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Home My WebLink About204-125 • /77-02o4-/z5 • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, August 18, 2015 1:43 PM To: 'NSK Problem Well Supv' Subject: RE: Report of SCP on Kuparuk producer 1Y-24A (PTD 204-125)4-18-15 Follow Up Flag: Follow up Flag Status: Flagged SCANNED MAR 1 5 2016' This is acceptable as long as 45%of the burst rating is not exceeded. From: NSK Problem Well Supv[mailto:n1617C�conocophillips.com] Sent: Saturday, April 18, 2015 10:57 AM To: Loepp, Victoria T(DOA) Subject: Report of SCP on Kuparuk producer 1Y-24A (PTD 204-125) 4-18-15 Victoria, Kuparuk gas lifted producer 1Y-24A(PTD#204-125) is experiencing sustained casing pressure of the outer annulus, and we are having trouble maintaining the pressure below its DNE of 1000psi. A TIFL and MITOA passed on 4-14-15 but the IC-POTs failed on 4-13-15, indicating the packoffs are the probable leak source. Pending approval from our management,we intend to waiver the well to allow IAxOA communication and let the OA pressure operate up to 1400psi. Attached is the schematic and 90 day TIO plot. • 0 Well Name 1Y-24 Notes: Start Date 1/18/2015 Days 90 End Date 4/18/2015 1€00 _ — 1E 114H Annular Communication Surveillance - 1.=CC — — 1? 1ZC0 1000 ECC . 0 k — V� zU4t LCC Jan-15 Jan-15 Jan-1E Feb-15 Feb-15 Feb-15 Mar-15 Mar-15 Mar-15 ,Apr-15 =4pr-1S =pr-1: E .e u , Jan-CC Jan-CO Jan-00 Jan-00 Jan-GO Jan-CC Jan-CC Date Victoria, I don't usually send notifications to you but heard rumor that you were taking over these duties. Can you confirm you are the correct person to whom I was supposed to send this note. Thanks Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 8 . 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 scanned during a special rescan activity or are viewable by direct inspection of the file. ::¿ Q Id- - ld.5 Well History File Identifier Organizing (done) D Two-sided "111111111" 111111 D Rescan Needed 11111111111 II 11/11I RESCAN ~Ior Items: '¢' Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date 1/1 (). ~I oft-; D Other:: BY: ~ 151 t11P Project Proofing 1111111111111111111 BY: ~ Date: U /~ÞI Ob I r ~ X 30 = 10 0 + tlir d-.wO = TOTAL PAGES <6"?? (Count does not include cover sheet) 151 151 Scanning Preparation BY: Date: f Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: '/YES BY: ~ Date: I//~()~ III 11111111111 11111 NO 151 Wff NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: 151 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc Conocillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2010 n ~~ ~~~~~~~. 'APR ~~'z~2010 . ,asks Uii ~ tas Cons. tommiss~or Anchorage Mr. Dan Seamount ~. Alaska Oil ~ Gas Commission r" 333 West 7th Avenue, Suite 100 .~~~y#~~~ ~ ~ ~~'~~ fi ~ ~ ~ t` ~ ~-~' ~~ Anchorage, AK 99501 Dear Mr. Dan Seamount: Enclosed please fmd a spreadsheet with a list of wells from the Kugaruk field (KRL~.. Each of . _ , these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering.the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru Apri117, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since .. ~ Perry ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4123/10 1A_ 1F_ 1Q & 1Y PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-0'I 50029205900000 1810590 SF n/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/6/2010 1A-05 50029206270000 1811040 SF Na 6" n/a 4.25 4/7/2010 1A-08 50029203130000 1780400 SF Na 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF Na 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" n/a 4.25 4/1/2010 1Q-02 50029212480200 2051420 22" n/a 22" n/a 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" Na 27" n/a 3.4 4/6/2010 1 Q-05 .50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1Q-06 50029212240000 1842080 32" n/a 32" n/a 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" n/a 32" n/a 3.82 4/1/2010 1Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1 Y 21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1 /2010 Y 24A 50029223717100 2041250 26" Ma 26" n/a 3.82 4/1/2010 1Y 28 50029223800000 1930890 28" n/a 28" Na 5.52 4/1/2010 1Y31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1/2010 ~ • -s.,,. .-- - -~ MICROFILMED 03/01 /2008 DO NOT PLACE ,', ; ~y-~ ~ ~~. -- ~.,._ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_InsertslMicrofilm Marker.doc ~ .. STATE OF ALASKA '` ALASKA OIL AND GAS CONSERVATION COMMISSION ~~(,yy ~iE ~~x ~ ,~ ~ .,. ~ n~~ ~~isairr REPORT OF SUNDRY WELL OPERATION ~ ,k~ ~ ... 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^~ Exploratory ^ 204-125 - 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22371-01 " 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 1 Y-24A - 8. Property Designation: 10. Field/Pool(s): ADL 025646 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9785' - feet true vertical 6116' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 2935' 9-5/8" 3041' 2506' SURFACE 1558' 9-5/8" 4599' 3600' PRODUCTION 7462' 7" 7568' 5733' WINDOW 1' 5-1/2" 7859' 5969' 5" LINER TOP 598' 5" 7862' 5972' Perforation depth: Measured depth: 8261-8602, 8615-9773 ~t ~ ~ ~~~~ t rti l d th 6127 31 6131 611 7 ~y ~~~~~ 1~N rue ve ca ep : -61 , - 4 Tubing (size, grade, and measured depth) 3-1l2" , L-80, 7682' MD. Packers &SSSV (type & measured depth) Packer= Baker'FHL' Packer= 7193' SSSV= Camco TRM-4E SSSV= 1966' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Brent Rogers/Martin Walters Printed Name Br t Ro ers Title Problem Well Supervisor Signature / Phone 659-7224 Date 12/28/2007 ~~ Form 10-404 Revised 04/2004 ~~4i ~~- ,t~~1 ~ ~ 200th ~~~ a~"b~ Submit Original Only • 1 Y-24A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/11/07 12/13/07 12/19/07 12/27/07 Summary DRIFTED TBG WITH 2.78" X 23" DUMMY PATCH TO 6650' WLM. PULLED EXT PKG DV @ 6579' RKB. SET/PULLED GUTTED 2.75"CLOCK @ 7211' RKB. SET 2.75" D X 2.25" D NIPPLE REDUCER @ 7211' RKB. READY FOR PATCH. SET HALLIBURTON ONE-RUN PERMANENT PATCH FROM 6572.5'-6594.1', TO ISOLATE LEAK IN GLM #4. P/T TUBING (TESTING PATCH) TO 2500#; MONITOR FOR 15 MINS -HELD SOLID. r°` PULLED CAT SV. @ 7211' RKB. JOB COMPLETE TIFL -passed, Initial T/I/0= 200/1000/600. Shut in the WH and the GL upon arrival. Shot the initial IA FL @ 4700' sta. # 2 OV. Stacked out the TBG with LG. Bled down the IA and shot the 2nd IA FL @ the same location. Final T/I/0= 850/300/580 Set Halliburton one-run permanent patch from 6572.5' to 6594.1' followed by a passing TIFL. ~ • • ~~ Memory Muitt-Finger Caliper 11 Log Results Summary ~~ ~ Company: ConocoPhillips Alaska, Inc. Well: 1Y-24A i Log Date; {dovember 28, 2007 Field: Kuparuk Log No.: 8649 State: Alaska Run No.: 2 API No.: 50-029-22371-01 Pipet Desc.: 3.5° 9.3 Ib L-80 EUE 8rd Top Lag Intvll.: Surface Pipet Use: Tubing Bot. Lag Intvl1.: 7,231 Ft. (MD) j Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS ~ ~ This log is tied into the CAMCO D Nipple @ 7,21 ~' (Oriil+~'s depth). ' This log was run to assess the condition of the 3.5° tubing with respect to corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing interval logged is in good condition with respect to corrosive damage. No significant wall penetrations (>ZO%), areas of significant cross-sectional metal loss, or significant ID restrictions are recorded. This is the second time a PDS caliper is run in this well but the first time in the 3.5 tubing. 3.5" Tubing -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded. 3.5" Tubing -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 11~°) are recorded. 3.5" Tubing -MAXIMUM RECORDED ID RESTRICTIONS: No significant ID restrictions are recorded. >~~~ ~ DEC ~. f~ 2007 Field Engineer: K. Mi!!er Analyst: 8. Qi Witness: C. Kennedy ~ ProActive Diagnostic Services, Inc, j P.O. Box 1369, Stafford, TX 17497 ~ Phone: (281} or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS~umemoryiog.com Rrudhoe Say Field Office Phone. (9073 659-2307 %ax: (907) 659-2314 ao~!-gas ~ ~~- ~-a~- i • PDS Report Overview ~ S. Body Region Analysis Well: 1Y-24A Survey Date: November 28, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body a~ metal bss body 250 200 150 100 50 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of'oints anal sed total = 239 pene loss . 0 105 24 214 134 0 0 0 1 0 0 0 Damage Configuration (body ) 50 40 30 20 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 47 47 0 0 0 0 Damage Profile (% wall) ~ penetraton body metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Bottom of Survey = 225 Analysis Overview page 2 Pipe: Body Wall: Upset Wall: Norninal LD.: • • PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 EUE 8rd Well: 1Y-24A 0.254 in Field: Kuparuk 0.254 in Cornpany: ConocoPhi9ips Alaska, Inc. 2.992 in Country: USA Survey Date: November 28, 2007 Joint No. )t. Depth (Ft.) NE~n. Uhs~~t (Ins.) Pen. Body (Ins.) Nen. `% Met,il Ic~cs `;~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 31 + t 0.02 7 -1 .89 2 59 a 0.02 ~3 4 .89 3 90 t).c)1 0.0 12 1 2.88 4 122 U 0.03 1 ~ 4 2.8 Isolate ittin 5 153 +) 0.03 12 t 2.93 6 184 +) 0.03 1 1 -1 2.95 7 215 +) 0.01 5 2 93 8 247 t+ 0.03 I1 5 2.93 9 276 U 0.03 1l ~ 2.93 1 310 +) .02 ~) 6 2.91 1 342 r) 0.03 1~ 3 .92 12 373 +) 0.03 1 ~' 1 2.91 13 404 +) 0.03 11 2.92 14 436 +t 0.03 I2 t, 2.92 15 467 l) 0. 1 6 6 2.93 16 498 1) 0.03 10 4 2.93 17 5 9 u .03 11 ; 2.93 1 56 l) .0 ~) 3 2.93 19 592 +) 0.02 i ~' 2.93 20 624 +) 0. 3 11 2 2.92 21 656 a 0.03 12 ~1 2.95 22 687 U 0.02 ~~ 5 2.92 23 718 a 0.02 ~~ ~ 2.92 24 749 +) 0.02 ~) +> 2.96 5 781 a .0 ~+ -1 .9 26 812 t) 0.03 12 ~ 2.93 27 844 (1 0.01 6 ~ 2.9 28 872 U 0.03 Il ~ 2.93 29 903 U 0.03 12 a 2.93 30 934 +I 0.02 ~) 7 2.92 31 965 t) 0.02 7 (~ 2.94 32 996 +? 0.03 II ~ 2.92 33 1027 tt 0.03 11 a 2.93 34 1057 U 0.02 7 5 2.94 35 1088 c) 0.01 S 5 2.94 36 1119 O 0.01 (> 3 2.94 37 1151 +) 0.01 5 ) 2.92 38 1182 +t 0.03 12 5 2.95 39 1213 +~ 0.03 12 5 2.93 40 1244 a 0.03 1 i 4 2.94 41 1275 a 0.02 8 (i 2.95 42 1306 U 0.03 1I 5 2.93 43 1338 +) 0.03 11 5 2.93 44 1366 U 0.02 ~) ; 2.92 4 13 8 u 0 0 1 1 6 2.93 46 1429 l) 0.03 12 G 2.93 47 1460 ++ 0.03 I2 4 2.92 4$ 1490 +> 0.02 ~) ~ 2.93 49 1521 +> 0.03 II - 2.93 50 1552 !+ 0.03 I I 1 2.93 _._ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L~0 EUE 8rd Body Wall: 0.254 in Upset WaN: 0.254 in Nominal I.D.: 2.992 in Well: 1 Y-24A Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: November 28, 2007 Joint No. Jt. Depth (Ft.) Pen. Ulxc•I (his.l Pen. Body (Ins.) Pen. % Metal loss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 1582 a 0.03 11 3 2.93 52 1613 U 0.02 7 ~ 2.93 53 1645 1) 0.03 1 ~ .92 54 1676 1 ~ 0.03 I 1 s .91 55 1708 U 0.02 `) ' ~ 2.94 56 1739 ll 0.03 111 5 2.95 57 1770 1) 0.03 II 2. 3 58 1802 a 0.03 1 Z 5 2.93 59 1833 U 0.03 11 6 2.94 60 1864 U 0.03 13 ~ 2.94 Shall w itUn . 6 189 I1 0.04 1 t 2.93 Sh Ilow 't0 62 1927 O 0. 3 12 ~ 2.94 Shallow ittin . 62.1 1958 U 0 11 t? 2.81 SSSV 63 198 U .03 12 -1 2.93 64 2014 I) 0.04 14 a 2.95 Shallow ittin . 65 2045 I) 0.03 12 2 2.92 Shal ow ittin . 077 U 0.04 17 ~1 2.90 Sha low itti 67 1 8 tl 0.03 I ; 4 .93 Sha o it'n . 6 139 U 0.03 I -1 2.93 Shallow 'ttin . 69 170 U 0.03 111 t, 2.9 70 220 1) 0.03 I 1 _' 2.95 7 223 U 0.03 I t t, 2.95 Shall w ittin . 7 2264 tl .04 1.3 t~ .94 S all w ~ttin . 73 2295 11 0.04 15 4 2.94 Shallow itFi 7 2 6 1~ 0. 3 1 l 4 .9 75 2358 Il 0.04 14 (~ 2.93 Shallow ittin . 76 2389 U 0. 4 14 E~ 2.94 Sha low ittin . 77 2420 U 0.03 1~ (~ 2.96 78 2452 tl 0. 3 11 ~ .93 79 2482 I1 0.03 I2 1~ 2.93 80 2513 Il 0.03 Ls 5 2.95 Shallow 'tii 81 2545 11 0.02 ~) ; 2.93 82 2576 U 0.04 I (> 2.9 Sh low ittin . 83 2607 a 0.03 11 ~ 2.94 84 63$ 1 ~ 0 03 1 l 2.91 85 2670 tl 0.02 6 5 2.93 86 701 ~ 0.03 11 1 2.91 87 2730 U 0.04 14 ~ 2.92 Shallow ittin . 88 2761 U 0.03 1 _, 9 2.93 Shallow itbn . 89 2793 11 0.04 15 5 2.93 Shallow its 90 2824 1 ~ 0.04 1 5 t; 2.9 Shallow itti 91 2856 11 0.02 `) 5 2.94 92 2887 u 3 I2 5 .9 93 2918 U 0.03 13 -1 2.94 Shallow itlin . 94 2950 U 0.03 12 5 .91 95 2981 U 0.02 ~) 2.91 96 3011 c ~ 0.03 1 ~ 2.92 97 3042 1 I 0.03 1,' S 2.94 9 30 4 0.03 1 ' -1 99 3105 0.01 { 2.93 Penetration Body Metal loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Body Wall: 0.254 in Upset WaN: 0.254 in Nominal I.D.: 2.992 in Well: 1 Y-24A Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: November 28, 2007 Joint No. Jt. Depth (Ft.) I'~~n. Upset (Ins.) Pen. Body (Ins.) Pen. % ~tet,~l I~»s °~~ Min. LD• (Ins.) Comments Damage Profile (%watl) 0 50 100 100 31 6 U 0.02 7 ~ 2.9 100.1 3169 t> 0 02 £i I .95 PU 100.2 177 u 0 O u N A LM 1 tch ~ 2:00 100.3 3186 O 0.02 ti _' 2.89 PUP 101 3197 a 0.0 ~~ 2.92 102 32 7 l1 .0 I I 2. 4 103 3258 O 0.03 13 1 .91 ShaNow it6n . 104 3289 t ~ 0.02 (~ -1 2.94 105 3321 U 0.0 ~~ ~ 2.93 106 352 t~ 0.0 l , 4 2.93 Shallow i 6 107 338 U 0. 13 ~ 2.94 Shallo it'n 108 3415 t1 0.04 15 ~ 2.92 Shallow 'ttin . 109 3446 a 0.03 11 > 2.93 110 3477 a 0.01 t~ 5 .93 111 3509 a 0.02 7 _' 2.94 112 540 t I 0.03 I l1 i, 2.93 113 3571 a 0.03 11 t, 2.93 114 3603 U 0 0 b 3 115 3634 U 0.02 b •1 2.92 116 3665 U 0.0 t3 .93 117 3697 tl .02 b _~ 2.94 118 728 U 0.03 1 S 2. 3 119 3759 (~ 0.0 ~) 5 2.93 120 3788 a 0.02 b 6 2.93 1 1 382 ti 3 11 5 122 3850 t I 0.02 i 2.94 123 3 3 U 0.02 ~) t .91 124 3914 a 0.02 ~~ (> 2.94 125 946 U 0. 3 12 4 2.9 126 3977 l l 0.03 1 _' -3 2.92 127 8 t) 003 11 5 2.94 128 4039 a 0.03 11 ~' 2.92 129 4069 t 1 0.03 12 _' 2.92 130 4101 t ~ 0.02 9 4 2.92 131 4132 U 0.0 15 4 2.92 Shall ~ttin . 132 4163 t I 0.03 1O 2.92 133 4193 U 0.0 ~) 2.92 134 4225 U 0.03 13 (, 2.92 Shallow ittin . 135 4256 U 0.02 9 2.92 136 4287 a 0.03 11 -t 2.94 137 4318 U 0.03 1 U 2.91 138 4350 l1 0.03 11 ~ 2.92 13 4381 (I 0.03 12 ~ .92 140 4412 t I 0.03 1 I -1 2.93 141 4443 t l 0 03 12 t 2.93 142 4475 t 1 0.03 12 _' 2.93 143 4506 0 0. 3 1 t) ~i 2.91 144 4536 t 1 0.02 ~) 2.92 45 4566 t~ 0.02 F3 ~ .92 146 4598 ! ~ 0.03 1 I I 2.91 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L$0 EUE 8rd Well: 1Y-24A Body Wall: 0.254 in Field: Kuparuk Upset Wafl: 0.254 in Company: ConocoPhilips Alaska Inc. Nominal I.D.: 2.992 in Country: , USA Survey Date: November 28, 2007 Joint No. Jt. Depth (Ft.) f'c~n. Illxe~t (Ins.) Pen. Body (Ins.) Pen. % Metal lo,s °~~ Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 147 4629 t~ .p q 1 4 60 a 0.04 14 -1 2.92 Sh Ilow ittin . 148 1 4691 O .03 1 3 5 .91 PUPS I w "ttin 148. 148.3 4701 47 0 t) ~) 0 0.02 O ~) U '~ N A 2.9 . GLM atch ~ 5:30 PUP 149 47 0 O 0.03 11 ~' 2.92 150 47 2 O 0.03 13 4 2.9 allow itti 151 4783 t) 0.03 11 r~ 2,93 1 4814 O 0.02 9 i 2.9 153 6 U 0.04 15 .5 .93 Sh low it "n . 1 77 t) 0.0 12 .91 155 490 O 0. 3 13 3 .90 Sallow ' 6n . 15 49 6 O 0.03 13 _' 2.92 Shallow ittin 157 4969 t ~ 0.03 11 2.93 . 1 8 5001 n 0.02 7 I 2.92 159 5032 U 0.03 11 _' 2.9 160 5064 t) 0.03 1 C) ~ 2.g4 161 5 9 a 01 V t) 2. 1 16 1 5 l) 0.03 1 1 ~ 2.90 163 155 U 0.03 11 2g2 164 5186 (~ 0.03 12 ~ 2 1 5 521 U 0.03 12 ~ 2.92 16 5 47 U .03 10 4 2.91 167 5277 U 0.02 6 ~' 2.91 5 u 0 02 9 ~ 1 169 5339 U 0.02 ~) I 2.91 170 5369 U 0.03 12 a 2.90 171 5399 t) 0.03 12 I 2.93 17 5430 U 0.0 10 2.90 173 5460 U 0.03 13 s 2.90 Shallow "t6n . 174 54 1 U 0.02 9 I 2.90 175 5522 U 0.02 9 ~ 2.93 176 5554 (t 0.03 1 1 2.90 177 5585 l) 0.03 12 2.91 17 616 O.(10 0.02 9 I .9 179 5648 O 0.01 5 -1 2.91 1 5679 U 0.02 8 ~ .90 181 5710 tl 0.02 ~) 1 2.92 1 2 5741 tt 0.03 I -! ~' 2,g1 183 5771 c t 0.01 5 ' ~ 2.92 183. 5 2 O 0.02 7 I .92 PUP 183.2 5812 ll 0 O I t N A GLM 3 Latch ®8:30 18 . 582 c) 0.03 1 I _ 94 P 184 5832 U 0.01 (~ t 2.91 185 5863 a 0. 3 13 ~' 2.92 Shallow "tiro . 186 5894 tt 0.04 14 I 2.91 Shallow it6n . 7 59 t) 0. 2 2.92 188 5957 t t 0.02 6 2.92 18 5988 U 0.02 ~~ -1 2.9 190 6020 l ~ 0.03 I ~' I 2.92 _ Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf L~0 EUE Srd Well: 1Y-24A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConoooPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 28, 2007 Joint No. Jt. Depth (Ft.) Pen. Uhsel (Ins.) Pen. Body (Ins.) Pen. % Mc•t,~l I u,s '%, Min. LD• (Ins.) Comments Damage Profile (% wa-I) 0 50 100 191 6050 U 0.03 13 Z 2.91 Sh Ilow it~n . 192 6081 t) 0.02 9 I .92 193 6111 t) 0.03 10 I .91 94 6143 tt 0.03 12 5 2.92 195 6174 U .02 7 2.91 196 6 04 U 0. 3 13 ~ 2.91 Sha) ow itGn 19 235 U 0. 2 7 ; 2.92 198 6265 a 0.01 5 5 2.91 199 6296 O 0.04 14 'i 2. 1 allow 'tUn . 200 63 U 0.03 t 3 2.91 Sh I w itUn . 201 635 U 0.03 10 ,! 2.90 202 6387 tt 0.02 `t 2.92 203 6418 t t 0.02 ~) 2.92 04 6449 t t 0.02 't 2.91 20 6480 O 0.02 t3 t, 2. 1 206 6509 t) 0.03 11 2.91 07 6541 a 0.03 10 ~t 2.92 207.1 6572 a 0.0 I 2.94 P P 207.2 6581 u 0 ~ U N A GLM 4 Lat h ®1 : 0 207.3 6591 u.U8 0.01 b 4 .93 PUP 08 6601 t t 0.02 9 5 2 91 209 6632 a 0.03 12 ~t 2.91 210 6663 tJ 0.03 11 I 2.92 211 6695 U 0.03 13 ? 2.91 Shallow 't6n . 1 676 U 11 4 0 213 6758 U 0.03 10 1 2.91 14 6789 t) 0.04 16 t3 .91 Shallow itfi 215 6820 tl 0.04 14 4 2.92 Shallow 't6n . 216 6 51 tl 0.02 8 1 2.91 217 6883 O 0.03 1 1 2.91 2 8 6915 ll 0.03 10 3 2.90 219 6946 It 0.03 1 3 t 2.91 Shallow it6n . 220 6978 U 0.04 1 i _' 2.92 Shallow ittin . 221 7009 U 0.02 t3 I 2.91 2 7040 t t 0.0 10 2.90 223 7072 t t 0.03 12 _' 2.91 .1 7103 U .02 t3 ? .95 PUP 223.2 7111 t t 0 U U N A GLM 5 Latch ®3:00 223.3 7121 tt 0.02 ~? 2.93 PUP 224 7132 ~t 0.03 I -1 2.92 Shallow 'tin . 224.1 7163 (t 0 l) l) 2.81 X Ni le 224.2 7166 tt 0.02 9 11 2.91 PUP 2 4.3 71 4 U 0. 7 1 9 P P 224.4 7188 It 0 U tt 2.94 Packer 24.5 7196 U 0.03 12 1 2.93 PUP 224.6 7210 t t 0 0 u 2.75 Camco D Ni le 224.7 7213 tt 0.02 ti t 2.95 P P 225 7 22 (t 0.02 ~) ? 2.94 Penetration Body Metal Loss Body Page 5 ConocoPhillips Alaska, Inc. • KRU 1Y-24A TUBING (0-7180, API: SSSV T Annular Fluid: 500292237101 TRDP Wall T : O ' Com lotion: Last W/O: PROD 8/28!2004 10/182004 An le TS: An le TD: Rev Rea on: U d 95 9785 GLV desi n 3/1 006 00:3.500, Reference L Ref L Date: Last ate: ID:2992) Last Ta TD: 9785 ftKB Last Ta Date: Max Hole An le: 95 9785 Casin Stfi - COM ON S TRINGS Descri tan Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H+10 SURFACE 9.625 0 3041 2506 47.00 L-80 PRODUCTION 7.000 0 7568 5733 26.00 L-80 _ SURFACE 9.625 3041 4599 3600 36.00 J-55 5" LINER TOP 5.000 7264 7858 5968 18.00 L-80 L1 TOP OF LINER 2.375 7600 7868 5977 0.00 L-80 WINDOW Cesi Strin -LINER LATE 6.156 AL LEG A M 7858 inimu ID L 7868 5977 0.00 A Uners 1.00"'NOT ACCESS IBLE FO R WELLWO Deacri lion ' e To Bottom ND Wt G e Thread LINER LEG A >f1 2.375 7906 8614 6131 4.70 L-80 STL LINER LEG A #2 2.3 5 8614 9785 ' ' 9785 4.70 L-80 STL Tu ' S Size 500 3 T 0 - C lion 7 Bottom ND 7180 5438 7 Wt 9.30 Grade L-80 Thread EUESrd . 3.500 7180 7682 5820 9.20 L-80 EUE8rdMOD Perforations Summa Interval ND Zone Status Ft SPF Date T Common 8261 -8602 6127 - 6131 341 8 10/102004 IPERF Slotted Liner, 3/8" holes, 8 spf, 90 d orient - I 8615 - 9773 6131 - 6117 1158 8 10/10!2004 IPERF Sbtted Liner, 318" holes, 8 spf, 90 orient Ge L' ndrele NeHes St MD TVD Men Mfr Msn Type V Mfr V Type V OD Latch Port TRO Dete Run Vlv Cmnt 1 3176 2599 CAMCO MMG GLV 1.5 RK 0.188 1248 11/112005 2 4700 3671 CAMCO MMG OV 1.5 RK 0.250 0 11/112005 - 3 5811 4447 CAMCO MMG DMY 1.5 RK 0.000 0 11/192004 4 6579 4994 CAMCO MMG DMY 1.5 RK 0.000 0 11/19/2004 5 7110 5386 CAMCO MMG DMY 1.5 RK 0.000 0 1192006 Oth er lu s u i .etc. - CO MON JEWELRY e th ND T Deacri lion ID 28 28 HANGER FMC TUBING HANGER 10/3/2004 3.800 1966 1766 SSSV CAMCO TRM~E SSSV ftHVS-379 set 10(3/2004 2.812 7161 5424 NIP HALLIBURTON'X' NIPPLE 10(3/2004 2.812 7172 5432 SEAL BOT 80-40 SEAL ASSEMBLY STABBED INTO ORIGINAL COMPLETION PBR ~ 7180' 10/3/2004 3.000 7180 5438 PBR BAKER PBR ORIGINAL COMPLETION 3•~ 7193 7211 7681 7870 5448 5461 5819 5978 PACKER NIP SOS TTL BAKER'FHL' PACKER ORIGINAL COMPLETION CAMCO'D' NIPPLE NO GO ORIGINAL COMPLETION BAKER ORIGINAL COMPLETION ORIGINAL COMPLETION 2.937 2.7`~ 2.992 2.992 Other s ui . e -LINER LEG A JEWE Y De ih ND T D ~ ~~ TUBING 7914 6009 L1 Deploy WEATHERFORD DEPLOYMENT SLEEVE/OH WHIPSTOCK from LEG AL1 TO LEG SLV A 1.000 (7180.7682• OD:3.500• 8614 6131 Deploy SLV SHORTY BAKER DEPLOYMENT SLEEVE CONNECTS TOP 8 BOTTOM LEG A LINER 2.250 ID:z.s92) enera l ores Date Nots 10/182004 CTD DUAL LATERAL WELL: LEG A -PRODUCING LATERAL LEG DRILLED OFF LEG AL1 "'NOT ACCESSIBLE FOR WELLWORK"' 5" LINER TOP (72647858, OD:5.000, Wt:18.OD) - LINER LEG A #1 (7906-8614, OD:2.375, Wt:4.70) 1 r . ~ - I I I 1 Y-24A (PTD 2041250) Report Of. comm - failed TIFL Regg, James B (DOA) . Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, August 16, 2007 8:53 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1Y-24A (PTD 2041250) Report of TxlA comm - failed TIFL Attachments: 1Y-24A.pdf; 1Y-24A 90 day TIO plot.gif ~ . fllZ'lo 7 ~~? <.J Tom & Jim, ,/ Kuparuk gas lifted producer 1Y-24A (PTD 2041250) failed a TIFL on 08/15/07 and has been added to the SCP report. The TIO immediately prior to SI for the TIFL was 200/1040/250. A leaking GL V check is suspected. Slickline will troubleshoot the tbg / leak and repair if possible. Attached is a schematic and 90 day TIO plot. Please let me know it there are any questions. Brent Rogers Problem Wells Supervisor 659-7224 «1Y-24A.pdf» «1Y-24A 90 day TIO plot.gif» SCANNED AUG 2 7 2007 8/21/2007 TUBING (0-7180, 00:3.500, 10:2.992) TUBING (7180-7682, 00:3.500, 10:2.992) 5"LINER TOP (7264-7858, 00:5.000, Wt:18.00) . API: 500292237101 SSSV TYDe: TRDP Annular Fluid: Reference Loç¡: Last Taa: Last Taa Date: .MMO Description CONDUCTOR SURFACE PRODUCTION SURFACE 5" LINER TOP L 1 TOP OF LINER WINDOW Imãlfñìì1iSl!!fIi¡'1J¡¡11JI Description LINER LEG A #1 LINER LEG A #2 mûlñññ1iSI!' Size 1 Top 3.500 I 0 3.500 7180 RiIfQIit¡Øil5.