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Home My WebLink About198-185Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~,-J~',',~ File Number of Well History File PAGES TO DELETE Complete RESCAN n/C/olor items - Pages: Ef Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other COMMENTS: Scanned by: Bevedy Mildred Damth~owell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Dare~owell Date.'~ Is~ MICROFILMED 7~30~02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS pAGE Saved asM:/weepie/micr°film marker.doc 3/24/99 r%~' GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12457 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak Well Job # Log Description Date Color Print 1D-110 99114 USIT-CEMENT IMAGER 990113 1 1~-110 9911~ us~-czm~:m' z~.oz~ 99011~ 1 , 1D-110 99114 USIT-CEMENT IMAOER 990118 1 SIGNE ~ DATE: RECEIVED ~,,!AR 2 6 1999 Alaska Oil & Gas Cons. Co~miffiKm Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. )- 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1D-110 CBL-SCMT 981020 1 1 2L'329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 1E-35 CEMENT MAPPING LOG 981203 I 1 E-35 PRODUCTION LOG 981208 1 1 -36 STATIC PRESS/TEMP 981123 1 1 1G-16 [9,~ MI INJECTION PROFILE 981202 1 1 Q-07 STATIC PRESS/TEMP 981119 1 1 1Y-15A ,CBL-SCMT 981109 1 1 2M-34 ~.._. MI INJECTION PROFILE 981110 1 1 2W-12 PRODUCTION PROFILE 981028 1 I 3F-04 tJd c.~ MI INJECTION PROFILE 981203 1 1 3F-12 L,MC. MI INJECTION PROFILE 981204 1 1 3F-19 RST WFL & GLS 981103 1 1 · 3G-03 PROD PROFILE W/DEFT 981104 1 1 ~:]'i~"k [E:L.. '~]i"] i .!~ ii~.,.. .... .?~'~ ...... ':-'~ 3K-25 LL{(~, INJECTION PROFILE 981014 1 1 3K-26 ~, ----- ~ INJECTION PROFILE 981014 1 1 i ; '~ .... ': :"-. :];; SIGNE DATE: ....,...,..,.., Please sign and cop this transmiflal to Sherrie at the above address. Thank you. 0 I:! I I__1--11~ G S E I:!~ I C I=: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lod Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 25, 1998 1D-110, AK-MM-80385 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22920-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company O I~! I I_1_1 hi G S~ I~IL/I ~-- E S W'EI,I, LOG TRANSMITFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-110, AK-MM-80385 November 25, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 ID-Il0: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-229204~ 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22920-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silvemdo Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company rlF! I CI_I N G SEFI~JICE S 10-Nov-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-110 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,973.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED v . NOV 1 ? 1998 Ala~a 0il & Gas ~ns. O0mmi~i0n 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company PLUGGIN= & LOCATION CLEA'_~Z~CE REPORT State of Alaska .A.I,ASKA 0IL & GA~ CONSERVATION C0~SSION Opera~or ~ Perf i=:s_~zais - tops: Review the well file, and' comment on plug,S_hq, well head sUatus, and location clearance - orovide loc. clear. Plugs: Well head cu= off: Harker ~os= or plata: Location Clearance: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL OOMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas r-] Suspended D Abandoned F~ Service 2. Name of Operator . . . 7. Permit Number Phillips Alaska, Inc. I,OCATION~ 98-185 / 300-063 3. AddressV~.~..V .... 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~,.[.~~, 50-029-22920-00 4. Location ofwell at surface C~ TT.~_¥;~%q~-~ 1-~~} 9. Unit or Lease Name ~ .,~ ~,.;~-~_~ ~!~ ~,,~,,~Ir.,r,-~,~r Kuparuk River Unit 44' FSL, 596' FEL, Sec. 14, T11N, R10E, UM ~ ~=,,~ At Top Producing lnterva, ' '~ ~ r~r~, 11~,,,~, : ,~_,_~/..~.~(..~ 10. Well Number 2333' FNL, 2486' FEE, Sec. 14, T11N, R10E, UM{ ~-~iU I L311 L 1D-110 At Total Depth:'i ~ ! 11. Field and Pool 2311' FNL, 2614' FWL, Sec. 14, T11N, R10E, uM'''~T-~t ........ ~'~-'~J Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. RKB 27' feetI ADL 25650 ALK 468 West Sak Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 25, 1998 September 28, 1998 March 31, 2000 (P&A'd)I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 5973' MD/4228'TVD 5874' MD/4134'TVD YES r'~ No [~]I N/A feetMD 1500' (approx) 22. Type Electric or Other Logs Run CBT/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SE1-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 9 cub. Yds. High Early 7.625" 29.7# L-80 Surface 5958' 9-7/8" 640 sx AS III Lite, 340 sx Class G set bridge plug @ 5179' 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) N/A N/A N/A ' ' ~,'~I ~ ~,~ ¢1~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Perfs at 5636' Squeezed 10 bbls cement Perf's at 5380'-5384' Squeezed 10 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing easing Pressure Calculated 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 pressence of oil, gas or water. Submit core chips. RECEIVED N/A JUN 22 2000 Alaska Oil & Gas Con,,. Commismon Anchorage Form 10-407 Rev. 7-1-80 OONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of West Sak Sand West Sak Base GEOLOGIC MARKERS MEAS. DEPTH 5383' 5848' TRUE VERT. DEPTH 3667' 4109' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Summary of 1D-110 SidetraCk Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Chip Alvord Title Drilling Engineering Supervisor Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JUN 22 2000 Alaska 0il & Gas Cons. Commission Anch0r~e Date: 05/18/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-110A RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:03/29/00 START COMP:03/28/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22920-01 03/28/00 (C1) TD: 0' PB: 0' 03/29/00 (C2) TD: 4184' PB: 5873' 03/30/00 (C3) TD: 4184' PB: 5873' 03/31/00 (C4) TD: 4184' PB: 5873' CONTINUE INSTALLING BELLY MW: 0.0 SUPV:DONALD L. WESTER' Clean up around well cellar while waiting on roads and pads to clean road from CPF-3 to 3H pad. Turn key rig move. Continue rig move to 1D pad. Rig on pad @ 15:00 hrs, 18 mile move. Spot rig. Install belly board and 11" BOP stack. TESTING BOPE. MW: 9.9 BRINE SUPV:M.C. HEIM Accept rig @ 0900 hrs. 3/29/00. PJSM. Move rig over iD-il0, level rig, build cellar berm. PJSM. Pick up lubricator & pull BPV, rig up circ. lines. Ail lines tested, circulate 9.9% brine, displace freeze protect fluid. HOLDING PRESSURE ON CEMEN MW: 0.0 SUPV:M.C. HEIM Continue circ 9.9# brine, monitor well. Set BPV, N/D tree. N/U BOPE and function test to 300-3000 psi. CBU. Pull 3.5" tubing change seal rings and stand in derrick. RIH with mule shoe and packer. Tag baker cement retainer @ 5636' and CBU. POH, set packer @ 5428', mule shoe @ 5466'. Squeeze cement thru perfs @ 5636' DISPLACE OUT BRINE W/ DRL MW: 0.0 SUPV:M.C. HEIM PJSM. RIH w/gamma ray, CCL and perf guns, log from 5480' to 5050', perf from 5380' to 5384'. POH. Set packer and test. Perform squeeze job. Monitor squeeze pressure, hold pressure on cement to keep from flowing back. Reverse circ out injection rate water and clean up DP. POH w/champ packer. Set test plug and test to 300/3000#, pull test plug. RIH with bridge plug and set @ 5179'. Test to 3000#. POH. RIH with whipstock and milling bha. ,JUN 22 2000 '~-~ Commission Alaska Oil & Gas ~,,~, Anchor~e. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 21,2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-110 (98-185 / 300-063) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the P&A operations on 1D-110. If you have any questions regarding this matter, please contact me at 265-6120 or Brian Noel at 265- 6979. Sincerely, G. C. Alvord Drilling Engineering Supervisor PA1 Drilling GCA/skad Kuparuk Unit Kuparuk f D 1D-ffO Job No. AKMMS0385, Surveyed: 28 September, 1998 SURVEY REPORT 3 November, 1998 .ORIGINAL Your Ref: API-500292292000 Last Survey Date 28-September-98 Job # AKMM80385 KBE- lfZf' Surface Coordinates: 5959708.86 N, 560490.58 E (70° 18' 01.7503" N, 149° 30' 36.2842" W) I:IR !LI~ING s liii R,V I r' Ii S Survey Ref: svy89 Sperry-Sun Drilling Services Survey Report for 1D-110 Your Ref: API-500292292000 Job No, AKMMS0385, Surveyed: 28 September, 1998 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0,000 0.000 -112.10 121.00 0.000 0.000 8,90 172.00 1.000 298.000 59,90 256.00 3.000 295.000 143,84 376.93 6,440 302.350 264,34 470.99 9.390 319.970 357,51 561.10 14.770 321.010 445.59 650.83 19,750 324,750 531.26 743.29 24.530 326,820 616.88 833,63 29,450 328,880 697.36 924.50 36.010 329.470 773.76 1015.69 43.120 329,620 844.01 1107.09 48.650 330,210 907.61 1198,33 52.590 329.420 965.49 1289.00 54.390 331.040 1019.43 1380,34 57.710 331.000 1070.44 1469.82 60,250 331.510 1116.54 1651.57 59.460 331.870 1207.82 2033.61 59.740 332.830 1401.15 2222.18 61.680 331.400 1493.40 2507.61 60.570 330.960 1631.23 2696.17 66.940 331.410 1714.57 2789.78 64,560 331,040 1753.02 2980.23 62.170 330.680 1838.39 3267.64 59,330 330.150 1978.81 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959708.86 N 560490.58 E 121.00 0.00 N 0.00 E 5959708.86 N 560490.58 E 172.00 , 0.21N 0.39W 5959709.07 N ' 560490.19 E 255.94 1.48 N 3.03W 5959710.32 N 560487.54E 376.44 6.45 N 11.63W 5959715.22 N 560478.90 E 469.61 15.15 N 21.03W 5959723.84 N 560469.43 E 557.69 29.72 N 32.99W 5959738.31 N 560457.35 E 643.36 51.00 N 48.95W 5959759.47 N 560441.22 E 728.98 79.84 N 68.48W 5959788.15 N 560421.46 E 809.46 114.57 N 90.23W 5959822.70 N 560399.43 E 885.86 156.75 N 115.38W 5959864.68 N 560373.94 E 956.11 206.79 N 144.79W 5959914.48 N 560344.13 E 1019.71 263.56 N 177.66W 5959970.98 N 560310.80 E 1077.59 324.50 N 213.13W 5960031.63 N 560274.85 E 1131.53 387.76 N 249.30W 5960094.60 N 560238.17 E 1182.54 454.03 N 286.00W 5960160.57 N 560200.93 E 1228.64 521.26 N 322.87W 5960227.50 N 560163.52 E 1319.92 659.63 N 397.41W 5960365.27 N 560087.87 E 1513.25 951.51 N 550.32W 5960655.91N 559932.62 E 1605.50 1096.85 N 627.25W 5960800.63 N 559854.52 E 1743.33 1315.84N 747.73W 5961018.63 N 559732.28 E 1826.67 1463.95 N 829.19W 5961166.09 N 559649.63 E 1865.12 1538.76 N 870.27W 5961240.56 N 559607.95 E 1950.49 1687.44 N 953.15W 5961388.57 N 559523.87 E 2090.91 1905.50 N 1076.93W 5961605.62 N 559398.34E Dogleg Rate (°/~OOft) 0.000 1.961 2.383 2.882 4.026 5.975 5.683 5,237 5.543 7.228 7.798 6.068 4.370 2.450 3.635 2,880 0.467 0.229 1.223 0.412 3.385 2.568 1.266 1.001 Vertical Section (ft) 0.00 0.00 0.39 2.93 11.89 24.37 43.15 69.72 104.55 145.50 194.51 252.43 317.84 388.17 460.81 536.24 612.55 768.85 1096.13 1259.55 1508.33 1676.59 1761.53 1931.06 2180.94 Kuparuk 1D Comment Continued,.. 3 November, '!998,9:27 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for ID-110 Your Ref: API-500292292000 Job No. AKMMS0385, Surveyed: 28 September, '!998 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 3549.76 58.010 330.690 2125.50 3643.10 57.410 331.330 2175.36 3737.10 55.700 329.570 2227.17 3834.55 51.850 329.200 2284.75 3929.01 49.080 328.060 2344.87 4024.13 46.410 327.430 2408.83 4119.64 43.810 326.920 2476.23 4214.24 41.380 325.690 2545.87 4307.90 39.160 324.590 2617.33 4404.49 36.270 323.100 2693.73 4499.72 34.130 321.510 2771.54 4594.18 33.150 318.260 2850.19 4688.44 31.650 313.290 2929.79 4784.90 30.230 309.390 3012.53 4879.96 28.470 306.200 3095.39 4976.91 26.530 299.370 3181.40 5071.12 25.350 293.880 3266.13 5166.22 23.330 288.560 3352.79 5260.14 21.200 284.620 3439.70 5354.78 19.620 276.300 3528.42 5546.87 18.320 276.370 3710.07 5737.00 17.470 278.690 3891.00 5905.63 17.130 276.890 4052.01 5973.00 17.130 276.890 4116.39 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2237.60 2115.06 N 1195.89W 5961814.23 N 559277.70 E 2287.46 2184.08 N 1234.14W 5961882.93 N 559238.90 E 2339.27 2252.31N 1272.80W 5961950.85 N r. 559199.68 E 2396.85 2319.96 N 1312.83W 5962018.17 N 559159.12 E 2456.97 2382.16 N 1350.73W 5962080,07 N 559120.71E 2520.93 2441.69 N 1388.30W 5962139,30 N 559082.67 E 2588.33 2498.55 N 1424.97W 5962195.86 N 559045.55 E 2657.97 2551.83 N 1460.47W 5962248.85 N 559009.61E 2729.43 2601.51N 1495.06W 5962298.25 N 558974.63 E 2805.83 2649.22 N 1529.89W 5962345.68 N 558939.41E 2883.64 2692.66 N 1563.44W 5962388.85 N 558905.52 E 2962.29 2732.68 N 1597.13W 5962428.60 N 558871.51E 3041.89 2768.88 N 1632.30W 5962464.51N 558836.05 E 3124.63 2801.65 N 1669.49W 5962496.98 N 558798.59 E 3207.49 2830.22 N 1706.27W 5962525.25 N 558761.58 E 3293.50 2854.49 N 1743.80W 5962549.22 N 558723.86 E 3378.23 2872.98 N 1780.59W 5962567.41 N 558686.92 E 3464.89 2887.22 N 1817.06W 5962581.36 N 558650.34 E 3551.80 2897.43 N 1851.13W 5962591.29 N 558616.19 E 3640.52 2903.49 N 1883.49W 5962597.09 N 558583.78 E 3822.17 2910.38 N 1945.55W 5962603.48 N 558521.66 E 4003.10 2918.01N 2003.46W 5962610.64N 556463.69 E 4164.11 2924.81N 2053.14W 5962617.05 N 556413.96 E 4228.49 2927.19 N 2072.84W 5962619.27 N 558394.25 E Dogleg Rate (o~ooft) 0.496 0.866 2.398 3.963 3.077 2.849 2.748 2.715 2.489 3.137 2.444 2.170 3.241 2.547 2.476 3.816 21839 3.133 2.768 3.487 0.677 0.583 0.376 0.000 Vertical Section (ft) 2421.09 2499.66 2577.81 2656.25 2728.99 2799.34 2866.98 2930.99 2991.52 3050.57 3105.36 3157.41 3207.13 3255.17 3299.50 3340.71 3376.72 3409.04 3436.6& 3459.94 3500.62 3539.57 3573.19 3586.27 Kuparuk 1D Comment Projected Survey Continued... 