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193-047
1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 193-047 4/10/1993 4/13/1993 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 194' FSL, 422' FEL, Sec. 10, T10N, R15E, UM 181' FSL, 202' FEL, Sec. 10, T10N, R15E, UM 213' FSL, 354' FEL, Sec. 10, T10N, R15E, UM Surface: x- y- Zone -712873 5936223 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 3/9/2020 15. 50-029-20980-01-00 16. PBU 03-20A Well Name and Number: 8836' / 8796' 27.83 17. TPI:y- Zone -713093 ASP 4x-5936216 Total Depth: x-y-Zone -712940 ASP 45936243 9336' / 9277' None DNR Approval Number:19. 74-017 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: GR / DLL / AD / CNL, SBT / GR / CCL CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 91.5# 72# 47# 29# L-80 NT-80/L-80 l-80 27' 26' 7931' 8' 9336' 27' 26' 7906'9277' 80' 8-1/2" 12-1/4" 2325# Poleset 500 sx Class 'G', 250sx CS I 295 cu ft Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# 13Cr80 8580' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 8836' Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): H-40 107'30"20" 13-3/8"27'2638'17-1/2"2100 sx CS III, 400sx CS II27'2638' 8529' / 8500' Set Whipstock Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 107' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028328 319-583 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF 29.23 (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 54.93 Water Depth, if Offshore:13. N/A Zero API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 8106' / 8080' 1900' (Approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 2:44 pm, Apr 08, 2020 RBDMS HEW 4/11/2020 Abandon Date 3/9/2020 HEW SFD 4/13/2020 DSR-4/8/2020 xGMGR10APR20 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Hyatt, Trevor Contact Email: Trevor.Hyatt@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4627 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations 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 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. 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. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 8695' 8767' 8944' 9012' 9268' 9280' 8661' 8730' 8899' 8964' 9211' 9223' Sag River / Shublik Sadlerochit - Zone 4 CGL - Zone 3 Base of CGL - Zone 2 TDF - Zone 1 Base Sadlerochit - Kavik Kavik 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 9280'9223' Top of Productive Interval 8767'8730' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Pre-Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.08 14:22:39 -08'00' ACTIVITYDATE SUMMARY 11/6/2019 T/I/O=280/1500/650, Temp=145*. PPPOT-T (PASS), PPPOT-IC (PASS), DRLG screen. PPPOT-T: Stung into test port (2000 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (900 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 11/22/2019 T/I/O = 270/1500/530. Temp =143°. Warm TIFL. PASSED. (eval TxIA). ALP = 1500 psi, AL open @ casing valve. IA FL @ 5113' (Sta #2, SO, 274 bbls). Shut well in @ WV. Stacked out WHPs to 1880/1880/480 in 30 minutes. Bled IAP from 1880 psi to 670 psi in 1 hour and 30 minutes to flowline. During bleed TP and IA FL unchanged, OAP decreased 230 psi. Monitored for 1 hour TP, IAP and IA FL unchanged, OAP decreased 30 psi. Turned well over to DSO to POP. FInal WHPs = 1880/670/220. SV, WV = C. SSV, MV = O. IA, OA = OTG. 11:00 12/12/2019 ***WELL S/I ON ARRIVAL*** (ctd screen) DRIFT W/ 20' x 3.70" DMY WHIPSTOCK & 1.75" S. BAILER, TAG BTM AT 8930' MD (+16' OF RATHOLE) RAN TEL W/ BP SBHP GAUGES AS PER PROGRAM. LOCATE TUBING TAIL AT 8568' SLM (+12' CORR) CURRENTLY LOGGING READ 40 ARM EXTENDED FINGER CALIPER FROM 8922' MD ***CONT. ON 12/13/19 WSR*** 12/13/2019 ***CONT. FROM 12/12/19 WSR*** (ctd screen) LOGGED READ 40 ARM EXTENDED FINGER CALIPER FROM 8922' MD TO SURFACE...GOOD DATA LRS LOAD IA & TBG W/ CRUDE (see lrs wsr) SET 4-1/2" PXN-PLUG @ 8567' MD LRS PERFORM PASSING MIT-T, CMIT-TxIA & MIT-OA (see lrs log) PULLED 4-1/2" PXN-PLUG 8567' MD ***CONT. ON 12/14/19 WSR*** Daily Report of Well Operations PBU 03-20A Daily Report of Well Operations PBU 03-20A 12/13/2019 T/I/O=1800/1800/150 Temp=SI Assist SLine w/ L&T (DRLG SCREEN (MAINT)) MIT-T Passed to 2577 psi. Target pressure 2500 psi. Max applied 2750 psi. Pressured up TBG to 2749 psi with 3 bbls 80* crude. 1st 15 min TBG lost 128 psi. 2nd 15 min TBG lost 44 psi for a total loss of 172 psi in 30 min. CMIT-TxIA Passed to 2637/2662 psi. Target pressure 2500 psi. Max applied 2750 psi. Pressured up T/IA to 2711/2738 psi with 19 bbls 80* crude. 1st 15 min T/IA lost 54/54 psi. 2nd 15 min T/IA lost 20/22 psi for a total loss of 74/76 psi in 30 min. Bled TBG to 500 andIA to 300 psi and recovered ~ 7 bbls. MIT-OA Passed to 1138 psi. Target pressure 1080 psi. Max applied 1200 psi. Pressured up OA to 1204 psi with 4.75 bbls 80* crude. 1st 15 min OA lost 48 psi. 2nd 15 min OA lost 18 psi for a total loss of 66 bbls in 30 min. Bled OA to 150 psi and recovered ~ 4.5 bbls. Pump 3 bbls 60/40 meth and 327 bbls crude down IA for load. Pumped 3 bbls 60/40 meth and 156 bbls 110* crude down Tbg for load. Pumped 5.6 bbls crude to assist SL setting prong SL in control upon departure. IA OA= OTG. Tags hung, AFE sign hung on well. Final WHP's=500/200/150 12/14/2019 ***CONT. FROM 12/13/19 WSR*** (ctd screen) RIG DOWN HES SLICKLINE UNIT 046 ***JOB COMPLETE, WELL LEFT S/I*** 1/11/2020 ***WELL S/I ON ARRIVAL*** (CTD) RIG UP HES SLICKLINE UNIT 046 ***CONT. ON 01/12/20 WSR*** 1/11/2020 T/I/O = SSV/Vac/150. Temp = SI. IA FL (Slickline request). IA FL @ 40' (2 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 19:45. 1/12/2020 ***CONT. FROM 01/11/20 WSR*** (CTD) SET 4-1/2" SLIP STOP CATCHER @ 5166' SLM PULLED TG-S/O @ 5113' MD SET RK-DGLV @ 5113' MD PULLED RK-LGLV @ 2968' MD SET RK-DGLV @ 2968' MD PERFORM PASSING MIT-IA (see data tab) PULLED 4-1/2" SLIP STOP CATCHER @ 5166' SLM DRIFT W/ 20' x 3.70" DMY WHIPSTOCK & 1.75" S. BAILER, TAG BTM @ 8930' MD ***JOB COMPLETE, WELL LEFT S/I*** 1/22/2020 ***WELL S/I ON ARRIVAL*** (SLB ELINE SET WHIPSTOCK) INITIAL T/I/0=500/200/300. MIRU & PT TO 3200 PSI. RUN 1: SET 4-1/2" x 7" BAKER DELTA WHIPSTOCK @ 8840' TOWS, 5 DEG ROHS, RA TAGS 8.64' FROM TOWS, OAL LIH ~ 18'. ALL LOGS CORRELATED TO SLB JEWLERY LOG DATED 28-APR-1993. WELL LEFT S/I ON DEPARTURE. FINAL T/I/0=500/200/300. ***JOB COMPLETE ON 22-JAN-2020*** 2/10/2020 (LRS unit 76 heat UR's) Circulate and heat UR's 1% KCL with safe lube to 120* F. ***Continued on 02/11/20*** 2/11/2020 ***Continued from 02/10/20*** (LRS unit 76 heat UR's) Continued to heat remaining two UR's of 1% KCL with safe lube to 120* F. RDMO. 2/15/2020 LRS Unit 46 Heat 3 x Uprights to 140*. Daily Report of Well Operations PBU 03-20A 2/18/2020 CTU #9 1.75" coil Pre CTD - Mill XN, Mill window Wait on scaffolding. MIRU. Begin BOP test. ***continued on 02/19/20*** 2/19/2020 CTU #9 1.75" coil Pre CTD - Mill XN, Mill window Perform BOP test. (AOGCC Witness Waived by Jeff Jones). MU & RIH w/ 3.80" LH milling BHA. Mill XN at 8567' MD. from 3.75" to 3.80". Dry difted down to 8590' md. POH. MU & RIH w/3.80 N.S. RH window milling BHA. ***continued on WSR 2/20/20*** 2/20/2020 CTU #9 1.75" coil Pre CTD - Mill XN, Mill window MU & RIH w/3.80 N.S. RH window milling BHA. Tagged tray @ 8809' ctm, puh. See motor work @ 8807.8' milling. Milled 1fph through 10.2', 1' past the string reamer's exit. Milled 10' of rat hole to a total depth of 8827'. Made multiple reaming passes and dry drifted down to 8828. POOH. Freeze protect TBG w/38bbl of 60/40. ***Complete*** 2/24/2020 T/I/O=Vac/0/0. Pre CDR2. Set 4" H TWC #444 @130". LTT Passed. RD 4" Cameron upper tree. RU 4" CDR2 tree #3, kill line #1. Torqued to API spec. PT 4" CDR2 tree #3 and kill line #1 to low 300psi and high 5000psi for 5 min ea. Passed. Pulled 4" H TWC #444 @130". RD 4" tree bonnet. RU 4x7 cross, test spool #4. Torqued to API spec. PT top side MV to low 300psi and high 3500psi for 5 min ea. Passed. PT top side SV to low 300psi and high 3500psi. Passed. PT top side of 2nd MV and bottom side of SV to low 300psi and high 3500psi for 5 min ea. Passed. Cycle 2nd MV and SV. Job Complete. See log. Final Whp,s Vac/0/0. 3/7/2020 T/I/O = /50/150. Temp = SI. Bleed OAP (CDR). OA FL @ near surface. Bled OAP to BT to 0+ psi in 1 hr (gas). Maintained an open bleed for an additional 15 min. Monitored for 30 min. OAP unchanged. Final WHPs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ll depths reported in Drillers Depths** !"! # !$ % &'& (% &)& 3 4 5 &1% 6(% & '&&)+/)7 5 8 5 ! % 99:91 4!94)+' ( 6;0*1+68<# = 7 $ 5 <+ 2 % #68<$ ( 8> % 8 <! 8"8 #$ % 8 !4 ! %!: :49%91!::4C!!9?% 9 1 ' )&).D0 14 -9%&" - &/D9&9-74%,- &/DE )&D ? 9- &/D9&9 !09&091 )9 ?- 9 -+-) % 9%&" - )-)-)-* 4 # &/D$- 9)---) *4 &/D9&9- 9- - - -)01 929- 7!?9 9 49%% 1 799: ?? 1).)* 9:4 " 9:?, 99 " 9 !C 1 !74 %!4 % 2! 9791 !%4 1 10).). !4 ! 94! 1 0).- )-)) .? 9# &/D$-'-+-)- ? !4"!! 1 !%! !' #29&C : &$ 42! '1"C% 49 !! &/D9&94 !!1 %%!474 ! 19! 2 !7 9:1 C!9 " "!792!%1 ' 7 !: !0-.- /1.29%1% 4 % C: 1 9 !4 !! !!7 1 :9A 474 ! 1 '! &/D9&9-0-.-/- ?) %9:%!!"9:"1!' "9%.1, .1% ! .17!?!1 /"!-"! 474 ! % %! .10). !4 ! 94! 4 @!9 19 1+F? 4 2! 9: )&D1 97! 9:!4 .2! 49 ??1 )1 &+& !4 ! 9: 2! )&D ."!??1 !09 )10) !4 +4 # )&$-)-*-. )? 9# )&D$-- 9G 7 )1) ( )0**7*&'&**All depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** 6WDUW% THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-20A Permit to Drill Number: 193-047 Sundry Number: 319-583 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.a[cska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Jessiee ielowski Commissioner DATED this )3 day of December, 2019. 3BDMS�JAN 9 2 2020 STATE OF ALASKA r"'A % r— ii Irl— ALASKA OIL AND GAS CONSERVATION COMMISSION 6y�0 07) APPLICATION FOR SUNDRY APPROVALS / z /� 20 AAC 25.280 E O 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ OEU Ipe24.0 15, shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChaAppro� Program ❑ 11Plug for Redrill El • Perforate New Pool ❑ Re-enter Susp Well Alter Casing ❑ r ijM`a ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development El 5. Permit to Dill Number. 193-047 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20980-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 03-20A ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028328. PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth WD(ft): Effective Depth MD: Effective Depth WD: MPSP (psi): Plugs (MD): Junk (MD): 9336 • 9277 8921 8877 2508 8921.8932 9226,9231 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 27-107 27-107 1490 470 Surface 2611 13-3/8" 27-2638 27-2638 5380 2670 Intermediate 8080 9-5/8" 26-8106 1 26-8080 6870 4760 Production Liner 1 1405 7" 7931-9336 7906-9277 1 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: 1 Tubing Grade: Tubing MD (ft): 1 8771 -8894 8734-8851 4-1/2" 12.6# 13Cr80 24-8580 Packers and SSSV Type: 4-1/2" BAKER SAB PERM PACKER Packers and SSSV MD (ft) and TVD (ft): 8529 / 8500 12. Attachments: Proposal Summary ® Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch RI Exploratory ❑ Stratigraphic ❑ Development D Service ❑ 14. Estimated Date for Commencing Operations: January 15, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 - 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Tmvor.Hyatt@bp.com Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: Engineering Team Lead - CTD Authorized Signature: Date: 12/11ZDVI COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Int ty ❑C—r-3—BOP Test O Mechanical Integrity Test ❑ Location Clearance ❑ 1 Otherr �OAG1� 1 �]�1 /Te �/! f Ka l�G-%r/fEXce-776 �� 2JiA( /C-1,0019i�ee / YN.6. 'I G�e/I'LL' Post Initial Injection MIT Req'd? Yes ❑ No ❑ •]p1��A7 '3BD Imo/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q _yQ� S r'�'_ JAN 0 Z 10?0 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 1-10 11L ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Submit Farm and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt - CTD Engineer Obp Date: December 18, 2019 Re: 03-20A Sundry Approval Request Sundry approval is requested to plug off the 03-20A production as part of the drilling and completing the proposed 03-20B coiled tubing sidetrack. History of 03-20A 03-20A was last worked over in 1993. 03-20A has watered out and there are no additional wellwork options to improve the oil rate. The plan is to sidetrack from 03-20A to establish offtake from the 03-07B MIST injector. Proposed plan for 03-20B The sidetrack will be a `1824' horizontal CST that will kicks -out from the 03-20A parent. The CST will establish offtake in Zone 4A and the upper portion of Zone 3. The sidetrack will be drilled around March 2020. During pre -rig work, it is proposed to set a 4-1/2" x 7" whipstock at a kickoff depth of 8833' MD and mill a 3.80" window. The rig will move in, test BOPE, kill the well, and drill the lateral. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr-80 solid liner and cemented in place. This Sundry covers Plugging the existing 03-20A production via the liner cement Fob or liner too packer, if the liner lap pressure test fails (alternate plug placement Per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin January 15th, 2020) 1. 1. S DMY GLVs, Drift for whipstock. 3. 2. EL Set Whipstock T ws X833 3. C Mill Window 0 /p 4. V Pre -CTD Tree work. Rig Work (scheduled to begin March 2020) 1. MIRU and test BOPE 250 psi low and psi high (MASP 2508 psi). & B 2. Drill production section: 4.25" OH 3. Run 3-1/4" x 2-7/8" liner to TD. 4. Pump primary cement job: 29.2 bbls, 15.3 ppg Class G, TOC at TOL (8525' MD)*. S. Freeze protect well to a min 2,200' TVDss. 6. Close in tree, RDMO. 11 * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. 3. C: Perforate toe, up to 200'. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 907-223-3087 T COPCV," 0' 1 �N to W� L w�ltc DF s The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EM W of 8.4 ppg KCL ("'507 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "open hole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting ys� tem) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: DS -03 is an H25 pad. Recent recorded H2S reading on 03-20A: 400 ppm on 11/5/2019. Max H2S recorded on the pad: 1100 ppm. Reservoir Pressure: • The reservoir pressure on 03-20B is expected to be 3403 psi at 8950' TVDSS (7.31 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2508 psi. • A min EMW of 8.4 ppg for this well will provide 507 psi over -balance to the reservoir. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 907-223-3087 I IGC - 2968 LHEAD = FMC TLE UATOR= OTLS rREF 67 ELEV = 54.93•LEV = 2923' KOP = 5600' Max Angie = 19-908751- 8" 8751'Dahm DatumMD = 8897' Dahxn TVD = ARM' RS 120- COND, 91.511, H-00,10=19.124• I --j T�4' I9-5/8• CSG 47C NT -80, D = 8.881 • T929' 13-3/8' CSG 72X, L-80, D = 12347' 284$' Minimum ID = 3.725 @ 8567' 4 1/2' PARKER SWN NIPPLE TOP OF T LNR7931' L-80, 14-irz- 1136, 12.8X, 13CR-80, 0.0152 bDf. D=3.958• 1 PERFORATION SUMMARY REF LOG: SWS GRICCL 0428193 & CNL/ GR 04/13/93 ANGLE AT TOP PERF: 187@ 8771' Note: Refer to Pmduction D B for NstDrical perf data SIZE I SPF 1 NTERVAL ONS SHOT SQZ SEE PAGE 2 FOR PERF SUMMARY D = 6.184• 03=20A SAFETY NOTES: 'CHROME TS(T"' L!M 3.813' 1 2968 2968 0 TE-TGPD DOME RK 16 0410611E 2 5113 5113 0 TE-TGPD SO TGF TG 24 0410811E 3 6004 6004 2 TE-TGPD )MY TG 0 KDC/PAG 4 6269 6269 2 TE-TGPD DMV TG 04/14/19 1023/11 5 6686 6685 5 TE-TGPD DMY TG 0 6 7067 7060 14 TE-TGPD DMY TG 0 7 7373 7357 12 TE-TGPD DMY TG 0 9' �—{ T X 9-5/e' BOT LNR HGR WM PKR MLLOUT WINDOW (03-20A) 8106'-8111' 4' 4-12' PARKEF2 SWS NP, D = 3.813• U"o —14 1rz wL�, D = 3.ssa 6688' H.MD TT LOG(`® 0428/93 DATE REV BYOPERF MENTS DATE REV BY COMMENTS ?7? 