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Home My WebLink About197-098STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG rgCl.0t1VtU MAP 9 R on1n MAR 2 9 2019 zs 9 \6 A L•• LV IJ 1a. Well Status: Oil ❑ Gas 11SPLUG ❑ Other ElAbandoned 0 Suspended ❑ 20AAC 25.105 20AAC 25.110 Well Cl 0 rr� GINJ 11WINJ 1:1 WAG C1WDSPL ❑ No. of Completions: Zero 11b. Developm J�.Ju r91�a[7# Service ❑ Stretigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp.,Abantl ' 2/27/2019 14. Permit to Drill Number/Sundry 197-098 318-238 & 318-394 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 10/1/1997 50-029-21948-01-00 ' 4a. Location of Well (Governmental Section): S. Date TO Reached: 16. Well Name and Number: Surface: 871' FNL, 326' FWL, Sec. 19, T11N, R15E, UM . Top of Productive Interval: 2601' FNL, 1884' FWL, Sec. 20, T71 N. RISE, UM 10/26/1997 PBU 18-25A Ref Elevations 9. KB qg GL 17.70 BF N/A 17. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL Total Depth: 3248' FNL, 4289' FWL, Sec. 20, T11N, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface / Surface ADL 028321 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 692084 . y- 5961005 • Zone - ASP 4 14250'/ 8742' . 79-190 TPI: x- 698644 y- 5959446 Zone - ASP 4 Total Depth: x- 701067 y- 5958863 Zone - ASP 4 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/rvo: 1900' (Approx.) S. Directional or Inclination Survey: Yes ❑ (attached) No 0 13, Water Depth, if Offshore: 21, Re-drillLateral Top Window Submit electronic and printed information per 20 AAC 25.050MD/rVD: WA (ft MSL) - 12722'/ 8733' 22. 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 MWD, GR 23. CASING, LINER AND CEMENTING RECORD CASING Wr. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# HJg 30' 110' 30' 110' 30" 2150# Poleset 13-3/8'• 68# K -55'1--m 30' 3840' 30' 3492' 17-1/2" 2500 sx CS III, 600 ax Class'G' 9-5/8" 47# 1.410 29' 10047' 29' 8254' 12-1/4" 750 sx Class'G' 7" 29# L-90 9720' 11873' 8110' 8715' 8-1/2" 810 sz Class'G' 4-1/2" 11,5# L -e0 11518' 12722' 8670' 8733' 6-3/4" Uncemented Solid/Slotted Liner 2-3/8" 1 4.6# L-ro 1 11509' 14243' 8668' 8741' 2-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number, Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 3-1/2" 9.3# L-80 11522' 11518-18670- 1518'/8670'26. 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE �2/Z r pq VERIFIED Washydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed Yes ❑ No 0 information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production. Not on Produa Method of Operation (Flowing, gas lift, etc.): WA Date of Test: Hours Tesletl: Production tur Test Period y Oil -Bbl: Gas -MCF: Wafer -Bbl: Choke Sine Gas -Oil Ralio: Flaw Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API(com: Press 24 Hour Rate —.111, Form 10-407 Revised 5/2017 CO! INUEO ON PAGE 2 Submit ORIGINAL only MAR 2 9 2019 zs 9 \6 A 28. CORE DATA Conventional Cores) Yes ❑ No ® Sidewall Cores Yes ❑ No IZZ If Yes to either question, list formations and intervals cared (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. 29, GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes ❑ No El Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 11732' 8709• separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 10167' 8294' CGL -Zone 3 10470' 8402' Base of CGL - Zone 2 10665' 8468' TDF - Zone 1 11732' 8709' Formation at total depth: Zone 1 1 11732' 1 8709' 31. List of Attachments: Summary of Daily Reports, Photo Documentation, Wellbore Schematic Diagram 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Goofed Name: Worthington, Ams J Authorized Title: SIMS ciah Contact Email: Aras.Worthfington@bp.com Authorized Signature: Dat 3/rU/ IVi Contact Phone: +19075644102 INSTRUCTIONS General: This form is designed for submitting a complete and cored 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 10404 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 tb. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only TREE = TREE 318' FRAC ABANDONDED.� WE 09/04/18 REV BY JB/JM0 CDR AD= FMC 10/01/18 SAFETY NOTES: WELL ANGLE >70'IT 10560' •`• ACTUATOR= AXE_SON 8_25A TBG LEAK @ 7244' - REPAIRED W IIA SOZ ON 48.0' V%LL 12/27/99. CEMENT DONUT, ID = 2.80" FROM 7250- ELEII = 46.0' 11330' (FB M SOZ). BF. ELB/ = NA KOP= 55' -265'x 1400 TBG & FC PUNCH 255' -265- xAngle = 96. 13809' (11/15/18) Datum MD= NA TBG & PC PUNCH 260' - 265' Datum TVD = 88DO'SS (11/15/18) OA CMT (9130/18) 960'- 1570' x •' , SURF - 266' oA c1Jr TBG X w CMT (9/30/18) SURF -11670' TBG & PC PUNCH, 1570' - 1575' 6 SPF (09/01/18) wroc 1612 TOP OF DPZ1 1897' 3-1/2'CAM-TRDP TRSSSV, 1)=2.812' 13-3/8'CSG,6B#,L-80,D=12.415- 3$40•ESTTOC(09roi/18) TRSV & CONTROL LNE LOCKED OPEN 12/1/00 4370' ELM BOTTOM OF DPZ1 U.9731' —8137•3-1/2' OTIS XNP, D=2.813' 7567' I Or OF DPZ2&3 . .9-5/8• X 7' TNV LNR HGR 9703' D = 8.681 L-80, .0087 TBG PUNCH HOLES 0 4 SPF 11330' - 11340' I /- W HAKER LNR PBR D = 2.250• —L—ii—s09 R PBR X 2-3/8' LNR XO, D = 1.941' 11612' Minimum ID =1.941" @ 11512' BKR PBR" X 2-3/8" LNR XO OF 4-1/2' 30-0371 PERFORATION SUMMARY RE= LOG: NA ANGLE AT TOP PERF: 82 @ 11717' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL Oprg DATE _2-3/8• I DRLD 12680- 14212 C 10/27/97 11.5#. L-80..0155 bof. D = DATE REV BY I COMMENTS 08/49/89 I ORIGINAL COMPLEr LNR, FISH- MSC BKR BP PARTS LOST ON 04/08/00 (1/60 3/4" X 2' SS BANDS, Nr. / E(T. RUBBER BP ELEMENTS)- EXACT DEPTH LNCNOVML SOME DEBRIS FISHED @ 11450' CTM ON 04/23/00. T1W POLISHED RISER W/ X -PROF., D = 2.813 T:]TNVOVERSHOT SEAL ASSY W/GLIDE I� 7'X3-1/4' TNV SS PIOR, D = 3250• 5- TNV MLLOtIT FOR., D = 4.494• BOTTOM OF DPZ2&3 I = 1.941' D = 1.941' 4-112' LNR SDETRACK VMDOW 12722' - 12728' (OFF CMr PLUG) L-45, .0039 bpf, D = 1.941' I— 14243' %9"13 2-3/8' LNF WE 09/04/18 REV BY JB/JM0 CDR 09/04/18 MS/,MD TBG 10/01/18 TWJMD TBG 111/29/181 MB/JM) I TBG FISH- MSC BKR BP PARTS LOST ON 04/08/00 (1/60 3/4" X 2' SS BANDS, Nr. / E(T. RUBBER BP ELEMENTS)- EXACT DEPTH LNCNOVML SOME DEBRIS FISHED @ 11450' CTM ON 04/23/00. T1W POLISHED RISER W/ X -PROF., D = 2.813 T:]TNVOVERSHOT SEAL ASSY W/GLIDE I� 7'X3-1/4' TNV SS PIOR, D = 3250• 5- TNV MLLOtIT FOR., D = 4.494• BOTTOM OF DPZ2&3 I = 1.941' D = 1.941' 4-112' LNR SDETRACK VMDOW 12722' - 12728' (OFF CMr PLUG) L-45, .0039 bpf, D = 1.941' I— 14243' %9"13 PRIDHOE BAY LINT DEPTHS WELL: 18-25A NCK13-M TOC TA PERMITNo: 1970980 T, OA CMr (09/30118) API No: 50-029-21948-01 S (11/15/18) SEC 19, TI I N, RI 5E, 871' FN- & 326' FWL V%LL 2122/19) BP Exploration (Alaska) WELL NAME: 18-25A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9803' Set Cement Retainer 4370' 69 Bbls Class'G' 1570'- 1575' Tubing & Casing Perforation 275' 248 Bbls Class'G' 255'- 265' Tubing & Casing Perforation Surface 29 Bbls Class'G' Surface 15.5 Bbls AS I Daily Report of Well Operations 18-25A ACTIVITYr1ATF ci IKARAA 0v TWO = SSV/ 140/0. Temp = SI. Cement control line (Pre P&A). No AL or flowline. Established injectivity down the control line w/ -2 gallons of hydraulic oil. Mixed and pumped 1.88 gallons of squeeze crete down the control line. Tags hung. FWPs = SSV/140/0. 7/5/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1330 hrs. TWO = SSV/140/0. Temp = SI. PT Control Line (P&A). No AL or flowline. Performed passing PT on Control line with hydraulic fluid to 2780 psi. Control line pressure lost 30 psi in 15 mins and showed stabilization. Final WHPs SSV/140/0. 7/15/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1530 hrs. CTU #8 --- 1.75" COIL Job Scope: Plug & Abandonment MOL RIG UP. 8/22/2018 ***job continued on WSR 8/23/18 Job Scope: Plug & Abandonment Weekly Bop test. MU RIH w/WFD MHA and SLB 2.80 JSN OAL=14.18", (MAX OD=2.80"). Tag at 9938' ctm. PUH to 9850 painted yellow flag. Pumped 50 bbls 160F Surfactant. POOH jetting TBG. MU RIH w/ WFD FH1 trip retainer, OAL=9.91', (MAX OD=2.75"). Tried to RIH couldnt get past 11'. Pop off well check tools, WFD one trip retainer soft set during bleed down from pressure test. Missing 11 slip segments, recovered 1 segment recovered from inside bop cavity. MU & RIH w/ venturi to 9810ft. POH. Recovered 5 segments. 8/23/2018 ***Job in progress*** Job Scope: Plug &Abandonment MU RIH w/ WFD FH1 trip retainer, OAL=9.91', (MAX OD=2.75"). Set retainer at 9803ft. Pressure up CT & confirm WRP is holding. CBU. Pump & lav in 69 bbls of 15.8 ppg clas G cement. Pumping cement at .7 bpm. losing returns .4 bpm on return MM. Clean out to Estimated top of cement top at 3980' ctm. Lay 9.8pg brine from 3970'ctm to 1900' ctm. Freeze protect TB w iese rom 19 0' to surface 17 bbls diesel. WHIP 0 psi IA 64 psi OA 0 psi 8/24/2018 ***Job complete*** TWO = 0/40/Vac. Temp = SI. Pre - AOGCC MIT -T to 2500 psi, Max pressure = 2750, Target pressure = 2500 psi (P&A). No AL or flowline. Tbg FL @ near surface. IA FL @ 40' (2.5 bbls). Used 1 bbl of DSL to pressure up TP to 2750 psi. Performed 21 tests, last test TP lost 22 psi 1 st 15 min, 22 psi 2nd 15 min, 21 psi 3rd 15 minutes. SI bleed TP to start MIT 8/28/2018 IA. Continued on WSR 8-29-18. Continued from WSR 8-28-18. T/I/O = 2513/40Nac. Temp = SI. Pre - AOGCC MIT -T to 2500 psi, Max pressure = 2750, Target pressure = 2500 psi (P&A). No AL or flowline. Tbg FL @ near surface. IA FL @ 40' (2.5 bbls). Used 1 bbl of DSL to pressure up TP to 2750 psi. Performed 21 tests, last test TP lost 22 psi 1st 15 min, 22 psi 2nd 15 min, 21 psi 3rd 15 minutes. SI, bleed TP to start MIT -IA. Bleed TP & IAP to 0 psi pre pumping. Used 2.2 bbl of diesel to fill IA Void. Used 3.78 bbl of diesel to pressure IA to 2756 psi, IA lost 151 psi in the first 15 minutes, IA lost 48 psi in the second 15 minutes for a total loss of 199 psi in 30 minutes, MIT -IA PASSED. Bleed IAP to 0+ psi (3 bbl of fluid returned) before MIT -T re -test. Used .7 bbl of diesel to pressure TP to test pressure (2750 psi). Test 28 : TP lost 22 psi in the first 15 minutes, 19 psi in the second 15 minutes (PASS). Bled TP to 1500 psi & rig down, (20 gallons of fluid returned). Final WHP's = 1500/120Nac. 8/29/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 07:00 TWO = 1020/100/Vac. Temp = SI. WHPs (Post MIT). No AL or flowline. T & IA FL @ surface. TP decreased 480 psi, IAP decreased 20 psi overnight. 8/30/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:10 Daily Report of Well Operations 18-25A T/1/0=950/84/0 Temp=S/I (LRS Unit 42 -AOGCC MIT-T, MIT-IA) MIT-T PASS to 2514 psi. (2700 psi Max, 2500 psi Target) State Witness Brian Bixby Pumped 0.3 bbls diesel down Tbg. to reach max pressure. Loss Of 78 psi 1st 15 min, Loss of 40 psi 2nd 15 min.Loss of 29 psi 3rd 15 min. Pass by Brian Bixby. Bled back 0.5 bbls. MIT-IA PASSED to 2585 psi. (2700 psi Max, 2500 psi Target) Pumped 1.4 bbls diesel down IA to reach test pressure, Loss oft 14 psi 1st 15 min, Loss of 39 psi 2nd 15 min for a total loss of 153 psi. during 30 min test. SV,WV,SSV shut MV,IA,OA Open 8/31/2018 1FWHP=120/10/0 ***WELL S/I ON ARRIVAL*** (SLB ELINE DRIFT AND PUNCH) INITIAL T/I/O = 150/0/0. MIRU & PT. RUN 1: RIH W/ 2.30" CENT. & 1-3/4" SAMPLE BAILER TO TAG TOC AT - 4370' MD. RECOVERD - 1/2 CUP OF CEMENT (state witnessed). RUN 2: PUNCH THROUGH TBG & PC 1570'- 15-75'W/ 2" HYPERJET, 6 SPF, 60 DEGREES PHASE GUNS. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 300/0/200. 9/1/2018 ***JOB COMPLETE ON 01-SEPTEMBER-2018*** T/I/0= 180/150/160 Temp= S/I Cir-out (PLUG AND ABANDONMENT) Heat 100 bbls FW 9/25/2018 w/ F103 & U067 to 160*, Begin RU to choke trailer ***WSR Continued on 09-26-18*** ***WSR Continued from 09-25-18*** T/I/0= 180/150/160 Temp= S/I Circ-Out (PLUG AND ABANDOMENT) Pumped 64 bbls FW + additives, 134 bbls 9.8 brine & 15 bbls diesel down TBG taking returns up IA to FL of 18-24, Pumped 33 bbls FW + additives & 120 bbls 9.8 brine down TBG taking returns up OA to FL of 18-24, U-tube diesel to place FL in T/I/0, Pumped 5 bbls 60/40 spear followed with 67 bbls crude down 18-24 FL for FP, Tags hung on well, DSO notified of well status, Valve position at departure- WV, SV, SSV= Close, MV= 9/26/2018 Open, IA & OA= OTG, FWHP= Vac/Vac/15 T/I/O = 0/0/0. IA and OA valve removal. RD hardline from working side IA and OA valves. Remove working side 2" IA and OA valves. Install 2" Integrol flanges onto working side IA and OA side outlets. Torque to API specs. Remove companion side IA and OA 2" tapped blind flanges. Remove IA and OA companion side 2" FMC VR plugs. Install 2" Integrol flanges onto companion side IA and OA side outles. Torque to API specs. Install block valves onto all Integrol flanges. RU hardline onto working side IA and OA block valves. PT 9/28/2018 hardline. RDMO ***Job Complete*** Final T/I/O = 0/0/0. SEE LOG FOR DETAILS. T/I/O = Vac/Vac/Vac. Temp = SI. Bleed IA & OA to 0 psi. (P & A). IA & OA on Vac, no bleed requried. OA gauge reading -100 psin needs replaced. 