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BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • APi; ~ ~` ~~ I~ G?~ GC's, t.~eai:t:c ,, ..~ AI~CI10ti~ ~6 c~~ ~' ~' `~ , ~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets. the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K~ lein - ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-036 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company' Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 10/31/03 Well Job # Log Description Date BL Color CD 1Y-19 ~ ~"~-1(~-~ PRODUCTION PROFILE/DEFT 10109103 1 3A-04 ~_~_c~_"~_ INJECTION PROFILE 10111/03 1 3B-03 ~ c~(Qp 'PRODUCTION PROFILE/DEFT 10113103 3.-08 t~-~ PRODUCTION PROFILE 10/14103 1 3A-05 l~-~ I PRODUCTION PROFILE 10/15103 1 3.-0e ~ ~-O~ P"ODUCT~ON PROF,LE ~0/~e/03 2T-21 1 ~ ~ LEAK DETECTION LOG 10117/03 1 1 E-20 ~~ SBHP SURVEY , 10/20/03 1 31-11)~ 'O~ LEAK DETECTION LOG 10/25/03 1 3e-o. ~EO-~'P"ODUCT~ON P"OmLE ~0/~S/03 3~'~ /~O~TD P"ODUCT~ON P"OF~LE IB-20 ~-~ PERF RECORD/STATIC SURVEY 10/30/03 I SIGNE .. . ~ (3~~.~ ~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission. TO: THRU: FROM: Julie Heusser, ~,~x; commissioner Tom Maunder, ~~~ P. I. SuPervisor. ~1o~.. ChuCk Scheve; PetrOleum-InspectOr DATE: SUBJECT: January 7, 2001 Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sunday, january 7, 2001 I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve System testing on 3A & 3B Pads. As the attached AOGCC Safety valve sYstem Test Reports indicate I Witnessed the testing of 8 Wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure obserVed: The sUrface safety valve on well 3A-08 had a slow leak when pressure tested.. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test procedure and was a pleasure to'Work with ' The Wellhouses on these two pads'were very clean and all related equipment appeared to be in good condition.' summary: I Witnessed the Semi annual SVS testing at 3A & 3B Pads in the KUparuk River. Field: KRU 3A Pad, 8 wellS, 16 components, 1 failure KRU 3B Pad, 6 wells' 12 components. 0 failures 19 wellhouse inspections Attachment: SVS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad: 1-7-01 CS X UnclasSified Confidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report operator: Phillips: Operator ReP: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: KuParuk / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, NUmber NUmber PSI PSI ·Trip Code Code Code Passed GAS or CYCLE 3~-01 1851860 64 70 50 P P OIL 3A-03 1852060 3A-05 -1852210 64 70 50 P P OIL 3A-08 1852240 · 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810 64 70 40 'P P OIL 3A-16 1852840 64 70 70 'p p oIL 3A-17 1961320 ' 3A-18 1961330 64 70 50 P P OIL Wells: Remarks: 8 CompOnents: 16 Failures:. 1 Failure Rate: 6.3% [] 90 var Surface Safety Valve on well 3A-08 had a slow leak when tested, vzlve to be service retested' by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls Alaska Oil and Gas ConserVation CommiSsion Safety-Valve SyStem Test Report Operator: PhilliPs' Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit SePar Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3B-03 1850600 64 70 60 P P OIL 3B-04 , 1850610 64 70 50 P P OIL 3B-06 1850760 . 64 70 S0 P P ' OIL ~,~,-08 1.850870 3B-09' 1851130 64 70 . 70 P P"' OIL 3B'll 1851150 64 70 50 P ' ' P OIL! 3i~-13 1850230 3B-14 1850240 , ,, Wells: 6 ComponentS: 12 Failures: 0 Failure Rate: Remarks: Good'Test Oat,~ I r~f 1 SVS KRU 3B Pad 1-7-01 CS.xls STATE OF ALASKA AL/-~,SKA OIL AND GAS CONSERVATION COMMISb~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 575' FSL, 762' FEL, Sec 7, T12N, RgE, UM At top of productive interval 1291' FNL, 1320' FEL, Sec 17, T12N, R9E, UM At effective depth 1377' FNL, 1063' FEL, Sec 17, T12N, R9E, UM At total depth 1400' FNL, 996' FEL, Sec 17, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8660 6376 6. Datum elevation (DF or KB) RKB 73 7. Unit or Property name Kuparuk River Unit 8. Well number 3^-05 9. Permit number/approval number 85-221 10. APl number 50-029-21442 11. Field/Pool feet feet feet Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8 5 5 4 true vertical 6298 feet feet Junk (measured) None Casing Length Structural Conductor 8 0' Surface 3 9 4 9' Intermediate Production 8 6 1 7' Liner Perforation depth: measured 8173'-8213', true vertical 6024'-6052', Size Cemented 16" 185SxAS II 9.625" 1100 Sx AS III & 400 Sx Class G 7" 400 Sx Class G & 250 Sx AS I Measured depth True vertical depth 104' 1 04' 3975' 3234' 8641' 6362' 8220'-8312', 8362'-8388', 8407'-8442' 6057'-6121', 6157'-6176', 6189'-6215' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8303' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 8090' & Baker 'FB-I' @ 8256'; SSSV: Baker'FVL'@ @ 1808' 13. Stimulation or cement squeeze summary .,. · . Fracture stimulated 'C' sand on 11/7/96. ORIGINAL Intervals treated (measured) 8173'-8213', 8220'-8312' Treatment description including volumes used and final pressure Pumped 48.5 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 6450 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing pressure Prior to well operation 48 1 2 6 142 1075 167 Subsequent to operation 373 140 102 1095 161 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. status of well classification as: Oil X Gas Suspended Service 17. I hereby/~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~ TiUe Wells Superintendent Form ly464tr R~gv""06'/~5/81~ SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Plugging Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 575' FSL, 762' FEL, Sec 7, T12N, R9E, UM At top of productive interval 1291' FNL, 1320' FEL, Sec 17, T12N, R9E, UM At effective depth 1377' FNL, 1063' FEL, Sec 17, T12N, R9E, UM At total depth 1400' FNL, 996' FEL, Sec 17, T12N, R9E, UM ORIG 12. Present well condition summary ~Total Depth: measured true vertical 8660 fe&t 6376 feet Perforate Other INAL 6. Datum elevation (DF or KB) RKB 73 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-05 9. Permit number/approval number 85-221 10. APl number 5o-029-21442 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None -. Effective depth: measured trUe vertical 8554 feet 6298 feet 'Junk (measured) None Casing Length Structural Conductor 8 0' Surface 3 9 4 9' Intermediate Production 8 61 7' Liner Perforation depth: measured 8173'-8213', true vertical 6024'-6052', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 8303' Packers and SSSV (type and measured depth) PKR: Size Cemented Measured depth 1 6" 185 Sx AS II 104' 9.625" 1100 Sx AS III & 3975' 400 Sx Class G 7" 400 Sx Class G & 8641' 250 Sx AS I 8220'-8312', 8362'-8388', 8407'-8442' 6057'-6121', 6157'-6176', 6189'-6215' Baker 'FHL' @ 8090' & Baker 'FB-I' @ 8256'; SSSV: Baker 'FVL' @ @ 18'08' True ve~ical depth 104' 3234' 6362' RECEIVED MAY 0 7 1996 13. Stimulation or cement squeeze summary Re-fracture stimulated 'A' sand on 1/27/96. Intervals treated (measured) 81 73'-821 3', 8220'-831 2' .. Treatment description including volumes used and final pressure Pumped 121 Mlbs of 20/40,16/20 & 12/18 ceramic proppant into formation,'fp 'was 5259 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-IVIcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 488 41 1 10 1297 166 Subsequent to operation 7 6 9 239 8 1297 174 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~~' ~'~J Title Wells Superintendent Form 10-404 Rev 06/15/88 Date ~~',,,~,~ SUBMI'~ IN DUPLICATE ARCO Alaska, Inc. 'KUPARUK RIVER UNIT WELL SERVICE. REPORT '~' K1(3A-05(W4-6)) WELL JOB SCOPE JOB NUMBER 3A-05 FRAC, FRAC SUPPORT 1 122951518.2 DATE DAILY WORK UNIT NUMBER 01/27/96 RE-FRAC A SAND DAY OPERATION COMPLETE ! SUCCESSFUL KEY PERSON SUPERVISOR 6 (~ Yes ['~) NoI (~) Yes O No DS-GALLEGOS FITZPATRICK FIELD AFC~ ~ DALLY COST ACCUM COST Signed ,,,~ J~'.-/---~. ¥, ESTIMATE 998506 23ODS36AL $1 1 1,145 $247,455 Initial 'l'b.ci Press Final Tba Press Initial Inner Ann Final Inner Ann I Initial Outer Anr~..~ Fia~0uter Ann 0 PSI 0 PS! 0 PSI 0 PSII 0 PSI! 0 PS! DALLY SUMMARY JA SAND RE-FRAC COMPLETE. FLUSHED EARLY DUE TO EXCESSIVE TREATING PRESSURE. PLACED 120,843 lbs. PROP IN FM, I I LEFT 992 lbs. IN CSG w/8 PPA 12-18 @ PERFS. TOTAL 1679 BBL. SLURRY PUMPED. TIME 06:30 10:00 11:00 11:27 12:53 14:47 19:00 LOG ENTRY MIRU DOWEL[_, HOT OILER. VAC TRUCK, &c. HELD SAFETY MEETING SET, TREE SAVER, PRIME PUMPS, TEST LINES TO 7450 PSI. HOT OILER TIED INTO 7" CSG LINE TO PRV SKID, HOLDING -3200 PSI. PUMP 392 BBL CONDITIONING STAGE @ 15 BPM W/3968 LBS. 20-40 PROP. MAX 6637 PSI, FINAL 3812 PSI. ISIP 2600 PSi. DOWELL YF150D. PUMP 185 BBL DATA FRAC @ 15 BPM. MAX 5405 PSi, FINAL 3950 PSI. ISIP 2650 PSI. PUMP 1102 BBL FRAC @ 15 BPM. DOWN TO 11.2 BPM W/6000 LBS. 20-40, 67300 IRS. 16-20, & 48535 LBS. 12-18. PLACED 120,843 IRS. IN FORMATION, LEFT 992 IRS. IN CSG W/8 PPA @ PERFS. MAX 6637 PSI, FINAL 5259 PSI. ISIP 3354 PSI. RD HOT OILER, LEAVING 1000 PS! ON 7" CSG. PULLED TREE SAVER, RECOVERING ALL CUPS. CLEAN UP & RD MNES, PUMPS, &c. WELL SECURED. RECEIVED SERVICE COMPANY - SERVICE APC-LABOR APC-PUMPING APC-TRUCKING DIESEL DOWELL-COILED TUBING DOWELL-ST1MULATION GELLED DIESEL HALLIBURTON LI'I-I'LE RED HOT OIL TOTAL FIELD ESTIMATE DAILY COST I ACCUM TOTAL $1 STATE OF ALASKA 0 ALAol<A OIL AND ~S CONSERVATION COMMI~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well 0 t h e r 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 575' FSL, 762' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1291' FNL, 1320' FEL, Sec. 17, T12N, R9E, UM At effective depth 1376' FNL, 1067' FEL, Sec. 17, T12N, R9E, UM At total depth 1400' FNL, 996' FEL, Sec. 17, T12N, R9E, UM 12. Present well condition summary 13. 6. Datum elevation (DF or KB) Total Depth: measured 8 6 6 0' true vertical 6 3 7 6' Effective depth: measured 85 5 4' true vertical 6 2 2 5' : Casing Length Size Structural Conductor 7 2' 1 6" Surface 3 94 3' 9 5/8" Intermediate Production 8 6 0 9' 7" Liner Perforation depth: measured 8173'-8220', true vertical 6024'-6057', feet feet feet feet 8362'-8388', 6157'-6176', Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 EUE, w/ tbg tail at 8283' Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) RKB 73 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-05 feet 9. Permit number 85-221 10. APl number 5o-029-21 442 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 185 Sx AS II 104' 104' 1100 Sx AS III & 3975' 3234' 400 Sx Class G 400 Sx Class G & 8 6 41' 6 267' 250 Sx AS I 8404'-8442' 6187'-6215' RECEIVED MAY - 6 3992 Alaska.Oil & Gas Cons. SSSV: Baker FVL @ 1808', PACKERS: Baker FHL @ 8090', Baker FB-1 @ 8256' Stimulation or cement squeeze summary Intervals treated (measured) A SAND REFRAC: 8362'-8388', 8404'-8442' 14. Treatment description including volumes used and final pressure Refrac w/690 bbl Pad, 347 bbl slurry carrying 70~500 pounds 12/18 proppant. Final Pressure 4812 psi. Re_oresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. 