. Xlt) Int'l .~tim ~IWD X,'S E~hV Mapg MapE DI .S ~'S TFO 'l'r~l E dag dag ft fl fi fl ft degt I ()Oft fi ~g ~00.06 ..... ~g,:~ ,~.~0 ~5bJ~' ~.:~ ~gg.o4 ~9~.~ ~gOZgl" 0.00 '"~84~.4z 0.00' 9625.00 24.53 91.61 8852,85 222,88 2609.56 5929353.84 722513.03 3.33 1855,77 206.47 MWD ~50.00 23,79 90,66 8875.66 222.68 2619.78 5929353.94 722523.25 3.33 1863.73 207.28 MWD 9660.00 28.79 90.66 8884,62 222,63 2624.21 5929354.01 722527.68 50.00 1867,16 0.00 MWD 9675.00 35,09 90.66 8897.34 222.54 2632,14 5929354.15 722535.61 42.00 1873.29 0.00 MWD 9700.00 45,59 90.66 8916,37 222,35 2648.30 5929354.44 722551.77 42.00 1885,79 360.00 MWD 9725.00 56,09 90.66 8932.14 222.13 2667.66 5929354.78 722571.12 42.00 1900.76 0.00 MWD 9750.00 66,59 90.66 8944,11 221.88 2689.56 5929355.16 722593.02 42.00 1917,70 360.00 MWD 9775.00 77,09 90.66 8951.89 221.60 2713,28 5929355.58 722616.74 42.00 1936.05 0.00 MWD 9800.00 87,59 90.66 8955,22 221,32 2738.02 5929356.02 72264~.48 42.00 1955,~9 360.00 MWD 9805.74 90.00 90.66 8955,34 221,25 2743.76 5929356.12 722647.22 41.99 1959,63 0.00 MWD 9825.00 90,33 92.56 8955.28 220.71 2763,01 5929356.14 722666.47 10.00 1974.72 80.00 MWD 9850.00 90,77 95.02 8955,04 219,06 2787.95 5929355.21 722691.45 10.00 1994,89 80.01 MWD 9875.00 91.20 97.48 8954,61 216,34 ' 2812.80 5929353.22 722716.37 10.00 2015,67 80.03 MWD 9900.00 91.63 99.95 8954.00 212.55 2837.50 5929350.15 722741.17 10.00 2037,03 80.07 MWD 9925.00 92.06 102.41 8953.19 207.71 2862.01 5929346.02 722765.81 10.00 2058,92 80.13 MWD 9950.00 92,48 104.88 8952.20 201.82 2886,29 5929340.84 722790.24 10.00 208~.30 80.21 MWD 9975.00 92.90 107.34 8951.03 194.89 2910.28 5929334.61 722814.42 10.00 2104,13 80.31 MWD 10000.00 93,31 109.81 8949.68 186,94 2933,94 5929327.36 722838.30 10.00 2127.37 80.42 MWD 10009.71 93.47 1~0.77 8949.10 183.57 2943.03 5929324.26 722847.49 9.98 2136,50 80,52 MWD 10025.00 93.47 112.30 8948.~7 177.97 2957,23 5929319.07 722861.84 10,00 2150.97 90.00 MWD 10050.00 93.46 1 ~4.81 8946.66 168.00 2980.10 5929309.77 722884.99 10.00 2174.90 90.09 MWD 10075.00 93,45 117.31 8945.16 157.03 3002,52 5929299.47 722907.72 10.00 2199.12 90.24 MWD 10100.00 93.43 ~ 19.82 8943.66 145.10 3024.43 5929288.18 722929.97 ~0.00 2223.58 90.40 MWD ~0125.00 93.40 122.32 8942.17 132.23 3045.81 5929275.93 722951.71 10.00 2248.23 90.55 MWD 10150.00 93.37 124.82 8940.69 118.43 3066.60 5929262.74 722972.90 10.00 2273.03 90.69 MWD 10~75.00 93.33 ~27.33 8939.23 103.73 3086.77 5929248.64 722993.48 10.00 2297.92 90.84 MWD 10200.00 93.28 129.83 8937.79 88.17 3106.28 5929233.65 723013.44 10.00 2322.87 90.99 MWD 10225.00 93.23 132.33 8936.37 71.77 3125.09 5929217.81 723032.72 10.00 2347.83 91.13 MWD 10250.00 93.17 134.84 8934.98 54.56 3143A7 5929201.14 723051.29 10.00 2372.74 91.27 MWD 10275.00 93.10 137.34 8933.61 36.58 3160.48 5929183.67 723069.12 10.00 2397.56 91.41 MWD ~0300.00 93.03 139.84 8932.27 ~7.86 3176.99 5929165.43 723086.~6 10.00 2422.24 91.55 MWD 10325.00 92.96 ~42.35 8930.97 -1.57 3192.67 5929146.47 723102.40 10.00 2446.73 91.69 MWD 10350.00 92.88 144.85 8929.69 -21.66 3207.48 5929126.82 723117.79 10.00 2471.00 91.82 MWD 10375.00 92.79 ~47.35 8928.46 -42.39 3221.41 5929106.51 723132.32 10.00 2494.99 91.98 MWD 10384.71 92.75 148.32 8927.99 -50.60 3226.56 5929098.45 723137.71 10.00 2504.2~ 92.1~ MWD 10400.00 92.67 146.79 8927.27 -63.49 3234.75 5929085.81 723146.27 10.00 2518.77 267.00 MWD 10425.00 92.53 ~44.29 8926.13 -84.08 3248.88 5929065.64 723160.99 10.00 2542.83 266.93 MWD 10450.00 92.39 141.79 8925.06 -104.04 3263.90 5929046.13 723176.58 10.00 2567.16 266.81 MWD 10475.00 92.25 139.30 8924.05 -123.32 3279,77 5929027.31 723193.01 10,00 2591.72 266.71 MWD 10500.00 92.10 136.80 8923.10 -141.90 3296,47 5929009.23 723210.24 10.00 2616.45 266.61 