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Home My WebLink About201-185MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-131 KUPARUK RIV U WSAK 1C-131 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-131 50-029-23041-00-00 201-185-0 W SPT 3705 2011850 1500 914 914 915 915 4YRTST P Austin McLeod 5/15/2022 Monobore. MITIA 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 1C-131 Inspection Date: Tubing OA Packer Depth 100 2050 1960 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220515191904 BBL Pumped:0.9 BBL Returned:0.8 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:48:24 -08'00' MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: P.I.m Regg S tZt PSupervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-131 FROM: Austin McLeod KUPARUK RIV U WSAK 1C-131 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 11 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1C-131 API Well Number 50-029-23041-00-00 Inspector Name: Austin McLeod Permit Number: 201-185-0 Inspection Date: 5/12/2018 Insp Num: mitSAM180513202649 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-131 'Type Inj W 'TVD 3705 Tubing 992 992 - 993 , 993 - PTD 1 zol laso Type Testi SPT Test psi 1500 IA 130 1840 - 1760 1750 BBL Pumped: 0.6 " BBL Returned: i 0.6 - OA Interval ] 4YRTST P/F P 1/ Notes: MIT-IA.5.5"x3.5"-No OA SCANNED JUN 0 12018 Wednesday,May 16,2018 Page 1 of 1 Z.C>5 V1 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /Zl/201G. Anchorage, Alaska 99501 Q ; �.K.BENDER RE: Multi Finger Caliper(MFC): 1C-131 ` Run Date: 11/13/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-131 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23041-00 SCANNED 3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: divate2-1z4za.... + f ' At WELL LOG TRANSMITTAL#902803240/902875059 To: Alaska Oil and Gas Conservation Comm. November 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 J C; ._ DATA LOGGED Anchorage, Alaska 99501 , 2 M.K.BENDER AOGC:C. RE: Static Bottom Hole Pressure and Temperature/Perforation Record Run Date: 10/02/2015 and 11/1/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-131 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23041-00 Static Bottom Hole Pressure and Temperature Survey(Field Print) 1 Color Log 50-029-23041-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari iCANNEE 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MEMORANDUM To: Jim Regg ~~l b(Z'~,io P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-131 KUPARUK RIV U WSAK IC-131 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV U WSAK 1C-131 API Well Number: 50-029-23041-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523174315 Permit Number: 201-185-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ 1C-131 3705 '/ IA T Well y e Inj. W~TVD~ 140 2230 / 2160 2150 ~ ~ ~soo ~ OA P.T.D~ zollsso yT peTest i SPT', Test psi ~~ 1 _ _ ~ _ ~ _ - .-- Interval aYRTST p/F P ~ Tubing s7s s78 s7s s79 i Notes: 1.1 bbl pumped for test. Monobore injector No problems witnessed. . ~~~ ~~, Tuesday, May 25, 2010 Page 1 of 1 04/06/09 ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~, u ~-~ -° ~"'~, " N0.5151 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3B-02 AYS4-00050 INJECTION PROFILE ' 03/23/09 1 1 iL-16 AYS4-00048 INJECTION PROFILE ( 03/21/09 1 1 1 F-13 AYS4-00046 INJECTION PROFILE / - t/L 03/19/09 1 1 2N-310 B14B-00018 INJECTION PROFILE ~ ~--v 03/21/09 1 1 2D-13 B14B-00017 PRODUCTION PROFILE / _ 0/a 1'~ ~ 03/20/09 1 1 3B-05 AZCM-00013 INJECTION PROFILE i '~-p'~ '" /~. ~ 03/29/09 1 1 2U-01 AYS4-00051 PRODUCTION PROFILE - (Xj 03/24/09 1 1 1 C-131 AYS4-00047 INJECTION PROFILE ~ - ~" 03/20/09 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . ConocJPhilIi ps Alaska REceiVED APR 1 8 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 16, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 aD (- l ttS- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off lprl , Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft çal 1 C-25 119-031 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1C-119 201-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1C-121 201-080 11' 2.0 18" 4/8/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 4/8/2007 6.8 4/15/2007 1C-135 201-220 11' 1.3 10" 4/8/2007 2.4 4/15/2007 1 C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14' 6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/15/2007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 Kuparuk Field A 1162007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Reytl ~H 101 iX,<> P.I. Supervisor . { DATE: Wednesday, August 09,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lC-131 KUPARUKRIVUWSAK IC-13! ~O\~ ~~5 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvJß~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IC-131 API Well Number 50-029-23041-00-00 Insp Num: mitCS060803182601 Permit Number: 201-185-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 8/3/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IC-131 IType Inj.TWj TVD -137õ5TIA I 650 I 1760 I 1740 I 1740! I ~~T. i 2011850 ¡TypeT~st i SPI ¡Test p;¡!-1500 ~ O~___~__ ; I ! -: Interval OTHER P/F P ;.// Tubing ; 900 I 900 I 900 i 900 I I Notes Well is a single casing string (monobore) design that had a casing leak. The casing has been repaired by excavating around wellhead and patching from the outside. v .- SCANNED f\UG 2 4: 2006 Wednesday, August 09, 2006 Page 1 of 1 MIT KRU lC-131&121 08-03-06.xls e e «MIT KRU 1C-131&121 08-03-06.xls» Attached are the results from the State Witnessed MITIA's on post surface casing patch wells 1C-121 (~1g~) and 1C-131 ~. 1686ðJ· _) ~O\-O2>O - ~ è)()\- \~~ / These MIT's also fullll the 4 year MIT requirement and will reset the clock. In addition, they will be removed from the Monthly failed MIT report. Let me know if you have any questions MJ Loveland (" t~ ;,J ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 .. MIT KRU lC-131&121 Content-DeSCriptIOn: 08-03-06.xls KRU lC-131&121 08-03-06.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 1 of I 8/4/20067:42 AM 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: ConoeoPhillips Alaska Inc. West Sak / KRU /1 C 08/03/06 Rogers / Ferreira Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. We1l11C-131 I Type Inj. I w TVD I 3,705' Tubing 900 900 900 900 Interval I 0 P.T.D.12011850 I Type test I P Test psil 1500 Casing 650 1760 1740 1740 P/F P Notes: Post SC patch OA na na na na We1l11C-121 I Type Inj. / w TVD I 3,561' Tubing 800 800 800 800 Interval I 0 P.T.D.12010800 I Type test I P Test psil 1500 Casing 100 1790 1760 1760 P/FI P Notes: Post SC patch OA na na na na Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test! Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test! Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test/ Test psi I Casing P/FI 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 o = Other (describe in notes) MIT KRU 1C-131&121 08-03-06.xls e e WELL LOG TRANSMITTAL PRoActiVE DiAGNOStiC SERvicES, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501-3539 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 : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1] 1C-119 MTT Report 16-May-06 2] 1 C - 121 MTT Report 16-May-06 -- ~(:)1-18~ 3) 1C - 131 MTT Report 14-Jun-06 4) 1 0 - 127 MTT Report 14-Jun-06 5] 10 - 121 MTT Report 14-Jun-06 6) 1 0 - 1 09 MTT Report 15-Jun-06 7) 1 0 - 120 MTT Report 15-Jun-06 8] 10-111 MTT Report 15-Jun-06 Signed: U òiJJ Print Name: µ Ö I.Jù 0-., V" Å~ Ok llt-~¿ !!<,f'~ Date: 11 J LA l¡ 2 ~ ~ PRoACTivE DiAGNOSTic SERViCES, INC., 1}0 W. INTERNATioNAl AiRpoRT Rd SuiTE C, ANdiORAGE, AK 99'718 PIiONE: (907)24'7-89'7 I FAX: (907)24'7-39'72 E-MAil: pdS.~I'ICHORAGE@MHi1CItV¡O(¡.CûM WEbsiTE: MEMORyloG.COM C:\My Documents\ W ork\ DistributionLablesNew\ Transmit_ Original. doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: e e Memory Magnetic Thickness Tool Log Results Summary ¡e\.... \g5 ConocoPhillips Alaska, Inc. June 14, 2006 8031 2 3.5" 9.3 Ib EUE Tubing 5.5" 15.51b BTC Production Casing 16" 62.6 lb. PEB Conductor Pipe Well: 1 C-131 Field: Kuparuk State: Alaska API No.: 50-029-23041-00 Top Log Intvl.: Surface Bot. Log Intvl.: 190 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 190 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 158 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log ofthis 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, 5.5" production casing, and 16" conductor pipe within the logged interval. 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 (80'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 3.5"" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 190'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show four intervals of metal loss. A maximum of (-12%) circumferencial metal loss is recorded in the interval between 2.5' and 8'. A maximum of (-3%) circumferencial metal loss is recorded in the interval between 28' and 32.5'. A maximum of (-2.5%) circumferencial metal loss is recorded in the interval between 12.5' and 18'. A maximum of (-2.5%) circumferencial metal loss is recorded in the interval between 58' and 60'. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 5.5" and 16" 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" tubing or 16" conductor. I Field Engineer: R. Richey & J. Halvorsen Analyst: M. Tahtouh & J. Burton Witness: T. Sendon ProActive Diagnostic Services, Inc. ! P.O. Box 1369, Stafford, TX 77497 Phone: (2.81) or (888) 565·9085 Fax: (2.81) 565-1369 E-maíl; PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ;t ~ l ~ f ßS- \J \'¿ I I I I I I I I I I I I I I I I I I I cIrk. 11.11I ~ I n............\ Im....11I n::nn.. n!(.;I'U ICi)i:) I Ch;'~J ..., Pm:>AcrI_ DiAq_lc SERviCE£, ¡"",,_ Database File: d:\warrior\data\1c-131\1c-131.db Dataset Pathname: u ~ II 2hzs !\,- I'" 'flU' Presentation Format: mtt10hz Dataset Creation Thu Jun 15 09:22:26 2006 Calc Sondex Warrior V7. 0 Charted in Feet scaled 1:150 Œ MTT Freql'IZ>f1"\/ (Hz) 20 3 MTTP01 (rad) 13 Delta Metal Thickness (%) 50 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ftlmin) -200 - -- Tree ,. .!!Jlng nc¡ Pup Jt 0.1 2% Metal Loss- \, - . - - Ë 3.5" - - Jt. 1 - :Þr5% Metal Loss - - 20 - -- i foIIr.--Line SŒed ...--.. ~ 1 C ~Mclal Loss f-3.5" Collar- = 40 ~ - 5.5" Cd:;¡¡~ Collar - ) - ') 3.5" ( . Jt. 2 .5% Meta! Loss 60 <.. ì ~ ~3.5" Collar ( { ; Ii" ~ 3.5" - I Jt 3 - .~ -- 80 I ( 5.5" Collar I I <J I I I 'C: Ic~ .£:; c::. .¥)):". I I I I I I I I I I I I I I I I I I I ------- -..-. ~e - -. - 3.5" Collar- ~".,.., 100 >--- I---- JI I---- I---- 35" >--- I I Jt4 >--- >--- I---- I---- ~tom of 16" Conductor I---- I---- I---- ""' >--- 120 I - I---- ~ - } I ,..-- c- >1 '--- 3.5" Collar-;; - 5.5" Casin¡ Collar I---- i-- R' 13 140 t-- 3.5" 1 Jt 5 1 I ) W - $5" Collar- ~:' 160 -¡ <. t I ( \ I .. ~ ,,-- i 35" .~~----- -- > Jt 6 ( 5 5" Casing Collar I;;;· 1;:;;+- I I 180 ± >- f-- ...- d ~ 3.5" Collar...: ...... 0 MTT ;-, ....'"!'-'....,¡l;y (Hz) 20 3 MTTP01 (rad) 13 t~9. Delta Metal Thickness (%) 50 -5.8 MTTP12 (rad) 4.2 0 L Speed 'UL -200 Ine ,IVIIIIII} I clas. nAt.... iI ~ Ii -.I. _I I n~~ rf...I. IrA~ - ..... ............ - I I ~ DIAq.ro,nl", !SEa"!",,,,,, INC. Database File: d:\warrior\data\1 c-131\1c-131.db I Dataset Pathname . UIV 1,,- 2hzs. Presentation Format: mtt10hz Dataset Creation: Thu Jun 15 09:22:26 2006 Calc Sondex Warrior V7. 0 - in Feet scaled 175 I Ci,CI"c", 0 MTT Freql~~' (Hz) ~ 3 MTTP01 (rad) 13 -25 Delta Metal Thickness (%) -5.8 MTTP12 (rad) 4.2 I 0 Line Speed (ítilll!ll) -200 I I ~, I Jt 0.1 3.5" Collar t= ~ I-- ~ ..- 2% Metal Loss-- --- ~- - -~ I i\ \ I-- < \ "\ 1\ \ \ l . I I- 3.5" f-------- I-- I Jt 1 ;'-1- , ~ 2.5% Metal Loss r-- I-- I ¥rl-- I 20 /;~, - } I ~~ Line Speed ! - .~. I J I f--.-3 5" Collar-~ ~,- I . l r- t ,''' l- I _'-7;. t±±t± '7 40 I~ ,ii . I MTT c,,,,,..,, ,,,,n,,,/ (Hz) 20 3 MTTP01 (rad) 13 25 Delta Metal Thickness (%) 25 -5.8 MTTP12 (rad) 4.2 I 0 Line Speed (ft/min) -200 --------------- I I I I I I I I I I I I I I I I I I I cIrk n,_.l._~1 lUll ..4,_1 I n~~ r".4" I J~I~II I - ~ DOO:¡N<>!iTÌc SE""¡".s, ¡NC. Database File: d:\warrior\data\1c-131\1c-131.db Dataset Pathname ~ 2hzs T 1\.;- I,,) ¡/fun I Presentation Format: mtt10hz Dataset Creation Thu Jun 15 09:2226 2006 Calc Sondex Warrior V7. 0 Charted in Feet scaled 175 0 MTT Freql,on~. (Hz) I 3 MTTP01 (rad) 13 -25 Delta Metal Thickness (%) -5.8 MTTP12 (rad) 4.2 0 Line Speed (ft/min) -200 ...v I¿'); 5 5" L;aS¡n¡ Collar ....... t ",. '." ~J;~:; "~" I.:è\ ( - ( ( t3> ..-" oY" #,/ < ) 35" = tf Jt 2 II ~ J \ f.--- 25% Metal Loss [ 60 f.--- < mt+ ..... } 3.5" Collar - .. (' ) 3.5" ;, Jt 3 \ ~. ..... <! . on 0 MTT rl\';l..!ul::l Ivy (Hz) 20 3 MTTP01 (rad) 13 -25 Delta Metal Thickness (%) 25 -5.8 MTTP12 (rad) 4.2 0 Line Speed (ftlmin) -200 I I 1 I I I 'RODUCTlON (0-5083. 00:5.500, Wt:15.50) Reference La : Last Ta : 5661 Last Tag Oate: 11122/2001 Rev Reason: Set WRP, Set PLUG Last U ate: 5/11/2000 TVO 158 1M Grade Thread 62.58 APISL PES GrB L-80 BTC L-80 EUE Thraad EUE I I NIP (5038-5039, 00:4.520) PLUG (5038-5039, 00:2.812) Comment 2.58 HSO BH Chg, 60 de¡-¡ h 2.5" HSO BH Cng, 60 dsg I Vlv Cmnt I NIP (5076-5077, 00:4.500) Descr! Ion CAMCO 'OS' NIPPLE WITH NO GO PROFILE 2.81 CA-2 BLANKING BAKER LOCATOR BAKER 80-40 SEAL WRF' set 5/8/2006 10 2.812 0.000 2.992 3.000 0.000 I SEAL (5077-5076. OD:4.000) I I I LINER (5083-5907, 00:3.500. Wt:9.30) PLUG (5106-5107. 00:3.500) I I Perf (5170-5232) I Perf (5270-5326) I I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIO-.",· Abandon 0 Repair Well 0· Plug Perforations 0 Stimulate 0 Other~ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-185/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23041-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1C-131 . 1. Operations Performed: tit tit J 8. Property Designation: Kuparuk River Unit At> c... ~ 's-o ,.,4l> 7- ,I· 0 , 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool measured 5915' feet true vertical 4247' feet measured 5661 feet true vertical feet Length Size MD 158' 16" 158' 5083' 5-112" 5083' 824' 3-1/2" 5907' Plugs (measured) Junk (measured) TVD Burst Collapse 158' 3708' 4241' Measured depth: 5170-5232',5270-5326' 8C}'~~~'dEÐ J U L 2 true vertical depth: 3763-3801',3825-3860' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5091' MD. Packers & SSSV (type & measured depth) no packer 5076' no SSSV no SSSV 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) Treatment descriptions including volumes used and final pressure: RBDMS BFL JUL 2 4 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-178 Contact Printed Name Signature Marie McConnell/Perry Klein Marie McConnell Problem Well Supervisor 659-7224 Date Title Phone Form 10-404 Revised 04/2004 7/16/2006 ~b 7-7..(· c,,- OR\G\NAL k~¡. J( Sub~ìWriQ!FJPI Only A1"Z ~;.Z¡ loc e 1 C-131 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 7/5/2006 Removed 12' 4" of conductor. Cement was removed from 5 1/2" casing and found 3 - 4" long hole that resembles a split. Location of hole is 5' 4" down from top of fluted mandrel hanger. See photo #1 7/6/2006 Notified AOGCC State Insp. (Jeff Jones) @ 11:30 a.m. that the conductor has been cut, Waived visual inspection @ 5:45pm 7/13/2006 Weld SC patch, Seal weld 4' mandrel hanger pup threads to ADD Vetco gray mandrel hanger. Install 98" long, 51/2" X65 pipe, .375 wall thickness SC patch. Total length of damaged SC from top of mandrel hanger to lower section of vis able corrosion repaired is 98". Total length of SC patch from upper weld located at bottom of Mandrel hanger to very lower most weld located at bottom of lower wedding band is 102 3/4" (8' 63/4") 7/14/2006 MITIA - Passed(see attached), Wrap SC with Denso corrosion resistant tape, Patched conductor with a 145" long section of 16",62.5#, API 5L Gr D Casing Conductor will be topped off with cement and a corrosion inhibited waterproof sealant at a later date If LDc-a,. t.s:::. s)eetJe ~ . . Go fI~ ('5.-._ ø./tl:uA rn.~/h~;':1J ¡t;~~t-.~;~~:'-~k · ::-::~~··t>~d;;t·*;';rL.~~é.,Ç!~;4fJ-·· /5 S /2.. ð D . ~ ',"' í)f. 22 .;';:' " ff-- 2' -- ?,f 2r 29'- -;¡{)- 31" §'-r'" :3<!' ~ - ~7 ,e i I \ . I ,~ \ Calculations Char .¡~ Subject Sheet number fl--odtLC/-/OJ1 C CÇ,. S/...,,J1 .2..1 .f of - :5 lee1../p' .Kepc¿Ù"'" I By ,AA' , '-" r/'?e-//rr,k- 94/¿CA ;78Ac. File Date /);;.1 c-1. 3.J. & 5e(;¡ L We t d I: A e.. Ca ~ /e-1 ~ t. h re ()<d $ - wellhead · GíD..çu.¿~ b../e Id5 c:.nð t=/¿Ùrt U/(;./d;. t::r:. W/a.fc.h ih/~Æne.$2. t/f collcrrj;2/eeve (tiP) . ~ -~- · r/f:: 5!eeu~ C/2l/4rA'" . .-L I:: . Í;; f-l 1-0 1e..IÞ1 Q _ 1e...._. . boe...,I.'+ the. s...~oJ ?Veld. ./' - ·1·~~"- £ xl$.iiti.-; t!..a..s.i'n if Collar I , . " ;r- II " U:?é?- ra. ¡qPl S,.L.)Š...-,X r;,S o. 280..:' f?.Jìe~ . for the. 'S/e..et./e co/lar..? .. · tI~ ÚJ" d?/ S"LX-X6.s- .0. 2-8D " wa ¡j (2!~~e.' &,ñ. 1_.:- for £Ae...._$/ee I/e. : ø .0 ue ra Lt sie.ß.vß.. L<?J1,7 lit J . ,0' 211 J-? ........ -D - _ . s.~e....U T 'Sire tc-Å.. .J.or det.e<. / I '5> P//lel:: we.ld$ 'f:; ò' ~~t~t-.. c b J.LQ. r- ti leßI/ß l::: A lc..k.ne$S (typ) (Ii. 1ft. -¡ I/!. f)(P , - ¡.. I I /. .... ·l· I I I ;:::::-~. ..:;-..... . . - . f rv> r r'<" rr:-.. ~;7 . !,~ -\(j) U~d)· U . , -' . . .'.-..".. . -', ,_. . .' , . . . -. . . ,-~- .-" ... . ... ...- ~ .-. . -' ...