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196-059
• bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg SIANAIIED AUG 0 8 2D12. Alaska Oil and Gas Conservation Commission 333 West 7 Avenue _ ©5 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 ea , Q „,,0 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, G'(g-v-- Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM-2 Date: 04/30/2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2 -08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 .� P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2-31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2-33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P241 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P242 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2 -43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P244 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P247 1951900 50029226280000 0.0 NA 0.0 NA NA NA P248 1921260 50029223090000 02 NA 0.2 NA 1.70 4/18/2012 P249 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2-59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 _ 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 02/18/09 --~-~-~ M t7~i~f~~~~~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou _i„h ~ N0.5089 ~~~a~~~~~ ~''~~ .a ~~ ~~~~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C1~ ~ .... r,ee.. ..a:.... ns., n~ .._,__ ..n R-40 AWJI-00012 MEMORY GLS ( ( Cp 12/12/08 1 P2-35 P2-20 AWL9-00010 AYTO-00004 BAKER IBP/CROSSFLOW DETERM - [ PRODUCTION PROFILE ~ 01/02/09 0?J05/09 1 1 1 1 4-10A/L-28 AYKP-00009 IBP/CROSSFLOW DETERMINATION ~ U 02/04/09 1 1 B-36 11999060 RST (~/ - - ~j/ 11/10/08 1 1 11-32 12071914 RST G _ 11/30/08 1 1 C-23C AXOY-00006 MCNL a 12/11/08 1 1 L2-16 12071912 _ RST ~- 11/28/08 1 1 L2-32 12113026 RST '~~ "a- 12/07/08 1 1 L2-24 12113025 RST f 12/06/08 1 1 r~ci+ac rat.nwvvvL000C rSC~.CIr~ DT AIUrvIrvU HIVV Fft1UF{rvlrvla urvt GVYr tNl: rl I V: BP Exploration (Alaska) Inc Petrotechnical Data Center CR 1 ~ " ~ , ;~.,,.., G 900 E. Benson Blvd. ft„,~,, ~ ~~, ~~ ~ ~-~ ~- Anchorage,Alaska 99508 Date Delivered: i. ~. ~~ rg, at~~~~t~~ $ ~~ ~' ~a, , cn ~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ,t Anchorage, AK 99503-28 8 ATTN: Beth \' Received by: l ........""",.'... , STATE OF ALASKA ALASKJ., )IL AND GAS CONSERVATION CC.)V1lSSIONFtECEtVED REPORT OF SUNDRY WELL OPERATION§\< ''9 2ðO~ Alaska ön & G., COOl. Comrnil*Ic.:t APcttAtJOe .'t' 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program IBI Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 52' 8. Property Designation: ADL 365548 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9680 9309 9587 9221 Casing Length Structural Conductor 1151 Surface 5036' Intermediate Production Liner 4743' Tieback Liner 4889' 99519-6612 Perforation Depth MD (ft): 9167' - 9390' Perforation Depth TVD (ft): 8819' - 90331 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4. Current Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 196-059 6. API Number: 50-029-22664-00-00 9. Well Name and Number: PBU P2-20 10. Field / Pool(s): Prudhoe Bay Field / Point Mcintyre Pool feet feet Plugs (measured) None feet Junk (measured) 9538 feet Size MD TVD Bu rst Collapse 20" 1151 1151 1530 520 9-5/8" 5077' 5044' 6870 4760 4-1/2" 4927' - 9670' 49051 - 9300' 8430 7500 7" 4922' 4900' 7240 5410 4-1/2", 12.6# 13Cr80 4955' 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'HXO' SSSV 4843' 2301' SCANNED APR 2. 5 2005 Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 267 Subsequent to operation: 74 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure 180 4700 5/28/01 895 2667 2010 Tubinq Pressure 956 15. Well Class after proposed work: o Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ken Allen, 564-4366 NI A Printed Name Terrie Hubble Signature ~1V\t {. ~_ Form 10-404 Revised 04/2004 R8,(1\15 Title Technical Assistant 1/ ~ Gi\\12f\ L Date 04f¡q/OS Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ) ) P2-20 Rig W orkover Prudhoe Bay Unit 1 Point Mcintyre 50-029-22664-00-00 196-059 Accept: Spud: Release: 03/16/05 N/A 03/26/05 Nabors 7ES PRE-RIG WORK 10/28/04 RAN IN HOLE W/3.84" CENT, XO, SAMPLE BAILER TAGGED SSSV AT 2096' SLM FOR ADJUSTED MEASUREMENT. (NO SAMPLE). RAN SBHPS FIRST 15 MIN STOP AT 9059' (SLM), 9067 MD. SECOND 15 MIN STOP 9163' (SLM), 9201 MD. THIRD 15 MIN STOP AT 9268' (SLM), 9306 MD. FOURTH 30 MIN STOP AT 9163' (SLM), 9201 MD. RIG DOWN. 02125/05 DRIFT W/3.75" CENT. AND SAMPLE BAILER TO 5000' SLM. 03/03/05 SET 4-1/2 HALLIBURTON FASDRILL PLUG MID ELEMENT AT 5000' (MIDDLE OF THE FIRST FULL JOINT BELOW THE BAKER SEAL STEM - REF TUBING TALLY DATED 3/28/96). 03/04/05 SHOT TBG PUNCH FOR CIRC OUT - (4833-4835). JOB COMPLETE. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 Dªte HourS· tås\< Code· NPT· Phase·· .. pesçri þtibnof Operatiqn~ 3/1 0/2005 09:00 - 00:00 15.00 MOB N WAIT PRE WOW to move rig from V221 i to P2-20. Phase 2, road condition Level 3 3/11 /2005 00:00 - 00:00 24.00 MOB N WAIT PRE WOW. Phase 1 weather, clearing snow drifts from roads and pads in preparation for rig move. Perform rig maintenance. Change Drawworks main brake bands and auxiliary disk brake pads. Service Drawworks. Service and repair valves in pits. Prep rig to lay derrick over. 3/12/2005 00:00 - 00:00 24.00 MOB N WAIT PRE WOW. Phase 1 weather, clearing snow drifts from roads and pads in preparation for rig move. Trucks unavailable due to other rig moves. Remove snow from rig. Inspect derrick. Remove snow from camp area to facilitate moving camp. Change oil in motor # 1. Clean and maintain pit suction equipment. Service and maintain solids control equipment. Paint pits and rig floor. Service iron roughneck. 3/13/2005 00:00 - 19:00 19.00 MOB N WAIT PRE Roads and weather improved to Level 1. R/D. Wait on trucks to move rig. 19:00 - 00:00 5.00 MOB P PRE Layover derrick. Move satellite camp, shop, pits. 3/14/2005 00:00 - 06:00 6.00 MOB P PRE Move lliamna satellite camp, shop, pit module to P2-20. 06:00 - 08:00 2.00 MOB P PRE Rig down Kuskokwim camp for move from S-Pad to Pt Mcintyre P2-20. Discover 45 gal diesel spill. 08:00 - 16:00 8.00 MOB N SFAL PRE Clean up diesel spill from camp generator unit. Recover 30 gal diesel from generator room floor, 13 gal from secondary containment and 2 gal from the pad. All departments and agencies notified. 16:00 - 00:00 8.00 MOB P PRE Move Kuskokwim camp from S Pad. At 00:00 at Pt. Mac Hovercraft facility at the start of the ice road. Changeout crews. 3/15/2005 00:00 - 01 :00 1.00 MOB P PRE Move Kuskokwim camp onto location Pt. Mac 2 pad. 01 :00 - 06:00 5.00 MOB P PRE Spot 3 modules and rig up Kuskokwim camp on Pt Mac 2 pad. 06:00 - 00:00 18.00 MOB P PRE Prepare main sub and derrick to move. Hold PJSM with security, drilling crew and truckers. Moving rig from V-221 ¡to Pt Mac 2 pad. Notified AOGCC rep' Jeff Jones of upcomming BOP test on P2-20 to be performed on Wednesday 16 March. 3/16/2005 00:00 - 03:00 3.00 MOB P PRE Continue to move rig from V-221 i to P2-20. 03:00 - 22:30 19.50 RIGU P PRE Begin rig-up on location, position rig over well (some location work required/delays), backed pit module up to rig and rig up same, inspect lifting components of derrick, raised derrick and complete rig-up on well, moved sate lite camp, take on 9.4 ppg brine. 22:30 - 00:00 1.50 P DECOMP Accept rig at 19:30 hrs 3/16/2005, RU lines to tree to circulate well to 9.4 ppg brine. 3/17/2005 00:00 - 01 :00 1.00 BOPSUPP DECOMP Complete RU to circulate well to brine through tree and test lines to 3500 psi, DSM pulled BPV with lubricator. 01 :00 - 04:00 3.00 BOPSUP P DECOMP Circulate well to 9.4 ppg brine (tried to reverse 30 bbls - no go - well pressured to 1400 psi at 2 bbls and held - did the entire displacement down the tubing and normal pressures), displacement went well (1 hole volume + 1/2 additional BU pumped). 04:00 - 05:00 1.00 BOPSURP DECOMP Attempt to reverse circulate (no go - SSSV closed). 