0725109 JCM/PJC DUMP SLUGGf S 07/18/09 04!22183 VER 0728/11 CJW PJC BALD PULL IBP 7/(IN11) 1221/05 COM/fLH NOTEDELETIF 0324/14 CJN/JMD TRSV LOCKED OPEN 12J17M3 01117MB KDC/PAG C/O5106) 1029/19 ZV/JMD GLV GO 1023/18 OSI30N6 DTM ORRECTION 04/14/19 JPK/JMD+ GLV CAD 01/06/19 0725/09 MV/PJC 7H6N9 1028/19 JNL/JMD ADDED BF & REF ELEV PRUDHOE BAY UNR WELL 03-20A PERMrr No: x1930470 API No: 50-029-20980-01 SP Exploration (Alaska) 03-20A PERFORATION SLMARY REF LOG: SM GR/CCL 04/28/93 & CNU GR 04/13/93 ANGLEAT TOP FBiF: 18? [Q 8771' Note: llefer to Roduction DB for hsbrical perf data SEE SFF INTBWAL Opn/Sgz SHOT SQZ JCMIPJC DUMP SLUGGITS 07/1&09 8888-8894 S 01/09193 01124/94 CJW PJC 4 8772 - 8776 S 04/28/93 11102193 CJWJMD 4 8782-8794 S 042853 11102163 ZVUMD 4 8888.8894 S 0412M3 11102163 JPKIJMD+ 4 8920-6940 S 04728193.11/02/63 2&19 JNLAIMD ADDED BF & REF ELEV 8920-8940 S 11/09/93 01/24/94 8888 - 8894 02/02/94 3-3(8' 4 8888-8894 O 02/02/94 8908-8914 02/02/94 3-3(8' 4 8908-8914 O 02/02194 8920-8935 02/02/94 8781-8793 02/17/94 8821-8831 02/17/94 3-3/8" 6 8771- 8777 O 07107196 8680-8686 07/07/96 8702-8719 07/07/96 8738-8745 07/07/96 3-3/8' 4/6 8782-8812 O 0710756 3-318' 416 8822-8842 O 07/0756 8757-8774 07/04/09 8748-8757 07/14/09 3,W 6 8842-8870 O 07/16109 3-3/8' 4 8920-8935 5 1027/03 3-3/8' 4 8935- 8940 S 012454 DATE REV BY COMMENTS DATE REV BY COMMENTS ??? ORIONAL?? /25/09 JCMIPJC DUMP SLUGGITS 07/1&09 O4127/93 LAST WORKOVER 28/11 CJW PJC BAFJ PULL IBP 07/04/11 1221/05 COM/fLH WAIVER SF7Y NOTE DELETE 24(14 ;/14119 CJWJMD TRSV LOCKED OPEN 12/17113 01/17/08 KDC/PAG GLV C/O (01105/06) 29118 ZVUMD GLV CIO (10123/18 05130106 DTM WELLHEAD CORRECTION JPKIJMD+ GLV CAD 04/06119 0725/09 MVIPJC IBP & PERF (07116109) 2&19 JNLAIMD ADDED BF & REF ELEV PRUDHOE BAY UNIT WELL 03-20A PERMrr No: 91930470 API No: 50-029-20980-01 I. TION. R15E. 194' FSL & 427 BP Exploration (Alaska) TREE= WELLHEAD= FMC ACTUATOR= DEV TYPE OKS. ELEV = 62' REF ELEV = 5433' BF. ELEV= 29.23' KOP = 6600' Max Anglee = 04/06/19 Dakrn M_D= 5113 Dalen TVD = 8800' SS PROPOSED 03-2 )" COND. 91.5#, HTO, ID=19.124" 114' 9-5/8" CSG 47# NT -80, D = 8.681" 192 1-38" CSG 72#, L-80, D = 12.347" Minimum ID= 2.377" @ 986T 3-3A6" X 2-718" XO 9-518" CSG, 47#, L-80, D=8.681"8106' TOP OF LNR 8525' 2" TBG, 12.6#, 13CR-80, 0.0152 bpf, D = 3.958" LNR, _4, 13CR45 STL, .0087 bpf, D = 2.992- 17" / 7" LNR, 29#, L-110_0371 bpf, ID = 6.184' LNR, 6.69,13CR43 TC11, .0079 bpf, D = 2-85" EYUy PERFORATION SUMMARY REF LOG: ON !_I ANGLEATTOPPERF: PBTD — 13CR-85 STL, .0058 bpf, D = 2.441' 10862' CAM TRGF-4A SSSV NP, ID= 3.813' LOCKED OPEN (12/17/13) (-.A6I ff�r MAmnRGI c ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2968 2968 0 TE-TGPD DOME RK 16 04/06/19 2 5113 5113 0 TE-TGPD SO TG 24 04/06/19 3 6004 6004 2 TE TGPD DMY TG 0 4 6269 6269 2 TE-TGPD DMY TG 0 10/23/18 5 6686 6685 5 TE-TGPD DMY TG 0 6 7067 7060 14 TE-TGPD DMY TG 0 7 7373 7357 12 TE-TGPD DMY TG 0 8 7676 7644 10 TE-TGPD DMY TG 0 12/10/05 WH PKR MLLOUT WNDOW (03.20A) 8106' - 8111' 1474' 4-1/2" PARKER SWP, S N 0=3.813" 1625' 3.70" DEPLOYMETNVE, D =—F3-12' X NP, ID 16� 7- BAKER PERMANENT PKR 8650' 14-12" PARKER SWS NP, ID=3.813" 14-1/2' PARKER SWN NP MILLED TO 3.80.1 1 1 1 ooaua958- 8689' SMD TT LOGGED 04/28/93 8600' 312" X 3-3/19" XO, D = 2.788' MLLOUT WNDOW(03-206)_'-_' DATE REV BY COMMENTS DATE REV BY COMMENTS ??? ORIGINAL?? 042293 LAST WORKOVER / I CTD 3-208 11/19/19 JMD BUILT PROPOSED = 2.377' PRUDHOE BAY UNIT WELL: 03-208 PERMIT No: API No: 50-029-20980-02 SEC 10, TON, R15E, 194' FSL 8 422' BP Exploration (Alaska) ------------------- �I D a 3 I Colled Tu6im unit ._._ _ _._._.� DOC I I I � Source Water Tank Farm_ _ _ Barrels of Oil per Month or Barrels of Water per Month IIII, I I11� �� IIII 1 IIII 11�■ IIII , 'u/�,uuu■ n . lnlll�lllllll, IIIII 1 III, Nlu Him �811�■�II111� �u�u�mum�N�H� ■ lull IIIIII� 111, p 11 ,■Ilul ■IIII 1,■IIII II�■VIII •. 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I,■IIII�11�■ 111111 ■ 11111,■`Ili �IIII�■IIII 1■■ml III,■11111 ,NIIIA 1111111 1;�'lu III■VIII 1 I'm 1 �II,■111111, I,■IIIIII,INN ■Ilull, • ._ �I,� �I II11,■IIII,■IUull� VIII, IIIIIII�■III�III III ,��III,■IIIIIII,■II'lll; ■ ulu■111uu■iu ones I!O-seg ao gjuow jad („jaw„) seg ;o taaj 3!qn:) puesnoyj x0 W N O � N m N O NI N ,A N � N � 0 0 o 0 O N v 31 s u' N ones I!O-seg ao gjuow jad („jaw„) seg ;o taaj 3!qn:) puesnoyj x0 W N O � N m N O NI N ,A N � N � v 31 s u' N O N � W � A O m 9 O _ a O I d w s a m Q D pq 6 N C o a � N 10 a m .Or 0 N 3 C 9 A u O 6 N 0 N � N � o � N C N w 0 a m m m r c m Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Task reviewer will check to ensure that the "Plug for Redrill" box 7The r left corner of Form 10-403 is checked. If the "Abandon" or boxes are also checked, cross out that erroneous entry and both copies of the Form 10-403 (AOGCC's and operator's 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial t/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). 7Drilling Instead, check the "Suspended" box and initial that change. The drilling engin6ers will serve as quality control for steps 1 and 2. 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-20A Permit to Drill Number: 193-047 Sundry Number: 319-583 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.a[cska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Jessiee ielowski Commissioner DATED this )3 day of December, 2019. 3BDMS�JAN 9 2 2020 STATE OF ALASKA r"'A % r— ii Irl— ALASKA OIL AND GAS CONSERVATION COMMISSION 6y�0 07) APPLICATION FOR SUNDRY APPROVALS / z /� 20 AAC 25.280 E O 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ OEU Ipe24.0 15, shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChaAppro� Program ❑ 11Plug for Redrill El • Perforate New Pool ❑ Re-enter Susp Well Alter Casing ❑ r ijM`a ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development El 5. Permit to Dill Number. 193-047 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20980-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 03-20A ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028328. PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth WD(ft): Effective Depth MD: Effective Depth WD: MPSP (psi): Plugs (MD): Junk (MD): 9336 • 9277 8921 8877 2508 8921.8932 9226,9231 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 27-107 27-107 1490 470 Surface 2611 13-3/8" 27-2638 27-2638 5380 2670 Intermediate 8080 9-5/8" 26-8106 1 26-8080 6870 4760 Production Liner 1 1405 7" 7931-9336 7906-9277 1 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: 1 Tubing Grade: Tubing MD (ft): 1 8771 -8894 8734-8851 4-1/2" 12.6# 13Cr80 24-8580 Packers and SSSV Type: 4-1/2" BAKER SAB PERM PACKER Packers and SSSV MD (ft) and TVD (ft): 8529 / 8500 12. Attachments: Proposal Summary ® Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch RI Exploratory ❑ Stratigraphic ❑ Development D Service ❑ 14. Estimated Date for Commencing Operations: January 15, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 - 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Tmvor.Hyatt@bp.com Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: Engineering Team Lead - CTD Authorized Signature: Date: 12/11ZDVI COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Int ty ❑C—r-3—BOP Test O Mechanical Integrity Test ❑ Location Clearance ❑ 1 Otherr �OAG1� 1 �]�1 /Te �/! f Ka l�G-%r/fEXce-776 �� 2JiA( /C-1,0019i�ee / YN.6. 'I G�e/I'LL' Post Initial Injection MIT Req'd? Yes ❑ No ❑ •]p1��A7 '3BD Imo/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q _yQ� S r'�'_ JAN 0 Z 10?0 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 1-10 11L ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Submit Farm and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt - CTD Engineer Obp Date: December 18, 2019 Re: 03-20A Sundry Approval Request Sundry approval is requested to plug off the 03-20A production as part of the drilling and completing the proposed 03-20B coiled tubing sidetrack. History of 03-20A 03-20A was last worked over in 1993. 03-20A has watered out and there are no additional wellwork options to improve the oil rate. The plan is to sidetrack from 03-20A to establish offtake from the 03-07B MIST injector. Proposed plan for 03-20B The sidetrack will be a `1824' horizontal CST that will kicks -out from the 03-20A parent. The CST will establish offtake in Zone 4A and the upper portion of Zone 3. The sidetrack will be drilled around March 2020. During pre -rig work, it is proposed to set a 4-1/2" x 7" whipstock at a kickoff depth of 8833' MD and mill a 3.80" window. The rig will move in, test BOPE, kill the well, and drill the lateral. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr-80 solid liner and cemented in place. This Sundry covers Plugging the existing 03-20A production via the liner cement Fob or liner too packer, if the liner lap pressure test fails (alternate plug placement Per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin January 15th, 2020) 1. 1. S DMY GLVs, Drift for whipstock. 3. 2. EL Set Whipstock T ws X833 3. C Mill Window 0 /p 4. V Pre -CTD Tree work. Rig Work (scheduled to begin March 2020) 1. MIRU and test BOPE 250 psi low and psi high (MASP 2508 psi). & B 2. Drill production section: 4.25" OH 3. Run 3-1/4" x 2-7/8" liner to TD. 4. Pump primary cement job: 29.2 bbls, 15.3 ppg Class G, TOC at TOL (8525' MD)*. S. Freeze protect well to a min 2,200' TVDss. 6. Close in tree, RDMO. 11 * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. 3. C: Perforate toe, up to 200'. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 907-223-3087 T COPCV," 0' 1 �N to W� L w�ltc DF s The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EM W of 8.4 ppg KCL ("'507 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "open hole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting ys� tem) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: DS -03 is an H25 pad. Recent recorded H2S reading on 03-20A: 400 ppm on 11/5/2019. Max H2S recorded on the pad: 1100 ppm. Reservoir Pressure: • The reservoir pressure on 03-20B is expected to be 3403 psi at 8950' TVDSS (7.31 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2508 psi. • A min EMW of 8.4 ppg for this well will provide 507 psi over -balance to the reservoir. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 907-223-3087 I IGC - 2968 LHEAD = FMC TLE UATOR= OTLS rREF 67 ELEV = 54.93•LEV = 2923' KOP = 5600' Max Angie = 19-908751- 8" 8751'Dahm DatumMD = 8897' Dahxn TVD = ARM' RS 120- COND, 91.511, H-00,10=19.124• I --j T�4' I9-5/8• CSG 47C NT -80, D = 8.881 • T929' 13-3/8' CSG 72X, L-80, D = 12347' 284$' Minimum ID = 3.725 @ 8567' 4 1/2' PARKER SWN NIPPLE TOP OF T LNR7931' L-80, 14-irz- 1136, 12.8X, 13CR-80, 0.0152 bDf. D=3.958• 1 PERFORATION SUMMARY REF LOG: SWS GRICCL 0428193 & CNL/ GR 04/13/93 ANGLE AT TOP PERF: 187@ 8771' Note: Refer to Pmduction D B for NstDrical perf data SIZE I SPF 1 NTERVAL ONS SHOT SQZ SEE PAGE 2 FOR PERF SUMMARY D = 6.184• 03=20A SAFETY NOTES: 'CHROME TS(T"' L!M 3.813' 1 2968 2968 0 TE-TGPD DOME RK 16 0410611E 2 5113 5113 0 TE-TGPD SO TGF TG 24 0410811E 3 6004 6004 2 TE-TGPD )MY TG 0 KDC/PAG 4 6269 6269 2 TE-TGPD DMV TG 04/14/19 1023/11 5 6686 6685 5 TE-TGPD DMY TG 0 6 7067 7060 14 TE-TGPD DMY TG 0 7 7373 7357 12 TE-TGPD DMY TG 0 9' �—{ T X 9-5/e' BOT LNR HGR WM PKR MLLOUT WINDOW (03-20A) 8106'-8111' 4' 4-12' PARKEF2 SWS NP, D = 3.813• U"o —14 1rz wL�, D = 3.ssa 6688' H.MD TT LOG(`® 0428/93 DATE REV BYOPERF MENTS DATE REV BY COMMENTS ?7? 0725109 JCM/PJC DUMP SLUGGf S 07/18/09 04!22183 VER 0728/11 CJW PJC BALD PULL IBP 7/(IN11) 1221/05 COM/fLH NOTEDELETIF 0324/14 CJN/JMD TRSV LOCKED OPEN 12J17M3 01117MB KDC/PAG C/O5106) 1029/19 ZV/JMD GLV GO 1023/18 OSI30N6 DTM ORRECTION 04/14/19 JPK/JMD+ GLV CAD 01/06/19 0725/09 MV/PJC 7H6N9 1028/19 JNL/JMD ADDED BF & REF ELEV PRUDHOE BAY UNR WELL 03-20A PERMrr No: x1930470 API No: 50-029-20980-01 SP Exploration (Alaska) 03-20A PERFORATION SLMARY REF LOG: SM GR/CCL 04/28/93 & CNU GR 04/13/93 ANGLEAT TOP FBiF: 18? [Q 8771' Note: llefer to Roduction DB for hsbrical perf data SEE SFF INTBWAL Opn/Sgz SHOT SQZ JCMIPJC DUMP SLUGGITS 07/1&09 8888-8894 S 01/09193 01124/94 CJW PJC 4 8772 - 8776 S 04/28/93 11102193 CJWJMD 4 8782-8794 S 042853 11102163 ZVUMD 4 8888.8894 S 0412M3 11102163 JPKIJMD+ 4 8920-6940 S 04728193.11/02/63 2&19 JNLAIMD ADDED BF & REF ELEV 8920-8940 S 11/09/93 01/24/94 8888 - 8894 02/02/94 3-3(8' 4 8888-8894 O 02/02/94 8908-8914 02/02/94 3-3(8' 4 8908-8914 O 02/02194 8920-8935 02/02/94 8781-8793 02/17/94 8821-8831 02/17/94 3-3/8" 6 8771- 8777 O 07107196 8680-8686 07/07/96 8702-8719 07/07/96 8738-8745 07/07/96 3-3/8' 4/6 8782-8812 O 0710756 3-318' 416 8822-8842 O 07/0756 8757-8774 07/04/09 8748-8757 07/14/09 3,W 6 8842-8870 O 07/16109 3-3/8' 4 8920-8935 5 1027/03 3-3/8' 4 8935- 8940 S 012454 DATE REV BY COMMENTS DATE REV BY COMMENTS ??? ORIONAL?? /25/09 JCMIPJC DUMP SLUGGITS 07/1&09 O4127/93 LAST WORKOVER 28/11 CJW PJC BAFJ PULL IBP 07/04/11 1221/05 COM/fLH WAIVER SF7Y NOTE DELETE 24(14 ;/14119 CJWJMD TRSV LOCKED OPEN 12/17113 01/17/08 KDC/PAG GLV C/O (01105/06) 29118 ZVUMD GLV CIO (10123/18 05130106 DTM WELLHEAD CORRECTION JPKIJMD+ GLV CAD 04/06119 0725/09 MVIPJC IBP & PERF (07116109) 2&19 JNLAIMD ADDED BF & REF ELEV PRUDHOE BAY UNIT WELL 03-20A PERMrr No: 91930470 API No: 50-029-20980-01 I. TION. R15E. 194' FSL & 427 BP Exploration (Alaska) TREE= WELLHEAD= FMC ACTUATOR= DEV TYPE OKS. ELEV = 62' REF ELEV = 5433' BF. ELEV= 29.23' KOP = 6600' Max Anglee = 04/06/19 Dakrn M_D= 5113 Dalen TVD = 8800' SS PROPOSED 03-2 )" COND. 91.5#, HTO, ID=19.124" 114' 9-5/8" CSG 47# NT -80, D = 8.681" 192 1-38" CSG 72#, L-80, D = 12.347" Minimum ID= 2.377" @ 986T 3-3A6" X 2-718" XO 9-518" CSG, 47#, L-80, D=8.681"8106' TOP OF LNR 8525' 2" TBG, 12.6#, 13CR-80, 0.0152 bpf, D = 3.958" LNR, _4, 13CR45 STL, .0087 bpf, D = 2.992- 17" / 7" LNR, 29#, L-110_0371 bpf, ID = 6.184' LNR, 6.69,13CR43 TC11, .0079 bpf, D = 2-85" EYUy PERFORATION SUMMARY REF LOG: ON !_I ANGLEATTOPPERF: PBTD — 13CR-85 STL, .0058 bpf, D = 2.441' 10862' CAM TRGF-4A SSSV NP, ID= 3.813' LOCKED OPEN (12/17/13) (-.A6I ff�r MAmnRGI c ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2968 2968 0 TE-TGPD DOME RK 16 04/06/19 2 5113 5113 0 TE-TGPD SO TG 24 04/06/19 3 6004 6004 2 TE TGPD DMY TG 0 4 6269 6269 2 TE-TGPD DMY TG 0 10/23/18 5 6686 6685 5 TE-TGPD DMY TG 0 6 7067 7060 14 TE-TGPD DMY TG 0 7 7373 7357 12 TE-TGPD DMY TG 0 8 7676 7644 10 TE-TGPD DMY TG 0 12/10/05 WH PKR MLLOUT WNDOW (03.20A) 8106' - 8111' 1474' 4-1/2" PARKER SWP, S N 0=3.813" 1625' 3.70" DEPLOYMETNVE, D =—F3-12' X NP, ID 16� 7- BAKER PERMANENT PKR 8650' 14-12" PARKER SWS NP, ID=3.813" 14-1/2' PARKER SWN NP MILLED TO 3.80.1 1 1 1 ooaua958- 8689' SMD TT LOGGED 04/28/93 8600' 312" X 3-3/19" XO, D = 2.788' MLLOUT WNDOW(03-206)_'-_' DATE REV BY COMMENTS DATE REV BY COMMENTS ??? ORIGINAL?? 042293 LAST WORKOVER / I CTD 3-208 11/19/19 JMD BUILT PROPOSED = 2.377' PRUDHOE BAY UNIT WELL: 03-208 PERMIT No: API No: 50-029-20980-02 SEC 10, TON, R15E, 194' FSL 8 422' BP Exploration (Alaska) ------------------- �I D a 3 I Colled Tu6im unit ._._ _ _._._.