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Home My WebLink About188-061188-061 T38902 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 12:50:08 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7916'feet None feet true vertical 6950' feet 7630', 7680', 7714'feet Effective Depth measured 7640'feet 7360'feet true vertical 6727' feet 6504' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7431' MD 6560' TVD Packers and SSSV (type, measured and true vertical depth) 7360' MD 1821' MD 6504' TVD 1821' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1523 mcf Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: AVA RHS Retrvbl Packer SSSV: Camco TRDP-1A Sfty Vlv Jill Simek jill.simek@conocophillips.com (907) 263-4131Staff Well Intervention Engineer 7580-7593', 7602-7624', 7646-7666' 6679-6689', 6696-6714', 6732-6748' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 171 bopd Gas-Mcf MD 1165 Size 78' 769 bwpd 9951702 mcf 151 bopd 143613 bwpd 142 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-061 50-029-21825-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025513 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3O-09 Plugs Junk measured Length Production Liner 7874' Casing 6943'7907' 4171' 78'Conductor Surface Intermediate 16" 9-5/8" 43' 4206' 4086' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:50 pm, Mar 12, 2024 Jill Simek Digitally signed by Jill Simek Date: 2024.03.12 11:56:42 -08'00' DSR-3/12/24 RBDMS JSB 031424 DTTMSTART JOBTYP SUMMARYOPS 12/23/2023 REPAIR WELL DRIFTED TUBING W/ 2'' x 10' DRIFT, TAGGED FILL 7640' RKB - EST 16' FILL, 60' OPEN PERFS... READY FOR E-LINE OR PLAN FORWARD. 2/8/2024 REPAIR WELL PERFORM DRIFT AND TAG WITH CCL AND GAMMA. TAGGED TD AT 7640'. TAG CORRELATED TO ORIGINAL CBL. GAMMA RAY VALUES TO HIGH TO USE FOR CORRELATION PURPOSES (LIKELY SCALE). GUN 1: PERFORATE INTERVAL WITH 1-11/16" STRIP GUN: 7614' - 7624' JOB IN PROGRESS 2/8/2024 MAINTAIN WELL FREEZE PROTECT TBG & FL FROM MANIFOLD 20 BBLS DSL FOR TBG FOLLOWED BY 5 BBLS METH FOR FLOWLINE 2/9/2024 REPAIR WELL JOB CONTINUED FROM 2/8/24 GUN 2 - PERFORATE INTERVAL: 7603' - 7613' GUN 3 - PERFORATE INTERVAL: 7581.5' - 7591.5'. ***FISH LEFT IN HOLE*** 9.5' OF STRIP GUN CARRIER (1.69" OD, 1/8" THICK) WAS LEFT DOWN HOLE AFTER FIRING GUN 3 (PICTURES IN ATTACHMENTS) JOB COMPLETE, NOTIFY DSO WELL IS READY TO BOL 3O-09 Perforations Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,640.0 3O-09 12/23/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Re-Perf & Fish LIH 3O-09 2/9/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL: IA x OA COMMUNICATION 11/29/1995 WV5.3 Conversio n NOTE: TUBING STRING: PREVIOUS COMPLETION Left in Hole Below 7346' 9/13/1992 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 35.0 78.0 78.0 62.58 H-40 Welded SURFACE 9 5/8 8.76 35.0 4,206.0 4,086.4 36.00 J-55 BTC PRODUCTION 7 6.28 33.0 7,906.9 6,942.9 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 7,431.5 Set Depth … 6,560.5 String Max No… 3 1/2 Tubing Description TUBING 3.5"x2.875" Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 33.0 33.0 0.06 HANGER 10.380 CIW GEN I TUBING HANGER CIW Gen I 3.500 1,821.5 1,821.5 0.29 SAFETY VLV 5.937 CAMCO TRDP-1A' SAFETY VALVE CAMCO TRDP- 1A 2.813 2,581.5 2,581.3 2.17 GAS LIFT 5.390 Camco, 3 1/2" x 1" KBUG, BK-5 latch, 5.390" OD, 2.867" ID Camco KBUG 2.867 4,462.9 4,286.9 39.25 GAS LIFT 5.390 Camco, 3 1/2" x 1" KBUG, BK-5 latch, 5.390" OD, 2.867" ID Camco KBUG 2.867 5,817.1 5,319.0 40.33 GAS LIFT 5.390 Camco, 3 1/2" x 1" KBUG, BK-5 latch, 5.390" OD, 2.867" ID Camco KBUG 2.867 6,575.9 5,897.6 40.47 GAS LIFT 5.390 Camco, 3 1/2" x 1" KBUG, BK-5 latch, 5.390" OD, 2.867" ID Camco KBUG 2.867 6,927.2 6,165.2 39.73 GAS LIFT 5.390 Camco, 3 1/2" x 1" KBUG, DV, BK-5 latch, 5.390" OD, 2.867" ID Camco KBUG 2.867 7,290.5 6,448.4 37.73 GAS LIFT 5.960 OTIS 3 1/2" x 1 1/2" LBX, 3/4" check, RM-1 latch, 5.960" OD, 2.867" ID OTIS LBX 2.867 7,341.1 6,488.6 37.44 XO-Reducing 3.500 CROSSOVER 3.5" x 2.875 2.875 7,342.0 6,489.3 37.44 PBR 4.750 AVA PBR STINGER 9' STROKE (2.18' LOCATOR) AVA 2.441 7,346.2 6,492.6 37.42 PBR 4.750 AVA HYD SHEAR PBR AVA 2.347 7,360.3 6,503.8 37.38 PACKER 6.151 AVA 'RHS' RETRIEVABLE PACKER AVA 2.347 7,397.1 6,533.1 37.25 NIPPLE 3.668 CAMCO D NIPPLE w/ 2.25" NO GO CAMCO D 2.250 7,431.1 6,560.1 37.21 SOS 3.750 AVA BALL SHEAT SHEAR OUT SUB (SHEARED); TTL ELMD 7423' SWS LOG 6/30/1988 AVA 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,630.5 6,719.2 36.81 FISH 9.5' STEEL STRIP GUN CARRIER, 1.69" OD, 1/8" THICK (PICTURES IN ATTACHMENTS) ***NOTE FISH LIKELY IN PROD CSG BUT COULD HAVE BEEN DRUG UP INTO TBG AFTER PERFORATING, FISH IS NON-MAGNETIC*** 2/9/2024 0.000 7,680.0 6,758.9 36.53 FISH 8 Slips & Seal Assy Lost 8 Slips & 80% of Seal Assy. f/ BTM PKR Assembly 1/23/1998 7,714.0 6,786.3 36.30 FISH Seal Element & 8 Slips Left in Hole from FISH Eclipse Pkr 6/5/1997 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,581.5 2,581.3 2.17 1 GAS LIFT GLV BK 1 1,261.0 10/29/2012 0.156 4,462.9 4,286.9 39.25 2 GAS LIFT GLV BK 1 1,272.0 10/29/2012 0.156 5,817.1 5,319.0 40.33 3 GAS LIFT GLV BK 1 1,310.0 10/29/2012 0.188 6,575.9 5,897.6 40.47 4 GAS LIFT OV BK 1 0.0 6/16/2020 0.188 6,927.2 6,165.2 39.73 5 GAS LIFT DMY BK-5 1 0.0 9/13/1992 0.000 7,290.5 6,448.4 37.73 6 GAS LIFT DMY RM-1 1 1/2 0.0 8/22/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,580.0 7,593.0 6,678.9 6,689.3 A-3, 3O-09 6/6/1989 12.0 APERF 60 deg. ph; 2 1/8" EnerJet 7,581.5 7,591.5 6,680.1 6,688.1 A-3, 3O-09 2/9/2024 6.0 RPERF 40 deg, ph; 1-11/16" OWENS STP HERO 7,602.0 7,624.0 6,696.5 6,714.0 A-2, 3O-09 6/6/1989 12.0 APERF 60 deg. ph; 2 1/8" EnerJet 7,603.0 7,613.0 6,697.3 6,705.2 A-2, 3O-09 2/9/2024 6.0 RPERF 40 deg, ph; 1-11/16" OWENS STP HERO 3O-09, 3/12/2024 7:57:29 AM Vertical schematic (actual) PRODUCTION; 33.0-7,906.9 FISH; 7,714.0 FISH; 7,680.0 IPERF; 7,646.0-7,666.0 FISH; 7,630.5 RPERF; 7,614.0-7,624.0 APERF; 7,602.0-7,624.0 RPERF; 7,603.0-7,613.0 APERF; 7,580.0-7,593.0 RPERF; 7,581.5-7,591.5 PACKER; 7,360.3 GAS LIFT; 7,290.5 GAS LIFT; 6,927.2 GAS LIFT; 6,575.9 GAS LIFT; 5,817.1 GAS LIFT; 4,462.9 SURFACE; 35.0-4,206.0 GAS LIFT; 2,581.5 SAFETY VLV; 1,821.5 CONDUCTOR; 35.0-78.0 KUP PROD KB-Grd (ft) 34.98 RR Date 7/2/1988 Other Elev… 3O-09 ... TD Act Btm (ftKB) 7,916.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292182500 Wellbore Status PROD Max Angle & MD Incl (°) 40.66 MD (ftKB) 5,500.00 WELLNAME WELLBORE3O-09 Annotation Last WO: End Date 9/13/1992 H2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,614.0 7,624.0 6,706.0 6,714.0 A-2, 3O-09 2/8/2024 6.0 RPERF 40 deg, ph; 1-11/16" OWENS STP HERO 7,646.0 7,666.0 6,731.7 6,747.7 A-1, 3O-09 9/20/1988 8.0 IPERF 45 deg. ph; 4.5" HDP Csg Gun 3O-09, 3/12/2024 7:57:29 AM Vertical schematic (actual) PRODUCTION; 33.0-7,906.9 FISH; 7,714.0 FISH; 7,680.0 IPERF; 7,646.0-7,666.0 FISH; 7,630.5 RPERF; 7,614.0-7,624.0 APERF; 7,602.0-7,624.0 RPERF; 7,603.0-7,613.0 APERF; 7,580.0-7,593.0 RPERF; 7,581.5-7,591.5 PACKER; 7,360.3 GAS LIFT; 7,290.5 GAS LIFT; 6,927.2 GAS LIFT; 6,575.9 GAS LIFT; 5,817.1 GAS LIFT; 4,462.9 SURFACE; 35.0-4,206.0 GAS LIFT; 2,581.5 SAFETY VLV; 1,821.5 CONDUCTOR; 35.0-78.0 KUP PROD 3O-09 ... WELLNAME WELLBORE3O-09 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 during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization Ior items: Grayscale items: Poor Quality Originals: Other: DIGITAL DATA [3 Diskettes, No. Other, No/Type TOTAL PAGES: ~'~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) n Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) [3 Logs of various kinds Other ISl Project Proofing [-3 Staff Proof By. Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI ga! the timee[ SCANNEE) BYi BEVERLY BR~ SHERYL MARIA LOWELL · ISI~ RESCANI'JED BY~ BEVERLY BRE SHERYL M~-RIA LOWELL DATE ' Is! General Notes or Comments about this file: Quality Checked ConocoPhillips aa~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: :~ ~ AFB `~ ~.r ~REC~IVED APR 0 =5 '2010 caQil&~cons.~m~ ~~- p ~ ~ ~o~ °~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, trop 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, MJ L veland 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 3/31/10 3e 3Ft ~r ~r_ ZI-r zr z_r znn zn n ~o oen~~ Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surface Na 26" Na 4.25 3/29/2010 3A-04 50029214330000 1852070 SF Na 26" n/a 4.25 3/29/2010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3/29/2010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3!29/2010 3B-10 50029213660000 1851140 6'6" n/a 6'6" Na 25.5 3/28/2010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/27!2010 3G-08 50103201280000 1900650 SF 0.65 27" 3/2!10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 3/2/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF Na 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF Na 21" Na 4.25 3/28/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/28/2010 3H-146 50103200920200 2050210 SF n/a 23" Na 3.4 3/29/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/29/2010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/29/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/28/2010 3J-15 50029214970000 1852890 SF Na 22" Na 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3!29/2010 30-09 50029218250000 1880610 SF Na 23" Na 4.25 3/27!2010 30-16A 50029217960100 1880430 SF Na 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/27/2010 MEMORANDUM TO: Julie Heusser, Commissioner THRU: State of Alaska Tom Maunder, P. I. Supervisor Alaska Oil and Gas Conservation Commission DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 26, 2001 Safety Valve Tests Kuparuk River Unit 30 Pad Friday, January 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. Earnie 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 welihouse inspections Attachment: SVS KRU 30 Pad 1-26-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ,phil~'lpS Operator Rep: Eamic Barndt AOGCC Rep: ChuCk Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Kuparuk / 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, Numbe,r Number , PSI . psI Trip Code Code Code , ,p, assed ,,G,,As or CYCLr 30-01 1880730 67 70 80 P P OIL 30-02 '' 1880740 67 '70 60 P P ...... 0iL 30-03 18~0750 '' 67 '70 60! '"P 1~ .............. OIL 30-04 1880620 67 70 · 65! P P OIL! 30-06 1880600 30-08 ' 1880~'0 67 "' 70 ' ~0 P .... P ..... 0i'L 30-09 ' '1880ii10" 67 70 40' P P OIL 30-11" 1850420:'' 67 '' 70 ....(~0t' P' ~ P ........ OIL 30-i3' "1880400' ' '~7 70 -60' ' P P......... OIL 30-14 1880390 30-i5 1'880310 ' ' 67 .... 70 · '70 P ' ~' ' .... OIL 30-18' 1880260 6~t" 70 55 "-P' P .......... OIL 30'-20 ' 19704~0 671 .... 70 '60 P ...... P ' ' ' OIL 30-05 1880760 3550 ' 2000" 1i'00 5' P ...... 1/26/01 ...... wAG Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% Elg0 Day Remarks: pilot On WAG .injector 30-05.tripped ~l.o.w req,uired set pr, essure, pilot was r,ete,,,sted .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 I -- 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 Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface: 8. Well number: 897' FNL, 1941' FWL, Sec 27, T13N, RgE, UM 30-09 At top of productive interval: 9. Permit number/approval number: 1270' FNL, 797' FEL, Sec 22, T13N, R9E, UM 88-61 At effective depth: 10. APl number: 1284' FNL, 587' FEL, Sec 22, T13N, R9E, UM 50-029-21825-00 At total depth: 11. Field/Pool: 1288' FNL, 534' FEL, Sec 22, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7916 feet Plugs (measured) None true vertical 6950 feet Effective Deptt measured 7824 feet Junk (measured) None true vertical 6876 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 164 Sx AS II 110' 110' Surface 4171' 9-5/8" . 1500 Sx AS Ill & 4206' 4086' 325 Sx Class G 80 Sx AS I Top Job Production 7872' 7" 300 Sx Class G & 7907' 6943' 175 Sx AS I & 100 Sx 50/50 FLYASH Liner Perforation Depth measured 7580'-7593';7602'-7624';7646'-7666' true vertical 6679'-6689';6696'-6714';6732'-6748' Tubing (size, grode, ond measured depth) 3.5", 9.3 Ib/ft, J-55 @ 7344' & 2.875", 6.5 Ib/ft, J-55 @ 7344'-7431' · : Packers and SSSV (type and measured depth) Packer: AVA RHS @ 7360'; SSSV: Camco TRDP-1A @ 1821' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/4/98. Intervals treated (measured) 7580'-7593 '; 7602 '-7624' Treatment description including volumes used and final pressure Pumped 188,200 lbs of 16/20 & 12/18 ceramic proppant into formation, fp was 7263 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 888 974 257 972 197 Subsequent to operation 1054 1037 298 768 185 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: Production Engineering Supervisor Date c^.