(j'~¡¡;¡i Interval TVD 8261-8602 6127-6131 8615 - 9773 6131 - 6117 . KRU Well TYDe: PROD Oria CamDletion: 8/28/2004 Last W/O: 10/18/2004 Ref Loç¡ Date: TD: 9785 ftKB Max Hole Anale: 95 dea (â) 9785 Size 16.000 9.625 7.000 9.625 5,000 2.375 6.156 Top Bottom o 121 o 3041 o 7568 3041 4599 7264 7858 7600 7868 .7~~~ TOD Bottom I 7906 8614 8614 9785 I ·im(j'lñiil~.;rløl¡j¡;:II~ 1 TVD Wt 1 5438 9.30 9.20 1 Y -24A Anale (â) TS: deo (â) Anç¡le ((j) TD: 95 dea (â) 9785 Rey Reason: GLV desiç¡n Last Uodate: 3/13/2006 TVD 121 2506 5733 3600 5968 5977 ~ 6131 9785 Wt 62.50 47.00 26.00 36,00 18.00 0.00 0.00 Grade H-40 L-80 L-80 J-55 L-80 L-80 Thread Size I 2,375 2,375 I I Bottom 1 7180 7682 " BÊI$i':IO __.. I Wt I Grade Thread I I 4.70 L-80 STL I 4.70 L-80 STL I I Grade I I L-80 I L-80 Thread EUE8rd EUE8rdMOD 1 I Status Ft SPF Date TYDe Comment 341 8 10/10/2004 IPERF Slotted Liner, 3/8" holes, 8 spf, 90 deç¡ orient 1158 8 10/10/2004 IPERF Slotted Liner, 3/8" holes, 8 spf, 90 dea Port TRO Date Vly Run Cmnt 0.188 1248 11/1112005 0.250 0 11/11/2005 0.000 0 11/19/2004 0,000 0 11/19/2004 0.000 0 1/9/2006 Depth TVD Type Description ID 28 28 HANGER FMC TUBING HANGER 10/3/2004 3.800 1966 1766 SSSV CAMCO TRM-4E SSSV #HVS-379 set 10/3/2004 2.812 7161 5424 NIP HALLIBURTON 'X' NIPPLE 10/3/2004 2.812 7172 5432 SEAL BOT 80-40 SEAL ASSEMBLY STABBED INTO ORIGINAL COMPLETION PBR @ 3.000 7180' 10/3/2004 " 7180 5438 PBR BAKER PBR (ORIGINAL COMPLETION) 3,000 7193 5448 PACKER BAKER 'FHL' PACKER ORIGINAL COMPLETION) 2,937 7211 5461 NIP CAMCO 'D' NIPPLE NO GO (ORIGINAL COMPLETION) 2,750 7681 5819 SOS _LETION) 2,992 TTL Depth TVD Tyoe Description ID 7914 6009 L 1 Deploy WEATHERFORD DEPLOYMENT SLEEVElOH WHIPSTOCK from LEG AL 1 TO LEG 1.000 SLV A 8614 6131 Deploy SL V SHORTY BAKER DEPLOYMENT SLEEVE CONNECTS TOP & BOTTOM LEG A 2.250 LINER Zone ._111 St MD TVD Man Mfr Man Type V Mfr 1 2 3 4 5 3176 2599 CAMCO 4700 3671 CAMCO 5811 4447 CAMCO 6579 4994 CAMCO 7110 53861 CAMCO ~ ~ LINER LEG A #1 (7906-8614, 00:2.375, Wt:4.70) .-- ----- MMG MMG MMG MMG MMG MON JEW' . V Type VOD Latch GLV 1.5 RK OV 1.5 RK DMY 1.5 RK DMY 1.5 RK DMY 1.5 RK :..fìjíj) Date 1 Note 10/18/20041 CTD DUAL LATERAL WELL: LEG A - PRODUCING LATERAL LEG DRILLED OFF LEG AL 1 I "'NOT ACCESSIBLE FOR WELLWORK'" ~ /8 N\" ;t~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041250 Well Name/No. KUPARUK RIV UNIT 1Y-24A Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-22371-01-00 MD 9785 TVD 6116 Completion Status 1-01l Current Status 1-01l UIC N Completion Date 10/18/2004 REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes ~-~.--~ DATA INFORMATION Types Electric or Other Logs Run: GR, Pressure Well Log Information: Log/ Data Digital Type Med/Frmt ~ I~ C Lis r~Pt f": !fOg ~ Electr Dataset Number Log Log Run Scale Media No Name Directional Survey Directional Survey Gamma Ray LIS Verification Gamma Ray Gamma Ray Pressure 25 Blu 25 Blu 1 Blu 13805 13805 Pressure Blu Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y ~ (data taken from logs Portion of Master Well Data Maint Interval OH/ Start Stop CH -~~- 7841 9785 Open 7870 9918 Open 7651 9785 Open 7651 9785 Open 7855 9785 Open 7855 9785 Open 50 1592 Case . Received Comments 11/8/2004 11/8/2004 PB 1 3/13/2006 GR ROP plus graphics 3/13/2006 GR ROP 3/13/2006 GR ROP 3/13/2006 GR ROP 8/8/2006 GlS, FBHP Survey, SPIN, PRES, TEMP, GRADIO, GR, eel 1-Aug-2006 7450 7600 Case 9/12/2006 SBHP, PRES, TEMP 25- Jul-2006 Received Sample Set Number Comments Chips Received? Y / N _ Formation Tops Daily History Received? ~N (j/N Analysis V : 14 Received? Comments: . .- DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041250 Well Name/No. KUPARUK RIV UNIT 1Y-24A Operator CONOCOPHILLlPS ALASKA INC MD 9785 TVD 6116 Completion Date 10/18/2004 Completion Status 1-01L Current Status 1-01L \~ Date: ì N'r,¡ ~J,o Compliance Reviewed By: API No. 50-029-22371-01-00 UIC N . . RECEiVED 09/11/06 SEP 1 2 Z006 Schlumberger NO. 3955 ~ Oil & Gas Cons. commission Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¿~LI-/()5- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Log Description CD Date BL Color Job # 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07/25/06 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1 D-06 11249948 INJECTION PROFILE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1 J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1J-170 11249954 PRODUCTION PROFILE 09/01/06 1 1 G-04 11216321 INJECTION PROFILE 08/31/06 1 1 D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . RECEIVED .AUG () ¡.; 2006 08/01/06 SCblumberger NO. 3899 ..\Jask,a On & Gas Cons. Corr~ Anchorage Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . .- ;)6'-( - (.g.E) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk . Well Job # Log Description Date BL Color CD . 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07128/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y -24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1D-107 11216309 INJECTION PROFILE 07112/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. - e Transmittal Form r'ill BAKER MUGHU Ii ....,..,-~"... II ,:¡;;~:',";:¿~':'::;'" ",- ",;(fe; ;::.;'~ : -'" - - "" -:. "" .,'" - ---"'--"'-~-'--------'---~ ~_~"""""_~:~~:_:_1_~~__~____~}~.,J INTEQ r,~_',.", ",",","'-'.,~~ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 1 Y -24APBl Contains the following: tP I ~\) 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional True Vertical Depth Log LAC Job#: 737190 Sent By: Glp Received By: ð tL,.J Date: APR 05, 06 Date: J )..~),J.¡ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hnghes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~,,;- - ,.) >"';;' _'" .. .. ...._:0 ------ ----,------ '----~---- ",.",,, Â ò '1--/) j-" (,t/~ e e Transmittal Form '&ill BAKER IIUGIIIS INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: lY-24A ¡¡= II Contains the following: II 1 LDWG Compact Disc II (Includes Graphic Image files) 1 LDWG lister summary I! II 1 blueline - GRJDirectional Measured Depth Log 11 1 blueline - GRJDirectional True Vertical Depth Log II II II ! ! 'I LAC Job#: 737190 ! I !I ",.- -# I ¡ßÖ'6 Ii ¡I ¡ JI I Sent By: Gle.c ¡YJJ Received By: j d- _ . Date: Mar 07, 06 Date: J 3 ~iJð' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAY. (Q07) ?n7_nn??' __~.:."''''.- II rM_-Ï-;~, _'!L~~ - ''-'; -~ ----,-----_._-~-.".~--~. ~_.~.~_.._-;~-_.~'-~~ ..... - ..- ..._.~....... _..".., ,-....-...---,- ..~"" '~~1 ~ ~t{ -ll ~- r:;t~ _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG "" 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: "-1 : 20AAC 25.105 20AAC 25.110 181 Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or A.?and. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 10/18/2004 204-125 304-337 I 304-356 3. Address: 6. Date Spudded 13. API Number clo P.O. Box 196612, Anchorage, Alaska 99519-6612 1017/2004 , 50-029-22371-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/10/2004 , Kuparuk 1Y-24A 570' SNL, 1762' EWL, SEC. 01, T11 N, R09E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 65' SNL, 2904' EWL, SEC. 12, T11 N, R09E, UM 106' Kuparuk River I Kuparuk River Oil Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 4907' SNL, 1352' EWL, SEC. 01, T11 N, R09E, UM 9785 + 6116 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: 9785 + 6116 .- Ft ADL 025646 Surface: x- 531432 y- 5974756 Zone- ASP4 ¡ TPI: x- 532596 y- 5969987 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 531042 y- 5970417 ' Zone- ASP4 1966' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo NIA MSL 1500' (Approx.) 21. Logs Run: 'VW..i..dD....J 7,. S'S"., '/772:> AÞ GR, Pressure S-; c:¡ b5" "TT/'.D /Ì·2..</'o'/ 22. c'ASING, LINER AND CEMENTING RECORD ::·..···i~~~~~~ ....:... . ::;ET1:1NGpEPTHMD SETTING DEPT'HJ'VP i~?i£ ........... /. ··/i "i" .' Vl!LPERF'l'. GRADE. Top BOTTOM Top I BOTTOM ·i.· /' PULLED 16" 62.5# H-40 Surface 121' Surface 121' 24" 260 sx Arctic Set (Approx.) 9-5/8" 47# 136# L-80 I J-55 Surface 4599' Surface 3600' 12-1/4" 00 sx PF 'E'. 480 sx 'G', Top Job: 105 sx PF 'C' 7" 26# L-80 Surface 7568' Surface 5733' 8-112" ?50 sx Class 'G' 5" 18# L-80 7264' 7857' 6417' 5968' 6-1/8" 175 sx Class 'G' 2-3/8" 4.7# L-80 7914' 9785' 6009' 6116' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of To,e and 24. TUBING /' Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 7185' MD TVD MD TVD 3-1/2", 9.3# 19.2#, J-55 I L-80 7185' - 7681' 7193' 8261' - 8602' 6127' - 6131' 25. ..... .~919r' ·d;";'·.i' . 8615' - 9773' 6131' - 6117' L ./. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7854' Set Whipstock 2000' Freeze Protected with Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 24, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE 1 GAS-Oil RATIO 11/6/2004 12 TEST PERIOD .. 692 2000 2363 176 2889 Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 241 1418 24-HoUR RATE 1384 4000 4727 24 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, ~'BFL NOV 2 6 20M r-CÖ~;l::'\:-";~-~ None 0 , , ! ¡ \ iº.~:i:i~6<j ;.~-,~ \ V¡:;/,;'·: \ ';R: , GF \. i , --'"~-'_. f l,.~-.,..<- '..¡.._.".ú,.-"·- .,....¥_.....,o;IO.Cf Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. Á GEOLOGIC MARKERS 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". C4 7765' 5889' None C3 7831' 5945' C2 7839' 5952' C1 7863' 5973' B4 7880' 5986' B3 7905' 6004' B2 7990' 6046' B1 8050' 6072' A6 8100' 6096' A5 8118' 6104' A4 8190' 6120' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date II· I Kuparuk 1Y-24A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dan Kara, 564-5667 204-125 304-337 1304-356 Permit No. I A roval No. 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 above 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, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 Submit Original Only BP EXPLORATION . mary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 1 0/1/2004 00:00 - 06:00 6.00 MOB P PRE Continue with rig move on 1 F access road and arrive at the Spine road at 0600 hrs. 06:00 - 15:00 I 9.00 MOB P PRE WO crew change and morning shift traffic before laying mats on Spine and resuming move. Also PU extra mats and take to i 1 Y Pad and begin setting mats on the Pad 15:00 - 17:20 2.33 MOB P PRE Enter Spine and make a quick 3 mile move to 1 Y Pad 17:20 - 20:00 2.67 MOB P PRE Park on access road to back Pad while continue to lay mats on back Pad up to well. Pick up mats on Spine and shuttle to Pad. Install 7-1/6" double gate to bottom of TOT stack. 20:00 - 20:20 0.33 MOB P PRE PJSM prior to moving over well. 20:20 - 21 :00 0.67 MOB P PRE Move last 100 yds and move onto well. Accept rig at 2100 hrs. 21 :00 - 00:00 3.00 RIGU P PRE Rig up out buildings. Set-in upright and Tiger tanks. R/U to circulate well with 10.5ppg brine. 10/2/2004 00:00 - 01 :50 1.83 RIGU PRE Continue RU. Offload 290 bbls 10.5ppg brine. 01 :50 - 02:00 0.17 BOPSU PRE PT circulation lines to 3500 psi. 02:00 - 03:05 1.08 BOPSU PRE Open well, no pressure. Circulate bottoms up at 4bpm. 03:05 - 03:15 0.17 BOPSU PRE Monitor well for flow. Dead. 03:15 - 04:00 0.75 BOPSU PRE RD circulation lines. 04:00 - 05: 15 1.25 BOPSU PRE Make up and set BPV. Test to 1000 psi from below. 05: 15 - 07:00 1.75 BOPSU PRE ND Production tree and load out for inspection and redressing. 07:00 - 12:30 5.50 BOPSU PRE Fin MU stack and get measurements for test jt. Swap lower rams to put 3-1/2" in top set and 4" in bottom set. NU BOPE. NU riser, replace boot in riser Tubing and accessories AOL APC fin berm and set tanks Load out rig mats. Move camp from front Pad and park in normal spot 12:30 - 13:00 0.50 BOPSU P PRE Function test rams. Fill stack and body test. Leaked thru blanking plug and IA ended up w/400 psi Begin loading pipeshed w/3-1/2" tubing 13:00 - 16:00 3.00 BOPSU SFAL PRE Bleed off press. WO FMC. Remove test jt. Try a few tricks. Pull blanking plug-nothing obvious 16:00 - 17:00 1.00 BOPSU SFAL PRE WO FMC to get parts and/or another blanking plug. Changed out ball and worked 17:00 - 23:00 I Fin load 3-1/2' tubing in pipeshed 6.00 BOPSU P PRE BOPE test. 250/4500psi Witness waived by AOGCC 23:00 - 00:00 1.00 WHSUR P DECOMP Pull FMC blanking plug. 10/3/2004 00:00 - 02:00 2.00 WHSUR N DECOMP Pull BPV. Had problem with jointed puller lining up properly. 02:00 - 03:00 1.00 WHSUR P DECOMP P/U 4" elevators and landing joint. MU circulating line. 03:00 - 03:15 i 0.25 WHSUR P DECOMP PJSM review plan forward for pulling hanger to rig floor. 03:15 - 03:35 0.33 PULL P DECOMP Block wt = 8k. String wt in 10.5ppg brine 62k. Pull to 70k and continue wt increase. Seals released at 105k. Pull hanger to floor level. Fluid level +/-10' below wellhead. 03:35 - 05:00 1.42 PULL P DECOMP Circulate at 4bpm w/ full returns. Same time clear floor and RIU Camco spooler equipment. 05:00 - 06:00 1.00 PULL P DECOMP RD circulation equipment. LD landing jt and breakout 4" hanger. Prep to LD 4' tbg. 06:00 - 07:00 1.00 PULL P DECOMP Load completion jewelry in pipeshed 07:00 - 15:00 8.00 PULL P DECOMP LD 4898' 4" 11 # J-55 DSS-HTC(AB) R2 tubing wI Cameo 4" TRDP SSSV and pups, Merla GLM #5 w/ pups. Recovered 25 of 32 reported SS bands 15:00 - 18:00 3.00 PULL P DECOMP RU and standback 35 stds 3-1/2" 9.3# J-55 EUE8Rd R2. Find that collars are pitted fairly good (on low side). WO Kuparuk Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations y Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 8/1 0/2004 8/28/2004 2 Spud Date: 6/10/1993 End: 8/28/2004 RWO specialist. Evaluate and decide to replace collars when RBIH. Fin stand back 3-1/2" J-55. Total of 70 jts. Remaining is 1 single and PBR's seal assembly to breakdown. 18:00 - 18:10 P DECOMP PJSM with new crews. Review hazards and plan forward. 18:10 - 18:25 0.25 P DECOMP Start to make break on the last full joint and PBR seal assembly. ( Seal assembly contains stuck Weatherford OHWS and tbg jt contains a Weatherford RBP) Crews noticed this connection was wet and also possibly held trapped pressure. This was reviewed in the PJSM. Crews wrapped the connection with Herculite and absorb while the pressure was bleeding down. Useing the Eckel tongs one more round was backed out of the connection and the connection parted due to the remaining trapped pressure. No injuries were incurred. Thick oily fluid sprayed on the front of the 3 rig hands working the area. Safety glasses prevented any fluids entering the eyes. 18:25 - 21 :00 2.58 PULL N DECOMP Called HSE field advisor and town engineer. Cleaned up the rig hands and the rig floor. Paided special attention to face areas to be sure all residual fluids were completely washed off with soap and water. No adverse affects to righands. 21 :00 - 21 :30 0.50 CASE P DECOMP PJSM with all hands. Reviewed trapped presure incident, the plan forward and running order for new 3-1/2" completion string. 21 :30 - 00:00 2.50 CASE P DECOMP Run 3-1/2" completion string. Usein9 70jts of the pulled 3-1/2" J-55 tbg and replacing the collars on each one. Remaining 3-1/2" tbg is new L-80. 10/4/2004 00:00 - 04:20 4.33 CASE P DECOMP Continue running 3-1/2" completion string. Changeing out collars on first 70jts of re-run tbg. 04:20 - 08:30 4.17 CASE P DECOMP MU new 3-1/2" 9.3# L-80 EUE8Rd R2 tubing and GLM's from pipe rack 08:30 - 09:40 1.17 CASE P DECOMP Install SWS (Cameo 3-1/2" TRM-4E) safety valve. Change out Cameo spooler. Install control line and PT 09:40 - 12:10 2.50 CASE P DECOMP MU 3-1/2" 9.3# L-BO EUE8Rd R2 with control line installing SS bands on every other joint Sent seal assy and one full jt (w/ WRP) to WII. Used borescope and saw WS anchor in seal assy confirming that no junk from OH WS was left in well 12:10 - 13:15 1.08 CASE P DECOMP PU extra jt and see textbook entry into PBR. Determine spaceout pups and none needed. Close annular. PT IA to 550 psi and hold for 5 min to verify seals holding. Bleed off press. Swap to pump down tubing. PUH 52k to put seals above PBR 13:15 - 14:00 0.75 CASE P DECOMP Pump 16.7 bbls corrosion inhibitor FRW132 mixed in 10.5# brine and displace w/1 0.5# brine to leave in the IA above PBR 14:00 - 16:15 2.25 CASE P DECOMP MU last jt, tubing hanger w/ XO, and landing jt. Install control line and test. RIH and land 27.50' below N2 RKB. Left landing jt in hanger as guide for WL. Left control line in stack pressured up (SSSV open) Used 35 SS bands. String wts before landing 54K up, 42k down 16:15 - 17:30 1.25 CASE P DECOMP Safety mtg: RU and run WL RU HES slickline unit. MU tool string and strip thru TIW valve on landing jt 17:30 - 21 :05 3.58 CASE P DECOMP Make drift run w/2.70" TS to 7826'. P/U TTP and set in Cameo D nipple at 7211' WLM. R?D SL Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page ,18 of 34 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 10/4/2004 21 :05 - 23:15 10/5/2004 23:15 - 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 06:30 06:30 - 11 :00 11 :00 - 15:00 15:00 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 22:10 22: 1 0 - 22:50 Task ~~. 2.171 CASE I P I I I I I 0.75 CASE I P 2.00 WHSUR I P 2.50 WHSUR I P 2.00 WHSUR P 4.50 BOPSU~ P 4.00 BOPSUF1 P 1.50, WHSUB I P I I ¡ 1.00 WHSUB [i P 1.00 WHSUR I P I IN IN Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 1.50 PULL 1.001 PULL I 1.001 PULL IP 0.17 DHEOP Ip 0.67 DHEOP 'P DECOMP Open IA RlU to tbg and PT to 2500 psi/15 min - good test. Bleed off to 1500 psi then PT IA to 2500psi 15 min - good test. Drop pressure on tbg and sheared DRC valve. Pressure up tbgllA to 1500 psi and close SSSV dump pressure above SSSV. Monitor pressure and SSSV is working. Dump all pressures. RID hoses. Remove landing joint and set FMC BPV. ND lower double gate and spools. NU production tree. PT tbg hanger pack-off to 5k. Pull BPV and set FMC test plug. PT tree to 5000 psi. Pull test plug NU BOPE Test BOPE. Witness waived by AOGCC Line up on IA and pump 55 bbls diesel. Final differential pressure 300psi. Blowdown lines. RlU slickliner equipment including lubricator. RIH with slickline pulling tool. Pull DRC plug from GLM station #1. Run dummy GLM in station #1. Kickover tool activated in station #2 while RIH. POOH to recock tool. Run dummy GLM again to set in station #1. Had 2nd failure to set. Unable to set the dummy. Reconfigure setting tool. Attempt to set dummy GL V in station 1 again. This attempt was successful. Hold safety meeting prior to PT'ing IA. Pressure test dummy GLV in station #1. 1512 psi at 22:28 pm. 1465 psi at 22:45 pm. Holding like a rock for the last 10 minutes. RIH with slickline to pull the prong from the TT plug. Recovered prong ok. RIH to recover TT plug. POOH, tag up at surface with TT plug. Recovered plug and all seals. Nothing left in hole. Rig down HES stickline lubricator and eq. Slip and cut drilling line. Safety meeting prior to stabbing coil and pumping slack management. Stab coil into injector. change packoffs. Pump slack management prior to cutting 2500' of coil. Cut 2500' of coil. Install SLB Kendel CTC. Pull test to 35k. Rehead with BHI upper quick connect. PT to 4k PIU BHi tools and 2.50' nozzle for cleanout. RIH to 7030'. Log tie in at GR marker -5' correction RIH 2.0/2.03400 11.8ECD tagged at 7815' with no progress. PU to 7800' RIH went to 7830'. PU clean to 7775'. RIH to 7854' pu clean RIH tagged at 7857' PU to 7850'. RIH 7870'. Work area to clean up fine snad over the shaker at bottoms up and small amount of gas. Still introducing new mud to the hole but as of now at 1.96 bpm 3360psi with the ECD at 11.9ppg annular at 3580psi Well is DECOMP DECOMP DECOMP DECOMP PRE PRE DECOMP DECOMP DECOMP DPRB DECOMP DPRB DECOMP DECOMP DECOMP DECOMP 22:50 - 23:30 0.67 PULL I: DECOMP 23:30 - 00:00 0.50 PULL DECOMP 10/6/2004 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 01 :15 0.75 PULL P DECOMP 01:15 - 03:15 2.00 CLEAN P WEXIT 03:15 - 03:35 0.33 CLEAN P WEXIT 03:35 - 05:15 1.67 CLEAN P WEXIT 05:15 - 07:30 2.25 CLEAN P WEXIT 07:30 - 10:30 3.00 DRILL P WEXIT 10:30 - 11 :00 0.50 DRILL P WEXIT 11 :00 - 12:30 1.50 DRILL P WEXIT 12:30 - 13:00 0.50 DRILL P WEXIT 13:00 - 14:30 1.50 DRILL P WEXIT 14:30 - 15:00 0.50 DRILL P WEXIT 15:00 - 16:50 1.83 DRILL P WEXIT Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Summary Re Page 19 of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 8/10/2004 8/28/2004 2 Spud Date: 6/10/1993 End: 8/28/2004 10/6/2004 15:00 - 16:50 1.83 DRILL P WEXIT drinking about .15bpm Shutdown pump and trapped 95psi on well. Stabilized annular 2911 psi and 9.86ECD reout (no circulation) 16:50 . 18:30 1.67 DRILL P WEXIT TOH following pressure schedule designed to maintain 3500psi at window. 18:30 - 19:30 1.00 CLEAN P WEXIT Trap 200 psi on WHP, close the SSSV. Check for flow. None. Tag up, lay down nozzle BHA. 19:30 - 20:00 0.50 WHIP P WEXIT Make up BHA #20. Baker 2.625" WS, Baker setting tool, BHI BHA. 20:00 - 22:10 2.17 WHIP P WEXIT RIH with BHA #20 to set whipstock. EDC open, RIH at 80 fpm, circulating at minimum rate. Following Dan Kara pressure schedule. Losing fluid to hole while following pressure schedule. We are basically getting 1 for 1 returns, with no extra for pipe displacement. Losing 3.8 bbls for every 1000' we run in the hole. 22: 1 0 . 22:35 0.42 WHIP P WEXIT Log tie in pass over GR spike at 7760' based on Cement Bond Log of 7-16-2004. Make -10' correction. 22:35 . 