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188-040
• • 1COU. 30.. is PF0 1!,45.4;2 Regg, James B (DOA) From: Jones,Jeffery B (DOA) Sent: Thursday, April 13, 2017 6:35 AM 147,p 611)417 To: Regg, James B (DOA) Subject: FW: 3H Deficiency Reports Attachments: 3H DEFICIENCY RPTS.pdf Looks like they are pushing back on this one. So far,they don't want to repair it like they have the other wells with this problem. Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 SCANNED ,JUL 1 4 ni? CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Wednesday, March 29, 2017 6:15 PM To:Jones,Jeffery B (DOA)<jeff.jones@alaska.gov> Subject: 3H Deficiency Reports Jeff—enclosed are the signed deficiency reports acknowledging receipt for11-1.22 and 3H-16. The reports have been sent to the responsible groups and I will send the completed forms with documentation when the work is completed. Thanks, Darrell Humphrey/ Matthew Raiche Production Engineering Specialist )11100" ConocaPhillips Alaska Ph:907.659.7535 I Pg:924 Mail: NSK 69 1 0 • State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: N. Slope KRF well aft.it 36.. 13 Date: 3/28/17 PTD: ,2,1.64-451— [(Acute J Operator: CPAI Type Inspection: SVS test Operator Rep: Matt Raische Inspector: Jeff Jones Position: SVS test Supervisor Op.Phone: 907 659 7535 Correct by(date): To be determined op.Email: NSKProdEngrSpecialist<n1139@conocophillips.coFnllow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected The surface pipe flutes are above the conductor allowing excessive well head movement that is causing stress on the flow line and AL line&requires repair. - Attachments: well head photo (1) Operator Rep /...4s) AOGCC Signatures: �,'114144-rc"..( AOGCC Inspector *After signing,a c y• •is form is a left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory Jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the Original file, may be scanned dudng the rescan activity or are viewable by direct inspection of the file. I g(~- 0-~-0 Well History File Identifier Organization (dooe) El Two~Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: 63 Diskettes, No. o Maps: Grayscate items' Poor Quality Originals Other: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds o Other TOTAL PAGES: 7~ NOTES' ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI Project Proofing i~) Staff Proof P_,,~ {','. a ~ r: PROOFED BY ~EVERL¥ BREN VINCENT SHERYL fv~ARIA LOWELL DATE. PA--G-ES-: '"~ ~-m e--m'~:r~~ SCA. NNED6'~" ~£',/ERLY BR[N VINCEN'[ SHERYO LOWELt ReScanned RE SCANi'JE O E ',' i O BI:~E N V~NCEr~1 SHERYL M,CRIA LOWELl. General Notes Or Co~,.-nmenls aboul th~s [lie ©ual~ty Checked • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ g~- o ~+~ 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 July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. 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, ~~ M.J. Loveland • ~~N~ Al~~ ~ 208 ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/30/2008 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 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30.06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 .188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder, P. I. Supervisor DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad Friday, Jan,uaw 26, 2001' I traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilot on WAG injector'30-05 tripped below the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90-day SVS testing at 30 Pad in the Kuparuk River Field. KRU 30 Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 12 wellhouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified t · Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ,Phil!ips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: ,K, upan~ / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS 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 CYC~ 30-01 1880730 ' 67 70 80 ' P P ' OIL 30-02 1880740 67 70 60 P P OIL 30-03 1880750 '67' '70 66 P P ....... OIL i , 30-04 1880620 67 70 65 P P OIL 30-06 1880600 30-08 18806401 '67 '70 ~'~ 70 P' P " ~)IL 30-09 ' 1886~10" '' 67 ' ' 70 '40 V P ' OIL 30-11 1880420! 67 70 ~0 P "P OIL 30-13' ' 1880400 67, 70 66 P P ' 'i)IL 30-14 1880390 30-15 188031067! 70 '70 P' P ' ' OIL ~O-18 1880260 ' 6;7' "70 55 P P ....... ~IL 30-20 ' 197045~0 - 67~ ' 701 ~0 P P ' OIL 30-05 '1880760 ~750~ 2000 ' 1100 3 P '1/26/01 ' WAG Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.'17% El oo oar Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested .and passed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska. Inc. Development X. 59' RKE 3. Address: Exploratory__ 7. Unit or Properly: P.O. Box 100360 Stratagrapic__ Anchorage. AK 99510-0360 Service __,. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1041' FNL, 2024' FWL, Sec 22, T13N, RgE, UM 30-13 At top of productive interval: 9~.~mber/~al n~b~ 1355' FSL, 1914' FWL, Sec 22, T13N, RgE, UM At effective depth: 10. APl number: 1173' FSL, 1946' FWL, Sec 22, T13N, R9E, UM 50-029-21803-00 At total depth: 11. Field/Pool: 1109' FSL, 1958' FWL, Sec 22, T13N, RgE, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7950 feet Plugs (measured) None true vertical 6901 feet Effective Deptt measured 7832 feet Junk (measured) Strip gun, DV, and tool string in rathole true vertical 6303 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 175 Sx AS I 110' 110' Surface 4322' 9-5/8" 1500 Sx AS III & 4339' 4046' 300 Sx Class G w/175 Sx AS I top job Production 7882' 7" 395 Sx Class G & 7915' 6872' 175 Sx AS I Liner Perforation Depth -~'' ~ '~ .'h~ ~ /iI ' measured 7612'-7642', 7638'-7660', 7860'-7700' 1~~'~ t true vertical 6620'-6645', 6642'-6667', 6676'.6693' SEP ? 199 Tubing (size, grade, and measured depth) 2-7/8", 6.5 lb/fi, L-80 @ 7449' Packers and SSSV (type and measured depth) Packer: Baker HB @ 7375' · SSSV: Baker FVLD @ 1789' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 5/11/98. Intervals treated (measured) 7612'-7642', 7638'-7668', 7860'-7700' Treatment description including volumes used end final pressure Pumped 252,939 lbs of 20/40, 12/18, and 10/14 ceramic proppant into formation, fp was 7458 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 520 319 185 1191 194 Subsequent to operation 820 651 408 1258 186 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended Service 17. I herel)y certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,,~, -~/. Title: Production Engineering Supervisor Date _ _ _ ~, ~, . Form 10-404 Ri ! 15/88 SUBMIT IN DUPLICATE~.~ ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(30-13(W4-6)) WELL JoB SCOPE JOB NUMBER 30-13 FRAC, FRAC SUPPORT 0501981326.1 DATE DAILYWORK UNIT NUMBER ' 05/1 1/98 A SAND REFRAC DAY OPERATION COMPLETE I' SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O NoI {~ Yes O No DS-GALLEGOS JORDAN FIELD AFC# CC# DAILY COST ACCUMCOST Signed ESTIMATE KD2171 230DS36OL $132,100 $157,401 Initial Tbg Pre~s Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann , Final Outer Ann 500 PSI 0 PSI 680 PSI 500 PSII 1500 PSI 500 PSI DALLY SUMMARY IA SAND REFRAC SCREENED OUT21 BBL INTO 45 BBL FLUSH' 252'939 LBS PROP IN FORMATION' 6956 LSD PROP LEFTIN PIPE. TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - GALLEGOS. SB FOR BLENDER. 10:00 MIRU BLENDER. TGSM. 11:15 PRIME UP AND PT LINES TO 10,520 OK. BEGIN BREAKDOWN AND SCOUR STAGES. 11:36 LOST ELECTRICAL POWER AND COMPUTERS AFTER I PPA STAGE. FLUSHED AND OVER-DISPLACED TUBIN( 13:10 ELECTRICAL POWER RESTORED. FINISH BREAKDOWN AND SCOUR STAGES. STEPDOWN TEST. SD AND CBT ISIP. PULSE TESTS. 14:55 BEGIN DATAFRAC. ADJUST PAD TO 275 BBL. 16:10 BEGIN FRAC. LOST PACKING ON PUMP #1. BRING ON PUMP #3. 16:36 LOST ALL PUMPS BRIEFLY. CAME BACK ON LINE WITH PUMPS #3 AND #4 AT REDUCED RATE. LOST PUMP #2 DUE TO HYDRAULIC FAILURE COMING ON LINE. CONTINUE FRAC WITH PUMPS #3 AND #4 AT DESIGN RATE. CONTINUED PUMPING PER PROCEDURE TO FLUSH. 18:03 259,859 LBS PROPPANT PUMPED. CUT PROPPANT AND BEGIN 7 BBL DELAY XL GEL FLUSH. BEGIN NON-XL GW FLUSH. SCREEN OUT.AFTER 14 BBL OF STAGE. TOTAL 21 BBL FLUSH OF 45. 252,939 LB PROP PLACED IN FORMATION. 6956 LBS PROP LEFT IN PIPE. SERVICE COMPANY - SERVICE DAILY COST AccuM TOTAL ,, $0.00 $844.00 APC $6,500.00 $10,550.00 ~ DOWELL $120,000.00 $125,000.00 HALLI BURTON $0.00 $5,601.00 "LITTLE RED ' $5,600.00 $9,722.00 SCH LUMI~ERG ER $0.00 $5,684.00 TOTAL FIELD ESTIMATE $132,100.00 $1~7,401.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 59' RKE 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Stratagrapic __ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: i8. Well number: 1041' FNL, 2024' FWL, Sec 22, T13N, R9E, UM 30-13 At top of productive interval: 9. ~mbe~~.val nu(~~ 1355' FSL, 1914' FWL, Sec 22, T13N, R9E, UM --'"- At effective depth: 10. APl number: 1173' FSL, 1946' FWL, Sec 22, T13N, R9E, UM 50-029-21803-00 At total depth: 11. Field/Pool: 1109' FSL, 1958' FWL, Sec 22, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7950 feet Plugs (measured) None true vertical 6901 feet Effective Deptt measured 7832 feet Junk (measured) Strip gun, DV, and tool string in rathole true vertical 6303 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 175 Sx AS I 110' 110° Surface 4322' 9-5/8" 1500 Sx AS III & 4339' 4046' 300 Sx Class G w/175 Sx AS I top job Production 7882' 7" 395 Sx Class G & 7915' 6872' 175 Sx AS I Liner Perforation Depth measured 7612'-7642', 7638'-7668', 7860'-7700' b/~/~_,~ true vertical 6620'-6645', 6642'-6667', 6676'-6693' Tubing (size, grade, and measured depth) 2-7/8", 6.5 Ib/ft, L-80 @ 7449' 8F_..P 7,~ 1999 _ -. Packers and SSSV (type and measured depth) Packer: Baker HB @ 7375' · SSSV: Baker FVLD @ 1789' ~,, , 13. Stimulation or cement squeeze summary Reperforate "A2/A3" sands on 5/6/98. Intervals treated (measured) 7612'-7642' Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns w/BH charges at 2 spt, 0 deg phasing, fp was 1400 psi. 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mot Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 520 319 185 1191 194 Subsequent to operation 820 651 408 1258 186 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil _X Gas _ Suspended _ Service _ 17. I hereby~certify that the foregoing is true and correct to the best of my knowledge. Signed~//~.~ . Title: Pr°ducti°n Engineering Supervis°r Date Form 10-404 RE~ ;/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT SERVICE REPORT K1(30-13(W4-6)) ,= WELL JOB SCOPE JOB NUMBER 30-13 FRAC, FRAC SUPPORT 0501981326.1 DATE DAILY WORK UNIT NUMBER 05/06/98 FRAC SUPPORT-REPERF A2/A3 SANDS 2128 DAY' OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 ~) Yes (") NoI (~) Yes O No BARTZ JONES /~.'~"'"". ESTIMATE KD2171 . 230DS36OL $6,839 $8,611 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial ~,. ' ' 550 PSI 1400 PSI 1050 PSI 1250 PSII 1200 PSII 860 PSI DAILY SUMMARY I SWS REPERFORATED A2/A3 SANDS FROM 7612' TO 7642' W/2 1/8" EJ, 2 SPF, DH, 0 PHASED. TIME LOG ENTRY 07:45 SWS (BARTZ & CREW) & LRS MIRU. HELD TGSM (PERF SAFETY). S/I WELL @ 8:15AM. FREEZE PROT FLOWLINE W/15 BBLS DIESEL & TBG W/20 BBLS DIESEL. SECURE RADIO SILENCE. 08:45 MU GUN & PT LUBRICATOR TO 3000~. RELEASE LRS. 09:45 RIH W/30' - 2 1/8" EJ, 2 SPF, DH, 0 DEG PHASED, DOWN. CORR TO CBL 6-6-88, TAGGED DOWN @ 7693' RKB. PERFED FROM 7612' TO 7642'. 10:50 POH & LD GUN, ALL SHOTS FIRED. 11:45 RIG DOWN. 13:00 RELEASED SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $135.00 $135.00 APC $250.00 $250.00 HALLIBURTON $0.00 $880.00 LITTLE RED $770.00 $1,662.00 ,,, SCHLUMBERGER $5,684.00 $5,684.00 , , ,,, ,,, ,, TOTAL FIELD ESTIMATE $6,839.00 $8,611 STATE OF ALASKA Al_~,.,~z~, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1041' FNL, 2024' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1355' FSL, 1914' FWL, Sec. 22, T13N, R9E, UM At effective depth 1175' FSL, 1941' FWL, Sec. 22, T13N, R9E, UM At total depth 1109' FSL, 1958' FWL, Sec. 22, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7 9 5 0 feet 6 9 01 feet Plugs (measured) 6. Datum elevation (DF or KB) 59' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 30-13 9. Permit num, ber/aEproval number 88-40 / ?o- .Sb 10. APl number 50-029-21803 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 7 8 2 8 true vertical 6800 feet feet Junk (measured) Casing Length Structural Conductor 8 5' Surface 4 31 4' Intermediate Production 7 8 9 0' Liner Perforation depth: measured 7612'-7632', true vertical 6620'-6637', Tubing (size, grade, and measured depth) Size 16" 9 5/8" 7" Cemented Measured depth 175 Sx CS II 1 1 0' 1500 Sx AS III & 4339' 300 Sx Class G; Top Job w/85 sx AS I 395 Sx Class G & 791 5' 175 Sx AS I 7638'-7668', 7680'-7700' 6642'-6667', 6677'-6693' 2-7/8", 6.5 Ib/ft, J-55 ABM Tbg; Tail @ 7448' MD Packers and SSSV (type and measured depth) Baker HB Packer @ 7375', Baker FVLD SSSV @ 1789' 13. Stimulation or cement squeeze summary True vertical depth 110' 4047' 6868' 14. Intervals treated (measured) 7612'-7700' Treatment description including volumes used and final pressure 944 BBL GW Pad; 378 BBL GW Slurry; 128M lbs Carbo-Lite in formation, FP = 4700 psi Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 424 8 1 0 - 1 1 00 1 30 Subsequent to operation 1259 522 0 - 1 100 133 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector m Oil X. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed *'~~"~ ,'~ ,, ~ Title ,,~4/t/~ Form 10-404 Rev 09/12/90 ~-~ Date SUBMIT IN DUPLICATE ARCO Alaska, Substdla~/of Atlantic Richfield Company WELL "mNTRACTOR REMARKS IPBDT IFIELD- DISTRICT-STATE ~' ~ TTIM- OPERATION AT REPOR I= WELL SERVICE REPORT · I Z~ Pm. ~ ',sS 4 ~7 Iz_o qA~ 5q5o 317 ~ Z. ,1 40 ~ 75'0 .5~70 ~ ~4o [-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ISign .ed~- STATE OF ALASKA ALA'-dKA OIL AND GAS CONSERVATION COMMIS31ON 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 Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1041' FNL, 2024' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1355' FSL, 1914' FWL, Sec. 22, T13N, R9E, UM At effective depth 1175' FSL, 1941' FWL, Sec. 22, T13N, R9E, UM At total depth 1109' FSL, 1958' FWL, Sec. 22, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 5' Surface 431 4' Intermediate Production 7 8 9 0' Liner Perforation depth: measured 7612'-7632', 7950 6901 7828 6800 Size 1 6" 9 5/8" i! feet Plugs (measured) feet feet Junk (measured) 7742' feet 6. Datum elevation (DF or KB) RKB 59 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-13 9. Permit number 88-40 10. APl number 50-029-21 803 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 175 Sx AS I 110' 1500 Sx AS III & 4339' 300 Sx Class G; Top Job w/85 sx AS I 395 Sx Class G 7 91 5' 175 Sx AS I 110' 4O47' 6868' 7638'-7668', 7680'-7700' true vertical 6620'-6637', 6642'-6667', 6677'-6693' Tubing (size, grade, and measured depth) 2-7/8", 6.5 Ib/ft, J-55 ABM Tbg; Tail @ 7448' MD Packers and SSSV (type and measured depth) Baker HB Packer @ 7375', Baker FVLD SSSV @ 1789' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch Refracture A Sand. 15. 14. Estimated date for commencing operation August. 1990 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil X .. Gas __ Service Suspended 17. I here~ce~i~ Signed that the foregoing is true and correct to the best of my knowledge. J, ~'~ Title Senior Operatoions Engineer FOR COMMISSION USE ONLY Date 7'-23-?0 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10-~ Original Signed By David W. johnston Commissioner Approved by the order of the Commission IApproval ~.~--~d..P ~ I Form 10-403 Rev 5/03/89 Approved Copy Rlturned' . .-1 7-/I o SUBMIT IN TRIPLICATE 30-13 Refrac Sundry Attachment 7/19/90 Kuparuk Well 30-13 is scheduled for a re-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 30-13 area is 2450 psi. WELL 30-13 GW FRAC DATA TABLE STAGE BREAKDOWN PUMP RATE (BPM) ICLEAN VOLUMEI (BBL) I PROPPANT I CUMULATIVEI (POUNDS) IPROPPANT DIRTY VOLUME (BBL) CUMULATIVE J STAGE HITS DIRTY VOL (BBL)J PERFS @ (BBL) 25 75 0 0 75 75 49 20 60 0 0 60 135 124 15 45 0 0 45 180 184 SD FOR ISIP, PROVE FLOWMETER. PAD 20 950 0 0 950 1130 229 SLURRY 2 PPG 20 92 7719 4 PPG 20 102 17138 6 PPG 20 111 27901 8 PPG 20 103 34776 10 PPG 20 56 23320 12 PPG 20 26 13185 7719 100 1230 1179 24858 120 1350 1279 52758 140 1490 1399 87534 140 1630 1539 110854 80 1710 1679 124039 40 1750 1759 FLUSH 20 47 0 TOTAL 1667 124039 124039 47 1797 1797 VOLUME TO PERFS (BBL) = 49.2 PROPPANT: 16/20M CARBOLITE or LWP THROUGH 10 PPG STAGE 12/18M CARBOLITE IN 12 PPG STAGE PUMP RATE = 20 BPM (Drop to 16 BPM if necessary) Estimated Surface Treating Pressure = 4450 psi (includes perf friction) BREAKDOWN = GW + 40 LB/1000 GAL Silica Flour + 8 Hour Breaker Cut XL during last part (flush) of BD stage. Perform step rate test as shown only if Petrodat gauge is installed; pump @ 20 BPM throughout if it is not. PAD = GW + 40 PPT Silica Flour + 8 Hour Breaker SLURRY = GW + 8 Hour Breaker (no Silica Flour) FLUSH = Slick Diesel JRS 7/19/9O 1. S000 PSI ?" WELLHEAD CONNECTOR IrLANG£ 2. 5000 PSI WIRELIN£ RAJAS (VARIABLE: SIZE) 3. ~)000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr H]REL]NE BOP. EOU]PHENT ~R-18-' 90 10: 2~ I D: KRU.,-'C I/NU/'DR ILL i NW ,I ~**$ ALL WELLS LOCATED IN SEC. 22 T. l$ N., R. gE., UMIAT MERIDIAN. 16 '0 I? NOT~:S I. AIL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S,L. 4. REFER. FIELD aC)OK L-sa-~ 5. Q.G. ELEVATIONS FROM CED-RIXX-$365,& 8. HORIZONTAL POSITION BASED ON MONUMENTS PER L.OUNSSURY & ............... ___, ................ O~ST. OiST. O.& '"p~- , We_l.l_,~ Y ASPs X LATITUDE ..... LONGITUDE ENL. FWL I~lev. F_Jev_ 6,02 2,095. Z7 525,478.27 ?Oe~8' 17.338'* 1490 47'30.897" 724' 1642' 17.5' 23.9' 6,022,075. 89 $~-$ ,490,94 70028` 17.128" 149° 47'$0.5Z6'' 745' 1855' 17.7: 3 6,022,052. 13 525,~3.67 ~' 16.913" 149047'~0. I~" 76~ 1867' 17.9 4 6,0a2,030,~ 5Z5,515 .Se ~28', I~I 149 47. Z9.8~, ~89', 1879~ la,~ 5 6,02~'~8.~ 525,528.38 7~8, i49° 47' 29.4~,. 81 I, 149 47,Z8.~. t8.3, ~ 6~0~ I ~. 12 5~ ~57~.Z7 i5.632 14~e47 ~7.~74 ~ 1941 18.~ I0 6,021,84~ ~ 525,623.61 ~28' 14.~3" 149047'26.6~'' 975' 1986' 18.7' Il 6,021,822. ~ 525,6~5.71 ~' 14.651" 149e 47'26.295" ~7' 1998' 18.0' 23.5' i~ 6~021,8~.87 525,648.~ 7~28', 14.437" 149e47'~.9~" 1019' 2011' 18.8' f3 6,OZl ,779. IS 5Z5,66t .~ ~e~, 14. 2Z3" 149°47:25.~" 1041'. ZOZ4', la.9', 14 6,0Z ,~7.~ 5Z5,6~.~ ~o~, 14.010 ~ o · ' 149_47,~5,~.. i0~ ~0~, t9.07 ~2.8, 15 6,02],135. 76 5Z5,~6. IZ ~e~ IS.~5 149~47 24.8~" 1084 2048, 19.0, ~.~ 16 6,0~ 1,714. 15 5Z5,6~. 17 ~e28' t3.~5" 149047',24.4~ I1~ ~0~ 19. I ~9 17 G,O;1,69~ 5Z5,710.85 ~' ~3. S69" 149°47 Z4.0~ t 12~ 2073' 19.0' t8 6,0~ t ,670. 97 525 ~7~.~ ~28' 13. 157' i49~47~Z3,73~' 1149' 2085' 19.0' 23.3' . _ m[~, i i _ ,,, D.S. 3.0 WELL CONDUCTOR AS-BUILT PREPARED BY LOUNSBURY 6 Associates Dwn. by, ~' AJR ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal Ct: 7470 Anchorage Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 . .~3A-03 ~3A-08 ~"30-11 ~"30-13 '~'-30-17 B-14 DO8 "- '~'3A-0 8 '~ 30-12 2 -14 '~1 FR-02 '~ 3F-16 ~1 R-02 ~1Y-06 '~' 2T-07 ~"'~1 E-25 Please acknowledge receipt and return Sub-Surface Pressure Survey 2 - 1 5 - 8 9 Kuparuk Fluid Level Report 4 - 2 3 - 8 9 Kuparuk Fluid Level Report 4- 2 3 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 2 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 4 - 8 9 Kuparuk Fluid Level Report 4- 2 4 - 8 9 Kuparuk Fluid Level Report 4- 2 4 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 2 9 - 8 9 Kuparuk Fluid Level Report 4 - 3 0 - 8 9 Kuparuk Fluid Level Report 4- 2 9 - 8 9 Kuparuk Fluid Level Report 5-03-89 Kuparuk Fluid Level Report 5 - 0 4 - 8 9 Kuparuk Fluid Level Report 5 - 0 3- 8 9 Kuparuk Fluid Level Report 5 - 0 8 - 8 9 Kuparuk Fluid Level Report 5- 0 7- 8 9 Kuparuk Well Presure Report I 1 - 0 7- 8 8 Ct64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date: ............ ~)ISTRIBUTION: D&M ~ SAPC Chevron Mobil Unocal ARCO Alaska, Inc. Date: March 24, 1989 Transmittal #: 7447 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return · '--, 30-16 -- 30-10 '""-- 30-13 .,.~, 30-03 -,,. 30-15 .-..,., 2G- 14 ~ 2G-13 '"',..- 2G-09 "'~ 1E-03 ~ 1 E-05 30-18 """ 3 H- 10 ~3A-03 '-'~3 H-04 ~2B-14 ~30-13 4,,,,,30-10 '~'30-16 ~'~1 B-07 ""'"'1B-03 ~1B-05 ""'"'~1 B-07 '""~ 1 L- 0 8 ~,,,,~1 L- 0 4 ~"~3 H- 1 0 '~-3M-01 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Well Pressure Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Kuparuk Fluid Level Report Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Kuparuk Fluid Level Report Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report 1-3-189 2-04-89 2-08-89 I -09-89 3-04-89 3-11-89 3-11-89 3-11-89 3-09-89 3-09-89 3-09-89 3-09-89 3-09-89 3-04-89 3-13-89 "2-08-89 2-04-89 1 -31 -89 3-31 -88 I -27-88 I -27-88 4-27-88 1 -27-88 2-12-88 Sand 'A' Sand 'A' Sand 'A' Sand 'A' Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing #72665 #72655 #72655 Casing Tubing Tubing Tubing Tubing Tubing 2- 1 2-88 Tubing 3 - 1 7- 89 Cas. Lng ~chorag~ ~ O- 09 Kuparuk Fluid Level Report 3 - 1 8 - 8 9 Casing "'""~3 O- 18 Kuparuk Fluid Level Report 3 - 1 8 - 8 9 Casing ~ O- 18 Kuparuk Fluid Level Report 3 - 1 7- 8 9 Casing ~"'~O-09 Kuparuk Fluid Level Report 3-1 7-8 9 Casing '--..-,3B - 1 3 Kuparuk Fluid Level Report 3 - 1 7- 8 9 Casing Receipt Acknowledged' . .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil .- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED [] ABANDONED ~ SERVICE I~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ 3, Address P.O. Box 100360~ Anchorage, AK 99510-0360 4. Location of well at surface 1041' FNL, 2024' FWL, Sec.22, T13N, R9E, UM At Top Producing Interval 1355' FSL, 1914' FWL, Sec,22, T13N, RgE, UM At Total Depth 1109' FSL, 1958' FWL, Sec,22, T13N, RgE, UH 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 59' I ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 05/15/88 05/21/88 10/07/88* 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 7950'MD/6901 'TVD 7832'MD/6803 ' TVD YES ~] NO [] 8. APl Number 50- 029-21 803 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 30-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 15. Water Depth, if offshore I16' No' of Completions N/A feet MSLJ 1 I20. Depth whereSSSV set I 21. Thickness of Permafrost 1789 ' feet MDI 1700 ' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, CAL,GR,CBT,GCT 23. CASING, LINER AND CEMENTING RECORD SETTIN( DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 9-5/8" 36.0# J-55 Surf 4339' 12-1/4" 7" 26.0# J-55 Surf 7915' 8-1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval_ size and number) Perforated w/8 spf, 45° Phasing 7680'-7700'ND/6676'-6693,TVD N/A 27. 175 sx AR I 1500 sx AS III & 300 s~ Tnp jnh w/85 sx AS I 395 sx Clas~ C & 17S ~x Class 25. TUBING RECORD SIZE 2-7/8" DEPTH SET (MD) 7449' PACKER SET (MD) 7375' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) ]AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 10/26/88, for Fracture dataI PRODUCTION TEST Date First Production Date of Test Flow Tubing Press. Hours Tested Casing Pressure Method of Operation (Flowing, gas lift, etc.) iPRO6UCTION FOR IOIL-BBL TEST PER,OD *I CALCULATED ~IO,L-BBL 24-HOUR RATE GAS-MCF GAS-MCF WATER-BBL ICHOKE SIZE IGAS'OILRATIO WATER-BBL /OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOTE: Drilled RR 5/22/88. Perforated well and ran tubing 6/26/88. Fractured well 10/7/88. CONTINUED ON REVERSE SIDE Form 10407 WC5/083 Rev, 7-1-80 Submit in duplicate 29. ' ' , 30. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7503' 7538' 7600' 7739' FORMATION TESTS TRUE VERT. DEPTH 6531' 6559' 6610' 6725' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendums (dated 08/10/88 & 10/26/88), 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engineer Signed ~[~) ~-- ~'~C _/-x.~_/~ _ 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 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 A D D E N D U M (cont'd) WELL: 30-13 10/19/88 Pmp 878 to 879 bbls gelled diesel, 9.4 - 9.5 ppg prop @ 20 BPM, 6550-8500 psi. Screened out w/7.3 ppg @ perfs. RU Hot Oil unit, pressure tst lines to 3500 psi. Pmp 21 bbls hot diesel w/5% Musol @ 1.5 BPM, 2200 psi dn tbg. Displ w/50 bbls cln diesel on tbg @ 2 BPM, 2600 psi. Secure well. RU CTU, tst hardline to 4000 psi; OK. RIH, pmp'g @ .36 BPM to 4000'. Increase fluid rate to 1.5 BPM. Wsh thru bridge f/4800'-5300'. Cont @ 1.5 BPM to tbg tail @ 7450', holding 250 psi back pressure. Pmp No @ 350 scf/min, wsh to 7802' CTM, circ 80 bbls gel/aiesel while reciprocating from PBTD to TT. Flush w/75 bbls cln diesel while POOH. Secure well. Release well to Production. Drilling Supervisor / Date ADDENDUM WELL: 6/06/88 8/16/88 9/25/88 10/07/88 30-13 RU SOS. Rn CBT f/7800'-6500'. Rn 6-1/8" GR. RIH w/GCT f/7775'-50'. RD Schl. Att to frac Kuparuk A sand perfs 7680'-7700' per procedure dated 8/9/88. Had hydraulic problem w/blender. Job screened out to 7450 psi when sand slug hit perfs. Tree saver stuck in wellhead when RD; get out; lost both cups. MIRU CTU. Tst BOPE to 4000 psi. RIH, feeling for swab cups lost during frac. Tag fill @ ±465'. Begin washing with 1.75" nozzle. Wash to ±2000', POH, chg nozzle to 1.95". RU Howco nitrogen unit.. RIH, begin washing with 0.5 BPM gel diesel and 300 scf N~/M. RIH, wash, tag fill @ 7825' PBTD @ 2 BPM. CBU, chec~ choke samples. Switch to diesel displacement, POH. RD CTU. Turn well over to Production. Ramp frac Kuparuk A sand perfs 7680'-7700' per procedure dated 10/6/88 as follows: Breakdown w/50 bbls gelled diesel @ 20 BPM, 6900 psi. Breakdown with 100/150 bbls gelled diesel @ 20 BPM, 6900-5400 psi. Pmp pad with 100/250 bbls gelled diesel @ 20 BPM, 6900-5500 psi. Pmp pad 390/690 bbls gelled diesel @ 20 BPM, 5550 psi. Pmp 640 to 690 bbls gelled diesel 1-3 ppg, 20 BPM, 5550 psi. Pmp 690 to 725 bbls gelled diesel 3-5 ppg @ 20 BPM, 5550 psi. Pmp 725 to 790 bbls gelled diesel, 5-2-5 ppg @ 20 BPM, 5600 psi. Pmp 790 to 820 bbls gelled diesel 5-7 ppg @ 20 BPM, 5600 psi. Pmp 820 - 878 bbls gelled diesel, 7 - 9 ppg @ 20 BPM, 5600 - 6550 psi. Attempt to tail in same 10 ppg and go to flush, pressure spiked with screen out. ADDENDUM WELL: 30-13 7/23/88: Pmp 21 bbls diesel w/5% Musol, 160°. Displ w/ 51 bbls cln diesel. Turn well over to Production. D r Xi~F~~~i~ Supervi~ ~ate / - SUB-SURFACE DIRECTIONAL SURVEY r-~l UIDANCE ~]ONTINUOUS '~'l OOL Company ARCO ALASKA, INC. Well Name 30-13 (1041'FNL, 2024'FWL, SEC 22, T13N, R9E,UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 72814 Log(led BY: MCBRIDE Date, 6-June-88 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. 