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200-047
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-137 KUPARUK RIV U WSAK 1D-137 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/09/2022 1D-137 50-029-22956-00-00 200-047-0 W SPT 3527 2000470 1500 740 740 740 740 4YRTST P Austin McLeod 10/10/2022 MITIA. Monobore 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1D-137 Inspection Date: Tubing OA Packer Depth 175 1840 1715 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221010185444 BBL Pumped:0.8 BBL Returned:0.7 Friday, December 9, 2022 Page 1 of 1 5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) &3) Q#FRQRFRSKLOOLSVFRP! 6HQW 0RQGD\-XO\ $0 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW .58'3DGQRQZLWQHVVHG0,7,$V $WWDFKPHQWV 0,7.58'3$'6,7(676[OV[ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001900 Type Inj N Tubing 580 585 585 585 Type Test P Packer TVD 5977 BBL Pump 2.1 IA 145 1800 1770 1770 Interval 4 Test psi 1500 BBL Return 2.1 OA 43 54 54 54 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001830 Type Inj N Tubing 150 160 160 160 Type Test P Packer TVD 3626 BBL Pump 0.3 IA 380 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 0.3 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1972400 Type Inj N Tubing 100 1800 1740 1730 Type Test P Packer TVD 3621 BBL Pump 1.7 IA 25 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.6 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000470 Type Inj N Tubing 500 505 505 505 Type Test P Packer TVD 3526 BBL Pump 0.8 IA 140 1800 1700 1690 Interval 4 Test psi 1500 BBL Return 0.5 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1D Pad Galle / Borge 07/14/22 Notes: Notes: 1D-40A 1D-101 1D-137 Notes:Single casing well 1D-106 Notes:Single casing well. Tubing plug at 4444' MD. Open Pocket at 4286' MD. CMIT T x IA. Notes:Single casing well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0714_MIT_KRU_1D-pad_4wells 9 9 9 9 9 9 9 9 - 5HJJ 1D-137 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~-~' ~¢7 Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) rn~ems: o Diskettes, No. o Maps: ~' Grayscale items: o Other. No/Type o Other items scannable by large scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds PAGES:J/")~ [] Other TOTAL NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL DATE: ~ ISl ~ Project Proofing PROOFED BY: BEVERLY BRE~RYL MARIA LOWELL DATE: Scanned (done) [] Staff Proof By: Date: Isl ~ PAGES: (at the time of scanning) SCANNED BY~ BEVERLY BREN VINCEJ~,3;'~~ARIA LOWELL DATE: /si RESCANNEDBY: BEVERLY BREN~I~HERYL MARIA LOWELL General Notes or Comments about this file: PAGES,: Quality Checked (done) MEMORANDUM To: Jim Regg j P.I. Supervisor 1 E'~j~2 ~~,, l U FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-137 KUPARUK RIV U WSAK 1D-137 Src: Inspector NnN-CONFTDENTIAL Reviewed By^ P.I. Suprv `J Comm Well Name: KUPARUK RIV U WSAK 1D-137 Insp Num: mitRCN100718144827 Rel Insp Num: API Well Number: 50-029-22956-00-00 Permit Number: 200-047-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~WCII p T Dl i 1D-137 i ioooa7o Type Inj. TypeTest N TVD 3527 ~ IA sPT Test psi I7oo ~ ~ OA 310 1700 ~ 1640 1620 _ Interval a~TST p/F P ~ Tubing aoo aoo ~ aoo aoo Notes: ~~ ~~ (` ~ lc~ ~~~ /~:~~s. Thursday, July 22, 2010 Page 1 of 1 l"a: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907~ 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Celiper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : PraActive Diagnostic Services, lnc. Attn: Robert Q. Richey 130 West international Airport Raad Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1) Caliper Report 01,Ju1-09 2] Caliper Report 01,JuF09 t11 ~ ~ - ~-l~ J~c 2~ -c~-~ 1 D-137 1 Report / EAE 1Q139 1 Report/EDE 50-029-22958-00 ~~ 3 L ~c 2~ ~/ '~~ ~ Signed : Print Name: ~~r~~~°~'~:~% ~1;~~~ 1 '~~ ~uv~ Date : - PROACTIVE DIAGNO5TIC SERVICES, INC., 1S0 W. INTERNATtONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FNC: (907)245-88952 E-fiAAIL : ~._ _ __ ~ <-__ . - - _-. , . . .:_: GVEBSITE _,: ~ . :~ ~_...~ ~ ~:`.Documen6 and Settmgs\Owner~Desk[op\Tiansmit_Conoco.docx ~ ' ~ ~ ~ ~ Memor~ Mu~ti-Finger Gaiiper ~ Log Results Sunnmary , Company: ConocoPhillips Alaska, Inc. We)1: 9D-137 Log ~ate: July 1, 2009 Fie1d: West 5ak Log No. : 7342 State: Alaska ' Run No.: 2(MIT) API No.: 50-029-22956-00 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl1.: 20 Ft. (MDj ' Pipe1 Use: Tubing and Liner Bot. Log Intvi1.: 5,009 Ft. (MDj , Inspection Type : Buckling & Cornosive & Mechanical Damage Inspection 1 COMMENTS : i"his caliper data is tied into the DS Nipp/e ~ 4,881' (Driller's Depth). ' This log was run to assess the condition of the tubing and liner with respect to subsidence induced buckling and corrosive and mechanical damage. The catiper recordings indicate the 3.5" tubing aRd liner logger! are in good to poor condition, with a maximum recorded wall penetration of 85% recorded in an area of mrrosion in joint 156 (4,996'). Recorded damage appears as isolated pitting and corrosion. No significant areas of ' cross-sectional wall loss are recnrded throughout the tubing and liner logged. Deposits are indicated in the caliper recordings from -4,840' to 5,009' (EOL), restricting the I.D. to 2.81° in joint 155 (4,964'). No other significant I.D, restrictions are recorded throughout the tubing and liner logged. A graph illustrating minimum recorded diameters on a joint-by joint basis ot the 3.5" tubing and liner logged is included in this report. ~ The caliper recordings indicate no significant buckling throughout the 3.5" tubing and liner logged. A log plot of the centered and off-centered caliper recordings from surtace to 1,000' is included in this report. ' This is the second time a PDS caliper has been run in this well and the first time this 3.5" tubing has been logged. The weltbore schematic indicates a change of tubing on December 23, 2005. 3.5" TUBING 8~ LINER - MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 55%) Jt. 156 ~ 4,996 Ft. (MD) Isolated Pitting ( 46%) Jt. 154.3 @ 4,944 Ft. (MD) Corrosion ( 45°~) Jt. 155 @ 4,975 Ft. (MD) Isolated Pitting ( 26°/a) Jt. 45 @ 1,44'1 Ft. (MD) Corrosion ( 22%) Jf. 153 ~ 4,85Q Ft. (MD) 3.5" TUBING 8, LINER - MAXIMUM RECORDED CROSS-SECTIDNAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing and liner logged. 3.5" TUBIIdG &~ LINER - MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.81" Jt. 155 @ 4, 964 Ft. {MD} No other significant I. D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: C. Fitzpatrick ProActive piagnostic Services, Inc. j P.O. Box 13n9, Stafford, TX 77497 Phane: (281) or {888) 565-9085 Fax: (281) 5b5-1359 E-mail: PDS,cumemorylcg.cam Prudhae Bay Field Office Phone: (907} 659-2307 Fax: (407) 659-2314 UzG 2~ - a~l ~- 1 ~s ~~3 • . PDS Multifinger Caliper 3D Log Plot ~_~_ Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 1D-137 Date : July 1, 2009 Description : Detail of Centered and Off-Center Caliper Recordings from Surface to 1,000' Depth Max I.D. (1N000 in.) 1ft:750ft 2500 3500 0° Min I.D. (1N000 in.) 2500 3500 Nominal I.D. (1/1000 in.) ~ .. ............»........................................ 2500 3500~ 0° 0° 90° 180° 270° 0°I ~ Tree . "..~ ---- Pup Jt. ~ ~ `~-_- ~ ~ ,~ ' Joint 1 ; 50 - _ . ~ .c T9'%~ ~,~ ` ~,,.~ : , Pup Jts. ' '_ ~„`~ -- ---- ...~.~...-- - -- - JoiM2 0~ . .. . . -'- ~ ;~ ~, __.; ~ ' -a,r--.a-^~-~ - _ .<..sz. ,. - . ._.',-" : _.,~,.~~, ;,..' . :,,~„ ..;~, ~ - - - , ,t."~ I Joint 3 i _ , ~, ,~_- - ,.. ;,.. ... , 150 - . - .~ointa .,, :...ri~rr~..~~: : -----~ ~ I Joint 5 ~~ , ' ~ ~,,~,~ s~~: ,, ,. :. 3'~'"` Jant 6 _ _ ~ ' ° ' `~ ~ '. ,~~:.: ~ , ~~ I I Joint 7 ZSQ ! a . ' ~ . ~.s ~ ~= i ~ ~ ~° ..aYlriY~; , _ . I I Joint 8 ~ _ i~ _ _ „~,y , ~ ,1 ~~r _ . .. ~h -':~ ~ Joint 8 300 -- - +' ~--~ " 'w " _ _~' ~~~f Joint 10 ' 50 """"° . , 3 .,, ~,~,:. , - ' 1 ~ .;:~ i Joint 11 - . - - - - . . • 400 Joint 12 . . .; , . -- -1- - t ~ ~ Joint 13 ; ,. _ _, . _ ~ , . ~ a.~.. , _ ~~ ~~ ~ 450 ~ .r~i .. ' ' • ,. , 1- _ . . . _ ~ .I ' 'R " ~.~z°` ~. .:: .. Joint 14 _ ~ . _ ; ? ._" ,' _ i i ~~ 5 0 ~~ Joint 16 0 ' ~ c.> _. . Joint 16 50 , _-'- ' _ 's; - - ~ -- f- Joint 17 - - i ' i Joint 18 600 Joint 19 -+- -+ 650 ; ,.~.;~.,,. Joint 20 , ~ 1 ~ -_' Joint 27 700 Joint 22 750 Joint 23 . ;¢ _ . ~ . -- - ,,,. ~.a. - - ~- Joint 24 $0~ Joint 25 - ~- - _ = - ~~ J 26 850 "' oint ~ _,, :,.~;,, Joint 27 -- , i ` : 900 _ -~ - . Joint 28 i s:a~, ~:,..: Joint 29 950 _ _- . -: _ ~ Joint 30 ~ _ Joint 31 _-~ _ _ _ ,_ . _ ,_ Nominal I.D. (1N000 in.) i .. ...................................................... 2500 3500~ Min I.D. (1/1000 in.) 2500 3500 Comments Depth Max I.D. (1N000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750ft 9-`~.~e_..~.~.._~~ 2500 3500 0° 90° 180° 270° 0° 0° 90° 180° 270° 0° ~ • Correlation of Recorded Damage to Borehole Profile ^ Pipe 1 3.5 in (19.4' - 4981.9') Well: 1 D-137 Field: West Sak Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 1, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 25 25 803 50 t 1588 ~ ~ ~ 75 . 2378 • E " ~ .~ z t ~ ' ~- °J o ~ 100 3168 125 3951 15( ~ r 472 9 GLM 1 156 4982 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 156 . • ~~~ Minimum Diameter Profile Well: 1 D-137 Survey Date: luly 1, 2009 Field: West Sak Tool: UW MFC 24 No. 218370 Company: ConocoPhiilips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1.69 0.7 13 5 9 13 17 21 25 29 33 37 41 45 49 53 57 61 65 69 ~ 73 ~ 77 Z 81 = 85 •~ 89 93 97 101 105 109 113 117 121 125 129 133 137 141 145 149 152 753 154 156 _. 2.89 ~ ~ ~ ~ -1 I ~i ~ Mirrmum Measured Diameters (In.) 1.89 2.09 229 2.49 2.69 • ~ PDS Report Overview ~ ~. Body Region Analysis Well: 1 Q137 Survey Date: )uly t, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fngers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 92 f L-80 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ~ metal loss body 0 15 100 50 ~ 0 to 1 to 1`% 10'% 10 to 20 to 40 to over 20% 40% 85% 85% Number of'oints anal sed total = 166 pene loss . 17 105 63 103 37 4 3 0 0 0 0 0 Damage Con~guretion ( body ) 10 c~ ic~la[~d genoral hne ring hole ~ poss pitting corrosion corrosion corrosion ible hde Number of 'oints dama ed total = 10 7 3 0 0 0 Damage Profile (% wall) ~ penetration body ~.• metal loss body 0 50 100 0 47 97 147 GLM 1 Bottom of Survey = 156 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf L-80 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 1 D-137 West Sak ConocoPhillips Alaska, Inc. USA ~uly ~, 2009 Joint No. Jt. Depth (Ft.) Nc~n. UF,~c~t Ilns.) Pen. Body (Ins.) Pen. °~, ~Ictal I o~~ °4, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 19 ~) 0.04 14 I 2.91 UP 1 25 (~ 0.02 ti I 2.94 1.7 6 t~ 0.00 1 i 2.95 PUP 1.2 66 n 0.01 I 2.95 PUP 1.3 72 u 0.00 1 ~ ~ 2.97 PUP 2 73 ~ ~ 0.01 ' i 2.94 3 105 ~~ 0.01 ' ' 2.95 4 137 U 0.01 ' 2.94 5 169 U 0.01 4 1 2.96 6 201 ~t 0.01 2 I 2.96 7 233 t~ 0.01 4 I 2.96 8 265 ~~ 0.00 1 ' 2.94 9 296 ~~ 0.0 Z > 2.94 10 328 ~~ 0.00 1 I .96 11 360 ~~ 0.01 ? I 2.95 12 3 2 ~~ 0.01 ~ f 2.94 13 424 ~~ 0.00 1 I 2.96 14 456 U 0.01 ' I . 6 15 487 (~ 0.01 3 1 2.96 16 518 t~ 0.01 ~ I 2.95 17 550 +~ 0.01 _~ 1 2.96 18 582 (~ 0.01 1 2.95 1 613 ~ 1 0.00 1 I 2.95 20 645 ~ ~ 0.01 > ' 2.96 21 77 ~) 0.01 _' ~~ 2.94 22 709 ~ ~ 0.01 ? 2.94 23 741 i ~ 0.00 2 I 2.94 24 771 ~? 0.00 1 I 2.96 25 803 u 0.00 1 1 2.95 26 835 ~~ 0.01 2 1 2.95 27 865 i~ 0.01 ~~ ' 2.9 28 897 ~~ 0.01 Z 1 2.95 29 928 U 0.01 2 1 2.96 30 960 ~~ 0.03 12 2.95 31 991 l~ 0.00 ~ I 2.95 32 1022 i) 0.01 .? I 2.95 33 1054 O 0.01 ~' 1 2.93 34 1085 U 0.01 2 1 2.97 35 1117 t~ 0.02 8 Z 2.96 36 1148 ~) 0.01 4 ' 2.95 37 1179 ~~ 0.00 I I 2.96 38 121 1 ~) 0.00 1 I 2.94 39 1241 ~) 0.01 ~~ 1 2.94 40 1274 ~) 0.01 Z 1 2.96 41 1306 li 0.00 1 1 2.96 42 1337 ~~ 0.04 16 I 2.97 43 1369 ~ ~ .01 4 ~ .95 44 1398 ~~ 0.01 Z ~' 2.95 45 1429 U 0.07 26 Z 2.94 Isolated ittin . 46 1461 i~ 0.04 1=1 2.96 ~ Penetration Body Metal Loss Body Page 1 ' • • PDS REPORT JOINT TABULATION SHEEf ' Pipe: 3.5 in 9.2 ppf L-80 EUE 8rd Well: 1 D-137 Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. ' Nominal I.D.: 2.992 in Country: USA Survey Date: July 1, 2009 Joint No. Jt. Depth (Ft.) I'~•n. i 1~ ~s~ ~i (In~.) Pen. Body (Ins.) I'c~n. % M~~t,il I o5~ °/~ Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 47 1492 ~ ~ 0.01 ~ ~ 2.96 48 1524 U 0.01 ~ 1 .95 49 15 6 (~ 0.01 -~ ' 2.95 50 1588 t~ 0.01 2 ? .94 1 1620 t~ 0.00 1 I 2.96 52 165 t) 0.01 _' 2.97 53 1683 ~~ 0.05 ' I ~ .94 Isol te 'tti . 54 1715 u 0.04 1: ' 2.97 55 1746 U 0.02 ~) _' 2.95 56 17 8 ~1 0.05 't I 2.94 solated ittin . 57 1810 ~ ~ 0.05 1 ~) _' .95 58 184 U 0.01 4 ~ 2. 59 1874 U 0.01 2 I 2.96 60 1906 ~~ 0.05 1 El _' .97 61 19 8 t~ 0. 5 2U ; 2.95 62 1968 (~ 0.01 1 I 2.94 63 1999 ~~ 0.03 1~ I 2.93 64 2031 U 0.04 4 ' . 3 65 2063 O 0.02 9 1 2. 6 66 2095 t? OA 9 ~ .95 67 2127 t~ 0.02 ~~ 2 2.94 68 2159 U 0.01 ti 1 2.95 69 2190 c 1 0.03 1 U ~' 2.95 70 2222 ~~ 0.03 11 ~ 2.95 71 2253 t~ 0.02 9 ? 94 72 2284 ~a 0.02 ~~ _' 2.95 73 2316 ~~ 0.01 ~ ~' 2.93 74 2347 t? 0.01 i ~' 2.95 7 237 U 0.01 -l ' .94 76 2411 ( ) 0.01 ~' ? 2.95 77 442 l t 0.01 4 2 .95 78 2473 t) 0.01 2 1 2.92 9 2504 l) 0.01 4 ~' 2.95 80 2534 l1 0.01 Z ~' 2.96 81 2566 U 0.02 ~~ ~' 2.96 82 2598 n 0.01 5 ~' 2.96 83 2629 u 0.01 -~ _' 2.96 84 2660 ~~ 0.00 1 I 2.95 85 2693 l~ 0.00 1 I 2 6 86 2725 U 0.01 ~' 2 2.95 87 2757 U 0.01 Z 1 .95 88 2788 tl 0.01 ~~ 2 2.95 89 2819 ~) 0.01 4 ~ 2.95 90 2851 ~~ 0.03 1 I S 2.95 91 883 tt 0.02 ~~ I 2.93 92 2915 ~~ 0.01 ~' 2.95 93 947 ll 0.01 4 2.94 94 2978 ~~ 0.01 _' I 2.96 5 010 (~ 0.01 2 ' . 6 96 3042 ~~ 0.02 ~> a .96 Penetra6on Body Metal Loss Body Page 2 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.2 ppf L-80 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 D-137 West Sak ConocoPhillips Alaska, Inc. USA July 1, 2009 Joint No. Jt. Depth (Ft.) f'c~n. tl~,~c~i iln;.~ Pen. Body (Ins.) f'e~n. ~„ ~1~~I,~1 I~~~ti "~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3073 ~> 0.01 4 ' 2.95 98 3105 U 0.01 5 I 2.95 99 3137 ~~ 0.01 ~' z 2.96 100 3168 ~~ 0.01 ~ I 2.96 101 3199 U 0. 2 tf ' 2.95 102 3231 « QO1 1 ~' .95 103 3263 (? 0.00 1 1 2.95 104 3294 (~ 0.03 11 ~' 2.95 105 3325 l1 0.01 ~ I 2.95 106 3354 U 0.02 9 Z 2. 3 107 3385 (~ 0.01 2 1 2.94 108 414 U OA2 ~) 1 2.95 109 3446 t) 0.02 ~~ 2.96 110 3479 ~~ 0.01 4 2.95 111 3510 U 0.03 I_3 ; 2.95 112 3541 U 0.03 I i _' 2.93 113 3573 t~ 0.02 ~~ t 2.95 114 3604 l? 0.01 1 I .96 115 3635 U 0.00 I I 2.96 116 3668 U 0.02 ~) ~~ 2.96 117 3700 tl OA2 8 _' 2.96 118 3732 u 0.02 9 ' 2.96 119 3763 t) 0.03 1 U i 2.96 120 3794 ! ~ 0.02 £t ' 2.94 1 1 3823 ~! 0.00 1 I 2.95 122 3855 ~~ 0.02 ~~ _' 2.95 123 3887 (~ 0.02 t3 2.94 124 3919 U 0.01 5 ' 2.96 125 3951 l) 0.02 E3 _' 2.95 126 3982 (1 0.03 lU ! 2.94 127 4014 ~~ 0.04 14 _' 2.96 128 4045 l) 0.04 1'> 2.95 129 4077 U 0.02 '~ 2.95 130 4109 ~ 7 0.02 ~> ; 2.96 131 4140 t~ 0.02 9 -a 2.93 132 4172 U 0.02 t9 2.95 133 4204 t~ 0.04 14 _' 2.96 134 4235 U 0.03 1O 2.96 135 4267 c~ 0.01 4 _' 2.96 136 4298 t~ 0.03 11 2.95 137 4329 t1 0.03 12 d 2.95 138 4362 t? 0.03 13 ! 2.93 139 4394 U 0.01 i s .96 140 4-42 5 t~ 0.04 1 ~ 1 2.95 141 4456 t? 0.05 2c1 Z 2.94 Isolated ittin . 142 4488 t~ 0.03 I 1 _' 2.94 143 4520 ~~ 0.04 1 t3 _' 2.95 144 4550 t i 0.04 17 _' 2.93 145 4579 l) 0.04 1 ~ ~~ 2.96 146 4611 ~) 0.05 19 ~ 2.95 Penetration Body ~ Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.2 ppf L-80 EUE 8rd Well: Body Wali: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1 D-137 West Sak ConocoPhillips Alaska, Inc. USA luly 1, 2009 )oint No. )t. Depth (Ft) I'~•n. l1E~s~~~ (ln..) Pen. Body (Ins.) f'c~n. % Mc~t,il I oss °4, Min. LU. (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4641 ~~ 0.0 1~) 2.94 148 4671 ~ 1 0.04 14 I .9 149 700 l1 0.04 15 I 2.93 150 4729 t) 0.05 ~'U ~~ 2.94 Isol ted itt n. 151 4758 U 0.05 10 ! 2.9 Isolated 'ttin . 152 4787 ~~ 0.04 17 ' 2.94 152.1 4816 l) 0.01 ! t~ 2.94 PUP 152.2 4826 U D U U N A GLM 1 Latch @ 9:00 152.3 4832 !? 0.02 i I 2.95 PUP 153 4842 c).c~3 0.06 ~2 ~ .83 Corrosion. t De os'ts. 153.1 4871 U 0.05 1 ti 3 2.83 P P Lt. s'ts. 153.2 4881 O 0 l) l) .81 Ca co D Ni le 153.3 4884 (~ 0.04 15 i 2.86 P P Lt. Ue sits. 154 4892 t1 .04 15 I 2.88 t. De osits. 154.1 4921 ~~ 0.02 fi 1 .92 PUP Lt. De sits. 154. 4927 U 0 U u 3.00 Baker Seal Asse bl 1543 4941 U 0.12 -1b 2.91 PUP To of liner. Isola ed 't6n Lt. De sits. 155 4952 ~~ ~!"- 0_11 1~ 2.81 Corrosion. De osits. 156 4982 0.14 2.86 Corrosion. Lt. De osits. Penetration Body Metal Loss Body Page 4 ~+c.;~ PDS Report Cross Sections ~w Well: 1D-137 Survey Date: July 1, 2009 Field: bbest Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Coimtry: USA No. of Fingers: 24 Tubin : 3.5 ins 9.2 t L-80 EUE 8rd Anal st; HY. Yan Cross Section for )oint 156 at depth 4995.74 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 % Tool deviation = 32 ° Finger 1 Penetration = 0.14 ins Corrosion 0.14 ins. = 55% Wall Penetration HIGH SIDE = UP ~ ~ Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections ~-~_ - ~-`'~~ ,. Well: 1D-137 Survey Date: July 1, 2009 Field: 4Nest Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size; 1.69 Country: USA ;~lo. of Fingers: 14 Tubin : 3.5 ins 9.2 ppf _ L-80 EUE 8rd Analyst: HY. YanA Cross Section for Joint 154.3 at depth 4943.513 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 33 ° Finger 22 Penetration = 0.1 16 ins Isolated Pitting 0.12 ins. = 46°/a Wall Penetration HIGH SIDE = UP C~ n U Cross Sections page 2 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ A ~ ~ ~ ~ ~ PDS Report Cross Sections ~'~ Weil: 1D-137 Survey Date: 1u1y 1, 2009 Field: b1/est Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.2 f L-80 EUE 8rd Anal st: HY. Yan Cross Section for Joint 155 at depth 4963.633 ft Tool speed = 43 Nomina~ ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 % Tool deviation = 33 ° Finger 23 Projection = -0.192 ins Deposits Minimum I.D. = 2.81 ins. HIGH SIDE = UP ~ ~ Cross Sections page 3 . KUP 1 D-137 ConocoPhillips "~ ^ ~~K .'