23:00 0.42 WHIP P WEXIT RIH position botton of WS at 7867', TOW at 7854'. Attempt to shut EDC. BHI had problems with the EDC. There is a new generation of EDC in hole. It only appears to close 67% of the way. BHI had to muck about in the diagnostics software for 10 minutes to get it shut completely. Pressure up on Baker setting tool. Got good indication of shear at 2670 psi. WS tool face for face of tray set at 0 deg. Set 3000 Ibs down on WS tray. It appears to be set. Depths for whipstock; TOWS=7854'. - Pinch Point=7857' RA tag=7861.35' BOWS=7867' 23:00 - 00:00 1.00 WHIP P WEXIT Attempt to open EDC to be able to pump while POOH. BHI couldn't get the EDC open. It would only open 67% of the way. BHI had to muck about in the diagnostics software again to finally get it open. Additionally, BHI reports power and corns are working, but rest of BHA is not working properly. Will need to change out for next run. POOH pumping 1 bpm to keep hole full. Follow pressure schedule while POH. 101712004 00:00 - 00:25 0.42 WHIP P WEXIT Continue POH with whipstock setting BHA. Trap 400 psi below SSSV. Close SSSV, continue to POH. 00:25 - 01 :00 0.58 WHIP P WEXIT Tag up at surface. Lay down WS setting BHA. Found that BHI EDC had been activated to disconnect and the lower section of the BHA left in the hole. In theory, this is not possible. lam not too impressed with the new generation of BHI EDC tool. 01 :00 - 04:00 3.00 FISH N HMAN WEXIT Call Baker TT for fishing equipment. Need a hydraulic GS, and a set of jars. They will prep and hotshot to rig ASAP. BHI has a model of the fishing neck, and gave to the BTT hand on location. The GS will match the model BHI has. The fish is 43.03' long, and should be setting on top of the whipstock. Top of fish at 7814'. 04:00 - 04:45 0.75 FISH N HMAN WEXIT Rig up fishing BHA. BHA #21 04:45 - 06:15 1.50 FISH N HMAN WEXIT RIH with BHA #21 to retrieve fish. 2.5" Hydraulic G Spear, 2.125" Bowen Bi directional oil jars, 1 joint of 2-1/16" CSH, BHI MWD tool. 06:15 - 06:40 0.42 FISH N HMAN WEXIT Log tie-in at 7760' .84/.831992 psi annular 3515psi 11.79 Printed: 11/16/2004 2:57:54 PM BP EXPLORATION perations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 20 of 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10/7/2004 WEXIT ECD 21 Opsi wellhead -8' correction. WEXIT RIH pumping at.9 bpm and tagged fish at 7812'. Seen pressure. Shutdown pump. P/U to 77790. RIH dry and tagged at 7812. 06:50 - 07:55 1.08 FISH N HMAN WEXIT pumping down backside maintaining scheduled BHP to SSSV. Close SSV and continue TOH. 07:55 - 08:30 0.58 FISH N HMAN I WEXIT Bleed trapped WH and monitor for flow. Pull BHA. Recovered entire fish. UD same and fishing tools. 08:30 - 09:10 0.67 STWHIP P WEXIT P/U window milling BHA 09:10 - 10:30 1.33 STWHIP P WEXIT RIH tagged pinch point. Correct depth and flag CT. 10:30 - 15:00 4.50 STWHIP P WEXIT milling window 1.65/1.643060psi 11.71 ecd 3528psi annular milled to 7859.5' Need to stop and change shaker screens blinding off with sand changed to 135 and 110 mesh. Continue on time milling 500psi MW good show of metal cuttings. Punch though at 7862.1'. 15:00 - 13:50 22.83 STWHIP P WEXIT Drill formation from 7862'.2 to 7867.2' 1 .55/1.58 3125psi 11.84 ECD 3576psi annular. Drilled only 5' to prevent possible interferance with other lateral below at 7874' 13:50 - 17:15 3.42 STWHIP P WEXIT Ream and backream window area 3 times. 1.54/1.57 2900psi 11.76 ECD 3550psi annular. Made dry run thru window - no problems. 17:15 - 18:40 1.42 STWHIP P WEXIT TOH following pressure schedule. 18:40 - 19:00 0.33 STWHIP P WEXIT Tag up at surface. Hold PJSM prior to making BHA swap. Check well for flow. No flow observed. 19:00 . 19:45 0.75 STWHIP P WEXIT Lay down BHA #22. window milling BHA. Mills recovered with good center wear on the D0261 showing a swirl pattern. The D0261 gauged 2.74 go/2.73 no go. The string mill gauged 2.74 go/2.73" no go. 19:45 . 20:30 0.75 DRILL P PROD1 PU BHA #23. Hycalog DS100 2.7x3.0· bicenter bit, 2.8 deg BHI X-tream mud motor, Full BHI MWD tool. 20:30 - 22:15 1.75 DRILL P PROD1 RIH with BHA #23 to drill build section. Open SSSV with 500 psi on the wellhead. Follow choke schedule while RIH, pumping thru an open EDC at minimum rate. 22:15 - 22:40 0.42 DRILL P PROD1 Log tie in pass at 7680'. Make -10' correction. 22:40 - 00:00 1.33 DRILL P PROD1 RIH thru window slick with pumps down. Shut EDC. Orient to o deg. Pit vol=300 bbls. IAP=470 psi, OAP=363 psi. Come on line with pumps. Free spin=3160 psi at 1.65 bpm. Drilling with choke open. 1.64/1.66/3230 psi. BHP=3612 psi. ECD=11.9 ppg. 10/8/2004 00:00 - 03:05 3.08 DRILL P PROD1 Continue drilling the build section of the well. 1.75/1.78/3460 psi. IAP=916 psi, OAP=581 psi. Pit vol=297 psi. TF=75R. ROP=25 fph. BHP=3670 psi. ECD=12.0 ppg. WHP=O. 03:05 - 03:30 0.42 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 22 klbs, and back in the hole. 03:30 - 05:55 2.42 DRILL P PROD1 Resume drilling. 1.67/1.72/3440 psi. Pit vol=314 bbls. (Mud aired up from centrifuge). ROP=75 fph. @ 8155' TF 50R BHP=3714 ECD=11.95 Drilled to 8165' need to trip for lower bend motor. 05:55 - 08:30 2.58 DRILL P PROD1 Pull above window. Open EDC. TOH following pressure schedule pumping at 2.4bpm flushing long tangent section. Change shaker screens to 175/175 Close SSSV. Tag up RIH 400' TOH flush annulus. 08:30 - 09:15 0.75 DRILL P PROD1 UD build assembly and P/U lateral BHA # 24 RR bit#11 Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 6/10/1993 End: 8/28/2004 8/10/2004 8/28/2004 2 1 0/8/2004 .75bpm to 1900' put 275psi on annulus and open SSSV. Noted 250psi beneath. RIH following pressure schedule. 11:15-13:00 1.75 DRILL P PROD1 from 7690' to 7904' 13:00 - 14:55 1.92 DRILL P PROD1 Directionally drill ahead f/8165' 1.47/1.51 3260psi Pit Vol= 312bbls BHP=3712 ECD=11.91 WHP=O 65fph 4-5k wob Drilled to 8310'. 14:55 - 15:20 0.42 DRILL P PROD1 Wiper trip to 7880'. 15:20 - 16:50 1.50 DRILL P PROD1 Directionally drill lateral f/ 8310' 1.59/1.72 9.48/9.453275psi 80-100fph Pit vol= 308 bbls BHP=3780 EDC=12.14 WHP=O !A=780 OA=530 Bleed down IA > 200psi OA > 200psi 16:50-18:15 1.42 DRILL P PROD1 Wiper trip to window. Open EDC sweep S" annulus. Clean back to bottom. 18:15 - 20:05 1.83 DRILL P PROD1 Resume drilling. IAP=340 psi, OAP=260 psi. Pit vol=302 bbls. Free spin=3350 psi at 1.69 bpm. Drilling at 1.68/1.863620 psi. BHP=3850 psi, ECD=12.33 ppg. In density=9.49 ppg, Out density=8.85 ppg. ??? Catch a sample from the possum belly and check with mud scale. Return mud weight using the mud engineers mud scale=8.7 ppg with the balance, and 9.5 with the presurized scale. No apparent gas in sample. No apparent gas breaking out of the mud in the possum belly. The mud appears a little "moussed up", kind of like it has in past jobs where we have had crosslinking due to high lubricant content. This, along with the drill solids, and higher bottom hole pressures means we will call for new mud. 20:05 - 22:10 2.08 DRILL P PROD1 Wiper trip to up inside production tubing. Clean PU off bottom. Open EDC above window. Pump at 2 bpm, 3950 psi, pull at 50%, and pump 15 bbls of high vis sweep to clean tubing. Pull up to 6000', then rub back thru window. Shut EDC, and run to bottom. Set down at 8114' when RIH. PU, and made it thru on 2nd attempt. - 23:20 1.17 DRILL P PROD1 Back on bottom. Still drilling with old mud. 9.49 ppg in, and 9.27 ppg out. The moussiness seems to be going away. On previous wells we were able to mousse up the mud by shearing the mud violently. We run the mud thru the choke when making a trip in and OOH, and this may be the reason for it. Drilling at 1.61/1.65/3550 psi. Pit vol=290 bbls. IAP=425 psi, OAP=350 psi. 23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. 10/9/2004 00:00 - 00:35 0.S8 DRILL P PROD1 Continue wiper trip back in hole. No problems at 8114' on this trip. 00:35 - 01:1 0 0.58 DRILL P PROD1 Resume drilling. Free spin with new mud=3360 psi at 1.63 bpm. Drilling at 1.62/1.64/3300 psi. ROP=150 fph. IAP=380 psi, OAP=320 psi. Annular pressure=3770 psi. ECD=12.1 ppg. New mud half way around. In density=9.47 ppg, out density=9.45 ppg. 01:10 - 02:40 1.50 DRILL P PROD1 New mud completely around. BHP=3690 psi. ECD=11.82 ppg. In density=9.48 ppg. Out density=9.53 ppg. The new mud seems to have cleaned up the mousse problem. 02:40 - 03:25 0.75 DRILL P PROD1 Wiper trip to window. Clean PU off bottom at 21 klbs. 03:25 - 03:55 0.50 DRILL P PROD1 Log tie in pass over RA tag in whipstock. Make +4' correction. 03:55 - 04:50 0.92 DRILL P PROD1 Continue back in hole on wiper trip. Set down at 8769'. Try it 3 Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operati mmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 1 0/9/2004 03:55 - 04:50 0.92 DRILL P PROD1 times with the at drilled toolface of 90L. No luck. This was a hard stringer (Ankerite?) when originally drilled. Orient to 45L, and got thru it. Probably a hard ledge. Continue to bottom clean. 04:50 - 06:00 1.17 DRILL P PROD1 Resume drilling. Free spin 2800 psi at 1.5 bpm. Drilling at 1.5/1.5/2890 psi. ROP=110 fph. IAP=230 psi, OAP=170 psi. Pit vol=463 bbls. BHP=3680 psi with 0 psi WHP. ECD=11.8 ppg. In density=9.47 ppg, Out density=9.53 ppg. Mud out looks normal - No Mousse. 06:00 - 08:35 2.58 DRILL P PROD1 Wiper trip to window open ECD continue to 6000'. No problems. Held "Parted Coil Drill". 08:35 - 11 :30 2.92 DRILL P PROD1 Directionally drill ahead f/ 9060' 1.58/1.68 3030psi BHP=3700 EDC=11.87 Drilled to 9214' 11 :30 - 13:30 2.00 I DRILL P PROD1 Wiper trip to window. RIH setdown at 9055' pick up then went trough. RI H wt at TD 1800# 20fpm Held "H2S Drill" 13:30 - 17:45 4.251 DRILL P PROD1 Directionally drill ahead f/ 9214' 1.58/1.60 FS=2950psi 2-300psi mw BHP=3730 ECD=11.9 pits=435bbls (aired up) IA=343 OA=250 ankorite drilling on bottom 15fph. Chert nodules in last few samples. Then at 1710hrs drilling break at 9313' 120'/hr 1.53/1.60 9.48/9.45 3000psi FS 2-300psi MW BHP=3740 ECD=12.03 pit vol 426 bbls Lost 80% returns at 9363'. BHP=3520 Drilled ahead regaining returns slowly at 9372' 1.54/1 .06 increasing to 1.12 at 9385'. BHP=3680 17:45 - 18:50 1.08 DRILL P PROD1 Wiper trip. Ratty PU off bottom up to 9300', then smoothed out. Pulling at 27 fpm, 1.54 in, 1.27 out. Returns have mostly healed up. Losing about 0.2 bbl/min. (12 bph) 18:50 - 19:50 1.00 DRILL P PROD1 Open the EDC at the window, and pull up hole pumping 2.2/1.94 bpm to 6000'. 19:50 - 20:20 0.50 DRILL P PROD1 Run back to window, and log tie in pass over the RA tag at 7862.5'. Make -15' correction. 20:20 - 21 :05 0.75 DRILL P PROD1 Continue wiper trip in back to bottom. 21:05 - 23:15 2.17 DRILL P PROD1 Resume drilling. IAP=600 psi, OAP=450 psi. Pit vol=380 bbls. Drilling 1.64/1.79/3500 psi. In density=9.5 ppg, Out density=9.1 ppg. It appears the mud is moussing up a bit again. ROP=120 fph. 23:15 - 00:00 0.75 DRILL P PROD1 Pit vol=373 bbls. Wiper trip to shoe. Clean PU off bottom at 21 klbs. BHP=3820 psi, 12.2 ppg. 10/10/2004 00:00 - 01:10 1.17 DRILL P PROD1 Continue wiper trip to window, and back to TD. No problems up to the window. Set down at 9072' while RBIH. (Ankerite stringer). Picked up, hit it a 2nd time, then bounced thru. 01:1 0 - 02:45 1.58 DRILL P PROD1 Free spin 3490 psi at 1.65 bpm. Resume drilling. 1.65/1.58/3550 psi. Pit vol=365 bbls. Lost 8 bbls of mud in last 2 hours. IAP=720 psi, OAP=530 psi. BHP=3820 psi. ECD=12.23 psi. Surface string weight=-7000 Ibs. Density in=9.48, Density out=9.52 psi. 02:45 - 05:00 2.25 DRILL P PROD1 9588', Hit an Ankerite stringer. Drilling at 10 fph. -70001bs ~ string wt at surface. 3500 Ibs downhole weight on bit. 150 psi Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10/10/2004 2.25 DRILL I P 0.33 DRILL P 02:45 . 05:00 05:00· 05:20 05:20 - 06:10 0.83 DRILL P I 06:10·08:20 08:20 - 09:30 09:30 - 09:45 09:45 - 11 :00 11:00·12:10 2.17 DRILL P 1.17 DRILL P 0.25 DRILL P 1.25 DRILL P 1.17 DRILL P 12:10 - 14:50 2.67 DRILL P 14:50·18:00 3.17 DRILL P 18:00 - 18:40 0.67 DRILL P 18:40 - 19:00 0.33 19:00 - 21 :00 2.00 21 :00 - 21 :35 21 :35 . 22:00 0.42 RUNCO 22:00 - 22:15 0.25 22:15 - 23:30 1.25 23:30 - 00:00 0.50 RUNCO 10/11/2004 00:00 - 01 :00 1.00 RUNCO 01 :00 - 02:30 1.50 RUNCO PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RUNCMP RUNCMP motor work. Just going to have to nibble our way thru it. Still beating our head against the wall. Drilling the same hard Ankerite stringer. Geo reports some pyrite in the samples, which won't help our ROP. Drilling at about 25 fph. Back in the good stuff! 1.68/1.67/3740 psi. Drilling at 140 fph. 350 bbls in the pits. IAP=522 psi, OAP=271 psi. BHP=3880 psi. ECD=12.43 ppg. Drilled to 9650' then back to the bad. Drill on to 9670'. Wiper trip to 6000' opened EDC above window. RIH to 7860' Log tie·in +2.5' Continue RIH Drilling ahead f/ 9670 3050psi FS 300psi MW 1.52/1.49 BHP=3800 ECD=12.20 holding at 120'/hr. Drilled to 9785' and hit another ankorite string. Town wants to call this TD. Wiper trip to window. RIH no problems. TOH. No problems off bottom. Following pressure schedule to SSSV. Close valve trapping 350psi. Pull to 200' then RIH to 1000'. TOH Tag up at surface, lay down BHA #24. Bit recovered in decent shape. DD Graded as 2,2 with 1 chipped cutter on the pilot section. Hold PJSM prior to running liner string #1 on "A" lateral leg. Discuss hazards of running liner, and mitigations to hazards. Make up BHA #25, "A" lateral liner string #1: Baker bullet botton nose-10' bent pup jt (1.8 deg)-O ring sub-37 joints of 2-318" predrilled liner at 8 holes/ft-Baker slim/shorty deployment sleeve. Liner string length=1171.01 '. RUNCMP Make up BHI tools to G spear, and attach to liner. BTT hand reports that the deployment sleeve profile has been modified to avoid the problems observed on 1 F pad that prevented releasing from the liner. RUNCMP DFAL RUNCMP DFAL RUNCMP RUNCMP RUNCMP RUNCMP MU injector, check the BHI tools. RIH with BHA #25. EDC is open. Pumping at minimum rate. Open SSSV, and follow choke pressure schedule while RIH. Bhi has a short in the BHA. The sort occured at 2500' while RIH. Pull back to surface to repair. Tag up, check for flow. Lay down BHI MWD tool. Found electrical short in BHI upper quick connect. Repair problem. Run back in hole with liner BHA. BHI tool working correctly. Continue RIH pumping at minimum rate thru an open EDC. Following choke pressure schedule while RIH. Weight check at window. Up weight=22 klbs. RIH thru the window. RIH weight= 7400 Ibs. Slick thru the window. Slick in open hole. Slight hang up at the A6 sand at 8125', then fell thru. Made it to 8556'. PU with ratty overpull at 30 klbs, tried to orient 90 deg right, and only got about 30 deg before the orienter locked up. RBIH, and made it past the first bad spot. Ratty running from 8556'. Try to orient to the left. Came all the away around to 315 deg. Set down at 8677'. PU at 29 klbs. RIH, and still hanging up. Orient around to the right 90 deg. Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Summary Page of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 02:55 - 04:25 1.50 RUNCO Set down at 8656'. PU to 8600', RIH with TF at 90R. Tagged up at 8645'. Orient to 0 deg. RIH and set down at set down at 8644'. PU, orient to 180 deg. RIH and made it thru bad spot. Continue in hole. Set down at 8819', PU and made it thru. Set down at 8935,9032, PU and set down 3 more times at 9030', PU and got thru. Made it to 9085'. PU, set down at 9147', 9169', Can't get thru, orient to 90L. Set down at 9159'. Orient to 120L, set down at 9163'. Orient to 60L, set down at 9138'. Orient to 90R, and made it to 9170'. Set downs at 9183',9203, 9193,9189', Orient to 270L. Set downs at 9220, 9215', 9216', Orient to 180 deg. 9215',9220, 9221', Orient to 0 deg. Set down at 9215',9221,9215,9221', Orient to 60R. 9218', then made it to 9243'. 9242', Orient to 120R. 9240',9267',9265', 9259'. Orient to 90R, 9264', 9282', 9282', 9283', 9273', 9271', Orient to 150R. 9276', 9269', 9273', 9272, Orient to 150L, 9268',9272', Orient to 90L, 9267', 9261 '. Orient to 60L, 9255', 9266', Heavy pickups at 36 klbs. 9252'. Orient to 0 deg. 9233', Orient to 60R, 9231', 9240', 9243', Orient to 120R, 9260',9269',9271'. Orient to 100R 9269', 9285', 9283', 9288', 9285', 9277. Stack 2000 Ibs on WOB, and try rotating orienter 360 deg to the left. DPRB RUNCMP Continue trying to work liner to bottom. Orient to 150R. 9299', 9298',9291,9284',9289',9282',9279', Orient to 150L. 9271', 9278',9275',9276', 9295, 9287'. Orient around to the right from 150R in 20 deg increments. 9286'. DPRB RUNCMP TF=150R. Try the Dave Duerr technique. Stack weight at 9282', shut EDC, and kick pumps on and pump 15 bbls. Trap 200 psi on WHP, open EDC. PU, RIH, made good hole, and tagged at 9343',9385',9383',9392',9389',9393',9402',9405'. Repeat the pump sequence. RIH easily to 9532', PU, 9561', 9561',9561. This seems to be working good. Repeat pump sequence. RIH making hole to 9653',9654', 9652', Repeat pump sequence. Made hole to 9718',9717,9714',9714'. Repeat pump sequence. RIH easily to TD at 9796'. PU tag again, this is it. (Tied in depth we drilled to was a TD of 9785') DPRB RUNCMP Close ECD. Bring pumps on to 1.95 bpm, 3950 psi. PU at 23 klbs, ratty. Last PU prior to tagging bottom was 26 klbs. RIH, set down at 9778'. Stack weight. Rate to 2 bpm, 4050 psi. PU at 24 klbs. DHWOB shows -1750 Ibs on pickup. Probably still have the liner. RIH to 9774'. 2.2 bpm at 4500 psi. PU at 26 klbs, DHWOB=-2600 Ibs. Still have liner. RIH, and set down at 9746'. DPRB RUNCMP Need to get liner back to bottom. Pump 15 bbls, down on the pumps, RIH. Made it to 9779',9780', then stopped. Repeat pump sequence. RIH to 9796'. Back on bottom again' DPRB RUNCMP One possibility is the GS is functioning properly, but the keyed portion is in a bind from the orienting we have been doing. Stack weight on BHA. DHWOB shows 6000 Ibs of compression in BHA. Bring up pumps to maximum rate, 2.2 bpm, 4750 psi. PU until DHWOB shows -1000 Ibs indicating the BHA is in tension. Rotate the orienter to remove the bind from the lower GS keyway profile. Cycle string weight trying to get released from GS. No luck. 02:30 - 02:55 0.42 RUNCO 04:25 - 04:35 0.17 RUNCO 04:35 - 04:55 0.33 RUNCO 04:55 - 05:10 Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Summary Report Page 25 of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10/11/2004 05: 10 - 05:25 DPRB RUNCMP Keep cycling the weight up and down, while turning the orienter, trying to get released. Cycle pump rate from 1.5 to 2.2 bpm. Watching DHWOB. Try cycling coil up and down as fast as possible to jerk the profile free. Keeping pump rate at 1.95 bpm. PU to 9763', DHWOB=-1700 Ibs, and we can't run back in. We still have the liner. Work the liner back down to bottom. 05:25 - 06:15 0.83 RUNCO DPRB RUNCMP Back on bottom at 9796' (Uncorrected). PU until the BHA is in tension. Rotate the orienter. Try to slack off and pick up to see if we can get free. Make a full 360 rotation in 20deg increments. 06:15 - 06:20 0.08 RUNCO DPRB RUNCMP Check pressures with EDC open and closed. Open EDC pump at 2.15 3800psi vs 4700psi with it closed. SD pump close surface choke trap 450psi. Close EDC. Open EDC coil wt at 20k(neutral wt.) crank up pump 2.4 at !4800PSi then setdown -12k then p/u hard on liner. Liner ,released. P/U wt steady 18-20k that's 10k less than all previous pick-ups. 06:20 - 06:50 0.50 RUNCMP TOH to 7850. 06:50 - 07: 1 0 0.33 RUNCMP Tie-in log -13' correction. Flag pipe at 7900'. 07:10 - 09:00 1.83 RUNCMP TOH following pressure schedule to above SSSV. Close SSSV trapping 300psi. TOH 09:00 - 09:15 0.25 RUNCMP UD BHI and BTT tools. 09:15 - 09:25 0.17 RUNCMP PJSM review Liner Running procedures and hazards, using Lift Subs for the straight bladed centrilizers. Review liner assembly. 09:25 - 11 :45 2.33 RUNCMP Change elevator. Start picking up Leg #2 of Lateral A's liner BHA #26 . MU Weatherford Aluminum billet and BHI tools. 11 :45 - 13:25 1.67 RUNCMP RIH open SSSV follow p sheduloe. Check wt at window 21k up. RIH wt 6k RIH setdown at 8581' plu 26k RIH stop at 8574' quick p/u RIH to 8625' uncorrected (bottom at 8614') p/u and repeat. Shutdown pump traop pressure and choke. Close EDC . Pump at 1.3bpm 4200psi p/u and release from liner PU wt 19k. 13:25 - 14:50 1.42 RUNCO RUNCMP TOH following presssure shedule. 14:50 - 15:05 0.25 RUNCO RUNCMP UD liner running tools. 15:05 - 16:25 1.33 STWHIP N SFAL PROD2 P/U BHA #27. Baker having tool problems. 16:25-18:15 1.83 STWHIP P PROD2 RIH open SSSV following RIH pressure schedule. 18:15 - 18:35 0.33 STWHIP P PROD2 Log tie in pass over RA tag in Whipstock. Make -16' correction. 18:35 - 19:30 0.92 STWHIP P PROD2 RIH, tag top of whipstock/Deployment sleeve at 7906'. PU, and begin time drilling at 3fph from 7905'. TF=135R. IAP=56 psi, OAP=59 psi. BHP=3630 psi. WHP=O psi. ECD=11.91 ppg. Pit vol=287 bbls. Free spin=3340 psi at 1.66 bpm. 19:30 - 20:30 1.00 STWHIP P PROD2 Begin time drilling at 6 fph. TF=135R. 20:30 - 21 :00 0.50 STWHIP P PROD2 Start controled drilling at 45 fph. No stalls. We appear to be off the whipstock. Drill ahead until MWD confirms we are not in the old wellbore. 21 :00 - 22:30 1.50 STWHIP P PROD2 Drilled to 7931', and confirmed that we are sidetracked from MWD data. PU and run back to bottom dry. Made it thru sidetrack at WS top with no problems. POH to pick up build section BHA. Follow pressure schedule and pump at full rate while POOH. 22:30 - 23:30 1.00 STWHIP P PROD2 Tag up at surface. Check well for flow. No flow observed. Printed: 11/16/2004 2:57:54 PM EXPLORA TION Summary Report 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10/11/2004 Change bit from STR324 to DS100 bicenter. Recovered bit graded 1, 1. Leave motor bend at 1.7 deg. 23:30 - 00:00 0.50 DRILL P PROD2 RIH with BHA #28. Hycalog bicenter bit. 1.7 deg motor. Full I MWD BHA. 10/12/2004 00:00 - 01:10 1.17 DRILL P PROD2 I Continue RIH with BHA #28 to drill L 1 build section. 01:1 0 - 01 :35 0.42 DRILL P PROD2 Log tie in pass over RA tag in window whipstock. Made -14' correction. 01:35 - 05:15 3.67 DRILL P PROD2 Begin drilling build section. Free spin 3130 @ 1.55 bpm. Pit vol=283 bbls. IAP=60 psi, OAP=45 psi. Mud density in/out=9.45/9.53. 05:15 - 05:30 0.25 DRILL P PROD2 Wiper trip to window. Clean. 05:30 - 06:00 0.50 DRILL P PROD2 Resume drilling build section. 06:00 - 07:55 1.92 DRILL P PROD2 Continue drilling build section. 