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201-114
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-127 KUPARUK RIV U WSAK 1C-127 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/21/2022 1C-127 50-029-23024-00-00 201-114-0 W SPT 3669 2011140 1500 784 784 784 782 4YRTST P Kam StJohn 11/6/2022 Single casing well 30 MinPretest Initial 15 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-127 Inspection Date: Tubing OA Packer Depth 275 1820 1790 1790IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221108201150 BBL Pumped:0.9 BBL Returned:0.9 Wednesday, December 21, 2022 Page 1 of 1 By Samantha Carlisle at 10:13 am, Sep 29, 2022 ! 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PTD 2011280 Type Inj N Tubing 605 745 740 730 Type Test P Packer TVD 3644 BBL Pump 0.6 IA 215 1830 1765 1760 Interval 4 Test psi 1500 BBL Return 0.5 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010800 Type Inj N Tubing 340 430 415 405 Type Test P Packer TVD 3564 BBL Pump 0.5 IA 450 1830 1770 1760 Interval 4 Test psi 1500 BBL Return 0.4 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011140 Type Inj N Tubing 665 705 690 685 Type Test P Packer TVD 3669 BBL Pump 1.0 IA 60 1820 1795 1785 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2030030 Type Inj NTubing50505050 Type TestP Packer TVD 3833 BBL Pump 1.1 IA 230 1810 1720 1715 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad N/A Miller 05/10/22 Notes: Notes: 1C-111 1C-121 1C-190 Notes: 1C-127 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechan i call In t eg r i t yy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0510_MIT_KRU_1C-pad_4wells - 5HJJ 9 9 9 9 9 9 $2*&&ZLWQHVVZDLYHGMEU 1C-127 05/10/22 $2*&&ZLWQHVVZDLYHGMEU C:\Users\aebell\Desktop\December 2021 Data Drop\CPA Data Drop 12242021\2021-12-21_15821_KRU_1C-127_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15821 KRU 1C-127 50-029-23024-00 Caliper Survey 21-Dec-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 37' (6HW ___________________________________________ Signatururuururururuuururrururururuururrurururuurururuuue 12/27/2021 By Abby Bell at 8:51 am, Dec 27, 2021 MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg P.I.Supervisor r-R�Gi rj 12111€ SUBJECT: Mechanical Integrity Tests 66 CONOCOPHILLIPS ALASKA,INC. IC-127 FROM: Austin McLeod KUPARUK RIV U WSAK IC-127 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry SW-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1C-127 API Well Number 50-029-23024-00-00 Inspector Name: Austin McLeod Permit Number: 201-114-0 Inspection Date: 5/12/2018 Insp Num: mitSAM180513201608 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-127 "Type Inj W "TVD 3669 • Tubing 957 • 957 957 ' 956 - 956- PTD _---- — --- ---__ __- 201114o " Type Test SPT Test psi 1500 IA 90 1820 - 1810 1790 1790 BBL Pumped: I1 - BBL Returned: 1 OA Interval 4YRTST P/F P ✓ Notes: MIT-IA.8.625"x7.625"at 135'-No OA SCANNED JUN 0 12 01 • IIS Wednesday,May 16,2018 Page 1 0f 1 7-_ • • � � al .� CO� Co o ` > E VC l t v Op C'` ,: O0 CO > CO �� 1:5 fa o -O ^ 0 EO U N ++ > Nz O O� p m v L- a C 0 CO c Q ca +, ML 'Q ''40 Y ILL�i p� CO O aJ > j Q t u o a • Q (w7 CO 03 CO 03 CO r° �„ L O a CO • . p c c c c c E + ,_ o �^. _1 ca ca at COW M M M M p C CO U -C al �, N F- Tr to In CO CO 0O O '6 l' 1- cn Z o al E - u Z g, L > - E Q.Iiii - u O C L f6 al TO ., U C L al 0 i W W W W W W ao 0.7 a � al c LL LL LL LL LL LL O > al 0 ' J J J J J J +' `I- jI Z Z Z Z Z Z C o '' 0� � .� LL LL LL LL LL LL K JD C W U O ! a v u > RI• � < v ° Ca a .xi U ,ILL LL y a, LL LL iw� p . 00 aaOO o CL Et ' ' ce tiv w U pp 0 .. a a U U a a 9"y • E U to .. \ CO 7 com a Wd4. GO . Zns z � � w 22 OA L CD E E 3 W W W W W W u > > > > > > U • Q' a' a' Q' cca' u • In - g Y Y Y Y Y Y — O s Q Q Q Q Q QC‘ Ce Q a a a a a a , 0 Y Y Y Y Y Y A C U 0 OA R$ V CC Wco O 0 D O rs. CO OCsi p X In .� � • O O 0 0 0 0 0 0 Gl rG Y MOM V r r ,-- 0 c Cl •_ > } 0 } LL r20 r2 CO n W w0 V z 0 CO Q H W Q OCC00000 to c Cr N _o u) v r E (Y1 0 M N N M L U N _ M M O O M M N N N N N N N L -D R 'I O C) M M T 6) a) an p .r N N 0 0 N NL Q) O O O O 3 0 0 0 0 0 0 ++ O al 000 C Y) In In IA I) In a u �_• W 111 .v ro al . i-- cn an Ec c • W Y Occ L U Coil Q N Ns- al 7 d .1:11 Z Y ,I N O N 0 0 E Gl I— A = In El N ' V ,- H ~ J, m E co L a C a < O N N N of z H 1c6' C +' CO w 0N7 aLaa °i H a aQ • • 2coScc3 WELL LOG TRANSMITTAL# DATA LOGGED tO Ilk/2015 K. BENDER To: Alaska Oil and Gas Conservation Comm. October 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 .w, Anchorage, Alaska 99501 , ata RE: Perforation Record: 1C-127 Run Date: 9/11/2015 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-127 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23024-00 SCANNED ; 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:; " f mat,, STATE OF ALASKA • • ALA OIL AND GAS CONSERVATION COIVIIRSIONCO a/ qjii REPORT OF SUNDRY WELL OPERATIONS . ; F 1.Operations Abandon RugPerforations Fracture Stimulate Pull Tubing r 4't --," ,n Performed: Suspend r Perforate Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-114 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic "° Service 50-029-23024-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 KRU 1C-127 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 6450 feet Plugs(measured) none true vertical 4270 feet Junk(measured) none Effective Depth measured 6350 feet Packer(measured) 5830, 5920, 5982 true vertical 4172 feet (true vertical) 3669, 3753, 3812 Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158 158 PRODUCTION 6400 7.625 6439 4260 SCM EO AN 1. 9 2_11 4--i, Perforation depth: Measured depth: 5864-5904, 5933-6003,6022-6038,6048-6070, 6097-6134 True Vertical Depth: 3700-3738, 3765-3832, 3850-3866, 3875-3897, 3923-3959 Tubing(size,grade,MD,and TVD) 3.5, L-80, 5997 MD,3826 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 5830 MD and 3669 TVD PACKER-BAKER S-3 PACKER @ 5920 MD and 3753 TVD PACKER-BAKER FB-1 RETAINER PRODUCTION PACKER @ 5982 MD and 3812 TVD NIPPLE-CAMCO DS NIPPLE @ 501 MD and 500 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 696 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P. Exploratory r Development r Service P Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ F WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact John Peirce (a?265-6471 Email John.W.PeirceAconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature io/‘ ���. Phone:265-6471 Date (7 12ct 1 I s . ..c `-�. b/2 J/5 RBDMS1 j ut;i 0 1 2015 Form 10-404 Revised 5/20015 / Submit Original Only ,0? /, /7s KUP INJ • 1C-127 ConocoPhillips �- WellAttrbutes --: webore APuwl Field NameAllska,Inc: Wellbore Status Max pi An Mg Dl e(ft&KB)MD, TD Act Btm(ftKB) ennn��nanrpz 500292302400 WESTSAK INJ 66.62 2,600.00 6,450.0 ".. .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-127,9113/2015137:42 PM . SSSV:NIPPLE Last WO: 46.29 7/2/2001 Vnrscakachem859(801110) Annotation Depth(HKB) End Date Annotation Last Mod By End Date Tag:SLM 6,184.0 8/27/2015 Rev Reason:PERFORATIONS lehallf 9/13/2015 HANGER 35.7- tib al Casing Strings C ing Description OD(in) ID(in) Top(ftKB) SetDepth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread Fr CONDUCTOR 1615.062 40.0 158.0 158.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 75/8 6.875 39.5 6,439.3 4,259.9 29.70 L-80 BTC-MOD . .. :, . was,8625x7625@135 I: Tubing Strings ,. -'' ,.,.--- 11111T11 =, Tubing Description String Ma..ID(in) Top(ftKB) Set D pth(ft...Set Depth(TVD)(.. Wt(Ib/ft) Grade Top Conn c ion ._TUBING 31/2 2.992 35.7 5,996.8 3,825.8 9.30 L-80 EUE-MOD Completion Details. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 35.7 35.7 0.00 HANGER VETCO GRAY HANGER 4.500 CONDUCTOR;40.0-158.0 500.9 500.4 6.38 NIPPLE CAMCO DS NIPPLE 2.875 It 5,829.5 3,668.3 23.37 XO BUSHING CROSSOVER BUSHING 3.500 NIPPLE,500.9 "" 5,830.3- 3,669.0 23.33 PACKER BAKER PREMIER PACKER 4.500 5,902.4 3,736.1 19.96 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/2.812"DS PROFILE 2.813 (OPEN 4/25/2013) 5,920.0 3,752.7 19.32 PACKER BAKER S-3 PACKER 3.875 5,958.5 3,789.2 17.90 SLEEVE-0 BAKER CMU SLIDING SLEEVE,2.75"D PROFILE 2.750 (OPEN 7/25/15) 5,974.3 3,804.3 17.20 LOCATOR 3.000 GAS LIFT;5,777.0 5,977.9 3,807.7 17.05 SEAL ASSY BAKER 80-40 NO GO LOCATOR SEAL ASSEMBLY w/ 3.980 it 1/2 MULE SHOE 5,981.9 3,811.5 16.87 PACKER BAKER FB-1 RETAINER PRODUCTION PACKER 4.000 5,984.6 3,814.1 16.75 MILLOUT BAKER MILLOUT EXTENSION 4.500 5,990.0 3,819.3 16.51 XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,86.5,L-80,EUE- 2.390 MOD PACKER;5,830.3 m 5,994.7 3,823.8 16.30 NIPPLE CAMCO D NIPPLE w/2.25"PROFILE 2.250 I5,996.3 3825.3 16.23 WLEG BAKER WIRELINE GUIDE 2.380 Other Indole(Wireline retrievable plugs,valves,ptdmps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) CI Des Com Run Date ID(in) _. _. Surf Csg Weld sleeve on surface casing to repair damage from 1/4/2013 Patch 5"below bottom of production hanger to 17'8 1/2", total length of sleeve 173 1/2". IPERF;5,8640-5,904.01_ 11: .: GAS LIFT:5,881.8 - Perforations&Slots - Shot Dens _ Top(ND) Btm(ND) (shots/f SLEEVE-0;5,902.4 - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5,864.0 5,904.0 3,7002 3,737.6 WS D,1C-127 8/4/2002 4.0 IPERF 3 3/8"HDS 5,933.0 6,003.0 3,765.0 3,831.7 WS B,WS 8/3/2002 4.0 IPERF 33/8"HDS PACKER;5,9200 `' m A4,1C-127 , 5,934.0 5,970.0 3,765.9 3,800.1 WS B,1C-127 8/4/2002 4.0 RPERF 3 3/8"HDS 6,022.0 6,038.0 3,850.1 3,865.5 WS A3,1C- 8/3/2002 4.0 IPERF 33/8"HDS 127 6,048.0 6,070.0 3,875.2 3,896.6 WS A3,1 C- 8/3/2002 4.0 IPERF 33/8"HDS 127 GAS LIFT;5,938.0 I`i 6,097.0 6,112.0 3,923.0 3,937.6 WS A2,1C- 9/12/2015 6.0 APERF TRIPHASE DEEPSTAR 127 RPERF;5,9340-5,9]0.0-� { 6,112.0 6,134.0 3,937.6 3,959.2 WS A2,1C- 8/3/2002 4.0 IPERF 33/8"HDS 127 SLEEVE-Q 5,9505 Mandrel Inserts IPERF;5,9330-6,003.0- _ st Top(ND) Valve Latch Port Sian TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com LOCATOR;5674.3 I 5,777.0 3,620.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/25/2012 SEAL Assv;5,97.07. 2 5,881.8 3,716.8 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.08/5/2002 3 5,938 0 3,769 7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/5/2002 PACKER;5,981.9 '- MILLOUT,5,984.6 NOteS;:General&Safety " End Date Annotation , 1 1/7/2013 NOTE:***MAXIUMUM ALLOWABLE PRESSURE 4000 psi***. DO NOT EXCEED FOR ANY REASON NIPPLE;5,994.7 WLEG;5,996.3 IPERF;6,022 0-6.038 0 IPERF;6,048 0-6,070.0 APERF;6,097.0-6,112.0-_ _. IPERF;6,1120-6,134.0 PRODUCTION 8.625x].625" 135';39.5-L 6,439.3 •1C-127 WELL WORK SUMMARY • DATE SUMMARY 8/27/2015 TAGGED @ 6180' SLM; MEASURED BHP @ 6040' RKB (1901 PSI); DRIFT DOWN TO 6120' RKB W/ 15'X 2.125 STEM (SLOW GOING THRU D-NIPPLE & PULLED 500 OVER PICKUP COMING BACK UP THRU). READY FOR E-LINE [pert]. 9/12/2015 PERFORATE INTERVAL 6097'-6112' USING 2-1/8" DEEPSTAR PERFORATING SYSTEM, 6 SPF, TRIPHASED, 15.5 GM DP CHARGES. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 13 JULY 2001. JOB COMPLETE. ( (, Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 i-I L Lf Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed IIIIIIIII~IIIIIIII RESCAN ~olor Items: ~GreYSCale Items: 0 Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Diskettes, No. D Other, No/Type: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Other: D Logs of various kinds: Scanning Preparation :J - x 30 = 0b 151 n1P 1111111111111111111 oate:JÓ}, '0,+ 151 MP + ~ = TOTAL PAGES <i51 (Count d.' oe. s rotJ;clude cover Shr~~. J(J Date: /01' / Olf /s/ VV(,- 1111111111111111111 D Other:: . I I Date:lõ I Of . , NOTES: BY: Helen~ Project Proofing BY: Helen ~ BY: Helen éia) Production Scanning Stage 1 Page Count from Scanned File: '?r a (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES , , , Date:} 0 / 0 'f , . YES NO NO /s/ nfP Stage 1 BY: Helen ~ If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: /5/ Scanning is complete at this pOint unless rescanning is required. ReScanned 1111111111111111 BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �j �'tO1 t DATE: Thursday,May 09,2013 P.I.Supervisor ( 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-127 FROM: Chuck Scheve KUPARUK RIV U WSAK IC-127 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry..3:1641- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1C-127 API Well Number 50-029-23024-00-00 Inspector Name: Chuck Scheve Permit Number: 201-114-0 Inspection Date: 5/5/2013 Insp Num: mitCS130506075109 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min yp W (Test psi 3669 IA 890 zolo • 2002 zooz Well IC 127 Type Inj TVD 842 847 844 PTD T e Test 1500 - 1 OA g J P/F Tubin 2011140 SPT InterV8110THER P t 844 i Notes: Post casing repair sCMME® FEB 2 0 2014 Thursday,May 09,2013 Page 1 of 1 • a STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Fbrforations r Perforate r Other [` SC sleeved repair Alter Casing r Pull Tubing r Stimulate - Frac r Waiver ' Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201 - 114 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service p-, r' 50- 029 - 23024 -00 7. Property Designation (Lease Number): 8. Well Name and Number,; ADL0025649 e 1C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6450 feet Plugs (measured) None true vertical 4270 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5830 true vertical 0 feet (true vertucal) 3669 Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158 158 0 0 PRODUCTION 6400 11 6439 4260' 0 0 SLEEVE 16'9" 10" .500 wall 65# 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 5864 -5904, 5934 -5970, 5983 -6003, 6022 -6038, 6048 -6070, 6112 -6134' True Vertical Depth: 3700 -3738, 3766 -3800, 3813 -3832, 3850 -3866, 3875 -3897, 3938 -3959' RECEIVED Tubing (size, grade, MD, and TVD) 3.5, L - 80, 5995 MD, 3824 TVD JAN 16 2013 Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 5830 MD and 3669 TVD AOGCC 12. Stimulation or cement squeeze summary: e APR 1 6 41� ►- AOGCC treated (measured): NA % WED Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r • 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -409 Contact MJ Loveland /Martin Waite Printed Name MJ Lov land Title WI Projects Supervisor Signature ne: Date 1/9/13 RBDMS JAN 2 8 2013 cfsl ∎( I r I 2\ r5 Form 10 -404 Revised 11/2011 b Submit Original Only AorctyV IPNRIPM4 s 0 a M x tt n • 4001 ' j ft t f. • yy •' y 4.1.4. '"4 .�„ ‘1," 333 Y .i • 1 4' it 4. *, , ‘43 ,4, r , f , c * a t • . A 0 ,, . - -, .. si .,,,,,, . • .t . ;‘ • a I 4. OOP" . 1104411„, alit .A, ! ir ' la , 21 1 * li Mk t • 7 , " s . �, rem •e, • „. , i ' * * s at li* ,rw Ty ..,i • i s w ° �s 1 AT . , , a 49 � * y 1 4 Ill • • • , i se • , S * k it r � , • ,w.+ tot I i ,lap r $ L } i . ' r w • x r , ' X • • Z f ,, " ©ConocoPhillips Alaska, Inc . + ; ' .. ' This photo is copyright by ' C, Inc • • f and cannot be released Alaska o "'""* * {i ` published onocoPhillips without express • J • ° - ? - .. ""+ ,, ii , . • + A written consent of r ' ..• ; • • ,',` ' ... ConocoPhillips Alaska r14‘ * yam. . . .. l 111 TN.) 0. r , • • IPP." • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 9, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the REVISED 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1C -127, PTD 201 -114, Sundry 312 -409 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, MJ Love nd ConocoPhillips Well Integrity Projects Supervisor a J • 1C-127 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06 /09 /12ISET 2.78" WEATHERFORD WRP AT 5859.4'. 12/20/12 Cut two 15" X 20" windows in conductor. Cleaned sealant out of conductor and chipped cement off of surface casing. Buffed surface casing for UT inspection, awaiting results. 12/21/12 Cut landing ring and conductor off of wellhead, total of 17' removed. Chipped cement off o surface casing and located leak point 13' 10 1/2" below landing ring. 12/23/12 E- mailed AOGCC to inform them of opportunity to witness damage to SC (waived Jeff Jones) 12/22/12 Cut and removed an additional 13" (18' 1" total) of conductor and chipped cement.Two casing hanger flutes cut 180 degree's apart. Buffed surface casing for inspection. UT confirmed good pipe on both A & B bands. 12/31/12 Cut 9" of conductor off SC, chipped cement and buffed SC. SC looks in good shape. Tota amount of conductor cut off so far is 18' 10 ". 01/011131E-mailed AOGCC to inform them of opportunity to witness repair to SC (no response) 01/02/13 Welders welded both 6" collars made with X65 10" .500 wall pipe in A &B bands onto SC and kakivik passed the welds. 01 /04 /13IWelders completed welding 16' 9" of 10" x65 .500 sleeve around bad SC, 01/07/13 Initial T /I= Si0 /5. Post SC repair MIT -IA (passed). Pressured up IA to 500 PSI (no visible leaks), Pressured up to 1000 PSI (no visible leaks), Pressured up to 1600 PSI (no visible leaks). Shut in for 1 hour monitor.15 Min= 1590, 30 Min= 1590, 45 Min= 1590, Final = 1590. Bled IA to 0 PSI. Wellhead vendor (Vetco -Gary), calculated service pressure @ 4000 psi. 01 /08 /13IWelders installed 18' 5.5" X 16" 62# .375 conductor pipe. s t , f 1 I , 41.10 114114 ' F sr t b. r , ter ± ,+ # „x,t .. ,,, .., : 5 - Ai , L , 'T'$) ' lt . r L 4 j*� ` " rte fit 4T [ ©ConocoPhillips Alaska, Inc • ';_ • ` i y '. ` This photo is copyright by le* 4. �^ a ` " ` � �;' ConocoPhillips Alaska, Inc t �, , -: o f r # x r�; . '5�' and cannot be released or > ', • €�� , published with express z a `" . = u vritten consent of t.*, • :' 4 `{ ' , S e J ConocoPhillips Alaska ..„ i- ; .. -,,,,,: , .4,- , , i � , k 4/4 ;.`".- ' r '''' :-,Vr'. "., , - '..t.'", i ' '' , "' 4 � :. RECEIVED • STATE OF ALASKA JAN 1 1 2013 • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AQ9Ce 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other p SC s eeved repair . Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r r 201 -114 ' 3. Address: 6 . API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service — 50 - 029 - 23024 - • 7. Property Designation (Lease Number): 8. Well Name and Number:_ ADL0025649 1C • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 6450 ' feet Plugs (measured) None true vertical 4270 • feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5830 true vertical 0 feet (true vertucal) 3669 Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158 158 0 0 PRODUCTION 6400 11 6439 4260' 0 0 SLEEVE 16'9" 10" .500 wall 65# 0 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 5864 -5904, 5934 -5970, 5983 -6003, 6022 -6038, 6048 -6070, 6112 -6134' True Vertical Depth: 3700 -3738, 3766 -3800, 3813 -3832, 3850 -3866, 3875 -3897, 3938 -3959' Tubing (size, grade, MD, and TVD) 3.5, L -80, 5995 MD, 3824 TVD s Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 5830 MD and 3669 TVD 12. Stimulation or cement squeeze summary: 2013 Intervals treated (measured): NA 5CPINNED JAN 2 5 LU Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA b . NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: .. Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r • WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -409 Contact MJ Loveland /Martin Waite Printed Name MJ Lov land Title WI Projects Supervisor Signature ne: Date 1/9/13 ABDMS JAN 11 20V Zen t-/q-/..S 19, .0 Form 10 -404 Revised 11/2011 , �ffi. Submit Original Only ;v' • • . ✓ „ RECEIVED ConocoPhillips JAN 11 2013 Alaska A0G0C P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 9, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1C -127, PTD 201 -114, Sundry 312 -409 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, MJ L eland ConocoPhillips Well Integrity Projects Supervisor • 1C-127 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/09/121SET 2.78" WEATHERFORD WRP AT 5859.4'. 12/20/12 Cut two 15" X 20" windows in conductor. Cleaned sealant out of conductor and chipped cement off of surface casing. Buffed surface casing for UT inspection, awaiting results. 12/21/12 Cut landing ring and conductor off of wellhead, total of 17' removed. Chipped cement off of surface casing and located leak point 13' 10 1/2" below landing ring. 12/23/12 E- mailed AOGCC to inform them of opportunity to witness damage to SC (waived Jeff Jones) 12/22/12 Cut and removed an additional 13" (18' 1" total) of conductor and chipped cement. Buffed surface casing for inspection. UT confirmed good pipe on both A & B bands. 12/31/12 Cut 9" of conductor off SC, chipped cement and buffed SC. SC looks in good shape. Total amount of conductor cut off so far is 18' 10 ". 01/01/131E- mailed AOGCC to inform them of opportunity to witness repair to SC (no response) 01/02/13 Welders welded both 6" collars made with X65 10" .500 wall pipe in A &B bands onto SC and kakivik passed the welds. 01 /04 /13IWelders completed welding 16' 9" of 10" x65 .500 sleeve around bad SC, 01/07/13 Initial T /I= Si0 /5. Post SC repair MIT -IA (passed). Pressured up IA to 500 PSI (no visible leaks), Pressured up to 1000 PSI (no visible leaks), Pressured up to 1600 PSI (no visible leaks). Shut in for 1 hour monitor.15 Min= 1590, 30 Min= 1590, 45 Min= 1590, Final = 1590. Bled IA to 0 PSI. 01/08/13 Welders installed 18' 5.5" X 16" 62# .375 conductor pipe. — .7 Cil 4.‘„, 4... .., i !Irk 4 ' , ,,, Lel) ,, , , r " e 4 i $ 6. ' ., 'r•r k i A 04 i z ° r ) e, olio . . , , „ . .14, *, i ' ' , i ' ' ''' * t 1 A T r ti T fe, ? ■ y t TT y� C �+ i a $ ' � — W i f ' Y • q s # w a . i{ g d t .e i �. i C ") 't , Ar [ tea `'F ', +' i -.. i `• ) f/ � �� � • , ti p ., • • 7 , • a .• - • ,p � i ji t 3 a 4 • a t + it, • • ,, •• • • a, C . Olt: ,ie;4'. *4.... .,L s I • n fi r • w t,, , , • . W ' * . . ' th IA .1, r , • '• 4 ' . # * . ' , 4 .w 1 • {t 4 ' a . j © ConocoPhillips Alaska, Inc `, y - 1 • , •" This photo is copyright by . • * • , • ConocoPhillips Alaska, Inc. P and cannot be released or • " published without express . • • w t' written consent of • ....a. •' • •s • • ConocoPhillips Alaska • •. 6 .' ' • i • • ..,, 1 , 1 . / / / / deo; ..' 6 00 ,‘ el'APt - ' t * 'P - '''' 401 41, • . -.. .,1,1?4,01 Orwi . ' MO "111 r 0 . ....., -,. ': , to -, , 4 • • @ConocoPhilliPs Alaska, Inc • : • This photo is copyright by ConocoPhillips Alaska, Inc. ...„ ''''' i and cannot be released or published without express written consent of . - ConocoPhillips Alaska ..t 0 s, THE STATE Alaska Oil and Gas 7 S °f ALA� Conservation Commission GOVERNOR SEAN PARNELL � *h , 333 West Seventh Avenue ( P. Anchorage, Alaska 99501 -3572 AL P` Main: 907.279.1433 Fax: 907.276.7542 MJ Loveland WI Projects Supervisor © J 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1C -127 SCANNED JAN Q�. Sundry Number: 312 -409 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. 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 reconsideration. A request for reconsideration 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. Sincerel, 0� ►•rm•n ommissioner DATED this j day of November, 2012. Encl. • • ConocoPhillips OCI r 1 Abe Alaska P.O. BOX 100360 E : ANCHORAGE, ALASKA 99510 -0360 October 20, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1C -127, PTD 201 -114 surface casing inspection and repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, mss I ' MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool F.. Repair well r; Change Approved Program (""' Suspend r Rug Perforations r Perforate r Rill Tubing r `P‘v Time &tension r Operational Shutdown r Re -enter Susp. WeII r Stimulate r Alter casing ft. Other: SC sleeved repair P 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201 -114 • 3. Address: 6 . API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23024 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 1C -127 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025649 ' 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): 6450 • 4270 Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158' 158' PRODUCTION 6400 11 6439' 4260' r i ii a •-a,,, .e, _¢, . I, I 1 s 3 2 0 17 di t`-. ; fi -, 4 v . Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5864 -5904, 5934 -5970, 5983 -6003, 6022 3700 -3738, 3766 -3800, 3813 -3832, 3850 -3866, 6038, 6048 -6070, 6112 -6134' 3875 -3897, 3938 -3959' 3.5 L - 5995 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER MD= 5830 TVD= 3669 No SSSV 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch C Exploratory (°' Development ]" Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/15/2012 Oil r Gas r WDSPL r Suspended r! 16. Verbal Approval: Date: WINJ 17 GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name MJ Loveland Title: WI Projects Supervisor ,/ - /- Phone: Date / U . / � /_ Signature r / j /.. ,'-" sr> u / ' - Commission Use Only Sundry Number:31 2 , vo l Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: pho ta do cvvv7 C - v/ rzp 5 Subsequent Form Required: d o ,/ APPROVED BY 11 /� I v (N; k � �, "', - d �co OCT 9 OMMISSIONER THE COMMISSION Da (( �� ( l -1 ' orm 03 Revised 1/2010 a J X31 I! 2 � Subm ' D \ It,,, iG1NAL / L N .� , /�-- ti • • Conoco Phillips Alaska, Inc. Kuparuk Well 1C -127 (PTD 201 -114) SUNDRY NOTICE 10 -403 APPROVAL REQUEST October 19, 2012 This application for Sundry approval for Kuparuk (WestSak) well 1 C -127 is for the repair of the surface casing near surface. This well is a single casing injector that was drilled in 2001. On 05/22/12 a surface casing leak was confirmed and reported to the AOGCC. ConocoPhillips would like to permanently repair the well with a welded patch. With approval, repair of the surface casing will require the following general steps: 1. Safe -out the well as needed with a tubing tail plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Excavate wellhead location as needed to repair leak. 4. Remove the previous sealant treatment from the conductor. 5. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 6. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Then start removing conductor to find damage to surface casing. Notify AOGCC Inspector for opportunity to inspect. 7. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 8. If a patch is required, QA/QC will verify the repair for a final integrity check. 9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to service. 13. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 10/19/2012 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 15, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANN FEB 2 5 2 RE: Plug Setting Record: 1C -127 X13 Run Date: 6/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -127 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23024 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com J I Date: ! %. Signed: r �'G • • lit iC -/z7 Pr6 Z01 Regg, James B (DOA) ``o From: NSK Sent: Tuesday, Mn Problem 2, 012 8:06 A M conocophillips.com] �f Z To: Regg, James B (DOA); Schwartz, Guy L (DOA) 7" 5I Subject: 1C -127 (PTD 201 -114) Report of failed MITIA on 05 -21 -12 Attachments: 1C -127 schematic.pdf; 1C -127 90 day TIO.ppt Jim, Guy West Sak injector 1C -127 (PTD 201 -114) failed a diagnostic MITIA yesterday (05- 21 -12). The leak appears to be shallow based on fluid flow into the conductor during the test. In the course of pressuring up the IA, fluid flow became visible when they had reached 150 psi, at which point the test was aborted. This is a single casing well and was recently returned to injection after being shut in for a couple of years for reservoir management. Slickline will be securing the well with a plug this morning and further DHD diagnostics will be pursued (to include but not limited to MITT and casing leak detect to pinpoint leak location). The well will remain shut in and appropriate paperwork filed when a path forward is determined. It will also be added to the monthly report. Attached are the schematic and 90 day TIO plot. ✓ Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 Well Name 1C -127 Notes: Failed MITIA Start Date 2.22/2012 Days 90 End Date 522,2012 Annular Communication Surveillance 1400 - yvriP 120 IAP OAP 1200 - WHT - 100 1000 • - 80 800 U. 1. -60 N 600 - 40 400 200 - 20 0 0 • Feb -12 May -12 f ■ 111 - Do 251 �r 61431 —PWI • 211 SWI • • 151 ∎ B , LPD ✓ ' = 111 SI 1 � Feb -12 Mar -12 Apr -12 May -12 Date y KUP 1C-127 • COnOCU 'IIIpS Well Attr Max ,; b ° Ie t 11k !S r 1f Welibore API /UWI Field Name Well Status Ind C) , MD (ttKB) Aot Bt. (MG) 0 - y 500292302400 WEST SAK INJ 66.62 2,600.00 6,450.0 • Comment H2S (ppm) Date Annotation End Date K8-Ord (ft) Rig Release Date ° wen conga 1c - 127 2/2612012212'350-55 , SSSV: NIPPLE Last WO: 46.29 7/2/2001 Schematic -Actual ` 7. : Annotation Depth (ftK8) End Date Annotation Lest Mod ... End Date Last Tag: SLM 6,204.0 2/18/2012 Rev Reason: TAG , 2/26/2012 HANGER, 36 i „v` iCasln. S - - w ",--2„,,,' ' ) h Casin Description S t ring 0 ... S ID . Top (mg) Set Depth (t... Set Depth (1 ... String Wt... String ... String T op Thrd CONDUCTOR 16 15.062 40.0 158.0 158.0 62.50 H-40 WELDED � : Casing Description String 0... String ID ... Top ( Set Depth (C.. Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 75/8 6.875 39.5 6,439.3 4,259.9 29.70 L -80 BTC -MOD 8 625x7.625' � ' . rx , Tubtria Stet; - _, 411 Tubing Descripbon String 0... String ID ... Top F T., 8) Set De (1 S et Depth (N ... String Wt_, String .. String Top Thrd It TUBING 3.5 x 2.875 31/2 2.992 5,993.0 3 822 3 9 30 L - EUE MOD ®t` Q11 a ~ v' i 4 . ( 7+ { fry; i �_ ' Top Depth _ (TVD) ToP Ind Item Descriptlon Comment ID (in) 35.7 35.7 -1.99 HANGER VETCO GRAY HANGER 4.500 CONDUCTOR, 500.9 500.4 6.38 NIPPLE CAMCO DS NIPPLE 2 40 teeReee 5,829.5 3,668.4 11M1XO BUSHING 3.500 5,830.3 3,669.1 22.62 PACKER BAKER PREMIER PACKER 4,500 1 NIPPLE, 501 5,902.4 3,736.3 19.96 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.812" DS PROFILE (CLOSED 2.813 11/7/2008) 5,920.0 3,752.9 1 9.32 PACKER BAKER S -3 PACKER 3.875 5,958.5 3,789.2 77.90 SLEEVE -C BAKER CMU SLIDING SLEEVE, 2.75" D PROFILE (CLOSED 9/21/2003) 2.750 5,974.3 3,804.6 16.51 SEAL ASSY BAKER 80-40 NO GO LOCATOR SEAL ASSEMBLY w/ 1/2 MULE SHOE 3.980 5,978.0 3,808.1 16.38 PACKER BAKER FB-1 RETAINER PRODUCTION PACKER 4.000 GAS LIFT. 5,980.7 3,810.7 MILL BAKER MILLOUT EXTENSION 4.500 5.771 1St 5,986.1 3,815.8 16.09 XO Reducing CROSSOVER 3.5 x 2.875, ID 2.441, 96.5, L -80, EUE -MOD 2.390 5,990.8 3,820.3 • NIPPLE CAMCO D NIPPLE w/ 2.25" PROFILE 2.250 5,992.4 3,821.8 WLEG BAKER WIRELINE GUIDE 2.380 Bha PACKER, 5,830 Top (TVD) Btm (TVD) Cnna Top (ftK8) Btm (ftK8) i (ftK8) (ftK8) Zone Date (eh••• Type Comment 5,864 5,904 3,700.2 3,737.8 WS D, 1C-127 8/4/2002 4.0 IPERF 33/8" HDS 5,933 6,003 3,765.0 3,831.9 WS 8, WS A4, 8/3/2002 4.0 IPERF 3318" HDS 1C -127 5,934 5,970 3,766.0 3,800.5 WS B, 1C -127 8/4/2002 4.0 RPERF 3 3/8" HDS 6,022 6,038 3,850.1 3,865.5 WS A3, 1C -127 8/3/2002 4.0 IPERF 3 3/8" HDS IPERF - 6,048 6,070 3,875.2 3,896.6 WS A3, 1C- 127 8/3/2002 4.0 IPERF 3 3/8" HDS 5,864 - 5,904 GAS LIFT. 5,882 t 3 6,112 6,134 3,937.7 3,959.2 WS A2, 1C- 127 8/3/2002 4.0 IPERF 3 3/8" HDS SLEEVE -C 5,902 PACKER. 5.920 v � I - , .. , -:_ . _ GAS LIFT, 5,938 - PERF, 5,934 - SLEEVE -C, - 5,968 T i' ._ PERF 5,933 -B,IX13 -Am - _ 5,974 PACKER, 5,978 _ MILL,5,981 ft y - - i TI- NIPPLE, 5,991 WLEG, 5.992 - . I Y - ;. ` =i ms s.„- ,,*; _ _ + 0 :.. Top Depth Top Port (NO) I ntl OD Valve Latch Sire TRO Run Stn Top (8K8) (ftK8) (°1 Make Model (In) Sery Type Type ON (psi) Run Date Cm... IPERF. - ." 1 5,777.0 3,621.2 24.59 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/17/2002 6,022 - 6,036 - . 2 5,881.8 3,716.8 20.72 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/5/2002 IPERF• 3 5,938.0 3,769.7 18.65 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/5/2002 IRF, 6,11 -6,134 I PRODUCTION 8.62507.625 ", 40-6,439 TD, 6,450 • MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~q ~ ~G `S (~ ~ 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-127 KUPARUK RIV U WSAK 1C-127 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~ Comm Well Name: KUPARUK RIV U WSAK 1C-127 Insp Num; mitJCr100523173943 Rel Insp Num: API Well Number: 50-029-23024-00-00 Permit Number: 201-114-0 Inspector Name: John Crisp Inspection Date: 5/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1C-127 P.T.D zoluaa Type Inj. TypeTest N'TTVD ~ 3669 / IA SPT Test psi lsoo , OA o _ zzzo ~' ztzo zloo Iriterval4YRTST p~F P / Tubing 893 ~ 897 894 893 Notes: 3.7 bbls pumped for test. Monobore injector. No problems witnessed. ~ r, "(j~,i grN Tuesday, May 25, 2010 Page 1 of 1 • • ~ ~~ ---___ ,. .i.~ ~ ~~ ~ ~~~~~ ~~oAc~ive Diac~rv~srie ~~etent~s, ~ivc. Ta: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTf] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the tollowing : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 1~0 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) MTT Report 15-Jun-09 1 C-127 1 Repor~ 50-02~2302400 2) (~~L' ~U~-~~~( } -+~ ~, ~f,~ ~: ~~~~ ~~,~-+,"~c~~~'~r~.~ u 111. r~ ~ . ~ Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AfRPORT RD SUITE C, ANCH012AGE, AK 99518 PHONE: (907)245-8951 FAx: (907~245-88952 ~-AflP11L : ;_ __ . ~ w _ ~ _. '~ ..:~~ _ ._ _ ~-= INEBSITE . ~~ _ ~ C:~Documenis and Settin~\Ownet~Desktup~Transmit_Conoco.docx / ~ . . Memory Magnetic Thickness Tool ~ Log Resufts Sumr~ary _, Company: ConocoPhillips Aiaska, Inc. Well: 1C-127 Log Date: June 15, 2009 Field: Kuparuk Log No. : 10560 State: Afaska Run No.: 3(2nd MTT) API NO.: 50-029-2302400 Pipe1 Desc.: 3.5" 9.3 Ib EUE 8rd MOD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 210 Ft. (MD) Pipe2 Desc.: 7_625" 29.7 Ib L-80 BTCMOD Top Log Intvl.: 134 Ft. (MD) Pipe2 Use: Production Casi~g Bot. Log Intvl.: 210 Ft, (MD) Pipe3 Desc.: $.625" 36 fb N-80 511 Hydril Top Log Intvl.: Surtace Pipe3 Use: Production Casing Bot. Log Intvl.: 134 Ft. (MD) Pipe4 Desc.: 16" 62.5 Ib. H-40 Welded Top Log Intvl.: Surface Pipe4 Use: Conductor Pipe ~ot. Log IntvL: 158 Ft. (MD) Inspe~tion Type : Corrosive 8 Mechanical Damage /nspection COMM~NTS : This MTT dafa is tfed into tbe Mandse/ Hanger ~ 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MagnetiC Thickness Tool responds to the total metai thickness of the 3.5" tubing, 7.625° casing, 8.625" casing and 16° conductor pipe vwithin the logged interval. Passes at SHz, BHz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz and 8Hz passes selected for analysis in this report. CQMPARISON TO PREVIOUS MTT LOG RESULTS : A comparison of the current 10Hz pass to the previous 10Hz pass (December 11, 2006) indicates no significant change in metal thickness during the time between logs, with the exception of a slight decrease over the interval ftom 17' to 28'. A log plot overlay of the average metal thicknesses recorded by #he MTT for the current and previous logs is inctuded in this report. An area of inetal loss beiween 12' and 17', betow the mandrel hanger, appears to show similar metal loss to the previous log over this interval. As indicated in the previous log, the current MTT recordings indicate a si~nificant dec~ease in metal volume at the Cross-over between the 8.625" casing and 7.625" casing (94' - 9$'), and increased metal volume over the inteNal of the first 3.5° tubing joint. The MTT indicates a higher metal volume over the interval of 7.625" 29 Ib. L-80 casing than it does over the interval of 8.625° 36 Ib N-80 casing. This is believed to be due to the M7T responding differently to L-80 grade pipe (of the same weight) than to N-80 grade pipe. During processing of the MTT data from the 2006 tog, separate calibrations were not applied to the interval that includes both 8.625" ca5ing and 16" conductor pipe, the interval below the 8.625" casing and within the 16" conductor pipe, and the interval below the 16" conductor pipe. The calibrations taken w~hin the conductor pipe intenral were applied to the entire log interval. In order to support a more consistent comparison, the previous data set vwas te-processed using separate c~librations for each interval. The current data set was processed similarly - using separate calitxations to represent the undamaged pipe in alt three intervals. This allows for a consistent comparison of the entire log intenral for both data sets. ProActive Diagnostic Services, Inc. / P.Q. Box 1369, 5tafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281j 565-1369 E-mail: PDSamemorylog.com Prudhoe Bay Field Office Phone: {9Q?