.,, .' ~'~ r wemoae ~ 50029229 nnn~n Flea nane 5600 WESTSAK wM atetus vraaml r+e INJ RNI a rype ~nd 1'1 65.52 ~ 1~~ m h~9 fp- 2.798.&1 5.615.0 oa e an~H ~+ commd[ ~~: NO H (p NE pm 0 M~oltla~ 7/7/2008 Last W0: 12f23l2005 31.09 p s~ 5f252000 . q„ ~ e IY~aMOn Last T: CTMD 5.485.0 1119/2008 Rev Reason: FCO TAG 11l172008 C/E~ $(TI E o esa~puon Ml 1 1~1 toP 1~81 p~~ ~ PbuO Q~ T Thrd CONDUC OR 13 J7 8 12.415 0.0 110.0 110.0 68.00 H~0 WEIDED I ~~ SURFACE 512 4.950 0.0 4,934.0 3,530.9 15.50 1$0 BTCM CONWCTOR, I~ ' IJNER 312 4.950 4,934.0 ,583. 4.105.0 9.30 B CM 110 Tubin 9M s o eu,~ 1~1 1~+1 I~al {~a) 1 f~el In+nq cnae r Tna TUBING 3 12 2.992 0. 4,938.0 3,5342 9.30 L-80 EU SRD ~~ ~~~. Otl1~r I n Hok A ll J~1 : Run 8 Ratrkwab Fish etc. a.an op !~ oP (~I 1~0) Top MMP) pm~et nOb D 4.927.0 3.444.7 3.45 GA S LJFT CAMCO/KBG29/1lDMY/BT AM// Comment STA 1 12R7 2.900 4,881.0 3,488.2 36.39 NI E DS NIPPI.E 19I232006 2.9 2 4,927.0 3.5252 35.46 LOC ATOR BAKER LOCATOR 12/23/2005 2.992 4,928 0 3,526.0 35.M SEA L BAKER 8030 SEAL ASSY 12/23f2005 3.000 NiPPIE. 4 881 P~r ~O~ T een Top~7W) PdW !Yn(TVD) P~) znne oNe ~a D~re 1~- cbmoot 5,040.0 5,090.0 3,619.5 3,680.9 WS D, 1D437 7/6l'2000 4.0 IPERF I 5,127.0 5,161.0 3,867.3 3, 22.0 WS B, 10.137 7/C~12000 4.0 IPERF ~ocnTOa. ~ .170.0 5,190.0 3,729.9 9,747.3 W M, 1D-137 7/6f2000 4.0 1 F a en 5.218.0 5,282.0 3. 71.7 3,611.0 WS . 1 -137 7/1 4.0 I RF ' 5,272.0 5.290.0 3,819.9 3.827.0 S0.9.1D- 37 7/ 4.O IPER SEAL.4.818 I. ! 5,298.0 5,347.0 3,&13.1 3,887.4 WSA2, 1D-13 7l12000 4.Q IPERF ~ ~ SUFFACE._~ 9.934 IPERF, S,PW5,090 IPERF, 5.1115.181 IPERF, 5.170-5,19a ~~.~ s.siea,~es IPERF, ~ s.s~zs.zso ~ ivEaF. s~aes.aai LINER.S 383 TD. 5 615 . 9 f ~ ~ ' ~ ~ ~ ~ ~~~ ~~~ ~ ~ ~ ~~ , . ~~ ~~ ~~~~~ ~~~A~iw~ ~iar+~srac ~~tcviers, ~a~c. ro: ~a~cc Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) G59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MT'f) The technical data I+sted below +s being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive ['~iagnos~tic Senrices, Inc. Attn: Robert A. Rechey 130 West tnternatianal Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) MTT Report 16-Jurr09 1 D~136 1 Report 50-029-22955-OQ ~ 2~ ]~,MTT Report ~ ~ ~ ~ oC~ ~-C~~ (o ~~ ~ ~~U ~~ ~~~~~~~ ! 4,f ~, ~+ ~,~~ ~ ~ 1 r~ ~ ~~ ~ Signed : Print Name: 17,Jun-09 1 D~137 1 Report 50-029-22956-00 Date . . PROACTIVE DlAGNOSTIC SERVICES, 1NC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907~245-8951 Fa~c: (907~245-88852 E-MAIL : : " '- UVEBSITE : ~ %:lDocuments and Settings~Owner~esktop\Transmit_Conoco.docx ~ ' I ' ,. Log Results Summary Company: ConocoPhillips Alaska, lnc. Well: 7D-137 ~og Date: June 17, 2009 Field: Kuparuk Log No. : 10563 State: Alaska Run No.: 3(2"d MTl) API No.: 50-029-22956-00 Pipe1 Desc.: 3.5" 9.31b L-80 EUE Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 210 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 210 Ft. (MD) Pipe3 Desc.: 13.375" 68 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Gonductor Pipe Bot. Log Intvl.: 110 Ft. (MD) inspection Type : Corrosive & Mechanica/ Damage /nspection COMMENTS : This MTT data is tied into ~e Mandrel Hanger ~ 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of inetal of the 3.5" tubing and 5.5" producfion casing, as well as influence from the 13.375° conductor pipe. Passes at SHz, 8Hz and 10Hz and were made at 20 ipm, with the 5Hz and 10Hz passes selected for anafysis in this report. COMPARISON TO PREVIOUS MTT LOG RESULTS : A camparison of the current 10H~ pass to the previous 10Hz pass (September 26, 2006) indicates some areas of slight increase in overall metal loss during the time between logs. A slight increase in metal volume is indicated over the interval (0' -10'). This increase in metal volume could be a result of an added feature to the well near surface during the fime between logs. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report, while the most significant areas of inetal loss indicated in the current and previous logs are listed in the table below. I ' ~ Maarimum Metal Loss Depth 2009 2006 69' - 78' 8°l0 7% 22' - 34 . 4%0 3% 192' - 212' 4% Not Log9 57' - 58' 3% 3°l0 150' -192' 3% 1 % 136' -146' 2% 1 % Description General circumferencial metal foss ' Generai arcumferencial metal loss ed" General circumferencial metal loss ' General circumferenaal metat loss Ge~eral circumferencial metal loss General circumferencial metal loss ` 20061og entled at 192' In the 2006 log, a single calibration taken within the conductor pipe was applied to the enfire log interval. This resulted in an indication of less metal below the conductor, relative to the interval including the conductor. The current data set was processed using calibrations from both zones, eliminating the appearance of inetal loss below the conductor pipe. In order to support a more consistent comparison ProActive C~iagnostic Se~rvi~es, Inc. j P.Q. 6ax 1369, St~ffor~l, TX 7'497 Phcn~; ~2~1) Qr (~SBj 5~5-9~85 Fax: (2E1) 565-1s69 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Ph~ne: (90?) 05~-2307 Fa~c (9~7) 659-231~+ U 2 C- ,~CX~ ' f~ ~("a- ' ~' beiween the current and previous log, the previous data set has been re-processed to include a calibration reference from the zone below the conductor pipe. {NTERPRETATION OF MTT LOG RESULTS : The MTT log results cover the interval from surface to 210'. Changes in metal volume are relafive to the ' calibration points at 60' and 160', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 5.5" casing, and 13.375" conductor pipe. , Log plots of the entire 5Hz and 10Hz passes and an overiay plot of the average metal thickness recorded by the MTT for the 5, 8 and 10Hz passes are induded in this report. A ma~cimum overall metal volume loss of 8% is indicated in h~bing joint 2(69' - 78') in the 10Hz pass. ' The percent arcumferential metal loss expressed in ~is summary is a percentage of the total metal that the #ool is responding to, which includes influences from the 3.5", 5.5" and 13.375" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the ' numbers expressed. Some of the metal loss indicated could be from either the 3.5" iubing or 13.375" conductor. ' ~ ' ' Field Engineer: G. Etherton Analyst: HY. Yang & J. Burfon Witness: R. Ober PraActive Diagnostic Services, Inc. J P.Q. 6ox 1369, Staffard, TX 7?497 Phene: (Z81) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PGS~amemorylog.com ' Prudhae 8ay Field Office Phone: {90%) 659-230i' Fax: {9o?} 559-2314 u Comparison to Previous MTT Log Overlay S 1 D-137 ~,:,~ o,,,~~,~ sE.,~~~, ~~. June 17, 2009 and September 26, 2006 Database File: 1d-137.db Dataset Pathname: 1/1/1/comp Presentation Format: comparis Dataset Creation: Sun Jun 21 21:29:59 2009 Charted by: Depth in Feet scaled 1:150 -50 Defta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness 2006 (10Hz) (%} 50 0 2006 (1 20 40 60 2d09 Bottom of 13.375" 80 ~-r-I---~~ 100 120 140 160 'I 80 2006 (1 ~00 2009 (1 -50 -5a Delta Metal Thickness 2009 (10Hz) (%} Defta Metal Thickness 2006 (10Hz) (%) 50 50 J~ Colla CO~~af ubing Jt. 3 100 120 >.5" Casing Collar Tubing Jt. 4 Metal Loss ~ ~ 160 Jt. 5 5" Casing Collar Metal ' , Tubing Jt. 6 200 1 ' 4% Metal Loss -50 Delta Metal Thickness (%) 50 3 0 Line Speed (ft/min) ~00 -5.8 ' , MTTP01 (rad) MTTP12 (rad) 13 4.2 1 D-137 Recorded Magnetic Thickness Log Data - 5Hz Pass ' ~ ` " (Surface to 210') ' PwoAc~ivE ou~qnos,:c se.,ric~, ~ryc. Database File: 1d-137.db Dataset Pathname: 5HzPas.1 Presentation Format: 1.8 scale ' Dataset Creation: Sun Jun 21 10:39:40 2009 by Calc Warrior 7.0 STD Cas Charted by: ~epth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 1.8 0 LSPD (ft/min) ~00 -7 ' , ' , ~ ~ ~ _ --~ , _ -- ___ _ _ ___ ~--_ i , ~ - _~- Line Speect ~ , Tree -- ' _,. :- --~ ' ~ T ~ H ` - - ; a er ' _ --t i --- --- Casing Collar P~P - ; i; -- - ~= -- -- ,. ._ ' Tubin g Collar -- - ~ r-- 1 - - - - _ Delta Metal Thickness ' _ Tubing Jt. 1 , ~d 1 3% Metal Loss ' Tubing Co llar ~ ~ - -- ~ 5% Metal Loss ' Pup T bi C ll ~ u ng o ar . - - ~ , ' - Pup ~ i Casing Col lar Tu bing Col lar ~ ~ - ' 60 ' - Tubing Jt. 2 ' Bo ttom of 13.325" Corx luct or ' 80 Tubi Collar ~ ' I Casing Collar June 17, 2009 MTTP01 (rad) 11.8 MTTP12 (rad) 3 ' , 100 Tubing Jt. 3 120 Jt. 4 140 160 , Tubing Jt. 5 ' Casing Colla ' ubing Collar ~ ' 1 Tubing Jt. 6 ' Delta Metal ThicN , 3% Metal Loss Line S eed -50 Delta Metal Thickness (%) 50 , 0 LSPD {ftlmin) 200 ' ' ~oo 1.8 MTTP01 (rad) -7 MTTP12 (rad) 11.8 3 SHz, 8Hz and 10Hz Passes Delta Metal Thickness Overlay S 1 D-137 June 17, 2009 PwoA.czrive Diwqnosri~ Se~vicq Inc. Database File: 1d-~37.db Dataset Pathname: 1/1/1loverlay Presentation Format: comparis Dataset Creation: Sun Jun 21 22:15:40 ~009 Charted by: Depth in Feet scaled 1~150 -50 Delta Metal Thickness 2009 (10Hz) (%} 50 -50 ` Delta Metal Thickness 2009 (8Hz) (°!o} 50 -50 Delta Metal Thickness 2009 (5Hz) (%) 50 0 (10H: (8Hz} 20 40 60 Bottom of 13.375" 80 1 ~ i i i 100 120 140 160 18~ 200 -50 Delta Metal Thickness 2009 (10Hz) (%} -50 V Delta Metal Thickness 2009 (8Hz) (%} -50 Delta Metal Thickness 2009 (5Hz) (%) ~\ KUP 1 D-137 ~ ConocoPhillips w~u nn ~~s WeGboreA --- PWWIFlNUNamc We9Stal usAOMtyWN lrype Indll ~In ~) mlm~Iln-~ '~''-"' ~" ' ~ ~ S00292295600 ~EST SAK INJ PWI 65.52 2,799.84 5,615.0 . ... .. I _-_. commnt _- ____ -_-___- _ .. ----~- --~ X2S~ppm) PMe Mwatlon BMOate IB6M11ry RIgRNeaseDae ... w 1 1 1 iv1 nC R ; i ~'. SSSV: NONE 0 7/1/2008 last WO: 12l23l2005 31.09 5/252000 e On :- ~C - A , . .. t]i;:.~~ . _. - . - ' 1 Afr1U18I~011 -- DeMll ~ItKd) 9 1d D!! ATdLI~011 B14 D~! LastTag: CTMD 5485.0 11l92008 RevReason: FCOTAG 11/1t12008 Casin Strin s tasrg o esatpum SI~90D Iti) S1M~y1D MI Top rytlm) SetDepV~ IR~cel SetDqM~I7VD) (rt~l ~~9Wt IbsiM SMn Graa g e stmg Top Md CONDUC TOR 133/ 8 12.415 0.0 110.0 170.0 68.00 H-00 WEIDED SURFACE 51/ 2 4.950 0.0 4,934.0 3,530.9 15.50 L-80 BTCM coNOUCroR LJNER 312 4.950 4.934.0 5,583.0 4,105.0 9.30 L$D BTCM ~io ?Y~bin Strin s St~ing OD SMng ID SN Depl~ Set DqNh (ND) SMn9 Wt Strtn g 7uuing o esulqton (M~) (m) 7oP (111m) (rtlB) (h~) (bslf~) crad e string Top MA 7UBING 312 2.992 0.0 4,938.0 3,5342 9.30 L~0 EUEBRD ~~~FT. Other M Hole All JewNry: TUbin Run 3 R etrievable , Fish, etc. a.827 ~ op Depth ITwI Top Tap (ryl~) (~) Incl (~ p~y~ CanmeM R~n DxRC ID pn) ~ 4,827.0 3.444J 37.45 GAS LIFT CAMCOIKBG29I1/DMY/BTM/!/ Cortvnen[: STA 1 12f27/2005 2.900 4,881.0 3,4882 36.39 NIPPLE CAMCO DS NIPPIE 12/23/2005 2.912 ~ ,~ 4,927.0 3,5252 35.46 LOCATOR BAKER LOC ATOR 12Y2312005 2.992 4,928.0 3,526.0 35.44 SEAL BAKER 80-40 SEAL ASSY 12123I2005 3.000 "~~`E ° ~, perfora tlons TonI~I ~I~1 sna °ens Top~MB~ BunptKB) (Rlm) (R~) Zone Cate (sh.. rype Ca nmett 5,640.0 5,090.0 3,619.5 3.660.9 WS D, 1D-137 7/6/2000 4.0 IPERF 5,121.0 5,161.0 J,687.3 J,771.0 WS B, 1D437 7/fi2000 4.0 IPERF ~ocnroa. 5,170.0 5,190.0 3,729.9 3,747.3 WSA4, 16137 7l62000 4.0 IPERF °~~~ 5,218.0 5,262.0 3,771.7 3,811.0 WSA3, 1D-137 7/7f2000 4.0 IPERF 5,272.0 5,280.0 3,819.9 3,827.O WSAi,id137 7I1/2000 4.O IPERF sEU,a,sza 5298.0 5,347.0 3,843.1 3,887.4 V/S A2, 10.137 7!i/t000 4.0 IPERF SURFACE, 8,934 ~ ! IPERF. 5,060.5,090~ C ~ ~ ~ = ~ G ~ ~ _ IPERF, ~ 5.121-5.181 - ~ ~ _ ~ IPERF. = 5,1T65,190 - ~ ~ = IPERF. - - 5,11&5,262 ~ _ IPEFiF. ~ 5.2T2-5.380 _ = ~ IPERf. ~ -r`. ~ 529&5,341 ~ C ~ LINER,5,583 ro, s,sis Jun 14 09 G7:12p PDS Inc 1 Dri~ed tut~ing. GuLls, 8 r~ge~ with 2.8~ir~ plasi~c rab~it. t~s~rt Araic c.rade aP~ Atlvd~ed No ~eaa thr~ cmrnpC+und on aA c~t-nectior~. 7ubing 9s non-coaied. ~ # vn~~~ sor. ~f C. Heln, _ 1VOi'~'HC RK~J ~ ITIQ SGf?firYt ' ~ ' i, ~ Philtips Ai~ska ~nc_ St~bsid~arv of Atlantic Rir.l~~+J~ CamQanv ~'UBt~iG Tubirrv o~ Liner Descrip da1: 9U7 6592314 p.24 W£LE.: 1 D-13T OATE: 5123fd0 1 OF 1 PAt~S ~ tTEM~ GOM~ETE ~ESGRiPTlON OF £QUIPDRENT Rt~t~ LE~+IG'fN UEP'Ti~i _.._._ . _~-_.._ _.~ - - _ ----- - - _ NORDIG RiG~i3 RY to LOS 28.'f9 ~ ~Vetco-Gray Tbg. Nan~er W/ 3.5" EUE S~ci pup ~.84' 8~ 3ian ~er 7.U~' 4.8f3 28_79 ~ 32.9g Pups 3.5" 9.3# L-80 EUE 8rti Mod Pups 10.05 E~ 1D.fl2 20.C:7 32.89 .!t ~3-155 3.5" 9_3# L-SQ El1E 8rd Mod tbr~. 4774 _41 53.Q6 Pup 3.5" 9.3~ L-8[} EUE 8rd Mod Pu[a~ XC? ~uri mod X Eue Sox 1d.:e5 +l824.~~' G~l~ 3.5° X 1" Camco 'fC8G-2-9' wl DCK 3 Durtt~ Kilt Walve Sa'#am tatc 6J~! ~$3$.72 Pup 3.5° 9.3# L-~t} Et1E Srd €~tccl Pup X~ Bu!# ma~i X F~se Pin ~14.~5 48A5,42 .lt~ #2 3.5" 9.3# L-8tl E~e 8 rd A9ed tbcj. 31.t~ 48fi0.07 3.5" Camco'C~5'tan~ng nipple ~.8t3 na-go profile .9E 489i.~7 J~ #1 3.5" 9.3# L~t~ EUE &rd Moci thg _ 3Z .~i ~892-43 Pup 3.~°' 9.3# L-$Q ~t1E 8rd Mlod Pup 6_93 4923_6d Locatssr Baker KBH-22 lacab~r Sp+t~tted i' up i.83 4J29.~T SA S°FlI ~!:n~lt7ibl$I 1S i l'#.5 ~Tb{I Of'r15-r=tl' SBE ~i.14~32' ~49.91.60 { --- , r ---; - -~-~ __ _ - -- - --- - _ ~ Rent~: S4riru~ Wei~ts wiGti Bksc[cs: 60K~ Up. 45 Kii Dn. 2UK# SIvCk::. Ran i 55 j c~inis af iu6m g Jun 14 t79 ~7:13p PDS Inc €'hillips Alaska l~c. CASING D~TAiL ~-9I2" X 3-Zf2" Casing Description 3__ ~7 6592314 p,~~ KRi11(Ji-137 DATE: 5tZ1f~D84 1 C~F 'i ~"~G~S ~F ~T'EN15 ~OIY~PLETE DESCRiP7[Qtri t}F EQt11t}MEHT R4:V ~E~IG'CH DEi'"E'li TaPS R.ar+ding jvint 6' abo ~e tle~ar A1tlftRt+G RT TO ~ANDiNG RIMG 3Q.OU 5 1!2" Gray Gasing hangerwJ pup 3.(~l 3~.00 ~'933'E$ 5-3l2' 75.5~, L-80, L"fC-Mad csg B~iU..34 33_4lQ 'S-i12' 55.5#, L-8d, BTC-Mad csg t'in X L7~-Mad $ax X-Over 42.$$ 893.$Q S-tf2" Tara Port Colfar 2.9:i 936.72 5-1/2' '~5.5#. L-SQ, ~TC-NEOd csg f~rri X BTG-ldod ~x X-4ver d2 ~6 939_G7 2f}t-247. ~-il2' 15.5#, L-80. E..TC-Nlod ~g 390k_3J 9$2.03 S-112" 1 ~.5#. L-$fl. BTC-Mo~i csg Pin X L"E~-Mod t3ox X-Qve~ " 37.59 ~48$6.42. _ 5-112" Baker Crcrssover ~wp 8.40" ~, d.93T' !D 7D_1 ~ ~924.Ot ~aker ~f2' ~B~ v~t S' {7C1, 4" I[~ 12 °0 4934.'18 3-tP2".9.3#, L-8Q, Eue 8 r~i Mod Pup TL~_C1 ~947A6 Jks #4 2(1 3-1l2`, 9.3#, L-80, Eue ~~d 141od Tbg 53{1_ !B ~}957.t~t 3-1/Z" Weatt,~rFo~c! iandin~ callar 5487.23 ji's #3 3-~12". 9.3#, L-80, ~'ue 8 rd Mad Thg 31.ED 548?.~3 3-112" Weatherford ~lo~t collar ~ue 8rd bnx x{sin 1.1 T 5~'[5.83 jt's #'. & 2 3-112", 9.3#. l-8fl. Eue 8 rd Mod Tbg 62.A9 552t1.00 3-i12^ Waatherforci Floaf shac ~ue $rd kx~x. 92 ~ 5582.a9 5583.74 Ftai~ T~sL'al t7e~ rth 5615_pQ ~ GentraCtzers 3-iJ2" ~ Run two 3-i12' X i-5J8" ROTCC? Sntid S¢~al Blade centr2~iz~~'s peri~t. P!~ stap ceNlar ir, ihe center af eac3~ j~. Let r,ertlrafizer flaai belween ~t and lE~e co~ats , t;entralizers 5-112° ftura 5-il2" X 7-71$" Bc3wspr'mg CenUaliz~rS 2{18r/jt fttt 50Q' a~xfve crossover. S{ap ~g ~n midd€s of ~oir~t leEteng cenhatizer fldat taFween cdE ar snd stop ~g_ .binG; 24'f thrit 2~2. Piace i Baeuspri~g every ,. joints 29 5.21$.221.Z24.227.230.233.236,239.2~2.245,~48.25'#.2S4,~57, 26Q,263,266.28J,272,275,2~8,287,284,Z$T,29Q X-aver's below $ Above T2~rn Coila~,295.298,301,304,347,31c? & 312 Rcmarks: Straic~ 1tV~gh~ w i#h Rlc}clcs: 7C-F{# U~. ~OIS# Eln. 2~~#~ Rk?c.~ca. ~~i f'I 12 { Ai~S 4i $.5' ~reri 20 jts 4f 3.5` cas~rg. D+rii~ted castrig, 8~ hanger wit~ 2.857" ~or 3.5" & 4_82:-' Fa~ 5.5" p lastic rabbit. l Isari arr4ic t~rarfP APt ~,ladifiec3 Nfa Lead ihread camoound o~ aU carFne^..tions. Tub irw is fton-ct~a~ed. lUeordic Rig #3 L)i~lling SupBrvrsor.' Uonc'~d ~_ We:~ter Schlumbel'gep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# 1A-10 2l-313 1D-137 2N-311A 2N-3378 1J-184 1H-10 2W-03 1 E-112 1J-156 1J-127 1J-105 1J-164 . 1J-164. 11638846 11628996 11628997 N/A 11638852 11638853 11638844 11649957 11638856 11638857 11638859 11628994 11638858 11638860 ¡\PR ? 0 L.G07 P~G¡~CO\Ìs.Cf)fnn)s~tANNED APR 2 5 2007 04/20/07 NO. 4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Kuparuk ( Date BL Color CD 04/05/07 1 04/08/07 1 04/09/07 1 04/06/07 1 04/11/07 1 04/12/07 1 03/20/07 1 04/10/07 1 04/14/07 1 04/15/07 1 04/17/07 1 04106/07 1 04/16/07 1 04/17/07 1 ( Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 13 U-l-C- ~'-O((? Log Description INJECTION PROFilE lDl INJECTION PROFilE USIT SCMT SBHP GlS MEM LDlIPPROF INJECTION PROFilE INJECTION PROFILE INJECTION PROFILE USIT INJECTION PROFILE INJECTION PROFILE . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 scANNED JAN 1 6 2007 ;)J>f>'DLlt1 Dear ]\IlL Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG24 0 1 that was 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28,2006 for 1D-Pad. SchlumbergerWell Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem Wells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTO# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 1 0-109 197-235 10' 9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13' 6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10' 8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 10-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 10-140 200-136 29'9" 3.4 12" 12/16/2006 na na A!KA OIL AND ~,:;~g:t';':~A";;ON COMMIS!N RE. C E. NE 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Repair Well 0 . Alter Casing 0 ~,\p" Pull Tubing D Change Approved Program D Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 101' 8. Property Designation: Æb Kuparuk River Unit ¡4:ÞL Z.S-G.b'"o /"" II'"" oG:. 