3150psi FS 1-200psi mw @ ¡1.60bpm 1 OO'+/hr 9.47/9.50 BHP=3650 07:55 - 08:20 0.42 DRILL P PROD2 Wiper trip above window clean running in past AI. billet 08:20 - 09:15 0.92 DRILL P PROD2 Continue drilling build section. 3220psi FS 400psi mw @ 1.60bpm 1 OO'+/hr 9.47/9.40 BHP=3760 ECD: 12.0 Drill to 8377' 09:15 - 10:55 1.67 DRILL P PROD2 Wiper trip to 6000'. Clean to bottom. 10:55 - 11 :50 0.92 DRILL P PROD2 Directionally drill ahead f/8377' 9.52/9.48 3130psi FS at 1.6bpm BHP=3740 ECD=11.97 11 :50 - 12:40 0.83 DRILL P PROD2 Wiper trip to window. SD pumps pulling thru OH whipstock. Orient to 135 R, and pumps down when running back down thru it. No problems observed up or down thru whipstock. 12:40 - 13:05 0.42 DRILL P PROD2 Free spin 3126 psi at 1.54 bpm. Resume drilling in sand. Well is landed but town Geo wants to drill ahead with high dogleg motor to be ready for fault. Potential for high doglegs in initial part of lateral and subsequent reduction in lateral length discussed. Drilling with TF=90R. 1.53/1.57/3501 psi. BHP=3750 psi. ECD=12.02 ppg. InlOut density=9.5/9.48 ppg. IAP=270 psi, OAP=200 psi. Pit vol=278 bbls. 13:05 - 13:30 0.42 DRILL P PROD2 Geo wiper to let town look at logs. Pull up to the window and wait. 13:30 - 16:40 3.17 DRILL P PROD2 At the window. Wait on orders from town. 16:40 - 17:05 0.42 DRILL P PROD2 RIH to continue drilling lateral section with build section BHA. (Average dog leg 21 deg) 17:05 - 19:45 2.67 DRILL P PROD2 Resume drilling. Free spin 3200 psi at 1.59 bpm. Pit vol=262 bbls. IAP=290 psi, OAP=244 psi. INC=95 deg. Drilling ahead smoothly. 19:45 - 22:00 2.25 DRILL P PROD2 POOH to change motor angle and check bit. Close SSSV with 500 psi WHP. PJSM in Ops Cab before getting to surface. 22:00 - 23:30 1.50 DRILL P PROD2 At surface. Get off well. Unstab coil. Hycalog bit in good condition (1-1). Change out motor. AKO adjusted to 1.1 degrees. Stab coil. Get on well 23:30 - 00:00 0.50 DRILL P PROD2 Run in hole. Open SSSV with 500 psi on well head. Continue to RIH as per pressure schedule 10/13/2004 00:00 - 02:00 2.00 DRILL P PROD2 Continue to RIH as per WHP pressure schedule. Some tight spots near TD. Back ream same. 02:00 - 02:30 0.50 DRILL P PROD2 Begin getting gas in rtns. Divert one btms up to tiger tank. Monitor tank. 02:30 - 05:00 2.50 DRILL P PROD2 Drill ahead. 3700 psi at 1.71 bpm fs. 200-300 dpsi. Rtns:1 :1. TF:270 deg. Inc: 96 deg. BHP: 3827 psi. ECD:12.3 ppg WHP:50 psi. Begin displacing to new mud. ROP variable. Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operati Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10/13/2004 05:00 - 06:15 1.25 DRILL P PROD2 Wiper trip to window. 06: 15 - 09:25 3.17 DRILL P PROD2 Resume drilling. Free spin 3157 psi at 1.54 bpm. Holding 130 psi WHP. BHP=3837 psi. ECD=12.38 ppg. Drilling at 1.54/1.58/3300 psi. In/Out Density=9.43/8.81 ppg. IAP=60 psi, OAP=50 psi. 07:30 - 09:25 1.92 DRILL P PROD2 Long wiper to 6000'. Clean PU off bottom. Getting crude and gas back in returns. Taking returns outside to the tiger tank. Will do a BHP check after the wiper to determine new BHA. 09:25 - 10:05 0.67 DRILL P PROD2 Stop at window. Trap 400 psi, and SI choke and pumps. 09:30 BHP=3625 psi WHP=605 psi ECD=12.15 ppg. 09:45 BHP=3812 psi WHP=894 psi ECD",12.63 ppg. 10:00 BHP=3813 psi WHP=941 psi ECD=12.63 ppg. 10:05 - 10:45 0.67 DRILL P PROD2 Kick on pumps and circulate bottoms up to clean up wellbore. 10:45-11:00 I Holding 3950 psi BHP. 0.25 DRILL P PROD2 Getting considerable gas to surface and hose to tiger tank is I jumping. Shut down pumping and secure well. Gather up the troops, and hold safety meeting to discuss well kill. 11 :00 - 14:20 3.33 DRILL P PROD2 Circulate out kick. Taking returns to tiger tank. Call for 10 ppg mud from MI. Call for Kuparuk vac truck to shuttle used mud from tiger tank to pits. 14:20 - 15:15 0.92 DRILL P PROD2 RIH to circulate bottoms up from TD. Tagging up at A6 sand at 8050'. Had to drop rate to get thru. Tagged up in A3 shale at 8767' and couldn't get thru. 15:15-16:00 0.75 DRILL P PROD2 Ream shales near 8760'. Holding drilled tool face. Getting packed off around BHA, and pit volume",150 bbls. Take a bite, and chase it up to the window so we can do another mud swap from the tiger tank. 16:00 - 16:45 0.75 DRILL P PROD2 SI pumps at the window trapping 900 psi. Transfer fluid from tiger tank to the rig via AES vac truck. 16:45 - 18:00 1.25 DRILL P PROD2 Ream to btm. Several tight spots. but able to get through by varying pump rate. No overpulls, just several set downs while RIH. Some packing off. 18:00 . 19:00 1.00 DRILL P PROD2 Ream out of hole at 25 fpm. Hole looks a lot better, at least no overpulls. Taking rtns to Tiger. 1:1 according to 30 minute strap. 19:00 - 21 :30 2.50 DRILL N WAIT PROD2 Pull into liner above window. Hold 3950-4000 psi on formation while circulating at min rate, waiting on rest of 10.0 ppg mud. 21 :30 - 23:30 2.00 DRILL P PROD2 Line up vac trucks. Displace well to 10.0 ppg flopro while RIH. Tag up at several spots from 8050 to 8150. Appear to be packing off. Reduce pump rate to 1.04 bpm @ 2580 psi. 1:1 rtns. Smooth from 8100 to 8825. WHP: 400 psi. ECD: 12.7 to 13.0. BHP: 3990 psi. Set down at 8826, 8860. Reduce circ rate to 0.4 bpm. Continue in hole. Increase rate to 1.55 bpm I 3700 psi fs. Lots of gas with old mud gettting to surface. Divert outside. Continue to circulate off btm to get new mud around. Continues to try and pack off when RIH near 9025. 23:30 - 00:00 0.50 DRILL P PROD2 Back ream hole to try and clean up shale intervals, to clean up pack off problem. Increase BHP to 4250 psi, 13.7 ppg ECD. Back ream to 8500. Run back in hole. 1.66 bpm @ 4000 psi fs. WHP: 285 psi. Having trouble getting past 8679. Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Su Report 1.50 DRILL P 1.25 DRILL P 0.75 DRILL P 1.00 DRILL P 0.50 DRILL P 1.50 DRILL N I 0.251 DRILL N 2.42 DRILL N 3.50 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 RREP PROD2 RREP PROD2 RREP PROD2 10:40 - 10:45 0.08 DRILL N RREP PROD2 10:45 -11:25 0.67 DRILL N RREP PROD2 11 :25 - 11 :50 0.42 DRILL N RREP PROD2 11 :50 - 12:50 1.00 DRILL N RREP PROD2 1Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 12:50 - 13:00 0.17 DRILL P PROD2 13:00 - 15:20 2.33 DRILL P PROD2 15:20 - 17:30 2.17 DRILL P PROD2 PROD2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 01 :30 - 03:00 03:00 - 04:15 04:15 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08: 15 08:15 -10:40 17:30-21:00 Drill ahead. 1.55 bpm @ 3900 fs. 200-400 dpsi. 1:1 Rtns. Very soft formation, high ROP. WHP: 350 psi. BHP: 4300 psi. ECD: 13.7-9 ppg. Some gas in rtns. Able to take rtns to pits most of the time. Climbing at 93.7 deg to get into upper target lobe. PVT: 355 bbls. Wiper trip to top of first liner. Motor work at 8650 on up pass. Several rough spots from 8600 to 8900 on trip back in. Only one set down, hole seems to be improving. Maintained 1.49 bpm, ran at 35 fpm. Drill ahead. 1.49 bpm @ 3650 fs. 200-400 dpsi. 1:1 Rtns. Very soft formation, high ROP. WHP: 311 psi. BHP: 4223 psi. ECD: 13.6-7 ppg. PVT: 335. Some gas in rtns. Able to take rtns to pits most of the time. Reduce angle to 91 deg in upper target lobe. Wiper trip to window. Log GR tie in. Make +3' correction, RIH. Drilling ahead at 180 fph. Free spin 3550 psi at 1.5 bpm. Drilling at 1.5/?/3690 psi. Taking returns to the tiger tank. IAP=60 psi, OAP=45 psi. Pit vol=239 bbls. WHP=400 psi, BHP=4230 psi. Driller found large blister on choke side rubber 3" flex hose. Need to repair ASAP. Pull up to the tubing tail to make repairs. Wiper trip up thru shaley interval mostly clean execpt for overpulls and motor work at 8650'. Safety meeting prior to starting rig repairs. Hazards, and mitigations to hazards discussed. Shut lower 2" combi rams. Blow down stack. Shut choke side HCR and manual valve. 3 barriers to flow. Change out flex hose on choke side of BOP. Pressure test hose with test pump against a blocked HCR valve. PT to 3800 psi. Held pressure fine. Pull up hole to inspect pipe where combi rams were shut to ensure that it is in good shape. RBIH, holding 14.4 ppg ECD. Log tie in pass over RA tag. Make -6' correction. RBIH to resume drilling. Pumping 1.0 bpm, holding 750 psi on the well. BHP=4400 psi. Returns are comeing inside, and are free of gas and crude. A few weight bobbles at 8700'. Had to work it to get past 9300'. Resume drilling. Keeping returns inside. Pit volume=337 bbls. IAP=60 psi, OAP=21 psi. Free spin =3880 psi at 1.63 bpm, and 420 psi. Drilling at 1.65/1.65/3930 psi. Getting gas back. Take returns outside. Continue drilling ahead. Wiper trip to the shoe. Clean PU off bottom at 24 klbs. Some small overpulls and motor work from 8700'-8600', but better than it has been previously on the way up. Relatively clean back to bottom. Minor motor work and no set downs going back thru shale from 8500'-8900'. Had to work it down from 9300'. Drill ahead. 1.65 bpm @ 4000 psi fs. 200-400 dpsi. 1:1 rtns. WHP: 510 psi, ECD: 14.14 ppg, BHP: 4360 psi. Soft formation, ROP variable. Hold 93 incl. Rtns to tiger tank due Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Page 29 of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 22:30 - 00:00 1.50 DRILL P 10/15/2004 00:00 - 03:00 3.00 DRILL P 03:00 - 03:45 0.75 DRILL P 03:45 - 04:00 0.251 RUNCO 04:00 - 06:00 2.00 I RUNCO 06:00 - 06:15 0.25 RUNCO 06:15-06:30 I 0.251 RUNCO 06:30 - 08:00 1.50 RUNCO 08:00 - 08:40 0.671 RUNCO I I 08:40 - 10:45 2.08 RUNCO I PROD2 PROD2 PROD2 RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP DPRB RUNCMP 10:45 - 12:25 1.67 RUNCO DPRB RUNCMP 12:25 - 12:50 0.42 RUNCO DPRB RUNCMP 12:50 - 13:05 0.25 RUNCO DPRB RUNCMP 13:05 - 14:00 0.92 RUNCO DPRB RUNCMP 14:00 - 14:45 0.75 RUNCO DPRB RUNCMP 14:45 - 16:30 1.75 RUNCO DPRB RUNCMP 16:30 - 16:45 0.25 RUNCO DPRB RUNCMP to gas. PVT: 121 bbls. Load pits with new 10.5 ppg flopro. Wiper trip to window to tie in. Prep to lay in new mud. Rtns going outside to tiger. GR tie in correction: add 2.5'. Official TD is 9678'. Run in hole, wiper to TD. A few sets downs: 9361, 9390, 9535. Verify TD. POOH laying in new mud. POOH for final wiper pass. Lay in new mud. Close SSSV with 900 psi on well. COntinue out of hole. At surface. Get off well. Unstab coil. LD drilling BHA. Hold PJSM with crew to discuss liner running procedure. MU 60 jts 2-3/8" pre-drilled liner with round nose guide shoe, o-ring sub, and shorty GS deployment sleeve. Safety meeting re running liner. Hazards of tagging SSSV are discussed and mitigations to hazards reviewed. Make up remaining liner. Make up BHI BHA. Confirm that the tool works electrically. Make up injector. Pressure up WHP to 1000 psi. Open SSSV. Kick on pumps to minimum rate. RIH with BHA #30 holding pressure schedule. Swabbing mud away, only getting a trickle of returns. Stop at the window. Make a -14' correction (Average of last runs). Check weight up = 22500 Ibs. RIH weight at the window=7000 Ibs. BHI WOB=-5000 Ibs. RIH slick past OH whipstok on top of "A" lateral. Slick to 8710', set down. PU at 28k Ibs and sticky. Work pipe down slowly. RIH weight=4500 Ibs, WOB=-1000 Ibs. Stack weight, and can't get thru. Stack +8000 Ibs down hole. Try the Dave Duerr pump technique. Shut the EDC, bring the pumps on to 1.5 bpm, and pump 15 bbls. Open EDC. Work pipe. No luck. Still can't get past 8710'. Tag up solid each time we set down. Work pipe repeatedly. Hit it from 10 to 100 fpm, and set down at the same place. Stack weight and watch it for 10 minutes, no movement. PU to 8650'. RIH slow while we shut the EDC and bring pumps on. No luck. Can't get past 8710'. The log shows a small sand at this depth in the midst of the 500' shale we drilled. May be a ledge here due to gauge hole in the sand with washed out shale on each side. Hole Inc is 95 deg, so this doesn't help any. PU 100' and RIH to hit it as hard as possible. RIH at 150 fpm. Still can't get thru it. Need to make cleanout run. Call town while we POH. Last PU off of tight spot =26000 Ibs. WOB=-7000 Ibs. We still have the liner. PUH clean in OH, and thru window. Follow pressure schedule on way OOH. Tag up at surface. Shut SSSV. Hold no-flow check and safety meeting to discuss standing back liner. Lay down BHI BHA (#30). Stand back 2-3/8" predrilled liner in derrick. Inspected bottom nose, and did not find any plugging in guide shoe. It was a clean as it could be. Make up BHA #31. Hycalog DS 1 00 bi center bit. 1.1 deg motor. Full BHI MWD eq. RIH with BHA #31 to cleanout well. Log tie in pass over RA tag. Make -16' correction. Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 10/15/2004 16:45 - 19:00 2.25 ì 19:00 - 19:45 0.75 RUNCO~ I I 19:45 - 20:45 1.00 RUNCOt 20:45 - 22: 15 1.50 RUNCOIlfN I 22:15 - 23:00 0.75 RUNCOf 23:00 - 00:00 1.00 RUNcot 10/16/2004 00:00 - 02:30 2.50 RUNCO ì I I I I I 02:30 - 03:30 1.00 RUNCO 03:30 - 04:00 04:00 - 05:30 05:30 - 06:00 0.50 06:00 - 07:00 1.00 07:00 - 08:30 34 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 DPRB RUNCMP RIH to clean out shale from 8500-8900'. Slick down thru build section. Set TF to as drilled TF of 90L, ran down and set down at 8707'. PU at 19 klbs, slightly ratty. Repeat set down several times. Orient to high side and RIH, set down at 8704'. Able to get to 9500' with pump rate at 0.59 bpm. Back ream hole from 8950 to 8500 at 10 fpm. 1.5 bpm @ 3900 psi fs. BHP: 4400 psi, ECD: 14.38 ppg, WHP: 510 psi. 1:1 rtns, PVT: 210 bbls. Ream in hole at 25 fpm. 1.55 bpm @ 3820 fs. A few set downs, hole mostly smooth. High EDC probably holding back formation. Ream to 9550'. Ream OOH from 9550' at 25 fpm. 1.55 bpm @ 3800 psi fs. Some mtr work, mostly smooth. 1.55 in/1.36 bpm out. BHP: 4550 psi, ECD: 14.3 - 14.6 ppg. Ream to 8500. TF: 90R. Ream to 8500. DPRB RUNCMP Ream in hole at 25 fpm. 1.55 bpm @ 3820 fs. A few set downs, hole mostly smooth. Problem spots: 8670, 8730. High EDC probably holding back formation. Ream to 9550'. DPRB RUNCMP Ream OOH at 10 fpm. 1.55 bpm @ 3850 psi. BHP: 4600 psi. ECD: 14.5 ppg. WHP:450 psi. DPRB RUNCMP Continue to back ream hole while circulating new 10.5 ppg flo pro. 1.55 bpm @ 3850 psi fs. 1:1 rtns. BHP: 4600 ps.i ECD: 14.4 ppg. WHP: 475 psi. 30 fpm coil speed. Overpulls from 8750 to 8650. Ream down and back again at 1.45 bpm, 10 fpm. Got stuck at 8680'. Pull 45k. Unable to go down. Able to circ at full rate. SHut dn pumps. Relax hole. Came free down. Continue to ream out of hole at 1.5 bpm 3550 psi fs, 27 fpm. BHP: 4500 psi. ECD: 14.3 ppg. WHP: 550 psi. DPRB RUNCMP POOH following WHP pressure schedule. Paint EOP flag at 5800'. CLose SSSV with 1220 psi on well. POOH to surface. I Flow check. Get off well. Unstab coil. DPRB RUNCMP RU to run liner. Hold PJSM to discuss runnign liner. Verify safety joint is ready to go. Swap solid btm joint for 10' bent pup wI bull nose. DPRB RUNCMP Swap solid btm joint for 10' bent pup w/ bull nose. Run 30 stands from derrick. Remove extra spiral turbos used as lift nubbins. DPRB RUNCMP MU Baker mwd tools wI orienter. DPRB RUNCMP RIH with liner BHA #32 at 80 fpm. Pumping at minimum rate down the coil thru and open EDC. Holding to pressure schedule while RIH. Initial WHP=1000 psi with no returns. Surging fluid away. Tie in at 5800' EOP flag. Make -17' correction. DPRB RUNCMP Weight check at window = 23000 Ibs. DHWOB=-5500 Ibs (In tension). RIH weight at window=5600 Ibs, DHWOB=-3000 Ibs. Non calibrated TF=105L. RIH slick thru window at 40 fpm. Set down at 7895', PU and orient 60 deg R. RIH and set down at 7900. PU, try to rotate 60 deg R, and BHA is in a bind and can't rotate. Kick pumps on down the coil. RIH pumping, and holding 1000 psi on WHP. Set down. Finally got the orienter to turn the liner. Holding 60R. Set down at 7899'. Kick on pumps down the backside, PU and pump 2 bpm down the backside at 2130 psi. RIH with TF at 120R set down at 7898'. DPRB RUNCMP IDPRB RUNCMP I I DPRB RUNCMP Printed: 11/16/2004 2:57:54 PM BP EXPLORATION Operations Summ Page 31 of 34 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/1 0/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 08:30 - 10:15 1.75 RUNCO Orient to 180 deg. RIH slow and set down. Orient all the way around in 20 degree steps, continuing to bullhead at 2 bbl/min to wash thru. No success, and BHA seems to be in a bind in the lower left quad rent. Can't really orient to hold tool face in this quadrant. Having consistent setdowns at 7898'. Orient to 30-60R, and RIH at 120 fpm while continuing to pump at 2 bpm down the backside. Tagged up at the same depth. Clean PU's. Repeat 10 times with no luck. Set down, swap to pumping down the coil. Pump 15 bbls thru a closed EDC. 1650 Ibs of compression in BHA. Try to RIH. Set down at same place. Try orienting on bottom to get thru, no luck. DPRB RUNCMP No luck getting past 7898'. This is a spot with 45 deg dog legs in the original well bore. It is 8' above the top of the whipstock/deployment sleeve for the "A" lateral liner. It could be debris stacking up at this point in the well, or our depth uncertainty could put us at the top of the aluminum billett, POOH and consult with town. Looked for flag on way OOH, but it is gone. Continue POOH. Safety meeting prior to running 1" CS hydril inner work string. Stand back injector. Lay down BHA #32, liner attempt #2 on L 1 lateral. Pickup and run a 1" CS hydril inner work string in the 2-3/8" predrilled liner. Space out so slick stick is thru Oring sub. Make injector back up. Check MWD tools electrically. RIH with liner for third attempt at getting liner down the L 1 lateral. BHA #33. RIH at 70 fpm. No flag on coil. Make the same -17 correction as last RIH. Weight check at the window, Up string weight = 26 klbs, WOB=-10300 Ibs. RIH at 40 fpm. Set down at same depth as last time, 7898'. Close EDC. Kick on pumps. String weight=4800 Ibs, DHWOB=6600 Ibs compresson. Pumps to 0.8 bpm, 3400 psi pump pressure. Pumps to 1.0 bpm, 4240 psi. Trying to wash thru it if it is debris/cuttings. Try rotating the orienter 90 deg right. Cycle weight from max tension to neutral weight. Can't PU due to GS releasing. Pumps to 1.1 bpm, 4370 psi. Bullheading fluid away. Try spinning the orienter on bottom. It turns, but no luck making any hole. Circulate 15 minutes with no headway. SI pumps, Open EDC. PU and orient around trying to set down around the clock with the orienter. Solid set downs with no indication of making any headway. Time to call town and make a plan forward. POOH. Tag up at surface. Hold safety meeting while checking well for flow. Stand back injector, begin tripping CS hydril inner work string OOH. Stand back 2-3/8" STL liner assy. No unusual marks on the shoe joint or guide shoe. MU 1.7 deg mtr with HTC 328 bit on full MWD. Stab coil. Get well. Test mwd. RIH. Get rtns at 1500. Close choke and pressure WH to 950 psi. Open sssv. Continue in hole. Maintain BHP using pressure schedule. Log gr tie in from 7880. Subtract 5.5'. 10:15 - 10:30 0.25 RUNCO DPRB RUNCMP 10:30 - 10:45 0.25 RUNCO DPRB RUNCMP 10:45 - 13:45 3.00 RUNCO DPRB RUNCMP 13:45 - 15:15 1.~0 RUNCO DPRB RUNCMP 15:15 - 15:55 0.67 RUNCO DPRB RUNCMP 15:55 - 17:20 1.42 RUNCO DPRB RUNCMP 17:20 - 17:35 0.25 RUNCO DPRB RUNCMP 17:35 - 19:30 1.92 RUNCO DPRB RUNCMP 19:30 - 21 :15 1.75 RUNCO DPRB RUNCMP 21:15 - 21 :50 0.58 RUNCO DPRB RUNCMP 21 :50 - 23:30 1.67 RUNCO DPRB RUNCMP 23:30 - 23:40 0.17 RUNCO DPRB RUNCMP Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y -24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 32 of 34 EXPLORATION ions Summary Spud Date: 6/10/1993 End: 8/28/2004 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 ~~:;t, Hwlth ~i~;~;tto t 35, Tag"p at 7904' (~"ffi d'p~) PU I I and circ at min rate. Tag again. Pump at 1.35 w/ 3650 psi fs. I Slowly mill ahead with TF: 135. Slight amount of mtr work. ,WHP: 800 psi BHP: 4450 psi ECD: 14.6 ppg. Mill to 7904.3'. ! PU and RIH. Take wt. PU. Mill ahead 0.2'. PU. RIH fast, no ¡ mtr work or wt, then set dn 7910'. Take wt and mtr work. PU. I' RIH fast at min rate. Tag again at 7911'. Punched through at 7914'. Appear to be back in "correct hole". DPRB RUNCMP RIH with HS tf, roll to 135r. Tag up at 7904' (billet depth). PU II and circ at min rate. Tag again. Pump at 1.35 w/3650 psi fs. Slowly mill ahead with TF: 135. Slight amount of mtr work. IWHP: 800 psi BHP: 4450 psi ECD: 14.6 ppg. Mill to 7904.3'. I PU and RIH. Take wt. PU. Mill ahead 0.2'. PU. RIH fast, no mtr work or wt, then set dn at 7910' . Take wt and mtr work. i PU. RIH fast at min rate. Tag again at 7911'. Punched ¡through at 7914'. Appear to be back in "correct hole". RUNCMP Make several reaming passes past billet. Back ream up at 315 I deg tool face to try and dress billet. RUNCMP RIH to clean out to 9500. 