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199-042
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ] 9~-'(..,,~ 2 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages' Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha~Lowell Date: ~/7 Is, /~. [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Isl RECEIVED . STATE OF ALASKA e ALAS~IL AND GAS CONSERVATION COMMISSION JUL 0 6 2006 WELL COMPLETION OR RECOMPLETION REPORT AND L9ffaska Oil & Gas Cons. Commission Anchorage 1 a. Well Status: D Oil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/11/2006 199-042 305-224 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 OS/29/1999 50- 029-20668-02-00 4a. Location of Well (Govemmental Section): 7. Date ToO. Reached 14. Well Name and Number: Surface: 06/02/1999 PBU E-15B 903' FNL, 501' FEL, SEC. 06, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1874' FNL, 142' FEL, SEC. 01, T11 N, R13E, UM 65.04 Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2088' FNL, 1148' FEL, SEC. 01, T11N, R13E, UM 11478 + 8987 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664463 y- 5976161 Zone- ASP4 11772 + 8994 Ft ADL 028280 TPI: x- 659956 y- 5975092 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 658955 y- 5974857 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR, ROP :a. CASING, LINER AND CEMENTING KECORD . '.' .ê...? I· 'é~~ ')r; 51':1'TING )Ep,T¡'¡MQ ..5E'fTIJIIØ DePTJ-I 1\ID 'i i···· .' ·.i.········..·.··.·.}···..·.....·..·3.fð~~~}¡@....? .,. ri·JSfig?·.. ..ii' i"i ··.i.. ;:>IZE;·. . ". . ....' , . ./i 'IV!"'i' .IV!'" . cv1"TöM .......;. .i 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2671' Surface 2671' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 9872' Surface 8391' 12-1/4" 1415 cu ft 'G', 130 cu ftAS I; 769 cu ftAS Lite 7" 26# L-80 9381' 10290' 8008' 8720' 8-1/2" 468 cu ft Class 'G' 4-1/2" 12.6# L-80 /13Cr 9736' 10427' 8283' 8809' 6" 162 cu ft Class 'G' 2-7/8" 6.16# L-80 9685' 11772' 8243' 8994' 3-3/4" 79 cu ft Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24..·.·.·.'.. ·..·.i...... i. ..... ··i.··..i······ Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 9450' - 9689' 9626' MD TVD MD TVD 2$..>........ ..............!'Â"'., i.. , ,7·~r,. .! t',' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED "';;.r". ...~ 9525' P&A w/ 22.5 Bbls Class 'G' Cement ',..~-' .- 9277' Set EZSV with Whipstock set on top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oil -BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BSl GAs-McF WATER-Bsl Oil GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8FL ,JUL 1 1 2006 Form 10-407 Revised 12/2003 ORIGJ~ IN ED ON REVERSE SIDE ~t ~ 28. . GEOLOGIC MARKER 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". 24N 1041 0' 8800' None 24P 10418' 8804' Zone 1 B 10632' 8931' 14P 1 0667' 8946' 13N 10749' 8970' 13P 10779' 8978' 12N 11744' 8992' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble.-r: Title Technical Assistant PBU E-15B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Barbara Lasley, 564-5126 199-042 305-224 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other, Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e E-15C Prudhoe Bay Unit 50-029-20668-03 206-060 Accept: Spud: Release: Ri: 05/16/06 OS/24/06 06/06/06 Nabors 7ES PRE-RIG WORK 04/17/06 DRIFTED TUBING W/3.625" CENT, 3' STEM, 3.70" CENT, 3,50" LIB, TAGGED LINER TOP AT 9673' SLM. LIB SHOWED IMPRESSION OF DEPLOYMENT SLEEVE. 04/21/06 T/I/O= 2330/12010. TEMP= SI. TUBING AND IA FL'S (PRE-LOAD). TUBING FL AT 9631' (146 BBLS) BELOW STA# 1. IA FL AT 114 (6 BBLS). 04/26/06 LOGGED GYRODATA TOOL FROM TOP OF 2 7/8" LINER AT 9711' TO 3400' AND TOOK STOP COUNTS EVERY 100' FROM 3400' TO SURFACE. JOB COMPLETE. TIO= 2300/150 I 0 ASSIST SLB E- LINE LOAD WELL WITH 5 BBLS METHANOL SPEAR FOLLOWED BY 130 BBLS CRUDE TO KILL WELL PRESSURE FWHP = 400/16010. 05/11/06 MU 3.5 NOZZLE FOR DRIFT AND FLAG. RIH TO TAG LINER TOP. TAG LINER TOP AT 9711. PUH 10 FEET AND FLAG PIPE. POOH. MU CEMENT BHA WITH 2" BDN. RU CEMENTERS, RIH WHILE KILLING WELL WITH 1% KCL. CORRECT AT FLAG. LOAD BACKSIDE OF COIL WITH DIESEL. PT CEMENTERS. PUMP 22.5BBL 15.8 CEMENT WITH 5BBL AGGREGATE. BULLHEAD CEMENT INTO LINER. PUMP 4 BBL BEHIND PIPE, LAY IN CEMENT 1/1. WAIT AT SAFETY FOR BUMP. GOOD BUMP, CLEAN OUT TO 9525' WITH BIO AND XS KCL. POOH PUMPING 80%. TRAP 500 PSIG WHP. JOB COMPLETE. 05/13/06 DRIFTED WI 2' STEM, 3.75" CENT, SAMPLE BAILER TO 9505' SLM + 33' = 9538' CORRECTED. PT CEMENT TO 1000 PSI, GOOD, TAG AGAIN AT SAME SPOT. SAMPLE BAILER CAME BACK EMPTY. TURNED WELL OVER TO PAD OP, LEFT SHUT IN. JET CUT TUBING AT 9450' AS PER PROGRAM, TAGGED CEMENT TOP AT 9525'. USED DOWN LOG TO CORRECT DEPTH, GLM AT 7881' AS REFERENCE POINT. WHP CHANGED FROM 600 TO 100 PSI AFTER SHOOTING AND lAP CHANGED FROM 350 TO 450 PSI AFTER SHOOTING. HELD POST JOB SAFETY MEETING/WALK AROUND, REQUESTED CLEARANCE FROM DSO AND DEPARTED LOCATION. JOB COMPLETE. PUMPED 10 BBLS NEAT METHANOL SPEAR. 05/14/06 CIRC-OUT (PRE-SDTRCK) CMIT TX IA TO 3500 PSI PASSED CIRC-OUT - PUMPED 10 BBLS NEAT METHANOL SPEAR, 1080 BBLS 1% KCL AND 152 BBLS DIESEL DOWN TBG TAKING RETURNS UP IA TO FLOW LINE VIA HARDLlNE JUMPER. LET U-TUBE FOR 1 HR. CMIT TX IA PRESSURED UP TO 3500 PSI WITH 9 BBLS DIESEL. TII LOST 120 PSI IN 1ST 15 MINUTES AND TII LOST 40 PSI 2ND 15 MINUTES FOR A TOTAL OF 160 PSI IN 30 MINUTES. BLED PRESSURES DOWN. FREEZE PROTECTED FLOW LINE WITH 5 BBLS NEAT METHANOL AND 50 BBLS DIESEL. FINAL WHP'S=OIOIO, TIIIO = SIIOIO TESTED CASING PACKOFF TO 3000 PSI. PRESSURE WAS 3000 PSI AT 15 MIN AND 3000 PSI AT 30 MIN. TEST PASSED. ALL LOCKDOWN SCREWS WERE FUNCTIONED. TESTED TUBING HANGER TO 5000 PSI. PRESSURE WAS 5000 PSI AT 15 MIN AND 5000 PSI AT 30 MIN. TEST PASSED. ALL LOCKDOWN SCREWS WERE FUNCTIONED AND TORQUED TO 450 FT LBS. e BP EXPLORATION Operations Sum Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-15C E-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 10/16/1981 End: 6/6/2006 Date From - To Hours Task Code NPT Phase Descriptiqn'of Oþèrati()ns 5/16/2006 00:00 - 10:00 10.00 MOB P PRE Move camp, pits, rig sub from C-pad to E-15. 10:00 - 12:00 2.00 MOB P PRE Move substructure over E-15. RU over well. 12:00 - 13:00 1.00 MOB P PRE Spot pits and level same. 13:00 - 15:00 2,00 MOB P PRE Raise derrick, bridle down, raise chute, rig up to pits, and floor. Take on seawater. Accept rig at 15:00 hrs. 15:00 - 15:30 0.50 BOPSU DECOMP Hold prespud meeting w/day tour crew, tool pusher, WSL, mud representative. Discuss overview of well. Discuss current decompletion phase in detail. 15:30 - 16:30 1.00 BOPSU DECOMP RU DSM and lubricate BPV from well, RD DSM 16:30 - 17:30 1.00 BOPSU DECOMP RU on tree to circulate freeze protection from well. 17:30 - 19:00 1.50 KILL DECOMP Reverse circulate 58 bbls down annulus to clear diesel from tubing. 4 bpm, 470 psi. 19:00 - 22:00 3.00 KILL P DECOMP Circulate down tubing w/33 bbl soap sweep followed by 500 bbls. 120 deg. F. seawater. 6 bpm, 670 psi. Monitor well, 25 psi on tubing. Well u-tubing, flow three bbls. back up tubing thru choke to pits. Pressure equalized and flow stopped. 22:00 - 22:30 0.50 BOPSU P DECOMP RU FMC and install Two Way Check valve. Test to 1000 psi from above. 22:30 - 23:30 1.00 BOPSU P DECOMP ND tree and adaptor. 23:30 - 00:00 0.50 BOPSU P DECOMP Hold prespud meeting w/night tour crew, tourpusher, WSL, mud representative. Discuss operations sumrnary of well. Discuss current decompletion phase in detail. 5/17/2006 00:00 - 05:30 5.50 BOPSU P DECOMP BOP test. 250 psi low side test. 3500 psi high side test. Test witnessed by Lowell Anderson, BP WSL and Lenward Toussant, Nabors tourpusher. John Crisp, AOGCC representative, waived AOGCC presence during the test. RD testing equipment. 05:30 - 06:30 1.00 PULL P DECOMP RU DSM lubricator to pull TWC and RD test equiprnent. 06:30 - 07:30 1.00 PULL P DECOMP Pull TWC and lay down DSM esquipment and lubricator. 07:30 - 09:00 1.50 PULL P DECOMP Changeout bails and RU to pull 4.5" tubing. 09:00 - 09:30 0.50 PULL P DECOMP MU spear BHA #1 and engage spear in tubing. 09:30 - 10:00 0.50 PULL P DECOMP Backout lockdown screws and pull hanger and tubing to RKB. String weight 130K. 10:00 - 10:30 0.50 PULL P DECOMP Break circulation. Pump dry job. 10:30 - 11 :00 0.50 PULL P DECOMP LD spear BHA #1. 11 :00 - 12:00 1.00 PULL P DECOMP LD tubing hanger. CO elevators, 12:00 - 15:30 3.50 PULL P DECOMP LD 4.5" completion tubing and spool control lines from SSSV. 15:30 - 16:00 0.50 PULL P DECOMP RD Schlumberger control line spooler after recovery of SSSV w/x-over pups w/50 bands recovered at surface. 16:00 - 22:30 6.50 PULL P DECOMP Continue laying down completion for a total of 224 jts. 4.5" tubing, 2 GLMs w/x-over pups, 1 cutoff stub = 21.72', 22:30 - 23:00 0.50 PULL P DECOMP RD tubing handling equipment and clear rig floor. 23:00 - 00:00 1.00 BOPSU P DECOMP RU and test lower pipe rams to 250 psi low side test, 3500 psi high side test. Test witnessed by Lowell Anderson BP WSL and Chris Weaver Nabors tourpusher. 5/18/2006 00:00 - 01 :00 1.00 EVAL P DECOMP RU Schlumberger E-line to run USIT log to determine cement top in 9-5/8" x 13-3/8" annulus. 01 :00 - 06:00 5.00 EVAL P DECOMP US IT log f/3000' MD to surface. Attempt to make 8,50" gage ring run to 2900'. 8.50" gage ring would not pass 70' below RKB. POH w/8.50" ring and RIH w/8.25" gage ring. No trouble to 2900'. Run & set 9 5/8" HES FasDrill bridge plug at 2588'. 06:00 - 07:00 1.00 EVAL P DECOMP RD Schlumberger wirelline equipment while testing 9-5/8" Printed: 6/1212006 9:42:31 AM e BP EXPLORATION Operations Summary Report Page 2 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-15C E-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 10/16/1981 End: 6/6/2006 Da.te From - To Hours Task Code NPT Phase Description of Operations 5/18/2006 06:00 - 07:00 1.00 EVAL P DECOMP casing from FasDrill at 2588' to surface, 1000 psi. Good test. 07:00 - 07:30 0.50 FISH P DECOMP MU Fishing BHA # 2 consisting of Baker multistring casing cutter w/knives sized for 9-5/8", X-over sub, stabilizer, and X-over sub. 07:30 - 09:00 1.50 FISH P DECOMP PU 65 jts of 4" drill pipe and AIH w/BHA #2. 09:00 - 10:00 1.00 FISH P DECOMP Cut 9-5/8" 47# casing at 2028'. PU wt. 60K, SO wt. 58K, 220 gpm, 900 psi, 90 rpm, 1 K tq. Casing cut through in 6 rnins. 10:00 - 10:30 0.50 FISH P DECOMP Break circulation pumping up 9-5/8" x 13-3/8" annulus. MU cement line. 10:30 - 12:30 2.00 FISH P DECOMP PJSM w/WSL, Hot Oil, crew, tool pusher, mud man. Purnp 50 bbls. 120 deg. diesel around and up 9-5/8" x 13-3/8" annulus to circulate out Arctic Pack. When hot diesel came up annulus returns were lost. Shut down and notified environmentalist Greg Guild as per remarks section of this report. Taking returns to the cuttings tank and to the cellar when pumping of diesel resurned. 2.5 bprn, 400 psi. Continued pumping 150 bbls of diesel while sucking out the portion of returns coming to the cellar w/vac truck. 12:30 - 13:00 0.50 FISH P DECOMP AD Little Aed Hot Oil and allow diesel to soak. 13:00 - 14:00 1.00 FISH P DECOMP Circulate 150 bbls. warrn seawater w/1 drum SafeSurf 0 surfactant. Stage pumps up to 5 bpm, 900 psi w/rams closed to clear 9-5/8" x 13-3/8" annulus. Still taking some returns to cuttings box and some to cellar w/vac truck removing fluid from cellar. Cellar returns decreasing. 14:00 - 14:30 0.50 FISH P DECOMP Open rams and circulate down drill pipe to clear 4" drill pipe x 9-5/8" annulus. 4.5 bpm, 700 psi. Now taking only slight returns to cellar w/rnost returns going to cuttings box. 14:30 - 15:00 0.50 FISH P DECOMP AD and BD. Leave vac truck stationed on cellar. 15:00 - 16:00 1.00 FISH P DECOMP Slip and cut 114' of drilling line. Inspect and adjust brakes. 16:00 - 16:30 0.50 FISH P DECOMP Service top drive and crown. 16:30 - 17:30 1.00 FISH P DECOMP POH w/Baker casing cutter BHA #2. 17:30 - 18:00 0.50 BOPSUF P DECOMP Pull wear bushing. 18:00 - 19:00 1.00 FISH P DECOMP MU fishing BHA # 3 consisting of Baker bull nose, spear packoff, ITCO spear for 9-5/8" 47# csg., spear extension, stop sub and X-over sub. Back out lock down screws. Pull 150K and see pipe pull free and continue pulling w/120K and drag to 150K. Pull 9-5/8" hanger, hanger pup and 1st 9-5/8" casing collar above AKB. 19:00 - 20:00 1.00 FISH P DECOMP LD 9-5/8" fishing BHA #3. 20:00 - 21 :30 1,50 FISH P DECOMP PJSM w/crew, WSL, tourpusher, mudman and discuss 9-5/8" casing lay down operation emphasizing avoidance of foot pinch point hazards when working with the 9-5/8" Baash Aoss false table. AU 9-5/8" casing pulling equipment. 21:30 - 00:00 2.50 FISH P DECOMP LD 20 jts. of 9-5/8' 47# casing using up to 40 K tq. w/rig tongs to break jts free. 25K of overpull on each jt when last 10' of jt. came above AKB. 5/19/2006 00:00 - 03:00 3.00 FISH P DECOMP POH and LD 30 jts. of 9-5/8" casing and stub 17,52' OAL 25K of overpull on each jt when last 10' of jt. came above AKB. Breakout torque on last 5 jts averaged 35K. No centralizers found on any joints removed. 03:00 - 04:00 1.00 FISH P DECOMP AD 9-5/8" casing handling equipment. 04:00 - 04:30 0.50 FISH P DECOMP Install wear bushing 04:30 - 07:30 3,00 FISH P DECOMP PU Baker fishing BHA # 4 w/1 jt. 11-314" washpipe, and 13-3/8" Printed: 6/1212006 9:42:31 AM e Page 3 ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-15C E-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date From - To Hours Task Code NPT Phase 5/19/2006 04:30 - 07:30 3.00 FISH P 07:30 - 08:30 1.00 FISH C 08:30 - 10:00 1.50 FISH C 10:00 - 11 :00 1.00 FISH C 11 :00 - 11 :30 0.50 FISH C 11 :30 - 12 :00 0.50 FISH C 12:00 - 18:30 6.50 FISH C Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 10/16/1981 End: 6/6/2006 Description of Operations DECOMP scraper. Start in hole. No-go at 70'. DECOMP LD BHA #4. DECOMP PU BHA # 5 including drill collars and 11.5" OD casing swage. DECOMP Attempt to swage casing open at 70'. No progress. DECOMP LD BHA #5. DECOMP PU BHA # 6 consisting of 12" OD tapered mill, bumper sub, oil jars, x-over, 3 drill collars. DECOMP Mill casing f170' to 82'. 