11. Present Well Condition Summary: Total Depth measured 5615' 4135' true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR PRODUCTION LINER Length Size 110' 4833' 649' 13-3/8" 5-1/2" 3-1/2" Perforation depth: Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D feet feet feet feet MD 110' 4934' 5583' Stimulate D Waiver D A\as[lrB¡Ht*pri:O~ Re-enter Suspended ¡\Mûì ji, ¡ [}J3 5. Permit to Drill Number: 200-0471 . 6. API Number: 50-029-22956-00 . Exploratory Service D o 9. Well Name and Number: 10-137 . 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 110' 3531' 4105' Measured depth: 5040-5090, 5121-5161, 5170-5190, 5218-5262, 5272-5280, 5298-5347' true vertical depth: 3619-3661, 3687-3722, 3730-3747, 3772-3811, 3820-3827, 3843-3887' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4934' MD. Packers & SSSV (type & measured depth) Seal assembly 4929' no SSSV no SSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured) Treatment descriptions including volumes used and final pressure: RBOMS SF\. r.·, I'> ~DD6' \~ 11 L Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casin Pressure N~ N~ N~ N~ N~ N~ 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 13. Oil-Bbl N/A N/A Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Loveland/Dethlefs M.J. Loveland Form 10-404 Revised 04/2004 Tubin Pressure N/A N/A . WDSPL D Sundry Number or N/A it C.O. Exempt: 306-223 Problem Well Supervisor Date 10/25/06 ORIGINAL !-u{tt' ~ //7'~ ~21P;/~ . 1D-137 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 1 0/14/2006 Excavate to 14' & back fill to 12'. Install shoring box + stairs. ./ 10/18/2006 Conductor removal. T/I= SilO Removed 11' of conductor with the measurement starting from the top of the landing ring. Removed cement and buffed the IA casing for UT inspection. The casing appears to be in fairly good condition tI' 1 0/22/2006 I Wrap SC wldenso after UT results confirm pipe is still in working spec. 10/23/2006 Install new conductor, T/O = 010, Assist welders installing 10' 2" of 16", 62.5#, API 5L Gr B Conductor. , . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road cf ~~,H'!EV Suite C <.¿ v~··, ,~ Anchorage, AK 99518 Fax: (907) 245-8951 tf:'¡. PL·. (¡ \W C t \:'-" 1J 2J 3J 4J 5J 6J 7J 1 Report 1 D - 136 MTT Report 26-Sep-06 UJ:c-' 900 -O'-/b 1 Report 1 D - 137 MTT Report ~~6 U;:¡:c. dfP-o<rj) 1 Report 1 D - 138 MTT Report 26-Sep-06 U:1 C- é)OÖ - tf-{{f 1 Report 1 D - 139 MTT Report 26-Sep-06 U:.t: c. 90D - 0'-/9 RECEIVED Print Name: 0,. Q~ ßtA r~:') t1 \A P CD, (\ ~ \^ t2 {)1/\ SEP 2 9 2006 Date· , . ~ 011 & l::ias COliS. CVllfml3SIOIl Anchorage Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\OO _ PDSANC·2006\Z _ WordlDistribulion\Transrnillat Shccls\Transmil_ Original.doc I I I I I I I I I I I I I I I I I . . . Memory Magnetic Thickness Tool Log Results Summary Company: ConoeoPhiJ/ips Alaska, Inc. Well: 1D-137 Log Date: September 26, 2006 Field: Kuparuk Log No. : 8053 State: Alaska Run No.: 1 API No.: 50-029-22956-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 110Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 13.375" 68 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 192 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 13.375" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 13.375" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report, The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 8% circumferential metal loss is recorded directly below the mandrel hanger in the interval between 0' - 2'. A 6% circumferential metal loss is recorded in the interval between 37' - 44', A 3% circumferential metal loss is recorded in the interval between 27' - 37' and 57' - 58', A 2% circumferential metal loss is recorded in the interval between 10,5' - 11'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5",5.5" and 13.375" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some ofthe metal loss indicated could be from either the 3.5" tubing or 13.375" conductor. ",,,;;; I Field Engineer: R. Richey Witness: J. Brake I Analyst: M. Tahtouh & J. Burton RECEIVED SEP 2 9 2006 U :r e ;;J.cQ...()4 ':}- ,.u.fœ 011 & Gas Cons eommissil" ~ '" I c9s. PII<>Ac-<IvE DiAq",o."¡c SER"¡CES, INC. I Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: r:5D agnetic Thickn d\warrior\data\1 d-137\1 d-137.db Kuparuk/1 D-137/run1 /p1 Ohz.1 28SCAL ~1 Wed Sep 2711 :08:13 2006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1150 3.5" Collar --I-'~ _... 40 -- ¡-~- ~- Pup Jt ~'-- 3 5" Collar '-f--'l '- Pup Jt. ,5" Collar -~,5" Collar I I o ,...., <L Metal Thickness (%) Line Speed (fUmin) I _ --'" "- -"-" I -8% Me ? LOSS- Z. ~-I--- f------ Hanger---- I I 5" Collar 3.5" Collar ,- I "-".,,, I r---2% Metal --+ -I-T~ Loss (~-r- -... -- I I I I '- - ~~...... .-.. -- ~~- ~._- ~.J_ _~ I ~~ 3% Metal -~ ~J II LO~S 3% Metal -~ Loss -~_.- I ,~.~. '-~ -~ --'- ~~. ;--- . I-éro MetalR -. - LOSs-~ ~~ - -t:- ~_.,,-- "---- ~'I---- I t---- - I - -~ I ~~3~ M~~~;~~ _~~ '_ ;--~ \ ~_. ¡--..- -~ -.~ -~_. ~- -~ I I I .-.- . .__c...._._I--~~ ___ I -- --_om __~ ...___.___ -- -- -~.- I I 50 -200 Q Pup Jt. 35" Joint 1 20 .~ 60 3.5" Joint 2 80 12.8 -5.6 MTTP01 (rad) MTTP12 (rad) Tree ¡---- -- ""! J -~ ~~ ~ I-- -~. ,~, ~ -: .- -- -I- -"" r--- ~- -s ..~ - ~--- -~:;j - -- - ;--- tt }- Ie- ---- - 1--. I-- f--- k.~ ¡-- ._. s Tool Log 12,8 4 ~ - .--- - -f- ~I---' -. - - --- -~ 1 -c'" ~, ~--- I-- 1--- ~~ -'--.. -- ~ -t1fJ'- : - .~ I _ _ _~I'~_ __ ___ I -- _·~~_·-c~-- '~")< I-- Bottom of 16" Conductor ~,'0~ I - ¡;,~ -~- ~- -- k.) k._.~ -;~~~~~ 5" ?Olla~~ \"" =.~ti.t=).5" Collar__ -r-- = -t~jj=-= ~.- ~- ¡.. ::j ~-t _.~ ~~ .~- ).:. '- - r .",.'Y~' ·It'' ( - ~ 1< 1\ .t ~~ _~~I ::::>- ~ ¡ 1··- --.,..- I f ~ +- -1- -I _. f--- Iþ /' ~, ~~. f ~~.~ rV ! I ¡ I ~. ~- I I I I I I I I I I I I I I I I I I I J / (~ I , ~ (, { (' ~~ I( ( ( ¡ , 100 - -- r--- - -. '-. -- '-, -- -..-- 3.5" ._. -~"- ,~ _'n_ ----- - '- ~ - Joint 3 r--- - -C'-" -..- .-- -,- "- ..- '- I j I .~ ì # I ~ ~ --., -.- -.- .- "--- -'-- ~'- -- - 1--" I" -...-- .~-- '- I =ffi-- 3.5" Collar- f:' ;;;::- r-- '-' ---., ~-+-- '-, "- J. ~- 1'- 120 ~ .-. "-'- - -- -- r--- ¡-- r-' - f---- -- '-t ~"-, -- -, --,~ ..-.... "--.- r-" -- '- r--- ¡-- '-, ~~F 3.5" i> '2 ¡:7 < :;> I ,,:> I '¿" ¿ :'" =g: ~ - ; ¿!: <:: '- ......5.5" Collar- ¡--- Joint 4 ¡--- -( r~ ..-- L _C ç=- I-~ ,(,,, ,.....- r .- ¡ ~ } 1 -- r-. 3 ~ '-. tf "- _... I/- I l ( t I / l :; 140 I ( ; " ì ~ ':1 ! __M - -- '-. "'-'--'-- -.. r I j. '( .- "t ~ , ~; J ~ ....- - = 1== --3.5" Collar '- f. I" , --- I-- '- _.,- ....--.. - ~. _._,-- I --. ..- _.._n_ -.- --. -.- f---.. "- -, ---- ---- -.---- .. ¡--- 160 I --. .._, -,- '--,--- -- 3.5" " ,-'o- j- -. -. --.-..,- ----- -"'-', -.-- "_m.._ ~_.- -- .....-- - Joint 5 '- ; f '\ t <- J: .. -f: 1'-- I '- {..... (~. -.. ,-'-' ....... ( .(, ..c; C V" I r-._ r--- 1-55" Collar-- -... - I r '- m_ ,/ I I - 180 ') - ~ - Collar 1- ~ 1. '-1--- I ..- - ¡--m.._ 3.5" } I ì ~ ~ ) .-. ,- 1=- - .-- Joint 6 I 1 k" AL.!- End of Lon ___----L-__._L~ -- --.-- ____n_...____..___ '- -'- -.._.._.1_. ~__L_ ._L.._ -. -50 Delta Metal Thickness(%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ftlmin) -200 -5.6 MTTP12 (rad) 4 I I I I I I I I I I I I I I I I I I I cS agnetic Th ick Tool Log ...}'-~ . 55 p~ DiAqN'''''¡C SE""¡C"", INC. Database File: d \warrior\data \ 1 d-137\top annotation\ 1 d-137. db Dataset Pathname: Kuparuk/1 D-137/run1/p1 Ohz.1 Presentation Format: 28SCAL ~1 Dataset Creation: Wed Sep 27 11 :08: 13 2006 by Calc Sondex Warrior V7. 0 Charted by: Depth in Feet scaled 150 " -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) -200 -5.6 MTTP12 (rad) 4 I "- "^--- ^--.- I I - Tree """ - I .J I -8% Met r--Hanger- :---- 0 I J "- Loss ):, =':~ ~ ='", :\~, J Pup Jt ~ ß P. -- 5.5" Collar 5 ,¿ .J \ ~:.J l I J ¿ -1. 3.5" Collar ~ 111::0-1 "Ç I <: I I r I ¡ i ( l ¡ '¿ ~ ~ ~ ,>' ] ''\ i 1, 'i:.'" > ;1 ~~ I"" ~ I 11 'I > :> < I , "'-", ; 2% Meta! -++ 'i ¡'st > «I'> ~I ( ~ < ¿ì Loss ? ;e> ,3' ¡ ¿I I 1, "í 2' " '1 <'';$ ~ 1- ;;¡., ¿: "< ~ < ':;;;' ¿ ,,' ;7' ~ ~ r;>, !t ':, :~ ~ i l .~ \ ,'" ;" 35" ¿ f:", :,> , (," 'C ~ 15 ,,> "i >- , < ~ ? J '-. ^-.------ _."-- -.'^- Joint 1 "" - ----- < ,1 ~ ';r I < ? ':;r '"I < 20 ,. < , ~¡ , Ii " ~ I~':;;,> - %!:I , -'" } ""> " -. - '- -- ~ ~~) <'I <,",,' .~ I il 0> '1- ~ 1 ~ ~ ,~ <I> :::;;;, "ì:;, ì , " . <: -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ftlmin) -200 -5.6 MTTP12 (rad) 4 I I I I I I I I I I I I I I I cIrk agnetic Th ick 55 T 01 Log p~ DIAqNosfic SER"¡CES, INC. Database File: d \warrior\data \ 1 d-137\bottom annotation\ 1 d-137. db Dataset Pathname: Kuparuk/1 D-137/run1 /p1 Ohz.1 Presentation Format: 28SCAL -1 Dataset Creation: Wed Sep 27 11 :08: 13 2006 by Calc Sondex Warrior V70 Charted by: Depth in Feet scaled 175 ., , , -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) -200 -5.6 MTTP12 (rad) 4 ¿,v . 1H~ßOO IT -. ...: ~ _.~ ~.-. I , J I ß ~ '" ~ [l ;, ~ ~_ 'ê -. -.. '- _.'.n --- I~ -. ~ 3% Metal - .... < I \ I l ? I Loss I < I 3% Metal - ~ .t :::>. :r ~ Loss ~ '~" \+ .-.- -,,~ ,- I I ~ * ""'~ ; 3.5" Collar - I 1 ~ 'f 1 .- 40 6% Metal I......, ..., ~ .'"\ ! ,¿~ !~~ ,*! ..5 ¿ ~ -, Loss Pup Jt . ? 1--. '-- I ¡g . ~ /Þ J. I ~ I ~ ·1 .."1 ~ "-,, ."'"' I f;~' I "'è:'2;" """', '- ,¡ ''''. L.'t, 3.5" Collar rl~ I~ I".':. ~ J - \ ~. -~- Pup Jt. ~ I·&~. (. f.··> 5" Collar r"" I I 5.5" Collar .~:-- \ <t. P- I . I----~ '- -. ¡--~ ~-,--- ".- '- ~r --.~ -- '- ? l 1/ I ? ~ 3% Metal - +') .",¡ "'Î j~ I Loss -, ~ ~ I '" 60 < ., \ I I , ~ '""", ....~ ~ ': ----~ __n_ ----., ____m -. ? . --, ¡--, > -50 Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 0 Line Speed (ft/min) ..200 -5.6 MTTP12 (rad) 4 I I I I I Gas Lift I ndrel/Oummy Valve 1 I (4827-4836, 00A.725) TUBING (0--4938, 00:3500, 10:2.992) I I ' ROOUCTION (0-4934, OD:5 .500, Wt:15.50) I LOCATOR (4927-4928, I ODA.500) SEAL (4928--4929, OD:4.000) I Perf (5040-5090) LINER I (4934--5583, OD:3500, Wt:9.30) Perf I (5121-5161) I Perf (5170·5190) I I Pelf (5218--5262) I I Pelf (5272-5280) I I Perf (5298--5347) I I - Interval ND 5040 - 5090 3619 - 3661 5121 - 5161 3687 - 3722 5170 - 5190 3730 - 3747 5218 - 5262 3772 - 3811 5272 - 5280 3820 - 3827 ~5298 - 5347 D 3843 - 3887 Man Man Type Mfr 1 / 4827/ 3445 CAMCO KBG29 ,E~U:P,"'¡"" Depth JVD Type 4881 3488 NIP 4927 3525 LOCA TOR 4928 3526 SEAL --- I--- -- ¡--- ---- ¡--- -- I---- '- f-·- - 1---- -- r-- - '--- -.- !--- - f------ --- c,_ -.-- - '-- - -'-- --. - -- - -'- '- -,- -'- '--- -- --- --- '-- --- :.........- - '-.- -.. _." -- -.- _. - "- - -- -- - '-'- --.. '-- - -.. -- - - - --- -- -- r= -. "'- -'- -...- -.-." "'- --.. '- '--'- "- - -'''- f--..- -- 1--" - ¡--- = 1--'- ~.._. -- 1-- "-- '-- "- 1,- "-... 1--- --.. 1- -- ¡-------...- -..... ---- IHM~7 API: 500292295600 SSSV Type: NONE Annular Fluid: Reference Loa: LastTaa: 5122 ~/2006 DescriDtion CONDUCTOR PRODUCTION LINER Al Size / Top 3.500 / 0 KRU 1D-137 Well Type: ¡NJ Orig 5/2512000 Completion: LastW/O: 1212312005 Ref~.99 Date: TO: 5615 ftKB Max Hol.. Ann¡e: 166 dea @ 2800 Angle @ TS: deQ @ Angle @ TO: 22 deg @ 5615 Rev Reason: TAG FILL Last Update: 81712006 Size Top Bottom NO Wt Grade Thread 13.375 0 110 110 68.00 H-40 WELDED 5.500 0 4934 3531 15.50 L-80 STCM 3.500 4934 5583 4105 9.30 L-80 STCM Bottom / NO / Wt I Grade .1 Thread I 4938 ¡ 3534 I 9.30 ¡ L-80 ¡ EUE 8RD lone Status Ft SPF Date Type Comment WSD 50 4 7/612000 IPERF WSB 40 4 7/612000 ¡PERF WSA4 20 4 7/6/2000 ¡PERF WSA3 44 4 7/1/2000 IPERF WSA3 8 4 7/1/2000 ¡PERF WSA2 49 4 7/1/2000 IPERF V Mfr I V Type I V 00 /latch I Port I mo I ~~~e I C~~t CAMCO / DMY I 1.0 / BTM I 0.000 I 0 n2127/20051 IN CAMCO OS NIPPLE BAKER LOCATOR BAKER 80-40 SEAL ASSY Description 10 2.912 2.992 3.000 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg~cr' 7/VS{o(P P.I. Supervisor . ( I DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lD-137 KUPARUK RIV U WSAK lD-137 aoo -047 FROM: JeffJones Petroleum Inspector Src: Inspector Reviewed By: Pol. Suprv. )ßiZ-. Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK lD-B7 API Well Number 50-029-22956-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ0607II180049 Permit Number: 200-047-0 Inspection Date: 7110/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ 10-137 !Type Inj. I W I TVD 3527 I IA 1 270 i 1810 1 1705 1700 I I . +:---1 lOA I I I P.T. i 2000470 iTypeTest ¡ SPT ! Test psi 1500 ! I ---t- -- Interval 4YRTST P/F P ./" Tubing ! 1150 I 1150 ! I ISO 1150 ! I Notes Monobore injector, 0.7 bbls diesel pumped. 1 well house inspected; no exceptions noted. ¡/' Wednesday, July 12,2006 Page 1 of 1 ..¡¡:.¡¡¡:."JJ.-.:¡r ConocoPhillips Ala.s. k3,'.,..tnc. . . ..... "10-137 " API: ,500292295600 SSSV Type: I NONE TUBING (0-4934, OD:3.500. ID:2.992) 'RODUCTION (0-4934, OD:5.500. Wt:1550) NIP (4891-4892. OD:3.500) SEAL (4929-4930. OD:3.500) LINER (4934-5583, OD:3.500, Wt:9.30) Perf (5040-5090) Perf (5121-5161) Perf (5170-5190) Perf (5218-5262) Perf (5272-5280) Perf (5298-5347) e e KRU 1D-137 Wt 68.00 15.50 ! 9.30 Grade H-40 L-80 L-80 Thread WELDED STCM STCM Thread EUE 8RD T e ¡PERF 7/6/2000 IPERF 7/6/2000 ' ¡PERF 7/1/2000 IPERF . 7/1/2000 ¡PERF 7/1/2000 IPERF Vlv i Cmnt ' ID 2.813 3.000 -- e j :;...d FRANK H. MURKOWSKI, GOVERNOR ; ,.,- j 1 i :¡ J ~ A.,ASIiA. OILAltD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Poo11D-137 Sundry Number: 306-223 Dear Mr. Dethlefs: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. DATED thisJ?day of June, 2006 Encl. 'dW .~ vL{'1- e Conoc~illips Alaska e EI\IED P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 J 'l 1 2006 AlasKa Oil 1St Gas Cons. Commission Anchorage June 19,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1D-136 (PTD 2000460), ID-137 (PTD 2000470) and ID-139 (PTD 2000490). The approval requests regard potential repairs for surface casing corrosion. Please call MJ Loveland or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Sincerely, ý~c~ Jerry Dethlefs Problem Well Supervisor Attachments 1. Type of Request: Abandon Cf4 ~ÞI°/tJ e (' 'VED STATE OF ALASKA It RECE ALASKA OIL AND GAS CONSERVATION COMMISSION tâ-Iv JUN 2 1 2006 APPLICATION FOR SUNDRY APPROVAL C .' n 20 MC 25.280 Alaska Oil & Gas Cons. 0f11111S510 o Suspend 0 Operational Shutdown 0 Perforate 0 Waiver An~rage Other 0 o Repair well [].. Plug Perforations 0 Stimulate 0 Time Extension 0 o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 6" ~75 ./£ Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 101' 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service [] 5. Permit to Drill Number: 200-047 . 6. API Number: 50-029-22956-00 . 9. Well Name and Number: 10-137 8. Property Designation: Kuparuk River Unit /¡þt... ~q,5() þì:> (...lJ.e>t- 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Total depth MD (ft): 5615' Casing PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 4135' Length Junk (measured): CONDUCTOR 11a PRODUCTION 4833' LINER 649' Size MD TVD Burst Collapse 13-3/8" 110' 110 5-1/2" 4934' 3531 3-1/2" 5583' 4105 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5040-5090,5121-5161,5170-5190,5218- 5262, 5272-5280, 5298-5347' Packers and SSSV Type: Seal assembly no SSSV 12. Attachments: Description Summary of Proposal [] Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for July 2006 Commencing Operations: 16. Verbal Approval: Commission Representative: 3619-3661,3687-3722,3730-3747,3772-3811, 3820-3827, 3843-3887' 3-1/2" L-80 4934' Date: Packers and SSSV MD (ft) 4929' no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service [] . Plugged 0 WINJ [] Abandoned 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature }JfY Dethlefs ~ 7~q'/¿f c Commission Use Only Contact: McConnell/Klein 659-7224 Title: Problem Well Supervisor Phone 659-7043 Date ¿. ß ? ftlð Conditions of approval: Notify Commission so that a representative may witness ISUndry~~ .~a3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: c..O"~'\- L......~~IÇC-~,~~c~\'(:),~~..:\~ \0 ~"\tt.~ ~~ '--~~~ fu~Q:., \-0 CcloL~MJè~~\\t)1f\. ~~\r-...,\ ~~~\"- COMM~R APPROVED BY THE COMMISSION Date: 6· ¿,'f ,..d-6 ~ "2./0" ~n~6 Approved by: Form 10-403 Revised 7/2005 ORIG\NAL RBDMS 8Fl ,¡UN 2 8 2006 e e ConocoPhillips Alaska, Inc. West Sak WelllD-137 (PTD 2000470) SUNDRY NOTICE 10-403 APPROVAL REQUEST 06/18/06 This application for Sundry approval for West Sak injection welllD-137 is for the proactive inspection and possible repair of the production casing. The well is to be excavated for an inspection of the near surface casing for damage due to corrosion observed on other similar wells in the West Sak field. The results of this inspection will help determine if similar actions should be performed on additional wells in the project area. The well is a 5-1/2" x 3-1/2" tapered casing completion that is designated as a water only injector, completed in May of2000. The well has a single casing string that is suspected of being subjected to accelerated corrosion processes. Mechanical Integrity Tests (MIT) have successfully passed on the casing and there are no known casing problems. However, the construction of this well is similar to those that have failed and a preventative inspection is warranted. With approval, inspection and repair of the casing will require the following general steps: 1. Notify AOGCC Field Inspector of inspection/repair plans for witnessing. 2. Safe-out the well with plugs and load the tubing and IA with water and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Excavate around wellhead and install construction shoring box. 6. Cut away the conductor casing and remove cement ftom around casing for inspection. Approximately the top 5-10 feet of conductor will be removed to provide access to the casmg. 7. CP AI Mechanical Engineers will determine the appropriate patch and/or repairs to return the casing to operational integrity should damage be found. 