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197-194
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 18-26 193-005 50-029-22329-00-00 18-26PB1 193-005 50-029-22329-70-00 18-26A 197-194 50-029-22329-01-00 18-26APB1 197-194 50-029-22329-71-00 18-26APB2 197-194 50-029-22329-72-00 18-26B 209-017 50-029-22329-02-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/20/2024 Main Folder Contents: Please include current contact information if different from above. T39182 T39183 T39184 T39185 T39186 T39187 18-26A 197-194 50-029-22329-01-00 18-26APB1 197-194 50-029-22329-71-00 18-26APB2 197-194 50-029-22329-72-00 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.15 13:40:18 -08'00' XHVZE Pages NOT Scanned in this Well History File 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. I ¢/-/ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [3 Other, No/Type 'OVERSIZED n Logs of various kinds n Other Complete COMMENTS: Scanned by: ~,,er~y Mildred Daretha owell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is/ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMI~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~9-09 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class:,, ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/6/2009 12. Permit to Drill Number 197-194 - 309-043 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 06/01/1998 13. API Number 50-029-22329-01-00 4a. location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 06/18/1998 14. Well Name and Number: PBU 18-26A" 755 FNL, 296 FWL, SEC. 19, T11N, R15E, UM Top of Productive Horizon: 3111' FSL, 2603' FEL, SEC. 13, T11 N, R14E, UM 8. KB (ft above MSL): 52' - Ground (ft MSL): 17' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3707' FSL, 4108' FEL, SEC. 13, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 9790' 8588' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 692051 y- 5961121 Zone- ASP4 10. Total Depth (MD+TVD) 12650' - 8665', 16. Property Designation: ADL 028321 & 028307 TPI: x- 689054 y- 5964912 Zone- ASP4 Total Depth: x- 687534 y- 5965470 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi I r ni an rin in rm r 2 AAC 2 . 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 1. -4 SurF 11 rfa 11 0" # C I II " 7 1 1413 sx CS III, 550 sx'G' 200 sx CS II 9- / " 47# T- S 8938' 36' 4 ' 1 -1/4" 1 25 I ' 2 NT-80 108 8' 7' 77' -1 5 I ' " 1 1 2' 77' I -3 8" 4. 1 1 6 65T - /4" 44 sx ' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, L-80 3126' MD TVD MD TVD 3-1/2", 9.2#, L-80 3126' - 10628' 8549' '' q 25. ACID,.FRACTURE,CEMENT.SOUEEZE ETC. {{ii {{{{ {~~ totd ggy~**~~yy'~~ E {~ ~~ '~ .'lr.~t*~~WyWp~ ~Iw1~ ~~' ~} ~~Vd DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERL4L USED 10496' Set CIBP 9700' - 10468' Tubing Punch for isolation and tubing stabilization 9848' Set Cement Retainer (9850') & Set CIBP (9848') 9790' P&A w/ 33 Bbls Class'G', & Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCUU-TEO 24-HouR RarE.~ OIL-BBL: GaS-MCF: WATER-BBL: OIL GRAVITY-API (CORR): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewall Co s ®No If Yes to either question, list formations and intervals gyred (MD+TVD of top and bottom of each), and summarize lithology an presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory ana I p C 250.071. t.~;~ ~t'iS ~ ~UU~ None ' ~- '=0 ,~laska Qii & Gas Cons. Cummissior~ ' 4~cktAl'~Ige Form 10-407 Revised 0212007 ~` Co ~ I lu D R I ~' ~-° ~~~~ .~~~, _. 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals an formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 10127' 8639' None Zone 1A / TDF 10923' 8677' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. ~~ ~ Signed Terrie Hubble Title Drilling Technologist Date ~~ PBU 18-26A 197-194 309-043 Prepared By NameMumber. Terrie Hubble, 564-4628 Drilling Engineer: Mel Rixse, 5645620 Well Number Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITela 23: If this well is completed for separate production from more than one interval (multiple completion), so state in Rem 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. SubmR detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 SubmR Original Only • 18-26A, Well History (Pre Rig Sidetrack) Date Summary 2/16/2009 MIRU. RIH w/ 2.75 drift. Tagged deployment sleeve at 10505' CTM. PUH, Flag pipe at 10475'. RIH with PDS memory GR/CCL in carrier w/2.2" nozzle. Tagged deployment sleeve at 10510' CTM. PUH, Repaint flag at 10475' CTM. 2/17/2009 Log with PDS memory GR/CCL in carrier w/2.2" nozzle from flag at 10475' CTM to 8400' CTM at 30 fpm. Good Log (+15' correction). RIH w/ 2.76" 035 CIBP. Set CIBP C~ 10496'. Recovered 1/2" alum ball, RIH w/2' x 4 spf (9 holes) tbg punch guns. Tag CIBP ~ 10496', p/u and punch tbq Q 10470' - 10468'. Confirmed shots fired, recovered ball. RIH w/2' x 4 spf (9 holes) tbg punch guns, tag CIBP C~ 10482', corrected depth to 10496'. PUH to 9702', drop .50" aluminum ball. Paint flag for retainer run. Punch fired. Shots from 9702' to 9700'.. POOH. Confirmed that guns fired and .50" ball recovered. Secure well due to going to Phase 2 weather. On weather Standby. 2/18/2009 Makeup Baker 2-1/8" retrievable packer and RIH. Tag top of CIBP for depth control. Set packer at 9901'. Circulate 30 bbls of 60/40 methanol through tubing punch holes. Confirmed circulation path for upcoming cement job. Overpull to release packer. Let elements relax for 30 minutes. POOH. OOH with packer, all elements recovered and ball recovered. PT MHA to 3500 psi. Standby for weather. 2/19/2009 Wait for weather to improve (Phase 1 w/level 2 on pads). MU and RIH with HES 3.5" cement retainer. Tag top of CIBP for depth control (+12' correction). PUH and set retainer at 9850'. POOH. MU and RIH with HES stinger with 2.65" centralizer. Coil at 9842' CTM, Attempt to establish if stinger stung into retainer by pumping 1 % KCL fluid. 2/19/2009 Wait for weather to improve (Phase 1 w/level 2 on pads). MU and RIH with HES 3.5" cement retainer. Tag top of CIBP for depth control (+12' correction). PUH and set retainer at 9850'. POOH. MU and RIH with HES stinger with 2.65" centralizer. Coil at 9842' CTM, establish if stinger stung into retainer. Begin turning well over with 1 %KCL fluid. Could not confirm if stinger was stung into retainer. Attempt 2000 psi pressure test on tubing. Pressure test failed after -- 3 minutes. Infectivity established at 1.9 bpm and 1152 psi. Confer with CT scheduler and town engineer. POOH for weekly BOPE test. 2/20/2009 MU and RIH with Baker 2 3/8" motor and 2.78" 5 bladed mill. POOH. MU and RIH with Weatherford 3- 1/2" CIBP. Tag HES cement retainer C~ 9844' ctmd. PUH and correct to 9850'. Set Weatherford 3-1/2" CIBP C~3 9848'. POOH. Rig back to make up cementing BHA. 2/21/2009 MU and RIH with 2.20" BDN. Tag CIBP C~ 9838' ctmd. Correct to CIBP. PUH and flag coil at 9680' (red and white). Fluid pack well with 75 bbls diesel. Circulate down coil with 1 %KCL. RU cementers to coil. Initial infectivity with 1 %KCI was 770 psi at 1 bpm. Pump 5 bbls fresh water, 33 bbls of 15.8 ppq Class G tUnislurry cement and displaced with 5 bbls of fresh water and 35 bbls of diesel while reciprocating from 9680' to 9660' (20' to 40' above the upper tubing punch). After 13 bbls had been squeezed into the wellbore, the CT overpulled 10k on up weight, begin gauging returns and laying in cement. Recovered 1 bbl, then well went back to drinking cement. Continue creeping uphole while finishing CT displacement leaving 4 bbls of cement in 3-1/2" tubing. Hesitate for 90 minutes and then ramp pressure 200 psi over static wellhead pressure with 1 bbl of fluid. Pressure loss was 200 psi over 90 minutes to static WHP. Bump pressure again with 1 bbl of fluid to 500 psi (200 psi over static) and monitor for 30 minutes. Pressure held 200 psi overbalance for 30 minutes. POOH pumping CT displacement with diesel holding 2/22/2009 MU and RIH with 2-1/8" Baker PDM motor and 2.78" 5 bladed mill. Dry tag first cement at 9607' ctmd. Mill cement stringers until hitting hard cement at 9650'. Continue milling using 863 bbls of 1 % XS KCI and Geovis XT sweeps performing short trips every 50'. Mill to 9832' ctmd. (Estimated 9842' corrected). Make final Geovis sweep and chase up hole opening circulation port on the BHA. Freeze protect well from 2500' with 60/40 meth. Perform 3000 psi MIT-T. MIT-T: Failed. Pressured tubing to 3000 psi with 9 bbl's of 60/40 meth. MIT-T lost 134 psi in 1st 15 minutes and 69 psi in 2nd 15 minutes for a total of 203 psi during 30 minute test. MIT-T failed. Bled tubing to 100 psi. Final WHPs = 100/661/24. Suspect well may have still been approaching temperature stabilization. Suggest a repeat of MIT-T. Page 1 of 2 • I 18-26A, Well History (Pre Rig Sidetrack) Date Summary 2/23/2009 RDMO. Notify DSO of well status. Job Complete. 2/24/2009 T/I/0=200/600/0 Temp=Sl MITT to 3000 psi Arrive on location, Spot unit, Standby to open permit. 