3700 psi fs @ 1.37 in/out. WHP: i 400 psi ECD: 14.3 ppg BHP: 4400 psi. Hole very smooth I going in. Some bobbles from 9300 to 9500. RUNCMP Ream OOH at 25 fpm. A few overpulls from 8600 to 8550. Otherwise very smooth. Clean out with 2.75 bit is much I smoother than with bi-center. A lesson learned? Not sure what's going on here. Back ream past billet. Run back through dry. Smooth. DPRB RUNCMP POOH to make up dummy liner assy. Hold pressure as per schedule. DPRB RUNCMP At surface. Get off well. Unstab coil. LD Baker motor. MU dummy liner asembly (MWD, 2 solid jts 2-3/8" STL, 1.1 deg I mtr, HTC bit) DPRB RUNCMP RIH with BHA #35, to make dummy drift. BHA: STR-324 PDC bit - 1.1 deg WF motor - x/o - 2 jts of solid 2-3/8" STL liner - BHI MWD tool. Following pressure schedule. DPRB RUNCMP Log tie in pass over GR charecter at 7760'. Make -13' correction. DPRB RUNCMP RIH dry, at 30 fpm, with TF at 135R, the "as drilled" TF for the L 1 lateral. Slick thru window. Kick on pumps to 1 bpm, 3080 psi (Same rate we will be able to achieve with liner and an inner work string.). Continue RIH. Rotating orienter to match "as drilled" toolface as we RIH. Set down at 8069'. Had motor work. PU, ease on back down slowly. DPRB RUNCMP Work interval at 8069'. Finally got thru it. Continue to bottom holding as drilled tool face the entire way. Holding 4300 Ibs BHP. Set down at 8685'. PU, made it thru on 2nd attempt. Clean rest of the way to TD. DPRB RUNCMP Bring pump rate up to 1.5 bpm, to provide best hole cleaning. PUH holding 4300 psi on annular BHP gauge. PU off bottom at 19 klbs. Pulling at 30 fpm. Slick up hole thru open hole interval. DPRB RUNCMP POOH following pressure schedule. DPRB RUNCMP Tag up at surface. No flow test. Stand back injector and lay down BHA. 10/16/2004 10/17/2004 100:00 - 01 :00 1.00 RUNCO 01 :00 - 01 :30 0.50 RUNCO DPRB 01 :30 - 02:30 1.00 RUNCO DPRB 02:30 - 03:30 1.00 RUNCO DPRB 03:30 - 05:00 1.50 RUNCO 05:00 - 06:30 1.50 RUNCO 06:30 - 07:50 1.33 RUNCO 07:50 - 08:10 0.33 RUNCO 08:10 - 08:25 0.25 RUNCO 08:25 - 09:20 0.92 RUNCO 09:20 - 10:20 1.00 RUNCO 10:20 - 11 :45 11 :45 - 12:15 1.42 RUNCO 0.50 RUNCO Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1Y-24 1Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 6/10/1993 End: 8/28/2004 8/1 0/2004 8/28/2004 2 Note· Made a crude scribe when running liner. Pointed motor bend away from drawworks, tried to keep liner straight when running it, and scribed MWD to a point facing away from the drawworks. It is crude, but the best we can do. DPRB RUNCMP RIH with liner BHA. (BHA #36). Follow pressure schedule. Mostly surging fluid away. DPRB RUNCMP Orient TF to HS to pass through window 7855. Orient to 135 to pass billet at 7906. Orient back to HS to continue in hole. 30 fpm, no pumps. Set dn at 8710. Work through. Several more set dns. PU and run through ok. Work to 9104. Lots of set dns. Close EDC to drill ahead. DPRB RUNCMP Shut dn pumps. PU liner. Free at 27k# up wt. Orient to HS. RIH. PU and tag hard several times at 9350. Set max dn wt. Bleed WHP from 1000 to 100 psi. Make 10-15 ft. Repeat WHP pressure cycle process until reaching liner TD of 9500'. Clrc at 1.05 bpm @ 4000 psi with zero WHP. PU and release from liner no problem. POOH as per pressure schedule. CLose SSSV with 1200 psi on well. POOH to surface. At surface. Get off well. Unstab coil. LD Inteq mwd tools. Stand back 1" CSH in derrick. Continue to stand back CSH in derrrick. MU nozzle assembly. Stab coil. Get on well. RIH to 7500. POOH displacing tbg to seawater. Take rtns to tiger. Stop at sssv. FP tbg with diesel to surface. Safety meeting to discuss fluid pumping order for remainder of rig down Pump diesel and FP well from 2000' to surface. Safety meeting prior to pumping N2 to blow down coil. Blow down reel with N2, taking returns to the tiger tank. Driller blew lines to pits clear with last bit of N2 from blowdown. Personnel H2S detectors for several individuals went off. All personnel evacuated to the rig camp. Highest reading recorded was 60 ppm. No rig H2S alarms went off, and they were checked and calibrated yesterday. No personnel H2S alarms went off other than the new Rattler style. There were still several old style personnel H2S monitors in service, and individuals in the area with the old style alarms did not get an alarm activation. Call BP safety, and discuss the situation. Call CPAI pad operator for assistance. A 2 man team consisting of the pad operator and BP company man sniffed the rig. They were equiped with 2, 4 gas monitors. No H2S, Carbon Monoxide, or Methane gasses were detected. Oxygen levels were good throughout the rig, including below deck level in the pits. After the entire rig was sniffed, a post incident safety meeting was held with the rig crew to discuss the 10/17/2004 16:30 - 18:00 1.50 RUNCO 18:00 - 20:00 2.00 RUNCO 20:00 - 22:00 2.00 RUNCO 22:00 - 23:45 1.75 RUNCO RUNCMP 23:45 . 00:00 0.25 RUNCMP 10/18/2004 00:00 - 02:30 2.50 RUNCO RUNCMP 02:30 - 03:00 0.50 RUNCO RUNCMP 03:00 - 04:00 1.00 RUNCO RUNCMP - 06:00 2.00 RUNCO RUNCMP 06:00 - 06:15 0.25 RIGD P POST 06:15 - 07:15 1.00 RIGD P POST 07:15 - 07:50 0.58 RIGD P POST 07:50 - 09:00 1.17 RIGD P POST 09:00 - 10:20 1.33 RIGD P POST meeting prior to making up liner BHA. Make up liner for L 1 lateral for the 4th time. MU STR-324 2.73" OD bicenter bit - WF mud motor at 1.1 degrees - X/O - 7' spaceout pup - 0 ring sub - 59 jts of predrilled liner. Running 1" CSH inner work string and space out. Make up deployment sleeve and BHI MWD tools. Printed: 11/16/2004 2:57:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Y-24 1 Y-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/10/2004 Rig Release: 8/28/2004 Rig Number: 2 Spud Date: 6/10/1993 End: 8/28/2004 10:20 - 13:00 2.67 RIGD P 13:00 - 16:00 3.00 RIGD P 16:00 - 18:00 2.00 RIGD P Note - The suspected cause of the false alarms is sensitivity of the new rattler H2S personnel monitors to a mixture of N2 gas and methanol vapor. Methanol was used to flush the coil ahead of the N2. Further investigation should be done to avoid this situation in the future. POST Resume rigging down. Clean pits. Unstab injector. POST Drop reel down from reel house. Nipple down BOP stack, and NU tree cap. PT tree cap to 3500 psi. POST Continue prepping for move to 1 D pad. Rlease rig at 1800 hrs on 10-18-2004 Printed: 11/16/2004 2:57:54 PM . ConocoPhillips Alaska, Inc" . KRU 1Y-24A j'\!",.24~ .T>¡ ;T;¡T;;' .. ¡....¡..;...;;.......... ;> >;> >..> ;;;.;. ...; ;> ..; "»"';F API: 500292237101 Well TVDe: PROD Anale (d) TS: dea (d) TUBING SSSV Type: TRDP Orig 8/28/2004 Angle @ TD: deg @ 9785 (0-7180, Completion: OD:3.500, ID:2.992) l Annular Fluid: Last w/o: 10/18/2004 Rev Reason: CTD SIDETRACK LEG A Reference Loa: Ref Loa Date: Last UPdate: 10/22/2004 Last Taa: TD: 9785 ftKB Last Tag Date: Max Hole o deg @ Anale: (i¡ulñã,.smooii;'(i¡iJMMØN'siJiRIISISs ..> ;....;; ii.';;.>;;.... ..> Description Size TOD Bottom TVD Wt Grade Thread SURFACE 9.625 0 4599 4599 36.00 J-55 PRODUCTION 7.000 0 7568 7568 26.00 L-80 CONDUCTOR 16.000 0 121 121 62.50 H-40 SURFACE 9.625 0 3041 3041 47.00 L-80 WINDOW 6.156 7858 7868 7868 0.00 c;U1nâ.'Si"ñå::;..lÄINI!R·'·~TS\I4.·.[¡e$il,\!rMinimuïÏ'l'[).in"lÄätéråí' l.2êd··>þ.· ··titnÊll$'¡s1;QO~\ ;;; ..',. ;U...i ;;.i DescriDtion Size TOD I Bottom TVD Wt Grade Thread LINER LEG A #1 2.375 7914 I 8614 8614 4.70 L-80 STL LINER LEG A #2 2.375 I 8614 I 9785 9785 4.70 L-80 STL .Tul)inãiSinnã;;'iJiUEJING;IOrîiajnål..Como'êiion:tfubinõ'7i1.80 -..76821 ;; >..F"".... F; ;; Size I Top Bottom TVD Wt Grade Thread 3.500 I 0 7180 7180 9.30 L-80 EUE8rd 3.500 I 7180 7682 7682 9.20 L-80 EUE8rdMOD Eléi\fðiiilonš.iSûïÏ'lmârv, ;; ;; ···.····..··F··.'.· .;.......;; ii· ;U ;; i; ..». ;......;> ;;i> » Fi;U·.i! Interval TVD Zone Status Ft SPF Date TVDe Comment 8261 - 8602 8261 - 8602 341 8 0/10/2004 IPERF Slotted Liner, 3/8" holes, 8 sm. 90 deo onent 8615 - 9773 8615.. 9773 1158 8 ~ 0/1 0/2004 IPERF Slotted Liner, 3/8" holes, 8 spf 90 dea orient St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3176 3176 CAMCO MMG GLV 1.5 RK 0.188 1337 0/21/200 2 4700 4700 CAMCO MMG GLV 1.5 RK 0.188 1314 0/21/200 3 5811 5811 CAMCO MMG GLV 1.5 RK 0.188 1293 0/21/200 4 6579 6579 CAMCO MMG GLV 1.5 RK 0.250 1311 0/21/200 5 7110 7110 CAMCO MMG OV 1.5 RK 0.250 0 U/.c.II.c.U,", Qttjêr!Ci.jIUâš·}êâi:lii:lii·····êtôì}·....c;OMMONJEWSI;.RY ........i; SEAL Depth TVD Type Description ID (7172-7172, OD:4.500) 28 28 HANGER FMC TUBING HANGER 10/3/2004 3.800 1966 1966 SSSV CAMCO TRM-4E SSSV #HVS-379 set 10/3/2004 2.812 7161 7161 NIP HALLIBURTON 'X' NIPPLE 10/3/2004 3.812 7172 7172 SEAL BOT 80-40 SEAL ASSEMBLY STABBED INTO ORIGINAL 3.000 COMPLETION PBR @ 7180' 10/3/2004 7180 7180 PBR BAKER PBR (ORIGINAL COMPLETION) 3.000 7193 7193 PACKER BAKER 'FHL' PACKER (ORIGINAL COMPLETION) 2.937 TUBING 7211 7211 NIP CAMCO 'D' NIPPLE NO GO (ORIGINAL COMPLETION) 2.750 (7180-7682, 7681 7681 SOS BAKER (ORIGINAL COMPLETION) 2.992 OD:3.500, ID:2.992) 7870 7870 TTL ORIGINAL COMPLETION 2.992 Otfièrî!Ci lûåsé i:lul'Q'··i.IfC¡};..'Iii'NSRUEG .·~~SVVeI.fR'i1 » '·.·"F DeDth TVD TVDe Description ID 7914 7914 SLEEVE WEATHERFORD DEPLOYMENT SLEEVElOH WHIPSTOCK from LEG 1.000 AL1 TO LEG A 8614 8614 SLEEVE SHORTY BAKER DEPLOYMENT SLEEVE CONNECTS TOP & 2.250 BOTTOM LEG A LINER t3eneiil!NöiEIŠ ....;;...... '; ................». >; ;; .,.....>. ;..........;......;.... ··.·T':··. '} i..··.·>i·(,'··. Date I Note 0/18/2001 CTD DUAL LATERAL WELL: LEG A - PRODUCING LATERAL LEG DRILLED OFF LEG AL 1 SLEEVE ***NOT ACCESSIBLE FOR WELLWORK*** (7914-7915, OD:2.500) - Perf (8261-8602) - - - - - - LINER LEG A #1 (7914-8614, OD:2.375, Wt:4.70) SLEEVE (8614-8615, - - OD:2.650) - - Perf - - (8615-9773) - - . BP-GDB Baker Hughes INTEQ Survey Report . ... ..... IN'fE'.Q Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1Y Pad North Slope Site Position: Northing: 5974755.95 ft Latitude: 70 20 31.499 N From: Map Easting: 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.24 deg Well: 1Y-24 Slot Name: KRU 1Y-24 Well Position: +N/-S 0.00 ft Northing: 5974755.95 ft Latitude: 70 20 31.499 N +E/-W 0.00 ft Easting : 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft Wellpath: 1 Y-24APB 1 Drilled From: 1Y-24 500292237170 Tie-on Depth: 7874.00 ft Current Datum: SITE Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/13/2004 Declination: 24.59 deg Field Strength: 57565 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 187.26 Survey Program for Definitive Wellpath Date: 8/23/2004 Validated: Yes Actual From To Survey ft ft 35.00 7870.70 7874.00 9918.00 Version: 3 Toolcode Tool Name Survey #1 (35.00-8375.00) (0) MWD (7874.00-9918.00) MWD MWD MWD - Standard MWD - Standard Annotation Survey: MWD Start Date: 8/20/2004 CoilTrak Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 7870.70 30.65 160.02 5979.39 5873.39 -4643.33 1258.96 5970118.40 532709.92 4447.16 0.00 0.00 7874.00 30.64 160.03 5982.23 5876.23 -4644.91 1259.53 5970116.82 532710.50 4448.65 0.34 153.00 7911.15 35.38 188.25 6013.55 5907.55 -4664.58 1261.23 5970097.16 532712.28 4467.95 42.93 85.11 7940.91 43.22 207.40 6036.65 5930.65 -4682.24 1255.28 5970079.48 532706.40 4486.22 48.29 64.84 7970.04 50.86 220.79 6056.54 5950.54 -4699.72 1243.26 5970061.95 532694.46 4505.08 42.56 56.79 8000.02 56.51 238.07 6074.37 5968.37 -4715.22 1224.95 5970046.37 532676.22 4522.77 50.02 73.22 8030.83 58.41 255.84 6091.04 5985.04 -4725.28 1201.19 5970036.21 532652.50 4535.75 48.95 87.64 8066.16 63.71 275.57 6108.26 6002.26 -4727.44 1170.58 5970033.92 532621.90 4541.76 51.04 77.92 8095.19 73.13 287.13 6118.95 6012.95 -4722.06 1144.22 5970039.19 532595.52 4539.75 49.18 51.04 8125.88 87.71 287.62 6124.05 6018.05 -4713.05 1115.41 5970048.09 532566.68 4534.45 47.53 1.94 8161.42 90.60 293.41 6124.57 6018.57 -4700.60 1082.15 5970060.39 532533.37 4526.30 18.21 63.54 . BP-GDB Baker Hughes INTEQ Survey Report . ..a: IN'fB,Q 92.96 299.80 6123.27 6017.27 -4681.85 1044.72 5970078.98 532495.86 4512.43 16.25 69.64 90.54 305.18 6122.17 6016.17 -4662.45 1014.25 5970098.25 532465.32 4497.03 16.31 114.13 87.62 309.11 6122.70 6016.70 -4642.27 987.61 5970118.32 532438.59 4480.37 14.64 126.63 86.18 314.70 6124.61 6018.61 -4618.73 961.38 5970141.75 532412.27 4460.34 16.33 104.61 8343.80 89.06 315.67 6126.09 6020.09 -4593.52 936.33 5970166.85 532387.12 4438.49 8.54 18.62 8377.06 89.95 311.62 6126.38 6020.38 -4570.57 912.27 5970189.70 532362.96 4418.77 12.47 282.37 8412.61 87.99 305.31 6127.02 6021.02 -4548.4 7 884.46 5970211.67 532335.06 4400.36 18.58 252.70 8448.80 90.63 301.17 6127.45 6021.45 -4528.64 854.20 5970231.37 532304.72 4384.51 13.57 302.49 8492.90 90.17 293.59 6127.15 6021.15 -4508.38 815.07 5970251.47 532265.51 4369.35 17.22 266.56 8525.77 91.34 289.06 6126.71 6020.71 -4496.43 784.46 5970263.29 532234.86 4361.36 14.23 284.51 8557.38 91.55 284.96 6125.91 6019.91 -4487.19 754.25 5970272.41 532204.61 4356.01 12.98 272.98 8590.54 91.74 279.84 6124.96 6018.96 -4480.07 721.89 5970279.39 532172.22 4353.03 15.44 272.20 8627.52 92.60 274.60 6123.56 6017.56 -4475.43 685.24 5970283.88 532135.56 4353.06 14.35 279.42 8661.53 95.42 269.76 6121.18 6015.18 -4474.14 651.35 5970285.03 532101.67 4356.05 16.44 300.44 8696.63 94.62 265.43 6118.11 6012.11 -4475.60 616.43 5970283.41 532066.75 4361.92 12.50 259.69 8740.50 87.99 264.55 6117.11 6011.11 -4479.43 572.76 5970279.40 532023.11 4371.23 15.25 187.57 8770.17 83.59 264.80 6119.29 6013.29 -4482.18 543.30 5970276.53 531993.67 4377.68 14.85 176.77 8800.95 83.56 267.70 6122.73 6016.73 -4484.18 512.79 5970274.41 531963.16 4383.51 9.36 90.76 8830.39 85.65 273.28 6125.50 6019.50 -4483.92 483.49 5970274.54 531933.87 4386.96 20.16 69.66 8860.81 86.49 278.07 6127.59 6021.59 -4480.92 453.30 5970277.41 531903.67 4387.80 15.95 80.20 8890.02 87.40 281.26 6129.15 6023.15 -4476.03 424.55 5970282.18 531874.90 4386.57 11.34 74.15 8922.75 89.28 286.66 6130.09 6024.09 -4468.14 392.81 5970289.94 531843.13 4382.75 17.46 70.89 8950.31 87.47 289.64 6130.88 6024.88 -4459.56 366.64 5970298.41 531816.93 4377.55 12.65 121.32 8980.82 89.09 295.29 6131.79 6025.79 -4447.91 338.47 5970309.94 531788.71 4369.55 19.26 74.09 9010.29 88.79 300.13 6132.34 6026.34 -4434.21 312.39 5970323.53 531762.58 4359.26 16.45 93.59 9040.20 89.22 303.15 6132.86 6026.86 -4418.53 286.93 5970339.10 531737.06 4346.91 10.20 81.92 9070.14 89.37 300.71 6133.23 6027.23 -4402.69 261.53 5970354.83 531711.59 4334.41 8.16 273.50 9108.57 88.42 294.85 6133.97 6027.97 -4384.79 227.55 5970372.58 531677.54 4320.95 15.44 260.74 9158.86 93.15 292.11 6133.28 6027.28 -4364.76 181.45 5970392.42 531631.35 4306.90 10.87 329.93 9192.15 94.54 288.83 6131.05 6025.05 -4353.15 150.33 5970403.90 531600.20 4299.31 10.68 293.12 9235.56 91.64 280.52 6128.70 6022.70 -4342.18 108.44 5970414.69 531558.26 4293.72 20.25 250.99 9268.29 88.82 278.94 6128.57 6022.57 -4336.65 76.19 5970420.08 531525.99 4292.31 9.88 209.27 9303.00 85.59 276.91 6130.26 6024.26 -4331.87 41.86 5970424.72 531491.64 4291.90 10.99 212.07 9336.26 87.50 273.15 6132.27 6026.27 -4328.96 8.79 5970427.49 531458.57 4293.19 12.66 296.85 9369.28 88.21 268.83 6133.51 6027.51 -4328.39 -24.19 5970427.92 531425.59 4296.79 13.25 279.25 9407.67 89.03 264.19 6134.43 6028.43 -4330.73 -62.49 5970425.42 531387.30 4303.95 12.27 279.96 9447.63 87.56 258.64 6135.62 6029.62 -4336.69 -101.97 5970419.30 531347.85 4314.84 14.36 255.09 9479.12 86.49 254.89 6137.25 6031.25 -4343.89 -132.57 5970411.97 531317.28 4325.85 12.37 253.96 9511.08 87.13 250.24 6139.03 6033.03 -4353.45 -163.01 5970402.29 531286.89 4339.18 14.66 277. 71 9540.46 91.21 249.36 6139.46 6033.46 -4363.59 -190.57 5970392.03 531259.37 4352.72 14.21 347.82 9575.60 97.82 252.15 6136.69 6030.69 -4375.13 -223.62 5970380.35 531226.37 4368.34 20.41 22.73 9615.91 99.14 257.33 6130.75 6024.75 -4385.62 -262.07 5970369.70 531187.97 4383.61 13.12 75.18 9647.39 99.17 261.90 6125.74 6019.74 -4391.22 -292.63 5970363.97 531157.44 4393.02 14.33 89.26 9680.37 96.51 265.75 6121.24 6015.24 -4394.73 -325.11 5970360.33 531124.98 4400.60 14.10 124.62 9720.91 96.35 272.33 6116.69 6010.69 -4395.41 -365.36 5970359.48 531084.73 4406.36 16.13 91.03 9771.78 92.16 278.06 6112.91 6006.91 -4390.81 -415.85 5970363.87 531034.23 4408.17 13.93 126.01 9789.01 92.90 281.45 6112.15 6006.15 -4387.89 -432.81 5970366.71 531017.26 4407.42 20.12 77.60 9831.78 92.01 288.76 6110.32 6004.32 -4376.77 -474.04 5970377.67 530975.99 4401.59 17.20 96.78 9861 .22 94.38 293.41 6108.68 6002.68 -4366.20 -501.46 5970388.12 530948.53 4394.57 17.71 62.84 9880.11 93.70 295.29 6107.35 6001.35 -4358.43 -518.62 5970395.82 530931.33 4389.03 10.56 109.86 9918.00 93.70 295.29 6104.90 5998.90 -4342.27 -552.81 5970411.83 530897.08 4377.32 0.00 0.00 Alaska, Inc. WELLPATH DETAILS 280.000 0.00 0.00 0.00 REFERENCE INFORMATION North 1f2f2004 AM . BP-GDB Baker Hughes INTEQ Survey Report . ..I: lNTEQ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1Y Pad North Slope Site Position: Northing: 5974755.95 ft Latitude: 70 20 31.499 N From: Map Easting: 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.24 deg Well: 1Y-24 Slot Name: KRU 1Y-24 Well Position: +N/-S 0.00 ft Northing: 5974755.95 ft Latitude: 70 20 31.499 N +E/-W 0.00 ft Easting : 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft Wellpath: 1Y-24A Drilled From: 1Y -24 500292237101 Tie-on Depth: 7855.00 ft Current Datum: SITE Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/6/2004 Declination: 24.52 deg Field Strength: 57570 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 280.00 Survey Program for Definitive Wellpath Date: 11/1/2004 Validated: Yes Actual From To Survey ft ft 35.00 7841.40 7855.00 9785.00 Version: 14 Toolcode Tool Name Survey #1 (35.00-8375.00) (0) MWD (7855.00-9785.00) MWD MWD MWD - Standard MWD - Standard Annotation 7841.40 7855.00 9785.00 5954.21 5965.89 6115.97 TIP KOP TD Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 10/10/2004 Engineer: Tied-to: From: Definitive Path 7841.40 30.90 160.24 5954.21 5848.21 -4629.23 1253.85 5970132.47 532704.76 -2038.66 0.00 0.00 7855.00 30.78 160.06 5965.89 5859.89 -4635.79 1256.22 . 5970125.93 532707.15 -2042.13 1.11 217.48 7879.44 38.85 171.35 5985.96 5879.96 -4649.28 1259.52 5970112.45 532710.50 -2047.72 42.14 43.38 7915.10 56.27 175.58 6009.94 5903.94 -4675.33 1262.36 5970086.41 532713.46 -2055.05 49.61 11.65 7937.64 61.43 185.93 6021.61 5915.61 -4694.57 1262.06 5970067.17 532713.24 -2058.09 45.44 62.54 7976.81 62.94 209.37 6040.09 5934.09 -4727.24 1251.62 5970034.47 532702.93 -2053.48 52.98 91.42 8026.48 66.63 237.53 6061.60 5955.60 -4759.29 1221.02 5970002.29 532672.47 -2028.91 51.72 88.03 8052.78 63.11 250.66 6072.81 5966.81 -4769.69 1199.69 5969991.80 532651.18 -2009.71 47.11 109.22 8087.31 60.00 267.02 6089.34 5983.34 -4775.60 1170.06 5969985.77 532621.59 -1981.56 42.58 106.04 8117.64 64.67 278.61 6103.46 5997.46 -4774.23 1143.31 5969987.03 532594.83 -1954.98 37.16 68.32 8132.98 71.07 281.29 6109.24 6003.24 -4771.77 1129.32 5969989.43 532580.84 -1940.78 44.75 21.72 . BP-GDB Baker Hughes INTEQ Survey Report . .Ii. ...... INTlr.Q 8173.07 83.95 291.49 6117.91 60'11.91 -4760.68 1091.93 5970000.36 532543.40 -1902.03 40.57 38.96 8210.86 84.70 297.46 6121.65 6015.65 -4745.11 1057.72 5970015.79 532509.13 -1865.63 15.85 83.11 8250.33 83.65 303.25 6125.66 6019.66 -4725.27 1023.85 5970035.48 532475.18 -1828.83 14.83 100.62 8285.40 86.82 299.27 6128.57 6O:!2.57 -4707.15 993.99 5970053.48 532445.24 -1796.27 14.48 308.45 8319.67 90.32 295.70 6129.43 60~~3 .43 -4691.34 963.60 5970069.15 532414.80 -1763.61 14.59 314.38 8354.74 89.34 290.78 6129.53 6D:!3.53 -4677.51 931.39 5970082.85 532382.53 -1729.48 14.30 258.73 8385.18 90.32 287.01 6129.62 60n.62 -4667.65 902.59 5970092.58 532353.70 -1699.41 12.80 284.56 8418.11 90.84 282.70 6129.29 60<~3.29 -4659.21 870.77 5970100.89 532321.84 -1666.61 13.18 276.90 8450.60 91.74 284.93 6128.56 60<~2.56 -4651 .46 839.23 5970108.51 532290.27 -1634.20 7.40 67.99 8482.02 89.92 289.37 6128.10 60:;~2.1 0 -4642.19 809.22 5970117.65 532260.23 -1603.04 15.27 112.25 8519.78 88.97 295.52 6128.47 60:;:2.47 -4627.79 774.34 5970131.91 532225.29 -1566.19 16.48 98.80 8561.08 87.25 303.26 6129.83 602:3.83 -4607.55 738.41 5970152.00 532189.27 -1527.28 19.19 102.64 8590.96 89.16 306.26 6130.77 6024.77 -4590.52 713.87 5970168.92 532164.67 -1500.16 11.90 57.56 8622.94 91.12 302.73 6130.69 6024.69 -4572.41 687.52 5970186.91 532138.25 -1471.07 12.63 299.04 8653.62 91.27 299.58 6130.05 6024.05 -4556.55 661.28 5970202.67 532111.94 -1442.47 10.28 272.76 8695.99 89.80 293.92 6129.65 6023.65 -4537.49 623.46 5970221.57 532074.04 -1401.91 13.80 255.48 8726.38 89.37 289.92 6129.87 6023.87 -4526.14 595.27 5970232.79 532045.81 -1372.19 13.24 263.85 8764.85 90.88 284.68 6129.79 6023.79 -4514.71 558.56 5970244.07 532009.05 -1334.04 14.17 286.07 8792.68 90.54 279.86 6129.45 6023.45 -4508.79 531.37 5970249.87 531981.85 -1306.24 17.36 266.00 8826.81 90.63 273.10 6129.10 6023.10 -4504.95 497.48 5970253.58 531947.94 -1272.20 19.81 270.80 8854.85 90.01 270.58 6128.94 6022.94 -4504.05 469.46 5970254.36 531919.92 -1244.45 9.25 256.19 8878.42 90.69 266.84 6128.80 6022.80 -4504.58 445.90 5970253.73 531896.37 -1221.34 16.13 280.31 8912.05 92.97 264.28 6127.72 6021.72 -4507.18 412.39 5970250.99 531862.87 -1188.79 10.19 311.74 8949.69 92.01 270.94 6126.08 6020.08 -4508.74 374.84 5970249.26 531825.33 -1152.08 17.86 98.06 8981.39 88.54 273.94 6125.93 6019.93 -4507.39 343.18 5970250.48 531793.67 -1120.67 14.47 139.14 9011.46 88.42 278.30 6126.73 6020.73 -4504.19 313.30 5970253.56 531763.78 -1090.68 14.50 91.63 9043.42 92.07 284.13 6126.59 6020.59 -4497.98 281.97 5970259.64 531732.43 -1058.75 21.52 57.96 9083.30 92.26 291.76 6125.09 601 !~.09 -4485.71 244.08 5970271.75 531694.49 -1019.31 19.12 88.43 9119.31 88.02 295.91 6125.00 6019.00 -4471.16 211.16 5970286.15 531661.51 -984.36 16.47 135.59 9148.01 87.43 300.35 6126.14 6020.14 -4457.65 185.88 5970299.56 531636.17 -957.12 15.59 97.66 9181.70 88.27 307.61 6127.40 602 '1.40 -4438.84 157.98 5970318.25 531608.20 -926.38 21.68 83.54 9212.19 85.13 306.79 6129.16 602:~.16 -4420.44 133.74 5970336.55 531583.88 -899.31 10.64 194.59 9243.56 87.80 301.98 6131.09 602!