8. QA/QC the repair and MIT -IA for a final integrity check (if repair was performed). 9. Install anti-corrosion coating to casing. 10. Replace the conductor and fill the void with material designed to seal out water and oxygen. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to injection service. 13. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 6/18/2006 e e KRU 1 D-137 C0r10coPhilJipsAla$ka, Inc. TUBING (0-4934, 00:3.500, 10:2.992) 'ROOUCllON (0-4934, 00:5.500, Wt:15.50) NIP (4891-4892, 00:3.500) I_ ~ :¡¡}!!} I I I I SEAL (4929-4930, 00:3.500) LINER (4934-5583, 00:3.500, Wt:9.30) Perf - (5040-5090) Perf (5121-5161) I : Perf (5170-5190) Perf (5218-5262) i Perf , (5272-5280) ¡ Perf ¡ (5298-5347) API: 500292295600 SSSV Type: NONE Well Type: INJ Orig 5/25/2000 Completion: LastW/O: Ref Log Date: TO: 5615 ftKB Max Hole Angle: 66 deg @ 2800 Angle @ TS: deg @ Angle @ TO: 22 deg @ 5615 Annular Fluid: Reference Log: Last Tag: 5076 Last Tag Date: 8/9/2005 Casing String- ALL Description CONDUCTOR PRODUCTION LINER Rev Reason: PULL WRP Last Update: 4/10/2006 Thread WELDED BTCM BTCM Interval 5040 - 5090 5121 - 5161 5170 - 5190 5218 - 5262 5272 - 5280 5298 - 5347 3843 - 3887 Gas Lift MahdrelsNalveS St I MD I TVD I Man I Man Type I V Mfr I V Type I V OD I Latch I Port 1 4838 3454 CA~~O KBG29 CAMCO DMY 1.0 INT 0.000 Other (plug$,Elql.lip"l¡ItI::.)- JEWELRY Depth I TVD I Type I 4891 3496 NIP CAMCO DS NIPPLE 4929 3527 SEAL BAKER GBH-22 SEAL ASSY Comment I TRO I Date I Vlv Run Cmnt o 6/27/2000 Description ID 2.813 3.000 [Fwd: ConocoPhillips Excavation & Repair Project] e e All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us _..._.....~. ........ --...... NSK Well Integrity proj <N1878@conocophillips.com>, aogcc prudhoe bay@admin.state.ak.us \\>-\š,\ dOCJ-Gl.\\ Subject: Date: From: To: CC: Tom: I don't remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 Content-Type: application/vnd.ms-excel 1 C and ID Casing Repair List AOGCC.xls Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/20067:51 AM PRIORITY 1 2 3 4 5 6 7 8 9 Joa-~~ ~ '~ 10 11 12 13 14 15 ) 16 Notes: NAME 1 C-121 1 C-131 1 0-109 I 1 0-111 Ie> . ·..¥6~W~¥' ., ... .. .... .... "··_"_'_·;·:'·"7"::--·-~~·'··:·""·"·~·····:·1 1·p~.127 . . J i·_··__··········..···-1·D~1-32..······· ........ ..... : I· ..... ..................--...-........................... ... ' , 1D-136 1....····..···················..·-·....··········-·....·····..·.............. ---." I 1D..137 I·........ ....-......-....--- ....--...-................ .... 1 0-138 ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE PTD# LEAK DEPTH (ft) ---------..-".--.------- ---- INJ 201-080 4 . --------.-- - INJ 201-185 7 INJ 197 -235 5* INJ 198-166 5* INJ 197-221 7 Gas Lift 197-181 None Gas Lift 198-109 None INJ 198-121 5 INJ 200-046 None INJ 200-047 None INJ 200-048 8 INJ 200-049 None INJ 201-139 16 -. Jet Pump 201-220 None ESP 197 -184 None Gas Lift 200-112 None COMMENTS I STATUS "'. 1 0-139 __·,""_,.~_._._._'L_'_'~._. 1 C-119 I.. __,_",," .._,,'~' '_0" "__','_ '~"_~_'~ .... __ .__.... tC-13f) . . """ I ,....-..... ._,.,..""...~.~,_.--~~_.._~_.__......,- ,-, ':--'" "'~ ,.·tD,,;1~5 -1,..._......_._.oI-.....__.,.._'-.__~_......._....._...._._.. I ' "." ,,, ", 1D-141 . ," :~ ~" Proactive dig Proactive dig Proactive dig' Proactive dig Proactive dig ,.~ ~,:.:.,;~;'~.""""" Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. . ol.'l.\'-:-'t. ,·,r,.' 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor .' .. ~.. . . \.. 6/26/2006 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'K&'t? '7 (3!{){p P.I. Supervisor ¡ ( DATE: Wednesday, May 03, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA !NC lD-137 KUPARUK RIV U WSAK lD-137 o~o't1 ~Ð FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv _ ....flS'iZ-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-137 API Well Number 50-029-22956-00-00 Inspector Name: John Crisp Insp Num: mitJCr060503045318 Permit Number: 200-047-0 Inspection Date: 4110/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I lD-I37 IType Inj. w! TVD ¡ 3496 I IA i 0 i 1650 1560 i 1560 I P.T. I 2000470 !TypeTest SPT! Test psi ¡ 1500 lOA i I i ! , I Interval !NIT AL PIF P Tubing I 970 I 970 i 970 ! 970 ¡ Notes Single string casing. No OA. SCANNED Mt¡Y Ü S 2005 Wednesday, May 03, 2006 Page 1 of 1 e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU lWestsak/1D-137 04/10/06 Perry L. Greenwood / Jon Arend John Crisp iQÙ{\ ~tQ" Packer Depth Pretest Initial 15 Min. 30 Min. We1l11D-137 Type Inj. W TVD I 3,496' Tubing 970 970 970 970 Interval I P.T.D.I 20004701 Type test I P Test psil 1500 Casing 0 1650 1560 1560 P/FI P Notes: Initial post rig MITIA OA Weill I Type Inj. I I TVD ! Tubing Intervall p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA Weill ! Type Inj.1 I TVD I Tubing Interval p.T.D.1 Type testl I Test psi Casing P/F! Notes: OA Weill I Type Inj. I TVD Tubing Interval p.T.D.1 I Type test I Test psil Casing P/FI Notes: OA Weill ! Type Inj.1 I TVD I Tubing Interval I p.T.D.1 I Type testl I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test ? INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 10-137 04-09-06-1.xls e e "~n II II....! ¡¡II ~ FRANK H. MURKOWSKI, GOVERNOR A....ASHA OIL AM) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~. Re: KRU West Sak 1D-137 Sundry Number: 305-297 ~^NNED "J; 'ìnn\"; (\ çj c:..Vl,~ Dear Mr. Peirce: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. Sincerely, DATED this,/- day of October, 2005 Encl. e e John Peirce Wells Group Technician Drilling & Wells ConocóÃ,illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6471 September 30, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 10-137 RECEIVED SfP 3 Alaska 0 2005 Oil & Gas (', < ""Ons. Co . Anchorage f17f17/SSion Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 10-137. We are planning to workover this well to pull and replace the tubing. If you have any questions regarding this matter, please contact me at 265-6471. Sincerely, I~~~~ / Jo~ Peirce Wells Group Technician CPAI Drilling and Wells J P /skad 1 L.__ e 1. Type of Request: D D D Suspend D o o Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 30' Repair well Pull Tubing 8. Property Designation: ADL 25650, ALK 468 11. Total depth MD (ft): 5615' Casing CONDUCTOR PRODUCTION LINER Total Depth TVD (ft): Effective Depth MD (ft): 4135' 5076' Length Size 110' 4833' 649' 16" 5-1/2" 3-1/2" October 14,2005 Date: Signature - œ /0 --3 ~():; ~ ¿o/J/S Perforate D D Stimulate 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational Shutdown D Plug Perforations D Perforate New Pool D JJ-w / \ Waiver D other D D D Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 1..Á 6. A I umber: 50-029-22956-00 ./ 9. Well Name and Number: 10-137 10. Field/Pool(s): Kuparuk River Field I West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3649' MD TVD Burst 110' 4934' 5583' 110' Perforation Depth MD (5040'-5090',5121'-5161', Perforation Depth TV[ 3619'-3661',3687'-3722' Tubing Size: 5170'-5190',5218'-5262',5272'-5280', 5298'-5347' 3730'-3747',3772'-3811',3820'-3827',3843'-3887' 3-1/2" Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name John Peirce 3531' 4105' no SSSV 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D Contact: Title: Phone Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test ~ Mechanical Integrity Test ~ Other: "3CCO ~::,'\ \SO\?~* O-sv\a~",-JJ Location Clearance D Collapse Tubing Grade: L-80 Tubing MD (ft): 4934' Service 0 Plugged D WINJ 0 Abandoned D WDSPL D John Peirce @ 265-6471 Wells Group Technician Date RBDMS BFL () CT 0 5 2005 APPROVED BY COMMISSIONER THE COMMISSION ORIGINAL Date: Submit in Duplicate e Rig Workover Procedure Well 1 D-137 West Sak Injector Tubing Replacement e Prep Work 1. Submit Application Sundry to AOGCC for tubing replacement on injection well. 2. RU Slickline. Pull DV at 4838' RKB. Leave pocket open. 3. Displace Diesel from tubing w/9.6 ppg Brine pumped down the tubing while taking returns up the IA through the open pocket. (Max BHP = 2079 psi; EMW = 11 ppg). 4. Prepare location for workover rig. 5. Set BPV within 24 hrs of MIRU. Rig Work 1. Verify Application Sundry approval from AOGCC for injector tubing replacement. 2. MIRU N3S. Verify that the well is dead. Paint line on tree, tubing head adapter, and tubing head. Take photo of tree position for reference at end of workover. 3. NO tree. NUBOP, 7-1/16" 5M. Top flange is 7-1/16", 5M. Function test BOP. MU blanking plug to lift threads. PT BOP rams to 250/3000 psi and annular to 250/3000 psi. (MASP = 1717 psi). Pull blanking plug. Pull BPV. (Note: 24 hr advance notification to AOGCC is required prior to testing BOPE) 4. Pick up the tubing hanger and attempt to pull tubing from Baker 80-40 GBH-22 Seal Assembly at 4929' RKB. If unsuccessful at 80% of 3.5" L-80 tubing yield strength (166M#), rig up E-line and chemical-cut the tubing in the middle of the first full joint above the seal assembly at 4908' RKB. POOH w/3.5" tubing and lay down all tubing pulled from seal assembly or above tubing cut. No equipment shall leave location until surveyed for NORM. Eauipment disposition: Tree Tbg Hanger and Adapter Tubing/Pups Mandrel Nipple Seal Assembly Inspect and re-use Inspect and re-use Junk Inspect and restock Inspect and restock Inspect and restock 5. If tubing was chemical cut, go to step #6. If seal assembly pulled OK, RIH w/3.5" completion, drifted to 2.867", as follows: · Use Jet Lube Run-N-Seal connection dope · Record OD's and ID's of all auxiliary equipment on tubing detail · Torque for IBT tubing is determined by averaging the makeup torque required for the first 15 joints. Proper makeup torque occurs when bottom of the pin makeup mark is flush with the top of the collar. a) Baker Seal Assembly w/Locator b) New full joint 3.5", 9.3#, L-80, IBT Mod SCC tubing c) 3.5" Camco 'OS' Nipple (2.813" 10, Top No Go) John Peirce Page 1 9/30/05 e Rig Workover Procedure Well 1 D-137 West Sak Injector Tubing Replacement e d) New full joint 3.5", 9.3#, L-80, IBT Mod see tubing e) 3.5 x 1" eamco KBG-2-9 Mandrel w/1500 psi SOY, w/10' IBT Mod see Pups above & below f) New 3.5", 9.3#, L-80, IBT Mod see tubing g) 3.5", 9.3#, L-80, IBT Mod see Pup(s) for space out h) New full joint 3.5", L-80, IBT Mod see tubing i) 3.5" IBT Mod see x 3.5" EUE 8rd XO j) Original 3.5" Vetco-Gray tubing hanger w/3.5" EUE 8rd Pup 6. If tubing was chemical cut, RIH w/3.5" completion, drifted to 2.867", as follows: · Use Jet Lube Run-N-Seal connection dope · Record OD's and 10'5 of all auxiliary equipment on tubing detail · Torque for IBT tubing is determined by averaging the makeup torque required for the first 15 joints. Proper makeup torque occurs when bottom of the pin makeup mark is flush with the top of the collar. a) Baker Slick Overshot (3.625" 10) b) 3.5" 'X' Nipple (2.75" 10) w/RHe plug installed c) New full joint 3.5", 9.3#, L-80, IBT Mod see tubing d) Baker SABL-3 Perm Packer (pinned 60M# shear) & PBR (pinned 40M# shear) e) New full joint 3.5", 9.3#, L-80, IBT Mod see tubing f) 3.5" eamco 'OS' Nipple (2.813" 10) g) New full joint 3.5", 9.3#, L-80, IBT Mod see tubing h) 3.5 x 1" eamco KBG-2-9 Mandrel w/1500 psi SOY, w/10' IBT Mod see Pups above & below i) New 3.5", 9.3#, L-80, IBT Mod see tubing j) 3.5", 9.3#, L-80, IBT Mod see Pup(s) for space out k) New full joint 3.5", 9.3#, L-80, IBT Mod see tubing I) 3.5" IBT Mod see x 3.5" EUE 8rd XO m) Original 3.5" Vetco-Gray tubing hanger w/3.5" EUE 8rd Pup John Peirce Page 2 9/30/05 e Rig Workover Procedure Well 1 D-137 West Sak Injector Tubing Replacement e 7. Locate seal assembly or tubing stub. Spot corrosion inhibited brine (1% by volume Baker Petro lite CRW-132) in IA below GLM prior to stabbing in/over. If necessary, hang tubing at neutral point, drop ball and rod, set SABL-3 Packer w/ 4500 psi and shear PBR. Space-out for 2' off bottom and land tubing hanger. RILDS. RU chart recorder to tubing & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 0 psi. PT IA to 2500 psi for 30 minutes. Bleed tubin to 1500 psi. Holding tubing pressure at 1500 psi, PT IA to 250U pSI lor 30 minutes. Bleed off tubing pressure to shear the ump I va ve. ns a NDBOP. NUWH. Test tree and packoffs to 5000 psi. RDMO. Turn well over to Production via Handover Form. Post Rig Work 1. Pull 2-way check valve. 2. Circulate out 9.6 Brine above GLM with corrosion inhibited brine (1% by volume Baker Petro lite CRW-132) and freeze protect well with Diesel. 3. RU Slickline. Pull SOV from GLM. 4. Reset DV in GLM. PT tubing to 2500 psi. 5. If necessary, retrieve ball & rod and RHC plug. 6. Pull WRP set in 3.5" liner at - 5000' RKB. Obtain SBHP. 7. RU CTU & perform FCO as deep as possible (tag of 8/9/05 showed 271' fill across the perfs). o ~ c <c "'-.)« \ \ '\ ~ \<C ~~ ,~~ ~ S<è.-<\,3\ CQ:- CD"'\--o-C+-- ~ \~::)\--~ \"'-J\ -\-'l't:"':,')éâ) K (l'" 1!f}]W \°7 f( John Peirce Page 3 9/30/05 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~r;- --'J g\~¡þ Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRU/1 0-137 07/29/05 Rogers - AES Packer Depth Well 10-137 Type Inj. N TVO 3,527' Tubing P.T.D. 2000470 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. d..()o"{)''+7 Pretest o o Initial 15 Min. 30 Min. 2000 1850 o 0 o F Interval P/F Well 10-137 Type Inj. N TVD 3,527' Tubing 1850 2000 P.T.D. 2000470 Type test P Test psi 1500 Casing 0 0 Notes: Mono-Annulus Integrity Verification MITT with plug in tbg 2nd bump up Well 10-137 Type Inj. N TVD 3,527' Tubing P.T.D. 2000470 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: 1950 o 1950 Interval o P/F o P 1800 2050 2050 2050 Interval 0 0 2540 2460 2450 P/F P Interval P/F Interval P/F SCi1~"NEJJ I\UG 0 9 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 06/19/02 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 1 D-137 07 -29-05-1.xls MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg IV (. , P.I. Supervisor 1\.er.1 b ZtloÇ DATE: Thursday, May 19,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lD-137 KUPARUK RIV U WSAK lD-137 ~..b/I"'"\ _.':At···t.7 otèYU . U T . FROM: J eff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :::JB¡z- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-137 API Well Number: 50-029-22956-00-00 Insp Num: mitJJ050518082411 Permit Number: 200-047-0 Rei Insp N urn: Inspector Name: Jeff Jones Inspection Date: 5/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lD-13 7 Type Inj. w TVD 3527 IA 0 1620 1570 1550 P.T. 2000470 TypeTest SPT Test psi 881.75 OA Interval 4YRTST P/F P Tubing 850 850 850 850 Notes: "Monobore" type injector. 1 well house inspected; no exceptions noted. Thursday, May 19, 2005 Page 1 of 1 .PHILLlPS Ala~ka, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY '1Ð'-137 j u' TUBING (0.4934, OD:3.500, ID:2.992) ~OOUCTION (0.4934, OD:5.500, Wt:15.50) Gas Lift mdrel/Dummy Valve 1 (4838-4839, 00:4.725) NIP (4891-4892, 00:3.500) SEAL (4929-4930, 00:3.500) Perf (5040-5090) Perf (5121-5161) Perf (5170-5190) Perf (5218-5262) Perf (5272-5280) Perf (5298-5347) r I r - l _J ( ì t ..............................,..."........,..."........,:......,..".....".:......:....."..',.....:..,.:..,.."..........".........,..'....:.......:...,...."....'..,.:...:"..."..,.:................,..',....,:.,:....:,.........,...:..::...'."....."........:.......:.. f··.···,·,·,··.'·,········ III ..'."'.,..,.'...'...:.:.,.....:...:.,:.'....":."".......:.."".'.:..:.,.:.........,'..,..,....:..'...:...:,.'.:....:..::.",.""'.'.":,,.'.'...,,':.:.:....'...',."........:::....:.:.,.....:....,...'.'...::.'.':..,..........::,.....'.....'.:.:.,..:.......':.....:..,.'..,......:"".......:,.........,.:..',:....:.....'...".',..:........"::.,'..,.:,......:.....,:.'.,:....'.,.:...'.',:....'...:.,..'......'..::.......':....'.,..:,...........,'....'..:..:......".'.....',.,.....:....:.:···.,··1 ... ....:.".,.:..,.."::,,.:';,:.:::.,. , .',.,.,',,-,.'- ..,"':"',"",':"'.':'" ----- - KRU API: 500292295600 SSSV Type: NONE Well Type: INJ Ong 5/25/2000 Completion: Last W/O: Rei Log Date: TO: 5615 ftKB Max Hole Angle 66 deg @ 2800 Size 16.000 5.500 3.500 Top o o 4934 Bottom 4934 Zone WSD WSB WSA4 WSA3 WSA3 WSA2 Status V Mfr 1 D-137 Angle 'â1 TS: deg ,11;1 Angle @ TO: 22 deg @ 5615 Rev Reason: Tagged nil Last Updale: 8/27:2002 Bottom 110 4934 5583 TVD 110 3531 4105 Wt 62.58 15.50 9.30 Annular Fluid: Reference Log: Last Tag: 5294 Last Tag Dale: 8/25/2002 Casing String - ALL Description CONDUCTOR PRODUCTION LINER TubilÏgStrii1g,.ALL Size I Top 3.500 0 Perforåiions Summary Interval TVD 5040 - 5090 3619 - 3661 5121 - 5161 3687 - 3722 5170-5190 3730-3747 5218-52623772-3811 5272 - 5280 3820 - 3827 5298 - 5347 3843 - 3887 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 4838 3454 CAMCO KBG29 CAMCO Other lJlugs, equip., etc.' - JEWELRY Depth TVD Type 4891 3496 NIP CAMCO OS NIPPLE 4929 3527 SEAL BAKER GBH-22 SEAL ASSY TVD 3531 Wt 9.30 Grade L-80 Ft SPF Date Type 50 4 7/6/2000 IPERF 40 4 7/6/2000 IPERF 20 4 7/6/2000 IPERF 44 4 7/1/2000 IPERF 8 4 7/1/2000 IPERF 49 4 7/1/2000 IPERF V Type VOD Latch Port TRO DMY 1.0 INT 0.000 0 Description Grade H-.10 L-80 L-80 Thread WELDED STCM STCM Thread EUE8RD Comment Date Run 6/27/2000 Vlv Cmnt ID 2.813 3.000 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Permit to Drill 2000470 Well Name/No. KUPARUK RIV U WSAK 1D-'137 Operator PHILLIPS ALASKA INC. APl No. 50-029-22956-00-00 MD 5615 TVD 4135 Completion Dat 7/1/2000.-~'' Completion Statu 1WINJ Current Status 1WINJ UIC Y ................... ._~.~.~_~_~" --~-'77_~i~_"-~i. ~. '~ ~7 ~-_'-~ '~7-'..