2/25/2009 Temp=S1 MIT T PASSED to 3000 psi. Pumped 7.8 bbls neat methanol down Tbg to reach test pressure for MITT. Tbg lost 140 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 180 psi in 30 min test. Bled Tbg (- 7 bbls). Final WHPs=200/600/0. Valve positions at departure: Swab, Companion, Wing = SI. SSV, Master, IA & OA =Open. 3/10/2009 T/IA/OA= 300/600/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (Fail) PPPOT-T RU 2 HP BT onto THA test void, 200 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment re-installed Alemite. Cycled LDS out 1.0" ran in torqued "ET style" all were in good working condition. PPPOT-IC RU 2 HP BT onto IC test void, 50 psi to 0 psi, flushed void until clean returns achieved. Would not pressure above 2000 psi, cycled all LDS "ET style" ran out 1.0" and ran in torqued, all were in good visual and working condition. (2nd) test same results. Bled IC void to 0 psi RD test equipment re- installed Alemite. 3/23/2009 T/I/0=0/600/0. Pressure test down on swab valve and wing valve to 5000 psi for 5 mins. Test good. Pressure test down on master valve for 5 mins. Test good, Service tree 100% with Clare 501. Pre CTD. 3/25/2009 T/I/O = MV/600/vac. Temp = SI. IA FL pre CTD. MV locked closed. IA FL @ 210' (12 bbls). Tie in crew currently removing well house and flow line. SV, WV, MV = C. SSV = O. IA, OA = OTG. 3/26/2009 T/I/0=200/600/Vac. Temp=S1. Bleed WHP's to 0 psi. TBG FL @ surface. Bled TBG from 200 psi to 0 psi in 20 mins (all fluid). Bled back 31 gallons. IA FL @ 210' (12 bbls). Bled IA to bleed trailer from 600 psi to 0 psi in 5 hrs (all gas). During the IA bleed, the TP increased to 2 psi. Bled off TP in <1 min (all gas). Monitor for 30 mins, TP &IAP increased to 0+. TBG FL near surface. IA FL @ 198'. Final WHPs=0+/O+Nac. SV, WV, MV =Closed. SSV =Open. IA, OA = OTG. NOVP. 3/27/2009 T/I/O = MV/30/VAC. Temp = SI. Monitor WHPs post bleed. Well house and flowline removed from well. Unable to access swab platform. IAP increased 30 psi overnight. SV, WV, MV =Closed. SSV =Open. IA & OA = OTG. NOVP. 3/28/2009 T/I/O = 10/40/VAC. Temp= SI. Monitor WHPs post bleed. IAP increased 10 psi overnight. SV, WV, MV = Closed. SSV =Open. IA, OA = OTG. NOVP. 3/29/2009 T/I/O = 5/45NAC. Temp = SI. Bleed WHPs to 0 psi (CTD Prep). Tbg FL @ surface. IA FL @ 258'. Bled Tbg from 5 psi to 0 psi in < 1 min. Bled IAP from 45 psi to 0 psi in 1 hr 30 min, multiple bleeds & monitors. TP increased to 0+ &IAP increased to 1 psi. IA FL unchanged. Final WHPs = 0+/iNAC. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 3/30/2009 T/I/O = 0+/10NAC. Temp = SI. Monitor WHPs post bleed. TP unchanged, IAP increased 9 psi, OAP remained unchanged. SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. 3/31/2009 T/I/O = 0+/18/VAC. Temp = SI. Monitor WHPs post bleed. Well house and flowline have been removed. IAP increased 8 psi overnight. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. Page 2 of 2 • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 18-26 Common Well Name: 18-26 Spud Date: 2/3/1993 Event Name: REENTER+COMPLETE Start: 3/3/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2009 09:00 - 23:30 14.50 MOB P PRE Move rig from DS9-33A to DS18-33B 23:30 - 00:00 0.50 MOB P PRE PJSM, Spot rig over well 4/5/2009 00:00 - 00:15 0.25 BOPSU PRE ACCEPT RIG AT MIDNIGHT 00:15 - 03:30 3.25 BOPSU PRE 03:30 - 10:30 7.00 BOPSU PRE 10:30 - 13:00 I 2.501 RIGU I I I PRE 13:00 - 15:00 2.00 RIGU N SFAL PRE 15:00 - 21:45 6.75 RIGU P PRE 21:45 - 23:00 1.251 RIGU P IWEXIT 23:00 - 00:00 1.00 RIGU P WEXIT 4/6/2009 00:00 - 03:45 3.75 WHIP P WEXIT 03:45-03:50 I 0.081WHIP IP I IWEXIT 03:50 - 06:15 2.42 WHIP P WEXIT 06:15 - 06:30 0.25 STWHIP P WEXIT 06:30 - 08:45 I 2.251 STWHIPI P I IWEXIT 08:45 - 10:30 1.75 STWHIP P WEXIT 10:30 - 10:45 0.25 STWHIP P WEXIT ~Td'a-1•d'717f1-'I-~1ZT S71T PJSM for N/U of BOPE N/U BOPE Pressure test BOPE at 250 and 3500 psi. Test witness waived by AOGCC inspector Chuck Scheeve. Send test report to AOGCC. Rig up new injecter head and guide arch. Found both inside support arms for guide arch were 2" to long. There was no way to measure the length until the guide arch was mounted, Call out for SWS welder to fix guide arch support Shorten support arms for guide arch at SWS shop. Install internal grapple and pull 2" coil from reel to injecter. Cut off grapple, boot end of E-Line. Fill coil, PT inner reel valve. Reverse circ. at 3800 psi for 30 seconds once E-line started moving, to limit E-Line slack. Cut off 330' of coil to find E-Line. Pressure test inner reel valve C~ 3500psi for 10min Install, Pressure test & pull test Kendal CTC P/U whipstock BHA Function test MWD Tool RIH with Whipstock BHA RIH with whipstock BHA Tie in C~3 9,670' to 9,750.3' no correction Run CCL From 9,670' to 9,812' Close EDC Shear at 3,900psi Set Top of Whipstock @ 9,790' POOH SAFETY MEETING. Review procedure, hazards and mitigation for L/O BHA and M/U 2.80" window milling BHA with CoilTrak tools. Lay out whipstock setting tools. M/U 2.80" window milling BHA #2 with 2.80" HCC, diamond window mill and string reamer, Xtreme motor, 2 jts CSH and CoilTrak. BHA OAL = 108.19'. RIH with milling BHA #2. Circ 0.3 bpm, 1100 psi. Log GR tie-in, added 3' to CTD an agge op o w ips oc a Mill 2.80" window thru 3-1/2" and 7" liners. Lowside exit. Hole inclination = 73 deg at 9790'. 1.5 bpm, 3150 psi, RIH very slow, not able to get WOB without a stall. Several stalls, 12 stalls and no progress. Strong stalls, not a motor problem. Tme mill at 0.05' every 5 min to ease down onto tray. Still stalls. Top of whipstock appears to be out from ID of 3-1/2" tubing. Hard Cement from the cement squeeze was milled out with a 2.78" mill, this may have left a cement sheath of hard cement Printed: 4/13/2009 2:53:58 PM IPtf=t 4-7{lb' C~IW Ifs1ELlHF1~ D ~ FMC ACTtiATOR - AXELSfJN KR, EL EV = 52' BF. ELEV . _. NA KOP = 2075 Max Angle = Datum MD = 99e,1 Datum TV D = YS600' SS SAEEt' TES: QA NOT ARCTIC PACKHS 42116193. T4P 2~OF' 13-318" CSG ARE 68#1K-55. ~~ f s. J ~" ~~ ~ WELL A1~LE> 74° ~ 9'500' & > 94" ~ 11174'. .~.. a ~,'r' ~T~'; 4-1/2° TBG, 12.6#, L-80, .€3152 bpf, [D = 3.958`" ~ 13-318" CSG, 68f72, K-551E-80, ID = 12.347" 3124' I ~ 374!)` ~ ~,E _., _ 2'~92~ 4-112 CAMCOTRDP-4A, TRSSSV, ID=3.812. 2640' ...EST TOP OF CEtJIENT (12105103) ', 312'5" 4-112" X 3-1 #2°' X<l. ID = 2.992" GAS LIFT MIA I~3RELS 1 32x7 3206' 21 MMG pOME RK 16 04120109 2 5497 5258'' 23 feMAG 5t3 RK 2(3 04120109 3 7673 725[3' 27 MMG DMY RK 0 0?ti 6193 4 8338 7811 ' 37 I+MMr1G DMY RK 0 {32/16193 5 8456 79034 4D MG DMY TGE 0 02/16193 $3(}7' 3-112" 0715 X NIP, ID = 2.81..3" TOP OF TMV TIEBA CK SI.V $6,r}~' ~ $549' ~-~9-Si8" Y. 3-1 f2" RKR SB-3 PKR, D = 3.875°, 9-51&" X 7" TM/ 5 PACKER $~~$' $593' 3-112" PARKER SUSiN NIP, "' MILLER TO 2.84`" (041121981 $~63` 8-518" X 7" TMU DTI=S FiGR 9-518" CSG, 47#, NT-8D5, ID = 8.881,. PERFORATc3N t JttillUlARY REF LOG GR-f'~`I ^`1'' 1119/98 ANGL` AT' .~=' ~_ 1Q22fl` Note: Refer to ProdE~ciron DB for historical perfi data SIZE SF's IPlTEF1.i;, L OpniStlz DATE ,._:;.~ 6 ,~....,,, ,, ;. Q ~,~, ~a ~; ', : O fi ,' "'C ~~ Q _ t 6 1 1 t t ,~:~ c'7 ~ 1,92 O 6 ~~. ;1-,°~ iJ ' ~ . - ~ _ i _i I'_ C3 ~ '. TOP OF 2-31$" LNR, lD = 1.941 " ~ 10533' 3-112" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992° '110616" J5$6` -1 Liner Tc~p Packer 35KB ~.~o~ .~~. _. ,.~ ,, r - -~-~7 .~' ~- , ., ~ of ,. ,;., . -- --- --- ,, >.-\ - 1., ,, ID -= 1,941" ~''~~ I ,. i __ _ __ .d _m-mm ~~ - ., ~ ,.,~ 't=~-,-~ _ it~~~~i 1052$ 2.70"BKRDf'LOYMEh3TSLV,ID=1.969" 10635` --j7" X 4-112" 7NV SS PKR ASSY jBEI-IIND LNR) 10651` --~4112"PORTED JOINT (37.98')(BEH1NpLNR) 7"LNR, 29tf, NT-805, ID = 6.1$4". ~ 10$$ 4112" LNR SIDETRACK WINDiO io$ss' - 113902' ~a~F ~PLtIG) LNR, 12.6#, Nfi 80, .0152 bpf, ID = 3.958" 11$5 12265'H1.75" HKRCIBP{T0;101001 ELM 2-318" LNR, 4.6tfi, L-80, :©039 bpf, ID ° 1.941......" QATE RE1! BY COMMENTS IJATE REV BY COMMENTS 02/16/93 ORIGINAL COMPLEfI€3N 06/21/98 CTI] SID!=TRACK ('I$-26~!) 01!28/02 CHr'KAK CORRECTIONS 44!15/09 NOf2DIC1 CTD 51L'~TRAGK (18-2681 04120; 09 TFA JTL H GLV C1Q 04/2:II0~1 TLH CORREC110NS PRUDHOE BA`l UNIT UVELL: 18-26$ PERMIT Na: API No; 50-(329-22329-02. SEC 19. T11 N, R14E, 755' SNL 8~ 298' ESNL 8P Expiaration (Alaska? ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. l~rotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and - f 9~- -/~i~/ !~ G~3Qi ~a -~ 1~-C~IU ProActive Diagnostic Services, Inc. Attn: - Avbert 74.=~"ichey 130 West International Airport Road Suite C ' ~ .~ ^ ~~~~~'_~ 1~ ~~~ `~ F' ~ ~i~''` Anchorage, AK 99518 Fax: (907) 245.8952 1) Coil Flag 16-Feb-09 18-26A EDE 50-029-22329-01 2) Leak Detection - WLD 20-Fetr09 J-27A 1 Color Log / EDE 50-029-21733-01 Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: 3~~a:'3i?g?4'~~ai~~3e971~f','~~il.~~t~u WEBSITE: ~ '~i n 4~ C:\Documen~ and Settings\OamerlDesktoplTransndY BP.docx • o SARAH PALIN, GOVERNOR ALASSA OII, A1~TD GA5 333 W. 7th AVENUE, SUITE 100 COIrT5ERQATION COI1Ll~II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. r PO Box 196612 t'~ ~ ~ ~ 1.