3 0-13 KUPARUK NORTH SLOPEtALASKA SURVEY DATE: 06-JUN-88 ENGINEER: M. MCBRIDE METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 3 DEG 26 MIN WEST ARCO ALASKA, INC. 3 0-13 KUPARUK NORTH SLOPE o ALASKA COMPUTATION DATE: 20-JUN-88 PAGE DATE OF SURVEY: 06-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE. INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 100.00 100.00 42.00 0 20 S 35 25 W 200.00 199.99 141.99 0 38 S 5 0 E 300.00 299.99 241.99 0 43 S 18 33 E 400.00 399.98 341.98 0 45 S 16 4 E 500.00 499.97 441.97 0 47 S 5 25 E 600.00 599.96 541.96 0 48 S 3 43 W 700.00 699.95 641.95 0 49 $ 9 33 W 800.00 799.94 741.94 0 49 S 8 32 W 900.00 899.93 841.93 0 42 S 10 57 W 1000.00 999.92 941.92 1100.00 1099.92 1041.92 1200.00 1199.92 1141.92 1300.00 1299.92 1241.92 · 1400.00 1399.91 1341.91 1500.00 1499.91 1441.91 1600.00 1599.91 1541.91 1700.00 1699.91 1641.91 1800.00 1799.91 1741.91 1900.00 1899.91 1841.91 2000.00 1999.90 1941.90 2100.00 2099.89 2041.89 2200.00 2199.85 2141.85 2300.00 2299.81 2241.81 2400.00 2399.76 2341.76 2500.00 2499.49 2441.49 0 33 S 20 23 W 0 27 S 28 21W 0 22 S 39 43 W 023 S 57 3 W 0 16 S 61 19 W 0 12 S 39 42 W 0 10 S 29 18 W 0 8 S 67 39 W 0 7 S 11 55 W 030 S 76 4 E 0 53 1 18 1 35 I 44 2 10 5 59 2600.00 2598.46 2540.46 10 31 2700.00 2696.02 2638.02 14 27 2800.00 2792.04 2734.04 17 49 2900.00 2886.04 2828.04 22 0 3000.00 2977.80 2919.80 24 20 3100o00 3068.44 3010.44 25 34 3200.00 3157.98 3099.98 27 20 3300.00 3245.72 3187.72 30 16 3400.00 3329.75 3271.75 35 26 3500.00 3408.60 3350.60 40 10 3600.00 3484.32 3426.32 41 1 3700.00 3559.83 3501.83 40 53 3800.00 3635.48 3577.48 40 46 3900.00 3711.36 3653.36 40 27 N 79 14 E N 73 42 E N 70 42 E N 68 3 E S 45 39 E S 0 51E S 6 12 W S 5 56 W S 8 24 W S 9 45 W S 9 41 W S 12 24 W S 12 49 W S 11 15 W S 10 2 W S 9 53 W S 10 29 W S 11 23 W S 11 54 W S 12 34 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET 'DEG MIN 0.00 0.00 0.00 N 0.00 E 0.19 0.41 0.18 S 0.16 W 1.05 0.23 1.04 S 0.30 W 2.19 0.10 2.19 S 0.03 W 3.40 0.03 3.43 S 0.37 E 4.72 0.22 4.76 S 0.65 E 6.11 0.09 6.16 S 0.65 E 7.53 0.20 7.57 S 0.49 E 8.96 0.03 8.99 S 0.25 E 10.31 0.15 10.33 S 0.04 E 0.00 N 0 0 E 0.24 S 41 20 W 1.08 S 15 59 W 2.19 S 0 54 W 3.45 S 6 13 E 4.81 S 7 43 E 6.19 S 6 0 E 7.59 S 3 41 E 8.99 S 1 36 E 10.33 S 0 12 E 11.39 0.16 11.40 S 0.25 W 12.19 0.01 12.18 S 0.61 W 12.83 0.18 12.80 S 1.00 W 13.28 0.01 13.22 S 1.50 W 13.62 0.14 13.52 S 2.02 W 13.88 0.10 13.76 S 2.35 W 14.15 0.17 14.03 S 2.50 W 14.34 0.17 14.20 S 2,.73 W 14.48 0.23 14.33 S 2.85 W 14.74 0.58 14.61 S 2.49 W 11.40 S 1 16 W 12.19 S 2 50 W 12.84 S 4 26 W 13.30 S 6 27 W 13.67 S 8 30 W 13.96 S 9 40 W 14.25 S I0 5 W 14.46 S 10 52 W 14.62 S 11 15 W 14.82 S 9 41 W 14.64 0.64 14.58 S 1.29 W 14.04 0.25 14.11 S 0.61 E 13.13 0.29 13.33 S 3.02 E 11.92 0.19 12.28 S 5.78 E 11.88 4.57 12.41 S 8.49 E 18.47 4.64 19.11 S 10.00 E 32.58 5.14 33.17 S 8.91 E 54.38 4.13 54.87 S 6.56 E 82.t8 3.16 82.51 S 2.98 E 116.05 4.61 116.13 S 14.64 S 5 3 W 14.12 S 2 28 E 13.67 S 12 45 E 13.58 S 25 11 E 15.04 S 34 21 E 21.56 S 27 37 E 34.35 S 15 I E ) 55.26 S 6 48 E 82.56 S 2 4 E 2.17 W 116.15 S 1 4 W 155.51 2.20 155.24 S 197.38 1.65 196.70 S 241.29 1.93 240.10 S 288.67 6.75 286.96 S 342.36 5.49 340.16 S 403.39 2.88 400.66 S 468.26 0.61 464.96 S 533.26 0.53 529.32 S 597.98 0.33 593.37 662.35 0.73 9.17 W 155.51 S 3 22 W 17.2.3 W 197.45 S 5 0 W 27.06 W 241.62 S 6 25 W 37.14 W 289.35 S 7 22 W 46.98 W 343.39 S 7 51 W 57.61 W 404.78 S 8 10 W 69.10 W 470.07 S 8 27 W 81.56 W 535.57 S 8 45 W 94.79 W 600.90 S 9 4 W 657.03 S 108.57 W 665.94 S 9 22 W ARCO ALASKA~ INC. 3 0-13 KUPARUK NORTH SLOPE~ALASKA COMPUTATION DATE: 20-JUN-88 PAGE ' DATE OF SURVEY:' 06-JUN-8~ KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE. INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRU~ SUB-SE~ COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 4000.00 3787.71 3729.71 39 57 4100.00 3864.61 3806.61 39 34 4200.00 3941.33 3883.33 40 26 4300.00 4016.84 3958.84 41 15 4400.00 4092.26 4034.26 40 46 4500.00 4168.23 4110.Z3 40 25 4600.00 4244.65 4186.65 39 53 4700.00 4321.5~ 4263.58 39 31 4800.00 4398.76 4340.76 39 31 4900.00 4475.84 4417.84 39 32 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5000.00 4553.10 4495.10 39 17 5100.00 4630.57 4572.57 39 7 5200.00 4708.37 4650.37 38 41 5300.00 4.786.69 4.728.69 38 13 54.00.00 4865.40 4807.40 37 56 5500.00 4.944.30 4886.30 37 58 5600.00 5023.02 4965.02 38 7 5700.00 5101.59 5043.59 38 18 5800.00 5180.04. 5122.04 38 20 5900.00 5258.42 5200.42 38 26 S 13 8 W 726.05 S 13 11 W 789.06 S 12 4. W 852.34 S 11 13 W 917.25 S 10 48 W 982.34 S 9 49 W 1046.88 S 5 46 W 1111.17 S 4 2 W 1175.03 S 3 27 W 1238.62 S 2 57 W 1302.32 6000.00 5336.68 5278.68 38 33 6100.00 5414.86 5356.86 38 35 6200,00 5493,10 5435,10 38 22 6300.00 5571,69 5513,69 38 1 6400.00 5650.67 5592,67 37 38 6500.00 5729.88 5671.88 37 38 6600.00 5809.05 5751,05 37 39 6700.00 5888.21 5830.21 37 39 6800.00 5967.41 5909.4.1 37 37 6900.00 6046.61 5988.61 37 34 S Z 16 W 1365.80 S I 43 W 14.29.02 S 0 58 W 1491.80 S 0 6 W 1553.90 S 0 42 E 1615,45 S I 10 E 1676,'71 S 1 26 E 1738,16 S I 45 E 1799,79 S 2 9 E 1361,53 S 2 32 E 1923,31 7000.00 6125.97 6067.97 37 20 7100.00 6205.68 6147.68 36 58 7200.00 6285.75 6227.75 36 39 7300,00 6366.06 6308.06 36 25 7400.00 644.6.81 6388.81 35 52 7500.00 6528.12 6470.12 35 19 7600,00 6609,98 6551,98 34 43 7700,00 6692,71 6634,71 33 42 7800,00 6776,01 6718,01 33 38 7900,00 6859,26. 6801,26 33 38 S 3 0 E 1985,20 S 3 30 E 2047,13 S 3 57 E 2108,92 S 4 23 E 2170,21 S 4 38 E 2230.95 S 4 56 E 2291,37 S 5 17 E 2351.78 S 5 39 E 2412,15 S 5 59 E 2472.40 S 6 15 E 2532.60 S 6 51 E 2592.53 S 7 31 E 2651.89 S 8 4. E 2710.63 S 8 29 E 2768.97 S 8 58 E 2826.66 S 9 31 E 2883.45 S 10 0 E 2939.36 S 10 14. E 2993,96 S 10 24 E 3047,69 S 10 24. E 3101,48 0,60 0.34. 2,22 0,29 0,95 1 2,16 0,66 0,35 0,55 719,98 S 122,97 W 730,40 S 9 41 W 782,22 S 137,56 W 794,23 S 9 58 W 844,77 S 151,75 W 858.29 S 10 11 W 909.01 S 164.80 W 923.83 $ 10 16 W 973.46 S 177,40 W 989.49 S 10 19 W 1037,41 S 189,13 W 1054.51 S 10 19 W 1101.29 S 197.94 W 1118.94 S 10 11 W ~ 1164.95 S 203.23 W 1182.54 S 9 53 W 1228.41 S 207.36 W 1245.79 S 9 34 W 1292,01 S 210',95 W 1309,12 S 9 16 W 0,33 0,60 0,78 0,54 0,66 0,27 0,21 0,27 0,28 0,26 1355,43 S 213,84. W 1372,19 S 8 57 W 1418,63 S 216,07 W 14.34,99 S 8 39 W 1481,43 S 217.57 W 1497,33 S 8 21 W 1543,60 S 218.17 W 1558,94 S 8 2 W 1605.28 S 217.86 W 1620.00 S 7 4.3 W 1666.72 S 216.80 W 1680.76 S '7 24 W 1728,36 S 215.40 W 1741,73 S 7 6 W 1790.21 S 213.66 W 1802.92 S 6 48 W 1852.19 S 211.54 W 1864.23 S 6 30 W 1914.23 S 208.99 W 1925.61 S 6 13 W 0,36 0,27 0,56 0,39 0,46 0,16 0,30 0,20 0,19 0,48 1976,41 S 205,99 W 1987.12 S 5 57 W 2038,67 S 202,43 W 2048.69 S 5 4.0 W 2100.81 S 198.39 W 2110.16 S 5 23 W 2162.48 S 193.87 W 2171.15 S 5 7 W 2223.62 S 189.06 W 2231.64 S 4. 51 W 2284.45 S 183.96 W 2291.85 S 4. 36 W 2345,30 S 178,52 W 2352,09 S 4 21 id 2406,12 S 172,68 W 2412,31 S 4 6 W 2466,86 S 166.48 W 2472,47 S 3 51 W 2527.56 S 160.01 W 2532.62 S 3 37 W 0,67 0°54 0,20 0,46 0,75 0,82 1.11 0.44 0o00 0.00 2588.01 S 153.05 W 2592.53 S 3 23 W 2647.93 S 145.50 W 2651.92 S 3 8 W 2707.26 S 137.35 W 2710.75 S 2 54 W 2766.22 S 128.78 W 2769.22 S Z 39 W 2824,55 S 119.85 W 2827.09 S 2 25 W 2882.01 S 110.51 W 2884.12 S 2 11 W 2938,60 S 100.74. W 2940.32 S 1 57 W 2993.90 S 90,84 W 2995,27 S I 44 W 3048,31 S 80,89 W 3049,38 S I 31 W 3102,81 S 70,88 W 3103,62 S I 18 W COMPUTATION DATE: 20-JUN-88 PAGE' . ARCO ALASKAt INC. 3 0-13 KUPARUK NORTH SLOPEtALASKA DATE OF SURVEY: 06-JUN-'.88 KELLY BUSHING ELEVATION:' 58.00 FT ENGINEER= M. MCBRIOE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG RIM DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 7950.00 6900.88 6842.88 33 38 S 10 24 E 3[28.38 0.00 3130.05 S 65.88 W 3130.75 S ! 12 W COMPUTATION DATE: 20-JUN-88 PAGE ARCO ALASKA~ INC. 3 0-13 KUPARUK NORTH SLOPEtALASKA DATE OF SURVEY: 06-J'UN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIOE~ INTERPOLATED VALUES FOR EVEN 1000 FEE'T OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH .OEG MIN OEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEOARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIMUTH FEET OEG/ZO0 FEET FEET FEET DEG MIN 0.00 0.00 -58.00 0 0 1000.00 999.92 941.92 0 33 2000.00 1999.90 1941.90 0 53 3000.00 2977.80 2919.80 24 20 4000.00 3787.7[ 3729.71 39 57 5000.00 ~553.10 4495.10 39 17 6000,.00 5336.68 5278.68 38 33 7000.00 6125.97 6067.97 37 20 7950.00 6900.88 6842.88 33 38 N 0 0 E 0.00 S ,lO 23 W 11.39 N 79 14 E 14.64 S 9 41 W 155.51 S 13 8 W 726.05 S 2. 16 W 1365.80 S 3 0 5 1985.20 S 6 51 E 2592.53 S 10 24 E 3128.3B 0.00 0.16 0.64 2.20 0.60 0.33 0.36 0.67 0.00 0.00 N 0o00 E 0.00 N 0 0 E 11.40 S 0.25 W 11.40 S I 16 W 14.58 S 1.29 W 14.64 S 5 3 W 155.24 S 9.17 W 155.51 S 3 22 W 719.98 S 122.97 W 7.30.40 S 9 41 W 1355.43 S 213.8& W 1372.19 S -8 57 W 1976.41 S 205.99 W 1987.12 S 5 57 W 2588.01 S 153.05 W 2592.53 S 3 23 W 3130.05 S 65.88 W 3130.75 S I 12 W COMPUTATION DATE: 20-JUN-88 PAGE ARCO ALASKA, INC. 3 0-13 KUPARUK NORTH SLOPEtALASKA DATE OF SURVEY: 06-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 -58.00 0 0 N 0 0 E 58.00 58.00 0.00 0 12 S 53 9 W 158.00 158.00 100.00 0 33 S 6 45 W 258.01 258.00 200.00 0 41 S 14 8 E 358.02 358.00 300.00 0 45 S 18 37 E 458.02 458.00 400.00 0 47 S 11 30 E 558.04 558.00 500.00 0 47 S 1 Z W 658.04 658.00 600.00 0 48 S 6 36 W 758.06 758.00 700.00 0 49 S 9 25 W 858.06 .858.00 800.00 0 46 S 8 49 W 0.00 0.00 0.00 N 0.00 E 0.02 0.38 0.02 S 0.02 W 0.62 0.44 0.60 S 0.30 W 1.71 0.17 1.70 S 0.18 W 2.88 0.09 2.90 S 0.21 E 4.15 0.16 4.19 S 0.56 E 5.52 0.10 5.57 S 0.67 E 6.93 0.03 6.98 S 0.57 E 8.36 0.05 8.39 S 0.35 E 9.77 0.17 9.79 S 0.13 E 0.00 N 0 0 E 0.03 S 47 40 W 0.67 S 26 24 W 1.71 S 6 4 W 2.91 S 4 7 E 4.23 S 7 38 E 5.61 S 6 52 E 7.00 S 4 41 E 8.40 S 2 21 E 9.79 S 0 45 E 958.07 958.00 900'.00 1058.08 1058.00 1000.00 1158.08 1158.00 1100.00 1258.08 12.58.00 1200.00 1358.09 1358.00 1300.00 1458.09 1458.00 1400,00 1558,09 1558.00 1500.00 1658.09 1658.00 1600.00 1758.09 1758.00 1700.00 1858.09 1858.00 1800.00 0 37 S 16 12 W 0 28 S 25 25 W 0 24 S 32 4 W 0 22 S 53 36 W 0 21 S 60 38 W 0 13 S 52 34 W 0 10 S 23 48 W 0 10 S 63 1W 0 5 S 38 24 W 0 18 S 46 49 E 10.98 0.20 10.99 S 0.12 W 11.89 0.15 11.88 S 0.45 W 12.59 0.09 12.56 5 0.83 W 13.11 0.09 13.06 S 1.27 W 13.50 0.18 13.41 S 1.82 W 13.77 0.10 13.66 S 2.24 W 14.04 0.10 13.92 S 2.44 W 14.28 0.20 14.15 S 2.62 W 14.41 0.04 14.26 S 2.82 W 14.64 0.69 14.50 S 2.76 W 10.99 S 0 37 W 11.89 S 2 11 W 12.59 S 3 45 W 13.12 S 5 32 W 13.54 S 7 43 W 13.84 S 9 17 W 14.13 S 9 57 W 14.39 S 10 29 W 14.54 S 11 11 W 14.76 S 10 47 W 1958.09 1958.00 1900.00 0 42 2058.10 Z058.00 2000.00 I 11 22158.13 I~58 O0 2100.00 1 28 258.18 58:00 2200.00 1 43 2358.22 2358.00 2300.00 1 35 2458.34 2458.00 2¢00.00 4 18 2558.98 2558.00 2500.00 8 31 2660.86 2658,00 2600.00 12 59 2764.36 2758.00 2700.00 16 47 2869.87 2858.00 2800.00 20 39 N 87 3O E N 75 38 E N 72 4 E N 68 57 E S 88 28 E S 12 31 E S 5 19 W S 6 9 W S 8 I W S 8 47 W 14.74 0.43 14.66 S 1.87 W 14.34 0.38 14.35 S 0.27 W 13.55 0.28 13.69 S 1.96 E 12.45 0.19 12.75 S 4.60 E 11.40 3.09 11.87 S 7.38 E 14.79 4.71 15.40 S 9.68 E 25.82 4.64 26.44 S 9.60 E 45.10 3.60 45.64 S 7.53 E 71.64 3.05 72.04 S 4.49 E 105.10 4.80 105.27 S 14.78 S 7 15 W 14.35 S 1 5 W 13.83 S 8 8 E 13.55 S 19 50 E 13.98 S 31 53 E 18.19 S 32 9 E 28.13 S 19 56 E 46.25 S 9 22 E 72.18 S 3 34 E 0.36 W 105.27 S 0 11 W 2978.30 2958.00 2900.00 24 4 3088.¢3 3058.00 3000.00 25 26 3200.02 3158.00 3100.00 27 20 3314.26 3258.00 3200.00 30 56 3434.93 3358.00 3300.00 37 23 3565.13 3458.00 3400.00 40 58 3697.58 3558.00 3500.00 40 54 3829.73 3658.00 3600.00 40 43 3961.17 3758.0-0 3'700.00 40 9 4091.42 3858.00 3,800.00 39 33 . S 9 59 W S 12 11 W S 12 49 W S 10 55 W S 9 59 W S 10 11W S 11 22 W S 12 2 W S 12 59 W S 13 12 W 146.68 1.80 146.48 S 192.45 1.66 191.83 S 241.30 1.93 240.11 S 295.85 5.04 294.07 S 362.75 5.85 360.37 S 445.56 0.60 442.46 S 531.69 0.55 527.77 S 617.19 0.43 612.37 S 701.40 0.63 783.66 0.25 7.63 W 146.68 S 2 58 W 16.16 W 192.51 S 4 48 W 27.06 W 241.63 S 6 25 W 38.53 W 296.58 S 7 27 W 50.55 W 363.90 S 7 59 W 64.99 W 447.21 S 8 21 W 81.25 W 533.99 S 8 45 W 98.81 W 620.29 S 9 9 W 695.62 S 117.33 W 705.44 S 9 34 W 776.89 S 136.31 W 788.76 S 9 57 W ARCO ALASKAt INC. 3 0-13 KUPARUK NORTH SLOPE,ALASKA COHPUTA'TION DATE: 20-JUN-88 PAGE DATE OF SURVEY: 06-JUN-88 KELLY BUSHING ELEVATION.' 58.00 FT ENGINEER: N. HCBRIOE. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUg-SEA OEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST' '."AZIMUTH FEET DEG/tO0 FEET FEET FEET DEG MIN 4222.01 3958.00 3900.00 40 42 4354.67 4058.00 4000.00 41 4 4686.56 4158.00 4100.00 40 26 6617.41 6258.00 4200.00 39 48 4747.19 4358.00 4300.00 39 27 4876.86 ¢658.00 4400.00 39 36 5006.32 4558°00 6500.00 39 17 5135.34 4658.00 4600.00 38 59 5263.43 4758.00 4700°00 38 21 5390.61 6858.00 4800.00 37 57 5517.39 6958.00 4900.00 38 0 5644.69 5058.00 5000.00 38 12 5771.91 5158.00 5100.00 38 19 5899.46 5258.00 5200.00 38 26 6027.26 5358.00 5300.00 38 33 6155.18 5458.00 5400.00 38 32 6282.63 5558.00 5500.00 38 4 6409.25 5658.00 5600.00 37 37 6535.51 5758.00 5700.00 37 39 6661.84 5858.00 5800.00 37 39 6788.12 5958.00 5900.00 37 36 6914.36 6058.00 6000.00 37 33 7040.24 6158.00 6100.00 37 10 7165.38 6258.00 6200.00 36 44 7289.97 6358.00 6300.00 36 27 7413.80 6458.00 64.00.00 35 4.8 7536.57 6558.00 6500.00 35 8 7658.18 6658.00 6600. O0 34 3 7950.00 6900.88 6842.88 33 38 S 11 44 W 866.57 S 11 6 W 952.91 S 10 I W 1038.22 S 5 6 W 1122.33 S 3 42 W 1205.03 S 3 7 W 1287.59 S 2 15 W 1369.81 S I 28 W 14.51.29 S 0 25 W 1531.26 S 0 37 E 1609.69 S i 13 E 1687.39 S I 35 E 1765.56 S 2 3 E 184~.19 S 2 31 E 1922.98 S 3 9 E 2002.09 S 3 44 E 2081.27 S 4 20 E 2159.61 S 4 40 E 2236.54 S 5 2 E 2312.83 S 5 31 E 2389.12 S 5 57 E 2465.24 S 6 20 E 2541.23 S 7 7 E 2616.49 S 7 55 E 2690.34 S 8 25 E 2763.13 S 9 Z E 2834.53 S 9 44 E 2903.98 S 10 10 E 2971.29 S 10 24 E 3128.38 1.69 0.63 1.00 1.29 0.49 0.35 0.31 0.55 0.71 0.66 858.85 S 154.66 W 872.66 S 10 12 W 966.31 S 171.77 W 959.81 S 10 18 W 1028.83 S 187.61 W 1045.79 S 10 20 W 1112.60 S 199.11 W 1130.08 S 10 8 W 1194.89 S 205.26 W 1212.39 S 9 44 W 1277.29 S 210.18 W 1294.¢7 S 9 20 W 1359.43 S 214.00 W 1376.17 S 8 56 W 1440.90 S 216.72 W 1457.10 S 8 33 W 1520.93 S 218.04 W 1536.48 S 8 9 W 1599.51 S 217.92 W 1614.28 S 7 45 W 0.27 1677.43 S 216.57 W 1691.35 S 7 21 W 0.36 1755.85 S 214.6'7 W 1768.93 S 6 58 W 0.28 1834.78 S 212.18 W 1847.01 S 6 35 W 0.26 '1913.90 S 209.00 W 1925.28 S 6 13 W 0.35 1993.38 S 205.08 W 2003.90 S 5 52 W 0.47 2073.00 S 200.26 W 2082.65 S 5 31 W 0.36 2151.81 S 194.69 W 2160.60 S 5 10 W 0.41 2229.24 S 188.60 W 2237.21 S 4 50 W 0.16 2306.06 S 182.08 W 2313.24 S 4 30 W 0.18 2382.92 S 174.95 W 2389.33 S 4 11 W 0.23 0 0.53 0.46 0.45 0.70 0.48 1.18 0.00 2459.64 S 167.23 W 2465.32 S 3 53 W 2536.26 S 159.06 W 2541.24 S 3 35 W 2612.19 S 150.09 W 2616.50 S 3 17 W 2686.77 S 160.21 W 2690.42 S Z 59 W 2760.32 S 129.65 W 2763.36 S 2 41 W 2832.51 S 118.58 W 2834.99 S 2 23 W 2902.79 S 106.97 W 2904.76 S 2 6 W 2970.93 S 94.97 W 2972.45 S I 49 W 3130.05 S 65.88 W 3130.75 S I 12 W ARCO ALASKA9 INC. 3 0-13 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 20-JUN-88 PAGE DATE OF SURVEY: 06-JUN-88 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: M. MCBRIDE. MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TO INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELON KB FROM KB SURFACE LOCATION AT ORIGIN= 1041 FNL, 2024 FWL, SEC. 2Z, T13N, RgE,UM TVO RECTANGULAR COORDINATES SU~-SEA NORTH/SOUTH EAST/WEST 7503.00 7538.00 7600.00 7739.00 7832..00 7950.00 6530.57 6471.57 2883.72 S 110.22 W 6559.17 6501.Z7 2903.60 S 106.83 W 6609.98 6551.98 2938.60 S 100.74 W 6725.17 6667.17 3015.15 S 86.98 W 6802.65 6744.65 3065.75 S 77.69 W 6900.88 6842.88 3130.05 S 65.88 W ARCO ALASKAt INC. 3 0-13 KUPARUK NORTH SLOPE'ALASKA COMPUTATION DATE: 20-JUN-88 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER= PAGE 06-JUN-88 58°00 FT M. MCBRIDE *~***~***~*~ S'TRATIGRAPHIC SUMMARY MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TO MEASURED DEPTH BELOW KB 7503.00 7538.00 7600.00 7739.00 7832.00 7950.00 ORIGIN= 1041 FNL, TVD FROM KB SUB-SEA 6530.57 6472.57 6559.17 6501.17 6609.98 6551.98 6725.17 6667.17 6802.65 674~.65 6900.88 6842°88 SURF 2024 F~L RECTA~G NORTH/ 2B83. 2903. 2938. 3015o 3065. 3130. ACE LOCATION AT SEC. 22~ T13N, RgEtUM ULAR COORDINATES SOUTH EAST/WEST 72 S 110.Z2 W 60 S 106.83 W 60 S 100o74 W 15 S 86°98 W 75 S 77°69 W 05 S 65.88 W FIN.AL MEASURED DEPTH 7950.00 WELL LOCATION TRUE VER'TICAL DEPTH 6900.88 AT TD: SUB-SEA VERTICAL DEPTH 6842.88 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3130.75 S I 12 g SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3 O- 13 F I ELD KUPARUK COUNTRY USA RUN ! DATE LOOOED 06 - JUN - 88 REFERENCE 72814 WELl 30-13 (1041'FNL, 2024'FWL, SEC 2.,_, T13N, RgE,UM) HORIZONTAL PROJECTION NORTH ~000 REF ?28 ! 4 SCALE = 1/IOOO [N/FT 2000 1000 - 1000 -~000 -5000 -4000 SOUTH -E;O00 -4000 14EST -9000 -2000 - ] 000 0 1000 2000 3000 4000 EAST WELL' 30-13 (1041'FNL, 2024'FWL, SEC 2~, T13N, R9E, UM) VERTICAL PROJECTION -2000 - 1000 0 0 1000 2000 9000 4000 ....... E;000 __ R000 t:±::): :..~.]:: ~]~ :-r?~-t-~ .~.~-,..~]~I ...... ~.+i-~k"+'~ ~--l--w~]..~m~...~i..~_?~.~...~q-~-.~..~ .-J-;-~.--k .... .--+-ki-+.'+"H'+' :]~i:i:~:: ]:~:~i:i:-.~.~4...;~_ .... ~..~.q...?? · "+ ...... ~"~ ....... ~"+'"~'"+ .... ~-.~-~--.~ ...... +---~--~--~ .... ~-+--~-~----~ ~ · -~ ~-4-~-- ~ 4 ~--~- ~ ~ ~ ~ .. ...... : . : : ~ i I ! , ! ~ ~ ~ ) ) · , , ~ ..... , , ..... ~ l"~"r"l ....... i'"t'"?? .... 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PROJECTION ON VERTICAL PLANE 189. - 9. $CI:ILED IN VERTICAL DEPTH8 HORIZ SCALE = 1/1000 IN/FT WELT, NAME : LOG Wl~,L LOG INVENTORY PAGE 1 of LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) CFD (compensated formatiOn density) BHC/SL (borehole compensated sonic) LSS (long spaced sonic) SSS (short spaced sonic) CYB (cyberlook) GCT (groscopie survey) DIPMETER SAMPLES: Require~i Comments: yes o Date Received: .... '~ STATE OF ALASKA ALAS.,,-~ OIL AND GAS CONSERVATION COM .... 3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing ~ Other 2. Name of Operator ARCO Alaska, Inco Stimulate [] Plugging [] Perforate r~ Pull tubing 5. Datum elevation (DF or KB) RKB 58 ' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number ' 30-13 8. Approval number 8-383 9. APl number 50-- 029-21803 10. Pool Kuparuk River 0il Pool 4. Location of well at surface 1041' FNL, 2024' FWL, $ec.22, T13N~ RgE, UH At top of productive interval 1355' FSL, 1914' FWL, 5ec.22, T13N, R9E, UM At effective depth 1173' FSL, 1946' FWL, Sec.22, T13N, RgE, UM At total depth 1109' FSL, 1958' FWL, Sec.22, T13N, RgE~ UH 7950 ' MD 6901 'TVD 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 7832 'MD true vertical 6803'TVD Casing Length Size Conductor 80' 16" Surface 4304' 9-5/8" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 175 sx AS i ll0'MD 1500 sx AS III & 4339'MD 300 sx Class G Top job w/85 sx AS I 395 sx Class G 7915'MD True Vertical depth 110'TVD 4046 'TVD 6872'TVD 12. Producti on 7882 ' 7" Perforation depth: measured 7680'-7700'MD true vertical 6676 ' -6693 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail (~ 7449' Packers and SSSV (type and measured depth) HB pkr ~ 7375' & FVLD SSSV (~ 1789', Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Copies of Logs and Surveys Run [] 14. Attachments Daily Report of Well Operations [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer (Dani) SW03/O18 Date 10'14-~ Submit in Duplicate Form 10-404 Rev. 12-1-85 (~- -- STATE OF ALASKA ALAS,,,-, OIL AND GAS CONSERVATION COMI~.:,¢SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Fi Stimulate [] Plugging ~ Perforate [~ Pull tubing Alter Casing [] Other X] .COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, inc. RKB 58' 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 7. Well number 30-13 4. Location of well at surface 1041' FNL, 2024' FWL, 5ec.22, T13N, R9E, UM At top of productive interval 1355' FSL, 1914' FWL, Sec.22, T13N, R9E, UM At effective depth 1173' FSL, 1946' FWL, Sec.22, T13N, R9E, UM At total depth 1109' FSL, 1958' FWL, Sec.22, T13N, R9E, UM 8. Approval number 8-484 9. APl number 50m 029-21803 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 7950 ' MD 6901 ' TVD Effective depth: measured 7832 'MD true vertical 6803 ' TVD Length Size 80' 16" 4304 ' 9-5/8" 7882 ' 7" Casing Conductor Surface Production feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 175 sx AS I 1lO'MD 1500 sx AS II1 & 4339'MD 300 sx Class G Top job w/85 sx AS I 395 sx Class G 7915'MD True Vertical depth 110'TVD 4046'TVD 6872'TVD Perforation depth: measured 7680'-7700'MD true vertical 6676'-6693' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 7449' Packers and SSSV (type and measured depth) HB pkr @ 7375' & FVLD SSSV @ 1789' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. Well Hi~tory) Daily Report of Well Operations E~ Copies of Logs and Surveys ,Run ~] Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Date ~'-/2-~,~3 Submit in Duplicate (Dani) SW03/018 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 indetinite or appreciable length of lime. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK3056 ICounty or Parish NORT}{ SLOPE Lease or Unit ADT,: 25513 Title COMPT,W..TE AND PFERFORATE I Accounting cost center code State API: 50-029-21803 Operator A.R.Co. W.I. ARCO 56.0000 Date 30-13 IWell no. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 06/26/88 ( TD: 7950 PB: 7832 SUPV:DL/KR Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our J Prlor status if a W.O. I 1130 }{RS 06/25/88 Complete record for each day reported NORDIC 1 RELEASED RIG 7"@ 7915' MW: 6.9 DIESEL ACCEPTED RIG @ 1130 MRS, 06/25/88. ND TREE. NU BOPE & TESTED TO 3000 PSI. PERFORATED 'A' SAND F/7680'-7700' WITH 8 SPF, 45 DEGREE PHASING. RIH WITH 2-7/8" COMPLETION EQUIPMENT. SET PACKER. TESTED TUBING TO 2500 PSI. SHEARED PBR. TESTED ANN TO 2500 PSI. TESTED SSSV TO 1500 PSI. ND BOPE. NU TREE & TESTED TO 5000 PSI. SECURED WELL AND RELEASED RIG @ 0600 MRS, 06/26/88. (TAIL @ 7449','FVLD' SSSV @ 1789','HB' PKR @ 7375') DAILY:S148,462 CUM:$963,034 ETD:S963,034 EFC:$1,275,000 Old TD New TD Released rig Date IPB Depth Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I 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 Signature For form preparation an~/distribution, see Procedures Manual,~ection 10, Drilling, Pages 86 and 87. IDate ITitle 7-/0 -ELe_, ASSOCIATE ENGINEER STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM,,.SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of RequeSt: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [_~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other fL3 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage: AK cj9510-O3RO 4. Location of well at surface 1040' FNL, 2023' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1320' FSL, 1848' FWL, Sec. 22, T13N, R9E, UM (approx) At effective depth 2031' FSL, 1250' FWL, Sec. 15, T13N, R9E, UM (approx) At total depth 2097' FSL, 2139' FWL, Sec. 15, T13N, RgE, UM (approx) 5. Datum elevation (DF or KB) RKB 59 ' 6. Unit or Property name KH.narHk Rivc, r llnif_ 7. Well number 30-13 8. Permit number 88-40 9. APl number 50-- 029-21 803 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 7950 'MD feet feet 6897'TVD 7832'MD 6799'TVD Size feet feet Plugs (measured) N o n e Junk (measured) None Cemented Measured depth True Vertical depth Conductor 80' Surface 4304' 1 6" 9-5/8" 7" Production 7882 ' Perforation depth: measured NONE true vertical NONE ~bing(size, grade and measured depth) NONE Packers and SSSV(type and measured depth) NONE 175 sx AS I 1500 sx AS I I I & 300 sx Class G Top job w/85 sx AS 395 sx Class G 1lO'MD 4339'MD -7915'MD RECEIVED JUN 2 2 ]988 Alaska 0il & 6as Cons. Commission Anchorage llO'TVD 4047 ' TVD 6868'TVD 12.Attachments Well History Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation June, 1988 14. If proposal was verbally approved Name of approver Form No. ~ ~3"..~/(~¢Dated--~/,~'~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢ ~ ~./)4J..~ Title Associ ate Engi neet Commission UseOnly (Dani SA3/108) Date Conditions of apprgval Approved by ~R. ii~.[NAt S~GNED BY Form 10-403 Rev 12-1-85 Notify commission SO representative may witness I Approval No. ~,~ [] Plug integrity [] BOP Test [] Location clearanceI Approved C.opy ~ Returneo -~ -, by order of Commissioner the commission Date (_.