-'~ ~ -~---~ REQUIRED INFORMATION Mud Log N_9o Sample N._~_o Directional Survey ~ ~,,/)~/j~q,~,~ .. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log Log Run Type MecjJa-''" Fit Name Scale Media No L --b-''''~' SCMT 5 FINAL L ~ Temp/Press/Spin 5 FINAL L '-E'~'~' TVD GR/ROP/EWR 5 FINAL L ~ MD GR/ROP/EWR 5 FINAL D EY'" .....· 10124 FINAL R ~ LIS Verification FINAL L ~-I=/'''''' Injection Profile 5 FINAL Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint) Interval OH / Dataset Start Stop CH Received Number Comments 69 5560 Open 5/1/2001 10124"~69-5560 4900 5442 CH 6/27/2000 BL(C) 4900-5442 4930 5300 CH 1/2/2001 4930-5300 BL, Sepia 110 5615 OH 5/1/2001 110-5615 110 5615 OH 5/1/2001 110-5615 BL, Sepia 69 5560 CH 5/1/2001 10124-"~5560 Digital Data CH 5/1/2001 LIS Verification 100 5310 OH 6/15/2001 100-5310 BL, Sepia Interval Name Start Stop Dataset Sent Received Number Comments ADDITIONAL INFORMA/~ON Well Cored? Y ~,.N_~ Chips Received? '~?'"/-N--' Analysis -"'i~7-1q'''~' Received? Daily History Received? ~--~N Formation Tops '~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Permit to Drill 2000470 Well Name/No. KUPARUK RIV U WSAK 1D-137 Operator PHILLIPS ALASKA INC. MD 5615 TVD 4135 C~o{npletion Dat 7/1/2000 Compliance Reviewed By: Completion Statu 1WINJ APl No. 50-029-22956-00-00 Current Status 1WINJ UIC Y i'2 "'~ -, Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1736 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 01/17~02 Well Job # Log Description Date BL Sepia CD Color 1C-125 ~'O'l-I(~j. PRESSURE STATION PBMS 12/28/01 I 1 1D-137 , ~C~-O~-f-/ INJECTION PROFILE 01/04/02 I 1 1D-138 ;~DC)-'OL./~ INJECTION PROFILE 01/05/02 I 1 1(~-2~ ?/5- / ~r~ PRESS-TEMP STAT,OHS PBMS 12/29/01 1 1 1Y-15A ! c~ ~,,_t ~O PRODUCTION PROFILE 01/02/02 I 1 1Y45A GAS UFT SURVEY 01/02/02 I 1 2K-28 :%1-I,,5'/ STATIC BOTTOM HOLE PRESS SURVEY 12/16/01 I 1 3A-03A ~Ob-' I c~/ LEAK DETECTION LOG 01/08/02 I 1 30-03 /~'-O~.~ PRODUCTION PROFILEW/DEFT 12/31/01 I 1 30-03 PROD PROF FIELD DEFT PRESENTATION 12/31/01 I 1 30-03 GAS LIFT SURVEY 12/31/01 I I DATE: RECEIVED JAN 2 5 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank Yl/~Jt!la~Oil&Gas C011s.~n ~e WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 24, 2001 MWD Formation Evaluation Logs 1D-137, AK-MM-00044 ., ofioO~0q-V 1 LDWG formatted Disc with verification listing. APl#: 50-029-22956-00 PLEASE ACKNOWI~EDGE RECEIPT ~Y SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date' RECEIVED MAY 01 2001 Alaska Oil & Gas C.x)ns. ~ 11128100 Schlumberger NO. 729 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print C' ,~ / '31-08 PRODUCTION PROFILE 001118 I I .. 3K-25 INJECTION PROFILE 001117 I 1 .., 1 D-136 INJECTION PROFILE 001119 1 1 1D-137 INJECTION PROFILE 001119 1 1 ..... 1 D-138 !INJECTION PROFILE 001120 1 1 ,,, 1 D-139 INJECTION PROFILE 001120 I 1 ,,. DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. _. STATE OF ALASKA ALAb,.A OIL AND GAS CONSERVATION COMk,,...;SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil F~ Gas F~ Suspended ~] Abandoned D Service [~] Water Injector 2. Name of Operator ~~! 7. Permit Number Phillips Alaska, Inc. ~ 200-47 3. Address ',SUf~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360r-i ~ i~¢.~,,, I-~ 50-029-22956 4. Location of well at sudace 4,,...-~,,..~,,~,¢~ 9. Unit or Lease Name · . 631' FNL, 602' FEL, Sec. 23, T11N, R10E, UM (ASP: 560491,5959034) - '- ; Kuparuk River Unit . *' ~ 10. Well Number At Top Producing Interval 1851' FSL, 90' FWL, Sec. 24, T11N, R10E, UM (ASP: 561206.5, 5956244), ,. ~.: 1D-137 At Total Depth ~ ~,"~"- 11. Field and Pool 1612' FSL, 163' FWL, Sec. 24, T11N, R10E, UM (ASP: 561282, 5956006) ....... .:. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool 30' RKB feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 16, 2000 May 20, 2000 N/A ,eet Ms, 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 5615' MD/4135'TVD 5487' MD/4016'TVD YES r~ No I N/A feet MD 1649' 22. Type Electric or Other Logs Run MWD/GR/Res/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 13.375" 68# L-80 Surface 110' 20" 7 cu yds High Early 5.5" X 15.5# L-80 Surface 4934' 7.875" 460 sx AS III, 375 sx Class G 3.5" 9.3# L-80 4934' 5583' 7.875" (included above) 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 4932' N/A 5298'-5347, MD 3843'-3890' TVD 4 spf 5272'-5280' MD 3820'-3827' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5218'-5262' MD 3772'-3811' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5040'-5090' MD 3619'-3661' TVD 4 spf N/A 5121'-5161' MD 3687,-3722' TVD 4 spf 5170'-5190' MD 3730'-3747' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak D Base West Sak D West Sak Base GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 5042' 5090' 5531' 3620' 3661' 4057' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF A-I-FACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~~¢~-,~~ Title Randy Thomas Kuparuk Drilling Team Leader Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/08/00 ARCO ALASKA INC. WELL SIIMMARY REPOI~~:I-~'~ :- "-~"" ' '::~'~':~ii::i-,~;~. Page: 1 WELL:iD-137 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:05/16/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22956-00 05/15/00 (D1) TD/TVD: 150/150 SUPV:M.C. HEIM MW: 0.0 VISC: ( 150) DRLG. ~ 150' 0 PV/YP: 0/ 0 APIWL: 0.0 Hang tree in cellar. NU diverter and function test. 05/16/00 (D2) MW: 8.8 VISC: 250 PV/YP: 51/57 APIWL: 5.0 TD/TVD: 1012/1009 (862) DRILLING AHEAD AT 1400' SUPV:DON WESTER & BRIAN NOEL Pre-spud meeting. RIH and tag at 99'. Spud well @ 0430 hrs., drill to 146' Drilling from 146' to 1012', kicked off at 500' 05/17/00 (D3) MW: 9.4 VISC: 250 PV/YP: 67/63 APIWL: 4.2 TD/TVD: 2564/2263 (1552) DRILLING AHEAD AT 2800' SUPV:DON WESTER & BRIAN NOEL Drilling from 1012' to 1789' Pumped hi-vis fiber sweep at 1700' Drilling from 1789' to 2564' Worked tight spot at 2468' to 2564' 05/18/00 (D4) MW: 9.5 VISC: 315 PV/YP: 77/95 APIWL: 4.3 TD/TVD: 3075/2515 ( 511) DRILLING AHEAD AT 3300' W/ BIT #2. SUPV:DON WESTER & BRIAN NOEL Drill from 2564' to 3075'. During last 100' gravel began sloughing ECD's increased to 11+ and ROP fell off, raised vis to 300+ to clean hole. Circ and condition hole. POOH, tight spot at 200', circ and ream, POOH. RIH. 05/19/00 (D5) MW: 9.4 VISC: 300 PV/YP: 62/75 APIWL: 4.2 TD/TVD: 4416/3152 (1341) DRILLING AHEAD AT 4805' SUPV:DON WESTER & BRIAN NOEL Finish RIH from 1900' to 3075'. Wash each stand to bottom, tight at 1925' and 2015'. Circ and work pipe to clean hole, lots of gravel in returns. Drill from 3075' to 4416' 05/20/00 (D6) MW: 9.6 VISC: 280 PV/YP: 55/63 APIWL: 4.0 TD/TVD: 5615/4135 (1199) POOH W/ BIT #2, TD IS 5615'. SUPV:DON WESTER & BRIAN NOEL Drill from 4416' to 5160'. Intermittent running gravel. Drill from 5160' to 5615' 05/21/00 (D7) MW: 9.6 VISC: 280 PV/YP: 67/73 APIWL: 4.2 TD/TVD: 5615/4135 ( 0) WAIT ON CEMENT.(WILL DRILL OUT @ 0700 HRS 5/22/2000) SUPV:DON WESTER & BRIAN NOEL Pre-trip sweep returns plugged flowline with large gravel Date: 08/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 and cobbles, cuttings auger broke down. Flush flowline w/water. POOH. RIH w/hole opener, set down at 170'. Start circulating at 1 bpm and 200 psi, wash to 190'. Lost returns, conductor broach, mud coming up outside of cellar. POOH. Pump cement. Mud returns up outside of cellar and draining into cellar. WOC. 05/22/00 (D8) MW: 9.6 VISC: 310 PV/YP: 56/73 APIWL: 4.2 TD/TVD: 5615/4135 ( 0) CIRCULATE & CONDITION MUD AT 5615' TD SUPV:DON WESTER & BRIAN NOEL Continue WOC. RIH and tag at 73' Drill cement to 121' Unplug flowline jet and clean rocks/cement from mud pit. Ream and work past tight spot from 173' to 210'. Wash into hole to 1208'. POOH to 150'. Ream tight spot from 173' to 223'. POOH. RIH w/7-7/8" hole opener. Run through tight spot w/o problems, wash and ream to 3554' 05/23/00 (D9) TD/TVD: 5615/4135 ( SUPV:M.C. HEIM MW: 9.6 VISC: 294 PV/YP: 52/61 0) TEST CSG. TO 3000# APIWL: 4.2 Circ and reaming hole from 3554' to 5615' Circ and condition mud and hole. Drop survey, pump liner pill and dry job. POH. PJSM. RIH with 3.5" and 5.5" casing. 05/24/00 (D10) TD/TVD: 5615/4135 ( SUPV:M.C. HEIM 0) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Circ, work pipe and condition mud for cementing casing. PJSM. Pump cement. Bump plug, check floats, OK. ND diverter. NU BOPE and test to 250/3000#. PJSM. Run 3.5" completion assembly. 05/25/00 (Dll) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 5615/4135 ( 0) RIG ON NEW WELL. SUPV:M.C. HEIM ND BOPE. N/U tree and test packoff 5000#, test tree 5000#. Freeze well with diesel. Prep and move rig off well. Release rig from 1D-137 0 1200 hrs. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-137(W4-6)) WELL 1D-137 DATE 07/01/00 DAY 3 JOB SCOPE DRILLING SUPPORT-CAPITAL DALLY WORK PERFORATE OPERATION COMPLETE I SUCCESSFUL NO I NO Initial Tbg Press I Final Tbg Press Initial Inner Ann 0 PSII 100 PSI 0 PSI DALLY SUMMARY JOB NUMBER 0602001836.3 UNIT NUMBER 2145 KEY PERSON SWS-SPENCER Final Inner Ann I Initial Outer Annlo PSI O PSI SUPERVISOR KENNEDY Final Outer Ann 0 PSI PERFORATED (5298'-5347', 5272'-5280', 5218'-5262') W/2-1/2" HSD, U J, DP, 4 SPF, 60 DEGREE PHASING.[Perf] TIME LOG ENTRY 07:30 SWS MIRU - SAFETY MEETING 08:45 PT WELL TO 3K PSI; DISCUSS W/DS ENGINEER DISCREPANCY IN PERF PROCEDURE. WAS DECIDED TO EXTEND 1ST INTERVAL TO 5347'. 09:00 09:20 ARMED GUN #1 ( INTERVAL 5317 - 5347 FT MD) - RIH LOG DOWN ACROSS JEWELRY COUNTING COLLARS 09:30 LOG UP A TIE IN PASS ACROSS JEWELRY 09:50 LOG INTO POSITION TO SHOOT GUN #1 - GOOD DETONATION INDICATION 10:30 AT SURFACE - CONFIRM ALL SHOTS FIRED - STAND DOWN FOR EVACUATION DRILL 12:00 DRILL COMPLETE - ARMED GUN #2 - INTERVAL = 5298 - 5317 FT - RIH 12:30 LOG DOWN ACROSS JEWELRY COUNTING COLLARS 12:45 LOG UP INTO POSITION TO FIRE GUN #2 - GOOD DETONATION INDICATION 13:00 AT SURFACE - CONFIRM ALL SHOTS FIRED 13:05 GUN #3 ARMED - INTERVAL = 5272 - 5280 FT MD - RIH 13:20 LOG DOWN ACROSS JEWELRY COUNTING COLLARS 14:00 LOG UP INTO POSITION TO SHOOT GUN #3 - GOOD DETONATION INDICATION 14:15 AT SURFACE - CONFIRMED ALL SHOTS FIRED 14:30 GUN #4 ARMED - INTERVAL 5238 - 5262 FT MD - RIH 14:50 LOG DOWN ACROSS JEWELRY - COUNTING COLLARS 15:15 LOG UP INTO POSITION TO SHOOT GUN #4 - GOOD INDICATION OF DETONATION 15:30 AT SURFACE - CONFIRMED ALL SHOTS FIRED 15:45 GUN #5 ARMED - INTERVAL = 5218 - 5238 FT - RIH 16:15 LOG DOWN ACROSS JEWELRY COUNTING COLLARS 16:30 LOG UP INTO POSITION TO SHOOT GUN #5 - GOOD INDICATION OF DETONATION 17:15 AT SURFACE - CONFIRMED ALL SHOTS FIRED - BEGIN RIG DOWN 18:15 RIG DOWN COMPLETE - CALLED DSO - LEFT PAD a3~l._-I $10H$ -I-IV (]31AiI::II-INO0 - 30V--I'dNS NOI_LYNOI30 30 NOII¥OIQNI GOO0 - cj# NNE) IOOHS O_L NOI_LISOd OJ_NI dN 909 01.:1~1. 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Schlumberger NO. 238 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ComPany: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1C-26 99450 MEM GR/CCL 991030 I ' I 1 1D-125 I,It(' 20248 SCMT 000529 1 1D-137 20249 SCMT 000604 1 1D-138 20250 SCMT 000604 1 , RECEIVED s,~.=o: O^TE: dUN 27 2000 Alaska 0ii & Gas Cons. C0mmissl0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax tO (907) 561-8317.jog16J~FJijjJJu. 6/13/00 07-Jun-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-137 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 5,615.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Alien Survey Manager Attachment(s) JUN 0 8 !00C 0ii & G~.s CoDs. Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-137 Surveyed: 21 May, 2000 SURVEY REPORT 7 June, 2000 Your Ref: API-500292295600 Surface Coordinates: 5959034.40 N, 560490.80 E (70° 17' 55.1166" N, 149° 30' 36.4361" W) Kelly Bushing: 101.22ft above Mean Sea Level sper~r',v-mum 13 R,! L L, ! ,,,N I~,,, RECEJYED JUN 0 8 ~00~. Anchorage Survey Ref: svy9227 90 3;0' ~ ~s~nOllHO uo!ss?.t;tuo3 'suo3 s~9 ~ 1!0 mtsqv t~,:Ol - 000~' 'aun[' Z ' "penu!¢uoo _. luetuwoo ZS'gg9 ZS'g9S 19'S61~ gg't, gt' 00'09S 9 I. 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Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4.834.37 37,220 165.060 3349.36 3450.58 2681.81 S 658.14 E 5956357.98 N 561170.50 E 4931.87 35.360 162,140 3427.95 3529.17 2737.16 S 674.39 E 5956302.76 N 561187.20 E 5028.83 33.400 162.400 3507.96 3609.18 2789.31 S 691.07 E 5956250.75 N 561204.30 E 5126.23 30.660 163.720 3590.53 3691.75 2838.71 S 706.14 E 5956201.47 N 561219.77 E 5223.92 27.860 162.380 3675.75 3776.97 2884.38 S 720.03 E 5956155.91 N 561234.03 E 5319.94 25.370 162,380 3761.59 3862.81 2925.38 S 733.05 E 5956115.02 N 561247.38 E 5415.86 23.380 162.530 3848.95 3950.17 2963.12 S 744.99 E 5956077.37 N 561259.62 E 5513.14 21.580 163.250 3938.84 4040.06 2998.67 S 755.94 E 5956041.92 N 561270.85 E 5615.00 21.580 163,250 4033.56 4134.78 3034.54 S 766.74 E 5956006.13 N 561281.94 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.629° (16-May-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 167.340° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5615.00ft., The Bottom Hole Displacement is 3129.91ft., in the Direction of 165.820° (True). Alaska State Plane 4 Kuparuk 1D ' Dogleg Vertical Rate Section (°/100fi) (fi) 3.135 2760,85 2.604 2818,42 2.027 2872.95 2.903 2924.45 2.943 2972.06 2.593 3014.92 2.076 3054.36 1,872 3091.44 0.000 3128.81 Comment Projected survey RECEIVED JUN 0 8 ,o00f - Anchorage Continued... 7 June, 2000 - 10:21 - 4 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 1D-137 Your Ref: API.500292295600 Surveyed: 21 May, 2000 Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 5615.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4134.78 3034.54 S 766.74 E Comment Projected survey Survey tool program' From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 5615.00 4134.78 Survey Tool Description MWD Magnetic RECEIVED JU~ 0 8 ~OOC, - Alaska Oil & Gas Oo:~s. Co,re.mission Ancho~'age 7 June, 2000 - 10:21 - 5 - DrillQuest 1.05.05 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson ~,.~._ Chairman DATE: May 23, 2000 THRU: Blair Wondzell ~1~~ P.I. Supervisor (o[~~ FROM: Lou Grimald~O.o.- ~etroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nordic rig #3 '- Phillips 1D pad 1D-137 200-047 Kuparuk River FieldlUnit':'~/ Operator Rep,: Dink Helm Contractor Rep.: Lance Johnson Op. phone: 659-7872 Rig phone: 7653 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 250/3000 Annular: 250/3000 Choke: 250/3000 TEST DATA MISC. INSPECTIONS: FLOOR VALVES: MUD SYSTEM: Visual Alarm P/F P/F Quantity P/F Trip Tank P P Location Gen.: P Sign: P Upper Kelly 1 P Pit Level Indicators P P Housekeeping: P Rig cond: P Lower Kelly I P Flow Indicator P P PTD On Location P -' Hazard: P ' Ball Type I P Meth Gas Detector P P Standing Order: P - Inside BOP I P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 11" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 11"x3 1/2 P Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 11"x3 1/2 P No. Valves 14 P After Closure 1850 - P Blind Rams 1 11" P Man. Chokes 1 P 200 psi Attained :17 P Choke Ln. Valves 1 3" P Hyd. Chokes 1 P Full Pressure 1:32 P HCR Valves 1 3" P Blind Covers (All Stations): P Kill Line Valves 2 2" P N2 Bottles (avg): 4 @ 1950 Check Valve 0 Test's Details I arrived to find the crew changing the bottom rams to 3 1/2 fixed pipe rams. The test was started immediately after. All BOP equipment was tested without any failures observed. The rig was in good shape and the crew performed well during the test. Total Test Time: 3 Number of failures: cc: MorrisonlOverstreet (KRF drilling) Attatchments: None BOP Nordic 6/28/00 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Umt 1 D- 13 7 ARCO Alaska. Inc. Permit No: 200-047 Sur. Loc. 633' FNL. 598' FEL, Sec. 23. TllN, R10E. UM Btmhole Loc. 1502' FSL. 105' FWL, Sec. 24, TllN, R10E, UM Dear Mr. Alvord: Enclosed is tile approved application for permit to drill tile above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other rcquircd permitting detemfinations are made. Annular disposal has not been requested as part of the Penmt to Drill application for Kuparuk River Unit Well No. 1 D-137. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing m~nulus of a -,','ell approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.00(} barrels through thc almular spacc of a single well or to use that well for disposal purposes for a period longer than one year. Thc blov,:out prevention cquiplnent (BOPE) must be tested in accordance with 20 AAC 25.(}35' and the mechanical integrit>.' (MI) of the injection wells must be demonstrated under 20 AAC 25.4 ! 