~ ~n AhA n^,,lrlZ~"~ ~Q~ RIIRMIT IN DUPLICAT~ Form 1 .,-~CO Alaska, Inc. -KUPARUK RIVER UNIT ~._-'LL SERVICE REPORT 30-09(4-1)) WELL JOB SCOPE JOB NUMBER 30-09 FRAC, FRAC SUPPORT 0528981615.8 UNIT NUMBER DATE 06/04/98 DAY 3 FIELD ESTIMATE DALLY WORK A SAND REFRAC OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ('~ Yes 0 No ('~ Yes 0 No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2336 230DS36OL $130,172 $149,489 InitiaITbg I Fina, Tbg I,nitia,,A I Fina,,A I Initia, OA I Fina, OA ITTLSize 875PSlI 200PSII 500PSII 500PSII 800PSII 900PSII 0.000 " SUPERVISOR JORDAN Signed JMin ID 0.000" Depth OFT DALLY SUMMARY A SAND REFRAC SCREENED OUT WITH 10 PPA AT PERFS. MAX TREATING PRESSURE 7263 PSI WITH 187,000 LBS PROPPANT PLACED IN FORMATION; 16,644 LBS PROPPANT LEFT IN PIPE. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - YOAKUM; APC; LRS. TGSM, 15 ON LOCATION. PT EQUIP TO 8000 PSI. 09:13 PUMP BREAKDOWN, SCOUR, AND CONDITION STAGES ACCORDING TO PROCEDURE. 09:33 FLUSH AND STEPDOWN TEST. SHUTDOWN. ISIP 1511 PSI. 10:26 PUMP DATAFRAC AND FLUSH.. SHUTDOWN. ISIP 1511 PSI. 11:40 PUMP FRAC PROCEDURE THROUGH 10 PPA PER PROCEDURE AT 15 BPM. BEGIN PRESSURING UP AT RAMP 12 PPA. CUT GEL TO 40 #, CUT RATE TO 13 BPM. 13:18 SCREEN OUT AT 10.1 PPA PROPPANT CONCENTRATION WITH 10 PPA ON PERFS, SHUTDOWN. MAX PRESSU 7263 PSI. TOTAL PROPPANT PUMPED 203,644 LBS, 187,000 LBS IN FORMATION AND 16,644 LBS 12/18 LEFT IN PIPE. 17:00 RDMO DS FRAC UNIT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $3,217.00 APC $5,000.00 $7,400.00 DIESEL $0.00 $150.00 DOWELL $121,972.00 $128,399.52 HALLI BURTON $0.00 $2,568.00 LITTLE RED $3,200.00 $7,755.00 TOTAL FIELD ESTIMATE $130,172.00 $149,489.52 STATE OFALASKA 0 fl I 6 IN A L AI.A,SKA OIL AND GAS CONSERVATION COMMI~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter c~_sing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ~RCO Alaska. Inc. ). Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 897' FNL, 1941' FWL, SEC 27, T13N, RgE, UM At top of productive interval 1270' FNL, 797' FEL, SEC 22, T13N, R93, UM At effective depth 1284' FNL, 587' FEL, SEC 22, T13N, R9E, UM At total depth 1288' FNL~ 534' FEL~ SEC 22~ T13N~ R9E, UM 12. Present well condition summary Total Depth: measured 7 91 6' feet true vertical 6950' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 59' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-O9 9. Permit number/approval number 88-61 10, APl number 50-029-2182500 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 8 2 4' feet true vertical 6876' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 1 6" 41 71 ' 9-5/8" 7872' 7" measured 7581 '-7594', true vertical 6680'-6690', 7602'-7624', 6697'-6714', Cemented 164 SX AS II 1500 SX AS III, & 325 SX CLASS G 80 SX AS I TOP JOB 300 SX CLASS G, 175 SX AS I 100 SX 50/50 FLYASH 7646'-7666' Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55 MOD @ 7432' Packers and SSSV (type and measured depth) AVA 'RHS' RET @ 7361', CAMCO TRDP-1A @ 1821' 13. Stimulation or cement squeeze summary 'A' SAND FRACTURE TREATMENT Intervals treated (measured) 7581'-7594', 7602'-7624', 7646'-7666' Treatment description including volumes used and final pressure SF_I:: ATTACHED WEII SERVICE REPORT SUMMARY 6732'-6748' Measured depth 110' 4206' True vertical depth 110' 4086' 7907' 6943' R'EEEIV£D DEC 1 6 1992 A_ la$~ Oil & Gas Cons. Commiss'to[) NIchorage 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1214 151 0 350 1 61 0 0 0 0 0 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Title Petroleum Engineer Form 10-404 Rev 09/12/90 Date 12'//I/ SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 11/20/92 TO 11120192 CPF-3 DS-30 30-09 11/20/92 A SAND REFRAC W/ DS USING YF14OD. PUMPED 200 BBL BD STAGE, SHUT DOWN FOR ISIP. DATA TRANSFER STOPPED 3.5 MIN INTO SHUTDOWN. CLOSURE PRESSURE, FLUID EFF. WAS NOT CALCULATED, (WORST CASE FLUID EFF. OF 20% - SMART COMPUTER). PUMPED 75 BBL BD STAGE, SHUT DOWN FOR ISIP. FALLOFF PRESSURE SPIKED 4 MIN INTO SHUTDOWN, CLOSURE PRESSURE, FLUID EFF. WAS NOT CALCULATED, (WORST CASE FLUID EFF. OF 40% - SMART COMPUTER). PUMPED 100 BBL PAD, FOLLOWED BY 476 BBLS OF 16/20 & 12/18 SLURRY IN 2-10 PPA STAGES. TREATING PRESSURES BEGAN TO SPIKE 66 BBLS INTO 10 PPA STAGE, WENT TO FLUSH EARLY. WELL SCREENED OUT 5 BBLS INTO DSL FLUSH. TOT PROP IN FORM: 7.6 MLBS OF 16/20 & 79.2 MLBS OF 12/18 W/ 10.1 PPA @ PERFS. TOT DESIGN: 268.7 MLBS. EFF PAD/SLURRY OF 21%. TOT PROP IN WELLBORE 14.7 MLBS (12/18). TOT FLUIDS: WATER = 851 BBL, DLS = 18 BBLS & OTHER ADDITIVES = 56 BBLS. ALL FLUIDS LOOKED GOOD. (HOLLINGSWORTH/GOLDEN) STATE OF ALASKA 0 /U_~K~ OIL ~D G~ CONSERVATION COMMI,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing x Alter casing Stimulate __ Plugging w Perforate Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 897' FNL, 1941' FWL, SEC 27, T13N, RgE, UM At top of productive interval 1270' FNL, 797' FEL, SEC 22 , T13N, RgE, UM At effective depth 1284' FNL, 587' FEL, SEC 22, T13N, RgE, UM At total depth 1288' FNL, 534' FEL, SEC 22, T13N, RgE, UM 12. Present well condition summary Total Depth: measured 791 6' true vertical 6950' 5. Type of Well: Development Exploratory Stratigraphic Service feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 59'. PAD 24' Gl 7. Unit or Property name Kuparuk River Unit 8. Well number 30-09 9. Permit number/approval number 88-61 (Conserv Order 10. APl number 50-029-21825 11. Field/Pool Kuparuk River Oil Pool No. 261.)___ Effective depth: measured 7824' true vertical 6876' Casing Length Size Structural 8 0' I 6 ' Conductor Surface 4171 ' 9 - 5 / 8 ' Intermediate Production 7872' 7 ' feet feet Junk (measured) Cemented 164 SX AS II Measured depth 110' ' 1500 SX as III & 325 SX CLASS G, 80 SXAS I TOP JOB 250 SX CLASS G 175 SX AS I 100 SX 50/50 FLYLASH True vertical depth 110' ' 4206' 4086' 7907' 6943' 13. Liner Perforation depth: measured 7646'-7666', 7602'-7624', 7581'-7594'M D true vertical 6731'-6747', 6696'-6713', 6679'-6689'TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 7432' Packers and SSSV (type and measured depth) AVA RHS RETRV PKR @ 7360'r CAMCO TRDP-1A SSSV @ 1821' MD Stimulation or cement squeeze summary RECEIVED NOV - 1992 Alaska Oil & Gas Cons. ~;ommiSS~m~ ~nch0rage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Tubing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ 'ogrnme dl0.4~R e~v -~-05/1/7/8~~ Title Area Drilling Engineer SUBMIT IN/OLIPL4C~.TE ARCo ALASKA INC. WELL: BORouGH: 30-09 UNIT: NORTH SLOPE FIELD. KUPARUK RIVE API: DAILy OPERATIoNs~" A CCEp T: PAGE: 09/09/92 TD: 7916 PB: 7824 09/10/92 (2) TD: 7916 PB: 7824 09/11/92 ( 3) TD: 7916 PB: 7824 09/12/92 TD: 7916 PB: 7824 50-029-21825 SPUD 09/09/92 11:09 APPROVAL. 88..61 ' RELEASE..' 09/14/92 04 OPERATION. MOVING RIG F/2Z PAD T/30 MVE RIG F/2Z PAD TO 30 PAD. ~:12'3 Nac1/Br ~U LANDING j ONT T~ . 09/09/~2~E RIG TO ~ - HA~ L_~' MU HA~ j u PAD A DISpT.n~E & KILL .._LINE. 'pr,,tUEPT RIG ~ ['~:10.6 N LA~, .... REp~. T~LL TEST ~rr,; NU BOp~ ~EZE p~ PROD ~ rEST ~u BY PLUG. MU LOAD PS W/3- ,, MU LAND~,~ 1/2 SLIpS ~ JT .... .PG. RU ~.- MBERGER .... ~CHLuMsER~r~_HUNG g '~ ,~C1/Br CIRC/o~,_t~ 4 J~o '~' FIND ~" ~RINE r~, ~ CUTTER' TBG e~?WLACE Wmr~' WELL o~~ STRIN~ ~? wITS Tm ~i W/Up u ABOV "' RU ' ~TILL "~ PER COM~- E COLLApe~SCHLuMBED~_ HUNG UP Y- PULL 2 .~ ~ ~ss~. ~~ s~. ~'~. cu~ ~I.s~ rSG & ,~ .... 'u~gRGER ~_°~ AT ~ ~LRy ' ~OOH RIH W/ 4 3/4,, DC S AND LOAD pipe SH ' SUSHIN~ ED W~ ~ ~ 3 1/2,, ~ s~Ctf,· ~A~cj'2.. o/s ~ss~ '~ s~ ~:~o ~- m~_ ~ED Gr,. -o14" B/~ ' dAR F~.. ~ W/5 ~/~,, ~LLING ,.~'~' 1 JT o ~o & JAR.q jo~ FREE -i~ ASSy ~UB ~..~NE R~ ~3//8'' TBa ~f RECovE~ 2_ POOH W '- ' ~an ' ~-o~T ~, ~ p "rHG ~FISH W/4-3/4" Do,~WEAR BUS~,,~BR STINGmo CUT-OFF. ~-~/~', O~,s.'''~ usso ~L~ RECEIVED Alaska Oil & Ga; Co~s. Corr~mission Anchorag~ WELL : 30-09 OPERATION: RIG : NORDIC 1 PAGE: 2 09/13/92 ( 5) TD: 7916 PB: 7824 RIH W/3-1/2 TBG COM ASSY MW:10.5 NaC1/Br RIG SERVICE. FUNCTION TEST BOPE. CONT RIH W/ 4-3/4" DC'S & 3-1/2" DP'S. WELL FLOW THROUGH DP. WEIGHT UP BRINE TO 10.3 PPG. CIRC. POOH, LD 3-1/2" DP'S. MONITOR WELL. WELL FLOW THROUGH DP AFTER LD 138 JTS DP. SHUT IN WELL. CIRC AROUND 10.5 PPG BRINE THROUGH CHOKE. MONITOR WELL. WEIGHT UP 10.5 PPG BRINE IN PITS. CONT LD 3-1/2" DP'S & 4-3/4" DC'S. PULL WEAR BUSHING. REMOVE DP'S & DC'S F/PIPE SHED. CLOSE BLIND RAMS. LOAD 3-1/2" TBG & JEWELRY TO PIPE SHED. TALLY. OPEN.BLIND RAMS. FILL UP HOLE W/4 BBLS BRINE. MONITOR WELL. MU PBR STINGER, X/O, 1 JT 3-1/2" TBG & OTIS GLM 3-1/2" X 1-1/2" WITH PUP JTS IN BOTH ENDS. CONT RIH W/3-1/2 "COMPL ASSY. 09/14/92 ( 6) TD: 7916 PB: 7824 RELEASE RIG MW:ll.0 NaCl/Br CONT RIH W/3-1/2" COMPL ASSY. MU CAMCO TRDP-1A-SSSV. TEST CONTROL LINE TO 5000 PSI. FIN RIH W/COMPL ASSY. BAND C/L EVERY OTHER JT. STING INTO PBR. SPACE OUT. MU TBG HBR & CONTROL LINE FITTING. TEST SAME TO 5000 PSI. LAND TBG HGR. RILDS. RU OTIS SLICKLINE. TEST LUB TO 1500 PSI. SET CRX PLUG IN D NIPPLE. TEST TO 600 PSI. LD LUB. PRESS ANN/TBG TO 1500 PSI. BLEED OFF C/L PRESS TO CLOSE SSSV. BLEED OFF TBG PRESS TO TEST SSSV. PRESS TEST ANN/TBG TO 2500 PSI. HOLD ANN PRESS, PRESS TBG TO 3500 PSI TO TEST PBR SEALS. BLEED OFF PRESS. CLOSE SSSV. SET BPV. ND BOPE. NU TREE. REPLACE BPV W/TEST PLUG. TEST TREE TO 250 & 5000 PSI. PULL TEST PLUG. DISPLACE ANN W/ 11.O PPG BRINE, TAKE RETURNS THROUGH CHOKE. RU OTIS LUB. TEST TO 1000 PSI. PULL CIRC VALVE F/ 1-1/2" GLM. SET DUMMY VALVE AT SAME. PRESS UP TBG TO 1000 PSI TO TEST DUMMY VALVE. PULL CRX PLUG F/D NIPPLE. BULLHEAD 17 BBLS DIESEL DN TBG. SHUT IN WELL. RIG RELEASED @ 0400 HRS 09/14/92. PREPARE RIG FOR MVE TO 3A PAD. SIGNATURE: ) (dr~ ~ li~n uperinte~ent DATE: MEMORAN JUM Sta e of Alaska ALASI~ OIL AND CdiS LI)NSERVATION CO~IMISSION TO: Leigh A Gr£Tfin ~-~' Commissioner DATE: Octol. e~- 12, 1992 FILE NO: LOUgl0-I. · doc THRU: Blair E Wondzet~/t( Sr Petr Engineer FROM: ~ou Grimaldi Petr Inspector TELEPHONE NO: SUBJECT: BOP Test Nordic ~)1 (659-7565) ARCO 30-9 Kuparuk Rv U Permit. ~)88-61 ~' !~, %992: I witnessed a BOP test: cat Nordi. c Rig ~.)1 whtch was preparing to work over ARCO's ~ell ~f30-9 in the Kuparuk River UuiL, The test. we~'tt well with one failure noted, that being the inside wt.l. ve on vent line, The valve could not be closed and eventually st:~:ipped in the open position. This was a redundant valve as it. had two valves downst:~eam o[ il. As this was the only fa. itu~'e, I allowed the rig to continue u, ith the they could repair the val. ve during their next rig move, I I:i~t.d that the Nordic: crew performs a good test. of all. BOP equipme~t up and inclmling the mw3 manifold. The test pressure, once applied, is hehl a minimmn of five minutes and usually longer. The area surrounding the rig is kept clean and orderly with easy ;.icces:¢ allowed to the rest. o~ the pad. ~) 1 In stmmmry'~ I witnessed the initial. BOP test on Nordic Rig with one ,::l~oke. valve failure. NOTE: Paul Haynes called on 9/i3/92 to repc)rt the failed valve k-as being repaired. A t tachment s 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report DATE TEST~ Intttal , , ~1, csg set ~ ~07 ft Location (general) J , y Weekly , . Other Rig phone # '~~ .~'-- Location: Sec ~u~-: T/3~, ,' R ?Z~ M ,0~ We11 sign ACCUMULATOR SYSTEM: Full charge pressure pstg Housekeeping (general)~ Rsrve pit, MUD SYSTEHS: Trip tank Pit gauge Flow monitor Gas detectors ! Audio Rtg. J BOPE STACK: Test Pressure Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Press after closul:e Pump incr clos press 200 psig Full charge press attained Controls: Master (~/~ pstg mtn '~' sec · mtn /~) sec pstg Remote )/~F B1 tnd swttch cover.~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure Lower Kelly ~2_ Test pressure ~"~'~0 Ball type ~ Test pressure ~.~Cx~8 Inside BOP / Test pressure .~'00(~ Choke manifold F Test pressure ~00 Number valves /~ Number,flanges ~ Adjustable chokes ~- Hydraulically operated choke , / TEST RESULTS: Failures /., Test time D~_ hrs Repair or replacement of failed equipment to be made within days. Notify the Inspector; fnd follow with written/FAXed [276-7542] verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.OOq (rev 07/92) STATE WITN~ REQUIRED? yes ~ no 24-HR NOTICE GIVEN? yes~/~ no m Waived by: AOGCC phone 279-1433 - FAX 276-7542 ,. // STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETIO# REPORT A#D LO 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~J ABANDONED ~ SERVICE [] 2. Name of Operator 7. Pern~i~_N~cber ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 029-21825 4. Location of well at surface 9. Unit or Lease Name 897' FNL, 1941' FWL, 5ec.22, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1270' FNL, 797' FEL, Sec.22, T13N, R9E, UM 30-9 At Total Depth 11. Field and Pool 1288' FNL, 534' FEL, Sec.22, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59'I ADL 25513 ALK 2554 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 06/24/88 07/01/88 1 2/05/88*J N/A feet MSLJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J 20. Depth where SSSV set J 21. Thickness of Permafrost 7916'MD/6950'TVD 7825'MD/6876'TVD YES ~ NO []J 1827' feet MDJ 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL. FDC/CNL, CAL.GR.CET. Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE !TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf !!0' 2~.'' !6 9-5/8" 36.0# ~-~ Surf ~.206' !2-!/~.'' !500 sx AS Tep jeb w/BO sx AS 7" 26.0# !-~ Surf 7907' 8-!/2" 250 175 sx AS 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7432 ' 7361 ' Perforated w/8 spf, 45° phasing 7646 ' -7666 'MD/6731 ' -6747 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addendum, dated 1-24-89 for fracture data. ,,, 27. M/~ PRODUCTION TEST Date F[~t' ~roduction J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. COP E DATA .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · · ., , NOTE: Drilled RR 7/3/88, Perforated well and ran tubing 9/22/88. Fractured wel 1 12/5/88 ~.L; ~i:~ ~=~;~ .... ;'.'~ '. ' Form 10-407 Rev. 7-1-80 100/WC5 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS ....... NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7472' 6592' N/A Base Kuparuk C 7528' 6637' Top Kuparuk A 7568' 6669' Base Kuparuk A 7709' 6782' 31. LIST OF ATTACHMENTS Addendum (dated 7-7-88 & 1-24-89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed P -~' ~ Title Area Drilling Engr Date .~ /[;,/ ¢ ,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool, Item 27: Method of Operation: Flowing, Gas Lift., Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If'no cores taken, indicate "none". Form 10-407 ADDENDUM WELL' 3-0-9 7/6/88 Rn CET 5500'-7830' Rn Gyro. Dri l~f~ S-upe i~so r ADDENDUM WELL: 9/21/88 12/4/88 12/5/88 30-9 RU Schl to perf well. Attempt to frac Kuparuk "A" sand perfs 7646'-7666' w/o success. (Tree saver failed). Frac Kuparuk "A" sand perfs 7646'-7666' in five stages per procedure dated 11/17/88 as follows: Pmp 100 bbls gelled diesel pre-pad @ 20 BPM, 5500-4800 psi Pmp 700 bbls gelled diesel pad @ 20 BPM, 4715 psi Stage 1: 48 bbls gelled diesel, 2 ppg 16/20 @ 20 BPM, 4715 psi Stage 2: 65 bbls gelled diesel, 4 ppg 16/20 @ 20 BPM, 4515-4750 psi Stage 3: 90 bbls gelled diesel, 6 ppg 16/20 @ 20 BPM, 4750-5285 psi Stage 4: 95 bbls gelled diesel, 8 ppg 16/20 @ 20 B?M, 5285-5875 psi Stage 5: 75 bbls gelled diesel, 10 ppg 16/20 @ 20-18 BPM, 5875-6133-5980 psi Flush w/49 bbls gelled diesel @ 18 BPM, 5980-5190 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1688 bbls 77,069# 3O8# 5200 psi J~rilling Supervisor ' Bate APR-!8-~90 10:28 I D: KRU,'C I/NU/DR ILL I NG .[. ~ . --- - iill ! I el ALL WELLS LOCATED IN ~:C. 22 *r, !3 N., R. 9 E,, UMIAT MERIDIAN. TEL N0:907-265-6218 ,- VtClI~TY MAP NOTES t. AIL COORDINATES ARE A,$.P., ZONE 4. ~, ALL DISTANCES SHOWN ARE TRUE. 3, ELEVATIONS ,tdqE 4. REFER. FIELD I)OOK 3. O,G, ELEVATIONS FROM CED-RIXX-$365& t~, HORIZONTAL POSITION BASED ON ~ CON~L MONUMENTS ~ kOU~IURY ....................... mST.mST. - Well y ASPs X LATITUDE LONGITUDE FNL. .F. W~L ~i~v. PAD ~1 6,02 2:,095,27 525,478. Z7 ?I:P ~8' 17,359" 1490 47' $0,897'' 724* 1,4~:' 6,022,075.89 525,490.94 70028' 17,129" 149047 '$0.5~6" 745' 1~55' 17.7~ 76~ 1867' 17.9 217 ~ 6,022,052. 13 525,~5,67 ~* 16.913" t49°47'~0, 6,02E,030,~ 5~5~515.58 ~28~ I~1 ~ a ' 1~2~. 7 6~021 ~965,~ 5~S,5~3.~ [~9 14~47 28.6~. e~ 1~17, 18.~, 2~1 149 47,~,~. t8.3, 6,021 ~92~, 12 5~ ,578,27 * 15.632' 1490 47 27.974 89T 1941 18.4 23,2 I0 6~021,84~ ~ 525,623,61 ~28' 14,~3" 149=47'26.6~'' 975' 1986' Il 6,0~1 ~822,~ 525 ~635,7t ~' 14.651" 149° 47'Z6,295' ~7' 1998'* 18.8' 23.5' 15 6,02~735. 76 $~5 ~G. IE ~' IS.~5 149°47 24.8~ 10~4 ~048, 19.0, ~2.~, 16 6,021~?14. 15 525,6~. 17 ~28' 13.~3" 149047'~4,4~: tl~ 20~, 19.1 17 6,0~1,69~ 5g5,710.85 ~' 13.36~" 149°47'Z4.0~ I t2~ 2073 19.0' 18 6~02 1,670.97 525,725,~ ~28' 13. 157" 149°47'23,733" 1149' 2~5' 19.0' 23.3' . · ,--, J i , , ........... - SUB-SURFACE DIRECTIONAL SURVEY F~UIDANCE I~ONTINUOUS r-flooL Company ARCO ALASKA, INC. Well Name 30-9(897' FNL, 1941' FWL, SEC 22, T13N, R9E,UM) Field/Location KUPARUKa NORTH SLOPE~ ALASKA Job Reference No. Date 72976 6-JUL-88 ~ Computed By: PEPPEL KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTTN~S FOR ARCO ALASKAt INC. 3 0-9 KUP~RUK NORTH SLOPE,ALASKA SURVEY D&TE: 06-JULY-88 ENGINEER: PEPPEL METHODS OF COMPUTATION TgOL LOC~TION: TANGENTI.~L- AVERAGED DEVIATION AND AZIMUTH INTERPPLaTION: LINEAR VERTICAL SECTION: HORIZ. gIST. PROJECTED ONTO ~ TARGET AZIMUTH OF SOUTH 80 DEG 34 MIN EAST ARCO ALASKA, INC. 3 0-9 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 23-0CT-88 DATE OF SURVEY: KELLY BUSHING ELEVATION: PAGE ' ~ ' 06-JULY-88 59.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ, DEmARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET OEG/IO0 PEET FEET FEET DEG MIN 0.00 0.00 -59.00 0 0 N 0 0 E 100.00 100.00 41.00 0 10 S 35 36 W 200.00 200.00 141.00 0 2 N 56 17 W 300.00 300.00 241.00 0 9 S 58 25 W 400.00 400.00 341.00 0 10 S 13 25 W 500.00 500.00 441.00 0 3 N 25 52 E 600.00 600.00 541.00 0 9 S 81 22 W '700.00 700.00 641.00 0 10 S 18 2 E 800.00 8OO.Og 741.00 0 16 S 52 58 E 900.00 899.99 840.99 0 31 S 55 47 E 0.00 0.00 0.00 N 0.00 E -0.08 0.23 0.05 S 0.09 W -0.07 0.17 0.22 S 0.11 W -0.23 0.12 0.25 S 0.27 W -0.37 0,21 0,51 S 0,46 W -0,28 0,55 0,66 S 0,39 W -0,44 0,44 0,53 S 0,54 W -0.53 0.22 0.73 S 0.66 W -0.17 0.19 0.99 S 0.34 W 0.44 0.38 1.313 S 0.22 E 0.00 N 0 0 E 0.12 S 49 26 W O. 24 S 26 6 W 0.37 S 47 22 W 0.69 S 42 22 W 0.77 S 30 58 W 0.76 S 45 19 W 0.98 S 42 10 W 1.04 S 18 50 W - 1.40 S 9 Z E 1000.00 999.99 940.99 0 22 S 79 7 E 1100.00 1099.99 1040.99 0 31 S TB 34 E 1200.00 1199.98 1140.98 0 33 S 63 38 E 1300.00 1299.98 1240.98 0 29 S 84 19 E 1400.00 1399.97 1340.97 0 40 S 67 14 E 1500.00 1499.97 1440.97 0 29 S 84 34 E 1600.00 1599.97 1540.97 0 24 S 82 32 E 1700.00 1699.96 1640.96 0 24 S 78 22 E 1800.00 1799.96 1740.96 0 15 S 5~ 49 E 1900.00 1899.96 1840.96 0 23 S 58 4 E 1.25 0.20 1.62 S 1.00 E 2.07 0.40 2.02 S 1.7'6 E 2.88 0.92 2.15 S 2.56 E 3.88 0.27 2.46 S 3.52 E 4.75 0.31 2.64 S 4.37 E 5.76 0.13 2.82 S 5.37 E 6.53 0.36 2.91 S 6.14 E 7.25 0.28 3.12 S 6.83 E 7.76 0.04 3.30 S 7.32 E 8.35 0.75 3.66 S 7.85 E 1.90 S 31 33 E 2.68 S 41 4 E 3.34 S 49 58 E 4.29 S 55 7 E 5.11 S 58 49 E 6.06 S 62 18 E 6.79 S 64 39 E 7.51 S 65 26 E 8.03 S 65 42 E 8.67 S 65 0 E 2000.00 1999.96 2100.00 Z099.95 2200.00 2199.94 2300.00 Z299.93 2400.00 2399.92 2500.00 2499.88 2600.00 2599.82 2700.00 2699.72 2800.00 2799.55 2900.00 2899.20 1940.96 0 36 S 32 0 E 2040.95 0 32 S 27 41 E 2140.94 0 49 S 17 35 E 2240,93 0 50. S 19 52 E 2340.92 1 20 S 13 44 E 2440.88 1 38 S 17 44 E 2540.82 2 17 $ 17 52 E 2640,72 2 57 S 16 .~ E 2740.55 3 46 S 17 44 E 2840,20 5 55 S 25 8 E 8.88 0.39 4.18 S 8.31 E 9.64 0.20 5.06 S B.93 E 10.23 0.23 6.09 S 9.36 E 10.96 0.09 7.45 S 9.87 E 11.73 0.78 9.09 S 10.38 E 12.84 1.11 11.69 S 11.07 E 14.37 0.88 14.95 S 12.08 E 16.44 0.41 19.37 S 13.44 E 18.91 1.55 24.89 S 15.04 E 23.25 3.15 32.55 S 18.16 E 9.30 S 63 17 E 10.26 S 60 28 E 11.17 S 56 58 E 12.36 S 52 58 E 13.80 S 48 46 E 16.10 S 43 27 E 19,22 S 38 57 E 23.58 S 34 45 E 29.08 S 31 8 E 37.28 S 29 9 E 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 3835.55 2998.33 2939.33 9 8 3096.46 3037.46 12 52 3193.19 3134.19 16 9 3288.63 3229.63 lB lO 3383.45 3324.46 18 41 3477.61 3418.61 21 B 3569.88 3510.88 24 3 3660.22 3601.22 26 35 3748.75 3589.76 28 46 3776.55 30 46 S 28 11 E S 30 35 E S 36 24 E S 43 56 E S 50 58 E S 55 0 E S 60 32 E S 67 32 E S 73 20 5 S 77 43 E 31.02 3.64 44.18 S 24.11 E 43.03 3.86 60.86 S 33.51 E 60.12 3.57 82.01 S 47.32 E 82.91 2.32 104.66 S 66.66 E 109.42 2.38 126.21 S 89.96 E 139.30 3.64 146.32 S 116.91 E 174.79 3.74 166.87 S 149.47 E 215.79 3.96 185.72 S 187.90 E 261.57 3.06 200.98 S 231.77 E 311.04 2.84 50.33 S 28 37 E 69.48 S 28 50 E 94.69 S 29 58 E 124.09 S 32 29 E 154.99 S 35 ZB E 187.29 S 38 37 E 224.02 S 41 51 E 264.20 S 45 20 E 306.77 S 49 4 E 213.20 S 279.89 E 351.84 S 52 42 E ~RCO ALASKA 3 0-9 KUPARUK NORTH SLOPE,ALASK~ TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION aZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN COMPUTATION D~TE: 23-0CT-88 PAGE ' 2 DATE OF SURVEY: 06-JULY'8,8 KELLY BUSHING ELEVATION: 59.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET O~ MEASURED DEPTH VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DE,G/lO0 4000.00 3920.29 3861.29 33 37 4100.00 ¢002.00 3943.00 36 40 4200.00 4081.18 4022.18 38 4300.00 4159.67 4100.67 38 34 4400.00 4237.62 417~.62 39 0 4500.00 4315.09 4256.09 39 23 4600.00 4392.13 4333.13 39 49 4'?00. O0 4458.75 440q. 75 40 8 4800.00 4545.03 4486.03 40 23 4900.00 4621,.1~ 4562.15 40 23 S 79 43 E 364.07 3.38 S 80 40 E 421.70 2.73 S ~34 40 E 482.71 2.97 S 86 20 E 544.38 0.47 S ~6 20 E 606.70 0.41 S 85 17 E 669.63 0.31 S 86 19 :. 733.05 0.40 S ~6 34 E 795.99 0.42 S ,~6 49 E 861.27 0.25 S ~6 37 E 925.75 0.17 5000.00 4697.2~ 4638.2,9 40 30 5100.00 4773.19 4714.19 40 34 5200.00 4849.27 4790.27 40 26 5300.00 4925.30 4866.30 40 34 5400.00 5001.25 4942.25 40 32 5500.00 5077.18 5018.18 40 39 5600.00 5153.11 5094.11 40 30 5700.00 5229.21 5170.2.1 40 23 5800.00 5305.43 5245.43 40 20 5900.00 53~1.71 5322.71 40 15 S 86 32 E 990.23 S 86 29 E 1054.97 S 96 22 E 1119.53 S 86 12 E 1184.16 S 86 5 E 1248.91 S ~6 1 E 1313.69 S ~6 0 E 1378.46 S 96 2 E 1443.05 S 36 10 E 1507.48 S ~6 .~ F 1571.84 6000.00 5458.02 539q.02 40 17 6100.00 5534.32 5475.32 40 13 6200.00 5610.64 5551.64 40 1~ 6300.00 5686.85 5627.95 40 20 6400.00 5763.12 5704.12, 40 18 6500.00 5839.34 57,~0.34 40 24 6600.00 5915.44 5~56.44 40 29 6700.00 5991.45 5932.45 40 35 6800.00 6067.44 6008.44 40 27 6900.00 6143.83 69~4.93 39 51 S ~6 6 E 1636.17 S <36 1,4 E 1700.50 S 86 22 E 1764.79 S R6 34 E 1829.19 S 86 37 E 1893.50 S 86 37 E 1957.87 S ~6 43 E 2022.38 S ~6 47 F 2086.99 S 86 51 E Z151.60 S ,~6 55 E 2215.74 7000.00 6220.89 6161.89 39 23 7100.00 6298.54 6239.54 38 41 7200.00 6376.74 6317.74 38 21 7300.00 6455.52 6396.52 37 34 7400.00 5535.05 6476.05 37 14 7500.00 6614.67 6555.67 37 9 7600.00 6694.49 6535.49 3~ 58 7700.00 6774.62 6715.62 36 25 7800.00 6855.54 ~.796.54 35 35 7900.00 6936.87 6977.~7 35 35 S ~6 50 E 2279.09 S ~6 47 E 2341.73 S 86 39 E 2403.69 S ~36 5 E 2464.97 S 95 53 E 2525.33 S !36 6 E 2585.55 S <36 16 E 2645.49 S $6 21 E 2705.02 S ~ 16 E 2763.53 S 95 16 E 2821.52 0.2g 0.31 0.15 0.17 0.20 0.19 0.19 0.19 0.15 0.07 0.23 0.19 0.19 0.19 0.33 0.10 0 .O9 0.11 0.46 0.65 0.45 0.55 0.65 1.0Z 0.37 0.47 0.16 0.45 0.00 0.00 FEET FEET FEET BEG MIN 223.34 S 331.96 E 400.10 S 516 4 E 233.07 S 388.76 E 453.28 S 59 3 E 241.29 S 449..25 E 509.95 S 61 45 E 245.54 S 511.06 5 566.98 S 64 20 E 249.52 $ 5?3.57 E 625.50 S 66 29 E 253.5'9 S 636.68 E 685.33 S 68 16 E 257.69 S 700.30 E 746.20 S 69 47 E · 261.72 S 764.44 E 808.00 S 71 6 E ) 265.34 S 829.00 E 870.43 S 72 15 E 269.05 S 893.7.4 E 933.36 S 73 14 E 272.92 S 958.47 E 996.57 S 74 6 E 276.87 S 1023.44 E 1060.23 S 74 51 E 280.90 S 1088.21 E 1123.B8 S 75 31 E 285.10 S 1153.03 E 1187.75 S 76 6 E 2~9.48 S 1217.94 E 1251.87 S 76 37 E 293.96 S 1282.87 E 1316.11 S 77 5 E 298.49 S 1347.77 E 1380.43 S 77 30 E 302.99 S 1412.49 E 1444.63 S 77 53 E 307.39 S 1477.08 E 1508.72 S 78 14 E 311.72 S 1541.60 E 1572.80 S 78 34 E 316.11 S 1606.08 E 1636.89 S 78 51 E 320.42 S 1670.58 E 1701.03 S 79 8 E 324.59 S 1735.06 E 1765.16 S 79 24 E 328.56 S 1799.68 E 1829.42 S 79 39 E 332.37 S 1864.24 E 1893.64 S 79 53 E 336.19 S 1928.85 E 1957.93 S 80 6 E 339.95 S 1993.62 E 2022.40 S 80 19 E 343.63 S 2058.50 E 2086.99 S 80 31 E 347.19 S 2123.41 E 2151.61 S 80 42 E 350.68 S Z187.84 5 2215.77 S 80 53 E 354.18 S 2251.48 E 2279.17 S 81 3 E 357.67 S 2314.40 E 2341.87 S 81 12 E' 361.25 S 23?6.62 E 2403.92 S 81 21 E 365.11 S 2438.09 E 2465.28 S 81 28 E 369.45 S Z498.56 E 2525.73 S 81 35 E 373.71 S 2558.90 E 2586.05 S 81 41 E 377.68 S 2619.05 E 7_646.10 S 81 47 E 381.48 S 2678.72 E 2705.75 S 81 53 E 3~35.72 S 2737.32 E 2764.36 S 81 58 E 390.51 S 2795.31 E 2822.46 S 82 2 E ARCO ALASKA, INC. 3 0-9 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 23-0CT-88 PAGE ' ~ ' DATE OF SURVEY: 06-JULY-~8 KELLY 6USHING ELEVATION: 59o00 FT~ ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIA'TION AZTMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH ERST/WEST DIST. AZIMUTH FEET DEG/IO0 CEET FEET FEET DEG MIN 7916.00 6949.88 6890.88 35 35 S ~5 16 E 2830.80 0.00 391.27 S 2804-59 E 2831.75 S 82 3 E COMPUTATION DATE: 2]-0CT-88 PAGE ARCO ALASKA, INC. 3 0-9 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 06-JULY-~8 KELLY 5USHING ELEVATION: 59.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEaSUrED DEPTH TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEO VERTICAL DOGLEG RECTANGULAR- COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIHUTH FEET OEO/lO0 FEET FEET FEET OEO MIN 0.00 0.00 -59.00 0 0 1000.00 999.99 940.99 0 22 2000.00 1999.96 1940.96 0 36 3000.00 2998.33 2939.33 9 8 4000.00 39210.29 3861.29 33 37 5000.00 4697.28 4638.28 40 30 6000.00 5458.02 5399.02 40 17 7000.00 6220.89 6161,,39 39 23 7916.00 5949.89 6890.38 35 35 N 0 0 E 0.00 S 79 7 5 1.25 S 3_~ 0 E 8.88 S 29 11 E 31.02 S 79 43 E 364.07 S 86 32 E 990.2.3 S 95 6 '5 1636.17 S ~6 50 E 2279.09 S 9,5 1~ E 2330.80 0.00 0.20 0.39 3.64 3.38 0.28 0.23 0.45 0 0.00 N 0.00 E 0.00 N 0 0 E 1.62 S 1.00 E 1o90 S 31 33 E 4.1.3 S 8.31 E 9.30 S 63 17 E ~4.18 S 24.11 E 50.33 S 28 37 E 223.34 S 331.96 E 400.10 S 56 4 E 272.92 S 958.47 E 996.57 S 74 6 E 316.11 S 1606.08 E 1636.89 S 78 51 E 354.18 S 2251.48 391.27 S 2804.59 E 2831.75 5 82 3 E ARCO ALASKA, INC. 3 0-9 KUPARUK NORTH SLOPE,ALASKA COMPUT.~T!ON DATE: 23-0CT-88 PAGE ~5" DATE OF SURVEY: 06-JULY-B'8 KELLY BUSHING ELEVATION: 59.00 ENGINEER: PEPPEL · 'INTERPOLATED VALUES FOR EVEN 100 FEET OF SU~-$Ea DEPTH TRUE SUB-SE,~ COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH gEPTH OEG MIN DEG MIN 0.00 0.00 -59.00 0 0 N 0 O E 59.00 59.00 0.00 0 6 S 60 33 W 159.00 159.00 100.00 0 4 S 36 31 E 259.00 259.00 200.00 0 6 S "6 1'~ W 359.00 359.00 1300.00 0 11 S 32 5 W 459.00 459.00 400.00 0 6 S 4B 41 E 559.00 559.00 500.00 0 8 N 51, 41 W 659.00 659.00 500.00 0 7 S 26 '+ W 759.00 759.00 700.00 0 15 S 5'9 4 E 959.00 859.00 ~00.00 0 24 S 57 44 E VERTICAL DOGLEG Rc_CTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 O.OO N 0.00 E -0.01 0.20 0.01 S 0.01 W -0.08 0.55 0.22 S 0.11 W -0.15 0.23 0.21 S 0.18 W -0.34 0.20 0.38 S 0.41 W -0.33 0.2% 0.65 S 0.44 W -0.34 0.27 0.56 S 0.44 W -0.54 0.22 C.62 S 0.66 W -0.36 0.30 0.90 S 0.51 W 0.14 0.40 1.17 S 0.05 W 959.01 959.00 900.00 1059.01 1059.00 lO00.O0 1159.01 1159.00 1100.00 1259.02 1259.00 1200.00 1359.02 1359.00 1300.90 1459.03 1459.00 1400.00 1559.03 1559.00 1500.00 1659.04 1659.00 1600.00 1759.04 1759.00 1700.00 1859.04 1859.00 1800.00 0 26 S 77 24 E 0 32 S 57 32 E 0 26 S 84 44 E 036 S 79 31E 0 26 S 82 52 E 0 33 S 85 7 E 026 S 83 11 E 0 28 S 73 1 E 0 14 S 59 42 E 0 28 S 56 43 E 1959.04 1959.00 1900.00 2059.05 2059.00 2000.00 2159.05 2159.00 2100.00 2259.06 2259.00 2200.00 2359.07 2359.00 2300.00 2459.10 2459.00 2400.00 2559.14 2559.00 2500.00 2659.23 2659.00 2600.70 2759.37 2759.00 2700.00 2859.62 2859.00 2300.00 0 21 S 38 4Z E 0 36 S 37 52 E 0 36 S 23 l Z E 047 S 23 1E 0 56 S 18 6 E ! 34 S 14 53 E 2 ~ $ !7 34 E 2 42 S 17 I E 3 20 S 15 49 E 4 55 S 23 3 E 2960.24 2959.00 2900.00 7 50 3061.67 3059.00 3000.00 11 25 3164.48 3159.00 3100.00 15 6 3268.82 3259.00 3200.00 17 44 3374.19 3359.00 3300.00 18 37 3480.07 3459.00 3400.90 20 31 3588.09 3559.00 3500.90 23 44 3698.64 3659.00 3600.00 26 34 3811.72 3759.00 3700.00 29 0 3927.34 3859.00 3800.00 31 24 0.97 0.36 1.57 S 0.72 E 1.69 0.2! 1.87 S 1.40 E Z.56 0.10 2.03 S 2.25 E 3.49 0.72 2.42 S 3.13 E 4.36 0.12 2.51 S 4.00 E 5.38 0.19 2.78 S 4.99 ~ 6.22 0.11 2.87 S 5.83 ~ 6.94 0.21 3.04 S 6.53 E 7.59 0.04 3.21 S 7.16 E 8.05 0.22 3.49 S 7.58 E 8.66 0.13 3.91 S 8.12 E 9.36 0.31 4.72 S 8.71 E 9.98 0.39 5.59 S 9.19 E 10.67 0.30 6.90 S 9.67 E 11.39 0.34 8.32 S 10.17 E 12.34 0.49 10.55 S 10.75 E 13.66 0.75 13.48 S 11.61 E 15.55 0.64 17.42 S 12.86 E 17.81 1.21 22.48 S 14.32 E 21.16 1.89 29.09 S 16.62 E S 27 28 E 27.48 3.03 S 29 29 E 37.86 3.66 S 33 44 E 53.39 3.66 S 41 51 E 75.17 2.88 S 49 3 E 102.37 2.41 S 54 9 E 132.92 3.54 S 59 4~9 E 170.24 3.67 S 67 26 E 215.21 3.96 S 73 53 E 267.23 3.06 S 78 33 E 325.07 2.83 0.00 N 0 0 E 0.01 S 62 58 W 0.25 S 27 44 W 0.28 S 41 29 W 0.56 S 46 55 W 0.78 S 34 9 W 0.71 S 37 57 W 0.90 S 46 29 W 1.04 S 29 31 W 1.1T S 2 30 W 1.73 S 24 34 E 2.34 S 36 47 E 3.06 S 47 14 E 3.96 S 52 21 E 4.72 S 57 55 E 5.72 S 60 51 E 6.50 S 63 47 E 7.21 S 65 2 E 7.85 S 65 51 E 8.35 S 65 15 E 9.02 S 64 16 E 9.90 S 61 32 E 10.75 S 58 41 E 11.88 S 54 27 E 13.14 S 50 42 E 15.06 S 45 32 E 17.78 S 40 44 E 21.66 S 36 26 E ] Z6.66 S 32 29 E 33.50 S 29 44 E 39.03 S 21.38 E 44.50 S 28 42 E 53.82 S Z9.44 E 61.35 S 28 40 E 74.16 S 41.81 E 85.13 S 29 24 E 97.62 S 59.99 E 114.58 S 31 34 E 1ZO.8T S 83.70 E 147.02 S 34 42 E 142.21 S lll.lZ E 180.48 S 38 0 E 164.46 S 145.26 E 219.43 S 41 27 E 185.48 S 187.35 E 263.64 S 45 17 E 202.55 S 237.25 E 311.95 S 49 30 E 216.09 S 293.64 E 364.58 S 53 39 E ARCO ALASKA, INC. 3 KUPARUK NORTH SLOPE,aLASK COMPUTATION DATE: 23-0CT-88 PAGE -6 DATE OF SURVEY: 06-JULY-88 KELLY BUSHING ELEVATION: 59.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUS-SE~ OEP'TH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 4046.89 3959.00 3900.00 35 8 4171.86 4059.00 4000.00 37 51 4299.14 4159.00 4100.00 38 34 4427.53 4259.00 4.~00. O0 39 8 4556.92 4359.00 4300.00 39 38 4687.25 4459.00 4400.00 40 6 4818.35 4559.00 4500.00 40 26 4949.69 4659.00 4600.00 40 25 5081.32 4'759.00 4700.00 40 37 5212.79 4859.00 4~00.00 40 27 VERTICAL DOGLEG RECTANGULAR COORDIN,~TES HORIZ. DEPARTURE SECTION ~ SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET BEG MIN 5344.38 4959.00 4900.00 40 35 5476.03 5059.00 5000.00 40 38 5607.74 5159.00 5100.00 40 30 5739.08 5259.00 5~_00.00 40 20 5870.24 5359.00 5300.00 40 15 6001.29 5459.00 5400.00 40 17 6132.33 5559.00 5500.00 40 13 6263.45 5659.00 5600.00 40 20 6394.60 5759.00 5700.30 40 lB 6525.82 5859.00 5~00.00 40 25 S qO 15 E 390.53 3.21 S 83 19 E 465.44 3.62 S ~6 20 E .543.85 0.48 S ~ 19 E 623.97 0.52 S 36 1~ F 705.65 0.46 S 86 31 E 788.~2 0.40 S ~6 47 E 873.10 0.20 S 8~ 34 E 957.77 0.10 S 96 30 E 1042.90 0.33 S 86 21 E 1127.78 0.17 6657.28 5959.00 5900.00 40 32 6788.90 6059.00 6000.00 40 29 6919.73 6159.00 6100.00 39 44 7049.24 6259.00 6200.00 ~9 4 7177.36 6359.00 6300.00 38 7304.40 6459.00 6400.00 37 32 7430.08 6559.00 6500.00 37 13 7555.55 6659.00 6600.00 37 1 7680.59 6759.00 6700.00 36 30 7916.00 6949.89 6990.~8 35 35 S ~6 8 E 1112.91 S 86 2 E 1298.13 S 86 0 E 1383.47 S B6 5 E 1468.24 S 86 9 E 1552.70 S 86 7 E 1636.99 S 86 16 E 1721.27 S 86 30 E 1805.65 S $6 37 ~ 1890.02 S 86 38 i 1974.51 S 86 45 E 2059.36 S B6 51 E 2144.43 S 86 53 E 222,9.28 S 36 48 E 2310.08 S 96 41 E 2389.70 S $6 3 E 2467.65 S 35 54 E 2543.45 S 36 14 E 2618.87 S 86 23 E 2693.56 S 85 16 E 2830.80 0.15 0.30 0.17 0.17 0.11 0.24 0.13 0.16 0.33 0.13 0.22 0.25 0.59 0.96 0.50 1.00 0.29 0.12 0.98 0.00 227.94 S 358.02 E 424.42 S 57 30 E 239.54 S 432.03 E 493.99 S 60 59 E 245.50 S 510.52 E 566.48 S 64 19 E 250.63 S 590.89 E 641.85 S 67 0 'E 255.93 S 672.81 E 719.84 S 69 10 E 261.22 S 756.24 E 800.09 S 70 56 E 256.01 S 840.8~ E 881.95 S 72 26 E 270.96 S 925.89 E 964.72 S 73 4I E ) 276.13 S 1011.32 E 1048.34 S 74 43 E 231.42 S 1096.49 E 1132.03 S 75 36 E 287.03 S 1131.85 E 1216.21 S 76 20 E 292.87 S 1267.27 E 1300.67 S 76 59 E 298.83 $ 1352.79 E 1385.40 S 77 32 E 304.74 $ 1437.74 E 1469.68 S 78 ! E 310.42 S 15Z2.42 E 1553.74 S 78 28 E 316.17 S 1606.91 E 1637.72 S 78 52 E 321.76 S 1691.41 E 1721.74 S 79 13 E 327.13 $ 1776.05 E 1805.93 S 79 33 E 332.17 S 1860.74 E 1890.16 S 79 52 E 337.17 S 1945.56 E 1974.56 S 80 10 E 342.06 S 2030.76 E 2059.36 S 80 26 E 346.79 S 2116.21 E 2144.43 S 80 41 E 351.36 S 2200.45 E 2228.33 S 80 55 E 355.91 S 2282.61 E 2310.19 S 81 8 E 360.4'4 S 2362.57 E 2389.91 S 81 19 E 365.30 S 2440.78 E 2467.96 S 81 29 E 370.72 S 2516.72 E 2543.87 S 81 37 E 375.93 S 2592.31 E 2619.42 S 81 44 E 380.76 S 2667.22 E 2694.26 S 81 52 E 391.27 S 2804.59 E 2831.75 S 82 3 E ARCO ALASKA, INC. 3 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A EASE KUPAqUK ~ PBTD TO COMPUTATION DATE: INTERPOLATED VALUES MEASUREO OEPTH BELOW KB 7472.00 7528.00 7568.00 7709.00 7825.00 7916.00 23-0CT-88 FOR CHOSEN HORIZONS .ORIGIN= 397 TVD FROM KB SUB-SEA 6592.38 6533.33 6637.00 6578.00 6668.94 6609.94 6781.~6 6722.86 6875.~7 6816.87 6949.88 ,$~90.8~ KELLY FNL, DATE OF SURVEY: BUSHING ELEVRTION: ENGINEER: PRGE 7 06-JULY-88 59.00 FT .. PEPPEL SURF 1941 FWL, S RECTANG NORTH/ 372. 374. 376. 381. 386. 391. ACE LOCATION EC 22, T13N, RgE, ULAR COORDINATES SOUTH EAST/WEST 55 S 2542.00 E ~4 S 2575.75 E 42 S 2599.79 E 82 S 2684.05 E 92 S 2751.82 E 27 S 2804.59 E UM ARCO ALASKA, INC. 3 0-9 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK BASE KUPARUK PBTD COMPUTATION DATE: ~*~, ~*~:)~ STRAT [G~.APHIC MEASURED DEPTH BELOW KB 7472.00 7528.00 7568°00 7709.00 7825.00 7916.00 23-0CT-38. KELLY SUMMARY FROM KB DATE BUSHING 6592.38 6537.00 6668.9~ 6781.86 6875.87 6949.88 SUR ORIGZN= ~DT mNL~ 1941 FWL~ TVD RECTAN SUB-SE~ NORTH/ OF SURVEY: ELEVATION: ENGINEER: FACE LOCATION AT SEC 22~ TZ3N~ GULAR COORDIN SOUTH EAST/ PAGE 8 06-JULY-88 5~o00 FT PEPPEL 6533.3~ 372. 6578.00 374. 6609.9~ 376. 5722.86 381. 5~16.87 386. 5890.88 391. 55 S 2542. 84 S 2575. 42 S 2599. B2 S 268&. 92 S 2751. 27 S 2804. RDE, ATES WEST O0 E 75 E 79 E 05 E 82 E 59 E UM ~INAL MEASURED DEPTH WELL LOCATION a~T TO: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 7916.00 6949.88 6890.88 2831.75 S 82 3 E SCHLUMBEROER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3 0-9 F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED 08 - dUL - 88 REFERENCE '720'76 WELL' (897' ,, ~0-9 ~'"' ~""tORIZONTAL PROJECTION FNL, 194l' FWL, aEC 22, T13N, R9E, UM) NORTH ZOO0 I SOo 1000 500 -SOO - 1000 - 1 ~00 ~OLrfH -2000 -SO0 WEST REF 72978 SCALE = l/S00 IN/FT '-CRT' ' ~ T"T'"T ...... 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'...~...{..4.-~,~ , ...... ~-..~....~....F.: ~ ..... ~; : .... ~ ..... ~... ~... ~. .......... ~...~....~.- L...F..~...~...i. : ~ ~ ..... ~:~ ~ ~ . · ::'" ~' "~ ~ .... ~ : : ' ~ ,:: [ .......... ~'., t~ : , ~ ~ ~' '~ '; ..... :' ~ ~ ~ ..h.~-.~.,. ~ ~-*-- : ...... ~...~ ..... ~...~ _.~.~..~.~.~_~.~_.~_~_~ : ~ . .~.. ~' : : : ~ . . ~ ~ ~ , , ?'r-'r-r'."'F?~-'--~ ....... r'r'r-~'i":':'. : ' ' · :':"r~'~'"~'~"'hi'?-'r-?"~'~ '~"~ ...... r"?'~ ? ~"~ r ~..f "r'~'f"~"F~ ' ~ ..... ~"?'"~'?'~ f"f'"*" +~-..f.-~---~---~.--~-..,-~ ....... ?.-~..?..? ~. ~ .~ ~. . ~. ~ ~..~ ~..?..?...~...~...~-..,-.,..~...~..~ ~..~ .N. ~ .... ~..~. ~..~ ..... ~I..~ ~ ........ ' '~'"~"*'~' ~ ...... ~ ~"~ ............. ~"'~'":i J"~ '.'R.'~"i"h d-~'"fT-'~-hf'"~'"f"',"-f"'?"-~"f"~"~"~'' ~ i "~'~ ~"f-'~'?'"~'-'~'"~'"N}'"f'"'N~-"~'"NL?'"~''~'~ "~ ~'"~'~ ~"~"~ '~'"'~ '~' f'"~";'~ ~'~'} ~ *"~'; + ..... 0 500 ]000 ]~00 2000 Z~O0 3000 3SO0 WELL: 30-9 (897' FNL, 1941' FWL, ~,£C 22, T13N, RgE, UM) ~'%ERTICAL PROJECTION -{~00 0 0 {300 1000 !SO0 2000 2~;00 3000 PROJECTION ON VERTICAL PLANE 99, - 2'79. SCALEB IN VERTICAL OEPTHS HORIZ SCALE = 1/S00 IN/FT Memo Multi-Finger Caliper Log Results Summary Company: Phillips Alaska, Inc. Well: 30-09 Log Date: October 7, 2001 Field: Kuparuk Log No.: 4424 State: Alaska Run No.: 1 APl No.: 50-029-21825-00 Pipe Desc.: 3.5" 9.3 lb. E.U.E. Top Log Intvl: 6,908 Ft. (MD) Pipe Use: Tubing Bot. Log Intvl: 7,350 Ft. (MD) Inspection Type: Corrosive Damage Inspection COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the tubing is in good condition. An isolated pit was recorded in the make-up between joint 230.1 and 231, just below GLM 5. A cross sectional diagram is included in this report. The caliper recordings indicate two other penetrations of 31% and 28% in upsets of joints 232 and 242 respectively. No other penetrations in excess of 17% wall thickness are recorded throughout the interval logged. No areas of significant cross-sectional metal loss or areas of significant ID restriction are recorded throughout the interval logged. The distribution of corrosive penetrations recorded throughout the tubing string is illustrated in the Body Region Overview sheet of this report. Note: Because the interval logged did not reach the surface, the joint count is a speculative assumption of the joint numbering at the depth of 6,908 ft. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (46%) Jt. 231 @ 6,936' MD No other penetrations in excess of 19% wall thickness are recorded throughout the body interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall-loss (in excess of 8%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No areas of significant ID restriction (in excess of 0.10") are recorded throughout the interval logged. J Field Engineer' L. Koenn Analyst: M. Lawrence Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 30-09 Field: Kuparuk Company: Phillips Alaska, Inc, Country: USA PDS Caliper Overview Body Region Analysis Survey Date: October 7, 2001 Tool Type: MFC24 No.99512 Tool Size: 1.69' No. of Fingers: 24 Ana[ysed: M. Lawrence Tubing: Size Weight Grade & Thread Nom. OD NomJD Nom~Upset 3.5 ins 9.3 ppf J-SS EUE 3.5 ins 2.992 ins 3.5 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 20~ 0 to 1 to 10 to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (~ptal = 15) Pene 1 5 9 0 0 0 Loss 2 13 0 0 0 0 Damage Configuration ( body ) Number of ioin~ damaged (total =6) 6 0 0 0 0 Damage Profile (% wall) penetration body ~ metal loss body 0 5O 0 GLM 5 239 GLM 6 Bottom of Survey: 242.1 100 Analysis Overview page 2 PDS CAL JOINT TABULATION SHEE Pipe: 35 ins 9.3 pp[ J-5S EUE Wall thickness. Body:0.254ins Upset:O.254it~s Nominal ID: 2.992 ins Well: 30-09 Field: Kupamk Company: Phillips Alaska, Inc. Joint Penetration No. Upset [ Body 12:30 Damage PrOfile % wall 50 100 0 PBR Damage Classifications Penetralion / projection class, in order of damage severily Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 50% of circumfe~enco, but depth range dof~ not exceed 2 * pipe ID Line - damage depth range exceeds 6 * pipe ID, but exlends less than 20% of circumference General - damage depth ~ange excel, ds 2 * pipe ID a~d/or extends more Iha~ 20% of circumferen~ e I~lated - damage d~th ~ange does not exceed 6 * pipe ID o~ extend more than 20% of circumference Damage re[~rting fi~reshold = 30 fl~ou inches deviation in body, 50 thotl in upset. Modal line lengfl~ = 0.163 feet Pipe Tabulations page 1 Well: 304)9 Field: Kuparuk Company: Phillips Alaska, lac. Country: USA Tubin~ 3.5 ins 9.3 f.~p~-55 EUE PDS Caliper Sections Survey Date: October 7, 2001 Toot Type: MFC24 No.99812 Toot Size: 1.69~' No. of Fingers: 24 Analysed: M. Lawrence Cross section for Joint 231 Too[ speed = 40 Nominal [D = 2.992 Nominal OD = 3,500 Remaining wail area = 72 % in Upset Region Too[ deviation = 44 ° at depth 6967.38 ft Fil~gel' 21 Penetration: 0.111 ins isolated Pi! 0. I I in = 44% \,Vail Penetration I IIGH SiDE = LIP Cross-Sections page I PDS C,,LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins I Joint Depth Length Measured Type No. ,, ID feet feet inches 230 6904.19 25.74 nominal 230.1 6929.93 5.69 nominal Glm 5 231 6935.62 31.82 3.002 232 6967.44 31.35 3.002 233 6998.79 32.33 2.994 234 7031.12 32.15 2.998 235 7063,27 31.33 2.997 236 7094.60 30.75 2.997 237 7125,35 31.19 2.995 238 7156.54 32.36 2.991 239 7188.90 31.19 2.994 240 7220.09 31.21 2,995 241 7251.30 31.15 3.004 241.1 7282.45 10.72 2.984 Pup 241.2 7293.17 8.86 nominal GIm 6 241.3 7302.03 9.76 2,987 Pup _ 242 7311.79 -34.21 2.998 242.1 7346.00 unknown 2.998 PBR Well: 30-09 Field: Kuparuk Company: Phillips Alaska, Inc. Country: U SA Date: October 7, 2001 Joint Depth Length Measure~ No. ID feet feet inche~ _ _ _ _ -- -- Joint Tally page 1 ARCO Alaska, Inc. Date: April 5, 1989 Transmittal #: 7457 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. 30-01 30-06 30-O9 30-O2 2Z-13 2Z-13 2Z-01 2D-16 2D-14 30-02 30-09 30-06 EM Ku Ku Ku Ku Ku Ku~ 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well Pressure Report 3aruk Well. Pressure Report 3aruk Fluid Level Report Camco BHP Report Camco BHP Report Sub-Surface Pressure Report Sub-Surface Pressure Report Sub-Surface Pressure Report 3 - 26 - 8 9 Sand 'A' Sand 'A' 2 - 1 5 - 8 9 Sand 'A' 2 - 1 9 - 8 9 Sand 'A' 3 - 24 - 8 9 Both Sands 3 - 24 - 8 9 Sand 'A' 3-21 -89 Tubing 3-09-89 BHP 3-09-89 BHP 2-1 9-89 #6461 3 2-19-89 #64613 2-20-89 #29855 Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Alas',~;~ C.,iJ & G_% Con2. Commissic~ Anchorage SAPC Mobil Chevron Unocal *~'",~30-09 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing '"'"~30-18 Kuparuk Fluid Level Report 3 - 1 8 - 89 Casing ~ O - 18 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing ~~;~OB-09 Kuparuk Fluid Level Report 3-1 7-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7- 89 Casing Receipt Acknowledged: ........................... Date: ............ DISTRIBt.JTION: D&M State of Alaska SAPC Chevron Unocal Mobil ARCO Alaska, Inc. Date: March 24, 1989 Transmittal Ct: 7447 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. ~ 30-16 Kuparuk Well Pressure Report I-3-1 89 Sand'A' -- 3 O- 1 0 Kuparuk Well Pressure Report 2 - 0 4 - 8 9 Sand 'A' "-- 30-13 Kuparuk Well Pressure Report 2-08-89 Sand'A' ~ 30-03 Kuparuk Well Pressure Report I - 0 9 - 8 9 Sand 'A' ,,,- 3 O- 15 Kuparuk Well Pressure Report 3 - 0 4 - 8 9 ~ 2G-1 4 Kuparuk Fluid Level Report 3-11-89 Tubing ~ 2G-13 Kuparuk Fluid Level Report 3-1 1-89 Tubing "~ 2G-09 Kuparuk Fluid Level Report 3 - 1 1 - 8 9 Tubing '~' 1 E-03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Tubing ~ 1 E- 05 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Tubing 30-18 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing '""" 3 H- 1 0 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing ~ 3 A- 03 Kuparuk Fluid Level Report 3 - 0 9 - 8 9 Casing ~ 3 H - 04 Kuparuk Fluid Level Report 3 - 0 4 - 8 9 Casing ~2 B - 1 4 Kuparuk Fluid Level Report 3 - 1 3 - 8 9 Casing · ~ 3 ©- 13 Sub-Surface Pressure Survey · 2 - 0 8 - 8 9 Ct 72 6 65 e"-,30-10 Sub-Surface Pressure Survey 2-04-89 Ct72655 '~ 3 O- 16 Sub-Surface Pressure Survey 1 - 31 - 8 9 Ct 72 655 ~ 1 B- 0 7 Kuparuk Fluid Level Re 3ort 3 - 31 - 8 8 Casing ~1 B - 03 Fluid Level Re 3ort 1 - 2 7 - 8 8 Tubing ~1B-05 Fluid Level Re2ort 1-27-88 Tubing '"""~1 B- 07 Fluid Level Re aort 4 - 2 7 - 8 8 Tubing ~1B-07 Fluid Level Re3ort 1-27-88 Tubing ~ 1 L-08 Fluid Level Re3ort 2- 1 2- 88 Tubing ~,,,~1 L- 0 4 Fluid Level Re 2ort 2 - 1 2 - 8 8 Tubing Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk ""3 H-1 0 Kuparuk Fluid Level Re ~ 3 M - 0 1 Kuparuk Fluid Level Re 3ort 3 - 1 7 - 8 9 Cas. Lng _. 3ort 3 - l~-r'~ ~ I V'r!~.~ ~ ~'~'~"~s~ ,-,,' ~ o:,~. Cons. 6ommissiori ~cnorage ~""',,,a30-09 Kuparuk Fluid Level Report 3-18-89 Casing '~'"'~30-18 Kuparuk Fluid Level Report 3- 1 8- 89 Casing ~ O - 18 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing "~~BO-09 Kuparuk Fluid Level Report 3-17-89 Casing - 13 Kuparuk Fluid Level Report 3 - 1 7 - 89 Casing Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Chevron Unocal Mobil · ARCO Alaska, Inc. Date: March 24, 1989 Transmittal Ct: 7447 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. one signed copy of this transmittal. Please acknowledge receipt and return ~ 30-16 --. 30-10 -'..,- 30-13 ..,,,~ 3 O- 03 -.,., 30-15 · .-=~ 2G- 14 ~ 2G-13 -~ 2G-09 '~" 1E-03 ~ 1 E-05 30-18 '""~ 3 H- 1 0 '~'- 3A-03 ~-~3H-04 '~--2 B- 1 4 ~30-13 e~,~30-10 '~30-16 ~'1B-07 "'"~1 B-03 '"'""~1B-07 1 -07 ~1L-08 · m,,~l L- 0 4 ~"~3 H- 1 0 "'~.. 3 M- 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 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-O9-89 3-O9-89 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 1 -27-88 4-27-88 1 -27-88 2-12-88 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 Tubing STATE OF ALASKA ALA,.,.,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging i Perforate ~ Pull tubing __ Alter casing I Repair well I Pull tubing __ Other ~ COHPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0o Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 897' FNL, 1941' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1270' FNL, 797' FEL, Sec.22, T13N, R9E, UM At effective depth 1284' FNL, 587' FEL, Sec.22, T13N, R9E, UM At total depth 1288' FNL, 534' FEL, Sec.22, T13N, RgE, UM 5. Type of Welt: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 59 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-9 9. Permit numbedapproval number 88-61/8-581 10. APl number 50-- 029-21825 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 7916 ' MD 6950 ' T VD feet feet Plugs (measured) None Effective depth: measured 7825 'MD true vertical 6876 ' TVD feet feet Junk (measured) None Casing Length Size Structural Conductor 80 ' 16" Surface 4171 ' 9-5/8" Intermediate Production 7874 ' 7" Liner Perforation depth: measured 7646 ' -7666 'MD true vertical 6731 ' -6747 'TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail ~ 7432' Packers and SSSV (type and measured depth) AVA 'RHS' pkr @ 7361' & OTIS 'FMX' SSSV ~ 1827' Cemented Measured depth True vertical depth 164 sx AS II 1lO'MD 1500 sx AS III & 4206 'MD 325 sx Class G - Top Job w/80 sx AS I 250 sx Class G & 7907'MD 100 sx 50/50 Fly Ash/Class G 110'TVD 4086'TVD 6943'TVD 13. Stimulation or cement squeeze summary N/A nte rva s treated (m eas u red) Treatment description including volumes used and final pressure 14. N/A Representative Dait¥ Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run '/ Gyro Daily Report of Well Operations _I7 , Oil v/ Gas __ Suspended "i 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 *NOTE: Title Area Drillinq Engineer (Dani) SW03/059 Completion Well History Service Date I¢ ~'/,J~ SUBMIT IN DUPLICATE Well History- Initial Report-. Dally Inatructtena: 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 ~CO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no, J~K3013 lCounty, parish or borough NORTH SLOPE - KUPARUK Lease or ~L: 25513 Title COM~'r,~.. TE ]State~K 30-9 IWell no. Operator ARCO API: 50-029-21825 IARCO w.I. 56,0000 Prior status if a W.O. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 09/21/88 ( TD: 7916 PB: 7824 SUPV:JWH I Oate 09/21/88 IH°ur 0215 HRS Complete record for each ~y reposed NORDIC 1 o) The above Is/~ct For form preparatlo~ d~str~tion, see Procedurea Mal~u:.q~,/$ectlon 10, Drilling, Pages 86 a'lT'd 87. RU SOS TO PERFORATE 7"~ 7907' MW:10.0 NaCl MIRU. ACCEPT RIG @ 0215 HRS, 9/21/88. NU AND TEST BOPE. RU SOS TO PERFORATE. DAILY:S18,891 C0M:$944,738 ETD=S944,738 EFC:$1,270,000 DRLG SUPER-I NENDENT ARCO Oil and Gas Company ,a~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD ICounty or P~TH SLOPE - KUPARUK Lease or Un~DL: 25513 Title COMPLETE. IAccounting cost center code State AK 30-9 lWell no. Auth. or W.O. nOAK3013 API: 50-029-21825 Operator ARCO A.R.Co. W.56. 0000 Spudded or W.OA~pT Date 09/21/88 Date and depth as of 8:00 a.m. Old TD Complete recor~(~[~lc~ d~y reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our 0215 }{RS IPrlor status if a W.O. I 09/22/88 ( TD: 7916 PB: 7824 SUPV:MDD [1) RIG RELEASED 7"@ 7907' MW:10.0 NaC1 PERF WELL. RIH W/2-7/8" COMPL. SET PKR, TEST TBG TO 2500 PSI,REL PBR. LAND TBG, TEST ANNULUS AND SSSV, SHEAR BALL. ND BOPE AND NU TREE. TEST SAME. DISPL WELL W/ DIESEL. RR AT 0230 HRS, 9-22-88. DAILY:S166,279 CUM:Si, ii1,017 ETD:SI,ii1,017 EFC:$1,270,000 NOTE: OTIS 'FMX' SSSV @ 1827', AVA 'RHS' PKR @ 7361' & TT @ 7432'. Released rig Classifications (oil, gas, etc.) Producing method Potential test data JNew TD I PB Depth Date IKind of rig Type completion (single, dual, etc.) Jeff c a reservoir name(s) Well no. Date I 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 T. he above ~orrect For form preparation/"a~d~stribution, ~ SDer~lliPnr~,C~da(~reesS 8M6aan~.~87S. ection 10, ORLG SbF'E i NENDENT ARCO Alaska, Inc. Date: July 29, 1988 Transmittal #: 7240 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- 0 9 OH LIS Tape and Listing 7 - 2 0 - 8 8 # 7 2 8 3 9 Receipt Acknowledged: DISTRIBUTION: State of Alaska Lynn Goettinger STATE OF ALASKA ALASr,,~ OIL AND GAS CONSERVATION COMIVl,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [~ Re-enter suspended well [] Alter casing ~J Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing E3 Amend order [] Perforate ~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. RKB 59' feet 3. Address 6. UnitorProperty name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of wellatsurface 897' FNL, 1941' FWL, Sec. 22, T13N, R9E, UM Attop ofproductiveinterval 1320' FNL, 792' FEL, Sec. 22, T13N, R9E, UM (approx) Ateffective depth 1301' FNL, 593' FEL, Sec. 22, T13N, R9E, UM (approx) Attotaldepth 1305' FNL, 537' FEL, Sec. 22, T13N, R9E UM (approx) 7. Well number 30-9 8. Permit number 88-61 9. APl number 50-- 029-21 825 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 41 71 ' 7874' Production 791 6 'MD feet 6947 ' TVD feet 7825 ' MD feet 6874 ' TVD feet Plugs (measured) None Junk (measured) None Size Cemented Measured depth 16" 164 sx AS II 110'MD 9-5/8" 1500 sx AS III 4206'MD & 325 sx Class G Top job w/80 sx AS I 7" 350 sx Class G 7907'MD ~ue Verticaldepth 110'TVD 4088'TVD 6939'TVD Perforation depth: measured None true vertical Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None N o n e 12.Attachments WELL HISTORY 13. Estimated date for commencing operation September ~ 198~ 14. If proposal was verbally approved Subsequent ~Vo:rl.; ~epo~er,]. o~ Form No../~::f/~YDated Name of approver Description summary of proposal [] Detailed operations program Date approved BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~ ~.~,~ ~ ./ Title Associ ate Engineer ~ Commission Use Only (5A3/0022) (Dani) Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy ORIGINAL SIGNED BY Returnecb,.,~. LONNIE C. SMITH ~.