3 November, 1998.9:27 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for ID-110 Your Ref: API-500292292000 Job No. AKMMS0385, Surveyed: 28 September, 1998 Kuparuk Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.386° (22-Sep-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 325.680° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5973.00ft., The Bottom Hole Displacement is 3586.79ft., in the Direction of 324.696° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E Tie-on Survey 5973.00 4228,49 2927.19 N 2072.84 W Projected Survey Kuparuk 1D 3 November, 1998 - 9:27 - 4 - DrillQuest STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _X Suspend _ Operational shutdown _ Re-enler suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Per/orate _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ~' M~' ~ 44' FSL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval 2333' FNL, 2486' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 2311' FNL, 2614' FWL, Sec. 14 T11N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratig raph ic __ Service __ 6. Datum elevation (DF or KB feet) 41 RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-110 9. Permit number / approval number 98-185 v'" 10. APl number 50-029-22920 11. Field / Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Surface Intermediate Production measured true vertical Length 80' 5917' 5973' 4228' 5874' 4134' Size 16" 7.625" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cub. Yds. High Early 640 sxAS III & 340 sx Class G Measured Depth True vertical Depth 121' 121' 5958' 4214' Perforation depth: measured 5623'-5712' true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3895'-3979' 3.5", 9.3#, L~80 @ 5593' N/A ORIGINAL RECEIVED -..., i 3 2000 Alaska Oil & Gas Cons. Commis n 13. Attachments Description summary of proposal__ Detailed operations program__ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation March 20, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~J4~ (~- ~"~ Title: Drilling Engineering Supervisor Chip Alvord Questions? Call Brian Noel 265-6979 Date Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ,, Plug integdfy ~ BOP Test ~ Location clearance __ i Mechanical Integrity Test __ Subsequent form required 10- t,¥~ ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 · ORIGINAL SIGNED BY Robert N...C. hri-~ten~rl Commissioner SUBMIT IN TRIPLICATE WEST SAK (1D-110) Suspension Schematic 7-5/8" Marker Joint (+/- 50' Above Top Per[oration) 3-1/2 Vetco-Gray Dummy Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint. Back pressure valve has been installed in tubing hanger 16" 62.5# H-40 @ 121' MD Tam Port Collar @ +/- 998' MD Directional KOP = 250' Max Angle = 66.94 Deg @ 2696' Avg Angle Thru W.Sak = 17 Deg Well was freeze protected w/160 bbls diesel ( 3747' MD / 2346' TVD ) 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing from 5593' to Surface (dead string - hung off open ended), Future Perforation Intervals: D-Sand 5385'- 5422' B-Sand 5454'-5493' A4-Sand 5493'-5526' A3-Sand 5550'-5596' A2-Sand 5623'-5712~ A2~Sand Per[s: 5623'¢7~712' ( 12 SPF 4-1/2" HSD Big Hole Charges ) Top of Baker K~I Cement Retainer @ +/? 5636! ( 13' below top of A-2 Perfs, pushed to TD by mill ) PBTD @ 5873' MD 7-5/8" 29.7# L*80 BTC Mod @ 5958' MD MAC 1/!7/99 KRU 1D-110 A GENERAL PROCEDURE Pre-Rig Work: 1. Set BPV and VR plug. 2. Remove well house and scaffolding. General Sidetrack and Completion Procedure: 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 9.1 ppg LSND mud and displace well. Shut in and monitor pressures to ensure well is dead. Set BPV. ND tree. NU and test BOPE. Screw in landing joint. Pull tubing hanger to floor and POOH standing back 3-1/2" tubing. Pick up 3-1/2" DP, RIH with R'f-I-S and set packer at +/- 5470' MD. Pump 8.7 bbls class G cement, squeezing +/- 4.1 bbls cement through A2 perfs at 5623-5636', leaving remainder (100') inside 7-5/8" casing. Release packer, POOH to +/- 5250' MD, circulate well, RU E-line and shoot squeeze perfs at +/- 5380' MD (=5' above top D sand). 7. Set packer at 5230' MD and pump 8.7 bbls class G cement. Squeeze +/- 4.1 bbls cement through perfs, leaving (100') inside 7-5/8" casing. Release packer, circulate well and POOH. 8. RIH and set bridge plug at +/-5201' MD, pressure test casing to 3500 psi, POOH. ~ PU Baker 7-5/8" Window Master Bottom Trip Whipstock and MW_D,, RIH. Orient and set whipstock w/MWD. ~ear off whipstock bolt and mill window in 7-5/8" casing and 15 formation. Perform FIT test to 10.0 ppg (m~ ECD at the window for 9.1 ppg LSND mud), POOH and LD milling assembly. 10. RIH w/6-3/4" ~WD / LWD and steerable ,d, rilling assembly. Slide out window and directionally drill per plan through the W~st Sa~k-~TD at +/- 5900 MD. POOH andlaydown drilling assembly. 11 ~~er tO TD (15~ap above top of window). Cement li,n, er in place, set liner hanger and liner top packer, circulate out excess ~:~,.and POOH laying down 3-1/2 DP. 12. Pressure test casing and liner lap to 3500 psi for~art Test for State). nd displace well to 9.1 ppg brine and clean 7-5/8" casing and 5-1/2" liner. Pump caustic wash and acid'pic, l~OH. ger, pump fracture stimulation, pull and LD hanger, kill well, circulate out excess sand, and filter brine,'P~~ 15. Repeat step #1_4 above for the A3, A4/B a~d_D sand inte~ai~. ............ . ."~.....~..~, 16. RIH w/mill and clean out frac sand to 15' below bottom of A2 perfs. Circulate and filter brine prior to grav pack, POOH.. 11" psi BOP Stack-- Nor t, ic Rig 3 Kuparuk River Unit Kill Line . ~ Choke Line 5 :3 .. 2 Ac~¥rn¥1~tor Caoacitv Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the-regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4, Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 10. 11. 12. 13. 14. BOP Stack Test Fill BOP stack and manllold with water. Check that all hold-down screws a~e fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws In head. Close annular preventer, chokes, and bypass valves on the manifold. All others open. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. Open annular preventer and manual kill and choke line valves. Close top pipe rams and HCR valves on kill and choke lines Test to 250 psi and 3000 psi as in.step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in ' step 4. DD nQt pressure test any choke that is not a full closing ' ' positive seal choke. Open top-pipe rams and-close bottom-pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. Open blind rams and recover test plug.-. Make sure manlf01d and lines are full of arctic diesel and all valves are set in the drilling position. Test standpipe valves [o 3000 psi for-.3 minutes. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. Record test information on blowout preventer test form. Sign and send to drilling supervisor. . · Perlorm BOPE test once per week and functionally operate BOPE dally. 1. 16" Starting Head " 2. 11 ' 5000 psi Horizontal Tubing Head 3. 11 ." 5000 psi Double Flange Adapter/Spacer Spool 4. 11 ' 5000 psi Hydril Type V Single -Pipe Rams, 3-1/8'5000 psi Side Outlets w/ manual locks 5. 11 ' 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3' 5000 psi Hydraulic gate and one 3' 5000 psi Manual gate, 2 Kill vanes - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams. on Bottom, 3-1/8' Side Outlets w/Manual Locks 7. 11 ' 5000 psi Hydrll Annular Preventer ' · TAB, 09/30/98, v.1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Robert Christenson ,~ltl~ DATE' January 16, 1999 Chairman THRU' Blair Wondzell, ~ FILE NO' .DOC P. I. Supervisor LawrenCe~~ Petroleum Inspector FROM: SUBJECT: Recement Casing KRU 1D-110 PTD 98-185 January 16,1996: About 9 PM, I got a page from Rick Overstreet, company man on Nordic 2 about a problem with a port collar being open and communicating with the perfs. They discovered it during a data frac. I notified Blair and he asked me to follow up on it. I went to the rig where they had a USIT and CBL log form PBTD to above the perfs which showed a poor cement job. We pumped down the tbg and waited to take returns up the annulus at rates up to 5 bpm. There were no returns. We then pumped down the annulus and out the port collar and waited to take returns from the tubing. There were none.. We figured out the frac gradient at the top perfs to be approx..65 psi/ft (from pumping down the tbg).; this is consistent with most west sak wells. The frac gradient at the port collar when pumping down the annulus was .84. If we extrapolated that out to .65 it puts it down to about 1280' which is probably close to the bottom of the permafrost. It was then decided to pull the tbg and packer prior to squeezing the perfs. The tbg and packer were pulled and a retainer ran back into the hole. It set prematurely at 4200'. A USIT log was then ran from 4200' up. The retainer was then milled out and another USIT log was ran from the PBTD up to insure that the same parameters were used as on the first two logs. The USIT showed a "ratty" cement job. The rig was moved off the hole while a decision is being made what to do. SUMMARY: Attachments: STATE OF ALASKA ~ ALASI',,,~ OIL AND GAS CONSERVATION COMM,,..,5iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown X Stimulate -- Pull tubing __ Alter casing __ Repair well Plugging Perforate -- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface : 5. Type of Well: Development X ~ Exploratory Stratigraphic _ Service 44' FSL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval 2333' FNL, 2486' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 2311' FNL, 2614' FWL, Sec. 14, T11N, R10E, UM 6. Datum elevation (DF or KB) RKB 41' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-110 9. Permit number/approval number 98-185 10. APl number 50-029-22920 11. Field/Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner measured 5973' true vertical 4228' measured 5874' true vertical 4134' Length Size 80' 16" 5917' 7.625" Perforation depth: measured 5623'-5712' true vertical 3895'-3979' feet Plugs (measured) feet feet Junk (measured) Baker K-~ cement retainer @ 5636' feet Cemented Measured depth True vertical depth 9 CY High Early 121' 121' 640 sx AS III L & 5958' 4214' 340 sx Class G Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 5593' Packers and SSSV (type and measured depth) N/A RECEIVED JAN 2 1 7999 AJaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 0RI61NAL 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations -X Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water~Bbl Casing Pressure N/A Tubing Pressure 16. Status of well classification as: Water Injector__ Oil Gas Suspended X Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Title West Sak Team Leader Date SUBMIT IN DUPLICATE Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-il0 WELL ID: AK9557 TYPE: -- AFC: AK9557 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: COLVILLE RIVER UNIT SPUD:09/25/98 START COMP:01/12/99 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22920-00 09/25/98 (D1) TD: 536'(536) SUPV:DON E. BREEDEN 09/26/98 (D2) TD: 3711'(3175) SUPV:DON E. BREEDEN 09/27/98 (D3) TD: 5472' (1761) SUPV:DON E. BREEDEN 09/28/98 (D4) TD: 5973'(501) SUPV:DON E. BREEDEN 09/29/98 (D5) TD: 5973' ( 0) SUPV:DONALD LUTRICK MW: 8.9 VISC: 310 PV/YP: 34/46 APIWL: 7.3 DRILLING Move rig from 1D-112 to iD-110. Accept rig @ 1330 hrs. 9/25/98. NU diverter system and function test. Spud at 121' and drill to 536' MW: 9.6 VISC: 310 PV/YP: 47/67 APIWL: 4.3 RIH WITH NEW BIT. Drill from 536' to 3711' MW: 9.5 VISC: 225 PV/YP: 43/62 APIWL: 4.0 CBU@ 5973' MD - TD Wash and ream to bottom from 2765' to 3711' Drill from 3711' to 5472' MW: 9.7 VISC: 268 PV/YP: 43/63 APIWL: 3.3 RUNNING CASING Drill from 5472' to 5973'. RIH w/9-7/8" hole opener. Ream from 298' to 358', 1850' to 2100', 3980' to 4108', 5164' to 5258'' 5734' to 5820' POH. Ream from 2555' to 2464' RU to run casing. MW: 9.6 VISC: 71 PV/YP: 26/30 APIWL: 3.8 RIG RELEASED AT MIDNIGHT RIH with 7-5/8" casing. Pump cement. ND diverter. NU tree and test to 5000 psi. Date: 1/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-il0 WELL ID: AK9557 TYPE: AFC: AK9557 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: COLVILLE RIVER UNIT SPUD:09/25/98 START COMP:01/12/99 RIG:NORDIC % 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22920-00 01/12/99 (C6) TD: 0' PB: 0' 01/13/99 (C7) TD: 0' PB: 0' 01/14/99 (C8) TD: 0' PB: 0' 01/15/99 (C9) TD: 0' PB: 0' 01/16/99 (CIO) TD: 0' PB: 0' SUPV: DOWELL PUMPING PICKLE. MW: 8.7 BRINE Move rig from 1D-116 to ID-Il0. ND tree. NU BOPE and test. Clean out hole to 5837' PERFORATING A2-SAND. MW: 8.7 BRINE SUPV:RICK OVERSTREET Pump caustic wash. Reverse circ hole clean, NTUs down to 57 and came back up to 96 NTUs, would not clean up. Pump acid pickle. Pump 52 sx of 20/40 sand down workstring. Tag top of sand @ 5766' Dump 7 sx 20/40 sand to bring top of sand up to 5750'. Ran USIT. Prepare to perforate. KILLING WELL BY PUMPING 9 MW: 8.7 BRINE SUPV:RICK OVERSTREET RIH w/perforating gun %1, perf from 5712' to 5692'. Ran 2nd gun, stuck while spotting, worked loose, perf from 5692' to 5623' Pump data frac with minimal pressure build-up indicating no fracture initiation and matrix bleed off. USIT log indicates about 75% of casing annulus uncemented, unable to perform A2 frac. Start to bleed well down. POOH WITH PACKER. MW: 8.7 BRINE SUPV:RICK OVERSTREET RIH w/RMC packer to 1012'. Moved packer up to 956', pressure test, OK. Lowered packer back down to 1012' and repeat test. POOH w/packer. RIH w/Port collar shift tool to 989'. RIH with packer. MILL CEMENT RETAINER AT 3 MW: 8.7 BRINE SUPV:RICK OVERSTREET Unset packer and POOH. RIH w/Baker cement retainer. Encounter obstruction @ 3413', attempted to POH and retainer stuck @ 3169', unable to free. Set retainer @ 3169' Run USIT log from 3112' to surface. Date: 1/21/99 01/17/99 (Cll) TD: 0' PB: 0' 01/18/99 (C12) TD: 0' PB: 0' ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 RIH W/KILLSTRING. MW: 8.7 BRINE SUPV:RICK OVERSTREET RIH to tag cement retainer @ 3156' Mill on retainer, milled plug free. Chased fish to bottom and tagged @ 5636' RIH w/USIT log. MOVING RIG TO 1D-108, SPO MW: 8.7 BRINE SUPV:RICK OVERSTREET Finished running USIT log. RIH w/kill string to 5593'. ND BOPE, NU tree and test to 5000 psi. Freeze protect well. Release rig @ 22:30 hfs 1/18/99. Daily Completion/Workover Report ARCO Alaska, Inc. I Date Rpt NO ~1 Rig Accept - hrs Days Since Accept/Est: / Rig Relase - hfs: AFC AK9557 J 01112/99 IIAMI 01/12/9g 02:30:00 Well: 1D-110 Depth (MD/TVD) / PBTD (MD) Top of Fill Contractor. NORDIC Daily Cost $. Com~'~,*inn/Workover Cost Total Well Cost $ ;$ , Rig Name: NORDIC #2 Intermediate Cs[l: Production Uner. Total Estimated Cost $ Operation At 0600 Dowell pumping pickle. Upcomi%l Operations: POOH w/workstrln~ = Run USIT. FLUID DATA FLUID LOSS : alt DATA . 