~_~... Submit in triplicate ARCO ~,i and Gas Company Well History - Initial Report - Daily Inatructionl: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County, parish or borough ARCO Alaska, Inc. I NORTH SLOPE FieJd Lease or Unit KUPARUK RIVER FIELD ADL: 25513 Auth. or W.O, no. lime AK3056 I DRILL IState AK 30-13 API: 50-029-21803 JWell no. Operator ARCO Spudded or W.O. begun IDate SPUD I 05/15/88 Date and depth aS of 8:00 a.m. Complete record for each day reported I ARCO W I IHour J 56.0000 w,o. iPrior status it a I 0900 HRS o5/16/88 ( ') TD: 2343'(2~43) SUPV:JS 05/17/88 ( TD: 3963'( SUPV:JS 05/18/88 ( ) TD: 4357'( 94) SUPV:JS 05/19/88 ( ) TD: 4694'( 37) SUPV:RB 05/20/88 ( .) TD: 6884'( 2 90) SUPV:RB 05/21/88 ( TD: 7950'(1(~6) SUPV:RB 05/22/88 ( TD: 7950'( 0) SUPV:RB DOYEN 14 RIH, PREPARE TO KICK OFF 16"@ 110' MW: 9.4 VIS: 59 ACCEPTED RIG @ 0330 HRS, 5/15/88. MIXED SPUD MUD. PU, STRAP BHA #1. TESTED DIVERTER. SPUDDED WELL @ 0900 HRS, 5/15/88. DRILLED 12-1/4" HOLE TO 2343'. PUMPED MWD SURVEY. CIRCULATE HOLE A/~D PUMPED DRY JOB. POOH. MU BHA #2. RIH AND PREPARE TO KICK WELL OFF. DAILY:S88,562 CUM:$88,562 ETD:S88,562 EFC:$1,275,000 DRILLING 16"@ 110' MW: 9.3 VIS: 83 CONTINUED RIH. REAMED TIGHT SPOT @ 1840'-1940'. REAMED TO 2343'. DRILLED TO 2579'. DYNA-DRILLED TO 3054'. CIRCULATE. PUMPED PILL. DROPPED SURVEY. POOH. DRILLED TO 3963'. DAILY:S46,049 CUM:$134,611 ETD:S134,611 EFC:$1,275,000 NU BOPE 9-5/8"@ 4339' MW: 9.3 VIS: 55 DRILLED TO 4357'. MWD SURVEY. CIRCULATE BOTTOMS UP. SHORT TRIP TO HWDP. CIRCULATED. DROPPED SURVEY. POOH. RAN 9-5/8", 36.0#, J-55, BTC CASING WITH SHOE @ 4339'. CMTD CASING WITH 1500 SX AS III & 300 SX CLASS G. PERFORMED TOP JOB WITH 85 SX. NU BOPE. DAILY:S199,329 CUM:$333,940 ETD:S333,940 EFC:$1,275,000 DRILLING 9-5/8"@ 4339' MW: 8.7 VIS: 33 NU BOPE & ATTEMPTED TO TEST. PULLED TEST JT AND DRESSED TUBING HEAD. NU BOPE & TESTED. (AOGCC WAIVED WITNESSING THE TEST) INSTALLED WEAR RING. MU BHA #4 & TIH. CUT DRILLING LINE. RIH & TAGGED FC @ 4255'. TESTED CASING TO 2000 PSI. DRILLED FS AND 10' NEW FORMATION. PERFORMED LOT TO 12.5 PPG EMW. CHANGED OVER MUD. POOH. DRILLED TO 4503'. MWD FAILED. POOH. CHANGED MWD & TESTED. RIH. DAILY:S59,279 CUM:$393,219 ETD:S393,219 EFC:$1,275,000 POOH FOR BIT 9-5/8"@ 4339' MW: 9.3 VIS: 34 DRILLED 8-1/2" HOLE TO 6884'. PUMPED DRY JOB AND POOH. DAILY:S42,952 CUM:$436,171 ETD:S436,171 EFC:$1,275,000 CIRC AND COND MUD 9-5/8"@ 4339' MW:10.0 VIS: 44 POOH. CHNG BITS. RIH. DRLD 8-1/2" HOLE TO 7950'. CIRC. SHORT TRIP TO SHOE. CIRC AND COND MUD. DAILY:S49,175 CUM:$485,346 ETD:S485,346 EFC:$1,275,000 RUNNING 7" 7"@ 7915' MW: 9.9 VIS: 40 CIRC. SURVEY. RU SOS. LOG W/ DIL/GR/SP/SFL F/ 7950' TO 4339' AND GR F/ 7950'- TO 1000'. LOG W/ FDC/CNL F/ 7950' TO 7200', CAL F/ 7950' TO 4339'. RD SOS. MU BHA AND RIH TO SHOE. CDL. CIRC AND SPOT DIESEL PILL. POOH LDDP. RU AND For form prepar~i/:)n and distribution, see Procedures~,~nual, Section 10, Drilling, Pages 6~ and 87. JDate J Title ~-'~-~ A88001A~ EN(~IN~'R RECEIVED AR3B-459-1'D JUN 2 2 1988 JNumber all dally well history forms consecutively Page no. as they are prepared for each well. J Alask~ 0il & Gas Cons. Commission Anchorage -:: ;. '.~ "~ t' ,';'. '..'.'.; .... -. '.' ' ':' ' ._,: :::;:;.:=..~:_;;:j:' ' _:: :_t -: :'-' ". ~:.' :__' :f :'_:..' ::- :~ ~:'.~C:. '::..L/J.' .'!.!_._: :J ' ,! , "'/ ARCO U~i and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pe'rforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following selling of oil string until completion. District Field ARCO Alaska, Inc. KUPARUK RIVER FIELD County or Parish IStafe NORT~ SLOPE I AK Lease or Unit 30-13 Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress DOYON 14 RUN 7" CSG. DAILY:S122, 714 CUM: $608,060 ETD:S608,060 EFC:$1,275,000 JUN 2 2 1988 0it & Gas Cons. Commission Anchorage Well no. The above is correct ~ _ ~.-7-~..~., ASSOCIATE ENGINEER For form prepara~i~n and distribution see Procedures ~l~lnual Section 10, Drilling, Pages 81~/and 87 AR3B-459-2-B JNumber all daily well history forms consecutively lPage no. as they are prepared for each well. I ARC~ 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, repot1 completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish ARCO Alaska, Inc. II NORT}{ SLOPE Field Lease or Unit KUPARUK RIVER FIELD ADL: 25513 Auth. or W.O. no. ~Title AK3056 J DRILL Accounting cost center code Stale AK 30-13 IWell no. API: 50-029-21803 Operator I A.R.Co. W,I. ARCO I 56. 0000 Spudded or W.O. begun Date SPUD 05/23/88 Date and depth !Complete record for each day reported as of 8:00 a.m. DOYON 14 05/23/88 ( TD: 7950 PB: SUPV:RB Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our Prior status if a W.O. 0900 HRS FINAL REPORT 7"@ 7915' MW:10.0 NACL RUN 199 JTS OF 7" 26# J-55 BTC CSG. RU DOWELL. CIRC AND COND MUD. CMT W/105 SX OF FLYASH/G AT 12.0PPG AND 290 SX CLASS G AT 15.8 PPG. CI? AT 1700 HRS 5/22/88. RD DOWELL. SET SLIPS. NU TREE. TEST SAME TO 3500 PSI. PUMP DIESEL CAP. SECURED WELL & RELEASE RIG AT 2230 HRS 5/22/88. DAILY:S206,512 CUM:$814,572 ETD:S814,572 EFC:$1,275,000 RECEIVED JUN 2 2 ]988 Alaska 0ii & Gas Cons, Commission Anchorage Old TD New TD Released ng Date Classifications (oil, gas, etc.) Producing method Potentia~ test data IPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on lest Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected IDate ITitle Signature For form prepar~on and distribution, see Procedure~' l~anual, Section 10, Drilling, Pages~ and 87. ~880ClATE ENGINEER AR3B-459-3-C INumber ell dally well history forms consecutively as they are prepared for each well, jPage no. Dlvldml of AIIsntlcRIchfletdCompany ARCO Alaska, Inc. Date: June 17, 1988 Transmittal #: 7193 RETURN TO: 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 O- 1 3 Cement bond Log (CBT) 6 - 6 - 8 8 6 4 9 0 - 7 81 8 3 O- 1 5 Cement Evaluation Log (CET) 6 - 5 - 8 8 2 6 9 5 - 9 3 2 4 3 O- 1 4 Cement Evaluation Log (CET) 6 - 5 - 8 8 2 2 9 5 - 8 0 0 6 ~~'^,ask~ 0,i &A~nacSh~rOan;~; Commission If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: NSK Drilling State of Alaska(+sepia) ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7165 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles 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. "~"30-16A 5" Dual Induction 4-27-88 4600-8337 ~30-16A Cyberlook 4-27-88 7500-8200 '"'~O-16A 2" Dual Induction 4-27-88 4600-8337 ~"30-16A 2" & 5" Porsity FDC 4-27-88 7450-8311 mmmi~O-16A 2" & 5" Raw FDC 4-27-88 7450-8311 ~O-15 5" Dual Induction 5-05-88 2773-9291 ,~ O- 15 2" Dual Induction 5 - 05 - 8 8 2773 - 9291 ~,~__~3330-15 2" & 5" Porosity FDC 5-05-88 2773-9265' O-15 2" & 5" Raw FDC 5-05-88 2773-9265 ~O-15 Cyberlook 5-05-88 8700-9291 ~30-14 Cyberlook 5-13-88 7490-8000 "~,,e O- 14 2" &5" Raw FDC 5-13-88 7490-8021 ~"~30-14 2"&5" Porosity FDC 5-13-88 7490-8021 "'~O 14 2" Dual Induction 5-13-88 2364-8046 3 O- 14 5" Dual Induction 5- 1 3 - 88 2364 - 8046 ~""'3 O- 13 2" Dual Induction 5 - 21 - 8 8 4340 - 7945 ~=~30-13 5" Dual Induction 5-21-88 4340-7945 ~'"'30-13 Cyberlook 5-21 -88 7300-7900 ,=~3 O- 13 2" & 5" Porosily FDC 5 - 21 - 8 8 71 96 - 791 9 30-13 2" & 5" Raw FDC 5-21-88 7196-7919 transmittals me a~~ If you have any questions, concerning this or any other please cai 265-6835. ~~~ Naska 0ii & Gas Cons. G0mmlallolt ARCO Alaska, Inc. Date: May 26, 1988 Transmittal #: 7162 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles 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. 30-1 6A Open Hole Tape and Listing 5 - 0 5 - 8 8 #72 71 6 3 O- 1 5 Open Hole Tape and Listing 5 - 1 5 - 8 8 # 7 2 7 4 6 3 O- 1 4 Open Hole Tape and Listing 5 - 1 8 - 8 8 # 7 2 7 6 0 3 O- 1 3 Open Hole Tape and Listing 5 - 2 5 - 8 8 # 7 2 7 6 5 If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Lynn Goettinger State of Alaska 011 & Gas Cons. C0mmissloD Anohorage STATE OF ALASKA ALASt,. , OIL AND GAS CONSERVATION COMM._,SION APPLICATION FOR SUNDRY APPROVALS 1."Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing 1~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. RKB 59' 3. Address 6. UnitorProperty name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1040' FNL, 2023' FWL, Sec. 22, At top of productive interval (~ target 1320' FSL, 1848' FWL, Sec. 22, At effective depth T13N, R9E, UM T13N, R9E, UM 7. Well number 30-13 8. Permit number 88 -40 9. APl number 50-- 029-21 803 At total depth 10. Pool 1146' FSL, 1838' FWL, Sec. 22, T13N, R9E, UM Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Proposed: Surface 4260 ' feet PlUgs (measured) feet feet Junk (measured) feet Size Cemented Measured depth 9-5/8" tail 300 sx Class G & lead 1500 sx AS ill True Vertical depth 4295'MD 4053'TVD Perforation depth: measured true vertical Tubing (size, grade and measured depth) In the original permit application the 9-5/8" surface casing was proposed at 2219'MD/TVD. This sundry proposes deepening the surface casing setting depth. The reason for the change is production casing sticking problems that are believed the result of the longer open hole section. Cement volumes for the 7" producation casing will be reduced to about 100 sx of lead and 200 sx of Class G. Sufficient volume will be used to place G cement 500' above the Kuparuk. Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation May 14, 1988 14. If proposal was verbally approved Name of approver ~~ ~ 2_~.C_~ ~_/_~/__~.~c,," Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~(~~ ~L/~ Title Associate Engineer Date ,~"/2-~x~ ~/ ' CommissionUseOnly ~,E~i $A3/103) Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI (27 ' Approved Copy ~--x--~~~,~Returned ~ '~=~--'/~ "-~) ~ "' · by order of Approved by CommiSSi'°ner the commission Date Form 10-403 Rev 12-1-85 ~' / / ..--,- S~bmi~ in triplicate feet IiECEtVEt ALASKA OIL & GAS B,O.P,E. Inspectlm Report Location: Sec Location, General____~'~- Well Sign ~'~._. General Housekeeping. ~... Reserve Pit ' Drilllng Cunt r ac to_r_~~.~t Visual Audio ~stems Trip Tank Pit Gauge Flow Monitor ~as Detectors BOPE Stack Annular Preventer Pipe Rams__ Blind Rams Choke Line Val~es H.C.R. Valve Y£ll Line Valves ,~: eck Valve Test Results: Faflures ACCUMULATOR SYSTLM 'Full Charge Pressure ~-~ psig Pressure ~-e~'~,r C~n~,r~ _/~__~_~.; ~sig ~,~,,: pz'~s 200 ~si~ ~ P7 Test Pressure ' u~al'ge -P,-eg.suI'e ~.,.2ained _sec, Remote ~ Blinds switch over _K~!}y~nd Floor Safet~ Valves Upper Lower Ke~. Ball Type las~de BO~___Z Test Pressure -- .... ~,~e w.~t:hin days and Inspector/ Repair or Replacement o Commission office notified. Di$czibution o~i3. - AO&GCC c c - Operat :: cc - Superv.£$or April 26, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Te l ecopy: (907) 276-7542 Re: Kuparuk River Unit. 30-13 ARCO Alaska, Inc. Permit No. 88-40 Sur. Loc. 104O'FNL, 2023'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. l146'FSL, 1838'FWL, Sec. 22, T13N, R9E, Ult. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The pe~it to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing 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. ~%~ere 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. Ver~y tru~y~urs, C.~~. Chatterton' Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~{ISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK,,,, ,.)IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL la. Type of work Drill [] 20 AA(::; 25.005 Redrill r-Il lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF-II Service [] Developement Gas [] Single Zone '~ Multiple Zone [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Po0. Box 100360, Anchorage, AK 99510-0360 4. ~cation of wellatsurface 1040'FNL, 2023'FWL, 5ec.22, T13N, R9E, UM (~ target) Attop ofproductiveinterval 1320'FSL, 1848'FWL, Sec.22, T13N, RgE, UM At total depth 1146'FSL, 1838'FWL, Sec.22, T13N, R9E, UM 13. Distance to nearest well 30-14 25' (~ surface feet 12. Distance to nearest property line 1146'~ TD Kickoff depth 2370 feet feet 16. To be completed for deviated wells Maximum hole angle 400 18. Casing program size Hole CaSing 24" 1 6" Specifications Coupling Weld BTC W BTC !2-1/4 9-5/8 MD 35' 35' 34' 5. Datum Elevation (DF or KB) RKB 59 ' PAD 24 ' feet , 6. Property Designation ADL 25513 ALK 2554 7. Unit or property Name Kuparuk River Unit 8. Well nurpber 30-13 9. Approximate spud date 05/09/88 14. Number of acres in property 2560 lO. Field and Pool Kuparuk River Field Kuparuk River Oil Poo' 11. ~pe Bond(see20AAC25.025) Statewide Number #8088-26-27 Amount $500,000 1578P.~o2P, OMSCd depth (MD and TVD, (6788 ' TVD) feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1 1 4 0 psig At total depth (TVD) Setting Depth Top Bottom TVU ] MDI TVa 34 ' J 7852 1 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ,~68 ps,g Quantity of cement (include stage data) 115' ±200 cf 2219' 900 sx AS II I & 300 sx AS II 6788' ~00 sx TLW lead & I 200 sx Class G tail lUC ~UU' above UUNU' Total depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Plugs (measured) Junk (measured) Length Size Cemented Measured depth True Vertical dept> · 20. Attachments Filing fee [] Property plat ~-- BOP Sketch ~ Diverter Sketch [] Drilling program [] Drilling fluid program ~ Time vs depth plot ~- Refraction analysis ~ Seabed report [] 20 AAC 25.050 requirements 21. I hereby certi,Pc'that the foreq_oing/i~ true and correct to the best of my knowledge Signed ? //~..¢f~¢//~..~.~_~_.././,<~' Title Reg,onal, Drillin, Engineer Date / ~ ~ /,/ / - Commission Use Only ~~ (TFM) pn~/R~ J6 ' ". Permit NumCer /JAPl number J Approval date I See ~over letter I50-- O~9 - Ct ~O~ I04/26/88 J for other requirements Conditions of approval Samples required - Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures [] Yes '~ No Directional survey required ~ Yes Requiredwor~~~M; ~ 10M; ~ 15M Other: ~'"~ ~~' ~~ ,~ · Approved by k,,~= ,- / .- k,~ _.J//~~~ Commissioner ~ No by order of the commission ......... tQO0 B/ PERIIAI"ROST TVD"'171 9 .............. 