450 250 0 1140 110 700 .~' 480 0 1200 16. Status of well classification as: Water Injector w Oil X Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 110 Form 10-404 Rev 09/12/90 Title Operations Engineer SUBMIT IN DUPLICATE R~ ~rt of Sundry Well Ope, ~ons Kuparuk River Unit Well 3A-05 April 22, 1992 On September 23, 1991, ARCO Alaska, Inc. performed an A Sand refracture treatment on Kuparuk Well 3A-05. The perforated A Sand intervals open to the refracture were from 8362' to 8388' and from 8404' to 8442' MD- RKB. The treatment was run with 690 bbl of pad followed by 347 bbl of slurry carrying 76,000 pounds proppant, of which 70,500 pounds went into formation. The remaining proppant was subsequently cleaned out of the tubing. The final pressure was 4812 psi. This Report of Sundry Well Operations is filed notifying you of refracture work completed. RECEIVE. D M AY - 6 1992 Alaska 0il & Gas Cons. C0mt~ss'to~ Anchorage ARCO Alaska, Inc. ) Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ~;ONTRACTOR///// / JFIELD - D~T~C~ STATE O P ERATI O N~~P~T~ E IPBDT REMARKS ! U~y - 6 1992 Anchorage [-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. !Chill Factor I Visibility °1=I °1=, milesI wind vel' knots i Sig~'~... REMARKS CONTINUED: ~: .. DESC RI PTION DAILY ACCU M. TOTAL :CAMCO 0TIS .. SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE :. TOTAL FIELD ESTIMATE -' / a ',~, OIL AND GAS CONSERVATION COMI ';ION REPORT OF SUNDRY WELL OPERATION"S 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown__ Stimulate X Pull tubing_ Alter casing __ Repair well 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 575' FSL, 762' F EL, Sec. 7, T12N, R9E, UM At top of productive interval 1291' FNL, 1320' FEL, Sec. 17, T12N, R9E, UM At effective depth At total depth 1400' FNL, 996' FEL, Sec. 17, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8660' feet 6376' feet Plugging __ Perforate _ Pull tubing __ Other 6. Datum elevation (DF or KB) RKB 73 7. Unit or Property name Kuparuk River Unit 8. Well number/~ 3A-05 ~f~,~ .I. ~, ~ ~ 9. Permit number 85-221/~)-425 10. APl number 50-02921 442 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Cement: Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural 7 2' Conductor Surface 3 9 4 3' Intermediate Production 8 6 0 9' Liner Perforation depth: measured 8173'-8220' true vertical 6024'-6057' Tubing (size, grade, and measured depth 3.5", 9.3#, J-55 EUE, 8283' Packers and SSSV (type and measured depth) Size 16' 9 5/8" 7" Cemented 185 sx AS II Measured depth True vertical depth 104' 104' 1100 sx AS III & 3975' 400 sx Class G 400 sx Class G 1 0 0 5 2' 250 sx AS I 3234' 6267' 8362'-8388' 6157'-6176' 8404'-8442' 6187'-6215' RECEIVED 3 U L 2 o 1989 SSSV: BAKER FVL 1808', PACKERS: BAKER FHL 8090', BAKER FB-1 8256' Alaska 0JJ .& Gas Cons. Commission 13. Stimulation or cement squeeze summary ,,. Anchorage Intervals treated (measured) 8362'-8388', 8404'-8442' Treatment description including volumes used and final pressure See attached stimulation summary 14. Re_oresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation I 65 1 1 7 0 977 1 33 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 555 462 0 1320 16. Status of well classification as: Oil X Gas __ Suspended __ Service 140 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~Ined , , . . - ~- ~z-,~'~c~ltle Date Form 10-404 Rev ¢?06/15/88 IN DUPLICATE WELL OPERATION REPORT SUMMARY WELL 3A-05 DATE OPERATION SUMMARY 04MAY89 TAGGED FILL @ 8422', BTM PERF @ 8442'. PULLED AVA COM SLV, FOUND SCALE ON SLV. RAN BLK SLV. 07MAY89 COMPLETED PRE-FRAC CTU. CLEANED OUT SAND FROM 8402'-8537' CTM. PUMPED 267 BBLS GEL DIESEL, 82 BBLS CLEAN DIESEL. 09MAY89 RIH TO TAG FILL, ENCOUNTER THICK FLUIDS, DISPLACE TBG W/ 70 BBLS DIESEL. PARTED WIRE, RECOVERED FISH. TAG FILL @ 8498' WLM (8522' RKB), BTM PERF @ 8442'. 10MAY89 PULLED GLV'S AND DUMMIED MANDRELS FOR FRAC. SET PLUG IN D-NIPPLE FOR TUBING PRESSURE TEST. llMAY89 PRESSURE TEST TUBING TO 2000 PSI, OK. WELL READY FOR FRAC. PULLED A-2 BLANKING PLUG. 12MAY89 GELLED DIESEL FRAC COMPLETE (HALLIBURTON) 3-1/2" TUBING PUMPED 511 BBLS GD, 41500# 16/20 CARBOLITE IN 2 THROUGH 12 PPG STAGES @ 25 BPM. SD FOR ISIP, TREATING PR= 4200 PSI, ISIP=2310 PSI, FG=0.73, PERF FRICTION = 482 PSI. SCREENED OUT 3 BBLS INTO FLUSH. POST JOB SHOWED THAT GEL RATE WAS ONLY 9.4 GPT, INSTEAD OF 10. THIS MAY HAVE ATTRIBUTED 'TO THIN GEL. PUMPED 19500# IN FORMATION, LEFT 220005 CARBOLITE IN TUBING. 17MAY89 cTu CO COMPLETE - PUMPED 482 BBLS, RETURNS = 467 BBLS, LOST 15 BBLS. CLEANED OUT TO 8570' CTU MEASURE. 20MAY89 POST CTU TAG @ 8507' RKB, BTM PERF @ 8442'. 20JUN89 RAN NEW GL STRING PER DESIGN. TAGGED FILL @ 8522', BTM PERF @ 8442'. ARCO.Alaska, Inc. Date: July 7, 1989 Transmittal #: 7505 RETURNTO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 02 Kuparuk Fluid Level Report 6 - 21 - 89 Casing 30-04 Kuparuk Fluid Level Report 6 - 21 - 89 Casing 3 J - 06 Kuparuk Fluid Level Report 6 - 21 - 89 Casing 3A-05 Kuparuk Fluid Level Report 6- 21 - 89 Casing 1E-20 Kupaurk Fluid Level Report 6-28-89 Tubing 1 E- 20 Kuparuk Fluid Level Report 6 - 28 - 89 Casing 0ii & Gas Cons. Commis,~Jor~ Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M sssv 13b~' DV or GLV 0¢ 0¢ 0¥ Fluid Level Found @ ~j?..~ Ft CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman KUPARUK FLUID LEVEL REPORT Well ~-5 Date ~ I~-~ b¢[ Fluid Level Shot Down: ~ Casing Tubing CSG Press During Shot = \;5~'(_.b .# TBG Press During Shot = .# Reason, F/q~Shooting FL: I/ To Determine Operating Valve Well Status: ~/'On Continuous GL Operating CSG Press= \.~O GL Rate (If Available)= On Intermittent GL On Time=~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle No GL # MCFD Min. Comments: /~-i~ska Oil & Gas Cons. · STATE OF ALASKA 0 ~. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X_~ Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska1 In(;:. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 575' FSL, 762' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1291' FNL, 1320' FEL, Sec. 17, T12N, R9E, UM At effective depth At total depth 1400' FNL, 996' FEL, Sec. 17, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 7;~ 7. Unit or Property name Kuparuk River Unit 8. Well number eet 9. Permit number 85-221 10. APl number 5o-029-21 442 11. Field/Pool Kuparuk River Field Kuparuk River O!,~;R0o,..~, ! 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8660' 6376' feet feet feet feet Plugs (measured) Cement: Junk (measured) Casing Length Size Structural 7 2' I 6" Conductor Surface 3943' 9 Intermediate Production 8 6 0 9' 7" Liner Perforation depth: measured 8173'-8220', true vertical 6024'-6057', Cemented Measured depth True vertical depth 185 sx AS II 104' 104' 5/8" 1100SxAS III & 400 Sx Class G 400 Sx Class G 250 Sx AS I 8362'-8388', 8404'-8442' 6157'-6176', 6187'-6215' Tubing (size, grade, and measured depth 3.5", 9.3#. J-55 EUE, 8283' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1808', Packers: BAker FHL 8090', Baker FB-1 8256' 13. Attachments Description summary of proposal Fracture stimulation of A Sand. 3975' 3234' 1O052' 6267' ~. ,.~, ~-~ ~- 'r; ..'.' i':- ~ _. Detailed operation program _ ~.,~~etch _ 14. Estimated date for commencing operation May 10. 1989 oi~ x___ 16. If proposal was verbally approved Name of approver ~. i~ ;'i& Date approved Service 17. I hereby certi~ that the foregoing is Eue and correct to the ~st of my knowledge. F~ ~MMI~D~E ONLY Conditions of approval: Noti~ Commission so representative may witness 15. Status of well classification as: Gas ~ Suspended Plug integrity ~ Mechanical Integrity Test BOP Test Location clearance __ Subsequent form require 10- Approved by the order of the Commission Form 10-403 Rev 5/03/89 0RIGIN^I. SIGNED BY I fll~MIl= t', Approved Copy ReturnS. Commissioner JApproval No. SUBMIT IN TRIPLICATE 3A-05 Refrac Sundry Attachment Kuparuk Well 3A-05 is scheduled for a fracture treatment of the A Sand Interval. A Pump Schedule for the job is attached. No workover fluids will be required for this stimulation treatment. Expected Reservoir Pressure for the 3A-05 area is 2600 psi. WELL 3A-05 FRAC DATA TABLE STAGE CLEAN VOLUME PROPPANT DIRTY VOLUME CUMULATIVE STAGE HITS (B B L) (POUNDS) (B B L) DIRTY VOL (BBL) PERES @ (BBL) BREAKDOWN 1 20 0 120 120 7 5 SD FOR ISIP (30 MINUTES TO ALLOW LEAKOFF OF PREPAD), PROVE FLOWMETERS PAD 230 0 230 350 195 SLURRY 2 PPG 18.4 1544 20 370 425 4 PPG 25.5 4285 30 400 445 6 PPG 27.7 6975 35 435 475 8 PPG 29.6 9936 40 475 510 10 PPG 48.6 20405 70 545 ~§0 FLUSH 7 3 0 7 3 61 8 .~ ~'~ ~"' TOTAL 573 43145 61 8 VOLUME TO PERFS (BBL) = 74.8 ,~."~ ~..:.:' c~,,'~,, PROPPANT = 16/20M CARBOLITE PUMP RATE = 25 BPM BREAKDOWN ~ GD + 40 LB/,1000 GAL OIL, ICA FLOUR + 8,HR BREAKER PAD = GD +, 40 LB/1000 G,AL SILICA FLOUR + 8 HR BREAKER SLURRY = GD + BREAKER , (NO SILICA ,FLOUR) LO TEMP BREAKER DURING L, AST HALF OF, FLUSH , 5/2/89 MEMORANDUM THRU: FROM: StatP-of Alaska ALASKA o~L A~nD GAS CONSERVATION COb~.-~£SSION C. V. ~h~ton DATE: February 2, 1987 Chairm~r Lonnie C. smith J?- Commissioner Bobby D. Foster~ - Petroleum. Inspector FILE NO.: D.BDF.8 TELEPHONE NO.: SUBJECT: BOP Test ARCO KRU 3A-5 Permit #86-196 Kuparuk River Field Friday, January 23, 1987: The BOP test began at 12=00 a.m. and was c~n~luded at"l:00 a.m, As the attached BOP test report shows, there were no failures. In summary, I Witnessed the BOP test on ARCO's 3Q-5. Attachment 02-001 A(Rev 10-84) STATE OF ALASKA ~ALASKAOIL & C~ CONSERVATION C.099~.~S$ION B.O.P.£. Inspection Report Location Oeneral ~ J~ ' , Well $ign~_~ Reserve Pi: Mud Svst~s Trip Tank Pi: Cauge Cas Detec:ors Visual Audio _. o . BOPE Stack Blind ~-~ Choke Line Valves H.C.R. Valve . TJ-!!