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Home My WebLink About180-040 cto-0240 WELL LOG TRANSMITTAL#902863340 DATA LOGGED 215/201 Co K.BENDER To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 2 0 2016 RE: Production Profile: 1B-01 AOGCC Run Date: 10/27/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-Ol Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20465-00 Production Profile Log 1 Color Log 50-029-20465-00 SCOANa PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , , Imag~roject.Well History File Cover ~ge XHYZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J__ ~ (~. ~) Z~ ~ Well Hist.~.~File Identifier RES~AN~,~ DIGITAL DATA OVERSIZED (Scannable) ~ Color items: [] Diskettes, No. [] Maps: [] Gr.~j~,cale items: [] Other, No/Type [] Other items scannable by p large scanner oor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN Project Proofing VINCEN~ARIA WINDY BY: BEVERLY o~VINCENT SHERYL MARIA WINDY Scanning Preparation DATE' / BY: BEVERL~VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO BEVER~INCENT SHERYL MARIA WINDY DATE.,~.~(~.._.~S/~'~ IF NO IN STAGE 1, PAGE(S) DISCREP~RE FOUND: <._~ j_~..~ ~.~_.YES. NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /SI General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 14, 2011 %46 F RECEIVED Commissioner Dan Seamount FEB 17 ZUi Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 4110116 & Gas Cons. Cm/mission Anchorage, AK 99501 Anctcr c Commissioner —040 Dan Seamount: � Q Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, 7 " 7 /1 " / ./ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/1512011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD �` . Corrosion "' t ` Iniart p of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement _ pumped cement date inhibitor sealant date ft bbls ft gal 1B -01 50029204650000 1800400 , SF N/A 19" N/A 1.4 2/11/2011 1D-119 50029228360000 1972220 2" l" N/A 23" N/A 4.2 2/10/2011 1E-117 50029232510000 2050260 12" _ N/A 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 5" N/A 5" N/A 5.2 2/12/2011 1Q -22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y-06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y-08 50029209440000 1830620 _ 6" _ N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A 3 2/11/2011 3J -17 50029227000000 1961460 SF 1 N/A 19" N/A 3.3 2/11/2011 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Jl 20m Gon~"çm~~ED JUN 1 4 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~\Y Field: Kuparuk /~6 -O~Ò Well Job# Log Description Date BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N'A MEM INJECTION PROFILE 05'05'07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05'04'07 1 2G-09 11638864 PRODUCTION PROFILE 05'06'07 1 2N-349A 11629004 RST/ WFL 05/04107 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05'03/07 1 1 E-11 11629012 INJECTION PROFILE 05'14'07 1 2L-321 11665439 USIT 05'25'07 1 2V-OBA 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03'19'07 1 1H-07 11665436 SBHP SURVEY OS/20'07 1 2F-11 11665434 PRODUCTION PROFILE 05'19'07 1 2X-07 11665433 INJECTION PROFILE 05/18'07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05'15'07 1 2Z-29 11665438 PRODUCTION PROFILE 05'22'07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE 05'23'07 1 1G-03 11637336 INJECTION PROFILE 05'14'07 1 1A-23 11665443 MEM PRODUCTION PROFILE 05'29'07 1 1 F-08 11665435 SBHP SURVEY OS/20'07 1 1J-170 11632709 INJECTION PROFILE OS/24'07 1 10-109 N'A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY 05'28'07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . PATCH (7038-7059, 002,875) SBR (7086-7087, 00 :2.875) PKR (7104-7105, 006,156) SLEEVE-C (7180-7181, 002.250) PKR (8199-8200, 004,688) NIP (8222-8223, 00:2.375) GUIDE (8233-8234, 002.375) Perf (8330-8346) FRAC (8330-8400) KRU 1 B-01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Well Operations for Phillips Alaska, Inc., on well lB-01. Attached is a discussion, an operations report and a well schematic diagram. Please call Jerry Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, Peter Nezaticky Phillips Problem Well Supervisor Attachment RECEIVE ~UG 0 1 ?~i)! Alaska 0il & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 496' FNL, 981' FEL, Sec. 9, T11N, R10E, UM 5. Type of Well: Development _X Exploratory __ stratigraphic _ Service__ (asp's 549457, 5969647) 6. Datum elevation (DF or KB feet) RKB 90 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 B-01 At top of productive interval 1274' FSL, 1129' FWL, Sec. 9, T11N, R10E, UM At effective depth At total depth 4138' FNL, 4472' FEL, Sec. 9, T11 N, R10E, UM (asp's 545999, 5965982) 9. Permit number / approval number 180-040 / 10. APl number 50-029-20465 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 80' SURFACE 3087' PRODUCTION 7405' LINER 1272' LINER 8585 feet Plugs (measured) 6554 feet 8388 feet Junk (measured) feet Size Cemented Measured Depth True vertical Depth 16" 200 sx Permafrost 80' 80' 10-3/4" 1300 sx Fondu, 1700 sx AS II 31 77' 2738' 7" 790 sx Class G, 175 sx AS II 7495' 5782' 5" 100 sx Class G 8580' 6550' Perforation depth: measured 8108'-8165',8330'-8346',8356'-8410' true vertical 6219' - 6260', 6376' - 6387', 6394' - 6432' Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 7212' MD; 2-3/8",4.6#, J-55 Tbg @ 8234' MD. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) CAMCO HRP-I-SP HYD SET @ 7104' MD; BAKER 'DB' @ 8199' MD; CAMCO TRDP-1A-SSA LOCKED OUT - CLOSURE TEST 3/11/01 GOOD @ 1905' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service _Water Injector 17. I hereby certify that. the foregoing is true_and correct to the best of my knowledge. Signed ./~~~,'~~j~"/~ Title Staff Engineer Peter Nezaticky V · Questions? Call Peter Nezaticky Prepared by Sharon Allsup-.Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE SUNDRY NOTICE 10-404 Phillips Kuparuk Well lB-01 Tubing Patch July 7, 2001 Phillips Alaska, Inc., Kupamk well lB-01 is a production well that had a leaking gas lift mandrel at 7046 MD. A 2-7/8" permanent Halliburton patch was set across GLM #8, depths 7038ft- 7058ft. The IA passed a 3500 psi pressure test. The field Well Service Report is attached. PHILLIPS Alaska, Inc. WELL 1B-01 DATE 07/07/01 DAY 21 FIELD ESTIMATE JOB SCOPE FRACTURING.{255) DAILY WORK TBG PATCH OPERATION COMPLETE ISUCCESSFUL Yes O No I Yes O No AFC# ICC# I DAILY COST 999651 230DS10BL $23,745 Initial Tbg I Final Tbg I Initial IA ! 1100 PSII 0 PSII 0 PSI I ;UPARUK RIVER UNIT WELL SERVICE REPORT 1B-01(4-1)) JOB NUMBER 0503011827.2 UNIT NUMBER 2145 IKEY PERSON SWS-GARCIA ACCUM COST $157,354 Final IA I Initial OA I Final OA ITI'L Size oPS~l oPS~l oPS~l 3.500" SUPERVISOR RIEDEL Signed IMin ID 2.290" IDepth 7086 FT DAILY SUMMARY I 'SET 2-7/8" PERMANENT HALLIBURTON PATCH ACROSS G'LM #8 (DEPTHS ( 7038-7058 FT'). PATCH DESCRIPTION: ID: 1.875" ID, LENGTH: 21.45 FT TIME LOG ENTRY 15:15 MIRU 15:40 HOLD TELLGATE SAFETY MEETING 16:00 CALL FOR RADIO SILENCE. 16:20 PT TO 3000 PSI 16:30 RIH WITH HEAD/CCL/NO GO CONECTION/HALLIBURTON SETTING TOOL/HALLIBURTON PATCH. TW: 290 LBS, TL:35, MOD:2.25 INCHES 16:40 CALL TO CANCEL RADIO SILENCE 16:45 GET STUCK AT 248 FT. UNABLE TO GO UP OR DOWN. WORK CABLE (PULL TO 800 LBS AND RELEASE). PUMPED TANER GAS IN ATTEMPT TO DE-ICE LUBRICATOR WITHOUT SUCCESS. ' 17:00 CALL HOT OIL 18:15 PUMP 10 BBLS OF METHANOL AT 1/2 BPM. TOOL STILL STUCK .. 18:40 HOOK UP 1/8" JUMPER LINE FROM ANNULUS TO FLOWLINE IN AN ATTEMPT TO BLEED IA PRESSURE TO GET TBG TO SLACK. DUE TO HOLE IN TBG STARTED FLOW WELL UP THE BACKSIDE. UNSUCCESSFUL AT BLEEDING PRESSURE. DISCONNECT AND REMOVE JUMPER LINE. 18:54 PUMP 10 BBLS OF HOT DIESEL, START AT 1/2 BPM, INCREASE RATE TO 1 BPM FOR 5 BBLS..TOOL STILL STUCK. SHUT DN PUMPS. 20:00 CLQSE THE BOP, BLEED THE LUBRICATOR, DISCONNECT THE LUBRICATOR ABOVE THE BOf?'S, MARK THE WIRE AND LIFT WITH THE CRANE. THIS VERIFIED THE CABLE IS STUCK IN THE FLOW TUBE. ':DECIDE TO 22:00 23:00 23:01 23:02 23:03 23:04 23:05 HEAT IT; MANLIFT ARRIVES ON LOCATION. PLACE HEAT TARP OVER FLOW TUBES, RUN HEATER TUBE TO TARP. 00:00 AFTER 30 MINUTES OF HEATING THE ~LUBRICATOR WAS LIFTED AND THE CABLE CAME FREE. PULLED ABOUT 70 FT OF CABLE USING THE DRUM TO CHECK IT. IT LOOKS OK. HOOK UP THE LUBRICATOR AND OPEN THE BOPS. 00:30. MAKE SEVERAL SHORT PASSES UP AN DN HOLE. TOOL IS FREE.CONTINUE RIH. 02:00 AT BTM, RUN CORRELATION PASSES. 02:14 STOP CCL AT 7027.6. SET TOP OF PATCH AT 7038 (21', BTM AT 7049') FT. POOH 03:20 OOH, RDMO. 04:30 CALL DSO. LEAVE LOCATION. PHILLIPS Alaska, Inc. A Subsidiary ol= PHILLIPS PETROLEUM COMPANY sssv (1905-1906, OD:2.875) PATCH (7038-7059, OD:2,875) SBR (7086-7087, 0D:2.875) PKR (7104-7105, OD:6.156) SLEEVE (7180-7181, OD:2.250) PKR (8199-8200, 0D:4.688) NIP (8222-8223, OD:2.375) GUIDE (8233-8234, OD:2.375) Perf (8330-8346) Perf (8356-8410) KRU 1B-01 1B-01 APl: 500292046500 / Well Type: PROD Angle (~ TS: 44 deg @ 8109 SSSV Type: LOCKED OUTt Odg Completion: 12/19/1980 Angle @ TD: 46 deg @ 8585 Annular Fluid: Last W/O: 10/17/1985 Rev Reason: GLV design, set TPI & tbg patch by ImO Reference Log: Ref Log Date: Last Update: 7/9/2001 Last Tag: 8388 TD: 8585 ffKB Last Tag Date: 5/4/2001 Max Hole Angle: 48 deg @ 5800 __ Casing String - All String.. ~_c__rij3tion Size Top Bottom 'I'VD L__ Wt___L_G_rade__~. _Th[e~d_ CONDUCTOR 16.000 ~ 0 80 80 [65.00 ~ H-40 ~ SURFACE 10.750 0 3177 2738 [45.50 [ K-55 ! PRODUCTION 7.000 ' 0 7495 5782 ~26.00 [ K-55 [ LINER 5.000 ' 7308 8580 6550 [15.00 J K-55 | j Tubing String - TUBING (Tight Spot 7068'-7075' {WLM)) Size I Top ] Bo.om I TVD Wt I GradeI Thread 2.875 I t 0 7212 5587 6.50 [ J-55 [ EUE 8RD 2.375 7212 8234 6309 4.60 j-55 EUE 8RD Perforations Summary Interval I TVI~ Zone Status Ft SPF Date Type Comment 8108-8165 6219-6260 UNIT Open 57 4 10/15/1985 IPERF ,C-3,C-2,C-1 B 8330 - 8346 6376 - 6387 A-5 Open 16 4 10/15/1985 IPERF 8356- 8410 6394 - 6432 A-4 ; Open 54 4 10/15/1985 IPERF St I MD I TVD [ Man [ Man [ V Mfr I VType I V OD ] LatchI Port I TROI Date [ VIv Mfr Type Run Cmnt 1 2037 1894 Camco KBMG DMY 1.0 BK 0.000 0 5/11/2001 2/ 35861 3065 Camco KBMG I [ DMY 1 1.0 [ BE 10.000{ 0 15/11/2001[ 3[45791 3784[ Camco[ KBMG [ / DMY [ 1.0 I BE [0.000I 0 5/7/2001I 41 50811 4134[ Camco[ KBMG I / DMY I 1.01 BE 10.000/ 0 ]10/17/1985I 5 I 5584[ 44791 Camco I KBMG I I DaY [ 1.0 / BK { 0.000/ 0 [~/!2/1999I 6[60831 48161 Camco I KBMG I I DMY I 1'0t BK 10'000[ 0 tS/12/1999I 7 / 6638{ 5194/ Camco / KBMG I / DaY / 1.0 I aK / 0.000 / 0 /4/8/1995/ ___8_1__7_0_46_1_5472/ Medal TGPD / / OPEN [ 1.5 1_ RK [ 0.~_~6/30_ /_2_~1_1._.~1} 1. TBG PATCH SET ACROSS GL V 7/7/01 i . ;Production MandrelsrValves St[ MD {WD[ Man [ Man I VMfr I VType tV OD{Latch[ Port [TROI Date [ Vlv I Mfr Type Run Cmnt 9 I 7143 5539 Camco KBMG DMY 1.0 BK 0.000 0 10/17/1985 Closed Other (plugs, equip,, etc. - JEWELRY Depth TVD Type Description ID 1905 !796 SSSV Camco TRDP-1A-SSA locked out - CLOSURE TEST 3/11/01 good 2.312 7038 5466 PATCH !PATCH SET 7/7/2001 1.875 7086 5500 SBR :Camco OEJ 2.313 7104 I 5512 I PKR Camco HRP-I-SP hyd set 2.347 7180 [ 5564 I SLEEVE AVA ISO SLEEVE- MODIFIED TPI w/o collets set 7/6/01 1.810 7180 5564 NIP AVA Ported BPL Nipple 2.250 8199 I 6284 PKR Baker'DB' 2.688 8222 I 6300 NIP i Camco'D' Nipple, NO GO 1.812 8233 6308 GUIDE I Otis Re-Entry Guide 1.995 8234 6309 TTL 1.995 General Notes Date Note 11/8/1992 Tight spot (~7300' 5/17/2001 E-line found leaks @ 7046' RKB & 8168' RKB 5/17/01 & 5/18/01 Memory Multi-Finger Caliper Log Results Summary o'-tO Company: PHILLIPS ALASKA Well: Log Date: June 2, 2001 Field: Log No.: 4341 State: Run No.: I APl No.: Pipe1 Desc.: 2 7/8' 6.5 lb EUE Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: Pipe2 Desc: 2 3/8' 4.6 lb EUE Top Log Intvl2.: Pipe2 Use: Liner Bot. Log Intvl2.: 1B-01 Kuparuk River Unit Alaska 50-029-20465-00 5,586 Ft. (MD) 7,213 Ft. (MD) 7,213 Ft. (MD) 8,233 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper log indicates that the interval of 2 7/8" tubing logged is in good condition, with no penetrations in excess of 12% wall thickness recorded. Scattered light deposits are recorded throughout the interval. No areas of significant ID reduction or cross-sectional wall loss are recorded throughout the interval logged. The distribution of the damage recorded throughout the tubing string is illustrated in the Body Region Analysis page of this report. A Probable Hole (95% Wall Penetration) is recorded in the 2 3/8" tubing @ 8,172'. There is significant wall loss around most of the internal circumference of the pipe at this point, that measures 62% total wall loss, or 38% wall remaining. The damage appears similar to the erosional damage expected from high pressure gas entering a small hole in the pipe at this location. These percent wall penetration and cross-sectional wall loss figures are based on the dimensions of 2 3/8" 4.6 lb tubing ( with a 0.19" nominal wall thickness), and are therefore probably exaggerated. The external dimensions of the Blast Joint that this damage appears in was unavailable at the time of this analysis. The remainder of the 2 3/8" tubing interval logged appears in good condition, with no penetrations in excess of 20% recorded above the D-Nipple, and a 27% maximum penetration recorded in the bottom joint of 2 3/8" pipe (below the D-Nipple). The distribution of the damage recorded throughout the tubing string is illustrated in the BodY Region Analysis page of this report. The caliper tool hung-up in GLM 5, @ 5,584' while logging out of the hole. The tool could not be freed until the caliper arms closed, at the end of time allotted for logging to surface. Therefore, the tubing between surface and GLM 5 was not inspected during this logging operation. 2 718" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No penetrations in excess of 12% wall thickness are recorded throughout the 2 7/8" tubing logged. 2 7/8" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (>6%) are recorded throughout the 2 7/8" tubing logged. 2 718" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant ID restrictions ( >0.10" ) are recorded throughout the 2 7/8" tubing inspected. (continued) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 2 318" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: 2 3/8" Probable HOLE in Blast Jt. (95%)* Jt. 30 @ 8,172' MD Isolated Pit (27%) Jt. 31.4 @ 8,229' MD Isolated Pit (21%) Jt. 23 @ 7,950' MD TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Area of apparent internal erosion (62%)* Jt. 30 @ 8,172' MD 2 318" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant ID restrictions, in excess of 0.10 inches, are recorded in the 2 3/8" tubing logged. * NOTE- The damage recorded in Jt. 30 @ 8,172' occurs in what appears to be a Blast Joint, which should have a significantly thicker wall than 2 3/8" 4.6 lb tubing. Therefore the % wall penetration and % cross-sectional wall loss numbers calculated and reported for this damage are probably exaggerated, or too high. The actual OD of the blast joints was not available at the time of this analysis. I Field Engineer: S. Adcock Analyst: J. Burton Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 1B-01 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA PDS Caliper Overview Body Region Analysis Survey Date: June 2, 2001 Tool Type: MFC24 No. 00812 Tool Size: 1 11/16" No. of Fingers: 24 Analysed: I. Burton Tubing: Size Weight Grade & Thread 2.875 ins 6.5 ppf J-55 EUE N om.O D N om. ID N om. Upset 2.875 ins 2.441 ins 3.085 ins Penetration and Metal Loss (% wall) penetration body metal loss body 60 40 20 0 0to 1 to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 51 ) Pene 0 47 4 0 0 0 Loss 0 51 0 0 0 0 Damage Contigumtion ( body ) 10 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total. = 0) 0 0 0 0 0 Damage Profile (% wall) JiJl penetration body metal loss body 0 50 100 GLM 6 GLM 7 GLM 8 Bottom of Survey = 51.1 Analysis Overview page 2 PDS CALIPER JOINT TABULATION SHEET Pipe: 2.875 ins 6.5 ppf J-55 EUE Wall thickness. Bod¥:0.217ins Upset=0.322ins Nominal ID: 2.441 ins Well: 1B-01 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Date: June 2, 2001 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches [3 50 10( 1 0 .02 10 3 0 0 2.35 [] 2 0 .02 8 3 0 0 2.34 [] 3 0 .01 4 5 0 0 2.31 4 0 .02 9 3 0 0 2.32 5 0 .03 12 3 0 .08 2.34 Lt Deposits. [] 6 0 .01 6 3 0 0 2.35 7 0 .02 8 3 0 0 2.34 " 8 0 .02 9 8 0 0 2.35 [] 9 0 .01 6 3 0 0 2.37 10 0 .01 6 2 0 .03 2.35 11 0 .01 5 5 0 0 2.35 12 0 .01 6 4 0 .04 2.34 13 0 .01 5 3 0 0 2.37 ,,, 14 0 .01 5~ 5 0 0 2.35 , , [] 15 0 .02 7' 2 0 0 2.35 16 0 .02 8[ 5 0 0 2.34 [] 16~1 ... 0 0 0 0 0 0 2.32 GLM 6 {Latch @ 1:30) 17 0 .02 10 5 0 .03 2.32 18 0 ...... 102 7 '5 0 0 " 2.35 19 0 .01 4 5 0 0 2.3.5 20 .... 0 .02 7 2 0 0 2.36 21 0 .01 4 3 0 0 2.36 ............ 22 0 "'.012 10 5 0 .05 2.36 Lt. Deposits. . .......... 23 0 .01 6 3 0 0 2.34 [] 24 0 .02 10 4 0 0 2.35 ..' .............. 25 0 .02 8 4 0 0 2.34 26 0 .01 3 3 0 0 2.36 ...... 27 0 .02 7 3 0 0 2.34 IIII 28 0 .02 10 4 0 0 2.35 29 0 .02 7 3 0 0 2.35 ,,3o o 7 5 o o ..... 31 0 .02 8 3 0 .05 2.3.4.. Lt. DePosits. . .... 32 0 -01 5 4 0 0 2,36 .. Ill 33 0 .02 8 4 0 0 2.35 [] 34 0 .02 10 5 0 0 2.35 [] 34.1 0 0 .0 0 0 0 2.33 GLM 7 (Latch @ 7:00) 35 0 .01 6 5 0 0 2.33 36 0 .01 6 6 0 .03 2.34 37 0 .02 10 3 0 .0,3, 2.32 38 0 .01 3 4 0 0 2.313 39 0 .0~ 6 3 0 0 2.31 40 0 .02 10 2 0 0 2.31 41 0 .01 5! 3 0 . .05 2.28 Lt. Deposits. 42 0 .01 6 5 0 0 2.30 43 0 .01 5 3 0 0 2.30 II 44 0 .02 11 6 0 0 2.33 i 45 0 .02 10 6 0 .04 2.36 46 0 .01 5 4 0 0 2.34 47 0 .02 7 3 0 0 2.35 47.1 0 0 0 0 0 0 2.33 GLM 8 (Latch @ 4:30) . Pipe Tabulations page 1 PDS CALIPER JOINT TABULATION SHEET Pipe: 2.875 ins 6.5 ppf J-55 EUE Wall thickness. Body: 0.21 7ins Upset: 0.322ins Nominal ID: 2.441 ins Well: 1B-01 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Date: June 2, 2001 I~1 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset 'Body ID Comments (% wall) inches inches % % inches inches inches D 50 10 48 0 .02 11 4 0 .03 2.33 w 48.1 0 0 0 0 0 0 2.33 SBR & Packer 49 0 .01 4 4 0 0 2.33 i 49.1 0 0 0 0 0 0 2.32 Prod. Mandrel 50 0 .02 7 3 0 0 2.32 [] 50.1 0 0 0 0 0 0 2.3 7 AVA 51 0 .02 11 4 0 0 2.37 w 51.1 0 0 0 0 0 0 0 X-OV R Damage Classifications Penetration / projection class, in order of damage severity' Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends !ess than 20% of circumference General- damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.2 ! 5 feet, Pipe Tabulations page 2 PDS CALIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 EUE Wall thickness. Body: 0.21 7ins Upset: 0.322ins Nominal ID: 2.441 ins Well: Field: Company: Country: Date: 1B-01 Kupamk River Unit PHILLIPS ALASKA USA June 2, 2001 I J°int No. ,il ii 11 12 13 ~ 14 16 16.1 18 !9 28 29 i Ol 31 32 35 38 41 14 1 44 45 47 47.1 Depth Length Measured Type ID feet feet m. ches 5585.80 30.66 2.430 5616.46 30.74 2.419 5647.20 31.48 2.426 5678.68 30.98 2.426 5709.66 30.86 2.427 5740.52 30.97 2.425 5771 5799.83 29.84 2.420 5829.67 31.19 2.437 5860.86 30.38 2.436 5891.24 31.43 2.430 5922.67 31.34 2.425 5954.01 31.96 2.434 5985.97 3i.32 2.4i8I 6017.29 30.18 2.427 6047.47 31.66 2.424 6079.13 6.07 nominal GIm6 6085.20 30.97 2.414 6116.17 31.40 2.420 6147.57 29.87 2.414 6177.44 31.61 2.421 6209.05 31.1 7 2.431 6240.22 29.78 2.426 6270.00 30.35 2.434 6300.35 30.83 2.418 6331.18 31.22 2.426I ' 6362.40 30.91 2.418 6393.31 30.29 2.430 6423.60 30.83 2.430 6454.43 3'0.53 2.429 6484.96 28.76 2.430 6513.72 29.59 2.430 6543.31 6574.35 31.04 30.17 30.23 2.422 6604.52 2.417 2.425 6..88 nominal 31.07 2.424 6634.75 6641.63 6672.70 31.00 2.423 6703.70 31.08 2.421 30.80 2.416 29.76 2.424 31.40 2.419 31.06 2.435 6734.78 6765.58 6795.34 6826.74 6857.80 30.75 2.421 6888.55 30.96 2.422 6919.51 30.19 2.416 31.70 2.420 31 .... .ua /_.~10 29.98 2.426 9.34 nominal 6949.70 6981.40 7012.43 7042.41 I I Joint No. 49 49.1 Depth feet Length feet 7051.75 31.84 7083.59 26.32 7109.91 31.!6 7141.07 6.93 7148.00 30.38 7178.38 3.36 7181.74 31.26 7213.00 unknown Measured JType IlO inches I nominal SBR&PK 2-434 I no,'nina12.422 IPRDM[~RL nominal [ AVA I 2.418 [ X-OVR I I i I I Joint Tally page 1 Well: Field: Company: Country: 1B-01 Kuparuk River Unit PHILLIPS ALASKA USA PDS Caliper Overview Body Region Analysis Survey Date: June 2, 2001 Tool Type: MFC24 No. 00812 Tool Size: 1 11/16' No. of Fingers: 24 Analysed: ). Burton Tubing: Size 2.375 ins Weight Grade & Thread 4.6 ppf J-55 EUE Nom. OD Nom. ID Nom. Upset 2.3 75 ins 1.995 ins 2.548 ins Penetration and Metal Loss (% wall) penetration body metal loss body 40 30 20 10 0 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 33) Pene 0 1 29 2 0 1 Loss 1 31 0 0 1 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 11) 10 0 0 0 1 Damage Profile (% wall) m~ penetration body 11 21 31 Bottom of Survey = 31.4 metal loss body 50 100 Analysis Overview page 2 PDS CALIPER JOINT TABULATION SHEET Pipe: 2.375 ins 4.6 ppf J-55 EUE Wall thickness. Body:0.190ins Upset:0.277ins Nominal ID: 1.995 ins Well: 1 B-01 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Date: June 2, 2001 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wail) inches inches % % inches inches inches ~) 50 10( 1 0 .02 13 4 0 0 1.94 []~ 2 0 .03 16 3 0 0 1.94 [][] 3 0 .02 12 2 0 0 1.93 [] 4 0 .03 15 4 0 0 1.93 []l 5 0 .03 13 2 0 0 1.92 6 0 .03 17 1 0 0 1.93 Shallow pitting. []i~ 7 0 .04 18 4 0 0 1.92 Shallow pitting. [][] 8 0 .03 17 2 0 0 1.94 Shallow pitting. []~- 9 0 .03 14 3 0 0 1.92 [] 10 0 .04 19 2 0 0 1.94 Shallow pitting, m 11 0 .03 14 2 0 0 1.94 [] 12 0 .04 2(3 7 0 0 1.94 Isolated pitting. Ill [] 13 0 .03 15 3 "' 0 0 ' '1.94 !m 14 0 .03 17[ 4 0 .03 1.93 Shallow pitting. [] 15 0 .03 14 3 0 0 1.93 III I 16 0 .03 15 4 0 0 1.95 i[! 