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Home My WebLink About200-123 Ima roject.Well History File Cover e 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. (~ L~_- J (~- Well History File Identifier REsC~.N DIGITAL DATA' OVERSIZED (Scannable) · Color items: · Diskettes, No.[ [] 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 BY: BEVERLY ROBI~SHERYL MARIA WINDY Project Proofing BY: BEVERLY ROBIN(~~HERYL MARIA WINDY Scanning Preparation / x 30 = ~ BY: BEVERLY ROBIN/)d'rNCENT.,]SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ¢'~ / -- PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~ YES , Stage 2 IF NO IN STAGE 1, PAGElS) OlSCREPA~ FOUND: ~ ~. YES _ DUE TO QUALITY, GRA¥$CALE OR COLOR IMAGES) NO NO ReScanned (ind~viduat p,~cje /,~pec~'a~ at~e~'~o/~J .~ca¢~nin~ complezec~½ RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10102Rev3NOTScanned.wpd ozi2~ios ~~I~'II~I~~N'~~1~ NO. 5324 ~ C s'~~ R~laska~ Data & Consul4ing Services -~ ~,x~; ~'~„~ ~, ~~ ~~'-~ Com an State of Alaska ,~~.~y~~, w~~^ P Y~ ?525 Gambell SYree4, Suite aoo Alaska Oii & Gas Ccros Comm ~lnchorage, AIL 99503-2838 Attn: Christine Mahnken ~~R~: ~eth 333 West 7th Ave, Suite 100 Anchorage, APC 99501 ~I/eli Job # Log Description Date BL Color CD _~ E-36A B1JJ-00018 MCNL ~ - J 05/18/09 1 ~~_ L2-28 BOCV-00018 RST ~` O6/19l09 1 1 _~ 12-Oi AYTU-00039 RST / G 06/02/09 1 1 ~,__ R-27 AYQQ-00034 RST (o - O6/17/09 1 1 F-45B B2NJ-00007 MCNL .- O6/08/09 1 1 __ 02-33A AYTU-00033 CH EDIT PDC USIT - 05h9/09 1 1 ~_ 18-298 AXBD-00023 CH EDIT PDC JEWELRY LOG c, s 05/06/09 1 .~~ G-16A B2NJ-00010 MCNL O6/18/09 1 1 _~ L3-05 AYTU-00042 RST O6/07/09 1 1 ~~, Z-01~ AXBD-00003 MCNL 11/26/09 1 1 _.__.~.~ ~'04 B6RIK-00001 RST 07/07/09 1 1 ~1A CACC AP`IlPIl1\P/1 G11/±L ~G f~LIf1T tfv [~ . _ . _ --_ '"'_ _'___"" " ~ " ~'~......~. ....~ ..~. v~ ~~~~~~~w v~~~ vvr ~ LI1V~ 1 V. BP Exploration (Alaska) Inc. Alaska Data & Consulting'Services Petrotechnical Data Center I_R2-1 2525 Gambell Street, Suite 400 900 C. Benson Blvd. Anchorage, AK 99503-2838 • • • STATE OF ALASKA ~ ~_~~~ J u N ~ 8 20096 /°~-a9' ALASKA OIL AND GAS CONSERVATION COMMISSIONqq~~ ~ Oi! ~ Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AND LO~~ A,nC"~orage 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 1 b. Well Class: zoAAC zs.~os zoAAC zs.»o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/22/2009 200-123 309-128 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 09/06/2000 50-029-22214-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 09/12/2000 PBU 02-33A FNL, 861 FWL, SEC. 36, T11N, R14E, UM 626 Top of Productive Horizon: 8. KB (ft above MSL): 66' 15. Field /Pool(s): 230' FSL, 203' FWL, SEC. 25, T11 N, R14E, UM Ground (ft MSL): 30.1' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Oil Pool 987' FSL, 1017' FWL, SEC. 25, T11N, R14E, UM 3194' 3194' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687604 y- 5950575 Zone- ASP4 10872' 8946' ADL 028308 TPI: x- 686924 y_ 5951414 Zone- ASP4 (MD+TVD) 11. SSSV DeN h 17. Land Use Permit: Total Depth: x- 687718 - 5952191 Zone- ASP4 A y 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' S bmit electrons an rint inf rma i n er 20 AAC 25.05 N/A ft MSL (Approx.) 1900 21. Logs Obtained (list all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR, MEM GR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD $ETfING DEPTH TVD HOB AMOUNT WT'. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surfa 110' 0" 11 ds Arcticset -5/ " J-55 7 ' 77' 2-1 /4" ~ szo cu n cs lll, 3as a ft'G', ss cu ft cs 11 7" 26# L-8 8615' rf ce 8453' 8-1l2" 792 cu ft Cla s'G' 5" 15# 13Cr80 31 9115' 8184' 887' 6" 138 cu ft Clas ' 2-3/8" 4. L- 0 14 ' 10 8 7' 945' 11 R 23. Open to production or inject ion? ^ Yes ®No 24, TusING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 3-1/2", 9.2#, 13Cr80 3835' - 8327 8212' MD TVD MD TVD ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ ~, . ~, ,x `,p~y,~~ ~' ~ ~- ~' ~~ DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 8234' P&A w/ 10.4 Bbls Cement 3499' Set EZSV 3194' Set Whipstock (on 7" Casing Stub) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24HOUR RATE• 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ® No Sidewal l Core s A wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. 'L~TIQ~1 =- None ~: ~ .lJN ~ ~ 2009 ~,~ ': ~~e~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE /~~ ~~t//'~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 9175' 8930' None Zone 1A / TDF 9230' 8959' Base Sadlerochit 10021' 8978' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore ing is true a d correct to the best of my knowledge. ~ / ~ ~/ ~O 1 Title Drilling Technologist Date Signed Terrie Hubble PBU 02-33A 200-123 309-128 Prepaid ey n/ame/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. orining Engineer: Mark Staudinger, 564-5733 INSTRUCTIONS GeNew-I.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • • 02-33A, Weil History (Pre Rig Sidetrack) Date Summary 4/4/2009 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void, 10+ psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "ET style" all were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 min test, 3400/ 15 minutes, 3400/ 30 minutes. Bled void to 0 psi. Cycle and torqued LDS "ET style" (1) LDS was not cycled, SSO in way only backed LDS out 1:00 position, all others were in good working condition. 4/6/2009 T/I/O=SSV/400NAC. Temp= SI. OA FL (for FB). IA FL C~ surface. OA FL near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 4/8/2009 T/I/O = 1570/400/0+. Temp = SI. T FL (pre FB load) & cellar gravel sample. Integral installed on IA.. T FL C~ 5130' (45 bbl). Cellar thawing obtained cellar gravel sample. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 4/9/2009 T/I/0=1590/480/30. Temp-SI. Remove gravel from OA valve to install integral. Gravel & ice from cellar has thawed. Shoveled out adequate space for integral to be installed. Super Sucker was not needed. Kevin Parks was notified cellar was ready for integral. Heater was left installed for Full Bore. SV = Closed. WV, MV, SSV =Open. IA & OA = OTG. NOVP. 4/9/2009 T/I/0=1600/420/150. (MIT OA to 2000 psi.). Start pumping crude down OA. OA pressured up to 1600 psi. Pressure started to fall. Establish LLRTw/ 10 bbls crude. LLRT=.9 bpm @ 1050 psi. Monitor OA pressure. Pressure bled down 300 psi in 22 minutes. Bleed OA pressure down to 120 psi. FWHP = 1600/400/120. 4/25/2009 MIRU. Perform weekly BOPE test. Load well with 160 bbls 1%KCL. RIH with 1.75" BDN assy. Tagged bottom at 10796' ctmd. Hard bottom, clean PU. PUH to above liner top. 4/26/2009 PUH to above liner top. Park nozzle at 8100' ctmd. Load well with 50 bbls of diesel down backside to attain positive WHP. Pump 1%KCL down coil to establish injection rates and pressures and cool down liner. Pump 8 bbls of fresh water followed by 10.4 bbls of 15.8 ppg Unislurry cement. Bullhead cement into liner. Achieve 3500 psig WHP displacing TOC to ~ 8630'. POOH filling coil voidage while maintaining 2500 psig WHP. At 2000', drop WHP to 500 psig and circulate remaining water out of coil with diesel. FP wellbore. Continue POOH. Trap 500 psig WHP. RD CTU. Job Complete. 4/27/2009 WELL SHUT IN PRIOR TO ARRIVAL. DRIFTED WITH 2.5" CENTRALIZER. TAGGED LNR TOP C~ 8110' SLM. DRIFTED TO 8234' SLM W/1.75" SAMPLE BAILER -SAMPLE OF CEMENT RECOVERED. PRESSURE TEST TBG TO 1,000#. PASS. TURN WELL OVER TO DSO -LEFT WELL SHUT IN. 4/28/2009 WELL SHUT IN PRIOR TO ARRIVAL. (E-LINE TUBING PUNCH AND JET CUT). INITIAL T/IA/OA: 700/250/250. RIG UP E-LINE, DSO PUMPED UP SSSV. 4/29/2009 T/I/0=320/200/80 Temp=S/I Circ-out F-Protect (Prep for CT Perf Straddle) Flow path Pumping down TBG taking returns up IA to neighboring well. Spear in to TBG w/5 bbls of amb. meth followed by 275 bbls 100° 2% kcl followed by 285 bbls of 50° Sea H2o followed by 80 bbls of 110° diesel. U-tube for TxIA F, protect F, protect 02-15 w/5 bbls of meth spear followed by 106 bbls of 100° crude. Shut IGV and psi up to 1500 psi w/6 bbls of diesel. Final Whp's = 5/vac/vac, Wing shut, swab shut, master open, casing valves open to gauges. 4/29/2009 RIH WITH 1.6875", 27' TUBING PUNCHER TOOL STRING. ,FIRED TUBING PUNCHER FROM 8070' - 8073'. RIH WITH 2.5" SLB POWER CUTTER TOOL STRING. CUT 3.5" TBG AT 3835'. SURFACE AND VISUAL INDICATION OF EXPLOSIVES FIRING. MASTER LEFT OPEN, SSV OPEN, SSSV OPEN, SWAB CLOSED, TREE CAP INSTALLED AND PT. NOTIFIED DSO. JOB COMPLETE. FINAL TBG/IA/OA: 0/0/0 PSI. Page 1 of 2 ` ~ • 02-33A, Well History (Pre Rig Sidetrack) Date Summary 4/30/2009 T/I/0= 0/0/0, temp= S/I. CMIT TxIA ""*PASS"" to 2250 psi. Pressured TxIA to 2250 psi with 3.6 bbls diesel. Initial test pressures= 2260/2240. CMIT TxIA lost 0/0 psi in 1st 15 minutes and 20/20 psi in 2nd 15 minutes, and 0/0 psi in 3rd 15 minutes for a total loss of 20/20 psi in 45 minute test. Bled TBG and IA pressure down to 0/0 psi. FWHP=O/0/0 Swab, Wing, SSV =Closed. Master, IA, OA =Closed. 5/1/2009 T/I/O = 0/0/0 Set 3' ias bpv used 1-2' ext and tag at 84' for pre rig no problems. 5/2/2009 T/I/0=0/0/0 Pulled 3" FMC ISA BPV. Well work not complete. 1-2' ext used, Tagged C~3 72", Plug #508. 5/3/2009 WELL S/I ON ARRIVAL. RAN FLAPPER CHECKER (GOOD FUNCTION TEST). SET 3-1/2" NO-GO HOLD OPEN SLV IN TRSSV AT 2173' SLM. LEFT WELL SI, NOTIFY DSO OF WELL STATUS. 5/4/2009 T/I/O = 250/0/0. Temp = SI. Bleed TP to 0 psi (pre Rig). No AL line. No F/L. T FL C~ surface. Bled TP from 250 psi to 0 psi in 15 min into BT (15 gal). Monitored pressures for 30 min. TP unchanged. Final WHPs = 0/0/0. WV, SV =closed. MV =open. IA, OA = OTG. 5/5/2009 T/I/0= 8/0+/VAC. Temp=Sl. WHPs (post bleed). Flowline & AL line removed from wellhead. TP increased 8 psi, OA went to vac overnight. SV, WV =closed. SSV, MV =open. IA, OA =open to gauge. NOVP. 5/7/2009 T/I/0=0/0/0 Set 3" FMC ISA BPV #508, 1-2' Ext Used, Tag C~ 74"; Pre Rig Nabors 9ES. Page 2 of 2 ' • • BP EXPLORATION Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To Hours ~, Task Code NPT __ _ 5/16/2009 17:00 - 00:00 7.00 I MOB P 5/17/2009 00:00 - 05:30 05:30 - 13:00 13:00 - 16:00 16:00 - 19:30 19:30 - 20:30 20:30 - 00:00 5/18/2009 00:00 - 01:00 01:00 - 03:00 03:00 - 07:00 07:00 - 14:30 14:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 00:00 5.50 MOB P 7.50 RIGU P 3.00 WHSUR P 3.50 WHSUR P 1.00 WHSUR P 3.50 WHSUR P 1.00 WHSUR P 2.00 WHSUR P 4.00 BOPSU P 7.50 BOPSU P 2.501 BOPSUFIP 1.00 BOPSU N SFAL 1.00 PULL P 1.00 PULL P 4.00 PULL P 5/19/2009 100:00 - 02:00 I 2.001 PULL I P Start: 5/17/2009 Rig Release: Rig Number: 9ES Page 1 ~"I Spud Date: 10/6/1991 End: Phase Description of Operations PRE PJSM. Take pits and shops from 14-23A to 02-336. LD derrick and jockey 9ES off of well. Leave DS14 ~ 23:30hrs; proceed west down Spine. PRE PJSM. Rig sub en route to DS02-33B from DS14-23A; turn on Oxbow, Oxbow to West Dock. Right on West Dock to DS02 access road. PRE Spot rig sub over 02-33B; lay down mats and herculite. Spot and level pits, MU interconnect. inspect and raise derrick. Take on seawater ~ 10:30hrs. DECOMP Rig Accept C~ 13:OOhrs. Handle bridle lines and RU pipe shed chute. DECOMP Pressure test: RU second kill line to OA, pressure test lines to 3500psi; good. Pressure up to test OA; pressure broke over at 1700psi and bled down to 1050psi; pump 1 bpm for 30min. Finai pressure 920psi; bleed off to open top tank DECOMP RU and test DSM lubricator to 1000psi; good. Pull BPV, LD lubricator. DECOMP RU to circulate out freeze protect. DECOMP PJSM. Reverse circulate 33bbls of diesel from tubing, taking returns to the open top tank. Circulate 50bbls of diesel from annulus, and circulate clean, chasing warm seawater with Safe-O-Surf. Install BPV and test from below via the IA to 1500psi; good. DECOMP ND tree and adapter flange. Functioned LDS, bleed off control lines. 