~ Line Valves Check V-~ive Test Pressure -- ACC,UM;W. ATOR SYSTEM Full Charge Pressure pressure After Closure Pu=p incr. clos. pres. 200 psiK Pull Charge Pressure Attained: psi~ " psis, -- =In~'~ec. · Controls: ~ster C~do ~ Remote~~ Blinds svitch cover~~ . Kelly an~ Floor Safety Valves ' Upper Kelly / Test Pressure Lover KeLly / Test Pressure Ball T)~e / Tes= Pressure inside BOP / Tes= Pressure Choke Pmnifold~3 Test Pressure ~o. Valves [ ~ No. flanges ~ Adjusuabie Chokes ,I ~v6rauica!lv oDera:ed choke Test Resu!ms: Failures O Test Time / hrs. . Repair or Replacement cf faiie~ equipment :o be =a6e ~=hin ~ . Co~--ission office no:~--~ied. '- day~ and inspector/ Reaark~: -- Disu--!bu=ion orig. - A0&GCC CC --- Opera,or cc - Supervisor Inspec~ ARCO AlasKa. In, Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone ~07 276 1215 RETURN TO: ARCO ALASKA, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage ~ AK 99510-0360 DATE 04-03-86 TRANSMITTAL # 5622 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: cET's or CBL's: One * of each ~lA-14 ~ 1E-24 '~ 1E-24 '~lQ-lO '~m2E-10 "~ 2E- 11 ~ 2E-12 '" 2H-9 ~42W-15 ~3A-5 ~ 3A-6 ~3A-8 ~ 3F-8 12-03-85 Run #2 7050-7732 02-21-85 Run #1 6390-6964 02-23-85 Run #2 6400-7000 04-16-85 Run #1 0695-4476 01-28-85 Run #1 5346-7359 01-14-85 Run #1 4710-6500 01-13-85 Run -#1 6050-8250 01-13-85 Run #1 5390-7522 12-06-85 Run #1 6000-8016 02-11-85 Run #2 6488-8062 11-03-85 Run #1 6771-8518 11-03-85 Run #1 6086-7545 11-04-85 Run #1 5186-7006 11-14-85 Run #1 5410-6885 AIEICO AlolAa InC. ,S · SU~Ohlt~ Of AlilntiClOh¢l~l'ell~COmOlnY STATE OF ALASKA ALASKA O'"~ AND GAS CONSERVATION CO'~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG g was run & we11 was perforated ii/2i/8_5. GRUi/WC04 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 1. Status of Well Classification of Service Well OIL E]XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, lnc. 85-221 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21442 4. Location of well at surface 9. Unit or Lease Name 575' FSL, 762' FEL, Sec.7, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1291' FNL, 1320' FEL, Sec.17, T12N, R9E, UM 3A-5 At Total Depth 11. Field and Pool 1400' FNL, 996' FEL, Sec.17, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 73' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 0/05/85 1 0/11/85 10/13/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 8660 'MD ,6376 'TVD 8554'MD,6298'TVD YES E~x NO []I 1838 feet MD 1550' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/FDC/CNL/Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 185 sx AS il 9-5/8" 36.0# J-55 Surf 3975' 12-1/4" 1100 sx AS Ill & 400 s( Class "G" 7" 26.0# J-55 Surf 8641' 8-1/2" 400 sx Class "G" & 250 sx AS I 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) 8407' - 8442' w/4 spf 3-1/2" 8303' 8110' & 8276' 8388' - 8362' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8312' - 8220' w/12 spf DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8213' - 8173' See attached Addendum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATERIBBL iOIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO 1986 Alaska Oil & Gas Cons. ~ommission ~c~or:~ge .~1, .~, i .*~.,.? ~r... ..?.. ,..~ ~ ........... .n .... 29. . ,.30:[ . . . ' GEOLOGIC MARKERS FORMATI°N TEsTs · · ', . ". :~ ~ . ., . - , ~ ;. ? . : . . NAME Include interval tested, pressure'data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C ' 8165' 6019 ' N/A Base Kuparuk C 8220; 6057' Top Kuparuk A ._.8347' 6146' Base Kuparuk A 8506' 6262' · . . , _ . . r · · . 31. LIST OF ATTACHMENTS .-_ Addendum (dated 2/27/86) · . 32. I hereby certify that the fore§oin§ is true and correct to the best of my knowled§e .. Signed ~ ~ Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item.~.3~. ~,tl~aClhe. d_,su~pplemental records for this well should show the details of any multiple stage cement- ing a~l~h~'l~c, at.i~n_j~the cementing tool. Item .~,.,.7~' M~et.ho..d~,,.f Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: ~lfno cqres taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/05/85 12/11/85 3A-5 Rn CET log f/8554'-6772'. Rn GCT gyro f/8465'-surf. Frac well w/325 bbls diesel, 1000# 100 mesh & 8490# 20/40 sand @ avg rate of 20 BPM, 4000 psi. Turn well over to Production. RECEIVED APRO ~ lg86 Alaska Oil & Gas Guns. ~;mnmi~ion Drilling S6perintendent z Da~e 8UB. SURFACE DIRECI'IONAL SURVEY [~]UIDANCE [~]ONTINUOU$ ~"IOOL Company Well Name ATLANTIC RICHFIELD COMPANY 3A-5 (575' FSL, 762' FEL, S7, T12N, R9E, UM) Fleld/Locatlon ~.A~..0~ S~O,~E. ALASKA Jots, Reference No. Oate. 70967 ~'~ E'C E i~~/~ D 18-NOVEMBER-a5 Computed HALFACRE CUDNEY ~aska 0il & Gas ...... SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3A-5 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE': 03-NOV-85 ENGINEER: HALFACRE METHODS OF COMPUTATION ~ TOOL LOCATION': TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTEO ONTO ~ TARGET AZIMUTH OF SOUTH 68 DEG 8 MIN EAST RCO ALASKA, iNC. A-5 UDARUK ORTH SLOPE,ALASKA COMPUTAT I ON INTERPOLATED VALUES FOR TRUE SUB-SEA ASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -73.00 100.00 100.00 27.00 200.00 200.00 127.00 300.00 300.00 227,00 400.00 400.00 327.00 500,00 500.00 427.00 600.00 599.93 526.93 700.00 699.48 626.48 800.00 798.38 725.38 900.00 896.49 823.49 000.00 993.93 920.93 100.00 1090.03 1017.03 200.00 1184.36 1111.36 300.00 1276.77 1203.77 400.00 1367.35 1294.35 500.00 1456.57 1383.57 600.00 1544.84 1471.84 700.00 1632.27 1559.27 800.00 1717.51 1544.51 900.00 1799.57 1726.57 ,000.00 1878.28 1805.28 100.00 1953.56 1880.56 :200.00 2024.75 195!,75 ,300.00 2092.33 2019,33 1400.00 2159.67 2086.67 :500.00 2226.76 2153.76 1600.00 2293.96 2220.96 :700.00 2361.81 2288.81 1800,00 2429.82 2356.82 1900.00 2497.70 2424.70 000.00 2565.63 2492.63 100.00 2633.69 2560.69 1200.00 2701.72 2628.72 300.00 2769.72 2696.72 400.00 2837.89 2764.89 500.00 2906.11 2833.11 600.00 2974.53 2901.53 700.00 3043.20 2970.20 800,00 3112.08 3039.08 90~.00 3181.30 3108.30 COURSE DEVIATION AZIMUTH DEG MIN OEG MIN 0 3 6 9 12 0 0 N 0 0 0 16 N 60 24 0 14 N 51 12 0 11 N 44 32 0 6 N 54 20 21 S 81 13 36 S 87 57 58 $ 85 43 41 S 81 41 8 S 73 11 14 17 S 69 25 17 43 S 71 6 20 57 S 73 37 23 50 S 70 31 25 59 S 69 35 27 33 S 71 33 28 27 S 73 37 30 1 S 73 31 33 7 S 73 28 36 32 S 73 17 39 32 S 73 42 51 S 73 46 28 S 72 47 41 S 72 47 45 S 72 47 56 S 72 47 34 S '72 47 4 S 70 47 14 S 70 47 15 S 70 23 E 2 E 52 E 58 = 43 E 28 E 10 E 5O E 8 E 2 E 47 10 S 69 51 47 5 S 69 54 47 10 S 69 46 47 3 S 69 42 47 3 S 69 42 46 58 S 69 37 46 42 S 69 20 46 33 S 69 3 46 18 S 68 49 46 10 S 68 41 E, E E E E E E E E DATE: 15-NOV-85 EVEN 100 FEE VERTICAL DOG SECTION SEV FEET DEG 0.00 0.17 0.40 0.55 0.68 0.93 3.99 12.73 26.89 45.97 68.35 95.97 129.02 167.09 209.42 254.56 301.36 349.68 401.71 458.59 520.00 585.53 655.48 728.92 802.61 876.54 950.39 1023.70 1096.96 1170.36 1243.70 1316.93 1390.20 1463.49 1536.62 1609.71 1682.62 1755.31 1827.78 1899.96 T OF LEG ERITY /100 0.00 0.18 0.13 0.16 0.13 1.23 3.80 3.10 2.64 1.67 3.54 3.57 3.31 3.02 1.67 2.52 1.01 2.79 3.43 3.05 2.86 3.42 3.68 0.32 0.26 0.34 0.70 1.02 0.31 0.27 0.09 0.14 0.29 0.44 0.18 0.20 0.21 0.27 0.29 0.25 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE MEASURE RECTAN NORTH/ FEE . O. O. O. O. O. O. O, 1. 5, 12. 22. 32. 43. 58. 74. 87. 101. 116. 132. 150. 169. 189. 211. 233. 255. 277. 301. 325. 350. 375. 400. 426' 451. 477. 5O2. 527. 553. 579. 605. D DEPTH GULAR COORDINATES HORIZ. OEP SOUTH EAST/WEST DIST. AZI T FEET FEET DEG O0 N 0.00 E 0.00 N 0 14 N 0.24 E 0.28 N 59 40 N O. 59 E O. 71 N 55 65 N 0.86 E 1.08 N 52 83 N 1.07 E 1.35 N 52 85 N 1.34 E 1.59 N 57 54 N 4.52 E 4.55 N 83 11 N 13.76 E 13.76 N 89 39 S 28.42 E 28.45 S 87 74 S 47.23 E 47.58 S 83 1 73.00 ARTURE MUTH MIN 0 56 54 41 2 35 13 33 12 4 E E E E E (~ 79 S 1189.31 E 1247.27 S 72 27 E 99 S 1258.11 E 1320.47 S 72 19 E 24 S 1326.92 E 1393.70 S 72 11 E 60 S 1395.71 E 1466.96 S 72 4 E O1 S 1464.3Z E 1540.05 S 71 57 E 40 S 1532.88 E 1613.11 S 71 51 E 95 S 1601.19 E 1685.99 S T1 45 E 76 S 1669.16 E 1758.62 S T1 38 E 83 S 1736.79 E 1831.02 S 71 32 E 96 S 1804.07 E 1903.12 S 71 2~ E 27 S 500.01 E 522.10 S 73 16 E 22 S 563.01 E 587.89 S 73 16 85 S 630.11 E 658.09 S 73 13 E 45 S 700.58 E 731.79 S 73 12 E 24 S 771.23 E 805.73 S 73 10 41 S 841.99 E 879.88 S 73 T E 86 S 912.56 E 953.93 S 73 3 E O1 S 982.27 E 1027.35 S 72 57 E 62 S 1051.33 E 1100.60 S 72 47 E 62 S 1120.38 E 1173.96 S 72 37 E FT 98 S 68.44 E 69.66 S 79 15 E 39 S 94.43 E 97.04 S 76 39 E 48 S 125.99 E 130.11 S 75 32 E 96 S 162.40 E 168.25 S 74 51 E 72 S 202.10 E 210.45 S 73 47 E 04 S 244.59 E 255.55 S 73 9 E T1 S 289.53 E 302.52 S 73 8 E 41 S 336.09 E 351.06 S 73 12 E 26 S 386.19 E 403.32 $ 73 14 E 61 S 440.93 E 460.43 S 73 15 E ARCO ~LASKA~ INC. 34-~ KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATe: 15-NOV-85 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: MALFACRE 2 73.00 FT INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN ~000.00 3250.92 3177.92 4100.00 3321.33 3248.33 4200.00 3392.49 3319.49 4300.00 3464.50 3391.50 4400.00 3535.83 3462.83 4500.00 3601.97 3528.97 4600.00 3665.41 3592.41 4700.00 3728.87 3655.87 4800.00 3792.42 3719.42 4900.00 3856.27 3783.27 45 17 S 68 38 E 45 2 S 69 38 E 44 10 .S 69 59 E 43 57 S 66 27 E 45 48 S 64 4 E 50 23 S 62 54 E 50 37 S 63 4 E 50 34 S 63 19 E 50 28 S 63 32 E 50 15 S 63 50 E 5000.00 3920.10 3847.10 5100.00 3983.87 3910.87 5200.00 4047.79 3974.79 5300.00 4112.15 4039.15 5400.00 4176.65 4103.65 5500.00 4241.30 4168.30 5600.00 ~306.02 4233.02 5700.00 4370.92 4297.92 5800.00 4436.09 4363,09 5900.00 4501.72 4428.72 50 23 S 64 8 E 50 20 S 64 16 E 50 6 S 64 26 E 49 53 S 64 29 E 49 44 S 64 32 E 49 41 S 64 36 E 49 37 S 64 44 E 49 2? S 64 50 E 49 7 S 65 9 E 48 58 S 65 27 E 6000.00 4567.51 4494.51 48 46 6100.00 4633.51 4560.51 48 35 6200.00 4699.76 4626.76 48 27 6300.00 4766.07 4693.0? 48 29 6400.00 4832.39 4759.39 48 26 6500.00 4898.77 4825.77 48 25 6600.00 4965.11 4892.11 48 33 6700.00 5031.16, 4958.16 48 52 6800.00 5096.93 5023.93 48 42 6900.00 5163.13 5090.13 48 26 S 65 33 E S 65 40 E S 65 43 E S 65 53 E S 65 54 E S 65 54 E S 66 2 E S 66 29 E S 66 34 E S 66 37 E 7000.00 5229.57 5156.57 48 13 7100.00 5296.10 5223.10 48 19 7200.00 5362.91 5289.91 47 53 7300.00 5430.03 5357.03 47 42 7400.00 5497.40 5424.40 47 40 7500.00 5564.66 5491.66 47 39 7600.00 5632.14 5559.14 47 26 7700.00 5699.84 5626.84 47 21 7800.00 5767.75 5694.75 46 59 7900.00 5836.07 5763.07 46 49 S 66 43 E S 67 4 E S 67 23 E S 68 0 E S 68 33 E S 69 1 E S 70 3 E S 71 14 E S 71 58 .