� DOC I I I � Source Water Tank Farm_ _ _ Barrels of Oil per Month or Barrels of Water per Month IIII, I I11� �� IIII 1 IIII 11�■ IIII , 'u/�,uuu■ n . lnlll�lllllll, IIIII 1 III, Nlu Him �811�■�II111� �u�u�mum�N�H� ■ lull IIIIII� 111, p 11 ,■Ilul ■IIII 1,■IIII II�■VIII •. 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If the "Abandon" or boxes are also checked, cross out that erroneous entry and both copies of the Form 10-403 (AOGCC's and operator's 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial t/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). 7Drilling Instead, check the "Suspended" box and initial that change. The drilling engin6ers will serve as quality control for steps 1 and 2. 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,June 4, 2018 2:27 PM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS2 Drillsites; Nottingham, Derek; Summers, Matthew; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer 03-20 (PTD#1930470) Sustained inner annulus casing pressure above NOL Attachments: 03-20A.pdf All, Producer 03-20(PTD#1930470) )was reported to have sustained inner annulus casing pressure above NOL after a pad shut down on 6/2/2018. The pressure were reported to be T/I/O=430/2158/188psi. The annulus pressure was bled to 1,875psi, but diagnostic work could not be carried out due to Sag river flood conditions restricting access to the pad. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. OPS—POP Well 2. DHD—Warm TIFL 3. Well Integrity Engineer—Additional diagnostics as needed. Please respond with any questions, Joshua Stephens Well Integrity Engineer p Office: 907-659-8110 %AWED JUN U0'20181 Cell: 907-341-9068 WO wow....«.rye.... 1 • • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] , ;2 It Sent: Sunday, July 29, 2012 4:09 PM ff To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Dos Santos, Higino W; Duong, Lea Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J; AK, D &C DHD Well Integrity Engineer; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During Proration All, The following producers were found to have sustained casing pressure on the IA during proration. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to I - • .r each individual well with a plan forward. 03 -20A (PTD #1930470) 03 -21 (PTD #1831120) titAY 2013 scam scam � 03 -27 (PTD #1840620) F -35 (PTD #1880810) All the wells listed above are reclassified as Not Operable until start -up operations commence and are stable or the well passes a pressure test confirming integrity. After start-up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegritvCoordinator (a�BP.com 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 '✓ Post Office Box 196612 Anchorage, Alaska 99519 -6612 3 December 30, 2011 0,0 \,‘ ED Mr. Tom Maunder 7017 Alaska Oil and Gas Conservation Commission w volts. Ciarniriss 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 4.•i ' J FEtj 2, 2, Me- BPXA, Well Integrity Coordinator • • .... BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS -03 10126/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date I ft bbls ft gal 03 - 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03 -02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03 -03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03 -06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03-07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03 -08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03-10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03 -11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03-12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03 -13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03 -14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03 -15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03 -16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03 -17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03 -19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 -am' 03 -20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03 -21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03 -22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03-24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/12/2011 13.6 7/17/2011 03 -26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03 -27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03 -28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 03 -29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03 -30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 03-33B 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03-34B 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03 -35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 03-37 2091390 50029234210000 2.5 NA 2.5 NA , 162 8/2/2010 02/03/11 Sclinkerger CA 1 1 NO. NO. 5688 Alaska Data 8 Consulting Services Company: State of Alaska Samba Samb Street, Suite 400 ttt!!! Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F -12 BMSA -00003 RST r" :-M —/ �l - 01/05/11 1 H -01A AWJI -00117 MCNL 4 #'' / O 10/15/10 1 0 /s- 1 J -20B BSJN -00073 CH EDIT PDC -GR (PLUG SET) .4.." 1 `3 (l 11/05/10 r ( 1 A -25A BCZ2 -00027 CH EDIT PDC -GR (GR/CCL) 8 ( .— „I Lf 4( 11/06/10 3j O 1 W -220 BG4H -00025 CH EDIT (USIT) (� — /A-/A-4, 12127110 } /0 1 D -33 BD88-00061 MCNL ( C., - - 3 . 10/21/10 1 O3/3 1 13 -37 BBKA -00056 USIT U(� � g �" 09/18/10 03 -20A 11503603 , PRODUCTION LOG I4'i 11/19/16 r40 �1 1 r+./4. 1 . • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ' NN t 7 I C ' • FFB0d 2011 Alaska it & Gas Cons. Commission A a ,...a ... se ‘;) \ ~~~ ~I~~'~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 '?'~ `"' ~"i Anchorage, AK 99503-2838 ~~ ,~, ~~ ~,'~;~ i' `"~` ~~' ATTN: Beth - •' ~-" '"' ' ~ Well Job # Log Description Date osi2~ios NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT L- ~ 07/26/09 1 1 L2-O6 ANHY-00101 PRODUCTION PROFILE 4 G ~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK C' 07/16/09 1 1 M-06A AZCM-00034 PRODUCTION LOG ' - '~ 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p L ~ 07/21/09 1 1 02-11A AYS4-00084 LDt J 07/20/09 1 1 W-212 B3SQ-00011 INJ PROFILE W/WFL ~ - 07l20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL ~ p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL ' -~C L 07/24/09 1 1 H-29A AYQQ-00027 RST 05/19/09 1 03-28 814B-00067 RST (- L-{ 07/17/09 1 1 B-27A AXBD-00029 MCNL 06/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 Q-04A B1JJ-00023 MCNL ' ~ ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T i0/13/08 1 1 07-066 AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/LWD EDIT ~ O6/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-196 B2WY-00004 MCNL (REPLACEMENT) - L 05/07/09 1 YLtASt AGKNVWLtUGt tit[;tlF'1 !iY SIGNING ANU Iit1UHNttVLi UNt I:VYT tAGH IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~ ~~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS .~~~ ~~~~~'~~~~~~,6,~09 Itl~ `3 ~. 7(~~ri7 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ x Pertormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ `~~~~~~ ,,, s~ <> ~+~ +,~ ;a z.'sza:S~ o.a~~`s.'c Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended W~L~ r,, , 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~elopment ~' Exploratory [~ 193-0470 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20980-01-00 7. KB Elevation (ft): 9. Well M1lame and Number: 53.83 KB PBU 03-20A 8. Property Designation: 10. Field/Pool(s): ADLO-028328 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Weil Condition Summary: ~ Total Depth measured 9336 feet Plugs (measured) 8876' true vertical 9277.3'1 feet Junk (measured) None Effective Depth measured 8921 feet true vertical 8877 feet Casing Length Size MD ND Burst Collapse Conductor 51 20" 91.5# H-40 29 - 80 29 - 80 1490 470 Liner 916 7" 29# 13CR80 8420 - 9336 8392 - 9277 8160 7020 Production 1900 9-5/8" 47# N-80 29 - 1929 29 -1929 6870 4760 Production 6177 9-5/8" 47# L-80 1929 - 8'!06 1929 - 8080 6870 4760 Surface 2616 13-3/8" 72# 1-80 29 - 2645 29 - 2645 4930 2670 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth} 4-1/2" 12.6# 13Cr80 29 - 8580 0 0 - Packers and SSSV (type and measured depth) 4-1/2" TRCF-4A SSV 2195 7" Top Packer 7931 4-1/2" Baker SAB Perm Packer 8529 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: '~~ ~~~'~`:~' ' ~`' ~~ `r~ `' ,_ ti f` L~ .. ~ ~ V i,3'3 13. Representative Daily Average Production or lnjection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 70 1198 6744 268 Subsequentto operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory T~ Dev~elopment ~'~+`° Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil r` Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre {e~ Title Data Management Engineer ~ ,u Signature ,~` = - Phone 564-4944 Date 7/22/2009 Form 10-404 Revised 04/2006 ~~'~~ ~~~ ~'~~ .~ <<; /?~1~~ ~ Submit Original Only f~Z ,~`"~~'~~'~`~ 03-20A 193-047 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd De th Base 03-20A 4/28/93 PER 8,772. 8,776. $,734.91 8,738.77 03-20A 4/28/93 PER 8,782. 8,794. 8,744.41 8,755.82 03-20A 4/28/93 PER ~ 8,888. 8,894. 8,845.41 8,851.15 03-20A 4/28/93 PER 8,920. 8,940. 8,876. 8,895.14 03-20A 11/2/93 SG1Z 8,772. 8,940. 8,734.91 8,895.14 03-20A 11/9/93 RPF 8,888. 8,894. 8,845.41 8,851.15 03-20Q 11/9/93 RPF U-~-~ 8,920. 8,940. 8,876. 8,895.14 03-20A 1/24/94 SG1Z 8,888. 8,940. 8,845.41 8,895.14 03-20A 2/2/94 APF ~ 8,908. 8,914. 8,864.53 8,870.26 03-20A 2/2/94 RPF "'~`' 8,888. 8,894. 8,845.41 8,851.15 03-20A 2/2/94 RPF 8,920. 8,935. 8,876. 8,890.36 03-20A 2/17/94 APF 8,821.1 8,831.1 8,781.62 8,791.14 03-20A 2/17/94 RPF 8,781.1 8,793.1 8,743.56 8,754.97 03-20A 3/13/94 SPS 9,007. 9,336. 8,959.37 9,277.31 03-20A 3/14/94 SPS 8,845. 9,007. 8,804.38 8,959.37 03-20A 7@/94 SPR 8,915. 8,970. 8,871.22 8,923.88 03-20A 9/11/94 FIL 8,936. 8,970. 8,891.31 8,923.88 03-20A 7/7/96 APF 8,771. 8,777. 8,733.96 8,739.66 03-20A 7/7/96 APF 8,794.1 8,812.1 8,755.92 8,773.05 03-20A 7/7/96 APF 8,832. 8,842. 8,792, 8,801.53 03-20A 3/19/02 SPR 8,845. 8,915. 8,804.38 8,871.22 03-20A 6/20/02 BPS 8,917. 8,922. 8,873.13 8,877.92 03-20A 8/29/03 BPP 8,917. 8,922. 8,873.13 8,877.92 03-ZOA 8/30103 BPS 8,452. 8,460. 8,423.95 8,431.89 03-20A 10/23/03 BPP 8,452. 8,460. 8,423.95 8,437.89 03-20A 10/24/03 BPS 8,932. 9,336. 8,887.48 9,277.31 03-20A 10/26/03 SPS 8,921. 8,932. 8,876.96 8,887.48 03-20A 7/14/09 APF 8,852. 8,870. 8,811.06 8,828.23 03-20A 7/16/09 APF 8,842. 8,852. 8,801.53 8,811.06 03-20A 7/16/Q9 BPS 8,882. 8,88$. 8,839.68 8,845.41 03-20A 7/17/09 SPS 8,876. 8,882. 8,833.96 8,839.68 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL 1SOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 03-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~a ~~,~ - . - s _, ~~ ~~~~i K ~ rv t .. , . _ ~ 7/13/2009~***WELL SHUT IN ON ARRIVAL.*"'` ~ ~ ; RIGGING UP FOR PERFORATING JOB. ; j ;***JOB CONTINUED ON 14-JULY-2009.*"" ~~ ~ 7/14/2009~~~~T/I/0=1400/1800/260, Temp= S/I. Assist E-line with load tubing to pump open~ ~ iSSSV. Pump 106 bbls crude down TBG. FWHP's= 800/1700/250 E-line on well ~ ~ ~ at time of LRS departure. ' : ~ 7/14/2009~T/I/0=1750/1770/180. Temp SI.~T FL (E-line). ALP=SIm@ lateral valve. T^FL ~ ~ @ 2450' (40 bbls). ` 'SV, WV, SSV=S1. MV=O. IA, OA=OTG. NOVP. ~ ; , ~ ~.~_~__~.~.~.~ _~.~ ....~...,~..~. .~.~__..~~ ~..~..~ ~ 7/14/2009'*""JOB CONTINUED FROM 13-JULY-2009.*** ~ ~ ~ RIH W TS: HEAD/CAL-B/ 20 FT 3.38" HSD PJ 3406, 6 SPF, 18 FOOT LOADED. ; ~ ;TS LENGTH/MAX OD/ WEIGHT: 25 FT/ 3.38 IN/ 360 LBS. ~ ~ ~TAG UP AT SSSV. GET LRS OUT TO PUMP OPEN SSSV. PERFORATE ~ FROM 8852'-8870' WITH 3 3/8" POWERJET HSD CHARGES. ~ ~ =SURFACE INDICATION OF SHOTS FIRED. STANDING BY AT 200 FT IN THE ; ;HOLE DUE TO HIGH WINDS. WAITING FOR WINDS TO DIE DOWN. E ~ f ~ ~ ;"*'JOB CONTINUED ON 15-JULY 2009.**"' t~__. ~~ ~~_~_ ---_ _~~._. ___ ~.. ____ _ __ _____ __..-----_.._._----W-~ i 7/15/20093***JOB CONTINUED FROM 14-JULY-2009."" ~ ( l ~ ~STABBED ON WAITING ON WIND TO DIE DOWN ? ' ; ~ ~ j*""CONTINUED ON 7-15-09 WSR*** ~ ~., .~~ ___..., __. ~~ 7/16/2009~***JOB CONTINUED FROM 15-JULY-2009.*** ~~~ ~~~_.~m~e~e.o .. ___ _.. _~.~.~ PERF~RATE FROM 8842'-8852' WITH 3 3/8" POWERJET 6SPF HSD GUNS. ~ ; LOG CROSSFLOW LOG AND FIND THAT FLUID IS MOVING FROM BELOW 3 ~ ' PLUG TO PERFS AT 8822'-8842' AT 3 FPM OR 0.1 BPM 3 ' ;SET 3 3/8 BAKER CROSSFLOW IBP AT 8882' CENTER OF ELEMENT. TOP I _ =0F PLUG AT 8874.5' ELMD. ` ; `***JOB COMPLETED'*" ~ 3 ~ ~ ~ 7/17/2009~"** WELL SHUT IN ON ARRIVAL"*" ~RAN 3.50" CENT., 4-1/2" TEL, 3.50" LIB. LOC. TT @@ 8570' SLM (+19 CORR. ~ TO ELM @ 8589') ~TAG 3-3/8" IBP @ 8857' SLM/8876' ELM, (IMPRESSION OF IBP FN) ~""`CONT. ON 7/18/09 WSR*** 7/18/2009' ****CONT. FROM 7/17/09 WSR**** ~ DUMPED 2 BAGS OF SLUGGITS W/ 3.50" DUMP BAILER ''**y`WELL LEFT S/I, DSO NOTIFIED**** FLUIDS PUMPED BBLS 2 diesel 2 Total 03-20A (PTD #1930470) Internal Waiver Cancellation - Normal Well e e K~' lzlZ! JE6 Suhject: 03-20A (P""("1) +f 1(30470) Internal Waiver Cancellation -Normal Well I'rom: ":'\SU, ADW Well Integrity Engineer" <NSlJADWWelllntcgrityEnginccr@BP.com> Date: [\'10n, 1<) Dcc 2005 18:44:43 -0900 To: "i\OGCC - \Vinton Aubert (E-mail)..<winton_élubcrt@:admin.statc.ak.us>. jim rcgg@admin.statc.ak.us, "NSU, ADW Well Operations Supervisor" <NSLADWWeIlOperationsSupervisor@BP.com>, "Rossbcrg, R Steven" <Stc\'cn.Rossberg(il;£3P.com>, "GPB, FS2/COTU Arca Mgr" <GPßFS2TL~_i!BP.com>, "Kurz, John" <john.kur/.@BP.com>·, "GPB, FS2 DS Ops Lead" <GPBFS2DSOpsLead«~;BP.eom> cc: "NSU, ADW Wc1llntegrity Engineer" <:\SlJi\DWWclHntcgrityEnginecr@BP.com>, "NSU, ADW WJ Tech" <NSUADWWITech@BP.com>, "Phillips, Patti .I" <phillpjl@BP.com>, "Mielke, Robert 1.." <robcrLmiclke@BP.com>, "GPB, \Vclls Opt Eng" <GPBWcllsOptEng@BP.eom>, "GPB, EOe Specialists" <.GP13EOCSpccialists@ßP.com> All, An internal waiver was issued for TxlA communication on well 03-20A (PTD #1930470) on 03/24/04. The gas lift valves were dummied and the subsequent MIT-IA pass on 12/15/05. The wellhead pressures were T/I/O = 18001320/200. Slickline will set a new gas lift valve design so that the well may be put on production. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (901) 659-5102 Pager: (907) 659-5100 x1154 · 'If Ct~n\\!!\~r.:r "~1v ~t '.>,; \_;t~,· r: ~:,:" c 1 of 1 12/21/20054:34 PM ~ (STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD SuspendD Operation ShutdownD Perforate D WaiverD OtherD Alter Casing 0 RepairWellD Plug Perforations[&] Stimulate DTime ExtensionO Change Approved ProgramD Pull TubingD Perforate New PoolO Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 193-0470 Development ŒJ ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20980-01-00 7. KB Elevation (ft): 9. Well Name and Number: 53.83 03-20A 8. Property Designation: 10. Field/Pool(s): ADL-028328 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9336 feet true vertical 9277.3 feet Plugs (measured) None Effective Depth measured 8921 feet Junk (measured) None true vertical 8877.0 feet Casing Length Size MD TVD Burst Collapse Conductor 51 20" 91.5# H-40 29 - 80 29.0 - 80.0 1490 470 Liner 916 7" 29# 13Cr80 8420 - 9336 8392.2 - 9277.3 8160 7020 Production 1900 9-5/8" 47# N-80 29 - 1929 29.0 - 1929.0 6870 4760 Production 6177 9-5/8" 47# L-80 1929 - 8106 1929.0 - 8079.7 6870 4760 Surface 2616 13-3/8" 72# L-80 29 - 2645 29.0 - 2644.9 4930 2670 Perforation depth: Measured depth: 8771 - 8772,8772 - 8776,8776 - 8777,8781.1 - 8782,8782 - 8793.1,8794.1 - 8812.1,8821.1 - 8831.1,8832 - 8842 True vertical depth: 8733.96 - 8734.91, 8734.91 - 8738.71, 8738.71 - 8739.66, 8743.56 - 8744.41, 8744.41 - 8754.97, 8755.92 - 8773.05 8781.62 - 8791.14, 8792 - 8801.53 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13CrSO @ 29 - 85SO R E C E \VE 0 Packers & SSSV (type & measured depth): 4-1/2" Baker SAB Perm Packer @ 8529 . nn4 4-1/2" TRCF-4A SSV @ 2195 \~N 2 {) LUU 7" Liner Top Packer @ 7939 .. 