>.D9 -4402.77 107.91 5970354.11 531557.98 -870.80 17.51 298.92 9271.83 88.36 298.30 6132.04 6021).04 -4388.58 83.48 5970368.19 531533.50 -844.28 13.16 278.59 9300.73 87.99 294.42 6132.96 602Eì.96 -4375.76 57.60 5970380.90 531507.57 -816.57 13.48 264.49 9336.03 86.73 288.68 6134.59 60211.59 -4362.81 24.82 5970393.71 531474.73 -782.03 16.63 257.48 9377.18 90.11 285.17 6135.72 602H.72 -4350.84 -14.52 5970405.52 531435.35 -741.21 11.84 313.87 9407.92 92.60 289.32 6135.00 602H.00 -4341.74 -43.87 5970414.50 531405.97 -710.74 15.74 58.99 9437.46 94.59 292.55 6133.14 602/'.14 -4331.20 -71.40 5970424.91 531378.40 -681.79 12.82 58.22 9465.85 94.38 288.41 6130.92 6024.92 -4321.30 -97.90 5970434.70 531351.85 -653.97 14.56 267.25 9495.35 93.95 285.38 6128.78 602:;~.78 -4312.75 -126.05 5970443.13 531323.67 -624.76 10.35 262.01 9526.88 92.66 282.30 6126.96 6020.96 -4305.23 -156.61 5970450.53 531293.08 -593.36 10.58 247.33 9551.20 91.92 278.54 6125.99 60121.99 -4300.83 -180.51 5970454.82 531269.17 -569.07 15.74 258.94 9581.40 91.55 274.08 6125.07 60191.07 -4297.51 -210.50 5970458.02 531239.16 -538.95 14.81 265.33 9619.03 90.05 265.94 6124.55 6018.55 -4297.51 -248.10 5970457.86 531201.57 -501.93 21.99 259.63 9646.22 92.84 263.11 6123.86 6017.86 -4300.10 -275.15 5970455.16 531174.54 -475.73 14.61 314.63 9678.72 91.55 258.91 6122.62 6016.62 -4305.18 -307.22 5970449.95 531142.49 -445.03 13.51 253.00 9719.34 93.06 252.85 6120.98 6014.98 -4315.07 -346.56 5970439.89 531103.20 -408.01 15.36 284.11 9753.49 94.84 248.33 6118.63 6012.63 -4326.39 -378.68 5970428.44 531071.12 -378.34 14.20 291.69 , 9785.00 94.84 248.33 6115.97 ' 6009.97 / -4337.98 -407.86 5970416.73 531042.00 -351.62 0.00 0.00 .. AM 112/2004 ·300 Alaska, WELLPATH DETAILS ;2 1 t 280.00° 0.00 0.00 0.00 REFERE TVD MO ArmÒ!atiOh STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Üm...fºSK1@ªçAm!.rJ.,§Aªt~~:.f!.~:.~g~ aO~1cc _prudhoe _ bay@adrnin.statø.ak,us bob_fleckenstein@admin.state.ak.us Contractor: NORDIC / SLB Rig No.: 2 DATE: 10/5/04 Rig Rep.: Mckeirnan/Olsen Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/Feketi E-Mail SUADWDRLGNORDIC2TOOl.PUSHER@BP.COM Well Name: Kupuuk 1Y-24A PTD # 2Ø4..125 Meridian: UM Location: Section: 01 Township: 11N Range: 09E Operation: Drlg: Workover: X Explor. : Test: Initial: X Weekly: Other: Test Pressure: Rams: 250/4500 Annular: 250/3500 Valves: 250/4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly 0 Housekeeping: P Dr!. Rig P Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP P BOP STACK: Quantity Size/Type P/F MUD SYSTEM: Visual Alarm Stripper Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves P HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve N/A Time/Pressure P/F System Pressure 3000 CHOKE MANIFOLD: Pressure After Closure 2400 Quantity P/F 200 psi Attained 24 sec No. Valves 14 PIP Full Pressure Attained 1 Min 10 sec Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2100 Test Results Number of Failures: º Test Time: § Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Üm...miKl@ª1m!.rJ.,§.~ªt§;:.fJ.~:.~g~ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Chuck Scheeve c - Database Date 10/4/04 Time 0800 c - Trip Rpt File Witness c - Inspector Test start 0930 Finish 1630 "'C·"tJ'>.'~!,,"· <~, ..\"'~, -,,'F,I )) 'V '~ ~<¡¡;.,..- Coil Tubing BFL OS/29/03 Nordic 2 BOP 10-5-04. .xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Üm...Œrm.@ª.g.m!.rJ.,§Aª.t§;:.f!.~:.~g~ aoncc _prudhoe _bay@adrnin.statt-;.ak,us bob_f!eckenstein@admin.state.ak.us Contractor: NORDIC / SLB Rig No.: 2 DATE: 10/2/04 Rig Rep.: Mckeiman/Olsen Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/Feketi E-Mail SUADWDRLGNORD!C2TOOl.PUSHER@BP.COM Well Name: Kuparuk 1Y-24A PTD # 2'*"'25 Meridian: UM Location: Section: 01 Township: 11N Range: 09E Operation: Drlg: Workover: X Explor. : Test: Initial: X Weekly: Other: Test Pressure: Rams: 250/4500 Annular: 250/3500 Valves: 250/4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly 0 Housekeeping: P Dr!. Rig P Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size/Type P/F MUD SYSTEM: Visual Alarm Stripper Trip Tank P P Annular Preventer 1 71/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams Meth Gas Detector P P #3 Rams 1 31/2" P H2S Gas Detector P P #4 Rams 1 4" P #5 Rams N/A Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves P HCR Valves 2 31/8" PP Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve N/A Time/Pressure P/F System Pressure 3100 CHOKE MANIFOLD: Pressure After Closure 2100 Quantity P/F 200 psi Attained 30 sec No. Valves 14 PIP Full Pressure Attained 1 Min 30 sec Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 ~ 2100 Test Results Number of Failures: º Test Time: § Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Üm...n;iKl@ªiAm!.rJ.,§Aª.t§;,.f!.~:.U.~~ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By Chuck Scheeve c - Database Date 10/1/04 Time 10:00 c - Trip Rpt File Witness c - Inspector Test start 1700 Finish 2300 Coil Tubing BFL OS/29/03 SCA.t\JNED ., F ')f; pç tJ § c-~0d Nordic 2 BOP 10-2-04..xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Hm...f~iJ.{l@ª.g.mJ.i}.'.§.~ªH~:.ªL\g~ aoocc _prudhoe _ bay@admin.statø.ak.us bob _fieekens1t:;¡ n@adm¡rJ.stat!.H1K.US Contractor: NORDIC I SLB Rig No.: 2 DATE: 8/16/04 Rig Rep.: Holmes I Olsen Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi / Hildreth E-Mail SUADWDRLGNORD!G2TOOLPUSH~:.R(él<8P.COM Well Name: Kuparuk 1Y-24A PTD # 2M-125 Meridian: UM Location: Section: 01 Township: 11N Range: 09E Operation: Drlg: XXX Workover: Explor. : Test: Initial: XXX Weekly: Other: Test Pressure: Rams: 250/4500 Annular: 250/3500 Valves: 250/4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.: P Well Sign P Upper Kelly 0 Housekeeping: P Dr!. Rig P Lower Kelly 0 PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 0 BOP STACK: Quantity SizelType P/F MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 23/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NIA Quantity P/F Choke Ln. Valves 1 31/8" P Inside Reel valves 1 * HCR Valves 2 31/8" PP Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve NIA Time/Pressure P/F System Pressure 3050 CHOKE MANIFOLD: Pressure After Closure 2250 Quantity P/F 200 psi Attained 21 sec No. Valves 14 PIP Full Pressure Attained 2 Min 27 sec Manual Chokes 1 P Blind Switch Covers: All stations XX Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2000 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: HLD...f~iJ.{l@ªg.mjD.'.§lªt~~&~:.m~ Remarks: * No "inside reel va/ve" installed with the 2" CT w/E-Line Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper.lRig Waived By Jeff Jones c - Database Date 8/15/04 Time ?? c - Trip Rpt File Witness c - Inspector Test start 05:00 Finish 09:30 Coil Tubing BFL 05/29/03 Nordic 2 BOP 08-16-04..xls e ~ &\ e AIfASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 27!H 433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~Q~ Re: Kuparuk 1 Y-24A Sundry Number: 304-356 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF THE'yoMMISSION DATED this ~ay of September, 2004 Enc!. e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 t~GIt- Ll!l¿/ZOD1 1. Type of Request: Re-Enter Ops Shutdown o Abandon o Repair Well o Plug Perforations o Stimulate III Other o Alter Casing o Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. perm~Drill Number Conoco Phillips Alaska Inc. a Development o Exploratory ,.,,204-1 ì ~O4-337 3. Address: o Stratigraphic o Service 6. API Number: / clo P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22371-01-00 7. KB Elevation (ft): 106' 9. Well Name and Number: r" Kuparuk 1Y-24A 8. Property Designation: 10. Field I Pool(s): ADL 025646 Kuparuk River I Kuparuk River Oil Pool j1. ....... PRESENT WELLCONDITIONSI.JMMARY i." '. i Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8375' 6420' 7171' 5431' (Whipstock) 7171' 7171' ii,,'..·...·i{ '···...ii· Sœ1êi""i';)' .··..;i.'·...·ii~ ii"i ...i ;;.ii.;:'·Riil'!;¡f......; "iIi i'. Strur.tural t r 121' 16" 121' 121' SUrf~r.A 4599' 9-5/8" 4599' 3600' 3520 2020 Inter~~"': t~ P 7568' 7" 7568' 5733' 7240 5410 Liner 1108' 5" 7264' - 7874' 5501' - 5982' 10140 10490 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): None None 4" 11# 13-1/2" 9.3 & 9.2# J-55 I L-80 7681' Packers and SSSV Type: Baker 'FHL' packer; Packers and SSSV MD (ft): 7193' 4" Camco 'TRDP-4' SSSV 1793' 12. Attachments: 13. Well Class after proposed work: IS! Description Summary of Proposal o BOP Sketch o Exploratory a Development o Service o Detailed Operations Program ~ 14. Estimated Date for ~¡; J 15. Well Status after proposed work: Commencing Operations: Septemb r 25.;1004 a Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Da~ o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Kara, 564-5667 Printed Name Dan Kara Title CT Drilling Engineer Signature~~ .£.. L)<:4.-I¿'~ Prepared By Name/Number: Phone 564-5667 Date Terrie Hubble, 564-4628 ............. > "';,...i··;· ..... i....""·'02,~·..'·..·;i ......i i.ii;·..; ·····>i....,;· ;i·.i;:...ii.;.i;; ii;;"':I I;i.;;;;I;ii;,'·;; i....i .... ;;.;........ Sundry Number: 3d-f~]5b Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: A-i i o rl ~ j,l-~·l 'Ú rvÚ t <; ~I)} Ì{! a.. bfhl~ C~fpí1 ' 407 t~~~.S ßFL SEP 2 ~l Subsequent For~e Approved Ç( ~-<- APPROVED BY ~~(£'I/ COMMISSIONER THE COMMISSION Date Form 1 0-403 ~ed 0~4 ~ubmit"'n Duþlicate OqIGf~LAL · e e bp To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Dan Kara CT Drilling Engineer Date: September 21, 2004 Re: Well KRU I Y -24A Restart of CTD Operations Nordic 2 is planning to move back onto Kuparuk well I Y -24A. Fishing operations were unsuccessful at removing the aluminium whipstock (for openhole sidetracking) that was inadvertently set in the tubing at 7171 'md. Plans are for Nordic to pull the production tubing, remove the fish and recomplete with 3-1/2" tubing. Nordic 2 will then redrilllY-24A and IY-24ALI, as detailed in Permit to Drill #204-125 & #204-126. It is assumed that the existing 3" openhole would have collapsed by now, requiring a redrill of the I Y-24A lateral. The only thing that may be salvageable from the first sidetrack attempt is the window. If the formation around the window is collapsed, another window will be milled above the existing window. No attempts will be made /' to isolate the existing window/openhole. Given the lack of recent success in fishing operations, Nordic 2 will be ready to move to this well by Sunday, 9/25/2004. Please call with questions. ~-- Dan Kara CTD Drilling Engineer 564-5667,240-8047 CC: Well File Terrie Hubble Dan Venhaus, CP AI .. . KRU 1Y-24A & Y-24AL1 Producer Proposed CTD Completion ~ Conoe illip5 Alaska,lnc H. 4" 11.0# J-55 OSS-HTC tubing to surface. G. 4" Cameo 'TRDP-4' SSSV set at 1793' MD, 3.312" 10 9-518" 36# J-55 casing @ 4599' 5" liner top @ 7264' MO I. 4" xi" Merla TMPO mandrel at 3006' MD i. 4" x 3-'h" crossover at 4893' MO Fish: 2.5" 00 Aluminum whipstock @ 7171'md O. 3-'h" Cameo Wi landing nipple with 2.813" ID at 1111' MO C. Baker 3-112" FHL packer at 1193' MD with PBRlseal assembly 1" 26# LBO @ 1568' MD B. 3-W Cameo 0 nipple with 2.15" 10 at 1211' MD (may be milled out to 2.80" for CTO bits) 2-3/8" liner top @ +/-1600' MD A. 3-1/2" tubing tall at 1681' M 0 Top of Whipstock 7874' MD Cemented in Place Window in 5" 3" openhole 1Y-24A, TD @ 9918' md 5" 18# LoSO @ 8312' MD e e FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 1, 2004 ~1~.·.·.,;"" ~".I-r.""Arò-' Thomas McCarty CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk lY-24A Sundry: 304-337 Dear Mr. McCarty: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure ¡ " OTJ ¡J¡/CI-- e STATE OF ALASKA e RECEIVED y ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 3 1 2004 #Fy \ APPLICATION FOR SUNDRY APPROVAL. &G C·" C 'ssion3 20 MC 25.280 Alaska 011 as ons. omml Anchorage 1. Type of Request: o Abandon o Alter Casing o Change Approved Program o Repair Well 0 Plug Perforations o Pull Tubing 0 Perforate New Pool III Operation Shutdown 0 Perforate o Stimulate o Waiver o Re-Enter Suspended Well o Other o Time Extension 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: B Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 204-125 6. API Number: 50- 029-22371-01-00 99519-6612 106' 9. Well Name and Number: Kuparuk 1Y-24A 8. Property Designation: 10. Field I Pool(s): ADL 025646 Kuparuk River I Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 7874 5982 121' 16" 121' 121' 4599' 9-5/8" 4599' 3600' 3520 2020 7568' 7" 7568' 5733' 7240 5410 1108' 5" 7264' -7874' 5501' - 5982' 10140 10490 Perforation Depth MD (ft): None Packers and SSSV Type: Perforation Depth TVD (ft): None Baker 'FHL' packer; 4" Camco 'TRDP-4' SSSV Tubing Size: Tubing Grade: 4" 11# 13-1/2" 9.3 & 9.2# J-55 I L-80 Packers and SSSV MD (ft): 7193' 1793' Tubing MD (ft): 7681' 12. Attachments: B Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: August 28, 2004 16. Verbal Approval: Date: 8/30/2004 Commission Re resentative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty Title CT Drilling Engineer 13. Well Class after proposed work: o Exploratory B Development 0 Service 15. Well Status after proposed work: BOil o Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Thomas McCarty, 564-4378 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: '-\'0 ~ Q4.. \' dO Þ..b,C d S ,a \. ~ \.\,) \ \- ç,,>'-'\ "S \'-ð \-s-.)~<;~\-.J \ ~r)MSafL SEP 0 2 ?004 Approved Form 10-40 COMMISSIONER OR\G\ APPROVED BY THE COMMISSION Date v' .. e e To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: Aug 31,2004 Re: Well KRU lY-24A temporary ops shutdown Nordic 2 moved off of KRU 1 Y -24A due to a failed open hole whipstock that set in the tubing at 7171 'md. The well is scheduled for service CT to attempt to fish the whipstock. - CTD Sidetrack Attempt 8/13/2004 - 8/28/2004 1) MIRU Nordic 2. NU 7-1/16" BOPE, test. 2) Mill 2.74" window at 7874' md. 3) Drill 3" bicenter hole horizontal sidetrack 1 Y -24A from window to 9918' TD. 4) Attempt to get liner to TD unsuccessful due to shale collapse at -8658'md, POR with liner. 5) Attempt to openhole sidetrack above shale area, unsuccessful. Left open hole whipstock fish in tubing at 7171'md. 6) Attempt to recover OR whipstock fish unsuccessful. 7) RDMO Nordic 2. CTD Pre-IDe Summary planned for Sept 2 1) SL- Diagnostics for fishing 2) Coil - Fish OR whipstock in tubing If the fish is recovered the decision to re-attempt the CTD sidetrack will be made at that time. Thomas McCarty CTD Drilling Engineer 564-4378, 748-2598 CC: Well File Terrie Hubble KRU 1Y-24A & 1 24AL1 Producer Proposed CTD Completion 9-5/8" 36# J-55 casing @ 4599' 5" liner top @ 7264' MO Fish: 2.5" OD Aluminum whipstock @ 7171 'md 7" 26# L80 @ 7568' MO 2-3/8" liner top @ +/-7600' MO Top of Whipstock 7874' MD Cemented in Place 5" 18# L-80 @ 8312' MD H. 4" 11.0# J-55 DSS-HTC tubing to surface. G. 4" Cameo 'TRDP-4' SSSV set at 1793' MD, 3.312" ID L 4" x 1" Merla TMPD mandrel at 3066' MD L 4" x 3-y." crossover at 4893' MD F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing to crossover w/ 3-1/2" x 1-112" Camqo 'MMG2' mandrels D. 3-%" Cameo Wi landing nipple with 2.813" ID at 7171' MD C. Baker 3-1/2" FHL packer at 7193' MD with PBR/seal assembly B. 3-'12" Cameo 0 nipple with 2.75" 10 at 7211' MD (may be milled out to 2.80"for CTD bits) Ä. 3-1/2" tubing tail at 7681' MD Window in 5" 3" open hole 1Y-24A, TD @ 9918' md Re; Ops shutdown on IY-24 . dO~.\ de;: Subject: Re: Ops shutdown on 1 Y -24 P-s. From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 30 Aug 200410:57:08 -0800 To: "McCarty, Thomas M" <McCartTM@BP.com> Thanks, Thomas. I will look forward to receiving the sundry. Just give a call in the future. Tom Maunder, PE AOGCC McCarty, Thomas M wrote: Tom: The tubing is not sealed but it is occluded with a whipstock at approx. 7171'md. In order to perform any additional work on this well the whipstock needs to be removed. Service coil is planning to fish the whipstock. Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. +1-907-564-4378 office +1-907-748-2598 mobile +1-907-272-3733 home -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, August 30, 2004 10:26 AM To: McCarty, Thomas M Subject: Re: Ops shutdown on 1Y-24 Thomas, I need a little information on this. Is the tubing "sealed" due to the whipstock that was lost?? What are the "off-rig" plans to clear the wellbore?? You should have a look at 20 AAC 25.072 (a) regarding the process for temporarily shutting down the operations. It appears you have a a valid reason for shutting down and moving, however it was appropriate that you made contact with the Inspectors or myself. Tom Maunder, PE AOGCC McCarty, Thomas M wrote: Tom: The company rep left a couple of phone messages on Saturday Morning regarding the pending BOPE test on lD-30L1. But there was not a conversation at that time with the inspectors. lof2 8/30/2004 10:57 AM Re: Ops shutdown on IY-24 Thanks, Thomas . . Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. +1-907-564-4378 office +1-907-748-2598 mobile +1-907-272-3733 home -----Original Message----- From: Thomas Maunder fmailto:tom maunder@admin.state.ak.us] Sent: Monday, August 30,20049:29 AM To: McCarty, Thomas M Subject: Re: Ops shutdown on lY-24 Thomas, Was anyone of the Commission informed about the problems with 1 Y-24A?? If not, there should have been an attempt to contact either the Inspectors or the on-call engineer. Look forward to your reply. Tom Maunder, PE AOGCC McCarty, Thomas M wrote: Tom: Nordic 2 moved off of KRU lY -24A on Saturday. We were unable to complete the well due to an open hole aluminum whipstock that was stuck in the tubing. Plan forward is for service CT to attempt to fish or mill up the whipstock. Nordic 2 may go back to finish the sidetrack if service CT is successful. I will send you a revised Sundry later today. Thank You. If you have any questions or concerns please give me a call. Thomas McCarty Coiled Tubing Drilling Engineer, Alaska Drilling & Wells BP Exploration (Alaska) Inc. +1-907-564-4378 office +1-907-748-2598 mobile +1-907-272-3733 home 20f2 8/30/2004 10:57 AM Re: CTD BOP Testing at KRU e e Subject: Re: CTD BOP Testing at KRU From: Thomas Maunder <tom_maunder@admin.state.akus> Date: Fri, 20 Aug 2004 11:58:50 -0800 To: "Kara, Danny T" <KaraDT@BP.com> CC: Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogcc yrudhoe _ bay@admin.state.ak.us> Dan, As I understand, the regulation change has been formally adopted by the Commissioners and will soon be signed off by the Lt. Governor. I have been advised that the Commissioner's action is sufficient to be able to grant your request. By copy of this email, the coil drilling activities of 1Y-24A and 1Y-24AL1 may use the 14 day interval. Please call with any questions. Tom Maunder, PE AOGCC Kara, Danny T wrote: Tom, BP operated CTD Nordic current drilling a bi-Iateral at Kuparuk River Unit, Well 1Y-24A Pe lt #204-125 a Lateral 1Y-14AL1, Permit #204-126. We are getting close to T ing the fi ateral and have at least another week left on the well. The ri the initial BOP test last Monday, 8/16. I would appreciate it if you could inform me on whether we are on a 7 day or 14 day BOP test interval at KRU. ~ Thanks for your time. Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240-8047 (cell) 564-5510 (Fax) karadt@bp.com 1 of 1 8/20/2004 11 :59 AM .KRU 1~-08Ll and Ll-O 1 Spacing Exceptions . . Sharon, In writing up the conservation order for these exceptions, I noted that CPAI has provided notification of the exception to co-owners, but don't see any notification in our records concerning the State. Since the stae is the landowner, per 20 AAC 25.005(d) (1), they must be notified. Could you have Bill van Dyke send me an email stating DNR has no objection to these wells and spacing exceptions? Thanks, Steve Davies AOGCC 1 of 1 8/31/20043:46 PM ~ . Œ ffiJ~ ~~~~æ . AI,A.SKA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (90~27~7542 Thomas McCarty CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk lY-24A ConocoPhillips Alaska Inc. Permit No: 204-125 Surface Location: 570' SNL, 1762' WEL, SEC. 01, TIIN, R09E, UM Bottomhole Location: 4900' SNL, 1310' EWL, SEC. 01, Tl1N, R09E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska Inc. assumes the liability of any protest to the spacing exception that may occur This permit to redrill 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. P se provide at least twenty-four (24) hours notice for a representative of the Commissio 0 wi ess any required test. Contact the Commission's petroleum field inspector at 6 - ager). BY ORDER ~~ THE COMMISSION DATED this þ2 day of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I STATE OF ALASKA . ALASKA L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 í ~(l3> 1a. Type of work o Drill 11II Redrill 1 b. Current Well Class o Exploratory 11II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: Conoco Phillips Alaska Inc. I Bond No. 2S100302630-277 Kuparuk 1Y-24A 3. Address: 6. Proposed Depth: f 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9850 ./ rvD 600655 Kuparuk River I Kuparuk River Oil 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: j ADL 025646 570' SNL, 1762' EWL, SEC. 01, T11 N, R09E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5114' SNL, 2986' EWL, SEC. 01, T11N, R09E, UM August 5, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4900' SNL, 1310' EWL, SEC. 01, T11N, R09E, UM 2560 25,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool ¡ Surface: x-531432 y- 5974756 Zone- ASP4 (Height above GL): 106 feet iy-l>7 ~~Wèj~'" zt5 c.tv M 16. Deviated Wells: Kickoff Depth: 7885 v' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) $þ ,6 Maximum Hole Angle: 94.1 deQrees Downhole: 3155 Surface: 2535 If 1ö.(.,ì~¡lngpro9ram: ,''''' .- , .T(~etting~ Size Hole Casinq Weiqht Grade Couclina Lenath MD rvD MD rvD 3" 2-3/8" " 6.2# L-80 STL 1965' 7885' 5886' 9850' 6006' Uncemented Slotted Liner 19> PRESENT WELL CONDITIQN~UMMARY(TøbØcornpletedfQfRêclrill AND Re-entry OPéi"åtiOn$) ",,'j"', j, i' Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth rvD (ft): Junk (measured): 8375 6420 None 8282 6338 ~ None F, ij i' >'C.y", Siz~i'F ii , 'f'y > >c ,i;WiZW·,i·ii¡ .,ii¡ iC, <c" StructlJr;:¡1 Conductor 121' 16" ;)18 sx Permafrost 'C' 121' 121' ~ .L 4599' 9-5/8" 800 sx PF 'E', 480 sx 'G', Top Job: 105 sx PF 'C' 4599' 3600' Intermediate Production 7568' 7" 250 sx Class 'G' 7568' 5733' Liner 1108' 5" 175 sx Class 'G' 7264' - 8372' 5501' - 6417' Perforation Depth MD (ft): 8014' - 8107' /perfOration Depth rvD (ft): 6103' - 6184' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty Title CT Drilling Engineer Siqnature/'; ~ Phone 564-4378 Date Teme Hubble. 