'i , . EH&S DRILLS/BOP DATA MUD TYPE DAILY LOSS (bbls) BIT NO. BIT NO. INCIDENT , LAST BOP/DIVERT LAST BOP/DRILL BRINE 0 N TST WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.Tppg 0 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP pERFORATED TYPE TYPE TYPE FUEL & WATER / INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 2295 /I APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 140 01/13/99 BBLS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 35 ml/30min : INJECTION USED- BBLS SOLIDS FOOTAGE FOOTAGE ' INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST souRcE WELL TEMPERATURE °F -20° 0bbl III / / MBT PUMP NO WOB 2 WOB 2. RATE (bpm) WIND SPEED 0 ppb III ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 135° LGS SPM I *FA TFA INJECTION FLUIDS CHILL FACTOR °F -20.00° o PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 obb, III IIIII IIIII o 0 DALLY MUD SPS 1 BIT COST BIT COST CONTRACTOR 16 PERSONNEL $w61 III o o TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl} MISC PERSONNEL 0 $~61 III III III o COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 2 MI I I I I I I J I I PERSONNEL TOTAL 19 : TIME '~i END~ I HOURS: '10PSCODE ! HOLESECT. IPHASEOPS J ~ OPERATIONS FROM 0000- 0000 12:00 01:00 AM 1.00 MIRU COMP Other Move rig from 1D-116 to 1D-110 = Spot & level over well. AM 01:00 03:30 AM 2.50 'MIRU COMP Other RePair suction valve damper = Cut & slip drill line. AM 03:30 06:00 AM 2.50 NU_ND COMP Other 900 psi on ann.-- bled off = Pulled BPV = ND tree. ~M 06:00 06:30 AM 0.50 OTHER COMP Other Service rig = check crown-o-matlc. :AM 06:30 02;30 PM 8.00 NU_ND COMP Other N/U BOPE = set test plug = Test BOPE, bag, all rams, HCR, choke AM etc.= Repair 3 1/8" valve & HCR on MudX. 02:30 03:00 PM 0.50 NU,ND COMP Other Pull test plug & set wear ring. PM . 03:00 07:00 PM 4.00 . RUN_ASSY COMP cOmpletion Strap & M/U BHA #1 w/scrapers and RIH w/3-1/2" workstring = PM . tagged up at 5833' = Cleaned out to 5837', solid. 07:00 09:30 PM 2.50 ClRC coMp Completion Displace well to Seawater @ 3 bpm w/220 psi, PM 09:30 12:00 AM 2.50 PL_ASSY cOMp Completion POOH to top scraper = RIH to 5835'. PM 24.00 Daily Completion/Workover Report: 1D-110 01/12/99 Page1 Daily Completion/Workover Report ARCO Alaska, Inc. AFC No. I Date Rpt NO'1 Rig Accept - hfs Days Since Accept/Est: / Rig Relase - hrs: AK9557I 01/13/99 2 101112J99 02:30:00 lAM Well: 1D-110 Depth (MD/TVD) / : PBTD (MD) Top of Fill Contractor. NORDIC Daily Cost $' Completion/Workover Cost Total Well Cost $ $, Rig Name: NORDIC #2 intermediate Csg: Production Liner. Total Estimated Cost $ Operation At 0600 Perforatiing A2-Sand. I Upcomi%l Operations: R/U Dowell & Frac. the A2-Sand. FLUID DATA FLUID LOSS BIT DATA EH&S DRILLS/Bop DATA MUD TYPE DAILY LOSS (bbls) BIT NO. BIT NOi INCIDENT LAST BOP/DIVERT LAST BOP/DRILL BRINE 88 N TST V~EIGHT TOTAL LoSs (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAsT FIRE DRILL 8.Tppg 88 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL I sqc N SPACE PV/YP PERFORATED TYPE TYPE TYPE FUEL & WATER / 'INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 1530 // APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 170 01/13/99 BBLS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 24 ml/30min INjEcTIoN USED - BBLS SOLIDS FOOTAGE FOOTAGE INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMPERATURE °F 0bbl III / / I~IBT PUMP NO WOB 2 WOB 2 RATE (bpi) WIND SPEED 10 ppb III :~h LINER SZ RPM 1 RPM I PRESSURE (psi) WIND DIRECTION 450 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -35.67° % 0 F;IT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 Obb, III IIIII IIIII o o I~AILY MUD SPS i BIT COST BIT COST CONTRACTOR 16 PERSONNEL $5381 III 0 0 TOTAL MUD SPP I DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 0 $13142 III III III 0 ,. COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 3 M, III III III PERSONNEL TOTAL 20 I TIME ~ END ~ HOURS~. ~ OPSCODE ~ HOLESECT ~PHASEOPS ~ OPERATIONS FROM 0000- 0000 12:00 01:00 AM 1.00 RUN_ASSY COMP Completion Continued to RIH w/scrapers and mlllshoe to 5837'. AM 01:00 07:30 AM 6.50 ClRC COMP - COmpletion PJSM -- PJU clean-out hose to 7 5/8" ann. -- Pumped Caustic Wash -- AM Reverse circ. hole clean -- NTUs down to 57 and came back up to 96 NTUs = would not clean up. 07:30 12:30 PM 5.00 ClRC COMP Completion PdSM on Acid wlDowell crew, rig crew & truck drivers -- Press. test AM lines to 3500 psi -- Pumped acid pickle ~ 1/2 BPM = displaced acid within 1/2 bbl of end of workstrlng -- Reversed out ~ 2BPM & took returns Into vac. truck = cont. to reverse circ. and filtering = 40 NTU$ out and 8 NTUs going In. 12:30 02:30 PM 2.00 OTHER COMP Completion Position workstring 200' above PBTD = Dowell pumped and'spotted PM 52 sks of 20/40 sand down workstrlng = allow sand to settle -- RIH and tagged top of sand @ 5766'. 02:30 04:00 PM 1.50 OTHER COMP Completion Reposition workstring = dumped 7 sks 20/40 sand to bring top of PM - sand up to 5750'. 04:00 07:00 PM 3.00 pL_AsSY COMP Completion POOH wi workstring and scrapers. PM 07:00 12:00 AM 5.00 LOG_PERF COMP Completion R/U SWS -- ran USlT -- R/U for perforating -- PJSM. PM 24.00 -. Daily CompletiOn/Workover Report: 1 D-110 01/13/99 Page1 -. Daily Completion/Workover Report ARCO Alaska, Inc. · AFC No. J Date Rpt No J Rig Accept - hrs Days Since Accept/Est: / Rig Relase - hrs: AK9557 ~ 01/14/99 3I 01112/99 02:30:00 I AM Well: 1 D-110 Depth (MD/I'VD) / PBTD (MD) Top of Fill Contractor:. NORDIC [ Daily Cost $'.. ComDletion/Workover Cost Total Well Cost $ $ · Rig Name:' NORDIC #2 Intermediate Csg: Production liner:. Total Estimated Cost $ Operation At 0600 Killin~l well by pumping 9.8 PP9 brine to replace the 8.7 ppg. Upcoming Operations: POOH with workstrin~l = RIH with 3-1/2" drill pipe and s¢lueeze. FLUID DATA FLUID LOSS BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DALLY LOSS (bbls) BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL BRINE N TST WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.Tppg VISCOSITY ' MAKE MAKE I sPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP PERFORATED TYPE TYPE I TYPE FUEL & WATER / INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 1495 // APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 40 01/14/99 BBLS HTHP WL DEPTH IN DEPTH IN' POTABLE WATER 14 ml/30min INJECTION USED - BBLS SOLIDS FOOTAGE FOOTAGE INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL I TEMPERATURE °F -14° 0bbl III / / MBT PUMP NO WOB 2 WOB 2 - RATE (bpm) WIND SPEED 0 ppb III I ph LINER SZ RPM I RPM 1 ,PRESSURE (psi) WIND DIRECTION 0° LGS SPM ~ TFA TF^ ~NJECT~ON FLUIDS C.~LL FACTOR OF .14.00° 0 PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 2 obb, Ill I I Ill I llll o o DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 16 PERSONNEL $13554 III o o TOT~ MUD SPP ~ DULL DULL TOTAL VOL <~b~> M~SC PERSONNEL 0 $25997 III III Itl o ~OMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 4 MI III III III PERSONNEL TOTAL 22 I TIME I END I HOURS I CPS CODE I HOLESECT IPHASE CPS I OPERATIONS FROM 0000-0000 12:00 09:30 AM 9.50 LOG_PERF COMP Completion Continued to R/U SWS to perforate = RIH w/gun #1- 20' = 4-1/2" guns AM - (12 shots per ft. HSD Big Hole Charges) Perf. from 5712' to 5692'=Ran 2nd gun, stuck while spotting. = Worked loose. = Perf. ' remainder of holes from 5692' to 5623' = R/D SWS. 09:30 10:00 AM 0.50 OTHER COMP Other Pull wear ring. AM 10:00 12:30 PM 2.50 RUN_ASSY COMP ComPletion M/U & RIH wi washshoe on 3-1/2" PH-6 workstrlng to 5394' = M/U AM hanger & land = Bottom of w.s. @ ,~,30' = R.I.LD.S 12:30 06:00 PM 5.50 STIM COMP Completion PJU Dowell = PJSM = Test all lines to 7500 psi = Start w/Frac. PM procedure = Pumped Data Frac. w/minimal pressure build up Indicating no fracture Initiation and matrix bleed off = USIT Icg indicates +/- 75% of casing annulus uncemented = Unable to - perform A2 Frac. 06:00 12:00 AM 6.00 PRB_STIM COMP Completion PJD Dowell and start to bled well down. PM' 24.00 SUpervisor: RICK OVERSTREET Daily Completion/Workover Report: 1D-110 01/14/99 .. Page 1 ~llk Daily Completion/Workover Report ~F ARCO Alaska' Inc.' AFC No. I Date Rpt No I Rig Accept - hfs Days Since Accept/Est: / Rig Relase - hrs: AK9557 101/15/99 4I 01112/99 02:30:00 I AM I Well: 1 D-110 Depth (MD/TVD) / PBTD iMD) ToD of Fill Contractor. NORDIC Daily Cost $ Completion/Workover Cost~ Total Well Cost $ Rig Name: NORDIC #2 Intermediate Cs~l: Production Liner: Total Estimated Cost $ Operation At 0600 POOH with packer. Upcoming Operations: RIH with cement retainer and squeeze. FLUID DATA FLUID LOSS I BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DAILY LOSS (bbls) i BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL BRINE- 126 N TST WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 214 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP PERFORATED TYPE TYPE TYPE FUEL & WATER / 'INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 1805 // APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 65 01/14/99 BBLS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 16 ml/30min INJECTION USED - BBLS SOLIDS FOOTAGE FOOTAGE INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AsT SOURCE WELL TEMPERATURE °F ~10° ob~, III / / MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 12 ppb III )h LINER SZ RPM I RPM 1 PRESSURE (psi) WIND DIRECTION 270' III LGS SPM 1 IFA . TFA INJECTION FLUIDS CHILL FACTOR °F -38.35° o PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 ob., III III1'1 IIIII o 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 16 PERSONNEL $~0825 III o o TOTAL MUD SPP 1 DULL DULL ' TOTAL VOL (bbl) MISC PERSONNEL 0 $40823 III III III o COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 3 M, II1 III. ' III PERSONNEL TOTAL 20 I TIME J END I HOURS I CPS CODE I HOLE SECT IPHASE CPS I OPERATIONS FROM 0000- 0000 12:00 05:30 AM 5.50 PRB_STIM COMP Completion Continued to bled off press, down to 120 psi ,= Pump 87 bbls down AM ann. @ 3BPM 340 psi = shut in monitor well, 05:30 08:00 AM 2.50 CIRC COMP . COmpletion 270 psi = opened up & bled down. = Reversed & displaced well from AM 8.7 ppg filtered brine to 9.8 ppg = shut down monitor well = Returns showing mud, gel, Carbollte & HEC from frac.= Aisc showing open. Port Collar and communication from perfs to surface behind 7-5/8". 08:00 09:00 AM 1.00 ClRC COMP Completion Pulled hanger to floor = circulated contaminated relurns @ bottoms AM up till clean = shut in monitor well, dead. 08:00 11:30 AM 2.50 OTHER COMP Completion LD hanger & circ. equip. = RIH & tagged top of sand @ 5663' = POOH AM w/3-1/2" workstring (PH-6). 11:30 02:00 PM 2.50 RUN_PKR COMP Completion Switch kill to mud X = Drain stack & set wear ring = MU BHA #3 = RIH AM w/RMC packer to 1012'. 02:00 03:00 PM ' 1.00 EVAL COMP COmpletion With packer at 1012' press; test ann.= pumped Into Port Collar = PM Moved packer up to 956' = press test, held 850 psi OK = Lowered packer back down to 1012' and repeat test and pumped into Port Collar again. 03:00 04:00 PM 1.00 PL_PKR coMp Completion POOH with packer. PM 04:00 -09:O0 PM 5.00 RUN_ASSY COMP Completion MU and RIH w/Port Collar shift tool to 989' = Locate & latched Into PM Port Collar = Made sure collar was open by pumping Into It = POH and LD shift tool. Daily Completion/Workover Report: 1 D-110 01/15/99 Page 1 12:00 AM 3.00 RUN_PKR COMP 24.00 Completion MU RMC packer again wilh 3 jts drill pipe below for tall = Started in hole. Supervisor: RICK OVERSTREET Daily Completion/VVorkover Report: 1D-110 01/15/99 Page 2 ~lllk Daily Completion/Workover Report '~1~ ARCO Alaska, Inc. AFC I Date Rpt No I Rig AccePt- hrs DaYs Since Accept/Est: / Rig Relase - hrs: AK9557 5 10111~/99 0~:30:00 Well: 1D-110 Depth (MD/TVD) / PBTD (MD) Top of Fill Contractor:. NORDIC Daily Cost $' Completion/Workover Cost Total Well Cost $ $ Rig Name: NORDIC #2 Intermediate Cs[i: Production Liner: Total Estimated Cost $ Operation At 0600 Mill Cement Retainer at 3169'. Upcoming Operations: Run USlT & CBL from 5623' to surface = Run killstrin~l, freeze protect & RDMO. FLUID DATA FLUID LOSS BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DAILY LOSS (bbls) BIT NO. BIT N©. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL BRINE 70 N TST WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 284 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP PERFORATED . TYPE TYPE TYPE FUEL & WATER / INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 2320 // APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 60 01/15/99 BBLS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 22 ml/30min INJECTION USED - BBLS SOLIDS FOOTAGE FOOTAGE INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMPERATURE °F -11° ,0bb, II1 / / MBT PUMP NO WOB 2 WOB 2- RATE (bpm) WIND SPEED 5 ppb III iph LINER SZ RPM I RPM I PRESSURE (psi) WIND DIRECTION 315° LGS SPM I TFA TFA INjEcTION FLUIDS CHILL FACTOR °F '16.15° o PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 Obb, III I llll I llll o 0 DALLY MUD SPS 1 BIT COST BIT COST CONTRACTOR 16 PERSONNEL $~4 III o 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL ~U) M~SC PERSONNEL 0 ~257 Ill III III o COMPANY MUD WT GR~E GRADE TOT FOR WELL (~e~) SERVICE 3 M~ III III Ill PERSONNEL IOIP&. 20 T~ME I END I HOURS I OPS CODE I HOLESECT IPHASEOPS I OPERA'nONS FROM O000-0000 12:00 12:30 AM 0.50 RUN_ASSY COMP COmpletion Continued to RIH = tagged sand @ 5623'. AM 12:30 05:00 AM 4.50 CIRC 'COMP Completion Reversed sand out to 5643', leaving 20' of perfs open =PU 90' and AM set packer = Try to establish Injection rates = Pumped dwn tbg. out perle @ 1-2 - 3 -4 & 5 BPM w/no returns through port collar = Switched valves around to reverse and pump down ann. and out Port collar same no returns. 05:00 08:30 AM 3.50 PL_PKR COMP Completion Unset packer = RIH and tagged sand @ 5642' = POOH slowing with AM packer. 08:30 09:00 AM 0.50 RIGS COMP other Service Rig. AM 09:00 01:30 PM 4.50 PL_PKR COMP Completion PJU SWS = PJSM = RIH w/Baker Cement Retainer = Encounter AM obstruction @ 3413' = attempted to POH and Retainer stuck @ 3169', unable free = set retainer @ 3169' = POOH wi setting tools and R/D SWS. 01:30 ' 04:00 PM 2.50 OTHER COMP Completion Redress & M/U Port Collar shifting tool = RIH locate Port Collar = PM .Pull 15K over & shift Port Collar to close = Press test to 1000 psi F/ 15 min = Shear out at 2100 psi and POH with shearing tool. 04:00 07:30 PM 3.50 LOG_PERF COMP Completion PJU SWS and ran USIT log from 3112' to surface. PM 07:30 12:00 AM 4.50 OTHER COMP ComPletion R/D SWS. = Shut down waiting on log interpretations. PM Daily Completion/Workover Report: 1D-110 01/16/99 Page 1 Daily Completion/Workover Report ARCO Alaska, Inc. AFC No~ I Date Rpt No I Rig Accept - hrs Days Since Accept/Est: / Rig Relase - hrs: AK9557'~ 01/17/99 6[ 01/12/99 02:30:00 I AM Well: 1D-110 Depth (MD/TVD) / PBTD (MD) Top of Fill Contractor. NORDIC Daily Cost $' Completion/~Vorkover Cost Total Well Cost $ $ Rig Name: NORDIC #2 Intermediate Cs~I: Pr(~(~uction Liner: Total Estimated Cost $ _Operation At 0600 RIH w/killstrin~l. Upcomin~ Operations: Freeze protect, ND BOPE, NU wellhead, RDMO. FLUID DATA FLUID LOSS BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DAILY LOSS (bbls) BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL BRINE 20 N TST WEIGHT TOTAL LOSS (bbls) i SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL .9.8ppg 304 VISCOSITY - MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE PV/YP PERFORATED TYPE TYPE TYPE FUEL & WATER / INTERVALS . GELS SERIAL NO SERIAL NO VOLUME FUEL USED 2145 // APl WL DEPTH OUT DEPTH OUT i LAST SAFETY MTG I DRILL WATER USED - 60 01/17/99 BBLS HTHP WL DEPTH IN DEPTH iN POTABLE WATER 18 ml/30min INJECTION USED - BBLS SOLIDS FOOTAGE FOOTAGE INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMPERATURE °F ~31 ° Obbl III / MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 3 ppb III ph LINER SZ :]PM I RPM 1 PRESSURE (psi) WINO DIRECTION 270° Ill LGS SPM 1 TFA TFA INJECTION FLUIDS ~CHILL FACTOR °F -31.00° 0 PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 0 bbl Ill I llll IIIII · 0 DALLY MUD SPS I BIT COST BIT COST CONTRACTOR 16 , PERSONNEL ~303o III o o TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 0 $47257 III III III 0 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) ,SERVICE 2 M, III III III PERSONNEL TOTAL 19 TIME ~ END ~ HOURS ~ CPs CODE ~ HOLE SECT ~PHASE CPS J OPERATIONS FROM 0000- 0000 12:00 02:30 AM 2.50 PRB_CMT COMP Other Wailing on lOgs to be analyzed. AM 02:30 03:30 AM 1.00 RIGS COMP Other Change out Kelly & Drive Bushing. AM 03:30 06:30 AM 3.00 MILL COMP Completion P/U & M.U BHA, RIH wi 10stnds, PU Kelly, test Kelly & valvels. AM 06:30 07:30 AM 1.00 MILL COMP COmpletion Cont' to RIH, tagged cement retainer @ 3156'. ~,M 07:30 11:00 AM 3.50 MILL COMP Completion Mill on retainer @ 90 RPMs = 90 SPM = Torque 4K, Pumped ~.M visc.sweep = milled plug free = Blow & Set back Kelly. 11:00 01:00 PM 2.00 MILL COMP Completion Chased fish to bottom and tagged @ 5636' = LD single and PU Kelly. AM 01:00 04:00 PM 3.00 CIRC COMP Completion Circulated clean brine and visc. sweep to clean up hole. PM :04:00 10:30 PM 6.50 PL_ASSY COMP Completion POOH LD drill pipe and BHA. PM 10:30 12:00 AM 1.50 LOG_PERF coMp Evaluation RU SWS EUSIT Icg = RIH. PM . 24.00 Daily Completion/WorkoVer Report: 1D'110 01/17/99 Page1 Daily Completion/Workover Report ARCO Alaska, Inc. AFC No~ Date Rpt No Rig Accept - hrs Days Since Accept/Est: / Rig Relase - hrs: 10:30:00 PM AK9557 01/18/99 7 01/1AM 2/99 02:30:00 Well: 1 D-110 Depth (MDFFVD) / PBTD (MD) Top of Fill Contractor:. NORDIC Daily Cost $ Completion/Workover Cost Total Well Cost $ $ Rig Name: NORDIC #2 Intermediate Cs~l: Production Liner: Total Estimated Cost $ Operation At 0600 Moving ri~l to 1D-108, spot & level, RU hardlines and fiowback tank, Pull BPV. .Upcomin~l Operations: Circulate over to 8.7 seawater + 3% KCL, determine KW & kill well. FLUID DATA FLUID LOSS BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DAILY LOSS (bbls) BIT NO. E,IT NO. INCIDENT LAST E,OP/DIVERT LAST E,OP/DRILL BRINE 0 N TST WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.Sppg 304 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL i sqc N SPACE PV/YP PERFORATED TYPE TYPE TYPE FUEL & WATER / INTERVALS GELS SERIAL NO SERIAL NO VOLUME FUEL USED 2425 // APl WL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 75 01/17/99 E,BLS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 16 ml/30min INJECTION USED - E,BLS SOLIDS FOOTAGE FOOTAGE ' INJECTION WELL WEATHER & % PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMPERATURE °F -33° obb~ III / MBT PUMP NO WOE, 2 WOB 2 . RATE (bpm) WIND SPEED 10 ppb III ph LINER SZ RPM I RRM I PRESSURE (psi) WIND DIRECTION 270° ~GS SPM I TFA TFA 'INJECTION FLUIDS CHILL FACTOR °F -61.48° o PIT VOL GPM 2 JETS JETS ARCO PERSONNEL 1 0 bbl III IIIII IIIII o o DALLY MUD SPS I BIT COST BIT COST CONTRACTOR 16 PERSONNEL $3230 III o o TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 0 $50457 III III III o COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 2 M, III III III PERSONNEL TOTAL 19 TIME J END J HOURS J CPS CODE J HOLE SECT JPHASE CPS J OPERATIONS FROM 0000- 0000 12:00 03:30 AM 3.50 LOG_PERF COMP' Completion Continued to run USlT log. AM 03:30 06:00 AM 2.50 LOADSHED COMP Other Unloading drillpipe from pipe shed and loading tubing. AM 06:00 07:30 AM 1.50 RIGS COMP Other Service rig = Change out Kelly from 4-3/4" to 3-1/2". AM 07:30 08:00 AM 0.50 oTHER 0OMP Other Pull wear ring. AM 08:00 02:00 PM 6.O0 RUN_COMP COMP Completion PU and RIH w/Killstring to 5593' = MU hanger & land tubing. AM 02:00 03:00 PM 1.00 NU_ND COMP Other RILDS = Set BPV = Break out & send out Dowell Frac. iron & SWS PM lubricator. 03:00 07:30 PM 4.50. NU_ND COMP Other ND DOPE = NU tree = Test hanger & tree t/5000psl = clean pits = PM Freeze protect well w/160bbls Diesel. 07:30 10:30 PM 3.00 OTHER' coMp Other Allow to diesel to swap over. Dress tree & clean cellar. Release rig @ PM 22:30. 22.50 Supervisor: RICK OVERSTREET Daily Completion/Workover Report: 1 D-110 01/18/99 Page I STATE OF ALASKA ALAS, .., OIL AND GAS CONSERVATION COMM,,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alte-F~asing __ Change approved program__ 2. Name of Operator ARCO Alaska, Inc. Suspend X Operation Shutdown Re-enter suspended well __ Repair w6ll Plugging Time extension Stimulate -- Pull tubing___ Variance__ Pe--rrorate __ Other __ 6. Datum elevation (DF or KB) 5. Type of Well: Development X Exploratory -- Stratigraphic__ Service -- 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 44' FSL, 596' FEL, Sec. 14, TllN, R10E, UM At top of productive interval 2333' FNL, 2486' FEL, Sec. 14, TllN, R10E, UM At effective depth At total depth 2311' FNL, 2614' FWL, Sec. 14, TllN, R10E, UM 41' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-110 9. Permit number 98-185 10. APl number 50-029-22920 11. Field/Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total Depth: measured 5973 feet (approx) true vertical 4228 feet Effective depth: measured 5874 feet (approx) true vertical 4134 feet Casing Length Size Structural Conductor 80' 16" Surface 5917' 7.625" Intermediate Production Liner Plugs (measured) None Junk (measured) Baker K-1 cement retainer @ 5636' Cemented Measured depth 9cu yds High Early 121' 640 sx AS III L & 5958' 340 sx Class G True vertical depth 121' 4214' Perforation depth: measured 5623'-5712' true vertical 3895'-3979' Tubing (size, grade, and measured depth) 3.5" 9.3~ L-80 @ 5593' Packers and SSSV (type and measured depth) N/A 13. Attachments Description summary of proposal X Contact Chip Alvord at 265-6120 with any questions. Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation January 18, 1999 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed .~,~..,, ~ -~r ~.[N.~1~.~¢~ Title West Sak Team Leader / ~- '_ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity Mechanical In-~grity Test_ 15. Status of well classification as: Gas -- Approved by the order of the Commission Form 10-403 Rev 06/15/88 David W. Johns[on Suspended Date IApprova, No. BOP Test Location clearance __~,. Subseque~-form require 10-~O~ ~3,~ Commissioner Date SUBMIT IN T~PLICATE RECEIVE JAN 2 1 1999 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 20, 1999 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Request for Shutdown of Well Operations for KRU 1D-110 (West Sak) Dear Blair, Per the attached sundry, ARCO Alaska, Inc. would like to apply for Shutdown of Well Operations status on West Sak well 1D-110. The remedial operations required to fully isolate the different productive sand horizons prior to the required proppant laden fracture stimulations are still being developed. For reasons still under investigation the primary cement job across the West Sak sands shows marginal to poor bond quality. This inadequate cement job will not provide the adequate and necessary zonal isolation required to keep the proppant laden frac jobs in zone. The upper portion for the cement job indicates adequate cement bonding that will ensure the well can be safely left in it's current status (See attached wellbore schematic). Due to extremely tight 1999 budget constraints ARCO Alaska, Inc. finds it necessary to laydown GKA drilling rigs that do not have long term contractual commitments as soon as possible in order to conserve this years capital spending for wellwork performed by rigs that do have long term contracts. The rig that had been working the West Sak completions, Nordic #2, is one of the GKA rigs that does not have a long term contractual commitment and needs to be stacked as soon as possible. ARCO Alaska, Inc. proposes to leave 1D- 110 in the Shutdown of Well Operations mode until some rig time becomes available on Nordic #3's schedule (one of three core GKA rigs), 1999 capital permitting. Tentatively this work would likely occur during the 3rd Quarter of this year. Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling RECEIVED JAN 2_ 1 1999 Alaska Oil & Gas Cons, Commissio~ Anchorage ORIGINAL Attachments: Form 10-403 Form 10-404 Well Schematic 1D-110 (West Sak) 1D-110 USIT Log (Already Submitted) Daily Reports: Nordic #2 on iD- 110 (1/12/99 - 1/18/99) WEST SAK (1D~110) (On'Rig FFSC W/G[avel Pack) Squeeze Schemat c 7-5/8" Marker Joint (+/- 50' Above Top Perforation) 3-1/2" Vetco;Gray Dummy Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint; Back pressure valve has been installed in tubing hanger 16" 62.5# H-40@ 121'MD Tam Port Collar @ +/- 998' MD Directional KOP = 250' Max Angle = 66,94 Deg @ 2696' Avg Angle Thru W.Sak = 17 Deg Well was freeze protected w/160 bbls diesel ( 3747' MD / 2346' TVD ) 3~1/2" 9,3# L-80 EUE 8rd Mod Tubing from 5593' to Surface (dead string - hung off open ended) Future Perforation Intervals: D-Sand 5385'-5422' B-Sand 5454'-5493' A4-Sand 5493'-5526' A3-Sand 5550~- 5596' A2-Sand 5623'-5712' A2-SandPerfs: 5623'-5712' (12SPF 4-112" HSD Big Hole Charges ) Cement Retainer @ +/- 5636' ( 13' below top of A-2 Perfs ) ~BTD @ 5873'MD 7-5/8" 29.7# L-80 BTC Mod @ 5958' MD MAC 1/17/99 ~lgl~'l' BY' /,..