17 0 .03 15 4 0 0 1.94 18 0 .04 19 4 0 0 1.96 Shallow pit~!ng. ~ [] 19 0 .02 13 '4 0 .0'4 1.93 . Lt. Deposits. ' ... 20 0 .03 15 4 0 0 1.95 21 0 .02 13 4 0 0 1.93 , , . 22 0 .03 13 4 0 .04 1.92 . Lt. Deposits. 23 0 .04 21 7 0 0 1.95 isolated pitting. :.~ 24 0 .02 11 4 0 0 1.94 [] .... 2.5 ..... 0 ...... .02 i'2 4 0 "'0 ...... i.93 ..... "'26 "'0 .03 14 4 0 " 0 1.94 ~1! 27 0 .02 13 6 0 0 1.95 ,,28 0 .02 13 2 0 .o4 1.89 BLAS~. , .....,, 29 0 .01 7 2 0 0 .... !.93 BLAST JT. 30 0 .18 95 62 .08 .10 1.93 BLAST;IT. HOLE ~ []W []~,~ [][][]1 31 0 .03 17 5 0 0 1.94 Shallow .... pitting. "~: ~ ' 31.1 0 0 0 0 0 0 1.96 PACKER ..... 3 i.2 0 .03 16 2 0 0 1.96 PUP ............. 31.3 0. ...... 0. . .. C] 0 0 ..0 1.80 .D'Nipple , 3.1..4 0 .05 2 7 5 0 .03 1.95 Isolated pitting. .. Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed I * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends ]ess than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length_ = 0~245 feet. Pipe Tabulations page 1 Well: 1 B-01 Field: Kuparuk River Unit Company: PHILLIPS ALASKA Country: USA Tubin[~: 2.375 ins 4.6 ppf ~-55 EUE PDS Caliper Sections Survey Date: June 2, 2001 Tool Type: MFC24 No. 00812 Tool Size: 1 11/16" No. of Fingers: 24 Analysed: J. Burton Cross section for Joint 30 Tool speed = 52 Nominal ID = 1.995 Nominal OD = 2.375 Remaining wall area = 47 % Tool deviation -- 5 7 ° at depth 81 71.75 ft Finger 19 Penetration = 0.18 ins ISOLATED AREA OF SEVERE WALL LOSS 0.18 in. = 95% Wall Penetration HIGH SIDE = UP Cross-Sections page 1 PDS CALIPER JOINT TALLY SHEET Pipe: 2.375 ins 4.6 ppf J-55 EUE \,Vall thickness. Body: 0.190ins Upset = 0.277ins Nominal ID: 1.995 ins Well: Field: Company: Country: Date: 1B-01 Kuparuk River Unit PHILLIPS ALASKA USA June 2. 2001 I J°int JDepthNo. Length Measured Type J ID ! ~ teet ~ teet I roches I 1 7213.49 30.97 1.982 2 7244.46 33.45 1.981 3 7277.91 32.10 1.982 4 7310.01 32.42 1.980 5 7342.43 33.45 1.983 6 7375.88 33.42 1.981 ~ 7~ 7409.30 33.35 1.980 8 7442.65 33.32 1.978 9 7475.97 33.50 1.981 10 7509.47 33.15 1.985 11 7542.62 32.42 1.981 12 7575.04 31.38 2.001 13 7606.42 29.78 1.979 14 7636.20 32.91 1.999 15 7669.11 30.18 1.989 16 7699.29 32.48 2.007 17 7731,77 31,82 1.989 18 7763.59 31.29 2.009 19 7794.88 32.63 2.002 20 7827.51 32.76 2.009 21 7860.2 7 29,24 nominal 22 7889.51 32.74 2.008 23 7922.25 31,65 2,006 24 7953.90 32.43 nominal 25 7986,33 30.90 1.990 26 8017.23 32.02 1.999 i 27 8049.25 28.91 1.998 28 8078.16 33.20 1.977 BLST JT 29 8111.36 32.97 1.975 BLST JT 30 8144.33 31.76 1.982 BLST JT 31 8176.09 29.t4 1.991 31.1 8205.23 12.46 nominal PKR 31.2 8217.69 9.15 1.999 Pup i 31.3 8226.84 2.66 nominal t D-N[P I 3~.41 8229.s0 unknown J 1.982 t Joint No. Il Depth feet Length feet Measured I Type inches I Joint Tally page 1 ARCO Alaska, Inc. Date: January 3, 1992 Transmittal #: 8322 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed co@y ~of this tr~smittal. 1 B - 0 6 Fluid Level Re :)ort 1 R - 2 2 ,/ Fluid Level Re 3orr I B - 01 ,~ Fluid 3A 05 / Fluid 3A-1 6 '"" Fluid 3 C- 0 6 ,.."/ Fluid. 3C-1 0 .~ Fluid 3C 1 5 Fluid 1 H - 0 3 '/ Fluid 1 A - 0 8 '/ Fluid 1 A- 1 0 ''/ Fluid 1 F- 1 4 '/ Fluid 1Q-04 '"' Fluid 1 Y - 0 3 '/ Fluid 1 Y - 0 5 '/ Fluid 1 Y - 2 5 ~, Fluid 1 Y - 2 6 Fluid 2 K - 0 8 ''/ Fluid 2 K 1 1 '/ Fluid 2 K 1 5 Fluid 3C-06 / Fluid 3G-02 Fluid 3 G- 1 3 ''/ Fluid 3G-23 -/ Fluid ~3N-14 ~/ Level Re :)ort Level Re x)rt Level Re x)rt Level Re x)rt Level Re x)rt Level Re x)rt Level Re x)rt Level Re x)rt Level Re 3ort Level Re :)orr Level Re :)ort Level Re ~ort Level Re :)orr Level Re3ort Level Re:)ort Level Re 3orr Level Re 3orr Level Re::)ort Level Re :)ort Level Re 3orr Level Re3ort Level Re :)ort Fluid Level Re3ort Sub-Surface Pressure Survey Please acknowledge receipt and return 1 2- 1 4 - 9 1 Casing 1 2 - 1 9 - 91 Casing 1 2 - 2 0 - 91 Casing 1 2 - 2 0 -. 91 Casing 1 2 - 2 0 - 91 Casing 1 2 - 2 0 - 91 Casing 1 2 - 2 0 - 91 Casing 1 2 - 2 0 - 91 Casing 1 2 - 2 2 - 91 Tubing 1 2 - 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2- 2 7- 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2- 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 8 - 91 Casing 1 2 - 2 8 - 91 Casing 1 2 - 2 8 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 7 - 91 Casing 1 2 - 2 7- 91 Casing 1 2 - 2 7 - 91 Casing 12-13-91 676.13 1839.35 Rl Crc IV F..D JAN 0 6 199?- Alaska 0il & Gas Cons. Commissio~ 1 STATE OF ALASKA (M ALASKA L AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IZXX OTHER [] 2. Nameof Operator 7. Permit No. ARCO Alaska, Inc, 80-40 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-20465 4. Location of Well Surface: 496' FNL, 982' FEL, Sec.9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 90 ' 12. I 6. Lease Designation and Serial No. ADL 25648 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1B-1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~, Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Well [] Change Plans [] Repairs Made [] Other Repair Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 0330 hrs, 10/10/85. ' Killed well. ND tree. NU BOPE & tstd - ok. Pulled 2-7/8" tubing. Fished and recovered bit, junk sub, and casing scrapers. Perforated the following intervals w/4 spf, 90° pha s i ng: 8410' - 8356' 8346' - 8330' Set pkr ~ 8195'WLM. Set BPV. ND BOPE. 0300 hrs, 10/i8/85. Ran 2-7/8"/2-3/8" completion assy w/tail @ 8234' SSSV ~ 1905', & pkrs @ 7104', 8199' , · NU tree & tstd to 5000 psi - ok. Displaced well w/diesel. Secured well & released rig RECEIVED APR 2 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Associate Engineer The space below for~ommission use Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 (JG) SN/150 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Drill Site lA Wel 1 No. ATTACHMENT ! I KUPARUK RIVER UNIT Production Logs Log Date _ 7/6/83 10/29/83 2/8/82~ ~. 5/7/82/ 1/25/82'-~'-- 3/23/83/ . 1/19/83") ~-~- 3/21/83/ 3/8/82 4/1/82 6/5/82 .-. 5111182,~ Drill Site 18 Well No. Log Date __ ~'~18'1 12/26/81 18-2 6/25/81 '~18-3 11/16-18/81~-7 '~ 3/12/82/ ~-18-6 11/18/81~ '~ 9/10/82J ~ ~18-7 11/23/81 ~'18-8 12/28/81',,~ '~ 8/4/82/ "iB-g N 6/24/82,._-~ x, 8/3/84'-' ~ . -_ .... Drill Site -. 1C Wel 1 No. C-2 '~1C-3 ',~1C-4 N~lC-5 '~1c-6" '~1C-7 '"- 1C-8 Log'Date 5/9/8'1 5/8/81 7/13/81 11/8/81'~ 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 18 Well No. Log Date "%18-1 1/80"~ ~ ~' 5/23/83/.. "~18-3 8/S/80 '" 18-4 ~7/30/80',~ ~ ~ 8/13/80/ ~ ~18-5 6/11/81 '~18-6 6/9/81 ': ]" ~18-7 6/8/81 ' ' '~18-8 (ws-8) $110178 - '" · ARCO Alaska, Inc. Post Office B 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1B-1 Dear Mr. Chatterton: Enclosed is the Well Completion Report questions, please call me at 263-4944. Si ncerely, d. Gruber Associate Engineer JG/tw GRU12/L140 Enclosure . for 1B-1. If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKAx'~"'., AND GAS CONSERVATION CO~~ .IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ., 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 80-40 .._ 3. Address 8. APl Number P. O. Box 100360, Anchorage, Al( 99510-0360 50- 029-20465 4. Location of well at surface 9. Unit or Lease Name 496' FNL, 982' FEL, Sec.9, T11N, R10E, UN Kuparuk River Un~t; At Top Producing Interval 10. Well Number 1274' FSL, 1129' FWL, Sec.9, T11N, R10E, UM 1B-1 At Total Depth. 11. Field and Pool 1144' FSL, 816' FWL, Sec.9, T11N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 90' RKBJ ADL 256/+8 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/15/80 12/1/+/80 12/19/80*J N/A feet MSL 1 17. Total Depth {MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21. Th,ckness of Permafrost 8585'MD,f553'TVD 8452'MD,6/+61 'TVD YES~ NO [] 1905 feet MD 1650' (approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR, FDC/CNL/NGT, VDL/CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED "Jb'~' 65,0# H-/+O Surf 80' 2/+" 200 sx Permafrost to s~lrface 10-3/M' /+5.5# K-55 Surf 3177' 13-3//+" 1300 sx Fondu & 1700 s: AS II 7" 26.0# K-55 Surf 7495' 8-3/M' 790 sx Class G & 'ir75 S; AS II , 5" 15.0# K-55 7308' 8580' 6" 100 sx Class G AB FL-45 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8/+10' - 8356' w/4 spf, 90° phasing 2-7/8,, 823/+' 710/+' & 8199' 83/+6' - 8330' 2-3/8", & 2" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .... N/A ., 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL cHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ ,, Flow Tubing Casing Pressure CALCULATED=k OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water, Submit core chips. None 2 0/$85 ""cf~°rage C°r~rniaaioa Form 10-407 *NOTE: Wel 1 was recompleted 10/18/85. TEMP2/WC66 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., 29. 30. GEOLOGIC MARKERS. FORMATION TESTS .... NAME Include interval tested, pressure data, all fluids recovered and gravity, ...... MEAS. DEPTH TRUE VERT. DEPTHI GOR, and time of each phase. Top Kuparuk 8090' 6206' N/A Top Upper Sand 8109' 6220' Bottom Upper Sand 8151' 6250' Top Lower Sand 8320' 6369' Bottom Lower Sand 8404' 6428' Bottom Kupa ru k 8476' 6478 ' -- 31. LIST OF ATTACHMENTS _ Workove~___Wel 1 History 32. I hereby certify that the foregoing is true and correct to the best Of my knowledge Signed //~~ ~~J Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. · Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company "~' Well History - Initial Report - Daily Instructions: Prepare and submit the "lnitinl Rnl~Ort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish o~' borough IStat® Alaska Alaska North Slope Borough Fia,d ILo~or Unit rN,ll no. Kuparuk River ADL 25648 lB-1 W/O Auth. or W.O. no, [Title AFE 703257 [ Recompletion Pool 102 AP1 50-029-20465 Operator [ ~] IARCO W.I. ARCO Alaska, Inc. " 56.24% Spudded or W.O. begun IDate iHour Prior status if a w.o. Workover 10/10/85 0330 hrs. Date and depth as of 8:00 a.m. lO/lO/85 thru 10111185 lO/12/85 thru 10/14/85 lO/15/85 lO/16/85 10/17/85 Complete record for each day reported 5" @ 8580' 8510' PBTD, PU BHA 9.3 ppg NaCl/NaBr Accept rig @ 0330 hrs, 10/10/85. ND tree, NU & tst BOPE. 2-7/8" tbg. Chg rams to 3½" & tst. PU BHA. Pull 5" @ 8580' 8510' PBTD, Prep to perf 9.3 ppg NaCl/NaBr TIH, tag TOF @ 7801', mill same, TOH. TIH w/OS, latch onto fsh @ 7801', attempt to stick f/backoff. RIH w/GO f/backoff, no left hand torque, fsh rotating, POH & chg BHA. RIH & jar in attempt to stick fsh f/backoff, stuck fsh. RU GO, RIH, attempt backoff, backoff @ OS. POH w/WL. 'RU & RIH w/severing charge, shoot @ 8436', pull loose f/rope socket, jar fsh out of hole, LD fsh'g tls & fsh. RU to perf "A" sand w/DA. 5" @ 8580' 8510' PBTD, RU Schl to perf 9.3 ppg NaC1/NaBr Rel DA. RU Schl, make CO rn, TOH. RU Schl to perf. 5" @ 8580' 8510" PBTD, LD 3½" DP 9.3 ppgNaC1/NaBr Perf "A" sand f/8410'-8356' & f/8330'-8346'. RIH w/gauge ring/JB to 8470', POH. RIH w/Bkr pkr, set @ 8195' (WLM), POH. RIH w/3½" DP, circ, POH & LD 3½" DP. 5" @ 8580' 8510' PBTD, Set hydraulic pkr 9.3 ppg NaC1/NaBr LD DP. Chg rams & tst. RU & rn 229 its, 2-7/8", EUE 8RD, 6.5#, J-55 AB Mod tbg, 30 its, 2-3/8", EUE 8RD, 4.7#, N-80 tbg, & 2 jts, 2" FL4S tbg. DB pkr @ 8199', "D" Nipple @ 8222', TT @ 8234', SSSV @ 1905'. Rn std'g vlv & RU te%s~t hydraulic pkr. -C£1v£o /l!astca 0il ~ ~as O~n~. Commissio~ AnChorage The above is correct Signature For form propa'~tlon and distrib~tion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title I Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 703257 North Slope Borough ADL 25648 Accounting cost center code State Alaska JWell no. lS-1 w/o Recompletion AP1 50-029-20465 Pool 102 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun J Date Workover .J 10/10/85 Date and depth Complete record for each day reported as of 8:00 a.m. lO/18/85 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this Well I our I Prior status if a W.O, I 0330 hrs. 5" @ 8580' 8510' PBTD, RR 9.3 ppg NaCl/NaBr Std'g vlv not holding, POH. Ck std'g vlv & re-rn; lnd 8' deeper. Set pkr, shear SBR, re-lnd tbg. Tst pkr to 2500 psi. Tst SSSV w/1500 psi. ND BOPE, NU & tst tree. Displ well w/diesel. Set BPV. RR @ 0300 hrs, 10/18/85. Old TD New TD Released rig Date 0300 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth JKind of rig 10/18/85 I Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8510' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. Well Action Date Performed 1B1 Frac 11/6/85 1E8 Frac 1 2 / 6/85 1E-1 9 Conversion 1 0/1 7/85 1 E-21 Convers i on 8 / 1 / 85 1E-23 Convers i on 1 0 / 23 / 85 1G-2 Frac 12/6/85 1R1 Frac 11/5/85 1R2 Frac 11/5/85 1R4 Frac 11/6/85 1R6 Frac 11/6/85 1R1 3 Frac 11/1/85 1R1 4 Frac 11 / 1 / 85 2D-5 Ac id i zed 6/1 8/85 2D-6 Ac id i zed 6/1 8/85 2V5 Convers ion 7/6/85 on the If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) cai I me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED ( STATE OF ALASKA ~M ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 7. Permit No. 2' N ~,~fc~P~[~S KA, INC. 80-40 8. APl Number 3. A~re~So. . BOX 1 00360 , ANCHORAGE , ALASKA 99510 so- 029 - 20465 9 4. Location of Well SURFACE LOCATI ON- T11N, R10E, 5. Elevation in feet (indicate KB, DF, etc.) 90 ' (RKB) 12. 496' FNL, 982' FEL, Sec. UM J6. Lease Designation and Serial No. ADL25648 ALK 466 9. Unit or Lease Name KUPARUK R IYER UN I T 10. Well Number 1B-1 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RlVER O I L POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well I--] Change Plans [] Repairs Made X~ Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or. Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 6, 1985, the "A" sands of Kuparuk well 1B-1 were hvdraul ical ly fractured and propped to improve production. The treatment consisted of 239 BBLS of gel led diesel as pad and carrying fluid and 750# of 100 mesh and 2881# of 20/40 sand as proppant. 54 BBLS of gel led diesel was used as a flush. Prior to pumping, equipment and lines were tested to 6500 psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Title KU PARU K OPERATIONS COORDi NATOR Date 12/6/85 Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.J Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B~1 (workover) '3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ALASKA ~- AND GAS CONSERVATION CO~,.,IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation)~ :2. Name of operator 7. Permit No. ARCO Alaska, Inc. 80-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20465 4. Location of Well at surface 496 ' FNL, 982' FEL, Sec.9, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 90' RKBI ADL 25648 ALK 466 9. Unit or Lease Name KuParuk River Unit 10. Well No. 1B-1 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of October ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 0330 hfs, 10/10/85. Displaced we]] to NaC1/NaBr. Set BPV. BOPE & tstd. Pulled 2-7/8" tbg. Fished & recovered bit, junk sub, & Perf'd 'A' Sand. Set Baker pkr ~ 8195'(WLN). Run 2-7/8" completion assy. tree & tstd. Displaced well to diesel. Set BPV. Secured well & RR 10/18/85. ND tree. NU csg scrapers. ND BOPE. NU ~ 0300 hfs, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 2-7/8", 6.5#/ft, J-55, 8rd, EUE tbg (229 jts) 2-3/8", 4.7#/ft, J-55, 8rd, EUE tbg (30 jts) 2", FL4S tbg (2 its) SSSV ~ 1905', hyd pkr ~ 7104', DB pkr @ 8199', TT ~ 8234' 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 16. DST data, perforating data, shows of H2S, miscellaneous data 8410' - 8356' w/4 spf, 90° phasing 8346' - 8330' RECEIVED l~kJV ,4, ,,~ A!as~a 0~i & ~as Co~s. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED o~t ~ ~~{,JL-- TITLE Associate Engineer DATE //-/,a~' NOTE--Report his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR47 Rev. 7-1-80 Submit in duplicate Alaska, Inc(" ARCO Post Office'b~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5292 R/~YURN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE kECEIPT KUPARUK ' lB-1 "lB-2 ~ ~lS-4~' ' 1C-4, .1C_6~' -1D_ 8_~ -1H-3' ~.iQ- 15 ~lQ-16j . 1R-5~ , 1R_6-~'~ "1R- 7/ -1R_8~ ~2A-2 ~2W-7 ~V-3 ~ >2h- 5 ' 38-2..?" '3B-3 .... ~3B-3" ~3B_4-~' ~3B-5 '3B-6 ~B-7 ' 3B-7 ~" - 3B-8~" ~3B-10-~ ~3B-11 - 3B-12 ' 3B-13. -3B-14 RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. WELL PRESSURE REPORT--ENVELQPE FACE DATA 05-30-85 CAMCO .""3B- 15 .~ 05-28-85 OTIS 05-30-85 CAMCO ~"~3B-16,'~'_~ 05-28-85 OTIS 05-16-85 CAMCO '~3C-11~ 07-29-85 CAMCO 07-24-85 CAMCO 07-25-85 CAMCO 07-30-85 CAMCO 07-30-85 CAMCO 06-24-85 CAMCO 06-23-85 CAMCO 06-21-85 06-21-85 07-05-85 07-06-85 07-06-85 07-08-85 07-04-85 07-26-85 07-11-85 08-04-85 06-14-85 06-14-85 06-28-85 06-15-85 06-15-85 06-26-85 06-26-85 06-28-85 06-27-85 06-28-85 07-18-85 07-20-85 07-20-85 07-21-85 05-29-85 05-29-85 ACKNOWLEDGE CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS DRESSEK OTIS OTIS ???? CAMCO OTIS CAMCO CAliCO CAMCO CA[~ICO CAMCO CALICO OTIS CA~CO CAMCO CAMCO CAMCO ..... OTIS OTIS D: DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON ~OBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* BPAE* B. CURRIER CHEVRON* D & M* STATE OF ALASKA* SOHIO* UNION* K . TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.'~r Post Office Bo~ ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1B-1 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUIO/L70 Enclosure If RECEIVED JUL 1 7 1985 Alaska 0ii & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ' L AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, inc. 80-40 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface-- 496' 'FNL, 982' FEL, Sec.9, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' 12. 8. APl Number 50--. 029-20~Rc~ 9. Unit or Lease Name I~upe~uk R~ver Unit 10. Well Number I6. Lease Designation and Serial No. An~ ~48 ALK Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data !R-1 11, Field and Pool Kuparuk River Field Kuparuk River 0il Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1500 hfs, 6/21/85. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing. Retrieved pkr. Drld LC & firm cmt to 8510'. Stuck pipe ~ 8271'. Twisted 2-3/8" DP off while attempting to recover fish. Set bridge plug @ 7270'. Tstd csg & plug to 2000 psi - ok. RIH & unseat bridge plug. Ran 2-7/8" completion assy w/tail ~ 7341'. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/75 bbls diesel & brine. Set BPV. Secured well & released rig ~ 1930 hfs, 7/1/85. RECEIVED JUL 1 7 1985 Alaska 0it & Gas Cons. C0~missi0n Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. The space below fq~Commission use Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU10/SN07 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, Inc. Post Office £ .)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 TRANSMITTAL NO: 5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1 ! 15B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE RECEIPT AND RETURN ONE SIGNED COPY OF SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE, FLUID, AND ACID DATA FOLLOWING ITEMS. PLEASE ACKNOWLEDGE THIS TRANSMITTAL. SBHP 05-3 0-8 5 lB-2 SBHP' 05-30-85 lB-4 SBHP 05-16-85 lB-4 PRE-WORKOVER 05-24-85 ID-8 SBHP 04-29-85 1E-lA TUBING LEAK 05-03-85 1E-5 COMP PBU ETC. 04-28-85 !E-11 LEUTERT Bi{ SMPL 06-02-85 1E-23 SBHP 05-22-85 !E-23 SBHP 05-23-85 iE-27 TEMP/SPIN-LEAK 05-03-85 1E-27 TUBING LEA]"{ 05-04-85 1G-6 PRESSURE Fk~LL- 05-07-85 OFF iH-6 SBHP 04-29-85 1L-5 PBU W/E-LINE 04-27-85 1L-5 PBU 04-29-85 lQ-1 ISIP 05-30-85 !Q-! SBHP 'A'SDS 05-26-85 lQ-3 TAG FILL BlIP 05-18-85 iQ-4 SBHP 'C' SD ETC 05-10-85 lQ-4 SBHP ETC 05-14-85 lQ-4 ACID JOB 05-17-85 iQ-5 ISIP TEST 04-29-85 lQ-7 ACID JOB 05-26-85 !Q-9 'C' SD PBU 05-12-85 iQ-9 PBU 'C'SD ETC 05-13-85 1Y-12 FALL-OFF TEST 05-05-85 2A-2 BHP 05-27-85 2A-4 'A'SD BHP 05-10--85 2A-4 'A'SD BHP 05-09-85 2A-4 'A'SD BHP 05-11-85 2A-5 SBi-iP 05-05-85' (ONE COPY OF CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO ***CONTINUED ON m,-' -~Hm FOLLOWING RECEIPT ACKNOWLEDGED: CAMCO CAMCO CAMCO CAMCO EACH) CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CAMCO CAMCO NOWSCO/B. J.HUGHES B. J. HUGHES NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO ....... CAMCO · CAMCO CA~;CO PA GE * * * --~ ISTR--/BIrlEftIN: W. PASHER EXXON PHILLIPS OIL* J. EATHMELL4~ BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* MOBIL* 9 & M.~' NSK CLERK DATE: ??-~"STATE OF ALASKA~ SOIIIO* UNION* K.TULiN/VAULT ARCO Alaska, Inc. is a Subsi~liary ol AtlsnticRichfieldCompany ARCO Alaska, Inc.'~r~ Post Office Bo'~( ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 30, 1985 Mr. C. V. Chatterton Commi ssi oner' State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Kuparuk 1B-1 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1B-1 to a selective single completion. Since we expect to start this work on June 7, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, · ing Engineer JBK/JWR/tw SN/L037 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany (~' STATE OF ALASKA OilyI ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L LXt~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: ~96' FNL, 982' FEL, Sec.9, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 90' I 6. Lease Designation and Serial No. ADL 25(G~8 ALK /~R_6 7. Permit No. 80-~0 8. APl Number 50- 029-20~+65 9. Unit or Lease Name i<uparuk River Uni~ 10. Well Number 1B-1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1B-1 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. Well will be drilled out to 8510'. ~ . The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally~ested each trip. A non-freezing fluid will be left in all uncemented annul( within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: June 7, 1985 S,abs~lue~.t Work Reportedt RECEIVED MAY 3 1 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. i here~ that the foregoing is~true and correct t° the best of my knowledge. Si,ned// //~~'~ ,"~~e,~,'l~-~'/ Title Area Drilling Engineer The spacke ~ ,~r ~on~is .oS~n u; - Conditicff~s of Approval' if any: Date Approved by ORI~:~AL SIGNED Approved Copy Returned By Order of COMMISSIONER the Commission Date 5-'3-I0~''~ Submit "Intentions" in Triplicate Form 10-403 (JWR) SN/061 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc~~ Post Office~.