2 and 20 AAC 25.030(g)(3). Sufficient notice (approximatcly 24 hours) of thc MI test before operation, and o1' the BOPE test performed before drilling below thc surface casing shoe. must be givcn so that a rcprcscntativc of thc Comnfission may witness the tests. Notice may be given by contacting the Comlnission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Clu'istenson. P.E. Chair BY ORDER OF THE..CLOMMISSION DATED this ! ~ ~ day of April, 2000 dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill [] Redrill D lb. Type ofwell. Exploratory D StratigraphicTest O Development Oil Re-entry D Deepen D Service r~l Development Gas D Single Zone r~ Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 101' above sea level 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 633' FNL, 598' FEL, Sec. 23, T11N, R10E, UM (ASP: 560493.3, 5959034) Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1652' FSL, 72' FWL, Sec. 24, T11N, R10E, UM (ASP: 561190, 5956045) 1 D-137 #U-630610 At total depth 9. Approximate spud date ~mount 1502' FSL, 105' FWL, Sec. 24. T11N, R10E, UM (ASP: 561224.8, 5955895.8) May 2, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1502' @ TD feetI 1D-08 29.3' @ 586' MD feet 2560 5695' MD/4138 'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 500' MD Maximum hole angle 64° I Maximum surface 1379 psig At total depth (TVD) 1811 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~ Weight Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 20" 13.375" 68# L-80 BTC 50' 30' 30' 80' 80' Pre-installed 7.875" 5.5" x 15.5# L-80 BTCM 4978' 30' 30' 5008' 3521' 440 sx Class G & 375 sx Class G 7.875" 3.5" 9.3# L-80 EUE 8rd M 687' 5008' 3521' 5695' 4138' (included in above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface -: Production #REF! Perforation depth: measured :, true vertical 20. Attachments Filing fee r~l Property Plat F~ BoP Sketch r~l Diverter Sketch r~l Drilling program r~l Drilling fluid program ~] Time vs depth plot r--~Reffaction analysis D Seabed report r'~ 20 AAC 25.050 requirements BI 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Carl Mark Chambers 265-131~. Signed ~ ~ ~-'~ Title: Drilling EngineeringSuperv/sot' Date 'l~-'~[O0 Chip Alvord prP, n~r~d hv ,~harnn AII.sun-I')rak~ Commission Use Onl} Permit Number lAP, number Approval date 4/ /C_,~' See cover letter 2 GO -- ~ 7 50- ~,2 ~--..~¢;~ -' 2~ ~., ~,.~"~" /'~ for other requirements Conditions of approval Samples required D Yes [~ No Mud logrequired FI Yes [] No Hydrogen sulfldemeasures E~] Yes I~ No Directional surveyrequired [] Yes r-1 No Required working pressure for BOPE F~2M; F~G BI 5M; FI lOM;D r~ cc~(,.-~ ~¢~,(-r ~(2~L Other: ORIGINAL SIGNED. By by order of ~ ~ Approved by Rober~ N. Chfist~.n.~r,~ commissioner the commission Date ,4L/ ~ Form 10-401 Rev. 12/1/85 · Submit in triplicate 1D-137 West Injector 5-1/2" x 3-1/2" Tapered String Planned Completion 13-3/8" 68# L*80 BTC ~ Conductor @ 80' TAM 5-I/2" Pod Collar BTC Box x Pin set @ +/~ 1000'TVD Set XO / SBE ~/: 100! above top Per[oration D-Sands (plan to perforate off rig) 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" EUE 8RD-Mod piti down. 3-1/2" 9.3# L-80 EUE 8RD Mod Tubing to surface. 3-1/2" x 1" Camco 'KBG-2*9' GLM w/DV & latcl' 3-1/2' x 6' Handltng Pups installed on lop and poi[om v., BTCM Pin x EUE 8RD Mod Box Special Clearance Couolings. 1 Joint 3-1/2" 9.3# L-80 EUE 8RD*Mod Tubing. 3-1/2" Camco 'DS' Landing Nipple w/2.812" No-Go Profile. I Joint 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing, 3-1/2" Baker GBH-22 '80-40 Locator Sea Assembly ,~ 12' of Seals and Locato. r 3-1/2" x 6' L-80 Handhng Pup installed on toD. EUE 8RD-Mod Box Baker Casin~c Bore Recepticle Assembly FB Baker 5-1/2" XO / Handl{ng Pup, BTC x LTC I Baker ~,O. Coupl?g w/locator shoulder, LTCx SBE Baker 5 OD x 4 tD Seal Bore Extension 12' bBBaker XO SBE x 3-1/2'~ EUE 8RD B-Sands (plan to perforate of/ rig) A'Sands (pla. n ~0 perforate off rig) 3-1/2" 9.3# L-80 EUE 8RD Mod Tubing from Landing Steeve to SBE 3-1/2" Weamerford Landing Sleeve installed in top of joint ¢S. 1 Joints 3-1/2" 9.3# L-80 EUE8RD-ModTubing. 3-1/2" Weatherfora =loat Collar w/3-1/2" EUE 8rd Box x Pin. 2Joints 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2 Weamerford Float Shoe w/3-1/2" EUE 8rd Drill, Case and Completion Plan for West Sak 1 D-137 Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 13-3/8". Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 7-7/8" hole to desired target through West Sak interval. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 3-1/2" 9.3# L-80 EUE 8rd x 5-1/2" 15.5# L-80 BTCM tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: 5-1/2" Port Collar to be installed @ +/- 1,000' TVD. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. 7. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 8. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to brine. 9. Sting into seal bore extension and space out. 10. With seal assembly unstung, freeze protect well with diesel 11. Sting into seal bore extension and land tubing. 12. Using diesel, pressure test tubing and annulus to 3,000 psi. Install back pressure valve. 13. Nipple down BOP stack. Install production tree and pressure test same. 14. Secure well and release rig. 15. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 16. Rig up E-line unit and RIH with CBL / CET. Run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 17. Rig up E-line unit and RIH with through-tubing perforating guns. 18. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 19. Install back pressure valve, shut in and secure well. MAC 3/28/00 Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1 D-137 Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Drilling Fluid Properties Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5 8-15 30-60 250 15-30 25-55 8-15 8-9 5-8 Spud to TD Final 9.4 - 9.6* 10-20 30-60 250 10-25 25-55 6 8-9 5-8 Drilling Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators * 9.8 ppg if hydrates are encountered. Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000 feet TVD. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1 D-137 well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can be safely drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.3 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,605'. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3938 ft)(0.46- 0.11 psi/ft) = 1379 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of 3,000 psi. The 5-1/2" 15.5# L-80 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-137 area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1 D drilling results, 9.8 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1 D-137. Well Proximity Risks: The nearest existing well to 1 D-137 is 1D-08. The wells are 29.3' from each other at a depth of 586' MD. The nearest planned well to 1D-137 is 1D-138. As currently planned, the wells will be 15' from each other at a depth of 300' MD. Gyro Surveys will be required to validate survey integrity. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-137 surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 16" DIVESTER SCHEMATIC- Nr'"dic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 10" 15O ANSI Blanked I4 3 Open I I Closed _,/~ '~_ _ Closed _ _ ..~lr 3" Ball Valve Blanked · To Accumulator I ~. .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16"x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line - Nordic MAC 3/7/OO 5000 psi BOP Stac' Kuparuk River Unit West Sak Operations -Injector Wells Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" x 11" 5000 psi Double Studded Adapter/Spacer Spool 4. 11" 5000 psi Pipe Rams 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines 6. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 7. 11" 5000 psi Annular Preventer MAC 3/28/OO 1D-137 West Sak Injector Well Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 300 % above. Drilled with 7 7/8" bit. 5 1/2", 15.5# X 3 V2", 9.3# Tapered string. Crossover Joint @ 4976' (approximately 100' above the D Sands), TI) @ 5696' MD. Top of Tail cement @ 4450' (minimum of 500' above the top of the crossover joint). Single Stage Design. Port Collar contingency at 1000' MD if no cement to surface. Base of the Permafrost at 1686' MD, Volume Calcs: Pump 20 bbls Arco Preflush, 50 bbls MUDPUSH XL @ 10.0 ppg. Cement from MD to 4450' with Class G + adds @15.8 ppg and from 4450' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 -4.44 ft3/sk Above Permafrost: 5.5" x OH (300% excess): (1686') x 0.1732 ft3/ft x 4 = 1168.1 ft3 Below Permafrost: 5.5" x OH (45% excess): (4450'-1686') x 0.1732 ft3/ft x 1.45 = 694.2 ft3 Total: 1168.1 ft3+ 694.2 ft3 = 1862.3 ft3 1862.3 ft3/4.44 ft3/sk = 420 sks - Round up to 440 sks Have an additional 260 sks of lead on location for Top Out/2"d stage, if necessary - enough cement to fill the annular space (300 % excess) and the inside of the drill pipe from port collar to surface. Tail Slurry Requirements: 15.8 ppg Class G + 0.5%S1, 0.2%D46, 0.3%D65, 0.4%D167 - 1.17 ft3/sk Below Permafrost: 5.5" x OH (45% Excess): (4976'-4450') x 0.1732 ft3/ft x 1.45 = 3.5" x OH (45% Excess): (5696'-4976') x 0.2714 ft3/ft x 1.45 = 80' shoe joint: 80' x 0.04822 ft3/ft = Total: 132.1 ft3 283.3 ft3 3.9 ft3 132.1 ft3 + 283.3 ft3 + 3.9 = 415.4 ft3/1.17 ft3/sk = 415.4 ft3 355 sks - Round up to 375 sks BHST = 70F, BHCT = 65F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.0 ppg MUDPUSH XL, 420 sks (332 bbls) ASLite Lead, drop plug, 355 sks (74 bbls) Class G + adds Tail, drop plug, displace with rig. Circulation: Circulation at or less than 7 bpm is within safe ECD limits without breaking down the formation. Perform the designed cement job at a rate between 4 and 6 BPM for mud removal in Effective Laminar Flow. Drop the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 1300 psi at 3 bpm. At 7 bpm, expect 10 minutes of u-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 9.5 ppg or lower, Pv =15 to 20, Ty = 15 to 20 or lower - As thin and as light as possible to aid in the removal of mud during the cement job. This is the most important part of the cement job. James Franks can be reached at the Arco Tower, home or by cellular at the following numbers regarding this job or any other assistance: 265-6205(w), 248-3595(h), 223-5148(ce11). Jdf 3/16/00 (qpoN enJ_L) o I.'178'Z91. :ql. nu.J!zv uo!l.0es 0008 00'ff~ I QA.L 00'gCL~ 'QI/q ZW§69g - Jeu!l .~/L ~ X .~/L g OA..L IJ00'SC LI:' 'GIN HZ'¢'§699: qldeQ lelO.i uoiloes leO!:l. 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Depth (ft) (ft) 0.00 0.000 0.000 -95.00 200.00 0.000 0.000 105.00 400.00 0.000 0.000 305.00 500.00 0.000 0.000 405.00 550.00 0.750 167.341 455.00 600.00 1.500 167.341 504.99 650.00 2.250 167.341 554.96 700.00 3.000 167.341 604.91 750.00 3.750 167.341 654.82 800.00 4.500 167.341 704.69 850.00 5.750 167.341 754.49 900.00 7.000 167.341 804.18 950.00 8.250 167.341 853.74 1000.00 9.500 167.341 903.14 1050.00 10.750 167.341 952.36 1100.00 12.000 167.341 1001.38 1150.00 13.250 167.341 1050.17 1200.00 14.500 167.341 1098.71 1250.00 16.250 167.341 1146.91 1300.00 18.000 167.341 1194.70 1350.00 19.750 167.341 1242.00 1400.00 21.500 167.341 1288.80 1450.00 23.250 167.341 1335.03 1500.00 25.000 167.341 1380.66 1550.00 26.750 167.341 1425.65 Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959034.01 N 200.00 0.00 N 0.00 E 5959034.01 N 400,00 0.00 N 0.00 E 5959034.01 N 500.00 0.00 N 0.00 E 5959034.01 N 550.00 0.32 S 0.07 E 5959033.69 N 599.99 1.28 S 0.29 E 5959032.73 N 649.96 2.87 S 0.65 E 5959031.14 N 699.91 5.11 S 1.15 E 5959028.91 N 749.82 7.98 S 1.79 E 5959026.04 N 799.69 11.49 S 2.58 E 5959022.54 N 849.49 15.85 S 3.56 E 5959018.19 899.18 21.26 S 4.78 E 5959012.79 948.74 27.74 S 6.23 E 5959006.32 998.14 35.26 S 7.92 E 5958998.81 1047.36 43.84 S 9.85 E 5958990.25 1096.38 53.46 S 12.01E 5958980.65 1145.17 64.12 S 14.40 E 5958970.01 1193.71 75.82 S 17.03 E 5958958.33 1241.91 88.76 S 19.94 E 5958945.42 1289.70 103.12 S 23.16 E 5958931.08 1337.00 118.90 S 26.71E 5958915.33 1383.80 136.08 S 30.57 E 5958898.18 1430.03 154.65 S 34.74 E 5958879.64 1475.66 174.59 S 39.22 E 5958859.74 1520.65 195.88 S 44.00 E 5958838.49 Global Coordinates Dogleg Eastings Rate (ft) (°/100ft) 560493.32 E 560493.32 E 0.000 560493.32 E 0.000 560493.32 E 0.000 560493.40 E 1.500 560493.62 E 1.500 560493.99 E 1.500 560494.51 E 1.500 560495.18 E 1.500 560495.99 E 1.500 N 560497.01 E 2.500 N 560498.27 E 2.500 N 560499.77 E 2.500 N 560501.53 E 2.500 N 560503.52 E 2.500 N 560505.76 E 2.500 N 560508.24 E 2.500 N 560510.96 E 2.500 N 560513.97 E 3.500 N 560517.31E 3.500 N 560520.98 E - 3.500 N 560524.98 E 3.500 N 560529.30 E 3.500 N 560533.94 E 3.500 N 560538.89 E 3.500 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 0.00 0.00 o.oo o.oo 0.33 1.31 2.94 5.23 8.18 11.77 16,24 21.79 28.43 36.14 44.93 54.79 65.72 77.71 90.97 105.69 121.86 139.48 158.51 178.94 200.76 Comment Start Dir @ 1.500°/100ft: 500.00ft MD, 500.00ft TVD Dir R~elncrease @ 2.500°/100~:800.00~ MD, 799.69ff TVD Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1193.71ft TVD Continued... 16 March, 2000 - 12:42 - I - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-137 WPs - 1D-137 WP1 Revised: 10 February, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 1600.00 28.500 167.341 1469.95 1770.68 28.500 167.341 1619.95 1800.00 29.673 167.341 1645.57 1850.00 31.673 167.341 1688.57 1900.00 33.673 167.341 1730.65 1950.00 35.673 167.341 1771.77 2000.00 37.673 167.341 1811.87 2050.00 39.673 167.341 1850.91 2100.00 41.673 167.341 1888.83 2150.00 43.673 167.341 1925.59 2200.00 45.673 167.341 1961.14 2250.00 47.673 167.341 1995.45 2300.00 49.673 167.341 2028.47 2350.00 51.673 167.341 2060.15 2400.00 53.673 167.341 2090.47 2450.00 55.673 167.341 2119.38 2500.00 57.673 167.341 2146.85 2550,00 59.673 167.341 2172.85 2600.00 61.673 167.341 2197.33 2650.00 63.673 167.341 2220.29 2667.27 64.363 167.341 2227.85 2800.00 64.363 167.341 2285.28 3000.00 64.363 167.341 2371.81 3200.00 64.363 167.341 2458.34 3400.00 64.363 167.341 2544.88 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1564.95 218.50 S 49.08 E 5958815.91 N 560544.16 E 1714.95 297.97 S 66.93 E 5958736.59 N 560562.64 E 1740.57 311.87 S 70.05 E 5958722.71 N 560565.88 E 1783,57 336.76 S 75.64 E 5958697.87 N 560571.67 E 1825,65 363.09 S 81.55 E 5958671.59 N 560577,79 E 1866.77 390.84 S 87.79 E 5958643.89 N 560584.25 E 1906.87 419.98 S 94.33 E 5958614.81N 560591.03 E 1945.91 450.46 S 101.18 E 5958584.38 N 560598.12 E 1983.83 482.25 S 108.32 E 5958552.64 N 560605.52 E 2020.59 515.32 S 115.74 E 5958519.64 N 560613.21E 2056.14 549.61S 123.45 E 5958485.41N 560621.19 E 2090.45 585.10 S 131.42 E 5958449.99 N 560629.45 E 2123.47 621.73 S 139.65 E 5958413.42 N 560637.97 E 2155.15 659.47 S 148.12 E 5958375.76 N 560646.75 E 2185.47 698.26 S 156.83 E 5958337.04 N 560655.77 E 2214.38 738.06 S 165.77 E 5958297.31N 560665.03 E 2241.85 778.82 S 174.93 E 5958256.63 N 560674.51E 2267.85 820.49 S 184.29 E 5958215.03 N 560684.21 E 2292.33 863.02 S 193.84 E 5958172.58 N 560694.10 E 2315.29 906.36 S 203.57 E 5958129.32 N 560704.19 E 2322.85 921.50 S 206.98 E 5958114.20 N 560707.71E 2380.28 1038.26 S 233.20 E 5957997.66 N 560734.87 E 2466.81 1214.19 S 272.72 E 5957822.06 N 560775.80 E 2553.34 1390.11 S 312.23 E 5957646.45 N 560816.73 E 2639.88 1566.04 S 351.75 E 5957470.85 N 560857.66 E Dogleg Rate (°/100ft) 3.500 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 223.95 305.39 319.64 345.15 372.14 400.58 430.44 461.68 494.27 528.16 563.31 599.68 637.22 675.90 715.65 756.45 798.22 840.93 884.52 928.94 944.46 1064.12 1244.44 1424.75 1605.06 Comment End Dir: 1600.00ft MD, 1564.95ft TVD Start Dir @ 4.000°/100ft: 1770.68ft MD, 1714.95fl TVD End Dir: 2667.27ft MD, 2322.85ft TVD Continued... 16 March, 2000 - 12:42 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-137 WPs - 1D-137 WP1 Revised: 10 February, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 3600.00 64.363 167,341 2631.41 3800.00 64.363 167.341 2717.94 4000.00 64,363 167,341 2804.47 4070.04 64.363 167.341 2834.78 4100.00 63.465 167.341 2847.95 4150.00 61.965 167.341 2870.87 4200.00 60.465 167.341 2894.95 4250.00 58.965 167.341 2920.16 4300.00 57.465 167.341 2946.50 4350.00 55.965 167.341 2973.94 4400.00 54,465 167.341 3002.46 4450.00 52.965 167.341 3032.05 4500.00 51.465 167.341 3062.68 4550.00 49.965 167.341 3094.34 4600.00 48.465 167,341 3127.00 4650.00 46.965 167.341 3160.64 4700.00 45.465 167.341 3195.24 4750.00 43,965 167.341 3230.77 4800.00 42.465 167.341 3267.21 4850.00 40.965 167.341 3304.53 4900.00 39,465 167.341 3342.71 4950.00 37.965 167.341 3381.72 5000.00 36.465 167.341 3421.54 5050.00 34.965 167.341 3462.14 5100.00 33.465 167.341 3503.48 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2726.41 1741.97 S 391.26 E 5957295.25 N 560898.59 E 2812.94 1917.90 S 430.78 E 5957119.64 N 560939.52 E 2899.47 2093.83 S 470.29 E 5956944.04 N 560980.45 E 2929.78 2155.44 S 484.13 E 5956882.54 N 560994.79 E 2942.95 2181.69 S 490.03 E 5956856.33 N 561000.89 E 2965.87 2225.05 S 499.76 E 5956813,06 N 561010.98 E 2989.95 2267.80 S 509.37 E 5956770.38 N 561020.93 E 3015.16 2309.93 S 518.83 E 5956728.33 N 561030.73 E 3041.50 2351.39 S 528.14 E 5956686.94 N 561040.38 E 3068.94 2392.17 S 537.30 E 5956646.24 N 561049.86 E 3097.46 2432.24 S 546.30 E 5956606.25 N 561059.18 E 3127.05 2471.56 S 555.13 E 5956567.00 N 561068.33 E 3157.68 2510.12 S 563.79 E 5956528.51 N 561077.30 E 3189.34 2547.88 S 572.27 E 5956490.82 N 561086.09 E 3222.00 2584.81 S 580.57 E 5956453.95 N 561094.68 E 3255.64 2620.90 S 588.68 E 5956417.93 N 561103.08 E 3290.24 2656.12 S 596.59 E 5956382.78 N 561111.27 E 3325.77 2690.44 S 604.30 E 5956348.52 N 561119.26 E 3362.21 2723.85 S 611.80 E 5956315.18 N 561127.03 E 3399.53 2756.31 S 619.09 E 5956282.77 N 561134.58 E 3437.71 2787.81 S 626.17 E 5956251.33 N 561141.91 E 3476.72 2818.32 S 633.02 E 5956220.88 N 561149.01 E 3516.54 2847.82 S 639.65 E 5956191.43 N 561155.87 E 3557.14 2876.30 S 646.04 E 5956163.01 N 561162.50 E 3598.48 2903.73 S 652.20 E 5956135.62 N 561168.88 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 0.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 1785.37 1965.68 2145.99 2209.14 2236.05 2280.48 2324.30 2367.48 2409.98 2451.77 2492.84 2533.14 2572.65 2611.35 2649,21 2686.2O 2722.30 2757.47 2791.71 2824.98 2857,26 2888.53 2918.77 2947.96 2976.07 Comment Start Dir @ 3.000°/100ft: 4070.04ft MD, 2929.78ft TVD Continued... 