~1-1~--~ ;1U'44AiVl ; AKL,g ~lXa-'- uul zig ~-o,~,,.,r,-'4 u MEMORANDUM Date: January 19, 1999 To: Blair Wondzcll Alaska Oil & Gas Conservation Commission From: Tom McKay Shallow Sands Drilling Team Leader ARCO Al~qka, Inc. Rc: Cement Job Status - West Sak 1D-110 This memo is pn)videxl to docmnent the current condition of the 7-5/8" cement job on West Sak well 1 D- 110. Current SituatiOn The well has been temporarily suspended, and the Nordic 2 fig has been moved to ID- 108 to complete that well. An engineering investigation continues at thi.q time to evaluate options for the repair of ID-110. The USIT and slimhole CBI~ log runs have been sent to ARCO's Plano research facility for additional investigation, Anchorage personnel are investigating why the primary cement job results were not adequate. Primary Cement Job History The 7-5/8" primary cement job went normally for thc most part. Full returns were seen throughout the job, and the plug was bumped. Cement to surface was achieved in a single stage job. A port collar was placed in the well at 997' MD, but was not utilized because of the first stage cement reaching the surface. The casing was then pressure tested to 3,000 psi for 30 minutes with minimM leak off as per state regulations_ This pressure test confirmed the port collar was closed when thc drilling rig left the well. A total of 503 bbls of Lead and 70 bbls of Tail slurry were pumpexl, with 90 bbls of cement returns captur~ at surface. Again full returns were seen throughout the job. Rig personnel were unable to reciprocate the casing after the lead slurry rounded the shoe because of sticky hole conditions. A slimhole Cement Bond Log was run off rig afler thc. drilling operation. This log was run to evaluate the integrity of the cement job across the West Sak pay sands. Zonal isolation was and is a top priority in the West Sak wells because of the fi-ac completions employed, and the close proximity of the West Sak sands to one another. A similar completion plan to 1D-118 was planned and subsequently altered based on the results of this log. Page 1 ,.51:PIT BY' This log was run from PBTD (float collar at 5,874' MD) up to approximately 4,3¢X)' MD, which was about 1,100' above the top oF the West Sak pay interval. This log showed generally poor bond, but AAI w,'mtexl to confirm that observation with the more sophisticated USYI' log when the completion rig moved on the well. Cgmpletion Problems Encountered When the Nordic 2 rig moved on to ID-110, the first unusual observation was 900 psi on the production c,xsing. This was more pressure than seen on other similar West Sak wells drilled in these latest projects. Normally we see no pressure when we move on the wells. We 'also saw no ice plug in the well, which was also an unusual observation.. We can now Speculate that this pressure was caused by: thermal expansion, or a leak in thc casing. Susequently, the 900 psi was bled. off, and it did not build back up. A back pressure valve was installed, the tree nippled down, and the Nordic 2 BOP stack nippled up and tested. During that time, no well flow or pressure build up indications were observed. A. bit and two (2) casing scrapers were then picked up and tripped in the well to PBTD. We cleaned out to 5,837' MD. The well was then displaced to seawater. There was no mention on the reports of any tight spots when thc bit and scrapers passed through the port collar area. A short trip was made ~o scrape thc well, and then several sweeps were employed to clean the well up for perforating. A sand plug w~s spotted up to 5,750' MI3 to provide a base for the first Ir'ac job. After tripping the work string, wireline was rigged up, and a USIT log was run l?om 5,750' up to about 4,300' MD, to cover the same interval as the previous CBL. This USIT again showed poor bond across the West Sak pay sands, and that a channel existed fi'om the primary cement job. Th~ecision Fj/s made to attempt the first of/bur frae jobs, the first job being on the A2 sands.-~A~'~i~h, the A2 sands were perforated from 5712' to 562Y MD (89' of petfs) at 12 spf, big hole charges, using wireline deployed casing guns in four runs. Again, no well Ilow or pressure build up was observed. Datafrac Observations Frac equipment was rigged up and datafrac operations were initiated. The dat,'ffrac consisted of: 15(I bbls breakdown stage with 8.7 ppg brine 150 hMs scour stage with 5,500 lbs of carbolite and 70 ppt HEC 200 bbls datafrac stage with 70 ppt HEC Page 2 A total of 600 bbls of fluid was pumped with 5,500 lbs of carbolite proppant added to model the zone's behavior t'or assisting the dcsibm of the final frae. The breakdown and scour stages were pumped at 30 bpm, and the datafrae at 20 bpm. Frae engineers observed that ao net pressure was built during the data.frae, and that this was very_ unusual compared to num~rotts previous West Sak frac .jobs. It appeared that the fluids were communicating behind the 7-5/8" casing, and not penetrating/fi-accing the A2 sands as desired. After thc datafrac, the operation was suspended to evaluate the unusuM datalYac re. suits. Reversing Out Frac Fluids Two entire wcllbore volumes were rcversed out of the well lbllowing the datafrac to remove the frac fluids form the wellbore. Frac fluids continued to be observed in the returns. Reversing continued, and proppant began to appear. Since proppant was found, even after being ovcrdisplaced behind thc casing by the 200 bbl datafrac, .it was sus~._ct. C~,.. thai a channel behind casing~was p?~ssi~ble. After reversing, cimulation was performed thc long way, ,and rig personnel observed "dirty" fluids fairly quic 'kly (42 bbls into the ckculation) which led to thc conclusion that there was a leak in the casing, and a possible charnel connected to the A2 pcrfs below. Continued circulation with clean brine failed to clean up the wcllbore, indicating that we were cmnmtuficating behind casing. Thc frac string was then tripped out with the well dead. Evaluation of C~qin~ lntcgrity A Baker Retrievamatic packer was run and set at 1,012 MD, just below the port collar at 997' MD. Pressure was applied to the annulus indicating that tlae port collar was at least partially open. The port collar was pumped into at 2.5 bpm with 350 psi. Thus it was confirmed the port collar was at least partially opened, between the time thc Parker rig moved off the well and the Nordic 2 rig attempted the A2 frae job. The packer was pulled out of the well, and a port collar isolation/shifting tool was run. The cups on thc isolation/shifting tool were pressured up on to confirrn again that the port collar was partially open. The port collar was then opened fully using the shifting tool fi:om what appeared to be a pmtially open position. The Ix~rt collar shifting tool was tripped out of the well. At this point, the AOGCC Field Inspirer, l. am3r Wade, was notified of the situation. AOGCC personnel in Anchorage were also notified of the situation by the AAI Drilling Engineer on Weekend Call. Page 3 The packer was picked up again and mn in the well, and set just above the A2 per£s. Pumping was initiated below the packer and into the A2 perfs to determine if circulation behind casing was possible, and to detemfinc if there was communication to thc port collar. Pumping was done at/, 2, 3, 4, and 5 bpm in stages, with no returns or pressure seen frmn tire port collar on the annulus side. We then attempted to reverse ~irculate down the tmnulus and up the work string to again try to establish a commmfication path behind casing between the A2 peffs and the port collar. No circulation was established, indicating cement bond and hydraulic isolation. The work string was tripped out of the well. Thc injection tests failed to demonstrate co~mnmtication between the port collar and thc West Sak sands. In addition, the absence of channels on the USIT logs between the port collar and 3,500' MD leads us to believe that co~mnunication behind casing is not possible between the port collar and the West Sak sands. AOGCC Field Inspector Larry Wade was also present for these tests. Squeeze Attempt Wireline was rigged up, and a cement retainer run in the well. The plan was to set the retainer just above the A2 peffs, m~d then to squeeze the West Sak pay sands from those same pcrlk. The port collar remained open in case circulation behind casing could be established during the squeeze job. It was felt that squeeze success would be enhanced if the port collar remained open. Unfortunately, thc retainer hung up at 3,169' MI), and became stuck. Thc retainer was intentionally set to allow the wireline to be retrieved. The Second USIT Run (s_u.r.f.~,tce to 3,156" MD) At this time, the decision was made to mn thc USIT log from the stuck retainer (3,156' MD) up to surface to evaluate cement integrity ia the upper portion of the well. Preliminary bond log interpretations indicated good bond to 1,100' MD (port collar at 997' MD) and generally moderate bond below 1,100' MD. Segments of g{,md bond exist in intervals of 50 to 300 feet in length between 1,100' MD and the retainer stuck point (3, ! 00' MD). It is important to note th~ previous port collar injection did not result in breaching to surface in 'ID-110, or any other offset well, indicating that good bond and hydraulic isolation is present above the port collar. Page 4 The Third USYI' Run Over The Entire Well Since we were missing approximately 1,200' of USIT. log in the well, and in order to avoid any confusion from previous multiple log runs, the decision was made to drill out the retainer and run a continuous USIT Icg fi'om PBTD to surface. This Icg is currently being evaluated and options m'e being discussed. The well is suspended with a deadstring, and thc rig has been moved to another well. Conclusion An engineering investigation of this well continues, and to determine the ma.sons for poor cement quality across the West Sak sands. However AAI's current base plan is to attempt to squeeze the interval across the West Sak sands to allow the well to be completed as a producer. A sundry notice with a repair plan will be provided t0r AOOCC approval in the near furore. Thomas W. McKay Shallow Sands Drilling ARCO Alaska, Inc. (907) 265-6890 (w) (907) 2754704 (pager) Fag, 5 SF_NT BY: FAX COVER SHEET Date: 1-1.9-99. To: Blair Wondzell' - A OGCC Fax #: 907-276-7542 ! Number of Pages: (including cover page) From: Tom McKay Work phone: Home phone: Home fax: Pager: 907-265-6890 907-522-9218 907-522-9398 907-275-4704 e-mail: tmckay @ mail.arco.corn Comments: Blair, please see the attached memo updating thc situation on West Sak 1D.110, as per your request. I will be out of state from 1/20 through 1/27, so please contact Mark Chambers at 265-1319 (or by e-mail at mchambe2@mnil.arco.com with additional questions regarding this well. Thank you. TONY KNOWLE$, (~OVEI:tNOB L&SKA OIL AND GAS CONSERVATION COMMISSION September 23, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Tom McKay Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 1 D- 110 ARCO Alaska, Inc. Permit No: 98-185 Sur Loc: 44'FSL, 596'FEL, Sec. 14, T11N, R10E, UM Btmhole Loc. 2347'FNL, 2553'FWL, Sec. 14, TI 1N, R10E, UM Dear Mr. McKay: Enclosed is the approved application for permit to drill thc above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-110. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may bc given ~roleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game~ Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI-,J~ OIL AND GAS CONSERVATION COMMI~dlON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. R~CJ~, 4]', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD]_, 25650, A~K 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 44' FSL, 596' FEL, Sec. 14, T11N, R10E, ~ Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2368' FNL, 2554' FEL, Sec. 14, TllN, R10E, UM ID-Il0 #U-630610 At total depth 9. Approximate spud date Amount 2347' FNL, 2553' FWL, Sec. 14, T11N, R10E, UM 9/23/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and property line 1D-109 6098' MD 2347' @ TD feet 13.4' @ 400' feet 2560 4322' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 62.65° Maximum surface 1447 psig At total depth (TVD) 1902 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 6057' 41' 41' 6098' 4322' 632 Sx Arcticset III L & 330 Sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) tree vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch X DiverterSketch X Ddlling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I here~t the foreg.~ng i~ true ?nd~ co~ect to th~~my knowledge, ~ ~.~.. ~ 0~,7t~ Signed '~"~/~L~'*~ ~/f,~ ~ ~P'p~ ~' c~o~mission use OnlyTitle Shallow Sands Team Leader Date Permit IXlumber _ I APl number\( ..., I Approval date ~ ,'3 ,.~ ~ ~ I See cover letter for 7'~ '-/fi',5' 150- 02_ ~ - 2. ~ '~ z.o l - t::;K,~ .-, ~7't~ I otherrequire~ents Conditions of approval Sample§ required Yes /~'~ Mud Icg required Yes Hydrogen sulfide measures Yes ~~-Directional survey required /,~"~s9 No Required working pressure for BOPE 2M ~ 5M 1OM 15M Othen Slgnea By Oavid W. Johnston by order of0~'~.~ Approved by Commissioner the commission Date o Form 10-401 Rev. 7-24-89 Submit in triplicate RECEIVED SEP 69 1998 Naska Oil & Gas Cons. Commission ~n~h~o~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-110 (C3) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drillinq Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A 7 5/8" surface / production casing string will be run to total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-110 (C3) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1D-110 (C3) Page I SG,09/08/98,v.1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.? ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,701' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP - (4134ft)(0.46-0.11 psi/fi) - 1447 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the ? 518" combination surface / production casing in this well, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 7 5/8" 29.?# 1.80 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. Drilling Area Risks: Drilling risks in the West Sak 1D-110 (C3) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-110 (C3) is WS 1D-109. As designed, the minimum distance between the two wells would be 13.4' at 400' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-110 (C3) surface casing will be filled with diesel and/or non-freezing brine after cleaning out the 7 5/8" casing and prior to the drilling rig moving off of the well. 1D-110 (C3) Page 2 SG,09/08/98,v.1 Drill, Case and Completion Plan for West Sak 1D-110 (C3) Frac Pack Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7 5/8" 29.7# L80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 7 5/8" casing +1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top j__oob may be performed in lieu of utilizing the port colJ.a.