~" Anchorage AK 99519-6612 ~ ~ 1 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-26A Sundry Number: 309-043 Dear Mr. McMullen: ~ f i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS .31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~ Daniel T. Seamount, Jr. .,~/ Chair DATED this~a day of February, 2009 Encl. G ,~'Q`~ STATE OF ALASKA r~ 1 ~ ~ ~'ALP~ OIL AND GAS CONSERVATION COM~ION `~0 ~ APPLICATION FOR SUNDRY APPROVAL ~~ ~~ 20 AAC 25.280 ~fA_ e ~7 ~09 m~ 7~~_ 1. Type Of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extens ~ Q~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspen$p~~~~~~• eQ/~; ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-194 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22329-01-00 - 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-26A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028321 8~ 028307 52' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12650' ~ 8665' ~ 12573' 8669' 12265' None i Br 11 1 ' / 1 2' /" 4' 7 4 Pr in r 7" ` 7' - 7 ' 1 70 'n 277' 4-1/2" 1 ' - 1 ' - 77' 0 7 ~~ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11450' - 12250' 8690' - 8679' 4-1/2", 12.6# x 3-1/2", 9.2# L-80 128' Packers and SSSV Type: 9-5/8" x4-1/2" Baker'SB-3' packer Packers and SSSV MD (ft): 8549' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: February 10, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name Jo M 11 Title Engineering Team Leader Prepared By Name/Number: Signature ~ Phone 564-4711 Date ( U~° Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ,-~ Conditions of approval: Notify Commission so that a representative may witness ,~,~, ~ ~~ ,„ F „ `, ' ~ r ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~C~~~~ ~.~~~~`~ ~~~~S~ ~~~~~aw-1 0.t~RJ~c~~ ~~g~'' Subsequent Form Required: ~,.~ `"'l APPROVED BY I I e / A raver B : C~MMISSI~NER THE COMMISSION Dat Form 10-403 Revis'~d 06/2006 .' ~ ~~ ~~~ ~ ~i ~ooa Submit In Duplicate ~~Qn _ ., .d ~L_ • To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: January 26, 2008 Re: 18-26A Perforation Abandonment and new CTD Sidetrack Sundry Approval Request Sundry approval is requested for well PBU 18-26A. It is proposed to set a CIBP with a cement plug to abandon the A lateral. A cement isolation/tubing support packer will be created between the 3-1/2" production tubing and the 7" liner. Anew coil tubing drilling sidetrack is planned to follow. The CTD side track will target the Zone 1 A sands in an offset fault block to the east. 1,200' of perforations in the Zone 1 A sands is anticipated. WELL CURRENT HISTORY AND STATUS: Well 18-26A is a horizontal producer sidetracked to lower Zone 1 in June 1998 with ~ 1000ft of perfs and 2-3/8" liner. The GOR rose quickly and the well began intermittent production within a year. Additionally, the well is twinned with 18-156 and has seen very little ontime since 18-15B has been a more competitive well in HP post the May 2005 RWO. A CIBP was set at 12,265' and in October 2000 shutting off the tail of the well. This operation brought no benefit as the GOR increased from significantly after setting the plug and the well was eventually shut in. The plug seemed to have shut-off mostly oil and no gas. An attempt was made to remove the CIBP in April 2001 but the CTU was not able to move the plug after several days of milling. The well remained SI for high GOR from then until mid 2002. The well showed some re-charge and stayed online until early 2003 when the gas rates crept back up, subsequently resulting in 18-26A going back to being a cycle well. The original pert strategy for 18-26A maintained 500' standoff from the parent wellbore and was placed ~5' TVD deeper in structure. That left --900' and of unperf'd wellbore in the heel of 18-26A. Therefore, a decision was made to shoot 180' of adperfs in May 2004. These heel adperfs brought in an additional gas without any increase in oil rates. The well stayed SI for anncomm for over 2-1/2 years -from the December 2005 to July 2007 when the anncomm issues were resolved. It proceeded to hit MGOR within 2 months of being POP'd. The most recent POP attempt was on 9/20/08 and the well hit marginal within 9-days even after being SI for 10 months. 18-26A has had a history of failed MITOAs. An OA cement downsqueeze that required 64 bbls of arctic cement was performed in December 2003 and eventually led to a passing MITOA to 3000 psi. However, the MITOA failed again in July 2005 (Tested to 3000 psi with a LLR = 0.28 gpm). The well then produced with a waiver until 12/17/05 when the waiver was cancelled due to a failing MITOA. A June 2007 passing MITIA to 3500 psi and a passing MITOA to 2000 psi brought the well back to operable status. The well is in sound mechanical shape, the March 2008 caliper indicates that the 4-1/2" x 3-1/2" L-80 tubing is in good condition with no significant penetrations in excess of 11 % recorded. The most recent pressure tests were performed on 12/14/08 with both the MITIA (to 3000 psi) and the MITOA (to 2000 psi) passing. REASON FOR SUNDRY AND SIDETRACK: The well currently has low remaining value, a very low ontime, has no viable wellwork options and quickly goes to high GOR even after being SI for extended periods of time. A sidetrack will enable this wellbore to be more effectively utilized and bring more value to the field. • Pre-Rig Operations • 1. O Dummy GLVs 12/08/2008 DONE 2. O MIT-OA - 2000 psi, MIT-IA - 3000 psi Passed 12/14/2008 DONE 3. C Drift to 10,528' (top 2-3/8" liner) for Halliburton cement retainer and BTT 3-1/2" Dummy WS/packer assembly (2.65" OD) 4. C Run MCNVCCL 10,528' ELMD - 8507' ELMD 5. C Set CIBP at 10,500' (mid first full joint above 2.70" liner deployment sleeve 6. C Punch holes in tubing at 10,468' ELMD(mid first full joint above CIBP). 7. C Punch holes in tubing at 9700' ELMD. 8. C Set Halliburton EZ drill Squeeze Packer/Retainer at 9850' MD 9. C Stab into retainer and establish returns through lower pert to upper perfs and out to surface. 10. C Circulate 31.0 bbls cement through perforations while taking returns. 11. O MIT-Tubing 3000 psi 12. O AC-LDS; AC-PPPOT-IC, T 13. O PT tree (MV,SV,WV), function LDS 14. O Bleed gas lift and production flowlines down to zero and blind flange 15. O Remove S-Riser, Remove wellhouse, level pad -Complete ~'~~ Rig Sidetrack Operations: (Scheduled to begin on March 1, 2009) " 1. NU 7-1/16 CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pu ll BPV. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Jet ~-1/L"" monOdOre WnIpSTOCK at y/yU" tLMU. Mill 2.80" window through 3-1/2" tubing and 7" liner at 9790' ELMD. Drill build/turn section with 3" bicenter bit, and land well. Drill lateral section to 11,937' MD w/ resistivity log. Run 2-3/8" solid liner w/cementralizers to TD. Place liner top at 9600' MD. Cement liner from TD to TOL (9590'MD) with 15.8ppb cement. Clean out liner/Run MCNUGR/CCL log. Test liner lap to 2000 psi. Perforate per geologist. Set liner top packer (if fails liner lap test) Freeze protect well to 2500' with methanol. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. RDMO Nordic 1. Post Rig: 1. Re-install wellhouse and FL's 2. Pull BPV 3. Install GLV 4. RU test separator, flow test well. e Rixse CTD Engineer c~PQrovc~,` CC: Well File Sondra StewmanlTerrie Hubble ~~~ ,~„ ~ w OYP'Nf/ • f YYf~'lTLM JU{ PItJOlET 01 K (11 1 WYBTIH W W'f O11W 9CiZ (f~IBf10'~ 07@1!07 V M 06f11A4 UK A ! TAOlRlC (QlHMO>y 0 ~~ ~.: ,~~ POMMI N~:'~Y71M0 ARPM: '.Nf~O!l723~01 Nl~~k~a (AIMka) ~~~,. Date: February 6, 2009 To: File ;, From: Jane Williamson ; r; / Subject: PBU 18-26/~ Ii BP has requested approval to plug-back Prudhoe well 18-26~~ Ivishak Zone 1 for later CTD sidetrack targeting the Zone 1 A. The well is a cyclic producer, and when on, produces at a GOR exceeding 50 Mscf/STB. Less than 30 MSTB remains for this completion, and the new CTD should recover any remaining reserves. I recommend approval of this sundry request. ,>~~, Cll Rye (CD) (bti/d ) SOOD - Ges Rate (CD) (Mcf/d ) -Gas /Oil Ratio (MdA1tl ) _..._ V1L31er Cat (%) ~~ i 1000 II ~ ~ ~ 1 ~I II e 10D ~, ~, , ~ ~~ f 10 . ` , . 5~ I e 1 ----- -- --------- - -- ---- 19W 98 99 2000 01 02 03 04 06 O6 07 OB DATE 18264 300D N61drg Forecael Rarargas R~aee al Case Name Case1 • b 0 Di 0.364466 Ae 2400 qi 15352t1,1/d ti :17!31(1008 to :0631(1003 Firs Rafe 127.285bd/d ~ CunProd 946473Mbd a 1800. Curt Dale :0930'1006 a Reaa~es 21.1389Mt3i p - Reserves Date :0631/1009 U EUR 967.612 Mbtil m Forecast Ended By Rafe 1200 ~ DB Forecast Dale :Not Saved Reserve Type :None ~ .. . ~ ~ 0 ._ j~l 0 200 400 800 • 800 100D Cun Oil Rod Mbd RECEIVED - STATE OF ALASKA ') ALA~ lOlL AND GAS CONSERVATION COMI"v..,ðION JAN 2 4 2006 REPORT OF SUNDRY WELL OPERATIONSA'lIsk~ O;'~G . _. 