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Home My WebLink About201-246 ImÌ"--~ Project Well History File Cov~Dage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Ö L -d t.f (p Well History File Identifier Organizing (dolle} RESCAN o Two-Sided 1111111111111111111 DIGITAL DATA v/ o Rescan Needed 1111111111111 111111 OVERSIZED (Scannable) 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: o Diskettes. No. I Other. Norrype o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) NOTES: o Logs of various kinds BY: (MAR~ o Other DATE q Mot leJ VV1f 11111111111111" III DA"y./~/6'fSI lliP BY: 'e Project Proofing Scanning Preparation -e2. x 30 =&0 + aL = TOTAL PAGES ~ Lf BY: DA,,4/pþcr leJ V~ PAGE COUNT FROM SCANNED FILE: -4 //' . V p;J~ CjUNT MATCHES NUMBER IN SCANNING PREPARATION:7/r_--'-'- YES ~ DATE:; 'ÿof/sl IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES 9 ~ Production Scanning Stage 1 NO BY: Stage 2 NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAlITY . GRAYSCALE OR COLOR IMAGES) 1111111111111111111 ReScanned (ìmUvidual fugs !-r,peci.1I.1tlû/Hiol1) Hanni!!!] ¡;OmpIDled) 1111111111111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 ... :.. . ......,,~ ""..~. '. J,·.........·,'h,,.··...._·..··..·""- ',.' ,~.." . ",:,-. General Notes or Comments about this file: ,. Quality Checked (done) III 111111111" 11111 SCANNED JUL 1 5 2004 12/1 OI02Rev3NOTScanned. wpd . . 10.;\ .··r'··' .......-. .."'....'.'........ . ',",-,. .. I. ............ .... .... .. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ì Co J'J.- fI1 À () Q tJ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 1: ",--L S' ({j;7 ~ è Ú:L Permit to Dri 2012460 Well Name/No. KUPARUK RIV U MELT 2P-422 Operator CONOCOPHILLlPS ALASKA INC API o. 50-103-20400-00-00 MD 8853 ~ TVD 5969 ,r Completion Date 3/6/2002 --- Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey yes/ DATA INFORMATION Types Electric or Other Logs Run: GR, RES, NEU, DEN, PLATFORM EXPRESS (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Data Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 77 8798 Open 5/24/2002 ---ì 1 77 8798 Open 5/24/2002 I Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? y/(W Daily History Received? ~/N Chips Received? '-.,y-N.,. Formation Tops 'G/N Analysis ---Y.LbI-- Received? /I~ ----- )~ - tMl(~,~~ Comments: 1(J6K ~~ 1f\..LJ iVl1.... J).e'-\-! C'~.Ni ~~ ~ 'ì j)l.'> ) ¡a--?.~ t ''ì ,"-J J , - - -.............. , . (.. \),.11' t'î r/i.. ~ ~~ /A. v..A ;{~).- t-lG I À. -------- ~ Compliance Reviewed By: Date: ~~ ---( J -.... ~ àOJ-ðc..¡lç IO"ð51 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska May 08, 2002 RE: MWD Fonnation Evaluation Logs 2P-422, AK-MW-22017 1 LDWG fonnatted Disc with verification listing. API#: 50-103-20400-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 sq¡n~~ Date: RECEIVED r I ~, , . '; "~v r¡ ,~ 1)002 ,;,. L '; L Alaska Oil & Gas Cons.Commissfon Anchorage ,.-.... ~ PLuGGING & LOCATION CLEF_~_~CE REPORT State of Alaska AL.iUjXÃ OI:' . ~ C::::NSERVATION CCMMISSICN ?ern "0.;)0 (- ~t} b . :ease Af)L ~~ ð S-f;. :'cca.t:'cn :~!~c=~::¿~ .:,= ::":e:: :..:! ~·10. fiell. ~T2!ne Cperatcr SP~ci: d-' 5/0 2r Abnci Date 3 - &~ I 02. Completed. ~- (¿,...()~. Sfc C.iq: .~~ :'iner: Rev:"ew ~e well :::"le, - Cop.: rer= :":':erTa~s well head. cecie. W.l~ ;..ci ~~t Qf~: . W .. ><arke" '?oec or place. æ . :'cca:icn C:earance: c...cluaiozg. ¡¿td1dl KPJLar~·tf~;IIhJJ ~),-07 lð1- 20'-10'0- é) I Cede c¡ . ~ ~ Þs;J' Signed() flItftitVzb C-~~"\\~te . /5 Jj.pf!. ð¿ ,r-'\ ~ PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265·6830 Fax: (907) 265-6224 April 9, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-422 (201-246/302-082) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater we1l2P-422. If you have any questions regarding this matter, please contact Scott Lowry at 265-6869. Sincerely, \<--~~~ R. Thomas Greater Kuparuk Team Leader PAl Drilling RECEIVED RT/skad APR 9 2002 ~OII&GI&CoIII.QJnniseion AndIoIIge o F< I I~L STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION Cv,v1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r"" ~ 1. Status of well Classification of Service Well Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address Suspended 0 Abandoned 0 Service 0 P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface ~() 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM rc:#gttC'~~(ArSp, 444049 586897 ~Hi. H' i ,i.1eJl., í' 1.1,. I IT"'J ; . , þ-~,,,..,';;:.~. ~.*' At Top Producing Interval ,~ ¡I;.';":" ¡ 371' FNL, 62' FWL, Sec. 21, T8N, R7E, UM 1 3 'Z:::_~~H (ASP: 447282, 5864202) ~~:~~~~P~~O' FWL, Sec. 21, T8N, R7E, UM :..-A-' (ASP: 447427, 5863988) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 35 feet ADL 389058 & 373112 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp. Or Aband. February 5,2002 February 28,2002 March 6, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 8853' MD / 5969' TVD 2657' MD / 2274' TVD YES 0 No D -"""- . u, 7. Permit Number 201-246/ 302-082 8. API Number 50-103-20400-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2P-422 11. Field and Pool Kuparuk River Field Meltwater Pool 15. Water Depth, if offshore P&A'd N/A feet MSL 20. Depth where SSSV set N/A 16. No. of Completions o 21. Thickness of Permafrost 1495' (approx) feetMD 22. Type Electric or Other Logs Run GR/Res/Neu Dens, Platform Express 23. CASING SIZE 16" 7.625" WT. PER FT. 62.5# 29.7# GRADE B L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Surface 120' 42" 45 sx AS 1 Surface 2857' 9.875" 316 bbls AS3 Lite & 81 bbls LiteCRETE AMOUNT PULLED 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" kill string Plug #1: 8253' - 8853' Plug #2: 7653' - 8253' Plug #3: 2657' - 3257' TUBING RECORD DEPTH SET (MD) 1678' PACKER SET (MD) N/A None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Plug #1: 8253' - 8853' 155 sx Class G Plug #2: 7653' - 8253' 155 sx Class G Plug #3: 2657' - 3257' 189 sx Class G Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Abandoned Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO 27. Date First Production N/A Flow Tubing press. psi 28. Casing Pressure GAS-MCF WATER-BBL OIL GRAVITY - API (carr) 24-Hour Rate> CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED None APR .9 2002 AlaakaOU &Gas Cons. Commission Anchor8ge Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,...",., I ~ , Ii \.,j Submit in duplicate G( 29. 30/ GEOLOGIC MAR,,~"'¡S FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 8402' 5679' RECEIVED T-2 8628' 5823' APR 9 2002 AlalkaOil&Ga&ConI.Q1w1llliltlon AndøIge Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Scott Lowry 265-6869 Signed ~~~itle KUDaruk Drillina Team Leader Date tj~/ðL Randy Th mas Prepared by Sharon Allsup-Drake 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 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 (OF, 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 /--..... .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 1/27/2002 00:00 - 00:00 24.00 MOVE MOB MOVE Beg i n m 0 v e fro m D e a d h 0 r set 0 2 P Pad (M e I t water) at 1800 on 1/20/02. Move across PR B field with stops at BOC and J Pad. Blew t ire on drilling sub between the East and Cen tral channels of the Kuparuk River at 0500 0 n 1/21/02. Replace tire and continue movin g at 1930 on 1/21/02. Stop at Z Pad and th en continue to KOC. Wait 5 hours at KOC fo r Kuparuk crew changes. Continue moving w ith stops at CPF-2, 2M, and 2N. Arrive 2P a t 0800 on 1/23/02. Total of 62 hours from D eadhorse to 2P. Spot camp. Move drilling sub over well. Position pipe shed and pits. All modules spotted at 0230 on 1/24/02. In stall herculite under drilling sub and pit mo dule. Start rigging up equipment. Raise de rrick at 1500 on 1/25/02. Put rig on hi-line power. Prepare to scope up derrick. Found crack in weld on derrick board brace at 023 o on 1/26/02. Grind out and repair crack. Magnaflux repair job. Repairs complete at 1 800 on 1/26/02. Scope up and pin derrick a t 2200 on 1/26/02. Continue rigging up. St ring out cable for camp hi-line power. 24.00 MOVE MOB MOBMIR R U K e II y s pin n era n d 5 W i vel. H a n g k e II y h 0 se in derrick. Hose is too short. RD kelly hose. Run skate controls to rig floor. Insta II cement line. Work on new man rider syste m. RU flowline from sub to pits. RU drillin g console and run lines for instrumentation. RU new kelly hose. RU kill line. Switch c amp over to hi-line power at 2300. 2 Ad ditional Nabors hands arrived today. Expect ing more to arrive tomorrow. 10 people st aying at satellite camp. 17 people staying at construction camp. 24.00 MOVE MOB MOBMIR P / U K e II y S pin n e r & S w i vel tor i g f I 0 0 r tow a rm up. P/U and hang kelly hose. (Wrong len gth hose) remove hose from derrick. Run s kate controls to rig floor Hook-up interconn ects between Sub base & Pit modules Test Glycol System "OK" no leaks General Rig cl eanup in all areas At this time Nabors ha s 2 full drilling crews on the Rig. 11 - Stay ing in Sat Camp 26 - Staying in "Constru ction"Camp 24.00 MOVE MOB MOBMIR Con' t G e n era I R / U . P / U K e II y - M / U K e II y S pinner - torque conn - Install kelly drive bus hing and safety vavles torque conn Work on all interconnects between modules Spot an d set Ball Mill - Berm same At this time N abors has 2 full drilling crews working on Ri g 12- staying in Sat camp - 27 staying in c 1/28/2002 00:00 - 00:00 1/29/2002 00:00 - 00:00 1/30/2002 00:00 - 00:00 Printed: 4/3/2002 1 :05:04 PM /.--. .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 1/30/2002 24.00 MOVE MOB MOBMIR 00:00 - 00:00 1/31/2002 24.00 MOVE MOB MOBMIR 00:00 - 00:00 2/1/2002 2.00 DRILL RIRD SURFAC 00:00 - 02:00 02:00 - 12:00 10.00 WELCT SURFAC 12:00 - 13:00 13:00 - 14:00 1.00 WELCT 1.00 WELCT SURFAC SURFAC 14:00 - 17:00 3.00 WELCT SURFAC 17:00 - 20:00 20:00 - 00:00 3.00 WELCT 4.00 WELCT SURFAC SURFAC 2/2/2002 2.00 WELCT NUND SURFAC 00:00 - 02:00 02:00 - 04:00 2.00 WELCT NUND SURFAC 04:00 - 06:00 2.00 MOVE OTHR MOBMIR 06:00 - 07:00 1.00 WELCT OTHR SURFAC onstruction camp Spud meeting with both crews planned for Friday 1:00PM @ Constru ction camp Con't R/U Equipment Assemble all 4" HT38 tools on rig floor Finish cleaning & arrang e all subs and equip in pipe shed. Remove ju nk .Weather seal pipe shed. Con't cleaning all area's of rig. R/U Automatic driller. Ins pect Derrick(report generated). Slip 5 raps drill line onto drum. Qudco did inspection & calibration on Totco Weight indicator,RPMs guage,Torque indicator & torque censors.F ull report of inspection will be generated.Co pys will be made available. Spot injection s kid & 400 bbl diesel freeze protect tank in b erm. R/U Hard line to 2P-417 injection well Personell in Camps: Nabors has 2 full r ig crews at this time 12 - In Sat Camp 27 - In construction camp Rig Accept @ 0001 hrs 2/1/02 Test Mud Syste m wI Fresh Water - No leaks - Test run all c intf pums "OK" N/U Diverter System - Run test Mud Pumps wI Fresh water to 2000 psi "OK" Con't N/U Diverter system Spud Meeting wI Both Drill Crews & all Cont ractors Troq Annular,Mud X & Knife Valve wI Sween y troq tool N/U 80' 16" diverter line & torq all flanges Winterize Cellar and diverter line exit area - Plum 4" outlets on diverter riser - Work on control lines to knife valve "Note" Jam es Daughterty fell on stairs to parts cone x - bruised thigh Steve McCauly wire puncher to thum on wire wheel Did first aid and clea ned Nabors has 2 full drilling crews on I ocation Personell location: 12 - Sat Camp 27 - Construction camp N/U Diverter - Install turnbuckles,install ko omey lines to annular,R/U stabbing board R/U Diverter riser - Riser had wrong flange bolt hole pattern - Send back to welding sho p for repair Change out Rig Camps - Move Satolite camp out and spot at edge of ice pad. Bring 60 m an camp in an set in same location, set gray water tank & SDU unit. Move Sat. camp back and spot at right angle to end of 60 man. Make drawing of change and send to lounsba ry for drawing change Fuction test Diverter - Koomey failed to ope Printed: 4/3/2002 1 :05:04 PM ~. /--.\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 18:00 - 00:00 rate properly Koomey will not fuction properly - Mechanic worked on pressure regulator SURFAC Aft err e p air - Ins t a II d i v e r t err i s e r .. C h a n g e riser air boot.. Install F.N. 2.00 DRILL PULD SURFAC M 0 v i n g B H A e qui P to u P per pip e 5 h e d 3.00 RIGMNT RGRP SURFAC R e p air & R e p I u m a c cum u I at 0 r I e a k 1.50 DRILL PULD SURFAC S t ray and pre par e B HAt 0 P / U 1.50 WELCT OTHR SURFAC New ann u I a r pac k e r s t iff - W 0 r k & a c c u ate t o loosen - Attach ground wire to connductor SURFAC F u c t ion t est D i v e r t e r S y s t e m - K n if e val v e 0 pen 8 sec , Ann fully closed 47 sec **AOG CC John Spaulding waived witness test 5.00 DRILL DRLG SURFAC PI U B H A # 1 - Will P / U B H A " " NOT E "" W e a re waiting on the welder to finish thr cutting shute from the rig augher to the ball mill. ""NOTE"" After long hrs of rig move SPO( Kevin Adams) got up this morning with his I eft hand sore and a little swollen.He said it only has a small sore spoLWe will keep it u nder observation. When phase 3 conditions h aye passed he will All person ell has mov ed into 60 man camp. 4.00 DRILL PULD SURFAC P / U B H A # 1 - 0 r i e n t too I s - U P loa d M W D 1.00 DRILL PULD SURFAC P / U K e II y - Tag @ 9 8' R K B 13.00 WAlTON EOIP SURFAC Ins t a II s hut e to B a II Mill fro m cut tin g au g e r **NOTE"" - While waiting on welder crews: Winterized air leaks in rig Mechanic worke d on pipe shep Tiogo .. Heating better now. Worked on floor drain system Plum up kelly spinner hose 6.00 WAlTON WOW SURFAC Ph as e 3 con d i t ion - W a i ton we art her He I d P hase 3 safety meeting with crews & all contr actors NO DRIVING ANYWHERE.. The loade r must escort pickups from camp tp rig. Us e Cold Weather procedures.. Stay inside -If you must go outside us the "BUDDY SYSTEM " Only emergency outside work should be do ne. ""Special Note"" @ 4:30 PM It was expl ained to the Rig Supervisor that the generat or running the Ball Mill would be close if no t under powered to run as a "Stand Alone". Phillips had paid for a set of plugs to" wire up & plug in " to the standby. These plugs a rrived but were not complete. The toolpushe r thinks the plugs he needs are at Nabors 1 8E Electrician hard wiring Ball Mill power to Ri 9 electric bus. ""NOTE"" Ball Mill ready for operation @ 1600 hrs Phase 3 weather conditions - WOW Phase 3 weather conditions - WOW Spud Meeting w/ Crew & Contractors - Phase 09:00 - 10:00 10:00 - 12:00 12:00 - 15:00 15:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 .. 00:00 2/3/2002 00:00 - 04:00 04:00 - 05:00 05:00 - 18:00 2/4/2002 00:00 - 16:00 16.00 WAlTON EOIP SURFAC 16:00 - 00:00 8.00 WAlTON WOW SURFAC 00:00 - 12:00 12.00 WAlTON WOW SURFAC 12:00 - 13:00 1.00 DRILL SFTY SURFAC 2/5/2002 Printed: 4/3/2002 1 :05:04 PM /.. ~ " \ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3n/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/5/2002 12:00 - 13:00 13:00 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 22:00 22:00 - 22:30 2/6/2002 22:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 13:30 13:30 - 16:00 16:00 - 16:30 16:30 - 00:00 2/7/2002 00:00 - 12:00 1.00 DRILL SFTY SURFAC 5.00 DRILL OTHR SURFAC 0.50 RIGMNT RGRP SURFAC 0.50 DRILL OTHR SURFAC 0.50 DRILL RIRD SURFAC 1.00 DRILL REAM SURFAC 1.50 DRILL REAM SURFAC 0.50 DRILL DRLG SURFAC 0.50 RIGMNT RGRP 1.00 DRILL DRLG 0.50 DRILL DRLG 0.50 DRILL CIRC SURFAC SURFAC SURFAC SURFAC 1.50 RIGMNT RGRP SURFAC 0.50 RIGMNT RGRP SURFAC 0.50 DRILL DRLG SURFAC 1.00 DRILL CIRC SURFAC 1.00 DRILL PULD SURFAC 0.50 DRILL PULD SURFAC 3.50 DRILL DRLG SURFAC 0.50 RIGMNT RGRP SURFAC 0.50 DRILL CIRC SURFAC 3.00 DRILL CIRC SURFAC 2.50 RIGMNT RGRP SURFAC 0.50 DRILL CIRC SURFAC 7.50 DRILL DRLG SURFAC 12.00 DRILL DRLG SURFAC 3 lifted to Phase 2 - We can convoy trucks Clear Snow so equip can move around pad - Get cutting Truck driver to pad - Condition Rig after weather shutdown - C/O leaking 4 " conductor vavle Ajust Kelly hose - New Kelly hose ,had to aj ust the hang in the derrick TIH w/ MWD - Slowly TIH w/ MWD warming w ith steam after standing and exposed to cold during shut down. Up LOad MWD - Orient Directional Tools Tag @ 99' - Circu & C/O conductor "Note ** Brad Beaty reported that his knee was bu mped by rig tongs while making up kelly C/O Ice & CMT 99' to 120' MD Dir Drlg 120' to 137' MD - Cuttings au gar fai led Repair Cuttings Augar Dir Drlg 137' to 148' MD Drlg 148' to 178' MD Hole Fill - Pump Hi Vis Sweep & Circu hole c I e a n Boot on riser failed - C/O boot P/U Kelly - Break circu and check circu syst em for leaks "OK" Drlg 178' to 240' MD - 6' fill on connection - Getting wood & coal across shakers Pump Wt/Hi Vis sweep - Circu hole clean - L arge pieces of wood and coal in returns LID 4 jts of HWDP used for drilling in assy - P/U 3 flex DCs P/U 1 jt HWDP and wash to bttm - 4' fill Drlg 240' to 330' MD Traction motor on Mud Pump #2 running hot - Clean outside air vents of frost Circu hole clean - Run & Record PWD base I ine - Could not complete test - Ball Mill full Ball Mill full - Crew did not dispach vac truc k for cutting returns Pucks failed on #4 SCR - C/O pucks - Repai r spring lift on IR Run & Record PWD base line test - Power La w "Clean Hole" = 9.8 -9.9ppg ECD hard/in e = 10.8 - 10.9ppg Dir Drlg & Slide 330' - 669' MD (667' TV D) **Note** Brad Beaty bumped his knee whil e making a conn. Note was made on report 2 /5/02. He went to medic @ KOC. The medic suggested he see his personal doctor on day s off. Brad is going in today on his regular crew change. Dir Drlg & Slide 669' to 1221' MD (1210' TV D) ART 3.7 hrs , AST 2.5 hrs Printed: 4/3/2002 1:05:04 PM ./."