05:00 - 06:00 1.00 BOPSUPP DECOMP Install TWC (FMC) and test from above 1000 psi. 06:00 - 07:30 1.50 BOPSUP P DECOMP Nipple down tree. Printed: 3/28/2005 8:06:38 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 ·Date From~Tö Hours Task CodeNPT . : DescriptionofOþerations DECOMP Made dry run with landing joint. Nipple up BOP. DECOMP Modify riser to fit BOP due to low wellhead level. DECOMP Rig service, lubricate rig & topdrive. DECOMP Center up stack and install flow nipple. DECOMP RU XO's, test joint, test pump. Fill stack, manifold and topdrive with water. Check for leaks (none found). DECOMP Test BOP's and all related equipment, witness waived by AOGCC rep (C. Sheavy), test choke minifold valves 1-13, TD IBOP, TD manual, upper pipe rams, kill HCR, kill manual, TIW, Koomey test, blind rams, dart valve, choke HCR & manual, choke manifold valves 14 & 15, lower pipe rams, annular preventer, all pressure tests were 250 psi low & 3500 psi high. (NOTE: All tests witnessed by BP Wellsite Leaders Ferguson/Rose and NAD Tool Pushers Davidson/Barnes.) Rig down testing equipment. Rig up to pull tubing hanger and tubing. Pull TWC (DSM) with lubricator. Make up landing joint, back out lock down screws (FMC). Pull hanger smothly with 145K, 60K overpull. Seal assembly came out of PBR with no problems. Circulate surface to surface at 500 gpm, 350 psi. LD landing joint and tubing hanger (some damage on hanger), complete RU to pull tubing. Pull out of hole with 4 1/2" tubing, control line and control line bands (53 bands recovered out of 54 run - 1 lost downhole), 25 joints left to pull. Service elevators. Continue to POOH. Lay down 41/2" tubing and completion equipment. Rig-down tubing running equipment. Lubricate rig/top drive. Clear floor & lay down tubing equipment. Install wear bushing. Load pipe shed & prep 156 joints of drillpipe. PU 71/2" polish mill, 95/8" scraper, 2 junk basket BHA. RIH picking up singles to 4920', tag up w/5K. MU top drive, circ 3 bpm, 100 psi, 30 rpm, 1 k tq, confirm tag up at 4920', dress tie-back PBR as per Baker rep w/90 rpm, 1.5k tq. Circ dirt magnet sweep around, 12 bpm, 1100 psi, some debris on bottoms-up. Rig up lines, close rams and test 95/8" casing to 3500 psi (3 attempts), test failed, losing 300 psi/5 minutes over 30 minute period, decision made to POOH for RTTS. Rig down testing equipment. OTHCMP POOH & lay down polish mill BHA. OTHCMP Lay down polishing mill BHA and clear rig floor, PJSM prior to pickup RTTS. OTHCMP Pick up 9 5/8" RTTS packer and RIH to 2000'. The initial test from below the packer indicated no leak below 2000'. The second test down the annulus and above the packer indicated a leak in the casing above 2000'. Tested casing above the RTTS packer pulling up one stand at a time to one stand in the 3/17/2005 07:30 - 10:00 10:00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 14:30 2.50 BOPSURP 1.50 BOPSURP 0.50 BOPSURP 1.00 BOPSUR P 1.50 BOPSUP P 14:30 - 19:00 4.50 BOPSUP P 19:00 - 19:30 0.50 BOPSUP P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 22:00 1.50 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 3/18/2005 00:00 - 05:00 5.00 PULL P DECOMP 05:00 - 05:30 0.50 PULL P DECOMP 05:30 - 07:00 1.50 PULL P DECOMP 07:00 - 07:30 0.50 PULL P DECOMP 07:30 - 08:00 0.50 PULL P DECOMP 08:00 - 09:00 1.00 PULL P DECOMP 09:00 - 09:30 0.50 TI EBAC P OTHCMP 09:30 - 13:30 4.00 TIEBAC P OTHCMP 13:30 - 14:00 0.50 TIEBAC P OTHCMP 14:00 - 18:30 4.50 TIEBAC P OTHCMP 18:30 - 19:00 0.50 TIEBAC P OTHCMP 19:00 - 20:00 1.00 TIEBAC OTHCMP 20:00 - 21 :00 1.00 TIEBAC P OTHCMP 3/19/2005 21 :00 - 00:00 00:00 - 01 :00 3.00 TIEBAC P 1.00 TIEBAC P 01:00-10:15 9.25 TIEBAC P Printed: 3/28/2005 8:06:38 AM ') ) BPËXPLQRATIQN '>()p;~ratiO[1s $·gmrftary Ff~port' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Hours . Task Code NPT Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 3/19/2005 01:00 -10:15 9.25 TIEBAC P OTHCMP hole. It was determined that the leak in the 9 5/8" casing is above 99'. A summary ofl the casing tests is detailed in the "Remarks" section of this report. 10:15-11:00 0.75 TIEBAC P OTHCMP Lay down RTTS and clean rig floor. 11 :00 - 12:00 1.00 TIEBAC P OTHCMP RIH 18 stands, make-up Halliburton 9 5/8" storm packer, RIH 3 stands on top of packer and set storm packer at 295' 12:00 - 14:30 2.50 TIEBAC P OTHCMP Nipple down BOP, remove FMC 9 5/8" X 11" 5M Gen 6 wellhead. 14:30 - 18:30 4.00 TIEBAC P OTHCMP Install new FMC 9 5/8" X 11" 5M Gen 5 wellhead and tubing spool. Pressure test pack off to 1000 psi. 18:30 - 19:30 1.00 TIEBAC P OTHCMP Install/change upper pipe rams to 7". 19:30 - 22:00 2.50 TIEBAC P OTHCMP Test door seal to 3000 psi, test casing head, tubing spool & double studded adapter flanges to 5000 psi (all tests charted), rig-down test equipment, install wear bushing, blow down all lines. 22:00 - 23:00 1.00 TIEBAC P OTHCMP RIH and retrieve storm packer and POOH and lay down same. 23:00 - 00:00 1.00 TIEBAC P OTHCMP POOH 18 stands drill pipe. 3/20/2005 00:00 - 05:00 5.00 TIEBAC P OTHCMP Rig up E-line unit to set #2 FastDril bridge plug in 41/2" liner. Run FastDril, could not get into liner. Held up at xo at 4941'. POOH with FastDril and rig down E-line. 05:00 - 06:00 1.00 TIEBAC P OTHCMP Pick up 3 5/8" junk mill and clean-out assembly to clean-out to top of #1 FastDril currently set in the 4 1/2" liner at 4988' TMD. 06:00 - 10:30 4.50 TI EBAC P OTHCMP RIH with clean-out BHA wiith 3 5/8" mill assembly, to top of FasDril bridge plug #1. Took weight at 4941' top of 4 1/2" liner. Noted pressure increase. 10:30 - 12:00 1.50 TI EBAC P OTHCMP String took weight at 4941'. Noted pressure increase. Work pipe down while circulate to bridge plug #1 at 4988'. Circulate and pump 15 bbl high vis weighted sweep. At bottoms up noted a significant amount dibris in returns. 12:00 - 13:30 1.50 TIEBAC P OTHCMP POOH to BHA. 13:30 - 14:00 0.50 TIEBAC P OTHCMP Lay down BHA. Recovered 4 Ibs sand and pea gravel from junk subs. 14:00 - 15:00 1.00 TIEBAC P OTHCMP Clear rig floor, RU E-line (PJSM). 15:00 - 17:00 2.00 TIEBAC P OTHCMP Run in with FastDril bridge plug #2 and set at 4979'. POOH with E-line, rig down unit. 17:00 - 17:30 0.50 TIEBAC P OTHCMP Pull wear bushing. 17:30 - 18:30 1.00 TIEBAC P OTHCMP RIH with RTTS to 1151'. 18:30 - 20:00 1 .50 TI EBAC P OTHCMP Set RTTS at 1151', test from below packer to 3500 psi and hold for 5 minutes (OK), POOH w/RTTS and rig down related equipment. 20:00 - 21 :00 1.00 CASE P TIEB1 Rig up casing running equipment, PJSM prior to running the 7" tie-back string. 21 :00 - 00:00 3.00 CASE P TIEB1 Run 7" seal assembly, shoe track and float collar. RunT' tie-back string, ran to 2300' at 24:00 hrs. 3/21/2005 00:00 - 03:15 3.25 TI EBAC P OTHCMP RIH with 7" 26# NT-80S NSCC casing tie-back string (106 joints). 03:15 - 04:15 1.00 TIEBAC P OTHCMP Rig up long bails to fit cement head. 04:15 - 05:15 1.00 TIEBAC P OTHCMP Run 18 joint 7" casing, picked up 2 pups (4.84' & 4.81'), tagged top of PBR with no go. 05:15 - 06:30 1 .25 TI EBAC P OTHCMP Make up cementing head and cement line, initiate circulation through portes in seal assembly stem. Space back out of PBR to cement the 7" tie-back string. Bring pumps to cementing rate of 6 bpm, 450 psi, PJSM for cement job. Printed: 3/28/2005 8:06:38 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 Hours Task Çode NPT··· Phase · DesëriptIon of OperåtionØ . 3/21/2005 06:30 - 08:00 1.50 TIEBAC P OTHCMP Pump 5 bbls of water, pressure test all cementing lines to 3500 psi. Pump 15 bbls of 9.6 ppg high-vis mud spacer, drop bottom plug,pump 51 bbls 10.7 ppg Arctic Set lite lead slurry,followed by 71 bbls of 15.8 ppg class 'G' tail slurry. Dropped top plug and switched to rig pumps, displaced 7" tie-back string and bumped the plug on the cement job with 185 bbls of 9.4 ppg brine, bumped plug with 2500 psi, slacked off 7" tie-back string back into the PBR. 08:00 - 14:00 6.00 TIEBAC P OTHCMP Wash out flow line and stack with retarder. Set emergency slips, remove cementing head, cut casing joint, install pack-off, run in lock down screws, NU BOP, test casing head pack-off and well head flange to 5000 psi f/10 minutes. 14:00 - 15:30 1.50 TIEBAC P OTHCMP Change upper rams from 7" to 2 7/8". 15:30 - 17:30 2.00 TIEBAC P OTHCMP Open all ram doors on BOP and clean cement from ram cavities, annular, HCR's. 17:30 - 20:30 3.00 TIEBAC P OTHCMP Fill stack, make up test joint and test plug, perform full body test on stack to 3500 psi, install wear bushing, rig down testing equipment, blow-down lines, change bails and elevators. 20:30 - 21 :30 1.00 CLEAN P CLEAN Pick up 6 1/8" mill tooth bit and clean-out BHA. 21 :30 - 00:00 2.50 CLEAN N WAIT CLEAN Due to wind direction and velocity - problems RIH, blower hose was removed, service loop continued to be blown outside windwall despite efforts to secure & prevent while TIH. (NOTE: Efforts to RIH were discontinued at 21 :30 hours due to high wind conditions. Activities around the rig were restricted to whatever work that could be done safely, i.e., continued to load pipe shed w/2 7/8" drillpipe.) 3/22/2005 00:00 - 07:00 7.00 CLEAN N WAIT CLEAN Wait on winds to die down prior to resuming tripping operations (TIH w/6 1/8" clean-out BHA). 07:00 - 08:45 1.75 CLEAN P CLEAN Trip in hole 48 stands to just above float collar at 4873'. 08:45 - 10:15 1.50 CLEAN P CLEAN RU to test casing, pressure test casing to 3500 psi f/30 min & chart (OK), RD testing equipment. 10:15 -11:45 1.50 CLEAN P CLEAN Drilled cement at 4807', drilled float collar at 4873', tagged cross-over (7" x 5 1/2") at 4939'. 11 :45 - 12:30 0.75 CLEAN P CLEAN Pump high vis sweep around, pump dry job, blow-down surface equipment. 