20QQ_, . , r~ 9 5/8" CSG PT TVD"2219 KOPI TVD"23ZO THD"2370 DEP'O 9 T/ UGNU SNDS TVD'2699 TPID'2701 DEP'29 5000, BUILD 3 DE(~ PER I O0 FT 33 T) ~/ SAK SNDS TVD=3444 THD=3511' DEP-331 39 EOC TVD"3591 TND-3695 DEP-441 K-12 TVD-3899 THD'4095 DEP-697 .. AVERAGE ANGLE 39 DEG 45 HI N K-5 TVD-5819 THD-6592 DEP-2294 I 1000 2000 VERTICAL SECT[ON T/ ZONE D TVD-6399 TPID-Z34Z DEP-2??B ~T/ ZONE C TVD-6481TMD-Z453 DEP-2845 ZONE A TVD=652! TI"ID=?505! DEP=2878 TARGET CNTR TVD=6578 TMD=7580 DEP=2925 B/ KUP SNDS TVD=6634 TND=?652 DEP=2972 ~ ~TD (LOG' PT)' TVD-678B"THD"?852 DEP-3100 3000 4000 , -.-~--~ --- ~ ........... ARCO' ALASKA. ['a~-~T- .................... : ............... WEST-EAS? ; t000 t · , ~ ....................................... ~.. 2000 ..... 1000 ~ , 0 1000 I I 2000 SI~~. I..OCAT ! ON, 1040' FII~. ~i}l~31' FLIT. TARGET~ CENTER TVD-61t~8 TI'IDm?500 SOUTH bm:ST .I ?$ TD i..O~AT I ON' 114~' FSI., 1838' FWI. 9~0. ;g,2. T13Ni, RIIE TAROIE:T LOCATIONs 13_2Q' F~L,. 184,0' gEC.~ 22. TI3N. ~ ( ...... ! .............. r ............... i ....... :--: .............. i .....2'92'5'"'r (TO' TARGET) ; ..- ~ ........................................................... -4 ...................... ~ ............................ ~ ......................... , 1250:, I / ~ 1900~ 900 2100- 2150 I 3300 ~,' !1 850 1 900 1 950 2000 2050 , . 900 950. 100( 1 05( 110( 115C 120C 1 25( 1 30C KUPARUK RIVER UN I T 20' DIVERTER SCHEHATIC DESCRIPTION 1. 16' CGt~XJCTC~ 2. FHC SLIP-ON ~ STARTII~ HEAD 3. FI'lC DIVERTER AS~d~LY WITH ~ 2-I/16' 20OO PSI BALL VALVES 4. 20' 2000 PSi ORILLINe SPOOL W/10' ~rrLETS 5. 10' HCR BALL VALVES W/lO' DIVERTER LINF~. A $1~ VALVE ~ AUT(~ATICALLY CL~ ar ~ I~EV~T~R. VALVES CAN BE DIVERSI(~N. 6. 20' 2000 PS1 ~ 4 ARCO ALASKA, INC., REGIJEST~ A~AL OF THIS DIVERTER SYSTEI~ AS A VARIANCE FRO~ 20AAC2$.O3$(b) I"IAINTE'NANCE & OPERATION 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOtJRS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS~OR GAS I$ DETECTED. OPEN APPROPRIATE VALVE'TO AC:HIEVE DOWNWIND DIVERSION. ,- DO NOT ,SHUT IN WELL UNDER ANY CIRCUHSTANCES DIAGRAM #1 13-5/8" 5000 PSI RSREA BOP STACK q 6 i I. 16' - 2000 PSI TAI~ STARTIN~ lEAD 2. II * - 3000 PSI CASII~ lEAD 3. II" - 3000 PSI X 13-5,/8' - ,SCX~ PSI SPACER ~ 4. 15-5/8" - 50:X) PSI PIPE ~ 5. 13-5/8" - 5C130 PSI DRILLING SPOCL ~t/Q-K)KE ~ KILL LIhE$ 6. 13--5/8" - 5030 PSI DCLSLE RAM N/PIPE RAI~ ON TCP, 7. 15-5/87 - ,5030 PSI AI~i~ ACCUvULAT~ CAPACITY TEST I. C~ECK ~ FILL ACCUM.L~TDR RESERVOIR TO PROPER LEVEL WITH HYDP. ALLIC FLUID. 2. ASSIJRE THaT AC~ATCR PRESSURE IS 3000 PSI WITH 1500 PSI [X]N~TREAM CF THE REGULATCR. 5. OBSERVE TIbE~ TFEN CLOSE NJ. UNITS SIMJLT~EOUSLY ~ RECORD 31-E TIldE N~D PRESSIJRE REMAINING AFTER ALL UNITS N~E CLOSED WITH ~ING ~ OFF. 5 4 3 ,> 4. RECORD ON NN3C REPORT, THE A~ABLE LO~R LIMIT IS 45 SE~ CLCE~INS TIbE ~ 1200 PSI RI'~INING 13-5/8" BOP STACK TEST FILL B~P STACK N~D CHCKE DI~IIF~ WITH AI~'TIC DIESEL. Q-ECK THAT ALL LOCK ~ SCRE~S IN VE1.L~c/~ ARE FULLY RETRACTED. SEAT TEST PLUG IN WITH RI,N~ING JT ~ ~ IN LOQ(DO/~ SCRE~ 3. CLOSE ~ PREVENrE~ AI~D ~ KILL ~ CHCKE LIkE VALVES ADJACENT TO BCP STACK. ALL o'n-ER VALVES AI~ Q-IOKES SHOJ.D BE CPEN, 4. I:~ESSUI~ UP TO 250 PSI A~D HOLD FOR I0 MIN, IN- (]~ PRESSLRE TO 3Z300 PSI A~ H~LD FOR I0 MIN, BLEED PRES~ TO 0 PSI. 5, CPEN AI~A~ PREVENTER ADI) ~ KILL AI~ CHOKE LIkE VALVES. CLOSE TCP PIPE RAI~ AI~ HCR VALVES ON Kill AI~ ~ LI~ES, 6, TEST TO 250 PSI Ai~ 5(330 PSI AS IN STEP 4, 7, C~IDi, E TESTING ALL VALVF~ LIt~ AI~ CHOKES WITH A ~50 PSI LOW AI~ 3000 PSI HIGH, lEST AS IN STEP 4, BO NDT PI~.~ T£s-"r ~ ~ A FULL CLOSING POSITIVE SEAL CHOKE, C~Y FI~TICN TESI (]-~ES -IHAI DO Da.Il FULLY CL(~E, 8, OPEN TCP PIPE RAI~ AI~ CLC~E BOTTOM PIPE RAI~. TEST BOTTOM PIPE RAMS ?0 250 PSI A~D 3000 PSI, 9. OPEN BOTTOM PIPE ~ BACK OUT RU~ JT A~D PULL OUT OF HOLE, I0, CLOSE BLIM) ~ ~ TEST TO 250 PSI ~ 30~ PSI, II. OPEN BLI~I) ~ AI~ ~ETRIEVE TEST PLUG, MaJ(E SURE Ma~IIF(I.D A~D LIltS ARE FULL OF NON-FREEZII~ FLUID. SET ALL VALVES IN CRILLING PClSITI(]~I, 12. lEST 5"TAM33IPE VALVES~ KELLY, KELLY C(XX.~ DRILL PIPE SAFETY VALVE, ~ INSIDE B(:P TO 250 PSI AM) 3000 PSI. 13. I~(:X:I~ TEST II'~FCRI~TION ON BLOViI:XJT PREVENTER TEST FORM, SIGN, AI~ ~ TO I~ILLING SUPERVISOR. 14. PERFORM CCM3LETE ~ TEST AFTER NIPPLII~ UP AM) t~EKLY TI-EREAFTER FI.J~TlCtlaJ..LY OPE~TE BCPE DALLY. 51008400 I I~¥ ! GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9,5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) 'Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) COntinue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psi§. 11) Downsqueeze Arctic pack and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move. in workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER ~ MUD CLEANER SHALE S STIR SHAKERS STIR MUD ENTRIFUGE CLEANER TYPICAL MUD SYSTEM SCHEMATIC Density YP Viscosity Initial Gel 10 Minute Gel Filtrate API pH % Solids DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20 -40 50-100 5-15 15-30 20 9-10 10+_ Drill .out to Weight Up 8.7-9.2 5-15 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD __ 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (VisTM & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This Shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area InjeCti°n Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. L~5 / ih CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1)' Fee (2) Loc (2 thru 8) (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg (14 thru 22) (5) BOPE ~,~,~'. (23 thru 28) (29 thru 31) Company /G/~O Lease & Well No. YES NO 1 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 ................ z'~ 7. Is operator the only affected party ................................. ~ . 8. Can permit be approved before fifteen-day wait ...................... ~__ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ,,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... 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 .... ......... , .............. 23. Is a diverter system required ....................................... 24. Is the drilling fluid program schematic and list of equipment adequate..~-9. 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~Ooo psig .. 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ....... 30. Are seismic analysis data presented on shallow gas zones'.. 31. If an offshore loc., are survey results of seabed conditions 32 Additional requirements · O ~Z Geo lofty: Eng~nPering: rev: 02/17/88 6.011 I~ITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, Additional Remarks: Well History File APPENDIX Information of detailed nature that is not Particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE YERfFICATION DISTING LVP OIO,H02 VERIFICATION blSTING PAGE 1 ** REEL HEADER ~* SERVICE NAME :EDIT DATE :B8/05/25 ORIGIN : ** TAPE HEADER *~ SERVICE NA~E :EDIT DATE :88/05/25 ORIGIN 1727~ TAPE NAME CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :EDIT LIS,ARCO KUPARUK 30-1],API # 50-029-21803 ** FILE HEADER ** FILE NAME :EDIT ,001 8ERVICE NAM~ : VER:$iO~ # . DATE : ~AXIMU~ LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ** INFORMATION RECORDS CONTENTS UNIT TYPE CATE SIZE CODE 000 000 018 065 CN : ARCO AhASKA, INC, 000 000 006 065 ~ : 3 0-13 FN : KUPARUK 000 000 008 065 RANG: 9E 0'00 000 002 065 TV~N: !3N 000 000 004 065 SECT: 2~ 000 000 002 065 N~ 000 000 012 065 COUNf OR~H SbOP:E 000 000 006 065 STAT~ ASASKA CTRY~ USA 000 000 004 ~NEM CONTENTS UNIT fY E CATE SIZE CODE 000 000 001 065 ******************************************************************************** bVP OlO,h02 V~i~RIFICATION LISTING PAGE 2 * SCHLUMBERGER * * ALASKA COMPUTING CENTER * WELL = 3 0-1' AP1 # = 50-029-21803 FIELD = KUPA~UK COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA LDP:R!CK KRU~ELL CASING TYPE FLUID DENSITY VISCOSITY PH FbOID LOSS 9.625" ~ 4~39" DSND POLYMER 10 LB/G 5 4,4 C3 BlT SIZE = 8,5" TO 7950' (DRILLER) R~ = 4,97 8 68 DF RMF = 5,41 ~ 65 DF R~C = 3,01 ~ 58 DF RN AT BNT = 2'469 g 144 DF ~ATRIX SANDSTONE NOTE{ I,~FILE EDIT 001 CONTAINS DATA OF' DUAL INDUCTION (OIL), FORMATION DENSITY FDC), COMPENSATED NEUTRON (CML), AND GAMMA RAY THRU CASING [CSG) LYP OIO,H02 ¥~RIFIC~3:ION i~ISTING PhGE 3 SAMPLED ~ ,5' 2,)FILE EDIT.O02 CONTAINS HI RES FORMATION DENSITY (FO,), COMPENSATED NEUTRON (CNH) SAMPLED ~ 1.2" THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WiTH THIS MAGNETIC TAPE{ DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIb) DATA AVAIbABbE~ 7945' TO 4340' FORMATION DENSITY COMPENS~,TED LOG (FDC~ DATA AVAILABLE: 7919' TO 7195 COMPENSATED NEUTRON bOG (CNL) DATA A~AILABbE~ 7904' TO 7195' GA~A RAY THRU CASING (CMG) DATA AVAILABLE: 4~40' TO 995' FORMATION DENSITY COMPENSATED LOG HI RES 1,2" DATA AYAILABLE~ 7919' TO 7!96' COMPE~. SATED NEUTRON LOG HI RES 1,2" (CNH) OATA AVAIbABLE~ 7904' TO 7~96' LVP OlO,H02 VERiFICATIO!i LISIING PAGE 4 $$ DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 B 4 73 60 9 4 65 ,lin 16 1 66 1 0 1' 66 0 DATUM SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT API APl API APi FILE SIZE SPL REPR ID ORDER # bOG TYPE CLASS MOD NO, DEPT FT O0 000 O0 0 0 4 SFLU DIL OHM~ O0 220 O1 0 0 4 ILD DIL OHMM O0 120 46 0 0 4 Ib~ DIL OH~ O0 120 44 0 0 4 SP DID MV O0 010 O1 0 0 4 OR DIL GAP! O0 310 O1 0 0 4 FDC GAPI oo 3!0 Ol 0 0 4 TENS FDC LB O0 635 21 0 0 4 CAbI FDC IN O0 280 O1 0 0 4 RHOB FDC G/C3 O0 350 02 0 0 4 DRHO FDC G/C3 O0 $56 Ol 0 0 4 DPMI FDC PU O0 890 O0 0 0 4 NFDC FDC CPS O0 354 01 0 0 4 FFDC FDC CPS O0 354 02 0 0 4 TNRA CNL O0 420 Ol 0 O' 4 ~TN~ ~b O0 000 O0 0 0 4 NPNI CNG pu O0 890 O0 0 0 4 RCNT CNL CPS O0 000 O0 0 0 4 RCFT CNL CPS O0 000 O0 0 0 4 CFTC CNL CPS O0 000 O0 0 0 4 CNTC CNL CPS O0 000 O0 0 0 4 T~NS CNL LB O0 635 21 0 0 4 OR CNL GAP! O0 3:10 O1 0 0 OR CSG 6API O0 31,0 Ol 0 0 4 TENS CSG LB O0 635 21 0 0 4 PROCESS COOE (OCTAL) I 68 00000000000000 1 68 00000000000000 1 68 O00OO000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 O000000UO00000 i 68 00000000000000 1 68 00000000000000 I 65 00000000000000 I 68 O0000OO0000000 i 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 DATA DEPT 7~78.~000 SFLU 875 OR DPHI Ilj2676 NFDC RTNR 3,2667 NPHI 3 0793 ILD 99 1875 TENS 8 5000 RHOB 602 0000 FFDC 32 3791 RCNT 2.12.79 iL~ 3084,0000 GR 2,4642 DRHO 483.5000 TNRA !998,!980 RCFT 2,2683 99~1875 0,0357 :1,0234 bo~5!7~ LVP OIO,H02 VERI~ICATIO~ CFTC 680,34bl CNTC GR -999,2500 TENS DEPT 7900,0000 SFbU SpN -14,2578 GR TE-S 4840 0000 CALl DpHI 10i5755 NFDC RTNR 3 3971 NPHI CFTC 639 7312 CNTC GR .999.2500 TENS DEPT 7800,o000 SFbU 5P -19.5000 GR TENS 4792,0000 CALl DpHI 12.0256 NFDC ETNR 3.7018 NPHi CFTC 556'8793 CNTC GR -999,2500 TENS DEPT 7!00.0000 SFLU SpN_ . 22,0000 OR TE $ S704~;0000 CALI DPH! ' 13;6082 NFDC RTNR 3~1149 NPHI CFTC 822,0552 CNTC GR .999;2500 TENS OEPT 7600,0000 SFLU SP &26,5000 O~ FENS 4660'0000 CALl DPHI I3,8735 NFDC ~TNR 3,5294 NPHI CFTC .592,4690 CNTC GR 999~2500 TENS DEPT 7500,0000 SFLU DPHI NFDC RTNR 3,0514 NPHi CFTC 749.0784 CNTC OR -999;2500 TENS DEPT 7400 0000 SFLU TENS 4400,5000 GR ,0000 CASI NFDC DPHI 1!,0743 RTNR 3~3000 NPHI 641, ~TC 2527 CN~C .999;2500 TENS DEPT 7300.0000 SFbU $p '41;5000 GR TE~S 4380'0000 CALI LISTING 2020 2224 -999:2500 3.1286 85.5000 9.5156 588.0000 36,5738 2024.16~1 -999.2500 3,2884 100,8750 8,5781 650,0000 39,0450 ~871,6187 999,2500 8,5537 80,8750 8,8906 590,0000 32,0959 ~289,1201 999,2500 2,7878 97,1875 8,6719 636'500O 38,3185 ~992,5437 999,2500 4,3665 112.6875 '9,4609 564.0000 33'4692 ~150'0308 999~2500 2,2990 125.0000 9.3516 567,0000 36,.:3984 ~003'21~8 !999,2500 1,7065 8750 TENS ILD TENS RHOB FFDC RCNT TENS IhD TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT RMOB FFDC RCNT TENS RHOB FFDC RCNT TENS TENS RHOB FFDC RCNT T~N$ ILD TENS R~OB 3084,0000 GR 3.0278 . 757 ORHO ~62.2500 TNRA 2031,3628 RCFT 4840,0000 2 b197 4792;0000 2,4517 DRHO 540.0000 TNRA 1839,8386 RCFT 4792,0000 GR 7.4736 4701,0000 ,4256 DRHO ,0o0o 2,20405 I514 4660, 000 GR 2,4212 DRHO 55 ,7639 RCFT 196~'5000 TNRA 4660,0000 GR 3,1602 IbM 4400.0000 GR 2,5001 ORHO fNR 424'5000 C'~ 2083;0464 R FT 4400 · 0000 2.3874 440~:04000 GR b74 ORHO 451,7500 TNRA 2073,4233 RCFT 4400,0000 (JR 1,5232 4380,0000 GR 2,3i48 DF{HO PAGE 5 99.1875 ],0837 85.5000 0,0289 3,2206 b79,3536 85.5000 2,7076 i00,8750 2791 5O2,3649 !00,8750 7,5799 80,8750 0,0151 2,9110 687;9865 80'8750 2,3754 97,1875 0,0471 3'2472 517;0410 97,1875 112,6875 0,0187 3,0466 b37'2563 2,'4522 125'0000 0,0113 3.1975 554'9359 I2b,O000 1,5901, 1~,8750 ,0022 LVP 010,H02 VERIFICATION LISTING PAGE 6 DPHI 20,9216 NFDC RTNR 4,1458 NPHI CFTC 447,5726 CNTC GR -999,2500 TENS 608,5000 FFDC 45,7981 RCNT 167],7693 TENS -999,2500 DEPT 7200,0000 SFLU 2,3319 IhD ~ '46,7813 GR 118,7500 TENS 094 RHOB PHI 16,7974 NFDC 58 ~TN~ 4,4000 NPHI 46.9145 RCNT CFTC .492.1429 CNTC ~786,8572 TENS GR 999,2500 TENS 999,2500 7100,0000 SFLU '48.7500 GR =999,2500 CALl -999,2500 NFDC -999,2500 NPHI -999,2500 CNTC -999,2500 TENS DEPT DPH! RTNR CFTC DEPT 7000,0000 SFLO ~N -36.7500 GR S '999,2500 CALl DPH! -999~2500 NFDC RTNR -999'2500 NPHI CFTC -999.2500 CNTC GR -999,2500 TENS DEPT SP TENS DPHI CFTC DEPT SP TENS DPHI CFTC 6~00,0000 SFLU .4!,9687 GR ~999"2500 CALI ~999'2500 NFDC ,999'2500 NPHI 999,2500 CNTC -999'2500 TEN8 6~00,0000 SFLU 4!'7500 GR -999,2500 CALl -999~2500 NFDC -999,2500 NP~! -999,2500 CN C -999;2500 TENS 6700 0000 SFbU -47 7188 GR -999 2500 CAbi -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC -999 2500 TENS DPMI RTNR CFTC ~R 3,0190 ILD .148'2500 TENS 999,2500 RHOB :999,2500 FFDC .999,2500 RCNT 999,2500 TENS -999,2500 I 7120 ILD 272 0000 TENS -999 2500 RHOB -99~ 2500 FFDC -~ 2500 RCNT -999 2500 TENS -999 2500 036 0000 TNRA 1664:2002 RCFT 4380.0000 GR I 9439 4304 0000 GR 2 3730 DRHO 550 SO00 TNRA 1799 4783 RCFT 4304 0000 GR 2,4866 IbM 4428 0000 GR -999 2500 DRBO -999 2500 TNRA -999 2500 RCFT -999 2500 GR 1,3417 Ih~ 4392,0000 GR '999,2500 DRHO -999,~500 TNRA -999, 500 RCYT -999.2500 GR 2,4026 IbP 2,1068 IbM 9],8750 TENS 4460,0000 GR -999~2500 RHOB '999,2500 DRHO '999'2500 FFDC '999,.2500 TNRA -999,2500 RCNT -999,2500 RCFT -999,2500 TENS -999,2500 OR -999,2500 2,7655 IGD 2,5860 Ib~! 