MWD 10525.00 91.94 134.30 8922.22 -159,73 3313.96 5928991.91 723228.25 10.00 2641.32 266.51 MWD 10550.00 91.78 131.81 8921.41 -176.79 3332,22 5928975.40 723246.99 10.00 2666.27 266.42 MWD 10575.00 91.62 129.31 8920,66 -193.04 3351.20 5928959.71 723266.44 10.00 2691.25 266.34 MWD 10600.00 91.46 126.81 8919.99 -208.44 3370,88 5928944.88 723286.55 10.00 2716.23 266.27 MWD 10625.00 91.29 124.32 8919.39 -222.98 3391.21 5928930.95 723307.30 t0.00 2741.15 266.20 MWD 10650.00 91,12 121.82 8918,87 -236.62 3412,15 5928917.93 723328.63 10.00 2765.96 266.14 MWD 10675.00 90,95 119.33 8918,41 -249,33 3433.67 5928905.84 723350.50 10.00 2790,61 266.09 MWD 10700.00 90,78 116,84 8918.04 -261.10 3455,72 5928894.72 723372.89 10.00 2815.07 266.04 MWD 10725.00 90,60 114.34 8917,74 -271,90 3478.27 5928884.59 723395.74 10.00 2839,28 266.01 MWD 10750.00 90,43 111.85 8917,51 -281,70 3501.26 5928875.46 723419.01 10.00 2863,19 265.98 MWD 10775.00 90,25 109.35 8917.36 -290.50 3524,66 5928867.35 723442.65 10.00 2886.77 265.95 MWD 10800.00 90,07 106.86 8917,29 -298,27 3548.42 5928860.27 723466.63 10.00 2909,97 265,94 MWD '~' ~(" t~ BP Amoco · Baker Hughes INTEQ Planning Report 'i.:~:~¥ili'(.~ ............... (.'OlilJ,~afl.~: BP Amoco Field; Prudhoe Bay ~ite; PB DS 16 V~'elh 16-06 Wcllp~t~: ~an~l 16-06A ................... -. , Xlt) h~t',l At. ira ff deg deg "' 10~10.38 ~'.~ ' 105.83 10825.00 89,06 104.71 10850.00 87.45 102.79 10875.00 85,85 100.87 10900.00 84,25 98.94 10925.00 82,66 97.00 10950.o0 81,08 95.05 10975.00 79,50 93.08 11000.00 77.94 91.08 11025.00 76,40 89.07 11050.00 74.87 87.03 11075.00 73,36 84.96 11100.00 71,87 82.85 , 11115.29 70.96 81.55 S,~ T'~:i) N.'.~ ft ft 891~.~8 -301.21 8917.40 -305,06 8918,16 -311.00 8919.62 -316.12 8921.78 -320.40 8924,62 -323,85 8928.16 -326.44 8932.38 -328.19 8937,27 -329.08 8942.82 -329.12 8949,02 -328,29 8955.87 -326.61 8963.34 -324.08 8968.21 -322.10 l)nte: ~, ,'9.'20'31 'l'im,~: 17:1§:55 Pa~e: 3 Co-,~rdinat(,(Nl<) Reft, fence: Weil: 1fi-~. Tn:e No,tn Yerlieal (I%'1)) Refermlce: System: Mean Sea [evel Section {¥~) Rt'i~reuce: Well (O.00E.0,{}0N.! 3O.t')0Az~) ....................................... ft ft dcg,," 10Oft f,.' deg ;~58,~"~"'5928857.62 723~"~6.66 9.95 29'~b.'48 '"~6~'.'~)~ MWO- 3572.47 5928854.18 723490.87 10.00 2932,76 230.00 MWD 3596.74 5928848.95 723515.30 10.00 2955,17 230.01 MWD 3621,17 5928844.55 723539.86 10.00 2977.17 230.07 MWD 3645,70 5928840.98 723564.51 10.00 2998.72 230.18 MWD 3670.30 5928838.25 723589.19 10.00 3019,78 230.35 MWD 3694.91 5928836.37 723613.86 10.00 3040.30 230.57 MWD 3719,48 5928835.35 723638.48 10.00 3060.25 230.84 MWD 3743.98 5928835.17 723663.00 10.00 3079,59 231.18 MWD 3768.36 5928835.84 723687.36 t0.00 3098.28 231.57 MWD 3792.56 5928837.37 723711.53 10.00 3116,29 232.01 MWD 3816,54 5928839.75 723735,45 10.00 3133.59 232.52 MWD 3840.26 5928842.97 723759.08 10.00 3150.13 233.09 MWD 3854.63 5928845.37 723773.39 10.02 3159.86 233.60 MWD RECEIVED JAN 1 2 Z001 Alaska Oil & Gas Cons. Commission Anchorage · '"" .-:::-'--. -- ~c~,~ ,"L,s-,~i ,'~.'", M Magnetic Norlh: 26.98' Magnellc Field i ~i ]! Stre~lgth: 57495~T ~'::~'~::':::' ::/":'":':'::':':: iiii[.i:~i~ Da,e: 1;~,2®, ""' .... i : i "~!'~;';'~ ' Model: BGGM2000 400-: : '' : : : : : : : .... .......: i ' :.:.. : -i i.i-:-i :-! :.- - ." , o0, ...................................... · ..... :,:-,-:-:.:. ::::::::::::::::::::::::::::::::::::: ..... · : : : .-.-:-.-. '-- ':':':-:-:' ":.-'" · ?i':':'i':' ': '--:-- ::::::::::::::::::::::::::::::::: REFERENCE INFORMATION 300".':' · .'.':'.' ............. ~ '"~ Y .... "?x. · ..... ........ ..~j~:' ':':~'~' ~"'" ~ '150"2~ : : .-:.- .'!'.T!'.T!'.¥.T!'.::':'.~'" 'T!' T:'.T:'~ ........ 'i ].'i.! .... · . 'x., .-.-:-... "i':i"?i':?.':i"i:il. i .......... ~ ~:i ~.