12:30 - 15:30 3.00 CLEAN P CLEAN POOH & lay down 6 1/8" clean-out BHA. 15:30 - 17:30 2.00 CLEAN P CLEAN RU to pick-up and run 4.7" mill BHA to clean out well to bottom of 4.75" PBR to @4960', make-up BHA. 17:30 - 18:00 0.50 CLEAN P CLEAN Rig service, lubricate rig/top-drive. 18:00 - 21 :00 3.00 CLEAN P CLEAN TIH & tag bottom of PBR @4962', polish PBR f/4945' t/4962' (7" scraper to 4857' f/completion packer), 40 rpm, 2k torq, 5 bpm, 400 psi, 11 Ok up, 11 Ok dn - (chased some junk/fill last 10' to 4962'). 21 :00 - 22:00 1.00 CLEAN P CLEAN Circulate sweep around 10 bpm, 1700 psi, saw significant sludge on bottoms up. 22:00 - 00:00 2.00 CLEAN P CLEAN Begin TOOH to PU clean-out BHA #3 (3 5/8" mill assembly). 3/23/2005 00:00 - 02:30 2.50 CLEAN P CLEAN Complete TOOH w/4.7 mill BHA. 02:30 - 10:30 8.00 CLEAN P CLEAN PU & RIH w/3 5/8" milling BHA, picking up 143 Jts of 2 7/8" PAC DP, XO & 2 ea. Boot baskets. 10:30 - 10:45 0.25 CLEAN P CLEAN PJSM with Baker fishing hand, Crew, TP & WSL. 10:45 - 11: 15 0.50 CLEAN P CLEAN R/U blower hose & RIH w/4 stands of 4" DP, tagging top FAS Drill BP @ 4984'. Printed: 3/28/2005 8:06:38 AM ) ) BPE)(PLORA TION . Operªti()DS·SíJrnrnary . ReÞ9rt Pump sweep & displace to clean, 9.4 ppg. Brine @ 194 GPM & 1950 psi. Mill through top Fas drill BP with no problems. Continue RIH. Tag up and mill on lower Fas Drill @ 4990'. Milling @ 70 RPM, 105 GPM, 650 psi & 1 K to 2K torque. At 4992' observed an increase in flow. Piked up & checked for flow. Well flowing. Set 25K down on Fas Drill - still in place. P/U to tool jt and shut well in with annular preventer. 10 Bbbl. gain when shut in. 450 psi stabilized SIDPP. Notified AOGCC that well is shut in - (see Remarks). DPRB CLEAN PJSM. Begin bullheading down annulus. Pressured up to 2000 psi after pumping 11 Bbls. Shut well back in. Pressure satabilized @ 1800 psi. Bleed to '0' psi. through choke and shut in . Pressure up to 230 psiin 2 minutes. Attempt to bull head down DP. Pressured up to 3000 psi after pumping 6 BBls. Shut well in and monitor. Well stabilized with 2750 psi. SIDPP. DPRB CLEAN PJSM. Circulate out kick through choke and gas buster maintaining 1600 psi back pressure. 60 GPM @ 1980 down to 1900 psi. when out. DPRB CLEAN Attempt to drill remainder of Fas Drill with annular closed & maintaining 1550 psi back pressure. While pulling up to establish rotion and torque, oily mud squirted up through table as tool joint came through. Approximately one quart went over wind wall onto snow drift next to rig. ( see Remarks ). Attempt to work back down rotating @ 340 RPM - slalled out @ 4000 torque when Tool Jt on Fas drill and also in annular. DPRB CLEAN With annular closed with minimal closing pressure, bleed well pressure to '0' through wide open choke. Drill Fas with 50 RPM & 10 to 12 K on mill. Fas drill fell through @ 4994'. RIH to next tool joint & shut well in. taking an total of 8 Bbl. gain. DPRB CLEAN Bullhead 80 bbls 9.4 ppg brine down Dp and annulus @ 2 BPM @ 800 psi. Shut pumps down and monitored pressures - 0/0 on drill pipe and annulus. Opened bag and monitored well - static. Blow down top drive. CLEAN RIH to 9538' (160' below bottom perf) where pipe took weight- no flow on TIH / no significant obstructions on TIH. CLEAN POOH to 9050' (105' above top perf) - OK. CLEAN Circulate the well at 2 bpm, 580 psi. Oil and gas cut returns to surface at 60% of one bottoms up. Oil and gas cut returns diminished significantly by surface to surface strokes. Saw gas cut returns again at 40 bbls past surface to surface strokes, however, the returns cleaned up nicely as the circulation continued past midnight. Continue to circulate - well on a slight loss w/circulating at 100 gpm, 800 psi (@10 bph). Shut down pumping and monitor well (well taking @ 1 0 bph 9.4 ppg brine). POOH w/46 stands of 4" drillpipe (@ 1 0 bph loss rate (9.4 ppg brine). LD boot baskets (no significant debris) & xo's, RU to lay down 27/8" PAC drillpipe, lay down 143 joints PAC drillpipe, 6 jts of 2 7/8" spiral drill collars. Lay down jars, boot baskets (partial control band recovered), Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Date From- To . Hours Task Code NPT Phase 3/23/2005 11 :15 - 12:00 0.75 CLEAN P CLEAN 12:00 - 13:30 1.50 CLEAN P CLEAN 13:30 - 15:00 1.50 CLEAN N 15:00 - 17:15 2.25 CLEAN N 17:15 - 18:00 0.75 CLEAN N 18:00 - 18:30 0.50 CLEAN N 18:30 - 19:30 1.00 CLEAN N 19:30 - 22:00 2.50 CLEAN P 22:00 - 22:30 22:30 - 00:00 0.50 CLEAN P 1.50 CLEAN P 3/24/2005 00:00 - 00:45 0.75 CLEAN P CLEAN 00:45 - 01 :15 0.50 CLEAN P CLEAN 01:15-03:45 2.50 CLEAN P CLEAN 03:45 - 09:00 5.25 CLEAN P CLEAN 09:00 - 10:15 1 .25 CLEAN P CLEAN Page50f7 Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 Description of Opéréltions Printed: 3/28/2005 8:06:38 AM ') ) ·SPEXPI...ÙRATION .ØpÊ!rations$Urt1m;ê1rYFl~ÞOrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 · Date From- To HoÜrs · NPT . DescriptiÒrtöfOpøra.tidns 3/24/2005 09:00 - 10:15 1.25 CLEAN P CLEAN mill, xo's. Rig down 2 7/8" handling equipment. Clean and clear rig floor. 10:15 -11:45 1.50 BOPSURP WHDTRE RIH w/15 stands 4" drillpipe to set storm packer, MU storm packer, RIH 1 stand, close bag & check PU weight through bag (60K), set storm packer, pull running stand. 11 :45 - 12:00 0.25 BOPSURP WHDTRE Pull wear bushing. 12:00 - 12:30 0.50 BOPSURP WHDTRE MU test joint and RIH wltest plug. 12:30 - 13:30 1.00 BOPSUPP WHDTRE Change upper rams to 3.5" x 6" variable. 13:30 - 17:30 4.00 BOPSUPP WHDTRE Test BOP's - top set of variable rams failed. (NOTE: Test witness waived by AOGCC rep - John Crisp. (AOGCC notified for test on 3/23 at 10:00 hrs and again on 3/24 at07:50 hrs.)) 17:30 - 19:00 1.50 BOPSUR P WHDTRE Lay down test equipment, change-out top rams to 4 1/2". 19:00 - 20:00 1.00 RUNCOMP RUNCMP MU 41/2" tubing hanger, make dummy run, test top rams. 20:00 - 20:30 0.50 RUNCOMP RUNCMP RD and blow down, set wear bushing. 20:30 - 21 :45 1.25 RUNCOMP RUNCMP PJSM wlall personnel for pulling storm packer, RIH to 75', sting into storm packer (no pressure), test lower pipe rams using storm packer, release packer wlannular closed (no pressure), fill hole from top (@ 19 bbls). 21 :45 - 23:00 1.25 RUNCOMP RUNCMP POOH, LD storm packer. 23:00 - 00:00 1.00 RUNCOIVP RUNCMP Pull wear bushing, rig up to run 41/2" completion. 3/25/2005 00:00 - 00:45 0.75 RUNCOIVP RUNCMP Rig-up to run the 4 1/2" completion. 00:45 - 06:30 5.75 RUNCOMP RUNCMP Running the 41/2" completion to 2626' (to SSSV). Well taking 2 to 3 Bbls Hr. 06:30 - 07:30 1.00 RUNCOMP RUNCMP RU control line equipment f/SSSV. 07:30 - 13:00 5.50 RUNCOMP RUNCMP Continue to RIH w/4 1/2" completion to PBR at 4944' (total 152 jts + 5.97 pup + jewelry). 13:00 - 14:15 1.25 RUNCOIVP RUNCMP MU hanger and landing joint, RD control line equipment (75 control line bands), land hanger, RILDS. 14:15 - 15:00 0.75 RUNCOMP RUNCMP RU to circulate, displace well wlclean 9.4 ppg brine at 3 bpm. 15:00 -16:15 1.25 RUNCOMP RUNCMP Reverse in 168 bbls brine, 3 bpm = 260 psi. 16:15 - 16:30 0.25 RUNCOMP RUNCMP RD circulating pin & hoses, drop ball & rod assembly @ 16:20 hrs. 16:30 - 18:30 2.00 RUNCOMP RUNCMP Pressure tubing to 3500 psi - hold & chart f/30 min (OK), bleed tubing to 1500 psi and pressure annulus to 3500 psi - hold & chart f/30 min (OK), bleed pressure on annulus then tubing to 0, pressure up on annulus to 3000 psi to shear DCR valve, circulate down tubing at 2 bpm - 350 psi (OK), circulate down annulus at 2 bpm - 430 psi (OK). 18:30 - 19:00 0.50 RUNCOrvP RUNCMP Blow down lines, pump out stack, set TWC (FMC) & test to 1000 psi from below - (OK). 19:00 - 20:30 1.50 BOPSUF P OTHCMP ND stack and adapter flange. 20:30 - 21 :30 1.00 WHSUR P OTHCMP Work on control lines and test t/5000 psi. 21 :30 - 00:00 2.50 WHSUR P POST NU adapter flange and tree, RU to test to 5000 psi. 3/26/2005 00:00 - 04:00 4.00 WHSUR P POST Test tree to 5000 psi, pull TWC (DSM), freeze protect well w170 bbls warm diesel (pumped down annulus - U-tubed over the top into the tUbing),set BPV (DSM) and tested f/below to 1000 psi - OK. placed VR plugs in one of two of the 4" x 7" annular valves (DSM could not get a VR plug in the driller's side [east side] Printed: 3/28/2005 8:06:38 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-20 P2-20 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 3/12/2005 Rig Release: 3/26/2005 Rig Number: Spud Date: 3/19/1996 End: 3/26/2005 Date· From ~ To Hours·· ..Task···· Code NPT ·Phase Descriptiôhbf Qþératiåns 3/26/2005 00:00 - 04:00 4.00 WHSUR P POST vavle) - see remarks, placed VR plug in 20" x 95/8" annular valve. RIG RELEASED @ 04:00 HRS. 3/26/2005 Printed: 3/28/2005 8:06:38 AM TREE = WELLHEÄD = ACTUATOR = ·kS:··ELe./·;··· BF. ELEV;" kCip; ............. ........,.,...,,,....,,,,,,..,..........,,...,.... Max Angle = ï5äiÙñï°MO·;···· \""....,....."",,,,,..,,,,.,...,,....,...,,..,......,. Datum TVD ::: FMC FMC ·"'·^BÁKER C ... ... ...."""".".".. 52.7' PL QO Actual RWO C~ìnpletion 3/26/05 .. ·····4438; .....""......... ........."..."."..."..,......,....... 28 @ 5509' ..0'0'9202'· ''''''''''''''''''''''''''.'''''''''''' 8800' SS FROM DRLG - DRAFT 7" TIE BACK STRING, 26#, L-80 1-1 4922' I TOP OF 4-1/2" LNR 1-1 4943' 4-1/2" TBG, 12.6#, 13CR, 0.0152 bpf, 10::: 3.958" 1--1 4955' ..... I I 9-5/8" CSG, 47#, NT-80, 10::: 8.681" 1-1 5075' ~ ~ I ~ ÆRFORA TION SUMMARY REF LOG: SWS CDRlGR ON 03/26/96 ANGLE AT TOP PERF: 16 @ 9167' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 9167-9197 0 09/05/98 2-1/2" 6 9200-9234 0 08/27/98 2-1/2" 4 9207-9257 S 08/20/98 2-1/2" 4 9295-9315 S 08/20/98 2-1J2" 6 9304-9324 0 08/27/98 2-1/2" 6 9345-9365 0 09/05/98 2-1/2" 6 9380-9390 0 09/05/98 I PBTD I-{ 4-1/2" LNR. 12.6#, 13CR. 0.0152 bpf, 10::: 3.958" I-{ 9587' 9670' DATE 03/30/96 11/21/00 02/20/01 09/18/01 03/18/02 I I I ~ I 0'· -4926' 1-1 CEMENT TO SURFACE DURING RWO 2301' 1-1 4-1/2" HES HXO SSSV, 10::: 3.813" 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3140 3138 1 KBG DMY BK 1 03/26/05 2 4765 4752 16 KBG DCK BEl< 1 03/26/05 4823' 1-1 4-1/2" HES X NIP, 10::: 3.813" 1 4843' 1-1 BAKER S-3 PKR 1 4897' 1-1 4-1/2" HES X NIP, 10::: 3.813" 1 4926' 1-1 9-5/8" BAKER LNR TOP ZXP PKR, 10::: 6.276" 4952' 1-1 7" X 5-1/2" XO, 10::: 4.875" 1 4954' 1-1 BAKER PBR, 10::: 4.75" 1 4955' 1-1 BAKER TIEBACK SEAL ASSY 4973' 1-1 5-1/2" X 4-1/2" XO, 10::: 3.968" 1 5071' 1-1 4-1/2" HES X NIP, 10::: 3.813" 1 8871' 1-1 4-1/2" HES X NIP, ID::: 3.813" 1 REV BY COMMENTS ORIGINAL COMPLETION CONVERTED TO CANVAS FINAL CORRECTIONS GL V UPDATE DA TE REV BY COMMENTS 03/26/05 BD RWO w /7ES KBE (28.05') from X' Nip @ 4897' Up to SVLN 03/29/05 A TDITLH OA CMT DURING DRLG POINT MCINTY RE UNrT WB..L: P2-20 ÆRMrT No: 96-059 API No: 50-029-22664-00 SEC14 T12N R14E2835.16 FB.. 3776.06 FNL BP Exploration (Alaska) SIS-lsl SIS-MD RNlTP RlItlh Upcoming work *' 1 of 1 ) ,. ..... .'. . . .,r )~l~.. P ?--ZO ~Y·~~~~:.¡~:c.ô.mm~~Oí'l<>'¡::·..·..·..·j¡.:":j:¡¡jj·.:y...........:. '. ...¡~:¡~:~~qri$p...-<j o~~ çl"~~~~~~j~;~~fl~~t~~µ~:t>.. Da;t ':WPA~';~4¥ar2~9?Ø8:Ø5:()) '~OQ~~,: . I am leaving the NS Office to witness BOP test on 141 Kokoda #5. I am trying to schedule the plug tags for Alpine P & A's while out there. Nabors 7ES on Pt. Mac #2-20 had no problems wi well control, they will test BOP's today. I arrived early out @ Ahtna #1-19 in Glenallen. I watched a portion of 10K test since they got me out early. I will attach the Casing test & FIT data, the Memo on the job will be coming later. ,¿ '1.1,\\0 ) 1&~?\ John Crisp ¡¡Intermediate Csg. & FIT Test Ahtna I' If'," r' ','.I!I ç",,' ') n O~~. ~ ··.'f" H. ~~~ì..\j¡¡:::r:¡,.~ ï'" ~~ _ €' LU , 1,"~'Ii-~~~~\'I!Ç':, ' 3/24/2005 8:32 AM PBU PT Mac 2-20 ) ) Nabors 7ES BP Drilling Foreman Bill Decker called & notified NS Inspector they encountered gas while drilling out EZSV @ 4990' MD. The perforations in this well are @ 9167' MD. Well was shut in without incident & 450 psi. Drill Pipe pressure observed. Well kill Operations are underway. John Crisp 1 of 1 3/23/2005 3:35 PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 2001 PL M ATE IA L U N M ARK T H IS W D E R E R C:LO]~%MFILM.DOC STATE OF ALASKA ALASK,~ 'L AND GAS CONSERVATION COMMIS N REPOR'I OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ Stimulate X' Plugging__ Perforate X' 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 48' FNL, 4042' FEL, Sec. 14, T12N, R14E At top of production interval 1371' FSL, 2386' FWL, Sec. 11, T12N, R14E At effective depth At total depth 3776' FNL, 2835' FEL, Sec. 11, T12N, R14E 5. Type of Well: Development ,)~ Exploratory __ Stratigraphic __ Service __ Datum elevation (DF or KB) KB 52.7 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P2-20 9. Permit number/approval number 96-59 / 0. APl number 500292266400 11. Field/Pool Point Mclntyre 12. Present well condition summary . Total Depth: measurea: true vertical: 9680 feet Plugs (measured) 9309 feet None. Effective Depth: measured: 9587 feet Junk (measured) None. true vertical: 9221 feet Casing Length Size Cemented Measured depth Conductor 115' 20" 260 SX Arcticset 115' Surface 5075' 9 5/8" 1055 sx PF 'E', 375 sx 'G', 5075' 250 sx PF 'E' Intermediate 4743' 4 1/2" 928 SX Class G 9670' Liner True vertical depth 115' 5043' 9300' Perforation depth: measured 9167-9197',9200-9207',9207-9234',9234-9257',9295-9304',9304-9315',9315-9324', truevertical 8766-8795',8798-8804',8804-8830',8830-8852',8889-8897',8897-8908',8908-8916', Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-9587' MD, Packers and SSSV (type and measured depth) 4 X 9 PKR @ 4926' MD, 3 4/5x 4 1/2 SSSV @ 2134' MD Please refer to attached. 3. stimulation or cement squeeze summary RECEIVED JUL 22 Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Alaska 0il & Gas C0~s. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2128 1728 5715 749 758 8297 5963 335 772 782 I16. Status of well classification as: Oil~x Gas __Suspended __Service 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X' 17. I hereby ce~i~ that the~ regoin, g is .~u,u/e and correct to the best of my knowledge. ~igned,~ ~~/~6 Title 0-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-20 WSO Perforation Squeeze 8/20/98 1 RU service company. Held pre-job safety meeting. Tagged TD at 9505' CTM. Pumped 20 bbl Neat LARC behind pipe. Pumped 2 bbl LARC with aggregate B.P.; formation locked up. Coil stuck in hole. Unable to move pipe until H20 contaminated cement. 3 PUH to safety. Squeeze 12 BB: down back side and held 3500 psi on SQZ. 4 Clean out to 9520 CTM 5 RD and released service company. P2-20 Reperforate 9/5/98 1 RU service company. Held pre-job safety meeting. 2 Arm Gun #1 3 RIH w/10' 2.5", 6 spf HSD/CCL 4 Tie-in (SWS GR/CCL log 21-APR-96) 5 Shot Gun and POOH 6 Gun did not fire - pinched O ring at CCL 7 RIH with second attempt on gun #1 8 Shot gun #1 at 9380-9390' -Good fire 9 POOH 10 RIH w/Gun #2 20" 2.5"6 spf HSD/CCL 11 Shot gun #2 at 9345-9365' -Good fire 12 POOH 13 RIH w/Gun #3, 20" 2.5"6 spf HSD/CCL 14 Shot gun #3 at 9187-9197'-Good fire 15 RD and release service company Summary Perforated 9200-9234' and 9304-9324' in three runs. Perforated while well was flowing Well: P2-20 SSSV-- PKR -- NIP I NIP Perf Perf - Cement squeeze Per-[ - Perf - Cement squeeze Perf - Perf Perf GPMA WEB Date: 4/16/99 APl: 500292266400 SSSV Type: CAT I - SSSV Annular Fluid: AL GAS T Reference SWS CDR/GR Log: Last Tag: 9506 SLM Last Tag Date: 2/18/99 Well Type: PROD Orig Compltn: 3/30/96 Last W/O: Ref Log Date: 3/26/96 TD: 9680 ftKB Max Hole 28 deg @ 5509 Anqle: Angle @ TS: deg @ Angle @ TD: 18 deg @ 9680 Rev Reason: New tag & revisions Last Update: 2/27/99 :safe~: NOtes:;:: :: :: Date Note 3/30/96 Minimum ID: 3.813" CAMCO TRDP-4A SSSV (~ 2134' MD General Notes : ID 3.810 4.000 3.810 3.810 Date Note 3/30/96 Tubing Hanger: FMC 6 @ 37' MD 3/30/96 Well Status: ACTIVE 2/18/99 Last Tag Depth @ 9506' w/2.0", only made it to 9187' w/3.8 gauge" Other(plugs, equip., etc.) - JEWELRY Depth TVD Type Description 2134 2132 SSSV 4-1/2" CAMCO TRDP-4A SSSV, ID=3.813" 4926 4904 PKR 9-5/8" X 4-1/2" BAKER LINER TOP 7_XP PACKER 5071 5039 NIP HES X NIPPLE, ID=3.813" 8871 8537 NIP HES X NIPPLE, ID=3.813" I Casing :Strings- Ali Size Weight Grade Top Btm Feet Description 9.625 47.00 NT80 0 5075 5075 PROD. CASING I Tubing Strings- All Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 9587 9587 TUBING Gas Lift MandrelsNalves Stn MD TVD Man Man VMfr VType rOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4015 4012CAMCO MMG CAMCO DMY 1.5 RK 0.000 0 3/28/96 2 4893 4873 CAMCO MMG HES OV 1.5 RK 0.380 0 8/28/98 PerforationsSummary Zone Status FeetSPF Date Type Comment 30 6 9/5/98 APERF 2.5" 31J UJ HMX 34 6 8/27/98 REPEF~ 2.5" 31J UJ HMX 23 0 8/20/98 9 0 8/20/98 20 6 8/27/98 APERF 2.5" 31J UJ HMX 20 6 9/5/98 APERF 2.5" 31J UJ HMX 10 6 9/5/98 APERF 2.5" 31J UJ HMX Interval TVD 9167-9197 8819-8848 9200- 9234 8851-8883 9234- 9257 8883- 8905 9295-9304 8942- 8950 9304- 9324 8950- 8970 9345-9365 8990-9009 9380 - 9390 9023 - 9033 stimulations & Treatments Interval Date Type Comment 9207- 9257 8/20/98 Cement squeeze 9295 - 9315 8/20/98 Cement squeeze PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 03/12/98 RUN RECVD 96-059 96-059 96-059 96-059 CDR CDR - TVD 7100 PERF RECD ~SEPIA ~SEPIA -CDR ~"~PIA 05/20/96 05/20/96 05/20/96 04/04/96 96-059 96-059 STAT PRESS GR/CCL /.~EPIA ~/~EPIA TIE IN 1 04/04/96 1 04/04/96 96-059 PROD PROF ~L/9100-9370 1 12/13/96 96-059 ROD ~~ ~ ~? 10 -407 ~/9100-9370 ~R/COMPLETION DATE ~/.~ ? / ~ / FINAL 02/14/97 DAILY WELL OPS R Are dry ditch samples required? Was the well cored? yes ~/And received? yes _~_Analysis & description received? Are well tests required?~t~es ~,~eceived? Well is in compliance ~'~'~,~ I~itial COMMENTS · T GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN- Sherrie NO. 10769 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 2/5/97 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27/NK-28)] Well Job # Log Description Date BL Floppy RF Sepia Disk P2-20 PRODUCTION LOG 9 61 2 0 3 I 1 -44 PRODUCTION PROFILE 9 7 01 2 7 I 1 ,, n and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10639 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12/13/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk P 2-07 PR~3DUCTI~)N PROFILE LOG I 9 61 1 1 4 I 1 P 2~ 12 PRODUCTION PROFILE LOG 9 61 1 1 6 I 1 P 2- 2 0 PRODUCTION PROFILE 9 61 2 0 3 I 1 P2-21 PRODUCTION LOG PROFILE 9 61 1 1 5 I 1 P2-44 PERFORATION RECORD 9 61 1 2 0 I 1 RECEIVED SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. . ---' STATE OF ALASKA ALAStv-~ OIL AND GAS CONSERVATION CuMMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-59 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22664 4. Location of well at surface 9. Unit or Lease Name · ,. ~--t:-r~ ........ ~ Point Mclntyre 50'SNL, 1239'EWL, SEC. 14, T12N, R14EEwL, 1, T12N, / ';"*"~:':": ". At top of productive interval: ~'~','~-~ ~ '~-'~/"'"':/'~,,;.' '¥r;""'~:~;":"~i 10. Well Number 1371' NSL, 2386' SEC. 1 R14E 12~.?.,,,~.z.,~_.~...~_ P2-20 At total depth ;'.~~ i ~! 1502' NSL, 2444' EWL, SEC. 11, T12N, R14E i ~f'_: -i .~. i 11. Field and Pool ...... Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease"D'bsigr~tion and Serial No. KBE = 52.7'I ADL 365548 12. Date Spudded03/19/96 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' Of COmpletiOns03/26/96 04/21/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 9680 9309 FT~ 9587 9221 FT []Yes I-INo I 2134' MD! 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, GR/RES i23. CASING, LINER AND CEMENTING RECORD CASING S E-I-'I~i'N G DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 115' 30" 260 sx Arctic Set (Approx.) 9-5/8" 47# NTSOS 41' 5077' 12-1/4" 1055 sx PF 'E', 375 sx 'G', 250 sx PF 'E' 4-1/2" 12.6# 13CR80 4927' 9670' 8-1/2" 928 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 13CR80 4955' 4940' M D TVD M D TVD 9207'-9257' 8857'-8905' 9295'-9315' 8942'-8961' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/200 bbls diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 04/22/96 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF :WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing Pressure CALCULATED. OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA ORIGINAL NOV 2 ~ 1996 Naska OD & Gas Cons. ComrnissioD Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. ' Geoiogic Mark~.,, Marker Name Kalubik Kuparuk River Zone UC1 Zone UB2 Measured Depth 9150' 9167' 9197' 9295' ~nts Summary of Daily Drilling Reports, Surveys 32. hereby certify that the fo ~g is True Vertical Depth 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED NOV 2 ]1996 Alaska 0il & ~as Cons. Commission Signed orrect to the best of my knowledge Title Senior Drilling.~Engineer Prepared By Name/Number: 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. I'rEa 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. I'rEM 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 cementing and the location of the cementing tool. ITEM 27; Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate ' , none. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: P2-20 Rig Name: Pool 7 AFE: 2C0092 Accept Date: 03/1 8/96 Spud Date: 03/1 9/96 Release Date: 03/30/96 Mar 18 1996 (1) RD Drillfloor / Derrick. Rig moved 80 %. Mar 19 1996 (2) Rig moved 100 %. RU divertor. Made up BHA #1. Tested divertor. RD survey wireline unit. Circulated at 115 ft. Repaired fluid system. Drilled to 160 ft. Mar 20 1996 (3) Drilled to 2650 ft. Mar 21 1996 (4) Drilled to 3008 ft. Circulated at 3008 ft. Took Gyro survey at 3008 ft. POOH to 1696 ft. RIH to 3008 ft. Drilled to 4865 ft. Mar 22 1996 (5) Drilled to 5088 ft. Circulated at 5088 ft. POOH to 863 ft. RIH to 5088 ft. Circulated at 5088 ft. POOH to 893 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 3000 ft (9.625 in OD). Mar 23 1996 (6) Ran casing to 5077 ft (9.625 in OD). Circulated at 5077 ft. Pumped spacers- volume 50 bbl. Mixed and pumped slurry - 408 bbl. Mixed and pumped slurry - 77 bbl. Displaced slurry- 358 bbl. RD cement unit. Circulated at 100 ft. Mixed and pumped slurry- 21 bbl. RD divertor. Installed adapter spool. RU all functions. Tested all functions. Installed wear bushing. Made up BHA #2. Functioned downhole tools at 954 ft. Mar 24 1996 (7) Functioned downhole tools at 954 ft. Singled in drillpipe to 3150 ft. RIH to 4953 ft. Serviced block line. Tested casing. Drilled to 5098 ft. Circulated at 5098 ft. Performed formation integrity test, 16.370 ppg EMW. Drilled to 6819 ft. Page Mar 25 1996 (8) Drilled to 7379 ft. Circulated at 7379 ft. POOH to 861 ft. Pulled BHA. Serviced top drive. MU BHA #3. RIH to 7379 ft. Took MWD survey at 7379 ft. Drilled to 7475 ft. Mar 26 1996 (9) Drilled to 8801 ft. Circulated at 8801 ft. POOH to 7300 ft. RIH to 8801 ft. Circulated at 8801 ft. Circulated at 8801 ft. Drilled to 9158 ft. Mar 27 1996 (10) Drilled to 9680 ft. Circulated at 9680 ft. POOH to 8650 ft. RIH to 9680 ft. Circulated at 9680 ft. POOH to 820 ft. Pulled BHA. Retrieved wear bushing. Installed wear bushing. RU casing handling equipment. Rig waited: Unsafe to continue operation. Mar 28 1996 (11) Rig waited: Unsafe to continue operation. Ran casing to 4743 ft (4.5 in OD). Circulated at 4743 ft. Ran drillpipe in stands to 9680 ft. RU high pressure lines. Circulated at 9680 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry- 339 bbl. Displaced slurry- 168 bbl. Tested mechanical packer- via annulus. Circulated at 4936 ft. Circulated at 4936 ft. Mar 29 1996 (12) Circulated at 4936 ft. Circulated at 4936 ft. RD high pressure lines. Pulled drillpipe in stands to 2400 ft. Laid down 2400 ft of drillpipe. Removed wear bushing. RU completion string handling equipment. Ran tubing to 4954 ft (4.5 in OD). Circulated at 4954 ft. Space out tubulars. Tested mechanical packer. Mar 30 1996 (13) Tested mechanical packer. RD tubing handling equipment. Held safety meeting. RD all functions. Installed Xmas tree. Tested all tree valves. Removed hanger plug. Tested mechanical packer. Freeze protect well - 60 bbl of diesel. Conducted slickline operations on slickline equipment - Retrival run. RD slickline unit. Freeze protect well - 200 bbl of diesel. Held safety meeting. Rig moved 0.05 %. Page 2 COMPANY S~ARED WELL NAME LOCATION~° a~,~ ~' 5002?22.{4 JOB BUMP. Erl 378iS REcEiVED NOV 2-/ 199B Oil & Gas 6ons. 6omm~Ssto~ AnChorage DEPTH DP?H ft ft ft 73,00 /3,0 /3JJO :¢u,O0 77,0 i50,00 200,0) 50& 200&O ft de~ cieq ft O, O0 O,:JO O, O0 O~ O0 -a.::i 0,i5 IR4,~ -0,i4 0:17 ~o, ~o ~ -- -O~i? 0,08 E7,63 -0,26 -0:i5 0,03 ,v~,~*"~ a~ -0,73_ DPARTURE ~' ...... ~ EI-W O,C,O 0,00 0:07 0,".:.,.,'"' n,r,~: 0,,23 ~. VJ O,Oi 0+26 0:04 0,23 AZIMUTH O,O0 1g7:47 i78,00 170:72 de~/ : U-'.J': i: "'J, 0(.: 'J ,. 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" i:'.Ji ,"J,. z,t, 4i ~.-.:.'7 ..-' m.,o: J ....... 4i,71 76i, 37 : ~ :.A. :q,~ 4i: 60 0150 VD; ?' , - r, ..... /o ii8017':' 4'. ;4A ::~r: .- , . .~ -'=.-':. , ~. 7454,47 7560~99 755q,51 7750,74 784.5,130 76~4 7207,42 ?6,2 :~ ~ '"'~ a 7573,Ag 1245,18 21&5 o~ ~ ~27.72 i277~76 ~ ...... o ~,iO o,',u~ ?65+65 1348,~q 21~06 36~73 i020,~%7 1382,34__,u:?~ "~ 2~=~9 ..... i048,46 ,.P, i c: -.0'', . ,.,,., i245:27 -::: ,~-'5 O,xr;, :. 660,01 i.'1513,54 %:90 0,5i '.;'00, '~2 ..... : ?,x.:, ~ ~,,., -:, C:, 67 0,2i ?74!,77 822?.--83 ~51:z ..:,: ?5,7 7662,99 98~5 7755,08 91,7 7840~92 97,7 7932~52 '?7~0 8023~$4 14i6~46 20,88 36.6/ 1075~97 isa~,3O 20,67 3b,8i 1104,14 ...... ~x g~ ii57, 1::ri.CO i?,77 := 0" ......::~4~ 721,23 14!6:':if 4(':, :i/' 0'~22 741~=-,,.~ ~ ~ 1451 .~ ?".) :ri,.... 47., 0,, .-.,- 760+i7 : :gR.. ::,q ~.~-'-.:. 'x: ,3 ~"' ......... ,. ,.~: . ?-89:?2 1!17 ~25 ~.:', ,':-.'7 O,:2i ~ :"...,:':, :'.', . 5;n.... ].150.~51 4;.::-,i..:.v,::" '"'"' ~423.--23 A5i7,47 ~4,2 8202~98 '74~i 829i.68 '~,0 8382~34 ?6,3 8473,32 i5830i? ~o o0 ...... i__ i6i4 .......... ~oi i?,57 ~,,~' iZ3/~56 IOqD~Yl 57~ ~o~m., i/Uo~i i~:c, 3i~06 9082,44 856i~/4 O0~7iJ,' 8826,90 8915,29 !764~72 i811£ 27,81 i367,87 i174~ii 16~73 28~25 1392,ii : ~-:.----:-,?. 9i ~4 9547,24 '73~7 ?i82~83 756!,8~ 34,7 9'215~82 i&,---' i -: 2iig,8i 24~0i i46.3,7:9 i 8':..-'A, A5 17+2a .... ' ....... ':'~ !723~72 i1-17© 22,6':.-" 1514-:ii l'.-;-'JJ.~ 81 ';:".-:-7 .... : ..... ~-'-:':<~ i <?'62,53 i/~ 87 22,73 '1551: '? GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10185 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 5/14/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Log Description Date BL RF Sepia Disk P2-20 ¢~_(5~c~ 96107 CDR 960326 I -~ I '~ 1 -'/'' ;~'7[00 P2-20 ~(~ (y~,'~' 96107 CDRTVD 960326 1 .