= S 72 25 E EVEN 100 VERTICAL SECTION FE~T 1971.74 2042.73 2112.96 2182,32 2252.28 2326.97 2403.96 2480.96 2557.91 2634.64 2711.42 2788.27 28.65.00 2941.38 3017.66 3093.79 3169.89 3245.84 3321.57 3396.93 3472.16 3547.22 3622.06 3696.85 3771.63 3846.37 3921.14 3996.18 4071.49 4146.41 4295.76 4370.16 4444.28 4518.18 4592.18 4665.95 4739.48 4812.75 4885.58 FEET OF MEASURED DEPTH DOGLEG SEVERITY DEG/IO0 0.74 0.75 0.55 4.30 5.52 1.16 0.18 0.32 0.34 0.33 0.37 0.26 0.72 0.27 0.17 0.25 0.22 0,26 0.4'7 0.44 0.21 0.24 0.08 0.31 0.22 0.17 0.56 0.48 0.50 0.55 0.51 0.20 0.66 0.51 0.63 0.44 1.13 0.79 0.77 0.23 RECTANGULAR COORDINATES HORIZ. NORTH/SOUTH EAST/WEST DIST. FEET FEET FEET 632.13 S 1870.91 E 1974. 657.47 S 1937.24 E 2045. 681.64 S 2003.22 E 2116. 706.59 S 2067.94 E 2185. 736.52 S 2131.31 E 2254. 770.11 S 2198.31E 2329. 805.24 S 2267.17 E 2405. 840.05 S 2336.17 E 2482. 874.60 S 2405.22 E 2559. 908.73 S 2474.20 E 2635. DEPARTURE AZIMUTH DEG MIN 82 S 71 19 E 77 S 71 15 E O1 S 71 12 E 33 S 71 8 .,=- 99 S'70 56( 30 S 70 41 ._ 92 S 70 26 E 62 S 70 13 E 30 S 70 1 E 80 S 69 49 E 942.48 S 2543.39 E 2712.39 S 69 40 E 976.00 S 2612.74 E 2789.08 S 69 30 E 1009.25 S 2682.08 E 2865.68 S 69 22 E 1042.24 S 2751.14 E 2941.95 S 69 15 E 1075.09 S 2820.15 E 3018.12 S 69 7 E 1107.86 S 2889.03 E 3094.17 S 69 1 E 1140.46 S 2957.94 E 3170.18 S 68 54 E 1172.82 S 3026,80 E 3246,08 S 68 49 E 1204.93 S 3095.51 E 3321.75 S 68 43 E 1236.41 S 3164.08 E 3397.08 S 68 39 E 1267.61 S 3232.63 E 3472. 1298.63 S 3301.05 E 3547. 1329.43 S 3369.33 E 3622. 1360.15 S 3437.59 E 3696. 1390.67 S 3505.92 E 3771. 1421.18 S 3574.21 E 3846. 1451.70 S 3642.52 E 3921. 1481.86 S 3711.29 E 399,6. 1511.83 S 3780.40 E 4071. 1541,63 S 3849.17 E 4146, 28 S 68 35 E 30 S 68 31 E 12 S 68 28 E 89 S 68 24..: 67 S 68 21(' 40 S 68 18'- _ 15 S 68 16 E 19 S 68 14 E 49 S 68 12 E 41 S 68 10 E 1571.,17 S 3917.82 E 4221.12 S 68 8 E 1600.47 S 3986.49 ~: 4295.76 S 68 7 E 1629.31 S 4055.08 E 4370.16 S 68 6 E 1657.45 S 4123.65 E 4444.28 S 68 6 E 1684.75 S 4192.33 E 4518.18 S 68 6 E 1711.50 S 4261.32 E 4592.18 S 68 7 E 1737.37 S 4330.43 E 4665.95 S 68 8 E 1761.71 S 4399.90 E 4739.48 S 68 10 E 1784.84 S 4469.56 E 4812.75 $ 68 13 E 1807.13 S 4539.09 E 4885.60 S 68 17 E COMPUTATION DATE: 15-NOV-85 PAGE 3 ARCO ALASKA~ INC, DATE OF SURVEY: 03-NOV-85 34-5 KUPARUK NORTH SLOPE~ALASKA KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET. DEG MIN 8000.00 5904.54 5831.54 46 43 8100.00 5973.51 5900.51 45 56 8200.00 6042.99 5969.99 46 5 $300.00 6112.63 6039.63 45 12 8400.00 6184.27 6111.27 43 17 8500.00 6257.89 6184.89 42 14 8600.00 6331.92 6258.92 42 14 8660.00 6376.33 6303.33 42 14 S 72 34 E 4958.25 S 71 55 E 5030.46 S 71 52 E 5102.23 S 71 55 E 5173.83 S 71 10 E 5243.46 S 70 59 E 5311.06 S 70 59 E 5378.21 S 70 59 E 5418.49 0.10 0.76 0.64 1.88 1.58 0.00 0.00 0.00 1828.98 S 4608.63 E 495'8.29 S 68 21 E 1850.92 S 4677.63 E 5030.52 S 68 24 E 1873.~4 S 4745.93 E 5102.31 S 68 27 E 1895.58 S 4814.19 E 5173.94 S 68 30i~ 1917.66 S 4880.36 E 5243.60 SI68 32( 1939.68 S 4944.37 E 5311.23 S 68 34 ~ 1961.57 S 5007.93 E 5378.40 S 68 36 E 1974.70 S 5046.07 E 5418.70 S 68 37 E COMPUTATION DATE: 15-NOV-85 PAGE 4 ~RCO &LASK~, INC. 3A-5 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -73.00 0 0 1000.00 993.93 920.93 14 17 ZO00.O0 1378.28 1805.28 39 32 3000.00 2565.63 2492.63 47 10 4000.00 3250.92 3177.92 45 17 5000.00 3920,10 3847.10 50 23 6000.00 4567.51 4494.51 48 46 7000.00 5229.57 5156.57 48 13 8000.00 5904.54 5831.54 46 43 8560.00 6376.33 6303.33 42 14 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 69 25 E 68.35 S 73 23 E 520.00 S 69 51 E 1243.70 S 68 38 E 1971.74 S 64 8 E 2711.42 S 65 33 E 3472.16 S 66 43 E 4221.12 S 72 34 E 4958.25 S 70 59 E 5418.49 0.00 3.54 2.86 0.09 0.74 0.37 0.21 0.51 0.10 0.00 0.00 N 0.00 E 0.00 N 0 0 E 12.98 S 68.44 E 69.66 S 79 15 E 150.27 S 500.01E 522.10 S 73 16 E 375.79 S 1189.31 E 1247.27 S 72 27 632.13 S 1870.91 E 1974.82 S '71 942.48 S 2543.39 E 2712.39 S 69 40 1267.61 S 3232.63 E 3472.28 S 68 35 E 1571.17 S 3917.82 E 4221.12 S 68 8 E 1828.98 S 4608.63 E 4958.29 S 68 21 E '1974.70 S 5046.07 E 5418.70 S 68 37 E 4RCD ~LASKA, INC. 3A-5 KUPARUK NORTH SLOPE,ALASKA TRUE EASURED VERTICAL DEPTH DEPTH 0.00 0.00 73.00 73.00 173.00 173.00 273.00 273.00 3?3.00 373.00 473.00 473.00 573.03 573.00 673.34 673.00 774.27 773.00 975.99 873~00 978.43 973.00 1082.16 1073.00 1187.86 1173.00 1295.88 1273.00 1406.28 1373.00 1518.55 1473.00 1632.08 1573.00 1747.34 1673.00 1867.17 1773.00 1993.18 1873.00 2126.71 1973.00 2271.26 2073.00 2419.84 2173.00 2568.89 2273.00 2716.42 2373.00 2863.61 24?3.00 3010.85 2573.00 3157.78 2673.00 3304.81 2773.00 3451.46 2873.00 COMPUTATION DATE: 15-NOV-85 INTERPOLATED VALUES FOR EVEN 100 FEET SUB-SEA VERTICAL DEPTH -73 0 100 20O 300 400 5O0 60O 70O 8OO COURSE VERTICAL DEVIATION AZIMUTH SECTION DEG MIN DEG MIN FEET .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 0 2 6 9 11 0 0 N 0 0 E 0.00 0 16 N 56 58 E 0.09 0 14 N 50 46 E 0.34 0 12 N 45 49 E 0.51 0 9 N 54 19 E 0.65 12 S 86 54 E 0.82 40 S 85 2 E 2.59 5 S 86 54 E 9.84 10 S ~3 19 E 22.80 50 S 74 25 E 41.01 .00 13 31 S 70 18 E 63.18 · 00 17 8 S 70 50 E 90.64 .00 20 33 S 73 18 E 124.76 .00 23 43 S 70 41 E 165.44 .00 26 5 S 69 37 E 212.17 .00 27 ~4 S 72 26 E 263.15 .00 28 45 S 73 38 E 316.65 .00 31 25 S 73 28 E 373.71. .00 35 26 S 73 20 E 439.39 .00 39 20 S 73 23 E 515.70 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 3597.77 2973.00 2900.00 3743.31 3073.00 3000.00 3888.03 3173.00 3100.00 4031.34 3273.00 3200.00 4172.78 3373.00 3300.00 4311.82 13473.00 3400.00 4454.98 3573.00 3500.00 4611.95 3673.00 3600.00 4769.47 3773.00 3700.00 4926.19 3873.00 3800.00 43 45 S 72 57 E 603.79 47 43 S 72 58 E 707.73 47 47 S 72 40 E 817.25 47 42 S 72 20 E 927.46 47 5 S 70 38 E 1035.72 47 15 S 70 6 E 1143.64 47 9 S 69 51 E 1251.66 47 8 S 69 50 E 1359.27 47 2 S 69 42 E 1467.01 46 56 S 69 41 E 1574.22 46 42 S 69 20 E 1681.00 46 28 S 68 54 E 1786.73 46 10 S 68 43 E 1891,32 45 16 S 68 51 E 1993.98 44 25 S 69 57 E 2093.97 44 2 S 65 50 E 2190.53 48 59 S 63 15 E 2292.66 50 37 S 63 7 E 2413.16 50 31 S 63 28 E 2534.43 50 19 S 63 54 E 2654.73 PAGE DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE OF SUB-SEA DEPTH DOGLEG SEVERITY DEG/IO0 .00 .15 .10 .05 .13 .38 .50 .24 .41 .81 .5O .36 .43 .03 .85 .45 .93 .45 .56 .88 .24 .09 .23 .50 .84 .11 .18 .24 .44 .51 5 73.00 FT .23 .25 .25 .95 .24 .74 .63 .36 .34 .34 RECTANGULAR NORTH/SOUTH FEET 0.00 N 0.07 N 0.33 N 0.59 N 0.79 N 0.87 N 0.61 N 0.31 N 0.83 S 4.35 S COORDINATES HORIZ. EAST/WEST DIST. FEET FEET 0.00 E 0.13 E 0.50 E 0.79 E 1.02 E 1.23 E 3.04 E 10.72 E 24.24 E 42.44 E DEPARTURE AZIMUTH DEG MIN 0.00 N 0 0 E O. 14 N 61 7 E 0.59 N 56 34 E 0.98 N 53 15 E 1.29 N 51 56 E( 1.50 N 54 46 E 3.10 N 78 34 E 10.73 N 88 21 E 24.25 S 88 1 E 42.66 S 84 9 E 11.19 S 63.58 E 6,4.56 S 80 0 E 20.65 S 89.38 E 91.73 S 76 59 E 31.26 S 121.89 E 125.83 S 75 36 E 43.41 S 160.84 E 166.60 S 74 53 E 59.68 S 204.67 E 213.19 S 73 44 E 76.72 S 252.76 E 264.15 S 73 6 E 92.03 $ 304.27 E 317.88 S 73 10 E 108.27 S 359.23 E 375.19 S 73 13 E 127.07 S 422.46 E 441.16 S 73 15 E 149.03 S 495.87 E 517.78 S 73 16 E 580.53 680.24 785.26 890.67 993.62 1095.25 1196.78 1297.88 1399.02 1499.60 E 606 E 710 E 820 E 930 E 1039 E 1147 E 1255 E 1362 E 1470 E 1577 .22 S 73 15 E · 53 S 73 12 E .42 S 73 9 E · 94 S 73 5 .38 S 72 56 ~ .26 S 72 40E~ · 22 S 72 26 E .78 S 72 14 E .48 S 72 3 E .64 S 71 54 E 527.38 S 565.03 S 602.82 $ 640.21 S 675.14 S 709.96 S 754.47 S 809.43 S 864.09 S 917.60 S 174.59 S 205.23 S 237.60 S 270.85 S 304.98 S 341.52 S '378.53 S 452,82 S 490.06 S 1599.67 E 1684.37 S 71 45 E 1698.49 E 1790.01 S 71 35 E 1796.03 E 1894.50 S 71 26 E 1891.64 E 1997.04 S 71 18 E 1985.36 E 2097.02 S 71 13 E 2075.43 E 2193.51 S 71 6 E 2167.62 E 2295.17 S 70 48 E 2275.40 E 2415.08 S 70 25 E 2384.14 E 2535.90 S 70 4 E 2492..29 E 2655.84 S 69 47 .E COMPUTATION DATE: 15-NOV-85 PAGE 6 ALASKA, INC. i-5 IPARUK IRTH SLOPE,ALASKA DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: ENGINEER: HALFACRE 73.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTUR.E kSURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH )EPTH DEPTH DEPTH DEG MIN )82.97 3973.00 3900.00 50 19 !39.22 4073.00 4000.00 49 57 394.35 4173.00 ~100.00 49 45 ~49.01 4273.00 4200.00 49 40 r03.20 4373.00 4300.00 49 27 )56.27 4473.00 4400.00 48 56 )08.32 4573.00 4500.00 48 45 L59.64 4673.00 4600.00 48 29 310.45 ~773.00 4700.00 48 28 ~61.17 4873.00 4800.00 48 24 511.93 4973.00 4900.00 48 34 ?63.69 5073.00 5000.00 48 52 )14.87 5173.00 5100.00 48 24 D65.24 5273.00 5200.00 48 22 215.06 5373.00 5300.00 47 56 363.82 5473.00 5400.00 47 36 512.38 5573.00 5500.00 47 38 560.34 5673.00 5600.00 47 23 307.70 5773.00 5700.00 46 58 953.98 5873.00 5800.00 46 47 D99.27 5973.00 5900.00 45 56 243.27 6073.00 6000.00 46 1 384.48 6173.00 6100.00 43 33 520.42 6273.00 6200.00 42 14 $55.50 6373.00 6300.00 42 14 560.00 6376.33 6303.33 42 14 DEG MIN FEET DEGYlO0 FEET FEET FEET DEG MIN S 64 13 E 2775.19 S 6w 27 E 2894.99 S 64 32 E 3013.36 S 64 40 E 3131.10 S 64 50 E 3248.27 S 65 21 E 3363.99 S 65 33 E 3478.42 S 65 44 E 3591.87 S 65 55 E 3704.67 S 65 56 E 3817.35 S 66 5 E 3930.08 S 66 34 E 4044.18 S 66 40 E 4157.53 S 66 57 E 4269.80 S 67 27 E 4381.35 S 68 23 E 4491.46 S 69 6 E 4601.33 S 70 49 E 4710.33 S 72 1 E 4818.36 S 72 35 E 4924.83 S 71 55 E 5029.94 S 72 4 E 5133.34 S 71 17 E 5232.81 S 70 59 E 5324.77 S 70 59 E 5415.47 S 70 59 E 5418.49 0.26 0.20 0.19 0.35 0.20 0.24 0.15 0.25 0.23 0.12 0.73 0.54 0.59 0.46 0.77 0.60 0.64 0.91 0.71 0.40 0.77 1.00 1.85 0.00 0.00 0.00 970.30 S 2600.93 E 2776.03 S 69 32 E 1022.22 S 2709.19 E 2895.62 S 69 19 E 1073.24 S 2816.26 E 3013.82 S 69 8 E 1123.86 S 2922.81 E 3131.44 S 68 58 E 1173.85 S 3029.00 E 3248.50 S 68 49 E { 1222.69 S 3134.09 E 3364.15 S 68 41 E 1270.20 S 3238.32 E 3478.53 S 68 34 E 1317.00 S 3341.79 E 3591.94 S 68 29 E 1363.34 S 3444.73 E 3704.71 S 68 24 E 1409.33 S 3547.69 E 3817.37 S 68 20 E 1455.33 S 3650.70 E 3930.09 S 68 15 E 1500.99 S 3755.33 E 4044.19 S 68 12 E 1546.04 S 3859.38 E 4157.53 S 68 10 E 1590.33 S 3962.58 E 4269.80 S 68 7 E 1633.60 S 4065.41 E 4381.35 S 68 6 E 1674.96 S 4167.46 E 4491.46 S 68 6 E 1714.77 S 4269.87 E 4601.33 S 68 7 E 1752.23 S 4372.29 E 4710.33 S 68 9 E 1786.58 S 4474.91 E 4818.37 S 68 14 E 1818.94 S 4576.65 E 4924.86 S 68 19 E 1850.75 S 4677.14 E 5030.00 S 68 24 E 1883.06 S 4775.59 E 5133.43 S 68 28 E 1914.23 S 4870.27 E 5232.95 S 68 32 E 1944.14 S 4957.35 E 5324.94 S 68 35 E i' 1973.72 S 5043.21 E 5415.67 S 68 37 E ~ 1974.70 S 5046.07 E 5418.70 S 68 37 E - ~R£O ALASKA, INC. 3A-5 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUP~RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION INTERPOLATED VALUES FOR MEASURED DEPTH BELOW KB B165.00 8220.00 8347.00 8506.00 8554.00 8660,00 DATE: 15-NOV-85 CHOSEN HORIZONS FROM KB 601B.71 6056,86 6146.00 6262.33 6Z97.86 6376.33 ORIGIN: TVD 575 ' SUB-SEA 5945.71 5983.86. 