-.'- '!'~'!'~'i'~':¥¥!:~ ::. :':'' ..:.i.:.i ~-~oo-.-! ...... ....... i...'''..:.... ':'~ ~' i iI iI i] ............................................. i ~. ~:.~ .? · · i i .]]i-!- i - · · ~ " i : : ':'-'.'-' ..................... : ...... . ........... ~ .: i ?.:i \.. · : . -- -..]]]]...?. . .. , . . -:-:-::!:: ............. : .............. ! ........ ! .... 'i':::'.' ] :: :] :]]':':::::]] :'" :]: :: · · $ .. : , : ..... .. ; ~ ~ ::?.':-:_.... · · \ : '-i-': : '~::::": .......... · ........... · "; "! ii -:!'?:~:-i~'-?":""'-'-?: ......... ~-'~ : . ... "~...~.:.-:...~ .... .:..-;.....:: .... ~ .... ~ .... ! .... ... .... ~ .. ..... .-~-~-~;?~-i.:~.:;-.~. ....... ~.:.~ .... i-i~--:.. .... :?~.._ ................... : ...... i .......... We st(+) [SOft/in] ~, · : . ...:.:...,:..: ,, :.. , · ~ ~ !: -:! ...... :---: ...... :':'i':'i':'i':'i"!- - - .:...:.:..:..:..:.:.:.:.:.:.:.: ................ ~ :'i':'i':i:'i':i:'i':!:'::':i:':i :" ..;.....:........:.....:....: ...: ...... , : : :' -: · ?-?:-?:-i-:?:-: : : ' ' ~.i .'i .. i : : -':'-i-':--!-':'-i-':'-!-'-! · ': :-! .... ": ':":-':': ':' :- :'-':' . !. ': · :-:-.-: . :-.-:-.--.- ............ ' : .~'i'~'i'i'!T!-! '~ · .... ~.':' ' ' i' .} ...... :. - i m · · .:-:---:---:-.-: .... · \"x . .~-, 5-': ?: ' ---~- ..... ~'"- ............ ~ -'~.' ..... ." ............. ~ ..................... ~..i. :.~. ?~...~ L- ......... -.. ~. ............ ~- ............................... i .........'~<~..~" ': .... · \[ ' ! : '.i-'.~-'~'-!.'~'.~.¥¥.'~ \ . ~ .... :::'?:'i':i:?:i:-i-:i:?:i:':i.. · ; ; . : . ... ....................... ........................ ., ............................. ........................... :.~ ----.----,-~--- , .-: :- ........................... i ! ::::::::::::::::::::::::::::::::::::::: · ,' - :.:-:-:-:':-:':':':-:-':-:.:-:-:-:--: · · · ' '-'~ ..... ~7.~:=i ~:-.'~ :."--;O :'~.~) ~,~-'"'J .!'.,)0 2050 2100 2'. . . ~.~ ~':~ :-:'cLO ?.",;~) :'~'..~t ::.'.::C ?:L.-': '-C:~ 2~;:-3 2700 27r~ ?~;,'-,; 2;:'/~ '-::~: ;'~".; '~. '."--.-'- .~;.-;; ',~.'~{; s;'~j j::~3, .:?:-.5 :.'.;~.-J 3350 3400 3450 Vedical Section at ~30.00° [5Oft/in] WELLPATH DETAILS Plan#'! 16-06A 500292058401 Parent Wellpath: 16-06 Tie on MD: 9650.00 Verl;ical Section Odgin: Slot- 06 (0·00,0.00) Vertical Section Angle: 130.00° Rig: Depth Reference: 7:06 4122/~981 00:00 Co-ordinate (N/E) Reference: Well Centre: 16-05, True North VP. rticel (TVD} Re[erP. nce: Sy~.m: Mean Se~ Level Section (VS') Refere~lce: Sk~ - rJI3 (0.00.0.00) Measured Depth Reference: 7: 06 4/22/19~1 00:00 72.0 Calculation Method: Minimum Curvature ANNOTATIONS P.875.66 ~.~.(X~ .~, oft 1 ~9.10 1~.71 ~ 8450' 9i00' .. · 915o- z rTl Plot 1/g/2001 5:32 PM Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA , , Quick Connect-- Il Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Combination Cutter/Blinds 2-3/8" Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with 2-7/8" Pipe & Slip Rams 2-3/8" Pipe & Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold ri Upper Annulus Lower Annulus RECEIVED JAN .t 2, 2001 Alaska Oil & Gas Cons. Commission Anchorage RE: Well B-29A BOP Configuration Subject: RE: Well B-29A BOP Configuration Date: Fri, 26 Jan 200t 23:21:14-0000 From: "Kara, Danny T" <KaraDT@BP.