9/28/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:54 SLB Fullbore Pumping Crew Scope: Plug and Abandonment. Pumped 15 bbls FW and 132 bbls 15.8 ppg Class G cement down TBG taking returns from OA, Did not get clean CMT returns to surface. SD and discuss w/Supt. Appears that TxIAxOA punch penetrated casing. Align valves to t ke returns from the IA. umpe s ppg as cement down TBG taking returns from the IA until out of CMT. Clean CMT returns from IA. DHD blew N2 across IA and OA casing valves, and small N2 cap to clear tree. Tags hung on MV, IA, OA. Tree and wellhead valves serviced. Operator notified. Class G cement in TBG from 1570'MD/1570'TVD to surface Class G cement in IA from 1570'MD1570'TVD to surface 9/30/2018 cement in OA from 1570'MD/1570"TVD to 961'MD/961'TVD (calculated) = 100/vac/vac. TBG/IA/OA FL (WIE Req). No flowline. TBG FL @ 305'(2.7 bbis), IA rulasSsG 90' (5.5 bbls), OA FL @ 40'(2.3 bbls). 10/1/2018 SV = C. MV = O. IA, OA = OTG. 10:30. Daily Report of Well Operations 18-25A TWO = 75/0+Nac. Temp = SI. OA Integrity test w/ N2 PASSED to 991 psi (P&A). No flowline or AL. IA FL @ 90', OA FL @ 30'. Used 5 bottles of N2 to pressure up OA from VAC to 1004 psi. OAP loss 13 psi in 5 min. No signs of activity @ surface for duration of test. OA FL @ 30'. Bled all WHPs to 0 psi. Hung tags. Final WHPs = 0/0/0. 10/3/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 T/1/0= 10/ONac. Temp = Sl. WHPs (post bleed). No AL or flow line. TP increased 10 psi, IAP unchanged, OAP went on a vac overnight. 10/4/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:30 ***WELL S/I UPON ARRIVAL*** (plug and abandonment) DRIFT TUBING WITH 2" CENT AND 1.75" SAMPLE BAILER. TAG TOC @ 275' SLM.(bailer returned empty) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*" 10/20/2018 ***SSV ONLY STROKES 3" OPEN*** T/I/0= 0/0/0. Removed 3" FMC upper tree. (SSV would not close all the way) Installed 3" CIW SSV and 3" FMC Crown valve. (Dry hole tree) PT 300 psi low 5000 psi high (PASS) *** Job Complete*** 10/26/2018 See log Final WHP's 0/0 ***WELL S/I ON ARRIVAL*** (SLB ELINE: PERFORATING) INITIAL T/l/O = 0//0. MIRU & PT. RUN 1: PUNCH TBG/PC AT 260'- 265'W/ 2" POWERFLOW, 6 SPF, 60 DEG PHASED GUNS. NO PRESSURE RESPONSE SEEN ON OA RUN 2: PUNCH TBG/PC AT 255' - 265' WLTH 2" HYPERJET, 6 SPF, 60 DEG PHASED GUNS AND MAGNET. NO PRESSURE RESPONSE SEEN ON OA RDMO. WELL LEFT S/1 ON DEPARTURE. FINAL T/I/O = 200/5/0. 11/15/2018 ***JOB COMPLETE ON 15-NOV-2018*** Wireless install (WOLP). Installed and pressure tested wireless pressure gauges on annuli. 11/16/2018 FCO complete and ready to turn over to Operations. T/I/O = 50Nac/Vac. Temp = SI. Thaw OA jewelry (P & A). No flowline, panel or AL. Dry hole tree installed. 1502 1/4 turn block valves installed on IA/OA. OA jewelry is free of obstructions. Verified by pumping 1+ gal hydraulic fluid. 11/17/2018 SV, SSV = C. MV = O. IA, OA = OTG. 01:00. T/1/0=70/0/0 (Circ Out -PLUG AND ABANDONMENT) Pumped .07 bbls 60/40 meth down Tbg and pressured up to 1200 psi. Pumped 6.6 bbls mix of 9.8 NaCl and 60/40 meth down OA andgot communication w/ Tbq. Circulated 10 bbls 60/40 meth, 15.24 bbls 9.8 NaCl and 1 bbls 60/40 meth down Tbg to OA and out to tank. Pumped 2 bbls 60/40 meth down OA to attempt integrity test, T x O LLR was 0.8 bpm at -550 psi and fell off quickly when pump disengaged. T x OA is fluid packed with NaCl with the exception of 2 bbls of meth at surface in the OA and <1 bbl of meth at surface in the TBG. 20 of 26 bbls circulated were returned to surface (6 bbls losses) DSO notified of well status per LRS departure. FWHP's=-14/-2/-11 SV,WV,SSV=C MV=O 11/18/2018 IA, OA=OTG Daily Report of Well Operations 18-25A SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment. Pumped 0.5 bbls 60/40 meth, 20 bbls FW, 29 bbls 15.8ppg Class G cement down TBG taking returns from OA, 11 bbis of "clean" 15.8 ppg cement returned to surface tank. -Worked cement bumpMg pressure over 30 minutes to get slight squeeze. Secured well and had grease crew service all valves on tree and wellhead. 15.8 ppg Class G cement in TBG from 265' MD/265 TVD to Surface 5.8 ppg Class G cement in OA from 265' MD/265' TVD to Surface 12/4/2018 ***Job Complete*** Pulled well house and tree platforms staged well house on east side of back pad in staging 12/6/2018 area took tree platforms off location, well sign on tree. *** JOB COMPLETE *** T/I/O = 0/0/0. Temp = SI. Strap T, IA, & OA (pre P&A). T has cement @ surface. IA 300'+. OA cemented to surface. 2/5/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 T/I/O = 0/0/0. Temp = SI. Strap TOC in IA (pre P&A). Shot IA FL with wireless echo meter @ 90' (6 bbls). Strapped IA @ 87'. 2/6/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:15 Job Scope: Top of IA from top of existing cement @ 87' to surface w/ 5.5 bbls AS1 cement Mix 10 bbis 15.8 ppg ASI cement in SLB pump truck. Pump slowly into [Awhile venting air from IA companion valve. Cement returns to companion side after 5.5 bbls away (equal to calculated fill -up volume) Circ additional 4 bbis across the top w/ good returns throughout. 2/12/2019 ***Job complete*** T/I/O= 0/0/0 POST CEMENT TREE WORK. R/D ASV #39 & SV. Leaving the MV. Installed tree cap assembely & torqued tree cap x MV to 543 ft lbs. R/D IA, OA & OA Comp. 2/14/2019 Iblock valves & install 1502 caps on intragals. RDMO. ***Job Complete*** FWHP= 0/0/0. Job Scope: Prep and cut wellhead 3' below tundra for full abandonment. Wellhead cut in 1 hr 23min. AOGCC replied to email and will be out at 3:30 PM to inspect/whitness cement to 2/22/2019 surface and approve welding of marker plate. . Job Scope : Weld marker plate on cut wellhead 3' below tundra.TBT/HOWF w/OSM. Open HWOF and CSE permits. Air quality checks and excavation inspection completed by Wells HSE advisor. Spot equipment and weld truck. Start gas monitoring, notify BP radio of CSE. Weld plate on 20" conductor complete. WSL got final pictures. AOGCC rep Lou Loubenstein inspected well stub for cement to surface, verified marker plate. and gave 2/27/2019 approval to backfill. Excavation crew in control of location. Job Scope: Excavate around Wellhead / Install Shoring Box (Permanent Plug and Abandon) Used an excavator to dig -12'x12' hole around wllhead to -14' deep (-75 cy). Assembled Engineered Modular Shoring Box and placed in excavation hole for wellhead cutting. After wellhead cut, cap welded and AOGCC inspection, pulled Shoring Box. Backfilled excvtion hole with removed gravel and deliniated aroundexcavatoin hole footprint. 3/1/2019 f tit '� a rte• ` �, r + •�_ �\� t �. .1`Y��' C ..gyp: •, • •� w a f� � 4 � • '• n: /` %L� a ray � . 'a . 1♦ ^ ( � L ` • ~ S •A`� ..moi : f!� '16* n ML MEMORANDUM TO: Jim Regg (�,7 P. I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission 5�Z4)tl. DATE: 2/27/19 SUBJECT: Surface Abandonment PBU 18-25A BPXA PTD 1970980; Sundry 318-394 2/27/2019: 1 traveled to Prudhoe Bay Unit Drill Site 18 to inspect the cutoff casing and marker plate that is to be installed on well 25A. The casing was cut below the required 3 ; feet from ground level, there was hard cement to surface in all casings. The marker plate had all the appropriate information and was ready to be installed. There was no , sign of oil spillage or seepage. Attachments: Photos (2) 2019-0227_ Surface_Abandon_PBU_18-25A 11.docx Page 1 of 2 •yoFr% • • ce\,\��yy��cv.), THE STATE Alaska Oil and Gas of e TT Conservation Commission � AL A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3672 Main: 907.279.1433 OF AL?rS11'P Fax: 907.276.7642 www.aogcc.alaska.gov Jaime Bronga 1- 1" Well Interventions Engineer JUN 1 BP Exploration(Alaska), Inc. P.O Box 199612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 18-25A Permit to Drill Number: 197-098 Sundry Number: 318-238 Dear Mr. Bronga: 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, Hollis S. French Chair DATED this(3 day of June, 2018. RBDMS RUK 13.Z . STATE OF ALASKA RECEIVED S ALASKA OIL AND GAS CONSERVATION CO ION APPLICATION FOR SUNDRY APPRLS JUN 0 6 20;8 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 •'•e.- •.r i h / Suspend RI • Perforate ❑ Other Stimulate 0 Pull Tubing 0 Chan.'- '`..v a Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 II' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 197-098 . 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 6. API Number: 50-029-21948-01-00• 99519-6612 Stratigraphic 0 Service 0 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 0 No 0 PBU 18-25A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028321 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14250• 8742 9750 8126 9750 11450 Casing Length Size MD TVD Burst Collapse • Conductor 80 20" 30-110 30-110 1490 470 Surface 3810 13-3/8" 30-3840 30-3492 3450/4930 1950/2270 Intermediate 10018 9-5/8" 29-10047 29-8254 6870 4760 Liner 2153 7" 9720-11873 8110-8715 8160 7020 Liner 1204 4-1/2" 11518-12722 8670-8733 7780 6350 Liner 2734 2-3/8" 11509-14243 8668-8741 11200 11780 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12679-14212 8733-8741 3-1/2"9.3# L-80 27-11522 Packers and SSSV Type: 3-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 11518/8670 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic 0 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development p Service 9 14.Estimated Date for Commencing Operations: July 1,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 ''I 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Bronga,Jaime be deviated from without prior written approval. Contact Email: Jaime.Brongat bp.com Authorized Name: Bronga,Jaime Contact Phone: 9075644151 Authorized Title: We L,terventions Engineer Authorized Signature: Date: 4 /2_,00 COMMISSION USE 0 Of Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1 2:„5? Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ( Spacing Exception Required? Yes 0 No g Subsequent Form Required: /0'4 O APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: b III I gb krt.- 6/// /t ORIGINALtcr‘ M JUN1320B C• - �/ RBD �1 � Submit Forma d Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplica e by41. S Well: 18-25 18-25 Suspend Well Intervention Engineer Jaime Bronga 907-632-5941 Production Engineer Chris Stone (907) 564-5518 History GPB Well 18-25 was initially drilled & completed in June 1989. The initial completion was in Zone 1A. The well was sidetracked into Z1A in 1997 and an IA cement job to repair TxIA was executed in 1999. The well was SI for unknown reasons in 2002 and subsequently could not be brought online even with N2 lifts. In 2006, downhole water samples suggested the well has a cretaceous leak and a caliper showed the tubing to be in poor condition with holes. The well was secured with a WRP that did not pass an MIT-T. An MIT-IA to 3000psi passed. An SCMT ran in 2008 shows the IA TOC to be 1612'md. Attempts to fish the failed WRP were not successful. The last SL tag was at 9842'slm. Well 18-25 has no future utility and has been fully approved by co-owners for permanent abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Attempt to reservoir P&A from above the WRP obstruction. Place a lower lateral cement plug by laying cement into the tubing to combine with the 1999 IA cement job. Place a lateral surface cement plug in the well. Cut off tubulars below pad grade and install marker plate. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Well History Notes: • Downhole samples showed cretaceous water in 2006 • Caliper shows holes in TBG 2006 • Well Secured with WRP 2006 • MIT-T failed at 1.9bpm @ 2900psi • MIT-IA passed to 3000psi • SCMT in 2008 shows IA cmt to 1612'md • SL last tagged with 2.80" gauge ring at 9842'slm • TRSSV locked out. WRDP 1-A out. Communication to control line established. • OA Integrity test to 1200psi passed. OA shoe has integrity. • TOC of 9-5/8" PC is 8137'md estimated with 30% washout. • In this part of the field, DPZ2 and DPZ3 do not have a seal and are in pressure communication and subnormally pressured. Procedural Steps Special Projects • 1. Cement control with 1.88 gallons each of Squeezecrete down to 1997'md at TRSSSV or treatment pressure of 5000 psi. a. Confirm injectivity prior to pumping cement. b. Control line is 1060ft/gallon. c. Follow Small Volume Cement Squeeze RP. Coiled Tubing - Reservoir P&A and Lower Lateral Cement Plug. 1. Drift for retainer, surfactant wash tubing. 