2 bprn, 25 psi, 80 rpm, 2K tq. on, .5K tq. off. Taking returns through cellar up conductor. Pump out cellar w/vac truck. Work rnill ukp and down through bad spot until no drag. POH w/ BHA # 6 and CO to 12.25 OD rnill and record as BHA #7. Mill f170' to 83'. 2 bpm, 25 psi, 80 rpm, 4-5K tq. on, .5K tq. off. Taking returns up conductor into cellar and pumping out w/vac truck. Work mill up and down through bad spot until no drag. LD BHA #7. Clean floor. PU BHA # 8 including washover rnill shoe, 1 jt. washpipe, washover boot basket, x-over, bumper sub, oil jars, x-over sub, 9 drill collars. RIH w/BHA # 8 to top of stub at 2028'. Wash down 31' w/washpipe assy. f/2028' to 2059'. Up wt. 85K, SO wt. 83K, Rot. wt 85K, 170 gpm, 35 psi, rpm 18, tq. .7K. Tag and SO 5K w/ washpipe shoe at 2059'. CBU and pump soap sweep around. 58 gprn, 35 psi, reciprocate washpipe 20'. Taking returns to cellar and sucking out w/vac trucks. POH w/BHA #8 to BHA. LD BHA #8. Clean rig floor. PU BHA #9 consisting of mule shoe, x-over sub, 9 drill collars, x-over sub below Baker 9-5/8" 47# backoff assy. consisting of lower anchor, back off tool, upper anchor, x-over sub, pump out sub, x-over sub. DECOMP RIH w/backoff assy. BHA #9 filling ea. jt. w/clean fresh water. Tag up on top of stub at 2028' w/stop on backoff tool assy. indicating that backoff tool is correctly positioned inside stub. Bottom of drill collars below backoff assy. at 2329' (drill collar weight necessary to actuate lower anchor portion of backoff assembly). Pressure up on drill pipe to 4200 psi. Increase pressure on drill pipe w/test pump to 5000 psi. and see connection break loose. Back off casing 5.25 turns. Drop ball and pressure up to 1400 psi to open pump out sub. POH f/2329' to 323' wlbackoff assy. LD BHA #9 and clear rig floor. PU Spear BHA #10 consisting of bull nose, spear packoff, ITCO type spear, spear extention, stop sub, bumper sub, oil jar, xover sub. RIH hole w/BHA # 10 and engage stub to spear stop sub. Turn 6 turns to left and come free at 9-5/8" collar. POH w/BHA # 10 and stub of 9-5/8" casing. LD BHA # 10 and 21.4' of 9-5/8" casing stub w/thread down, 18:30 - 20:00 1.50 FISH C DECOMP 20:00 - 21 :00 1.00 FISH C I DECOMP 21 :00 - 22:00 1.00 FISH C I DECOMP 22:00 - 00:00 2.00 FISH P DECOMP 5/20/2006 00:00 - 01 :30 1.50 FISH P DECOMP 01 :30 - 02:00 0.50 FISH P DECOMP 02:00 - 03:00 1.00 FISH P DECOMP 03:00 - 04:00 1.00 FISH P DECOMP 04:00 - 06:30 2.50 FISH P DECOMP 06:30 - 08:30 2.00 FISH P DECOMP 08:30 - 10:30 2.00 FISH P 10:30 - 12:00 1.50 FISH P DECOMP 12:00 - 12:30 0.50 FISH P DECOMP 12:39 - 14:30 2.00 FISH P DECOMP 14:30 - 15:30 1.00 FISH P DECOMP 15:30 - 16:00 0.50 FISH P DECOMP 16:00 - 17:00 1.00 FISH P DECOMP 17:00 - 18:30 1.50 FISH P DECOMP 18:30 - 19:00 0.50 FISH P DECOMP Printed: 611212006 9:42:31 AM e BP EXPLORATION Operations Summary Report Page 4~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E -15C E-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 10/16/1981 End: 6/6/2006 Date From - To Hours Task Code NPT Phase Description of Operations 5/20/2006 18:30 - 19:00 0.50 FISH P DECOMP collar left in hole, (Total jt. recovery 50 jts + 21.4' + 17.52 = 38.92'.) Inspect threads on stub, threads in good shape. 19:00 - 20:00 1.00 FISH P DECOMP RU to run 9-5/8" csg. and pull wear ring. 20:00 - 20:30 0.50 CASE P DECOMP PJSM w/all hands and WSL on 9-5/8" casing handling. Cover hazards w/side door elevators and positioning while picking up casing. Cover foot pinch hazards associated w/false table use. 20:30 - 00:00 3.50 CASE P DECOMP Run 9-5/8" 47#, BTC-M, L-80 casing f/jt #1 to # 37to 1518'. Average MU tq. = 8.6K. 5/21/2006 00:00 - 01 :30 1.50 CASE P DECOMP RIH w/9-5/8" 47# BTC-M casing f/jt. 37 to jt. 50 + 15' pup to bring casing above RKB. 01 :30 - 02:00 0.50 CASE P DECOMP MU Baker 9-5/8" 47# BTC-M triple joint sub w/pin down into 9-5/8" 47# BTC-M casing collar looking up at 2050' by circulating down over collar w/triple jt. kick over skirt. Tag up. Up wt 125K, SO wt 120K, Rot wt 125K, Tq limiter set at 8.5K. SO w/ 126 gpm, 20 rpm, 25 psi, returns to vac truck via cellar, and MU pipe 9.5 turns to torque limiter. Increase tq. limiter to 11.0 K and work pipe up and down. Get one more turn for total of 10.5 turns and 11.0K. Pull test 200K. 02:00 - 02:30 0.50 CASE P DECOMP Test to 3500 psi, 9-5/8" casing f/FasDrill plug at 2588' to surface w/chart for 30 mins. Straight line. 02:30 - 03:00 0.50 CASE P DECOMP RD casing running equiprnent and clear floor. 03:00 - 05:00 2.00 BOPSUF P DECOMP Split BOP stack and install 9-5/8" emergency slips. Hang off casing w/100K Ibs. on slips. 05:00 - 06:30 1.50 BOPSUF P DECOMP RU and cut 9-5/8" casing off w/Wachs casing cutter. LD I casing stub and 15' pup jt. 06:30 - 08:00 1.50 BOPSUF P DECOMP RU and install packoff. Test sarne. 08:00 - 10:00 2.00 BOPSUF P DECOMP NU BOPs. Body test same. 10:00 - 10:30 0.50 CASE P DECOMP PU TAM port collar shifting tool. 10:30 - 12:00 1.50 CASE P DECOMP RIH to 2039'. 12:00 - 12:30 0.50 CASE P DECOMP PJSM w/crew, WSL, toolpusher, service hands. RU head pin and cementing hose. Up wt. 63K, SO wt 60K. SO and open TAM port collar at 2039' w/10K down weight. Pump 3 bbls to verify tool is open. RU Schlumberger cement trucks. Batch mix slurry , 12:30 - 13:30 1.00 CASE P DECOMP Break circulation at 12:37 w/Schlumberger and pump 5 bbls. water. Pressure test to 3500 psi and check all lines. 12:42 start pumping batch mixed 135.5 bbls of 11.5 ppg LiteCrete w/GasBlok + additives. Avg. pump rate 5.5 bbls/min. Taking good returns to cellar removing w/vac truck. Start pumping at 550 psi. Final lifting pressure at pumps 980 psi. Pump 5 bbls of fresh water displacement w/Schlumberger to clean lines. Switch to rig pumps, Displace cement two bbls short of TAM combo tool w/13bbls of 8.5 ppg seawater. Total displacement = 18 bbls. 167 gpm, 450 psi. Rotate per T AM/PES rep and PU to close TAM port collar w/20K overpull. CIP at 13:20. Pressure down drill pipe to 1000 psi to verify TAM port collar closed. Tested ok. PU 3' wfTAM combo tool and blow choke open w/2300 psi to allow circulation. Add retarder to 7 bbls of cement in cellar and remove w/vac truck. Total of 3 test @ 1000 psi to ensure TAM collar remained closed. 13:30 - 15:30 2.00 CASE P DECOMP Circulate heated seawater at 290 gpm, 235 psi. for two hrs. 2 bbls cement back to surface at bottoms up, RD headpin, BD Printed: 611212006 9:42:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/21/2006 5/22/2006 5/23/2006 e PageS .. BP EXPLORATION Operations Summary Report E-15C E-1S REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Frôm - To Hours Task Code NPT Phase 13:30 - 15:30 15:30 - 17:30 17:30 - 19:30 19:30 - 21:00 21:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 06:30 06:30 - 08:00 08:00 - 11 :30 11:30 -13:00 13:00 - 14:00 14:00 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 21:00 21 :00 - 21 :30 21 :30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 11 :30 2.00 CASE P 2.00 CASE P DECOMP DECOMP 2.00 CLEAN P DECOMP 1 ,50 CLEAN P DECOMP 1.00 CLEAN P DECOMP 1.00 CLEAN P DECOMP 1.00 CLEAN P DECOMP 0.50 CLEAN P 6.00 CLEAN P DECOMP DECOMP 1.50 CLEAN P DECOMP 3.50 CLEAN P DECOMP 1.50 CLEAN P 1.00 CLEAN P 2.50 CLEAN P 0.50 CLEAN P 1.00 CLEAN P DECOMP DECOMP DECOMP DECOMP DECOMP 3.00 WHIP P WEXIT 0.50 WHIP P 1.00 WHIP P 1.50 WHIP P 2.50 WHIP P WEXIT WEXIT WEXIT WEXIT 0.50 WHIP P WEXIT 1.50 STWHIP P WEXIT 7.00 STWHIP P WEXIT Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 10/16/1981 End: 6/6/2006 Description of Operations lines. Add retarder to all cernent returned through pits. POH wfTAM combo tool and LD. MW 8.5 ppg in / out. Clean rig floor. PU Cleanout BHA # 11 consisting 01 8.5" Srnith tri-cone bit, 2 boot baskets, bit sub, bumper sub, oil jar, xover, 3 drill collars, xovers, and 15 jts 4" HWDP. RIH 1/576' to 2395'. Tag and take wt at 2395'. Test 1000 psi after we passed thru TAM collar @ 2039 ft to ensure collar stayed closed. Ream arctic pac f/2395' to 2587'. 80 rprn tq on 2K, tq. off .5K, 211 gpm, 240 psi. Up wt. 80K, SO wt 80K, Rot. wt 80K. Tag up on FasDrill plug at 2587'. Circulate bottoms up w/seawater and overboard residual ArcticPac to cuttings box until fluid cleaned up. Circulate 231 bbls, 225 gpm, 250 psi, 80 rpm. 1.5K tq. Drill up FasDrill bridge plug 1/2587' to 2590' and see it lall away. Service rig and topdrive. Clean Arctic Pack out of pits. PU 4" HT-40 drill pipe single and RIH to liner top at 9376'. PU wt 175K, SO wt 150 K, Rot. wt. 160K. Circulate 25 bbl. 80 vis sweep around. 550 gpm, 2300 psi., 80 rpm, 4.5K tq. Pump dry job and POH to BHA. MW = 8.5 ppg when pulling off bottom. LD cleanout BHA #11. RU Schlumberger wireline truck. RIH w/EZSV CIBP on wireline and set at 9285'. POH. RD Schlumberger wireline unit. Test casing w/3500 psi f/9285' to surface. Hold 30 mins and chart. PU whipstock BHA #12 consisting 01 bottom trip anchor, Baker Gen, 2 whipstock w/45K shear bolt, window mill, bit sub, upper string mill, 1 jt. 5" HWDP, float sub, mwd, ubho sub, bumper sub, 9 drill collars, xover, xover, 15 jts. 4" HWDP and RIH to 926', Surface test MWD equipment. Cut and slip 61' of drilling line. RIH w/whipstock BHA #12 to 3893'. RIH w/whipstock BHA #12 f/3893' to 9225'. Up wt. 188K, SO 160K. At 9225' orient whipstock 69 deg right of high side, 427 gpm, 1600 psi. RIH and tag up on EZSV at 9277' and slackoff 20K and set whipstock anchor, Attempt to PU 10K over string wt. to verify anchor is set. Shear bolt already sheared when anchor set. Slack off 20K again and PU second try. No overpull. Anchor set and bolt sheared early w/20K SO wt. Whipstock in place 69 deg. right of high side. Top of window = 9254' MD17905' TVD. Middle of window = 9263' MD17912 TVD. Bottom of window = 9271' MD17919' TVD. Circulate 429 gpm, 1655 psi to displace well to 10.8# LSND mud surface to surface. Up wt. 185K, SO 158K, rot wt 170K. Mill window from 9254' to 9271' + 21' of new hole from center of whipstock to 9283'. At 445 gpm, 2495 psi, rpm 117, tq. off = Printed: 611212006 9:42:31 AM · , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date BP EXPLORATION Operations Summary Report Page 6 .. E·15C E-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/16/2006 Rig Release: 6/7/2006 Rig Number: Spud Date: 1 0/16/1981 End: 6/6/2006 Description of Operations 5/23/2006 04:30 - 11 :30 From - To Hours Task Code NPT Phase 7.00 STWHIP P WEXIT 5.5K, tq. on. = 8.7K, WOB 8K. Confrim abilty to pass thru window with no rotation. WEXIT Circulate 20 bbl Hi-Vis sweep around at 446 gprn 2375 psi. 110 rpm, 7k torque. Mud weight in 10.8 ppg, Out 10.8 ppg. Recovered 290# of metal while milling 8-1/2" window WEXIT Rig up test equipment and perform FIT to equivalent mud weight of 11.8 ppg 410 psi. MD 9283', TVD 7923'. Rig down and blow down test equipment. WEXIT Pull out of the hole from 9283' to 835'. WEXIT Lay down BHA # 12, 9 drill collars, cross over sub, bumper sub, ubho sub, mwd, float sub, 1 joint 5" hwdp, upper string mill, bit sub, and window mill. String mill 1/32 out of full gauge. Window mill 3/16 out of full gauge. WEXIT Pull wear ring. Pick up ported sub and wash / jet BOP stack to remove any metal from BOP rarn cavities. Install wear ring WEXIT Pick up BHA #13, Hughes HCM605 8-1/2" bit, 1.15 deg 6-3/4" PDM motor, NM string stb, ARC, MWD, NM string stb. WEXIT Continue to pick up BHA #13, 2 NM drill collar, MN string stb, NM spiral drill collar, Float sub, Hyd jar, cross over sub. and run in the hole with 23 joints of 4" HT-HWDP. Shallow pulse test MWD at 909' OK. WEXIT Run in the hole from 909' to 8942' with 4" HT-40 drill pipe. Filling drill pipe at 3774',6640', 189 gpm 605 psi. WEXIT Mad pass from 8942' to 9142' at 300' an hour. WEXIT Run in the hole from 9142' to 9283'. Orienting 60 degrees right of high side, pass the bit thru window with out incident. BHA and stabs hanging up in window, work each stab through window while sliding INT1 Drill 8-1/2" hole section from 9283' to 9902' MD 8425 TVD. Up weight 195k, Slack off weight 150k, Rotating weight 165k rprn, 6k torque off bottom, 7 to 8k torque on bottom B 7 to 20k, 504 gpm 3640 psi, AST = .27 hours ART = 2.12 hours AST = 2.39 hours Jar hours = 63.39 INT1 Circulate up sa or Geo. to verify casing point at 503 gpm 3680 psi. ing and recipcating drill pipe at 100 rpm 6k torqu ud weight in 10.8 ppg. Out 10.8 ppg. ort trip from 9902' to 9223'. TOW at 9254'. Monitor well bore for 15 minutes, static Run in the hole from 9223' to 9902'. No problems. late Hi-Vis sweep around at 500 gpm 3540 psi. Rotating and rec ting drill pipe at 130 rpm 7k torque. Mud weight in 10.8 ppg. Ou ,8 ppg. INT1 Pull out of the hole 9902' to 2150'. Pumping dry job at 9539'. Drop 2-5/16" rabt5 stand 87. INT1 Continue to pull out of the hol m 2150' to 909'. INT1 Stand back 4" HT-40 HWDP. INT1 Lay down BHA #13, Cross over sub, Hy Float sub, NM spiral dc, NM string stab, 2 NM spiral dc, NM s' I stab, MWD, ARC, NM string stab, 1.15 degree PDM motor, Bit. 11 :30 - 13:00 13:00 - 13:30 13:30 - 18:00 18:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 5/24/2006 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 15:30 15:30 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 00:00 5/25/2006 1.50 STWHIP P 0.50 STWHIP P 4.50 STWHIP P 3.00 STWHIP P 1.50 STWHIP P 1.50 STWHIP P 1.50 STWHIP P 3.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 9.50 P 0.50 DRILL P 0.50 DRILL P 1.50 DRILL P P P P Printed: 611212006 9:42:31 AM E-15B (PTD #1990420) Internal Waiver Cancellation - Trouble Well - e All, An internal waiver was issued for a Surface Casing leak on well E-158 (PTD #1990420) on 07/12/03. The well is currently being sidetracked, cementing new 9-5/8" casing to surface, fixing the leak. The well will no longer require a SC leak waiver The well is reclassified as a Trouble well until the rig has moved off. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, }lnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~.' ~'..~ }lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of! 5/30/20064:36 PM Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 n_ Anchorage, AK 99501 a _ 0 If r- Field: Prudhoe Bay l q \ RECEIVED Scblumberger MAY 2 4 2006 NO. 3812 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1'1 d 4JasXa C4I & Gas 0-1lS. Cc~c;: And1c~ Well Job# Loa Descriction Date BL Color CD D-23A 10942207 MCNL Ie¡ G:: - h~ 04/22/05 1 (J)e ra¿·d·,t"'. L3-08 11136738 RST I /..(~ - I <../'7¡ 11/04/05 1 1 L3-08 11212839 RST 1.I,f ~ - t../3 03/29/06 1 1 03-14A 11212846 USIT ;::)CG'" r:J 7i- 04/24/06 1 D.S. 3-09 11212840 USIT 1'1'1 - ò ,p 03/31/06 1 D.S. 15·17 11221562 SCMT ì ~'-I- ()~ 04/10/06 1 NGI-08 11225958 USIT U'lC- l-r (..., -Ò;"¡~ 04/11/06 1 D.S.01-04A N/A USIT g6 I I~::J 05/06/06 1 12-08C 11221571 USIT riò;) - I :3 J.. 05/06/06 1 AGI-07 11221569 USIT U1::è:. \ "1:'1;,09"1- 05/05/06 1 E-15B 11212857 USIT Ie>,c~ -n4::J 05/18/06 1 L-50PB1 40012467 OH LDWG EDIT OF MWD/LWD ;"I{~ ..<:; - I ~ C-. 10118/05 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~;Jk- 6"/ e sfð~ 05/19/06 e e i~ ~ i~"\ ~~-::J :r-::E J,V..J ,\ 1 j'l~ \ l! :\',' " '\. . 1 I 1\\ 'I ' .,~, '''-. :', '1 I ; '\ I :1 ' ,-,.,:1 ì '\ II ,'-' " 'I l1') !; /;~\\ I ,~ ,"":;:.", ~>.J.~ w w "- (fn rç : I :111 1 \,~~:.~~) L /_... .-~ " /~-~\ :1-1 /~7 /1~\ I \ '. l' iT\ ,(1,..;;, I¡" if I' ., )l~ bLkt © ü\i¿¿~ 333 W "JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AlQ) GAS CONSERVATION COMMISSION Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 lqq# 04-'d- Re: Prudhoe Bay E-15B SCANNED f4UG 1 t'l2005 Sundry Number: 305-224 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decisi 0 Superior Court unless rehearing has been requested. (,....--... Si hl1 K. jrorma Chai?níán ~ DATED this /~day of August, 2005 Encl. C{l{ g~/~~cç W4^ ~fl~/lOOS- ( STATE OF ALASKA (" 0'15 df/(;15 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALRECE.IV~~~ 20 AAC 25.280 AUG 1 2 a~ l'L o 00.'1...... , o o1i\løska Oil & Ga . r ~ ~ o Re-Enter suspe~de8 W'éI1S. vommissio ì o Time Extension nchorage 1. Type of Request: 1m Abandon 0 Suspend 0 Operation Shutdown 0 Perforate o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11478 8987 11478 MD TVD Burst 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 65.04 8. Property Designation: ADL 028280 11. Total Depth MD (ft): 11772 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8994 Length Size 110' 20" x 30" 2671' 13-3/8" 9872' 9-5/8" 909' 7" 691' 4-1/2" 2087' 2-7/8" Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 10675' - 11478' 8949' - 8987' Packers and SSSV Type: 7" x 4-1/2" Baker 'SAB3' packer; 4-1/2" Otis SSSV Nipple 4. Current Well CI,ss: !HI Development D Exploratory D Stratigraphic D Service 9. Well Name and Number: 110' 2671' 9872' 110' 2671' 8391' 9381' - 10290' 9736' - 10427' 9685' - 11772' 8008' - 8720' 8283' - 8809' 8243' - 8994' Tubing Size: 4-1/2", 12.6# 5. Permit To Drill Number 199-042 ../ 6. API Number: "./ 50- 029-20668-02-00 E-158 /' Junk (measured): None COllapse 4930 6870 2670 4760 7240 8430 13450 5410 7500 13890 Tubing Grade: L-80 Packers and SSSV MD (ft): 9626' 2076' Tubing MD (ft): 9689' 13. Well Class after proposed work: / D Exploratory !HI Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance 12. Attachments: !HI Description Summary of Proposal D BOP Sketch D Detailed Operations Program '-ì 14. Estimated Date for ~ Commencing Operations: Septemb r 5.e 005 16. Verbal Approval: Dat . Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Namø:Da. Wesley Title Senior Drilling Engineer ,'. /././ / ) ~ /. _ /. _ Prepared By Name/Number: Signature ,/ .¿r4At.- .~rL~,-I/ . Phone 564-5153 Date !/tJ '1/tl~ Terrie Hubble, 564-4628 Commission Use Only Other: Test ßo (? E to 3çoo f?~¡. ~ D Plugged DWINJ // !HI Abandoned D WDSPL Contact Ken Allen, 564-4366 Sundry Number: c-? OS ) 2.b 30 5 - 2 ¿ Lj RBDMS BFl AllG 1 7 2005 APPROVED BY ~Lt .~ THE COMMISSION Date (S j I rJ O~ o l~ I G ! r~ A L bmit n Duplicate COMMISSIONER O~~~h"".' '- Jp I, ," "'" G~N4Yßa6r'" RECEIVED AUG 1 0 2005 Alaska Oil & Gas Cons. Corr.~mi~~s¡an Anchorage To: Winton Aubert - AOGCC Date: August 8, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: E-15B Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well E-15B. This conventional well is currently being cycled due to high GOR. The well is providing little production or value to the field ./ as it currently sits. Well E-15B is a 1999 sidetrackE;.h t)Nas completed in Zone 1A. In ~03 the well failed a MIT-OA and is currently on a surface . ~er. Due the surface casing wf;¿~er and high GOR this well ' became a candidate for a rotary-sidetrack. The surface casing bommunication problem will be rectified during the sidetrack operations by adding a 7" liner to surface. The intermediate casing /' has passed a MIT-IA for the last 3 years. The well, E-15C, will be kicked off in the Kingak formation and a 8-1/2" hole will be drilled to the intermediated 7" casing point at the top of the Sag River. A top job will be performed on the 13- / 3/8" annulus to eliminate the possibility of water entering, and damaging, the conductor by 13-3/8" annulus. A 7" tie-back will be run from the top of the new 7" liner to surface. The top 3,670' of the 7" tie-back will have premium connections. Cement will be brought up to -3,170' in the 9-5/8" by 7" annulus. A 6-1/8" 2,900' Zone 1 A horizontal will be drilled to the Northwest. A 4-1/2" solid liner will be run, cemented and perforated throughout the production interval. The E-15C sidetrack is currently scheduled for Nabors 2ES beginning around 12/05/05, after completing the Y-11 C sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Pre-RiQ Work: 1. Rig up slickline. Drift 4-1/2" tubing through WLEG. Tag and record top of 2-7/8" liner below WLEG. 2. Fluid pack the tubing and inner annulus. 3. RU e-line. Survey wellbore from the top of the 2-7/8" liner to surface. Send a copy of the surveys and reports to the Drilling Engineer at allenkw@bp.com so the new directional plan can be developed ASAP. lSi-' 4. Rig up coil. P&A perfs in 2-7/8" liner from the top of the HES CIBP at -11,478' inside the 4- 1/2" tubing at -9,550' MD. RIH with coil to the top of the 2-7/8" liner top. Lay i 1 ~/6bls of cement. Pull above cement top and squeeze away -5bbls if possible. Wash d Wh to confirm TOC -9,550' MD. POH with coil. a. Cement Calculations: · 2-7/8" liner = 11,478' - 9,711' or 1,767' (-10.1 BBLS) ~ · 7" liner = 9,736' - 9,689' or 47' (-1.8 BBLS) · 4-1/2" tubing = 9,689' - 9,550' or 139' (-2.1 BBLS) · Squeeze of -5 BBLS E-15B Application for Sundry OR\G\NAL · Total cement volume of 19 BBLS / 5. Rig up slickline, drift 4-1/2" tubing. Tag TOC. . 6. Chemical cut the 4-1/2",12.6#, L-80 tubing at - 9,450' MD. / ,Araska Oil & Gas Cí)n~~. tdj;"'~~!·;,:-;;,~jùfl 7. Circulate the well to sea water through the Chemical cut. Anch ::-'-'.1 8. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 pSI tor ?IdGlG minutes. 9. Freeze protect the IA and tubing with diesel to -2,200'. 10. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to ./ 5,000 psi. Function all lock-down screws. Repair or replace as needed. 11. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 12. Remove the well house. level the pad. Please provide total well preparation cost on the handover form. RECEI\/f:~) AUG 1 0 2005 -' RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull 4-1/2" tubing from the pre-rig Chemical cut -9,450'. Spool up SSSV control lines. 5. RU e-line. Run Gauge Ring I Junk basket and Gamma Ray tool for 9-5/8",47# casing with CCl to the top of the 7" liner at 9,381'. 6. RIH with 9-5/8" EZSV on e-line. Set EZSV at -9,305' to avoid cutting a casing collar during window milling operations. RD e-line. Close rams and pressure test the 9-5/8" casing and bridge plug. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH picking up 4" DP to EZSV. Orient and set the whipstock. Swap well over to 10.8 ppg milling fluid. Note: If MWD signals are too weak to obtain toolfaces, swap over to milling fluid before setting the whipstock. 9. Mill a window in the 9-5/8" casing at ±9,285' MD plus 20' from mid window. Perform FIT to 11.8 ppg. POOH for Drilling BHA. Note: Verify that the mud weight is 10.8 ppg prior to cutting the window. 10. MU the 8-1/2" drilling assembly with DIR/GR/RES and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top Sag River. 11. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to -9,135' MD. Set hanger I liner top packer and displace cement with mud. Displace entire wellbore to fresh water and POOH. 12. RU and run 7" Tie-back liner to surface. Top 3,670' of 7" will have premium TC-II threads. Cement will be brought up to -3,170' MD. Remainder of 9-5/8" by 7" annulus will be freeze protected to surface. 13. Perform a top job on the conductor by 13-3/8" annulus. 14. MU 6-1/8" BHA with DIR/GR/RES/ABI and RIH on 4" DP to the 7" tie-back landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. 16. Drill tie-back cementing equipment and RIH to 7" drilling liner landing collar. 17. Pressure test wellbore to 3500 psi for 30 minutes. 18. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 9.8 ppg. 19. Drill the 6-1/8" production interval building to -90°, targeting Zone 1 formation. POOH. 20. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU/ABI and drill ahead to an estimated TO of 12,839' MD. 21. Run and cement a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" liner 150'. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A perf pill will be left in the 4-1/2" liner. 22. RIH with OPC perf guns, Perf intervals to be determined from LWO logs. Plan to perforate overbalance. POOH, LO OP and perf guns. 23. Run the 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 24. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 7. rk£ç I o-~ 40"S 8. ~)r ~"A. t. E-158 Application for Sundry ORIGINAL 25. Set and test TWC. 26. NO BOPE. NU and test the tree to 5,000 psi. 27. Freeze protect the IA and Tubing to -2,200' and secure the well. 28. RDMO. "R E C E ¡ \/j~:~' ;:'~ AUG 1 () .200S .A'a$IŒ Oil & D"' ~ , "-...(,~.;,,\ ..,- \J~~~, Post-RiQ Work: AfI(;j;J;:~~~' 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-Rig Start: Estimated Spud Date: 09/05/05 12/05/05 Ken Allen Operations Drilling Engineer 907.564.4366 E-15B Application for Sundry OR\GINAL Est TOC - 2,200' ~ - 113-318" CSG. 7211. L-BO. ID = 12.347" H 2670' J TREE = waLHEAD= ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 6" CrN FMC BAKER 65,04' 32.21' 3304' 98 @ 11350' 1 0520' 8800' SS E-15B Current ~, . j e L Est TOC - 6,950' -.- I TOP OF 7" LNR 1--1 9381" Minimum ID = 2.37" @ 9711' TOP OF 2-7/8 LINER 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1--1 9689" TOP OF 2-7/8" LNR 1--1 r TOP OF 4-1/2" LNR 1--1 9711" 9736" 9-5/8" LNR, 47#, L-80, .0732 bpf, 10 = 8.681" 1--1 9872" TOP OF WHIPSTOCK 1--1 10427" I CIBP 1--1 10520" ÆRFORA TION SUMMARY REF LOG: SPERRY SUN MWD-GR ON 06/03/99 ANGLE AT TOP ÆRF: 69 @ 10675' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10675 - 10750 0 03/03/02 2" 4 10790 - 11000 0 06/05/99 2" 4 11 064 - 1111 0 0 06/05/99 2" 4 11300 - 11440 0 06/05/99 2" 4 11470 - 11560 C 08/26/99 2" 4 11590 - 11700 C 08/26/99 I 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1--1 10801" DATE 10/01/81 12/19/94 06/04/99 03/04/02 06/27/03 07/22/03 REV BY COMMENTS ORIGINAL COM PLETION ML SIDETRACK (E-15A) HUPP SIDETRACK (E-15B) RNlTP CORRECTIONS JRC/KK GL V CORRECTIONS ATD/TLH WAIVER SAFETY NOTE ~ 'I ....1 f -:eTY NOTES: ***SURFACE CASING LEAK. ~r'ERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 100 PSI (07/12/03 W AlVER)*** 70° @ 10701' AND 90° @ 11035' J> 1 ~ ~ 2076" 1--14-1/2" OTIS SSSV NIP, ID = 3.813" 1 2600" 1--19-5/8" DV PKR 1 GAS LIFT MA NDRELS ST MD TVD DEV lYÆ VLV LATCH 2 4418 4187 41 MER DMY RM 1 7881 6817 40 MER DMY RM '¡¡þ I ~ I ~ . « PORT DA TE o 04/15/04 o 04/15/04 RECEIVFfi AUG 1 0 2005 1--1 ~~~,ki!rR~I~tii¥®6~.813::;;.kn., 'k.,..~.íi Anchrm;¡p'~!1 1--11" X 4-1/2" BAKER SAB~ PKR, 10 = 3.875" . t ~ I',j . I' , 9605" 9626" 9660" 1--14-1/2" OTIS X NIP, ID = 3.813" 1 9677" 1--14-1/2" OTIS XN NIP, MILLED TO 10 = 3.80" 9689" 1--14-1/2" WLEG 1 9701" 1--1 ELMO TT LOGGED 08/05/99 1 9711" I--IDEPLOYMENTSLEEVE 1 MILLOUT WINDOW 10406' - 10412' 111478" ctml- 2-7/8" HES CIBP(PUSHED DOWN / FROM 11450') 08/01/03 WSR 12-7/8" TBG, 6.16#, L-80 STL, .00579 bpf, ID = 2.441" l-i 11772" 1 ~ l ~ L (i~ .'~ ( I ~I$ ;~ . ~'" "". . OA TE REV BY COMMENTS 09/17/03 CMO/TLP ÆRF ANGLE CORRECTION 02/26/04 A Y/TLP CIBP PUSHED DOWN - 08/01/03 04/15/04 JLJKAK GLV C/O j .:' .. ~ PRUDHOE BA Y UNIT WELL: 6-15B ÆRMIT No: 1990420 API No: 50-029-20668-02 SEC 6, T11 N, R14E, 903' FNL & 501' FEL BP Exploration (Alaska) TREE = 6" C~ WB..LHEAD/= FMC ACTUATOR = SAKER Kg, ELEV = 65,04' SF. ELEV' = 32,21' KOP = 3304' Max Angle = 98 @ 11350' ~~~ ~~~-3/8" :~5:~, L-80, ID = 12.347" ~: TOC26::~O' ) E-15B Pre-Rig I) . .1 - L Est TOC - 6,950' -". I TOP OF 7" LNR l-i 9381' TOC P&A - 9,550' Minimum ID = 2.37" @ 9711' TOP OF 2-7/8 LINER 14-112" TSG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9689' f "®; · " . :"1 . :¡¡ ~ ~ « I I~ I) . i' EY NOTES: ***SURFACE CASING LEAK. 'L.-ERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 100 PSI (07/12/03 WAlVER)*** 70° @ 10701' AND 90° @ 11035' 2076' li4-1/2" OTIS SSSV NIP, ID = 3,813" I 2600' 1-19-5/8" DV PKR 1 GAS LIFT rv1ANDRB..S ST MD lVD DEV TYÆ VLV LATCH FDRT DATE 2 4418 4187 41 MER DMY RM 0 04/15/04 1 7881 6817 40 MER DMY RM 0 04/15/04 RECEIVED AUG 1 0 Z005 .Alaska Oil & Gas C~:ms. Cmnrni~8¡òn Am:hma~le "') 9,450'<.