92~9375 TENS 4540,0000 GR -999;2500 RHOB -999'2500 DRHO -999'2500 FFDC -999,2500 TNRA -999'2500 RCNT -999,2500 RCFT -999,2500 TEN8 -999,2500 GR -999'2500 .11~:2537 2500 .999'2500 RHOB ~999,2500 FFOC .999~2500 RCNT .999,2500 '999'2500 2.7448 IbM~ go .oooo 99,2500 DRHO -999,2500 TNRA -999,2500 RCFT -999,2500 GR 3.~799 40~,0922 106,8750 2,U341 118,7500 '0,'0028 ~,7524 483,5026 118,7500 2,5659 -999,2500 -999,2500 -99~,2500 -999,2500 -999,2500 ! 4194 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,1762 -999;2500 -99~'2500 -999.2500 -999,2500 .999,2500 2,6682 -999'2500 -999,2500 -999,2500 -999;2500 -999,2500 2 8292 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 DEPT 6600,0000 SFbU 2,7460 ihD 2,4674 IbM 2,b297 LYP OlO,H02 yERIFICATION LISTING -47,2500 GR SPNS -999.2500 CALI ~TNR -999.2500 NPHI CFTC ~999 2500 CNTC GR 999:2500 TENS DEPT 6500,0000 SFbU SP -47,0313 GR TENS -999'2500 CAbI NFDC UPN! :999.2500 RTNR 999'2500 NPH! CFTC .999,2500 CNTC OR -999,2500 TENS DEPT 6~00,0000 SFbU ~PN 46.7500 GR E.S :999,2500 CgbI DPHI .999,2500 NFDC RTNR ,999,2500 NPHI CFTC 999,2500 CNTC GR -999,2500 TENS DEPT 6300,0000 SFbU TENS .999,~500 CAbI PPHl -999~2500 NFDC RTNR .999'2500 NPHI CFTC -999.~500 CNTC GR -999;:2500 TENS OEPT 6200,0000 '0000 SP TENS .999,2500 CAbI DPHI -999,2500 NFDC RTNR .999'2500 NPHI .999;2500 CNTC ~[TC .999,2500 TENS DEPT 6100,0000 SFhU SP -47.7500 G~ -999'2500 CAbi PM .999,250C NFDC RTNR -99~'~500 N ~HI CFTC .999. 500 CNTC GR -999'2500 TENS DEPT 6000,0000 SFbV Sp '53,7188 GR TENS .999,~500 CALI DPHI -999'2500 NFDC ' NPHI RTNR .999,2500 2500 CNTC CFTC '999'2500 TENS GR -999. .113.8750 TENS 999,2500 RHOB -999,2500 FFDC -999,2500 RCNT -999,2500 TENS -999,2500 ,oo.25oo TENS ~999.2500 RHOB .999,2500 FFDC 999,2500 RCNT '999,2500 TENS '999,2500 3,0664 .103,1250 TENS 999,2500 RHOB 999'2 RCNT .999,~500 TENS .999'2500 3,0793 .100,2500 TENS 999,2500 RHOB :999,2500 FFDC 999.250: 3,4430 ILD 99,1875 TENS .9~9,1~500 RMOB .999,250.. RCNT .999,2500 TENS 999,2500 2,9271 .10t,9375 TENS .999,2500 RHOB .999'2500 FFOC .999'2500 RCNT .999,2500 TENS 999'2500 !03,6250 TE~S :999'2500 R~OB .999'2500 FFDC .999;2500 RCNT 999'~500 TENS -999,2500 4248,0000 GR -999.2500 ORHO -999,2500 TNRA -999,2500 RCFT -999.2500 OR 2.5824 IbM ~108,0000 OR -999,2500 DRHO -999,2500 TNRA -999,2500 RCFT -999,2500 GR 2,8633 4180,0000 GR -999,2500 DRHO -999,2500 TNRA .999.1500 RCFT -999, 500 OR 2.9957 4070,0000 GR -999,2500 DRHO -999,2500 TNRA -999'2500 RCFT .999.2500 3.2130 4020,0000 GR -999,2500 DRHO -999~2500 TNRA :999'2500 RCFT 999~2500 GR 2,6881 $894~0000 GR -999,2500 DRMO '999, 500 '999, 500 RCFT '999* 1500 0o00 · .999,2500 DRHO '999, GR PAGE 7 -999,2500 -999,2500 -999.2500 :999.2500 999,2500 2,6641 -999,2500 -999,2500 999,2500 999,2500 999,2500 . 2,9296 999,2500 -999,2500 -999,2500 .997,2500 -999,2500 3,0648 :999,2500 999'2500 :999,2500 .999,~500 999,2500 3,2715 -999'2500 -999,2500 -999,2500 -999,2500 -999,2500 2,7289 .999;2500 .999,2500 .999'2500 .999,2500 .999'2500 2,9239 ~999,2500 -999,2500 .999,2500 .999,2500 -999~2500 LVP OIC,H02 VERIf'ICATIOM LISTING PAGE 8 DEPT TENS DPMI RTNR CFTC GR DEPT TENS DPHI FTC DEPT DPMI CFTC DEPT sp TENS DPHI RTNR CFTC GR DEPT DPHI RTNR CFTC GR DEPT TENS RTNR CFTC GR DEPT TENS DPHI RTNR 5900.0000 SFLU =4~,2500 GR -999.2500 CALl -999,2500 NFDC -999,2500 NPHI -999.2500 CNTC -999.2500 TENS l O0,O000 SFLU 49.5000 GR 999.2500 CALl -999 2500 NFDC -99912501) NPHI -999 2500 CNTC -999 2500 TENS I 8574 90 5000 TENS -999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999 2500 TENS -999 2500 98 -999 -999 -999 -999 -999 2 7460 0000 TENS 2500 RHOB 2500 FFDC 2500 RCNT 2500 TENS 2500 5~00.0000 SFbO 3.1270 ILD 53,5000 GR 98.6875 TENS -999~2500 CALI -999,2500 RHOB :999,2500 NFDC -999.2500 FFDC .999.2500 NPHI -999.2500 RCNT .999'2500 cNTC -999,.2500 TENS 999.2500 TENS -999,2500 5600,0000 SFLO -57,2500 GR "999 2500 CALI '999.2500 NFDC -999'2500 NPHI -999'2500 CNTC -999'2500 TENS 5500.0000 SFLU '5b,7500 GR -999;2500 CAGI -999,2500 NFDC -999,2500 NPMI -999'2500 CNTC -999,2500 TENS 875 TENS -999,2500 R~OB -999;2500 FFDC -999;2500 RCNT :999,2500 TENS 999~500 89 -999 -999 -999 -999 -999 4375 TENS 2500 RHO~ 2500 FFDC 2500 RCNT 2500 TENS 2500 5400,0000 SFbU 3,7372 ILO -59.~500 GR 91~0000 TENS -999"2500 CALi -999'2500 RHOB -999'~500 NFDC -999,2500 FFDC -999'~500 NPMI -999'2500 RCNT -999'~500 CMTC -999,2500 TENS -999'2500 TENS -999;2500 5300 0000 SFLU -60 7500 GA -999 2500 CALi -999 2500 NFDC -999 2500 NPMI 3:8781. Ih~ . 8 3750 TE:.$ 999~2500 RH:OB :999,2'5oo ~FDC 999,2500 RCNT 2,3098 IbM 3754,0000 OR '999.2500 ORHO =999.2500 TNRA '999,2500 RCFT "999,2500 GR 2,6460 Ih~ 3894,0000 GR 999 2500 DRHO :999!2500 TNRA '999 2500 RCFT '999,2500 OR 2,9778 3590!i000 OR -999 500 PRHO -999 500 TNRA .C T -999 500 GR 2 3809 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,6847 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 3 0043 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,7487 I5~ 2,7598 3520,0000 GR -999,2500 -999,2500 DRHO -999,2500 -999,2500 TNRA -999,2500 -999,2500 RCFT -999,2500 -999.2500 GR -999,2500 2,7030 Ib~ ~g0.o000 GR 99,2500 DRHQ -999,~500 TNRA '999, 500 RCFT '999.2500 GR 3,3430 IbM 3534,0000 GR "999,2500 ORHO -999'2500 TNRA -999'2500 RCFT -999'2500 GR 3.2567 .3350,:0000 GR :999,2500 DRHO .999. 2500 TNRA 999' 2500 RCFT 2 7027 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 . '99~,2500 -999,~500 -999'2500 "999.2500 -999'2500 3,2940 -999'2500 '999,2500 -'999,2500 -999.2500 LVP OlO,HO2 VERIFICATION LISTING PAGE 9 CFTC GR DEPT ~TN~ CFTC GR DEPT Sp TENS DPHI RTNR CFTC DEPT TENS DPHI RTNR FTC R DEPT TENS RTNR CFTC GR DEPT TENS OPH! RTNR CFTC GR DEPT SP TE~S DPHI RTNR CFTC OR · DEPT SP TENS ~999.2500 CNTC 999.2500 TENS 5200 0000 SFbU -60 2500 GR -999 2500 CALI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC -999 2500 TENS 5100,0000 8FGO -59,2813 GR -999,2500 CAb! -999,2500 NFDC -999,2500 NPH! -999'2500 CNTC '999,2500 TENS -999 2500 TENS -999:25oo 3 0190 86i1250 TEN~ -999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999.2500 TENS -999,2500 2 5161 86 2500 TENS -999 2500 -999 2500 FFDC -999 2500 RCNT -999 2500 TENS -999 2500 -999.2500 GR 2,8205 3264,0000 GR -999,2500 DRHO -999,2500 TNRA -999.2500 RCFT -999.2500 GR 32 ,0000 GR '9~.2500 DRHO '999 2500 TNRA -999 2500 GR 5000,0000 SFLU 2,7017 ILO 2,4469 iLM -60,7500 GR . 87,9375 TENS 3!00,0000 GR -999.2500 CALI .999,2500 RHOB -999,2500 DRHO -999.2500 NFDC :999,2500 FFDC -999,2500 TNRA -999,2500 NPH! 999,2500 RCNT -999,2500 RCFT :999~25U0 CNTC -999,2500 TENS -999~2500 GR 999'2500 TENS -999,2500 4900,0000 SFLU 3,0473 lbD -61,2500 GR . 9.3,6250 TENS -999'2500 CAb! .999;25'00 RHOB -999,2500 NFDC .999,2500 FFDC -999,2500 NPHI .999.2500 RCNT - 99'2500 CNTC m999':2500 TENS -~99,2500 TENS 999,2500 2.7772 86'5625 TE -999,~500 RHOB -999.2500 FFDC -999~,2500 RCNT -999,2500 TENS -999' 2500 2,6967 IbD '999,2500 RHOB :999,2500 FFDC ~999,2500 RCNT ~999,2500 TENS 999'2500 2,9776 90.5000 TENS -999'2500 RHOB 4800 000:0 SFLU -670000 UR '999 2500 CAL! -999 2500 NFDC -999 2500 NPHI 9 2500 TENS 7oo.oooo SFUU -999,~§00 CAb! -999,~500 NFUC -999'~500 NPHI -999'2S00 CNTC -999,2500 TENS . 999,2500 CALl 2,8320 IbM 3244,0000 GR -999.2500 DRHO -999'2500 TMRA -999.2500 RCFT -999'2500 GR 2.7669 ILL ~944,0000 GR .999,2500 DRHO ~999, 500' TNRA 999'~500 RCFT -999,2500 GR 2.7745 Iba ~!20,0000 GR 999,2500 DRHO -999,2500 TNRA -999,2500 RCFT '999,'~500 GR 2,8599 28t~,0000 GR '99 ,2500 D~HO -999.2500 2,8392 -999,2500 '999,2500 '999'2500 :999,2500 999,2500 2,3892 -999,2500 -999,2500 -999,2500 -999,~500 -999,2500 . 2,4821 ~999;2500 999,2500 :999,2500 .999,2500 999,2500 2,8392 - 99,2500 -999,2500 -999;2500 -999;2500 2 7239 -999 2500 -999 2500 -999 2500 -999 2500 ~999 2500 2,6868 999;2500 -999,2500 -999;2500 -999, 500 '999,2500 DPHI -999 2500 NFDC RTNR -999!2500 NPHI CFTC -999 2500 CNTC GR -999.2500 TENS DEPT TENS DPHI RTNR CFTC GR DEPT TENS DpNI CFTC DEPT SP TENS CFTC GR DEPT O~ RTN~ CFTC GR DEPT TENS DPHI RTNR CFTC GR 4500 0000 SFbU -65 1250 GR -999 2500 CALl -999 2500 NFDC -999 2500 NPHI '999 2500 CNTC -999 2500 TENS 4400,0000 SFLU -69 4375 GR -999 2500 CALl -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC -999 2500 TENS ~300,0000 SFLU :999,2500 GR .999,2500 CAbI .999,2500 NFDC -999'2500 NPHi -999.2500 CNTC 63,53!3 TENS 4200 0000 SFbU -999 2500 GR -999 2500 CAbI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 71 6875 TENS 4100 0000 SFbO -999 2500 GR 99 N 2500 PHI -999 2500 CNTC 51 093B TENS -999 2500 FFDC -99912500 RCNT -999 2500 TENS -999 2500 2.1672 IbD 94.2500 TENS -999.2500 RHOB -999,2500 FFDC -999.2500 RCNT -999.2500 TENS -999,2500 2.9373 80.4375 TENS 999,2500 RHOB -999.2500 FFDC -999.2500 RCNT :999.2500 TENS 999.2500 -999 2500 IL.D -999 2500 TENS -999 2500 RHOB -999 2500 FFDC -999 .2500 RCNT -999 2500 2780 0000 -$99.2500 IhD - 99,~500 TENS -999,2500 RHOB - 99,2500 FFDC '~99;2500 RCNT -999,2500 TENS 2674,0000 -999.2500 TNRA '999.2500 RCFT -999.2500 GR 2.0094 IbM 2734 0000 GR -999:2500 DRHO '999 2500 TNRA '999:2500 RCFT '999.2500 GR 2,9807 IbM 2724.O000 GR :999 2500 DRhO 99,2500 '999.2500 '999.2500 -999.2500 2 0261 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,8369 '999,2500 '999,2500 '999.2500 '999,2500 -999,2500 '999.2500 IbM '999,2500 '999.2500 GR -999,2500 '999;2500 DRHO "999.2500 '999"2500 TNRA '999,2500 '999'2500 RCFT -999'2500 -999.2500 OR -999,2500 ,, -999.2500 IbM -999 2500 GR -999 2500 DRHO -999 ~500 TNRA 5O0 -999 RCFT -999 2500 G~ -99 .2500 -99 ~2500 TENS -999,2500 GR -999~:2500 RHOB -999,2500 DR~O -999;2500 FFDC -999'2500 TNRA -999,2500 RC~ -999,2500 ~CFT -999.2500 TE S -999.2500 GR 2704,0000 -999.2500 Ib~ :999.2500 O~ ~999,2500 DRHO :999,2500 TNRA ,999..2500 RCFT 999'2500 GR DEPT 4000,0000 SFLO :999.2500 ILD SP~_ '999,2500 GR :999~2500 TENS ~50 RHOB TE:!,..!$ '999,25:00 CALl :999, 0 DpHI -999,2500 NFDC ~999~2500 FFDC RTNR -999,2500 NPHI ~999;2500 RCNT ~FTC -999'2500 CNTC .999;2500 TENS OR 57,0938 !fENS 2734,0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999.2500 -999 2500 '999 2500 -999 250:0 -999 2500 '999 2500 '999 2500 -999,2500 '999,2500 -999,~500 -999,2500 -999'~500 -999,:2500 DEPT 3900,0000 SFbO '999,2500 IhD '999.2500 i5~ -999,2:500 LVP OlO,H02 VERIFICATION [.ISTING PAGE TENS DP~I RTNR CFTC GR DEPT SP TENS DPHI RTNR CFTC GR DEPT SP TENS DPBI RTNR CFTC GR DEPT TENS DPHI RT~ CFTC DEPT SP TENS DPHI RTNP CFTC DEPT DPHI CFTC GR DEPT SP TENS DPHI RTNR CFTC -999 2500 GR -999 2500 CALI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 56 5625 TENS 3800 0000 SFLO -999 2500 GR -999 2500 CAbI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 58 8750 TENS 3700= -999 -999 -999 -999 -999 57 0000 SFUU 2500 GR 2500 CAbI 2500 NFDC 2500 NPH! 2500 CNTC 6875 TENS 600,0000 SFbU 999,2500 GR 999,2500 CAb! '999,2500 NFDC -999;2500 NPHi -999,2500 CNTC 55,4375 TENS 3500.0000 SFbU -999,2500 GR -999;2500 CALI -999~500 NFDC -999'2500 NPH! -999,2500 CNTC 58'1562 TENS ~400,0000 SFLU 999,2500 GR ~999,2500 CALl .999,2500 NFDC ~999,2500 NPHI -999~2500 CNTC 50,6563 TENS 300.0000 SFLU 999,2500 GR .999;2500 CAbI '999,2500 NFDC -999,2500 NPH! -999.2500 CNTC 60'5938 TENS -999 2500 TENS '999' .999.2500 RHOB ,2500 FFDC '999,2500 RCNT '999,2500 TENS 2630,0000 -999,2500 IbD =999,2500 TENS -999,2500 RHOB -999.2500 FFDC -999,2500 RCNT -999,2500 TENS 2470,0000 -999 2500 -999i2500 -999 2500 RHOB '999.2500 '999,2500 '999,2500 2454,0000 999,2500 .999, 00 .999, O0 999'2500 2374'0000 -999 2500 :999.2500 GR 999.2500 URHO '999 ~500 TNRA -999! 500 RCFT -999 2500 OR -999.2500 IL~ -999,2500 GR :999 2500 U~HO 999~2500 TNRA '999.2500 RCFT '999,2500 GR '999,2500 DRHO FFDC -999,2500 TNRA RCNT -999,2500 RCFT TENS -999,2500 GR -999 -999 -999 '999 -999 2500 2300 0000 '999,2500 '999,2500 -999'2500 -999,2500 -999,2500 '999,2500 22~0.0000 '999,2500 '999,25'00 ~999,2500 .999~.2500 ~999~2500 999,2500 2234,0000 ILD -999.2500 I~ TENS ~999,2500 GR RHOB 999,2500 DRHO FFDC -999'2500 TNRA RCNT -999'2500 RCFT TENS -999,2500 GR 2500 TENS 2500 R H OB 0 FFOC TENS ILO TENS RHOB FFDC RCNT TENS TENS ~HOB FFDC RCNT TENS -999 2500 -999 2500 '9 2500 RCFT -999 2500 GR ~999,2500 ILB 999.2500 GR :999.2500 DR,O .999'2500 TNRA 999,2500 RCFT -999.2500 GR -999 500 OR '999 500 OR -999 2500 =999i2500 -999 2500 '999,2500 -999,2500 ~999,2500 .999,2500 .999,2500 ~999,2500 999,2500 -999,2500 '999 2500 -999 2500 -999 2500 .