2. RIH with cement retainer. Set at -9800'md above obstruction above WRP. 3. Attempt to establish injectivity into the formation with -20bbls of KCI. 4. If injectivity is established, pump until 2000 psi squeeze pressure is built or 19 bbls of cement are pumped. 5. Unsting from retainer and lay in -69bbls of cement to bring TOC in the tubing to -1900'md. 6. POOH pumping pipe displacement with 9.8ppg brine and a 500'md cap of diesel. Cement Calculations - Lower Cement Plug Total cement to pump 88 bbls Cement Type/Weight Class G 15.8 ppg batch mixed Field blend to by equal to lab +/-0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 1 Cement displacement 3 Cement contamination 1 Safety 1 Minimum required thickening time: 6 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 0 120 0 1:00 0 120 4000 2:00 60 100 4000 3:00 88 80 4000 4:00 88 70 4000 5:00 88 60 1000 6:00 88 60 1000 Fulibore - MIT-IA and MIT-T A067CC 1. MIT-IA to 2500psi with diesel 2. MIT-T to 2500 psi with diesel 55 2 • • Eline — Tag TOC, perforate through OA for surface plug G 1. Drift and tag TOC. — b C2S 2. Shoot 5' of perforations at —1600'md. Fullbore — Circ hydrocarbons from well /j4 �0 • Circulation point will be the perforation holes @ 1600'. • Fluid being circulated out will be diesel and crude. • The measured volume down to 1600' for the tubing is 14 bbls, the IA is 98 bbls, and the OA is 96 bbls. 1. Pump 100 bbls of hot surfactant wash (160F FW + 2 gpt of F103 and 2 gpt of U067) a. Take the first 50 bbls of returns from the IA 2. Pump 250 bbls of 9.8 ppg NaCI down the tubing taking returns as follows: a. Take 130 bbls of returns from the IA. b. Take 120 bbls of returns from the OA. c. If weather is freezable and cementing will not occur immediately consider freeze protecting with 5bbls of diesel u tubed. Fullbore — Place Surface Cement Plug 2. Swap to taking returns from the OA and pump 15 bbl FW spacer 3. Swap to 15.8 ppg Class G Cement and continue taking returns from the OA 4. Pump roughly 120 bbls of cement and take returns from the OA until clean cement returns are seen at surface. a. Shut in OA. 5. Pump an additional 110 bbls of cement taking returns from the IA. a. Shut in tubing and IA. Cement Calculations — Surface Cement Plug Total cement to pump 230 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM _ 0 Cement displacement 3 Cement contamination 1 Safety 1 Minimum required thickening time: 5 Cement Ramp for Blend Volume Pumped Temperature Pressure Time (bbls) (°F) (psi) 0:00 0 100 0 3 • • 0:30 150 100 1315 1:00 230 100 1315 2:00 230 90 1315 3:00 230 80 1315 4:00 230 70 1315 5:00 230 60 1315 Special Projects 6. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 7. Photo document all steps. 8. Cut off all casings and wellhead -1' below pad level. 9. Top off tubing and annuli with cement if needed. 10. Install marker cap on outermost casing string. The marker plate should have the following information bead welded onto it: a. BP Exploration Alaska b. Permit to Drill number- 1970980 c. Well Name— 18-25A d. API Number—50-029-21948-01 Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. 4 • • Pre-Job Schematic $ —•-- •- ii 7244',Rt03 AJ RED '1 ' 1 1 8-25A w - -, - 4141 DONUT ID.2 in 80: •• ,vnth returns to CLZEL) WL ANGLE>70' -..: •-•._'_•'-.'. tOC IA at 1612rnd 1999 in timi. su::::and . . .,,. L t III _ DPZ1: 1897'md . ID-'2 Z71-1 ItSit t 404 ,..440. NEtik!itiEl 1,41 , to 7587'md Ai ew 044 II um:C.1 or,..,.. . caffir fw auz.z27,% i--- le'I.941 @ 11 51,,,iimi pi=rai , .. . i II * ft lculated to : 2318" " :I'''. . 4744 3 0 g73-r 9-Ser X r"TIV,...NIR i•C_...._jti 137'md ' . , m....- r ww,im.e,r441 ith 30% i-80 CA,8 EA"=— .10" I 46 # .4 . ."1,, ,,X AS11°Ut : * .t. #' FIS4-MSC SKR tir.PARTS LOST'UN 04E4A00 f 010 it,L41 CCAJ Mt,Et,,21r yr a 7 ss twos.ea,iory fieeLLL 4LP ' e all*Att S'i EXACT iMPTHLANKNOV&SOW t'',I Ay, MEM FISNED 4!t"4NY CIO ON 0412313 ITS G RI.P.CH f-C LE: ,,". SW"337-''W' j I * 12.6B7-DO BAKER_'-; -.5. L _ ,5,7 H 11$09' i 1507 T.tVe Htl)hISEE w' ILO R PER 4 2ill".44.xr.:,. 1)... '----I-1T tis,--13-4-1,------ 4 , —r1 11 511-27-'i fri:47:0;ttlq)t SEX": A t'11 1151e Fir*3,-.4'rw ss PIG?,u -3251? I , %Auk.r s.'', 1 4 494° I ,, Ito!,Or 4''..,2'SOLO,,t4R H 1152e r DPZ2&3: 9703'md to H tine J , 1 r',1 11660'md /7-DJ( 2911 L.BO C37"trpf 0.6"64" H 11742' 1 4 1 Ii I I 12680' HET OF 2.-1.0"SOLD INK 0 1 t i- -- FOP Ot Z} CEtE LEO L NR,E.),'''EX"- - 1 0 14:0401-10-*.I 10,,,a ELXIVAt& t 1. 1 t I I REF L3G Nt, 1 t $ ANGIE A t t OP Pa* !..12 is 1.,t.r 4 o 4-1,2°'4404 SIOE1104,04 WA0004 Pt to ROO'la,Pf act.c.ior De,,g,Pekic*Poe 4AtA 1 ,212.7 '1,724'IC0# tV't Pt.uf,,:-..,,,. SLE SW PITE.PV.A.L. .."C.E.0.5q2 CIA rt 2-3F° DRL 0 '2680-'42'2 C ltkezir#7 i 41410A *.*, 11 104 0'SE 41 t>-3558 :TA ...AAA ''t",.., ''' ILIUM 14 Li,DREES)LNR,4'7 a ;4_,„.,1F. ,x,39to g..) ,, -,,t.. hi 14212s 12-3.e"LNR,4 70 FL-4.5.. 0039 bpi,ID- "94'* 14242' :...0*rt Rt',. 6' Cr_t 000.00..1 S. 00.TE- REV BY CO time,rs mUCA-CE 8A" LOX; 041294 00 0010GINAL COMPLETION C.7 - JO E TEE'PiC SET WM' WEI.L. "8,25A 1007,9T CID SIDETRACK f 18-2SA) PERMI%,,,4 970983. :29,C2 L'...x.EAK ai!Et:SCIONS (4r,° f.--m..)-Ln KB tiFV4 ro N COPMLL;TILIN A.-43 C4)"L1' °.:4:4 34 CM ,,,,P PETS','..."-CIThS BP Exploration LANs It 4,I 5 S • Post P&A Schematic ) - ( r4F4 8 ''''•- ' 0 7244'-FtEP/4FED 'I 8-25A w _ OMIT,10*280. -4. with returns to W).WELL ANGLE>70, lA at :prize nd .. .. d le'md 1999 _ ,mil_„,..... i ub„,..z.,.. al .... 'WSW 13-2 812- 1 Lateral -••• -,4 1 L-A Surface I __et 9 sr 10 rvp r"Pv v DPZ1: 18971rnd Plug in T, •••••,-k wo 1-40,D-'2 4 ":.:_11 38se 1 ,sej ed ” .. 3436 ‘406 IA,OA- - tO 7587'n-id Ad ta 1600md -wrt ID=1_94 is" 1'I 512" Afil 19:4/77.././y L PC cement 97 50 , Amine II I 4 1 - I , 1 IBKR PBR" X 2-3/8- ' " • W4 • ___i L ,,-, 10104' Ai i calculated to r ;ASH-tolir.BKTT op PAM tosr ox Gomm 4*60 , rimpompupr,,,p 1„4 i i,, j g 9 ''' 8137'md alM , *4*X?SS/WC&Oil i IX 1 filAillifi lop k iiIIIRAS) k.XAC I"Miiiii LittitY"stAL with 30% .12841S HOW @ 44.115CY Cly ON 04 23,113 4. washout , Egang ' ' '''' 94 IL--,- x e-• 15f4 r-, 2'15L- I 11509' I- 6044 -01 „ii ,_11507 i IA ID....t--ii-D 41347 isi DiDif D 2 8" Lower T , i .,...L...1 11512, 1,,,,_-i-- i IL:__I 11K-1.2. -1-[4;4 4,4.•4,.Lt 1 1",11,k 75 72'.‘:-A 7ilil CMTto -190Cemdaro .tro , time 11--. , .4-A..'SSV . - vx 138.1r EX 4 El 4 4' 1 ill DPZ2&31: ' 1152g I , 9703'rnd to so'---77-1 11717' 1,-- L. 11660'md , D ..„ _. . L.!,), -{- :/. - , _ _,...„..... ...._ 1 Imo, i lieifORATION StARL4V0 REF Loa No Mat AT TOP RIFt - 4 42- ts,A,-41Y M4,)1 WIN4X4,0t 44,40 14104404 t"114431:‘41414,08" -rt - sw igrERvAL LPL 0 •28-&:,-'42'2 - 6,. Cement here is eit.. •, 0.A dependent on t• 0 I .0,-.---- injectivity after setting retainer. ••• I .1124..14, - sm L 8;2 t'55 bpi O:,....1351"" H 12803* I. -2- MU 14212" air I:MLLE?-NR,4 7# it-15 4-1e 4° 1L1 ` 94"' El 14212, 1------ . 2-1V L144 4 44 1L-4c -4-4;,,L4,1 u L i1/444/3.,IS LIA 11 -. ,,- 1,14.4,1m,E BA, iivr :.,....1 4 41 0411GP4AL C OM PL LITTON 0?,'tig), . .., ,. 1 WELL .4 2.5A CT13 SIDETFtAC K 0&ISA I PETTMTP-A g 9709410 AP'v ',."- ,z,' L' , ' ' — BP IBtpbr*Bo n(Alas k st 6 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: /c/~3 GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED [] Logs of various kinds Complete Other COMMENTS: Scanned by:(~M~md-Damtha Nalhan Lowell TO RE-SCAN Notes: Re-Scanned by: E~ve,y Mildred Daretha Nathan Lowell Date: /si AI a I 1. Operations Performed: Stimulate OAnchorage OtherŒjSecure Well Abandon 0 Repair WellO Plug PerforationsD Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 1A7.OQ80 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21948-00-00 7. KB Elevation (ft): 9. Well Name and Number: 48.00 18-25A 8. Property Designation: 10. Field/Pool(s): ADL-028321 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 14250 feet true vertical 8693.0 feet Plugs (measured) Secured Well· 3-1/2" WRP @ 9750' (07/16/2006) Effective Depth measured 14212 feet true vertical 8741.0 feet Junk (measured) Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H·40 31 · 141 31.0 - 141.0 1490 470 SURFACE I 3828 13-3/8"68# K-55 30 - 30.0 - 3450 1950 SURFACE 13-3/8" 68# L-80 · 3858 - 3506.0 4930 2270 PRODUCTION 10075 9·5/8" 47# L-80 29 - 10104 29.0 - 8272.0 6870 4760 LINER 2011 7" 29# L-80 9731 · 11742 8116.0 - 8710.0 8160 7020 LINER 1210 4-1/2"11.5# L-80 11512 · 12722 8669.0 . 8733.0 7780 6350 LINER 2733 2·3/8" 4.6# L-80 11509 - 14242 8668.0 . 8741.0 11200 11780 Perforation depth: 'SGANNEn ~£P 2 7 2[j(iS ',' \."J \.. :,.,&,- '!,.,<'. - , .~ ...- Measured depth: Drilled Liner Interval 12680-14212 True vertical depth: Drilled Liner Interval 8733-8741 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L·80 @ 27 . 11511 Packers & SSSV (type & measured depth): 7" TIW SS Packer @ 11518 3-1/2" CAM-TRDP TRSSSV @ 1997 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft SIP .2 6 2UU6 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI 0 0 --- --- Subsequent to operation: 51 0 0 --. -- 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~ '2/. ~ ~Xp_ ./ Phone 564-5174 Date 9/21/06 aRECEIVED STATE OF ALASKA ., " ALASKA Oil AND GAS CONSERVATION COMMISSY2~ 2 2 Z006 REPORT OF SUNDRY WELL OF!~~I&º~commission . 9Þ.54 Form 10-404 Revised 4/2004 \ \'~A . . 18-25A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/23/2006 T/I/O= 150/6010 Temp= SII MIT T FAILED to 3000 psi. (Secure Well) Pumped 35 bbls crude down tubing to establish LLR= 1.9 bpm @ 2900 psi. MIT IA PASSED to 3000 psi. Pumped 12 bbls crude to pressure IA up to 3000 psi. 3rd test results- 1 st 15 min lost 40 psi, 2nd 15 min lost 30 psi with a total of 70 psi in 30 min test. Bled down pressure and hung tags. Final WHP's= 780/15010 07117/2006 T/l/0=30/120NAC Temp=SI TBG & IA FLs (pre-MITT & MITIA). TBG FL @ 42' < 1 bbl. IA FL @ 162' 10 bbls. IA casing valve has integral installed. 07/16/2006 RUN 8' 17/8 STEM, LSS, WI SLB E-FIRE RUNNING TOOL WI WEATHERFORD WRP PLUG (0.0.2.70" LENGTH 3.85') SET WRP AT TARGET DEPTH 9918' SLM, 9950' MD. ***LEFT WELL SHUT IN*** 07/15/2006 *** WELL SHUT IN ON ARRIVAL*** DRIFT TUBING WI 31/2" X-LINE TO 9927' SLM, STOP DUE TO DEV. COULD NOT LOCATE X-NIPPLE @ 8800' MD. RUN 2.25" CENT WI 31/2" B-LlNE BRUSH TO 8850' SLM, PULL UP LOCATE X-NIPPLE @ 8768' SLM. FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 47 Crude 48 TOTAL Page 1 TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV D = 3-18" FMC FMC AXELSON 48.0' N/A 1400' 96 @ 13809' NIA 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" H Minimum ID = 1.941" @ 11512' BKRPBR"X2~m"LNRXO 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I 18-25A . 3858' ]....J ~ I I 10104' ~ ~~ 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID 2.992" I ., I TBG PUNCH HOLES @ 4 SPF 11330' - 11340' : 12.687" OD BAKER LNR PBR, ID = 2.250" 1 BKR PBR X 2-3/8" LNR XO, ID = 1.941" I TOPOF 4-1/2" SOLID LNR I TOPOF 4-1/2" SLOTTED LNR 1 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11509' - 11512' - - ''r 2<; ~ 11528' I 11717' I S OTES: TBGLEAK@7244' - REPAIRED W IIA SQZ ON 12/27/99. CEMENT DONUT, ID = 2.80" FROM 7250-11330' (FB IA SQZ). WELL ANGLE> 70° @ 10560' & > 90° @ 11850'. 1997' H3-1/2- CAM- TRDPTRSSSV, ID = 2.812" I .. GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 * 3894 3535 36 MMG RKP 2* 8498 7250 33 MMG RKP * CEMENT (IA SQZ 12/27/99) 8800' H3-1/2" OTIS X NIP, ID = 2.813" 1 9731' H 9-5/8" X 7" TIW LNR HGR 1 9750' H3-1/2"WRP(07/16/06) I "-----I FISH - MISC BKR IBP PARTS LOST ON 04/08/00 ( #60 3/4" X 2' SS BANDS, INT. I EXT. RUBBER IBP ELEMENTS). EXACT DEPTH UNKNOWN. SOME DEBRIS FISHED @ 11450' CTM ON 04/23/00. 11502' -1TIW POLISHED RISER WI X-ffiOF., ID = 2.813" 11512' -TIW OVERSHOT SEAL ASSY WI GUIDE 1 11518' - 7" X 3-1/4" TIW SS PKR, ID == 3.250" I 11521" -15"TIWMILLOUTEXT., ID = 4.494" I I ~ .. I ......I 12680' - BTM OF 2-3/8" SOLID LNR, ID == 1.941" I /" I 12680' -TOPOF2-3/8"DRILLEDLNR,ID==1.941" I 11742' I PERFORA TION SUMMARY REF LOG: NA ANGLEA TTOP PERF: 82 @ 11717' Refer to Produetion DB for historical perf data SPF INTERVAL Opn/Sqz DATE DRLD 12680 - 14212 C 10/27/97 Note: SIZE 2-3/8" .... .... .... .... .... ~ .... .... .... .... .... .... .... .... .... .... .... """-- ~ ~~~ .