9" ACME threads: 4.5 turns to MU. 4" ACME threads: 8.5 turns to MU. -Install Blanking Plug DECOMP NU BOPs; RU to test. AOGCC rep Chuck Shieve waived witness of BOP test ~ 02:28hrs. DECOMP Test BOP equipment to 250psi low, 3500psi high for 5min each; chart all tests. Test witnessed by WSL Blair Neufeld and Nabors TP Bruce Simonson. Test using 4" and 3.5" test joints; good test. Remove blanking plug and blow down surface equipment. DECOMP Prep cellar and wellhead. RU DSM lubricator to pull TWC. Test lubricator to 1000psi; good. Make 3 attempts to pull BPV; unsuccessful. RD lubricator and drain stack; plug discovered laying sideways in stack. DECOMP PJSM. Fish BPV out of stack utilizing t-bar and sash cord noose. DECOMP RU FMC tools to pull tubing hanger. MU 9" ACME crossover to drillpipe and MU assy to tubing hanger. PU and un-seat hanger at 70k up. Pull hanger to floor. DECOMP Circulate 230psi @ 5bpm; small amount of gas breaking out at surface. Shut in and monitor for 10min; static. DECOMP PJSM w/ SLB hand. RU to spool control line; RU power tongs to LD 3.5" 9.2# 13Cr FOX tubing. Pull tubing from cut C~3 3800' MD to 1601'. DECOMP PJSM. Finish pulling 3.5" 13Cr FOX tubing from cut at 3500' to rig floor. Change out elevators, clean and clear floor of third party equipment. Pulled 85 joints, 1 cut joint (24.92'), 1 SSSV, 3 pup joints and 1 GLM. All 52 control bands retrieved. Tubing in fairly good condition with no noticeable corrosion or pitting. Printed: 5/26/2009 2:31:15 PM ' . • BP EXPLORATION Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To Hours Task Code NPT Page 2 ofd Spud Date: 10/6/1991 Start: 5/17/2009 End: Rig Release: Rig Number: 9ES Phase Description of Operations 5/19/2009 02:00 - 04:00 2.00 BOPSU P DECOMP PU 4" test joint to test lower VBRs (2-7/8" x 5"). Test to 250psi 04:00 - 05:30 I 1.501 CLEAN I P 05:30 - 09:00 I 3.501 CLEAN I P 09:00 - 10:00 I 1.001 CLEAN I P 10:00 - 11:00 I 1.001 CLEAN I P 11:00 - 12:00 1.00 CLEAN P 12:00 - 13:30 1.50 EVAL P 13:30 - 17:00 3.50 EVAL P 17:00 - 20:00 I 3.001 DHB I N 20:00 - 21:30 I 1.501 DHB I N 21:30 - 00:00 I 2.501 DHB I N 5/20/2009 100:00 - 01:00 I 1.001 DHB I N 01:00 - 02:00 1.00 DHB N 02:00 - 03:30 1.50 DHB N 03:30 - 05:00 1.50 DHB P 05:00 - 06:00 1.00 DHB P 06:00 - 06:30 I 0.50 I STCTPL I P 06:30 - 08:00 I 1.50 I STCTPL I P low, 3500psi high; good. Test witnessed by WSL Amanda Rebol and Nabors Tool Pusher Roy Hunt. RD testing equipment. DECOMP PU Baker 7" casing cleanout assembly: Used 6 1/8" Hughes Christensen bit, 7" casing scraper, two 4 3/4" boot baskets, bit sub and 4 3/4" lubricated bumper sub. DECOMP RIH with 7" casing cleanout BHA #1 with 4" DP singles from 25' MD and tagged 3.5" tubing stump at 3831' MD. PUW 95k, SOW 95k. DECOMP POH from 3831' MD to 3640' MD. Circulate one bottoms up at 7 bpm with 545 psi. - MW in 8.5 ppg / MW out 8.5 ppg DECOMP POH with 7" casing clean out assembly from 3640' MD to 25' MD. - MW in 8.5 ppg / MW out 8.5 ppg DECOMP LD 7" casing clean out assembly. Both 4 3/4" boot baskets were empty. DECOMP RU E-line. Stage truck unit, RU sheaves and air line wiper. PJSM on E-line operations. DECOMP RIH with E-line for USIT /CCL logging from 3820' MD to surface. USIT indicated possible cement up to 3300' MD. POOH and LD USIT /CCL. DFAL DECOMP RIH with Halliburton EZSV bridge plug on E-line to 3500' MD. Unable to set EZSV. Repeated firing sequence three times without success. Decision made to POH and inspect tools. DFAL D ECOMP POH and LD CCL and Firing Head. Found shorted Thru Rod in CCL which prevented the firing signal to get to the Firing Head. Replaced CCL and Ignitor. Trouble shoot all equipment. DFAL DECOMP RIH with Halliburton EZSV bridge plug on E-line to 3500' MD. Unable to set EZSV. Repeated firing sequence three times without success. Contacted Schlumberger E-line supervisor, decision made to POH and inspect tools. DFAL D ECOMP POH and LD CCL and Firing Head. Inspect equipment - no issues found. Rebuilt firing head and re-wired entire system. Inspect E-line cable, cut approximately 100 ft of 7-46 E-line cable. Trouble shoot all equipment. DFAL D ECOMP RIH with Halliburton EZSV bridge plug on E-line to 3500' MD. Unable to set EZSV. Mobilize tools for setting EZSV with 4" DP. DFAL D ECOMP POH and LD CCL and Firing Head. Inspect tools. Change Ignitor (same style but different batch). D ECOMP RIH with Halliburton 7" EZSV bridge plug and set at 3499' MD (top element), 29' above casing collar at 3528' MD and 14' below casing collar at 3485' MD. Positive indication at surface of set. Tension in E-line lost 290 lbs. PU and SO on EZSV 100 Ibs to confirm set. POH and verified tension sleeve in EZSV setting tool sheared. D ECOMP Pressure test EZSV plug to 3500 psi for 10 minutes -good test. Rig down testing equipment. Rig down E-line unit. D ECOMP Make up 5 1/2" multi string cutter assembly: 5 1/2" Multi String cutter, 4 11/16" pump out sub, XO sub. D ECOMP RIH with 5 1/2" multi string cutter to 3144' MD. Printed: 5/26/2009 2:31:15 PM • • BP EXPLORATION Page 3 ~! Operations Summary Report Legal Well Name: 02-33 Common W ell Name: 02-33 Spud Date: 10/6/1991 Event Nam e: REENTE R+COM PLET E Start : 5/17/2009 End: Contractor Name: NABOR S ALAS KA DRI LLING I Rig Release: Rig Name: NABOR S 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase i Description of Operations 5/20/2009 08:00 - 08:30 0.50 STCTPL P DECOMP Service Top Drive, Drawworks, Crown and Blocks. 08:30 - 09:00 0.50 STCTPL P DECOMP RIH from 3144' MD to 3218' MD (casing collar found at 3218' MD). Pick up to 3216' MD to avoid cutting collar at 3218' MD. PUW 85k, SOW 85k. 09:00 - 09:30 0.50 STCTPL P DECOMP Displace well from seawater to 9.2 ppg brine at 6 bpm with 1190 psi. 09:30 - 10:30 1.00 STCTPL P DECOMP Pump at 5 bpm with 575 psi while rotating at 95 rpm with 0.5k - 1.5k ft-Ibs torque to open knives and make cut. Positive indication that 7" casing was cut with a pressure drop of 350 psi and immediate fluid returns from OA (7" x 9 5/8" annulus). Spot 32 bbls of hot 9.2 ppg brine (130 deg F) with Safe-Surf-O at the cut point and close annular preventer. Circulate until returns from the OA clean up at 6 bpm with 450 psi. Approximately 80 bbls of diesel circulated out of OA. 10:30 - 13:00 2.50 STCTPL P DECOMP POH from 3216' to surface. LD multi string casing cutter. 13:00 - 13:30 0.50 STCTPL P DECOMP Remove wear bushing, pull wear ring and install test plug. 13:30 - 14:30 1.00 STCTPL P DECOMP Change out upper set of rams from 3.5" x 6" to 7". 14:30 - 15:00 0.50 STCTPL P DECOMP Test upper rams to 3500 psi High / 250 psi Low for 5 minutes and chart -good test. Test witnessed by BP WSL Blair Neufeld. 15:00 - 16:00 1.00 STCTPL P DECOMP MU spear assembly with: 4 1/4" Bull Nose, 6 1/16" Spear Pack Off, 5 11/16" Itco Spear, 5 3/4" Spear Extension, 8 1/8" Stop Sub, XO subs. Stab into 7" mandrel hanger, back out lock down screws. Pull the 7" casing hanger free with 118k lbs. 16:00 - 17:30 1.50 STCTPL P DECOMP Rig up 7" casing handling equipment. Change out rotary tongs to Off Driller's Side. Break out spear and LD. LD 7" mandrel hanger and pack oft. 17:30 - 18:00 0.50 STCTPL P DECOMP Circulated one bottoms up of 9.2 ppg brine at 6 bpm with 110 psi. Mointor well for 10 minutes -static. RU to pull 7" casing while circulating. 18:00 - 00:00 6.00 STCTPL P DECOMP Pull 7" 26# L-80 LTC casing from 3216' MD. PUW 115k, SOW ', 105k. Break out all joints with 18k - 22k ft-Ibs torque. Recovered 73 joints of 7" casing and one cut joint of 42.90'. Bow Spring centralizers with stop ring on every third joint. Casing in good condition. 5/21/2009 00:00 - 01:00 1.00 STCTPL P DECOMP RD 7" casing handling equipment. 01:00 - 02:00 1.00 BOPSU P DECOMP Change out upper set of rams from 7" to 3.5" x 6". 02:00 - 03:00 1.00 BOPSU P DECOMP RU testing equipment and test upper rams to 3500 psi High / 250 psi Low for 5 minutes and chart -good test. Test witnessed by BP WSL Eli Vazquez and Nabors Tour Pusher Roy Hunt. 03:00 - 03:30 0.50 BOPSU P DECOMP RD testing equipment. Install 9.125" wear ring. 03:30 - 06:00 2.50 CLEAN P DECOMP PU Baker 9 5/8" casing cleanout assembly: 5" Bull Nose, XO, 9 5/8" Casing Scraper, two 7" Boot Baskets, Bit Sub, 8 3/4" Upper Mill, 6 1/4" Lubricated Bumper Sub, 6 1/4" Oil Jar, nine 6 1/4" DC, XO. 06:00 - 08:00 2.00 CLEAN P DECOMP RIH with Baker 9 5/8" Casing cleanout BHA #4 with 4" DP singles from 328' MD to 3194' MD. PUW 105k, SOW 105k. Tag 7" casing stump at 3216' MD. 08:00 - 08:30 0.50 CLEAN P DECOMP Circulate one sufarce to surface at 247 gpm with 250 psi. Shakers look clean. - MW in 9.2 ppg brine / MW out 9.2 ppg brine. 08:30 - 09:30 1.00 CLEAN P DECOMP Cut 91' of drilling line. 09:30 - 11:00 1.50 CLEAN P DECOMP POH from 3216' MD to 328' MD standing back 4" DP in stands Printed: 5/26/2009 2:31:15 PM • BP EXPLORATION Page 4 ~ Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 9ES Rig Number: 9ES Date I From - To Hours Task Code NPT Phase Description of Operations 5/21/2009 09:30 - 11:00 1.50 CLEAN P DECOMP (30 stands stood back). - MW in 9.2 ppg brine / MW out 9.2 ppg brine. 11:00 - 14:00 3.00 CLEAN P DECOMP RIH with Baker 9 5/8" Casing Cleanout BHA #4 with 4" DP singles from 328' MD to 3194' MD. PUW 105k, SOW 105k. Tag 7" casing stump at 3216' MD. 14:00 - 15:00 1.00 CLEAN P DECOMP Displace well from 9.2 ppg brine to 9.2 ppg LSND Milling Fluid. First bottoms up brought back black scale and asphaltenes (Schmoo). Circulated until returns cleaned up for a total of two bottoms up circulated. 15:00 - 16;00 1.00 CLEAN P DECOMP POH from 3216' MD to 328' MD standing back 4" DP in stands (30 stands stood back). - MW in 9.2 ppg LSND / MW out 9.2 ppg LSND. 16:00 - 18:00 2.00 CLEAN P DECOMP LD Baker 9 5/8" Casing Cleanout BHA #4. All components in gauge and both boot baskets were empty. 18:00 - 18:30 0.50 CLEAN P DECOMP MU RTTS BHA #5 with: 9 5/8" RTTS, 8 5/8" - 20" Circulation Valve, 4 1/2" x 3 1/2" IF XO, HT 40 x 3 1/2" IF drill pipe pup. 18:30 - 21:00 2.50 CLEAN P DECOMP RIH with RTTS BHA #5 from 20' to 593' MD with 4" DP singles (18 4" DP singles picked up). Continue to RIH from 593' MD to 3173' MD with 4" DP stands. 21:00 - 22:00 .1.00 CLEAN P DECOMP Set RTTS Packing Element at 3205' MD (middle of planned whisptock ramp depth). PUW 88k, SOW 85k. Pressure test 9 5/8" casing from above the RTTS to 2200 psi for 30 minutes - good test, lost 0 psi during entire test. Release RTTS, blow down kill line. 22:00 - 00:00 2.00 CLEAN P DECOMP POOH from 3205' MD to surface and LD RTTS BHA #5. - MW in 9.2 ppg LSND / MW out 9.2 ppg LSND 5/22/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Finished LD RTTS BHA. Clean and clear rig floor. 