~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/7/2002 12:00 - 19:00 19:00 - 21 :00 21 :00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 2/8/2002 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 13:00 13:00 - 17:30 17:30 - 00:00 2/9/2002 00:00 - 10:30 10:30 - 13:00 13:00 - 17:30 17:30 - 21 :00 21 :00 - 22:30 7.00 DRILL DRLG SURFAC 2.00 DRILL CIRC SURFAC 0.50 DRILL WIPR SURFAC 1.50 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 2.00 DRILL WIPR SURFAC 2.00 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 2.00 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 1.50 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 1.50 DRILL WIPR SURFAC 4.50 DRILL WIPR SURFAC 6.50 WELLS JAR SURFAC 10.50 FISH JAR SURFAC 2.50 DRILL PULD SURFAC 4.50 DRILL CIRC SURFAC 3.50 DRILL TRIP SURFAC 1.50 RIGMNT RGRP SURFAC Dir Drlg & Slide 1221" to 1505' MD (1467' T VD) ART 3.4 hrs ATS 1.3 hrs Pump Tandem sweeps -Pump 20 bbl Wt I Hi Vis sweep followed by 15 bbl Hi Vis Sweep - Circu hole clean - Total circu 7000 stks ( 7 07 bbls) Monitor well (Static) - Pump dry job - Blow down Kelly & Mud lines Wipertrip - Tight hole @ 983 P/U Kelly - Work tight hole @ 983' to 935' u ntil clean - TOH to 895' tight hole - P/U Kell y Break circu @ 935' - LID 1 jt HWDP - P/U K elly work tight hole @ 904' P/U Kelly @ 812' Ream tight hole - LID 2 jt s HWDP SIB Kelly - Pull 1 std & stand back in derric k - LID 1 jt HWDP -Tight P/U Kelly -Wash and ream - to 700' - String free - Pump sweeps -Circu hole clean Pump Out 11 jts to 313' - Circu hole clean Wash & Ream 17 jts HWDP back in hole to 8 57' Pump Hi Vis sweep - Circu hole clean - Blow dn & SIB Kelly TIH wI 4 stds HWDP - Tight @ 1210' P/U Kelly - Wash & Ream 1210' to 1310' - H ard Bridge @ 1310' String Stuck @ 1310' - Can not rotate or rec ip R/U head pin - Attempt to circu - No returns - Circu @ 5 spm I 500psi wI No returns - Ci rcu slowly 2-3 SPM to insure mud line does not freeze. - Jar on String - Work up to 50K overpull. No Movement "Note" Spoke wit h Weatherford rep (Chas Kidd) about rating of jars. He advised 200K max overpull. Spo ke with Team Leader about plan for jaring a nd pull rating It was decided to use 80% 0 f max on jars or 160K max overpull. Jar on String @ 1310' - Start at 50K overpul I and work up to 150K overpull. String movin g up slowly.- LID singles as they are worked out. String Free @ 10:30 AM (1243' MD)- P/U K elly - Pump Circu & Rotate to clean up hole - Circu up to 600 gpm I Rotate @ 100rpms - Circu hole clean Monitor well - Pump out of hole from 1284' t o 165' LID BHA - Dn Load MWD - LID Sperry Tools & Mud Motor Square sholder on motor stab hung on squar Printed: 4/3/2002 1 :05:04 PM o ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/9/2002 21 :00 - 22:30 22:30 - 00:00 2/10/2002 00:00 - 01 :00 01 :00 - 05:00 05:00 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 13:30 13:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 21 :00 2/11/2002 21 :00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 05:00 05:00 - 05:30 05:30 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00·17:30 17:30 - 19:00 19:00 - 21 :30 21 :30 - 22:30 22:30 - 00:00 1.50 RIGMNT RGRP SURFAC e end 0 f u P per r i 5 e r s e c t ion and pull e d it 0 u t. - Re install upper section of riser. 1.50 DRILL PULD SURFAC PI U H 0 I e 0 pen erA s s y .. Not e .. F I 00 r h a nd had small sliver of steel in toe. Removed and addministered fisrt aids 1.00 DRILL PULD PROD PI U H 0 ass y - LID 1 s t d 4" D P 0 u t 0 f d err i c k 4.00 DRILL REAM PROD 3.00 DRILL REAM PROD 1.50 DRILL TRIP PROD 1.00 RIGMNT RGRP PROD 1.00 DRILL TRIP PROD 0.50 DRILL REAM PROD 1.50 DRILL 3.00 DRILL TRIP PROD PULD PROD 0.50 DRILL 1.00 DRILL 1.00 DRILL PULD PROD TRIP PROD DRLG PROD 2.00 DRILL CIRC PROD 1.00 DRILL TRIP 1.00 DRILL PULD 1.00 DRILL PULD 0.50 RIGMNT RSRV 4.50 RIGMNT RGRP 0.50 DRILL TRIP 9.50 DRILL REAM PROD PROD PROD SURFAC SURFAC SURFAC SURFAC 1.50 DRILL CIRC SURFAC 0.50 DRILL 0.50 DRILL REAM SURFAC TRIP SURFAC 1.50 DRILL 2.50 DRILL 1.00 DRILL REAM SURFAC CIRC SURFAC TRIP SURFAC 1.50 DRILL CIRC SURFAC Wash & Ream dn 8 jts HWDP & Jars wI Kelly to 402' - Hit Bridge Attempt to ream thru Bridge - Work wt f/ 5-2 OK - Varied RPM's- Spudded lightly - Could not break thru Bridge SIB Kelly - blow dn Kelly - TOH - LID String Stab (DD thinks we may have been to stiff) CM Bullfeathers C/O air boot on flow riser TIH w I DCs & HWDP P/U Kelly - Attempt to Ream thru bridge· N o Progress - SIB Kelly and blow dn TOH - LID HO assy P/U BHA - P/U Mud Motor, bit, MWD and orie nt same Program MWD TIH to 402' wI Drlg assy - Hard bridge Drlg Bridge 402' to 407' - Bridge broke thru , work area until clear - Wash & Ream 407' t o 485' - Area clear - No torque - No overpull thru area. Pump Hi Vis sweeps - Circu - Rotate & Reci p until hole clean TOH wIDrig assy LID BHA - LID Motor,bit & MWD P/U HO assy Service Rig Repair Auger TIH to 414' Wash & Ream 414' to 1313' MD (tight 1257' thru 1313')work area until clear Pump Wt I Hi Vis sweeps - Rotate & Recip D P - Circu hole clean Wash & Ream 1313' -1416' Pull back up thru tight spot @ 1313' ( No Ov e r pull) Wash & Ream 1313' to 1505' (Bttm) Pump Wt I Hi Vis sweeps - Circu hole clean Attempt to TOH - Had over pull immediately if pumps not on. If pumps run @ 25-30 spm "No Overpull" YP 36-40 Vis 63-70 Wt 9.6 -9.7ppg Pump back to back sweeps - Circu holeclea n - Visit with Team Leader( Randy Thomas) t o discuss problems -Ajust Mud properties: " "Note"" 50-52 YP ,75-78 Vis 9.9 ppg Aft Printed: 4/3/2002 1 :05:04 PM ~. ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/11/2002 22:30 - 00:00 2/12/2002 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 08:30 08:30 - 12:00 2/13/2002 12:00 - 12:30 12:30 - 13:00 13:00 - 13:30 13:30 - 00:00 00:00 - 09:00 09:00 - 12:00 12:00 - 12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 00:00 2/14/2002 00:00 - 03:00 03:00 - 07:00 07:00 - 08:30 08:30 - 09:00 09:00 - 14:00 14:00 - 16:30 16:30 - 17:00 17:00 - 19:00 19:00 - 21:00 21 :00 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 2/15/2002 00:00 - 00:00 - 00:30 00:30 - 03:00 1.50 DRILL 1.50 DRILL 3.00 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 3.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 10.50 DRILL 9.00 DRILL 3.00 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 6.00 DRILL 3.00 DRILL 4.00 DRILL 1.50 DRILL 0.50 DRILL 5.00 DRILL 2.50 DRILL 0.50 DRILL 2.00 DRILL 2.00 CASE 1.50 CASE 0.50 CASE 0.50 CASE 0.50 CASE CASE 0.50 CASE 2.50 CASE CIRC CIRC TRIP TRIP TRIP TRIP TRIP REAM CIRC REAM DRLG DRLG SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC WIPR SURFAC REAM SURFAC WIPR SURFAC REAM SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC CIRC SURFAC TRIP OTHR PULD RURD RURD OTHR RURD SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC PUTB SURFAC er circu until these properties were achieve d the first 2 jts were worked out of the hole with 25-30K overpull - The remainder of the TOH overpull was minimal ,2-5K Circ and condition mud. Weight up to 9.9 P pg POOH LID stabilizer, setback flex collars, LID hol eopener M/U directional BHA, (P/U new motor) Orient and upload MWD RIH to 349', pulse test MWD, RIH, CBU @ 8 10' and 1179', tag up @ 1357' Wash and ream from 1357' to 1369' Perform PWD baseline test Wash and ream from 1369' to 1505' Drill from 1505' to 2015' Drill from 2015' to 2488'. AST=2.7, ART=2. 5, TVD=2179 Circ and condition mud Monitor well, blowdown and set back kelly Short trip out to 1273'. Pulled 15k to 35k 0 ver then reciprocate thru-OK RIH to 1537' tagged bridge Wash through bridge to 1601'-CBU RIH to 2447' Wash/ream 2447' to 2488'. Circ and pump s weep Drill from 2488' to 2730'. ART=3.8, AST=.3, TVD=2313' Drill from 2730' to 2878'. ART 1.6, AST .5, TVD 2402' Circ and condition mud. While circulating tr action motor on #2 Mud pump shorted out ca using small fire Short trip to 2225'-25k drag RIH wash 48' to bottom Circ 2 sweeps and condition mud. Monitor w ell and set back kelly POOH Down load MWD LID BHA R/U casers and hold safety meeting Work on stabbing board Change out 4" valve on conductor Changed over to sidedoor elevators because stabbing board wouldn't work P/U 7-5/8' 29.7# L-80 BTC-mod casing and R IH SURFAC RURD SURFAC C h a n g e 0 ute a sin gel e vat 0 r s RUNC SURFAC P / U s hoe j t . B L j t ., and coil a r j t . C h e c k f I 0 ats, RIH wI 7-5/8" surface casing to 1192' Printed: 4/3/2002 1 :05:04 PM ~. ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/15/2002 03:00 - 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 11 :00 11 :00 - 11 :30 11 :30 - 14:30 14:30 - 16:00 16:00 - 22:00 22:00 - 00:00 2/16/2002 00:00 - 00:30 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 18:00 2/17/2002 18:00 - 19:00 19:00 - 00:00 00:00 - 00:30 00:30 - 05:30 05:30 - 09:30 09:30 - 13:30 13:30 - 00:00 2/18/2002 00:00 - 09:30 09:30 - 21 :00 21 :00 - 00:00 2/19/2002 00:00 - 10:00 050 CASE CIRC SURFAC 2.00 CASE RUNC SURFAC 050 CASE 1.00 CASE 0.50 CASE 3.50 CASE CIRC RUNC RUNC CIRC SURFAC SURFAC SURFAC SURFAC 0.50 CEMEN SFTY SURFAC 3.00 CEMEN PUMP SURFAC 1.50 CEMEN PULD SURFAC 6.00 CASE NUND SURFAC 2.00 CASE NUND SURFAC 0.50 CASE 0.50 CASE 0.50 CASE 16.50 CASE 1.00 CASE 5.00 CASE 0.50 CASE 5.00 CASE NUND SURFAC NUND SURFAC NUND SURFAC NUND PROD NUND PROD NUND PROD NUND PROD NUND PROD 4.00 CASE NUND PROD 4.00 CASE NUND PROD 10.50 CASE NUND PROD 9.50 WELCT PROD 11.50 WELCT PROD 3.00 WELCT BOPE PROD 10.00 WELCT BOPE PROD Circ casing volume RIH w/ 7-5/8" casing, M/U TAM port collar,R IH to 2086' TITE Circ and work thru tite spot 2086' to 2346' Continue running 7-5/8" surface casing M/U casing hanger and landing jt Circ and condition mud @ 6 bpm while recipr ocating casing Safety meeting w/ crews, cementers and tru ck drivers M&P 5 bbl CW100-PT lines to 3500 psi-OK. M& P 75 bbl CW100. Drop bottom plug, M&P 50 bbl Mudpush XL @10.2, 316 bbl Lead @ 10.7,81 bbl Tail @ 12 ppg. Drop top lug an d pump 10 bbl water to clear lines. Displac e w/ 117 bbl mud wI rig pump. Bump plug a nd check floats. CIP @ 14:06 R/D cement head and LID landing jt. Wash out stack N/D diverter equipment Clean starting head and install casing/tubin g head Orient tubing head Set BOP stack on tubing head Set BOP and speed head on starting head Test metal to metal seal on speed head to 000 psi-OK. NU BOPE R/U test equipment Work on test pump and replace same Tighten flange on choke line Test annular to 250/3500 psi-no good. Repa ir leaks on mud cross. Tighten connection 0 n bell nipple. Tighten flanges on chokeline going to manifold Test annular to 250/3500. Test kill line to 4500 psi Test choke manifold to 250/4500 psi while r epairing leaks in bell nipple. Attempt to test top PRo Weep hole in door on driller's side leaking water and bonnet Ie aking hyd. fluid. Open door and prep for re p air Work on test pump and wait for parts Remove driller side bonnet of top Pipe Ram. Hydril rep replacing seal/packing. Replace door Function test rams. Test upper kelly cock 2 50-5000 psi. Attempt to test lower kelly coc k-failed. Change kelly cock. Prep to test u pper pipe rams and HCR valves Test BOP stack and floor valves to 250/500 o psi, annular to 250/3500 psi. Test witnes sed by John Crisp, AOGCC Printed: 4/3/2002 1 :05:04 PM .r---. . /...-.., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm @ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 10:00 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 17:00 17:00 - 23:00 2/20/2002 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 04:00 04:00 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 00:00 2/21/2002 00:00 - 07:30 07:30 - 08:30 08:30 - 20:00 20:00 - 21 :00 21 :00 - 23:00 2/22/2002 23:00 - 00:00 00:00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 13:30 2/23/2002 13:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 00:00 2/24/2002 00:00 - 01 :30 1.00 WELCT 0.50 WELCT 0.50 DRILL 1.00 DRILL 2.00 DRILL 2.00 DRILL 6.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 1 .50 DRI LL 1.50 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 1.50 DRILL 5.00 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 6.00 DRILL 7.50 DRILL 1.00 DRILL 11.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 12.00 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 10.50 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 20.00 DRILL 1.50 DRILL PULD PROD SURV PROD SURV PULD PULD PULD TRIP TRIP REAM CIRC DEOT PROD PROD PROD PROD PROD PROD PROD PROD PROD OTHR PROD CIRC PROD FIT PROD DEOT PROD DRLG PROD DRLG PROD CIRC PROD DRLG PROD WIPR PROD CIRC PROD WIPR PROD DRLG PROD CIRC PROD DRLG PROD CIRC PROD DRLG PROD CIRC PROD SURV PROD WIPR PROD WIPR PROD CIRC PROD DRLG PROD DRLG PROD R/D BOP test equipment. Set wearring M/U new saver sub on kelly M/U BHA Encounter ice plug @ 34.5', L/D BHA and P/ U 2 jts d.p and thaw plug wI steam P/U and orient BHA Test and trouble shoot MWD. P/U backup M WD Program MWD Upload MWD Safety meeting. Load sources in MWD Finish P/U BHA and test MWD RIH and rotate past port collar @ 982' RIH to 2725' Wash and ream. Tag at 2765' Circ and condition mud R/U and test casing to 2500 psi for 30 min- OK. R/D test equipment Drill float collar, shoe track, float shoe. CI ean out to 2878' and drill to 2895' Circ and condition mud. Displace contamina ted mud Perform FIT to 18.0 ppg EMW Perform PWD baseline test and check SPP/S P R 's Drill from 2895' to 3255'. ART=3.4, AST=.5 TVD=2615 Drill from 3255' to 3655'. ART=3.5, AST=.5, TVD=2855' Pump sweep @ 3593' Circ and condition mud to reduce ECD Drill from 3655' to 4226', Pump high vis sweep. Circ and condition m ud Observe well, Stand back kelly, and POOOH to shoe @ 2823' RIH to 4226'. P/U kelly and brk circ. No Drill from 4226' to 4890' (3603' TVD) AST=. 5 ART=7.5 Pump hi-vis weighted sweep and circ/conditi on hole Drill from 4890' to 4912' Pump hi-vis weighted sweep and circ/ condi dtion hole Drill from 4912' to 5333' (3856' TV D) Circ/condition mud Pump survey, monitor well POOH to 4226' RIH to 5332' CBU Drill from 5332' to 6091', AST=2.0, ART=8. 