~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1983 Mr. Lonnie Smith State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Re' Subsequent Reports, Sundry Notices, Your Letter 10-12-83 Dear Mr. Smith: I'have researched the wells you asked about and the status is as follows: Well ARCO Date Comments Kuparuk 1-B1 1-8-83 A change notice was prepared. Copy dated 1-8-83 is attached. The clean out attempt was never done. Kuparuk 1-H1 4-21-82 This well to 1H-5. for 1-H1 number was changed See attached notices and 1-H5. Kuparuk 1-E28 9-23-82 Subsequent notice was prepared 4-5-83. See attached copy. Kuparuk WSW-1 8-5-82 I am collecting the injection dates and volumes. I will submit the subsequent notice within two weeks. Please call me at 263-4527 if you Charles K. House Kuparuk Operations Coordinator CKH/kmc have any questions. Attachments cc: W.L. Crandal 1/M.D. Schall R. S. May R. A. Ruedrich October 12, 1983 Mr. Charles l'Iouse Kuparuk Operations Coordinator ARCO Alaska, Inc. P. O..Box 100360 Anchorage, Alaska 99510 Re~ Subsequent Re~rts, Sundry' ~otices and Reports on Wells (Form 10-403) Dear Mr. Louse For the following list of "~otice of Intention To~" Sundr)- },'otices and Reports on Wells (form 10-403) this office does not have on record the "Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report'of the disposition of the intention. we 1 ! A~CO ~ate Brief Description of Intention 10-22-82 Clean out wel lbore with coiled tubin~ unit. F, uparuk WSW-1 08-05-82 In ject water Kuparuk 1E-28 09-23-82 change kick-off depth. ~uparuk 04-21-82 Change surfac~ casing setting depth. · Sincerely, ........ "'/ // :~.."'" '" ' t ' t.. '/ ~ ....... ~.,' /....... ,..,..., ....... ~.... .... Lonnie C.'.. S~i~h Commissioner LCS/EJ}! ~ lc ~ 105 :D1 KUP~ E1'¢31NEERIi~ TO: William VanAlen ~4: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following. PLEASE ~, F - F I LM, T - TAPE, PC - R-IOTOC~PY // JUN 0 6 t:983 PLEASE ~ RECEIPT TO:/ ARCD ALASKA, IN t Z, ATTN- SHELBY J. IVIATT]-I~S - ATO/11 '~l~a 0il & Gas Cons, 0ommission P. O. BOX 100360 Anchorage AI'~,,~E, AK. 99510 KUPARUK ENGINEERING TRANSMITTAL # ~/~7/~ TO: William Van Allen FROM: D. W. Bose/Shelby J. Matthews DATE' ~"~,~,._~:~]~_~,_~ WELL NAME: /~-" / Transmitted herewith are the following' PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: DATE: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC.' ATTN: SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM- D.W. Bose/Shelby J. Matthews Transmitted herewith are the following. PLEASE NOTE' BL- BLUELINE, S- SEPIA, F-FILM, T-'TAPE, C~--~ R~EIPT ACKNOWLEDGED- ~/~LEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN'. SHELBY J. 'MATTHEWS - AFA/3!I P.O. BOX 360 ANCHORAGE, AK. 99510 DATE: ~.!~i;~,.t'.~.,..] · .., i ;, .......... : . '! .,-, February. 16, .19 83 ARCO Alaska, Inc. .'- " P.O. Box 360 - Anchorage, Alas'ka 99510 Re z Subsequent Reports, Sundry }~otices and Reports on Wells {Form 10-403) · Attnl Pete Van Dusen .: District Drilling Engineer For the following lists of "Notice- of Intention To:" Sundry -' ~" Notices and Reports' on Wells (form 10-403) this office does no= .. -~'{'.: ~ ~'i~ ~',', ,.% - . 3' have on record the "Subsequent ~eport ell" defining the action ? ... taken on the approved intention. Please advise this office by "~-.' ~ Subsequent Report of the disposition of the intention. l~el 1 :..,:~'.~" :, '.~ ~ -~ ..~:. , .. ~: DS 14-18 '~ W. Sak River State B5 ?% ~,- ~.,.. ...::. -.. .. DS,.,12- 8A . · ~ ~ ?;.' · · ~ ,:., , DS 13-3 DS 12-4 ARCO Date 2/11/8,1 61.91 81 10123181 11123181 11/2/81 12115181 BP 24-10-14 : DS 13-2 West Bay State 1 BP 31-'10-16 DS 15-3 · ' Oliktok Pt. 1 :- DS 15-3 .,~ .~': ,..... . :, . ..... DS 5-11 · {-v.. DS 16-13 .,~ '~ N. Prudhoe Bay St. 2 · ~' guparuk 1E-12 , · . ,$. .... 12115/81 12123/81 212152 2/23/82 3/17/~2 3~23~82 4/2/82 4/5/82 6~2~82 6/2/82 Drief Description of Intention Change' course of this well- Workover Abandon lower borehole prior to sidetrack Abandon lower boruhol~ prior .to sidetrack Pull and replace tubing Abandon lower borehole prior to sidetrack Plug and abandon Pull and replace tubing Test Lisburne forr~ation Plug and abandon Change setting depth 9 5/8" casing Deepen 8% hole to baze~ent Change setting depth 9 5/8" casing Pull tubing and repair casing Sidetrack ' Abandonment procedure C~ange grade L-80 portion ' :. of" 7" casing Mr, .Pete' Van D~ n 2 f February 16, 1983 Sag River State 1 Kuparuk 1E-14 Kuparuk '1B-1 LCS/JKT/g lh 6/9/82 s/4/82 9/9/82.A "Dummy" nickel plated tree Perforate and flow test Stimulate Kuparuk sands . '~U STATE OF ALASKA E~' ALASKA iLAND GAS CONSERVATION C ivfMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 7. Permit No. 2' Na~,~SPe~t°& S ka, Inc. 80-40 · 8. APl Number 3'Ad~reSSOo BOX 360, Anchorage, Alaska 99510 50_029-20465 4. Lo~tion~f Well burtace Location' 496' FNL, 982' Sec. 9, T11N, R10E. Bottom Hole Location' 1144' FSL, FWL, Sec. 9, T11N, R10E. 5. Ele~vs,tiCn in_ feet_(indicate KB, DF, etc.) KB) FEL 815' 6. Lease Designation and Serial No. ADL 25648 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1 -B1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] ' Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 13, 1982 the Kuparuk Sands in Kuparuk River Unit Well 1-B1 were stimulated with a gelled water fracture treatment. The treatment consisted of 530 bbls. of gelled water, 13,000 lbs. of 20/40 sand, and 14,000 lbs. of 12/20 bauxite. Prior to the treatment all surface equipment was tested to 6000 psig. The average rate during the treatment was 15 BPM with a maximum treating pressure of 4800 psig. Prior to the treatment, this well produced following the cleanup period showed that B, OPD. Recent tests show that the rate has at a rate of 400 BOPD. A test the rate had improved to 585 declined to about 450 BOPD.-----~ Current Well Status' Producing to CPF. RECEIVED F E B - 9 1983 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission Anchor. age Kuparuk Title Operations Coordinator Date /"-'~- ~ Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ILAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-40 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20465 4. Location of Well Surface Location' 496' FNL, Sec. 9, T11N, R10E. Bottom Hole Location' 1144' FWL, Sec. 9, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 98 ' (KB) 12. 982' FEL FSL, 815 ' (Submit in Triplicate) / ' Perforate [] Alter Casing [] Stimulate [] Abandon [] J Stimulation Repair Well [] Change Plans Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1-B1 I6. Lease Designation and Serial No. ADL 25648 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Based on the poor results of the cleanout attempt on Kuparuk River Unit Well 1A-11, our plans to perform a similar cleanout on well 1B1 have been cancelled. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. r~C ~ Kuparuk Signed · Tide OD~r~t i~rl~ The space ~]ow for Com~iission use /"~ ' Conditions-of Approval, if any: Coord ! nator Date BY Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. { Post OfficeE~0x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager October 22, 1982 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation · 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Commission Attached is a notice of wellbore in Kuparuk well If you have any questions, our intent 1-B1 with a please call R. L. Stramp Kuparuk Operations Coordinator RLS/b xc' D. J. Caffrey - AFA 350 L. M. Sellers - ANO 332 E. A. Simonsen - AFA 331 H. C. Vickers - AFA 326 to clean out the coiled tubing unit. met at 263-4528. RECEIVED OCT 2 2 1982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK ~ ILANDGAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ARCO Alaska, ]:nc. 3. Address P. O. Box 560, Anchorage, Alaska 99510 4. Location of Well Surface Location' 496' FNL, Sec. 9, T11N, R10E. Bottom Hole Location' 1144' FWL, Sec. 9, T11N, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 98' (KB) 982 ' FEL FSL, 815 ' I 6 . Lease Designation and Serial No. ADL 25648 12. 7. Permit No. 80-40 8. APl Number s0-029-20465 9. Unit or Lease Name Kuparuk River Unit 10. Well Number ! -B1 11. Field and Pool Kuparuk River Field Kuparuk River Oi] Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to use a coiled tubing unit to clean out 144' of wellbore fill resulting from a recent fracture treatment in Kuparuk well 1B-1. This fill .currently covers the "A" Sand perforations in the well limiting production from this zone. A diesel/nitrogen foam will be displaced through the coiled tubing to lift the fill from the wellbore. All surface equipment and BOP's will be tested to 4000 psi. Anticipated start date' October 27, 1982. Sub~equen~ Work Re,or, ecl RECEIVED OCT 2 2 1982 Alaska Oil & Gas Cons. Comr~Jss~on Anchorage ' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b(~ow ;~r Commission us; ' Title Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Kuparuk Operations Coord i .n. at or Date Approved opy By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ;:, rich :;~.,ger, ,.&,~.~sR~ ~.}95 ! 0 'reier. s. hone 907 27'? 5637 i'(ups=uk Opera'!.ior;s Manager September 9, 1982 Mr. Chat Chatterton State of Alaska 'Oi 1 and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Attached are two Sundry Notice forms. The first indicates our change in plans regarding the fracturing of Kuparuk River Unit well 1A-4 and the second is a Notice of Intent to perform a fracture treatment on Kuparuk River Unit well ~t.B-1~ Please call met at 263-4528 upon your approval or if you have any questions. paruk Operations Coordinator RLS/b Attachments xc' L. B. Kelly E. A. Simonsen L. M. Seilers H. C. Vickers L. A. Blacker STATE OF ALASKA ALASK~'L AND GAS CONSERVATION C_i¢" ' 4MISSION SUNDRY ,,, TICES AND REPORT ON WELLS' 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, 1nc. 80-40 - 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20465 982 ' FEL 4. Location of Well Surface Location' 496' FSL, Sec. 9, TllN, R10E. Bottom Hole Location' 1144' FWL, Sec. 9, TllN, R10E. 5. Elevation in feet (indicate KB, DF, etc.) 98 ' (KB) FSL, 815 ' 6. Lease Designation and Serial No. ADL 25648 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1-B1 11. Field and Pool Kuparuk River Field Kuparuk River Oi 1 Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I-] Perforations [] Altering Casing ['-I Stimulate [;~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, with a strat gallons of b t a 1 t P treatment. tot. Inc. proposes to stimulate the Kuparuk sands in this well ofrac (gelled water) fracture treatment consisting of' 42,210 stratofrac, 13,000 pounds of sand and 14,000 pounds of auxite. All pumping equipment will be pressure tested to 5000 psi and reating pressures will be maintained below this valve. All circulated nd flowed fluids will be diverted to tanks on location. Temperature ogs will be run both before and after the treatment to define the reated intervals. A suite of production logs will be run along with a ressure buildup test after the treatment to analyze the effects of the All wirel ine work will be done through a 3000 psi lubrica-. Expected start date is September 11, 1982. Subsequeat Work IteporteCl so. 14. I her correct to the best of my knowledge. ~,~,~ ~ Kuparuk Signed~;,Z/ JIlL -,~l'-t' :ritle Operations Coc~rdin~t. or Date The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy Returned By Order of COMMISSIONER ~he Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TO: DATE: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE KUPARUK ENGINEERING D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: .PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE ( RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. Alaska Oil & Gas Con~._c,,~,~. .' P. O. BOX 360 ANCHORAGE , AK 99510 ARCO Alaska, Inc. ', '.p,; ~ c. ;,:., :." May 14, 1982 Mr. C. V. Chatterton Commissioner State oF Alaska Alaska 0~1 & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised Well Completion Reports Dear Mr. Chatterton: Enclosed are revised well completion reports and gy~oscop.~c surveys f'o~ the following wells: 1B-9GI Reports fcc the three B-pad wells ace being resubmitted due ~o an RKB change. The original 1A-13 completLon repott ~nd.~caked that ce~kain i~ems would be submitted at a la~ez date; these items are now included on the revised report. P. A. Van Dusen PAV: JG/llm Enclosures GRUS/B15 ,Ai~.ska Oil ii, Gas C, ons, :' A(']/'~' STATE Of ALASKA ~ ALASK .-~ ,~ND GAS CONSERVATION C JSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-40 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20465 4. Location of well at surface 9. Unit Or Lease Name 496' FNL, 982' FEL, Sec. 9, T11N, R10E, UN ' ~A~~ON.~,7' Kuparuk 25648 At Top Producing Interval t VERIFIED I 10. Well Number 1274' FSL,1129' FWL, Sec. 9, T11N, R10E, UN jSurf F,_.~rl B-1 At Total Depth J~.j~. ~..~.~ ll. Field and Pool 1144' FSL, 816' FWL, Sec 9, T11N, R10E, UM ..... Prudhoe Bay F±eld 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupa~uk River 0J. 1 Pool 90' RKB ADL 25648 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 11-1.5-80 12-14-80 12-19-80I .... feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set 121. Thickness of Permafrost 8585'MD, 6553'TVD 8452'MD, 6461'TVD YES~] NOF-I 1782' feetMD 1650' (approximate) 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, VDL/CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 SUrf 80' 24" 200sx Permafrost to surface 10-3/4" 45.5# K-55 Surf 3177' 13-~/4" 1300sx Fondu & 1700 sx AS II 7" 26tt K-55 Surf 7495' 8-3/4" 790sx Class G & 175 sx AS II 5" 15t! K-55 7308' 8580' 6" 100 sx Class G AB FL-45 24. Perforations open to Production (MD+TVD of Top and Bottom'and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" 7241' 7175' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A N/A , 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A'IN/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ . I Flow Tubing Casing Pressure cALCULATED. '.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR 'RATE~ TM 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . ~ RECEIVED' 1 8 1982 . . . Alaska 0il & Gas Cons. Commission Anchorage -- Form 10-407 GRU4/B1/2/3 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS Kupa~uk Up Sand Up Sand Low Sand Low Sand Kuparuk TRUEVERT. DEPTH MEAS. DEPTH 8090' 8109' 8151' 8320' 8404' 8476' 6206' 6220' 6250' 6369' 6428' 6478' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. None 31. LISTOFATTACHMENTS Revised Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Area Drlg. Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate non~ Form 10-407 ALASKA _ .,ND GAS CONSERVATION C ,-,:. ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERV.ICE I-I 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-40 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20465 4. Location of well at surface 496'FNL,982'FEL, Sec 9, T11N, R10b, gm 9. Unit or Lease Name Kuparuk 25648 At Top Producing lnterval 1379'FSL, 1141'FWL, Sec 9, T11N, R10E, gM 10. WellNumber At Total Depth 1144'FSL, 815'FWL, See 9, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} I 6. Lease Designation and Serial No. 90' RKBI ADL 25648 Kuparuk River 0il Pool -12, Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/15/80 12/14/80 12/19/80, -- feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set [ 21. Thickness of Permafro't 8585' 6553' 8452' 6461 ' YES I~,. NO [] 1782 feet MD 1650' (approx.) 22. Type Electric or Other Logs Run DTL/BHCS/GR. FDC/CNL/NGT. VDL/CBL/CCL/GR, Gyro. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED !6, '. 6511 . F!_-g0 _~ln-f '80, 24- 200sx Permafrost t~i surface ... ?"' 26.~.~ N-SS .~,mf. 7495" .8,3/4"' 790 sx Class G & 1 15, sx AS II ~,, 15~} K-55 7308' 8580' 6" 100 sx Class G 24. Perforations bpen to Production (MD+TVD'of Top and Bottom and 25. TUBING RECORD . . interval, size and number) " SIZE DEPTH SET (MD) PACKER SET (MD) 8330 ' -8346' :3 1/2" 7241 ' 7175 ' 8356'-8410' w/4 SPF . 8108'-8165' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. "DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. " PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) Date of'Test' Hours Tested PRODUCTION FOR OIL-SBU " GAs. MCF' WATER/SBU CHOKE SIZE IGAS-OILRATIO ' FIo~v'Tu'-bi"ng: C~s'~ng Pressur.e CALCULATED ' OIL-SBu 'GAS-MCF WATER-BB~. ' OIL GRAVITY-APl (cor~) 28. ' .... ' ' ' CORE DATA ' . - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ,. ,. 29. 30. GEOLOGIC MARKERS FORMATION TESTS , .... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kupacuk River Form. 8084' ': 6202' Base Kupacuk River Focm. 8474 ' 6476' ,, , 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ...... Title Area 0ps. Engr. Date /LL ......... // ....... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 NORTIi ~LOPE EiIGIi.IEERIi;G( TC' TRAilSMITTAL ~ J. J. Pawelek/Ann Simonsen DATE- / - Z~ ?- ~ L. WELL,,~,.,_:"~';~- Transmitted here:.:ith are the following' PL ' " ' -.x~; HOTE - BLucL .... , SEPIA, F - FILM, T - TAPE EECE ! PT ACK;;O',.~L EDGE v,,~ ~N.._DATE' ARCO ALAS)LA, Ih'C. ATTH' A~';N SIMO~iSE~! AFA/311 P.O. BO:< 360 A.,~,,n~.~ ~,, 9~510 RECEIVED r ~ B 0 2 ]982 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Bo~ ~ Anchorage, -'~ .... Telephone 907 277 5637 December 17, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached please find subsequen~ reports for Kuparuk Wells: 1E-lA, 1E-3, 1E-4, 1E-5, 1E-6, 1C-6, and lB-1 Sincerely, J. S. Area Dayton Op.er at ~ ons EAS/bl Attachment Engineer ,~' C E ! ~' OEC'" /~[aska Oil & E:~s Cons. Anchorage SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLX[] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0.Box 360, 4. Location of Well Anchorage, Surface Location' AK 99510 496' FSL, 982' FEL Sec. 9, T11N,. RiOE 5. Elevation in feet (indicate KB, DF, etc.) __ KB:98' 12. 6. Lease Designation and Serial No. ADL Check Appropriate Box To In~i~a-te' I~ature of Notice, Report, or NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing 7. Permit No. 80 -40 8. APl Number 5o- 029-20465 9. Unit or Lease Name Kupar~lk 25648 10. Well Number lB-! 11. Field and Pool uparuk River Field Kunaruk R~ver 0i.1 Other i~ata ' SUBSEQUENT REPORT OF: (Submit in Duplicate) X [] Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Pool 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations on 11/25/81. to 3000 psi. Perforated from 8106'-8165' Enerjets using 4 SPF, 0° phasing. Ran HP, temperature, and fullbore spinner. HP was ISIBHP=3120 psi. Pressure test lubricator with Schlumberger 2 1/8" CCL, gradiomanometer, set at 6099' SS. The wel~x~w~as flowed to the test separator The well flow_e._d~ at of 400 B~OP/D with a FFBHP of 1758 psi, a F'FTP of 833Psi- aha a of 506 SC~F//STBO. SI well for PBU. Final SIBHP : 116 psi. Shut SSSV andJsecured well on 11/27/81. a rat e GOR 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space ~)l~w for Comm ission ~'e Conditions of Approval, if any: l~Area Operations Engineer tie Date DEC2 2 Approved by. AJaska 0il & Gas Corm. CommJssi0r, COMMISSIONER the CommisSion Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TDA~ q'.l T T-- n .......... ~.-~L ~ TO- ~ FROM:-. a.j. Pav;el ek/Ann Simonsen BATE- /,~o_./7-fY/ WELL,,,~,.,. Transmitted here:.:ith are the following' -,.. PLEASE HOTE' BL - BLUEL!HE, S - SEPIA, F- FILM, T - TAPE .- /£._./ . ,.'.C ~,,, O,'; L [: u,..~'"' EFCEiPT ~ .......... / · .,:_: ,'.E,uR,~ t'~EC ~?T TO' ARCO ALAS~$, It~C. A~T~,: A,'~; SIM0~}Sc'~, P.O. BOX 360 .... ~. ~ ~,, 9~510 A,~CxO~,~G~, ,~, RECEIVED DATE- DEC? I Ig&l- Alaska Oil & Gas Cons. Com~jssjoll Anchorage - AFA/311 ," ' , ?-- STATE OF ALASKA --', ~ ALASKA ~;( AND GAS CONSERVATION CO',~ ,ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. See below 3. Address P.O.Box 360, See below 4. Location of Well Anchoraq~] AK 99510 8. APl Number 50- See below 9. Unit or Lease Name See below 10. Well Number See be]._ow 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Desi'gnation and Serial No. _See below I See below Ku_n_aruk P_~ver Oil 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other~Data Pool! NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] t Repair Well [] Change Plans [] Repairs Made [] Other X[_YJ Pull Tubing ~] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). During August 1981 ARCO Alaska, Inc. performed a water injectivity test in the Kuparuk Sands to gain pertinent reservoir data in preparation for its Increment I Waterflood of the Kuparuk Sands. Injection was successfully achieved in that Upper and Middle Kuparuk Sands in Well lB-2 but not achieved in the Lower Sand in Well lB-1. Reservoir pressure response was monitored in two wells, lA-3 and lB-5. Water for the test was produced from our water source well No. 1. A brief review of test is attached. Well API Number B~_2 50-029-20465 50-029-20531 lB-5 50-029-20237 lA-3 50-029-20615 WS-1 50-029020090 Location Sec.9 TllN R10E Sec.4 TllN R10E Sec.9 TllN R10E Sec.5 TllN R10E Sec.9 TllN R10E Elev. Unit Name Lease Designation KB-98' Kuparuk 25648 ADL 25648 KB-98' Kuparuk 25648 ADL 25648 KB-89.5' Kuparuk 25648 ADL 25648 KB-100' Kuparuk 25647 ADL 25647 KB=98' Kuparuk 25648 ADL 25648 f 14. I here t to the best o my knowledge. Conditions of Approval, if any: EngineeDate lo-Z?