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Home My WebLink About204-202 · . Image Project Well History File Cover Page 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 sèanned during a special rescan activity or are viewable by direct inspection of the file. d...o '1-- aO d-- Well History File Identifier Organizing (done) D Two-sided 11111111111 III" III D Rescan Needed 1111111111111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date '1;)./ () 7 /s/ ~p 111111111111111111/ Project Proofing BY: ~ Date I/;;"j 0 7 ~ = (P(!J /s/ ~ tob Scanning Preparation = TOTAL PAGES (Count does not include cover sheet) /s/ + BY: Date: J 111111111111111111/ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ Date:I/~07 If NO in stage 1, page(s) discrepancies were found: YES NO Stage 1 /s/ MF NO BY: BY: Maria Date: /s/ 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc I � Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK -69 PO Box 196105 Anchorage, 6 99519-6105 ConocoPhillips Phone: (907)659 -7535 Fax: 659 -7314 I November 10, 2010 Dan Seamount AOGCC Commissioner NOV 1 U10 10 State of Alaska, Oil & Gas Conservation Commission th i t �, ' Cons. Ui r "w310P 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 13iIYfliara Dear Mr. Seamount, Enclosed you will find 10 -404 reports of Sundry Well Operations recording the isolation of the B sands for West Sak Well 1E -168, 168L1, 168L2 (PTD 204 -200, 204 -201 04 -' � 202). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey Attachments Sundry notification Well schematic t STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed. it w ell ate Other A andon Rea Perfor St b p ❑ Aug Plu Ft' ❑ Q Pull D ISO SLV ❑ 9 ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Fool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development G Exploratory ❑ - 204-202 3. Address: 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic F71 Service ❑ - 50 029 - 23230 - 61 7. Property Designation (Lease Number): 8. Well Name and Number: ALK 25651 ►1 E -1681-2 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11960 feet Plugs (measured) None true vertical 3514 feet Junk (measured) None Effective Depth measured 11989 feet Packer (measured) 6943, 6982 true vertical 3512 feet (true vertucal) 3446, 3453 Casing Length Size MD TVD Burst Collapse D -SAND LINER 4908 6.65 11937 3513 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7122 -11896 True Vertical Depth: 3483 -3581 'I Tubing (size, grade, MD, and TVD) 4.5, L -80, 6982 MD, 3453 TVD '10V 1 2 2010 Packers & SSSV (type, MD, and TVD) NIPPLE - DB -6 NIPPLE / 3.812 @ 6943 MD and 3446 TVD 3s" - A oil & Gas Cons, Ca `33ion LOCATOR - LOCATOR SUB @ 6982 MD and 3453 TVD AI1ftratle 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 600 111 176 790 260 Subsequent to operation 144 462 700 859 273 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service ❑ Stratigraphic ❑ r G STOR Well Status after work: ^ Oil 17 Gas ❑ WDSPL Daily Report of Well Operations X ❑ WINJ ❑ WAG r GINJ ❑ SUSP ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Darrell Humphrey /Bob Christesen Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659 -7535 Date t f' I fO l { R$DMS N O V I 2 �r.,�. Form 10-404 Revised 10/2010 Submit Original Only 1E-168L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/03/10 PULLED ISO SLEEVE FROM D -LAT @ 7046' CTMD, PULLED IBP FROM A -LAT @ 7458' CTMD,WELL LEFT SHUT IN, RETURN IN THE AM TO RE- INSTALL ISO SLEEVE (IN PROGRESS) 11/05/10 SET ISO SLEEVE IN B -LAT LEM @ 7391' CTMD, WELL LEFT SHUT IN, TURN OVER TO DSO (COMPLETE) II KUP 1 E-1 68L2 Conoa;Phillips , all Attributes ax Angle & MD J Alaska it 1t, --- IIbore API /UWI Fleltl Name Well Status Intl ( °) MD (rtKB) Act.." (fll(0) 500292323061 WESTSAK PROD 92.28 8,730.18 11,960.0 Comment H23 (ppm) Data Annotation End Date 110431d (R) Rig Release Date Wall Conti.: - re -166' n�rm1 rss.o9 aM SSSV: NIPPLE 65 816/2009 Last WO: 2/10/2007 34.69 11/2612004 thematic- Nat Annotation DepN (ftKO) Entl Date Annotation Laat Mod ... End Date Last Tag: Rev Reason: Set ISO SLV B Lateral, Pull IBP Imosl or 11/6/2010 Casing Strings Casing Description String 0... String ID ... Top (rtKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 23 D-;= LINER 41/2 3.958 7,029.4 11,936.9 3,512.7 12.60 L -80 DWC Liner Details Top Depth (TVD) Top Intl Noml... Top InKS) (RKB) (°) Item Description Comment ID (in) 7,029.4 3,4623 79.361 HANGER BAKER MODEL B-1 FLANGED HOOK HANGER 5.660 11,898.3 3,511.01 87.50 BUSHING BAKER DRILLABLE PACKOFF BUSHING 2.380 Perforations & Slots Shot Top (TVD) Stm (TVD) Den. Top (RKB) BM IRKS) IRKS) (RKB) Zone Data (.h... Type Comment 7,122.0 11,896.0 3,478.5 3,510.9 WS D, 1 E -168L2 11/2312004 32.0 IPERF Slotted Uner 2.5" x' 125" wide, 4 circurnf rows, 3" centers staggered 18 CONDUCTOR, deg 2&;06 Notes: General & Safe End e Annotation NIPPLE, 469 12/23/200 NOTE: TRI- LATERAL WELL: 1E- 168(A- SAND), 1E- 168L7(B- SAND), 1E- 168L2(D -SAND) 2/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Schernat(c9.OREV GAS LIFT. 4270 I t _ SURFACE, 26 -4.41 s GAS LIFT, 6,706 NIPPLE, 6, 943 LOCATOR, 6,962 SEAL ASSY, 6,983 D -SAND window, 7,031 -7,043 D -SAND LINER LEM, I 8.97 7,321 PRODUCTION, 27 -8,156 Akndfel Details Top Depth Top Port (TVD) Intl OD Val- Latch Size TRO Run Stn Top(RKB) IRKS) ( °) Make Modei (in) S— Type Type (in) (psi) Run Data Co.... IPERF, 1 4,270.2 2,423.4 66.45 CAMCO KBMG 1 GAS LIFT GLV BKS 0.188 1,531.0 2/20/2004 7.122- 11'896 2 6,708.2 CAMCO KBMG 1 GAS LIFT OV BK -5 0.250 0.012/20/2D07 D -SAND LINER, 7,029-11,937 TD (1 E- 168'2), 11,960 • • _8~$ Y.~ :. .gyp: MICROFILMED 43/01/2448 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\L.aserFicl~\CvrPgs_InsertslMicrafilm Marker.cbc . . RECEIVED MAR 0 2 Z007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "AIAAI'A na ø. ~.... f""n.. - 0 Repair Well Q Plug Perforations 0 Stimulate 0 . .._~n~ \.ij( 1. Operations Performed: Abandon Other A orage . Alter Casing 0 Pull Tubing Q Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory 0 204-202 1 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23230-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-168L2 - 8. Property Designation: 10. Field/Pool(s): ALK 25651, ADL 469/466 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11960' . feet true vertical 3515' feet Plugs (measured) . Effective Depth measured 11898' feet Junk (measured) true vertical 3512' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 4387' 10-314" 4415' 2477' PRODUCTION 8130' 7-5/8" 8158' 3715' SLOTTED LINER 4908' 4-1/2" 11937' 3513' :R \. Î' -::pO ;ørC:> ~ Perforation depth: Measured depth: slotted liner from 7122'-11896' '.:\.0= (L<£. -;P ~.c>. 'i ~.~ ,,1,0" S::v.--...-¡ q... '1'f"I .0"1 true vertical depth: 3478'·3511' -ç:. - Þ ~\ \.0 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6983' MD. \ ~, Packers & SSSV (type & measured depth) HRD ZXP liner top packer @ 6974.8'~CANNED JUL 1 1 2007 Cameo DB nipple @ 469' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable I reatment deSCriptions including vOlumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 680 269 197 -- 185 Subsequent to operation 528 291 636 -- 295 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development Q Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: n/a Contact Jill Long @ 265-1102 Printed Name Ji1a"/ Title Wells Group Engineer Signature è!y I' :?: Phone Date 03/01/07 ~ LtJJ ~ ¡(. (! PreDared bv Sharon AI/suo-Drake 263-4612 1/ C/... i:\ u ., REPORT OF SUNDRY WELL OPERATIONS n J Form 10-404 Revised 04/2004 U\~\G \~AL RBDMS 8FL ,/UL 11 2ßDj.ß....Zß~2/..£ Submit Original Only -r ø~?/4Ø /'" .ÁÞ ~ -2... .0/ ~ .. ~ TUBING (0-<5983, 00:4.500, 10:3.958) 'ROOUCTION (0-8158, 00:7.625, Wt:29.70) SURFACE (!M415, 00:10.750, Wt:45.50) Gas Lift I ndrel/Dummy Valve 2 (6708-<5709, 00:6.437) NIP (6943-6944, 00:5.210) SEAL (6983-6984, 00:4.740) HANGER (7029-7030, 00:7.000) BLANK LINER (7029-7122, 00:4.500, Wt:12.60) Perf (7122-11896) SLOTTEO LINER (7122-11936, 00:4.500, Wt:12.60) . . ConocoPhillips Alaska, Inc. ... I I I '3 == ~ == -== == -~ m== =_ ~~ I r == ~m ::::¡ E == == -== I = ...~ ~ i ~ ~ I ~.'." == == ~- 2I1ËiI!i2'1~-",,;. .. API: 500292323061 SSSV Type: NONE Well TVDe: PROD Orig 11/26/2004 ComDletion: Annular Fluid: Last W/O: 2/1012007 Reference Loa: 28' RKB Ref Loa Date: LastTan: TD: 11960 ftKB Last Tan Date: Max Hole Anale: 92 dea íaJ 8730 ~~øntSt6n '*" ~é<. ,~ ' BBIL DescriDtion Size PRODUCTION 7.625 CONDUCTOR 20.000 SURFACE 10.7!:D WINDOW 7.000 "., è Ugn¡¡¡IIIIIIlllEEEI_¡' Size I 4.500 I 4.500 I TOD o o o 7031 Bottom 8158 108 4415 7032 IDescriDtiòn I BLANK LINER I SLOTTED LINER --ø.n:-strin ' ~ß ; Size TaD 4.500 0 lemIllRI11øh'šiis'umma Interval TVD 7122 - 11896 3478- 3511 TOD 7029 7122 Bottom , 7122 , 11936 "",t~( I I KRU 1 E-168L2 Anale íaJ TS: deQ (éiJ Angle @ TD: 87 deg @ 11960 Rev Reason: WORKOVER Last UDdate: 2115/2007 TVD Wt Grade Thread 3509 29.70 L-80 BTC-M 108 62.50 H-40 WELDED 2478 45.50 L-BO BTC 3463 0.00 TVD T Wt Grade I Thread 3478 I 12.60 I L-80 I DWC 3513 I 12.60 I L-80 I DWC 1tt~~@~I;~:{Jnlti%, ' Thread IBT TVD 3454 Wt Grade I 12.60 I L-80 T //::1&:. I I Bottom 6983 I Zone WS D,WS D,WSD Status Ft SPF Date Tvne 4774 32 11/2312004 IPERF Comment Slotted Liner 2.5" x .125" wide, 4 circumf rows, 3" centers staQQered 18 deQ 1 4270 2423 CAMCO KBMG SOV 2 6708 3384 CAMCO KBMG DMY 0.111 -'" . í.I,ô¡¡¡¡:etei A -!!I'..11m De th TVD Tvoe DescriDtion 7029 3462 HANGER I BAKER MODEL B1 FLANGE HOOK HANGER 11935 3513 SHOE BAKER GUIDE SHOE ~E:ÐfUQs./·Ø"-:¡'''''''O._a'I!1[.mllIII Denlh TVD TVDe DescriDtion 469 467 NIP CAMCO DB NIPPLE 2/9/2007 6943 3446 NIP CAMCO DB-6 NIPPLE 2/9/2007 6983 3454 SEAL GBH-22 LOCATING SEALASSEMBLYwlLOCATOR SUB 2/912007 7029 3462 HANGER BAKER MODEL B1 FLANGE HOOK HANGER FOR D-SAND L2 IiR1iIiêcalllløllS!:'; . Dai~ T Note 2/23/2004 NOTE: TRI-LATERAL WELL: 1E-1681A-SAND\, 1E-168L 11B-SAND\, 1E-168L2/D-SAND) d.·!ltliaanrlliè_j:â.s St MD TVD Man Mfr Man Type ;liIi V Mfr J<Ä\'l~' V Type VOD ~ .,\ii'~1j ,: Latch Port TRO Date Run Vlv Cmnt 1.0 1.0 BK-5 BK-5 0.000 0.000 2/9/20Ul 219120Ul o o I 10 I 4.500 I 0.000 10 3.875 3.812 3.880 4.500 ~ ~ D!t..t:- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042020 Well Name/No. KUPARUK RIV U WSAK 1E-168L2 Operator CONOCOPHILLlPS ALASKA INC .s;. LLd.. (~(\¡"tv ~ '1 API No. 50-029-23230-61-00 MD 11960./'" TVD ~ ~- 3515 ~ Completion Date 11/26/2004 Completion Status 1-01L Current Status 1-01L ule N --_._"---~------------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~-"----_.._-_._._~-- --~- ~---~_._._-_._. ._~.- ..-...------ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number t (data taken from Logs Portion of Master Well Data Maint I nd u ctio n/Resistivity Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments --~~~._- 7375 11960 1/5/2005 7030 7913 1/5/2005 PB1 25 Blu 108 11960 6/10/2005 Multiple Propagation Resistivity Gamma Ray/RWD 25 Blu 108 11960 6/10/2005 Multiple Propagation Resistivity Gamma Ray/RWD 108 11960 Open 6/10/2005 Multiple Propagation Resistivity /Gamma Ray Open 6/10/2005 Multiple Propagation Resistivity /Gamma Ray 108 7914 Open 6/14/2005 MPR/GR/RWD-PB 1 25 Blu 108 7914 Open 6/14/2005 MPRlGR/RWD-PB 1 Name Directional Survey Directional Survey I nd uction/Resistivity e Tf e Las 13158 I nd u ctio n/Resistivity 13158 LIS Verification 13171 I nd u ction/Resistivity 13171 I nd u ction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~N Well Cored? Y ìlti) Chips Received? -. / 14 Formation Tops ~N ·è/N Daily History Received? Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042020 Well Name/No. KUPARUK RIV U WSAK 1E-168L2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23230-61-00 MD 11960 TVD 3515 eompletion Date 11/26/2004 eompletion Status 1-01L eurrent Status 1-01L ule N ----..------ --~~----- Comments: Compliance Reviewed By: _~ Date: ( ~~--~--~-~- ----\p ( , STATE OF ALASKA AlA"sJ(A Oil AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged D Abandoned D Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other _X Pre-Produced Injector Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. 0( 204-202 or Aband.: November 26, 2004 3. Address: 6. Date SPudded~ (~ 11f1 UX:>Ý 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 Qd ?r 28, £06'4 .,¿]> 1.7.- ðÇ' 50-029-23230-61 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM November 21 , 2004 , 1E-168L2 At Top Productive ,-- 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 489' FNL, 1617' FEL, Sec. 22, T11 N, R10E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1302'FNL, 1243'FEL, Sec. 15,T11N,R10E,UM 11898' MD /3512' TVD \"b ¡r~ ..s~tAd LA..fb-4...l ,4l) 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: /-7·oÇ Surface: x- 549890 . y- 5959380 I Zone- 4 11960' MD 1 3515' TVD ALK 25651 TPI: x- 554195 y- 5959127 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 554529 y- 5963597 Zone-4 nla ADL 469/466 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1895' MD 21. Logs Run: '"1'/ ¿J~.~ "7, 031'" ;?1z:> GRlRes 3~&./"3¡' 'Tvb 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT GRADE BOTTOM BOTTOM CEMENTING RECORD CASING SIZE WT. PER FT. TOP TOP SIZE PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 250sx AS I 10.75" 45.5# L-80 28' 4415' 28' 2477' 13.5" 720 sx AS Lite, 220 sx DeepCrete 7.625" 29.7# L-80 28' 8158' 28' 3715' 9.875" 422 sx DeepCrete 4.5" 12.6# L-80 7029' 11937' 3463' 3513' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6158' slots in liner from 7122'-11896' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED slots are 32 slots/ft n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 12, 2004 Gas Lift oil - production shared with 1 E-168 and 1 E-168L 1 Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 12/12/2004 7 hours Test Period --> 693 382 13 25 Bean 603 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (carr) press. 463 psi not available 24-Hour Rate -> 2323 1400 46 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RECEIVED RBDMS 8FL JAN 0 7 200~ONE f DEC 2 2 2004 If. ?l...óc/ '.iJ!;':':; Alaska Oil & Gas Cons. Commission Anchorage t .~ ~I Form 10-407 Revised 12/2003 CONTINUED ON REVERSE OR\G\NAL 28. 29. GEOLOGIC MARKERS >',....-." FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-168L2 West Sak D 7475' 3503' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 p~intedN~d~ Signature .- Title: Phone KUDaruk Drillina Team Leader 4r bß 3"0 Date l '2:../ e to (0 <1' 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: Blow down steam and water lines, disconnect service loops and prepare to move rig Moved rig off 1 E-114 and moved to 1 E-168 Spotted sub base over well, set in rig complex's and RU, hooked up service loops and completed rig acceptance checklist Accepted Rig @ 12:00 hrs 10/27/04 NU 21 1/4" 2M diverter system with 16" line, began mixing spud mud and loading pipe shed with 5" DP & HWDP Changed over top drive and iron roughneck from 4" to 5" DP Slip and cut 106' of drlg line and serviced top drive PU and stood back in derrick 38 stds of 5" DP and 10 stds of 5" HWDP and Jars Function test diverter system and checked ok, Chuck Scheeve W / AOGCC waived witnessing of test Began PU 13 1/2" BHA #1 to rig floor MU 13 1/2" bit, mud motor with 1.8 deg bend on BHA #1and tagged ice at 85' Flooded conductor checking lines for leaks and pressure tested surface equipment Cleaned out ice and cement inside conductor from 85' to 108' Spudded well and drilled 13 1/2" hole from 108' to 231', ART 1 hr POOH to 53', MU MWD and oriented, then MU UBHO sub and oriented, PU 3- NM flex DC's RIH to 231' Drilled 13 1/2" hole per directional plan from 231' to 900' MD/ 865' TVD (669') ART 1.7 hrs, AST 2.3 hrs, 10-15K wob, 40-60 rpm's, 140 spm, 592 gpm, off btm pressure 1,300 psi, on btm 1,400 psi, off btm torque 2K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 85K, dn wt 83K, took 2-gyro surveys on slickline at 279' and 369' 10.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 900' to 2,034' MD/ 1,602' TVD (1,134') ART 2.6 hrs, AST 4.5 hrs, 10-20K wob, 60 rpm's, 140 spm, 592 gpm, off btm pressure 1,600 psi, on btm 1,850 psi, off btm torque 4K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 95K, dn wt 82K Monitored well-static Circ to clear BHA and pumped out of hole from 2,034' to HWDP at 1 ,110', pumped out at 300 gpm at 500 psi, monitored well at HWDP-static POOH on elevators from 1,110' to 650' to change out motor per directional plan, no problems POOH Fin POOH, stood back HWDPand MWD, LD 1.8 deg bend MM and bit MU RR bit and 1.2 deg bend MM and oriented, RIH with MWD and HWDP, MU ghostreamer RIH to 1,115' RIH from 1,115' to 1,951', washed 83' to btm at 2,034 with no problems Drilled 13 1/2" hole per directional plan from 2,034' to 3,061' MD/ 1,972' TVD (1,027') ART 4.2 hrs, AST .7 hrs, 5-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,250 psi, on btm 2,350 psi, off btm torque 5K ft-Ibs, on btm 9K ft-Ibs, rot wt 86K, up wt 103K, dn wt 76K, 9.4 ppg MW, 200 Vis 12.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 3,061' to 4,361' MD/2,459' TVD (1,300') ART 6.2 hrs, AST 1.7 hrs, 10-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,400 psi, on btm 2,600 psi, off btm torque 11 K ft-Ibs, on btm 14K ft-Ibs, rot wt 98K, up wt 147K, dn wt 63K, 9.4 ppg MW, 180 Vis Began seeing gas hydrates at 3,800' MD/ 2,236' TVD 02:00 - 06:00 4.00 MOVE MOVE MOVE 06:00 - 12:00 6.00 MOVE RURD MOVE 12:00 - 14:30 2.50 WELCT NUND SURFAC 14:30 - 17:00 2.50 DRILL RIRD SURFAC 17:00 - 18:30 1.50 RIGMNT RSRV SURFAC 18:30 - 23:00 4.50 DRILL PULD SURFAC 23:00 - 23:30 0.50 WELCT BOPE SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 1 0/28/2004 00:00-01:15 1.25 DRILL PULD SURFAC 01:15 - 01:45 0.50 DRILL CIRC SURFAC 01 :45 - 02:00 0.25 CEMEN COUT SURFAC 02:00 - 03:15 1.25 DRILL DRLG SURFAC 03: 15 - 05:00 1.75 DRILL TRIP SURFAC 05:00 - 12:00 7.00 DRILL DRLG SURFAC 12:00 - 22:00 22:00 - 22: 15 0.25 DRILL OBSV SURFAC 22: 15 - 23:30 1.25 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC 10/29/2004 00:00 - 02:00 2.00 DRILL TRIP SURFAC 02:00 - 03:30 1.50 DRILL PULD SURFAC 03:30 - 04:00 0.50 DRILL TRIP SURFAC 04:00 - 12:00 8.00 DRILL DRLG SURFAC 12:00 - 00:00 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 0.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 4,361' to 4,425' MD/ 2,481' TVD (64') (Csg pt) ART .3 hrs, AST -0- hrs, 10-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,400 psi, on btm 2,600 psi, off btm torque 11 K ft-Ibs, on btm 13K ft-Ibs, rot wt 100K, up wt 150K, dn wt 63K, 9.4 ppg MW, 160 Vis Circ hole to clear BHA, circ at 700 gpm, 2,400 psi Monitored well-static Backreamed out of hole from 4,425' to BHA at 1,115', back reamed out at 110 rpm's, 550 gpm at 1,700 psi, last 2 stds pulled slower to circ hole clean, no problems POOH Monitored well at BHA-static, LD ghost reamer, POOH standing back HWDP, LD std of NM flex DC's, MWD, motor and bit, cleared rig floor RU Doyons 10 3/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of csg MU 103/4" float shoe, 2 jts 103/4" 45.5# L-80, BTC csg and fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 2,030' (49 Jts & 1-10' pup jt), st wt up 117K, dn wt 77K RIH circ csg down from 2,030' to 2,301' circ out heavy mud, circ hole clean while RIH, staged pump rate up to 6 bpm at 375 psi Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,419' and float collar at 4,335', no problems RIH, Ran a total of 106 jts (4,373') of 45.5#, L-80, BTC csg and 1-10' pup jt, total including float equip, csg and hanger, 4,389', ran 15 bow spring centralizers and 2 stop rings per well plan, st wt up 215K, dn wt 62K Began to circ and cond mud thru fill up tool, circ at 4 bpm 350 psi While reciprocating pipe, csg hanger snagged riser causing the riser to PU out of diverter causing 4 bbls of mud to spill into cellar, cleaned up cellar and reinstalled riser Cont to circ and condition mud thru fill up tool, staged pump rate up to 7 bpm at 490 psi, circ 2X btms up, st wt up 195K dn wt 66K LD Franks fill up tool, blow down top drive and MU Dowell cement head Fin circ and cond mud for cementing, circ at 7 bpm, 450 psi, conditioned mud from 9.6 ppg, 83 vis, PV 23, YP 41 to 9.3 ppg, 39 vis, PV 14, YP 12, Hanger was tagging 1" high, pulled hanger to rig floor and looked ok with small area of scarring, held PJSM with Dowell, APC vac truck drivers and rig crew while circ hole 1.25 CEMEN PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped add. 40 bbls of CW 100 (50 bbls Total), then pumped 50 bbls of 10.5 ppg XL Mudpush, ave 5 bpm at 200 psi, shut down and dropped btm plug, began mixing and pumping lead cement, at report time have pumped 200 bbls of 570 bbls of 10.7 ppg Arctic set lite cement, st wt up 195K, dn wt 67K 1.00 CEMEN PUMP SURFAC Cont to cement 103/4" csg, pumped an additional 370 bbls of lead cmt (570 bbls total, 720 sxs) at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 150 psi, followed with 97 bbls, 220 sxs of tail cmt at 12.0 ppg and 2.49 yield with add. ave 6 bpm at 320 psi, shut down and dropped top plug. NOTE: while reciprocating pipe and after pumping 475 bbls of lead cmt and with 50 bbls of lead cmt out of shoe, pipe stuck off hanger 1', attempted to work pipe down with no success, was able to PU on pipe, but was unable to get back down into hanger, PU on pipe 5' to get hanger and pup jt above landing ring, Landed csg with fit shoe at 4,414' with fit collar at 4,330' 1 0/30/2004 00:00 - 00: 15 00: 15 - 00:30 0.25 DRILL CIRC SURFAC 00:30 - 00:45 0.25 DRILL OBSV SURFAC 00:45 - 05:45 5.00 DRILL REAM SURFAC 05:45 - 09:00 3.25 DRILL PULD SURFAC 09:00 - 10:45 1.75 CASE RURD SURFAC 10:45 - 11 :00 0.25 CASE SFTY SURFAC 11:00-14:15 3.25 CASE RUNC SURFAC 14:15 - 15:45 1.50 CASE RUNC SURFAC 15:45 - 18:30 2.75 CASE RUNC SURFAC 18:30 - 18:45 CIRC SURFAC 18:45 - 19:15 OTHR SURFAC 19:15 - 20:30 CIRC SURFAC 20:30 - 21 :00 0.50 CEMEN RURD SURFAC 21 :00 - 22:45 1.75 CEMEN CIRC SURFAC 22:45 - 00:00 10/31/2004 00:00 - 01 :00 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 1 0/31/2004 01 :15 - 01 :45 0.50 CEMEN SURFAC 01 :45 - 05:00 3.25 WELCT SURFAC 05:00 - 06:00 SURFAC 06:00 - 09:00 3.00 WELCT SURFAC 09:00 - 12:00 3.00 WELCT SURFAC 12:00 - 13:45 1.75 DRILL RIRD SURFAC 13:45 - 14:30 0.75 RIGMNT RSRV SURFAC 14:30 - 15:30 1.00 WELCT NUND SURFAC 15:30 - 18:15 2.75 WELCT SURFAC 18:15 - 23:00 4.75 WELCT SURFAC 23:00 - 23:30 0.50 DRILL OTHR SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 11/1/2004 00:00 - 00:30 0.50 DRILL RIRD SURFAC 00:30 - 04:00 3.50 DRILL PULD SURFAC 04:00 - 07: 15 3.25 DRILL PULD SURFAC 07:15 - 07:45 0.50 DRILL RIRD SURFAC 07:45 - 11 :00 3.25 DRILL PULD SURFAC 11 :00 - 11 :30 0.50 DRILL TRIP SURFAC 11 :30 - 12:00 0.50 DRILL SFTY SURFAC 12:00 - 12:15 0.25 RIGMNT RGRP SURFAC 12:15 - 13:15 1.00 DRILL TRIP SURFAC 13:15 - 14:00 0.75 DRILL DEOT SURFAC 14:00 - 15:00 1.00 DRILL TRIP SURFAC 15:00 - 16:00 1.00 DRILL TRIP SURFAC 16:00 - 16:30 0.50 DRILL CIRC SURFAC 16:30 - 17:30 1.00 CASE DEOT SURFAC 17:30 - 20:45 3.25 CEMEN DSHO SURFAC Dowell pumped 20 bbls FW and turned over to rig and rig displaced cmt with 398 bbls of 9.4 ppg mud, ave 7 bpm, initial pressure 550 psi, max pressure 800 psi, slowed to 4 bpm and bumped plugs on calc displacement to 1,400 psi, ck floats and floats held, CIP at 01 :15, Had 178 bbls of 10.7 ppg lead cmt back to surface NOTE: Had 1 Hr time change Flushed CMT out of diverter system and flowline ND diverter line and lifted up riser, diverter and starting head, set 10 3/4" emergency slips with 50K Ibs string wt, made rough cut on 10 3/4" csg and set diverter back down RD cement head, LD landing jt with hanger and cut-off piece of 10 3/4" csg ND diverter and starting head, used crane to set out dverter system over flow line of well 1 E-28. DSO had well shut in during operation. Made final cut on 103/4" csg and GBR welder welded on Vetco/Gray csg head adapter per Vetco/Gray procedure. VetcoGray rep present for complete operation. Changed out saver sub, bell guide and grabber on top drive to 4" Serviced top drive and drawworks while allowing well head to cool down, tested weld on adapter head to 2,000 psi for 10 min and ck ok Oriented and NU Vetco/Gray 13 5/8" 5M# MB 222 wellhead, tested btm wellhead sub to 5,000 psi for 10 min and ck ok NU BOP stack RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC waived witnessing of test Installed wear bushing RIH with 4 stds of 5" DP from derrick and POOH LD same Changed out 5" handling tools over to 4" DP PU and RIH with 72 jts (24 stds) of 4" XT-39 DP, POOH and stood back PU and RIH with 63 jts (21 stds) of 4" XT-39 DP, POOH and stood back Changed out 4" handling tools over to 5", cleaned rig floor MU 97/8" BHA #3 with Autotrak tool, MPS, stop sub and float sub, uploaded Autotrak, PU 3-NM flex Dc's & RIH with HWDP and jars, MU ghost reamer RIH with BHA #3 from 1,077' to 2,007' with 5" DP Held tripping drill with rig crew and post drill discussion Worked on Iron roughneck, top door latch wouldn't close, hydraulic ram broke POOH from 2,007' to BHA at 1,077' checking connections to ghost reamer due to iron roughneck hydraulic ram breaking and ck ok RI H to 1,160' and shallow tested Autotrak tool, staged pump rate up to 550 gpm, had MWD pulse but no confirmation RIH from 1,160' to 2,007' RIH from 2,007' to 4,324' Circ hole evening MW in & out at 9.3 ppg for csg test, circ at 595 gpm, 2,400 psi, rot wt 90K, up wt 142K, dn wt 62K, 12K ft-Ibs torque at 60 rpm's RU and tested 10 3/4" csg to 3,000 psi for 30 min, good test RIH and tagged plugs above float collar, drilled out plugs, float collar at 4,330', shoe track, float shoe at 4,414' and cleaned out to btm at 4,425', drilled 20' of new formation to 4,445' MD/2,488' TVD, 5-30K wob, 60-90 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/1/2004 17:30 - 20:45 3.25 CEMEN DSHO SURFAC rpms, 595 gpm at 2,300 psi, ADT .2 hrs 20:45 - 21 :45 1.00 DRILL CIRC SURFAC Displaced out 9.3 ppg spud mud in hole with reconditioned 9.0 ppg LSND 21 :45 - 23:00 1.25 DRILL LOT SURFAC RU & performed LOT to 10.7 ppg EMW at 2,447' TVD with 9.3 ppg MW and 220 psi, downlinked Autotrak and discussed LOT with town and decision was made to drill ahead 23:00 - 00:00 1.00 DRILL DRLG INTRM1 Drilled 97/8" hole from 4,445' to 4,511' MDI 2,512' TVD (66') ADT .4 hrs, 5-15K wob, 80 rpm's, 551 gpm, 1,900 psi, off btm torque 14K ft-Ibs, on btm 14K ft-Ibs, rot wt 94K, up wt 160K, dn wt 57K, while drilling out of shoe GRlResistivity tool failed on Autotrak tool. 11/2/2004 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 Circ btms up while POOH from 4,511' to 4,414' to csg shoe, circ at 550 gpm, 1,900 psi and 40 rpm's 01 :00 - 01 :15 0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job 01 :15 - 02:00 0.75 DRILL TRIP INTRM1 POOH from 4,414' to 3,861', decision was made to RIH and drill ahead thru curve section with Autotrak tool then POOH and PU mud motor and MWD, back-up RNT/DIR tool had dead battery and would not be able to use with Autotrak tool and also would allow time to put tools in pipe shed to warm up 02:00 - 03:00 1.00 DRILL TRIP INTRM1 RIH from 3861' to 4,421', washed 90' to btm at 4,511' and downlinked Autotrak to ribs on 03:00 . 12:00 9.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4,511' to 5,542' MD/2,970' TVD (1,031') ADT 5.3 hrs, 5-15K wob, 120 rpm's, 138 spm, 585 gpm, off btm pressure 2,550 psi, on btm 2,600 psi, off btm torque 6K ft-Ibs, on btm 7K ft-Ibs, rot wt 99K, up wt 120K, dn wt 82K, with 9.0 ppg mud, clean hole ECD was 9.6 ppg, while drlg with 9.1 ppg mud, ECD ave 10.3 ppg, added 2% lubricants to mud, rig and camp off highline at 08:30 hrs 12:00 . 23:00 11.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole from 5,542' to 6,941' MDI 3,445' TVD (1,399') ADT 6.4 hrs, 5-20K wob, 120 rpm's, 585 gpm, off btm pressure 3,075 psi, on btm 3,125 psi, off btm torque 6K ft-Ibs, on btm 8K ft-Ibs, rot wt 100K, up wt 128K, dn wt 84K, 9.2 ppg mud, ECD ave 11.0 ppg with no mud loss, preparing to POOH to LD Autotrak tool, rig and camp back on highline at 13:45 hrs 23:00 . 23:30 0.50 DRILL CIRC INTRM1 Circ for survey and clear BHA, downlinked Autotrak tool to backreaming mode (steering mode w/-O- force), monitored well-static 23:30 . 00:00 0.50 DRILL REAM INTRM1 Began backreaming out of hole from 6,941' to 6,564', backreaming out at 120 rpm's, 585 gpm at 3,100 psi with no problems 11/3/2004 00:00 . 03:45 3.75 DRILL REAM INTRM1 Backreamed out of hole from 6,564' to 5,448', backreamed at 120 rpm's, 585 gpm, 3,000 psi, pumped out of hole from 5,448' to 4,327' to inside 103/4" csg, pumped out at 585 gpm, 2,500 psi 03:45 - 04: 15 0.50 DRILL CIRC INTRM1 Circ hole clean at 4,327', circ at 585 gpm, 2,400 psi 04: 15 - 04:30 0.25 DRILL OBSV INTRM1 Monitored well-static, pumped dry job 04:30 - 05:45 1.25 DRILL TRIP INTRM1 POOH from 4,327' to BHA #3 at 1,077' 05:45 - 06: 15 0.50 RIGMNT RGRP INTRM1 Repaired hydraulic leak on iron roughneck 06:15 - 08:30 2.25 DRILL PULD INTRM1 Stood back HWDP, jars and NM flex DC's, download MWD/Autotrak and LD same 08:30 - 11 :15 2.75 DRILL PULD INTRM1 MU 97/8" BHA #4, 63/4" mud motor with 1.1 deg bend, MAP/MPR and MWD, oriented and uploaded MWD, RIH with NM flex DC's, HWDP, jars and ghost reamer to 1,113' 11:15 -12:00 0.75 DRILL TRIP INTRM1 RIH from 1,113' to 2,041' 12:00 - 12:15 0.25 DRILL DEQT INTRM1 Shallow tested MWD at 2,041', circ at 490 gpm at 2,100 psi and tool ck ok 12:15 - 13:15 1.00 DRILL TRIP INTRM1 RIH from 2,041' to 4,360', st wt up 115K, dn wt 76K Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1 0/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/3/2004 13:15 - 14:15 1.00 RIGMNT RSRV INTRM1 Slip and cut 65' of drlg line and serviced top drive 14:15 - 15:45 1.50 DRILL TRIP INTRM1 RIH from 4,360' to 6,885', washed down 56' to btm at 6,941' with no problems 15:45 - 17:30 1.