01:00 - 03:00 2.00 STWHIP P WEXIT Make up 9 5/8" whipstock BHA #6 with 8 5/16" Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock, 8 1/2" window mill, 8 5/8" lower string mill, 4 7/8" flex joint, 8 3/4" upper watermellon mill, float sub, UBHO sub, 1 jt 5" HWDP, bumper sub, nine 6 1/4" DC, XO. Orient Whipstock Slide to UBHO Sub. 03:00 - 05:00 2.00 STWHIP P WEXIT RIH with whipstock BHA on 4" DP from 369' MD to 3203' MD. 05:00 - 06:00 1.00 STWHIP P WEXIT Fill pipe and circulate to clean 4" DP and BHA from any debris in preparation for Gyro Run. RU Gyro Data Sheaves and take and record slow pump rates while circulating at 213 gpm with 288 psi. 06:00 - 07:30 1.50 STWHIP P WEXIT Run Gyro to UBHO Sub at 3153' MD. Orient Baker Gen II 9 5/8" whipstock 330 degrees azmith. POH with Gyro. 07:30 - 08:30 1.00 STWHIP P WEXIT Tag 7" casing stump at 3216' MD and SO 20k to set bottom trip anchor. Pick up to confirm anchor set and saw no overpull. SO and moved down freely. Rotated and saw no increase in torque. Picked up and confirmed mills had sheared from whipstock assembly at same time as anchor had set with 20k. PUW 105k, SOW 150k. 08:30 - 13:00 4.50 STWHIP P WEXIT Mill 8 3/4" window in 9 5/8" casing with t e following ,~.L ~~Q J parameters: 345 gpm and 470 psi, weight on mills 1 k - 8k Ibs, torque on bottom 2k - 5k ft-Ibs at 70 - 100 rpm. PUW 107k, SOW 105k, ROT 105k. Pump 20 bbl Hi Vis Super Sweep at middle of window - no considerable increase of cuttings with return of Hi Vis Super Sweep. - Top of window at 3194' MD Printed: 5/26/2009 2:31:15 PM TREE = 4 1 /16" CM/ WEtrLHEAD = FMC Gen 5 ACTUATOR = KB. ELEV_- 58.6 BF. ELEV - 28.5 KOP = 3194 Max Angle = 98.30-12397 Datum MD = 12820 DatumTVD= 8809.1 IKOP-Top of Whipstock I~ 3194' t 9-5/8" CSG, 36#, J-55, ID = 8.921" 3478' 7° ¢sv 3499' JET CUT 3835' TOP OF 2-3/8" LNR 2.70' DEPLOY SLV, ID = 1.969" 8 43' (LOGGED 09/10/00) 7" X 3-1/2" OTIS BWD PERM PKR, ID = 4.00" 8212' SEAL BORE IXTENSION, ID = 4.00" 8216' 5-1/2" MILLOUT EXTENSION, ID = 4.67" 8232' 5-1/2" X 3-1/2" XO, ID = 2.992" 8238' 3-1/2" PARKER SWN NIP, ID=2.75" 8313' 7" x 5" TNV LNR HGR, ID=? 8313' 3-1/2" TBG, 9.2#, 13CR-80, .0087 bpf, ID = 2.992" 8327' 7" CSG, 26#, L-80, ID = 6.276" ~-~ 8615' PERFORATION SUMMARY REF LOG: BRCS ON 10/19/91 ANGLE AT TOP PERF: 64° @ 9220' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8 6 10730-10970 Open 06/08/09 2 7/8 6 11040-11570 Open 06/08/09 2 7/8 6 11620-11840 Open 06/08/09 2 7/8 6 12500-12540 Open 06/08/09 2 7/8 6 12580-12720 Open 06/08/09 ~ 5" LNR, 15#, 13CR-80, .0189 bpf, ID = 4.408" ~ NOTES: ***CHROMETBG*** 2201' - 4-1/2" HES X-NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 6681 3725 5922 3716 46 14 Cameo Cameo Shear Dunxny RKP 2C 0 0 06/08/09 06/08/09 Minimum ID = 3.725" @ 9652.7 HES XN-NIPPLE 4'V2' I-~~NP X3813' I B~S3 FFtDI#~ 9516 9546 41/2' F~~NP X3813' 9~ 41/2' f$~NP ~37Z5' 41/Z' ~ 126#,13Q-80; 9663 X28 BI~TCPR~ 9654 T' ~ ~#, L~q 6TC~MxT~ ~-~ 9621.a'~ 4'UZ' ~ 12E~; L~q BT-M 12$'IS MILLOUT WINDOW (02-33A) 9115' - 9122' I PBTD I I TD I 2-3/8" LNR, 4.6#, FL4S, L-80, .0039 bpf, ID = 1.995" ~-{ 10853' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 06/08/09 MS/AR Sidetrack 09/17/00 N CDR1 SIDETRACK (02-33A) 11/10/06 JPK/TLH GLV C/O CORRECTION (10/6/00) 07/18/08 ?/JMD GLV C/O CORRECTION (10/6/00) 07/25/08 PJC DRAWING CORRECTIONS 04/07/09 MIS Proposed ST PRUDHOE BAY UNIT WELL: 02-33A PERMff No: 2001230 API No: 50-029-22214-01 SEC 36, T11 N, R14E, 626' FNL & 861' FEL BP Exploration (Alaska) 02-3~B Final • • -~ ~ ~'~ 9 E ~ ~ ~ ~`t ~ 1.~ ~ t~ ~,, r-~ 4 + ~ ! ~ , j , -.r ~ SARAH PALIN, GOVERNOR 7~T~+ ~p~S~ 0~ ~ ~ ('r 333 W. 7th AVENUE, SUITE 100 Cois-7~i~QAii01s CQ~'IISSIQi` ~/ ANCHOR4GE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader ~.1~~~' BP Exploration Alaska Inc. ~ . '~~x `~ ~~r ~ ~~~ ~~ "`~ ~ PO Box 196612 ""~~~~~~ ~ ~ ~ Anchorage AK 99519-6612 ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-33A Sundry Number: 309-128 Dear Mr. Tirpack: 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. When providing notice for a representative of the Corrunission 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 Corrunission 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. Sincerely, Cathy . Forster Commissioner DATED this .~ day of April, 2009 Encl. ~~~` \~~ ~~' ~ ~ \ ~~ ~~ ~~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMA~ION /~~ .. APPLICATION FOR SUNDRY APPR~~VAL ` ° ~ i~ 20 AAC 25.280 ~8 ~~ & " 1. Type of Request ®Abandon • ^ Suspend ^ Operation Shutdown ^ Perforate ^ T~1'e~xteTon ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-123 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22214-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 02-33A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028308 - 66' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10872' • 8946' ~ 10833' 8944' None None in iz M TVD II r ral n r 11 2 11 11 14 47 rf 3478' - / " 7 ' 3477' 3 20 2 20 Int rme i 8 15' 7" 8615' 84 3' 724 10 P n Lin r 8 2' 8313'- 11 8184'-8 7' 2 0 72 0 Liner 2711' -3/ " 14 ' - 10 54' 27' - 894 ' 112 117 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9220' - 10770' 8955' - 8948' 3-1/2", 9.2# 13Cr80 8327 Packers and SSSV Type: 7" x 3-1/2" Otis'BWD' perm packer Packers and SSSV MD (ft): 8212' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 17, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Staudinger, 564-5733 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Phone 564-4166 Date ~ ~ ~ Terrie Hubble, 564-4628 Signature ,ten Commission Use Onl Sundry Number: - Conditions of approval: Notify Commission so that a representative may witness ntegrity Test ^ Location Clearance ^ Plug Integrity BOP Test ^ Mechanical I i - Other: ~ :i~,~Q r`~-`-~ 'lZ~.t'~ `~~~, ~ ~ u V ~~ 'V~~ 6~t ~v ~y~-~ G.'n'1111 ~'~" ~`~~ Subsequent Form Required: ~'O~ APPROVED BY n _ ~ , /~~ `f' V A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06006 E ~ ~ Submit In Duplicate Y, - , ~ x, ? ~ y~~ y • by cr y, 02-33A u Well Type: Producer Current Status: This well is completed with 3-1/2" 13Cr-80 tubing with a 2-3/8" L-80 liner and is currently shut-in. Tubing: A caliper log from 8/26/07 shows the 3-1/2" and 2-3/8" liner in good condition (max penetration of 22%). An SCMT log found cement at the top of the 2-3/8" liner and the TOC @ 8190'. MIT-IA Passed to 3000 psi 03/31/09 MIT-OA Failed to with a LLR of 11,2 gpm C«~ 1700 psi 08/04/00 Request: Approval is requested for the P&A of Prudhoe Bay well 02-33A. 02-33A is a Zone 1 A coiled- tubing sidetrack completed in October 2000. In June 2001 production began to drop and eventually ceased in July 2004 despite monthly hot-oil treatments. The well still failed after an extended reperf job in July 2008, leaving 02-33A with no remaining value. The development team decided to used this wellbore as a rotary sidetrack to target another area. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Scope of Work: The sidetrack plan for the 02-33B well (a Zone 1 producer) includes de-completing current 3-1/2" tubing and a 7" cut and pull. A sidetrack departure will be from a window in the 9-5/8" surface casing shoe. The 8-3/4" hole will be drilled to the Top of the Sag River where a 7" intermediate casing string will be run to surface and cemented up to 750' below the 9-5/8" casing shoe. The production hole will be drilled to a final TD of 12,744' MD where a solid liner will be run and fully cemented to TD. A 4-1/2" completion will then be run to complete the well. The 02-33B sidetrack is currently scheduled for Nabors 9ES beginning January 2009. The pre-rig work for this sidetrack will begin as soon as possible. MASP: 2333 psi Estimated Start Date: May 1St, 2009 Pre-rig prep work: • O 1 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. F 2 Fluid ack the tubin and inner annulus w/seawater/diesel. C 3 1. P & A the perforations in the 02-33A wellbore with cement from 10,833' MD to --9,000'. a. CEMENT CALCULATIONS i. 1833' of 2-3/8", 4.6# liner: .003866 bbls/ft = 7.1 bbls TOTAL = 7.1 bbls WOC and test cement lu to 2,250 si for 10 minutes. S 4 RU, drift for Tubin Punch and Jet Cutter. Ta to of 2-3/8" liner. E 5 Punch holes in the 3-1/2" tubin in the middle of a full 'oint above 2-3/8" liner to . F 6 Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with diesel to -2,200' E 7 Jet cut the 3-1/2" tubin in the middle of a full 'oint at --3800' MD. F 8 CMIT - T x IA to 2,250 si for 30 minutes revious MIT-IA test assed 3/31/2009 D 9 Bleed all casin and annulus ressures to zero si. W 10 Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. V 11 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form. Proposed Procedure: 1. MIRU. 2. MIT - OA to 2000 psi for 30 minutes (expect failure and obtain the LLR). CMIT - TxIA to 2,250 psi for 30 minutes. 3. Pull BPV. Circulate out freeze protection and displace well to seawater. 4. Set BPV using a T-bar and test from below to 1000 psi for 10 minutes (also tests TxIA). 5. Nipple down tree. Install a blanking plug into the tubing hanger's lifting threads. Nipple up and test BOPE to 3,500 psi. Remove the blanking plug using the retrieval sub and a joint of drill pipe. Pull BPV. 6. RU and pull the 3-1/2", 9.2#, 13Cr-80, FOX tubing from the pre-rig jet cut. Spool up the control lines. Test the lower set of pipe rams. 7. PU 4" drillpipe and 7" clean-out assembly and clean-out well to tubing stub. 8. Run a CCVUSIT in cement evaluation mode from tubing stub to surface. 9. With E-line, run a 7" EZSV for 26# casing. Set the EZSV at 100' below proposed 7" casing cut and test to 3500 psi for 10 minutes. Rig down E-line. 10. Pull 7" packoff through the BOP Stack. 11. MU amulti-string casing cutter. Run in hole and cut the 7" casing above the 9-5/8" surface casing shoe, without cutting a collar. 12. Establish circulation through the casing cut and circulate out the dead crude through the cut with seawater. 13. Spear the 7" casing from mandrel hanger. Circulate as required to clear the annulus. Pull and lay down. ~'h1S e. r~,\ 14. Perform a 9-5/8" cleanout/scraper run to the top of the 7" casing stub. Q~ 15. PU 9-5/8" whipstock, bottom trip anchor and 8.75" window milling assembly (to include full gauge string mills). RIH to the top of the 7" casing stub. Orient and set the whipstock. Swap the well over to 8.8 ppq fresh water LSND millino fluid. i ti. nnm a wmaow m the y-5/8" casing above the 9-5/8" casing shoe plus 20' of formation from mid- window. Perform LOT. 17. MU an 8-3/4" drilling BHA with MWD/LWD package and bent housing motor. RIH.. Kick off and drill intermediate interval to 7" casing point at the top of the Sag River. CBU, perform short trip, RIH back to TD, circulate well clean and POOH. • NOTE: The mud will need to be weighted up with spike fluid. Ensure that the mud weight is sufficient for shale stability prior to drilling into the HRZ and Kingak formation. 18. Run and cement 7", 26#, L-80, BTC-M x TCII casing from top of the Sag River Formation to surface Cement the casing in one stage bringing the estimated TOC to 750' below the window. NOTE: Establish infectivity and freeze protect the 7" x 9-5/8" annulus off the critical path. 19. MU a 6-1/8" BHA with MWD/LWD package and RIH. Wash down to the shoe track in the 7" casing. Swap the well over to 8.5 ppg FloPro SF drilling fluid. 20. Pressure test the 7" casing to 3500 psi for 30 minutes and chart. 21. Drill out the remaining shoe track plus 20' of formation. Perform an FIT. 22. Drill ahead per plan to TD in Zone 1 B. Plan on a bit/BHA trip after drilling the Conglomerates. 23. Circulate bottoms up as necessary, short trip, circulate until clean and POOH. 24. Run and fully cement a 4-1/2", 12.6#, L-80, IBT-M, liner throughout the 6-1/8" wellbore with 150' liner lap. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A pen` pill will be left in the 4-1/2"liner. 25. Pressure Test the 4-1/2" liner to 3500 psi for 30 minutes once sufficient compressive strength has been achieved. Chart the test. 26. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 27. Run the 4-1/2", 12.6#, 13Cr-80, Vam Top completion. Tie into the 4-1/2" liner top. 28. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes each. 29. Set and test TWC. 30. ND BOPE. NU and test the tree to 5,000 psi. 31. Freeze protect the well with diesel to 2200' MD. Set a BPV. 32. RDMO. Drilling Engineer: Mark Staudinger (907) 564-5733 Production Engineer: James Dean (907) 564-4668 Claudia Rico-Hernandez (907) 564-5626 Geologist: Priya Maraj (907) 564-4781 ATTACH: Current Schematic Proposed Schematic TREE = 3-1 /8" FMC WELLHEAD = FMC ACTUATOR = OTIS-SHORT KB. ELEV = 66' BF. ELEV KOP = Max Angle= 97° @ 10537 Datum MD - Datum TV D = 9092' 8800' SS 9-5/8" CSG, 36#, J-55, ID = 8.921" 0 ~ -3 3A SAFErY NOTES: ***CHROME TBG ~ LNR*** • C Minimum ID =1.995" @ 8143 2-3/8" LINER TOP TOP OF 2-3/8" LNR I~ 8143' 22~~' - 3-1/2" OTIS FMX TRSV SSSV NIP, ID = 2.81" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3098 3098 2 MMG-2 DOME RK 16 10/06/00 2 4904 4902 1 MMG-2 DOME RK 16 10/06/00 3 6138 6134 8 MMG-2 DMY RK 0 09/17/00 4 6945 6918 21 MMG-2 DOME RK 16 10/06/00 5 7408 7345 23 MMG-2 DMY RK 0 09/17/00 6 7697 7612 20 MMG-2 DMY RK 0 09/17/00 7 7900 7802 21 MMG-2 SO RK 20 10/06/00 8 8102 7989 24 MMG-2 EO DMY RKP 0 09/28/00 8143, I-12.70' DEPLOY SLV, ID = 1.969" (LOGGED 09/10/00) 8212' 7" X 3-1 /2" OTIS BWD PERM PKR, ID = 4.00" $216' SEAL BORE EXTENSION, ID = 4.00" $232' S-1/2" MILLOUT IXTENSION, ID = 4.67" $2$$' 5-112" X 3-1/2" XO, ID = 2.992" 8283' 3-1/2" PARKER SWN NIP, ID = 2.75" TOP OF 5" LNR ~-~ 8313, 3-1/2" TBG, 9.2#, 13CR-80, .0087 bpf, ID = 2.992" $327' 7" CSG, 26#, L-80, ID = 6.276" $615' PERFORATION SUMMARY REF LOG: BHCS ON 10/19/91 ANGLE AT TOP PERF: 64° @ 9220' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9220 - 10020 O 09/17/00 1-11/16" 6 9400 - 9500 O 07/07/08 1-11/16" 6 9680 - 9730 O 07/07/08 1-11/16" 6 9790 - 9830 O 07/07/08 1-11/16" 6 9940 - 9985 O 07/07/08 1-11/16" 4 10440 - 10720 O 09/17/00 1-11/16" 6 10585 - 10685 O 07/06/08 1-9/16" 6 10720 - 10770 O 08/04/03 $~ 313' ~~ 7" X 5" TNV LNR HGR, ID = ? $327 3-1/2" TUBING TAIL $327' ELMD LOGGED xx/xx/xx MILLOUT WINDOW (02-33A) 9115' - 9122' I PBTD I I TD I 5" LNR, 15#, 13CR-80, .0189 bpf, ID = 4.408" ~ 9384' 2-3/8" LNR, 4.6#, FL4S, L-80, .0039 bpf, ID = 1.995" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17/00 N CDR1 SIDETRACK (02-33A) 11/10/06 JPK/TLH GLV GO CORRECTION (10/6/00) 07/18/08 ?/JMD GLV GO CORRECTION (10/6/00) 07/25/08 PJC DRAWING CORRECTIONS PRUDHOE BAY UNIT WELL: 02-33A PERMff No: 2001230 API No: 50-029-22214-01 SEC 36, 711 N, R14E, 626' FNL & 861' FEL BP Exploration (Alaska) ~= 4-1/8" F WELLHEAD= FMC ACTUATOR = Ke6. ELEV = BF. ELEV = KOP = Max Angle = Datum MD = Datum TVD = SAFETY NOTES: ***CHROME TBG*** 02-3~B Proposed 2200' - 4-1/2" HES X-NIP, ID = 3.813" GAS LIFT MANDRELS 2 ~KOP-Top of Whipstock ~ 3435' 9-5/8" CSG, 36#, J-55, ID = 8.921" 3478' 9-5/8" ¢SV -3750' JET CUT -3800' TUBING PUNCH -8100' TOP OF 2-3/8" LNR 2.70' DEPLOY SLV, ID = 1.969" 8143' (LOGGED 09/10/00) 7" X 3-1/2" OTIS BWD PERM PKR, ID = 4.00" 8212' SEAL BORE EXTENSION, ID = 4.00" 8216' 5-1/2" MILLOUT EXTENSION, ID = 4.67" 8232' ~ 5-1/2" X 3-1/2" XO, ID = 2.992" 8238' 3-1/2" PARKER SWN NIP, ID=2.75" 8313' 7" x 5" TNV LNR HGR, ID=? 8313' 3-1/2" TBG, 9.2#, 13CR-80, .0087 bpf, ID = 2.992" 8327' ~~ ~ ~; I_~ ~~~ ~~~ TOC ~~ -9000' PERFORATION SUMMARY REF LOG: BHCS ON 10/19/91 ANGLE AT TOP PERF: 64° @ 9220' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE ~ 5" LNR, 15#, 13CR-80, .0189 bpf, ID = 4.408" ~ Minimum ID = 3.725" @xxxx' HES XN-NIP 4-112" HES X-NIP, ID = 3.813" xxxx BAKERS-3 PROD PKR xxxX 4-1/2" HES X-NIP, ID = 3.813" xxxx 4-1/2" HES XN-NIP, ID = 3.725" xxxx 4-1/2" TBG, 12.6#, 13G-80, V 9810' BAKER ZXP LINER TOP PKR g$10' 7" CSG, 26#, L-80, BTGM x TCII 4-1/2" LNR, 12.6#, L-80, IBT-M 12733' MILLOUT WINDOW (02-33A) 9115' - 9122' I PBTD I I TD I ~ 2-3/8" LNR 4.6#, FL4S, L-80, .0039 bpf, ID = 1.995" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17100 N CDR1 SIDETRACK (02-33A) 11/10/06 JPK/TLH GLV GO CORRECTION (10/6/00) 07/18/08 ?/JMD GLV GO CORRECTION (10/6/00) 07/25/08 PJC DRAWING CORRECTIONS 04!07/09 MIS Proposed ST PRUDHOE BAY UNfT WELL: 02-33A PERMfT No: 2001230 API No: 50-029-22214-01 SEC 36, T11 N, R14E, 626' FNL & 861' FEL BP Exploration (Alaska) • Page 1 of 2 Maunder, Thomas E (DOA) From: Staudinger, Mark [Mark.Staudinger@bp.com] Sent: Monday, April 13, 2009 3:02 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: RE: DS 02-33A (200-123} Tom- Sorry for the confusion, but I will be the drilling engineer on this one (Garret is my twin brother). My base plan will be to kick off the 9-5/8" surface casing via a whipstock due to the high success rate we have with our wellbore departures in 9-5/8" casing. Also, there is some uncertainty in pulling this casing from below the 9-5/8" shoe as we are uncertain where the top of cement is on the original 7" casing job. According to records, they pumped enough cement on the original job to bring the TOC inside of the 9-5/8" x 7" casing annulus. However, MIT-OA tests indicate that we have at least a partially open shoe on this well. Internally on the 7" stub, we will have 2 barriers to the production zone (a cement P&A) and a shallow, tested EZSV. Externally, the drilling reports for running and cementing the 7" casing indicates a good cement job with full returns, and reciprocation through the entire job. I would like to begin the pre-rig operations as soon as possible. The rig will likely be ready to move to this well in the first week of May. Please let me know if you have any questions. Thanks, Mark Staudinger BP Exploration Alaska Operations Drilling Engineer GPB Rotary Drilling (907) 564-5733 (907) 440-7403 cell From: Staudinger, Garret Sent: Monday, April 13, 2009 2:42 PM To: Staudinger, Mark Subject: FW: DS 02-33A (200-123) This is for you 1 `:.d G-- ~t-~ c3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 13, 2009 2:30 PM To: Staudinger, Garret Cc: Tirpack, Robert B Subject: DS 02-33A (200-123) Garrett, I am reviewing the sundry submitted for the P&A for redrill of this well. Your plan is to cut and pull slightly above 4/13/2009 Page 2 of 2 the surface casing shoe and then effect your kickoff via a whipstock. It does not appear that you have a plan to externally isolate the 7" stub. Prior proposals I have seen cut the 7" below the surface shoe and then cover the stub with cement up into the surface casing and then kick-off below the shoe. I look forward to your comments about your planned way forward versus the prior method. Also, is April 17 still the planned start date for operations. Tom Maunder, PE AOGCC 4/13/2009 ~ _ STATE OF ALASKA ~~ ~~ ~ -•~ ~- ALA~ OIL AND GAS CONSERVATION COM ION f, ~ ~~~ Atli . REPORT OF SUNDRY WELL OPERATION~I~,~,, ~ ZO 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ t , ~ Performed: Alter Casing Pull Tubin Perforate New Pool Waiver Time Extension ^ g^ ^ ^ ~-' ~~~~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well ~ ~ .'> 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~ 200-1230 - 3. Address: P.O. Box 196612 Stratigraphic ~' SerViCe 6. API Number: Anchorage, AK 99519-6612 50-029-22214-01-00 ' 7. KB Elevation (ftj: 9. Well Name and Number: 66 KB' PBU 02-33A 8. Property Designation: 10. Field/Pool(s): ADLO-028308 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10872 ' feet Plugs (measured) None true vertical 8945.56 ~ feet Junk (measured) None Effective Depth measured 10817 feet ~~`'~~~~ ~UL ~ 4 ZD~$ . true vertical 8944 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 35 - 115 35 - 115 1490 470 Surface 3443 9-5/8" 36# J-55 35 - 3478 35 - 3477 3520 2020 Production 8595 7" 26# L-80 34 - 8629 34 - 8465 7240 5410 Liner 809 5" 15# 13CR80 8313 - 9122 8184 - 8893 8290 7250 Liner 2711 2-3/8" 4.7# L-80 8130 - 10841 8015 - 8944 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.2# 13Cr80 33 - 8327 0 0 - Packers and SSSV (type and measured depth) 3-1 /2" Otis BWD Packer 8212 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): \N~~~ ~6~5~ t~l~~ Treatment descriptions including volumes used and final pressure: ~~ ~` ~~~~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~' Service I" Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas i`"' WAG ~1 GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer '~~ Signature Phone 564-4944 Date 7/11/2008 Form 10-404 Revised 04/200po ~ f ~ ~ ~' ~ ~~~ ~~ ~ ~' ~~~- ~ ~ 1~~8 Submit Original O ly ~,- , ~r~ . ~~ ~ ~ ~ 02-33A 200-1230 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth lop Meas Depth Base Tvd Depth Top Tvd Depth Base 02-33A 9/17/00 PER 9,220. 10,020. 8,954.66 8,977.83 02-33A 9/17/00 PER 10,440. 10,720. 8,967.3 8,951.47 02-33A 8/4/03 APF 10,720. 10,770. 8,951.47 8,948.32 02-33A 7/7/08 APF 9,400. 9,500. 8,984.82 8,986.36 02-33A 7/7/08 APF 9,680. 9,730. 8,985.85 8,986.13 02-33A 7/7/08 APF 9,790. 9,830. 8,984.81 8,983.26 02-33A 7/7/08 APF 9,940. 9,985. 8,977.9 8,977.93 02-33A 7/7/08 APF 10,585. 10,685. 8,955.81 8,951.14 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • LJ • 02-33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY - -~ 7/4/2008 k**WELL SHUT IN ON ARRIVAL'''"' 'DRIFTED W/ 2.84" NO-GO CENT. TO 2155' SLM. 'FISHED MEMORY TOOLS FROM TRSSSV AT 2200'MD. !CURRENTLY FUNCTION TESTING TRSSSV. ***CONT WSR ON 7/5/08*** 7/4/2008 CTU #9 1.5" CT (WWP) Perforating Stuck at SSSV, continue trying to ;get free, drop 5/8" ball to disconnect .pooh. Left 13' x 1.5" OD of Memory Tools in sssvn ,bottom portion of disconnect takes 2 3/8" gs to :pull, ID is 1.375" of G fishing neck. Lay mast down for slickline to get on :well & Stand by. RU Slick Line to retrieve BHA stuck in SSSV. BHA :recovered, gouge at the Bull Nose of the Mem Tool shows it was stuck :there. Bull Nose has a square shoulder that caused it to hang up in :SSSV. LD BHA and download Log Data. Continue SL OPS to verify :SSSV is in good operating condition. ***Job continued on WSR 7/5/08*** 7/5/2008';CTU #9 1.5" CT (WWP) Perforating <InterACT is Publishing>. ***Job ',continued from WSR 7/4/08""* Continue SL OPS to verify SSSV is in ',good working condition. SSSV is operating and open, RD Sllick Line, RU CT and set up to Flow check well. Data quality of tie in log is questionable with charactor changes, decision was made to rerun the :log over a longer interval. Called out for Mem Logger. Rih with Memory GR/CCL to 10750 to 9400', flag at 10400' Pooh. Bad data from log (battery failure). Cut off 100' of pipe and install new Baker weld on :connector. Rih with Memory GR/CCL to 10760' and log to 9400'. Flag 10300' ***Job continued on WSR 7/6/08*** 7/5/2008:***CONT WSR FROM 7/4/08*"" :RAN 2.84" NO-GO CENT. FLAPPER CHECKER TO TRSSSV AT 2200'MD.(GOOD FUNCTION TEST.) 'RAN 2.805" SWAGE TO 2225'SLM."'`NOTE WORKED THROUGH 'TIGHT SPOT IN TRSSSV AT 2184'SLM. "'`*RDMO"** *"***"NOTE: THE FLOW TUBE IN THE TRSV IS SUSPECTED OF BEING SLIGHTLY DINGED OR SLIGHTLY OUT OF ROUND. MULTIPLE PASSES WERE MADE THRU THE TRSV WITH A 2.805" TAPERED SWAGE BUT IT WOULD OCCASIONALLY SIT DOWN. ***,** • 7/6/2008 PERFORATIONS • CTU #9 1.5" CT (WWP) Perforating. <InterACT is Publishing> ~*Job continued from WSR 7/5/08*** Logging run completed, download data and perform No-Flow Test. Good data from tool (correct depth +20'). No-Flow Test good, 0 flow at tank and took .2 bbls to fill hole. PJSM to MU Perf Guns included lift plan (Weights, Wind & Equipment) and roles & responsibilities. MU 100' of 1.56" HSD, 1606 PJ HMX, 6 SPF Perf Guns monitoring returns and RIH to flag and correct depth, stop at bottom shot at 10,685'-10,585' drop 1/2" aluminum ball and fire guns, Pooh. All shots fired. Rih with Memory GR/CCL to 10750' to 9400', Pooh. OOH download data & start 30 min No-Flow Test. Good Data (correct depth +18'), PJSM to MU Perf Guns included lift plan (Weights, Wind & Equipment) and roles & responsibilities. Guns made up, RIH. '`"*Job continued on WSR 7/7/08""* CTU #9 1.5" CT (WWP) Perforating. <Interact is Publishing> ""*Job continued from WSR 7/6/08"*" Continue RIH W/ 620' of 1.56" HSD, 1606 PJ HMX, 6 SPF Perf Guns monitoring returns and RIH to flag and correct depth, stop at flag and correct to top shot at 9,400'-9,985'. Pump 10 bbls of Flo-Pro and drop 1/2" aluminum ball to fire guns, POOH. All shots fired. R/D guns. Rih with 2" JSN and freeze protect from 2300' to surface. Injector stopped working ,cannot move up or down @ 896'. Problem corrected Pooh. CTU going back to shop for Mast MPI & Hardline annual inspection. BOPE will remain on tree until BPV can be set. Stack tested to 4k. Called Nick (WS Foreman) and Ely (Valve Shop Coordinator) and we are 3rd in line behind 2 rigs for a BPV. *"*'`Well Freeze Protected**** ***Job Completed*** TOP DEPTH BOTTOM DEPTH GUN DIAMETER ORIENTATION SHOT DENSITY SHOT PHASE 9,400 _.