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Home My WebLink About202-105 Imagl )roject 'Well History File Cover ~ \o4~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. cio a- L Q 5 'Well History File Identifier Organizing (done) RES CAN .¡ Color items: y"Rescan Needed OVERSIZED (Scannable) 0 Two-Sided DIGITAL DATA ~ Diskettes, No. ~, 0 Maps: Other items scannable by large scanner 0 Grayscale items: Other, Norrype 0 0 0 Poor Quality Originals: Other: OVERSIZED (NonøScannable) 0 0 Logs of various kinds NOTES: 0 Other BY: BEVERLY ROBIN VINCENT SHER@INDY j DATE:~I ~7 Cftjsl V14tJ Project Proofing BY: BEVERLY ROBIN VINCENT SHE~INDY r , DATE:fV J:.7fY/SI .. I. + 10 Scanning Preparation ~ x 30 = 100 IM~ = TOTAL PAGES r¡ ¡) / ( / I DATE( "7 ðifrsl VV,J BY: BEVERLY ROBIN VINCENT SHER~~Y'NDY Production Scanning . ~ 0-.. "" D. ~ Stage 1 PAGE CDUNTFRDMSCANNED FILE: 7'. JJJv r~Q PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: PES - NO BEVERLY ROBIN VINCENT SHERY~INDY DATE: ~ ;;:::::,' b~1 VV\,i P BY: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY ISI DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS Due TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (iPI1Í\'id(li.11 PJ9" hl'n ". 1.11 ,~frN!1Í0n} ,<,r;..1,¡ni1i9 I:P/!:pII'10d) RESCANNED m< BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (clnllt.'1 12/1 O/02Rev3NOTScanned, wpd ~ ~ I. * t>J 2: Page 1 of 2 • • Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Tuesday, November 04, 20081:23 PM To: Maunder, Thomas E (DOA) Cc: Vazquez, Eleazar Subject: RE: D-226(202-105) ~,.,;;{4~j~~p_ ~~~:,` 'iil.i~ Tom, Eli, the Rig and I have discussed this operation, and I reviewed the DIMS reports. While the test was in the wellplan and the summary that was with the Drilling Permit, it was questioned when it came up in operations. The EZSV was set via a-line at that point in operations because the a-line unit was there running a GR log to confirm the kick off point in a shale. The Rig team questioned the 3500 psi test for these reasons: 1) Testing a casing string that was being pulled in the next operation for a near surface leak to gas did not make much sense. 2) The well was abandoned with a cement plug, and proving that the EZSV would hold a standing column of 9.8 brine following the cut and pull, without losses would prove it as a second mechanical barrier for us to split the stack and install the 9 5/8" pack-off. 3) If there was a leak on a 3500 psi test prior to a cut and pull of a casing string with a known leak, it would not have changed the next operation. With this reasoning, it was decided to test the EZSV and the new casing after cut and pull and re- complete operations. The oversight was that we did not include yourself in the loop of communication that eliminated a step that was in the operations summary attached with the permit. I will discuss this with the engineers. If you have any other questions, let me know. Thanks- Greg From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.govj Sent: Monday, November 03, 2008 10:41 AM To: Vazquez, Eleazar Cc: Hobbs, Greg S (ANC) Subject: D-22B (202-105) Eli, I am reviewing the completion report submitted for the abandonment of this well. When the EZSV was set at 4235' on August 6, I don't find that any pressure test of the wellbore was conducted. I thought it was standard practice to conduct such a test. A combo T x IA test was conducted on August 4, however tubing was pulled and a scraper run made. Am l missing something? Thanks in advance, 11 /4/2008 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ _.~ :Y~ `'~ ' t ut18 WELL COMPLETION OR RECOMPLETION REPORT AND LOCH ~.; , ,~.., ~ „~,. ~,ofnr~dSSiQra Ala~~~~~ :.~t .. , 1a. Well Status: ^ Oil ^ Gas ^ Plugged ~ Abandoned' ^ Suspended zoAAC 25.105 20AAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions Zero 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp., Susp., or Aba 8/10/2008 12. Permit to Dril{ Number 202-105 ~ 308-207 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Date Spudded 06/02/2002 „ 13. API Number 50-029-20737-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 06/09/2002 - 14. Well Name and Number: PBU D-22B FNL, 1692 1550 FEL, SEC. 23, T11 N, R13E, UM top of Productive Horizon: 2893' FNL, 124' FEL, SEC. 23, T11 N, R13E, UM g. KB (ft above MSL): 71.83' ~ Ground (ft MSL): 41.48' 15. Field /Pool(s): Prudhoe Bay Field / Pnidhoe Bay Total Depth: 4048' FNL, 807' FWL, SEC. 24, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) ~ 10856' 9010' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653460 y- 5959438 Zone- ASP4 10. Total Depth (MD+TVD) 10945' 9003' 16. Property Designation: ADL 028285 TPI: x- 655056 y- 5958128 Zone- ASP4 Total Depth: x- 656012 - 5956992 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, DIR, GR, RES, DEN, NEU 22. CASING, LINER ANO CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TvD HOLE AMOUNT Wr. PER FT. GRADE ToP BoTroM TDP BDTronn SIZE CEns=NnNC RECORD .PULLED ,~ " 1170 cu ft'G' 130 cu ft PF 'C' 1235 cu ft 4' 7 I L~0 / 13Cr80 23. Open to production or inject ion? ^ Yes ®No 24. T UBING RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; 4-1/2", 12.6#, 13Cr80 8567' - 8629' 8572' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 9422' P&A w/ 24.5 Bbls of Cement 4235' Set EZSV 4211' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24HouR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CARE DATA Conventional Cores Ac uired? ^ Yes ®No Sidewal l Core s A uired? ^ Yes ®No If Yes to either question, list formations and intervals coned (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 resuks_pg~,~~.071. ~~yt~~.r.~;tx~I ~' None J?!r/:D t•orm ~u-au/ Kevlseo u-rrzvo/ "~~~=~. tiONTINUED UN KEVERSE SIDE ~..~. 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND KERS ENCOUNTERED: 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals arxt formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 8808' 8499' None Shublik A 8848' 8532' Shublik B 8894' 8570' Shublik C 8914' 8586' Shublik D 8955' 8620' Sadlerochit /Zone 3 9146' 8777' Base CGL /Top Zone 2C 9239' 8848' Zone 26 / 23S6 9355' 8922' 22TS 9445' 8969' 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 forego' g is true and correct to the best of my knowledge. ~~~~ /~ 1~• '/ Signed Terrie Hubble Title Drilling Technologist Date ~ PBU D-226 202-105 308-207 PrePaBd ey NameMumber. Ter-ie Hubble, 564-4628 Well Number Drilling Engineer: Eleezar'Eli' VSzquez, 564-5918 Irosrnucnaus GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands arxl leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Prodrxang Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 showthe producing intervals for only the interval reported in ltem 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Mettrod of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 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 by20 AAC 25.071. ITEM 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 ~ ~ D-226, Well History (Pre Rig Sidetrack) Date Summary 6/22/2008 T/1/O = 100/60/10 Temp = S/I - MIT T Passed to 3000 psi, MIT IA Passed to 3000 psi (RWO prep) - Pressured up TBG to 3000 psi w/1.1 bbls 80° crude. TBG lost 100 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 140 psi in 30 min test. Bled TBG to 100 psi. Pressured up IA to 3000 psi w/6 bbls 80° crude. IA lost 60 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 80 psi in 30 min test. Fuid in flutes of conductor pipe 3 ft from surface appears to be drilling mud f Bled IA to starting pressure. Tagged wing, master and IA valves with info. FWHP's=260/0/0 AT DEPARTURE VALVES in following positions -and operator notified of positions and results. Lateral open, Wing closed, Swap closed, SSV closed, Master open, IA open, OA open. 6/22/2008 T/I/O = 100/80/10. Temp = SI. Assist fullbore during MIT-IA (RWO). OA FL near surface. Bled OAP from 10 psi to 0 psi in 30 sec, all gas. Maintained open bleed on OA during MIT IA to 3000 psi (No returns noticed, fluid or gas). Gravel in the conductor is at 6'. There is a 3' void with 3' of fluid in conductor, it appears to be 2' of grey water with 1' of drilling mud on the bottom. During the MIT IA the fluid level remained at the 3' level in the conductor. LRS bled WHP's. FWHP's = 260/0/0. 6/23/2008 T/I/O=SSV/0/0, Temp=S1. PPPOT-T (PASS), PPPOT-IC (FAIL). Pre CTD. PPPOT-T: External check installed. Stung into test port (500 psi), bled to 0 psi. Functioned LDS, all were tight but moving. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: External check installed. Stung into test port (50 psi), bled to 0 psi. Functioned LDS, 3 were tight but moving, all the rest moved freely. Re energized secondary Y seal with plastic (1.5 J sticks). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, Post 200 psi in 15 min, lost 200 psi in second 15 min (FAIL). Bled void to 0 psi. 6/24/2008 WELL S/I ON ARRIVAL. PULL PXN PRONG C~3 8607' SLM. PULL PXN PLUG BODY FROM 8609' SLM. DRIFT TO DEV C~ 9639' SLM W/ 2.5" CENT, SAMPLE BAILER (EMPTY). WELL LEFT SHUT IN NOTIFY DSO. 7/23/2008 Perform weekly BOP test. RIH with 2.5" BDN. Tagged TD down at 10870' ctmd. PU ~ 10865' ctmd. Paint flag at 10855' ctmd. Load well with 200 bbls of 1 % KCL followed by 125 bbls of diesel. Mix 24.5 bbls of 15.8 #/gal cement, begin laying in cement. 7124/2008 Finish laying in Cement, got 20 bbls in 40 bbl return tank. POOH, freeze protect 500' with 7 bbls 50/50 meth. Job Complete. 7/24/2008 WELL S/I ON ARRIVAL. RAN 2.50" CENT, S-BLR TO 9,433' SLM, STOP DUE TO DEVIATION, CURRENTLY POOH W/DRIFT. JOB IN PROGRESS. 7/25/2008 RAN 2.50" CENT. S-BLR W/ R-STEM TO 9,448' SLM. APPEARED TO STOP DUE TO DEVIATION NOT THE TOC (recovered 2/3 cup of unset cement). DRIFT TUBING W/ 3.70" CENT TO 9,426' SLM W/O ANY PROBLEMS (target 8,567' md). MIT-T (cement p&a) TO 1000PS1 W/ TRI-PLEX (Pass). WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS. 7/25/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 50/150/0 PSI. RIG UP ELINE WITH 3.65" POWER CUTTER. 7/26/2008 RIH WITH 3.6~" POWER CUTTER, CUT TUBING AT DEPTH 8567'. WELL SHUT IN ON DEPARTURE, MASTER-OPEN, IA/OA-OPEN TO GAUGES, SWAB CLOSED, DSO NOTIFIED. FINAL T/I/O = 180/100/0 PSI. JOB COMPLETE. 7/28/2008 T/I/O/= 50/400/0 Temp=Sl Circ well, CMIT Tx IA PASSED to 2230 psi (Pre RWO). Pumped 900 bbls 9.3 NaCI brine down tbg taking returns to the IA to open tops. Pumped 10 bbls diesel to freeze protect well. U-tube T/IA. CMIT TxIA. Pumped 4.1 bbls diesel down TBG to reach test pressure. T/IA lost 20/20 1st 15 mins, T/IA lost 20/20 2nd 15 mins, ran test an additional 15 mins, T/IA lost 10/0 3rd 15 mins for a total loss of 50/40 psi in 45 mins. Bled WHP to 0 psi. Final WHP's=0/0/0. 7/31/2008 T/I/0=0/0/0. Set 6" CIW J BPV, Pre-Rig. Page 1 of 1 BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12!22!1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: .8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date ~ From - To ~ Hours Task Code NPT ~ Phase Description of Operations 8/3/2008 00:00 - 13:00 13.00 MOB N WAIT PRE Release rig from DS 06-21 B at 00:00 hrs. Bridle up and prepare derrick & lay down. Perform Preventive Maintenace Wait on rig mats to be laid on road 13:00 - 17:00 4.00 MOB P PRE Move Satellite camp, Pit Module and Rig Shop to D Pad Lay mats, spread herculite, 17:00 - 00:00 7.00 MOB P PRE Move Rig from DS 06 to D Pad 8/4/2008 00:00 - 03:30 3.50 MOB P PRE Continue moving Rig from DS 06 to D Pad Spot Sub-structure over well 03:30 - 05:00 1.50 MOB P PRE Spot pit module, -Prepare and inspect derrick to raise. -Spot open top contingency tank along side of pits 05:00 - 06:00 1.00 MOB P PRE PJSM -Raise Derrick, Cattle chute and Hang Bridle Lines Acce t Ri ~ 06:00 hrs 8/4/2008_ 06:00 - 08:30 2.50 KILL P DECOMP Take On water in Pits and start mixing 8.5 NaCI brine -Prep Rig Floor for Workover operations -Prep Cellar For pumping kill fluid and testing IA x Tubing -Finish R/U of Rig 08:30 - 09:00 0.50 KILL P DECOMP Hold Pre-Spud Safety meeting 09:00 - 10:00 1.00 KILL P DECOMP R/U and Test IA x 4 1/2" Tubing to 2230 psi for 30 min. O.K. - hart Recorded Test 10:00 - 11:30 1.50 DHB P DECOMP Rig Up Lubricator on top of Tree and Test to 1000 psi -Pu 11:30 - 12:00 0.50 KILL P DECOMP Reverse Circ. out 15 bbls of Diesel from Tubing 12:00 - 14:00 2.00 KILL P DECOMP Circ. down tubing with 50 bbl soap sweep, followed by 130 degree seawater -210 gpm / 400 psi -Sweep Back at 213 bbls Stop Circ and Monitor well, 170 psi on tubing / 0 on IA 'Hold Pre-Spud Safety meeting with crew coming' 14:00 - 16:00 2.00 KILL P DECOMP R/U and U-Tube IA x T -After 1 hr 234 psi on Tubing and / 0 IA 16:00 - 21:00 5.00 KILL P DECOMP Reverse Circulate and balance fluid in well -Mud Weight reading from 9.5 ppg to 8.5 ppg pump until 8.5 ppg In /Out -Monitor well , Tubing 70 psi /zero on IA -Bleed of tubing to zero, bled back 4 bbls still "dribbling" -Pump 40 bbl down tubing of 8.7 ppg brine -Monitor well, zero on annulus and zero on IA -Monitor well for 10 min, well is dead 21:00 - 22:00 1.00 DHB P DECOMP Set TWC and test from below to 1000 si for 10 min. - ood test 22:00 - 23:00 1.00 WHSUR P DECOMP Nipple down tree -screw in hanger crossover, 7" NSCC Threads - 8 turns 23:00 - 00:00 1.00 BOPSU P DECOMP N/U BOP's 8/5/2008 00:00 - 01:00 1.00 BOPSU P DECOMP Finish nippling up BOP's -Set Bell Nipple and Riser Connect Kill and Choke Lines 01:00 - 04:30 3.50 BOPSU P DECOMP PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 psi High Printed: 9/2/2008 11:50:34 AM • • BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 8/5/2008 01:00 - 04:30 3.50 BOPSU P DECOMP -Witness of Test by waived by AOGCC rep Jeff Jones, test witnessed by BP WSL Dave Newlon, NAD Toolpusher Lenward Toussant Test to 250 psi low and 3500 psi high, each test held for 5 minutes and charted #1 Test -Top Pipe 3 1/2" x 6" Var.Rams, Choke Valves 1,2,3,16, HCR Kill valve, Upper IBOP #2 Test -Choke Valves 4,5,6, Manual Kill valve, TIW, Manual IBOP #3 Test -Choke Valves 7,8 & 9 #4 Test -Test Super Choke and Manual Choke to 250 psi low, 3000 high #5 Test -Choke Valves 10, 11 and 15 #6 Test -Choke Valve #14 #7 Test -Manual Valve on BOP stack #8 Test -Annular, Choke Line HCR Valve on Stack -Accumulator Test #10 Test -Blind Pipe Rams, Choke Valves 12 &13 No Failures, Good Test 04:30 - 06:30 2.00 DHB P DECOMP PJSM with NAD Drill Crew and DSM on pulling TWC -R/U Lubricator, test to 1000 psi, O.K. 06:30 - 08:00 1.50 PULL P DECOMP Make up a landing joint to the Top Drive and cross over to the tubing hanger threads. -Engage the tubing hanger. -Back out lock down screws. -Hanger pulled free at 125,000 - ree 1 0,000 SOW - 115,000 08:00 - 09:00 1.00 PULL P DECOMP Circulate Hole volume -500 gpm / 600 psi Monitor well for 10 minutes, Static 8.5 ppg In /Out 09:00 - 15:30 6.50 PULL P DECOMP Laydown tubing -200loints o Vam Ace, 2 GLM, 1 "x" Nipple -Cut off joint 4.28' 15:30 - 18:30 3.00 BOPSU P DECOMP PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 psi High -Witness of Test by waived by AOGCC rep Jeff Jones, test witnessed by BP WSL Mike Dinger, NAD Toolpusher Larry W urdemann -Recorded each test on chart -Test with 4" test joint -Test bottom set of Pipe Rams with 2 7/8" x 5" Var - est top se og pipe rams wd 3 1i2" x 6" VacRams ~~, Test Annular with 4" test joint -No Failures, Good Test 18:30 - 23:00 4.50 CLEAN P DECOMP Make u 9 5/8" casin scra er and Cross over -Pick up 18 jts of 4" HWDP -Pick up 144 jts of 4" Drill Pipe to 5155' No Problems RIH 23:00 - 00:00 1.00 CLEAN P DECOMP CBU -555 gpm / 1930 psi -PUW 110 k /SOW 110k rnnteo: arucwa ~ rau:av nrvi • • BP EXPLORATION `Operations Summary Report ILega1 Well Name: D-22 Common Well Name: D-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To ~ Hours Task Code NPT 8/5/2008 23:00 - 00:00 1.00 CLEAN P 00:00 - 0.00 CLEAN P 8/6/2008 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:30 1.50 BOPSU P 03:30 - 12:30 9.00 DHB ~ P Start: 8/4/2008 I Rig Release: 8/22/2008 Rig Number: 7ES Page 3 of 16 Spud Date: 12/22/1982 End: 8/22/2008 Phase Description of Operations DECOMP Monitorwell for 10 minutes, Static 8.5 ppg In /Out DECOMP POOH DECOMP POH standing back Drill Pipe and HWDP DECOMP Change Top set of pipe rams to 9 5/8" wi ig rew on es mg sand Changing Rams Test BOP's to 250 Low and 3500 psi High -Witness of Test by BP WSL Dave Newton, NAD Toolpusher Lenward Toussant -Recorded test on chart -Test with 9.625" test joint Good Test DECOMP Rig UP and Run E-Line Run 8.52 gauge ring and junk basket, unable to get by 48' Run 8.25" Gauge Ring and Junk Basket to 4500', no problen -Run in with CCU GR / 9 5/8 EZSV, set EZSV at 4235' -RIH and shoot 5 strand String Shot ~ collar located at 2088' ire me and 12:30 - 16:00 3.50 CLEAN P DECOMP RIH with Bit Sub and 8 1/2" bit to displace well to 9.8 ppg brine - Picking up DP 1 x 1 16:00 - 17:00 1.00 CLEAN P DECOMP Displace to 9.8 Brine 17:00 - 19:30 2.50 CLEAN P DECOMP POH 19:30 - 22:00 2.50 FISH P DECOMP P/U String Cutter and RIH - to -RIH into hole slow as per faker Service Rep. - P/U stand, M/U Top Drive., Establish Circulation - Locate Collar ~ 2088 - P/U 16' ~ 2072' - Up wt 73K and DN wt 73k As Soon as Cut was made, started taking returns into cellar via the 20" x 13 3 8" Annu us - too oumoina an a well balance out 22:00 - 00:00 2.001 FISH ~ P 18/7/2008 ~ 00:00 - 01:30 ~ 1.50 (FISH ~ P 01:30 - 03:30 I 2.00 FISH I P -IA fell apx 60' -No Flow out to the Open Top Tank via the OA -Total of 25 bbls of Arctic Pack taken into cellar DECOMP Monitor Well and consult with Anchorage Rig Team -Well is in balance with the fluid level in IA apx 60' down and no flow though 13 3/8 mandrel into cellar DECOMP Displace Arctic Pack from the 13 3/8 X 9 5/8 annulus -Returns going in cellar and being suck out with vac truck -Circulating across top hole with charge pump with 9.8 brine -Hydrostatic head forcing returns up the 20" x 13 3/8" annulus Pump a total of 20 bbls and the returns in the cellar stop and started to get returns through the 13 3/8 x 9 5/8 annulus to the open top tank DECOMP PJSM with Little Red Pumping services and NAD rig crew -Pressure test line to Rig floor to 3000psi, O.K. -Pump 60 bbls of diesel heated to 130 degrees down the DP -With 20 bbls in DP and 40 bbls in annulus, shut the bag and pump another 60 bbls down the DP through 9 5/8" cut and • • BP EXPLORATION Operations Summary Report ,Legal Well Name: D-22 '.Common Well Name: D-22 Event Name: REENTER+COMPLETE Start: 8/4/2008 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABORS 7ES Rig Number: 7ES Page 4 of 16 Spud Date: 12/22/1982 End: 8/22/2008 Date From - To ~ Hours Task Code NPT Phase Description of Operations ~ 8/7/2008 ~ 01:30 - 03:30 ~ 2.00 ~ FISH ~ P 03:30 - 05:00 1.50 ~ FISH ~ P 05:00 - 06:30 1.50 FISH P 06:30 - 07:30 1.00 FISH P 07:30 - 09:00 1.50 CASE P 09:00 - 10:00 1.00 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 14:00 2.00 CASE P 14:00 - 22:00 8.00 CASE P 22:00 - 23:30 I 1.50 I CLEAN J P 23:30 - 00:00 0.50 CLEAN P 8/8/2008 00:00 - 01:00 1.00 FISH P 01:00 - 03:00 2.00 FISH P 03:00 - 06:00 I 3.00 I FISH I P 06:00 - 08:00 I 2.00 FISH I P DECOMP taking returns up 13 3/8 x 9 5/8 annulus, -50 % retums going though OA line to open top tank and 50% going in o ce ar - pump pressure = 500 psi ~ 1 bpm -Pump a total of 120 bbls DECOMP Reverse Circ., Pumping Down to IA ~ 2 bpm / 50 psi -Pump 50 bbls of Safe Surf O, 9.8 ppg brine pill -Pump another 100 bbls of 9.8 brine down IA 90% of returns going to Open Top Tank via OA DECOMP Pump down DP A 3 bpm with IA Shut in DECOMP POH with Casing Cutter -L/D Casing cutter BHA DECOMP Rig and Pull 9 5/8" casing hanger to floor -Prepare ig Floor for Laying down casirig -Pull Wear Bushing -P/U