-~ . . . .--- . -- _. ....... .-, ....-.... - .... ',. - --- ... --. . -L ~.. Q.L. PRINTING (907) 563·4743 tit 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 OPERA TOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak / KRU /1 C-131 07/14/06 Jon Arend/Dennis Sauvageau - ASRC Packer Depth Pretest Initial 15 Min. 30 Min. Well1C-131 I Type Inj. I W TVD I 3,705' Tubin~ 0 0 0 0 Intervall 0 P.T.D.12011850 I Type test I P Test psil 1500 Casing 0 3000 2950 2950 P/F! P Notes: Post SC patch OA Well! I Type Inj. I TVD Tubin~ Intervall P.T.D.I I Type test I Test psil Casing p/FI Notes: OA Well' I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type tes~ Test psil Casing p/FI Notes: OA Weill I Type Inj, I TVD I Tubing Intervall P.T.D.I Type tes~ T est psi! Casing p/FI Notes: OA Weill I Type Inj.1 I TVD I TubinQ Interval P.T.D. I Type tes~ Test psil Casing p/FI 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 o = other (describe in notes) MIT KRU 1C-131 7-14-06 RE: KRU 1 C-121 & 1 C-131 Passing MIT data e e Tom, Going very well. The 1C-121 & 1C-131 repairs were the best executed yet. These are a lot of work as it involves several groups from construction for scaffolding and shoring box, roads and pads group for excavation and backfill, drill site operations for safety work permits, OHO prep and N2 purge support, Well Integrity Engineering project management (MJ, Jerry, myself), welders to remove conductor landing ring and fab and install both surface casing and conductor patches, insulators to install denso anti corrosion coating, and wellwork to set and pull plugs. We are planning to break ground on the next 2 wells, the first ones at 10, 10-109 and 10-111, on Sat 7/22. If all goes well, the conductor will be removed at the end of July and welding repairs will be completed the first week of August. Even with the efficiencies gained by doing 2 wells side by side, they will probably take 3 to 4 weeks per set of two as we work down the list Jerry sent last month rather than 2 every 2 weeks. These are very interesting projects from an engineering prospective, so they are fun to work even with all the extra workload. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, July 18, 2006 8:03 AM To: NSK Problem Well Supv Subject: Re: KRU 1C-121 & 1C-131 Passing MIT data Thanks Marie. How goes the "big dig"? Tom ('f"' b.Í'\hJ¡:;',' -:H..../"\. "''ic¡,,¡..'~i ~~ ~¡ NSK Problem Well Supv wrote, On 7/17/200610:40 PM: Tom, Jim, & Bob, Attached are MITs for 1C-121 (PTO 2010800) & 1C-131 (PTD 2011850) post single casing excavation welded sleeve patch repair. The repairs were completed on 7/12 and 7/13. 10-404's are in the mail reporting completed repair operations under sundry approvals 306-093 & 306-178. Both wells will be schedule for witnessed MITIAs after BOI and thermally equalized, tentatively planned for August 2006. Once witnessed MITIAs pass, the wells will be removed from the failed MITIA report. Please let me know if there are any questions. «MIT KRU 1C-121 7-14-06.xls» «MIT KRU 1C-131 7-14-06.xls» Marie McConnell 7/19/20069:09 AM KRU 1 C-121 & 1 C-131 Passing MIT data e e Tom, Jim, & Bob, Attached are MITs for 1C-121 (PTO 2010800) & 1C-131 (PTO 2011850) post single casing excavation welded sleeve patch repair. The repairs were completed on 7/12 and 7/13. 10-404's are in the mail reporting completed repair operations under sundry approvals 306-093 & 306-178. Both wells will be schedule for witnessed MITIAs after BOI and thermally equalized, tentatively planned for August 2006. Once witnessed MITIAs pass, the wells will be removed from the failed MITIA report. Please let me know if there are any questions. «MIT KRU 1C-121 7-14-06.xls» «MIT KRU 1C-131 7-14-06.xls» Marie McConnell Problem Well Supervisor 659-7224 KRU lC-121 Content-Description: MIT KRU 1C-121 7-14-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 KRU lC-131 Content-Description: MIT KRU 1C-131 7-14-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 7/18/20068:01 AM 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 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRU 11C-131 07/14/06 Jon Arend/Dennis Sauvageau - ASRC C6~ ~.,. ~ 1> \ \ ð-.~\' ,,\ '-V- V Packer Depth Pretest Initial 15 Min. 30 Min. We1l11C-131 I Type Inj. ! W TVD I 3,705' Tubing 0 0 0 0 Interval I 0 PTD.2011850 I Type test I P Test psil 1500 Casing 0 3000 2950 2950 P/FI P Notes: Post SC patch OA Weill I Type Inj. ! TVD Tubing Interval! PTD.I I Type test I Test pSi Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval I PTD.I I Type testl Test psil Casing P/FI Notes: OA Well I Type Inj.1 TVD I Tubing Interval PTD.I I Type testl Test psi! Casing P/FI Notes: OA Well I Type Inj.1 TVD I Tubing Interval! PTD.I I Type test! 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) ". "( ( ..l.W MIT KRU 1C-131 7-14-06.xls L.L TT........ '-""'......""-"".& "'A"A"'At'~ &...Iß'Io.__ 'I' _"A_A'" -- ... --r-...... .... ... -J - - -.J '~ ~ Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 lun 2006 07:00:24 -0800 1'0: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding <john _ spaulding@admin.state.ak. us>, John Crisp <john _ crisp@adm.Ì1Lstáte.ak.us>, Jeff Jones i<jeffjones@admin.state.ak.us>, Chuck Scheve<chuck_scheve@admin.state.ak.us>, Jim Regg kjim_ regg@admin.state.ak.us> . 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 Subject: Date: From: To: CC: -------- 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 NS""i(wefl....i-nt-egr-UyProj <N1878@conocophillips ·~~i..N -- .- JUN" ¡"".' .... aogcc prudhoe bay@admin.state.ak.us .:)\.1" NcD . 12 ¡200b \~-\~\ -ð(:)\-\)s-Ç 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. «IC 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: applicationlvnd.ms-excel 1 C and ID Casing Repair List AOGCC.xls Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 FinaI.doc Content-Type: applicationlmsword lof2 6/26/20067:51 AM ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates PRIORITY NAME TYPE PTD# LEAK DEPTH (ft) COMMENTS I STATUS .-..- _.-- ___._.. '_n__'___ ----..----....---, ...-.. 1 1 C-121 INJ 201-080 4 dC> \ .-\ 15-S- - ,~ 2 ~ 1 C-131 INJ 201-185 7 3 1 0-109 INJ 197 -235 5* - ------.-.--.--- -..--- 4 10-111 INJ 198-166 5* ~ ) 5 10-120 INJ 197-221 7 6 Gas Lift 197-181 None Proactive dig 7 Gas Lift 198-109 None Proactive dig 8 INJ 198-121 5 9 1 D-136 INJ 200-046 None Proactive dig 10 10-137 INJ 200-047 None Proactive dig 11 10-138 INJ 200-048 8 . .._.,,_..._...,,_...._......~- -.--...... I 12 10-139 INJ 200-049 None . 1 Proactive dig . """._.__.". ,.._"_ U_'_' 1 ~ 13 1 C-119 INJ 201-139 16 ~....._-.~-.. ...-.-~-_.. ~ ~ 14 10-135 Jet Pump 201-220 None Proactive dig 15 . -... _.. ._...~._-..-..~._....... ·'--"'-·1 ESP 197-184 None Proactive dig, backup candidate (has 500' casing) 10-135 I ....,...__._.._.~_.n.._._._.._,_'__...._,...,_......._ """I ) 16 1D-141 l Gas Lift 200-112 None Proactive dig backup candidate. Notes: 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 1 C-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 FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AM) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 g.,Ð \ - V~6 Re: Kuparuk River Field, West Sak Oil Pool, 1 C-131 Sundry Number: 306-178 ,.. F ;<1 \ Dear Ms. Loveland: 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. Sincerely, dt.¡f~ Cathy P. Foerster Commissioner tJ. DATED this23 day of May, 2006 Encl. e Conoc;p.,illips Alaska e P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 14, 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 Approval to repair a surface casing ./ leak for ConocoPhillips Alaska, Inc. well1C-131 (PTD # 201-185). Please call Marie McConnell or Perry Klein at 659-7224 if you have any questions. Sincerely, ~ / ~~L~ ~ Well Integrity Project Supervisor Attachments e e 4rd-) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALlIh,,;s!'. 20 AAC 25 280 .... c, 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 ".,'," Other 0 Alter casing 0 Repair well 0' Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-185 3. Address: Stratigraphic 0 Service 0 . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23041-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1C-131 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5915' 4247' 5661 Casing Length Size MD TVD Burst Collapse CONDUCTOR 158' 16" 158' 158 PRODUCTION 5083' 5-1/2" 5083' 3708 LINER 824' 3-1/2" 5907' 4241 , Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5170-5232', 5270-5326' 3763-3801', 3825-3860' 3-1/2" L-80 5091' Packers and SSSV Type: Packers and SSSV MD (ft) no packer Baker 80-40 Seal assembly 5076' 110 SSSV . '," . no SSSV 12. Attachments: Description Summary of Proposal [2] 13. WellClass after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 1, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marie McConnell/Perry Klein Printed Name MJ Loveland ~ Title: Problem Well Supervisor --~ Date ) lf m /9 {/ ð?Ó Signature //""v/ - Phone 659-7224 / Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry N7ñf~ _ \--¡ ~ ....... Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: c.o~\<:.§C.-\- t=~c\o\~\""-a~\-'«Dt-~ <¿~~t'Jè <"<J-c:.\ ~ ~~~. \=> ~\O ~C-U6-'(~J/~ \Q ?c.l1\"? , RBDMS 8Ft MAY .2 4 2006 Subsequent Form Required: l\~~\ Approved by: ~ ¡/Ju -/ LA APPROVED BY S- ,23-&,6 COMMISSIONER THE COMMISSION Date: ! , ~,.. :è ç,lt. . " """< Form 10-403 Revised 7/20t) JGlr~AL ..A o? ~~JPi~b e e ConocoPhillips Alaska, Inc. Kuparuk WelllC-131(PTD 201-185) SUNDRY NOTICE 1 0-403 APPROVAL REQUEST May 14, 2006 This application for Sundry approval for Kuparuk well 1 C-131 is for the repair of a production casing leak. This well is a single casing injector; it has no surface casing. It was completed in October 2001. On May 8, 2006, the well failed an MITIA. A leak rate was not established but the leak depth has been estimated at 6' 8" below the production casing annular valve corresponding to the top of cement in the conductor. Since the mode of failure is suspected to be the same as other wells with similar construction, it is requested to inspect and repair the production casing near surface on this well. With approval, repair ofthe production casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater 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. Cut away the conductor casing and remove cement around su~face casing for inspection. Approxilnately'the tQpt~n feet ofcogd-u.cjOLwjllbe re1110vedíè provide access to the ~ production casing. ~ t-<:)-\"{ ~l :t..~~~~,:\c> \-~~~~+\ß-~ð~\~)f211:J)1 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the.!:7~3 casing to operational integrity. 7. QA/QC the repair and MIT -IA for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top offwith sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to water injection. 12. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 5/14/2006 1 C-131 (PTD 201-185) Failed 4 year witnessed MITIA e e Tom, 1C-131 ( PTD201-185) produced water injector failed it's 4 year MITIA 05/08/06 during the witnessed testing. The injection casing failed, at approx 1000psi, to atmosphere via the conductor during the MITIA. This is a single casing string injection well. 1C-131 last passed an MITIA on 07/27/05. The well was shut in at 9:13 a.m. 05/08/06 and secured with a WRP. Initial T/I = 806/0 Final TII = 806/0 Let me know if you need any additional information Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «1 C-131.pdf» Content-Description: 1 C-131.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/23/2006 12:08 PM .' MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg~" _ ( P.I. Supervisor KrY"'1 '5 Z3/[~~ DATE: Monday, May 22,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-131 KUPARUKRIVUWSAK IC-13l ,/\ C6 6 ~O\ FROM: J eff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv --.:JE'iZ-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IC-131 API Well Number 50-029-23041-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060508183230 Permit Number: 201-185-0 Inspection Date: 5/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min, 30 Min, 45 Min, 60 Min, ~ iIA I ! Well IC-131 !Type Inj, : W i TVD 3705 0 ¡ I I í I P.T, ! 2011850 ITypeTest ! SPT I Test psi 1500 i OA i -----¡-- I í I I ! Interval 4YRTST PIF F Tubing ¡ 806 ¡ ! i ! -- Notes Monobore injector; surface casing experienced catastrophic failure to atmosphere while pressuring (failed at approx. 1600 PSI) up the IA for the MIT The well was immediately shut in.) well house inspected; no exceptions noted, V SG/',NNED J (~ Monday, May 22, 2006 Page 1 of 1 e (lPHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING 1C-131 (0-5001. 00:3.500, 10:2.992) ~OOUCTION (0-5083, 00:5.500, Wt:15.5O) NIP (5038-5039, 00:4.520) NIP (5076-5077, 00:4.500) SEAL (5077-5078, 00:4.000) Perf (5170-5232) LINER (5083-5907, 00:3.500, Wt:9.30) Perf (5270-5326) . KRU 1C-131 API: 500292304100 SSSV Type: NONE Annular Fluid: Rev Reason: Format update by ImO Last U date: 6/23/2002 Bottom 158 TVD 158 Wt Grade Thread 62.58 API5L PEB GrB 15.50 L-80 BTC 9.30 L-80 EUE 5083 5907 3708 4241 Thread EUE Comment 2.5" HSO BH Chg, 60 deg h 2.5" HSO BH Chg, 60 deg h Vlv Cmnt Descri tion CAMCO 'OS' NIPPLE WITH NO GO PROFILE BAKER LOCATOR SUB NIPPLE BAKER 8040 SEAL ASSEMBLY ID 2.812 2.992 3.000 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\MicrofiJm _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) ) :S'; ,,;!Þt'l:' . .,.:",,~¡."',('!\'~' . ",,'~. , dÞl;,l"" Jf~1 1l~'jIÒ) 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 I KRU/ 1 C 07/27/05 Rodgers - AES Packer Depth We1l1C-131 Type Inj. N TVD 3,705' Tubing ~O P.T.D. 2011850 Type test P Test psi 1500 Casing -/ Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Pretest o o Initial 15 Min. 30 Min. 2050 1850 000 Interval P/F o F Well 1C-131 Type Inj. N TVD 3,705' Tubing 1850 2000 P.T.D. 2011850 Type test P Test psi 1500 Casing 0 0 Notes: Mono-Annulus Integrity Verification MITT 2nd bump up test with plug in tbg. Well 1C-131 Type Inj. N TVD 3,705' Tubing 1800 P.T.D.2011850 Type test P Test psi 1500 Casing 0 Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Well 1 C-133 Type Inj. N TVD 3,666' Tubing 0 P.T.D. 2010770 Type test P Test psi 1500 Casing 0 Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Well 1 C-133 Type Inj. N TVD 3,666' Tubing 1900 P.T.D. 2010770 Type test P Test psi 1500 Casing 0 Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Test Details: 1960 1950 Interval o 0 P/F o P 2000 2000 2000 Interval 2500 2450 2440 P/F o P 2060 2010 2010 Interval o 0 0 P/F o P 2130 2125 2100 Interval 2550 2475 2460 P/F o P SC;\NNED J'\UG 0 9 20Œj 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 2005-0727 _MIT _KRU_1C-133_MITT.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) SChlumbergel' NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ð· ----- e::;7) ¿? I - l?f:;; 02/28/05 SCANNED .JUN 1 7 2005 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL i'ð'5 -c;5C 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 (84-153 2D-03 10922538 PROD PROFILE/DEFT 02/06/05 1 ;Z f.YO - 2.i 0 1 D-39 10942838 INJECTION PROFILE 02/11/05 1 /:75- -Dl~ 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 '~O(- 163 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 /90 - /~I 1 A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79 _úí¿:; 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 19/ - ~ 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 ., OP-,_11 h 1 B-15A 10922540 SCMT 02/24/05 "- ( 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 ftl,()&f¡;; Kuparuk Color CD - 1 -' SIGNdÄ&)/ /lÞ~~ DATE: ~þ- Please sign and return%ne copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ L> fìu- DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011850 Well Name/No. KUPARUK RIV U WSAK 1C-131 Operator CONOCOPHILLIPS ALASKA INC S¡1~J..)Y¥~, API No. 50-029-23041-00-00 MD 5915 ~ TVD 4247/, Completion Date 11/25/2001 r Completion Status 1WINJ REQUIRED INí-ORMATION Mud Log No Samples No Directional Survey -No -1 -~- ------ .~---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) --{ Logl Data Digital Typy MedlFrmt rcog .J!og ~ Electr Dataset Number Name ~^~~ Log Log Run Interval Scale Media No Start Stop 5 Blu 1 4300 5372 5 Blu 1 4990 5405 1 104 5905 OHI CH Received Comments Case 7/2612002 with WFL anCi- Temp-- -. - i Warm back 11262 ~À~~).. Case 7/19/2002 Case 11/1/2002 Digital Data: Rate of ¡ Penetration, Dual Gamma i Ray, Electromagnetic Wave Resistivity i i I ----- - ---- ------ __I ; , ~D 10644 1 103 5851 Open 3/4/2002 Sample Set Number Comments Well CoreslSamples Information: Name Interval Start Stop Sent Received ~--- ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/N ðlN Chips Received? -Y I N .--, Formation Tops Analysis Received? ~ -- -. --- un --- --- - Comments: ()J 0\ 't- ~r--- K V":> \';> V'\ C ~ h1 : <- 'b ~. ~ u.\^-"). I b- 1M...c.. ~ ~ I Cß L. M ¥ a~ I ~k (:)~ ~ ß,t.. $ ~ --- - -- --- Compliance Reviewed By: Date: - - -- - - q-~~ 3 \ t: do/-/'I5 /Geod;? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage, Alaska 99501 October 31, 2002 RE: MWD Fonnation Evaluation Logs: IC-131, AK-MM-II162 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lC-131: Digital Log Images: 50-029-23041-00 1 CD Rom ~~ REceIVED NOV 0 1 2002 Ala!ka Oii &. G~Q c.. . \ ~,;) ons. Cc.ilnmilSion Anchorage Schlombel'gel' Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth '-- Log Description Date Well Job # 1C-131 1 C-133 1 F-02 1Q-15 2G-03 2H-15 2K-08 2K-27 2X-13 3C-15 1 D-1 03 07/08/02 07/05/02 07/07/02 07/03/02 07/01/02 07/09/02 07/02/02 06/30/02 07/04/02 07/07/02 06/08/02 -- SIGN~ ~~ NO. 2255 Company: Field: BL 1 1 1 1 1 1 1 1 1 1 07/23/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Sepia CD Color 1 RECEIVED DATE: JtJL 26 20&. Alaska OH & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ScblUlll-epger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Log Description Date Job# 1C-131 1 E-03 1 E-23 1 G-07 - 10-12 1 R-11 2A-17 2H-13 - 2U-06 - 2U-09 - 2X-10 3B-05 3F-18 3H-03 3H-18 INJECTION PROFILE PROD PROFILE/DEFT INJECTION PROFILE DDL & PROD PROFILE/DEFT INJECTION PROFILE PRODUCTION PROFILE STATIC PRESSITEMP LOG INJECTION PROFILE STATIC PRESSITEMP LOG PRESSITEMP-STATIC BHP PRODUCTION PROFILE INJECTION PROFILE PRODUCTION PROFILEIDEFT PRODUCTION PROFILE INJECTION PROFILE 06/18/02 06/10/02 06/28/02 06/25/02 06/06/02 06/27/02 06/15/02 06/22/02 06/15/02 06/19/02 06/26/02 06/11/02 06/17/02 06/12/02 06/13/02 SIGNED~ G. 0 Q 0 ~ BL NO. 2226 Company: Field: Sepia 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 07/15/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk _. CD Color Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. -~ RECE'VED DATE: JUL mOa2 Alaska oa & Gas Cons. Commisskm Anchorage II' I I. WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 26, 2002 RE: MWD Formation Evaluation Logs 1 C-131 , AK-MM-11162 1 LDWG formatted Disc with verification listing. API#: 50-029-23041-00 aO/-/~S- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signe~' IA i)Jl~ Date: RECEIVED r,~.~ P D / r;no? '. \: , .. L.. ..... Alaska Oil & Gas Conso Commission Anchorage "~'5"'" aOJ-O(d Ô1DI- , 515 Iq~~ I~ I d ~- p./.,;; } -0 l.D 1../ ) 5-\ \5 a.. Ob-~O ~ òù)-IO't '--- Sc~._epgep NO. 1732 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Field: Well Log Description BL Sepia Job # Date 01 !l7!O2 Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color 2P-438 21276 DSI OH EDIT OS/28/01 1 2P-438 21276 DSI OS/28/01 1 1 2P-438 21276 DSI TVD OS/28/01 1 1 1C-131 STATIC BOTTOM HOLE SURVEY 12/15/01 1 1 1H-16 (REDO) PRODUCTION PROFILE WIDEFT 11/21/01 1 1 2N-348 JEWELRY lOG 12/09/01 1 1 2Z-07 LEAK DETECTION 12/21/01 1 1 3B-11 PRODUCTION PROFILE WIDEFT 12/11/01 1 1 3F-21 RST WATERFLOW LOG 12/10/01 1 1 3K-19 RST WATER FLOW LOG 12/09/01 1 1 3K-19 INJECTION PROFILE 12/09/01 1 1 RECEIVED SIGNE~ {" Q Oo~ J DATE: v~ 252002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8~Qj~Cons.Commission M chorage ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 January 11, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1C-131 (201-185) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West Sak well 1 C-131. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, Q,~ C. Mallary Drilling Engineering Supervisor P AI Drilling CM/skad OR I GI NAL RECEIVED JAN 1 -4 2007 AlaSka Oil & Gas C - AnChor:~ CommisSion ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil D Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface . ~'--..,-. ..."'" -.. . '", - I -:: ',: Suspended 0 Service [2] Abandoned 0 LUuÙKJNS , YfilFttÐ 'S",~k. , .. ,,' ~"':-". ' 'c'-'", ""_'.:: -.- -,. -"",~,~',~~';':"""""'" (ASP: 561981, 5968564) 1673' FNL, 973' FWL, Sec. 12, T11N, R10E, UM ' ; At Top Producing Interval i / ::;';:'-: , . LL 2.S' '0(1 326' FSL, 965' FWL, Sec. 12, T11N, R10E, UM : - ------, ~1'?~:, ¡: '~:.-' ~ At Total Depth < -J P.-- ,~ 61' FNL, 968' FWL, Sec. 13, T11 N, R10E, UM ~"'--'~"-'~~""~ (ASP: 562009, 5964896) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 102' AMSL ADL 25649 & 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date~I'IP., SI,!.Sp. Or Aband. ð~, z.S, September 29, 2001 October 3, 2001 ~001 ){1> 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 5915' MD 14247' TVD 5811' MD / 4177' TVD YES [2] No 0 22. Type Electric or Other Logs Run GR/Res 23. (ASP: 562002, 5965283) Classification of Service Well Water Injector 7. Permit Number 201-185 8. API Number 50-029-23041-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1C-131 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore NIA feet MSL 20. Depth where SSSV set N/A feet MD CASING SIZE CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 5083' 5083' 5907' GRADE H-40 L-80 L-80 HOLE SIZE 16. No. of Completions 1 21. Thickness of Permafrost 1991' MD 24" CEMENTING RECORD 367sxAS1 500 sx AS mLite, 400 sx Class G included above WT. PER FT. 62.5# 15.5# 9.3# 16" 5.5" 3.5" 7.875" 7.875" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) AMOUNT PULLED 3.5" TUBING RECORD DEPTH SET (MD) 5091' PACKER SET (MD) N/A 25. SIZE 5270' - 5326' MD 5176' - 5232' MD 5170' - 5175' MD 3825' - 3860' TVD 3767' - 3801' TVD 3763' - 3766' TVD 4 spf 4 spf 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 27. Date First Production PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period> Calculated 24-Hour Rate> WATER-BBL Date of Test Hours Tested WATER-BBL Flow Tubing OIL-BBl GAS-MCF Casing Pressure 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 tll ~r ð 1EN~t~ ~ B 0 M 5 B F l fJ ~ JAN 2 4 2002 CHOKE SIZE GAS-Oil RATIO Oil GRAVITY - API (corr) RECEIVED JAN 1 4: 2002 Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate . i " GEOLOGIC MARKERS 30. (' FORMATION TESTS 29. NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested. pressure data, all fluids recovered and gravity. GOR, and time of each phase. West Sak D West Sak A3 West Sak Base 5170' 5399' 5837' 3763' 3905' 4194' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 S. d C /1;1ALQ/~ / Igne ... ~ v Title Drillina Enaineerina Supervisor Date {I ~/.... D :;L C. Mallary Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, W~~ë'o~Gas IË'ection, Shut-in, Other-explain. t(1:: 1:.1 V: [,' Item 28: If no cores taken, indicate "none". JAN 1 4 ?nrn Form 10-407 OR 1 G1 NAL Alaska Oil & Gas Cons. Commission Anchorage (' ( Page 1 of 3 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-131 Common Well Name: 1 C-131 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 9/28/2001 10:00 - 14:00 4.00 MOVE MOVE MOBMIR 14:00 - 21 :30 7.50 WELCTL NUND PROD 21 :30 - 22:00 0.50 WELCTL BOPE PROD 22:00 - 00:00 2.00 RIGMNT OTHR PROD 9/29/2001 00:00 - 01 :00 1.00 DRILL RIRD PROD 01 :00 - 02:30 1.50 DRILL PULD PROD 02:30 - 05:30 3.00 DRILL PULD PROD 05:30 - 06:00 0.50 DRILL CIRC PROD 06:00 - 06:30 0.50 DRILL SFTY PROD 06:30 - 07:30 1.00 DRILL DRLG PROD 9/30/2001 10/1/2001 07:30 - 09:00 1.50 DRILL OTHR PROD 09:00 - 10:30 1.50 DRILL DRLG PROD 10:30 -11:00 0.50 DRILL SURV PROD 11 :00 - 15:30 4.50 DRILL DRLG PROD 15:30 - 19:00 19:00 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:30 03:30 - 20:00 20:00 - 20:30 20:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 02:30 02:30 - 05:00 3.50 RIGMNT RGRP PROD 3.00 DRILL DRLG PROD 2.00 RIGMNT RGRP PROD 1.00 RIGMNT RGRP PROD 1.50 RIGMNT RGRP PROD 1.00 RIGMNT RGRP PROD 16.50 DRILL DRLG PROD 0.50 DRILL 2.50 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 2.50 DRILL DEOT PROD TRIP PROD PULD PROD SURV PROD SURV PROD PULD PROD SURV PROD TRIP PROD Spud Date: 9/29/2001 End: 10/5/2001 Group: Start: 9/29/2001 Rig Release: 10/5/2001 Rig Number: 245 Description of Operations Mil and RIU Nabors 245E - accept rig at 14:00 hrs. 09/28/01 N/U diverter system, Build spud mud and check out tanks and lines for leaks. P/U Vetco casing hanger and landing jt. set in well head and mark landing jt. Test diverter and accumulator. Shut down to clean on rig. Ordered by Nabors management. Rig up to pick up HWDP P/U and stand back 20 jts of 4" HWDP, jars and 1 stand of flex DC's P/U Sperry Suns Mud motor & MWD, upload MWD, adjust and test motor. Fill conductor with mud and circ. system, checking for leaks. Have pre-spud meeting and diverter drill. Clean out fill in conductor from 120' to 158', spud and drill new formation from 158' to 194', flow line packed of with foam insulation, paper sacks and gravel. Spud and drill new formation at 0700 hrs. 09/29/01 Clean out flow line Drill from 194' to 282' Run gyro survey, first attempt failed, rerun survey, .45 degree, direction 185 degree Drill from 282' to 611' ART = 3 hrs. AST = 1 hr. Murphy swithch on fuel system failed causing motors to run out of fuel. When this happened we lost all power, discflow pumps and lines then packed off with sand and gravel. Had to get a vac. truck out to help clean out discflow system. After Motors were started and fuel pressure was restored to fuel system, a screw on fuel filter on a tioga heater on top of rig blew a gasket. Fuel leaked down the side of rig and onto the matting boards and gravel under rig. Notified and turned in spill report to all authorities, claiming a 42 gal. spill. Spill was immediatly caught and taken care of by drill crew, with oil absorbant clothes and removing contaminated gravel. We will still have some to clean up under mat boards when rig is moved. Drill from 611' to 833' ART = 1.5 hrs. AST = 1.25 hrs. Top drive koomey actuator pump failed for pipe grabber POOH into conductor pipe Replace hydraulic pump on torque tube TIH to 833', tight spot at 715' Drill from 833' to 2474' MD, 2083' TVD AST = 5 ART = 5.75 MWD failed, attempt to regain pulse POOH to check out MWD tool and repair. UD BHA . Download MWD Download MWD. Change out Pulsar sub. MU bit. Orient Mtr & MWD. PU Pony DC Load MWD data. RIH to HWDP. Surface test MWD. RIH to 2451'. Pump Survey. Contine RIH to bottom at 2474'. - Printed: 10/25/2001 8:33:36 AM ..... ...... ..... 1~'PHILLiPS) ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/1/2001 10/2/2001 10/3/2001 10/4/2001 10/5/2001 Date ( (" Page 2 of 3 PHilliPS ALASKA INC. Operations Summary Report 1 C-131 1 C-131 ROT - DRILLING n1268@ppco.com Nabors 245 Spud Date: 9/29/2001 End: 10/5/2001 Group: Start: 9/29/2001 Rig Release: 10/5/2001 Rig Number: 245 Description of Operations Sub From - To Hours Code Code Phase 05:00 - 14:00 14:00 - 14:30 14:30 - 00:00 00:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 08:30 08:30 - 10:30 10:30 - 11 :00 11 :00 - 13:30 13:30 - 19:30 19:30 - 21:00 21 :00 - 23:30 23:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 04:30 04:30 - 05:00 05:00 - 05:30 05:30 - 07:30 07:30 - 10:00 10:00 -11:00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 13:30 13:30 - 15:00 15:00 - 16:00 16:00 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 05:30 9.00 DRILL DRLG PROD 0.50 RIGMNT RSRV PROD 9.50 DRILL DRLG PROD 18.00 DRILL 1.00 DRILL 3.00 DRILL DRLG PROD CI RC PROD TRI P PROD 0.50 DRILL PULD PROD 0.50 RIGMNT RSRV PROD 1.00 DRILL TRIP PROD 1.00 DRILL TRIP PROD 0.50 DRILL TRIP PROD 7.00 DRILL 2.00 DRILL 0.50 DRILL 2.50 DRILL 6.00 DRILL 1.50 DRILL 2.50 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 2.50 DRILL 1.00 DRILL 0.50 CASE 0.50 CASE 1.50 CASE 1.50 CASE 1.00 CASE 3.00 CASE 1.00 CASE TRIP PROD REAM PROD CIRC PROD REAM PROD DRLG PROD CIRC PROD WIPR PROD CIRC PROD CIRC PROD SFTY PROD TRIP PROD SFTY PROD TRIP PROD PULD PROD PULD PROD PULD PROD SFTY PROD RUNC PROD RUNC PROD PUTB PROD RUNC PROD OTH R PROD RUNC PROD 1.00 CASE RUNC PROD 3.00 CASE RUNC PROD 1.50 CASE RUNC PROD 0.50 CASE RUNC PROD 3.50 CEMENl CIRC PROD Drill ahead AST =0.25 ART =6.25 Service top drive. Drill ahead. AST =0.5 ART =5 Drilling from 4446' to 5345' MD (3885' TVD) AST =2.25 ART =10.5 Circ. bottoms up, check flow, pump pill, blowdown. TOOH for bit change. Bit 1" undergauge, balled up, and 1 cone locked up. Change bit. Service top drive. Safety Meeting and TIH. RIH wI Bit, BHA, and 2 stds HWDP. Surface test MWD. RIH to 1260'. Took full string wt. Reorient string. Came loose. Same at 1479' RIH to 1620'. Pushing rocks ahead to 4356'. MU top drive. Wash and ream f/4356' to 4641' Circ btms up. Condition hole. Wash and ream f/4641 , to 5345'. Drill ahead f/5345' to TD at 5915' MD (4247' TVD) ART =4 AST=1 Circ btms up. Pump hi vis sweep. Short trip to 4072'. Max overpull = 10000 Ibs. Circ btms up. Pump hi vis sweep. Pump 40 bbl high vis sweep. Circ and condition hole. Monitor well. Pre job safety meeting. Pump pill. POOH w/5 stands. Blowdown top drive. Install air slips. POOH to HWDP. Monitor well. Pre job safety meeting. POOH to MWD. Hole tight at 650' (35K over) and 320' (20K over). Download MWD. LD BHA Pre job safety meeting. Stand 33 jts 3-1/2" tubing in derrick. Change out saver sub on top drive. Pre job safety meeting prior to running casing. Run shoe and float joints. Install landing sleeve. Check floats. Run 3-1/2" casing. PU SBE assembly. RU GBR spiders and elevators. Run 5-1/2" casing Frank's fill up tool broke into 3 pieces. Middle piece fell to rig floor. Bo,ttom piece fell downhole. SD for incident investigation. POOH w/ 6 jts 5-1/2" casing. Recovered bottom part of Frank's fill up tool. Run 5-1/2" casing. Continue running 5-1/2" casing. Continue running 5-1/2" casing PU csg hangar and landing joint. MU cementing head. Land casing. Circ and condition mud. Blend cement in Dowell unit while circ. R/U Dowell cementers Printed: 10/25/2001 8:33:36 AM ~ ~ ~ ~'PHILLIPS ~~ IrÐJ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/5/2001 10/6/2001 ( f PHILLIPS ALASKA INC. Operations Summary Report 1 C-131 1C-131 ROT - DRILLING n1268@ ppco.com Nabors 245 Sub From - To Hours Code Code Phase 05:30 - 06:00 06:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 18:30 18:30 - 19:30 19:30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 04:00 04:00 - 05:30 05:30 - 07:00 07:00 - 07:30 07:30 - 10:30 10:30 - 11 :30 11 :30 - 14:00 14:00 - 17:00 0.50 CEMENl SFTY PROD 2.50 CEMENl PUMP PROD 2.00 WELCTL NUND PROD 1.50 WELCTL NUND PROD 6.50 WELCTL NUND PROD 1.00 WELCTL NUND PROD 2.50 WELCTL BOPE PROD 0.50 CMPL TN SFTY PROD 1.50 CMPL TI\ RUNT PROD 1.50 CMPL TN RUNT CMPL TN 1.00 RIGMNT RGRP CMPL TN 1.50 CMPL TN RUNT CMPL TN 1.50 CMPLTN SOHO CMPLTN 1.50 CMPLTN CIRC CMPLTN 0.50 CMPL TN FRZP CMPL TN 3.00 CMPL TN DEQT CMPL TN 1.00 CMPL TN NUND CMPL TN 2.50 CMPL TN NUND CMPL TN 3.00 RIGMNT RURD CMPL TN Page 3 of 3 Spud Date: 9/29/2001 End: 10/5/2001 Group: Start: 9/29/2001 Rig Release: 10/5/2001 Rig Number: 245 Description of Operations Hold pre-job safety and job planning meeting Pump 10 bbls CW-100, test lines to 3000 psi, pump 50 bbls CW-100, 50 bbls. Mud Push with red dye, Pump 500 sx (395 bbls) artic set lite lead and 400 sx (83 bbls) Artic set tail cement. Displace with 127 bbls 3% KCL water, bumped plug with 1300 psi, pressure to 1600 psi, bled back pressure and floats held. RID Dowell. Recipricated the casing string with 165,000 up and 105,000 down, until red dye hit surface, casing started sticking, so set in hanger the rest of cement job. Had 82 bbls good cement back to surface. Held pre-job meeting - Wash out diverter and N/D Hold pre-job meeting - N/U well head and test to 1500 psi for 15 mins Hold pre-job meeting - N/U BOP's PIU tubing hanger and landing jt. and make sure it would go into wellhead. Test BOP's to 250 psi low and 2500 psi high Held pre-job safety and tubing running planning meeting RIH wlseal assembly, DS nipple w/2.8121D, and camco gas lift mandrel on 3 1/2" 9.3# L-80 EUE tubing. Presently 30 jts in hole. Continue RIH wI 3-1/2" tubing Pre-job safety meeting. Repair air hose on top drive. Continue RIH wI 3-1/2" tubing RIU and Circ. into SBE to verifify landing, run in seal assembly into SBE and tag locator, space out and install tubing hanger PIU out of SBE and reverse circ hole clean with 8.5 ppg clean KCL brine, pump 60 bbls diesel down annulus for freeze protection Hook annulus and tubing in communication and let diesel U-tube Sting into seal bore extention and land hanger, pressure test annulus to 500 psi, check for communication, test tubing to 500 psi and check for communication, everything ok. blow down all lines for freeze protection Install 2 way valve, N/D BOP's N/U tree, test to 5000 psi, pull 2 way valve, install BPV Slip and cut drill line, change out TDS saver sub back to HT -38 for next well Release rig at 1700 hrs. 10/06/01 Printed: 10/25/2001 8:33:36 AM Date 10/19/01 11/22/01 11/25/01 12/15/01 12/20101 12/27/01 ( 1 C-131 Event History ( Comment DRIFTED TBG WI 10' OF 1.87511 STEM & TAGGED @ 5757' RKB [TAG] DRIFTED TBG WI 23' OF 2.6011 DUMMY GUN'S & TAGGED @ 5661' WLM [TAG] PERFORATED B SAND INTERVAL 5270' - 5326', W/ 2.511 HSD 4 SPF BH CHGS 60 DEG PHASING. JOB IN -- PROGRESS [PERF] PERFORATED 4 RUNS: INTERVALS: 5212-5232/5192-5212/5176-5192/5170-5175 FT MD WITH 2.511 HSD @ 4 SPF. 2506 POWERFLOW HMX (BH) CHARGES. RAN A SBHP - AT 5250 FT MO = 1628.2 PSIA @ 75.7 DEGF. AT 5150 FT MD = 1608 PSI PSIA @ 76.5 - 75.8 DEGF. TOOL PULLED 0 RECOVERED 22', SWS LOGGING TOOL STRING FI 5732' WLM, COMPLETE [FISH] INJECTED 5 BBLS METH, 15 BBLS DIESEL, AND 5 BBL METH TAIL (TOT 25 BBLS). EST INJ AT 0.75 BPM AT 600 PSI PRESSURE CLIMBED TO 1250 PSI, INCREASED RATE, PERFS BROKE ON AT 1.25 BPM AND 1550 PSI. FINAL RATE 1 BPM AT 1350 PSI. FINAL TGB PRESSURE 950 PSI. Page 1 of 1 1/3/2002 ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( 08-Nov-Q 1 Definitive Re: Distribution of Survey Data for Well 1C-131 aO)-i t 5 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 5,920.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RE(~E'\lE,[' NOV 1 3 2001 Alaska. Oil & Gas Cons, Commì$Slon Anchorage t f ~~J'~.~.}~I..,¡.J.,.,.;" ÇY.>,:;~\S.. .',' :"':;¡" ,..,.,;",:;.':1~.:~ 1 O-Jan-O2 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-131 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 5,915.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN oj 1 2002 Alaska OU & Gas Cons, Commission Anchorage DEFt N ITIVE \..... . Kuparuk River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-131 1C-131 Job No. AKMM11162, Surveyed: 3 October, 2001 .--. SURVEY REPORT 10 January, 2002 Your Ref: API 500292304100 Surface Coordinates: 5968563.88 N, 561980.83 E (10° 19' 28.7247" N, 149029' 50.7030" W) Kelly Bushing: 101.45ft above Mean Sea Level --" h 5 P E! ...,..... Y -5 U fl DRILLIN~ A H8111burton Comp8ny Survey Ref: svy9640 Sperry-S un Dr; /ling S erv;c¡~ Survey Report for 1C-131 Your Ref: API 500292304100 Job No. AKMM11162, Surveyed: 3 October, 2001 .. . North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) \ . 0.00 0.000 0.000 -101.45 0.00 0.00 N 0.00 E 5968563.88 N 561980.83 E 0.00 MWD Magnetic -. \",.,.... 176.00 0.450 185.000 74.55 176.00 0.695 0.06W 5968563.19N 561980.78E 0.256 0.69 323.93 3.680 222.130 222.37 323.82 4.79 S 3.30 W 5968559.06 N 561977.57 E 2.253 4.79 412.74 6.420 225.550 310.82 412.27 10.385 8.75 W 5968553.43 N 561972.16 E 3.102 10.38 504.88 6.490 225.680 402.38 503.83 17.635 16.16W 5968546.12N 561964.82E 0.078 17.63 596.45 7.250 231.010 493.29 594.74 24.885 24.35W 5968538.80N 561956.69E 1.082 24.88 686.90 11.120 240.380 582.57 684.02 32.785 36.37 W 5968530.80 N 561944.73 E 4.573 32.78 778.80 15.170 239.270 672.04 773.49 43.31 S 54.42W 5968520.12 N 561926.77 E 4.415 43.31 873.92 15.450 228.310 763.81 865.26 58.105 74.59W 5968505.16N 561906.73E 3.052 58.10 969.08 16.090 221.640 855.39 956.84 76.395 92.81 W 5968486.73 N 561888.65 E 2.019 76.39 1064.12 18.430 208.000 946.18 1047.63 99.51 5 108.63 W 5968463.48 N 561873.03 E 4.903 99.51 1157.85 21.350 192.810 1034.37 1135.82 129.255 119.37W 5968433.64 N 561862.53 E 6.308 129.25 1252.92 23.200 189.350 1122.35 1223.80 164.61 5 126.26 W 5968398.23 N 561855.94 E 2.385 164.61 1346.65 25.700 190.200 1207.66 1309.11 202.84 8 132.85 W 5968359.95 N 561849.66 E 2.693 202.84 1440.11 31.120 192.840 1289.84 1391.29 246.365 141.82W 5968316.35N 561841.05E 5.952 246.36 1535.65 36.220 192.880 1369.33 1470.78 297.988 153.60 W 5968264.64 N 561829.69 E 5.338 297.98 1631.06 39.160 190.390 1444.82 1546.27 355.118 165.32W 5968207.42N 561818.45E 3.470 355.11 1725.49 44.200 187.530 1515.34 1616.79 417.128 175.02 W 5968145.33 N 561809.26 E 5.703 417.12 1820.12 47.400 183.340 1581.31 1682.76 484.628 181.38W 5968077.78 N 561803.46 E 4.637 484.62 --'" 1915.50 50.700 177.650 1643.85 1745.30 556.598 181.91 W 5968005.80 N 561803.52 E 5.679 556.59 2009.53 53.900 174.750 1701.35 1802.80 630.808 176.94 W 5967931.64 N 561809.11 E 4.187 630.80 2103.83 54.970 170.180 1756.22 1857.67 706.81 5 166.86 W 5967855.72 N 561819.81 E 4.102 706.81 2199.22 55.030 170.330 1810.93 1912.38 783.82 S 153.64 W 5967778.82 N 561833.67 E 0.143 783.82 2293.88 53.180 169.800 1866.43 1967.88 859.358 140.41 W 5967703.40 N 561847.52 E 2.006 859.35 2386.10 51.540 178.690 1922.81 2024.26 931.87 S 133.04 W 5967630.94 N 561855.49 E 7.834 931.87 2478.86 52.090 178.240 1980.16 2081.61 1004.76 S 131.09 W 5967558.07 N 561858.05 E 0.705 1004.76 2572.91 51.790 178.060 2038.14 2139.59 1078.775 128.70 W .5967484.08 N 561861.05 E 0.353 1078.77 2667.45 52.040 179.480 2096.46 2197.91 1153.16 S 127.10W 5967409.71 N 561863.26 E 1.211 1153.16 2758.79 51.910 177.360 2152.73 2254.18 1225.088 125.12 W 5967337.81 N 561865.83 E 1.834 1225.08 2853.47 51.910 177.910 2211.13 2312.58 1299.53 S 122.04 W 5967263.38 N 561869.52 E 0.457 1299.53 ---------- ---- ---------- -- - ---.. -- .. t; 10 January, 2002 - 16:11 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1C-131 Your Ref: API 500292304100 Job No. AKMM11162, Surveyed: 3 October, 2001 . . North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth 'ncl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) r 2950.06 51.740 178.210 2270.83 2372.28 1375.42 S 119.47W 5967187.52 N 561872.72 E 0.301 1375.42 \ 3044.74 51.160 176.820 -- '- 2329.84 2431.29 1449.39 S 116.27 W 5967113.57 N 561876.54 E 1.301 1449.39 3139.92 50.750 178.720 2389.80 2491.25 1523.25 S 113.39 W 5967039.74 N 561880.03 E 1.609 1523.25 3234.76 50.790 176.670 2449.78 2551.23 1596.65 S 110.43 W 5966966.37 N 561883.59 E 1.675 1596.65 3329.59 50.800 178.790 2509.73 2611.18 1670.07 S 107.52 W 5966892.98 N 561887.11 E 1.732 1670.07 3424.27 50.730 177.220 2569.62 2671.07 1743.36 S 104.97 W 5966819.72 N 561890.26 E 1.286 1743.36 3518.73 50.540 177.430 2629.53 2730.98 1816.31 S 101.56 W 5966746.80 N 561894.27 E 0.265 1816.31 3612.07 50.270 176.960 2689.02 2790.47 1888.14 S 98.04 W 5966674.99 N 561898.39 E 0.484 1888.14 3708.97 50.740 177.800 2750.65 2852.10 1962.84 S 94.63 W 5966600.33 N 561902.42 E 0.826 1962.84 3803.79 51.100 177.100 2810.42 2911.87 2036.37 S 91.35 W 5966526.82 N 561906.30 E 0.687 2036.37 3895.81 51.220 178.820 2868.14 2969.59 2108.00 S 88.80 W 5966455.22 N 561909.44 E 1.462 2108.00 3990.24 51.060 178.110 2927.38 3028.83 2181.50 S 86.83 W 5966381.74 N 561912.02 E 0.609 2181.50 4085.07 51.640 178.010 2986.61 3088.06 2255.52 S 84.32 W 5966307.74 N 561915.14 E 0.617 2255.52 4179.44 51.780 175.330 3045.09 3146.54 2329.45 S 80.02 W 5966233.85 N 561920.05 E 2.234 2329.45 4274.97 51.980 174.150 3104.07 3205.52 2404.29 S 73.13 W 5966159.07 N 561927.56 E 0.994 2404.29 4370.71 52.200 174.480 3162.89 3264.34 2479.45 S 65.65 W 5966083.97 N 561935.67 E 0.356 2479.45 4465.37 52.630 173.770 3220.63 3322.08 2554.07 S 57.97 W 5966009.42 N 561943.96 E 0.748 2554.07 4561.09 52.170 177.110 3279.04 3380.49 2629.65 S 51.93 W 5965933.89 N 561950.62 E 2.806 2629.65 4655.88 51.400 173.330 3337.69 3439.14 2703.84 S 45.74 W 5965859.75 N 561957.42 E 3.236 2703.84 --", 4750.57 51.170 175.370 3396.92 3498.37 2777.36 S 38.47 W 5965786.30 N 561965.31 E 1.698 2777.36 4846.59 50.370 175.670 3457.65 3559.10 2851.51 S 32.65 W 5965712.20 N 561971.73 E 0.868 2851.51 4940.95 50.800 177.050 3517.56 3619.01 2924.26 S 28.03 W 5965639.49 N 561976.95 E 1.218 2924.26 5035.59 50.990 174.550 3577.26 3678.71 2997.49 S 22.65 W 5965566.31 N 561982.94 E 2.060 2997.49 5128.93 51.280 175.510 3635.83 3737.28 3069.89 S 16.35 W 5965493.96 N 561989.83 E 0.859 3069.89 5223.54 52.000 177.320 3694.55 3796.00 3143.93 S 11.72 W 5965419.96 N 561995.08 E 1.682 3143.93 5316.56 51.530 177.920 3752.12 3853.57 3216.93 S 8.69W 5965346.99 N 561998.71 E 0.716 3216.93 5413.37 50.540 177.090 3813.00 3914.45 3292.13 S 5.41 W 5965271.82 N 562002.61 E 1.221 3292.13 5507.86 49.100 179.360 3873.96 3975.41 3364.27 S 3.16W 5965199.69 N 562005.45 E 2.386 3364.27 5602.40 48.930 180.230 3935.97 4037.42 3435.64 S 2.91 W 5965128.33 N 562006.30 E 0.718 3435.64 5696.89 48.140 179.920 3998.54 4099.99 3506.45 S 3.00W 5965057.53 N 562006.79 E 0.871 3506.45 n______--------. --------- -------.- 10 January, 2002 - 16:11 Page 3 of 5 DrlllQuest 2.00.08.005 .'.. . . 'Sperry-Sun Drilling Serviées Survey Report for 1C-131 Your Ref: API 500292304100 Job No. AKMM11162, Surveyed: 3 October, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5792.78 47.770 180.540 4062.75 4164.20 3577.65 S 3.29 W 5964986.32 N 562007.09 E 0.616 3577.65 .- \,--, 5841.56 47.440 178.840 4095.65 4197.10 3613.68 S 3.09W 5964950.30 N 562007.59 E 2.661 3613.68 5915.00 47.440 178.840 4145.32 4246.77 3667.76 S 2.00W 5964896.23 N 562009.13 E 0.000 3667.76 Projected survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (102.0' MSL). Northings and Eastings are relative to 1673' FNL & 973' FWL. Magnetic Declination at Surface is 26.115° (27-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1673' FNL & 973' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5915.00ft., The Bottom Hole Displacement is 3667.76ft., in the Direction of 180.031° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) ---. Comment 5915.00 4246.77 3667.76 S . 2.00 W Projected survey .-----.-------- --------.---- 10 January, 2002 - 16:11 Page 4 of 5 DrlllQuest 2.00.08.005 . 'Kuparuk River Unit Survey tool program for 1C-131 \...- From Measured Vertical Depth Depth - (ft) (ft) 0.00 -------------- 10 January, 2002 - 16:11 Sperry-Sun Drilling Services Survey Report for 1C-131 Your Ref: API 500292304100 Job No. AKMM11162, Surveyed: 3 October, 2001 . ~ North Slope, Alaska Kuparuk 1 C To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 5915.00 4246.77 MWD Magnetic -~- -~ Page 5 of 5 Dr/llQlIest 2.00.08.005 11/8/2001 Sc~IuJl~e'gep NO. 1608 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Kuparuk --..... Well Job # Log Description Date BL Sepia CD Color ¿).Ct-I<g5 dDD-1 ~l£; 1C-131 21466 SCMT 10/19/01 1 1D-140 (REDO) 21414 RST 09/09/01 1 "-. SIG~~ RECEIVED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-831~haQülcßas Cons. Commission A.rJchmage (' Post Office Box 100360 Anchorage, Alaska 99510-0360 P4~ October 3, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Permit # 201-185: Correction to Application for Permit to Drill, West Sak Injector lC-131 Dear Mr. Maunder: Further to our phone conversation this afternnon, this letter provides the details of the mistake that I made on the Application for Permit to Drill that was approved with Permit # 201-185. As I prepared the application I was working with both welllC-125 and this well. I inadvertently copied the lC-125 surface location into the application for 1C-131. The correct surface location for lC-131 is 1673' FNL, 973' FWL, Section 12, Tl1N, R10E, Umiat Meridian. This location is ASP Zone 4 coordinates (NAD 27): X = 561,980.83, Y=5,968,563.88. Please find attached a copy of the lC pad As Built Survey. If you have any questions or require any further information, please call me at 265-6826. Sincerely, ~ ¿:Œ:~ Drilling Engineer RECEIVED OCT 0 3 2001 Alaska Oil & Gas Cons. Commi . Anchorage SSlon . f . . . . .'~ ( (' . . . Lounsbury & Associates Transm ittal Letter TO: D. Wester/G.Rizek FROM: B. MangoldlA.J. Rookus PAl-Company Rep. (Nabors 245) Kuparuk Construction Group DS1C WELL CONDUCTORS ASBUIL T LOCATION We are sending you the following: X Herewith Preliminary Originals Under Separate Cover For Construction E-Mail transmittal For Reference X Black lines (copies) X For Your Use Specifications For Approval Data Sheets For PAl Doc Control 3.511 Floppy Disks aty. Drawina Number Sheet Rev. Description 1 CEA-D1 eX-61 03001 3 shts 1 DS1 C Well Conductors Asbuilt Location (101,102,104,106,109,111,113,115,117,119,121,123, 125, 127, 129.131.133 This Survey) , " Remarks: SRI 01-004 AFC# 999593 cc: B.Morrison/R. Overstreet-PAl Drilling(w/enclosure) Date: 07/04/01 S.MarcumN.Porto.PAI Proj. Engineer (w/enclosure) T.Bean/D.Harbison-NSK 4 (w/enclosure) S.AlIsup.Orake - ATP 1205 (w/mylar) T.Jones.Baker Hughes Inteq (fax only 267-6621) R.Piltz-Ak.Anvil, Anchorage (w.enclosure) J.Galvin/B.Allen-IFR Personnel--Sperry-Sun (fax only 273-3535) T. Gorup PAl. Geo Proj. Analyst ATD 340 S ~ McK êeve r-PAI W aI/sAT 0 1590 File: 6.00.3, 6.103 RI=(;F IVF f) OCT 0 3 ?on1 Alaska Oil & Gas Cons. CommissiorP Anchorage ~ V DA IT .. . BY CK APP r DESCRIPTION REV DA IT '1( APP DESCRIPTICII 2 1 11 + 12 Dr'own Per KØ1 Ø46ACS ... 1 7/3/01 MRT AJR T11N . LEGEND I.&J CS} .- 0:: . PLANNED LOCATIONS . EXISTING CONDUCTORS (;) AS-BUILT CONDUCTORS ~ DS-1E VICINITY MAP 1" = 1 Mile N . SCALE: 1" = 2.' SEE SHEETS 2 & 3 FOR NOTES AND LOCATION INFORMATION. LOUNSBURY & ASSOCIATES. INC. . SURVEYORS ENGINEERS PLANNERS ~ AR~: IC . rtIJ~~!Fr~LI~I!f!~~1 c!DSÿ . CADD FILE NO. DRAWING NO: LK6103O31 MODULE: XXXX DS1C WELL CONDUCTORS ASBUILT LOCATIONS SHEET. CEA-D1CX-61Ø3D31 .1 Of 3 . UNIT: 01 RE¥'. 1 .. . . ~ ," . !õlEV. DATE BY APP DESCRIPTION REV DA 1£ BY'" '< DESCRIPTION APP CK . 1 7/3/Ø1 MRT AJR NOTES 1. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-C MONUMENTS PER LHD AND ASSOCI A TES. 2. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 3. ALL ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 4. ALL DISTANCES ARE TRUE. 5. DRILL SITE 1-C GRID NORTH IS ROTATED S6'2Ø'37" WEST FROM GRID NORTH. Drown Per K01 046ACS Sec. T. 11 N., R. 1 ø E. 12, Well A.S.P.s LA TITUDE LONGI TUDE SEC. SEC. PAD D.G. L~'f L~'~E No. 'y' 'X' 0 S 0 S ELEV. ELEV. F.N.L. F. W.L. 101 5 968 821.46 561 593.72 70"19' 31.289 149'30'01.941" 1412' 588' 60.6' 56.7' 102 5968 813.50 561 606.18 70"19' 31.210" 149'30'01.579" 1420' 600' 60.6' 56.7' 104 5 968 796.65 561.631.04 70"19' 31.042" 149'30'00.857" 1 437' 625' 60.6' 56.7' 106 5 968 779.74 561 656.61 70"19'30.874" 149'30'00.115" 1454' 650' 60.7' 56.7' 109 5 968.746.59 561 706.13 70"19' 30.544" 149"29'58.678" 1487' 699' 60.7' 56.6' 111 5968 730.13 561 731.01 70"19' 30.380" 149'29'57.955" 1504' 724' 60.7' 56.5' 113 5968.713.56 561 755.87 70"19' 30.215" 149'29'57.233" 1521' 749' 60.7' 56.5' 115 5.968.696.96 561 780.86 70"19' 30.050" 149'29'56.508" 1538' 774' 60.7' 56.4' 117 5.968.680.39 561 805.95 70"19'29.885" 149'29'55.780" 1555' 799' 60.8' 56.3' 119 5,968.664.02 561,830.61 70"19'29.722" 149'29'55.064" 1 5 71' 823' 60.8' 56.2' 121 5,968,646.80 561,856.20 70"19'29.550" 149'29'54.321" 1589' 849' 60.8' 56.1' 123 5,968,630.35 561,880.54 70"19'29.387" 149'29'53.614" 1605' 873' 60.8' 55.9' 125 5,968,613.75 561,905.78 70"19'29.221" 149'29'52.882" 1622' 898' 60.8' 55.8' 127 5,968,597.14 561,930.71 70"19'29.056" 149'2~i'52.158" 1639' 923' 60.8' 55.7' 129 5,968,580.60 561,955.57 70"19'28.891" 149'29'51.436" 1656' 947' 60.8' 55.6' 70'19'28.725" " 1673' 973' 131 5.968.563.88 561.980.83 149'29'50.703" 60.8' 55.5' 133 5.968,547.28 562,005.48 70"19'28.559~' 149'29' 49.987" 1690' 997' 60.8' 55.4' ~""-... ..~c OF A/ "" .~ ~'\ ~"...........l....A, ~'. .. '\,r~ ,., ..;"1 t Ie, ..." *"... f... . ..- ... "... ..H.. .e...t..'I6 - "Y'l 49 , - ~ 'i " . . :íIIIi "- .............. ... u.. ....... i ~ ~ ~ ......... ................. ill 1I".:;g~ :fJ::III \ 'ô \ J. ROOKUS ¡ P- :;&......-- .'kJ. , ~ .e. ~LS~5 ..' ~ . f. ~ ..... "-I ,f"t'J, ..,.- ¿,-t I ". ~ð '..,J. 8i'. ,.., ("\ . "',0, " ".' Þ-~v . -,..1ro,c-rss 10 NI\\.. \, ~.. "."""'~ SURVEYOR'S CERTIFICA TE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY D/.RECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JUL Y 2, 2001. LOUNSBURY & ASSOCIATES,INC. SURVEYORS ENGINEERS PLANNERS 'qb MODULE: XXXX DS1C WELL CONDUCTORS AS8UIL T LOCATIONS CEA-D1 eX-51 Ø3D31 SHEET:2 OF 3 REV: 1 ~ AR~: IC . r~!b~!f:~L~'!~~!' c!D~Ÿ CADD FILE NO. DRAWING NO: LK61 Ø3D31 UNIT: 01 ~ . REV DATE BY CK APP I DESCRIPTION REV DATE BY 4' "'K APP DESCRIPTION ". ~ \ 1 7 /3/Ø1 MRT AJR Drown Per KØ1 Ø46ACS Sec. 12. T. 11 N.. R. 1Ø E. Well A.S.P.s LATITUDE LONGI TUDE SEC. SEC. PAD O.G. L~,r L~'~E No. 'y 'X' 0 S 0 S ELEV. ELEV. J:".N.L F. W.L. WELLS 1-8 PER CEC-1C00-331 1 5.968.523 562,372 70" 19' 28.29" 149" 29' 39.30" 1,717' 1.363' N/A N/A 2 5,968,590 562,271 70" 19' 28.96" 149" 29' 42.21" 1,649' 1,263' N/A N/A 3 5,968,656 562,172 70' 19'29.61" 149" 29' 45.10" 1,582' 1,164' N/A N/A 4 5,968,727 562,065 70" 19' 30.32" 149" 29' 48.18" 1,510' 1 ,058' N/A N/A 5 5,968,793 561,965 70" 19' 30.98" 149" 29' 51.08" 1,442' 958' N/A N/A 6 5,968,860 561,864 70" 19' 31.65" 149" 29' 54.04" 1,375' 859' N/A N/A 7 5,968,926 561,765 70' 19' 32.30" 149" 29' 56.92" 1,308' 760' N/A N/A 8 5,968,993 561,664 70" 19' 32.97" 149" 29' 59.85" 1,240' 660' N/A N/A WELLS 9 Be 10 PER CEA-1C00-90S103D2 9 5,968,851.99 561,548.05 70" 19' 31.5934" 149" 30' 03.266" 1,381' 542'. N/A N/A 10 5,968,763.33 561,680.92 70" 19' 30.7107" 149" 29' 59.410" 1,471' 674' N/A N/A WELLS 11 Be 12 PER CEA-D1CX-6103D8 .. 11 5,969,008.74 561,641.06 70" 19' 33.1 28" 149" 30' 00.514" 1,225' 6.37' 60.4' 55.0' 12 5,969,000.20 561,653.40 . 70" 19' 33.043" 149" 30' 00.156" 1,2.34' 649' 60.4' 55.1' WELLS 13 Be 14 PER CEA-D1CX-6103D15 13 5,968,842.13' 561,891.29 70" 19' 31.469" 149" 29' 53.249" 1,394' 885' 60.4' 55.0' 14 5,968,672.21 . 562,146.39 70' 19' 29.777" 149" 29' 45.844" 1,566' 1,139' 60.4' 55.0' WELLS 15 Be 16 PER CEA-D1CX-6103D20 15 5,968,605.15 562,247.15 70' 19' 29.109" 149" 29' 42.919" 1.634' 1239' 60.3' 55.0' 16 5,968.825.37 561,916.31 70" 19' 31.302" 149" 29' 52.523" 1,411' 910' 60.3" 55.0' WELL 17 PER CEA-D1CX-61 03D17 17 5,968,838.00 561,568.78 70' 19' 31.454" 149" 30' 02.665" 1,395' 563' 60.5' 56.2' WELLS 18 Be 25-27 PER CEA-D1CX-6103D22 18 5.968,758.80 562,016.22 70' 19' 30.639" 149" 29' 49.623" 1,478' 1,01 ø' 60.4' 55.0' 25 5,968,546.4 7 562,335.47 70" 19' 28.525" 149" 29' 40.355" 1,693' 1,327' 60.2' 55~0' 26 5,968,538.05 562,347.93 70" 19' 28.441" 149" 29' 39.994" 1,702' 1,339' 60.2' 55.0' 27 5,968.529.79 562,360.58 70' 19' 28.358" 149" 29' 39.626" 1,710' 1,352' 60.2' 55.0' WELL 21 PER CED-DC1X-6103D25 21 5,968,637.75 562,198.12 70" 19' 29.434" 149" 29' 44.342" 1,601' 1,191' 60.3' 55.0' WELLS 23 Be 24 PER CEA-D1CX-6103D27 23 5,968.579.61 562.285.45 70" 19' 28.855" 149" 29' 41.807" 1,660' 1,277 60.3--'- 55.2' 24 5,968,571.44 562,297.94 70" 19' 28.773" 149" 29' 41.445" 1,668' 1.290' 60.3' 55.2' ~~ LOUNSBURY' il \ & ASSOCIATES, INC~ ~'-S~EYORS ENGINEERS PLAIIlJERS AREA: 1 C MODULE: XXXX UNIT: 01 . PHILLIPS Alaska, Inc. DS1C . ' , . A Subsidiory of PHILLIPS PETROLEU~ COMPANY WELL CONDUCTORS ASBUILT LOCATIONS CADD filE NO. 6 13Ø 111 DRAWING NO: CEA-D1 eX-51 Ø3D31 SHEET: Rat: LK61Ø3D31 3OF3 1 ,/I . (' (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 October 2, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: 1 C-131 (201-185) Permit to Drill - Corrected Dear Commissioner: Phillips Alaska, Inc., as operator of the Kuparuk River Unit well, lC-131, submits the attached corrected "Permit to Drill" (AOGCC form 10-401). The surface location has been corrected. No other documents are attached in this package. . If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, q!:~õ Drilling Engineering Supervisor P AI Drilling CRM/SM/skad RECEIVED 'OCT 0:3 2001 Alaska Oil & Gas Cons. Commission Anchorage (.'