-. "~ -- ~-" Approved by Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate ARCO Oil and Gas Company,~," Well History - Initial Report- Daily Instructions: 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 ARCO Alaska, Inc. Field KUPARUK RIVER FIELD lCounty, parish or borough NORTH SLOPE - KUPARUK Lease or Unit ADL: 25513 Title DRILL Jstate AK 30-9 JWetl no. Auth. or W.O. no. AK3013 Operator ARCO Spudded or W.O. begun SPUD API: 50-029-21825 IARCO W.I 56.0000 Prior status if a w,o. Date and depth as of 8:00 a.m. 06/25/88 ( TD: 900' ( SUPV: JP S 06/26/88 ( TD: 3439' ( SUPV: JP S 06/27/88 ( TD: 4226' ( SUPV: JP S 06/28/88 ( TD: 4751' ( SUPV: JP S 06/29/88 ( TD: 6710'( 1 SUPV: JP S 06/30/88 ( TD: 7791'( 1 SUPV:SLC 07/01/88 ( TD: 7916'( SUPV:SLC 07/02/88 ( TD: 7916'( SUPV:SLC JDate ]Hour 06/24/88 Complete record for each day reposed DOYON 14 2300 HRS ,) ~00) DRILLING 12-1/4" HOLE 16"@ 110' MW: 8.7 VIS: 58 MOVE RIG. ACCEPTED RIG @ 1900 HRS, 6/24/88. NU DIVERTER ORIENT MWD. SPUDDED WELL @ 2300 HRS, 6/24/88. DRILL TO 900'. DAILY:S54,409 CUM:$54,409 ETD:S54,409 EFC:$1,270,000 ') 2~ 39) PREP TO DRILL/SLIDE 16"@ 110' MW: 9.0 VIS: 54 DRILLED 12-1/4" HOLE TO 3439'. POOH. LD STAB, NAVIDRILL & BIT. NU NEW BHA. RIH. REAMED F/1969'-2256'. RIH TO BOTTOM 3439'. DROPPED SURVEY. PREPARE TO DRILL/SLIDE AHEAD. DAILY:S56,386 CUM:$110,795 ETD:S165,204 EFC:$1,215,591 ) '87) CIRC AND COND CASING 9-5/8"@ 4206' MW: 9.4 VIS: 45 DRILL/SLIDE TO 4226'. CIRCULATE. DROPPED SINGLE SHOT. POOH. RETRIEVED SURVEY. TIH. CIRCULATE. POOH; LD BHA. RAN 4206' OF 9-5/8",36.0#, J-55 BTC CASING. LANDED SAME. FS @ 4206', FC @ 4123' CIRC AND COND MUD. DAILY:S43,832 CUM:$154,627 ETD:S209,036 EFC:$1,215,591 ) 25) POOH TO REPL. TURBINE 9-5/8"@ 4206' MW: 0.0 VIS: CMT 9-5/8" CASING W/1500 SX AS III, & 325 SX CLASS G. LOST LOST RETURNS. BUMPED PLUG. TOP JOB W/80 SX AS I. NU BOPE & TESTED (WITNESSED BY H. HAWKINS (AOGCC)) DAILY:S215,757 CUM:$370,384 ETD:S370,384 EFC:$1,270,000 ) 59) ) 81) DRILLING AHEAD AT 6710' 9-5/8"@ 4206' MW: 9.3 VIS: 35 FINISHED POOH. LD TURBINE. INSPECTED BIT. MU AND ORIENT NEW TURBINE. TIH. DRILLED 8-1/2" HOLE TO 6470' REPAIRED MUD LINE FLANGE LEAK. CONTINUED DRLG 8-1/2" HOLE TO 6710' DAILY:S43,024 CUM:$413,408 ETD:S413,408 EFC:$1,270,000 DRILLING AHEAD AT 7791' 9-5/8"@ 4206' MW:10.0 VIS: 40 DAILY:S47,940 CUM: $461,348 ETD:S461,378 EFC:$1,269,970 CIRC FOR CASING 9-5/8"@ 4206' MW: 9.9 VIS:'~8~' " ' SHORT TRIP. REAMED TO 7816'. CIRCULATE. SURVEY; S~O~T~ PILL. POOH, LD BHA. RAN DIL/SFL/GR/SP F/7810'2'4~0~ FDC/CNL/CAL F/7783'-7100'. PU BHA. RIH. REAMED TO 7816'!. DRILLED TO 7916'. CIRCULATE FOR CASING. DAILY: $97,724 CUM: $559,072 ETD: $559,072 EFC:$1,270,000 ) 25) NU LOWER TREE 7"@ 7907' MW: 9.9 VIS: 43 POOH LDDP. LD BHA. RUN 199 JTS OF 7", 26.0#, J-55, BTC CSG W/ FS AT 7907'. CMT W/100 SXS OF 50/50 FLYASH AND W/250 SXS OF CLASS G. CIP AT 2350 HRS, 7/1/88. ND BOPE. NU LOWER TREE. DAILY:S173,942 CUM:$733,014 ETD:S733,014 EFC:$1,270,000 The above Is correct For form preparatl distribution, see Procedures Mafu,fal, Section 10, Drilling, Pages 86 and 87. JDate , Title ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK3013 Operator ARCO Spudded or W.O. begun SPUD Cate and depth as of 8:00 a.m. ICounty or Parish NORTH SLOPE - KUPARUK Lease or Unit ADL: 25513 Title DRILL Accounting cost center code State AK 30-9 Jwo,, no. 07/03/88 ( TD: 7916 PB: SUPV:SLC API: IA.R.Co. W.t. 56.0000 IDate 06/24/88 Complete record for each day reported DOYON 14 50-029-21825 I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our ~ Prior status if a W.O. I 2300 HRS RIG RELEASED 7"@ 7907' MW: 9.9 VIS: 43 NU LOWER TREE. FREEZE PROTECT . RIG RELEASED AT 0730 HRS ETD:S906, 956 EFC:$1, 443, 942 07/02/88. DAILY:S173,942 Type completion (single, dual, etc.) CUM: $906,956 Released rig IDate IKind of rig Classifications (oil, gas, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Produclion Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature ] Date ITitle ~ OmAr-- _~/~ 7-2o ~e ASSOCIATE ENGINEER For form preparatioJ~and distribution, see Procedures Ma~0al, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Date' July 15, 1988 Transmittal #: 7224 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- 0 9 Cement Evaluation Log 7 - 0 6 - 8 8 5 9 5 0 - 7 8 2 2 Receipt Acknowledged' ' Date' - ........... DISTRIBUTION: NSK Drilling State of Alaska(+sepia) MEMORANDUM ' State of Alaska ALASka& OIL AND GAS CONSERVATION COMbIISSION TO: Lonnie C Smith-/ ~* DATE: July 12 , 1988 Co~s s ione'~' ~LE NO: D. HRH. 51 THRU: Michael T Minder ,,/4f~,~' Sr Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test AAI KRU 30-9 Permit No. 88-61 Kuparok Rv Field FROM: Harold R. Hawkins Petroleum Inspector Monday June 27, 1988: I left AAI PBF, subject of other reports to AAI ~ to Witness a BOP-Test on AAi KRU 30-9. There were no failures. I filled out an AOGCC Report which is attached. In summary, the BOP Test was satisfactorily performed by AUDI crew, for AAI KRU Well No. 30-9. Attachments 5/84 Insoector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date_ ~/~ ~//~ ~ Well Operator Well ~ Location: Sec ~ I T/.,~R~ U M Drillin~ Contractor Location, General ~/f Well SignO/~ General Housekeeping ~ese~e ~t Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure _?Q oo Test Results: Failures. Representative ~-//~f .~//L,,.L~f~H_,~' Pe~t # ~:~"~-~ I f~Ca~g Se: ~ CZOf ~t. ACC~ATOR SYST~ Full Charge Pressure /~~ psiR Pressure After Closure /~--~ psi~ Pump incr. clos. pres. 200 psig ~ min'~sec. Full Charge Pressure Attained: ~ min --sec. Controls: Master Remote ~/~ Blinds switch Kelly and Floor Safety Valves Upper Kell~ Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves No. flanges .~. Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure..~~ Adjustable Chokes Hvdrauica!l¥ operated choke Q/)~ ~r/~ Test Time / hrs. Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Corm~f~sion office notified. Rema=~s: JZ=z~ ~/ _/7 o-o L> ,~jT- / Distribution orig. - A0&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc. Date: Transmittal #: 7214 July 8, 1988 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. 30-09 Cyberlook 6-30-88 4206-781 0 3 O- 09 5" Dual Induction 6 - 3 0 - 8 8 4206 - 781 0 30-09 2" Dual Inducation 6-30-88 4206-7810 '~30-09 2"& 5" Porosity FDC 6-30-88 71 00-7783 '~'"'~30-09 2" & 5" Raw FDC 6-30-88 71 00-7783 ~30-06 2" Dual Induction 6-23-88 4702-81 08 ~30-06 5" Dual Induction 6-23-88 4702-8108 .,~ O- 06 Cyberlook 6 - 23 - 88 4702- 8050 0-06 2" & 5" Porosity FDC 6-23-88 7500-8081 ~..,30-06 2" & 5" Raw FDC 6-23-88 7500-8081 Receipt Acknowledged: DI~;TRIBUTION; NSK Alaska(+sepia) Franzen Drilling D & M State of L. Johnston(vendor package) June 9, 1988 Telecopy: (907)276-7542 Mr. J, B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 30-9 ARCO Alaska, Inc. Permit No. 88-61 Sur. Loc. 89-7'FNL, t941-'F%~, Sec. 22, T13N, R9E, UM. Btmho!e Loc. 1348'FNL, 622'FEL, Sec. 22, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well, The permit, 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~trul~ youths, ~, ~ / ~. ~.'Z' Z~"u' d'' ' C. V. Chatterton .x Chairman of Alaska Oil and Gas Conservation Comission BY ORDER OF THE COi~R-,~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ~ STATE OF ALASKA -"'~-, ALASK. OIL AND GAS CONSERVATION _,OMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen©1 Service [] DevelopementGas [] Single Zone ~ Multiple Zone I] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 59', PAD 24'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25513 ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 897'FNL,1941 'FWL,Sec.22,T13N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(@ target) 8. Well nu.mber Number 1320'FNL, 792 ' FEL,Sec. 22,T13N,R9E,UM 30-9 #8088-26-27 At total depth 9. Approximate spud date Amount 1348'FNL, 622 ' FEL,Sec. 22, T13N,R9E, UM 06/25/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD aodTVD) property line DS 30-6 7800 ' /HO 622 ' ~ TD feet 75 ' @ surface feet 2560 68,5~ ' -/'V'(~ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2865 feet Maximum hole angle 400 Maximum surface 2420 psig At total depth (TVD) 3210 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 115 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 4159' 35 35 4194 4089' 1500 sx AS I II & F-ERIA 325 sx Class G 8-1/2" 7" 26.0# J-55 BTC 7766' 34 34 780(~' 6858 100 sx 50/50 Poz Lea i F-ERi~ 200 sx Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. KT~a~fukG 500' above Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate '~ :,: ........ Production Perforation depth: measured ,a, rlch0r~,oe true vertical 20. Attachments Filing fee [] Property plat 1~ BOP Sketch [] Diverter Sketch ~ Drilling program 1~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements [] 21. I hereby c~T'f~that the fore~o, qi,ing i~ trjJe and correct ,// / ~/'//~'""~ _ to the best of my knowledge Signed !~~>f-'~,-¢ //'~~-_~,/_¢--~,,[ .~.' Title R¢,~,~,~ n,-~l-i~. F,,,~,,,,,,- Date -./- ¢ v / ...... Commission Us~ Only (TE~) P~3/~-'e~'~'') Permit Nurn'6er I APl number J Approval date I See cover letter P45~'''6~ I 50-029-~.~z.¢ I 06/09/88 I for other requirements Conditions of approval Samples required [] Yes ~LNo Mud Icg required ~ Yes ~ No Hydrogen sulfide measures [] Ye~.~ No Directional survey required ~' Yes [] No Required work~~,s~e~r~Py,~C)M~M; El 10M; iq 15M ~/~'/ Other: ~.~ ~.._. ~~~ by order of Approved by L ' Commissioner the commission Date Form 10-401 Rev. ~2-1-~5 Submit it triplicate 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 psig. 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. MUD CLEANER SHALE SHAKERS STI STIR STIR RECE, jVED MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: Triple Tandem Shale Shaker 2 Mud Cleaners Centrifuge Degasser Pit Level Indicator (Visual & 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 13.5 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 Injection 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. R Er ~ ~ V'~ LWK5 / ih 20' DIVERTER SCHEHATIC · ., I~ESCRI PTION 1. 16' C0M)U~TC~- 2. FI*lC SLIP-0N ~ STARTII~ HEAO 3. FPIC DIVERTER A~EPIBL¥ WITI~ ~ 2-1t16' 2OOO PSI BALL VALV~- 4. 20' 2000 PSI 01aJU. ll'~ ~ WI 10' 0UTLET~ $. 10' HCR BALL VALVE~ W/lO' 01VERTER LINE~. A SlNeLE VALVE ~ ~11CA~¥ tJla0N DIVERSION. 6. 20' 2000 PSI ~ PI~Li~/~,iTER' 4 ARCO ALASI~A, INC., REOLIE$11 APPR0V~. OF THIS OlVERTER ~VSTEtl AS A VARIANCE FR0et 20AAC2~.035(b) r'iAINT,,ENANCE & OPERATION RECEIVE 2 . UPON INITIAL ~NSTALLATION. CLOSE PI~VENTER VERIFY THAT VALVE OPENS PR~Y. CLOSE ANNULAR PREVENTER AN0 BLOW AIR DIVERTER LINES EVERY 12 CLOSE ANNULAR PREVENTER IN THE EVENT THAr AN INFLUX OF W[LLBORE FLUIO$ OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE 00WNWINO DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 7 6 ' DZ~ ltl I E~-~/8" ,E~O0 PS] PRRR~ ~ STACK ACCUivLq. AT~ CAPACITY TEST -I. CI-~CK NO FILL ACCUM. LATOR RESERVOIR TO PRaa~R LEVEL WZTH ~IC ~UI~ 2. ~ T~T ~~ ~ IS ~~I ~TH I~ ~I ~T~ ~ T~ ~~T~. 3. ~~ TI~ T~ ~ ~ ~T5 SIXThlY ~ ~TS ~ ~D ~TH ~I~ ~ ~. 4. ~~~ ~ ~T. T~ ~~ L~ LI~T IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 1~-5/8" B~, STACK TEST I. FILL ~ STAQ( A/~ CHCI<E Iv~N]F~ WIll-I ARCTIC DIE~. 2. ~ ~T ~L L~ ~ ~ IN ~L~ ~LY ~T~~ ~T TEST ~ IN ~L~ ~TH ~I~ JT ~ ~ IN L~ ~~ 3. ~ ~ ~~ ~ ~ KILL ~ ~ LI~ V~ ~~ TO ~ ST~ ~ O~ v~s ~~ ~ ~ ~ 4. ~~ ~TO ~~[ ~~DF~ I0~ [~ ~ ~~ TO ~~[ ~~~ I0~ 5.'~N~ ~~ ~~ K]~ ~~ ~ ~ TO ~~ ~~ ~[ ~ IN ~ 4. 7. ~[~ ~[~L V~ L[~ ~ ~S 8. ~ T~ P[~ ~ ~~ ~~P[~ 9. ~N~T~P]~ ~ ~ ~ ~~ i ii i i iii i ii I MINZFCLD AN~ LII~.S ARE FLLL CF NON-FREE'ZING FLUID. SET ALL VALVES IN ~RILLING PC~ITICN. 12. TEST STA~CPIPE VALVES, KELLY, KELLY COO<S, ~RILL PIPE SAFETY VALVE, ~ I~IC~ Ba~ TO 250 PSI ~300 PSI. , ~ ~¢ [[j~' FORM, SIGN, AI~ ~ TO CR]LL[NG SLPERVI~. ~EKLY I'HEi~AFTE~ FI.I~'TICNALLY OPERATE BCPE DAILY. 1.000__ 2OOO_ B/ PERHAFROST [ TVD" 17' 19 i m 3000_ I,.,-I 4000 _ T/ UGNU, SNDS ' TVD-2?04 KOPI TYD-2865I TIID-2855 DEP-O , --3. .......................... L- ..................... ~ ................................. BUILD 3 DEI~ 15 T/ W SAK SNDS TVD-3509 Tt'ID-3522 OEP-II2 K-12 TVD-3889 THD-3946 DEP-298 3e-'EOC--/'9 5/8" CSG PT'-' TVD-4089 TIID-4194 DEP-444 5000. :, $000~ -rooo. 0 1000- K-$ J 2000 vERT'! CALf-SECT ! ON ....... AVERAGE ANGLE 39 DEG 51 HIN TVOk5879 TIIDm6525' OEP'I 9:38 T/ 'ZONE D TVDm6459 TI1D"T280iDEP-2422 i T/ ZONE C TVD-6542 TIID-7.389 DEP-2491i T~ ZONFrA.-TVD-6598-TIID-?462, DEP-253S 'TARGET CNTR TYD-665! TI'ID.?$31* DEP-2582 B/ KUP SNDS TVD-$?04 T~O-ZeO0 OeP-2e2e TO! (LOG_:.pT.L ...... TVD.__-~SSZ?..HD_~?__8.q~ p~P-2r$4 .... 3000) · ; , .............. 2 ....... t .......... ~ + SURF~ LOO&T[QII ~ 8eT' filL. lC41' Fla. ~1~C.'~2. Ti311. ReE · . . HORIZONTAL PROJECTION SCALE 1 IN. - 1000 FEET 2000 z 1000 _ ',:3:: 1000 _ · CO' ALASKA. l mid 30, Well No (upiruk Fl~pld, North $1op~, Al mk WEST?EAST 0 1000 I 3 000 :~000 3000 TD LOCAT[ON ~ 1348' FNL. 622' FEL SEC. 2582' ARGET) CENTER TVD,46SI TII)qTS31 i .SOUTH 423 , TMIGET LOCAT [ ON, 1 1 800'~: ' 1 850* 1 900" 1 950' ! I I I 750_ .... ~~ . ~ ---.-- ~- --- -- " ' ".T-":' ,~600I ~. .; 4200t-. ' .... ~ ' ' ~ ~'~4oo : ~4~oa ..... 8.5~__ ~ - ~ ~ " t-:-' ' ' , t~800 2000' I 2050f I 2100: _ 800~ .- 850- 90Q: .... 9.50._ . 9.00- 0 1 I 1 00( O0 _ _..-.,.,,~,., 600, , - ~ _ .- .... _......... 2..9~-0-.-2800~, uu I *!:l" '~'L'oS' - "' 3'~ oo 3o00 ! 600 I ~,~ I , 4800 1 0501 .... ...... ~. · . ......... 05~ / : i,-, -- ......... . l 2500'"~ 200 I / ~' ~"~: ~ '": ~" "" ' 5200, ~.T.~ t'too. I._. ............... I .................... '..:-. ~,,~! ~'~il. !?::,~i~.!.,,:'}.~::i.:: c?,:.. -.,','.:. / -~ot ~?.~ .... \~ 400 __ L__.I 10 1150 .1.15 · ;. i 800' 1 850~ 1 900 1 950 2000 2050' 21 O0 ..................... I I CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) ~.C. ~. &--f-9~' (8) ( 3 ) .. "~ '110. Admin (9 thru (10 and 13) 12. 