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 6,941' to 7,149' MDI 3,490' TVD (208') ADT 1.1 hrs, 5-10K wob, 120 rpm's, 138 spm, 585 gpm, off btm pressure 3,150 psi, on btm 3,250 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs, rot wt 101 K, up wt 135K, dn wt 78K 17:30 - 18:30 1.00 RIGMNT RGRP INTRM1 Changed out swivel packing on top drive 18:30 - 00:00 5.50 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 7,149' to 7,630' MDI 3,595' TVD (481') ADT 3.3 hrs, 5-20K wob, 90-120 rpm's, 138 spm, 585 gpm, off btm pressure 3,250 psi, on btm 3,300 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, rot wt 100K, up wt 137K, dn wt 75K, 9.3 ppg MW, ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units Est top of West Sak "D" at 7,029' MDI 3,463' TVD, Est top of "B" sand at 7,353' MD/3,535' TVD 11/4/2004 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 7,630' to 8,158' MDI 3,715' TVD (528') ART 1.4 hrs, AST 2.1 hrs, 5-15K wob, 90 rpm's, 138 spm, 585 gpm, off btm pressure 3,300 psi, on btm 3,400 psi, off btm torque 10K ft-Ibs, on btm 9K ft-Ibs, rot wt 100K, up wt 135K, dn wt 80K, 9.3 ppg MW, ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units 06:00 - 06:15 0.25 DRILL OBSV INTRM1 Monitored well-static 06:15 - 08:00 1.75 DRILL REAM INTRM1 Backreamed out from 8,158' to 7,072', backreamed out at 120 rpm's, 585 gpm, 3,300 psi with no problems 08:00 - 10:30 2.50 LOG DLOG INTRM1 Backreamed out and logged up from 7,072' to 6,250' to above K-13 top, logged at 5-10'/min, 120 rpm's, 585 gpm 3,300 psi 10:30 - 13:15 2.75 DRILL REAM INTRM1 Cont to backream out of hole from 6,250' to 5,577', till ghost reamer was at csg shoe then pumped out of hole from 5,577' to 4,360', 120 rpm's, 585 gpm, 2,750 psi, st wt up 128K, dn wt 77K 13:15 - 14:15 1.00 DRILL CIRC INTRM1 Circ hole clean at 4,360', circ at 585 gpm, 2,400 psi, 80 rpm's and 7K ft-Ibs torque, circ 2X btms and was clean at shakers 14:15 - 15:00 0.75 DRILL CIRC INTRM1 POOH 1 std to 4,267' and hole taking proper fill, pumped 40 bbl EMI 920 lubricant pill and spotted in hole to 500' 15:00 - 18:00 3.00 DRILL PULD INTRM1 Dropped 5" DP wiper dart and POOH LD 102 jts of 5" DP 18:00 - 20:30 2.50 DRILL PULD INTRM1 POOH LD 5" HWDP, jars and ghost reamer, downloaded MWD and LD BHA #4, cleared rig floor and pulled wear bushing 20:30 - 21 :30 1.00 CASE RURD INTRM1 RU Doyons 7 5/8" csg equipment with Franks fill up tool 21 :30 - 22:00 0.50 CASE SFTY INTRM1 Held PJSM with rig crew and tong operator on running of 7 5/8" csg 22:00 - 00:00 2.00 CASE RUNC INTRM1 RIH with 75/8",29.7#, L-80, BTC-M csg to 1,140', MU 75/8" Float shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru float equip and ck ok, RIH with 22 add. jts along with pup jts for spacing out to 1,140' 11/5/2004 00:00-01:15 1.25 CASE RUNC INTRM1 RIH with 75/8" csg from 1,140' to 2,002' 01 :15 - 01 :45 0.50 CASE CIRC INTRM1 Circ a csg capacity at 2,002', circ at 3 bpm at 300 psi 01 :45 - 04:15 2.50 CASE RUNC INTRM1 RIH with 7 5/8" csg from 2,002' to 4,380' to above 103/4" csg shoe 04: 15 - 05:30 1.25 CASE CIRC INTRM1 LD Franks fill up tool, MU circ swedge and circ a csg capacity at shoe, staged pump rate up to 5 bpm at 350 psi, st wt up 110K, dn wt 75K, changed out rubber cup on fill up tool and made tool back up 05:30 - 10:15 4.75 CASE RUNC INTRM1 Fin RIH with 7 5/8" csg, RIH to btm at 8,158' with no problems. Landed 75/8" csg at 8,157' MDI 3,715' TVD with float collar at 8,026', ran a total of 189 jts 7 5/8",29.7#, L-80 BTC-M csg with 5-pup jts (Total 8,165.95'), ran 58 tandem rise cent on 58 stop rings per well plan, 3/2 jts (every 30'), did not use hanger, will use emergency slips 10: 15 - 11: 15 1.00 CEMEN CIRC INTRM1 Circ btms up thru Franks fill up tool while conditioning mud, staged Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/5/2004 10:15 -11:15 11:15 -11:45 11 :45 - 13:30 1.00 CEMEN CIRC INTRM1 0.50 CEMEN RURD INTRM1 1.75 CEMEN CIRC INTRM1 13:30 - 15:00 1.50 CEMEN PUMP INTRM1 15:00 - 16:15 1.25 CEMEN DISP INTRM1 16:15 - 17:00 0.75 CASE DEQT INTRM1 17:00 - 17:30 0.50 CEMEN RURD INTRM1 17:30 - 18:15 0.75 CASE NUND INTRM1 18:15 - 20:30 2.25 CASE OTHR INTRM1 20:30 - 21:15 0.75 CASE NUND INTRM1 21:15 - 22:45 1.50 CASE RURD INTRM1 22:45 - 23:00 0.25 WELCT BOPE INTRM1 23:00 - 00:00 1.00 DRILL OTHR I NTRM1 11/6/2004 00:00 - 02:00 2.00 DRILL OTHR INTRM1 02:00 - 08:00 6.00 DRILL PULD INTRM1 08:00 - 10:30 2.50 DRILL PULD INTRM1 10:30 - 14:45 4.25 DRILL TRIP INTRM1 14:45 - 15:15 0.50 RIGMNT RSRV INTRM1 15:15 - 17:30 2.25 DRILL TRIP INTRM1 17:30 - 18:00 0.50 CEMEN DSHO INTRM1 pump rate up to 6 bpm, 525 psi, st up wt 190K, dn wt 80K LD Franks fill up tool and MU Dowells cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 425 psi, st wt up 200K, dn 85K, initial MW out, 9.6 ppg, 78 vis, PV 32, YP 40, Conditioned mud to final MW out of 9.2 ppg, 41 vis, 11 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100, Pumped 50 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 168.2 bbls, (422 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 250 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. Rig displaced cement with 9.3 ppg OBM, Bumped plug on calc displacement after pumping 368.3 bbls OBM (96% pump eff.) ave 7.0 bpm while displacing cmt, Max pressure 1100 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 16:10 hrs, Reciprocated pipe until 73.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating wi Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had full returns thru out job. Tested 75/8" csg to 3,000 psi for 30 min, good test RD cement head and used rig vacuum to drain landing jt ND & PU on BOP stack Set 7 5/8" csg slips with 135K block wt, 100K st wt, made rough cut using cold cut saw and LD cut piece, made final cut and installed pack-off, Tested same to 3800 psi fl 10 min. NU BOP stack and choke line RD Doyons 7 5/8" csg equipment, changed out elevator bales and installed wear bushing NOTE: at 21 :30 Pumped 30 bbls fresh water down 7 5/8" x 10 3/4" annulus, ave 1 bpm at 720 psi Tested choke line at 250 psi and 3,500 psi, due to breaking flange on stack to set slips Loaded pipe shed with 4" XT -39 DP and strapped Cont. to load 4" DP into pipe shed and strap, Pumped 10 bbls add. water down 7 5/8" x 10 3/4" annulus at 1 bpm, 680 psi PU and stood back 4 stds 4 3/4" DC's, 9 stds hybrid push pipe (2-dc's, 1 hwdp), 11 stds of 4" HWDP NOTE: Finished flushing 7 5/8" x 10 3/4" annulus with 135 bbls water (175 total) after CIP 12 1/2 hrs and surface cement was hard, initial rate 1 bpm at 720 psi, final rate 2 bpm at 700 psi MU 6 3/4" BHA #5 with 4 3/4" MM with 1.2 deg bend and MWD, oriented and uploaded MWD, MU 3-NM flex DC's and std of HWDP with jars RIH to 251'. NOTE: Little Red freeze protected 7 5/8" x 10 3/4" annulus with 90 bbls diesel RIH with BHA #5 from 251' to 4,835', PU singles of 4" XT-39 DP from pipe shed, shallow tested MWD at 1,185' Serviced top drive and inspected saver sub Cont RIH with BHA #5 from 4,835' PU DP from pipe shed, tagged plugs above float collar at 8,026' Drilled out float collar at 8,026', shoe track, float shoe at 8,157' and 20' Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/6/2004 17:30 - 18:00 of new formation to 8,178' MD/ 3,716' TVD, ADT.1 hrs, 5-15K wob, 70 rpm's, 255 gpm, 2,200 psi, rot wt 84K, up wt 119K, dn wt 65K 18:00 - 19:30 1.50 DRILL CIRG INTRM1 PU till bit was up into csg and circ hole clean evening MW in and out at 9.1 ppg, circ at 297 gpm, 2,350 psi, circ 2X btms up 19:30 - 20:15 0.75 DRILL LOT INTRM1 RU and performed LOT to 14.8 ppg EMW, 1,110 psi at 3,715' TVD and 9.1 ppg OBM 20:15 - 00:00 3.75 DRILL DRLG PROD Drilled 63/4" hole in "A" sand lateral from 8,178' to 8,500' MD/ 3,722' TVD, (322') ART 1.5 hrs, AST .4 hrs, 2-5K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 7K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 137K, dn wt 53K, clean hole ECD with 9.1 ppg OBM was 10.5 ppg, drlg with 9.1 ppg OBM, ave ECD 10.8 ppg, Est top of West Sak "A" 8,357' MD/3,719' TVD 11/7/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 63/4" hole in "A" sand lateral from 8,500' to 9,778' MD/ 3,711' TVD (1,278') ART 5.1 hrs, AST 1.7 hrs, 2-5K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,550 psi, on btm 2,650 psi, off btm torque 8K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 140K, dn wt 51 K, 9.0+ ppg OBM, ave ECD 10.9 ppg, ave BGG 250 units, max gas 650 Units from 8,500' 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 63/4" hole in "A" sand lateral from 9,778' to 11,136' MD/ 3,739' TVD (1,358') ART 6.1 hrs, AST 1.1 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,050 psi, off btm torque 9K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 160K, dn wt 35K (blk wt, -0- dn wt), pumped weighted hi vis sweep at 10,900' and had 10% increase in cuttings back, 9.1 ppg OBM, ave ECD 11.4 ppg, max EGD 11.8 during sweep ave BGG 175 units, max gas 350 units, on last stand unable to slide due to -0- dn wt, preparing to backream out of hole 15 stds, and RIH with 5 stds HWDP 11/8/2004 00:00 - 03:00 3.00 DRILL WIPR PROD Backreamed out of hole 15 stds to wipe hole from 11,136' to 9,781', backreamed at 120 rpm's 318 gpm 2,700 psi, pulled 1st 13 stds to get a btms up, pulled last 2 stds slow to get add. btms up and clean at shakers 03:00 - 03:15 0.25 RIGMNT RGRP PROD Changed out hi-low drum clutch control valve on drillers console 03:15 - 04:00 0.75 DRILL TRIP PROD RIH with 10 stds 4" DP then RIH with 5 stds HWDP to 11,078' and washed 58' to btm, no problems, st up wt 150K, dn wt 57K 04:00 - 12:15 8.25 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "A" sand lateral from 11,136' to 11,927' (791'), ART 2.9 hrs, AST 1.4 hrs, 2-7K wob, 120 rpm's, 318 gpm, off btm pressure 3,150 psi, on btm 3,500 psi, off btm torque 8.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 92K, up wt 160K, dn wt 49K, 9.0+ OBM, ave EGD 11.3 ppg, ave BGG 150 units, max gas 300 units, attempted to slide and was unable to get wt to bit 12:15 - 12:45 0.50 DRILL TRIP PROD Pumped out of hole 3 stds of 4" DP from 11,927' to 11,700', RIH with 3 stds hybrid push pipe 12:45 - 14:15 1.50 DRILL DRLG PROD Directionally drilled 63/4" hole in "A" sand lateral from 11,927' to 12,073' MD/ 3,723' TVD (146'), ART .4 hrs, AST .4 hrs, 2-7K wob, 120 rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,500 psi, off btm torque 9K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 100K, up wt 177K, dn wt 40K, 9.1 + OBM, ave ECD 11.5 ppg, ave BGG 75 units, max 150 units 14:15 - 14:45 0.50 DRILL CIRC PROD Circ hole and evaluate logs for geology, decision made to back ream out of hole to shoe to wipe hole and PU Lo-Tads for add. st wt and appears we drilled out of formation and will do a open hole sidetrack at +/- 11,725' 14:45 - 20:30 5.75 DRILL WIPR PROD Backreamed out of hole from 12,073' to 8,100' to inside 7 5/8" csg, backreamed out at 120 rpm's, 318 gpm, 3,050 psi, no problems Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 21 :45 - 23:00 1.25 DRILL TRIP PROD 23:00 - 00:00 1.00 RIGMNT RSRV PROD 11/9/2004 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 05:30 5.00 DRILL TRIP PROD 06:00 - 08:15 2.25 DRILL DRLG PROD 08:15 - 09:15 1.00 DRILL CIRC PROD 09:15 - 12:15 3.00 DRILL DRLG PROD 12:15 - 00:00 11.75 DRILL DRLG PROD 11/10/2004 00:00 - 03:45 3.75 DRILL DRLG PROD 03:45 - 04:00 0.25 DRILL CIRC PROD 04:00 - 04: 15 0.25 DRILL OBSV PROD 04:15 -11:15 7.00 DRILL REAM PROD 11 :15 - 12:45 1.50 DRILL CIRC PROD 12:45 - 16:00 3.25 DRILL TRIP PROD 16:00 - 18:30 2.50 DRILL CIRC PROD 18:30 - 18:45 0.25 DRILL OBSV PROD 18:45 - 00:00 5.25 DRILL TRIP PROD 11/11/2004 00:00 - 04:00 4.00 DRILL TRIP PROD Pumped weighted hi vis sweep and circ hole clean at 8,100', had no increase in cuttings back from sweep and circ an add btms up and clean at shakers, circ at 318 gpm, 2,450 psi, 80 rpm's and 6K ft-Ibs torque Monitored well-static, POOH wet from 8,100' to 6,698' to PU Lo-Tads, cleaned rig floor Slip and cut 74' of drlg line Service top drive and drawworks RIH from 6,698' to 11,725' installing Lo-Tads on 4" DP and HWDP (PU 61 Lo-Tads) Oriented to low side, time drilled and open hole sidetrack 6 3/4" hole from 11,725' to 11,765' and drilled to 11,809', AST 1.4 hrs, 2-5K wob, 318 gpm, 3,250 psi Setting up MWD database for sidetrack Cont. to sidetrack well, drilling 6 3/4" hole from 11,809' to 12,073' MD/3,753' TVD (At orig. hole depth) ART 1.1 hrs, AST .7 hrs, 2-5 k wob, 120 rpm's 75 spm, 318 gpm, off btm pressure 3,100 psi, on btm 3,250 psi, off btm torque 7.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 89K, up wt 145K, dn wt 55K, 9.0 ppg OBM, ave ECD 11.35 ppg, ave BGG 75 units, max gas 200 units Directionally drilled 6 3/4" hole in "A" sand lateral from 12,073' to 13,106' MD/ 3,767' TVD (1,033'), ART 4.6 hrs, AST 1.6 hrs, 2-8K wob, 120 rpm's, 318 gpm, off btm pressure 3,600 psi, on btm 3,800 psi, off btm torque 8.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 105K, up wt 183K, dn wt 40K, 9.1 OBM, ave ECD 11.55 ppg, ave BGG 150 units, max gas 325 units, Directionally drilled 6 3/4" hole in "A" sand lateral from 13,106' to 13,477 MD/ 3,763' TVD (371'), (T.D.) ART 2.5 hrs, AST .1 hrs, 5-11 K wob, 120 rpm's, 318 gpm, off btm pressure 3,850 psi, on btm 4,050 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 107K, up wt 174K, dn wt 50K, 9.0+ OBM, ave ECD 11.6 ppg, ave BGG 200 units, max gas 375 units, pumped weighted hi vis sweep on last std Fin circ out weighted hi vis sweep and to clear BHA, had no increase in cuttings from sweep, circ at 318 gpm, 4,000 psi and 120 rpm's Monitored well-static Backreamed out of hole from 13,477' to 8,145' (7 5/8" csg shoe), backreamed out at 120 rpm's, 318 gpm, 3,800 psi with no problems Pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep and circ an add btms up and was clean at shakers, circ at 318 gpm, 2,450 psi, 80 rpm's with 6K ft-Ibs torque, rot wt 89K, up wt 113K, dn wt 75K RIH from 8,145' to 13,379', washed 98' to btm at 13,477', while RIH set down at 11,735', rotated string 180 deg and went thru spot, no other problems RIH Circ btms up at 13,477' then displaced out 9.1 ppg MOBM with 9.1 ppg SFMOBM, circ at 300 gpm, 3,600 psi, 120 rpm's and 10K ft-Ibs torque, rot wt 1 07K, up wt 164K, dn wt 69K Monitored well-static Dropped 1 3/4" rabbit and began POOH on elevators from 13,477' to 6,511' with no problems, monitored well at shoe-static, removed 11 Lo-tads from HWDP to be installed on 11 stds of 4" XT-39 DP POOH wet on elevators from 6,511' to BHA #5 at 67', stood back NM flex DC's and installed 11 Lo-Tads on DP on trip out Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1 0/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: Downloaded MWD and LD MWD and MM, cleaned rig floor, calc fill on trip out of hole 91 bbls, actual fill 121 bbls with 9.1 ppg SFMOBM in hole RU Doyon's 4 1/2" liner running equipment Held PJSM on running of liner PU and ran 41/2" liner per well program to 5,980', ran 4 1/2" ROT silver bullet guide shoe with no float, 192 jts, (5,943.11') of 4 1/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 89 jts (2,751.19') of blank liner and 103 jts (3,191.92') of slotted liner, ran 64- 41/2" x 61/4" spiralglide centralizers 1/jt jt #1 to Jt #54 and on jts with restrictor packers, then ran 108,41/2" x 53/4" straight blade centralizers 1/Jt on jts #55 thru #172 (csg shoe) ran 17 restrictor packers placed on blank liner to isolate shale sections per geology. MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 6,047' RIH with liner on 4" DP to 8,073' (csg shoe) est