1, TVD=4296 Drill from 6059' to 6186'. Hole packed off Printed: 4/3/2002 1 :05:04 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/24/2002 01 :30 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 10:00 10:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 21 :30 2/25/2002 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :00 2/26/2002 01 :00 - 01 :30 01 :30 - 17:30 17:30 - 18:00 18:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 05:30 05:30 - 08:00 08:00 - 08:30 08:30 - 15:00 15:00 - 17:00 17:00 - 17:30 17:30 - 22:00 2/27/2002 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:30 04:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 1.50 DRILL CIRC 0.50 DRILL 0.50 DRILL 2.50 DRILL 0.50 DRILL TRIP CIRC CIRC SFTY PROD PROD PROD PROD PROD 1.50 DRILL WIPR PROD 1.50 DRILL 4.00 DRILL 1.00 DRILL 0.50 DRILL 6.00 DRILL OBSV WIPR REAM CIRC DRLG 1.00 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL TRIP CIRC REAM CIRC DRLG 0.50 DRILL 16.00 DRILL 0.50 DRILL 5.00 DRILL 0.50 DRILL 0.50 DRILL 5.50 DRILL 2.50 DRILL 0.50 DRILL 6.50 DRILL 2.00 DRILL REAM DRLG OTHR DRLG CIRC DRLG DRLG CIRC OBSV TRIP PULD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD 0.50 DRILL PULD PROD 4.50 WELCT BOPE PROD 1.00 WELCT 0.50 DRILL 0.50 DRILL 1.50 DRILL 1.50 DRILL BOPE OTHR PULD PULD PULD 1.50 DRILL TRIP 5.50 DRILL TRIP 1.00 DRILL CIRC 1.00 DRILL TRIP PROD PROD PROD PROD PROD PROD PROD PROD PROD Lost returns, pump out of hole to 6080'. No extra drag or torque. Pipe free Set one stand back R/U head pin and regain circulation P/U kelly and circ 3 bottoms up Hold safety meeting. Monitor well. Pump dr y job POOH to soe and monitor well. Well took co rrect fill. No excess drag Monitor well while servicing rig RIH to 5954' Wash and ream from 5954' to 6186' CBU Drill from 6186' to 6472'. Hole packed off a nd lost returns Single out of hole to 6334' Establish returns and CBU Wash/ream to 6472. Circ 20 bbl hi-vis sweep Drill from 6472' to 6487'. Off bottom pressu re inc. by 350 psi LID single and ream from6440' to 6487' Drill from 6487' to 7096' Clean mud pump screens Drill from 7096' to 7330' Circ and condition hole to dec ECD Drill from 7330' to 7362' Drill from 7362' to 7648' ( TVD 5224') Circ and condition mud Monitor well, Pump dry job, set kelly back POOH to BHA Download MWD and remove RA sources. Ser vice MWD LID bit and pony collar Pull wear ring, set test plug. Test all BOPE to 350/3500 psi Install wear ring Clear floor and blow down mud lines P/U bit and mud motor P/U BHA - Orient MWD to Motor Up Load MWD data - PJSM - Load RA Scorce s TIH to jars - C/O jars - New set Jars Sr# 14 00-1175 Con't TIH - Shallow test MWD @ Shoe "OK· - Con't TIH - Break Circu every 2000' - **No te** @ 7223' it was noted that the pipe displ acement for stds run was short. Toolpusher had driller CBU Break Circu -CBU - Break circu slowly - Slo wly work rate up to 6.5 BPM - Circu Total 34 00 stks Con't TIH - Kelly up @ 7595' - Wash to Bttm Printed: 4/3/2002 1 :05:04 PM ..-..... ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 2/27/2002 11 :00 - 12:00 12:00 - 23:00 23:00 - 23:30 23:30 - 00:00 2/28/2002 00:00 - 12:00 12:00 - 14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 19:00 19:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 3/1/2002 00:00 - 01 :30 01 :30 - 02:00 02:00 - 09:30 09:30 - 12:00 12:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 21 :30 21 :30 - 00:00 1.00 DRILL TRIP PROD 11.00 DRILL DRLG PROD 0.50 DRILL OTHR PROD 0.50 DRILL DRLG PROD 12.00 DRILL DRLG PROD 2.50 DRILL DRLG PROD 0.50 DRILL CIRC PROD 1.50 DRILL DRLG PROD 2.50 DRILL CIRC PROD 2.50 DRILL WIPR PROD 1.50 DRILL CIRC PROD 1.00 DRILL CIRC PROD 1.50 DRILL CIRC PROD 0.50 DRILL TRIP PROD 7.50 DRILL TRIP PROD 2.50 DRILL PULD PROD 2.50 DRILL PULD PROD 0.50 DRILL PULD PROD 0.50 DRILL PULD PROD 2.50 DRILL PULD PROD 1.00 DRILL TRIP PROD 0.50 DRILL SFTY PROD 2.00 LOG PULD PROD 2.50 LOG ELOG PROD 7595' to 7638' Dir Drlg & Slide 7638' to 8061' MD - ** Note ** Lost Hi Line Power Switch Rig & Camp over to Generators due o loss of Hi Line power Dir Drlg & Slide 8061' to 8080' MD ( 5482' T VD) ART 6.9 hrs AST O.Ohrs Dir Drlg & Slide 8080' to 8651' MD Dir Drlg & Slide 8651' to 8777' MD (Calulat ed T D) Pump HI Vis sweep- Circu Hole Clean - Drill ing Eng & Geoligist deciding "New Plan Forw ard" Town meeting **NOTE***We were directed by town to Drill ahead to 8853' MD ( 5967' TVD) This will pi ace the Nu Den tool @ 8751' MD (5902' TVD )per Steve Moothart request. Drlg from 877 7' to 8853' MD (5967' TVD) Pump Hi Vis sweep - Circu hole clean Wiper trip to 7500' - No Swab - No Excess d rag - No Tight hole P/U Kelly - Wash to Bttm - Circu BU- Stage pump rate up slowly to 74 SPM ** Note** On BU strokes had gas bubble - Cut Mud wt to 9.4ppg for 250 stks- Disipated afterward to nothing. Pump Hi Vis sweep - Circu hole clean - Visit with town about trip gas & possible increas e Trip margin Wt up Mud from 9.8 to 10.0ppg ( .2 ppg)for Trip Margin Monitor Well - Pump dry job - Blow dn Kelly & Mud lines TOH slowly - SLM - No Tight hole - No swab - No problems TOH - LID SWDP & Jars - LID Flex collars LID BHA -PJSM Remove RA scorces - Dn 10 ad MWD LID all BHA - LID Mud Motor & Bit Clean Rig floor - Remove all BHA & tools fro m rig floor & out of pipe shed P/U 42 jts 4" HT 38 DP out of shed TOH - Stand back 4" DP in derrick (DS pipe rack) This DP has been drifted wI 2.25" rabb i t PJSM with Rig crew & Schlumberger Wire Li ne Crew - Covered scope of task at hand & all know hazards R/U Wire Line - P/U Wire Line Tools Run #1 - Run CMR on E-line - Can not get to ols below 2200' - Work from 2100' to 2200' f or 2 hrs with no progress.**Note** Co Rep m ade town aware of progress @ 23:30 hrs. De Printed: 4/312002 1 :05:04 PM ~ '-". Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 3/1/2002 21 :30 - 00:00 3/2/2002 00:00 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 00:00 3/3/2002 00:00 - 01 :30 01 :30 - 02:30 02:30 - 04:00 04:00 - 11 :30 11 :30 - 15:00 15:00 - 18:00 18:00 - 00:00 3/4/2002 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:30 2.50 LOG 4.50 LOG 1 .50 LOG 2.00 LOG 0.50 LOG 15.50 LOG 1.50 LOG 1.00 LOG 1 .50 LOG 7.50 LOG 3.50 LOG 3.00 LOG 6.00 LOG 2.00 LOG 2.00 LOG 1.00 CEMEN 1.50 CEMEN ELOG PROD DLOG PROD PULD PROD SFTY PROD PULD PROD DLOG PROD DLOG PROD RURD PROD RURD PROD DLOG PROD DLOG PROD CI RC PROD DLOG PROD DLOG PULD PULD PULD PROD PROD PROD PROD 1.50 CEMEN PULD PROD 5.50 CEMEN TRIP PROD 3.50 CEMEN CIRC PROD 1.00 CEMEN PLUG PROD 1.00 CEMEN TRIP PROD 1.50 CEMEN CIRC PROD CIS Ion was made after conference call, to T OH and change configuation of tools. .. Not e .. Because of tripping off Hi line ( blown f use @ 2L pad) we were on generators from 4 :OOPM to 5:30PM (1.5 hrs)Rig & Both camps) TOH & Reconfigure tool (remove tool turners ) - TIH - Con't to attempt to Run CMR log on E-line - Still can not get tools worked belo w2210' RID CMR tools PJSM Schlumberger and Rig Crew - Discuss all hazards assoicated with task at hand "Dr ill Pipe Conveyed Logs"- RIU to Run NDT 10 g I drill pipe conveyed Surface Test NDT Tools "All OK" TIH slowly with DP conveyed NDT Logging to 01 - Circu BU @ Shoe and break circu every 1000' per Schlumberger request(keeps pin c onnector clear of dp dope).Max pump rate 3 bpm or 1000psi Come off and set on slips slowly - reduce all hard jolts possible to too Is. Drift all DP run wI 2.1875" drift TIH wI DP conveyed NDT log to 8221' P/U side entry sub M/U wet connection - Test NDT- Install line cl am p TIH we-line to latch - Run NDT logs - Attem pt 53 samples between 8487' to 8598' - Had all "seal failure" indication on shots TOH wI Logging tool E-Line after disconnect - LID Side entry sub Circu & Condition - Gas cut mud to surface - Wt cut to 9.4 ppg for 300 stks - Final circ u wt out & in 10.0ppg Monitor well "Static" - Pump dry job - TOH w I DP conveyed logging tools TOH wI DP conveyed NDT log LID NDT tools - RID Schlumberger Remove all GBR Csg tools from pipe shed Put 24 jts 2.0625 tbg & handling tools in pip e shed and up to rig floor P/U 731.10' of 2.0625 tbg (CMT Stinger) TIH wI CMT Stinger on 4" DP to 8853' Circu & COndition Mud - PJSM wI Rig Crew and all contractors - Discuss all Hazards of task at hand Pump CMT plug#1 - Pump 30.1 bbl 15.8# cl ass G +0.3% D06S + 0.2% D046 + 1.0% SO 01 - Addded 0.25 # I sx D029 (celoflake) Plu s 15% excess CIP 5:45PM TOH to 8245' Circu & Condition Printed: 4/3/2002 1 :05:04 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 3/412002 20:30 - 21 :00 3/5/2002 21 :00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 08:00 08:00 - 09:30 09:30 - 13:00 13:00 - 14:30 14:30 - 17:00 17:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 00:00 3/6/2002 00:00 - 04:30 04:30 - 05:00 05:00 - 09:30 09:30 - 14:00 0.50 CEMEN PLUG PROD 1.50 CEMEN TRIP 1.00 CEMEN CIRC 0.50 CEMEN TRIP 3.00 CEMEN TRIP PROD PROD PROD PROD 1.00 CEMEN TRIP PROD 1.00 CEMEN TRIP PROD 3.00 CEMEN TRIP PROD 1.50 CEMEN TRIP PROD 3.50 CEMEN TRIP PROD 1.50 CEMEN CIRC PROD 2.50 CEMEN TRIP PROD 0.50 CEMEN PLUG PROD 0.50 CEMEN TRIP PROD 1.00 CEMEN PLUG PROD 1.00 CEMEN TRIP 0.50 CEMEN CIRC 3.50 CEMEN TRIP PROD PROD PROD 4.50 ASAND ASANDN 0.50 ASAND 4.50 ASAND ASANDN ASANDN 4.50 ASAND ASANDN Pump CMT plug#2 - Pump 30.1 bbl 15.8# cl ass G +0.3% D065 + 0.2% D046 + 1.0% SO 01 - Addded 0.25 # I sx D029 (celoflake) Plu 515% excess CIP 9:00PM POH to 7140' Circu & Condition TOH LID DP WOC plug set @ 7653' -(While Waiting)TOH - LID 57 jts 4" HT38 DP WOC plug set @ 7653' -(While Waiting)TIH wI 19 stds 4" HT38 DP out of derrick WOC - (While waiting) TIH w I 4" HT 38 - 8 hr CMT time up @ 0500 - TIH to 7707' - CMT appears to be low &" green" - Decission ma de to wait 3 more hrs and then tag. Stand back 1 std dp - Pump drill string clea r - WOC @7600' TIH to Tag CMT - Tag up hard @ 7699' - Set 15K on plug per AOGCC rep request AOGC C rep Chuck Scheeve on location to witness tag. ( 161' CMT above Carin) Monitor well - Pump dry job - TOH laying dn drill pipe to 7600' Circu string clear - (While waiting Hold Pre- Spud for Grizzly well with ALL personell. Con't tripping out hole laying dn drill pipe Ck all jts for CMT residue) All look clean Spot Viscuss plug @ 3457' - 3257' (200') TOH to 3257' Set #3 17.0 ppg plug ( KO plug )- 3257' bac k to 2657' (600' 1200' above 7 5/8" shoe & 400 ' below shoe ( Pumped 27.2 bbls Class G wI 0.09gps D185 = 0.2% D046 + 2.0% SOO 1 -Add 4.5 #/bbl Dowell Nylon fiber (Calcula ted TOC 2657') TOH to 2577' Circu String Clean TOH laying dn 4" DP UNote" Fork Driver shut tool box lid on index finger. Red mark on middle finger nail. right hand UNote" H ad Ambulance pick up Cook complaining of c hest pains. After talking and discribing pati ance's comments medic at KOC sent out Am bulance. Cook reported back that a full batt ery of test were run "No problems found by Medic's. He is back at work Con't TOH Laying dn 4" DP - LID CMT Stinge r Pull wear bushing Clean all pipe & equip off floor and out of p ipe shed. RIU Tbg tools - PIU 7 Run 54 jts 3 1/2" 9.3 # L-80 ISTM Tbg for Kill string I Freeze pro Printed: 4/3/2002 1 :05:04 PM ~. /"""'--\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-422 2P-422 ROT - DRILLING naborscm@ppco.com Nabors 19E Start: 1/21/2002 Rig Release: 3/7/2002 Rig Number: Spud Date: 1/25/2002 End: Group: 16:30 - 17:30 17:30 - 18:30 t e c t D ABANDN M I U T b g H an g e r & Lan din g j t - D r a in BOP s - Land Tbg ABANDN Clean BOPs & Cellar Area ABANDN B low d n c h 0 k e I i n e , kill I i n e and a II c i r c u s y s tem in cellar 5.50 ABAND NUND ABANDN N I D BOP san d set b a c k 0 n t ran s p 0 r t s t u m p 4.00 CMPLTNNUND MOBMIR N/U & Orient Tree 0.50 CMPLTNSEOT MOBMIR Test Hanger & Adspter to 5K "OK" 0.50 CMPLTNSEOT MOBMIR Test Tree - Fill and test tree to 5K 1.00 CMPLTNNUND MOBMIR Pull 2 way ck and R/U to test csg 0.50 CMPLTNDEOT MOBMIR Test Csg & Plug per AOGCC request - AOGC C request to test to 16.0 EMW - Applied 709 psi @ surface wI 10.0ppg mud -TOC plug 22 7 3' T V D " H e I d 30m in 0 n c h art Bleed off psi - RID test hoses R/U to Freeze protect well Pump 70 bbls diesel dn 7 5/8' X 3 1/2" annul as Put Tbg & Ann in communication and let U-T ube RID Hoses - Secure well - Clean cellar "" N ote"" Rig Released 1600 hrs 3/7102 ""Not e"" SP~ received a small cut from grinded 0 n left wrist. Medic cleaned and dressed wou n d. 14:00 - 16:30 3/7/2002 18:30 - 00:00 00:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 07:00 0.50 CMPL TN NUND MOBMIR 07:00 - 08:00 1.00 CMPL TN FRZP MOBMIR 08:00 - 09:00 1.00 CMPL TN FRZP MOBMIR 09:00 - 12:00 3.00 CMPL TN FRZP MOBMIR 12:00 - 16:00 4.00 CMPL TN RURD MOBMIR Printed: 4/3/2002 1 :05:04 PM ~ AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 .~ Definitive Re: Distribution of Survey Data for Well 2P-422 dO/~aLj f.Q Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 8,853.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE'VED .,.1 .~. G I)L 0 "L' OO? \ ~f"\t \ - AlaskaOU&GasCons.commi8s\on Ancboraøe 14-Mar-02 t~rrJY~ ') Kuparuk River Unit North Slope, Alaska Kuparuk 2P, Slot 2P-422 2P-422 Job No. AKMW22017, Surveyed: 28 February, 2002 ~- SURVEY REPORT 14 March, 2002 ) Survey Ref: svy9845 W) Your Ref: 501032040000 Surface Coordinates: 5868975.44 N, 444049.42 E (70003' 09.6641- N, 150026' 51.9006- Kelly Bushing: 258. 70ft above Mean Sea Level !5J::I1!!..........y-Sl..Jr1 SERVices A Halliburton Company Sperry-Sun Drilling Services e Survey Report for 2P-422 Your Ref: 501032040000 DEF'~\. , I "f:. Job No. AKMW22017, Surveyed: 28 February, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) ) 0.00 0.000 0.000 -258.70 0.00 0.00 N 0.00 E 5868975.44 N 444049.42 E 0.00 MWD Magnetic 120.00 0.000 0.000 -138.70 120.00 0.00 N O.OOE 5868975.44 N 444049.42 E 0.000 0.00 197.80 0.180 242.590 -60.90 197.80 0.068 0.11 W 5868975.38 N 444049.31 E 0.231 -0.02 230.04 0.220 204.840 -28.66 230.04 0.148 0.18W 5868975.31 N 444049.24 E 0.418 0.Q1 260.74 0.210 274.460 2.04 260.74 0.188 0.26W 5868975.26 N 444049.16 E 0.800 0.00 332.20 0.940 163.090 73.50 332.20 0.748 0.22W 5868974.71 N 444049.19 E 1.449 0.48 384.99 3.530 153.480 126.24 384.94 2.60S 0.63E 5868972.83 N 444050.03 E 4.940 2.50 415.72 4.380 152.290 156.90 415.60 4.49 8 1.60 E 5868970.94 N 444050.99 E 2.779 4.61 508.66 4.950 155.980 249.53 508.23 11.29 8 4.88E 5868964.11 N 444054.22 E 0.693 12.07 599.27 6.420 148.790 339.69 598.39 19.208 9.10 E 5868956.18 N 444058.38 E 1.800 20.97 691.91 7.230 148.740 431.68 690.38 28.61 8 14.81 E 5868946.72 N 444064.02 E 0.874 31.96 783.77 9.230 146.160 522.59 781.29 39.67 8 21.91 E 5868935.61 N 444071.04 E 2.213 45.10 875.91 10.820 145.520 613.32 872.02 52.94 8 30.92 E 5868922.27 N 444079.95 E 1.730 61.14 970.87 12.590 146.130 706.30 965.00 68.88 8 41.74 E 5868906.25 N 444090.65 E 1.868 80.41 1061.94 15.920 146.660 794.55 1053.25 87.56 8 54.14 E 5868887.48 N 444102.91 E 3.659 102.82 1154.49 19.900 147.290 882.60 1141.30 111.438 69.63 E 5868863.50 N 444118.23 E 4.305 131.27 ) 1249.80 20.400 148.460 972.08 1230.78 139.24 8 87.09 E 5868835.57 N 444135.48 E 0.674 164.07 1343.91 20.580 146.850 1060.23 1318.93 167.06 S 104.71 E 5868807.61 N 444152.90 E 0.629 196.99 1441.71 23.380 145.810 1150.91 1409.61 197.51 8 125.02 E 5868777.01 N 444172.98 E 2.890 233.58 1534.38 26.560 143.920 1234.91 1493.61 229.47 8 147.56 E 5868744.89 N 444195.29 E 3.537 272.69 1629.46 29.080 143.590 1319.00 1577. 70 265.26 S 173.80 E 5868708.92 N 444221.26 E 2.655 317.04 1724.86 31.720 143.940 1401.27 1659.97 304.198 202.32 E 5868669.77 N 444249.50 E 2.774 365.29 1820.70 35.510 142.370 1481.07 1739.77 346.62 S 234.16 E 5868627.11 N 444281.03 E 4.057 418.29 1916.40 39.130 145.430 1557.17 1815.87 393.52 S 268.28 E 5868579.96 N 444314.80 E 4.249 476.26 2011.39 43.420 145.510 1628.55 1887.25 445.138 303.79 E 5868528.09 N 444349.93 E 4.517 538.91 2106.49 47.340 145.300 1695.33 1954.03 500.84 S 342.22 E 5868472.10 N 444387.95 E 4.125 606.59 2200.83 51.130 146.050 1756.92 2015.62 559.84 8 382.49 E 5868412.80 N 444427.79 E 4.062 678.03 2296.17 55.070 146.740 1814.16 2072.86 623.34 S 424.67 E 5868349.00 N 444469.50 E 4.173 754.24 2395.91 56.550 144.770 1870.21 2128.91 691.528 471.10 E 5868280.47 N 444515.43 E 2.207 836.73 2484.31 56.520 144.800 1918.95 2177.65 751.778 513.62 E 5868219.91 N 444557.51 E 0.044 910.47 - ..