1. Operations Abandon D Repair Well D Plug Perforations 0 Stimulate D Other OS COU~. CommissiOn Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension nL"horage Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development R'i Exploratory 0 197-1940 3. Address: P.O. Box 196612 Stratigraphic r: Service 6. API Number: Anchorage, AK 99519-6612 50-029-22329-01-00 7. KB Elevation (ft): 9. Well Name and Number: 8. Property Designation: 52 KB ADL-028307 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Surface Production Liner Liner Perforation depth: measured 12650 true vertical 8665.46 measured 12573 true vertical 8669.02 Length 80 71 3633 8906 2239 2108 Size 20" 91.5# H-40 13-3/8" 68# K-55 13-3/8" 72# L-80 9-5/8" 47# NT80S 7" 29# NT80S 2-3/8" 4.6# L-80 Measured depth: 11450 - 12571 True Vertical depth: 8690.18 - 8669.16 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 18-26A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) 8507 XX, 12265 CIBP Junk (measured) None feet feet MD 37 - 117 36 - 107 107 - 3740 32 - 8938 8649 - 10888 10528 - 12636 Closed Closed TVD 37 - 117 36 - 107 107 - 3651.89 32 - 8239.52 8046.84 - 8676.89 8657.31 - 8665.85 Burst 1490 3450 3450 6870 8160 Collapse 470 1950 1950 4760 7020 4-1/2" 12.6# 3-12/" 9.3# L-80 L-80 31 - 3125 3125 - 10628 4-1/2" Cameo TRDP-4A SSV 4-1/2" Baker SB3 Packer 7" Baker S Packer 2192 8549 8658 í\.í\V CZ '5! '¿nÜb RBDMS 8FII ~Çf\NNE1) J¡h~': ~r ('. .. . .. ~. .IAN ,2 5 2006 Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure SHUT-IN SHUT-IN 15. Well Class after Droposed work: Exploratory [" Development P' 16. Well Status after proposed work: Oil P' Gas r WAG r Tubing pressure 1350 1010 Service r WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal _ .~ . C::::-1 - - 1/_ _ -r-/ Signatu~~· (/,~ Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 1/23/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ) ') 18-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 12/26/2005 *** WELL SHUT IN ON ARRIVAL *** DRIFT W- 3.5 B.L.B, 2.70 CENT AND S.B TO 9945' SLM. STOPPED DUE TO DEV..81 DEG.( S.B. EMPTY) PULL PDS 24 ARM CALIPER FR. 9922' SLM TO SURFACE. SET 3 1/2 XX-PLUG (EO-SUB WI 12/64 PORTS) @ 8461' (SLM) CONFIRMED WI CHECK SET AND DIFFERENTIAL TEST SITP 1350 psi. *** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** FLUIDS PUMPED BBLS o o TOTAL 18-26A (PTD #1971940) Internal Waiver Cancellation - Trouble Well e e K~1 (2,( VI( ~ Suh.iect": 18-2()A (PTI) t? 1 (71940) Internal Waiver Cancellation - Trouhle Well From: "?\ISlJ, ADW Wclllntcgrity Engineer" <?\:SUADWWelllntcgrityEnginccr@BP.com> Dat{~: Fri, 16 Dec 2005 13 :42: 14 -0900 To: "AOGCC - \-Vinton Aubert (E-mail)..<wintol1_auhcI1@admin.statc.ak.us>. jim. rcgg@~.admin.state.ak.us, "NSU, AD\V Wcll Operations Supervisor" <NSUAD\V\VcIlOperationsSupervisor@BP.com>, "Rossberg, R Stcvcn" <RossbeRS@BP.com>, "GPß, FS líSIPiSTP Arca Mgr" <GPBFS I TL@ßP.com>, "Kurz, John" <john.kurz@)ßP.eom>, "GPR FSI DS Ops Lcad" <GPßFS I DSOpsI.cad~DBP.com> cc: "NSLJ, ADW Well Integrity Engineer" <~SLADWWclllntcgrityEnginccr@;~BP.com>, "'~SLJ, ADW WI Tcch" <l\iSlJ/\DW\VJTcch@BP.com>, "Schmoyer, AI" <SchmoyAL@BP.com>, "Mielke, Robert L." <robcrLmiclkc@BP.com>, "Julian, Jennifer '{" <JulianJY@BP.com> All, An internal waiver was issued for TxlA communication on well 18-26A (PTD #1971940) on 12/09/03. The well no longer meets waiver requirements and therefore the waiver is cancelled. The well is currently shut-in with plans to secure and evaluate the well for a rig sidetrack. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 c 1 of 1 12/21/20054:30 PM (' STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K) 4. Current Well Class: Stimulate D OtherO waiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-1940 Name: BP Exploration (Alaska), Inc. Development [!] Exploratory 0 Service 0 6. API Number 50-029-22329-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.00 8. Property Designation: ADL-0028307 11. Present Well Condition Summary: Total Depth Stratigraphic D 9. Well Name and Number: 18-26A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool measured 12650 feet 12265 Effective Depth true vertical 8665.5 feet None measured 12265 feet true vertical 8680.0 feet Casing Conductor Liner Liner Production Surface Surface Length 80 2239 2108 8906 71 3633 Plugs (measured) Junk (measured) Size 20" 91.5# H-40 7" 29# NT80S 2-3/8" 4.7# L-80 9-5/8" 47# NT80S 13-3/8" 68# K-55 13-3/8" 72# L-80 MD TVD Burst Collapse 37 - 117 37.0 - 117.0 1490 470 8649 - 10888 8046.8 - 8676.9 8160 7020 10528 - 12636 8657.3 - 8665.9 11200 11780 32 - 8938 32.0 - 8239.5 6870 4760 36 - 107 36.0 - 107.0 3450 1950 107 - 3740 107.0 - 3651.9 4930 2670 Perforation deDth: Measured depth: 11450 -11530,11610 -11710,11762 -11860,11885 -12250 True vertical depth: 8690.18 - 8690.7,8687.63 - 8684.05,8682.05 - 8683.93,8684.18 - 8679.16 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 31 3-1/2" 9.3# L-80 @ 3125 3125 10628 Packers & SSSV (type & measured depth): 4-1/2" Baker SB3 Packer 4-1/2" Camco TRDP-4A SSV 7" Baker S Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 29 0 2360 Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron .}1~ Ced&n.. Form 10-404 Revised 4/2004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Signature @ 8549 @ 2192 @ 8658 JUL 0 1 2004 Oil-Bbl 647 Tubing Pressure 1252 786 725 33.5 0 0 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil[!] GasD DevelopmentŒ) ServiceD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 ORfC';INAI Date 6/25/04 I :~\~t, (f'¡ \ 'I \-;)'[i8111. ,1\ \ "-" ( ( 18-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/07/04 ***WELL SHUT IN ON ARRIVAL***. DRIFTED TUBING WITH 10' X 1.875" DUMMY GUN. STOPPED DUE TO DEVIATION AT 9910' SLM. (TARGET DEPTH 10550').. ***LEFT WELL SHUT IN*** 05/09/04 TIO= 2400/2400N AC. WELL SI. BLEED WHpIS. (PREP FOR FB). INITIAL TBG FL @ 10,400' (112 BBLS). INITIAL IA FL @ 7175' (416 BBLS). OA FL @ 60' (5 BBLS). BLED IA FROM 2400 PSI TO 650 PSI IN 4 HRS. IA FL REMAINED THE SAME. IA BLEED SIIN DUE TO WELLHOUSE BEING REMOVED. FINAL WHplS 2400/650NAC. 05/10/04 T/I/O=2400/650/0 WELL KILL. BLED DOWN LA. TO 0 PSI. PUMPED 607 BBLS CRUDE DOWN LA. TO FLUID PACK. CONTINUED TO 5-11-04 05/11/04 CONTINUED FROM 5-10-04 WELL KILL, FOR PRE-CT COMPLETION, TCP. PUMPED 5 BBLS 50/50 METHANOL DOWN TUBING, 178 BBLS 1 % KCL, 20 BBLS FLO-PRO, 60 BBLS 1% KCL, 48 BBLS 50/50 METHANOL. FINAL TIO=400/0/20 05/13/04 CTU#9 & KLONDIKE #1: PERFORATING. «<CONTINUED FROM WSR 5/12/04»>. CONTINUE RU. TEST BOP'S. MU BAKER MHA W/1-11/16" PDS MEM GR/CCL. RIH TO 11,9001 AND LOG UP TO 11,380' WHILE LAYING IN FLO PRO. FLAG COIL AT 11,380'. CONTINUE LAYING IN FLO PRO WHILE COMPLETING LOGGING INTERVAL. LAY IN REMAINING FLO PRO AND PUH TO 9500' AND PERFORM NO FLO TEST, OK. POOH WHILE REPLACING VOIDAGE. CHECKED FOR FLOW AT SURFACE, WELL DEAD. LAY DOWN PDS TOOLS. MU 2801 PERFORATING BHA W/1.56" OD 6 SPF 1606 PJ PERFORATING GUNS AND RUH. PERFORATED 11450' TO 11530' MD AND 11610' TO 117101 MD (TIED IN TO PDS GR/CCL LOG DATED JUNE 19,1998). FLUIDS PUMPED BBLS 607 196 287 45 5 1140 Crude Methanal 1 % KCL Flo Pro Diesel TOTAL Page 1 TREE = 4-1/16" CM! W8..LHEAO = FMC AtrUA. TOR = AXELSON .. . . KB. ELEV = 52' " " BF. ELEV = NA .... . KOP = 2075 Max Ange = 96 @ 12440' Datum MD = " N/A Datum TVD = "8800' SS 14-112" lBG, 12.6#, L-BO, .0152 bpf,lD =3.958" H f \ 18-26A ( SAFETY NOTES: ***SLOW TxIACOMM.OPERATING LIMITS: MAX lAP = 2500 PSI, MAX OAP = 1000 PSI (12/09/03 WAIVER)*** OA NOT ARCTlC PACKED 02/16/93. WELL ANGLE> 70° @ 9500. & > 90° @ 11170.. 8 1 2192. H 4-1/2 CAMCO 1R0P-4A, 1RSSSV, ID= 3.812" I J r 2640' H ESTmpOFCBlAENT(12/OS/03) I " J 1 3125. H 4-1/2" X3-1/2"XO, ID= 2.99Z" GAS LIFT MANrRELS ST MD lVD DBI TYPE VLV LATCH FDRT DATE 1 3257 3207 20 MWG DOME RK 16 06/26/98 L 2 5497 5258 23 MWG SIO RK 20 06/26/98 3 7693 7267 26 MWG [N RK 0 02/16/93 4 8338 7811 31 MWG [N RK 0 02/16/93 5 8456 7903 38 MWG [N TGE 0 02/16/93 3124. 113-318" CSG, 72#, L-BO, ID = 12.347" H 3740. Minimum ID = 1.941" @ 10533' TOP OF 2-3/8" LNR ITOPOFTIWTlffiAO< SLV H 8649' 19-5/8" X 7' TW S PACKER H 8658' 19-5/8" CSG, 47#, NT-805, ID = 8.681" H 1 TOPOF2-3I8"LNR,ID= 1.941" l-t 1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-i 8~~ 1053~ 10616' 1 TOPOF 4-1/2" SL lD LNR, 12.6# 1-1 10841' 1 1 7" LNR, 29#, NT-805, ID = 6.184" 1-1 10888' 1 PffiFORA TION SUMMARY REF LOG: GR-CGL ON 06/19/98 ANGLEATTOPÆRF: 87 @ 11450' I\bte: Refer to Produetion DB for historieal perf data SIZE SIT IN1ERVAL Opn/Sqz DATE 1-11/16" 6 11450- 11530 0 05/13/04 1-11/16" 6 11610-11710 0 05/13/04 1-11/16" 4 11762-11860 0 06/20/98 1-11/16" 4 11885-12250 0 06/20/98 1-11/16" 4 12305 - 12571 C 10/10/00 I BTMOF4-1/2"SLTOLNR,12.6# H 1182T 1 I 4-112" LNR, 12.6#, NT-80, .0152 bpf,ID= 3.958" l-i 11853' I DA TE REV BY COMMß\JTS 02/16193 ORIGINAL COM PLETION 06/21198 CTD SIDETRACK (18-26A) 01/28/02 CI-VKAK CORRECTONS 09/13/03 Ctv1O/lLP OA TUM MD & PERF ANGLE 12/12/03 T JP/TLH W AIV ffi SA FETY NOTE 12120/03 PWEllLH OA CMf OWN SQZ (12/05/03) 8507' H 3-1/2" OllS X NIP, ID = 2.813" 1 8549' H 9-5/8" X 3-1/2" BKRSB-3 A<R, ID = 3.875" 1 8593' H 3-1/2" PARKffi SWN NP, ID = 2.750" I I MLLED TO 2.80" (04/12/98) 1 8663' 1-t 9-5/8" X 7' llW DTH-S I-k3R 1 ~ 1 10528' H 2.70" BKR DEPLOY rvENT SL V. ID = 1.969" 1 l-t 1--1 l-i l-i 10651' l-i 4-1/2" PORTED JOINT (37.98') (B8-fINDLNR) ~~ ~ ~ ~ 1 I r ~ ~ 1 I 10616' 10618' 10625' 10635' 3-112" X 4-112" XO (BEHND LNR) 1 4-1/2" TIW SEAL ASSY (BB-iINO LNR) I TIW FOLlSHED RlSffi {BEHND LNR} I 7" X 4-1/2"llW SS A<RASSY (BB-iIND LNR) 1 ! ~ ~ 4-1/2" LNR SIDEfRACK WINDOW 10898' - 10902' (OFF CMT PLUG) 112265'1-11.75" BKR CIBP (1 O/10/00) 8..M I 1 2-3/8" LNR, 4.6#, L-80, .0039 bpf, 10 = 1.941" 1-1 12636' 1 OA TE REV BY COMMENTS 02/04104 CMO/TLP PffiF INTERVAL CORRECllON 05/14/04 BJMeUKK ADPffiFS - - ~ ..,. ~ ~ X ~ X PRUDHOE BAY UNIT WELL: 18-26A PffiMrr I\b: 1971940 AA I\b: 50-029-22329-01 SEC 19, T11 N, R14E, 755' SNL &298' BNL BP Exploration (Alaska) ~s ~ II' WELL LOG TRANSMITTAL ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7'" Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 J q 7 ~ { q lot 1 8-26A 5/13/04 i ¡ s- )..8 Mech. CH 1 Caliper Survey Print Name: I '71 ' ./ ,I;h~. ()4d }~ ~l~~~ l\ \i\~ ~ Date: .J, trJ ""'- Å ~ (¡ "'I Signed: PI{oA(:fiVE Dil\(INO~Ji(: SERvi([~, INC, PO Box I ~69 SJAffORd TX 77477 Phone:(281) 565-9085 Fax:(181) 565-1369 E-mail: pds,g:'memorylog.com Website: w\n\.memol)'log.com . . r-... ~ " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair WellŒ Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197.1940 OtherD Name: BP Exploration (Alaska), Inc. Development ŒJ Stratigraphic 0 9. Well Name and Number: 18.26A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029.22329.01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519.6612 7. KB Elevation (ft): 52.00 8. Property Designation: ADL-0028307 11. Present Well Condition Summary: Total Depth measured 12650 feet true vertical 8665.5 feet Plugs (measured) 12265 Effective Depth measured 12265 feet Junk (measured) None true vertical 8680.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 117 37.0 - 117.0 1490 470 Liner 2239 7" 29# NT80S 8649 - 10888 8046.8 - 8676.9 8160 7020 Liner 2108 2-3/8" 4.7# L.80 10528 - 12636 8657.3 - 8665.9 11200 11780 Production 8906 9.5/8" 47# NT80S 32 - 8938 32.0 . 8239.5 6870 4760 Surface 71 13-3/8" 68# K-55 36 107 36.0 - 107.0 3450 1950 Surface 3633 13-3/8" 72# L-80 107 - 3740 107.0 - 3651.9 4930 2670 Perforation depth: Measured depth: 11762 -11860,11885 -12250 q~CEI\/(;..r",; I II-.. ~IV!knt True vertical depth: 8682.05 - 8683.93, 8684.18 - 8679.16 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 31 3125 3-1/2" 9.3# L-80 @ 3125 10628 Packers & SSSV (type & measured depth): 4-1/2" Baker SB3 Packer @ 8549 4.1/2" Cameo TRDP-4A SSV @ 2192 7" Baker S Packer @ 8658 MAR 1 5 200~ ^I~'.k;¡ G.1 ? G~~ C(!:L{, C!¡';;(~jiq¡on ¡\I1~hJr-;i1r: 13 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2640 - Treatment descriptions including volumes used and final pressure: 30 bbls ArcticSet Cement w/1/4 ppb Celloflake @ 480 psi Representative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 30.7 27 247 Prior to well operation: Subsequent to operation: Oil-Bbl 779 790 29.7 27 420 Tubing Pressure 972 1049 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 Oil 00 GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron SCANNeD Mm~ 1 6 2004 Printed Name Garry Catron Title )1~ ~"'" Production Technical Assistant Form 1 0-404 Revised 12/2003 0 RIG I N AT" 564-4657 18)IAS tll"L Dat-., tÓ2l~~n~ Signature f'. r'\ t 18-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/05/03 OA Cement Downsqueeze: Pump 10 bbls Meth, 25 bbls surfactant wash, 325 bbls fresh water, 15 bbls surfactant spacer, 5 bbls fresh water spacer, 30 bbls arcticset cement with 1/4 ppb celloflake, 34 bbls neat arctic set, 5 bbls fresh water spacer, 143 bbls crude displacement; 125 psi pressure increase seen in last 5 bbls of displacement @ 0.5 bpm. FW flush pumped at 3.8 bpm @ 1600 psi, majority of displacement at 6 bpm @ 1700 psi. Shut down with cement 5 bbls from shoe, monitor. Pressure dropped from 880 psi to 480 psi, slowly decreasing. Est TOC @ 2640'. Well left shut-in, LRS will MIT-OA in 3 days. 12/08/03 TIO=2150/420/0 MIT OA TO 3000 PSI. PASSED PUMPED 4.0 BBLS CRUDE. LOSS 20 PSI IN 1ST.15 MIN & 5 PSI IN 2ND 15 MIN, FOR A 25 PSI LOSS IN 30 MIN. PASSED ON FOURTH ATTEMPT, BLED DOWN OA TO STARTING PRESSURE. TIO=2150/420/0 FLUIDS PUMPED BBLS 10 480 50 147 687 Neat Methonal 80 deg F fresh water Cement Contaminant Crude TOTAL Page 1 , .' , TREE = 4-1/16" CIW W8.LHEAD = FMC ACTUð. TOR = AXELSON KB. B..EV = 52' BF. B..EV = NA KOP = 2075' Max Angie = 96 @ 12440' Datum MD = N/A DatumTVD = 8800' SS 14-112" TBG, 12.6#, L-80, .0152 bpf,lD =3.958" H 113-318" CSG, 72#, L-80, ID = 12.347" H Minimum ID = 1.941" @ 10533' TOP OF 2-3/8" LNR ITOPOFTIWTIEBAO< SLV H 19-518" X 7" TIN S PACKER H 19-5/8" CSG, 47#, Nr-805, ID = 8.681" H I TOPOF2-3I8"LNR, ID= 1.941" H I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H I'"'"'" r"\ 18-26A SAFETY NOTES: ***SLOW TxlA COMM. OPERAT~G' . LIMITS: MAX lAP = 2500 PSI, MAX OAP = 1000 PSI; (12/09/03 WAIVER)*** OA NOT ARCT1CPACKED . 02/16/93. WELLANGLE>70o @9500' & > 90o@ 1117 0' . 3124' J 3740' 8649' 8658' :8: h- ~ 8938' ~ 10533' I 10616' I r 8 - 1 TOPOF4-1/2"SLlDLNR,12.6# H 10841' 1 1 7" LNR, 29#, Nr-805, ID = 6.184" H 10888' 1 ... ÆRFORA TON SUMMARY REF LOG: GR-CGL ON 06119/98 ANGLE AT TOP PERF: 88 @ 10841' Note: Refer to Produetion DB for historieal perf data SIZE SPF INlERVAL Opn/Sqz DATE 1-11/16" 4 11762 - 11860 0 06/20/98 1-11/16" 4 11885-12250 0 06/20/98 1-11/16" 4 12305-12571 C 10/10/00 I BlMOF4-1/2"SLTDLt\R,12.6# H 11827 I I 4-1/2" LNR, 12.6#, NT-80, .0152 bpf, ID = 3.958" H 11853' DL\ TE 02/16/93 06£21/98 0112B¡Q2 09/13¡Q3 12/12¡Q3 12120¡Q3 COMMENTS ORIGINAL COM PLErION CTD SIDETRACK (18-26A) CI-VKAK CORRECTONS CMOfTLP DATUM MD& PERF ANGLE TJPITLH WArvfR SAFETY NOTE PWEJlLH OA CMf ONN SOl (12/05/03) RBI BY . 1 r ST MD lVD 1 3257 3207 2 5497 5258 3 7693 7267 4 8338 7811 5 8456 7903 2192' H 4-1/2CAMCO1RDP-4A,1RSSSV,ID=3.812"'1 2640' H B5TTOPOFCEMENr(12/05/03) I 3125' H 4-112" X 3-1/2" XO,ID = 2.992" I GAS LIFT MANDRB..S DBI TYPE VLV LATCH FQRr DATE 20 MM3 DOME RI< 16 06/26/98 23 MM3 SJO RI< 20 06/26/98' 26 MM3 rN RI< 0 02/16/93 31 MM3 rN RI< 0 02/16/93 38 MM3 rN TGE 0 02/16/93 ----1 8507' .2S. 8549' J 8593' ~ 8663' ~ 1 10528' I ~ I I 10616' H 10618' H 10625' H 10635' H 10651' H ~ ... ~ ~ X ~ X H 3-1/2" OTIS X NP,ID=2.813" 1 H 9-5/8"X3-1œBKRSB-3A<R,ID=3.875" I.: H 3-1/2" PARKfR SWN NP, ID = 2.750" I I MLLED TO 2.80" (04112/98) H 9-5/8" X 7" 1lW IJTH-S I-«3R 1 H 2.70" BKR DEPLOYtvENr SLV, ID = 1.96g' 1 3-1/2" X 4-1œ XO (BEHND Lf'R) 1 4-112" TIW SEAL ASSY (BB-IINJ LNR) 1 TIW FQLlSHED RlSfR (BEHND LNR) I 7" X 4-1/2"1lW SS A<RASSY (BB-IIND LNR) 1 4-1/2" PORTED JOINr (37.98') (BB-IIND Lf'R) I 4-112" LNR SIDETRACK WINDOW 10898' -10902' (OFF CMTPLUG) 1.75" BKR CIBP (10/10/00) B.M I I 2-3/8" LNR, 4.6#, L-BO, .0039bpf,ID= 1.941" H 12636' I DA lE REV BY COMtvENTS 02/04104 CMOITLP PfRF INlERVAL CORRECTION PRLOHOE BAY U'JIT WELL: 18-26A PfRMIf NJ: 1971940 AR NJ: 50-029-22329-01 SEC 19, T11 N, R14E, 755' SN... & 298' eNL BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M PL A T E W E IA L UNDER THIS. MARK E R C:LORI~IFILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X (ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 753' FNL, 4656' FEL, Sec. 19, T1 1N, R15E, UM At top of productive interval 2836' FNL, 2172' FEL, Sec. 13, T11N, R14E, UM At effective depth At total depth 1569' FNL, 4122' FEL, Sec. 13, T11N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 692051, 5961121) (asp's 689501, 5964255) (asp's 687518, 5965471) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-26A 9. Permit number / approval number 197-194 10. APl number 50-029-22329-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12650 feet Plugs (measured) 8665 feet Set CIBP (10/10/2000) @ 12265' MD. Effective depth: measured true vertical 12265 feet Junk (measured) 8680 feet Casing Length Conductor 1 1 O' Surface 3668' Intermediate 8886' Production 2239' Slotted Liner 251' Liner 2108' Size Cemented 20" 200# Coldset II 13-3/8" 1413 sx cs iii, 550 sx Class G, & 200 Sx CS II 9-5/8" 1025 Sx Class G 7" 355 Sx Class G unoemented in~lally, later 4-1/2" squeezed while running new liner 2-3/8" 9 bbls 15.8 ppg LARC Measured Depth True vertical Depth 110' 110' 3740' 3652' 8938' 8240' 10888' 8677' 1 O9O2' 8677' 12636' 8666' Perforation depth: measured 11762' - 11860'; 11885'- 12250'; (Isolated below ClBP 12305'- 12571'). true vertical 8682' - 8684'; 8684' - 8679'; (Isolated below ClBP 8682' - 8669'). Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 3127' MD; 3-1/2", 9.2#, L-80 Tbg @ 10618' MD; 4-1/2", 12.6#, L-80 Tbg @ 10898' MD. Packers & SSSV (type & measured depth) 9-5/8 X 3-1/2 BAKER SB-3 PACKER @ 8549' MD; 7 X 4-1/2 TIW SS PACKER ASSEMBLY (BEHIND LINER) @ 10635' MD. 4-1/2 CAMCO TRDP-4A, SSSV NIP ID=3.812" @ 2192' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 793 Subsequent to operation 579 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 20844 0 19534 18 Casing Pressure Tubing Pressure 1691 1495 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 · Title: DS 18 Surveillance Engineer K i L Prepared'by Paul Rauf 564-5799 SUBMIT IN DUPLICATE 18-26A DESCRIP'I'ION OF wORK coMPLE'fED SE'f clBP FOR GSO 1011012000: RIH & ran GR/CCL tie-in. Set o~BP @ 12265' MD for GSO to isolate the following perf intervals: 12305' - 125'71' MD (zone 1 B) 1012712000: TIFL passed. placed well BOL & obtained valid production data. RECEIVED NOV 0 '9 2000 AlaC, a Oil & Gas Cons. Commis~en Anchorage Page 1 Well Compliance Report File on Left side of folder 197-194-0 PRUDHOE BAY UNIT 18-26A 50- 029-22329-01 ARCO MD 12650 ~-~'TVD 08665 '~'Completion Date: ~6324~38 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8876 "/61// BH GR OH 12/1/98 12/3/98 · D 8877 (~ BH GR PB2 OH 12/1/98 12/3/98 L GRoMD 'F41qAL 11420-12665 OH 12/1/98 12/3/98 L GR-MD L GR-TVD L GR-TVD R EOW RPT. ffU ,/,.u% R EOW RPT ~NAL 11765-12190 PB2 (,.~AL 265-275 INAL 8633-8709 PB2 ~I4I 10766.70-12650. cfl3}qF-10766.70-12191. PB2 Daily Well OpsS¢~/~ Was the well cored? yes ~- OH 12/1/98 12/3/98 OH 2 12/1/98 12/3/98 OH 12/1/98 12/3/98 OH 9/10/98 9/1/98 OH 9/10/98 9/1/98 Are Dry Ditch Samples Required? yes/m~_,.And Received?~~___ Analysis Desc -- ' .es no ' Comments: Tuesday, May 30, 2000 Page I of l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG t Status of Well Classification of Service Well Oil_X Gas__ Suspended__ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-194 3 Address . . 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ? .................. 1~~ 50-029-22329-01 4 Location of well at surface i *~- '~ ~ ' ' ' ~ ~.,ui',ql-'j_~: ,..'..);~ ~. 9 Unif or Lease Name 755' SNL, 298' EWL, Sec 19, T11N, R15E, UM ! I~'ATF/ i '~ PRUDHOE BAY UNIT At Top Producing interval 10 Well Number ! V~fF!~ [ 18-26A At Total Depth .... i If 1 Field and Pool 1570' SNL, 4106' WEL, Sec 13, T11 N, R14E, UM. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 52' RKB ADL 28307 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 6/1/98 6/18/98 6/21/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12650' MD / 8665' TVD 12573.5' MD / 8669' 'I'VD YES_X NO__ 2192' MD 1900' (approx) 22 Type Electdc or Other Logs Run MWD & GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30" 2000# Coldset II 13-3/8" 68#/72# K55/L-80 36' 3470' 16" 1413 Sx CS III & 550 Sx Class G & 200 Sx CS II 9-5/8" 47# NT-80S 36' 8938' 12.25" 1025 Sx Class G 7" 29# NT-80S 8649' 10888' 8-1/2" 355 Sx Class G 4-1/2" 12.6# NT-80 10651' 10902' 6" (slotted liner) 2-3/8" 4.6# L-80 10528' 12636' 2-3/4" 9 bbls 15.8 ppg Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 3126' 8549' ,, 11762' - 11860' MD; 8682' - 8684' TVD; @ 4 spf. 3-1/2" Tbg 10618' 11885' - 12250' MD; 8684' - 8679' TVD; @ 4 spf. 4-1/2" 10628' 12305' - 12571' MD; 8682' - 8669' TVD; @ 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED L 27 PRODUCTION TEST U '"'--"' 'L~' i ;''~' /:'~"~ Date First Production Method of Operation (Flowing, gas lift, etc.) ~ ~\ i ~ · 6/27/98 Flowing Dateof Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER ~ BBL CHOKE SIZE I GOR 7/9/98 3.0 TEST PERIOD__I 6642 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER ~ BBL OIL GRAVITY - APl (corr) 1074 - 24 HOUR RATE _X 2917 19376 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved 10/16/97 (Permit # 97-194). RECEIVED AU¢ 1'1 1998 Alaska 0il & 8as Cons. Commissk,[ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Shublik Sadlerochit Top (other pics) GEOLOGIC MARKERS MEAS DEPTH 8847' 8918' 9009' 31 LIST OF ATTACHMENTS Summary of 18-26A CT Sidetrack Drilling Operations + Survey. TRUE VERT DEPTH FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. 8183' 8227' 8381' 32 1 hereby certify th~the foregoing is/t~'ue and correct to the best of my knowledge Erin Oba Engineering Supervisor Date INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. 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. 7-1-80 18-26A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 5/28198: MIRU CTU. PT'd BOPE. 5/29/98: RIH &tagged TOC @ 10995' MD. POOH. RIH w/BHA & underreamed cement from 10800' to 11274'. 5/30198: Reamed cement to 11308' MD & POOH w/BHA. RIH w/nozzle & pumped Biozan sweep to cleanout 4- 1/2" liner. Pumped 15.5 bbls of 17 ppg Neat Class G Cement into wellbore. Attained a max sqz press of 1200 psi & placed 3 bbls of cement behind pipe. Contaminated cement w/Biozan & jetted contaminated cement from the wellbore to 10800'. POOH w/500 psi on wellhead. WOC. 5/31/98: WOC. RIH & tagged TOC @ 10794'. Milled to 10899' & POOH. RIH w/BHA & tagged BTM. 6/01/98: Milled to 10908' through the 4-1/2" liner. POOH. RIH w/BHA & reamed window from 10902' to 10906'. Drilled into formation to 10925' & POOH. RIH w/BHA & performed LOT to EMW of 9.8 ppg. 6/02/98: Displaced well to FIo Pro. Drilled to 11076' & POOH. RIH to BTM & pumped 2 LCM pills. POOH. 6/03/98: RIH & squeezed LCM pill from 10950' - 9600' @ a max sqz press of 1500 psi. POOH. RIH & drilled to 11190' MD w/severe fluid losses. Switched to KCI Water & circulated mud from the hole. 6/04/98: Drilled from 11190' - 11533' w/periodic FIo Pro sweeps every 60'. POOH. RIH w/nozzle. Squeezed LCM pill from 11150' to 10150'. Bullheaded 2nd LCM pill @ 10900'. 6/05/98: POOH. PT BOPE. RIH w/BHA & washed out LCM in wellbore from 10900' to 11533'. Experienced MWD noise interference. Drilled to 11680' & became stuck. 6/06/98: Freed stuck pipe w/Crude & POOH. RIH several times w/MWD signal problems. 6/07/98: RIH & reamed from 11530' - 11570'. Tagged BTM @ 11700' & backreamed to 11300'. Swapped to new FIo Pro & drilled to 11868' w/loss of MWD signal. POOH. 6/08/98: RIH &drilled ahead to 11888'. POOH. Abandoned 11755' - 11888' segment. RIH & cut a trough, from 11755' to 11765'. Drilled OH sidetrack to 11832'. 6/09/98: Drilled OH sidetrack to 11980' MD. 6/10/98: Drilled OH ST to 12190'. Reamed shaley intervals. Page 1 18-26A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 6/11/98: Backreamed OH sidetrack interval but kept venturing into the abandoned segment. Unable to get into OH sidetrack. Pumped 5 bbls of Neat Class G Cement plug from 11750' to 11000' MD & jetted out cement to 11400', Abandoned both segments w/plug. Laid in LCM pill & POOH. RD. 6/12/98: Performed CTU maintenance. 6/13/98: RU CTU & PT'd BOPE. RIH &tagged TOC @ 11419'. POOH. 6/14/98: RIH w/BHA & drilled cement to 11626 (attempted sidetrack). POOH. 11646' MD. Slowly drilled sidetrack to 11659'. RIH & drilled trough from 11636' to 6/15/98: Drilled to 11966' while circulating new mud. High circulation losses, 6/16/98: Drilled to 12355' w/several shod trips to TT. POOH w/BHA. 6/17/98: RIH & backreamed shaley intervals from BTM to 11680'. Drilled ahead to 12639 MD'. 8/18/98: Drilled to TD @ 12650'. RIH to BTM & spotted new FIo Pro. POOH. RIH w/the 2-3/8" liner. 6/19/98: Landed liner @ 12636'. Cemented liner in place w/9 bbls of 15.8# Neat Class G Cement w/TOC estimated to be @ 10525' (in 2-3/8" X 4-1/2" annulus). Unstung from flapper valve & cleaned out liner w/ Biozan. POOH w/displacing well to KCL Water. POOH while laying in clean FIo Pro across horizontal section. WOC. 6~20~98: Did CTU maintenance. PT'd liner lap. RIH w/perforating guns & tagged flapper valve @ 12573.5' MD. 6/21/98: Shot initial perforations @: 11762' - 11860' MD (Z1) 11885'- 12250' MD (Z1) 12305'- 12571' MD (Z1) Used 1-11/16' carriers & shot all perfs at 4 SPF. POOH w/perf guns and noted all shots fired. Circulate well to Crude. RDMOL. Placed the well on initial production w/gas lift & obtained a valid well test. Page 2 RECEIVED ORI6INAL ~S '~ c r ' mis' n · ~~~0 ~LASKA, Inc Well: 1 8-26A APl 500292232901 18-26APB2 APl 500292232971 Prudhoe Bay North Slope, Alaska Rig: Nabors 3s DIS Unit #4 End of Well Survey Report Provided in: True - Grid - ASP BHI Rep: Dwain YoUng Job Number: 98330 AFE Number: AP1254 Reviewed by: Date: EOW Survey Calculations ,> Coordinates provided in: TRUE and GRID relative to Wellhead ORIGINAL Company: ARCO Alaska, Inc. Rig: Nabors 3s/DS CTU #4 Job No: 98330 Well: 18-26A Location: Prudhoe Bay~ Alaska AFE No: AP1254 Calculation Method: Minimum Curvature Mag. Declination: 28.350 BHI Rep: Philip Marwood Vertical Sect. Plane: 282.790 GRID Grid Correction: 1.460 Job Start Date: 31-May-98 Vertical Sect. Plane: 284.250 TRUE Total Correction: 26.890 Job End Date: 17-Jun-98 Measured Depth from: RKB DLS (°/100 ft): 100.00 True Vertical Depth from: Sea level Meas. Incl. TRUE Subsea Coords. - TRUE Coords. - ASP GRID Coords. - GRID Dogleg Vertical Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) Section Comments (deg) (deg) (ft) Lat. (Y) Dep. (X) l~at. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) (Deg/100ft) (from liP) 10766.70 86.28 329.38 8620.20 3734.70 -2815.80 5964782.50 689140.3{) 327.92 3661.80 -2910.38 0.00 0.00 Tie in Position 10900.00 89.65 327.25 8624.93 3848.04 -2885.76 5964894.02 689067.48 325.79 3773.32 -2983.20 3.00 95.70 Kick off Point 11055.00 88.08 310.00 8628.03 3963.89 -2987.80 5965007.23 688962.52 308.54 3886.53 -3088.16 11.20 223.10 11081.70 88.46 306.00 8628.83 3980.31 -3008.82 5965023.12 688941.08 304.54 3902.42 -3109.60 ! 5.00 247.50 11111.70 88.25 302.00 8629.69 3997.08 -3033.68 5965039.24 688915.81 300.54 3918.54 -3134.87 13.30 275.80 11170.40 90.00 291.70 8630.59 4023.55 -3085.97 5965064.37 688862.86 290.24 3943.67 -3187.82 17.80 332.90 11231.80 89.60 286.10 8630.81 4043.43 -3144.04 5965082.77 688804.30 284.64 3962.07 -3246.38 9.10 394.10 11291.80 88.90 280.20 8631.59 4057.07 -3202.43 5965094.92 688745.58 278.74 3974.22 -3305.10 9.90 454. i 0 11350.40 88.10 273.20 8633.13 4063.90 -3260.58 5965100.27 688687.28 271.74 3979.57 -3363.40 12.00 512.10 11412.40 86.30 265.80 8636.16 4063.37 -3322.46 5965098.15 688625.44 264.34 3977.45 -3425.24 12.30 571.90 11480.00 88.90 258.00 8639.00 4053.86 -3389.26 5965086.94 688558.89 256.54 3966.24 -3491.79 12.10 634.40 11513.00 90.90 255.90 8639.06' 4046.40 -3421.41 5965071S.67 688526.95 254.44 3957.97 -3523.73 8.80 663.70 11540.00 92.40 254.90 8638.28 4039.60 -3447.52 5965071.21 088501.0 253.44 3950.51 -3549.67 6.70' 687.30 11612.00 92.00 263.10 8635.51 4025.89 -3518.09 5965055.70 688430.82 261.64 3935.00 -3619.86 11.40 752.40 11655.00 92.20 266.00 8633.93 4021.81 -3560.86 5965050.53 688388.17 264.54 3929.83 -3662.51 6.80 792.80 11696.00 91.80 270.30 8632.50 4020.48 -3601.81 5965048.16 688347.27' 268.84 3927.46 -3703.41 10.50 832.20 11725.00 92.80 274.90 8631.34 4021.80 -3630.74 5965048.74 68831 ~.31 273.44 3928.04 -3732.37 16.20 860.50 11776.00 90.80 283.40 8629.73 4029.90 -3681.02 5965055.56 (,88267.S4 281.94 3934.86 -3782.84 17.10 911.30 11816.00 87.10 291.10 8630.47 4041.74 -3719.18 5965066.43 68~229.39 289.64 3945.73 -3821.29 21.40 951.20 ~'~ ~ i ~ ! ~][ 11840.00 88.30 294.10 8631.43 4050.96 -3741.32 5965075.07 688207.03 292.64 3954.37 -3843.65 13.50 974.90 ~ [ ~ [ ~ ] [ 11872.00 89.60 301.60 8632.02 4065.89 -3769.58 5%5089.29 688178.39 300.14 3968.59 -3872.29 23.80 1006.00 11915.00 88.90 306.60 8632.58 4089.99 -3805.18 5965112.47 b88142.19 305.14 3991.77 -3908.49 11.70 1046.40 11947.00 91.80 313.00 8632.38 4110.46 -3829.75 5965132.3 68~117. I I 311.54 4011.61 -3933.57 22.00 1075.20 12020.00 92.30 323.90 8629.77 4164.98 -3878.06 5965IS5.57 bBS067.42 322.44 4064.87 -3983.26 14.90 1135.50 12037.00 90.90 324.20 8629.29 4178.73 -3888.04 5965199.07 688057.10 322.74 4078.37 -3993.58 8.40 1148.50 12069.00 88.40 325.30 8629.49' 4204.86 -3906.50 5965224.72 688037.97 323.84 4104.02 -4012.71 8.50 1172.90 12111.00 90.90 320.40 8629.74 4238.32 -3931.86 5965257.52 688011.77 318.94 4136.82 -4038.91 13.10 1205.70 12130.00 93.50 317.50 8629.01 4252.64 -3944.32 5965271.52 68799~.95 316.04 4150.82 -4051.73 20.50 ! 22 ! .30 12209.00 90.90 311.40 8625.98 4307.89 -4000.65 5965325.31 687941.23' 309.94' 4204.61 -4109.45 8.40 1289.50 12232.00 87.60 310.40 8626.28 4322.94 -4018.03 5965339.92 687923.47 308.94 4219.22 -4127.21 15.00 1310.00 Meas. Incl. TRUE Subsea Coords. - TRUE Coords. - ASP GRID Coords. - GRID Dogleg Vertical Depth Angle Azi. TVD N(+~S(-) E(+)/W(-) N(+~S(-) E(+)/W(-) Azi. N(+~S(-) E(+)/W(-) Section Comments (deg) (deg) (~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (de~) Lat. (Y) Dep. (X) (DeE/IO0t~) /from TIPI 12287.00 86.20 304.40 8629.26 4356.29 -4061.64 5965372.14 687879.03 302.94' 4251.44 -4171.65 11.20 1360.50 12320.00 87.20 299.30 8631.16 4373.66 -4089.61 5965388.80 687850.62 297.84 4268.10 -4200.06 15.70 1391.90 12345.00 89.30 296.90 8631.92 4385.43 -4111.65 5965400.00 687828.29 295.44 4279.30 -4222.39 12.80 1416.20 12395.00 92.20 292.00 8631.27 4406.12 -4157.14 5965419.52 687782.28 290.54 4298.82 -4268.40 11.40 1465.30 12440.00 95.60 288.50 8628.20 4421.65 -4199.25 5965433.98 687739.79 287.04 4313.28 -4310.89 10.80 1510.00 12523.00 94.70 282.00 8620.75 4443.38 -4278.96 5965453.67 687659.56 280.54 4332.97 -4391.12 7.90 1592.60 12578.00 93.90 279.90 8616.62 4453.80 -4332.81 5965462.71 687605.47 278.44 4342.01 -4445.21 4.10 1647.30 12625.00 92.10 276.80 8614.16 4460.61 -4379.24 5965468.34 687558.88 275.34 4347.64 -4491.80 7.60 1694.00 12650.00 91.40 275.15 8613.40 4463.21 -4404.09 5965470.31 687533.97 273.69 4349.61 -4516.71 7.20 1718.70 T.D. Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth from: Meas. Incl. Depth Angle (deg) 10766.70 86.28 10900.00 89.65 11055.00 88.08 11081.70 88.46 11111.70 88.25 11171.70 90.14 11201.80 90.75 11231.80 89.65 11261.70 89.01 11291.80 89.04 11321.70 88.49 11351.70 88.08 11381.90 87.26 11411.90 86.37 11441.90 86.92 11481.80 89.25 11511.80 91.20 11542.70 91.89 11572.70 91.50 11601.80 91.89 11631.80 92.30 11672.90 89.97 11735.00 90.10 11765.00 91.80 11789.00 90.30 11803.00 89.90 11840.00 89.90 11879.00 91.30 11921.0( 92.50 11974.00 81.90 ARCO Alaska, Inc. 18-26APB2 Minimum Curvature 282.79{I GRID 284.250 TRUE RKB Sea level EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ORIGINAL Rig: Nabors 3s/DS CTU #4 Job No: Location: Prudhoe Bay~ Alaska AFE No: Mag. Declination: 28.35{) BHI Rep: Grid Correction: 1.460 Job Start Date: Total Correction: 26.890 Job End Date: DLS (°/100 ft): 98330 AP1254 Philip Marwood 31-May-98 17-Jun-98 100.00 Subsea TVD fit) 8620.20 8624.93 8628.81 8629.67 8630.51 8630.28 8630.18 8630.53 8631.04 8631.68 8632.58 8633.81 8635.48 8637.23 8638.45 8637.62 8636.73 8635.87 8634.77 8633.96 8633.92 8633.42 8632.98 8632.96 8633.02 8632.61 Coords.-TRUE N(+)/S(-) E(+)/W(-) Lat.(Y) Dep.(X) 3734.70 -2815.80 3848.04 -2885.76 3978.04 -2970.10 4000.25 -2984.89 5965043.66 688964.50 4025.00 -3001.83 5965067.96 688946.93 4072.24 -3038.75 5965114.25 688908.83 4094.63 -3058.87 5965136.12 688888.14 4116.06 -3079.85 5965157.01 688866.62 4136.12 -3102.02 5965176.50 688843.95 4155.04 -3125.42 5965194.81 688820.07 4172.46 -3149.71 5965211.61 688795.35 4188.45 -3175.06 5965226.95 688769.59 4202.83 -3201.59 5965240.65 688742.71 4214.98 -3228.95 5965252.10 688715.04 4225.13 -3257.13 5965261.52 688686.62 4235.81 -3295.53 5965271.23 688647.96 4241.93 -3324.90 4247.94 -3355.19 4255.74 -3384.13 4265.11 -3411.67 4276.17 -3439.52 4294.28 -3476.40 4328.42 -3528.18 4347.40 -3551.40 4362.40 -3570.13 4370.77 -3581.35 4390.52 -3612.60 4406.82 -3648.00 Coords. - ASP GRID N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) Lat. (Y) Dep. (X) Lat. (Y) 5964782.50 689140.30 327.92 3661.80 5964894.02 689067.4-8 325.79 3773.32 5965021.83 688979.85 325.34 3901.13 324.44 3922.96 323.84 3947.26 317.24 3993.55 315.94 4015.42 312.34 4036.31 309.04 4055.80 305.94 4074.11 302.44 4090.91 299.14 4106.25 Coords.-GRID Dogleg E(+)/W(-) Dep. (X) (Deg/100ft) -2910.38 0.00 -2983.20 3.00 -3070.83 1.10 -3086.18 3.70 -3103.75 2.10 -3141.85 11.40 -3162.54 4.80 -3184.06 12.50 -3206.73 11.2( -3230.61 10.30 -3255.33 11.80 -3281.09 11.10 294.84 4119.95 -3307.97 290.14 4131.40 -3335.64 286.54 4140.82 -3364.06 281.64 4150.53 -3402.72 5965276.59 688618.45 278.98 4155.89 5965281.83 688588.01 280.54 4161.13 5965288.89 688558.88 286.72 4168.19 5965297.56 68~531.11 287.95 4176.86 5965307.91 688502.98 292.44 4187.21 5965325.07 688465.66 296.94 4204.37 5965357.88 688413.03 306.94 4237.18 5965376.26 688389.33 308.64 4255.56 5965390.78 688370.22 305.84 4270.08 5965398.85 688358.79 304.64 4278.15 5965417.81 ~ - . . 68~7.(D 297.04 4297.11 5965433.20 688291.25 289.49 4312.50 688250.58 278.54 688197.99 272.54 8631.21 4418.01 -3688.39 5965443.35 8633.80 4424.46 -3740.83 5965448.46 -3432.23 Vertical Section (from TIP) 0.00 95.70 209.50 229.20 251.80 299.10 324.10 349.80 376.30 403.50 431.40 459.90 14.50 489.10 15.90 518.70 12.10 548.40 13.60 588.30 11.00 618.30 -3462.67 5.50 649.20 -3491.80 20.60 679.10 -3519.57 4.40 708.00 -3547.70 15.00 737.80 -3585.02 12.30 778.00 -3637.65 16.10 836.60 -3661.35 8.00 863.80 -3680.46 13.20 885.60 -3691.89 9.00 898.60 -3723.63 20.50 933.70 -3759.43 19.70 972.00 4322.65 -3800.10 4327.76 -3852.69 26.20 1013.90 23.00 1066.40 Comments Tie in Position Kick off Point Meas. Incl. TRUE Subsea Coords. - TRUE Coords. - ASP GRID Coords. - GRID Dogleg Vertical Depth Ang~ Azi. TVD N(+VS(-) E(+)/W(-) N(+VS(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) Section Comments (deg) (de~) (~) Lat. (Y) Dep. (X) LaL (Y) Dep. (X) (de~) Lat. (Y) Dep. (X) (De~/100ft) /from TIP) 12003.00 78.00 270.00 8638.86 4425.46 -3769.36 5965448.74 688169.45 268.54 4328.04 -3881.23 19.10 1094.30 12024.00 74.40 269.00 8643.87 4425.28 -3789.75 5965448.04 688149.07 267.54 4327.34 -3901.61 17.80 1114.00 12058.00 67.80 267.00 8654.88 4424.17 -3821.88 5965446.11 688116.98 265.54 4325.41 -3933.70 20.20 1144.80 12072.00 66.90 266.00 8660.27 4423.38 -3834.77 5965445.00 688104.11 264.54 4324.30 -3946.57 9.20 1157.10 12113.00 65.20 262.00 8676.92 4419.48 -3872.03 596544().14 688066.97 260.54 4319.44 -3983.71 9.80 1192.30 12158.00 65.40 258.00 8695.73 4412.38 -3912.28 5965432.02 688026.91 256.54 4311.32 -4023.77 8.10 1229.60 12191.00 65.55 255.07 8709.43 4405.39 -3941.47 5965424.29 687997.91 253.61 4303.59 -4052.77 8.10 1256.10 T.D. ARCO Alaska Inc. AOGCC, Lori Taylor Well Reference Data: Well No: 18-26A PB2 Field: Prudhoe Bay County: North Slope State: Alaska Date: December 1, 1998 API No: 500292232972 BHI Job #: 98330 Enclosed is the following data as listed below: Log Type Bluelines Navig~m~a BDEN MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~a BDEN MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tapes LIS Verification Listings Upon Receipt, Please sign and fax to: Rec~ Baker Hu=hes IHTEQ Fax~~.0~!~'~2 Attn: Raquel Olsbo DEC 05 1998 ARCO Alaska Inc. AOGCC, Lori Taylor Well Reference Data: Well No: 18-26A Field: Prudhoe Bay County: North Slope State: Alaska Date: December 1, 1998 API No: 500292232901 BHI Job #: 98330 Enclosed is the following data as listed below: Log Type Bluelines Navig~mma BDEN MDL/MNP DPR/MDL/MDP 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film TOTALS: Log Type Navig~mma BDEN MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tapes LIS Verification Listings Up__se sign and fax to: B~.~~~~) ~EQ Attn: _R.aque.~^O1 sbo DEC 0 lvw TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1997 Erin M. Oba Engineering Supervisor ARCO Alaska. Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re.' Prudhoe Bav Unit 18-26A ARCO Alaska. Inc. Permit No. 97-194 Sur. Loc: 755'SNL, 298'EWL. Sec. 19, T11N, R15E, UM Btmhole Loc: 1892'FNL, 4134'FEL, Sec. 13, TllN, R14E, UM Dear .'.'vis Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may,,b~gg~y contacting the Commission petroleum field inspector on the North · David W. Joh~on ~ Chairman ~ ,~ BY ORDER OF THE COMMISSION dlffenclosurcs Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation xv/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL " &AC 25.005 la. Type of Work Drill_ Reddll X i lb. Type of Well Exploratory__ Stratigraphic Test_ Development Oil X Re-Entry __ Deepen _ ! Service _ Development Gas _ Single Zone ~ Multiple Zone 2. Name of Operator [ 5.Datum Elevation (DF or KB) I 10. Field and Pool ARCO Alaska, Inc. I RKB 52' 3. Address I 6. Property Designation I P.O. Box 100360I I Prudhoe Bay Field 14` Anchorage, AK 99510-0360 ! ADL 28307 Prudhoe Bay Oil Pool Location of well at surface I 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 755' SNL, 298' EWL, Sec 19, T11N, R15E, UM. I Prudhoe Bay Unit ~ Statewide ! 8. Well number i Number At top of productive interval 1595' NSL, 1564' WEL, Sec 13, T11N, R14E, UM. I 18-26A/ #U-630610 At total depth 9. Approximate spud date I Amount , (Proposed) 1892' FNL, 4134' FEL, Sec 13, T11N, R14E, UM. i October 22, 1997 I $200,000 12. Distance to nearest i t3. Distance to nearest well i 14. Number of acres in property 15. Proposed depth (MD and TVD) -property line I NO Close Approach I ! 12700' MD / 8707' TVD 16. To be completed for deviated wells I 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10930' MD Maximum hole angle 92° I Maximum surface 2800 psig At total depth (TVD) 8707' Setting Depth t8. Casing program I I Quantit~ of cement Size ! S ecification _ _. {.._ To ...... Bottom ~ ~ IGrade ~ lin 'Len~_, Lv,,~,,, ,.v,..~ .... TVD1- ~.6 iL-80 FL4S I 8707' 4 bbls .19. To be'completed for Redrill, Re-entry, and Deepen Operations. ' Present well condition summary "' Total depth: measured 11853 feet Plugs(measured) A[2~$k~. true vertical 8682 feet Effective depth: measured 11853 feet Junk (measured) true vertical 8682 feet Casing Length Size Cemented Measured depth True Vedical depth Conductor 11 O' 20" 2000 Sx Coldset II 110' 11 O' Surface 3704' 13-3/8" 1413 Sx CS III, 400 Sx Cl G, & 3740' 3652' 200 Sx CS II Production 8897' 9-5/8" 1025 Sx Class G 8933' 8234' Liner 2219' 7" 355 Sx Class G 10886' 8675' Slotted Liner 1202' 4-1/2" Uncemented 11853' 8682' Perforation depth: measured Slotted Liner interval (not squeezed): 11235 - 11827' true vedical Slotted Liner interval (not squeezed): 8689 - 8681' 20. Attachments Filing fee X__ Property plat _ BOP Sketch x Diverter Sketch _ Drilling program x Drilling fluid program __ Time vs depth plot _ Refraction analysis ~ Seabed report 20 AAC 25.050 requirements 21. I hereby cedify that the foregoing is true and correct to the best °f my kn'°wledge ~,~,o(~%1'~'c,~5 ~ C¢~-~\ 5~~/~ ~ ~ Title En~ervisor Date Commission Use Only Permit Number . . i APinumbe. z, ' Approvaldate [4[ [O[,-,~ See cover letter for ~.7 ' '//~ ~ I 50- ~,,~ ~' -- ~ ~ '~ '~ ? - 4:3 / ~ other requirements Conditi~)ns of approval'Samples required Yes z~'No ' Mud Icg required-- _ Yes ~'No Hydrogen sulfide measures -- Yes .~ No Directional survey required ,~ Yes _ No Required working pressure for BOPE ~ 2M; _ 3M; _ 5M; _ 10M; _ 15M X_~si for CTU Other:Original Signeo % David W. J0hnstor,by order of Approved by Commissioner the commission Date n~t?~lioate DS 18-26A CT Extension and Completion Intended Procedure Objective: Directionally drill -1900', 2-3/4" horizontal hole fi'om Complete with 2-3/8" cemented liner. the existing wellbore. Intended Procedure: Cement squeeze the current slotted liner and plugback the existing completion to - 10800' md. Mill window in 4-1/2" liner at -10930' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -90°. Directionally drill 2-3/4" x 1900' horizontal well to access Lower Romeo reserves. · Run and cement 2-3/8" liner to TD. · Perforate selected intervals. ° Place well on production. September 30, 1997 4-1/2" Tubing to 2978' 4-1/2" Camco TRDP- 4A SSSV @ 2192' DS 18-26A PROPOSED CT ST AND COMPLETION TD @ ~ 1~700' Initial perforations 3-1/2" Production Tubing 2-3/8" Cmt'd liner 3-1/2" X Nipple@ 8593' 9-5/8" SB Pckr. @ 8549' 3-1/2" SWN Nipple@ 8593' 2.75" hole Window cut in 4.5" liner and cmt in 6" annulus @ 10930' 10635' MD TIW SSHS Pkr. 0888' MD 7" Liner shoe 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 11853' MD End of 4-1/2" liner & 6" OH 4-1/2" Slotted Liner 928'( shoe at 11853') .A DRIL _EX ! ARCO ALASKA II~C,. t , ALASKA ~ I ~tRCC, ALASt4. A INC. "Ye'tical ~ectioq ~,cale I inch · --.-r-: % I~ PLANE CF VERT SECT...-.. 288.97- R.-,.2LA./~ ,.,E TC, TRUE NORTH 18.26AT 182~60R T .R. f8-26 A ;4 F5 ,,- ,]') 46OO .. 44O0 .., .. -. ~20D --. '- · . .. ' \ MD ~rm. Orr $$ DI~PTH ft d~ ~g ~ v$ ft &5.37 E',2S ~2 5 e23 a: 2.5,3 ~? ' 5 .:.28 E..3 ~ {522.' '.- C 2~c 4,2, &'"'q7? ?.27 .-34 562¢.3C 7' 80 :~. ': 3".. :-. 1' 1L3.0~ ,E~ 3,1~ ~ 5.625 2G 2~1.60 4,C03.C,0 1' 1[C,.-3:, S,~."..9 3'.-~. -:'7 6{~256[I 317.60 4:,~630 1'. 1~.32 .88.CG 3~7 ~ ~ 626 CO .'M3.60 1' 22C..T 8~..$? ~!~.~ 55..'~,60 36690 4,'~390 1~-.2."£.::k.~. 8,&?=- ~15.~.. _~G~7 20 3~5C 4.'2260 1' .,,,.,>...'"'"'"' 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T~e in 6Ft.:~ 135 O~ 1.".2 ~.G,9 1.35 2,"1 65~ 38g ?~ 6~' :::)-36. 33 ~ 05G 23 ~ ~ .:iD 2. XO~ 3.4'/1~0 131...~l' ftc 588927 686, 98g.~-~ ~8.~85 70 ~8..~4.40 688.822 ~ 6~ 792 ~ $. Tgt. I rll~ dl ~' 'TI'e $95 ..-'55 3~ 6~.~ 73~ 30 ~ ?~5 9D 6r:~ 6'3~ 33 ~ 6~E, -30 A MI:) ~n¢. !~ ~,5 13E~TH It d~l deg It '?.C,..3~ ...~. 57.96 290 53 5 §$' ~ '~..' ~.f.C 3~ ~: ~ 25,3 93, 6 635 80 I, 2. ~C 3~ ~7 ~4 2~-5 53 ~ 636 90 IZ240.33 8: ~ 2:372 12.270.33 ~q7 _.6-7 2~1 32 12 3' 6 ~-D fl6 CC, 237 ~ 6 6~:'. ?0 1~.3~3 8; ~ 23B7'3 56.t2 20 12.3L~, 93 ii7.9;: 2:1 13 12 ~20 83 8;' ~ 2~5,~ 125'0~3 ~;~ 255;~ 125~3 ~7~ 2555' IZ~.33 ~;~ 2~3' ~55~ 80 12.9L~..~ 33 12.9'~1 5.3 36 c2 2,E;? 5' .".-'~',6 2, ,.9.5, 6-2 25? ~. VBI~"ICAL SECTION U3ED NOTE GRID CONVERGENCE :. MAGNETIC DECUNATION GUI~:ACE X ~URFAGE Y V$ N/~! E,'-W O~iW Turn tt fl it ~e,~,,lOI 4a~10~ da~'lO0 ~, '--~-5. }i~ 5[' f.96~. ~3 5E* f.995,~. 5~, 1.084:0 4 ~ .'-c .3.746.46 -8 03 C.L~C, ~ 3-;3 1.C~.00 4 36;3 ~ -3.,:5D.¢C, -0 10 -a.,~ 5 O0 1.11~20 43~2 -3.779.9D ~, 10 1.141.~ 43565,: -3..~6 5C .0 19 -,9 .',.32 6-3'3 1,167.,~ 4351 ~ .3,~3.q00 0'.33 -,a.~ 5.9(~. 3,r',8 33 ~.98'5,378 52 '~,'965,372 5?.: .329.~ 4 2;8.~ -:.035. ~C C ~ .a ~ 5 33 :~S.~' 4. 2~.~ -:.061 1C C' 10 ~.~ 6 1.~.C~ 1.2~.33 -z,075.1C .3e~.~ 4 247 1,3a8.20 34g8.~ z52.~, 4~4~ -4 ~93 .475 70 4. ~H3.~ ~gg.~, 4, 52~ ~' 4,~.4fl 4 279 ~ ~ 6 ~O ~.-~ 549 7Q 4, 57570 802 ~' 4, '..3.~3 56 .' 1z.4 39 -4 428 .,'0 0 13 9.30 5 985.. 150 5D 5 9~5..150 5D .z,a? ,; A~IP X ft 6~S 279 ,cC 6.68.2a9 ,?~C- 6SS 239 18 4. ~ 8'/10~' ~ ~ Inc. 193 ~ ~. ~'rlO0' .~1' for .3~1)' ng&l§O 60 ~131 C~ 131 7~ 6_%8 -372 76- ~ 34,,r. ,CC ~ 315 70 r:~.7 98;.' I~ S8,7 963 5.G ~7 ~33 70 S8,? 9074.3 687...~,~ 9.3 ~7. ~. 13 ~. 8'11~' 91~ ~ ~ ~. ~7. ~, 93 ~7, ~6. ~0 ~7,75t~ ~7,723. b3 667,578 ~: 687 516 ~ C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over .Hydraulic 7-1/16" I D with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus Tanks 6O/40I I TrplxI t--~re Ext. Shop Fuel Boilers Water Pump Fire Ext. I-ire Ext. Pipe rack Dowell Drilling J Equipment TraiJer Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY WELL NAME /?,~/-?/,,,/0~-2~/~ PROGRAM: exp [] dev~redrl'~serv [] wellbore seg [] ann. disposal para req [] FIELD & POOL ~ C/C3 ,/D",'C) INIT CLASS .,,~,,' /'- ~,~//) GEOL AREA ~-? ~ UNIT# //~'..../"~ ON/OFF SHORE C~ ~ ADMINISTRATION 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING APPR 14. Conductor string provided ................... Y N '") 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... ~NNN 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ~-'~,t~.~ .)~t~ptP--¢<¢" - 22. Adequate wellbore separation proposed ............. N ' ~/ 23. If diverter required, does it meet regulations .......... ""~i ,D,~. 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~5-O 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 ................. YC~ N GEOLOGY _PR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ '///-'"/" YY N // /~/~-'~ 31. Data presented on potential overpressure zones ....... ,. 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. N 34. Contact name/phone for we,eklyprogress reports ...... /'" Y N lexplora~ory only] REMARKS GEOLOGY: ENGINEERING' COMMgSSJ ON' r c.4 d, ,47 -- JDH ~ RNC~ CO 6,0 Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97