16 March, 2000 - 12:42 ~ 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-137 WPs - 1D-137 WP1 Revised: 10 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 5107,80 33.231 167.341 3510.00 3605.00 2907.91 S 653.14 E 5150.00 31.965 167.341 3545,55 3640.55 2930.09 S 658.12 E 5184.52 30.929 167.341 3575.00 3670.00 2947.67 S 662.07 E 5200.00 30,465 167.341 3588.31 3683.31 2955.38 S 663.80 E 5250.00 28,965 167.341 3631.73 3726,73 2979.56 S 669.23 E 5282,16 28.000 167,341 3660.00 3755.00 2994.52 S 672.60 E 5300.00 27.465 167.341 3675.79 3770.79 3002,62 S 674.41 E 5350,00 25.965 167.341 3720.45 3815.45 3024,55 S 679.34 E 5400.00 24.465 167.341 3765.69 3860.69 3045.33 S 684.01 E 5450.00 22,965 167.341 3811.46 3906.46 3064.95 S 688.41 E 5484.12 21.941 167.341 3843.00 3938.00 3077.67 S 691.27 E 5500.00 21.465 167.341 3857.75 3952.75 3083,40 S 692.56 E 5550.00 19.965 167.341 3904.52 3999.52 3100.65 S 696.43 E 5600.00 18.465 167.341 3951.73 4046.73 3116.71 S 700.04 E 5650.00 16.965 167.341 3999.36 4094.36 3131.55 S 703.37 E 5695.47 15.601 167.341 4043.00 4138.00 3143.99 S 706.17 E Global Coordinates Northings Eastings (ft) (ft) 5956131.45 N 561169.85 E 5956109.31 N 561175.01 E 5956091.77 N 561179.10 E 5956084.07 N 561180.89 E 5956059.94 N 561186.52 E 5956045.00 N 561190.00 E 5956036.92 N 561191.88 E 5956015.03 N 561196.99 E 5955994.28 N 561201.82 E 5955974.70 N 561206.39 E 5955962.00 N 561209.34 E 5955956.29 N 561210.68 E 5955939.06 N 561214.69 E 5955923.04 N 561218.43 E 5955908.22 N 561221.88 E 5955895.81N 561224.77 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-137. Northings and Eastings are relative to 1D-137. Magnetic Declination at Surface is 26.703° (24-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1 D-137 and calculated along an Azimuth of 167.341 o (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5695.47ft., The Bottom Hole Displacement is 3222.32ft., in the Direction of 167.341 o (True). Dogleg Rate (°/100ft) 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 Alaska State Plane 4 Kuparuk 1D Vertical Section 2980.36 3003,10 3021.11 3029.01 3053.79 3069.13 3077.43 3099.91 3121.21 3141.31 3154.35 3160.22 3177.90 3194.36 3209.57 3222.32 Comment A3 1 D-137 TARGET A1 Total Depth: 5695.47ft MD 4138.00ft TVD ' 5 1/2" X 3 1/2" Liner Continued... 16 March, 2000- 12:42 -4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-137 WPs - 1D-137 WP1 Revised: 10 February, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth TVD ~t) (ft) 500.00 500.00 800.00 799.69 1200.00 1193.71 1600.00 1564.95 1770.68 1714.95 2667.27 2322.85 4070.04 2929.78 5695.47 4138.00 Formation Tops Measured Depth (ft) 5107.80 5184.52 5282.16 5484,12 Station Coordinates Northings (ft) 0.00 N 11.49 S 75.82 S 218.50 S 297.97 S 921.50 S 2155.44 S 3143.99 S Eastings (ft) 0.00 E 2.58 E 17.03 E 49.08 E 66.93 E 206.98 E 484.13 E 706.17 E Vertical Depth Ct) 3605.00 3670.00 3755.00 3938.00 Sub-Sea Depth (ft) 351o.oo 3575.o0 3660.00 3843.00 Northings (ft) 2907.91S 2947.67 S 2994.52 S 3077.67 S Comment Start Dir @ 1.500°/100ft: 500.00ft MD, 500.00ft TVD Dir Rate Increase @ 2.500°/100ft: 800.00ft MD, 799.69ft TVD Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1193.71ft TVD End Dir: 1600.00ft MD, 1564.95ft TVD Start Dir @ 4.000°/100ff: 1770.68ft MD, 1714.95ft TVD End Dir' 2667.27ft MD, 2322.85ft TVD Start Dir @ 3.000°/100ft · 4070.04ft MD, 2929.78ft TVD Total Depth · 5695.47ft MD, 4138.00ft TVD Eastings Formation Name (ft) 653.14 E D 662.07 E 13 672.60 E A3 691.27 E A1 Continued... 16 March, 2000 - 12:42 - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-137 WPs - 1D-137 WP1 Revised: 10 February, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 5695.47 Targets associated with this wellpath Target Name 1 D-137 TARGET Vertical Depth Casing Detail (ft) 4138.00 5 1/2" X 3 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3755.00 2994.52 S 672.60 E 3660.00 5956045.00 N 561190.00 E 70° 17' 25.6585" N 149° 30' 16.7617" W Target Target Shape Type Point 16 March, 2000- 12:42 -6- DrillQuest 1.05.05 Sperry-Sun Alaska Anticollision Report ::::Co;°rdinate(NE) Reference: Well: 1 D-137 WPs, True North : Yertical:(T~)Reference: 1 D-137 WPs 95.0 above Mean Sea Level :: : Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Definitive Plan Interpolation Method: MD Interval: 100.000 ft Error Model: ISCWSA Ellipse Depth Range: 0.000 to 5730.944 ft Scan Method: High Side + Azimuth Maximum Radins:10000.000 ft Error Surface: Ellipse Survey Program for Definitive Wellpath Date: 02/28/2000 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 0.000 4231.580 Planned: 1D-137 WP1 V1 MWD MWD - Standard Summary ::<. !hi: Reference Offset Ctr-Ctr No-Go Allowable ;site i ::;Wellpath::;::::: ::;: ::::: : : MD :i : MD Distance Area Deviation Warning ; : ft] ft ft ft ft Kuparuk 1 D Pad 1 D-07 Kuparuk 1D Pad 1 D-08 Kuparuk 1D Pad 1 D-10 Kuparuk 1D Pad 1D-11 Kuparuk 1D Pad 1 D-131 Kuparuk 1D Pad 1 D-132 Kuparuk 1D Pad 1 D-133 Kuparuk 1D Pad 1 D-133 Kuparuk 1D Pad 1D-134 Kuparuk 1D Pad 1D-135 Kuparuk 1D Pad 1 D-138 WPs Kuparuk 1D Pad 1 D-139 WPs 1 D-07 V2 1D-08 V12 1D-10 V2 1D-11 V4 1D-131 V2 1 D-132 V2 1D-133 V2 1D-133PB1 V2 1D-134 V2 1 D-135 V2 1062.258 1000.000 143.499 21.622 121.878 Pass: Major Risk 586.357 600.000 29.255 9.897 19.358 Pass: Major Risk 581.027 600.000 66.490 10.527 55.963 Pass: Major Risk 686.260 700,000 38.450 12.372 26.078 Pass: Major Risk 740.074 800.000 147.120 18,867 128.254 Pass: Major Risk 838.353 900.000 105.768 21,111 84.657 Pass: Major Risk 1874.936 2000.000 168.047 64.176 103.871 Pass:Major Risk 1874.219 2000.000 166.879 65.259 101,620 Pass:Major Risk 1051.289 1100.000 66.836 23.663 43.174 Pass: Major Risk 581.283 600.000 106.453 9,063 97,390 Pass: Major Risk 1D-138 WPs V0 Plan: 1D 300.000 300.000 15.002 0.952 14.050 Pass: Minor Risk 1D-139 V3 Plan: 1D-139 400.000 400.000 30,004 1.477 28.527 Pass: Minor Risk Site: Kuparuk 1D Pad Well: 1 D-07 Wellpath: 1 D-07 V2 Rule Assigned: Major Risk Inter-Site Error: 0.000 ft : :Offset: : S~i~Maj~ :: :: : Ctr. Ctr No-Go Allowable : MD:: :TVD i:Re~:: Offset ]TFO+AZI TFO-HS: Casing Distance Area Deviation Warning i:; :::::: : ::::::::::::::: :ft;:::::::::::';ft :i:::ft:: : ft : ] deg deg: in ft ft ft 195.000 195.000 100.000 201.000 0.053 0.000 359.32 359.32 294.999 294.999 200.000 300.999 0.163 0.000 359.18 359.18 394.998 394.998 300.000 400.998 0.275 0.224 359.19 359.19 494.998 494.998 400.000 500.998 0.388 0.485 359.29 359.29 591.480 591.471 500.000 600.983 0.493 0.707 359.10 191.76 687.727 687,652 600.000 700.824 0.501 0.945 357.88 190.54 783.775 783.514 700,000 800.240 0.427 1.145 355.11 187.77 877.518 876.853 800.000 898.895 0.402 1.457 350.29 182.95 970.293 968.807 900.000 996.367 0.490 1.757 343.49 176.15 1062.258 1059.395 1000.000 1092.260 0.687 2.098 334.81 167.47 1153.129 1148.211 1100.000 1186.314 0.963 2.516 324.86 157.51 1242.001 1234.229 1200.000 1278.242 1.303 2.917 314.84 147.50 1328.440 1316.666 1300.000 1367.897 1.697 3.360 305.88 138.54 1413.507 1396.345 1400.000 1455.033 2.149 3.763 298.50 131.16 1500.000 1475.663 1500.000 1539.839 2.673 4.091 292.68 125.34 1581.864 1548.962 1600.000 1622.158 3,240 4.466 288.08 120.74 1670.069 1626.525 1700.000 1701.261 3.882 4.933 284.10 116.76 1758.039 1703.834 1800.000 1777.009 4.531 5.467 280.25 112.91 1837.710 1773.081 1900.000 1849.390 5.151 5.954 276.83 109.49 1915.507 1838.513 2000.000 1919.480 5.799 6.420 274.31 106.96 1993.222 1901.500 2100.000 1989.465 6.503 6.593 272.77 105.43 2070.698 1961.744 2200.000 2060.071 7,267 6.587 272.06 104.72 2147.255 2018.602 2300.000 2130.936 8.068 6.703 271.92 104.58 2221.972 2071.376 2400.000 2202.415 8.890 6.860 272.28 104.93 2300.000 2123.467 2500.000 2274.349 9.790 7.009 272.96 105.61 150.383 1.660 148.723 Pass 150.307 3.489 146.818 Pass 150.053 5.997 144.056 Pass 150.080 8.618 141.462 Pass 149.771 11.048 138.725 Pass 148.495 13.230 135.274 Pass 145.845 15.050 130.854 Pass 143.256 17.323 126.203 Pass 141.932 19.885 122.790 Pass 143.499 22.886 121.878 Pass 150.717 26.339 125.913 Pass 163.814 29.902 135.493 Pass 185.429 33.739 153,211 Pass 213.970 37,615 177.795 Pass 246.086 41.435 206.031 Pass 281.258 45.532 237.056 Pass 319.973 50.240 270.884 Pass 361.655 55.032 307.510 Pass 407.028 59.689 348.088 Pass 456.020 64.343 392.371 Pass 507.147 68.282 439.548 Pass 559.481 71.935 488.269 Pass 612.992 76.021 537.791 Pass 668.297 80.300 588.948 Pass 724.649 84.608 641.246 Pass 2366.464 2165.288 2600,000 2346.438 10.603 7.176 273.81 106.46 780.759 88.735 693.570 Pass Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement / above Port / Collar / (1000' TVD)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Begin Primary One Stage Cement Job to Surface Cement below Port Collar (1000' TVD) If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion Nipple Up and Test BOP's Continue with Completion West Sak Monobore Injector 5-1/2" TAM Port Collar The goal for using this tool is to eliminate use of a two stage cementing collar while still ensuring cement is successfully circulated to surface. This is yet another way to reduce rig time on West Sak wells while still providing operational integrity. This tool will only be opened if cement does not reach the surface with a single stage cement job and also is out of top job range. The decision to use the port collar will be made by the ARCO Drilling Foreman on location. This tool is basically a sliding sleeve which is opened with a "Combo Tool" that has packoffs on either side of 1" pods. The Combo Tool is run in on drillpipe until latching into a profile on the collar which places the pods on the combo tool across from the sliding sleeve of the pod collar. Approximately 15,000 lbs. of weight is applied to shift the collar open. The packoffs ensure that cement is pumped out the ports into the annulus. When the cement job is complete, the Combo Tool is pulled out of the well. The port collar provides a full ID upon closing. Therefore no drill out is required after cementing, If conditions indicate a good iob, the tubing should then be run without a cleanout run. Detailed operational procedures are enclosed. The Pod Collar should be placed at approximately 1000' TVD. This depth was chosen because it is most likely out of top job range, but is still accessible with drillpipe in a reasonable time. Therefore it is recommended that if the Drilling Foreman believes that the top of cement is deeper than 1000' TVD the Port Collar should be used, otherwise a top job should be performed. An estimate of the top of cement can be made through the final slow circulating pressure before bumping the plug. In addition, a dye or a small amount of LCM should be mixed with the spacer to give an indication of top of cement. In order to facilitate a quick turn around should the Pod Collar be used, it is also recommended that the Combo Tool be made up on a pup joint and be ready on the catwalk and approximately 12 stands of 3 Y2" tubing be racked back. As mentioned above, the tool does require approximately 15,000 lbs to open, therefore some heavy weight pipe may need to be run. A top job is the preferred remedial action to take if at all possible in the event cement does not reach the surface. The use of a Port Collar should be the last option for achieving cement to surface. The AOGCC must approve all top jobs in advance. Pre-approval should be considered since the time to make a decision whether to use the Port Collar or a Stage job will be small. Combo Tool and Port Collar Running Procedure 1. Check that all materials are at the rig site · 5 Y2" TAM Combo Tool, with 2 7/8" EUE Box by Pin and 5 Y2" 15.5 ppf Packer Cups · 5 Y2" TAM Port Collar with 5 Y2" BTC Box x Pin Connections · 3 Y2" Choke Sub with 2 7/8" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers 2. Ensure that all connections are compatible or there are appropriate crossovers available 3. Pick up and run 5 Y2" 15.5 ppf casing with Port Collar placed at 1000' TVD 4. If the Drilling Foreman determines that it is necessary to use the Port Collar, run in the hole with the 3 Y2" tubing as a workstring until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. · In order to trip in with the 3 ~" work string and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. 5. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure 6. Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. 7. Establish circulation rate and pressure 8. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing 9. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar 10. Pressure up on workstring to confirm collar is closed 11. With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar 12. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub 13. Reverse out excess cement as required 14. Pull out of hole with tools Greater Kuparuk Area Casing Pressure Test Standard Draft 4 The AOGCC requires a 30 minute casing pressure test prior to drilling out the float equipment. Current AOGCC regulations require surface casings to be tested to 1500 psi or 0.25 psi/ft, whichever is greater. This test needs to be charted for the AOGCC. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Casing Test Procedure Pressure test the surface casing to the value specified in the well plan, above and below the stage collar, if one has been run. Hold each of these tests for 10 minutes to insure the stage collar is completely closed. The AOGCC does not require this test to be charted. Check the well plan for any site specific drill out details. 2. Run in hole to top of baffle plate or float collar, whichever occurs first. Establish circulation and insure well is stable for the 30 minute test. Pressure test surface casing to the value outlined in the well plan for 30 minutes. This test needs to be charted for the AOGCC. Pressure vs. volume needs to be plotted for AAI records and as a minimum volume line for the upcoming LOT/FIT. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record the pump pressure every two pump strokes until the pressure specified in the well plan is reached (this will insure enough data points on the LOT/FIT). Monitor shut in casing pressure for 30 minutes. Make sure test is being accurately recorded on a chart. Check surface equipment for leaks if pressure drops more than 10 percent in 30 minutes. If surface leaks are discovered repair them and do the casing test over. If no surface leaks are found and casing pressure continues to bleed off contact, the AAI Drilling Engineer assigned to the rig, prior to drilling out the casing float equipment. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 4. After achieving a successful casing test. Drill out remaining cement and all float equipment. Clean out any existing rat hole. Drill 20 feet of new hole. Perform a LOT/FITper the standard procedure that follows. RLM 7/31/98 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (th_is may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilhng ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510 March 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: West Sak 1 D-137 Surface Location: Target Location: Bottom Hole Location: 633' FNL, 598' FEL, Sec 23, T11N, R10E 1652' FSL, 72' FWL, Sec. 24, T11 N, R10E 1502' FSL, 105' FWL, Sec. 24, T11 N, R10E Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1 D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of 1D Pad. The well is designated as a monobore injector using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. The well will be drilled and completed using Nordic Rig 3. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.05O. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany lO) 11) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is May 2, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Tom McKay at 265-6890 or Chip Alvord at 265-6120. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: cc: KRU 1 D-136 Well File Chip Alvord Tom McKay ATO-1 O30 ATO-1060 I:P,O~.i:B0xi!i~102776;' AnCh0rage:, AK.. :9951.0 p&y ONEHUNDRED ~OL~ ~ ~o~'~ 0100919 *************'100 00' To the order of: Dale 03-21-00 Amount ' STATE OF ALAS~ ALASKA OIL & GAS CONSERVATION COMPIISSION 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 ,'O000[OO9~-q,' ~:0839062~2[: 09 90000"' Void after 90 days Two signatures required for amounts over $25,000.00 WELL PERMIT CHECKLIST FIELD & POOL ~'?¢,2~',/'~ COMPANY/'~r"-~L.-'¢ WELL NAME//'Z~'/.