~ 1 , ;ign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeOQuest irp 500 ,W. International (~rt Road Anchorage, AK. 99518-1199 ii'il. AITN: Sherrle '~:' NO. 10185 Company: Field: Well Job # Log Description Date BL Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Greater Point MclntYre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy RF Sepia Disk 5/14/96 p2-20 ~i'~ - G ~"~I' 96107 CDR ........ 960326 1 p2-20 ~,¢:,- ~-~-~ _ , 96,1. 07 CDR TVD 960326 ' I / I ""~ L_ .......... · .. sign and return one copy of this transmittal {o Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie no. 10151 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 4/26/96 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Well Job # Log Description Date BL Floppy RF Sepia Disk P2-20 ~TA~C PRESSURE SURVEY 960421 I 1 P2-20 u PERFORA~NG RECORD 960421 I 1 P2-20 G~CCLTIEIN LOG 960421 I I SIGNED' ;" "" '"" ~"' ";';" 'ase sign ~,,~le and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: - ! ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 13, 1996 Tim Schofield, Sr. Drlg. Eng. ARCO Alaska, Inc.. P O Box 196612 Anchorage, AK 99519-6612 R~e~ Point Mclntyre P2-20 ARCO Alaska, Inc. Permit No: 96-59' Sur. Loc. 50'SNL, 1239'EWL, Sec. 14, T12N, R14E, UM Btmhole Loc. 1518'NSL, 2576'WEL, Sec. 11, T12N, R14E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and dqes not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659~3607. J. David Norton, P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 53 fe et Point Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL Q2,~,~'4 .,~ ~ .¢ ¢" ~ ~ ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^AC 25.025) 50' SNL, 1239' EWL, SEC. 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 1349' NSL, 2439' EWL, SEC. 11, T12N, R14E P2-20 U-630610 At total depth 9. Approximate spud date Amount 1518' NSL, 2576' WEL, SEC. 11, T12N, R14E 03/15/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 365548 50 feet P2-21, 11.6' @ 700'MD feet 2560 9727'MD/9310'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 4080 feet Maximum hole angle23.s o Maximum sudace 3415 psig At total depth (TVD) 8852'/4350 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 9411 H-40 Weld 80' Surface Surface 80' 80' 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 4711 NT80S NSCC 5044' 41' 41' 5085' 5052' 1055 sx PF 'E', 375 sx 'G', 250 sx PF 'E' 8-1/2" 4-1/2" 12.611 13CR80 NSCT 4792' 4935' 4966' 9727' 9310' 928 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. 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 , ,, Intermediate Production ,. ,,, ,', ¢~, 'i ~I '~,"i;'ii '~'. i;'\~ \ Liner Perforation depth: measured '::': %'.:-,'. '.:...-~-.:,..: .. :,~ .:: :. t true vertical .' :'.' :, :~.- 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report• 20 AAC 25.050 requirements[] ~2,~1 hereby ce, d;ify th~at thee foregoing is true and correct to the best of my knowledge Signed /-~ ~__¢ ~;i~. Title Senior Drilling Engineer Date Commission Use Only Permit Number APl number Approval dante See cover letter ~' --~-'f/~ 5 0- Oz.. ~- ~ ~ ~ ~" ~" ~,~ / ! ~/¢~ for other requ rements Conditions o approval Samples required [] Yes ~ No Mud Icg requi'red ' []Yes ~No Hydrogen sulfide measures 'Ri Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOP6~i~i6~Y ~5M; []10M; []15M; Other: ~, David Nortorl, P. E, by order of Approved by Commissioner me commission . Form 10-401 Rev. 12-1-85 Submit ir I Well Name: ]P2-20 Well Plan Summary I Type of Well (producer or injector): [Producer Surface Location: 50' FNL, 1239' FWL, SEC 14 T12N, R14E Target Location: 1349' FSL, 2439 FWL, SEC 11, T12N, R14E Bottom Hole 1518' FSL, 2576' FEL, SEC 11, T12N, R14E Location: I AFE Number: 12C0092 I I Rig: l eoo~#7 I Estimated Start Date: I Ma~ ~5, 1996 I I Operating days to complete: 117 IMD: 19727' I ITVD: 19310' ] IKBE: 153.2, ] Well Design (conventional, slimhole, etc.): ]Monobore Formation Markers: (an depths feet RKB) Formation Tops MD TVD Base Permafrost 1789 1787 UG4A (K-15) 5178 5138 Lower Ugnu 6481 6332 West Sak 7162 6957 Minimum mud weight required: 9.5 ppg K-10 8818 8476 K-5 8883 8536 HRZ 9019 8660 Kalubik 9167 8796 Kuparuk 9183 8810 Minimum mud weight required: 10.0 ppg Miluveach -9627 9218 Casing/Tubing Program: (all depths feet RKB) Hole Csg/ Wt/Ft Grade Conn. Length Top Btm Size Tbg OD MDfrVD MD/TVD 30" 20" 94g H-40 WLD 80 GL 80/80 12 1/4" 9 5/8" 47# NT80S NSCC 5044 41/41 5085/5052 8 1/2" 4 1/2" 12.6# 13CR80 NSCT 4792 4935/4966 9727/9310 TBG 4 1/2" 12.6# 13CR80 NSCT 4895 40/40 4935/4966 P2-20 Well Plan Summary Page 2 Logging Program: Open Hole Logs: Surface Production Cased Hole Logs: mVVo MWD GR/Resistivity (From top of HRZ to TD) GR from West Sak to Kuparuk (MAD) GR/USIT/CET/CCL (optional) Mud Program: I Special Considerations [ 3% KCL mud through Kuparuk Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 Intermediate Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 50 20-40 15-20 20-30 9-10 4-6 Production Mud Properties: 3% KCL (open hole change over) Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8 to 8-15 25-30 5-15 10-20 9-10 4-6 10.2 HTHP<15 Well Control: Well control equipment consisting of 5000 psi WP pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional'. KOP: 4080'; nudge well to the southeast from 300' to 1600' Maximum Hole Angle: Close Approach Wells: 23.5° angle @ 39° azimuth P2-21 (producer): 11.6' @ 700'; shut-in to 1500' P2-58 (producer): 40.4' @ 2800'; shut, in to 3000'. 3/7/96~LW P2-20 Well Plan Summary Page 3 P2-20 Drilling Hazards/Risks Abnormal differential reservoir pressure are not expected in this well. Original reservoir pressure is 4350 psi at 8852' TVD. The most likely reservoir pressure is estimated at 4300 psi (9.5 ppg), but could range from 4250 to 4350 psi at 8852' TVD. P2-20 is offset by two producers and two injectors. The bottom hole location is approximately 1900' equidistant from producers P2-07 to the west and P2-31 to the east; and 1750' equidistant from injectors P2-16 to the north and P2-46 to the south. The well is approximately 300' north of a normal fault cutting the top of the Kupamk formation. It is believed the fault does not pose any drilling hazards. P2-21 and P2-58 are close approach wells and will be shut-in from spud until passing the shut-in zone. Well Control: Well control equipment consisting of 5000 psi WP pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, nOPE and mud fluid system schematics on fde with AOGCC. Contact: Larry Wolfson 564-5510 Adrian Clark 564-4720 3/7/96 .LW P2-20 Well Plan Summary Page 4 Operations Summary o . . . o o o ° 10. POST 11. MIRU drilling rig. NU and function test diverter. Spud well and drill 12 1/4" hole to 300' MD; nudge well to the southeast per attached directional plan. Drill to 4080'mkick-off and build angle to 23.5° inclination at 39° azimuth. Hold angle to 5085' MD surface hole TD. Run and cement 9 5/8" casing; perform top job. Test casing to 3000 psi for 10 minutes. Nipple up Bop's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. P/U 8 1/2" BHA, drill 10' new hole and perform LOT. Drill ahead holding tangent angle and azimuth to top of HRZ at 9019'. perform open-hole change over to 3% KC1 polymer mud at 10.0 ppg and drill to 9727'. Obtain LWD logs through Kupamk and MAD pass on trip out of hole. POH and stand back drill pipe. Run 4 1/2" NT-13Cr-80 liner and cement per attached cement program~displace with seawater. Bump plug and set liner top packer. Release and displace 9 5/8" casing to filtered seawater. Run dummy seal assembly and test the casing to 4000 psi for 30 minutes. Run 4 1/2" NT- 13Cr-80 tie-back string/completion assembly. Sting liner tieback seals into liner top. Test tubing and annulus to 4000 psi. Shear RP valve in top GLM. Displace tubing to diesel, U-tube to freeze protect the annulus. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Secure well, release rig. RIG WORK Replace RP valve with dummy or GLV as required. Perforate and flow test well. 3/7/96---LW VERTICAL VIEV SCALE 500 Ft. ! DIVISIEIq TVD RE}-.' 6qELI_~ VERTICAl_ SECTIEI4 REF'~ ~ 3~0 e i305 ~D ~I'~T ~ (LR~ e il~O/iOO f~ lid 8 1505 ~ I-I~Pi.. ~ (TM.E: N:RT1-D SCALE 1(30 Ft. / DIVISII3~ 8810 765 ~t9 i~38 N 1309 FYq,/ 1:3~)3.88 E Halliburton Travelling Cylinder Report Computed using WIN. CADDS REV2. I.B Page 1 Date: 2/28/96 Time: 11:12 pm Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Pt Mac: PM2 P2-20 1>2-20 Wp2 N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 3000.00 ft.(MD) Ail Directions using BP Highside Method in Dec.Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Enter Enter Well Safety Min. Safety Safety Shut-in Danger Clear Spread MD TVD Dist Dist Zone Zone MD MD P2-56 MWD 440.6 466.0 2050 2049 30.5 5.1 P2-41 MWD 229.5 244.5 1200 1199 18.0 3.0 P2-47 St-M P2-47 GIHR 361.9 370.7 700 700 10.5 1.8 1>2-35 GmR 146.3 175.4 2550 2549 35.5 6.4 1>2.37 Rig 229.9 239.9 800 800 12.0 2.0 P2-32a G-M 174.4 186.3 950 949 14.3 2.4 P2-50B MWD 411.4 422.7 900 899 13.5 2.2 P2-34 Fina 195.6 208.1 1000 999 15.0 2.5 P2-28 Rig 172.8 180.9 650 650 9.8 1.6 P2-60(13) 252.7 278.9 2150 2149 31.5 5.4 P2-59(09) 56.3 8-2.4 2150 2149 31.5 5.4 P2-~8(06) -20.5 10.5 2800 2799 38.0 7.0 1>2-57(10) 497.8 511.0 1050 1049 15.8 2.6 P2-55 336.9 363.4 2200 2199 32.0 5.5 P2-54 458.9 471.4 1000 999 15.0 2.5 P2-51 45.7 73.3 2350 2349 33.5 5.9 P2-49 254.4 275.0 1650 1649 '24.8 4.1 P2-48 Gyro 350.8 365.2 1150 1149 17.3 2.9 P2-46 304.9 322.4 1400 1399 21.0 3.5 P2-42 229.2 253.6 1950 1949 29.3 4.9 P2-31 119.5 144.5 2000 1999 30.0 5.0 P2-30 179.5 188.2 700 700 10.5 1.8 P2-29 131.0 148.5 1400 1399 21.0 3.5 P2-23 18.9 27.7 700 700 10.5 1.8 P2-21 -4.1 4.6 700 700 10.5 1.8 P2-18 17.3 22.9 450 450 6.7 1.1 P2-16 56.7 58.0 100 100 1.5 0.3 P2-15 70.0 71.2 100 100 1.5 0.3 P2-12 111.1 114.8 300 300 4.5 0.8 P2-07 186.2 190.6 350 350 5.2 0.9 P2-06 199.8 204.2 350 350 5.2 0.9 P2-35 MWD 147.9 176.6 2500 2499 35.0 6.2 ~r~ ~: V~'..;.-. ~93.~ -~.i 36~0 2799 40.0 Exit Exit Danger Shut-in Zone Zone MD MD 2750 2900 Close Approach Status OK OK OK OK OK OK OK OK OK OK OK SHUT-IN OK OK OK OK OK OK OK OK OK OK OK OK SHUT-IN OK OK OK OK OK OK OK P2-20 Cement Surface Casing I , Surface casing cement volume is based on open hole volume plus with 70% excess. _ 75 bbls ' Casing depth 5085 ft Spacer ! Fresh water Casing size 9.625 in ! Casing ID I 8.681~in LEAD (TYPE i'E' PERMAFROST) Casing weight i 47!lb/ft Volume i 1055 Sacks (2289 ft3)! __ (_4 0 8_ _b _b l s_) Bit diameter i 12.25 in Length ', 4297 ft Excess factor i 1.7! Yield i 2.17 ft3/sack Shoe track i 80ft Density 12 ppg , CIRC TEMP I 50 Deg F TOC40 ft MD Top of Lead 40 ft Mix water 11.55 gps 50° - 65° Fresh Top of Tail ! 4337 ft Thicken time 4 hrs I TAIL (Class 'G' + 2% CaCl2 accelerator ) i Volume 375 Sacks (431 ft3)J (77 bbls) i Length 748 ft ' _. I i Yield ! 1.15 ! , Density i 15.8 ppg _ i I TOC I 4337 ff __ ~1 ~1 Mix water . 5 gal/sk Fresh _ ! I Thicken time 3.5 hrs i i TOP JOB I (Type 'E' PERMAFROST) ~ _ i ~1 Volume 250 Sacks ft3/sac(lk 15 ft3) , (21 bbls) I Yield 2.17 I ! Density 12 ppg ~ I 11.55 gal/sk Fresh ~ ........... I Mix water I , Production Liner i i I Cement volume is based on bringing up cement to the shoe of the 9 5/8" casing string to prevent buckling of the liner after the well is put on production. Final volumes to be determine from actual casing setting depth. I 9727 ft ' Casing depth Spacer 70 bbls NSCl SPACER Casing size ! 4.5 in Casing ID i 3.9581in Slurry Class 'G' cement i I . i Casing weight i 12.6 Ib/ft ! 15 #/sk Silicalite Bit diameter i 9.75 in 0.3% CFR3 dispersant Excess factor i 1 0.8% HALAD 344 Fluid loss Shoe track 80 ft HR-5 (as required ) ClRC TEMP ] 140 Deg F Top of Cement il 5085 ft Volume [t 928 Sacks (1902 ft3) (339 bbls)_ ,i i Length I 4642 ft . ~ I Yield ~ 2.05 ft3/sack ,i I Density. !1 13.1 ppg ...... . ......... . ......... t. ..... _ ~i il TOO II 5085 ff MD 'i i Thicken time 13 1/2 to 4 1/2 hrs i',,"~i:,~ ~, '! ';'~":-~-~!..¢ ,.;, ;.',., WELL PERMIT CHECKLIST FIELD & POOL INIT CLASS ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... Y N Y N ~ N .~ N .~ N ~ N ~ N ~ N .~ N .~ N ~ N .7 N ~ N 4 ENGINEERING APPR DATE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y~_ N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.-~---N-- 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... N 26. BOPE press rating adequate; test to a 27. Choke manifold complies w/API RP-53 (M 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: DWJ JDN ~ -- Comments/Instructions: HOW/Ijb - A:~FORMS\cheklist rev 11/95 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2 - 20 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22664-00 REFERENCE NO : 96107 * ALASKA COMPUTING CENTER . ****************************** * ............................ ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NA~E : ARCO ALASKA, INC. WELL NAME : P2-20 FIELD NAME : POINT MCINTYRE BOROUGH · NORTH SLOPE STATE : ALASKA API NUM~ER : 50-029-22664-00 REFERENCE NO : 96107 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:±8 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/ 7 ORIGIN · FLIC REEL NAb!E : 96107 CONTINUATION # : PREVIOUS REEL : COt4MENT : ARCO ALASKA INC. , POINT MCINTYRE P2-20, API #50-029-22664-00 **** TAPE HEADER **** SERVICE NAbtE : EDIT DATE : 96/05/ 7 ORIGIN · FLIC TAPE NAME : 96107 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., POINT MCINTYRE P2-20, API #50-029-22664-00 TAPE HEADER POINT MCINTYRE MW/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 ......... 96107 DAb~iEYER T. JOHNSON WELL CASING RECORD 1ST STRING 2ND STRING P2-20 500292266400 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 7-MAY-96 BIT RUN 2 BIT RUN 3 14 12N 14E 50 1239 52.00 52.00 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 5077.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~8 3RD STRING PRODUCTION STRING Well drilled 24-MAR through 26-MAR-96 with CDR only. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NACRE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MAD 4967.0 MWD 7384.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 9455.0 9375.0 9348.0 9335.5 9319.0 9302.0 92 65.0 9215.0 9197.0 9188.5 9182.5 9168.5 9159.5 9152.0 9144.0 9140.5 9137.5 STOP DEPTH .......... 7384.0 9680.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD MWD 88889.5 9456.5 9375 0 9348 5 9337 5 9319 0 9302 5 9264 5 9214.0 9196.0 9188.5 9183.5 9169.0 9160.5 9151.5 9145.0 9142.0 9138.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:±8 PAGE: 9132.0 9130.0 9121.5 9116.5 9108.0 9099.0 9095.0 9075.0 9034.5 9027.5 8950.0 8945.0 8928.5 8902.0 8880.5 8860.5 8833.5 8828.5 5077.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 9132.5 9130.5 9122 0 9117 5 9108 5 9098 5 9094 5 9074 0 9034 0 9026.5 8948.0 8943.5 8927.5 8903.0 8881.0 8861.0 8834.0 8829.5 5077.0 BIT RUN NO. MERGE TOP MERGE BASE 1 4967.0 7384.0 1 7384.0 9680.0 The depth adjustments shown above reflect the MWD GR to the GR/CCL logged by SWS. Ail other MWD/MAD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~d PAGE: TYPE REPR CODE VALUE 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE ~ CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630368 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~M630368 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~4~630368 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~M630368 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4M630368 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~M630368 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630368 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630368 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630368 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHWL GAPI 630368 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9681.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 82.194 FET.MWD GR.MWD -999.250 GRCH. WL -999.250 DEPT. 9000.000 RA.MWD 2.491 RP.MWD 2.297 VRA.MWD VRP.MWD 2.338 DER.MWD 2.362 ROP.MWD 238.477 FET.MWD GR.MWD 141.698 GRCH. WL 66.438 DEPT. 8000.000 RA.MWD 1.740 RP.MWD 1.491 VRA.MWD VRP.MWD 1.418 DER.MWD 1.573 ROP.MWD 132.075 FET.MWD GR.MWD 99.625 GRCH. WL -999.250 DEPT. 7000.000 RA.MWD 3.934 RP.MWD 3.755 VRA.MWD VRP.MWD 3.765 DER.MWD 3.811 ROP.MWD -999.250 FET.MWD GR.MWD 71.584 GRCH. WL -999.250 DEPT. 6000.000 RA.MWD 2.164 RP.MWD 2.152 VRA.MWD VRP.MWD 2.159 DER.MWD 2.157 ROP.MWD -999.250 FET.MWD GR.MWD 45.910 GRCH. WL -999.250 -999.250 -999.250 2.690 0.344 1. 482 O. 614 3. 917 0.200 2.148 O. 008 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:xd PAGE: DEPT. 5000.000 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD 36.043 GRCH. WL -999.250 DEPT. 4966.000 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD 33.002 GRCH. WL -999.250 -999.250 -999.250 -999.250 -999.250 VRA . MWD FET.MWD VRA . MWD FET.MWD -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 2 EDITED~IERGEDMAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SU~ff~RY LDWG TOOL CODE $ MERGED DATA SOURCE LDWG TOOL CODE $ START DEPTH STOP DEPTH 4967.0 7384.0 MAD RUNNO. MAD PASS NO. MERGE TOP MERGE BASE REM_ARKS: Data obtained during washdownpass. LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:.~d PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API APIAPI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630368 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OH~M 630368 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD OH?4~ 630368 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD OH~M 630368 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD Otff~M630368 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD OHMM 630368 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 630368 O0 000 O0 0 2 1 1 4 68 0000000000 FET MAD HR 630368 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630368 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7384.617 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 127.497 FET. MAD GR.MAD -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~ PAGE: DEPT. 7000. 