~----_._-- 14 March, 2002 - 16:35 Page 20'6 DrillQllest 2.00.08.005 I) Sperry-Sun Drilling Services Survey Report for 2P-422 Your Ref: 501032040000 Job No. AKMW22017, Surveyed: 28 Fe North Slope, Alaska Kuparuk 2P bruary, 2002 Vertical Section Dogleg Rate (0/100ft) Global Coordinates Northlngs Eastlngs (ft) (ft) Coordinates Eastlngs (ft) Loca Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. Kuparuk River Unit Incl Measured Depth (ft) ) Comment 990.03 1016.09 1095.02 1172.51 1255.57 0.509 3.143 1.510 1.532 1.304 444603.16 E 444617.98 E 444661.92 E 444705.30 E 444751.58 E 5868154.74 N 5868133.31 N 5868067.75 N 5868003.53 N 5867934.57 N 559.75 E 574.73 E 619.15 E 663.01 E 709.79 E 816.61 5 837.94 5 903.175 967.07 5 1035.695 2230.58 2247.96 2301.85 2357.45 2417.46 1971.88 1989.26 2043.15 2098.75 2158.76 144.340 145.510 145.980 145.090 146.330 56.220 56.370 54.980 53.710 54.590 2579.87 2611.20 2706.77 2802.15 2904.62 1333.98 1412.42 1491.42 1569.23 1645.27 1.888 1.524 2.181 2.143 2.056 444795.69 E 444839.97 E 444885.02 E 444929.63 E 444972.03 E 5867869.73 N 5867804.99 N 5867740.09 N 5867676.31 N 5867613.19 N 754.37 E 799.13 E 844.65 E 889.73 E 932.59 E 1100.205 1164.61 5 1229.185 1292.63 5 1355.44 5 2472.33 2525.82 2579.76 2634.70 2691.56 2213.63 2267.12 2321.06 2376.00 2432.86 144.390 146.020 143.600 145.630 145.750 55.450 55.980 55.380 54.190 52.240 3000.33 3095.27 3190.94 3286.21 3381.16 1720.83 1795.94 1874.04 1951.82 2027.56 1.024 1.179 2.365 1.596 2.261 445013.74 E 445054.43 E 445097.76 E 445141.33 E 445183.48 E 5867550.18 N 5867487.03 N 5867422.04 N 5867357.62 N 5867294.68 N 974.77 E 1015.91 E 1059.72 E 1103.77 E 1146.37 E 1418.135 1480.98 5 1545.65 5 1609.755 1672.38 S 2749.22 2804.76 2860.67 2915.86 2971.92 2490.52 2546.06 2601.97 2657.16 2713.22 146.390 147.180 144.610 146.400 145.130 53.070 53.970 54.860 54.430 52.560 3476.21 3569.64 3665.70 3761.07 3855.31 ) 2100.64 2176.75 2247.74 2321.04 2395.16 0.692 1.950 0.829 0.797 2.299 445225.21 E 445269.11 E 445310.31 E 445352.56 E 445395.63 E 5867234.69 N 5867172.50 N 5867114.66 N 5867054.75 N 5866994.40 N 1188.54 E 1232.91 E 1274.52 E 1317.21 E 1360.73 E 1732.07 5 1793.94 5 1851.46 S 1911.065 1971.105 3028.13 3088.99 3148.44 3210.33 3270.67 2769.43 2830.29 2889.74 2951.63 3011.97 144.390 144.320 143.910 144.860 143.290 52.310 50.410 49.710 49.950 51.780 3947.51 4044.98 4137.59 4233.53 4329.13 2472.07 2548.71 2624.69 2700.67 2777.82 2.752 1.374 1.301 2.116 0.558 445439.95 E 445483.79 E 445527.29 E 445571.30 E 445617.02 E 5866931.52 N 5866868.65 N 5866806.34 N 5866744.39 N 5866682.18 N 1405.51 E 1449.80 E 1493.76 E 1538.22 E 1584.40 E 2033.65 5 2096.20 5 2158.18 S 2219.81 5 2281.695 3329.11 3385.03 3440.21 3495.66 3552.02 3070.41 3126.33 3181.51 3236.96 3293.32 145.490 143.900 145.410 142.970 143.560 53.780 54.000 54.030 53.750 53.990 4425.75 4520.63 4614.54 4708.62 4804.21 2854.28 2931.80 3009.95 3089.03 3143.94 1.556 2.269 0.424 0.902 1.926 445662.85 E 445708.80 E 445753.95 E 445799.24 E 445830.79 E 5866620.86 N 5866558.37 N 5866494.55 N 5866429.71 N 5866384.77 N 1630.68 E 1677.09 E 1722.71 E 1768.47 E 1800.35 E 2342.66 5 2404.82 S 2468.30 5 2532.81 5 2577.52 5 3606.85 3660.74 3714.50 3769.56 3807.49 3348.15 3402.04 3455.80 3510.86 3548.79 142.050 144.440 144.160 145.140 143.880 54.790 55.650 55.320 54.990 55.750 4898.37 4992.83 5087.70 5184.07 5250.81 DrillQllest 2.00.08.005 Page 3 0'6 16:35 14 March, 2002 ) ) Sperry-Sun Drilling Services e Survey Report for 2P-422 Your Ref: 501032040000 Job No. AKMW22017, Surveyed: 28 February, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eaatlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5341.92 54.030 144.370 3601.19 3859.89 2637.91 S 1844.03 E 5866324.06 N 445874.02 E 1.938 3218.45 5437.41 54.380 147.280 3657.04 3915.74 2701.98 S 1887.53 E 5866259.67 N 445917.05 E 2.499 3295.89 5533.88 54.600 147.940 3713.08 3971.78 2768.29 S 1929.59 E 5866193.05 N 445958.62 E 0.602 3374.36 5627.61 55.060 148.370 3767.07 4025.77 2833.37 S 1970.02 E 5866127.67 N 445998.57 E 0.618 3450.89 5721.63 54.800 146.970 3821.09 4079.79 2898.39 S 2011.17E 5866062.35 N 446039.24 E 1.250 3527.78 5815.98 54.190 146.520 3875.89 4134.59 2962.62 S 2053.28 E 5865997.82 N 446080.89 E 0.754 3604.57 5910.85 54.970 147.550 3930.87 4189.57 3027.49 S 2095.35 E 5865932.64 N 446122.47 E 1.208 3681.85 6004.93 55.080 147.290 3984.80 4243.50 3092.44 S 2136.86 E 5865867.38 N 446163.50 E 0.255 3758.90 6098.71 53.070 144.830 4039.83 4298.53 3155.45 S 2179.23 E 5865804.07 N 446205.41 E 3.017 3834.82 6195.63 53.570 146.330 4097.72 4356.42 3219.57 S 2223.16 E 5865739.63 N 446248.87 E 1.344 3912.55 6293.34 53.820 146.940 4155.57 4414.27 3285.33 S 2266.47 E 5865673.55 N 446291.69 E 0.564 3991.27 6385.40 54.580 144.770 4209.43 4468.13 3347.11 S 2308.38 E 5865611.46 N 446333.15 E 2.082 4065.93 6482.08 54.160 147.600 4265.76 4524.46 3412.39 S 2352.11 E 5865545.87 N 446376.40 E 2.418 4144.49 6513.99 54.400 146.950 4284.39 4543.09 3434.18 S 2366.11 E 5865523.97 N 446390.24 E 1.817 4170.38 6609.99 52.260 144.850 4341.72 4600.42 3497.95 S 2409.26 E 5865459.89 N 446432.92 E 2.837 4247.37 6704.78 52.400 144.010 4399.65 4658.35 3558.97 S 2452.90 E 5865398.54 N 446476.11 E 0.717 4322.39 6800.06 53.010 143.900 4457.38 4716.08 3620.26 S 2497.51 E 5865336.93 N 446520.26 E 0.647 4398.16 6894.83 53.590 144.590 4514.02 4772.72 3681.92 S 2541.90 E 5865274.94 N 446564.21 E 0.846 4474.12 6985.46 53.650 145.880 4567.77 4826.47 3741.86 S 2583.51 E 5865214.70 N 446605.37 E 1.148 4547.09 7085.83 52.570 145.420 4628.02 4886.72 3808.14 S 2628.80 E 5865148.09 N 446650.17 E 1.137 4627.36 7180.91 52.070 146.340 4686.14 4944.84 3870.43 S 2671.01 E 5865085.49 N 446691.93 E 0.929 4702.60 7276.48 52.630 145.970 4744.52 5003.22 3933.28 S 2713.15 E 5865022.34 N 446733.61 E 0.661 4778.27 7372.59 52.970 146.610 4802.63 5061.33 3996.96 S 2755.64 E 5864958.35 N 446775.62 E 0.638 4854.81 7468.49 53.650 146.880 4859.93 5118.63 4061.27 S 2797.81 E 5864893.73 N 446817.32 E 0.744 4931.69 7530.75 53.980 146.190 4896.69 5155.39 4103.19 S 2825.52 E 5864851.61 N 446844.72 E 1.040 4981.94 7623.64 54.340 145.840 4951.07 5209.77 4165.63 S 2867.61 E 5864788.86 N 446886.35 E 0.493 5057.23 7718.72 54.390 146.860 5006.47 5265.17 4229.95 S 291Q.43 E 5864724.22 N 446928.70 E 0.873 5134.50 77!:jO.22 54.500 145.920 5024.79 5283.49 4251.29 S 2924.61 E 5864702.78 N 446942.73 E 2.453 5160.12 7845.33 53.220 145.000 5080.88 5339.58 4314.56 S 2968.16 E 5864639.19 N 446985.80 E 1.556 5236.93 7940.89 52.780 144.970 5138.39 5397.09 4377.07 S 3011.95 E 5864576.37 N 447029.13 E 0.461 5313.24 .-..--------- 14 March, 2002 - 16:35 Page 4 0'6 DriflQllest 2.00.08.005 e '~,~'.1~·'. Sperry-Sun Drilling Services" Survey Report for 2P-422 Your Ref: 501032040000 Job No. AKMW22017, Surveyed: 28 February, 2002 North Slope, Alaska Kuparuk 2P Vertical Section Dogleg Rate (0/100ft) Coordinates Eastlngs (ft) Globa Northlngs (ft) Coordinates Eastlngs (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. Kuparuk River Unit Incl Measured Depth (ft) ) Comment 5388.43 5464.04 5539.84 5615.49 5666.67 0.027 0.432 2.104 1 .409 1.082 447071.85 E 447115.11 E 447157.41 E 447199.17 E 447227.75 E 5864514.50 N 5864452.47 N 5864389.57 N 5864326.48 N 5864284.03 N 3055.12 E 3098.83 E 3141.59 E 3183.82 E 3212.71 E 4438.62 S 4500.33 S 4562.92 S 4625.70 S 4667.93 S 5454.19 5511.71 5570.08 5629.43 5670.24 5195.49 5253.01 5311.38 5370.73 5411.54 144.940 144.440 146.880 145.270 145.980 52.790 52.690 52.130 51.650 51.210 8035.30 8130.31 8225.99 8322.15 8387.60 5689.94 5763.70 5836.20 5909.16 5968.96 1.489 1.216 0.300 0.670 0.867 447240.73 E 447281.67 E 447321.63 E 447362.10 E 447395.70 E 5864264.71 N 5864203.35 N 5864142.86 N 5864082.14 N 5864032.67 N 3225.82 E 3267.22 E 3307.62 E 3348.53 E 3382.50 E 4687.16 S 4748.21 S 4808.42 S 4868.83 S 4918.05 S 5688.95 5749.26 5809.58 5871.04 5922.17 5430.25 5490.56 5550.88 5612.34 5663.47 145.410 146.320 145.960 145.820 144.970 51.190 50.270 50.210 49.580 49.360 8417.46 8512.75 8607.06 8702.46 8781.14 Projected Survey 6023.49 0.000 447426.67 E 5863987.79 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North Vertical depths are relative to Well. Northings and Eastings are relative to Well 3413.80 E 4962.70 S 5968.97 5710.27 44.970 49.360 8853.00 The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an ) DrillQuest 2.00.08.005 Azimuth of 145.476° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8853.00ft. The Bottom Hole Displacement is 6023.49ft., in the Direction of 145.476° (True). 14 March, 2002 - 16:35 Page 5 0'6 ') ) I) North Slope, Alaska Kuparuk 2P DrillQuest 2.00.08.005 .. . Sperry-Sun Drilling Services Survey Report for 2P-422 Your Ref: 501032040000 Job No. AKMW22017, Surveyed: 28 February, 2002 Kuparuk River Unit Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8853.00 5968.97 4962.70 S 3413.80 E Projected Survey Survey tool program for 2P-422 Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 8853.00 5968.97 MWD Magnetic ------ 14 March, 2002 - 16:35 Page 60f6 AlaakaOil&GasQms.CotmiSiOn And\oI8J}e 1 H-15 3B-10 3B-15 3J-17 3N-16 3N-18 I -0.:( 2P-415 dOJ-l31 ~ 2P-415 ..v 2P-422;:).Ol-;)t./r, PROD PROFIDEFT/GLS INJECTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE DSI,MDT MDT DSI MDT ( Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. SIGNED: 21489 21489 21489 /93-00 I ~'5-11iJ 02127/02 03/06/02 03/02102 03/01/02 03/05/02 03/06/02 11/24/02 11/24/02 11/24/02 03/01/02 DATE: 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 RECEIVED 1 ~ t Well Job # Log Description Date BL Sepia CD Color Schlumberger Technology Corporation, by and through is Geoquest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Field: Company: Kuparuk Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 100 Sc~Itn~IPg.. Division NO. 1926 03/26/02 Re: 2P-422 Suspension ~ ,r--... Subject: Re: 2P-422 Suspension Date: Wed, 06 Mar 2002 14:30:53 ~0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Scott L Lowry <sllowry@ppco.com> é}-O \ -d-~ þ Scott, Thanks for the note. This is acceptable, you don't need to file any amended 403. Since you are planning to be back on the well "shortly-', I don't believe you have to file any 404. I will check on that, maybe changing the rig might have something to do with what you need to file. Use caution when you attempt the pressure test so you don't pump the plug away. As we discussed, the volume necessary shouldn't be a lot different from your casing test. Good luck. Tom Maunder, PE AOGCC Scott L Lowry wrote: Tom, After setting the cement plug across the surface casing shoe as per Sundry Approval # 302-082, we are currently running in with 3 1/2" tubing to +/- 200' below the base of the permafrost. We will test the shoe of the 7 5/8" surface casing to a 16.0 ppg equivalent for 30 minutes, freeze protect across the permafrost, hang off the tubing, and install a dry-hole tree to suspend the well. We are planning to drill a sidetrack using the existing surface casing, but will not do this immediately. I will be submitting a permit application for the sidetrack after the details are worked out. Please let me know if this is sufficient for your approval to change the sundry from "Abandon" to "Suspend". Thank you for your help, Scott L Lowry Drilling Engineer Phillips Alaska Inc. Voice: 907-265-6869 Cell: 907-240-5322 E-Mail: sllowry@ppco.com Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 3/61022:31 PM . MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor (p'" Commissioner DATE: March 5, 2002 THRU: Tom Maunder P.I. Supervisor tlt~ 'Y\ö--""'\ \ SUBJECT: Plug & Abandonement 2P-422 Phillips Meltwater 201-246 FROM: Chuck Scheve Petroleum Inspector CONFIDENTIAL Section: Lease No.: Operator Rep.: Dearl Gladden Township: Drilling Rig: Range: Rig Elevation: Meridian: Total Depth: CasinglTubing Data: Conductor: 16" 0.0. Shoe@ 80 Surface: 7 5/8" 0.0. Shoe@ 2823 Intermediate: N/A 0.0. Shoe@ Production: N/A 0.0. Shoe@ Liner: N/A 0.0. Shoe@ Tubing: N/A 0.0. Tail@ Casing Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Type Plug (bottom up) Open Hole I Founded on Bottom of Cement 8853 Plugging Data: Top of Cement Depth Verified? 7699 I Drillpipe Tag Mud Weight Pressure above plug Test Applied Bottom Type PluQ Open Hole Perforation Annulus Casing Stub Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No Surface I traveled to Phillips Meltwater location in the KRU to witness the integrity test of the bottom cement plug in this well. A cement plug had been spotted in two stages from TO (8853) to an estimated top of cement at 7663. After 12 hours wac drill pipe was run in the hole to 7707 with no sign of cement. The samples taken at the time of the job were still very soft so pipe was pulled above the estimated top of cement and another 4 hours allowed to pass. Drillpipe was then rerun and solid cement tagged at 7699' with 15K DP weight. The top of upper formation in this well is at7860. ~ -'t ç£ Attachments: Distribution: orig - Well File c - Operator c - DNRlDOG c - Database c - Rpt File c - Inspector SCANNEr) N()\f n 5 2004 Rev.:5/28/00 by L.R.G. P&A Plug 2P422 3-5-02 CS.xls 3/7/02 · -"'"-:: ... "'-\ ~ "'<,.... PHILL.PS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: crmalla@ppco.com March 4, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: 2P-422 Application for Sundry Approval (APD 201-246) Dear Commissioner Taylor: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to P&A the current Meltwater well 2P-422. If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, (l'R- Chuck Mallary Drilling Engineering Supe RECEIVED MAR 0 4 ?DUI Alaska Oil & Gas Cons. Commission Anchorage OR\GiNAl ~... /'~ ......t' ~, ~~ ~\ 5< STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Alter casing _ Repair well_ Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 901' FNL, 3189' FEL, Sec. 17, T8N, R7E, UM At top of productive interval 356' FNL, 53' FWL, Sec. 21, T8N, R7E, UM At effective depth At total depth 584' FNL, 225' FWL, Sec. 21, T8N, R7E, UM 12. Present well condition summary Total depth: measured true vertical Operational shutdown _ Plugging _ Pull tubing 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service (asp's 444049,5868975) (as proposed) (asp's 447440,5863988) 8853 feet 5969 feet Plugs (measured) Effective depth: measured 2657 feet true vertical 2273 feet Casing Length Size Cemented Conductor 90' 16" 9 cu yds High Early Surface 2827' 7.625" 316 bbls AS III Lite, 81 bbls LiteCrete Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers & SSSV (type & measured depth) None None Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 30 feet 7. Unit or Property name Other Kuparuk River Unit 8. Well number 2P-422 9. Permit number / approval number 201-246 10. API number 50-1 03-20400 11. Field / Pool Kuparuk River Unit Field / Meltwater Pool Plug #1: 8253' - 8853' Plug #2: 7653' - 8253' Plug #3: 2657' - 3257' Measured Depth 120' 2857' True vertical Depth 120' 2389' RECE\VEO MAR 0 4 2.002 Alaska Oil & Gas cons. Commission Anchorage Detailed operations program 15. Status of well classification as: BOP sketch Oil_X Service Approved by order of the Commission 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation March 4, 2002 16. If proposal was verl{alty approved \\;~...)~, ""-",,--(""\ \ d-C~;> Name of approver Date approved 17. I hereby ce~ that the foregoing is tr correct to the best of my knowledge. Signed (' . R: Title: Drilling Engineering Supervisor c. Malia FOR COMMISSION USE ONLY Conditions of approval: Notify CO~lT)ission so representative may witness Plug integrity X. BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent fonn required 10-Y() \ Form 10-403 Rev 06/15/88 . ORIGlr~AL Gas Suspended _ Questions? Call Scott Lowry 265-6869 Date ~ ¡!Jt2¿ Jðo;L Pre ared b Sharon AlIsu -Drake 263-4612 Approval no. ~ _ Or:¡- d.... Commissioner Date SUBMIT IN TRIPLICATE ! 1 ! i i i -J"~t-,j._.j-",""L-lo ~ I --L ~ '\ ~,<" ,\" \ , Ii! I ' I t;3c"~~.\~ ; I ¡ ¡ __~~0J.'\.'\ I ¡ 3,oí ~!N c..V!J RJ¡J ~~~~ ~!=. ~~ - ~ .~~j~~ I - /1/ /YJ_J ! ·t~-r~/",// Y I I I t1~f///I// 1,dr> ~ /l/V ~ 1 i-=I_)I , 2 ~2 /~ it? i J'< Mbp~ , ,__" t--I" " I0'V / Ii ¡ ~ I 5"0' I:::>! I 10.1._ C!)I '2 ' 1-1 / / I -, - I;l- -' I / /' /;1 ./ //V /0_ .// //" ~ ~v vrç,..1 rt-c) \ ~ ". PHILLIPS Alaska, Inc. €_~> " A Subsidiary of PHILLIPS PETROLEUM COMPANY Subject 2 P - 41f 2 2 File ,\{9 9'3 : "7 "L !':LA ~.., , ! . . . , , ·7 r: h I '0' ":" I I ,: , '¡ S2 ¿.,.:~ J i) ¡,I: IS , I !') i i ~._-J,._---,"-__ ~--:---__ j j > j :-,--l--Jf~t--"- ."illl I : :-S--f"--1"-""" . ---+7- -:¡ z I ;;Cj"-- , ~--t >::, 11< ?S ,'ô :'7 á, á' :0 C-f'o ..., I :;> 'i I (.: I 1:1' I'll :;,'. : I ,/--" ~ Calculations Chart -:PI. d ~ ~ A-" (;.../f:. Sheet number I By ? .:TI( Date '3/1/ CJ 2- f>1D INLI JA-110","" ~! 7f1 is'''rtt<-l¿!S~J~ L \I j i:! ¡"----;- -- ,; , í ¡'----,-"'·'·r'-"r : 1 ~o ,; ~ ~~~ ~ "I' ~ !,., '"-¡"--~t~,~r~·il----t--'+-'-'T-"__I I " :;, · ~;:,,-tT " ""~T~;.;r¡- +()O' ~'t-:::: i~ "'1 \ ' 'i~-~r" :'\ , . of I -, ' -J - ' ! ; : : i ; ! I \ J ">~ r ""'/"'V ·H Hilt 1-1- V lS P l..- , --" , - ,vv ) - - I '" l' I? ". 7"D1 ~/ w- ','" ""- ~ ,. ð _ /'\1 , J:rv' - \ I .- ) i! I ¡ I ¡- ítE I - , . ~ i , ,. J .$ , ) ! ; I : I 136 L:+i:-I-f I ;; I I IF J 1;13 ¡ Q.L. PRINTING (907) 563-4743 159-5881 /' ~ /.~ .~ Melwater 2P-422 Plug Bé:.. "Requirements Cement Plug #1: 8253' MD - 8853' MD = 600' liner fill. (30.1 bbls slurry) Cement with 15.8 ppg cement consisting of Class G + 0.3% D065 + 0.2% D046 + 1.0% SOO1. Add 0.25 #/sx D029 (Celoflake) Assume 15% excess on open hole volume. Cement Plug #2: 7653' MD - 8253' MD = 600' liner fill. (30.1 bbls slurry) Cement with 15.8 ppg cement consisting of Class G + 0.3% D065 + 0.2% D046 + 1.0% SOOl. Add 0.25 #/sx D029 (Celoflake) Assume 15% excess on open hole volume. Cement Plug #3: 2657' MD - 3257' MD =600' liner fill. (27.2 bbls slurry) Cement with 17.0 ppg cement consisting of Class G + 0.09 gps D 185 + 0.2 % D046 + 2.0% SOO1. Add 4.5 #/bbl Dowell Nylon Fibers for consolodation during drilling. Assume 15% excess on open hole volume End of job hydrostatics are plotted below. o § LO o § ft Ib/g aI 8 9 10 11 12 13 14 15 - - - - Max. Dynanic - Frac -F\:)re - - Mn. Dynamic - - Mn. Hydrostatic - Hydrostatic [~mamic Well Secu rity ¡iI.-", ,.-..ç ~V~VŒ (ill~ ~~~~æ~ /~ ALASKA. OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 2P-422 Phillips Alaska, Inc. Permit No: 201-246 Sur Loc: 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 555' FNL, 189' FWL, Sec. 21, T8N, R7E, UM Dear Mr. Mallary: 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 does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Û ~~ C~echsli TayÍ01L) Chair BY ORDER OF THE COMMISSION DATED this 21th day of December, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,,--..,. ,....-...... k \(f./~\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill o Redrill 0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-e ntry o Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 30 feet 3. Address 6. Property Designation 3'7.3//2-,x Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 389058 ALK "i.ì") Meltwater Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 901' FNL, 2089' FWL, Sec. 17, T8N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 356' FNL, 53' FWL, Sec. 21, T8N, R7E, UM 2P-422 #59-52-180 At total depth 9. Approximate spud date Amount 555' FNL, 189' FWL, Sec. 21, T8N, R7E, UM January 4, 2002 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 53' @ TARGET feet 2P-420 , 40' @ 100' 2560 8777' MD / 5911 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 350 MD Maximum hole angle 53° Maximum surface 2027 psig At total depth (TVD) 1988 psig 18. Casing program Setting Depth size Specilications Top Bottom Quantnv of Cement Hole Casing Weiaht Grade Couplina Length MD TVD MD TVD (include stage data) 42' 16" 62.5# H-40 welded 80' Surf. Surf. 110' 110' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTC, ABmo( 2847' Surf. Surf. 2877' 2395' 400 sx AS III Lite & 190 sx Litecrete 6.75" 5.5" 15.5# L-80 BTC, ABmo( 7720' Surf. Surf. 7750' 5299' 340 sx Class G 6.75" 3.5" 9.3# L-80 EUE 8rd Mo 1027' 7750' 5299' 8777' 5911' included above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condi!ion summary Total Depth: measured feet Plugs (measured) tru e vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED Liner DEC 1 8 2001 Perforation depth: measured Alaska Oil & Gas COOS. Commission true vertical Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid progr"WI o Time vs depth ~t DRefraction analysis o Seabed report o 20 MC 25.050 requirements 0 21.1 ho~;;r&ru'rctIOV 01 my,"~."" an",oo,7 Pat ""Diy 2ir~ Signed -:Øi// ...... L.:::::-'~. ~¡Ú;tA/Title: DrillingEngineeringSupervisor Date I J- /'-1 D / Chuok Malia ....., Commission Use Onl\ Permi! NumbeW I ~ zt/6 API number . mð CJ6 Approval date ~ ~\ 0\ See cover letter 50- /D3-- WL - for other requirements Conditions of approval Samples required DYes 121 No Mud log requirecÍ" , o Yes ~ No Hydrogen sulfide measures DYes ii1 No Directional survey required ~ Yes 0 No JIJ.'Iv1 Required working pressure for BOPE O~MlI S¡~AJy 0 5M; 0 10M;D ~ ~CÖt';', ~C~-'t~"';.-\ ~'''\.....~ Other: Cammy Oaehali by order of I~ ~\ 'n \ Approved by Commissioner the commission Date ORIGINAL . - . . Form 10401 Rev. 12/1/85 Submit In tnpllcate ~. Ap~tion for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 Permit It - Meltwater 2p· 422 Application for Permit to Drill Document M(lxir'l'li;z:E Well "IQlu ~ Table of Contents 1. Well Name .................................. .............. ................ ............ .......... ................ ........... 3 Requirements of 20 AAC 25.005 (f)................... .................................................................. ........... ........ 3 2. Location Summary................ .... ............. ... ........ ...... ....... ... ........... ................. ........... 3 Requirements of 20 AAC 25.005(c)(2) .............................................................. .............. ....................... 3 Requirements of 20 AAC 25. 050(b)........................ ......... ......................... ................................. ............. 3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25.005(c)(3) ...................................... .... ............. .......... ........... .......... ..... ........ 4 4. Drilling Hazards Information ...................................................................................4 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................4 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) . .......... ............................. ..................... ....... ............ ............. ...... 4 7. Diverter System Information ...................................................................................5 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 5 8. Dri II i ng FI uid Program ......... .............................. .......... ........................ .............. ...... 5 Requirements of 20 AAC 25.005(c)(8) ... ................ .......... ...... ........................ ........... ......... ....... ............. 5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) ................................... ................................ ................... ............ 6 10. Seismic Analysis ............. ......... ......... .... ............. ............ ........... ........... ..... ......... ...... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 2P-422 PERMIT IT 12-17-01.doc Page 1 of7 Printed: 17-Dec-01 ,~ Ap~tion for Permit to Drill. Well 2P-422 Saved: 17-Dec-01 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments. ............. ........................................................ .................. ............ ......... 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................ 7 Attachment 2 Directional Plan. ............................................................... ............................................... 7 Attachment 3 Drilling Hazards Summary............................................................................... ................ 7 Attachment 4 Well Schematic................................................................................................................ 7 Attachment 5 Cement Details............. ........................................................................................... ........ 7 ORIGI^JAL 2P-422 PERMIT IT 12-17-01.doc Page 2 of 7 Printed: 17-Dec-O 1 ~. A~tion for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique APl number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche!>~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number a::."'Signed to the well by the commission. The well for which this Application is submitted will be designated as 2P-422. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except f..r;r an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surfac~ at the top of each objective formation and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed loc:-ation of the we/I at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmosphetic Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth,' Location at Surface NGS Coordinates Northings: 5868975.31 I 901'FNl I 2089' FWl Sec 17, T8N, R7E, UM RKB Elevation: 252.0 ft AMSl Pad Elevation: 224.0 ft AMSl Eastings: 444049.45 Location at Top of 356' FSl, 53' FWl, Sec 211 T8N, R7EI UM Productive Interval (Bermuda Formation) NGS Coordinates Measured Depth (RKB feet): 8476' Northings: 5864217.06 Eastings: 447268.90 True Vertical Depth (55 feet): 5480' True Vertical Depth (RKB feet): 5732' Location at Total De th NGS Coordinates Northings: 5864017.70 555' FNl 189' FWl Sec 21 T8N1 R7E UM Measured Depth (RKB feet): 8777 Eastings: 447408.55 True Vertical Depth (55 feet): 5659' True Vertical De th RKB feet: 5911' and (D) other information required by 20 MC 2s'050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated; the application for a PermIt to Drill (Form 10-401) must (1) include a plat, drawn to a 5vitable scale, showing the path of the proposed wellbore, including all adjacent wellbores wIthin 200 feet of any poltion of tfle proposed well; Please see Attachment 2: Directional Plan and (2) for all wells wIthin 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certjfied mai~' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. ORIGl/~AL 2P-422 PERMIT IT 12-17-01.doc Page 3 of 7 Printed: 17-Dec-01 -~ A~tion for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applIcatIon for a PermIt to DrIll must be accompanIed by ecxh of the followti7g items¡ except for an item already on file wIth the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as requIred by 20 AAC 25.035~ 20 AAC 25.036, or 20 AAC 25.037, as applicable," Please refer to Doyon Rig 141 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applIcatIon for a PermIt to Drill must be accompanied by each of the followIng Items¡ except for an item already on fIle with the commissIon and IdentIfied In the application: (4) Information on drilling hazards¡ Ineluding (A) the maximum downhole pressure that may be encountered, cnteria used to determine If., and maximum potential surface pressure based 017 a methane gradient· The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 pSijft, or 8.5 to 8.9 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2j2A. The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is: MPSP =(5792 ft)(0.46 - 0.11 psi/ft) =2027 psi Assuming a leak off of 15.9 ppg (0.83 psi/ft) based on open hole LOT results from offset Meltwater exploration wells, formation breakdown at the surface casing shoe (2395' TVD) can be expected to occur at 1988 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above. (B) data on potential gas zones,' The Cairn interval is a potential gas zone. and (C) data concernIng potential causes of hole problems !juch as abnormally geo-pressured strata, lost circulation zones¡ and zones that have a propensity for differential sticking; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pem/it to Drill must be accompanied by each of the followIng items¡ except for an item already on file wIth the commission and identifíed in the application: (5) a description of the procedure for c"Onducting formation integrity tests¡ as required under 20 AAC 25.030(f); A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT j FIT procedure, currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a PermIt to Drill must be accompanied by each of the following Items¡ except for an item already on fIle with the commission and identIfied In the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 03~ and a description of any slotted liner, pre- perforated liner, or screen to be installed/ ORIGlfJAL 2P-422 PERMIT IT 12-17-01.doc Page 4 of 7 Printed: 17-Dec-01 /"---- Ap~tion for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 Casing and Cementing Program Hole Top Btm Csgrrbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (/blft) Grade Connection (tt) (ft) (ft) Cement Pro.aram 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Early 7-5/8 9-7/8 29.7 L-80 BTC,AB 2847 30 / 30 2877 / 2395 400 sx 10.7 Modified ppg AS3 Lead, 190 sx 12.0 ppg LiteCrete Tail Planned Top of Cement: Surface 51/2 6-3/4 15.5 L-80 BTC,AB 7720 30 / 30 7750 / 5299 340 sx 15.8 Modified ppg Class 'G' 3-1/2 6-3/4 9.3 L-80 EUE, 8rd 1027 7750 / 5299 8777 / 5911 Planned Top of Mod Cement: 7250' MD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as requked by 20 AAC25.03~ unless this requirement is waived by the commis..çion under 20 AAC 25.035(h)(2); Please refer Doyon Rig 141 Diverter Schematic currently on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid ::.ystem, as required by 20 AAC 25.033; Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: Spud to 9-5/8" Drill Out to Top Bermuda Surface Casing Top Bermuda To Well TO Initial Value Final Value Initial Value Final Value Initial Value Final Value Oensity (ppg) 9.6 9.6 9.6 9.6 9.6 9.6 Funnel Viscosity 60 70 50 65 50 65 (seconds) Yield Point 35 30 10 25 20 30 (cP) Plastic Viscostiy 13 23 6 14 6 14 (lb/1 00 sf) 10 second Gel 10 15 2 6 4 7 Stren.ath (/b1100 sf) 10 minute Gel 15 40 4 8 4 8 Strenath (lb/100 sf) pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <15 <15 <6 <6 8-10 8-10 ORIGI/VAL 2P-422 PERMIT IT 12-17-01.doc Page 5 of 7 Printed: 17-Dec-01 ~ ,r-";ation for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pelmit to Dlfll must be accompanied by each of the following ¡temSr except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f)/ Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dlill must be accompanied by each of the following ¡temSr except for an Item already on file with the commission and identmed in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or refiection analysis as required by 20 MC 25.061(a),· Not applicable: Application is not for an exploratory of stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item5~ except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore piatform, mobile bottom-founded structure, jack-up fig, or fioating drilling vesse~ an analysis of seabed conditions as required by 20 MC 25.061(bJ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following item5~ except for an item already on file with the Gvmmission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met/ Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following ItemSr except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon 141. Install diverter & function test same. 3. Spud and directionally drill to surface casing point according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. 4. Run surface casing and cement to surface using ArcticSet 3 lead slurry and UteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud. *Note: Port collar will be run in the string at 1000' MD 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 Dsi. Record results. 4R /D/~t-:ð1l~ /t1> - ORIGINAL 2P-422 PERMIT IT 12-17-01.doc Page 6 of 7 Printed: 17-0ec-01 r' ~~ation for Permit to Drill, Well 2P-422 Saved: 17-Dec-01 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. tj/?j~£5/"Þ<F/lfIÆ.l~u.¡ 8. Directionally drill production hole to total depth according to directional plan. Run MWD / LWD ?>(~h~~ logging tools in drill string for directional monitoring and formation data gathering. Circulate and ,.¿{lJ condition hole. POOH. 9. Run open hole e-line or drill pipe conveyed logs as needed. 10. Run and cement tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top perforation. 11. Run and land production tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set BPV. Release rig and turn well over to production. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fol/owing items; except for an item already on file with the commission and /dentitled in the application' (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25. 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings will be either processed on-site and disposed of down the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing and disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details O...R I G ! ;'f:1 L f1 JJ '<.:i>';' '" :1 ->i ¡j ... 2P-422 PERMIT IT 12-17-01.doc Page 7 of 7 Printed: 17-Dec-01 Phillips Alaska, 111 C . Structure: Drill Site 2P Well : 422 Field : Meltwater Location : North Slope, Alaska For: P Reilly O-Dee-200t rotary table. PROFiLE COMMENT DATA 2P-422 Version #1.D. ect reference slot #422. reference !I1!:i\l!l! "f&s ~ ) ) 0 TVO North East V. Sect Oeg/100 45.44 350.00 0.00 0.00 0.00 0.00 45.44 847.47 -35.84 24.69 43.52 2.00 45.44 452.00 -213.88 47.31 259.69 3.00 45.44 852.00 -460.99 317.50 559.75 3.00 45.44 2049.41 --647.39 445.89 786.09 3.,(J 0 45.44 2.395.40 1031.30 710..30 252.24 0.00 45.44 2455.00 1097.43 755.84 332.54 0.00 45.44 3008.00 1711.02 178.45 2077.58 0.00 45.44 3319.00 -2056.10 416.12 2496.59 0.00 45.44 3508.00 -2265.81 560.56 2751.22 0.00 45.44 45~!5.00 -3383.15 2330.11 4107.94 0.00 45.44 5299.40 -4253.50 2929.56 5164.75 0.00 45.44 5359.00 --4319.63 2975.11 5245.04 0.00 45.44 5380.00 -4:542.93 2991.16 5273.34 0.00 45.44 5732.00 -4733.50 3260.16 5747.58 0.00 45.44 5761.99 -4766.78 .3283.07 5787.98 0.00 45.44 5792.00 -4800.08 .3.306.01 5828.42 0.00 45.44 5902.00 -4922 3 3390.07 5976.62 0.00 nc 0.00 53.42 53.42 5.3.42 53.42 53.42 53.42 53.42 53.42 0.00 29.35 44.40 5.3.42 53.42 53.42 53.42 53.42 53.42 Pain MIJ KOP 350.00 <::) Begin .3/100 Bid 850.00 ::0 Bose Permafrost 495.08 -- Bose West Sak 996.55 C:> EOC 2297.20 -- ==== 7 5/8 CSG 2877.72 )::::... C80 2977.72 r-- C50 3905.57 C40 4427 .38 C37 4744.49 6434.08 ~-~ /2 x 3 1/2 XO 7750.19 1 (Top Cairn) 7850.19 ---- - 1 7885.42 (Top Bermuda) 8476.02 jet-Bermuda MidPt :v 8526.34 (Bose Bermuda) 8576.70 876 26 /"~ .r"'--, Phillips Alaska, Inc, ~ /pulII IP~> ¡_n___"1 Created by michael For: P Reilly Date ploUed : 10-Dec-2001 Plot Reference is 2P-422 Version #1.D. Coordinates ore in feet reference slot #422. Vertical Depths ore reference rotory Structure: Drill Site 2P Well: 422 Field: Meltwater Location: North Slope, ~~. ....y~- ~ TRUE NORTH ~~ ~ ~ ® .. 0 1500 = ~ . 12 , 0 , 35D 10 340 20 . 1200 , 330 , 210 30 320 40 310 50 300 ~O -2 : 1500 290 70 280 80 270 90 260 100 250 110 ~ " " 240 1500 3000" 1 2 0 ø ~ 130~,·;9 230 220 140 210 150 200 160 190 180 170 ® ~ Normal Plane Trave ling Cylinder - Feet All depths shown are Measured de s on Reference Well ORIGINAL Crected by michael For: P Reilly Dote piotted 10-Dec-2001 Plot Referer.ce i~ 2P-422 Ver~¡on # I.D. Coordinates ere if) feet reference slot #422. Vertical Depths ore reference rotary ~~W ~~~ 300 I I l 0 I l 1 ::: I ~ I 900 1 I ] I 1200 -1 I 1500 ~ I ~ i 1800i J ~ I ->- Q) 21001 Q) i ~ 1 '---" L 24001 ->- :J 2700 ~ 0 (f) I V 3000 ~ I 3300 j I 3600 I I '"""1 4200 ~ 4500 ~ '"'" 1 l 5100 l 300 ~ '~" Phillips Alaska, lnc -"- -""'- -==- .....----..=-----=------.... 'fPHU.LIPS{ I .. ! Structure: Drill Site 2P Well: 422 Field: Meltwater Location ; North Slope, !t";Tt:·.} ESTIMATED SURFACE LOCATION: 901' FNL, 2089' FWL SEC. 17, T8N, R7E 145.44 AZIMUTH 5788' (TO TARGET) ,".Plane of Proposal'" p ~ f~ CSG TRUE ..,? 7Û- 7 7 '1'"2 TOP BERMUDA LOCATION: 356' FNL, 53' FWL SEC. 21, T8N. R7E TARGET LOCATION: ' 389' FNL, 76' FWL i Target-Sermedc MidPI SEC. 21. T8N, R7E 13 (Top Bermuda) T2 (Bose Bermuda) C35 TO TO LOCATiON: 555' FNL. 189' FWL SEC. 21, T8N. R7E 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 East (feet) -> ORIGINAL rc· ...-.." Phillips Alaska, Inc. Created by michael For: P Reilly Dote plolted : 10-Dee-2001 Plot Reference is 2P-422 Version # 1.0. Coordinates are in feet reference slot #422. Verticol Deptns ore reference rotary 0 400 800 1200 1600 ,.-.., +- Q) 2000 Q) '+- '--" .r: 2400 +- 0... Q) 0 2800 0 Ü +- 3200 !.... Q) > Q) 3600 ::¡ !.... I-- I 4000 V J I 4400 4800 """~ 5600 I ~ 6000 ~ I I BAKl!I'ft H"~G~:E! iï'ii:.Ü ------- Structure: Drill Site 2P Well : 422 Field : Meltwater Location : North Slope. 145.44 AZIMUTH 5788' (TO TARGET) ***Plone of Proposoi*** i '"" "'"";'00 "" DLS: 2.00 deg per 100 It Begin 3/100 Bid 15.00 18.00 21.00 DLS: 3.00 deg per 100 ft 24.00 27.00 30.00 Base Permafrost 33.00 39.00 45.00 Bose West Sak 5't.88 ~ 7 5/8 CSG C80 C50 C40 C37 TANGENT/TARGET ANGLE 53.42 DEG 400 T7 5 1/2 x 3 1/2 XO T4.1 (Top Cairn) 13.1 13 (Top Bermuda) Target-Bermuda MidPt T2 (Bose Bermuda) 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Vertical Section (feet) -> AzimLlth 145.44 with reference 0.00 N, 0.00 E from slot #422 ORIGINAL 6000 ,--... ~ Crected by michacl For: P Reilly Dote plotted ; 10-Dec~200' Plot Reference is 2P-422 Version #1.D. Coordinates ore in feet reference slot #422. True Vertical Depths ore reference rotary Alaska , Field : Meltwater Location : North Slope, Structure: Drill Site 2P Well 422 !õõiifi 1WIii< ~yç~~ East (feet) -> 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 1600 ~y ~" ~&;.. 9' ~~ ; "'.p ~ "y .300. 2 o. 2200 /ij-. ~I ~ ~ J ~ . 00 ~ @})...... .340õffiD 1800 . 3000 . 4600 . .3600 . 34Q@800 . 2600 . .3200 . 26Q¡J3800 . 5000 . 5200 . 34QQ;400 4000 . 5600 . . 5800 . 2800 . 6000 . 4200 . 3t3å.ög200 I±ill . 2800 2000 2200 2400 ~ 2600 2800 2200 . '~ 3400 2800 . 2400. 3200 '< 3600 . .3400 . 3000 . 2600 ~ 5000 2400' . 3800 . .3600 . 4400 . 3000 . 3800 ... 4000 . 4600 . .3200 . 4400 . 4000 . 32QCJl800 ~ 3000 . 5000 3200 (J) .~ 0 C ~ -+- 3400 :r -"'"""' --., CD 3600 CD -+- '-" I 3800 V 4000 . 5200 . 2800 íS> . 5400 . 3400 . 5600 . 2800 > 3800 \, 4200 2600 · . 4400 . 3400 . 4000 . 3000 . 5800 . .3000 ... 4600 . 4200 . 3600 ~oo 2800 . . 3600 " 4800 . .3200 . 3200 . 3800 .. 5000 . 3800 3000 . '..5200 . 3400 * 4600 . 4000 . 3400 4200 " 5400 . 4000 . 4800 4400 . 3600 . 4200 . 3600 3200 . . 5600 ~ 4600 05800 . 4200 4800 . 3800 l±.21J ~ 5000 * 3400 . 4400 5200 ~ <%J , 5400 . 4400 . 3800 íS> ~ ORIGINAL 700 1 400~ 300 ® 300 ~ 300'1866 -$-300, . 500 ~300 600 . 600 600 * 400 ... 1;<- . 700 , 700 .500 .800 .600 Created by mLchael For: P Reilly Dote plotted: 10-Dec-2001 Plot Reference is 2P-422 Version #1.D. Coordinates are in feet reference slot #422. Vertical Depths orB reference rotary ....-... uiiii"'~ ~"G~,Æ~ 60 40 20 ~ ~ ~ .600 .700 700. .800 .900 ~ ,..-, Phillips Alaska, Inc. Structure: Drill Site 2P Well : 422 Field : Meltwater Location: North Slope, East (feet) -> 20 40 60 80 120 160 180 100 i40 200 220 240 !iJ ~. 800 4;-300 -$- . 700 4;-300 . 500 . k300 . 600 . 600 32 0 ~ 'TT (fðJ 2900 3000 ..... 41 300 kêOO :¡SBo 2600 2700.'18. ..700 .Ð21 0023'IJ. 400 "'. 40ß' . 800 ~300·.... . 800 .(,;,.300 .. 500 .... . 500 . 900 -'2iOOJ0290d' 60~ " ;;~eo" ;J880 .600 "'..600 . 600"~~~ 100 " 1000 . 900 ~ .700 ·....700 ". . 700 . gOO..~200 "',..3300 . 1000' .800 "····êOO .. 800 . 700 .800 .900 '* 900 ·.3400 .900 .800 . 1100 "."..iJ~ . 1000 '* 1000 .800 .1100 ". 1 000 ··..".*"~600 . ""'Iilv . 1000 . 900 ., 1100 . 1200 "* 1 '100 ~ .900 . 1200 ... 1200 . 1000 . 1300 ~ . 1200 140 . 1000 ,,1300 . 1300. 1000 .1400 160 " 1100 . 1200 . 1300 <f® 180 "* 1400 . 1100 . 1400 .1100 200 " 1300 1200... ~ 220 .. 1400 ~ 1500 240 ... 1500 .1200 . 1200 260 " 1400 . 1500 280 " 1600 " 1600 ~ 300 ~ ~ % ~ ~ 320 ORIGI/VAL 260 60 40 20 20 40 60 80 100 If) o c ..... => 120 ------ -<> CD CD ..... '-" I V Created by michael For: P Reilly Dote plotted : 10-Dec~2001 Plot Reference is 2P~422 Version #1.0. Coordinates are in feet reference slot #422 Vertical Depths ore reference rotary 100 200 ~~~~ '~ '® , 1.4¡;¿~200 . 1600 ~2~0 1600 ~ *1600 14ÒO. 14'00 ...1800 1800 ~ 1; 1800 . 2000 . 1 600 1 600 . 2200 . 2000 Œ\ ® . 2400 . 2600 . 2800 ® 300 .1500 . 2200 r--. Phillips Alaska, Inc. Structure : Drill Site 2P Well: 422 Field: Meltwater Location: North Slope, East (feet) -> 400 500 700 800 500 900 1000 1100 1200 @Ð -:¡ '00 1300 ~400 too, I .-L- I ~~~*140dlI0 . 1800 . 20Co- .1400 * 1800 "+",600 " ·...1800 -···.-",,800 '-. \400'i¡t 1 800 ~'·1;'¡0.0 " 2000' 2200 ". . 2000 . 1800 '. . 1600 * 2400 * 2000 . 2200 '.2000 . 1600 . 2600 . 2200 . 2000 . 2200 . 2400 * 1800 '~ 2200 . 2400 . 1800 . 2200 . J ij®)o . 2400 . 2400 1800. . 2800 " 2600 . 3000 . 2600 . 2400 . 2000 . 2400 . 2000 . 3200 '. 2800 * 3400 2000 · " 3000 . 2600 . 3600 . 2200 . 3800 ~ ~e;:' e '" "" ORIGINAL .-..... 1300 1500 1400 1600 '. ..,,000 '. ....2000 500 * 1800 "'0v 700 . 2800 . 3000 . 2400 . 2600 800 ~ ~ 900 ì . 3200 ~ (J) 0 ~ 1000 C -+ ~r ::r ,--..., .2800 1·,00 -.. ro ~ ~ '--" 1200 I ~ V 1300 1400 " 2000 . 2600 1500 . 2800 1600 1700 . 2200 ~ 1800 ~ 1900 ~ 2000 -, . 3200 ~ ~ ~ Phillips Alaska, Inc. Drill Site 2P 422/AB slot #422 Meltwater North Slope, Alaska PRO P~S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-422 Version #I.D prop45l4 Date printed Date created Last revised lO-Dee-200l 25-Feb-200l lO-Dee-200l Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235.5869891.466,999. OOOOO,N Slot location is n70 3 9.663, w150 26 51.900 Slot Grid coordinates are N 5868975.310, E 444049.451 Slot local coordinates are 900.33 S 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ~ r--- ,,---.., Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,4221AB Your ref 2P-422 Version #1.D Meltwater,North Slope, Alaska Last revised , 10-Dee-2001 Measured Inclin. Azimuth True Vert R E C TANGULA R Dogleg Vert Depth Degrees Degrees Depth C 0 0 RDINATE S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 145.44 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 145.44 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 145.44 300.00 0.00 N 0.00 E 0.00 0.00 350.00 0.00 145.44 350.00 0.00 N 0.00 E 0.00 0.00 KOP 450.00 2.00 145.44 449.98 1.44 S 0.99 E 2.00 1. 75 550.00 4.00 145.44 549.84 5.75 S 3.96 E 2.00 6.98 650.00 6.00 145.44 649.45 12.92 S 8.90 E 2.00 15.69 750.00 8.00 145.44 748.70 22.96 S 15.81 E 2.00 27.88 850.00 10.00 145.44 847.47 35.84 S 24.69 E 2.00 43.52 Begin 3/100 BId 916.67 12.00 145.44 912 .90 46.32 S 31. 90 E 3.00 56.24 1016.67 15.00 145.44 1010.13 65.54 S 45.14 E 3.00 79.58 1116 . 67 18.00 145.44 1106.00 88.93 S 61. 25 E 3.00 107.98 1216.67 21. 00 145.44 1200.25 116.42 S 80.18 E 3.00 141. 36 1316.67 24.00 145.44 1292.63 147.93 S 101.89 E 3.00 179.62 1416.67 27.00 145.44 1382.88 183.38 S 126 .30 E 3.00 222.67 1495.08 29.35 145.44 1452.00 213.88 S 147 . 31 E 3.00 259.69 Base Permafrost 1516.67 30.00 145.44 1470.75 222.68 S 153.37 E 3.00 270.38 1616.67 33.00 145.44 1556.01 265.70 S 183.00 E 3.00 322.62 1716.67 36.00 145.44 1638.41 312.34 S 215 .12 E 3.00 379.26 1816.67 39.00 145.44 1717.74 362 .47 S 249.65 E 3.00 440.13 1916.67 42.00 145.44 1793.77 415.95 S 286.48 E 3.00 505.06 1996.55 44,40 145.44 1852.00 460.99 S 317 . 50 E 3.00 559.75 Base West Sak 2016.67 45.00 145.44 1866.30 472.64 S 325.53 E 3.00 573.89 2116 _ 67 48.00 145.44 1935.12 532.37 S 366 _ 67 E 3.00 646.42 2216.67 51.00 145.44 2000.06 594.99 S 409.79 E 3.00 722.45 2297.20 53.42 145.44 2049.41 647.39 S 445.89 E 3.00 786.09 EOC 2500.00 53.42 145.44 2170.28 781. 51 S 538.26 E 0.00 948.93 2877 72 51,ß._B_ó.....4:L_~l2.~..iQ._.__. 103L~Q__S______nO. 3ILIL 0~_1252 ~_L1.J5j,g,':...£.êSL-- 2977 . 72 53.42 145.44 2455.00 1097 . 43 S 755.84 E 0.00 1332.54 C80 3000.00 53.42 145.44 2468.28 1112.16 S 765.99 E 0.00 1350.43 3500.00 53.42 145.44 2766.28 1442.82 S 993.73 E 0.00 1751.92 3905.57 53.42 145.44 3008.00 1711.02 S 1178.45 E 0.00 2077.58 C50 4000.00 53.42 145.44 3064.28 1773.47 S 1221. 46 E 0.00 2153.41 4427.38 53.42 145.44 3319.00 2056.10 S 1416.12 E 0.00 2496.59 C40 4500.00 53.42 145 . 44 3362.28 2104_13 S 1449.20 E 0.00 2554_90 4744 A 9 53.42 145.44 3508.00 2265.81 S 1560.56 E 0.00 2751. 22 C37 5000.00 53.42 145.44 3660.28 2434.78 S 1676.93 E 0.00 2956.39 5500.00 53.42 145.44 3958.28 2765.43 S 1904.67 E 0.00 3357.88 6000.00 53.42 145.44 4256.28 3096_09 S 2132.40 E 0.00 3759.37 6434.08 53.42 145.44 4515.00 3383.15 S 2330.11 E 0.00 4107.94 T7 6500.00 53.42 145.44 4554.29 3426.74 S 2360.14 E 0.00 4160.87 7000.00 53.42 145.44 4852.29 3757.40 S 2587.87 E 0.00 4562.36 7500.00 53.42 145.44 5150.29 4088.05 S 2815.61 E 0.00 4963.85 7750.19 53.42 14.5.44 5299.40 4253.50 S 2929.56 E 0.00 5164.75 5 1/2 x 3 1/2 xo 7850.19 53.42 145.44 5359.00 4319.63 S 2975.11 E 0.00 5245_04 T4.1 (Top Cairn) 7885.42 53.42 145.44 5380.00 4342.93 S 2991.16 E 0.00 5273.34 T3.1 8000.00 53.42 145.44 5448.29 4418.70 S 3043.34 E 0.00 5365.34 8476.02 53.42 145.44 5732.00 4733.50 S 3260.16 E 0.00 5747.58 T3 (Top Bermuda) 8500.00 53.42 145.44 5746.29 4749.36 S 3271.08 E 0.00 5766.83 All data is in feet unless otherwise stated. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Total Dogleg for wellpath is 53.42 degrees. Vertical section is from wellhead on azimuth 145.44 degrees. Calculation uses the minimum curvature method_ Presented by Baker Hughes INTEQ Q. y...,r1....' .l'\." .....'.!1i...! A. - L . ", ',I .' ., ¡(~ kt;~~;~'~'ttln ~ /'""'\ Phillips Alaska, Inc. Drill Site 2P,422/AB Meltwater, North Slope, Alaska Measured Inc lin. Azimuth True Vert R E C TAN G U L A R Depth Degrees Degrees Depth C o 0 RDINA T E S 8526.34 53.42 145.44 5761. 99 4766.78 S 3283.07 E 8526.36 53.42 145.44 5762.00 4766.79 S 3283.08 E 8576.70 53.42 145.44 5792.00 4800.08 S 3306.01 E 8761.26 53.42 145.44 5902.00 4922.13 S 3390.07 E 8776.70 53.42 145.44 5911.20 4932.34 S 3397 .11 E PROPOSAL LISTING Page 2 Your ref 2P-422 Version #1. D Last revised : lO-Dee-200l Dogleg Vert Deg/100ft Sect 0.00 5787.98 Target-Bermuda MidPt 0.00 5788.00 MW(AB) 14-FEB-01 0.00 5828.42 T2 (Base Bermuda) 0.00 5976.62 C35 0.00 5989.02 TD All data is in feet unless otherwise stated. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Total Dogleg for wellpath is 53.42 degrees. Vertical section is from wellhead on azimuth 145.44 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL ~ /'.. Phillips Alaska, Inc. Drill Site 2P,422/AB Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 2P-422 Version #l.D Last revised : lO-Dee-200l Cormnents in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 350.00 350.00 0.00 N 0.00 E KOP 850.00 847.47 35.84 S 24.69 E Begin 3/100 B1d 1495.08 1452.00 213.88 S 147.31 E Base Permafrost 1996.55 1852.00 460.99 S 317.50 E Base West Sak 2297.20 2049.41 647.39 S 445.89 E EOC 2877.72 2395.40 1031.30 S 710.30 E 7 5/8" CSG 2977.72 2455.00 1097.43 S 755.84 E C80 3905.57 3008.00 1711. 02 S 1178.45 E C50 4427.38 3319.00 2056.10 S 1416.12 E C40 4744.49 3508.00 2265.81 S 1560.56 E C37 6434.08 4515.00 3383.15 S 2330.11 E T7 7750.19 5299.40 4253.50 S 2929.56 E 5 1/2 x 3 112 xo 7850.19 5359.00 4319.63 S 2975.11 E T4.1 (Top Cairn) 7885.42 5380.00 4342.93 S 2991.16 E T3.1 8476.02 5732.00 4733.50 S 3260.16 E T3 (Top Bermuda) 8526.34 5761. 99 4766.78 S 3283.07 E Target-Bermuda MidPt 8526.36 5762.00 4766.79 S 3283.08 E MW(AB) 14-FEB-01 8576.70 5792.00 4800.08 S 3306.01 E T2 (Base Bermuda) 8761. 26 5902.00 4922.13 S 3390.07 E C35 8776.70 5911.20 4932.34 S 3397.11 E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2877.72 2395.40 1031.30S 710.30E 7 5/8' CSG Targets associated with this wellpath - - - - - - - - - - - - - - - - - - -- ---- - - - - -- - -- ---- -- - - - - - - - - - - - - - --- ----- - ~ - - ----- - ---- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AB) 14-FEB-01 447295.800,5864184.100,999.00 5762.00 4766.79S 3283.08E 22-Feb-2001 ORIGINAL ~ ~ Phillips Alaska, Inc. Drill Site 2P 422/AB slot #422 Mel twater North Slope I Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License 2P-422 Version #l.D prop4514 Date printed Date created Last revised 10-Dec-2001 25-Feb-2001 lQ-Dee-200l Field is centred on 441964.235,5869891. 466,999.00000 ,N Structure is centred on 441964.235,5869891. 466,999.00000, N Slot location is n70 3 9.663,w150 26 51_900 Slot Grid coordinates are N 5868975.310, E 444049.451 Slot local coordinates are 900.33 S 2092 .34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 3-Dec-2001 139.7 200.0 200_0 2-Dec-2001 139.7 200.0 200.0 4-Jun-2001 320.2 100.0 100.0 25-May-2001 98.1 775.0 775.0 30-0ct-2001 40.0 100.0 562.5 6-Mar-2001 42038.5 8776.7 8776.7 26-Feb-2001 4004.4 8000.0 8000.0 26-Feb-2001 2076.6 4480.0 4480.0 26-Feb-2001 2013.1 4840.0 4840.0 MWD <5552 - 9038'>, ,41SA,Drill Site 2P MWD <3660 - 11075'>,,415,Drill Site 2P MWD <0-9224' >, ,438, Drill 5i te 2P MWD <0 - 6008' >, ,417 I Drill Site 2P MWD <0-6860 I >, ,420 I Drill Site 2P PMSS <O-8935'>"MWSouthl,Meltwater South #1 PMSS <0-6122'>, ,MWN#l.Meltwater North #l PMSS <2212-7349'>, .MWN#2A.Meltwater North #2 PMSS <0-6300'>, ,MWN#2,Meltwater North #2 ORIGINAL ~ Phillips Alaska, Inc. Drill Site 2P 422/AB slot #422 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref Our ref License 2P-422 Version #l.D prop45l4 Date printed Date created Last revised 10-Dec-200l 25-Feb-200l 10-Dec-200l Field is centred on 44l964.235,5869891.466,999.00000,N Structure is centred on 44l964.235,586989l.466,999.00000,N Slot location is n70 3 9.663, w150 26 51. 900 Slot Grid coordinates are N 5868975.310, E 444049.451 Slot local coordinates are 900.33 s 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGllvAL ~ .~. /"""', Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,422/AB Your ref 2P-422 version H.D Meltwater,North Slope, Alaska Last revised : 10-Dee-2001 Measured Inclin. Azimuth True Vert R E C TAN GULAR Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN ATE S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 145.44 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 145.44 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 145.44 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 350.00 0.00 145.44 350.00 0.00 N 0.00 E 0.00 0.91 0.91 0.53 N/A 450.00 2.00 145.44 449.98 1.44 S 0.99 E 1. 75 1.18 1.18 0.68 N/A 550.00 4.00 145.44 549.84 5.75 S 3.96 E 6.98 1.48 1.44 0.83 325.44 650.00 6.00 145.44 649.45 12.92 S 8.90 E 15.69 1.85 1.71 0.98 325.44 750.00 8.00 145.44 748.70 22.96 S 15.81 E 27.88 2.31 1.99 1.13 325.44 850.00 10.00 145.44 847 .47 35.84 S 24.69 E 43.52 2.89 2.28 1.28 325.44 916.67 12.00 145.44 912.90 46.32 S 31. 90 E 56.24 3.36 2.49 1.39 325.44 1016.67 15.00 145.44 1010.13 65.54 S 45.14 E 79.58 4.24 2.81 1.55 325.44 1116.67 18.00 145.44 1106.00 88.93 S 61.25 E 107.98 5.34 3.17 1.72 325.44 1216.67 21. 00 145.44 1200.25 116.42 S 80.18 E 141. 36 6.66 3.55 1.91 325.44 1316.67 24.00 145.44 1292.63 147.93 S 101.89 E 179.62 8.23 3.96 2.12 325.44 1416.67 27.00 145.44 1382.88 183.38 S 126.30 E 222.67 10.04 4.39 2.35 325.44 1495.08 29.35 145.44 1452.00 213.88 S 147.31 E 259.69 11.65 4.76 2.56 325.44 1516.67 30.00 145.44 1470.75 222.68 S 153.37 E 270.38 12.10 4.86 2.62 325.44 1616.67 33.00 145.44 1556.01 265.70 S 183.00 E 322.62 14.42 5.35 2.93 325.44 1716.67 36.00 145.44 1638.41 312 .34 S 215.12 E 379.26 17.02 5.85 3.28 325.44 1816.67 39.00 145.44 1717.74 362 . 47 S 249.65 E 440.13 19.88 6.38 3.68 325.44 1916.67 42.00 145.44 1793.77 415.95 S 286.48 E 505.06 23.02 6.91 4.13 325.44 1996.55 44.40 145.44 1852.00 460.99 S 317.50 E 559.75 25.74 7.34 4 _ 54 325.44 2016.67 45.00 145.44 1866.30 472.64 S 325.53 E 573.89 26.43 7.45 4.64 325.44 2116.67 48.00 145.44 1935.12 532.37 S 366.67 E 646.42 30.11 7.99 5.20 325.44 2216.67 51. 00 145.44 2000.06 594.99 S 409.79 E 722.45 34.06 8.52 5.83 325.44 2297.20 53.42 145.44 2049.41 647.39 S 445.89 E 786.09 37.41 8.95 6.36 325.44 2500.00 53.42 145.44 2170.28 781. 51 S 538.26 E 948.93 45.90 10.02 7.75 325.44 2877.72 53.42 145.44 2395.40 1031.30 S 710.30 E 1252.24 61. 83 12.02 10.38 325.44 2977 . 72 53.42 145.44 2455.00 1097.43 S 755.84 E 1332.54 66.05 12.55 11.07 325.44 3000.00 53.42 145.44 2468.28 1112.16 S 765.99 E 1350.43 66.99 12.67 11.23 325.44 3500.00 53.42 145.44 2766.28 1442 _ 82 S 993.73 E 1751. 92 88.16 15.34 14-75 325.44 3905.57 53.42 145.44 3008.00 1711.02 S 1178.45 E 2077.58 105.37 17.51 17.62 325.44 4000.00 53.42 145.44 3064.28 1773.47 S 1221. 46 E 2153.41 109.38 18.01 18.28 325.44 4427.38 53.42 145.44 3319.00 2056.10 S 1416.12 E 2496.59 127.53 20.30 21.31 325.44 4500.00 53.42 145 _ 44 3362.28 2104.13 S 1449.20 E 2554.90 13 0.61 20.69 21. 83 325.44 4744.49 53.42 145 _ 44 3508.00 2265.81 S 1560.56 E 2751. 22 141.00 22.00 23.56 325.44 5000.00 53.42 145.44 3660.28 2434.78 S 1676.93 E 2956.39 151. 86 23.37 25.38 325.44 5500.00 53.42 145.44 3958.28 2765.43 S 1904.67 E 3357.88 173 .12 26.06 28.93 325.44 6000.00 53.42 145.44 4256.28 3096.09 S 2132.40 E 3759.37 194.37 28.74 32.49 325.44 6434.08 53.42 145.44 4515.00 3383.15 S 2330.11 E 4107.94 212.83 31. 08 35.57 325.44 6500.00 53.42 145.44 4554.29 3426.74 S 2360.14 E 4160.87 215.64 31. 43 36.04 325.44 7000.00 53.42 145.44 4852.29 3757.40 S 2587.87 E 4562.36 236.90 34.12 39.60 325.44 7500.00 53.42 145.44 5150.29 4088.05 S 2815.61 E 4963.85 258.17 36.80 43.16 325.44 7750.19 53.42 145.44 5299.40 4253.50 S 2929.56 E 5164.75 268.81 38.15 44.94 325.44 7850.19 53.42 145.44 5359.00 4319.63 S 2975.11 E 5245.04 273.06 38.69 45.65 325.44 7885.42 53.42 145.44 5380.00 4342.93 S 2991.16 E 5273.34 274.56 38.88 45.90 325.44 8000.00 53.42 145.44 5448.29 4418.70 S 3043.34 E 5365.34 279.44 39.49 46.72 325.44 8476.02 53.42 145.44 5732.00 4733.50 S 3260.16 E 5747.58 299.69 42.05 50.11 325.44 8500.00 53.42 145.44 5746.29 4749.36 S 3271.08 E 5766.83 300.71 42.18 50.28 325.44 All data is in feet unless otherwise stated. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Vertical section is from wellhead on azimuth 145.44 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL ~ ~~ Phillips Alaska, Inc. PRO POSAL LISTING Page 2 Drill Site 2P,422/AB Your ref 2P-422 Version #1.D Meltwater, North Slope, Alaska Last revised : 10-Dec-2001 Measured Inclin. Az imu th True Vert R E C TAN G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C o 0 R DIN ATE S Sect Major Minor Vert. Azi. 8526.34 53.42 145.44 5761. 99 4766.78 S 3283.07 E 5787.98 301. 83 42.32 50.46 325.44 8526.36 53.42 145.44 5762.00 4766.79 S 3283.08 E 5788.00 301. 83 42.32 50.46 325.44 8576.70 53.42 145.44 5792.00 4800.08 S 3306.01 E 5828.42 303.97 42.59 50.82 325.44 8761.26 53.42 145.44 5902.00 4922.13 S 3390.07 E 5976.62 311 . 82 43.59 52.14 325 . 44 8776.70 53.42 145.44 5911.20 4932.34 S 3397.11 E 5989.02 312.48 43.67 52.25 325.44 POSITION UNCERTAINTY SUMMARY -- -- - - - - - -- - -------- ----- - - - -- ------------------------------ Depth From To Survey Too 1 Error Model position uncertainty Maj or Minor Vert. - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- 8777 ARCO (H.A) Mag) User specified 312.48 43.67 52.25 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Vertical section is from wellhead on azimuth 145.44 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL ~ .~ Phillips Alaska, Inc. Drill Site 2P,422/AB Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 2P-422 Version #1.D Last revised : lQ-Dec-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 350.00 350.00 0.00 N 0.00 E KOP 850.00 847.47 35.84 S 24.69 E Begin 3/100 BId 1495.08 1452.00 213.88 S 147.31 E Base Permafrost 1996.55 1852.00 460.99 S 317.50 E Base West Sak 2297.20 2049.41 647.39 S 445.89 E EOC 2877.72 2395.40 1031.30 S 710.30 E 7 5/8" CSG 2977.72 2455.00 1097 . 43 S 755.84 E C80 3905.57 3008.00 1711.02 S 1178.45 E C50 4427.38 3319.00 2056.10 S 1416.12 E C40 4744.49 3508.00 2265.81 S 1560.56 E C37 6434.08 4515.00 3383.15 S 2330.11 E T7 7750.19 5299.40 4253.50 S 2929.56 E 5 1/2 x 3 1/2 XO 7850.19 5359.00 4319.63 S 2975.11 E T4.1 (Top Cairn) 7885.42 5380.00 4342.93 S 2991.16 E T3.1 8476.02 5732.00 4733.50 S 3260.16 E T3 (Top Bermuda) 8526.34 5761. 99 4766.78 S 3283.07 E Target-Bermuda MidPt 8526.36 5762.00 4766.79 S 3283.08 E MW(AB) 14-FEB-Ol 8576.70 5792.00 4800.08 S 3306.01 E T2 (Base Bermuda) 8761.26 5902.00 4922.13 S 3390.07 E C35 8776.70 5911.20 4932.34 S 3397.11 E TD Casing positions in string 'A' ------------------------------ ------------------------------ TOp MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2877.72 2395_40 1031.30S 710.30E 7 5/8" CSG Targets associated with this wellpath ------------------------------------- --- - - ----- ----- - - - -- - - - - - - -- -- ------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AB) 14-FEB-01 447295.800,5864184.100,999.00 5762.00 4766.79S 3283.08E 22-Feb-2001 ORIGlfvAL ~ Phillips Alaska, Inc. Drill Site 2P 422/AB slot #422 Meltwater North Slope I Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-422 Version #l.D prop4514 Date printed Date created Last revised 10-Dec-2001 25-Feb-2001 10-Dec-2001 Field is centred on 441964.235,5869891.466.999.00000,N Structure is centred on 441964.235,5869891.466,999.00000, N Slot location is n70 3 9.663, w150 26 51. 900 Slot Grid coordinates are N 5868975.310, E 444049.451 Slot local coordinates are 900.33 S 2092.34 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ~ r'- ~ Phillips Alaska, Inc. PROP08AL LI8TING Page 1 Drill 8ite 2P,422/AB Your ref 2P-422 Version H.D Meltwater, North Slope, Alaska Last revised : 10-Dee-2001 Measured Inclin Azimuth True Vert R E C TANGU LA R G RID COO R D 8 G EO GRAPHIC Depth Degrees Degrees Depth C 0 0 RDINA T E 8 Easting Northing C o 0 RDINATE 8 0.00 0.00 0.00 0.00 O.OON O.OOE 444049.45 5868975.31 n70 09.66 w150 26 51. 90 100.00 0.00 145.44 100.00 O.OON O.OOE 444049.45 5868975.31 n70 09.66 w150 26 51. 90 200.00 0.00 145.44 200.00 O.OON O.OOE 444049.45 5868975.31 n70 09.66 w150 26 51. 90 300.00 0.00 145.44 300.00 O.OON O.OOE 444049.45 5868975.31 n70 09.66 w150 26 51. 90 350.00 0.00 145.44 350.00 O.OON O.OOE 444049.45 5868975.31 n70 09.66 w150 26 51.90 450.00 2.00 145.44 449.98 1.448 0.99E 444050.43 5868973.87 n70 09.65 w150 26 51. 87 550.00 4.00 145.44 549.84 5.758 3.96E 444053.36 5868969.53 n70 09.61 w150 26 51. 79 650.00 6.00 145.44 649.45 12 . 928 8.90E 444058.25 5868962.32 n70 09.54 w150 26 51. 64 750. 00 8.00 145.44 748.70 22.968 15.81E 444065.09 5868952.23 n70 09.44 w150 26 51. 44 850.00 10.00 145.44 847.47 35.848 24.69E 444073.86 5868939.28 n70 09.31 w150 26 51.19 916.67 12.00 145.44 912.90 46.328 31. 90E 444081. 00 5868928.75 n70 09.21 w150 26 50.98 1016.67 15.00 145.44 1010.13 65.548 45.14E 444094.09 5868909.43 n70 09.02 w150 26 50.60 1116.67 18.00 145.44 1106.00 88.938 61.25E 444110.02 5868885.92 n70 08.79 w150 26 50.14 1216.67 21. 00 145.44 1200.25 116.428 80.18E 444128.74 5868858.30 n70 08.52 w150 26 49.59 1316.67 24.00 145.44 1292.63 147.938 101.89E 444150.20 5868826.62 n70 08.21 w150 26 48.97 1416.67 27.00 145.44 1382.88 183.388 126.30E 444174.34 5868790.99 n70 07.86 w150 26 48.26 1495.08 29.35 145.44 1452.00 213.888 147.31E 444195.11 5868760.34 n70 07.56 w150 26 47.66 1516.67 30.00 145.44 1470.75 222.688 153.37E 444201.10 5868751. 49 n70 07.47 w150 26 47.48 1616.67 33.00 145.44 1556.01 265.708 183.00E 444230.40 5868708.25 n70 07.05 w150 26 46.63 1716_67 36.00 145.44 1638.41 312.348 215.12E 444262.17 5868661.37 n70 06.59 w150 26 45.71 1816.67 39.00 145 A4 1717.74 362.478 249 _ 65E 444296.31 5868610.98 n70 06.10 w150 26 44.71 1916.67 42 _00 145.44 1793.77 415.958 286 A8E 444332.73 5868557.23 n70 05.57 w150 26 43.65 1996.55 44.40 145.44 1852.00 460.998 317.50E 444363.40 5868511.96 n70 05.13 w150 26 42.76 2016.67 45.00 145.44 1866.30 472.648 325.53E 444371.33 5868500.25 n70 05.01 w150 26 42.53 2116.67 48.00 145.44 1935.12 532.378 366.67E 444412.01 5868440.21 n70 04.43 w150 26 41.34 2216.67 51.00 145.44 2000.06 594.998 409.79E 444454.66 5868377 .28 n70 3 03.81 wlSO 26 40.10 2297.20 53.42 145.44 2049.41 647.398 445.89E 444490.35 5868324.60 n70 3 03.29 w150 26 39.06 2500.00 53.42 145.44 2170.28 781. 518 538.26E 444581.69 5868189.80 n70 3 01.97 wIS0 26 36.40 2877.72 53.42 145.44 2395.40 1031. 308 710 _30E 444751. 80 5867938.73 n70 2 59 _ 52 w150 26 31. 45 2977.72 53.42 145.44 2455.00 1097.438 755.84E 444796.84 5867872 .26 n70 2 58.87 w150 26 30.14 3000.00 53.42 145.44 2468.28 1112.168 765.99E 444806.87 5867857.45 n70 2 58 _ 72 w150 26 29.85 3500.00 53.42 145.44 2766.28 1442.828 993.73E 445032.06 5867525.10 n70 2 55.47 w150 26 23.29 3905.57 53.42 145.44 3008.00 1711. 028 1178.45E 445214.72 5867255.52 n70 2 52.83 w150 26 17.97 4000.00 53.42 145.44 3064.28 1773.478 1221.46E 445257.25 5867192.75 n70 2 52.22 w150 26 16.74 4427.38 53.42 145.44 3319.00 2056.108 1416.12E 445449.73 5866908.68 n70 2 49.44 w150 26 11.13 4500.00 53.42 145.44 3362.28 2104.138 1449.20E 445482.43 5866860.41 n70 2 48.96 w150 26 10.18 4744.49 53.42 145.44 3508.00 2265.818 1560.56E 445592.55 5866697.89 n70 2 47.37 w150 26 06.98 5000.00 53.42 145.44 3660.28 2434.788 1676 _ 93E 445707.62 5866528.06 n70 2 45.71 w150 26 03.63 5500.00 53.42 145.44 3958.28 2765.438 1904.67E 445932.81 5866195.71 n70 2 42.46 w150 25 57.08 6000.00 53.42 145.44 4256.28 3096.098 2132.40E 446157.99 5865863.36 n70 2 39.20 w150 25 50.52 6434.08 53.42 145.44 4515.00 3383.158 2330.11E 446353.49 5865574.83 n70 2 36.38 w150 25 44.83 6500.00 53.42 145.44 4554.29 3426.748 2360.14E 446383.18 5865531.01 n70 2 35.95 wiSO 25 43.97 7000.00 53.42 145.44 4852.29 3757.408 2587.87E 446608.37 5865198.67 n70 2 32.70 w150 25 37.42 7500.00 53.42 145 _ 44 5150.29 4088.058 2815.61E 446833.55 5864866.32 n70 2 29.44 w150 25 30.87 7750 19 53 42 145 44 5299 40 4253.508 2929 56E 446946 23 5864700.02 n70 2 27.82 w150 25 27.59 7850.19 53.42 145.44 5359.00 4319.638 2975.11E 446991. 27 5864633.55 n70 2 27.16 w150 25 26.28 7885.42 53.42 145.44 5380.00 4342.938 2991.16E 447007.14 5864610.13 n70 2 26.94 w150 25 25.82 8000.00 53.42 145.44 5448.29 4418.708 3043.34E 447058.74 5864533.97 n70 2 26 _ 19 w150 25 24.32 8476.02 53.42 145.44 5732.00 4733.508 3260.16E 447273.13 5864217.56 n70 2 23.09 w150 25 18.08 8500.00 53.42 145.44 5746.29 4749.368 3271.08E 447283.93 5864201.62 n70 2 22.94 w150 25 17.77 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Total Dogleg for wellpath is 53.42 degrees. Vertical section is from wellhead on azimuth 145.44 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL r---. ,.--...., Phillips Alaska. Inc. PROPOSAL LISTING Page 2 Drill Site 2P,422/AB Your ref 2P-422 Version #1.D Meltwater ¡North Slope, Alaska Last revised , 10-Dec-2001 Measured Inclin Azimuth True Vert R E eTA N G U L A R G RID C OaR D 5 G E 0 G RAP HIe Depth Degrees Degrees Depth C o 0 R DIN ATE 5 Basting Northing C OaR D I N A T E S 8526.34 53.42 145.44 5761. 99 4766.785 3283.07E 447295.79 5864184.11 n70 2 22.76 w150 25 17.42 8526.36 53 _42 145.44 5762.00 4766.795 3283.08E 447295.80 5864184.10 n70 2 22.76 wI SO 25 17.42 8576.70 53.42 145.44 5792.00 4800.085 3306.01E 447318.47 5864150.64 n70 2 22.44 w150 25 16.76 8761. 26 53.42 145.44 5902.00 4922.13S 3390.07E 447401.59 5864027.96 n70 2 21. 24 w150 25 14.35 8776 70 53.42 145.44 5911.20 4932.345 3397.11E 447408.55 5864017.70 n70 2 21.14 w150 25 14.14 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #422 and TVD from rotary table (252.00 Ft above mean sea level). Bottom hole distance is 5989.02 on azimuth 145.44 degrees from wellhead. Total Dogleg for wellpath is 53.42 degrees. Vertical section is from wellhead on azimuth 145.44 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ OR/GI/VAL .r--. ~\ Phillips Alaska, Inc. Drill Site 2P,4221AB Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 2P-422 Version #l.D Last revised : lO-Dec-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 350.00 350.00 O.OON O.OOE KOP 850.00 847.47 35.84S 24.69E Begin 3/100 BId 1495.08 1452.00 213.88S 147.31E Base Permafrost 1996.55 1852.00 460.99S 317.50E Base West Sak 2297.20 2049.41 647.39S 445.89E EOC 2877 . 72 2395.40 1031.30S 710.30E 7 5/8" CSG 2977 . 72 2455.00 1097.43S 755.84E C80 3905.57 3008.00 1711. 02S ll78.45E C50 4427.38 3319.00 2056.10S 1416.12E C40 4744.49 3508.00 2265.81S 1560.56E C37 6434.08 4515.00 3383.15S 2330.11E T7 7750.19 5299.40 4253.50S 2929.56E 5 1/2 x 3 1/2 XO 7850.19 5359.00 4319.63S 2975.11E T4.1 (Top Cairn) 7885.42 5380.00 4342.93S 2991.16E T3.1 8476.02 5732.00 4733.50S 3260.16E T3 (Top Bermuda) 8526.34 5761. 99 4766.78S 3283.07E Target-Bermuda MidPt 8526.36 5762.00 4766.79S 3283.08E MW(AB) 14-FEB-01 8576.70 5792.00 4800.08S 3306.01E T2 (Base Bermuda) 8761.26 5902.00 4922.13S 3390.07E C35 8776.70 5911.20 4932.34S 3397.11E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2877.72 2395.40 1031.30S 710.30E 7 5/8" CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(AB) 14-FEB-01 447295.800,5864184.100,999.00 5762.00 4766.79S 3283.08E 22-Feb-2001 ORIGINAL ,~ ---- , 2P-422 DrillinQ Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) Surface Casina Interval Event Conductor Broach Well Collision Risk Level Low Low Gravel and sand slou hin Shaker/Trough Cuttings S stem Overflow Permafrost Hydrates Low Low Low Shoe Fracture/Lost Returns during cement 'ob Low Interval Risks Miti ation Strate Monitor cellar continuousl durin interval. Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud; Hi dens sweeps. Controlled ROP Controlled drilling, reduced pump rates, higher mud weights, cold mix water and mud, lower viscosities, and lecithin additions as needed Reduced pump rates, and lightweight tail cement Event Risk Level Mitigation Strategy Lost Circulation in High Good drilling practices. LCM as needed. Bermuda interval Stay within ECD Hardline of 11.1. High ECD and Low Pumping and rotating out on all trips to swabbing if higher reduce swab and barite sag potential. MW is required Hole stability during e- Moderate Emphasis on maintaining mud properties. line runs Clean out runs as needed. Good drilling practices ORIGINAL 2P-422 Drilling Hazards Summary. doc prepared by Pat Reilly 12/12/01 Page 1 of 1 ~ Meltwater 2P-~ ____2 Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +/- 110' MD Port Collar 1000' MD Depths are based on Doyon 141 RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 2877' MD / 2395' TVD 12' Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 BTCM run CSR to surface +/- 7750' MD I 5299 TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TD to CSR +/- 8777' MD I 5911' TVD ~., PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple KBf, -)."1 3-1/2" x 1" Camco '+æ1:fQ 29' Mandrels wI DVs and RK latch's (Max. OD 4.725", ID 2.90"), IBT box x box, 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced out wI 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/ DCK-3 shear valve and bottom latch (Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +1- 100' above top of the Bermuda (Or 100' above the top of the Cairn if the Cairn is present) or:}l err 11{ -~ .;; n ;;' ',_.,:'¡ 1 ~ . J ;) ~ PJR, 12/11/01 Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 12/11/2001 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 450% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 20' below base of permafrost.) Lead Slurrv (minimum pump time 186 min.) AS Lite @ 10.7 pp~, Class G + 50%0124,9%044,0.4%046,30%053, 1.5%S1, 1 .5%079' 4.44 ft Isk < TOC at Surface Pre.jous Csg. < 16",62.6#, H-40 grade Welded Connection at 120 ft. MD < Base of Permafrost at 1,495 ft. MD (1,452 ft. TVD) < Top of Tail at 1,515 ft. MD < 75/8",29.7#, L-80 grade BTC, AB Modified in 9 7/8" OH TO at 2,878 ft. MD (2,395 ft. TVD) Mark of Schlumberger 0.9513 fe/ft x (120') X 1.00 (no excess) = 0.2148 ft3/ft x (1495" 120') x 5.50 (450% excess) = 0.2148 fe/ft x (1515" 1495') x 1.45 (45% excess) = 114.2 fe + 1624.4 fe+ 6.2 fe = 1744.8 fe 14.44 ft%k = Round up to 400 sks 114.2 fe 1624.4 fe 6.2 ft3 1744.8 fe 393 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv (minimum pump time 133 min.) LiteCRETE @ 12.0 ppg' 2.40 fe/sk 0.2148 fe/ft x (2878" 1515') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 424.5 fe + 20.6 ft3 = 445.1 fel 2.40 ft%k = Round up to 190 sks 424.5 fe 20.6 fe 445.1 fe 185.5 sks BHST = 57°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 6 40 6.7 6.7 Orop Bottom Plug 5.0 11.7 MudPUSH XL 6 50 8.3 20.0 Lead Slurry 6 316 52.7 72.7 Tail Slurry 6 81 13.5 86.2 Drop Top Plug 5.0 91.2 Displacement 6 108 18.0 109.2 Bump Plug 3 20 6.7 115.9 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* XL, Pv = 17-20, T y = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client:· Phillips Alaska, Inc. Revision Date: 12/11/2001 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurrv (minimum thickening time 148 min.) GasBLOK wI Class G + D53, D600, D135, D800, D047, D065, per lab testing @ 15.8 ppg, 1.2 ft%k PrelÁous Csg. < 75/8",29.7#, L-80 grade BTC, AB Modified at 2,878 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 6 3/4" OH < Top of Tail at 7,250 ft. MD < X-o\er at 7,750 ft. MD < Top of Bermuda Fm. at 8,476 ft. MD < 31/2", 9.3#, L-80 grade EUE, 8rd Modified in 6 3/4" OH TO at 8,777 ft. MD (5,911 ft. TVD) Mark of Schlumberger 0.0835 ft3/ft x 500' X 1.75 (75% excess) = 0.1817 fe/ft x (8777" 7750') x 1.75 (75% excess) = 0.0488 ft3/ft x 80' (Shoe Joint) = 73.1 fe + 326.6 fe + 3.9 fe = 403.6 fel 1.2 fe/sk = Round up to 340 sks 73.1 ft3 326.6 fe 3.9fe 403.6 fe 336.3 sks BHST = 148°F, Estimated BHCT = 126°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 6 80 13.3 13.3 MudPUSH XL 6 40 6.7 20.0 Tail Slurry 6 73 12.2 32.2 Drop Top Plug 3.0 35.2 Displacement 6 94 15.7 50.9 Slow Rate 4 90 22.5 73.4 Bump Plug 2 9 4.5 77.9 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv '" 19-22, T y '" 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL /,"--, PHILLIF J Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ~ Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 December 13, 2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-422 Surface Location: Target Location: Bottom Hole Location: 901' FNL,2089' FWL,Sec. 17, T8N,R7E 356'FNL,53'FWL,Sec.21, T8N,R7E 555'FNL,189'FWL,Sec.21,T8N,R7E Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-422. The well will be drilled and completed using Doyon 141. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Steve Moothart, Geologist 265-6965 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. ~, Mö'~ Chuck Mallary Drilling Engineering Supervisor RêCê/VêD DEe 1 8 2001 Alaska Oil & Gas c AnChor: CommisSion ORIGINAL I / / ¡ .I ./ .r--- ;' 1"""'\ ./ .....".". ,:1' ,,/" ; ¡ ~ w Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 III 0000 iI. Oil. 3 ? 2111 I: 0 8 :ì gO'" 2 b 21: o g gOOOOuI /---- /",..." TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME kR!1 Z¡¿c/¿z- CHECK 1 CHECK WHAT APPLIES STANDARD LEITER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wenbore segment of existing weD ---'---' Permit No, . API No. . (If api number last two (2) Production should continue to be reported as a function of digits are between 60-(9) the original API number stated above. I DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), an records, data and REDRlLL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logS acquired for wen (name on permit). . EXPLORATION ANNULAR DISPOSAL Annular disposal has not been requested. . . L-.)NO INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L-.) YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRILL THIS WELL DlSPOS~ OrnER Please note that an disposal of fluids generated. .. . ANNULUS YES + SPACING EXCEPTION Enclosed is the approved application for permitto.drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates _ann. disposal para req _ ON/OFF SHORE 0/'1 serv _ wellbore seg UNIT# redrll PROGRAM: exp GEOLAREA WELL PERMIT CHECKLIST FIELD & POOL V ) ) c o z o -i :e ::0 - -i m - z -i J: - en > ::0 m » -YV -;J ?-It ¿ß~ 0~. .. ~y '1r Q,~......~~" ·N N <t:i- \ "'>: -'t-I+ ~ Þo... N \0 N N N N N Y~ CÎ>N 1. Pennit fee attached. . . . . . . . . . . ·.;d;h ~ . . /I.' . ~ 2. Lease number appropriate:* . ~ 0; . . I. . "r':l f . ~ -:-. V 3. Unique well name and number. .. . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . 7. Sufficient acreage available· in drilling unit.. . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . 11. Pennit can be issued without conservation order. . . 12. Pennit can·be issued without administrative approval 13. Can pennit be approved before 15-day wait. . . . sig. Conductor string provided . . . . . . . . ... .. Surface casing protects all known USDWs. . . . . . CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg. . . . CMT will cover all known productive horizons. . . . . .. Casing designs adequate for C, T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . . If a re-drill. has a 10-403 for abandonment been approved. Adequate wellbore separation proposed.. . . . . . . . If diverter required, does it meet regulations . . . . . . Drilling .fluid program schematic & equip list adequate. BOPEs, do they meet regulation . . . . . . . . . ';--";' BOPE press rating appropriate; test to S«)Ò'-...) Choke manifold complies w/API RP-53 (May 84) . Work will occur without operation shutdbwn. ., . Is presence of H25 gas probable.. . . . . Pennit can be issued w/o hydrogen sulfide measures. Data presented On potential overpressure zones . . . Seismic analysis of shallow gas zones. . . . . . . ~. . . . . Seabed condition survey (If off-shore). . . . . . . . . . . . Contact name/phone for weekly progress reports [ex tory only] 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. ADMINISTRA TlON ~ DATE I iZ fj.D ENGINEERING ~ DATE \;> I¡) \ GEOLOGY ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . .. ., (B) will not contaminate freshwater; or cause drilling waste. . to surface; (C) will not impair mechanical integrity .of the well used for disposal (D) will not damage producing formation or impair recovery from a pool; and E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. UIC/Annular COMMISSION: WM c, O\>t>~~~ o."~~\\J'S. '" DATE /2· 19.() APeR \)'~".>o.. \ ~<:::> c.. \~~ ~ ~ \\ Y N Y N Y N Y N Y N DATE APPR Commentsllnstructions: 11/01/100) GEOLOGY: ~ c:\msoffice\wordian\diana\checklist (rev. ~ ,--.., 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 readabilrty 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. .~ .--.... àOJ -al./ to /O~5/ .' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 08 13:46:45 2002 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 0 5 / 0 8 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .02/05/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field (Meltwater MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2P-422 501032040000 Phillips Alaska, Inc. Sperry-Sun Drilling Services 08-MAY-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22017 JASON PITCHE DEARL GLADDE MWDRUN 3 AK-MW-22017 JASON PITCHE GUY WHITLOCK MWDRUN 4 AK-MW-22017 JASON PITCHE GUY WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 5 AK-MW-22017 PHIL ROGER DEARL GLADDE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 17 8N 7E 901 2089 258.70 224.00 ~ ,-.. # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.750 CASING SIZE (IN) 16.000 7.625 DRILLERS DEPTH (FT) 120.0 2858.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, AND 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), AND PRESSURE WHILE DRILLING (PWD). RUN 2 WAS A WIPER TRIP - THESE DATA ARE NOT PRESENTED. 4. MWD RUNS 4 AND 5 COMPRISED DIRECTIONAL, DGR, PWD, ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4), STABILIZED LITHO-DENSITY (SLD) , AND COMPENSATE THERMAL NEUTRON POROSITY (CTN). DUE TO FILLED DOWNHOLE MEMORY, REAL-TIME DENSITY DATA ARE PRESENTED FROM 7519'MD - 7551'MD. THERE IS A GAP IN THE Pe DATA OVER THIS INTERVAL BECAUSE THESE DATA ARE CALCULATED FROM RECORDED DATA 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 4/16/02, QUOTING AUTHORIZATION FROM GKA GROUP. 6. MWD RUNS 1, 3, 4, AND 5 REPRESENT WELL 2P-422 WITH API# 50-103-20400-00. THIS WELL REACHED A TOTAL DEPTH OF 8853'MD / 5969'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA RATE. SBD2 BIN) . SC02 SNP2 SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC "~ ~ ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN PROCESSING POROSITY LOGS: FIXED HOLE SIZE: MUD WEIGHT: MUD SALINITY: CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: MATRIX: MATRIX DENSITY: $ File Header Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NPHI FCNT NCNT RPX RPS RPM RPD FET DRHO RHOB PEF $ 1 6.75" 9.6 - 9.9 PPG 27,000 - 32,000 PPM 22,727 PPM CHLORIDES 1.0 G/CM3 SANDSTONE 2.65 G/CM3 and clipped curves; all bit runs merged. .5000 START DEPTH 77.0 120.5 2835.0 2835.0 2835.0 2845.5 2845.5 2845.5 2845.5 2845.5 2859.5 2859.5 2859.5 STOP DEPTH 8798.0 8853.0 8750.0 8750.5 8750.0 8805.0 8805.0 8805.0 8805.0 8805.0 8765.5 8765.5 8765.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 3 4 5 MERGE TOP 77.0 1505.0 2878.0 7648.5 MERGE BASE 1505.0 2878.0 7648.5 8853.0 /~ ,-., # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 8853 4465 17553 77 8853 ROP MWD FT/H 0.08 719.03 96.653 17466 120.5 8853 GR MWD API 29.12 241. 87 119.474 17443 77 8798 RPX MWD OHMM 0.36 1135.89 4.54274 11920 2845.5 8805 RPS MWD OHMM 0.44 1136.02 4.62757 11920 2845.5 8805 RPM MWD OHMM 0.26 2000 5.02698 11920 2845.5 8805 RPD MWD OHMM 0.52 2000 8.36483 11920 2845.5 8805 FET MWD HOUR 0.57 159.54 2.73074 11920 2845.5 8805 NPHI MWD PU-S 7.27 56.3 32.6825 11831 2835 8750 FCNT MWD CNTS 114 1228 276.121 11832 2835 8750.5 NCNT MWD CNTS 13209 35004 19422.3 11831 2835 8750 RHOB MWD G/CM 1.96 3.83 2.40726 11813 2859.5 8765.5 DRHO MWD G/CM -0.12 1. 36 0.0542479 11813 2859.5 8765.5 PEF MWD BARN 1. 03 8.01 2.78455 11748 2859.5 8765.5 First Reading For Entire File......... .77 Last Reading For Entire File.......... .8853 Fi:;Le Trailer Service name............ .STSLIB.OOl Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 ~ Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/05/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ,~ header data for each bit run in separate files. 1 .5000 START DEPTH 77.0 120.5 STOP DEPTH 1462.5 1505.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 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 VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: 07-FEB-02 Insite 66.37 Memory 1505.0 120.0 1505.0 .2 23.4 TOOL NUMBER PB02406HWG6 9.875 120.0 Clayseal 9.85 63.0 8.4 30000 5.0 .000 .000 .000 .000 .0 87.8 .0 .0 ~. ............., MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 77 1505 791 2857 77 1505 ROP MWD010 FT/H 0.08 719.03 103.512 2770 120.5 1505 GR MWD010 API 29.12 108.51 69.04 2772 77 1462.5 First Reading For Entire File......... .77 Last Reading For Entire File.......... .1505 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Corrunent Record FILE HEADER FILE NUMBER: 3 RAW MWD /~ ,..--...... header data for each bit run in separate files. 3 .5000 Curves and log BIT RUN NUMBER; DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 1463.0 1505.5 STOP DEPTH 2835.0 2878.0 # LOG HEADER DATA DATE LOGGED; SOFTWARE SURFACE SOFTWARE VERSION; DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) ; 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 VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN); DRILLER'S CASING DEPTH (FT); # BOREHOLE CONDITIONS MUD TYPE; MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ); # REMARKS; $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined 14-FEB-02 Insite 66.37 Memory 2878.0 1505.0 2878.0 26.6 56.5 TOOL NUMBER PB02415HWG6 9.875 Clayseal 9.90 68.0 8.7 28000 5.0 .000 .000 .000 .000 .0 102.2 .0 .0 ~ .~. Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Channel 1 2 3 Offset o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1463 2878 2170.5 2831 1463 2878 ROP MWD030 FT/H 0.8 219.7 99.3454 2746 1505.5 2878 GR MWD030 API 40.13 148.24 90.0583 2745 1463 2835 First Reading For Entire File......... .1463 Last Reading For Entire File..... . . . . . .2878 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/05/08 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPS RPM FET RPX RPD PEF DRHO 4 header data for each bit run in separate files. 4 .5000 START DEPTH 2835.0 2835.0 2835.0 2835.5 2845.5 2845.5 2845.5 2845.5 2845.5 2859.5 2859.5 STOP DEPTH 7536.5 7536.5 7536.0 7583.5 7590.5 7590.5 7590.5 7590.5 7590.5 7519.0 7551.5 /~ RHOB ROP $ 2859.5 2878.5 7551.5 7648.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 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 VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ."...-..." 27-FEB-02 Insite 66.37 Memory 7648.0 2878.0 7648.0 52.0 56.0 TOOL NUMBER PB2459HAGR4 PB2459HAGR4 PB2459HAGR4 PB2459HAGR4 6.750 2858.0 Clayseal 9.60 50.0 8.6 32000 5.0 .030 .019 .120 .140 70.0 113.0 70.0 70.0 "~. .~ Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2835 7648.5 5241.75 9628 2835 7648.5 ROP MWD040 FT/H 0.27 355.18 95.9512 9541 2878.5 7648.5 GR MWD040 API 62.53 241.87 135.684 9497 2835.5 7583.5 RPX MWD040 OHMM 0.36 1135.89 4.50607 9491 2845.5 7590.5 RPS MWD040 OHMM 0.44 1136.02 4.61855 9491 2845.5 7590.5 RPM MWD040 OHMM 0.26 2000 5.10669 9491 2845.5 7590.5 RPD MWD040 OHMM 0.52 2000 9.16002 9491 2845.5 7590.5 FET MWD040 HOUR 0.58 159.54 2.76893 9491 2845.5 7590.5 NPHI MWD040 PU-S 7.27 56.3 34.3661 9403 2835 7536 FCNT MWD040 CNTS 114 1228 244.365 9404 2835 7536.5 NCNT MWD040 CNTS 13209 35004 18645.2 9404 2835 7536.5 RHOB MWD040 G/CM 1. 96 3.83 2.39069 9385 2859.5 7551.5 DRHO MWD040 G/CM -0.12 1. 36 0.0536036 9385 2859.5 7551.5 PEF MWD040 BARN 1. 99 8.01 2.80729 9320 2859.5 7519 First Reading For Entire File......... .2835 Last Reading For Entire File.......... .7648.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER ,---... FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT RPS RPX PEF RHOB DRHO GR RPM RPD FET ROP $ 5 ,~ header data for each bit run in separate files. 5 .5000 START DEPTH 7536.5 7537.0 7537.0 7547.5 7547.5 7552.0 7552.0 7552.0 7584.0 7591.0 7591.0 7591.0 7649.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8750.0 8750.5 8750.0 8805.0 8805.0 8765.5 8765.5 8765.5 8798.0 8805.0 8805.0 8805.0 8853.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 28-FEB-02 Insite 66.37 Memory 8853.0 7648.0 8853.0 49.4 54.5 TOOL NUMBER PB2459HAGR4 PB2459HAGR4 PB2459HAGR4 PB2459HAGR4 6.750 Clayseal 9.80 47.0 8.8 27000 5.0 .170 .103 .140 .200 70.0 120.2 70.0 70.0 ~. ~ HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . .'. . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7536.5 8853 8194.75 2634 7536.5 8853 ROP MWD050 FT/H 0.75 310.03 88.4763 2409 7649 8853 GR MWD050 API 79.84 195.85 146.897 2429 7584 8798 RPX MWD050 OHMM 1. 37 12.86 4.67285 2516 7547.5 8805 RPS MWD050 OHMM 1.42 11.51 4.65614 2516 7547.5 8805 RPM MWD050 OHMM 1.44 10.33 4.71554 2429 7591 8805 RPD MWD050 OHMM 1. 62 10.87 5.25771 2429 7591 8805 FET MWD050 HOUR 0.57 31. 69 2.5815 2429 7591 8805 NPHI MWD050 PU-S 13.07 38.17 26.1625 2428 7536.5 8750 FCNT MWD050 CNTS 211 819 399.119 2428 7537 8750.5 NCNT MWD050 CNTS 17544 29672 22433.2 2427 7537 8750 RHOB MWD050 G/CM 2.15 2.78 2.47128 2428 7552 8765.5 DRHO MWD050 G/CM -0.01 0.57 0.0567381 2428 7552 8765.5 PEF MWD050 BARN 1. 03 3.87 2.69725 2428 7552 8765.5 First Reading For Entire File......... .7536.5 Last Reading For Entire File.......... .8853 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/08 /-~ ,--.... Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name........... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 0 5 / 0 8 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .02/05/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File