Spear! Pack off assembly -Engage Casing and Back out Lock Down Screws -Pull to 200 k and Hanger Pull free -Free P/U Wt 110k DECOMP Rig Rig floor with Power Tongs, Elevators and False Bowl / Slips DECOMP Pull 2 jts of 9 5/8 casing -Breakout 42 - 52 kft/Ibs DECOMP Ready Cellar for taking returns via 13 3/8 x 20" Annulus - y ercu i e an erm DECOMP CBU -3 bpm / 105 psi DECOMP Lay Down 9 5/8" Casing -50 jts and 22.88' cut off jt -No Centralizers recovered -26 - 62k fUlbs to breakout casing -Clear floor of casing handling equipment -Clean Arctic Pack off rig floor and drip pan DECOMP M/U 12 1/8" bit , 13 3/8" casing scraper, jars, bumper sub, 6 - an Tag at 53 feet in, attempted several times to work own unsuccess u -POH and L/D 12 1/8" Bit -RIH and Tag at 53 feet in, Body of casin scra er 11.00 inches -Scrape Marks on body of csg scraper apx 10 3!4" DECOMP Lay Down Casing scraper BHA DECOMP Remove IBOP from Top Drive and Ready rig for Swaging O erations DECOMP Pick Up Swaging BHA with 10 13/16 Swage -Tight at 53' but was able to wor own wit 15k ~ n a n ii c~~ e....,..e ..,.,. e t .r,. ~., DECOMP POH and change to 11 1!2" Swage -RIH to 53' ,Begin waging opera ions -Unable to make any progress DECOMP Pick up HWDP on top of 7 DC's below 11 1/2" Swage • BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/8/2008 06:00 - 08:00 2.00 FISH P DECOMP -Swage Between 53-55' -After working 11 1/2" Swage through several times -10-20 c rag through 53-55' 08:00 - 10:00 2.00 FISH P DECOMP Slip and cut drilling line -Service Top Drive, Crown and Draw Works -Perform Derrick Inspection -Replace Sheared bolt on the "J" Box on the Top Drive 10:00 - 12:30 2.50 FISH P DECOMP Make up 12 3/16" Swage BHA and RIH tagging at 53' -Attempt to Swage out to 12 3/16" unsuccessfully 12:30 - 15:30 3.00 FISH P DECOMP s an ing ac s an -UD Swaging BHA 15:30 - 17:30 2.00 FISH P DECOMP Make up Baker Back off tool and BHA 17:30 - 19:30 2.00 FISH P DECOMP RIH filling DP with fresh water 19:30 - 21:00 1.50 FISH P DECOMP Position Baker Back off tool across casing collar at 2088' -PJSM with all Personne -Test Lines to 5000 psi -Pressure up to 1500 and shear pins ,set bottom slips at 2095 -Slack off 20k and confirm slips set -Pressure up to 4600 psi and set top set of slips -Perform 8 cycles of pressuring up to 2500 psi and bleeding to zero for a total of 5 rounds -Release slips and Rig Down circulating equipment 21:00 - 22:30 1.50 FISH P DECOMP POH with Back off BHA 22:30 - 00:00 1.50 FISH P DECOMP UD Back Off BHA 8/9/2008 00:00 - 00:30 0.50 FISH P DECOMP Clean Arctic Pack off Rig Floor and Fishing Tools -Lay Down Fishing Tools off Rig Floor 00:30 - 01:30 1.00 FISH P DECOMP Install IBOP back on Top Drive -Detail Derrick Inspection 01:30 - 02:30 1.00 FISH P DECOMP Make Up Spear BHA and RIH to 2072' -Engage spear in 9 5/8 cut off s u~Tani~ back out 5 turns -Pull out of box 2" 02:30 - 03:30 1.00 FISH P DECOMP Circulate Safe Surf O pill around -400 gpm / 345 psi -Residual Arctic Pack Returns initially but turn to clean brine affer CBU -Less then 1 bpm coming out of the 20 x 13 3/8 annulus while circulatin 03:30 - 05:00 1.50 FISH P DECOMP POH with cut off joint -14.76' cut off joint, -Back off at pin, will screw into a box on top of 9 5/8" in the hole 05:00 - 06:30 1.50 CASE P DECOMP Rig u to run 9 5/8 casing 06:30 - 10:00 3.50 CASE P DECOMP Run 50 joints of 9 5/8" 40# Hydril 563 casing -BOT screw sub, Baffle Collar, ES Cementer -1 Pup Joint used to space out for spaceout -No centralizers due to collasped 13 3/8 casing -Jet Lube Seal Guard thread compoun -Baker-Locked connections on Cementer and below -M/U Torque on Hydril 563 to 15800k ft/lbs 10:00 - 11:00 1.00 CASE P DECOMP Tag Casing top ~ 2089' -Free PUW 100 OW 98k -Screw in with 7 Turns and Work 10k Torque down -Pull Test to 250k, O.K. 11:00 - 11:30 0.50 CASE P DECOMP Pressure Test Casing to 2000 psi for 30 minutes, Good Test rnrnea: mucvvo ~ i.o~av wvi BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: D-22 Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2008 11:30 - 12:30 1.00 CASE P DECOMP M/U Cement Head, hoses and Valves -Shear out cementer at 3100 psi -CBU ~ 6 bpm / 270 psi 'Arctic Pack still coming out intermittently 12:30 - 14:30 2.00 CASE P DECOMP amen casing ac o su ace -Pump 5 bbl fresh water and pressure test to 4000 psi -Batch Mix and pump 220 bbl Class "G" cement (100 bbls excess a ppg wit as o rop -emen er c osing pug. -Drop Plug -Pump 10 bbl fresh water behind plug to clear lines. -Switch to rig pump and displace with 147 bbl (2534 strokes) fresh water at 5-6 bpm. -At 2000 strokes, reduce rate to 2 bpm, close bag and squeeze the last 30 arre s out in tote x annu us. o0 cement returns in 20" x 13 3 8" or ast s o isp acement. -Bump plug to 1700 psi, then continued to pressure up to 3000 psi to shear pins and close ES-Cementer. -Hold for 5 minutes then bleed off and check for flow back, -Rig Down Cementing equipment CIP ~ 14:00 Hrs 14:30 - 15:30 1.00 BOPSU P DECOMP Slit Stack to set emergency slips -Drain cement and flush lines 15:30 - 20:30 5.00 WHSUR P DECOMP Land 9 5/8 casing and Install New casing Wellhead -Set Emergency slips on 9 5/8" casing -Set with 100k -Cut off casing with Wachs Cutter -UD Cut Off Joint -NU new McEvoy SB-3 SSH Tubing Spool with YBT Packoff -Fill Void with Plastic sealant -Test to 2500 psi for 30 minutes 20:30 - 22:30 2.00 BOPSU P DECOMP Nipple up BOP's -Install Riser, secondary valves and tighten turnbuckles 22:30 - 00:00 1.50 BOPSU P DECOMP Change Top Set of Pipe Rams from 9 5/8 to 3 1/2" x 6" VBR -Open a o t e am oors an us ou emen an nspect cavities 8/10/2008 00:00 - 01:30 1.50 BOPSU P DECOMP Finish Cleaning and Inspecting Ram Bodies -Open all of the Ram doors and flush out Cement and Inspect -Close Bag and Flush out cement behind bag 01:30 - 02:30 1.00 BOPSU P DECOMP Function Test All Rams PJSM with Rig Crew on testing BOP's es s o ow an psi igh -Witness of Test BP WSL Dave Newlon, NAD Toolpusher Biff Perry -Each test held for 5 minutes and charted -Test Top Set of Pipe Rams with 4" Test Joint, This test also tested flange breaks on New Spool -Good Test n__._~. ninnnna ~~•cn~~~ ens BP EXPLORATION Page 7 of 16 Operations Summary Report Well Name: D-22 Legal . Common Well Name: D-22 Spud Date: 12/22/1982 Event Name: REENTER+COMPLETE Start: 8/4/2008 End: 8/22/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/22/2008 Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/10/2008 02:30 - 03:30 1.00 CLEAN P DECOMP Make up an 8 1/2" bit, 2 junk baskets, Jars, 3 stands of 6 1/4" drill collars 03:30 - 04:30 1.00 CLEAN P DECOMP RIH to ES cementer at 2061'. 04:30 - 06:30 2.00 CLEAN P DECOMP Cleanout ES cementer and Plug catcher -Tag Cement Stringers at 2049 -Wash Down to plugs ~ 2077' -400 gpm / 600 psi -80 rpm 1-2k fUlbs of Torque -PUW - 75k SOW - 73k 06:30 - 07:00 0.50 CLEAN P DECOMP RIH and Tag EZSV (~ 4235' 07:00 - 08:00 1.00 CLEAN P DECOMP Pump High Vis Sweep around -550 gpm / 1170 psi -Monitor Well, static 8.4 ppg In/Out 08:00 - 11:30 3.50 CLEAN P DECOMP POH and UD Junk Baskets - no debris in baskets 11:30 - 14:00 2.50 CLEAN P DECOMP Make 9 5/8" casing Scraper - RIH Picking up the remaining drill pipe 1x1 14:00 - 16:30 2.50 CLEAN P DECOMP POH Rack Back DC's and VD Scrapper -No Issues running scraper 16:30 - 19:30 3.00 STWHIP P WEXIT Make up Whipstock and Mills 19:30 - 22:00 2.50 STWHIP P WEXIT RIH to 4189' -Shallow hole test MWD, O.K. 22:00 - 22:30 0.50 STWHIP P WEXIT Displace to 9.2 ppg LSND Milling Fluid -500 gpm / 1000 psi 22:30 - 23:30 1.00 CASE P DECOMP Test Casing to 3500 psi for 30 min -Lost 50 psi for the first 15 mionutes -Lost 20 psi for the second 15 minutes -Total pressure loss for test of 70 psi 23:30 - 00:00 0.50 STWHIP P WEXIT Set Whipstock -Orient Whip stock to 60 degees left of high side -set anchor with 20k down weight -Confirm anchor is set pulling 15k h -Sheared off with 40k slack off weight p~ 2C -Whi stock set at 57 derees left of hi h side 8/11/2008 00:00 - 04:00 4.00 STWHIP P WEXIT Mill window from 4211 - 4239' -370 gpm / 650 psi -90 rpm 1-3 off btm torque / 3 -7 on bottom torque TOW ~ 4211 BOW ~ 4227' Middle of window is 4219' 04:00 - 04:30 0.50 STWHIP P WEXIT CBU 04:30 - 05:00 0.50 STWHIP P WEXIT Perform FIT test to 11.7 EMW -Chart test, Good test Fit Test Data - 4219' MD / 4217' TVD 9.2 ppg / 550 psi 05:00 - 06:30 1.50 STWHIP P WEXIT Finish Milling window to 4248' -370 gpm / 650 psi -90 rpm 1-3 off btm torque / 3 -7 on bottom torque -Work Mills through window to clean up, Good Window -CBU -Monitor Well, Static 9.2 ppg In /Out 06:30 - 08:00 1.50 STWHIP P WEXIT POH standing back Drill Pipe and HWDP 08:00 - 09:00 1.00 STWHIP P WEXIT Lay Down Drill Collars and Window Milling BHA 09:00 - 10:00 1.00 STWHIP P WEXIT Flush Stack with Jetting Tool -Clear Floor of Milling Equipment and tools o-......w. nimm~na 11~rn•'U eln ._ ... .. it NELLHEAR= MCEVOY ~ \CTUATOR = OTIS D ~ CB ~ELEV = 70.55' - 3F. ELEV = COP = .~.... .. Flax Angle = 92° @ 10137 )atum MD = 9196' }atum TV D = 8800' SS 9-5/8" CSG, 47#, L-80, BTC, ID = 8.681" 2089' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2684' Minimum ID = 3.725" @ 8581' 4-112" HES XN NIPPLE TOP OF WHIPSTOCK ~oL~l 9-5/8" CSG, 47#, L-80, ID = 8.681" 4211' r ~' i~~'u'~i14'tl!I~,hx~~~,d,~,~~ii,; II ph~i'I~IIU ~ ~ , ~~ r~o 9-5l8" ¢SV 4235' SA~NOTES: ***4-112" CHROME TUBING*** 2077' ~ 9-5/8" HES ES CEMENTER 2188' 4-1/2" HES X NIP, ID = 3.813" GAS LIFE MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 1 3595 6435 3595 6338 0 19 MMG1 MMG1 DCR DMY BEK BK 0 0 08/20/08 08/20/08 3691' ~ 9-5/8" x 7" ZXP LTP, ID = MILLOUT WINDOW (D-22C#} 4211' - 4227' $443' --I4-1/2" HES X NIP, 4-1/2" TBG, 12.6#, 13CR80, VAM TOP, ID = 3.958" H 8561' 4-1/2" TBG, 12.6#, 13CR80, TCII, ID = 3.958" 8593' PERFORATION SUMMARY REF LOG : ANGLEATTOPPERF: 90° @ 9820' Note : Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9820 - 9920 O 08/21 /08 2-7/8" 6 9940 - 10030 O 08/21/08 2-7i8" 6 10060 - 1031 D O 08/21 /08 2-7/8" 6 10340 - 10760 O 08/21/08 ~ 7" LNR 26#, L-80, BTGM, ID = 6.276" ~ 14-1/2" LNR, 12.6#, L-80, IBT-M, ID = 3.958" I I 8739' I I ID = 3.813" 8516' 7" x 4-1/2" BKR S-3 PKR, ID = 3.87" 8550' 4-1/2" HES X NIP, ID = 3.813" _8581' --I4-1/2" HES XN NIP, ID = 3.725" I I_I Q~SQ'~'~ 7" x 4-1/2" HR ZXP ' LTP, ID = 4.46" 8593' 4-1/2" WLEG, ID = 3.958" 8600' 7" x 5" BKR HMC LNR HGR, ID = 4.45" 8610' 5" x 4-1/2" XO, ID = 3.93" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINAL COMPLETION 12/03/97 PARKER SIDETRACK (D-22A) 06/14/02 JDM/KA RIG SIDETRACK (D-22B) 08/23/08 N7ES SIDETRACK (D-22C) PRUDHOE BAY UNff WELL: D-22C PERMIT No: "2081210 API No: 50-029-20737-03 SEC 23, 711 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) • • AI.A51~-A Ol[L aisil GA5 333 W 7th AVENUE, SUITE 100 C01~5L'`RVATIOi~T C01rII-II55IO1~T ANCHORAGE,AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. ~~~NNEf~ JUN ~ ~ 2008 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-22B Sundry Number: 308-207 ~ ~ ~- '~ Q'S Dear Mr. Hobbs: 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 Commission to witness any required test, contact the Commission's petroleum $eld inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2008 Encl. ~,~,~i STATE OF ALASKA ~®~p ,1~~ ALA OIL AND GAS CONSERVATION COM~ION J~~ ~ 2 2 N ~ ~13 ~ APPLICATION FOR SUNDRY APPROVAL~~~~~~ fir! ~ Gas Cons. is~iori 20 AAC 25.280 Attt?ht~rarsa 1. Type of Reques t : ®A andon / ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ , n ~~~ I~ \ Aner Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®bevelopment ^ Exploratory 202-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20737-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property tine where ownership or landownership changes: PBU D-22B , Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028285 - 71.83' ~ Prudhoe Bay Field / Prudhoe Bay 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): 10945" ~ 9003' - 10856' ~ 9010' ' 861 T None Ca in en h ize '' MD TVD Bur Colla se Structur I d r 110' 20" x 30" 110' 110' S rta 2646' 13-3/8" 26 4' 2684' 4930 2670 Intermedi to 8243' 9-5/8" 8278' 8040' 6870 4760 Pr i Lin r 676' 7" 8141' - 8817' 7910' - 8507' 7240 5410 Liner 2327' 4-1/2" 8618' - 10945' 834 ' - 9003' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 10150' - 10650' 9026' - 9025' 4-1/2", 12.6# 13Cr80 8629' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 8572' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 26, 2008 ^ 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 John Rose, 564-5271 Printed Name Gre obb Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4191 Date ~' /~ ~, Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ` 8'_ ~ Conditions of approval: Notify Commission so that a representative may witness ~ ~/ ^ Plug Integrity P Test ^ Mechanical Integrity Test ^ Location Clearance ~''~~``` ~ ~`~® Other: ~~~~ i~;'1~ ~~ Subsequent Form Re 'red: ~-.~~ APPROVED BY ~ ~ g A B i roved : .COMMISSIONER THE CO MISSION Date Form 10-403 Revised 0612066 " ^ ~ I ^ I ` , • ~ ~ ~ ~,t ~ Submit In Duplicate D-22B Request for Sundry Approval Current Well Type: Ivishak Zone 2 Producer Current Status: D-22B is currently shut-in for a surface casing leak. • Request: In preparation for the proposed D-22C rotary sidetrack, approval is requested for the P&A of PBU D-22B perforations as well as a cut and pull of the 9-5/8" production casing from 2175' MD which will then be tied-back with a fully cemented 9-5/8" tie-back string. Scope of Work: P/A the existing perforations (10,150' - 10,650' MD) with cement, cut and pull the existing 4-1/2" completion f/~8567' MD, set a CIBP at 4172' MD, cut and pull the existing 9-5/8" production casing from above TOC at 2175' MD, run a premium threaded 9-5/8" tie-back casing string (w/ES Cementer) and fully cement the 9-5/8" x 13-3/8" annulus back to surface in preparation for setting a 9-5/8" whipstock on the CIBP at 4172' MD for the proposed D-22C rotary sidetrack (an Ivishak Zone 2 producer). MASP: 2310 psi Estimated Start Date: June 26, 2008 Proposed Pre-Rig Work: 1. MIT-IA to 3000 psi. MIT-T to 3000 psi. (MIT-OA failed Feb. 2006.) 2. Perform a PPPOT -T. (PPPOT-IC failed 10/2/02). 3. Cycle all LDS, repair or replace as needed. 4. Pull PXN plug at 861 T MD. G ~ v C`v ~~ /,~9'11~I~ ~ 4 5. Drift for service coil to PBTD. ~~J ~ ~"'~'" ~- 6. Using service coil, seta 22.9 bbls class G cement plug from 10856' (PBTD) to 9351' MD (100' TVD above top pert at 10,150' MD) displacing the tubing to seawater above the cement plug. 7. Jet cut 4-1/2" tubing at 8567' with a-line. 8. Circulate the tubing and IA above cement plug to seawater. 9. Perform CMIT-IA x T to 2230 psi to test cement plug (.25 psi/TVDft). 10. Freeze protect IA and T with seawater and 2200' TVD of diesel. 11. Set a BPV and test to 1000 psi from tubing annulus (or maximum allowable up to 1000 psi). 12. Secure the well 13. Remove well house and flow lines. Level the pad as necessary. Proposed Qrillins~ Rise Operations: 1. MI/RU Nabors rig 2ES. Pull BPV. 2. Circulate out diesel freeze protection and displace the well to seawater. 3. Set and re-test TWC to 1,000 psi from above and below. 4. Hook up OA to a bleeder tank and monitor (OA will not pass pressure test / no OA test required). 5. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 6. R/U. Pull 4'/2" tubing from the cut depth at 8567' MD. 7. RIH w/ 8 '/2" gauge ring /junk basket to 4300'. 8. RIH with HES EZSV bridge plug on E-line and set at 4172' MD, as required to avoid cutting a casing collar while milling the window. Test CSG to 3500 psi. POOH. 9. String shot 9'/s" casing at back off point (two joints above where USIT indicates TOC~2,175') to ease break out. RD a-line. 10. MU a Baker 9 °/s" cutting assembly. RIH picking up DP. Cut the 9 °/s" casing per Baker representative instructions. Cut ~4' above the string shot casing collar. POOH, UD assembly. 11. Change out to 9 °/s" rams, and test rams. 12. BOLDS, RU/MU casing spear assembly, and unseat the 9%". Circulate the annulus. Pull the 9 s/s" casing from the cut (will attempt to pull casing through wellhead/BOPS). 13. MU wash-over assembly and 13'/s" casing scraper. 14. RIH, clean-out the 13-'/s" casing, and the 9 °/s" casing stub, POOH, UD the assembly. 15. RU back-off assembly, RIH, and back off the 9 °/s" casing joint. POOH, L/D assembly. 16. MU casing spear assembly, RIH, recover cut stub. POOH. 17. MU 9 "/e" ES Cementer on screw in sub w/ baker ball and seat and RIH w/ new 9 s/s", Hydril 563 casing. 18. Test new 9-5/8" / ES cementer /screw in sub to 2000psi for 10mins. 19. Shear open ES cementer and cement 9-°/s" x 13-9/" annulus w/167 bbls class G 15.8ppg cement (2,175' of 13-'/s" x 9 °/s" plus 40 extra bbls). 20. Split stack and install FMC 13" x 9-5/8" emergency slips with primary pack off per FMC wellhead specialist in the casing head. Set slips. Cut and LD excess 9-5/8" casing. Set back BOPE test breaks to 3500 psi and test packoff to 3800 psi. NU BOPE. Change BOP rams back to VBR's and test rams. 21. Set test plug and test stack to 250psi/3500psi. 22. PU 4" DP and mill tooth bit. Make clean out run through the ES Cementer. 23. Pressure-test the 9 5/e" casing to 3,500 psi for 30 minutes. Record test. 24. P/U and RIH with 9 5/s" Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. Contacts Name Phone # ODE John Rose 564-5271 Geologist Roger Sels 564-5215 Pad Engineer Chris Stone 564-5518 E-mail John.G.RoseCcr~,bn.com Ro eg r,_ 5els(a,bn.com Christopher. Stone(a~bp. com ATTACH: Current Schematic Proposed Schematic TREE _ ` 6" MCEV OY WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 71.8' BF. ELEV = 43.13' KOP - 8278' Max Angle = 95 @ 10786' Datum MD = 9275' Datum TV D = 8800' SS ~ D-22B S TES: ***4-1 /2" CHROME LINER*"* 27' I--17" X 4-1/2" XO, ID = 3.958" $7' 1~4-1/2" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 3.725" @ 8617' 4-1/2" HES XN NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3257 3257 0 MMGM DMY RK - 09/03/04 3 5291 5245 22 MMGM DMY RK - 09/03/04 2 6661 6507 21 MMGM DMY RK - 06/14/02 1 7728 7519 18 MMGM DMY RK _ 06/14/02 MILLOUT WINDOW - 8278' - 8294' PERFORATION SUMMARY REF LOG: SPERRY MWD/GRON 11/18/97 ANGLE AT TOP PERF: 88 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10150 - 10650 C 06/11/02 9-5/8" CSG, 47#, L-80, ID = 8.681" 81419-5/8" X 7" ZXP LNR TOP PKR $277' TOP OF BKR WHIPSTOCK 8552' 4-1/2" HES X NIP, ID = 3.813" $572' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8596' 4-1/2" HES X NIP, ID = 3.813" 8617' 4-1/2" HES XN NIP, ID = 3.725" 8617' 4-1/2" PXN PLUG (12/13/07) 8618' 7" X 4-1 /2" ZXP LNR TOP PKR, ID = 4.430" _ 8629' 4-1/2" WLEG 10856' I~ PBTD 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 4-1/2" LNR, 12.8#, 13-CR-80, .0013 bpf, ID = 3.958" i-1 t36LS' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 4-1/2" LNR, 12.8#, .0013 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINAL COMPLETION 08/29/06 RDW/TLH WAVER SFTY NOTE DELETED 12/03/97 PARKER SIDETRACK (D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13/07) 06/14/02 JDM/KA RIG SIDETRACK (D-226) 10/03/02 TLHITP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRRITLP GLV GO 03/16/06 ELZ/PAG WANERSAFETY NOTE (03/08/06) PRUDHOE BAY UNfT WELL: D-22B PERMfT No: 2021050 API No: 50-029-20737-02 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) TREE=' 6" MCEVOY WELLHEAD = MCEVOY ACTUATOR - OTIS KB~ ELEV = 71.8' BF. ELEV...- 43.13' KOP = 8278' Max Angle = 95 @ 10786' Datum MD = 9275' Datum TVD = 8800' SS S TES: ***4-1 /2" CHROME LINER*** D-22B Sundry -HES ES Cementer, 9-5/8", 47#, L-80, Hydril 563 Casing - -2175` MD 13-3/8" CSG, 72#, L-80, ID = 12.347" 2684' Minimum ID = 3.725" @ 8617' 4-1 /2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: SPERRY MWD/GR ON 11/18/97 ANGLE AT TOP PERF: 88 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 9-5/8" CSG, 47#, L-80, ID = 8.681" 8618' 7" X 4-1 /2" ZXP LNR TOP PKR, ID = 4.430" = 8629' 4-1/2" WLEG /TOC at -9351` MD PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" EZSV CIBP - 4172` MD 8147' 9-5/8" X 7" ZXP LNR TOP PKR iTubing Cut at - 8567` MD 8572' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8596' 4-1/2" HES X NIP, ID = 3.813" 8617' 4-1/2" HES XN NIP, ID = 3.725" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 4-1/2" LNR, 12.6#, .0013 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/11/83 ORIGINALCOMPLETION 08/29/06 RDW/TLH WANERSFTYNOTEDELETED 12/03/97 PARKER SIDETRACK (D-22A) 12/19/07 TFA/PJC SET PXN PLUG (12/13/07) 06/14/02 JDM/KA RIG SIDETRACK (D-22B) 06/06/08 JGR D-22B Sundry Application 10/03/02 TLHITP CORRECT 9-5/8" CSG DEPTH 09/03/04 WRR/TLP GLV C/O 03!16/06 ELZ/PAG WANERSAFETY NOTE (03/08/06) ~4-1/2" LNR, 12.6#, 13-CR-80, .0013 bpf, ID = 3.958" PRUDHOE BAY UNff WELL: D-22B PERMf1- No: 2021050 API No: 50-029-20737-02 SEC 23, T11 N, R13E, 1550' SNL & 1692' WEL BP Exploration (Alaska) MILLOUT WINDOW - 8278' - 8294' 12/19/07 Sch[~mberger NO. 4525 Alaska Data & Consulting Services ~ Cps ~? ~}(y Com an State of Alaska 2525 Gambell Street, Suite 400 ~~ ~°it ° ~ ~ 6~ Fs' L U~~ p y~ ~lu ~~,,,.,,,~ ~ Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne Wall _Inh it 1 nn nncrrin4inn n~~e Q~ r.. i... nn 15-39A 11661174 MCNL '~ 09/24/07 1 14-32 11676961 RST 09/14/07 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG '} i y 10/06/07 1 03-36A 11745217 CH EDIT PDC GR (USIT) t U1'~- 05/03/07 1 15-30A 11767139 MCNL 09105/07 2 1 18-126 11216204 MCNL ~ 07/04/06 2 1 E-21 B 11133205 MCNL ,./G j $ 12/07/05 2 1 P2-56 11686777 RST - ~ 08/08/07 2 1 H-33 11686792 RST Cj~ .. 'a 10/20/07 2 1 06-16 11686797 RST - ~ 11!15!07 2 1 L2-16 11626482 RST 05!10107 2 1 D-22B 11661167 MCNL O j 5 08/26/07 2 1 03-14A 71212846 CH EDIT SDCL GR (USIT- ~~ - ®A ~l5 ~ 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) --~~ ~`~ ~~j, 01/15/07 2 1 C-22A 40013486 OH MWD/LWD EDIT („ -p ? ~-'~/ 05/10/06 2 1 E-15C 40013555 OH MWD/LWD EDIT p .- (o (~ a '~-~j~ 06103/06 2 1 r'LCAJC Nli r\IYV VYLC UbC RC~.CIF' 1 tai JIIa IVIIVb NIVU Kt 1 UKIViNta VIYt I.VF'T tAlitl 111: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ) E:CE=JVED OC1 2 6 2005 WELL LOG TRANSMITTAL ~~~a~~k(jl Œ~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 08, 2003 RE: MWD Formation Evaluation Logs: D-22B, AK-MW-22086 D-22B: j:. I) 5> 3 8 Digital Log Images 50-029-20737-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob K.alish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:;Z~ Ò~ ç- Signed: ~~~ 6> ýI..., ~ U F E (/,.(;:, ýJ µ ¡4H-i ~ ~ {.6 r\ I+~ ß . .' " '.... ~., '......... .. -'..,' . ,.,.,.. ....,.. :'~ :JÇ.ANNED OCT 3 1 2DDS '. t .. ~ G,t~·'~~- F,~~ j 1, j~t"1 ^.~~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2021050 Well Name/No. PRUDHOE BAY UNIT D-22B Operator BP EXPLORATION (ALASKA) INC J I}' t/l L ^ J,,",-,-- AÞ-{ll- API No. 50-029ø20737-02-00 MD 1 0945 ~ TVD 9003 / Completion Date 6/13/2002 ~ Completion Status 1-01L - ------ - -- --------- REQUIRED INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset ,T~~e~ _Med/F~~- __Nurr1~~r . ~e t-EÓ .~ C-ôirectional Survey ~/ LIS Verification :~-- - -- ---- ---- -- ------ DATA INFORMATION ! Rpt/ ~D i Log l-Eo/ (Ž ~ ~t . 0::69 jJ-09- ~- [ ~/ I í ~ C Tf i €Ð----- C Pds I Mud Log No Samples No -" -----~--- Log Log Run Scale Media No 1 ~nt Ev~luatíon d)iréêtionatSurVey MaáLIS Verification Corrosion v1SÍrectional Survey £...-8'0 n i c Col 5 5 Col 5 Col 2 Blu 2 Blu 2 Blu éPireét~onaISurv~y t-PfÕd~ction ~g collar locatpf ~utron 4-2135 LIS Verification 4.2--135 Neutron 2 2 2 Blu 2 Blu ! ~é Pds ~5 Casing collar locator ~ . ,~- jQog--- i~-Asc I i =Nãlítron L-.GáSÍng collar locatOr G-t153 LIS Verification Current Status 1-01L UIC N Directional Survey ~) (data taken from Logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments 8193 10945 Open 8/10/2002 MWD 7307 10893 Case 1/21/2003 0 8353 Case 7/12/2002 8193 1 0945 Open 8/10/2002 MWD 7307 1 0893 Case 1/21/2003 0 8353 Case 7/12/2002 8193 10945 Open 8/1 0/2002 0 8353 Case 7/12/2002 8193 10945 Open 8/10/2002 8008 1 0842 Case 6/10/2003 Production profile - Memory GRlCCUCNUSTP 8008 1 0842 Case 6/10/2003 Production profile - Memory GRlCCUCNUSTP 8008 Case 6/10/2003 ----. 1 0842 Production profile - Memory GRlCCUCNUSTP 8008 10837 Case 7/23/2003 8008 1 0837 Case 7/23/2003 Memory CNL Borax Log - Memory GRlCCUCNUSTP 8008 10837 Case 7/23/2003 Memory CNL Borax Log - Memory GRlCCUCNUSTP 8008 10837 Case 7/23/2003 Memory CNL Borax Log - . Memory GRlCCUCNUSTP 8008 10837 Case 7/23/2003 Memory CNL Borax Log - Memory GRlCCUCNUSTP 8278 1 0945 Permit to Drill 2021050 MD (ED ~.ED : ED I : ED -----L- 10945 C Pdf C Pdf C Pdf C Pdf DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Well Name/No. PRUDHOE BAY UNIT D-22B 9003 Completion Date 6/13/2002 Rate of Penetration Induction/Resistivity TVD t~~~: 11753 753 --------- ------~~ Neutron Density Well Cores/Samples Information: Name ADDITIONAL INFORMATION y@ Well Cored? Chips Received? - Y I N -- Analysis Received? -¥-J-N . --- -----._---------~~ Comments: -- .-------- Compliance Reviewed By: - - -------- H-ù Interval Start Stop Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L 25 8278 10945 Open 25 8278 10945 Open 25 8278 1 0945 Open 25 8278 1 0945 Open Sent Sample Set Number Comments Received Daily History Received? (])/N &N Formation Tops API No. 50-029-20737-02-00 UIC N Rap, DGR, EWR ROP, DGR, EWR DGR, CTN, SLD DGR, CTN, SLD ~ Date: d~ ~ \èJ ~1 l-f\}'-A '-,-~~,,/ Schlumbepgep NO. 2890 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S.2-05A O~-j~ 23376 MCNL 06/02/03 1 1 1.8. ) ~() Hø27A - Q 23319 MCNL 05/09/03 1 1 J~J~~ E-02A ~ - j/J:f 23275 MCNL 03/15/03 1 1 NK-62A o,~'W 23277 MCNL 04/27/03 1 1 )t.,l . Â . E-01A ~ -:5 23280 MCNL 04/12/03 1 1 ~~~~( P2-54A [:S-O 23274 MCNL 03/27/03 1 1 Dø22B -I (;') 23348 MCNL OS/22/03 1 1 J~JI";1Y; D.S. 2-08B)'1' ...:oCj C) MEM PROD PROFILE 05/31/03 1 J-26 LDL 06/20/03 1 D.S. 2ø29A LDL 06/22/03 1 D.S. 15ø28 LDL 06/21/03 1 D.S. 12ø20 LDL 06/03/03 1 J-08 LDL 06/26/03 1 D.S. 2-25 PRODUCTION PROFILE 06/07/03 1 PSI-01 TEMPERATURE WARMBACK LOG 06/09/03 1 PSI-06 TEMPERATURE WARMBACK LOG 06/13/03 1 PSI-09 TEMPERATURE WARMBACK LOG 06/19/03 1 K-317B SBHP SURVEY 04/05/03 1 C-04A SBHP SURVEY 06/26/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth RECEIVED 07/02103 - '~ Date Delivered: JuLdl3 2003 Received ~-~ l /~ \. G ~ ~d':-/'"í'-.. Aiaska ON & Gas Cons. Commi8etoo .Anchorage Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well v"Wþ9AL1 ê2Œ2-d, ~6 vØ'2-57A I;1C)~ -éJ- \ 1.:.\ D.S.12-20 \ <¡J~ ~\~ p.S.15-21A ( CfQ -0" - B-04 11-0 -0 -., oJ ;.;F -1 OA ()-(!;(J"" d (.Q . i ~ -~OA~' -~.liC/ )A:f-~2B (;; - \0 C) vK-01 ~ \ &. \ Job # Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 23099 TIE-IN MGR/CCL 23272 MCNL LDL PRODUCTION PROFILE PRODUCTION PROFILE/GHOST LDL MEM PRODUCTION PROFILE MEM PRODUCTION PROFILE LDL 0 / /.() --- (J~ Date 03/06/03 03/15/03 06/03/03 05/15/03 05/17103 05/18/03 05/20/03 05/22/03 05/16/03 Blueline ~ :~ .;-~-~ -(; E ~ ~:/ i~ 1:) JUì\} ;~¿:f-:2 ~..- '-~ -- 1 ;J 2- 06/05/03 NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 1 1 1 1 1 1 1 1 - la/~)J5 1 I~() / Iç; -"--~r Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~(/ Received ~yrzjjlÞtf' 1/1; (f¡ø~ . .... .. ~..... ..~' : - -" -_.._j.1.".""~'--i.--.... . . Schlumbel'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well (ÁO~' ^~W-19AL1 ~ ~~~ij P2-57A,.~ ¡3d .-, q \ D.S. 12-20 -...j j qq. 02.q D.S.15-21A-.J 11 c . () 3'2 B-04 .~ J.Útì. 0 v 1 Fø10A -'--..J ?- u ~ . ?-~o D-30A "'-....J ~\J~.ìÓ? D-22B J J t.?J .lll K-01 -~ Job# Log Description 23099 TIE-IN MGRlCCL 23272 MCNL LDL PRODUCTION PROFILE PRODUCTION PROFILE/GHOST LDL MEM PRODUCTION PROFILE MEM PRODUCTION PROFILE LDL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 9950B Date Delivered: ø /' 10 ~(J-"3 06/05/03 NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee.pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 03/06/03 1 1 03/15/03 1 1 06/03/03 1 05/15/03 1 05/17/03 1 05/18/03 1 OS/20/03 1 OS/22/03 1 05/16/03 1 -- - Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN, B.~ uP 111/1 ( /' /'1,( : Received ~ .Q; ~ I \fL.) .JVVi/Z",~ \ ' ) ') dOd--tD~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 May 08, 2003 RE: MWD Formation Evaluation Logs: D-22B, AK-MW-22086 D-22B: Digital Log Images 50-029-20737-02 1 CD Rom , 1103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration ( Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. i\nchorage, Alaska 99508 Date: lç, " 10.03 Signed Q~ I3JV\£?}-- RECEIVED MAY 13 2003 AI." 01 & Gas Coni. CornmiMioll Må1<nge ) ") aDd -/05 I I L} <l~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cotnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska January 16, 2003 RE: MWD Formation Evaluation Logs D-22B, AK-MW-22086 1 LDWG formatted Disc with verification listing. API#: 50-029-20737-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~(.L (kf) ("--J RECEIVED JAN 2 1 2003 AfaMa Oil & Gas Cons. ComnHaeion Anœcnge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well Iia Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519ø6612 4. Location of well at surface r~~:'''~"'::;;'-;:::F;-;,''':: 1550'SNL 1692'WEL SEC. 23 T11N R13E UM; Lur,I.(:,.I"", I At top of productive interval ' , 'i r;, ;/:~ ~ 0 z.,i 2893' SNL 124' WEL SEC. 23 T11 N R13E UM ,~---¿.,-,--- ¡ At total depth' , , , ,l' VEFi!tiEi.} I 4048' SNL, 80T EWL, SEC. 24, T11 N, R13E, UM '_.~,¿.?.,,:=::J 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 71.6' ADL 028285 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/2/2002 6/9/2002 6/13/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10945 9003 FT 10858 9010 FT Iia Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, DEN, NEU Classification of Service Well ,.~~"~,-~~¡"~\.~'HVY, " ~)~.. f~ '~!~~L~ 7. Permit Number 202-105 8. API Number 50- 029-20737 ø02 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.22B 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2181' MD 1900' (Approx.) 23. CASING SIZE 20" X 30" 13ø3/8" 9ø5/8" 7" WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor Lø80 Lø80 Lø80 L-80 /13Cr80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 9.6 cu yds Concrete 38' 2684' 17-1/2" 3720 cu ft Permafrost 'C' 35' 8278' 12ø1/4" 1170 cu ft 'G', 130 cu ft PF 'C' 8141' 8817' 8-1/2" ~22 cu ft Class 'G' 8618' 10945' 6-1/8" 342 cu ft Class 'G' AMOUNT PULLED 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 10150' - 10650' 9026' - 9024' 25. SIZE 4ø 1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 8623' PACKER SET (MD) 8566' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 27. Date First Production June 22, 2002 Date of Test Hours Tested 6/27/2002 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OILøBBL TEST PERIOD 1822 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAsøMcF 23,653 GAs-McF WATERøBBL 126 WATERøBBL CHOKE SIZE 58.55° OIL GRAVITY-API (CORR) 26.7 GAS-OIL RATIO 12,980 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~Þf: ~: \, ~"... ~.: ~ F " , No core samples were taken. ,JUl- '? .~) 200? Form 10ø407 Rev. 07ø01ø80 Alaska Oii & Gas Cons. GOùur¡¡SSIOn Anchorage b t:- Ani f"t'1~\! ;\L ' ~~< ~lJ ~ Ii '\,j l~'\ R B D M 5 B F l JUL 2 9 2~mit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Sag River 8808' 8499' Shublik A 8848' 85321 Shublik 8 8894' 85701 Shublik C 8914' 8586' Shublik D 8955' 8620' Zone 3 9146' 8777' Base CGL I Top Zone 2C 9239' 8848' Zone 28 I 235B 93551 8922' 22T5 9445' 8969' 31 ~ List of Attachments: Summary of Daily Drilling Rèports, Surveys ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. '\1 f ~, -"", JU~~ t) -, t')fìfì2- ~-- c, ,j Lllv ' iB~\On A1 ki on & lias ~l.Hi'5. vlJnHH ;:) as a Anchorage 32. I hereby certify that the fo~in~ is true and correct to the best of my knowledge Signed Terrie Hubble --r 0 )\J\H! t\u~ Tme TechnicalAssistant D~22B 202-105 Well Number Permìt No. I Approval No. INSTRUCTIONS Date 0'1 ~Õ.O~ Prepared By Name/Number: Terrie Hubble, 5644628 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 only 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. IreM 21: Indicate whether from ground level (GL) or other elevation {OF, KB, etc.}. IreM 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 Iniection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 r p, I I: :, , ò I L~ Legal Name: 0-22 Common Name: 0-22 Test Date 6/1/2002 6/6/2002 FIT FIT Test Type Test Depth (TMD) 8,278.0 (ft) 8.804.0 (ft) BPEXPLORATION Leak-OffTøstSUITUT1ary Test Depth(TVD) 8,040.0 (ft) 8,505.0 (ft) AMW 10.60 (ppg) 8.40 (ppg) SurfacePreSSlJre 600 (psi) 930 (psi) .LeåkOff Pressure> (BHP) 5,027 (psi) 4,641 (psi) EMW 12.04 (ppg) 10.50 (ppg) -.-'" '-'" Printed: 6/17/2002 11 :27:40 AM ) ) BPEXPLORA TION Operations Summary Réport . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-22 D-22 REENTER+COMPLETE NABORS NABORS 2ES Date From - To Hours Task Code NPT Phase 5/27/2002 5/28/2002 09:00 - 00:00 00:00 - 02:00 02:00 - 04:00 15.00 RIGU P 2.00 MOB P 2.00 RIGU P PRE PRE PRE 04:00 - 05:00 05:00 - 09:30 1.00 WHSUR P 4.50 KILL P DECOMP DECOMP 09:30 - 10:00 10:00 -11:30 11 :30 - 15:00 15:00 - 21 :00 0.50 WHSUR P 1.50 WHSUR P 3.50 BOPSUR P 6.00 BOPSUR P DECOMP DECOMP DECOMP DECOMP 21 :00 - 22:00 1.00 PULL P 22:00 - 23:00 1.00 PULL P 23:00 - 00:00 1.00 PULL N 5/29/2002 00:00 - 01 :30 1.50 PULL N 01 :30 - 02:30 1.00 PULL P 02:30 - 03:00 0.50 PULL P 03:00 - 03:30 0.50 PULL P 03:30 - 04:00 0.50 PULL P 04:00 - 06:30 2.50 PULL P 06:30 - 07:00 0.50 PULL P 07:00 - 12:00 5.00 PULL P 12:00 - 13:00 1.00 PULL P 13:00 - 14:30 1.50 BOPSURP 14:30 - 16:30 2.00 CLEAN P 16:30 - 18:00 1.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P DECOMP DECOMP WAIT DECOMP WAIT DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 18:30 - 19:30 1.00 EVAL N WAIT DECOMP 19:30 - 20:00 20:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 0.50 CLEAN P 1.00 CLEAN, P 1.50 CLEAN P 1.50 CLEAN P DECOMP DECOMP DECOMP DECOMP Page 1of6 Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: Spud Date: 12/22/1982 End: Description of Operations Turnkey rig move from E-31A to D-22B well. Rig up on D-22 well. Take on seawater into pits. Accept rig at 0200 hrs, 5/28/02. Hold pre-spud safety meetng. Install second annular valve. Rig up circulating lines. Rig up Drill Site Maintenance lubricator and pull BPV. PJSM. Reverse circulate diesel out of tubing. Change lines and pump diesel out of 95/8" x 5 1/2" annulus. Circulate around 40 bbl Baraclean pill. Blow down lines. Install Two Way Check and test to 1000 psi. Nipple down tree and adapter. Nipple up BOP. Test BOP and surface valves to 250 psi and 3500 psi. NOTE: Witness waived by AOGCC rep. Chuck Scheve. Service top drive. Slip and cut drilling line. Wait on Drill Site Maintenance lubricator to pull Two Way Check. Only one DSM unit working at night, not available at time of call out (20:00 hrs) Wait on Drill Site Maintenance lubricator to pull Two Way Check. Only one DSM unit working at night, not available at time of call out (20:00 hrs) Rig up DSM lubricator. Pull two way check. Rig down lubricator. Screw into tubing hanger with 4" drill pipe and cross over. Pull tubing hanger to floor, max pull 200K, PU Wt 178K Rig up Cameo control line spooling unit. Lay down drill pipe joint, cross over and tubing hanger. Change handling tools to 5 1/2" . POH with 5 1/2" completion lay down tubing. Recovered SSSV, 25 rubber clamps and 4 stainless steel clamps. Rig down control line spooling unit. POH with 5 1/2" completion and lay down tubing. Recovered 12 gas lift mandrels and 5.34' of cut off tubing. Rig down 5 1/2" handling equipment and clear rig floor. Pressure test lower BOP pipe rams 250 psi and 3500 psi. Install wear bushing. Make up milling BHA with 9 5/8" casing scraper. RIH, work through wear bushing, continued RIH, tagged up at 56'. Work pipe wI 40 rpm, 1500 ftllbs Ta, 3 bpm with no success. POH to remove casing scraper from assembly. While working the BHA a tong die fell from the top drive grabber striking a worker on his hard hat and shoulder. Stop operation. Clear rig floor. Clear the rig floor and secure the area. The Derrick man inspects the top drive and confirms no danger of more falling objects. BP and Nabors supervisors and safety personnel are advised and an investigation is carried out. Remove casing scraper from BHA. RIH and tag up at 56'. Rotate and work mill down to 59'. Metal shavings on BHA. Lay down milling BHA. PJSM with rig crew and Schlumberger logging crew. Rig up Printed: 6/17/2002 11:39:34AM ) ') BP EXPLORATION Operations Summary R~port Page 2 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/29/2002 5/30/2002 5/31/2002 6/1/2002 6/2/2002 0-22 0-22 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: Spud Date: 12/22/1982 End: From - To Hours Task Code NPT Phase Description of Operations 22:30 - 00:00 1.50 CLEAN P DECOMP Schlumberger. Prepare to run gauge ring. 00:00 - 02:00 2.00 CLEAN P DECOMP Run 6 5/8" gage ring and junk basket with CCL, GR to 8350'. 02:00 - 03:00 1.00 CLEAN P DECOMP Lay down gage ring, pick up USIT logging tools. 03:00 - 07:00 4.00 CLEAN P DECOMP Run USIT log to 200'. Find under gage casing from 50 'to 58'. Run USIT log to 8350' with no problems. 07:00 - 08:00 1.00 CLEAN P DECOMP Rig down Schlumberger E-line unit. 08:00 - 09:30 1.50 CLEAN P DECOMP Pick up 8 5/16" swage BHA and RIH to 70' with no problems. 09:30 - 10:00 0.50 CLEAN P DECOMP Change out casing swage to 8 1/2". 10:00 - 12:00 2.00 CLEAN P DECOMP Work 8 1/2" casing swage through restriction from 55' to 57'. 12:00 - 12:30 0.50 CLEAN P DECOMP Change out casing swage to 8.58" 12:30 - 14:30 2.00 CLEAN P DECOMP Work 8.58" casing swage through restriction from 51' to 57'. Max drag after working through restriction 15K up and down. 14:30 - 15:30 1.00 CLEAN P DECOMP Inspect derrick and top drive after jarring operations. 15:30 - 16:30 1.00 CLEAN P DECOMP Lay down swaging BHA. 16:30 - 18:30 2.00 CLEAN P DECOMP Make up milling BHA with 9 5/8" casing scraper. 18:30 - 20:00 1.50 CLEAN P DECOMP RIH with milling BHA to 1100' pick up 4" drill pipe. No problems passing through restricted section between 51' and 57'. 20:00 - 21 :30 1.50 CLEAN P DECOMP Service top drive and adjust brakes. 21 :30 - 00:00 2.50 CLEAN P DECOMP RIH with milling BHA pick up 4" drill pipe. 00:00 - 04:00 4.00 CLEAN P DECOMP RIH with milling BHA to 8345' top of 5 1/2" tubing stub. Pick up 4" drill pipe. 04:00 - 05:00 1.00 CLEAN P DECOMP Circulate. Pump high vis sweep around. 05:00 - 08:00 3.00 CLEAN P DECOMP POH to milling BHA. 08:00 - 09:30 1.50 CLEAN P DECOMP Lay down casing scraper and mills. Stand back drill collars and HWDP. 09:30 - 10:30 1.00 CLEAN P DECOMP Rig up Schlumberger E-line unit. PJSM with crews. 10:30 - 12:30 2.00 CLEAN P DECOMP Run and set 9 5/8" EZSV bridge plug at 8311' 12:30 - 13:00 0.50 CLEAN P DECOMP Rig down E-line unit. 13:00 - 14:00 1.00 STWHIP P WEXIT Test 9 5/8" casing to 2500 psi for 30 minutes. OK. 14:00 - 17:30 3.50 STWHIP P WEXIT Pick up Whipstock and MWD tools. Test MWD. 17:30 - 21 :30 4.00 STWHIP P WEXIT RIH with Whipstock to 8301'. 21 :30 - 22:30 1.00 STWHIP P WEXIT Orient Whipstock to 20 Deg left of high side. Set Whipstock at 8301' with mill at 8278'. 22:30 - 00:00 1.50 STWHIP P WEXIT Displace sea water in well to 10.6 ppg LSND mud. 00:00 - 10:00 10.00 STWHIP P WEXIT Mill window in 9 5/8" casing from 8278' to 8294' and drill open hole to 8310'. 10:00 - 11 :00 1.00 STWHIP P WEXIT Work mill through window. Recovered 174 Ibs metal cuttings from milling operation. 11 :00 - 11 :30 0.50 STWHIP P WEXIT Perform FIT. TVD 8040' 600 psi with 10.6 ppg mud, EMW 12.0 ppg. 11 :30 - 14:30 3.00 STWHIP P WEXIT POH to BHA. 14:30 - 16:30 2.00 STWHIP P WEXIT Lay down mill and drill collars. Upper mill OD 8.51". 16:30 - 17:00 0.50 STWHIP P WEXIT Clear rig floor of milling tools. 17:00 - 18:30 1.50 STWHIP P WEXIT Flush out BOP, pull and inspect wear bushing. 18:30 - 20:00 1.50 DRILL P PROD1 Pick up 8 1/2" bit, mud motor and MWD. 20:00 - 20:30 0.50 DRILL P PROD1 Test MWD. 20:30 - 21 :00 0.50 DRILL P PROD1 RIH with drilling BHA, pick up 4" drill pipe. 21 :00 - 23:00 2.00 DRILL P PROD1 RIH to 7400'. 23:00 - 00:00 1.00 DRILL P PROD1 RIH. Drill to section TD. Circ. POH. Run liner. 00:00 - 00:30 0.50 DRILL P PROD1 Run tie-in log from 7442' to 7534' 00:30 - 01 :00 0.50 DRILL P PROD1 RIH to 8190'. 01 :00 - 02:00 1.00 DRILL P PROD1 Slip and cut Drilling line 91'. Printed: 6/17/2002 11 :39:34 AM ) ') BP EXPLORATION Operations SUl11maryReport Page 3 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/2/2002 6/3/2002 6/4/2002 0-22 0-22 REENTER+COMPLETE NABORS NABORS 2ES Spud Date: 12/22/1982 End: Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: From - To Hours Task Code NPT Phase Description of Operations 02:00 - 02:30 0.50 DRILL P PROD1 Service top drive. 02:30 - 03:30 1.00 DRILL P PROD1 Orient BHA above window. Pass through window and wash to 8310'. 03:30 - 13:00 9.50 DRILL P PROD1 Drill 8 1/2" directional hole to 8534'. ART= 1.4 Hrs AST= 5.1 Hrs 13:00 - 14:00 1.00 DRILL P PROD1 Repair pump #1. Change out swab. 14:00 - 00:00 10.00 DRILL P PROD1 Drill 8 1/2" directional hole to 8815'. ART= 5.0 Hrs AST= 3.75 Hrs 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate 25 bbl sweep around. 01 :00 - 01 :30 0.50 DRILL P PROD1 POH to 9 5/8" casing window. 01 :30 - 02:00 0.50 DRILL P PROD1 Serivce top drive. 02:00 - 03:00 1.00 DRILL P PROD1 RIH to bottom, 3' of fill. 03:00 - 04:30 1.50 DRILL P PROD1 Circulate 25 bbl weighted sweep around. 04:30 - 05:00 0.50 DRILL P PROD1 POH to 9 5/8" casing window. 05:00 - 05:30 0.50 DRILL P PROD1 Pump dry job and blow down surface equipment. 05:30 - 08:00 2.50 DRILL P PROD1 POH to BHA. 08:00 - 08:30 0.50 DRILL P PROD1 Change out handling equipment. 08:30 - 12:00 3.50 DRILL P PROD1 Lay down BHA. Down load MWD. 12:00 - 12:30 0.50 DRILL P PROD1 Pull wear bushing and install test plug. 12:30 - 13:30 1.00 DRILL P PROD1 Change top BOP rams to 7". 13:30 - 14:00 0.50 DRILL P PROD1 Test 7" rams to 250 psi and 3500 psi. Remove test plug install wear bushing. 14:00 - 14:30 0.50 DRILL P PROD1 Rig up to run 7" liner. 14:30 - 15:00 0.50 DRILL P PROD1 PJSM with crews on pick up and run liner. 15:00 - 15:30 0.50 DRILL P PROD1 Make up shoe track and check floats. 15:30 - 16:30 1.00 DRILL P PROD1 Run 16 jts 7" 26# L-80 BTC-M liner. Pick up Baker 9 5/8" x 7" HMC liner hanger with ZXP liner top packer. 16:30-17:00 0.50 DRILL P PROD1 Circulate liner volume. 17:00 - 21 :00 4.00 DRILL P PROD1 RIH with liner on 4" drill pipe to casing window. 21 :00 - 21 :30 0.50 DRILL P PROD1 Circulate drill pipe and liner volume. 21 :30 - 22:00 0.50 DRILL P PROD1 RIH with liner on 4" drill pipe to 8815' with top of liner at 8147'. 22:00 - 22:30 0.50 DRILL P PROD1 Make up cementing head and lines. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate and condition mud prior to cement job. 00:00 - 00:30 0.50 DRILL P PROD1 Circulate and condition mud prior to cement job. 7 BPM and reciprocate pipe. PJSM with crew. 00:30 - 01 :30 1.00 DRILL P PROD1 Pump 5 bbl water. Test lines to 4000 psi. Pump 5 bbl water. Pump 50 bbl weighted Alpha Spacer. Mix and pump 35.8 bbl (175 sx) Premum cement at 15.8 ppg at 4 bpm. Displace with cementing unit with mud at 6 bpm. Bump plug. Cement in place at 01 :31 6/4/2002. Floats held. 01 :30 - 02:00 0.50 DRILL P PROD1 Set liner hanger with 4000 psi. Release from liner hanger. Pick up and circulate. Set ZXP liner top packer with 80K down weight. 02:00 - 03:00 1.00 DRILL P PROD1 Circulate. Recover Alpha Spacer and trace of cement returns. 03:00 - 04:00 1.00 DRILL P PROD1 Rig down cement head and lines. 04:00 - 07:00 3.00 DRILL P PROD1 POH with liner hanger running tools. 07:00 - 07:30 0.50 DRILL P PROD1 Lay down liner hanger runing tools. Clear rig floor. 07:30 - 08:30 1.00 DRILL P PROD1 Change out rams, 7" to 31/2" x 6" variable. 08:30 - 09:00 0.50 DRILL P PROD1 Pull wear bushing and install test plug. 09:00 - 12:00 3.00 DRILL P PROD1 Test BOP and all related valves to 250 psi and 3500 psi. NOTE: Witness waived AOGCC rep. John Crisp. Printed: 6/17/2002 11:39:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BPEXPLORATION Operations Summary Report Page 4 of 6 0-22 0-22 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: Spud Date: 12/22/1982 End: Date From -To Hours Task Code NPT Phase Description of Operations 6/4/2002 12:00 - 12:30 0.50 DRILL P PROD1 Pull test plug and install wear bushing. 12:30 - 14:00 1.50 DRILL P PROD1 Make up MWD and 61/8" drilling BHA. Pin from drill collar safety clamp fell down the hole. Pin dimentions 4 1/4" long, 3/4" diameter. 14:00 -15:30 1.50 DRILL N SFAL PROD1 Stand back BHA. 15:30 - 16:00 0.50 DRILL P PROD1 Service top drive. 16:00 - 17:30 1.50 DRILL N SFAL PROD1 Make up milling BHA with 61/8" junk mill. 17:30 - 20:30 3.00 DRILL N SFAL PROD1 RIH with milling BHA to 8131'. Tag top of 7" liner. 20:30 - 21 :00 0.50 DRILL N SFAL PROD1 Circulate and wash top of 7" liner at 8131'. 21 :00 - 21 :30 0.50 DRILL N SFAL PROD1 RIH to 8510'. 21 :30 - 00:00 2.50 DRILL N SFAL PROD1 Drill cement from 8510' to 8603' 6/5/2002 00:00 - 03:30 3.50 DRILL N SFAL PROD1 Mill cement from 8603' to 8720' 03:30 - 04:30 1.00 DRILL N SFAL PROD1 Circulate bottoms up. 04:30 - 05:00 0.50 DRILL P PROD1 Test 9 5/8" casing, 7" liner and liner top packer to 2500 psi OK. 05:00 - 08:30 3.50 DRILL P PROD1 Mill float equipment and cement to 8804'. 08:30 - 09:30 1.00 DRILL P PROD1 Circulate hole clean. Pump dry job, blow down surface lines. 09:30 - 13:00 3.50 DRILL N SFAL PROD1 POH to BHA. SLM. 13:00 - 14:30 1.50 DRILL N SFAL PROD1 Lay down BHA and junk subs. 14:30-17:00 2.50 DRILL P PROD1 Make up 6 1/8" drilling BHA. 17:00 - 17:30 0.50 DRILL P PROD1 Test MWD. OK. 17:30 - 19:00 1.50 DRILL P PROD1 RIH to 2850'. Pick up 4" drill pipe. 19:00 - 21 :30 2.50 DRILL P PROD1 RIH to 8720'. 21 :30 - 22:30 1.00 DRILL P PROD1 Slip and cut 81' of drilling line. 22:30 - 23:00 0.50 DRILL P PROD1 PJSM with crew on mud change out. 23:00 - 00:00 1.00 DRILL P PROD1 Displace well to 8.4 ppg Quickdril-N mud. 6/6/2002 00:00 - 02:00 2.00 DRILL P PROD1 Displace well to 8.4 ppg Quickdril-N mud. 02:00 - 03:00 1.00 DRILL P PROD1 Drill out 7" shoe and 20 ' of new hole to 8835'. 03:00 - 04:30 1.50 DRILL P PROD1 Circulate and condition mud to constant weight. 04:30 - 05:00 0.50 DRILL P PROD1 Perform FIT. EMW 10.5 ppg with 930 psi, 8505 TVD. 05:00 - 00:00 19.00 DRILL P PROD1 Drill 6 1/8" directional hole to 9355'. Rotate and slide to control angle and direction. ART= 9.15 hrs AST= 7.25 hrs 6/7/2002 00:00 - 18:00 18.00 DRILL P PROD1 Drill 6 1/8" directional hole from 9355' to 9944'. Rotate and slide to control angle and direction. ART= 4.15 hrs AST= 9.2 hrs 18:00 - 20:00 2.00 DRILL P PROD1 Circulate around high vis sweep. 20:00 - 21 :00 1.00 DRILL P PROD1 POH to 8730'. No excessive drag. 21 :00 - 21 :30 0.50 DRILL P PROD1 Pump dry job. Blow down top drive and lines. 21 :30 - 00:00 2.50 DRILL P PROD1 POH to 3412'. No excessive drag. 6/8/2002 00:00 - 01 :30 1.50 DRILL P PROD1 POH from 3412' to BHA. No excessive drag. 01 :30 - 03:00 1.50 DRILL P PROD1 Handle BHA. Remove Radio active source, lay down tool. Change bit. 03:00 - 04:30 1.50 DRILL P PROD1 Make up BHA and surface check MWD. 04:30 - 07:00 2.50 DRILL P PROD1 RIH to 8798'. 07:00 - 07:30 0.50 DRILL P PROD1 Service top drive. 07:30 - 08:00 0.50 DRILL P PROD1 RIH from 8798' to 9944'. No fill. 08:00 - 00:00 16.00 DRILL P PROD1 Drill 6 1/8" directional hole from 9944' to 1 0667'. Slide and rotate for angle and directional control. Pump sweeps to enhance hole cleaning. ART= 10 hrs AST= 2.4 hrs Printed: 6/17/2002 11:39:34AM ') ') BP EXPLORATION Operations Summary <Report Page 50f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-22 0-22 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: Spud Date: 12/22/1982 End: Date From- To Hours Task Code NPT Phase Description of Operations 6/9/2002 00:00 - 06:00 6.00 DRILL P PROD1 Drill 6 1/8" directional hole from 1 0667' to 1 0945'. Slide and rotate for angle and directional control. Pump sweeps to enhance hole cleaning. ART= 4.4 hrs AST= 1.1 hrs 06:00 - 08:00 2.00 DRILL P PROD1 Circulate around sweep. 08:00 - 10:30 2.50 DRILL P PROD1 Wiper trip to 7" liner shoe. No problems. 10:30 - 13:00 2.50 DRILL P PROD1 Circulate around sweep. Spot liner running pill. 13:00 - 15:00 2.00 DRILL P PROD1 POH from 10945' to 8800'. Lay down 4" drill pipe. Drop 2" drill pipe drift. 15:00 - 19:30 4.50 DRILL P PROD1 POH from 8800' to 7525'. Run MAD pass log from 7525' to 7425'. POH to BHA. SLM. 19:30 - 21 :30 2.00 DRILL P PROD1 Lay down BHA. Down load MWD. 21 :30 - 23:30 2.00 CASE P CaMP Rig up casing tongs and compensator to run 4 1/2" liner. 23:30 - 00:00 0.50 CASE P CaMP Make up 4 1/2" float equipment. 6/10/2002 00:00 - 00:30 0.50 CASE P CaMP Make up 4 1/2" float equipment and check floats.. 00:30 - 04:30 4.00 CASE P CaMP Run 54 jts 41/2" 12.6# 13CR80 Vam Ace liner. 04:30 - 05:00 0.50 CASE P CaMP Make up 5" x 7" HMC hydraulic liner hanger with ZXP liner top packer. Pick up 1 stand 4" drill pipe. 05:00 - 05:30 0.50 CASE P CaMP Circulate liner volume. 05:30 - 09:00 3.50 CASE P CaMP Run 41/2" liner on 4" drill pipe to 8108'. Fill pipe every 1 0 stands. 09:00 - 09:30 0.50 CASE P CaMP Circulate drill pipe and liner volume. 09:30 - 10:30 1.00 CASE P CaMP Run 41/2" liner on 4" drill pipe from 8108' to 10945'. No problems. 1 0:30 - 11 :00 0.50 CEMT P CaMP Make up cementing head and lines. 11 :00 - 12:30 1.50 CEMT P CaMP Circulate and reciprocate pipe. Final rate 8 BPM at 1150 psi. Hold PJSM with crew, Haliburton and Peak truck drivers. 12:30 - 14:00 1.50 CEMT P CaMP Test lines with fresh water to 4000 psi. Pump 10 bbl Kcl water and 25 bbl Alpha spacer weighted to 9.6 ppg. Mix and pump 63 bbl (300 sx) class G cement at 15.6 ppg. Displace using cementing unit with 51 bbl perf pill and 69 bbl mud at 5.5 BPM. Bump plug. Cement in palce at 13:42 hrs. Pressure up to 3500 psi to set liner hanger. Floats held. Release form liner, pick up, circulate to clear cement from liner top. Set ZXP liner top Packer with 70K weight down. 14:00 - 15:00 1.00 CEMT P CaMP Circulate. Recovered 1 bbl contaminated cement in returns. 15:00 - 16:30 1.50 CEMT P CaMP Displace mud in well with sea water. 16:30 - 17:00 0.50 CEMT P CaMP Rig down cement head and lines. 17:00 - 19:30 2.50 CEMT P CaMP POH with liner hanger setting tools from 8717' to 2000'. Test choke on trip. 19:30 - 20:30 1.00 CEMT P CaMP Slip and cut 95' drilling line. 20:30 - 21 :00 0.50 CEMT P CaMP Service top drive. 21 :00 - 22:00 1.00 CEMT P CaMP POH from 2000' to surface. Lay down running tools. 22:00 - 23:00 1.00 PERF P CaMP Pull wear bushing. Set test plug and rig up to test BOP. 23:00 - 00:00 1.00 PERF P CaMP Test BOP 250 psi low and 3500 psi high. 6/11/2002 00:00 - 02:30 2.50 PERF P CaMP Continue testing BOPE. Test upper pipe RAMS, and hyd choke to 250 I 3,500 psi for 5/5 minutes. Test Annular and manual Kill and Choke valves to 250 I 3,500 psi, for 5/5 minutes. Test TD, (2) TIW valves, and dart valve to 250 I 3,500 psi for 5/5 minutes. Test Blind RAMS, HYD Kill and Choke valves to 250 I 3,500 psi for 5/5 minutes. Testing witnessed by Jeff Jones of the AOGCC. Printed: 6/17/2002 11 :39:34 AM ') ) BP EXPLORATION Operations Sum máry Report Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-22 0-22 REENTER+COMPLETE NABORS NABORS 2ES Start: 5/28/2002 Rig Release: 6/13/2002 Rig Number: Spud Date: 12/22/1982 End: Date From- To Hours Task Code NPT Phase Description of Operations 6/11/2002 02:30 - 03:00 0.50 PERF P COMP Pull test plug, install wear bushing. 03:00 - 03:30 0.50 PERF P COMP Pressure test casing to 2,500 psi for 30 min - okay. 03:30 - 04:00 0.50 PERF P COMP PJSM, RU handling tools for perf guns. 04:00 - 05:30 1.50 PERF P COMP PU 2-1/2" TCP perf guns with 500' loaded, and no blank intervals. 05:30 - 07:00 1.50 PERF P COMP PU 56 joints (1,762.5') of 2-3/8" drillpipe. 07:00 - 13:00 6.00 PERF P COMP RIH with 4" drillpipe and tag up on landing collar at 10,857'. UWT=173K, DWT = 157K. PU to 10,650' to locate on depth. 13:00 - 14:00 1.00 PERF P COMP Pressure drillpipe to 2,500 psi, and bleed off pressure. Fire guns. Perforate 10,650'-10,150', with 2-1/2" scalloped guns, with 4 SPF and 60 degree shot phasing, using 11 gm, Millennium HMX charges. POOH to 10,025', monitor wellbore - static. 14:00 - 15:30 1.50 PERF P COMP Pump slug, POOH, standing back 4" drillpipe. 15:30 - 18:30 3.00 PERF P COMP Continue POOH laying down 4" drillpipe. 18:30 - 20:30 2.00 PERF P COMP RU handling equipment and continue POOH, and LD 2-3/8" drillpipe. No SW was lost while POOH. 20:30 - 22:00 1.50 PERF P COMP PJSM, LD perf guns, all shots fired. 22:00 - 23:00 1.00 PERF P COMP Rig down handling equipment, clear rig floor. 23:00 - 23:30 0.50 RUNCOIVP COMP PuIlWB. 23:30 - 00:00 0.50 RUNCOIVP COMP RU 4-1/2" handling equipment. 6/12/2002 00:00 - 00:30 0.50 RUNCOIVP COMP RU tubing handling equipment. 00:30 - 13:00 12.50 RUNCOIVP COMP Run completion and tread-lock tail assembly. Run 200 Jts of 4-1/2", 12.61b/ft, 13CR, VAM-ACE tubing with an average MU torque of 3,400 ft-Ib. 13:00 - 14:00 1.00 RUNCOIVP COMP Stab into the tie-back recepticle and tag up at 8,632'. DWT=120K, UWT=125K. Space out with 2.29' + 6.17' pups. 14:00 - 16:00 2.00 RUNCOIVP COMP Make up tbg hanger and landing joint. Land tubing hanger, run in Lock Down Screws. 16:00 - 19:30 3.50 RUNCOIVP COMP Reverse circulate corrosion inhibitor at 3 BPM and 170 psi. 19:30 - 21 :00 1.50 RUNCOIVP COMP Drop 1-7/8" Ball and Rod. Pressure up tubing to 3,500 psi, (set permanent packer at 1,900 psi), and test tubing for 30 min - okay. Bleed tubing pressure to 1,500 psi. Pressure up annulus to 2,500 psi and test packer + casing for 30 min - okay. Bled down tubing pressure, and RP sheared with 1,500 psi, of differential pressure. 21 :00 - 22:00 1.00 BOPSURP COMP Install TWC and test from below to 2,000 psi - okay. Blow down surface equipment. 22:00 - 00:00 2.00 RUNCOIVP COMP ND BOPE. 6/13/2002 00:00 - 03:00 3.00 WHSUR P COMP NU adapter flange and tree. 03:00 - 03:30 0.50 WHSUR P COMP Pressure test flange to 5,000 psi - okay. 03:30 - 04:30 1.00 WHSUR P COMP Attempt to test tree. Leaks in Wing and Master valves. Repack valves. Test tree to 5,000 psi - okay. 04:30 - 05:00 0.50 WHSUR P COMP Pull TWC with lubricator and LD. 05:00 - 06:30 1.50 WHSUR P COMP RU Hot Oil services and freeze protect tubing and annulus wI 155 bbl of diesel. 06:30 - 07:30 1.00 WHSUR P COMP U-tube diesel. 07:30 - 08:00 0.50 WHSUR P COMP Set BPV and pressure test to 2,000 psi - okay. 08:00 - 09:00 1.00 WHSUR P COMP Install secondary annulus valve, secure tree. RIG RELEASED AT 09:00 6/13/2002. Printed: 6/17/2002 11 :39:34 AM 'r } ) ~ o?oa-- J o~ 08-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 0-228 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,193.33' MD Window / Kickoff Survey: 8,278.00' MD (if applicable) Projected Survey: 10,945.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED JUL 1 0 2002 AJalka Oil & Gas Cons. Commission AncfJorage . w - ) ~ ROOMS 8Ft AliG 2 2 2f1D2 r-~--::' North Slope A-I.aka BPXA PBU_WOA 0 Pad, Slot 0-22 0-22BMWD Job No. AKMW22188, SURVEY REPORT 28 June, 2002 Your Ref: API.6iJ02ØI1l3702 Surface Coordinates: 5959438.00 N, 853480.00E (fr'11' 48.0898" N, 148045' 28.3074" W) Kelly Bushing: 71.B3ft abovellean Sea Level ~, IIp8II 'ï IV-did" o..ILLIW-- 81I'RvU... A Halliburton Company Survey Ref: svy11226 Sperry-Sun DrilliQ8,.Services . Survey Report'ør~~.:ÃfWl) Your Ref: API$DD~7D2 Job No. AlCh .' .- BPXA North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlnge Eastlngs Northlnge Eaetlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8193.33 19.050 135.500 7888.06 7959.89 807.91 5 1112.45 E 5958652.97 N 654588.72 E 1356.13 Tie On Point MWD Magnetic 8278.00 18.810 136.090 7968.15 8039.98 827.60 5 1131.61 E 5958633.68 N 654608.27 E 0.363 1383.60 Window Point 8344.55 22.060 136.730 8030.50 8102.33 844.435 1147.62 E 5958617.18 N 654624.62 E 4.895 1406.83 8407.93 24.670 137.200 8088.68 8160.51 862.81 5 1164.77 E 5958599.16 N 654642.14 E 4.128 1431.95 8498.65 29.300 137.740 8169.50 8241.33 893.145 1192.57 E 5958569.39 N 654670.56 E 5.111 1473.08 8590.70 32.560 138.180 8248.45 8320.28 928.28 5 1224.25 E 5958534.91 N 654702.94 E 3.550 1520.34 8622.95 33.100 138.690 8275.55 8347.38 941.36 5 1235.85 E 8858522.07 N 654714.81 E 1.881 1537.80 8683.77 35.210 139.680 8325.88 8397.71 967.21 S 1258.18 E &958498.68 N 654737.84 E 3.588 1571.87 8751.82 35.240 142.210 8381.47 8453.30 997.68 5 1282.88 E 5958466.72 N 654762.98 E 2.145 1610.93 8850.37 35.240 141.050 8461.96 8533.79 1 042.26 5 1318.18 E 5958422.87 N 654799.18 E 0.679 1667.46 8944.23 34.950 133.150 8538.80 8610.63 1081.735 1354.83 E 5958384.16 N 654836.64 E 4.846 1721.31 9038.36 33.970 131.860 8616.41 8688.24 1117.725 1394.09 E 5958348.98 N 654876.62 E 1.298 1774.49 9131.44 34.060 132.810 8693.56 8765.39 1152.795 1432.58 E 5958314.70 N 654915.82 E 0.579 1826.48 9165.20 38.330 136.260 8720.80 8792.63 1166.785 1446.76 E 5958301.00 N 654930.28 E 14.010 1846.41 9197.28 41.600 139.550 8745.39 8817.22 1182.085 1460.55 E 5958285.99 N 654944.39 E 12.134 1866.96 9225.04 42.960 141.680 8765.93 8837.76 1196.525 1472.40 E 5958271.80 N 654956.52 E 7.116 1885.58 9257.12 48.070 145.090 8788.41 8860.24 1214.895 1486.02 E 5958253.70 N 654970.51 E 17.638 1908.23 - 9290.22 50.570 147.350 8809.98 8881.81 1235.765 1499.96 E 5958233.13 N 654984.88 E 9.157 1932.88 9317.67 50.570 147.190 8827.42 8899.25 1253.59 5 1511.43 E 5958215.53 N 654996.71 E 0.450 1953.64 9351.44 54.060 147.260 8848.06 8919.89 1276.06 5 1525.89 E 5958193.36 N 655011.63 E 10.336 1979.80 9383.68 58.350 147.960 8865.98 8937.81 1298.68 5 1540.24 E 5958171.04 N 655026.43 E 13.428 2005.98 9412.34 58.510 148.220 8880.99 8952.82 1319.41 5 1553.15 E 5958150.58 N 655039.76 E 0.953 2029.81 9443.80 62.690 147.690 8896.43 8968.26 1342.635 1567.69 E 5958127.65 N 655054.77 E 13.367 2056.56 9474.49 66.710 146.270 8909.54 8981.37 1365.89 S 1582.81 E 5958104.71 N 655070.37 E 13.750 2083.75 9505.47 67.980 145.700 8921.48 8993.31 1389.59 5 1598.80 E 5958081.35 N 655086.84 E 4.437 2111.85 9537.72 72.750 144.870 8932.31 9004.14 1414.55 S 1616.10 E 5958056.75 N 655104.64 E 14.988 2141.77 9568.79 76.760 145.170 8940.48 9012.31 1439.105 1633.28 E 5958032.55 N 655122.32 E 12.940 2171.33 9599.06 81.600 146.970 8946.16 9017.99 1463.775 1849.86 E 5958008.23 N 655139.41 E 17.022 2200.54 9628.21 86.610 147.160 8949.15 9020.98 1488.10 S 1665.62 E 5957984.22 N 655155.66 E 17.202 2228.93 9662.61 89.750 147.080 8950.24 9022.07 1516.97 S 1684.28 E 5957955.73 N 655174.90 E 9.133 2262.60 ._~---~--- 28 June, 2002 - 15:09 Page 2 of of Dr/llQuest 200.08.005 Sperry-Sun Dr;lli1J'!$~rvices . Survey Reportf6rtJ.r~.1IWD Your Ref: API ~ 702 Job No. A BPXA North Slope Alaska PBU_WOA D Pad Mea8ured Sub-Sea Vertical Local Coordlnattl GlobIl Coordln.. Dogleg Vertical Depth Incl. Azlm. Depth Depth Northing. EI.tlng. Northlnga Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9692.31 91.600 145.400 8949.89 9021.72 1541.668 1700.18 E 6951931.39 N 655191.90 E 8.414 2291.77 9722.74 90.550 141.590 8949.32 9021.15 1566.11 S 1118.8ð E 5951901.31 N 655210.50 E 12.985 2321.89 9784.43 90.180 139.330 8948.93 9020.76 1613.688 1758.15 E 5951860.55 N 655250.73 E 3.712 2383.34 9876.52 89.140 138.880 8949.48 9021.31 1683.29 S 1818.43 E 5951792.19 N 655312.42 E 1.231 2475.24 9945.35 88.950 139.910 8950.62 9022.45 1735.54 S 1863.22 E 5957740.87 N 655358.27 E 1.521 2543.90 10038.94 89.630 138.000 8951.78 9023.61 1806.118 1924.67 E 5957671.56 N 655421.15 E 2.166 2637.31 10132.95 88.280 139.000 8953.50 9025.33 1876.51 S 1986.95 E 5951602.45 N 655484.85 E 1.787 2731.16 10227.16 89.200 136.050 8955.57 9027.40 1945.978 2050.55 E 5951534.30 N 655549.85 E 3.279 2825.28 10322.04 88.460 135.410 8957.51 9029.34 2013.89 S 2116.76 E 5957467.75 N 655617.44 E 1.031 2920.14 10414.82 89.140 132.930 8959.45 9031.28 2078.52 8 2183.29 E 5957404.49 N 655685.27 E 2.771 3012.87 10508.66 91.480 137.990 8958.94 9030.77 2145.38 S 2249.08 E 5957338.99 N 655752.42 E 5.940 3106.67 10602.27 92.770 144.640 8955.47 9027.30 2218.36 S 2307.52 E 5951261.22 N 655812.33 E 7.231 3199.67 10696.20 94.000 149.990 8949.92 9021.75 2297.24 S 2358.14 E 5951189.38 N 655864.55 E 5.835 3291.40 10786.19 94.620 151.310 8943.16 9014.99 2375.46 8 2402.12 E 5957112.08 N 655910.12 E 1.617 3378.00 10877.07 94.000 150.160 8936.33 9008.16 2454.51 S 2446.42 E 5957033.95 N 655956.03 E 1 .434 3465.42 10945.00 94.000 150.160 8931.59 9003.42 2513.29 S 2480.14 E 5956975.87 N 655990.94 E 0.000 3530.97 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. -- lertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference . The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 135.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0945. 0 Oft. , The Bottom Hole Displacement is 3530. 97ft. , in the Direction of 135.380° (True). ------.---- 28 June, 2002 - 15:09 Page 3 of4 DrIllQuesl2.00.08.005 Sperry-Sun Dtillj .~ Survey Reportr.ÒÎ'r~~ Your Ref:APlrtJi Job No. A . -.~~,;'i.:y , . North Slope Alaska BPXA PBU_WOA D Pad Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 8193.33 8278.00 10945.00 7959.89 8039.98 9003.42 807.91 S 827.60 S 2513.29 S 1112.45 E 1131.61E 2480.14 E Tie On Point Window Point Projected SUNey Survey tool program for 0-228 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 8193.33 0.00 8193.33 7959.89 10945.00 7959.89 AK-1 BP _HG - BP High Accuracy Gyro (D-22) 9003.42 MWD Magnetic (Dø22B MWD) /- -----~- ------~---- 28 June, 2002 - 15:09 Page " of" DrlffQuest 1.00.08.005 ) ) óìœ.. JoS 08-Jul-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well D-228 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,193.33' MD Window / Kickoff Survey 8,278.00' MD (if applicable) Projected Survey: 10,945.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED '~'I A "00 \'>J~ ;' 0 L 2 Alaska Oil & Gas Cons. Camm' , Anchorage lSSion ú) 0 - ) Sð ~ "ö .~.. -. -:;:1 1\. i T'.- i V r:.. .J r:~; I ~ . a - - -I..~ North Slop. A.aka BPXA PBU_WOA D Pad, Slot D-22 D.22S Job No. AKZZ22OB6, Surve",-:' June, 2002 SURVEY ".ORT 28June,20Q1 Your Ref: API StJD2ØØ13702 Surface Coordinates: 5959438.00 N, 65U60.tJO E (tlP 17' 46.0698" N, 148045' 26.3074" W) Kelly Bushing: 71.83ft above Mean S.. Level -- Survey Ref: svy11225 . BPXA North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 8193.33 19.050 135.500 7888.06 7959.89 807.91 8 1112.45E 5958652.97 N 654588.72 E 1356.13 Tie On Point .~ AK-6 BP _IFR-AK 8278.00 18.810 136.090 7968.15 8039.98 827.60 8 1131.61 E 5958633.68 N 654608.27 E 0.363 1383.60 Window Point 8344.55 22.060 136.730 8030.50 8102.33 844.438 1147.62 E 5958617.18 N 654624.62 E 4.895 1406.83 8407.93 24.670 137.200 8088.68 8160.51 862.81 8 1164.77 E 5958599.16 N 654642.14 E 4.128 1431.95 8498.65 29.300 137.740 8169.50 8241.33 893.14 S 1192.57 E 5958569.39 N 654670.56 E 5.111 1473.08 8590.70 32.560 138.180 8248.45 8320.28 928.28 8 1224.25 E 5958534.91 N 654702.94 E 3.550 1520.34 8622.95 33.100 138.320 8275.55 8347.38 941.338 1235.89 E 5958522.10 N 654714.85 E 1.691 1537.80 8683.77 35.210 139.200 8325.88 8397.71 967.01 8 1258.39 E 5958496.89 N 654737.87 E 3.563 1571.89 8751.82 35.240 142.190 8381,47 8453.30 997.37 8 1283.25 E 5958467.04 N 654763.34 E 2.535 1610.96 8850.37 35.240 141.590 8461.96 8533.79 1042.11 8 1318.34 E 5958423.02 N 654799.34 E 0.351 1667.47 8944.23 34.950 133.410 8538.80 8610.63 1081.838 1354.72 E 5958384.06 N 654836.52 E 5.017 1721.29 9038.36 33.970 131.900 8616.41 8688.24 1117.928 1393.88 E 5958348.77 N 654876.41 E 1.381 1774.48 9131.44 34.060 132.570 8693.57 8765.40 1152.928 1432.43 E 5958314.57 N 654915.67 E 0.414 1826.47 9165.20 38.330 136.240 8720.81 8792.64 1166.888 1446.64 E 5958300.90 N 654930.16 E 14.179 1846.39 9197.28 41.600 139.590 8745.39 8817.22 1182.188 1460.43 E 5958285.88 N 654944.26 E 12.199 1866.97 9225.04 42.960 141.800 8765.93 8837.76 1196.64 8 1472.25 E 5958271.68 N 654956.38 E 7.258 1885.56 9257.12 48.070 145.450 8788.41 8860.24 1215.078 1485.79 E 5958253.52 N 654970.29 E 17.873 1908.20 9290.22 50.570 147.220 8809.98 8881.81 1235.96 S 1499.70 E 5958232.92 N 654984.62 E 8.572 1932.85 t- -.,,==.... 9317.67 50.570 147.060 8827.42 8899.25 1253.778 1511.20 E 5958215.35 N 654996.49 E 0.450 1953.61 9351.44 54.060 147.170 8848.06 8919.89 1276.21 8 1525.71 E 5958193.21 N 655011.45 E 10.338 1979.78 9383.68 58.350 147.290 8865.99 8937.82 1298.748 1540.21 E 5958170.98 N 655026.41 E 13.310 2006.00 9412.34 58.510 147.720 8880.99 8952.82 1319.338 1553.33 E 5958150.66 N 655039.94 E 1.395 2029.88 9443.80 62.690 147.670 8896.43 8968.26 1342.49 8 1567.97 E 5958127.80 N 655055.06 E 13.287 2056.66 9474.49 66.710 145.940 8909.55 8981.38 - 1365.708 1583.16 E 5958104.91 N 655070.72 E 14.055 2083.86 9505.47 67.980 145.440 8921.48 8993.31 1389.31 8 1599.28 E 5958081.63 N 655087.31 E 4.362 2111.99 9537.72 72.750 144.900 8932.31 9004.14 1414.248 1616.62 E 5958057.06 N 655105.16 E 14.874 2141.93 9568.79 76.760 144.370 8940.48 9012.31 1438.68 8 1633.97 E 5958032.98 N 655123.Ò1 E 13.011 2171.51 9599.06 81.600 146.820 8946.16 9017.99 1463.2Ò 8 1650.76 E 5958008.81 N 655140.29 E 17.856 2200.77 9628.21 86.610 147.080 8949.16 9020.99 1487.508 1666.57 E 5957984.84 N 655156.59 E 17.210 2229.17 9662.61 89,750 146.620 8950.25 9022.08 1516.28,8 1685.37 E 5957956.45 N 655175.98 E 9.225 2262.88 28 June, 2002 - 15:04 Page 20'4 DrillQuest 2.00.08.005 Sperry-Sun DI!i!l'..- ices . Survey ReIIi#fti!t . Your Ref: APlftlG L " ',02 Job No. AKZZ22tJ88,~:", . '~Z"-='.!,,'ljUtle,2002 BPXA North Slope Alaska PBU_WOA D Pad M...ured Sub-Sea Vertical Loc.1 Coordinate. Global Coordinate. Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlnga Ea.tlnga Northlngs Elating. Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9692.31 91.600 144.150 8949.90 9021.73 1540.72 S 1702.24 E 5957932.36 N 655193.34 E 10.390 2292.13 9722.74 90.550 140.130 8949.33 9021.16 1564.745 1720.91 E 5957908.73 N 655212.50 E 13.651 2322.34 ..' 9784.43 90.180 137.510 8948.93 9020.76 1611.165 1761.52 E 5è57863.14 N 655254.05 E 4.289 2383.91 9876.52 89.140 137.600 8949.48 9021.31 1679.11 5 1823.67 E 5957796.47 N 655317.57 E 1.134 2475.94 9945.35 88.950 136.760 8950.63 9022.46 1729.59 5 1870.44 E 5957746.96 N 655365.37 E 1.251 2544.73 10038.94 89.630 136.730 8951.79 9023.62 1797.755 1934.57 E 5957680.12 N 655430.87 E 0.727 2638.29 10132.95 88.280 136.040 8953.50 9025.33 1865.80 5 1999.41 E 5957613.41 N 655497.09 E 1.613 2732.27 10227.16 89.200 135.710 8955.57 9027.40 1933,41 5 2064.98 E 5957547.16 N 655564.03 E 1.037 2826.45 10322.04 88.460 135.110 8957.51 9029.34 2000.96 5 2131.58 E 5957480.98 N 655631.99 E 1.004 2921.31 10414.82 89.140 134.940 8959.45 9031.28 2066.58 5 2197.14 E 5957416.71 N 655698.88 E 0.755 3014.07 10508.66 91.480 140.090 8958.95 9030.78 2135.755 2260.49 E 5957348.85 N 655763.63 E 6.028 3107.81 10602.27 92.770 143.120 8955.48 9027.31 2209.06 5 2318.58 E 5957276.74 N 655823.20 E 3.516 3200.80 10696.20 94.000 148.420 8949.93 9021.76 2286.55 5 2371.31 E 5957200.34 N 655877.50 E 5.783 3293.02 10786.19 94.620 148.910 8943.16 9014.99 2363.20 5 2417.98 E 5957124.66 N 655925.72 E 0.877 3380.38 10877.07 94.000 148.480 8936.33 9008.16 2440.63 5 2465.06 E 5957048.21 N 655974.38 E 0.829 3468.60 10945.00 94.000 148.480 8931.59 9003.42 2498.39 5 2500.49 E 5956991.18 N 656010.98 E 0.000 3534.62 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ,~ Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference . The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 135.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0945.0Oft. , The Bottom Hole Displacement is 3534.75ft., in the Direction of 134.976° (True). -------- ------- - , 28 June, 2002 - 15:04 PIIge 3 of" DrillQuest 2.00.08.005 North Slope Alaska Comments "'~-=" Measured Depth (ft) 8193.33 8278.00 10945.00 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 7959.89 8039.98 9003.42 807.91 S 827.60 S 2498.39 S 1112.45 E 1131.61 E 2500.49 E Tie On Point Window Point Projected Survey Survey tool program for D-228 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 8193.33 - 28 June, 2002 - 15:04 0.00 8193.33 7959.89 10945.00 7959.89 AK-1 BP _HG ø BP High Accuracy Gyro (D-22) 9003.42 AK-6 BP _IFR-AK (D-22B) -~- ----- Page" of" . . s BPXA PBU_WOA D Pad DrlllQuest 2.00.08.005 Scblllllbel'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth Well Job# J3-23A 1 q Î~ 0 ~9 M-12A ~OO-'51 M-17A ~OD-O...~ D-228 ~D~.../o5 Log Description Date 22227 RSTøSIGMA 22253 MCNL 22305 SCMT 22272 USIT 04/29/02 04/25/02 06/08/02 06/07/02 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED 11 if 1 rì 2002 VVL... Ii- Alaska Oi! & Gas Cons. Commission Anchorage Blueline 07/09/02 NO. 2198 Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD -~~ 2 2 . ,~~. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Recelvedb~~' ~~ ( ~~fÆ~E : F fÆ~fÆ~~~fÆ A.I,A.SKA. OIL A1O) GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -r" AVENUE. SUITE 1 00 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit D-22B BP Exploration (Alaska), Inc. Permit No: 202-105 Sur Loc: 1550' SNL, 1692' WEL, Sec. 23, TIIN, R13E, UM Btmhole Loc. 4064' SNL, 780' EWL, Sec. 24, TIIN, R13E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redriIl 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 detenTIinations 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. Sincerely, Cæ~~~ Cammy ~chsli Taylor ( Chair BY ORDER OF THE COMMISSION DATED this£ day of May, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 8-1/2" 6-1/8" STATE OF ALASKA , ALASKA olf .NO GAS CONSERVATION COMMIS! .IN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test R Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 71.63' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028285 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ( D-22B 9. Approximate spud date 06/01/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10950' MD I 9003' TVD 17. Anticipated pressure {se~ 20 AAC 25.035 (e) (2)} 920 Maximum surface 2400 ~Sig At total depth (TVD) 8800' I 3275 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 662' 8150' 7913' 8812' 8505' 2288' 8662' 8394' 10950' 9003' 'JJ(;,A- 5/~1 f} L f4q; 1 a. Type of work 0 Drill R Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519ø6612 4. Location of well at surface 1550' SNL, 1692' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 3039' SNL, 62' EWL, SEC. 24, T11 N, R13E, UM At total depth 4064' SNL, 780' EWL, SEC. 24, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028286,1214' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 7" 26# Lø80 BTC-M 4ø1/2" 12.6# 13Cr80 Vam Ace 11. Type Bond (See 20 MC 25.025) Number 2S100302630-277 Quantitv of Cement (include staae data) 197 cu ft Class 'G' 331 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11 034 feet 9003 feet 1 0250 feet 9016 feet Length Plugs (measured) HES CIBP set at 10250' (09/98) Bridge Plug set at 10510' (04/98) Junk (measured) Size Cemented MD TVD 110' 110' 2684' 2684' 8745' 8480' 110' 20" x 30" 2646' 13ø3/8" 8710' 9-5/8" 472' 7" 2531' 2-7/8" 9.6 cu yds Concrete 3720 cu ft Permafrost 'C' 1170 cu ft Class 'G', 130 cu ft PF 'C' 360 cu ft Class 'G' 130 cu ft Class 'G' 8466' ø 8938' 8218' - 8661' 8500 ør11 ~t~" ~ ,,~253' ,- 9003' ~~, r" t ~,,,. g ,\ j F D ,~I ~" ~!1IW, t~)II": !;:"Ut' ¡j \\¡ ¡\\~.. Ifl 9410' - 9428', 9930' - 9988', 10050' ø 10210' Below Bridge Plugs: 10290' - 10440', 10570' - 10750', 10860' ø 10960' true vertical 8990' ø 8997', 9018' ø 9019', 9020' ø 9018' Below Bridge Plugs: 9015' ø 9012', 9011' ø 9003', 9001' ø 9003' £~as]<a OH & Gas Cons. CommissiQn iii Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch iii Dri"~6ahÐQíIii R Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requ irements Contact Engineer Name/Number: Dave Wesley, 564-5773 Prepared By Name/Number: Terrie Hubble, 564-4628 21. ~:~:~y c::~~:::e foregi~~,t: ~.a .o"e:t tOth:b~;eO~~:~~:~;:~I~~:",~~, ;i,n, ,~",er Date)' - b- 0 ~ , '.' ,'I I. ,',,' .<, ,CQmmi!.t~Jon tJ.e"Qnly",111 "', ' " Permit Number API Number Approval Da~ See cover letter 2.. 0 <2- - / c>. -s 50- 029ø20737-02 c:; , 'L\ - (t'y0 for other reauirements Conditions of Approval: Samples Required 0 Yes 8 No Mud Log Required 0 Yes JRI No Hydrogen Sulfide Measures t8I Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Press,~re for B,~PE 0 2K ,0 3K "°. 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Te.s t 8 -op t- 'tv š'5" 00 P ~. VJM- by order of Approved By 0nglnai Signed By C" Ä L the comm'ss'on Form 10-401 Rev. 12-01ø85 \bMtRiy Qtchsli ToylO1' 0 F~ rG'lsi\rr I I 20. Attachments Perforation depth: measured u Ô 2002 Date S'14-0;;- Submit In Triplicate (, ( I Well Name: I D-228 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer I AFE Number: 14P1837 I Estimated Start Date: 106/01/02 I I MD: 110,950' 1 I TVD: 19,003' I Surface Location: Estimated Target Location: Sadlerochit Zone 28 Bottom Hole Location: x = 653,460.00 Y = 5,959,438.00 1550' FNL , 1692' FEL Sec. 23, T11 N, R13E Umiat X = 655,245.00 Y = 5,957,985.00 TVDss 8950 2240' FSL, 62' FWL Sec. 24, T11N, R13E Umiat X = 655,985.00 Y = 5,956,975.00 TVDss 8931 1215' FSL , 780' FWL Sec. 24, T11 N, R13E Umiat I RiQ: I Nabors 2ES ./ I OperatinQ days to complete: 120.3 1 BF/MS: 143.13' I 1 I 1 RKB: 171.63' 1 1 1 I Well DesiQn (conventional, slim hole, etc.): 1 Horizontal Sidetrack 1 Objective: I Zone 2A, Sadlerochit Casin~/Tubin~ Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDfTVD 81/2" 7" 26.0# Lø80 8TCM -662' 8150' / 7913' 8812' /8505' 61/8" 4 Y2" 12.6# 13Cr-80 Vam Ace -2288' 8662' / 8394' 10950'/9003' Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace -8662' GL 8662'/8394' Directional KOP: 18,300' MO Maximum Hole Angle: Close Approach Well: Survey Program: 0-228 Sidetrack -24.0° in original well bore at -6000' MO. -92.0° through reservoir section of planned sidetrack from -10500' MO to TO at 10950' MO. There are no close approach issues: The closest well to the 0-228 is 0-05 with a center-to-center distance of 1073' and allowable deviation of 331' at the planned depth of 10,887' MD. All wells pass Major Risk criteria. Standard MWO Surveys from kick-off to TO. (" Page 1 ( Mud Program Window Milling Mud Properties: LSNO Density (p~) Viscosity PV 10.6 55 ø 65 10- 15 Intermediate Mud Properties: LSNO Density (ppg) Viscosity PV 1 0.6 / 45 - 55 1 0 - 15 Production Mud Properties: Quickdril-N Density (pPgj Viscosity PV 8.4 - 8.5 45 ø 55 4 - 7 I Whip Stock Window 9 5/8" I YP tauO MBT pH API FI 22 - 27 5-7 9.0- 9.5 <9 I Whip Stock Window 9 5/8" I YP tauO MBT pH API FI 22 - 27 5-7 9.0- 9.5 <9 I 6 1/8" hole section I YP tauO MBT pH API FI 22 - 28 N/A <3 8.5 - 9.0 N/C Logging Program 8 1/2" Intermediate: Sample Catchers - None Drilling: MWD Dir/GR/Res- Real time GR/Res throughout entire interval Open Hole: None Cased Hole: None Sample Catchers - Two, at Company man call out MWD Dir/GR/Res- Real time GR/Res throughout entire interval; Recorded Den/Neu from 7" shoe to lower Zone 2; end of the build section. None None 6 1/8" Production: Drilling: Open Hole: Cased Hole: Cement Program Casing Size 17" 26#, L-80 Intermediate Liner I Basis: Lead: None Tail: Based on 80' of 7" shoe track, 512' of 8 1/2" open hole with 40% excess, 150' of 7" x 9 5/8" liner lap, and 200' of 9 5/8" x 4" DP annulus ¡ølume. Tail TOC: -8150' MD (7913'TVD) Liner top. Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer Lead Tail Casing Size 25 bbls Alpha Spacer at 11.6 ppg None 35 bbl I 197 fe I 165 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 1900 41/2", 12.6#, 13Cr-80 Production Liner Basis: Lead: None Tail: Based on 80' of 4-1/2" shoe track, 2138' of 6 1/8" open hole with 40% excess, 150' of 4 Y2" x 7" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: -8662' MD (8394'TVD) - Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail 0-22B Sidetrack 20 bbls Alpha Spacer at 9.5 ppg None 59 bbl 1331 ft3 I 278 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 2100 Page 2 ( ( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. ./ BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: -3275 psi @ 8800' TVDss - 22 . Maximum surface pressure: -2400 psi @ surface / (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 7.2 ppg Diesel . . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DSø04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . Formation Markers Formation Tops (Wp#4) LCU KINGAK T JD / TOP KINGAK D SAG RIVER TSHU / TOP SHUBLIK TSAD / TZ4B TCGL / TZ3 BCGL / TZ2C 23SB 22TS 21TS TZ1B TDF / TZ1A MD TVDss 7423 7423 7975 8433 8463 8540 8734 8797 8870 8919 8962 9057 9102 Comments Est. Pore Pressure 3300psi (-7.01 ppg EMW) TD Criteria: 10,950' MD (-8,931 'ss) or sooner depending upon contingencies. D-22B Sidetrack Page 3 (' Sidetrack and Complete Procedure Summary RiQ Operations: / 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC./ 3. Nipple down tree. Nipple up BOPE and test to 3500psi per AOGCC permit requirement. 4. Pull and lay down 5 Y2", 17#, Lø80 tubing from E-line cut and above. 5. P/U 4" drill pipe and 8 Y2" milling assembly. RIH, drift 9 5/8" casing, tag tubing stump. POOH. 6. R/U E line and M/U 95/8" bridge plug. RIH and set at -8,318' MD. POOH. 7. Pressure test 9 5/8" casing to 3500 psi for 30 minutes. 8. RIH with E IinelUSIT to determine quality of cement behind the 9 518" casing, and attempt to determine the condition of the 9 518" casing wall. 9. RIH with 95/8" Baker whip stock assembly. Orient whip stock as desired and set on bridge plug. Displace well to 1 0.6ppg milling fluid. Mill window in 9 5/8" casing at 8,300' MD. 10. Mill -20 feet new formation and conduct FIT to 12.0ppg EMW. POOH. / 11. RIH with 8 1/2" drilling assembly (with MWD/GR/Res) to whip ,tock. Kick-off and drill the 8 1/2" intermediate section to Top Sag at -8,812' MD, (-8,504' TVD). / 12. Run and cement 7",26# intermediate drilling liner to -150' back into window. POOH. 13. Make up and RIH with a 6 1/8" drilling assembly (with MWD/GR/Res/Den/Neu). DensitylNeutron logging data (recorded) will be r1qUired through the build section into Zone 2. Pressure-test the 7" liner to 3500 psi for 30 minutes. ) 14. Drill -20 feet new formation and conduct FIT to 10.0ppg EMW. ) 15. Drill 6 1/8" production section, as per directional plan, to an estimated TD of 10,950" MD (-9005' TVD). 16. Run and cement a 4 Y2", 12.6# 13Cr-80 production liner. Displace well to brine. POOH. 17. P/U DPC perforating guns, RIH, pýMorate interval (approximately 600'), as determined by LWD log data. POOH and UD guns. / 18. Run the 4 1/2", 12.6# 13Crø80 completion, tying into the 4ø 1/2" liner top. 19. Drop Ball and Rod to set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 20. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 21. Freeze protect the well to -2200' and secure the well. 22. Rig down and move off. Post-RiQ Work: 1. MIRU slick line. Pull the ball and rod I RHC plug from 'X' nipple below the new production packer. Install gas lift valves. Estimated Start Date: June 01, 2002 D-22B Sidetrack Page 4 ( ~' Job 1: MIRU Hazards and Contingencies >- No wells will require shut-in for the rig move onto Dø22A. 0-28 is 54' to the North, and 0-27 is 56' to the South. These are the two closest neighboring wells. ~ D-Pad is not designated as an Hß site. Standard Operating Procedures for H2S precautions should, however, be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: D-27 0 ppm D-05 0 ppm D-28 0 ppm D-20 10 ppm The maximum level recorded of H2S on the pad was 10 ppm, in 03/2001. );> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP ~,~;¡m..I.-:.:A:, .-.1.-. ..II,I.....I.DJ,I.IJ),I.l.-I!.I.:.:_U:;,._, "". .-.-J -':;JJ,I'_IH_';,IH,r;,-,IJJ;~J:J:¡,I,I',~,'JJJJI1;J,IJHI;J,IJ':IJA11;,J_.,U)),IMH,ra;mm,IJI,I~,I'mmJ',I,U',U.IJ,,I.)J,:JJ,:um,IJ,-.:/l-.:;¡K.Io.Ul:,I;,-,l-AA-,-;',-lUJ,IJ,I,;,I.IJ,rmU-¡lJlI,-,r¡)¡!oJIIo.IWml,IUmm 'AI,I,~II~.I,U;ml,l,II,:,\I;~,lmJ;~IH,I,I.I,B.I,IIJ,I;;m,11;,;,;J;mmJmmml',:,c,_:,-,-,lml!;,:J¡;¡am¡¡,:I,~-.. ,--1,-,-, ...1... ,_,I';,¡,_:",_,lc,--'~:,I)!,I,1.I ~:,-"..,. ". ,-¡'.- ,,-, ,-.I¡',LI,IA!,,I,',H~.,,-,-: ,_i,:,I.W'¡,~,O:,~:'-". ,-A Job 2: De-complete Well Hazards and Contingencies >- The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is a McEvoy SSH and has a 7" TC4S tubing hanger; the tree is a 6 3/8" McEvoy model 'C'. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ~-~':II-';t;«-l:lU:'.f~-~itt.\':I¡~:;:;;';'\..\'>..~\'o,i.-."~.,,;~'I!I:I!I':<\~~~~~~~~' ,~ ".WA......,~~~-:;;*!It;~I;~"S~:~),I,~I:Ic,*I:'~~~~~""v,~~~;¡I,'~I,~,~ÿ",;1,~~,I!W;~~:~AAI:Ii~¡,.IM,,,;..',-,'A1,I,~J;J:I,~~~~~~~«'~~W:W;~1:I;W;'~J;~~:I:~~J;I.~:¡I,~iIt:;¡I;..IM,\"."~~\WMJ;~~¡.1:",I,,-,It!A;'~~',:";',.'-":"~;~~J;~~'¡Yfi;;;I:',,,J;~~~ Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whip stock Sidetracks" RP :;:::::;.II::::::::::::~~--""'III~~~IIIIIIII~il'III::I:'^t....: ------'"' .V --_m_-'. ...._--__--___m_~_>;.. ,. ,--.-..-.--#. .,- -------......--.-------~~o'... D-22B Sidetrack Page 5 ( (' Job 5: Drill 8Y2" Intermediate Hole Hazards and Contingencies » The well will kick off in the Kingak shale, sub-zone D, and drill the remainder of the Kingak, into the Sag River formation. Previous D Pad wells drilled the Kingak with 9.7 to 10.2ppg mud weights. For this well, maintain mud weight at 10.6ppg, minimally, to 7" liner point. Follow all shale drilling practices to minimize potential problems. » KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a fracture gradient of 11.0ppg at the 9 5/8" casing window, and 10.6ppg mud in the hole, the kick tolerance is infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ,-- '"I,ml:;-- '''I~!lmmm- _m. ,. ~ 1..1 ,.. .1111:-- -:I-~!lml""''---_U'Wml~UH.I'.'.iU- -~. .. ,r:-::"mlm:II'Hlml~I'-i:I:;:.t!«:""W"I'~"'I'''' .1. .1. ---1---_:1::,-' _m":,'1 Job 6: Install 7" Intermediate Liner Hazards and Contingencies » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .'.:"~~lllallll:I=I::IIII:III:II': "II!II~>'I":""'--~.~ I'I¡..,~:«.-..._-" .~._.Io...-.~III:;'..(-...~..... 'I~~H'::':_~ Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies » It will be necessary to Geo-steer this interval of the well. The majority of the interval will be placed in Zone 2A, toeing up into Zone 2B during the last 300 - 400 feet of drilling. ~ There are two anticipated fault crossings while drilling this build section of D-22B. These faults have an estimated throw of +/ø 15 feet. They are expected in Zone 4 I Zone 3. Based upon previous experience encountering these faults, while drilling the D-22A CTD well bore, no significant losses are expected. However, all precautions showed be taken and lost circulation procedures should be followed. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP D-22B Sidetrack Page 6 ( ~~ Job 9: Install 4112" Production Liner Hazards and Contingencies ~ The completion design is to run a 4 Y2" 13Cr-80 liner throughout the horizontal interval. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 7" intermediate liner, set at -8,812' MD. Reference RP .:. "Running and Cementing a Liner Conventionally" RP .:. "Combination Solid - Slotted Production Liners" RP 1- -111:-'llllmllll:!lUIII:m:m~IIII~Lmlll'lmll~II:'II:~CIIHI_ILI_I- 11::::.11:-1'.1 I 1_-II--U:_'-_L::!lII:::-I-lltIlLllm'IIIIIIIIII:III:rlmln'lll1t+::I'III:IUL__¡;¡(IW>C::lr:::III::I:III_III~_II_':I_IILII.L :'... '~"''''''''''-m-''l.''''.,-'joID- -1--:ILlII_Ll:II~I'II_.::'I_ltl:l:m: "tt( Job 1 0: DPC Perforate Hazards and Contingencies ~ The well will be perforated, balanced, after running 4 Y2" liner. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. ~ Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Reference RP .:. "Drill Pipe Conveyed Perforating" RP (..:,,¡-~;;:;;~;m--::mll::I'::~:::tll'I:I'~:II:::_:!II::_III__:_:~:-:--IIII::':~:"::I::II:m_-I«+::::::':=,JUJJ"U""wu",wu.",."~,-",,,,^".~'.".". i*:~~_~_o(.o."1I4«~('WNN"""""""I'-~X«««__:««"_.'N,.'A"'''.»_.'''''-''''~....'''{....'''&O Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP ),'i!o,w:r~:«.,1\,$;I¡"'lØ,"'~')":>J."";"N'-';"H;'.w;..,';"',~"........,.,.,,.,.,,.~,.,.;.o,.,,.,..,.,-n,,........,.,....,,.................,,,,.,.,.,.,,,,,,,,,,,,,,,,,,,.,.,.~«-.'I\."~~:<w.~ ¡C~"~.-»fl¡.,m~mW:I~:IWMI,I'-;;'m1<I~'i~>'1I!'!'~')$I;~~~"t/#:«r.;m,"~ I:~I¡'m,.m¡.',."..)/#i.1$;~ Job 13: ND/NU/Release Riq D-22B Sidetrack Page 7 Hazards and Contingencies >- Though there are no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. Reference RP .:. "Freeze Protecting an Inner Annulus" RP Dø22B Sidetrack Page 8 Revised: 30 Apri¿ 2002 PROPOSAL REPORT 30 April, 2002 Surface Coordinates: 5959438.00 N, 653460.00 E (70° 17' 46.0698" N, 148° 45' 26.3074- W) Surface Coordinates relative to Project H Reference: 959438.00 N, 153460.00 E (Grid) Surface Coordinates relative to Structure Reference: 3820.52 N, 1373.98 E (True) Kelly Bushing: 71.63ft above Mean Sea Level spsï Ii .Y--&L.r! ~flttl\ ,..... -'-.~..VJ:r=-... Ii. """;IDt Còìiì,.,...,. - - Propossl Ref: pro11182 ~BPXA ~',dJ 1IN-.i,~~V~ North Slope Alaska 7950 - 8250 - - 0> 0 c: ~ 0> - 0> a:: Q) 8550 - ~ ..c: - a. 0> C ~ ~ 8850 - 0> > .t:: 8 9150 - C') II .t:: 0 .s (¡) ~ en 9450 _-"11"____&'" ^^ ^^ .,...^" '20000 KOP TF HS Begin Dir @ 10.0000/100ft 83OO.00ft MD, 8060.79ft TVD Decrease in Dir Rate @ 3.988°/1ooft 8320.ooft MD, 8079.61ft TVD End Dir, Start Sail @ 34.000° 8650.80ftMD,8372.64ftTVD .00 ~~U_WuA U pad DrillQuest~ D-22B WP-05 Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation : Plan D-22B W~ 5959438.00 N, 653460.00 E 3820.52 N, 1373.98 E 70° 17'46.0698. N, 148° 45' 26.3074" W North Reference : Units: 71.63ft above Mean Sea Level 71.63ft above Structure Reference True North Feet (US) #0 ~O # <Ø~~1"~ ~Q ?JcØ-. 90r¡,r¡,9Þ'ð~ ~Q~tp,~Q.çp~Q~ éJ'~ ~Q' 'õ~ 'õ~ _d.'J....,fF'~- .9'õ90. ¡11:\O~ .\or¡,9r¡,'.\~9~..\\P- ~ . .99 ~. ""~. l},4J çpØJ ~. 909() 0\\V"' 9r¡,. .~ @ oø\'\ ~ @ berØ' ~~ @ ~ c¿P @ be. ~ ~ ri\~ @ ~'\.0-~ 41/2" liner Total Depth . çJ3i- Q~ . ~~ ~~ v O\~, 10950.00'P.I> 10950.00ftMD ~ Q~' . ~~ Ò Q\~' ~rA <;;,~ 9004.43'lVD 9004.43ftTVD ~X) ¡tmØJ""'--~ .1010000 ~~~ ~05ØØ1i0 .,10100;228 WP¿~ D-228 WP.05 T1 D.228 WP.05 T2 lJ-22ß wp.os T3 ~~~ ~~~ ~8~ 1489.45 S, 1754.92 E 2084.97 S, 2220.33 E 2515.29 S. 2475.03 H 100.00 Begin Dir @ 10.000o/100ft 913O.6Oft MD, 8770.41ftTVD I 1350 Scale: 1 inch = 300ft I 1650 I 1950 I I I 2250 2550 2850 Vertical Section (Well Reference) I I 3450 3750 Section Azimuth: 135.4600 (True North) I 3150 ~.~8LI1 BPXA ~~.d~ B !N.-,,;;~~~ North Slope Alaska ~-=SU_WuA u ~ad DrillQuest- D-22B WP-05 Measurement Units : Target Name D-228 WP-04 Fauk 1 D-228 WP-04 Fault 2 D-228 WP-04 Fauk 3 it Coordinate PoinI Type Entry Point Boundary Poim A B C Entry Point Boundary Point A B C Entry Point Boundary Point A B C D-228 WP-04 Geo-Poly Entry Point D-228 WP-04 Tl D-228 WP-04 12 D-228 WP-04 13 _-'!I'"..__&''''' ^^ ^^~ Boundary Point A B C D E Entry PðÎllt Entry Point Entry Poim Scale: 1 inch = 500ft 500 I Eastings (Well Reference) 1500 2000 I I 2500 I 3000 I - -750 KOP TF HS Begin Dir @ 10.0000/100ft: 83OO.00ft MD, 8060.79ft Decrease in Dir Rate @ 3.988°/100ft : 8320.00ft MD, 8079.61ft TVD End Dirt Start Sail @ 34.000° : 8650.8OftMD,8372.64ftTVD Begin Dir @ 10.0000/100ft: 9130.600 MD, 8770.41ftTVD - -1250 tI/ \ \ End Dirt Start Sail @ 9O.()()()o : 9690.6OftMD,9022.9~ft' Fault Fault Q) o-~ c. Q) '- Q) 'Q) a: - -1750 ëD ~ - 7., .',~....<&- '" ~"'OJ' . " ?--o. .~~ (/) C) c: :c t: 0 - -2250 Z Begi~ ~i~'; 4.c;r./1Cxm ~9977.1 Oft MD, 9ü2?99ft TVD End Dir, Start Sail @ 90.000" : 10292.6OftMD,gf122. ftTVD Begin Dir @ 4.004°/lOOft: 10449.600 MD, ~22. 8ft TVD End Dir, Start Sail @ 92.250°: 10505.8OftM~1. ftTVD '. ". ) Single Well Target Data for Plan D-22B WP~5 '. ::: 8 LO II .s= 0 .5 - -2750 ~ Q) ãš 0.- en -, TVD SSTVD Northlngs Eastlngs ASP-4 Northings ASP-4EastingsTarget Shape 71.63 0.00 956104.63 S 173017.89 W 500000o.00 N 5(((Q}.00 E Polygon 71.63 0.00 1787.89 S 1151.73 E 5957674.00 N 654648.00 E 71.63 0.00 1905.57 N 153353.06 W 595&21200 N 500100.00 E 71.63 0.00 1787.89 S 1151.73 E 5957674.00 N 654648.00 E 8981.63 8910.00 956104.63 S 173017.89 W 500000O.00 N 5fXXm.00 E Polygon 8981.63 8910.00 1368.82 S 1985.47 E 5958110.00 N 655473.00 E 8981.63 8910.00 1690.04 S 17%.87 E 5957785.00 N 655291.00 E 8981.63 8910.00 1378.82 S 1985.26 E 5958100.00 N 655473.00 E 8966.63 8895.00 956104.63 S 173017.89 W 500000O.00 N 500000.00 E Polygon 8966.63 8895.00 1553.08 S 2191.75 E 5957930.00 N 655683.00 E 8966.63 8895.00 1736.09 S 1896.95 E 5957741.00 N 655392.00 E 8966.63 8895.00 1553.08 S 2191.75 E 5957930.00 N 655683.00 E 9021.63 8950.00 2084.76 S 2219.90 E 5957399.00 N 65572200 E Polygon 9021.63 8950.00 1307.14 S 1413.61 E 5958160.00 N 654900.00 E 9021.63 8950.00 1151.66 S 1636.83 E 5958320.00 N 655120.ooE 9021.63 8950.00 2004.15 S 2729.65 E 5957490.00 N 656230.00 E 902L63 8950.00 2711.15 S 2575.18 E 5956780.00 N 656090.00 E 902 1.63 8950.00 2193.69 S 1725.57 E 5957280.00 N 655230.00 E 9022.9& &951.35 14&9.45 S 1754.92 E 59579&4.69 N 655244.97 E Point 9022.98 8951.35 2084.97 S 2220.33 E 5957398.80 N 655722.44 E Point 900M3 8932.80 2515.29 S 2475.03 E 5956973.77 N 655985.87 E Point D-22B WP-OS Comments Measured Vertical Comment Depth Depth (It) (It) 8300.00 8320.00 8650.80 9130.60 9690.60 9977.10 10292.60 10449.60 10505.80 10950.00 8060.79 8079.61 8372.64- 8770.41 9022.98 9022.98 9022.98 9022.98 9021.87 9004.43 KOP 11' HS Begin Dir @ JO.()()()o/JOOf1: 8300.00ft MD. 806O.79ft TVD Decrease in Dir Rate @ 3.988°/1000: 8320.000 MD, 8079.61ft TVD End Dir. Start Sail @ 34.000°: 8650.8OftMD.8372.64-ftTVD Begin Dir @ 1O.OOOOIl00ft: 9130.6Oft MD. 8770.41ft TVD End Dir, Start Sail @ 90.000° : 969(t6OftMD,9022.98ftTVD Begin Dir @ 4.00001l00ft : 9977.100 MD. 9022.98ft TVD End Dir. Start Sail @ 90.000": 10292.6OftMD.9022.98ftTVD Begin Dir @ 4.004°/100ft : 10449.600 MD. 9022.98ft TVD End Dir. Stan Sail @ 92.2500: 10505.8OftMD.9021.87ftTVD Total Depth: 10950.00ftMD.9004.43ftTVD Sperry-Sun Drilling Services Proposal Report for Plan Dø22B Revised: 30 April, 2002 BPXA North Slope Alaska PBU_WOA D Pad Measured SubøSea Vertical Local Coordinates Depth lnel. Azlm. Depth Depth Northlngs Eastings Comment (It) (It) (It) (It) (It) Dø22 8300.00 18.809 136.314 7989.16 8060.79 832.77 S 1390.75 KOP TF HS Begin Djr @ 10.0000/1OC : 8300.00ft MD, 8060.79ft TVD Dø22B WP-DS --¿;J 8320.00 20.809 136.314 8007.98 8079.61 5958623.81 N 654618.10 E 10.000 1397.53 Decrease jn Djr Rate @ 3.988°/100ft: 8320.00ft MD, 8079.61ft TVD 8400.00 23.999 136.460 1162.26 E 5958602.17 N 654639.57 E 3.988 1428.01 8500.00 27.987 136.598 1192.40 E 5958570.99 N 654670.36 E 3.988 1471.82 8600.00 31.974 136.705 1226.70 E 5958535.36 N 654705.39 E 3.988 1521.77 8650.80 34.000 136.750 1245.65 E 5958515.62 N 654724.75 E 3.988 1549.42 End Djr, Start Sail @ 34.000° : 8650.8OftM0 ,8372.64ftTVD 8700.00 968.05 S 1264.51 E 5958495.97 N 654744.01 E 0.000 1576.92 8800.00 1008.78 S 1302.82 E 5958456.03 N 654783.15 E 0.000 1632.83 8810.01 1012.86 S 1306.66 E 5958452.03 N 654787.06 E 0.000 1638.43 7" Casing 8811.70 1013.55 S 1307.30 E 5958451.35 N 654787.73 E 0.000 1639.37 8900.00 1049.51 S 1341.14 E 5958416.09 N 654822.28 E 0.000 1688.73 9000.00 8590.51 8662.14 1090.24 S 1379.45 E 5958376.15 N 654861.42 E 0.000 1744.64 9100.00 8673.41 8745.04 1130.97 S 1417.77 E 5958336.21 N 654900.56 E 0.000 1800.55 9130.60 8698.78 8770.41 1143.44 S 1429.49 E 5958323.99 N 654912.54 E 0.000 1817.65 Begjn Djr @ 10.0000/100ft: 9130.600 MD, 8770.41ft TVD 9200.00 40.940 136.752 8753.83 8825.46 1174.17 S 1458.40 E 5958293.85 N 654942.07 E 10.000 1859.83 9300.00 50.940 136.755 8823.28 8894.91 1226.45 S 1507.57 E 5958242.59 N 654992.30 E 10.000 1931.59 ~ 9400.00 60.940 136.756 8879.22 8950.85 1286.72 S 1564.26 E 5958183.49 N 655050.20 E 10.000 2014.31 9500.00 70.940 136.758 8919.93 8991.56 1353.15 S 1626.74 E 5958118.34 N 655114.03 E 10.000 2105.48 9600.00 80.940 136.759 8944.20 9015.83 1423.73 S 1693.11 E 5958049.14 N 655181.82 E 10.000 2202.33 9690.60 90.000 136.760 8951.35 9022.98 1489.45 S 1754.92 E 5957984.69 N 655244.96 E 10.000 2292.53 End Djr, Start Sail @ 90.000° : 9690.6OftMD,9022.98ftTVD Target - D-22B W¡r05 Drillers @ 95 o/c Current Target 9700.00 90.000 136.760 8951 .35 9022.98 1496.30 S 1761.35 E 5957977.97 N 655251.54 E 0.000 2301.93 30 April, 2002 ø 16:23 Page2of9 DrillQuest 2.00.09.008 Sperry-Sun Drilling Services Proposal Report for Plan 0-228 Revised: 30 April, 2002 BPXA North Slope Alaska PBU_WOA D Pad Measured SubøSea Vertical Local Coordinates Depth lnel. Azlm. Depth Depth Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) 9800.00 90.000 136.760 8951.35 9022.98 1569.15 S 1829.86 E 0.000 2401.91 9900.00 90.000 136.760 8951.35 9022.98 1642.00 S 1898.37 E 0.000 2501.88 9977.10 90.000 136.760 8951.35 9022.98 1698.17 S 1951.18 E ~ 0.000 2578.96 Begin Dir @ 4.000°/1000: 9977.100 MD, 9022.98ft TVD 10000.00 90.000 137.676 8951.35 9022.98 1714.97 S 655461.34 E 4.000 2601.85 10100.00 90.000 141.676 8951.35 9022.98 1791.20 S 655527.58 E 4.000 2701.56 ---- 10200.00 90.000 145.676 8951.35 9022.98 655588.44 E 4.000 2800.51 10292.60 90.000 149.380 8951.35 9022.98 655639.73 E 4.000 2891.05 End Dir, Start Sail @ 90.000° : 1 0292.6OOMD,9022.9OOTVD 10300.00 90.000 149.380 8951.35 5957525.96 N 655643.63 E 0.000 2898.23 10400.00 90.000 149.380 8951 .35 5957440.96 N 655696.31 E 0.000 2995.30 10449.60 90.000 149.380 8951 .35 5957398.80 N 655722.44 E 0.000 3043.44 Begin Dir @ 4.0Q4°/100ft: 10449.6Ofi MD, 9022.900 TVD Target ø D-226 WP-04 T2, Current Target 10500.00 2128.33 S 2246.00 E 5957355.97 N 655748.99 E 4.004 3092.35 10505.80 2133.32 S 2248.95 E 5957351.05 N 655752.04 E 4.004 3097.97 End Dir, Start Sail @ 92.250° : 1 0505.8OOMD,9021.87ftTVD 10600.00 9018.17 2214.32 S 2296.89 E 5957271.04 N 655801.63 E 0.000 3189.34 10700.00 9014.25 2300.31 S 2347.79 E 5957186.11 N 655854.27 E 0.000 3286.33 10755.60 9012.06 2348.12 S 2376.09 E 5957138.88 N 655883.53 E 0.000 3340.25 10800.00 8938.69 9010.32 2386.30 S 2398.68 E 5957101.17 N 655906.91 E 0.000 3383.31 10900.00 8934.77 9006.40 2472.29 S 2449.58 E 5957016.24 N 655959.55 E 0.000 3480.30 10950.00 8932.80 9004.43 2515.29 S 2475.03 E 5956973.77 N 655985.87 E 0.000 3528.80 Total Depth: 1 0950.00ftMD,9004.43ftTVD --.-/ 4 1/2" Liner Target ø Dø226 WP-04 T3, Current Target 30 April, 2002 ø 16:23 Page30f9 DrillQuest 2.00.09.008 North Slope Alaska Sperry-Sun Drilling Services Proposal Report for Plan 0-228 Revised: 30 April, 2002 All data Is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.322° (26-Apr-Q2) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 135.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10950.00ft., The Bottom Hole Displacement is 3528.8Oft., in the Direction of 135.462° (True). Comments Measured Depth (ft) 8300.00 8320.00 8650.80 9130.60 9690.60 9977.10 10292.60 10449.60 10505.80 10950.00 30 April, 2002 ø 16:23 Station Coordlna TVD Northlngs (ft) (ft) 8060.79 8079.61 8372.64 8 1 KOP TF HS Begin Dir @ 10.000°/1000 : 83OO.00ft MD, 8060.700 TVD Decrease in Dir Rate @ 3.988°/100ft : 8320.00ft MD, 8079.61ft TVD End Dir, Start Sail @ 34.000° : 8650.8OOMD,8372.64ftTVD Begin Dir @ 10.00Qo/100ft: 9130.600 MD, 8770.41ftTVD End Dir, Start Sail @ 90.000° : 9690.6OOMD,9022.9OOTVD 1698.17 S 1949.86 S 2084.97 S 2133.32 S 2515.29 S 1951.18 E 2140.37 E 2220.33 E 2248.95 E 2475.03 E Begin Dir @ 4.0000/100ft: 9977.100 MD, 9022.98ft TVD End Dir, Start Sail @ 90.000° : 10292.6OftMD,9022.98ftTVD Begin Dir @ 4.oo4°/100ft: 10449.600 MD, 9022.900 TVD End Dir, Start Sail @ 92.250° : 10505.8OOMD,9021.87ftTVD Total Depth: 10950.00ftMD,9004.43ftTVD Page 4 of 9 BPXA PBU_WOA D Pad ~-- ~ DrillQuest 2.00.09.008 North Slope Alaska Formation Tops Formation Plane (Below Well Origin) Sub-Sea Dip Dip Dlr. (ft) Deg. Deg. 7423.00 7975.00 0.000 0.000 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> Targets associated Target Name D-22B WP-04 Fault 1 30 April, 2002 ø 16:23 Sperry-Sun Drilling Services Proposal Report for Plan Dø22B Revised: 30 Apri~ 2002 Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) 0.000 0.000 7702.32 8285.04 7494.63 8046.63 7423.00 7975.00 To Measured Vertic Depth D (ft) Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Mean Sea Level/Global Coordinates: Geographical Coordinates: 71.63 0.00 956104.63 S 173017.89 W 500000O.00 N 500000.00 E 67° 40' 43.0684" N 150° 00' 00.0000" W Target Boundary Point #1 #2 #3 1787.89 S 1905.57 N 1787.89 S 1151.73 E 153353.06 W 1151.73 E 71.63 71.63 71.63 Page50f9 BPXA PBU_WOA D Pad --- Target Target Shape Type Polygon Current Target --- DrillQuest 2.00.09.008 N::tD!' +N.r.s B..n 3,~10H' J.Pl.fj.~ ! -182 -175 ¡ I -150 -125 -100 -75 -50 -25 -0 270- -25 -50 -75 -100 -125 -150 -175 -182 \\11 I. )HAD~S ANll-COLLISlON SETI1NGS .l'J.\\ No..rthin~ L~hllll:; 1.3.[du.,k 1..f>nþ!u.J<" Sht Interpolation Method:MD Interval: 50.00 Depth Range From: 8300.00 To: 10950.00 Maximum Range: 1150.20 Reference: Plan: D-22B WP-05 5'/.'ítj.OS.(XJ {¡:'.tWJKJ 7ft ITVt.l1iON I~ .s:¡ï~ft.;.rm\' -- From Colour 0 8300 8500 8750 9000 9250 9500 9750 10000 10250 10500 180f82 ToMD 8300 8500 8750 9000 9250 9500 9750 10000 10250 10500 10750 90 - fJ17(þ COMPANY DETAILS Sl.iR\"EY PROGR.".M ()¿pIlI Fill Depth To S",,~,Pbn Tool \\"ELLPATH DETAILS poo D-21B BP lUD)CO Cakub:!inn Meth~: Minimum Curyarure Ermr S'~!dn: ISCWSA ScanAÍetlnf: TIaYCyinJerNorth Euor Surface: E.liptical + Casing \\"~~Idb>J: RuhB2s.cJ s:<oo~oo 1œ50~OO P".....o<d: I)~!!ß WP-ili VI M\\TI 1).22 8:<00.00 "'iO:ø From Colour 0 8300 8500 8750 9000 9250 9500 9750 10000 10250 00 Parent \\'~~: T1e ('Ii MI): Rì2; R~f. DatWÌ1: Phn 0-1'2871.63 7I.63fr -15,0 V..&elion AngI< Origin +N..S 0ri2in +Ei~W Star1ing From TVD -10.0 -5.0 -5.0 -10.0 -15.0 -!OJ! ToMD 8300 8500 8750 9000 9250 9500 9750 10000 10250 10500 10750 :X: O.JJ lEGEI'iD - [).{6 ([).{6). Mapr Risk - D-:!O (D-:!O). Maj>r Risk - D-21 (D-21). NOFRRORS - D-2! (~22A), NOERRORS ~ D-21 (D-21.-\PBI). NOERRORS - D-31A (D-31A). Ma,x Ris.1.: - D-3J (D-3J). Maj>r Risk - D-33PBI CD-3JPBl). M3prlllik - Phn ()'118 - D-nB WP-05 ::L:~ ~' 90 Pbn: D-22ß WP-O:\ (D-22IPOO D-22ß) Û<'OI<d 11): Scon Ma<Donal:l CbxL-øl: Date: .j/3()"2Oœ Date:- Rð~~: Dare: ~ Appnw6:l: Dale: Travelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation [15ft/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] SECTION DETAIL'> See Mf) I..., An TVD +NI-S +E/.W fJI"'J1 Tfae<: VSee Target 8.100,00 18.81 136.31 soro,79 -8.~.77 11365.' 0.(\) 0.00 1-103.28 8J:!O.oo 20.81 136.31 8079.61 -837.67 11412-' 10.00 359.96 141O.ü3 86.<0.80 _'4.00 136.75 8372.{» -9.JS.0l 12-15.66 3.99 Lœ 1561.J3 4 SSILïO 34.00 1.'6.75 85()).OJ -lOB..55 1307..11 o.ro 0.00 1650.91 5 9130.60 34.00 136.75 8770.41 .114.1.