.'..'..."'...'..t.~.t...'i...;;..'" . '\ :..:; "i: "\J' f\'§ : ) r' i J'. r: I"'" El ,," . \, ," .'" ~. 6. Property Designation ADL 25649 & 25650 ALK 468 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-131 #59-52-180 9. Approximate spud date Amount September 24,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and ìVD) 2560 5897' MD I 4244 ' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1462 psig At total depth (TVD) 1952 psig Settina Depth ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 0 20 MC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB = 102 feet AMSL 1 a. Type of work: Drill b!J Redrill Re-entry 0 Deepen 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1673' FNL, 973' FWL, Sec. 12, T11 N, R10E, UM At top of productive Interval 536' FSL, 947' FWL, Sec. 12, T11 N, R1OE, UM At total depth 55' FNL, 978' FWL, Sec. 13, T11N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 55 @ TD feet 1 C-133 29 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size feet Maximum hole angle 51 Top TVD 41.2' 41.2' 3700' 41.2' Hole 24" Casina 16" 5.5" Specifications Grade Coupllna H-40 Weld L-80 BTCM L-80 EUE 8rd M L-80 EUE 8rd M Length 120' 4993' 863' 4993' Bottom TVD 158' 3700' 4244' 3700' MD 41.2' 41.2' 5034' 41.2' Welaht 62.5# 15.5# 9.3# 9.3# MD 158' 5034' 5897' 5034' 7.875" 7.875" 5.5" Csg 3.5" 3.5" 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical Junk (measured) feet feet Casing Conductor Surface 0 Length Cemented Measured depth Size Perforation depth: measured Development 011 U Multiple Zone 0 10. Field and Pool Kuparuk River Field West Sak Oil Pool Quantitv of Cement (Include staae data) 225 cf AS 1 490 sx AS III L & 380 sx Class G Tapered String - cemented above (Tubing String) True Vertical depth RECE IVED OCT 0:3 2001 true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth ppt) DRefraCtion analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I. hereby cec.rtifY thzt e foregoing Is true ~'tfr1ct to the best of my kn.oWledge Questions? Call Ste~ MCKe~Ln r:16S-682E Signed A VJ~ I ./ Title: Drilling Engineering S£lpeNisor Date"""" 0 ~ . M lIa./ hi' , -f>r::!k, ,/1 Commission Use Onl, Permit Number, ;2 API num~~ rC / n, ,..,. "'" \\ Dh Approval ~ate. ~ \'1 '\ \1\\ See cover letter tcJ/-/o5 50- \V1\"'1'" (".l~UY ~ U '(\ljt\~rftO'n.\r1'y\\(J\1 ~ for other requirements Conditions of approval Samples required O./es 1~ No Mud log reqUired'.'r"'I, 0 Yes W No Hydrogen sulfide measures 0 Yes ..EJ- No Directional survey required I+! Yes 0 No + :::;~;P~=Q~~~~\ n,~~~~E\~ D 5M; D 10M:D 1$1 3000 ¡:hI i(\\\\\1X\"'~ ~O'Y i~ 'Ongmal'Signed BŸ' by order of (\ f\\ Approved by 1". n. I .. Commissioner the commission Date \J\ (J\ 0 \ Y\;lkî'\tf ~O . Dt f\ C, Submit In triplicate Form 10-401 Rev. 12/1/85. '"~\ c') , G , ~\J li~\ t ,f II, ~' ~lr~1fŒ ffi)~ ~~~~æ~ ALAS KA 0 IL AND GAS CONSERVAnONCO~SSION / I / / / TONY KNOWLES, GOVERNOR 333 W. 7"' AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279- 1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit IC-131 Phillips Alaska, Inc. Pennit No: 201-185 Sur. Loc. 1622' FNL, 898' FWL, Sec. 12, TIIN, RIOE, UM Btmhole Loc. 55' FNL, 978' FWL, Sec. 13, TIIN, RIOE, UM Dear Mr. Mallary: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Armular disposal has not been requested as part of the Pennit to Drill application for Kuparuk River Unit IC-13!. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on I C pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. " .. Sincerely, Ccu~ ~tJ.' ~ . LJ Cam~echsli T~. Chair BY ORDER OF THE COMMISSION DATED this 21st day of September, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (' Post Office Box 100360 Anchorage, Alaska 99510-0360 Chuck Mallary Phone(907)26S~ Fax: (907) 265-1535 Email: anallar@ppco.com September 17, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Injector 1C-131 Dear Commissioners: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, #lC-131, an injector well to provide pressure support for West Sak production. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005. If you have any questions or require any further information, please contact me at 265-6434 or Steve McKeever at 265-6826. ,1 Sincer y,-, ~? A ~(.,/ ;? o/j/été'j á & ~ Chuck Mallary . GKA Drilling Engineering Supervisor ,tor &4û,-~ fJ/l c111~1 RECF~v[:=r<) ~ œ ~".,"" tn",j SEP 1 7 zorn Alaska Oil & Gas Cons, Commission Anchorage ORIGINAL ( ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Re-entry 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0361 4. Location of well at surface 1622' FNL, 898' FWL, Section 12, T11 N, R10E, UM At top of productive interval 536' FSL, 947' FWL, Section 12, T11 N, RWE, UM At total depth 55' FNL, 978' FWL, Section 13, T11 N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 55 @ TD feet 1C-133 29 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size 1b. Type of well. Service ~ 0 Maximum hole angle Hole Casin 24" 16" 7.875" 5.5" 7.875" 3.5" 5.5" Csg 3.5" Perforation depth: measured API number 50- )J .-2: Conditions of appro al Samples required 0 Yes 1&:1 Hydrogen sulfide easures 0 Yes I!' No Required work' g pressure for BOPE 0 2M; 0 3M; 0 Other: \ \~ ~~"'~ ~ ~CJ. \. \ ~ \0 \ Exploratory Stratigraphic Test Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB = 102 feet AMSL 6. Property Designation ;;?.bbL/9:z.. ADL 25650 ALK 46e 7. Unit or property Name Kuparuk River Unit 8. Well number 1C-131 9. Approximate spud date September 24, 2001 14. Number of acres in property 2560 feet j!t\\'r O¡I1ÞIO' ~/~ Development Oil Multiple Zone 0 10. Field and Pool Kuparuk River Field West k Oil Pool 11. e Bond (see 20 AAC 25.0251) Statewide mber #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 5897 ' MD I 4244' TVD 20 AAC 25.035 (e)(2)) At total depth (TVD) 1952 psig 51 MD 41.2' 41.2' 5034' 41.2' / Bottom TVD 158' 3700' 4244' 3700' 19. To be completed for Redríll, Re-entry, and Deepen Operations. Present well condition summary / Total Depth: measured feet I true vertical feet ;1 Effective Depth: measured feet true vertical fe 1 ) Casing Length Size Cemented / \ ,~V Conductor / \ ~ ,ra ~urfac. / ,~\.~V~~ ~ Plugs (measured) Junk (measured) Measured depth True Vertical depth R f:-. é"""1). !F. "'."'" I;. ~\ Ii'" OC"'~'" ['.""\ , it""~ ¡¡ ~I""" ~ \ ,~"... ) ~n '"""JI' !i>_~ ~ L..., SEP 1. 7 2001 Alaska Oil & Gas Cons. Commission ,;nchora~:Je '1/ .-60 No Mud log r quire Directional survey required 5M; 0 10M;D See cover letter for other requirements 0 Yes B1 No IRI Yes 0 No T$... 'IDöO ~ \ ~\1\\t'I\~'('A. ~ ~ ~~~ 20, Attachments Filing e ~ Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program~ Drilling fluid program ~ T e vs deQ plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ~ 21. I hereby certif. .. ... t the fOr,;-g.Q..'. . is t.ru. e. .. ä. coÆrect t the best of my knowledge Questions? Call Steve McKeever 265-682.6 ., , / ~L~ ø £/1 I, Cl/Í7~V . /. . "?:! ,~ . f' /1J'~. á vVt""-'" , " SIgned /' ~. ~~ ~/u9 /"i..-'U¿ ~/It:d"4- . Title: Drilling Engineering Supervisor Date V, Chuck Mallar , Y Pre ared b Steve McKeever Commission Use Onl Approv Form 10-401 Rev. 12/1/85. Commissioner by order of the commission ORIGINAL Date Submit in triplicate ( {...."cation for Permit to Drill, We1l1C-131 Revision No.O Saved: 17-Sep-O1 Permit It - West Sak Well #1 C-131 Application for Permit to Drill Document MClximizE W~II VgIU~ Table of Contents 1. Well Name........................................................................... ......................................2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary .............................................................. .....................................2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b)........................................................................................................3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...................................................................................................3 4. Dri II i ng Hazards Information................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casi ng and Cementing Program .............................................................................4 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................... 4 7. Diverter System Information............................................ .................. .....................4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program ..... ............................................... .......... ...............................5 Requirements of 20 AAC 25.005(c)(B) ...................................................................................................5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seism ic Analysis...... ......... ....................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ..........................................................,.....................................5 11. Seabed Cond ition Analysis................ ............. ......... .......... ....... .............. ......... ....... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bond i ng........................... .............................. ........................ ....... ......... 6 Requirements of 20 AAC 25.005 (c)(12) ..........................................................,.....................................6 ORIGINAL 1C-131 PERMIT IT DOC Page 1 of 7 Printed: 17-Sep-O1 { !...,...,cation for Permit to Drill, Well 1 C-131 Revision No.O Saved: 17 -Sep-O1 13. Proposed Dri II i ng Program........ ... .................. ....... ............. ....... .......................... .... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments... ... ... ....... ................... ..... .......................... ......... ....... ..... ...................... 7 Attachment 1 Directional Plan................................................................................................................7 Attachment 2 Drilling Hazards Summary...............................................................................................7 Attachment 3 Cement Loads and CemCADE Summary. ...................................................................... 7 Attachment 4 Well Schematic. ...............................................................................................................7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name de5ignated by the operator and a unique API number as'"f:>I'gned by the commission under 20 AAC 25.040(b). For a well with multiple well branches¡ each branch must 5imilaliy be Identified by a unique name and API number by addti7g a suffix to the name designated for the well by the operator and to the number as!3igned to tlm well by the commission. The well for which this Application is submitted will be designated as 1(-131. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Drill must be accompanied by each of the following items, except for a/7 item already 0/7 file with the commission and identified in the application.' (2) a plat identifying the property and the property's owners and 5i¡owing (A)the coordinates otthe proposed location o/the well at the surface, at tile top oteach objective lolïrJation, and at tottll depth, referenced to govemmental section línes. (B) the coordinates of the proposed location olthe well at the surface, relerenced to the state plane coordinatf~ system for tl7t:'i state as maintained by the Nation~11 Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth ot the well at the top of each objective lormðtio/7 and at total depth,' Location at Surface 11622' FNL, 898' FWL Section 12, T11N, R10E, UM NGS Coordinates RKB Elevation 102.0' AMSL Northings: 5,968,613.75 Eastings: 561,905.78 Pad Elevation 60.8' AMSL Location at Top of Productive Interval West Sak "D" Sand NGS Coordinates Northings: 5,965,493 536' FSL, 947' FWL, Section 12, T11N, R10E, UM Eastings: 561,983 5134 3763 3661 Location at Total De th 55' FNL NGS Coordinates Northings: 5,964,902 Eastings: 562,019 UM 5897 4244 4142 and ORIGINAL 1C-131 PERMIT IT DOC Page 2 of 7 Printed: 17-Sep-O1 ( I" !t-r-olcation for Permit to Drill, Well 1 C-131 Revision No.O Saved: 17-Sep-O1 (D) other 1Ì1formation required by 20 AAC 25.050(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale/ showing t!7e path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any portion of the proposed wel¿' Please see Attachment 1: Directional Plan and Anti-Collision Report and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable 1i1 public record~ and sl7ow tl¡at each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pennit to Dnll must be accompanied by each of the following Item5~ except for an item already on file with the commission and identified in the application: (3) a diagram and description olthe blowout prevention equipment (80PE) as required by 20 AAC 25.03~ 20 AAC 2S.03ti or 20 AAC 25.03~ as applicable/ Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill mast be accompanied by each of the (ollowing itemS;, except {or an item already on ¡¡Ie with the commL';'5ion and Identified in the application: (4) irllormation on dnlling tJðZard5~ including (A) the maximum downhole pressure that may be encountered, CTiteria used to determine it and maximum potential !:;u!fåœ pre.~-ure based 017 a methane gradient: The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-0l well. The maximum potential surface pressue (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1462 psi, calculated thusly: MPSP =(4178 ft)(0.46 - 0.11 psi/ft) =1462 psi (8) data on potential gas zones;"; The well bore is not expected to penetrate any gas zones. and (C) data conceming potential c:ë7uses of hole problems such as atmol7Tlally geo-pressured slrata/ lost circulation ?OfJe~ and zones that have a propensity for differential sticking; Please see Attachment 2: lC-131 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application lor a Permit to Olilf mu!;,£ be accompanied by each of the following item.'i¡ except for an item already on file with the commission and identlfìed in the application: (5) a description of the procedufe (Of conducting formation integrity tests, as required lindeI' 20 MC 2S:030(f)/ ORIGINAL 1C-131 PERMIT IT. DOC Page 3 of 7 Printed: 17-Sep-O1 ( At_..vation for Permit to Drill, We1l1C-131 Revision No.O Saved: 17 -Sep-O1 As the well will be completed with a single casing string that will not be drilled out, no formation integrity tests are planned. In the unlikely event that it does become necessary to drill out a casing string with blowout prevention equipment installed, a formation integrity test will be performed in accordance with the LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item already on file with the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- pelforated liner, or screen to be installed; Casing and Cementing Program Hole Top atm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (tt) (ft) Cement Program 16 24 62.5 H-40 Welded 117 41/41 158 / 158 Cemented to surface with 225 cf ArcticSet 1 5-1/2 7-7/8 15.5 L-80 BTC,AB 4993 41/41 5034 / 3700 Cemented to Modified Surface with 3-1/2 7-7/8 9.3 L-80 EUE 8rd, 863 5034/3700 5897 / 4244 490 sx ASLite AB Lead, 380 sx Mod ified Class G Tail See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill mast be accompanied by each of the fallowing item!;.~ except far an item already on file wIth the commi~:;ion and Identifìed in the application: (7) a diagram and description of'the divertl,?r system as reqwì-ed by 20 AAC 25. 035, unless this requirement is waived by the commiS!:,70n under 20AAC 25,O3.'i(h}{2); Please see "Diagram And Description of the Diverter System For Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001. ORIGINAL 1C-131 PERMIT IT. DOC Page 4 of 7 Printed: 17-Sep-O1 ~ AC....;ation for Permit to Drill, Well 1 C-131 Revision No.O Saved: 17-Sep-O1 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of tl7e following items, except for an item already 017 file with the commission and Identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25:033; Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Spud to Base of Permafrost Base of Permafros to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 9.2-9.4 9.2-9.4* 9.2-9.4* Funnel Viscosity 150-200 150-200 150 75 (seconds) Yield Point 30-60 30-60 20-40 18-30 (cP) Plastic Viscostiy 8-15 11- 22 15-30 15-30 (lb1100 sf) 10 second Gel 10-30 10-25 10-25 10-25 Strenqth (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 20-40 Strenqth (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for weIl1C-133, dated April 26th, 2001. This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at 600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-VT- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An r1pplication for a PermIt to Olill must be accompanied by eacl7 of the following Items, except fÓr an item already 017 fïk: with the commission and identifted in the application: (9) for an exploratory or stratigrap!7ic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressllred strata as required by 20 MC 25:03J(f}; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to 01711 must be accompanied by each of the following Items; except for an item already on fï/e with the commission and identlfìed In the application: (10) for an exploratory Or stratigraphic test well a seismic refraction or reflection ana/ysi'i as required by 20 MC 25.061 (a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fÓr a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and Identified in the application: ORIGINAL 1C-131 PERMIT IT ODe Page 5 of 7 Printed: 17-Sep-O1 ( At"",~ation for Permit to Drill, We1l1C.131 Revision No.O Saved: 17-Sep-O1 (11) for a well dr;/Ied from an offshore platform/ mobile bottom-founded structure/ jack-up rig/ or floating dr;II¡{7g vesse~ an analysis of seabed conditions as required by 20 MC 25. 061 (b),' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill mu5t be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}/7ave been met,' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter and function test same. 3. Spud and directionally drill 7-7/8" hole to desired targets through West Sak interval. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. 5. Run and cement 5-1/2" 15.5# L-80 BTCM x 3-1/2" 9.3# L-80 EUE 8rd tapered casing string to surface. Displace cement with seawater 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 to 5,000 psi. 7. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to clean seawater. 8. Sting into seal bore extension and space out. 9. Unsting seal assembly, and freeze protect well with diesel. 10. Sting back into seal bore extension and land tubing. 11. Using diesel, pressure test casing x tubing annulus to 3,000 psi for 10 minutes. 12. Install back pressure valve. 13. Nipple down BOP stack. Install production tree and pressure test same. 14. Secure well and release Nabors Rig 245e. Post Rig Work: 1. Pull Back Pressure valve. 2. Rig up and pressure test tubing and tubing annulus to 3,000 psi for 30 minutes, recording test on chart. 3. Rig up wireline and make a dummy run to PBTD. 4. Rig up and run SCMT Bond log at 1000 psi tubing pressure. 5. Rig up and perforate well for injection. ORIGINAL 1C-131 PERMIT IT.ODC Page 6 of 7 Printed: 17-Sep-O1 ( -", !¡.....o,cation for Permit to Drill, We1l1C-131 Revision No.O Saved: 17-Sep-O1 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Dr/II mustc be accompanied by each of the following ItemSr except for an Item already on file with the commission and identified Ii] the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan and Anti-Collision Report(10 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (1 page) Attachment 4 Well Schematic. (1 page) ORIGINAL 1C-131 PERMIT ITDOC Page 7 of 7 Printed: 17-Sep-O1 Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 -131 (wpO1) 800 1600 ..c. - c... 0) Om -~ ~a: t- O) > 2400 4000 0 SHL: X '" 5C"FÆC'.H3' 1:. & y '" 59Sf;5C~3.BB' N (H}7:r¡::NL~"D7;¡'¡::'¡VL. :')ÜG1?.T~1N..¡:~,DE) Begin Dir @ 3.0c/100ft (in 7-7/8" Hole): 300.00ft MD, 300.00ft TVD fFfJ .ffJ Increase in Dir Rate @ 4.0o/100ft : 800.00ft MD, 794.31ft TVD ____.._n_o_n..~ n.~ Eastings -600 Scale: 1 inch = 600ft 600 Un "_~"nn"""",,'on"" Uno' . SHL: X ~ 5(":;'<'<',;::<' E ß .¡..~ ':,:"",';(';5.:";' 'i :f:f;?'.YFNL.5C;7'3'FVJL. S,.;,~ '?-r:¡N.;c',,~¡c, 0 Begin Oir @ 3.0c/1001t (in 7-7/8' Hole) : 3oo.ooft MO, 3oo.OOIt TVO 0 Increase in Dir Rate @ 4.0"/10011 : 8oo.OOIt MO, 794.3111 TVO End Dir, Start Sail @ 50.88' : 1913.49ftMD,1731.02ftTVD Reference is TRUE North Well: Current Well Properties 1C-131 i Horizontal Coordinates: I Ref. Global Coordinates : ,. Ref. Stucture Referance : Ref. Geographical Coordinates : I RKB Elevation: ¡ I North Reference: I Units: End Dir, Start Sail @ 50.88c: 1913.49ft MD, 1731.02ft TVD 5968563.88 N, 561980.83 E 44.65 N, 390.86 W 70° 19' 28.7247" N, 149029' 50.7030' W (1673' FNL & 973' FWL, Sec 12-T11N-R10E) 102.000 above Mean Sea Level True North Feet (US) 7- QT aT {~ I?~ n "" <o,<:fJO'çp /// 5-1/2")(3-1/2" Casing X-O X. // (100' MD above West SakD): ~, // S034.00ft MD, 3699.977ft TVD ".:..~/ çp ~O. '" 5-1/2" x3.1!2' Casirg ~ 5897.0011 MD 4244.5Oft TVD 0 800 1600 2400 OriliQuest 2.00.09.003 Scale: 1 inch = 800ft n ;J&iIrIr'Y-SUJ1 PB'~l..Iì\fG Se¡RVJE:;e;¡S A HiIW!Üft-ðØ: c.-Mtplf!-ÿ ....-........-.....-...........................................-.....--.................................................. TAF'¡GET (75' Radius Circle 'ç;; A:3 Top) : 5365.28ft MD. 3909.00ft TVD 3249.88' S & 13..67' iN of SHL 357' FSL& 957' FWL, See 12.. T11N.. P10E) Total Depth (250' Below A1): 5897.00ft MD, 4244.5011 TVD (55' FNL & 978' FWL, Sec 13 - T11N.. R1OE) 3200 4000 B.' 1"&"1';. 1Ff., ¡ý"';,'.. ."~.."" ...".'.;~.' ".:t..~ In ."'..,p "7"" (1 ø¡f \ ';&<'k,,& KJ,^iJfJ/JW' Ìi "'1$11.11'4../1 ¡; >; "_ft",, v," 4"Ú"...... ,"""'-.;,~?_"'II,, . " . ",7 '\!J F ! J '" '. -600 1 BOO.OO 2100.00 -1200 2400.00 (J) 0) c: .L:: t 0 Z 2700.00 -1800 Q -" (¡.) -" 3000.00 ~ '0 0 -" ~ -2400 3300.00 ~', 3600.00 5.112"><3-1/2" Casing x.a (100' MD above West Sak D): 5034.0011 MD. 3699.97711 TVD -3000 /t., -""'" '. 3gpO.OO \.. ../ ~200_00 5-1/2" x 3.1/2" Casing sa97.001t MD 4244,5011 TVD -3600 C ::0 - - c-> - - :æ: ~ r-- Kuparuk River Unit North Slope, Ai- Kuparuk 1 C, Slot 1 a~J31 -" " . ReKlseiJ:16.Sêþtelil,ber, 2001 OSAL REPORT 16 September, 2001 Your Ref:... per 'MaxBook' (9-13-01) Surface Coordinates: 5968563.88 N, 561980.83 E (700 19' 28.7247" N, 149029' 50.7030" W) Surface Coordinates relative to Project H Reference: 968563.88 N, 61980.83 E (Grid) Surface Coordinates relative to Stucture Referance: 44.65 N, 390.86 W (True) Kelly Bushing: 102.00ft above Mean Sea Level -~, ~ It ita iíturttl1 e:U1i1~ y Proposal Ref: pr09624 <::) :::t:J - - t;:) - ~ r--- Kuparuk River Unit Measured Depth (ft) 100.00 120.00 200.00 - 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 1913.49 2000.00 2032.32 2100.00 Incl. 0.00 0.000 Azim. 0.000 0.000 0.000 0.000 0.000 236.000 236.000 236.000 236.000 236.000 16.694 222.684 19.071 .212~1.71 21.91 () '. 204:097 25.054.197.876 ~ . .. 28.402192.999 Sub-Sea Depth (ft) -102.00 -2.00 18.00 98.00 198.00 297.95 397.63 496.77 595.0 692.3 1244.91 1328.12 1407.65 1483.13 1554.18 1620.47 1629.02 1683.61 1704.00 1746.71 Vertical Depth (ft) 100.00 120.00 200.00 300.00 399.95 499.63 598.77 ~7.08 4.31 890.54 985.72 1079.41 1171.13 1260.44 1346.91 1430.12 1509.65 1585.13 1656.18 1722.47 1731.02 1785.61 1806.00 1848.71 0.00 Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref:... per 'MaxBook' (9-13-01) Revised: 16 September, 2001 Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E Global Coordinates Northings I;~$tings (ft) . (fl:) 5968!?63.88N 5968563.88 N 5968563;88 N 5968563.88 N 5968562.40 N 5968557.96 N 5968550.57 N 5968540.26 N 5968527.05 N 5968509.07 N 5968484.53 N 5968453.52 N 5968416.21 N 5968372.77 N 5968323.41 N 5968268.39 N 5968207.96 N 5968142.41 N 5968072.08 N 5967997.30 N 5967986.89 N 5967919.90 N 5967894.88 N 5967842.47 N 561980.83 E 561980.83 E 561980.83 E 561980.83 E 561980.83 E 561978.67 E 561972.20 E 561961.45 E 561946.42 E 561927.18 E 561906.85 E 561888.61 E 561872.55 E 561858.73 E 561847.24 E 561838.12 E 561831.42 E 561827.17 E 561825.39 E 561826.10 E 561829.29 E 561829.91 E 561834.02 E 561835.56 E 561838.77 E Dogleg Rate C/100ft) 0.000 0.000 0.000 0.000 3.000 3.000 3.000 3.000 3.000 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 Vertical Section 1.46 5.85 13.15 23.34 36.39 54.19 78.59 109.46 146.66 190.00 239.28 294.25 354.64 420.17 490.50 565.31 575.72 642.75 667.78 720.22 North Slope, Alaska Kuparuk 1 C Comment 0.00 SHL: X = 561980.83' E & Y = 5968563.88' N (1673' FNL & 973' FV Sec 12-T11N-R10E) -" 0.000 0.000 0.000 0.000 3.000 6.000 9.000 12.000 15.000 31.890 35.475 39.131 42.840 46.588 50.367 50.878 50.878 50.878 50.878 189.091 185.890 183.210 180.923 178.936 177.182 176.960 176.960 176.960 176.960 0.00 N O.OON 0.00 N 0.00 N 2.17W 8.67W 19.49 W 34.60 W 53.95 W 54.19 S 78.59 S 109.46 S 146.66 S 190.00 S 74.43 W 92.87 W 109.19 W 123.31 W 135.17W 0.00 0.00 0.00 0.00 13-3/8" Casing Begin Dir @ 3.0°/1 OOft (in 7-7/8" Hal 300.00ft MD, 300.00ft TVD 239.28 S 294.25 S 354.64 S 420.17S 490.50 S 144.70 W 151.85 W 156.60 W 158.91 W 158.78 W Increase in Dir Rate @ 4.0o/1O0ft : 800.00ft MD, 794.31ft TVD .~~. End Dir, Start Sail @ 50.88° : 1913.4 MD, 1731.02ft TVD Base Permafrost 16 September, 2001 - 17:25 565.31 S 575.72 S 156.22 W 155.68 W 642.75 S 667.78 S 720.22 S 152.12 W 150.79 W 148.01 W Page 2 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Measured Depth (ft) 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2789.88 2800.00 2900.00 C 3000.00 ::t:J 3100.00 - - 3200.00 ~ 3300.00 - 3400.00 ;æ: 3500.00 :t::=...: r--- 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4228.93 4300.00 4400.00 4500.00 4600.00 4669.52 4700.00 4745.60 Incl. 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878. 50.878..... 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 50.878 Azim. 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.9~q .....176.96Q .176.960 .1.76:960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 176.960 Sub-Sea Depth (ft) 1809.80 1872.90 1936.00 1999.09 2062.19 2125.29 2182.00 2188.39 2251.48 2314.58 6 756.26 2819.36 2882.45 2945.55 3008.65 3071.74 3090.00 3134.84 3197.94 3261.04 3324.13 3368.00 3387.23 3416.00 Vertical Depth (ft) 1911.80 1974.90 2038.00 2101.09 2164.19 2227.29 2284.00 2290.39 2353.48 2416.58 2795.16 2858.26 2921.36 2984.45 3047.55 3110.65 3173.74 3192.00 3236.84 3299.94 3363.04 3426.13 3470.00 3489.23 3518.00 Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref:... per 'MaxBook' (9-13-01) Revised: 16 September, 2001 Local Coordinates Northings Eastings (ft) (ft) 797.69 S 875.16 S 952.63 S 1030.10 S 1107.57 S S 1572.40 S 1649.88 S 1727.35 S 1804.82 S 1882.29 S 1959.76 S 2037.23 S 2114.70 S 2192.18 S 2269.65 S 2347.12 S 2369.53 S 2424.59 S 2502.06 S 2579.53 S 2657.01 S 2710.87 S 2734.48 S 2769.80 S 143.90 W 139.78 W 135.67 W 131.55 W 127';44 W .32W 63W .21 W 15.10 W 0.98W 106.87 W 102.75 W 98.64 W 94.53 W 90.41 W 86.30 W 82.18 W 78.07 W 73.96 W 69.84 W 65.73 W 61.61 W 60.42 W 57.50 W 53.39 W 49.27 W 45.16 W 42.30 W 41.04W 39.17W Global Coordinates Northings Eastings (ft) (ft) . 5967377.86 N 5967308.26 N 5967300.42 N 5967222.99 N 5967145.55 N 5967068.12 N 5966990.68 N 5966913.25 N 5966835.81 N 5966758.38 N 5966680.94 N 5966603.51 N 5966526.07 N 5966448.64 N 5966371.20 N 5966293.77 N 5966216.33 N 5966193.93 N 5966138.90 N 5966061.46 N 5965984.03 N 5965906.59 N 5965852.76 N 5965829.16 N 5965793.85 N 561843.53 E 561848.28 E 561853.04 E 561857.79 E 561862.54 E 561867.30 E 561871.57 E 561872.05 E 561876.81 E 561881.56 E 561886.31 E 561891.07 E 561895.82 E 561900.57 E 561905.33 E 561910.08 E 561914.84 E 561919.59 E 561924.34 E 561929.10E 561933.85 E 561938.60 E 561939.98 E 561943.36 E 561948.11 E 561952.87 E 561957.62 E 561960.93 E 561962.37 E 561964.54 E Dogleg Rate (0/100ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 797.69 875.16 952.63 1 030.1 0 1107.57 1185.05 1254.68 1262.52 1339.99 1417.46 1494.93 1572.40 1649.88 1727.35 1804.82 1882.29 1959.76 2037.23 2114.70 2192.18 2269.65 2347.12 2369.53 2424.59 2502.06 2579.53 2657.01 2710.87 2734.48 2769.80 North Slope, Alaska Kuparuk 1 C Comment Top K-15 Top Ugnu C Top Ugnu B Top Ugnu A -. --. 16 September, 2001 - 17:25 Page 3 of 7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref:... per 'MaxBook' (9-13-01) Revised: 16 September, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates, Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings I;a$tings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/1 OOft) 4800.00 50.878 176.960 3450.33 3552.33 2811 .95 S 36.93 W 5965751.72N 561967.13 E 0.000 2811.95 4900.00 50.878 176.960 3513.42 3615.42 2889.42 S 32.81 W 59þ56'Z~;29N, ' 561971.88 E 0.000 2889.42 4956.38 50.878 176.960 3549.00 3651.00 2933.10 S 30.50 W 596,563Œ63N 561974.56 E 0.000 2933.10 K-13 Shale ~~ 5000.00 50.878 176.960 3576.52 3678.52 2966.89 S 28.70 'M. 59ô5t)96.85N 561976.64 E 0.000 2966.89 5034.00 50.878 176.960 3597.97 3699.97 2993.23 S 27;30 W', 5965570.52 N 561978.25 E 0.000 2993.23 5-1/2"x3-1/2" Casing X-O (100' I. above West Sak D): 5034.00ft MD, 3699.977ft TVD 5100.00 50.878 176.960 3639.62 3741.62 5965519.42 N 561981.39 E 0.000 3044.36 5133.89 50.878 176.960 3661.00 3763.00 5965493.18 N 561983.00 E 0.000 3070.62 Top West Sak D <:::) 5190.94 50.878 176.960 3697.00 3799.00 5965449.00 N 561985.71 E 0.000 3114.82 C 5200.00 50.878 176.960 3702.71 3804.71 5965441.98 N 561986.14 E 0.000 3121.83 ::0 5235.32 50.878 176.960 3725.00' ,. 3827.00 5965414.63 N 561987.82 E 0.000 3149.20 B - - c-) 5289.20 50.878 176.960 3a~.1;:OO 3190.94 S 16.80 W 5965372.91 N 561990.38 E 0.000 3190.94 A4 - 5300.00 50.878 176.960 ,..,,'386r;'8î 3199.31 S 16.36 W 5965364.55 N 561990.90 E 0.000 3199.31 - 5365.28 50.878 176.960 8909.00 3249.88 S 13.67 W 5965314.00 N 561994.00 E 0.000 3249.88 TARGET (75' Radius Circle @ A3 Tc ~ : 5365.28ft MD, 3909.00ft TVD A3 Target r-- A3 Target, 75.00 Radius., Current Target 5400.00 50.878 1]6.960 3828.91 3930.91 3276.78 S 12.24 W 5965287.11 N 561995.65 E 0.000 3276.78 5476.22 50.878 176.960 3877.00 3979.00 3335.83 S 9.11 W 5965228.09 N 561999.27 E 0.000 3335.83 A2 ~. 5500.00 50.878 176.960 3892.01 3994.01 3354.25 S 8.13W 5965209.68 N 562000.40 E 0.000 3354.25 5600.00 50.878 176.960 3955.10 4057.10 3431.72 S 4.02W 5965132.24 N 562005.16 E 0.000 3431.72 5647.38 50.878 176.960 3985.00 4087.00 3468.43 S 2.07W 5965095.55 N 562007.41 E 0.000 3468.43 A1 5700.00 50.878 176.960 4018.20 4120.20 3509.19 S 0.10 E 5965054.81 N 562009.91 E 0.000 3509.19 5791.61 50.878 176.960 4076.00 4178.00 3580.16 S 3.87 E 5964983.87 N 562014.27 E 0.000 3580.16 Base West Sak 5800.00 50.878 176.960 4081 .30 4183.30 3586.66 S 4.21 E 5964977.37 N 562014.67 E 0.000 3586.66 .- 5897.00 50.878 176.960 4142.50 4244.50 3661.81 S 8.20 E 5964902.26 N 562019.28 E 0.000 3661.81 Total Depth (250' Below A 1): 5897.0C MD, 4244.50ft TVD 5-1/2" x 3-1/2" Casing 16 September, 2001 - 17:25 Page 4 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref:... per 'MaxBook' (9-13-01) Revised: 16 September, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (102.0' MSL). Northings and Eastings are relative to 1673' FNL & 973' FWL. Magnetic Declination at Surface is 26.135° (05-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from SHL to Target and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5897.00ft., The Bottom Hole Displacement is 3661.82ft., in the Direction of 179.872° (True). ~ c5 ;:: ~ r-- Comments Measured Depth (ft) 0.00 300.00 800.00 1913.49 5034.00 5365.28 5897.00 Station Coordi TVD Northings (ft) (ft) 0.00 300.00 794:31. .... 1731.02 3699.97 3909:99... 4244.50 0.00 E 0.00 E 53.95 W 155.68 W 27.30 W SHL: X = 561980.83' E & Y = 5968563.88' N (1673' FNL & 973' FWL, Sec 12-T11 N-R1 OE) Begin Dir @ 3.00/1O0ft (in 7-7/8" Hole) : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 4.00/100ft : 800.00ft MD, 794.31ft TVD End Dir, Start Sail @ 50.88° : 1913.49ft MD, 1731.02ft TVD 5-1/2"xa-1/2" Casing X-O (100' MD above West Sak D): 5034.00ft MD, 3699.977ft TVD . North Slope, Alaska Kuparuk 1 C _. - 16 September, 2001 - 17:25 3249.88 S 3661.81 S 13.67 W 8.20 E TARGET (75' Radius Circle @ A3 Top) : 5365.28ft MD, 3909.00ft TVD Total Depth (250' Below A1): 5897.00ft MD, 4244.50ft TVD Page 5 of 7 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref: on per 'MaxBook' (9-13-01) Revised: 16 September, 2001 . Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Measured Vertical Depth Depth (ft) (ft) Penetration Point Sub-Sea Depth Northings (ft) (ft) 1704.00 0.000 0.473 2032.32 1806.00 1704.00 2182.00 0.000 0.473 2789.88 2284.00 2182.00 3090.00 0.000 0.473 4228.93 3192.00 3090.00 3368.00 0.000 0.473 4669.52 3470.00 3368.00 3416.00 0.000 0.473 4745.60 3518.00 .34:16.00 3549.00 0.000 0.473 .... 3549.00 S C 3661.00 0.000 0.473 ...3661.0tr 3070.62 S 3697.00 0.000 0.473 . .Bo@9£;OO 3114.82 S :::0 3725.00 0.000 0.473 3725.00 3149.20 S 3759.00 0.000 0.473 3759.00 3190.94 S - - ~ 3807.00 G909.00 3807.00 3249.88 S - - 3877.00 3979.00 3877.00 3335.83 S :æ: 3985.00 4087.00 3985.00 3468.43 S ~ 4076.00 4178.00 4076.00 3580.16 S r-- North Slope, Alaska Kuparuk 1 C --. 150.79W Base Permafrost 119.63 W TopK-15 60.42 W Top Ugnu C 42.30 W Top Ugnu B 39.17 W Top Ugnu A 30.50 W K-13 Shale 23.19 W Top West Sak D 20.85 W C 19.02 W B 16.80 W A4 13.67 W A3 Target 9.11 W A2 2.07W A1 3.87 E Base West Sak .-...." 