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... I 14-1/2" SLIDLNR, 11.5#, L-80, .0155 bpf,ID==3.958" I DATE 06/29/89 10/27/97 2/29/02 06/15/03 09/13/03 02/04104 12803' I 4-1/2" LNR SIDETRACK WINDOW 12722' - 12728' (OFF GMT PLUG) PBID H 14212' I 12-3/8" DRILLEDLNR, 4.7#, FL-45. .0039 bpf,ID== 1.941" H 14212' I REV BY COMMENTS ORIGINAL COMPLETION CTD SIDETRACK (18-25A) CH/KAK CORRECTIONS CMOITLP KB ELEV A TION CORRECTION CMJITLP DATUM MD CORRECTION CMOITLP PERF CORRECTIONS I 2-3/8" LNR, 4.7#, FL-45, .0039 bpf, ID == 1.941" DA TE REV BY COMMENTS 07/16/06 TEL./PJC SET WRP ffiUDHOE BA Y UNIT WELL: 18-25A PERMIT No: "1970980 API No: 50-029-21948-01 SEC 19, T11N, R15E, 871' FNL & 326' FWL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECE\VED DEC 2 1 2005 ~ Oil & Gas eons. Ccmæi$SKJ1 Anchorage Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L1-15A 10715359 PROD PROFILE WIDEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE WIDEFT 07/16/05 1 D.S 18-03B 11057071 SBHP SURVEY 12/02105 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 1't7·ðq, 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07 i05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE WIDEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/0-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNEIt) JAN 2 5 2006 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD _/ .~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY~n THE MATER/AL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL M .A T. E IA E C:LOPJ~F~M. DOC W L U N._____~D E R TH IS M ARK E ~~-'--- . ~_~ STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Pertorate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 870' FNL, 4626' FEL, Sec. 19, T11N, R15E, UM At top of productive interval 2109' FNL, 472' FWL, SEC. 20, T11N, R15E, UM At effective depth At total depth 3247' FNL, 989' FEL, Sec. 20, T11N, R15E, UM 5. Type of Well: Development X Explorato~__ Stratigraphic__ Servia___ (asp's 692084, 5961004) (asp's 697217, 5959899) (asp's 701068, 5958862) 6. Datum elevation (DF or KB feet) RKB 49 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-25A 9. Permit number / approval number 197-098 / 399-187 10. APl number 50-029-21948-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3791' Production 9998' Uner 2153' Slotted Liner 1077' 14250 feet Plugs (measured) 8742 feet 11456 feet Junk (measured) 8656 feet IBP fish tagged @ 11456' MD (1/13/2000) Size Cemented Measured Depth True vertical Depth 20" 215o Sx Poleset 110' 110' 13-3/8" 2500 Sx cs ~ & 600 Sx C~ass G 3840' 3492' 9-5/8" 750 Sx C~ass G 10047' 8254' 7" 610 Sx C~ass G 11873' 8715' 4-1/2" Uncemented 12569' 8727' Perforation depth: measured 11717' - 12569' (4-1/2" slotted Liner); 12679' - 14212' (Pre-drilled Liner). (both under IBP fish) true vertical 8707' - 8727' (4-1/2" slotted Liner); 8733'- 8741' (Pre-drilled Liner). (both under IBP fish) Tubing (size, grade, & measured depth) 3-1/2", * RECEIVED Packers and SSSV (type & measured depth) 7" X 3-1/2" TIW SS Mech Set Packer @ 11519' MD. 3-1/2" Camco TRDP SSSV nipple @ 1998' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Anchorage 14. OiI-Bbl Prior to well operation (sh ut in) Subsequent to operation (shut in) Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ___X 16. Status of well classification as: Oil __ X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Erin Oba ~/) . Form 10-404 Rev 06/15/88 · Title Arco Engineering Supervisor Date Prepared by Pau/ Rauf 263-4990 SUBMIT IN DUPLICATE 18-25A ~ESCRIPTION OF WORK COMPLETED ANNULAR ISOLATION SQUEEZE Date Event Summary 10/09/1999: 10/30/1999: 12/02/1999: 12/03/1999: 12/04/1999: 12/27/1999: 1/08/2000: 1/09/2000: 1/10/2000: 1/11/2000: 1/13/2000: OMIT tubing x IA failed; LLR 1.3 bpm @ 2500 psi. RIH & pulled PXN plug. Drifted to 10057' SLM. MIRU CTU. PT'd equip. RIH & set IBP @ 11500' CTM to isolate the following production intervals: 11717' - 12569' MD (slotted liner) 12679'- 14212' MD (pro-drilled liner) PT'd tbg to 2000 psi- lost 150 psi in 5 minutes. POOH. PT'd tubing to 2500 psi - failed. Circulated 1% KCL Water. Tagged IBP @ 11488' MD. Pumped 2.8 bbls of 8 ppg sand slurry ontop of the IBP. Made a final TOS tag @ 11480'. PT'd tubing again & it failed. POOH leaving 1000 psi on wellhead. RIH & layed in 17 ppg mud f/11350' - 11476' CTM. Punched tubing circulation holes f/11330' - 11340' @ 4 SPF. POOH & FP'd well. OMIT of tubing & IA to 2500 psi - lost 500 psi in 15 minutes. RDMOL. AFB Annular Isolation Squeeze to eliminate annular communication caused by a tubing leak @ 7244' was performed as follows: MIRU. PT'd equip to 3000 psi. Stabbed onto well & pumped 120 bbls diesel, followed by 488 bbls of 11 ppg Litecrete Cement, followed by 68 bbls of 11 ppg mud, followed by 17 bbls of MeOH Water. Estimated TOO in IA @ 2530'. RD. WOO. MIRU CTU. PT'd equip. RIH & tagged TOO @ 7252' MD. Milled Cement to 9103'. Milled Cement to 11330'. Washed 17 ppg mud to 11460'. Tagged TOS @ 11466'. PT'd tubing to 2000 psi - passed. Unable to work fishing tool past GLM #2. RIH & attempted to latch onto IBP for retrieval. POOH without IBP. PT'd IA to 2000 psi - lost 150 psi in 15 min. RIH & tagged IBP @ 11456' CTM. Attempted to latch IBP but it did not appear to latch. POOH & recovered fish-neck & top sub of inner mandrel off the IBP. IBP is still inflated & exists in hole as fish. RD. This well is currently shut in. Additional work options to initiate production flow are currently being evaluated. RECEIVED 15 .000 _. AOGCC Geological Materials Inventory "l-b_lq PERMIT 9 7-098 ARCO Log Data DIR SRVY ~ SCHLUM 12624.-14103. PB1 Sent Recieved 10/14/1997 11/20/1997 Box DIRSRVY d..R/' SCHLUM 12575.14250. 10/26/1997 Completion Date 11/20/1997 Are dry ditch samples required? yes Was the well cored? Are tests required? Well is in compliance yes r~ no no And received? --~ye~s~ no Analysis description-recieved? ............ yes' Received? no Comments Friday, October 08, 1999 Page 1 of 1 . STATE OF ALASKA '-' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS "- 1. Type of request: Abandon _ Suspend_ '" Operational-shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 49 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 870' FNL, 4626' FEL, Sec. 19, T11N, R15E, UM 18-25A At top of productive interval 9. Permit number / approval number 2109' FNL, 472' FWL, SEC. 20, T11 N, R15E, UM 97-98 At effective depth 10. APl number 50-029-21948-01 At total depth 11. Field / Pool 3247' FNL, 989' FEL, Sec. 20, T11 N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: truemeasuredvertical 14250 feet8742 feet Plugs(measured) 0 R I 6 1 ~i A L Effective depth: measured 14250 feet Junk (measured) true vertical 8742 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 215o Sx Poleset 110' 110' Surface 3791' 13-3/8" 2500 Sx CS III & 600 sx Class G 3840' 3492' Production 9998' 9-5/8" 750 sx class G 10047' 8254' Liner 2153' 7" 61o sx Class G 11873' 8715' Slotted Liner 1077' 4-1/2" Uncemented 12569' 8727' Pre-drilled Liner 2734' 2-3/8" Uncemented 14243' 8741' Perforation depth: measured 11717' - 12569' (4-1/2"s/ottedL/ner); 12679'- 14212' (Pre-dr/lledLiner). truevertical 8707' - 8727' (4-1/2" slotted Liner); 8733'- a741' (Pre-drilled LineR E 6 E l V E D Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80, PCT @ 11511' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" TIW SS Mech Set Packer @ 11519' MD. 3-1/2" Camco TRDP SSSV nipple @ 1998' MD. ~[~t~a~l 0il & 13. Attachments Description summary of proposal __X Detailed operations program __ BOP ske~l~rl.~ora~8 14. Estimated date for commencing operation 15. Status of well classification as: September 29, 1999 16. If proposal was verbally approved Oil __X Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tony Singh @ 265-6282. Signed ~_ ~'.,,,~,¢, ~'~ Title: AAI Wellwork Design & Optimization Supervisor Date Erin Oba Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity __ BOP Test__/ Location clearance __ J Approval no.~C~ Mechanical Integrity Test _ Subsequent form required 10- ~)_ .~ · ORIGINAL SIGNED 13Y Approved by order of the Commission Robert N. Christenson .A^ CJ°~)~c°mmissioner Date / ~ '"',~'"~¢ Form 10-403 Rev 06/15/88 · - SUBMIT IN TRIPLICATE 18-25A Annular Isolation Squeeze Primary Objective Note: Primary objective is to cement the tubing x inner annulus with 11 ppg LiteCRETE cement to eliminate annular communication caused by a tubing leak and a possible casing leak. . RU CTU. Set IBP @ 11500' and sand plug to 11470'. Shoot circulation holes from 11440'-11450'. Establish circulation (pumping down tubing and taking returns up . Pump 119.5 bbls of filtered diesel, 524 bbls of 11 ppg LiteCRETE cement, 81 bbls of 11 ppg drilling mud, and 17 bbls of filtered diesel down tubing, taking returns from annulus. This will result in a cement plug from 1950' to 11513' in the tubing by casing annulus. 3. Wait on cement 7 days. Pressure test tubing, and inner annulus. 4. MilI/FCO to IBP. Pull IBP. 5. Return well to production. RECEIVED $£P 24 i999 & l~as Cons. ~ommisslon Anchorage Diesel to Surface Permafrost - 1800' 3-1/2" TRSSSV 1997' 13-3/8", 68#, 3858' Tubing / Casing Annulus Filled with 11 ppg Litecrete Cement 1950' - 11513' 3-1/2", 9.3#, 0-11512', production tubing 9-5/8", 47#, 10104' 2-3/8", 4.6#, 11509' ' 12679' liner Packer 11513' 7", 29#, 9731-11742' 2-3/8", 4.6#, 12679' - 14212' drilled liner 4-1/2", 11.5#, 11528'- 12728' 2-3/8", 4.6#, 14212' - 14242' liner 6 4 -3 2 COILED BOP iUB-[NG LIN EQUIPMENT 1. 5000 PSI 7" WELLHEAD CONNEC'I'OR FLANGE 2. 5000 PSI 4 1/16" PIPE RAI~S ,~. ~>000 PSI 4 1/6" HYDRAULIC ,SEIP$ 4~ 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS ~ ,,,nnn'pSI 4 1/16" STUFFING BOX . 3 2 H ] REL ] NE BOP .EOU] PHEN'I' 1. 5000 PSI ?" WELLHEAD CONNEC10R FLAN( 2. 5000 PSI WIR£LIN[ RAMS (VARIABLE' SIiZE) . 5. 5000 PSI 4 ;1/6" L UB'RICAiOR · . 4. 5000 PSI 4 1/6" FLOW 'I'UB[ PACK-.OFF ARCO ALASKA, INC. Tubing Casing Casing TRSSSV Gas Lift Mandrel/Dummy Valve 1 Gas Lift Mandrel/Dummy Valve 2 NIP PBR Liner Liner XO PKR Liner Perf Slotted Liner Perf Perf 12728' 4-1/2 SFF Window in Slotted Liner 10/28/97 Drilled Liner Liner TTL FISH ,~, 18-25A APl: 500292194801 SSSV Type: Annular Fluid: Gelled Diesel Reference Log: Last Tag: 8500 Last Tag Date: 1/23/99 Well Type: PROD Depth Annotations Depth Comment Prudhoe Bay Orig CompItn: 10/27/97 Last W/O: 9/23/97 Ref Log Date: RKB: 49 ff TD: 14250 ftKB Max Hole 96 dog @ 13809 Angle: Angle @ TS: deg @ 12728 12728' 4-1/2 S/T Window in Slotted Liner 10/28/97 Safety Notes Date Note 5/4/98 LDL Tubing Leak at 7244' Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 1997 1969 TRSSSV 3-1/2" Camco TRDP SSSV 8800 7497 NIP 3-1/2" Otis X Nipple 11509 8668 PBR 3-1/2 Baker Liner PBR ID=2.25 11512 8669 XO 3-1/2 X 2-3/8 Crossover ID=1.901 11513 8669 PKR 7° x 3-1/4' SS Packer 14242 8741 3-1'L 2-3/8 Guide Shoe Fish - FISH Depth Description Comment 14245 FISH Casing Strings - All Size Weight Grade 7.000 29.00 L-80 2.380 4.60 FL45 4.500 11.50 L-80 4.500 11.50 L-80 2.380 4.60 FL45 2.380 4.60 FL45 13.380 68.00 L-80 9.630 47.00 L-80 Tubing Strings - All Size Weight Grade 3.500 9.30 L-80 Gas Lift Mandrels/Valves Stn MD TVD Man Man Mfr Type 1 3894 3535 CAMCO MMG 2 8498 7250 CAMCO MMG (4) 4-1/2" Cent Arms & Bull Plug Top 9731 11509 11528 11717 12679 14212 0 0 Btm Feet Description 11742 2011 Liner 12679 1170 Liner 11717 189 Liner 12728 1011 Slotted Liner 14212 1533 Drilled Liner 14242 30 Liner 3858 3858 Casing 10104 10104 Casing Top 0 V Mfr Btm Feet Description 11512 11512 Tubing CAMCO DMY CAMCO EDMY 18-25A Angle (~ TD: 88 deg @ 14250 Rev Reason: Visual Last Update: 9/11/99 ID 2.810 2.810 2.250 1.900 0.000 0.000 Date 9/15/92 VType VOD Latch Port TRO Date VIv Run Commenl 1.5 RK 0.000 0 4/9/98 RD 1.5 RKP 0.000 0 6/28/89 (1) 1. RKED, STUCK, unable to pull 4/18/98 Perforations Interval TVD Zone Status 11717 - 12650 8706 - 8732 C 12650 - 12728 8732 - 8732 C 12679 - 14212 8733 - 8741 O FeetSPF Date Type Comment 933 0 7/7/89 SQZ Slotted Liner 78 0 8/17/97 SQZ Slotted Liner 1533 210/28/97 Drilled Ddlled Liner Liner RECEIVED SEP 24 t999 A aska 0it & Gas Cons, C0mini si0r, Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development~X RKB 49 feet 3. Address Explorato~.__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Servi~_~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 870' FNL, 4626' FEL, Sec. 19, T11N, R15E, UM 18-25A At top of productive interval 9. Permit number / approval number 2109' FNL, 472' FwL, Sec. 20, TllN, R15E, UM 97-98 At effective depth 10. APl number 50-029-21948-01 At total depth 11. Field / Pool 3247' FNL, 989' FEL, Sec. 20, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 14250 feet Plugs (measured) true vertical 8742 feet Effective depth: measured 14250 feet Junk (measured) true vertical 8742 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 2150 Sx Poleset 110' 11 o' Surface 3791' 13-3/8" 25oo Sx CS III & 6oo Sx Class G 3840' 3492' Production 9998' 9-5/8" 75o sx C~ass G 1 0047' 8254' Liner 2153' 7" 610 SX Class G 11873' 8715' Slotted Liner 1077' 4-1/2" uric@merited 12569' 8727' Predrilled Liner 2734' 2-3/8" uncemented 14243' 8741' Perforation depth: measured 11717'- 12569' (4-1/2~ Slotted lJner); 12679' - 1421'Z(PredrilledLiner). true vertical 8707' - 8727' (4-1/2" Slotted Uner); 8733' - 8741'(Predrilled Liner). 'ULTM¢'' 19 9 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 PCT @ 11511' MD. .~as~a 0ii & 8as C0r~e, 00remission, Packers & SSSV (type & measured depth) 7" X 3-1/2" TIW SS MECH SET PACKER @ 11519' MD. Anchorage 3-1/2" CAMCO TRDP SSSV @ 1998' MD. 13. Stimulation or cement squeeze summaryORIGINAL Intervals treated (measured) (see atfached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1033 19465 0 - 1151 Subsequent to operation 884 20425 11 1278 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedErin Oba .(~/ I,,I'¢/*,.,.~ Prepa[ed by Paul Rauf 263~4990, Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-25A DESCRIPTION OF WORK COMPLETED SET TUBING PATCH Date Event Summary 1/23/1999: MIRU. RIH & set lower patch assembly @ 7253' MD. POOH. RIH & set upper patch from 7239' - 7253' MD. POOH. RD. Returned well to production & obtained welltest data. Re: Wells capable of unassisted flow. Subject: Re: Wells capable of unassisted flow. Date: Fri, 04 Jun 1999 11:19:12 -0800 From: Blair Wondzei1 <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: PRB Problem Wells <P 1041 ~mail.aai.arco.com> Jerry, I just finished reading your comments on these wells. Your proposal sounds fine to me. I agree you should proceed as you've proposed. Blair 6/4/99 PRB Problem Wells wrote: Blair: This is a summary of the requests I have from Engineering to temporarily flow wells that are capable of unassisted flow: DS 3-34: Post packer cement squeeze; determine if capable of unassisted flow to surface. Has broken gaslift valve in station 4. Flow period approximately 1-week. DS 11-25: Documented hole below 5 1/2" x 3 1/2" crossover, needs patching. Needs flow testing after add perforations to determine if additional wellwork is needed prior to patching. Wireline tools will not be able to get below patch once installed. Flow period request for 2-4 weeks. DS 13-33: Documented hole in tubing, not economic to repair. Passed CMIT T x IA. Need flow test to determine if worthy to apply for Sundry Notice to continue flowing with known communication (capable of unassited flow). Flow period for 2-3 weeks. DS 16-31: SI since 1994 with leaking patch over GLM #10. Need flow test to determine if worthy to apply for Sundry Notice to continue flowing with known communication (capable of unassited flow). Flow period for 2-3 weeks. DS 18-17: Documented T x IA communication through corrosion holes. Request to flow well with corrosion probe installation for 4-6 weeks to determine corrosion_ rate for engineering study. This well is capable of unassisted flow. DS 18-25: Documented T x IA communication through corrosion holes. Request to flow well with corrosion probe installation for 4-6 weeks to determine corrosion rate for engineering study. This well is capable of unassisted flow. I can provide more detail, but the main concern is that these wells are, or may be, capable of unassisted flow and have known communication. At the termination of these flow tests the wells will be SI and secured. Let me know if you need additional information, and whether these short-term flow tests are worth bothering you with. Thanks ! Jerry Dethlefs Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 05/24/99 10:34:46 AM To: PRB Problem Wells/AAI/ARCO cc: Subject: Re: Wells capable of unassisted flow. Jerry, These types of problems are in a poorly defined area of our regulation, therefore my practice has been to check on the regulation goals of protection of casing. If the casing appears to be protected, then agree that the request is appropriate. For example if you have a "minor" tubing leak in a gas lift well, this is not much different than having a choke in a gas lift mandrel - so no problem. My suggestion is that by E-mail you provide data on the the specific wells such as depth of leak, severity, type of lift, why annulus will not be subjected to well bore fluids and similar thoughts that come to mind. We can evaluate and advise (on most I'm sure) that there is no problem with continued production. Lets give this a try. Thanks. Blair. PRB Problem Wells wrote: 1 of 2 6/4/99 11:21 At Re: ~qells capable of unassisted flow. > > Blair: As a producrion well develops T x IA communication it has always been our > practice to SI the well except for very short periods of time we may need to do > diagnostics. The wells have been repaired and tes¢ed prior to resuming routine > production. As you have noticed, recently we have been evaluating several wells > with iow future potential, especially due to the cost of RWO's. It has been > great to get approval for some of these wells (14-40, 14-06) to continue to flow > with known communication problems. I expect more of these requests to come your > way. > As part of the process to develop a Sundry we have found it necessary to flow > these wells for a limited period of time prior to submission of the 10-403 to > figure out if they are even worth producing on a routine basis. In addition, I > receive requests periodically from the Engineering staff to flow other wells > capable of unassisted flow that have not yet been repaired, or have some other > diagnostic or evaluation requirement needed. Since the frequency of these > requests have increased, I feel some guidance from you is in order so we don't > risk operating wells out of compliance. > I currently maintain a list with my alternate of wells that have been requested > for flow by Engineering. This list now has 7 wells capable of unassisted flow, > of which 2 wells are currently on line. The list includes the well name, purpose > of flowing the well, approximate duration (1-6 weeks), the date brought on line, > and the mechanical condition or problem with the well. Our criteria is based on > flowing the well no longer than is needed to obtain the requested data; in other > words, flowing for production of oil is not a legitimate request. At the > termination of the flow period the well is SI, secured, and removed from the > list. > Do you want to be informed of the wells on this list, given the short duration > of these tests? This is a fairly new procedure for us to use, but has be very > useful for tracking' these situations. Should you want to be kept informed at > this level of detail, I could periodically forward the list to you. Let me know > what you prefer. Thanks! > Jerry Dethlefs > ARCO Problem Wells Specialist 2 of 2 6/4/99 11:21 AM ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 May 25, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conse~ation Commission 3001 Porcupine Dhve ~chorage, Alaska 99501-3192 Re: Flow testing of xvells capable of unassisted flow to the surface. Dear Mr. Wondzell: This letter is in response to your emails on May 25 regarding justification for flow testing of wells capable of unassisted flow to the surface. The folloxving text provides a brief reason for the flow test, as well as arguments why casing damage should be minimal. In all cases, the wells will be tested for a limited duration and then shut-in and secured until approved by your office for some action (via 10-403) or the well is repaired. Tracking of the flow testing duration will be done from the Problem Wells Specialist office. DS 3-J~Had a failed packer, which has recently been cement squeezed to regain pressure integrity to the tubing string. It has subsequently been tested to not be capable of unassisted flow to the surface, so an exemption for flowing is not requested. DS 11-25: Has a documented hole below the 5 1/2" x 3 1/2" crossover as per LDL 5/4/98. This single hole needs patching, since the well is capable of unassisted flow to the surface. Casing damage is not expected to be a concern, since the well will require gaslift and the annulus will be gas filled. Flow testing is requested prior to patching since perforations were added and need to be evaluated before a patch is set. Additional perforations or a squeeze may result post flow-test. A patch in the 3 1/2" tubing will not allow further downhole work without the patch being pulled, and subsequently reset before sustained production. The flow period request is for 2-4 weeks. DS 13-33: Has a documented hole in the tubing at a failed non-retrievable patch set over GLM # 10 in 1990. The well has been shut-in since 1995, and does not have the reserves to justify a RWO to replace the tubing. The well passed a CMIT T x IA to 3000 psi in 1995. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslift from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. DS 16-31: SI since 1994 with leaking patch over GLM #10. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for a Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslift from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. A CMIT T x IA passed to 3000 psi in 1994. DS 18-17: Has documented T x IA communication through a corrosion hole at 4546'. The request is to flow the well after a corrosion probe installation for 4-6 weeks to determine the corrosion rate for an engineering study of the corrosion mechanism in the gravity drainage portion of the field. This well is capable of unassisted flow to the surface. Due to the GOR of the well and the single leak point, the annulus is expected to be gas-filled during the study period, which should minimize casing exposure to production fluids. The ~vell will be SI and secured after the study is completed. ! DS 1 ~-2~.' Has documented T x IA communication through a corrosion hole at 7244'. The request is to flow the well after a corrosion probe installation for 4-6 weeks for the corrosion mechanism study in the gravity drainage portion of the field. This well is capable of unassisted flow to the surface. Due to the GOR of the well and the single leak point, the annulus is expected to be gas-filled during the study period, which should minimize casing exposure to production fluids. The well will be SI and secured after the study is completed. I hope this letter provides enough explanation for approving a flow-test of these wells for a limited period of time. Please call or email if you need additional information. n~thlwee[~ Specialist ~ ARCO Tubing -- (0-11512, OD:3.500, ID:0.000) Alaska, TRSV -- (1997-1998, OD:3.500) Casing (0-10104, OD:9.630, V~:47.00) NIP (880688O1, OD:3.500) Liner (9731-11742, OD:7.000, '¢,~:29.00) XO (11512-11513, OD:3.500) Liner (11528-11717, OD:4.500, Wt:11.50) Perf (11717-12650) Perf (12650-12728) Sbtted Liner (11717-12728, OD:4.500, Wt: 11.50) Perf (12679-14212) FISH (14245-14246, OD:2.500) Inc. 18-25A PRB 18-25A API:1500292194801 i Well Type: i PROD SSSV T~r13e: I !l Orig Completion:i 10/27/97 Annular Fluid: I Gelled Diesel i Last W10:i9123197 Angle ~ TS: deg ~ Angle ¢, TD:I88 deg ~ 14250 Rev Reason: i Corre~:tions by lmO Last Update: 12J14/99 Reference Log:t ! Ref Log Date:i Last Tacj: i 8500 i TD:i 14250 ftKB Date:i 1/23/99 ': Max_Hole Angle:!96 deg @ 13809 Casing String - PRODUCTION Size Top Bottom TVD Wt Casing String - LINER Size Top 7.000 9731 2.380 115O9 4.5O0 11528 4.500 11717 2.380 12679 2.380 14212 Grade 9.630 0 10104 8272 47.00 L-80 Bottom TVD : Wt Grade 11742 8709 ! 29.00 L-80 12679 8733 4.60 FL45 11717 8706 ' 11.50 L-80 12728 8732 11.50 L-80 14212 8741 4.60 FL45 14242 8741 4.60 FL45 Casing String - SURFACE Thread Thread Size Top ! Bottom ~ TVD Wt i Grade i Thread 13.380 ~ 0 3858 3506 ~ 68.00 : L-80 ~ Tubing String - TUBING Size ' Top Bottom TVD ' Wt ' Grade ! Thread. Comment 3.500 ; 0 11512 : ._~66~9 i___ 9.30 L-80 Perforations Summary Interval i TVD 11717-12650! 8706-8732 Zone Status;Feet SPFi Date. Type : C 933 i 01 7/7/89: SQZ Slotted Liner 12650- 126791 8732 - 8733 ~: C ; 291 018/17/97tSQZ i Slotted Liner 12679- 14212i 8733-8741 i O i 15331 21 0/28/97.,Drilled iDdlled Liner , i ~ i Liner Gas Lift Mandrels/Valves Stn MD IT VD! Man Man i VMfr I I Mfr Type 1 i 3894 35351CAMCOi MUG i CAMCO 2 i 8498 72501CAMCO1 MMG I CAMCO 1. RKED, STUCK V Type DMY EDMY V OD Latch Port i TRO Date Vlv I Run iComment 1.5 RK 0.000 0 4/9/98 tRD t 15 I RKP !00001 01 6/28/89 Other (plugs, equip., etc.) - JEWELRY Depth199711TVD196911 TRsvType 3-1/2" Camco TRDP SSSV Description 74381 63821 PATCH I Eclipse Tubing Patch, Series III, (15') installed 2/3/99 88001 7497! NIP ! 3-1/2" Otis X I~ipple ID 2.810 1.750 115121 8669! XO !3-1/2X2-3/8 Crossover ID=1.901 115131 8669! SEAL 13-1/2 T/W Overshot SealAsemblyw/.quide 2.810 115091 86681 PBR 13-1/2 BakerLinerPBRID=2.25 2.250 1.900 0.000 142421 8741 ! TTL 12-3/8 Guide Shoe 0.000 Depth Annotations Depth! Comment 12728i 12728' 4-1/2 SFF Window in Slotted Liner 10/28/97 ',Fish - FISH Depth ~ Description 142451 FISH General Notes Date i Note Comment 'FISH: _(4) 4-1/2" Cent Arms & Bull Plug (Lost 09/15/9~)_~ .~_~___ 4/17/98 I Unable to pull staff_on #2 5/4/98 I LDL Tubing Leak at 7244' .__.~ STATE OF ALASKA .._~.,. .... - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil_X Gas__ Suspended_ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-98 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21948-01 4 Location of well at surface 9 Unit or Lease Name 871' FNL, 326' FWL, Sec 19, T11N, R15E, UM. ~./'~'?/~.~ i ~[~ ;i'.':'i'i i-, .....: i:i". i~ PRUDHOE BAY UNIT At Top Producing interval i' ?' ! 10 Well Number 2109' FNL, 472' FWL, Sec 20, T11N, R15E, UM. ,'! :~:'; ~ . Ii 18-25A At Total Depth ? .' ~i!- ' ~ 11 Field and Pool 3247' FNL, 989' FEL, Sec 20, T11N, R15E, UM. i; ,,':~'~-""_____ ;... --....--- _--~~--'-'";~~ PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 48' RKB ADL 28321 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 10/1/97 10/26/97 10/27/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 14250' MD / 8693' TVD 14250' MD / 8693' TVD YES_X NO 1997' feet MD 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30" 2150 Sx Poleset 13-3/8" 68# K-55/L-80 Surf 3840' 17.5" 2500 Sx CS III & 600 Sx Class G 9-5/8" 47# L-80 Surf 10047' 12.25" 750 Sx Class G 7" 29# L-80 9720' 11873' 8.5" 610 Sx Class G 4-1/2" 11.5# L-80 11492' 12569' - - Uncemented (Slotted Liner) 2-3/8" 4.6# L-80 11509' 14243' 2.75" Uncemented (Pre-drilled Liner) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Slotted Liner interval: 3-1/2" Tbg 11511' 11518' 11717 - 12569' MD; 8705 - 8678' TVD and 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 2-3/8" Pre Drilled Liner interval: 12679 - 14212' MD; 8684 - 8692' TVD 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 11/4/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 11/5/97 6.6 'TEST PERIOD --I 9571 Flow Tubing Press 'Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 908 24 HOUR RATE _X 1729 16549 69 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 5/30/97 (issued Permit # 97-98). RECEIVED 0 i997 Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Naska 0il & Gas Cons. commission Anchorage NAME Top Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 10167' TRUE VERT DEPTH 8293' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Summary of 18-25A Coil Tubing Wellbore Extension Drilling Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Engineering Supervisor Date 7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injectio~,~ E C [ iV E D Gas Injection, Shut-In, Other-explain. '2 0 9_97 A~ch0ra~ e 18-25A DESCRIPTION OF WORK COMPLETED CTU WELLBORE EXTENSION DRILLING 8/17/97: MIRU CTU & PT equipment. RIH w/nozzle & tagged top of fish (four 4-1/2' Centralizer Arms & Bull Plug lost 9/15/92) at 12770' MD. PU & pumped 9 bbls of 17 ppg Class G cement on top of fish to place a cement plug in the 4-1/2" slotted liner to 12650' MD in preparation for CT Wellbore Extension Drilling operations. POOH. RD. 9/27/97- 9/28/97: MIRU CTU. Test BOPE. Bullheaded down 215 bbls KCl Water to kill well, then displaced CT w/FIo-Pro. 9/29/97: Fluid losses at 8 - 12 bph. RIH w/nozzle to 11700' & pumped LCM pills to slow losses to 3 bph. POOH w/CT. 9/30/97: MU & RIH w/3.8" underreamer while circulating in FIo-Pro. Reamed through 4-1/2" slotted liner from 12300' to hard cement at 12562' MD. Added 120 bbls biozan to system and underreamed cement plug to 12675' MD, 10/1/97: Underreamed cement to 12728' MD. POOH w/BHA. RIH w/window milling BHA. MD, then started milling a 2.75" window through the slotted liner at 12722' MD. 12727' MD, then drilled formation to 12731' MD. Tagged bottom at 12726' Finished milling window to 10/2/97: POOH w/milling BHA. RIH w/finishing mill & reamed multiple passes through window at 12722 - 12727' MD. 10/3/97: Continued reaming window, then drilled formation to 12742' MD. POOH w/BHA. RIH w/drilling BHA. horizontal 2.75" hole to 13002' MD, w/periodic shod trips to slotted liner top at 11650' MD. Drilled 10/4/97: Drilled to 13060' MD. POOH w/BHA. RIH w/drilling BHA & reamed hole to bottom. Drilled to 13210' MD. 10/5/97: Drilled to 13295' MD w/periodic shod trips. Circulated in new FIo-Pro, then drilled to 13414' MD. 40 bph. POOH to window. RIH pumping Hi-Vis pill. Mud loss at 10/6/97: Drilled to 13451' MD, w/mud loss up to 60 bph. PU to window & circulated LCM pill. squeezed to 1450 psi. POOH w/BHA. PT BOP. RIH w/drilling BHA. No mud loss. w/periodic shod trips to sweep hole. Hesitated 5 minutes & Drilled to 13542' MD 10/7/97: Drilled to 13555' MD. Mud loss back to 50 bph. PU BHA to park at 12683' MD. Circulated in new FIo-Pro & Hi-Vis pill. Squeezed well to 540 psi. Mixed & pumped two LCM pills. Squeezed to 1200 max psi. POOH w/BHA. RIH w/drilling BHA. Drilled to 13565' MD w/mud loss at 10 bph. 10/8/97: Drilled to 13754' MD w/mud losses back up to 50 bph. Tripped to window & added new mud to pits. RIH & drilled to 13774' MD. Lost all returns. PU to 12710' & pumped LCM pill. Squeezed away pill to 1200 psi. POOH w/BHA. 10~9~97: RIH w/drilling BHA. Drilled to 13839' MD. 10/10/97 - 10/11/97: Standbyto swap reel pipe. MIRU CTU. POOH w/BHA. RIH w/drilling BHA. Blew down CT w/N2 & RD CTU for CT swap. 10/12/97: Drilled to 14100' MD w/mud losses up to 55 bph. Backreamed to window & pumped LCM pill. ..... ' 18-25A ......... DESCRIPTION OF WORK COMPLETED CTU WELLBORE EXTENSION DRILLING 10/13/97: Squeezed LCM pill away to 1000 psi. Circulated CCH. PT BOPE. RIH w/drilling BHA. Reamed down through shale section and stuck pipe at 12825' MD. Pumped Hi Vis pill and attempted to free pipe. 10114197: Attempted to free stuck pipe. Pumped LCM pill to slow losses. Circulated Crude & jarred on pipe. Pipe pulled up to 12774' and stuck again. Continued to work pipe while pumping Crude; no movement. Disconnected from BHA & POOH. RIH w/fishing BHA. Latched TOF at 12726' MD. Jarred on stuckfish. 10/15197: Jarred on fish; no movement. around BHA to dissolve LCM. POOH. RIH w/fishing BHA & latched fish at 12726'. Spotted 15 bbls Bleach Jarred on fish; no movement. Circulated Crude & POOH. RIH w/nozzle. 10/16/97: Pumped 3 bbls of Class G cement on top of fish. 12514' MD. Reamed cement to 12556' MD. POOH & WOC. RIH w/underreamer & tagged cement at 10/17~97: Underreamed to 12570'. POOH w/underreamer. RIH w/window milling BHA. Couldn't orient mill. POOH. 10/18/97: RIH w/window milling BHA. Oriented & started milling a window at 12569' MD through the 4-1/2" slotted liner. Milled window down to 12576' MD. POOH w/BHA. 10/19~97: RIH w/window mill & finished window to 12581' MD. POOH w/BHA. RIH w/dressing mill & dressed window. 10/20/97: POOH w/BHA. RIH w/drilling BHA & drilled a 2.75" hole w/FIo Pro to 12630' MD. 10/21 ~97: Drilled to 13000' MD w/periodic short trips to window. POOH w/BHA. 10/22/97: RIH w/drilling BHA. Drilled horizontally to 13350' MD. POOH w/BHA. 10/23/97: RIH w/drilling BHA. Drilled horizontally to 13577' & stuck pipe. pill into open hole & POOH w/BHA. Pumped Crude to free pipe. Pumped Hi Vis 10/24/97: RIH w/drilling BHA & drilled to 13740' MD w/mud loss at 45 - 60 bph. Spotted Hi Vis pill on bottom. 10/25/97: POOH to window. Losses slowed to 40 bph. RIH & drilled to 13875' MD. 10/26/97: Drilled to 13901' & stuck pipe. Spotted Hi Vis pill in open hole. Circulated Crude to free pipe, then drilled w/short trips to TD at 14250' MD. POOH w/BHA. 10/27/97: MU & RIH w/2-3/8" drilled & solid liner assembly. Landed BOL at 14243' MD; TOL at 11509' MD. Released liner & POOH displacing well to 1% KCI Water. RIH w/nozzle. POOH displacing well w/Crude. ND BOPE. 10/28/97: NU & test tree. RD & MOL. Placed the well on initial production & obtained a valid production test. Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Client ................... : ARCO ALASKA INC. Field .................... : PRUDHOE BAY Well ...................... DS 18-25A pt-1 API number ................ 50-029-21948-07 Job number ................ 40001673 Rig ....................... Nabors 3S County ............................ Prudhoe Bay State ..................................... Alaska Survey rel~ort NOV 20 1997 ~ska 0~i & Gas Cons. Com~ssion ~orage Spud date ................ : 26-Sep-97 Last survey date ......... : 13-Oct-97 Total accepted surveys...: 40 MD of first survey ....... : 12624.00 ft MD of last survey ........ : 14103.00 ft ..... Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor .... Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : RKB GL above permanent ....... : 17.00 ft KB above permanent ....... : 49.00 ft DF above permanent ....... : 48.00 ft ..... Vertical section origin. Latitude (+N/S-) ......... : -1955.68 ft Departure (+E/W-) ........ : 7330.00 ft ..... Platform reference point Latitude (+N/S-) ......... : -148.4444 ft Departure (+E/W-) ........ : 70.2980 ft Azimuth from rotary table to target: 110.00 degrees Geomagnetic data ---~ Magnetic model ........... : BGGM 1996 version Magnetic date ............ : O-Jan- 0 Magnetic field strength..: 57375 HCNT Magnetic dec (+E/W-) ..... : 28.55 degrees Magnetic dip ............. : 80.76 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 57375 HCNT Reference Dip ............ : 28.55 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 28.55 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.55 degrees (Total az corr = magnetic dec - grid conv) Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 1 12624.00 86.70 106.0 0.00 8681.40 2 12717.00 86.10 106.4 93.00 8687.24 3 12746.00 79.70 97.0 29.00 8690.83 4 12794.00 81.60 89.0 48.00 8698.64 5 12802.01 82.40 88.0 8.00 8699.75 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) 100f) type 7605.65 -1969.30 7698.26 -1995.19 7726.70 -2001.04 7771.94 -2003.50 7779.31 -2003.29 7377.00 7635.33 104.95 0.00 TIP 7466.13 7728.12 104.96 0.77 MWD 7494.26 7756.81 104.95 38.99 ~D 7541.52 7803.11 104.88 16.91 MWD 7549.43 7810.71 104.86 16.89 MWD 6 12832.06 85.10 86.9 30.10 8703.03 7 12862.17 87.98 88.5 30.10 8704.85 8 12886.00 91.30 89.9 23.80 8705.00 9 12917.05 90.95 88.0 31.00 8704.39 i0 12947.05 89.55 87.1 30.10 8704.26 1i 12977.23 89.49 84.7 30.10 8704.51 12 13000.00 90.80 82.6 22.80 8704.45 13 13037.11 92.20 79.7 37.10 8703.48 14 13071.00 94.50 80.8 33.90 8701.50 15 13101.83 95.53 83.2 30.80 8698.81 16 13131.00 94.70 85.5 29.20 8696.20 17 13161.86 93.77 87.5 30.90 8693.92 18 13191.95 91.95 87.6 30.10 8692.42 19 13217.20 90.20 89.6 25.20 8691.95 20 13238.78 88.63 91.9 21.60 8692.17 21 13277.23 88.65 94.1 38.40 8693.08 22 13307.01 90.05 96.6 29.80 8693.42 23 13337.18 91.95 99.5 30.20 8692.89 24 13367.00 90.60 100.9 29.80 8692.23 7806.93 -2001.93 7834.73 -2000.73 7856.97 -2000.40 7885.89 -1999.80 7913.69 -1998.49 7579.32 7839.25 104.80 9.56 MWD 7609.34 7867.97 104.73 10.94 MWD 7633.13 7890.90 104.69 15.14 MWD 7664.12 7920.73 104.62 6.55 MWD 7694.19 7949.50 104.56 5.36 MWD 7941.17 -1996.34 7724.21 7961.60 -1993.81 7746.87 7994.08 -1988.11 7783.51 8023.46 -1982.38 7816.86 8050.54 -1978.11 7847.24 8076.76 -1975.24 7876.18 8105.02 -1973.36 7906.94 8132.80 -1972.08 7936.97 8156.26 -1971.46 7962.15 8176.65 -1971.75 7983.75 8213.36 -1973.76 8022.08 8242.18 -1976.53 8051.75 8271.72 -1980.76 8081.64 8301.08 -1986.04 8110.96 7978.02 104.49 7.98 MWD 7999.33 104.43 10.86 MWD 8033.40 104.33 8.68 M~ 8064.31 104.23 7.52 MWD 8092.72 104.15 8.45 8120.09 104.08 8.34 MWD 8149.47 104.01 7.12 MWD 8178.30 103.95 6.06 MWD 8202.60 103.91 10.54 MWD 8223.63 103.87 12.89 MWD 8261.33 103.82 5.73 MWD 8290.80 103.79 9.61 MWD 8320.84 103.77 11.48 MWD 8350.57 103.76 6.53 MWD ORIGINAL Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 4O 13402.00 13433.18 13463.16 13493.11 13523.26 13594.00 13623.00 13663.00 13723.20 13753.00 13804.06 13862.58 13922.93 13975.89 14045.00 14103.00 91.55 92.35 91.40 91.30 89.85 87.60 87.80 88.60 89.73 87.90 87.67 87.55 91.10 89.90 87.74 87.74 105.2 35.00 8691.57 107.4 31.20 8690.51 109.2 30.00 8689.53 112.4 29.90 8688.82 114.6 30.20 8688.52 110.9 70.70 8690.09 109.8 29.00 8691.26 107.4 40.00 8692.51 103.1 60.20 8693.39 99.4 29.80 8694.01 99.8 51.10 8695.98 95.2 58.50 8698.42 99.1 60.30 8699.13 104.4 53.00 8698.67 108.1 69.10 8700.09 111.2 58.00 8702.38 8335. 8366. 8396. 8426. 8456. 8527. 8556. 8596. 8656. 8685. 8736. 8793. 8851. 8904. 8973. 9031. 80 -1993.94 92 -2002.69 89 -2012.10 77 -2022.71 91 -2034.76 50 -2062.08 47 -2072.16 44 -2084.91 41 -2100.74 85 -2106.55 07 -2115.07 11 -2122.64 86 -2130.09 29 -2140.88 21 -2160.21 16 -2179.70 8145.04 8174.97 8203.44 8231.38 8259.07 8324.24 8351.40 8389.29 8447.35 8476.57 8526.91 8584.85 8644.67 8696.53 8762.84 8817.42 8385.55 8416.70 8446.59 8476.26 8506.02 8575.84 8604.64 8644,48 8704,65 8734.40 8785.32 8843.38 8903.23 8956.18 9025.18 9082.84 103.76 103.77 103.78 103.81 103.84 103.91 103.93 103.96 103.97 lO3.9~ 103.93 103.89 103.84 103.83 103.85 103.89 12.58 7,50 6,78 10.70 8.72 6,12 3.85 6.32 7.38 13.85 0.90 8.03 8.87 10.25 6.20 5.34 Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Date: Well Name: October 14, 1997 Company: DS 18-25aPb. 1 APl#: Arco Alaska Inc. Location: 50-029-21948-07 Field: NSB, Alaska Rig: Prudhoe Bay Nabors 3S Anadrill Personnel: Field Crew: Cell Manager: Mark Brown Cell Engineers: Don Webb Doug Hinnaland RECE V NOV 20 1997 Field Support: ~aska 0ii & Gas Cons, C0mr~ssi0p - 0rage Alaska District Manager: Martin Varco Field Service Manager: Craig Brown Services Provided: MWD SHARP GAMMA RAY MWD SHARp (DSS) ORIENTER Operating Statistics: Total MWD Pumping hours: Total MWD Below Rotary hours: 177.75 Total MWD Footage: 220.25 Total MWD Runs: 1405 13 Job Performance: Service Dates 9/28 - 10/15f~'7 9/28 - 10/15/97 12700'__ 14105' ~2700'__ 14105' Directional: SHARP MWD was picked up on 9/28/97 to drill cement and tie in gamma ray marker @ 11831 . SHARp Gamma Ray and (DSS) was used from 12700' to 14105' which was TD, due to getting stuck in hole, and loosing bha. , Shocks: Anadrill constantly moniters shocks in realtime and recorded. realtime or recorded. Washout Detection: No major shocks were incountered in Washouts can be detected from monitering pump pressure, and motor differencial pressure with same pump rates. Anadrill appreciates the opportunity to provide Arco Alaska Inc. with Directional Survey (DSS) and Logging While Drilling (LWD). We look forward to continue working for you in the future. Sincerely, Mark Brown Cell Manager Craig Brown Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Survey report Client .................... ARCO ALASKA INC. Field ..................... PRUDHOE BAY Well ...................... DS 18-25A API number ................ 50-029-21948-01 Job number ................ AP1218 Rig ....................... Nabors 3s County/State .............. COUNTY: Prudhoe Bay State/Country ............. STATE: Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Magnetic field strength..: 57375 HCNT Depth reference Permanent datum .......... : GROUND LEV-EL Depth reference .......... : RKB GL above permanent ....... : 17.70 ft KB above permanent ....... : 30.30 ft DF above permanent ....... : 31.30 ft Vertical section origin. Latitude (+N/S-) ......... : -1955.68 ft Departure (+E/W-) ........ : 7330.07 ft ..... Platform reference point Latitude (+N/S-) ......... : 70.2980 ft Departure (+E/W-) ........ : -148.4444 ft Azimuth from rotary table to target: 110.00 degrees RECE VbU 20 ~k¢ 0ii & Gas 0or~$, Com~ssion Spud date ................ : 26-Sep-97 Bast survey date ......... : 25-0ct-97 Total accepted surveys...: 34 MD of first survey.- ...... : 12575.00 ft MD of last survey ........ : 14250.00 ft Geomagnetic data -- Magnetic mode .... : BGGM 1996 version b Magnetic date ............ : 28-Sep-97 Magnetic dec (+E/W-) ..... : 28.55degrees Magnetic dip ............. : 80.76degrees .... MWD survey Reference Criteria Reference G ............... 1002.68 mGal Reference H ............... 57375 HCNT Reference Dip ............. 80.76degrees Tolerance of G ............ +/-3.0mGal Tolerance of H ............ +/-7.00 HCNT Tolerance of Dip .......... +/-.3degrees Corrections Magnetic dec (+E/W-) ..... : 28.55degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.55degrees Total az corr = magnetic dec-grid cony Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 1 12575.00 86.70 106.4 0.00 8678.59 2 12581.00 86.70 106.3 6.00 8678.94 3 12603.70 84.16 98.0 22.70 8680.75 4 12660.90 89.19 91.8 57.20 8684.07 5 12740.87 92.02 93.5 80.00 8683.22 6 12800.92 93.00 99.5 60.00 8680.59 7 12861.22 90.17 101.4 60.30 8678.92 ~ 12921.22 88.08 94.8 60.00 8679.84 9 12979.42 88.46 98.9 58.20 8681.60 !0 13036.89 88.32 89.5 57.50 8683.22 !1 13061.90 89.86 91.3 25.00 8683.62 12 13121.89 91.15 94.4 60.00 8683.09 lq ~181 92 91 37 97.7 60.00 8681.77 14 13242.04 90.40 100.2 60.10 8680.84 15 13302.09 92.30 104.2 60.10 8679.42 16 13329.02 92.70 104.5 26.90 8678.25 17 13382.28 90.60 101.6 53.30 8676.71 !8 13442.23 85.35 98.8 59.90 8678.83 19 13499.20 82.70 103.4 57.00 8684.77 20 13542.36 85.25 106.7 43.20 8689.30 21 13599.40 90.50 102.0 57.00 8691.42 22 13645.00 89.80 102.0 45.60 8691.30 22 13675.00 90.35 100.9 30.00 8691.26 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) 100f) type 7556.89 -1955.68 7562.87 -1957.37 7585.27 -1962.13 7640.35 -1966.99 7716.70 -1970.69 7330.07 7586.48 104.94 0.00 TIP 7335.82 7592.46 104.94 1.66 MWD 7357.92 7615.04 104.93 38.12 MWD 7414.77 7671.23 104.86 13.94 M~ 7494.67 7749.43 104.73 4.13 MWD 7774.96 -1977.47 7834.39 -1988.40 7893.06 -1996.85 7949.69 -2003.79 8004.94 -2007.99 7554.19 7808.73 104.67 10.12 MWD 7613.46 7868.83 104.64 5.65 MWD 7672.82 7928.41 104.59 11.54 MWD 7730.57 7986.04 104.53 7.07 MWD 7787.83 8042.53 104.46 16.34 MWD 8028.48 -2008.17 8085.81 -2011.15 8144.01 -2017.47 8202.99 -2026.82 8262.49 -2039.46 7812.82 8066.78 104.42 9.47 MWD 7872.74 8125.56 104.33 5.60 M~ 7932.38 8184.92 104.27 5.51 MWD 7991.73 8244.75 104.23 4.46 MWD 8050.46 8304.77 104.22 7.22 MWD 8289.24 -2046.10 8342.11 -2058.13 8401.07 -2068.68 8457.04 -2079.53 8499.84 -2090.69 8076.50 8331.65 104.22 2.10 MWD 8128.39 8384.91 104.21 6.72 MWD 8187.29 8444.59 104.18 10.01 8242.91 8501.18 104.16 9.43 MWD 8284.39 8544.13 104.16 9.62 MWD 8556.48 -2104.79 8601.64 -2114.27 8631.31 -2120.23 8339.54 8601.05 104.16 12.36 MWD 8384.14 8646.62 104.15 1.54 MWD 8413.54 8676.58 104.14 4.10 MWD L Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) 24 13718.00 93.10 104.5 43.00 8689.96 8673.93 -2129.67 8455.46 8719.54 104.14 10.53 ~*~ 25 13762.00 95.62 111.0 44.00 8686.61 8717.74 -2143.04 8497.22 8763.30 104.16 15.80 MWD 26 13809.00 96.10 113.2 47.00 8681.81 8764.46 -2160.59 8540.55 8809.61 104.20 4.56 tcS~D 27 13843.00 92.60 115.3 34.00 8679.24 8798.26 -2174.48 8571.47 8842.99 104.23 12.15 ~D 28 13881.00 89.30 114.9 38.00 8678.61 8836.10 -2190.60 8605.87 8880.30 104.28 8.75 MWD 29 13925.00 86.00 115.7 44.00 8680.41 8879.87 -2209.38 8645.61 8923.45 104.34 7.72 MWD 30 13960.00 85.00 117.0 35.00 8683.16 8914.55 -2224.87 8676.88 8957.58 ~04.38 4.68 MWD 3! 14015.00 87.70 120.0 55.00 8686.66 8968.82 -2251.06 8725.10 9010.81 104.47 7.33 MWD 32 14200.00 89.00 121.0 185.00 8691.98 9150.64 -2344.91 8884.43 9188.67 104.79 0.89 MWD 33 14232.60 89.74 122.3 32.60 8692.34 9182.57 -2362.01 8912.18 9219.87 104.84 4.59 MWD 34 14250.00 88.00 122.0 i7.40 8692.69 9199.57 -2371.27 8926.91 9236.48 104.88 10.15 MWD Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Date: Well Name: Company: API#: Location: Field: Rig: October 26, 1997 DS 18-25a Arco Alaska Inc. 50-029-21948-01 NSB, Alaska Prudhoe Bay Nabors 3S Anadrill Personnel: Field Crew: Cell Manager: Mark Brown Cell Engineers: Don Webb Doug Hinnaland Field Support: Alaska District Manager: Martin Varco Field Service Manager: Craig Brown RECE v u NOV 20 1997 Al~,ka Oil & Gas Cons, 0ommission ~r.,horage Services Provided: MWD SHARP GAMMA RAY MWD SHARP (DSS) ORIENTER Service Dates 10/20- 10/26/97 10/16- 10/19/97 10/16 - 10/26/97 Depth Interval 12589'- 14258' 12518'- 12589' 12518'- 14258' Operating Statistics: Total MWD Pumping hours: Total MWD Below Rotary hours: Total MWD Footage: Total MWD Runs: 138.25 195.75 1740 10 Job Performance: Directional: SHARP MWD was picked up on 10/16/97 to drill cement and tie in gamma ray marker @ 11831' SHARP Gamma Ray and (DSS) was used from 12518' to 14258' which was TD. Shocks: Anadrill constantly moniters shocks in realtime and recorded. No major shocks were incountered in realtime or recorded. Washout Detection: Washouts can be detected from monitering pump pressure, and motor differencial pressure with same pump rates. Lessons Learned: The orienter was a big facter in drilling this well without hny problems, with all the people involved in repairing it some of the information was not relayed to others that ended up working on it. To solve the problem in the future, there has been a written procedure on how and what to do to the orienter in its repairs. Anadrill appreciates the opportunity to provide Arco Alaska Inc. with Directional Survey (DSS) and Logging While Drilling (LWD). We look forward to continue working for you in the future. Sincerely, Mark Brown Cell Manager Craig Brown Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) October 26, 1997 Larry Grant Arco Alaska Inc. Anchorage, Alaska Mr. Grant C'~. Oq~ Enclosed is a copy of the survey program, and performance letter for 18-25a. Please let me know ii' you have any questions regarding this data. Craig Brown or myself can be reached at (907)-349-4511. Sincerely, Mark Brown Craig Brown Cell Manager, Anadrill Arco Coil Tubing Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) October 14, 1997 Larry Grant Arco Alaska Inc. ~ '7' O~ ~' Anchorage, Alaska Mr. Grant Enclosed is a copy of the survey program, and performance letter for 18-25a Pbol. Please let me know if you have any questions regarding this data. Craig Brown or myself can be reached at (907)-349-4511. Sincerely, Mark Brown Cell Manager, Anadrill Arco Coil Tubing Criag Brown Field Service Manager ARCO Alaska ;. Post Office Bd~(' 400360 Anchorage, Alaska 99510-0360 Phone: (907)276-1215 [.~c>~ Stephen L. Ward Sr. Operations Engineer Prudhoe Bay Resource Development ATO 1544 Phone :265-1305 Fax: 265-1336 October 15, 1997 ! Mr. Blair Wondzell, Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission ~ 3001 Porcupine Drive Anchorage, AK 99501 ('i:-:? -~ .-. Re' 18-25A Plugback and redrill ~ 1997 Dear Mr. Wondzell: ............. ~¢~i~ag~ As per our conversation this morning, ARCO Alaska Inc. is plugging back the current sidetracked hole on DS 18-25A and redrilling the well. The reasons for this action are as follows: 1) The 2-3/4" bottom hole assembly (BHA) that we were drilling with became stuck while running back in the hole to resume drilling. A window had been milled in the 4-1/2" horizontal slotted liner at approximately 12,725' md and the well drilled to a depth of 14,100' md. The assembly had been tripped out of the hole due to MWD problems and was being run back in the well to resume drilling. After passing through the window, the shale that existed approximately 70' beyond the window had to be reamed. While reaming, 90% lost returns were experienced and the BHA became stuck. 2) Subsequent fishing operations were unable to recover the stuck BHA. Approximately 1.5 days were spent in trying to recover the BHA. Several unsuccessful recovery attempts were made in trying to jar the fish free. Crude was circulated, in order to free the BHA due differential sticking and the BHA was moved uphole 14' leaving the top of the BHA at -12726' md and the bottom at - 12782' md., but the BHA could not be moved further uphole or downhole. The LCM that was pumped to stop lost circulation was thought to possibly be a problem, so 15 bbls of bleach were pumped and allowed to soak, but the BHA could still not be recovered. 3) The horizontal position of the 4-1/2" liner and the fish, along with the pull limitations of the 2" CT are also believed to have added to the difficulties in recovering the BHA. Plans are to cement back the existing hole and window above the fish to - 12, 600' md and mill a new window at - 12, 630' md, then redrill the open hole to the proposed TD of 14,900' md. Sincerely, Sr. Operations Engineer Prudhoe Bay Resource Development TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 3 0, 1997 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 18-25A ARCO Alaska, Inc. Permit No 97-98 Sur. Loc.: 871'FNL. 326'FWL, Sec. 19, TllN, R15E, UM Btmhole Loc: 3378'FNL. 310'FEL, Sec. 20, T11N, R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by 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 xvith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bx' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W.'~nston ~ -~ Chairman ~ BY ORDER OF THE COMMISSION dl/Tenclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. . . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll _ Redrill ~ I lb. Type of Well Exploratow._ Stratigraphic Test _ Development Oil Re-Entry__ Deepen _~XI Service_ Development Gas_ Single Zone __X Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 48' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 871' FNL, 326' FWL, Sec 19, T11N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2109' FNL, 472' FWL, Sec 20, T11N, R15E, UM. 18-25A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 3378' FNL, 310' FEL, Sec 20, T11N, R15E, UM. July, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line I No Close Approach 14920' MD / 8778' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A Maximum hole angle 90° Maximum surface 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 2200' 12700' 8735' 14920' 8778' Slotted Liner (uncemented) !19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12885 feet Plugs(measured) true vertical 8747 feet Effective depth: measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 2150 # Poleset 110' 110' Surface 3792' 13-3/8" 2500 Sx CS III & 600 Sx G 3840' 3491' Production 9999' 9-5/8" 750 Sx Cl G 10047' 8252' Liner 2153' 7" 610 Sx Cl G 11873' 8723' Slotted Liner 1311' 4-1/2" U ncemented 12803' 8741' Pedoration depth: measured Slotted Liner: 11717 - 12767' N, L true vertical Slotted Liner: 8705 - 8739' 0RI6~ 20. Attachments Filing fee X Property plat_ BOP Sketch X Diverter Sketch _ Ddlling program x Ddlling fluid program~ Time vs depth plot Refraction analysis ~ Seabed report -- 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (~J(?S~o'~,$ ~ o,%jj ,~'E,V(d, '~'~f'~ Signed '~,~.4~ "~") · ~ Titlle Engineering Supervisor Date ~'- Z ~ ~ ¢/ -7 Commission Use Only Number J APl number ¢2 / Approval date See cover letter for Condltions of approval Samples required Yes ~-~'No Mud log required _Yes~i~'~t~ ~/ ~'~ ,~,T~,, ~1~/~ Hydrogen sulfide measures ~'Yes _ No Directional survey required '~Yes Required working pressure for DOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X 3500 ' ' Other: Approved by Commissioner the commission .... Form 10-401 Rev. 7-24-89 Submit in triplicate DS 18-25A CT Extension and Completion Intended Procedure Objective: Directionally drill -2200', 2-3/4" horizontal extension from the Complete with 2-3/8" slotted liner. existing wellbore. Intended Procedure: RU CTU and place cement around fish in 4-1/2" slotted liner at - 12760' RD CTU. RU CTU/Nabors 3S. RIH and mill out cement and fish and shoe in 4- 1/2" slotted liner. Spot cement in remaining 8.5" open hole from 12885' to 12800' md. · Load well with +8.9 ppg polymer mud. Directionally drill -2200' of 2-3/4" horizontal hole to access Romeo reserves. · Run 2-3/8" slotted liner to TD. · RD CTD, return well to production. May 21, 1997 DS 18-25A Proposed Wellbore Sketch Extension of Wellbore & Completion 3-1/2" Camco TRDP-2A SSSV 2.81" ID 1997' ~ 3-1/Z" Production Tubing 1/Z" Camco GLMs 3-1/2" Otis "X" Nipple 7" Liner top 9-5/8" Shoe 101 04' 8800' 9731' 2.375" Slotted Liner 7" Liner Shoe l 1742' 4-1/2" Slotted Liner to 1 2767' 2.75" Openhole +/-11 00' TIW Overshot Seal Assy, SS Packer @ 11518' T12,800' 2.375" TOL ~12700' TD +/- 3 .~'900' ~ i iii i i i _ I I ~ I I i ii ii I iljllJll I I i iljll i I i i. ,i ii . I .i I I I IIIIIIIj ijllll_ iiiiii IL i I . II iiii I I I ARCO ALASKA INC. PRUDHOE BAY ALASKA E/W Scale I Inch ' 400 ft 18-25 . ooo , ARCO ALASKA INC. o -2400 _.e -2800 NORTH REF. T° TRUE Mr u e (+0) ag (+28,$t) PLANE OF VERT SECTn 103.19° RELATIVE TO TRUE NORTH i i i I I ii i a i a i ii I i I FILE NAME: C:~ARCOALK\18-25\lS-25AI .DW2 DRAWN BY : BIMO HADIPUTRO DATE : MAY 8, 1997 i ii I i ii ! i i I i I i 8400 18-25 _ : 18-25 A ....... 2 TD 8730.1 SS 8800- -~ MD 14918 92.2° _- 1 D1.4t°1100 Tf-41.2° - MD 12811 86.8~ KOP o2oo - Ve~ical Section Scale 1 inch · 400 ~ 18-25A.xls 4:17 PM .... --:-f PAGE NO. I 18-25 A PLAN PREPARED ON MAY 8. 1997 Comments MD Inc. Dir SS TVD VSi NI(-S) E/(-W) Build Turn DoglegI ASP Y ASP X ft deg deg ft ft ft ff degll00' degll00' deg/100' ft ft !1. TIE IN KOP 12811.00 85.80 106.00 8693.90 7818.10 -2021.30 7556.20 0.00 0.00 0.00 5959178.01 699689.3 0.41 ° DLS -41 TFC 12840.00 85.90 105.90 8696.00 7847.00 -2029.30 7584.00 0.30 -0.30 0.40 5959171.0 699717.3 12870.00 86.00 105.80 8698.10: 7876.90 -2037.50 7612.80 0.30 -0.30 0.40 5959163.5 699746.3 12900.00 86.10 105.80 8700.20 7906.80 -2045.60 7641.60 0.30 -0.30 0.40 5959156.0 -699775.3 12930.00 86.20' 105.70 8702.20 7936.70 -2053.80 7670.40 0.30i -0.30 0.40~ 5959148.5 699804.3 12960.00 86.30 105.60 8704.20 7966.60 -2061.80 7699.20 0.30 -0.30 0.40 5959141.01 699833.3 12990.00 86.40 105.50 8706.10 7996.50 -2069.90 7728.10~ 0.30 -0.30 0.40 5959134.0 699862.4 13020.00 86.40 105.40, 8708.00 8026.40 -2077.80 7756.90 0.30 -0.30 0.40 5959126.5 699891.4 13050.00 86.50 105.40 8709.80 8056.30 -2085.80 7785.80 0.30 -0.30 0.40 5959119.5 699920.4 13080.00 86.60 105.30 8711.60 8086.30 -2093.70 7814.70 0.30 -0.~ 0.40 5959172.5 699949.6 13110.00 86.70 105.20 8713.40 8116.20 -2101.60 7843.60 0.30 -0.30 0.40 5959105.0 699978.6 13140.00 86.80 105.10 8715.10 8146.10 -2109.40 7872.50 0.30 -0.30 0.40 5959098.0 700007.8 13170.00 86.90 105.00 8716.70 8176.10 -2117.20 7901.40 0.30 -0.30 0.40 5959091.0 700036.8 13200.001 87.00 105.00 8718.30 8206.00~ -2125.00 7930.30 0.30 -0.30 0.40 5959084.0 700065.9 13230.00 87.10 104.90 8719.90 8235.90 -2132.70 7959.30 0.30 -0.30 0.40 5959077.0 700095.1 13260.00 87.20 104.80 8721.40 8265.90 -2140.40 7988.20 0.30 -0.30 0.40 5959070.0 700124.3 13290.00 87.30 104.70 8722.80 8295.80 -2148.00 8017.20 0.30 -0.30 0.40 5959063.0 700153.4 13320.00 87.40. 104.60 8724.30 8325.80 -2155.60 8046.20 0.30 -0.3~' 0.40 5959056.5 700182.6 13350.00 87.40 104.60 8725.60 8355.80 -2163.10 8075.20 0.30 -0.30 0.40 5959049.5 700211.8 13380.00 87.50 104.50 8726.90 8385.70 -2170.70 8104.20 0.30 -0.30 0.40 5959043.0 700241.0 13410.00 87.60 104.40 8728.20 8415.70 -2178.10 8133.30 0.30 -0.30 0.40 5959036.0i 700270.2 13440.00 87.70 104.30 8729.40 8445.70 -2185.60 8162.30 0.30 -0.30 0.40 59590~ 700299.4 13470.00 87.80 104.20, 8730.60 8475.60 -2193.00 8191.30 0.30 -0.30~ 0.40 5959022.5 700328.6 13500.00 87.90 104.20 8731.70 8505.60 -2200.30 8220.40 0.30 -0.30 0.40 5959016.0 700357.9 13530.00 88.00 104.10 8732.80 8535.60 -2207.60 8249.50 0.30 -0.30' 0.40 5959009.5 700387.~ 13560.00 88.10 104.00 8733.80 8565.60 -2214.90 8278.60 0.30 -0.30 0.40 59590~-3.0 700416.4 13590.00 88.20 103.90 8734.80 8595.50 -2222.10 8307.70 0.30 -0.30 0.40 5958996.5 700445.7 13620.00 88.30 103.80 8735.70 8625.50 -2229.30 8336.80 0.30 -0.30 0.40 5958990.0 700475.0 13650.00. 88.40 103.80 8736.60 8655.50 -2236.50 8365.90 0.30 -0.30 0.40 5958~84.0 700504.3 13680.00 88.50 103.70 8737.40 8685.50 -2243.60 8395.00 0.30 -0.30 0.40 5958977.5 700533.6 13710.00 88.50 103.60 8738.20 8715.50 -2250.70 8424.20 0.30 -0.30 0.40 5958971.0 700562.9; 13740.00 88.60 103.50 8739.00 8745.50 -2257.70 8453.30 0.30 -0.30 0.40 5958965.0 700592.3 13770.00 88.70 103.40 8739.70 8775.50 -2264.70 8482.50 0.30 -0.30 0.40 5958958.5 700621.6 13800.00 88.80 103.40 8740.30 8805.50 -2271.60~ 8511.70 0.30 -0.30 0.40 5958952.5 700650.9 13830.00 88.90 103.30 8740.90, 8835.50 -2278.60 8540.90 0.30 -0.30 0.40 5958946.0 7~0680.3 13860.00 89.00 103.20 8741.40 8865.50 °2285.40 8570.10 0.30 .0.30 0.40 5958940.0 700709.6 13890.00 89.10 103.10 8741.90 8895.50 -2292.30 8599.30 0.30 .0.30 0.40 5958934.0 700739.0 13920.00 89.20 103.00 8742.40 8925.40 -2299.10 8628.50 0.30 -0.30 0.40' 5958928.0 700768.4 ...... 13~50.00 89.30 103.00 8742.80 8955.40 -2305.80 8657.70 0.30 -0.30 0.40 '--- 595§~22.0 .... 700:~-.~ 13980.00 89.40 102.90 8743.20 8985.40 -2312.50 8686.90 0.30 -0.30 0.40 5958916.0 700827.2 14010.00 89.50 102.80 8743.50 9015.40 -2319.20 8716.20 0.30 -0.30 0.40 5958910.0 700856.6 14040.00 89.60 102.70 8743.70 9045.40 -2325.80 8745.40 0.30 -0.30 0.40 5958904.5 700886.0 14070.00 89.60 102.60 8743.90 9075.40 -2332.40 8774.70 0.30 -0.30 0.401 5958898.5 700915.4 __ 14100.00 89.70 102.60 8744.10 9105.40 -2338.90 8804.00 0.30 -0.30 0.40 5958893.0 700944.9 14130.00 89.80 102.50 8744.20 9135.40 -2345.40 8833.30 0.30 -0.30 0.40 5958887.0 700974.3 14160.00 89.90 102.40 8744.30 9165.40 -2351.90 8862.60 0.30 -0.3b 0.40~-~95~88;I.5- '701003.8 14190.00 90.00 102.30, 8744.30 9195.40 -2358.30 8891.90 0.30 -0.30 0.40J5958875.5-- 7~ Page1 5~/97 18-25A.xls 4:17 PM .... ' .... --~ PAGE NO. 2 Comments MD Inc. Dir SS TVD VS N~(-S) FJ(-W> eu,d 'TurnDoglegI ASP YI ASP X ft deg deg ft ft ff ff deg/100' degll00, deg/100.IftJ ft 14220.00 90.10 102.20' 8744.30 9225,40 -2364.70 8921.20 0.30 -0.30 0.40 5958870.0 701062.8 14250.00 90.20 102.20 8744.20 9255.40 -2371.10 8950.50' 0.30 -0.30' 0.40 5958864.5 701092.2 14280.00 90.30 102.10 8744.10 9285.40 -2377.40 8979.80 0.30 -0.30 0.40 5958859.0 701121.7 14310.00 90.40 102.00 8743.90 9315.40 -2383.60 9009.20 0.30 -0.30 0.40 5958853.5 701151.2 14340.00 90.50 101.90 8743.70 9345.40, -2389.80 9038.50 0.30 -0.30 0.40 5958848.0 ~01180.7 14370.00 90.60 101.90 8743.40 9375.40 -2396.00 9067.90 0.30 -0.30 0.40 5958842.5 701210.21 14400.00 90.70 101.80 8743.10 9405.40 -2402.20 9097.20 0.30 -0.30 0,40 5958837.5 ~-01239.7 14430.00 90.70 101.70 8742.70 9435.40 -2408.30 9126.60 0.30 -0.30 0.40 5958832.0 701269.3 14460.00 90.80 101.60 8742.30 9465.40 -2414.30 9156.00 0.30 -0.30i 0.40 595882--~.5 ~'01298.8 14490.00 90.90 101.50 8741.90 9495.30 -2420.30 9185.40 0.30 -0.301 0.40 5958821.5 701328.3 14520.00 91.00 101.50 8741.40 9525.30 -2426.30 9214.80 0~30 -0.30 0.40j 5958816.5 701357.8 14550.00 91.10 101.40 8740.80 9555.30 -2432.20 9244.20 0.30 -0.30 0.40 5958811.0 701387.4 14580.00 91.20 101.30 8740.20 9585.30 -2438.10 9273.60 0.30 -0.30 0.40 5958806.0 701416.6 14610.00 91.30 101.20 8739.50 9615.30 -2444.00 9303.00 0.30 -0.30 0.40 5958801.0 701446.5 14640.00 91.40 101.10 8738.80 9645.20 -2449.80 9332.40 0.30 -0.30 0.40 5958796.0 701476.1 14670.00 91.50 101.10 8738.10 9675.20 -2455.50 9361.90 0.30 .-0.30 0.40 5958791.0 701505.6 14700.00 91.60 101.00 8737.30 9705.20 -2461.30 9391.30 0.30 -0.30 0.40 5958786.0 701535.5 14730,00 91.70 108.90 8736.50 9735.10 -2467.00 9420.70 0,30 -0.30 0.40 5958781.0 701564.8 14760.00 91.80 100.80 8735.60 9765.10 -2472.60 9450.20 0.30 -0.30 ~).40 5958776.0 701594.4 14790.00; 91.80 100.70 8734.60 9795.00~ -2478.20 9479.70 0~0 ~0.30 0.40 5958771.51 701624.0 14820.00 91.90 100.70 8733.60 9825.00 -2483.80 9509.10 0.30 -0.30 0.40 5958766.5l 701653.6 14850.00 9~.00 100.60 8732.60 9855.00 -2489.30 9538.60 0.35 -0.30I- 0.40 5958762~I 701683.2 14880.00 92.10 100.50 8731.50 9884.90 -2494.80 9568.10 0.30 -0.301 0.40 5958757.0 701712.8 14910.00 92.20 100.40 8730.40 9914.80 -2500.20 9597.50 0.30 -0.30 0.401 5958752.5 701742.4 2. TD 14918.00 92.20: 100.40 8730.10 9922.80 -2501.60 9605.40 0.30 -0.30 0.40 5958751.5 701750.3 I ~JERTICAL SECTION PLANE USED · 10:~.-19o RELATIVE TO TRUE NORTH -- MAG DEC. '28.61° TO TRUE NORTH RKB: .-48' GRID CONVERGENCE: '1.46° SURFACE X: 692084 ~: 5961006 Page2 5~/97 Drilling Wellhead Detail .... ~ CT Injector Head Methanol Injection Otis 7" WLA Quick I Connect -'--- I Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manualover Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2' Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mul T~ks m 60/40 I TrplxI I-ire Ext. Fuel Shop Boilers Water Pump Ext. Pipe ra~//~ Fire Ext. Dowell Drilling I Equipment Trailer Preferred Major Equipment Layout for CT Drilling WELL PERMIT CHECKLISTco ,NY FiE~,~ ~ voo~, ~5/~/,_C~_~ INI~ C~,*SS /3 ,xj GEOL AREA PROGRAM: expo dev~redrl~servQ wellbore segU ann disp para reqU · ~g o UNI~# /?~._('¢-'3 ON/O~'~' SHO~ ADMINISTRATION ____ D~ATE / 1. ' 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ........ . · Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y N ~'~ 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ....... ~Y N~ 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~~J/T-' 22. Adequate wellbore separation proposed .......... Y~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~)~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis of shallow gas zones .......... /~ N 33. Seabed condition survey (if off-shore) ....... / Y N 34. Contact name/phone for weekly progress reports . . .~/ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: JDH ~ ~e~rm HOW/dlf- A:\FORMS\cheklist rev 01/97