12. Stimulation or cement squeeze summary: 01 &. Ga'5 0". Intervals treated (measured): Mas\c.a \ ~nchotaUe Treatment descriptions including volumes used and final pressure: 13 RePresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: 420 2.16 7575 1520 304 Subsequent to operation: 466 2.41 8054 1200 271 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best òf my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature I'" Ci- _. Phone 564-4657 Date 1/15/04 ~Çf~lN!~E( Jn~N 2 1 2004 R ¡ G I NA L RBDMS Bfl JAM 21 100~ Form 10-404 Revised 12/2003 i .. ,,~- . ( ( 03-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/28/03 FOUND BAKER IBP IN TBG @ ST A. # 8 @ 76581 WLM. KNOCKED DOWN TO 8326' WLM. UNABLE TO LATCH UP OR PULL AFTER SEVERAL ATTEMPTS LIB SHOWS PICTURE OF IBP FN ON HIGH SIDE OF HOLE LDFN. SECURE WELL. NOTIFY DSO. 08/29/03 Pull Baker IBP element from 83331 WLM. Several attempts made to latch up to IBP. LDFN 08/29/03 ***WELL SHUT IN UPON ARRIVAL***PULL BAKER IBP ELEMENT FROM 83331 WLM SEVERAL ATTEMPTS MADE TO LATCH UP TO IBP. LDFN. SECURE WELL. NOTIFY DSO. LEAVE SHUT IN. 08/30/03 IBP fish @ 8452' 08/30/03 ***WELL SHUT IN UPON ARRIVAL*** FISHED A inBROKEin FN? (1-3/411 00 X 2-1/211) LONG OFF OF TOP IBP FN. FROM 8333' WLM. UNABLE TO LATCH IBP FISH AFTER SEVERAL RUNS W/DIFF. CONFIG. OF TOOLS. SECURE WELL NOTIFY DSO RDMO. 09/02/03 SPEARED BLADDER ON IBP @ 8333' WLM. ( AFTER SEVERAL ATTEMPTS) IBP FELL TO 8452' WLM. UNSUCESSFUL IN RETRIEVING IBP SECURE WELL. NOTIFY DSO. LDFN. WILL CONTINUE IN AM. 09/03/03 ATTEMPT TO FISH OUT IBP W/ NO SUCCESS 09/03/03 Freeze protect flow line. Pumped 5 bbls neat meth155 bbls crude 5 bbls meth. 09/08/03 ATTEMPTING TO FISH IBP W/ MULTIPLE CONFIGURATIONS OF BELLGUIDE PULLING TOOLS AND OVERSHOTS (NO SUCCESS) 09/09/03 TI0=1700/1650/150 Assist slick line with I.B.P. retreaval. Pumped 140 bbls crude & 45 bbls diesel down TBG @ 5 BPM to displace. Final TI0=750/1800/180 09/09/03 ATTEMPT TO FISH POSSIBLE IBP RUBBER FROM AROUND TOP OF IBP @ 8453' W/ NO SUCCESS PUMPED 180 BBLS OF CRUDE TO TRY AND GET IBP TO GO OUT OF TUBING INTO LINER TAGGED IBP W/ 3.22in LIB @ 8457' indicating IBP Possibly went down only 4'. 09/10/03 T/I/0=1000/1575/160 Assist wireline. Pumped 307 bbls crude and 3 bbls diesel down tbg Final WHP=400/1575/200 09/10/03 T/I/O=1000/1575/160 ASSIST WIRELlNE. PUMPED 307 BBLS CRUDE AND 3 BBLS DIESEL DOWN TBG FINAL WHP=400/1575/200 09/14/03 T/I/0=1790/1580/140. Temp=SI. TBG FL. (Slick Line). TBG FL @ 4980' (76 bbls) 09/17/03 TI0=1700/1650/150 Freeze protect tbg & flowline. Pump 5 bbls of methanol 35 bbls of crude down tbg. Pump 5 bbls of methanol 155 bbls of crude 3 bbls of methanol down flowline. Pressure flowline up to 1500 psi. Final TI0=1200/1650/150 09/29/03 T/I/0=1600/1625/150. Spear 5 bbls meth followed by 293 bbls water mixed w.25 gals L-064 down tbg. Freeze protect tbg w/5 bbls meth & 40 bbls diesel. FWP=0/1400/140. 09/30/03 RUN VIDEO LOG TO 84671. PICTURE SHOWS WHAT APPEARS TO BE SECOND FISHING NECK LODGED AGAINST IBP FISH NECK. 10/12/03 ATTEMPTED TO FISH WHAT APPEARS TO BEFN FROM IBP W/ NO SUCCESS BEAT FISH FREE W/ 2" BLIND BOX, RAN DOWN TO 8600' SLM (TT @ 8580' MD) W/ NO PROBLEMS CURRENTLY RUNNING A 4-1/2" BRUSH THRU ALL GLM'S TO CLEAN UP ANY DEBRIS ***CONTINUED ON 10/13/03 WSR Page 1 . ( ~~~EAD= -ë; 03 20A I SAFETY NOTES: I ACTUA TOR = OTIS - KB. H.EV = 54' BF. H.EV = ? KOP = 6600' Max Angle = 18 @ 8751' DatumMD= 8897' 8) I 2195' 1 4-1/2"CAMTRCF-4ASSSV NIP. ID=3.813" Datum 1VD = 8800' SS GAS LIFT MANDRH.S I 9-5/8" CSG47# NT-80, ID = 8.681" I ST MD 1VD DEV TYÆ LATCH PORT DATE I 13-3/8" CSG 72#, L-80 ID = 12.347" I 1 2968 2968 0 TE- TGPD RK , 2 5113 5113 0 TE-TGPD TG 3 6004 6004 2 TE- TGPD TG Minimum ID = 3.725 @ 8567' 4 6269 6269 2 TE-TGPD TG 4 1/2" PARKER SWN NIPPLE 5 6686 6685 5 TE-TGPD TG 6 7067 7060 14 TE-TGPD TG 7 7373 7357 12 TE- TGPD TG I TOP OF 7" LNR 1-1 7920' 8 7676 7644 10 TE- TGPD TG -I 7" X 9-5/8" BOT LNR HGR W/H PKR I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1 4-1/2" PARKER SWS NIP, ID = 3.813" 1 4-1/2" PARKER SWN NIP, ID = 3.725" 1 14-1/2" TBG, 12.6#. 13-CR-80, 0.0152 bpf, ID = 3.958" 1 4-1/2" WLEG 1 H.MD TT LOGGED 04/28/93 1 PERFORATION SUMMARY REF LOG: SWS GRlCCL 04/28/93 ANGLE AT TOP ÆRF: 18 @ 8767' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 8771-8777 0 07/07/96 3-3/8" 4/6 8782-8812 0 07/07/96 3-3/8" 4/6 8822-8842 0 07/07/96 3-3/8" 4 8888-8894 0 02/02/94 -I CEMENT CAP (10/27/03) I 3-3/8" 4 8908-8914 0 02/02/94 3-3/8" 4 8920-8935 C 06/20/02 3-3/8" 4 8935-8940 S 01/24/94 -I 3-3/8" BAKER IBP (10/24/03) I I 7" LNR, 29#, L-80. .0371 bpf , ID = 6.184" 1-1 9336' I ~-I 9336' 1 DA TE REV BY COMMENTS DA TE REV BY COMMENTS PRUDHOE BA Y UNIT 04/22/93 LAST WORKOVER 09/30/03 BJMcN/TLH IBP FISH WH.L: 03-20A 01/08/01 SIS-LG REVISION 11/25/03 BJMcN/TLH IBP, SAND & CMT CAP ÆRMrr No: 1930470 02/11/01 TP CORRECTIONS API No: 50-029-20980-01 05/03/02 GC/KAK REFERENCE LOG SEC 10, TION,R15E 352.65 FEL 5063.61 FNL 06/20/02 TMN/TLH SET IBP 08/09/02 BHC/KK ÆRF CORRECTION BP Exploration (Alaska) MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor State of Alaska L~ Alaska Oil and Gas Conservation Commission DATE: January 15, 2001 o,, t ~..-o t, FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site 03 Janua .ry 15, 2001' I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-14-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat Or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15-00jc cc; NON-CONFIDENTIAL SVS PBU DS 03 1-15-01jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Womble AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field DS 03 Separator psi: LPS 185 HPS 1/15/01 69O ' -- ~ - ' ......... -- .................. 2'~"fl'll~ill'mt' Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 03-01 1750750 185 150 100 P P OIL 03-02 1760240 185 150 120 · P P OIL 03-03 1760390 185 150 110 P P OIL 03-04 1760510 03-05 1760570 03-06 1760600 03-07 1760530 03-08 1760730 185 150 130 P P OIL 03-09 1790220 185 150 100' P P OIL 03-10 1790210 03-11 1790470 03-12 1790580 03-13 1790710 03-14 1790820 185~ 150 100 · P P OIL 03-15A 1930150 185 150 100 P P OIL 03-16A '1970330 03-17 1791020 03.18A 1930420 03-19 1830920 185 150 90 P P OIL 03-20A 1930470 185 150~ 1001 P P OIL b3-21 1831120 185 150 100 P P OIL 03-22 1831230 690 600 420 P P OIL 03-23 1831270 185 150 0 1 P OIL 03-24A 1980060 690 600 530 P P OIL 03-25A 1930230 03-26 1831510 185 150 110 P P OIL 03-27 1840620 185i 150 100 P P OIL 03-28 1840720 '03-29 1840790 185 150 110 P P OIL 03-30 1840830 185 150 90 P P OIL 03-31 1840920' 185 150 140 P P OIL 03-32A 1940540 185 150 110 P P OIL 03-33A 1970390 03-34B 2000110 185 150 0 1 P OIL 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15-01c.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 03-35 1910800 185 150 90 P P OIL 03-36 1930190 Wells: 21 Components: 42 Failures: 2 Failure Rate: 4.8% E39o var Remarks: 1/18/01 Page 2 of 2 SVS PBU DS 03 1-15-01c.xls i ,'-~'~-~, STATE OF ALASKA ALASKA G,,_ AND GAS CONSERVATION COlV,,,,,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging , Perforate ,X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 194' NSL, 422' WEL, Sec 10, T10N, R15E, UM. At top of productive interval 197' NSL, 192' WEL, Sec 10, T10N, R15E, UM. At effective depth At total depth 236' NSL, 353' WEL, Sec 10, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-20A 9. Permit number/approval number H 93-47 10. APl number 50 - 029-20980-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9336 feet Plugs(measured) PBTD Tagged @ 8939' MD (6/4/96). true vertical 9278 feet Effective depth: measured 8939 feet true vertical 8894 feet Junk(measured) 0RJ~INAL Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2325# Poleset 80' 80' Surface 2583' 13-3/8" 2100 Sx CS III & 400 Sx CS II 2645' 2645' Production 8094' 9-5/8" 500 Sx Cl G & 250 Sx CS I 8156' 7890' Liner 1416' 7" 295 cuff CIG 7920 - 9336' 7655 - 9276' Perforation depth: measured 8771 - 8777'; 8782 - 8812'; 8822 - 8842'; 8888 - 8894'; 8908 - 8914'; 8920 - 8935' true vertical 8734 - 8740'; 8744 - 8773'; 8782 - 8801'; 8845 - 8851'; 8864 - 8870'; 8876 - 8890' Tubing (size, grade, and measured depth) 4-1/2", 12.64¢, 13CR-80, Tbg @ 8580' MD. Packers and SSSV (type and measured depth) H Packer @ 7939' MD; Baker Perm Packer @ 8529' MD; Camco TRCF-4A SSSV @ 2195' MD. ..... C-iV'E- 13. Stimulation or cement squeeze summary ~'.~ ~._.. I'~. !.? 14. Intervals treated(measured) see Attached AU Treatment description including volumes used and final pressure , , ^~ ,,,~,l,,n n!l P,, P.,n.~ ¢,nn~, Commission Reoresentative Daily Average Production or Injeqti¢n I;)at~' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 616 3398 7138 -- 352 Subsequent to operation 1'5. 'Attachments Copies of Logs and Surveys run Daily Report of Well Operations 636 2368 7448 -- 324 16. Status of well classification as: Oil X Gas . Suspended..._ Service, 17_ I horel3y certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,~ ~ . ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 cc: JWP. Date ~'- /~, - ~'~ SUBMIT IN DUPLICAT.[..~ 3-20A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/4/96: RIH & tagged PBTD at 8939' MD. 7/7/96: MIRU & PT equipment. Added Perforations: Reperforated: RIH w/perforating guns & shot 34' of perforations as follows: 8771 - 8772' MD (Z4) 8794 - 8812' MD (Z4) 8832 - 8842' MD (Z4) 8772 - 8777' MD (Z4) Used 3-3/8" carriers & shot at 6 spf at 60 degree phasing at underbalanced pressures. POOH w/perf guns. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. PERMIT 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 93-047 DATA 5680 568O 407 DWOP SURVEY SURVEY SURVEY SURVEY AOGCC Individual Geological Materials T DATA_PLUS Well Inventory BHC/AC/GR CNL/GR DB TDTP DB TDTP DLL/GR/SP JEWL/GR/CCL 93-047 PERF 93-047 PERF 93-047 PERF 93-047 PERF 93-047 PROD T DLL/AC/CN/GR ~f/8129-9341DLL/AC/CN/GR Q~/COMP DATE:04/28/93 ~04/05-04/22/93 ~8110-8710 ANADRILL ~8110-9300 SPERRY SUN 93-047 93-047 ~ 8110-8710 ANADRILL ~R/8110-9300 SPERRY SUN PROD/SPIN/TEMP/ SBT/GR/CCL 8129-9341 t~8129-9284 ~L/8700-9103 ~8129-9308 ~L~7600-9299 93-047 SSTVD ~L~8700-9100 b/~ 8680-9218 ~8450-9155 (.~/8650-8936 ~650-9000 ~'~1800-3049 8129-9341 Page: 1 Date. 01/12/95 RUN DATE_RECVD 06/07/93 1 06/28/93 09/07/93 09/07/93 08/31/93 09/13/93 09/07/93 09/07/93 1 05/06/93 1 05/06/93 1 09/13/93 1 03/18/94 1 05/06/93 1 05/10/93 1 05/10/93 1 12/15/93 1 03/18/94 1 03/18/94 1 10/12/94 1 09/13/93 1 05/10/93 1 05/06/93 AOGCC Individual Well Geological Materials Inventory Page · 2 Date: 01/12/95 PERMIT DATA T DATA_PLUS RUN DATE_RECVD Are dry ditch samples required? yes ~LAnd received? yes~~ Was the well cored? yes ~~alysis & description received? ~ no Are well tests required?!l yes Received? ye Well is in compliance ~ Initial COMMENTS BOO W. International Airport Road Anchorage, AK 99618-1199 ' NO. 8989 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1.10 ~ 'L~ ~ ' PERF RECORD ..... 9-29-94) ......... .......... , ,, 1 1 ..... D.S. 3-20A Z ~,~. ~ PROD. LOG (9-30-94) ..... 1 1 ., , D.S. 3-21 ~" '~ -- I I ~ LEAK DETECTION (9-28-94) 1 1 D.S. 3-32A ' ~/~{ -(.~-_.~"~ PERF RECORD (10-1-94) ... 1 I" 1'" D.S. 13-2A'~:i(~ "'~-~ PROD PROFILE (9:28-9,4) .... 1 ............ 1 D.S. 16-09A . ,~' (,-- ~ ~ PROD LOG (9-30-94) 1 , . 1 ....... D.S. 15-7A ~ el/---- e) }l GR-OOL (101~94) .... 1 1 D.S. i5-33 ,, ~Z.//.-O~/' GR-OOL(10-1-94) ........ 1......... 1, . SIGNED: Please sign and retum or~e copy of this transmiUai to Sherrle at the above address. Thank you.' 10/12/94 STATE OF ALASKA ALASKA " AND GAS CONSERVATION CC ,/IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X ,, Pull tubing AItercasing Repair well Other X ,, 2. Name of Operator ARCO Alaska, I.nc; 3. Address 5. Type of Well P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 194' NSL, 422' WEL, Sec. 10, T10N, R15E, UM At top of productive interval 197' NSL, 192' WEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 236' NSL, 353' WEL, Sec. 10, T10N, R15E, UM 1"2. Present well'condition summary Development X · Exploratory . Stratigraphic Service , RECEIVED 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-20A 9. Permit number/approval number 93-47 10. APl number 50 - 029-20980-01 11. Field/Pool Prudhoe Bay Oil Pool feet Total depth: measured 9336 feet true vertical 9278 feet Effective depth: measured 8832 feet true vertical 8699 feet Casing Length Size Conductor 80' 20" Surface 2583' 13-3/8" Production 8094' 9-5/8" Liner 1416' 7" Plugs(measured) Fill @ 8832' MD (5/26/94) Junk(measured) Cemented 2325# Poleset 2100 sx CS III & 400 sx CS II 500 sx CL G & 250 sx CS I 295 cu ft CL G Measured depth True vedicaldepth 80' 80' 2645' 2645' 8156' 7890' 7920-9336' 7655-9276' Perforation depth: measured 8782-8794'; 8822-8832'; 8888-8894'; 8908-8914'; 8920-8935' true vertical 8745-8756'; 8783-8793'; 8848-8853'; 8866-8872'; 8878-8892' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr-80, w/tail @ 8580' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" pkr @ 7939, Baker 7" Permanent pkr @ 8529' MD, Camco TRCF-4A SSSV @ 2195' MD 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 In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 506 780 4979 -- Subsequent to operation 628 1653 5940 -- Tubing Pressure 302 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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 /~~ ~~ .~ ~. b.~,,.~x.~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 1118/9 AJB/JCA cc: JED, JWP Date ~"-Z.