-999 2500 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 ~999,2500 999, 5oo '99~,2500 '99~2 O0 -999;2~00 -999 2500 -999 2500 '9991500 -999 500 -999 500 -999 2500 '999,2500 -999,~500 '999;2500 '999,2!500 -999;2500 -999,2500 LVP 010,H02 VERIFICATIDN bIGTING ~AGE 12 DEPT RTNP CFTC P PHI RTNR CFTC DEPT TENS DPHI RTNR CFTC GR DEPT Sp DPH! DEPT DPH! RTN~ CFTC G~ DEPT TE'S DPH! RTNR CFTC GR DEPT SP TENS PHI TNR 3200 0000 SFbl] -999 2500 GR =999 2500 CAb! -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 46 0625 TENS 100,0000 $FLU .999,2500 GR .999,2500 CALI .999.2500 NFDC 999,2500 NPBI -999,2500 CNTC 28,3750 TENS 3000 0000 $FLU -999 2500 GR -999 2500 CALl -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 48 6250 TENS 2900,0000 SFLU -999'2500 GR -999, ~500 CAbI ..999,2500 NFDC -999,~500 NPHI -~99;2500 CNTC 33,3750 TN ~800 999 -999 -999 -999 -999 3! 0000 SFbU 2500 GR 2500 CAbI 2500 NFDC 2500 NPHI 250O CNTC 8750 TENS 2700 0000 SFLU -999 2500 GR -999 2500 CALI -999 2500 NFDC -999 2500 NPHI -999 2500 CNTC 47 0625 TENS 2600 '999 "999 '999 "999 0000 SFLD 2500 GR 2500 CALl 2500 NFDC 2500 NP~I -999 2500 ILD -999i2500 TENS -999 2500 RHO~ -999 2500 FFDC -999,2500 RCNT -999,2500 TENS 2250,0000 -999 2500 ILD -999 2500 TENS -999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999 2500 TENS 2204 0000 -999 2500 -999' ,2500 TENS '999,2500 RMOB '999,2500 FFDC "999,2500 ~CNT '999,12500 2~70,0000 '999,2500 '999,2500 TENS "999,2500 RHOB '999,2500 FFDC '999,2500 RCNT '999,2500 TENS 2045~0000 '9992500 '999 2500 TEN5 =999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999 2500 TENS ~990 0000 -999, ~ 0 -999;~ 0 00 T~NS -999,2500 RHOB -999'2500 FFDC -999,2500 ~CNT -999,2500 TENS 1935'0000 -999 2500 IbO "999 2500' TENS -999 2500 RHOB '999 2500 FFDC =999 2500 RCNT -999.2500 Ib~ =999 2500 GR -999 2500 DRHO -999 2500 TNRA -999 2500 RCFT -999 2500 GR -999 2500 Ib~ -999 2500 GR -999 2500 DRHO -999 2500 TNRA '999 2500 RCFT '999,2500 GR -999,~500 IbM -999, 500 GR -999,2500 DRHO -999,2500 TNRA =999,2500 RCFT -999'2500 G~ -999,2500 IbM 99,2500 GR -~99,i2500 DRHO -999'2500 TNRA -999,2500 RCFT =999,2500 GR -999,2500 IbM -999,2500 GR -999,2500 DRHO -999,2500 ?NRA '999,2500 RCFT -999,2500 GR '999,2500 ibm '999,'~00 GR '999': O0 DRHO -999'2500 TNRA -999,2500 RCFT -999,2500 GR '999,2500 -999,2500 '999,2500 -999,2500 '999,2500 '999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250O -999,2500 "999,2500 '999,2500 '999,2500 '999,2500 -999,2500 -999,2500 '999,2500 -999~2500 -99~,2500 : 9 ; 5oo 99~,2500 - -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -999 2500 · -999,2500 -999,2500 "999,2500 -999,2500 "999,2500 -999,2500 -999,2500 Ib~ -999,2500 -999,~500 G~ -999.2500 -999,2500 DRHO -999,2500 -999,2500 TNRA '999'2500 '999,2:500 RCFT -999'2500 LVP OIO,H02 VERIFICATION LISTING CFTC DEPT sp TENS OPHI RTNR CFTC DEPT sp DPHX RTNR CFTC DEPT ~P TENS RTNR CFTC DEPT TENS DPM! RTNR CFTC DEPT Sp PP~I RT~R CFTC OEPT DPHI. CFTC GR ~EPT TENS -999,2500 29,2969 2500,0000 =999,2500 '999 2500 '999 25O0 '999 250O '999 2500 35,~375 2400.0000 -999,2500 -999,2500 -999,2500 -999,2500 -99~,2500 2300,0000 :999.2500 .999;2500 999,2500 .999'2500 .999.2500 37,6875 2200,0000 -999,2500 .999~2500 .999'2500 :999,2500 999'2500 47.7188 2100,0000 .2999,2500 ~99,2500 .999.2500 ~999,2500 .999,2500 30,3906 2000,0000 .999'25:~ -999,2500 -999;2500 -999,2500 42,7813 ~900,0000 999,2500 -999'2500 CNTC TEN5 GR CALX NFDC NP~I CNTC TENS GR CALI NFDC NPHI CNTC TENS SFLU CALl NFDC NPHI CNTC TENS SFLU GR CALl NFDC NPHX CNTC TENS SFhO CALl NFDC NPHI CNTC TENS SFLU GR CALl NFDC NPHI SFLt) CA~I 1999 2500 TENS 860:0000 -999.2500 -999,2500 TENS .999,25 FFDC 999,2500 RCNT -999,2500 TENS 1790~0000 -999,2500 I50 -999,2500 -9~9,2500 RHOB -999'2500 FFDC ~999,2500 RCNT 999.2500 TENS 1745,0000 -999,2500 -999,2500 TENS -999,2500 RHOB -999,2500 FFDC -999,2500 RCNT -999,2500 TENS 1700,0000 -999,2500 ILD -999~::2500 TENS ~999'25 FFDC ~999,2500 RCNT 999,2500 1665,0000 -999,2500 -999,2500 TENS -999,2500 RHOB -999'2500 FFDC -999,2500 RCNT -999'2500 TENS ~610,0000 -999,2500 -999,2500 TEN5 -999,2500 RHOB -999'2500 FFDC -999,2500 RCNT "999'2500 TENS i575,0000 -999~2500 -999,2500 TENS '999.2500 RHOB -999.2500 GR -999.2500 -999.2500 -999,2500 DRHO -999,2500 -999,2500 RCFT -999,2500 GR -999,2500 -999.2500 GR -999.2500 DRHO -999,2500 T~RA -999,2500 RCFT~ -999,2500 GR -999.2500 1'bM :999,2500 .999.2500 DRHO 999.2500 TNRA -999'2500 RCFT .999'2500 -999,2500 -999.2500 GR -999,2500 DRHO -999 2500 TNRA -999:2500 RCFT -999,2500 GR -999,2500 IbM '999,~500 GR '999'2500 DRHO "999,2500 TNRA -999,2500 RCFT -999,2500 -999,2500 -999,2500 GR '999,2500 ORHO -999.2500 TNRA -999.2500 RCFT -999,2500 GR -999,250~ -999,250.. GR '999.250,0 DRHO PAGE 13 -999,2500 .999,2500 -999,2500 -999~2500 -999,2500 .999,2500 -999,2500 -999,2500 -999,2500 -999'2500 -999,2500 -999.~509 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999e2500 -999,2500 :999,2500 999,2500 -999,2500 -999,2500 -999,2500 .999'2500 -999,2500 .999,~500 :999,2500 999,2500 .999,~500 .999,2500 9:99,2500 999'2500 999;:2500 .999,2500 .999,2500 .999,2500 . . 9~,2500 -~9 ,2500 .999'2500 ., bVP OlO,H02 VERIFICATION blSTING PAGE 14 RTNR CFTC DEPT TENS DPHI RTNR CFTC DEPT RTNR CFTC GR DEPT DPH! CFTC DEPT CFTC DEPT DPMI RTNR CFTC GR DEPT DPMI RTNR CFTC GR DEPT -999,2500 NFDC -999,2500 NPHI -999 2500 CNTC 48:4063 TENS 1800.0000 SFLU -999,2500 GR -999.2500 CAbI -999,2500 NFDC -999,2500 NPHI -999,2500 CNTC 39;J750 TENS 1700 O00O SFbU -999 2500 GR -999 2500 CALl -999 2500 NFDC -999 2500 NPH! -999 2500 CNTC 41 N375 TENS 00,0000 SFLU !!99'2500 GR 99.2500 CAbi -999'2500 NFDC -999,2500 NPHI -999'2500 CNTC 44~9375 TENS -999 2500 FFDC -999:2500 RCNT -999.2500 TENS 1535.0000 -999 2500 -999 2500 TENS -999 2500 RHO8 -999 2500 FFDC -999 2500 RCNT -999 2500 TENS 1495 0000 :999,2500 999.2500 TENS -999,2500 RHOB '999'2500 FFDC '999.2500 RCNT -999'2500 TENS 1445'0000 -999,2500 IL, D -999,2500 TENS -999,2500 RHOB -999'2500 FFDC -999,2500 RCNT -999,2500 TENS 1.420,0000 1500.0000 SFbU -999,2500 -999,2500 GR -999,2500 TENS -999,2500 CAbI -999,~500 RHOB .999.2500 NFDC -999,2500 FFDC -999,2500 NPHI -999,2500 RCNT .9979'2500~= CNTC -999,2500 TENS ,8750 TENS 1380,0000 1400 0000 SF5U -999,2500 GR -999.2500 CAb! -999,2500 NFDC -999,2500 NPMi -999,2500 CNTC 26,0938 TENS 1300 0000 SFLU '999 2500 GR -999 2500 C~LI -999 2500 NFDC -999 2500 NPMI -999 2500 CNTC 4~ 7188 TENS 1200,0000 SFbU -999 2500 TNRA -999:2500 RCF~~ -999,2500 GR -999,2500 lb~ -999,2500 GR -999.2500 DRHO -999,2500 TNRA -999,2500 RCFT -999,2500 GR -999 2500 IbM -999 2500 GR -999 2500 ORHO -999 2500 TNRA -999 2500 RCFT -999 2500 GR -999 2500 -999 2500 GR -999 2500 ORHO -999 2500 TNR~ -999 :~ GR -999,2500 -999,~500 GR ,-999, 500 DRHO -999,2500 -999,2500 RCFT -999,2500 GR. -999 2500 IhD -999,2500 Ib~ -999:2560 TENS -999,2500 GR m999,2500 RMOB -999,2500 DRHO -999,2500 FFDC -999,2500 TNRA -999,2500 RCNT -~99,2500 RCFT -999;2500 TENS -999;2500 GR 1350,0000 -999,2500 IhD -9992!2500 TENS -999.2509 RHOB -999,2500 FFDC -999'2500 RCNT -999,2500 TENS t310,0000 '999,2500 ILO -999 2500 *'999 :2500 GR -999 2500 ORHO -999 2500 '999 2500 RCFT '999 2500 GR -999,2500 IL~ -999 2500 -999:2500 -999,2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 -99~ 2500 '999,2500 '999'25O0 -999'2500 '999,2500 '999,2500 -999,2500 -999,2500 -999,2500 .~99,2500 -999,2500 '99~;2500 ' 0 -999,250' .99 , 5oo -999'2500 -999,2500 -999,2500 -999,2500 -999,2500 -999'~500 :99 .25oo 99~'2500 '99~,~500 -999,2500 -999,2500 bVP OIO,H02 VERIFICATION LISTING PAGE 15 Sp -999 2500 GR TENS -999i2500 CAbI DPHI -999 2500 NFDC RTNR -999 2500 NPH! CFTC -999i2500 CNTC GR 63 53i3 TENS DEPT RTNR CFTC SP CFTC DPHI RTNR CFTC GR 100.0000 SFbU 999,2500 GR 999,2500 CAbI -999 2500 NFDC -999:2500 NPHI -999.2500 CNTC 57,0938 TENS 1000,0000 -999,2500 -999'2500 NFDC -999,~500 -999'2500 CNTC 55,8750 TENS .994,5000 SFbU .999,2500 GR 1999,2500 CA:bi ~999,2500 NFDC .999,2500 NPH1 999,2500 CNTC -999 2500 TENS -999 2500 RHOB '999 2500 FFDC -999 2500 RCNT -999 2500 TENS I275 0000 -999 2500 Ibb -999 2500 TENS -999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999 2500 TENS 1230 0000 -999 2500 IhD '999 2500 TENS '999 2500 RHOB -999 2500 FFDC -999 2500 RCNT -999 2500 TENS 1195 0000 -999.2500 lbo -999~2500 -999~2500 RHOB: :999,2500 FFDC ,999'2500 RCNT 999,2500 TENS 1205.0000 FILE NAME :EDIT ,001 VE~S!ON # : DATE l ~AXI~U~ LENGTH : 1024 FI~ TYP~ ~ ~EXT FIL ~A~E ~ FILE ~EADER ** FIbE NAME : ED!~,~ ,002 SERVICE NANE . MAXiHUM ~N'~TN ~ 1(2~ FIbE TYPE , ~REVIOUS FIbE -999 2500 GR -999:2500 DRHO -999.2500 TNRA '999,2500 RCFT "'999,2500 GR -999.2500 Ibm '999.2500 GR -999.2500 DRHO -999,2500 TNRA -999,2500 RCFT -999.2500 OR -999 2500 -999:2500 OR -999.2500 ORHO '999.2500 '999.2500 RCFT -999,2500 GR -999 -999 -999 -999 -999 -999 2500 Ib~ 2500 GR 500 ORHO .500 TNRA 2500 RCFT 2500 GR -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 =999,2500 -999;2500 -999.2500 -999.~500 99~,2500 bVP OIO,H02 VERIFICATION b16T!NG PAGE 16 DATA FORMAT RECORD ~ TYPE SIZE REPR CODE ENTRY 2 1 66 o 4 1 66 9 4 65 16 1 66 i 0 1 Bt 0 DATUM SPECIFICATION BLOCKS ~NEM SERVICE SERVICE UNIT API APl API APl FILE SIZE SPL RgPR ID ORDER # LOG TYPE CLASS MOD NO, DEPT FT O0 000 O0 0 0 4 GR FDH GAPI. O0 310 01 0 0 4 ~EN$ FDH LB O0 635 21 0 0 4 CALl FDH IN O0 280 Ol 0 0 4 RMOB FDH G/C3 O0 350 02 0 0 4 DRMO FD~ G/C3 O0 356 O1 0 0 4 DpHI FDH PU O0 890 O0 0 0 4 mFDC FDH CPS O0 354 01 0 0 4 FFDC FDH CPS O0 354 02 0 0 4 TNRA CNH O0 420 Ol 0 0 4 RTNR CNM O0 000 O0 0 0 4 NPHI CNM PU O0 890 O0 0 0 4 RCNT CNH CPS O0 000 O0 0 0 4 RCFT CNH CPS O0 000 O0 0 0 4 CFTC CNH CPS O0 000 O0 0 0 4 CNTC CNH C~8 O0 000 O0 0 0 4 TENS CN~ LB O0 635 21 0 0 4 GR CNH GAPI O0 310 Ol 0 0 4 PROCESS CODE (OCTAL) 68 00000000000000 68 O00OO000000000 68 00000000000000 68 00000000000000 ~8 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O000000000OO00 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O0000000000OO0 ** DATA DEPT 79'73,8994 OR 88,0875 TENS 794 DRMO 0,1599 OPHI 2'00. ~'*",r.~RA ,4141 FFDC 1322 O0 3 RTNR RCNT 2003.3083 RCFT 535,3798 CFTC TENS 2020:,0000 GR 88,6875 2020,0000 CAhI 28,5274 NFDC 3,6888 NP~I 60J,,5;:~39 CNTC 7,6602 932,0000 42,8506 2025,3894 DEPT RHOB FFDC RCNT TENS 7900 2998 GR 2 4880 ORHO 461 7500 TNRA 2039 ~267 RCFT 4844 0000 GR 92 1875 TENS 0 0408 DPHI 3 4042 RTNR 527 8870 CFTC 92 i875 4844,0000 CAhI 3448 NPHI 630'1211 CNTC 598 ' LO00 4i, &820 204q;1721 DEPT FFDC ~CNT T~NS 780~ 2998 G8 4240 DRMO 529 5000 TNRA 1852 7700 RCFT 4760 0000 GR 92,1875 TENS 5915 RTNR 474' 9981 CFTC 92.1875 476 C I I~,0000 AL .~086 N~Oc . 2381 N P ~ I 546. 0397 CNTC ~, 859 6149. 000 1906' 501 ,5076 DEPT RHOB 7700.2998 GR 2,4532 DRHO 76.6875 TENS 0,0304 DPBI 4608.0000 CALl 1!.9375 NFDC 59~ '7813 ,5000 LVP OlO,M02 VERIFICATION LISTING FFDC 490,2500 TNRA 2,9420 RTNR RCNT 2300,7930 RCFT 703,9139 CFTC TENS 4608,0000 GR 76,6875 DEPT 7600,2998 GR 97,5000 TENS RHOB 2,4200 ORMO 0,0724 DP~I FFDC 590.0000 TNRA 3,3730 RTNR ~CNT 1979,7964 RCFT 497,5538 CFTC TENS 4660,0000 GR 97,5000 DEPT 7500.2998 GR 11~:8750 TENS RHOB 2,5045 DRHO 0256 DPHI FFDC 427,0000 TNRA 2"8959 RTNR RCNT 2130,4434 RCFI 638 5856 CFTC TENS 4400,0000 GR 114:8750 DEPT 7400 2998 GR 1~2,3125 TENS RHOB 2:4572 DRHO .0.0014 DPHI FFDC 449.0000 TNRA 3,1629 RTNR RCNT 1958,234b RCFT 647~9985 CFTC TENS 4352,0000 GR 122,3~25 DEPT 7300,2998 GR 115,7500 TENS RHOB 2.3370 DRHO 0,0091 DP'HI FFDC 619,0000 TNRA 3..7211 RTNR RCNT 1749,1519 RCFT 435,2217 CFTC TENS 4344~0000 GR 1~5,7500 MOB FFDC 547,5000 TN~A 3,5492 RTNR 1952,0212 RCFT 415,3468 CFTC RCNT 1~6,1250 TENS 4328,0000 GR DEPT 7!9~,0000 GR 1~9'.7500 TENS RHOB .4051 DRHO .0,0023 [)PHI FFDC 509~'2500 TN~A 3'66!2 RTNR RCNT !83 ,0291 RCFT 46~3010 CFTC TENS 4'27 ,0000 GR 11 ,7500 3,3662 NPHI 790.5946 CNTC 46 o oooo i3:9496 3,8846 NPHI 588,~597 CNTC 4400,0000 CAbI 8,~244 NFDC 3.0124 NPHI 772,0728 CNTC 4152,0000 iI,~926 NFDC $.9098 NPHI 654,9902 CNTC 4344,0000 CA~ 18;9778 NFDC 3~4828 NPH! 457'0214 CNTC 4328,0000 CRbi ~6,4720 NF~C 3,97~9 NPHI 498~5~69 CNTC 4272,0000 CAbI F ~ ~4,85~2 4,0952 508,74~ CNTC PAGE 17 32,b952 2324,2808 8,4219 40,9944 1948,2532 9,4219 571,5000 ]1,2120 2194,1587 9,2500 551,0000 35,9177 2040,0774 8,9062 b20,O000 46'6489 1703'5149 9,0391 587,5000 4~, 3022 1807.0447 9,0935 569,5000 45,2737 1777,5903 *$ FILE TRAILER ** FiLE NA~E ~EDIT ,002 SERVICE NAME VERSION ~ DATE ~ - MAXIMUM LENGTH S 1024 FILE TYPE NEXT FILE NAME ********** EOF ** TAPE TRAILER ** bVP OlO,H02 VERIFIC~TIOi~ blSTING P~GE 18 SERVICE NA~E :EDIT DATE :88/05/25 ORIGIN :7276 TAPE NA~E : CONTINUATION # :01 NEXT_TAPE NAME : CO~ENTS :EDIT bIS,ARCO KUPARU~ 30-13,~PI # 5()-029-21803 ** REEb TRAIGER SERVICE NAME IEDIT DATE :88/05/25 CONTINUATION # NEXT REEh NAME COMMENTS :EDXT bIS,ARCO ~UPARUK 30-13,API # 50-029-2.1803 EOF ********** EOF