13. (4) Casg ~,,/-ff:~./. ~-7-~f (14 thru 22) (~) ~oP~. ,~.,~-~. (23 thru 28) (6) (29 thru 31) (6) Add: Company ~~G Lease & Well No. ~~ YES NO Is the permit fee attached .......................................... ~ ~S 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before 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 ............. ,~w Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~s, Are necessary diagrams and descriptions of diverter and BOPE attached.~ Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............ · .................... For 29. 30. 31 exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones .... If an offshore loc., are survey results of seabed conditions 32. Additional requirements ............................................. 0 ~0 Geology: Eng~_eering: rev: 02/17/88 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE /-t. gof©oL':')~v - / -co('L c9:.)o l (/6. o c0r-,,j 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 TAP~ VERI~C~TZON LISTING ,VP 010.H02 VERI~ICaTIgN LISTING PAG5 1 REEL HE~DSR ~m ;ERVICE NAME :EDIT lATE :88/07/20 iRIGIN :FLIC IEEL NaME :728~9 'ONTINUATIgN e : ~REVIQUS REEL : 'OMMENTS :LIS TAOE~ ARCO KUP~RUK 3 0-9, APl ~50-029-Z1825 ::~ TAPE HEADER..*'~-. ;ERVICE NAME :EDIT lATE :BS/0T/20 iRIGIN :FLIC 'APE NAME :72,~39 :ONTINUATZDN ~ :1 'REVZ~US T~P~ : :OMMENTS :LIS TAPE, ~RCO KUPARUK 3 0-9, ~PZ ~50-029-21B25 '-~ FILE HEADER-,."'"'-~- :ILE NAME :SDIT .001 ;ERVIC~ NAME :'FLIC ~ERSZON ~ :001A02 )ATE :88/07/20 ~AXIMUM LENGTH :1024 :ILE ~¥PE :LO ~REVIOUS FiLE : COMMENTS '~* SCHLU~BERgEp "-~ ~LASKA CgMPUTING CENTER ~-~ JOB NUMBER AT AKCC: 72839 ~UN ~1, DATE LgGGEO: 3O-JUN-~8 ,DP: J. KOHR]NG ]ATE CgMPUTED: 2O-JUL-~$ VP 010.H02 VERIFIC~TISN LISTING PAGE 2 ASING YPE FLUID 'ENSITY 'ISCOSITY 'H :LUID LOSS 9.6Z:" ~4ZO6'CLOGGEq) - BYT SIZE : ~.S" TO 7816'(LOGGER) N~ ~DLYMER !0.0 L~/G R?~ : 3.'97 @ 76 DF 40.0 S RMF = ~.11 @ 61 DF 9.0 R~C : 3o31 ~ 70 OF 4.9 C3 pu aT BHT = 2.072 @ 152 DF IEL'D ~EMARKS: I 1/2" ST&NgC:m USE'D gN DIL S~NDE; MATRIX DENSITY = S&Ng (2.55); IOLE CORRECTION = CALIm~; BHS = OPEN. TYPES/NU~'BERS: DIS 21¢0 DZC 2190 ~GS '508 CNC 1238 SGC 3109 :*~-~-~-~ THIS DAT,~ HAS NOT ~EEN~ D:PTH- SHICT:D_ - OVERLAYS ~:IELO PRINTS ~'~"~'~'~-~-~-~-~- SCHLUMBERGER LOGS INCLUDED W[TH THIS FILE '[EOIT.O01): <S::~.. mILE, EDIT.002 FDR_ 1.2" SAMPLEO FDC/CNL -,- DUlL INDUCTION SPHERICALLY FOCUSED LOG (.DZL) '~-~ ~IRST, TP_ L~ST RE~DiNG'. 7BlO' T~ 4205' ,VP 010.H02 VERIFICATION LISTING FOR'4~TION DENSITY CSM'PENSATEO LOG (.FOCi) .~ FIRST TO LAST READING: 7TB3' TO 7011' ~ COMPENSATED NEUTRON LOG (.CNL) ~k F~RST TO LEST RE~DING: 777z,~ TO 70.11~ ~ R&Y ZN CASING (.CHL) ~ :ZRST TO L&ST RE&D[NS: 4205" TO 9~8~ ~ :~ INFORMATION RECOROS 'ABLE TYPE :CONS MNEM TUNZ VALU OEFI CN FN WN NATI STAT COUN SECT TOWN RANG LATI LONG OPE~ SON APIN tABLE TYPE :CU~V ~RCO ~LASK~, I~ COMPANY N~ME KUP~RUK FIELD N~E 3 0-9 W!ELL NAME U. S . A. NAT 'ION ALASKA STATE OR P~OVI~ NORTH SLOPE COUNTY 22 SECTION 13N TOWNSHIP 9E R4NGE 897' FNL LATITUDE 1941' FWL LONGITUDE MALLARY OPERATOR'S COD'~.' 5~0~52 SERVICE ORDER ~ ~PT, SERIAL NUM~ MNEM D 5 F I DEPT 'TENS SFLU ILM ILO :DEPTH CHANNEL: .."' T ~ N S ION SFL UN~VERAGED¢~- IL-M'EDIUH RESI~- ZL-DEEP qESIST.~ VO OlD.H02 VERIFiCATIgN LISTING PAGE 4 S° SP3NT~NEgUS GR G ~.,"4A qAY TENS T:NSIgN DPHI gEMSITY P C RO S i .,'k- DRHO EELTA RHg RHO~ ~ULK DENSITY C~LI C~L!P:R GR G~ TENS TENSIgN NPHI NEUTRON POROSI~ TNRA C~LISR~TED THE~ RTNR RaW THERMAL NE~¢ RCFT RCFT RCNT RCNT C ~TC C FTC CNTC CNTC C~LZ C~L~P~R GR G~M~ R~.Y TENS TSNSION GR G&MMA R~Y DATA FORMAT RECORg ~ !NTRY 5LDCKS TYPE SIZE ~EPR CODE ENTRY 1 1 66 0 2 1 66 0 3 4 73 100 8 4 6~ 9 4 65 :T '11 1 66 10 13 1 66 0 14 4 65 ~T IS 1 66 68 16 I 66 1 0 I 66 0 0. 5000 )A'TU~ SPECIFICATION 'SLOCKS ~NEM SERVICE S~RVICE U~[T API A ~ API ~'P FILE SIZE SPL REPR ID O~D~R ~ LOG TYPE CLASS MOD NO. )EPT 530852 FT O0 000 O0 0 1 FENS OIL 530:~52 LB O0 000 O0 0 1 ~FLU OIL 530~5Z gHMM O0 000 O0 0 1 [LM Oil 530852 OHMM O0 OOO O0 0 1 ILO OIL 530852 gHMM O0 000 O0 0 1 ~P DIL 530852 MV O0 gOO O0 0 1 ~R DIL 5130852 G~PI O0 000 O0 0 1 4 rEMS FD,C 530852 LB O0 OOO O0 0 1 ]PH! FDC 530852 PU O0 000 O0 0 1 3RHO FDC 530852 G/C3 O0 000 RHOB FDC 530852 G/C3 O0 OOO O0 0 1 4 'ALI FCC 5]30352 IN O0 000 O0 O I 3R FDC 530852 G~PI O0 OOO O0 0 1 TENS CNL 530352 LB 00 OOO O0 0 1 P R 0 C ~ S S CODE (OCT.~L) 68 O000000OO00000 68 O000000OO00000 6,8 00000000000000 68 00000000000000 .,68 00000000000000 58 00000000000000 68 00000000000000 68 O0000OO0000000 68 O00000000OO000 68 00000000000000 58 00000000000000 68 00000000000000 68 O000000000000O 68 00000000000000 ,VP OlO.HO2 VEqI~ICaT!CN LISTING PaGE 5 JPHI CNL 530352 PU O0 OOg 'NRA CNL 530852 O0 000 :TNR CNL 530~5! O0 000 :CFT CNL 530852 CPS O0 gO0 ICNT CNL 530852 CPS gO OOg :FTC CNL 530852 CPS O0 OOO :NTC CNL 530852 CPS O0 000 :ALI CNL 53085Z IN O0 900 ;R CNL 530851 G~! O0 000 'ENS CHL 530852 LB gO OOO ;R CHL 530852 G~I O0 gO0 30 0 I 4 O0 0 I ~+ O0 0 I 4 O0 0 I z. O0 0 t ~ O0 0 1 ~+ O0 0 I 4 O0 0 I 4 O0 0 1 4 O0 0 1 4 O0 0 1 ~+ 1 66 00000000000000 1 68 O00000000OO000 ! 68 00000000000000 1 68 00000000000000 1 68 O000000OO00000 I 58 OOO00000000gO0 1 68 OOO0000OO0000O 1 68 O0000OO0000000 I 68 O000000000000O 1 68 O000000OO00000 1 68 OOO00000000000 DATa FORMAT RECORD *~ !NTRY 5LOCKS TYOF SIZE REPR CODE ENTRY I 1 66 0 2 I 66 0 3 4 73 100 4 1 66 1 8 4 68 9 4 65 FT 11 I 6.6 10 13 I 66 0 14 4 65 F T 15 1 66 68 16 1 66 1 0 I 66 I 0.5000 ]ATUM SPECIFICATION BLOCKS 4N~M SERVICE SERVICE UNLIT API ~PI API ~PI ~ILE SIZE SPL REPR ID ORDER '# LOG TYPE CL4SS MOD NO. ]EPT 530852 FT O0 OOO O0 0 1 ~ tENS DIL 530852 LB, O0 gO0 O0 0 1 4 SFLU OIL 530852 OHMM O0 000 O0 0 1 4 ILM OIL 530852 OHMM O0 000 O0 0 1 4 ILO OIL 530852 OHMM 90 DO0 O0 0 1 4 SP L 3 ~ MV O0 gI 5 085- O0 OOO 0 1 4 SR OIL 5:30~5Z GAPI O0 000 O0 0 I ~ TENS FD,C 530852 LB O0 000 O0 0 1 4 DPHI FDC 530852 PU O0 OOO O0 0 1 4 DRHO FDC 530852 G/C3 O0 OOO O0 0 1 ~ RHOB FDC 530851 GIC3 O0 000 O0 0 1 4 C~LI FDC 53085.2 IN O0 000 O0 0 1 ,~ ~R FDC 530352 G~P! O0 000 O0 0 I 4 TENS CNL 530852 LB O0 000 O0 0 I 4 NPHI CNL 530852 PU O0 000 O0 0 1 4 TNRA CNL 530852 O0 000 O0 0 1 4 RTNR CNL 530852 O0 go0 O0 0 1 4 RCFT CNL 530852 CPS O0 OOO go O 1 4 RCNT CNL 530852 CPS O0 000 O0 0 1 ~ CFTC CNL 530852 CPS O0 go0 O0 0 1 ~ CNTC CNL 530851 CPS O0 000 O0 0 1 4 CALI CNL 530852 IN O0 000 O0 0 1 4 GR CNL 5:30852 GAPI O0 000 O0 0 1 4 PROCESS CODE (OCTAL) 68 O000000OO000OO 68 O0000000000OO0 68 OOO00000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00OO000000000 68 00000000000000 68 00000000000000 68 O0000000000OO0 68 O000000000000O 68 O0000OO0000000 68 00000000000000 68 00000000000000 68 O000000000000O $B 00000000000000 VD OIO.H02 VERIFICATION LISTING PAGE 6 ENS CHL 530352 LB O0 000 R CHL 530852 GAPl O0 DO0 DATA 'EPT 7929.5000 TENS LD 2.5953 SP ,PHI 67.9195 ]PHD. 'R 95.8750 TENS ',TNR 3.9299 RC:T :NTC 1855.594! C~LI ;R -999.2500 tEPT 7800. OOOO TENS ]LO 2.6458 SP )PHI 68. 4359 DRHO ~R 95.8750 TENS [TNR 3. 9299 RCFT ;NTC 1855.6941 CALI ;R -99~9. 2500 )EPT 7700.0000 TENS ~LD 5.2107 SP )PHI .18.6797 BRHO ;R 8710625 TENS [TNR 3.7935 RCFT ;NTC 243!.4570 CALI ;R -999.2500 )EPT 7600.0000 TENS [LD 6.4699 SP )PHI 15.4797 9RHg ;R 95.3125 'TENS ~ T N R 3.3 O .5:2 R C F T ;NTC 2518.8008 CALI ;R -999.2500 )EPT 7500.0000 TENS [:LD 5. 9870 SP )PHI 16.4767 DRHO .;R 100.2500 'TENS ~TNR 2-7788 RCFT ]NTC 2'~+01.19B2 CAL! .;R -999. 2500 ]EPT 7400.0000 'TENS ILO 3.3406 SP ]PHI 12.2800 DRHO ~R 125. 3125 TENS RTNR 3.4349 RC~T 3NTC 2037.3540 CALI SR -999.2500 O0 0 I ~+ O0 0 I 4 295&.0000 S~LU -7.5977 GR -0.0527 RHOB 285~.0000 NPHI 460.8094 RCNT 4.4258 GR 5944.0000 SFLU -16.9906 GR -0.05:81 RHOB 5344.0000 NPHI 469.8094 RCNT 4.4258 GR 5624.0000 SFLU -32.9375 GR 0.0103 RHOB 5624.00D0 NPHI '768.~.594 ~CNT 9.'1719 GR 5504.0000 SFLU -33.~375 GR 0.0118 RHOB, 5504.0000 NPHI 781.8560 ~CNT 8.9766 GR 5804.0000 SFLU -44.4375 GR 0.0121 RHOB 5904.0000 NPHI 812.1898 RCNT 9.2'734 GR 5504.0000 SFLU -~9-5000 GR 0.1099 RHOB, 5504.0000 NPHI 600.8611 ~CNT 9.27]34 GR 3.5094 95.8750 1.5293 50.5006 1835.3865 95.8750 2.7699 95.B750 1.5208 50.5006 1835.3865 95.8750 6.1695 87.0625 Z.3418 35.4525 2406.6655 87.0625 6.1631 95.31Z5 2.3946 32.9301 2479.9126 95.3125 5.2258 100.2500 2.3781 29.9931 2~29.1128 100.2500 2.6500 125.3125 2.~474 34.2999 1917.4883 125.312~ 1 68 O00000OO00000O 1 58 OgO0000000000O ILM 2.7989 TENS 2854.0000 CALI 4.425B TNRA 3.6379 C~TC 519.336~ TENS -999.2500 ILM 2.6599 TENS 5844.0000 CALI 4.4258 TNRA 3.6379 CFTC 519.3868 TENS -99'9.2500 ILM 6.,4184 TENS 5624.0000 CALI 9.1719 TNRA 3.1312 CFTC 805.611'9 TENS -999. Z500 ILM 6.0942 TENS 550,4.0000 CALI 8.9766 TNRA 2.9735 CFTC 881.0134 TENS -999.2500 ILM 6.1046 TENS 5804.0000 CALI 9.2734 TNRA 2.8023 CFTC 931.0156 'TENS -999.2500 ILM 3.1503 TENS 5504.0000 CALI 9.27]34 TNRA 3.0768 CFTC 573.05'70 'TENS '-999.2500 VP OlO.HOZ VERI:ICATION LISTING PAGE 7 EPT 7300.9000 TENS L9 1.6~2 SP PHI 15.7942 gRHO R 144.3750 TENS TNR 3.9677 RC=T NTC 1777.6521 C~LI R -999.2500 EPT 7200.0000 TENS LO 1.1753 SP ,PHI 20.9749 9RHO ,R 127.4375 TENS ;TNR 4.0876 RC:T iNTC 1633.54.48 CALl ;R -999.2500 IEPT ?t00.0000 TENS iLD 1.6430 SP IPHI 13.8600 9RHO ;R 112.6875 TENS ITNR 3.8506 RCFT 'NTC 1828.0320 CALI ;R -999.2500 )EPT 7,900.0000 TENS :LD 2 . 5251 SP )PHI -"999.2500 DP, HO ;R -999.2500 TENS [TNR -'999. 2500 RCFT ;NTC -999.2500 CALI ;R -'999. 2500 )EPT 6900.0000 TENS [LO 1.1143 SP )PHI -999. 2500 ORHO ;R -999. 2500 TENS ~TNR -999.25 O0 RCFT ]N'TC -999.2500 CALI ;R -999.2500 )EPT 6BO0.O000 TENS ltd 1.0635 SP )PHI -999.2500 ORHO ;R -999.2500 TENS ~TNR -999.2500 ~CFT ~NTC -999.2500 CALI ;R -999.2500 )EPT 6700.0000 TENS [LO 1.9895 SP )PHI -999.2500 9RHG ;R -999.2500 'TENS ~'TNR --999.2500 RC~T ~NTC -999.2500 C~LI 5352.0000 SFLU -27.1719 GR 0.0246 RH3B 5352.0000 NPHI 420.4881 ~CNT 9.1094 GP 5360.0000 SFLU -39.2187 GR 0.0221 RH~ 5360.0000 NPHI 378.6980 RCNT 9.0313 ~R 5!8~.0000 SFLU -42.2187 GR 0.0263 RHOB 5188.0000 NPHI 501.8478 RCNT 9.2813 GR 5,452.0000 SFLU -39.8750 ~R -999.12500 RHOB -999.2500 NPHI -999.2500 RCM'T -999.2500 GR 5492.0000 SFLU -36.1562 GR -999.2500 RHOB -999.2500 NPMI -999.2500 RCNT -999.2500 GR 5452.0000 SFLU -36.0000 GR -999.2500 RHOB -999.2500 NPHI -999.2500 ~CNT -999.2500 GR 5240.0000 SFLU -41.0000 GR -999.2500 RHgB -999.,2500 NPHI -999.2500 RCNT --999.2500 GR 1.8996 144.3750 2.3729 46.4813 1682. 3840 144.3750 1. 3219 127.4375 2.3039 51.8893 1543.8508 I27.43']'5 1.6049 112.6875 2.4213 40.3975 1818.5212 112.6875 2.8926 191.1250 -999.2500 -999.2500 -999.2500 -999.2500 1.0579 172.6250 -999.2500 -999.2500 -999.2500 -999.2500 1.0395 175.3750 -999.2500 -999.2500 -999.2590 -999.2500 2.06'73 105.0625 -999,2500 -999.2500 -999.2500 -999.2500 ILM TENS CALl TNRA CFTC TENS ILM TENS C~tI TNR~ CFTC TENS ILM TENS C~LI TNRA CFTC TENS ILM 'TENS CALI TNRA CFTC TENS 'ILM TENS CALI 'TNRA CFTC 'TENS ILM 'TENS CALI TNRA CFTC TENS ILM TENS CALI T N R A CFTC TENS 1.6877 5352.0000 9.1094 ~.7284 494..3817 -999.2500 1.2329 5360.0000 9.0313 4.0174 451.3028 -999.Z500 1.6755 5188.0000 ).2813 3.4104 522.6876 -999.2500 2.5996 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1.1435 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1.0510 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.0186 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 VP 010.902 VErIFiCaTION LSSTZNG PAGE B R -~9 9. 2500 EPT 6500.0000 TENS LO 2.2024 SP PHI -999.2500 ORHO ,R -999.2500 'TENS TNR -999.2500 RCFT NTC -999.2500 C~:LI ,R -999.2500 tEPT 6500.0000 TENS ]LD Z.2839 SP tPHI -999.2500 gRHO ;R -999.2500 TENS ~TNR -999.2500 RCFT iNTC -999.2500 C~LI ;R -999.2500 )EPT 6409.0000 TENS :LD 2. B135 SP )PHI -999.2500 ORHO ;R -999.2500 TENS ITNR -999.2500 RCFT ]N'TC ,-999.2500 C~LI ;R -999.2500 )EPT 6300.0000 TENS ltd 3.1897 SP )PHI -999.2500 D~Hg ;R -999.2500 TENS ~TNR -999.2500 ~CFT ]NTC -999.2500 CALl ;R -999.2500 )EPT 6200.0000 TENS ltd 2.6664 SP )PHI -999.2500 ORHg ~R '-999.2500 TENS ~TNR -999.2500 ~CFT ~NTC -999.2500 CALI ;R -999.2500 )EPT 6100. 0000 TENS [ED 2.7100 SP )PHI -999. 2500 DRHg ~R -999.2500 TENS :~TNR -999.2500 RCFT ~NTC -'999.2500 CALl ;R -999. 2500 )EPT 6000.0000 'TENS ILO 2.3803 SP )PHI -999.2500 DRHO ~R -999.2500 TENS 4984.0000 SFLU -48.5313 ~R -999.2500 RHCB -999.2500 NPH! -999.2500 ~CNT -999.2500 gP 4952.0000 SFLU -46.1875 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 gR 5024.0000 SFLU -52.7813 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 4900.0000 SFLU -53.¢68B GR '-999.2500 RHOB -999.2500 NPgI -999.2500 RCNT -999.25~0 GR 482B.0000 SFLU -45.3125 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 4600.0000 SFLU -62.9687 GR -999.2500 RHDB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 445,2.0000 SFLU -57.5625 GR -999.2500 RHOB -999. 2500 NPHZ 2.1172 129.8750 -999.2500 -999.7_500 -999.2500 -999.2500 2.2~67 102.