~' ~y ~ SUBMIT IN DUPLICAT~ 3-20A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES FOR WATER SHUTOFF & FRACTURE TREATMENT OF ZONE 4 10/18/93: RIH & tagged PBTD at 9260' MD. 11/1/93: MIRU CTU & PT equipment. Loaded the wellbore w/Seawater, then RIH w/CT & reciprocated an Acid Wash across the open perforations located at: 8772 - 8776' MD (Z4) 8782 - 8794' MD (Z4) 8888 - 8894' MD (Z4) 8920 - 8940' MD (Z4) Pumped 25 bbls of 12% HCI w/10% Xylene @ 2.1 bpm, followed by 25 bbls of 6% HCI - 0.75% HF w/3% Acetic Acid @ 1.5 bpm, followed by 135 bbls NH4CI Water, followed by 70 bbls inhibited Seawater. Continued pumping 11 bbls Latex Acid Resistive Cement, followed by 18 bbls Superfine Cement, followed by another 24 bbls Latex Acid Resistive Cement, to squeeze the perforations (listed above). Placed 31 bbls of cement behind pipe, and attained a maximum squeeze pressure of 2200 psi. Held a final squeeze pressure of 1550 psi for 30 minutes, after repeated pressure breaks from 2050 - 2200 psi. Contaminated cement w/biozan & jetted contaminated cement from the wellbore. POOH w/CT. Rigged down. 11/9/93: Reperforated: 8888 - 8894' MD (Z4) 8920 - 8940' MD (Z4) 1/24/94: MIRU CTU & PT equipment. Loaded the wellbore w/Seawater & Crude, then RIH w/CT & pumped 10 bbls Latex Acid Resistive Cement, followed by 18 bbls Superfine Cement, followed by another 33 bbls Latex Acid Resistive Cement, to resqueeze the perforations (listed above). Placed 9 bbls of cement behind pipe, and held a maximum squeeze pressure of 3500 psi for 90 minutes. Contaminated cement w/biozan & jetted contaminated cement from the wellbore. POOH w/CT. Rigged down. 2/2/94: Reperforated: 8888 - 8894' MD (Z4) 8920 - 8935' MD (Z4) Added perforations: 8908 - 8914' MD (Z4) 2/17/94: Reperforated: 8782 - 8794' MD (Z4) Added perforations: 8822 - 8832' MD (Z4) 3/12/94 - 3/14/94: Pumped 23 bbls of Gelled Sand Slurry to place a sand plug over the lower perforations, to 8853' MD. 3/15/94: MIRU & PT equipment to 10000 psi. Pumped a Frac Treatment through the perfs above the sand plug (above), consisting of 225 bbls 20# Pre-Pad Gel @ 40 bpm, followed by Shutdown. ISIP @ 1900. Resumed pumping 919 bbls Crosslinked Pad @ 40 bpm, followed by 1091 bbls of Crosslinked Slurry in 1 - 10 ppg proppant stages, followed by Shutdown. Placed a total of 179,000 lbs of proppant into the formation. RD. 3/19/94: Performed a proppant fill cleanout to 8915' MD. Returned the well to production w/lift gas & obtained a valid production test. ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, /~'"",~orage, AK Mar 15,' 1994 Transmittal #: 94029 John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510~ ~, Well i Log Date Tool Type i Run, Contractor Nurrber (M-D-Y) Scale ~-t\c~ [ 01-02!2-26-94 Prod/Spin/Temp[~ 1,5" Schlumber --i'o-- t~ i 01-03 i 2-19-94 Prod~::BS/Temp ~.'~'~ 1, 5" Schlumber "~-7(0 ! 01-09 I 3-01-94 Tubing Cutter ~ 1, 5" Schlumber Or'~-- $~ ! 01-11 f 2-27-94 Prod Prof/Spin I 1,5" Schlumber ~c~- Ici i 01-18I 2-23-94 Leak Detection I 1, l"& 5" Schlumber ~.- ?J~ ! 01-25 I 3-06-94 CNL I 1, 5" Schlumber q'~- j,/03-20A i 2-17-94 Perf ! 1, 5" Schlumber .i~03-20A i 3-03-94 Dual Burst '~¢)[~ 1, 5" Schlumber ~O~ 03-32 I 2-26-94 Leak/Press/Tempi 1,,2" Schlumber ~ i 03-34A 2-24-94 Prod/Press/Tempi 1, 2"&5" Schlumber ~?- i 04-01 2-19-94 Prod 1, 5" Schlumber 80~* 04-24 2-22-94 PrOd ! 1, 5" Schlumber -['~[ ! 04-40 2-22-94 Perf ! 1, 5" Schlumber ~_~ ~ 04-46 2-16-94 Rope Perf I 1, 5" Schlumber t2'~ !~04-47 2-18-94 v perf I 1,5" Schlumber 4-47 '2-15-94 '/CBT-GR 1, 5" Schlumber i ~,04-47 2-15-94 v CET-GR 1, 5" Schlumber 50 05-06 2-11-94 Perf 1, 5" Schlumber ~ 05-14A 7-11-93 USlT/Cem&Corr (.'j~"~l, 5" Schlumber c/-;/. 05-15A i 05-15A cC~ ~ND/GR-~>~,¢. 1, 5" Schlumber lt"~ 05-26 3-02-94 Dual Burst 1'o'[~ 1, 5" Schlumber ~?.. / 06-15 2-21-94 Prod 1, 5" Schlumber \ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 5~ 06-22A 3-01-94 Perf 1, 5" Schlumber ~1o [ 07-08 3-02-94 Prod~e~ ~1, 5" Schlumber - 07-23 3-07-94 Leak/Spin/Temp)~!~ 1, 5" Schlumber i 09-34 2-21-94 Tubin9 Cutter ~. 1, 5" Schlumber ['"C~ .11-02 2-10-94 Inj Prof/~ ~l~l'~, 5" Schlumber ~ / 11-04 2-20-94 Tubing] Cutter r~'-'"l ,5" Schlumber i~11-04 2-17-94 Tubing ~r~ ~ ~v_J, 5" Schlumber ~.--+~. 11-7ST 3-06-94 Inj Prof/Spin ~c~l~'~._ 1, 5" Schlumber / 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ! 16ST /Spin/~c.~b ~--'[t X,~ll 1- 3-08-94 Comp/l~l~table 1,5" Schlumber k-"cl ,,~11-17 ,2-20-94 Leak 1, 5" Schlumber 1-17 3-08-94 Prod 1, 5" Schlumber ~t% 11-23 8-09-91 TMD 1, 5" Halliburton ~ ~11-24A 3-05-94 Perf/GR/CCL 1, 5" Schlumber J~11-24A t 2-22-94 Comp/Perf 1, 5" Schlumber i ARCO Alaska, Inc. I$ · ~ub~l~m'y of All~ttlcFIlchfbldComp.ff Z.~ J 12-01 tL~ ! 13-10 ~ ! 14-2B i 14-2B I I 14-2B ~ ~ 14-2B t ,, l 14-2B ~ 14-2B i . 4-2a :~ I 14-24 3-06-94 2-24-94 1 - 16-94 1-16-94 1-16-94 1-16-94 1-19-94 1-23-94 1-23-94 2-19-94 Prod Perf CNL/GR Sub-Sea Bi-Ok Acoustilo,g t~ 1 Dual Latedog/GR/ ~ Seg Bond/GR PFC/GR/CCLI i 1, 1"&5" i 1,5" ! 2"&s" i 1, 1"&2" , 2"&5" Schlumber Schlumber Schlumber Schlumber Schlumber 1, 5" Schlumber 1, 5" Schlumber 1, 5" Schlumber PFC/Collar t 1, 5" bea~ f 1, 5" Leak i 1, 1"&5" Prod/Press/Tempi 1, 2"&5" Schlumber ,, Schlumber 14-28 3-05-94 14-34 2-15-94 16-08 3-07-94 17-21 PWDW 02-01 2-24-94 2-09-94 Prod Prof/Spin I 1, 2"&5" Perf i 1, 2"&5" Water ~ 1, 5" Inj/FBS/Templ~-{ Well 4-24 the correct APl # is 50-029-21508-00 Schlumber Schlumber Schlumber Schlumber Schlumber 20o0-10Ol00 lo550-tt Number of Records: John F. DeGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon stat6bf AlaSka ~ . Mobil Please acknowledge receipt by signing and retuming a copy of transmittal. RECEIVED ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, Transmittal #: 94023 ~orage, AK Subject: ARCO Case~ From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well i Log Datei Tool Type i Run, Contractor Number (M-D-Y) , Scale 1-24A i 12-24-92 I PFC/GR I 1, 5" Atlas i PWDW I 01'24'94 Static press/TemP2-1 1,5"q~0~_ .'/3-1 1-30-94 Pen` Record 1, 5" Sch '"% 3-1 t 2-5-94 CNL 1, 5" Sch 3-20A i 2-2-94 I Pen' Record 1, 5" Sch 3-21 I 2-4-94 I Compi Record 1, 5" Sch i 3-25A i 2-4-94 Compi Record 3-27 f 2-3-94 t Prod Rrofile i 3-32 i 1-25-94 ~ Bridge Plu~] ~I 1, 5" Sch f 4-5 I 1-26-94 Tubin~ Cutter ~, 1, 5" Sch !/4-:~2 I 2-2-94 CompI Record ~, '4-46 i 2-6-94 1 USIT/Cement 4-46 f 2-6-94 PDC&Jewerly 1, 5" Sch J "5-35 ! 2-7-94 LeakDetec ~" 9-9 ! 2-7-94 Leak Detec 9-9 f 1-26-94 Leak Detec f 1, 1"&5" Sch 9-11 i 1-24-94 Bridge Plug~t~t~.c. 1, 5"(~? 9-13 1-29-94 {~ Brid~]e Plu~] 9-20 1-24-94 Mi Inj Profile 9-34 1-25-94 ~1 Brid~e Plu~ 11- I 2-3-94 b~ Bridge Plug&~.~ 1, 5" Sch 16ST1 11-17 2-5-94 Leak Detec 1, 1"&5" Sch f 12-16A 2-2-94 Pen' Record ~'~14-2B 2-3-94 USIT/Cement 1, 5" Sch ~,,,14-2B 2-4-94 Pen' Record 1, 5" Sch 14-31 2-4-94 Prod Profile 1, 5" Sch 15-9A 2-6-94 Pen' Record 1, 5" Sch 15-22 2-6-94 Pen' Record 1, 5" Sch 16-7 6-16-92 Casin~] Collar 16-22 2-3-94 Gas lift survey/ 16-29A ~ 1-31-94 Prod Log DS# 1-24ST the correct well name is 1-24A DS# 11-16ST1 the correct APl# is 50-029-21581-00 Number of Records:32 John E. DeGrey ARCO Alaska, Inc. la a Subsidiary of AtlantlcRIchflMdC;:omp~ny ARCO Alaska, Inc. P.O.Box 1OO360 Anchorage, Alaska 99510 DATE: 12-2-93 REFERENCE: ARCO CASED HOLE FINALS ------- 10-31-93 Z~ 1-4 11-5-93 1-16 11-5-93 ~1-22 .11-7-93 -24A 10-14-93 -26 10-31-93 10-31-93 ~--~~-32 10-31-93 -19 10-17-93 -20A 11-9-93 o~;-~, 11-2-93 -4t~' 11-4-93 - 11 11-8-93 -21 10-18-93 ~ 4-23A 11-2-93 ~7-29 11-4-93 /9-7 10-20-93 ~U~-~~ 9-7 10-25-95 9-49 11 - 1-93 "~-~~--50 11-1-93 1-12 ~~1-12 11-9-93 11-9-93 1-16ST 11-8-93 /12-16A 10-26-93 ~2~,12 - 16A 11-8-93 12-16A 11-8-93 ~(~~13-2A 11-2-93 ~~14-2 11-7-93 ~ ~L_ 14-4 11-6-93 ~I::~39A 11-10-93 10-19-93 and return the attached copy as RECEIVED By__~~_~ ~ Have l Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA Perf Record ]O~ % -ll007. Run 1, ~' Sch Perf Record ~/-~ ~:b~J~ Run 1, 5" Sch D~ B~t T~P ]1~0--1160~ R~ 1, ~' Sch Pe~ Record qT~0~10~Z~ R~ 1, ~' Sch Pe~ Record 5~0-q%~ R~ 1, ~' Sch Completion Record %~0%~a~ R~ 1, ~' Sch USIT (Co~i~(~,a~ Color R~ 1, ~' %700'N0100 Sch Peal Record ~5%~_~Z%% R~ 1, ~' Sch TBG Patch Record R~ 1, ~' '?~0-TL~ Sch ~od ~o~e~a~y~/l~-~/~ R~ 1, 1'&5" 0'-I 50~ Sch Collar (Packer Set) . R~ 1, ~' ~0~7~-/0q%~ Atlas D~ B~st TDTP iL~O-{%oaO R~ 1, ~' Sch Pe~ Record %~0~qgb0 R~ 1, ~' Sch Pe~ Record I~%--~ R~ 1, ~' Sch ~od ~offie t%ha ~rs~}~]~P~R~ 1, 1"~" ~l~-~ Sch IBP Set ~00~L~o R~ 1, ~' Sch Leak Det~ct/~0t0}~)~ R,~ 1, 1" 0-~ Sch ~od ~o~e [~ ~)~~~ 1, ~' ~So~165 ~ 5 Sch Pe~ Record ;10~ ~~,O R~ 1, ~' Sch CNL ~%~ 00- ~9~ R~ 1, ~' Sch Pe~ Record i [~ a0 ~ 1%%~ R~ 2, ~' Sch ~ Detect ~0~[~O R~ 1, 1"&5' Sch USIT/ce~.aT~~]Color R~ 1, ~' ~0 ~1 ~ Sch Peal Record ~9~ R~ 1, ~' Sch L~er/Jewe~/G~ R~ 1, ~' ~7~0-~0~ Sch ~ Detect (~]~~ ~ 1, T'~" 0--%~o Sch ~od ~offie l~~e)e~~~ 1, 1"~" O-~0%L Sch TBG ~cher Zu~-a95o R~ 1, =' Sch Pe~ Record ~O0 ~0~% R~ 1, ~' Sch D~ B~st TDTP R~ 1, ~' Sch receipt of data. # MOBIL The correct API# for 3-20A is 50-029-20980-01. This log was ran on 4-11 not the sidetrack and the correct API# is 504)29-20286-00. The correct API# for !)-7 is This log was ran on 12-16A and the correct API# is 50.029-20899-01. he correct API# for 18-29A is 50-029-22316-01. STATE OF ALASKA AI_~SKA AND GAS CONSERVATION CO'~IlSSION REPORT SUNDRY WELL OPErlATIONS::; 1. Operations performed: Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Stimulate Plugging Perforate X Repair well Other 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 194' NSL, 422' WEL, Sec. 10, T10N, R15E, UM At top of productive interval 197' NSL, 192' WEL, Sec. 10, T10N, R15E, UM At effective depth At total depth 236' NSL, 353' WEL, Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-20A 9. Permit number/approval number 93-47 10. APl number 50 - 029-20980-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9336 feet 9278 feet Effective depth: measured 9294 feet true vertical 9238 feet Casing Length Size Conductor 80' 20" S u dace 2645' 13 -3/8" Production 8156' 9-5/8" Liner 1416" 7" Plugs(measured) Junk(measured) Cemented 2325# Poleset 2100 sx CS III & 400 sx CS II 500 sx CL 'G'& 250 sx CS I 295 cu ft CL 'G' Measured depth 80' 2645' 8156' 7920'-9336' True veHicaldepth 80' 2645' 7890' 7655'-9276' Perforation depth: measured 8772'-8776';8782-8794';8888-8894';8920-8940' true vertical 8736-8740' ;8745-8756' ;8848-8853' ;8878-8897' Tubing (size, grade, and measured depth) 4-1/2",12.6#,13CR-80,w/tail @ 8580' MD RECEIVED NOV 1 6 199~ Alaska Ull & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 9-5/8"x7" H pkr @ 7939,Baker 7" Permanent pkr @ 8529' MD, Camco 'TRCF-4A' SSSV @ 2195' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 - 3313 3783 1241 Tubing Pressure 0 285 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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 ~~,.,,.~._. b ~ Title FS-2 Senior Engineer Form 10-404 Re~ 06/15/88 Date SUBMIT IN DUPLICATE .tHY REPORT OF WELL OPER. iONS DS 3-20A Perforating Operations: ARCO Alaska, Inc. perforated DS 3-20A at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 4/28/93. The intervals perforated were the following: 8772'- 8776', 8782'- 8794', 8888'- 8894' and 8920' - 8940' MD (Reference Log: AWS-BHCS dated 4/13/93). Completion fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 4/28/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH, opened well to flow and perforated 8920'-8940' MD at 4 SPF, SI well, POOH, and confirmed all shots fired. RIH, opened well to flow and perforated 8888'-8894' MD at 4 SPF, Logged up and perforated 8772'-8776' MD at 4 SPF, SI well, POOH, and confirmed all shots fired. RIH, opened well to flow and perforated 8782'-8794' MD at 4 SPF, SI well, POOH, and confirmed all shots fired. (ref: AWS-BHCS of 4/13/93).Rigged down and secured well. RECEIVED Gas Gong. Commissio~ Anchorage RDC: 9/29/93 ARCO .~l,,ska, Inc. P.O.Box 100360 Anchorage, Alaska 995 10 DATE: 9-10-93 REFERENCE: ARCO DIRECTIONAL DATA c{~. ~L 3-18A 4-24-93 Electronic Multi-Shot Survey Job~~ Sperry q~-1~-/ 3-20A 4-14-93 Electronic Multi-Shot Survey Job~~2 Sperry c~%_~ 5-3A 5-26-93 MWD Directional Survey Aha c[~-~2- 5-14A 626-93 MWD Directional Sm-vey Ana c/~_~ 5-15A 6-26-93 MWD Dire~o~ Survey Aha c{%-5~ 6-22A 4-30-93 MWD Directionsl Survey Aha c/.~. q0 18-29A 4-26-93 MWD Directional Survey Ana q 1;1-- {~5 AGI-3 4-14-93 MWD Directional Survey Job~ 1163 BHI c~._ 1~ AGI-4 4-14-93 MWD Directional Survey Job~1168 BHI q~-27 AGI-7 4-28-93 MWD Dlrectionni Survey Job~ 1185 Teleco /AGI-9 3-17-93 MWD Directional 8ttrvey Job#1195-450 BHI ~5 <,,,AGX-9 ~ alva) Directional Survey joi~96-4~o Bm Please sign and return the attached copy as receipt of data. y Have A Nice Day! Sonya Wallace APPROVED~ ATO- 1529 Tr~ns# 93 102 CENTRAL FILES CHEVRON D&M # CLIN CHAPMAN # EXXON MARATHON MOBIL # PB WELL FILES R&D #BPX # ST. OF Al~; (2 COPIES) TEXACO # LUCILLE JOI~NSTON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ARCO CASED HOLE FINALS ~- I~ 1-6 7-31-93 ?~_r:~ 1-12 7-27-93 ~- i~6 1-29 7-27-93 q~'q'? ~3-20A 8-1-93 ~-~ 6-6 7-26-93 to~o 6-13 7-30-93 ~q- 2t ~ * 11-13A 7-28-93 %tt-~ 12-26 7-29-93 ~1-~;~ 13-7 7-30-93 9~- ~Z$ ** 14-22A 7-31-93 ~z-~-~ 15-4 7-27-93 ~'-~ 15-6 8-2-93 q~-~ 15-24 7-27-93 ~~ 15-25 8-3-93 ~-~ *** 16-6 7-30-93 ~'~ 17-1 8-1-93 ~i-~.~ 17-7 8-3-93 ~-~.c~ 17-9 8-2-93 Production log Production Perf Record~gqz-q~to Production ~ Burst TDTP Perf Record Perf Record Perf Record9%v Perf Record Perf Record Pe~ Record ~So-izt~O ~ B~t ~ ~ B~t ~ 1, 5" to~c~-~ I?~ch 1, 5" Sch 1, 2"&5" Sch 1, 5"~05~-~ tsoSch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" 1, Please sign and return the attached copy~ as receipt of data. RECEIVED B¥_~~ Have A Nice Day! Sonya Wallace APPROVED ATO- 1529 Trans# 93081~ CENTRAL # CHEVRON PB WELL FILES # CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA MARATHON TEXACO # MOBIL The correct API# f~r 11-13A is 504)2~212~1 not 5~12~21229-01. The correct API# for 14-22A is ~)-02~20747-01. The .A. pI# fur 1~6 is 5O-O'29-2O584. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 SEPTEMBER 7, 1993 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 93-0002 PRUDHOE BAY UNIT AGI-5 COMPLETION REPORT. 93-0009 PRUDHOE BAY UNIT AGI-6 COMPLETION REPORT 93-0082 PRUDHOE BAY UNIT DS5-14A COMPLETION REPORT 93-0047 PRUDHOE BAY UNIT DS3-20A COMPLETION REPORT 93-0057 PRUDHOE BAY UNIT DS6-22A COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. MAY AND JUNES MONTHLY PRODUCTION i'~REPORTS INDICATE THAT THESE WELLS ARE GAS INJECTORS AND OIL PRODUCERS FOR YEAR 1993. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE MENTIONED WELLS. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-47 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20980-01 4. Location of well at surface 9. Unit or Lease Name 194'NSL, 422' WEL, SEC. 10, TION, R15~ '0kPLETION I Prudhoe Bay Unit At Top Producing Interval~~ L ATE ~; .1~3'20A ~~[ 10. Well Number, 197'NSL, 192' WEL, SEC. 10, TION, R1 ti. Field and Pool At Total Depth t--~~'- ! t: Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.83' I ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions I 4/10/93 4/13/93 4/28/93 N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set ~1. Thickness of Permafrost I 9336'MD/9278' TVD 9294' MD/9238' TVD YES [] NO [] 2195' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run Run #1 GR/DLI../AC/CNL Run #2 SBT/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surface 80' 30" 2325 # Poleset 13-3/8" 72# L-80 Surface 2645' 17-1/2" 2100 sx CS 111/400 sx CS II 9-5/8" 47# L-80 Surface 8702' 12-1/4" 500 sx "G"/250 sx CS I 7" 29# L-80 7931' 9336' 8-1/2" 295 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MD) Gun Diameter 3-3/8" 4 spf 4-1/2", 13CR 8580' 8529' MD TVD 8772'-8776' 8736'-8740' 8782'-8794' 8745'-8756' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8888'-8894' 8848'-8853' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8920'-8940' 8878'-8897 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 5/1/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MGF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips. RE( EIVED $ EP - ? 1993 Alaska 0il & Gas Cons. CommisstO~' Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ~-,.,'RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag River 8695' 8662' Top Shublik 8695' 8662' Top Sadlerochit 8767' 8732' Zone 3 8947' 8904' ,AJasJ(a. Oil & Gas Cons. Com,mj,~siu~ 31. LIST OF ATTACHMENTS .