} 659-2307 Fax: (907} 659-2314 v~~ 2a ~-~~`~~ ,, ~ ' ~ , INTERPRETATION OF MTT LOG RESULTS : The MTT log results cover the interval 0' - 210'. Changes in metai volume are relative to the calibration 1 points at 66', 906' and 166', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing, 8.625" casing and 16" conductor pipe. A maximum overall metal volume loss of 15% is indicated in joint 1(10' -18') in the 5Hz pass, relative to the calibration point at 66'. However, the 5Hz MTT pass indicates a general increase of +5°~ to +7% metal thickness over the interval (2' - 31'), which may be a more valid "undamaged reference" for the metal Ioss event indicated over the inteNal (10' -18'). Using the elevated uundamaged reference" of ~+12% in the 10Hz pass over this interval would indicate a metal loss of -9% over the intervaf (10' -18'). A log plot overlay of the average metal thicknesses recorded by the MTT for the SHz, 8Ha, 10Hz and 12Hz passes is included in this report. The spread in tool response at different frequencies over this interval (10' - 18'~ suggest the metal loss over this interval is associated with the outer layer strings of the concentric pipe. Log plots of the full 5Hz and 8Hz passes are included in this report. lntervals of overall metat loss indicated within tne 8.625" casing and 16" conductor pipe interval in the 8Hz pass are as follows: A 2°~o circumferential metal loss is recorded in the interval between 10' -18'. Intervals of overall metal loss indicated below the 16" condudor pipe interval in the 8Hz pass are as follows: A 1°~ circumferential metal loss is recorded in the interval between 158' -163'. Over the key event interval of (10' -18'), the ma~cimum indicated overall metal loss by the four recording frequencies retative to the calibratiun point at 66' are as follows: 5 Hz -15% 8 HZ - 2% 10 HZ - -4% 12 Hz - -7% The percent circumferential metal loss expressed in this summary is a percentage of the total metat that the tool is responding to, which may include influences from the 3.5", 8.625" and 16" pipe. ff all of #he metal loss is speci~ic to the 8.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal Ioss indicated could be from either the 3.5" tubing or 16" conductor. ~ield Engineer. G. Etherton Anatyst: HY. Yang & J. 8urton Witness: R. Ober ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffard, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-maii: FDSru~memoryiog.cam Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 • Comparison to Previous M~Log Overlay 1C-127 P~~ o~,~+~ s~~„ i~. June 15, 2009 and December 11, 2006 Database File: 1c-127.db Dataset Pathname: 1/'I /1 /comp? Presentation Format: comparis Dataset Creation: Thu Jun 18 19:19:54 2409 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness 2006 (10Hz) (%) 50 0 Delta Metal Thicl<ness 2Q06 (1 ~0 Metal Thickness 2009 (1 4~ 60 80 ~z, 8Hz, 10Hz and 12Hz Passes Del~etal Thickness Overlay 1C-127 June 15, 2a09 PaoAedve DL~qwosrie Seaviea, Ine. Database File: 1c-127.db Dataset Pathname: 1/1/1/comp Presentation Format: comparis Dataset Creation: Thu Jun 18 19:11:46 ~009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2009 (12Hz) (%) 50 -50 Delta Metal Thickness 2009 (10Hz} {%} 50 -50 Delta Metal Thickness 2009 (8Hz) (%} 50 -50 Delta Metal Thickness 2009 (5Hz) (%) 50 0 2009 ~ ~ ~ ?009 (1C "?0 40 60 80 • , DMT 2009 (1~I-I~ DMT ~009 (1~f I~) DMT 2009 (8Hz - - `-~ DMT 2009 „___ -- Bottom of 8.625" 104 120 140 160 180 ~00 -50 Delta Metal Thickness 2a09 (1~Hz} (%) -50 Delta Metal Thickness 2009 (10Hz} (%} -50 De-ta Metal Thickness ~009 (8Hz) (%} -50 Delta Metal Thickness 2009 (5Hz) (%} of 16" Conductor 50 50 ~1 C-127 Recorded Magnetic Thickn~Log Data - 5Hz Pass (Surface to 210') June 15, 2009 P4wAedve Dlwqnosrte Seeviea, IMC. Database File: 1c-127.db Dataset Pathname: 5HzPass.1 Presentation Format: 1.8 scale Dataset Creation: Tue Jun 16 17:33:~6 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -5~ Delta Metal Thickness (%) 50 1.8 MTTP~1 (rad) 11.8 0 LSPD (ftlmin) 200 -7 MTTP1? (rad) 3 -- - _ - - , i , __ - .-6-r _ . ~ .---- =__ = ~ , ; ; : - - _ ~ - ine Speec ~' ~ f~~`t~'" ; ' ~ ~ ~ -= - - ___ __ _.. __ -- _ - - - - ` i i ~ - Tree - - ~ ' I I = '- --- , I ~ Hanger ` ~ ; -__ . _ - -. ~ ~ ~~- ~ ~ 3.5 " Tu bing Col lar I ~.~.. ° _~~ = R_625" Collaf . - - ~-_ ~- i ~-~ ~ ~ Delta Metal Thickness 15% Met al Loss Tubing Jt 1 . ~0 ~ , 3 5" T bi C ll . u n o ar ~ Pup 3.5" Tu bing Collar ' ~~ ` - ~ ~ ~ ~ ~ ' I Pup ` , 3.5" Tu bin Collar ~ ~ ~ ' •• ~~ ` .5 " Tu bing Co -~ llar:a -~ --- ~ i ~~ f ~` ~ - - ~~ ~ = Pup .;. " '" ~ ` ~ 6~5 " Collar , 5 Tu bing Co llar ~~ 60 ~ Tubing Jt. 2 3.5 " Tu bing Col lar ~~ - Bottom of 8.625" • .625" X 7.625" Cross-overs Tubing Jt. 3 ~% Metal Loss ~pp T Bottom of 16" Conducto 1~0 Tubing Jt. 4 •7.625" Casing Coilar 5" Tubing Jt. 5 % Metal Loss ~~ 5" -~--~}--{ 180 ---}- }-- -~ .625" Casina Collar Jt. 6 200 ~ i Delta Metal Thickness Line S e Delta Metal 7hickness (°/a) 50 1.8 LSPD (ft/min) 200 -7 MTTP01 (rad) 11.8 MTTP12 (rad) 3 90 ' __-gottom of 8.625" • .625" X 7.625" Cross-overs Tubing Jt. 3 r ,~ ' 11Q 3.5" Tubing Colla ~~ ' ~' ~ Bottom of 16" Conductoi 120 Tubing Jt. 4 130 ~ 4i-~7.625" Casing Collar> ~: ~ ~~ ' 3I5" Tubing Collar ' ' 1 % Metal Loss- ' , 3.5" Tubing Collar 150 ng Jt. 5 160 170 180 , 7 G25 " Ca sin Collar . 190 ~ Tubing Jt. 6 Delta M eta l Thi ckness ~ 200 Line Speed ' 3.5" Tubing Collar ' -50 Detta Metal Thickness (%) 50 0 Line Speed (ft/min) ?00 ~ ' 210 f 1 I j ~ ~ ~ ?.4 MTTP~1 (rad) 1~.4 -6.4 MTTP12 (rad) 3.6 KUP 1 C-127 . ConocoPhillips w~u WdBOr aa~c e ~ O am! En ~ an t~ a~ c! ro Act ) HI:~ti~.l.'~II / 5002 92302400 WEST SAK INJ PWI 66.62 2,600.00 6,450.0 Comm~ SSSV: t NIPPLE 0 e 7I12008 Last YVO: 4629 9 ~se 7/2l2001 a,~ e, 3 oN -,na~ y LastTa : RKB 6,246.0 1/1Y1009 Rev Reason: TAG de 1/2l2009 C aSf Sb i ce~n n~e IMI me (M+I Top oe~m Qucel sN oenm 9~1 ) s~rx~s wr I~tl a~ mra CONDI KTOR 7 6 15.06 2 0.0 158.0 158 .0 62.50 H~40 WELDED coNWCroa. COND UCTOR 85/ 8 7.82 5 0.~ 134.0 734 .0 36.00 N~0 571 Hydri i3a RFI PROD 7 5/ 8 .87 5 134.0 6.450.0 4.2 0 .5 29.00 L-80 C corioucroa. Tubl SUI 158 StMB St~YgW[ WVg n~oh g oescnano n MI 0~1 TuP I~al I~ei f~G lo~q Q'~ a iap itra TUBIN G 31/ 2 2.99 2 0.0 5,981.0 3,810 .9 9.30 L~0 Eue&dAAod NIPP~E.095 Ofha I n Mole All J : Tu Run 8 Ratrie Fish eLe. 00 (N~I Top YM Top Mtl( 6) (~8) (') Desvlpnat Cmv~t R~n oete ro cns uFr, 495 .0 494. 5 622 NI PLE CAMCO 0.5 NIPPLE 002 2.8 5 s,m 5,777 .0 3,621. 1 24.59 G AS LIFT CMACO/MMGl1.5/DMV/RK!!/ Co~m~ent: STA 1 1 2/ 72002 2.920 5,830 .0 3,6fi8. 8 22.63 PA CI~R BAKER PR MI PACKEA 8 I6I2002 3.875 PACNER.5.830 5,882 .0 3,717. 0 20. 2 1N JEC1'lON CAMCO/MWiGl1.5/DMV/RKN/Camtwt~t TA2 S I''.J200 2.920 6,902 .0 3,735. 9 19. SI. E-C BAKER C U SLIqNG SLEE W/2.61 Y DS PROFILE 8 /5IN102 2.812 . . (CLOSED 11A/2008) 5,920 .0 3,752. 9 19.32 PA CKER BAlC S3 PACKER Y2002 3.8~5 5,938 .0 9,769. 9 18.65 1N J TION CAAACO/MMG'1.5/DMY/RKl//ConrnenC STA3 & 5I2002 2.920 5,958 .0 3,788. 7 17.91 SI .E E-C BAKER CMU SIIDING SLEEVE, 2.75"'d PROFILE - & 002 2.750 iN.~cnow. s.esz CLOSED 9/212003 iv~RF, 5 974 0 804 3 3 16 52 LO CAT R AKER NO GO LOCATOR 8 /Gl2002 3 000 S.SBE3.90E , . . , . . 5,975 .0 3,805. 3 16.48 SE AL BAKER 80-40 SEAL ASSEMBLY W/ 1P2 MULE SHOE & Ci/20D2 3.980 ~~~~ 5,978 .0 3,808. 1 18.38 PA CKER AKER FBt RETAINER PRO CT10N PACKER 2002 4.000 59°2 6,981 .0 3,810. 9 16.2 Ex Omaa~ BAICER MILLO EXTE ION & 5f2002 4.500 5,986 .0 3,815. 7 16.09 X O & 5J2002 2. 5,991 .0 3,820. 4 15.92 NI PPLE CAAACO'D' N~P W/2.25' PROFILE 8 /92002 22 4 ;i .992 .0 3. L . 8 8A ll G ID 2 2. 80 PACKEN.5.920 ~ OIK ~D Rwl ~ Rwl oer~s T BOn P~S) P~N 2ar Die H~_ Qola roNt 5,66 4.0 5,9D4 .0 ,7002 3,737.8 WS D, 1C-127 BIU2002 4.0 IPERF 3 3I8" H0.S 5,93 3.0 6.003 .0 3,765.0 3,831.9 WS B. WS M. 8Pd/2002 4.0 IPER 3 3l8' HDS 1 C-127 5.93 4.0 5,970 .0 3, 66.0 3,800.5 WS , 1 -12 8! 4.0 RPER F 3 3/8' HDS M,fCTION, B,OY 2.O 6,038 .0 3,850.1 3.865.5 W3la, iC-727 &3l2002 4.O IPERF 33B"HDS 5~ 6,d1 8.0 6.070 .0 3, 75. 3.896.6 WSl3, iC427 8I3f2002 1.O IPERf 33B'HDS RPERP, g,~~Y.O 6,134 .0 3,977.7 3,9592 WSA2, 1C- 27 4.O IPERF 3318"HDS 5,93C-5 910 SLEEVE-C. 5,958 IPERF, 5,933-6,003 lAG1TOR, - 5,916 SEHL,5.975 - PACKER. 5.978 - ~ EktBnslM, 5,981 = _ X0, 5 HSft ~ JJINT - NBING.5,99] ~ - NIPPLE, 5.991 NLEG, 5,994 IPOtF, 6,0I28.038 IPFl2F. 6,618E.010 IPERF. 6.7116.13~ SURFiPROD. 6 650 TD 6a50 • • Jun 14 09 07:05Q PDS Inc 907 65923~4 PHIE.UPS Ala~it~, lna. ~ASlN~ Dk`T'AA. 8 ~!8° By 7 ~J8" p.5 SNe~I_ vC-'t2~ o~e-~: ~ 1 tl~ 1 PIiI~ES # tTEMS CidMPLET~ DRt~itPT10N ~ EtlIJ1PwMEM" l~1A1 1.ENtiTH D~P7Ff TO~S -5.98 iriABC1RS REG ?AbE RT TD I~W(~[GEf~ L.~S 40. 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CA3~1'+IG i~At~¢R SPAYZONE~ 7-~!"S', "'9 7~ 33. ~ 5868.59 P1~ 7-8J~' 29_7#~ L-~ B CC ~aIC~I3 CSG P{N X PIN1 ~ 2. f 3 BOd'1.84 •~s ~-ao ~-s~ 2s_~ ~.-~ ~arc r~ou c:s~ ~a~ ~a sa~a.~ FLUAT ~t?t.U4R, WEA7HERFflRD M(3DEL d~Q2 i~.0 6349.81 ' 1- 2 7'-5J8' 29.T#, L-~ t3TC ~ CSG B4X X P~N ~i7 6351_17 FL~AT SHf~ WEATHERFOF~ MOQEi. ~13 i:~U 643T_78 C~4SNd; ~ SFIOE -a 54.~.428 T{3~At. iaEPTH -a 84~OA0 Baker Loc bc#fom 3' } Pin end of Jt ~4 i 7-518" X it?-fP2' BOW SRRIAIG CENZRA~.lZ~R flIV SHQi~ J'C' 1iN13TO E+ RAd ~ 1 T-518" X tc--ifz~ ~1hr SPFtING GENTRA~.¢~R ~1.1 #' Br~_ZOw FLT CLR ~ ~ ~ 22 7-5~' X 10-112" BE?W SPR~[~ CENi' Ji'S 3 TH~iU 25 ~ 7~' x~c~vz- ec~nr s~r~uv~~ c~+rr ~r~ ~t~i~ ~r, x~.~~,3a.~~ 40 ~i649~. ~8.81.84~&7,7f3,73.7578828 $8,$'! 94 7100t(}3'fQ6,4~9, 11~1'i5,9i8,122 2 7-~J8` ~ 30-7Q" S~DW St~Riil~ ~'1' OAi ABQ1/E &~:LUW Ti3M F+'~Rf CC1~k AR • Z y~~5/B" )t 10-'Et2" BCriM SPRII~G CENT ON CtRS TC?P 8 tsTM OF ECP '-' TiDTAL 9 BQW BPWI~tG C~N1'RALI,22ERS .~.. Rernerks: ~ W~ w~h 6lvcks; 265# UR.1~ Qn, T5~'k 8t~oclcs. Ran ? 48 Jis 7-SF8 8 2~ts 8~' c~. dri(~ad c~ 6 75` & ltas' wI 7.717' dastic ~ft. tksed A~ Gr~de API Mof?t'ied tdo l.:ead thread comt~lQ oR 8~ c~1q8~dr-s. T __T NA80RS J4ig #29~6E Dr~1t{~ 5tt~rviaor.• t30N i~~ESTE'hl~R~1NVJE.[E RiZEK .!un 14 09 Q7:06p PQ5 Inc ~ sa~ s5s~ p.~ 5 , PH#L~.~P~ ~laska~ Inc. Ats~,tis'~ry of PtitLtWS PEBOtEt~,t CGW.f~4N1' CASqiCiTALtY PACsE: 1 bf 2 Ylt~J.~ NUh~R: tC-1Z7 RiC~: Pl~aara 2~E TUBING [f~'TI{ri+t: S.'!ti', 8.3~f L-S~, EUE~B R~af Tubitog E]ATE: 98105102 Colur~ 1 CaiuiNn 2 CoGuna 3 Calumn 4 CoMmn ~ Ca~min ~ Cohuae~ 7 Cnhu~an 8 No FerE [~ Feet No Faa~t Ffo Fess Ho Fe~t Uto f~sat No ~ No ~eet 1 3b 97 26 3L4i 51 31.~i 78 3i.34 i0t ~1.37 iZ6 Si.34 157 3~.3~i 17fi 31_38 2 31:42 2T 31.~? 52 31.36 77 31_36 4D2 91.38 127 31_39 152 31.41 1TT 37.38 ~ 28.69 ~ 81.42 53 31.dU 78 39.42 1U3 31.35 i29 31.36 f53 St.3d 178 31.28 4 St.33 22 31.39 54 31.34 T9 30.3& 9fl4 3i.4i !29 31.34'i 154 31.4~1 178 31.MR 9 3"1.32 30 31.38 55 31_-0~ S(3 3~.33 ill5 31.37 1~ 31 d2 1~ 89.3ti '!8p 3t.3F 6 297$ 39 31~7 56 3S_39 81 3t.35 1(16 31.3b 931 31.37 1~ 37.3fi 181 34.29 7 31_36 32 31.3fr 57 31.37 E2 31.93 107 31A5 i3Z 31.~ t57 31.33 182 31.44 8 31.36 93 81.~ 58 3t.43 $3 3i.48 1~ 31_39 133 3l.43 1~ ~f.33 183 9i 34 ~ 3G9Q 3~4 ~~1.35 59 31.~5 84 31A7 t~ 33.43 't34 31.3& SS9 31_3'7 184 31.37 f0 3~.30 3S 31.35 Stf 31_4O S~ 31.37 iS0 31.44 435 31.44 46~ 31,3: 985 4i 31.45 36 8i.42 61 31.38 86 31.38 t19 3t.41 139 3i.3~ t$7 31.3i 18B t2 3~.38 37 3Q29 62 31.3T H7 31.42 112 31.q2 137 31.3& ?82 8'I_3:i 287 i8 31.39 38 51.37 63 8~.3Q 88 31.43 'f13 31_39 13B 3i.37 t63 30.2~: 9$8 14 31.38 ~9 31_34 64 31.42 89 3i.43 114 3t.A3 T39 31.37 184 3'i.~' 1~ 45 31.9U 4Q 31.34 ' 65 31.34 EO 31.38 115 3i.40 940 31.35 iSt3 343.'i 79Q 1B 3i.42 41 31A6 66 31.4~ 91 ~1.38 1'I6 31_4f '~44 39.43 f66 3i.~• 491 17 3t_37 42 3t.38 8T 3t,dU 92 3t,3? 917' 39.38 44'1 3f.39 46'7 31~ 1~2 '!8 3i.dd d3 35.31 f38 39_A& 93 3126 l1t3 9t.34 t43 91_38 168 31AEi 193 19 31.~8 ~4 ~d.20 BS S1~Sr 94 37.4i 1'19 31.42 l44 3t_35 1BH ~7~ 194 2~ 31_~ d5 34.47 7Et 31.39 95 3"1.40 12d 31.41 74.5 31.38 1i0 31.4fi 195 21 ~1.4:! 4$ 31.3~4 71 31.44 96 31.41 121 91.36 f4B 3f.A4 171 3t.39 !98 7'1 31.d5 47 51.~ 72 31.3B 97 81_4~ 122 31.3B 147 31,42 172 31.4C SQ7 ~ 23 31_34 48 31.31 7~ 31.3.5 9B 37.4t3 123 34?!d ide :31.38 173 31.~ t98 24 34.35 48 3I.32 74 39~34 ~ 31.38 124 ~tA3 149 .31_42 1T4 31_~ 799 25 85.36 50 3t.36 75 31.43 1DU 3f.43 129 3t.45 i''sD '3i.42 t75 3p.27 ZtKt 7ot TI~22 7~t 78207 To1t 784.58 '£ot 784_73 To# 786_O'- Tot ;'34.67 Tot 78U~t~i Tat ~2.2~J Tt7T/'~E. tL~iG~`}I 1'HS PA6E = 5762BZ IIIRECi"lOhiS; TOTAL JOEMTS T!~!3 PAfa~ m 184 41l"t 12.8ANH. N3C1" pup jas~# tek:wrha~tgar ~ 2.04' RlCS tn tbp han9et t[l3 = 3bskf~' HANGER = 2.A$' Jun 14 {39 dT.O~p , ~ - ''~ ' , ' ' ' ~ , ~ ~ , , i I ~ ~ , ( ~ ~ ' ~ ~_ i- ~ 3 , PDS Inc ~ 907 ~14 p.2 P}!lLLEPS ALASKA tNC. CASINGTAt1Y PAGE: 1 ot 2 ~~. -- t~itELE. H1UhtBER: 1C-727 fttti: NAf30f;S 245~ CaWrnn 1 Caluran 2 . Cotuo~rt 3 Coitlimn a ~ Geriumn 5 Co~~mn 6 Columr, 7 ~C~ure~~ l~ta E~eex t~ka Pe~ Na Feet Ho Feet No ~eet Na ` Feet !~a Fec:t Ata Fee~ 1 43.43 ~$ 43,38 51 39-61 76 ~3.25 101 42.54 t28 48.32 ~51 f76 2 43.54 27 42.91 52 42.54 77 +I2.39 102 41.75 't27 4a.92 '152 177 3 43.61 28 41.50 53 47 _35 78 d3.~2 408 43.53 12E 41 ~7p 153 178 4 d3.55 29 43.59 54 43.47 T9 d263 104 42_55 9Z9 43.59 t54 179 5 43.59 3fJ A3.S$ 55 ' 49.4fl ~0 d3.d5 1d5 93.d4 i30 4239 455 180 6 43.A3 31 ~4.3AS 56 d3.48 81 43.3fl 146 43_47 131 41.78 15S '}8i 7 43.45 32 39.64 57 d1.77 82 43.48 '!07 43.53 182 42.Ox 'F'S7 18? ~ d3A8 33 4i.75 ~ A3.d4 83 4Q.90 108 43.46 #33 d3.~d t58 183 9 42.3f~ 34 43A2 59 42.23 ~4 43.88 1#tQ 43.54 i3d d3.48 159 184 i0 41.9~ ~5 43.46 t~ 43.3l3 85 42.31 944 43.03 135 43,U;i 154 18S ii 43.45 3S 42.44 Sl 4Q.92 ~$ 42.7+~ 941 43A5 f35 43.37 161 13S 12 41.6$ 3i 4:3.5U 62 42.50 87 43.22 1'f2 d3_50 f3T 41.23 i82 1fiP i3 a2.d5 3$ d2S7 B3 43~2 8S 43_38 1'E8 4346 ~~ 42.8~ 469 188 1A A3~4$ 39 43.05 64 A341 8g 4225 714 43.47 13n A1.89 464 189 15 q3.d9 dQ d3D9 65 43.5D 8ti 43.46 7t5 43.50 'f4~0 43A$ 183 190 76 43.d4 $1 d3.5Ct 66 43_31 91 41.84 1t6 41.8$ '!81 AO.fiB 1~$ T91 17 40.?6 d2 41.74 6T 43.49 '92 42,93 11T 41.53 7a2 42.32 167 182 '18 43.39 ~3 d~ .~f 68 43.35 93 d2S8 11 B d3.A4 Od3 41 _d9 1$8 193 19 42.5~ 44 43.40 ~ 42.U3 94 43.52 119 4'~.63 i44 4'S.BU i~9 194 2Q A3.3~ 4S 43.5d 70 4~34 95 42~3 i2Q 43.~,1 1~4b 43.43 170 195 2i 41.62 +f8 ~1.fi2 71 43.83 96 d3_09 'f29 44.20 148 43.~ 171 19& ZZ 4124 47 ~1.5~5 72 43.39~ 9! ! 42.48 i22 40.84 147 472 197 23 43.43 48 ~43,57 73 43.4~ 98 ~ ~41_fi1 123 +61.14 !A8 '!73 19b 24 d3.l2 49 ~i3.5~t Td 39.45 96t ' +43f18 1?.+4 A3.37 t48 '!74 999 25 4~.~42 ~ 43.45 75 42.2~ 1dQ' 43.05 12S E 43.38 150 175 2tl0 'FOt 7D71,7S TW 1c~3~.'lt5 1oi 'IUt~r.~r ~a[ 7alu.tsts ~ot ~urU.is ~oc tsa~.w iaz Tt7TAl. ~ENG'lH 7HI5 PAG'~ = 623625 DIRECT~ONS: ~ T4ra~.lat,rrs nats p,aG~ = ~46 ! Oi Jun 14 09 07:Q5p Pt3S Inc ~ g~t~~~,~ p.4 ~ w.as~ca ~. c~s~r~ r~ ;~r PAGE ~s of 2 11~ LL NtAfiBES: tC~127 N3~ NA~SORS ?45E C~4$NG ~1~710N: T~6d6'~ 3fJ1R, L~9Q, BYG~iI W WITE. Ccinstr- i Cok~ovw 2 iGoM~ms a Colurtm d Coliaraa ~ <:Wtmnn ~ tC~ol~na- T Coionn B !Iv fcet NA Paet! ~o Fs~+t No ~E Na Feat !~b fwt No Fvet No FYet 1 A3.13 ?$ ~3.~ $~ 3D.81 Ti d3.26 !~1 43.54 12S =#3.32 ~S1 '!7t $ 43 54 27 ~12.91 62 +1~5d T7 4?.34 0$~ 4i.75 417 d0.82 75@ 177 3 4~.6't ~B A7.fi0 '.£i 47.9~ 78 R342 f0'1 4353 !28 • b1.70 157 i7S 4 4~.SS 7!! ~K~.51 ',i4 43.47 7! 42.83 764 42.5$ 1Z9 ~l3.59 1i~ 1T! S 4$.S1 ~ 13.58 65 A3iD AQ 43.45 ~.5 43.+i4 13Q i~.3~i1 156i 9'@ 6 ~0343 31 43.d6 '.~ 43.i8 6'1 ~8.38 1~6 43.~7 't31 ~11.7$ 1~8 ~i'1 7 43A5 3~ ~9.64 57 4177 82 43.A8 ~T +1~.59 182 ~ZA2 i57 13t 6 43.48 ~i 41.75 58 43.4~4 $S +10.90 '1!E ~i3.46 183 f3~14 iS8 1~ 8 42.~4 ~R d3.4Z 59 42?.9 84 4$.98 !08 43.84 434 't3A~ 4S9 ~~ 'lit 18 41.89 ~ i3A8 BO 43.5Q ffi 4234 1'EO 43.d2 !SS d311B 4iQ 't~S 11 +~+IS 3B ~.44 64 40.9Q 86 A274 ~~N! +t8.45 136 •43.3T i6t ~~ 1~IC t2 4~2.6~ '3f 43.50 6Z 92.Stt a7' ~t3.22 1'E2 43-50 13'l 31.23 i62 1tl is a~s ~s 4z.a~ es a~.s¢ ~ a~ t~a ~s.~ ~as r~.~ ~sa ~~ tt 4s~ ~ rt3.~ ss fs.st se a~ ~~e q.~r ~rss .~t.a~ iea tas ~s ~.a~ ~e ~ e3~.os as 4s.so wt aa,aas ~~~ 4*.so t~o ~.a~ ~gs rt~a ~6 a3,4t s1 as.so es f3.3f ~i s~_ea 1Y6 a~ ~~is ?4a ~tae t8~ ~s~ iT dA.76 42 41.?~ 67 13.48 !~'2 42.9Cf 1'17 4'l.a~i 14Y ~2.32 1B7 '!!2 !~ 43.39 x# <1~7 iE A3.9b !3 A2.86 748 +Ra[4 'l+13 ~1 A9 1~ 193 '!9 rl2S2 4t A3.40 ~ ~.09 !4 13.~ 1t8 41.68 'l4ri 11.80 769 '!'J# 2~ ~3.39 ~ 43.50 70 42.54 !5 4~73 12p {3.32 7A3 43.~f3 fY0 't!6 21 41.62 46 41.82 T9 43~G9 !~ #3.~8 42! 4i30 9A6 ~3.lX2 17"1 'f!B 22 4124 iT 41.55 7'~ 43~95 !7 42,{0 '122 40.64" 94T i7,~ ~!F 28 43+~3 AS +13.57 73 43„43 ~ 4i.~7 1t1 41.i4 1~8 t7~ t9R Y4 48.t2 !! ~3.St 78 384$ 83 43s4B 124 43.37 149 17.4 '!!s ?5 4+2.A2 36 ~,15 I5 4,2.20 100 43A5 428 43.96 150 1]~ 9fOD ~ 187'1.T9 Tot 1pB9.~8 7'ot Z085.7/ Tot A! LE[~1~1'N Tf~ P,~G1E = 623~ Ctl'AL.lUN~tS 7~IIS ~'AC~ _ 'F4$ 107{F.88 7at D~CTION~._ ~OTO_i$ TaR .~._..__.. ~84.d0 Tot ~ 7ot Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ANNE~ JUN ~ fi 200 Well Job # Log Description Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. I _____~ _ ___ _ _ 06/ 10/08 NO. 4741 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /q - (~ 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / _ / / t~ 06/03/08 1 1 16-10 11994672 PROD PROFILE/DEFT ~ 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT - 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3 - ~Po~~a/~ 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT /(pa.~~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT _I r ®( Lf 06/05/08 1 1 1C-125 11994677 p INJECTION PROFILE T - ~,~~~ 06/05/08 1 1 10-127 11994675 INJECTION PROFILE ~J - C. `~~/ ~ 06/03/08 1 1 1F-09 11994671 PROD PROFILE/DEFT -/ ®~c'~ 05/30/08 1 1 1C-27 11994679 SBHP SURVEY ~~ ®~C.f 06/07/08 1 1 • . . ~ ConocoPhillips Alaska ,JUL I) 3 2007 & Cons, P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 .. . 0 5 2007 Anchorage, AK 99501 SCANNED JUL ~b \ - \ \ 4- 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 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 Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. ~~ M.J. Loveland ConocoPhillips Well Integrity Supervisor e----/ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement cumced cement date inhibitor sealant date ft bbls ft na oal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1 C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 ~_ne 27" na 10 6/24/2007 i;,U";i;·; 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-51 02 ,-'r f. ~riit.~¡r·:;\n .~ ¡¡¿J\\11'J 5U,",¡) :L ö RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 t~ U --I ?' 1 J c~1 .<~~ ...".~", \.;\J~1~. 1) 1 Report 2) 1 Report 3) 1 Report 4) 1 Report 5) 1 Report 6) 1 Report 7) Signed: Print Name: 1C - 111 MTT Log 1C - 117 MTT Log 1 C - 127 MTT Log 1C - 133 MTT Log 10 - 114 MTT Log 10-117 MTT Log 1 0- Dec -06 u:r Q... ó)o I - I d 'fJ 11- Dec -06 UTe.. dOL-Ie I 11- Dec -06 U ~c....;;O 1- /I~I 12- Dec 06 U:r C- 861 - 6-::;''7- 08- Dec -06 U 1" c... lq"'õ - 15'ì 09- Dec -06 U:rc... \ DO -d37- ê.Jj~ ~/ h r ~¿¡ IÆ (L Ih (J, M VI V~1/1 Date: It)! lð!()~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E ..MAIL: :~ .JG),¡ ¡ C~~::J ;~~<3 -:=(ÔrH'=f".:1 :0;~"~"'~ '.:>è ~;;G~'J¡ WEBSITE: ·h'!è'''1.;VE~2J1C;R··/\..()G.·.;·'):v1 D:OO _ PDSA'IC·2006\Z _ W ord\DistributionITransmittal_ Sheels\Transmit_ Original. doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-127 Log Date: December 11, 2006 Field: Kuparuk Log No. : 8081 State: Alaska Run No.: 1 API No.: 50-029-23024-00 Pipe1 Desc.: 3.5" 9.3 Ib EUE 8rd Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 191 Ft. (MD) Pipe2 Desc.: 7.625" 29.7 Ib Top Log Intvl.: 134 Ft. (MD) Pipe2 Use: Production Casing Bot. Log Intvl.: 191 Ft. (MD) Pipe3 Desc.: 8.625" 36 Ib Top Log Intvl.: Surface Pipe3 Use: Production Casing Bot. Log I ntvl.: 134 Ft (MD) Pipe4 Desc.: 16" 62.5 lb. Top Log Intvl.: Surface Pipe4 Use: Conductor Pipe Bot. Log I ntvl. : 158 Ft. (MD) Inspection Type: Assess External Co«osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total metal thickness of the 3.5" tubing, 7.625" and 8.625" production casings, 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 (60'), 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, 7.625" & 8.625" casing, and 16" conductor pipe. The MTT recordings indicate less metal volume over the interval of 8.625" casing relative to the interval of 7.625" casing. The tool appears to have recorded an inverted response (indicating less metal) at the cross- over between the 8.625" and 7.625" casing at 96', which has been noted when the volume of metal surrounding the tool exceeds the tool's capacity. We believe this to be the case at this point, where the extra metal in the cross-over is exceeding the tool's capabilities and causing an inversion in the tool's normal response. Above this cross-over and throughout the interval of 8.625" casing, the tool continues to indicate less metal relative to the interval of 7.625" casing, but there are no obvious signal inversions at tubing collars throughout this interval. This points to the possibility that the extra distance from the tool sensors (of the 8.625" casing relative to the 7.625" casing) may be overriding the effects of the additional 6 Ibltt of pipe weight - resulting in an indication of less metal volume. The tool's response over the interval of the top 3.5" tubing joint generally indicates more metal than that in the pup joints and second full joint of 3.5" tubing. There are no noted casing changes within this interval, pointing to the possibility that the top joint of 3.5" tubing may have different metallurgic properties than the tubing joints below it. Within the interval of the top 3.5" tubing joint, there is an indication of general metal loss from 12' to 17' below the mandrel hanger and a more serious isolated metal loss event at 16'. No other areas of significant metal loss are indicated throughout the logged interval. Details of the tool recordings are included in this report. ProA.ctive Diagnostic Services, Inc. i P.O. Box 1369, Stafford, TX 77497 Phone: (281) 01 565-9085 Fax: (281) 565-1369 E-maii: PDS@memor-yiog.corr: Prudhoe Sav Field Office Phone: 659-2307 Fax: 659-231.4 u~ c.... 8C l - t 1<-( I . . I INTERPRETATION OF MTT LOG RESULTS : I I I I The MTT log results cover the interval 0' - 191 '. 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 2 intervals of metalloss. A maximum of (-18%) isolated metal loss is recorded at -16'. A (-5%) circumferential metal loss is recorded in the interval between 12' and 17'. The percent circumferential meta/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", 8.625" and 16" pipe. If all of the metal loss is specific to the 8.625" 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 I I I I I I I I I I I I Field Engineer: R. Richey Analyst: M. Tahtouh & J. Burton Witness: C. Fitzpatrick I PrOf'\ct¡Ve DiòfJnostic Sen/jces¡ Inc, /' P.O, Boy 1369, Stafforct TX 77497 659··23:l{1 I I I I I I I I I I I I I I I I I II I I <lac Magnetic Thickness T (10Hz Pass) F'omAcrIvE Ð!AqNOSTic SERvicES, INC. - Database File: d\warrior\data\1 0-127\1 0-127. db Dataset Pathname: 10hz.1 Presentation Format: 22SCAL -1 Dataset Creation: Tue Dee 12 12:29:142006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 - 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 MTTP12 (rad) 3.4 ._- - -20 .- ^^~--- -- -10 -- ~ Tree Ì""-Lìpe ~Pjd I Hanger Pup Jt ;3.5" Col ~--- ~I ~ -~-- 10 I-- '? I ~ f-- ....+-- Metal Loss - t1 Ii' f-- I I 3.5" f-- I Jt 1 . 18% Isolated Metal ..i - 20 - i--- -- I iF I ~..... 30 :L. ---=! Pup Jt. Pup Jt. "'TV Pup Jt. i Pup Jt. 5" Collar _ [ I - - -- - 60 - - ¡,.. f-- .~-- ...... 3.5" --- ~ Ji. 2 iø... --- ~^-~ 70 I~ - -:E'~ ,- IF . QIl ", <: ~ I- f_ I I I I I I I I I I I I I I I I I I I , =W- uv ! I r ~~ - -0.625" Casing Collar I 90 h - Ii ""~-- ;l .1 - - om of 8625" ¿V ¿ I t:: ''%í ~ .--=:' I 100 - 1 - 3~5" '- -' --o¡¡ r- - ~-- ., Jt 3 '..:1.5" Collar-= 110 '" -.- -- -~~-- - Bottom of 1 ~ Conductor ( 120 3.5" , Jt. 4 b ~ I' 1---..- -.. --~ I 130 -", -~ M__ I ---.......- ""- - 1-,- ~ 7.625" C31'ng, , ,..- 140 -.,.. I 3.5" Collar .......- ~ I s: f-... -. - 1f 150 ') - -...- _.~ '-"- _.~,~- 3.5" Jt. 5 ""- 1---.- -"" I "l .- I 160 I ~ - ') '%' "- -- ,"-- ~ , :00- I ~i ... -.. - 170 i:' ) I ?I - > I ;~ 3.5" Collar 180 l IT 1:. -~.. -. '- "":', --" F=; í~ 3.5" b -i.62(;' ~asi~g Collar ,.......> [.."::1::, .....þ .5 .> :~ -. - ,~ - Jt. 6 i I I , ( I \ \ \. .~. "' \:" \ \ End of LogJO , , , 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness ('Yo) 50 ·6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I ~ Magnetic Thickness T (10Hz Pass) PR<>ÁCfIVE D!AqNOSTlc SERvicES, "'c. Database File: d\warrior\data\1c-127\15% metal loss\1c-127.db Dataset Pathname: 10hz. 1 Presentation Format: 22SCAL -1 Dataset Creation: Tue Dee 1212:29:142006 by Cale Sondex Warrior V7.0 Charted by: Depth in Feet scaled 150 .. 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I I : I I J I 1 '"I Line Spee;:; I I Har;yer I I I Pup Jt I = 13+ bOllar .r I I I þ- ç < .;::= - r c < ,fi;, ~ "_::J ;:: ~ '- ~ ~ > 17 þ ( < ( .¡ ~ :J ~ I ( ì " 10 Þ 'l I ~ \ ( < ¡ LI' I? ~{ 1 I "-.- - I I :f ¿ ) / ¡ J ¿ if 1 .. 5% Metal Loss ( ., (~ fiT I 3.5" ?-1 ~\ > I l . 1 \..' I~ .~ 18% Isolated Metal L I ~ (r; t? .~ /, ~ >- .Lr- Jt. 1 > :1 ¡ I -,~ r"'" > r t---- ~ If ~ I 1(: - '" ~ 20 ~ . .. '" ,_. ."" :;;;.... ~ .: " '" < I'" ~..m 11 rl} """S ~';:;. ,~ "' - J. ~; - 'f '-¡ ..~ ~ .~ , .- '--..-- 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 I -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I I I TUBING (0-5981, 00:3.500, 10:2.992) I SURF/PROO (134-6450, 00:7.625, Wt:29.00) PACKER (5830-5831, OD:6.590) - Perf - (5864-5904) -- -- -.- -- -,. -- - - SLEEVE·O (5902-5903, - OD:4.550) PACKER (5920-6921, OD:6.650) - Perf - (5933-6003) -- Perf (5934-5970) -.- -- - -.- - -, SLEEVE-C (5958-5959, OD:4.520) - SEAL - (5975-5978, 00:4.000) - - -.- - -- - PACKER (5978-5981, - OD:6500 ) JOINT (5987-5991, OD:3.690) NIP (5991-5992, --- OD:3.670) --- - - - Perf - (6022-6038) -- Perf --- (6048-6070) -- Perf - (6112-6134; I I I I I I I I I I I I I I I KRU 1 C-127 11C-127 API: 500292302400 SSSV Type: Nipple Well Tvoe: INJ Orig 7/2/2001 Comoletion: Last W/O: Anole Fa) TS: deo (â) Angle @ TO: 10 deg @ 6450 Annular Fluid: Rev Reason: TAG, OPEN SLEEVE Last Uodate: 10/17/2005 Reference Loa: Last T aa: 6259 9/9/2005 ,:Ät.t Ref Loa Date: TO: 6450 ftKB Max Hole Anole: 67 dea (â) 2600 . tion CONDUCTOR SURF/PROD SURF/PROD 11"l.Il:Iif1(3Stril"ll''l'' IUðlNIii Size I Too 3.500 1 0 Size TOD Bottom TVD Wt Grade Thread 16.000 0 158 158 62.50 H-40 WELDED 8.625 0 134 134 36.00 N-80 511 Hvdril 7.625 134 6450 6450 29.00 L-80 STCMOD I Bottom TVD 1 Wt 1 Grade 1 Thread 1 5981 I 3811 T 9.30 I L-80 I Eue8rdMod Interval TVD Zone Stetus Ft SPF Date TVDe Comment 5864 . 5904 3700 - 3738 WSD 40 4 8/4/2002 IPERF 3 318" HDS 5933 - 5934 3765 . 3766 WSS 1 4 8/3/2002 IPERF 3 318" HDS "- 5934 - 5970 3766 - 3800 WSB 36 8 8/4/2002 RPERF 3 318" HDS '--- 5970 - 6003 3800 - 3832 WSA4 33 4 8/3/2002 IPERF 3318" HDS 6022 - 6038 3850 - 3866 WSA3 16 4 8/3/2002 IPERF 3 318" HDS 6048 - 6070 3875 - 3897 WSA3 22 4 8/312002 IPERF 3318" HDS ~~:Ì!!~~(S~ 22 4 8/312002 IPERF 3 3/8" HOS ~ Type V Mfr V Type VOD latch Port TRO Date VI" Run Cmnt 1 5777 36211 CAMCO I MMG I I DMY I 1.5 RK 1 0.000 r o /12/17120021 MD TVO Man Man Type V Mfr V Type V 00 latch Port TRO Mfr 2 I 5882 3717 CAMCO MMG 3 5938 3770 CAMCO MMG IOthêri rnIÚn!'l.iåi"lhin"t, /'IJ::\¡(¡£OV --- DeDth TVD Tlfne - 495 495 NIP CAMCO OS NIPPLE 5830 3669 PACKER BAKER PREMIER PACKER 5902 3736 SLEEVE-O BAKER CMU SLIDING SLEEVE W/2.812" OS PROFILE -OPEN 9/9/2005 5920 3753 PACKER BAKER S-3 PACKER 5958 3789 SLEEVE-C BAKER CMU SLIDING SLEEVE, 2.75" '0' PROFILE - CLOSED 9/2112003 5974 3804 LOCATOR BAKER 80-80 NO GO LOCATOR 5975 3805 SEAL I BAKER 80-40 SEAL ASSEMBLY W/1/2 MULE SHOE 5978 3808 PACKER BAKER FB1 RETAINER PRODUCTION PACKER 5981 3811 Extension BAKER MILL OUT EXTENSION 5986 3816 XO 5987 3817 JOINT 5991 3820 NIP CAMCO 'D' NIPPLE W/2.25" PROFiLE 5992 3821 WLEG BAKER WIRELlNE GUIDE DMY DMY Date Run 8/5/2002 8/5/2002 Vlv Cmnt 1.5 1.5 RK RK 0.000 0000 o o DescriDtion 10 2.875 3.875 2.812 3.875 2.750 3.000 3.980 4.000 4.500 2.390 2.441 2.250 2,380 - - - .-- - -- ~._- MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ' )-,' 1«;1;t:' :5/ l3lJ ( l ,te.,. DATE: Monday, May 22,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-127 KUPARUK RIV U WSAK IC-127 dJJ ~ - I tL¡- FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..'IPY:1- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IC-127 API Well Number 50-029-23024-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060508182938 Permit Number: 201-114-0 Inspection Date: 5/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! lC-127 !Type Inj. i W ! TVD 3669 i IA ] 450 I 1740 ] 1735 1720 1715 I P. T. I 2011140 ITypeTest i SPT! Test psi 1500 OA I I i ] ! -- I Tubing I 650 i 650 ! 650 650 I 650 Interval 4YRTST P/F P Notes 1.2 bbls diesel pumped. 1 well house inspected; no exceptions noted. Monobore injector. C'. ~-'.~'D""'·'I<\,~¡;¡.~r:.:~4 ('\J~1~L~t:,.c. ,. 2 rnr' o C _L'~J Monday, May 22, 2006 Page 1 of 1 e e ConocoPhillips Alaska, Inc. KRU 1C-127 1 C-127 API: 500292302400 Well Type: INJ Anale tã> TS: dea tã> I TUBING SSSV Type: Nipple Orig 7/2/2001 Angle @ TD: 10 deg @ 6450 (0-6981 , 00:3.500, Completion: 10:2.992) Annular Fluid: Last W/O: Rev Reason: TAG,OPEN SLEEVE I Reference Loa: 1 Ref Loa Date: Last Ucdate: 10/17/2005 Last Taa: 6259 I TD: 6450 ftKB Last Taa Date: 9/9/2005 I Max Hole Angle: 67 deg @ 2600 SURF/PROD CasinQ StrinQ - ALL STRINGS (134'{)450, Description Size Top Bottom TVD Wt Grade Thread 00:7.625, CONDUCTOR 16.000 0 158 158 62.50 H-40 WELDED Wt:29.00) SURF/PROD 8.625 0 134 134 36.00 N-80 511 Hvdril SURF/PROD 7.625 134 6450 6450 29.00 L-80 BTCMOD PACKER TubinQ Strina - TUBING (5830-6831, Size Top I Bottom 1 TVD I Wt I Grade 1 Thread 00:6.590) 3.500 0 I 5981 1 3811 I 9.30 1 L-80 I Eue8rdMod - - Perforations Summary Perf (5864-6904) - - Interval TVD Zone Status Ft SPF Date Tvpe Comment - 5864 - 5904 3700 - 3738 WSD 40 4 8/4/2002 IPERF 3 3/8" HDS - - 5933 - 5934 3765 - 3766 WSB 1 4 8/3/2002 IPERF 3 3/8" HDS , - 5934 - 5970 3766 - 3800 WSB 36 8 8/4/2002 RPERF 3 3/8" HDS - 5970 - 6003 3800 - 3832 WSA4 33 4 8/3/2002 lPERF 3 3/8" HDS - 6022 - 6038 3850 - 3866 WSA3 16 4 8/3/2002 IPERF 3 3/8" HDS - 6048 - 6070 3875 - 3897 WSA3 22 4 8/3/2002 IPERF 3 3/8" HDS - 6112 - 6134 3938 - 3959 WSA2 22 4 8/3/2002 IPERF 3 3/8" HDS - Gas Lift MandrelsNalves - - f-- St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv SLEEVE-O Mfr Run Cmnt (5902-6903, - ~ 1 1 57771 36211 CAMCO I MMG ¡ DMY ¡ 1.5 1 RK 1 0.000 0 12/17/20021 00:4.550) - r-- Injection MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt PACKER 2 5882 3717 CAMCO MMG DMY 1.5 RK 0.000 0 8/5/2002 (5920-6921, 3 5938 3770 CAMCO MMG DMY 1.5 , RK 0.000 0 8/5/2002 , 00:6.650) Other pluas, eauip., etc.) - JEWELRY - - Depth TVD Tvpe Description ID Perf (5933'{)003 ) - - 495 495 NIP CAMCO OS NIPPLE 2.875 Perf - 5830 3669 PACKER BAKER PREMIER PACKER 3.875 (5934-6970) - 5902 3736 SLEEVE-O BAKER CMU SLIDING SLEEVE W/2.812" OS PROFILE -OPEN 9/9/2005 2.812 - - 5920 3753 PACKER BAKER S-3 PACKER 3.875 - 5958 3789 SLEEVE-C BAKER CMU SLIDING SLEEVE, 2.75" '0' PROFILE - CLOSED 9/21/2003 2.750 - 5974 3804 LOCATOR BAKER 80-80 NO GO LOCATOR 3.000 - 5975 3805 SEAL BAKER 80-40 SEAL ASSEMBLY W/ 1/2 MULE SHOE 3.980 - 5978 3808 PACKER BAKER FB1 RETAINER PRODUCTION PACKER 4.000 - - 5981 3811 Extension BAKER MILLOUT EXTENSION 4.500 - 5986 3816 XO 2.390 - 5987 3817 JOINT 2.441 SLEEVE-C (5958-6959, - 5991 3820 NIP CAMCO '0' NIPPLE W/2.25" PROFILE 2.250 00:4.520) - 5992 3821 WLEG BAKER WIRELlNE GUIDE 2.380 - - I - - I SEAL - - (5975-6978, - - 00:4.000) - - - - - - - - - - - - PACKER (5978-6981, - 00:6.500) -i ~ -: - - JOINT - - (5987-6991, 00:3.690) - - NIP I-- (5991-6992, - I-- 00:3.670) - I-- - I-- - I-- - I-- Perf - I-- (6022~038) - I-- Perf - I-- (6048'{)070 ) - 1--. Perf - r---: (6112'{)134) : - e e -- .}..........-~. ·r··'·'······ ~. .. .":. ,"" . j.' .. (; -.. l' . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) ) Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us ~~ ~\\\\)S OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRUI 1 C-127 07/29/05 Rogers - AES aOI~ Ilif Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-127 Type Inj. N TVD 3,669' Tubing 0 2000 1840 Interval 0 P.T.D. 2011140 Type test P T est psi 1500 Casing 0 0 0 P/F F Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Well 1C-127 Type Inj. N TVD 3,669' Tubing 1840 2040 1970 1950 Interval 0 P.T.D. 2011140 Type test P Test psi 1500 Casing 0 0 0 0 P/F P Notes: Mono-Annulus Integrity Verification MITT with plug in tbg 2nd bump up Well 1C-127 Type Inj. N TVD 3,669' Tubing P.T.D.2011140 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: 1800 2050 2050 2050 Interval 0 0 2525 2450 2450 P/F P Interval P/F Interval P/F If t Or , .. '.E"c"~".\\ 1,:\lIG 0 ,) f_D,,J S" ö"" t\ N N !', ß-\ ~.,j J '.. · \"....,_:~(tph'. . TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 06/19/02 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 1C-127 07-29-05-2.xls '.~ (. .~" :> ,,,-.\ ''1 "',. .t~\I /I"V.J '-1 . DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Current Status 1WINJ S¡1 wi. ), )J ~,)J'~i I API No. 50-029-23024-00-00 /" ') ~\lLC ~- Permit to Drill 2011140 Well Name/No. KUPARUK RIV U WSAK 1C-127 Operator CONOCOPHILLlPS ALASKA INC MD 6450 -- --- Completion Status 1WINJ TVD 4270,... Completion Date 8/5/2002 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Cbcg Induction/Resistivity 7' ,1,/1> J,.øg/ Induction/Resistivity tv'"!) j..Qg.- Cement Bond Log Rpt LIS Verification ~ Cement Evaluation d.øg Gamma Ray ~C Lm'â8 Gamma Ray ~ Gamma Ray Log Log Run Scale Media No 25 Blu 1 25 Blu 1 5 FINAL 1 5 Blu 25 Blu 25 Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION ,Y(ß Chips Received? ~ Well Cored? Daily History Received? Formation Tops Analysis Received? '-Y/N- Comments: ---~~--_."-------.._.-.~._._~- ----->--- ~._---_._--~---_.- Directional Survey No -~-----~_._-_._--~~~ ~--~~-------._- (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received 158 6450 Case 11/20/2002 158 6450 Case 11/20/2002 5454 6320 Case 8/3/2001 158 6450 Case 11/20/2002 5454 6320 Case rJ.(,A:~ 158" 6450 Case 11/20/2002 158 6450 ~ 11 /20/2002 158 6450 Case 11/20/2002 Sample Set Number Comments Comments -----_._----~- 5454-6320 Color Print ìJ ('11 L- ,^L v~ ~---~---~._--_._-- ~N (j/N ~---------~-----~-- ~---~-------~. ----------~.._-----------_.__._-- - ---~--- -------------_._---------~ --- DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2011140 Well Name/No. KUPARUK RIV U WSAK 1C-127 Operator CONOCOPHILLlPS ALASKA INC MD 6450 TVD 4270 ;J::.~tion Date 8/5/2002 Completion Status 1WINJ API No. 50-029-23024-00-00 Date: Current Status 1WINJ UIC Y ~. ~ '~ïH-J.-\¡!L~l Compliance Reviewed By: ~--. ( MEMORANDUM (, State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner 1Jf;~' SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~l JV ConocoPhillips Petroleum Engineer. \( --0 ~ 1 C Pad d-~ 1C-127 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON. CONFIDENTIAL ~vP DATE: January 26, 2003 Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-127 Type Inj. S T.V.D. 3669 Tubing 1380 1380 1380 1380 Interval I P.T.D. 2011140 Type test P Test psi 1500 Casing 1000 2000 1975 1960 P/F f Notes: Pretest pressures obseved 15 min. & stable. Initial MIT. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details January 26, 2003: I traveled to ConocoPhillips Alaska's (CPA) monobore water injection well lC-127 to witness an initial MIT. Dennis Sauvageau was the CPA representative for the test, which was perfonned in a safe and proficient manner. The pretest pressures were monitored and found to be stable and the standard annulus pressure test was then perfonned with the well passing the MIT. Summary: I witnessed a successful MIT on CPA's water injection welllC-127 in the Kuparuk River Field. M.I.T.'s performed: 1 Number of Failures: Q Attachments: Wellbore schematic (1) Total Time during tests: 1.5 cc: MIT report form 5/12/00 L.G. MIT KRU 1C-127 1-26-03 JJ.xls 1/29/2003 -- CO_hIAIps_~ka, I"", TUBING (36$61, QD:3.5( (), 1~2,992) Pelf (!i8!i4-5904) Perf (5933-6003) Part (~) SEAL (597'505978. 00:4.000) PACI(ER (597Sôœ1, OD:6.500) JOI~-17 (5987.5991, OD:3.690) (' 01/28/0S( :45P P.0øs KRU 1C-127 1C-127.", . ~: 5OO2S2302400 VV~ITvøo~ INJ SSSVType: Nipple' ,.-. ,-' ~m Orlg 7/2/2001 Completion: Last WID: ~gle (fb TS: ' deg (lÏ! Angla@ TO: 10 deg @ 6450 . -Annular FlUid: R'ëv Reason: Tag, set PlUg, DMY bylmO Last ~pdBte: 1212412002 Reference Log: last Tag: 6281 La$1 Ta~LPate: 12/20/2002 Casing, $1rtng .. ALL STRINGS .00000ptJon Size CONDUCTOR 1.6..000 ."", $URF/PROC 6,625 SURF/PROb 1.625 Tubing $1I:It')á:.~~ rU,8IÑG :.~~~ .I'OJ": J, '§;m I ~~ I ~1 I ~L~~ë I Perforattons SummarY" Interval r ND 5864 - 5904 _u 3700-; ~'1~US 5933 - 593_4 37-65_-:.3766 5934 . 5970 3766 - :i80." 5970 . 6003 3800 . 3632 6022-6038 3850-3866' 6,~,8 - 6,0.70, 3875 - 3897 e11~.6134 3938.3959 GaauLlft'MãndrelsNalvæ St MD TVD Man Man Mfr Type 1 5777 36~ 1 C,AM~.P, U Y..C InJeçtlon MlndrelsNalves St MD ND- '''Man Man IItffr Type 2 5882' 3717 CAMCO MvG 3 ~!)38. 3770 CAMCO MI«iì Other l)IUQ9. eQulp..,.~~;'. JEWELRY Qo~b TY:D.. 'l'ype 495 495 NIP CAMeO DS N!~e~E,.,.. h h . 5830" -3669PACKêF{;.:BAKER:PREMIERPACKER _h- -.. .. 5902 3736 SLEEVE:O' BAKER CMU SLlOINGSI,.I;I;VI; w/2.812" D5 PROFILE 5920 3753 PACKER.:~E~,S,3eACKER ' . ,,".. ,5956 3759 SLEEVE-O BAKER CMl,I ~,L.\DJ~G.SLEEVE, 2.76" 'D' PROFILE 5974 :fão4 I.OCATOR BAKER Bo-50 NO GO LOCATOR 5975 ~,~O5- ,..sEAL BAKER BQ.:40' SEÄC Ã$$E;Mãl.. Y WI 112 MULE SHOE 5976 3808PACKER(BAKERFB1REJ~INERPRODUC"'ION. >ACÏ<~R $961 3811 Extonslon - BÃKER 'MIL-LOUT EXTENSION 5986 3816'" ""'Xc '5987 3817 JOINT 5991 382Ó"''''' NIP' CAMCO 'D' NIPPLE WI2.25" PROFILE' n.'--' 5991 3820 PLUG -2.25" cÄ2 PLUG SET 14t2.Q~_.oO.2 ,,., 5992 3821 wLeG 'e-ÃKER WrR¡¡¡I..IN~ GUIDE R(\f I..og Date: TO: 6450 nKe Max Hole Angle:, 67'deg cð! 2600 "Tõp 0 _.a ...... 134 TVD ""\\'."" 'G~ ' 'J:h¡:ead. 158 --'62':50 1-1-40 . WELDED 134 36..00 tiI:aÕ 511 HYdrfl (1450 29..00 L-80 BTCMOD Botb)m 158 134 645.0 Thread Eue8,dMod Zone Status Ft SPF W$ 0 40 4 WS B ,_n,_" 1 4 ~,B" 36 a WSAA 33 4 "'WsAã 16 4 VIIS A3 .,. ,~" 22 4 WS_/Sl.u, .. . 22 04 Oate 1'ypø Comment 8/412002 "'IPERF 3 3/8" !::IDS, . 6/312002 IPeRF 3 3/8~ HDS A/4J2062....R-I¡ï~R.F 33/8" ,",DS 8J3~Q.O,2 ' I~ERF 3 318" HOS 8/312002 IPI;:,RF .3,3/8" HDS 8r.i12002 IPERF' :3 3/B" t-IDS 81312002 IPERF~:f3/fi" HO$ V Mf,. V"ry.pã Ÿ OD Latch Port T~O Dato Vlv .. Run Cmnt 1.5 'm~'5..... 0.000 0 12/17~Q.Q2. OMY V Mfr V Typ~ V OD uich. r Port TRO Date Vlv Run Croo' RK .0.000 O. 8/5/2002 ~... RK O.''-OO''u .0 8t5~2D02 OMY 1,5 DMY 1.5 ...... ..m..,_..""... - ...........-.......,., ¡'D 2,875 3.875 2.812 3.1[~5_.. 2.750 3.000 3.980 . 4.000 4.500 2.390 .2.441 2.~.5.0 0,00.0 ~'2~3S0 Desc-:lp.~~ .... .,.. ,.-.-- ~'Tf~~H ~þ F !~~; m ~T ß~~ tç... id:1 I"'~~ -~~ ~J. ""~ (' Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: lC-127 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 160417 Sent By: Glen Borel Receive~{Jb~ dOl-lit.{ lid ~ '&1. BAKER HUGHES I!mT~-I.»iJlIUT:a:! -------";;"-:"::-;-~;;;¡.-¡;;------ _"II! -- .., :at, W\!8.', .. ...,.,.~ ... ~ ."1 ~;.: Anchorage GEOScience Center ~.,.. .-,,. .... . - .,. .:::< 10-0-. -.... IIIIœ .... :~-::., .~:-~... 1J"e'" _'! '" ." .'.' . ... .. .. -.-. - - -..-.. ---.---------- 8IC:":'". "'-.-.-.-.-.-,;.; Date: Date: Nov 19, 2002 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 NOV 20 2002 AJastœ o¡.¡ & Gas Cons. Commi8lìn Anchorage ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i:' èòMp,'~-ri~¡~' ~ . 1.000- ~v 'if: - 1639' FNL, 923' FWL, Sec. 12, T11N, R10E, UM ~ aärn .~ At Top Producing Interval ."... ." ~. ~Î). 2.':,.'... 302' FSL, 1338' FEL, Sec. 11, T11 N, R10E, UM ~' æ t (ASP: 559700, 5965240) At Total Depth ;' .' l .~" ¡: 234' FSL, 1381' FEL, Sec. 11, T11N, R10E, UM 'J.!....(¡¡!~1ò ,.-..",,.,J (ASP: 559657, 5965172) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKS 40.4 feet ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., S.usP. Or A~tnd. June 22, 2001 June 27, 2001 August~2002flJ> 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 6450' MD /4270' TVD 6350' MD I 4172' TVD YES 0 No D 22. Type Electric or Other Logs Run GR/Res, USIT 23. 1. Status of well Oil D Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Sox 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended CASING SIZE WT. PER FT. 62.5# 36# 29.7# GRADE H-40 N-80 L-80 16" 8.625" x 7.625" Classification of Service Well D Abandoned D Service 0 Water Injector 7. Permit Number 201-114/301-190/302-230 ~toèAtJcti! . ' ,. 8. API Number 50-029-23024-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1 C-127 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Land Nipple @ 495' 16. No. of Completions 1 21. Thickness of Permafrost 2020' MD CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 133' 133' 6439' AMOUNT PULLED HOLE SIZE CEMENTING RECORD 31 0 sx AS 1 640 sx AS IIIL, 455 sx Class G 24" 9.875" 9.875" included above 25. SIZE TUBING RECORD DEPTH SET (MD) 5981' PACKER SET (MD) 5830' & 5920' & 5978' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 5864' - 5904' MD 5934' - 5970' MD 5983' - 6003' MD 6022' - 6038' MD 6048' - 6070' MD 6112' - 6134' MD 3700' - 3738' TVD 3766' - 3800' TVD 3813' - 3832' TVD 3850' - 3866' TVD 3875' - 3897' TVD 3938' - 3959' TVD 27. Date First Production N/A Date of Test N/A Hours Tested Flow Tubing Casing Pressure pressure 28. psi Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. CORE DATA N/A Form 10-407 Rev. 7-1-80 3.5" 4 spf 4 spf 4 spf 4 spf 4 spf 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) " AMOUNT & KIND OF MATERIAL USED N/A PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injector Production for OIL-BBL GAS-MCF Test Period> Calculated W A TER-BBL CHOKE SIZE GAS-OIL RATIO WATER-BBL OIL GRAVITY - API (corr) OIL-BBL GAS-MCF 24-Hour Rate> CONTINUED ON REVERSE SIDE II Ra ~ ! ~j~ A L ~.,' I '1 ~'\ U .\ ! ~ i \\,:_\ Submit in duplicate '. '1 ~~ 5 B F L PJJ3 2 9 2002 29. { 30. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top D Sand Top B Sand Base B Sand Top A4 Sand Top A1 Sand 5861' 5932' 5970' 5970' 6209' 3697' 3764' 3800' 3800' 4033' 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 Vern Coyner 265-6074 Signed~~~ R. Thom~s - _Title K-f ,,-t-....,k 'b~t ll~ -, ""t ..,,-~- L~-...t e r Drilling EnQin88ring Su~rvisor Date --B r",¿c!ó (ò ~ lIþ1v 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 (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 :'\ ~ a ~ i L ~þ TfI7I ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/22/2001 6/23/2001 6/24/2001 6/25/2001 PHilliPS ALASKA INC. Operations Summary ,Report 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From -To Hours Code Code Phase 00:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 09:30 09:30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 06:30 06:30 - 09:00 09:00 - 12:00 12:00 - 23:00 23:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 05:30 05:30 - 06:30 06:30 - 07:30 07:30 - 12:00 12:00 - 12:30 12:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 07:30 4.50 DRILL RIRD PROD 1.00 WELCTL BOPE PROD 0.50 WELCTL SFTY PROD 3.50 DRILL DEQT PROD 14.50 DRILL DRLG PROD 2.50 DRILL OTHR PROD 1.50 DRILL TRIP PROD 2.50 DRILL PULD PROD 2.50 DRILL TRIP PROD 3.00 DRILL DRLG PROD 11.00 DRILL OTHR PROD 1.00 DRILL OTHR PROD 2.50 DRILL TRIP PROD 1.00 DRILL SURV PROD 2.00 DRILL PULD PROD 1.00 DRILL DEQT PROD 1.00 DRILL TRIP PROD 4.50 DRILL DRLG PROD 0.50 RIGMNT RSRV PROD 11.50 DRILL DRLG PROD 1.50 DRILL DRLG PROD 0.50 DRILL CIRC PROD 5.50 DRILL WIPR PROD 07:30 - 10:00 2.50 DRILL PULD PROD 10:00 - 10:30 0.50 DRILL SURV PROD 10:30 - 11 :30 1.00 DRILL TRIP PROD 11 :30 - 13:30 2.00 DRILL PULD PROD 13:30 - 15:30 2.00 DRILL TRIP PROD 15:30 - 23:30 8.00 DRILL DRLG PROD 23:30 - 00:00 0.50 DRILL SURV PROD 6/26/2001 00:00 - 13:00 13.00 DRILL DRLG PROD Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description .of Operéltions PJSM, UIU 20" DIVERTER SYSTEM. TEST KOOMEY UNIT & SURFACE TEST MUD EQUIPMENT. DIVERTER DRILL, SPUDISAFETY MEETING WIALL CREW & SERVICE PERSONNEL. BHA- ORIENT & LOAD MWD. TAG ICE & CMT @ 147', CLEAN OUT TO 161' , DRLD TO 1234', ART 2.8 HR, AST 6.5 HR. MWD FAILURE, WORK ON MWD & VARY SUR FACE MUD PUMPING PARAMETERS. POH, TITGHT SPOT @ 637' PULLED 25K OV E R. DOWNLOAD MWD & CHANGE OUT MWD. RIH, TEST MWD, TAG UP @ 615', WASH & R EAM THROUGH. DRLD F/1234-1460' ART 1.0 HR, AST .9 HR BRAKE ELECTRICAL PROBLEMS THROWING TRANSFORMER OFF LINE. CAREFULLY WO RKED PIPE AND CIRCULATED AT SLOW RAT E (2 BPM) WHILE TROUBLESHOOTING AND REPAIRING. RIG DOWNTIME. MWD PULSER FAILURE, ATTEMPT TO GET W ORKING BY CHANGING SURFACE PUMPING RATES, PRESSURES, ETC. PREPARE TO PO H. monitor well, poh, test mwd pulser sub faile d. download mwd & check bit. replace mwd pulser sub. orient bha & surface test mwd. rih, wash f/1373-1460', no hole problems. drld f/1460-1839', ART.6 HR, AST 2.7 HR service rig & top drive. drld f/1839-3329' ART 7.4 HR, AST 2.0 HR DRLD F/3329-3516' ART .9 HR, AST .25 HR CIRC BTMS UP, MON ITOR WELL, PUMP DRY JOB, BLOW DOWN. POH FIWIPER TRIP & BIT. WELL SWABBIN G OF 2ND STAND, PUMP OUT OF HOLE TO 1 478', POH W/O SWAB TO SURFACE. CHANGE BIT, LAY DOWN MWD PULSAR SUB & PROBE, SERVICE RIG. ORIENT BHA, LOAD MWD, SURFACE TEST M WD. RIH W/HWDP. PIU 27 JTS 5" DRILLPIPE. FINISH RIH, CIRCULATE BOTTOMS UP. DRLD F/3516-4542' ART 1.1 HR, AST 4.0 HR PULL UP TO 4260' TAKE CHECK SURVEY, R UN BACK TO BOTTOM. Directional drill 9 7/8" hole fl 4542' to 5290 , (748'). TVD 3245'. AST= 5.6 hr, ART=3.7 h Printed: 8/23/2002 3:46:23 PM ~~~ TfTfI ~~ Page20f 9 PHILLIPS ALASKA INC~ Operations Summary Report Legal Well Name: 1 C-127 Common Well Name: 1 C-127 Event Name: ROT - DRILLING Contractor Name: n 1268@ ppco.com Rig Name: Nabors 245 Date From- To . Hours Code Sub Phase Code 6/26/2001 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30 - 16:30 3.00 DRILL WIPR PROD 16:30 - 00:00 7.50 DRILL DRLG PROD 6/27/2001 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 12:30 0.50 RIGMNT RSRV PROD 12:30 - 22:30 10.00 DRILL DRLG PROD 22:30 - 00:00 1.50 DRILL CIRC PROD 6/28/2001 00:00 - 06:30 6.50 DRILL TRIP PROD 06:30 . 09:00 2.50 DRILL TRIP PROD 09:00 . 10:30 1.50 DRILL OTHR PROD 1 0:30 - 12:30 2.00 DRILL SFTY PROD 12:30 - 14:00 1.50 RIGMNT RURD PROD 14:00 - 19:30 5.50 DRILL TRIP PROD 19:30 - 23:30 4.00 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 6/29/2001 00:00 - 04:30 4.50 DRILL TRIP PROD 04:30 - 06:30 2.00 CASE RURD PROD 06:30 - 13:00 6.50 CASE RUNe PROD 13:00 - 14:00 14:00 - 16:00 16:00 - 17:00 1.00 CASE CIRC PROD 2.00 CASE RUNC PROD 1.00 CASE RUNC PROD 17:00 - 17:30 17:30 - 20:30 0.50 CEMENT RURD PROD 3.00 CEMENTCIRC PROD 20:30 - 21 :00 0.50 CEMENT SFTY PROD 21 :00 - 00:00 3.00 CEMENT PUMP PROD 6/30/2001 1.00 CEMENT DISP PROD 00:00 - 01 :00 01 :00 - 01 :30 0.50 CEMENTOTHR PROD Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 DescriptionotOperations Circulate & Condition hole for short trip. Monitor well, Pump dry job, POOH to 3400'. RIH. No problems. Directional drill 9 7/8" hole fl 5290' to 5625 , (335'). TVD 3492'. AST =7.1 hr, ART = 0.4 h r Directional drill 9 7/8" hole from 5625' to 59 25' (300') TVD 3755'. AST = 10.4 hr, ART .2 hr Service rig and Top Drive. Directional drill 9 7/8" hole from 5925' to 64 50' (525') TVD 4268'. AST = 5 hr, ART 3.2 hr Survey @ TD. Circulate & Condition mud and hole for trip @ TD. Monitor well, Pump dry job, POOH, no probl ems. Download MWD, PJSM, LID BHA PJSM, MU 8 5/8" casing hanger on landing j oint & run and locate in starting head. OK. LID Same. Quarterly Safety Assessment with Nabors & Phillips management. PJSM. Slip and cut 148' of drilling line. PJSM. MU hole opener, RIH, break circ @ 38 10', continue to bottom. No fill. Circulate and condition mud and hole for ca sing. Pump dry job, blow down top drive. POOH with hole opener for casing run. Continue POOH wI 9 7/8" Hole opener. LID BHA. PJSM. RU to run 7 5/8" x 8 5/8" casing. PJSM wI co. rep & Toolpusher. Run 7 5/8" c asing. Work through tight spots @ 2009'. & 2518'. Continue to run casing to 4339'. (Jt 1 00) Circulate & Condition mud and hole. Continue to run 7 5/8" casing (Jt 101-146) L/D Frank's fillup tool. Change elevators an d slips to 8 5/8". Continue with x-o, 2 joints 8 5/8" casing, hanger & landing joint. Land casing @ 6439'. RU cementing equipment. Circulate & Condition mud and hole for cem ent. Circ 1623 bbls. 16075 strokes. Safety meeting with all on cement job. Prim e u p for ce men t job. T est c e men t I i n e s to 4 0 00 psi. Load plugs. Cement 7 5/8" x 8 5/8" per cement program. Displace cement. Bump plug wI 1250 psi. Ch eck floats, OK. CIP 00:20 hr 6/30/2001. I n f I ate e x t ern a I cas i n g pac k e r wI .5 b b I s c e Printed: 8/23/2002 3:46:23 PM ~.. I'fIti ~~ ( (' PHilliPS ALASKA INC. Operations Summary Report. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/30/2001 7/112001 7/2/2001 8/2/2002 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From - To Hours, Code Code Phase 01 :00 - 01 :30 01 :30 - 02:30 0.50 CEMENTOTHR PROD 1.00 CEMENT PULD PROD 02:30 - 05:30 3.00 CEMENTOTHR PROD 05:30 - 08:00 2.50 WELLSR NUND PROD 08:00 - 11 :00 3.00 WELLSR NUND PROD 11 :00 - 13:00 2.00 DRILL OTHR PROD 13:00 - 14:30 1.50 DRILL OTHR PROD 14:30 - 16:30 2.00 DRILL TRIP PROD 16:30 - 21 :00 4.50 DRILL TRIP PROD 21 :00 - 22:00 1.00 CEMENTOTHR PROD 22:00 - 00:00 2.00 CEMENT COUT PROD 00:00 - 05:00 5.00 CEMENT COUT PROD 05:00 - 05:30 0.50 CEMENTOTHR PROD 05:30 - 07:00 1.50 DRILL CIRC PROD 07:00 - 09:30 2.50 DRILL TRIP PROD 09:30 - 13:00 3.50 DRILL TRIP PROD 13:00 - 14:30 1.50 DRILL TRIP PROD 14:30 - 17:30 3.00 DRILL TRIP PROD 17:30 - 20:30 3.00 WELLSR FRZP PROD 20:30 - 22:30 2.00 DRILL TRIP PROD 22:30 - 00:00 1.50 DRILL OTHR PROD 00:00 - 01 :00 1.00 DRILL OTHR PROD 01 :00 - 03:30 2.50 DRILL TRIP PROD 03:30- 05:00 1.50 WELCTL NUND PROD 05:00 - 07:00 2.00 WELCTL NUND PROD 15:00 - 00:00 9.00 WAlTON OTHR MOVE Page 3 of 9 Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description of Operations ment. Appeared to take fluid @ 2600 psi. PJSM. RID cementing equipment & casing eq uipment.. Blow down top drive. PJSM. Rinse out diverter system & flowline. Nipple down diverter. PJSM. Install Vetco/Gray quick disconnect h ead. Test to 1000 psi. Install tubing spool. Test to 1000 psi, OK. Install wear bushing. PJSM. NU 13 5/8" riser, adapter flange, rise r, flowline, turnbuckles, fill up line, and mou se hole. Change top drive and iron roughneck to work 3 1/2" pipe. Install bales & 5" elevators- move 5" HW to off driller's side of derrick. Change elevator s to 3 1/2". PU 7 5/8" casing scraper and (6) 4 3/4" drill collars. RIH. POOH LID casing scraper. PU Mtr. bit and (4) more 4 3/4" drill collars. PJSM. PU (72) joints 3 1/2" drill pipe. Rabbi t pipe and TIH. Run 33 stands from derrick. TOC @ 5798'. Circulate bottoms up at top of cement. Drill cement in 7 5/8" casing from 5798' to 6 003' . Drill cement in 7 5/8" casing from 6003' to 6 350'- PBTD. Circulate bottoms up. Displace well with 200 bbls water and then 2 90 bbls Seawater. Monitor well. PJSM. LID (45 joints) 3 1/2" D P. POOH wi 3 1/2" DP. LID BHA. TIH open ended wI 49 stands 3 1/2" drill pip e. Safety meeting. RU & pump 80 bbls diesel d own drill pipe. Let stabilize 15 min. then U- Tube. RID pumping equip. POOH, rack 49 stands 3 1/2" drill pipe on dr iller's side of derrick. Change over iron roughneck and top drive fo r 4 1/2" if (5" drill pipe) Finished changing grabs on top drive. Chang e saver sub to 4 1/2" IF, PU 5" elevators. Transfer 5" HW to driller's side of derrick. L ID 48 joints 5" DP from derrick. N/D risers & pull wear bushing. NU adapter flange and big bore valve. Rig r eleased @ 0700 hrs 7/02/01 for move to 1C- 117 (150' away from CPM) Prepare rig f/ move fl 1C-117 to 1C-127 (15 0' move towards utility module). Waiting on Printed: 8/23/2002 3:46:23 PM (~~ TfI'lI ~ Page 4 of 9 PHilliPS ALASKA INC. OperationsSummary'Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Date 8/2/2002 8/3/2002 Sub From~To Hours Code Code Phase 15:00 - 00:00 9.00 WAlTON OTHR MOVE 00:00 - WAlTON MOVE 00:00 - 03:00 3.00 WAlTON OTHR MOVE 03:00 - 05:00 2.00 MOVE OTHR MOVE 05:00 - 05:30 0.50 MOVE MOVE MOVE 05:30 - 06:30 1.00 MOVE MOVE MOVE 06:30 - 07:00 0.50 MOVE MOVE MOVE 07:00 - 09:00 2.00 MOVE MOVE MOVE 09:00 - 10:30 1.50 MOVE MOVE MOVE 10:30 - 11 :30 1.00 MOVE POSN MOVE 11 :30 - 12:00 0.50 MOVE OTHR MOVE 12:00 - 13:00 1.00 MOVE MOVE MOVE 13:00 - 14:00 1.00 MOVE RURD MOVE 14:00 - 14:30 0.50 WELCTL NUND CMPL TN 14:30 - 14:31 0.02 CMPL TN 14:31 - 17:00 2.48 WELCTL NUND CMPL TN 17:00 - 17:30 0.50 WELCTL OTHR CMPL TN Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Desçription qfQperations wireline work on well 1C-127 to be complet ed. Raise cellar box. Set mats. Load both modules on crib blocks. Perform rig maint. Waiting fl pre rig work to be completed on w ell 1C-127. Schlumberger WL through wI well @ 2330 hr s 8/2/2002. Pressure test FB-1 packer to 95 0 psi f/ 30 min. OK. Test complete @ 0100 h rs. RID testing equipment. Schlumberger rig ging down. At midnight, stilll need scaffold crew to disasssemble scaffold, also the rise r needs to be removed fl 7 1/16" valve. All work completed @ 1C-127 @ 0300 hrs 8/3/2 002. Waiting f/ wireline work on 1C-127 to be co mpleted. Pre rig work included perf, set FB -1 packer, test FB-1 packer to 950 psi fl 30 min. OK. RID Schlumberger, RID riser fI Sch lumberger, rig down test pump, remove scaff olding. All work completed @ 0300 hrs 8/3/2 002. Rig crew worked on maint items on ri g and prep rig fl move {raised cellar box, ra ised stomper, jacked rig & utility modules, I oaded modules on Lampson moving system, set a few mattting boards towards 1C-127, s eperated utility module f/ drill module. Level up around 1C-127 cellar area. Set mat s f/ 1C-117 to 1C-127 fl 150' move towards utility module side of rig. Move utility module down past well 1 C-127. Set mats to manuever rig module out of well line (to miss thermosyphons @ well 1C-121, 1C-123, 1C-125) f/ move to 1C-127. Start moving rig module off 1C-117--- Broke chain on # 2 Lampson while making counter rotation to move out of well line (thermosyp hons in the way f/ in line move). Repair secondary chain on right track of # 2 Lampson. Lay mats and making counter rotations wI La mpsons while moving to 1C-127. Lower stomper, lower cellar box, maneuver t 0 center of hole. Remove crib blocks on rig module. Set rig d own on mats, check fl level. Move utility module, mat up to rig, remove c rib blocks, set on mats. RU cellar, build cellar berm. Nipple down 7 1/16" 5m valve. Install test pi ug , RILDS. Rig floor to LOS = 36.40' Rig accept @ 1500 hrs 8/3/2002. Nipple up 13 5/8" BOPE. RU to test 13 5/8" BOPE. Printed: 8/23/2002 3:46:23 PM ~. T¡r¡I ~ ( Page 5 of 9 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Date 8/3/2002 Sub From - To - Hours Code Code Phase 17:30 - 22:00 4.50 WElCTl BOPE CMPl TN 22:00 - 22:30 0.50 WElCTlOTHR CMPl TN 22:30 - 00:00 1.50 CMPl TN PERF CMPl TN 00:00 - CMPl TN CMPl TN 8/4/2002 00:00 - 00:30 0.50 CMPl TN PERF CMPl TN 00:30 - 01 :30 1.00 CMPl TN PERF CMPl TN 01 :30 - 02:00 0.50 CMPl TN PERF CMPl TN 02:00 - 02:30 0.50 CMPl TN PERF CMPl TN 02:30 - 02:31 0.02 CMPl TN PERF CMPl TN 02:31 - 03:30 0.98 CMPl TN PERF CMPl TN 03:30 - 04:00 0.50 CMPl TN PERF CMPl TN 04:00 - 04:30 0.50 CMPl TN PERF CMPl TN 04:30 - 04:31 0.02 CMPl TN PERF CMPl TN 04:31 - 05:00 0.48 CMPl TN PERF CMPl TN 05:00 - 05:30 0.50 CMPl TN PERF CMPl TN 05:30 - 06:00 0.50 CMPl TN PERF CMPl TN 06:00 - 06:30 0.50 CMPl TN PERF CMPl TN 06:30 - 07:00 0.50 CMPl TN PERF CMPl TN 07:00 - 07:30 0.50 CMPl TN PERF CMPl TN 07:30 - 08:00 0.50 CMPl TN PERF CMPl TN Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 De~cription of Operations Witness of 13 5/8" BOPE test waived by AO GCC inspector John Crisp. Test 13 5/8" BOP E. Test all valves and all rams to 250 psi 10 w, then 5000 psi high. Hold each test 5 min. Test annular to 250 psi, then 3500 psi f/ 5 min. each. Test accumulator. Rig down test equipment. Set Vetco wear bu s h i n g. RU Schlumberger to perforate. Note: Extra time required on rig move to mo ve around Thermosyphons Pre job safety meeting wI Schlumberger to p erf well. RU Schlumberger, MU 20', 3 3/8", 4 spf gun (loaded 16') wI CCl & Gamma Ray. RU Riser . Test riser and packoff on line to 500 psi. OK. RIH to 5950' CCl depth (Bottom of guns @ 5 976.5') Corrolate guns wI Cement bond log 7/13/200 1 . Perforate well with CCl @ 5943.5' (10.5' CC l to top shot), perf West Sak "B" sand @ 59 54' to 5970' (16'). POOH wI Run # 1. All shots fired, hole stati c. MU 20', 3 3/8", 4 spf gun (loaded 20') wI CC l and Gamma Ray. Pressure test riser and p ackoff to 500 psi. OK. RIH to 5950' CCl depth (Bottom of guns @ 5 976.5'). Corrolate guns wI cement bond log 7/13/2001. Perforate well with CCl @ 5927.5' (6.5' CCl to top shot), perf West Sak "B" sand @ 593 4' to 5954' (20'). POOH wI Run # 2. All shots fired, hole stati c. MU 20', 3 3/8",4 spf gun (loaded 20') wI CC l and Gamma Ray. Pressure test riser and p ackoff to 500 psi. OK. RIH to 5950' CCl depth (Bottom of guns @ 5 976.5'). Corrolate guns wI cement bond log 7/13/2001. Perforate well with CCl @ 5877.5' (6.5' CCl to top shot), perf West Sak "D" sand @ 588 4' to 5904' (20'). POOH wI Run # 3. All shots fired, hole stati c. MU 20', 3 3/8", 4 spf gun (loaded 20') wI CC l and Gamma Ray. Pressure test riser and p ackoff to 500 psi. OK. RIH to 5950' CCl depth (Bottom of guns @ 5 976.5'). Corrolate guns wI cement bond log Printed: 8/23/2002 3:46:23 PM <.~~ TfI'fi ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/4/2002 Frorn -To 07:30 - 08:00 08:00 - 08:01 08:01 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 12:30 12:30 - 14:00 Page 6 of 9 PHILLIPS ALASKA INC. Operations Summary Report 1 C-127 1 C-127 ROT - DRILLING n 1268 @ ppco.com Nabors 245 Sub Hours ."Gode ,Code Phase 0.50 CMPL TN PERF CMPL TN 0.02 CMPL TN PERF CMPL TN 0.98 CMPL TN PERF CMPL TN 0.50 CMPL TN OTHR CMPL TN 2.50 CMPL TN TRIP CMPL TN 0.50 CMPL TN TRIP CMPL TN 1.50 CMPL TN CIRC CMPL TN 14:00 - 20:30 6.50 CMPL TN TRIP CMPL TN 20:30 - 21 :30 1.00 CMPL TN RURD CMPL TN 21 :30 - 00:00 2.50 CMPL TN RUNT CMPL TN 8/5/2002 00:00 - 04:30 4.50 CMPL TN RUNT CMPL TN 04:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 09:30 1.50 CMPL TN SOHO CMPL TN 2.00 CMPLTN OTHR CMPLTN 0.50 CMPL TN PCKR CMPL TN Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description of Operations 7/13/2001. Perforate well with CCL @ 5857.5' (6.5' eeL to top shot), perf West Sak "D" sand @ 586 4' to 5884' (20'). RIH to 5876' bottom of gu n, log pass across perf interval. POOH wI Run # 4. All shots fired, hole stati c. RID Schlumberger. RID riser. Blow down choke and kill lines. MU/RIH wI assembly to cleanout below FB-1 packer (mill out extension). RIH to 4369'. Continue RIH to clean out 5' down into FB-1 packer. (Packer top @ 5977' DPM) RIH wI m ule shoe to 5982' DPM Displace wI 8.5 ppg seawater, 100 degree te mp., @ 100 spm (10.1 bpm) with 1400 psi. W arm up fluid in hole- clean out debris in mill out extension below WL set packer. Final w eight of fluid in hole 8.7 ppg. Observe well. OK. POOH wI clean out assembly. LID stinger, sc raper, junk basket and crossover. Hole takin g 1 bbl per hour. RU to run 3 1/2" completion. Pre job safety meeting wI GBR and crew. PU I MU 3 1/2" completion string. 26 joints i n h 0 Ie. Continue to run 3 1/2", 9.3 31ft, L-80, Eue 8 rd-mod tubing per well plan. Ran total of 18 5 joints of tubing to 5955'. MU headpin on jt # 186 to locate. Circ jt # 186 down @ 1.5 bpm to locate seal s into FB-1 packer (top of packer @ 5978' W LM). Pressure up @ 22.5' in on jt # 186. Ble ed off pressure. Slack off to 28.95' in on jt # 186. PU & LID jt's # 186,185, and 184. Le ave Jt # 183 in hole. Space out with pups (6 .12',2.35',4.09' & 4.10'). MU jt # 184 then Vetco Gray hanger with 3 1/2" eue 2.04' pu p below, land same wI locator 2.73' above f ully inserted. Bottom of mule shoe @ 5982.6 , DPM, bottom of locator @ 5975.9' DPM PU wt 134 K SO wt 94 K Block wt 75 K RILDS. Test hanger upper and lower seals t 0 5000 psi f/ 10 min. RU and test pumping I ines to 4000 psi. (high pressure hoses and c hart recorder f/ setting and testing packers ) Pressure up tubing and set S-3 packer @ 25 00 psi while bringing pressure up to 4000 ps i to set the Baker Premier packer. Hold 400 0 psi fl 15 min. Bleed pressure to 1000 psi. 1.00 CMPL TN PCKR CMPL TN Wit h 1 0 0 0 psi I eft 0 n tub i n g, pre s sur e U p 0 n Printed: 8/23/2002 3:46:23 PM (~.~ TfI7I ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/5/2002 8/6/2002 Page 7 of 9 PHilliPS ALASKA INC. Operations Summary Report 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From -To Hours Code Code Phase 08:30 - 09:30 09:30 - 10:00 10:00 - 14:00 14:00 - 15:30 15:30 - 17:30 1.00 CMPL TN PCKR CMPL TN 0.50 CMPL TN OTHR CMPL TN 4.00 WELCTL NUND CMPL TN 1.50 WELCTL NUND CMPL TN 2.00 WELCTL NUND CMPL TN 17:30 - 18:00 0.50 CMPL TN OTHR CMPL TN 18:00 - 19:00 1.00 CMPL TN OTHR CMPL TN 19:00 - 19:30 0.50 CMPL TN FRZP CMPL TN 19:30 - 21 :00 21 :00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 10:00 10:00 - 12:00 12:00 - 00:00 1.50 CMPL TN FRZP CMPL TN 0.50 WELCTL OTHR CMPL TN 1.50 CMPL TN OTHR CMPL TN 1.00 CMPLTN OTHR CMPLTN 1.00 RIGMNT RSRV DEMOB 9.00 RIGMNT RSRV DEMOB 2.00 RIGMNT RSRV DEMOB 12.00 RIGMNT RSRV DEMOB Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description of Op~rations 7 5/8" x 3 1/2" annulus to 2500 psi to test Premier packer for 30 min. Chart test. OK. Bleed off pressure. RID chart recorder and hoses. Back out & LID 3 1/2" landing joint. Pull sle eve out of tubing hanger. Set 4" BPV. PJSM. Nipple down flowline and riser. Remo ve turnbuckles on BOP stack. Open all ram doors. Flush cavity of BOP's with water. Re move all rams. Grease rams and store fI sta ckout. Nipple down 13 5/8" 5m BOP stack. Nipple up Vetco Gray 4 1/8" 5m tree. Pull B PV. Set two way check. Test tree to 350 psi low and 5000 psi high f/ 10 minutes each. C hart test. Pull two way check. RU pumping hoses in cellar to shear out RP in GLM @ 5777'. Test lines to 2700 psi prior to shearing RP valve in GLM. Test 3 1/2" tubing to 1000 psi (4 strokes). H old tubing pressure while pressuring up on 7 5/8" x3 1/2" annulus to 2700 psi (21 stroke s). Hold f/ 5 min. Bleed off tubing pressure and shear RP valve in GLM @ 5777'. Freeze protect well by pumping 115 bbls die sel down 7 5/8" x 3 1/2" annulus (3362'). IOU " tube diesel to tubing.This will leave diesel in tubing and annulus @ 2693' MD = 2092' TVD Set Vetco Gray BPV. Secure well. Blow down all lines in cellar. RID lines. Cle an up in cellar. Prepare rig f/ stackout: Flush lines wI fresh water and blow down real good. Cleaning pi ts, hauling fluids to 1R-18. Finish picking up tools in cellar, Rig up man rider on rig floor, Continue cleaning pits & flushing out lines to remove brine. PJSM, Lock out & tag out drawworks, Wash t op drive & rig inside wind walls, Clean on pi pe shed floors in perparation for stack, Con tinue cleaning on mud pits, Gather & load pi pe shed wI DSA's & spools, Change oil in #1 motor, Drain radiators on #2 & 3 motors. Finish cleaning active mud pits & move to R AW mud pits, Start changing oil in Lampson motors, Continue cleaning in pipe shed & rig floor, Flush stand pipe with fresh water, St art prepairing #1 mud pump for stack out. N ote: Released rig at 12:00 hrs 8/6/2002 Continue cleaning inside wind walls, R i gf I 0 or & pipe shed, Change oil in Lampson engi Printed: 8/23/2002 3:46:23 PM ~~ r¡:r¡¡ ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/6/2002 8/7/2002 8/8/2002 8/9/2002 8/1 0/2002 8/11/2002 PHilliPS ALASKA INC. Operations'Summary'Report 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From-To Hours Code Code Phase 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS Page 8 of 9 Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description of OperatiQns nes, Prep. mud pumps for stack out, Clean c harge pump room, Clean up under floor, Gre ase mud agitators, Inspect Dis-Flo pumps, C lean & Grease Iron Roughneck, Clean & Gre ase Drawworks, Clean out Swaco Degasser, Change oil in 353 rig moving generator. Continue cleaning rig floor, Prep. pumps for stack out, Clean Dis-Flo tank, Clean 400 bb I storage tank, Change oil in mud dock lift, Start cleaning in upper & lower cellar box, F in ish cleaning pipe shed & charge pump roo m, Pulled brushes out of top drive motor. Dope drill pipe out in yard, Remove orange house off top deck of rig with crane, Clean out boiler, Pull rotary table cover and clean , Change oil in rotary table, Clean cellar ar ea, Go thru stack out procedures, Start zon al derrick inspection, Steam clean engine ro om, Clean drains under floor. Continue with stack out procedures, Clean p ump room, Service chock manifold for stack out, Clean cave room, Clean lower cellar bo x, Pick up dewater room, Clean koomy room, Clean pump room, Continue derrick inspect ion, Pick up trash and hoses in Raw mud pit s. Clean out drains, Work on zonal derrick ins pection, Check oil in pipe skate, Install whit e in crown, Clean brake bands on airhoists, Grease pipe skate, Clean mud mixing room, Perform work order on SOP hoist (Install bu mper blocks properly). Note; Held quarterly rig safety assessment with all crews and pe rsonal. Continue stack out procedures, Paint choke room floor, Change out stop on skate, Finis h derrick inspection Continue stack out procedures, Inspect Dra wwork chains, Pull covers on centifuges- cle an & inspect same, Clean radiators on #2 & 3 rig engines, VCI wrap choke & kill lines, Change out strobe light on derrick crown se c t ion Continue with stack out procedures, Prep. c ellar box for painting, Change hydralic hose s on stabbing board, Clean radiators on #1 & #4 motors, Change out air hose on top dri ve, Service loop. Continue stack out procedures, Install new air hose on top drive, Clean out radiator roo m, Prep. cellar box for painting. Continue stack out procedures, Install back stop on skate, Paint cellar box, Remove cab Printed: 8/23/2002 3:46:23 PM <.~~ r¡r¡i ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHILLIPS ALASKA INC. Operations Summary Report 1 C-127 1 C-127 ROT - DRILLING n1268@ppco.com Nabors 245 Date From- To Hours Code Sub Phase Code 8/11/2002 00:00 - 12:00 12.00 RIGMNT RSRV DEMOS 12:00 - 00:00 12.00 RIGMNT RSRV DEMOS 8/12/2002 00:00 - 06:00 6.00 RIGMNT RSRV DEMOS 06:00 - 07:30 1.50 MOVE MOVE DEMOS 07:30 - 09:00 1.50 MOVE MOVE DEMOS 09:00 - 11 :00 2.00 MOVE MOVE DEMOS 11 :00 - 00:00 13.00 MOVE MOVE DEMOS 8/13/2002 00:00 - 02:00 2.00 MOVE MOVE DEMOS 02:00 - 03:30 1.50 MOVE MOVE DEMOS 03:30 - 04:00 0.50 MOVE MOVE DEMOS 04:00 - 12:00 8.00 RIGMNT RSRV DEMOS 12:00 - 00:00 8/14/2002 00:00 - 12:00 12:00 - 00:00 8/15/2002 00:00 - 12:00 12:00 - 00:00 8/16/2002 00:00 - 12:00 12:00 - 00:00 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 RIGMNT RSRV DEMOS 12.00 MOVE MOVE DEMOS Page 9019 Spud Date: 6/22/2001 End: Group: Start: 6/22/2001 Rig Release: 8/6/2002 Rig Number: 245 Description of, Operations inets & lockers in doghouse, Repair oil leak on #1 pump. Continue stack out procedures, Continue pai nting cellar box, Prepare rig floor to skid, U nhook chokel kill I cmt./ mudlines, Slow dow n water on rig. Continue stack out procedures, Paint cellar box floor, Prep. to skid rig floor, Slow down steam lines on drill module Skid rig floor back over drill module Raise cellar box & Stomper Jack up both modules & install crib blocks Move both Drill & Utility modules into stack out position on Pad, Remove crib blocks Skid rig over cellar Lower stomper & secure Lower cellar box Continue stack out procedures, Nipple down & remove lower single gate on SOP for servi ce, Slow down steam lines in Utility module. Continue stack out procedures, Drain water tanks, Drain #2 boiler, Serm up around Lam psons, Remove batteries and Anti Freeze fro m Lampsons, Remove stand by stand pipe. Continue stack out procedures, Rig down sta nd by stand pipe, Drain & prepare #2 boiler for stack, Remove batteries from cold start motors, Prepare #1 399 & 353 stand by moto rs for stack, Vacuum remaining water from R aw mud pits & Sumps. Continue stack out procedures, Vacuum out Dis Flo tank, Slow down test pump, Drain bo iler feed pumps, PJSM- Weld Pad eyes for m an riders in derrick & Install new sheaves a nd lines on same. Continue stack out procedures, Plug holes, Cover vents, Coat wires, Remove Iron rough neck for service, Change oil in Koomey pum p. Continue stack out procedures, Remove all Nitrogen bottles from rig & shop, Prep. Sho p & Parts house for move, Pull brushes from Drawworks electric motors. Finish Stack out procedures, Weather protec t electric cables & Drilling console, Change oil in camp motor, Cover radiator vents, Shu t down all rig generators, Clean & tranport SAA & RAA areas, Remove all paint & etc. 0 f f rig. Move Camp into stack out position on 1 C Pa d, Clean & shut down same. Printed: 8/23/2002 3:46;23 PM Date 07/12/01 07/13/01 07/31/02 08/01/02 08/02/02 1 C-127 Event H ¡story Comment MADE SEVERAL ATTEMPTS WITH USIT BUT UNABLE TO COLLECT DATA. APPEARS TOOL MAY BE FAILING. JOB IN PROGRESS. USIT LOG COMPLETED. GENERAL GOOD CEMENT. FOUND POOR CEMENT FROM 6186' TO 6294'. BAKER ECP AFFECTING READING FROM 5952' TO 6008'. ENCOUNTERED CMT & ICE @ 1563' WLM. OBTAINED SAMPLE OF SAME. [TAG, HYDRATES-ICE] CLEAN OUT CASING DOWN TO 6250' CTMD USING 3" JET SWIRL NOZZLE. PUMPED SLICK SW AND 1.5# BIO SWEEPS. DID NOT ENCOUNTER ANY FILL OR SEE SOLID RETURNS IN FLOWBACK TANKS. LAYED IN 9.3# KCL BRINE WHILE POOH. [HYDRATES-ICE] RUN 6.625" JUNK BASKET PRIOR TO PERF-- SHOOT PERF INTERVALS 5983'-6003'; 6022'-6038'; 6048'- 6070'; 6112'-6134' WITH 33/8 HJ 11- RUN ADITIONAL JUNK BASKET-- SET TOP BAKER FB-1 PACKER @ 5978' ----PRESSURE TEST PACKER TO 1000 PSI FOR 30 MIN, NO PRESSURE DECLINE. Page 1 of 1 8/23/2002 ( (' Phillips Alaska, Inc. Pad lC 127 slot #127 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref: MHD <0-6450'> OUr ref: svy6548 License: Date printed: 7-Jan-2002 Date created: 24-Jun-2001 Last revised: 3-Jul-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.053,w149 29 52.183 Slot Grid coordinates are N 5968596.841, E 561929.843 Slot local coordinates are 1639.00 S 923.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( Phillips Alaska, Inc. 5URVEY LI5TING Page 1 Pad 1C,127 Your ref: MHD <0-6450'> Kuparuk River Unit, North 5lope, Alaska Last revised: 3-Jul-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORD5 Depth Degrees Degrees Depth COORDINATE5 Deg/100ft 5ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 561929.84 5968596.84 158.00 0.00 0.00 158.00 O.OON O.OOE 0.00 0.00 561929.84 5968596.84 200.92 0.70 255.79 200.92 0.065 0.25W 1.63 0.20 561929.59 5968596.77 291.74 1.58 250.17 291. 72 0.635 1.97W 0.98 1.63 561927.88 5968596.20 382.64 2.81 237.86 382.55 2.245 5.04W 1.44 4.69 561924.83 5968594.56 472.96 5.63 233.99 472. 62 6.025 10.50W 3.14 10.90 561919.40 5968590.74 563.96 8.09 229.42 562.96 12.815 18.97W 2.77 21. 29 561910.98 5968583.88 654.99 10.46 224.50 652.80 22.875 29.63W 2.74 35.61 561900.40 5968573.73 745.82 13.89 221.69 741. 57 36.905 42.66W 3.83 54.55 561887.49 5968559.60 836.46 17.31 220.99 828.86 55.215 58.75W 3.78 78.74 561871.55 5968541.16 927.54 18.98 221.34 915.41 76.565 77 . 42W 1.84 106.91 561853.05 5968519.67 1018.09 21. 57 221.69 1000.34 100.055 98.22W 2.86 138.04 561832.45 5968496.01 1112.17 26.46 221.69 1086.25 128.635 123.68W 5.20 176.01 561807.23 5968467.22 1204.33 29.79 222.39 1167.52 160.885 152.78W 3.63 219. 06 561778.39 5968434.74 1234.00 30.53 222.15 1193.17 171.915 162.80W 2.51 233.82 561768.46 5968423.63 1296.56 32.08 221.69 1246.62 196.095 184.52W 2.51 266.04 561746.94 5968399.27 1390.03 34.01 220.99 1324.97 234.375 218.18W 2.10 316.64 561713.60 5968360.73 1460.00 35.60 220.45 1382.42 264.635 244.22W 2.31 356.33 561687.80 5968330.26 1483.07 36.12 220.28 1401.12 274.935 252.98W 2.31 369.77 561679.13 5968319.89 1576.54 37.88 225.56 1475.78 316.055 291.29W 3.88 425.35 561641.16 5968278.46 1667.62 40.52 229.07 1546.37 355.035 333.62W 3.79 481.42 561599.15 5968239.15 1762.39 43.68 226.96 1616.68 397.555 380.81W 3.65 543.16 561552.31 5968196.25 1854.46 46.93 225.20 1681. 43 442.965 427.93W 3.78 607.25 561505.57 5968150.46 1948.12 50.63 223.80 1743.14 493.215 477. 28W 4.11 676.59 561456.64 5968099.82 2040.69 53.26 222.74 1800.19 546.295 527.22W 2.98 748.61 561407.13 5968046.34 2133.06 58.45 220.63 1852.03 603.385 578.01W 5.93 824.41 561356.81 5967988.84 2226.39 61.88 220.28 1898.45 664.985 630.53W 3.69 904.91 561304.80 5967926.82 2319.39 65.04 219.58 1940.00 728.785 683.92W 3.46 987.71 561251.94 5967862.60 2414.16 65.65 217.12 1979.54 796.325 737.35W 2.45 1073.62 561199.06 5967794.63 2507.65 66.27 213.25 2017.64 866.085 786.53W 3.84 1158.98 561150.45 5967724.47 2600.10 66.62 211.85 2054.58 937.525 832.12W 1.44 1243.67 561105.45 5967652.68 2693.35 66.09 210.09 2091.99 1010.765 876.08W 1.82 1328.94 561062.09 5967579.09 2786.62 65.92 210.09 2129.92 1084.485 918.80W 0.18 1413.91 561019.98 5967505.03 2880.30 65.30 209.28 2168.60 1158.605 961.06W 1.03 1498.94 560978.33 5967430.57 2972.27 65.04 209.03 2207.22 1231.505 1001.72W 0.38 1582.06 560938.26 5967357.36 3065.96 64.07 210.79 2247.48 1304.835 1043.90W 1.99 1666.39 560896.69 5967283.70 3160.11 64.69 211.14 2288.19 1377.625 1087.58W 0.74 1751.13 560853.61 5967210.56 3251.76 64.42 210.44 2327.56 1448.715 1129. 94W 0.75 1833.73 560811.82 5967139.13 3345.04 63.63 210.44 2368.42 1521.015 11 72 . 43W 0.85 1917.39 560769.93 5967066.49 3439.29 63.98 210.44 2410.02 1593.935 1215.27W 0.37 2001.75 560727.68 5966993.24 3531.29 64.78 210.79 2449.80 1665.325 1257.52W 0.93 2084.53 560686.02 5966921.52 3624.56 64.51 211.14 2489.74 1737.595 1300.88W 0.45 2168.66 560643.25 5966848.90 3718.24 64.78 212.55 2529.86 1809.505 1345.55W 1.39 2253.23 560599.18 5966776.64 3810.21 65.30 212.55 2568.67 1879.785 1390.41W 0.57 2336.57 560554.89 5966706.00 3903.90 65.04 212.20 2608.01 1951.595 1435.94W 0.44 2421.54 560509.95 5966633.83 3998.05 65.65 210.09 2647.29 2024.825 1480.19W 2.14 2506.96 560466.30 5966560.25 4089.70 65.57 210.09 2685.14 2097.055 1522.04W 0.09 2590.20 560425.05 5966487.69 4182.98 65.74 210.79 2723.59 2170.325 1565.10W 0.71 2674.98 560382.59 5966414.08 4277 . 23 65.30 210.44 2762.65 2244.145 1608.78W 0.58 2760.57 560339.51 5966339.92 4369.98 65.30 210.44 2801.41 2316.795 1651. 47W 0.00 2844.64 560297.42 5966266.93 All data in feet unless otherwise stated. Calculation uses min~um curvature method. Coordinates from slot #127 and TVD from RKB 102'(N-245E) (102.00 Ft above mean sea level). Bottom hole distance is 4110.96 on azimuth 214.04 degrees from wellhead. Vertical section is from wellhead on az~uth 214.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ( Phillips Alaska, Inc. 8URVEY LI8TING Page 2 Pad 1C,127 Your ref: MWD <0-6450'> Kuparuk River Unit, North 8lope, Alaska Last revised: 3-Ju1-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORD8 Depth Degrees Degrees Depth COORDINATES Deg/100ft 8ect Easting Northing 4464.47 65.30 210.44 2840.89 2390.808 1694.96W 0.00 2930.28 560254.53 5966192.57 4556.61 65.30 212.90 2879.40 2462.038 1738.91W 2.43 3013.88 560211.17 5966120.99 4650.16 64.95 212.55 2918.75 2533.438 1784.79W 0.51 3098.72 560165.88 5966049.22 4742.24 63.98 211.14 2958.44 2604.018 1828.63W 1. 74 3181.72 560122.62 5965978.30 4836.34 63.63 211.49 2999.98 2676.148 1872.51W 0.50 3266.03 560079.33 5965905.82 4931. 27 61.70 211. 49 3043.57 2748.058 1916.56W 2.03 3350.25 560035.87 5965833.56 5025.09 59.50 211.14 3089.62 2817.888 1959.04W 2.37 3431.86 559993.96 5965763.40 5118.75 57.48 210.09 3138.57 2886.598 1999. 71W 2.36 3511.53 559953.85 5965694.37 5211.57 52.82 208.33 3191.60 2953.038 2036.90W 5.26 3587.37 559917.21 5965627.63 5305.28 48.34 207.58 3251.09 3016.958 2070.84W 4.82 3659.29 559883.79 5965563.44 5398.21 44.56 209.30 3315.11 3076.188 2102.88W 4.28 3726.26 559852.24 5965503.96 5492.36 40.61 212.55 3384.42 3130.848 2135.55W 4.80 3789.81 559820.02 5965449.04 5585.99 36.30 214.66 3457.73 3179.358 2167. 72W 4.81 3848.01 559788.25 5965400.28 5679.99 31. 46 210.44 3535.76 3223.428 2196.00W 5.72 3900.35 559760.33 5965355.99 5773.21 26.54 207.63 3617.27 3262.878 2217.99W 5.48 3945.33 559738.66 5965316.37 5867.07 21.27 206.57 3703.05 3296.698 2235.34W 5.63 3983.04 559721.59 5965282.40 5960.19 17.84 210.09 3790.79 3324.158 2250.06W 3.89 4014.01 559707.10 5965254.83 6051.32 13.80 215.01 3878.45 3345.148 2263.30W 4.67 4038.81 559694.03 5965233.73 6143.08 10.55 216.77 3968.14 3360.848 2274.61W 3.56 4058.15 559682.85 5965217.95 6236.95 10.02 211.14 4060.50 3374.718 2283.97W 1.21 4074.89 559673.60 5965204.00 6331.25 9.76 208.33 4153.40 3388.778 2292.01W 0.58 4091.03 559665.68 5965189.88 6372.03 9.67 207.98 4193.59 3394.848 2295.26W 0.26 4097.87 559662.48 5965183.78 6450.00 9.67 207.98 4270.46 3406.408 2301.40W 0.00 4110.89 559656.43 5965172.17 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #127 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level). Bottom hole distance is 4110.96 on azimuth 214.04 degrees from wellhead. Vertical section is from wellhead on azimuth 214.40 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Sc~lullbel'gep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job# log Description Date '2£.0 .-eft Lt 1 D-125A INJECTION PROFilE 07/20/01 'F\Cô,..-t2' 1D-132 INJECTION PROFilE 07/20/01 1511- lJ'lQ. 2C-12 PRODUCTION PROFilE 07/23/01 l~l-{, Z/1.,-'7- 2W-11 PRODUCTION PROFilE 07/24/01 \ 1-}a:, 1D-130 INJECTION PROFilE 07/19/01 2.0l-oßti1 C-123 21345 CBUUSIT 07/11/01 ~\ "UC:¡ 1C-127 21346 CBUUSIT 07/13/01 SIG~~~(,' Oe1f:? 7/31/2001 NO. 1338 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk (' Bl Sepia CD Color 1 1 1 1 1 1 1 1 1 1 1 1 (", DATE: RECEIVED AUG 0 3 2001 '-'OU& Gas Qms. Commilllon Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ~ PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 July 17, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approvals for 1 C-127 Dear Commissioner: Phillips Alaska, Inc. submits the attached Application for Sundry Approvals for 1C-127. We are requesting approval to change the approved program for this well. If you have any questions regarding this matter, please contact Vem Coyner at 265-6074. Sincerely, .\~~ R. Thomas Kuparuk Team Leader PAl Drilling RT/skad /¡[/ RFCEIVED JUL 211 2002 AlasKa UII & lias Cons. CommisSIOI; Anchorage ORIGINAL 1IJ6A J~ iOT:f APPLICATION FOR SUNDRY APPROVALS ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION (' 7..'l1/0L- 1~t~ 8/;/oZ- 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1642' FNL, 924' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 346' FSL, 1334'FEL,Sec. 11,T11N,R10E,UM At effective depth 338' FSL, 1339' FEL, Sec. 11, T11N, R10E, UM At total depth 338' FSL, 1339' FEL, Sec. 11, T11 N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 6450 4268 6350 4182 measured true vertical Length 158' 4204' Casing Conductor Surface Size 16" 8.625" X 7.625" Perforation depth: measured No Perforations true vertical No Perforations Tubing (size, grade, and measured depth No Tubing Run Packers & SSSV (type & measured depth) No Packers or SSSV"s 13. Attachments Description summary of proposal _XX 14. Estimated date for commencingpp§Tat1on" ( J~ly 26,~io02 16. If proposal was verbally appro~/ Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory Stratigraphic - Service _XX (asp's: 561931, 5968597) (proposed) (proposed) (proposed) feet feet feet feet Plugs (measured) Junk (measured) Cemented 9 cu yds High Early 635 sx AS III, 410 sx Class G Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 41.2 feet above pad, 102' above MSL 7. Unit or Property name Other - Kuparuk River Unit 8. Well number 1 C-127 9. Permit number I approval number 201-114/301-190 10. API number 50-029-23024-00 11. Field I Pool Kuparuk River Field/West Sak Oil Pool Measured Depth 158' 6438' True vertical Depth 158' 4256' RECEIVED ~2002 '",,,-,,-~-'" Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program 15. Status of well classification as: Oil- Name of approver Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represen!~tive may witness Plug integrity - ppP Test ~ Location clearance - ; J MechanicallntegrityT~A , Subsequent form required 10- '-f07 T~f {$oPE l~ '~ÇÐO &'gi'nal~~{~õ~~J ph\(l;r ~ t0e,,;þ:t--ø Cammy Oechsh Taylor Commissioner Signed K.~ \~. R. Thomas Approved by order of the Commission Form 10-403 Rev 06/15/88 . Title: Drilling Engineering Supervisor 0 BOP sketch - Gas- Suspended - Questions? Call Vern Coyner 265-6074 ì ("(Q 'l.... Date Prepared by Sharon Allsup-Drake Approval no..3 2.. 0 0 ..2..3 Date %)þ~- L SUBMIT IN TRIPLICATE Well # 1C-127, AFE #AK0174 West Sak Planned Completion Schematic 8-5/8" 32 Casing ) 16" Conductor @ +/-158' MD 8-5/8" x 7-5/8" X-Q at 135 Ft 7-5/8" 29.7# L-80 Casing I I I I I I ~ I I ~ PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY 500' of 3-%" EUE-Mod Tubing & Pups I 2.875" Camco D nipple with 3-%" EUE-Mod and ~ Ft. Pups installed on top and bottom xx Joints of 3-%" EUE-Mod Tubing Cameo MMG 3-1/2" X 1-1/2" Gas Lift Mandrel 1 Joint of 3-%" EUE-Mod Tubing 7-5/8" Premier Packer with 3-%" EUE-Mod Pups 3-%" EUE-Mod Tubing Pups Cameo MMG 3-1/2" X 1-1/2" Gas Lift Mandrel 3-%" EUE-Mod Tubing Pups Baker 3-%" CMU Sliding Sleeve. profile with 3-1/2" EUE-Mod 3-%" EUE-Mod Tubing Pups 2.81 Camco 7-5/8" S-3 with 3-%" EUE-Mod Pups 3-%" EUE-Mod Tubing Pups Cameo MMG 3-1/2" X 1-1/2" Gas Lift Mandrel 3-%" EUE-Mod Tubing Pups Baker 3-%" CMU Sliding Sleeve. 2.75 Camco profile with 3-1/2" EUE-Mod 3-1/2" EUE-Mod Tubing Pups Baker, 7 Ft 80-40 Locator Seal Assembly Baker 7-5/8" FB-1 Packer I I I ~ I I 2-7/8" EUE-Mod Wireline Entry Guide ~ 5- %" x 4' Pup Joint + x-o 2.31" Camco nipple with 2-7/8 EUE-Mod with a 4 Ft. Pup above and a 2 Ft. pup below TO 9-7/8" Hole: Plug Back TO 6,450' MD 14,270' TVD @ +/- 6,350' MO 1 C-127 Completion Schematic Prepared by Jose Iguaz Checked by Skip Coyner ( 1 C - 127 Completion Procedure Well Geometrv (see diaaram): 8-5/8" 32.0# l-80 RKB - 133' MD 7-5/8" 29.7# l-80 133' - 6439' MD Wellhead is VETCO "Horizontal" wI 11" (5M) Tubing Head flange. Swab Valve: there is a 7-1/16" (5M), full bore valve on the wellhead Baker "ECP" set at 5968.6' - 6001.8' MD (Rig Talley) (5976' - 6008' Schlumberger) Maximum angle is 49° at 2697' MD Maximum Dog leg is 6.0°/100' at 2133' MD BH P is estimated to be 5 1600 psi Kill Weight Brine = Seawater Perforations (Pre-Rig): 5983'~6))03', 6022'-6038', 6048'-6070', 611t;,61~;~MD -381-3':3832', 3850'-3865', 3875'-3897', 3938-3959' TVD Perforations (On the Rig): 5934'-5970', G-5904' MD 3765'-3800', ~'-3738' TVD Casing Pre-ria Work: (Test all surface equipment with diesel) / 1. USIT log: done 07/13/2001. 2. NU "full bore" 11" x 7-1/16" adapter and 7-1/16" swab valve from 1 C-117. 3. RU SlU. Run a 6.625" drift to :t 6200' to check for ice, fill etc. RD SlU. 4. RU E-Line, W/L BOP's, lubricator and Packoff on the swab valve. Test to 1500 psi with diesel. Perforate the West Sak "A" with 3-3/8" guns, 4 spf as follows: West Sak "A" 5983' - 6003' MD (load top & bottom shots) 6022' - 6038' MD 6048' - 6070' MD 6112' - 6134' MD Keep the hole full with heated diesel (unless the fill rate gets too high). 5. Run a 6.625" gage ring and junk basket tO:t 6000' MD. Set a Baker "FB-1" packer with tail pipe (incl pump out plug) in the top of the ECP. Set the top of the packer at 5978' MD (as per the CCUGR on the USIT log 07/13/01). The top of the FB-1 will be 2' below the collar, which is at 5976'. Test the packer to 1000 psi. Secure the well. RD E-Line. The packer assembly is as follows (top-down): FB-1 packer (:t 4'), 5-1/2" sub (:t 4'), X/O (:t 1 '), 2-7/8" pup jnt (:t 4'), DS nipple (:t 1 '), 2-7/8" pup jnt (:t 1 '), WLEG. Estimated total length is 16' plus the setting tools, CCl, etc. 7/21/02 VMC Version 1 RiQ Work: (f 1. MI RU Nabors Rig #245 from 1 C-117 with 5800' of 4" drill pipe in the derrick. Check the well to be sure it's dead. Pick up a 7-5/8" storm packer. Run it through the swab valve and set it in the casing (below the 8-5/8"). Test the storm packer to 1 000 psi. ND the swab valve and NU BOP's. Set a test plug in th~ellhead and mark the landing joint at the rotary table. Test the BOP's to 250/3500 psi. Pull the test plug. Measure the length from the rotary table to the bottom of the test plug for future use. Retrieve the storm packer. Minimum 24 hours notification to AOGCC is reQuired prior to nipplinQ up and testinQ 2. Pick up a 6-3/4" bit, casing scraper and (6) 4-3/4" DC's. RIH on 4" DP to the FB-1 packer at :t 5978' MD and displace the diesel freeze protect fluid to a tank and circulate th~asing clean with heated seawater (~1300 F) to ''warm up" the wellbore. LDDP and BHA. 3. RU Schlumberger with a riser and pack off. Test to 1000 psi. Perforate the West Sak "B" / and "D~ith 3-3/8" guns, 4 spf as follows: West Sak B: 5934' - 5970' MD (3765' - 3800' TVD) West Sak D: 5864' - 5904' MD (3700' - 3738' TVD) 4. Keep the hole full (if possible) andlor keep track of the fluid additions (bbl/hr) and fluid level / between perforating runs. RD E-Line. 6. RIH with the locator seal assembly for the FB-1 packer, the straddle packer assembly and the new 3-1/2", 9.3#, L-80, EUE-Mod tubing. Space out will be difficult but critical for the S- 3 packer. The S-3 must be set between 5915' and 5925' MD. There is a casing collar at 5912'. Do not set a packer element across a casing collar. RIH (bottom - up) as follows: 6' 6' 6' 6' 6' 6' 6' 6' 6' 5' 6' 6' 6' 6' 30' 6' 6' 6' 30' 6' 5' 7/23/02 Baker Locator 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint Baker, CMU (2.750" Bore) wI RHC sleeve 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2" x 1-1/2" Cameo MMG GLM with DGLV 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint Baker, 8-3 Packer (Sets at 2500 psi) 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint Baker, CMU (2.813" Bore) 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2" x 1-1/2", Cameo MMG GLM with DGLV 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod tubing joint 3-1/2",9.3#, L-80, EUE-Mod pup joint Baker, Premier Packer (Sets at 4000 psi) (5978' MD) r (5960' MD) (5942' MD) (5919' MD) (5901' MD) (5853' MD) (5816' MD) 2 1 C-127, Version 1 1 ' 6' 30' 6' 6' 6' :t 5244' 6' l' 6' :t 470' x-O 3-1/2",9.3#, L-80, EUE-Mod pup joint 3.1/2",9.3#, L-80, EUE-Mod Tubing Joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2 x 1-1/2"", Cameo MMG GLM with RP Shear valve (2500#) 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod tubing 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", Cameo "DS" nipple (ID = 2.875") 3-1/2",9.3#, L-80, EUE-Mod pup joint (special drift) 3-1/2",9.3#, L-80, EUE-Mod tubing (special drift) (5757' MD) (500' MD) Note: - Drift all the 3-1/2" tubing below 500' to 2.867" except the CMU's - Drift all the 3-1/2" tubing above 500' to 2.875" - Verify that all drifts are accounted for prior to RIH. - Record OD's and ID's of all auxiliary equipment on tubing detail. - Drain BOP stack before landing tubing. 6. Carefully tag the FB-1 packer. PU and circulate the well with heated seawater (~1300) (if circulation is possible) to warm up the tubing. Space out the tubing string such that the seal nipple is stung into the FB-1 packer but the GBH-22 locator is :!: 2' above the FB-1 PKR. This allows for downward movement when setting the other two packers. Use the measurement from step #1 to help space out correctly. Install the tubing hanger. 