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak. us> CC: "Prudhoe AOGCC (E-mail)" <aogcc_prudhoe_bay@admin.state.ak.us>, "GPB, 3S Supervisor" <GPB3SSupervisor@BP.com>, "Stanley, Mark J (ANC)" <StanleMJ@BP.com> Tom, Attached is a schematic of the agreed upon BOPE configuration for Nabors 3S, Prudhoe well B-29A. The 2-7/8" pipe rams will be installed during the next weekly BOP test, probably tonight/tomorrow. As discussed on the phone, this same BOP configuration will also be used for Prudhoe well 16-05A and 16-06A. Both the DS16 well will have tapered liners. The longer term solution will be to replace the Hydril D stack with a TOT. This will allow us to install both 2-7~8" pipe/slips and 3-112" pipe/slips (TOT configuration top to btm: B/S, 3.1/2" P/S, mud cross, 2-7~8" P/S, 2-3~8" P/S). The 3-1/2" PIS have been ordered and will arrive in 8 weeks. Please let me know if I can provide additional information. Thanks, <<B-29A BOPE Tapered Liner. doc>> Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240-8047 (cell) ,564-5193 (Fax) karadt~bp.com ..... Original Message---- From: Tom Maunder[mailto:tom maunder@admin.state.ak.usl Sent: Thursday, January 25, 2001 4:30 PM To: Kara, Danny T Cc: AOGCC North Slope Office Subject: Re: Well B-29A BOP Configuration << File: Card for Tom Maunder >> Dan, This note confirms our conversations regarding the proposed ram arrangement when you are running the 2-7/8" x 3-3/16" liner with a 3-1/2" deployment joint. I forwarded your note to John Spaulding and discussed it with both he and Chuck Scheve. The new proposed stack arrangement does not provide any ram coverage for the 2-7~8" section of yoUr liner which comprises the majority of the string. Sealing ram coverage for the 3-3/16" and 3-1/2" Sections is not striCtly required due to th® much shorter length of these sections. They are in essence treated as "stingers". You indicated you do require 3-1/2" slip rams to hold the liner while NU the injector since the injector trolley cannot simultaneously support the hanging liner and the injector. I of 3 1/27101 6:21 AM (!::::.' Well f::l-2~A I~Lll~ L;orlTlguratlorl In our discussion you indicated that combi rams have been ordered to outfit a new TOT stack for 3S. Such a stack would be a significant improvement to the rig equipment and provide the necessary multiple diameter capabilities your coil and liner combinations need. You proposed that until the new stack is available, at your earliest opportunity you would install a set of 2-7/8" pipe rams above your mud cross to provide sealing ability when running the 2-7~8" portion of the liner. I discussed your 2-7/8" ram proposal with John. He and I are in agreement that your proposal is an acceptable interim solution. We hope the combi rams are available shortly to provide a better equipped stack. Please provide us with an update on the scheduled delivery of the new rams. Please contact either John or myself with any questions. Tom Maunder Petroleum Engineer "Kara, Danny T" wrote: > Tom, > The Nabors 3S BOP configuration on well B-29 is different than what is on > the Permit to Drill application. As we discussed on the phone, Prudhoe well > B-29A was permitted for a 2-7/8" liner (Permit #200-209). The BOP stack in > the application included the following (top to btm): annular, blind/shears, ' > 2-3/8" pipe/slips, fidw cross, 2.7/8" pipes and 2-7/8" slips. We would like > to install a tapered linerof3-1/2"FL4$ x 3-3/16" TCll x 2.7'/8" FL4S. A > tapered liner allows for future sidetracking options in this well. The > current BOP stack arrangement is. as follows (top to btm): annular, 3-1/2" > slips, 3-1/2" pipes, flow cross, blind/shears, 2-3/8" pipe/slips. > Attached are drawings of both BOP arrangements; the configuration that was > included in the permit to drill (B-29A BOPE Permit to Drill) and the > configuration that is currently on the rig (B-29A Tapered Liner). > In addition to B-29A Prudhoe wells 16-05A and 16.06A will both have tapered > liners and a similar BOP arrangement.. I would appreciate it if you could > make reference to this on both 16-05A and 16.06A application for permit to > drill. > Thanks for your help Tom. Please call me with questions. > <<B-29A BOPE Permit