6073.00 6189.33 6224.86 6303.33 PAGE 7 DATE OF SURVEY: 03-NOV-85 KELLY BUSHING ELEVATION: 73.00 ENGINEER: HALFACRE SURFACE LOCATION AT FSL,762' FEL,SEC 7,TJ2NtRgE~UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1865.54 S 4721.99 E 1877.90 S 4759'63 E 1905.94 S 4845.6,3 E 1940.99 S 4948.18 E 1951.50 S 4978.69 E 1974.70 S 5046.07 E FT COMPUTATION DATE: 15-NOV-85 PAGE 8 ~RCO ALASKA~ INC. 3A-5 KUPARUK NORTH SLOPE,ALASKA TOP BASE TOP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUP&RUK A KUPARUK A ~~~:x: STRATIGRAPHIC MEASURED DEPTH BELOW.KB 8165.00 8220.00 8347.00 8506.00 8554.00 8660.00 DATE OF SURVEY: 03-NDV-85 KELLY BUSHING ELEVATION: 73.00 FT ENGINEER: HALFACRE SUMMARY ORIGIN: 575' FSL,762' F SURFACE LOCATION AT EL,SEC 7,T12N,RgE,UM TVD FROM K8 SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6018.71 5945.71 6056.86 5983.86 6146.00 6073.00 6262.33 6189.33 6297.86 6224.86 6376.33 6303.33 1865.54 S 4721.99 E 1877.90 S 4759.63 E 1905.94 S 4845.63 E 1940.99 S 4948.18 E 1951.50 S 4978.69 E 19,74.70 S 5046.07 E FINAL MEASURED DEPTH WELL LOCATION AT TD: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH 8660.00 6376.33 6303.33 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 5418.70 S 68 37 SCHLUMBEROER 0 1REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL BA-S FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 000090967 WELL NAME: 3A-o SURFACE LOCATION: 575' FSL, 762' EEL, S7, T12N, R9E, UM VERTICAL PROJECTION - 1000 0 0 1000 2000 3000 4000 .~000 6000 7000 i i:iiiiii ii i, i iii I iii _,.~---H.-.++H-+.4 ........ ...... , H..-~-~---H...;.... .......... .4+~~., ....... ,~~-;..~.~ -~.;4.!4~ _~_ a4.-~., h~ '~'" h~-~-~a~'L~kL; 2~, ~ ~ ~ ~~N_'_2 :, ~ ~ '"f"f"t"-f-'J"'f-'f-'f"ff- '~-f-flH ~ +f+'--f--h f yf'H ~' fi-+~tf++--~--f-hH--f%-f-%-f-- %-~-~eH---b .............. : .... . ..... ~ -~..~_ .~ .~.~. ~.-.~.~ -~..~.~ ,-++-b.bf-H-%--b~.--H..F+-.H-.4 ...... ~+HHq~{~%~N---H-H--+%~b 4~:. ~ ~-;-~-.4-~--.ab~4-s.%.--S-N~-;.-~ ,'-f"t-'i-r't'"t-f--f-'{ ..... f"f"t"{-'r'+'4i'-{ ..... fe'%t't!i'-h-~-f%N+~ ~ i ?+-~t-~-~: : :-~--+~- : : ~ '.+%+%-H ¢-~~4a .... e.+-+..+-J-+.--H+-.~ ....... 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H--H.--b-b.~--~--~,-q--~-bb~--~--~---H--~-----HLbbi4---~--~-,-~ ..... H-.-~-.-~--b-b-~--.H-4---bbb~-,-b-Lb,H---,---H-.-H b-H-~ ~--- ..-?'-H.'-t"-[+'F'f--~ ...... H---?--?-j---F-t'-+--~ ..... H---f---?.--~-+-?---?---~ ....... ?-'f-'~'-~Tt'"?'-f"~'"j-%"t'+T-'??~'"~"J"?"?'-'?'"?'l'-F~"?'''~ 0 1000 2000 2000 4000 5000 6000 7000 E~T ...'. r {'" ( or' ,..; Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: / /-/c2--F:.r Date Required Date Received Remarks Completion Report '1,."ø"' th-J,' ,,""<"""':: Samples - OA Mud Log " II G Core Chips /l/ëJ Core-Description 27/1'e, ~.~-- ", -,. - ()~ Ó Registered Survey Plat -a (j--8':$ Inclination Survey -r;) --' -0 Directional Survey Drill Stem Test Reports ..). ò Production Test Reports """'" - Log Run Digitized Data ~ L.FJ.O4 ARCO Alaska, Inc. Post Office B0-~.-~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3A-5 Dear Mr. Chatterton' Enclosed is an addendum to the 3A-5 Well the Well Completion Report, dated 12/4/85. questions, please call me at 263-4944. Sincerely, Associate Engineer JG/tw GRU13/L97 Enclosure History to include with If you have any ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldC0mpany '~ ADDENDUM WELL: 3A-5 Rn CET log f/8554'-6772' Rn GCT gyro f/8465'-surf. Drilling ~ Superintendent Date ARCO Alaska, Inc. Post Office B~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil &'Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-5 Dear Mr. Chatterton' Enclosed is a Copy of the 3A-5 Well History to include with the Well Completion Report, dated 12/4/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L108 . Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History - Initial Report- Daily Insfructlonl: Prepare and submit the "Initial Reporl'.' On- the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPudding should bo summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth, or W.O. no. Parker 141 ICounty, parish or borough North Slope Borough JLease or Unit ADL 25632 ITitle Drill JState Alaska IWell no. 3A-5 AP1 50-029-21442 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded JDate 10/5/85 I"°ur Date and depth as of 8:00 a.m. lO/O5/85 thru 10/07/85 lO/O8/85 10/09/85 lO/lO/85 Complete record for each day reported IARCO W.I. Prior status 56.24% if a W.O. 2000 hrs. 16" @ 104' 3000', (2896'), Drlg Wt. 9.2, PV 9, YP 21, PH 10.0, WL 8.0, Sol 7 Accept ri~ @ 1500 hfs, 10/5/85. NU diverter sys. Spud Well 2000 hrs, 10/5/85. Drl, DD & surv 12¼" hole to 3000'. 710', 7.4°, SS1.SE, 709.42 TVD, 13.16 VS, 1.93S, 13.40E 1307', 24.2°, S68.SE, 1283.13 TVD,- 169.63 VS, 53.57S, 161.28E 1974', 38.7°, S73E, 1857.14 .TVD, 505.38 VS, 157.27S, 481.45E 2700', 47.1°, S7OE, 2362.33 TVD, 1024.80 VS, 322.39S, 974.86E 9-5/8" @ 3975' 3990', (990'), ND diverter sys Drl & surv 12¼" hole to 3990', circ hi-vis sweep w/dye, short trip, POOH. RU & rn 100 jts, 9-5/8", 36#, J-55 HF-ERW BTC csg to 3975'. FC @ 3890', FS @ 3975'. Cmt w/ll00 sx AS III w/10#/sx Coalite, followed by 400 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. Good rtns thruout job. ND diverter sys. 3165', 47.3°, S70E, 2678.27 TVD, 1365.86 VS, 439.09S, 1295.47E 3770', 46.6°, S70.3E, 3083.79 TVD, 1801.11VS, 594.61S, 1702.12E 9-5/8" @ 3975' 4900', (910'), Turbine drlg8 Wt 8.9, PV 4, YP 12, PH 11.5, WL 30, Sol 4.7 ND diverter sys. NU & tst BOPE. TIH w/8½" bit to FC, tst csg to 1500 psi. DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW, POOH. PU turbine, TIH, drl to 4900'. 3940', 46°, S68E, 3208.15 TVD, 1931.21VS, 640.92S, 1823.72E 4520', 51°, S63.5E, 3602.64 TVD, 2355.63 VS, 804.82S, 2215.27E 9-5/8" @ 3975' 8046', (3146'), Turbine drlg Wt 10.2, PV 19, YP 19, PH 10, WL 7.8, Sol 10 Turbine drl & surv 8½" hole to 8046'. 5020', 50.7°, S64E, 3918.32 TVD, 2742.25 VS, 976.31S, 2563.03E 5838', 49.5°, S66E, 4442.91TVD, 3368.84 VS, 1242.55S, 3131.34E 6760', 49.1°, S67.3E, 5047.89 TVD, 4064.27 VS, 1520.53S, 3769.13E 7255', 48°, S68.3E, 5375.76 TVD, 4435.28 VS, 1660.71S, 4112.64E The above is correct Signature For form preparation an~ distribution, see Procedures Manuel, Section 10. Date I Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ITitle AFE AK0286 I Drill Parker 141 API 50-029-21442 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 10/11/85 10/12/85 0ate and depth as of 8:00 a.m. ':~:.:OI8 TDJ 10/13/85 Released rig Classifications (oil, gas, etc.) O±l Flowing Producing method A.R.Co.- W.I. 56.24% Date 10/5/85 Complete record for each day reported cost center code Alaska Well no. 3A-5 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 2000 hrs. 9-5/8" @ 3975' 8660', (614'), Short trip Wt. 10.2, PV 13, YP 7, PH 9.5, WL 6.1, Sol 12 Turbine drl & surv to 8660', 20 std short trip. 7503', 48°, S69.5Es 5541.50 TVD, 4619.56 VS, 1727.06S, 4284.58E 8242', 46.2°, S76.6E, 6044.53 TVD, 5158.54 VS, 1884.77S, 4802.06E 8620', 39°, S71.3E, 6323.24 TVD, 5412.53 VS, 1959.51S, 5045.74E 7" @ 8641' 8554' PBTD, (0'), RR 10.0 ppg NaC1/NaBr Trip back in hole on short trip, circ hi-vis sweep, TOH. RU Schl, log DIL/SFL/GR/FDC/CNL/CAL to 8656', cont w/DIL to 3972'. Log FDC/CNL to 7900', RD Schl. TIH, CBU, wrk tight hole, POH on 20 std short trip, rm 6 its to btm, circ hi-vis sweep, TOH. LD 5" DP & HWDP. Chg rams & tst doors to 3000 psi. RU & rn 200 jts, 7", 26# BTC csg w/FS @ 8641', FC @ 8554'. Cmt w/400 sx C1 "G" w/3% KC1, .8% D-60 & .2% D-46 & displ plug w/rig pmp. Bump plUg. ND BOPE, set pack-off & tree, tst to 3000 psi. RR @ 0600 hfs, 10/13/85. Arctic packed well w/250 sx AS I. New TD Date 8660 ' TD 0600 hrs. PB Depth Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8554' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and gistribution, see Procedures Manual, Section tO, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office B6"z"'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-5 Dear Mr. Chatterton: Enclosed is a copy of the 3A-5 Well History (completion details) to include with the Well Completion Report, dated 12/4/85. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L81 Enclosure A~ask20ij & Gas 6'ons. Oommission A~chorace ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany - AtlanticRichfieldCompany Daily-Well History Initial ReP°rt Inltruoflona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally wore prior to spudding should be summarized on the form giving inclusive dates only. District I Cout~ty or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ITItle I AFE AK0286 North Slope Borough ADL 25632 Completion State Alaska IWell no. 3A-5 Nordic 1 API 50-029-21442 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Complete I Date and depth as of 8:00 a.m. 11/2o/85 11/21/85 Complete record for each day reported 11120185 IHour 0600 hrs. A.R.Co's W.I. 56.24% Prior status if a W.O. 7" @ 8641' 8554' PBTD, NU BoPE 10.0 ppg NaC1/NaBr Accept rig @ 0600 hrs, 11/20/85. 7" @ 8641' 8554' PBTD, POOH w/JB & gage ring 10.0 ppg NaC1/NaBr ND tree, NU & tst BOPE. TIH w/BHA, PU 3½" tbg, tag PBTD, rev CBU, POH w/3½" tbg. RIH w/4" perf gun, perf @ 4 SPF f/8362'-8388' & 8407'-8442'. Perf w/5'" gun @ 12 SPF f/8312'-8220', 8193'-8213' & 8173'-8193'. RIH w/6-1/8" JB & gage ring, TOH. The above is correct Title Signature,~ a~n For form prepar , sea Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. · I Accounting Oislrict J County or Parish ] State Alaska North Slope BorOugh Field ~Lease or Unit Kuparuk River I ADL 25632 Auth. or W.O. no. ITitle ' AFE AK0286 I Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun 'Complete 11/22/85 Date and depth as of 8:00 a.m. API 50-029-21442 A.R.Co. W.I. 56.24% IDate 11~20/85 Complete record for each day reported Iotal number of wells (active or inactive) on this, est center prior to plugging and I bandonment of this well . our ]Pr,or status if a W.O. I 0600 hrs. 7" @ 8641' 8554' PBTD, RR 10.1+ ppg Diesel POH w/JB & gage ring. RIH, set FB-1 pkr @ 8276', POOH, RD Schl. RIH w/3½" tbg, drop ball, lnd tbg. Tst to 2500 psi. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. Tst orifice vlv. Set BPV. PR @ 2400 hfs, 11/21/85. FB-1Pkr @ 8276', FHL pkr @ 8110 - SSSV @ 1838' - "D" Nipple @ 8293' - TT @ 8303' COSt center code Alaska IWell no. 3A-5 Did TD Released rig 2400 hrs. New TD Date 11/21/85 Depth PBTD 8554 ' IKind of rig Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil Or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Effective date corrected The above is correct Signature For form preparation a~l distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date . ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3A-5 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L111 Enclosures // RECEIVED Aiaska 0il & Gas Oons. Oor,_-~rnissior,, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ o STATE. Of ALASKA ALASKA ~ AND GAS CONSERVATION cO,_.~ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL F~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-221 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21442 4. Location of well at surface_ 9. Unit or Lease Name ~¥ERIFIED At Top Producing Interval . 10. Well Number 1291' FNL, 1320' FEL, Sec.17, T12N, R9E, UN Surf.~ 3A-5 At Total Depth !iB. H. _i~[vf 11. Field and Pool 1400' FNL, 996' FEL, Sec.17, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0il Pool 73' RKBJ ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/05/85 10/11/85 10/13/85'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MEX-TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of PermafrOst 8660'MD,6376'TVD 8554'MD,6298'TVD YES [~]X NO [] 1838 feet MD 1550' (approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/FDC/CNL/Cal , CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 185 sx AS II 9-5/8" 36.0# J-55 Surf 3975' 12-1/4" 1100 sx AS Ill & 400 s~ Class "G" ._ 7" 26.0# J-55 Surf 864i' 8-1/2"' 400 sx Class "G" & 250 sx AS ! 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) 8407' - 8442' w/4 spf 3-1/2" 8303' 8110' & 8276' 8388' - 8362' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. 8312' - 8220' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8213' - 8173' N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None E CE VED ~!aska 0J! & 6as 6o~s. 6or:~.,:r:isaior~ Form 10407 * NOTE: Tubing was run & well was perforated 11/21/85. TEMP2/WC69 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH :.GOR, and.time of each phase. . Top Kuparuk C 8165~ 6019~ N/A Base Kuparuk C 8220~ 6057~ ' ' Top Kuparuk A 83~7~ 61~6~ . Base Kuparuk A . 8506' 6262'' : .. , . : : : : 31. LIST OF ATTACHMENTS 32. I hereby certif(th~t the foresoinfl is true and correct to the best of m~ kno~ledfle ;~ ~~ Title' Associate Engineer Date /~-4-~ Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from .more than one interval (multiple completion), so state in item 16, and in item 24.show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water in- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Oflice B, 00360 Anchorage, Ai~'~ka 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports 1B-1 (workover) 3A-7 3C-15 3J-6 2A-8 3A-8 3F-3 3J-7 2D- 12 (workover) 3C-6 3F-4 3J-8 3A-5 3C-13 3F-5 4-21 3A-6 3C-14 3F-6 4-22 If you have any questions, please call me Si ncerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures for the following wells- 9-24 L2-3 9-36 L2-13 16-17 L3-5 16-18 L3-11 18-6 (workover) at 263-4944. RECEIVED NOV Alaska Oil & Qas Cons. Comm!ssJon Anchorags ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, inc. ~"' Post Office Bt.,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-13-85 TR3LNSMITTAL NO: 544 0' ~TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS. CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING ~zd~sMI TTk'D ~CEIPT AND RETURN NAL PRINTS/ SCHL/ ~.2-v ~2 "--- HEI~L%~ITH ARE THH FOLLOWING IT~IS. PLEASE ACKNOWLEDGE ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE/ ONE * OF EACH DIL/SFL-GR 09-15-85 RUN '~1 3858-7622 DIL/SFL-GR 09-15-85 RUR ~1 3858-7622 D~'.N/NEU PORO 09-15-S5 RUN %1 3858-7596 DEN/NED PORO 09-15-85 RUN ~1 3~5~-7596 DEN/N~.'U ' RAW 09-15-85 RUN ~1 3858-7596 DHN/NEU PAW 09-15-85 RUN ~.1 3858-7596 CYBER.LOOK 09-15-85 RUN %1 6750-7550 DIL/SFL-GR 10-18-85 RUN ~1 3412-7596 DIL/SFL-~R 1~-18-85 RUN fl 3412-7596 DEN/NED PORO 10-18-85 RUN ~1 6900-7570 DEN/NED PORO 10~18-85 RUN ~1. 6900-7570 DEN/NEU PAW 10-18-85 RUN ~1 6900-7570 DEN/NED RAW !0-18-85 RUN #1 6900-7570 CYBERLOOK 10-18-85 RUN ~1 6950-7547 ~ .~5 "/ DIL/SFL ,~ 10-11-85 kUN ~1 3972-8648 ,"- 2 ,,~ DIL/SFL 10-11-85 RUN %1 3972-8648 ~5 DEN/NED PORO 10-11-85 RUN ~.1 7900-8622 ~2'''~- DEN/NHU PORO 10-1!-85 RUN ~1 7900-8622 5'~'~ DEN/NED 'kAW 10-11-85 RUN ~1 7900-8622 "~2 "->.,,%,. DE N/.N EU PAW' 10-11-85 RUN ~1 7900-8622 CYBERLO~K 10-11-85 RUN %1 8100-8550 IPT DIL/SFL-GR 09-21-85 RUN %1 3852-8461 ~'~2 "'~ DIL/SFL-GR ~9-2!-85 RUN %1 3852-8461 ""'~" '- DEN/NEU PORO 09-21-85 RUN ~1 7000-8436 '~2"" DEN/.NEU PORO 09-21-85 }~UN ~1 7000-8436 "~5" ~ DHN/NEU PAW 09-21-85 t{UN ~1 7000-8436 -~'2" -~ DEN/NED RAW 09-21-85 /--~Y~ERLOOK --- 09-22-85 ~RFT LOG ~ 09-21-85 ACKN OWLED GE D: URRtER .~ON d*BL DISTRIBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL j. RUN fl 7000-8436 kUN ~! 7750-~330 DATE: STATE OF so~[o UNION ~THMELL*BL 'VAULT/ANO* FILMS ARCO AlasKa. Inc. Is a SuDs~diarv nf A~l=.,;.o;-~.~:-,-,"--- ~' * ,-~. STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION COl',, ,~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling we~(Yl~] Workover operation [] 2. Name of operator 7. Permit No. ARCO A]aska, Inc. 85-221 8. APl Number 50-- 029-21442 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 575' FSL, 762' FEL, $ec.7, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 25632 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. October ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2000 hrs, 10/5/85. Drld 12-1/4" hole to 3990'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8660'TD (10/11/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8554'. Secured well & RR ~ 0600 hfs, 10/13/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 104'. Cmtd w/185 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3975'. Cmtd w/1100 sx AS III & 400 sx Class 7,', 26.0#/ft, J-55, BTC csg w/shoe ~ 8641'. Cmtd w/400 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/$FL/GR/FDC/CNL/Cal f/3972' - 8656' 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~,[~S~(8 0it & Gas Cons, O0mmioe']0~ SIGNED }~~~ TITLE A,sooi a,e E, gi,eer DATE /0' Z~'~ NOTE--Report ~n this form is required for ~a~h ~alendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Fnrrn 1 m4r)4 TEMP2/MR19 Submit in duplicate MEMORANOUM TO: THRU: State of Alaska ALASKA OIL AND GAS CONSERVATION COMbIISSION C./~na~terton DATE: October 11 1985 ' i~.~.Y "' FILE NO: D. HRH. 7 6 Lonnie C. Sm i 6h Commis s ioner TELEPH ON E NO: FROM: Harold R. H~wkins SUBJECT: Petroleum inspecgor,~'~ . BOPE Test ARCO, KR~ DS 3A-5 Permit No. 85-221 Kuparuk River Field Tuesday, October 8, 1985: While I was on the slope, subject of ~her~epOrts, I witne~s~ed the BOPE test on ARCO's K.R.U. DS 3A-5 Well. There was one failure, the lower pipe rams failed and were replaced. I filled out an A.O.G.C.C. Report which is attached. in summary: I witnessed the BOPE Test on ARCO's, KRU DS 3A-5, that Parker crew 141 perfomed for ARCO. When the BOPE test was com- pleted, they were satisfactory. Attachment 02-00IA(Rev. 10/79) o&g #4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date · Well Reserve Pit Mud Systems Trip Tank Pit.Gauge Flow Monitor Gag Detectors . .-. Operator Afl~'~ ~A~ ~/f~,,~, L o c a t ion: S e c ? T~R ff~, d M Drilling Contractor ~~ Location, General ~ Well Sign ~/~ General Housekeeping ~ Rig BORE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves · H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Visual . Audio Test Pressure~ Representative Permit ACCUMULATOR SYSTEM Full Charge Pressure ~~0 psis Pressure After Closure /~¢~ psig -- Pump incr. clos. pres. 200 psiK --- min3~ sec. Full Charge Pressure'Attained: ~- min ~ sec. Controls: Master_ ~,~ Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower KellM Ball Type Inside BOP Choke Manifold No. Valves 9 Test Pressure ~~ Test Pressure Yz~ Test Pressure _~_z~,'~ Test Pressure ,? Test Pressure No. flanges Adjustable Chokes. ~,~- ~/~ ,drauicall, ~erated choke d/~~ Test Time" ~- hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. .- / Distribution orig. - AO&GCC cc - Operator September 17, 1985 ~Ir. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-5 ARCO Alaska, Inc. Permit No. 85-221 Sur. Loc. 575'.FSL, 762'FEL, Sec. 7, T12N, R9E, UM. Btmhole Loc. !422'FNL, 1067'FEL, Sec. 17, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not inden~uify you from the probable need to obtain additional permits required by law from other governmental agencies prior to co~encing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very~ truly yg~rs, ~ /%-: / Lonnie C.~ ~mith Co~issioner of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo., 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-5 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 3A-5, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on September 18, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JFB/tw PD/L167 Enclosures RECEIVED S£p I 0 Alaska Oil & Gas Cons. Cornrniss]o/~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. DRILL REDRILL DEEPEN [] STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COl~,,vllSSlON PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE DEVELOPMENT OIL D~X SING LE ZON~( ^ DEVELOPMENT GAS [] MULTIPLE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 575' FSL, 762' FEL, Sec.7, T12N, RgE, UM At top of proposed producing interval 1273' FNL, 1439' FEL, Sec.17, T12N, R9E, UM At total depth 1422' FNL, 1067' FEL, Sec.17, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 73', PAD 40.9' ADL 25632 ALK 2565 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-5 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $ 500 ~. 000 /'~:~,~,J~. 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 14, Distance to nearest property or lease line 1067 feet 15. Distance to,~,.[est drilling or completed 3A-4 well -.