564-4628 <i·ii:i",j Permit To Drill API Nu er: Permit ApRro al See cover letter for Number:2D'I-/Z,¿;;- 50- 029-22371-01-00 Date: '17/3/t?'-I other requirements Conditions of Approval: Samples Required DYes Jij'No Mud Log Required \ DYes .8I""No . '15Jffide Mea,,"es :RYes [] No Directional Survey Required ~es 0 No Other: 4500 \>s\ I. ~ ~s~ 6-.<:> ~\ ~~",~ù. ADDroVOO B~I/Itú. APPROVED BY Date 1f¡3/lih ~ --. THE COMMISSION V Form 10-401 Rev1\,ed' 0671d~ UKllJII\JAL S~bmit IrfDupliéate ~ ¥ KR'V -24A & V1-24AL 1 Sidetrack - COil'TUblng Drilling l"b ... (z.e4 Summary of Operations: P' 7· Coiled tubing drilling will sidetrack KRU 1 Y-24 using the dynamically overbalancedll-Ied tubing drilling (DOCTD) technique (see description below). This horizontal laterals (lY-24A1/1&JIIf> will target Kuparuk A ,/ sand reserves for production. The Kuparuk A Sand perforations in the existing well, 1 Y -24 will be isolated with cement pumped past the whipstock. CTD Drill and Complete lY-24A & Yl-24ALl proe:ram: Planned for AUf!ust 5. 2004 1. Pre CTD No flow test on SSSV, MIT-IA, MIT-OA 2. Pre CTD install mechanical whipstock at approx 7885' V~ ~ ~Ol...\ -d<ø \ 3. Pre CTD pump approx. 15bbls 15.8ppg cement past whipstock / 4. 5. 6. Mud Program: · Steps 1-2: 9 ppg Potassium-Formate biozan brine · Steps 3-10: Potassium-Formate based Flo-Pro (9 ppg) Disposal: · No annular injection on this well. · Class IT liquids to KRU lR Pad Class II disposal well · Class II drill solids to Grind & Inject at PBU Drillsite 4 · Class I wastes will go to Pad 3 for disposal. Casing Program: · lY-24A: 23/8",6.2#, L-80, STL slotted liner from 9850' md to 8140' md · lY-24ALl: 23/8",6.2#, L-80, STL slotted liner from 7600' md to TD at 10225' md Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for lY-24A & lY-24A Ll · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · The nearest well to 1 Y -24A is 1 Y -16 which is offset by 537'. The nearest well to 24ALl is 2Z-05 815' away. L.., ~ Þ>",G ~6\\ lY- Logging · A Gamma Ray log will be run over all of the open hole section. ./ Thomas McCarty 564-4378 office, 748-2598 cell 1/2 KR~-24A & Y1-24AL 1 Sidetrack - COil!-Ubing Drilling Hazards · One mapped fault in the plannedJ,ð"well path; lost circulation risk is low. · Reservoir pressure is estimated to be 9.8 ppg in the existing well. L2 will penetrate a potentially over- pressured fault block (hence DOCTD). Best estimate is IOppg in the fault block. v · Well1Y-24 has a H2S reading of 60 ppm (measured 08/05/02). 1Y is an H2S pad. All H2S monitoring ¡/ equipment will be operational. .---. ~ L- L ¡"~7'r'fl "l { \ ~ Reservoir Pressure J · Reservoir pressure is approx. 3155psi at 6200' TVD 9.8 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2535 psi. Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 9 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration), and/or the tested tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. At least two times hole volume of kill weight fluid will be on location as a contingency. Both production liners (L1 & L2) will be deployed into the wellbore after killing the well with kill weight fluid. Estimated reservoir pressure: 3155 psi at 6200' TVD, 9.8 ppg EMW. Expected annular friction losses while circulating (ECD): 500 psi Planned mud density: 9 ppg equates to 2902 psi hydrostatic bottom hole pressure. While circulating 9 ppg fluid, bottom hole circulating pressure is estimated to be 3400 psi When circulation is stopped, a minimum of 500 psi surface pressure will be applied to balance the reservoir. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling. Thomas McCarty 564-4378 office, 748-2598 cell 2/2 St MD TVD Man Man Type V Mfr V Type Mfr 1 3066 2523 Merla 2 4899 3811 Camco 3 5658 4340 Camco _11- 6420 4878C amco 5 Camco TVDe I 1645 SSSV 7171 5431 NIPPLE 7180 5438 PBR 7193 5448 PKR I 7211 5461 NIP I 7680 5819 SOS I 7681 I 5819 TTL bN'ðtêš ~Note . A <>'"'HAL , t ofGneHrom I PBTD with No Obstructions. u,Wv~ 1 'indicates oossible Cso Damage) See WSR 1/17/97 API~7100 SSSV Type: TRDP SSSV (1793-1794. 00:4.000) Annular Fluid: Reference Loa: ~ SUR CASING PROD. r::ASING SUR. CASING LINER TUBING Too o 4893 7223 Gas Lift Mandrel/Valve 1 (3066-3067, Gas Lift "M~~I;¿;j Size 4.000 3.500 3.500 Gas Lift MandrelNalve 3 (5658-5659. I Interval TVD 8014 - 8016 6103 - 6105 8016 - 8022 6105 - 6110 8022 - 8030 6110 - 6117 I 8030 - 8038 6117 - 6124 I 8038 - 8039 6124 - 6125 I 8060 - 8074 6143 - 6155 I 8101 - 8107 6179 - 6184 Gas Lift 'ndrellOummy Valve 4 (6420-6421, 00:5.968) Gas Lift MandrelNalve 5 (7126-7127, NIPPLE (7171-7172, 00:3.500) PßR (7180-7181. 00:3.500) PKR '"0' ,~q. NIP n"~ '"~O 00:3.500) n~~Y~;~? . OD3.5ÕÒ Pert :::=:= 1:=== (8016-8022) - ~ ~~~,., ,~""- Pert -==:"" =~= (8014-8039) ,~::=,,' :==, =::=.=,: :==- Perf =~== .=;=:;:::::::::: (8030-8038) ':=~ =,= :~- ,~~ ".,. ..,-= Perf ."" =.--." (8060-8074) ,-,- ,'_" ,--... ,--~ ..=-- 1==" ,_. ,-"- Perf .,.-- 1,==, (8101-8107) 1--- ----- I""" "" KRU Well Tvoe: I PROD Orig 6/28/1993 Comoletion: Last W/O: 3/21/1994 Ref Loa Date: ~KB 2431 Size Too Bottom 16.000 0 121 9.625 0 3041 7.000 0 7568 9.625 3041 4599 5 000 7264 R~7? Anm==== An~ Last UOdate~ I ~Th~d ~ L-80 L-80 J-55 TVD 121 2506 5733 3600 6417 Bottom 4893 7223 7681 TVD Wt 3807 11.00 5470 9.30 ~ 9.20 ~ Date 2 4 9/911993 Thread ¡:-¡:-¡t 1(; !::II!:: ¡¡pn MOD ==: 8RD MOD '180deg. Grade J-55 J-55 L-80 Zone A-5 TVDe ¡PERF '" viP A-5 6 A-5,A-4 8 A-4 8 A-4 1 A-3 14 A-3 ß 10 12/2211996 RPEHr 4 91911993 ¡PERF "';119 10 12/2211996 APERF 4 919/1993 ¡PERF '~'np 180 deg. 180 deg. 6 12/22/=~996APERFI21/8" 6 12/2211996 APE V OD Latch tl TMPD MMG2 MMG2 MMG2 MMG2 C~~t i7' GLV 1.0 BK 0.156 1342 DMY 1.5 RK 0.000 0 GLV 1.5 RK 0.188 1292 DtvY D~:L~ 2.812 3.000 9~~7 .750 .992 .992 Cameo 4" TRDP-4 Cameo 'W-1' Landino Baker f"'" "HL' '0' NioDle NO GO ,,'-',,-,,,,,,, '" WUII1 KRU 1 Y -24A & 1 Y -24AL 1 Producer Proposed CTD Completion 9-5/8" 36# J-S5 casing @ 4599' 5" liner top @ 7264' MO 7" 26# L80 @ 7568' MO 2-3/8" liner top @ +/-7600' MO Top of Whipstock +1-7885' M D Cemented in Place 5"18# L-80 @ 8372' MD UIi Alaska, Inc. H. 4" 11.0# J-55 OSS-HTC tubing to surface. G. 4" Cameo 'TROP-4' SSSV set at 1793' MD, 3.312" ID I. 4" xi" Merla TMPD mandrel at 3066' MD I. 4" x 3-'12" crossover at 4893' MD F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing to crossover w/ 3-1/2" x 1-1/2" Cameo 'MMG2' mandrels C. Baker 3-1/2" FHL packer at 7193' MD with PBR/seal assembly B. 3-'12" Camco 0 nipple with 2.75" 10 at 7211' MD (may be milled outto 2.80" for CTO bits) A. 3-1/2" tubing tail at 7681' M D 3" open hole Lateral (1Y-24AL 1), TD @ 10225' md o o o o o o o 0 0 0 0 o 0 0 0 0 000 0 0 0 1--- I ConocoPhiUips Alaska, Inc. I I 1 I -~,~_._-~ Wt!:LLPATH OETJUlS PI~rt#5 1'f44A 500U2237160 Pal'OlIt Wellp!IIItJH Tie..nMO: 1Y«2:4 7870.70 ""', R." Dlrium: Nordic-2 $ITE 106.00« V.s.etkm Al'JSlI. :Z,¡U).OO" ~~,~ r¡= ~~~o 0.00 .... $@1'iOt.!ÐEtAII,.$ ... tn, WO ,"'. ..,.,. Oi,.tI.Q Tf"1t(;", Tm<get 7870.70 "',e 16Ø.02: 5873.3$ .4e4J.33 12;:13.96 0,00 MO ~ij 7&ßOO 3ff.62 1/UMI'$ ....... .4650.1& 1U1A.S ~.. 1~: 3 7:$05.00 32:,1& 131,14 ""~'" .4\1fI(!.02 12$4.ì:I$ MO 4 """'.. 41.$Ø 181.70- 5934.81 -" 1287.81 "'.. .~.. , ."""" %,00 231.'HI- 6007.80 47$0.54 U#.5:t "'... n.., .2ß3Ø.8i · ì:lUa,$ .~'" 2&1.11:5 _... -4&01.31 1125..03 "'.. ....., ~1$4U"7 7 ....." 94;'13- 2$2:'.4' ~~~:: ::~~::: 1-0.46.$1 "".., ..,.., -18&2.$3 · MO:?35 iIØ,tIIi 310,15 9i§.29 12.00 100.00 --17U,i'ln- · &72/1;35 11C1'.$2 Vi.iS SMO.16 4ßOi,6.0 62i.05 12.00 27(f.4í) ·U-1D¡I16 ,. 8.97-3.35 ..... 301.14 6Otn'.4tõ 4u.n 383.66 ,~.., $1.öO _1164,114 " 9U3<;35 90-.25. 28$.14 ......" ......" 12Ut5 ,~.., v-ø.oo. -.. " 9SU,U ..... 301,14 ......" -439$.88 ~&:Ó~ 12,00 91.(10 ....... " $81W.OO ...." 262,54 SO)!J.$ -4;t30.92 ,~... 211,(10 ·~.85 ANNOTATIONS TVD fAn Amwtatioø TARGISTOÐAK$ +8* Sh<>P\' ~~¡ ~~~ _ 5750-= III - U - :e 5800- Ga :> 5850- Ga _ ë 5900::' ... Plan: Plan #5 (1Y-24/Plan#51Y-24A) Created By' Azimuths to True North Magnetic North: 24.69' etic Field 57547nT gle: 80]7' ate: 612212004 Model: bggm2003 Contact .... -4400 c: i -4600 ~ -480 .... ;"-500 - J: 1:: -520 <:) ! -5400 - . - J: -560 .... :::I I:) -580 en -62 -66 I , 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 West(-)/East(+) [200ft/in] "T"']"-', ,_ i _ , : ' ¡ T:'TTT -2100 -2050-2000-1950 -1900-1850-1800-1750 -1700-1650 -1600 -1550 -1500 -1450-1400 -1350 -1300 -1250 -1200-1150 -1100-1050-1000 -950 -900 -850 -800 Vertical Section at 280.00' [50ft/in] . . B.. ..... INTEQ BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: KRU 1Y Pad North Slope Site Position: Northing: 5974755.95 ft Latitude: 70 20 31.499 N From: Map Easting: 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.24 deg Well: 1Y-24 Slot Name: KRU 1Y-24 Well Position: +NI-S 0.00 ft Northing: 5974755.95 ft Latitude: 70 20 31.499 N +E/-W 0.00 ft Easting : 531431.63 ft Longitude: 149 44 41.698 W Position Uncertainty: 0.00 ft Wellpath: Plan#5 1Y-24A 500292237101 Current Datum: SITE Magnetic Data: 6/22/2004 Field Strength: 57547 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1Y-24 7870.70 ft Mean Sea Level 24.69 deg 80.77 deg Direction deg 280.00 Height 106.00 ft Targets 1Y-24L 1 T5.4 1Y-24L 1 T5.5 1Y-24L 1 T5.3 1Y-24L1 T5.1 1Y-24L 1 T5.2 Annotation 7870.00 5872.78 TIP 7885.00 5885.69 KOP ./ 7905.00 5902.76 3 7945.00 5934.81 4 8063.35 6007.80 5 8173.35 6027.92 6 8253.35 6021.97 7 8403.35 6015.39 8 8728.35 6010.16 9 8978.35 6007.46 10 9253.35 6006.13 11 9528.35 6006.35 12 9850.00 6006.29 TO 6006.00 -4394.75 -161.07 5970361.00 531289.00 70 19 48.277 N 149 44 46.400 W 6006.00 -4313.41 -478.76 5970441.00 530971.00 70 19 49.077 N 149 44 55.676 W 6007.00 -4549.91 351.33 5970208.00 531802.00 70 19 46.751 N 149 4431.440 W 6008.00 -4807.08 1101.34 5969954.00 532553.00 70 19 44.221 N 149 44 9.545 W 6017.00 -4719.15 881.68 5970041.00 532333.00 70 1945.086 N 149 44 15.957 W . . B.. ..... INTEQ BP-GDB Baker Hughes INTEQ Planning Report 7870.70 30.65 160.02 5873.39 -4643.33 1258.96 0.00 0.00 0.00 0.00 7885.00 30.62 160.05 5885.69 -4650.18 1261.45 0.24 -0.21 0.21 153.01 7905.00 32.19 161.74 5902.76 -4660.02 1264.85 9.00 7.85 8.45 30.00 7945.00 41.68 181.70 5934.81 -4683.57 1267.81 38.00 23.73 49.91 60.00 8063.35 65.00 231.16 6007.80 -4760.54 1222.52 38.00 19.70 41.78 77.00 8173.35 94.20 261.95 6027.92 -4801.31 1125.03 38.00 26.55 28.00 50.00 8253.35 94.13 292.43 6021.97 -4791.44 1046.81 38.00 -0.09 38.10 89.00 8403.35 90.86 310.15 6015.39 -4713.90 919.29 12.00 -2.18 11.81 100.00 8728.35 90.92 271.15 6010.16 -4601.50 621.05 12.00 0.02 -12.00 270.40 8978.35 90.29 301.14 6007.46 -4532.78 383.66 12.00 -0.25 12.00 91.00 9253.35 90.25 268.14 6006.13 -4464.22 121.25 12.00 -0.02 -12.00 270.00 9528.35 89.66 301.14 6006.35 -4395.68 -141.16 12.00 -0.21 12.00 91.00 9850.00 90.36 262.54 6006.29 -4330.92 -450.05 12.00 0.22 -12.00 271.00 7870.00 30.66 160.02 5872.78 -4642.99 1258.84 5970118.74 532709.80 -2045.96 0.00 0.00 TIP 7870.70 30.65 160.02 5873.39 -4643.33 1258.96 5970118.40 532709.92 -2046.14 0.82 187.29 MWD 7875.00 30.64 160.03 5877.09 -4645.39 1259.71 5970116.35 532710.68 -2047.23 0.24 153.01 MWD 7885.00 30.62 160.05 5885.69 -4650.18 1261.45 5970111.56 532712.44 -2049.78 0.24 153.00 KOP 7900.00 31.80 161.33 5898.52 -4657.51 1264.02 5970104.24 532715.03 -2053.58 9.00 30.00 MWD 7905.00 32.19 161.74 5902.76 -4660.02 1264.85 5970101.73 532715.88 -2054.84 9.00 28.90 3 7925.00 36.52 172.84 5919.28 -4671.00 1267.27 5970090.76 532718.34 -2059.13 38.00 60.00 MWD 7945.00 41.68 181.70 5934.81 -4683.57 1267.81 5970078.20 532718.94 -2061.85 38.00 50.82 4 7950.00 42.14 184.46 5938.53 -4686.91 1267.63 5970074.86 532718.78 -2062.25 38.00 77.00 MWD 7975.00 45.37 197.41 5956.62 -4703.80 1264.31 5970057.96 532715.53 -2061.91 38.00 74.95 MWD 8000.00 49.88 208.74 5973.50 -4720.71 1257.04 5970041.02 532708.32 -2057.68 38.00 65.58 MWD 8025.00 55.36 218.53 5988.69 -4737.17 1246.01 5970024.51 532697.37 -2049.68 38.00 57.92 MWD 8050.00 61.51 227.03 6001.79 -4752.74 1231.53 5970008.88 532682.96 -2038.13 38.00 51.96 MWD 8059.18 63.90 229.89 6006.00 -4758.14 1225.43 5970003.46 532676.88 -2033.06 38.00 47.50 1Y-24L 1 8061.47 64.50 230.59 6007.00 -4759.47 1223.84 5970002.13 532675.29 -2031.72 38.00 46.18 1Y -24L 1 8063.35 65.00 231.16 6007.80 -4760.54 1222.52 5970001.05 532673.98 -2030.61 38.00 45.88 5 8063.82 65.12 231.31 6008.00 -4760.81 1222.19 5970000.78 532673.65 -2030.33 38.00 50.00 1Y -24L 1 8075.00 67.89 234.81 6012.46 -4766.96 1214.00 5969994.59 532665.48 -2023.33 38.00 49.94 MWD 8088.00 71.21 238.72 6017.00 -4773.63 1203.81 5969987.88 532655.32 -2014.45 38.00 48.54 1Y-24L 1 8100.00 74.34 242.19 6020.55 -4779.28 1193.84 5969982.19 532645.38 -2005.62 38.00 47.17 MWD 8125.00 81.02 249.11 6025.89 -4789.32 1171.61 5969972.06 532623.19 -1985.46 38.00 46.14 MWD 8150.00 87.82 255.78 6028.33 -4796.80 1147.91 5969964.48 532599.53 -1963.43 38.00 44.66 MWD 8173.35 94.20 261.95 6027.92 -4801.31 1125.03 5969959.88 532576.67 -1941.67 38.00 44.01 6 8175.00 94.21 262.58 6027.79 -4801.53 1123.40 5969959.65 532575.03 -1940.11 38.00 89.00 MWD 8200.00 94.31 272.11 6025.93 -4802.68 1098.52 5969958.39 532550.17 -1915.81 38.00 89.05 MWD 8225.00 94.29 281.63 6024.05 -4799.71 1073.80 5969961.26 532525.43 -1890.95 38.00 89.76 MWD 8250.00 94.15 291.16 6022.21 -4792.68 1049.91 5969968.19 532501.52 -1866.20 38.00 90.47 MWD 8253.35 94.13 292.43 6021.97 -4791.44 1046.81 5969969.42 532498.41 -1862.93 38.00 91.17 7 8275.00 93.67 295.00 6020.49 -4782.75 1027.03 5969978.02 532478.60 -1841.94 12.00 100.00 MWD 8300.00 93.14 297.95 6019.01 -4771.63 1004.70 5969989.05 532456.22 -1818.02 12.00 100.17 MWD 8325.00 92.59 300.91 6017.76 -4759.36 982.95 5970001.22 532434.43 -1794.47 12.00 100.35 MWD 8350.00 92.05 303.86 6016.75 -4745.98 961.86 5970014.51 532413.28 -1771.38 12.00 100.50 MWD 8375.00 91.49 306.81 6015.98 -4731.53 941.48 5970028.87 532392.84 -1748.79 12.00 100.62 MWD 8400.00 90.93 309.76 6015.45 -4716.05 921.86 5970044.27 532373.16 -1726.79 12.00 100.71 MWD 8403.35 90.86 310.15 6015.39 -4713.90 919.29 5970046.41 532370.59 -1723.89 12.00 100.77 8 · e .Ii. ..... lNTEQ BP-GDB Baker Hughes INTEQ Planning Report 8425.00 90.87 307.55 6015.07 -4700.32 902.43 5970059.92 532353.67 -1704.93 12.00 270.40 MWD 8450.00 90.89 304.55 6014.68 -4685.61 882.23 5970074.54 532333.41 -1682.47 12.00 270.36 MWD 8475.00 90.91 301.55 6014.29 -4671.98 861.28 5970088.09 532312.40 -1659.47 12.00 270.31 MWD 8500.00 90.92 298.55 6013.89 -4659.46 839.64 5970100.51 532290.72 -1635.99 12.00 270.27 MWD 8525.00 90.93 295.55 6013.49 -4648.09 817.38 5970111.78 532268.41 -1612.10 12.00 270.22 MWD 8550.00 90.94 292.55 6013.08 -4637.91 794.56 5970121.87 532245.55 -1587.85 12.00 270.17 MWD 8575.00 90.94 289.55 6012.67 -4628.93 771.23 5970130.75 532222.19 -1563.32 12.00 270.12 MWD 8600.00 90.94 286.55 6012.26 -4621.18 747.47 5970138.40 532198.39 -1538.58 12.00 270.07 MWD 8625.00 90.94 283.55 6011.85 -4614.69 723.33 5970144.79 532174.23 -1513.68 12.00 270.02 MWD 8650.00 90.94 280.55 6011.44 -4609.48 698.89 5970149.90 532149.77 -1488.70 12.00 269.97 MWD 8675.00 90.94 277.55 6011.03 -4605.55 674.21 5970153.73 532125.07 -1463.71 12.00 269.93 MWD 8700.00 90.93 274.55 6010.62 -4602.91 649.35 5970156.26 532100.21 -1438.78 12.00 269.88 MWD 8725.00 90.92 271.55 6010.22 -4601.58 624.40 5970157.48 532075.25 -1413.97 12.00 269.83 MWD 8728.35 90.92 271.15 6010.16 -4601.50 621.05 5970157.55 532071.90 -1410.66 12.00 269.78 9 8750.00 90.87 273.74 6009.83 -4600.58 599.42 5970158.38 532050.27 -1389.20 12.00 91.00 MWD 8775.00 90.81 276.74 6009.46 -4598.29 574.53 5970160.56 532025.38 -1364.29 12.00 91.04 MWD 8800.00 90.76 279.74 6009.12 -4594.71 549.79 5970164.04 532000.63 -1339.31 12.00 91.08 MWD 8825.00 90.70 282.74 6008.80 -4589.84 525.28 5970168.81 531976.09 -1314.32 12.00 91.13 MWD 8850.00 90.64 285.74 6008.51 -4583.69 501.05 5970174.86 531951.84 -1289.39 12.00 91.16 MWD 8875.00 90.57 288.74 6008.25 -4576.28 477.18 5970182.17 531927.94 -1264.59 12.00 91.20 MWD 8900.00 90.51 291.74 6008.01 -4567.63 453.73 5970190.72 531904.46 -1240.00 12.00 91.23 MWD 8925.00 90.44 294.74 6007.80 -4557.76 430.76 5970200.48 531881.45 -1215.66 12.00 91.26 MWD 8950.00 90.37 297.74 6007.63 -4546.71 408.34 5970211.44 531858.99 -1191.66 12.00 91.28 MWD 8975.00 90.30 300.74 6007.48 -4534.50 386.53 5970223.56 531837.13 -1168.06 12.00 91.30 MWD 8978.35 90.29 301.14 6007.46 -4532.78 383.66 5970225.27 531834.25 -1164.94 12.00 91.32 10 9000.00 90.29 298.54 6007.35 -4522.01 364.88 5970235.96 531815.43 -1144.57 12.00 270.00 MWD 9025.00 90.29 295.54 6007.22 -4510.64 342.61 5970247.23 531793.12 -1120.67 12.00 269.99 MWD 9050.00 90.29 292.54 6007.10 -4500.46 319.79 5970257.32 531770.25 -1096.42 12.00 269.97 MWD 9075.00 90.29 289.54 6006.97 -4491.48 296.46 5970266.20 531746.88 -1071.89 12.00 269.96 MWD 9100.00 90.28 286.54 6006.84 -4483.74 272.69 5970273.84 531723.09 -1047.14 12.00 269.94 MWD 9125.00 90.28 283.54 6006.72 -4477.25 248.55 5970280.22 531698.92 -1022.24 12.00 269.93 MWD 9150.00 90.28 280.54 6006.60 -4472.03 224.10 5970285.34 531674.46 -997.26 12.00 269.91 MWD 9175.00 90.27 277.54 6006.48 -4468.11 199.42 5970289.16 531649.76 -972.26 12.00 269.90 MWD 9200.00 90.26 274.54 6006.37 -4465.47 174.56 5970291.69 531624.89 -947.33 12.00 269.88 MWD 9225.00 90.26 271.54 6006.25 -4464.15 149.60 5970292.91 531599.93 -922.51 12.00 269.87 MWD 9250.00 90.25 268.54 6006.14 -4464.13 124.60 5970292.83 531574.93 -897.89 12.00 269.85 MWD 9253.35 90.25 268.14 6006.13 -4464.22 121.25 5970292.71 531571.59 -894.62 12.00 269.84 11 9275.00 90.20 270.74 6006.04 -4464.44 99.60 5970292.41 531549.94 -873.33 12.00 91.00 MWD 9300.00 90.15 273.74 6005.97 -4463.46 74.63 5970293.28 531524.96 -848.56 12.00 91.01 MWD 9325.00 90.09 276.74 6005.91 -4461.18 49.73 5970295.46 531500.06 -823.65 12.00 91.02 MWD 9350.00 90.04 279.74 6005.89 -4457.59 24.99 5970298.94 531475.31 -798.67 12.00 91.03 MWD 9375.00 89.99 282.74 6005.88 -4452.72 0.48 5970303.71 531450.77 -773.68 12.00 91.03 MWD 9400.00 89.93 285.74 6005.90 -4446.57 -23.75 5970309.75 531426.52 -748.75 12.00 91.03 MWD 9425.00 89.88 288.74 6005.94 -4439.17 -47.63 5970317.06 531402.62 -723.95 12.00 91.03 MWD 9450.00 89.83 291.74 6006.00 -4430.52 -71.08 5970325.61 531379.13 -699.35 12.00 91.02 MWD 9475.00 89.77 294.74 6006.09 -4420.66 -94.05 5970335.37 531356.12 -675.02 12.00 91.02 MWD 9500.00 89.72 297.74 6006.20 -4409.61 -116.47 5970346.33 531333.66 -651.02 12.00 91.00 MWD 9525.00 89.67 300.74 6006.33 -4397.40 -138.28 5970358.44 531311.79 -627.42 12.00 90.99 MWD 9528.35 89.66 301.14 6006.35 -4395.68 -141.16 5970360.15 531308.92 -624.29 12.00 90.98 12 9550.00 89.71 298.54 6006.47 -4384.91 -159.94 5970370.84 531290.09 -603.92 12.00 271.00 MWD 9575.00 89.76 295.54 6006.59 -4373.54 -182.20 5970382.11 531267.78 -580.02 12.00 271.01 MWD 9600.00 89.82 292.54 6006.68 -4363.36 -205.03 5970392.20 531244.91 -555.77 12.00 271.03 MWD e e ... ..... INTEQ BP-GDB Baker Hughes INTEQ Planning Report 9625.00 89.87 289.54 6006.75 -4354.39 -228.36 5970401.07 531221.55 -531.24 12.00 271.04 MWD 9650.00 89.93 286.54 6006.79 -4346.65 -252.13 5970408.72 531197.75 -506.49 12.00 271.05 MWD 9675.00 89.98 283.54 6006.82 -4340.16 -276.27 5970415.10 531173.59 -481.59 12.00 271.05 MWD 9700.00 90.04 280.54 6006.81 -4334.94 -300.72 5970420.21 531149.12 -456.61 12.00 271.06 MWD 9725.00 90.09 277.54 6006.78 -4331.02 -325.40 5970424.04 531124.42 -431.61 12.00 271.05 MWD 9750.00 90.15 274.54 6006.73 -4328.38 -350.26 5970426.56 531099.55 -406.68 12.00 271.05 MWD 9775.00 90.20 271.54 6006.66 -4327.06 -375.22 5970427.79 531074.59 -381.86 12.00 271.05 MWD 9800.00 90.25 268.54 6006.56 -4327.04 -400.22 5970427.70 531049.59 -357.24 12.00 271.04 MWD 9825.00 90.31 265.54 6006.44 -4328.33 -425.18 5970426.31 531024.64 -332.88 12.00 271.02 MWD I 9850.00 90.36 262.54 6006.29 -4330.92 -450.05 5970423.61 530999.79 -308.85 12.00 271.01 TO lit. , J. e e BOP-Tree ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: KB Elevation Well Rig Floor 1ª,,:®þQp~¡ tŒ:M¢i@(¡ð.#.êjMg~MijijêBa¡ikD.6iØhMt .. 1I!:1!"\\'i!1!!!íIllÆI~,*H8~;:1 ..................... 4-----J I ....,.,::::I:::·,·:.:'::::::::::.,......; 17jh@'~~MB*4~ ...... 