[. This is based on the cement thickening time and time[~'~quire-d to trip in the hole and open the Port Collar to perform the second stage cement job.~--.,¢n~ c~//~0~¢¢-. ~p/o u~., 6. Rig up and run workstring to 2000'. Circulate the upper +2000' with diesel 7. Install production tree and pressure test same. 8. Secure well, release rig 1D-110 (C3) Page I SG, 09/08/98, v.1 Completion Plan for West Sak 1D-110 (C3) Four-Stage, Single-Trip Frac-Pack Job, Frac-Packed Producer General Procedure: Well Preparation 1. Move in / rig up completion rig. Pull back pressure valve, nipple down tree and install 11" 5M WP BOP stack and pressure test same. . Trip in with 6-3/4" bit and scraper on 3-1/2" workstring, and RIH to PBTD. Pressure test 7-5/8" 29.7# L80 BTC-MOD casing. Perform casing wash and displace well to filtered brine. Pickle workstring as required. Filter brine to desired level. Trip out. . Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. . Make up Baker sump packer on E-line. RIH and set same below A2 sands (bottom pay sands). Space out and set sump packer to position TCP guns accurately on next trip in. POOH with E-line. . Pick up TCP perforating gun string to perforate all West Sak intervals in one trip. Trip in with 3-1/2" workstring, and sting into sump packer seal bore. Locate TCP guns on depth. Set TCP packer above West Sak. . Use diesel cap and/or void tubing to achieve desired underbalance. Drop bar and fire guns. . Release packer and reverse out to clean brine. Kill well as required. TOH with TCP gun string. Pick up gravel pack assembly, including wire-wrapped screens, gravel pack and isolation packers, blank pipe, frac-pack crossover tool, and other jewelry and trip in hole on 3-1/2" workstring. Screens and packers should be spaced out to allow for isolated frac-packs on the following four West Sak intervals in one trip: Stage 1: A2 Stage 2: A3 Stage 3: A4 + B Stage 4: D 1D-110 (C3) Page 2 SG, 09/08/98, v.1 Stage 1 10. 11. 12. 13. 14. Stage 2 15. 16. 17. 18. 19. Stage 3 20. 21. 22. 23. 24. Locate gravel pack string into seal bore of sump packer. Sting lower screen seal assembly and snap-latch into sump packer. Set all isolation packers. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 1. Using 16-20 mesh carbolite proppant, proceed to frac Stage I with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 1. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 2 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 2. Using 16-20 mesh carbolite proppant, proceed to frac Stage 2 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 2. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Re-position frac-pack tools to frac-pack Stage 3 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 3. Using 16-20 mesh carbolite proppant, proceed to frac Stage 3 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 3. Shift gravel pack tools, and reverse out excess proppant and frac fluids. 1D-110 (C3) Page 3 SG, 09/08/98, v.1 Stage 4 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 35. 36. 37. 38. Re-position frac-pack tools to frac-pack Stage 4 interval. Rig up and pressure test frac equipment at surface. Position frac-pack crossover tool as required. Perform data frac for Stage 4. Using 16-20 mesh carbolite proppant, proceed to frac Stage 4 with the specified volume of proppant. Shift crossover tool, and gravel pack Stage 4. Shift gravel pack tools, and reverse out excess proppant and frac fluids. Release frac-pack running tools and trip out of well. At this point, the flow conduit inside the screens from the sump packer to the upper packer should be free of sand and any plugs. Rathole should be available below sump packer. Circulate well to clean brine. TOH with workstring. Change rams to 3 1/2" and pressure test same unless VBR's are available. Pick up Centrilift ESP on 3 1/2" production tubing. Run in well with ESP pump with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required, and set back pressure valve in tubing hanger. Nipple down BQP stack, and nipple up production tree. Pressure test production tree. Secure well. Release rig and turn well over to production. 1D-110 (C3) Page 4 SG, 09/08/98, v.1 West Sak Well 1D-110 (C3) Four (4) Stage Frac-Pack 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Set at 6098' MD/4322' TVD 16' Conductor Casing @ 80' TAM International 7 5/8" Port Collar Set at approximately 1000' TVD D Sand Frac-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker Oil Tools A3 Sand Frac-Pack Assembly with Screer~ Baker Oil Tools A2 Sand Frac-Pack Assembly with Screen Be, ker Oil Tools ARCO Alaska, Inc. SG, 09/08/98 3-1/2" Production Tubing 9.3# L-80 EUE 8RD-Mod Power Cable for ESP Centdiift West Sak Producer Well Four (4) Stage Frac,Pack 16" Conductor Casing @ 80' Raychem Heat Trace (through permafrost) Weathedord Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Arctic Lift 3500 psi Shear circulating valve pre-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centdlift ESP Gearbox Centrilift ESP Motor Section Centdlift D Sand Frac-Pack Assembly with Screen Baker Oil Tools B + A4 Sands Frac-Pack Assembly with Screen Baker OII Tools A3 Sand Frac-Pack Assembly with Screen Baker Oil Tools 7-5/8" Combination Sudace/Production Casing, 29.7# L-80 BTC~MOD (Cemented to Sudace) A2 Sa~d Frac-Pack Assembly with Screen Baker Oil Tools ARCO Alaska, inc. TAB, 05/18/98, v.2 West Sak Phase lB TAM Port Collar Utilization Decision Tree for Frac Pack Producers Cement above Port Collar (1000' TVD) Perform Top Job as per requirements of AOGCC Continue with Completion Begin Primary One Stage Cement Job to Surface Surface Pressure test casing after bumping plug to 3000 psi for 30 min Cement below Port Collar (1000' TVD)/ Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Run in with RTTS Packer and pressure test casing Pressure test casing after bumping plug to 3000 psi for 30 rain Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion For: GOLDBERG Date Catted : 3.-$ep-gS I ARC0 Alaska, Inc. Structure: Pod lO Well: 110 I Field : Kuporuk River Unit Location : North Slope, Alask <- Wes) (feet) 2400 2100 1800 1500 1200 900 I I I I I I I I I I I I I 6OO TO LOCATION: ) 2347' FNL, 2555' FWL SEC. 14, T11N, RIOE TD - Casing Pt 2?7 Az 7 5/8 Casing - West Sok A3 Top Ugnu Sands 300 0 3O0 3000 I2700 I v 300 300 6OO 9OO 1200 1500 1800 2100 2400 27OO 3000 3300 3600 3900 4200 4500 300 325.68 AZIMUTH 3472' (TO TARGET) ***Plane of Proposal*** RKB ELEVATION: 112' K0P TVD=250 TMD=250 DEP=0 5.00 BEGIN TURN TO TARGET TVD=390 TMD=390 DEP=8 11.94 16.73 21.61 26.54 DLS: 5.00 deg per 100 ft 31.49 36.45 41.42 46.39 51.37 61.34 EOC WD--1290 TM0=1526 0EP--622 TARGET LOCATION: ] 2368' FNL, 2554' FEL SEC. 14, T11N, RIOE TARGET WD=3843 TMD=5588 DEP=3472 NORTH 2868 WEST 1958 Begin Turn & Drop to Target Base Permafrost EOC MAXIMUM ANGLE 62.65 DEG B/ PERMAFROST TVD= 1653 TMO=2317 DEP= 1320 Begin BEGIN TURN/DROP TO TARGET TVD=2185 TMD=3475 DER=2341 61.96 56.37 50.85 48.12 45.41 42.73 40.09 37.50 34.96 32.48 30.10 T/ UGNU SNDS TVD=3096 TMD=4781 DEP=3240 ~ 27.82 ~.~ 25.67 ' ~ 23.70 21.94 END DROP/TURN TV0=3513 TMD=5237 DEP=3393 ~ 20.47 T/ W SAK SNDS TVO=3701 TM0=5437 0EP=3438 ~ TARGET - T/A3 TVD=3843 TMD=5588 DEP=3472 ~ s/w SAK SNOS wo:4134 TMo:5898 DE~:3542 \ TARGET ANGLE '\~ 20 DEG SURFACE LOCATION: 44' FSL, 596' FEL SEC. 14, T11N, RIOE DLS: 3.00 deg per 100 ft i i i i i i i i i ii i i i i i i i ii I i I I I 0 500 600 900 1200 1500 1800 21 O0 2400 2700 3000 3500 3600 Vertical Section (feel) -> Azimufh 525.68 wifh reference 0.00 N, 0.00 E from sial #110 i 3900 2400 2100 1800 1500 1200 900 600 300 L aDO Z 'O ARCO Alaskaw Inc.[ Structure : Pod lO II : 110 Field : Kuporul< River Unit Locotion : North Slope, AloskoI I <- West (feet) 0 "- ',, 700 90~'"'-.. .\..,... 700 20 ~ 1800 1700 1600 ' 700 '"'-..~ 1100 1400'-. 1300 60 I I I I I ! I I I I I I I I ] I I I / I 260 240 220 200 180 160 140 120 100 8'0 60' 40 <- West (feet) 6O 2O 0 2O 40 6O 500 1200 500 20 4O 26(3 240 220 200 18(3 160 140 120 1 O0 80 60 40 20 0 20 40 60 '"'"5'""",, i\ \ 320 '",, '~ ~ 1000 · ,,, ~ ~ ~ ~ ~ 2ooo ;oo ,,~ ~1~oo ~, i ~9oo ~ ~ ~co ~oo 1100~ ~ '~ ~ ~ ~ "'x5 ',, 260 "~ ~ ~ 1700 - 260 "~ ! ~ - ~ 1soo ' 4 ~,,, ~ · ~8oo ~ ~ ' 240 : o ~ ~ ~ ~oo ~ ~ ~oo 220 >, ~1 "' ~', ~900 ~ ~1500 ~ / [220 200 ~ oooxx ~ x,, ~, X ~ ~ 400 / , X X ~ 1300~, ~ ~ ~ 2000 ~ /800 " ~ 1 ~00 200 ,,.. ~oo~ k k k,, ~ ~--- 180 "'"" ~ ~ ~ ~ '~' 't t, ,t'/700 /' ',.,. ~N ,~1~ooX ",, ~oo~ ~oo ~ ~oo ~ ~o~,,, ~ 6o "'-. ~ ~ ~ ~ ", ~ ~ ~oo /'' ',.. ~X ~oo ~"~ X X X ",, ~oo~ ,,,,~ ,,,' ~ o 140- "'""".,'"" 1~ooX Z "~'""~ t X"1100x 'X ~! "" "-.~ 600/' -" I ,'"~,,. --,, . ~ ? ~o~ ,~, ~, 500 .'"'~00,''17°°/ ",~. ~ ~,, ~'~oo t~oo >'~oo,,'"' x, '~ ', ', .... 1300 ~ '"~.__NN1"°° ~,, X',,'",~ ~o "'-.. -.,,,ooo XN ",_X", --~ ~oo ~o/'~ ~o """"....... "'"x,,. ~ '"',.:,go ~,:uu ',,,, ~~ 1 O0 1700 ~o '--~.. ~_ ',.,,_ ~o~ k,,,.. ',,~oo ~ ~o -..~~ ~,., ~o~?OO,., ,o - "'---..... ,.?o ~oo' '..., ~-..,...'~ "--,.~ ~x ~o~,,, ~oo~--.,. "... '-~, '.,~ 1000 ~x.,. "'~ _~ 'xx. 60~ 20 "-..... 'x.,., 800 5~,. 500 20 '"-~ 800 ", "-, /k I c,~tea ',~, t~,,c~ For: GOLDBERG Plot Reference ;s ~ 1D-110/C3 V~. Co~di~tea ere ;n (e~ reference slot ~11o. T~e Ve~icot ~p~s are r~ence ~B (Park~ ARCO Alaska~j Inc.] Structure : Pod lO II : 110 Field : Kuporuk River Unit Locofion : North Slope, AloskoI 1040 lOO0 96O 920 880 84O 800 760 72O 680 640 600 56O 520 480 440 400 360 520 280 <- West (feet) 720 680 640 600 560 520 480 440 400 560 320 280 240 200 160 120 ,,,,,, ' ' ' ' ,, 1 ¢00 ,~o~,,, \ ,,,, \,,,,\~oo '"-- ~\2~00 '" 1 ~3 ' 5, -- ~ aoo' ~oo ¢00 ' "'",,\"',, Z '"", ' '", k~2°° ',,, ", \ ,.,,,,,~oo , ,,,,,,. \ ,,,,, ,,.,,.\ · ,, ,,,, \ ,,,,, ,,,, \~ooo '"-.. ,4o;',, ',, ~oo",,, "',,, ,,,,,,,, ~ ,,,,,,,Vooo ,~:,~oo ',,,,, ~oo~ "-,.' ",, ' ',,, ",,, ',~ 13oo "" '"' ~ 20 '"',0 "... "',, ,~oo ",,, '"",, ~soo ~ aoo",,,, x ',,,, ',,,, '..,...~9oo '-, ',, 8 o '., ~r'>. "~ '" " ~ ' '~1oo ~.~... ' ".. "",, "'k, '"",, ""- ", \', X \, 1100 '~ "-.......... ..,,., .,,,,, "'-. '". 1400 120(~~ '" / i i i i i i i i i i I ! i i i i i i i i i i i i i i 720 680 640 600 560 520 480 440 400 360 520 280 240 200 160 120 <- West {feet) 1040 1000 960 920 88O 84O 800 760 720 680 640 6OO 560 520 480 440 4OO 360 32O 280 /X I Z 0 AI~CO Alaska~ Inc. Fiel~f : Dunif Slope, A osko u kP;idve; Locofion : North <- West (feet) 2900 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 600 700 600 I I I I I I I I I I I I I I I I I t I I I I I I I ] I I I I ? ............ 3 O0 ',, 2600 ',, ................. 3500 k ....... ~ 3500 28OO 2700 260O 25OO 2400 2300 2200 2100 "*'- 2000 "-,I-- 2800 '--.,,. 3200 " · , 5100 '"... 3100 '~ 2300 '"'-. 3000 '" "I; 2500 '% 2900 "' 5000 '% 2800 · '.. 2500 2700 ", ~-90C) ",, '""% 2700 ~ 2200 O( "..\\.. %.\..2600 '"\,, 480( , '-.. 2400 2600 "". 2500 · %\\... 4700 '"'\.... ";%, 21 O0 '",, 2400 '" ".,. 2300 2500 , . "~ 2300 ",,,,. 2000 · , "~ 2200 2400 ', ",, 2200 ",, · , ",, '"',.. ~ ~ 900 ',~ 21 O0 2300 , ., 1900 "'"'\. '~, 21 O0 ',.,, (- ' '"",,,~ 4200 '"',, o '"",,, ',,, \ 41oo ", ~8oo Z 18oo "'~ 2000 ',,, ~ 4000 ', · .. 2200 ",; ~ 3900 ",, · 2000,,.. ~ 3800 ", ""'.. ",.,. ~ 3700 ",,, ; 700 t- '"'"' '"\ ~ 3600 ',,, ~ "%. 1900 "\'. X 3500 1700"~ ° '",,.,, ,, 3500 ',\ -,,,,~ ~oo ~ooo .__":, \~oo "<'""-..-~-x. '"'"' 3000 '"'L%.. ".... , 1300 ~ "., 1 '"',,,,\~29 O0 '"'"'"""""L 1900 . 17OO ',, ~ '""-..._ '",%.2500 · 1800 ~ooo , ,~o -..~ '".,..~ i i I i i t i i I i i i I i I i i i I i i i i i i i i i i 2200 2100 2000 1900 1800 1700 1600 1500 1400 1.300 1200 1100 1000 900 800 700 600 <- West (feet) 2900 2800 2700 2600 2500 2400 2300 2200 2~00 /~, I 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 lOO0 Structure: Pad 1D Well : 110 Field : Kuparuk River Unit Location : North Slope, a WELL PROFILE DATA ..... P~nt ..... UO Inc 0~' 1~D Ne~h [alt V. Sect r,~ ~ o.~ o.~ o.~ o.~ o.oo o.~ o.~ o.~ ~ 25o.~ o.~ ~.~ 2~.~ o.oo ~ o.~ o.~ Dean Turn to Targ~ ~go.~ 7.~ ~.~ ~g.~ ¢.27 --7.~ 7.70 ~ of ~ld~um 1526.346~ ~3~491289.61 ~.32 -3~.11 622.~2 ~ ~ H~d ~475.26~ ~32.4g 21~.01;o~.e* -1126.70 23~1~7 ................................................... T~UE NORTH 35O 34O 330 520 510 10 2O ~)~7oo 30 ./ 500 300 Cr.al,d by finch For: GOLDBERG Dale ~a~ed : 3-Sep-g8 Plot Reference is WS ID-IIO/C.~ Verl. ~6. I True ~i(; a~ I~ ......... 40 290 ........ ,o 8iD70 280 80 500 270 21 0 1 go 260 100 250<5~ ..... 11 0 240 230 1 30 120 140 220 2500 2500 1 ioo ~ 2900 210 % % 190 180 17O Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 110 slot #110 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref = WS 1D-110/C3 Vets. #6 Our ref = prop2216 License = Date printed = 3-Sep-98 Date created = 1?