to Drill. doc>> <<B-29A BOPE Tapered Liner. doc>> 2 of 3 1127/01 6:21 AM Well B-29A BOP Configuration > Dan Kara > BP Coiled Tubing Ddlling > 564-5667 (office) > 240-8047 (cell) > 564-5193 (Fax) > karadt@bp.com > Name: B-29A BOPE Permit to Drill. doc > B-29A BOPE Permit to Dr~il. doc Type: Microsoft Word Document (applicationlmsword) > Encoding: base64 > > Name: B-29A BOPE Tapered Liner. doc > B-29A BOPE Tapered Liner. doc Type: Microsoft Word Document (application/msword) > Encoding: base64 i Name: B-29A BOPE Tapered Liner.doc ~B-29A BOPE Tapered Liner.doc1 Type: Microsoft Word Document (application/msword)i {Encoding: base64 3 of 3 1/27/01 6:21 AM Nabors 3S BOP Stack for Running 3-3/16" x 2-7/8" Tapered Liners ~___~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ !- 7"Riser Otis 7" WLA Quick Connect ~ Annular BOP (Hydril),7-1116" ID 5000 psi WP Alignment Guide Flange 7-1116", 5M Ram Type Dual Gate BOPE ~ HCR 3-1/2" Slip Rams 2-718" Pipe Rams Manual Valves Drilling spool 7-1116", 5M by 7-1116", 5M 7-1116", 5M Ram Type Dual Gate BOPE Manuel Master Valve 0.458' (5.5") -- 2" Pump-In Blind/Shears ~ 2-318" Pipe/Slip Rams Fire resistant Kelly Hose to Flange by Hammer up 114 Turn Hanger Valve on DS Hardline to Standpipe manifold Upper Annulus Lower Annulus H 179183 /ol;oo VENDC)R ALASKASTAT 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 113000 CKl13000I 100. O0 100. O0 PYMT (;OMMENTS: Pe~it to d~ill t:ee HANDL]iN~ INST: S/H - Te~ie X4~,28 E ATTACHED CHECK IS I" PAYMENT FOR ITEMS DESCRIBED ABOV~m~~m ~ 00, OO 1 OO. OO ~AY ',i:,., ;::'D~TI:: :,.'.,,:~:~.. I 12/01/00 $100. O0 :! ":::" : NOT'!~VALID AFTER 120 DAYS ~ ...,....., ,- .... ':,.. ,,, WELL PERMIT CHECKLIST COMPANY WELL NAME ~ PROGRAM: exp ~ FIELD & POOL ~:~ ADMINISTRATION INIT CLASS ~~/' A~,~ DATE l.l .ot 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 drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling 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 ........... ?'/~//_. GEOL AREA 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. Ddlling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~.~+'~,~ 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~ reddl v' serv wellbore seg ann. disposal para req ~_.'~ UNIT# ,O / / ~ ~-'"~...~ ON/OFF SHORE GEOLOGY ..~ DATE 30. Permit can be issued wlo hydrogen sulfide measures ..... Y ('1~,~ 31. Data presented on potential overpressure zones ....... ,Y, ~, 32. Seismic analysis of shallow gas zones ............. .r/l~ ~ 33. Seabed condition survey (if off-shore) .......... .~,~,~. Aj~rt y N 34. Contact name/phone for weekly progress reports [expleCatory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... 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 C~ O Z O Z -I -1- GEOL(~GY: ENGINEERING: UlL'/A~nular · . WM COMMISSION: ~,~S (.;..o-r' "/~.¢· JMH O-~_,L~:4. d'Zc~/01 Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01fl00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this. nature is accumulated at the end of the file under APPE'N. DIXi ., No'special'effort has been made to chronologically '. organize this category of information. Suerry-Sun Dri!iinc Services LIS Scan Utility SRevision: 3 $ lisLib SRevislon: 4 Thu Jun 20 09:00:53 Reel Header Service name ............. LISTPE ~ate ..................... 02/06/2C Orlgin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 16-06A 50029205'8401 BP Exploration (Alaska), Inc. Sperry Sun 20-JUN-02 MWD RUN 1 MWD RUN 2 MAD RUN 2 AK-MW-10050 AK-MW-10050 AK-MW-10050 B. JAHN B. JAHN B. JAHN JOHN MCMULLE JOHN MCMULLE JOHN MCMULLE 24 i0N 15E 1893 1121 72.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 7.000 9650.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: !. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. MWD RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE {NGP) UTILIZING A SCINTILLATION DETECTOR. M~D RUN £ iS 2iRECTiONAL WiTH DUAL G~2~I2-L~ .RAY ,'DGR. UTILiZiNG SEiSER MUELLEF. TUBE DETECTORS ELECTRO~L%GNETiC WAVE RESiSTiViTY PHASE 4 EWR4 . GAN~. RAY ,SSRD LDGSEi BEHi.N2 CASING FROM 9631' 8858' SSTVD TC 9650' MD, 8--6' CCTV2. 5. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 9661' MD, 8885' SSTVZ TO 9800' MD, 8972' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE AFTER DRILLING MWD RUN 2 AND IS APPENDED TO TOP OF MWD RUN 2 DRILLING DATA TO COMPLETE THE RESISTIVITY DATA. 6. A MADPASS WAS PERFORMED WHILE PULLING OUT OF THE HOLE AFTER DRILLING MWD RUN 2 AND IS PRESENTED AS A TAIL TO THIS LOG. 7~ DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG OF 02/23/01 WITH KBE = 72.0' A.M.S.L.. THIS WELL KICKS OFF FROM 16-06 AT 9650' MD, 8776' SSTVD (TOP OF WHIPSTOCK) ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 & 2 REPRESENT WELL 16-06A WITH API % 50-029-20584-01. THIS WELL REACHED A TOTAL DEPTH OF 11132' MD, 8969' SSTVD. CROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9634.0 RPD 9658.5 RPX 9658.5 RPM 9658.5 FET 9658.5 STOP DEPTH 11082.5 11093.5 11093.5 11093.5 11093.5 RPS 965~.5 ROP 966f. C $ BASELINE CURVE FOR SHIFTS: CURVE SHiF/ DATA (MEASUREi DEPTH' BASELINE DEPTH 9634.0 9643.5 9652.5 9657.0 9658.5 9661.0 9665.5 9668 0 9672 0 9677 0 9680 0 9683 0 9689 5 9694 0 9696 5 9704 0 9708 5' 9714.0 9717.5 9722.5 9731.5 9745.5 9751.5 9759.5 9763.0 9769.5 9777.5 97815 9789 5 9792 5 9794 5 9796 5 9802 0 9822 0 9829 5 9839 0 9844 5 9853 0 9856 5 9867 5 9881 0 9894 0 9899 0 9907 5 9916 5 9949 5 9954 0 10022 0 10042 5 10055 0 10072 0 10076.0 10077.5 10082.0 10094.5 10100.0 10105.0 10129.0 10134.0 10140.0 10144.5 10151.5 10159.0 10161.0 10171.0 10181.5 10187.0 10203.0 11093.5 !i129.C GR 9631 5 9641 0 9649 0 9655 5 9661 5 9662 5 9668 0 9670 0 9675 0 9680 0 9683 5 9685 0 9692 5 9697 5 9700.0 9706.5 9711.5 9717.0 9720.5 9725.5 9735.0 9747.5 9753.5 9761.0 9765.5 9770.5 9779.0 9785.5 9791.5 9795.0 9797.0 9799.0 9804.0 9820.5 9827.5 9837.0 9841.5 9849.5 9854.0 9866.0 9880.5 9889.0 9898 5 9908 5 9918 5 9948 0 9952 5 10020 5 10041 0 10051 5 10063 5 10068 5 10072 5 10080 0 10089 5 10097 0 10102 0 10124 5 10129 5 10136 5 10141 0 10149 5 10156 0 10159 5 10171 0 10179 0 10187 0 10203 0 EQUIVALENT UNSHIFTED DEPTH 10225,C 10231. C 10241.5 iC254.C 1028C.~ 10292. C i031i.C 10315.5 10339.0 i0349.C 10359.C 10375.5 10379.0 10383.0 10390.5 10400.5 10414.0 10442.0 10453.5 10482.5 10489.5 10502.5 10513.5 10527.5 10546.5 10552.0 10578.5 · 10589.5 10595.0 10602.5 10605.0 10608.5 10623.0 10627.0 ,,' 10640 . 5 ,'.~io647. o 10651.0 10657.0 10672.5 10685.5 10719.0 10732.0 10742.0 10754.0 10759.0 10763.0 10768.5 10779.5 10793.5 10810.0 10815.0 10823 5 10827 5 10831 0 10836 5 10841 5 10844 5 10847 5 10863 0 10867 5 10870 5 10874 5 10880 0 10889 5 10908 0 10917 5 10929 5 10936 5 10944.5 10953.0 10958.0 10962.5 10967.0 10969.0 10970.5 102£~.~ !022~.~ iC249.~ 1029J.3 10313.2 10333.C 10344.5 1035-.2 103r4.0 10379.5 10383.0 10388.0 10399.0 10411.0 10439.5 10452.5 10480.0 10485.5 10500.5 10512.0 10526.0 10542.0 10548.5 10576.0 10584.5 10590.0 10598.5 10601.5 10606.0 10627.5 10630.5 1,0643.0 10647.5 10651.0 10657.5 10673.0 10685.5 10721.0 10733.5 10745.5 10755.0 10759.5 10762.0 10768.0 10777.5 10791.5 10808.0 10814 0 10821 5 10828 0 10832 5 10835 5 10841 5 10844 0 10848 0 10862 0 10868 5 10872 0 10875 0 10879 0 10887 0 10904 5 10917 5 10928 5 10938 5 10945 5 10956 0 10961 5 10965 0 10969 5 10971 5 10973 5 10986.5 10989.5 11129.2 i!!3£.f # ~,iERGED DATA SOUR£E FBU TOOl CODE BiT RUN !iS biERGE .~.= MWD 1 963!.5 ~WD 2 9836.5 $ RE~ARKS: MERGED N~IK PASS. S Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 ,RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 MERGE BASE 9836.0 11132.0 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9634 11129 ROP MWD FT/H 0.14 2808.11 GR MWD API 20.15 512.21 RPX MWD OHMM 1.35 35.44 RPS MWD OHMM 1.45 33.56 RPM MWD OHMM 1.43 56.56 RPD MWD OHMM 2.48 32.16 FET MWD HR 0.215167 75.82 First Reading For Entire File .......... 9634 Last Reading For Entire File ........... 11129 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean 10381.5 90.5048 61.7131 8.72274 8.9385 9.22127 9.66496 12.5271 Nsam 2991 2923 2898 2871 2871 2871 2871 2871 First Reading 9634 9668 9634 9658.5 9658.5 9658.5 9658.5 9658.5 Last Reading '11129 11129 11082.5 11093.5 11093.5 11093.5 11093.5 11093.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physlcal Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FiLE HEADER FiLE NUMBER: 2 EDITED MERGED ~S~i' . .. _ .._ _ : . se Depth shifte! and cliuue~ curves; all b~i ~u~: merged usinc ear!ie_~ ~as s. DEPTH INCREMENT: .50~,3 # FILE S UM31ARY PBU TOOL CODE START DEPTH GR 9785.5 FET 9798.0 RPM 9798.0 RPD 979f. C RPX 9796.0 RPS 9798.0 RAT 9837.5 $ # MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MWD 2 1 $ # REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 . liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 STOP DEPTH 11083.0 11094.0 11094.C 11094.C 11094.0 11094.0 11129.0 Name Service Order Units Size Nsam Rep Code Offset Channel MERGE TOP MERGE BASE 9788.5 11132.0 DEPT FT 4 i 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 i 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 9785.5 11129 RAT MAD FT/H 63.66 1087.65 GR MAD API 18.2 145.32 RPX MAD OHM~ 2.62 260.69 RPS MAD OHMM 4 1153.25 RPM MAD OHMM. 4.58 1153.71 RPD MAD OHMM 5.54 1154.48 FET MAD HR 1.57 61.1 First Reading For Entire File .......... 9785.5 Last Reading For Entire File ........... 11129 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean 10457.3 701.104 61.8264 7.87023 9.14869 9.64843 10.2937 34.7369 Nsam 2688 2584 2596 2593 2593 2593 2593 2593 First Reading 9785.5 9837.5 9785.5 9798 9798 9798 9798 9798 Last Reading 11129 11129 11083 11094 11094 11094 11094 11094 Physical File Header Service name ............. STSLiB.O03 Service Sub Level Date of Generation ....... C2,'06,'20 Maximum Physlcal Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENI: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9631.5 9805.5 ROP 9670.0 9836.0 $ # LOG HEADER DATA DATE LOGGED: 18-FEB-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 1.22 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9836.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.2 MAXIMUM ANGLE: 77.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 017 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD'DENSITY (LB/G): 8.90 MUD VISCOSITY S): .0 MUD PH: 9.5 MUD CHLORIDES PPM): 66000 FLUID LOSS (C3 : 13.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT .MAX CIRCULATING TERMPERATURE: .000 137.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depzh units ........... Feez Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined ~senz value ...................... -999 Depth Unlts ....................... Datum Speclflcasion 51cck sub-zype...C Name Serv!ce Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD0![ FT/H 4 i 68 4 2 GR MWD0iC API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9631.5 9836 9733.75 410 ROP MWD010 FT/H 3.12 133.13 63.6452 333 GR MWD010 API 20.15 794.43 56.6934 349 First Reading For Entire File .......... 9631.5 Last Reading For Entire File ........... 9836 File Trailer Service name ............. STSLIB.003 .Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 9631.5 9670 9631.5 Last Reading 9836 9836 9805.