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'/~I~/ ~)-¢~ Title Drillino Enoineer Suoervisor Date _ _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 3-20A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/05/93 02:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 04/05/93 ( 1) TD: 9270 PB: 8857 RIG UP LUBRICATOR MOVING RIG TO 3-20A, R/U LUBRICATOR MW: 0.0 04/06/93 (2) TD: 9270 PB: 8857 04/07/93 (3) TD: 9270 PB: 8857 04/08/93 (4) TD: 9270 PB: 8857 04/09/93 (5) TD: 8156 PB: 8323 04/10/93 (6) TD: 7982 PB: 7956 POH, L/D 5-1/2" TBG MW: 0.0 PULL BPV, NO PRESSURE ON TBG, CIRC FREEZE PROTECTION F/WELL, SET BPV, N/D TREE, N/U BOPE & TEST, PULL TBG HGR TO FLOOR, TBG PULLED FREE, APPEARS PARTED DOWNHOLE, CHG SEALS ON TBG HGR, ALIGNMENT PIN WON'T BACK OUT, RERUN TBG HGR, ATTEMPT TO TEST BOPE, UNABLE TO HOLD TEST PRESSURE, LEAKING PAST TBG HGR, PULL HGR TO FLOOR, TEST BOPE, STACK LEAKING IN FLANGE, CHG OUT GASKETS, TEST - OK, POH W/5-1/2" TBG RIH W/GRAPPLE MW: 0.0 POH W/5-1/2" TBG, M/U FISHING BHA #1, RIH TO 6392' WASH F/6392'-6547', JARS FIRED, TBG PARTED, POH W/TBG, RU & RIH W/ATLAS W/L JET CUT TBG @ 8323', RIH W/OVERSHOT MILLING 9-5/8" CSG SECT MW: 0.0 CUT & SLIP DRLG LINE, RIH TO 6518', R/U SINGLE, RIH TO 6950', KELLY UP, TAG FISH @ 8071', PULL FREE, CBU, GAS RETURNS @ 2300 3TK3, POH W/TBG, R/D TBG & FISHING EQUIP., TEST 9-5/8" CSG TO 3500 PSI F/30 MINS, TEST OK, M/U MILLMASTER, DISPLACE WELL WITH MILLING FLUID, SPOT 18 PPG PILL @ 8297', POH TO 8106', START MILLING F/8106' RIH W/MULESHOE F/KO PLUG MW: 0.0 MILL 9-5/8" CSG F/8114'-8139', PUMP HI VIS SWEEP, POH W/MILLING BHA #1, L/D MILLMASTER, RIH W/5" DO W/MULESHOE, P/U DP DRLG CMT @ 7982' MW: 9.7 KC1 P/U DP F/7176'-8106', CBU @ TOP STUB, RIH F/8106'-8256', CBU, PREP RIG FLOOR FOR PUMPING KO PLUG, PUMP 32 BBLS "G" CMT(180 SX YIELD .982 CU FT/SX) PULL 17 STDS 5" DP, PERFORM SQUEEZE TO 2000 PSI, REV CIRC, PUMP DRY JOB, POH, PULL WEAR BUSHING & INSTALL TEST PLUG, TEST BOPE, INSTALL BOWL PROTECTOR, M/U BHA # 2, TEST WMWD, STRAP IN HOLE, BREAK CIRC EVERY 1000', WASH F/7723'-7852', DRLG CMT F/7853'-7982' E( EIVED $ E P - ? 199;5 .Aiask~ Oil & Gas C~ns, (,urmnissiO~ Anchorage WELL : DS 3-20A OPERATION: RIG : DOYON 16 PAGE: 2 04/11/93 ( 7) TD: 8473' (8473) 04/12/93 ( 8) TD: 8768' ( 295) 04/13/93 (9) TD: 8768' ( 0) 04/14/93 (10) TD: 9336' ( 568) 04/15/93 (11) TD: 9336 PB: 9297 04/16/93 (12) TD: 9336 PB: 9297 DRLG 8-1/2" HOLE @ 8473' MW: 9.7 VIS: 63 DRLG CMT F/7982'-8111', PASSED TOP STUB @ 8106', ORIENT DIR ASSEMB @ 8111', BEGIN KO W/135 DEG ANGLE, DRILL F/8111'-8196', DRLG F/8196' TO 8473', MAGNET CSG INTERFERENCE STILL PRESENT-1ST GOOD SURVEY RIH W/8-1/2" PACKED ASSEM MW: 9.7 VIS: 62 DRLG F/8473' TO 8505', CIRC HI VIS SWEEP, SHORT TRIP TO 9-5/8" SHOE @ 8106', DRLG F/8505'-8768', CIRC HI VIS SWEEP, DROP SINGLE SHOT, POH F/BHA CHG, M/U BHA #3 & RIH DRLG 8-1/2" PROD HOLE MW: 9.7 VIS: 62 RIH TO 8106', FILL DP @ 9-5/8" TOP STUB, CONT RIH TO 8725', REAM F/8725'-8768', DRLG F/8768'-9110', TORQUE ERRATIC, MAKE CONNECTION @ 9110', PULL TIGH @ 9050', REAM THRU TIGHT SPOT, DRILL F/9110'-9336', TD PROD HOLE SECT @ 9336' CBU, DROP SURVEY MW: 9.7 VIS: 57 WORK PIPE THRU TIGHT SPOT F/9254'-9336', CBU, SHORT TRIP TO 9-5/8" CSG, TIGHT SPOT @ 9082', KELLY UP, WASH TO BTM @ 9336', CBU, PUMP DRY JOB, RIH W/OPEN HOLE LOGS, GR/DLL/ACCNL TO 9340', 2ND RUN SBT/GR/CCL TO 3000', RIH W/8-1/2" BHA FOR WIPER TRIP & TO DROP SURVEY TOOL, KELLY UP, WASH DOWN TO BTM, NO TIGHT SPOTS, CBU DROP SS SURVEY TOOL POH W/LINER RUNNING TOOL MW: 9.7 KC1 POH W/8-1/2" BHA, R/U TORQUE TURN, RIH W/7" LINER, CIRC LINER VOL @ 8106', RIH W/7" LINER ON DP TO 9336', CIRC & COND FOR CMT JOB, PUMP 52 BBLS CMT, DROP PLUG, SET HGR, PRESSURE UP TO 4000 PSI TO SET LINER TOP PKR, REV CBU, REV CIRC WELL OVER TO SEAWATER, POH W/LINER HGR RUNNING TOOL CIRC THRU ANNULUS MW: 9.7 KC1 CIRC DP VOL, FLUID U-TUBE IN DP, POH W/LINER RUNNING TOOL, PULL WEAR RING, SET TEST PLUG, PERFORM, HI-LO PSI BOPE TEST, ATTEMPT TO SET BRIDGE PLUG-WILL NOT SET, POH, LOST BRIDGE PLUG DOWN HOLE, RIH W/RETRIEVING TOOL, TAG UP ON PLUG @ 2737', RETRIEVE & POH, SET @ 2527', POH, SET 1 JT 7" CSG IN TABLE, DUMP 40 SX SAND DOWN HOLE, CHG TOP RAMS TO 9-5/8", PULL WEAR RING, N/D BOPE, PULL PACKOFF F/TBG SPOOL, N/U SPOOL & BOPE, SET TEST PLUG, TEST, M/U CSG CUTTER, RIH TO 1885', MAKE CUT @ 1865', CLOSE PIPE RAMS, CIRC OUT ARCTIC PACK F/9-5/8" X 13-3/8" ANNULUS R'ECE[VED Alaska Oil & Gas Cons. Cornrnis. sio~ Anchorage WELL : DS 3-20A OPERATION: RIG : DOYON 16 PAGE: 3 04/17/93 (13) TD: 9336 PB: 9297 04/18/93 (14) TD: 9336 PB: 9297 04/19/93 (15) TD: 9336 PB: 9297 04/20/93 (16) TD: 9336 PB: 9297 P/U BACKOFF TOOL MW: 9.7 KC1 CIRC ANNULUS, POH, L/D CSG CUTTER, M/U SPEAR, SPEAR INTO 9-5/8" CSG, NO MOVEMENT, RELEASE SPEAR, POH, BREAKOFF STOP, SPEAR CSG-NO MOVEMENT, RELEASE SPEAR, M/U BUMPER SUB & JARS, N/D BOPE & TBG SPOOL, INSPECT CSG & HGR-OK, SPEAR INTO CSG & JAR-NO MOVEMENT, N/U BOPE & TEST, M/I CSG CUTTER, RIH TO 1623' CUT @ 1623', CIRC ANNULUS, POH, M/U SPEAR, SPEAR , INTO CSG & JAR FREE, L/D SPEAR, PULL 9-5/8" CSG, M/U SPEAR & RIH TO 1623', SPEAR INTO FISH & POH, LOST FISH @ DC'S, REDRESS SPEAR & RIH TO 1623', WORK INTO FISH, POH, L/D 5 JTS CSG, M/U CSG SCRAPER, RIH TO 1864', DP TAIL @ 2226', REV CIRC, PUMP DIESEL PILL, POH, L/D SCRAPER, CLEAR FLOOR, PREPARE TO P/U BACKOFF TOOL POH W/BACKOFF TOOL MW: 9.7 KC1 M/U BACKOFF ASSEM.& RIH, FILL EACH STD W/H20, SET TOOL @ 1885', PRESSURE UP, DROP DART TO OPEN PUMP-OUT SUB, REV CIRC OUT WATER, POH, SURFACE TEST TOOL-OK, L/D ASSEM, M/U 8-1/2" TAPERED MILL & CSG CUTTER & SPEAR ASSEM, RIH, DRESS TOP OF STUB, CUTTER WILL NOT ENTER STUB, POH, ONE BLADE STUCK OPEN, REDRESS & RIH, CUT CSG @ 1905', WORK SPEAR INTO FISH, REV CIRC, POH, RECOVERED 36' CSG, M/U BACKOFF TOOL ASSEM, RIH, FILL EACH STD W/ WATER, WORK BACKOFF TOOL INTO STUB, TOOL WILL NOT BREAK COLLAR WORK TORQUE INTO PIPE F/SURFACE, NO BREAK -NO MOVEMENT, DROP DART TO OPEN PUMP-OUT SUB, POH W/BACKOFF TOOL RUN 9-5/8" CSG MW: 9.7 KC1 POH, L/D BACKOFF TOOL, M/U TAPERED MILL, RIH TO 1884', DRESS TOP OF 9-5/8" CSG @ 1885', RIH, TAG TOP OF SAND @ 2467', POH TO 1980', CBU, POH, L/D MILL, M/U SPEAR, RIH TO 1890', WORK SPEAR INTO TOP OF CSG, RIH W/STRING SHOT, FIRE S~RING SHOT ACROSS CSG @ 1922', POH, R/D ATLAS, RELEASE SPEAR, POH W/SPEAR, M/U BACKOFF TOLL ASSEM, PRESSURE UP & SET @ 1927', POH, RIH W/SPEAR, SPEAR INTO CSG @ 1898', POH W/SPEAR, L/D SPEAR, M/U SCREW-IN SUB, RIH W/48 JTS CSG, TAG UP ON CSG @ 1927', REV CIRC TO CLEAN UP SEAWATER RETRIEVING BRIDGE PLUG MW: 9.7 KC1 REV CIRC,R/I HOT OIL PUMP TRUCK, PUMP 10 BBLS DIESEL & 120 BBLS DRY CRUDE, ROTATE 9-5/8" CSG & SCREW INTO CSG @ 1928', R/D CSG CREW & CLEAR FLOOR, CHG RAMS, P/U BOP STACK, SET CSG SLIPS, CUT 9-5/8" CSG, DRESS OFF TOP CSG STUMP, N/U NEW TBG SPOOL, TEST PACKOFF, N/U BOPE, TEST, RIH W/JB TO TOP OF SAND @ 2467', REV CIRC JB, POH, RIH W/NEW JB, REV CIRC JB, POH M/U BRIDGE PLUG RETRIEVING TOOL, RIH TO TOP, REV CIRC OUT SAND TO TOP OF BRIDGE PLUG $ E P -- 7 199 Alaska Oil & Gas Col]s, i3orr,~rDjssiof.', Anchorage WELL : DS 3-20A OPERATION: RIG : DOYON 16 PAGE: 4 04/21/93 (17) TD: 9336 PB: 9297 04/22/93 (18) TD: 9336 PB: 9297 RIH W/TUBING MW: 9.7 KC1 REV CIRC SAND OFF BRIDGE PLUG, LATCH PLUG @ 2527', POH & LD PLUG, RIH W/6" DC'S, LD DC'S, PU BIT & SCRAPER, RIH TAG TOL @ 7930' & TOC @ 9232', DRLD CMT F/9232'-9294', REV CIRC CMT OUT OF WELL, TESTED 9-5/8" CSG & 7" LNR, TO 3500 PSI FOR 30 MINS, DISPLACE WELL W/CLEAN SEAWATER & COREXIT, RU TORQUE TURN, RUN 4-1/2" CR TBG RIG RELEASED 04:30 4/22/93 MW: 9.7 KC1 RUH W/4-1/2" 13CR80 TBG, N/D BOPE, N/U ADAPTOR FLANGE & TESTED 5000 PSI, N/U TREE, TEST TO 5000 PSI, SET PKR, HELD PRESSURE FOR 15 MINS TO TEST TBG, TESTED PKR & CSG TO 3500 PSI FOR 30 MINS, SHEAR OUT RP VALVE, PUMP 140 BBLS DIESEL DOWN ANNULUS, U-TUBE TO TBG TO FREEZE PROTECT, CLOSE SSSV, INSTALL BPV, SECURE TREE, PUMP OUT CELLAR, RELEASE RIG @ 04:30 SIGNATURE: (drilling superintendent) DATE: PRUDHOE BAY PBU/3-20A 500292098001 NORTH SLOPE COMPUTATION DRILLING DATE: 4/16/93 - SI' 'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 04/14/93 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-30022 KELLY BUSHING ELEV, = '54,93 FT, OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT, SECT. 8110 8083.64 8028,71 7 51 S 78,36 E ,00 3,86S 292,65E 8193 8166,14 8111,21 6 5 S 11,35 E 9,44 9,34S 299.09E 8286 8258,70 8203,77 5 5 S ,05 E 1.60 18,32S 300.06E 8379 8351,38 8296.45 5 18 S 61,25 W 5.70 24,52S 296.30E 8472 8443.79 8388,86 7 48 N 89.15 W 4.43 26.49S 286.22E 284.34 289,39 288.32 283.27 273.00 8565 8535,44 8480,51 11 41 N 79,45 W 4,54 24,67S 270,63E 8658 8625.89 8570,96 15 6 N 75.95 W 3,76 20.00S 249.60E 8751 8714.96 8660,03 18 1.7 N 76,85 W 3.45 13,74S 223,63E 8844 8803,43 8748,50 17 36 N 77,55 W .79 7,39S 195,68E 8937 8892.27 8837,34 16 47 N 78,45 W .91 1,66S 168,78E 258,22 238.77 214,86 189,05 164,12 9030 8981,46 8926,53 16 6 N 78,55 W ,75 3,59N 142,98E 9123 9070,97 9016.04 15 23 N 78.35 W .76 8.64N 118.24E 9217 9161,76 9106.83 14 36 N 79,25 W .89 13,37N 94,38E 9279 9221.87 9166,94 13 48 N 79,15 W 1.29 16,22N 79.44E 9300 9242,28 9187,35 13 23 N 79,05 W 1.91 17,15N 74.59E 140.14 117.17 94.98 81.05 76.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 76.54 FEET AT NORTH 77 DEG. 2 MIN. EAST AT MD = 9300 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 77.05 DEG. MICROFILMED R'ECEIVED ,- L P - 7 Alaska 0il & Gas Cons. Commission Anchorage SI:' RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/3-20A 500292098001 NORTH SLOPE COMPUTATION DATE: 4/16/93 DATE OF SURVEY' 04/14/93 JOB NUMBER' AK-EI-30022 KELLY BUSHING ELEV. = 54.93 FT. OPERATOR' ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST HD-TVD VERTICAL DIFFERENCE CORRECTION 8110 8083.64 8028.71 3.86 S 292.65 E 9110 9058.43 9003.50 7,94 N 121.62 E 9300 9242.28 9187.35 17.15 N 74.59 E 26.36 51.57 25,21 57.72 6.16 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. 'SP~"~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/3-20A 500292098001 NORTH SLOPE COMPUTATION DATE: 4/16/93 DATE OF SURVEY: 04/14/93 JOB NUMBER: AK-EI-30022 KELLY BUSHING ELEV. = 54,93 OPERATOR: ARCO ALASKA INC PAGE FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8110 8083,64 8028,71 3,86 S 292,65 E 26,36 8181 8154,93 8100,00 8,27 S 298,70 E 26,80 .44 8282 8254,93 8200,00 17,98 S 300,06 E 27.29 ,49 8382 8354,93 8300,00 24,65 S 295,97 E 27,64 ,35 8483 8454,93 8400.,00 26,43 S 284,62 E 28,32 .69 8584 8554,93 8500,00 23,87 S 266,52 E 30,01 1.68 8688 8654,93 8600,00 18,05 S 241,71 E 33,22 3,21 8793 8754,93 8700,00 10,74 S 210,78 E 38,16 4.94 8897 8854,93 8800,00 3,92 S 179.83 E 43,06 4,90 9002 8954,93 8900,00 2,07 N 150,48 E 47,46 4.39 9106 9054,93 9000,00 7,75 N 122,57 E 51,43 3.98 9209 9154,93 9100,00 13,04 N 96,13 E 55,01 3.58 9300 9242,28 9187,35 17,15 N 74,59 E 57,72 2.71 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS PA~E ~, COMPS: P~O)flOE t~¥ I;RILLIN~ WELL NAME DS 3-20A LE~TION 1 PRIJI~E BAY I,OCATI~ 2 Ag MA~ETIC I)~LI~TION 30,17 ])ATE: 9-APR-93 WELL HUI'IBER 0 WEI,L ~ LOCATION: LAT(N,'-E;; AZII~U'I~t ~ ROTARY TA~I.P. TO ?AR.2ZT IS TIE IN FOIl, IT(TIP) MEASU[~,~I) DEPTH ?~tlE VER~ D~P~ INCLINATION AZIMU?H LATITUI)E(~[/-S) D~ARll]RI~(E/-W) 8110,(X) 7,~ 101,64 -4.00 293,00 D~(~-W) 260.79 REEEIVED S i,:. P - 7 ~,9~ Alaska Oil & Gas Cons. Comrflissio~ Anchorage PAC;£ NO. 2 ~ASURED INTI~U~ UI~'TICAL I)~I'H DB:'TH ft ft ft 8110,® 0,0 8084,® 8476,59 .%6,6 8449,45 8.508.14 31,5 8480.69 8538.68. 30.5 8510.83 856%48 30,8 8541.13 8600.64 31.4 8571.85 8632.16 31,3 8602,37 8662.56 30.4 8631.82 8694,06 31.5 8~2o~ 8710.50 16.4 8677.96 PROJI~EI) ~;'JEY 8768.00 57.5 8732,98 SURVEY CALCULAI] 3NS *******. ~INI~L~ ~TU~ ~ETHOD ~.~,~ TARGET STATION AZiFLFII~ LA?IIlDE SEC?ION INCLH, N/-S ft deg. d~ ft -288.58 7.86 IO1.E4 -4.00 -288,05 7.58 268,66 -9.57 -283.72 8.57 275.~5 -9,38 -279.03 9.94 279.G3 -8,69 -273.80 10.77 283-27 -7.73 -267,87 12.43 200,~9 -6,58 -26i.27 13,55 261.44 -5,23 -254.27 15.08 282.43 -3.64 -246.51 15.85 263.4~ -1.72 -242,24 16.86 283,74 -0.63 -226.87 16.90 263.70 3.33 D~'ARTURF. DISPLACEMENT at AZ]ILlTH E/-W ft ft 2?3.00 2?3.03 2¢.3.37 2?3.52 ~J,87 268,95 289.10 91.86 284.08 284.22 ~1,75 278.63 278.74 91.57 dso./ lOOft 0.00 4,19 4.42 4,~ 2.70 ~.2~ 22~,32 89.17 0,08 272,44 272.52 Sl,&~ 5,30 265,53 265,58 91.13 3.63 258.18 258,21 ~0,81 5.16 250.00 250,01 ~,39 2,49 245,51 245,51 ~0,15 6,16 ARCO Al, sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA c{2_~ 1~21-24A 12-20-92 MWD Directional Survey Ana _/3-15A 2-25-93 MWD Directional Survey Ana q~l~3-15A 2-27-93 Electronic Multi-Shot Survey Job#AKEI30010 Sperry c}~-ql--3-18A 4-19-93 MWD Directional Survey Job#1209 BHI c[~q-7--3-20A 4-9-93 MWD Directional Survey Aha q~r_Z.~/3-25A 3-19-93 MWD Directional Survey Ana %3-25A 3-23-93 Electronic Multi-Shot Survey Job #AKEI30016 Sperry q'5~lc~ --3-36 4-18-93 MWD Directional Survey Job#AKMW30020 Sperry q3~E~~/~_~4Aa'4A 2-23-93 MWD Directional Survey Job#1188 Teleco _~ 2-26-93 Electronic Multi-Shot Survey Job#AKEI30009 Sperry '-- Z 9-5A MWD Directional Survey Job#1192 Teleco C/"~- ~'~ _ 3-7-93 ~~A9-28 3-13-93 Electronic Multi-Shot Survey Job#AKEI30012 Sperry 4-6-93 MWD Directional Survey Job#1202 BHI q ~_-c~$_ 9-3 lA 4-15-93 MWD Directional Survey Aha c1~1--9-35A 3-7-93 MWD Directional Survey Aha ~-~--9-36A 4-1-93 MWD Directional Survey Ana c~2~~L~-9-49 12/6-23/92 MWD Directional Survey Job#1159 Teleco -~' '~9-50 1/23-2/6/93 MWD Directional Survey Job#1175 Teleco clZ_l~i- 9-51 12/30-1/15/93 MWD Directional Survey Job# 1167 Teleco ~ ffb~--15-23 12-9-91 MWD Directional Survey Job#AKMM911128 Sperry q~_.1~O~15-26 1-15-92 MWD Directional Survey Job#AKMM911231 Sperry c~?~-C)/o 15-27 1/92 MWD Directional Survey Sperry ~ ~l.a~ ~ 16-4A 2-9-93 MWD Directional Survey Ana ~t~.~18-27 1-16-93 MWD Directional Survey Job#AKMW30003 Sperry 2~ [~18-29 12-27-92 MWD Directional Survey Job#AKMM921231 Sperry ~~-AGI-4 1-18-93 MWD Directional Survey Job#1168 Teleco ctz~ iq (~ ~-~~GI-5 1-17-93 MWD Directional Survey Job#1172 Teleco '~,~ 0'~'"'""'"'-~--AGI-6 2-16-93 MWD Directional Survey Teleco c~ ~ ~~--/~GI-7 2-24-93 MWD Directional Survey Job#1185-450 Teleco ~r~ gt~r_~AGI.7 4-28-93 MWD Directional Survey Job#1185 Teleco ~----AGI-8 3-7-93 MWD Directional Survey Job#1190 Teleco ^<~.~ ~ ~GI-9 3-17-93 MWD Directional Survey Job#II95-450 Teleco ~.~; _/AGI-10 3-30-93 MWD Directional Survey Job#1205 Bill Please sign and return the attached copy as receipt of data. ..... ,' /,-/-- ilave ~ ~xce ~y. ~.~. ~ ~ ~ _ ~n~ W~ce A P P R O V i D--~~'~co~ ATO-1529 ~~s~ 93059 C~~ON ~ PB ~LL F~ES ~ CLOT C~~ ~ BPX ~ E~ON ~ ST. OF ~. (2 COP~) MOB~ t LUC~LE JO~STON ARCO ,~ln~lr~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-20-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS nnt,/~.~.IAC lCNI G~,IZnL InEI~ I~ Run I Job~5940 Atlas DLL/AC/CN/GR Run I Job#5927 Atlas DLL/CN/ZDL/GR Run 1 Job~5930 Atlas DLL/AC/CN/GR l~_m 1 Job~5948 Atlas DLL/MLL/AC/GR Run1 Job#5900.01 Atlas Please sign and return ~he attac.hed copy as receipt of data. RECEIVED BY_~~ff~~ Have A Nice Day! Sonya Wallace APPROVED ..... ATO-1529 Trans# 93061 CENTRAL FILES (CH) CHEVRON D&M # BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILF~ R&D # BPX # STATE OF ALAS~ TEXACO The correct APl# for 3-20A is 50-029-20980-01. ARCO Alaska, Inc. Date: File Code: Subject: From/Location: Telephone: To/Loca'tion: 5- ! 1-93 Transmittal 93051 $onya Wallace (907) 263-4310 Co-Owner Distribution I inadvertently made two errors on this transmittal. 1. The correct API# for the 3-20A logs are 50-029-20980-01. 2. The correct API# for the 9-35A logs are 50-029-21314-01. I'm sorry for any trouble that these omissions might have caused. 5.-q7 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Ahska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOLE FINALS '~'~1-24A 2-7-93 3-20 4-6-93 ~'~~0A 4-13-93 ~'~~20A 4-28-93 ~~ii 4-23-93 V-¢~ 4-22-93 4-16 ¢~-f~ 4-18-93 -10 ~Z~ 7~ 1-2-93 -12A C~ ~ 4-19-93 ~6-12A~ . / 4-24-93 ~6-17 ~* 4-25-93 -4A ~2' ~ ~ 4.23-93 -7A ~-~_~- 4-21-93 ~-2~ ~ ~~ 4-20-e~ ~-3 ZA ~.~3 4- **~2-148T FI~/~ 4-27-93 ~3-20~2-O~ 4-25-93 ~/13-25 ~-~/ 12-26-93 ~6-27 ~2,~ 12-27-92 ~-~7-13 ~7~ 4-18-~3 Plense sign and GR/CCL/Jewelry/Temp Run 1, 5" Tubing Cutter Run 1, 5" 8BT/GR/CCL Run 1. Perf Record Run 1, 5" Jewelry/GR/CCL Tie-In Run 1, 5" CNL/GR Color Run 1, 5" USIT/GR Color Run 1, 5" Leak Detect Run 1, Static Press/Temp Run 1, 5" Leak Detect Run 1, Prod Profile Run 1, Production Log' Run 1, 5" Pressure Build-Up Run 1,. 5" Press/Temp Run 1, 5" Perf Record Run 1, Production Log Run 1, r'&5- Dual Burst TDTP (Borax) Run 1, 5" P, rf Record Run 1, 5" PFC/GR (Packer Set) Run 1, lnJ Profile Run 1, Leak Detect Run 1, Leak Detect Run 1, 5" Leak Detect Run 1, lnJ Profile Run 1, Prod Profile Run l, Prod Profile Run 1, Leak Detect Run 1, 2"&5" SBT/GR/CCL Run 1, ~'&~' RECEIVED Have A Nice Sonya wattace ATO-1529 as rect4J~ of data. 93056/ # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL # PB WELL FILES. # BPX # STATE OF ALASKA The Correct well name for this log is 1-24A. The conect APl# for 3-20A is 50-029-209804)1. The correct Al'I# for 12-14ST is 50-029-206594)0. Camco Atlas Atlas Sch Sch 8ch Sch Camco Sch Sch Camco Sch Sch Sch Sch Sch -2ch Atlas Camco Camco Sch Camco Camco Camco Sch Atlas ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-29-93 REFERENCE: ARCO ~INALS 4-13-93 SSTVD 4-13-93 DLL/GR/SP 4-13-93 BHCA/~R 4-13-93 CNL/GR 3-23-93 SSTVD 3-23-93 DLL/GR/SP 3-23-93 - BHCA/GR 3-23-93 CNL/GR 3-23-93 BH Profile 3-31-93 DLL (Simultaneous) 3-31-93 ' BHCS/SSTVD 3-31-93 BHCS 3-31-93 CNL 3/25-31/93 MWD: DPR/GR 3/26-31/93 MWD: DPR/GR 4-17-93 SSTVD 4-17-93 DLL/GR 4-17-93 ZDL/CNL/GR 3/13-18/93 LWD: CDN Mad Pass 3/13-17/93 LWD: CDN Drilling Pass 3/13-18/93 LWD: CDR Mad Pass 3/13-17/93 LWD: CDR Drilling Pass 3/13-18/93 LWD: CDN N/F Mad Pass 3/13-17/93 LWD: CDN N/F Drilling Pass 3/13-18/93 LWD: CDN Mad Pass TVD 3/13-17/93 LWD: CDN Drilling Pass TVD 3/13-18/93 LWD: CDR Mad Pass TVD 3/13-17/93 LWD: CDR Drilling Pass TVD 4-6-93 SSTVD 4-6-93 DLL/GR 4-6-93 BHCA/GR 4-6-93 CNL/GR 4-6-93 , ~ .... 4 Arm Cal/GR (BH Profile) 3-19-93 ~Induction Electrolog 3-20-93 CNL/GR 4-20-93 DLL/MI,L/GR/SP/Cal 4-20-93 BHCA/GR. 4-20-93 BH Profile 3-28-93 SSTVD 3-28-93 DLL/MLL/GR/Cal 3-28-93 BHCA/GR 3-28-93 BH Profile / Please sign and return t~e attach~d..copy u receipt of data. Have l Nice Day! Sonya Wallace ATO-1529 Run 1, l'&2' Run 1, 2'&5" Run 1, 2'&5" Run 1, 2"&5' Run 1, l"&2~ Run 1, 2'&5' Run 1, 2'&5' Run 1, ~'&5' Run 1, 5~ Run 1, 2"&5" Run 1, 5' Run 1, 2'&5" Run 1, Runs 1-3, :~'&5'q~D Runs 1-3, :~'&5'~IWD Run 1, 1"&2~ Run 1, 2"&5' Run 1, 2'&5" Composite, 2"&5" Composite, 2"&5" Composite, 2"&5" Composite, Composite, 2"&5" Composite, 2"&5" Composite, Composite, 2"&5" Composite, 2'&5" Composite, 2'&5" Run 1, 1'&2~ Run 1, 2"&5~ Run 1, Run 1, 2~&5~ Run 1, 5" Run 1, 2"&5" Run 1, 2'&5" Run 1, Run 1, 2~&5" Run 1, 5" Run 1, 1"&2~ Run 1, 2"&5" Run 1, 2'&5" Run 1, 5" * The lo~s for this well all say field, but are actually .finals. Atlas Atlas Atlu Atlu Atlas Atlu Atlu Atlu Atlas 9ch Sch 8ch Teleco Teleco Atlas Atlas Atlas Sch 8ch Sch Sch 8ch 8ch ~ch Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 26, 1993 R M Lemon Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 3-20A ARCO Alaska, Inc. Permit No. 93-47 Sur. Loc. 194'NSL, 422'WEL, Sec. 10, T10N, R15E, UM Btmnhole Loc. 135'NSL, 371'WEL, Sec. 10, T10N, ~15E, UM Dear Mr. Lemon: ~ 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 law 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) 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 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~._~ printed on recycled paper b y o. rJ. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll;'lllb. Type of well. Exploratory• Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen!-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 62'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28328 4. Location of well at surf-ace ~7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025 194' NSL, 422' WEL, SEC. 10, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 164'NSL, 191' WEL, SEC. 10, TION, R15E, UM 3-20A U-630610 At total depth 9. Approximate spud date Amount 135'NSL, 371' WEL, SEC. 10, TION, T15E, UM 4/12/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 28331-135' f e e t No Close Approach fee t 2560 9332' MD/9266' TVDt e e t 16. To be completed for deviated wells 17. Anticipated pressure (see 20 Mc 25.035 (e)(2)) Kickoff depth e~ ~ofeet Maximum hole ancjle ~e.e 0 Maximum surface 3330pslg At total depth (TVD) 118. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# NT80/ NSCC 1372' 7960' 7933' 9332' 9266' 244 sx Class "G" ~ ~iaska Oil & Gas Cons. 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~tlc[lora§8 Present well condition summary Total depth: measured 9295 feet Plugs (measured) Cement cap @ 8868'MD (6/5/92) true vertical 9261 feet Effective depth: measured 8868feet Junk (measured) true vertical 8836 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20" 2325 # Poleset 80' 80' Surface 2611' 13-3/8" 2100 sx CS III& 2645' 2645' Intermediate 400 sx CS II Production 8671' 9-5/8" 5OOsx"G"/25OsxCS/ 8702' 8671' Liner 886' 7" 320 sx Class "G" 9295 9261' Perforation depth: measured 8804;8844' true vertical 8872;8812' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth pict [] Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirements[] 21. I here~fy that the foregoing is true and correct to the best of my knowledge Signed~ /~. ~ ~ Title Drilling Engineer Supervisor Date 3//i'7/?3' -- Commission Use Only Permit Number IAPI number IApproval da, te ISee cover letter ~3 - ~' 7 15 O- 0 ..~ ~' - ..7_. 0 ? ~0 "o ! I ~ - '~ ~ - P~-~ Ifor other requirements Conditions of approval Samples required [] Yes J~No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~rea j;~ Yes [] No Required working pressure for BOPE []2M; 1-13M; ~5M; I-I10M; I-I15M; Other: Approved by Origir~l .~neci ~¥ by order of _ ,-, .... ~ V'.~I j<-~hr~stor~ Commissioner tne commission Date~,'~"~:~-~ Form 10-401 Rev. l~V-'~J5 Submit in triplicate DS 3-20A Drilling Permit Information Objective: The goal of this sidetrack is to move the bottom hole location 250' to the west. The current well is producing with a high water cut due to a frac or channel into the Victor sands. The sidetrack should remove the well from this water source. Additionally, this well has 9-5/8" x 13-3/8" communication while on gas lift. A 9-5/8" cut and pull should repair this problem. Scope: 1. Lay a cement plug across the current perforations from TD to at least 100' above the top perforation with coiled tubing. 2. MIRU the Doyon 16 workover rig. 3. Kill the well, nipple up the BOPE, and pull the 5-1/2" tubing out of the well. 4. Pressure test the 9-5/8" casing to 3500 psi. If needed, identify the source and extent of the leak. 5. Mill a 50' window in the 9-5/8" at 8105'. Lay a cement plug across the window. The window is 213' above the production packer. 6. Drill an 8-1/2" hole to 9332' MD. Run open hole logs. 7. Run and cement the 7" L-80/CR-80 liner. Test the liner and 9-5/8" casing to 3500 psi. 8. Cut and pull the 9-5/8" casing at 2250'. Run new 9-5/8", 47#, NT-80, NSCC casing and screw into the stub. Test the wellhead and casing to 3500 psi. 9. Run the 4-1/2" CR-80 completi~on with a 7" packer. Timing: Doyon 16 will move to the DS 3-20 after completing the 3-18A sidetrack. The DS 3-20 sidetrack should be completed in about 15 days. Work should begin about April 12, 1993. MAR AJaska 0il & Gas Cons. ~nch0rag~ David Crockett Page I March 16, 1993 DS 3-20A Drilling Permit Information .. Well' DS 3-20A Redrill PBU EOA APl No.' 50-029-20980-00 Location' Surface: 194 FSL 422 FEL Tie in: 190 FSL 130 FEL Target: 164 FSL 191 FEL BHL: 135 FSL 371 FEL Original KB 62' AMSL S10 T10N R15E UM S10 T10N R15E UM S10 T10N R15E UM S10 T10N R15E UM @ 8110' MD @ 8768' MD @ 9332' MD Estimated Start' April 12, 1993 Operating days to complete- 15 Contractor' Directional- Doyon Rig #16 Kickoff @ 8110' with a 4°/100' build rate. Build from 7.9° to 18.8° and turn from 101.6° to 260.8°. Maximum angle 18.8° @ 8768' MD. No close approaches. TVD (BKB) MD (BKB) Mud Weight KOP 8084' 8110' 9.7 Sag River N/A N/A Shublik 8679' 8712' 9.7. Sadl e roch it 873 2' 876 8' 9.7 TD 9266' 9332' 9.7 Open Hole Logs- GR/Resistivity/Neutron/Density Mud Program' The mud progra.m, will be typical of the sidetracking program and will consist of a 9.7 - 9.6 ppg Biozan polymer/KCI water based mud. DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD .(TVD) (PPG) ...(CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE KOP' 9.6 10 10 5 7 8 0 5 Water to to to to to to to to to Base TD' 9.7 16 18 10 15 5 0 7 Mud RECEIVED MAR 1 ? 199 Alaska 0il & Gas Cons. Commtss~oa Anchorage David Crockett Page 2 March 16, 1993 DS 3-20A Drilling Permit Information MUD WEIGHT CALCULATIONS / WELL CONTROL: Est. Pore Press. Sag River: N/A psi/N/A' ss TVD. Est. Pore Press. Sadlerochit: 3500 psi/8800' ss TVD. Mud Wt.: 8-1/2" Hole = 9.7 ppg. Overbalance Sag River: N/A psi. Overbalance Top Sadlerochit: 940 psi Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible, bottomhole pressure is 4300 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3300 psi based upon a gas column to surface from 8800' TVDss with no oil column. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 29# NT-80 NSCC 7" 29# CR-80 NSCC ~7960' - 8450' MD 8450 - 9332' MD 8160 psi 7030 psi 676 klbs 8160 psi 7030 psi 676 klbs CEMENT CALCULATIONS: Measured Depth' 7960'MD (Hanger) - 9332'MD (Shoe) Basis' 40% open hole 6xcess, 40' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Vol: 244 sxs of Class G blend @ 1.18 ft3/sx TUBING DETAILS' 4-1/2" 12.6# 13CR-80 NSCT MAR ! ~' t99,] ,4~aska 0il & Gas Coas. ' ' ' 6orr~m~ss~o~ ~nchorags David Crockett Page 3 March 16, 1993 DS 3-20A Drilling Permit Information SUMMARY PROCEDURE o Rig work: MIRU Doyon 16. Pull the BPV with a lubricator. Circulate and kill the well. An injection rate down the 9-5/8" and into the tubing of 4.5 BPM at 775 psi was established on 11/22/92. o Set a two way check valve. ND the tree and NU the BOPE. Test the BOP's to 5000 psi. Pull the TWC with a lubricator. o . Puli the 5-1/2" tubing. Pressure test the 9-5/8" casing to 3500 psi. If the casing leaks, determine depth of the leak with packers and the extent of the casing damage with a USIT Icg. Notify ARCO Engineering before continuing. . RIH with a 9-5/8" section mill. Spot an 18 ppg on top of the packer. Mill a 50'. window in the casing at 8105'. . Spot a 170 sx balanced cement plug from 8360'- 8010' across the window. Squeeze the cement into the window. . Run an 8-1/2" steerable drilling assembly. Dress off the cement plug to 5' below the window. Drill to 9332' MD 9266' TVD. Lay down the MWD and PDM once the well is aligned with the target. 8. Rig up Atlas and run a GR/Resistivity/Neutron/Density log. . 10. Run the 7" 29# CR-80/L-80 NSCC liner. Cement the liner with 244 sxs of CIG blend cement. This includes 40% excess in the open hole. Set the liner hanger and liner top packer. Reverse out the exces¢ cement. RIH with a retrievable bridge plug to 2500'. Set the plug and displace the well to diesel. POOH. Dump 40 sxs sand down the casing. 11. 12. 13. Cut the 9-5/8" casing in the middle of a joint at +2250'. Circulate out the old Artic Pack. Lay down the old 9-5/8" casing. Run the Tristate backoff tool to loosen the stub. Recover the stub with a spear. Run an 8-1/2" mill and 12-1/4" casing scraper and clean out to the top of the stub. .. Run a 9-5/8", 47#, NT-80, NSCC tieback. Screw into the casing stub and torque the connection to 20,000 ft-lbs. Test the tieback to 3500 psi. Set the 9-5/8" emergency slips. Nipple up the wellhead and test the 9-5/8" packoff to 3500 psi. RIH and wash out the sand and junk on top of the retrievable bridge plug. Displace the diesel with mud. Recover the bridge plug. 14. Clean out the liner to PBTD. Test the liner and 9-5/8" to 3500 psi. Displace the mud with clean inhibited sea water. RE( EIV D David Crockett MAR 1 7 !993 Page 4 .March 16, 1993 Aiaska 0ii & Gas Cons. 6ommissto~" Anchorage 15. DS 3-20A Drilling Permit Information Run the 4-1/2" 12.6# CR-80 NSCT completion with a 7" permanent packer. Position the packer at 8570' 16. Set the TWC. ND the BOPE and NU the tree. Test the tree to 5000 psi. 17. Pull the TWC with a lubricator. Set the packer and test the tubing to 4000 psi. Test the packer to 3500 psi. Shear out the RP valve and freeze protect the well. 18. Set the BPV. Release the rig. Anticipated BHP: 7.7 ppg EMW Drilling fluid: 9.7 ppg Workover fluid: 8.5 ppg E£E VED MAR 1 7 199,~ Alaska 0il & Gas Cons. Cornmissior~ Anchorage David Crockett Page 5 March 16, 1993 MUD & _ _ _ _ DS 3-20A Drilling Permit Information SOLIDS CONTROL EQUIPMENT Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 HP agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual andaudio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console Oil & Gas Cons. Oommiss'iof~ Anchorage David Crockett Page 6 March 16, 1993 GREAT LA3~-D DIRECTIONAL DRILLING, INC. Corporata Office 1111 East 80~h Avenue Az%chora~e, ~31 99518 (907) 3~9-~511 Fax 349-2%87 DIP, ECTIONAL WELL PLAN for PRUDHOE BAY DRILLING ;.;ell ......... : DS 3-20A (P2) Field ........ : PRLUDHOE BAY DRZLL SiTE 3 Co~t~Dutation..: MiNIM73q4 CURVATLTRE Units ........ : PEET Prepared ..... : 03/'15/93 Section at...: 260.79 ~ elevation.: 62.00 ft LEG~LL DEgCRIDTION X ASP ZONE 4 Y Surface ...... : 194 FSL 422 FEL S!0 T10N R15E b~ 712872.41 59~g222.57 Tie-in ....... : 190 FSL 130 FEL SI0 T10}I R15E ~ 713165.0~ 5936226.9B Target ....... : 164 FSL 191 FEL S10 T!0N R15E -uq~ 713104.09 5936198.75 EKL .......... : 135 FSL 371 FEL S10 T!0N ~153 UM 7!2925.%% 5936164.59 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN MEAS l NCLI'J VERT- DEPTHS SECT DIRECTION REL- COORDINATES DL/ DEPTH ~GLE BKB .SUB-S DiST ~Z~ML~H FROM~WELLHE_~D i00 81!0 7.86 8084 8022 -288 !01.6~ 4 S 292 E <TiE 8200 ~.g8 8173 ~lll -297 ll3,~S 7 $ 302 8300 2.03 8273 8211 -300 176.88 10 S 306 E 4.0 8400 4.49 8373 83!1 -2~6 239.93 l~ S 302 E ~.0 8500 8.25 $~72 8420 -285 252.63 18 S 292 E SA~d~LI:< END O? CURVE SADLEROCHIT ~600 12.17 R57! 8509 -268 8700 !6.!3 8668 8606 -243 8712 16.60 86~9 8617 -240 8768 18.8i ~8732 8670 -223 8768 18.81 8732 8670 -223 257.21 22 S 275 E 4.0 259.73 27 S 251 E 4.0 259.94 28 S 248 E 4.0 260.79 30 S 23! E 260.79 30 S 231 E 4.0 TD_RGET ~OT OWC RASE SA~LEROCHIT TD 8768 18.81 8732 8670 -223 9097 18 8! 