-Apr-9? Last revised = 3-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w149 30 18.908 Slot location is n?0 18 1.749,w1%9 30 36.284 Slot Grid coordinates are N 5959708.680, E 560490.602 Slot local coordinates are 44.00 N 596.00 W Projection ty~e= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 100.00 0.00 300.00 100.00 0.00 N 0.00 200.00 0.00 300.00 200.00 0.00 N 0.00 250.00 0.00 300.00 250.00 0.00 N 0.00 350.00 5.00 300.00 349.87 2.18 N 3.78 390.00 7.00 300.00 389.65 4.27 N 7.40 400.00 7.42 302.21 399.57 %.92 N 8.47 500.00 11.94 315.32 498.14 15.72 N 21.21 600.00 16.73 321.16 595.00 34.29 N 37.52 700.00 21.61 324.43 689.43 60.50 N 57.27 800.00 26.54 326.54 780.70 94.14 N ~0.32 900.00 31.49 328.03 868.13 134.96 N 106.48 1000.00 36.45 329.14 951.04 182.64 N 135.56 1100.00 41.42 330.03 1028.80 236.83 N 167.35 1200.00 46.39 330.75 1100.83 297.11 N 201.58 1300.00 51.37 331.36 1166.57 363.02 N 238.02 1400.00 56.35 331.90 1225.52 434.07 N 276.37 1500.00 61.34 332.37 1277.24 509.70 N 316.34 1526.34 62.65 332.49 1289.61 530.32 N 327.11 2000.00 62.65 332.49 1507.23 903.46 N 521.44 PROPOSAL LISTING Page 1 Your ref : WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Dogleg Vert Deg/100ft Sect E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 W 5.00 3.93 W 5.00 7.70 W 5.OO 8.84 W 5.00 24.94 W 5.00 49.48 W 5.00 82.26 W 5.00 123.03 W 5.00 171.50 W 5.00 227.28 W 5.00 289.95 W 5.00 359.04 W 5.00 .434.02 W 5.00 514.39 W 5.00 599.32 W 5.00 622.42 W 0.00 1040.16 2317.29 62.65 332.49 1653.00 1153.41 N 651.61 W 0.00 1319.99 2500.00 62.65 332.49 1736.94 1297.35 N 726.57 W 0.00 1481.13 3000.00 62.65 332.49 1966.66 1691.24 N 931.71 W 0.00 1922.11 3475.26 62.65 332.49 2185.01 2065.64 N 1126.70 W 0.00 2341.27 3500.00 61.96 332.19 2196.51 2085.04 N 1136.86 W 3.00 2363.02 3600.00 59.16 330.95 2245.66 2161.62 N 1178.30 W 3.00 2449.63 3700.00 56.37 329.63 2299.00 2235.08 N 1220.21 W 3.00 2533.93 3800.00 53.60 328.23 2356.37 2305.23 N 1262.45 W 3.00 2615.69 3900.00 50.85 326.72 2417.62 2371.88 N 1304.93 W 3.00 2694.68 4000.00 48.12 325.09 2482.59 2434.83 N 1347.52 W 3.00 2770.69 4100.00 45.41 323.31 2551.08 2493.92 N 1390.11 W 3.00 2843.51 4200.00 42.73 321.36 2622.93 2548.99 N 1432.58 W 3.00 2912.93 4300.00 40.09 319.21 2697.92 2599.89 N 1474.82 W 3.00 2978.78 4400.00 37.50 316.80 2775.86 2646.46 N 1516.70 W 3.00 3040.86 4500.00 34.96 314.10 2856.52 2688.60 N 1558.12 W 3.00 3099.01 KOP Begin Turn 4600.00 32.48 311.04 2939.70 2726.18 N 1598.95 W 3.00 3153.07 4700.00 30.10 307.54 3025.15 2759.10 N 1639.10 W 3.00 3202.89 4781.14 28.24 304.32 3096.00 2782.32 N 1671.08 W 3.00 3240.10 4800.00 27.82 303.51 3112.65 2787.26 N 1678.44 W 3.00 3248.34 4900.00 25.67 298.85 3201.96 2810.60 N 1716.87 W 3.00 3289.28 EOC Base Permafrost Begin Turn & Drop to Target Top Ugnu Sands 5000.00 23.70 293.43 3292.83 2829.05 N 1754.29 W 3.00 3325.61 5100.00 21.94 287.15 3385.01 2842.55 N 1790.59 W 3.00 3357.23 5200.00 20.47 279.92 3478.26 2851.08 N 1825.67 W 3.00 3384.05 5237.09 20.00 277.00 3513.06 2852.97 N 1838.35 W 3.00 3392.76 End Drop & Turn 5437.09 20.00 277.00 3701.00 2861.30 N 1906.25 W 0.00 3437.92 Top West Sak Sands 5500.00 20.00 277.00 3760.11 2863.93 N 1927.60 W 0.00 3452.13 5588.19 20.00 277.00 3842.99 2867.60 N 1957.54 W 0.00 3472.05 5588.20 20.00 277.00 3843.00 2867.60 N 1957.54 W 0.00 3472.05 5897.88 20.00 277.00 4134.00 2880.51 N 2062.67 W 0.00 3541.98 6000.00 20.00 277.00 4229.96 2884.77 N 2097.34 W 0.00 3565.04 TARGET - West Sak A3 WS 1D-C3 Rvsd 22-Jan-98 Base West Sak Sands All data is in feet unless otherwise stated. Coordinates from slot #110 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Total Dogleg for we11path is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River U~it,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 6097.88 20.00 277.00 4321.94 2888.85 N 2130.56 W PROPOSAL LISTING Page 2 Your ref : WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 3587.14 TD - Casing Pt All data is in feet u~less otherwise stated. Coordinates from slot #110 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azlun~th 323.59 degrees from wellhead. Total Dogleg for we11path is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the m/nimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref ; WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Comments in we11path ========== HD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 390.00 1526 34 2317 29 3475 26 4781 14 5237 09 5437 09 5588 19 5588 20 5897 88 6097 88 389.65 4.27 N 7.40 W Begin Turn 1289.61 530.32 N 327.11 W EOC 1653.00 1153.41 N 651.61 W Base Permafrost 2185.01 2065.64 N 1126.70 W Begin Turn & Drop to Target 3096.00 2782.32 N 1671.08 W Top Ugnu Sands 3513.06 2852.97 N 1838.35 W End Drop a Turn 3701.00 2861.30 N 1906.25 W Top West Sak Sands 3842.99 2867.60 N 1957.54 W TARGET - West Sak A3 3843.00 2867.60 N 1957.54 W WS 1D-C3 Rvsd 22-Jan-98 4134.00 2880.51 N 2062.67 W Base West Sak Sands 4321.94 2888.85 N 2130.56 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6097.88 4321.94 2888.85N 2130.56W 7 5/8" Casing Targets associated with this we11path ================================ ..... Target nane Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C3 Rvsd 22-Jan 558510.000,5962560.000,0.0000 3843.00 2867.60N 1957.54W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 300.00 100.00 200.00 0.00 300.00 200.00 250.00 0.00 300.00 250.00 350.00 5.00 300.00 349.87 390.00 7.00 300.00 389.65 400.00 7.42 302.21 399.57 500.00 11.94 315.32 498.14 600.00 16.73 321.16 595.00 700.00 21.61 324.43 689.43 800.00 26.54 326.54 780.70 "900.00 31.49 328.03 868.13 1000.00 36.45 329.14 951.04 1100.00 41.42 330.03 1028.80 1200.00 46.39 330.75 1100.83 RECTANGULAR COORDINATES 44.00 N 596.00 W 44.00 N 596.00 W 44.00 N 596.00 W 44.00 N 596.00 W 46.18 N 599.78 W 48.27 N 48.92 N 59.72 N 78.29 N 104.50 N 603.40 W 604.47 W 617.21 W 633.52 W 653.27 W 138.14 N 676.32 W 178.96 N 702.48 W 226.64 N 731.56 W 280.83 N 763.35 W 341.11 N 797.58 W PROPOSAL LISTING Page 1 Your ref ~ WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 5.00 0.00 0.00 0.00 0.00 KOP 3.93 5.00 5.00 5.00 5.00 5.00 7.70 Begin Turn 8.84 24.94 49.48 82.26 5.00 123.03 5.00 171.50 5.00 227.28 5.00 289.95 5.00 359.04 1300.00 51.37 331.36 1166.57 407.02 N 834.02 W 5.00 434.02 1400.00 56.35 331.90 1225.52 478.07 N 872.37 W 5.00 514.32 1500.00 61.34 332.37 1277.24 553.70 N 912.34 W 5.00 599.32 1526.34 62.65 332.49 1289.61 574.32 N 923.11 W 5.00 622.42 E0C 2000.00 62.65 332.49 1507.23 947.46 N 1117.44 W 0.00 1040.16 2317.29 62.65 332.49 1653.00 1197.41 N 1247.61 W 2500.00 62.65 332.49 1736.94 1341.35 N 1322.57 W 3000.00 62.65 332.49 1966.66 1735.24 N 1527.71 W 3475.26 62.65 332.49 2185.01 2109.64 N 1722.70 W 3500.00 61.96 332.19 2196.51 2129.04 N 1732.86 W . 3600.00 59.16 330.95 2245.66 2205.62 N 1774.30 W 3.00 2449.63 3700.00 56.37 329.63 2299.00 2279.08 N 1816.21 W 3.00 2533.93 3800.00 53.60 328.23 2356.37 2349.23 N 1858.45 W 3.00 2615.69 3900.00 50.85 326.72 2417.62 2415.88 N 1900.93 W 3.00 2694.68 4000.00 48.12 325.09 2482.59 2478.83 N 1943.52 W 3.00 2770.69 0.00 1319.99 Base Permafrost 0.00 1481.13 0.00 1922.11 0.00 2341.27 Begin Turn & Drop to Target 3.00 2363.02 4100.00 45.41 323.31 2551.08 2537.92 N 1986.11 W 3.00 2843.51 4200.00 42.73 321.36 2622.93 2592.99 N 2028.58 W 3.00 2912.93 4300.00 40.09 319.21 2697.92 2643.89 N 2070.82 W 3.00 2978.78 4400.00 37.50 316.80 2??5.86 2690.46 N 2112.70 W 3.00 3040.86 4500.00 34.96 314.10 2856.52 2732.60 N 2154.12 W 3.00 ' 3099.01 4600.00 32.48 311.04 2939.70 2770.18 N 2194.95 W 3.00 3153.07 4700.00 30.10 307.54 3025.15 2803.10 N 2235.10 W 3.00 3202.89 4781.14 28.24 304.32 3096.00 2826.32 N 2267.08 W 3.00 3240.10 Top ~gnu Sands 4800.00 27.82 303.51 3112.65 2831.26 N 2274.44 W 3.00 3248.34 4900.00 25.67 298.85 3201.96 2854.60 N 2312.87 W 3.00 3289.28 5000.00 23.70 293.43 3292.83 2873.05 N 2350.29 W 3.00 3325.61 5100.00 21.94 287.15 3385.01 2886.55 N 2386.59 W 3.00 3357.23 5200.00 20.47 279.~2 3478.26 2895.08 N 2421.67 W 3.00 3384.05 5237.09 20.00 277.00 3513.06 2896.97 N 2434.35 W 3.00 3392.76 End Drop & Turn 5437.09 20.00 277.00 3701.00 2905.30 N 2502.25 W 0.00 3437.92 Top West Sak Sands 5500.00 20.00 277.00 3760.11 2907.93 N 2523.60 W 0.00 3452.13 5588.19 20.00 277.00 3842.99 2911.60 N 2553.54 W 0.00 3472.05 TARGET - West Sak A3 5588.20 20.00 277.00 3843.00 2911.60 N 2553.54 W 0.00 3472.05 WS 1D-C3 Rvsd 22-Jano98 5897.88 20.00 277.00 4134.00 2924.51 N 2658.67 W 0.00 3541.98 Base West Sak Sands 6000.00 20.00 277.00 4229.96 2928.77 N 2693.34 W 0.00 3565.04 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Total Dogleg for wellpath is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 6097.88 20.00 277.00 %321.94 2932.85 N 2726.56 W PROPOSAL LISTING Page 2 Your ref ~ WS 1D-110/C3 Vets. #6 Last revised = 3-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 3587.14 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from ~ (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Total Dogleg for wellpath is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the m/nimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = WS 1D-110/C3 Vets. #6 Last revised = 3-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 390.00 1526.34 2317.29 3475.26 4781.14 5237.09 5437.09 5588.19 5588.20 5897.88 609?.88 250.00 389 65 1289 61 1653 00 2185 01 3096 00 3513 06 3701.00 3842.99 3843.00 4134.00 4321.94 44.00 N 596.00 W K0P 48.27 N 603.40 W Begin Turn 574.32 N 923.11 W EOC 1197.41 N 1247.61 W Base Permafrost 2109.64 N 1722.70 W Begin Turn & Drop to Target 2826.32 N 2267.08 W Top Ugnu Sands 2896~97 N 2434.35 W End Drop & Turn 2905.30 N 2502.25 W Top West Sak Sands 2911.60 N 2553.54 W TARGET - West Sak A3 2911.60 N 2553.54 W WS 1D-C3 Rvsd 22-Jan-98 2924.51 N 2658.67 W Base West Sak Sands 2932.85 N 2726.56 W TD - Casing Pt Casing positions in string 'A' __ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 44.00N 596.00W 6097.88 4321.94 2932.85N 2726.56W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C3 Rvsd 22-Jan 558510.000,5962560.000,0.0000 3843.00 2911.60N 2553.54W 9-0ct-96 A~CO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C 00 R ANGULAR DINATES PROPOSAL LISTING Page 1 Your ref : WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 300.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 300.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 250.00 0.00 300.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 350.00 5.00 300.00 349.87 2.18 N 3.78 W 3.93 0.96 0.92 0.53 300.00 390.00 7.00 300.00 389.65 4.27 N 7.40 W 7.70 1.13 1.03 0.59 300.00 400.00 7.42 302.21 399.57 4.92 N 8.47 W 8.84 1.17 1.06 0.60 300.19 500.00 11.94 315.32 498.14 15.72 N 21.21 W 24.94 1.83 1.35 0.76 309.15 600.00 16.73 321.16 595.00 34.29 N 37.52 W 49.48 2.84 1.69 0.92 314.72 700.00 21.61 324.43 689.43 60.50 N 57.27 W 82.26 4.22 2.08 1.11 318.45 800.00 26.54 326.54 780.70 94.14 N 80.32 W 123.03 5.99 2.51 1.35 321.11 900.00 31.49 328.03 868.13 134.96 N 106.48 W 171.50 8.15 2.99 1.63 323.09 1000.00 36.45 329.14 951.04 182.64 N 135.56 W 227.28 10.70 3.51 1.99 324.64 1100.00 41.42 330.03 1028.80 236.83 N 167.35 W 289.95 13.64 4.04 2.44 325.87 1200.00 46.39 330.75 1100.83 297.11 N 201.58 W 359.04 16.95 4.58 2.98 326.87 1300.00 51.37 331.36 1166.57 363.02 N 238.02 W 434.02 -20.63 5.12 3.61 327.71 1400.00 56.35 331.90 1225.52 434.07 N 276.37 W 514.32 24.65 5.63 4.34 328.43 1500.00 61.34 332.37 1277.24 509.70 N 316.34 W 599.32 28.97 6.11 5.15 329.04 1526.34 62.65 332.49 1289.61 530.32 N 327.11 W 622.42 30.12 6.24 5.37 329.18 2000.00 62.65 332.49 1507.23 903.46 N 521.44 W 1040.16 51.05 8.44 9.40 330.57 2317.29 62.65 332.49 1653.00 1153.41 N 651.61 W 1319.99 65.13 9.92 12.12 330.94 2500.00 62.65 332.49 1736.94 1297.35 N 726.57 W 1481.13 73.24 10.77 13.68 331.16 3000.00 62.65 332.49 1966.66 1691.24 N 931.71 W 1922.11 95.45 13.09 17.97 331.47 3475.26 62.65 332.49 2185.01 2065.64 N 1126.70 W 2341.27 116.57 15.29 22.06 331.66 3500.00 61.96 332.19 2196.51 2085.04 N 1136.86 W 2363.02 117.66 15.41 22.27 331.66 3600.00 59.16 330.95 2245.66 2161.62 N 1178.30 W 2449.63 122.00 15.90 23.08 331.64 3700.00 56.37 329.63 2299.00 2235.08 N 1220.21 W 2533.93 126.22 16.42 23.84 331.57 3800.00 53.60 328.23 2356.37 2305.23 N 1262.45 W 2615.69 130.31 16.95 24.56 331.47 3900.00 50.85 326.72 2417.62 2371.88 N 1304.93 W 2694.68 134.25 17.49 25.22 331.33 4000.00 48.12 325.09 2482.59 2434.83 N 1347.52 W 2770.69 138.03 18.04 25.85 331.16 4100.00 45.41 323.31 2551.08 2493.92 N 1390.11 W 2843.51 141.63 18.60 26.42 330.96 4200.00 42.73 321.36 2622.93 2548.99 N 1432.58 W 2912.93 145.05 19.16 26.95 330.73 4300.00 40.09 319.21 2697.92 2599.89 N 1474.82 W 2978.78 148.25 19.71 27.43 330.48 4400.00 37.50 316.80 2775.86 2646.46 N 1516.70 W 3040.86 151.25 20.25 27.86 330.21 4500.00 34.96 314.10 2856.52 2688.60 N 1558.12 W 3099.01 154.02 20.77 28.25 329.91 4600.00 32.48 311.04 2939.70 2726.18 N 1598.95 W 3153.07 156.55 21.28 28.61 329.60 4700.00 30.10 307.54 3025.15 2759.10 N 1639.10 W 3202.89 158.86 21.77 28.92 329.26 4781.14 28.24 304.32 3096.00 2782.32 N 1671.08 W 3240.10 160.53 22.15 29.15 328.98 4800.00 27.82 303.51 3112.65 2787.26 N 1678.44 W 3248.34 160.92 22.24 29.20 328.91 4900.00 25.67 298.85 3201.96 2810.60 N 1716.87 W 3289.28 162.74 22.67 29.46 328.55 5000.00 23.70 293.43 3292.83 2829.05 N 1754.29 W 3325.61 164.32 23.08 29.68 328.17 5100.00 21.94 287.15 3385.01 2842.55 N 1790.59 W 3357.23 165.66 23.45 29.89 327.78 5200.00 20.47 279.