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): START DEPTH STOP DEPTH 9660.5 11096.5 9660.5 11096.5 9660.5 11096.5 9660.5 11096.5 9660.5 11096.5 9806.0 11085.5 9836.5 11132.0 22-FEB-01 Insite 4.05.5 4.3 Memory 11132.0 BlT ROTATING SPEED .iRP.M : HOLE iNCLINATiON iDEG MiNi.MUM ANGLE: M_AXiMUM ANGLE: 98.6 76.6 TOOL STP. i:(G TC, FTC BOTTOM, VENDOF. TOC, L CODE TCEi TYPE TOOL NUMBER DGR DUAL SAM>~ RAY PBOi853RF3 EWR4 ELECTROMAG. REGIS. 4 PBOI853RF3 BOREHOLE ANT 2ASiNS DATA OPEN HOLE BIT SIZE (iN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): .0 MUD PH: 9.3 MUD CHLORIDES (PPM): 39300 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .060 MUD AT MAX CIRCULATING TERMPERATURE: .029 MUD FILTRATE AT MT: .047 MUD CAKE AT MT: .097 .NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 0 1 4 2 8 3 12 4, 16 5 20 6 24 7 28 8 70.0 153.0 70.0 70.0 Name Service Unit Min Max DEPT FT 9660.5 11132 ROP MWD02C FT/H 0.14 2808.11 GR MWD02C API 21.2 147.38 RPX MWD020 OHM~ 1 35.99 RPS MWD02C OHMM. 1.08 33.56 RPM MWD020 OH~ 1.1 56.56 RPD MWD02C OHMM 1.97 32.16 FET MWD020 HR 0.215167 75.83 Mean 10396.3 94.3653 62.7418 8.70179 8.92292 9.20904 9.66153 12.5026 First Reading For Entire File .......... 9660.5 Nsam 2944 2592 2560 2873 2873 2873 2873 2873 First Reading 9660.5 9836.5 9806 9660.5 9660.5 9660.5 9660.5 9660.5 Last Reading 11132 11132 11085.5 11096.5 11096.5 11096.5 11096.5 11096.5 Last Readlnq For Entire Fzle ........... 11132 File Tra~ler ServLce name ............. STSLiS.$C4 Servlce Sub Level Name... Version !~umber ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO .. Next File Kar, e ........... STSLIB.0O5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9788.5 11086.0 FET 9800.5 11097.0 RPD 9800.5 11097.0 RPM 9800.5 11097.0 RPS 9800.5 11097.0 RPX 9800.5 11097.0 RAT 9835.5 11132.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMF~ RAY EWR4 ELECTROMAG. REGIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (03 : 22-FEB-01 In$ite 4.05.5 4.3 Memory 11132.0 98.6 76.6 TOOL NUMBER PBO1853RF3 PBO1853RF3 3.750 FloPro 9.00 .0 9.3 39300 5.2 RESiSTIViTY ~OHb[M, AT TEMPERATURE MUD AT MEASURED TEM?ERATURE iMT MUi AT b'-~>i CiRSULATiNG TEPiMPERA. TUEE: MUi FILTRATE AT .?.:U_~ SAKE AT MT: NEUTRON TOOL Y~TRiX: MATRIX DENSITY: HOLE CORRECTION lIN): TOOL STANDOFF (IN): EWR FREQUENCY :HZ}: REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .O60 .029 .047 .097 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 RAT MAD021 FT/H 4 1 68 GR MAD021 API 4 1 68 RPX MAD021 OHMM 4 1 68 RPS MAD021 OHMM 4 1 68 'RPM MAD021 OHMM 4 i 68 RPD MAD021 OHMM 4 I 68 FET MAD021 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 Name Service Unit Min Max DEPT FT 9788.5 11132 RAT MAD021 FT/H 63.66 1087.65 GR MAD021 API 18.2 145.32 RPX MAD021 OHMM 2.62 260.69 RPS MAD021 OHMM 4 1153.25 RPM MAD021 OHMM 4.58 1153.71 RPD MAD021 OHM}4 5.54 1154.48 FET MAD021 HR 1.57 61.1 First Reading For Entire File .......... 9788.5 Last Reading For Entire File ........... 11132 File Traile~ Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Mean 10460.3 698.672 61.7086 7.90756 9.2033 9.70765 10.3173 34.5529 Nsam 2688 2594 2596 2594 2594 2594 2594 2594 First Reading 9788.5 9835.5 9788.5 9800.5 9800.5 9800.5 9800.5 9800.5 Last Reading 11132 11132 11086 11097 11097 11097 11097 11097 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/06/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Nex~ Tape Name ........... UNKNOWN Co~ments ................. STS LiS Wr±z±nc Library. Reel Trailer Service name ............. LiSTPE Date ..................... 02/06/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Numbe! ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writinc L~brary. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File