16 September, 2001 - 17:25 Page 6 of 7 DrillQuest 2.00.09.003 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 120.00 5897.00 120.00 4244.50 Targets associated with this wellpath c ::a - - c;-:) - - ~ r-- Target Name A3 Target Sperry-Sun Drilling Services Proposal Report for 1C-131 Your Ref:... per 'MaxBook' (9-13-01) Revised: 16 September, 2001 Casing Detail 13-3/8" Casing 5-112" x 3-1/2" Casing Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Radius: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3909.00 3807.00 3249.88 S 13.67 W 5965314.00 N 561994.00 E 70018' 56.7594" N 149029' 51.1019" W North Slope, Alaska Kuparuk 1 C Target Shape Target Type ,- Circle Current Target ~'~" 16 September, 2001 - 17:25 Page 7 of 7 75.00ft DrillQuest 2.00.09.003 ( Sperry-Sun Anticollision Report ( Company: Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 C Pad 1C-131 1C-131 Date: 9/16/2001 Time: 17:18:24 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 1C-131, True North SITE 102.00 102.0 GLOBAL SCAN APPLIED: All wellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 41.20 to 5898.00 ft Maximum Radius: 785.68 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/14/2001 VaJidated: No Planned From To Survey ft ft 41.20 900.00 900.00 5898.00 Version: Toolcode Tool Name Planned: 1C-131 WP01 V1 Planned: 1C-131 WP01 V1 CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard Casing Points MD TVD Diameter Hole Size ft ft in in 120.00 120.00 16.000 16.000 5898.00 4245.04 5.500 6.000 Summary Name 16.00 51/2" <---------------------- Offset Wellpatb ----------------------> Reference Offset Ctr-Ctr No.Crt) Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 C Pad 1 C-03 1C-03 VO 1658.14 1850.00 425.77 43.15 395.56 Pass: Major Risk Kuparuk 1 C Pad 1 C-117 1C-117 V1 811.27 800.00 203.16 14.28 188.92 Pass: Major Risk Kuparuk 1 C Pad 1C-121 1C-121 V1 814.53 800.00 172.18 15.57 156.73 Pass: Major Risk Kuparuk 1 C Pad 1C-123 1 C-123 V5 856.06 850.00 114.04 16.71 97.39 Pass: Major Risk Kuparuk 1 C Pad 1 C-127 1C-127 V5 953.05 950.00 51.14 20.09 31.80 Pass: Major Risk Kuparuk 1 C Pad 1 C-133 1C-133V6 399.21 400.00 28.77 6.83 21.97 Pass: Major Risk --'-"---------------------------"------------'--'-'------.-------..--.--.---.------.--- ----..-----------..--- WELL Dff AILS A.VI1-COLLISION SElTINGS cmlP.",,"Y DìoTAItS WIlil'Arn OErAlt8 Sl1HVEY I'HOGH,I.\1 Name +Nt-S +EJ-W Northing Ea.<tin, ulit"le Longitude Shl ~,."""-'loc. IC.nI Ixplh I'm IXl'lh To Su".")'II'L", ",.,1 Interpolation Method:MD Interval: 50.00 &pwà" K~ 1% IC-131 44.67 -390.90 596&563.S8 561980.83 7(Fl9.1s.715N 149'l'T50.703W NiA Depth Range From: 41.20 To: 5898.00 Rd: Ihturn Srl1' 102.00 102.000 41.~U '~~J.OO I'L"u"" I: IC.1.11 WI'OI VI CB.GYlW.SS Maximum Range: 785.68 Reference: Plan: !C-B! WPOI Cilillib-..M.-<fcl Mr,rn.mf.:m."", ')(XJ.f)() 5K'J7.OU I'I..Hlk.J: IC.1.I1 WPUI VI MWi> fu.xS¡-""m IseWSA 1'5-"...... 0,-",. 0"". ~"""" S=~k<lDŒ T",C!ÐJ.~"- .....~ .,,/-s ,E;-W hem"lYD fucAS",-",""", ~+C..,r" 179.>7" w."..,,~kIh>d, RuI.-.R=! D."" 0.00 0.00 0 0 0 40 30 20 30 40 -0 '0 Pbn: \C-ß\ wpm {\C-I3l!lC-\3\) ',.-",,00 By, Do,." EgOOahl :~.eckOO: :e"","": ------- ,ppm,,:.!, Dole: 9/1612001 Dote, [Me: f)-ale, 0 27 DID +Nf-S Colour To \o1D 200 500 1000 1500 2000 3000 4000 5000 6000 7000 SOOO 9000 10000 11000 12000 13000 14000 15000 16000 ~-~ ñ :- ~ From () 200 500 1000 1500 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 § 15000 rJ :::: 90 LEGEND I C-03 ( 1 C-03). Major Risk 1C-117 (IC-117), M¡~or Risk IC-121 (IC-I:!!), Major Risk IC-12.l (IC-123), Major Risk IC-127 (lC-127). Major Risk 1 C-13 3 ( 1 C- ¡ 33). M¡ijor Risk IC-DI 1('-131 WPOI ~- SECTION DETAIL~ +E/-W Dl..cg 11';I<:c Vs.:. T"rgcl See MD Ai.i III<: 180 I 2 41.20 300.00 gOO.OO ] 913.54 5365.51 5K97.00 0.00 0.00 41.20 (U~I (1.00 IU~) O.lHI O.ŒI (>.00 0.00 300.00 (>.00 O.lX) O.lX) (UX) (UX) 15.00 236.00 7'14.31 -3(,.39 -53'15 3.00 B('.O\! 3(,.27 50.88 176.96 17-'1.05 .575.77 -155.71 4.00 -nS] 575A2 50.K8 176.% .W09.0(J -3250.19 -1.1.84 O.(HI (UH) .nso.ls 50.88 176.96 4244.3:1 -)(.61.% 8.1X) (!.OO (UXI .1(061.97 Draft Plan (wpOl) IC-131 (A3) 4 5 6 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [30ft/in] ( ( lC-131 Drilling Hazards Summary (SEE WELL PLAN AND ATTACHEMENT FOR DETAILED DISCUSSION OF THESE RISKS) 7-7/_8" Open ~ 5-1/2" x 3-1/2" Casi.nQ..!rnerval Hazard Broach of Conductor Risk Level Low Gas Hydrates Low Running Sands and Gravels Moderate Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate Miti ation Strate Monitor cellar continuously during interval, reduced flow rates until BHA is bleow conductor. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of d ri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s run ravel isolation strin . Diverter drills, increased mud weight. Reduced um rates, mud rheolo ,LCM Trip speeds, Proper hole filling, pumping out This Summary to be Posted in the Rig Doghouse, in accordance with instructions of the AOGCC. ORIGINAL I. ..... 1C-131 Drilling Hazards Summary prepared by Steve McKeever 9/16/01 S ch 10mb e rg er Cen ICADE Preliminary Job Design 5 1/2" X 3 1/2" Longstring I Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nabors 245E Location: West Sak Client: Phillips Alaska, Inc. Revision Date: 9/17/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. Top of tail slurry is designed to be 500' above the crossover. Lead Slurry (minimum pump time 200 min.) ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 0.3% D65, 1.5%D79 - 4.44 feJsk 50 bbls x 5.6146 ft3Jbbi (cement to surface) = 1.1034 felft x (120') x 1.00 (no excess) = 0.1733 felft x (2032' - 120') x 3.50 (250% excess) = 0.1733 felft x (4534' - 2032') x 1.35 (35% excess) = 280.7 fe + 132.4 fe + 1159.7 fe+ 585.4 ft3 = 2158.2 fe J 4.44 fe Jsk = Round up to 490 sks 280.7 fe 132.4 fe 1159.7ft3 585.4 ft3 2158.2 ft3 486.1 sks A"evious Csg. < 16",62.6# casing at 120' MD < Base of Permafrost at 2,032' MD (1 ,806' TVD) < 5112",15.5# casing in 7 7/8" OH Top of Tail < at 4,534' MD < X-over at 5,034' MD < Top of A3fTarget at 5,365' MD < 3112",9.3# casing in 7 7/8" OH TO at 5,897' MD (4,244'lVD) " Mark of Schlumberger Have 160 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 130 min.) Class G + 2.0 gps D600G, 0.2 gps D47, 0.3% M117, 0.45% D65 -1.16 ft3Jsk 0.1733 ft3Jft x (5034' - 4534') x 1.35 (35% excess) = 0.2714 ft3Jft x (5897' - 5034') x 1.35 (35% excess) = 0.0488 ft31ft x 90' (Shoe Joint) = 117.0 ft3 + 316.2 ft3 + 4.4 ft3 = 437.6 ft3J 1.16 ft3Jsk = Round up to 380 sks 117.0 ft3 316.2 ft3 4.4 ft3 437.6 ft3 377.2 sks BHST = 91°F (BHST calculated using a gradient of 2.4 °FJ1 00 ft. below the permafrost) BHCT = 80°F PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW1 00 6 60 10.0 10.0 Drop Bottom Plug 3.0 13.0 MudPUSH XL 6 50 8.3 21.3 Lead Slurry 6 387 64.5 85.8 Tail Slurry 6 79 13.2 99.0 Drop Top Plug 3.0 102.0 Displacement 6 107 17.8 119.8 Bump Plug 3 20 6.7 126.5 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv ~ 15-20, Ty ~ 15-20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-20, T y ~ 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Well # 1C, .;1, AFE # 0155 West Sak Monobore Injector Planned Completion Schematic, Sheet 1 of 1 PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Christmas Tree: (475-0605) Vetco-Gray, API 5K 7-11 16" Flange Bottom x API 5K 3-1/8" Valves, with Otis 5-3/4" 5K Tree Top Tubing Head: (475-0515) Vetco-Gray, 10- 3/4" Gray Quick Connect Bottom x API 5K 7-1/16" Flange Top Tubing Hanger: (475-0525) 3-1/2" Vetco-Gray wI 3-1/2" pup (EUE 8rd, AB Mod pin) down x 3.725" MCA box up Casing Hanger: (492-1810) 5-1/2" Vetco-Gray wi 5-11 2" pup (BTCM pin) down x 7.790" MCA box up Landing Ring: (492-9750) Vetco-Gray, 16" Weld on Bottom x 13-5/8" Male Overshot Top Nabors Rig 245 RKB @ 0' ASP Zone 4 "X'~ 561,980.8 ASP Zone 4 "Y": 5,968,563.9 Elevation: 1 02.0' AMSL 16" Conductor @ +1-158' MD Port Collar @ 1,000' MD: (491-9350) TAM 5-1/2" BTC Box x Pin Production Tubing: (423-1660) 3-1/2" 9.3# L-80 EUE 8rd, AB Modified. Gas Lift Mandrel: (477-4825) 3-1/2" x 1" Cameo 'KBG-2-9' w/ dummy valve (474-7315), IBT special clearance box up x IBT special clearance box down, with 6-foot tubing handling pups (XO to EUE 8rd) installed on top and bottom. (1) Joint Tubing Landing Nipple: (461-6545) 3-1/2" Cameo 'OS' w/2.812" No-Go Profile. (1) Joint Tubing Production Casing (467-0750) 5-1/2" 15.5# L-80 BTCM XO / SBE to surface Locator Seal Assembly: (461-3435) 3-1/2" Baker GBH-22 '80- 40' w/12' of Seals and Locator, 3-1/2" x 6' L-80 Handling Pup (455-3185) installed on top. EUE 8rd AB Mod Box up. Set XO / SBE +/- 100' above top Perforation 0( Casing Bore Receptacle Assembly (461-3470) @ +1- 5,034' MD, 3,700' TVD: Baker 5-1/2" XO / Handling Pup, BTC x BTC Baker XO Coupling wI locator shoulder, BTC x SBE Baker 5" 00 x 4" 10 Seal Bore Extension 12' Baker XO, SBE x 3-1/2" EUE 8rd Production Casing (423-1660) 3-1/2" 9.3# L-80 EUE 8RO-Mod TO to XO I SBE (x) Joints Tubing, from Landing Sleeve to Seal Bore Extension Landing Sleeve: 3-1/2" Weatherford, installed in top of joint #3. (1) Joint Tubing (468-0725) Joint with Collar Thread Locked '- ,g~ co() E~ () (;) i3~ Ci)~ "2.æ <:::C/) <::::>0.. J!1.Q 0.:"2--- ---...§:? "'>CO<Ci ~ Q.~ ol!:!", --- Q.O Float Collar: 3-1/2" Weatherford wI 3-1/2" EUE 8rd Box x Pin. . . (468-0720) Joint with Float Collar made up (2) Jomts Tubmg (468-0710) Joint with Float Shoe made up Float Shoe: 3-1/2" Weatherford wI 3-1/2" EUE 8rd Box Up. TD 7-7/8" Hole 5,897' MD, 4,245' TV I' I( ( " American Express. Cash Advance Draft 164 . DATE 5~Jl, 2/JOL '0> 1 ~~y::~1td!o;c; ~~~ $ ~~ Issued by, Integrated Payment System. Ine. Englewood. Colorado ~ALlD F~T OVER $~OOO Payable at Norwest Bank of Grand junction - Downtown. NA ' SHARD ~s D Grand junction. Colorado ~ PERIOD ENDING ' --- Ic'-- /5 ( . I: . 0 2 . DOL. 0 0 I: 3 5 III 0 . 7 5 0 0 0 5 3 b III 0 . b L. ,C ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) ~ DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION i ANNULAR DisPOSAL {\/)NO INJECTION WELL /' ANNULAR DISPOSAL <--J YES INJECTION WELL RED RILL ¡.. NNlYLAR DISPOSAL .- TUT~ ""J¡"T T ' }:::¡< ¿ ,( /C--/3! "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Å ... . . nf .. . WQstes will nnt L .- . . . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS/, W YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The, permit is approved, subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. K£¿¿ WELL PERMIT CHECKLIST COMPANY WELL NAME I C!- ..- /3 / PROGRAM: exp - dev - redrU FIELD & POOL . i - I,. D INIT CLASS Glz. tJ I /1/J GEOL AREA Be¡ () ADMINISTRATION 1. Pennitfeeattached. , , '--i..,' , . . '¡"/'c,. . , "ÍÔ" ' . . YN , 2, Lease number appropriate:r ?r:;~ ~~.~~/. /Ç>:- . ,'. . . . ~ ..5<'kff¿u;¿ (:/vfA.-d -I~r r()d~c-"¡"'~ 1V/...f-4,..v-If'/ ~ ADL D2$t:.tf9; 'T'Þ L-*- A7;)C öz.S-656 3, Unique well name and number, ,. . , , , . . . . , , . . . . . - . N 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 induded, , , , , , , . . . . . . , . 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.. . , , . . . . . . 14. Conductor string provided. . . . . . , . .. , . , . , . . . , ~ N 15, Surface casing protects all known USDWs. . " , . . . , , . Y N 16, CMT vol adequate to circulate on conductor & suñ csg. , , , , N 17, CMT vol adequate to tie-in long string to suñ csg. , . . . , . , '( N ~G \~~~ ~-\\'\"'~ 18, CMT will cover all known productive horizons. . , . ,.'. . , . . ~ N 19. Casing designs adequate for C, T, 8 & permafrost. , . . . . . . N , 20, Adequate tankage or reserve pit.. . . . , . . . . . , , . , , . N ~,~-\,""' ~ ,,\ ~ I ~~ ~~~~<è. ~\~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~~ J ~ \. ("\. \ ...J'.. ' (\ 22. Adequate well bore separation proposed" . . . , , . . , . . . N i'.C\ '-..\~~~ o.~~Q..(" ~ \~C\. ~~'\~ 23. If diverter required, does it meet regulations, . , , . . , . . , N 24, Drilling .fluid program schematic & equip list adequate. , , , , N DATE . ~~: :g~~p..:~=~~~~~:~te'sÙ~ . . . . .?;;òQ ~S¡9: ~ \-\1>. <;, ~ ~,-\- Q \ 1-1 ~ V"': < ~~ \ =~ -\M- Ç> '." ,,~W~ ~.. ~(~ -\;r-s\ q¡ d-Ô 27. Choke r:nanifold C?mplies w/A~I RP-53 .(May 84), . . . . . , . N . . . ~~öa'û~'\ 28. Work WIll occur WIthout operation shutdown. . . , , , . . , . , ) Â. . " 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y Qi) . 30, Permit can be issued w/o hydrogen sulfide measures. , . ". rJ), N 31. Data presented on potential overpressure zones. . . . . , . Y.-w" 32. Seismic analysis of shallow gas zones. . . , . . , , . . . . . I \A f N APPR DATE 33. Seabed condition survey (if off-shore). . . , , . . , '.' ~; f'/" Y N ~ 7', Ir. D I 34. Contact name/phone for weekly progress reports [ex9JlKatory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan , (A) will contain waste in a suitable receiving zone; . , . . , . , (8) will not contaminate freshwater; or cause drilling waste. " to suñace; ." .' (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 MC 25.252 or 20 MC 25.412. Y N §'E~ ENGINEERING: . UIC/Annuiar COMMISSION: ~þ . ~~W WM '--- . '8~s fÉ' ~ ;> 0 "') JM (.1 I.x:,/ö- serv well bore seg _ann, disposal para req - UNIT# 0/ / /¿;ó ON/OFF SHORE D/? A~ 9t Tf .f1"'61 , ENGINEERING GEOLOGY ~~ r-Æ'- ~-k-d 1r<--'!6Vrf- fl, z.. iD 6". 'i tfrfif 6'h1/AJ APPR Y N Y N t\""ùlo.~~'>.C>\.\ \~ ~~ \)~, \ \, ~ ~Ö- ~~ \ b \" c.... \ ö..c; ~ -s:s: ~ \ \ &..~,~ Vë '\~ -\:~~ ~~t\.; \<ë ~~,,~\~~ DATE Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -t ~ :::u ( - -t m - Z -I :J: - CA :Þ :::0 m » ( ~ ,t Well History File APPENDIX Information of detailed nature that is not , particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding ¡nfoonation. 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. ( ( Memory Multi-Finger Caliper Log Results Summary ck3S," Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLlPS ALASKA, INC. August 2, 2005 6520 1 3.5" 9.3Ib. L-80 Tubing Well: 1C-131 Field: Kuparuk State: Alaska API No.: 50-029-23041-00 Top Log IntvI1.: Suñace Bot. Log IntvI1.: 5,122 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 5,038' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing appears to be in good to fair condition with respect to corrosive damage, with the maximum wall penetration of43% in joint 101 (3,183'). Wall penetrations ranging between 20% and 43% are recorded in 107 of the 166 joints logged. A line of pits is recorded in the interval between joints 50 and 161 (1,600' - 5,122'). The damage appears in the forms of isolated pitting, general corrosion, and lines of pits. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. The caliper recordings indicate buckling from 5,000' to 5,122.' A minimum 1.0. of2.70" is recorded in an area of severe buckling in joint 161 (5,106'). 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: Line of Pits ( 43%) Jt. 101 @ 3,183 Ft. (MD) Line of Pits ( 40%) Jt. 85 @ 2,695 Ft. (MD) Corrosion ( 40%) Jt. 125 @ 3,943 Ft. (MD) Line of Corrosion ( 40%) Jt. 126 @ 3,969 Ft. (MD) Corrosion ( 39%) Jt. 130 @ 4,084 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Severe Buckling Minimum 1.0. = 2.70" Jt. 161 @ 5,106 Ft. (MD) No other significant 1.0. restrictions are recorded. SCj~NNEÜ 14UG 2 6 2005 I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TIC 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565--1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~J~i-Ig~' clds., Well: Field: Company: Coun try: 1 C-131 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal Loss (% wall) _ penetration body 200 RØ! metal loss body 150 !d 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 = 166) pene. 0 0 59 106 1 loss 12 1 54 0 0 0 o o 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 = 158) 38 58 62 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 2, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) _ penetration body o O~ e;;;. i =- ==- ~ GLM 1 _ metal loss body 50 100 - 50 ==- ===- ==== .pææ= ~L.- - 'ë-- r' 't \ :; 100 1. r: 150t It.::.-- (I""""-- Bottom of Survey = 161 ''1---- Analysis Overview page 2 ( ( PDS REPORT JOINT TABULATION~HEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-131 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC. NominaII.D.: 2.992 in Country: USA Survey Date: August 2, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 SO 100 .1 25 0 0.03 11 .2 2.88 PUP Lt. Deposits. 1 29 0 0.03 13 .2 2.91 Shallow pitting. 2 62 0 0.04 17 .2 2.91 Shallow corrosion. 3 93 0 0.04 17 2.92 Shallow corrosion. 4 125 0 0.04 16 .2 2.91 Shallow corrosion. Lt. Deposits. 5 156 0 0.03 11 .2 2.92 Lt. Deposits. 6 187 0 0.05 19 3 2.92 Shallow corrosion. 7 219 0 0.04 16 1 2.91 Shallow corrosion. 8 250 0 0.04 16 6 2.95 Shallow corrosion. 9 282 0 0.04 15 2 2.91 Shallow corrosion. 10 313 0 0.04 16 2.91 Shallow corrosion. 11 345 0 0.04 15 2.91 Shallow corrosion. 12 375 0 0.04 16 .2 2.92 Shallow pitting. 13 407 0 0.03 12 .2 2.91 14 438 0 0.04 14 5 2.91 Shallow pitting. 15 469 0 0.03 11 .2 2.92 16 500 0 0.03 12 .2 2.92 17 532 0 0.04 17 .2 2.92 Shallow pitting. 18 563 0 0.03 13 1 2.91 Shallow corrosion. 19 595 0 0.04 16 2 2.91 Shallow corrosion. 20 626 0 0.04 14 .2 2.91 Shallow corrosion. 21 658 0 0.04 17 1 2.91 Shallow corrosion. 22 689 0 0.04 14 2 2.91 Shallow pitting. 23 721 0 0.04 17 .2 2.91 Shallow corrosion. 24 752 0 0.03 12 .2 2.93 Shallow pitting. Lt. Deposits. 25 784 0 0.03 13 2 2.91 Shallow pitting. 26 815 0 0.04 17 1 2.91 Shallow corrosion. 27 847 0 0.04 16 2 2.92 Shallow pitting. 28 878 0 0.03 11 .2 2.92 29 910 0 0.04 14 .2 2.92 Shallow corrosion. 30 941 0 0.03 13 .2 2.91 Shallow pitting. 31 973 0 0.03 13 .2 2.92 Shallow pitting. 32 1003 0 0.06 25 .2 2.91 Isolated pitting. 33 1034 0 0.03 12 2 2.91 Shallow pitting. 34 1066 0 0.04 17 2 2.91 Shallow corrosion. 35 1097 0 0.04 15 2.92 Shallow pitting. 36 1129 0 0.04 17 2 2.91 Shallow corrosion. 37 1160 0 0.08 31 4 2.94 Isolated pitting. 38 1192 0 0.03 13 1 2.91 Shallow pitting. 39 1223 0 0.04 14 .2 2.92 Shallow pitting. 40 1255 0 0.04 16 .2 2.91 Shallow corrosion. 41 1286 0 0.03 13 2 2.90 Shallow pitting. 42 1318 0 0.04 17 2 2.91 Shallow corrosion. 43 1349 0 0.05 19 .2 2.91 Shallow pitting. 44 1381 0 0.08 30 .2 2.92 Isolated pitting. 45 1412 0 0.06 22 2 2.91 Isolated pitting. 46 1444 0 0.04 17 .2 2.92 Isolated pitting. 47 1475 0 0.05 21 2 2.92 Isolated pitting. 48 1507 0 0.03 11 2 2.91 49 1538 0 0.05 21 .2 2.92 Isolated pitting. ! Penetration Body ~!:i;'ii Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-131 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC Nominal 1.0.: 2.992 in Country: USA Survey Date: August 2, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins. ) (Ins.) 0!c) (Ins.) 0 50 100 50 1570 0 0.05 19 2 2.92 Shallow Pitting. 51 1601 0 0.04 17 2.92 Shallow pitting. 52 1633 0 0.03 13 :2 2.93 Shallow pitting. 53 1664 0 0.03 13 1 2.93 Shallow pitting. 54 1696 0 0.06 24 3 2.95 Line of pits. 55 1727 0 0.05 20 :2 2.91 Line of shallow pits. 56 1758 0 0.05 20 2.91 Line of shallow pits. 57 1790 0 0.04 16 :2 2.90 Shallow pitting. 58 1821 0 0.05 21 :2 2.91 Isolated pitting. 59 1852 0 0.05 21 2 2.89 Isolated pitting. 60 1884 0 0.05 18 :2 2.91 Line of shallow pits. 61 1915 0 0.07 26 :2 2.89 Line of pits. 62 1947 0 0.07 26 :2 2.88 Line of pits. Lt. Deposits. 63 1977 0 0.09 35 2 2.88 Line of pits. 64 2009 0 0.05 19 4 2.91 Shallow pitting. 65 2040 0 0.07 27 3 2.90 Line of pits. 66 2072 0 0.05 20 2 2.86 Line of shallow pits. 67 2103 0 0.06 22 2 2.86 Line of pits. Lt. Deposits. 68 2135 0 0.07 29 3 2.91 Line of pits. 69 2166 0 0.07 28 3 2.87 Line of pits. Lt. Deposits. 70 2198 0 0.07 29 3 2.84 Line of pits. 71 2229 0 0.06 24 :2 2.85 Line of pits. 72 2261 0 0.07 27 2 2.89 Line of pits. 73 2292 0 0.06 23 3 2.93 Line of pits. 74 2323 0 0.07 30 2 2.91 Line of pits. 75 2355 0 0.05 20 2 2.91 Line of shallow pits. 76 2386 0 0.07 29 3 2.92 Line çf pits. 77 2417 0 0.05 21 2 2.90 Line of pits. 78 2448 0 0.06 24 4 2.90 Line of pits. Lt. Deposits. 79 2479 0 0.06 22 6 2.89 Line of pits. 80 2511 0 0.06 23 3 2.8.8 Line of pits. 81 2542 0 0.07 27 4 2.90 Line of pits. 82 2574 0 0.06 25 3 2.91 Line of pits. 83 2605 0 0.06 22 2 2.92 Line of pits. 84 2636 0 0.06 24 3 2.89 Line of pits. 85 2668 0 0.10 40 2 2.85 Line of pits. Lt. Deposits. 86 2699 0 0.07 28 3 2.84 Line of pits. Lt. Deposits. 87 2731 0 0.07 28 4 2.88 Corrosion. 88 2762 0 0.07 28 3 2.86 Corrosion. 89 2793 0 0.08 31 4 2.88 Corrosion. 90 2824 0 0.07 29 5 2.88 Corroison. 91 2854 0 0.07 29 4 2.86 Corrosion. 92 2885 0 0.07 29 4 2.88 Corrosion. 93 2917 0 0.07 28 4 2.88 Corrosion. 94 2948 0 0.07 28 2 2.84 Line of pits. 95 2979 0 0.06 24 3 2.84 Line of pits. 96 3011 0 0.07 28 4 2.91 Line of pits. 97 3042 0 0.08 31 4 2.88 Line of pits. 98 3074 0 0.07 29 3 2.89 Line of pits. 99 3105 0 0.09 33 4 2.92 Corrosion. I Penetration Body ~&8 Metal Loss Body Page 2 ( { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 p pf L-80 Well: 1 C-1 31 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC NominaII.D.: 2.992 in Co u ntry: USA Survey Date: August 2, 2005 Joint J1. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (F1.) Upset Body °/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) °/0 (Ins.) 0 50 100 100 3136 0 0.08 31 .., 2.83 Line of pits. J 101 3167 0 0.11 43 4 2.86 Line of pits. L1. Deposits. 102 3199 0.07 0.07 30 4 2.87 Line corrosion. 103 3231 0 0.09 34 4 2.88 Isolated pitting. 104 3262 0 0.07 26 .., 2.86 Isolated pitting. L1. Deposits. J 105 3293 0 0.06 22 3 2.85 Isolated pitting. 106 3325 0 0.06 25 .1 2.86 Line of pits. 107 3356 0 0.06 23 4 2.86 Line of pits. 108 3387 0 0.06 25 4 2.89 Isolated pitting. L1. Deposits. 109 3419 0 0.08 30 5 2.91 Corrosion. 110 3450 0 0.10 38 5 2.91 Corrosion. 111 3480 0 0.09 36 4 2.90 Corrosion. 112 3510 0 0.07 29 6 2.85 Corrosion. 113 3542 0 0.06 23 3 2.83 Line of pits. 114 3573 0 0.06 24 .1 2.84 Line of pits. 115 3604 0 0.05 20 4 2.85 Line of pits. 116 3635 0 0.07 26 7 2.89 Corrosion. 117 3666 0 0.05 20 3 2.91 Line of pits. 118 3698 0 0.09 36 4 2.89 Corrosion. L1. Deposits. 119 3729 0 0.08 30 3 2.90 Corrosion. 120 3761 0 0.07 28 3 2.86 Line of pits. 121 3793 0 0.06 24 3 2.89 Line of pits. 122 3824 0 0.07 29 6 2.92 Corrosion. 123 3855 0.09 0.08 30 6 2.92 Corrosion. 124 3886 0 0.08 31 6 2.88 Corrosion. 125 3918 0.08 0.10 40 5 2.91 Corrosion. 126 3949 0 0.10 40 4 2.86 Line corrosion. 127 3981 0 0.07 27 2 2.83 Isolated pitting. L1. Deposits. 128 4012 0 0.06 24 3 2.84 Isolated pitting. L1. Deposits. 129 4044 0 0.05 20 .1 2.89 Shallow pitting. 130 4075 0 0.10 39 4 2.91 Corrosion. 131 4107 0 0.07 26 3 2.88 Line of corrosion. 132 4138 0 0.07 26 2 2.89 Line of pits. 133 4170 0 0.07 28 3 2.88 Line of corrosion. 134 4201 0 0.07 26 3 2.85 Line of corrosion. L1. Deposits. 135 4233 0 0.06 24 4 2.85 Line of corrosion. L1. Deposits. 136 4264 0 0.08 32 3 2.90 Line of corrosion. 137 4296 0 0.08 30 3 2.88 Line of corrosion. 138 4327 0 0.08 30 3 2.89 Line of corrosion. 139 4359 0 0.08 31 2 2.88 Line of corrosion. 140 4390 0 0.09 35 4 2.88 Corrosion. Lt. Deposits. 141 4421 0.04 0.07 26 4 2.83 Line of corrosion. 142 4453 0 0.06 25 4 2.88 Line of corrosion. 143 4485 0 0.06 25 3 2.89 Line of corrosion. L1. Deposits. 144 4516 0 0.06 25 3 2.84 Line of corrosion. L1. Deposits. 145 4548 0 0.07 28 3 2.83 Line of corrosion. Lt. Deposits. 146 4579 0 0.06 25 4 2.88 Line of corrosion. Lt. Deposits. 147 4610 0 0.09 33 3 2.85 Line of corrosion. 148 4642 0 0.07 26 4 2.83 Corrosion. Lt. Deposits. 149 4673 0 0.07 28 3 2.85 Corrosion. Lt. Deposits. I Penetration Body ·:',!w ~..J'J Metal Loss Body Page 3 I" PDS ~REPORT JOINTTABULATION(~rlEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-131 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC. N ominaII.D.: 2.992 in Country: USA Survey Date: August 2, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 150 4705 0 0.08 31 4 2.81 Corrosion. Lt. Deposits. 151 4737 0 0.06 24 3 2.84 Corrosion. Lt. Deposits. 152 4768 0 0.05 21 4 2.83 Corrosion. Lt. Deposits. 153 4799 0.06 0.06 25 4 2.88 Corrosion. 154 4831 0 0.07 27 3 2.85 Corrosion. Lt. Deposits. 155 4862 0 0.05 21 4 2.86 Corrosion. Lt. Deposits. 156 4894 0 0.06 24 :2 2.88 Corrosion. Lt. Deposits. 157 4925 0 0.08 30 5 2.91 Corrosion. 158 4957 0 0.06 24 4 2.89 Corrosion. 158.1 4989 0 0.07 28 :2 2.92 PUP Isolated pitting. 158.2 4994 0 0 0 0 N/A GLM(Latch @ 1 :30) 1 58.3 5001 0 0.08 30 3 2.86 PUP Corrosion. 159 5007 0 0.07 28 5 2.89 Corrosion. Buckling lower body 159.1 5038 0 0 0 0 2.81 OS Nipple 160 5039 0 0.08 31 7 2.88 Corrosion. 160.1 5070 0 0.03 11 2 2.86 PUP 160.2 5076 0 0 0 0 3.00 SEAL (Corrosion.) Buckling 160.3 5091 0 0.09 36 6 2.79 PUP Corrosion. Buckling lower body 161 5102 0 0.05 21 2 2.70 Corrosion. Severe Buckling. Lt. Deposits. "Penetration Body [Ii'): Metal Loss Body Page 4 ~"'-. ..,....'..'---....,-........,--..,..., .'.....-.: ",LS , .. 1" Well: Field: Company: Country: Tubing: PDS Report Cross Sections 1 C- 131 Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 2, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for joint 101 at depth 3183.47 ft Tool speed = 53 Nominal 10 = 2.992 Nominal aD = 3.500 Remaining wall area = 96 % Tool deviation = 48 0 Finger 2 Penetration = 0.11 ins Line of Pits 0.11 ins = 43% Wall Penetration HIGH SIDE = UP Cross Sections page 1 --=--- ). :....... . ...--... ......... ~s (...!!!!=~] . .. I"~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-131 Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 2, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 85 at depth 2695.45 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 47 0 Finger 2 Penetration = 0.102 ins Line of Pits 0.10 ins = 40% HIGH SIDE = UP Cross Sections page 2 clr. ,J. lS - - IJ· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-B1 Kuparuk CONOCOPHILLlPS ALASKA, INC USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 2, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 161 at depth 5106.18 ft Tool speed = 47 NominalD = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 48 0 Finger 24 Projection = -0.155 ins Severe Buckling Minimum 1.0. = 2.70 ins HIGH SIDE = UP Cross Sections page 3 ~PHILLlPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY 1C-131 TUBING (o.tœ1, 00:3.500, 10:2.992) ~OOUCTION (~, 00:5.500, wt:15.50) NIP (5038-5æ9, 00:4.520) NIP (5076-5077, 00:4.500) SEAL (5077-5078, 00:4.000) Perf (5170-5232) LINER (5083-5007, 00:3.500, Wt:9.30) Perf (5270-5326) . API: 500292304100 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: 5661 Last Tag Date: 11/22/2001 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 PRODUCTION LINER Tubing String - TUBING Size I Top 3.500 0 Peñorations Summary Interval TVD 5170 - 5232 3763 - 3801 5.500 3.500 I Bottom 5091 Zone WS D,WS C WSB 5270 - 5326 3825 - 3860 Gas Lift MandrelsNalves st MD TVD Man Man Mfr Type 1 4995 3653 CAMCO KBG-2-9 Other (:>Iugs, equip., etc.) - JEWELRY Depth TVD Type 5038 3680 NIP 5076 3704 NIP 5077 3705 SEAL KRU Well Type: INJ Orig 10/6/2001 Completion: Last W/O: Ref Log Date: TD: 5915 ftKB Max Hole Angle: 55 deg @ 2199 Top o Bottom 158 o 5083 5083 5907 TVD 3713 Wt 9.30 Status Ft SPF Date Type 62 4 12/15/2001 IPERF 56 4 11/25/2001 IPERF 1C-131 Angle ~ TS: deg ~ Angle @ TO: 47 deg @ 5915 Rev Reason: Format update by ImO Last Update: 6/23/2002 TVD 158 Wt 62.58 Grade API5L GrB L-80 L-80 Thread PEB 3708 4241 15.50 9.30 BTC EUE I Grade L-80 Thread EUE Comment 2.5" HSD BH Chg, 60 deg ph 2.5" HSD BH Chg, 60 deg ph DMY 1.0 V Type V OD Latch Port TRO o V Mfr Description CAMCO 'DS' NIPPLE WITH NO GO PROFILE BAKER LOCATOR SUB NIPPLE BAKER 80-40 SEAL ASSEMBLY DK-1 Date Run 10/5/2001 Vlv Cmnt 0.000 ID 2.812 2.992 3.000 (' (' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 18 07:57:59 2002 Reel Header Service name.............LISTPE Date.....................02/02/18 Origin...................STS Reel Name............... .UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................02/02/18 Origin...................STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA - West Sak JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-11162 J BOBBITT DPRESNEL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 1C-131 500292304100 PHILLIPS Alaska, Inc. Spe r ry Sun 18-FEB-02 MWD RUN 2 AK-MM-11162 J BOBBITT D PRESNEL MWD RUN 3 AK-MM-11162 S HUIBAN D PRESNEL 12 llN 10E 1673 973 .00 101.45 60.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 158.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE a aI-Irs (" ( RESISTIVITY PHASE 4 (EWR4). 3. MWD DATA IS PDC PER THE GKA GEOSIENCE GROUP (E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. DATED 01/04/02. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 4. MWD RUNS 1 - 3 REPRESENT WELL lC-131 WITH API # 50-029-23041-00. THIS WELL REACHED A TOTAL DEPTH OF 5915' MD, 4247' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED "RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( PEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 File Type..... '" .... . . . . . LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX ROP FET $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 103.5 148.0 148.0 148.0 148.0 158.0 158.0 STOP DEPTH 5851.5 5858.5 5858.5 5858.5 5858.5 5914 . 5 5858.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 103.5 2 2474.0 3 5340.0 MERGE BASE 2473.5 5339.5 5914 .5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined ( (' Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 103.5 5914.5 3009 11623 103.5 5914.5 ROP MWD FT/H 1. 08 651.19 176.392 11514 158 5914.5 GR MWD API 9.98 139.55 71.5889 11497 103.5 5851.5 RPX MWD OHMM 0.24 1411.6 39.7525 11422 148 5858.5 RPS MWD OHMM 0.28 2000 58.1587 11422 148 5858.5 RPM MWD OHMM 0.53 2000 97.6175 11422 148 5858.5 RPD MWD OHMM 0.31 2000 152.745 11422 148 5858.5 FET MWD HR 0.12 21.68 0.903906 11402 158 5858.5 First Reading For Entire Fi1e..........103.5 Last Reading For Entire Fi1e...........5914.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number. ... .. . .. . .1. 0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 Fi Ie Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log B!T RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX ROP FET $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 103.5 148.0 148.0 148.0 148.0 158.0 158.0 STOP DEPTH 2432.0 2438.5 2438.5 2438.5 2438.5 2473.5 2438.5 # ( LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units.................,...... Datum Specification Block sub-type...O 30-SEP-01 Insite 4.05.5 66.37 Memory 2474.0 .0 55.0 TOOL NUMBER PB02205GRV4 PB02205GRV4 7.875 Water 9.30 107.0 9.3 700 8.6 4.800 4.466 3.100 2.900 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 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 28 8 Name Service Unit DE PT FT Min 103.5 Max 2473.5 Mean Nsam 1288.5 4741 (" Based 60.0 65.0 60.0 60.0 First Reading 103.5 Last Reading 2473.5 (' (' ROP MWD010 FT/H 1.08 332.87 174.132 4632 158 2473.5 GR MWD010 API 12.96 121.06 65.4551 4658 103.5 2432 RPX MWD010 OHMM 0.24 1411. 6 82.5043 4582 148 2438.5 RPS MWD010 OHMM 0.28 2000 128.13 4582 148 2438.5 RPM MWD010 OHMM 0.53 2000 225.873 4582 148 2438.5 RPD MWD010 OHMM 0.31 2000 362.657 4582 148 2438.5 FET MWD010 HR 0.12 6.28 0.55774 4562 158 2438.5 First Reading For Entire File..........103.5 Last Reading For Entire File...........2473.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......O2/02/18 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OO2 Comtttent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE Sill1MARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2432.5 2439.0 2439.0 2439..0 2439.0 2439.0 2474.0 STOP DEPTH 5276.0 5283.0 5283.0 5283.0 5283.0 5283.0 5339.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 02-OCT-Ol Insite 4.05.5 66.37 Memory 5339.0 50.3 52.6 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBO2205GRV4 PB02205GRV4 # BOREHOLE AND CASING DATA ( ( OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.875 # 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: Based Water 9.30 107.0 9.3 700 8.6 4.800 3.492 3.100 2.900 60.0 85.0 60.0 60.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specificatiòn Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..........................-999 Depth Units....................... Datum Specì.fication Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO20 FT/H 4 1 68 4 2 GR MWDO20 API 4 1 68 8 3 RPX MWDO2.0 OHMM 4 1 68 12 4 RPS MWDO20 OHMM 4 1 68 16 5 RPM MWDO20 OHMM 4 1 68 20 6 RPD MWDO20 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 Fì.rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2432.5 5339.5 3886 5815 2432.5 5339.5 ROP MWD020 FT/H 7.49 341. 59 181.079 5732 2474 5339.5 GR MWDO20 API 9.98 139.55 73.2517 5688 2432.5 5276 RPX MWDO20 OHMM 1. 03 96.07 11.8536 5689 2439 5283 RPS MWD020 OHMM 0.76 1090.49 12.0697 5689 2439 5283 RPM MWDO20 OHMM 1.15 1819 12.551 5689 2439 5283 RPD MWD020 OHMM 1.17 1607.01 12.9954 5689 2439 5283 FET MWD020 HR 0.21 10.1 0.827636 5689 2439 5283 First Reading For Entire File...........2432.5 Last Reading For Entire File...........5339.5 File Trailer Servì.ce name.............STSLIB.003 Servì.ce Sub Level Name... Versì.on Nurnber...........1.0.0 Date of Generation.......O2/02/18 Maxì.mum Physical Record..65535 Fi Ie Type................ LO Next File Name...........STSLIB.OO4 ( ( Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5276.5 5283.5 5283.5 5283.5 5283.5 5283.5 5340.0 STOP DEPTH 5851.5 5858.5 5858.5 5858.5 5858.5 5858.5 5914.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 03-0CT-01 Insite 4.05.5 66.37 Memory 5915.0 47.4 51.5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02205GRV4 PB02205GRV4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER t S CASING DE PTH ( FT) : 7.875 # 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: Water 9.30 107.0 9.3 700 9.0 Based 4.800 3.347 3.100 2.900 60.0 89.0 60.0 60.0 # 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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5276.5 5914.5 5595.5 1277 5276.5 5914.5 ROP MWD030 FT/H 5.45 651. 19 162.135 1150 5340 5914.5 GR MWD030 API 54 137.37 88.194 1151 5276.5 5851.5 RPX MWD030 OHMM 2.26 31.79 7.45727 1151 5283.5 5858.5 RPS MWD030 OHMM 2.28 31.18 7.41522 1151 5283.5 5858.5 RPM MWD030 OHMM 2.32 30.48 7..50102 1151 5283.5 5858.5 RPD MWD030 OHMM 2.56 36.,04 7.84602 1151 5283.5 5858.5 FET MWD030 HR 0.26 21..68 2..65292 1151 5283.5 5858.5 First Reading For Entire File.... u. ...5276.5 Last Reading For Entire File.... ""'" .5914.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/18 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.O05 Physical EOF Tape Trailer Service name.............LISTPE Date.....................02/02/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service :oame.............LISTPE Date.....................02/02/18 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN I . (O ( Comments___._---._..--...STS LIS Writing Library- Scientific Technical Services Physical EOF Physical EOF End Of LIS File