~.._..~........__._~___________.____._ 9,680 9, 790 9,500 . .-__._-- 9,730 9, 830 1.687 ~~e~__ _~~~~_~~e__. 1.687 1.687 Y _____._____ .._~~~e~_.~_ Y Y 6.00 ._..______~____...__....___._._......________ 6.00 6.00 60 ~~~~_...__.._._ ....................~_.~__.~.............~..~~. 60 60 9,940 9,985 1.687 Y 6.00 60 10,585 10,685 1.687 Y 6.00 60 FLUIDS PUMPED BBLS 33 50/50 METH 26 XS 1 % KCL 10 FLOW PRO 69 Total 09/27/07 al~r~l~~~~~~~ Alaska Data 8~ Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99603-2838 ATTN: Beth ~;;,~ N~1~! ~ `~ 200? weu 1.,-. it I nn neQ~.l.,a.,., NO. 4437 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~lp al r.~h~ cn • 15-29A 11686783 SCMT b 09/05/07 1 05-25B 11630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - ~ 09/12/07 1 05-22A 11813086 SGMT 09/18107 1 S-400A 11855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT? j - 09!18!07 1 E-27A 11676963 USIT CORROSION) 09/18/07 1 MPG-07 11594520 USIT = ' 08/29/07 1 MPS-37 N/A SCMT 09/08107 1 YLtASt AGKNUWLtUGt KtGt1Y l tSC SfIiNINl9 ANU Kt f UKNINIS UNt tiUYT tAliri 1 U: SP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 }, r, ~ .~~ , -~-~, 900 E. Benson Blvd. ~`~' +~ , k~ '~ Q - ~? Anchorage, Alaska 99508 ~ t. tj ` ` Date Delivered: ,.r- - u,:~ .~ ., Alaska Data & Consulting Serv es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth \ `r ~,. ~__ Received b /b 19:~~s~~,~~~~C ' a!~'j(i't'tills~iu41 ) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY' 0 6 Z005 REPORT OF SUNDRY WELL OPERATI8M¡/&Gd1ì.~~r~",,',. " 1. Operations Periormed: It '..~.. \., li'l W ng;~S'CJn AbandonD Repair Well 0 PluQ PeriorationsD Stimulate 00 MnC~m.øu Alter CasingD Pull TubingD Periorate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 200-1230 6. API Number 50-029-22214-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 66.00 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 02-33A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 10872 feet true vertical 8945.6 feet Effective Depth measured 10817 feet true vertical 8944.4 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 35 115 35.0 115.0 1490 470 Liner 809 5" 15# 13CR80 8313 - 9122 8183.6 - 8892.7 8290 7250 Liner 2711 2-3/8" 4.7# L-80 8130 - 10841 8014.8 - 8944.3 11200 11780 Production 8595 7" 26# L-80 34 - 8629 34.0 - 8465.4 7240 5410 Surface 3443 9-5/8" 36# J-55 35 - 3478 35.0 - 3477.0 3520 2020 Measured depth: 9220 -10020,10440 -10720, 10720 -10770 True vertical depth: 8954.66 - 8977.83, 8967.3 - 8951.47,8951.47 - 8948.32 SCANNED MAY 11 200S TubinQ ( size, Qrade, and measured depth): 3-1/2" 9.2# 13Cr80 @ 33 8327 Packers & SSSV (type & measured depth): 3-1/2" Otis BWD Packer @ 8212 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9220' -10770' Treatment descriptions including volumes used and final pressure: 42 Bbls 50/50 DiesellXylene, 48 Bbls DAD Acid @ 3760 psig 13 Prior to well operation: Subsequent to operation: Oil-Bbl 85 93 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10.7 0 1150 12.9 0 1160 Tubing Pressure 364 245 14. Attachments: ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil Œ] Gas D Development Œ] Service D Copies of Logs and Surveys run_ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )ja~'A.l C ~ Title Production Technical Assistant Signature Phone 564-4657 Date 5/4/05 ~) \l .' "-, :. I ',.,' . . "\0 L RBDMS BFL MAY 1 0 2005 Form 10-404 Revised 4/2004 ) ') 02-33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/06/05 CTU #9 W/1.5" CT, COMPLETE BOP TEST. KILL WELL WITH 1% KCL, RIH WI 1.5" JET NOZZLE, TAG BOTTOM AT 10773' CTD, PUH ABOVE PERFS FOR INJECTIVITY TEST.. . *** CONTINUED ON 03-07-05 WSR*** 03/07/05 CTU #9 W/1.5" CT. ***CONTINUED FROM 03-06-05 WSR*** DIESEL I XYLENE WASH, ACID TREATMENT, PRE ACID INJECTIVITY TEST = 0.5 BPM =15 PSI WHP, 1 BPM = 450 PSI WHP, 1.2 BPM = 650 WHP. WASH 42 BBLS DIESEL I XYLENE ACCROSS PERFS, LAY IN 10 BBLS DAD ACID, SOAK FOR 30 MINUTES, JET 48 BBLS DAD ACID ACROSS PERFS, FLUSH WITH 60 BBLS 1 % KCL, FINAL INJECTIVITY IS 1.2 BPM @ 1148 PSI WHP. BLOW DOWN COIL WITH N2 AT SURFACE. WELL IS FREEZE PROTECTED WITH METH. WELL LEFT SHUT-IN. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 101 60 / 40 Methonal / Water 174 1 % KCL Filtered 42 50 / 50 Diesel/Xylene 48 DAD Acid 365 TOTAL Page 1 T.REE ~ 3-1/8", 5M FMC WELLHEAD = ? ACTuAToR:; . ï=Mc'ÒilS .v" .."" "'" """'. '" """". KB. ELEV = 66' BF.äE\j;; ? '¡(OÞ;;" . ,... ,. ? ""..",,,,,".",,,.,,,,,,,,. ...."""". ~x A~9~.~ ~m 9!@~0!5~?' Datum MD = 9091' ",,,,,,,,,,,,,,,,,,,.,,,,,.,,,,,,. ,.,..,.".. Datum TV D = 8800' SS ) 9-5/8" CSG, 36#, J-55, ID = 8.921" 1-1 3478' ~ Minimum ID = 1.995" @ 8143 2-3/8" LINER TOP 02-33A ) SAFETY NOTES: 3-1/2" CHROMETBG & 5" CHROME LNR fa 2200' 1-13-1/2" OTIS FMX TRSV SSSV NIP, ID = 2.81" 1 L ~ ST MD TV D 1 3098 3098 2 4904 4902 3 6137 6133 4 6945 6918 5 7408 7346 6 7697 7612 7 7899 7802 8 8102 7989 GAS LIFT MANDRELS DEV 1YÆ VLV LATCH PORT DATE 2 CA-MMG-2 RK 1 CA-MMG-2 RK 7 CA-MMG-2 RK 20 CA-MMG-2 RK 23 CA-MMG-2 RK 20 CA-MMG-2 RK 21 CA-MMG-2 RK 24 CA-MMG-2 RKP I TOP OF 2-3/8" TBG 1-1 8143' I TOP OF 3-1/2" LNR 1-1 8212' I--Z & I I I TOP OF 5" LNR 1-1 8313' . 13-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.992" 1-1 8327' 7" CSG, 26#, L-80, 10 = 6.276" 1-1 8629' ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/19/91 ANGLE AT TOP ÆRF: 64 @ 9220' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 9220 - 10020 0 09/17/00 1-11/16" 4 10440 - 10720 0 09/17/00 1-9/16" 6 1 0720 - 1 0770 0 08/04/03 15" LNR, 15#, 13-CR-80, .0188 bpf, ID = 4.408" 1-1 9384' 8143' 1-1 2-3/8" DEPLOYMENT SLEEVE 8212' 1-1 7" X 3-1/2" OTIS BWD PKR 1 8283' 1-1 3-1/2" PARKER SWN NIP, 10 = 2.75" 8327' 8327' 1-1 3-1/2" TUBING TAIL 1 1-1 ELMD TT NOT LOGGED .. 5" MILLOUT WINDOW: 9122' PBTD 1-1 10833' 1 ~-I 10872' I 2-3/8" LNR, 4,6#, FL-4S, L-80, ID = 1.995", CAP= .00387" 1-1 10853' I DATE 10/29/91 09/17/00 01/03/01 02/17/01 08/13/01 08/04/03 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION SIS-MO 2ND REVISION GSN/TP CORRECTIONS ? ITP CHA NGE 2- 7/8" TO 2- 3/8" TBG JGM/TLH ADO PERF, CORRECT LOCATION DA TE REV BY COMMENTS 08/17/03 CMOITLP PERF ANGLE CORRECTION 03/27/05 KCFITLH TREE CORRECTION PRUDHOE BA Y UNrT WB...L: 02-33A PERMrT No: 2001230 API No: 50-029-22214-01 SEC 36, T11 N, R14E, 626' FNL & 861' FB... BP Exploration (Alaska) Schlurnberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 2,2()'j.jjL,G-12B ~15-35'B J..O:?··; q "I . '""oj-ll [; 0-04B ./ OS 18-13A LC'!;-/<15 K-10B OS 02-15A ~~... }-¿; OS 2-33A ¡9Flh>' OS 07-03A 2ClJ~iql DS 07-29C ¡:¡r¡ ð/l- E-15B 1_, ~iJ DS 18-27C ~'t/c) ~ ., ...., ~"C'~{' E-24B H,-!()9 DS 18-31 ~'¡~iJO K-09C ./0'/-0'11 C-17B ('1)-0:14 C-39 Job # 10715391 10728396 10715393 10715395 10715402 10715404 10670016 10715406 10715407 10861913 10715410 10861916 10715413 10861920 10715418 10715421 (Prints.... only-Job not complete) MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL SC/\NNED JUN 1 7 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: /- / /~ /'7 /08 c::-¡ J ./ I I . ID 7SP-VA v~ / O<FY[) - /(:2 :3 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 03/21/04 1 04/03/04 1 04/07/04 1 04/16/04 1 05/16/04 1 05/18/04 1 OS/23/04 1 06/03/04 1 06/04/04 1 06/05/04 1 06/13/04 1 06/20/04 1 07/05/04 1 07/16/04 1 08/10/04 1 08/19/04 1 ~ -" Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-283 " U' A TTN: Beth · / 7' ~~~ F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~~~,"'~... ~'IIr...~ \_ ,-'o.j" " ,). . .1' Permit to Drill 2001230 DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. PRUDHOE BAY UNIT 02-33A Operator BP EXPLORATION (ALASKA) INC MD 10872 TVD 8946 Completion Dat 9/18/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22214-01-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample N_go Directional Survey N_go DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Medi 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 D 7988 10830 Case 1/3/2001 0979~988-10830 9129 10872 Open 5/8/2001 10046/~9-10872 MWD Survey Report FINAL 2/2/2001 Digital Data MWD Survey Report FINAL 9115 10872 2/2/2001 9115-10872 Paper Copy 9795 FINAL 7988 10830 CH 1/3/2001 97~'~' 7988-10830 Digital Data GR/CCL/CNL 5 FINAL 7988 10830 CH 1/3/2001 / 7~8-10830 BL, Sepia 10046 FINAL 9129 10872 oh 5/10/2001 1004~ 9129-10872 Digital Data MD GR 5 FINAL 9129 10872 oh 5/10/2001 9129-10872 BL, Sepia TVD GR 5 FINAL 9129 10872 oh 5/10/2001 9129-10872 BL, Sepia LIS Verification FINAL oh 5/10/2001 LIS Verification Paper Copy Well Cores/Samples Information: .Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? y Chips Received? Analysis R ~.c.~.iv~.d ? Daily History Received? ~ Formation Tops ~/N Comments: Permit to Drill 2001230 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 02-33A Operator BP EXPLORATION (ALASKA) INC APl No. $0-029-22214-01-00 MD 10872 TVD 8946 Completion Dat 9/18/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Transmittal Form HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska 02-33A Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print Sent By: Josef Berg Date: May 8, 2001 Received ~ ~_P t_o~'z~.~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED ~AY 1 0 2001 111281OO Schlumberger NO. 726 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-I'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-33A 20431 MCNL (PDC) 000916 I I 1 D.S. 6-21A 20432 MCNL 000918 1. I 1 · D.s. 11-38A 20437 RST-SlGMA 001003 I I I SIGNE~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oi, E] ~s D suspended D Abandoned D Service D 2. Name of Operator 7. Permit Number BP Exploration (Alaska), Inc. 200-123 3. Address 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 50-029-~'~14-01 4. Location of well at sudace r .............. 9. Unit or Lease Name 623' FNL, 4418' FEL, Sec. 36, T11N, R14E, ua (asp's 687604, 5950575) j ;...,:.;~.: ' ; Prudhoe Bay Unit At Top Producing Interval 'i - At 5036' FNL, 5090' FEL, SEC 25, T11N, R14E, UMTotal Depth (asp's 686910' 5951427) i ' ~'~ ~i .... 11. Field02'33Aand Pool 4293' FNL, 4262' FEL, SEC 25, T11N, R14E, UM (asp's 687719, 5952190) .......... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 66 feetJ ADL 28308 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Su~/%Aband. 115. Water Depth, if offshore 16. No. of Completions September 7, 2000 August 13, 2000 Septemberc,f~ 2'000 J N/A feet MSL 1 I 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness o! Permafrost 10872' MD /8946' TVD 10817' MD /8945' 'I'VD YES ~] No DI 2200' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mem GR/CCL/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 110 30" 11 yards AS 9-5/8" 36# J-55 Surface 3478' 12-1/4" 1920 cuft cs III, 348 Sx cuft Class G, & 89 cuff CS II 7" 26# L-80 Surface 8615 8,1/2" 792 cuft Class G 5" 15# 13CR-80 8313 9115' 6" 138 cuft Class G 2-3/8" 4.6# L-80 8143' 10872' 3.0" 20-1/2 bbls 15.8 ppg LARC 24. Perlorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8327' 8212' 9290' - 10020' MD; 89732' - 8978' TVD; @ 4 SPF 10440'-10720' MD; DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N0V 0 Z000 (See Sidetrack Summaryfor details) Date First Production ~JW~lt~lJJ~G~ration (Flowing, gas lift, etc.) October 12, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO' 10/16/2000 3.0 Test Period >I 14160 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -217 psi 24-Hour Rate > 620 8779 0 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 August 22, 2000 (Permit #200-123) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGiN, i_ Submit in duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone lB GEOLOGIC MARKERS MEAS. DEPTH 8564' 8629' TRUE VERT. DEPTH 8373' 8465' 8930' Top of Zone lA 9175' 9200' 8945' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time el each phase. RECEIVED NOV 09 2000 Alaska 0il & Gas Co~s. C0~ 31. LIST OF ATTACHMENTS Summary of 02-33A 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. Signed ~~ ~,~ Title CoilTubin,qDrillin,qEn,qineer Larnar Gantt Date 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". Form 10-407 02-33A (' DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 8/2312000: MIRU CTU. BOPE test to 4000 psi. RIH & tagged TOC @ 9039' MD. POOH w/BHA. 8/24/2000: '~l;llH w/UR & milled cement to 9113'. POOH w/UR. RIH w/window milling BHA. Milled to 115'. Commenced window milling operations through the 5" liner. 8/25/2000: Milled window f/9115' to 9122', drilled FM to 9132' MD, & POOH. RIH w/Crayola Mill & polished window interval. POOH. RD CTU. 9/05/2000: MIRU Nabors CDR1. Rig accepted 2030 hrs. 9/06/2000: Continued RU of CDR1. Began BOPE test. 9107/2000: Completed BOPE test. RIH w/bi-centered bit & tagged BTM @ 9129' MD. Drilled ahead to 9108/2000: 9/0912000: 9/10/2000: 9/11/2000: 9112/2000: 9/13/2000: 9114/2000: 9/15/2000: 9/16~2000: 9/17/2000: 9/18~2000: 9/19/2000: 10/04/2000 - 10/06/2000: 9137'. Performed LOT to EMW of 9.0 ppg. Drilled to 9285' & POOH. RIH & drilled to 9525'. POOH. RIH w/BHA. Drilled to 10051. Swapped to new mud. Drilled to 10123' & POOH. RIH & UR'd f/10000' to 10123'. Drilled to 10140'. CT stuck @ 10123'. Pulled free. Drilled to 10413'. Swapped to new mud. Drilled to 10785'. Reamed OH. Drilled to TD @ 10872' & POOH. PT'd BOPE. MU BHA. RIH & reamed to BTM (shales were tough to clean out after extended time out of OH). Conditioned OH f/liner run. POOH. MU 2-3/8" FL4S liner. RECEIVED choro e RIH & landed liner @ 10872'. TOL = 8143'. Dropped ball & confirmed liner release. Pumped 20.5 bbls of 15.8 ppg LARC to cement liner. Released f/liner. POOH. WOC. RIH w/Mem GR/CNL/CCL tools & tagged PBTD @ 10817'. Logged well. New mud. POOH w/tools. PT'd liner to 2000 psi - bled to 1400 psi in 3 min. MU perf guns. RIH w/2-9/16" CT conveyed perforating guns & shot 1010' of Initial Perforations f/: 9290'- 10020' MD (Zone lA) 10440'- 10720' MD (Zone lA) All perfs @ 4 SPF, 60° phasing, & overbalanced press. POOH w/guns - ASF. FP'd well. RDMOL. CDR1 released 1500 hrs. Installed GLV's. Placed well 02-33A on initial production & obtained a valid well test. Sidetrack Summary Page I BP Amoco WELLPA TH DETAILS 02-33A 50029222f401 Parent Wellpath: 02-33 Tieon MD: 9t~5.00 Vertical Section Orfgin: Slot - 33 (0.00,0.00) Vertical Section Angle: 5LO0° Rig: CDR l Depth Reference: 65: 33 ~0161199~ 00:00 66.0Oft REFERENCE INFORMATION Coordinate (N/E) Reference: Well Centre: 02-33, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 33 (0.00,0.00) Measured Depth Reference: 65: 33 10/6/1991 00:00 66.0 Calculation Method: Minimum Curvature ,ANNOTATIONS TARGET DETAJ L~ No. 1MO ~ .Nlno~So~ Name ~ ~ *~-w ~ 8820.64 91t5,00 Kick-offPoint (e~3A~ ~m~eo ~7o4~ 887g.6810872.00 ProjededtoTD(~-33APOIfi~2.1(~AT24 888~000~0185~5494Z3~ -83fi¢3~487'67 p~ao0aadlu~ 3) LEGEND 02-33 02-33A Plan 02-33'(02-33)' 02-33A T I Wellpalh: (02-33/02-33A) .~. Azimuths to ]'rue North I /[\ l~lagnetic North: 27.11° I (:,~d By: Bnj Porto, Date: I I/6/ZO~ Iff Magnet c Fie d I f ~ I ~ Dip Angle: 80.7l°~ D~rc~l (90~) 267~13 ~ Date: 9/1/20001 E r~l ~il I~tn~ml*~l c~ ~ Model: BGOM2000 ] Bak~ H~hea INTEQ: (~7) 26~-~ -'1500 -1000 -500 0 500 '1000 -200 0 200 400 600 800 1000 1200 1400 1600 Vertical Section at 51.00° [20Oft/in] Plot 11/8/2000 2:58 PM BP Amoco Baker Hughes INTEQ Survey Report ~T~.O Site: PBDS02 : , ::: : :: , I Well: 02-33: : : Well (0+~;0:00N,51..~) W~patb: 02-33A . Sm'~?C~:~= ~ Mi~CUrvature Db: i Field: Prudhoe Bay i North Slope . UNITED STATES i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre , Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 -- i Site: PB DS 02 TR-11-14 UNITED STATES · North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N l From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-33 02-33 Slot Name: 33~- ~ ~/~2~~-~ Well Position: +N/-S 1774.97 ft Northing: 5950574.92 ft Latitude: 70 16 11.304 N Ill +E/-W 9.52 ft Easting: 687603.72 ft Longitude: 148 28 57.783 W Position Uncertainty: 0.00 ft IIlll I [J .... Current Wellpath: 02-33ADatum: Height AboveDrilled FrOm:system Datum: 02-33Mean Level --W ~' ~ ~i~ 500292221401 Tie-on Depth: 9115.00 ft O 65 ' 33 10/6/1991 00:00 66.00 ft Sea ~''~ Magnetic Data: 91112000 Dedinafion: 27.11 degI1! 0 Field Strength: 57361 nT Mag Dip Angle: 80.71 dog ~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~~ ~ ff ft ff doga,,a=,, ..~ ~ o.oo o: o o: o Survey: MWD Start Date: 9/15/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path -- Annotation 9115.00 8888.64 Kick-off Point 10872.00 8045.68 Projected to ID Snrvey 9115.00 29.00 326.20 8886.64 8820.64 822.18 -633.67 5951381.01 686949.79 0.00 24.96 9121.00 34.50 ' 326.20 8891.74 8825.74 824.81 -635.43 5951383.59 686947.97 91.67 25.25 9149.00 45.90 325.90 8913.09 8847.09 839.77 -645.51 5951398.29 686937.52 40.72 26.83 9183.00 52.60 312.90 8935.33 8869.33 859.14 -662.31 595141?.24 686920.25 34.97 25.97 9221.00 64.20 315.40 8955.21 8889.21 881.68 -885.46 5951439.19 686896.54 31.03 22.'16 0255.00 75.10 319.30 8967.02 8901.02 905.11 -?06.99 5951462.0? 686874.44 33.81 20.17 9287.00 83.00 327.00 8973,.110 8907.10 030.23 -725.78 5951486.71 686855.03 34.16 21.38 9319.00 82.60 328.80 8977.11 8911.11 957.12 -742.65 5951513.18 686837.49 5.?2 25.19 9352.00 83.70 331.90 8981.05 8915.05 085.59 -758.85 5951541.23 686820.58 9.90 30.51 0383.00 85.?0 334.70 8983.01 8917.91 1013.16 -772.72 5951568.45 686806.04 11.07 37.09 9415.00 88.90 337.20 8985.42 8919.42 1042.35 -?85.74 5951507.30 686792.29 12.68 45.33 9453.00 89.40 341.40 8985.99 8919.99 10?7.88 -?99.1 ? 5951832.49 686777.98 11.13 57.26 9483.00 89.20 343.20 8986.35 8920.35 1106.46 -808.29 5951660.82 686768.15 6.04 68.16 9520.00 90.90 347.00 8986.32 8920.32 1142.21 -817.80 5951696.32 686757.75 11.25 83.26 9550.00 92.00 351.30 8985.56 8919.56 1171.65 -823.44 5951725.62 686751.38 14.79 97.41 9583.00 91.00 356.90 8984.70 8918.70 1204.45 -826.83 5951758.32 686747.17 17.23 115.42 9621.00 89.30 1.10 8984.60 8918.60 1242.44 -827.50 5951796.27 686745.56 11.92 138.81 9659.00 88.20 6.40 8985.43 8919.43 1280.33 -825.01 5951834.22 686747.10 14.24 164.58 BPAmoco BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 02 Well: 02-33 WeBpath: 02-33A Date: 11/6/2(X)0~ Ti~e: 15:38:10 Page: 2 Ce-erdi~) R~: Well: 02-33, Tree North 65: 33 10/611991 00:00 66.0 Well (O.OOE,0,00N,51,00Azi) Minimum Curvature Db: Oracle Survey MD Incl Azim $STVD , ~PN MapE DL$ VS ff deg deg ff : ~: ft ff deg/100ft 9705.00 89.60 11.60 8986.31 8920.31 1325.74 -817.82 5951879.79 686753.16 11.70 198.75 9737.00 91.00 19.00 8986.14 8920.14 1356.58 -809.38 5951910.83 686760.83 23.53 224.72 9774.00 91.40 20.40 8985.37 8919.37 1391.41 -796.91 5951945.95 686772.42 3.93 256.32 9815.00 92.30 26.40 8984.04 8918.04 1429.00 -780.65 5951983.94 686787.75 14.79 292.62 9855.00 93.60 31.30 8981.98 8915.98 1463.98 -761.38 5952019.38 686806.14 12.66 329.61 9884.00 94.60 38.00 8979.91 8913.91 1487.76 -744.94 5952043.57 686821.97 23.30 357.35 9923.00 90.60 40.80 8978.14 8912.14 1517.86 -720.22 5952074.27 686845.94 12.51 395.50 9962.00 89.70 42.90 8978.04 8912.04 1546.91 -694.20 5952103.95 686871.22 5.86 434.00 9999.00 90.60 46.10 8977.94 8911.94 1573.29 -668.27 5952130.98 686896.48 8.98 470.76 10029.00 88.80 50.30 8978.10 8912.10 1593.28 -645.91 5952151.52 686918.33 15.23 500.72 10060.00 88.20 53.50 8978.91 8912.91 1612.40 -621.53 5952171.24 686942.23 10.50 531.70 10089.00 88.10 58.00 8979.84 8913.84 1628.71 -597.58 5952188.14 686965.77 15.51 560.57 10121.00 85.00 61.90 8981.77 8915.77 1644.70 -569.94 5952204.81 686993.00 15.55 592.12 10152.00 87.60 63.70 8983.77 8917.77 1658.84 -542.43 5952219.63 687020.15 10.19 622.40 10182,00 90.70 67.50 8984.22 8918.22 1671.23 -515.12 5952232.69 687047.14 16.34 651.41 10216.00 92.20 73.20 8983.35 8917.35 1682.65 -483.12 5952244.91 687078.84 17.33 683.47 10246.00 94.00 77.70 8981.73 8915.73 1690.18 -454.14 5952253.15 687107.63 16.13 710.73 10275.00 94.20 82.00 8979.66 8913.66 1695.27 -425.67 5952258.96 687135.95 14.81 736.06 10309.00 93.00 87.20 8977.52 8911.52 1698.46 -391.90 5952262.99 687169.63 15.67 764.31 10343.00 94.50 93.90 8975.29 8909.29 1698.14 -358.00 5952263.51 687203.53 20.15 790.46 10390.00 95.30 102.30 8971.27 8905.27 1691.55 -311.68 5952258.08 687250.00 17.89 822.31 10421.00 94.40 101.30 8968.65 8902.65 1685.23 -281.44 5952252.52 687280.38 4.33 841.83 10469.00 91.00 92.90 8966.39 8900.39 1679.32 -233.91 5952247.79 687328.04 18.86 875.05 10504.00 94.70 87.20 8964.65 8898.65 1679.29 -198.98 5952248.63 687362.96 19.40 902.18 10537.00 96.90 83.40 8961.31 8895.31 1681.97 -166.26 5952252.13 687395.60 13.25 929.29 10579.00 96.10 88.60 8956.55 8890.55 1684.88 -124.65 5952256.07 687437.12 12.45 963.46 10625.00 93.90 92.50 8952.54 8886.54 1684.44 -78.84 5952256.77 687482.93 9.71 998.78 10667.00 90.00 99.90 8951.11 8885.11 1679.91 -37.15 5952253.28 687524.72 19.90 1028.33 10697.00 88.50 104.80 8951.50 8885.50 1673.49 -7.85 5952247.60 687554.16 17.08 1047,06 10743.00 93.70 109.00 8950.62 8884.62 1660.13 36.13 5952235.34 687598.46 14.53 1072.83 10773.00 95.80 110.10 8948.14 8882.14 1650.13 64.30 5952226.04 687626.87 7.90 1088.43 10802.00 94.80 115.40 8945.46 8879.46 1638.97 90.92 5952215.55 687653.76 18.52 1102.09 10831.00 89.90 114.60 8944.27 8878.27 1626.72 117.17 5952203.96 687680.30 17.12 1114.79 10860.00 87.00 109.00 8945.05 8879.05 1615.96 144.07 5952193.88 687707.46 21.74 1128.93 10872.00 87.00 109.00 8945.68 8879.68 1612.06 155.41 5952190.26 687718.89 0.00 1135.28 ALASI~A OIL AND GAS CONSERVATION CO~L~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Stephen L. Ward CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 02-33A BP Exploration (Alaska) Inc. Permit No: 200-123 Sur Loc: 626'SNL, 861'EWL, Sec. 36, T1 IN, R14E, UM Btmhole Loc. 1013'NSL, 1355'EWL, Sec. 25, T11N, R14E, UM Dear Mr. Ward: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ 2. ~ day of August, 2000 dlf/Enclosurcs CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . ' ST^T ^ s4' ,,. ^.. CO.S .V^T,O. PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Ddll [] Reddll 11 b. Type of well [] Exploratory [] Stratigraphic Test [] Development ~il [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. RKB = 66' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 626' SNL, 861' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 8' SNL, 359' EWL, SEC. 36, T11N, R14E, UM 02-33A Number 2S100302630-277 At total depth 9. Approximate spud date 1013' NSL, 1355' EWL, SEC. 25, T11N, R14E, UM 08/23/00 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 028309, 1355' MDI No Close Approach 2560 11189' MD / 8885' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9115' MD Maximum Hole Angle 98 ° Maximum surface 2515 psis, At total depth (TVD) 8800' / 3395 psig, 18. Casing Program Specifications Setting Depth ?.ize Tr,17 I~gtl om Quaqtitv of Cement Hole Casin(] Wei(]ht Grade Couolin(] Len(]th MD TVD MD TVD finclude sta(]e data) 3" 2-3/8" 4.6# L-80 FL4S 3029' 8160' 8042' 11189' 8885' 118 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical 91 939029 feet feet Plugs (measured) . Effective depth: measured 9338 feet Junk (measured) · ~ "' % ~ ~'~ true vertical 9083 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 11 yds Arcticset 110' 110' Surface 3408' 9-5/8" 1920 cuft CS III, 348 cu ft 'G', Top Job 89 cu ft CS II 3478' 3477' Intermediate Production 8551' 7" 792 cu ft Class 'G' 8615' 8453' Liner 1071 5" 138 cu ft Class 'G' ~,-,~ ~, ,~?~ ~,"~ ;~.~.t8 - 9384' 8184' - 9124' , ,,.. ',..., ' !., ~- ;, '., Perforation depth: measured 9226' - 9242' ,...:= true vertical 8984' - 8998' Anchorsge 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: Steve Ward, 564-5545 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the forf)J;loing is true and co.rrect to_,~the best of my knowledge Signed Steve Ward ~ ,~'~///'~ Title C ~ Drilling E~?neer Permit Number APl Number Approval Date. See cover letter ~O - i ~ 50-029-22214-01v' . ~"/~-"~/¢0 for other requirements Conditions of Approval: Samples Required [] Yes ~NIo Mud Log Requirec~ [] Yes ~ No Hydrogen Sulfide Measures ,J~Yes [] No Directional Survey Required ,~f'es [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3500 psi for CTU Other: by order of Approved By ORIgINAl .~Mt~r~ m~, Commissioner the commission Date Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate DS 2-33A Potential Drilling Hazards POST ON RIG No H2S production from this well. BHP: 3395 psi @ 8800' ss (7.4 ppg EMW), BHT 190 °F (BHP run on 11/29/99). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2515 psi. Gas saturated intervals are expected in build section. The drilling fluid will be 8.5 ppg Flopro which will overbalance the formation by 500 psi. Past experience has shown that the formation is able to withstand this overbalance plus the high ECD due to slimhole drilling. There is 1 possible fault that will be intersected in the horizontal section. The fault is anticipated to have approximately 15' of throw. Precautions should be taken for handling lost circulation. August 9, 2000 DS 2-33A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate and produce. Intended Procedure: Service CTU: Cement squeeze and plugback the existing completion to - 9115' md. Underream cement as necessary to leave TOC at 9115'. Mill window in 5" casing at -9115' md. Drill 10' of formation with 8.5 PPg CT Drilling Rig: Directionally drill 3" x 1900' horizontal well to access Lower Romeo reserves. Build angle to -91° at TD. Run and cement 2-3/8" liner to TD. Perforate selected intervals. · Place well on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. August 9, 2000 PHILLIPS Alaska, Inc. WELLPATH DETAILS Plan #2 02-33A 500292221401 Pezent Weltpath: 02-33 Tie on MD: 9115.00 Ve~cal Set,on OHgln: Slot - (0.00.0.00) VertdcalSec#onAngle: 51.00°' Rig: CDR Depth Reference: 0233 ANNOTATIONS No. TVD MD Annotminn I 8718,27 9000.80 Tie-in Point 2 8818,~3 9t 18.00 Kick*oS Point 3 8917.00 9~18,40 1 4 8917.00 9467.6O 2 5 8~17.00 9774.6O 3 7 8911.g3 I03~5.6O 5 8 8885.47 10~70.OO 6 iNTEQ '~ LEC~ND REFERENCE INFORMATION 2000--i Co-ordinate (N/E) Reference: Wellhead: 02-33, True North --i Vertical (TVD) Reference: Field - Mean Sea _evel Section (VS) Reference: Slot- (0.00,0.00) i ~ ~ i 102-33A T4OTD I Measured Depth Reference: 02-33 68.0 above Mean Sea Level Calculation Method: Minimum Curvature .......... ..-;i : ii ~i [~ m-3aA Po . .....,6 .6 ~:~ o~T.~o 1500 ........................................................................................................... ' : ' ' 8885.OO 1705.~0 13.31 02-33R T3 ~ 3913.OO 1704.35 441.82 0~-33A T2 3917.OO 109~.51 437.13 02-33A T1 8400--'i '"i · : i ' I -1500 -1000 -500 0 500 1000 1500 · 'i': : i : i I : : Wes~(-)/East(+) [500ft/in] "? ............................. ! ....................... : ...................... : ......... i .......... : ..................... "' i ' i 1~\ " i i :. !1~~ : 102-33AT3 I 102-33AT40TD |: IPlan~202-33A I sooo..:.i---...i~ ........... : .............................................. : ........... i ................................... -I' : .................................. ...L....~ ........... .,, .......... + .......... ~ .......... ~ .......... .~. .......... ~ .......... i ........... ~.~o2.:= -200 0 200 400 600 800 1000 1200 1400 1600 Vertical Section at 51,00° [200fi/in] Prepared by Baker Hughes INTEQ Proposal Calculations HUGHES Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: PHILLIPS Alaska~ Inc. Vertical Sect. Plane: 51.000 TRUE Job No: 0 Field: Prudhoe Bay Unit Mag. Declination: 27.182 AFE No: 0 Well: 2-33A Plan g2 Grid Correction: 1.430 API No: ~0-029-22214-01 Rig: CDR Total Correction: 25.752 BHI Rep: Surface Location Dip: 80.716 Job Start Date: 0-Jan-00 X: 687604.2 RKB Height: 68.000 Job End Date: 0-Jan-00 Y: 5950574.7 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section ,~ Comments (de~) (de~) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 9000.00 29.72 327.00 8718.27 775.85 -603.34 5951335.27 686981.71 0.00 19.38 0.00 0.00 0.00 Tie-in Point 9100.00 29.04 326.20 8805.41 816.81 -630.34 5951375.54 686953.70 0.79 24.17 -150.36 -0.68 -0.80 9115.00 28.96 326.20 8818.53 822.85 -634.38 5951381.48 686949.50 0.53 24.83 -180.00 -0.53 0.00 Kick-off Point 9120.00 30.46 326.20 8822.87 824.91 -635.76 5951383.51 686948.07 30.01 25.05 0.00 30.01 0.00 9130.00 33.46 326.20 8831.35 829.31 -638.71 5951387.83 686945.02 30.01 25.53 0.00 30.01 0.00 9140.00 36.46 326.20 8839.55 834.07 -641.89 5951392.51 686941.72 30.01 26.05 0.00 30.01 0.00 9150.00 39.46 326.20 8847.43 839.18 -645.32 5951397.54 686938.17 30.01 26.61 0.00 30.01 0.00 9160.00 42.46 326.20 8854.98 844.63 -648.96 5951402.89 686934,39 30.01 27.20 0.00 30.01 0.00 9170.00 45.47 326.20 8862.18 850.40 -652.82 5951408.56 686930.38 30.01 27.83 0.00 30.01 0.00 9180.00 48.47 326.20 8869.00 856.47 -656.89 5951414.53 686926.17 30.01 28.50 0.00 30.01 0.00 9190.00 51.47 326.20 8875.43 862.83 -661.15 5951420.79 686921.75 30.01 29.19 0.00 30.01 0.00 9200.00 54.47 326.20 8881.45 869.47 -665.59 5951427.31 686917.15 30.01 29.91 0.00 30.01 0.00 9210.00 57.47 326.20 8887.05 876.35 -670.20 5951434.07 686912.37 30.01 30.66 0.00 30.01 0.00 9220.00 60.47 326.20 8892.20 883.47 -674.97 5951441.07 686907.42 30.01 31.44 0.00 30.01 0.00 9230.00 63.47 326.20 8896.90 890.81 -679.88 5951448.28 686902.33 30.01 32.24 0.00 30.01 0.00 9240.00 66.47 326.20 8901.13 898.33 -684.92 5951455.68 686897.11 30.01 33.06 0.00 30.01 0.00 9250.00 69.47 326.20 8904.88 906.04 -690.07 5951463.25 686891.76 30.01 33.90 0.00 30.01 0.00 9260.00 72.47 326.20 8908.14 913.89 -695.33 5951470.98 686886.31 30.01 34.76 0.00 30.01 0.00 9270.00 75.48 326.20 8910.90 921.88 -700.68 5951478.83 686880.76 30.01 35.63 0.00 30.01 0.00 9280.00 78.48 326.20 8913.16 929.97 -706.10 5951486.78 686875.14 30.01 36.51 0.00 30.01 0.00 9290.00 81.48 326.20 8914.90 938.15 -711.57 5951494.83 686869.46 30.01 37.40 0.00 30.01 0.00 ~!i!i,i-~ ~! ? ~,.i: 9300.00 84.48 326.20 8916.12 946.40 -717.09 5951502.93 686863.74 30.01 38.30 0.00 30.01 0.00 9310.00 87.48 326.20 8916.82 954.69 -722.64 5951511.08 686857.99 30.01 39.21 0.00 30.01 0.00 9318.40 90.00 326.20 8917.00 961.67 -727.31 5951517.94 686853.14 30.01 39.97 0.00 30.01 0.00 9325.00 90.00 327.00 8917.00 967.18 -730.95 5951523.36 686849.37 12.13 40.61 89.99 0.00 12.13 9350.00 90.00 330.03 8917.00] 988.50 -744.00 5951544.34 686835.79 12.131 43.88 89.99 0.00 12.13 i 9375.00 90,00 333.06 8917.00 1010.47 -755.91 5951566.02 686823.34 12.13 48.46 89.99 0.00 12.13 9400.00 90.00 336.10 8917.00 1033.05 -766.64 5951588.32 686812.05 12.13 54.33 89.99 0.00 12.13 9425.00 90.00 339.13 8917.00 1056.16 -776.16 5951611.19 686801.95 12.13 61.47 89.99 0.00 12.13 Me. as. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. CY) De[~. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 9450.00 90.00 342.16 8917.00 1079.75 -784.45 5951634.56 686793.08 12.13 69.88 89.99 0.00 12.13 .... 2 , 8917.00 1096.50 -789.50 5951651.18 686787.61 12.13 76.49 9467.50 90.00 '~,4,~ 81 89.99 0.00 12.13 2 9475.00 90.00 345.181 8917.00 1103.74 -791.48 5951658.36 686785.46 12.06 79.51 90.01 0.00 12.06 9500.00 90.00 348.20 8917.00 1128.06 -797.23 5951682.54 686779.10 12.06 90.35 90.01 0.00 12.06 9525.00 90.00 351.211 8917.00 1152.66 -801.70 5951707.02 686774.02 12.06 102.35 90.01 0.00 12.06 9550.00 90.00 354.23 8917.00 1177.45 -804.86 5951731.72 686770.24 12.06 115.50 90.01 0.00 12.06 9575.00 90.00 357.24 8917.00 1202.38 -806.72 5951756.60 686767.76 12.06 129.74 90.01 0.00 12.06 9600.00 90.00 0.26 8917.00 1227.37 -807.27 5951781.57 686766.59 12.06 145.04 90.01 0.00 12.06 9625.00 90.001 3.27 8917.00 1252.36 -806.50 5951806.56 686766.73 12.06 161.36 90.01 0.00 12.06 9650.00 90.00 6.281 8917.00 1277.27 -804.42 5951831.52 686768.19 12.06 178.66 90.01 0.00 12.06 9675.00 90.00 9.30 8917.00 1302.03 -801.03 5951856.36 686770.96 12.06 196.88 90.01 0.00 12.06 9700.00 90.00 12.31! 8917.00 1326.59 -796.35 5951881.03 686775.04 12.06 215.97 90.01 0.00 12.06 9725.00 90.00 15.331 8917.00 1350.86 -790.37 5951905.44 686780.40 12.06 235.89 90.01 0.00 12.06 9750.00 90.00 18.34 8917.00 1374.79 -783.14 5951929.54 686787.04 12.06 256.57 90.01 0.00 12.06 9774.04 90.00 21.24 8917.00 1397.40 -775.00 5951952.35 686794.61 12.06 277.12 90.01 0.00 12.06 3 9800.00 90.00 24.37 8917.00 1421.33 -764.94 5951976.52 686804.07 12.08 300.01 90.00 0.00 12.08 9825.00 90.00 27.39 8917.00 1443.82 -754.02 5951999.28 686814.42 12.08 322.64 90.00 0.00 12.08 9850.00 90.00 30.41 8917.00 1465.70 -741.94 5952021.46 686825.95 12.08 345.80 90.00 0.00 12.08 9875.00 90.00 33.43 8917.00 1486.92 -728.73 5952043.00 686838.64 12.08 369.42 90.00 0.00 12.08 9900.00 90.00 36.45 8917.01 1507.41 -714.41 5952063.84 686852.44 12.08 393.45! 90.00 0.00 12.08 9925.00 90.00 39.47 8917.01 1527.12 -699.03 5952083.92 686867.32 12.08 417.80 90.00 0.00 12.08 9950.00 90.00 42.49 8917.01 1545.99 -682.64 5952103.20 686883.24 12.08 442.41 90.00 0.00 12.08 9975.00 90.00 45.51 i 8917.01 1563.97 -665~27 5952121.60 686900.15 12.08 467.23: 90.00 0.00 12.08 10000.00 90.00 48.53 8917.01 1581.01 -646.99 5952139.10 686918.01 12.08 492.16] 90.00 0.00 12.08 ~.~ ~ ~! :~ .~ ~'~ ~a~'= ~'~ 10025.00 90.00 51.55 8917.01 1597.07 -627.82 5952155.62 686936.76 12.08 517.16 90.00 0.00 12.08 10050.00 90.00 54.57 8917.01 1612.09 -607.85 5952171A4 686956.36 12.08 542.14 90.00 0.00 12.08 10075.00 90.00 57.59 8917.01 1626.04 -587.10 5952185.60 686976.75 12.08 567.04 90.00 0.00 12.08 10100.00 90.00 60.61 8917.01 1638.88 -565.65 5952198.97 686997.87 12.08 591.78 90.00 0.00 12.08 10125.00 90.00 63.63 8917.01 1650.57 -543.56 5952211.21 687019.67 12.08 616.31 90.00 0.00 12.08 10150.00 90.00 66.65 8917.01! 1661.08 -520.88 5952222.28 687042.08 12.08 640.55 90.00 0.00 12.08 10175.00 90.00 69.67 8917.01i 1670.38 497.67 5952232.15 687065.05 12.08 664.44 90.00 0.00 12.08 10200.00 90.00 72.69 8917.01 1678.44 -474.01 5952240.80 687088.50 12.08 687.90 90.00 0.00 12.08 10225.00 90.00 75.71 8917.01 1685.25 449.96 5952248.21 687112.37 12.08 710.87 90.00 0.00 12.08 10250.00 90.00 78.73 8917.01 1690.78 -425.58 5952254.35 687136.60 12.08 733.30 90.00 0.00 12.08 10275.00 90.00 81.75 8917.02 1695.02 400.95 5952259.20 687161.13 12.08 755.11 90.00 0.00 12.08 10292.00 90.00 83.80 8917.02 1697.16 -384.09 5952261.76 687177.93 12.08 769.56 90.00 0.00 12.08 4 10300.00 90.88 84.20 8916.95 1697.99 -376.13 5952262.79 687185.86 12.07 776.27 24.66 10.97 5.04 10325.00 93.62 85.46! 8915.97 1700.24 -351.25 5952265.66 687210.68 12.07 797.02 24.67 10.96 5.04 10350.00 96.36 86.731 8913.80 1701.94 -326.41 5952267.97 687235.47 12.07 817.40 24.72 10.96 5.07 10365.00 98.00 87.50 8911.93 1702.69 -311.55 5952269.09 687250.31 12.07 829.42 24.83 10.95 5.12 5 10400.00 97.34 90.28 8907.25 1703.36 -276.87 5952270.63 687284.96 8.09 856.79 103.25 -1.88 7.94 , 10450.00 96.37 94.24 8901.28 1701.40 -227.28 5952269.91 687334.59 8.09 894.10 103.62 -1.94 7.91 10500.00 95.37 98.18 8896.16! 