1#4Ji;ìrJi4IN~Ÿ#./' .... ~~~~liliRi~~i~_~I}~: tþ Swab Valve Tree Size SSV I Master Valve Base Flange Page 1 1 ~ ConocoPhillips e ¿ST e- v r:= Post Office Box 100360 Anchorage, Alaska 99510-0360 Mike Mooney Phone (907) 263-4574 Fax: (907) 265-1535 July 8, 2004 JUl 0 9 1004 Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Amendment for application for Spacing Exception, producer 1Y-24A L 1 and L2 Dear Commissioner: This amendment provides information that was omitted in the original application for Spacing Exception for producer 1Y-24A L 1 and L2. The original application did not include bottom hole locations for the two laterals at the point where they intersect the interval to be produced or the TO of the legs. Following is a list of bottom hole location information for 1 Y -24A L 1 and L2: 1Y-24: Surface Location 570 FNL, 1762 FWL, Sec. 1, T11N, R9E, U.M. (Y~'fll Leg 1: Top of Productive Interval TO 5237 FNL, 2274 FEL, Sec. 1, T11N, R9E, U.M. 4899 FNL, 3982 FEL, Sec. 1, T11 N, R9E, U.M. I JZJ(AL ( Leg 2: , Top of Productive Interval TO 5240 FNL, 2274 FEL, Sec. 1, T11N, R9E, U.M. 1705 FNL, 2053 FEL, Sec. 12, T11N, R9E, U.M. If you have any questions or require any further information, please contact Nick Pysz at 265-6831. Sincerely, MJd Mike Moon~ GKA Wells Supervisor 1 conoc~iIIiPS e Post Office Box 100360 Anchorage, Alaska 99510-0360 Mike Mooney Phone (907) 263-4574 Fax: (907) 265-1535 July 8, 2004 Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 JUL 0 9 2004 Re: Application for Spacing Exception, producer 1Y-24A L 1 and L2 Dear Commissioner: ConocoPhillips Alaska, Inc. as sole Operator of the Kuparuk River Unit, applied for a spacing exception in accordance with 20 AAC 25.540 on June 29, 2004. In accordance with this rule, notification was sent via certified mail on June 29, 2004 to the Owners and Landowners described below: Owners: BP Exploration Alaska 900 E. Benson Blvd. Anchorage, Alaska 99508 Chevron U.S.A. Inc. 11111 So. Wilcrest Drive Houston, Texas 77099 ExxonMobil Alaska Production, Inc. 3301 'C' Street Suite 400 Anchorage, Alaska 99519 Union Oil Company of California 909 W. 9th Avenue Anchorage, Alaska 99501 Landowners: Alaska Department of Natural Resources Division of Oil and Gas 550 West th Avenue Suite 800 Anchorage, Alaska 99501-3560 Operators: ConocoPhillips Alaska Inc. 700 G Street Anchorage, Alaska 99501 In addition to the notification letter, an amendment to this notification was sent via certified mail on July 9, 2004 to the Owners and Landowners stated above. This amendment included pertinent bottom hole location information not included in the original notification. Please find attached for the review of the Commission the copy of this amendment as required by 20 ACC 25.005 (d). If you have any questions or require any further information, please contact Nick Pysz at 265-6831. Sincerely, MonØ~ GKA Wells Supervisor · e Mike Mooney Wells Group Team Leader Drilling & Wells \ ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 8, 2004 J. MacArthur Union Oil Company of California 909 W. 9th Avenue Anchorage, Alaska 99501 JUL (I 2004 Dear Mr. MacArthur: RE: Notice of Amendment for Exception to the Provisions of 20 AAC 25.055(d) for the Kuparuk well 1 Y -24L 1 and L2 Pursuant to the requirements of 20 AAC 25.055(d), ConocoPhillips Alaska, Inc. hereby gives notice of an amendment to the request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055(d). A copy of the request to AOGCC is attached. Sincerely, (j ðt::Jy Wells Group Team Leader CPAI Drilling MM/skad . . Mike Mooney Wells Group Team Leader Drilling & Wells '\ ConocóPhiiii ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 8, 2004 BP Exploration Alaska, Inc. 900 E. Benson Boulevard Anchorage, Alaska 99508 o 9 7004 Attention: D. Nicolson Dear Mr. Nicolson: RE: Notice of Amendment for Exception to the Provisions of 20 AAC 25.055(d) for the Kuparuk well 1 Y -24AL 1 and 1 Y -24AL2. Pursuant to the requirements of 20 AAC 25.055(d), ConocoPhillips Alaska, Inc. hereby gives notice of an amendment to the request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055(d). A copy of the request to AOGCC is attached. Sincerely, I4(M~ M. Mooney Wells Group Team Leader CPAI Drilling MM/skad · Aike Mooney ~ells Group Team Leader Drilling & Wells .. ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 8, 2004 J. P. Williams, Jr. ExxonMobi Alaska Production, Inc. 3301 'C' Street Suite 400 Anchorage, Alaska 99519-6601 Dear Mr. Williams: RE: Notice of Amendment for Exception to the Provisions of 20 AAC 25.055(d) for the Kuparuk we1l1Y-24L 1 and L2 Pursuant to the requirements of 20 AAC 25.055(d), ConocoPhillips Alaska, Inc. hereby gives notice of an amendment to the request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055(d). A copy of the request to AOGCC is attached. Sincerely, )), !I/~ M. Mooney Wells Group Team Leader CPAI Drilling MM/skad . .ike Mooney ells Group Team Leader Drilling & Wells . ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 8, 2004 Chevron U.S.A. Inc. G. M. Forsthoff 11111 So. Wilcrest Drive Houston, Texas 77099 Dear Mr. Forsthoff, RE: Notice of Amendment for Exception to the Provisions of 20 AAC 25.055(d) for the Kuparuk well 1 Y-24AL 1 and L2 Pursuant to the requirements of 20 AAC 25.055(d), ConocoPhillips Alaska, Inc. hereby gives notice of an amendment to the request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25.055(d). A copy of the request to AOGCC is attached. Sincerely, !M~::;> Wells Group Team Leader CPAI Drilling MM/skad TERRIE L HUBBLE BP EXPLORATIONAK INC PO BOX 196612 MB 7"5 ANCHORAGE, AK 99519-6612 89-6/1252 123 "Mastercard Check" . 6~5~~N~~~~G First National Bank Alaska ::::rage, AK 99501 /fO~ ~ DATE 07-oA-O~ $ JCX), òD DeLLAnD .: ~ 2 5 20 00 b 0 .: ~ ~ ~... III b 2 2 ? II' It 5 5 b ,,- 0 It 2 :1 . . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER K/2¿( Ic;~¿t/A 2Dc./-- / ¿~ WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new weIJbore segment of LATERAL existing well . Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function' of the original API number. stated are between 60-69) above. Pn.,OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to / perforate and produce is contingent upon issu~nce of a conse,¡ation o~er appro~ ¡; f spaclDg exception. ''-'''''D t:.CJ IA (Companv Name) assumes tbe liability of any protest to tbe spacing . e:ICeption tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. , ~ Rev: 07/10/02 C\jody\templates Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1Y-24A Program DEV Well bore seg D COPHILLlPS ALASKA INC Initial ClasslType ----.l:LEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D Administration fee ¡¡ttaçt¡e_d _ _ _ _ _ _ - - - - - Y~s _ - - - - - 2 le¡¡s_e_number _apRropriate_ _ _ - - - - - - Xes_ Entire wellin ADL 02_5646 - - - -- 3 _Unique weltnarn~_and Ol!.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ - _ _ - - - - - - - - - Y~s __ - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - -- . ~ - - - - - 4 WellJQcat~d lnad_efineøpool _ _ - - - - - - - - - - - Y~s KRU Kuparu_k_Riv_er Oil PooJ, .9o\lerned by Cons~(Vation Qrder No._ 4_326 _ _ _ _ 5 WellJQcat~d proper distance from drilling unitb_ound_ary_ _ _ - - - - - Xes - - - - - 6 WenJQcat~d proper _distance_ from otber weUs_ No_ _ SRaclng exception re_quire_d; Horizwltatsjdetr¡¡c_k; well bore wilt beJesJ; th_an1 OOOfeet from 1 Y -07._ 7 _S!Jtficient acre¡¡~e_ay¡¡ilable lndrillio~ unjL _ _ _ _ _ - - - - - _ _ No_ SRa~ing exceRtlon re_quire_d; 20d welUn two _qu¡¡rt_er sectiQnJ> aod 3rd well in aOQtber çuarter ~eçtjon. 8 Jtd~vi¡¡ted, js weJlbQre plaUncJuded _ _ _ _ _ _ Y~s_ - - - - -- 9 _Operator only ¡¡ffeçted party _ _ - - - -- xes_ - - - - - - - - - - - - - - - - - - - 10 _Operator bas_appropriate-'~9nd inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _Y~$ - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P~rmit c_an be issued wHbQut conservation order _ _ _ _ No - - - - - - - - - - Appr Date 12 p_ermit can be issued wjtbQut administratÏ\¡e_approvaJ _ Xes_ - - - - -- - - - - - - - - - - SFD 7/12/2004 13 Can permit be approved before 15-day wait Yes .. 14 WellJQcat~d within ¡¡rea ¡¡ndstrataauthorized by Injectioo Order # (putlO# incomrn_ents) (For_ NA _ - - - - - - - - - - 15 AJI weUs_wit]1ln Jl4JDile_area_of reyiew jd~ntified (For ~ervjc_ewell only>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; øurationof pre-productionl~ss_ than 3 montbs_ (For_se(Vlce well QnJy) _ _ NA - - - - - - - - -- 17 ACMP findjngof CQnsistency_h_as bee_ni~sued for tbis proieçÌ - - - - - NA. Sidetrack of _e~isting w~IJ. _ _ . - - - - - - - - - - - - - - - - - -- Engineering 18 _C9nductor stringprQvided _ . _ _ _ . . - - - - - - - - - - - NA CQndUGtQrinstaJled_ inJY-2A-<193:072), _ _ - - - -- 19 _Surfaceca~ingpJotects all_known_ USDWs . - - - - - - - - - - -- NA _ AI! aquifers ex_ernpt~d 40 cm 147_.103(b)(3), . - - - - - - 20 _CMT vol adeq u ate_ to circ_ulate o_n _cood_uçtot & surf CJ>g _ . - - - - - NA. Surface casing inJ>talJe_din1,{-24. _ . - - - - -- - - - - - - - -- 21 _CMT v_oj adequ_ate to tie-inJQngstring to_surf çsg_ . NA E'roductiQn_casing install_ed in_ ty-24, . . - - - - - - - - - - - 22 _CMTwiIJ coyeraJl know_n_productiye bQri~ons_ _ . - - - - - No Slotte_dJiner _completion planneø. Production ca_sing aod liner_ cerneoted as_ required on 1,{-24. _ 23 Casing de_signs ad_eçua_te for C,_T~ 6_&_perroafros! - - - - - Y~s. - - - - - - - - - 24 _Mequatet¡¡nJ<age_oJ reserye pit. - -- .. Y~s Rig jsequipRe_dwith st~elpits.. No_ reseJ\le_pjtplanned, All waste to_Class JI weUs_. _ . 25 JfaJe-drilt has a_ 10-403 fQr abandonment be~n apPJQved _ . . Y~s. 3Q4:2_61 . - - - - -- 26 Adequate-,f"ellbore separatjon_proppsed _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es __ Pro>.dmity, analysis performe_d< _1Y-W 215~ distalJLatTD within_ r~ser\(ojrc _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jfdjverter req!Jired, dQes it meet reguJations_ _ _ _ . NA Appr Date 28 _Drilliog fJujdprOgTam schematic&e~uipJi$tadequat~_ _ . - -- _ _ Yes SHE' expected at9c8_EMW._ Plao to_u_se dynamic.0Yerbalance with 9 ppgftuiøand 500_p_si at surface. _ . . TEM 7/13/2004 29 BOPEJ>,dothey meet r~guJation . - - - - Y~s. - - - - - - - - - - - - - -- - - - - - - - - - . 30 _BOPEpress rating appropÖate;test to (puJ psig in_comments)_ _ . . Y_es_ Res~(Voir MASP çalcuJaJeda_t 2535 PJ>t MASPcircuJating 3400 psi. 4500 psLBQP_ test planned_ 31 C_hokeroanjfold çQmpJies w/APIR~-53 (May 84)_ _ . . Y~s - - - -- - - - - - - - - - -- - - - - - 32 WQrk will OCCUr withoutoperatjonshutdown_ . Yes _ - - - - - - - - - - - - - - - - - - - - - - 33 J~ presence_ Qf H2S gas_ prOQable . - - - - -- _ _ _Yes_ 60_ Rpm H2S_ prod_uced_ Qn_1Y_p_ad. Mud sh_ould preçlude_H2S Qn_rig._ Rig_equippeø wjtb senJ;ors aod alarrnJ>. 34 Me~ba_nicalcondition of wells within AOR yerified (for_service welJ only) _ _ NA. - - - - - - - - - - - - - - Geology 35 P~rmit can be iSSl!.ed wlQ hydrogen s_ulfide me¡¡SureJ> _ - - - - - - No_ Parent welJ bOJe (KRUJY-2A) meas!Jred ßO PRro H2S on 8/5/02. 36 _Data_presented on Rote_ntial overRressur~zoneJ>. Xes_ Expected r~ser\(ojr pre,SsuJe is _9<8 - 1 O.D ppg EMW; wiJI Þe drilled with GoHed_ tubin~ and. 9..0 PP.9_nJud, Appr Date 37 SeiJ;mic_analysis_ Qf shaJlow gaszooes NA - - - - - SFD 7/12/2004 38 S~abedcondjtioo survey _(if off-shore) _ . .. NA - - - - - 139 _ CQnta_ctnamelp]1oneJorVt(e~lsly progressJeports [exploratory _onlYl . NA - - Geologic Date: Engineering Public Commissioner Commissioner Date Commissioner Date D/s 7//3/1- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, int'ormation of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of information. . . **** REEL HEADER **** MWD 06/04/05 BHI 01 tþ)7l~~ LIS Customer Format Tape **** TAPE HEADER **** MWD 23/03/06 737190 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg .las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 7881.5000: STOP.FT 9918.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 01 TOWN.N 11N RANG. 09E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 52 DMF KB EKB .F 52 EDF .F N/A EGL .F 0 CASE.F 7881.5 OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value ConocoPhillips Alaska Inc. 1Y-24APB1 Kuparuk River Unit 70 deg 20' 31.499" N 149 deg 44' 41.698" W North Slope Alaska Baker Hughes INTEQ 2.375" NaviGamma - Gamma Ray 20-Aug-04 50-029-22371-70 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~o L{ -I ;t~-: . . (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are realtime data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub,a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit),a Gamma and Directional Sub, and a Hydraulic Orienting Sub, with a Near Bit Inclination Sensor. (6) Data presented here is final and the Inteq MWD GR is the primary depth control data for this well. (7) The sidetrack was drilled from 1Y-24 through a milled window in 5" liner. Top of Window 7874 ft. MD (5876.2 ft TVD) Bottom of Window 7881.5 ft. MD (5882.7 ft. TVD) This wellbore, 1Y-24APB1, was drilled through a casing window approximately 18 ft MD deeper than the casing window used for the final wellbore, 1Y-24A. (8) The interval from 9890 ft. to 9918 ft. MD (5999.8 ft. to 5995.9 ft. TVD) was not logged due to bit to sensor offset. (9) Tied to 1Y-24 at 7678 ft. MD (5711 ft. TVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips Alaska Inc. 1Y-24APB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final and the Inteq MWD GR is the primary depth control data for this well. *** INFORMATION TABLE: CIFO . . MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 49 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7881.500000 9918.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 58 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN raw.xtf 150 ConocoPhillips Alaska In lY-24APBl . . FN COUN STAT Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! 11!!! 1! 1! 1 1!! 1! 1! 1 Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX MWD ROPS MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 97 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7881.500000 9918.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 106 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 23/03/06 737190 01 . **** REEL TRAILER **** MWD 06/04/05 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . Tape Subfile 2 is type: LIS DEPTH 7881.5000 7882.0000 7900.0000 7950.0000 8000.0000 8050.0000 8100.0000 8150.0000 8200.0000 8250.0000 8300.0000 8350.0000 8400.0000 8450.0000 8500.0000 8550.0000 8600.0000 8650.0000 8700.0000 8750.0000 8800.0000 8850.0000 8900.0000 8950.0000 9000.0000 9050.0000 9100.0000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9700.0000 9750.0000 9800.0000 9850.0000 9900.0000 9918.0000 GR 105.9400 109.2100 102.3300 137.0200 121.8600 153.3000 87.5200 49.6600 101.8300 85.0500 88.2400 97.4900 94.6200 69.2383 63.0100 88.2014 103.8700 146.1800 140.9200 136.7200 97.6700 48.4367 64.1700 46.4500 73.2900 74.5300 79.3500 91.2100 90.7100 89.7500 85.0700 78.3900 74.9600 111.8700 124.9700 120.8300 122.1400 97.1000 77.5900 83.9400 72.0300 83.8400 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units . ROP -999.2500 -999.2500 78.4000 25.5600 16.9900 34.4200 51.1000 108.0000 106.5200 91.5200 114.5500 111.3600 112.4400 125.3300 126.1100 124.9200 102.8200 65.9100 39.1000 53.4700 92.2900 54.9000 96.5900 30.1800 98.5800 94.5400 93.8400 104.5800 126.9300 95.2400 95.4200 106.6800 132.8000 115.1900 100.9700 93.4100 68.5300 128.5100 143.8700 122.1600 119.3800 115.8500 76.3400 -999.2500 7881.500000 9918.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 7881.5000 105.9400 -999.2500 7881.7500 107.5750 -999.2500 7900.0000 102.3300 78.4000 7950.0000 137.0200 25.5600 8000.0000 121.8600 16.9900 8050.0000 153.3000 34.4200 8100.0000 87.5200 51.1000 8150.0000 49.6600 108.0000 8200.0000 101.8300 106.5200 8250.0000 85.0500 91.5200 8300.0000 88.2400 114.5500 8350.0000 97.4900 111.3600 8400.0000 94.6200 112.4400 8450.0000 69.2383 125.3300 8500.0000 63.0100 126.1100 8550.0000 88.2014 124.9200 8600.0000 103.8700 102.8200 8650.0000 146.1800 65.9100 8700.0000 140.9200 39.1000 8750.0000 136.7200 53.4700 8800.0000 97.6700 92.2900 8850.0000 48.4367 54.9000 8900.0000 64.1700 96.5900 8950.0000 46.4500 30.1800 9000.0000 73.2900 98.5800 9050.0000 74.5300 94.5400 9100.0000 79.3500 93.8400 9150.0000 91. 2100 104.5800 9200.0000 90.7100 126.9300 9250.0000 89.7500 95.2400 9300.0000 85.0700 95.4200 9350.0000 78.3900 106.6800 9400.0000 74.9600 132.8000 9450.0000 111.8700 115.1900 9500.0000 124.9700 100.9700 9550.0000 120.8300 93.4100 9600.0000 122.1400 68.5300 9650.0000 97.1000 128.5100 9700.0000 77.5900 143.8700 9750.0000 83.9400 122.1600 9800.0000 72.0300 119.3800 9850.0000 83.8400 115.8500 9900.0000 -999.2500 76.3400 9918.0000 -999.2500 -999.2500 Tape File Start Depth 7881.500000 Tape File End Depth 9918.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . # Tape Subfile 4 is type: LIS . . **** REEL HEADER **** MWD 06/01/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/10/10 737190 01 2.375" CTK jJ3R6\ *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!! !!!!!! !!!!! Remark File Version 1.000 Extract File: ldwg.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame -Well Information Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 7651.0000: Starting Depth STOP.FT 9785.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMPo COMPANY: ConocoPhillips Alaska Inc. WELL. WELL: 1Y-24A FLD . FIELD: Kuparuk River Unit LOC . LOCATION: 70 deg 20' 31.499" N149 deg 44' 41. 698" W CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" NaviGamma - Gamma Ray DATE. LOG DATE: 10-0ct-04 API . API NYUMBER: 500292237101 -Parameter Information Block #MNEM.UNIT Value Description #--------- ------------------------- ------------------------------- SECT. TOWN.N RANG. PDAT. EPD .F 01 UN 09 MSL o Section Township Range Permanent Datum. Elevation Of Perm. Datum. 9..ö ~ -/ À ~- . . LMF . RKB FAPD. F 106 DMF KB EKE .F 106 Bushing EDF .F N/A Floor EGL .F 0 Level Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Elevation of Derrick Elevation of Ground CASE.F OSl . -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub, With a Near Bit Inclination Sensor (6) Data presented here is final and the Inteq MWD GR is the Primary Depth Control data for this well. (7) The sidetrack was drilled from lY-24 through a milled window in 5" liner. Top of Window 7858.0 ft. MD (5859.9 ft. TVD) Bottom of Window 7863.0 ft. MD (5866.7 ft. TVD) (8) The interval from 9757 ft. to 9785 ft. MD (6012.3 ft. to 6009.9 ft. TVD) was not logged due to bit to sensor offset. (9) Tied to 1Y-24 at 7760 ft. MD (5778 ft. TVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 7863 DIRECTIONAL Casing Depth Other Services Line 1 DISPLACEMENT Tape Subfile: 1 62 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU . . ---------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 ConocoPhillips Alaska Inc. lY-24A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!! !!!! !!! !!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per ConocoPhillips Alaska instructions, the MWD Gamma Ray is the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP ---------------------------------------------------- GRAX ROPA GR ROP 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 2 68 68 1 1 4 4 4 4 GR ROP MWD MWD AAPI F/HR ------- 8 Total Data Records: 51 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7651. 000000 9785.000000 0.500000 feet **** FILE TRAILER **** . . Tape Sub file : 2 60 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 ConocoPhillips Alaska In lY-24A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: . . Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 102 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7651.000000 9785.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 111 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/10/10 737190 01 **** REEL TRAILER **** MWD 06/01/04 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS . . Tape Subfile 2 is type: LIS DEPTH GR ROP 7651. 0000 79.0400 -999.2500 7651.5000 78.7020 -999.2500 7700.0000 90.2650 -999.2500 7750.0000 99.4950 -999.2500 7800.0000 49.7971 -999.2500 7850.0000 62.4000 -999.2500 7900.0000 128.8850 54.7300 7950.0000 118.5800 46.9800 8000.0000 114.4000 33.3500 8050.0000 141.3400 69.4300 8100.0000 130.0000 48.9600 8150.0000 147.2250 70.0400 8200.0000 126.8367 63.8500 8250.0000 61.2500 102.7200 8300.0000 48.9000 21. 3800 8350.0000 50.9000 129.1100 8400.0000 52.0600 91.9300 8450.0000 53.4100 187.1800 8500.0000 48.0233 154.8900 8550.0000 48.7200 157.9300 8600.0000 47.9300 60.2400 8650.0000 49.2300 146.9400 8700.0000 65.8700 127.2200 8750.0000 55.2450 137.2600 8800.0000 47.1100 160.1800 8850.0000 46.2260 154.1400 8900.0000 49.6775 167.1800 8950.0000 70.1233 149.3200 9000.0000 51. 5940 232.5600 9050.0000 49.6033 204.8700 9100.0000 67.8233 157.5100 9150.0000 76.5891 136.4600 9200.0000 53.2600 162.7800 9250.0000 58.9200 185.3800 9300.0000 44.4000 4.5800 9350.0000 60.7800 160.8600 9400.0000 78.8500 159.1500 9450.0000 78.8300 147.5200 9500.0000 59.6000 145.9200 9550.0000 60.7700 210.4300 9600.0000 48.3733 179.3800 9650.0000 85.9000 121.9400 9700.0000 56.2400 215.9900 9750.0000 50.7900 106.0100 9785.0000 -999.2500 -999.2500 Tape File Start Depth 7651.000000 Tape File End Depth 9785.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units feet ·. . Tape Subtile 3 is type: LIS DEPTH GRAX ROPA 7651.0000 79.0400 -999.2500 7651. 2500 78.8710 -999.2500 7700.0000 90.2650 -999.2500 7750.0000 99.4950 -999.2500 7800.0000 49.7971 -999.2500 7850.0000 62.4000 -999.2500 7900.0000 128.8850 54.7300 7950.0000 118.5800 46.9800 8000.0000 114.4000 33.3500 8050.0000 141.3400 69.4300 8100.0000 130.0000 48.9600 8150.0000 147.2250 70.0400 8200.0000 126.8367 63.8500 8250.0000 61.2500 102.7200 8300.0000 48.9000 21. 3800 8350.0000 50.9000 129.1100 8400.0000 52.0600 91.9300 8450.0000 53.4100 187.1800 8500.0000 48.0233 154.8900 8550.0000 48.7200 157.9300 8600.0000 47.9300 60.2400 8650.0000 49.2300 146.9400 8700.0000 65.8700 127.2200 8750.0000 55.2450 137.2600 8800.0000 47.1100 160.1800 8850.0000 46.2260 154.1400 8900.0000 49.6775 167.1800 8950.0000 70.1233 149.3200 9000.0000 51. 5940 232.5600 9050.0000 49.6033 204.8700 9100.0000 67.8233 157.5100 9150.0000 76.5891 136.4600 9200.0000 53.2600 162.7800 9250.0000 58.9200 185.3800 9300.0000 44.4000 4.5800 9350.0000 60.7800 160.8600 9400.0000 78.8500 159.1500 9450.0000 78.8300 147.5200 9500.0000 59.6000 145.9200 9550.0000 60.7700 210.4300 9600.0000 48.3733 179.3800 9650.0000 85.9000 121.9400 9700.0000 56.2400 215.9900 9750.0000 50.7900 106.0100 9785.0000 -999.2500 -999.2500 Tape File Start Depth 7651.000000 Tape File End Depth 9785.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units teet . . . Tape Subfile 4 is type: LIS