117 RA.MAD VRP. MAD 3.765 DER. MAD GR. MAD 71. 584 DEPT. 6000.117 RA.MAD VRP.MAD 2.159 DER.MAD GR.MAD 45.910 DEPT. 5000.117 RA.MAD VRP.MAD -999.250 DER.MAD GR.MAD 36.043 DEPT. 4966.117 RA.MAD VRP.MAD -999.250 DER.MAD GR.MAD 33.002 3.934 RP.MAD 3.755 3.811 ROP.MAD 7477.848 2.164 RP.MAD 2.152 2.157 ROP.MAD 940.982 -999.250 RP.MAD -999.250 -999.250 ROP.MAD -999.250 -999.250 RP.MAD -999.250 -999.250 ROP.MAD -999.250 VRA . MAD FET.MAD VRA.MAD FET.MAD VRA.MAD FET.MAD VRA . MAD FET.MAD 3. 917 0.200 2.148 0.008 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUM~ER: 1 MAD PASS N73MBER: 1 DEPTH INCREF~_2VT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH MAD 4967.0 STOP DEPTH 7384.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~ PAGE: $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH 88888.0 9455.0 9375.0 9348.0 9335.5 9319.0 9302.0 9265.0 9215.0 9197.0 9188.5 9182.5 9168.5 9159.5 9152.0 9144.0 9140.5 9137.5 9132.0 9130.0 9121.5 9116.5 9108.0 9099 0 9095 0 9075 0 9034 5 9027 5 8950 0 8945.0 8928.5 8902.0 8880.5 8860.5 8833.5 8828.5 5077.0 $ 88889.5 88889.5 9456.5 9456.5 9375.0 9375.0 9348.5 9348.5 9337.5 9337.5 9319.0 9319.0 9302.5 9302.5 9264.5 9264.5 9214.0 9214.0 9196.0 9196.0 9188.5 9188.5 9183.5 9183.5 9169.0 9169.0 9160.5 9160.5 9151.5 9151.5 9145.0 9145.0 9142.0 9142.0 9138.5 9138.5 9132.5 9132.5 9130.5 9130.5 9122.0 9122.0 9117.5 9117.5 9108.5 9108.5 9098.5 9098.5 9094.5 9094.5 9074.0 9074.0 9034.0 9034.0 9026.5 9026.5 8948.0 8948.0 8943.5 8943.5 8927.5 8927.5 8903.0 8903.0 8881.0 8881.0 8861.0 8861.0 8834.0 8834.0 8829.5 8829.5 5077.0 5077.0 88889.5 9456.5 9375.0 9348.5 9337.5 9319.0 9302.5 9264.5 9214.0 9196.0 9188.5 9183.5 9169.0 9160.5 9151.5 9145.0 9142.0 9138.5 9132.5 9130.5 9122.0 9117.5 9108.5 9098.5 9094.5 9074.0 9034.0 9026.5 8948.0 8943.5 8927.5 8903 0 8881 0 8861 0 8834 0 8829 5 5077 0 REMARKS: Data obtained during washdownpass. $ LIS FORMAT DATA 88889.5 9456.5 9375.0 9348.5 9337.5 9319.0 9302.5 9264.5 9214.0 9196.0 9188.5 9183.5 9169.0 9160.5 9151.5 9145.0 9142 0 9138 5 9132 5 9130 5 9122 0 9117 5 9108 5 9098.5 9094.5 9074.0 9034.0 9026.5 8948.0 8943.5 8927.5 8903.0 8881.0 8861.0 8834.0 8829.5 5077.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:.o PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630368 O0 000 O0 0 3 1 1 4 68 RA MAD Ot{M~ 630368 O0 000 O0 0 3 1 1 4 68 RP MAD OHMM 630368 O0 000 O0 0 3 1 1 4 68 VRA MAD OH~k4 630368 O0 000 O0 0 3 1 1 4 68 VRP MAD OH~k4 630368 O0 000 O0 0 3 1 1 4 68 DER MAD OH~4~ 630368 O0 000 O0 0 3 1 1 4 68 ROP MAD FPHR 630368 O0 000 O0 0 3 1 1 4 68 FET MAD HR 630368 O0 000 O0 0 3 1 i 4 68 GR MAD GAPI 630368 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 7384.617 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 127.497 FET.MAD GR.MAD -999.250 DEPT. 7000.117 RA.MAD 3.934 RP.MAD 3.755 VRA.MAD VRP.MAD 3.765 DER.MAD 3.811 ROP.MAD 7477.848 FET.MAD GR.MAD 71.584 DEPT. 6000.117 RA.MAD 2.164 RP.MAD 2.152 VRA.MAD VRP.MAD 2. 159 DER.MAD 2. 157 ROP.MAD 940. 982 FET. MAD GR.MAD 45. 910 -999.250 -999.250 3. 917 0.200 2.148 0.008 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~d PAGE: 10 DEPT. 5000.117 RA.MAD VRP.MAD -999.250 DER.MAD GR.MAD 36.043 DEPT. 4966.117 RA.MAD VRP.MAD -999.250 DER.MAD GR.MAD 33.002 -999.250 RP.MAD -999.250 -999.250 ROP.MAD -999.250 -999.250 RP.MAD -999.250 -999.250 ROP.MAD -999.250 VRA . MAD FET.MAD VRA . MAD FET. MAD -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE ' FLIC VERSION ' O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUPPLER Y VEuXrDOR TOOL CODE START DEPTH MWD 7313.0 $ LOG HEADER DATA DA TE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TItlE): STOP DEPTH 9680.0 26-MAR-96 FAST2.5 4. OC MEMORY LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 PAGE: TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIS/GR $ 9680.0 7313.0 9680.0 65 17.9 20.8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) TOOL NUMBER RGS022 8.500 5077.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : MUD PH : MUD CHLORIDES (PPM) : FLUID LOSS (C3): 3.6 RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 251 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 0.189 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 20000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 7384' - 9680' WASHDOWN 5077' TO 7162'@NORMAL TRIP SPEED WASHDOWN 7162' TO 7384'@900 FPH RES TO BIT: 60.65'; GR TO BIT: 71.07' TD WELL @ 13:35 26-MAR-96 CHLORIDES = 16K, K = 19K DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 70.0 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:-d PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 28 1 0.5 FT 36 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAIVE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630368 O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW1 OH3ff4630368 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW1 OH~M 630368 O0 000 O0 0 4 1 1 4 68 0000000000 DER LWl OH~ 630368 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW1 F/HR 630368 O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW1 HR 630368 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 630368 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. ROPE.LW1 9680. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 DER.LW1 82.194 TABR.LW1 -999.250 GR.LW1 -999.250 DEPT. 9000.000 ATR.LW1 2.404 PSR.LW1 2.196 DER.LW1 ROPE.LW1 235. 565 TABR.LW1 O. 339 GR. LW1 163 . 424 DEPT. 8000. 000 ATR. LW1 1. 868 PSR. LW1 1. 966 DER. LW1 ROPE.LWl 134. 005 TABR.LW1 O. 612 GR.LW1 93. 528 DEPT. 7000. 000 ATR. LW1 ROPE. LW1 5548. 835 TABR. LW1 3. 969 PSR.LW1 3. 730 DER.LW1 O. 196 GR. LW1 75. 348 -999. 250 2.266 1. 926 3. 803 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~ PAGE: 13 DEPT. 693 O. 000 ATR. LW1 ROPE. LW1 2063. 239 TABR. LW1 1.604 PSR.LW1 O . 007 GR. LW1 1.637 DER.LW1 56. 621 1. 623 ** END OF DATA ** **** FILE TRAILER **** FILE NAjVZE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1V-UI4~ER 5 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN ~ER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH MAD 4967.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~EMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) STOP DEPTH 7384.0 26-MAR-96 FAST 2.5 4. OC MEMORY 9680.0 4967.0 7384.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:,d PAGE: 14 MINIMUM ANGLE: MAXIMUM ANGLE: 21.0 28.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIS/GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: · MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0t~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): P~S: ************ RU/V 1 DRILLED INTERVAL 7384' - 9680' WASHDOWN 5077' TO 7162'@NORMAL TRIP SPEED WASHDOWN 7162' TO 7384'@900 FPH RES TO BIT: 60.65'; GR TO BIT: 71.07' TD WELL @ 13:35 26-MAR-96 CHLORIDES = 16K, K = 19K DATA FROM DOWNtIOLE FZE~ORY, V4. OC SOFTWARE $ LIS FORMAT DATA 20000 TOOL NUMBER RGS022 8.500 5077.0 LSND 10.20 3.6 O. 251 70.0 O. 189 70.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:~d PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 i 5 66 6 73 7 65 8 68 0.5 9 65 FT 1i 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFi~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 630368 O0 000 O0 0 5 1 1 4 ATR MAi OH~4 630368 O0 000 O0 0 5 1 1 4 PSR MAI OH~q 630368 O0 000 O0 0 5 1 1 4 DER MAi OH~4 630368 O0 000 O0 0 5 1 1 4 ROPE MA1 F/HR 630368 O0 000 O0 0 5 1 1 4 TABR MAi HR 630368 O0 000 O0 0 5 1 1 4 OR MAi GAPI 630368 O0 000 O0 0 5 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 7384.000 ATR.MA1 -999.250 PSR.MA1 ROPE.MAi 127.497 TABR.MA1 -999.250 GR.MA1 DEPT. 7000.000 ATR.MA1 3.969 PSR.MA1 ROPE.MAi 5548.835 TABR.MA1 0.196 GR.MA1 DEPT. 6000. 000 ATR.MA1 2. 164 PSR.MA1 ROPE.MAi 940. 982 TABR.MA1 O. 008 GR.MA1 DEPT. 5000. 000 ATR.MA1 O. 103 PSR.MA1 ROPE.MAi -999.250 TABR.MA1 -999.250 GR.MA1 -999.250 DER.MAI -999.250 3.730 DER.MAI 75.348 2.152 DER.MAI 45.910 20.203 DER.MAI 36.043 -999.250 3.803 2.157 0.105 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1996 15:,~ PAGE: 16 DEPT. 4966.000 ATR.MA1 -999.250 PSR.MA1 ROPE.MAi -999.250 TABR.MA1 -999.250 GR.MA1 -999.250 DER.MAi 33.002 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE . 96/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/05/ 7 ORIGIN : FLIC TAPE NAlViE : 96107 CONTINUATION # : 1 PREVIOUS TAPE : COf~fENT : ARCO ALASKA INC., POINT MCINTYRE P2-20, API #50-029-22664-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/05/ 7 ORIGIN : FLIC REEL NAME : 96107 CONTINUATION # : PREVIOUS REEL : CO~Z~fENT : ARCO ALASKA INC., POINT MCINTYRE P2-20, API #50-029-22664-00