9044 8982 -117 9!82 18.81 9124 9062 9312 18.81 9247 9185 -4g 9332 18.81 ~266 9204 260.79 30 S 231 E 4.0 260.79 47 S 126 E 0.0 2~0.79 52 S 99 E 0.0 260.79 58 S 38 E 0.0 260.79 59 $ 51 E MAR 1 7 1993 Alaska Oil & Gas Cons. Cornmissior~ Anchorage TOTAL P.82 PBUDHOE MD 8] ID 876B B76B BAY ,IS ID S )0 S 59 'S DRILLING E/~ 293 E 231 E 231 £ 5~E DE; 3-20A PLAN VIEW Sreat Land t?JrectJona] OrillJng ] CLOSURE ' DECL [NATION ' SCALE · 79 Feet at Azimuth i39.~8' 30.]7 E ! inch : t00 feel DRAHN ' 03/15/93 © F 350 LCU O:)g2 D53=~D.~ tll.~,] 11:114 Itl 21 300 ]50 50 0 5O <-- NESI ' EAST -> t OD 150 200 250 300 _,JO 4 O0 450 -PRUDH'~pE BAY DRILLING Narker ldent ificatt2n 8) ENO OP CURVE C) TARGET D) TD MD BKB SECTN INCLN 8JJO 6084 -288 7.86 8768 8732 -223 1B.81 9~2~ 9266 -41 18,81 DS 3-20A (P2) , , EcT ~~~¥/ o~ction aL; 250.79 TVD Sca]~,: J ~nch = ~00 fe~tr Dep Scale.: ~ ~nch ~00 feet'w~'~f~ / I Dma~n ' 03/~5/93 Alaska OJt ~-6as Oons, Anchorage Ore~t Land ~Yrect~ona] ~riYYing t i 1 -500 8! .42 '.i:[: $4 P.w 2~'''-'"'I 0 ,tOO - ,. ...! : , t.T __ , 300 400 Sect]on Departure I 2O0 t'.- i i i I:i ' i' j,. 500 600 700 ~00 P'RU~DHOE BAY DR ILL ]] NG <KB> Marker Identlfzcation A) TIE-!N END OF CU.qVE C) TARGET D) TD MD' BK8 SECiN i~CLN B~O 8084 -289 7.86 8752 $732 -223 ~8.G~ 8768 8732 -223 18.8J 9335 S265 -4! ~8.8J DS 3-20A (P2) VERTICAL SECTION VIEW TVD Scale.' 1 inch : 2200 f Dep Sca]e.: I inch : 1200 f~t Dra~m ..... : 03/~5/93 ~A,.~ '~ ,~ ~9~ Alaska Oil & Gas Co~s. 6ommissi~ .. 6600 7~60-- i ill ;fl' ! i , . I ' - ~oo -~oo o 600 ~2oo ~8oo ~4oo 3o0o %oo -~'~oo ~oo 5,~oo 5000 L__.. Section Departu¢~ DOYON 16 13 5/8" 5,000 psi Stack 10.15 4.5 FRKB ] 5.02 1.02 1.80 2.35 0.25 GROUND LEVEL HYDRIL ~FLO, ,J Variable 3.5" x 6" Pipe Ram 12.40 Variable 4.5" x 7L" Pipe Ram R 15.40 17.60 MuD CROSS Blind Ram TBG SPOOL TBG SPOOL BASE FLG 20.70 24.85 25.10 REEEIVEg MAR 1'( t993 Alaska 0il & Gas Cons. Oornmissio~'~ Anchorage State: Alaska Borough: Well: DS3-ZOA Field: Prudhoe Bay St. Perm ~93-47 Date Engr: DS3-20A.XLS 3122/9b M. Minder Casing Interval Interval Size Bottom Top Length lA 7 9266 7933 1372 2A 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 29 NT-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/it 9.7 0.504 0.404 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure psi 3330 0 0 0 0 0 0 0 0 0 Yield psi BDF 8160 :~.5 0 #DIV/O! 0 #DIV/O! 0 #DlVfO! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! lC 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 39.798 0 0 0 0 0 0 0 0 0 K/Lbs TDF 676 16.99 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O.! Collapse Collapse Pr-Bot-Psi 3747 0 0 0 0 0 0 0 0 0 Resist. CDF 7020 1.873 0 #DIV/0! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #OlV/O! 0 #DiV/O! Page 1 CHT.XLS State: Well: Field: State Permit DS3-20A Prudhoe Bay 9~47 Engineer: Work Sheet: Date: M/x/er Volume Calcula#on~ 3/22/.93 Ca~ T~ Casing Size Ceding Length Hole Diamete~ £emer~ - Sacks Cement- ¥,~:1 Cement- Cubic ft Cement- Cubic It Cement- Sacks Cement- Yield Cement- Cubic It · Inche~ - Feet -Inches 111 111 111 111 112 112 112 Cement- Cubic tt 112 Cement- Sacks113 Cement- Yield113 Cement- Cubic It 113 Cement- Cubic fl :113 Cement- Cubic ft /Vol Cement- Fill Factor Conductor 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 II:DIV/O! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 IIDIV/O! Liner 7.000 1,372.000 8.500 244.000 1.180 287.920 287.920 0.000 0.000 0.000 ~000 287.920 1.655 Ca~'~ T.~e Ca~in~ Size -Inche~ Casing Depth - Feet Hole Diamele~-Inche.~ Cement- Sacks111 Cement- Yield111 Cement- Cul:~ ft 111 Cement- Cubic It 111 Cement- Sacks112 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic tt 112 Cemat - Sacks113 Cement-Yield 113 Cement- Cubic fl 113 Cement-Cubic It 113 Cement- Cubic It /vom Cement-Interval tt Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIWO! ~IV/O! Intermediate 112 0.000 0.000 [k000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! ttOIV/O! Production 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! ~DIV/0! Measured Depth Pried 3/22/93 STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COMMISSK .. APPLICATION FOR SUNDRY APPROVALS .~f Request: Abandon x Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well ~ Plugging X Time extension, Stimulate ~ Change approved program Pull tubing ~ Variance ~ Perlorate ~ Other .X Plulgback lot redrlll ,'ame of Operator 5. Type of Well: 6. ARCO Alaska, Inc. Development .X , Exploralo~y ~ 3. Address S~-atigraphic , 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service 4. Location of well at surface 8. 194'NSL, 422' WEL, SEC. 10, TION, R15E, UM At top of productive interval 165' NSL, 55' WEL, SEC. 10, TION, R15E, UM At effective depth 141'NSL, 11'WEL, SEC. 10, T10N, R15E, UM At total depth 139'NSL, 7' WEL, SEC. 10, TION, R15E, UM 12. Present well condition summary Total depth: measured true vertical RECEIVED MAR 1 7 1993 Alaska 0il & Gas Cons. c0mmissim" Anchorage 9295 feet 9261 feet Datum elevation (DF or KB) KBE = 62' feet Unit or Property name Prudhoe Bay Unit Well number 3-20 9. Permit number 83-101 10. APl number 50- 029-20980 11. Field/Pool Prudhoe Bay Field/Oil Pool Plugs (measured) Cement cap @ 8868' MD (6/5/92) Effective depth: measured 8868 feet Junk (measured) true vertical 8836 feet Casing Length Size Cemented Measured depth Structural Conductor 80' 20" 2325 # Poleset 80' Surface 2611' 13-3/8" 2100 sx CS III & 2645' Intermediate 400 sx CS II Production 8671' 9-5/8" 500 sx "G"/250 sx CS ! 8702' Liner 886' 7" 320 sx C/ass "G" 9295' Perforation depth: measured 8804'-8844' True vertical depth 80' 2645' 8671' 9261' true vertical 8872'-8812' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8382'MD; 4-1/2", 12./6#, L-80, PC T @ 8451'MD Packers and SSSV (type and measured depth) Baker FB- 1 packer @ 8362' MD; 5-1/2", Camco Bal-O SSSV @ 2195' MD 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 3/31/93 16. If proposal was verbally approved Name of approver Date approved 15. 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. Sig, ned ~)~ ~ TitloDrillin.gEnginoorSupervisor FOR COMMISSION USE ONLY Date Conditions ~fluagPiPnrtOe~arli:tyNO_~. Com;~)~ne~;3 represenL~tic~iomnacYleW~trna~ Mechanical Integrit~~ 10- 5'07 Approved by order of the Commi~,' ..~.~~'-~ Form i 0-403 Rev 06/15/88 ' J Approval No. ,~.~,~. O ~'~" Commissioner SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee /~ 3//F/~ Loc [ 2 thru [10 & 13] [14 thru 22] [23 thru 28] Lease & Well ~Z)A YES NO 1. Is permit fee attached ............................................... ~ ... 2. Is well to be located in a defined pool .............................. /~ 3. Is well located proper distance from property line ................... L 4. is well located proper distance from other wells ..................... /~. 5. Is sufficient undedicated acreage available in this pool ............. ~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~ .... 8. Can permit be approved before 15-day wait ............................ /~ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name $ nunber ................................ Is conductor st r ing prov ided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface g intermediate or production strings ...... Wi 11 cement cover al 1 known product ive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other [:29 thru 31] (7) Contact [32] ( 8 ) Ad d l ~.~-/~/. geology' engineering: RPC/f/c BEW JDI-/j~ LG rev 12/92 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ~1£~ ~ 1-~,'/ ?~o //g~ ~ut Add i t i ona 1 remarks' // UM X M ER I D I AN' SM · , TYPE' v Inj ~< Rev 0 ~0 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, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. %-'(47 ARCO ALASKA INC D.S. 3 - 20A PRUDHOE BAY ,.IU~ 2 8 1993 Alaska Oil 8, Gas Cons. e-,ommi~ion Ancl~rago Run 1' 15 - April - 1993 DLL/AC/CNIGR 8129 1341 Tape Subfile 2 is type: LIS TAPE HEADER ~ PRUDHOE BAY UNIT OPEN HOLE WIRELINE 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 lST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN1 5927.00 ESARY/DAHL SEE REMARKS REMARKS: D.S. 3 - 20A 500292098000 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 29-APR-93 OPEN HOLE RUN2 RUN3 10 i0N 15E 194 422 62.00 28.00 DLL/AC/CN/GR LOGS WITNESSED BY: M. WILSON, D. ADDIE, N. SCALES. CIRCULATION STOPPED: 11:30 13-APR-93. LOG TIED TO D.S. 3-20 CBL-GR (16-JUL-83) AT WINDOW. LOGGED GR TO 8000' FOR TIE-IN TO CBL-GR. NEUTRON IS CORRECTED FOR 8.5" HOLE, NO CASING CORREC- TIONS, & CHISM FILTERING IS ACTIVE. $ 9.625 8106.0 8.500 9336.0 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) FILE HEADER FILE NUMBER: EDITED OPEN HOLE MAIN All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 1 PASS depth shifted and clipped curves; 0.5000 START DEPTH STOP DEPTH 8129.0 9277.5 8129.0 9341.0 8129.0 9308.0 8129.0 9284.0 GR (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH DT NPHI LL3 LLD 8129.0 8129.0 8129.0 8129.0 8129.0 8152.5 8152.5 8152.5 8154.0 8154.0 8165.5 8165.5 8165.5 8202.0 8202.0 8205.0 8205.5 8248.0 8249.0 8248.5 8265.5 8266.0 8266.0 8286.5 8287.0 8287.5 8287.5 8295.0 8295.5 8298.0 8298.0 8304.5 8304.5 8306.0 8305.5 8317.5 8317.0 8319.0 8319.5 8333.5 8333.5 8340.5 8340.5 8342.0 8342.0 8357.0 8357.0 8360.0 8360.0 8360.5 8361.0 8368.0 8368.0 8370.0 8370.0 8376.0 8376.0 8392.5 8392.0 8400.0 8400.0 8402.5 8403.0 8402.5 8405.5 8405.5 8419.5 8420.0 8419.5 8424.0 8424.0 8429.5 8429.5 8429.5 8430.0 8430.5 8437.0 8437.5 8437.0 8446.5 8446.5 8447.5 8447.0 8448.0 8448.0 8452.0 8452.0 8463.0 8463.5 8468.0 8467.5 all runs merged; no case 8474.0 8476.0 8476.5 8486.0 8492.0 8500.0 8510.5 8544.0 8549.5 8603.0 8613.5 8615.0 8616.0 8627.5 8630.5 8632.0 8633.0 8641.5 8642.0 8646.5 8648.5 8655.5 8657.0 8696.5 8697.0 8703.5 8705.5 8706.0 8719.0 8720.5 8722.5 8723.0 8731.0 8733.0 8739.5 8741.0 8744.5 8747.0 8752.0 8753.0 8754.0 8757.5 8758.0 8763.5 8766.0 8768.0 8769.5 8785.0 8814.5 8815.5 8828.5 8829.0 8831.0 8836.5 8837.5 8846.0 8847.0 8853.5 8859.0 8860.5 8474.5 8477.0 8487.5 8499.0 8510.0 8549.5 8613.5 8697.0 8703.5 8706.0 8721.0 8731.5 8758.0 8763.5 8766.0 8829.5 8838.0 8853.5 8476.0 8487.0 8500.0 8510.0 8549.5 8696.5 8703.0 8719.0 8732.0 8741.0 8757.5 8765.5 8770.0 8814.5 8476.5 8549.0 8697.0 8705.5 8723.0 8731.5 8740.0 8745.0 8747.5 8757.5 8763.0 8770.5 8829.5 8853.5 8492.0 8543.5 8602.5 8613.5 8615.0 8615.5 8627.0 8630.5 8632.0 8632.5 8641.0 8642.0 8646.5 8648.0 8656.0 8657.0 8722.5 8733.5 8752.5 8753.0 8753.5 8757.5 8768.0 8770.5 8786.0 8816.5 8832.0 8837.0 8846.5 8847.0 8859.0 8861.0 8865.5 8866.0 8870.5 8871.0 8883.04 8883.0 8886.5 8886.5 8893.0 8892.5 8893.0 8896.5 8896.0 8909.5 8909.5 8915.5 8915.5 8916.0 8916.5 8916.5 8916.0 8925.5 8926.0 8928.0 8927.5 8936.0 8935.5 8941.0 8941.0 8941.5 8941.5 8958.5 8958.5 8967.0 8967.5 8967.5 8968.0 8986.0 8986.5 8986.5 8987.5 8988.5 8989.0 8998.5 8999.5 9016.5 9017.5 9040.5 9042.0 9057.0 9058.5 9079.5 9081.5 9086.5 9088.5 9089.5 9091.5 9093.0 9094.5 9097.0 9098.5 9097.5 9097.5 9099.0 9100.5 9104.5 9105.0 9111.5 9112.0 9115.5 9115.5 9116.5 9116.0 9121.5 9122 . 0 9122 . 0 9121.0 9128.5 9128.5 9130.0 9129.5 9131.5 9132.0 9131.0 9136.5 9137.0 9137.0 9137.0 9137.0 9141.5 9141.5 9143.0 9142.5 9144.5 9145.0 9147.5 9147.5 9147.0 9161.0 9161.0 9163.5 9163.0 9164.5 9164.5 9167.5 9167.0 9170.0 9170.0 9170.5 9170.5 9183.0 9183.0 9195.0 9195.5 9197.5 9197.5 9200.0 9200.5 9202.5 9202.5 9203.0 9207.5 9207.0 9208 . 0 9208.0 9208.0 9208.0 9221.0 9221.0 9225.5 9238.5 9239.0' 9243.5 9253.0 9253.5 9264.0 9268.5 9269.5 9301.5 9302.0 9364.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DLL 2435 $ REMARKS: CN WN FN COUN STAT 9225.5 9239.0 9243.5 9243.5 9252.5 9239.0 9254.5 9253.5 9264.0 9269.0 9268.5 9364.0 9364.0 9364.0 RUN NO. PASS NO. 1 6 1 6 1 6 1 6 FUCT & NUCT WERE SHIFTED WITH NPHI. TENS & TEND WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : D.S. 3 - 20A : PRUDHOE BAY : NORTH SLOPE : ALASKA 9301.5 9302.5 9364.0 MERGE TOP MERGE BASE 8129.0 9277.5 8129.0 9341.0 8129.0 9308.0 8129.0 9284.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL3 DLL 68 1 OHMM 4 6 LLD DLL 68 1 OHMM 4 7 SP DLL 68 1 MV 4 8 NPHI 2435 68 1 PU-S 4 9 FUCT 2435 68 1 CPS 4 10 NUCT 2435 68 1 CPS 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 108 Tape File Start Depth = 9364.000000 Tape File End Depth = 8129.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27182 datums Tape Subfile: 2 363 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8000.0 8129.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PA S. $ : ARCO ALASKA INCORPORATED : D.S. 3 - 20A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB 4 4 21 990 60 6 4 4 10 579 41 1 4 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 8129.000000 Tape File End Depth = 7892.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: ' 68 1901 datums Tape Subfile: 3 33 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 6 0.2500 VENDOR TOOL CODE START DEPTH GR 8000.0 AC 8124.0 DLL 8128.0 2435 8125.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION TEMP TEMPERATURE GR GAMMA RAY CN COMPENSATED NEUTRON PCM PULSE CODE MODULATOR KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT MIS MASS ISOLATION SUB DLL DUAL LATEROLOG FTS FEED THROUGH SUB FTS FEED THROUGH SUB MIS MASS ISOLATION SUB AC BHC-ACOUSTILOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): STOP DEPTH 9293.0 9350.0 9325.0 9300.0 13-APR-93 FSYS REV. J001 VER. 1.1 1130 13-APR-93 1855 13-APR-93 9336.0 9348.0 8129.0 9341.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1603MA/1609EB 8.500 8106.0 8129.0 KCL POLYMER 9.70 58.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 20A : PRUDHOE BAY : NORTH SLOPE : ALASKA 10.5 5.2 174.0 0. 108 0.045 0.093 0.000 0.222 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 68.0 174.0 69.0 0.0 69.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 421 Tape File Start Depth = 9364.000000 Tape File End Depth = 7892.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 133185 datums Tape Subfile: 4 504 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 8697.0 AC 8697.0 DLL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 8697.0 8697.0 STOP DEPTH 9266.0 9330.0 9298.0 9272.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC-ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 13-APR-93 FSYS REV. J001 VER. 1.1 1130 13-APR-93 1823 13-APR-93 9336.0 9348.0 8129.0 9341.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1603MA/1609EB 8.500 8106.0 8129.0 KCL POLYMER 9.70 58.0 10.5 5.2 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) M~UD A~ MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 20A : PRUDHOE BAY : NORTH SLOPE : ALASKA 174.0 0. 108 0.045 0.093 0.000 0.222 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 68.0 174.0 69.0 0.0 69.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 CHT AC 68 1 LB 4 4 TTEN AC 68 1 LB 4 5 SPD AC 68 1 F/MN 4 6 RS DLL 68 1 OHMM 4 7 RD DLL 68 1 OHMM 4 8 SP DLL 68 1 MV 4 9 ED DLL 68 1 MV 4 10 ES DLL 68 1 MV 4 11 ID DLL 68 1 A 4 12 IS DLL 68 1 A 4 13 CNC 2435 68 1 PU-S 4 14 CNCF 2435 68 1 PU-S 4 15 CN 2435 68 1 PU-L 4 16 LSN 2435 68 1 CPS 4 17 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 183 Tape File Start Depth = 9337.000000 Tape File End Depth = 8697.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 48000 datums Tape Subfile: 5 264 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS 93/ 4/28 01 **** REEL TRAILER **** 93/ 4/28 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 APR 93 3:14p Elapsed execution time = 46.30 seconds. SYSTEM RETURN CODE = 0