~;~' @ S~-p,(~:~~ feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8596' MD, 6374' TVD feet 2560 09/18/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 47 Ol (see 20 AAC 25.035 (c) (2) 2686 psig@__80° F Surface 3087 psig@ 5997 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 24" 16" 62.5# 12-1/4" 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade J Coupling J Length H-,+o / '-55/HF-EIW BTC J -55/HF-EIW BTCI 8565' SETTING DEPTH MD TOP TVD 80' 32' I 32' 3894' 32' I 32' I 31' I 31 ' M D BOTTOM TV D 1121 1-12' 3926~ 3172' 8596'1 6374' I I QUANTITY OF CEMENT (include stage data) + 200 cf 890 sx CS III & 400 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8596' MD (6374' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16". conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psi~ upon installation and weekly thereafter. Expected maximum surface pressure is 2686 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing.the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A-5 will be 25' away from 3A-4 at the surface. ~There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pUmping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby certi~y~that the foregoing is true and correct to the best of my knowledge SIGNED ////~//~f//~,~ TITLE Regional Drilling Engr. DATE T h e space b,~ ~° r~o~rn~I;~ss i~n u S~- CONDITIONS OF APPROVAL Directional Survey required APl number /:~ES [~]NO 50_~ 'L.'~ -"L. ( ~'~ SEE COVER LETTER FOR OTHER REQUIREMENTS Samples required I Mud log required []YES .[~N O []YES ~LNO Permit number .... I Approval date J-~ //2 ,09/17/85 L. ,COMMISSIONER DATE September 17, 1985 by order of the Commission Form 10-401 (JFB) PD/PD167 Submit in triplicate PERMIT TO DRILL 3A-5 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. J ~ i ' I'61 ,FEL 2N. RgEi 1,320' FNL.i ,320 FELt SEC. I?, T 2N,:RgE ' 68 ' DE ' 5o87~' ,i 'tENTER SOUTH 1895 EAST.4?21 .TO gOCAl'iO 1422' FNL. SEC, I?. T 1067" JFEL~ 2N RigEI I _.;~__:_; ~ ;_.' :_~_' .... .._i..[ .... __i - · ' .i ' ~ ' . ....... _ ......... -.-;~:-~oo.:;-'.'-.-~-:'-~_O00j~-.---~-~.o~o-~S-::~ 8oo ' FOo ----~. 6.00 -'.500 ' ' 400 ....... .......... '---: ' - : ' :i-~ ' t I ~ '-i ......... I '1 ...... - i .... o .... I- ., ·~ - i -- . ~ · . ,... . ~ ''' ;~ :'!i: ~ '~ ;;;!!-~ -;"~: i_:_.-'~L_i'- ':; KUP-ARUK--FI-ELI:);--NDRTH-SL-BPE;-'^K--:--~ ...... :--~-::_:_¥:--,-:~:~:~--'_-:~--:-~.--~-:-;:~~---:__-:~-:-::~:-. ~ :_£X.,_, ;_:' ._ ~_ ..'' _._, ./~...':_: ..... ~ "-._-: : ;--? :.-? :.-:~-;-i -..-:~ !;-.-:--:~ ~-:/~ ! '- - ,i ...... ' '- ...... ~ .... ~ - ~ .... ~ ..... ; : _:_.._.~. : - ; ~ '. , - - , I ~ _ ' ' ~.. ' ..... ~_L_;-. · ._ :..~ .... :~-:~-- i ~ L PATHS EXTEND .~-"- THIS' ¥ ! EW_I NG. _W.I ND.O.W ...... · :. , . . .... ; .. _ . . ' :_-._ ; .:. '_ ; - .-;_...;' 277 455 ' ' ~ ~' .... -"--'-:-i .... --- - 154.0 -' : :: ---:--- -:---; - ; ~- :. - ! : i.:-;--~,-: ; ; ' : _ ,",~B~ ..... 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' . _ · .... ; . . -;:~-':~:'t/~,~:~ :'.~ ~-:,-.-,--,~/::~.-,.~-,.-,::.:-'./J'-.: ~---:-,---:~--~.--:-: ..... ----~-:.~P.~,-~.~S~i~:-.\ - -.-.:-:-. - -:-~----. Y ~: .~..- '-.~: =f-H'/---'-i-_-f-f~-:+.-.::--~: :: f ..... -:---~--.~. ~ '--i--:,---~--- .... : .... :-~.--: ............ - ? .... ;---~--~. ..... -'--,-~-. ' . .~! ....:-.~-- ,I.-..~-- -~.------;--4' .... . .-: -: .....~ .... ' ..... -' .- , -' ::-.~ ........ ~-------.-;--- . , ..... : ......... :-]-~0:/ ..:> _ : :-. _~ -..-- !. .; 'J-.--:-;.-- !. ~-.._ .;---'J_~ : . _ :! ..... '~lr~i~..:rhl & c,~s e_.or!_~. ~,:_m_~ o.r~..__.._~ ....... - : - - - ; · · ~ .. ' ' - . ~ I .... --i ' ' ' ~ -, . , : . i . . , y-~ ..... ---:-.~...-T-: .: ,-T-:-T-:-i--:'-:'-:---f-: .~,., ~ -.---"i .... i - : : -"---~ ....... 7-:-- i ' % · -" 7- '-; ...... ~7 -~' --: ........ ~ .... : -,~-.-~-~/½-:---~--~-.----f · --+---- -;------,- : ................ -~ ..... ~ ........ , ....... -:- - / ....-: ----: ~ :--4-'_ ~ -----4-;--S-~-t .-,-----;~-:--4 --;--~--c-;-4-. '- -/---~ --~_ : · *~: - -~'~.~-4--?- -- . ....... ' -; .......... . · - ; ;':/ ; ,.~ ; · ',~ {" · i--L-.:, : ~,J ! .... .' ..,/ [ ., '~ ~ ; : _-.; .... : ........ · '_ .... -',, -'-'--:- "::'':' '.{:--q~'Z.-:": :~+-" .... -'.-:..~li--:'~-:-' : .... :'-:; ..... ' ............. KUPAIRUK IRI VER UNIT 20" DIVEDTER SCHEMATIC DE S CR I PT I ON i. 16- C~CTOR. 2. TANI<:O STARTER HEAD. 3. TABOO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TAKI(O UPPER QUICK-C~CT ASSY. 6. 20' 2ex:x3 PSI DRILLIN6 SPCX::IL W/I0" OUTLETS. 7. I0" HCR BALL VALVES W/lO' DIVERTER LIh~So VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Ah,N.~AR PREVENTER. 8. 20' 20CX3 PSI Ah~JLAR PREVENTER. 7 6 7 ,MA} NTENANCE & oPERAT.] ON ECEiVED !. UPON INITIAL INSTALLATIC)N, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE At~X~JLAR PREVENTER A~D BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ArtiCULAR PREVENTER I N THE EVENT'THAT AN It~c'LUX OF WELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE Ah[:) CLOSE APPROPR I ATE VALVE TO ACHIEVE ~Ihl:) DIVERSION. DO NOT SHUT IN ~LL Anchorage UI'~:)ER ANY CIRCUMSTAI'~gES. 7 6 L DIAGRAM #1 ~ I~-5/8" 5C)(]O PS;[ RSRRA BOP STA I. 16' - 2000 PSI TAi~CO ST~TI~ ~ 2. I1' - ~ ~I ~I~ ~ 4. 1~8' - ~ ~I PI~ ~ 5. 1~8' - ~ ~I ~I~I~ ~ ~~ ~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ ~I~ ~ ~ T~, ACCLMJLATOR CAPACITY TEST 1. (~C~( AhD FILL AC~TCR RESERVOIR TO PR~ LEVEL WITH HYDRA~IC ~UID.' 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ 1~ ~I ~~ ~ ~' ~~T~. 3. ~ TI~, T~ ~ ~ ~ITS SIXThlY ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 ,i 4 3 2 -! . 13. RECEIVED,.. S EP I o 1985 13-5/8" BOP STACK TEST I. FILL BOP STACK AIND CHOKE I~IF~ WITN ARCTIC DIESEL. 2. ~Cl< THAT ALL LOCK D6~ SCRE~ IN ~E1.LNE. AD ARE FULLY RE-FRACTED. SE. AT TEST PLUG IN WELIJ-F_AD WITH I~IN6 JT AIND RUN IN LOCXI:~ S~. LIllE VALVES ADJA~ TO BOP STACX.. ALL OTi-IER VALVES At~ Q-EKES SHOJ.D BE ~. PR~~ UP TO ~ FC~ lO MIN ~ PRE~ TC~__~ PSUAN) MCI_D FC~ I~) MIN. 5LEF,9 ~E~ TO 0 ~ 5. OPEN AINNJ_AR PREV~ AN:) MANJAL KILL AI~ C:M~E LINE VALVES. CLO~ TI:~ ~I~E ~ AI~ II(iR VALVES CI~ KiLL AN) CaChE 6. TEST TO 250 PSI AINI~__~!-~S IN STE~ 4. · CO~IM..~ TESTING ALIa--V'AEVES, LIINF_.5, AINI) WITH A 2_50 PS! LON A~ 3000 PSI HIG4. TEST AS IN STEP 4. DO NOT PRESSU~ TEST ~h' CHO(E THAT NOT A FLLL C~.OSING POSITIVE SEAL Q-KiI<E. 6~LY ~I(2N TEST CHOKES THAT [20 NOT F-~LY CLOSE. CPEN TOP PIPE RAMS AhD CLOSE__ BOTTC~ PIPE RAMS. TEST BOTTO~ PIPE RAMS TO 2.~ PSI AhD 3000 PSI. ~ 60TTCM PIPE RAMS, BACK OJ'f RL~ING JT CLOSE BLIRD RAMS AbE) TEST TO 250 PSI Ah~ PSI. · c~ ~INO RA~S A~ ~=-T~IEVE TEST PLU~. ~<E SU~ '~ANIFO..D A~ LI~ES A~ FU_L OF FLUID. SST ALL VALVES IN DRILLINS POSITION. ~2. TEST STAr, CCIPE VALVES, KB_LY, ~_L¥ COCXS, mILL PIPE SAFE'r¥ VALVE, A~ INSICE SOP TO 250 PSI A~ 3000 PSI. EECO~ TEST IhFORVlATION ON BLOCKX.rT PR~-VENq~ TEST FC~, SIGN, AhD SEN] TO DRILLIN3 SUPERVI~. PEEFC~ ~ETE BOPE TEST AFTER NIPPLING UP AhD WEEXLY THEREAFTER ~IONALLY OPERATE BOPE DAILY. Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3A Pad Wells 1-16 ~ Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Si ncerely, · Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED 019 5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany 7 8 NOTES - C..:'CRDINAT~S 4, RE A.S.R, ZONE 4 2. SECTION ~.,NE DISTANCES ARE TRUE. 3. HOR!ZONTAL POSITIONS BATED CN THE D.S.-TA WEST & 3AMID PER LHD E), ASSOC. ~.VERTICAL POSITION BASED CN SA EAST ,.iA MID PER LHD I~ ASSOC. 5.OS. ELEVATIONS INTERPOLATED FROM S/CDWG. CED- RlXX- 3020 rev. ~ ~-~_~- F ROBERT BELL ; ~. ~.-, , No. HEREBYCERTIFY THAT I AM PROPERLY REGISTERED AND LISCENSED TO PRACTISE LAND SURVEYIN6 IN THE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14,1985 LOCATED IN PROTRACTED _. 7 THIS SUF 18 AS BUILT 1- Y=5,996,860.05 X= 507,712.01 478' FSL, 736' 2- Y=5,996,88~.17 X= 507,705.57 503' FSL, 743' 3- Y=5,996,908.32 X= 507,699.06 CONDUCTORS I- 16 LAT= 70°24'09.520" LONG= 149°56' t~,.020" FEL, 36.8' CC, ~.0.8 PAD LAT= 70o74' 09. 758" LONG: I-~9°56 I/+.207" FEL, 3.5. 8 0'3, :,0. 9 P~O LAI'= 70°2~'0 .']95" LONG: 14'-J°56 1L,. j97' 527' ;SL, 749'FEL, 36.7 OG, 4- Y=5,996,932.72 LAT= 7002~'10.235'' x= 507,692,55 LONG: I49°56 1~.58/" 551' FSL, 756' FEL, 36.70G, ~0.8 PA5 5- Y=5,996,956.61 LAT= 70°2~'I0.~70'' X= 507,686.21 LONG= 1~9°56 14.773" 575'FSL, 762'~EL, 36.5 OG, 40.9 PAD 6- Y=5,996,980.84 LAT: 70°2~' 10.709'' X= 507,679.66 LONG- 149°56 14.963" 599' FSL, 768' FEL, 36.50G, 40.8 PAD 7- Y=5,997,004.90 LAT= 70°24'10.945'' X= 507,673.26 LONG= 149056 15.15I" 623' FSL, 774'FEL, 36.5 0~, ~1.1 Pig 8- Y=5,997,029.03 X= 507,666.81 6~7' FSL, 781' 9- Y=5,997,101.24 X= 507,647.70 720' FSL, 800~ 10- Y=5,997, 125.66 X= 5,J ,640.89 LAT= 7002~' 1I. i8.)'' LONG= 149°56'15.33:~'' FEL, 36.4 OG, 40.9 ~AD LAT= 70°24'11.893'' LONG= 149°56'15.896'' FEL, 30.3 OG, 41.7 LAT= 70°24'i2.134'' LONG= 149°56'16.095" 15- :EIVED /44' :'L, 806.' FEL, 36.30G, ~,1.6 P~lO 11- Y=5,99',149.84 LAT= 70°24'12.371'' X= 507,634.4/+ LONG: 149056' 16.283" 768' FSL, 813 FEL, 36.20G, ~L.2 PAD 2- Y:5,997, 173.97 LAT= 70024' 12.509" X= 507,627.96 LONG: 149o56' 16.,/ ~" 792' FSL, 819 FEL, 36.10G, ~,1.3 13- Y=5,997, 198.08 LAT= 70°2'.,' !.Z.8~.6" X= 507,6Zl.q8 LONG= 1~9°56' .~17' FSL, 825 FEL, 36.0 OG, ~,I.g ~- 14- Y=5,997,222.29 LAT= 70°24' X= 507,6[5.0 LONG= [~9°55' 16.3~.~'' 841' FSL, 832 FEL, 35.8 OG, ~l.0 PaS Y=5,997,2~6.44 LAT: 70°24'13,322'; X= 507,608.55 LONG= 149056' 17.03'.~" 865' FSL, 838 FEL, 35.6 OG, ~,1.3 01985 - x= 5n~,b02. 10 LONG= I/,9°55' 17. .,, Gas Cons. Commis~'~' ; '-, ~ ~ ~ ~EL, ~5.5 .],~, ,',I. ~ -- knchorage ~uparuk Project CONDUCTOR . AS-BUILT LOCATIONS , Drafted by:~ DwQ.,o.:NSK 85-16 CttECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM (1) Fee (2) Loc APPROVE DATE '(2 thru 8) (9>"thru 12) ('10 'and (13 thru (22 th~u/26~ · Is the permit fee attached ......................................... 2. Is.well to be located in a defined pool ............................ 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells ....... '"''''''.''' 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ..... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... o 10. 11. 12. 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO Does operator have a bond in force f~l_/ .... Is a conservation order needed ...................................... Is administrative approval needed Is the lease number appropriate ..................................... Is conductor string provided ......................... , ............. Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production'stringslii Will cement cover all known productive horizons .................. Will surface casing protect fresh water zones ................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate wellbore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: REMARKS peo logy: .Eng i,n~eer lng: HWK ~ LCS ~)~ BEW JAL ~'~,,,-. ' ' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special:effort has been made to chronologically ' -: . .. organize this category of information. t, VP OlO.qO~ VEPIFICA~ION 6ISTING PAGE ~E~VTC~ NAME :EDIT DATE IR5/10/16 ORTGTN : REEL NAME t149216 CONTiNUA?ION # :01 PREVIOUS R~E5 : COmMeNTS :SI~RAR¥ ~APE *, TAPE HEADER DATE ORIG~ ~0000 ?APE NI~ :OB~2 CONTTNUATI~N # :01 PREVTOI.IS TaPE COM~N?S :LI~R~RY TAPE FISE NA~ ~EDT~ ,001 SE~V~C~ NA~E I VE~$TO~ # I ~AX~U~ [,E~G?H I 1024 r~t,E TYP~ l ~R~VYOI,IS FTLE' % ~N~M CONTENTS CN i ARCOAt, ASKA ZNC ra = KU~A~UK SECT~ CDt'N, ~ SbOP~ ~NEM CONTENTS UNIT TYPE CA,'t'E siZE CODE 000 000 000 000 000 000 0 0 000 000 016 O65 00, 000 00~ 065 000 065 0~0 002 06~ 000 004 O6 000 002 0:6' 000 0~2 065 000 006 065 000 003 065 TYPE CATE SIZE CODE: 000 000 001 O65 LVP Ola,HO~ VE~IFICA?iON LISTING PA~E 2 ~ SCHLUMB~RCER ~ AbASKA COMPUTING CENTE~ COUNTY = NORTH st, OPE BOROUGH STAT~ = AI~ASKA JOB ~U,B~R AT ACC{ 70872 RUN #1~. DAff'E bOGgED{1,1'. OCT-~5 ~DPl ~, OG~EW CASING = 9,625" P 3974.0' - BIT SIZE = 8.5" TO 8660,0' YPEFI..UTD = WI, XC. PObYM~R ENSITY ~ 10,20 b~/~ RM = ~,800 m 47,0 DF ISCOSTTV = 40,0 S RMF = 4.560 ~ 60,0 D~ H =. 9,5 RMC = 3,060 P 73.0 D~ Phi,liD LOSS = 6,6 C~ RM AT BH? = 1,.]68 ~ ~ATR{X SANDSTONE ***** ?HIS DATA HAS NOT BEEN D~PTH SHZ~?ED - OVERI.,AYS ~IEbD PRINTS LVP OI~,HO~ VERIFICATION LIS?ING PAGE 3 DATA ~VAILAB6~I 8648.0 TO 3972,0* fOrMaTION DENSITY CO~P~NSATBD LOC DATA AV~XLAB6~ B622,0' TO NOTE: F~EI',D TAP~ hATA (DXt,) IS /kPPROX, ?iVE FEET LESS THAN THE BLI.IEL:I. NE DEPlrCTS,~ TYPE ~IZE REPR COD~ ENTR¥ 2 ! 66 0 4 I 66 1 8 4 73 60 9 4 65 1,6 1 66 ! 0 1 66 0 ~ATUM SP~CTFTc~TTo~ B6OCKS LVP 01~.~0~ VERIFICATION LISTING PAGE 4 ID DEPT SFLU SP ~IL RHOB ORHO rDN NRRT ~DN MCNL ORDER # FT O0 000 OH~ 00 ~20 OH~M O0 120 OMWM O0 120 ~ O0 010 ~AP! no 310 GAPI O0 3t0 ~N O0 280 G/C3 O0 350 ~/C3 O0 356 O0 42O O0 000 PU O0 ~PS' O0 330 CPS O0 930 ~SS ~0~ NO. CODE (OCT~o~~ r~nG TYPI?, CbO0 0 0 4 I ~8 00000000000 O1 0 0 4 46 0 0 4 44 0 0 4 O1 0 0 4 01 0 0 4 Ol 0 0 4 O1 0 0 4 02 0 0 4 01 0 0 4 O~ 0 0 4 O0 0 0 4 O0 0 0 4 31 0 0 4 .t0 0 0 4 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00~00000000000 1 68 O0 00000000000 1 68 00000000000000 1. 68 0~00~000000 I 68 00000000000000 DEPT SP RHOB OEP? RHOB NPHI SP RHOB MPHI DEPT $P RHOB NP~I DEPT ~HOB NPHI SP R~HOB 868] ~000 -7~..2227 ,3557 ~R~O 34,~2~5 8~00o000 90 NC~ 8400,~000 -99,,4727 ]899 DRHO 3:6895 8]00,0000 -80.~2~? ~a ~,~00 31'~7383 8200,0000 SFLU 8 ~R~O 26~4'48 ~C~h 3538 ~R~O 0 1936 7 86 0 2381 3.~8 2o8, 1, ooo 40 0503 NRR? 6875 rC~b o05~5 .5273 ~R .0615 NRRT · .~5000 rCNb 8F; 148 ~R 0,.0166 MR.AT 2159,,5000 rC~L 6..~937 ~b[): 8 !. 2773 GR 0,.05'62 NRA? 2379,5000 rCNb 2 3831 IbM 91 3398 CALl. 3 02~6 RNRA R31 .3i25 t O0, ' CALl ~.9944 RNRA 601,812'5 $ 86 3 668 RNRA e125 2'148 CALl 660~:887081~5 RNRA CALl 21.8330 {bP 19.6299 I[,~ 70,.4648 ~R 70,~648 CALl =0~.0313 ~RR~ 2,5706 RNRA 204~.~000 rCNb 11.10.6875 01~2 NRRT · 6523 CALX 12~,6682 lmNRA 9, 8 3, O' 6.:5945 ,08 ,7468 2,~249 t, VP 010.HO~ VERIFICATION L~S?XNG PAGE 5 DEBT ~EPT iEPT NPHI DEBT DEBT RHOB OEPT OE, PT ~0~ ~PHI DEPT RHOB DE~T RHOB MpH! DEPT 42.9687 NCNb 1762,6875 FCNL 7~oo oooo sFt,u 2,3772 DRHO 47,9004 HCNL 7~O0.0000 SFLU -5~.9510 ~R -09 ,~500 OReO -999,~500 ~tCNb 2 1409 111~3398 0.0347 NRAT 1146.6B~5 ~CN~ ~.R5B7 ~LD 231.~815 ~R '990. 500 NRAT '999.2500 FCNL 7ZO0,O000 SFLU 5 0750 7LD 40.1445 ~R 240.:3125 ~R -099,~500 DRHO -990,2500 NRRT -~90.2500 ~CNL -990.,~500 FCNb 7.600,?t0500 RFLU . 59.. 10 ~R. 999,2500 DRHO -099.~$00 NCNb 1500.0000 SFt. U -51,7383 ~R -099,2500 DR,O -999,~500 NCNb . 9319 13 ,6815 OR -99~.2500 ERRT -99~,2500 FCNL 4 ~054 -999:i 500 rCNb 0000 SFLU 3633 OR 2500 DRHO 2500 NCNb 7300 -49 -999 -999 7200 0000 8Fi. U -5! 1445 ~R '999 2500 DRHO -099 2500 NCNb 7~00,,0000 SFLU 72.72~7 CR 2500 :090. DRHO 99q.,2500 NCHL 7ooo oooo sr~.,u 3,'/756 121; 0808 -999,2500 lYRAT -'990.2500 5.49~8 ~LD 99.$2 3 CR -999,.2500 NRAT -999.2500 rCNb, 446.6406 ].20i4 .'t LI~ 3,6 178.6875 CALI 9. 3.5627 RNRA 3,8459 468,1406 CALI 3:8792 RNEA 436.6406 ~..2327 IbM -a99"2500 CALX -999.2500 RNRA =999.2500 3,7092 -099.2500 CALX -~99,2500 RNRA -099,2500 -099 5~0 CALX -999 RNRA . ,,:.{5OOsoo 4.1510 -~99,2500 CALX' ,500 RNRA '099'~500 2,'5139 -999,2'500 CALI ~999,2:500 RNRA '990,2500 -999~2500 CALl ~999'2500 RNRA ~999~2500 3 8752 -999 O0 -999 ~5 50O -099 2500 999,2500 CALl 999,2500 RNEA 999*2500 4 9968 999' -, .2500 CALl 9,986~ .4,0007 -999. ,500 3,7600 -999' 2500 '"g~q, ~500 "099,2500 -99q, 2500 2,6096 '999,2500 .099,2500 4'!898 'g99, '999, 550000 -9'99,2500 -.999,2500 4,6510 2500 ~ 5 0 0 5. ~906 -999, 500 t.'VP OlO.~02 VERIFICA?ION hISSING PAGE 6 RHOB -090.9500 DRHO ~EPT SP -54,~258 RHOB -099,~500 NP~! -q99.~500 ~FLU ~FLU ~R SFLU ~R ~FLU DRHO ~R NCNb SFE, U DRHO SFt, U 8F'LU ~RHO NCNb 8FbU ~R DEPT bSO0.O000 Spo. -42._67~8 RH ~ ~099.2500 MpH! ~99,~500 DEPT 6700,0000 ~PH -60.8945 OB ..<)99.9..500 MPHI DEPT 660g,0000 ~P '4 ,~570 R'HOB -999,~500 NPHI -g99.~500 DEPT 8P RHOB NPHI 6400,0000 -50. 6]3' -999, 500 -q99. 500 DE'PT SP RHOB 6~00,0000 RHOB 6~00.0000 51,3633 -999,~.500 NP~I 6[00,0000 ,_64,9102 .g99,~500 .ggg,~500 P. 6000 0000 -'56: 4258 -999,2500 r)EPT 5gO0.O000 ~FLU -~99.~500 ~R~T -999.~500 -99q.~500 WCNb -~99.~500 ~.i702 ,b~ 2.2444 102.,52, ~R -q99.2500 -g99.2500 NR~T -999.2500 -99q,,2500 NRAT -q99, 0 -999.2500 ~CN5 -999,25 0 1,07'.7148 g~ -999 2500 -999,2500 NR~T -999':2'500 -999..2500 FCNI, -999.2500 2 5413 ,bD . 2.,026 ,27:$3,8 CR .999,1~00 -099.2500 MRAT '999. O0 -999.~500 FCML -999.. O0 105 ~3 OR '999,25 0 '999 2500 NRA~ '999,25 0 -~99 2500 ~CNb -99q,2500 ~..]792 XbD 2, . 9,. soo -999,2500 F¢~ -,,,99, 500 1, t),08~8 ~R -999, 5 0 -999,2500 NRAT -999,2500 '999,9500 FCN~ -999,2500 · 35)8 ~bn '2.678,0 89,0273 ~R -999,.~00 "999,2500 NRA, T '999. 300 -999,2500 FCM~ -999,,. 500~ 80'0273 CR -99~-2~00 -99g~250 NRA2 "99q.,2500 -99q,~508 WCNS' -99q,~500 ~,.6448 i~D ~,~8~0 R NRA CAt, I ~A£,I ~N~A WNRA CAt,]: RNRA CALI RNRA CALX RNRA CA[~Z RNRA CA ~N~A CAI,! RNRA -999,2500 2 3088 -999~2500 .~99,2500 2,'17~0 0 2,~042 -999.2500 -999,2500 -99.,. 0 -999,:500 3,0295 '-999,2500 -99q,2500 3928 999,2500 2,6445 -q99,2500 -999.2500 2,$803' 999,250'0 -999', 2,6018 -999,.2500 -999,2500 2,8459 LVP 010,~0~ VEPIFICATION ETS?InS PAGE SP -61.9258 RHOB -099.2500 DRNO ~PHI -999.9500 ~CNL DEPT SRO0 0000 SF[.U SP · ,4102 ~R RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 5700 0000 SP -60!~445 RHOB -q99 2500 DRMO NPMI .099 2500 NCN~ OEUT 5600.0000 HOB .~99,2500 DRHO NP~I 099.~500 ~C~ DEPT 5~00.0000 SF~,U SP 64, ~R 500 DRHO NPH! 099.~500 O2 HOB -999; 500 DEPT 5300,0000 SFI, U SP -66.,.6602 RHOB -999, O0 DRHO ,PNI -~~q.{~O0 ~,CNL D.EPT 5200 0000 8FLU SP -64' RH, OB .qgq,~ 02 ~R 2' O0 ~RHO ~PHI -q99'~ O0 ~C~b DEPT 51,00 0000 SFt, U '~0 RHOB MpH[ -q99,2500 DEPT 5000,.0000 SFLU SP -79,~477 RHOB -q9'9.~500 ~RHO NP~I -099.,~500 NCNb DEPT 4~00,0000 ~FLU SP 7,,4.9i02 ~R RHOB -999.~500 ~RHO NPHI .-q99,~500 NCNB 93.2773 GR -999.2500 NRAT -99~.2500 rCMb 2 3948 IbD -999. NRA -qgq. 9500 FCNb 5647 TED .99q~2500 qRA? 999.~500 F'CNb 84. 71,3 GR -~99 2500 MRAT -q9q:2500 FCNb 77:{5148 GR .'999,2500 rC~Ib 89,6523 OR '999.2500 NRAT '990'2500 FCNb 2 -999 63 2500 2500 .~342 TLD -999.2500 -999.2500 FCNL 2 ,. :27 17 .TLD 108,7773 DR -.999,2500 ~4RAT '999,2500 F'CNL 3 ].04 ~952 TLD 02.3 GR -999 2500 ~RAT -999 2500 FCNL ],,0393. !C,D '999 500 ~RAT '999.~500 WCN{~ -u. 99.2500 CALX '999.~5500 ENRA 'q9q, O0 2.6506 -999.2500 CALI -999.2500 RN~A -~99.2500 2 1''756 -999 2500 · .999 2500 RNRA -999 2500 2,8459 TLM -999.2500 CALl '"999, '2500 RNRA "999.2500 2 1,249 IbM -999 2500 CALX -,)9.0' 2.7229. -999:~500 CALl ,,~99 500 RNRA "'999,.500 9 500 -999' 500 RNRA -999 50O '999 5~0 . CALl, -999 500 ~NRA: '999, 5~0 CAlX 5 0 'q99,.' RNRA: -99~, 500 '099,2500 RNRA -~99,2500 ] 4944 -q~O 2500 CALl '999 ~ 500 '~99 ~500 -999,2500 '999.2500 -999. 2500 2,7190 -999,.~500 -999,2500 2'i186 -999., 500 -999'. 500 2, 3 .999,:;! 1 2,6545 -999,2'500 -999,2:500 2' 3~ .q99,_~$09 0 -999,2500 2,531' 4 -999,2500 '999,2500 2,5,764 -999,, .~00 "999, ],6174 -99~,2500 ,I596 '99 , 1500 "999, 8P -85!]477 GR RHOB -~99 2500 DRHO NPHI -ggg 2500 MCNL DEPT 4700 0000 KFLU RHOB '999 ~500 DRHO gPgl -999o~500 NCNb DEPT 4600.0000 SFLU SP -81,4102 RHOB -~9~.~500 ~RHO OEPT 4500.0000 SFLU SP .-86,~477 RHOB 999,2500 DRHO WP'HI '999,~500 NCN~ ~EPT 4400,. 77 ~R RHOB -~99.~500 DRHO MPR! -999.~500 MCN5 DEPT I~00.0000 SFLO SP '9],~227 GR RHOH ,999,,~,500 DRHO ~'~P~ 4~00 0009 mF~U RHOB .~,9,9,1602 GR .2500 ~C~ OEPT 4100,0000 SFLU $:P -9:~,,9102 Ga D,EPT 4000,~ 0 SFE. U RHOB -999,2500 ORHO NPHI -999,.~500 NCN~ DEPT 19S~..~O00 SP -{6,6670 GR RHOB 999,2500 DRHO ~P'HI -999.~500 NCNb ** F~L~ TRAILER *$ ,OOi 3 ~502 103!00?3 ~R -qgq 2500 HRAT -999.2500 rC~b 3.2874 95 65~3 -99 T . FC~L 3,6956 102,7148 ~R '999.2500 '999.~500 rC~b ] 5549 9313398 ~R -999,2500 -999 ~500 rCNb 5.3992 100o4093 '999.2500 ~RRT '999.2500 FCN~ 3,9768 YLD 99.. 500 148 GR '9~9, 500 NRAT '999,~500 FCN~ 999,2500 ~.!RAT -999.2500 ~.,9690 {5D 8.!i9023 GE 5~i~930 GR '999. 2500 .RAT -999.:~500 3.5823 -999.2500 1999.~500 999.2500 -999. O0 -999 ~500 -999~500 4 2546 -999i~500 -999 2500 -999.~500 4 0828 .9992msoo '999.2500 -999.2500 5.7429 ~99,2500 -999.2500 ~999.2500 . 3,9417 ~99.'2500 ~999, 5 0 '999,25 "999.2500 -999.~500 5,8718 -m99.2500 '999,~500 '999.2500 4',4343 -999.2500 '999;2500 '999.2500 ~ 24.,0~6 .999,.250~ 999,~500 -999.~500 CALl WNRA CALl RNRA CAL! RNRA YbM CALl RflRA CALl RNRA CA[,I ~NRA CAbI RNRA RNRA CabZ CAbI ],4299 '999,2500 '099,2500 '999,2500 -999,2500 . 999,2500 -999.2500 3,8 $ .999,3~00 0 -999.2500 5,5203 -999,2500 -999,2500 3,7268 -999,'2500. -999.2500 -999.~'500 '999, "999, 500 4,:687 "99~,.i500 -999, 500 ,2500 -99'9,2500 ~VP 01~.~02 VERI~ICA?ION LTS~ING PAGE 9 OATE : MAXI~U~ LENGTH : 1024 ~ILE TYPE : NEXT FIL~ g~E : ** T~PE TROIS'ER ~A?E :8b110/16 O~G~ ~0000 CONT?NUA?ION # ~01 ~EXT_TAP£ ~AME COmMeNTS :t,~R~RY TAPE ** REEL TRAILER ** DATE :~5/10/16 OR~G~N : ~E~ N~ME . :149216 COnTinUATION NEXT R~EL,NA~E_{_ COMM~N~S ,~,,I~R~,RY TAPE EOF EOF