Øéut I 9605' 1-14-1/2" OTIS X NIP, ID = 3.813" 1 I 9626' 1-17" x 4-1/2" SAKER SAS3 PKR, ID = 3.875" I 9660' 1-14-1/2" OTIS x NIP, ID = 3.813" 1 I 9677' 1-14-1/2" OTIS XN NIP, MILLED TO ID = 3.80" I 9689' l-i 4-1/2" WLEG 1 I:.,~ 1 9701' l-i ELMD TT LOGGED 08/05/99 I o:¡ 1 9711' I-iDEPLOYMENT SLEEVE 1 « .,IN ~'.,. I", I TOP OF 2-7/8" LNR 1-1 9711' · 1 TOP OF 4-1/2" LNR l-i 9736' · ~ 9-5/8" LNR, 47#, L-80, .0732 bpf, ID = 8.681" l-i 9872' TOP OF WHIPSTOCK l-i 10427' I CISP l-i 10520' ÆRFORA TION SUMrv1ARY REF LOG: SPERRY SUN MWD-GR ON 06/03/99 ANGLE AT TOP ÆRF: 69 @ 10675' Note: Refer to Production DS for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 10675 - 10750 0 03/03/02 2" 4 10790 - 11000 0 06/05/99 2" 4 11064 - 1111 0 0 06/05/99 2" 4 11300 - 11440 0 06/05/99 2" 4 11470 - 11560 C 08/26/99 2" 4 11590 - 11700 C 08/26/99 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 10801' DATE 10/01/81 12/19/94 06/04/99 03/04/02 06/27/03 07/22/03 REV BY COMMENTS ORIGINAL COM PLEfION M L SIDEfRACK (E-15A) HUPP SIDEfRACK (E-15B) RNlTP CORRECTIONS JRC/KK GL V CORRECTIONS A TD/TLH WAIVER SAFErY NOTE ....il~ 'I " \1 .", .~ ;,~ .: ~f/I MILLOUT WINDOW 10406' - 10412' 4 ,111478' ctml- 2-7/8" HES CISP(PUSHED DOWN FROM 11450') 08/01/03 WSR 2-7/8"TBG,6.16#,L-80STL,.00579bpf,ID=2.441" l-i 11772' 1 .. ~ \ ' '\".,) "II' i \ I. \:. L DA TE REV BY COMMENTS 09/17/03 CMO/TLP ÆRF ANGLECORREeTION 02/26/04 A Y /TLP CISP PUSHED DOWN - 08/01/03 04/15/04 JLJKAK GLV C/O PRUDHOE BA Y UNIT WELL: E-15B ÆRMrT No: 1990420 API No: 50-029-20668-02 SEe 6, T11 N, R14E, 903' FNL & 501' FB.. BP Exploration (Alaska) Est TOC - 2,200' ~ .- .f= ~ TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 6" CNV FMC BA KER 65.04' 3221' 8800' SS E-15C Proposed Completion ~¡I; . t '" . -2,200' - HES 4-112" X Nipple ID = 3,813" . . II: :::,LI . GAS LIFT MANDRELS DEV 1YÆ VLV dmy dmy dmy dmy LA TCH PORT 2600' 1-19-5/8" DV A<R 1 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2670' TOC - 3,170' - 7" L-80, 26# TC-II - -3,670' Est TOC - 6,950' -00 ',_ I _Ii,¡ ., ]~~ . ST MD lVD 4 3 2 1 .-J ~ . 4' ~, .- ",:I~'" . , .. i;:~) (f "f ~r¡,,~ 7" Seal Assy stung into Tieback sleeve -9,135' ~. ..':~':. 7" L-80, 26# BTC-M - -9,135' "':i: I 9-5/8" x 7" LNR Top PKR & HGR -9,135',~ !lIe, . . REC,EIVE.D AUG 1 0 2005 .. Top of Window - -9,285' -----. ~!;~ I TOP OF 7" LNR 1-1 9381' I~ .... ~ \~ Itl Alaska Oil & Gan C911;'¡' GOImníssion -9,703' HES 4JMt~tM~rè ID = 3.813" -9,725' BKR 7" x 4-1/2" BKR PKR ¡ -9,751' HES 4-1/2" X Nipple ID = 3.813" '.. -9,773' HES 4-1/2" XN Nipple ID = 3.725" <II, -9,785' 4-1/2" WLEG TOC P&A - 9,550' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 I TOP OF 2-7/8" LNR 1-1 1 TOP OF 4-1/2" LNR l-i 9-5/8" LNR, 47#, L-80, .0732 bpf, ID = 8.681" 1-1 TOP OF WHIPSTOCK 1-1 I CIBP 1-1 9689' 9711' 9736' 9872' 10427' 10520' ÆRFORA TION SUMMARY REF LOG: SPERRY SUN MWD-GR ON 06/03/99 ANGLE AT TOP ÆRF: 69 @ 10675' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10675 - 10750 0 03/03/02 2" 4 10790 - 11000 0 06/05/99 2" 4 11064 - 11110 0 06/05/99 2" 4 11300 - 11440 0 06/05/99 2" 4 11470 - 11560 C 08/26/99 2" 4 11590 - 11700 C 08/26/99 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 10801' DATE 10/01/81 12/19/94 06/04/99 03/04/02 06/27/03 07/22/03 REV BY COMMENTS ORIGINAL COM PLETION M L SIDETRACK (E-15A) HUPP SIDETRACK (E-15B) RNlTP CORRECTIONS JRC/KK GL V CORRECTIONS A TD/TLH WAIVER SAFETY NOTE DATE 09/17/03 02/26/04 04/15/04 07/18/05 !,[ I .~ 7"x5" BKR ZXP PKR & HGR -9,783' .ø . ;....- 7" LNR 26#, L-80 BTC-M -9,933' .I~~ .. .~ ¢~;~ i':'~\' :' >:::";,:",,,::<,,:I:,;~;\:. d" II!> '.! .".,;í~": ~ ' ·'to . . ·.·.A fI ,j ~ìÄ 1 .... ·..111 ~" PBTD -12,739' ~ I"'·W \ .: 4-1/2" LNR 12.6#, L-80 IBT-M -12,839' .. Nt AA' -:-. ~~, 111478' ctml- 2-7/8" HES CIBP(PUSHED DOWN FROM 11450') 08/01/03 WSR I PBTD 1-[ 11705' MILLOUT WINDOW 10406' - 10412' \ 12-7/8" TBG, 6.16#, L-80 STL, .00579 bpf, ID = 2.441" 1-1 11772' .. I, 'I L ~ REV BY COMMENTS CMO/TLP ÆRF ANGLE CORRECTION A Y /TLP CIBP PUSHED DOWN - 08/01/03 JLJKAK GL V C/O KWA Proposed Completion WP02 PRUDHOE BAY UNIT WELL: E-15C ÆRMIT No: API No: 50-029-20668-03 BP Exploration (Alaska) Memorandum State of Alaska Oil and Gas Conservation Commission To: PBV E-15B File - 194-134 PBV E-15C File - 205- ??? Fm: Jack Ha~ Subj: PBV E-15B Recompletion Evaluation August 11, 2005 PBV E-15B is a Prudhoe Oil Pool producer and is the 2nd sidetrack from the E-15 well bore. E-15A and E-15B were Zone 1 producers, both of which reached marginal GOR. E-15B last produced in October 2004 at 556 BOPD and 45300 SCF/STB GOR and 1 % water cut. The well cycled at 160 to 570 BOPD since April 2000 for 1-25 days per month with several shut-in periods each year. Decline curve remaining reserves (unconstrained) range from 735 MBO (exponential decline) to 1800 MBO (harmonic decline). E-15, 15A and 15B appear to be draining the same area and their composite decline and production graph look as though they are one well. Cumulative production from E-15B is 506MBO and the E-15, 15A and 15B composite production has been 8.5MMBO. PBV E-15C is being sidetracked from E-15B with a 2900' horizontal section and will continue to drain to Zone 1. In addition, the well has had OA communication since 2003. The OA communication will be repaired during the sidetrack operation. No other obvious alternatives are apparent. Conclusion: PBO E-15B has mechanical OA communication problems that need to be repaired. The GOR has reached marginal proportions and cycling is not adding substantial production. Recommend approval of the Sundry to plug PBV E-15B and the E-15C sidetrack to Zone lA for continued drainage of Zone 1 Reserves. jdh 8/11/2005 DATE I I II lib' II II I I I I I I I ! II I I I I II I I I ' I' I' I I I I I I I I I I I I I I I I I I I' 98 200 02 04 06 08 10 12 14 16 18 20 22 24 19161 10- I I ' I ' I I I I I I I Ii' I I I I I I I I I i I '982 84 86 88 90 92 94 Forecast Ended By : Rate DB Forecast Date : 08/11/2005 Parameters :O¡I : SideTrackTEval :0 : 0.20242 A.e. : 556.4 bbl/d : 06/01/2005 : 01131/2013 : 98.2018 bbl/d : 8509.61 Mbbl : 01/15/2005 : 739.948 Mbbl : 9249.56 Mbbl Working Forecast Phase Case Name b Di qi ti te Final Rate Cum. Prod. Cum. Date Reserves EUR E-15, E-15A & E-15B Composite Historical Performance PRUDHOE BAY, PRUDHOE OIL 50 - 100- "'C 5ì!0 ~ 5' a... - - Q) - m c:: ð 1000 - 5000 - 10000 - 5 1 0 =cuu u' PRUDHOE BAY, PRUDHOE OIL 100 .. ..-.--- ... - -.----- ._'. --.-. .:._--- ----- '- ;.---.------ ---- ---.----,----- -- 10< p;~l~. 3 "\ ~,~ m,1"'<YT· 1021,... ...J,"-Wt, ~ \ ,.... , · ~ ~'r "11, 10 -= ~! f ¿i-t~u~....r t ~ ~ 1":: I o -j'\':-;; i~ .~ &Wd~l' :~ ! : ~ ~ !t ' ~ : 1 0 -= +: ~ !! ..:::'" . ~ t 1 10 -= ~ E-15-15A-15B_Composit Oil Rate (CD) ( bbVd ) un__A. Water Rate (CD) (bblld ) Water Inj Rate (CD) ( MbbVd ) .. t Gas Rate (CD) ( MMcf/d ) -2 · · Gas I Oil Ratio ( cf/bbl ) 1 0 "'''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''"I'''''I'''''I''''' '''''I''''' '''''I'''''I'''''I'''''I'''''I''''' '''''I''''' '''''P'"'I'''''I''"'1""'1"'''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''''1'''"1''''' 1982 84 86 88 90 92 94 96 98 2000 02 04 -.. AdA -1 1 0 --::C. 1.0 0.8- 0.6- 0.4- 0.2- 50- E-15, E-15A & E-15B Composite Historical Performance I I I I I I I E-15-15A-15B _ Composit Cum Oil Prod ( MMbbl ) Cum Gas Prod ( MMMcf ) Cum Water Prod ( MMbbl) - , ,-- /" I[ I f I I I 1-fT: J 0.1 11111111I111111I)1111I11I11111I1111I1111111I11I1111111111I1111111111111111I111111I11111I1111I111I1111I111111111111I111I111111I111I111111111111I1111I111I111111I111I1111I111"11I111111"11I111111'111111111111I111111I1"11I 111II l1I1111I1I11II1I 1111I111I11 III II I II II 10 5 0.5 1982 84 98 2000 02 04 86 88 90 92 94 96 5000 . PRESS E-15-15A-15B_Composit I 4000 - . . . .. . 3000 - 2000 - 5 10 ~.m PRUDHOE BAY, PRUDHOE OIL 100 104-= .~... ....... "u~ ~........ .".".. .. 103 2 10 -=u V\ ,Q,.,..,.,.'.,."'.',"',.'.,....',.."',1,'.,,,·.'.· ',:.',...,. /}\\u,,',., .,',....., "., .u,..,.,',.·.",·,\...,·,·,.·..·..,. ",'..".",.".,."." ,... ..%,' ,..~....J':... ...~ u· uu .... .....J:....·.'...·.·.··......f\ , 1 10 :: 1'£ ;}:.; ',..,.,".~,';....... ?t-..../ liT.': I t-- - : _'--_·.·-~C.· t' '11 . uul I , . ! \(: 'I,j,::' .,.u'..u,: ,..:, ..., :,',.\, .' I .. . ;t , ¡ I -1 10 10°=. \ 029206680200: 150 Oil Rate (CD) (bblld ) ...-.... Water Rate (CD) (bbl/d ) Water Inj Rate (CD) ( Mbblld ) .'" '11 t Gas Rate (CD) (MMcf/d ) -2 - , .. Gas I Oil Ratio ( cf/bbl ) 10 "'" I"'" I"'" I"'" I'" "I"" 'I"" 'I'" "I ' ,., I""'!"" 'I"'" I'" , I' , , , 1999 01 03 05 1.0 0.8- 0.6- 0.4- 0.2- 50- 10 0.5 0.1 E-15B I 029206680200: 150 Cum Oil Prod ( MMbbl ) Cum Gas Prod ( MMMcf) Cum Water Prod ( MMbbl ) 5 1 / / ~, '" / / I I I I I II I I I I I I I I I II I I I I I I I I I II I I I I I I I I I II ; I I I I I , I I II I I I I I I I I I II I ! I I "'''1'''''\ 05 5000 4000 - 3000 - 2000 - / 1999 01 03 . PRESS 029206680200: 150 I 0.0 I i I I I I I I I I I II I I I I I I I I I I , I I ; I I I ! I I I I I' I ! I I I I I I I I II I I I I I I I I I I II ! I I I I I 1 I I I II I I I I I I I I I 1000 I I I I I I I I i I I II I I I I I I I I I I I I I I I I I I I , I I II I I I I I I I I I I I' I r I I I I I I I I I' I I I I ¡I I I I I' I I I I I I I , I I 1999 01 03 . 05 1999 '01 03 05 10000 - 5000 - "C - :c ..c o 1dèo - Q) - - co a::: ð - 500 - PRUDHOE BAY, PRUDHOE OIL E-15B 100- I I I I I 1999 01 Working Forecast Parameters Phase : Oil Case Name : SideTrackTEval b :1 Di : 0.150724 A.e. qi : 556.4 bbl/d ti : 06/01/2005 te : 06/30/2025 Final Rate : 129.988 bbl/d Cum. Prod. : 506.173 Mbbl Cum. Date : 01/15/2005 Reserves : 1808.76 Mbbl EUR : 2314.93 Mbbl Forecast Ended By : Time DB Forecast Date : 08/11/2005 I I I I I I I I 03 05 I I 07 I I I 09 ¡ I I I i I I I I I 11 13 15 DATE I I I I I I I I I I I I I I I 17 19 21 23 i I 25 ~iDA Schlumbel'gel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well E-15B L5-05 02-07 A L5-09 OWDW-SE L5-09 L5-09 Y -06A Y-03A Job# 10861913 10866591 10772244 10672350 10672381 10679071 10893030 10913004 10877803 SCANNED JUN 1 r12005 Log Description MCNL 11Cf - D &.( L RST /51'7- Ofð9 RST . ¡q)[- 107 RST Ie¡ 0 - {2. '-/ RST /tJV - ;{.?/'1 RST f90 -./2. tf RST jlJo - /2.,'1 SCMT .201- Pð/ USIT 2.CJ~- 2.3/i" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: z f /o6~ 19?-O~2- 02/11/05 NO. 3340 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 06/05/04 1 09/05/04 1 1 04/07/04 1 1 01/25/04 1 1 05/03/04 1 1 04/06/04 1 1 09/12/04 1 1 01/24/05 12/13/04 -- -' Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 2o)JiL.G-12B ~15-39B ;"0:3" iq'f '""C':'-l ¡ C D-04B / DS 18-13A =C'!;-1"¡5 K-10B DS 02-15A t 'Z..- ¡-¿; DS 2-33A /9S:-~), DS 07 -03A '.2f}}~iq¿ DS 07-29C }1''ý'ð!.z.. E-15B )(-t "r5i.f DS 18-27C J..¡,"\:,.Cqi E-248 '1'./09 DS 18-31 ~..¡~ il 0 K-09C ¿¡)If. {)l! if C -17 8 !'lj .~ì1 C-39 (Prints~ only-Job not complete) Job # 10715391 10728396 10715393 10715395 10715402 10715404 10670016 10715406 10715407 10861913 10715410 10861916 10715413 10861920 10715418 10715421 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL SCANNED JUN 1. ? 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: d;£~ I I / () 7S~ /rC:¡-"ð~ 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 03/21/04 1 04/03/04 1 04/07/04 1 04/16/04 1 05/16/04 1 05/18/04 1 OS/23/04 1 06/03/04 1 06/04/04 1 06/05/04 1 06/13/04 1 06/20/04 1 07/05/04 1 07/16/04 1 08/10/04 1 08/19/04 1 -~ -' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 :~iU~~ MEMORANDUM TO: Randy Ruedrich, Commissioner THRU' Regg/Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ~ ')~/"~l'o-- DATE' June 26, 2003 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector E-15 Casing Leak BPX E-15 Prudhoe Bay Field PTD 199-0420 NON-CONFIDENTIAL Thursday, June 26, 2003: I made an inspection of a reported casing leak on BPX well E-15 in the Prudhoe Bay field. I had been informed by DEC that they had received a spill report of crude oil in the cellar of this well. I drove to the above location and found the following conditions; · Well flowing. · Approximately 10 gallons crude oil lying around fluted conductor. · Conductor full of crude oil. · No apparent leaking at the time. · No smell of crude oil (wellhouse doors open). · Tubing=2060, I.A.=250, O.A.=0, Flowing tubing temp--107 deg F. hanger in I checked the adjacent wells, E-3 and E-14, and the pit area behind the wells. I found no problems with these. NON-CONFIDENTIAL Attachments: E-15 Oil in cellar 6-26-03 LG.jpg E-15 Oil in cellar 2 6-26-03 LG.jpg ~C~NN~[.',) ~U~ 0 4 20~3 2003-0626_Casing_Leak_PBU_E-15_lg.doc PBU E- 15B 6/25/03' Spill Rpt; 10 gal crude in cellar removed by vac truck 6/26/2003' AOGCC inspection, photos (L. Grimaldi) - Estimate 10 gal crude in cellar - TIO=2060/250/0 psi - Conductor full of crude; fluid released out fluted hanger in conductor 6/30/03' BP Well Integrity Group (response to AOGCC email) - Set TTP 7/1/03 w/slickline for MITT and MITA (confirm 2 barriers) - Suspect OA x Conductor leak 7/10/03 status request (Regg to BP Well Integrity Engineer) 7/10/2003 Re: E-15 PTI3 (19~U4ZU) ~status up(late Subject: Re: E-t5 PTD (1990420) Status update Date: Tue, 19 Mar 2002 07:20:39 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelilntegrityEngineer@BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak. us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak. us>, Daniel T Seamount JR <dan_seamount@admin,state.ak.us>, Winton G Aubert <winton_aubert@admin.state,ak. us> Kevin and Joe, Thanks for the update. Communication appears to be relatively quick. I will be interested in what the diagnostics show, particularly the pressure behavior of the IA and the OA. Please keep us informed. As you note, this well should remain shut in pending the determination from the diagnostics. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom, Disappointing news on this well that had a diesel smell in the cellar in December and was subsequently shut in. We were allowed to put it on production again with frequent monitoring and weekly status reports to you. The well was brought on line day before yesterday with Jeff Jones inspecting it before hand. It produced for almost 10 hours that evening and then the operator on his inspection of the well noticed a diesel smell and bubbles in the conductor pipe flutes. We immediately shut the well in. Once the well was shut in, the bubbles of fluid in the conductor pipe flutes stopped and have not returned. Our initial diagnostic plan which was enacted today consists of slick line dummying off the two live gas lift valves, performing MIT test's on the inner and outer annulus's and performing pressure test's on the tubing and casing hangers. We will continue to update you on the diagnostic work as results become available and the well will remain shut in. Please let Joe or I know if you have any suggestions or comments on the planned action items. Kevin. Joe Anders, P.E. / Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) Inc. (907) 659-5102 email: NSUADWWelllntegrityEngineer~bp. com Tom Maunder <tom maunder~,admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 3/19/02 12:16 PM Subject: Re: E-15 Date: Sat, 16 Mar 2002 07:48:12 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us> Kevin, Sorry for the delay with regard to E-15. Your monitoring indicates that there at present no problem evident. By copy of the email, I approve your proposal to return the well to production. As the well is brought on, it is most important that "frequent" monitoring occur. Please be sure that the responsible operators and Team Leaders are informed of the need to frequently check the well as it warms up. My understanding of frequently is "multiple times per day". Please provide me and the Inspectors with updates as to the status of the well. At a minimum send us a note weekly as the operation proceeds. Good luck, please call with any questions. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom, The fo/lowing information is provided per you request dated 02/06/02 on this well after the field inspector observed fluids in the cellar. The well has remained shut in since the successful SSV testing dated 12/21/01. Under the following submitted information I would like to put this well back on production with daily monitoring to see if we still might have a problem, then if produces fluid again perform a full blown diagnostic program. 12/22/01 T/IlO = 2330/320/0 Monitor cellar and snoop bottom collar on braiden head, no bubble's appeared from the snoop Clean lC LDS and snoop for leaks, found no leaks on tC, LDS. 12.24.0!T/!/0 = 2330/320/0 Monitor cellar. @ this time there is no fluid in the cellar, cellar is dry with a light smell of diesel. Fluid is down inside the flutes about 1"~ 12/26/01T/i/0 =2330/320/0. (Monitor fluid in cellar). Cellar is dry, there is no fluid in conductor pipe. There is still a heater in well house. 12/26/01T/I/0 =2320/320/0. (Monitor fluid in cellar). Cellar is dry. snooped bradenhead. Could not see any bubbles on bradenhead at this time. The fluid in conductor pipe is 8" down in conductor. 1 2/30/01T/I/0 =2320/320/0. (Monitor fluid in cellar). Cellar is dry. snooped bradenhead. Could not see any bubbles on bradenhead at this time. The fluid in conductor pipe is 8" down in conductor. 12/31/0~T/i/0 =2320/320/0. (Monitor fluid in cellar). Cellar is still dry. Snooped bradenhead again, still no bubbles appeared. No fluid inside of conductor pipe. 1/16/02 T/IlO =2320/320/0. (Monitor fluid in cellar). Cellar is dry. Snooped bradenhead still no bubbles. Fluid is about 15" down inside of conductor pipe. 2/06/02 T/ilO = 2260/300/0. Monitor Fluids in Cellar. Cellar clear of fluids. No leaks around bradenhead. Fluids in flutes not visible. 1 Of 2 3/19/02 12:16 PM Re: E-15 Kevin. Joe Anders, P.E. /Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) inc. (907) 659-5102 emaih NSUADWWelllntegdtyEngineer~bp.com iTom Maunder <tom maunder .~admin.state.ak. us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 3/19/02 12:16 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Rerfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 65 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 903' FNL, 500' FEL, Sec. 06, T11 N, R14E, UM (asp's 664463, 5976160) E-15B At top of productive interval 9. Permit number / approval number 1877' FNL, 112' FEL, Sec. 01, T11 N, R13E, UM (asp's 659986, 5975090) 199-042 At effective depth 10. APl number 1898' FNL, 895' FEL, Sec. 01, T11 N, R13E, UM (asp's 659204, 5975O52) 50-029-20668-02 At total depth 11. Field / Pool 2087' FNL, 1148' FEL, Sec. 01, T11 N, R13E, UM (asp's 658955, 5974857) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11772 feet Plugs (measured) CIBP set @ 11450' (08/26/1999) true vertical 8994 feet Effective depth: measured 11450 feet Junk (measured) true vertical 8988 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 c.f. concrete 142' 142' Surface 2639' 13-3/8" 3720 cf ArcticSet II 2671' 2671' Intermediate 9840' 9-5/8" 1415 cf 'G', 130 cf AS I 9872' 9391' Liner 909' 7" 468 cf Class 'G' 9381' - 10290' 8008'- 8720' Sidetrack Liner 691' 4-1/2" 162 cf Class 'G' 9736'- 10427' 8283' - 8809' Sidetrack Liner 2087' 2-7/8" 79 cf Class 'G' 9685' - 11772' 8243' - 8994' Perforation depth: measured Open Peris 10675' - 10750', 10790' - 11000', 11064' - 11110', 11300' - 11440' Open Peris belowCIBP 11470'- 11560', 11590'- 11700' true vertical Open Peris 8949' - 8970', 8981' - 8996', 8998' - 8999', 9000' - 8988', Open Peris below CIBP 8987' - 8987', 8988' - 8991' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG@ 9626'. 4-1/2",12.6# L-8O Tubing Tail@ Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker SAB3 Packer @ 9626'. 4-1/2" Otis SSSV Landing Nipple @ 2076'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/20/2002 Shut-In Subsequent to operation 03/16/2002 601 19465 17 1062 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is t_rue and correct to the best of my knowledge. ,~~~¢,'~u~~~~ Title: TechicalAssistant Date March 25, 2002 Dewayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE E-15B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/02/2002 PERF(ADD-PERF): DRIFT/TAG; PERFORATING 03/03/2002 PERF(ADD-PERF): PERFORATING EVENT SUMMARY O3/O2/02 MIRU UNIT #8. MAKE GAGE RUN WITH 2.25" NOZZLE TO 10800'. POH. RIH WITH GR/CCL FOR TIE IN. SET DOWN ON LINER TOP, POOH. ADD KNUCKLE JT AND CENTRALIZER TO GR/CCL TOOL, RIH. LOG FROM 10800' - 10475'. PAINT FLAG. POOH. RIH WITH GUN #1,2" 6 SPF WITH 2006 PJ CHARGES AT 60 DEGREES PHASING AND RANDOM ORIENTATION. PERFORATE 10725'- 10750'. POH. O3/O3/O2 SHOOT GUN #2:10700'-10725', 2" 2006 P J, 6 SPF, 60 DEG PHASE, RANDOM ORIENTAION. POOH. ALL SHOTS FIRED. PU GUN #3, RIH. SHOOT GUN #3: 10675'-10700', 2" PJs SAME SPEC AS GUN #2. POOH. ALL SHOTS FIRED. FREEZE PROTECT TUBING. RDMO CTU #8. FLUIDS PUMPED BBLS 229 METHANOL WATER 170 2% KCL WATER 399 TOTAL ADD PERFS 03/02-03/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" PJ 6SPF, 60 DEGREE PHASING RANDOM ORIENTATION. 10675' - 10750' Page 1 199-042-0 PRUDHOE BAY UNIT E-15B 50- 029-20668-02 Roll #1: Start: Stop Roll #2: / Sta~~'~~._ Stop MD 11772~TVD 08994"Completion Date.t-~ 6/5/99 ~C~ompleted Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: T Name Interval Sent Received T/C/D D 9527~ 1,2 SPERRY GR OH 4/25/00 4/28/00 D 9528~ I SPERRY GR PBI OH 4/25/00 4/28/00 L LEAK-SPIN/TEM/'~. FINAL PRES 9450-10150 CH 5 6/21/99 6/23/99 L NGP-MD ~"~..- FINAL 10406-11772 OH 2/5 4/27/00 4/28/00 D L NGP-MD ~ FINAL 10406-11675 PBI OH 2/5 4/27/00 4/28/00 D L NGP-TVD ~ FINAL 8733-8938 OH 2/5 4/27/00 4/28/00 L NGP-TVD""L.,,..''''''~ '' FINAL 8733-8933 PBI OH 2/5 4/27/00 4/28/00 R SRVY LSTNG /"~" BHI 10290.-11780. OH 7/6/99 7/8/99 D R SRVY LSTNG ~-" BHI 10290.11675. PB1 OH 7/6/99 7/8/99 D R SRVY RPT'~/'' SPERRY 10576.27-11772. OH 7/6/99 7/8/99 D R SRVY RPT k,,,,,~''- SPERRY 10204.30-11675. PB1 OH 7/6/99 7/8/99 D Wednesday, May 02, 2001 Page 1 of 1 DRI LLI I~1 !~ c; EE Ft ~./I r- ~=: c; To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 April27,2000 MWD Formation Evaluation Logs E-15B & E-15B PB1 AK-MW-90129 E-15B: 2"x 5"MDGammaRayLogs: 50-029-20668-02 2"x 5" TVD Gamma Ray Logs: 50-029-20668-02 E-15B PBI: 2"x 5"MD Gamma Ray Logs: 50-029-20668-72 2"x 5" TVD Gamma Ray Logs: 50-029-20668-72 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: AP~ 28 2000 AJaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 · !. ' fl,' S~gn 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company =per r -sun O R I I._1_11M r~ 5 l~ Ri/I C ¢:: c~ WELL LOG TRANSMITTAL To: State of Alaska April 25, 2000 Alaska Oil and Gas Conservation Comm. . \ ~ Attn.: Loft Taylor ,~-~ ~-~ 3001 Porcupine Dr..(x-""Ci. U,-~ ./.~ it ,~ ,,~ r3 ~ Anchorage, Alaska 99501 ~,-'\ \ c.-/~ , MWD Formation Evaluation Logs E- 15B & E- 15B PB 1 AK-MW-90129 2 LDWG formatted Disks with verification listing. API#: 50-029-20668-02 & 50-029-20668-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITYAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Yrm Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: APR 28 2000 Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA -,~ --- ALASKA OiL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 99-042 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20668-02 4. Location of well at surface !' '~;';",7~i~:;~."~' i ' , 9. Unit or Lease Name , i~~i ~' Prudhoe Bay Unit 903' SNL, 501 WEL, SEC. 06, T11N, R14E, UM ~ ' At top of productive interval 10. Well Number 1877'SNL, 112'WEL, SEC. 01,T11N, R13E, UM ! ~~-i E-15B At total depth 2086' SNL, 1149' WEL, SEC. 01, T11N, R13E, UM ,. ...................... ~ 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease. Designation and Serial No. Pool KBE = 65.04'I ADL 028280 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 16. No. of Completions 5/29/99I 6/2/99I 6/5/99I N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. Directional Survey 120. Depth wher~S~¥~selt-12~l~ T~Cigss of Permafrost 11772 8994 FT 11706 8991 F-r 6~Ves i--INo, (Nipple) ii~.,~.'~~ ~. V ~'¢9~)0'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, ROP 23. CASING~ LINER AND CEMENTING RECORD CASING SE~I-ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD 20"x 30" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2671' 17-1/2" 3720 cuft Arcticset II 9-5/8" 47# L-80 Surface 9872' 12-1/4" 1415 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 9381' 10290' 8-1/2" 468 cu ft Class 'G' 4-1/2" 12.6# b-80 / 13Cr 9736' 10427' 6" 162 cu ft Class 'e' 2-7/8" 6.16# L-80 9685' 11772' 3-3/4" 79 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9689' 9626' MD TVD MD TVD 10790' - 11000' 8980' - 8996' 11060' - 11110' 8998' - 8999' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11300' - 11440' 9000' - 8988' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11470' - 11560' 8987' - 8987' 11590' - 11700' 8988' - 8991' 2000' Freeze Protect with 20 Bbls of MeOH 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 7, 1999I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BEE ~GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate '[ 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. 24N 10410' 8800' 24P 10418' 8804' Zone 1B 10632' 8931' 14P 10667' 8946' 13N 10749' 8970' 13P 10779' 8978' 12N 11744' 8992' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubb,e '~,/~./~ (~,~~--~ Title Technical Assistant III Date O ~'~' ¢? E-15B 99-042 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: E-15B Accept: 05/26/99 Field: Prudhoe Bay Spud: 05/29/99 APl: 50-029-20668-02 Release: Permit: 99-042 CTD Unit: Nordic #1 05/27/99 1 10237' Moved Nordic 1 f/E-10A to E-15. Rig accepted at 12:30 hrs 5/26/99. RU slickline. Ran Sperry EMS & TIW indicator. Located in WS anchor. Orientation of Key is 46° R. POH & RD slickline. RIH w/TIW WS tray & anchor. Latched tray into WS anchor. Released running tool w/6K overpull. POH w/running tool. LD running tool. MU Weatherford 3.80" window mill & 2-7/8" motor. RIH w/window mill assy. 05/28/99 2 10428' TIH w/Milling BHA. Tag up on XN Nipple, correct depth (+18'). Mill thru XN Nipple, TIH to whipstock. Tag up on whipstock, flag pipe at 10427'. Begin milling, unable to make headway. Motor stalling, not drilling off. POOH. Found chunks of rubber had come off stator. Replace motor, TIH. Milled for 5 hrs. Made very little progress. POH to check mill and motor. Changed motor and mill. RIH. Attempt to mill at 10427.5'. (Motor stalling.) 05/29/99 3 10433' Attempted to mill w/ bladed mill. Made no progress below 10427'. POH. Changed to Weatherford.tapered (crayon) mill. RIH. Attempted to mill. Continued to stall at 10427'. Attempted injectivity test. Held 2000 psi. Have not milled thru csg wall. POH. Changed Packoff. Cut off 50 ft of coil. Changed to HC Diamond one step mill. RIH. Milled f/10427-10433'. 05/30/99 4 11032' Finish milling window. POOH, LD Milling BHA, PU Drilling BHA. TIH, tag up and correct depth (+16'). Drill and orient to move away from casing and drop angle. Drill ahead to 10835' (uncorrected depth). Wiper trip. Ran tie-in log. Made -21 ft correction to original E-15 open hole log (10/81). Corrected Depths: Window f/10406-412'. RA tag at 10,412'. Drilled to 10889'. Stuck while surveying. Worked stuck pipe. Pipe came free w/o crude. Wiper trip to window. Drilled to 11032'. Attempted to orient to 45R. Tool kept flipping to 90-100R. Short trip to improve orienting. 05/31/99 5 11675' Finished wiper trip. Drilled to 11253'. 500 ft short trip. Drilled to 11415'. Short tripped to window. Drilled to 11515'. Wt transfer problems. Short tripped to window. Drilled to 11629'. Wt transfer problems. Short tripped to window. Drilled to 11675'. Decision made to plug back due to poor sand quality. POH. Ran tie-in log (+18 correction). POH to plug back. E-15B, Coil Tubing Drilling Page 2 06/01/99 6 10602' Finish POOH, LD Drilling BHA. PU Cementing BHA, TIH and correct depth to flag. TIH to 11,000'. Pull uphole while circulating to 10,000' to clean hole. TIH and put nozzle at 11,000'. Pump 10 bbl cement, drop dart. Pump 2 bbl and check to be sure dart gone-OK. Displace dart w/FIo-Pro. When 1 bbi cement out nozzle start up hole at 69 fpm while pumping at 0.9 bpm. Lay in cement and pull to safety and shear dart at 3000 psi. Let cement settle for 1 hour and wash back in hole to 10,580'. Circulate while POOH. Circulated cement to surface. OOH, LD Cementing BHA. Test BOP. John Spaulding/AOGCC waived witnessing test. Cut off 1400 ft of coil to maximize coil life. MU drlg assy. RIH. Ran tie-in log. RIH. Tagged at 10565'. Appeared to partially packoff. Made wiper trip to window. RIH. Tagged cmt at 10580'. Drld to 10602'. 06/02/99 7 11436' Kicked off at 10580'. Displaced well to new mud. Drilled to 10735'. Short trip to window. Drilled & oriented to 11046'. Stacking wt. Started wiper trip to window. Pulled into tight spot at 10887' (Bit depth). Motor stalled BHA stuck. Worked free going down. Finished wiper trip to window- no overpulls. RIH. Oriented & drilled to 11196'. Short tripped to window. RIH clean to TD. Orient TF. Drilled horizontal hole from 11196 - 11425 ft. Wiper trip to window, hole was clean. Tied-in with GR at 10081 ft. Added 13 ft to CTD. RIH. Difficult to get thru window. RIH to TD. Orient TF. 06/03/99 8 11772' Drilled to 11500'. 100 ft wiper trip. Drilled & oriented to 11636'. Wiper trip to window. Drilled & oriented to 11651'. Lost wt &diff pressure. Differentially stuck. Work stuck pipe free. Drilled to 11750'. Wiper trip to window. Drilled to 11772'. Wiper trip to window. Ran tie-in log (+8.5' correction). RIH. Tagged TD at 11,772 ft BKB, final corrected TD. POOH. Flagged CT at 7900 ft EOP. POOH. L/D Sperry MWD and drilling BHA. Held Safety Meeting. Prepared to run 2 7/8" liner. Ran 64 jts, 2 7/8", 6.16#, STL liner. M/U Baker CTLRT and pull test with 30K. M/U Baker CT connector, pull / press test. RIH with 2 7/8" liner on CT. 06/04/99 9 11705' RIH w/2-7/8", 6.16#, L80, STL liner on coil. Tagged btm at 11772'. TOL at 9685'. Circ & cond mud. Released liner running tool. Displaced well to 2% KCI. Cemented liner w/14.0 bbls, 15.6 ppg cmt. Bumped plug. Applied 500 psi. & pulled out of sleeve. POH circulating 2% KCL. LD liner running tool. RIH w/nozzle & 1-1/4" CS Hydril tbg. Tagged Latch collar at 11705'. Spotted 150k LSRV FIo-pro in liner. POH to 10150'. Repair bearing in injector head drive chain. POOH. Stand back CSH workstring. Pressure test 2 7/8" liner lap with 1500 psi. OK. Replace cotter pins in injector drive chain. Stand back CSH workstring. Held Safety Meeting. RIH with 44 SWS 2" Power Jet perforating guns, loaded at 4 SPF. RIH with CSH workstring. RIH with CT. Tag PBTD of 11705 ft. Drop 5/8" steel ball and position bottom perforating charge at 11700 ft BKB. Sheared Firing head at 2900 psi. Lost 1 bbl fluid. POOH with perf guns. 06/05/99 10 POH w/perf gun assy. LD 40 1-1/4 CS Hydril. LD perf guns. All shots fired. RIH & LD 48 jts 1- 1/4" CS Hydril from derrick. Perforated Interval: 10,790-11,000', 11,064-11,110', 11,300- 11,440', 11,470-11,560' & 11590-11,700', 2" Power Jet guns 4 SPF. Released Rig at 05:00 Hrs, 06-05-99. 8400- 8500 c" 8600 '4'-- 8700 -- -~ ~o 8800, >. 8900 I 9000 V B.P. Exploration (True) Structure : Pad E Field : Prudhoe Bay Well · E-15B, 50-029-20668-02 Location : North Slope, Alaska <- West (feet) Created by potnia Dote plotted : 5-Jun-1999 Plot Reference Coordlnotea ere in feet reference E-15. True Vertical Dcptha ore reference RK~ - MSL = 67,06ft --- Baker Hughea INTEQ --- Tie on / t Projected t ORIGINAL Projected to TD r~ Projected to ID 5700 5600 5500 5400 5300 5200 5100 5000 4900 4800 4700 4600 4500 4400 4300 4200 4100 I I I I I I I I I I f I I I I I I I I I I I I I I I I I I I f I I 700 800 9O0 9100 [ [ [ ~ ~ [ ] ~ [ [ ] [ ~ I I II I II I II I I I I I [ I I I I I I 400 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 Vertical .Section (feet) -> Azimuth 259.26 with reference 972.80 S, 4444.86 W from E-15 10o0 11oo I 1400 0 E 12O0 (I) ,-t- 1~oo I V 1400 1500 1600 1 700 B.P. Exploration (True) Pad E E-15B E-15 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : E-15B Our ref : svy164 License : 50-029-20668-02 Date printed : 3-Jun-1999 Date created : 3-Jun-1999 Last revised : 3-Jun-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 664940.580,5977074.330,999.00000,N Slot location is n70 20 28.220,w148 39 54.967 Slot Grid coordinates are N 5976160.760, E 6644'62.750 Slot local coordinates are 902.90 S 497.85 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad E,E-15B Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N SURVEY LISTING Page 1 Your ref : E-15B Last revised : 3-Jun-1999 U L A R Dogleg Vert G R I D C O O R D S A T E S Deg/100ft Sect Easting Northing . 10290.00 37.01 270.72 8656.00 943.36S 4229.59W 0.38 0.00 660255.23 5975124.64 10299.00 43.00 265.30 8662.89 943.57S 4235.36W 76.94 5.71 660249.47 5975124.29 10329.00 46.60 260.40 8684.18 946.23S 4256.32W 16.62 26.80 660228.58 5975121.18 10359.00 49.70 256.40 8704.20 950.74S 4278.19W 14.33 49.13 660206.81 5975116.19 10406.00 53.36 250.77 8733.45 961.17S 4313.45W 12.19 85.71 660171.79 5975104.98 10449.80 58.08 257.56 8758.13 970.98S 4348.24W 16.73 121.72 660137.23 5975094.41 10514.10 47.16 272.66 8797.25 975.80S 4398.77W 25.16 172.26 660086.82 5975088.49 10547.50 48.42 275.83 8819.69 973.96S 4423.43W 7.98 196.15 660062.12 5975089.78 10575.00 54.28 270.58 8836.87 972.80S 4444.86W 26.00 216.99 660040.68 5975090.47 10585.00 54.64 268.10 8842.68 972.89S 4452.99W 20.50 225.00 660032.55 5975090.20 10609.30 57.57 273.47 8856.24 972.60S 4473.15W 21.95 244.74 660012.39 5975090.04 10638.30 63.37 275.75 8870.53 970.56S 4498.28W 21.14 269.06 659987.22 5975091.53 10668.85 67.85 279.80 8883.14 966.78S 4525.83W 18.99 295.42 659959.59 5975094.70 10701.47 72.95 287.00 8894.10 959.64S 4555.69W 26.01 323.42 659929.59 5975101.19 10736.10 76.11 292.63 8903.34 948.32S 4587.06W 18.13 352.14 659897.98 5975111.81 10771.30 74.27 288.23 8912.34 936.44S 4618.94W 13.17 381.24 659865.85 5975122.99 10807.20 80.73 284.15 8920.11 926.69S 4652.58W 21.14 412.48 659832.01 5975132.00 10847.75 85.17 275.93 8925.09 919.69S 4692.16W 22.90 450.06 659792.28 5975138.12 10880.00 88.24 269.78 8926.95 918.09S 4724.30W 21.28 481.34 659760.12 5975139.01 10922.65 88.77 257.65 8928.06 922.75S 4766.60W 28.46 523.77 659717.93 5975133.42 10962.55 85.87 249.39 8929.93 934.05S 4804.78W 21.92 563.39 659680.01 5975121.29 11002.07 86.92 253.60 8932.42 946.56S 4842.18W 10.96 602.46 659642.91 5975107.96 11035.00 89.12 259.93 8933.56 954.09S 4874.20W 20.34 635.32 659611.06 5975099.73 11070.00 88.68 266.79 8934.23 958.13S 4908.93W 19.64 670.20 659576.42 5975094.92 11106.97 88.46 276.22 8935.16 957.16S 4945.84W 25.51 706.28 659539.51 5975095.08 11145.47 89.03 280.32 8936.00 951.63S 4983.92W 10.75 742.66 659501.32 5975099.77 11177.75 87.89 276.81 8936.87 946.82S 5015.82W 11.43 773.11 659469.32 5975103.88 11210.17 87.80 275.40 8938.09 943.38S 5048.04W 4.35 804.11 659437.04 5975106.61 11248.75 92.02 271.89 8938.15 940.93S 5086.52W 14.23 841.47 659398.51 5975108.22 11284.05 92.25 268.00 8936.83 940.96S 5121.79W 11.03 876.13 659363.26 5975107.41 11312.45 94.04 262.75 8935.27 943.24S 5150.04W 19.50 904.31 659335.06 5975104.50 11351.45 97.73 254.84 8931.27 950.77S 5188.06W 22.28 943.07 659297.22 5975096.14 11380.05 95.98 248.16 8927.85 959.77S 5214.97W 23.98 971.19 659270.51 5975086.55 11420.85 93.16 243.94 8924.60 976.28S 5252.13W 12.41 1010.77 659233.73 5975069.23 11458.27 90.26 236.73 8923.48 994.78S 5284.60W 20.76 1046.12 659201.68 5975050.02 11490.00 90.35 228.47 8923.31 1014.04S 5309.79W 26.03 1074.45 659176.92 5975030.22 11527.15 91.32 220.21 8922.77 1040.58S 5335.73W 22.38 1104.88 659151.58 5975003.11 11559.45 88.24 216.52 8922.89 1065.90S 5355.77W 14.88 1129.29 659132.10 5974977.36 11594.95 87.10 221.96 8924.34 1093.36S 5378.20W 15.64 1156.44 659110.28 5974949.41 11630.60 87.54 230.40 8926.01 1117.99S 5403.87W 23.68 1186.26 659085.16 5974924.22 11667.47 89.65 239.19 8926.91 1139.22S 5433.96W 24.51 1219.77 659055.55 5974902.34 11698.45 89.75 246.16 8927.08 1153.43S 5461.46W 22.50 1249.44 659028.36 5974887.53 11728.52 87.36 249.39 8927.83 1164.80S 5489.28W 13.36 1278.90 659000.80 5974875.55 11780.00 87.36 249.39 8930.20 1182.90S 5537.42W 0.00 1329.56 658953.08 5974856.39 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from E-15 and TVDss from RKB - MSL = 67.06ft. Bottom hole distance is 5662.35 on azimuth 257.94 degrees from wellhead. Vertical section is from tie at S 943.36 W 4229.59 on azimuth 259.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA E Pad, Slot E-15 E-15B Job No. AKMW90129, S UR VEY REPORT 6 July, 1999 Your Reft API-500292066802 Surface Coordinates: 5976161.68 N, 664462.61 E (70° 20' 28.2290"N, 211° 20' 05.0292"E) Kelly Bushing: 65.04ft above Mean Sea Level DRILLING SERVICES Survey Ref: svy8635 Sperry-Sun Drilling Services Survey Report for E-15B Your Ref: API-500292066802 Job No. AKMW90129, Prudhoe Bay Unit Measured Depth (ft) Incl. 10576.27 10585.00 10609.30 10638.30 10668.85 10701.47 10736.10 10771.30 10807.20 10847.75 10880.50 10922.65 10962.55 11002.07 11035.00 11070.00 11106.97 11145.42 11177.75 11210.17 11248.75 11284.05 11312.45 11351.45 11380.05 54.560 54.640 57.570 63.370 67.850 72.950 76.110 74.270 80.730 85.170 88.240 88.770 85.870 86.920 89.120 88.680 88.460 89.030 87.890 87.800 92.020 92.250 94.040 97.730 95.980 Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 270.360 8836.39 8901.43 975.46 S 4450.58W 268.100 8841.45 8906.49 975.56 S 4457.69W 273.470 8855.00 8920.04 975.27 S 4477.84W 275.750 8869.29 8934.33 973.22 S 4502.98W 279.800 8881.91 8946.95 969.45 S 4530.53W 287.000 8892.86 8957.90 962.30 S 4560.38W 292.630 8902.10 8967.14 950.98 S 4591.76W 288.230 8911.10 8976.14 939.10 S 4623.64W 284.150 8918.87 8983.91 929.35 S 4657.28W 275.930 8923.86 8988.90 922.36 S 4696.86W 269.780 8925.74 8990.78 920.73 S 4729.50W 257.650 8926.85 8991.89 925.34 S 4771.30W 249.390 8928.71 8993.75 936.63 S 4809.48W 253.600 8931.20 8996.24 949.15 S 4846.88W 259.930 8932.34 8997.38 956.67 S 4878.90W 266.790 8933.01 8998.05 960.72 S 4913.63W 276.220 8933.94 8998.98 959.75 S 4950.54W 280.320 8934.78 8999.82 954.22 S 4988.57W 276.810 8935.65 9000.69 949.41 S 5020.52W 275.400 8936.87 9001.91 945.96 S 5052.73W 271.890 8936.93 9001.97 943.51S 5091.22W 268.000 8935.61 9000.65 943.54 S 5126.49W 262.750 8934.05 8999.09 945.83 S 5154.74W 254.840 8930.05 8995.09 953.35 S 5192.76W 248.160 8926.63 8991.67 962.36 S 5219.67W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°ll00ft) 5975088.83 N 660034.51 5975088.57 N 660027.40 5975088.42 N 660007.24 5975089.91 N 659982.07 5975093.09 N 659954.44 5975099.57 N 659924.44 5975110.20 N 659892.82 5975121.38 N 659860.69 5975130.39 N 659826.85 5975136.51 N 659787.12 5975137.42 N 659754.45 5975131.90 N 659712.76 5975119.78 N 659674.84 5975106.44 N 659637.72 5975098.21N 659605.88 5975093.41N 659571.24 5975093.57 N 659534.32 5975098.26 N 659496.18 5975102.37 N 659464.13 5975105.11N 659431.85 5975106.72 N 659393.32 5975105.91 N 659358.06 5975103.01 N 659329.86 5975094.65 N 659292.01 5975085.05 N 659265.31 21.121 21.946 21.136 18.992 26.007 18.130 13.166 21.137 22.900 20.958 28.796 21.917 10.959 20.339 19.637 25.506 10.763 11.411 4.355 14.226 11.031 19.504 22.280 23.982 Vertical Section (ft) 4554.39 4561.40 4581.15 4605.46 4631.83 4659.83 4688.54 4717.65 4748.88 4786.47 4818.23 4860.16 4899.78 4938.85 4971.71 5006.59 5042.67 5079.01 5109.50 5140.51 5177.86 5212.52 5240.71 5279.46 53O7.58 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 PBU WOA E Pad Continued... 6 July, 1999 - 12:28 - 2 - DrillQuest 'L Sperry-Sun Drilling Services Survey Report for E- 15B Your Ref: API-500292066802 Job No, AKMW90129, Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 11420.85 93.160 243.940 8923.38 8988.42 978.87 S 5256.83 W 5975067.74 N 659228.52 E 11458.27 90.260 236.730 8922.26 8987.30 997.37 S 5289.30 W 5975048.53 N 659196.46 E 11490.00 90.350 228.470 8922.09 8987.13 1016.62 S 5314.49 W 5975028.73 N 659171.71 E 11527.15 91.320 220.210 8921.55 8986.59 1043.16 S 5340.43 W 5975001.62 N 659146.35 E 11559.45 88.240 216.520 8921.67 8986.71 1068.48 S 5360.47 W 5974975.87 N 659126.87 E 11594.95 87.100 221.960 8923.12 8988.16 1095.94 S 5382.90 W 5974947.92 N 659105.05 E 11630.60 87.540 230.400 8924.79 8989.83 1120.58 S 5408.57 W 5974922.73 N 659079.93 E 11667.47 89.650 239.190 8925.69 8990.73 1141.80 S 5438.66 W 5974900.85 N 659050.31 E 11698.45 89.750 246.160 8925.86 8990.90 1156.02 S 5466.16 W 5974886.04 N 659023.13 E 11728.52 87.360 249.390 8926.61 8991.65 1167.38 S 5493.98 W 5974874.06 N 658995.56 E 11772.00 87.360 249.390 8928.62 8993.66 1182.67 S 5534.64 W 5974857.88 N 658955.25 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°/~OOft) 12.412 20.758 26.033 22.384 14.880 15.644 23.681 24.509 22.500 13.359 0.000 Vertical Section (ft) 5347.16 5382.51 5410.84 5441.28 5465.68 5492.84 5522.65 5556.16 5585.84 5615.29 5658.08 Comment Projected Survey Alaska State Plane Zone 4 PBU WOA E Pad The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 259.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11772.00ft., The Bottom Hole Displacement is 5659.59ft., in the Direction of 257.938° (True). Continued... 6 July, 1999 - 12:28 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for E-15B Your Ref: AP1-500292066802 Job No. AKMWg0129, Prudhoe Bay Unit Alaska State Plane Zone 4 PBU WOA E Pad Comments Measured Depth (ft) 10576.27 10585.00 11772.