+1 1429.-19 o.ro O.ro 1828.-16 6 9690.60 90.00 136.76 9022.97 .1-189.45 175.1.92 Io.ro 0.01 2¡01.J8 7 9977.10 90.00 136.76 9022.97 -1698.16 19:11.19 0.00 0.00 2586..63 g Høn,m 90.00 1-19.38 9021.97 -19-19.86 21..KJ37 4.00 90.00 2894.97 9 101-19.60 90.00 1-19,38 9022.97 -2O&J.96 21:!0--'4 0.00 0.00 30+1.30 10 10505.80 !Tl.25 1-19.38 9021.87 .21.H.32 224&.95 4.00 360.00 :<1)7.73 11 10755.60 92.25 1-19.38 9012.1)') -13-t8..11 1376.0:1 0.00 0.00 3J35.1-t 11 10050.00 91.25 1-19.38 900UJ -2515.28 1..H5-Q~ 0.00 0.00 3519.89 ) ) Sperry-SUD Anticollision Report D,~~ ...... ;4I3OI~Q02' " , T~: 16:.14:t5, , Com~y: BPAmoco Field: , Prudhoe Bay Reference Site: ' PB DÞad ReferenceWell:D-22 ' Reference WeUpath: Plan D-22B GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are 18öIiIiIè1lUll1s in this fØdtI: D-22B WP-05 & NOT PLANNED PP<JGRA Interpolation Method: MD Interval: 50.00 ft Error Model: ISCW SA Ellipse Depth Range: 8300.00 to 10950.00 ft Scan Method: Trav Cylinder North MaximUßl Radius: 1291.89 ft Error Surface: Ellipse + Casing 'I """ ,I ,:. , ,I,' ,I'" ":,'1:,"1,1,..,1 I I Co-o~~lUtte(NE)~~~~l1ce:' W$lI:<[)~?2. True North' ver~C.(1'Vn)Rt!eJ;'~~c~: 'PlànD,~22B71.6371.6 Casing Points M)) , 'ft 8811.82 8506.13 10949.99 9004.43 7.000 4.500 7" 41/2" 8.500 6.125 D-22B W P-05 4/30/2002 1 From: Definitive Path Plan: Date Composed: Version: Tied-to: Principal: Yes Summary , <~-~~.~.._~-~_..~~-~--~.otrset Wellpath,-.-~".~-_.;~~;;--~-_.ø.> Site' ,We~1 " ' , I :WeUPiJth, I I I I I I 'I "ll Rd'erençe Offset.,,' Ctí'~ttr¡'No~Qø' 'AlI()~ble', " 'MD ,MDPls""c;~:Arêa" "D~rlåt1øn',': W~.gnlf ,ft"',,,' It ,', '::ft',':"fti '"ft' !' 10932.67 10000.00 1064.90 809.52 302.23 Pass: Major Risk Out of range 0.00 FAIL: NOERRORS 0.00 FAIL: NOERRORS 0.00 FAIL: NOERRORS Out of range Out of range Out of range PB D Pad PB D Pad PB D Pad PB D Pad PB D Pad PB D Pad PB D Pad PB D Pad D-05 D-20 D-22 0-22 D-22 D-31A 0-33 0-33PB1 Dø05 V1 D-20 V1 0-22 V1 D-22A V2 D-22APB 1 V3 D-31A V1 D-33 V1 D-33PB1 V1 0.00 0.00 0.00 0.00 0.00 0.00 8300.00 8300.00 8300.00 8300.00 8300.00 8300.00 Site: PB D Pad Well: 0-05 Wellpath: 0-05 V1 Reference MD TVD 'ft 'ft, 10200.00 9022.97 10200.00 9022.97 10238.07 9022.97 10262.94 9022.97 10292.60 9022.97 Major Risk 0.00 ft 'ÀII9~le ' 'DeViation, ''''.-ning , , ,f,t, " ' 855.46 Pass 825.94 Pass 800.84 Pass 775.08 Pass 750.83 Pass Rule Assigned: Inter-Site Error: , ctr~dl':,'No~Go ,J)~~êeAriIJ' ' , ft" ft 1277.48 616.98 1263.23 627.11 1249.60 630.45 1236.87 635.99 1225.06 640.38 seøli~Ml\iør",~ '., .'.. ,'.... .' .. .'.. . ... ..' '.,.' , Ref ' Off~~t';('Fo+Å;ZI':rF()-~Ça.,ijlg , .ft ft' ',',', ,peg' ,d~' .in. .. 59.39 133.44 104.20 318.52 59.39 136.66 103.00 317.32 59.08 138.14 103.29 316.09 58.87 140.23 103.03 314.84 58.63 141.99 102.94 313.56 Oft'set' MJ). . TVD ft' ft . 9000.00 8065.95 9050.00 8094.43 9100.00 8122.71 9150.00 8150.83 9200.00 8178.86 10324.58 9022.97 9250.00 8206.87 58.83 145.28 101.62 312.24 1213.96 651.39 722.85 Pass 10364.52 9022.97 9300.00 8235.06 59.09 148.54 100.29 310.91 1203.13 661.94 694.86 Pass 10404.46 9022.97 9350.00 8263.37 59.35 151.84 98.94 309.56 1192.59 672.85 666.89 Pass 10444.48 9022.97 9400.00 8291.69 59.62 155.10 97.58 308.20 1182.44 683.45 639.22 Pass 10512,15 9021.62 9450.00 8320.08 60.10 158.43 96.18 306.80 1172.08 695.45 603.48 Pass 10551.05 9020.09 9500.00 8348.74 60.37 161.69 94.73 305.35 1161.27 706.06 574.67 Pass 10589.86 9018.57 9550.00 8377.68 60.65 164.92 93.26 303.88 1150.52 716.60 545.91 Pass 10628.49 9017.05 9600.00 8406.97 60.94 168.11 91.76 302.38 1140.01 727.50 517.38 Pass 10666.98 9015.54 9650.00 8436.57 61.22 171.29 90.24 300.86 1129.64 737.90 488.96 Pass 10705.49 9014.03 9700.00 8466.36 61.51 174.43 88.71 299.33 1119.10 748.46 460.55 Pass 10743.92 9012.52 9750.00 8496.39 61.81 177.54 87.15 297.77 1108.56 758.69 432.25 Pass 10782,03 9011.03 9800.00 8526.83 62.11 180.61 85.55 296.17 1098.60 769.02 404.61 Pass 10819.83 9009.54 9850.00 8557.67 62.42 183.64 83.91 294.53 1089.24 779.50 377.71 Pass 10857.46 9008.07 9900.00 8588.77 62.72 186.62 82.24 292.86 1080.36 789.36 351.59 Pass 10895,00 9006.59 9950.00 8620.01 63.03 189.63 80.53 291.15 1072.13 799.33 326.23 Pass 10932.67 9005.11 10000.00 8651.10 63.35 192.63 78.81 289.43 1064.90 809.52 302.23 Pass ' ) ) Sperry-Sun Anticollision Report Cømpany: .. BP Amoco Då~: ::'4t3P/2002 .~~i,116:14:15, .Pag~: 2 Field: Pl\JdhœBay Reference Site: PBD. Pad ' ço,;()rdi~~(~)Refereneê: , WeU:D~?2,Truø North Reference Well: . D-22 Vertiçal(TVD)R.efere~é:., . , Plân .D~22B 71;6371.6 It~(ereDce\Vellpjth: Plan.0-22B ' ',.. . ' .'" 'I . , ' Db: ,OraclEt Site: PB D Pad Well: Dø22 Rule Assigned: NOERRORS Well path: Dø22 V1 Inter-Site Error: 0.00 ft Reference Offset ,~nû~~Jijor~' .,'. ...... ' ... ',.1 ,: ....." Ctr~Ctr.No~GO .' ~O~bl~ ' MD TVD MO'.. . 'TVQ ,Ref.., Qtfse~ '1:~~:I-~TI'9~B$~~Jijg,' ,ÐiS~ç~~.I.. . ~viatió~ ,waralia;tg It ' ft",' ft . ft', ,," ,ft'.. " . ..ft'.:'" .', .~I:Ig:, ' "~~,. , ".,.i,:". " . "",ft ,,', "'ff."" ,.U I,.. .', ': I I I 8300.00 8060.79 8300.00 8060.79 57.85 57.85 316.31 0.00 9.620 0.00 0.00 0.00 FAIL 8349.95 8107.49 8350.00 8108.08 57.97 58.59 312.29 175.92 9.620 1.59 0.00 1.59 Pass 8399.73 8153.31 8400.00 8155.29 57.95 59.34 311.31 174.85 9.620 4.88 0.00 4.88 Pass 8449.27 8198.22 8450.00 8202.35 57.93 60.13 310.10 173.57 9.620 9.48 0.00 9.48 Pass 8498.47 8242.08 8500.00 8249.32 57.91 60.93 308.63 172.03 9.620 15.62 0.00 15.62 Pass 8547.20 8284.73 8550.00 8296.27 57.90 61.72 307.26 170.61 9.620 23.48 0.00 23.48 Pass 8595.33 8326.06 8600.00 8343.21 57.88 62.51 306.22 169.52 9.620 33.11 0.00 33.11 Pass 8642.75 8365.95 8650.00 8390.17 57.87 63.30 305.45 168.71 9.620 44.54 0.00 44.54 Pass 8690.85 8405.84 8700.00 8437.16 57.89 64.10 304.78 168.03 7.000 57.25 0.00 57.25 Pass 8739.14 8445.88 8750.00 8484.14 57.91 64.91 303.93 167.18 7.000 70.18 0.00 70.18 Pass 8787.39 8485.88 8800.00 8531.08 57.94 65.71 302.95 166.20 7.000 83.24 0.00 83.23 Pass 8835.61 8525.85 8850.00 8578.00 57.97 66.51 302.11 165.36 7.000 96.39 0.00 96.39 Pass 8883.81 8565.81 8900.00 8624.94 58.01 67.31 301.45 164.70 7.000 109.63 0.00 109.63 Pass 8931.99 8605.75 8950.00 8671.91 58.04 68.10 300.92 164.17 7.000 122.96 0.00 122.96 Pass 8980.14 8645.68 9000.00 8718.89 58.08 68.89 300.48 163.73 7.000 136.39 0.00 136.39 Pass 9028.28 8685.58 9050.00 8765.88 58.13 69.70 300.10 163.35 7.000 149.87 0.00 149.87 Pass 9076.41 8725.48 9100.00 8812.86 58.18 70.49 299.75 163.00 7.000 163.39 0.00 163.39 Pass 9124.56 8765.40 9150.00 8859.82 58.23 71.29 299.46 162.71 7.000 176.84 0.00 176.84 Pass 9162.58 8796.41 9200.00 8906.77 58.23 72.07 299.35 162.60 7.000 191.30 0.00 191.30 Pass 9200.00 8825.46 9250.00 8953.71 58.23 72.87 299.51 162.76 7.000 208.55 0.00 208.55 Pass 9231.40 8848.60 9300.00 9000.65 58.23 73.67 299.84 163.09 7.000 228.45 0.00 228.45 Pass 9263.27 8870.87 9350.00 9047.59 58.24 74.49 300.27 163.51 7.000 250.91 0.00 250.91 Pass 9300.00 8894.91 9400.00 9094.54 58.26 75.30 300.73 163.98 7.000 275.87 0.00 275.87 Pass 9321.64 8908.22 9450.00 9141.49 58.28 76.13 301.22 164.47 7.000 302.73 0.00 302.73 Pass 9350.00 8924.68 9500.00 9188.43 58.30 76.96 301.72 164.97 7.000 331.65 0.00 331.65 Pass 9364.82 8932.83 9533.13 9219.54 58.32 77.50 302.05 165.29 7.000 351.78 0.00 351.78 Pass Site: PB D Pad Well: D-22 Rule Assigned: NO ERRORS Wellpath: D-22A V2 Inter-Site Error: 0.00 ft Reference Qffset Semi.M",or AxIs Ctr..Ctr. . . No-Go Allowable MD TVD MD TVD Ref Offset. . TFO+AZI TFO.HS Casing Distance Area Deviation Warning ft ft ft ft ft ft d~ deg In ft ft ft 8300.00 8060.79 8300.00 8060.79 57.85 57.85 316.31 0.00 9.620 0.00 0.00 0.00 FAIL 8349.95 8107.49 8350.00 8108.08 57.97 58.59 312.29 175.92 9.620 1.59 0.00 1.59 Pass 8399.73 8153.31 8400.00 8155.29 57.95 59.34 311.31 174.85 9.620 4.88 0.00 4.88 Pass 8449.27 8198.22 8450.00 8202.35 57.93 60.13 310.10 173.57 9.620 9.48 0.00 9.48 Pass 8498.47 8242.08 8500.00 8249.32 57.91 60.93 308.63 172.03 9.620 15.62 0.00 15.62 Pass 8547.20 8284.73 8550.00 8296.27 57.90 61.72 307.26 170.61 9.620 23.48 0.00 23.48 Pass 8595.33 8326.06 8600.00 8343.21 57.88 62.51 306.22 169.52 9.620 33.11 0.00 33.11 Pass 8642.75 8365.95 8650.00 8390.17 57.87 63.30 305.45 168.71 9.620 44.54 0.00 44.54 Pass 8690.85 8405.84 8700.00 8437.16 57.89 64.10 304.78 168.03 9.620 57.25 0.00 57.25 Pass 8739.14 8445.88 8750.00 8484.14 57.91 64.91 303.93 167.18 9.620 70.18 0.00 70.18 Pass 8787.39 8485.88 8800.00 8531.08 57.94 65.71 302.95 166.20 9.620 83.24 0.00 83.23 Pass 8835.61 8525.85 8850.00 8578.00 57.97 66.51 302.11 165.36 9.620 96.39 0.00 96.39 Pass 8883.81 8565.81 8900.00 8624.94 58.01 67.25 301.45 164.70 9.620 109.63 0.00 109.63 Pass I 8932.19 8605.92 8950.00 8671.68 58.04 67.28 301.02 164.27 9.620 122.17 0.00 122.17 Pass 8981.86 8647.10 9000.00 8715.73 58.09 67.28 301.68 164.93 9.620 127.10 0.00 127.10 Pass 9031.58 8688.32 9050.00 8757.32 58.13 67.29 303.99 167.24 9.620 126.53 0.00 126.53 Pass 9080.19 8728.62 9100.00 8796.95 58.18 67.30 308.99 172.24 9.620 123.32 0.00 123.32 Pass 9125.82 8766.44 9150.00 8832.80 58.23 67.31 318.38 181.63 9.620 118.71 0.00 118.71 Pass 9163.05 8796.79 9200.00 8864.83 58.23 67.30 330.12 193.37 9.620 115.55 0.00 115.55 Pass ) Sperry-SUD ) Anticollision Report Company: BP Amoco b~~:.. .'.4I30/2OQ2 Tim.è: .,. .16:14:15 Field: PrudhøeBay Co~rciùUrte(l~E)~efer~D~e: . Reference. Site: PB D Pad Referente. Well: D-22 . 'V~rf:ical. (T.VD)ltèfe~e~c~: ReferenceWellpath:. Plan D-22B Site: PB D Pad Well: Dø22 Rule Assigned: NO ERRORS Wellpath: D-22A V2 Inter-Site Error: 0.00 ft Reference . Offset ~D1i~~ro~r~. . Ctro.Cw ' No;,Go Allowable MD TVI) MD TVD Ref OtJset,~'()tAZJ;'J.'FO.as CasJèg. .DiStaDceAreå .. Deviation. ft ft ft ft ft ft , .. ~eg. . . d~'. in' . , ft ft. ft 9200.00 8825.46 9250.00 8896.14 58.23 67.29 341.82 205.06 9.620 119.62 0.00 119.62 Pass 9233.78 8850.30 9300.00 8926.12 58.23 67.28 353.10 216.34 9.620 134.72 0.00 134.72 Pass 9265.21 8872.18 9350.00 8954.82 58.24 67.28 1.89 225.14 9.620 158.98 0.00 158.98 Pass 9293.76 8890.96 9400.00 8981.50 58.26 67.26 8.39 231.63 9.620 189.55 0.00 189.55 Pass 9320.08 8907.29 9450.00 9000.70 58.28 67.26 14.74 237.98 9.620 220.76 0.00 220.76 Pass 9344.52 8921.59 9500.00 9011.67 58.30 67.26 21.01 244.25 9.620 251.93 0.00 251.92 Pass 9368.31 8934.69 9550.00 9014.99 58.33 67.26 27.09 250.33 9.620 282.06 0.00 282.06 Pass 9395.85 8948.82 9600.00 9014.15 58.36 67.28 32.65 255.90 9.620 308.03 0.00 308.03 Pass 9427.00 8963.40 9650.00 9010.72 58.41 67.30 37.58 260.83 9.620 331.37 0.00 331.37 Pass 9459.56 8977.02 9700.00 9007.24 58.47 67.33 41.49 264.74 9.620 358.23 0.00 358.23 Pass 9493.20 8989.31 9750.00 9006.20 58.54 67.36 44.12 267.36 9.620 389.42 0.00 389.42 Pass 9526.98 8999.77 9800.00 9006.61 58.62 67.40 45.79 269.04 9.620 423.56 0.00 423.56 Pass 9559.48 9008.04 9850.00 9008.23 58.71 67.44 46.73 269.98 9.620 460.66 0.00 460.66 Pass 9590.72 9014.29 9900.00 9010.13 58.80 67.49 47.24 270.48 9.620 499.55 0.00 499.55 Pass 9619.53 9018.57 9950.00 9011.40 58.89 67.53 47.53 270.77 9.620 540.52 0.00 540.52 Pass 9645.68 9021.21 10000.00 9012.29 58.98 67.58 47.64 270.88 9.620 583.33 0.00 583.33 Pass 9668.21 9022.54 10050.00 9012.87 59.06 67.62 47.64 270.88 9.620 628.13 0.00 628.13 Pass 9692.41 9022.97 10100.00 9012.23 59.14 67.67 47.68 270.92 9.620 672.07 0.00 672.06 Pass 9719.39 9022.97 10150.00 9012.38 59.25 67.73 47.61 270.85 9.620 714.15 0.00 714.14 Pass 9748.49 9022.97 10200.00 9010.71 59.36 67.80 47.69 270.93 9.620 754.78 0.00 754.78 Pass 9779.77 9022.97 10250.00 9008.87 59.49 67.87 47.78 271.02 9.620 793.76 0.00 793.76 Pass 9813.00 9022.97 10300.00 9008.21 59.63 67.96 47.78 271.02 9.620 831.12 0.00 831.12 Pass 9847.92 9022.97 10350.00 9007.41 59.78 68.05 47.79 271.03 9.620 866.89 0.00 866.89 Pass 9885.43 9022.97 10400.00 9005.67 59.95 68.16 47.86 271.10 9.620 899.91 0.00 899.91 Pass 9924.83 9022.97 10450.00 9004.32 60.13 68.28 47.91 271.15 9.620 930.68 0.00 930.68 Pass 9966.29 9022.97 10500.00 9003.86 60.33 68.42 47.90 271.14 9.620 958.61 0.00 958.61 Pass 10000.00 9022.97 10550.00 9003.70 60.34 68.37 48.80 271.12 9.620 986.46 0.00 986.46 Pass 10000.00 9022.97 10600.00 9003.65 60.34 68.51 48.77 271.09 9.620 1016.94 0.00 1016.93 Pass 10040.87 9022.97 10650.00 9002.82 60.19 68.26 50.41 271.10 9.620 1049.19 0.00 1049.19 Pass 10062.71 9022.97 10700.00 8999.77 60.12 68.17 51.41 271.23 9.620 1081.50 0.00 1081.50 Pass 10100.00 9022.97 10750.00 8996.01 59.98 67.89 53.07 271.39 9.620 1111.73 0.00 1111.73 Pass 10100,00 9022.97 10800.00 8993.57 59.98 68.06 53.16 271.48 9.620 1138.64 0.00 1138.64 Pass 10132.94 9022.97 10850.00 8994.41 59.79 67.80 54.40 271.41 9.620 1163.08 0.00 1163.08 Pass 10157.60 9022.97 10900.00 8995.86 59.64 67.64 55.29 271.31 9.620 1185.02 0.00 1185.02 Pass 10200.00 9022.97 10950.00 8995.94 59.39 67.18 56.96 271.28 9.620 1206.14 0.00 1206.14 Pass 10200.00 9022.97 11000.00 8995.96 59.39 67.38 56.94 271.26 9.620 1225.77 0.00 1225.77 Pass 10200.00 9022.97 11027.13 8996.23 59.39 67.46 56.92 271.24 1237.20 No Reference Casings Site: PB 0 Pad Well: 0-22 Rule Assigned: NOERRORS Wellpath: D-22APB1 V3 Inter-Site Error: 0.00 ft Reference Offset SemiøMajor Axis Ctr-Ctr No-Go ADowable MD TVD MD 1'VD Ref Oft'set 1'FO+AZI 'fFO-HS Casing DistaDce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft /! 8300.00 8060.79 8300.00 8060.79 57.85 57.85 316.31 0.00 9.620 0.00 0.00 0.00 FAIL 8349.95 8107.49 8350.00 8108.08 57.97 58.59 312.29 175.92 9.620 1.59 0.00 1.59 Pass 8399.73 8153.31 8400.00 8155.29 57.95 59.34 311.31 174.85 9.620 4.88 0.00 4.88 Pass 8449.27 8198.22 8450.00 8202.35 57.93 60.13 310.10 173.57 9.620 9.48 0.00 9.48 Pass 8498.47 8242.08 8500.00 8249.32 57.91 60.93 308.63 172.03 9.620 15.62 0.00 15.62 Pass 8547.20 8284.73 8550.00 8296.27 57.90 61.72 307.26 170.61 9.620 23.48 0.00 23.48 Pass 8595.33 8326.06 8600.00 8343.21 57.88 62.51 306.22 169.52 9.620 33.11 0.00 33.11 Pass ') Sperry-SuD ) Anticollision Report Company: BPAmoco Date: 413012002 Time: 16:14:15 Page: 4 Field: Pruc:thoeBay Reference Site: PBO Pad Cò-ordiDate(NE) Reference: Well:[)..22. True North Reference Well: Oø22 Vertieal (TVD) Refereace: Plan 0-228 71.63 71.6 Reference WeDpath: Plan o.22B Db:. Oracle Site: PB D Pad Well: 0.22 Rule Assigned: NO ERRORS WeDpath: o.22APB1 V3 Inter-Site Error: 0.00 It Referenct Offset ~~.;MIÙ()I'~ ... . CtM:ti>~o~ Allowable MD TVD MD TVD Ref ()ftket.TfØ+AZI.'rfQ.HS ....CasbIg DistJmce ..~ Deviatioo Wari.iag ft ft ft ft It ft. deg c1eg in, '. ft ,'It It 8642.75 8365.95 8650.00 8390.17 57.87 63.30 305.45 168.71 9.620 44.54 0.00 44.54 Pass 8690.85 8405.84 8700.00 8437.16 57.89 64.10 304.78 168.03 9.620 57.25 0.00 57.25 Pass 8739.14 8445.88 8750.00 8484.14 57.91 64.91 303.93 167.18 9.620 70.18 0.00 70.18 Pass 8787.39 8485.88 8800.00 8531.08 57.94 65.71 302.95 166.20 9.620 83.24 0.00 83.23 Pass 8835.61 8525.85 8850.00 8578.00 57.97 66.51 302.11 165.36 9.620 96.39 0.00 96.39 Pass 8883.81 8565.81 8900.00 8624.94 58.01 67.25 301.45 164.70 9.620 109.63 0.00 109.63 Pass 8932.19 8605.92 8950.00 8671.68 58.04 67.28 301.02 164.27 9.620 122.17 0.00 122.17 Pass 8981.86 8647.10 9000.00 8715.73 58.09 67.28 301.68 164.93 9.620 127.10 0.00 127.10 Pass 9031.58 8688.32 9050.00 8757.32 58.13 67.29 303.99 167.24 9.620 126.53 0.00 126.53 Pass 9080.19 8728.62 9100.00 8796.95 58.18 67.30 308.99 172.24 9.620 123.32 0.00 123.32 Pass 9125.82 8766.44 9150.00 8832.80 58.23 67.31 318.38 181.63 9.620 118.71 0.00 118.71 Pass 9163.05 8796.79 9200.00 8864.83 58.23 67.30 330.12 193.37 9.620 115.55 0.00 115.55 Pass 9200.00 8825.46 9250.00 8896.14 58.23 67.29 341.82 205.06 9.620 119.62 0.00 119.62 Pass 9233.78 8850.30 9300.00 8926.12 58.23 67.28 353.10 216.34 9.620 134.72 0.00 134.72 Pass 9265.25 8872.21 9350.00 8954.81 58.24 67.28 1.89 225.14 9.620 158.92 0.00 158.92 Pass 9294.11 8891.18 9400.00 8983.71 58.26 67.27 7.62 230.87 9.620 190.42 0.00 190.42 Pass 9320.87 8907.76 9450.00 9013.17 58.28 67.27 11.07 234.31 9.620 226.17 0.00 226.17 Pass 9350.00 8924.68 9500.00 9042.67 58.30 67.26 13.38 236.62 9.620 261.42 0.00 261.42 Pass 9377.27 8939.42 9550.00 9072.29 58.34 67.27 14.90 238.15 9.620 294.75 0.00 294.75 Pass 9407.26 8954.33 9600.00 9103.01 58.38 67.28 15.59 238.84 9.620 326.45 0.00 326.45 Pass 9437.84 8968.12 9650.00 9134.90 58.43 67.29 15.59 238.84 9.620 356.41 0.00 356.41 Pass 9450.00 8973.20 9667.13 9146.31 58.45 67.30 15.36 238.60 9.620 365.29 0.00 365.29 Pass Dø22B Kick Tolerance ) Page 1 of 2 ') 4/30/2002 11 :08 AM b KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Well: Version 6.0, December 2000 Units (UK/US): Kick Zone Parameters: 1 Open hole Size? 2 Measured Depth? 3 Vertical Depth? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal? 6 Min Pore Pressure Gradient? 7 Max Pore Pressure Gradient? 8 Kick Zone Temperature? Weak Point Parameters: 9 Measured Depth? 10 Vertical Depth? 11 Section Angle «87 deg) ? 12 Min Fracture Gradient / EMW ? 13 Max Fracture Gradient / EMW 14 Weak Point Temperature? Other Parameters: 15 Drill Collar 00 ? 16 Drill Collar Length? 17 Drillpipe 00 ? 18 Surface Pressure Safety Factor? 19 Mud Weight in Hole? (inch) (H) (H) (H) (deg) (ppg) (ppg) (deg.F) (H) (H) (deg) (ppg) (ppg) (deg.F) (inch) (H) (inch) (psi) (ppg) (bbl/H) (bbl/H) Annular Capacity Around BHA: Annular Capacity Around DP: At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/H) (H) (bbl) (H) (bbl) At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/H) (H) (bbl) (ft) (bbl) Input Error Messages: 8810 8502 Non-Horizontal 7.300 9:600 190 8300. 8060 11.000 12.000 185 150 to.600 0.02592 0.05464 Comments: 17 0.0752 3101 Extends above weak point Infinite 965 Extends above weak point Infinite 436 0.0799 4021 Extends above weak point Infinite 1864 Extends above weak point Infinite 0-228 Kick Tolerance ) Page 2 of 2 ) 4/30/2002 11 :08 AM I-Ö-Min Fracture Grad -o-Max Fracture Grad I 200 180 160 - jj 140 e.. 8 120 s::: e 100 Q) ~ 80 ~ .2 60 ~ 40 20 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient APPENDIX: 8.00 10.00 12.00 Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure? (psi) Near Surface Casing 10 ? (inch) Near Surface Annular Temperature? (deg.F) Gas Gradient at Max Surface Pres: (psi/ft) Near Surface Annular Capacity: (bbl/ft) At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) - 4500 ! 4000 ~ 3500 ::::J Õ 3000 > ~ 2500 CJ Q) 2000 jj as == .2 < )( as :E 1500 1000 500 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient 5000 12.347 32 0.113 0.13253 Comments: 14404 Extends to hole TO infinite 12086 Extends to hole TD infinite '" ~ '1.") 8.00 10.00 12.00 P } THIS NOTICE IN THE DOGHOUSE ) D-22B Rig site Summary of Drilling Hazards ../ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 10 ppm, March 2001. ../ NORM test all retrieved well head and completion equipment. ../ All wells pass major risk criteria. The closest neighboring wells, at surface, are D- 27 and D-28. Each is approximately 55' away. No shut-in will be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ../ There are two fault crossings expected, during the drilling of the 6 1/8" production interval. The anticipated throw is .....15'. No significant losses are expected, but due attention to the possibility should be paid. ../ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ../ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 550 psi. Always follow established drilling and connection practices for stuck pipe prevention. ../ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ..... 0.1 psia at 100° F. CONSULT THE D- PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. D-22B TREE = 6" MCEV OY . . WELLHEAD= MCEVOY ÄëTÛÃ.TÕR;'"~""_"_'_M-õîis KB~CE\7w,;-w_'_M_~W.""'7ã~'Š3Î' "BF."ELEV";''''''''''''W' ""''''''''¿î'3:'13 ;' KÖpW;"WM.~_~^_._~_ww-::Ï30Õ;' ,'Mãx'ÄñgÎë''';''''''''''''''g'5''@''gïfl2ì ! Ê~!,~~:~~":§~,~=~,~~=:~:',~':,,:~3,,j,~.', Datum TVD= 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2684' I--.J Minimum ID = 2.37" @ 8503' 3-1/2" x 2-7/8" XO Below Baker Deploy Slv 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 8443' I TOP OF 7" LNR 1-1 8466' TOP OF 2-7/8" LNR -I 8503' 1 BKR DEPLOY SL V WIGS PROFILE, ID = 3.00" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 8575' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 8784' PERFORA TION SUMMARY REF LOG: Sperry MWD/GR, 11/18/97 ANGLEATTOPPERF: 88 @ 9930' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9930 - 9990 0 12/03/97 1-11116" 4 10050 - 10210 0 12/03/97 1-11116" 4 10290 - 10440 C 09/12/98 1-11116" 4 10570 - 10750 C 04/12/98 1-11116" 4 10860 -10960 C 04/12/98 ) SAFETY' )S: WELL EXCEEDS 70° @ 9447' AND GOES HOklLONTAL @ 9550' D-22A (f) 2137' 1-15-1/2" OTIS SSSV LAND. NIP, ID = 4.562" I 2583' 1-1 FOC I 11 GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH SIZE DATE ~ 12 3051 2973 1 OTIS RA 1-1/2" 11 4349 4265 12 OTIS RA 1-1/2" 10 5437 5301 23 OTIS RA 1-1/2" 9 6271 6067 23 OTIS RA 1-1/2" 8 6676 6441 21 OTIS RA 1-1/2" 7 6832 6588 20 OTIS RA 1-1/2" 6 7180 6917 18 OTIS RA 1-1/2" 5 7337 7068 17 OTIS RA 1-1/2" 4 7614 7330 18 OTIS RA 1-1/2" 3 7770 7479 18 OTIS RA 1-1/2" 2 8131 7821 19 OTIS RA 1-1/2" 1 8287 7969 19 OTIS RA 1-1/2" I 8362' 1-I5-1/2"BKRSS'L'SLlDNGSLV,ID=4.313" I ì I 8420' H1BG SEAL ASSY I ~ 8443' 1-19-5/8" x 5-1/2" BKR PKR, ID = 4.00" I I I 8443' 1-15-1/2" X 4-1/2" XO I I ---i 8466' 1-17" LNR HGR 1 ~ b I 8491' 1-I4-1/2"OTISXNIP,ID=3.813" I ~ 8532' H 4-112" DTIS XN NIP, D = 3.725" (BEHND 2-7/8" LNR) I I 8575' 1-14-1/2" TBG TAIL ID = 3.958" 1 '\ 1 8561' H B-MD I Cement top at 8710' L I I i ~ ~ MILLOUTWINDOW 8938' - 8944' I~ I 10250' 1-12-7/8" HES CIBP 09/12/98 1 I 10510' 1-12-7/8" EZ DRILL BP04/12/98 I 8935' l-i TOP OF BKR WHIPSTOCK I 8944' 1-1 RA TAG 1 17" LNR, 26#, L-80, .0383 bpI, ID ~ 6::' ~ ::' ~ 12-7/8" LNR, 6.16#, L-80 ST-L, .0058 bpf, ID = 2.37" l-i 11034' DATE 01/11/83 12/03/97 02/09/01 03/08/01 05/28/01 REV BY DATE REV BY COMMENTS PRUDHOE BA Y UNrT WELL: D-22a PERMrT No: 97-2040 API No: 50-029-20737-01 Sec.23,T11N,R13E BP Exploration (Alaska) COMMENTS ORIGINAL COMPLETION PARKER SIDETRACK COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL CH/tlh CORRECTIONS TREE = 6" MCEV OY . r WELLHEAD= MCEVOY Ac-rüÄ TOR';'" .... OTIS Klf~ELEV =-'-'~ . 7à.š"jì "BF:"ELË\7";""^"""""""""""""4ff'1§;' -Kõp^;w_''"''''~'-''""'"'"'~~f3^Õõ'~ 'Max'Arlg'ìe;";'^''''''''''9s''@'''§672ï M5ãtûrñMÕ;;--"'-"'"~921ãì 5ãtü'm^iV"5;"'''~'''Ww''''''ãí3õ'õ'tss' D-:"lA Pre-Rig WO~.{ 8) 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2684' I~ L Minimum ID = 2.37" @ 8503' 3-1/2" x 2-7/8" XO Below Baker Deploy Slv I Chemical cut tubing at -8350'. ~ 'I~¡I~ : :><.",;,:,'".,'",.".,:.,:,',;,\4,~,¡¡:,',','",,', .:.....~ \_';~";>\'( i I~ 1 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 8443' 1 TOP OF 7" LNR 1-1 8466' w ~" . ~¡~{ 1 TOP OF 2-7/8" LNR -I 8503' 1 BKR DEPLOY SL V WIGS PROFILE, ID = 3.00" 2137' 1-15-1/2" OTIS SSSV LAND. NIP, ID = 4.562" I 2583' 1-1 FOC 1 ~ GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH SIZE DATE 12 3051 2973 1 OTIS RA 1-1/2" 11 4349 4265 12 OTIS RA 1-1/2" 10 5437 5301 23 OTIS RA 1-1/2" 9 6271 6067 23 OTIS RA 1-1/2" 8 6676 6441 21 OTIS RA 1-1/2" 7 6832 6588 20 OTIS RA 1-1/2" 6 7180 6917 18 OTIS RA 1-1/2" 5 7337 7068 17 OTIS RA 1-1/2" 4 7614 7330 18 OTIS RA 1-1/2" 3 7770 7479 18 OTIS RA 1-1/2" 2 8131 7821 19 OTIS RA 1-1/2" 1 8287 7969 19 OTIS RA 1-1/2" 8362' 1-15-1/2" BKRSS 'L' SLlDNG SLV, ID = 4.313" 1 8420' I-ITBG SEAL ASSY 1 8443' 1-19-5/8" x 5-1/2" BKR PKR, ID = 4.00" I 8443' 1-1 5-1/2" X 4-1/2" XO 1 8466' 1-17" LNR HGR 1 8491' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 8575' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 8784' 8532' 1-14-1/2" OTIS XN NIP, ID = 3.725" (BEHIND 2-7/8" LNR) 1 I 8575' 1-14-1/2" TBG TAIL ID = 3.958" 1 \~ 1 8561' 1-1 ELMD 1 \ Cement top at 8710' ... PERFORA TION SUMMARY REF LOG: Sperry MWD/GR, 11/18/97 ANGLE AT TOP PERF: 88 @ 9930' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9930 - 9990 0 12/03/97 1-11116" 4 10050 - 10210 0 12/03/97 1-11116" 4 10290 - 10440 C 09/12/98 1-11116" 4 10570 - 10750 C 04/12/98 1-11116" 4 10860 - 10960 C 04/12/98 8935' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 9538' I 2-7/8" LNR, 6.16#, L-80 ST-L, .0058 bpf, ID = 2.37" 1-1 11034' DATE 01/11/83 12/03/97 02/09/01 03/08/01 OS/28/01 REV BY COMMENTS ORIGINAL COMPLETION PARKER SIDETRACK COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL CH/tlh CORRECTIONS DA TE REV BY COMMENTS 12/17/01 DEW Proposed Pre-Rig work MILLOUT WINDOW 8938' - 8944' -I auFBl\œm1 PLQ prl ~ rwe I 10250' 1-12-7/8" HES CIBP 09/12/98 1 I 10510' 1-12-7/8" EZ DRILL BP 04/12/98 I PRUDHOE BAY UNIT WELL: D-22A PERMIT No: 97-2040 API No: 50-029-20737-01 Sec. 23, T11N,R13E BP Exploration (Alaska) I TREE =; 6" MCEVOY WELLHEAD= MCEVOY 'AëTuÃfõR;'M"~""_'''"_W'''''"ÕTIS' 'KB:-êL'E\r;;" ", n"""73':1MJ'i' ,",''''',',',',',',','"",'','.'',',,,,"m..',,,",,'',,',',.'''''..... """,",','".',"""'W.","'''''.' BF. ELEV = 43.13' "...,''HHM'MW"^,U'''W."yw,w.w.'M',y""w,,,,'.W^",,'_Y.w,W,y,w,''''',YMW,WMWMW',' KOP = 8300' :~ãxM'~~g~~~~~~~:"'~':'~'ò'~Ö~: Datum MD = 9691' ,,,,,,',,Y'''''',',''''','''''''''''''.'.'M,,'.,........,....'..,',','.w,....,......,.,',''''W,',','''''',','....,',',w"w,w"""""",,,,',,,,,'.'''''',y,, Datum lVD= 8950' SS ST MD 6 TBD 5 TBD 4 TBD 3 TBD 2 TBD 1 TBD I Top of Whipstock I Bridge Plug set D-22f)Proposed COr: pletion I) I -40' 1--1 Crossover from 51/2" to 4 1/2" \ 112.6#, 13Cr-80 tubing I 2200' 1-i4 1/2" 'X' Landing Nipple, ID = 3.813" -~I 2583' l-i FOC I ~ 2684' SIZE 4 1/2" X 1" 4 1/2" X 1" 41/2" X 1" 4 1/2" X 1" 41/2" X 1" 41/2" X 1" l-i 8300' 1 l-i 8318' 1- 8362' 1-15-1/2" BKR SS 'L' SLlDNG SLV, 10 = 4.313" 1 8420' l-i TBG SEAL ASSY 1 8443' 1-i9-5/8" x 5-1/2" BKR PKR, 10 = 4.00" I 1 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-i 8443' I 1 TOP OF 7" LNR l-i 8466' I 8491' 1-i4-1/2" OTIS X NIP, 10 = 3.813" I TOPOF 2-7/8" LNR l-i 8503' 8532' 1-14-1/2" OTIS XN NIP, 10 = 3.725" (BB-iINO 2-7/8" LNR) 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i GAS LIFT MANDRELS 1'10 DEV TYPE VLV LATCH TBD TBD TBD TBD TBD TBD 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 8575' 1 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 8784' PERFORA TION SUMMARY REF LOG: Sperry MVV DIG R, 11/18/97 ANGLE A T TOP PERF: 88 @ 9930' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 1-11/16" 4 9930 - 9990 0 12/03/97 1-11116" 4 10050-10210 0 12/03/97 1-11116" 4 10290 - 10440 C 09/12/98 1-11116" 4 10570 - 10750 C 04/12/98 1-11116" 4 10860 - 10960 C 04/12/98 -.J DATE L I I 8150' 1--1 Baker 9 5/8" x 7" ZXP Liner Top I I packer; HMC Liner hanger. I \ . 8- I-iTOp of window; Exit from 95/8" 1 141/2" 12.6# ,13Cr-80 tubing; VamAce 8596' 1-i4-1/2" 'x' Nipple, ID = 3.813" 1 8609' l-i 7" X 4-1/2" Baker S-3 Packer 1 8624' 1-i4-1/2" 'X' Nipple, ID = 3.813" 1 8647' 1-i4-1/2" 'XN' Nipple, ID = 3.75" I 8662' - Baker 13Cr 7" X 4 1/2" '11e- back sleeve; ZXP Liner Top packer; 'FlexLock' Liner I JJ I-j l ~ ~ ~ I 8812' l-i 7" 26#, L-80 BTG-M Liner 1 I PBTD l-i 10870' 1 / I 10950' 1-i4 1/2" 12.6# 13Cr-80 Liner 12/17/01 DÐN Proposed 0-22B Completion I CTU P & A cement plug; perf squeeze. 10250' 1-i2-7/8" HES CIBP 09/12/98 1 l-i 2-7/8" EZ DRILL BP 04/12/98 1 1 PBTD l-i 10967' 1 1 8944' I 7" LNR, 26#, L-80, .0383 bpi, ID: 6~:':~ :::: : =- .. 1 2-7/8" LNR. 6.16#, L-80 ST-L, .0058 bpi, [ = 2.37" H 11034' 1 01/11/83 12/03/97 02/09/01 03/08/01 OS/28/01 ORIGINAL COMPLETION PARKER SIDETRACK COMPLETION SIS-SLT CONVERTED TO CANVAS SIS-LG FINAL CH/tlh CORRECTIONS WELL: o.22B PERMIT No: 97-2040 APt No: 50-029-20737-02 Sec.23,T11N,R13E BP Exploration (Alaska) H 206703 DATE INVOICE / CREDIT MEMO DESCRIPTION 040902 CK040902E PYMT COMMENTS: HANDLING INST: PERMIT TO DRILL FEE S/H - TERRIE HUBBLE THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ ./ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY GROSS iOO. 00 X4628 î). ~ '?.-!ú !~( E (' f." A!aska OJ¡ ¿t, (,2; :.: i,,', '- PJlciìûraQi.:' 100. 00 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 DATE 04i i i i()2 CHECK NO. 002û6703 VENDOR ALASV..AO I LA NET DISCOUNT 1 ()O. 00 J ~~ -~ .¡-'" ~ . : . ~, i ~_:. iOO.OO No. H 208703 CONSOLIDATED COMMERCIAL ACCOUNT 00206703 ONE HUNDRED & 00/100************************************* US DOLLAR To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 DATE 04/11/02 AMOUNT $100. 00 NOT VALID AFTER 120 DAYS \2- 't .. ~ þ ,7 'lA If .. -...ßf!¡f'~~ itA. III 20 b 70 ~III 1:0... ¡. 20 ~8 t151: OOB"'''' ¡. t1111 -~ 00 H '- '- CHECK 1 ST ANDARD LEITER DEVELOPMENT DEVELOPMENT REDRlLL V EXPLORATION INJECTION WELL INJECTION WELL REDRILL ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LEITER WELL NAME I'ß4 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60~9) PILOT HOLE (PH) ANNULAil D~OSAL ~NO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL 0-22..~ "CLUE" The permit is for a Dew well bore segment of existing weD ~ Permit No, ,API No. . ' Production should continue to be reported as a function of the original API number stated above. ' In accordance with 2,0 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY A fJ X WELL NAME PI< u D~ 2.2..Ii FIELD & POOL ~ 7'ò / 50 INIT CLASS IJe-d J ....C>~ í ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . R\N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~PR DATE 12. Permit ca~ be issued without administrativ~ approval.. . . . . \ Y N I(PC .Ç/1/c>'L 13. Can permIt be approved before 15-day walt.. . . . . . . . . . ~ N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . '-¥---N- 15. Surface casing protects all known USDWs. . . . . . . . -¥-N- fJ IA- 16. CMT vol adequate to circulate on conductor & surf csg. . . . .-¥----N- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥-N- 18. CMT will cover all known productive horizons. . . . . . . . . . <9 N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . fP N l. 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . éÍl. N III ti. p..ø ÿ s 2 G Ç. 21. Ifareødrill,hasa10-403forabandonmentbeenapproved... &..N Á}>ph/ll¿¿ SltPloz... 22. Adequate well bore separation proposed.. . . . . . . . . . . . œ N 23. If diverter required, does it meet regulations. . . . . . . . . . -¥-'N- NIt+- 24. Drilling fluid program schematic & equip liS. t a. dequate. . . . . !.'. , N 25. BOPEs, do they meet regulation. . . . . .: . . . . . . . . . . . N , APPR DATE 26. BOPE press rating appropriate; test to - 3500 psig. N (14<;r) '2..'-1-00 f~' WbA- ? I ~ 101- 27. Choke manifold complies w/API RPø53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . f)l. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (bY GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y @ 31. Data presented on potential overpressure zones. . . . . . . )fN .4 J../J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y , v 77 ~)'R ?f~ 33. Seabed condition survey (if offøshore). . . . . . . . . . . . . N flit': .:y7~ 02- 34. Contact name/phone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y to surface; (C) will not impair mechanical integrity of the well used for disposal; (0) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ SFD- PROGRAM: Exp - Dev ~ Redrll ~ Serv - Wellbore seg - Ann. disposal para req - GEOL AREA Ÿ? I':) UNIT# /1 b .ç~ ON/OFF SHORE gJA.:} APPR DATE ,(p¿ 0þ"l- /V.. A ~ ~ WGA WÚk- JMff COT DrS OS,! J~ JMH ( ( Commentsllnstructions: ) ) 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 infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically organize this category of information. ) ) ~oa,"/o 5 { 14 ~<6 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 16 08:18:19 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN C omme n t s . . . . . . . . . . . . . . . . . S T S LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name...... . UNKNOWN C omme n t s . . . . . . . . . . . . . . . . . S T S LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA D-22B 500292073702 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 16-JAN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22086 R. MCNEILL R. BORDES / MWD RUN 2 AK-MW-22086 R. MCNEILL R. BORDES / MWD RUN 3 AK-MW-22086 J. SACK J. RALL / D. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-22086 E. QUAM J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 23 llN 13E 1550 1692 MSL 0) 71.83 44.18 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8278.0 6.125 7.000 8813.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. ) ) THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 8278'MD/8040'TVD) - ONLY SROP DATA FOR RUN 1 DATA ARE PRESENTED. DGR DATA OVER THE INTERVAL 7395'MD/7184'TVD TO 7534'MD/7319'TVD WERE ACQUIRED WHILST RIH FOR MWD 2. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3 & 4 INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNORR, BP ALASKA, DATED 7/08/02. 5. MWD RUNS 2 - 4 REPRESENT WELL D-22B WITH API#: 50-029-20737-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10945'MD/9003'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 500 - 900 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/01/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FI LE NUMBER: EDITED MERGED MWD 1 ) Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT NPHI FCNT DRHO RHOB PEF $ ) clipped curves; all bit runs merged. .5000 START DEPTH 7307.0 8270.5 8270.5 8270.5 8270.5 8270.5 8278.0 8716.5 8717.0 8717.0 8804.0 8804.0 8804.0 STOP DEPTH 10893.5 10900.5 10900.5 10900.5 10900.5 10900.5 10945.0 9844.0 9844.0 9844.5 9860.0 9860.0 9860.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 8278.0 8310.5 8815.0 9943.5 MERGE BASE 8310.5 8815.0 9943.5 10945.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value................... ...-999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7307 10945 9126 7277 7307 10945 ROP MWD FT/H 0.02 164.36 52.2441 5335 8278 10945 GR MWD API 10.78 537.25 51. 3318 5933 7307 10893.5 RPX MWD OHMM 0.75 2000 27.6354 5261 8270.5 10900.5 RPS MWD OHMM 0.49 1553.23 20.2344 5261 8270.5 10900.5 RPM MWD OHMM 0.47 2000 36.8727 5261 8270.5 10900.5 RPD MWD OHMM 0.38 2000 41.3217 5261 8270.5 10900.5 ) FET MWD HOUR 0.4918 79.3596 3.10589 5261 NPHI MWD PU-S 4.58 84.71 23.7362 2255 FCNT MWD CNTS 66.5 3435.6 762.34 2256 NCNT MWD CNTS 10982.8 52019.3 29445.9 2256 RHOB MWD G/CM 1. 235 3.029 2.28955 2113 DRHO MWD G/CM -0.524 0.431 0.0432958 2113 PEF MWD BARN 0.76 15.48 2.15024 2113 First Reading For Entire File......... .7307 Last Reading For Entire File.......... .10945 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8278.0 STOP DEPTH 8310.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 01-JUN-02 Insite Memory 8310.0 8278.0 8310.0 .0 .0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.510 8278.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): LSND 10.60 59.0 8.6 1000 ) 8270.5 8717 8717 8716.5 8804 8804 8804 10900.5 9844 9844.5 9844 9860 9860 9860 ) ). FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 4.0 .000 .000 .000 .000 .0 168.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 8278 0.02 Max 8310.5 7.91 Mean Nsam 8294.25 66 3.27667 66 First Reading 8278 8278 Last Reading 8310.5 8310.5 First Reading For Entire File......... .8278 Last Reading For Entire File.......... .8310.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FI LE NUMBER: RAW MW D Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 2 .5000 ) FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 7307.0 8270.5 8270.5 8270.5 8270.5 8270.5 8311.0 STOP DEPTH 8782.5 8775.0 8775.0 8775.0 8775.0 8775.0 8815.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Da ta Record Type............... . . .0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing......... ...., ...... .60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O ) 02-JUN-02 Insite 66.16 Memory 8815.0 8310.0 8815.0 21.0 35.2 TOOL NUMBER 134347 151812 8.500 8278.0 LSND 10.60 55.0 9.2 1000 4.2 2.350 1.540 2.300 5.800 100.0 156.2 100.0 100.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 ) RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 OHMM OHMM OHMM HOUR 4 4 4 4 ) 1 68 1 68 1 68 1 68 16 20 24 28 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7307 8815 8061 3017 7307 8815 ROP MWD020 FT/H 2.09 131.79 38.7114 1009 8311 8815 GR MWD020 API 49.82 158.21 102.608 1711 7307 8782.5 RPX MWD020 OHMM 0.99 1552.33 6.04635 1010 8270.5 8775 RPS MWD020 OHMM 0.95 1553.23 6.68604 1010 8270.5 8775 RPM MWD020 OHMM 0.93 2000 11.9137 1010 8270.5 8775 RPD MWD020 OHMM 0.95 2000 37.997 1010 8270.5 8775 FET MWD020 HOUR 0.97 30.38 3.28525 1010 8270.5 8775 First Reading For Entire File......... .7307 Last Reading For Entire File.......... .8815 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT GR RPX RPS RPM RPD FET RHOB DRHO PEF ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 8716.5 8717.0 8717.0 8763.5 8775.5 8775.5 8775.5 8775.5 8775.5 8804.0 8804.0 8804.0 8815.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : STOP DEPTH 9844.0 9844.0 9844.5 9892.0 9899.0 9899.0 9899.0 9899.0 9899.0 9860.0 9860.0 9860.0 9943.5 07-JUN-02 Insite 66.37 Memory ) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 9944.0 8815.0 9944.0 34.0 91. 6 TOOL NUMBER 100626 65830 112439 16777215 6.125 8813.0 QUICKDRIL-N 8.40 48.0 9.1 600 11. 0 4.000 2.120 4.250 4.500 86.0 168.0 78.0 78.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 Name Service Unit Min Max Mean Nsam First Reading Last Reading ) DEPT FT 8716.5 9943.5 9330 2455 ROP MWD030 FT/H 0.22 164.36 51. 456 2257 GR MWD030 API 13.26 537.25 40.9033 2258 RPX MWD030 OHMM 0.75 2000 56.1454 2248 RPS MWD030 OHMM 0.49 1217.16 37.9453 2248 RPM MWD030 OHMM 0.47 2000 73.3003 2248 RPD MWD030 OHMM 0.38 2000 71.7015 2248 FET MWD030 HOUR 0.4918 79.3596 4.35776 2248 NPHI MWD030 PU-S 4.58 84.71 23.7362 2255 FCNT MWD030 CNTS 66.5 3435.6 762.34 2256 NCNT MWD030 CNTS 10982.8 52019.3 29445.9 2256 RHOB MWD030 G/CM 1. 235 3.029 2.28955 2113 DRHO MWD030 G/CM -0.524 0.431 0.0432958 2113 PEF MWD030 BARN 0.76 15.48 2.15024 2113 First Reading For Entire File......... .8716.5 Last Reading For Entire File.......... .9943.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 ) 8716.5 8815.5 8763.5 8775.5 8775.5 8775.5 8775.5 8775.5 8717 8717 8716.5 8804 8804 8804 9943.5 9943.5 9892 9899 9899 9899 9899 9899 9844 9844.5 9844 9860 9860 9860 header data for each bit run in separate files. 4 .5000 START DEPTH 9892.5 9899.5 9899.5 9899.5 9899.5 9899.5 9944.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) STOP DEPTH 10893.5 10900.5 10900.5 10900.5 10900.5 10900.5 10945.0 09-JUN-02 Insite 66.37 Memory 10945.0 9944.0 10945.0 88.3 94.6 ) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ') TOOL NUMBER 100626 65830 6.125 8813.0 QUICKDRIL-N 8.40 52.0 9.1 500 10.0 2.250 .940 2.250 2.500 68.0 172.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9892.5 10945 10418.8 2106 9892.5 10945 ROP MWD040 FT/H 0.95 119.58 61.5627 2003 9944 10945 GR MWD040 API 10.78 90.46 19.8394 2003 9892.5 10893.5 RPX MWD040 OHMM 1. 35 18.32 6.52415 2003 9899.5 10900.5 RPS MWD040 OHMM 1. 75 20.48 7.18896 2003 9899.5 10900.5 RPM MWD040 OHMM 2.23 21.97 8.57469 2003 9899.5 10900.5 RPD MWD040 OHMM 2.6 20.87 8.90232 2003 9899.5 10900.5 FET MWD040 HOUR 0.53 15.29 1.61044 2003 9899.5 10900.5 First Reading For Entire File........ ..9892.5 Last Reading For Entire File.......... .10945 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... ) ') version Number.......... .1.0.0 Date of Generation...... .03/01/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/01/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File