1696.02 -177.84 5952265.76 687384.14 8.09 929.13 104.10 -2.00 7.88 10550.00 94.35 102.11 8891.93~ 1687.24 -128.81 5952258.21 687433.38 8.09 961.71 104.50 -2.05 7.86 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (det~) (ft) Lat. (Y) De[,. (X) Lat. (Y) De}}. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) ,. ..... 10600.00 93.30 106.03 8888.59 1675.12 -80.43 5952247.29 687482.04 8.09 991.68 104.83 -2.09 7.84 10650.00 92.24 109.94 8886.17 1659.70 -32.94 5952233.07 687529.91 8.09 1018.89 105.09 -2.12 7.82 10670.00 91.81 111.50 8885.47 1652.63 -14.24 5952226.46 687548.77 8.09 1028.97 105.28 -2.14 7.81 6 10699.46 90.00 109.99 8885.00 1642.20 13.30 5952216.72 687576.56 8.00 1043.81 - 140.25 -6.16 -5.12 7 10750.00 90.00 105.92 8885.00 1626.62 61.37 5952202.35 687625.01 8.06 1071.36 -90.00 0.00 -8.06 10800.00 90.00 101.89 8885.00 1614.61 109.90 5952191.55 687673.82 8.06 1101.51 -90.00 0.00 -8.06 10850.00 90.00 97.86 8885.00 1606.04 159.15 5952184.21 687723.26 8.06 1134.39 -90.00 0.00 -8.06 10900.00 90.00 93.83 8885.00 1600.95 208.88 5952180.36 687773.11 8.06 1169.84 -90.00 0.00 -8.06 10950.00 90.00 89.80 8885.00 1599.37 258.84 5952180.02 687823.09 8.06 1207.67 -90.00 0.00 -8.06 11000.00 90.00 85.77 8885.00 1601.30 308.79 5952183.20 687872.98 8.06 1247.71 -90.00 0.00 -8.06 11050.00 90.00 81.74 8885.00 1606.75 358.49 5952189.88 687922.52 8.06 1289.75 -90.00 0.00 -8.06 11100.00 90.00 77.71 8885.00 1615.67 407.67 5952200.03 687971.47 8.06 1333.59 -90.00 0.001 -8.06 11150.00 90.00 73.67 8885.00 1628.02 456.11 5952213.59 688019.59 8.06 1379.01 -90.00 0.00 -8.06 11188.98 90.00 70.53 8885.00 1 640.00 493.20 5952226.48 688056.37 8.06 1415.37 -90.00 0.00 -8.06 TD DS 2-33A CHOPOSED CT HORIZONTAL SIDETRACK ,3-1/2" Otis FMX TRSSSV @ 2200' 3-1/2",9.2# 13 Cr Production Tubing 8- Camco MMG GLMs Otis 7 x 5-1/2" BWD Packer @ 8212' 3-1/2" TT @ 8327' Top of 2-3/8" Liner @ +/- 8160' Nipple @ 8283' Top of 5" 13 Cr Liner @ 8313' 7" Casing to 8629' ,p of P&A Cement @ 9115' Mill Window through 5" Casing @ 9115' 2-3/8" FL4S 4.6# Liner Cemented & Perforated 5" Shoe @ 9384' 5" Liner & Perfs P&A'd with 17 ppg Cement ~.,....~ 3" Open hole TD @ 113,00 CDR1 Drilling Wellhead Detail I ~ CT Injector Head I .Annular BOP (Hydril),7-1/16" ID Annular BOP (Hydril),7-1/16" ID II 5,000 psi working pressure Ram Type Dual Gate BOPE 7-1/16" ID with ~ Pipe& Blind/Shear Rams Choke Line to dual HCR~ ~ ~....__M~ual Valves Drilling spo,o,I 7-1/16", 5M . Kill Line 7-1/16" ID with Slip & XO spool as necessar~ Manual Master Valve Hanger II 9-5/8" Annulus 13-3/8" Annulus STATE OF ALASKA i. Type of Request: Bil Abandon [] Suspend [] Alter Casing ~ [] Repair Well [] Change Approved prO~ram [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 626' SNL, 861' EWL, SEC. 36, T11N, R14E, UM At top of productive interval 8' SNL, 359' EWL, SEC. 36, T11N, R14E, UM At effective depth 284' NSL, 169' EWL, SEC. 25, T11 N, R14E, UM At total depth 305' NSL, 155' EWL, SEC. 25, T11N, R14E, UM [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back for Sidetrack Type of well: Ifil Development r-! Exploratory I-I Stratigraphic r"l service 6. Datum Elevation (DF or KB) RKB = 66' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 02-33 9. Permit Number 191-116 10. APl Number 50- 029-22214-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9390 feet true vertical 9129 feet Effective depth: measured 9338 feet true vertical 9083 feet Casing Length Structural Conductor 110' Surface 3408' Intermediate Production 8551' Liner 1071' Plugs (measured) Junk (measured) ORIGINAL Size Cemented 20" 11 yds Arcticset 9-5/8" 1920 CUft CS III, 348 cu .ft ~', Top Job 89 cuff CS II 7" 792 cuft Class 'G' 5" 138 cu ft Class 'G' ' MD TVD 110' 110' 3478' 3477' 8615' 8453' 8313'-9384' 8184'-9124' Perforation depth: measured 9226' - 9242' true vertical 8984' - 8998' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, 13Cr80 to 8327' Packers and SSSV (type and measured depth) Otis 'BWD' packer at 8212'; 3-1/2" Otis 'FMX' TRSV at 2200' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation August 16, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Numbec Steve Ward, 564-5545 15. [] Detailed Operations prOgram [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: rerrie Hubble, 564-4628 17. I hereby certify that the. forgoing is true and correct to the best of my knowledge Signed Steve Ward.~'- ~ ~'~ Title CT Drilling Engineer Conditions of Approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission Date Approval Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE / CHECK NO. H 172504 p./o=/oo {po,7= o4 I 'FiRsT:~'~,TIOi~:BAN K::j~F ASh~ND i" !:'. ........:AN:iAF~..!i, dATF..i.~.:.. ........ . ........ · . · ........ '"i.%:.-:,.:.:: C..I~EVEi_,~,~D, dHio ..... i:::::.:.;; .::':" :::.:}1:: . '. '.i:'::? *:::;!':i{ '.!¥ :..: .:. .:..........: ... :.:.:..:..::::; ...' ......... :i:i:::"56-389 -" ." ,-,.:.....::: 412 AY ...' :..... '...:.:: . ':{?:":' '"::!ii:ii':':?/:.:: :.:i;;: ~: {::!::?:!:~.~:i?' .{::i,::::::' "ii...:.::' :i;i.:":' ':i:.! '":::;:i::i:i:!?: DATE "{:.:::;:AMOUNT I' 08/02/00 l: I $100; O0 ii{i:.::: {'.:"}::;: : ..:':-':.:::' }:.:....:::::' NO.T:r::~VALID AFTER 120 D,~,YS .. ' ... :. >--. ..1}:- {{. ':.::' .... i:i:ii:i:i,' i:.'i. :i: ::::': .' ':.: ':::.': :::i ...:.. . i:i.' :: '.:':.:':' ". .: ' .. 2: . -:'"' '.. '" .' 'i' . ".::." . ':: ....' :'"'::: ':. ANCHORA(~E AK c~9501 ," ], ? i? 50 h," ,:O t, ]. i?0 3, Rq5,: OORht, l,q," WELL PERMIT CHECKLIST FIELD & POOL ~:~ WELL NAMEO~- ;~/~ PROGRAM: exp ADMINISTRATION DATE ENGINEERING )R DATE N TCLASS ~D/l-- 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 ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet:regulation ................ 26. BOPE press rating appropriate; test to ~(-'-'-%(,..~ 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 V~'redrll serv wellbore seg ann. disposal para req ON/OFF SHORE GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... Y(~) 31. Data presented on potential overpressure zones ....... ~ 32. Seismic analysis of shallow gas zones .......... '. ".: [~/ Y N 33. Seabed condition surveY (if.off-shore) .......... ..~ ./~ r, Y N 34. Contact name/phone for weekly progress reports/~tory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and IE) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: L41C/Annular COMMISSION: W " ' Comments/Instructions: c:~nsoffiCe\wordian\diana\checklist (rev. 02117100) I§ 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 APPEN. DIXi No special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/05/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/01 73871 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT.FT STOP.FT STEP.FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 9129.0000: Starting Depth 10872.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: BP Alaska, WELL: 02-33A FIELD: Prudhoe Bay Unit LOCATION: 626' FNL, 861' FEL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 14-Sep-00 API NYUMBER: 502092221401 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 36 : Section TOWN.N liN : Township RANG° 14E : Range PDAT. MSL : Permanent Datum EPD oF 0 : Elevation Of Perm. Datum LMF o RKB : Log Measured from FAPD.F 66 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 66 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 02-33A was kicked off @ 9129' MD (8832' SSTVD) on Run 1. (5) Well 02-33A was drilled to TD 10883' MD (8880' SSTVD) on Run 4. Data on Run 4 was squeezed by 11' after a final tie-in resulting in a final TD of 10872' MD (8880' SSTVD). (6) The interval from 10842' MD (8878' SSTVD) to 10872' MD (8880' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Exploration (Schlumberger, 09/15/00). (8) Final Tie-in adjust TD to 10872' MD (8880' SSTVD). (9) A Magnetic Declination correction of 27.11 degrees has been applied to the Directional Surveys° MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 22.40 ft. 17.81 ft. 2 22.92 ft. 18.33 ft. 3 22.92 ft. 18.33 ft. 4 22.96 ft. 18.37 ft. 5 22.97 ft. 18.38 ft. CURVE SHIFT DATA BASELINE, MEASURED, 9133 06, 9138 53, 9194 95, 9199 84, 9211 65, 9215 39, 9222 01, 9238 25, 9242 29, 9261 57, 9279 40, 9358 09, 9364 59, 9379 56, 9480 41, 9494 35, 9521 69, 9738 76, 9778 77, 9827 53, 9883 86, 9982 64, 10023.2, 10135.1, 10159.3, 10380.3, 10385.1, 10411.0, 10419.9, 10430.6, 10442.6, 10450.7, 10468.9, 10507.2, 10513.8, 10540 3, 10544 7, 10696 4, 10711 6, 10772 1, 10776 5, 10801 8, EOZ END 9130 18, 9135 65, 9191 21, 9197 54, 9209 05, 9212 51, 9218 55, 9233 65, 9237 68, 9256.39, 9277 10, 9353 48, 9361 71, 9373 80, 9472 92, 9488 30, 9519.39, 9737.03, 9777.62, 9827.82, 9884.15, 9984.65, 10027.3, 10132 5, 10152 4, 10374 8, 10379 9, 10401 2, 10408 4, 10421 9, 10437 2, 10443 8, 10462 6, 10502 6, 10507 5, 10537 7, 10540 3, 10692 6, 10703 0, 10758 9, 10763 8, 10795.5, DISPLACEMENT -2.87891 -2.87891 -3.74219 -2.30273 -2.59082 -2.87891 -3.4541 -4.60547 -4.60645 -5.18066 -2.30273 -4.60645 -2.87891 -5.75684 -7.48438 -6.04492 -2.30273 -1.72754 -1.15137 0.288086 0.288086 2.01562 4.03027 -2.59082 -6.9082 -5.46875 -5,18164 -9.78711 -11.5137 -8.63574 -5.46973 -6.9082 -6.33203 -4.60547 -6.33301 -2.59082 -4.31836 -3.74219 -8.63477 -13.2412 -12.666 -6.33301 BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 118 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Alaska WN 02-33A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 15-Sep-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXl2 0.0 ROPSl2 0.0 2 ROP * FORMAT RECORD (TYPE% 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 F/HR 4 Total Data Records: 42 Tape File Start Depth = 9129.000000 Tape File End Depth = 10872.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Length 4 4 8 **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: 51 records... 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Alaska WN 02-33A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!~! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 ROPS 0.0 2 ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Size 4 4 Length 4 4 8 Total Data Records: 42 Tape File Start Depth = 9129.000000 Tape File End Depth = 10872.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 51 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/07/01 73871 01 **** REEL TRAILER **** MWD 01/05/07 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes [] Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GR ROP 9129.0000 25.5605 45.8124 9129.5000 38.0012 30.8811 9200.0000 100.7239 23.7345 9300.0000 44.7764 31.9040 9400.0000 48.9602 59.1916 9500.0000 51.4350 51.0968 9600.0000 43.8368 88.2567 9700.0000 44.9707 73.6524 9800.0000 46.6240 43.6402 9900.0000 52.3026 116.5522 10000.0000 46.7408 74.7006 10100.0000 116.0834 31.3962 10200.0000 125.4361 9.5719 10300.0000 124.3244 28.5650 10400.0000 132.1969 35.9659 10500.0000 82.1346 98.6006 10600.0000 52.5260 76.4821 10700.0000 61.5319 96.5505 10800.0000 115.2384 54.1826 10872.0000 -999.2500 -999.2500 Tape File Start Depth = 9129.000000 Tape File End Depth = 10872.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet [] Tape Subfile 3 is type: LIS DEPTH 9129 9129 9200 9300 9400 9500 9600 9700 9800 9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10872 GRAX 0000 14.1550 5000 16.7940 0000 19.0560 0000 42.6180 0000 43.1830 0000 51. 6660 .0000 48.6500 .0000 46.0110 .0000 44.5030 .0000 51.4290 .0000 60.5410 .0000 119.1850 .0000 126.5460 .0000 139.7880 0000 136.9080 0000 28.9400 0000 56.0620 0000 77.5290 0000 152.5300 0000 -999.2500 ROPS -999.2500 -999 2500 45 7600 17 0190 41 9530 67 3710 74 2040 63.3240 43.0110 119.7660 15.5240 23.8940 14.2660 20.4920 42.3240 73.0220 156.9140 104.6020 64.7310 94.6470 Tape File Start Depth = 9129.000000 Tape File End Depth = 10872.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS