The URL can be used to link to this page

Home My WebLink About203-107 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q 3 - J 0 7 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 5 5" (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: (p / aCf /o(P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided 1111111111111I" III RESCAN ~olor Items: ~reYSCale Items: \ r~ DIGITAL DATA ~skettes, No. I D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date ~ / d-éj 10 b I I Date 10 / ;).7/ () ~ I I ~X30= 0 Date: (¡, 0 Project Proofing BY: ~ Scanning Preparation BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: 151 mf II 11111 1111I11 11111 151 m.L +~ = TOTAL PAGES 54- (Count does not include cover sheet) 151 11I11111111I11 11111 NO 151 V\1f NO 151 11/11111111I1111111 ReScanned BY: Maria Date: 151 Comments about this file: '" 11111111111 11111 Quality Checked III II 111I111 II 11111 1 0/6/2005 Well History File Cover Page. doc • • --, _~~`' . ~~ ~~~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CWrPgs_Inserts\Microfilm Marker.doc ;¿ Cf J~ Æ ~ \ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2031070 Well Name/No. PRUDHOE BAY UNIT A-30L1 Operator BP EXPLORATION (ALASKA) INC .5f!~ ¡l ~~~ API No. 50-029-21372-60-00 MD 11900 ,/ TVD 8926 ~. Completion Date 5/29/2004 ."., Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR Well Log Information: (data taken from Logs Portion of Master Well Data Maint Name Interval Start Stop Interval . Log Log Run OHI Scale Media No Start Stop CH Received Comments final 10700 11900 Open 7/24/2003 10809 11900 Open 2/22/2006 ROP DGR EWR plus Graphics 10773 11854 Open 1 0/3/2003 GR, EWR4, ROP - 10773 11854 Open 10/3/2003 GR, EWR4, ROP 10773 11854 Open 10/3/2003 GR, EWR4, ROP 10773 11854 Open 10/3/2003 GR, EWR4, ROP Sample Set Sent Received Number Comments . Daily History Received? ~N Formation Tops (Î)N Log/ Electr Data Digital Dataset Typ-," Med/Frmt Number Name ~t D Asc Directional Survey .-er)" C Lis 13622 Induction/Resistivity D ~'Jç 12202 Rate of Penetration D D )..a6t.JS 12202 Induction/Resistivity Rpt 12202 Rate of Penetration Rpt 12202 Induction/Resistivity Well Cores/Samples Information: ADDITIONAL INFOR~N Well Cored? Y tV Chips Received? ~ Analysis Received? ....x.m- Comments: Compliance Reviewed By: tio Date: ~j~~~ It . WELL LOG TRANSMITTAL ~D?J- J 07 To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 I~~"~ RE: MWD Formation Evaluation Logs A-30 Ll, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 A-30 Ll: LAS Data & Digital Log Images: 50-029-21372-60 1 CD Rom Q«~ ~) ~~IDlv } I STATE OF ALASKA . ALASKA L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .... 1a. Well Status: 0 Oil o Gas o Plugged 181 Abandoned o Suspended o WAG 1b. Well Class: 20MC 25.105 20MC25.110 181 Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions Zero Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/29/2004 203-107 303-180 & 304-142 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/27/2003 50- 029-21372-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/29/2003 PBU A-30L 1 3181' SNL, 1014' WEL, SEC. 35, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2499' SNL, 1694' EWL, SEC. 01, T10N, R13E, UM 80.88' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3349' SNL, 2317' EWL, SEC. 01, T10N, R13E, UM 3446 + 3341 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 654398 y- 5947265 Zone- ASP4 11900 + 8926 Ft ADL 047472 --,._--~--~ -~..--_.._-_.__. --- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 657203 y- 5942724 Zone- ASP4 --~---~------ "----~-- ------- NIA MD Total Depth: x- 657844 y- 5941888 Zone- ASP4 ---- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo NIA MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DËPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE Top BOTTOM IOÞ i tjOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2677' Surface 2653' 17-112" 3746 cu ft Permafrost 'E' & PF 9-5/8" 47# L-80 Surface 10752' Surface 8815' 12-1/4" 2065 cu ft Class 'G', 23ilCb.ft 'G' 7" 26# L-80 10496' 10790' 8609' 8846' 8-1/2" 254 cu ft Class 'G' \¡l'4'~¡Â' . ~-.;frlr"'J " ;" J . '" V ¡....r~;, 23. Perforations open to Production (MD + TVD of Top and 24. TUBING R~... 'Vb'/') ""'f;."J Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (M~I iii,,,, PAC~ER1~1. (MD) None 4-1/2", 12.6#, L-80 3500' - 10560' ~J.I'J.:'" CDn" 1 0443" MD TVD MD TVD wð~J>.., , "-...Q¡htñ¡ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3446' Set Bridge Plug & 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-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HOUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None {¡\US 1 1 'lnnl¡ RBDMS BfL c.J t¥. ~~~6( Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (, 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik 10779' 8837' None Sadlerochit 1 0880' 8914' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date C8 -05-0 PBU A-30L 1 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 203-107 303-180 & 304-142 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/24/2003 18:30 - 19:00 0.50 MOB P PRE Safety meeting prior to moving rig off of well F-26B. Hazards were discussed and mitigation to hazards was covered. NordiclSchlumberger proceedures as well as BP procedures for moving off the well were reviewed. 19:00 - 19:30 0.50 MOB P PRE Move rig forward off of well F-26B. 19:30 - 00:00 4.50 MOB N WAIT PRE Standby on weather. Current winds are 20 mph, gusting to 32 mph. Maximum for laying down derrick is 20 mph gusts. Standby until winds moderate. 6/25/2003 00:00 - 06:00 6.00 MOB N WAIT PRE Wait on weather, Wind at 16-25 MPH. 06:00 - 06:20 0.33 MOB N WAIT PRE Technical limits pre tour meeting for day crew. 06:20 - 14:30 8.17 MOB N WAIT PRE Wait on wind. 14:30 - 14:31 0.02 MOB P PRE Winds have moderated to the point where it is now safe to rig down the wind walls and derrick. Hold PJSM with all rig hands, visitors, temporary workers, rig management, and BP Co Reps. Discuss the proceedure, the hazards involved in this process and mitigations to the hazards. Simultanious operations by the welders will be halted until the rig down process is completed. Persons unneccessary to the operation will be in a safe area and will not interfer with the rig down. Off standby at 14:30 14:31 - 18:00 3.48 MOB P PRE Rig down wind walls and derrick. 18:00 - 18:30 0.50 MOB P PRE Crew change and safety meeting. 18:30 - 20:00 1.50 MOB N WAIT PRE Wait on security [busy with another rig move]. Wait on Nordic toolpusher change out. 20:00 - 20:30 0.50 MOB P PRE SAFETY MEETING. Pre-rig move meeting with Nordic, Security, CPS and tool service. Review rig move, location of power lines and rig matting. 20:30 - 00:00 3.50 MOB P PRE Move Nordic 1 to A pad. 6/26/2003 00:00 - 03:30 3.50 MOB P PRE Continue rig move from F pad to A pad. Arrive on A pad at 04:00. Good quick move, no problems. 03:30 - 04:00 0.50 MOB PRE SAFETY MEETING. Review procedure, hazards and mitigation for picking up derrick and wind walls. 04:00 - 06:00 2.00 RIGU P PRE Raise derrick and wind walls. Held PJSM prior to begining operations. 06:00 - 06:20 0.33 RIGU P PRE Technical limits meeting. Discussed accident on Nordic 2. 06:20 - 08:10 1.83 RIGU P PRE Bleed WHP from 60 psi to 0 (gas). S riser bilind flanged and FL bled to O. Rig up new cuttings box. 08:10 - 08:30 0.33 RIGU P PRE Safety meeting prior to moving rig over well. 08:30 - 08:45 0.25 RIGU P PRE Back rig over well. 08:45 - 10:30 1.75 RIGU P PRE ACCEPT RIG AT 10:00 HRS, 6/26/03. Nipple up BOP stack. Rig up IA and OA pressure moniters. IAP=138 psi, OAP=65 psi. Backing out time for stabbing pipe. 10:30 - 11 :35 1.08 RIGU P PRE Pick injector up out of stabbing box, adjust chains bracing the tree. Attach goose neck to injector. 11:35-12:15 0.67 RIGU P PRE Stab pipe. 12:15 - 12:50 0.58 RIGU P PRE Take fluid into pits. Taking on 290 bbls of 2% KCL with 1/2 #/bbl biozan. 12:50 - 14:00 1.17 RIGU P PRE Changeout packoffs on SWS injector. 14:00 - 18:30 4.50 BOPSU P PRE BOP test. Witness of BOP test waived by State of Alaska, Lou Grimaldi. Printed: 7/812003 1: 13: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/26/2003 18:30 - 19:30 1.00 RIGU P PRE Inspect injecter head chains. Found 1 broken link in chains. 19:30 - 21 :00 1.50 RIGU N SFAL PRE Maintenance time, no rig charge, Repair broken link in injector chains. Not able to do this during rig move because injector head is in pipe bay during derrick down rig move. 21 :00 - 21 :50 0.83 RIGU P PRE Maintenance on new hydraulic floor winch for internal CTC. 21 :50 - 23:00 1.17 STWHIP P WEXIT M/U BKR CTC. Pull test 40K, OK. Fill coil with Biozan water. 2.80 bpm, 1000 psi. Press test CTC with 3500 psi. 23:00 - 23:15 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for milling BHA M/U. 23:15 - 23:45 0.50 STWHIP P WEXIT M/U BHA #1. 3.80" HC Diamond window mill, 3.80" HC diamond string reamer, strait motor. BHA = 83.38 ft. 23:45 - 00:00 0.25 STWHIP P WEXIT RIH with milling BHA. Well is dead. Circ. freeze protect fluid in 4.5" tubing to tiger tank. 6/27/2003 00:00 - 01:15 1.25 STWHIP P WEXIT RIH with BHA #1, 3.80" diamond window mill and string reamer on straight motor. 01:15 - 01:45 0.50 STWHIP P WEXIT Set down wt at 8230', at GLM. Pick up RIH with 1.2 bpm, clean. Slow to 0.4 bpm and continue to RIH. Saw wt loss at next 2 GLM's. Stack wt at XN nipple at 10519' CTD. Correct depth to 10,503' BKB. [-16 ft CTD]. 01 :45 - 02:40 0.92 STWHIP N DPRB WEXIT Mill down across XN nipple, It was milled out to 3.80" with service coil on 06/20/03. Circ. 1.7 bpm, 650 psi, mill down easy with minimum motor work [0-50 psi], had 250 psi stall at 10502.4'. Pick up and ease down time milling again. 0-50 psi motor work. Stalled at 10,502.4'. Pick up. 02:40 - 03:30 0.83 STWHIP P WEXIT Some gas in returns, shut in well. SIWHP = 10 psi. Circ.2.0 bpm thru choke. Hold 500 psi whp while circ. bottoms up [100 bbl]. Circ. 120 bbls with returns to flowback tank. Stop pump, check for flow, no flow. Well dead. 03:30 - 04:30 1.00 STWHIP N DPRB WEXIT RIH to XN nipple. Time mill down with 0-50 psi motor work, 1.8 bpm, 720 psi. Back ream, some motor work. Ream down, 250 psi stall. Time mill down again. some motor work, 300 psi stall at 10,502.7'. Pick up and ream down again. RIH OK with not pump. Pick up thru clean with no pump. RIH clean. 04:30 - 04:50 0.33 STWHIP P WEXIT RIH to 10750'. Up wt = 38K, Dwn wt = 22K, RIH and tag top of BKR whipstock at 10785'. Pick up and ease down, 2.6 bpm, 1180 psi, Tag pinch point at 10790'. 04:50 - 06:00 1.17 STWHIP P WEXIT Milling 3.80" window thru 7", 26# liner. Flag CT at 10,790'. 2.6 /2.6 bpm, 1180-1400 psi, Milled to 10,791.3 ft. 06:00 - 06:30 0.50 STWHIP P WEXIT Milling 3.80" window, 2.6/2.6 bpm, 1180-1400 psi, Milled to 10,791.8' 06:30 - 07:30 1.00 STWHIP P WEXIT 10791.8', Milling ahead. 2.6/2.6/1239 psi. Free spin=1180 psi at 2.6 bpm. Pit vol=283 bbls. IAP=366, OAP=95 psi. 07:30 - 08:30 1.00 STWHIP P WEXIT 10792.7', Milling ahead. 2.5/2.5/1214 psi. Pit Vol=282 bbls, IAP=368, OAP=98 psi. 08:30 - 09:30 1.00 STWHIP P WEXIT 10794.1', Milling ahead. 2.5/2.5/1239 psi. Pit Vol=283 bbls, IAP=389, OAP=100 psi. 09:30 - 10:30 1.00 STWHIP P WEXIT 10,794.9'. Milling ahead. 2.5/2.5/1218 psi. Pit Vol=282 bbls, IAP=379, OAP=103 psi. 10:30 - 11 :30 1.00 STWHIP P WEXIT 10,795.7'. Milling ahead. 2.6/2.6/1300 psi. Pit Vol=282 bbls, IAP=386, OAP=105 psi. 11:30-12:10 0.67 STWHIP P WEXIT 10796.6', Milling ahead. 2.6/2.6/1415 psi. Pit Vol=283 bbls, Printed: 7/8/2003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/27/2003 11:30-12:10 0.67 STWHIP P WEXIT IAP=394, OAP=107 psi. Possibly exited window with mill at 10796.3'. Continue time milling until string reamer exits. 12:10 - 13:25 1.25 STWHIP P WEXIT Thru casing, mill rathole from 10797.4'. Milling formation at 15 fph. 13:25 - 14:05 0.67 STWHIP P WEXIT 10806.0', 10' of rathole. Backream window while pumping 20 bbl sweep of 2# biozan. Dry drift down thru window. Window depth 10790'-10796.3' TD=10806'. 14:05 - 14:30 0.42 STWHIP P WEXIT Swap to mud. Continue reaming. 14:30 - 16:25 1.92 STWHIP P WEXIT POH with milling BHA. 16:25 - 17:00 0.58 STWHIP P WEXIT Tag up at surface, stand back injector, lay down milling BHA. Secure well. 17:00 - 18:15 1.25 DRILL P PROD1 Safety stand down. Discuss results of first day of safety observations. Cover other items including CTD safety history of the past 6 months. 18:15 - 19:15 1.00 DRILL P PROD1 SAFETY STAND DOWN WITH NIGHT CREW. Review Nordict 2 incident and action items. Review other safety allerts. Finished with Tech Limits meeting for night operations. 19:15-19:30 0.25 DRILL P PROD1 SAFETY MEETING. Reviewed procedure, hazards and mitigation for C/O CTC. 19:30 - 20:00 0.50 DRILL P PROD1 C/O BKR CTC for DS CTC. Pull test and press test. 20:00 - 20:15 0.25 DRILL P PROD1 SAFETY MEETING. Reviewed procedure, hazards and mitigation for MWD BHA M/U. 20:15 - 21:15 1.00 DRILL P PROD1 M/U MWD BHA #2. 2.29 deg motor, HYC Bi-Center Bit. Total Length = 64.8 ft. 21 :15 - 23:15 2.00 DRILL P PROD1 RIH with MWD BHA. Shallow test tools. RIH. 23:15 - 23:30 0.25 DRILL P PROD1 Orient TF to 15L. 23:30 - 23:40 0.17 DRILL P PROD1 Ran thru window clean. Tag TD at 10,823' CTD, correct depth to 10806'. [-17']. 23:40 - 00:00 0.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3020-3500 psi, 5L TF, 37 incl, 20 fph, Drilled to 10,807'. 6/28/2003 00:00 - 02:30 2.50 DRILL P PROD1 Drilling build section in Shublik. 2.6/2.6 bpm, 3000 - 3600 psi, several stalls, high side TF, Drilled to 10,839 ft. 02:30 - 05:00 2.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3800 psi, 10L TF, Drilled to 10,862'. 05:00 - 05:45 0.75 DRILL P PROD1 Log Tie-in with GR to RA tag to original BHCS/GR log. Added 3 ft to CTD. 05:45 - 06:30 0.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3800 psi, 10L TF, Drilled to 10,874'. 06:30 - 07:30 1.00 DRILL P PROD1 10874', Drilling ahead 2.6/2.6/3010 psi. Free spin 2800 psi. Pit vol=317 bbls. IAP=429 psi, OAP=129 psi. 07:30 - 08:10 0.67 DRILL P PROD1 10909', Entered Zone 4. Encountered losses. 2.6/1.8/3150. Loosing .5 to 1 bbl/min. Plan to drill ahead and see if they heal. MI notified to mix another system on standby. 08:10 - 09:45 1.58 DRILL P PROD1 10944', Wiper trip to shoe to allow geo to discuss well plan with town. Moter did not give us enough build in the shublik. We will come in 6' deep to plan. Discuss whether this is adiquate, whether we need to trip for a bigger motor, or to set an OH whipstock. Printed: 7/8/2003 1: 13: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/28/2003 09:45 -10:10 0.42 DRILL P PROD1 Resume drilling. 2.6/2.1/3200 psi. Still have 0.5 bpm losses. Pit vol=295 bbls. 10:10 - 10:55 0.75 DRILL P PROD1 Sticky pickup. Make wiper trip to shoe. 10:55 - 12:50 1.92 DRILL P PROD1 11036', POOH with build section BHA. Well is landed horizontally. Trip for 1.04 deg motor, 3.75" PDC bit and RES tool. Pit vol=240 bbls when POOH. 12:50 - 13:05 0.25 DRILL P PROD1 Tag up at surface with BHA. Hold pre task safety meeting prior to laying BHA down. 13:05 - 13:30 0.42 DRILL P PROD1 Lay down BHA #2. Bit recovered 0,2 with 1 chipped cutter on the gauge. 13:30 - 13:50 0.33 DRILL P PROD1 Safety meeting prior to cutting coil for pipe management. 13:50 - 15:00 1.17 DRILL P PROD1 Cut coil to move wear spot from window downhole. 15:00 -16:15 1.25 DRILL P PROD1 Attach SWS coil tubing connector. Pull test to 35k Ibs ok. Pressure test to 3500 psi ok. 16:15 - 16:30 0.25 DRILL P PROD1 PJSM making up BHA. 16:30 - 17:20 0.83 DRILL P PROD1 MU BHA #3, DS49 bit, 1.04 deg BHI motor, MWD/GR, RES. Program RES tool. 17:20 - 19:20 2.00 DRILL P PROD1 RIH with BHA #3, Shallow hole test at 500', OK. RIH. 19:20 - 19:30 0.17 DRILL P PROD1 RIH clean to 10730 ft. Orient TF to High side to exit window. 19:30 - 19:45 0.25 DRILL P PROD1 Run thru window clean, RIH clean to TD. Tag at 11062 ft and correct depth to 11,036'. [-26 ft CTD]. 19:45 - 22:00 2.25 DRILL P PROD1 Log MAD pass up to window with Sperry RES/GR tool. 3 fpm, Added 6 ft to CTD at RA tag. RIH and tag TD at 11,041'. 22:00 - 22: 15 0.25 DRILL P PROD1 Orient TF to 90L. 22:15 - 00:00 1.75 DRILL P PROD1 Drilling, 2.7/2.2 bpm, 2750 - 3300 psi, 80L, 92 deg incl. Drilled to 11,134 ft. Landed well at 11,036 ft at 8889.6 ft. Plan to drill lateral at 92 deg incl. to top of Z4. 0.5 BPM fluid loss while drilling. 6/29/2003 00:00 - 00:30 0.50 DRILL P PROD1 Drilling Zone 4, 2.7/2.2 bpm, 3000 - 3600 psi, 93 deg incl, Drilled to 11,157'. 0.5 BPM mud loss. Not getting better. 00:30 - 01 :00 0.50 DRILL P PROD1 Wiper trip to window. Clean trip. RIH clean to TD. 01 :00 - 03:00 2.00 DRILL P PROD1 Drilling, 2.7/2.2 bpm, 3000 - 3600 psi, 92 deg incl, 0.5 BPM mud loss. Drilled to 11,220'. 03:00 - 04:00 1.00 DRILL P PROD1 Drilling, 2.7/2.2 bpm, 2900 - 3600 psi, 92 deg incl, 0.5 BPM mud loss. Drilled to 11,285'. 04:00 - 05:20 1.33 DRILL P PROD1 Wiper trip to window. Circ. 30 bbl LCM pill with 10# fine and 10# medium LCM to treak loss zone at 10,909'. Lay in LCM pill from 10950 - 10850'. Park Bit at 10905' and squeeze 5 bbls away at 0.5 bpm. Circ. 0.9 bpm with 0.8 bpm returns. Circ. 2.2 bpm with 2.0 bpm returns, slight improvement. 05:20 - 06:00 0.67 DRILL P PROD1 Drilling, 2.6/2.2 bpm, 2900 - 3600 psi, 93 deg incl, 0.4 BPM mud loss. Drilled to 11,320'. 06:00 - 06:30 0.50 DRILL P PROD1 Orient TF to SOL. 06:30 - 06:40 0.17 DRILL P PROD1 11344', Drilling ahead at 2.7/2.2/3260 psi. Free spin 2800 psi. Pit vol=293 bbls, 75 bbls left on standby vac truck. IAP=52, OAP=122 psi. lAP is 350 psi less than yesterday's. Inspect tree, no problems found. Something changed. Tried varying pump rate and monitoring lAP. As pumps come down, lAP drops 20 psi. 06:40 - 07: 10 0.50 DRILL N DPRB PROD1 11347', Begin pumping LCM pill. PUH slowly to loss area at Printed: 7/812003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/26/2003 7/2/2003 N1 Spud Date: 6/6/1985 End: 6/29/2003 06:40 - 07:10 0.50 DRILL N DPRB PROD1 10909'. Pump 30 bbls with 18 sx medium, 6 sx fine. Position bit at 10909', pump 1 bbl out nozzle, SI chokes. Pump at 1/2 bbls/min. Got 6.2 bbls away for a 1000 psi squeeze. Pressure started breaking back over at that point, so didn't want to fraq fluid away. Opened choke slowly, and ran to bottom to continue drilling. BBLS AWAY WHP lAP 1.5 0 59 1.9 600 66 3.3 905 71 4.8 1007 71 6.3 1054 68 07:10 - 07:30 0.33 DRILL P PROD1 Run back to bottom. Resume drilling. 07:30 - 08:05 0.58 DRILL P PROD1 Resume drilling. 2.6/2.3/3260 psi. Pit vol=277 bbls. 08:05 - 08:15 0.17 DRILL P PROD1 Orient to right side. 08: 15 - 09:00 0.75 DRILL P PROD1 Resume drilling. IAP=93 psi, OAP=125 psi. 2.6/2.3/3200 Pit vol @ 8:45=316 bbls. 09:00 - 09:40 0.67 DRILL P PROD1 Sticky on bottom. Wiper trip to shoe. 09:40 - 11 :25 1.75 DRILL P PROD1 Resume drilling. IAP=94 psi, OAP=124 psi. 2.6/2.3/3240 psi. Pit vol=300 bbls. 11:25-12:15 0.83 DRILL P PROD1 11602', Wiper trip to shoe. 12:15 - 13:00 0.75 DRILL P PROD1 Resume drilling, Getting lots of reactive torque (200 deg)! May be on a fault. 2.7/2.4/3360 psi. 13:00 -13:10 0.17 DRILL P PROD1 11646', Orient. Pit vol down to 240 bbls, order a truck of mud to top off pits. 13:10-13:30 0.33 DRILL P PROD1 Resume drilling. 2.6/2.4/3450 psi. Pit vol=226 bbls. 13:30 - 13:45 0.25 DRILL P PROD1 11701', Orient to the left side. 13:45 - 14:10 0.42 DRILL P PROD1 Resume drilling. 14:10- 14:55 0.75 DRILL N DPRB PROD1 11730', Bottom fell out. Returns went to 50%. 2.6/1.4/2100 psi. Pick up off bottom, then returns went to O. Pull to the shoe. No returns. Order a 2nd truck of mud. 155 bbls in pits. Instruct MI to keep 580 bbls mixed at mud plant at all times. Pulling heavy. Kick pump rate up to war emergency. Pumping at 3.0 bpm. Continue to pull to the tubing tail. 14:55 -15:40 0.75 DRILL N DPRB PROD1 Up in tubing tail. Go to pumping accross the top to keep the hole full. Continue POH with BHA at slow rate. Took 12 bbls to fill hole. 14:57,89 bbls in pits. 15:02, 86 bbls 15:05, 80 bbls 15:10,66 bbls 15:20, 50 bbls, Sure be nice to have those trucks on location soon. 15:35, 18 bbls, Vac truck #1 on location. 15:40 -17:15 1.58 DRILL N DPRB PROD1 Swap back to pumping down the coil, RIH slowly (14 fpm), while they mix an LCM pill. Mixing 20#/bbl medium Mix II into 30 bbls of new mud. (24 sx). This is maximum concentration that Sperry indicates is acceptable for their tool. 17:15 -18:10 0.92 DRILL N DPRB PROD1 Pump 30 bbl LCM pill with 20 #/bbl of Mix II medium. Chase with mud. Displace pill to BHA at 2.6 bpm, 0 whp. LCM to formaiton and started building pressure. Put 18 bbls away at 1 bpm, last 10 at 0.5 bpm. Built sqeeze pressure of 850 psi. Open choke, bring rate up to 2.6 bpm. Getting returns! Printed: 7/8/2003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/29/2003 18:10 - 19:00 0.83 DRILL P PROD1 Start drilling at 11740'. 2.4/1.9/2850 free spin. Tag bottom, make -7' correction. Begin drilling. Drilled 6.8', then lost returns again. 2.4/0.0/2100 psi. Full losses. Drilled to 11,820'. 19:00 - 20:00 1.00 DRILL P PROD1 Drilling, Full losses. 2.5 / 0.0 bpm, 2000 psi, [very low circ press - 900 psi below normal press with returns]. Drilled to 11,900'. Fluid loss zone at 11,730'. Very clear on RES/GR log. 20:00 - 23:00 3.00 DRILL N DPRB PROD1 POH. Flag CT at 11,690'. [11,600' EOP]. Back ream open hole to window, 2.3/0 bpm, 1650 psi. Clean hole to window. POH, fill hole from backside. 23:00 - 23:15 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review procedure, hazrds and mitigation to UO MWD BHA and download RES/GR data. 23:15 - 00:00 0.75 DRILL N DPRB PROD1 UO MWD BHA. Download memory data from Sperry RES/GR. Filling well across the top with 2% KCL water. 1.0 bpm loss with OWHP. 6/30/2003 00:00 - 00:30 0.50 DRILL N DPRB PROD1 UO MWD BHA with Sperry RES/GR tool. Recovered good memory data. Fill hole across top with 2% KCL water. 1.0 bpm, No returns. 00:30 - 00:40 0.17 DRILL N DPRB PROD1 SAFETY MEETING. Review procedure, hazards and mitigation to M/U CMT Nozzle BHA. 00:40 - 01 :00 0.33 DRILL N DPRB PROD1 M/U big hole nozzle [0.75"] Cementing BHA. Total Length = 70.0 ft. 01 :00 - 02:50 1.83 DRILL N DPRB PROD1 RIH with Cementing Nozzle BHA. Pump 0.5 bpm while RIH at 105 fpm. No returns. 02:50 - 03:30 0.67 DRILL N DPRB PROD1 Run thru window at 10790'. Pull back thru as safety check. OK. RIH clean to Flag, correct depth [-12 ft] to 11,670'. RIH and Tag TD at 11,901 ft. Dwn wt = 24K. Up Wt = 42K. 03:30 - 03:45 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for Pumping cement for lost returns. 03:45 - 04: 1 0 0.42 DRILL N DPRB PROD1 Circ. with 2% KCL water at 3.3 bpm, 1800 psi, looking for returns, Reciprocate CT, Had 10K overpull at loss zone with FloPro in open hole and in CT [20 bbls KCL water pumped]. Will not go below 11,720' with nozzle again. Pump 80 bbls, 3.3 bpm, no returns. 04:10 - 05:00 0.83 DRILL N DPRB PROD1 Stg 3 bbl water. Stg 30 bbl, 13.8 ppg, 4% Bent / G CMT, 3.1 bpm, 1500 psi. no returns. Stg 20 bbl, 13.8 ppg, 4% Bent / G CMT w/ 15 PPB Aggregate, 3.8 bpm, 2100 psi Stg 10 bbl, 13.8 ppg, 4% Bent / G CMT, 3.8 bpm, 2000 psi, no returns. CMT at Nozz at 56 bbls. Slow pump to 1.2 bpm, lay in CMT. Stg water to displace, lay in 1 for 1. 25 bbl, displ. Nozz at window, inc. rate to 2.5 bpm, No returns. 56 bbl displ, Nozz at 10,150', CT fully displaced, stop pump. Pull to safety. Cemt in place. 0500 hrs. 05:00 - 05:25 0.42 DRILL N DPRB PROD1 Pull to safety. No pump. Let cement thicken. 05:25 - 06:20 0.92 DRILL N DPRB PROD1 Nozz at safety, Circ. KCL water to fill hole, no returns. 2.5 bpm, 1150 psi, RIH to cleanout cement with Biozan water. 30 bbls. RIH to 10100 ft. No cement, No returns. Printed: 7/8/2003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/30/2003 06:20 - 07:15 0.92 DRILL N DPRB PROD1 Cleanout hole of residual cement. Tag up at 11467'. Worked it a couple of times, and could not get thru. Sticky on pickup. 07:15 - 08:00 0.75 DRILL N DPRB PROD1 Pull up to the window. 08:00 - 08:55 0.92 DRILL N SFAL PROD1 Stopped moving coil. Bushing on coil reel failed. SWS making repairs to reel. Continue pumping down the backside to keep hole full. 08:55 - 10:45 1.83 DRILL N DPRB PROD1 PUH slowly, still pumping down the backside, waiting on crude. 10:45 - 11 :05 0.33 DRILL N DPRB PROD1 Safety meeting prior to pumping crude. Held in ops cab with rig crew, SWS crew, Veco truck driver. Discussed hazards of pumping crude. Need to check vapor pressure of crude, and limit of 1.5 psi for pumping crude thru coil. Shut down all rig hot work permits. 11:05-12:10 1.08 DRILL N DPRB PROD1 Pump 110 bbls of crude down the backside. 12:10 - 12:30 0.33 DRILL N DPRB PROD1 PJSM to discuss the cement job. 12:30 - 14:45 2.25 DRILL N SFAL PROD1 Small leak on sws lubricator between injector and lubricator quick union. Can not fix the leak as it is, and should not continue with the job, in case the leak should get worse. Close annular, pump 2% KCL to kill well prior to POH. 14:45 - 16:30 1.75 DRILL N SFAL PROD1 Open annular bag, POH with cementing BHA to repair SWS lubricator. 16:30 - 16:45 0.25 DRILL N SFAL PROD1 Safety meeting prior to standing back injector. 16:45 - 18:00 1.25 DRILL N SFAL PROD1 Stand back BHA. Pull defective lubricator pup. It had an obvious corrosion ring in the box end where the oring seats. PU a new pup. Stab injector back on w/o BHA. PT against a closed swab valve to 100 psi and 3500 psi. 18:00 - 18:20 0.33 DRILL N SFAL PROD1 M/U Cementing nozzle BHA. Total length = 70 ft. 18:20 - 20:00 1.67 DRILL N SFAL PROD1 RIH with cementing nozzle BHA. Circ. at 0.3 bpm. FULL RETURNS. RIH to window. Full returns at window at 0.5 BPM. Ran out window. Returns dropped to 70%. 20:00 - 20:30 0.50 DRILL N SFAL PROD1 RIHtoPBTD. Tag at 11506'. Correct [-13 ft] and call PBTD at 11,493'. Up wt = 42 k. Dwn wt. 22K. 1.1 /0.9 BPM, 80 % returns. Pump 2.2 / 1.8 bpm, 80% returns. Pump 3.0 bpm with 80% returns. 20:30 - 22:10 1.67 DRILL N DPRB PROD1 Rig back on clock. POH. Overpull at 11410', Work thru. Overpull at 11200'. Work thru. Overpull at 11170'. Work thru. Appear to have clay ball on BHA. Overpull at 11080'. Pull into 4.25" hole, Pull up thru window. 2.5/2.0 bpm, 1800 psi. Pull up thru tailpipe pumping at 3.4 / 2.4 bpm to clean off clay from BHA. RIH to wid now pumping 3.4 BPM. 22:10 - 22:30 0.33 DRILL N DPRB PROD1 RIH pumping 3.3 bpm to 10900', clean, RIH to 11000', pick up clean. RIH to 11,100'. Clean 39K up wt. RIH to 11,110' stack wt, see overpull. work pipe. Clean hole above 11,100'. Will treat fault from that depth. 22:30 - 22:45 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for Pumping Cement SQZ. 22:45 - 23: 15 0.50 DRILL N DPRB PROD1 Cement at 13.8 PPG at 22:55 hrs. STG 3 bbl water spacer STG 5 bbl, 13.8 ppb, 4% Bentonite / G CMT STG 10 bbl, 13.8# Bent / G CMT with 1.5 PPB SWS CemNet Fiber Printed: 7/8/2003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 6/30/2003 22:45 - 23:15 0.50 DRILL N DPRB PROD1 STG 5 bbl, 13.8 ppb, 4% Bentonite / G CMT STG 10 bbl, 13.8 ppb, 4% Bentonite / G CMT with 15 PPB SWS aggregate. STG 16 bbl, 13.8 ppb, 4% entonite / G CMT Total Cement Volume = 6 Is. 23: 15 - 23:30 0.25 DRILL N DPRB PROD1 Displace with rig water 3 bpm, 2000 psi, using DS CMT pump. Nozzle at 11,100 ft. Close choke with 5 bbls displacement [Cement 5 bbl short of nozzle]. Cmt at nozzle, slow pump to 2.1 bpm, P Press = 550 psi, SIWHP = 640 psi. 15 bbl displacement, 5 bbl CMT out nozz, Pulling heavy at 11,080', slow pump to 1 BPM. Pull free and pull CT up to 10,928' and pull tight again [first lost returns seen during drilling was at 10,909']. Work pipe and pump rate. 28 bbls water displacement behind CMT. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Fiber / Aggregate plugged in BHA while pumping at 1 bpm, [most likely at 0.70" ID nozzle, DS hyd disconnect ID = 0.93"]. Unable to circulate. 28 bbls diplacement places 10 bbl Fiber CMT out nozzle and 3 bbl Neat cement out nozzle with 2 bbl neat CMT, 10 bbl Agg CMT and 16 bbl neat CMT inside coil. Coil capacity = 55.7 bbls. 28 bbls cement inside coil and 18 bbls out side nozzle. Press up to 4000 psi, not able to circulate. Work CT. Nozzle stuck at 10,928 ft. 7/1/2003 00:00 - 00:30 0.50 DRILL N STUC PROD1 Stuck Pipe, CT CMT nozzle at 10,928'. Unable to work free. Fault at 10,909'. Cement node at this depth. Unable to pump down coil, Fiber and Aggregate plugged nozzle. Attempt to Reverse circ to clean plugged nozzle. Able to pump down back side, 2.5 bpm, 2200 psi. Nozzle still plugged. Work CT. CT still stuck at 10,928'. 00:30 - 01 :30 1.00 DRILL N STUC PROD1 Pump down CT with DS cement pump to 6000 psi, still plugged. Bleed to 0 psi, Press up to 6000 psi, total of 5 times. Hyd Disconnect did not release. Plug at nozzle, not at disconnect. 01 :30 - 02:00 0.50 DRILL N STUC PROD1 Pump FloPro down back side, 2.5 bpm, 2200 psi, Work CT Max up and down. Still stuck. Bleed off all press and work CT at max up and down. Stuck. 02:00 - 04:15 2.25 DRILL N STUC PROD1 Order 15% HCL Acid to soak on BHA. Work pipe and pump down backside while waiting for acid to arrive. Pull to 100K on CT, [90%]. Still stuck. 28 bbls CMT inside coil. 04:15 - 04:30 0.25 DRILL N STUC PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for pumping HCL acid. 04:30 - 05:10 0.67 DRILL N STUC PROD1 Pump 30 bbl water spacer dwn CT X 4.5" tbg ann. 2.3 bpm, 1940 psi. Pump 40 bb115%, HCL Acid. 2.2 bpm, 1900 psi. Pump 20 bbl water spacer behide. 2.1 bpm, 1650 psi. Total volume = 90 bbl. 05:10 - 06:30 1.33 DRILL N STUC PROD1 Displace with FloPro with rig pump. total vol to place acid at fish = 52.5 bbl. Printed: 7/8/2003 1:13:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 7/1/2003 05:10 - 06:30 1.33 DRILL N STUC PROD1 10 bbls displ, 2.0 bpm, 1650 psi, 20 bbls displ, 2.1 bpm, 1680 psi. 40 bbls displ, 2.1 bpm, 1650 psi. 52.5 bbls, acid at fish, pump 10 bbls at 0.3 bpm, work pipe. Still stuck. Let acid soak on cement. 06:30 - 10:00 3.50 DRILL N STUC PROD1 Pump 5 bbls past stuck point down hole at 0.5 bpm, then SD and let soak again. Repeat at 07:00, 07:30, 08:00, 08:30, 09:00,09:30. At 10:00 pull to 100 klbs and hold 5 minutes. Repeat. No movement, or sign of success. 10:00 - 13:15 3.25 DRILL N STUC PROD1 Sent acid transport back to Schlumberger for more acid. Will repeat acid soak with 60 bbls of 28% acid. This is a stronger concentration and a larger volume than the first attempt. Wait on acid. 13:15 - 13:50 0.58 DRILL N STUC PROD1 Acid transport on location. Spot in transport. Back shower trailer in next to transport. Confirm with BP rep and SWS rep that shower trailor is functioning. Hold PJSM with cementers, rig SWS and Nordic personnel, Veco vac truck driver. Talk about job proceedure, hazards, and mitigation. 13:50 - 15:00 1.17 DRILL N STUC PROD1 PT cementers hardlines to 4000 psi, passed ok. On line with water preflush. Pump 30 bbls rig fresh water at 3 bpm, 1700 psi. Pump 60 bbls of 28% HCL acid at 3 bpm, 1850 psi. Pump 20 bbls rig fresh water at 3 bpm, 1800 psi. Pump 40 bbls 2% mKCL water as displacement fluid. 120 bbls to lead of acid. 8 bbls past fish. Let acid soak. 15:00 - 18:00 3.00 DRILL N STUC PROD1 Pump 5 bbl displacement 2% KCL each 30 min. Work CT to -10K to +100K. Still stuck. 18:00 - 21 :00 3.00 DRILL N STUC PROD1 Pump 5 bbl displacement 2% KCL each 30 min. Work CT to -10K to +100K. Still stuck. 21 :00 - 21 :45 0.75 DRILL N STUC PROD1 Over-displace acid to upper fault with 50bbls of 2% KCL water @ 3.8bpm/1420psi. Work CT from -10k to 95k - no luck. Meanwhile spot SWS E-line unit. 21 :45 - 22:30 0.75 FISH N STUC PROD1 PJSM & HA/HM with SWS E-line crew & all personnel on CT chemical cutting operations. 22:30 - 00:00 1.50 FISH N STUC PROD1 RlU & prep for cutting CT @ surface & stripping up injector. Assemble & check required tools. Call for 2-3/8" hand slips. Meanwhile establish static loss rate of 35bbls/hr. Call for 2% KCL water. 7/2/2003 00:00 - 01 :00 1.00 FISH N STUC PROD1 W.O. 2-3/8" hand slips (from Baker fishing) & KCL water. 01 :00 - 01 :45 0.75 FISH N STUC PROD1 Pull CT to 26k - 5k above neutral wt. Close upper combi rams. S/O to Ok & P/U back to 5k over to engage slips. Close manual lock downs on rams. 01 :45 - 02:00 0.25 FISH N STUC PROD1 P/U injector & strip 5' above well. Install C-plate, slip bowl, hand slips, & dog collar on CT. 02:00 - 02:25 0.42 FISH N STUC PROD1 Install hot-tap on CT. Hot-tap & drain CT. RID hot-tap. 02:25 - 03:00 0.58 FISH N STUC PROD1 RlU hydraulic cutter & cut CT. Set back injector. Dress up & bevel edges of cut CT. 03:00 - 04:00 1.00 FISH N STUC PROD1 M/U grapple CTC, block valve & pump in sub. RlU sling from bails to tbg elevators for 200k pull. Pressure test CTC to 1000psi - no leaks. Pull test to 31 k - OK. Back out manual locks & open upper combi rams. Printed: 7/8/2003 1:13:18 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/26/2003 Rig Release: 7/2/2003 Rig Number: N1 Spud Date: 6/6/1985 End: 7/2/2003 04:00 - 05:00 1.00 FISH N STUC PROD1 RlU SWS E-line tools. Hang sheave from derrick. M/U packoff. 05:00 - 05:15 0.25 FISH N STUC PROD1 RIH with 1-11/16" x 13' dummy drift wt bar on E-line & tag TOC solid @ 3765'ELM. 05:15 - 05:45 0.50 FISH N STUC PROD1 Paint flag @ 3665'ELM. POOH & UD E-line tools. 05:45 - 06:30 0.75 FISH N STUC PROD1 Tech limit meeting, crew change & PJSM for RIH chemical cutter. 06:30 - 09:30 3.00 FISH N STUC PROD1 RIH with Chemical cutter. Cut coil at 3600' as planned. 09:30 - 09:45 0.25 FISH N STUC PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for recover Chem cutter and rig down SWS. 09:45 - 10:30 0.75 FISH N STUC PROD1 Rig down SWS E-line equipment. 10:30 - 11 :30 1.00 FISH N STUC PROD1 Rig up to M/U weld on internal flush CTC to pull 3600' of CT. Gave tour of rig to BP Personnel. 11 :30 - 11 :45 0.25 FISH N STUC PROD1 SAFETY MEETING. Review procedure, hazards and mitigation to weld on CTC. 11:45 -13:15 1.50 FISH N STUC PROD1 M/U SWS internal weld on CTC to each end of CT. Grind welds smooth. 13:15 -15:00 1.75 FISH N STUC PROD1 POH with 3600 ft of 2-3/8" coiled tubing. No problems. Bull head freeze protect tubing with 30 bbls of MEOH. Well on vacuum. 15:00 - 15:15 0.25 RIGD N STUC PROD1 SAFETY MEETING. Review procedure, hazards and mitigation to blow down reel with N2. 15:15 - 16:00 0.75 RIGD N STUC PROD1 Blow down CT with N2 & bleed off. 16:00 -17:30 1.50 RIGD N STUC PROD1 PJSM. Remove injector gooseneck & unstab coil. Meanwhile cleanout pits & tanks. 17:30 - 18:45 1.25 RIGD N STUC PROD1 Pull back CT to reel & secure reel for swap. 18:45 - 19:45 1.00 RIGD N STUC PROD1 PJSM. RID & store injector in stabbing bay. 19:45 - 21 :15 1.50 RIGD N STUC PROD1 PJSM. N/D BOP. N/U & P/Test tree cap. Release rig @ 21 :15 on 07/02/03. From rig acceptance to rig release = 6.47days. Printed: 7/812003 1: 13: 18 PM Well: Field: API: Permit: e e OS/27/04 05/30/04 07/07/04 Nabors 7ES 04/28/04 DRIFT WI 3.77 SWEDGE SBSD @ 3592' SLM (CT TOP) POOH (SB EMPTY). DRIFT WI 3.80 GR I SD @ 3592' SLM. POOH. RDMO. A-30A Prudhoe Bay Unit 50-029-21372-01-00 204-078 Accept: Spud: Release: Ri: PRE-RIG WORK 05/07/04 SET HALIBURTON 4.5" EZ DRILL SV SQUEEZE PACKER 3550 FT. RUN GRICCL FROM 3575 TO 2850'. 05/15/04 ATTEMPT P&A THRU HOWCO EZSV SQUEEZE PACKER. COULD NOT ESTABLISH INJECTION RATE THRU STINGER ASSEMBLY, ATTEMPTED SEVERAL TIMES WITHOUT LUCK. FREEZE PROTECTED TUBING TO 3500' WITH 50/50 METHANOL. RIG DOWN. OS/20/04 CUT 41/2" L-80 TUBING AT 3500' WITH 3 5/8" CHEMICAL CUTTER SHOT 12' X 2" STRING SHOT 3489' TO 3501' PRIOR TO CHC, DID NOT RUN TUBING PUNCH. WHPIIAlOA UNCHANGED 010/100. - e BP EXPLORATION Page 1 _ ()pe"~tions Summary Report ... Legal Well Name: A-30 Common Well Name: A-30 Spud Date: 6/6/1985 Event Name: REENTER+COMPLETE Start: 5/26/2004 End: 7 n /2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7n/2004 Rig Name: NABORS 7ES Rig Number: ,TÖ Hours Task Code NPT Phase Description of Operations . 5/25/2004 20:00 - 00:00 4.00 MOB P PRE Held PJSM Blow down and disconnect service lines, prepare Camp, Tuck shop for move. Pull pit complex away from rig and install jeep for move. 5/26/2004 00:00 - 06:00 6.00 MOB P PRE Held PTSM. Move Camp, truck shop and pit complex from P-27 to A-30. Components on location at 0:600 hrs. (Rig crew preparing rig for move, lay down derrick and pull rig off P-27. Pickup mats,and herculite, clean up location.) 06:00 - 09:00 3.00 MOB P PRE Lay mats for camp and truck shop spot same. Position pit module out of the way. 09:00 - 00:00 15.00 MOB P PRE Move rig from P-27 to A-30. Rig on location @ 22:00 hrs, Set mats and herculite for Rig. 5/27/2004 00:00 - 02:00 2.00 RIGU P PRE Held PTSM. Spot Rig on A-30 02:00 - 03:00 1.00 RIGU P PRE Set mats for pit module, spot pits 03:00 - 04:00 1.00 RIGU P PRE Burm cellar, close cellar doors, spot cuttings tank, hookup service lines 04:00 - 04:30 0.50 RIGU P PRE Held PJSM, Raising derrick. 04:30 - 05:30 1.00 RIGU P PRE Raise and pin derrick. 05:30 - 08:00 2.50 RIGU P PRE Bridle down, tie back bridle lines, pin skate chute and clean Rig. 08:00 - 10:00 2.00 WHSUR P DECOMP Take on Seawater in pits, Rig up to cirulate out freeze protect. Load DP in pipe shed. Accept Rig @ 08:00 hrs. on 5/27/2004 10:00 - 11 :30 1.50 WHSUR P DECOMP Rig up DSM lubricator, zero pressure on annulus, pull BPV and rig down lubricator. 11 :30 - 12:00 0.50 WHSUR P DECOMP Pressure test lines to 3,500 psi ok. 12:00 - 14:30 2.50 KILL P DECOMP Displace 155 bbls diesel from well taking returns to cuttings tank. circulating rate 3 bpm @ 90 psi. 14:30 - 16:00 1.50 KILL P DECOMP Circulate one complete hole volume 245 bbls, Rate 6 bpm @ 570 psi, monitor well (static) 16:00 - 18:30 2.50 WHSUR P DECOMP Install and test TWC to 1,000 psi, nipple down tree and adapter flange, inspect lock down srews, and lift threads on hanger, ok made up 4.5" XO into hanger 7 1/2 turns. 18:30 - 21 :00 2.50 BOPSUF P DECOMP Nipple up 135/8" spacer spool, BOPs and drilling nipple. 21 :00 - 22:00 1.00 BOPSUF P DECOMP Rig up BOP test equipment 22:00 - 00:00 2.00 BOPSUF P DECOMP Test BOP, choke manifold, floor valves, IBOP, and Topdrive to 250 psi. low and 3,500 psi high. The position indicator shaft on the HCR valve started leaking. The blind rams and two choke valves and HCR valve remain to be tested. Chuck Scheeve with AOGCC witnessed BOP test. 5/28/2004 00:00 - 03:00 3.00 BOPSUF N RREP DECOMP Held PTSM. Change out choke HCR Valve 03:00 - 04:30 1.50 BOPSUF P DECOMP Test Choke HCR valve, blind rams, and three choke manifold valves to 250 psi low 3,500 psi high. unable to test lower pipe rams at this time, due to the limited space between the lower rams and tool joint of the test joint. 04:30 - 05:00 0.50 BOPSUF P DECOMP Rig down test equipment 05:00 - 06:30 1.50 BOPSUF P DECOMP Rig up DSM lubricator and pull TWC, Rig down lubricator 06:30 - 07:00 0.50 PULL P DECOMP Monitor well, makeup landing joint, back out lockdown screws 07:00 - 07:15 0.25 PULL P DECOMP Pull tubing hanger to rig floor. Pickup weight 65,000# 07:15 - 10:00 2.75 PULL P DECOMP Circulate one hole volume 245 bbl. 6 bpm @ 600 psi. Monitor well. RIU spooling unit for control lines, Lay down tubing hanger and landing joint. Printed: 7/1312004 9: 13:52 AM e BP EXPLORATION Operations Summary Report .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 6/6/1985 End: 7/7/2004 Date From - To Code NPT 5/28/2004 10:00 - 17:00 7.00 PULL P 17:00 - 17:30 0.50 CLEAN P 17:30 - 19:30 2.00 CLEAN P 19:30 - 00:00 4.50 CLEAN P 5/29/2004 00:00 - 03:00 3.00 CLEAN P 03:00 - 04:30 1.50 CLEAN P 04:30 - 05:00 0.50 CLEAN P 05:00 - 09:30 4.50 CLEAN P 09:30 - 10:30 1.00 CLEAN P Phase 21 :30 - 22:00 22:00 - 00:00 0.50 STWHIP P 2.00 STWHIP P DECOMP Held PJSM. POH lay down 88 jts 4.5" tubing, SSSV, and cut joint. recovered 27 control line clamps and 3 stainless steel bands. DECOMP Rig down tubing handling equipment DECOMP Rig up BOP test equipment and test lower pipe rams to 250 psi low, 3,500 psi high. Rig down test equipment, pull test plug and install wear ring. DECOMP Held PJSM, RIH, pickup 108 joints of 4" Dp and rack back in derrick DECOMP Held PTSM, RIH Pickup 66 joints 4" DP and rack back in derrick DECOMP Pickup clean out assembly,8.5" flat bottom mill, Bit sub, XO, 9 DC's, Float sub, Jars, XO, 23 Joints 4" HW DECOMP Service rig and topdrive. DECOMP RIH, with clean out assembly, picking up 4" DP 1X1. Tag top of fish @ 3,507' DECOMP Picked up 5' above top of fish and pumped 35 bbl. weighted, high vis. sweep, Pump rate 600 gpm @ 1,450 psi, rotating drill string at 120 rpm, torque 2,000ft/lbs. Pickup weight = 100,000# down weight = 95,000#, string weight = 100,000#. Sweep brought back minimal increase of well debris. Held PJSM. POH with clean out assembly. Monitor well at BHA, rack back HW and DCs, lay down mills. Held PJSM. Rig up Schlumberger E-line, RIH with HES bridge plug and CCUGR, set bridge plug @ 3,466', Log out of hole with Gamma Ray for well tie in. Rig Down Schlumberger tools. Held PJSM, Rig up test equipment, and test 9 5/8" casing to 3,500 psi. record test on chart. Rig down test equipment. Held PJSM, Pickup Mills, Whipstock, MWD, and orient. Pickup remaning BHA. test MWD. RIH to 3,390'. Break circulation, orient whipstock 40 deg. right of high side, Tag bridge plug and set anchor with 20k, pickup to confirm set, set down 40k and shear off whipstock. Top of Whipstock @ 3,446' bottom of whipstock @ 3,462' Pickup weight = 105,000# down weight = 100,000# WEXIT Displace well with 9.5 ppg LSND mud @ 450 gpm 705 psi. WEXIT Mill Window from 3,446' to 3,451' With 5k wob, 450 gpm @ 900 psi, 80 rpm, 5,000 ft/Ibs torque. WEXIT Mill Window from 3,451' to 3,462' With 5k wob, 460 gpm @ 900 psi, 100 rpm, 5,000 ft/lbs torque. Pumped a 50 bbl weighed high vis sweep (10.5 ppg) @ 3,462', had a considerable increase in metal cuttings when sweep came back. Mill formation from 3,462' to 3,474' 8-10 K wOb, 460 gpm @ 900 psi 120 rpm, 5500 ft/lbs torque. WEXIT Circulate 50 bbl high vis weighted sweep. (10.5 ppg). Did not see a significant amount of cuttings at surface when sweep came back. Recovered a total of 285 Ibs. of metal cuttings during milling operations. WEXIT Pull mills up inside window. Rig up testing equipment and perform FIT at 3,446' 3,365' tvd. mud weight 9.5 ppg. 287 psi = EMW 11.1 ppg. WEXIT Held PJSM,Monitor well, Pump dry job and POH with milling assembly. 10:30 - 12:00 1.50 CLEAN P DECOMP 12:00 - 13:00 1.00 CLEAN P DECOMP 13:00 - 16:30 3.50 DHB P DECOMP 16:30 - 17:30 1.00 DHB P DECOMP 17:30 - 21 :00 3.50 STWHIP P WEXIT 21 :00 - 21 :30 0.50 STWHIP P WEXIT 5/30/2004 00:00 - 04:30 4.50 STWHIP P 04:30 - 05:00 0.50 STWHIP P 05:30 - 06:30 1.00 STWHIP P 06:30 - 08:30 2.00 STWHIP P Printed: 7/1312004 9:13:52 AM e e Page 3'- BP EXPLORATION Operations·Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-30 A-30 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date From- To Task Code NPT Phase 5/30/2004 08:30 - 10:00 1.50 STWHIP P WEXIT 10:00 . 12:00 2.00 STWHIP P WEXIT 12:00 - 13:00 13:00 - 13:30 13:30 . 16:00 1.00 STWHIP P 0.50 STWHIP P 2.50 STWHIP P WEXIT WEXIT WEXIT 16:00 - 17:30 17:30 - 18:00 1.50 STWHIP P 0.50 STWHIP P WEXIT WEXIT 18:00 - 00:00 6.00 DRILL P INT1 5/31/2004 00:00 - 12:00 12.00 DRILL P INT1 12:00 - 00:00 12.00 DRILL P INT1 6/1/2004 00:00 - 01 :30 1.50 DRILL P 01 :30 - 03:00 P INT1 DRILL P INT1 0.75 DRILL P 2.75 DRILL P INT1 INT1 1.50 DRILL P INT1 Start: 5/26/2004 Rig Release: 7f7/2004 Rig Number: Spud Date: 6/6/1985 End: 7f7/2004 Description of Operations Held PJSM, Lay down 9 DCs and Baker mills. Upper srting mill was in gauge. Pull wear ring, Rig up and flush BOP stack, Blow through choke and kill lines. Instal wear ring. Clear floor of milling tools. Held PJSM, Slip and cut drilling line. Inspect and adjust brakes. Service Rig and topdrive. Held PJSM, Pickup 8.5' drilling assembly as per Directional driller, orient and shallow test MWD. RIH with 8.5' driling assembly, picking up 4' DP to 3,411' Establish ECD base line, orient BHA and work through window, no roblems Directional drill 8.5' hole from 3,474' to 4,464' Drill with 8 - 12k wob, 100 rpm, torque on bottom = 3,000 ft/lbs, off bottom = 2,000 ft/lbs. pump rate 550 gpm with 1,820 psi, on botto 1,645 psi off bottom. Pumped weighted (11.5 ppg) hi weep @ 3,985',5% increase in cuttings. Calculated clea ole ECD = 10.35, Actual = 10.5. Directional drill 8.5' hole from 4,464' to 6,18 rill with 15 - 20k wob, 100 rpm, torque on bottom = 5,000 bs, off bottom = 4,000 ft/lbs. pump rate 580 gpm with , 00 psi, on bottom, 2,380 psi off bottom. Pickup weig - 135,000# down weight = 110,000#, rotating weight = 1 ,00#, Calculated clean hole ECD = 10.26, Actual = 10. . Pumped 25 bbl high vis weighted sweep (11.5 ppg) at 5,7 ',had a 30% increase in cuttings when sweep came k. ART = 4.9 AST .8 ADT = 6.7 Directional dr" .5' hole from 6,185" to 7,811' Drill with 15 - 20k wOb, rpm, torque on bottom = 5,500 ft/Ibs, off bottom = 4,000 s. pump rate 580 gpm with 3,260 psi, on bottom, 2,9 psi off bottom. Pickup weight = 155,000# down weight = 0,000#, rotating weight = 135,000# Calculated clean hole ECD = 10.26, Actual = 10.75. Pumped 25 bbl high vis weighted sweep (11.5 ppg) at 6,280' - 6,854' - 7,337", all had a 30 . 40% increase in cuttings when sweep came back, no reduction in ECD. ART = 5.8 AST = 1.8 ADT = 7.60 Held PTSM, Directional drill 8.5' hole from 7,811' to 8,003' Drill with 15 - 20k wob, 120 rpm, torque on bottom = 5,500 ft/Ibs, off bottom = 4,000 ft/Ibs. pump rate 580 gpm with 3,300 psi, on bottom, 2,990 psi off bottom. Pickup weight = 160,000# down weight = 120,000#, rotating weight = 135,000# Calculated clean hole ECD = 10.26, Actual = 10.68 ART =.7 AST =.4 ADT = 1.1 Pump 30 bbl high vis weighted sweep, rotating string at 120 rpm, reciprocating full stand, circulate until shakers cleaned up. Held PJSM, POH to 6,575' pump dry job, POH to shoe, had some tight spots 5,860'· 5555' - 4440' 1 0-15k over pull wiped back through,no problem, saw nothing pulling through window. Service rig and topdrive, install clamp on topdrive blower hose. Held PJSM, RIH to 7,908' Fill pipe every 25 stds. no hote problems on trip in. Break circulation, staging up pumps, ream from 7,908' to 8,003' adjust flow rates to keep ECD with in set limits. Circulate Printed: 7/1312004 9:13:52 AM , . AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well A-30 L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,700.00' MD 10,785.00' MD 11,900.00 I MD . 20-Jul-03 (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) d, 0 '3 --I D 7 RECEIVED JUL 24 2003 NaMaœ~~ Sperry-Sun Dri"tngServices North Slope Alaska BPXA PBU_WOA A Pad A-30L1 Job No. AKMWOO02527659, Surveyed: 29 June, 2003 Survey Report 18 July, 2003 Your Ref: API 500292137260 Surface Coordinates: 5947265.00 N, 654398.00 E (70· 15' 46.1762" N, 148· 45' 06.2477" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 947265.00 N, 154398.00 E (Grid) Surface Coordinates relative to Structure Reference: 1115.75 N, 912.30 E (True) Kelly Bushing: 80.88ft above Mean Sea Level Elevation relative to Project V Reference: 80.88ft Elevation relative to Structure Reference: 80.88ft SlI:JI!!f'""r""\I-.U1 DRIL.L.ING ~E~VIe:es A Halliburton Company DEFINITIVE e e Survey Ref: 5vy4072 Sperry-Sun Drilling Services Survey Report for PBU_WOA A ".d . A·30L 1 Your Ref: API50029~137~60 Job No. AKMWOO02527659, Surveyed: 29 June, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10700.00 36.220 157.000 8692.57 8773.45 4564.92 S 2697.58 E 5942756.35 N 657188.62 E 4901.62 Tie On Point MWD Magnetic 10785.00 36.180 158.190 8761.17 8842.05 4611.33 S 2716.71 E 5942710.34 N 657208.70 E 0.828 4944.83 Window Point 10817.09 38.980 159.690 8786.60 8867.48 4629.60 S 2723.74 E 5942692.23 N 657216.09 E 9.179 4961.43 10849.96 41.940 160.930 8811.60 8892.48 4649.68 S 2730.91 E 5942672.30 N 657223.68 E 9.332 4979.25 10888.24 48.190 162.130 8838.63 8919.51 4675.37 S 2739.48 E 5942646.78 N 657232.77 E 16.4 77 5001.56 e 10928.17 59.920 163.180 8862.03 8942.91 4706.18 S 2749.08 E 5942616.18 N 657243.00 E 29.453 5027.76 10962.79 69.600 162.150 8876.77 8957.65 4736.04 S 2758.41 E 5942586.52 N 657252.94 E 28.089 5053.18 10999.29 79.560 160.210 8886.46 8967.34 4769.29 S 2769.76 E 5942553.51 N 657264.97 E 27.763 5082.26 11029.99 88.550 162.850 8889.64 8970.52 4798.22 S 2779.42 E 5942524.78 N 657275.22 E 30.504 5107.38 11060.36 91.280 158.270 8889.69 8970.57 4826.85 S 2789.52 E 5942496.36 N 657285.91 E 17.555 5132.68 11092.81 92.860 155.280 8888.51 8969.39 4856.65 S 2802.31 E 5942466.83 N 657299.30 E 10.416 5160.83 11126.51 92.950 151.400 8886.81 8967.69 4886.72 S 2817.41 E 5942437.08 N 657315.02 E 11.502 5190.98 11159.74 93.130 145.760 8885.04 8965.92 4915.03 S 2834.70 E 5942409.13 N 657332.89 E 16.957 5221.83 11188.96 91.370 142.410 8883.89 8964.77 4938.67 S 2851.82 E 5942385.85 N 657350.49 E 12.942 5249.73 11219.06 90.660 138.890 8883.36 8964.24 4961.94 S 2870.90 E 5942362.97 N 657370.04 E 11.928 5278.97 11250.61 91.280 135.720 8882.83 8963.71 4985.12 S 2892.29 E 5942340.24 N 657391.90 E 10.236 5310.00 11283.21 91.980 132.020 8881.90 8962.78 5007.70 S 2915.78 E 5942318.14 N 657415.85 E 11.546 5342.35 11315.42 94.630 129.020 8880.04 8960.92 5028.59 S 2940.21 E 5942297.76 N 657440.71 E 12.415 5374.44 11345.59 95.330 124.260 8877 .42 8958.30 5046.52 S 2964.32 E 5942280.32 N 657465.18 E 15.888 5404.49 11384.49 96.210 120.030 8873.51 8954.39 5067.11 S 2997.09 E 5942260.41 N 657498.36 E 11.053 5443.04 11424.39 96.920 121.440 8868.95 8949.83 5087.37 S 3031.16 E 5942240.86 N 657532.84 E 3.936 5482.44 11457.42 97.090 126.910 8864.92 8945.80 5105.77 S 3058.27 E 5942223.01 N 657560.32 E 16.445 5515.17 e 11488.54 96.120 130.250 8861.34 8942.22 5125.05 S 3082.43 E 5942204.23 N 657584.87 E 11 .108 5546.07 11519.92 95.150 135.190 8858.25 8939.13 5146.23 S 3105.36 E 5942183.53 N 657608.24 E 15.968 5577.13 11558.14 93.660 138.890 8855.32 8936.20 5174.11 S 3131.33 E 5942156.18 N 657634.77 E 10.409 5614.65 11589.11 93.660 142.590 8853.34 8934.22 5198.04 S 3150.88 E 5942132.66 N 657654.81 E 11.923 5644.67 11619.54 94630 144.000 8851.14 8932.02 5222.37 S 3169.02 E 5942108.71 N 657673.44 E 5.614 5673.80 11650.96 94.100 146.110 8848.75 8929.63 5248.05 S 3186.97 E 5942083.40 N 657691.91 E 6.905 5703.58 11686.11 92.420 151.400 8846.75 8927.63 5278.04 S 3205.16 E 5942053.79 N 657710.72 E 15.767 5736.16 11707.34 92.250 152.100 8845.88 8926.76 5296.73 S 3215.20 E 5942035.32 N 657721.14 E 3.390 5755.42 ----_._-~----~-'_.._-- 18 July, 2003 - 14:16 Page 2 of 4 DrillQuest 3.03.02.005 \ Sperry-Sun DrlllingiServices Survey Report for P8U_~AJ./J'd· A-30L.1 Your Ref: API500292f37260 Job No. AKMW0002527659, Surveyed: 29 June, 2003 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11735.46 91.630 148.400 8844.93 8925.81 5321.12 S 3229.14 E 5942011.21 N 657735.58 E 11766.71 90.310 144.530 8844.40 8925.28 5347.16 S 3246.40 E 5941985.53 N 657753.37 E 11804.96 90.130 140.650 8844.25 8925.13 5377.54 S 3269.64 E 5941955.64 N 657777.22 E 11840.74 89.690 136.950 8844.31 8925.19 5404.45 S 3293.20 E 5941929.21 N 657801.33 E 11900.00 89.690 136.950 8844.63 8925.51 5447.76 S 3333.65 E 5941886.74 N 657842.66 E All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 127.000° (True). Magnetic Declination at Surface is 25.756°(29-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11900.00ft., The Bottom Hole Displacement is 6386.81ft., in the Direction of 148.536° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10700.00 10785.00 11900.00 4564.92 S 4611.33 S 5447.76 S 2697.58 E 2716.71 E 3333.65 E Tie On Point Window Point Projected Survey 8773.45 8842.05 8925.51 18 July, 2003 - 14:16 Page 3 of 4 Dogleg Rate (O/100ft) 13.334 13.083 10.155 10.414 0.000 BPXA Vertical Section Comment 5781.24 5810.69 5847.53 5882.55 5940.92 Projected Survey e . --~_. DríllQuest 3.03.02.005 North Slope Alaska Sperry-Sun Drilling Services Survey Report for PBU_WOAA Pad· A·30L 1 Your Ref: AP/SO()292137260 Job No. AKMWoo02527659, Surveyed: 29 June, 2003 Survey tool proqram for A-30L 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 10700.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10700.00 8773.45 11900.00 8773.45 BP High Accuracy Gyro (A-30) 8925.51 MWD Magnetic (A-30L 1) 18 July, 2003 - 14:16 Page 4 of 4 BPXA e e -----..-----.."- DrillQuest 3.03.02.005 ~ e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 'yJ(7!r 4/2-2-lzoo4- 1. Type of Request: Œa Abandon o Suspend o Operation Shutdown o Perforate o Waiver o Other o Alter Casing o Repair Well Œa Plug Perforations o Stimulate o Time Extension o Change Approved Program o Pull Tubing o Perforate New Pool o Re-Enter Suspended Well o Annular Disposal 2. Operator Name: 4. Current Well Cla¡: 5. Permit To 9rill Number BP Exploration (Alaska) Inc. a Development D Exploratory 203-107/ 3. Address: D Stratigraphic Test D Service 6. API Number: . /.. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21372-60-00 7. KB Elevation (ft): 80.88' 9. Well Name and Number: /" PBU A-30L 1 8. Property Designation: 10. Field I Pool(s): ADL 047472 Prudhoe Bay Field I Prudhoe Bay Pool ft. .................. I!.' 00'::11'. .·llµI'i·.···C:OI.· i.·' '.i······.. ., ii. ,·'i Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11900 8844 3600 3466 - 3600 ·.Cåsin(Í··· \ ". .·.·il.....Í'ith·'. '>,..> ···,····...iii· ·ii·..··'·M! ····'i\· if. i ·i>' '. i. .¡ Structur;1I 110' 20" x 30" 110' 110' Surface 2677' 13-3/8" 2677' 2652' 5380 2670 i::ltp. 10752' 9-5/8" 10752' 8815' 6870 4760 Pr Linp.r 744' 7" 10496' - 11240' 8609' - 9211' 7240 5410 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): None. None 4-1/2", 12.6# L-80 10560' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker packer; Packers and SSSV MD (ft): 10443' 4-1/2" Otis SSSV Nipple 2104' 12. Attachments: 13. Well Class after proposed work: a Description Summary of Proposal D BOP Sketch D Exploratory a Development D Service D Detailed Operations Program »"""""'-'< 14. Estimated Date for A~~04 15. Well Status after proposed work: Commencing Operations: DOil DGas D Plugged a Abandoned 16. Verbal Approval: (~: DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Bill Isaacson Title Senior Drilling Engineer L L~. À. Date L I 1.11 O~\ Prepared By Name/Number: Signature --- Phone 564-5521 Terrie Hubble, 564-4628 .... . .......... ····i> ii.. ...\..... ,·'ð2,i i.·.·i. ........... /.< ,;i; ......... .......... ii . ...., i.' . >. i i" I Sundry Number: 30tf.)'Ñ-/ Conditions of approval: Notify Commission so that a representative may witness '- . D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance RECEIVED Other: APR 2 1 2004 S"bsequent~~1 Alaska Oil & Gas Cons. Commission Approved B~ /''V It! Anchorage BY ORDER OF Date ~Ä00 COMMISSIONER THE COMMISSION Form 10-403 ReotISed f'a2QØ3 ~ RßDW# c. . .ß,ubmitfln Dúplicate -- ORIGINAL s APft ~} 2' e e o bp To: Winton Aubert - AOGCC Date: April 19, 2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: A-30L 1 Application for Sundry Approval - P&A for Sidetrack Operations Reference: API # 50-029-21372-60 Approval is requested for the proposed P&A of PBU well A-30L 1. V;ell A-30 is a low angle (480 max) conventional water-flood producer. It was drilled and completed in June 1985. Initial oil rates were 7,000 BOPD with 0% WC. A channel to water was found in July 1990; 3 squeezes were needed to control the water, but oil rate suttered too, so the well was fractured (Ivishak only) and stimulated in December 1990. Oil production increased from 1,000 to 3,Ooobopd and the water cut returned to pre-squeeze levels (-40%). An acid stimulation in April 1988 gave a response of 10oobopd, but subsequent stimulations (10/89, 7190 and 7/00) have not improved rates. Fluid rates had been maintained at about 2,000 bfpd and a static survey in May 2001 gave a pressure reading of 3,337psi, which suggests good support for the parent location. Small MI responses have also been noted, most likely from A-17i and X-06i. The well has open perforations in the Sag, but their contribution is likely small. Well A-30L 1 has been shut in since the lateral leg was attempted in May 2003 when it was producing 250bopd at 88% water cut and 6200 GOR. A-30A, a proposed 3,050' Zone 4B horizontal rig sidetrack, will parallel the original A-30 and A- 30L 1 and extend an additional 1,850' beyond the A-30L 1 planned TD. It will target a potentially large oil reserve left by inefficient sweep between four offset injectors (X-06i, A-17i, A-21i, X-29i). The planned profile will crosscut stratigraphy four times, staying well above a possible MOWC at -8,900sstvd. Real- time geo-steering sensors will be used to continuously evaluate fluid saturations and an early TD will be called if pervasive high water saturations are encountered. The A-30A sidetrack is scheduled for Nabors 7ES. Current estimates have it beginning around May 25, 2004, following the completion of the P-27. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Ria Ooerations: 1. RIU and pressure test the 4 112" tubing string, against the cemented coil tubing fish, to 3,OOOpsi. Determine whether or not the well is effectively plugged and abandoned by the cemented fish. (Done 4/14/2004. Injection rate of 4.9bpm established at 1,350psi. Also, conducted MIT IA to 3,OOOpsi for 30 minutes and MIT OA to 2,OOOpsi for 30 minutes.) 2. RIH and set a 4 Yz" cementing retainer at -3,55O'md. 3. RIH with coil tubing, sting into the retainer and perform a hesitation squeeze to -3,OOOpsi. The estimated total slurry volume to P&A the well bore is 85bbls. This consists of 67.5bbl in the 4 Yz" X 2 3/8" annulus, 7.5bbl in the 7" X 2 3/8" annulus, plus -10bbl to squeeze. 4. Pull out of the retainer and circulate the tubing, above the cement retainer, clean. POOH. 5. Drift the 4 Yz" tubing to tag at -3,550' md to confirm clear for upcoming chemical cut. 6. Fluid-pack the 4 Yz" tubing and 9 5/8" x 4 Yz" annulus to surface. Test the tubing and the annulus to 3,000 psi. (Tubing X IA passed test to 3,000psi on 4/14/2004. This test is primarily to confirm the tubing has been successfully isolated.) 7. RIU E-line. RIH with the appropriate chemical cutter and cut the 4 Yz" tubing at -3,500' md. A-30L 1 Application for Sundry e e 1 8. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater retums to surface. Freeze protect to -2,200' MD with diesel. 9. Test the 9 5/8" pack-off and tubing hanger seals to 5,000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Level the pad as necessary. TUs I ð ··40) a..pprih/Dt.1. Ria ODerations: 1. Mil RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. RlU. Pull the 4Y2" tubing from the cut at -3,500' MD and above. 5. M/U 8 Y2" mills BHA and P/U 5" drill pipe. RIH and tag tubing stump. POOH. 6. RIH with HES 9 5/8" EZSVon drill pipe. Set bridge plug at -3,490'. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. 8. Displace the well to 9.7ppg LSND based milling fluid. POOH. 9. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 10. Mill window in 9 5/8" casing at ± 3,475' MD, plus approximately 20' beyond middle of window. Circulate the well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 12. M/U 8 Y2" Dir/GRlPWD assembly. RIH, kick off and drill the 8 112" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a r, 26.0#, L-80 intermediate drilling liner. 14. M/U a 61/8" Dir/GRlRes/ABI drilling assembly. RIH to the landing collar. 15. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.5ppg Flo-Pro drilling fluid. 18. Drill out the r shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0ppg EMW. Drill ahead to section TD per directional proposal. 19. Circulate well bore clean, short trip to the 7" shoe. Circulate. POOH. 20. Run and cement a 4 Y2", 12.6#, L-80 solid production liner. POOH. 21. P/U and RIH with Schlumberger 2 Y2" tcp perforating guns. Perforate approximately 2,000' of 24 interval, per subsurface team. POOH. 22. RIU and run a 4 1/2", 9.2#, 13Cr-80, VAM TOP completion, stinging into the 4 1/2" liner tie back sleeve. 23. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 24. Install a TWC. 25. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 26. Freeze protect the well to -2,200'. Install BPV. Secure the well. 27. Rig down and move off. Post-Ria ODerations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 04/25/04 Estimated Spud Date: 05/25/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 A-30L 1 Application for Sundry TREE = WB.LHEAD= ACTUATOR= KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MJ = Datum TVD= 4" CrN McEVOY AXB.SON 80.88' 52.92' 2200' 47 @ 6800' 10833' 8800' SS 13-3/8" CSG, 72#, L- -i 80, I) = 12.347" I 2,677' I Pre rig Chern cut 4 1/2" tbg. H 3,500' I Pre rig Cement retainer: P&A. H 3,550' I CHEM CUT 2-3/8" CT (B.MJ) H 3600' TOPOF CEMENT (B.MJ) H 3765' TOPOF7" LNR H 10497' 4-1/2" TBG, 12.6#, L- -i 10560' 80, ID = 3.958" I 9-5/8" CSG, 47#, L- 80, ID = 8.681" I 10847' I PBTO H 11197' 7" LNR, 26#, L-80. -1 11240' .0383 bpf, ID = 6.276" I A-30L 1 Pre Rig NOTES: WARNING: RADIO TRANSMmER IN WEA THER MONITORING SHACK MUST BE TURNED OFF BEFOREANY WB.L WORK INVOLVING EXA...OSrIIES CAN BEGIN. CONTACT PAD OPERATOR . 2104' H4-1/2" OTIS SSSV NIP, ID = 3.813"1 Minimum IC = 1.995" @ 3600' / 2-3/8" CT, 4.45#, HS-90 GAS LIFT MANDRB.S ST MD TVD DEV 1YÆ VLV LAT PORT DATE 6 3774 3518 44 OTIS DMY RA 0 06/17/03 5 6366 5418 46 OTIS DMY RA 0 06/17/03 4 8219 6722 43 OTIS DMY RA 0 ~ 3 9366 7611 36 OTIS DMY RA 0 06/17/03 2 10102 8209 36 OTIS DMY RA 0 1 10253 8381 36 OTIS DMY RA 0 06/17/03 I 10358' 1-14-1/2' OTIS XA SLIDING SLEEVE, 10 = 3.813" 1 I 10419' 1-1 BOT SBR SEAL ASSY W/OTlS X NIP, ID = 3.813" I 10443' H9-5/8" x 4-112" BOTPKR. 10= 3.958"1 I 10485' H4-1/2" OTIS X NIP, I) = 3.813" I I 10516' H4-1/2" OTIS XN NIP, MillED ID = 3.80" I 10547' H B.MJ TT LOGGED 07/31/99 1 I 10560' H4-1/2" BOT-SOS TBG TAIL I MIlLOUTWINOOW 10790' - 10796' I 10928' H STUCK CEMENT NOZZLE I PERFORA TION SUMMARY REF LOG: SWS-BHCS ON 06/23/85 ANGLE AT TOP PERF: 36 @ 10763' Note: Refer to Production DB for historical perf data SIZE SPF MERV AL Opn/Sqz DA TE 3-3/8" 3 10763 - 10774 0 01/22/91 3-3/8" 3 10877 - 10896 0 12/20/90 3-3/8" 3 10900 - 10906 0 12/20/90 3-318" 12 10914 - 10924 0 01/18/90 3-3/8" 3 10932 - 10962 0 12/20/90 3-118" 4 10974 - 11038 S 08/11/90 3-3/8" 4 11043-11048 S 08/11/90 11900' H TO DATE 06129/85 06/19/03 06121/03 07102/03 04/19/04 PRUDHOE BA Y UNIT WB.L: A-30L 1 PERMIT No: 2031070 AA No: 50-029-21372-60 SEC 35, T11 N, R 13E DATE REV BY COMMENTS BP exploration (Alaska) A-30A Proposed Comp&tion 13-3/8" CSG, 72#, L- Î 80, Ð = 12.347" 2,677' I G 9 5/8" X 7" Baker Flex Lock liner hanger, ZXP packer w / TBS. 9 5/8" Whip stock set Î on EZSV bridge plug. ICHM CUT 2-3/8" CT (B.MD) H TOP OF CeÆNT(B.MD) H 3,500' 3600' 3765' I TOP OF 7" LNR H 1049T 4-1/2" TBG, 12.6#, L- Î 1 0560' 80, ID = 3.958" 9-5/8" CSG, 47#, L- 80, Ð = 8.681" BKR WHPSTOCK RA TAG 1084T HBKRIBPW/STANDlNGVLV I I PBTD H 1119T 7" LNR. 26#, L-80, Î 11240' .0383 bpf, Ð = 6.276" 2,200' H4 1/2" 'X'landing nipple, Ð = 3.813"1 TREE = 4 1/8" CrN WB.LHEAD= McEVOY ACTUA TOR= AXB.SON KB. B.EV = 79.00' BF. B.EV = 52.92' KOP = 2,200' Max Angle = 96° @ 13,435' DatumMD= 10,913' Datum TVD= 8,840' SS GAS LFT MANDRB.S ST MD TVD DEV TYÆ VALVE 6 3340 3250 32.0 41/2" Xi" KBG- av 5 4200 3900 43.5 4 1/2" X 1" KBG- DC!< 4 6070 5250 43.5 4 1/2" X 1" KBG- av 3 7790 6500 43.5 4 1/2" X 1" KBG- av 2 9170 7500 39.0 41/2" X 1" KBG- DV 1 10390 850034.5 41/2" X 1" KBG- DV LAT BK BK BK BK BK BK 10550' H 41/2" - 'X'landing nipple 10,570' H 41/2" X 7" Baker 5-3 Pkr 10,590' H 4 1/2" - 'X'landing nipple 10,610' H 41/2" - 'XN' landing nipPIe I 10,620' H 41/2",12.6#, 13Cr-80, VAMTOP I 10,625' 5" X 7" Baker HMC finer hanger, ZXP liner top packer w / Tie Back Sleeve. 10,774' H 7",26.0#, L-80, BTG-M liner I o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 o 0 13,969' H 4 1/2",12.6#, L-80 solid liner 10928' H STUCK CEMENT NOZZLE DATE 06129/85 06/19/03 06/21103 07102103 03104104 PRUDHOE SAY UNIT WB.L: A-30A PERMIT No: API No: 50-029-21372-01 SEC 35, T11N, R 13E DATE REV BY COMMENTS BP exploration (Alaska) . . eé\3'- ICT WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska September 30,2003 RE: MWD Formation Evaluation Logs A-30 L1, AK-MW-2527659 1 LDWG fonnatted Disc with verification listing. À-A:..' ('1' ~ '}.; API#: 50-029-21372-60 11 \ d- (/'V PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: <..:: - ~ Signed~El...~_~~,~~ ~~~\\\~ · STATE OF ALASKA e ALASKA"'5IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL vJ6A- D' .". r , 10 '/'1 I ~UV, '7/7/3 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. o Suspend 0 Plugging 0 Time Extension 0 Perforate o Repair Well 0 Pull Tubing 0 Variance 0 Other II Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: a Development o Exploratory o Stratigraphic o Service 6. Datum Elevation (DF or KB) KBE = 80.9' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 3181' SNL, 1014' WEL, SEC. 35, T11N, R13E, UM At top of productive interval 2500' SNL, 1694' EWL, SEC. 01, T10N, R13E, UM At effective depth 3712' SNL, 709' WEL, SEC. 35, T11N, R13E, UM At total depth 3850' SNL, 3514' EWL, SEC. 01, T10N, R13E, UM 12. Present well condition summary Total depth: measured x = 654398, Y = 5947265 8. Well Number / A-30L 1 9. Permit Number 203-107 / 10. API Number / 50- 029-21372-60 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool x = 657203, Y = 5942724 x = 654714, Y = 5946740 (Planned) x = 659052, Y = 5941412 Effective depth: true vertical measured true vertical 11900 feet 8844 feet 3600 feet 3466 feet Plugs (measured) Junk (measured) Cemented up Coil BHA, Top of Cement in Coil at about 3765'; Cut Coil at 3600', Bottom of Coil at 10928' Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 8 cu yds Concrete 110' 110' 3746 cu ft Permafrost 2677' 2652' 2065 cu ft Class 'G', 230 cu ft 'G' 10752' 8815' 254 cu ft Class 'G' 10496' - 10790' 8609' - 8846' 110' 20" x 30" 2677' 13-3/8" 10752' 9-5/8" 744' 7" Perforation depth: measured Open: 10763' - 10774', 10877' - 10896', 10900' - 10906', 10914' - 10924', 10932' - 10962' Sqzd: 10962' - 10964', 10974' - 11038', 11043' - 11048' true vertical Open: 8824' - 8833', 8917' - 8932', 8935' - 8940', 8947' - 8955', 8961' - 8986' Sqzd: 8986' - 8987', 8995' - 9047', 9052' - 9056' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10560' Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker packer at 10443'; 4-1/2" Otis SSSV Nipple at 2104' 13. Attachments a Description Summary of Proposal 14. Estimated date for comm cin operation Iy 2 003 i 6. If proposal was verba roved o Detailed Operations Program "0 aé)p Sketch 15. Status of well classifications as: a Oil 0 Gas 0 Suspended'}" . Service Name of approver Contact Engineer NameINumber: Prepared By NameINumber: Terrie Hubble, 564-4628 e best of my knowledge I CT Drilling Engineer LfD·~ Commissioner JUL 1 V It e Hubble, Terrie L From: Sent: To: Cc: Subject: Winton Aubert [Winton_Aubert@admin.state.ak.us] Monday, July 07, 2003 3:41 PM Endacott, Mary S Hubble, Terrie L Re: A-30L 1 operations shut down Mary, Per 20 AAC 25.072, shut down of drilling ops requires official documentation (Form 10-403). I can't find a pool rule that eliminates this requirement. Please review the regulation and contact me if anyone has questions. Winton Aubert AOGCC 793-1231 "Endacott, Mary SOl wrote: > Winton > As you must have deduced Nordic 1 has shut down operations on A-30 on 7/2/03 > and moved to Z - 23. > > We experienced unexpected 100% total loss of circulation, treated it with > LCM and cement and restored to 20% losses then tried pumping one more cement > job, the hole packed off and the cementing nozzle packed off. We couldn't > pump down the coil and we left 28bbl of cement inside the coil, got 18bbl > out. We could pump down the back side and were able to bullhead the cement > out of the annulus into the loss zone, but left 19ft of BHA below the loss > zone and were unable to pull it free. > Unable to pull free and unable to pump down the coil... it was ugly. The > coil was cut and recovered from 3600'. We are presently evaluating plan > forward. > > Mary S. Endacott > Coil Tubing Drlg Engr > 907-564-4388 737d > endacoms@bp.com 1 TREE =' WELLHEAD= ACTUA TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD= 4" CrN McEVOY AXELSON 80.88' 52.92' 2200' 47 @ 6800' 10833' 8800'SS e 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2677' CHEM CUT 2-3/8" CT I 3600' ELMD I TOG H 3765' ELMD I Minimum ID :::: 1.995" @ 3600' 2-3/8" CT, 4.45#, HS-90 CB1ENTED 2-3/8" CT, 4.45#, HS-90, 10 1.995" TOPOF 7" LNR I 10497' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I 10560' 19-5/8" CSG, 47#, L-80, ID = 8.681" H 10752' I A-30 L 1 CTD Attempted Sidetrack . &rv NOTES: WARNING: RADIO TRANSMITTER IN __ THER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR 2104' -14-1/2" OTIS SSSV NIP, ID = 3.813" I GAS LIFT rvlANDRELS ST MD TVD DEV TYPE SIZE 6 3774 3518 44 OTIS 1-1/2" 5 6366 5418 46 OTIS 1-1/2" 4 8219 6722 43 OTIS 1-1/2" 3 9366 7611 36 OTIS 1-1/2" 2 10102 8209 36 OTIS 1-1/2" 1 10253 8381 36 OTIS 1-1/2" LATCH RA RA RA RA RA RA 10358' -14-1/2' OTIS XA SLIDING SLEEVE, ID = 3.813" 10419' -1 BOT SBR SEAL ASSY W/OTIS X NIP, ID = 3.813" 10443' -19-5/8" x 4-1/2" BOT PKR, ID - 3.958" I 10485' -14-1/2" OTIS X NIP, ID = 3.813" I 10516' -14-1/2" OTIS XN NIP, ID = MILLED TO 3.80" 10560' -14-1/2" BOT-SOS TBG TAIL I 10547' H ELMDTTLOGGED07/31/99 PERFORA TION SUMrvlARY REF LOG: SWS-BHCS ON 06/23/85 ANGLEAT TOP PERF: 36 @ 10763' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 3 10763-10774 0 01/22/91 3-3/8" 3 10877-10896 0 12/20/90 3-3/8" 3 10900-10906 0 12/20/90 3-3/8" 12 10914-10924 0 01/18/90 3-3/8" 3 10932-10962 0 12/20/90 3-1/8" 4 10974-11038 S 08/11/90 3-3/8" 4 11043-11048 S 08/11/90 PBTD I 17" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" I DATE 06/29/85 02/05/01 02/27/01 OS/24/01 06/12/03 11197' 11240' REV BY SIS-MH SIS-MD RN/TP LLG COMMENTS ORIGINAL COMPLEllON CONVERTED TO CANVAS FINAL CORRECTIONS PROPOSED CTD SIDETRACK DATE 07/02/03 REV BY JUE COMMENTS NORDIC-1 ATTEMPTED SiT / I PRUDHOE BA Y UNIT WELL: A-30L 1 PERMIT No: 203-107 API No: 50·029-21372-60 Sec. 35, T11N, R 13E BP Exploration (Alaska) ~ 1I ~ 1I Œ (ill f ~ ~ ~ ~ [ß ~ / ~ANK H. MURKOWSK'. GOVERNOR A_.ASIiA. OIL Al'O) GAS / CONSERVATION COMMISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit A-30L1 BP Exploration (Alaska), Inc. Permit No: 203-107 Surface Location: 3181' SNL, 1014' WEL, Sec. 35, T11N, Rl3E, UM Bottomhole Location: 3850' SNL, 3514' EWL, Sec. 01, TlON, R13E, UM Dear Ms. Endacott: 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, ~y2~~ Commissioner BY ORDER OF THE COMMISSION DATED thisL1- day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ítJ4Æ f., li7/~o3 12. Distance to nearest property line 13. Distance to nearest well / ADL 028313,1765' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10785' MD Maximum Hole Angle 18. Casing Program S ·f· t' Size pecl lea Ions _ STATE OF ALASKA .. ALASKA __ AND GAS CONSERVATION COM~ION PERMIT TO DRILL 20 AAC 25.005 / 1 b. Type of well 0 Exploratory 0 Stratigraphic Test . Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 80.9' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 047472 7. Unit or Property Name Prudhoe Ba Unit 8. Well Number A-30L 1 9. Approximate spud date. 06/23/03 7 Amount $200,000.00 14. Number of acres in property 15. p~sed depth (MD and TVD) 2560 13175' MD I 8885' TVDss 17. Anticipated pressure {~20 MC 25.035 (e) (2)} o 95 Maximum surface 2281 psig, At total depth (TV D) 8800' I 3337 psig Setting Depth To Bottom 1 a. Type of work 0 Drill . Redrill ORe-Entry 0 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 x = 654398. Y = 5947265 3181' SNL, 1014' WEL, SEC. 35, T11N, R13E, UM At top of productive interval x = 657203, Y = 5942724 2500' SNL, 1694' EWL, SEC. 01, T10N, R13E, UM At total depth x = 659052, Y = 5941412 3850' SNL, 3514' EWL, SEC. 01, T10N, R13E, UM 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 true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11240 feet 9211 feet 11197 feet 9177 feet Length Plugs (measured) Junk (measured) Jt}t~ M ¡ ,..)q') -,v,D TVD Size Cemented 110' 20" x 30" 2677' 13-318" 10752' 9-5/8" 744' 7" 8 cu yds Concrete 3746 cu ft Permafrost 2065 cu ft Class 'G', 230 cu ft 'G' 10752' 110' 2652' 8815' 254 cu ft Class 'G' 10496' - 11240' 8609' - 9211' Perforation depth: measured Open: 10763' - 10774', 10877' - 10896', 10900' - 10906', 10914' - 10924', 10932' - 10962' Sqzd: 10962' - 10964', 10974' - 11038', 11043' - 11048' true vertical Open: 8824' - 8833', 8917' - 8932', 8935' - 8940', 8947' - 8955', 8961' - 8986' Sqzd: 8986' - 8987', 8995' - 9047', 9052' - 9056' 20. Attachments . Filing Fee 0 Property Plat B BOP Sketch 0 Diverter Sketch B Drilling Program . Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report . 20 AAC 25.050 Requirements Contact Engineer NameINumber: Mary Endacott, 564-4388 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I ~erebY certify that the fore oing is true~de<y~~t~est of my kn~~ledge , Signed Mary Endacott -~1!.tt/l.[Uti( Title CT Dnlllng Engineer API Number 50- 029-21372-60 Samples Required 0 Yes J8I No Hydrogen Sulfide Measures .EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: T-e.s\- ß" t' E f-o ~ÇOO pç.¿ , ~ ~ i Rev. 12-01-85 D4K D5K D10K by order of the commission Date e e BP A-30L 1 CTD Sidetrack Summarv of Operations: Phase 1: Prep work - integrity testing, set standing valve, set whipstock Phase 2: Mill window with Nordic 1 /" Phase 3: Drill and Complete 3 %" hole sidetrack, with Nordic 1, scheduled to begin June 23rd. Mud Program: · Phase 2: Viscosified Seawater · Phase 3: Flo-Pro (8.6 - 8.7 ppg) /"" 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: .,,/ The production liner will be 33/16" TC-II solid x 2 7/8" ST-L slotted liner from TD 13175' to approx. 10500'MD (-8531'ss) with slotted/pre drilled pipe in Zone 4 target. 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 95 deg. · Plan to enter objective formation, Sadlerochit at -10,930'MD · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and resistivity will be run in the open hole section. Hazards ~/ · The maximum recorded H2S at A Pad is Opp A-43), latest recorded on A-30 = 30ppm. · No mapped faults will be crossed. No I~· culation events in surrounding wells. · Parent well was hydraulically fractured, standing valve to prevent mud losses. Reservoir Pressure · Reservoir pressure is estimated to be 3337psi @ 8800'ss (7.3 ppg emw). Measured on A-30, 5/01. · Max. surface pressure with gas (0.12 psi/ft) to surface is 2281 psi. ,/ TREE = WELLHEAD= ~';';';',';';',';';';'~~'" ACTUA TOR= 4" CNV McEVOY AXELSON e -30 L 1 S~ NOTES: WARNING: RADIO TRANSMrTTER IN W~ MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR. Proposed CTD Sidetrack Max Angle = Datum MD = DatumTVD= 47 @ 6800' 10833' 8800' SS . 2104' -14-1/2" OTIS SSSV NIP,ID = 3.813" I Minimum ID = 3.725" @ 10516' OTIS XN NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYÆ SIZE 6 3774 3518 44 OTIS 1-1/2" 5 6366 5418 46 OTIS 1-1/2" 4 8219 6722 43 OTIS 1-1/2" 3 9366 7611 36 OTIS 1-1/2" 2 10102 8209 36 OTIS 1-1/2" 1 10253 8381 36 OTIS 1-1/2" LA TCH RA RA RA RA RA RA 113-3/8" CSG, 72#, L-80, ID = 12.347" 2677' I I 10358' -i4-1/2' OTIS XA SLIDING SLEEVE, ID = 3.813" ITOP OF 7" LNR I TOP OF 3-3í16" LNR 3.5" X NIP, 2.813 10 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" -i BOT SBR SEAL ASSY W/OTIS X NIP, 10 = 3.813" -i 9-5/8" x 4-1/2" BOT PKR, 10 = 3.958" I -14-1/2" OTIS X NIP, ID = 3.813" I -14-1/2" OTIS XN NIP, ID = 3.725" I 10560' -14-1/2" BOT-SOS TBG TAIL I 10547' H ELMO TT LOGGED 07/31/99 Mechanical Whipstock H 10785' 1- 19-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: SWS-BHCS ON 06/23/85 ANGLE AT TOP ÆRF: 36 @ 10763' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 3 10763-10774 0 01/22/91 3-3/8" 3 10877 -10896 0 12/20/90 3-3/8" 3 10900-10906 0 12/20/90 3-3/8" 12 10914-10924 0 01/18/90 3-3/8" 3 10932-10962 0 12/20/90 3-1/8" 4 10974-11038 S 08/11/90 3-3/8" 4 11043-11048 S 08/11/90 H 13175' I / 11197' 17" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" I 11240' OATE 06/29/85 02/05/01 02/27/01 OS/24/01 SIS-MH SIS-MO RN/TP COMMENTS ORIGINAL COMPLETION CONVERTED TO CANVAS FINAL CORRECTIONS DATE REV BY COMMENTS PRUOHOE BA Y UNIT WELL: A-30 ÆRMITNo: 85-1190 API No: 50-029-21372-00 Sec. 35, T11N, R 13E BP Exploration (Alaska) REV BY M f BP WELLPATM DETAILS Pl$n#3A-::!OI..1 SOG2:G21:mær; Parent WeHpath; ..,. TI$OfiMO: 10700,00 Rig, Nordiç1 SO,90ft Ref, Datum: 34 J 30 61611&85 01 V.$l!¡(::tioft Origin ~~r.= Sbu1:ing Angle +NI.$ From.TVD , , , , , , , . . ,. " " " ObP BP Baker Hughes INTEQ Planning Report e e .Ii. ..... INTEQ Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB A Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5946131.57 ft 653509.42 ft Latitude: 70 15 Longitude: 148 45 North Reference: Grid Convergence: 35.209 N 32.775 W True 1.17 deg Well: A-30 Slot Name: 30 A-30 Well Position: +N/-S 1115.15 ft Northing: 5947264.98 ft Latitude: 70 15 46.176 N +E/-W 911.56 ft Easting : 654397.99 ft Longitude: 148 45 6.248 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 A-30L 1 500292137260 Current Datum: 34 : 30 6/6/1985 00:00 Magnetic Data: 6/17/2003 Field Strength: 57539 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 A-30 10700.00 ft Mean Sea Level 25.76 deg 80.79 deg Direction deg 127.00 Height 80.90 ft Targets A-30L 1 Polygon3.1 0.00 -4587.70 2702.70 5942734.00 657194.00 70 15 1.051 N 148 43 47.646 W -Polygon 1 0.00 -4587.70 2702.70 5942734.00 657194.00 70 15 1.051 N 148 43 47.646 W -Polygon 2 0.00 -4894.63 2646.39 5942426.00 657144.00 70 14 58.033 N 148 4349.287 W -Polygon 3 0.00 -5820.90 3329.59 5941514.00 657846.00 70 14 48.920 N 148 4329.430 W -Polygon 4 0.00 -6155.64 4629.10 5941206.00 659152.00 70 14 45.622 N 148 42 51.649 W -Polygon 5 0.00 -5785.94 4648.68 5941576.00 659164.00 70 14 49.257 N 148 42 51.073 W -Polygon 6 0.00 -5319.53 3561.94 5942019.99 658068.00 70 14 53.850 N 148 4322.667 W -Polygon 7 0.00 -4590.71 2849.68 5942734.00 657341.00 70 15 1.021 N 148 43 43.372 W A-30L 1 Fault 1 0.00 -4073.42 3476.47 5943264.00 657957.00 70 15 6.106 N 148 4325.136 W -Polygon 1 0.00 -4073.42 3476.47 5943264.00 657957.00 70 15 6.106 N 148 4325.136 W -Polygon 2 0.00 -4966.24 4333.41 5942389.00 658832.00 70 14 57.321 N 148 43 0.227 W A-30L 1 Fault 2 0.00 -4651.97 5251.11 5942722.00 659743.00 70 15 0.406 N 148 42 33.533 W -Polygon 1 0.00 -4651.97 5251.11 5942722.00 659743.00 70 15 0.406 N 148 42 33.533 W -Polygon 2 0.00 -4966.24 4333.41 5942389.00 658832.00 70 14 57.321 N 148 43 0.227 W A-30L 1 T3.4 8830.00 -5755.38 4085.15 5941595.00 658600.00 70 14 49.561 N 148 43 7.459 W A-30L 1 T3.1 8850.00 -4910.78 2897.13 5942415.00 657395.00 70 14 57.873 N 148 4341.995 W A-30L 1 T3.3 8860.00 -5560.87 3624.01 5941780.00 658135.00 70 14 51.476 N 148 43 20.866 W A-30L 1 T3.2 8880.00 -5267.81 3234.91 5942065.00 657740.00 70 14 54.360 N 148 4332.177 W A-30L 1 T3.5 8880.00 -5940.09 4556.50 5941420.00 659075.00 70 14 47.742 N 148 42 53.757 W ObP e e B.. IIAKD. ....... IN'TEQ -- BP Baker Hughes INTEQ Planning Report Annotation 10700.00 10785.00 10805.00 10938.39 11163.39 11338.39 11663.39 11913.39 12163.39 12313.39 12663.39 13013.39 13175.00 8692.55 8761.15 8777.10 8837.93 8853.95 8866.49 8880.62 8875.66 8862.46 8851.94 8834.94 8861.17 8885.31 TIP KOP 3 4 5 6 7 8 9 10 11 12 TO Plan: Plan #3 Identical to lamar's Plan #3 Principal: Yes Date Composed: Version: Tied-to: 6/17/2003 2 From: Definitive Path Plan Section Information 10700.00 36.22 157.00 8692.55 -4564.80 2697.62 0.00 0.00 0.00 0.00 10785.00 36.18 158.19 8761.15 -4611.21 2716.76 0.83 -0.05 1.40 93.74 10805.00 37.98 158.19 8777.10 -4622.40 2721.24 9.00 9.00 0.00 0.00 10938.39 86.00 158.19 8837.93 -4728.56 2763.72 36.00 36.00 0.00 0.00 11163.39 85.98 131.12 8853.95 -4909.93 2892.34 12.00 -0.01 -12.03 269.00 11338.39 85.89 152.18 8866.49 -5046.05 3000.04 12.00 -0.05 12.03 91.00 11663.39 89.32 113.29 8880.62 -5262.03 3234.05 12.00 1.05 -11.97 274.00 11913.39 92.90 143.08 8875.66 -5414.75 3428.31 12.00 1.43 11.92 83.00 12163.39 93.01 113.04 8862.46 -5566.91 3622.63 12.00 0.04 -12.02 271.00 12313.39 94.96 95.10 8851.94 -5603.16 3767.16 12.00 1.30 -11.96 276.80 12663.39 90.36 136.91 8834.94 -5753.24 4074.25 12.00 -1.32 11.94 95.00 13013.39 81.41 95.72 8861.17 -5905.13 4379.78 12.00 -2.56 -11.77 256.70 13175.00 81.57 115.33 8885.31 -5947.69 4533.00 12.00 0.10 12.13 91.00 10700.00 36.22 157.00 8692.55 -4564.80 2697.62 5942756.79 657188.45 4901.58 0.00 0.00 TIP 10725.00 36.21 157.35 8712.72 -4578.41 2703.35 5942743.30 657194.46 4914.35 0.83 93.74 MWD 10750.00 36.20 157.70 8732.90 -4592.05 2709.00 5942729.78 657200.38 4927.07 0.83 93.46 MWD 10775.00 36.18 158.05 8753.08 -4605.73 2714.56 5942716.22 657206.22 4939.74 0.83 93.17 MWD 10785.00 36.18 158.19 8761.15 -4611.21 2716.76 5942710.79 657208.53 4944.79 0.83 92.89 KOP 10800.00 37.53 158.19 8773.15 -4619.56 2720.10 5942702.51 657212.04 4952.49 9.00 0.00 MWD 10805.00 37.98 158.19 8777.10 -4622.40 2721.24 5942699.69 657213.24 4955.11 9.00 0.00 3 10825.00 45.18 158.19 8792.05 -4634.72 2726.16 5942687.48 657218.42 4966.45 36.00 0.00 MWD 10850.00 54.18 158.19 8808.21 -4652.39 2733.24 5942669.95 657225.85 4982.74 36.00 360.00 MWD 10875.00 63.18 158.19 8821.19 -4672.20 2741.16 5942650.31 657234.18 5000.99 36.00 0.00 MWD 10897.83 71.40 158.19 8830.00 -4691.73 2748.98 5942630.94 657242.40 5018.99 36.00 360.00 A-30L 1 10900.00 72.18 158.19 8830.68 -4693.65 2749.75 5942629.04 657243.20 5020.76 36.00 0.00 MWD 10925.00 81.18 158.19 8836.43 -4716.21 2758.78 5942606.67 657252.69 5041.55 36.00 0.00 MWD 10938.39 86.00 158.19 8837.93 -4728.56 2763.72 5942594.43 657257.89 5052.92 36.00 360.00 4 10950.00 85.98 156.79 8838.74 -4739.26 2768.15 5942583.82 657262.54 5062.91 12.00 269.00 MWD 10975.00 85.94 153.79 8840.50 -4761.92 2778.58 5942561.39 657273.42 5084.86 12.00 269.10 MWD 11000.00 85.90 150.78 8842.28 -4783.99 2790.17 5942539.56 657285.47 5107.41 12.00 269.31 MWD 11025.00 85.89 147.77 8844.07 -4805.42 2802.91 5942518.39 657298.64 5130.48 12.00 269.52 MWD 11050.00 85.88 144.76 8845.87 -4826.16 2816.76 5942497.95 657312.91 5154.02 12.00 269.74 MWD 11075.00 85.88 141 .76 8847.67 -4846.14 2831.67 5942478.28 657328.23 5177.95 12.00 269.96 MWD ObP e e ... ..... ._---."---~- INTEQ BP Baker Hughes INTEQ Planning Report -4865.31 2847.61 5942459.44 657344.56 5202.22 12.00 270.17 MWD -4883.61 2864.54 5942441.49 657361.86 5226.76 12.00 270.39 MWD -4901.01 2882.41 5942424.46 657380.08 5251.49 12.00 270.60 MWD -4909.93 2892.34 5942415.75 657390.19 5264.80 12.00 270.81 5 -4917.65 2900.97 5942408.20 657398.98 5276.34 12.00 91.00 MWD 11200.00 85.92 135.53 8856.54 -4934.98 2918.90 5942391.25 657417.26 5301.09 12.00 90.90 MWD 11225.00 85.89 138.53 8858.33 -4953.23 2935.90 5942373.36 657434.62 5325.64 12.00 90.69 MWD 11250.00 85.87 141.54 8860.12 -4972.34 2951.91 5942354.58 657451.02 5349.93 12.00 90.47 MWD 11275.00 85.86 144.55 8861.93 -4992.26 2966.90 5942334.97 657466.42 5373.89 12.00 90.26 MWD 11300.00 85.86 147.56 8863.73 -5012.94 2980.82 5942314.58 657480.76 5397.45 12.00 90.04 MWD 11325.00 85.88 150.57 8865.53 -5034.33 2993.64 5942293.46 657494.01 5420.56 12.00 89.82 MWD 11338.39 85.89 152.18 8866.49 -5046.05 3000.04 5942281.88 657500.65 5432.73 12.00 89.61 6 11350.00 85.99 150.78 8867.32 -5056.22 3005.57 5942271.82 657506.39 5443.27 12.00 274.00 MWD 11375.00 86.21 147.78 8869.02 -5077.66 3018.31 5942250.64 657519.56 5466.34 12.00 274.10 MWD 11400.00 86.44 144.79 8870.62 -5098.41 3032.15 5942230.18 657533.83 5489.89 12.00 274.30 MWD 11425.00 86.68 141.79 8872.12 -5118.42 3047.07 5942210.49 657549.15 5513.84 12.00 274.49 MWD 11450.00 86.93 138.80 8873.51 -5137.62 3063.02 5942191.62 657565.49 5538.13 12.00 274.67 MWD 11475.00 87.19 135.80 8874.80 -5155.96 3079.95 5942173.63 657582.79 5562.69 12.00 274.84 MWD 11500.00 87.45 132.81 8875.97 -5173.41 3097.81 5942156.56 657601.01 5587.46 12.00 275.00 MWD 11525.00 87.72 129.82 8877.02 -5189.90 3116.57 5942140.46 657620.10 5612.36 12.00 275.14 MWD 11550.00 88.00 126.83 8877.95 -5205.39 3136.17 5942125.37 657640.01 5637.34 12.00 275.26 MWD 11575.00 88.28 123.84 8878.76 -5219.84 3156.55 5942111.35 657660.68 5662.31 12.00 275.37 MWD 11600.00 88.57 120.86 8879.45 -5233.21 3177.66 5942098.41 657682.06 5687.21 12.00 275.47 MWD 11625.00 88.86 117.87 8880.01 -5245.46 3199.44 5942086.61 657704.08 5711.98 12.00 275.55 MWD 11650.00 89.16 114.88 8880.44 -5256.57 3221.83 5942075.97 657726.69 5736.55 12.00 275.62 MWD 11663.39 89.32 113.29 8880.62 -5262.03 3234.05 5942070.75 657739.02 5749.60 12.00 275.67 7 11675.00 89.49 114.67 8880.74 -5266.75 3244.66 5942066.26 657749.73 5760.91 12.00 83.00 MWD 11700.00 89.86 117.65 8880.88 -5277.77 3267.10 5942055.70 657772.38 5785.46 12.00 82.99 MWD 11725.00 90.22 120.62 8880.86 -5289.94 3288.93 5942043.98 657794.46 5810.22 12.00 82.97 MWD 11750.00 90.59 123.60 8880.69 -5303.22 3310.10 5942031.13 657815.90 5835.13 12.00 82.97 MWD 11775.00 90.95 126.58 8880.35 -5317.59 3330.56 5942017.18 657836.64 5860.11 12.00 82.99 MWD 11800.00 91.32 129.56 8879.85 -5333.00 3350.23 5942002.18 657856.63 5885.10 12.00 83.03 MWD 11825.00 91.68 132.54 8879.20 -5349.41 3369.08 5941986.16 657875.80 5910.02 12.00 83.09 MWD 11850.00 92.03 135.52 8878.39 -5366.78 3387.04 5941969.17 657894.12 5934.82 12.00 83.17 MWD 11875.00 92.38 138.50 8877.43 -5385.05 3404.07 5941951.26 657911.52 5959.42 12.00 83.27 MWD 11900.00 92.72 141.48 8876.32 -5404.18 3420.13 5941932.46 657927.96 5983.75 12.00 83.38 MWD 11913.39 92.90 143.08 8875.66 -5414.75 3428.31 5941922.06 657936.36 5996.65 12.00 83.51 8 11925.00 92.93 141.69 8875.07 -5423.94 3435.39 5941913.02 657943.62 6007.83 12.00 271.00 MWD 11950.00 92.97 138.68 8873.78 -5443.11 3451.37 5941894.18 657960.00 6032.14 12.00 270.93 MWD 11975.00 93.01 135.68 8872.48 -5461.42 3468.34 5941876.22 657977.33 6056.71 12.00 270.77 MWD 12000.00 93.04 132.67 8871.16 -5478.82 3486.24 5941859.20 657995.59 6081.47 12.00 270.62 MWD 12025.00 93.05 129.67 8869.83 -5495.25 3505.03 5941843.15 658014.71 6106.37 12.00 270.46 MWD 12050.00 93.07 126.67 8868.50 -5510.68 3524.66 5941828.13 658034.64 6131.32 12.00 270.30 MWD 12075.00 93.07 123.66 8867.16 -5525.05 3545.06 5941814.18 658055.34 6156.27 12.00 270.14 MWD 12100.00 93.06 120.66 8865.82 -5538.34 3566.19 5941801.33 658076.74 6181.15 12.00 269.98 MWD 12125.00 93.05 117.65 8864.49 -5550.50 3587.99 5941789.62 658098.78 6205.87 12.00 269.82 MWD 12150.00 93.03 114.65 8863.16 -5561.50 3610.40 5941779.08 658121.41 6230.39 12.00 269.66 MWD 12163.39 93.01 113.04 8862.46 -5566.91 3622.63 5941773.93 658133.74 6243.41 12.00 269.50 9 12175.00 93.18 111.65 8861.83 -5571.32 3633.35 5941769.74 658144.55 6254.62 12.00 276.80 MWD 12200.00 93.52 108.67 8860.37 -5579.92 3656.78 5941761.62 658168.15 6278.51 12.00 276.73 MWD 12225.00 93.86 105.68 8858.76 -5587.29 3680.61 5941754.75 658192.12 6301.98 12.00 276.55 MWD 12250.00 94.19 102.69 8857.00 -5593.40 3704.78 5941749.13 658216.42 6324.96 12.00 276.36 MWD 12275.00 94.50 99.70 8855.11 -5598.24 3729.23 5941744.80 658240.96 6347.40 12.00 276.15 MWD ObP BP Baker Hughes INTEQ Planning Report e e .Ii. ..... INTEQ 94.81 96.71 8853.08 -5601.79 3753.89 5941741.75 658265.69 6369.24 12.00 275.92 94.96 95.10 8851.94 -5603.16 3767.16 5941740.65 658278.98 6380.66 12.00 275.68 12325.00 94.84 96.49 8850.95 -5604.33 3778.67 5941739.71 658290.51 6390.55 12.00 95.00 MWD 12350.00 94.57 99.49 8848.90 -5607.80 3803.34 5941736.76 658315.24 6412.34 12.00 95.12 MWD 12375.00 94.28 102.49 8846.97 -5612.55 3827.81 5941732.51 658339.80 6434.74 12.00 95.36 MWD 12400.00 93.98 1 05.48 8845.17 -5618.57 3852.00 5941726.98 658364.11 6457.69 12.00 95.60 MWD 12425.00 93.67 108.47 8843.50 -5625.86 3875.86 5941720.19 658388.11 6481.12 12.00 95.81 MWD 12450.00 93.35 111.46 8841.96 -5634.38 3899.31 5941712.15 658411.73 6504.98 12.00 96.01 MWD 12475.00 93.03 114.45 8840.57 -5644.11 3922.29 5941702.89 658434.90 6529.19 12.00 96.19 MWD 12500.00 92.69 117.43 8839.33 -5655.03 3944.74 5941692.44 658457.57 6553.69 12.00 96.36 MWD 12525.00 92.35 120.41 8838.23 -5667.11 3966.60 5941680.81 658479.67 6578.42 12.00 96.51 MWD 12550.00 92.00 123.40 8837.28 -5680.31 3987.80 5941668.05 658501.14 6603.30 12.00 96.64 MWD 12575.00 91.64 126.38 8836.49 -5694.60 4008.30 5941654.18 658521.92 6628.26 12.00 96.75 MWD 12600.00 91.28 129.36 8835.85 -5709.94 4028.02 5941639.25 658541.96 6653.25 12.00 96.85 MWD 12625.00 90.92 132.33 8835.37 -5726.28 4046.93 5941623.30 658561.19 6678.19 12.00 96.92 MWD 12650.00 90.55 135.31 8835.05 -5743.59 4064.96 5941606.37 658579.58 6703.01 12.00 96.98 MWD 12663.39 90.36 136.91 8834.94 -5753.24 4074.25 5941596.91 658589.05 6716.22 12.00 97.02 11 12675.00 90.03 135.55 8834.90 -5761.62 4082.28 5941588.69 658597.25 6727.68 12.00 256.70 MWD 12700.00 89.34 132.63 8835.04 -5779.02 4100.23 5941571.67 658615.56 6752.49 12.00 256.70 MWD 12725.00 88.66 129.71 8835.48 -5795.47 4119.05 5941555.61 658634.71 6777.42 12.00 256.71 MWD 12750.00 87.97 126.79 8836.21 -5810.94 4138.67 5941540.55 658654.64 6802.40 12.00 256.76 MWD 12775.00 87.29 123.86 8837.24 -5825.38 4159.04 5941526.53 658675.31 6827.36 12.00 256.85 MWD 12800.00 86.62 120.94 8838.57 -5838.76 4180.12 5941513.59 658696.65 6852.24 12.00 256.97 MWD 12825.00 85.96 118.00 8840.19 -5851.03 4201.84 5941501.76 658718.61 6876.97 12.00 257.12 MWD 12850.00 85.30 115.07 8842.10 -5862.17 4224.14 5941491.09 658741.13 6901.48 12.00 257.31 MWD 12875.00 84.66 112.13 8844.29 -5872. 13 4246.95 5941481.59 658764.15 6925.71 12.00 257.54 MWD 12900.00 84.03 109.18 8846.75 -5880.91 4270.23 5941473.30 658787.60 6949.58 12.00 257.80 MWD 12925.00 83.42 106.22 8849.48 -5888.46 4293.90 5941466.23 658811.42 6973.03 12.00 258.09 MWD 12950.00 82.83 103.26 8852.47 -5894.78 4317.90 5941460.41 658835.54 6996.00 12.00 258.41 MWD 12975.00 82.25 100.29 8855.72 -5899.84 4342.17 5941455.85 658859.90 7018.42 12.00 258.76 MWD 13000.00 81.70 97.31 8859.21 -5903.63 4366.63 5941452.56 658884.43 7040.23 12.00 259.15 MWD 13013.39 81.41 95.72 8861.17 -5905.13 4379.78 5941451.33 658897.62 7051.65 12.00 259.56 12 13025.00 81.39 97.13 8862.91 -5906.41 4391.19 5941450.28 658909.05 7061.53 12.00 91.00 MWD 13050.00 81.36 100.16 8866.66 -5910.13 4415.63 5941447.07 658933.55 7083.28 12.00 90.79 MWD 13075.00 81.36 103.19 8870.42 -5915.13 4439.83 5941442.56 658957.85 7105.62 12.00 90.33 MWD 13100.00 81.37 106.23 8874.17 -5921.40 4463.73 5941436.78 658981.88 7128.48 12.00 89.88 MWD 13125.00 81.42 109.26 8877.91 -5928.94 4487.27 5941429.73 659005.56 7151.82 12.00 89.42 MWD 13150.00 81.48 112.30 8881.63 -5937.71 4510.38 5941421.44 659028.85 7175.55 12.00 88.97 MWD 13175.00 81.57 115.33 8885.31 -5947.69 4533.00 5941411.92 659051.67 7199.62 12.00 88.52 TO All Measurements are from top of Riser ~ Q) (f) a: top of bag .......................... bttm of bag middle of slips Blind/Shears middle of pipes middle of flow cross Mud Cross middle of blindlshears middle of pipelslips Flow Tee 6/16/2003 BAG 7 1/16" 5000psi TOTs 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs 7 1/16" 5000psi DATE CHECK NO. P055069 DATE 4/4/2003 e 4/4/2003 055069 INVOICE I CREDIT MEMO VENDOR DISCOUNT NET DESCRIPTION GROSS INV# CK0401 038 PERMIT TO DRILL H ~. èt)L. \ REC JUN 1. Alaska Oil & Am::ho age THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK995.19-6612 PAY: e· TO THE ORDER OF: NATlpNAL CITY BANK. Ashland, Ohio No. P 055069 56-389 412 CONSOLlQATED COMMERCIAL ACCOUNT AMOUNT 1110 5 SOb ~ III I: 0 L. ~ 2 0 ~ a ~ 5 I: 0 ~ 2 ? a ~ bill e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new well bore segment of LATERAL existing weD ~ Permit No, API No. . (If API number Production should conônue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) 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). SPACING The permit is approved subject to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to peñorate 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. DRY DITCH .. All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. . Rev: 07/10/02 ajody\templates PTD#: 2031 070 Administration 1 2 3 4 5 6 7 8 9 10 11 Appr Date 12 RPC 6/17/2003 13 14 15 16 17 Engineering 18 19 20 21 22 23 24 25 26 27 Appr Date 28 WGA 6/1712003 29 30 31 32 33 34 Geology 35 36 Appr Date 37 RPC 6/17/2003 38 39 Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT A-30L 1 Program DEV Well bore seg ~ Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType DEV I 1-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 0 P~rmitfee attachep. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . .. ............. . . . . . . . . . . . . . . . . . . . . . . . . . . .Leas~.number.appropriate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s. . . . . . . . . . . . . . . . ... . . . . . . . . . . . . . . . . . . . . .. ....... .Unique well_n_arn~.aod Ol!mb.er . _ _ . . . . _ _ . . . . _ _ _ . . . . _ _ _ . . . . _ _ . . . . . _ _ . . y~s _ _ . . . . _ _ _ _ . . . . _ _ . . . . _ _ _ _ . . . . . _ _ . . . . _ _ . . . . _ _ _ . . . . . _ _ _ _ . . . _ _ _ _ . . . _ _ _ . . . . _ _ . . . WeJUocat~d in.a.ctefil!eppool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . WellJocat~d pr.oper.distance.fromdriJling ul!itb.oul!d.ary . . . . . . . . . . . . . . Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WellJocat~d proper .distance.from other welJs. . . . . . . . . . y~s . . . . . . .. ............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .S.utfjciel!tacreag.e.aYailable in.drillio9 unjL . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . Jf.d~viated, js weJlbore plaUl!cJu.ded . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Oper.ator only affected party. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . _ . . . . . . . . .Operator lJas.appr.opriate.bond inJorce . _ _ . . . . _ _ . . . . . _ _ _ . . . . . _ _ . . . . _ . . . . Y~s . . . . . . . _ _ . . . . _ _ . . . . _ _ . . . . . . _ _ _ . . . _ _ _ _ _ . . . _ . _ . _ _ . . _ _ _ _ _ _ . . . . _ _ _ . . _ _ _ _ _ . . _ . . . P~rmit c.ao be issued wjtlJout conserva.tiOI! order _ . . . . . . _ . . . . . _ _ _ . . . . _ . . . . . . . y~s . _ _ _ . . . . . . . . _ . . . . . . . . . . _ . . . . . . . . . _ . _ _ . . . . . _ . . . _ . . _ . . . . . . . . . . . . . _ . . . . _ _ . . P~rmit c.ao be iSSl!ed wjtbout ad.mil!istratÎlle_appr.ovaJ . _ . . . . . . . _ . . . . _ _ _ _ . . . . . . . y~s . . . . . . . _ . . . . . . _ . . . _ .... _ _ . . . . . _ _ _ . . . . . . . . . Can permit be approved before 15-day wait Yes WelUocated withil! area .m.d.strata .authorized by.lojectioo Ord~r # (putlO# in.comrn~ot:>).(For. y~s . . . . . . . . . . _ . . . . . . . _ . . . . . _ _ . . . . _ . . . . . . . _ _ . . . . _ _ _ _ . . . . . . _ . . . . _ _ _ . _AJI welJs. wit!1iJl.1l4_ruile.area_of reyiew jd~otified (F.or servj~ well ç)l]lYL _ _ _ . _ _ _ _ _ _ . _ _ _ .NA . _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ _ _ . . _ _ . _ _ _ . . _ _ _ _ _ . . _ _ _ . . . . . _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _. . . _ _ . . Pre-produ~c:tiojeçtor; puration.ofpre-propuctiOI! l~s$than.3months.(For.servicewellonJY). .NA ... . . . . .. .. _ _.. . . . . . _. .... _ . ... _ . _.... . _. .... _ _ _ _ . . . . . . . . . . . . . .. _AÇMP.F:ïndingof Con.si$teocy.h_as bee.n.Îssued.forJlJis proiect. . . . . . . . _ . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . .Coodu.ctor string.provided . . . . . _ . . . . _ . _ . . . . . . . . . . . .NA ............. _ _ . . . . . . _ _ . . . . _ _ . . . . _ _ _ . . . . . _ _ . . . . . . _ . . . . . . . . . .Surfa~ .casil!g.protec.t$ aILk!1own. USQWs . . . _ . . . . . . _ . . . . . . . . . . . . . . . .NA . . . . . . . . _ . . . . _ _ . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . _ . . . . . . _ _ . . . _ _ . . .CMT v.ol adequ.ateJo circ.\Jlate.oncood.uctor. & su_rf.csg . . . . _ . . . . _ _ . . . . _ _ . . . . _ _ . _NA . _ _ _ _ . . . . _ _ . _ . . _ _ _ . . . . . _ . . . . . . . _ _ . . . . _ _ . _ _ . . . _ _ _ . . . . . _ _ _ . . . . . . . . . . . . . . .CMT v.ol adeql!ate.to tie-in Jong .striog to.surf çsg_ . . . . . . _ . . . . . . _ _ _ . . . . . . .NA . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . _ . _ . . .CMTwill coyer.aJl kI!Qw.n.p[o.ductiye lJorilOn.s. _ . . . . . . . . . . . . . _ . . . . . . _ . . NA . . Slotte.dc . . . . . . . . . . .. .... _ . . . . . . _ . . . . . . . .. ................. _ _ . . .C.a:>iog desigos ad.equa_te f.or C,.T. B.&.Rerruafr.ost . _ _ _ . . _ _ . . . _ . . _ . Y~s . _. ...... . . _ . . . . . . _ . _. .. _ . . . . . . . . _ . . . . . . . Mequaletan.kage.or re.serve pil . . . . . _ . . . . . _ _ . . y~s . . . CTQU.. . . . . _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . . _ . . . . . . . . . . . . . . . . . . _ _ . . Jf.a.re..prill. hasa. to,403 for abandOIJme.nl be~o approved. _ _ . . . . . _ . . . . . . _ . . . . . . NA . . . . _ . _ Lateral. . . . . . . . . . . . . _ _ . . . . . . . _ _ _ . . . . . _ . . . . . . . . Apequalewellboreseparatjo.n_proppsed. . _ _ . . . _ _ _ . _ _ _ . _ _ _ . . _ _ _ _ _ . . _ . _ _ _ . _Y~s _ _ . . _ . _ _ _ . . _ _ _ _ _ _ . _ _ . _ _ _ . . . _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ . _ Jf.diverter req.uired, doe:> itmeel reguJatiol!s. . . . . . . . . . . _ . . . . . . . . . _NA _ _. ... _ _ . . . . _ _ . . . . . _ . . . . . . . . _ . . . . . _ . . . . . . _ _ . . . . . . _ . . . . _ . . . . . _ . _ . .DriUiogfJuid.p-rogramsc.hematic.&eq.uipJistadequale. _. ....... .. _...... Y~s_ _ _... . MaxMW.8J.PPQc . _ _........ _... _ _ _.. ... _..... .... _ _ _... _... .BOPE:>,.d.othey meelreguJatioo . . . _ _ . . . . . . . _ . . . . . . _ . . . . . . _ .Yes. . _ _ _ _ . . . . . . _ . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . _ _ . .BOPEpress ra.tiog appropriate;.test lo(pu.t psig iJlcommeots). . _ . . . . . _ _ _ . . . . .Y~s. . . . . . . Test t.o.3500.p-sl. .MS~ 228j psi.. . . . . . _ . _ . . . . . . . . . . . . . _ _ . . . . . . . . . . . . _ . _ . .C.hoke.ruanifold comp-lies w/APtR~-53. (May 84). . . . . . . . . . . . . . . . _ . . . . _ _ . . . . . _Y~s _ . . . _ . . . . . . . . _ . . . . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . . . . . . _ . . Work: will occur withoytoperatio!1.shutdQwJl_ . . . . _ _ . . . . . . . . . . . . _ . . . . . . Y~s. . . . _ . _ . . . . . . . . . _ _ _ . . . . . . . . . . . . _ . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . .Is preseoce of H2S gas. p-robable. . . . . . . . . . . . . . . . . . _ _ _ . . . . . Y~s . . . _ _ . _ 2QO.pprn.o!1 A,~a_dc . . . . . . . _ . . . . . . . . . . . . . . . . . . . . _ _ . . . . . _ _ . . . . _ . . . . . . . . . MecbanicaLcç:mditioo .otwells withil! AOß yerifiec:t (For.s.ervjœ w~1J onJy) . . . . _ _ . . . NA _ _ . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . _ . . . . _ . _ . . . . _ . . . . . . . _ . P~rmit c.ao be iSSl!ed w{o hydrogen. $ulfide meas.\Jre:> _ _ . . . . . . . _ . . . . . . . No. . _ _ _ . . . . . . . . . . . . _ . .. .... _ . . . . _ . . . . . . . . . .. .... _ . . . . . _ _ . . . .Data.preseoted on_ pote.ntial overpressure .zone$ _ _ _ . . . . . _ _ . . . . . . . _ _ .NA . . . . _ . . . . . . . . . . . . _ . . . . . .. ... _ . . . . . . _ _ . . . . _ . . . . . . _ . . . . . . . . _ _ . . . _ _ _ _ . .S~isrnica!1alysjs. of :>haJlow gasz.ooes. . . . . _ . _ . . _ . . . . . . _ _ . . .NA _ _ . . . . . _ _ . _ . . . _ . _ . . . . . . _ . . . . . . _ . . . . . . _ . . . . . . . . . S~abed _condjtioo survey.(if off-sh.ore) . . . . . . _ . . . . _ . . . . . . . . . . . . . . . . . NA . . _ . . . . . . . . . . . _ . . . . . . . . . . . . . . _ . _ . . . . _ . . . . . . . . _ . . . . . . . . . . . . _ _ . . . _ _ _ . . . Conta.ct l!am.elphoneJorweelsly progress.reports [exploratory .ooly]. . . . _ . . . . . . . .NA . . . . _ . _ . . . . _ _ . . . . _ . . . . . . . _ . . . . _ . . . . _ . . . . _ _ _ . . . _ . . _ . . . . . _ . . . . . . . . e e Geologic Commissioner: ~~~ Date: Engineering : ~ c;:r'5i~ Public ~ Commissioner dp Date./ j/ 6//~/ '/"'O~ ..5 Date ò~J)ì/ð3 e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplìfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~~ng Services LIS sca~ility . ex ()3-- I c)f $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 29 09:57:06 2003 ~ ] ;Z ?-t) }... Reel Header Service name............ .LISTPE Date.................... .03/09/29 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. . . . . . . . . . . . . . . . . . . . .03/09/29 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 A-30L1 500292137260 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 29-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002527659 S. LATZ SARBER/WHITL MWD RUN 2 MW0002527659 S. LATZ SARBER/WHITL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 11N 13E 2099 1013 MSL 0) 80.88 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 7.000 10785.0 # ~~~N\.& REMARKS: 1. ALL DEPTHS4ItE MEASURED DEPTH (MD) UNLESS O4ltRWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 10785'MD AND THE BOTTOM WAS AT 10796'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH GAMMA MODULE (GM), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MAD PASS DATA (EWR4 ONLY) FROM 10810'MD (BIT) TO THE START OF RUN 2, ACQUIRED WHILE RIH FOR RUN 2, WERE MERGED WITH RUN 1 MWD DATA. 7. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 1 FT SHALLOWER, PER E-MAIL INSTRUCTIONS PROVIDED TO SSDS BY DEWAYNE SCHNORR ON 17 SEPTEMBER 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 8. MWD RUNS 1 & 2 REPRESENT WELL A-30 L1 WITH API#: 50-029-21372-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11900'MD/8845'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . $ File Header Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/09/29 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 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH GR 10773.. 11854.5 . RPD 10789.5 11867.5 RPM 10789.5 11867.5 RPS 10789.5 11867.5 RPX 10789.5 11867.5 FET 10789.5 11867.5 ROP 10807.5 11898.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10773.0 11898.5 $ GR 10774.0 11899.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 10774.0 11036.0 MERGE BASE 11036.0 11899.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction... ...... ...... ..Down Optical log depth units.......... .Feet Data Reference Point.. ........... .Undefined Frame Spacing.............. .... ...60 .1IN Max frames per record............ . Undefined Absent value...... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 10773 11898.5 11335.8 2252 10773 11898.5 ROP MWD FT/H 1 1349.18 100.251 2183 10807.5 11898.5 GR MWD API 24.28 502.88 76.8719 2164 10773 11854.5 RPX MWD OHMM 0.3 1481.75 15.1117 2157 10789.5 11867.5 RPS MWD OHMM 0.42 1817.77 18.1573 2157 10789.5 11867.5 RPM MWD OHMM 0.31 2000 19.6033 2157 10789.5 11867.5 RPD MWD OHMM 0.29 2000 21.4474 2157 10789.5 11867.5 FET MWD HOUR 0.17 21.78 3.90175 2157 10789.5 11867.5 First Reading For Entire File......... .10773 Last Reading For Entire File.......... .11898.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name...4IÞ Version Number....... ... .1.0.0 Date of Generation...... .03/09/29 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...... .03/09/29 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 GR ROP $ 2 4IÞ header data for each bit run in separate files. 1 .5000 START DEPTH 10774.0 10808.5 STOP DEPTH 11014.0 11036.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # 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: 28-JUN-03 Insite 4.3 Memory 11036.0 10809.0 11036.0 36.2 79.6 TOOL NUMBER 93091 4.125 10796.0 Flo Pro 8.60 62.0 9.0 19000 5.0 .000 .000 .000 .0 166.0 .0 MUD CAKE AT MT: . .000 . # 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. ..0 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWDOIO Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10774 11036 10905 525 10774 11036 ROP MWD010 FT/H 1 128.67 55.4184 456 10808.5 11036 GR MWD010 API 29.5 502.88 116.752 481 10774 11014 First Reading For Entire File......... .10774 Last Reading For Entire File.......... .11036 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/29 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...... .03/09/29 Maximum Physical Record. .65535 File Type.......... . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 · header data for 2 .5000 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ START DEPTH 10790.5 10790.5 10790.5 10790.5 10790.5 11014.5 11036.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # each bit run in separate fi4lt. STOP DEPTH 11868.5 11868.5 11868.5 11868.5 11868.5 11855.5 11899.5 RES IS. 4 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 29-JUN-03 Insite 4.3 Memory 11900.0 11036.0 11900.0 88.6 97.1 TOOL NUMBER 82758 126589 3.750 10796.0 Flo Pro 8.60 62.0 9.5 21000 5.0 .150 .070 .260 .160 68.0 152.0 68.0 68.0 Optical log depth units. .4IIÞ..... .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 4IIÞ 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 10790.5 11899.5 11345 2219 10790.5 11899.5 ROP MWD020 FT/H 1. 38 1349.18 112.089 1727 11036.5 11899.5 GR MWD020 API 24.28 234.86 65.4742 1683 11014.5 11855.5 RPX MWD020 OHMM 0.3 1481.75 15.1117 2157 10790.5 11868.5 RPS MWD020 OHMM 0.42 1817.77 18.1573 2157 10790.5 11868.5 RPM MWD020 OHMM 0.31 2000 19.6033 2157 10790.5 11868.5 RPD MWD020 OHMM 0.29 2000 21.4474 2157 10790.5 11868.5 FET MWD020 HOUR 0.17 21.78 3.90175 2157 10790.5 11868.5 First Reading For Entire File..... .....10790.5 Last Reading For Entire File......... ..11899.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .03/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/29 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 te. . . . . . . . . . . . . . . . . . . . . 03/09/29 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