circ at 2.5 bpm, 200 psi, then rotated liner at 20 rpm's with 4K ft-Ibs torque, rot wt 80K, up wt 98K, dn wt 65K Cont to run 41/2" liner in open hole, RIH from 8,073' and tagged btm at 13,477' with no problems, PU to 13,473', st wt up 172K, dn wt 67K Note: RIH with 4" DP with Lo-Tads, HWDP, 4 stds 4 3/4" DC's and Push Pipe to run and set 41/2" liner 0.75 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 400 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, slacked off 30K, cont to set packer, pressured up to 3,900 psi and set ZXP packer, no problems setting hanger/packer, set "A" sand liner with Tal @ 7,437' MD/ 3,553' TVD and shoe at 13,473' MD 3,763' TVD, st wt up after setting liner 140K, lost 32K st wt RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck ok PU out of SBE 45' to 7,392' and circ btms up, circ at 7.5 bpm at 2,550 psi Monitored well-static POOH wet from 7,392' and LD Baker setting tool, cleaned rig floor, clac fill on trip out of hole 59 bbls, actual 64.5 bbls MU Baker 75/8" whipstock assembly BHA #6 and RIH to 560', MU milling assembly and LD same, PU seal assembly, locator sub, 3 1/2" DP pup jt, unloader sub, then PU 1 jt of 31/2" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 4 stds 4 3/4" DC's to 560' RIH with whipstock assembly from 560' to 6,440' Made MADD pass from 6,440' to 6,466' (6,320' to 6,346' sensor depth) and correlated MWD to K-13 sand RIH with whipstock from 6,466' to 7,400', st wt up 135K, dn wt 90K Oriented whipstock to 15 deg left of high side, RIH, tagged TOL at 7,437', set whipstock and sheared off from same, top of whipstock at 7,355' Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg MOBM, Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,355', btm of window at 7,367', drilled 6 3/4" hole to 7,386' MD/ 3,542' TVD (31'), 2-10K wob, 70-120 rpm's, 295-315gpm, 2,840 psi, rot wt 103K, up wt 11/11/2004 04:00 - 05:45 1.75 DRILL PULD PROD 05:45 - 06:15 0.50 CASE RURD CMPL TN 06:15 - 06:30 0.25 CASE SFTY CMPL TN 06:30 - 12:00 5.50 CASE PULR CMPL TN 12:00 - 12:45 0.75 CASE PULR CMPL TN 12:45 - 14:00 1.25 CASE RUNL CMPL TN 14:00 - 18:00 4.00 CASE RUNL CMPL TN 18:00 - 18:45 18:45 - 19:00 0.25 CASE DEQT CMPL TN 19:00 - 20:00 1.00 DRILL CIRC CMPL TN 20:00 - 20:15 0.25 DRILL OBSV CMPL TN 20: 15 - 00:00 3.75 DRILL TRIP CMPL TN 11/12/2004 00:00 - 02:30 ULD CMPL TN 02:30 - 07:45 CMPL TN 07:45 - 08:15 CMPL TN 08:15 - 09:15 CMPL TN 09:15 - 09:45 CMPL TN 09:45 - 10:30 0.75 WINDO CMPL TN 10:30 - 15:00 4.50 WINDO CMPL TN Printed: 12/1012004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1 0/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 12:00 - 00:00 132K, dn wt 92K, 5-8K ft-Ibs torque, pumped weighted hi vi sweep Circ out weighted hi vis sweep and circ hole clean, had 5% increase in cuttings from sweep, circ at 340 gpm at 3,200 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH from 7,386' to 80', stood back 4 3/4" DC's LD MWD and milling assembly and upper mill was in gauge, cleaned rig floor Pulled wear bushing and flushed out BOP stack RU and began testing BOPE, valves, choke manifold and rams to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, test witnessed by Chuck Scheve W / AOGCC Fin testing BOPE to 250 psi low and 3,500 psi high, test witnessed by Chuck Scheve with AOGCC Installed wear bushing and cleared rig floor MU 6 3/4" BHA #7, 4 3/4" motor with 1.2 deg bend and MWD, oriented and uploaded MWD, RIH to 251' RIH from 251' to 7,338', (above window at 7,355') shallow tested MWD at 1,652' and tool ck ok Slip and cut 72' of drlg line and serviced top drive Changed out XT-39 saver sub on top drive Oriented and RIH thru window and washed 18' to btm at 7,386' with no problems Directionally drilled 63/4" hole in "B" sand lateral from 7,386' to 8,886' MD/ 3,551' TVD (1,500'), ART 7.1 hrs, AST 1.7 hrs, 2-10K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 120K, dn wt 60K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 250 units, max gas 475 units 12.00 DRILL DRLG PROD2 Directionally drilled 63/4" hole in "B" sand lateral from 8,886' to 10,139' MD/3,553' TVD (1,253'), ART 5.8 hrs, AST 1.2 hrs, 2-14K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,700 psi, on btm 2,750 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 81 K, up wt 125K, dn wt 58K, 9.0+ ppg MOBM, ave ECD 11.0 ppg, ave BGG 275 units, max gas 430 units 12.00 DRILL DRLG PROD2 Directionally drilled 63/4" hole in "B" sand lateral from 10,139' to 11,145' MD/3,566' TVD (1,006'), ART 4.7 hrs, AST 2.1 hrs, 2-10K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,800 psi, on btm 2,900 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 90K, up wt 150K, dn wt 48K, 9.0+ ppg MOBM, ave ECD 11.2 ppg, ave BGG 200 units, max gas 420 units, Note: Drilled out of "B" sand from approx. 10,675' to 10,835' and drilled thru calcite stringers 8.25 DRILL DRLG PROD2 Directionally drilled 63/4" hole in "B" sand lateral from 11,145' to 11,969' MD/3,583' TVD (824') (T.D.), ART 3.9 hrs, AST .7 hrs, 2-14K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 3,500 psi, on btm 3,600 psi, off btm torque 9.5K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt 151 K, dn wt 67K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 200 units, max gas 420 units. T.D. well using hybrid wt pipe, NOTE Phase 3 weather condition field wide at 00:30 hrs 1.50 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out, had 10% increase in cuttings back from sweep, circ at 310 gpm, 3,500 psi, 120 rpm's 0.25 DRILL OBSV PROD2 Monitored well-static 6.00 DRILL REAM PROD2 Backreamed out of hole from 11,969' to 7,330' ( Above window at 16:00 - 16:15 CMPL TN 16:15 - 19:00 CMPL TN 19:00 - 20:00 CMPL TN 20:00 - 21 :30 CMPL TN 21 :30 - 00:00 CMPL TN 11/13/2004 00:00 - 01 :30 CMPL TN 01 :30 - 02:00 0.50 DRILL OTHR CMPL TN 02:00 - 03: 15 1.25 DRILL PULD PROD2 03: 15 - 07:30 4.25 DRILL TRIP PROD2 07:30 - 08:30 1.00 RIGMNT RSRV PROD2 08:30 - 09:45 1.25 RIGMNT RSRV PROD2 09:45 - 10:00 0.25 DRILL REAM PROD2 10:00 - 00:00 14.00 DRILL DRLG PROD2 11/14/2004 00:00 - 12:00 11/15/2004 00:00 - 08:15 08:15 - 09:45 09:45 - 10:00 10:00 - 16:00 Printed: 12/1012004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n 1334 @ ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/15/2004 10:00 - 16:00 6.00 DRILL REAM PROD2 16:00 - 17:30 1.50 DRILL CIRC PROD2 17:30 - 20:30 3.00 DRILL TRIP PROD2 20:30 - 00:00 3.50 DRILL CIRC PROD2 11/16/2004 00:00 - 08:45 8.75 DRILL TRIP PROD2 08:45 - 09:45 1.00 DRILL PULD PROD2 09:45 - 10:30 0.75 FISH PULD CMPL T2 10:30 - 12:00 1.50 FISH TRIP CMPL T2 12:00 - 14:00 2.00 FISH TRIP CMPL T2 14:00 - 15:30 1.50 FISH FISH CMPL T2 15:30 - 16:30 1.00 FISH CIRC CMPL T2 16:30 - 21 :30 5.00 FISH TRIP CMPL T2 21 :30 - 23:30 2.00 FISH PULD CMPL T2 23:30 - 00:00 0.50 FISH OTHR CMPL T2 11/17/2004 00:00 - 00:30 0.50 CASE RURD CMPL T2 00:30 - 01 :00 0.50 CASE SFTY CMPL T2 01 :00 - 04:45 3.75 CASE RUNC CMPL T2 7,355'), no problems, backreamed out at 120 rpm's, 310 gpm, initial circ pressure 3,300 psi, final pressure 2,200 psi, NOTE: Phase 3 lowered to Phase 2 at 11 :30 hrs Pumped weighted hi vis sweep and circ out, had no increase in cuttings back from sweep, circ additional btms up and clean at shakers, circ at 310 gpm, 2,200 psi, rot wt 85K, upwt 90K, dn wt 70K RIH from 7,330' to btm at 11,969' with no problems Circ hole 2 X btms up then displaced out 9.0 ppg MOBM to 9.1 ppg SFMOBM, circ at 70 spm, 300 gpm, 3,400 psi, 100 rpm's, rot wt 100K, up wt 150K, dn wt 60K, Phase 2 in effect Monitor well. Static. POOH on elevators. Monitor well at window. Static. No problems POOH. No tight hole noted. At TD, UP wt 165K, DN wt 65K. UD BHA. Download MWD. Clear rig floor. Hycalog 6-3/4" DSX146 rated O-O-NO-A-X-I-ER-TD. P/U Baker Whipstock retrieving assembly. BHA # 8: Retrieving hook, 1 jt 3-1/2" HWDP, FS, BS, Oil Jars, 4 stds 4-3/4" DC's, & XO. TIH to 2363' MD. Continue TIH to 7360' MD. Drill string above BHA: 54 stds 4" DP w/ Lo-Tads, 11 stds 4" HWDP, & 7 stds Hybrid Push Pipe. Latch & retrieve whipstock. Trip anchor sheared at 65K over. PU 1 std & CBU @ 75 spm at 2250 psi. - Had a 2 ppg gas cut bubble @ BU - Circu until fluid uniform out and in 9.1 ppg. Observe well. Static. POOH to Whipstock retrieving assembly. UD Baker Whipstock retrieving assembly, whipstock, debris barrier sub, US, shear disconnect, btm trip anchor, DP XO, 1 jt 3-1/2" HWDP, US, 3-1/2" pup jt, LS, & seal assembly. Clear & wash rig floor. Prep to run 4-1/2" B-Lat Liner. R/U equipment to run 4-1/2" liner. Held PJSM on running 4-1/2" liner w/ rig crew, casing hand, and company rep. PU & ran 4-1/2" liner per program to 4,542'. Ran 3-1/2" Baker guide shoe, 3-1/2· bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 145 jts (4,500.46') of 41/2" 12.6#, L-80, DWC liner. Placed blank liner across shale sections per geology, ran 137 jts (4,250.50') of slotted liner and 8 jts (249.96') of blank liner. Ran (141) 41/2· x 61/4· spiralglider centralizers 1/jt jt except on the 2 jts with constrictor packers (#34 & #39). Ran 2 constrictor packers placed on blank liner to isolate shale sections per geology f/ 10,678' MD to 10,833' MD. Up wt 66K, dn wt 54K. 0.25 CASE RUNC CMPL T2 M/U Baker Model B1 Flanged Hook Hanger & running tool. Up wt 70K, Dn wt 55K. 0.75 CASE CIRC CMPL T2 RIH 1 std of DP & break circulation. ROT WT 63K, TQ 2K ft-Ibs torque. 6.75 CASE RUNL CMPL T2 RIH with liner on 4· DP to csg shoe at 7,355' MD. Up wt 95K, Dn wt 65K. Cont to run 41/2" liner in open hole. RIH from 7,355' to 11,927' seeing 75% of centralizers exiting window f/ 8,934' MD to 10,435' MD (set dwn 15K max). Hook hanger on window on 2nd attempt. Unhook and rehook to verify. Up wt 160K, dn wt 80K. Drop 1-3/4· ball & pump to seat @ 3 BPM at 425 psi. Pressure up to 3500 psi to release running tool. Liner Running String - 53 stds 4· DP with Lo-Tads, 11 stds 4· HWDP, 4 stds 4-3/4· DC's, & 9 stds Hybrids. 04:45 - 05:00 05:00 - 05:45 05:45 - 12:30 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E -168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/17/2004 12:30 - 13:30 1.00 CASE CIRC CMPL T2 PU to verify release of liner & CBU @ 7.5 BPM at 2500 psi. Shut down & Monitor well. Static. 13:30 - 17:00 3.50 DRILL TRIP CMPL T2 POOH f/11 ,831' MD. 17:00 - 17:30 0.50 CASE RURD CMPL T2 UD liner running tool & clear rig floor. 17:30 - 18:30 1.00 CMPL TN PULD CMPL T2 MIU LEM assembly. 18:30 - 22:30 4.00 CMPL TN RUNT CMPL T2 TIH wI LEM assembly V 7480' MD. Up wt 140K, dn wt 95K. Latch LEM & slack-off 60K. PU & pull 10K over to verify latch. 22:30 - 23:00 0.50 CMPLTN CIRC CMPL T2 Drop 1-3/4" ball & pump to seat at 3 BPM at 375 psi. Pressure up to 4000 psi to release LEM. Pusher tool sheared at 2400 psi, ZXP set at 2800 psi, & pusher tool neutrilized at 3400 psi. Bleed off pressure & PU to verify release of running tool. Top of LEM at 7297' MD. 23:00 - 23:30 0.50 CMPL TN DEOT CMPL T2 Close Hydril & pressure test annulus (ZXP) to 1500 psi for 15 min. Held OK. 23:30 - 00:00 0.50 DRILL TRIP CMPL T2 Blow down top drive. Monitor Well. Static. 11/18/2004 00:00 - 03:45 3.75 DRILL TRIP CMPL T2 POOH f/7,297' MD. 03:45 - 04:15 0.50 DRILL PULD CMPL T2 Make service breaks and UD Baker running tool & hydraluic setting tool. 04:15 - 04:45 0.50 DRILL OTHR CMPL T2 Clear rig floor to run Whipstock. 04:45 - 07:00 2.25 WINDO ULD CMPL T2 M/U Baker 75/8" whipstock assembly. M/U seals & no-go, 3-1/2" pup, US, 7 jts 3-1/2" DP, DP XO, btm trip anchor, shear disconnect, US, debris barrier, 7-5/8" whipstock, starting mill, lower mill, flex jt, upper mill, 1 jt 3-1/2" HWDP, FS, Orient & Upload MWD, jars, 4 stds 4-3/4" DC, XO, & RIH to 742'. 07:00 - 07:45 CMPL T2 RIH with whipstock assembly to 830' & shallow test MWD. OK. 07:45 - 12:00 CMPL T2 Continue to RIH to 6,568' MD. Break circulation @ 7 BPM & 2100 psi. 12:00 - 12:30 CMPL T2 Made MADD pass from 6,619' MD to 6,643' MD and correlated MWD to K-13 shale. Continue to RIH to 7,291' MD. 12:30 - 13:00 CMPL T2 RIH to 7,291' MD. Orient and set Whipstock. Sheared off same. Top of Whipstock at 7,031' MD. 13:00 - 13:45 CMPL T2 Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg MOBM @ 7 BPM at 2100 psi. 13:45 - 18:00 CMPL T2 Milled window in 7 5/8" csg for "D" Lateral. Top of window at 7,031', btm of window at 7,043'. Drilled 6 3/4" hole to 7,061' MD 13,468' TVD (31'), 2-10K WOB, 70-120 RPM, 295-315 GPM, 2000-2200 psi, 5-8K ft-Ibs torque. 18:00 - 19:00 Pump hi vis sweep and circ hole clean. Circulate @ 7 BPM at 2100 psi. Worked mills thru window with no problem. Monitor Well. Static. 19:00 - 22:00 CMPL T2 POOH f/7,061' MD to BHA at 476' MD. 22:00 - 22:30 CMPL T2 UD Milling Assembly BHA. UD 4 stds 4-3/4" DC, jars, MWD, FS, 1 jt 3-1/2" HWDP, upper mill, flex jt, lower mill, & starting mill. 22:30 - 23:00 OTHR CMPL T2 Clear rig floor & pull wear ring. 23:00 - 00:00 THR CMPL T2 RIU & flushed BOP stack. 11/19/2004 00:00 - 00:30 0.50 WINDO OTHR CMPL T2 Install wear bushing & clear rig floor. 00:30 - 02:00 1.50 RIGMNT RSRV CMPL T2 Inspect saver sub, shim grabbers, & service top drive. 02:00 - 02:30 0.50 DRILL PULD PROD3 M/U 6-3/4" D-Lat BHA #10. PIU 6-3/4" bit, 1.2 deg motor, & MWD. 02:30 - 03:00 0.50 DRILL PULD PROD3 Upload MWD & Orient. 03:00 - 07:00 4.00 DRILL TRIP PROD3 RIH V 1,185' MD & shallow test MWD. Continue to RIH V 6947' MD filling pipe every 10 stds. 07:00 - 08:00 1.00 RIGMNT RSRV PROD3 Slip & cut 70' drilling line. Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1 0/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/19/2004 08:00 - 08:30 0.50 DRILL TRIP PROD3 Orient & pass thru window with no problems. Wash & ream f/7046' MD to 7061' MD. 08:30 - 12:00 3.50 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/7,061' to 7,470' MD / 3,498' TVD (409'), ART 1.3 hrs, AST 0.8 hrs, UP 125K, DN 55K, Rot 83K, TO on/off 6K/6K, 310 gpm @ 2400 psi, 2-10K WOB, 120 RPM, avg ECD's 10.8 ppg, Max gas 210 units. 12:00 - 16:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/7,470' to 7,913' MD / 3,489' TVD (443'), ART 0.6 hrs, AST 2.3 hrs, UP 125K, DN 55K, Rot 83K, TO on/off 6K/6K, 310 gpm @ 2300 psi, 2-10K WOB, 120 RPM, avg ECD's 10.7 ppg, Max gas 290 units. Geologist advised that after crossing fault @ 7475' MD we had not been able to stay in the sand and had come out the top @ 7640'. After conferring with the engineers in town the decision was made to back up and do an OH side track. 16:00 - 16:30 0.50 DRILL DRLG PROD3 Pump out of hole V 7431' MD to sidetrack well. 16:30 - 19:00 2.50 DRILL DRLG PROD3 Perform OH sidetrack f/ 7,431' MD to 7,555' MD, ART 0.6 hrs, AST 2.3 hrs, UP 123K, DN 55K, Rot 82K, TO on/off 5.5K/6K, 310 gpm @ 2450 psi, 0-2K WOB, 120 RPM, avg ECD's 11.6 ppg, Max gas 190 units. 19:00 - 20:00 1.00 DRILL DRLG PROD3 Running shale at 7,555' MD. Circulate hole clean @ 310 gpm at 1475 psi while recip & rot string. Max ECD 11.1 ppg, Max gas 180 units. 20:00 - 00:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 7,555' to 7,913' MD /3,508' TVD (358'), ART 1.9 hrs, AST 3.1 hrs, UP 115K, DN 65K, Rot 81 K, TO on/off 6K/6.5K, 310 gpm @ 2300 psi, 2-10K WOB, 120 RPM, avg ECD's 10.9 ppg, Max gas 260 units. 