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8901.43 975.46 S 4450.58 W 8906.49 975.56 S 4457.69 W 8993.66 1182.67 S 5534.64 W Comment Tie-on Survey Window Point Projected Survey 6 July, '1999 - 12:28 - 4 - DrillQuest Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA E Pad, Slot E-15 E-15BPB1 Job No. AKMWg0129, SURVEY REPORT 6 July, 1999 ORIGINAL Your Ref: APl 500292066872 Surface Coordinates: 5976161.68 N, 664462.61 E (70° 20' 28.2290"N, 211° 20' 05.0292" E) Kelly Bushing: 65.04ft above Mean Sea Level =l=,=r-,r-,~-=um DRILLING SERVICES Survey Ref: svy8633 A [LALLIBURTON COMPAN~t' Sperry-Sun Drilling Services Survey Report for E-15BPB Your Ref: APl 500292066872 Job No. AKMW90129, Prudhoe Bay Unit Measured Depth (ft) 10204.30 10299.00 10329.00 10359.00 10406.00 10449.80 10514.10 10547.50 10576.27 10616.77 10660.90 10692.40 10725.55 10771.00 10802.52 10839.10 10875.12 10918.38 10954.77 10997.95 11029.12 11060.07 11108.77 11141.67 11195.70 37.330 43.000 46.600 49.700 53.360 58.080 47.160 48.420 54.560 55.280 56.600 63.020 70.49O 80.680 88.860 91.350 87.630 88.680 87.710 82.700 84.370 92.550 92.55O 91.850 84.580 Azim. 270.800 265.300 260.400 256.400 250.770 257.560 272.660 275.830 270.360 259.930 246.400 245.870 241.300 239.720 240.950 247.220 255.190 263.100 272.240 279.270 286.830 287.710 298.080 304.760 297.570 Sub-Sea Depth (ft) 8589.31 8661.67 8682.96 8702.98 8732.23 8756.91 8796.03 8818.48 8836.39 8859.71 8884.50 8900.33 8913.41 8924.71 8927.58 8927.52 8927.84 8929.23 8930.38 8933.99 8937.51 8938.34 8936.17 8934.90 8936.59 Vertical Depth (ft) 8654.35 8726.71 8748.00 8768.02 8797.27 8821.95 8861.07 8883.52 8901.43 8924.75 8949.54 8965.37 8978.45 8989.75 8992.62 8992.56 8992.88 8994.27 8995.42 8999.03 9002.55 9003.38 9001.21 8999.94 9001.63 Local Coordinates Northings Eastings (ft) (ft) 944.00 S 4179.08W 946.25 S 4240.05W 948.90 S 4261.00W 953.41 S 4282.88W 963.85 S 4318.13W 973.65 S 4352.92W 978.47 S 4403.45W 976.63 S 4428.12W 975.46 S 4450.58W 978.27 S 4483.52W 988.85 S 4518.37W 999.87 S 4543.26W 1013.43 S 4570.49W 1035.09 S 4608.75W 1050.61 S 4636.00W 1066.58 S 4668.88W 1078.18 S 4702.95W 1086.31 S 4745.38W 1087.79 S 4781.68W 1083.49 S 4824.45W 1076.50 S 4854.60W 1067.32 S 4884.12W 1048.42 S 4928.88W 1031.29 S 4956.92W 1003.38 S 5003.06W Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°/lOOft) Vertical Section (ft) 5975126.24 N 660305.25 E 4281.79 5975122.65 N 660244.35 E 7.058 4342.11 5975119.54 N 660223.45 E 16.620 4363.19 5975114.55 N 660201.68 E 14.329 4385.52 5975103.34 N 660166.67 E 12.185 4422.10 5975092.78 N 660132.10 E 16.731 4458.11 5975086.85 N 660081.68 E 25.159 4508.66 5975088.15 N 660056.99 E 7.977 4532.55 5975088.83 N 660034.51 E 26.002 4554.39 5975085.29 N 660001.63 E 21.140 4587.29 5975073.95 N 659967.02 E 25.556 4623.50 5975062.39 N 659942.38 E 20.433 4650.00 5975048.23 N 659915.45 E 25.843 4679.29 5975025.75 N 659877.68 E 22.671 4720.91 5975009.63 N 659850.78 E 26.241 4750.58 5974992.94 N 659818.25 E 18.441 4785.86 5974980.60 N 659784.45 E 24.414 4821.49 5974971.53 N 659742.21 E 18.436 4864.69 5974969.26 N 659705.95 E 25.245 4900.63 5974972.62 N 659663.09 E 19.941 4941.85 5974978.95 N 659632.80 E 24.687 4970.17 5974987.48 N 659603.08 E 26.582 4997.46 5975005.39 N 659557.92 E 21.272 5037.91 5975021.90 N 659529.52 E 20.400 5062.27 5975048.80 N 659482.77 E 18.914 5102.40 Comment Tie-on to E-15 Window Point Alaska State Plane Zone 4 PBU WOA E Pad Continued... 6 July, 1999 - 12:25 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for E-15BPB1 Your Ref: APl 500292066872 Job No. AKMW90129, Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11235.57 82.790 288.230 8940.98 9006.02 987.97 S 5039.52 W 5975063.40 N 659445.98 E 11262.07 84.810 283.490 8943.85 9008,89 980.77 S 5064.85 W 5975070.04 N 659420.49 E 11292.50 87.440 277.410 8945.90 9010.94 975.27 S 5094.69 W 5975074.89 N 659390.54 E 11331.82 86.310 273.290 8948.05 9013.09 971.61 S 5133.78 W 5975077.69 N 659351.39 E 11371.52 86.400 265.380 8950.58 9015.62 972.07 S 5173.36 W 5975076.36 N 659311.82 E 11406.72 86.040 255.710 8952.90 9017.94 977.83 S 5207.97 W 5975069.84 N 659277.35 E 11439.37 90.970 254.660 8953.75 9018.79 986.18 S 5239,51 W 5975060.81 N 659246.00 E 11480.37 95.890 247.100 8951.30 9016.34 999.56 S 5278.14 W 5975046.58 N 659207.67 E 11508.47 93.600 240.070 8948,97 9014.01 1012.01 S 5303.20 W 5975033.58 N 659182.89 E 11544.72 92.610 231.440 8947.00 9012.04 1032.36 S 5333.09 W 5975012.58 N 659153.45 E 11599.30 98.380 219.390 8941.76 9006.80 1070.39 S 5371.72 W 5974973.71 N 659115.67 E 11637.35 96.770 212.120 8936.74 9001.78 1100.98 S 5393.74 W 5974942.65 N 659094.33 E 11675.00 96.770 212.120 8932.30 8997.34 1132.65 S 5413.62 W 5974910.55 N 659075.15 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. ,., Dogleg Rate (o/100ft) 23.712 19.346 21.726 10.850 19.885 27.431 15.438 21.967 26.228 23.928 24.378 19.406 0.000 Vertical Section (ft) 5135.35 5158.90 5187.19 5224.91 5263.89 5298.96 5331.51 5371.95 5398.90 5432.06 5477.09 5504.43 5529.86 Comment Projected TD Alaska State Plane Zone 4 PBU WOA E Pad The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 259.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11675.00ft., The Bottom Hole Displacement is 5530.84ft., in the Direction of 258.183° (True). Continued... 6 July, 1999 - 12:25 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for E-15BPBI Your Ref: APl 500292066872 Job No. AKMWg0129, Prudhoe Bay Unit Alaska State Plane Zone 4 PBU WOA E Pad Comments Measured Depth 10204.30 10406.00 11675.00 Station Coordinates TVD Nothings Eastings (fi) (fi) (fi) 8654.35 944.00 S 4179.08W 8797.27 963.85 S 4318.13W 8997.34 1132.65 S 5413.62W Comment Tie-on to E-15 Window Point Projected TD 6 July, 1999 - 12:25 - 4 - DrillQuest B.P. Exploration (True) Pad E E- 15B PB1 E-15 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes iNTEQ Your ref : E-15B Plugback~l Our ref : svy163 License : 50-029-20668-70 Date printed : 3-Jun-1999 Date created : 3-Jun-1999 Last revised : 3-Jun-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 664940.580,5977074o330,999.00000,N Slot location is n70 20 28.220,w148 39 54.967 Slot Grid coordinates are N 5976160.760, E 664462.750 Slot local coordinates are 902.90 S 497.85 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exp' Pad Prudhoe Bay Measured Inclin Depth Degrees (True) ~B1 3pe, Alaska 10290.00 37.01 8656.00 10299.00 43.00 265.~ 8662.89 10329.00 46.60 260.40 8684.18 10359.00 49.70 256.40 8704.20 10406.00 53.36 250.77 8733.45 10449.80 58.08 257.56 8758.13 10514.10 47.16 272.66 8797.25 10547.50 48.42 275.83 8819.69 10576.27 54.56 270.36 8837.61 10616.77 55.28 259.93 8860.93 10660.92 56.60 246.40 8885.73 10692.40 63.02 245.87 8901.55 10725.55 70.49 241.30 8914.63 10771.00 80.68 239.72 8925.93 10802.52 88.86 240.95 8928.80 10839.10 91.35 247.22 8928.74 10875.12 87.63 255.19 8929.06 10918.38 88.68 263.10 8930.45 10954.77 87.71 272.24 8931.60 10997.95 82.70 -279.27 8935.21 11029.12 84.37 286.83 8938.73 11060.07 92.55 287.71 8939.56 11108.77 92.55 298.08 8937.39 11141.67 91.85 304.76 8936.12 11195.70 84.58 297.57 8937.81 SURVEY LISTING Page 1 Your ref : E-15B Plugback~l Last revised : 3-Jun-1999 11235.57 82.79 11262.07 84.81 11292.00 87.44 11331.82 86.31 11371.52 86.40 11406.72 86.04 11439.37 90.97 11480.37 95.89 11508.47 93.60 11544.72 92.61 11599.30 98.38 11637.35 96.77 11675.00 96.77 ~ubsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing-. 943.36S 4229.59W 0.38 0.00 660255.23 5975124.64 943.57S 4235.36W 76,94 5.71 660249.47 5975124.29 946.23S 4256.32W 16.62 26.80 660228'~58 5975121.18 ~50.74S 4278.19W 14.33 49.13 660206.81 5975116.19 961.17S 4313.45W 12.19 85.71 660171.79 5975104.98 970.98S 4348~24W 16.73 121.72 660137.23 5975094.41 975.80S 4398.77W 25.16 172.26 660086.82 5975088.49 973.96S 4423.43W 7.98 196.15 660062.12 5975089.78 972.79S 4445.89W 26.00 218.00 660039.65 5975090.46 975.60S 4478.84W 21.14 250.89 660006.77 5975086.92 986.19S 4513.70W 25.54 287.12 659972.15 5975075.57 997.19S 4538.57W 20.45 313.60 659947.53 5975064.02 1010.76S 4565.81W 25.84 342.89 659920.60 5975049.86 1032.41S 4604.06W 22.67 384.51 659882.83 5975027.37 1047.93S 4631.32W 26.24 414.18 659855.93 5975011.26 1063.91S 4664.20W 18.44 449.46 659823.41 5974994.56 1075.50S 4698.26W 24.41 485.09 659789.61 5974982 22 1083.64S 4740.69W 18.44 528.29 659747.37 5974973.16 1085.12S 4777.00W 25.25 564.24 659711.11 5974970.88 1080.82S 4819.77W 19.94 605.46 659668.26 5974974.24 1073.82S 4849.92W 24.69 633.78 659637.97 5974980.56 1064.65S 4879.43W 26.58 661.07 659608.26 5974989.09 1045.75S 4924.19W 21.27 701.52 659563.10 5975007.00 1028.62S 4952.23W 20.40 725.87 659534.69 5975023.51 1000.70S 4998.38W 18.91 766.01 659487.95 5975050.40 288.23 8942.20 985.29S 5034.84W 23.71 798.96 659451.16 5975065.00 283.49 8945.06 978.10S 5060.17W 19.35 822.51 659425.67 59750711~3 277.41 8947.09 972.69S 5089.52W 22.09 850.33 659396.21 5975076.40 273.29 8949.26 968.98S 5129.10W 10.71 888.53 659356.57 5975079.23 265.38 8951.79 969.44S 5168.68W 19.89 927.51 659317.00 5975077.90 255.71 8954.11 975.20S 5203.29W 27.43 962.58 659282.54 ~5975071.38 254.66 8954.97 983.55S 5234.83W 15.44 995.12 659251.19 5975062.35 247.10 8952.51 996.93S 5273.46W 21.97 1035.57 659212.86 5975048.12 240.07 8950.18 1009.38S 5298.52W 26.23 1062.52 659188.08 5975035.12 231.44 8948.22 1029.73S 5328.42W 23.93 1095.68 659158.65 5975014.11 219.39 8942.97 1067.76S 5367.04W 24.38 1140.71 659120.87 5974975..25 212.12 8937.95 1098.35S 5389.06W 19.41 1168.05 659099.53 5974944.18 212.12 8933.51 1130.02S 5408.94W 0.00 1193.48 659080.36 5974912.09 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from E-15 and TVDss from RKB - MSL = 67.06ft. Bottom hole distance is 5525.72 on azimuth 258.20 degrees from wellhead. Vertical section is from tie at S 943.36 W 4229.59 on azimuth 259.26 degrees, ~ Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad E,E-15B PB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : E-15B Plugback#1 Last revised : 3-Jun-1999 Comments in wellpath .... MD TVDss Rectangular Coords. Comment 10290.00 8656.00 943.36S 4229.59W Tie on 11675.00 8933.51 1130.02S ~408.94W Projected to TD , NO PROPOSAL GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12667 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) 6/21/99 Well Job # Log Description Date Blueline Sepia CDR E-06A 99178 MCNL "~. ~ ~"SL~ 990412 1 I 1 E-15B PSP LEAK DETECTION 990612 1 1 M-09A PSP PRODUCTION PROFILE 990613 ! 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson BIvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 ATTN: Sherrio~ .......... TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 12, 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoc Bay Unit E-15B BP Exploration (Alaska) Inc. Permit No: 99-42 Sur Loc: 903'SNL, 501~3/'EL, Sec. 06, T1 IN: R14E, UM Btmhole Loc. 2082'SNL. 1072~/EL, Sec. 01. TllN, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to rcdrill the above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required bv law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. . Chairman BY ORDER OF THE COMMISSION dlffEnclosurcs ce: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA ~-~ AND GAS CONSERVATION corv,~lSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65.04' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028280 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 903' SNL, 501' WEL, SEC. 06, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 28100302630-277 2005' SNL, 214' WEL, SEC. 01, T11N, R13E, UM E-15B At total depth 9. Approximate spud date Amount $200,000.00 2082' SNL, 1072' WEL, SEC. 01, T11N, R13E, UM 05/20/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028304, 1072'I No Close Approach 2560 11678' MD / 8941' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 10434'MD Maximum HoleAngle 90° Maximum surface 3300 psig, At total depth (TVD) 8800'/4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2036' 9642' 8210' 11678' 8941' 124 cuft Class 'G' 19. To be completed for Redrill,Re-entry, and Deepen Operations. ?"' ~'~ .... Present well condition summary .~. ,.._:i,', f 0 Total depth: measured 11684 feet Plugs (measured) 4-1/2" Baker IBP at 11495' [, .',', -' true vertical 8990 feet Effective depth: measured 11667 feet Junk (measured) .-~8.8k~. 0ii & Gas C0ri$, true vertical 8990 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 8 cu yds concrete 110' 110' Surface 2671' 13-3/8" 3720 cuft Arcticset II 2671' 2671' Intermediate 9872' 9-5/8" 1415 cuft Class 'G', 130 cuft AS I 9872' 8391' Production 909' 7" 468 cu ft Class 'G' 9381' - 10290' 8009' - 8723' Liner 1931' 4-1/2" 162 cu ft Class 'G' 9736' - 11667' 8284' - 8992' ORIGINAL Perforation depth: measured 10890' - 10920', 10988' - 11495' (Slotted section), 11495' - 11655 (Slotted, below IBP) true vertical 8983' - 8985', 8990' - 8998', 8998' - 8993 (below IBP) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~~ ~.../¢.¢,~/, Ted Stagg Title CT Drilling Engineer Bate Commission Use Only '"'-' / Permit Number I APl Number Approval Date I See cover letter ¢,~- ~I 50-029-20668-02 ~"'/c>'¢'"' ¢¢I for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes J~ No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required ~Yes []No Required Working Pressure for DOPE []2K; []3K; 1~4K; []SK; [] 10K; [] 15K Other: ORIGINAL SIGNED'BY by order of Approved By Robert N. Christenson Commissioner the commission Date ,.~'--'//,~ Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX E-15b Sidetrack Summary of Operations: E-15a is currently shut in due to declining productivity. The sidetrack, E-15b, will target Zone 1 mouth bar sands. This sidetrack will be conducted in two phases. Phase 1: Set Bridge Plug and Whipstock Anchor: Planned for 5/15/99. A Cast Iron Bridge Plug will be set on E-Line at 10,500 ft, above the existing horizontal completion interval. The well will be tested to 1500 psi against this bridge plug. A whipstock anchor, also a sealing plug, will be set at approx. 10,440 to place the top of the whipstock tray at 10,424. Orientation of the whipstock anchor will be confirmed with an E- Line positioning tool. Phase 2: Set Whipstock Tray, Mill Window and Drill Directional Hole: Planned for 5/20/99. Directional drilling coil tubing equipment will be rigged up and utilized to install the whipstock tray into the anchor, mill the window and drill the directional hole as per attached plan. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and other Class II wastes will go to CC-2a for injection. - All Class 1 wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,642' MD and cemented with approx. 22 bbls. to bring cement 200 ft above the window. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,434' MD (8,754' TVD ss) - TD: 11,678' MD (8,941' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging - A Gamma Ray log will be run over all of the open hole section. TREE: 6" CIW WELLHEAD: FMC ACTUATOR: BAKER E-15b Proposed Completion KB. ELEV = 60.74' BF. ELEV = 32.21' 9-5/8 D.V. PACKER I 2,600 13 3/8" 72# L-80 BTRS 12,670 4.5", 12.6#, NSCT, L-80 TUBING ID: 3.958" CAPACITY: .01522 BBL/FT SSSV LANDING NIPPLE (OTIS) (3.813" ID) GAS LIFT MANDRELS 4.5"xl .5" (MERLA)(W/RA LATCHES) NO MD(BKB) TVDss I Dev 2 4,418 4,191 I 41 1 7,881 6,821 I 40 Top of 7" Liner 19,381 I ~ 9-5/8", 47#/ft, L-80, 19,872 BTRS Shoe PERFORATION SUMMARY REF: LOG: SPERRY SUN MWD 12/1/94 I I 2-7/8"I 6 110,890- 10,920' Open 12/98 4-1/2" [ n/a 110,988-11,495' 136RSlotted I B elow liP set 11,49i 4/96 4-1/2" n/a 11,495- 11,655' 13CR Slotted 4-1/2 .... X" NIPPLE (OTIS)(3.813"ID)I 0,605 7" Baker Packer (SABL-3)(3.875" ID) 9,626 4-1/2 .... X" NIPPLE (OTIS)(3.813"ID) 19,660 4-1/2 .... XN" NIPPLE (OTIS)(3.725"ID) 19,677 ~ 4-1/2" WLEG ELMD 9,689 9,701 6"41/2" TIW Tie Back I9'736 I ~ 7" 26# L-80 BTRS Section Cut ~0,290 I 4.5" 12.6#,L-80,NSCT ~9,750 Solid Liner~10,950 IProposed 2 7/8" Cemented LinerI Proposed Whipstock 10,424' I Proposed Cast Iron Bridge Plug 10,500' I Top Perf 10,890 6"x4.5" CTC Packer ~ 0,953 Baker IBP top fishing neck [ 1,495 3ement sheath around slotted liner 1,500 1,511 PBTD 111,667 I 4.5",12.6#,13CR Slotted Liner ~11,667 J E-15A Vertical Section 3OO 8600 8650 ...... TZ2C 8700 8750 ~8800 8850 .... 14N~ 8900 8950 9000 Path Distance(Feet) 800 1,300 1,800 2,300 Angle @ K.O.= 54 deg MD:10434 8,940 Tot Drld: 1244 ft 12N ........................................................................................ 11678 TD Marker Depths @Orig Wellbore 14N [ 8,8801ff TVD TZ2C [ 8,653]ffTVD 12N I 8,958]ffTVD TSAD [ 8,476JftTVD Kick Off Deprtr @KO 8,754[ft 'I-VD 10,4341ft MD 4,453 ff IMD KO Pt 10,434 MD New Hole 1244 Total MD 11,678 TVD TD 8,941 DLS degll00 Tool Face Length Curve 1 6 0 30 Curve 2 18 140 95 Curve 3 18 15 271 Curve 4 8 -90 599 Curve 5 8 90 249 1,244 Drawn: 5/3/99 16:38 Plan Name: Case 107 E-15A i t i , I -500~ -6,000 -5,500 -5,000 -4,500 -4,000 -3,500 X distance from Sfc Loc -1,500 -2,000 IWell Name E-15A I CLOSURE Distance 5,584 ft Az 257 deg NEW HOLE E/W (X) N/S (Y) Kick Off -4,310 -1,059 TD -5,432 -1,297 State Plane 659,031 5,974,864 Surface Loc 664,463 5,976,161 DLS deg/100 Tool Face Length Curve 1 6 0 30 Curve 2 18 140 95 Curve 3 18 15 271 Curve 4 8 -90 599 Curve 5 8 90 249 1,244 Drawn: 5/3/99 16:38 Plan Name: Case 107 E'15b CT Drilling & Completion BOP 22.5" 18"I 38" 7 1/16" Annular 7 1/16" 5000 psi ~ 7 1/16" I 7 1/1~"x 5,000 psi '-~ ~ Slips ~ -~ ~ 7/8" ~ 7 1/16" , Pipe ~ --~ 2 3/8" SWAB OR MASTER VALVE I STATE OF ALASKA ALASKA".olL AND GAS CONSERVATION COIt~/F~MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon ~. Suspend [] Plugging []Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Sus,oended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 903' SNL, 501' WEL, SEC. 06, T11N, R14E, UM At top of productive interval 2005' SNL, 214' WEL, SEC. 01, T11N, R13E, UM At effective depth 2325' SNL, 1050' WEL, SEC. 01, T11N, R13E, UM At total depth 2330' SNL, 1063' WEL, SEC. 01, T11N, R13E, UM 5. Type of well' ,~ Development i~ Exploratory [] Stratigraphic I-~ Service 6. Datum Elevation (DF or KB) KBE = 65.04' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number E-15A 9. Permit Number 94-134 10. APl Number 50-029-20668-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11684 true vertical 8990 Effective depth: measured 11667 true vertical 8990 Casing Length Structural Conductor 110' Surface 2671' Intermediate 9872' Production 909' Liner 1931' feet Plugs (measured) feet feet Junk (measured) feet 4-1/2" Baker IBP at 11495' Size Cemented MD 20"x 30" 8 cu yds concrete 110' 13-3/8" 3720 cu ft Arcticset II 2671' 9-5/8" 1415 cu ft Class 'G', 130 cu ft AS I 9872' 7" 468 cu ft Class 'G' 9381' - 10290' 4-1/2" 162 cu ft Class 'G' 9736' - 11667' TVD 110' 2671' 8391' 8009'-8723' 8284'-8992' Perforation depth: measured true vertical 10890' - 10920', 10988' - 11495' (Slotted section), 11495' - 11655 (Slotted, below IBP) 8983' - 8985', 8990' - 8998', 8998' - 8993 fbelow IBP) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9689' Packers and SSSV (type and measured depth) 7" Baker packer at 9626'; 4-1/2" Otis SSSV landing nipple at 2076' 13. Attachments [] Description summary of proposal 14. Estimated date for commencing operation May 15, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved [] Detailed operations program [] BOP sketch 15. Status of well classifications as: ,. Gas [~ Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fo~ and correct to the best of my knowledge Signed ~ Ted Stagg C~ Title CT Drilling Engineer i" /¢,"~' Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test~ Subsequent form required 10- I Approval No.,.~,~.-. ~ Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE J H 1 5 0 2 R., 9 I o3/2~,/~s~ ~ VENDOR ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 03269c2 CKO32&99B 100. O0 100. O0 HANDLING INST- S/H TERRI HUBBLE X4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, ~I[o]IJ/-~J ~ 100, O0 100. O0 ::~:.::.AN~HO~AG~:::.AL/i, SI~:?:99519.6612 ':.i.:':::~::'.:.i!::!'.' ..':.? .%. ::?;..:..: ... ......... '::':..:...;:.': c~,wL~,D, eH,o ....... :?:" :.!:;:: ::::: :;':~:!; :?.::i.:..:':' '::"::::~;' "~"::~ili!"?:': ~:'':~ ::~":':':::~ ~::~":.¥?" ": '. .':;i;~:~:~::~ : !::?' .~::':.': ~':'' :~::""'" 412 ANCHORAGE ," ], 50 i]P, q,' I:O h ], i~O 3P, q c;~: OOP, h h :~ q,' WELL PERMIT CHECKLIST FIELD & POOL ?.~-/)/'~ _//,~'~ ADMINISTRATION COMPANY ENGINEERING D,~TE ~'~ WELL NA.M~,.~ ~'-_/~r-/~ PROGRAM: exp__dev X redrll--~ INIT CLASS ~ //-,~.~// GEOL AREA ,~?.~.~ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to /-/. _¢~'~_ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. serv __ wellbore seg __ ann. disposal para req_ UNIT# .//~'_~C~ ON/OFF SHORE N N ~ N N (~ N---- ..~q ~ - O"r. ;~'- (_~N ~N N ON GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N // 31. Data presented on potential overpressure zones ....... ~ ~~ ~, 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. Y N 34. Contact name/phone for weekly pro§mss reports £exptorator¥/xfnty] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a s.~,~e r.~ceiving zone; ....... Y N (B) will not contaminat.,e,,r~eshwat~or cause drilling waste... Y N to surface; (C) will not imp.,~if'mechanica~ntegrity of the well used for disposal; Y N (D) will not/dafnage produ/qifig formation or impair recovery from a Y N pool; afld (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE GEOLOGY: ENGINEERINg.: UIC/Annular COMMISSION: RPC~ BEW {~.~',~' W~,,''''~ DWJ ~"-'~" JDH ~ RNC CO ¢/;o/~,i c~ Comments/Instructions: c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, informati~)n 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 b~illing Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Apr 21 09:11:13 2000 Reel Header Service name ............. LISTPE Date ..................... 00/04/21 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 ..................... 00/04/21 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 Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW- 90129 S. LATZ PARKER/HUPP BP Exploration (Alaska), Inc. Sperry Sun 21 -APR- 00 6 liN 14E 903 501 60.74 .00 32.21 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10412.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RECEIVED APR 28 000 Alaska 0il & Gas Cons. Commission Anchorage REMARKS: 1. ALL DEPTHS ARE SUB SEA TRUE VERTICAL DEPTHS (SSTVD) UNLESS OTHERWISE NOTED. 2. MWO RUN 1 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DEPTH CORRECTION IS WAIVED PER T. LOVE PER THE EMAIL MESSAGE FROM D. DOUGLAS OF BP EXPLORATION (ALASKA), INC. OF 4/18/00. RA TAG ADJUSTED MINUS 21 FT. FROM 10433' TO 10412'MD IN ORDER TO CORRECT TIE-IN BACK TO E-15 PARENT WELL. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM E-15A AT 10406'MD, 8733'SSTVD (TOP OF WHIPSTOCK). 4. MWD RUN 1 REPRESENTS WELL E-15BPB1 WITH API # 50-029-20668-72 THIS WELL REACHED A TOTAL DEPTH OF 11675'MD, 8933'SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10385.5 11650.5 SROP 10421.0 11675.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 10385.5 11675.0 Optical log depth units~ .......... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10385.5 11675 11030.3 2580 ROP MWD FT/H 0.31 3275.6 126.706 2509 GR MWD API 14.75 325.67 58.5923 2531 First Reading 10385.5 10421 10385.5 Last Reading 11675 11675 11650.5 First Reading For Entire File .......... 10385.5 Last Reading For Entire File ........... 11675 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ........ 00/04/21 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 ....... 00/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10385.5 11650.5 ROP 10421.0 11675.0 $ LOG HEADER DATA DATE LOGGED: 31-MAY-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 1.03 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR3uL GAMMA PROBE $ 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 TEMPEP~ATURE (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 STA/qDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 11675.0 47.1 98.4 ToOL NUMBER 066 3.750 10412.0 FLOPRO 8.80 65.0 9.0 29500 6.0 .000 .000 .000 .000 .0 154.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10385.5 11675 11030.3 2580 ROP MWD010 FT/H 0.31 3275.6 126.706 2509 GR MWD010 API 14.75 325.67 58.5923 2531 First Reading 10385.5 10421 10385.5 Last Reading 11675 11675 11650.5 First Reading For Entire File .......... 10385.5 Last Reading For Entire Fm~ ........... 11675 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/04/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/04/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun D~lling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Apr 20 13:46:46 2000 Reel Header Service name ............. LISTPE Date ..................... 00/04/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/04/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: R3kNGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 1 A_K-MW-90129 S. LATZ PARKER/HUDP OPEN HOLE BIT SIZE 3.750 3.750 (IN) E-15B 500292066802 BP Exploration (Alaska), Sperry Sun 20-/LPR-00 Inc. MWD RUN 2 AK-MW-90129 S. LATZ PARKER/HUDP 6 liN 14E 903 501 60.74 .00 32.21 CAS ING DRILLERS SIZE (IN) DEPTH (FT) 4.500 10412.0 RECEIVED APR 2 8 !000 Alaska Oil & G~s Cons. Commissio~ Ar~chorage Rk~'~kR KS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESs OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH NATLrR~_L GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DEPTH CORRECTION IS WAIVED PER T. LOVE PER THE EMAIL MESSAGE FROM D. DOUGLAS OF BP EXPLORATION (ALASKA), INC. OF 4/18/00. RA TAG ADJUSTED MINUS 21 FT. FROM 10433' TO 10412'MD IN ORDER TO CORRECT TIE-IN BACK TO E-15 PARENT WELL. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM E-15A AT 10406'MD, 8733'SSTVD (TOP OF WHIPSTOCK). 4. MWD RUNS 1 AND 2 REPRESENT WELL E-15B WITH API # 50-029-20668-02 THIS WELL REACHED A TOTAL DEPTH OF 11772'MD, 8930'SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10385.5 11744.0 ROP 10421.0 11772.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMJ~RKS: EQUIVALENT UNSHIFTED DEPTH - Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 10385.5 10585.0 2 10585.5 11772.0 '.Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 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 Name Service Unit Min Max Mean Nsam DEPT FT 10385.5 11772 11078.8 2774 ROP MWD FT/H 0.31 1712.89 112.067 2703 GR MWD API 14.75 325.67 62.0008 2718 First Reading 10385.5 10421 10385.5 Last Reading 11772 11772 11744 First Reading For Entire File .......... 10385.5 Last Reading For Entire File ........... 11772 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/20 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 ....... 00/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10385.5 10585.0 ROP 10421.0 10585.0 $ LOG HEADER DATA DATE LOGGED: 31-MAY-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 1.03 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11675.0 ......... 47.1 98.4 TOOL NLTMBER 066 3.750 10412.0 FLOPR0 8.80 65.0 9.0 29500 6.0 .000 .000 .000 .000 .0 154.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10385.5 10585 10485.3 400 ROP MWD010 FT/H 0.31 158.26 77.3931 329 GR MWD010 API 14.75 325.67 29.3458 400 First Reading 10385.5 10421 10385.5 Last Reading 10585 10585 10585 First Reading For Entire File .......... 10385.5 Last Reading For Entire Fi,~ ........... 10585 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/20 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 ....... 00/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10585.5 11772.0 GR 10585.5 11744.0 $ LOG HEADER DATA DATE LOGGED: 02-JLrN-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 1.03 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11772.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 54.7 MA~XIMUM ANGLE: 97.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER 066 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 10412.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLOPRO 8.65 65.0 9.3 32000 Dat FLUID LOSS (C3) : '- RESISTIVITY (OHM_M) AT TEMPERATURE (DEGF) MTJD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MI/D FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 7.0 .000 .000 .000 .000 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 .0 154.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10585.5 11772 11178.8 2374 ROP MWD020 FT/H 4.57 1712.89 116.872 2374 GR MWD020 API 25.42 172.58 67.6358 2318 First Reading 10585.5 10585.5 10585.5 Last Reading 11772 11772 11744 First Reading For Entire File .......... 10585.5 Last Reading For Entire File ........... 11772 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/04/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments .............. ~-.-~STS LIS Writing Library. Scie~t±fic Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/04/20 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 B.P. Exploration (True) Pad E,E-15B Prudhoe Bay,North Slope, Alaska SI/RVEY LISTING Page 2 Your ref : E-15B Last revised : 3-Jun-1999 Comments in wellpath MD TVDss Rectangular Coords. Comment 10290.00 8656.00 943.36S 4229.59W Tie on 11780.00 8930.20 1182.90S 5537.42W Projected to TD NO Targets associated with this wellpath