~2 3478.26 2851.08 N 1825.67 W 3384.05 166.77 23.79 30.07 327.37 5237.09 20.00 277.00 3513.06 2852.97 N 1838.35 W 3392.76 167.14 23.92 30.14 327.22 5437.09 20.00 277.00 3701.00 2861.30 N 1906.25 W 3437.92 169.20 24.58 30.50 326.42 5500.00 20.00 277.00 3760.11 2863.93 N 1927.60 W 3452.13 169.85 24.80 30.62 326.16 5588.19 20.00 277.00 3842.99 2867.60 N 1957.54 W 3472.05 170.77 25.09 30.78 325.82 5588.20 20.00 277.00 3843.00 2867.60 N 1957.54 W 3472.05 170.77 25.09 30.78 325.82 5897.88 20.00 277.00 4134.00 2880.51 N 2062.67 W 3541.98 174.06 26.16 31.35 324.63 6000.00 20.00 277.00 4229.96 2884.77 N 2097.34 W 3565.04 175.16 26.51 31.54 324.24 411 data is in feet u~less otherwise stated. Coordinates from slot #110 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = WS 1D-110/C3 Vets. #6 hast revised = 3-Sep-98 Measured Inclin. Azimuth T=ue Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Vert Ellipse S~mi Axes Minor Sect Major Minor Vert. Azi. 6097.88 20.00 277.00 4321.94 2888.85 N 2130.56 W 3587.14 176.22 26.86 31.72 323.88 POSITION UNCERTAI1T~Y SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 6098 ARCO (H.A. Mag) User specified 176.22 26.86 31.72 1. Ellipse dimensions are half axis. 2. Casing dimensions are n~t included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations sta=t at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two sur~eys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trakmanual. All data is in feet unless otherwise stated. Coordinates from slot #110 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Vertical section is from wellhead on azimuth 325.68 degrees. Calculation uses the ~nlm~m curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = WS 1D-110/C3 Vets. #6 Last revised = 3-Sep-98 Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 390.00 389.65 4.27 N 7.40 W Begin Turn 1526.34 1289.61 530.32 N 327.11 W EOC 2317.29 1653.00 1153.41 N 651.61 W Base Permafrost 3475.26 2185.01 2065.64 N 1126.70 W Begin Turn & Drop to Target 4781.14 3096.00 2782.32 N 1671.08 W Top Ugnu Sands ~237.09 3513.06 2852.97 N 1838.35 W End Drop a Turn 5437.09 3701.00 2861.30 N 1906.25 W Top West Sak Sands 5588.19 3842.99 2867.60 N 1957.54 W TARGET - West Sak A3 5588.20 3843.00 2867.60 N 1957.54 W WS 1D-C3 Rvsd 22-Jan-98 5897.88 4134.00 2880.51 N 2062.67 W Base West Sak Sands 6097.88 4321.94 2888.85 N 2130.56 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00B 6097.88 4321.94 2888.85N 2130.56W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C3 Rvsd 22-Jan 558510.000,5962560.000,0.0000 3843.00 2867.60N 1957.54W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,110 Kupa=uk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-110/C3 Vets. Last revised : 3-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 560490.60 5959708.68 100.00 0.00 300.00 100.00 0.00N 0.00E 0.00 0.00 560490.60 5959708.68 200.00 0.00 300.00 200.00 0.00N 0.00E 0.00 0.00 560490.60 5959708.68 250.00 0.00 300.00 250.00 0.00N 0.00E 0.00 0.00 560490.60 5959708.68 350.00 5.00 300.00 349.87 2.18N 3.78W 5.00 3.93 560486.81 5959710.83 390.00 7.00 300.00 389.65 4.27N 7.40W 5.00 7.70 560483.17 5959712.89 400.00 7.42 302.21 399.57 4.92N 8.47W 5.00 8.84 560482.09 5959713.53 500.00 11.94 315.32 498.14 15.72N 21.21W 5.00 24.94 560469.27 5959724.22 600.00 16.73 321.16 595.00 34.29N 37.52W 5.00 49.48 560452.81 5959742.66 700.00 21.61 324.43 689.43 60.50N 57.27W 5.00 82.26 560432.85 5959768.71 800.00 26.54 326.54 780.70 94.14N 80.32W 5.00 123.03 560409.53 5959802.15 900.00 31.49 328.03 868.13 134.96N 106.48W 5.00 171.50 560383.04 5959842.75 1000.00 36.45 329.14 951.04 182.64~ 135.56W 5.00 227.28 560353.57 5959890.20 1100.00 41.42 330.03 1028.80 236.83N 167.35W 5.00 289.95 560321.35 5959944.12 1200.00 46.39 330.75 1100.83 297.11N 201.58W 5.00 359.04 560286.63 5960004.11 1300.00 51.37 331.36 1166.57 363.02N 238.02W 5.00 434.02 560249.67 5960069.72 1400.00 56.35 331.90 1225.52 434.07N 276.37W 5.00 514.32 560210.74 5960140.44 1500.00 61.34 332.37 1277.24 509.70N 316.34W 5.00 599.32 560170.16 5960215.74 1526.34 62.65 332.49 1289.61 530.32N 327.11W 5.00 622.42 560159.23 5960236.27 2000.00 62.65 332.49 1507.23 903.46N 521.44W 0.00 1040.16 559961.89 5960607.78 2317.29 62.65 332.49 1653.00 1153.41N 651.61W 0.00 1319.99 559829.70 5960856.65 2500.00 62.65 332.49 1736.94 1297.35N 726.57W 0.00 1481.13 559753.58 5960999.95 3000.00 62.65 332.49 1966.66 1691.24N 931.71W 0.00 1922.11 559545.27 5961392.12 3475.26 62.65 332.49 2185.01 2065.64N 1126.70W 0.00 2341.27 559347.26 5961764.90 3500.00 61.96 332.19 2196.51 2085.04N 1136.86W 3.00 2363.02 559336.94 5961784.21 3600.00 59.16 330.95 2245.66 2161.62N 1178.30W 3.00 2449.63 559294.88 5961860.44 3700.00 56.37 329.63 2299.00 2235.08N 1220.21W 3.00 2533.93 559252.39 5961933.56 3800.00 53.60 328.23 2356.37 2305.23N 1262.45W 3.00 2615.69 559209.57 5962003.35 3900.00 50.85 326.72 2417.62 2371.88N 1304.93W 3.00 2694.68 559166.56 5962069.64 4000.00 48.12 325.09 2482.59 2434.83N 1347.52W 3.00 2770.69 559123.46 5962132.25 4100.00 45.41 323.31 2551.08 2493.92N 1390.11W 3.00 2843.51 559080.39 5962190.98 4200.00 42.73 321.36 2622.93 2548.99N 1432.58W 3.00 2912.93 559037.48 5962245.70 4300.00 40.09 319.21 2697.92 2599.89N 1474.82W 3.00 2978.78 558994.84 5962296.24 4400.00 37.50 316.80 2775.86 2646.46N 1516.70W 3.00 3040.86 558952.58 5962342.47 4500.00 34.96 314.10 2856.52 2688.60N 1558.12W 3.00 3099.01 558910.83 5962384.27 4600.00 32.48 311.04 2939.70 2726.18N 1598.95W 3.00 3153.07 558869.69 5962421.51 4700.00 30.10 307.54 3025.15 2759.10N 1639.10W 3.00 3202.89 558829.29 5962454.10 4781.14 28.24 304.32 3096.00 2782.32N 1671.08W 3.00 3240.10 558797.12 5962477.05 4800.00 27.82 303.51 3112.65 2787.26N 1678.44W 3.00 3248.34 558789.72 5962481.94 4900.00 25.67 298.85 3201.96 2810.60N 1716.87W 3.00 3289.28 558751.11 5962504.96 5000.00 23.70 293.43 3292.83 2829.05N 1754.29W 3.00 3325.61 558713.54 5962523.10 5100.00 21.94 287.15 3385.01 2842.55N 1790.59W 3.00 3357.23 558677.14 5962536.31 5200.00 20.47 279.92 3478.26 2851.08N 1825.67W 3.00 3384.05 558641.99 5962544.55 5237.09 20.00 277.00 3513.06 2852.97N 1838.35W 3.00 3392.76 558629.30 5962546.34 5437.09 20.00 277.00 3701.00 2861.30N 1906.25W 0.00 3437.92 558561.34 5962554.12 5500.00 20.00 277.00 3760.11 2863.93N 1927.60W 0.00 3452.13 558539.97 5962556.57 5588.19 20.00 277.00 3842.99 2867.60N 1957.54W 0.00 3472.05 558510.00 5962560.00 5588.20 20.00 277.00 3843.00 2867.60N 1957.54W 0.00 3472.05 558510.00 5962560.00 5897.88 20.00 277.00 4134.00 2880.51N 2062.67W 0.00 3541.98 558404.78 5962572.05 6000.00 20.00 277.00 4229.96 2884.77N 2097.34W 0.00 3565.04 558370.09 5962576.03 #6 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #110 and TVD from P-KB (Parker #245) (112.00 Pt above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Total Dogleg for we11path is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kupar~k River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref ~ WS 1D-110/C3 Vets. #6 Last revised : 3-Sep-98 Dogleg Vert G R I D C 0 0 R D S Deg/100ft Sect Basting Northing 6097.88 20.00 277.00 4321.94 2888.85N 2130.56W 0.00 3587.14 558336.83 5962579.83 All data in feet unless otherwise stated. Calculation uses min/mmm curvature method. Coordinates from slot #110 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 3589.53 on azimuth 323.59 degrees from wellhead. Total Dogleg for we11path is 116.67 degrees. Vertical section is from wellhead on azimuth 325.68 degrees. Grid is al&ska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,110 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : WS 1D-110/C3 Vers. #6 Last revised : 3-Sep-98 Comments in we11path MD TVD Rectangular Coords. Comment 250.00 250.00 0.00N 0.00E KOP 390.00 1526 34 2317 29 3475 26 4781 14 5237 09 5437 09 5588 19 5588 20 5897 88 6097.88 389.65 4.27N 7.40W Begin Turn 1289.61 530.32N 327.11W EOC 1653.00 1153.41N 651.61W Base Permafrost 2185.01 2065.64N 1126.70W Begin Turn & Drop to Target 3096.00 2782.32N 1671.08W Top Ugnu Sands 3513.06 2852.97N 1838.35W Bud Drop & Turn 3701.00 2861.30N 1906.25W Top West Sak Sands 3842.99 2867.60N 1957.54W TARGET - West Sak~t~ 3843.00 2867.60N 1957.$4W WS 1D-C3 Rvsd 22-Jan-98 4134.00 2880.51N 2062.67W Base West Sak Sands 4321.94 2888.85N 2130.56W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6097.88 4321.94 2888.85N 2130.56W 7 5/8" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-C3 Rvsd 22-Jan 558510.000,5962560.000,0.0000 3843.00 2867.60N 1957.54W 9-0ct-96 ARCO Alaska, Inc. Pad 1D 110 slot #110 Kupar~k River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref = WS 1D-110/C3 Vets. #6 Our ref = prop2216 License : Date printed : 3-Sep-98 Date created : 17-Apr-97 Last revised : 3-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 1.749,w149 30 36.284 Slot Grid coordinates are N 5959708.680, E 560490.602 Slot local coordinates are 44.00 N 596.00 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke o 1866 Reference North is True North Object we11path PMSS <377 - 6224'>,,134,Pad 1D PMSS <0 - 6472~>,,131,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0-4414~>,,121,Pad 1D PMSS <0-4530~>,,120,Pad 1D PMSS <O-4515~>,,119,Pad 1D PMSS <O-4590~>,,118,Pad 1D PMSS <O-5205'>,,117,Pad 1D PMSS <O-4850~>,,109,Pad 1D PMSS <O-5126~>,,106,Pad 1D PMSS <381-6092~>,,105,Pad 1D PMSS <1957-5265~>,,133,Pad 1D PMSS <O-5015'>,,135,Pad 1D PMSS <O-5047~>,,124,Pad 1D TOTCO Survey,,WS-8,Pad 1D P~MS <O-8365~>,,1,Pad 1D PGMS <O-8950~,,5,Pad 1D PGT&S <O-8610~>,,6,Pad 1D MSS <3311-8200~>,,7,Pad 1D PMSS <556-7024~>,,9,Pad 1D PMSS <0 - 7340~>,,10,Pad 1D PMSS <O-5462">,,129,Pad 1D PMSS <O-4778'>,,130,Pad 1D PMSS <0 - 6716'>,,126,Pad 1D PMSS <0 - 7432~>,,127,Pad 1D PGMS <O-9783~>,,2,Pad 1D PGMS <O-7502~>,,4,Pad 1D PMSS <0-5142~>,,115,Pa~ 1D Closest approach with 3-D Last revised Distance 3-Aug-98 554.4 23-Jul-98 465.0 6-Aug-98 480.0 2-J~ul-98 224.7 2-Jun-98 209.8 2-Jun-98 194.5 2-Jun-98 150.0 2-Jun-98 133.9 2-Jun-98 13.4 2-Jun-98 51.9 2-Ju.n-98 87.0 2-Ju.n-98 492.6 2-Jun-98 570.0 2-Jun-98 314.2 21-May-98 647.0 10-Dec-97 119.3 13-Nov-97 287.1 13-Nov-97 407.2 6-Nov-97 527.0 29-Apr-98 180.0 28-Apr-98 600.0 2-Jun-98 434.4 2-Jun-98 450.0 1-Jul-98 344.4 6-Jul-98 358.7 4-Aug-92 56.2 4-Aug-92 167.1 2-Jun-98 101.0 Minimum Distance method M.D. 250.0 100.0 100.0 275.0 250.0 275.0 100.0 275.0 400.0 575.0 450.0 275.0 100.0 275.0 100.0 875.0 0.0 100.0 250.0 250.0 100.0 250.0 250.0 275.0 275.0 575.0 100.0 450.0 Diverging from M.D. 250.0 100.0 100.0 275 0 250 0 5588 2 100 0 275 0 5588 2 575 0 450.0 275.0 100.0 275.0 100.0 6060.0 0.0 100.0 250.0 6097.9 100.0 250.0 250.0 275.0 275.0 575.0 100.0 450.0 PMSS <0 - 6580t,,,128,Pad 1D PMSS <291 - 5795~,,125,Pad 1D PGMS <0-8070'~,,3,Pad 1D PMSS <0 - 5445'),,122,Pad 1D PMSS <0 - 6270'),,114,Pad 1D PMSS<O-7045~>,,111,Pad 1D PMSS <O-??~,,123,Pad 1D 17-Aug-98 19-Augo98 13-Aug-98 29-Aug-98 2-Sep-98 3-Sep-98 3-Sep-98 374.8 328.2 46.7 240.0 90.0 15.0 255.0 250.0 275.0 250.0 100.0 100.0 200.0 100.0 250.0 275.0 6097.9 5780.0 6097.9 200.0 100.0 ?-5/8" 5000 psi BOP Kuparuk River Unit West Sak Operations - Producer Wells L, J 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" x 13-5/8" 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8" 5000 psi x 13-5/8" 5000 psi Spacer Spool 5. 13-5/8" 5000 psi Pipe Rams 6. 13-5/8" 5000 psi Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.1 '._J" DIVERTER SCHEM,_ ;lC Kuparuk River Unit West Sak Operations 6 4 3 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20" - 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16" Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line WilI Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20" - 2000 psi Annular Preventer TAB, 06/12/98, v.2 · i ii ~ 'OUl 'eXselV 03ur i · N "i II $1H./ O-I '$*0 KUPURKiK TOOL HOUSE' ;'KIX 0;'-27'-98 r, C~A FE$ 5HOHN AlE A IP. ZONE CEA--OIDX-6104OI$ FOR ~113R~ 9 a~ I0, AND 7H15 14, 7'.11 N.. R. IO E. , ya,(n' 5.9~9. e5..~ ~/ 560.49G89, Pi ARCO Alaska, Inc. Fit.£ ND. DRAMN~ NO: 1_1(6104,16 ,~~,~,,,LOU1VSBURY & AS'SOcI&'FES. INC. kqF. A: ti} kl00ULE: ~ SNC ~ lB - 'AGL CCN)4JCTCRS .~S-BUILT LOCAl10NS SHEET= REV:. CEA-DIDX-6104016 2 ~ 2 UNiT: D! ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Sept 8, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-110 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designated as a monobore production well using a single 7 5/8" casing string, with 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-110, such as shallow gas. There have been ten (10) Kuparuk wells and (22) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only.R E F IV E D ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SEP 09 1998 Alaska Oil & Gas Cons. Commission 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is September 23, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Sincerely, Scott Goldberg /,' _~J Operations Drilling Enginee'r~ CC: West Sak 1 D-110 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 · WELL PERMIT CHECKLIST ,,¢£6/ COMPANY /~7¢~'_.: c~ ,WELL NAME -, . "///20 ,,, PROGRAM: exp [] dev~'redrll [] serv [] wellbore segl, ann. disposal para I,IT CLASS 0~¢.~,u," ,/c, O,// GEOL AREA C-4/ ? O UNIT# ///__~ O O,/OFr SHORE ADMINISTRATION 1. Perrnit fee attached ....................... 2. I. ease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... ' 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... '15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... N N .,D~TE GEOLOGY 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 300 ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y(~ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N,// 31. Data presented on potential overpressure zones ....... ~Y,~,Y 2'. 33. Seabed condition survey (if off-shore) ............. Y N .... 34. Con, tact.nam, e/phon,e.for weekly progress repods ....... lexploramry only] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N .......... pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE G E 0,.~?~GY: ENGINEERING: UIC/Annj~ COMMISSION: RP~ BEW<~ ~,~'~; WM,'/'~ DWJ JDH ,,-..--- R N C_______,~ ~/g,(".,.~ co ~~ M ,':hel~l~sl mv 05/2919~] dlf (: \rH';~ltlll ~\wl)l(Jl;~tl\lJl;irl;l\, h,!~ Com mentsll nstructions :,