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.8729 121.3750 -999.2590 -999.2500 -999.2500 -999.2500 3.4056 102.3750 -999.2500 -999.2500 -999.2500 -999.2500 2.6656 1t2.18'75 -999.2500 -999.2500 -999.2500 -999.2500 2.6754 136.8T50 -'999.2500 -999.2500 -999.2500 -999.2500 2.5390 115.,{375 -999.2500 -999.2500 [t~, TENS CALI TNR.A CFTC TENS ILM TENS CALI TNRA C FTC TENS ILM TENS CALI TN~A CFTC TENS ZLM TENS C AL ! TNRA C F'TC 'TE NS ILM TENS CALI TN~A CFTC TENS TENS CALI TNRA CFTC TENS ILM TENS CALI TNRA 12.2223 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.2942 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.8307 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 3.2040 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 2.6688 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.'?124 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 ,2.4010 -999.2500 -999.2500 -999.2500 VD OlO.H02 VERIFIC~TI3N LISTING PAGE 9 TNR -999.2500 RCFT NTC -999.2500 CALI R -999.2500 EPT 5900.0000 TENS LO 2.4065 SP PHI -999.2500 gRHO ,R -999.2500 TENS TNR -999.2500 RCFT NTC -999.2500 CALI :R -999.2500 IEPT 5800.0000 TENS LD 2.6409 SP IPHI -999. 2500 DRHO ;R -999.2500 TENS 'TNR -999.2500 RCFT iNTC -999.2500 CALI iR -'999. 2500 )EPT 5700.0000 TENS :LD 2-6147 SP )PHI -999.2500 9RHO ;R -999. 2500 TENS ITNR -999.2500 RCFT iNTC -999. 2500 CALI ;R -'99 9. 2500 )EP'T 5600.0000 TENS :LO 2.8729 SP )PHI -999. 2500 gRHO ;R -999.2.500 TENS ITNR -999.2500 RCFT ;N'TC -999.2500 CALI ;R -999.2500 )EPT 5500. 0000 TENS :LO 3. 3800 SP )PHi -999.2500 DRHO ;R -999. 2500 TENS ~TNR -999. 2500 RCFT ;N'TC -999.2500 CALl ;R -999.2500 tEPT 5~00.0000 'TENS :LO 3.04'75 SP )PHI -999.2500 DRHO ;R -999.2:500 TENS ~TNR -999.2500 {CFT ;NTC -999.2500 CALl ;R -999.2500 )EPT 5300.0000 'YENS :LO 3. 110133 SP -999.2500 RCNT -999.2500 GR 4480.0000 SFLU -43.2813 gR -999.2500 RHgB -999.2500 NPHI -999.2500 RCNT -999.2500 gR 4409.0000 SFLU -52.5625 GP -999.2500 RHOB --999.2500 NPH! -999.2500 qCNT -999.2500 GR 4264.0000 SFLU -56.1562 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 4348.0000 SFLU -48.3437 GR -999.2500 ~HOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 4Z~. 0000 SFLU -57.8750 GR -99'9.2500 RHOB -999.2500 NPHI -999.2:500 RCNT -999.2500 GR 4452.0000 SFLU --5B.7500 GR -999.2500 RHOB -999.2500 NPH~ -999.2500 RC!~T -999.2500 GR 4030.0000 SFLU -55.9052 gR -999.2500 -999.2500 2.1318 105.{375 -999.2500 -999.2500 -999.2500 -999.2500 2.6950 91.3750 -999.2500 -999.2500 -999.2500 -999.2500 2.5097 101.3750 -999.2500 -999.2500 -999.2500 -999.2500 2.74.15 93.9375 -999.2500 -999.25'00 --999.Z500 -999.2500 3.56'90 100.3750 -999.2500 -999.2500 -999.~500 -999.2500 3.0051 87.6250 -999.2500 -999.2500 -999.2500 -999. 2500 3.04,~0 104.1250 CFTC TENS ILM TENS CALI TNRA CFTC TENS ILM TENS CALI TNR~ CFTC TENS ILM TENS C~L I TNRA CFTC TENS ILM 'TENS CALI TNR~ CFTC 'TENS ILM TENS CAt I TNR A CFTC TENS ILM TENS CALl TNR~ CF'TC TE NS ILM TENS -999.2500 -999. 2500 2.3282 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6225 -999.2500 -999.2500 -999.2500 -'999.2500 -999.Z500 2.5880 -999.2500 -993.2500 -999.2500 -999.2500 -999.2500 2.8200 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.3454 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 2.9889 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.0568 -999.~500 VP OlO.HO2 VERIfICaTION LISTING PAGE 10 PHI -999.2500 DRHO R -999.2500 TENS TNR -999.2500 RCFT NTC -999.2500 C~LI R -999.2500 iEPT 5200.0000 TENS ,LD 2.6605 SP mPHI -999.25000RH0 iR -999.2500 TENS ITNR -999.2500 RC~T :NTC -999.2500 CALI ;R -999.2500 )EPT 5100.0000 TENS ]LO 2.~401 SP }PHI -997.2500 DRHO ;R -999.2500 TENS ~TNR -99'9.2500 RCFT ;NTC -999.2500 CALI ;R -999.2500 )EPT 5000.0000 TENS :LO 2. 7177 SP )PHI -999.2500 ORHO ;R -999.2500 TENS ITNR -999.2500 RCFT ;NTC -99;9.2500 CALl ;R -999.2500 )EPT 4900.0000 TENS :LD 2.7402 SP )PHI -999.2500 ORHO ;R -999.2500 ~TENS ITNR -999.2500 RCFT 3NTC -999.2500 C~LI ;R -999°2500 )EPT 4800.0000 TENS ltd 2.8374 SP )PHI -999.2500 DRHO ;R -999.2500 TENS ITNR -999.2500 RCFT ;NTC -999.2500 CALl ;R -'999.2500 )EPT 4700.0000 TENS ltd 2.6150 SP )PHI -999.2500 ORHO ;R -999.2500 TENS 1TNR -999.2500 RCFT ]NTC -999.2500 CALI ;R -999.2500 -999.2500 RHg9 -999.2500 NPHI -999.2500 RCNT -999.2500 GR 3930.0000 SFLU -52.9375 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 3g24.0000 SFLU -59.5000 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GU 356~.0000 SFLU -72.0000 G~ -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 381~.0000 SFLU -72.0000 GR -999.2500 RHOB -999.Z500 NPHI -999.2500 RCNT -999.2500 GR 3540.0000 SFLU -73.5625 GR -999.2500 RHgB '-999.2500 NPHI --999.2500 RCNT -999.2500 GR 3~1~.0000 SFLU -T8.3750 GR -999.2500 RHOB -999.2500 NPHI -'999.2500 RCNT -999.2500 GR -999.2500 -999.2500 -999.2500 -999.2590 2.5757 96.3125 -999.2500 -999.2500 -999.2500 -999.2500 2.8286 99.0000 -999.2500 -999.2500 -999.2500 -999.2500 2.9345 108.6250 -999.2500 -999.2500 -999.2500 -999.2500 2.4644 93.$875 -999.2500 -999.2500 -999.2500 -999.2500 2.7518 108.8750 -999.2500 -999.2500 -'999.2500 -999.2500 2.~288 110.3125 -999.2500 -999.2500 -999.2500 -999.2500 CALI TNR~ CFTC TENS TENS CALI TNRA CFTC TENS ILM TENS CALI TNR~ CFTC TENS ILM TENS CALI TNRA CFTC TENS ILM TENS CALI TNRA CFTC TENS ILM TENS CALI TNRA CFTC TENS ILM TENS CALI TNRA CFTC TENS -999.2500 -999.2500 -999.2500 -999.2500 2.6331 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Z.7685 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6963 -999.2500 -999.21500 -999.2500 -999.2500 -999.2500 2.6688 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500, -999.2500 -999.2500 -999.2500 -999.2500 2.5161 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 VP 010.H02 VERIFIC~TIgN LISTING PAGE 11 EPT 4600.0000 TENS LD 3.4335 SP PHI -999.2500 ORHO R -999.2500 TENS TNR -999.2590 RC~T NTC -999.2500 C~LI R -999.2500 EPT 4500.0090 TENS LD 2.9707 SP :PHI -99 9. 2500 9RHO ,R -999.2500 TENS ~TNR -999.2500 RC=T iNTC -999.2500 CALI iR -999.2500 )EPT 4:~00.0000 'TENS ',rD 3.2620 SP )PHI -999.2500 9RHO ;R -999.2500 TENS ',TNR -999.2500 RCFT :NTC -999. 2500 CatI ;R -999.2500 IEPT 4300.0000 TENS iLD 3.4223 SP ~PHI -999.2500 DRHO ;R -999.2500 TENS ITNR -999.2500 RCFT iNTC -999.2500 C~LI ;R -999.2500 ;EPT 4200.0000 TENS :LD 81.7004 SP tPHI -999.2500 DRHO ;R -999.2500 TENS :TNR -999.25'00 RCi~T iNTC -999.2500 CALI ;R 64.0625 ;EPT 41100.0090 TENS [LO -999.2500 SP )PHI -999.2500 ORHO ;R -999.2500 TENS ~TNR -999. 2500 RC~T ~NTC -999. 2500 CaLl ;R 56.2500 )EPT 4000.0000 TENS ]LO -999.2500 SP )PHI -999.2500 ORHD ;R -999.25100 TENS ~TNR -999.2500 ~C~T ;N'TC -999.2500 CALI 3370.0000 SFLU -82.3750 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 3394.0000 SFLU -81.1250 GR -999.2500 RHOB -999.2500 NPH~ -999.2500 RCNT -999.2500 GR 3304.0000 SFLU -79.4375 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 3220.0000 SFLU -81.1875 GR -999.2500 RHOB -999.2500 NPHI -999.2500 RCNT -999.2500 GR 310~.0000 SFLU -57.8125 GR -999.2500 qHgB -999.2500 NPHI -999.2500 ~CNT -999.2500 G~ -999.2500 SFLU -999.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 ~CNT -999.2500 GR -999.2500 SFLU -999.2500 GR -999.2500 -999.2500 NPHI -999.,2500 RCN'T -99'9.2500 GR 3.2261 105.5625 -999.2500 -999.2500 -999.2500 -999.2500 2.6913 86.8125 -999.2500 -999.2500 -999.2500 -999.2590 :3.0791 81.1875 -999.2500 -999.2500 -999.2500 -999.2500 .3.0662 '9:1.6875 -999.2500 -999.2500 -999.2500 -999.2500 2000.0000 63.5313 -999.2500 -999.2500 -999.2500 -99~.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 ILM TENS CALI TNRA CFTC TENS iLM TENS CALI TNRA CFTC TENS ILM 'TENS CALI TNRA CFTC TENS ILM TENS CALI TNRA CFTC TENS ILM TENS CALl TNRA C F'T C TEN S It~ TENS CALI :CF'TC TENS ILM TENS CALI TNRA CFTC TENS 3.2717 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.8299 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 3.12~0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.2495 -999.2500 -999.Z500 -999.Z500 -999.2500 -999.2500 2000.0000 -999.2500 -999.2500 -999.2500 -999.2500 3160.0000 --999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 3120.0000 -999.2500 -999.2500 --99'9.2500 -999.2500 -999.2500 2970.0000 VP OlO.H02 VEqI:IC~TION LISTING PAGE 12 70.9375 EPT 3900.0000 TENS L9 -999.2500 SP ~PHI -999.2500 ORHO ~R -999. 2500 ~rENS TNR -99 '9. 2500 RCFT iNTC -999.2590 CALI iR 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CODE (OCTAL) DEPT 530~52 FT O0 DO0 00 0 2 4 1 68 O0000OO00gOOOO V? 010.H02 VEP, IFICA'TIgN LISTING PAGE lg ENS =DH 530~52 LB 00 PHI ~DH 530852 ~U O0 RH0 =DH 530852 G/C3 00 HOB FDH 530852 5/C2 00 ALI FDH 530852 IN 00 R :DH 53085] GA~I 00 ENS CNH 530952 LB 0e PHI CNH 530852 PU 00 NqA CNH 530852 00 TNR CNH 530852 00 CFT CNH 530~52 CPS 00 CNT CNH 53085] CPS 00 FTC CNH 530852 CPS O0 NTC CNH 530852 CPS 00 ,R CNH 530852 GAPI 00 000 00 0 2 00O O0 0 Z O0O 00 0 Z O00 00 0 Z 00O 00 0 2 000 00 0 Z 000 00 0 2 O00 00 O Z O0O 00 0 2 000 O0 0 Z 00 O 00 0 2 000 00 0 Z 000 O0 0 Z 000 00 0 Z 00O O0 0 2 :~ DAT~ FORMAT RECORD NTRY BLOCKS TYPE 1 2 9 11 14 15 :16 0 )ATUM SPECIFICAT!ON BLOCKS INEM SERVICE SERVICE UNIT ID ORDER ~ IEPT 530852 FT 'ENS FDH 530852 LB )PHI FDH 5'3085Z ~U )RHO FDH 530852 G/C3 ~HOB FDH 530~5Z G/C3 ;ALI FDH 530852 'IN ;R FDH 530852 GA~I 'ENS CNH 530852 LB IPHI CNH 530852 PU "NRA CNH 5~0852 {TNR CNH 53085Z ICFT CNH 530852 CPS ~CNT CNH 530852 CPS :FTC CNH 530852 CP'S :NTC CNH 530852 CPS ;R CNH 530852 GAPI SIZE 1 4 1 4 4 1 1 4 1 t 1 REPR CODE 66 66 66 68 65 66 66 65 66 66 66 ENTRY 0 0 1 FT FT API API API API FILE SIZE LOG TYPE CLASS MOD NO. O0 000 O0 0 2 O0 000 00 0 2 O0 000 O0 0 Z 00 000 90 0 2 4 O0 000 O0 0 2 O0 O00 OD 0 Z O0 000 O0 0 Z 4 O0 000 O0 0 :Z 4 O0 000 O0 0 2 O0 000 O0 0 Z O0 O00 O0 0 Z O0 000 O0 0 2 O0 000 O0 0 2 4 O0 OOO O0 O 2 4 O0 000 O0 0 :Z 4 O0 000 O0 0 2 16 0 68 t 1 SPL 1 68 O00OO000000000 1 68 00000000000000 1 68 OOO00000000000 I 65 O00000000OO000 1 65 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 58 OOO00000000000 I 68 00000000000000 1 68 00000000000000 -0.0000 REP~ PROCESS CODE (OCTAL) 68 O0000OO00OO000 58 O0000OO000000O 68 OOOO0000000000 68 00000000000000 68 00000000000000 6)3 O000000000000O 68 00000000000000 68 00000000000000 68 O00000000OO000 68 00000000000000 68 00000000000000 58 00000000000000 68 O0000OO000000O 68 00000000000000 68 O0000OO0000000 68 00000000000000 VP OlO.HO2 VERI;ICATION LISTING PAGE 20 ,EPT 7817.7002 TENS HOB 2.3495 CALl IPHI 36.7155 TNP~ ]CNT 1762.0757 CFTC IEPT 7900.2998 TENS IHOB 2.3495 C~LI IPHI 36.7155 TNPA [CNT 1762.0757 CFTC tEPT 7700.2998 TENS IHOB Z.3631 CALI IPHI 35.2133 TNRA ICNT 2532.1899 CFTC )EPT 7500.2998 TENS ',HDB Z.4126 CALl iPHI 32.1637 TNRA ~CNT 2423.1289 CFTC )EPT 7500.2998 TENS )HOB 2.3779 CALl IPHI 29.6943 TNRA ICNT 2425.4204 CFTC )EPT 7400.2998 TENS IHOB 2.4402 CALI ~PHI 32.0672 TN~ ~CNT 1953.3513 CFTC )EPT 7300.2998 TENS ~HQB 2.34T6 CALI 4PHI 48.0106 TNR~ ~CNT 1700-6050 CFTC )EPT 720g.2998 TENS ~HOB Z.2596 CALI 4PHi 47.2651 TNRA ~CNT 1674.3103 CFTC )EPT 7100.2998 TENS ~HOB 2.3642 CALl ~PH! 44.75.21 TNRA ~CNT 1870..4451 CFTC )EPT 7093.7998 TENS ~HOB 2.3495 qPHI 45.6678 TNRA RCNT 1718.5403 CFTC 3980.D000 9..Z57R 3.2076 565.2247 561!.0000 9.25T8 3.2076 566.2247 5620.0000 9.2344 3.1235 843.6289 5604.000O 9.0000 2.9247 ~62.2291 5784.0000 9.4141 '2.7937 834.9182, 552&.0000 9.4609 2.9559 721.6464 5300.0000 9.0938 3.$108 476.94'77 5320.0000 9.0703 3.7683 443.5374 5164.0000 9.5234 3.6682 527.4913 5128.0000 9.1875 3.6908 486.2004 FILE TRAILER,-,--,.~""- LE NAME :EDIT .002 OPHI RTNR CNTC DPHI 8R RTNP CNTC gPHi RTNR CNTC QPH! GR RTNR CNTC DPHI RTNR CNTC 9PHI ~TNR CNTC 9PHI RTNR CNTC gPHI GR RTNR CNTC DP HI GR ~TNR CNTC DPMI GR ~TNR CNTC l~.ZllO DRHO 101.0000 TENS 3.4650 RCFT 1781.5723 GR 18.2110 DRHO 101.0000 TENS 3.4650 RCm'T 1781.5723 GR 17.4484 DRHO 90.9375 TENS 3.4370 RCFT 2514.8726 GR 14.3879 DRHO 98.5000 TENS 3.2564 RCFT 2455.5820 GR 16.4906 DRHO 100.8750 'TENS 2.9474 RCFT 2315.7979 GR 12.7123 DRHO 119.3125 TENS Z.8611 RCFT 2033.3000 GR 18.3264 DRHO 127.5000 TENS 4.0098 RCFT 1'766. '7534 GR 23.6587 DRHD 123.0625 TENS · 4.2632 RCFT 1657.6160 GR 17.3207 DRHO 1108. 1875 TENS 3.4167 RCFT 1848.1826 GR 18.2127 9RHO 134.1250 TENS 4.2000 RCFT 1760.9114 GR 0.1304 3980.0000 502.3649 I01.0000 0.1304 5612.0000 502.3649 101.0000 0.0191 5620.0000 712.6306 90.9375 0.00'74 5604.0000 659.6769 98.5000 -0.0030 5784.0000 759.3577 100.8750 0.0856 5524.00O0 656.,4897 119.3125 -0.0029 5300.0000 440.6752 127.5000 -0.0022 5320.0000 401.4395 123.0625 -0.0185 5164.0000 472.6573 108.1875 0.0117 51128.0000 435.2217 134.1250 V~ O!O.HOZ VE?IFICATION LISTING P~GE ERV!CE N4ME :=LIC EgSION ~ :001402 ATE :88107120 AXIMUM LENGTH :1024 ILE TYP5 :LO EXT FILE NA~E : :~ TAP~,_ TRAILER -.~- ,ERVICE NAME :EDIT ,ATE :88707/20 !RZGIN ::LIC 'APE NAME :72839 ;ONT!NUATION # :l IEXT TAPE NAME : ;OMMENTS :LIS TAPE, .~PCO KUPARUK 3 0-9, ~PI ~50-029-21825 ~ REEL TR~ILE~..~ ;ERVICE N~ME )ATE :88/07./20 )RIGIN :FLIC ~EEL NAME .:72~39 'ONTINUATION ~ : ~EXT REEL NAME : 'OMMENTS :LIS T~PE, ~RCO KUPARUK 3 0-9, ~P[ ~50-029-21825