11/20/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/7,913' MD to 9,074' MD / 3,504' TVD (1161'), ART 5.8 hrs, AST 1.6 hrs, UP 117K, DN 63K, Rot 82K, TO on/off 7K/7.5K, 305 gpm @ 2400 psi, 0-15K WOB, 100-120 RPM, avg ECD's 11.0 ppg, Max gas 405 units. 12:00 - 00:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 9,074' MD' to 10,663' MD / 3,499' TVD (1589'), ART 9.0 hrs, AST 0.0 hrs, UP 125K, DN 55K, Rot 85K, TO on/off 9K/9K, 304 gpm @ 2400 psi, 0-5K WOB, 120 RPM, avg ECD's 11.5 ppg, Max gas 440 units. (NOTE: DWS costs from 11/8 to 11/18 were updated on today's report.) 11/21/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 10,633' MD to 11,683' MD (1,050'), ART 6.7 hrs, AST 1.0 hrs, UP 145K, DN 60K, Rot 97K, TO on/off 10K/9K, 305 gpm @ 3200 psi, 0-15K WOB, 120 RPM, avg ECD's 11.6 ppg, Max gas 430 units. 12:00 - 15:00 3.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 11,683' MD to TD at 11,960' MD / 3,515' TVD (277'), ART 1.1 hrs, AST 1.0 hrs, UP 150K, DN 65K, Rot 100K, TO on/off 1 0K/1 OK, 305 gpm @ 3300 psi, 2-10K WOB, 120 RPM, avg ECD's 11.8 ppg, Max gas 280 units. Pump weighted Hi-vis sweep on last connection. 15:00 - 16:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 70 spm at 3500 psi. 16:00 - 22:30 6.50 DRILL REAM PROD3 Back Ream out of hole at drilling rates V 7,140' MD. Pull thru window with no problems. 22:30 - 23:00 0.50 DRILL OBSV PROD3 POOH to 6,947' MD. Monitor Well. Static. 23:00 - 00:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 72 spm at 2250 psi. 11/22/2004 00:00 - 03:00 3.00 DRILL TRIP PROD3 Observe well. Static. TIH to 11,867' MD (fill DP at 9752'). Wash last std to btm at 11,960' MD. 03:00 - 05:30 2.50 DRILL CIRC PROD3 CBU @ 305 gpm at 3700 psi & 120 RPM. Displace entire mud system to 9.0 ppg Solids-Free OBM @ 305 gpm at 3700 psi. Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/22/2004 05:30 - 12:00 6.50 DRILL TRIP PROD3 Shut down & monitor well. Static. Blow Down Top Drive. POOH wet on elevators f/11 ,960' MD to 2,493' MD. 12:00 - 13:00 1.00 DRILL TRIP PROD3 Continue POOH f/ 2,493' MD to BHA. 13:00 - 15:00 2.00 DRILL PULD PROD3 UD BHA & Download MWD. UD all tools. Rerun Hycalog 6-3/4" DSX146 rated 0-1-CT-G-X-I-NO-TD. 15:00 - 15:30 ULD CMPL T3 Clear floor & P/U Whipstock retrieving assembly. P/U retrieving hook, 1 jt 3-1/2" HWDP, FS, bumber jar, oil jar, 4 stds 4-3/4" DC, & XO. 15:30 - 18:30 CMPL T3 RIH w/ Whipstock retrieving assembly. Run 50 stds 4" DP w/ Lo-Tads, 11 stds 4" HWDP, & 9 stds Hybrid Push Pipe. 18:30 - 19:00 0.50 WINDO CMPL T3 Hook whipstock on 2nd attempt & on depth. Sheared bolt at 35K over & Pull 60K over to unseat btm trip anchor. UP 140K, DN 88K. 19:00 - 20:00 1.00 WINDO CMPL T3 CBU @ 40 spm at 900 psi. Monitor well. Static. 20:00 - 00:00 4.00 WINDO CMPL T3 POOH w/ D-Lat whipstock to retrieving assebmly at 692'. 11/23/2004 00:00 - 03:00 3.00 WINDO CMPL T3 POOH standing back 4 stds 4 3/4" dc's and LD whipstock anchor assembly, cleaned rig floor 03:00 - 03:30 0.50 CASE RURD CMPL T3 RU Doyon's 4 1/2" liner running equipment 03:30 - 03:45 0.25 CASE SFTY CMPL T3 Held PJSM on running of liner 03:45 - 08:30 4.75 CASE PULR CMPL T3 PU & ran 4-1/2" liner per program to 4,875'. Ran 3-1/2" Baker guide shoe, 3-1/2" bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 156 jts (4,834.08') of 41/2" 12.6#, L-80, DWC liner, ran 154 jts (4,773.06') of slotted liner and 2 jts (61.02') of blank liner. Ran (154) 41/2" x 6 1/2" spiralglider centralizers, 1/jt on slotted liner none on blank liner 08:30 - 09:00 0.50 CASE PULR CMPL T3 M/U Baker Model B1 Flanged Hook Hanger & running tool. RIH 1 std and broke eire, Up wt 69K, Dn wt 58K. 09:00 - 10:15 1.25 CASE RUNL CMPL T3 RIH with 41/2" liner on 4" DP from 4,919' to 7,326' and tagged up on no go on "B" lat 10:15 - 11 :00 0.75 CASE OTHR CMPL T3 PU to 7,017' and re-oriented and after 3rd attempt, RIH thru window with bent jt and liner 11 :00 - 14:00 3.00 CASE RUNL CMPL T3 RIH with liner from 7,326' to 11,937' with no problems, st wt up 150K, dn wt 75K 14:00 - 17:00 3.00 CASE RUNL CMPL T3 Hooked hanger on window on 1st attempt at 7,046'. Unhook and rehook to verify setting 35K st wt down. Hooked window 3 times, unhooked and went past window 10' then rehooked 4 more times Up wt 150K, dn wt 75K. Drop 1-3/4" ball and pumped to seat @ 4 BPM at 900 psi, staged pump pressure up 3500,3700,4000, to 4,700 psi working pipe per Baker rep procedure to release running tool with no sign liner was released, rotated liner to safety off & release running tool, appeared running tool was not released, Shut down and conferred with town engineer and team leader. The decision was made to TOH and replace Hook Hanger, After confrence call we PU and running tool had released, st wt after releasing running tool 135K up and 90K dn wt. Liner Running String - 50 stds 4" DP with Lo-Tads, 11 stds 4" HWDP, 4 stds 4-3/4" DC's and 9 stds Hybrids, TOL at 7,029' with shoe at 11,937'. Went back down and tagged liner at setting depth Top. 17:00 - 18:00 1.00 CASE CIRC CMPL T3 POOH 1 std to 6,936' and circ hole clean, circ at 8 bpm at 2,600 psi, st wt up 135K, dn wt 90K 18:00 - 18:15 0.25 DRILL OBSV CMPL T3 Monitored well-static 18:15 - 20:30 2.25 DRILL PULD CMPL T3 POOH with running tool from 6,936' to 5,736', LD hybrid push pipe and 4 3/4" DC's 20:30 - 23:00 2.50 DRILL TRIP CMPL T3 POOH from 5,736' to Baker running tool 23:00 - 00:00 1.00 CASE RURD CMPL T3 LD Baker running tool and cleared rig floor, NOTE: Running tool appears to have released when safety released and not from pressure 11/24/2004 00:00 - 00:45 0.75 DRILL RIRD CMPL T3 RU to LD DP from mousehole Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n 1334 @ ppco.com Doyon 141 Start: 1 0/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/24/2004 11/25/2004 LD 18 stds 4" DP from derrick Slip and cut 78' of drlg line and serviced top drive Worked on pipe skate, got skate back into operation, will need to change out electric switch on skate Fin LD 4" DP & HWDP from derrick, LD an additional 87 stds of 4" DP, 61 stds with Lo-Tads and 11 stds of 4" HWDP Clear and clean rig floor RU to PU and stand back 41/2" completion tubing PU & RIH with 130 jts of 41/2", 12.6#, L-80 IBTM tbg to 4,000' Fin PU and RIH with 41/2",12.6#, L-80 IBTM-SCC tbg, RIH from 4,000' to 5,930' (PU a total of 192 jts) POOH and stood back 64 stds of 41/2" tbg, changed out seal rings on trip out Pulled wear bushing RU Centrilift to run ESP completion assembly Held PJSM with rig crew and Centrilift on running of ESP completion PU Centrilift's ESP motor assembly, tandem seal section with screen intake, filled motor with oil and connect ESP cable and checked same, Installed 1/4" control line for pump gauge Repaired Centrilift's protectorlizer clamp, clamp was used and had to change out bolts RIH with ESP assembly to 131', PU 2 jts 41/2",12.6#, L-80, IBTM SCC tbg and MU well discharge pressure sub Repaired Centrilift's air supply system for banding and clamping tools Connected 1/4" control line to discharge pressure sub and checked cable continuity RIH slow with ESP completion assembly from 131' to 4,900', running cable and installing cannon clamps on every other jt and checking cable conductivity every 1,000' 2.00 CMPL TN RUNT CMPL T3 Cont to RIH slow with ESP completion assembly from 4,900' to 6,168', running cable and installing cannon clamps on every other jt and checking cable conductivity every 1,000' 4.00 CMPL TN RUNT CMPL T3 MU Hanger and Landing jt with TWC, spliced ESP Cable and MU to tbg hanger, landed hanger and RILDS, Land string as per detail w/ Tail @ 6,220', Pump guage @ 6,216', Motor @ 6,182', Seal Section @ 6,168', screen intake @ 6,157' ( 68.3 deg), GLM #1 @ 5,390' MD ( 2,901' TVD), GLM #2 @ 4,195' MD (2,396' TVD), GLM #3 @ 138' (138' TVD), GLM #4 @ 89' (89' TVD), ran a total of 195 jts (6,024.66') of 4 1/2" 12.6#, L-80, IBTM tbg with special clearance collars, st wt up 90K, dn wt 61 K Parts used on ESP cable; 3 - Protectolizer guards= OD 5.875" 2 - Flat guards= OD 5.625" 14 - Flat stainless steel bands 106 - Cannon clamps= 6.75" ND BOP stack NU Vetco Gray tree and tested adapter void and tree to 250 psi low and 5,000 psi high Checked continuity on ESP cable and perform MEG test on penetrator and checked ok Pulled TWC and rig freeze protect well with 255 bbls diesel, Pumping down 4 1/2" tbg thru screen intake @ 6,157' with returns up 7 5/8" annulus, Had good diesel to surface. circ at 6 bpm at 800 psi 00:45 - 02:15 1.50 DRILL PULD CMPL T3 02: 15 - 03:45 1.50 RIGMNT RSRV CMPL T3 03:45 - 06:45 3.00 RIGMNT RGRP CMPL T3 06:45 - 18:30 11.75 DRILL PULD CMPL T3 18:30 - 19:30 1.00 DRILL OTHR CMPL T3 19:30 - 20:15 0.75 CMPL TN RURD CMPL T3 20: 15 - 00:00 3.75 CMPLTN RUNT CMPL T3 00:00 - 01 :30 1.50 CMPL TN PULD CMPL T3 01 :30 - 05:00 3.50 CMPLTN TRIP CMPL T3 05:00 - 05:30 0.50 CMPL TN OTHR CMPL T3 05:30 - 07:45 2.25 CMPL TN RURD CMPL T3 07:45 - 08:00 0.25 CMPL TN SFTY CMPL T3 08:00 - 13:30 5.50 CMPL TN PULD CMPL T3 13:30 - 14:00 0.50 RIGMNT RGRP CMPL T3 14:00 - 15:00 1.00 CMPL TN PULD CMPL T3 15:00 - 15:30 0.50 RIGMNT RGRP CMPL T3 15:30 - 16:30 1.00 CMPL TN PULD CMPL T3 16:30 - 00:00 7.50 CMPLTN RUNT CMPL T3 11/26/2004 00:00 - 02:00 02:00 - 06:00 06:00 - 07:45 1.75 WELCT NUND CMPL T3 07:45 - 09:45 2.00 WELCT NUND CMPL T3 09:45 - 10:15 0.50 CMPL TN DEOT CMPL T3 10:15 - 12:30 2.25 CMPL TN FRZP CMPL T3 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 15:30 - 16:30 16:30 - 18:00 RU scaffolding and lubricator, installed SPV, RD lubricator and scaffolding CMPL T3 Installed actuator valve on tree and secured well CMPL T3 Used crane and changed out Saker Inteq's MWD shack to Sperry Sun and fin cleaning mud pits. RELEASED RIG @ 18:00 Hrs 11/26/04 to move to 1E-104 Printed: 12/10/2004 2:59:08 PM conoc~illips ConocoPhillips AlåšKa, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska Wellb~168L2 Well path: MWD wI Mag-Sag <7471 - 11960'> Date Printed: 16-Dec-2004 .~. BAKER HUGHES INTEQ ~_. (j- t A- q - )" J ,t1 à ~ (,¡ ( Á fJ i.1 - Jv CJJ.... Wellbore Name 168L2___ . -- - ----------- ------.-- ~._------ ~ -- Created 21-Nov-2004 Last Revised i 24-Nov-2004 Well Name 168 I Government ID i 1 Last Revised I 1-0ct-2004 Slot . Name I Grid Northina I Grid Eastina I Latitude I Lonaitude I North lEast Slot #168 i 5959380.0000 1549890.0000 I N70 17 59.2815 I W149 35 45.4169 1206.83S I 639.66W ! Installation Name ___.___________ Easting Pa~tlç___._________.___ Northin 550528.194€ --~~~-~---- Field Name Ku aruk River Unit Eastin 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6269.88 Feet on azimuth 48.11 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~Hips ConocoPhillips AIàš1<a, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska WellDath (Grid) ReDort MO[ft] Inc[deg] Azi[deg] TVO[ft] c--_I~75.J2__j __ _~._tl______3,2_L----L_ 3502.34 7471.44 89.49 2.47' 3502.68 _..lß67 ,ß4__L ___{~ªjiQ.___ ____2ßL..._J 3504.24 I ------'l9_65.5º--_J_ ____ª-ª..E)~_____ ____~.JA..__--L 3506.55 I 7761.47' 90.26 4.39: 3507.47 i ----.Z858,Zf:L_L_.1HtQ2______ ------Q.&L...J 3507.24-J 7956.42· 90.23 6.48 I 3507.02 i 8052.81 I 89.31 7.25 i 3507.41 8149.39 I 88.54 8.01 3509.22 8246.28 i 88.88 6.95 I 3511.40 8342.08 I 91.64 7.29 3510.97 8439.91 I 90.17 7.04 3509.42 8536.57~~j~Q..~___ 4.99 3508.75 _ 8633'~~_l_.......Jtl,M____ 3.24 3506.83 8730.20 I 92.28 ~3.78 I 3503.52 -:~~:~~E-~~~} ~}~ : ~~~~:~~ ~19.73 _L___--ª.ª.'-º-9.__._~.~~ 3503.51 9115.93 I. 8.9.83 5.16 3504.76 9212.41 90.41 4.74 3504.55 __ 93Jl9.J.º--__._ 90.3ª--_ 6.09 3503.89 9405.93 90.26 5.64 3503.35 9503.01 90.23 4.13 3502.93 9598.76 90.29 5.36 3502.50 9696.41 90.08 5.34 3502.18 9792.91 _~9.83 __~502.26 9888.43 89.92 ··4.91 r· 3502.47 9985.58 I 89.68 5.56 3502.80 ~.89 l_.__~.~ - 6.12 3503.04 10179.84 1----- 90..1.4__.__ 5.31 3502.63 1 0270.2W___~0.45 5.82 3501.92 10361.77 --t- 90.48 6.49 3501.18 ~.1.9L_L___ 90.87 ___ 4.17 3500.12 ¡---.1Q.Q43.01 J_-----ª9..49__ 3.55 3499.83 10636.03' 89.95 5.86 3500.29 10724.83 89.62 3.02 3500.62 10815.82 89.77 3.80 3501.11 10907.63 90.26 3.61 3501.08 10998.29 88.94 1.56 3501.71 11089.36 i 87.15 1.56 i 3504.82 11180.49 I 86.95 __ 1.07 3509.51 11270.27 I 88.27 1.28 3513.26 11360.10L_89.43_.. 1.63 3515.06 11450.08 I 90.05 1.35 3515.47 ~1J4 _] - 96~~i-=. =~ 1.85 3514.68 11632.25 91.67 3.13 I 3512.60 11721.41 ~FI--=~~12 -~=- 4.45 i 3510.43 11811.82. .Jlll71 6.55! 3509.78 11901.84 _ 87.41 __ 6.00 ! 3512.04 11960.00 87.41 6.00 I 3514.67 Station Position(Y) 1 380.345 284.145 187.865 90.315 5.39N 102.25N 199.25N 294.95N I 390.65N 486.69N I 581.75N 678.80N 774.92N 871.46N 968.03N 1063.63N 1159.73N I 1256.24N 1351.96N 1448.08N 1544.39N 1640.66N 1737.38N 1832.80N 1930.02N 2026.17N 2121.37N 2218.11N 2315.91N 2411 .38N 2501.34N 2592.35N 2682.10N 2772.98N 2865.68N 2954.20N 3045.03N 3136.65N 3227.20N 3318.18N 3409.17N 3498.85N 3588.63N 3678.58N 3769.60N 3860.60N 3949.53N 4039.52N 4128.96N 4186.75N Wellbbré: 168L2 Wellpath: MWD wI Mag-Sag <7471 - 11960'> Date Printed: 16-Dec-2004 Station Position(X) 4298.06E i 4302.90E 4307.42E 4312.57E 4318.87E 4328.18E 4339.29E 4350.81E 4363.64E 4376.25E 4388.12E 4400.32E 4410.45E 4417.39E 4423.32E 4430.58E 4439.52E 4449.56E 4459.05E 4467.37E 4476.50E 4486.39E 4494.66E 4502.58E 4511.68E 4519.93E 4527.74E 4536.61E 4546.61E 4556.17E 4564.93E 4574.74E 4583.12E I 4589.25E 4596.88E 4603.75E 4609.17E 4615.10E 4619.19E 4621.66E 4623.75E I 4625.59E 4627.87E 4630.21E 4632.76E 4636.71E 4642.60E 4651.27E 4661.10E 4667.18E Oogleg Severi 0.00 1.07 0.97 0.24 2.14 2.27 0.24 1.24 1.12 1.15 2.90 1.52 2.17 2.09 0.86 1.42 3.72 0.83 1.58 0.74 1.40 0.48 1.56 1.29 0.22 0.94 0.47 0.71 0.68 0.94 0.56 0.73 2.61 1.66 2.53 3.22 0.87 0.57 2.69 1.97 0.58 1.49 1.35 0.76 1.12 1.62 1.60 2.80 2.63 0.00 Vertical Sectionfftl -47.59 48.69 145.03 242.70 338.59 435.88 533.45 629.75 726.16 822.89 918.57 1016.28 1112.89 1209.68 1306.43 1402.30 1498.80 1595.80 1691.96 1788.44 1885.17 1981.91 2078.98 2174.73 2272.36 2368.86 2464.38 2561.52 2659.80 2755.72 2846.09 2937.58 3027.71 3118.79 3211.80 3300.59 3391.57 3483.37 3573.97 3664.87 3755.75 3845.30 3934.99 4024.85 4115.80 4206.83 4295.96 4386.34 4476.28 4534.36 Easting 554190.06 554194.26 554198.14 i 554202.65 I 554208.31 554216.98 554227.45 554238.33 ! 554250.51 554262.48 554273.72 554285.28 554294.77 554301.07 554306.35 I 554312.98 I 554321.28 554330.68 i 554339.53 I 554347.22 554355.71 554364.96 554372.58 554379.87 554388.32 554395.94 554403.11 554411.33 554420.69 554429.61 554437.77 554446.98 554454.76 554460.29 554467.30 554473.58 554478.39 554483.72 554487.20 554489.08 554490.56 554491.80 554493.49 554495.23 554497.17 554500.52 554505.82 554513.89 554523.13 554528.82 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Oatum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6269.88 Feet on azimuth 48.11 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ... BAKER IIUGIIE5 INTEQ Northing 5959028.24 5959124.46 5959220.76 5959318.34 5959414.06 5959510.97 5959608.03 5959703.80 5959799.58 5959895.69 I 5959990.81 I 5960087.93 5960184.10 5960280.68 5960377.28 I 5960472.92 5960569.06 5960665.63 5960761.40 5960857.56 5960953.92 5961050.24 5961147.01 5961242.47 5961339.74 5961435.93 5961531.17 5961627.96 I 5961725.81 ! 