-~ By Order of Approved by COMMISSIONER the Commission Date Form 1.0-403 Rev. 7-1-80 Submit "Intentions" in Trip,mate and "Subsequent Reports" n [.3upl~cate Attachment to Sundry Notices and Reports on Wells Kuparuk Water Injectivity Test The Kuparuk Water Injectivity Test began on August 7, 1981 with injection into the Upper and Middle Sands in Well lB-2 at a constant surface pressure of + 1050 psi. Injection continued until August 24, 1981. A stabilized injection rate during this period of +1050 BWPD was observed. An average BHP of + 3850 psi during this period yielded an injectivity index of + 1.7. Injection profiles run during the test indicated tha--t the majority (70%+) of the water was going into the Middle Sand. After completion of the steady state injection period, injec- tion'was stopped for a pressure fall off test. Following this shut in period, a step rate test was run. Results of the step rate test ~ indicated a reservior parting pressure of + 4320 psi. -- Having successfully demonstrated the injectability of the Upper and Middle Sands in lB-2, attention was turned to the Lower Sand in Well lB-1. On August 27 attempts were begun to estab- lish injection in lB-1. Two attempts to begin injection with surface pressur~es of up to 2250 psi were unsuccessful. A coiled tubing unit was used to displace wellbore fluids with diesel and again attempt to inject. This too proved unsuccess- ful. The well was flowed to be sure that the perforations were open. No further efforts to inject were made. It is felt that some sort of plugging is preventing injection in the well. The test was concluded on AUgust 30, 1981. During the injectivity test, reservoir pressure r-esponse was monitored in two offset wells, lA-3 and lB-5. A bottom hole pressure increase of + 3.7 psi and + 8.0 psi respectively was measured in the wells. Attached as part of this report are charts and plots of injec- tion parameters, step rate testing, and offset pressure response. HCV 10/26/81 KUPARUK WATER IN~MTY TEST Steady State Injection DATE INJ RATE BHP TE~-~ 8 6 0 3230.9 160.2 8 7 2448 3847.9 76 8 8 2398 3827.3 69 8 9 2273 3817.5 69 8 10 1520 3854.2 77 8 11 1254 3861.0 77 8 12 1210 3867.5 77 8 13 1301 3811.4 77 8 14 1297 3855.3 76 8 15. 1018 3850.1 76 8 17 1063 3846.7 77 8 18 1068 3843.7 77 8 19' 1112 3848.9 76 8 20' 1082 3842.4 76 8 21 975 3844.3 75 8 22 1063 3846.5 77 8 23 1050 3844.8 75 8 24 923 3860.8 78 Ap 617.0 596.4 586.6 623.3 630.1 636.6 580.5 624.4 619.2 615.8 612.8 618.0 611.5 613.4 615.6 613.9 629.9 II 3.97 4.02 3.87 2.44 1.99 1.90 2.24 2.08 1.64 1.73 1.74 1.80 1.77 1.59 1.73 1.71 1.47 Cumulative Steady State Injection = 22 MBW KUPARUK WATER INJECTIVITY TEST Ii'IJECTION RATE KUPARUK ID-2 .. 250O-- 200O- 1500- . ~ lO00- 1,,--I 50O- .. 6 I DAYS ! 4'000~ 380O- 360O- 340O- 3200- 3OOO KUPARUK WATER INJECTIVITY TEST IliJECTIO[~, BHP · IIIJECTIVITY INDEX,~ KUPARUK 1D--2 i 11 ti i i i 6 ~ · 12 !4 16 DAYS _5 ~ 4 _3 _2 1 18 KUPARUK ~FATER INJECZMTY TEST Step Rate Test INJ PRESS 750 1000 1250 1550 1800 2000 iNJ ~'~-~- ~m BHP 'T~4P A P II 0 3260 · 122. 336 3433 117. 173 1.94 692 3797 109. 537 1.29 1266 4068 100. 808 1.57 3060 4344 77. 1084 2.82 4648 4490 70. 1230 3.78 7968 4554 64. 1294 6.16 ... ......... . ...... 3750 . -4OOO : [ · . .. 4500' -- .......... ~. . · . 4250 - -- ..... . .. _ . ~ .. l' 1' KUPARUK WATER INJECTIVITY TEST i STEP RATE-TEST' KUPARUK 1D-2 i:;L:' · ,: .. i i ; '. ..~, i i , 1 Parting Pressure 4320 PSI :.., ....... ~ .... ~_- i ............... , .... :'!" i :"' ,_ ...~ I -':' · ; ' '';' . . :., . . ~..: . "t ' .... _! ., : 1. ..... , ..-t .... : .i ........ L; ... '-! ..... ~'i · --f~:.~. , - i ' ' ' ' '- ..... ~i;!' 2 ~-{i ' 3 "~'i:~!~4 '' 5 , !"!~ INJECTION RATE:(MBD) ,-. · , ! 'i .- KUPARUK WATER INJECTIVITY TEST ~,bnitor ~'Jells Pressure Response DATE 8 6 8 7 8 8 8 9 8 10 8 11 8 12 8 13 8 14 8 15 .8 16 8 17 8 18 8 19 '8 20 8 21 8 22 8 23 8 24 8 25 8 26 8 27 8 28 8 29 KUPARUK lB-5 T~P 3261.8 157.1 3262.1 157.1 3261.6 157.2 3262.6 157.4 3263.5 157.6 326'3.8 157.6 3264.4 157.7 3264.3 157.9 3265.3 157.9 3265.7 158.0 3266.4 158.1 3266.9 158.2 3267.4 158.3 3267.9 158.4 3268,4 158.5 3268.6 158.6 3269.3 158.5 3269.8 158.6 3270.0 158.7 3269.9 158.7 3270.2 158,7 3270.3 158.7 3270.2 158.8 3270.2 158.8 KUPARUK lA-3 TE~ 3173.4 158.2 3173.4 158.4 3173.4 158.6 3173.6 158.8 3173.8 159.0 3173.9 159.1 3174.0 159.2 3174.2 159.4 3174.4 159.6 3174.6 159.7 3174.9 159.9 3175.1 160.0 3175.3 160.1 3175.5 160.1 3175.7 160.2 3175.9 160.3 3176.2 160.4 3176.4 160.6 3176.7 160.7 3176.8 160.8 3177.1 161.0 Pressure Response ± 8.0 PSI Pressure Response ± 3.7 PSI 3180. 3177'. 5 3175.0 - 3172.5 3170.0 :-' KUPARUK ~&TER INJECTIVITY TEST MONITOR I~,IELLS PRESSURE RESPONSE Kuparuk !A-3 16 18 20 22 .... 24, : 3270.0 - 3.2,6Y .:5 3265..0 - 3262..5 - 3260.0 I-." I "i- t--- 2 4 6 8 10 12 14. 16 !g 20 22 24 iiORTH '.~LOPE EHGI TRAilSHiTTAL ~ '~7~& FP, OM' J.J. Pa;.;elek/Ann Simonsen DATE' ~ Z~-8// WELL · · Transmitted here;.;ith are the following: PLEASE HOTE' BL - BLUELI~IE, S - SEPIA, F - FILM, T - TAPE STATE OF ALASKA ALASKJ( )IL AND GAS CONSERVATION (~' ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-IX OTHER [] 2. Name of Operator ARCO A1 aska, Inc. 3. Address P.O.Box 360, Anchorage, AK 99510 4. Location of Well Surface Location: 496' FSL, 982' FEL, Sec. 9, TllN, R10E 7. Permit No. 80-40 8. APl Number 50- 029-20465 9. Unit or Lease Name Kuparuk 25648 10. Well Number B-1 5. Elevation in feet (indicate KB, DF, etc.) KB=98 ' 12. 11. Field and Pool Kuparuk River Field J 6. Lease Designation and Serial No. . ADL 25648 Kuparuk River Oil Poo. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report'multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe. Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perf operations on 5/22/81.Tested B.O.P's & LUBR @ 3000 psi. Perf'd intervals 8383'-8410', 8356'-8383' & 8~30'-8346' w/Schlumberger 2 1/8" Enerjet gun w/4 SPF. Ran HP, CCL, GRADIOMANOMETER & Temp tool. Flowed well to tank. FFBHP=3123 psi. RIH w/BH sample tool & took samples @ 8370' & 7200'. SI well for PBU. Flowed well @ rate of 153 BOPD. FTP=75 psi. FBHP=2069 psi. Final SI BHP 3126 psi. Shut SSSV and secured well on 5/26/81. NOTE: HP Tool set at 6115'ss RECEIVED SEP2 9 ]98]. Alaska 0ii & (~as Cons. C0rnmissi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~)~ Area Operations Engineer Signed ; , _ Title Thespaceb I~Nfo'rCommissiLnu/ COnditions of Approval, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NORTH SLOPE Ei'IGINEERI!iG -- TRAf~SMITTAL # ~/~'/ J. J. Pa;,;eiek/Ann Simonsen DATE- ~-} t._-.2 ¢_~--~.?' WELL ,NAME- -. Transmitted herewith are the follo;,;~ng' PLEASE IlOTE' BL - BLUELIilE, S - SEPIA, F - FILM, T - TAPE .... n, I r-n"'Fl-! ~ . .,, IPT TO' ARCO ALASKA, INC. ATTk': AIiN SIMONSEH - AFA/311 P.O. BOX 360 A;~CI;C,;-,.~GE, AK 9a~lO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND'REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator ARCO A1 aska, !nc. 3. Address P.O. Box 360, Anchorage, AK 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) See bel ow 12. 7. Permit No. 8. APl Number 5o- See below 9. Unit or Lease Name See bel ow j~l ~ ~ (~ I 10. Well Number See be1 ow See bel ow 6. Lease Designation and Serial No. See be] ow Check Appropriate Box To Indicate Nature of Notice, Repo~, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~]] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool (Submit in Duplicate) [] Altering Casing [] [] Abandonment r-~ [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In preparation for its Increment I Waterflood of the Kuparuk Sands, ARCO Alaska, Inc. intends to perform a water injectivity test in two wells in late July and August, 1981. The purpose of the test is to gain pertinent data on the ability of the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging will be used to aid in determining injection characteristics. Monitoring of reservoir pressures in three offset wells during the injection, the A-3, B-4, and B-5 will be used in evaluating reservoir response to the injection. Water for the injection testing will be produced from our water source well No. 1. Expected start date is July 27, 1981 ~ API NUMBER LOCATION ~~) 50-029-20465 Sec 9 TllN RIOE B-2 50-029-20531 Sec 4 TllN RIOE B-4 50-029-20595 Sec 9 TllN RIOE B-5 50-029-20237 Sec 9 T11N R10E A-3 Not Assigned Sec 5 TllN RIOE ELEVATIONS UNIT NAME LEASE DESIGNATION KB = 98' Kuparuk 25648 ADL 25648' KB = 98' Kuparuk 25648 ADL 25648 KB = 98' Kuparuk 25648 ADL 25648 KB = 89.5' Kuparuk 25648 ADL 25648 KB = 100' Kuparuk 25647 ADL 25647 ADL 25648 WS-1 50-029-20090 Sec 9 Tll.~ RIOE KB = 9.8' Kuparuk 25648 14. I hereby certify that the fore, going i's true and Crrect to the best of my knowledge. /' ~/ . // .?. The space~'elow for Commission use Date Conditions of Approval, if any: Approved by. BY order O~f ....... COMMISSIONER the Commission 8Y HARRY W. KOI L[ii I Date Form 10-403 Rev. 7-1-80 Submit '"Intentions" in Triplicate and "Subsequent Reports" in Duplicate . STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION CG/i.~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No, ARCO Alaska Inc. 80-40 3. Address 8. APl Number Box 360 Anchorage, Alaska 99510 50-029-20465 4. Location of Well Surface Location: 5. Elevation in feet (indicate KB, DF, etc.) KB elevation=98' 12. 496'FNL,982'FEL Sec. 9, TllN, R10E I 6. Lease Designation and Serial No. ADL 25648 9. Unit or Lease Name Kuparuk 25648 10. Well Number 11. Field and Pool Prudhoe Bav Field -. Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing i--] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pdrtinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Atlantic Richfield Company proposes to perforate and flow test selected intervals within the upper and lower Kuparuk Sands. All wireline work will be done through a 3000 psi lubricator, which will be pressure tested after being installed on the well head. All perforated intervals, test volumes, and production log runs will be reported on a subsequent report. Expected Start Date 5-11-81 Subsequent Work Reported on Form. N0/~___~ Dated MAY - 1 1981 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S, ne The space below for Commiss~o~n ule ~ Date Conditions of Approval, if any: Approved by. Approved '"'o~y Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.~,~x Post Office 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 6, 1981 Mr. Hoyle Hamil.ton State of Alaska Alaska Oil and Gas Conservati on Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: B-1 Dear Sir: Enclosed please find the Completion Report and Gyroscopic Survey for B-1. An updated Completion Report will follow as soon as production data becomes ava'liable. Sincerely, ~ P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Stat-us of Well Classification of Service Well OIL ~X GAS [] SUSPENDED F-} ABANDONED [] SERVICE [] 2. Name o¥ Operator 7. Permit Number Atlantic. Richfield Comp_any 80-40 .. 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 995]0 s0-029-20465 ,, 4. Location of well at surface 9. Unit or Lease Name 496' FNL, 982' FEL, Sec 9, TllN, R10E, UM Kuparuk 25648 At Top Producing Interval 10. Well Number 1379' FSL, ll41' FWL, Sec 9, TllN, R10E, UM B-1 At Total Depth 11. Field and Pool ]]44' FSL, 8]5' FWL, Sec 9, TI]N, R]0E,'UH. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i] Pool 98' RKB! ADL 25648 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/15/80 12/14/80 12/19/80' "-' -- feet MSLI 1 8585MD 6553'TVD 8452MD 6461'TVD YES[~ NO[] 1782 feetMD 1650' (approx) . 22. Type Electric or Other Logs Run DIL/BHCS/GR, FDC/CNL/NGT, VDL/CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING REcoRD SETTING DEPTH MD ' CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD, AMOUNT PULLED 16" 65# H-40 surface 80' 24" 200 sX Permafrost tc surface .. 10-3/4" 45.5# K-55 surface 3177' 13,3/4" 1300 sx Fondu & 170C sx AS II 7" 26# K-55 surface 7495' 8-3/4,' 790 sx Class G & 175 sx AS II ,5" 15# K-55 7308' 8580' . 6" 100 sx Class G AB FL-4$ , 24. Perforations open to Production (MD+TVD of .Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~ i 3½" 7241'", 717.5' · , n/a ; 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED . , n/.a , .. " , . . · 27. PRODUCTION TEST , , Date F!r~t Production ..~. I Method of Operation (Flowing, gas lift, etc.) n/a I ' Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF' WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) -Press. ~ 24-HOUR RATE · , - 281' ' CORE DATA . . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. noFie -- 0 P. ~,t~.~<a Oil a ~ ,on:~. Commission Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GQR, and time of each phase. T Kuparuk 8090' 6206' T Up Sand 8109' ;' 6220' None B Up Sand 81 51' 6250' T Low Sand 8320' 6369' B Low Sand 8404' 6428' B Kuparuk 8476' 6478' · ....... 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey ...... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ............. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, 'injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent 'to such interval. item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". B-1 DRILLING HISTORY Spudded well @ 1900 hrs,~ 11/15/80. Drld 13-3/4" hole to 2712'. Ran multishot. Drld 13-3/4 hole to 3200'. Ran DIL/BHCS/SP/GR, FDC/CNL/ GR, BGT, RFT. Ran 77 jts 45.5# K~55 BTC 10-3/4" csg w/shoe @ 3177'. Cmtd w/1300 sx Fondu and 1700 sx AS II. ND Diverter. Instld and tstd 10-3/4" pkoff. NU BOPE. Tstd csg to 1500 psi. Drld cmt, shoe + 10' new form to 3210'. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 3999'. Cond mud and POH to run RFT on waste water injection zone. Started injecting at CPF-1 and observed immediate flow at B-1. SI well @ 225 psi and SI CPF-1 @ 560 psi. Pump 150 bbl 12.5 ppg to kill well. TIH. Circ and cond to 12.1 ppg. Lost 50 bbls. Spot LCM pill. Drill 8-3/4" hole to 4066'. Spot LCM pill. Build mud volume and cond to 12.0 ppg. Drill ahead to 5145' losing total of 180 bbls between 4510' and 5145. Drld 8-3/4" hole to 7515'. Ran multishot. Ran 180 its 7" 26# K-55 BTC csg ,w/shoe @ 7495'. Cmtd w/790 sx Class G cmt thru shoe and 175 sx AS II cmt thru DV @ 4050' 'Instld and tstd 7" pkoff to 3000 psi - ok. Arctic packed 7" x 10-~/4" annulus w/580 sx AS II cmt and 117 bbls Arctic Pack. Tstd csg to 1500 psi--ok. Drld cmt shoe and 10' new hole to 7525'. Tstd form to 12.5 ppg EMW. Tstd 7" x 10-3/4" annUlus to 1000 psi--ok. Changed to oil base mud. Drld 6" hole to 8500' Ran DIL/GR/BHCS, FDC/CNL/NGT, Drld 6" hole to 8585'. Ran 31 jts A~ FL 4S K55 5" liner f/7308'8580'. Cmtd w/lO0 sx Class G cmt. Drld cmt 8400'-8450'. Tstd csg and liner lap to 1500 psi - ok. Displace well with NaC1/NaBr. Ran Gyro, VDL/CBL% CCL/GR. Ran 3½'.' completion assy w/tail @ 7241' and pkr @ 7175'. Displace well to diesel. Dropped ball and set pkr. Tstd tbg to '3000 psi and ann to 200 psi - ok. Tstd tbg to 200 psi and ann to 1500 psi ok. ND BOP. NU & ts t tree to 3000 psi. Secured well and released rig @ 0200 hrs, 12/19/80. 700 West 41st, Suite 101 Anchorage, Alaska 99502 Phone 272-2496 Telex: 25-364 World Leader in Service to the Oil Industry December 16', 1980 Job #4435 North Slope Drilling' ~ .... Enclosed please find our ~y~ro~urvey on Kuparuk B-1 along with our Vertical Section and Horizontal View maps. Also enclosed you will find the Gyro Film, Field Sheet and Calculations. If any other information is needed please call 272-2496. Thank you for using Scientific Drilling International and please call again. Sincerely Manager :OMPL. ETION REPORT ~P, CO OIL & GAS 5YROSCOPIC SURVEY ~.ADIUS OF CURVATURE :O,MPUTED FOR SDC FY METHOD OF FM LINDSEY COMPUTAT I ON & ASSOC 9 JAN 81 KUPARUK B-1 ,.,JOB 1"40 4435 RECORD OF SURVEY TRUE 4EA5, DRIFT VERTICAL )EPTH ANGLE DEPTH 0 0 O 0.00 100 0 0 100,00 200 0 0 200.00 30O 0 O 300,00 400 0 C 400,00 500 2 O 499,97 600 4 0 599,83 700 7 30 699,31 800 8 30 798,34 900 10 15 897,00 1000 11 15 .995,24 1100 14 0 1092,82 1200 17 45 1188,99 1300 20 30 12~3,46 1400 25 45 1375,39 1500 20 45 1467.24 1600 32 0 1556.69 1700 36 45 1639,20 1800 41 n 1717o03 1900 4] 45 1792.07 2000 41 0 1867oll 2100 45 0 1940,23 2200 45 0 2©10,94 2360 44 15 20~2,11 24~0 42 30 2154,80 SUB SEA -98,00 2,00 102,00 202,00 302,00 401,97 501,83 601,31 700,34 799,00 897,24 994,82 1090,99 1185,46 1277,39 1369,24 1458,69 1541,20 1619,03 1694,67 1769,11 1842.23 1912.94 1984.11 2056,80 DRIFT DIREC DEG, N O.OOE N O,OOE N O,OOE N O,OOE N O,OOE 'S50,OOW S46,00W S30,OOW S30.OOW S33,00W S29.00W 534,00W S34,00w S33.00W S36,00W S36,00W S36.00W S40,OOW S38.00W S37.00w S38.00W S26,00W S26,00W S25,00W S30,OOW TOTAL COORDINATES O.OO S O.OO S 0.00 S :..~ 0.00 S 0,00 S _ 0,58 N 2..9t.~ 10.77 22.83 S 36,71 S 52,70 S 71.33 S 94.00 S 121,32 S 153.6'7 S 185.60 S 221.48 S 265.95 S 314.71S 367.15 S 419.59 S 477.31 S 540.86 $ 604.26 S 665.16 S 0.00 w 0.00 W 0.00 W 0.00 W 0.00 w i,.26--:W 11.29 W 18.25 W 26,76 W 36,37 W 47.78 w 63,08 w 81,16 w 103.39 w !26,59 W 152.66 w 187.40 W 226,89 W 267.12 W 307.36 w 343,43 W 374.43 W 404,67 W 436,37 W CLOSURES DISTANCE ANGLE D M 0,00 S 0 O,O0 S 0 0,00 S 0 0,00 b 0 0,00 S 0 1,39 N 64 5,91 S 60 15,61 S 46 29.23 S 38 45,44 S 36 64,03 S 34 85.86 S 33 113.20 S 33 145.96 S 33 185.22 S 33 224,66 S 34 268,99 S 34 325.34 S 35 387.97 S 35 454.04 $ 36 520,12 S 36 588.02 S 35 657.82 S 34 727,25 S 33 795 · 52 S 33 DOG LEO SEVERITY DEG/.IOOFT 0 0 w 0.000 0 0 w O.OOO 0 0 w 0 0 w O.O00 0 0 w 0,000 59 59 w 2,006 31 29 W 2,000 20 49 W 3.511 38 ~9 w 1,000 5 28 W 1,753 36 37 W 1.012 49 9 W 2../66 51 46 W 3,750 46 53 ~ 2.753 56 1W 5.280 17 47 W 5.~00 34 38 W 11.250 47 22 w 4.336 2 18 w 0.571 13 27 w 0,865 44 $ W 7.211 41 39 w 0.000 48 35 W 0.894 15 59 W 2.876 SECTIo,N DIbTA,'~Cg 0.00 O.OC O.O0 0.44 5.66 15.60 29,11 45,03 63.22 84,57 111,53 i45.77 ldZ.Sz 2Zl.62 265.5'1 ~21.72 j~4.25 4~9.~6 515.66 282.30 649,66 716,37 782.29 ~RCO KUPARUK 5-1 GYROSCOPIC SURVEY JOB NO 4435 9 JAN 81 RECORD OF SURVEY TRUE 4~AS. DRIFI' VERTICAL )EPTH A~iGLE DEPTH 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 a200 43O0 ~400 4500 4600 4700 4800 4900 5000 5100 52 o 3300 ., 3!~ 0 2231,10 41 15 2308,12 44 0 2381,69 44 45 2453,17 44 45 ~.°524,. 18 40 0 2598.04 40 0 2674.64 30 0 2756.45 30 15 2842.95 40 0 2924.64 41 0 3000.68 42 0 3075,57 42 15 3149,74 42 30 3223.62 43 0 3297,05 43 15 9.370,03 44 0 3442.42 43 30 3514,66 44 15 3586.74 45 0 3657.91 45 15 3728.47 45 30 3798.72 46 0 3~68.49 45 0 3938,5~ 46 O 4008.67 46 30 4077,83 46 0 4146.98 46 15 4216.29 46 45 42R5.12 SUB SE4. 2133,10 2210,12 2283.69 2355.17 2426,18 25C0.04 2576.64 2658.45 2744.95 2826.64 2902,68 2977.57 3051.74 3125.62 3199.05 3272.03 3344.42 3416.66 3488.74 3559,91 3630.47 3700.72 3770.49 3840.58 3910.67 3979.83 4048.98 4118.29 4187,12 DRIFT DIREC DEG. S30, S32, S30, S34, S33. S32, S33, S31, S32, S35, 'S37, S37. S38. S38, S38. S37. 538. 538, $39, S40. S41. $39. $39. S42, S40. S40. S41, S40. S41. OOW OOW OOW OOW OOW OOW OOW OOW OOW OOW OOW OOW OOW 0 OW OOW OOW OOW OOW OOW OOW 0 OW OOW OOW OOW 0 OW OOW OOw TOTAL COORDINATES 721,10 S 775.76 S 833,79 S 893.09 S 951.80 S 1008,62 S 1062.83 S 1111.41 S 1154.2-0 S 1202.12 S 1254.66 'S 1307 · 58 ~S 468.67 W 501.51 W 536.38 W 573'. 43 W 612 · 29 W 648 · 49 W 683,03 W 713 · 38 W 739.61 W 771,32 W w 849-3'7 W 136o. 9 s .ago.zo w 1467.39 .Sc 973.49 W 15 1. z s zoz .zo w s 10 7. 0 w s 1739,29 S 1187,50 W 1~93,18 S 1233,52 w 1847,70 S 1279,27 W 1903,36 S 1324,35 W 1957,59 S 1370,66 w 2011,42 S 1417.45 W 2066.75 S 1463.89 W 2121.68 S 1510,80 W 2176.50 S 1557.61 W 2231.65 S 1604.72 W CLOSURES D I STANCE ANGLE D M 860.02 S 33 1 16 ,',' 923.75 S 32 52 54 w 991,42 S 32 45 11 w 1061.34 S 32 42 13 w 1131,73 S 32 45 11 W 1199.11 S 32 44 20 W 1263.39 S 32 43 36 W 1320.67 S 32 41 42 W 1370.84 S 32 39 5 w 1428.30 S 32 41 8 W 1493 · 13 S 32 49 46 W 1559.23 S 33 0 24 w 1626.i0 S 33 11 30 W 1693.27 S 33 22 59 W 1760.94 S 33 33 39 W 1829.14 S 33 42 28 W 1897,99 S 33 50 44 W 1966.97 S 33 59 29 W 2036,07 S 34 8 41 w 2106.02 S 34 19 23 W 2176.48 S 34 31 26 ~ 22z+7.34 5 34 41 49 W 2318.77 S 34. 49 47 W 2389.75 S 34 59 55 W 2460.69 S 35 10 20 w 2532.68 S 35 18 36 W 2604,62 S 35 27 13 W 2676.43 S 35 3'5 22 W 2748.71 S 35 43 8 W DOG LEG SEVERITY DEG/iOOFT 4.500 3.~64 2.914 2.120 0.704 4.768 0.643 10.012 0.~56 9.828 1.319 0.517 0,250 0.500 0.532 0.892 0.500 0.894 0.901 0.563 1,045 0.500 1.803 1.439 0.500 0.720 0.579 0.729 5LCT I 0~',, D I STA~\CE 845.04 907.24 973.28 1041.74 1iil.02 1177.11 1240.16 1296.24 i~45.29 1401.C4 i466.19 1531.99 159W.67 1665.73 1733.27 1~i.23 1~69.81 1938.62 2007.64 2077.69 2i48.44 2~19.46 2290.84 2362,05 2*33.29 2bOb.37 2577.49 20~9.46 2721.60 kRCO KUP A RUK B-1 GYROSCOPIC SURVEY JOB NO 4435 JAN 81 RECORD OF' SURVEY EAS. EPTH DRIFT A ~'.....~ L El 5400 47 O 5500 47 15 5600 47 45 5700 47 15 5800 48 3 5900 47 15 6000 47 15 6100 47 0 6200 47 15 6300 46 45 6400 47 0 6500 47 15 6600 47 C 6700 47 30 6800 47 0 6900 47 15 7000 46 45 7100 46 15 7200 46 15 7300 46 30 7400 46 15 7500 46 15 7600 45 0 7700 44 ~© 7800 44 0 7900 44 30 8000 44 0 8100 43 45 ~200 45 15 TRUE VTRT ICAL DEP TH 4353,48 4421.52 44B9,()g 4556,64 4624,04 46ql,43 4759.31. 4~27.35 4~05,39 4953,59 5031.~5 5099,99 5168,03 5235,91 5303,79 5371,83 5440.03 5508.87 5578.02 5547,01 5'716,00 5785,16 5555.09 5926,11 5997.74 6069.37 6141,00 6213,08 6284,41 SUB SEA 4255,48 4323,52 4391.C)8 4458,64 4526,04 4593.43 4661,31 4729.35 4797,39 4865,59 4933,95 5001,99 5070,03 5137,91 5205,79 5273.83 5342,03 5410,87 5480,02 5549,01 5618,00 5687,16 5757,09 5828.11 5899,74 5971.37 6043,00 6115,08 6186,41 DRIFT DIREC DEG. S43,00W S42,00W S44,00W S42,00W S44,00W S43,00W S47,00W S45,00W S46,00W S46,00W 'S46,00W 547,00W S47',00W 548,00W S49,00W S50,OOW S54,00W S53,00W 555.00w S55.OOW S57.00w S58.00W S58.00W S61.OOW S62.00W S63,00W 564,00W S68,00W S67,00W TOTAL COORDINATES 2285,89 S 1653,56 W 2339.92 S 1703,07 W 2393,84 S 1753.35 W 2447,76 S 1803',62 W 25.01,78 S 1854,00 W 2555,37 S 1904.86 W 2607,28 S 1956.77 w 2658.19 S 2009.48 W 2709.55 S 2061,75 W 2760,35 S 2114.36 W 2811.06 $'"' 2:166,8:6 W 2861.50FS 2220.02 W 2911,48~.S ~:2273,62 W 2961,09 S' :' 2327.-76 W 3009.75 S 2382,75 W 3057,34 S 2438,48 W 3102,36 S 2496.10 W 3145,50 S 2554,41 W 3187.96 S 2612.84 w 3229,48 S 2672,14 W 3269,96 S 2732,15 W 3308,77 S 2793,07 W 3346.~4 S 2853.69 W 3382.37 S 2914.34 W 3415,67 S 2975.66 W 3447.89 S 3037,55 W 3479.02 S 3100,00 W 3507.21 S 3163.31 W 3534.03 S 3225.06 W C L 0 D I STANCE S U R E S A~".~G LE D M 2821,27 S 35 52 51 2894,07 S 36 2 53 2967,27 S 36 13 14 W 304G,49 S 36 23 4 W 3113,88 S 36 32 25 W 3187,22 S 36 42 7 w 3259,89 S 36 53 17 3332.26 S 37 5 16 w 3404.78 S 37 16 5 w 3477,08 S 37 27 4 3549.27 S 37 37 34 w 3621,70 S 37 48 18 w 3694,06 S 37 >.766,50 S 38 10 17 w 3838.76 S 38 22 4 3910.69 S 38 34 30 w 3981,85 S 38 49 10 W 4052.06 S 39 4 45 W 4121,90 S 39 20 16 W 4191,64 S 39 36 18 W 4261 · i 3 S 39 52 47 W 4330,04 S 40 10 8 W 4396.13 4464,73 S 40 44 56 W 4530,05 S 41 3 42 ,'~' 4595.07 S 41 22 47 W 4659,79 S 41 42 10 W 4723.03 S 42 2 55 4786,41 S 42 24 33 w DOG LEG SEVERITY DEC/1OOFT 1,099 0.594 1.205 1.189 1.335 0.924 2,937 1.099 0.594 0.500 0.250 0,594 0,250 0,739 0 · 132 0,594 2,180 0.723 1,445 0,250 i,073 0,722 1.250 1,556 0,695 0.701 0.695 1.929 1.583 SiCTIGN mlSTANCL Z7~4.83 2663.10 2941.81 3015.53 3069.40 3236.67 3~09.89 3383.14 3~56,2Z 3602.34 ~o75.51 3~21.96 3967.23 4038.71 4i09.79 4~51.5i 4321,67 4390.94 4525.14 4591.20 4~56.87 4720.~ 4785.14 ~,P,C 0 KlJP A!.-~LJK GYROSCOPIC SURVEY JOB NO 9 JA~ U1 RECORD OF SURVEY 4EASo DRIFT )EPTH ANGLE D 8300 45 15 8400 46 0 8500 46 0 85~/46 0 ~OTTOM HOLE TRUE VERT I CAL DEPTH 6354.81 6a24.74 6494.21 6553.25 CLOSURE SUB SEA 6256,81 6326.74 6396.21 6455.25 5037.60 DRIFT DIREC DEG, TOTAL COORDINATES S66.00W 3562.35 S 3293.19 568.00W 3590.27 S 3358.98 S68.00W 3617.22 S 3425.67 S68.00w 3640.12 S 3482,37 FEET AT S 43 43 52 W C L 0 S U R F. $ D I STANCE ANGLE D M 4851.33 S 42 45 5 w 4916°59 S 43 5 57 W 4981.92 S 43 26 31W 5037.60 S 43 43 52 W DOG LEG SEVERITY DEG/IOOFT 0.710 1.278 O.O00 O.OOO SECTION ~ISTANC~ 4650.62 4916.28 4W81.86 5:037.60 kRCO KUPARUK B-1 ~NTFRPOLAT[! TRUE .'ODE ?E A SI, JR E D ,lAME D'-':'P TH GYROSCOPIC SURVEY JOB NO 4435 VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE VERTICAL TOTAL COORDINATES C L O $ U R E DEPTH D [STANCE ANGLE D M 9 JAN SUb SEA r KUPARUK PO90 r UP SA,ND e~lOg B UP SA;,~,h 8 151 F LOW S/~,ND 8320 ~ LOW SAND ~404 )LUG BACK 9~52 3 KUPARUK ~ 4"/6 rD ~585 5205,86 3504,59 S 3156,90 W 4716,80. S 42 0 43 6219,58 3509,55 S 3169,08 W 4728,64 S 42 4 54 6249,69 3520,66 S 3196.17 W 4755,06 S 42 14 3 6368,87 3568,09 S 3300.20 W 4864.38 S 42 49 5 6427,52 3591,35 S 3361,65 W 4919,20 $ 43 6 28 6460.86 3604°29 S 3393,66 W 4950,54 S 43 16 33 . 6477,54 3610,75 S 3409,67 W 496~,22 $ 43 21 33 6553,25 3640,12 S 3482,37 W 5037,60 S ~3 43 52 6107,86 6121,58 6151.69 6270,87 6329,52 6362.86 6379,54 6455,25 k~CO KUPA~I. JK 4EA$ORgD D,L'PTH MEASURrm DEP TH B-1 AND OTHER TRUE VERTICAL DE P TH DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4435 FEET OF SUB SEA SUB MD-TVD VERT I CAL SEA DIFFERENCE CORRECTION TOTAL DEPTH. COORDINATES JAN 1o,8 408 59,8 6q9 800 1P, 03 1105 1209 1316 1425 1533. 1649 1775 190 q 2042 21.~1 2322 2457 2586 2723 2863 3000 3!30 3248 3366 3496 3630 3765 3901 4038 4177 4316 198. 298. 398. 49P. 59a, 698. 798, 898, 99R, 1098. 1198, 129B, 1~8. la98. 1598. 1698. 1798, 1898, 1998, 2098, 2198. 2298. 2398. 2498. 2598. 269~. 2798. 2898. 2998, 3098. 3198. 3298. 3398. 3498. 3598, 100 0 200 0 300 0 400 0 500 0 600 0 700 1 800 3 9O0 4 1000 7 1100 11 1200 17 1~00 27 1400' 35' 1500 51 1600 76 1700 110 1800 143 1900 183 2000 224 2100 259 2200 288 2300 324 2400 365 2500 402 2600 432 2700 449 2800 468 2900 498 3000 532 3100 567 3200 603' 3300 640 3400 679 '3500 717 0 0 0 0 0 0 1 2 1 3 4 6 10 8 16 25 34 33 40 41 35 29 36 41 37 30 17 19 30 35 36 37 39 38 0.00 0.00 0.00 0.59 2.81 10.63 22.78 36.86 53.18 72.34 96.29 125.97 162,25 195,99 243,05 301,99 371,36 442,40 528,78 618,12 697,92 767,96 847.41 930,00 1008.57 1078.48 1131.97 118~.78 1252.56 1323.59 1395.28 1467.93 1542.42 1618.36 1693.62 0.00 0.00 0,00 1.21 5.05 11.20 18.23 26.86 36,63 48,46 64,62 84.20 109,62 134.14 168.92 216.84 270.31 323,61 368.54 411.29 455.28 496.68 544.39 598.03 648,46 693.08 725.85 759,47 807.92 861.50 917.15 973.91 1030.88 1089,92 1149.74 ~,RCO KUPARUK B..-1 4EASOREr) DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB FEET OF NO SUB 4435 SEA DEPTH. J AN 81 t,..~E ASUR E D DEPTH TRUE VERTICAL DEPTH SUB SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 445 459 474 4.88 502 517 531 546 5,61 576 590 605 623 635 664. 679 603 70 ~ 722 737 751 7,66 7eO 807 821 836 7 2 4 9 3 5 3 1 9 7 4 O. 7 4 1 9 4 0 0 0 9 1 5 69 79 9q 09 19 29 39 49 59 59 79 89 99 09 19 29 39 49 59 69 79 89 99 C9 19 29 39 49 8. 8. 8. 8. 8. 8. 8. 8. 8. fl, 8, 8, 8. 8. 8, 8. 8. 8. 8. 8, 8, 8. 8, 6O0 700 800 900 000 100 200 300 400 500 6O0 700 800 900 ' O00 100 200 300 400 500 600 700 800 900 000 100 200 300 400 758 800 844 886 931 975 1020 1067 1115 1163 1211 1259 1306 1352 1399 1446 1493 1540 1586 1630 1676 1720 1762 1802 1842 1281 1921 1963 2007 41 42 44 42 45 44 45 47 48 48 48 47 46 47 47 47 47 46 44 44 42 40 4.0 39 40 42 44 1769,95 S 1847.13 S 1926,55 S 2002,64 S 2C82,81 S 2161.60 S 2241.96 S 2320.89 S 2400.77 S 2480.84 $ 2560,19 S 2636.05 S 2711.51S 2755,68 S 2860.00 S 2933.37 S 3005.42 S 3074.96 S 3138.56 S 3199.95 S 3259.63 S 3315.64 S 3368.50 S 3415.67 S 3460.53 S 3501,66 S 5539,32 S 3579.01S 3618.57 S 1213,48 1278.81 1343.55 1410,04 1477,43 1545,05 1613.74 1685.82 1760,01 1834.06 1909 · 38 1987.01 2063 · 78 2140,59 2218.41 2297.28 2377.79 2460,06 2545.16 2629,96 2716,40 2804,08 2389.92 2975,66 3062.58 3149,88 3240,47 3533.11 3429.01 ~RCO KUPA,RLJ~ r~-i_~ [NTERPOLATED VALUES FOR EVEN T IR U E ,"4EASUR ED VE :.RTI (:AL DEP TH '.'-)E P TH 1000 995. 8 Z000 1867. 17 3000 2598. 25 a00O 33'70. 32 5000 40'77. 39 6000 4759. 46 7009 5440. 53 ~OOO 6141o 60 GYROSCOPIC SURVEY JOB NO 1000 FEET OF MEASURED DEPTH. SI, JLR SEA TOTAL COORD I NATES 97° 52.70 S 36.37 69. 419.59 S 307.36 00. 1008.62 S 648.49 72. 1521.62 S 1015.1.0 79. 2066.V5 S 1463.8,9 61. 2607.28 S 1956.77 42. 3102.36 S 2496.10 43. 3479.02 S 310d.00 4435 ,JAN 81 HORIZONTAL VIEW ARCO OIL 8~ GAS KUPARUK El- I RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"" I000' JAN. 12, 1981 TII N, R I0 E, U. M. -4 '~ 9 '~' 982' 1200 1600 4800 .... 5600 6.0 O0 6400 " - TVD = 655 TMD = 8585' -' · , 2000 2400 . . 2800 ..... 5200 *3600 4000· 4400 ALL DEFrI'HS SHOWN ARE TVD ' - -: '. -. 8OO SURFACE LOCATION ~S 496'SNL,982 WEL, SEC. 9 TIIN, RIOE, U.M. VERTICAL SECTION ARCO OIL (~ GAS KUPARUK B- I RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"-' I000' JAN. 12, 1981 24~ 2.8( $20C I ARE TVD ALL DEPTHS SHOWN 4400 4800 · . ........................................................................................... ~ ........................................ '.. so oo 640~ T VD = 6553' TMD = 8585' COMPLETION REPORT ARCO OIL & GAS OYRO$COP IC SURVEY RADIUS OF CURVATURE COMPUTED FOR SDC BY >lEAS. DRIFT DEPTH ANGLE D M 0 0 0 100 0 0 2 O0 0 0 300 0 0 400 0 0 500 2 0 600 4 0 700 7 30 800 8 3O 90O 10 15 1000 11 15 1100 14 0 1200 17 45 13(i)0 20 30 1400 25 45 1500 20 45 16()0 32 0 1700 36 45 1800 41 0 1900 41 45 2000 41 0 2100 45 0 2200 45 0 23'00 44 15 2400 42 30 TRUE VERTICAL DEPTH METHL.)D OF COMPUTATION FM L INDSEY & ASSOC RgCORo OF SURVEY 2 APRIL 82 KUPANUK KB ELEV 90, JOD NO 44~5 SUB DRIFT SbA DIREC DEC, 0.00 -90.00 N 0,00[ 100,00 10.00 N O.OOE 200.00 110.00 N O.OOE 300.00 210.00 N O.OOE 400.00 310,00 N O,OOE 499.97 409.97 SSO.OOW 599.83 509.83 S46.00W 699.31 609.31 S30.OOW 798.34 708,34 $30,00W 897.00 807.00 SS3.OOW 995.24 905.24 S29,00W 1092.82 1002.82 S34.00W 1188.99 1098.99 S34.00W 128~,46 1193.46 S33.00W 1375.39 1285,39 1467.24 1377.24 S36,00W 1556e69 1466,69 $36.00W 1639,20 1549.20 S40.OOW 1717.03 1627.03 538.00W 1792,07 1702.07 $37.00w 1867,11 1777.11 S~8,00W 1940.23 1850.23 $26,00W 2010,94 1920.94 S26,00W 2082.11 1992.11 S25.00W 2154,80 2064.80 S30,OOW TOTAL COORDINATES 36.71 S 26,76 W 52,70 S 36,37 W 71,33 5 47.78 W 94.00 S 63.08 W 121,~2 S 81,16 W 153.67 S 103.39 W 185.60 $ 12~,59 W 221.48 5 152.66 W 265.95 S 187.40 W 314.71 S 226,89 W 367~15 S 267,12 W 419.59 S ~07,36 W 477.31 $ 343.43 W 540.86 S 374,43 W 604.26 S 404,67 W 665e16 S 436e37 W C L 0 S U R E ,5 DI STANCE ANGLE D M ,5 0.00 S 0 0 u w 0.00 S 0 0 0 w 0.00 S 0 0 0 W 0,00 S 0 0 0 w 0.00 ,5 0 0 0 W le39 I'Xi64 59 59 W 5.91 S 60 31 29 W 15,61 ,5 46 20 49 W 64,03 S 34 36 ~7 w 85,86 5 33 49 9 W 113,20 S ~ Pl 46 W 145,96 $ 33 46 53 W 1.85,22 S 33 56 i w 2~4.66 5 34 17 ~7 W 268e99 S 34 34 38 W 325.~ S 35 10 1~ W 387.97 S 35 47 ~2 w 454.0, S 36 2 18 W 520.12 S 36 13 27 W 65/,82 S 34 41 39 W 727.25 S 33 48 Jb W DOG LE~ SEVENITY DEG/IOOP'T O,O00 O'OOO O,oOU 2.006 2,000 3.511 1.OOO 1,755 1.012 ~.766 5,ZSO 5,000 11.250 4.961 4,33~ 0,~71 7,211 0.000 0,89' 2,876 ,SECTIUN U.O0 O,UO 0,44 5.66 lP.60 29.1i 143.77 162.52 ~Z1.72 .49.96 049. Om ~tb.37 '/82.Z9 ARCO KUPARUK B-1 GYROSCOPIC SURVEY JOB APRIL 62 RECORD OF SURVEY ,'lEAS. DRIFT DEPTH ANGLE D M 2500 38 0 2600 41 15 2700 44 0 2800 44 45 2900 44 45 3000 40 0 3100 40 0 3200 30 0 3300 30 15 3400 40 0 350 tJ 41 0 3600 42 0 3700 42 15 3800 42 30 3900 43 0 4000 43 15 4].00 44 0 4200 43 30 4.30:) 44 15 4400 45 0 4500 45 15 4600 45 30 4700 4,6 0 4.800 45 0 4900 46 0 5':)0(.) 46 30 5100 46 0 5200 46 15 53'00 46 45 TRUE VERTICAL DEPTH 2231,10 2308,12 2381,69 2453,17 2524,18 2598,04 2674,64 2756,45 2842.95 2924,64 3000,68 3075.57 3149,74 3223,62 3297.05 3370.03 3442.42 3514.06 3586.'14 3657.91 3728.47 3798.'72 3868,49 3938.58 4008,67 4.077.83 l+146,98 4216,29 4235,12 SUB SEA 2141,10 2218,12 2291,69 2363e17 2434,18 2508,04 2584.64 2666,45 2752.95 2834.64 2910.68 2985.5? 3059,74 3133.62 3207.05 3280.03 3352.42 3424,66 3496e'14 3567,91 3638,47 3708,72 3778,49 3848,58 3918,67 3987,83 4056.98 4126,29 4195.12 DRIFT DIREC DEG. S30.OOW $32.00w $30.00w 534,00W S33o00W 532,00W 533.00W S31,OOW 532.00W 535.00W $37.00W S37,00W S38.00W 538,00W $38,00W 537.00W S38.00W S38,00W S39.00W S40.OOW S41,OOW S39.00W 539.00W 542,00W S40,OOW S40,OOW S41,OOv, S40,OOW S41.OOW TOTAL COORDINATES C L 0 S U DISTANCE 721 775 833 893 '951 1008 1062 1111 1154 1202 1254 1307 1360 1413 1467 1521 1576 1630 1685 1739 1793 1847 1903 1957 2011 2066 2121 217~ 22~1 · 10 S 468,67 W 860.02 S 3 .76 S 501,51 W 923,75 S 3 · 79 S 536,38 W 991,42 S 3 ,09 S 573.43 W 1061,34 S 3 · 80 S 612,29 W 1131,73 S 3 ,62 3 648,49 W 1199,11 ~ 3 · 83 S 683.03 W 1263.39 S 3 · 62 S 1015,10 W ,36 $ 1057,10 W · 85 S 1099,67 W · 09 S 1142,82 W · 29 S 1187.50 W · 18 S 1~33.52 W · 70 $' 1279.27 W .3b S 1324.35 W · 59 S 1370.66 W · 42 S 1417,45 W · 75 S 1463,89 W · 68 S 1510.80 W ,50 S 1557,61 W .65 S 1604.72 W 1829,14 $ 33 1897,99 S 33 1966,97 S 33 2030,07 S 34 Z!06,02 S 34 2176,48 S 34 2247.34 S 34 2318,77 $ 34 2389.75 ~ 34 2460,69 $ 35 2532.68 $ 35 2604,62 ~ 35 2676,43 S 35 2748,71 ~ 35 E S NG LE M DOG L~G SEV~RII'Y DEG/iOOFT 2,914 2,120 O. 104 4,76~ 10-012 0.356 9.~28 1,319 1,000 u.~ 17 0,250 0,500 0.532 0,892 0,500 0.894 0,901 0,563 1,048 0.500 1.803 1,439 0.500 0.720 0,579 0,729 OlOTANCE 84 ~ 901 · ~4 973 · 28 111i,0~ 1177,11 lZ40.16 iZ96,24 1~01.84 t598.~7 1~69,81 1936,6Z 2007.64 2077 · 09 214.8,44 2219.46 2290,84 2362,05 2433.29 2505,37 2577.49 2649.46 Z721,88 ARCO KUPARUK B-1 GYROSCOPIC SURVEY JOB NO 4435 APRIL 82 RECORD OF ,SURVEY ?4FAS. DR!FT i)EPTH AS!C-,L E D N 54O0 47 0 550O 47 15 5600 47 45 57OO q7 15 58OO 48 0 5900 ~7 15 ~oor) 47 15 619o ~7 0 6200 47 15 6300 46 45 6400 47 0 650O ~7 15 6600 07 0 6700 47 30 6800 47 0 ~900 ~7 15 7O0O 46 45 7100 46 15 72 O0 ~6 15 7300 ~6 30 74OO 46 15 7500 4~ 15 7600 45 0 7700 ~4 30 800 {) g 4 0 S2oo 05 15 TRUE VERT I CAL D E P T Pt 4353,48 4421,52 4489,08 4556.64 4624.04 4691.43 4759 · 31 4827.35 4895,39 4963.59 5031.95 5099.99 5168.03 5235.91 5303.79 5371,93 5440. (13 5508 · 87 5578.02 5647,01 5716.00 5785.16 5fi55.09 5926.11 5997,74 6069,37 6141 · 6213,08 6284.41 SUB SEA 4263.48 4331,52 4399.08 4466.64 4534.04 4601 4669.31 4737.35 4805.39 4872~. 59 4941e95 5009,99 5078.03 5145.91 5213.79 5281,83 5350.03 5418 · 87 5488.02 5557.01 5626-00 5695,16 5765.09 5836,11 5907.74 5979.37 6051 6123.08 6194.41 DR IFT DIREC DEG, S43 · OOW $42.00W $44.00W S42.00W $44.00W S43. OOW 547.00W 545.00W $46.00W 546.00W S46 · OOW $47,00W S47 · 0 OW S48.00W S49.00W S50,OOW $54.00W S53.00W $55,00W 555.00W S57.00W 558.00W S58.00W S61.00W $62,00W S63.00W S64.00W S68 · OOW 56 7 · OOW TOTAL COORDINATES C L 0 S U R E 5 DISTANCE ANGLE D M DOG LEG SEVERITY DEC/iOOFT 2285 2339 2393 2447 2501 2555 2607 2658 2709 2760 281Z 2861 2911 2961 3009 3057 3102 3145 ~187 3229 3269 3308 3346 3382 3415 3447 ~479 3507 3~34 · 89 S 1653.56 W 2821.27 S 35 52 · 92 S 1703,07 W 2894.07 S 36 2 .84 S 1753,35 W 2967.27 S 36 13 · 76 S 1803.62 W 3040.49 S 36 · 78 S 1854,00 W 3113.88 S 36 32 .37 S 1904.86 W 3187.22 S 36 42 · 28 6 1956.77 W 3259,89 S 36 53 · ~9 S 2009.48 W 3332,26 S 37 5 .~5 S 2061.75 W 3404.78 $ 37 16 .~5 $ 2114.36 W 3477,08 S 37 27 .75 S 2382.75 W 3838,76 S 38 22 · 34 S 2438.48 W 3910.69 S 38 34 · ~6 S ~496,10 W 3981,85 S 38 49 ~1 W 53 W 14 W 4 W 28 W 7 W 17 W 16 W 5 W 4 W 34 W 18 W 12 W 17 W 4 W 30 W 10 W .50 S 2554,41W 4052.06 S 39 4 45 W · 96 S 2612.84 W 4121.90 S 39 20 16 W · 48 S 2672.14 W 4191.64 S 39 36 18 W · 96 S 2732,15 W 4261,13 S 39 52 47 W ,77 S 2793,07 W 4330.04 S 40 10 8 W · 64 S 2853,69 W 4398.13 S 40 27 15 W .~7 S 2914.~4 W 44:64,73 S 40 ~4 56 W · 67 S 2975.66 W 4530,05 $ 41 3 42 W · 89 S 3037.55 W 4595.07 S 41 22 47 W · 02 S 3100.00 W 4659.79 $ 41 42 10 W · 21 $ 3163.31 W 4723.03 S 42 2 55 W · 03 S 3228.06 W 4786,41 $ 42 24 ~3 W 1,099 0.594 1.205 1,189 1'335 0,924 2.937 1,099 0.594 0.500 0.250 0.594 0,250 0.739 0,732 0.594 2,180 0.723 1,445 0.250 '1,073 0,722 1.250 1,556 0.695 0,701 0.69~ 1.929 1.583 SECTION DISTANCE 2794,83 2868,10 29~1,81 3015.53 3089.40 3163.27 3236,67 3309,89 3383.14 3456.22 3529,15 3602,34 3675.51 3148.78 3821,9b 3894,87 3967.23 4038,71 4109.79 4180.78 4251,51 4321,67 4390.94 ~458.69 4525.14 4591.20 4656.87 4720,99 4785,14 ,'iPC O KUPARUK I~-1 ,~YROSCOP!C SURVEY JOB NO 4435 2 APRIL ~2 RECORD OF SURVEY TRUE :EAS. DRIFT VERTICAL DEPTH AI'-,~GLE DEPIH I) 51 SUB DR IFT SEA DIREC DEG. TOTAL COORDINATE5 830(} 45 15 6354.81 5264.81 S66.00W 3562.3~ S 3293.19 8400 ~5 () 642a.74 ~334.74 S68.00W 3590.27 S 3358.98 ~500 46 0 6a94..21 6404.21 568.00W 3617.22 S 3425.67 8585 46 0 6553.25 6463.25 S68.00W 3640.12 S 3482.37 7,0TTO[,! HOLF CLOSURE 5037.60 FEET AT $ 43 43 52 W CLOSURES DI STANCE ANGLE D M S 4851.33 S 42 45 5 W 4916.59 S 43 5 37 W 4981.92 S ~3 26 31W 5037.60 S 43 43 52 W [)OG LEG SEVERITY DEG/iOOFT 0.710 1.278 0.000 0.000 SECTIOi~ DISTANCE 4850.62 4916.28 4981.86 5037.60 ~RCO KI, JPAR',.IK. B-1 GYROSCOPIC SURVEY JOE3 i",i0 4/-+35 2 APRIL I?,ITEP, POLATEt~ TR(JE VERTICAL. DEPTHS, CO(3RDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE ~ 0['; E :"4E ASUR E D VERTICAL -..i A r,.,,, E D E P T H D E P T H TOTAL COORD I NATES CLOSURE DISTANCE ANGLE D M S SUB ,SEA T KUPARdK 809(',) 62C)5.86 F UP SAND 8109 6219.58 ~, UP SAND B151 6249.69 T LOW SAND 8320 6368.8'7 3 LOW SAND 8404 6427.52 ~ LI. JG BACK 8452 6460.86 :'~ KttPARUK 8476 6477.54 TD 8585 6553,25 3504,59 S 3509,55 S 3520,66 S B568,09 S 3591,35 S 3604,29 S 3610.75 S 3640,12 S 3156,90 W 3169,08 W 3196,17'W 3306.20 W 33611,65 W 3393.66 W 3409,67 W 3482,37 W 4716.80 S 42 0 43 W 6115.86 4728,64 S 42 4 54 W 6129,58 4755,06 S 42 14 3 W 6159,69 486~e38 $ 42 49 5 W 6278,87 4919,20 S 43 6 28 W 6337,52 4950,54 S 43 16 33 W 6370,86 4966.22 S 43 21 33 W 6387,'54 5037e60 S 43 43 52 W 6463.25 ARCO KUPARUK t3-1 ~v-:EASURED DEPTH AND OTHER DATA GYRO$COP I C FOR EVERY SURVEY EVEN 100 JOB NO 4435 FEET OF SUB SEA DEPTH. APR I L 82 MEASURE D [)EP TH TRUE VEF',T ICAL SUB DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 190 290 390 490 590 691 792 893 995 1097 1201 ].307 1416 1525 1640 1755 1897 2031 2170 2Bll 2447 2576 2711 2~52 2989 3120 3239 3356 3486 3754 3890 4027 4166 4304 190, 100 290, 200 390. 300 490. 400 590, 500 690, 600 790, 700 890. 800 990. 900 1090, 1000 1190. 1100 1290. 1200 1390, 1300 1490, 1400 1590, 1500 1690. 1600 1790. 1700 1890, 1800 1990. 1900 2090, 2000 2190, 2100 2290, 2200 2390, 2300 2490, 2400 2590, 2500 2690, 2600 2790, 2700 2890, 2800 2990. 2900 3090. 3000 3190, 3100 3290. 3200 3390. 3300 3490. 3400 2590, 3500 0 0 0 0 0 0 1 2 4 7 11 16 26 34 49 74 107 140 180 221 257 286 321 362 399 430 448 466 495 529 564 60O 637 676 714 40 521, 41 611, 36 692, '29 762 · 35 840. 41 923, 37 1002. 31 1073, 18 1128. 18 1].79. 29 1247. 34 1317, 35 1389. 36 1462. 37 1536, 39 1612. 38 1687, O0 S 0,00 O0 S 0,00 O0 S 0,00 61N 1.00 44 S 4,65 77 S 10.65 75 S 17.63 66 S 26,08 79 $ 35.86 73 $ 47.38 25 S 63,25 39 S 82.51 27 S 107.46 23 S 132e13 90 $ 165.69 99 S 212.85 56 S 265,92 22 S 319.50 79 $ 365.13 18 S 407.93 08 S 451,91 41 S 493,26 40 S 540.23 45 S 593,71 59 S 644,72 29 S 689.77 O1 S 723,43 91 S 756,21 25 S 803e94 72 S 857.04 44 S 912.58 02 S 969.29 40 S 1026,29 35 S 1085e22 26 $ 1144,58 W W W E W W W W W W W W W W W W w W W W W W W W W W W W W W W W W W W ~RCO K[JPARUK B-1 ~EASURED DEPTH AND OTHER DATA GYRO$COP!C SURVEY FOR EVERY EVEN 100 JOb NO 4435 FEET OF SUB SEA DEPTH. APRIL 82 TRUE MEASURED VERTICAL DEPTH DEPTH SUB SEA MD-TVD DIFFERENCE VE RTI CAL CORRECT !ON TOTAL COORDINATES 4445 3690. 4587 3790. 4731 3R90, 4873 3990, 5017 4090, 5162 4190. 5307 4290, 5453 4390. 5601 4490, 5749 4590. 5898 4690, 6045 4790. 6192 4890. 6485 5090. 6632 5190, 6780 5290. 6926 5390, 7072 5490. 7217 5590, 7362 5690, 7507 5790. 7649 5890. 7789 5990. 7929 6090, 8068 6190, 8208 6290, 5350 6390, 8494 6490. 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 54O0 5500 5600 57OO 5800 5900 6000 6100 6200 6300 6400 755 797 841 883 927 972 1017 1063 1111 1159 1208 1255 1302 1348 1395 1442 1490 1536 1582 1627 1672 1717 1759 1799 1839 1878 1918 1960 2004 41 1763 42 1840 44 1920 42 1996 44 2076 45 2155 45 2235 46 2314 48 2394 48 2474 4 7 2 7 o 5 46 3069 46 3133 45 3195 45 3254 45 3311 42 3364 40 3412 40 3457 39 3498 40 3536 42 3576 44 3615 · 61 S · 51 S ,46 .64 S ,18 .54 ,50 ,39 S · 37 5 · 37 S · 23 $ e99 S ~47 S · 60 S .98 .41 S · 00 S ,46 S ,36 S · 01 S .84 S · 44 S ,59 · 07 S · 02 S · 69 $ · 23 S · 55 S · 59 S 1208,07 W 1273,41 W 1338.42 W 1404,92 W 1471,82 W 1539,91 W 1608.07 W 1679,89 W 1753.86 W 1828,00 W 1903.79 W 1980.74 W 2057.53 W 2134.29 W 2211.98 W 2290.80 W 2371.58 W 2453.20 W 2538.20 W 2622.91.W 2709.21 W 2797,35 W 2883,24 W 2968.91 W 3055.59 W 3142,88 W 3233.25 W 3325,~6 W 3421,63 W ,RCO KUPARUK B-1 GYROSCOPIC SURVEY JOB NO 4435 2 APRIL 82 NTERPOLATFD' VALUES FOR [VEN 1000 FEET OF: MEASURED DEPTH, TRUE MEASURED VERT ! CAL .SUB F_)EP TH DEPTH SEA TOTAL COORDINATES IOO0 995, 2000 1367, 3000 2598, 4000 3370, 5000 4077, 6000 4759, 7000 5440, 8000 6141e 905, 52,70 $ 36,37 W 1777, 419.59 S 307,36 W 2508, 1008,62 S 648,49 W 3280, 1521,62 S 1015,10 W 3987, 2066,75 S 1463,89 W 4669, 2607,28 S 1956,77 W 5350, 3102,36 S 2496,10 W 6051, 3479,02 S 3100,00 W HORIZONTAL VIEW ARCO ALASKA INC. KUPARUK WELL B-I RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE : I" = I000' APRIL 2 t 1982 TVD = 6555' TMD = 8585' 4 9 982' ALLARE DEPTTvDHS SHOWN SURFACE LOCATION IS 496' SNL, 982' WEL, SEC. 9 TIIN, R I-OE, U.M. 4OO 8OO VERTICAL SECTION ARCO ALASKA INC. KUPARUK WELL B-I RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE: i" -'- I000' APRIL 2t 19S2: 1200 600 2000 2.400 28OO _. 3200 3600 IALL DEPTHS SHOWN ARE TVD 40OO 4400 48OO °yoo %6400 TV~D = 6555' TMD = 8585' Check Form for timely compliance with our regulations. Operator, Wel 1 Nam~ and Number Reports and Materials to be received by: /--/~' Date Completion Report Well History Samples Required Yes Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data ...... Yes Yes Date Received Remarks NORTH SLOPE ENG~ Date: F~ Transmitted herewith are the following: Please note: BL- Blueline, S - Sepia, From: J. J. Pawelek / Leo Lash F - Film, T - Tape RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash/ AFA-311 P. O. Box 360 Anchorage, AK 99510 FEB 1 3 1981 Alaslm 0il & Gas Cons. r~ommission A~chomge NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL -Transmitted herewith are the following for the subject well' DATE SCALE XEROX BL SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensai~ed Neutron Log Core Analysis - Interval Core No. Core Description (SWC)- Interval Core Description (Conv.) Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log ! / / i .RECEIPT ACKNOWLEDGED FOR' DATE: P~~LEA'SE RETURN RECEIPT TO' Anchorage ARCo 0i] ~nd G~s Compan~ A~n: ~. Leo Lash P.0. Box 360- Rm. ~3~-FAB Ancho~9e, AK 99510 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Jerry J. Pawelek/Leo Lash WELL NAME-' /~/~/~0_/AX ~ Transmitted herewith are the following for the subject well' .. DATE SCALE XEROX II/~1-1~/~ BHC Sonic/Gamma Ray Log t~' Cement Bond Log/VDL II~l-I~/15 Compensated Formation Density Log I~/~.l-I~.Jl& Compensated Neutron-Formation Density ~'~/~" Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC)- Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log' Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-~Oxygen Log RECE-[ PT ACKNOWLEDGED DATE- SE RETURN RECEIPT TO- ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 BL SEPIA LINE I?t FILM I BY' _"--~ T. ·. - ~ ARCO Oil and Ca( ~)mpany -Alaska Region Post ,Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 .. December 29, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas ConServation Commi ssi on 3001 Porcupine Drive Anchorage, Al.aska 99501 Subject: Kuparuk B-1 Dear Sir: Enclosed Please find the revision of the monthly report of drilling for Kuparuk B-1 as requested. Sincerely yours, P. A. VanDusen District Drilling Engineer PAV/DEB :ruo Enclosures ECEIVED Alaska Oil & Ga= Cons. Commission Anchorage ARCO Oil and Gas Company is a 3ivision of AtlanticRichfieldCompany Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS- 1o 2. NAME OF OPERATOR Atlantic Richfield Company - 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL 496' FNL, 982' FEL, Sec 9, T11N, RIOE, UM $. APl NUMERICAL CODE 50-029-20465 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648 7. IF I,NDIAN-ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. 13-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Kuparuk River I1. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 4, T11N, RIOE, UM 12. PERMIT NO. 80-40 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spud @ 1900 Hrs. 11/15/80. Drld 13 3/4" Hole to 3200' '.,run DK/SP/BHCS/GR, FDC/CNL/GR, BGT, RFT. Run 77 jts 10 3/4" 45.5# K55 BTC CSG w/shoe @ 3177'. CMT w/1300 sx fondu & 1700 sx AS,::,II, bumped plug. Floats held. ND diverter & NU 13 5/8 psi stack & Test to 3000 psi. Ok. Test Annular to 1800 psi. Ok. Drilled shoe & 10' new hole test formation to 12.5 ppg emw. Drill 8 3/4" hole to 3999. Psh to run RFT logs in injection interval. Well began flowing @ 0800, 11/27/80. Closed well in w/SIP @ 225 psi. Ab- andoned logging effort. Pump in 150 BBLS 12.5 mud in stages @ slow rate & monitored well. Well dead @ 1830 11/27/80. TIH w/new bit & BHA. Circ & Cond hole prior to drilling ahead as of 12/1/80. , ECEIYE ~aska 0il & Gas Cox.:. ,; Anchorages. ~ 14. I hereby c~[/~j~he for~ing is t~) and correct SIGNED .~ ~- 7rL/~.'~~l~[~_~' TITLE District Drlg Engineer DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. ARCO Oil and Ga~c)mpany North Slop~ strict Post Office Box 360 Aqchorage, Alaska 99510 Telephone 907 277 5637 December 16, 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 17-5 DS 17-6 DS 16-10 DS 2-17 DS 11-14 DS 1 5-21 DS 15-10 DS 14-10 DS 16-11 DS 2-9 DS 2-2 DS 6-15 DS 6-9 DS 6-10 DS 6-11 DS 6-12 DS 6-13 DS 6-14 DS 6-16 Ku Pa ru k ,z .. C-1 C 5 Dear Sir' Enclosed please 1. A Compl~t'ion Report, Drilling History and a Gyroscopic multi~Wbt survey for wells DS 17-5, DS 17-6, DS 16-10, DS 27~7, DS 11-14 & C-1. (An updated Completion Report w/GXfo will be submitted for DS 2-17 & DS 11-14 and. the ggfo for DS 17-5, as soon as data becomes available.) 2./:?A Sundry Notice or subsequent report for wells DS 2-2, ~./~ E-5, DS 6-9 thru DS 6-14 & DS 6-16. (An updated sub- /,/ sequent Sundry Notice will be filed for DS 6-9 thru DS /?' 6-14, DS 6-16 and E-5 as soon as production test data ,//' becomes available. ) // 3. A MonthlY Report of drilling for wells DS 15-21, DS 15- 10, DS 14-10, DS 16-11, DS 2-9, DS 6-15, B-I & C-2. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures RECEIVED DEC ~ 8 1:380 Alaska Oil & Ga,?,- Cons. Comrnissior~ Anchorage ARCO Oil and Gas Company is a Division o! AtlanticRich~'ielclCompany Form No. 10-404 REV. 3-1-70 STAT~ OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL 496' FNL, 982' FEL, Sec 9, TllN, RIOE, UM SUBMIT IN DUPLICATE,¢ 5. AP! NUMERICAL CODE 50-029-20465 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648"' 7.IF INDIAN~'~LOTTEE OR TRIBE NAME 8. UNI,'IrFARM OR LEASE NAME /~Kuparuk 25648 ~t). WELL NO. 13-1 -~: 10. FIELD AND POOL, OR WILDCAT / ~. ~rudhoe Bay Field/Kuparuk River Oi ., 11. SEC. T. R. M. (BOTTOM HOLE Po( ,' OBJECTIVE) ., ~?': Sec 4, TllN, RIOE, UM ," 12. PERMIT NO. '~ 80-40 13.REPORT TOTAL DEPTH AT END OF MONTH. CHANGES 1N HOLE SIZE, CASING AND CEMENTING SOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Spud @ 1900 hrs, 11/15/80. ~ 1~.~3/4" hole to 3093'. Run DIL/SP/BHCS/GR, FDC/ CNL/GR, BGT, RFT. Run 77 its 10-3/4" K-55 BTC cs-~shoe @ 3177'. Cmt w/1300 sx Fondu & 1700 sx AS II. Drl shoe.& lC' new hole. Tst form. POH for logs. Well started flowing, as of 12/1/80. DEC ~ 8 ~iaska 0il & ~a2 Cons, Cornrnissio~ Anchorage 14. ! hereby certifv~at theW~~~~ forego' g is tru d correct SIGNED ~C,~, TITLE District Drlg Engineer DATE'/~)~_C~"~-/a-~ Io. Iqla NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month.unless otherwise directed. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton Chairman Thru: Lonnie C. Smith / Commissioner Ben LeNorman Petroleum Inspector December 8, 1980 BOPE Test on ARCO'S Kuparuk B-1 Sec. 9, TllN, R10E, UM Kuparuk River Undefined. Friday Novembe~_21, 1980 - I departed my home at 7:45 am for an 8:15 am showup and 9:15 am departure via the Sohio charter for Deadhorse arriving at. 10:45 am. Weather: -8°F, light wind, clear skies. _s~tnrday. Nove~ber 2_2, !980 - Standing by on well N-10. _8~nday N0~m.~r~ 23, ~98-0 - BOPE tests on Sohio's N-10 began at 12:00 midnight . . . Monday November 24, 1980 - . . . and were completed at 3:00 am, It~e'~ S~eCt'~ 0~' a~ Sep~r'ate report' BOPE tests 'on Arco's Kuparuk B-1 began at 7:15 am but were suspended at 8:30 am due to a frozen kelly system. Tests re- sumed at 12:30 pm and were completed at 2:00 pm. BOPE Inspec- tion report is attached. ~Tuesday November 25, 1980- Witnessing of cleaning of strainers on S0hi0's mete~'~ ~t~ .... ~mp station %1 began at 8:30 am and was completed at 4:00 pm, the subject of a separate report. I departed Deadhorse via the Sohio charter at 7:00 pm arriving in Anchorage at 8:30 pm and at my home at 9:00 pm. In summary, I witnessed successful BOPE test on Arco's Kuparuk B-1. O&G #4 4/80 STATE OF ALASKAi %~ ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Z~ ~~. ~.~. ~ Operator , /~ ~ Well ~Z~ ~; ~,~_ ~-/ Location: Sec ~ Drilling Contractor Well/~/J ~.~ ~ A~f Representative Permit ;(9 Casing Set Rig # /~/ Representative Location, General Well Sign General Housekeeping Reserve pit . Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pres sure ~ ~ ~ psig Pressure After Closure /~-~'6)~D' psig 200 psig Above Precharge Attained: min~'~s Full Charge Pressure Attained: ~' min ~' s N2~/~~ /~W~ -~/~/ /~'O psig Controls: Master O/~_ Remote ~F3~ Blinds switCh cover.~_~ Kelly and Floor Safety Valves Upper Kelly. Test Pressure ~,~)~ Lower Kelly Test Pressure... ~u~ Ball Type Test Pressure ~O~DO Inside BOP (D/~. Test Pressure Choke Manifold., Test Pressure ~~ No. Valves ~ No. flanges Adjustable Chokes Hydrauically operated choke Test Time2~_~hrs. Repair or Replacement of failed equipment to be made within , days and Inspector/C~mmission office notified. · Distribution' ~ orig. - AC&GCC cc - Operator cc - Supervisor Inspector ARCO Oil and Gaff? ')mpany Alaska Disf,, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 1, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamil ton: Attached please find a Sundry Notice on our Kuparuk B-1 well (Permit #80-40) revising our production string setting depth. Lonnie Smith is familiar with the changes as per our discuSsion with him Wednesday, November 26, 1980. Please call if you need any further information and we will be glad to assist you. Sincerely, P. A. VanDusen District Drilling Engineer PAV:sp Attachment I ECEIVE ARCO Oil and Gas Company Form 10-403 Submit "Intentions" in Triplicate REV. Z-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20465 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648 ~. ,~ ,NO,AN. ALLOTTEE or TR,BE NAME WELLl~i WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 496' SNL, 982' WEL, Sec 9, TllN, RIOE, UM @ 6000'ss' 1320' NSL, 1320' EWL, Sec 9, TllN, RIOE, UH 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Tundra 63' +fftOP of pad 71' +_/ RKB 98' +__ 14. Check Appropriate Box To Indicate Nature of Notice. Re 8. UNIT, FARM OR LEASE NAME K.uparuk 25648 9. WELL NO. B-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay/Kuparuk River 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 9, TllN, RIOE, UM 12. PERMIT NO. 80-40 ~ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER S~UT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Initial planning on the Kuparuk B-1 well (permit #80-40) called for 7" 26# K55 BTC production casing set thru the Kuparuk Sands from suface to TD. As a result of the wellbores proximity to our CPF-1 well an increase in mud wt from 10.5 to 12.1 ppg was required to counteract unex- pected flows from the zone of injection. As a result it was felt the higher mud weight might damage or be lost to the Kuparuk production interval and result in reduced productivity or possible uncontrolled flow from the injection zone into the wellbore and subsequently downhole into the Kuparuk zone. We therefore have requested (and received.verbal permission as per L°nnie smith, 11/26/80) to alter the 7" casing depth from 8413 (below Kuparuk) to 7500= 340' +_MI above Kuparuk. This will preclude any damage or well control problems the weighted mud may have caused. A 6" hole will be drilled to the original TD : 8413 and 5" 15# FL4S liner run to TD with a 250' + overlap with the 7". As per the original permit, the well will be com- pleted w/3½" 9.2# J--55 Buttress tbg. Non-freezing fluids will be left in uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk for- mation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. R ECL I VED DEC- 3 1980 16. / I hereby cer_tif~that t.he fq~re~oing/t~ true an.d correct Alaska 0il & Gas Cons. Comrnissio. Anchorage (This space for State office use) APPROVED BY II CONDITIONS OF APPROVAL, If ANY: TITLE See Instructions On Rever~e Side DATE " a ~Form 10-401 ,. ',:,,REV. 9-1-78 I~' PLICATE SI~{~]I instrt~,:tions on ~ ~p,ers~ ~ .de) STATE OF ALASKA PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL E~ b. TYPE OF WELL WELL WELL. OTHER ~. NAME OF OPERATOR Atlantic Richfield Company DEEPEN r'-I SINGLE ZONE 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 ... 4. LOCATION OF WELL At surface 496'SNL, 982'WEL, Sec 9, TllN, RIOE, UM At proposed prod. zone 6000'ss, 1320' NSL, 1320'EWL, Sec 9, TllN, 5. 50~029-20465 6.LEASE DESIGNATION AND SERIAL NO. ADL 25648 7. IF INDIAN, ALLOTTEE OR TRIBE, NAME 8. UNIT FARM OR LEASE NAME Kupa. ruk 25648 9. WELL NO. 10. FIELD AND POOl=. OR WILDCAT Prudhoe Bay Kuparuk River R10E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs 30 miles northwest of Deadhorse 11. SEC., T., IL, M., (BOTTOM ' HOLE OBJECTIVE) . Sec 9, TllN, R10E, UM Po 14. BOND INFOI~MATION: Oi I & Ga s Bond r~E Statewides,,e,y,,d~orNo. #8011-38-40 IS. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTYOR LEASELINE. FT. Bottom hole 1867 (Also to nearest drig, unit. if any) "' 18. .. (Fed... Insurance Co. ) .... ~" A~o,,t~ ~:"$500,000 " 16. No. OF ACRES IN LEASE 17. NO ACRES ASSIGNED 5~0 ToT.,s WELL? . 2. ~.- .? "' "' .3'2.0 DISTANCE FROM PROPOSED LOCATION ,9. Pf40~OSE~H 20. ROTARY OR CABLE TOOLS To NEAREST WELL DRILL, NG.COMPLETED. Surf 480' OR APPLIED FOR. ~. Target 3700' PR/E8 } TVDx 6513 Rotary 21. ELEVATIONS (Sho~ whether DF, RT, CR, etc.) ~ ' 22. APPROX. DATE WORK ~LL START 63 Tundra/71 Top of Pad/98 RKB ~o' 11/15/80 23. P~ CEMENTING PROGRAM SIZE 0~' tlOLE SIZE OF CASING ~IGI~"PER FOOT ' ~, ~p~'DE SETrI'NG D'I~PTH ' , Q~antity of c'ement ' _ .... 2'4" 16-Fiq[0 " 65# ' ~._', "80 +'MD ~' Cmt to surf - approx 200 ft~ ' 13-3/4" 10-3/4" 45.5# ~'t{55BTC 3168'+ 'MD Cmt to surf - approx 3100 ft 8_3/4'~ 7" 2'6# . ~ K55BTC 8413 + HD Cmt w~apP, rox '2700'f't3 primary ~~' ~' " 93 ft~ s~condary ' ' ., '" , Arctic Pack from +2000' to_.. surf'. Atlantic Richfield Co. prop~ses'Nto drill a Purdhoe Bay Kuparuk River Oil Pool deveT~pment well to approximately + 8413 M_D :X~513 TVD. The surface hole will be logged & a shallow gas sand tested following lnstatl/[tion of 10-3/4" surf pipe as per attached procedure. 8-3/4 hole will be logged and tested,, bei~oL~running production csg. A 20" x 2000 psi annular diverter will be installed on the 16, co u~or (as per attached diagram) while drilling the surf hole. A 13-5/8" 5000 psi RS~ BOPE stack (diagram attached) will be installed on the surface pipe & will be tested u~ i~al'lation and weekly to 3000 psig. The well will be completed w/3~ 9.2~ J55 Buttres~ ~g. x Non-freezing fluids will be left in uncemented annul i thru the permafrost i~~el~cted intervals will be perforated within the Kuparuk formation and reported o~ubs~nt report. A downhole safety valve will be installed & tested upon con- cl us inn n~ Il mh ,$~o~ SPACE DESCRIBE PRO~SED PROGRAM: If propo:! is to deepen ~v. data on present productive zone and pro~sed ~ ~cal depths. Give blowout preventer pro.am. ~ ~. ~Y~..XZ.-~ 10-28-80 Dist. vr, g. ~ng. SIGNED /- - ~ - ~ ~ : .' - ' DATE ~TLE (This space for State office use) SAMPLES AND CORE CItIPS REQUIRED [] YES DIRECTIONAL SURVEY REQUIRED ~YES ~ No 8O-4O PERMIT NO. CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES ER NO OTtIER REQUIREMENTS: A.P.I. NUMERICAL CODE S0-029-20465 APPROVAL DATE ~ ..... .*.SRe. JJ1struction On Reverse Side BY ORD;R OF THE February 28, 1980 11-4-80 DATE November 3, 19,80 Mr. P. A, Van Dusen District Drilltnl~ Engineer ARCO Oi I and Gas Company P,O, Box 360 Anchorage, Alaska 99.$10 Res Kuparuk 25648 B-1 Atlantic RichfieldCompany Permit No. 80-40 Sur. L.oc.~ 496~SNL, 982*WEL, Sec. 9, TIlN, R10E, Bottomhole Loc.t 1320tNSL, 1320tEl~, Sec. 9, TilN, R10E, Dear Mr. Van Dusen~ Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated October 28, 1980 accompanying the original approved permit are in effect for this revision, Very truly yours, H, Ham~ll[t on Chat rman of . ~.__i]DF.~ OF. THE COM~IiS$~Qf~. Alaska Oil & Gas Conservation Enclosure cc$ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of~Laborl Supervisor, Labor Law Compliance Division w/o encl, B P Alaska Exploration ! nc. ~55 Calit'ornia S;,eet, San Francisco, Calilornia 94111. Telephone- (415) -t45-9211 · I~'TE~. HARDW~K October 8, 1980 ~Oil &~ ~~ny North Slop~ District P.O. Box 360 Anchorage, Al,~qka 99510. Attention: )tr. $. R. Jaime L~tter of Non-Obj~tion Oil '~nd C~ 'Le.~e ADL 25651 -. C~nt] amen' %Ve .~fer to your letter of 23 Soptc~3or 1980, ~n which you a.c%~ised us of your intent.ion to dr~]t the £o]]owing deve]o~'~nt %%~11s: tk~ t~n Hole · E'6 A-~ A-Z A-6 h,~L, 2GDO' ~{7~ ~ec, 16, T1LN R]OE, UM t320~ ~;~, 1320' ~L, SeC, 9, ~IN, R]~, lo~ Sb~I_,~-1320' ~%~, Sec. 6, ~.IN, R].~, ] ~.,20 ~ ' ~L, 1320' A%~, Sec. ~'-"~;'"~~, ]320 %~, ~eC. 5, Ti~, RIOE, ?L'.. ~ ??L. ]320' ~%L, Sec. P(7; ./.,[ ,~z~. ~.~o~'.. ~'..~ , .....~ affected Lessee of ~ord, hereby to ~h~i'ci.~e ~he ~up~ .f'~ ;..'-; ;~ervoir in a Eair ;~d c~uit~le ~er ado~t~ by tho ~~;~,~ nvolv~, 5amh thai said p~.ios ~y a~ the te~ of ~ch unit~ion ~d their ro~ctive rights ~d obligations therein, prior to the e&~nc~nt of ~y pr~ucution rr~ tho Yours very truly, · cc' Mr. G. Abrnh~m, Sohio, SF SOHIO ALASKA PETROLEUM COMPANY 100 PINE STREET, SAN FRANCISCO, CA 94111 October 17, 1980 ARCo Oil and Gas Company North Slope District P. O. Box 360 Anchorage, 'Alaska 99510 Attention: Mr. S. R. Jaime ~LAND ~DE ?r. OCT ~? 1980 ': NOltTI-I gLA. SKA. ii ARCo Oil and Gas Company, by letter of September 23, 1980, has requested a letter of non-objection by Sohio Alaska Petroleum to the drilling of the following development wells: Well No. Bottom Hole Location :E-6 A-1 A-2 A-3 A-6 A-7 500' NSL, 2640' EWL, Sec. 16, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 9, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 6, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 6, TllN, R10E, UM 1320' SNL, 1320' WEL, Sec. 5, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 8, TllN, R10E, UM 1320' NSL, 1320' EWL, Sec. 7, TllN, R10E, UM Please.be advised that Sohio Alaska Petroleum Company does not object to -the drilling of the proposed wells. For your information consent to E-6 was previously forwarded by Sohio to the Conservation Commission at the request of P. A. Van Dusen of your office. Sohio's concurrence to the drilling of the listed wells is with the understanding that ARCo, Sohio and other affected working interest owners will proceed in good faith toward an equitable unitization of the Kuparuk Reservoir and that such unitization is achieved prior to the commencement of production from the wells. GJA:c cc: P. Hardwick, BPAE P. Rumley, Anchorage Yours very truly, ARCO Oil and~"[ Company North Slope District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 31, 1980 Mr. Hoyle Hamilton State of A1 aska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Letters of Non-Objection Kuparuk 25648 B-1 Dear Sirs: Pursuant to the Alaska Oil and Gas Commissions April 1980 Regulations, section 20-AAC-22-050, we have requested and received letters of non-objection from the affected oper- ators for the bottom hole location at 1320' NSL, 1320' EWL, Sec 9, TllN, RIOE, U.M. This location is addressed as well No. B-3 on the attached copies of the subject letters, under .the assumption that the well would be drilled from the third conductor on the pads' first row. We haVe since reassigned this same well to the first conductor on the row, and have changed the well name to Kuparuk 25648 B-1. In addition we have permitted the well under this new name. For your ref- erence, we have attached a copy of our Application for Permit to Drill, which was previously sent to your office under seperate cover. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Attachments ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10~401 REV. 9-1-78 S~t~ FRIPLICATE ~ ,ructions on reverse side) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [-~ b. TYPE OF WELL WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company DEEPEN [--] SINGLE~ MULTIPLE I---I ZONE I~J ZONE I I 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 496'SNL, 982'WEL, Sec 9, TllN, RIOE, UM At proposed ~rod. zone 6000'ss, 1320' NSL, 1320'EWL, Sec 9, TllN, 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648 7.IF INDIAN, ALLOTTEE OR TRIBE NAME 8.UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. B-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oi SEC.. T.. 1L, M., (BOTTOM Po( il. HoLE OBJECTIVE) RIOE, UM Sec 9, TllN, RIOE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 30 miles northwest of Deadhorse 14. BOND INFORMATION: Oil & Gas Bond nE Statewides,re,yana/orNo. #8011-38-40 (Fed Insurance Co.) 15. DISTANCE FROM PROPOSED * I 16. No. OF ACRES IN LEASE LOCATION TO NEAREST ] PROPERTYOR LEASELINE, FT.Bottom hole 1867 2560 (Also to nearest dfig, unit. if any) 18. DISTANCE FROM PROPOSED LOCATION ~9. PROPOSED MD 8 13 TVD 6513 21. ELEVATIONS (Show wh,ther DF, RT, CR, e'¢.) 63 Tundra/71 Top of Pad/98 RKB TO NEAREST WELL DRILLING, COMPLETED, Surf 480 ' OR APPLIED FOR, FT. Ta'rget 3700' FR/E8 Amount $500,000 17. NOACRES ASS.{G~ED TO THIS WEE'il/,:. ,. 320 ,~0.;~ R~A/~Y OR CABLE TOOLS , ~:. ~,,,~ RD ta ry a. ~px. ~A~a WOaZ ~n STAa~ 11/15/80 23. PROPOSED CASING AND CEMENTI~I~'~OGI~ ~ C,;, ..... ', K 'C S,~ , ...... ' , SIZE OF llOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTIt b.~l~F~r~c:'c:: Quantity of cement 24" 16" 65# H40 80 + MD Cmt to Surf - approx 200 ft~3 13-3/4" 10-3/4" 45.5# K55BTC 3168 + MD Cmt to surf - approx 3100 ft~ ..... 8-,3/4" .7" 26# KBBBTC 8413 +_'. MD Cmt w~approx 2700 ft..3 'pri'marY ,,, 93 ft secondar.y Arctic Pack from +2000' to surf. Atlantic Richfield' Co. proposes to drill a Purdhoe Bay Kuparuk River Oil Pool development well to approximately + 8413 MD: 6513 TVD. The surface hole will be logged & a shallow gas sand tested following installation of 10-3/4" surf pipe as per ~attached procedure. 8-3/4 hole will be logged and tested before running production csg. A 20" x 2000 psi annular diverter will be installed on the 16" conductor (as per attached diagram) while drilling the surf hole. A 13-5/8" 5000 psi RSRRA BOPE stack (diagram attached) will be installed on the surface pipe & will be tested upon installation and weekly to 3000 psig. The well will be completed w/3½ 9.2# J55 Buttress tbg. Non-freezing fluids will be left in uncemented annul i thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed & tested upon con- c 1 u s i on 0f ~ ob IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is ,o deepen give data on present productive zone and proposed · new productive zone. If proposal is to drill or deepen dLrectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. ~4''h'"~zThe~77;':'.r'7].°:re'] ._ 10-28-80 Dist. Orlg. Eng. SIGNED d/- * ~ ' &'r' ~*'"~'m'~- ~- DATE TITLE (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE ClllPS REQUIRED MUD LOG OTHER REQUIREMENTS: [] YES [] NO [] YES [] NO DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE [] YES [] .NO PERMIT NO. APPROVAL DATE APPROVED BY TITLE *See Instruction On Reverse Side DATE PRESSURE DETERMINATIONS Reservoir pressure in the Upper Kuparuk as provided by repeat formation testers (RFT) and bottom hole pressure bomb data is 3150 psi. This would be balanced @ 6098 TVD with 9.94 ppg mud. It is anticipated surface pressures as seen by the 5000 psi 13-5/8 BOP stack would not exceed 2700 psi, due to the formation integrity at the surface casing shoe. This is 10% less than the BOP test pressure. ARCO Oil an ,s Company North S~ope District Post Office Box 360 Anchorage, A'taska 99510 Telephone 907 277 5637 October 28, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk 25648 B-l, Atlantic Richfield Company Surface Location' 496' SNL, 982' WEL, Sec 9, TllN, RIOE, UM Target Location' 1320' NSL, 1320' EWL, Sec 9, TllN, RIOE, UM Dear S i r s- "'~ -~ ~'~' ~'~' "u~ ~ Due to bottom hole location and testing changes affecting per- mit # 80-40, we are resubmitting our application to drill Kuparuk B-1. The new BH location as shown above is 1320' NSL, 1320' EWL, Sec 9, TllN, RIOE, UM. Enclosed please also find the procedure for testing the 1600' gas sand, a plat showing surface and bottom hole lOcations, a conductor "as built" and maps showing affected operators. Also attached are diverter and BOP diagrams. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Enclosures ARCO OH aqd Gas Company ~s a Diw$~on of AtlantlcRichfieldCompany KUPARUK B-1 SHALLOW GAS ZONE TESTING PROCEDURE (1) Drill surface hole w/spud mud as usual. (2) Run open hole logs in 10-3/4 open hole. (3) Run repeat formation tester (RFT) tool for sample and pressure of zone of interest. (4) (5) If logs and RFT data justify, procede w/test as follows- Set 10-3/4 surface csg and cmt to surface as usual. (6) (7) Nipple up and test 5000 psi 13-5/8" BOP stack. Run 8-3/4 bit and csg scraper to float collar. (8) Press test casing to 1600 psi. (9)- Displace spud mud w/9.8#/CaC12 brine and POH. (10) Make up RTTS packer w/temperature and pressure bomb info equipment on 5" DP. (ll) RIH to 50' above top of zone to be perforated. (12) Over displace tbg w/diesel by 3 Bbls & wait 20 min. (this will provide ll5' diesel freeze protection at surface in annulus). (13) Set pkr and test annulus to 1000 psi. (14) RU lubricator and test to 2500 psi. (15) RIH and perf interval as specified by well site engineer. (16) Test zone- 10 min initial flow for supe~°~h~rge drawdown 30 min shut in for initial buildup 12 hr clean up fl ow 24 hr flow @ 5 MM CFGPD 24 hr shut in fOr final buildup (17) After test, bullhead brine down tbg into formation and kill well. Check for fl ow. (18) Unset RTTS and POH. (19) RIH w/cmt ret on 5" DP & set 100' above top perf. Press test annulus to 1000 psi (20) Sqz perfs w/lO0 sx cmt to 1600 psi. If cannot build pressure overdisplace cmt past perfs and resqz. (21) Unsting stinger & reverse out excess cmt. POH. (22) TIH w/bit and scraper, drill out cmt, tag float collar, & test csg & sqzd perfs to 1600 psi. If successful displace to oilbase fluid and continue .. drilling as per usual well plan. NOTE' If the shallow perforations cannot be sqzd or tested to withold the stated test pressure anticipate setting 7" above top of Kuparuk prior to drilling in. BLI DID RAMS · · · pIPE. RAMS ® I PE RAMS PAD LE~.,"~L . 2. 3. 4. 5. 6. 7. 8. 16" 2000 ,',~,_'~u~ BR~D~-,~ 16" 2000 PS[ x 10" 3000 CS'S ,-.E.:,3. 10" 3000 x 10" x 3-1/2" T,'3G 10" 3000 PS[ x 13-5/3" 5008 SPCSL. 13- 5/8" 5000 13-,5/8" 5000 CHOKE SPOOL. 13- 5/8" 5000 13- 5/8" 5000 ACCUHULATOR CAPACITY TEST e CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID:. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME THEN CLOSE ALL UHIT SIHUL- TANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSIXG TIME AND 1100 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCRE~,!S ARE FULLY RETRACTED. PREDETERMINE DEPTH PLUG WILL SEAL & MARK RUNNING JOINT. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 HI NUTES. 5. 'INCREASE ~RESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES..,"BLEED'TO ZERO-F~(~ 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. - 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED PRESS TO 0 PSI. 8. OPEN TOP SET OF PIPES RAMS AND CHOKES, THEN CLOSE BOTTOM SET OF PIPE RAHS AND VALVES DIRECTLY UPSTE~q OF CHOKES. 9. TEST REMAINING UNTESTED MANIFOLD VALVES IF ANY WITH 3000 PSI UPSTE~I OF VALVE AND ZERO PRESSURE DOWNSTREAM. 10. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE CLOSE BLIND RANS AND TEST TO 3000 PSI FOR 10 MINUTES. 11. BLEED PRESSURE OFF ALL EQUIP. OPEN BOTTOH PREVENTERS MAKE SURE MANIFOLD & LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3000 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOHE PUMP. 14. CHECK OPERATION OF DE GASSER. 15. RECORD TEST INFORHATION ON BLO~.IOUT PREVENTER TEST FOR SIGN AND SEND TO DRILLING TO SUPERVISOR. 16. PERFORH COHPLETE BOPE TEST ONCE A WEEK AND FUHCTIONAL OPERATE BOPE DAILY. ] L ' ~o',to s.~p ~11~' ~II~T~ ~ ' .~ t~%-~JL~ ~I~ ,,. ' ~1~ '~!~~ ' {~) .~I !1 It~ ~o ~o sump · ' · ~ ~ w ~:k ~-'-~'~g~-'"'~ ~:~-' '. . ' .e..: .'. · ~ .... _~......~..~ ~.,~,~ .. .~...?~ ~- , 1. lo" x 20" 20~0 ps~ drilling 'spoo]J ~ J ' I. Upon initial installation outlets blanked "~' ' · ' operate pr:ventor to c 3. 16" 2000 psi ~nnular prevente~ ~ J 2. Every 12 hours blow air o' 4. lO",ball valves ' ~ ' ' diverter lines. 5. 16' B~adenhaad J -.. J ' - ' . . 6. Tarqet Tee's , · . ~ ' ' ~ Operating Instruction ' ' .~~lbo,v - ' N - / ' 1 Open valve to dowm~ncl l'i . Connections on -~ ~ ~ ~ -~' ~,- ~ ' ~nnectid .... . ...... . ~. '.b~ose ~nnular revert . ' D~verter Blo,,v Down . ~ } . ~ . j P tot . "~r' -~' t; PM EL,. RL HAM ET AL ; I .............................. ............. ~ .................... ,.-SOCA~ [ ARCO f ....... 996.,P/ .... -, ........ tC[:V'1,' ,',~T.- ¢~- ........ .HC~M- -,=T- ~L-,;,;'~2"~ AME~RDA ET RL ,~ - ,_. --v.v.v.'. t~..iaE:v.'.':v.v.v.-.-.'... ". ~-..F.v.v.':.'.v.v.'..'~'£~-,~.-.-. ?.'.' .9-'79 " RL%~.w.-.~ I ,.-'.::, ~....................~......~.........................~-<`.~.~...........~................~..;..~ ..... .;,~:':', . -, I I I , ........... t .... -'~ .............. ~':- -f ........... ~ .............. ':'.~-'-'~-'1 !I '"' ' ........... l-~ ........ . ......... --! ........... , ................ ;?- - t e I I . , I.:.:.:.:.:.:.:.:.:.:.'_:...:.L:.:_:_:_:Z_:_:_:_;_:_:.:_:: :_ :::::: :.::: :::::::::::::::::::::::::: ::~::i !,. I I I f..........~4`...........................:.;:....................h..................1.....................;.....~..............~ ,.~ !1 soc~. i , I f-v-'--~:'-V-T-V-V-V-'-V-T-V-'-v-v-v-'hv-v-v-'-v-lv-'-v-v-v-v:'-'-v-v-'-v.v!. '" I1 SZM~,so. ~oo~ ~_-~.,,.,~', [':.'f'X'X'X'X&;'X'X'X'Z'Y'X'X'X'X'XtX'X':'X'X'XtX'X'"T'7'v:v'v'v'v'v'1 "' t ' ' '"v.v.v.'.v.'.~v.v.v.-.v.-.'~-.-:.-.-::.-.v.i-.-.v. ..... '-! '--%" '-' Y:'" '"-:: "F-"-- ....... ~" ~ - ,:,,oo-,:, i ,,ct,,:,,_ I:-.-.-.-,,o.o,..-~.o.,,,,-.-.-.-.,-.-.-.-.-.-.-.~.~,~-.-.-,-.-.-iF ,:,,:,.oo-,~×xo,. ,:,~.oo-,:.xxo,,, -"75 I 1-85 ~'.'.'.'.'-'.'.'3v:7.S'.'.'.'.'.'.'.'.t'.'.'.'.'.'.'.'.L:=..S.S'.'.'.'.'.'.'S~ c ~ L 9-"75 ,' I 9-'75 ~ ~ ~....v.......v...~.....................i.........v.....v.~.v.v.....v...;`~v'~*",~,, ,;-,- ~_xL,~sI ' I I I ;:.:.:.:.:.:.:.:.:.:.~.:.:.:.:.:.:.:.:.:.:.;~.:.:.:.:.:.:.:.:.:.:.~:.:.:.:.:.:.:.:.:.:.i~ ~ i ! ! :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: I t ,n~'o-~.~ n~co-~,pr !'V'":"':""~ ...... :rE "; I - 3-84 3-84 v.v.v.-.-~.:., e 4 3-~4 9-'79 3 6 -.-.-.-.-.-.-.-.-.-.' I _AIR NO , f ARCO-BP · 3-84 ARCO-BP 3-84 BP E UGNU NO i RROO~BP 3-84 RRCO-SP ~ 3-84 ,,..~ K R NO g MOB-SOCRL 9-?9 t- MOB-SOCRL 9-79 r, ARCO-BP 3-84 ARCO 3-84 ARC( 3G RRCO-BP 3-84 ARCO 3-84 R t 3-84 1 MOB-PH I L 3-84 T'A ~..( LO C ~-fR 0 ARCO-BP 3-84 ARCO-BP 3-84 -1 ARCO 3-84 RR( -I. RRCO-8P 3-84 ,q~co SAK NO 3. 1 RRCO-BP 3-84 AR( I I '26 ! l ARCO-BP 21 ARCO ARCO 3-84 ............ ! ........... i ARCO-EXXON ! ! RR 3-84 I I nnCO_-F..XXON RRCO-EXXCN 3-84 t ~ i U SPK R NO 5 I I ARCO-EXXON ~.. ARCO-FXXON ARCO i . + ~ · '~ 3 I I' ARC · MOBTL U KUP S MOB-SOCR~L_.1 ARCO-EXXON RRC 9-?~ !: I 1 ....... '--'~'"':~'~',~ .u ~L.~E~ .o ~ SO¢~L I I X = 549,457°40 LAT = 70°19.'40.290,, LONG 149°35,56oO5~,, WELL ~2 Y = 5.969.647.44 kx/ X = 549.577°7'3 LAT = 70°13~40o2qO,, LONG = 149°35~52.543,, WELL ~3 V = 5.969°646..89 X = 549,697.47 LAT -:- 70019'40°276'' LONG = !49°35'49oO48" WELL -~4 Y --. 5.o. 6~,647~31 X = 549 817.'''~ LAT -- 7OOI):4Oo272,, LONq = 149°3~' 4.3,, 537,, WELL ~5 Y ~ 5.969,647°24 x : $4~.937.6~ LAT = 70olg,40.263,, LONG = 149°35~42oO3[,, X = 550,lZ~oS2 LAT : 7OO19~40.2Q~,~ LONG : ]49°35,35.035,, WELL ~8 Y 5,~69.64Oo~8 X :. 550.297°=q LAT : 7OO19~4Oo237,, LONG = 149°35~31 q~2" ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALAS~GN AND THAT THIS PLAT REPRESENTS AND AS- BUILT SURVEY MADE BY ME, AND THAT ALL DI,MEI;SIONS AND OTHER DETAILS ARE CORRECT, AS O~F' · DATE 7/g,O :, ..... . .:. .0 ., · :.,,:. - '. ., · .,~ 20 X 20 TO THE INCH * 7 x lo INCHES - KEUFFEL & ESSER CO. MADE IN U 5.A. 46 1240 ¥orm 10-401 REV. 0-1-78 SUBMIT :PLICATE (Other~ =tions on reverse side) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL b. TYPE OF WELL WELL WELL DEEPEN r-] SINGLE I-~ MULTIPLE V'--I OTHER ZONE IAI ZONE 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 496'SNL, 982'WEL, Sec 9, TllN, RIOE, UM At proposed prod. zone 6000'ss, 1320' NSL, 1320'EWL, Sec 9, TllN, RIOE, UM R, ECEIVEI7 CT 3 0 19 , 5. ~. LEASE D~I~~i~ SERIAL NO. ADL 25648 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. B-1 I0. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oi' SEC., T., R., M., (BOTTOM POD' 11. HOLE OBJECTIVE) Sec 9, TllN, RIOE, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 30 miles northweSt of Deadhorse 14. BOND INFORMATION : Oi 1 & Gas Bond ~E State.wides~etyand/orNo. #8011-38-40 (Fed Insurance Co.) 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT.Bottom hole 1867 2560 (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION 19. Ph%PO ~H TO NEAREST WELL DRILLING, COMPLETED,SUrf 480' SE . OR APPLIED FOR, FT.Target 3700' FR/E8 TYD 6513 21, ELEVATIONS (Show whether DF, RT, CR, etc.) 63 Tundra/71 Top of Pad/98 RKB Amount $..500,000 17. NO,ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 11/15/80 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 24" 16" 65# H40 80 + MD Cmt to surf - approx 200 ft~ 13-3/4" 10-3/4" 45.5# K55BTC 316~ + MD Cmt to sUrf - approx 3100 ft° 8-3/4" 7" 26# K55BTC 8413 +' MD Cmt wZapprox 2700 ft3 primary - 93 ft~ secondar.y Arctic Pack from +2000' to surf. Atlantic Richfield Co. proposes to drill a Purdhoe Bay Kuparuk River Oil Pool development well to approximately + 8413 MD = 6513 TVD. The surface hole will be logged & a shallow gas sand tested following installation of 10-3/4" surf pipe as per attached procedure. 8-3/4 hole will be logged and tested before running production cst. A 20" x 2000 psi annular.diverter Will be :installed on the 16" conductor (as per attached diagram) while drilling the surf hole. A 13-5/8" 5000 psi RSRRA BOPE stack (diagram attached) will be installed on the surface pipe & will be tested upon installation and weekly to 3000 psig. The well will be completed w/3½ 9.2# J55 Buttress tbg. Non-freezing fluids will be left in uncemented annul i thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed & tested upon con- c 1 u s i on o f j o b IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed · new productive zone. If proposal is to drill or deepen dkectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, 24'Ihere~whev&~is.l_rUe~rec~t 10--28--80 Dist Orlg. Eng. SIGNED f * ~ - J~"' ~."~"~'~~ DATE. TITLE (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~[ NO DIRECTIONAL SURVEY REQUIRED CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES ~NO OTHER REQUIREMENTS: ~YES [] NO PERMIT NO. ~ g ~'" &~ O ~/~~~ TITLE C h&'i rman APPROVED BY o' "-~ " ~' *See Instruction On Reverse Side BY ORDER OF THE "~ ~, A.P.I. NUMERICAL CODE APPROVAL DATE DATE 11-4-80 February 28~ 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas COmpany P. O. Box 360 Anchorage, Alaska 99510 Re ~ Kuparuk 25648 B-1 Atlanti= Richfield Company Permit No. 80'40 Sur. Loc.~ 496mSNL, 982~WEL, Sec 9, TllN, R10E, Bottomhole Loc.= 1320tNSL., 1320tEWL, Sec 4, T11N, R10E, UM. Dear Mr . VanDusen = Enclosed is the approved application for permit to drill the above referenced wel 1. We.Il samples, core chips and a mud log are not required. A dtre.ctional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be sub- mitred for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.8~70 and 'the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of .the State is prohibited by AS 46, Chapter 3, ArtiCle 7 and the regulati.ons promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25648 B-1 -2- February 28, 1980 cc~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dril 1. TO aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a 'repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advanoe notification so that we may have a witness present. Very truly yours, Hoyll H. Hamilton Chairman of "~Y O~D~i~ 0,~ THE Alaska Oil & Gas Conservation Commission Enclosure cc~ Department of Fish & Game, Habitat Section w/o eno1. Department of EnVironmental Conservation w/o/eno1. Department of Laborl Supervisor, La.bur Law COmpliance Division w/o eno1. ARCO Oil and Ga~~ mpany North Alask~ ~,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 21,. 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS B-l, DS E-1 Dear Mr. Hamilton' Enclosed herewith is our Application for Permit to Drill DS B-l, the $100 filing fee, and the required survey plat. Also please find our Application for Permit to Drill DS E-l, along with the $100 filing .fee. The survey plat for this well is not yet avail- able but will be forwarded to you as soon as possible. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401' REV. 1-1-71 STATE O F ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK b. TYPE OF WELL OIL WELL ['~ OTHER 2.NAME OF OPERATOR Atlantic Richfield Company DRILL [] GAS SUBMIT IN T ,ATE (Other instructi~)ns on 3. ADDRESS OF OPERATOR P.O. Box 360 Anchoraqe, AK 4. LOCATION OF WELL At surface DEEPEN reverse side) SINGLE MULTIPLE 3 1 1980 99510 , API #50-029-20465 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648 7.IF. INDIAN, ALLOTYEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. B-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Kuparuk River Oi 496'SNL, 982'WEL, Sec 9, TllN, RIoE, UI~izska0~'a At proposed prod. zone ~[tO ]v~ ~i~ 6140'SS, 1320'NSL, 1320'EWL, Sec 4, TllN, RIOE, UM 13.' DISTANCE IN MILES AND DIllON.FROM NEAREST TOWN OR POST OFFICE* 30 miles Northwest of Deadh°rse [~li.i SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 4, TllN, RlOE, UM 12. Poe 14. BONDIN-FORbiATION: Oil and Gas Bond rOE Statewidesuretyand/o~No. #8011-38-40 (Federal Insurance Co.) 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE ~ATION TO NEAREST PROPERTY OR LEASE LI~, FT. 4298' (~SO to n~est ~g, u~t, ff any) · 2560 18. DISTANCE FROM PROmSED ~CATION TO NEAREST ~LL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 61.5'GL, 95.5RKB 120' 19. PROPOSED DEPTH , 668t'TVD Amount ~1 00. 000 17.NO°ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Rotary 320 22. APPROX. DATE WORK WILL START 23. PROPOSED CASING AND CEMENTING PROGRAM · , SIZE OF HOLE SIZE OF CASING. WEIGHT.PIeR FOOT. GRADE. SETTING DEPTH Quant.ity of cement 24" 16" 65 .... H-40 80+MD Cmt to surf-.annrn~ 7130 ft3~ 13-3/4" 10-3/4" 45.5 K-55BTC 2828+MD Cmt to surf - a~rnx ~100 ft~ 9-7/8" 7" 26 . K-55BT£ :., RO36+MD Cmt w~th annvn~' ~700 ft3 primar_~"---~§' ~3 ~.eCondary I Arctic Pack from +2000'MD to surl Atlantic Richfield Company proposes to drill a Prudhoe Bay Kupavuk River Oil Pool.. development well to approximately +8036'MD, +6681'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3½" 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be per- forated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subiurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby~certi~hat the Forel~ing is Tnje~and Correct DATE 2/21/80 TITLE District Drlg. Enqineet (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [ MUD LOG [] YES [~ NO [ [] YES ~NO DIRECTIONAL SURVEY REQUIRED, r~YES [] NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.L NUMERICAL CODE PERMIT NO. 8 ~ -tif~ g' ' ~' *See Instruction On Reverse Side DY O~D~R 07 T't'i~ CO~",iSSiON APPROVAL DATE Fetx'u~ 28: 1980 DATE 02/28/80 A A A I----< v v v v WELL V X LAT LONG 'bC_-AL_E. '. I" =~OO' co- o~011~1 ATE. ~ 5,969.,646,,72 'WELL x'7 Y = 549,457o40 X = 550,177o~2 70°197/4Oo290'' LAT = 70°19~40o248'.' O ~- 1~9°35~56. DOc'7''.,, LONC = t49 WELL i'72 Y = g,967 64= 4~ WELL .'!/8 Y = 5 969 646 98 ~ ~ · /' ~ ~ , , o x = 549,q77 7~ x = ~50,297o7q LAT = 70°19'q0,~790'' LAT = 70°19~0o2~7'' LONe =- t~9°35t52.Sa3'' LONG = t~9°35~31~,522.'' WELL Y = $ 969°646 89 X -= 549,697°47 LAT = 70°19~40o276'' LONG = 149o35'4a. .,~048" WELL. Y = 5,969,647:31 X = 549,817~62 L, AT = 70o19:4Oo272'' LONG = 149°35'45o539'' W E L L //5 Y = 5,969,G47~24 X t~ ~ q37 65 LAT = 70°19'40o26}'' LONG = ]49°BS~2~O3F'' WELL."6 Y =5,969,647o3n. X = 5.50,057~83 LAT = 70o19~40~256'' LONG= 149°35'38,5"7 P.').WELL5 1 -8 I HEREBY CERTIFY 'THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AND AS- BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT~ ASpF: DATE _. 3 ~ LOCATIOM'5 AS- I UILT' AtlanticRichfieldCompany {) IDATE: IDRAWlNG No: NORTH AMERICAN PRODUCING DIVISION ! ALASKA DISTRICT- KUPARUK ~ I I I I II1~ 51 I ~}i/*F~f~ii -~ f%'¢ "': '? ...... Il I I I II II I IIIII / CHECK LIST FOR NEW %~ELL. ?EP~ITS Yes 1.Is. the permit fee attached 2. Is ~11 to be located in a defined pool ............................. Company 3. Is a registered Survey plat attached ................................ 4. Is ~11 located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool . 7. Is well to be deviated ......................... 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait ....... .0. Does operator have a bond in force ....... .1. Is a conservation order needed ...................................... .2. Is administrative approval needed ................................... .3. Is conductor string provided ........................................ Remarks .Lease & Wellitem. No. /Ap~'~e~p~o Date (1) Fee ~'Tg~-- / (2) Loc,. ~~__ (3) Admin. .4. Is enough cement used to circulate on conductor and surface ......... .5. Will cement tie in surface and intermediate or production strings ... .6. Wil 1 cement cover all known productive horizons ..................... (4) Casg. ~.c~ .7. Will surface casing protect fresh water zones ....................... ~ _8. .9. ~ditional Requirements: Will all casing give adequate safety in collapse, tension and burst.. ~ Does BOPE have sufficient pressure rating - Test to ~oc>~ psig .. ~ Approval Reccmmended: I (5) BOPE ~ Engin.ee~ring: rev: 12/12/79 CHECK LIST FOR NEW WELL PERMITS Item (1) Fee Agprove Date 1. Is 2. Is (2) _...~_~ .j~ ./~-. 3. Is ,/ 4 Is ~5 Is 6. Is 7. Is (3) e 11. ( 4 ) Casg.~4~ Yes No the permit fee attaChed .......................................... ' ~.. w~ll to be located in a defined pool ............................ a registered survey plat attached ............. . ............... well located proper distance frcm p~opert~ lin~ ..... well located proper distance frcm other wells .. . sufficient undedicated acreage available in this pool ........... ~ / well to be deviated .............................................. ~6<, / operator the only affected party ................................. 8. Is Can permit be approved before ten-day wait ......................... Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ ,~9. 14. Is enough cement used to circulate on conductor and surface ......... (~ 15. Will c~nent tie in surface and intermediate or production strings . .~, ~ ~6. Will cement cover all known productive horizons ..................... ~~ ,, 17. Will surface casing protect fresh water zones ....................... ~_ 18. Will all casing give adequate safety in collapse, tension, and burst. ~ (5)B OPE-~~' /~o,~/~ 19. Does BOPE have sufficient pressure rating - Test to 3 Doo psig . ~ Approval Reccmmended: C olog : ngig eering: rev: 03/05/80 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated' at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. 11 000000 11 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 1111Jl 000000 111111 000000 666666 11 666666 11 66 1111 66 1111 66 11 66 11 66666666 66666666 66 66 11 66 66 11 66 66 11 ~6 bb 11 666666 111111 666666 11111.1 7~7777777 7 7?77777 77 77 77 77 77 77 77 77 77 77 77 77 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 O00OO0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 666666 666666 66 66 66 66 66666666 66656666 66 66 66 66 66 66 66 66 666666 606666 '777777777~ 7777777777 77 77 77 77 77 77 77 77 77 77 77 ?? 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 PPPP AAA M M PPPP RRRR P P A A M~4 MM P P I~ R p P A A M M M P P R R PPPP A A M M ..... PPPP RRRR P AAAAA M M P R R [) A A ~. M P 1~ R P A A M M P R R U U DDDD U U D D U U D O U U D D U U D D U U D D UUUULi DDDD H H OOO EEEEE H H O O E HHIJHH 0 O EEEE H H O00 EEEEE *START* USER PCAL [10707,61260] ,.]OB MONIT(IR S~$ KL10E40 NOV-BO. *START* ,8]~ART* USER PCAL [10707,61260] dUB MONITiIR SWS KL10E40 NOV-80. *START* SHIP SEW. 1735 SHIP SE'Q. 1.735 DATE 14-JAN-81 DATE 14-dAN-B1 14:06:00 14:06:00 VV , VV EEEEEEEEEE VV' VV gEEEEgEEEg VV V¥ gE VV VV EE VV VV EE VV VV EEEEEEEE YV VV EEEEEEEE VV VV gE VV VV EE VV VV EE YV VV EE VV EEEEEEEEgE VV EEEEEgEEEE ~RRRR~R IIIIII E~RRRRRR IIIIII ~R RR II RR RR II RR RR II RR RR II R~RRRR~R II RRRRRRRR II RR RR EB RR Il RR RR II RR RE II RE RR IIIIII RR RR iiilli Y¥ YY YY YY YY YY YY YY YY YY YY 000000 000000 000000 000000 O0 O0 O0 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 O0 O0 O0 000000 000000 000000 000000 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222 2222222222 *START* USER PCAL [10Z07,61260] ,JOB SHIP SEn MONITUR SWS KL10E40 NOV-80. *START* ' FILE: DSKH:VERIFY.002<05!>[10707 61260] CREATED: PEINTED: 14-JAN-81 14:Og:29 OUEUP: SWITCHES: /FILE:FORT /COPIES:I /SPAC1NG:I /LIMIT:140 /FORMS:NORMAL 1715 DATE 14-JAN-81 14-dAN-81 IB:58:57 14:06:00 6HIPPING INSTRUCTI(]NS ISSUED 14-JAN-8.! !2:08 SHIP TO : VENTilRA, CALIFO]~NIA 9300J PCCC BY PAM PCCC D%TA ~ORMAT SPECIFICATION LENGTH: 770 BYTES EMTRY BLOCKS: ?fYPE SIZE REP CODE ENTRY 0 1 66 0 S$SSS, SSS HH HH SSSSSSSfi HH HH SS HH HH SS HH HH SS HH HH ,5~ HH HH 6SSSSS HHHHHHHHHH $SSSSS HHHHHHHHHH S,S HH HH SS HH SS HH HH SS HH HH SSSSSSSS HH HH SSSSSSSS HH HH II 1I II i1 II II II II II II II I1 II II I1 I1 I1 II 1I II II II PPPPPPPP PPPPPPPP PP PP PP PP pp Pp PP PP PPPPPPPP PPPPPPPp pp PP PP PP PP PP TTTTTTTTTT UOOOOO TTTTTTTTTT OOOOOO TT OO OD TT O0 OO TT O0 TT O0 0[) TT O0 OD TT O0 OO TT []0 O[] T T [] O [} [} TT OO O0 T T [J O O 0 TT DO00[)[') TT 0000[~(} *START* USER PCAL [10707,61260] JOB SHIP SEO. 1715 DATE 14-JAN-B! MONITflR SWS KhlOE40 NOV'80. *START* PILE: DSKH:SHIP.TO<2~5>[IO707pRiNTED: 14--JAN 8! 1~:06:1561260] CREATED: 14-JAN-8~ 12:08:53 QUEUE SWITCHES: /FILE:FORT /COPIES:I /SPACING:I /I,!MIT:140 /FORMS:NORMAL 14:06:00 LIS VERSION 15.H01 79/03126 SCHDUMBERGER COMPUTING CENTER 10707,61260 PEEL HEADER LENGTh: 132 BYTES REEL NAME: P.C.A.L. SERVlCF: NAME: EDIT REEL C(]NTINUA'[ION NUMBER: Ol PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 81/ 1/14 TAPE HEADER LENGTH: 112 BYTES TAPE NAME: 61260 DATE: 81/ 1/14 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 0! PREV1OUS TAPE NAME: COMMENTS: TAPE COMMENTS DIL RUN # 1. LOGGED 21-NOV-80 NO VISUAL VERIFICATION AYA1LABLE FOR NPHI. CASING DRILLER = 16.00 IN. ~ 3200 FT. BlT SIZE = 13.75 IN. FLUID IN THE HOLE = P'GM DENS = 10.30 VISC = 220.0 PH = 9.5 FLUID LOSS = 10.2 ML RM " " : 5.68 8 50 F RM ~ BHT = 3.26 0 87 F THE TWO RUNS D(J NOT OVERLAP. Dll, RUN # 2 LOGGED 13-DEC-80 N(-J SP OR SFJl, ON THiS RUN BECAUSE OF OIL BASE MILD. CASING DRILLER : 7.0 IN. ~ 8500 BlT SIZE = ~,0 IN. FLU1D IN THE HOLE : OIL BASE DENS : 10.4 VISC : 48.00 FLUID LOSS = 5.4 ML k l~'II~E HE;ADEI~ I, ENGTH: 62 BYTES ?ILK NAME: EDIT .00! MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: COMPANY : ATLANTIC RICHFIELD C WELL : KUPARUK B-I FIELD : KIJPA~UK EANGE : IOE TOWNSHIP : lin SECTION : 9 COUNTY : N. SLUPL S~ATE : ALASKA DENSIT~ : 800. 1024 BYTES DATUM ~PECIFICATION SHOCKS: NAME TOOL UNIT AP1 API AP1 AP1 FILE SIZE SAM REP PROCESS iNDICATORS 1 DEPT FT 0 0 0 0 0 4 1 68 2 SP OIL MY 7 1 0 0 0 4 1 68 ] ILO OIL ~HMM 7 I 2 46 0 0 4 1 58 4 ILM DIL OHMS 7 12 44 0 0 4 I b8 5 SFLU OiL OHMS 7 22 I 0 0 4 I 68 6 GR DIL GAPI 7 31 32 0 0 4 1 68 7 GR CNL GAPI 42 31 ]2 0 0 4 1 68 8 CALI CNL IN 42 28 1 0 0 4 1 68 9 DRH[] CNL G/Ca 42 44 0 0 0 4 I 68 10 NPHI CNL PU 42 68 ] 0 0 4 ! 68 11 RHOB CNL G/C] 42 35 1 0 0 4 1 68 12 NRAT CNL C/C 42 42 1 0 0 4 1 68 13 NCNL CNL CPS 42 34 92 0 0 ~ ! 68 14 PCNL CNL CPS 42 34 9] 0 0 4 I 68 15 THOR PPN 0 0 0 0 0 4 1 68 16 [iRAN PPN 0 0 0 0 0 4 1 68 17 P~TA PCT 0 0 0 0 0 4 1 68 18 GR BHC GAP1 60 31 ]2 0 0 4 1 68 19 DT BHC US/F 60 52 ]2 0 0 4 1 68 USER DEFINED OUTPUT ARRA~ OUTPUT SP AT 2 OUTPUT ILO AT 3 OUTPUT ILS AT 4 OUTPUT $~LU AT 5 OUTPUT GR AT 6 OUTPUT GR A~ 7 OUTP{]T CALl AT 8 OUTPUT DRH(] AT 9 OUTPUT NPHI AT 10 OUTPUT RHUB AT OUTPIIT NRAT AT 12 OUTPUT NCNL AT OUTPUT FCNL AT 14 OUTPUT THOR AT 15 OUTPUT IIRAN AT 16 OUTPUT PUTA AT 17 OUTPUT GR AT 18 OUTPUT DT AT 19 DEPTH 8518.000 850O.000 8400,000 R300oO00 8200,000 8100.000 8000,000 7900.000 7800.000 MNEMONIC SP NPI-{ I FCNL GR SP (JR NPHI FCNL SP GR NPHI ~'CNL GR $P GR NPH1 FCNb GR SP GR NPHI FCNL GH SP GR NPHI FCNL GR SP GR NPHI FCNL GR SP GR NPHI FCNL GR SP GR NPHI ~CNL GR VALUE -999.25O 90.750 40.869 229.500 90.750 -999.250 90.750 40.820 229.500 90.750 -999.250 50.250 24.414 1499.000 56.250 -999.250 101.813 32.813 849.000 101.813 -999.250 89.063 30.322 1018,000 89.063 -999.250 117.000 27.783 1089.000 117.000 -999.250 126.938 45.557 487.75O 126.938 -999.250 133.625 10.918 545.5OO 133.625 -999.250 241.875 39,258 622.500 241.875 MNkMONIC ILD RHOB THOR DT ILL GR RHUB THOR DT ILL GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RH(')B THOR DT ILL GR RHOB THOR DT ILL GR RHOB THOR DT ILD GR RHOB THOR DT iLD GR RHOB THOR DT VALUE 3.271 ]2,375 2.576 2.393 9].188 3.204 32.375 2.539 2.393 93.188 15.508 63.594 2.383 8.859 85.00O 3.416 107.81] 2.461 14.828 94.]75 6.887 86.625 2.]87 10.547 4. ]63 122.938 2.533 12.52] 8t1750 1.781 128.125 2.387 13.711 100.000 2.182 135.500 2.410 13.656 105.000 3.447 2tl.625 2.512 11.875 96.188 MNEMONIC CALl NRAT URAN ILM CALl NRAT URAN IbM CALl NRAT URAN ILM CALl NRAT URAN ILM CALl NRAT URAN CALl NRAT URAN CALl NRAT ORAN iL~ CALl NRAT URAN IbM CALl NRAT URAN VALUE 3.145 6.000 ].176 1.764 3.145 5.816 3.176 1.704 16.422 6.063 2.205 0.338 3.500 0.108 2.773 0.951 7.098 6.059 2.600 ] .929 4.301 6.180 2.436 3.406 1.813 6.242 3.463 3.225 2.217 6.206 3.209 4.527 3.457 6.109 3.107 16.109 MNEMONIC SFLU DRHU NCNb POTA SFLU DRHO NCNL POTA SFLU DRHO NCNb POTA SFLU DRHU NCNb POTA SFLU DRHO NCNb PUTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA VALUE -999.25O -0.345 811.000 0.005 -999.250 0.016 811.000 0.005 -999.250 0.035 3568.000 0.018 -999.250 -0.004 2504.000 0.025 -999.250 O.Olb 2988.000 0.018 -999.250 -0.002 2892.000 O.027 -999.250 0.016 1943.000 0.031 -999.250 0.021 1919.000 0.026 -999.250 0.023 21 34. 000 0.036 DEPTH ?700.000 7600.000 7500.000 7400.000 7300,000 7200.000 7100.000 7000.000 6900.000 MNE~MONIC SP NPHI FCNb GR GR NPHI F'CNI, GR SP GR NPHI FCNL GR SP GR NPHI ~CNb GR SP GR NPHi FCNL GR NPHI FCNL GH 8P G~ NPHI ~CNL GR SP GR NPH I FCNL GR 8P GR NPH I FCNL GR VALUE -999.250 242,250 45.752 551,50O 242,250 -999.250 172.250 44.043 474,000 172.250 -999.250 109.250 41,357 462.750 109.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 MN EM{INIC ILO Gl{ RHOB THOR DT ILD GR RHOB TH(JR DT ILD GR B-.HOB THOR DT iLD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT GR RHOB THOR DT VALUE 3.104 235,125 2.420 11,922 104,563 125 2,350 10,367 108,750 2.932 113,250 2,330 7,492 110.188 -999.250 -.999.250 999.250 .-999,250 999,250 ~qq 250 9999: so -999,250 99:250 -999,250 -999,250 -999,250 999,250 -'999.250 .-999,250 999,250 2999.250 999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 999 250 -'9992250 -999.250 9gg.250 MNEMONIC CALl NRAT URAN CALl NRAT URAN CALl NRAT URAN CALl NRAT ORAN CALl NRAT URAN ibm CALl NRAT ORAN ILg CALl NRAT ORAN IbM C AL I NRAT ORAN IbM CALl NRAT URAN VALUE 3.180 6.363 3.480 18.000 3.330 6,219 3,379 11,828 3.316 8.820 3,408 6.313 -999,250 999,250 9991250 -999,250 -999,250 2999.250 999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,25O -999,250 -999,250 -999,250 -999,250 MNEMONIC SFbU DRHO ~C~L POTA SFLU DRHU NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNL POTA SFLU ORHO NCNb POTA SFLU DRHO NCNb POTA SFUU DRHO NCNb PUTA VAbUE -999.250 -0.007 2188.000 0.024 -999,250 0.012 1844.000 0,028 -999.250 0.045 1719.000 0.019 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -.999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25O -999.250 -999.250 -999.250 -999,250 -999.25O -999.250 -999.250 -999.250 DEPTH 6800.000 6700,000 6600,000 6500,000 6400.000 6300.000 6200,000 6100.000 6000,000 MNEMi.INIC SP NPHi FCNL GR SP GR NPHI FCNL GR Si-' GR NPHI I~CNL GR SP GR NPH I FCNL GR SP GR NPHI ~CNL GR SP GR NPHI GR GR NPHI FCNL GR NPHI ~'CNL GR SP GR NPHI ~CNL GR VAL -999 -999 -999 -999 -999 UE .25 .25 .25 .25 .25 -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 25 MNEMONIC ILD RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB TH[JR DT ILD GR RHOB THOR DT ILO RHOB THOR DT ILD GR RHOB THOR DT V AL UE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9g9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -099.250 -999 25O -999~250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEM[]NIC ILM CALl NRAT bRAN CALl NRAT URAN IbM CAL, I NRAT bRAN CALl NRAT [IRAN ILM CALk NRAT URAN CALl NRAT bRAN ILM CALl NRAT URAN CALl NRAT URAN IbM CALl NRAT bRAN VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFLU DRHO' NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLO DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU RHO CNL POTA SFbU DRHO NCNb POTA SFLU DRHO NCNb POTA VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH .qgoo.ooo 5800. 000 5700.000 5600.000 5500.000 5400,000 5.300. 000 5200.000 5i00.000 MN EMON kC SP GR NPHI F'CNL GR NPH! FCNL GR SP GR NPHI ~'CNL GR SP GR NPHI FCNL GR SP NPHI FCNL GR SP GR NPHI FCNL GR SP GR NPHI FCNb SP GR NPHi FCNL SP GE NPHI FCNL VAL -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999. -999. -999. -999. -999. -999, -999. -999. -999. -999. -999. -999, -999. -999. -999. -999. -999, -999. -999. -999. UE .250 .25O .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 ,250 .250 ,250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 250 MN EMONIC ILD GR RHOB THOR DT ILD RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT iLD GR RHOB THOR DT ILD GR RHOB THOR DT VAL -999 -999 ~999 999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 iJE .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 ,250 .250 .250 .250 .250 .250 .250 .25O .250 .250 .250 .250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 2999 999 -999 999 .250 ,250 .250 .250 .250 CALl NRAT ORAN ILM CALl NEAT ORAN CALl NRAT ORAN kLM CALl NRAT URAN ibm CALl NEAT URAN ILM CALl NEAT URAN ILM CALl NEAT ORAN CALk NRAT ORAN ILM CALl NRAT ORAN VALUE -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999:250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFLU DRHO NCNb POTA SFLU DRHO NCNL POTA SFLU DRH(3 NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCN6 POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250-' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 5000.000 4900,000 4800.000 4700.000 4600,000 4500,000 4400,000 4]00.000 4200.000 MN SP NPH[ FCNL GR GR NPHI FCNL GR SP GR NPHI ~CNL GR SP GR NPHI PCNL GR SP GR NPHi FCNL GR SP GR NPHI ~'CNL GR SP G~ NPHI FCNL GR SP GR NPHI ~CNL GR SP NPHI GR VAL -999 -9gg -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 tie .250 .250 · 25o .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 .250 ,250 .250 .250 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. -999, -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. 25O 250 250 250 250 250 250 250 25O 250 250 250 250 250 250 250 25O 25O 25O 25O MNEMONIC iLD GR RHOB THOR DT iLD GR RHUB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR R}IOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT iLD GR RHOB THOR DT VALUE -999.250 -999.250 -999.250 -9g9.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999 250 -999~250 -999.250 -999.250 -999.25O -999.250 -999.250 -999.250 -999.250 -999.250 -999250 -999:250 -999250 -999.250 -999.250 -999.250 -999.250 ~999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 ~50 -999:50 -999.250 -999.250 -999.250 -999250 -999~250 MNEMONIC NRgT URAN CALl NRAT URAN ILM CALl NRAT URAN ILM CALl NRAT ORAN CALl NRAT URAN ILM CALl NRAT URAN CALl NRAT U[~AN ILN CA6I NRAT URAN CALl NRAT URAN VALUE -999250 -999:250 -999.250 -999.250 '999.250 -999~250 -999 250 -999.250 -999.250 -999,250 -999.,2,50 -999.250 -999.250 -999. -999.~5050 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 MNEMONIC SFLU ORHO NCNL POTA SFLU DRHO NCNL PUTA 8FhU DRHO NCNL PUTA SFLU DRHU NCNL POTA SFLU DRHU NCNL POTA SFLU DRHU NCNG -POTA SFLO DRHO NCNL POTA SFLU DRHU NCNL POTA SFLU DRHO NCNL PUTA VALUE -999.250 -999 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -.999.250 999.250 -999.250 -999.250 -999250 -999:250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 4100,O00 ~000,000 3900.00O 3800.000 3700.000 3600.000 3500.000 3400.000 3300.000 MNEflf}NIC SP NPH1 FCNL SP GR NPHI f'CNL GR SP GR NPHi FCNL GR SP GR NPHI fCNL SP GR NPHI GR SP GR NPHI FCNL GR SP GR NPHI FCNb GR SP GR NPHI FCNL GR SP GR NPHI f'CNL GR VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.25O -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.25O -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -999,250 MNEMONIC ILD RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT VALUE -999.250 '99q.250 -999.250 -999 250 -999~250 -999.250 -999,250 -999~250 -999.250 -999.250 -.~99.250 99.250 -999.250 .-990.250 999.250 990.250 -'999.250 -999.250 -999,250 -999.250 -999,250 .-990.250 9g9o250 999,250 2999.~so -999.250 :9oo. 5o 999'250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 MNEMONIC ILt4 CALl NRAT ORAN CALl NRAT ORAN ihM CALl NRAT URAN CALl NRAT URAN 1LM CALl NRAT ORAN CALl NRAT URAN CALl N~AT ORAN CALI NRAT ORAN CALl NRAT ORAN VALUE -999.250 -999,250 999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~999.250 999.250 -999.250 -999.250 -999 250 -9991250 -999.250 -999.250 999,250 2999.250 -999.250 -999.250 -999,250 -999'250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 MNEMON1C SFLU DRHO NCNb POTA SFLO DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNL POTA SFLU DRHO NCNL POTA SFLU DRHU NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA VALUE -999.250 -999;250' -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 3200,000 '~100.000 3000.00O 2900.000 2800.000 2700.000 2600,000 2500,000 2400.000 MNEMON lC SP NPHI FCNL GR SP GR NPHI P'CNL GR SP GR NPHi FCNL GR SP GB NPHI FCNb GR SP GR NPHI FCNb GR $P GI~ NPHi FC NL GP SP GR NPHI FCNL GR SP GR NPHi F-CML GR SP GR NPItI FCNb GR -1 -1 5 ALOE 95.250 47.7J9 19.287 34.000 47.719 01.750 54.844 38.770 03.250 54.844 52.969 53.313 45.703 16,750 53.313 -13.219 47.250 46.582 486.250 47.250 -80.750 51.188 42,676 360.500 51.188 -41,469 42.750 37.109 520.500 42.750 -107 41 38 706 41 -107 34 30 735 34 -96 49 44 449 49 .938 .500 .086 .000 .500 .250 ,000 .029 ,000 .000 .625 .406 ,824 ,500 .406 M N EMON lC ILD RH[)B THOR DT ILD GR. RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT 1LD GR RHOB THOR DT ILO GR RHOB THOR DT ILD GR RHOB THOR DT VALUE 10.109 -12.938 1.767 -999.250 131.125 9.211 67.063 2.098 -999.250 130.500 8.7Jl 66.125 2.139 -999.250 134.500 10.641 51,125 2.148 -999.250 131.500 14.750 50,688 2.043 -999,250 135.000 12.945 51,438 2.08O -999.250 129.750 18.656 48.031 2.219 -999.250 130.125 18.906 40,094 2.~76 -999._50 146.375 11.680 45.375 2.139 -999,250 146.000 MNEMONIC iLM CALl NEAT UfiAN 1LM CALl NEAT ORAN ILM CALl NEAT URAN iLM CALl NEAT ORAN IbM CALl NEAT ORAN CALl NEAT URAN ILM CALl NEAT ORAN ILM CALl NRAT' URAN CALl NEAT URAN VALUE 9.859 8.031 1.989 -999.25O 8.898 13.906 3.502 -999,250 8.063 14.820 3.910 -999.250 10.992 14,938 3.963 -999.250 14.053 15.898 3.773 -999.250 12.81] 14.992 3.438 -999.250 20.125 15.109 3.496 -999.250 20.688 15.195 3.039 -999,250 11.250 15.398 3.879 -999.250 MNEMONIC SFLO DRH(J NCNL PDTA SFLU DRHO NCNb PUTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLO DRHO NCNb POTA SFLU NCNb POTA SFLU DRHO NC NL POTA SFLU DRHO NCNb POTA VALUE 7.270 0.054 -29~.750 -999.250 13.695 0.012 1926.000 -999.250 6,902 0.023 1795.000 -999.250 10.969 0.012 2062.000 -999.25O 14.148 0.031 1601.000 -999.250 18.297 -0,001 2074.000 -999.250 17.688 0.019 2672.000 -999.250 20.70.3 0.000 2360.000 -999.250 10.609 0.007 I942.000 -999.250 DEPTH 2300,000 2200,000 2100,000 2000.000 1900.000 1800.000 .1700,000 1600,000 1500.000 MNEMONIC SP GR NPHI FCNb GR SP GR NPHI I~CNL GR SP GR NPHI FCNL GR SP GR NPHI FCNb GR GR NPH1 FCNL GR SP GR NPHI FCNL GR SP GR NPHI FCNL GR SP GR NPHi FCNL GR SP GR NPHI FCNL GR VALUE -72.750 49.688 b4.209 289.750 49.688 -99.750 43.438 41.699 518.000 43.4]8 -91.500 52.906 44.043 439.750 52.906 -102.500 56.313 50.391 390,750 56.313 -104.188 60.688 49.023 397.750 60.688 -103.375 56.281 4'6.582 399.750 56.281 -97.750 40.563 44.482 415.000 40.503 -93.500 49.125 40.723 449.750 49,125 -111.750 40.844 46.289 371.500 40.844 MNEMONIC iLD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT ILD GR THOR DT ILD GR RHOB THOR DT ILD GR RHOB THOR DT VALUE 15,703 52.938 1.748 -999.250 158.125 20.906 39.469 2.070 -999.250 160.1.25 14,508 65.313 2.143 -999.250 151.125 1.4.031 66.250 2.125 -999 250 161:ooo 18,031 bl.875 2.166 -999.250 156.125 18.875 65.750 2.182 -999.250 153.750 87.313 084 -999,250 161.1_25 88.688 50.031 2.041 -999.250 139.125 285.500 45.219 2.047 -999.250 140.O00 MNEMONIC CALl NRAT URAN IBM CALl NRAT URAN CALl NRAT URAN CALl NRAT ORAN IbM CALl NRAT URAN ILM CALl NRAT URAN ILM CALl NRAT URAN iBM CALl NRAT ORAN CA6I NRAT URAN VALUE 13.914 15 594 -999,250 21.328 14.b64 3.684 -999.250 13.750 15.313 3.832 -999.250 13.180 16 547 -999.250 16,641 15.742 4,121 -999,250 16.734 15.211 3,973 -999.250 380.000 16.844 3.896 -999.250 74.938 18.141 3,723 -999.250 225.375 19.656 4.070 -999.250 MNEMONIC SFLU DRHO NCNb POTA SFLU DRHO NCNL POTA SFbU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb POTA DRHU NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNB PUTA VALUE 13.063 o0.018 1571.ooo -999.250 22.453 0.004 2150.000 -999.250 13.430 -0.001 1871.000 -999.250 12.750 0.036 1678.000 -999.250 16.453 0.019 1767.000 -999.250 15,109 0.026 1755.000 -999.250 88.375 189~ '018 .000 -999,250 80.000 -0.007 1775.000 -999.250 222.875 0.0il 1818.000 -999.250 D E Ir' T H 1400.000 1300,000 1200.000 11.00.000 1000.000 900.000 800.000 700.000 600.000 MNEM(]NIC SP NPHI FCNL GR SP GR NPHI FCNh GR SP GR NPHI FCNL GR SP GR NPH I f'CNL GR SP GR NPHI FCNL GR SP GR NPHi FCNL GR SP GR NPHI FCNL GR SP GR NPHI GR SP NPHI PCNh GR VALU -123. 58. 50. 326. 58. -107. 40, 43. 442. 40. -476. 55. 46, 345. 55, -88. 43. 48, 342. 43. -94. 22. 27. 609. 22. -156, 53. 56. 294. 53. -161. 66, 55. 320. 66, -205, 41. 45. 463, 41. -215, 28, 43. 465, 28. 938 ]44 488 50O 344 938 781 164 000 781 250 000 289 500 000 000 688 389 500 688 000 172 930 5OO 172 000 594 201 75O 5'94 25O 5OO 469 75O 5OO 500 188 313 250 i88 500 64! 115 500 641 MNEMON lC ILD GR RHOB THOR OT 1LD GR RHOB THOR DT iLD GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT ILD GR RHOB THOR DT ILO GR RHOB THOR DT ILD GR RHOB THOR DT 1LD GR RHOB THOR DT VALUE 42.938 64.313 .115 -99 ,250 181.750 132.000 50.125 2.047 -999.250 139.125 17.79'7 084 -999.250 161.125 115.313 47.281 1.970 -999.250 125.000 26.391 23,141 1.732 -999.250 79.750 46.813 68.875 2.072 -999:250 176 000 35.281 72.063 1.873 -999.250 159.750 387.500 48.125 1.367 -999,250 91.375 271.500 33.250 1,352 -999.250 8].000 MNEMfjN lC CALl NRAT ORAN CALl NRAT URAN ILM CALl NRAT URAN CALk NRAT ORAN CALl NRAT ORAN CALl NRAT ORAN ILM CALl NRAT ORAN CALl NRAT ORAN CALl NRAT URAN VALUE 33.750 18.891 4.281 -999.250 122.438 19.656 3.898 -999.250 17.375 O7O -999.250 88.500 19.656 4.188 -999.250 16.078 19.65o 3.016 -999,250 37.406 16.078 4.527 -999,250 26.438 17.219 4.516 -999.250 122,438 13.500 3.855 -999,250 163.375 15.539 3,787 -999.250 MNEMONIC SFLO DRHO NCNb POTA SFLO DRHU NCNb POTA SFGU DRHO NCNb P(]TA SFLU DRHU NCNb POTA SFhU DRHO NCNb POTA SFLU DRHO NCNb POTA SFLU DRHO NCNb PUTA SFLU ORHO NCNb POTA SFLO DRHO NCNb POTA V A b U 42.844 0.043 1583.000 -999.250 111.563 -0.005 1863.000 -999.250 33.156 0.057 1570.000 -999.250 157.000 0.018 1713.000 -999.250 27.031 0.044 1954.000 -999.250 45.625 0.043 1396.000 -999.250 36.250 0,038 1613.000 -999.250 282.000 -0.035 1959.000 -999,250 325.250 -0.030 1870,000 -999,250 D E ? T H 500,000 400.000 300.000 200.000 100.000 90,000 N N E M O N I C SP NPHI FCNL GR GR NPHI FC NL GR SP GR NPH 1 FCNL SP GR NPHI FCNL GR SP GR NPHi ~CNL GR SP GR NPH1 FCNL GR VAL -197 52 39 428 52 -243 59 45 412 59 -239 43 57 268 43 -2290 26 58 226 26 -860 21 65 225 21 -965 16 66 218 16 UE .125 .219 .258 .000 .219 .750 .031 .117 .000 .031 .375 .313 .080 .250 .31_~ .000 ,250 .496 ,000 .250 .000 .20] .479 ,000 .203 .500 .609 .064 .500 .609 MNEMONIC ILD GR RHOB THOR DT 1LD GR RHOB THOR DT iLD GR RHOB THOR DT ILD RHOB THOR DT 1LO GR RHOB THOR DT 1LD GR RHOB THOR DT VAL 147 58 1 -999 90 63 1 -999 118 62 49 1 -999 115 1 25 1 -999 90 2000 19 1 -999 55 2000 1 -999 109 tie O00 ..354 250 :563 .250 .250 .]50 .250 ,000 .438 .O00 .820 .250 .O00 .035 .703 .668 .250 .000 . O00 °688 .250 .781 .000 .734 .798 .250 .188 MNEMONIC CALl NRAT URAN 1bM CALl NRAT URAN IbM CALl NRAT ORAN CALl NRAT URAN ILM CALl NRAT ORAN ibm CALl NRAT URAN VALUE 58.563 13-~84 3.520 -999.250 37.406 12.258 3.811 -999.250 20.328 17.641 4.b17 -999.250 1.200 19.056 4.750 -999.250 2.256 16.016 5.043 -999.250 1.715 070 -999.250 MNEMONIC S~'LU DRHO POTA SFLU DRHO NCNL POTA SFLU DRHU NCNL PUTA SFLU DRHO NCNb POTA SFbU DRHU NCNb POTA SFUU DRHO NCNb PUTA VALUE 146.125 -0.025 1838.000 -999.250 146.125 -0.020 1665.000 -999.250 14b.125 0.026 1315.000 -999.250 10.742 0.044 1391.000 -999.250 4.020 -0.401 1290.000 -999.250 5.773 -0.385 1302.000 -999.250 v ,$[JMt,~AR¥ OF DATA RECORDS N~NBEE OF RECORDS: 1297 LENGTH OF LAST RECURD: 690 BYTES ~ILE TRAILER LENGTH: 62 BYTES P"ILE NAME: ED1T ,001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT fILE NAME: EOF TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 61260 SERVICE NAME: EDIT TAPE CtINTINUATION NUMBER: 01 NEXT TAPE NAME: COMMENTS: 1024 BYTES DATE: 81/ 1/14