~ 7 PROGRAM: exp INIT CLASS GEOL AREA ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... N N N N N N N dev redrll serv ~ wellbore seg ~,.0 UNIT# ann. disposal para req ON/OFF SHORE ~/'~ 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~ O'O O psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N 'pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: c:\rnsoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Je ù_(]Cf ') Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 31,2005 6516 1 3.5" 9.3Ib. L-80 Tubing Well: 1D-137 Field: Kuparuk State: Alaska API No.: 50-029-22956-00 Top Log IntvI1.: Suñace Bot. Log IntvI1.: 4,972 Ft. (MD) Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the OS Nipple @ 41891' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The condition of the 3.5" tubing ranges from good to poor with respect to corrosive damage. A possible hole with a wall penetration of 86% is recorded in joint 87 (2,757'). Wall penetrations ranging from 20% to 86% are recorded in 121 of the 163 joints logged. The damage appears in the forms of isolated pitting, corrosion, and lines of pits. No significant areas of cross-sectional wall loss or 10 restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole Corrosion Corrosion Corosion Corosion ( 86%) ( 66%) ( 66%) ( 65%) ( 63%) Jt. Jt. Jt. Jt. Jt. 87 @ 150 @ 153 @ 139 @ 140 @ 2,757 Ft. (MD) 4,729 Ft. (MD) 4,816 Ft. (MD) 4,361 Ft. (MD) 4,415 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. . - 1II.iR.iE"·-··· 1\UG C'} "1 20nJr ~j CI\s'~ ~ VI _ t/ 1-\ ~J) ..1- ,). I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Pllone: (907) 659-2307 Fax: (907) 659-2314 clds, Well: Field: Company: Country: 1 0-13 7 Kuparuk ConocoPhillips USA I Tubing: Weight 9.3 ppf Grade & Thread l-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 ¡¡œ¡m metal loss body 150 ILLI 100 50 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 163) pene. 0 6 36 45 75 1 loss 1 157 5 0 0 0 Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 142) 19 55 67 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 31,2005 MFC 24 No. 99628 1.69 24 M. Tahtouh Upper len. 1.2 ins lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) íRIDIi metal loss body 50 _ penetration body o O~ -==::. ==- := ië:::=o !!!EE:: æ: c:::- 48~ 100 r) I . GlM 1 I i' 98J. . r 4 Bottom of Survey = 156 Analysis Overview page 2 't PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-137 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips NominaII.D.: 2.992 in Country: USA Survey Date: July 31, 2005 Joint Jt. Depth [>('n. Pen. Pen. ./vi (' t £11 Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) %) (Ins.) 0 50 100 .1 25 0 0.04 17 ') 2.89 PUP Shallow corrosion. .) 1 29 0 0.03 11 4 2.90 1.1 60 0 0.02 7 4 2.93 PUP 1.2 70 0 0.05 21 2 2.88 PUP Isolated pitting. 2 81 0 0.04 15 2 2.91 Shallow pitting. 3 112 0 0.02 9 3 2.90 4 143 0 0.02 9 2 2.93 5 174 0 0.03 13 5 2.90 Shallow pitting. 6 206 0 0.03 12 2 2.90 7 237 0 0.03 11 ] 2.91 8 268 0 0.03 12 2 2.91 9 299 0 0.03 13 2 2.89 Shallow pitting. 10 331 0 0.03 12 3 2.92 11 361 0 0.03 13 3 2.90 Shallow pitting. 12 392 0 0.04 17 2 2.89 Shallow pitting. 13 423 0 0.03 13 2 2.92 Shallow pitting. 14 455 () 0.03 13 2 2.91 Shallow pitting. Lt. Deposits. 15 487 0 0.03 13 2 2.91 Shallow corrosion. 16 518 0 0.03 12 4 2.91 17 550 0 0.03 12 2 2.90 18 581 0 0.03 11 2 2.90 19 612 0 0.03 11 2 2.91 20 643 0 0.03 11 2 2.89 21 675 0 0.04 18 2 2.93 Shallow corrosion. 22 707 0 0.02 7 2 2.90 23 738 0 0.03 11 2 2.90 24 769 0 0.04 15 2 2.89 Shallow corrosion. 25 801 0 0.04 16 3 2.90 Shallow corrosion. 26 832 0 0.02 9 2 2.90 27 864 0 0.04 16 4 2.88 Shallow corrosion. Lt. Deposits. 28 893 0 0.03 11 2 2.90 29 925 0 0.03 11 2 2.89 30 956 0 0.04 15 2 2.92 Shallow pitting. 31 988 0 0.03 13 3 2.91 Shallow pitting. 32 1019 0 0.03 13 3 2.91 Shallow pitting. 33 1050 0 0.03 11 2 2.91 34 1082 \ 0 0.04 14 :3 2.90 Shallow corrosion. Lt. Deposits. 35 1113 0 0.03 12 2 2.90 36 1144 0 0.02 9 :3 2.91 37 1176 0 0.03 13 2 2.91 Shallow pitting. 38 1207 0 0.04 17 1 2.92 Shallow pitting. 39 1238 0 0.07 27 2 2.91 Isolated pitting. 40 1269 0 0.06 24 3 2.88 Corrosion. Lt. Deposits. 41 1301 0 0.07 28 2 2.92 Isolated pitting. 42 1332 0 0.06 24 2 2.91 Corrosion. 43 1364 0 0.05 21 2 2.91 Isolated pitting. 44 1395 0 0.05 19 :3 2.93 Shallow pitting. 45 1427 0 0.06 22 4 2.91 Corrosion. Lt. Deposits. 46 1458 0 0.04 16 2 2.90 Shallow corrosion. Lt. Deposits. 47 1490 0 0.10 39 6 2.87 Corrosion. I Penetration Body Metal Loss Body Page 1 { PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pc ). Pen. Pen. Metal Min. No. (Ft.) Upset Body 0/0 Loss I.D. (Ins.) (Ins.) %, (Ins.) 48 1521 0 0.06 24 :) 2.90 49 1553 0 0.09 36 3 2.90 50 1584 0 0.06 24 6 2.90 51 1615 0 0.06 23 :3 2.91 52 1646 () 0.09 34 :3 2.89 53 1677 () 0.08 30 4 2.89 54 1709 0 0.13 52 4 2.91 55 1739 0 0.10 40 4 2.90 56 1770 0 0.07 28 3 2.91 57 1801 0 0.10 38 2 2.93 58 1833 0 0.09 34 4 2.90 59 1864 0 0.10 40 5 2.90 60 1895 0 0.11 43 4 2.87 61 1927 0 0.11 44 5 2.88 62 1958 0 0.11 42 :3 2.90 63 1988 0 0.11 43 3 2.89 64 2020 0 0.11 44 4 2.87 65 2051 0 0.12 46 3 2.88 66 2082 0 0.14 56 4 2.90 67 2113 0 0.14 55 5 2.87 68 2145 0 0.12 45 4 2.88 69 2176 0 0.14 55 3 2.88 70 2207 0 0.11 43 5 2..89 71 2239 0 0.14 53 6 2.88 72 2270 0 0.14 56 5 2.88 73 2301 0 0.12 49 5 2.84 74 2333 0 0.10 41 5 2.85 75 2364 0.05 0.09 35 4 2.87 76 2396 0 0.12 45 5 2.87 77 2427 0 0.12 46 5 2.83 78 2458 0 0.10 39 4 2.83 79 2489 0 0.13 53 6 2.84 80 2518 0 0.14 54 6 2.84 81 2546 0 0.14 54 6 2.85 82 2575 0 0.09 35 4 2.86 83 2606 0 0.11 43 5 2.84 84 2638 0 0.12 46 5 2.86 85 2669 0 0.12 48 5 2.87 86 2700 0 0.15 59 6 2.85 87 2732 0 0.22 86 9 2.85 88 2763 0 0.14 54 7 2.85 89 2794 0 0.13 52 8 2.82 90 2826 0 0.11 43 6 2.82 91 2857 0 0.11 45 7 2.81 92 2889 0 0.08 31 7 2.81 93 2919 0 0.14 55 8 2.85 94 2950 0 0.15 61 6 2.85 95 2981 0 0.10 39 6 2.86 96 3012 0 0.11 45 6 2.82 97 3044 0 0.10 39 7 2.84 Well: Field: Company: Country: Survey Date: 1 D-137 Kuparu k ConocoPhillips USA July 31, 2005 Comments Isolated pitting. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line .of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Possible Hole! Line of pits. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Corrosion. Lt. Deposits. Corrosion. Page 2 Damage Profile (% wall) o 50 100 II. ~ II. e: ... I.. I. .. I.. I. .1 I.. ~. .. .. .. I. .. ... ... .. ~. I I ... ..~ .. I ... ... Penetration Body Metal Loss Body \ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-137 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Ph ill ips Nominal 1.0.: 2.992 in Country: USA Survey Date: July 31, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) (fc, (I ns.) 0 50 100 98 3075 0.05 0.09 37 7 2.81 Corrosion. Lt. Deposits. 99 3106 0 0.09 34 7 2.82 Corrosion. Lt. Deposits. 100 3138 0 0.14 54 11 2.85 Corrosion. Lt. Deposits. 101 3169 0 0.10 41 a 2.88 Corrosion. Lt. Deposits. 102 3201 0.11 0.10 39 B 2.81 Line corrosion. Lt. Deposits. 103 3232 (un 0.08 32 6 2.78 Corrosion. Lt. Deposits. 104 3264 0 0.09 37 7 2.79 Line corrosion. Lt. Deposits. 105 3295 0 0.07 27 7 2.83 Line corrosion. Lt. Deposits. 106 3327 0 0.13 51 6 2.83 Line corrosion. Lt. Deposits. 107 3359 0 0.07 29 b 2.84 Line corrosion. Lt. Deposits. 108 3389 0 0.10 38 6 2.80 Line corrosion. Lt. Deposits. 109 3421 0 0.10 41 6 2.80 Line corrosion. Lt. Deposits. 110 3452 0 0.11 44 8 2.82 Line corrosion. Lt. Deposits. 111 3483 0.06 0.13 50 10 2.83 Line corrosion. Lt. Deposits. 112 3513 0 0.08 30 5 2.84 Line corrosion. Lt. Deposits. 113 3544 0 0.08 33 9 2.79 Line corrosion. Lt. Deposits. 114 3576 0.04 0.10 39 6 2.81 Corrosion. Lt. Deposits. 115 3607 0.09 0.09 35 6 2.80 Line corrosion. Lt. Deposits. 116 3639 0.08 0.09 35 7 2.80 Line corrosion. Lt. Deposits. 117 3670 0 0.10 39 8 2.82 Corrosion. Lt. Deposits. 118 3701 0.09 0.08 32 8 2.83 Line corrosion. Lt. Deposits. 119 3732 0.11 0.13 49 a 2.81 Corrosion. Lt. Deposits. 120 3763 0 0.09 35 6 2.84 Line corrosion. Lt. Deposits. 121 3794 0 0.10 39 5 2.82 Line corrosion. Lt. Deposits. 122 3827 0 0.11 44 7 2.86 Line corrosion. Lt. Deposits. 123 3857 0 0.12 46 7 2.86 Line corrosion. Lt. Deposits. 124 3889 0 0.15 61 7 2.84 Corrosion. Lt. Deposits. 125 3920 0 0.10 37 6 2.80 Line corrosion. Lt. Deposits. 126 3952 0 0.14 55 8 2.83 Corrosion. Lt. Deposits. 127 3983 0 0.11 43 3 2.79 Corrosion. Lt. Deposits. 128 4014 0.10 0.11 43 9 2.81 Corrosion. Lt. Deposits. 129 4046 0 0.14 54 6 2.82 Corrosion. Lt. Deposits. 130 4077 0.04 0.10 41 7 2.80 Corrosion. Lt. Deposits. 131 4109 0 0.15 58 8 2.83 Corrosion. Lt. Deposits. 132 4140 0 0.13 51 9 2.80 Corrosion. Lt. Deposits. 133 4171 0.08 0.13 50 9 2.82 Corrosion. Lt. Deposits. 134 4202 0 0.13 52 8 2.83 Corrosion. Lt. Deposits. 135 4234 0 0.15 59 8 2.84 Corrosion. Lt. Deposits. 136 4264 0.09 0.11 44 7 2.84 Line corrosion. Lt. Deposits. 137 4295 0 0.12 46 9 2.83 Line corrosion. Lt. Deposits. 138 4327 0.11 0.12 46 5 2.82 Corrosion. Lt. Deposits. 139 4358 0 0.17 65 8 2.86 Corrosion. Lt. Deposits. 140 4389 0 0.16 63 8 2.81 Corrosion. Lt. Deposits. 141 4420 0 0.11 43 7 2.82 Line corrosion. Lt. Deposits. 142 4451 0.05 0.09 37 8 2.83 Line corrosion. Lt. Deposits. 143 4482 0 0.08 33 11 2.84 Line corrosion. Lt. Deposits. 144 4514 0 0.14 53 4 2.86 Corrosion. Lt. Deposits. 145 4545 0 0.10 41 8 2.88 Line corrosion. Lt. Deposits. 146 4576 0.12 0.15 57 5 2.81 Corrosion. Lt. Deposits. 147 4605 0 0.13 51 7 2.88 Corrosion. Lt. Deposits. I Penetration Body Metal Loss Body Page 3 ~. PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-137 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips NominaII.D.: 2.992 in Country: USA Survey Date: July 31,2005 Joint J1. Depth Pen. Pen. Pen. Metal Min. No. (F1.) Upset Body % Loss I.D. Comments (Ins.) (I ns.) % (Ins.) 148 4636 0 0.13 50 () 2.89 Line corrosion. L1. Deposits. 149 4668 0 0.12 46 10 2.82 Line corrosion. L1. Deposits. 150 4700 0 0.17 66 9 2.85 Corrosion. L1. Deposits. 151 4730 0.07 0.13 52 13 2.85 Corrosion. Lt. Deposits. 152 . 4761 0 0.12 45 12 2.85 Line corrosion. Lt. Deposits. 153 4793 0.09 0.17 66 13 2.89 Corrosion. Lt. Deposits. 153.1 4824 0 0.14 56 7 2.93 PUP Line corrosion. 153.2 4838 0 0 0 0 2.81 GLM (Latch @ 3:00) 153.3 4845 0 0.10 41 6 2.91 PUP Corrosion. L1. Deposits. 154 4859 0 0.15 57 9 2.90 Corrosion. Lt. Deposits. 154.1 4889 0 0 0 0 N/A DS Nipple 155 4892 0 0.12 49 7 2.92 Corrosion. 155.1 4922 0 0.12 48 4 2.92 PUP Isolated pitting. 155.2 4929 0 0 0 () N/A SEAL 155.3 4941 0 0.11 41 2 2.86 PUP Line corrosion. Lt. Deposits. 156 4952 0.09 0.13 51 9 2.84 Line corrosion. Lt. Deposits. Page 4 Damage Profile (% wall) o 50 100 p. .. f' III ~. .. I!IIII I I Penetration Body ~.;¡j:!i Metal Loss Body · --->. lS ~ .' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-13 7 Kuparuk ConocoPhillips USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 31,2005 MFC 24 No, 99628 1.69 24 M. Tahtouh Cross Section for Joint 87 at depth 2757.31 ft Tool speed = 54 Nominal 10 = 2.992 Nominal 00 = 3,500 Remaining wall area = 92 % Tool deviation = 82 0 Finger 12 Penetration = 0.218 ins Possible Hole 0.219 = 86% Wall Penetration HIGH SIDE:::: UP Cross Sections page 1 ..1 ~.__.. .& ~ ~. PDS Report Cross Sections Well: Field: Company: Coun try: Tubing: 1 0-13 7 Kuparuk ConocoPhillips USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No. 99628 1.69 24 M. Tahtouh Cross Section for Joint 150 at depth 4729.11 ft Tool speed = 51 Nominal 10 = 2,992 Nominal 00 = 3,500 Remaining wall area = 95 % Tool deviation = 39 0 Finger 12 Penetration = 0.168 ins Corrosion 0.17 = 66% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .PHllLlPS Alat..a, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 1D-137 TUBING (Q.4934, 00:3.500, 10 :2.992) ~OOUCTION (Q.4934, 00:5.500, Wt:15.50) GasUl! II1drellÐummy Valve 1 (4838.4839, 00:4.725) NIP (4891-4892, 00:3.500) SEAL (4929-4930, 00:3.500) Perf (5040-5090) Perf (5121-5161) Perf (517G-5190) Perf (5218-5262) Perf (5272-5280) Perl (5298-5347) 8 API: 500292295600 SSSV Type: NONE KRU Well Type: INJ Orig 5/25/2000 Completion: Last W/O: Ref Log Date: TD: 5615 ftKB Max Hole Angle: 66 deg @ 2800 Annular Fluid: Reference Log: Last Tag: 5294 Last Tag Date: 8/25/2002 Casing String - ALL Description CONDUCTOR PRODUCTION LINER Tubing String - ALL Size I Top 3.500 0 Perforations Summary Interval TVD 5040 - 5090 3619 - 3661 5121 - 5161 3687 - 3722 5170 - 5190 3730 - 3747 5218-5262 3772-3811 5272 - 5280 3820 - 3827 5298 - 5347 3843 - 3887 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 4838 3454 CAMCO KBG29 CAMCO Other (:>Iugs, equip., etc.: . JEWELRY Depth TVD Type 4891 3496 NIP CAMCO DS NIPPLE 4929 3527 SEAL BAKER GBH-22 SEAL ASSY Size 16.000 5.500 3.500 I Bottom 4934 Zone WSD VVSB WSA4 WSA3 VVS A3 WSA2 VMfr Top o o 4934 1D-137 Angle @ TS: deg @ Angle @ TD: 22 deg @ 5615 Rev Reason: Tagged fill Last Update: 8/27/2002 Bottom TVD Wt Grade Thread 110 110 62.58 H-40 WELDED 4934 3531 15.50 L-80 BTCM 5583 4105 9.30 L-80 BTCM TVD Wt Grade Thread 3531 9.30 L-80 EUE 8RD Status Ft SPF Date Type 50 4 7/6/2000 IPERF 40 4 7/6/2000 IPERF 20 4 7/6/2000 IPERF 44 4 7/1/2000 IPERF 8 4 7/1/2000 IPERF 49 4 7/1/2000 IPERF V Type VOD Latch Port TRO ]IJ Y 1.0 INT 0.000 0 Description Comment Date Vlv Run Cmnt 6/27/2000 ID 2.813 3.000 I f Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Sat Apr 21 10:51:13 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00044 J. PANTER D. HIEM 1ST STRING 1D-137 500292295600 Phillips Alaska, Inc. Sperry Sun 19-APR-01 MWD RUN 2 AK-MM-00044 N. HERNANDEZ D. WESTER MWD RUN 99 AK-MM-00044 29 lin 10E 669 698 .00 101.22 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.875 13.375 110.0 2ND STRING 7.875 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER THE PHONE CONVERSATION BETWEEN M.WERNER OF PHILLIPS ALASKA, INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 05/02/00. MWD DATA ARE CONSIDERED PDC. 4. VERTICAL RESISTIVITY INVERSION (VRI) DATA IS PRESENTED AS A DEEP PHASE ENHANCED (RDVR) CURVE IN MWD MERGED DATA, AND AS 4 ENHANCED CURVES AND 4 MODELED CURVES IN THE FINAL RAW MWD FILE. 5. MWD RUNS 1 AND 2 REPRESENT WELL 1D-137 WITH API#: 50-029-22956-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5615'MD, 4135'TVD. File Header SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALLOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED). VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP RDVR $ START DEPTH 69 5 76 5 76 5 76 5 765 110 5 113 0 4290 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 5560 5 5567 5 5567 5 5567 5 5567 5 5567 5 5614 5 5513 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 69.5 3075.0 2 3075.0 5615.0 99 4290.0 5513.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 RDVR MWD OHMM 4 1 68 32 9 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD ~D OHMM FET MWD HOUR RDVR MWD OHMM Min 69.5 0 11.64 0 74 0 89 0 74 0 66 0 26 1 43 Max 5614.5 538.01 131.28 2000 2000 2000 2000 75.83 233.542 Mean Nsam 2842 11091 94.4316 11004 69.5156 10983 50.0229 10983 75.1957 10983 91.1463 10983 120.271 10983 19.347 10915 13.733 2447 First Reading 69.5 113 69.5 76.5 76.5 76.5 76.5 110.5 4290 Last Reading 5614 5 5614 5 5560 5 5567 5 5567 5 5567 5 5567 5 5567 5 5513 First Reading For Entire File .......... 69.5 Last Reading For Entire File ........... 5614.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ 69.5 76 5 76 5 76 5 76 5 110 5 113 0 LOG HEADER DATA DATE LOGGED: STOP DEPTH 3031 0 3038 0 3038 0 3038 0 3038 0 3038 0 3075 0 18-MAY-O0 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Insite 0.43 MEMORY 3075.0 .1 65.5 TOOL NUMBER PB01451GRV4 ?B01451GRV4 7.875 110.0 SPUD 9.40 250.0 9.5 50O .0 3. 600 2. 957 2.400 3.250 70.0 86.7 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 K?M MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 20 24 28 Name Service Unit Min Max DEPT FT 69.5 3075 ROP MWD010 FT/H 0 245.01 GR MWD010 API 11.64 118.83 RPX MWD010 OHMM 0.74 2000 RPS MWD010 OHMM 0.89 2000 RPM MWD010 OHMM 0.74 2000 RPD MWD010 OHMM 0.66 2000 FET MWD010 HOUR 6.84 62.44 Mean Nsam 1572.25 6012 89.3235 5925 65.3434 5924 83.9744 5924 130.504 5924 160.107 5924 213.825 5924 34.3731 5856 First Reading 69.5 113 69.5 76.5 76.5 76.5 76.5 110.5 Last Reading 3075 3075 3031 3038 3038 3038 3038 3038 First Reading For Entire File .......... 69.5 Last Reading For Entire File ........... 3075 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 3031.5 3038 5 3038 5 3038 5 3038 5 3038 5 3075 5 LOG HEADER DATA STOP DEPTH 5560 5 5567 5 5567 5 5567 5 5567 5 5567 5 5614 5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 20-MAY-00 Insite 0.43 MEMORY 5614.8 21.6 64.9 TOOL NUMBER PB01451GRV4 PB01451GRV4 7.875 110.0 SPUD 9.40 300.0 9.2 5OO .0 2.600 1.922 3.200 2.900 68.0 94.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 ~PS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR 1 68 1 68 1 68 1 68 16 20 24 28 Name Service Unit Min DEPT FT 3031.5 ROP MWD020 FT/H 0 GR MWD020 API 26.14 RPX MWD020 OHMM 2.15 RPS MWD020 OHMM 2.2 RPM MWD020 OHMM 2.22 RPD MWD020 OHMM 2.39 FET MWD020 HOUR 0.26 Max 5614.5 538 01 131 28 84 04 96 45 80 93 75 29 75 83 Mean Nsam 4323 5167 100.39 5079 74.4013 5059 10.2664 5059 10.43 5059 10.3948 5059 10.7207 5059 1.95378 5059 First Reading 3031 5 3075 5 3031 5 3038 5 3038 5 3038 5 3038 5 3038 5 Last Readinc 5614 5614 5560 5567 5567 5567 5567 5567 First Reading For Entire File .......... 3031.5 Last Reading For Entire File ........... 5614.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 99 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH VEMP VESP VEXP MEDP MEMP MESP MEXP VEDP $ 4290.0 4290.0 4290 0 4290 0 4290 0 4290 0 4290 0 4290 0 STOP DEPTH 5513 0 5513 0 5513 0 5513 0 5513 0 5513 0 5513 0 5513 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 19-APR-01 Insite MODELED TOOL NUMBER Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 MEXP MWD099 OHMM 4 1 68 4 2 MESP MWD099 OHMM 4 1 68 8 3 MEMP MWD099 OHMM 4 1 68 12 4 MEDP MWD099 OHMM VEXP MWD099 OHMM VESP MWD099 OHMM VEMP MWD099 OHMM VEDP MWD099 OHMM 68 68 68 68 68 16 20 24 28 32 Name Service Unit Min DEPT FT 4290 MEXP MWD099 OHMM 2.143 MESP MWD099 OHMM 2.183 MEMP MWD099 OHMM 2.037 MEDP MWD099 OHMM 2.167 VEXP MWD099 OHMM 1.644 VESP MWD099 OHMM 1.666 VEMP MWD099 OHMM 1.42 VEDP MWD099 OHMM 1.43 Max 5513 88 293 94 833 84 966 85 097 138 099 226 178 212 207 233 542 First Last Mean Nsam Reading Reading 4901.5 2447 4290 5513 11.714 2447 4290 5513 11.8601 2447 4290 5513 11.6327 2447 4290 5513 11.9778 2447 4290 5513 12.5584 2447 4290 5513 12.9813 2447 4290 5513 12.992 2447 4290 5513 13.733 2447 4290 5513 First Reading For Entire File .......... 4290 Last Reading For Entire File ........... 5513 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/04/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