5961821.33 5961911.34 5962002.41 I 5962092.20 I 5962183.11 I 5962275.85 5962364.41 5962455.26 5962546.90 5962637.48 5962728.46 5962819.45 i 5962909.13 i 5962998.92 5963088.87 5963179.90 I 5963270.91 5963359.87 5963449.91 5963539.41 i 5963597.22 Conocó'Phillips ConocoPhillips AI~a, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska Wellb'bré: 168L2 Well path: MWD wI Mag-Sag <7471 - 11960'> Date Printed: 16-Dec-2004 Bií. BAKIR HUGHIS INTEQ Comments i i MDrftl I TV-ºIID-_ _NotlbffiJ EasUftl I Comment I 7085.72 _347a,5J__ -- 667.52S 4283.73E i Interpolated Azimuth i , __IHll§4__ _ ,___~4ªª-._ºº_ - ------- 572.96S 4288.98E i Interpolated Azimuth 11960.00 3514.67 4186.75N 4667.18E I Proiected Data - NO SURVEY -~~- Hole Sections Diameter Start in MD ft 131/2 108.00 97/8 4425.00 6 3/4 7030.00 ~L__~_L~~~-,Qº-__ Well bore 168 PB1 168 PB 1 168L2 PB1 168L2 Casings I Name Top Top Top I~op Shoe Shoe Shoe Shoe Wellbore M01ft1 TVDrftl Northrftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl 20" Conductor 0.00 0.00 O.OON I O.OOE 108.00 108.00 O.OON O.OOE 168 PB1 10 3/4" Casing ---~~-- c--_ 0.00 O.OON i O.OOE 4419.00 2479.18 1818.52S 2647.81 E 168 PB1 -- I 7 5/8" Casino 0.00 0.00 O.OON i O.OOE 8157.00 3714.22 i 371.36N 4373.61 E 168 PB1 4 1/2" Liner 7029.00 3462.61 723.10S I 4280.64E 11937.00 3513.63 I 4163.90N 4664.77E 168L2 I All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6269.88 Feet on azimuth 48.11 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocóPhï"ips ConocoPhillips AI~a, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska WellborH'68L2 PB1 Well path: MWD wI Mag-Sag <7085- 7913'> Date Printed: 16-Dec-2004 .~. BAKER HUGHES INTEQ 2úv/-.~ û ~ We II bore Name 168L2 ~-ª-t_____ __ __.__u~__________~_______ Created : 21-Nov-2004 Last Revised i 24-Nov-2004 Well Name 168 I Government 10 ! I Last Revised I 1-0ct-2004 Slot Name Slot #168 Latitude N70 17 59.2815 Lon itude I W149 35 45.4169 North 206.83S Installation Name Pad 1 E ---~- 550528.194 Coord S stem Name 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datu Field Name Ku aruk River Unit Eastin 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from a.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 4360.98 Feet on azimuth 87.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated conocó'Phillips ConocoPhillips AI~a, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska WellDath (Grid) ReDort MD[ft]l,nC[deg] Azi[deg] I TVD[ft] f-- 70~~ºº_~¡ n__ _ZIi.2Q_ _____~3_'_11L___! 3462.81 7085.72 79.67 3.18 3473.51 __Itltl~nL__ß2.HL__ __ 3.18 3488.66 __ 7278.~__j__~~,-I!j _____ __2-,J6 ! 3498.85 7375.12 i 90.11 3.29 3502.34 r--I4IQI1_J____~--,~__ __ ___3.93 ---L 3500.13 7568.62! 92.53 5.59 I 3495.80 7664.71 i 92.38 6.43 I 3491.68 : 7762.12 T 90.84 7.85 ì 3488.95 i 7858.86 I 89.86 9.99 I 3488.36 i 1_]913.0Q_J______ß~áQ__ 9.00 T 3488.66 I I Station PositionlY) : 722.128 667.52S 572.96S 476.96S i 380.34S I 284.97S I 187.50S 92.02S 4.59N 100.15N 153.54N WellborH'68L2 PB1 Well path: MWD wI Mag-Sag <7085- 79131> Date Printed: 16-Dec-2004 Station PositionlX) 4280.70E 4283.73E 4288.98E 4293.46E 4298.06E I 4304.07E i 4312.19E 4322.24E 4334.34E 4349.34E 4358.27E Dogleg Severi Vertical Sectionrftl 0.00 i -389.70 2.65 i -335.03 2.59 -240.34 3.87 I -144.28 4.65 -47.59 2.63 47.96 1.69 145.76 0.89 241.73 2.15 338.99 2.43 435.42 1.95 489.35 Easting 554174.97 554177.64 554182.27 554186.10 554190.06 554195.44 554202.91 554212.33 554223.79 554238.15 554246.73 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 4360.98 Feet on azimuth 87.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ... BAKER HUGHES INTEQ Northing I 5958686.38 I 5958741.00 5958835.58 i 5958931.60 I 5959028.24 I 5959123.64 I 5959221.15 I 5959316.68 I 5959413.36 I 5959509.01 I 5959562.46 I <:onoc6PhïUips ConocoPhillips AI~a, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska Wellbo~68L2 PB1 Well path: MWD wI Mag-Sag <7085 - 79131> Date Printed: 16-Dec-2004 IIi. BAKER HUGHES JNTEQ Hole Sections Diameter Start Wellbore in MDft 13 1/2 108.00 168 PB1 97/8 4425.00 168 PB 1 63/4 7030.00 168L2 PB1 Casinas Name Top Top Top Top Shoe Shoe [Shoe Shoe Well bore MDrftl TVDrftl Northrttl Eastrftl MDrftl TVDrftl Northfftl Eastrftl 0.00 0.00 O.OON O.OOE 108.00 108.00 I O.OON O.OOE 168 PB1 20" Conductor I I 10 3/4" Cas in a 0.00 0.00 O.OON O.OOE 4419.00 2479.18 I 1818.52S 2647.81E 168 PB1 7 5/8" Casina 1-------- 0.00 0.00 O.OON O.OOE 8157.00 3714.22 I 371.36N 4373.61E 168 PB1 4 1/2" Liner 7029.00 3462.61 723.10S 4280.64E 11937.00 3513.63 I 4163.90N 4664.77E 168L2 I All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 4360.98 Feet on azimuth 87.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 1<--, 'o.~ ~1J~1rŒ (DJ~ !Æ~!Æ AIfASIiA. OIL Alft) GAS R d Th CONSERVATION COMMISSION <;in y omas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-168L2 ConocoPhillips Alaska, Inc. Permit No: 204-202 Surface Location: 207' FNL, 640' FEL, SEC. 21, TIIN, RI0E, UM Bottomhole Location: 1302' FNL, 1249' FEL, Sec. 15, TIIN, RI0E, UM FRANK H. MURKOWSK/, GOVERNOR 333 w. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Thomas: Enclosed is the approved application for permit to drill' the <above referenced development well. The permit is for a new well bore segment of existing well KRU lE-168, Permit No. 204-200, API No. 50-029-23230-00. Production should continue to be reported as a function of the original API number stated above. 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. ConocoPhillips Alaska. Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 6 -3 07 (pager). SI BY ORDER OF THE COMMISSION DATED this-'/- day of month, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department ofEnvir0m;tental Conservation w/o encl. .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIV,f?CY<t OCT 0 8 2004 1 a. Type of Work: Drill 0 Redrill U 1b. Current Well Class: Exploratory U Development ,,~. Oil & Ga!ll\l)~ i Re-entry 0 Stratigraphic Test 0 Service 0 Development Gàs" - '- A' c-: .,. ""one 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1E-168L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12009' TVD: 3500' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: "'1\-\ l ~ \) Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM ALK 25651~ ,C I,,~ West Sak Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1003' FNL, 1638' FEL, Sec. 22, T11N, R10E, UM ADL 469/466 11117/2004 Total Depth: 9. Acres in Property: 14. Distance to 1302' FNL, 1249' FEL, Sec. 15, T11N, R10E, UM 2560 Nearest Property: 8922' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 549890 y- 5959380 Zone- 4 (Height above GL): 28 feet Well within Pool: 365' @ Œ-123L1 , 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 7222 ft. Maximum Hole Angle: 94.5° Max. Downhole Pressure: 1546 psig 1 Max. Surface Pressure: 1141 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 4422' 28' 28' 4450' 2459' 710 sx ASLite, 205 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 8381' 28' 28' 8409' 3702' 510sx DeepCrete 6.75" 4.5" 12.6# L-80 DWC 5001' 7008' 3442' 12009' 3500' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): t;fV Perforation Depth TVD (ft): 20. Attachments: Filing Fee L..- BOP SketchD Drilling Program0 Time v. Depth Plot 0 Shallow Hazard Analysis 0 Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name Rand~ Thomas Title Kuparuk Drilling Team Leader Signature ?~ fJ1 ~6 '- Phone Date JD/ð,/z004. PreDared bv Sharon Al/suD-Drake f " Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: dO \..\.- d-.CJ d- 50- Qà--<;- a~â-~C)'-<O t Date: /0//1 /ð f/ for other requirements Conditions of approval : Samples required DYes ßNo Mud log required , RYes ~ No ~~rogen sulfide measures 0 Yes it3-JIIo Directional survey required Yes 0 No ::m . \?) \>~\-~'>~br-~. '(;CJ\",~,>·\,\~~~CIl \ '=- \ 4. ~\'t'>.. BY ORDER OF /Dj, A c¡- V COMMISSIONER THE COMMISSION Date: "'V - ( I Form 10-401 Revised 3/2003 · on ORIGINAL Submit in duplicate ,,~ Co no coP hill ips Alaska '~'Øi. Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com RE ~ EIVED OCTO 5 2.004 Alaskf) Oil & Gas Cons. Commissíon Anchorage October 1, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, lE-168 L2 Dear Commissioners: J ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production wellbore, the , upper lateral wellbore of a multilateral horizontal well, in the West Sak "DfI sand. The main bore of this / well will be designated 1 E-168 and has been permitted under a separate application, submitted on October 1, 2004. This application is for the upper lateral of that well, to be designated lE-168L2. The expected date that operations will begin on lE-168L2 is November 17, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. / Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for lE- 168L2. Sincerely, 'R~~~m~ \ ~ GKA Drilling Team Leader o I~\J/~L "'-' RECeIVE:D OCT 0 52004 Alaska Oil & Gas Con . Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL .. Exploratory U Development Oil U T1l1fJ'" ,,"one D Service 0 Development Gas D / Single Zone 0 5. Bond: L:d Blanket U Single Well 11. Well N~ and Number: Bond No. 59-52-180 / 1E-168L2 6. Proposed Depth: ;:2. eld/Pool(s): MD: 12009' ./ TVD: 3500' / uparuk River Field 7. Property Designation: þ"J> ¡O'¿;, ~ ALK 25651~ / West Sak Pool 8. Land Use Permit: / 13. Approximate Spud Date: ADL 469/466 11117/2004 9. Acres in Property: / 14. Distance to 2560 -' Nearest Property: 10. KB Elevation / 15. Distance to Nearest 4 (Height above GL): fi8 feet Well within Pool: 365' @ 1 E-123L 1 , 17. Anticipated P. ~ssure (see 20 AAC 25.035) / Max. D~~ i~: 1546 psig f I Max. Surface Pressure: 1141 psig ~! D1PJh Quantity of Cement Top / '\.. Bottom c. f. or sacks Length MD e'" ~D MD TVD (including stage data) 80' 28' V~' 108' 108' 260 cf ArcticCrete 4154' ~ lv{~' 4182' 2295' 718 sx AS Lite, 189 sx DeepCrete 8752' . 2rF í µ 28' 8780' 3733' 508 sx DeepCrete 4357" ¥'Jtv 3494' 11849' 3574' slotted liner £A./ PRESENT WELL CONDITION SUMMARY I (~ (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measure~ctive Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Length Size ~ement Volume MD TVD / / / / / / / 1a. Type of Work: Drill 0 Re-entry 0 1b. Current Well Class: Stratigraphic Test 0 Redrill U 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM / Top of Productive Horizon: 1003' FNL, 1638' FEL, Sec. 22, T11N, R10E, UM Total Depth: 1302' FNL, 1249' FEL, Sec. 15, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890" y- 5959380 / Zone- 16. Deviated wells: / Kickoff depth: 7222 18. Casing Program Size Maximum Hole Angle: ft. 94.5° Specifications Grade Coupling K-55 Welded L-80 BTC L·80 BTCM L-80 DWC Hole Driven 13.5/1 9-7/8/1 6.75/1 Casing 20/1 Weight 94# 45.5# 29.7# 12.6# 10.75/1 7-5/8/1 4.5/1 19 Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Drilling Program 0 Seabed Report D Filing Fee 0 Bfp Sketch D Property Plat D Di~rter Sketch D 21. Verbal Approval: Commission Represent,rve: 22. I hereby certify that the foregOin~~iS true nd correct to the best of my knowledge. Printed Name Rand Thomas Signature \~. t·~.... ~ -71' - / Permit to Drill Î / ....J: Number: ;t-D., - /fO 2- 50- C> ¿,.it,. 2.3 2.. '30 -" I Conditions of' 7Pprov: Samples required D Yes ~ No Hydrogen sulfide measures DYes ß(rNO Other: ~ 20 AAC 25.005 8922' Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Fluid Program 0 Date: Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone "Lf,56 ~ ) c:> Date ( 0 (~r e y Preoared bv Sharon AI/suo-Drake API Number: Commission Use Only Permit Approval See cover letter for other requirements Approved by: Date: Mud log required Directional survey required D Yes ~ No ~ Yes D No COMMISSIONER BY ORDER OF THE COMMISSION Date: Form 10-401 Revised 3/2003 · ORIGINAL Submit in duplicate Appli~l for Permit to Drill, We1l1E-168 L2 Revision No.O October 1, 2004 Permit It - West Sak Well #1 E-168 L2("D" Sand) Application for Permit to Drill Document Mo)xir'ñiz~ We-II "1011.11; Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ..................... ......... ............................... .......................... ............. 2 2. Location Sum mary....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .......................... ...................................................................... 2 Requirements of 20 AAC 25.050(b) ... ......... ...... ..... .......................... ............ ... ........ .... ... '" ........ ..... ..... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) ......... ..... ........ ....... ...... _........................... ............... .................. 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ......................................... .................. ................ ............ ........ 3 5. Procedure for Conducting Formation Integrity Tests .............................................3 Requirements of 20 AAC 25.005 (c)(5) ............. ...... ....... .............. ................. .................. ............... ..... 3 6. Casing and Cementing Program ................................................................... .......... ...4 Requirements of 20 AAC 25.005(c)(6) ...................... ............................ .................... ................ .......... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AA C 25. 005(c) (7) ................................................................................................ 4 8. Drill i ng Flu id Program................................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ........ ............................ ..... .... ............ ........... ........ .................... 5 Lateral Mud Program (MI FloPro NT) ........................ ......... ........................... .................... ............ ...... 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AA C 25.005 (c)(9) .................... ................................................................ ........... 5 1 o. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ............. ........ ................................. ..... ............ ................ ...... 5 11. Seabed Condition Analysis.. .......... ...................................................................... ...... 5 Requirements of 20 AAC 25.005 (c)(11) .......... ... ...... ...................................................... .............. ...... 5 12. Evidence of Bonding .............. ......... ............................................................ .......... ...... 6 Requirements of 20 AAC 25.005 (c)(12) .......... ......... ..... ............................... ......... ............................. 6 ORIGINAL L2 PERM/T IT (Producer) RevO.doc Page 10f7 Printed: October 1, 2004 ApplitJ,-",,' for Permit to Drill, Well 1 E-168 L2 Revision No.O October 1 , 2004 13. Proposed Dri lling Program .............. ................... ............. .............................. ............. 6 Requirements of 20 AA C 25.005 (c)(13) ........ ...... ............ ........ ..................... .......................... ............ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ................... .... .............. ........ ............ ............................... ..... 6 15. Attach ments.................................................................................................................. 7 Attachment 1 Directional Plan......................... ..... .... ..................................... ............. .............. .... ....... 7 Attachment 2 Drilling Hazards Summary.......... ........................................................... ...... ..... ............. 7 Attachment 3 Well Schematic............... ........................................................................... .................. 7 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 API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, 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 assigned to the well by the commission. The well for which this Application is submitted will be designated as 1 E-168 L2. 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 for 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 surface/ at the top of each objective formation/ and at total depth referenced to governmental section lines. (8) the coordinates of the proposed location of the well 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 Atmospheric Administration/ (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,959,380 Eastings: 549,890 FNL:207', FEL:640', See 21, T11NjR10E, UM I RKB Elevation I I Pad Elevation I ,/ 98.4' AMSL 70.4' AMSL Location at Top of Productive Interval West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Northings: 5,958,613 Eastings: 554,178 FNL:1003', FEL:1638, See 22, T11N/R10E, UM 7008' 3442' 3344.0' Location at Total Depth I FNL:1302', FEL:1249', See 15, T11NjR10E, UM ,/ ASP Zone 4 NAD 27 Coordinates Measured Depth RKB: 12009' Northings: 5,963,597 Eastings: 554,524 Total Vertical Depth, RKB: 3500' Total Vertical Depth 55: 3402.0' ,/ and (D) other information required by 20 MC 25.050(b)/ ORIGINAL L2 PERMIT IT (Producer) RevO.doc Page 20f7 Printed: October 1, 2004 Appli~1 for Permit to Drill, Well 1 E-168 L2 Revision No.O October 1, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviat~ the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: 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 certified mail; or (8) slate that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) 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: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.03ï; as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-168 L2. Please see information on Doyon 141 blowout prevention equipment placed 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, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lE-168 L2 area vary from 0.46 to 0.44 psi/ft, or 8.8 to 8.5 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1141.336 psi, calculated thusly: MPSP =(3514.4 ft)(0.44 - 0.11 psi/ft) =1141.336 psi /' Since the estimated pore pressure is well below the rating of a 3,000 psi BOPE system, we would like to request permission to operate our 5,000 psi system as a 3,000 psi system which would allow us to maintain a set of casing rams in the second pipe ram cavity and also permit us to test to only 3500 psi. (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) 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: ORIGINAL L2 PERMIT IT (Producer) RevO.doc Page 3 of 7 Printed: October 1,2004 Appli~i for Permit to Drill, Well 1 E-168 L2 Revision No.O October 1, 2004 (5) a description of the procedure for conducting formation integrity test~ as required under 20 MC 25.030(f)/ The parent wellbore,lE-168, will be completed with 7 5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed 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 item~ 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/ Casing and Cementing Program See also Attachment 3, APO for 1E-168: Cement Summar) Hole Top Btm CsglTbg Size Weight Length MDITVD MDITVD OD (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108/ 108 Cemented to surface with 260 cf ArcticCRETE 10 3/4 13 1/2 45.5 L-80 BTC 4422 28 / 28 4450 /2459 Cemented to Surface with 710 sx ASLite Lead, 205 sx OeepCRETE Tail 7 5/8 9 7/8 29.7 L-80 BTCM 8381 28 / 28 8409 / 3702 Cement Top planned @ 4786' MO / 2595' TVO. Cemented w/ 510 sx OeepCRETE 4 1/2 6 3/4" "A" 12.6 L-80 OWC 6051 7470/3535 13521/3771 Slotted- no slotted Latera I (1 E- cement 168) 4 1/2 6 3/4" 12.6 L-80 OWC 4689 7326/3514 12015/3560 Slotted- no slotted "B" Lateral cement ..... r----. I 11::: 1t::.O I 1\ ..~,-~ -~ -~~ ~- 4 1/2 63/4 12.6 L-80 OWC 5001 7008/3442 12009/j~UU ~Iotted-no ) slotted "0" Lateral cement (lE-168 L2) /' ~ 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 required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); ORIGINAL L2 PERMIT /T (Producer) RevO.doc Page 40f7 Printed: October 1,2004 Appliö, ..i for Permit to Drill, Well 1 E-168 L2 '-' Revision No.O October 1, 2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Value Density (ppg) 9.1 Funnel 30 Viscosity (seconds) Yield Point 18-28 (cP) Electric Stability 650-900 Chlorides (mg/I) 40000 pH N/A API filtrate <4 (cc / 30 min) **HTHP filtrate <10 (cc / 30 min) MBT (lb / gal) / Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) 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: (9) for an exploratory or stratigraphic test well 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 or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) 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: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. 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 items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. ORIGINAL L2 PERMIT /T (Producer) RevO.doc Page 50f7 Printed: October 1, 2004 Appli" /1 for Permit to Drill, Well 1 E-168 L2 ~ Revision No.O October 1, 2004 11. 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 items, except for an item already on file with the commission 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. 12. 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 items, except for an item already on file with the commission and identified in the application: The proposed drilling program for lE-168 L2 is listed below. Note: Previous operations are covered under the 1E-168 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7008' MD 3442' 1VD, the top of the D sand. 2. Mill 63/4" window. POOH. , / 3. Pick up 6 3/4" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 12009' MD / 3500' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool, POOH 10. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as re and RIH to depth. Land tubing. Set BPV. 11. Nipple down BOPE, nipple up tree and test. Pull BPV. 12. Set BPV and move rig off. 13. Freeze protect well with diesel by pumping into 4 1/2"" x 7 5/8" annulus, taking returns from tubin allowing to equalize. 14. Rig up wire line unit. Pull BPV and install gas lift valves 15. Operate well on gas lift for +/- 180 days. 16. Replace gas lift valves with dummies. 17. Run ESP pump through tubing. -r~\") ired a. ~ ~(t)J~' 13. 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 following items, except for an item already on file with the commission and identified 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 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved ORIGINAL L2 PERM/T IT (Producer) RevO.doc Page 6 of 7 Printed: October 1,2004 AppIiG,,-,,;i for Permit to Drill, Well 1 E-168 L2 Revision No.O October 1, 2004 disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL L2 PERMIT IT (Producer) RevO.doc Page 7of7 Printed: October 1, 2004 lE-168L2 Drilling Hazards Summarï 6 3/4" Open Hole / 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low / Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener, Decreased mud wei ht Reduced um rates, Mud rheolo ,LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out Low Lost Circulation Hole Swabbing on Trips Moderate Low ORIGINAL 1 £-168 Drilling Hazards Summary prepared by Steve Shultz 9/1/20044:25 PM Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 'aker Hughes Incorporatl Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 7008.18 to 12009.38 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 9/28/2004 Validated: No Planned From To Survey ft ft 7008.18 12009.38 Planned: 1 E-168L2 VER#2 V7 Version: 2 Toolcode Tool Name MWD+SAG MWD + Sag correction Casing Points Pad 1 E 104 104 VO Plan: 1E-104 VE 7459.06 6967.50 3654.33 310.67 3343.66 Pass: Major Risk Pad 1 E 105 1E-105 Plan V1 Plan: 1 Out of range Pad 1 E 105 1 E-1 05L 1 Plan V1 Plan: Out of range Pad 1 E 105 1E-105L2 Plan VO Plan: Out of range Pad 1 E 112 1E-112 V6 Out of range Pad 1 E 112 1E-112L1 V3 Out of range Pad 1 E 112 1E-112L2 V2 Out of range Pad 1 E 112 1E-112PB1 V1 Out of range Pad 1 E 114 1E-114 Vers#2 V6 Plan: Out of range Pad 1 E 123 1E-123 L 1 V2 11898.59 11700.00 4578.57 569.70 4008.87 Pass: Major Risk Pad 1 E 123 1E-123 V18 11898.29 11700.00 4581.04 573.51 4007.54 Pass: Major Risk Pad 1 E 123 1 E-123PB1 V1 11898.29 11700.00 4581.04 573.56 4007.48 Pass: Major Risk Pad 1 E 126 1 E-126 V5 Out of range Pad 1 E 126 1E-126L1 V2 Out of range Pad 1 E 126 1E-126L2 V3 Out of range Pad 1E 168 1E-168 Vers#2 V4 Plan: 9075.96 13521.48 4559.08 501.54 4057.54 Pass: Major Risk Pad 1 E 20 1 E-20 VO Out of range Pad 1 E 3 1 E-03 V1 Out of range Pad 1 E 33 1 E-33 VO Out of range Pad 1 E 33 1E-33PB1 VO Out of range Pad 1 E 7 1 E-07 VO 7021.89 7050.00 3312.07 230.86 3081.21 Pass: Major Risk ORIGiNAL · e -..:- ConocoPhillips ConocoPhillips Alaska, Inc., Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 168L2 Well path: 168L2 Ver#2 Date Printed: 29-Sep-2004 INTEQ 3-Sep-2004 ~7754j:¡208 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated R Gll'~AL . e ~illips ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 168L2 Well path: 168L2 Ver#2 Date Printed: 29-Sep-2004 ... ..,. INTEQ ... ... .... ... ........ ......... .... .... < MD[ftli .... IT\lf.)[ftl I Eást[ftl :.>tâtiön $tati ...... ..... .'",,' .., ."" y~ruc.al I ''Il1'UI[llJ ltr~::~ ~...'--. -...,,,... ............ ,.. .,.... I.···.· 10ti{ ... ...... ...... .... ..... North)·.· ÊastY 1fT .... ... > .... ......... 7008.18 75.00 4.43 3442.40 3344.00 795.538 4283.24E 5958613.0Q_ .....Þ.5417--ª'-ºº- O.OL _ -462.69 Top Whipstock Face. Tie on .~ 7020.18 76.91 4.43 3445.31 3346.91 783.928 4284.14E 5958624.61 554178.82 15.90 -451.05 Base WhipStock Face End of Build 7038.18 76.91 4.43 3449.39 3350.99 766.448 4285.49E 5958642.10 55418006 0.00 -433.Q.2.. ß1c:f Milled Hole. End of Hold 7138.18 82.91 4.43 3466.91 3368.50 668.33S 429308E 5958740.25 554187.00 6.00 -335.11 7222.21 87.95 4.43 3473.60 3375.20 584.848 4299.54E 5958823.77 554192.91 6.00 -251.37 3DX8 Kick off Point / 7300.00 90.28 4.38 3474.80 3376.40 507. 30S 4305.52E 5958901.35 554198.36 3.00 -173.60 ...1322.23 90.95 4.37 3474~Q§ ~3376.16 485.138 4307.21E 5958923.52 _554199.91 3.00 -151.37 End of BuildfTurn 7386.90 90.95 4.37 3473.49 3375.09 420.66S 4312.14E 5958988.02 554204.41 0.00 -86 71 End of Hold -- 7400.00 90.56 4.37 3473.32 3374.91 407.608 4313.14E 5959001.08 554205.32 3.00 -73.61 7486.91 87.95 4.41 3474.45 3376.05 320.968 4319.79E 5959087.75 554211.4.IL ~~ 13.28. End of DropfTurn 7500.00 87.95 4.41 3474.92 3376.52 307.928 4320.79E 5959100.8Q 554212.31 0.00 26.37- 7600.00 87.95 4.41 3478.49 3380.09 208.288 4328.47E 5959200.48 554219.33 0.00 126.30 7700.00 87.95 4.41 348ßÆ ~_3383.67 108.648 4336.14E 5959300.16 554226.34 0.00 226.24 -- 7800.00 87.95 4.41 3485.65 3387.25 9.008 4343.1321; ~959399~M.. J5.42Q3.35 . O.Qº-- .326.1.L --..--.------- f--79OO,Q,Q. 87~~ ~41. 3489.22 3390.82 90.64N 4351.49E 5959499.52 554240.37 0.00 426.11 -- 8000.00 87.95 4.41 3492.80 3394.40 190.28N 4359.17E 5959599.20 554247.38 000 526.04 8100.00 87.95 4.41 3496.38 3397. 98 289.92N 4366.85E 5959698.88 554254.39 0.00 625.98 ~OO.OO 87.95 4.41 3499.95 34Q151:L 389.5§1'L cA;37452E . 595979855 554261.40 0.00 725.91 -- 8300.00 87.95 4.41 3503.53 3405.13 489.20N 4382.20E 5959898.23 554268.42 0.00 825.85 8400.00 87.95 4.41 3507.11 3408.71 588.84N 4389.87E 5959997.91 554275.43 0.00 925.78 8408.11 87.95 4.41 3507.40 3409.00 596.93N 4390,49E 5960006.00 554276.00 0.00 933.89 W8 1E C5 D-MDPT#1 RV8D090204, -- -- 3DJ Kick off Point 8500.00 90.71 4.45 ~4ß. ..MJQ~illL 688. 52N 4397.58E 5960097.63 ~4.82Aª-- ~"'"ºº-- ¡-1.Q.25.76 8600.00 93.71 4.49 3504.63 3406.23 788.13N 4405.37E 5960197.28 554289.60 3.00 1125.68 f----8925~N 1-- 94.48 4.50 3502.79 3404.39 813.75N 4407.39E 5960222.9.1_ .....Þ.Q4291.4º-. ~m. 1151.37 End of BuildfTurn -- 8700.00 94.48 4.50 3496.99 3398.59 887.53N 4413.20E 5960296.72. _5-º4296.77 0.00 1225.38 8800.00 94.48 4.50 3489.18 3390.78 986.92N 4421.02E 5960396.15 554303.94 0.00 1325.08 -- 8900.00 94.48 4.50 3481.38 3382.98 1086.31N 442/ißQE ~960495.58 554311.10 0.00 1424.77 8912.50 94.48 4.50 3480.40 3382.00 1098.72N 4429.83E 5960508.00 554312.00 0.00 1437.23 W8 1E C5 D-MDPT#2 RVSD090204, 3DJ Kick off Point 9000.00 91.85 4.46 3475.57 3377.17 1185.82N 4436.66E 5960595.13 554318.25 3.00 1524.59 9075.97 89.58 4.4.2_ 3474.62 3376.22 1261.55N 4442.53E 5960670.89 554323.62 3.00 1600.55 End of DropfTurn 9100.00 89.58 4.42 3474.80 3376.40 1285.51N 4444.39E 5960694.86 554325.3.L c-.JLOQ._ ~4.58 -- 9200.00 89.58 4.42 3475.54 3377.14 1385.21N 4452.09E 5960794.6Q_ --º54332.3Q.. __QlIO 1724.58 '-..9300.00 89.58 4.42 3476.28 3377.aJL 1484.91N 4459.80E 5960894.34 5543~ ~O.OO 1824.58 .- 9400.00 89.58 4.42 3477.02 3378.62 1584.61N 4467.50E 5960994.08 554346.44 0.00 1924.57 9500.00 89.58 4.42 3477.76 3379.36 1684.31N 4475.21E 5961093.82 554353..49 0.00 2024.57 9600.00 89.58 ~ 3478.51 3380.11 1784.01N 4482.92E 5961193.55 554360.53 0.00 2124.57 9700.00 89.58 4.42 3479.25 3380.85 1883.71N 4490.62E 5961293.29 55436757 0.00 2224.56 9800.00 89.58 4.42 3479.9.9. 3381.59 1983.41N 4498.33E 5961393~,(& ~.4374.62 0.00 2324.56 9900.00 89.58 4.42 3480.73 3382.33 2083.11 N 4506.03E 5961492.77 554381.66 0.00 2424.56 10000.00 8958 4.42._ 3481.47 3383.07 2182./illi .4513.74E 5961592.51 554388.70 0.00 2524.56 10100.00 89.58 4.42 3482.21 3383.81 2282.51N 4521.44E 5961692.25 554395.74 0.00 2624.55 10200.00 89.58 4.42 3482.95 3384 55 2382.21 N 4529.15E 5961791.99 554402.79 0.00 2724.55 ..JQ30Q...00 89.58 4.42._ 34aU!I ~85.:W 2481.91 N 453gJlliE ___596189.Lrr. 554409.83 0.00 2824.55 .- 10400.00 89.58 4.4.L 3484.44 3386.04 2581.61N 4544.56E 5961991.47 554416.87 --ºcOO 2924.55 10500.00 89.58 4.42 3485.18 3386.78 2681.31 N 4552.27E 5962091.20 554423.92 0.00 ~45.4. 10600.00 89.58 4.42 3485.92 3387.52 2781.01N 4559.97E 5962190.94 554430.96 000 312454 10700.00 89.58 4.42 3486.66 3388.26 2880.71N 4567.68E 5962290.68 554438.00 _.0.00 3224.54 10800.00 89.5L 4.42 3487.40 338900 .2980.41 N 4575.39E 5962390.42 ~444504 0.00 3324.53 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated D IILJ~ I f\. ,i A· L-. }\.!. ..~¡ \} " '" !# Ï!!. t . e ConocÒPhillips ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Well bore: 168L2 Well path: 168L2 Ver#2 Date Printed: 29-Sep-2004 INTEQ ~..... , ..... ........ . ....... ...... ...... ... > ....... ..... ..... ...... ... M[)lftl i Incla6al^""""· -,. ITVO!ft}'Ilerti¢a.1 ",' I~ast¡ftl ~tatl()n. '.' ~ ....6tati()ÍJ . . ... .-'" . ". -'.. '~V'~'l,,¡ 1\o'?!:I':;~ ..... LJ",PUIQO.. l\Iòrthl· East) . .'. loot 'tt -". i" ..'.' . ....... .... .'. .... ...... ......... .......... 10900.00 89.58 4,4~_ 348ß..15 3389.75 3080.11N 4583.09E 5962490.16 554452.09 000 3424.53 -~ 11000.00 89.58 4,42 3488.89 3390,49 3179.81N 4590.80E 5962589.90 55445913 0.00 3524.53 11100.00 89.58 4,42 348963 3391.23 3279.51N 4598.50E 5962689.64 554466.17 0.00 3624.53 11200.00 89.58 4,42 3490.37 3391.97 3379.21 N 4606.21 E 5962789,38 554473.22 0,00 3724,52 11300.00 89,58 4,42 3491,11 3392,71 3478,91 N 4613,91E 5962889,12 554480.26 0,00 3824,52 11400,00 89,58 4,42 3491,85 3393,45 357861N 4621,62E 5962988,86 554487.30 000 3924,52 11500.00 89,;;-ª---- ------A~42 3492,59 3394,19 3678,31 N 4629,32E 5963088.59 554494,35 0.00 4024,52 11600,00 89,58 4,42~~493.34 3394,94 3778,01N 4637,03E 5963188,33 554501,39 0,00 4124,51 11608,69 89,58 4,42 3493,40 3395,00 3786,67N 4637,70E 5963197,00 554502,00 0,00 4133.20 WS 1E C5 D-MDPT#3 RVSD090204, -- 3DJ Kick off Point 11645,77 88,97 349 3493,87 3395.47 382366J'icA640~2§E 5963234,OQ 554504,31 3,00 4170.28 End of DropfTurn 11700,00 88,97 3.49 3494,84 3396.44 3877.78N 4643,55E 5963288,14 554507.25 0,00 4224.49 11800,00 88.~7 3.49 3496,64 3398.24 39n58N 4649,63E 5963387,97 554512'ºº---. ~--º"ºº--- ...1324,46 11900,00 88,97 3.49 3498,44 3400,04 4077,3aN 4655.71E 5963487,79 554518,08 0,00 4424,43 12000,00 88,97 3,49 3500.23 3401,83 4177,18NcA§Q179E 596358762 554523.49 0,00 4524,40 " 12009,40 88,97 3,49 3500.40 3402.00 4186,56N 466236E 596359700 554524,00 0,00 4533,80 TO, WS 1 E C5 D TOE RVSD090204, - End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O,OOE on azimuth 4,43 degrees Bottom hole distance is 6266,17 Feet on azimuth 48.08 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated f~I(31~JN41_ . . Conoc~U¡ps ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 168L2 Well path: 168L2 Ver#2 Date Printed: 29-Sep-2004 ... ... lNtEQ To WhipStock Face Base Whipstock Face End Milled Hole TD 795.53S 783.92S 766.44S 4186.56N WS 1 E C5 3786.67N 4637.70E 3493.40 N70 18 36.5090 W149 33 30.1475 554502.00 5963197.00 D-MDPT#3 RVSD090204 ~_. WS 1 E C5 596.93N 4390.49E 3507.40 N70 18 5.1396 W149 33 37.4122 554276.00 5960006.00 D-MDPT#1 RVSD090204 WS 1 E C5 1098.72N 4429.83E 3480.40 N70 18 10.0746 W149 33 36.2567 554312.00 5960508.00 D-MDPT#2 RVSD090204 WS 1 E C5 D TOE 4186.56N 4662.36E 3500.40 N70 18 40.4417 W149 33 29.4211 554524.00 5963597.00 RVSD090204 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated O· " R······ I (~ I.'. Nll\ ·~·<J~~ð' 'Tubing Head Assy, 11" X 4-1/2" 'insulated Conductor, 20" X 30" (2) Gas Lift Mandr~ls, 4-1/2" Xi" KBG-2 Conoe illips West Sak 1 E-168 Producer 7 -5/8" Tri-Lateral Completion Tubing String: 4-112" 12.6#, L-BO, IBTM, Spec. Ciearance Couplings, (4.$20" OD) 'D' Sand Lateral 6,3/4" Lateral TD @ 1200$' MD, 350Q' TVD B-sand Window at +1- 7326' MD, 3514' TVD / Tubing, 4-112" 12.6#, from LEM to A2 Liner, wl seal stem and 3.562" DB Nipple 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs ¢' 00 00 N " E " ill "& (j) 2400 mn:Q Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. Slot: Slo! #168 Well: 168 Wellbore: 168 ""'Þ"""" ConocoPhillips Planner 1-0ct-2004 41/2" Casing PI, 10-Acre Grid KRU 1 E..168L2 non Sand 1 2042020 SFD N . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER KKU IE - /fo?l LZ- ¿Ûv- 202- WELL NAME PTD# ¡/. Development Service CHECK WHAT APPL1ÈS ADD-ONS (OPTIONS) MULTI LATERAL V' (If API Dumber last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new we})bore 'segment of existing well ;<æ « IE: ~ /08 .~ Permit No,2ó':'/-2tÐAPJ No.-50-0¿C:¡- 25d~ -Gó ProductioD. sbould continue to be reponed as a function' of tbe original API Dumber. stated above. HOLE In accordance witb· 20 AAC 25.005(1), an records, data and logs acquired .for tbe pilot bole must be clearly differentiated ID botb name (name on permit plus PH) and API number (SO - 70/80) from records, data and logs acquired for we}) (name on permit). Pll.,OT (PH) SPACING EXCEPTION I DRY DJTCH SAMPLE Tbe permit is approved subject ·to fuD comp1iance witb 20 AAC 25..055~ Approval to perforate and produce is contingent upon issuance of ~ conservation ordel" approving a spacing ncep1ion. (Company Name) assumes tbe liability of any protest 10 tbe sp,cing "...JCeptio, tbai m. ay occur. ¡J~ Ç~/~ j-(4-r~b All dry ditch sample sets submitted to tbe Commission must be in DO greater 1ban 30' sample interva)s from below tbe permafrost or from where samples are fint caugbt and ] 0' sample iliter:va)s tbrougb target zones. p,Ç-CJt .' Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1E-168L Program DEV Well bore seg ~ COPHILLlPS ALASKA INC Initial ClassfType ~EV 1 PEND GeoArea 890 Unit 11160 ~ On/Off Shore On Annular Disposal 0 - Administration ! attaçhed - - - -- - - - , - .NA . . WestS.a1s. D.Saod multilateral wellsegroent;Jeewajved per.20 AAC25..005(e) - - - - - - 2 .Lease .numberappropriate. . . · .Yes. · . . froe 4Qtc.orrecJed; wells.egment lies. entirely withio AOL 02565t . - - - - - 3 .Uniqµe weltnarne.aod Ol!mb.er . . . . . . . . . . . _ . . . . . . . . . . . . _....... Yes._ - - . - . - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - ~ - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WelllQcated in a. defjoe.dpool Yes. · . . KRU West Sa.k .OJ Pool, goyerned. byc.onseJl!.atiQn. Order .No, 406A. . . . . . . 5 WeJlJocated pr.oper .distance. from driJling unitbound.ary. . Yes. - - - - - - - - - - - -- - - - - 6 Well located proper .øistaoce. from Qtber wells. . . Yes. . · . . NQroioal spa.cing withio the pool is.1 I) .açres.. . 7 .SjJtfjçient.acreage.ayailable in dJilliog unjt .1'1.0. . · . . SI?ACING EXCEPTION REQUJREQ:cJo.se approa.cb to.1E-123L 1. Operator wiU su.bmjt .applicatiDo for exception. 8 Jf.deviated, js weJlbQre plaUncJu.ded . . . - - - - - - .... Yes.. 9 .Qper.ator only aff.ected party. . - - - - - Yes. - - -- - - - - - -- - - - - - 10 .Operator bas.apprppriate.bond inJQrce . . . . . . . . _ _ . . . . . . . . ... . . .. .. .Yes.. - - - - - - - - - - - - - - - - - - - - - - - ~ . - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit cao be issued withQut conservaJion Qrder - - - - - - - - . - - - - Yes. - - - - - - -- - - - - - Appr Date 12 Permit C.an be issl!ed wjtbQut aclmioistratille.approvaJ . . . . .Yes. . - - - -- - - - - - - -- i. 10/5f2004 13 Can permit be approved before 15-day wait Yes 14 WelllQcated within area and.strata .authQrized by Injection Order # (put 10# in. commeots). (FQr. NA - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - -- 15 .AJlw~lJs.withinJl4.roite.are.a.ofreyi~wjdeotifjed(For~ervjce.w.ellonly)...... _........ .NA. __ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -. 16 Pre-produ.ced. iojector; .dur.atiQn.of pr~-pro.ductioo tes$. than. 3 montbs (For.servi.ce welt QnJy) . .NA . - - - - - - - - - - - - - - - - - - - - 17 A.CMP. Findjngof CQn$i.ste!1CY. has been Js.sued. for. tbis pr.oject. NA. · . . Multilat~rat well.bore, . - - - - - - - - - - - - - - - - -- Engineering 18 .C.ondu.clor string.pJQvided . . . - - - - -- NA. . · . . CQn.ductQr JnstaJled. in j E-.166.. . - - - - - - - - - - - - - - - 19 S.uúace .casingpJQtect$. alLknown. USQWs . . . . .NA · . . 81l aquifers exempted, AD .CFR 1,47.j 02~b)(3). - - - - 20 CMT vol. adequate. to çirc.utate.on .conductor. & surf. C$g . . . - - - - · .NA · . . Surface ca.sing in$t.alJe.din1E-168, . . - - - - - 21 .CMT v.ot a.d~q u.ate. to tie-in Jongstring to .sur:f csg. . . NA. . · . . tnlerroediate. c.asing Î.nstalled jn lE...168.. . - - - - - - - -- 22 CMTwill coyer all knOw.n.Pfo.dµctiYe bori;Z:Qn.s. . . - - - - 1'1.0. · . . Slotte.dliner .completion ptanned.. lnteJmecliate ca.si.ng cement planned above aoy/aJlhydroc.arbpo.. 23 .C.asiog de.signs ad.equa.te for C, 1", B.& perroafr.ost . . . · .Y.es. - - - - - - - - - - - - - - -- 24 A.dequatetan.kage.or re.serve pit. . . Yes. . · . . Rig ise.qµippe.dwith steel.pits. . NQ r~senle.pjtplanoed, All waste 10.apprOlle.da!1nuJu.s.or dispo$al wells.. 25 Jf.a.re-drill~ has. a 10Æ.03 fQr .abaMonme.nt been apPJQv~d . . - - -- .NA. - - -- - - - - - - - - - - - 26 A.dequ.ate .wellbore separatjon propo~ed. . . . . . . . _ . . . . . . . . . . ..... Yes.. _ _ . /?ro~il)1ity. an.!llysis performe.d, Nearest welJbpreJs B .sandJaterat -. 1.1 O'Jvd.t~eJow, . . . 27 Jf.div~cter required. dQes it.m.eet reguJa.tions. . . . . . . . - - - -- .NA · . . BOI? wiJl.be in.pJace.. . . Appr Date 28 Drilling flujd.program sc.hematic.& eq.uipJistadequate. . . . ... Yes.. · BI-II? expected. betwe.eo 8..5.- B,8.EMW. Planned MW 9.:1 ppg. . if 1017/2004 29 .BOPt=s,.dothey meet reguJa.tioo . . . . . - - - - - - - -- - - - - - · .Yes. - - - - - - - - 91Vtc {~vl 30 .BOPJ::.press ra.tiog appropriate; .test lo.(pu.t psig Î.n .comments) · Yes. · MAS/? ~lcuJated.at 11A.1 psi.. 350.op¡¡Î. BQ~ testp!anoed, . 31 Chokeroanjfold cQmpJies w/API. Rf>-53 (May 84). . . Y.es. . - - - - - - - - 32 WQrk will occur withoutoperation .shutdown. Yes. - - - ~ - - - - - 33 .Is presence of H2S gas. prQb.able. . . . . . . . . · No.. · 1-125 is notpre.sent jn. off$etwells. .Rig is equipped with sensors and.aJarms.. . 34 Mecba.nicaLcondjtio!1 pi wells within.40R veriJiecl (for. s.erv¡~ weIJ only) .NA. - - - - - - - - - - - - Geology 35 .Permit c.a!1 be iSSl!ed w/o hydrogen. sulfide measjJres. . . Yes. - - - - - - - - - - - - - - - - - - -- - - - -- 36 D.atapreseoted on pote.ntial overpressure .zone$. . . . . . Yes · Expectecl reservojr pre.ssu.re is 8,5. -8,8.ppg t=MW; wm.bedrilled wjtb 9."1 ppg mud.. . Appr Date 37 .Setsmic.analysjs Qf $ballow gaszJ:JOes . NA - - - - - - - - -- SFD 10/5/2004 38 .Seabedconditioo su.rvey(if Qff-sh.ore) . . . · .NA - - - - - - -- - - - - - - - - 39 . Contact name{phoneJof.weels.ly progress.reports [explQratoryonly] NA. . - - - - - - - - - - - - - - - - - - - Geologic Date: Engineering Date Date West Sak D Sand multilateral horizontal well segment. SPACING EXCEPTION REQUIRED. Commissioner: Commissioner: 11111 tI Ð~ O'TJ /°1//11- . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 05/06/07 AWS 01 **** TAPE HEADER **** LDWG 05/06/07 01 *** LIS COMMENT RECORD *** . . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 4 G. SUTING D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.875 6.750 1E-168L2 500292323061 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 07-Jun-05 MWD RUN 9 9 F. WENDLER D. GLADDEN 21 11N 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 MWD RUN DRILLERS DEPTH (FT) 148.0 4414.0 7043.0 11960.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR ;;k::ftÃ 02. jÞ I :> ç[S . . TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 59.2815" LONG: W149 DEG 35' 45.4169" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 148 to 4425 feet MD (148 to 2481 feet TVD) . 2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 to drill from 4425 to 6941 feet MD (2481 to 3445 feet TVD). The FE (Formation Evaluation) section of the tool failed due to extremely high torque values while drilling out the 10 3/4" casing shoe. No MWD data was acquired on this run. 3) Baker Hughes INTEQ run 4 utilized a 6.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure, to drill from 6941 to 8158 feet MD (3445 to 3714 feetTVD). 4) Baker Hughes INTEQ run 8 utilized a milling assembly to mill a window in the 7 5/8" casing and to drill from 7043 to 7061 feet MD (3465 to 3469 feet TVD). 5) Baker Hughes INTEQ run 9 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure, to drill from 7061 to 11960 feet MD (3469 to 3515 feet TVD). This wellbore included an openhole sidetrack at 7431 feet MD (3502 feet TVD) from 1E-168L2PB1 during run 9. REMARKS : 1) Data from 6220 to 6842 feet MD (3228 to 3424 feet TVD) was acquired with a MAD pass. 2) This lateral wellbore, 1E-168L2, was kicked off from the parent wellbore, 1E-168, through a window in the 7 5/8" casing. Depth of 7 5/8" Casing Window - Top: 7031 feet MD (3463 feet TVD). Depth of 7 5/8" Casing Window - Bottom: 7043 feet MD (3465 feet TVD). 3) The interval from 11929 to 11960 feet (3513 to 3515 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 88 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH . . MWD $ 6200.0 11960.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MAD MWD MWD $ BIT RUN NO 4 4 9 MERGE TOP 6200.0 6842.0 7061. 0 MERGE BASE 6842.0 7061. 0 11960.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-168L2 5.xtf 150 ConocoPhillips Alaska, Inc. lE-168L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROP 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 . 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 372 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6200.000000 11960.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 415 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!! !!! !!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 4 .2500 START DEPTH 6200.0 STOP DEPTH 7061. 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 DIR PRES MPR GRAM BOTTOM) TOOL TYPE DIRECTIONAL PRESSURE MULT. PROP. GAMMA RAY RES. 04-NOV-04 MSB 18704 6.75 MPR MEMORY 8158.0 6200.0 7061. 0 o 74.5 85.8 TOOL NUMBER 90424 100009727 97378 5309 . $ # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 9.875 4414.0 F.W. Spud 9.10 .0 .0 200 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 4 (MWD Run 4). MPR/GR. The Gamma Ray and Resistivity data from 6220 - 6842 feet was recorded as a MAD pass at the beginning of this run. Data from 6842 - 7061 (lE-168L2 kop) is MWD data from this bit run. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-168L2.xtf 150 ConocoPhillips Alaska, I 1E-168L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) . . Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ...,....------ 28 Total Data Records: 112 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6200.000000 7061. 000000 0.250000 feet **** FILE TRAILER **** Tape Subfi1e: 3 201 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! !! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD 3 log header data for each bit run in separate files. 9 .2500 START DEPTH 7061. 0 STOP DEPTH 11960.0 . $ # 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 DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY PRESSURE RES. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 21-NOV-04 MSB 18704 4.75 MPR MEMORY 11960.0 7061. 0 11960.0 o 84.5 92.9 TOOL NUMBER 12290 1033 10060365 10075536 6.750 7043.0 OBM 9.05 .0 .0 5000 .0 .000 .000 .000 .000 105.0 .0 .0 .0 .00 .000 .0 o BIT RUN 9 (MWD Run 9) . MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN 1e-168L2.xtf 150 ConocoPhillips Alaska, I 1E-168L2 . . FN COUN STAT Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 633 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7061.000000 11960.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 718 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/06/07 01 . **** REEL TRAILER **** LDWG 05/06/07 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes