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Home My WebLink About202-240 1a. Well Status: DOil DGas D Plugged ~ Abandoned D Suspended 1b. Well Class: Mcnorage 2JJAN:. 25.105 2OAAC25.11:Q ~ Development D Exploratory DGINJ DWINJ D WDSPL DWAG D Other No. of Completio~ero D Service D Stratigraphic 2. Operator Name: 5. Date Comp., Susp., o(Aba~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 413012007 7Pl'n1 202-240 ./ 306-398 3. Address: 6. Date Spudded 6'U· 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 0110712003 5O-029-22646-O1~ / 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 0110912003 PBU D-30A ..- 3625' FSL, 1066' FEL, SEC 23, T11N, R13E, UM 8. KB (ft above MSL): 78.25' ' 15. Field I Pool(s): Top of Productive Horizon: / 4992' FSL, 2665' FWL, SEC 24, T11N, R13E, UM Ground (ft MSL): 40.6' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ NO) Pool 4965' FSL, 4450' FWL, SEC 24, T11N, R13E, UM 11260 9044 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+1VD) 16. Property Designation: Surface: x- 654088 y- 5959346 Zone- ASP4 11935 ./ 9042 ADL 028285 TPI: x- 657789 y- 5960791 Zone- ASP4 11. SSSV Depth (MD+ 1VD) 17. Land Use Permit: Total Depth: x- 659574 5960801 Zone- ASP4 NJA N/A y- 18. Directional Survey D Yes ~ No 19. Water depth, if offshore 20. Thickness of Permafrost (NO): (Submit electronic and orinted information œr 20 AAC 25.050\ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): MWD, GR, RES, ROP, Memory GR, CCL 22. CASING, LINER AND CEMENTING REcORD . SErrJNG:DEPTH MD 8EmNG DEPTH 1VD HOlE AMooNr Wr. PER FT. GRADE Top BOTTOU Top BoTTOM SIZE Ca.IErmNG·RECORO PUllED 20" 91.S#- H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set (ADorox.) 10-314" 45.S#- L-80 35' 3456' 35' 3276' 13--112" 1165 sx Permafrost 'E' 498 sx 'G' 7-5/8" 29.7# USSS-95 36' 10405' 36' 9048' 9-718" 553 sx Class 'G' 4-1/2" 12.6# L-80 10234' 10453' 9050' 9047' 6-314" 636 sx Class 'G' 3-112" x 3-3116" x2·71S" 881# ¡ 6.2# 1516# L-80 9944' 11935' 8982' 9042' 3--314" 113 sx Class 'G' 23. Open to production or injection? DYes ~No 24. . TOáJNGREcORO .. :. If Yes, list each interval open SIZE DEPTH SET (MO) PACKER SET eMD) (MD+ TVD of Top & Bottom; Perforation Size and Number): 4-112",12.6#, L-80 9991' 9933' MD 1VD MD NO 25. AcÐ,FRACTt)RE,. CEMENTSooEEiE.ETC. SCANNED JUL 1 'S 2007 DEPTH ItoilŒRVAL eMD) AMoUNT & KIND OF MATERIAl USED 10495' ~et Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: PRODUCTION FOR OIL-Bat: GAS-MCF: WATER-BaL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD ... Flow Tubing Casing Press: CALCULATED OIL -BBL: GAS-MCF: WATER-BaL: OIL GRAVITY-API (CORR): Press. 24-HouR RATE+ 27. CORE DATA Conventional Core(s) Acquired? Dyes ~No Sidewall Core(s) Acquired? Dyes ~No If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summañze lithoJogy and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptîons, core chips, photographs and laboratory analytical results _~.071. None RBDMS 8FL JUll·9 2D07 ..;¡..JJ:()l..\ ..~j i. -. ,..0' ...... tv I''''' ~ . STATE OF AlASKA I ¿'6~ RECE\VED ALASKA OIL AND GAS CONSERVATION COM ISSION JUN 0 5 2007 WELL COMPLETION OR RECOMPLETlON REPORT AND LOG Alaska Oil & Gas Cons, Commission Form 10-407 ReVised 0212007 CoNTINuED ON REvERSE SloE .~~ 6 , 28. GE.PLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): NAME MD NO Permafrost Top Permafrost Base 29. FORMATION TESTS Well Tested? D Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top of Zone 2A (From D-30) 10029' 9014' None Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram Signed Terrie Hubbl Title Technical Assistant Date 0<0/05/07 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. PBU D-30A Well Number Prepared By NamelNumber. Drilling Engineer: Terrie Hubble, 564-4ô28 Pedro Rangel, 564-4ô23 202-240 306-398 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. 1TEM1a: 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. 1TEM4b: TPI (Top of Producing Interval). ITEII 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 pennafrost 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 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed descñption and analytical laboratory information required by 20 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 Digital Wellfile . . Page 1 of 2 Well: D-30 Well Events for SurfaceWell - D-30 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC1 -> D -> D-30 Date Range: 14/Jan/2007 to 27/Apr/2007 Data Source(s): AWGRS Description T/I/0=0+/100/0. Temp=S1. WHPs (post bleed, pre rig). TBGP & OAP unchanged. lAP increased 95 psi since 04/25/07. No integrals. T/I/O = 7.5/140/0. Temp = S/1. Bleed WHPs to 0 psi (pre-CTD). No AL. FLP = 2340 psi. Bled lAP to tank from 140 psi to 0+ psi in 2 hrs. Bled TBGP from 7.5 psi to 0 psi in 30 mins. Post 30 min monitor lAP increased 5 psi to 5 psi. FWHPs = 0/5/0. T/I/0=0/120/300 Load & Kill OA (CTD Prep) Pumped 5 bbls methanol, 146 bbls 9.8 Brine, 5 bbls Methanol, 30 bbls Diesel down OA. Final WHP's=0/120/300 Load fluids for Load & Kill OA T/I/O = 0+/60/220. Temp = S1. WHP's (pre-rig). AL = None. FL = 2420 psi. lAP increased 60 psi, OAP decreased 10 psi overnight. T/I/O = 50/265/230. S1. Bleed WHPs to 0 psi post-pull BPV (pre-CTD). Bleed TBGP & lAP to 0 psi (4 hrs) all gas. Bleed OAP to 100 psi, shut-in for 2 min, OAP increased 100 psi to 200 psi, continue bleed until bleed trailer at max.capacity. Had bleed trailer vac'd out. Continue OA bleed to 100 psi, shut-in bleed, OAP increased 100 psi to 200 psi in 2 min. Approximately 16 bbls of fluid returns total. RDMO. Final WHPs = 0+/0+/230. 04/21/2007 TIO = 40/260/260. Temp = S1. TBG & IA FL (post-pulled BPV). TBG FL @ 990'. IA FL @ 90'. OA FL @ surface. 04/20/2007 PULL BPV/ POST RIG 04/10/2007 T/I/0=2190/350/240. Temp=S1. Bleed WHP's to 0 psi. (Pre-Rig). Flow line pressure @ 2050 psi. TBG, IA & OA FL's near surface. Bled TP from 2190 psi to 0 psi in 5 minutes. Bled lAP from 350 psi to 10 psi in 2 hours 30 minutes. Bled OAP from 240 psi to 140 psi in 2 hours 30 minutes. Sl to check bleed trlr lvI, OAP increased 90 psi to 230 psi in 5 minutes. Sl & rig down job. Need OT Tank to bleed this well. TP increased to 50 psi during IA & OA bleeds. lAP increased 10 psi to 20 psi during OA bleed. Final WHP's= 50/20/230. 03/29/2007 SET BPV / PRE RIG 03/23/2007 Fish Liner Top Packer, Drift for Whipstock. ***Continued from 03/22/07*** TIH with BHA# 2, Latch liner top packer at 9937' CTMD. Pull free after 5 hits from the jars. POOH with fish. Recovered Liner top packer and all elements. MU BHA#3 and RIH to drift with 2.625" OD x 16.86' Dummy Whipstock. Tagged 3-3/16" x 2-7/8" XO at 10506.5" CTMD. No Dbstruction.POOH.RDMO.Leave Well Shut In. Notify Pad Op of well status. ***Job Completed*** 03/22/2007 Fish liner top packer/ drift w/ dummy WS. CTU #9. MIRU. Perform weekly BOP test. MU and RIH with BHA #1(2-1/8" fishing tools) and 4" GS to 9934' ctmd. Latch and unable to jar packer free. TOOH, cut 54' pipe and MU 3-1/8" tools with wt bars and accelerator. **** Continued on 03/23/07**** 03/19/2007 T/I/O = 2225/240/240. MIT 1A to 3500 pSi.(PASSED) Pumped 12 bbls crude to achieve test pressure. Lost 120 psi in the 1st 15 min and 40 psi in the 2nd 15 min, for a total loss of 160 psi in 30 min. Bled bck pressure. MIT OA to 2000 psi FAILED Pumped 118 bbls crude down OA established LLR of 3 bpm at 1100 psi FWHP=2250/400/250 03/19/2007 TIO = 2180/300/240. Temp = S1. No AL. IA & OA FL's pre-M1T's (CTD prep). 1A FL @ 240' (7 bbls). OA FL @ surface. Both IA & OA need a 2" integral flange installed. 03/03/2007 T/1/0=2200/250/300. PPPOT-T (PASS), PPPOT-IC (PASS). CTD prep. FMC New Standard. Casing head: 133/8" x 13 5/8" 5M w/ (1) 2" 5M FMC model 120 OA valve. Tubing head: 13 5/8" 5M x 13 5/8" 5m w/ (2) 2" FMC model 120 IA valves. Tubing head adapter: 13 5/8" 5M x 4" 5M. Tree: Cameron 4" w/ Axelson actuator. PPPOT-T: Sting into test void to check pressure (0 psi). Funtioned LDS, all moved freely with no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressure void to 5000 psi for 30 min test, lost 50 psi in first 15 min, lost 0 psi in second 15 min (PASS). PPPOT-IC: Sting into test void to check pressure (30 psi), bled pressure to 0 psi (gas/ fluid). Functioned LDS, all moved freely with no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 3000 psi for 30 min test, lost 100 psi in first 15 min, lost 0 psi in second 15 min (PASS). 01/15/2007 ***Continued from 01-14-07 WSR*** MIT IA to 3000 psi, PASSED / MIT OA to 2500 psi, FAILED **Well flowing throughout job** (CTD Prep) - IA failed 4 tests on stabilization 01-14- 07, Bleed lAP to 60 psi (Gas), Repressure IA to 3000 psi w/ 26 bbls crude, Start testing, IA lost 60 psi in 15 min, Lost 20 psi in 2nd 15 min, PASS, Bleed lAP, RD lA, RU OA MIT OA to Events Source Well Date AVYGRS D-30A 04/27/2007 AWGRS D-30A 04/25/2007 AWGRS D-30A 04/24/2007 AWGRS D-30A 04/23/2007 A~\f'LGR5 D-30A 04/23/2007 AWGRS D-30A 04/22/2007 AWGRS D-30A 8WGRS D-30B AWGRS D-30A AWGRS D-30A AWGRS D-30A AWGRS D-30A 8WGRS D-30A 8'fILGRS D-30A AWGRS D-30A 8WGBS D-30A http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 6/412007 Digital Wellfile . . Page 2 of 2 2500 psi - Pumped 60 bbls crude down OA to establish LLR of 3 bpm @ 1225 psi (52 bbls used for LLR once pressure stabilized) . Final WHP's= 1400/280/740 A.WGRS D-30A 01/14/2007 T/I/O= 1400/650/360 MIT IA to 3000 psi, INCOMPLETE **Well flowing throughout job** (CTD Prep) Pumped 76 bbls crude down IA to pressure up to 3000 psi., Start testing, Failed 2 tests on stabilization, Attempt to bleed gas cap of lA, Crude returns, Repressured IA to 3000 psi w/ 1.8 bbls crude, Start testing, Failed 2 more tests on stabilization(4 total), Results getting better every test, Suspect gas bubble in lA, Bleed lAP, IA returns switched to gas w/ 21 bbls crude back ***Continued on 01-15-07 WSR*** ~ii;""1 http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 6/4/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/27/2007 Rig Release: 5/12/2007 Rig Number: N1 Spud Date: 12/20/2002 End: 5/12/2007 4/27/2007 13:30 -17:00 3.50 RIGD P PRE Prep rig for turnkey rig move from P2-22 to D-30B, 12.4 miles 17:00 - 00:00 7.00 MOB P PRE Turnkey rig move - At 2100 hrs, Nordic 1 broke down with a blown inside rear tire off driller's side at the front of K pad access road, prepping tire for change out 4/28/2007 00:00 - 09:30 9.50 MOB N RREP PRE Turnkey rig move - Prepping inside rear tire on off driller's side, change out tire with new one 09:30 - 10:30 1.00 MOB N WAIT PRE Wait on Security, 1 hour, Tumkey rig move to D-Pad 10:30 - 20:30 10.00 MOB N WAIT PRE Waiting on Well Site Prep, changed top rams in BOP stack 20:30 . 22:00 1.50 MOB P PRE PJSM for moving over well, Back in over well, spot cutting box. Accept rig at 22:00 hours, 4/28/07 22:00 . 00:00 2.00 BOPSU PRE Greased tree and choke manifold, NU BOP's 4/29/2007 00:00 . 02:30 2.50 BOPSU PRE NU BOPs, change out btm set of rams 02:30 - 08:30 6.00 BOPSU PRE Testing BOP, all rams, valves and lines to 250 psi - 4000 psi, annular preventer 250 psi - 2500psi, choke manifold valve #2 failed, redressed and tested #2 valve, OK, tested rams with 2" and 2 3/8" test joint, hard line to tiger tank OK, Jeff Jones wI AOGCC waived witnessing BOP test. 08:30 - 11:00 2.50 HMAN PRE Re tests to 4000 psi test performed between 06:00 & 08:30 due to conflicting documents. 11 :00 - 12:30 1.50 BOPSU P PRE RU lubricator and Pull BPV.LD BPV and lubricator. 12:30 - 15:00 2.50 STWHIP P WEXIT Fill pits while stabbing stripper and injector. Thread cable thu injector to reel house. Attach grapple to CT. PT & pull coil to injector. Cut off coil connector. 15:00 - 18:30 3.50 STWHIP P WEXIT Coil straightener test. Attempt to straighten pipe with 600, 650, 700,750,900 & 1100 psi No impact. ram has bottomed out. Adjusted ram but still bottoming out. Repin to allow for more cylinder travel. Retest getting reverse bend at 500 psi. Retest 350 psi required to make 3 contact points. Increase pressure to 450 psi. Test Successful pipe deflection approximately 1/16" in 3' run. No pipe damage on any of the samples. Total 93' cut. 18:30 - 19:00 0.50 STWHIP P WEXIT Prep for slack management, RU reverse line to pits 19:00 - 19:30 0.50 STWHIP P WEXIT PJSM on slack management 19:30·20:15 0.75 STWHIP P WEXIT Circ, 5bbls, 1.50bpm, 200 psi, test inner reel valve to 4000 psi, filled CT wI 42 bbls 20:15-21:30 1.25 STWHIP P WEXIT Rev circ for slack management while bring up Baker tools to rig floor 21 :30 - 21 :55 0.42 STWHIP P WEXIT Std Bk Injector, RU hydraulic CT cutter, cut 65' of 2" CT, leaving 8' of e-line hanging, offload cut pieces of CT to pipeshed 21 :55 - 23:00 1.08 STWHIP P WEXIT Installed dipple CTC, pull test to 35k 23:00 - 00:00 1.00 STWHIP P WEXIT Heading up 2" e-coil thru Baker upper quick connect 4/30/2007 00:00 - 00:45 0.75 WHIP P WEXIT Finish heading up 2" e-coil thru Baker upper quick connect, Megger Eline, 2000+ Meg Ohms, 46 Ohms continuity test SLB installed RA tag, 5' from top of whipstock 00:45 - 01 :35 0.83 WHIP N SFAL WEXIT RU nozzle, stab injector, attempt to circ, CT froze up, RIH to thaw out CT to 2337', pump at 1.02bpm, 1050psi 01 :35 - 02:00 0.42 WHIP N SFAL WEXIT POH to BHA, brk out inj and UQC, LD nozzle 02:00 - 02: 1 0 0.17 WHIP P WEXIT Install base plate plug, test CTC to 3500psi 02: 1 0 - 02:30 0.33 WHIP P WEXIT PJSM on handling and running whipstock assy 02:30 - 03:30 1.00 WHIP P WEXIT MU whipstock, packer assy, BHA #1, orient WS to MWD, Stab injector 03:30 - 06:30 3.00 WHIP P WEXIT RIH wI Whipstock/Packer Assy, surface check mwd tools, Up Printed: 5/1412007 10:50:45 AM . . s~ 1)·30ß BPEXPLORATI'ON PagE:} 2 14 Op~"Eltion$.SummaryRèport Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From ~ To Hours Task Code NPT Phase Description of Operations 4/30/2007 03:30 - 06:30 3.00 WHIP P WEXIT wt 34.5k at 9900', Dn wt 18.8k RIH to 10440'. 06:30 - 07:10 0.67 WHIP P WEXIT Log down at 2.4 fpm Tie - in log. Correction -11 ft. Up Wt = 31.8K RIH place top of WS at 10495'. 93R . 07:10 - 07:30 0.33 WHIP P WEXIT Close EDC. Pressure up slowly to 1500 psi. hold for 1 minutes pressure to 2000 psi Shear at 2000 psi. 07:30 - 08:00 0.50 WHIP P WEXIT PU to 10449 and Circulate crude from well. 08:00 - 08:30 0.50 WHIP P WEXIT POH. Turbo Charger FIRE on #2 Cat extinguished by crew. Notify PBU Fire Chief. L Crane & Alan Graft 08:30 - 11 :15 2.75 WHIP P WEXIT POH slow on one motor 11:15 -11:30 0.25 WHIP P WEXIT LD WS running tools. 11 :30 - 00:00 12.50 WHIP N RREP WEXIT Wait on Cat mechanic to evaluate fire damage, Turbo chargers failed on #2 Cat, cause under investigation. Using turbo chargers from motor that had exciter failure, located at Catipillar in Anchorage. Shipping from Anchorage on first flight out on 05/01/2007, Performing general housekeeping, inspecting rig equipment 511/2007 00:00 - 14:30 14.50 WHIP N RREP WEXIT Wait on repair parts for #2 Cat from Anchorage, Turbo chargers failed on #2 Cat, cause under investigation. Performing general housekeeping, inspecting rig equipment 14:30 - 20:30 6.00 WHIP N RREP WEXIT Cat mechanic arrived at rig, installing blower on motor, waiting on turbo chargers to arrive from Anchorage, ETA on slope at 17:30 hours with Alaska Airlines, Performing general housekeeping, inspecting rig equipment 20:30 - 00:00 3.50 WHIP N WEXIT Turbo chargers arrive rig. Changeout turbo charges on Gen Set #2. Function test Gen #2 ESD valves - OK. Meanwhile fill hole with 11 bbls of bio-KCL water. 5/2/2007 00:00 - 00:15 0.25 STWHIP P WEXIT PJSM for P/U & RIH window milling BHA. 00:15 - 01:30 1.25 STWHIP P WEXIT MIU window milling BHA #2 with a 2.74" HC DSM, 2.74" diamond string reamer, Baker straight Xtreme motor, BHI DGS, DPS, EDC, P&C & LaC. MIU injector. 01 :30 - 03:45 2.25 STWHIP P WEXIT RIH with milling BHA #2 pumping @ min rate thru open EDC. Observe BHI VSS (Vibration Stick-Slip) sensors not working. Continue RIH past XN nipple to 10100'. Wt check: Up = 32.7k, down = 15k. 03:45 - 04:00 0.25 STWHIP P WEXIT Log down GR @ 150fph & tie into formation marker. Had +31' correction on BHI depth. Suspect wrong BHI depth tracking - did not correct CTD. Check & found out that wrong BHA length was used for bit to GR sensor calculation. 04:00 - 04:25 0.42 STWHIP P WEXIT RIH with milling BHA #2. Dry tag WS/Lnr pinch pt @ 10493.7'. Close EDC & bring on pumps. Wt check: Up = 30k, down = 17.5k. Retag WS/Lnr pinch pt @ 10493'. Flag pipe & correct both CTD & BHI depth to 10495' (pinch pt CTD). 04:25 - 05:25 1.00 STWHIP P WEXIT Start milling window with 1.7/1.7bpm 3150/3350psi, 1-2k DWOB & 1fph ave ROP. Mill to 10496'. 05:25 - 10:40 5.25 STWHIP P WEXIT Mill window to 10500' with 1.7/1.7bpm 3150/3350psi, 1-2k DWOB & 1fph ave ROP, Drilled 10' of new hole from 10500' - 10510' with 1.6/1.6bpm 3350/3300psi, 2 - 3k DWOB Unconfirmed depths of TOWS 10495', BOWS 10504', RA tag 10500', TOW 10495', BOW 10500' 10:40 - 11:45 1.08 STWHIP P WEXIT Displacing well to Flo-Pro, worked thru window several times, no problems Printed: 5/1412007 10:50:45 AM . ~ ... . . SARAH PALIN, GOVERNOR A.I/A.~1iA. OIL AlVD GAS £ONSBRVATlON £OMJIISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pedro Rangel CT Drilling Engineer BP Exploration (Alaska) Inc P.O. Box 196612 Anchorage, Alaska 99519-6612 ,¡;'"p '<1 I;" -;\CÛ{7 .'i" ~í.~lÀi~r H&,..'-" :k ~p"' '. ':;~.rt.: In-··~ tI Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Well D-30A Sundry Number: 306-398 ;}.Oð-~ ð- \fO Dear Mr. Rangel: 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 field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this1-"ZtGy of December, 2006 Encl. {}.~ ~ '\) ¥ . STATE OF ALASKA ~ J¡, ~ rf ~' \y-?I ALASKA OIL AND GAS CONSERVATION COMM.~N Ir"Þ RECEIVED DEC 1 9 2006 AP~71CAT~ FOR SUNDRY APPROVA~ Alaska Oil & Gas Cons. C-' tTTS /2-.2. ¿/ 20 AAC 25.280 1. Type of Request: ~ Abandon . , 0 Suspend o Operation Shutdown o Perforate o Time ExtensionAnchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 202-240 - 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22646-01-00 7. If perforating, closest approach in pool{s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU D-30A ' Spacing Exception Required? DYes ~No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool{s): ADL 028285 78.25' . Prudhoe Bay Field / Prudhoe Bay Pool i<.; ;<. $;t@'~J_ Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11935 9042 11260 9044 11260 None Casino Lenoth Size MD TVD Burst Collanse Strllctll ral Conductor 110' 20" 110' 110' 1490 470 SurfaC'.P. 3421' 10-3/4" 3456' 3276' 5210 2480 Intermediate 1 0369' 7-5/8" 1 0405' 9048' 8180 5120 Prodlldion Liner 219' 4-1/2" 10234' - 10453' 9050' - 9047' 8430 7500 Liner 1991' 3-1/2" x 3-3/16" x 2-7/8" 9944' - 11935' 8982' - 9042' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10880' - 11875' 9038' - 9041' - 4-1/2", 12.6# L-80 9991' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'S-3' packer I Packers and SSSV MD (ft): 9933' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: January 1, 2007 DOil DGas D Plugged ~ Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pedro Rangel, 564-4623 Printed Name Pedro Rafgel,. Title CT Drilling Engineer '?)A/c/; Prepared By Name/Number: Signature [¡vi /Vv'"'j ~ ~~qJtO (1J\.f\9~l Phone 564-4623 Date Terrie Hubble, 564-4628 , Commission Use Only , Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:~ao" æ ~ ...... D Plug Integrity ~BOP Test D Mechanical Integrity Test D Location Clearance Other: ~GO~\ ~~\~'-.)~·~~~s~( Subsequent Form Required: 40"\ R8DMS 8Ft 2 6 2006 ~MMISSIONER APPROVED BY Date I]" - ~z..,..f) {, Approved By: ....o THE COMMISSION Form 10-403 Revised 0612006 V_~V \ Submit In Duplicate -',..,.,.., , J \ ¡ I " L. \\íN\8\ on . . To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission Pedro f2c..~e..' CTD Engineer December 15,2006 Prep D-30B for CTD sidetrack Obp From: Date: Re: Sundry approval is requested to prepare D-30A for a sidetrack. D-30a kicked out of the 4.5" below the upper two sets of perforations in D-30 and was drilled to TD of 11,935. The cement job appeared to go well, with 22 bbl returns for 23 bbl pumped. However, the well failed the liner lap pressure test, so a liner top packer was run. D-30a was completed with 450' of initial perforations. D-30a went to cycle in several months, and rapidly increased its GOR. High GOR was thought to be the result of possible rractures identified on openhole logs, as a borax survey did not indicate any channels. In June, 2004 a cmp was set above the initial perfs, and perforations added uphole. This resulted in low initial gas rates, confirming completion isolation rrom the parent well. D-30a produced competitively for ~ 6 months. 60' of perforations were added at 8960-61 SS TVD in 2005, within the range of the original perforations. D-30a has been a poor cycle well since then, indicating that the problem with this well is a thin LOC. Currently D-30a is a high gas rate cycle/swing well with very little on-time. Due to the low remaining value ofthis well and the lack of well work options, the wellhas been selected for a through tubing sidetrack. With SLB/Nordic I Coiled Tubing Drilling in on or around ApriI15t1\ 2007. The sidetrack, D-30B, will exit the existing 3-3/16" liner from a whipstock and will target the bottom Z2A sand, Goesteering to remain 5' above HOT. The existing perforations will be isolated by a Cast Iron Bridge Plug and the liner cement job. The following describes work planned and is submitted as an attachment to Fonn 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: 1. 0 MIT -IA, and OA. (Last MIT IA/OA was done on 09/04/06) 2. S Run caliper log (Done on 09/03/06) 3. S Install Dummy valves on all GL mandrels (Done 09/04/06). 4. C Fish liner top packer@ 9,944' 5. C Dummy WS (15' x 2.625") drift to 10,516' 6. C Set cmp @ 10,536' 7. 0 Set BPV 8. 0 AC-LDS; AC-PPPOT-IC, T 9. 0 Test MV, SV, WV 10. 0 Bleed gas lift and production flowlines down to zero and blind flange 11. 0 Remove wellhouse, level pad The pre CTD work is slated to begin on January 01, 2007. ?:OCo-s<;,<6 Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high. \ '0' \ \ 2. Pull BPV ht:.ùJ "'"\ o..\> ~m~~ 3. Set 3-3/16"monobore whipstock @ 10,495'. Reference Log: Liner Top Tie-In Memory GRlCCL 01/10/03 4. Mill 2.74" window at 10,495' and 10' of openhole. Swap the well to Flo-Pro. 5. Drill Build: 3" OH, 322' (45 degl100 planned) 6. Drill Lateral: 3" OH, 1,883' horizontal (12 degll00 planned) - include resistivity . 7. Run 23/8" solid liner leaving TOL at 10,250' 8. Pump primary cement job to TOL, 10 bbl of 15.8 ppg cmt planned 9. Run CO assembly 10. Run MCNL/GRlCCL log 11. Test liner lap to 2000 psi. 12. Perforate 600 ft at the toe. 13. Freeze protect well, Set BPV, RDMO . . Post-Hit! Work 1. Pull BPV 2. Install well house. Hook up flow line. Pedro Rangel CTD Drilling Engineer 564-4623 CC: Well File Sondra Stewman/Terrie Hubble REE,¡: . 4"CW ~OTES: HORIZONTAL & SDTRCKWELL I /VELLHEAD = FMC D-30A '\CTUATOR = AXElSON I\B. ELEV = 78.25' F. ELEV = 40.6' I\OP= 1215' Iftax Angle = )8 @ 10517' I 2215' H4-112" HES HXO SSSV NIP, 10 = 3.813" I Datum MD = 9738' Datum TVD = 8800' SS . GAS LIFT MANDRELS 110-3/4" CSG, 45.5#, L-80, ID = 9.953" I 3466' 1---J ST MD TVO DEV TYPE VLV LA TCH R:>RT DATE 3 3779 3567 25 KBMG-M DOME BK 16 01/18/03 . 7144 6573 26 KBMG-M SO BK 20 01/18103 ~ 1 9812 8921 59 KBMG-M DMY BK 0 12/14102 Minimum ID = 2.372" @ 10616' 2·7/8" LIN ER I 9923' 4-112" HES X NIP, 10 = 3,813"1 ~ .... .... 9933' 7-518" x 4-112" BKR S-3 PKR, 10 = 3.875" I ~ ~ I 9944' H4-112" x 3-112" LNR TOP PKR, 10 = 2,560" I I I 9959' HBAKER LNR OEPLOY SLV W/SEAL LOC., ID = 2.39" 1 ITOP OF CEMENT 1 ~ i~ I 9957' H4-112" HES X NIP, ID = 3.813" (BEHIND CT LNR) I 9960' '= H4-112" HES XN NIP, 10 = 3.725" (BEHINDCT LNR) I 9979' 13-3/16" LNR, 6.2#, L-80, ,0076 bpf, 10 = 2.80" I 9983' J-- -I 9980' H 3-112" HES XN NIP, 10 = 2.750" 1 W'\I I 9982' 3-112" x 3-3/16' BAKER XO, 10 = 2.80" I 14-112" TBG, 12.6#, L-BO, .0152 bpf, 10 = 3.958" 9991' ~ 9991' H4-112" WLEG, 10 = 3.958" I ITOPOF 4-112" LNR 10260' ~ 17-5/8" CSG, 29.7#, USSS-95, 10 = 6.875" I 10405' µ ... I TOP OF WHIPSTOCK I 10453' r- I RA TAG I 10462' 4-1/2" WTHFO KS-WS PKR 10464' r I 10516' -13-3/16" x 2-7/8" XO, 10 = 2.441" I PBTO 13530' 1- 11260' BKR aBP (06106104) 14-112" LNR, 12.6#, L-BO, 10 = 3.953" H 13621' ~~ ~ PERFORATION SUMMARY REF LOG: SWS MEMORY GRlCCL ON 01/10103 ANGLE AT TOP PERF: 88@ 11020' l' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ~ ~ 2" 6 11020 - 11070 0 06/06104 2" 6 10880 - 10910 0 07/11105 1 PBTO H 11902' 1 " .; 2" 6 10920 - 10950 0 07/11/05 ... t- 12-7/8" LNR, 6.16#, L-80-STL, .0058 bpf, ID = 2.372" 11935' 2" 4 11325 -11500 0 01/11103 2" 4 11550 -11750 0 01/11103 2" 4 11800 - 11875 0 01/12/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrr 03/23196 ORlO. HORZ. COMPLETION 06125104 LWB/KAK MA NDREL DEPrH CORRECTIONS WElL: D-30A 01/12/03 JLMITLH CTD SIDETRACK (D-30A) 07/11105 JLGlPJC PERFS PERMrr No: ':1022400 01/18/03 MHlTLH GLV UPDATE API No: 50-029-22646-01 05/18/03 TMNlTLH LINER 10 CORRECTION SEC 23, T11 N, R13E, 3625' NSL & 1066' WEL 09/17/03 CMOITLP PERF ANGLE CORRECTION 06106104 BJMcUKK ADPERFS & SET BKR aBP BP Exploration (Alaska) 4"crN '" FMC '" AX8..50N 78.25' 40.5' 1215' }8 @ 10517' 9738' 8800' 55 & 10-314" e5G, 45.5#, L·80, 10 '" 9923' 9933' PERFORA TION SUMMARY REF LOG: SWS MEMORY GRlCCL ON 01110/03 ANGLEA T TOP PERF: 88@ 11020' Note: Refer to Production DB for historical perf data SPF INTERVAL 6 11020 - 11070 2" 6 10880 - 10910 2" 6 10920 - 10950 2" 4 11325 - 11500 2" 4 11550 - 11750 2" 4 11800 - 11875 11260' e e . ·r······························,- .,'\ ......... ,.,'IJ¡Þ ,4 MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ Marker.doc ') ) RE"" E:".,,,'"' "Iff.:,.."",,, I....'" rii\1'.tI~ ~ M~'t:U\~ I .' 1:~t.rl'1j":,\ OCT 2 6 2005 WELL LOG TRANSMITTALA~aslu'i Oil & GifjS To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: D-30A, AK-MW-30002 D-30A: .I-}- J 3 S)' ( Digital Log Images:...¡..r- ijCANNEu NO\! () 2; 200~ CD Rom 50-029-22646-01 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: . / NOv ~ ~ ~ Signed: iLl (JJi¡ ~ 0 ^- Â'1o F;'t-t... \ STATE OF ALASKA ) AlA~ .A Oil AND GAS CONSERVATION COMMI~SION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 78.25 KB 8. Property Designation: ADl-028285 11. Present Well Condition Summary: Total Depth measured 11935 true vertical 9042.07 Effective Depth measured 11902 true vertical 9041.28 Casing Conductor Liner Liner Production Surface length 80 535 1417 10369 3421 Size 20" 91.5# H-40 3-3/16" 6.2# l-80 2-7/8" 6.16# l-80 7 -5/8 " 29.7 # S-95 10-3/4 " 45.5 # l-80 Perforation depth: Measured depth: 10880 - 10910 True Vertical depth: 9038.05 - 9037.93 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Developm entJ;?': Stratigraphic feet feet feet feet MD 36 - 116 9983 - 10518 10518 - 11935 36 - 10405 35 - 3456 1 0920 - 10950 9038.08 - 9039.67 4-1/2" 12.6# E""'" ("\~ I...... ~ VE' ~Di, 1Øò.... , ."\w.'I'~ \, ',ar.:,I\;II . ~:_ J '.tomIQ'I v::!i=:m AUG 2 4 Z005 Stimulate 0 Other 0 ,,' . WaiverD -Ittr\q~~t~~ª'n~s f.:öi~., Lm1:missmn Re-enter Suspended weltrnhm"sge 5. Permit to Drill Number: Exploratory JJ 202-2400 Service D 6. API Number: 50-029-22646-01-00 9. Well Name and Number: D-30A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) Junk (measured) 11260 None TVD 36 - 116 8997.34 - 9041.14 9041.14 - 9042.07 36 - 9047.92 35 - 3276.41 Burst Collapse 1490 470 13450 13890 8180 5120 11020 - 11070 9044.94 - 9047.6 l-80 32 - 9944 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 o 0 0 15. Well Class after proposed work: Exploratory r Development W 16. Well Status after proposed work: Oil P Gas r WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signature Form 10-404 Revised 04/2004 9933 9944 SCi"NNEL, JJ¡UG 3 Ü 2005 Tubing pressure o o Service c GINJ r WDSPL r WINJr Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr ,'. " : P.hQ.ne ?~-4~24L 'Date 8/17/2005 U~/\\ !¡ A .1LJIY1/1 \ \ 10 ~ I ;"(rn/fJ5 d5 ~IOnIY ) ') D-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I SUMMARY 7/10/2005 MIRU CTU #8... 13,951' of 1.75" I-Coil.... (mother board not working, Will not be able to get data from I Coil while logging). ***** Job Scope: Memory log GR/CCL & Adperf**** MU BHA wI GR/CCL in 2.2" carrier. OAL = 12.96'. RIH. Tag CIBP at 11,266' up wt. Paint flag at 11,050.3' uncorrected. Log up to 10,400'. POOH. -3.0' depth correction. Corrected EOP at flag = 11,036.1'. MU MHA wI 2" guns for 1st 30' perf run. OAL = 40.55'. RIH. Corelate to flag. all indications guns fired. POH Job in progress (continued) 7/11/2005 Continued from 7-10-05 WSR........ Laid down spent perforating guns. Run 1 of 2. PU 30' of SLB 2" guns for 2nd perf run. RIH. Correlate to flag. Pump 1/2" ball to fire guns. POOH. All charges fired. RDMO. Notify DSO to POP well. ****** Job Complete***** FLUIDS PUMPED BBLS 129.1 2% KCL 129.1 TOTAL I ( Fe.-Í;?À Ó 0) DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022400 Well Name/No. PRUDHOE BAY UNIT D-30A Operator BP EXPLORATION (ALASKA) INC 5 VI "l.-cL 7J '" .Lt,~ ?> API No. 50-029-22646-01-00 MD 11935 ./- TVD 9042 Completion Date 1/11/2003"/ Completion Status 1-01l Current Status 1-01L UIC N c __"___ ~_________~___ REQUIRED INFORMATION Mud log No Samples No Directional surveyc~_~~ - - --~-------- - - - --------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ROP, Memory GR, CCl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from logs Portion of Master Well Data Maint) --- Log Log Run Scale Media No Interval Start Stop OH/ CH Received Comments ------ ------- ~--E 0 C 0"1538 Gamma Ray 9692 11884 Case 2n /2003 c./ log Gamma Ray 2 Blu 9692 11884 Case 2n /2003 {sý'Õ Directional Survey 10430 11935 Open 2/5/2003 Rpt Directional Survey 10430 11935 Open 2/5/2003 ~ 0 cA"1694 LIS Verification 9808 11887 Open 4/17/2003 :;fu1t-- - ~Verification 9808 11887 Open 4/17/2003 (Log Production 2 B1uì 1 ~ 9810 11890 Case 6/10/2003 Production Profile - t loJ'-'~ Memory GRlCCUCNUSTP V log Casing collar locator 2 Blu ¡{'J\, 9810 11890 Case 6/10/2003 Production Profile - Memory GRlCCUCNUSTP i-log Neutron 2 Blu .¡ 9810 11890 Case 6/10/2003 Production Profile - '--'"' Memory GRlCCUCNUSTP (ED C Pdf (12429 Rate of Penetration 25 1-2 10473 11935 Open 2/26/2004 ROP, DGR, EWR - I Horizontal Presentation - ! .- MWD \ i ED C Pdf I.' 12429 I nd uction/Resistivity 25 1-2 10473 11935 Open 2/26/2004 ROP, DGR, EWR - \ /\ Horizontal Presentation - J) MWD ED C Lis 12429 Rate of Penetration 1-2 10473 11935 Open 2/26/2004 ROP, DGR, EWR - Horizontal Presentation - MWD ..;;ED C Lis ..j 2429 I nd uction/Resistivity 1-2 10473 11935 Open 2/26/2004 ROP, DGR, EWR - Horizontal Presentation - MWD .----- ----------- Permit to Drill 2022400 MD 11935 TVD 9042 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? = Y / N ... Analysis Received? ~ -- --- -- -- -- ------------- Comments: - ------- - -~------- Compliance Reviewed By: _ DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Well Name/No. PRUDHOE BAY UNIT D-30A Operator BP EXPLORATION (ALASKA) INC Completion Date 1/11/2003 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops I~ Current Status 1-01L Sample Set Number Comments (i)N @/N Date: API No. 50-029-22646-01-00 UIC N -- q VVU, M'\\ ~-- ---- -) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Rf.cE..'VED REPORT OF SUNDRY WELL OPERATIO~ 2 1. Operations Performed: 7 2004 Abandon 0 Repair WellD PluQ Perforations[K] Stimulate E. k O. O.1/1e~ . . as a II & lias OS. Commission Alter Casing D Pull Tubing D Perforate New Pool D Waiver Time Extel']ß.io HOC age Change Approved ProgramD Operation Shutdown 0 Perforate [K] Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: ) 5. Permit to Drill Number: 202-2400 BP Exploration (Alaska), Inc. Development 00 ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 78.25 8. Property Designation: ADL-0028285 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: D-30A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-22646-01-00 Total Depth measured 11935 feet true vertical 9042.1 feet Effective Depth measured 11260 feet true vertical 9044.1 feet Plugs (measured) Junk (measured) 11260 None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 36 116 36.0 - 116.0 1490 470 Liner 39 3-1/2" 9.3# L-80 9944 - 9983 8982.1 - 8997.3 10160 10530 Liner 535 3-3/16" 6.2# L-80 9983 - 10518 8997.3 - 9041.1 Liner 219 4-1/2" 12.6# L-80 10234 - 10453 9049.8 - 9046.5 8430 7500 Liner 1417 2-7/8" 6.16# L-80 10518 - 11935 9041.1 - 9042.1 13450 13890 Production 10369 7-5/8" 29.7# S-95 36 - 10405 36.0 - 9047.9 8180 5120 Surface 3421 10-3/4" 45.5# L-80 35 - 3456 35.0 - 3276.4 5210 2480 Perforation depth: Measured depth: 11020 - 11070 True vertical depth: 9044.94 - 9047.6 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 32 9947 4-1/2" 12.6# 13Cr80 @ 9947 9991 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 9933 4-1/2" Liner Top Packer @ 10234 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: , BFl .RBf)MS ÞlJ6 3,:0 . 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1276 394 Representative Daily Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 43 198 1400 8.9 54 1139 Tubing Pressure 1300 179 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations, ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil 00 GasD Development ŒJ Service D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature E~ C~~. Form 10-404 Reviseg 4/2004 WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 8/18/04 ( J R , (~ , ~, A f._ -) ) D-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/05/04 CTU #5, CIBP/ADDPERF; MIRU DS CTU #5. RIH WITH PDS MEMORY GR/CCL. CONT' ON WSR 6/06/04... 06/06/04 CTU #5, CIBP/ADD PERF; CONT' FROM WSR 6/05/04... RIH WITH PDS MEMORY GR/CCL. LOG FROM 11350' UP TO 108501 CTMD. FLAG PIPE AT 111001 CTMD. POOH. RIH WITH BAKER 2 7/8" CIBP. SET CIBP @ 112601 MD. POOH. RIH WI 25 FT OF 2" 6 SPF 2006 PJ GUNS AND SHOOT @ 11,0451 TO 11,0701 MD. POOH. RIH WI 25 FT OF 2" 6 SPF 2006 PJ GUNS AND SHOOT @ 11,0201 TO 11,0451 MD. POOH AND FREEZE PROTECT WELL. WELL LEFT SHUT IN. PAD OPERATOR TO KICK OFF WI POOR BOY GAS LIFT NEXT MORNING. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 267 1 % KCL 45 50/50 Methanal 312 TOTAL Page 1 ) TREE = WELLHEA D = ACTUA. TOR = i<B. 8... EV = BF. 8...EV = KOP= rv'Iax Angle = ï5ãtÚiïï Wö'~ DatLimiVb = 4"CIW FIVe AXELSON 78.25' 40.6' 1215' 98@10517' ....... 'giàäi 8aOÖ' sS' 110-3/4" CSG, 45.5#, L-80, ID = 9.953" 1-1 3456' ~ Minimum ID = 2.372" @ 10516' 2-7/8" LINER 1 TOP OF CEMENT l-i 9960' 1 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" l-i 9983' 14-1/2"TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 1--1 9991' 1 TOP OF 4-1/2" LNR 1-1 10260' 1 17 -518" CSG, 29.7#, USSS-95, ID = 6.875" 1--1 10405' 1 TOP OF WHPSTOO< - 10453' 1 RA TAG - 10462' 4-112" WTHFD KS-WS PKR l-i 10464' 1 R3ID l-i 13530' 1 4-1/2" LNR, 12.6#, L-80, ID = 3.953" 1-1 13621' PERFORATION SUMMARY REF LOG: SWS MBv10RY GRlCCL ON 01/1 0/03 ANGLE AT TOP ÆRF: 88 @ 11020' Note: Refer to Production DB for historcal perf data SIZE SPF INTER\! AL OpnlSqz DA TE 2" 6 11020 - 11070 0 06/06/04 2" 4 11325-11500 0 01/11/03 2" 4 11550 - 11750 0 01/11/03 2" 4 11800-11875 0 01/12/03 ) D-30A SAFETY NOTES: HORIZONTAL & SCTRCK WELL . 2215' 1-14-1/2" HES HXOSSSV NIP, ID= 3.813" L ~ GAS LIFT MANDRELS ST MD TVD DEV TY Æ VL V LA TŒi PORr DATE 3 3779 3567 25 KBMG-M DOME BK 16 01/18/03 2 7144 6573 26 KBMG-M SO BK 20 01/18/03 1 9812 8921 59 KBMG-M DMY BK 0 12/14/02 g 1 9923' H4-1/2" HES X NIP, ID = 3.813" I &---i 9933' 1-17-5/8" X 4-112" BKRS-3 PKR, [) = 3.875" 1 , II . 1 9944' 1-14-1/2" X 3-112" LNRTOP PKR, ID = 2.560" 1 1---1 9959' 1-1 BAKER LNR DEPLOY SLV W/SEAL LOC., ID =2.39" 1 1 9957' 1-14-1/2" HES X NIp, ID= 3.813" (BEHIND CT LNR) 1 ;:, 1 9979' H 4-1/2" HES XN NIP, [) = 3.725" (BB-JIND CT LNR) 1 N 9980' Ilj 3-1/2" HES XN NIP, [) = 2.750" 1 I 9982' ,3-1/2"X 3-3/16'BAKERXO, ID= 2.80" 9991' 1-14-1/2"WLEG, ID= 3.958" 1 ~. ~~ ~~ 10516' 1-13-3/16" X 2-7/8" XO, ID = 2.441" 1 1 PBTD H 11902' i 12-7/8" LNR 6.16#, L-80-STL, .0058 bpf, ID = 2.372" H 11935' r--- DA TE REV BY COMI\.£NTS I 06/25/04 LWBlKAK tv1A NDR8... ŒPTH CORRECTIONS OA. TE REV BY COMI\.£NTS 03123196 ORlG. HORZ. COM PLEfION 01/12/03 J LM /TU CTD SlDEfRAC K (D-30A) 01/18103 MHIlLH GLV LPDA TE 05/18103 TIV1NIlLH LINER ID CORRECTION 09/17/03 Crv1O/1LP PERF A NGLE CORRECTION 06106/04 BJMcUKI< A [PERFS & SET BKR aBP PRUDI-K)E BAY U'JIT WELL: D-30A PERMT f\b: 2022400 API f\b: 50-029-22646-01 SEC 23, T11 N, R13E, 3625' NSL & 1066' W8... EP Exploration (Alask a) 12/18/03 Schlumbergel' NO. 3079 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Midnight Sun Prudhoe Bay Endicott Well Job# Log Description Date BL Sepia CD .3-25B/L-27 ~ ..3-C~ \ 10563054 SBHP SURVEY 04/30/03 1 A-23 ~~-O~LI 10687642 RST/GRA VEL PACK 09/07/03 1 E-102 &.' ,\ ... 1 ~ Co 10708040 SBHP SURVEY 12/1 0/03 1 F-15 ')31-) ~ 10684302 DDL 08/29/03 1 D-30A ~C'.~-02 1- 0 10563448 MCNUSIGMA OS/20/03 1 1 /í9Ll'5to /~"'"'" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. =~g~~::~~ ~I~~ Center LR2-1 RECEIVED Anchorage AK 99508-4254 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth . . \....... . 9 f\!\" 1 1- -. .." '! II L : .~:-':-,:,..: f. i-l..:v, Received ~() ~,,~~.~,,~ Date Delivered: .-<E'~V>.i ,~;¡! !~ das (Œi~:, CiJmm~~ ~ þf?t;-Jra~~q ..,~~~ f\."I. Ç::. ) ) dOD -- ûLIO WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3 33 West 7th Avenue, Suite 100 J\nchorage,Alaska99501 February 23,2004 RE: MWD Formation Evaluation Logs: D-30A, AK-MW-30002 D-30A: Digital Log Images: 50-029-22646-01 1 CD Rom J()L/8 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED Sign~~L,,^-~'" ~ F:~8 2 62004 ,'~~Bska Œt & Gas Cons. Commission AnMorage ~~~\'\\~ " f)lf9- & L{() ids C!l II, ) WELL LOG TRANSMITTAL ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print( s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska),lnc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 K-20B 12-09-03 Res. Eva!. CH 1 1 1 Â~<- 3f:f- Mech. CH 1 Caliper Survey Signed: ~ \ ~ J...~ ,Q <Ñ-~/'v\. Date: RECEIVED Print Name: ,~ · I 2 (\ "'IQO 4 ,.~;.. ; L. 4- "'. ,. j ,~aska Oil & Gas Cons. Commlskm AndMøge PRoAcTivE DiAGNOSTic SERViCE~, INC., PO Box 1 ~b9 STAHol{d TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~~\,~ Schlumbel'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well vi^J~9AL1 ~Œ2-d. ~5 v-P2-57 A I)..()~ -co.., Ic\ D.S.12-20 \ ?f0l-\~ D.S.15-21A t~q-O" - B-04 1 7-f'2.. -0 -.., oJ YF-10A ()-C!::ð -- d to . t "Ð"-~OA~æ- -~. ~<"? )tÕj28 "- \(?..l::) vK-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 99508 Date Delivered: o / /.0 -- C)~ 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 Date Blueline Prints CD 03/06/03 1 1- laO/~ 03/15/03 1 1 /d() II() 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 -. -. .- -y -- ~ - - . ~. ~_ :C:~ ~C; ;:: ~'\l E L JUì\l ;:~2::--:2 7,._"~ '-~~ ~ ~-\ ('- ~ yO . p. - ~~... . . --~ '."'-'.~..~~..._-;,--... .~~ - - ~~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~ ~ r! .r¿¿4 - I;í~' .... Received bY<-"''' f' jJ( (}¡ø~ Schlumbel'ger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job# Log Description ~O(\· ~~W-19AL1 ~ J1jd-,. ~~ P2-57 A," ."-.) i Jf). '- q \ D.S. 12-20 --.j i qq. 02~ D.S.15-21A·-.J 1 D . () 32 8-04 .--J i).Ùlì. 0 (':1 F-10A _ '"---.j :.?- C1 ¿,1\ . :;;\\.10 0 -30A "-l r.u?-.. í ó ') 0-228 .-J j t.? . ¡ 2.1 K-01 .--.......1 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 99508 Date Delivered: 0/IO~()-'3 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 8ay Color Date Blueline Prints CD 03/06/03 1 1 03/15103 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 ATINo B~~.lf / It, (/' Î¡,(; Received ~ I!..r '---. ll(L.j' !" v ...r1..,-3 \ ) ) TREE = WELLHEA 0 = AcrUATO R'; . 'kB:"ËLï3/= BF. 8..EV = KOP= Max Angle = DatÙrÖÏVD = DatumTVO = 4"CW FMC ·····ÁXElSŒ.j' ... .. 7iL2Si 40.6' 1215' 98 @ 10517' 9738' '8800'SS D-30A I SAÆTY NOTES : HORIZONTAL & SDTRCK WELL e·"ili'H9'.¡" ·',.,...l#-,¡ ,~!:r~~¡, 2215' 1-14-1/2" HES HXO SSSV NIP, ID = 3.813" 110-3/4" CSG, 45.5#, L-80, ID= 9.953" 1-1 3456' ~ ~ GAS LIFT MANDRELS ST rvo TVD DEV TYÆ VLV LA To-I PORr DATE 3 3779 3489 25 KBMG-M Dürv1E BK 16 01/18/03 2 7144 6495 26 KBMG-M SO BK 20 01/18/03 1 9812 8843 59 KBMG-M IJrv1Y BK 0 12/14/02 L Minimum ID = 2.372" @ 10516' 2-7/8" LINER ".".:;. .. . 1 9923' 1-i4-1/2"HESXNIP,ID=3.813" 1 &----f 9933' 1-17-5/8" x 4-1/2" BKRS-3 PKR, 0 = 3.875" I I:' I 9944' H 4-1/2" X 3-1 Q. LNR TOP P\<R, ID · 2.560" I Î 9959' 1-1 BAKER LNR DEPLOY SLY W/SEAL LOC., ID = 2.39" 1 9957' 1-14-1/2" HES X NIP, ID= 3.813" (BEHNDCTLNR) 1 9979' 1-i4-1/2" HES XN NIP, D = 3.725" (BB-iIND cr LNR) I 9980' 1-13-1/2" HES XN NIP, D = 2.750" I 9982' 1-13-1/2" X 3-3/16' BAKERXO, ID = 2.80" I 9991' 1-14-1/2" WLEG, ID = 3.958" I ~ )00.. z PffiFORATION SUIVfv1ARY REF LOG: SWS M8v10RY GR/CCL ON 01/1 0/03 A f\JGLE AT TOP ÆRF: 91 @ 10325' Note: Refer to Production DB for historbal perf data SIZ E SPF INTER\! AL Opn/Sqz DA TE 2 4 11325-11500 0 01/11/03 2 4 11550-11750 0 01/11/03 2 4 11800-11875 0 01/12/03 I PBTD 1-1 11902' ¡ l2-7/8" LNR, 6.16#, L-80-STL, .0058 bpf, ID = 2.372" Ii. 11935' ITOPOFCEI'vENT 1-1 9960' 13-3/16" LNR, 6.2#, L-80, .0099 bpf, ID = 3.190" 1--1 9983' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9991' 1 TOP OF 4-1/2" LNR 1-1 10260' I 17-5/8" CSG, 29.7#, USSS-95, ID = 6.875" l-i 10405' ~ 1 TOP OF WHPSTOO< - 10453' I RA TAG - 10462' 4-1/2"WTHFDKS-WSPKR 1--1 10464' l 10516' 1-13-3/16" X 2-7/8" XO, 0=2.441" 1 1 PB1D 1-1 13530' 14-1/2" LNR, 12.6#, L-80, ID = 3.953" l-i 13621' DA lE RBI BY COM\llENTS 03/23/96 ORlG. t-DRZ. COrvPLETION 01/12/03 JLM/lLH CTD SoETRACK (D-30A) 01/18/03 tv1-iIth GLV lPDATE DA TE REV BY CO M\IIS\JTS FRUDHOE BA Y um W8..L: D-30A ÆRI'v1IT No: 2022400 API No: 50-029-22646-01 sæ 23, T11 N, R13E, 3625' NSL & 1066' WEL 8P Exploration (Alaska) ') ~ } ðOêY-dlJO I / &/1'-1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska April 08, 2003 RE: MWD Formation Evaluation Logs D-30A, AK-MW-30002 1 LDWG formatted Disc with verification listing. API#: 50-029-22646-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Semces Attn: Rob Kalish 6900 Arctic Blvd. i\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed:cyý~~ RECEIVED APR 1 7 2003 Alaska ütl & Gas Cons. Commission Anchorage 1. Status of Well 181 Oil 0 Gas 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3625' NSL, 1066' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 4992' NSL, 2665' EWL, SEC. 24, T11 N, R13E, UM At total depth 4965' NSL, 4450' EWL, SEC. 24, T11 N, R13E, UM X = 659574, Y = 5960801 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.25 ADL 028285 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 1/7/2003 II 1/9/2003'" 1/11/2003; 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11935 9042 FT 11902 9041 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, ROP, Memory GR, CCL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~.:~ ~LOCA!4OM$~ o Suspended 0 Abandoned ~~~;~~~~~! 7~1::::~::::~~eNice Well ~ .. -. ~...'. ¡., '".~I\} ~ ¡ n e r': ; 202-240 t ";.{" J.. I" \ .1:.~L.:._e3¡ ~ ¿VtP!FŒD ; ¿ ..-.-. i1) .___.... ;;. ~.,"'". ".,,',.~...~,~..,",..~ 9. X = 654088, Y = 5959346 ) ) 8. API Number 50- 029-22646-01 Unit or Lease Name Prudhoe Bay Unit X = 657789, Y = 5960791 10. Well Number D·30A 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) .2215' MD 1900' (Ap~rox.) -y/ ¿O ~~4<J /0/ t-/5:D Þ-z~ 7; ðt/7 .. TV'/~ 23. CASING SIZE 20" 10-3/4" 7-5/8" 4-1/2" WT. PER FT. 91.5# 45.5# 29.7# 12.6# 8.81# / 6.2# / 6.16# GRADE H-40 L-80 USSS-95 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 30" 35'35' 3456' 13-3/12" 36' 10405' 9-7/8" 10234' 10453' 6-3/4" 9944' 11935' 3-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1165 sx Permafrost 'E', 498 sx 'G' 553 sx Class 'G' 636 sx Class 'G' 113 sx Class 'G' AMOUNT PUllED 3-1/2" X 3-3/16" x 2-7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 11325' - 11500' 9041' - 9038' 11550' - 11750' 9038' - 9040' 11800' - 11875' 9040' - 9041' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9991' PACKER SET (MD) 9933' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with MeoH 27. Date First Production January 25, 2003 Date of Test Hours Tested 2/08/2003 4 Flow Tubing Casing Pressure Press. 377 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl TEST PERIOD 1,815 Oll-BBl CALCULATED 24-HoUR RATE GAs-McF 41 ,399 GAs-McF WATER-BBl 390 WATER-BBl CHOKE SIZE 96° Oil GRAVITY-API (CORR) GAS-Oil RATIO 22,806 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. GJ; Form 10-407 Rev. 07-01-80 "QOMS 8FL M~R . 4 2003 Submit In Duplicate ') ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. There were no new Markers. This well was kicked off and drilled in Zone 2A. I know you will be asking about D-30A tops fairly soon. The KOP for this sidetrack was in the horizontal so we have no knew tops. The entire sidetrack was drilled and completed in Zone 2A. 'Top of Zone 2A (0-30) 10029' 9014' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fOr,Oin? is true and correct to the best of my knowledge Signed Terrie Hubble /fd ~ ~ Title Technical Assistant Date Da· ¿;t ( - O'-~ D-30A 202-240 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Thomas McCarty, 223-7156 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, ir Ijection 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. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Page 1 of 7 Operations Summary Rep.ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-30 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To H oLi rs Task Code NPT Phase 1/6/2003 00:00 - 00:20 0.33 MOB P PRE 00:20 - 01 :45 1.42 MOB P PRE 01 :45 - 03:45 2.00 MOB P PRE 03:45 - 05:00 1.25 MOB P PRE 05:00 - 08:00 3.00 BOPSURP PRE 08:00 - 15:30 7.50 BOPSURP PRE 15:30 - 15:45 0.25 BOPSURP PRE 15:45 - 16:20 0.58 BOPSUR P PRE 16:20 - 20:00 3.67 BOPSUR N SFAL PRE 20:00 - 22:00 2.00 STWHIP P WEXIT 22:00 - 22:35 0.58 STWHIP P WEXIT 22:35 - 00:00 1.42 STWHIP P WEXIT 1/7/2003 00:00 - 00:20 0.33 STWHIP P WEXIT 00:20 - 01 :00 0.67 STWHIP P WEXIT 01 :00 - 01 :25 0.42 STWHIP P WEXIT 01 :25 - 01 :45 0.33 STWHIP P WEXIT 01 :45 - 02:30 0.75 STWHIP P WEXIT 02:30 - 03:45 1.25 STWHIP P WEXIT 03:45 - 04:20 0.58 STWHIP P WEXIT 04:20 - 04:45 0.42 STWHIP P WEXIT 04:45 - 05:30 0.75 STWHIP P WEXIT 05:30 - 06:00 0.50 STWHIP P WEXIT 06:00 - 06:30 0.50 STWHIP P WEXIT 06:30 - 07:00 0.50 STWHIP P WEXIT Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Description of Operations Fin move across G Pad Enter K Pad access and head to twin towers. Then onto Spine and down 0 Pad access Arrive on 0 Pad and spot rig in front of well. Scope out derrick and secure guy wires. Meanwhile, RU Little Red to tree cap. Pump 300 bbls 2% KCI to liquid pack before moving over tree. FIP 4.9 bpm @ 950 psi. RD MO Little Red/Peak. FLP=O Lay herculite under sub. NO tree cap. Move rig over tree and set down Accept rig for operations at 0500 hrs NU BOPE Spot Cutting box and tiger tank, begin pressure test of BOP stack. PT witness waived by State of Alaska, AOGCC, Jeff Jones. All items passed, no failures. Pick up lubricator and equipment to pull BPV. Pre spud meeting. Discuss well configuration, GaR, BPV set, open perfs, MITOA failed, Mud requirements, Tripple flowline, Plan forward, hazards and mitigation. BPV pulling proceedure, no hot work, possible high pressure on well, PT lubricator prior to pulling BPV, pinch points, overhead loads, lifting hazards and mitigation. Try to pull BPV. Found ice in tree (-24F, -75CF ambient). Thaw tree with steam hose. Put heater in cellar. Determine well on vac. Pump 20 bbls KCI thru kill line. Pull BPV-find hydril rubber in latch. RDMO DSM. IA -2, OA 270 Replace packoff. Cut off 87' CT. Install WII CTC, PT 32k. Load dart and fill CT w/ KCI w/ biozan. Dart hit at 57.7 bbls. PT CTC 3500 psi, inner reel valve 3500 psi MU milling BHA (3.80" window mill w/ 3.80" dia SR) RIH w/ BHA #1 pumping down CT to fill hole at 1.5 bpm. Got returns after 117 bbls pumped and at 8500' Continue RIH w/ milling assy 9900' 46k, 20.5k PUH slow from 9900' and circ (1.5/500) out gas to determine loss rate and while wo additional fluids Returns cleaned up-looks like 1.5/0.8 @ 580 psi. RIH from 9600' to mill window-did not see XN Tag WS at 10474' CTD at min rate. PUH 46k, start pump 2.6/1.8/1500. Ease in hole and first motor work at 10473.3'. Corr -38.3' (muse, muse) to 10435.0' and flag CT Begin milling window from 10434.8' 2.6/2.0/1500. Got some crude back at btms up and dump returns. About out of KCI anyway, so swap to mud. Pump #2 started leaking. Swap to pump #1 Resume milling from 10435.0'. After mud exited mill returns healed to 2.5/2.2/2450, but started slowly losing more as mud filled annulus 10435.9' Mud back to surface 38.8k, 17.6k 2.6/1.6/2850 FS 10436.4' Returns getting better 38k, 18k 2.6/2.0/3060 FS 10436.8' And better 36.1 k, 18.4k 2.6/2.2/3150 FS 10438.0' 36k, 18k, 2.5/2.0/3150 FS 10439.0' 36k, 18k 2.5/2.2/2870 FS 10440', Drilling break. Possibly exited window. Rap 25 fph. Free spin 2850 psi at 2.6 bpm. 2.6/2.4/3025, Pit vol 149 bbls. Printed: 1/14/2003 2:52:16 PM ) ) BPEXPLORA TION Page 2 of 7 Operations Summary Report Legal Well Name: CQmmon Well Name: Event Name: Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/7/2003 06:30 - 07:00 0.50 STWHIP P WEXIT More mud on the way. ROP 45 fph. Drilling rathole. 07:00 - 07:30 0.50 STWHIP P WEXIT 10455', Ream window. No motor work observed up or down thru widow while reaming. Dry drift window. No weight bobbles up or down thru window. Dry tag bottom. Still at 10455'. Good firm tag. 07:30 - 08:55 1.42 STWHIP P WEXIT 10455', POOH with the milling BHA. Pumping new mud as we POH to fill pits. Geo reports significant amounts of formation sand in last sample prior to POH. 08:55 - 09:30 0.58 STWHIP P WEXIT Tag up at surface. Lay down milling BHA. Window mill in gauge at 3.80" and has swirl pattern on face indicating window exit. String mill in gauge at 3.80", and looks in great shape. 09:30 - 10:45 1.25 DRILL P PROD1 Make up first drilling BHA to drill turn section. BHA #2 = 2.57 deg BHI mud motor, Smith M-09 bit, Sperry MWD, SWS MHA. Cut off WF CTC, make up SWS CTC. Pull test CTC to 35 klbs. Pressure test CTC to 3500 psi. 10:45 - 12:35 1.83 DRILL P PROD1 RIH with BHA #2. Shallow hole test pass ok. RIH. 12:35 - 14:40 2.08 DRILL P PROD1 Log time in pass over gamma character at 9900'. Use Geo's PDC log to tie in. Make -18' correction. Note - Correction on milling run to pinch point on whipstock was -38'. This tie in is 20' different. Expect window depths to shift by 20'. 14:40 -15:05 0.42 DRILL P PROD1 RIH with pumps down. Saw weight bobble at 10455', probable top of whipstock corrected to PDC log depth (It was 10435' based on wells group setting depth). Tag bottom at 10474'. PU, kick pumps on to 2.5 bpm. Free spin pressure=3150 psi. Pit volume=274 bbls. Orient to 60R. IAP=180 psi, OAP=320 psi. RA Pip tag @ 10462'. TOW = 10453' & BOW = 10458'. 15:05 - 15:45 0.67 DRILL P PROD1 Start drilling turn section. Drill to 10500' with 50R TF, 2.6/2.6bpm, 3440/3500psi, 40fph ave ROP. 15:45 - 16:00 0.25 DRILL P PROD1 Orient 1 click & drill to 10509' with 60R TF, 2.6/2.6bpm, 3440/3550psi, 36fph ave ROP. 16:00 - 16:10 0.17 DRILL P PROD1 Orient 1 click & drill to 10515' with 90R TF, 2.6/2.6bpm, 3440/3550psi, 36fph ave ROP. 16:10 -16:30 0.33 DRILL P PROD1 Orient 1 click & drill to 10530' with 1 OOR TF, 2.6/2.6bpm, 3440/3750psi, 45fph ave ROP. 16:30 - 16:45 0.25 DRILL P PROD1 Orient 1 click & drill to 10540' with 1 06R TF, 2.6/2.6bpm, 3440/3600psi, 40fph ave ROP. 16:45 - 17:30 0.75 DRILL P PROD1 Drill to 10590' with 130-160R TF, 2.6/2.6bpm, 3440/3600psi, 70fph ave ROP. 17:30 - 18:30 1.00 DRILL P PROD1 Orient TF to 90R. Pulled up to window. TF flop. Re-orient TF to 90R 18:30 - 19:30 1.00 DRILL P PROD1 Drilling with 90R TF, 2.6/2.6bpm, 3450/3600psi. 100 fph, Drilled to 10620'. 19:30 - 20:20 0.83 DRILL P PROD1 Pulled up to window, Orient TF to 90R. 20:20 - 22:00 1.67 DRILL P PROD1 Drilling with 90R TF, 2.6/2.6 bpm, 3300/3900 psi. 100 fph, Incl = 91.5 deg. Drilled to 10,700'. 22:00 - 23:20 1.33 DRILL P PROD1 Drilling with 90R TF, 2.6/2.6 bpm, 3300/3900 psi. 90 fph, Incl = 91.9 deg. Drilled to 10,760'. 23:20 - 00:00 0.67 DRILL P PROD1 POH for MWD Resistivity Lateral BHA. 1/8/2003 00:00 - 01:15 1.25 DRILL P PROD1 POH with turn BHA. 01:15-02:00 0.75 DRILL P PROD1 UO bit, motor and MWD. bit graded at 0-3-1. Adjust motor to 1.37 deg. 02:00 - 02:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA M/U. Review well plan with new crew. Printed: 1/14/2003 2:52:16 PM ) ) Bp·EXPLORATION Page 3·of7 Ope.rationsSu mmaryRèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-30 0-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From~To Hours Task Code NPT Phase Description of Operations 1/8/2003 02:15 - 03:40 1.42 DRILL P PROD1 M/U Bit #3, HYC, DS49, M/U 1.37 deg motor. M/U MWD RES and surface test tool. 03:40 - 05:30 1.83 DRILL P PROD1 RIH with BHA #3, MWD RES Lateral BHA, DS49 bit, new and 1.37 deg motor. Shallow test tools. OK. RIH. 05:30 - 05:45 0.25 DRILL P PROD1 Log tie-in with GR at RA tag at 10,462 ft. [-20 ft CTD]. 05:45 - 06:00 0.25 DRILL P PROD1 RIH to TO of 10,758'. 06:00 - 06:10 0.17 DRILL P PROD1 Orient TF to 80L. 06: 1 0 - 06:20 0.17 DRILL P PROD1 Drilling Lateral with Resistivity. 2.7/2.7 bpm, 3100/3600 psi, 80L TF, 160 FPH, Full returns. Drill to 10782'. 06:20 - 06:35 0.25 DRILL P PROD1 Drill to 10826' with 80L TF, 2.5/2.5bpm, 3000/3400psi, 155fph ave Rap. 06:35 - 07:00 0.42 DRILL P PROD1 Drill to 10860' with 77-80L TF, 2.57/2.5bpm, 3000/3400psi, 89fph ave ROP. 07:00 - 07:20 0.33 DRILL P PROD1 Wiper trip to window. Saw slight motor work @ 10750' (end of 2.57 motor run). RBIH clean to btm. 07:20 - 07:35 0.25 DRILL P PROD1 Orient TF to 80R. 07:35 - 07:45 0.17 DRILL P PROD1 Drill to 10873' with 80-90R TF, 2.6/2.6bpm, 3100/3350psi, 156fph ave ROP. 07:45 - 07:55 0.17 DRILL P PROD1 Drill to 10891' with 90-100R TF, 2.6/2.6bpm, 3100/3350psi, 90-120fph ave Rap. 07:55 - 08:20 0.42 DRILL P PROD1 Drill to 10918' with 11 0-120R TF, 2.6/2.6bpm, 3100/3350psi, 60fph ave ROP. Trajectory is 4.9ftvd higher than planned. Aiming to land into plan @ polygon entrance. 08:20 - 08:30 0.17 DRILL P PROD1 Orient TF to LS. 08:30 - 08:45 0.25 DRILL P PROD1 Drill to 10935' with 150R TF, 2.6/2.6bpm, 3100/3350psi, 120fph ave ROP. 08:45 - 09:00 0.25 DRILL P PROD1 Orient & drill to 10971' with 1 05L TF, 2.6/2.6bpm, 3100/3350psi, 120fph ave ROP. 09:00 - 09:25 0.42 DRILL P PROD1 Orient & drill to 11008' with 80-90L TF, 2.6/2.6bpm, 3100/3350psi, 88fph ave ROP. Enter polygon as planned @ 1 0980'. 09:25 - 10:30 1.08 DRILL P PROD1 Wiper trip clean up to 9700' (50 degs inclination). RBIH clean to btm. Saw slight bobble @ 10455' (window). 10:30 - 10:35 0.08 DRILL P PROD1 Drill to 11021' with 20L TF, 2.6/2.6bpm, 3100/3400psi, 97fph ave ROP. 10:35 - 11 :00 0.42 DRILL P PROD1 Orient TF to 70-80L. 11 :00 - 11 :20 0.33 DRILL P PROD1 Drill to 11047' with 70-90L TF, 2.6/2.6bpm, 3100/3400psi, 87fph ave ROP. 11 :20 - 11:45 0.42 DRILL P PROD1 Orient & drill to 11064' with 70-80L TF, 2.6/2.6bpm, 3100/3400psi, 38fph ave Rap. Seeing 100degs reactive & erratic TF. Inclination = 86degs & trajectory is 4ftvd below plan. No tar in samples. To aim up to plan. 11 :45 - 12:20 0.58 DRILL P PROD1 Orient & drill to 11098' with 60-70L TF, 2.6/2.6bpm, 3100/3400psi, 55fph ave Rap. TF staying steady but angle is still holding @ 86degs. 12:20 - 12:40 0.33 DRILL P PROD1 Orient & drill to 11114' with 60L TF, 2.6/2.6bpm, 3100/3400psi, 58fph ave ROP. Trajectory is 6ftvd below plan. Saw slight tar in 11100' samples. 12:40 - 12:45 0.08 DRILL P PROD1 Orient TF to HS. 12:45 - 13:00 0.25 DRILL P PROD1 Drill to 11151' with 30-40L TF, 2.6/2.6bpm, 3100/3500psi, 148fph ave ROP. Inclination up to 92 degs. 13:00 - 13:30 0.50 DRILL P PROD1 Wiper trip clean to window. Printed: 1/14/2003 2:52:16 PM ) ) BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From - To Hours Task· Code NPT Phase Description of Operations 1/8/2003 13:30 - 13:45 0.25 DRILL N DFAL PROD1 Attempt to tie-in - unable to toggle MWD tool. 13:45 - 14:05 0.33 DRILL P PROD1 RBIH clean to btm. 14:05 - 14:25 0.33 DRILL P PROD1 Orient TF to 90L. 14:25 - 14:40 0.25 DRILL P PROD1 Drill to 11185' with 80L TF, 2.6/2.6bpm, 3100/3400psi, 113fph ave ROP. 14:40 - 14:50 0.17 DRILL P PROD1 Drill to 11195' with 80L TF, 2.6/2.6bpm, 3100/3400psi, 100fph ave ROP. Angle dropping @ 85L TF. 14:50 - 15:15 0.42 DRILL P PROD1 Orient & drill to 11244' with 60L TF, 2.6/2.6bpm, 3100/3400psi, 105fph ave ROP. 15:15 - 15:30 0.25 DRILL P PROD1 Orient TF to 70L. 15:30 - 16:15 0.75 DRILL P PROD1 Drill to 11308' with 70L TF, 2.6/2.6bpm, 3100/3400psi, 130fph ave ROP. Level up to plan trajectory @ 11300' (proposed top perf). 16:15 - 16:35 0.33 DRILL P PROD1 Wiper trip clean to window. 16:35 - 16:45 0.17 DRILL P PROD1 Tie-into RA pip tag & added l' to CTD. 16:45 - 17: 1 0 0.42 DRILL P PROD1 RBIH clean to btm. 17:10 -17:35 0.42 DRILL P PROD1 Drill to 11366' with 90L TF, 2.6/2.6bpm, 3100/3450psi, 160fph ave ROP. Geo wants a TVD ceiling of 8960'. 17:35 - 17:50 0.25 DRILL P PROD1 Orient & drill to 11400' with 90L TF, 2.6/2.6bpm, 3100/3400psi, 150fph ave ROP. 17:50 - 18:05 0.25 DRILL P PROD1 Orient TF to 90R. 18:05 - 18:50 0.75 DRILL P PROD1 Drill to 11420' with 80R TF, 2.6/2.6bpm, 3100/3400psi, 140fph ave ROP. Drilled to 11458'. 18:50 - 19:45 0.92 DRILL P PROD1 Wiper trip to window. One overpull on trip out. RIH. 19:45 - 21 :00 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200/3900 psi, 90 deg incl, 100 FPH, Drilled to 11,550'. 21 :00 - 21 :45 0.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200/3900 psi, 90 deg incl, 90 FPH, Drilled to 11,595'. 21 :45 - 22:45 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 22:45 - 23:00 0.25 DRILL P PROD1 Orient TF to 75R 23:00 - 00:00 1.00 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200/3900 psi, 89 deg incl, 90 FPH, Drilled to 11,660'. Swapped to new FloPro at 11630'. Total footage on FloPro was 1,160'. 1/9/2003 00:00 - 00:20 0.33 DRILL P PROD1 Drilling, New FloPro, 2.6/2.6 bpm, 3200-3600 psi, 90 deg incl, 80L, Drilled to 11682'. 00:20 - 00:40 0.33 DRILL P PROD1 Orient TF to 60L. 00:40 - 02:00 1.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200 - 3700 psi, 60L, 89 deg incl, Drilled to 11,775'. 02:00 - 03:20 1.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 03:20 - 03:40 0.33 DRILL P PROD1 Orient TF to 70L 03:40 - 04:30 0.83 DRILL P PROD1 Drilling, 2.6 / 2.6 bpm, 3200 - 3700 psi, 60L, 90 deg incl, Drilled to 11,840'. 04:30 - 05:20 0.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200 - 3700 psi, 60L, 90 deg incl, Drilled to 11,900'. 05:20 - 06:00 0.67 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3200 - 3700 psi, 80L, 89 deg incl, Drilled to 11,930'. At TO. 06:00 - 06:45 0.75 DRILL P PROD1 Wiper trip clean to window. 06:45 - 07:00 0.25 DRILL P PROD1 Tie-into RA pip tag & subtracted 2.5' to CTD. 07:00 - 07:45 0.75 DRILL P PROD1 RBIH clean to btm. Saw little bobble @ 10970' shale. 07:45 - 07:50 0.08 DRILL P PROD1 Tag TD @ 11927'. Drill to 11935' for liner tally spaceout. 07:50 - 11 :00 3.17 DRILL P PROD1 POOH to run Liner. Backream & ream shales clean from Printed: 1/14/2003 2:52:16 PM ) ) BP EXPLORATION PageS of 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations. 1/9/2003 07:50 - 11 :00 3.17 DRILL P PROD1 11050' to 10950'. Paint CT EOP flags @ 9900' & 8400' & continue POOH. 11 :00 - 13:00 2.00 DRILL P PROD1 OOH. Download memory MWD data. LlO drilling BHA#3. Bit looks new & grades 1,1,1. 13:00 - 13:30 0.50 CASE P COMP RIU to run liner. 13:30 - 13:45 0.25 CASE P COMP PJSM for running liner. 13:45 - 16:30 2.75 CASE P COMP MIU 47 jts 2-7/8" 6.16# L-80 STL & 17 jts 3-3/16" 6.2# L-80 TC11 liners with float equipment, pup, 'XN' nipple & XO's. Total length of liner = 1973.91 ft. 16:30 - 17:25 0.92 CASE P COMP Install Baker CTLRT. Install Baker CTC. Pull test to 35k & pressure test to 3500psi. 17:25 - 19:00 1.58 CASE P COMP RIH with liner completion BHA#4. Stop at first flag at 10,383' and correct, -19 ft CTD correction. Up wt = 41 K. Own wt = 19.5K. 19:00 - 19:30 0.50 CASE P COMP Ran thru window clean, lost wt at shale at 10970', Cont RIH clean at 60 FPH, Land Liner on bottom at 11,933'. Up wt = 43K, Tag again at 11933'. Liner at TO of 11,935'. 19:30 - 20:15 0.75 CASE P COMP Insert 5/8" steel ball and displace with FloPro at 2.0 bpm at 2400 psi. Slow to 0.5 bpm at 42 bbls. Ball on seat at 47.9 bbls. Sheared at 4200 psi. Pick up free at 35K. 20:15 - 23:00 2.75 CASE P COMP Circulate well to 2% KCL water with double friction reducer. Recover 460 bbls of used FloPro and send to MI plant for reconditioning. Circ at 2.8 bpm, 1850 psi, with full returns with KCL water. Clean pits and fill with 2% KCL water. 23:00 - 23:30 0.50 CEMT P COMP Rig up OS cementer while circ KCL water. Full returns. 23:30 - 23:45 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and mitigation for cementing liner. 23:45 - 00:00 0.25 CEMT P COMP Press test cement line. 1/10/2003 00:00 - 01 :10 1.17 CEMT P COMP Stage 23.0 bbls. 15.8 PPG, G CMT with Latex. 2.0 BPM into coil. Stop at 23.0 bbls CMT. Close inner reel valve. Purge cement lines. Pump 0.5 bbls Biozan behind dart. Check, dart gone. Displace CMT with 2 PPB Biozan water and KCL water at 3.0 bpm, full returns. CMT at shoe at 46.2 bbls displ. Full returns. Zero out totalizer. 2.9/2.7 bpm with cement on formation. Slow to 2.0 BPM, 1100 psi at 55 bbls displ. Dart on LWP at 57.7 bbls. Sheared at 3400 psi. Displ Cement at 2.4 bpm with 2.3 bpm returns. Slow to 1.5 bpm at 68 bbls displ. Bump LWP at 69.6 bbls [calc= 69.9 bbls]. Bump with 1000 psi over [1600 psi]. Held 1600 psi tight. Bled to zero. Floats holding. Sting out. 22 bbls cement returns out of 23 bbls pumped. Circ at top of liner at 1.5 bpm at 500 psi, Full returns. Cement job went very well. Cement at weight at 23:30 hrs. In place at 01 :00 hrs. 01: 1 0 - 01 :30 0.33 CEMT P COMP Circ 2% KCL water with friction reducer at 1.5 bpm, 500 psi, Full returns. 01 :30 - 03:30 2.00 CASE P COMP POH with BKR CTLRT. Circ. 1.5 bpm while POH. Saw contaminated cement returns at surface, indicating cement to top of liner. 03:30 - 04:30 1.00 CASE P COMP Layout BKR CTLRT. Close Swab valve. Jet BOP stack with jet nozzle to clear any cement from rams. 04:30 - 04:45 0.25 EVAL P COMP SAFETY MEETING. Review procedure, hazards and mitigation for M/U of SWS memory GR/CCL and motor/mill Printed: 1/14/2003 2:52:16 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Page 6 of 7 Operations Sum maryReport D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From -To Hours Task Code NPT Phase Description of Operations 1/10/2003 04:30 - 04:45 0.25 EVAL P COMP BHA. 04:45 - 08:00 3.25 EVAL P COMP M/U 2.30" diamond Parabolic mill, motor and SWS memory GR/CCL inside carrier. M/U BKR circ sub and hyd disconnect. M/U 33 stds of 1-1/4" CSH workstring. M/U injector. 08:00 - 09:30 1.50 EVAL P COMP RIH with logging/cleanout BHA to 9700' circ 150k LSRV Flo-Pro perf pill @ 0.5bpm & 720psi. 09:30 - 10:45 1.25 EVAL P COMP Log down from 9700' @ 30fpm. 10:45 - 12:00 1.25 EVAL P COMP Tag PBTD at 11896' CTD. PUH 41k logging @ 30fpm & leaving 20bbls fresh 150kLSRV Flo Pro pill in liner. 12:00 - 13:45 1.75 EVAL P COMP POOH from 9700'. Compressive strength of cement - 2000psi as @ 12:00 hrs. 13:45 - 14:00 0.25 EVAL P COMP OOH. Setback injector. 14:00 - 15:45 1.75 EVAL P COMP Standback 24 stds of 1-1/4" CSH & LID 18 jts. No loose connections on CSH jts. 15:45 - 16:45 1.00 EVAL P COMP Line up to test liner lap. Fill hole. IA/OA @ 13/286psi @ onset of test. Staged up in 500 psi intervals, monitoring IA/OA. PT @ 2000psi - leaked 850psi in 7mins, no change in IA/OA pressures during test. Double block valves & repeat test @ 2000psi - leaked 11 OOpsi in 1 st 15mins & 300psi in 2nd 15mins. Will run L TP after peforating. 16:45 - 17:00 0.25 PERF P COMP Load perf guns in pipeshed. Meanwhile download MCCLlGR data & faxed to town geologist. Logged PBTD @ 11899' & TOL @ 9959'. 17:00-17:15 0.25 PERF P COMP PJSM for RIH perf guns. 17:15 - 18:00 0.75 PERF P COMP M/U 27 SWS 2" HSD 4 spf PJ guns & blanks with firing head. 18:00 - 18:15 0.25 PERF P COMP Crew change & PJSM for RIH perf guns. 18:15 - 19:00 0.75 PERF P COMP M/U 24 stds of 1-1/4" CSH workstring. M/U OS MHA. 19:00 - 21 :30 2.50 PERF P COMP RIH with Perforating BHA. Circ. at 0.3 bpm at 90 psi. No wt. loss RIH at top of liner. RIH at 60 FPM. Circ. 0.3 bpm at 70 psi. Tag PBTD at 11904' CTD, Pick up and correct Depth to PBTD of 11,899.5 ft. [-4.5' CTD]. 21 :30 - 21 :50 0.33 PERF P COMP Position perf guns at correct depth, Bottom shot at 11,875' BKB. Greased wing valve on tree. Wing closed. Press test liner lap to 1000 psi, Hold 5 min. lost 225 psi. Press test liner lap to 1500 psi, Hold 5 min. lost 350 psi. Liner lap failed second pressure test. 21 :50 - 22:45 0.92 PERF P COMP Bottom perf charge positioned at 10,875' BKB. Pump 10 bbls of high viscosity FloPro pill ahead of ball. Insert 5/8" steel ball. Displace steel ball with 2% KCL water. Slow rate to 1.5 bpm, 800 psi at 47 bbls. Ball on seat at 51.9 bbls. Firing head sheared at 2900 psi, good indication of fired guns, lost returns, pumped 3 bbls before seeing returns, then 1.2 bpm in with 0.6 bpm out, returns increased quickly to 80% returns. 22:45 - 00:00 1.25 PERF P COMP POH with perf guns. Full returns. 1/11/2003 00:00 - 00:30 0.50 PERF P COMP POH with perf guns. 00:30 - 01:45 1.25 PERF P COMP Layout CSH workstring in singles. 01 :45 - 02:00 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitgation for laying out fired perf guns. Safety joint ready on catwalk. Printed: 1/14/2003 2:52:16 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/20/2002 Rig Release: 1/11/2003 Rig Number: N1 Spud Date: 12/20/2002 End: 1/11/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2003 02:00 - 03:45 1.75 PERF P COMP Layout SWS 2", 4 SPF Perf guns. All shots fired. PERFORATED INTERVALS: 11,325 - 11,500' 11,550 - 11,750' 11,800 - 11,875'. Total Feet = 450'. 03:45 - 05:00 1.25 RIGD P COMP RIH with 1-1/4" CSH workstring in stands, LlO in singles for derrick down rig move. 05:00 - 06:00 1.00 CASE P COMP MIU BKR 4-1/2" KB Liner top Packer with 3.00" seal assembly and running tools. BHA = 59.88 ft. 06:00 - 08:05 2.08 CASE P COMP RIH with BKR Liner top Packer assembly. Circ. at 0.5 bpm, 120 psi. 08:05 - 10:00 1.92 CASE P COMP Up wt at 9900 ft = 41 k, Own wt. = 24k. RIH circ @ 0.5bpm & 100psi. Stung seal assy into deployment sleeve from 9976 to 9981' CTD. Set down 10k @ 9983.6'. Sting out with seal assy & PUH to ball drop position @ 9948'. Pump 5/8" AL ball & chase @ 2bpm & 800 psi. Ball on seat at 49.8bbls. SID pump & RBIH. Set down 10k at 9983.5'. P/U to 41k @ 9979.2'. PUH 1.5' off to 9977.7'. Set pkr slips with 2500psi. Pull 5k over to energize pkr element. Stack 10k @ 9982.2'. Locator is 1.3' above PBR. PT pkr @ 2170 psi for 30min - Lost 5 psi in 30 min. 10:00 - 11:45 1.75 CASE P COMP Pressure CT to 3600psi & release from KB Packer. POOH with running tools. Top of 4-1/2" KB Packer @ 9943.8' (from pipe tally). 11 :45 - 12: 1 0 0.42 CASE P COMP FP 4-1/2" tubing with MEOH from 2200' to surface. Meanwhile clean rig pits. 12:10 - 12:30 0.33 CASE P COMP OOH. LlO Baker running tools. SI master & swab (23-1/2 turns). 12:30 - 12:45 0.25 RIGD P COMP PJSM for blowing down CT with N2. Continue to clean pits. 12:45 - 14:00 1.25 RIGD P COMP PT hardlines to 3000psi. Blow down CT with N2 @ 1 OOOscf for 15mins & bleed off. 14:00 - 14:15 0.25 RIGD P COMP PJSM for unstabing CT & RID injector gooseneck. 14:15 - 15:00 0.75 RIGD P COMP Unstab coil & remove injector gooseneck. Store injector in stabbing box. 15:00 - 16:00 1.00 RIGD P COMP PJSM for NO. Nipple down BOP. Nipple up & pressure test tree cap. Rig released @ 16:00 on 1/11/2003. Rig Accept to Rig Release Time = 5 Days & 11 Hrs. Prepare for derrick down rig move to OS 14-17A. Printed: 1/14/2003 2:52:16 PM ) ì ~oa~¿)t/(J 03-Feb-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well D-30A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,430.51 ' MD Window / Kickoff Survey 10,450.00' MD (if applicable) Projected Survey: 11,935.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 05 2003 Alaska Qi & Gas Cons. CormHeeton Ancftcnge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA D Pad D-30A ---- Job No. AKMW30002. Surveyed: 9 January. 2003 Survey Report 3 February, 2003 Your Ref: API 500292264601 Surface Coorçlinates: 5959346.19 N, 654087.87 E (700 17' 45.0406" N, 148045' 08.0639" W) ! Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 959346.19 N, 154087.87 E (Grid) Surface Coordinates relative to Structure Reference: 3715.74 N, 2000.15 E (True) Kelly Bushing: 78.25ft above Mean Sea Level Elevation relative to Project V Reference: 78.25ft Elevation relative to Structure Reference: 78.25ft Spcr-'I'"""Y-SUI'1 DRILLING seRVIc:es A Halliburton Company Survey Ref: svy11438 Sperry-Sun Drilling Services Survey Report for PBU_WOA D Pad ~ D-30A Your Ref: API 500292264601 Job No. AKMW30002, Surveyed: 9 January, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10430.51 91.780 70.760 8968.85 9047.10 1486.62 N 4109.59 E 5960916.75 N 658166.12 E 3995.88 Tie On Point 10450.00 91.110 71.360 8968.36 9046.61 "" 1492.94 N 4128.02 E 5960923.45 N 658184.41 E 4.613 4013.82 Window Point 10486.99 94.890 78.740 8966.42 9044.67 1502.47 N 4163.67 E 5960933.70 N 658219.87 E 22.389 4048.72 10517.37 98.100 84.870 8962.98 9041.23 1506.77 N 4193.53 E 5960938.62 N 658249.63 E 22.660 4078.21 10550.12 95.330 95.210 8959.14 9037.39 1506.74 N 4226.01 E 5960939.25 N 658282.10 E 32.473 4110.61 10582.84 88.990 99.260 8957.91 9036.16 1502.62 N 4258.42 E 5960935.80 N 658314.59 E 22.984 4143.23 / '- 10623.76 85.990 106.840 8959.70 9037.95 1493.40 N 4298.21 E 5960927.40 N 658354.56 E 19.903 4183.57 10655.87 90.040 112.830 8960.82 9039.07 1482.52 N 4328.38 E 5960917.14 N 658384.95 E 22.506 4214.42 10685.76 91.540 118.640 8960.40 9038.65 1469.55 N 4355.29 E 5960904.72 N 658412.12 E 20.073 4242.17 10719.89 91.890 127.630 8959.38 9037.63 1450.92 N 4383.83 E 5960886.68 N 658441.03 E 26.349 4271.94 10756.77 89.430 134.500 8958.96 9037.21 1426.71 N 4411.61 E 5960863.04 N 658469.31 E 19.784 4301.34 10797.54 89.1 60 128.160 8959.46 9037.71 1399.80 N 4442.21 E 5960836.77 N 658500.45 E 15.564 4333.74 10832.69 89.250 121.280 8959.95 9038.20 1379.80 N 4471.08 E 5960817.36 N 658529.72 E 19.573 4363.94 10870.39 90.830 117.620 8959.92 9038.17 1361.26 N 4503.90 E 5960799.50 N 658562.92 E 10.574 4397.97 10907.82 89.940 125.020 8959.67 9037.92 1341.82 N 4535.85 E 5960780.72 N 658595.26 E 19.912 4431.20 10944.99 85.810 127.280 8961.05 9039.30 1319.92 N 4565.84 E 5960759.43 N 658625.69 E 12.663 4462.65 10980.97 84.4 1 0 122.170 8964.11 9042.36 1299.50 N 4595.29 E 5960739.63 N 658655.56 E 14.675 4493.45 11020.07 88.020 116.530 8966.70 9044.95 1280.39 N 4629.28 E 5960721.22 N 658689.93 E 17.098 4528.69 11057.47 86.260 110.710 8968.56 9046.81 1265.43 N 4663.49 E 5960706.96 N 658724.44 E 16.238 4563.86 11089.34 86.870 105.780 8970.48 9048.73 1255.48 N 4693.69 E 5960697.63 N 658754.84 E 15.559 4594.68 11127.79 91.450 104.720 8971.04 9049.29 1245.37 N 4730.77 E 5960688.28 N 658792.12 E 12.226 4632.38 11158.39 92.510 99.260 8969.98 9048.23 1239.02 N 4760.68 E 5960682.55 N 658822.15 E 18.166 4662.65 11204.07 91.280 90.980 8968.47 9046J72 1234.95 N 4806.11 E 5960679.41 N 658867.65 E 18.315 4708.26 11239.44 93.390 86.220 8967.03 9045.28 1235.81 N 4841.43 E 5960680.99 N 658902.94 E 14.710 4743.43 ~ 11278.19 92.860 79.520 8964.91 9043.16 1240.61 N 4879.80 E 5960686.58 N 658941.21 E 17.319 4781.37 11321.09 91.890 73.530 8963.13 9041.38 1250.59 N 4921.46 E 5960697.42 N 658982.66 E 14.133 4822.24 11368.14 90.660 64.190 8962.08 9040.33 1267.54 N 4965.29 E 5960715.26 N 659026.13 E 20.017 4864.77 11406.94 91.190 62.080 8961.46 9039.71 1285.07 N 4999.89 E 5960733.49 N 659060.36 E 5.606 4898.07 11435.19 91.810 67.540 8960.72 9038.97 1297.08 N 5025.44 E 5960746.03 N 659085.66 E 19.445 4922.71 11470.09 90.480 73.530 8960.02 9038.27 1308.71 N 5058.32 E 5960758.32 N 659118.30 E 17.578 4954.71 11510.74 89.780 80.230 8959.93 9038.18 1317.93 N 5097.89 E 5960768.35 N 659157.66 E 16.572 4993.53 11540.19 91.720 86.570 8959.54 9037.79 1321.31 N 5127.12 E 5960772.34 N 659186.83 E 22.511 5022.46 11572.89 90.480 89.210 8958.91 9037.16 1322.51 N 5159.79 E 5960774.21 N 659219.46 E 8.918 5054.97 11603.42 88.460 93.620 8959.19 9037.44 1321.76N 5190.30 E 5960774.08 N 659249.98 E 15.887 5085.46 11635.64 89.250 99.080 8959.84 9038.09 1318.20 N 5222.30 E 5960771.18 N 659282.05 E 17.119 5117.63 3 February, 2003 - 13:41 Page 2 of4 DríllQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA D Pad - D-30A Your Ref: API 500292264601 Job No. AKMW30002, Surveyed: 9 January, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11667.47 89.600 102.080 8960.16 9038.41 1312.36 N 5253.59 E 5960765.97 N 659313.45 E 9.489 5149.24 11705.67 89.340 95.560 8960.51 9038.76 1306.50 N 5291.31 E 5960760.90 N 659351.29 E 17.081 5187.29 11743.57 88.370 90.980 8961.27 9039.52 1304.34 N 5329.13 E 5960759.51 N 659389.14 E 12.350 5225.17 11776.59 90.660 86.400 8961.55 9039.80 1305.10 N 5362.13 E 5960760.94 N 659422.12 E 15.506 5258.03 11805.07 89.780 82.870 8961 .44 9039.69 1307.76 N 5390.48 E 5960764.18 N 659450.41 E 12.774 5286.13 11839.62 88.460 79.350 8961.97 9040.22 1313.10 N 5424.61 E 5960770.22 N 659484.42 E 10.880 5319.80 .~ 11869.27 89.520 74.410 8962.49 9040.74 1319.82 N 5453.47 E 5960777.54 N 659513.14 E 17.038 5348.12 11900.89 88.630 67.540 8963.01 9041.26 1330.12 N 5483.34 E 5960788.45 N 659542.79 E 21.905 5377.20 11935.00 88.630 67.540 8963.82 9042.07 1343.15 N 5514.85 E 5960802.12 N 659574.03 E 0.000 5407.73 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 94.000° (True). Magnetic Declination at Surface is 25.953°(07-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11935.00ft., The Bottom Hole Displacement is 5676.06ft., in the Direction of 76.312° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) ~ Comment 10430.51 10450.00 11935.00 9047.10 9046.61 9042.07 1486.62 N 1492.94 N 1343.15 N 4109.59 E 4128.02 E 5514.85 E Tie On Point Window Point Projected Survey 3 February, 2003 - 13:41 Page 3 of4 DriflQuest 3.03.02.004 North Slope Alaska Sperry-Sun Drilling Services Survey Report for PSU_WOA D Pad - D-30A Your Ref: API 500292264601 Job No. AKMW30002, Surveyed: 9 January, 2003 BPXA Survey tool program for D-30A From Measured Vertical Depth Depth (ft) (ft) 0.00 3 February, 2003 - 13:41 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11935.00 9042.07 MWD Magnetic(D-30) - ~ Page 4 of4 DrillQlIest 3.03.02.004 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503·5711 ATTN: Beth Well F-10A ~()O..~ ï D-30A ~nrl.-d4{J D.S.1-12A~~-lq:J D.S.11-06 J CfI-/0/ D.S.18-25A Jq 7-oCfct D.S.2-37 fq ~ - L'7 e:) L5-05 ð'- I-Ot,., t::t D.S.1-26A Job# 23002 23030 22513 23019 22487 22511 22512 22509 01120/03 NO. 2821 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Sepia Prints CD 12/10/02 2 01/10/03 1 1 10/30/02 1 1 11/20/02 1 1 10/22/02 1 1 10/27/02 1 1 11/01/02 1 1 11/08/02 1 -~ SCMT LINER TOP TIE-IN MGRlCCL (PDC) MCNL RST-SIGMA MCNL MCNL RST -SIGMA RST-SIGMA (REPLACES BLANK CD) ....~ 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: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECEIVED Received~ ~~ J FEB 0 7 2003 Alaaka Ql & Gas Cons. Corrtmlaeion Andmge r' @l!¡®'\urE0ìIT;IMn ® ~Jr Æ\ @ U lAì lb lW If lru l1lf~ @ U~úD ) ALASKA. OIL AND GAS CONSERVATION COMMISSION / I I I / f I j TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit D-30A BP Exploration (Alaska), Inc. Permit No: 202-240 Surface Location: 3625' NSL, 1066' WEL, Sec. 23, TIIN, RI3E, UM Bottomhole Location: 5020' NSL, 4446' EWL, Sec. 24, TI1N, RI3E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~c?-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this /3 ~ day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA '\ ALASKA ....1 AND GAS CONSERVATION COMM¡_..~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 78.25 Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028285 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' D-30A 9. Approximate spud date 12/21/02 ./ Amount $200,000.00 / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11925' MD / 8960' TVDss o 17. Anticipated pressure {s,e 20 AAC 25.035 (e) (2)} 97 Maximum surface 2194 psig, At total depth (TVD) 8800' / 3250 psig Setting Depth . 6Pc Top Bottom '.¡ì"'"Quantitv of Cement Lenath MD TVD MD TVD 1,:1.. ßi>1 ~ (include staae data) 1960' 9965' 8912' 11925' 8960' ~ã·S)( Class 'G' ,/ 1 a. Type of work D Drill II Redrill D Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3625' NSL, 1066' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 4831' NSL, 2214' EWL, SEC. 24, T11N, R13E, UM At total depth 5020' NSL, 4446' EWL, SEC. 24, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028305,833' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10450' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 3-3/4" 3-3I16"x2-7/S" 6.2#/6.16# L-80 ST-L j¡Jl.) A- j l'fll-I 0 ~..- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13621 feet Plugs (measured) Bridge Plugs Set at 10268', 10635' and 11109' true vertical 9007 feet Effective depth: measured 13530 feet Junk (measured) true vertical 9012 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 110' 20" 3421' 10-3/4" 1 0369' 7-5/8" 3387' 4-1/2" Cemented MD TVD 260 sx Arctic Set (Approx.) 110' 110' 1165 sx Permafrost 'E', 498 sx 'G' 3456' 3276' 553 sx Class 'G' 10405' 9048' 636 sx Class 'G' 10234' - 13621' 9050' - 9007' Perforation depth: measured Open: 10159' - 10201' Below Bridge Plugs: 10420' - 13480' (11 Intervals) true vertical Open: 9043' - 904' Below Bridge Plugs: 9047' - 9014' 20. Attachments II Filing Fee D Property Plat II BOP Sketch II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis Contact Engineer Name/Number: Thomas McCarty, 223-7156 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas McC."~/_if #c~ ... .~tle . CT Orilling En~ineer . .... ...... ,.COQ1t1)l..OQ UseJ';)t;'ly".:, , Permit Number API Number Approval Date See cover letter Zð¿ - 2- ~o 50-029-22646-01 1'2../IJ/Øt- forotherreQuirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log Required 0 Yes J8I No Hydrogen Sulfide Measures m Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: "Tis tE' f) P t.:..~ fc ~ S,,'" DeS' ¡ . Approved By ~/ ? ~ Form 10-401 Rev. 12-01-85 D Diverter Sketch II Drilling Program D Seabed Report II 20 AAC 25.050 Requirements Prepared By NamelNumber: Terrie Hubble, 564-4628 Date /2}1 / (/ L. Commissioner by order of the commission Date / "2-/13/· t... Submit In Triplicate ) ) Summary of Operations: /. A CTD through tubing lateral is planned for D-30. The coiled tubing sidetrack, D-30A, will exit the 4-1/2" liner in zone 2 and target Zone 2A. Prior to CTD sidetracking the well, the IBP at 10268' will be released /' and a whipstock will be set. After the window is milled in the 4-1/2" liner, approximately 1475' of 3-3/4" open hole is planned to access the Zone 2A target. The well will be completed with a solid, cemented and perforated liner. BP D-30A CTD Sidetrack Phase 1: Prep work. Planned for December 15, 2002. 1 . M IT tubing and casing. /' 2. Service coil to release IBP at 10268'md (either push to bottom or pulllBP after release) 3. Service coil to set a mechanical whipstock with sealing element at 10450'. 4. Mill window with coiled tubing Phase 2: Mill window, Drill and Complete sidetrack: Planned for December 21, 2002. / Drilling coil will be used to mill the window in the 4-1/2" liner if service coil could not mill the window in Phase 1. Drilling coil will then drill and complete the directional hole as per attached plan. Maximum hole angle is planned for 90 degrees. The lateral will be completed with a 2 7/8" x 3 3/16" solid ~ cemented and perforated liner. Resistivity will be run in addition to MWD gamma ray. Mud Program: · Phase 1: Sea water and 2ppb B2)'O ri) · Phase 2: Drill with Flo-Pro (8.6 - .7.J1pg) ~/ Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. ¡ Casing Program: j The production liner wUL\be 27/8" ST-L solid liner from TD to approx. 10650' MD, where it will be crossed over to 3 3/16" Ii~er D~ired top of 3 3/16" liner will be at approx. 9965'md. The liner will be cemented in place with appro 22 I6ìs of cement. Approx. 400' of perforations will be made in the target zone. Use of the 3-3/16" liner . reserve future sidetrack options. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is approx. 90deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over the entire open hole section. Resistivity will be run in the open hole. Hazards · D-Pad is not an H2S pad. Max recorded H2S on D-Pad is 15ppm.. · Lost circulation risk is considered low based on fault orientation and regional history. · D-30 is facility twinned, the twinned well will be isolated and shut-in during drilling ops. Reservoir Pressure ) ) Res. press. is estimated to be 3250 at 8800'ss (7.1 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. TREE = 4" CrN WEL~HEA D= FMC "AëtÜA"TOR;·· ............. ··AXELsON· "KB~"'ËlE\i ;...... ...·...·...7·8·~·2·5ï· Bï=~ "E[vE\Ï .=.... .. . .......... ·......4Ój5ï· .n ........................................ ................. KOP= 1215' ................................................ ................ ............ .~~...~...~.!;!I~.~._....................._...~~....~....!.~-~~..~~.. Datum MD = 9738' .......~...'...'_...N.....'...."..........._...·. .............._......................................_.. Datum TVDss= 8800' ) D-30 crt 110-3/4" CSG, 45.5#, L-80, ID = 9.953" 1-1 3456' ~ L Minimum 10 = 3.725' @ 9979' 4-1/2" HES XN NIPPLE I :8: I :8: 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9991' f \ I TOP OF 4-1/2" LNR 1-1 10260' I o .~ 7-5/8" CSG, 29.7#, USSS95, ID= 6.875" 1-1 10405' ~ ÆRFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 07/20/96 ANGLEATTOPÆRF: 84 @ 10159 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 4 10159' -10180' 0 08/08/97 2 4 10180' -10201' 0 08/08/97 2 4 10710' -10820' C 01/18/97 2 4 10710' -10820' C 01/18/97 2 4 10880' -11010' C 01/18/97 2 4 10880' -11010' C 01/18/97 2 4 11050' -11090' C 01/18/97 2 4 11050' -11090' C 01/18/97 2 4 11130'-11550' C 01/18/97 2 4 11130' -11550' C 01/18/97 I PBTD 1-1 13530' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11 13621' DATE 03/23/96 02/07/01 03/08/01 05/19/01 REV BY COMMENTS ORK3INAL COMPLETION SIS-SLT CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS REV BY COMMENTS DATE I SAF£ )OTES: HORIZONTAL WELL 2215' 114-1/2" HES HXO SSSV NIP, ID = 3.813" I ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VALVE LATCH SIZE DATE 3 3779 3489 25 KBrv1G-M BK 1" 2 7144 6495 26 KBrv1G-M BK 1" 1 9812 8843 59 KBrv1G-M BK 1" 9923' 114-1/2" HES X NIP, ID = 3.813" 1 9933' 117-5/8" x 4-1/2" BKRS-3 PKR, ID= 3.875" 9957' 1-14-1/2" HES X NIP, ID = 3.813" I 9979' 114-1/2" HES 'XN NIP, ID = 3.725" 9991' 114-1/2" WLEG, ID = 3.958" I 9988' 11 ELMD IT - LOGGED 07/20/96 1 10268' 113-3/8" BKR IBP I ~ I 10635' 1-13-3/8" BKR IBP I I 11109' 113-3/8" IBP I PRUDHOE BA Y UNIT WELL: 0..30 ÆRMIT No: 96-0260 API No: 50-029-22646-00 Sec.23,T11N,R13E BP Exploration (Alaska) TREE = WELLHEAD= ACTUÀ TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ìVDss= 4"CMI FMC AXELSON 78.25' 40.6' 1215' 96@13018' 9738' 8800' ) 110-3/4" CSG, 45.5#, L-80, ID = 9.953" l-i 3456' ~ Minimum 10 = 3.725' @ 9979' 4-1/2" HES XN NIPPLE TOP OF 3-3/16" LNR- 9965' Top of Cement 9965' 13.5" XN Nip 2.75" 101-1 9985' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9991' 1 TOP OF 4-1/2" LNR 1-1 10260' I D-30A ~)N01ES: HORlZONTALW8.L Proposed CTD Sidetrack ' - L I ;g I :8: JI...ì'..i!'.:.!.~.',.,_:.,:.:.:.:L'.:. . " ; :.:.: . ' : ,.' ,~ " . I ¡' , ! I :: I "'1.", .,:' I I' I, ',"1 : ':l:;:,:;·:"r:':,';:,'i::""; .." '~.:; ,,' : I :": .:,:, ,',:¡";;' I , . " ' , -: :', .:: ':: I : : ,II::" I'~ ,:i ;.':: ::i,:,~, ,":/: :,:'11 'I ':'!:,:' \:/".::.,::.\':,.'1:;. '..' .,..'..:..:,' lit·! I i¡1};I:I\~", I ¡I,' '.' ,I,'" I', ,.~I " '.': ,.' .1...........::.'..'.'.'....'i.":: ,,:,r , . ,·1, . :::¡I:;¡\ '"'''·"r:' 17-5/8" CSG, 29.7#, USSS95, 10 = 6.875" 1-1 10405' ~ ÆRFORA TION SUMMARY REF LOG: PDS JEWELRY LOG ON 07/20/96 ANGLE AT TOP ÆRF: 84 @ 10159 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 4 10159' -10180' isolated proposed 2 4 10180' -10201' isolated proposed 2 4 10710' -10820' C 01/18/97 2 4 10710' -10820' C 01/18/97 2 4 10880' -11010' C 01/18/97 2 4 10880'-11010' C 01/18/97 2 4 11050' -11090' C 01/18/97 2 4 11050' -11090' C 01/18/97 2 4 11130'-11550' C 01/18/97 2 4 11130' -11550' C 01/18/97 1:'1 I PBID l-f 13530' I ~ 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 1-1 13621' ~ DATE 03/23/96 02/07/01 03/08/01 05/19/01 REV BY COMMENTS ORIGINAL COMA...EOON SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS DATE COMMENTS REV BY 2215' 1-14-1/2" HES HXO SSSV NIP, 10 = 3.813" I ~ GAS LIFT MANDRELS ST MD ìVD DEV TYÆ VALVE LATCH SIZE DATE 3 3779 3489 25 KBMG-M BK 1" 2 7144 6495 26 KBMG-M BK 1" 1 9812 8843 59 KBMG-M BK 1" 9923' 1"4-1/2" HES X NIP, 10 = 3.813" I 9933' 1-17-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" I 9957' 9979' 9991' 9988' 1"4-1/2" HES X NIP, ID = 3.813" 1 1-14-1/2" HES 'XN' NIP, ID = 3.725" 1"4-1/2" WLEG, 10 = 3.958" I 1-1 ELMO IT - LOGGED 07/20/96 I Note:IBP01028W·· 181,..,(1. / 10650' 1-13-3/16 x 2-7/8 X-over "~'''''' ,,"', '!~"",..........." "'".:.'.........\ .:, '''',,(:,.~::.¡,:.::'¡',::::' , . .::¡,"~::.:' ,'::1.·'.,::,.,,··:,.. '. ..:1.: .:1:1.. " J 3-3/16" X 2-7/8" cOlt'ed and perfedl-1 11925' ¡I' /' 10450' 1-1 Mechanical Whipstock 10635' I., 3-3/8" BKR IBP I I 11109' 1-13-3/8" IBP I PRUDHOE BA Y UNIT WB...L: 0-30 ÆRMIT No: 96-0260 API No: 50-029-22646-00 Sec.23,T11N,R13E BP Exploration (Alaska) Plan: Plan #2 (D-30/Plan#2 D-30A) Created By: Brij Palnis Date: 1: ConmCi information: DirerA: 191.)7) 2137-8613 E-rnaH: ·i-.:ij.potr;;s@inte:q.com Bake: Hughes ;N!EQ: (9û7} 267-650ü Azimuths to True North Magnetic North: 25.97" Magnetic Field Strength: 57532nT Dip Angle: 80.80· Date: 12/11/2002 Model: BGGM2002 T AM 4 LEGEND 0-30 (0-30) Plan#2 D-3OA Plan #2 .. B>-JïUêiÌl£S ~:ÑrEQ----- i tIf) BP Amoco WI!LLPATH ÐETAILS p~ D-30A 5002.822&4801 ",'0 10030.1;1 1).0')0 RK8 ~'IJj~ = 71.2.5tt ::::-~D Parent Wellpattu TI. on MO: 11.111 .... DatumJ V.s.ctlOft A..... !l4.oo· cvrn~;':f ~51 ~:¡~:~: ~y~:e~:n~:~~-~ 1r;::e~Of\h Me~=~~ ~:¡:;:~: ~~ ~~O.OON.;g:ggE) Calculation Method: Minimum Curvature ECTlON DETAILS .w.. tÐ-W Dut! TF~ VSec 1481.&4 41"..51 0.00 0.00 305.17 ~=:E :Hi::i ~!5 1:== ::!:ii j[~ = !m~j ~ H!~:: :~i~~ ~~:E:S =:!! he MD I_CI Ad TVO 1 104JO.51 '1.11 70.71 1..1.15 ~ ~::~::: ~ lli: :=~: .. 10500.00 17.n ao.11 '''5.13 I 10544.'" ~.OO .~ ,,,2-2'1 i m~ Ë~ii ¡~ 15~ 10 11 372...U H.50 61.54 1M3." ~~ ~~::.~::1: ~:~ :::::: ANNOTATIONS TVD MD Annotation 88....5 10430.51 TIP 8811.31 10.450.00 MOP 8987.70 10470.00 1 89"5.13 10500.00 2 1912.21 10546.... 3 11183.11 10697.14 4 aiM." 1 "72.84 5 8Iow,ea "Ou.u e 11114...6 11222...84 7 8813.6 11372.84 . aUz.oe "8C2.84 8 8959.75 1192S.00 TO 8473.00 1336.71 TSAD ___ _8&ID.OO.-.52L51-JZ3 --- is 8710.00 "13.03 TnC 18 1775.00 H98.51 TZ2B 17 aa4Q.OO U06.52 ~ 18 "1'3.00 1917.1' ZiTS ~: :=~1=::= ~~ ~ TARGET DET AI.S TVD ++¡ ·5 .-£. -W Shape 0.00 1339.30 .(611.19 f'oÞtgcn 0.00 13ð9.09 4Q221 ~ 0.00 ICßl:~2 .(649.so Pct,ogm ei:~ ~æ:g ~~ æ ....... 0-""'_' f~~¡ .~..,--,/ __,__.___...__ ·-o-~"----7-.- . . . . : . . . . . . . -" . -' -. -. 5400 5500 5600 5700 5800 11:08 AM 12/11/2002 Vertical Section at 94.00° [100tt/in] L@_ L·T~CJ r.I~ ,~ .~ í}.fTSI ':---~ [!>~ LE!!!J -.........~ 7800 7900 8000 - C æ 8100 o o 8200 ~ - .c 8300 ... a. Q) 8400 CI Ci 8500 to) :e 8600 Q) > 8700 G.I 2 8800 t- 8900 9200 9100 9000 ) ) Ii. BA HUGHES l.N'I'.EQ ,bp BP Baker Hughes INTEQ Planning Report ---~-----_.~ Company: BP Amoco Field: Prudhoe Bay Site: PB 0 Pad Well: D-30 Wellpath: Plan#2 D-30A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 12/11/2002 Time: 11 :08:38 Page: Co-ordinate(NE) Reference: Well: D-30, True North Vertical (TVD) Reference: System: Mean. Sea Level Section (VS) Reference: Well (O.00N,O.00E,94.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2002 ------ Site: PB D Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5955590.34 ft From: Map Easting: 652165.06 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Latitude: 70 17 Longitude: 148 46 North Reference: Grid Convergence: 8.492 N 6.316 W True 1.16 deg .------ ---.--,.- Well: D-30 Slot Name: D-30 Well Position: +N/-S 3716.81 ft Northing: 5959346.55 ft Latitude: +E/-W 1998.28 ft Easting: 654087.58 ft Longitude: Position Uncertainty: 0.00 ft 30 70 17 45.044 N 148 45 8.072 W -.--,-----.-.-..---.,.-- -.---.--- w.._._________,__~_,_____ Wellpath: Plan#2 D-30A 500292264601 Current Datum: D-30 RKB Magnetic Data: 12/11/2002 Field Strength: 57532 nT Vertical Section: Depth From (TVD) ft 0.00 _.'_____M___'.___~__ +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 D-30 10430.51 ft Mean Sea Level 25.97 deg 80.80 deg Direction deg 94.00 --'-'.-...---.-- Height 78.25 ft --------,-------------~--,- ---'--'--'-"'''-.--- Targets ---.-.~...-_._._.-..--.-.-----.---..----...-".~,.-.-.----.-.,-----..--.--.----.-.....--.-..~..---.______.__._·_..·,,_·_···______·...__..m.__'___,,___,___..~_._____..'.____._._,_______.._0._______ Map Map <--- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/"'W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft -.-.------.-"--- ---~.-.......-_----_.- ---------- D-30A Polygon2.1 0.00 1339.30 4611.19 5960780.00 658670.00 70 17 58.202 N 148 42 53.646 W -Polygon 1 0.00 1339.30 4611.19 5960780.00 658670.00 70 17 58.202 N 148 42 53.646 W -Polygon 2 0.00 1309.79 4830.65 5960755.00 658890.01 70 1757.911N 148 42 47.249 W -Polygon 3 0.00 1475.62 5524.24 5960935.00 659580.00 70 17 59.537 N 148 42 27.025 W -Polygon 4 0.00 1314.62 5570.96 5960775.00 659630.01 70 17 57.953 N 148 42 25.667 W -Polygon 5 0.00 1209.81 4828.60 5960655.01 658890.01 70 17 56.927 N 148 42 47.310 W -Polygon 6 0.00 1234.83 4584.04 5960675.00 658645.00 70 17 57.175 N 148 42 54.439 W D-30A Fault 1 0.00 1389.09 4622.21 5960830.00 658680.00 70 17 58.692 N 148 42 53.323 W -Polygon 1 0.00 1389.09 4622.21 5960830.00 658680.00 70 17 58.692 N 148 42 53.323 W -Polygon 2 0.00 1369.68 4836.87 5960815.00 658895.00 70 17 58.500 N 148 42 47.066 W D-30A Fault 3 0.00 1033.42 4649.93 5960475.00 658715.00 70 17 55.194 N 148 42 52.522 W -Polygon 1 0.00 1033.42 4649.93 5960475.00 658715.00 70 17 55.194 N 148 42 52.522 W -Polygon 2 0.00 1159.22 4612.50 5960600.00 658675.00 70 17 56.431 N 148 42 53.611 W D-30A Fault 2 0.00 1093.31 4656.16 5960535.00 658720.00 70 17 55.783 N 148 42 52.339 W -Polygon 1 0.00 1 093.31 4656.16 5960535.00 658720.00 70 17 55.783 N 148 42 52.339 W -Polygon 2 0.00 1176.25 4757.89 5960620.00 658820.00 70 17 56.598 N 148 42 49.372 W D-30A T2.3 8960.00 1395.74 5517.60 5960855.00 659575.00 70 17 58.751 N 148 42 27.221 W D-30A T2.1 8965.00 1299.51 4600.37 5960740.00 658660.00 70 1757.811N 148 42 53.962 W D-30A T2.2 8965.00 1260.01 4819.62 5960705.00 658880.00 70 17 57.421 N 148 42 47.571 W ---,- -,._--_._.__.-~------ ---,------- -,- - --- -------~,-,._,-------_._---~-------- ----- ----- - - --, -----------'--------,..--------.-- -,------ ._-,------,------ ____J ) ') BP Baker Hughes INTEQ Planning Report BA , IWGHIS INTEQ --.--"----- Company: BP Amoco Field: Prudhoe Bay Site: PB D Pad Well: 0-30 Wellpath: Plan#2 D-30A -..- Annotation ---.-.."'-- .----.---- .._---'---- MD TVD ft ft 10430.51 8968.85 TIP 10450.00 8968.36 KOP 10470.00 8967.70 1 10500.00 8965.13 2 10546.84 8962.21 3 10697.84 8963.11 4 10972.84 8964.68 5 11022.84 8964.68 6 11222.84 8964.66 7 11372.84 8963.99 8 11602.84 8962.06 9 11925.00 8959.75 TD 9336.71 8473.00 TSAD 9529.52 8640.00 TZ3 9613.03 8710.00 TZ2C 9699.51 8775.00 TZ2B 9806.52 8840.00 22TS 9917.19 8893.00 21TS 9934.30 8900.00 PGOC 10140.30 8963.00 TZ1B BSAD Date: 12/11/2002 Time: 11 :08:38 Page: 2 Co-ordinate(NE) Reference: Well: D-30, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,94.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ~_.__._----,- -----,_._------".._._~._._-"_..__._--,-_.__._-_...._--,..__.-._---,~..._.__..__._-----"-".._.._-_...__._.__.-_._-----_..._-,~"...,"-----_._--,..,,-----_._"'_._-~--"---"-. __.___._.___,,__.4____.__._______.___________. -.----...-.------..--.,-.,....--- Plan: Plan #2 Date Composed: 12/11/2002 Identical to Lamar's Plan #2 Version: 3 Principal: Yes Tied-to: From: Definitive Path --..-----.-.-------.-.--..,. ----~--_._- ...__._.--_...__._--_.._------,--_.__."--,~, .---.....-.....-..-..---..----....- --.-...---.-.---- -.--- .-....'.-..- -----...-.--.---------.-.-.-......--... Plan Section Information ..._..,,_..~_._-~"_._. _._--~_._---- ---,,_._--,,-._._-~..-"'.- . .""._.._._,,-~~..-----,,-- MD Inel Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ~-~-~_._"..._---_._.__._-----~-_._-- ----_..__..".~._._._""._~_._--_._--..-._.__.._.__._-_.--...--".----... 10430.51 91.78 70.76 8968.85 1486.64 4109.58 0.00 0.00 0.00 0.00 1 0450.00 91.11 71.36 8968.36 1492.96 4128.01 4.61 -3.44 3.08 138.16 10470.00 92.67 72.26 8967.70 1499.20 4147.00 9.00 7.79 4.50 30.00 10500.00 97.13 80.11 8965.13 1506.34 4175.99 30.00 14.87 26.16 60.00 10546.84 90.00 92.25 8962.21 1509.43 4222.52 30.00 -15.23 25.91 120.00 10697.84 89.36 137.54 8963.11 1447.51 4355.95 30.00 -0.42 30.00 90.90 10972.84 90.01 104.55 8964.68 1307.64 4588.31 12.00 0.24 -12.00 271.00 11022.84 90.01 110.55 8964.68 1292.58 4635.96 12.00 0.00 12.00 90.00 11222.84 90.01 86.55 8964.66 1263.06 4832.30 12.00 0.00 -12.00 270.00 11372.84 90.50 68.56 8963.99 1295.26 4978.17 12.00 0.33 -12.00 271.60 11602.84 90.44 96.16 8962.06 1325.56 5203.92 12.00 -0.02 12.00 90.00 11925.00 90.35 57.50 8959.75 1397.60 5511.67 12.00 -0.03 -12.00 270.00 ----~--"~.."------_.--~_._-----_.._~--- ----.--..---.----. -..----.---"..-.-----.- --".-----.-.-- Survey -"---'-~'_._-_. -.------.-----.--.-.-.--. .~_._-~----_..._-_._._--_..._"-- _._-_._._-----"---~--,,._--_._---._..._..__.._-_._---- MD Inel Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg ------.---.---.. --_._--_._--".~- .__._-_._--_._-_._-----_._~--~ 9336.71 28.20 70.46 8473.00 1205.15 3275.13 5960618.50 657337.08 3183.09 0.00 0.00 TSAD 9529.52 31.67 68.13 8640.00 1238.94 3365.32 5960654.13 657426.55 3270.70 1.90340.49 TZ3 9613.03 35.91 69.18 8710.00 1255.92 3407.52 5960671.97 657468.39 3311.61 5.14 8.27 TZ2C 9699.51 46.55 71.81 8775.00 1274.67 3461 .20 5960691.81 657521.67 3363.85 12.46 10.27 TZ2B 9806.52 57.28 69.75 8840.00 1301.87 3541.52 5960720.65 657601.40 3442.08 10.14 350.71 22TS 9917.19 65.45 70.91 8893.00 1338.16 3631.48 5960758.78 657690.60 3529.29 7.45 7.39 21TS 9934.30 66.23 71.52 8900.00 1343.18 3646.27 5960764.10 657705.28 3543.69 5.59 35.84 PGOC 10140.30 82.18 73.93 8963.00 1400.59 3832.99 5960825.32 657890.77 3725.95 7.82 8.63 TZ1B 10430.51 91.78 70.76 8968.85 1486.64 4109.58 5960917.01 658165.52 3995.87 3.48341.65 TIP 10450.00 91.11 71.36 8968.36 1492.96 4128.01 5960923.71 658183.81 4013.81 4.61138.16 KOP 10470.00 92.67 72.26 8967.70 1499.20 4147.00 5960930.34 658202.67 4032.32 9.00 30.00 1 10475.00 93.42 73.56 8967.43 1500.67 4151.77 5960931.91 658207.41 4036.98 30.00 60.00 MWD 10500.00 97.13 80.11 8965.13 1506.34 4175.99 5960938.07 658231.51 4060.74 30.00 60.07 2 10525.00 93.34 86.61 8962.85 1509.21 4200.70 5960941 .45 658256.15 4085.19 30.00 120.00 MWD 10546.84 90.00 92.25 8962.21 1509.43 4222.52 5960942.11 658277.96 4106.94 30.00 120.59 3 - -..---.----- .-.--"..-------- ---~ --..- -...--..-.-.-"".--. ..__._"_._~--------~-_._~---_.,,.~---~-_._..."------- ~.__..._- ) ') lB.. bp BP BAKE. MUGHIS Baker Hughes INTEQ Planning Report ...... " ,.-,......""""..... l.N'r.EQ __'_'W~""_'_'_'___ ..~._.._-_.__._.__._~- Company: BP Amoco Date: 12/11/2002 Time: 11 :08:38 Page: 3 Field: Prudhoe Bay Co-ordinate(NE ) Reference : Well: D-30,True North Site: PB D Pad Vertical (TVD) Reference: System: Mean Sea Level Well: D-30 Section (VS) Reference: Well (0.00N,0.OOE,94.00Azi) Wellpath: Plan#2 D-30A Survey Calculation Method: Minimum Curvature Db: Oracle -----.--.- Survey .-..-....-.--.----..-..---..------.-.--..----..---.------"'--'--'--"'-'-' --..--.-.-.------- ..--.----.------------".--.--.--.-.-------. MD Inel Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 10550.00 89.98 93.19 8962.21 1509.28 4225.68 5960942.03 658281.12 4110.10 30.00 90.90 MWD 10575.00 89.86 100.69 8962.25 1506.26 4250.48 5960939.52 658305.97 4135.05 30.00 90.90 MWD 10600.00 89.75 108.19 8962.33 1500.03 4274.67 5960933.78 658330.28 4159.62 30.00 90.89 MWD 10625.00 89.64 115.69 8962.4 7 1490.69 4297.84 5960924.93 658353.64 4183.39 30.00 90.86 MWD 10650.00 89.53 123.19 8962.65 1478.41 4319.60 5960913.10 658375.64 4205.94 30.00 90.82 MWD 10675.00 89.44 130.69 8962.87 1463.40 4339.56 5960898.50 658395.91 4226.91 30.00 90.77 MWD 10697.84 89.36 137.54 8963.11 1447.51 4355.95 5960882.95 658412.62 4244.36 30.00 90.70 4 10700.00 89.36 137.28 8963.14 1445.92 4357.41 5960881.39 658414.11 4245.93 12.00 271.00 MWD 10725.00 89.42 134.28 8963.40 1428.01 4374.84 5960863.84 658431.91 4264.57 12.00 271.00 MWD 10750.00 89.47 131.28 8963.65 1411.03 4393.19 5960847.24 658450.59 4284.06 12.00 271.03 MWD 10775.00 89.53 128.28 8963.86 1395.03 4412.39 5960831.64 658470.12 4304.33 12.00 271.06 MWD 10800.00 89.58 125.29 8964.06 1380.07 4432.41 5960817.09 658490.44 4325.35 12.00 271.09 MWD 10825.00 89.64 122.29 8964.23 1366.17 4453.19 5960803.62 658511.50 4347.04 12.00 271.11 MWD 10850.00 89.70 119.29 8964.37 1353.37 4474.66 5960791.27 658533.23 4369.36 12.00 271.13 MWD 10875.00 89.76 116.29 8964.48 1341.72 4496.78 5960780.07 658555.58 4392.23 12.00 271.15 MWD 10900.00 89.83 113.29 8964.57 1331.24 4519.47 5960770.06 658578.48 4415.60 12.00 271.16 MWD 10925.00 89.89 110.29 8964.64 1321.96 4542.68 5960761.26 658601.87 4439.40 12.00 271.18 MWD 10950.00 89.95 107.29 8964.67 1313.91 4566.35 5960753.70 658625.70 4463.57 12.00 271.18 MWD 10972.84 90.01 104.55 8964.68 1307.64 4588.31 5960747.88 658647.78 4485.92 12.00 271.19 5 10975.00 90.01 104.81 8964.68 1307.10 4590.40 5960747.38 658649.88 4488.04 12.00 90.00 MWD 11000.00 90.01 107.81 8964.68 1300.08 4614.39 5960740.85 658674.01 4512.46 12.00 90.00 MWD 11022.84 90.01 110.55 8964.68 1292.58 4635.96 5960733.80 658695.73 4534.50 12.00 90.00 6 11025.00 90.01 110.29 8964.68 1291.82 4637.99 5960733.08 658697.77 4536.58 12.00 270.00 MWD 11050.00 90.01 107.29 8964.67 1283.77 4661.65 5960725.52 658721.59 4560.74 12.00 270.00 MWD 11075.00 90.01 104.29 8964.67 1276.97 4685.71 5960719.21 658745.78 4585.21 12.00 270.00 MWD 11100.00 90.01 101.29 8964.67 1271.44 4710.08 5960714.18 658770.26 4609.92 12.00 270.00 MWD 11125.00 90.01 98.29 8964.67 1267.19 4734.72 5960710.44 658794.97 4634.79 12.00 270.00 MWD 11150.00 90.01 95.29 8964.66 1264.23 4759.54 5960707.99 658819.85 4659.76 12.00 270.00 MWD 11175.00 90.01 92.29 8964.66 1262.58 4784.48 5960706.85 658844.82 4684.75 12.00 270.00 MWD 11200.00 90.01 89.29 8964.66 1262.23 4809.4 7 5960707.02 658869.81 4709.71 12.00 270.00 MWD 11222.84 90.01 86.55 8964.66 1263.06 4832.30 5960708.32 658892.61 4732.42 12.00 270.00 7 11225.00 90.01 86.29 8964.65 1263.20 4834.45 5960708.50 658894.77 4734.56 12.00 271.60 MWD 11250.00 90.10 83.29 8964.63 1265.47 4859.35 5960711.28 658919.61 4759.24 12.00 271.60 MWD 11275.00 90.18 80.29 8964.57 1269.04 4884.09 5960715.35 658944.27 4783.67 12.00 271.60 MWD 11300.00 90.26 77.29 8964.47 1273.90 4908.61 5960720.71 658968.68 4807.79 12.00 271.59 MWD 11325.00 90.35 74.29 8964.34 1280.03 4932.84 5960727.34 658992.78 4831.53 12.00 271.58 MWD 11350.00 90.43 71.30 8964.17 1287.42 4956.72 5960735.22 659016.50 4854.84 12.00 271.56 MWD 11372.84 90.50 68.56 8963.99 1295.26 4978.17 5960743.50 659037.78 4875.69 12.00 271.54 8 11375.00 90.50 68.81 8963.97 1296.05 4980.18 5960744.32 659039.78 4877.64 12.00 90.00 MWD 11400.00 90.50 71.81 8963.75 1304.47 5003.72 5960753.22 659063.13 4900.53 12.00 90.00 MWD 11425.00 90.50 74.81 8963.53 1311.65 5027.66 5960760.89 659086.92 4923.92 12.00 90.03 MWD 11450.00 90.49 77.81 8963.32 1317.56 5051.95 5960767.30 659111.08 4947.73 12.00 90.05 MWD 11475.00 90.49 80.81 8963.10 1322.19 5076.51 5960772.44 659135.54 4971.91 12.00 90.08 MWD 11500.00 90.48 83.81 8962.89 1325.54 5101.28 5960776.29 659160.24 4996.39 12.00 90.11 MWD 11525.00 90.47 86.81 8962.68 1327.58 5126.19 5960778.84 659185.10 5021 .1 0 12.00 90.13 MWD 11550.00 90.47 89.82 8962.48 1328.31 5151.18 5960780.09 659210.07 5045.97 12.00 90.16 MWD 11575.00 90.46 92.82 8962.28 1327.74 5176.17 5960780.02 659235.06 5070.94 12.00 90.18 MWD 11600.00 90.44 95.82 8962.08 1325.86 5201.09 5960778.65 659260.02 5095.94 12.00 90.21 MWD 11602.84 90.44 96.16 8962.06 1325.56 5203.92 5960778.42 659262.85 5098.78 12.00 90.23 9 11625.00 90.44 93.50 8961.89 1323.70 5226.00 5960777 .01 659284.96 5120.93 12.00 270.00 MWD 11650.00 90.44 90.50 8961.70 1322.83 5250.98 5960776.65 659309.95 5145.91 12.00 269.98 MWD 11675.00 90.44 87.50 8961.50 1323.26 5275.97 5960777.60 659334.93 5170.81 12.00 269.96 MWD l_.." __..__..... ___,______ ___.__.__"'_____..'.___.._____..._ ___ .__ ________...______"___,_.__ ...___._._'.'_n..._________'_._..___" _____._,...__ ,___,__._ . --"---'-----------'--'-----' ~-'''--- .--. ---.---- ) ) 1"1'. SAKi_ MUGNU IN'I'EQ bp BP Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 12/11/2002 Time: 11 :08:38 Page: 4 Field: Prudhoe Bay Co,-ordinate(NE) Reference: Well: 0-30, True North Site: PB 0 Pad Vertical (TVD) Reference: System: Mean Sea Level Well: D-30 Section (VS) Ref~rence: Well (0.00N,O.00E,94.00Azi) Wellpath: Plan#2 D-30A Survey Calculation Method: Minimum Curvature Db: Oracle ----------- .----- Survey -----_._._.,.~._.__._--_.__...- --_._.~_._...._.- -"--.---.. MD Inel Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 OOft deg 11700.00 90.43 84.50 8961.31 1325.01 5300.91 5960779.85 659359.82 5195.57 12.00 269.93 MWD 11725.00 90.43 81.50 8961.13 1328.06 5325.72 5960783.41 659384.56 5220.10 12.00 269.91 MWD 11750.00 90.42 78.50 8960.94 1332.40 5350.33 5960788.25 659409.08 5244.36 12.00 269.89 MWD 11775.00 90.41 75.50 8960.76 1338.02 5374.69 5960794.38 659433.31 5268.26 12.00 269.87 MWD 11800.00 90.41 72.50 8960.58 1344.92 5398.72 5960801.76 659457.19 5291.75 12.00 269.84 MWD 11825.00 90.40 69.50 8960.40 1353.06 5422.35 5960810.38 659480.65 5314.76 12.00 269.82 MWD 11850.00 90.38 66.50 8960.23 1362.42 5445.53 5960820.22 659503.63 5337.22 12.00 269.80 MWD 11875.00 90.37 63.50 8960.07 1372.99 5468.18 5960831.25 659526.06 5359.08 12.00 269.78 MWD 11900.00 90.36 60.50 8959.91 1384.72 5490.25 5960843.43 659547.88 5380.28 12.00 269.76 MWD 11925.00 90.35 57.50 8959.75 1397.60 5511.67 5960856.74 659569.04 5400.76 12.00 269.74 TD --.-----.-- ) All Measurements are from top of Riser s.... Q) en .- Ct:: top of bag bUm of bag middle of slips Blind/Shears .......... ................ middle of pipes 2 -3/8" co m b i ra mls Ii ps .......................... ~ middle of flow cross Mud Cross ~ middle of blind/shears 2-3/8" x 3-1/2" VBR pipe rams r-- '---' .......................... middle of pipe/slips 2 -3/8" co m bi ra mls Ii ps .......................... Flow Tee .') 1111111111111111 BAG TOTs / Mud Cross ¡' TOTs . __~vuv DATE INVOICE I CREDIT MEMO 11/18/02 INV# CKll1402I DESCRIPTION DATE 11/18/02_ CHECK NO. P054968 GROSS VENDOR DISCOUNT NET PERMIT TO DRILL FEE \),30Pr THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF ALASKA OIL & GAS COMMISSION 333 W 7THAVENDE ANCHORAGE, AK( 99501 REEEIVED DEC 11 2002 Þ:aska 011 & Gas Gons. Commission Anchorage NATIONAL CITY BANK Ashland, Ohio No. p 054968 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT -..". - ".-.-' ."'. _.--. -. n" . .' .,",.";.u . -- --. . ..·.¡·..._~13-~·p~Jwr. t. u~ tmïf_;~:::;vj _:;.,_ .':, ... .Jf~ fJlÞ' ItlfØ..}t1tIU - "'Utl- DATE·'·-- AMÓUNT ~-J:r**;$Ioo.oo**** NQTVALlD AFTER 120 DAYS ._....~~~:\~:~.\::::.::::::~\:::~~~.:?~:::...~:.~~.~~~.~\::~:::~E\~~~:\ . ..:.::.~,::.~. .. .. .....__...:-.--.--.-.-......'.-..... .............. ...._.1 -....-..---- .:..:....:~ -..-- . ---·':;~S·'''·' :;'.' ~~ ":"':.! ¿;:\:::;;j~. .:i·::~é\{;:~~f~}::~}Ùiš;j¡ II- 0 5 ... q b 811- I: 0 L. ~ 20 :¡ 8 q 5 I: 0 ~ 2 ? 8 q b II- H ..-..."",...¡/ -~- ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit. No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 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 well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject 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) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ,)f.P,)::' WELL NAME PA'q ()-. ?oA PROGRAM: Exp _ Dev £ Redrll-X- Re-Enter _ Serv _ Well bore seg_ FIELD & POOL .c '/e/ S ð INIT CLASS /)....v /-0' ') GEOL AREA ?? C) UNIT# I) b S~ ON/OFF SHORE 0 A.J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . fY 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. W ell located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells. . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N fJ) ,""' J.. } B. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N /IT/~ /~ó.z.. 9. Operator only aftected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \:Þ N (Service Well Only) 13. W ell located wlin area & strata authorized by injection order # _ '! Y /\ ..J. .a , (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. /' N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y-N 16. Surface casing protects all known USDWs. . . . . . . -¥-N- . 17. CMT vol adequate to circulate on conductor & surf csg. Y N ¡vIA- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . -¥-N- 19. CMT will cover all known productive horizons. . . . . . . . . . ~N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N ~. ,\ 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N (/T /.J Vl. 22. If a re-drill, has a 10-403 for abandonment been approved. .. -it(;-y N 23. Adequate wellbore separation proposed.. ...' . . . .. . . . . @ N _, 24. If diverter required, does It meet regulations. ., . . . . . . . "¥-N- Nlft- I!) 1 25. Drilling fluid program schematic & equip list adequate. . . . . ~_ N m.. PLy" J11l+- u' Ppc¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N D v. Ii' i , APPR DATE 27. BOPE press rating appropriate; test t03 t5' 00 p sig. N M ~ , 2- 1 J -. P' l- ,. lJJ4Ä- 'Z.112-/"" 2--- 2B·. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N I¡ f.)I 29. Work will occur without operation shutdown. . . . . . . . . . . ð) N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 7:fJ N ,'!;. p(J M- 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N- N/k y<fi) H' N.A. (Service Well Only) GEOLOGY APPR DATE !t~" /06L (Exploratory Only) Rev: 10/15/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if oft-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... . GEOLOGY: RP~ RESERVOIR ENGINEERING JDH UIC ENGINEER JBR PETROLEUM ENGINEERING: TEM SFD WGA /' MJW G:\geology\perm its\checklist.doc COMMISSIONER: COT .CÆ-¡' l-t~~ DTS I~.J I Z- MLB "'~/;'..1'./c>~ ( Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To inlprove the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of infonnation. ) ) õ?œ-d(/O 1109'1 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 13:32:51 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . .. .03/04/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS 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-30A 500292264601 BP Exploration (Alaska) Inc. Sperry Sun 04-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-30002 S. LATZ SARBER MWDRUN 2 AK-MW-30002 S. LATZ EGBEJIMBA # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 23 11N 13E 3625 1066 MSL 0) 78.25 .00 .00 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10460.0 ') ) 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS - SUBSEA (TVDSS) . 3. WELL KICKED OFF FROM D-30 WITH TOP OF WHIPSTOCK SET AT 10460' MD, 8968' TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 WAS DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER GAMMA RAY LOG OF 01/10/2003, PER THE 1/27/2003 E-MAIL FROM D.SCHNORR (BP EXPLORATION). HEADER AND RUN INFORMATION DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-2 REPRESENT WELL D-30A WITH API # 50-029-202646-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11935' MD / 8963' TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS 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 $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 File Type.. .. .. .. .. . .. .. . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9808.0 9835.0 10729.0 10729.0 10729.0 10729.0 10729.0 STOP DEPTH 11887.0 11932.0 11900.5 11900.5 11900.5 11900.5 11900.5 # ) ) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9808.0 9804.5 9812.0 9808.5 9904.0 9902.5 9907.0 9905.0 9919.0 9917.0 10462.5 10461.5 10479.5 10477.5 10487.5 10485.5 10539.0 10538.5 10624.5 10623.5 10639.0 10638.0 10706.5 10706.5 10931.5 10931.5 11094.5 11093.0 11588.0 11590.5 11844.5 11847.0 11932.0 11935.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9832.0 10760.0 MWD 2 10715.5 11935.0 $ # REMARKS: MERGED MAIN PASS. $ # 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9808 11932 10870 4249 9808 11932 ROP MWD FT/H 2.18 1143.52 108.47 3108 9835 11932 GR MWD API 11.69 169.49 32.667 3114 9808 11887 RPX MWD OHMM 2.37 25.17 14.4441 2344 10729 11900.5 RPS MWD OHMM 3.56 27.53 15.7177 2344 10729 11900.5 RPM MWD OHMM 4.53 30.78 16.0817 2344 10729 11900.5 ) ') RPD MWD OHMM 7.63 25.97 15.6429 2344 10729 11900.5 FET MWD HOUR 0.17 7.25 0.83427 2344 10729 11900.5 First Reading For Entire File........ ..9808 Last Reading For Entire File......... ..11932 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 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...... .03/04/04 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 GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9832.0 10445.5 STOP DEPTH 10760.0 10731.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 07-JAN-03 Insite 4.3 Memory 10760.0 9804.0 10760.0 86.0 98.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # 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 ) 3.750 10460.0 Flo Pro 8.65 65.0 9.3 22000 6.8 .150 .070 .170 .170 65.0 138.0 65.0 65.0 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9832 10760 10296 1857 9832 10760 ROP MWD010 FT/H 2.53 148.9 72.909 770 9832 10760 GR MWD010 API 19.75 169.49 35.1696 573 10445.5 10731.5 First Reading For Entire File........ ..9832 Last Reading For Entire File......... ..10760 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 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...... .03/04/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 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 $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 10715.5 10729.0 10729.0 10729.0 10729.0 10729.0 10760.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11889.5 11903.5 11903.5 11903.5 11903.5 11903.5 11935.0 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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): 09-JAN-03 Insite 4.3 Memory 11935.0 10760.0 11935.0 84.4 93.4 TOOL NUMBER 78012 125361 3.750 10460.0 Flo Pro 8.80 65.0 9.0 20000 ') ') 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: 6.0 .150 .070 .170 .170 65.0 156.0 65.0 65.0 # 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 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 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 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10715.5 11935 11325.3 2440 10715.5 11935 ROP MWD020 FT/H 2.18 1143.52 120.007 2350 10760.5 11935 GR MWD020 API 16.37 144.76 33.0996 2349 10715.5 11889.5 RPX MWD020 OHMM 2.37 25.17 14.4554 2350 10729 11903.5 RPS MWD020 OHMM 3.56 27.53 15.728 2350 10729 11903.5 RPM MWD020 OHMM 4.53 30.78 16.0909 2350 10729 11903.5 RPD MWD020 OHMM 7.63 25.97 15.6491 2350 10729 11903.5 FET MWD020 HOUR 0.17 7.25 0.83403 2350 10729 11903.5 First Reading For Entire File......... .10715.5 Last Reading For Entire File......... ..11935 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/04 Maximum Physical Record. .65535 ) ') File Type.. .. .. .. .. .. .. .. LO Next File Name......... ..STSLIB.004 physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/04 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 Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 04 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