7. After the tubing is warmed up and the space out is correct, sting into the FB-1 packer, land the tubing hanger and RILO's. Pressure up on the tubing and blow the pump out plug below the FB-1 packer. Drop the RHC ball/rod. 8. Pressure up on the tubing and set the S-3 packer at:!: 2500 psi. Increase the pressure to ::!: 4000 psi and set the Premier Packer. Hold the 4000 psi on the tubing for 15 minutes and / then bleed it off to 1000 psi. Test the annulus and the Premier packer to 2500 psi for 15 minutes. Bleed off the annulus and then bleed off the tubing. Flow check. 9. Lay down the landing joint and install BPV. NO BOP's and NU tree. Pull the BPV. Install test plug. Test tree to 250 and 3500 psi. Pull the test plug. 10. Pressure up the tubing to 1000 psi. Test the IA to 2500 psi for 30 minutes on chart. Bleed off the tubing and pressure up the IA further (if necessary) to shear the RP shear valve. Displace with seawater containing corrosion inhibitor and freeze protect the tubing and IA with diesel to 2500' MO. Set a BPV & VR plug. 11. De-Mobilize the rig on 1 C pad. Post-ria Work: 1. 2. 3. 4. 5. 6. Pull the BPV and VR plug. RU Slickline. Replace the RP shear valve with a OGL V. Retrieve the RHC sleeve, ball/rod from the 2.75" CMU. Retrieve the plug in the 2.31" profile nipple (bottom). Connect flow lines, etc. Set the well house. 7/23/02 3 1C-127, Version 1 .. /PHI~PS'~ ,rÐ !:~t~~!~~I~~~~~~~J~~~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 July 6, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approvals, West Sak Dual Purpose Well lC-127. Permit to Drill # 201-114 API # 50-029-23024-00 Dear Commissioners: Further to a change in drilling procedure authorized by Jane Williamson on June 29, 2001, Phillips Alaska, Inc. hereby requests a Sundry Approval for a well in the West Sak Oil Pool, designated #lC-127 Please find attached for the review of the Commission Form 10-403, and two attachments: -a copy of the e-mail from Jane Williamson, authorizing the change in procedure. -a copy of the Proposed Drilling Program which was submitted with the Application for Permit to Drill, with approved changes shown. If you have any questions or require any further information, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, .. '-/:, 3- ;t1~4 Randy Thomas GKA Drilling Team Leader -Ç( IfCf'0 rÁd~'V RECEIVED JUL 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage OR\Gl(~ j-'"1. ()'). Co< STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon - Suspend - Alter casing - Repair well - Change approved program X i 2. Name of Operator Phillips Alaska, Inc. 3. Address i P. O. Box 100360 ! Anchorage, AK 99510-0360 , 4. Location of well at surface 1642' FNL, 924' FWL, Section 12, T11 N, R10E, UM At top of productive interval 346' FSL, 1334' FEL, Section 11, T11 N, R10E, UM At effective depth 338' FSL, 1339' FEL, Section 11, T11 N, R1 OE, UM At total depth 338' FSL, 1339' FEL, Section 11, T11 N, R1 DE, UM 12. Present well condition summar Total depth: measured true vertical Effective depth: 6450 4268 6350 4182 measured true vertical Casing Conductor Surface Length 158' 4204' Size 16" 8.625" X 7.625" , Perforation depth: measured No Perforations true vertical No Perforations !TUblng (size, grade, and measured depth I Packers & SSSV (type & measured depth) 13. Attachments Description summary of proposalX 14. Estimated date for commencing operation July 7, 2001 16. If proposal was verbally approved No Tubing Run No Packers or SSSV"s Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development X Exploratory - Stratigraphic - Service - feet feet feet feet Plugs (measured) Junk (measured) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 41.2 feet above pad, 102' above MSL 7. Unit or Property name Other - Kuparuk River Unit 8. Well number 1 C-127 9. Permit number / approval number 201-114 10. API number 50-029-23024-00 11. Field / Pool Kuparuk River Field / West Sak Oil Pool Measured Depth 158' 6438' True vertical Depth 1581 42561 Cemented 9 cu. Yds High Early 635 sx AS 111,410 sx Class G RECEIVED JUL 0 6 2001 Alaska Ofl & Gas Cons. Commission Anchorage Detailed operations program - 15. Status of well classification as: Oil X BOP sketch - Gas- Suspended- Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 Signed ~ ¡'/"'-f1A~~ TItle: Greater Kuparuk Area Drilling Team Leader Date Randy Thomas, I', ~ ~ I y( c:r/¡..., Cir Prepared by Steve McKeever / FOR COMMISSION USE ONLY i Conditions of approval: Notify Commission so representative may witness I Approval no. '~/"\.\ )/1,0 Plug integrity -- BOP Test - Location clearance - ...::LJ - ~~ Mechanical Integrity Test - Subsequent form required 10- ì.\D"t l.. ApPi~Y.~.~.!?Y order of the Commission ORlelNAL SIGNED tj Y J. M. Heusser Form 10-403 Rev 06/15/88 . ORl Commissioner Date ~8ß J SUBMIT IN TRIPLICATE Mark A Chambers 06/29/01 03:56 PM To: Nabors 245 Company Man/PPCO@Phillips, Randy L. Thomas/PPCO@Phillips, Steve McKeever/PPCO@ Phillips, Sharon AlIsup-Drake/PPCO@ Phillips cc: Subject: Re: Request for Procedural Change on 1 C-127 FYI ----- Forwarded by Mark A Chambers/PPCO on 06/29/01 03:58 PM ----- Jane Williamson <Jane_Williamson@admin.state.ak.us> 06/29/01 03:16 PM To: Mark A Chambers/PPCO@Phillips cc: "AOGCC Prudhoe Bay (E-mail)..<aogcc_prudhoe_bay@admin.state.ak.us>. Julie M Heusser <julie_heusser@ admin.state.ak. us> Subject: Re: Request for Procedural Change on 1 C-127 Mark, I have talked with John Crisp. The only problem he had w/ this was swapping over to seawater after C/O without testing casing. If you have to do a top job through the Tam Collar, you will have to N/U BOP's to test casing. Assuming that is not the case, you have approval to proceed. You do need to follow up on this well with a 403 sundry for changes in planned drilling operations per 20AAC25.015 (c) (2). For remaining wells for which we have 401s here (lC-111 and 1C-117), it would be easiest if ammend your 401 application per (20AAC25.005(c) (1). You do not have to send the $100 fee for this change. Good luck with your program, Mark, and thank you for the call. Jane Williamson Petroleum Engineer > Jane: > > Under the Proposed Drilling Program section (13) of the 1C-127 Approved > Permit to Drill it states that after cementing the 8-5/8" x 7-5/8" tapered > casing string and inflating the ECP we intend to nipple down the 21-1/4" > diverter, nipple up the dual completion wellhead and 13-5/8" 5000 psi BOP > and test to 5000 psi. A cleanout assembly would then be picked up and the > well would be cleaned out to +/- 50' below the proposed bottom A-Sand > perforation. Following the cleanout the well would be displaced to > seawater, freeze protected, the BOPE would be nippled down, a 7-1/16" valve > would be installed on top of the wellhead and Nabors 245e would rig down > and move off the well. > > Nabors 245e will move back over the well at a later date to perforate and > install the dual completion. > > Since we do not intend to drill out the shoe or perforate the well at this > time, we would like to change our Proposed Drilling Plan to the following: > > 1. Run and cement the 8-5/8" x 7-5/8" tapered casing string to surface > (cement to be displaced w/ Kill Weight Mud) . > 2. Inflate ECP > 3. Bleed off pressure and confirm floats are holding. > 4. Nipple down 21-1/4" diverter. > 5. Nipple up Vetco Gray 11" 5000 Tubing Head and Flow Riser. > 6. Run in hole with cleanout assembly and cleanout well to +/- 50' below > proposed bottom A-Sand perforation. > 7. Displace well to seawater (confirm well is dead) and freeze protect. > 8. Nipple down riser. > 9. Nipple up 11" 5000 psi flange and 7-1/16" valve. > 10. Rig down Nabors 245e and move off well. > > > > > > If you have any questions please feel free to give me a call. > > Thank you, > > Mark Chambers > Drilling Engineer This revision eliminates the nipple up / nipple down of the 13-5/8" BOPE. This same request was recently approved and performed on well 1C-123 without incident. 118;) 898S-0vG < )[.:IOM 61E1-S9G < A(' tion for Sundry Permitl, We1l1C-127 Revision No.O Saved: 5-Jul-01 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 tile with tl7e commission and identified in the application: The proposed drilling program is listed below. 1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A- Sand. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Perform wiper trip. Circulate and condition hole to run casing. Run hole opener if required. POOH. 5. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: ECP to be inflated as part of primary cement job. Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD. 6.Nipplc down 21"'1/4" divcrter, nipple up dW3! comp~ction wel! head and 13 5/8 x 5000 psi blowout prcventcr stuck tmd test to 5,000 psi. 6. Nipple down 21-1/4" diverter, nipple up dual completion well head and flow riser. 7. RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf. 8. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze protect. Continue POOH backfilling w/ seawater. 9,Nipplc down BOPE ¿:md instuH 7 1/1611 x 5,000 psi full bore valve atop wellhead. 9. Nipple down flow riser and install 7-1/16" x 5,000 psi full bore valve atop wellhead. 10. RD Nabors Rig 245e and move off location. 11. RU E-Line Unit. Complete cement bond log. RD E-line unit, 12. MIRU Nabors Rig 245e. 13. ND full bore valve, nipple up 5,000 psi BOPE and test to 5,000 psi. 14, Pressure casing to 3,000 psi for 30 minutes. 15. RIH with drill bit and casing scrapers. 16. Displace well to filtered brine and perform caustic wash and pickle. POOH. 17. RU E-line unit and RIH with 4-1/2" guns. Perforate A2 / A3-Sands. RD E-Line unit. 18. RIH with workstring (open ended) and perform A-Sand frac. 7/6/01 Sundry Application A(' '.lion for Sundry Permitl, We1l1C-127 Revision No.O Saved: 5-Jul-01 19. RIH and clean out frac sand and perforation debris. POOH. 20. PU tubing conveyed perforating guns. RIH and re-perforate the A-Sand as required. POOH. 21. RIH and set bridge plug +/- 15' below bottom perforation. POOH. 22. PU gravel pack assembly. RIH and tag top of bridge plug. Set packer and perform gravel pack of A sand as designed. POOH. 23. RU slick line unit. RIH and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit. 24. RIH, set packer plug and spot sand on top of packer to catch perforation debris. POOH. 25. RU E-line unit and RIH with 4-1/2" guns. Perforate S / D-Sands. RD E-Line Unit. 26. RIH, circulate sand off top of packer and retrieve packer plug. POOH. 27. PU and RIH with dual string completion assembly as designed. 28. RIH to just above top of gravel pack packer. 29. RU and circulate into top of SSE. PU and perform space out. With seal assembly unstung from SBE, freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-1/2" tubing strings. Land tubing. 30. RU Slick Line Unit. RIH and set plug in XN Nipple below gravel pack packer. 31. Set completion packers as per Service Representative on location. 32. Retrieve plug from XN Nipple. RD slick line unit. 33. ND BOPE, NU Dual Tree and pressure test. 34. RD Nabors 245e and move off. After the rig has moved off a jet pump will be landed in a nipple in the 3-1/2" tubing string and tied back to surface with 2" coil tubing. 'A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when jet pump power fluid is pumped down the 2" coil tubing. 7/6/01 Sundry Application ( ~~]~E :¡ ~~fÆ~~~fÆ A.1~A.SIiA. OIL AlQ) GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. -¡nt AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineer Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 1C-127 Phillips Alaska, Inc. Pennit No: 201-114 Sur Loc: 1642' FSL, 924' FWL, SEC 12, T11N, R10E, UM Btmhole Loc. 338' FSL, 1339' FEL, SEC 11, TIIN, R10E, UM Dear Mr. Trantham: 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. Annular disposal has not been requested as part of the Pennit to Drill application for KRU lC- 127. Based on our current records, no annuli are currently approved for disposal on 1Cpad. The blowout prevention equipment (BOPE) mustbe tested in accordance with 20AAC 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. ' aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED, this' J s-+< day of June,' 2001 jjcÆnclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department, of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~ ~k) 1 a. Type of work: Drill ø Redrill U Re-entry 0 Deepen 0 , 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-036( ¡ 4. Location of well at surface 1 1642' FNL, 924' FWL, Section 12, T11N, R10E, UM , At top of productive interval 346' FSL, 1334' FEL, Section 11, T11 N, R10E, UM i At total depth 338' FSL, 1339' FEL, Section 11, T11N, R10E, UM 12. Distance to nearest property line I 13. Distance to nearest well 338' @ TD feet 1C-10 163 16. To be completed for deviated wells Kickoff depth: 300' MD 18. Casing program size 1b. Type of well. Service ø 20 AAC 25.005 Exploratory U Stratigraphic Test U Development Gas 0 Single Zone 0 5. Datum elevation (OF or KB) RKB = 102 feet AMSL feet 6. Property Designation ADL 25649 ALK 467 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-127 #59-52-180 9. Approximate spud date Amount June 21,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 6474 ' MD / 4282 ' TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2» Maximum surface 1498 psig At total depth (TVD) 1969 psig Setting Depth Development Oil b!J Multiple Zone ø 10. Field and Pool Kuparuk River Field West Sak Oil Pool Maximum hole angle 64 deg Hole Casing Weight 24" 16" 62.5# 9.875" 8.625" 36# 9.875" 7.625" 29.7# Specifications Grade Coupling H-40 Weld N-80 Hyd 511 L-80 BTCM Length 120' 79' 6354 Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 41.2' 41.2' 161' 161' 225 cf AS 1 41.2' 41.2' 120' 120' 670 sx AS III L & 390 sx Class G 120' 120' 6474' 4282' Tapered String - Cemented above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth F"' t Perforation depth: measured " C:1. true vertical 20. Attachments Filing fee ø Property Plat 0 BOP Sketch ø Diverter Sketch 0 Drilling program ø Drilling flL 'd program ø Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ø 21. I hereby ce;ify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-682E Signed ~ 11V\Æ(¿ó I ~M~~l,~ ~mf.t}Trantham Title: Orillíng Engineering SupeNisor Date 'fJUV\ ?Løv'+ PrP-DArp-d bv .c;tevr~ McKp-evp-r Commission Use Onl~ Permit Number API number ,- ¿.) I Approval date r~' /('V-r7 see cover letter :2D I - /.J 9 50- ð ¿ <7"" 2. '3 ö.z /' (t1 I ) If./ I for other requirements Conditions of approval Samples required 0 Yes E No Mud log required 0 Yes 181 No Hydrogen sulfide measures £I Yes 0 No Directional survey required EYes 0 No Required working pressure for BOPE 0 2M; 0 3M; 0 5M; 0 10M;D 0 Other:,>\~t.("' ~"\\~~t.,~NÄt~I~~~'~'\"\"'."" ~\>~()~""~~\C)", ~,\" ~~~\~~ 0 Taylor Seamount by order of l ~/' //.--'7 Approved by Commissioner the commission Date 0 / ) I 0 ,-, OR\G\NA\l- Form 10-401 Rev. 12/1/85. Submit in triplicate ( APPIiCé ,~,' ~ for Permit to Drill, Well 1 C-127 , Revision No.O Saved: 7-Jun-01 Permit It - West Sak Well #1C-127 Application for Permit to Drill Document MòximizE We-II VQIi!,II¡ 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) 4 6. Casi ng and Cementi ng 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 uid Program... ................ ........... ....... ... ... .............. .... ...... ..........................4 Requirements of 20 AAC 25.005(c)(B) 4 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 Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bond i ng. ...... ......... ...... ........... ..... ...... ........ ........... ............ .... ..... ............ 5 Requirements of 20 AAC 25.005 (c)(12) 5 1C-127 PERMIT IT. DOC Page 1 of 8 Printed: 7-Jun-01 Apphc¡r , for Permit to Drill, We1l1C-127 . ," Revision No.O Saved: 7-Jun-01 13. Proposed Dri Iii 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 . Attach me nts ............................................................................................................. 8 Attachment 1 Directional Plan (10 pages) Attachment 2 13-5/8" 5k x 11" 5k BOP System, Nabors Rig 245e (1 page) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (1 page) Attachment 5 Well Schematic (3 pages) 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number as:<;igned by the commis-sion under 20 MC 25.040(b). For a well vdth multiple well branä7es; each branch must similarly be Identified by a unique name and APi number by adding a suffix to the name designated for the vlell by the operator and to the number assigned to the viell by the commis-slon The well for which this Application is submitted will be designated as lC-127. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An applic8tion for a Permit to Drill must be 8t.:r:ompanied by each of the following Items; except for an Item already 017 file with the cammiS!;'7an and identified in the application: (2) a plat identifying the property and the property:5 owners and showing (A)the coordinates of the proposed location of fhe well at the surface, at the top of each objectille formation, and at total depth¡ referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the sutface¡ referenced to the state plane coord1'nate system for this state as maintained by the National Geodetic SUf1,'ey I'll the National Oceanic and Atmospheric Administration; (C) the propos(;d depth of the well at the top of each objective formation and at total depth; Location at Suñace NGS Coordinates Northings: 5,968,597.14 Eastings: 561,930.71 1642' FNL, 924' FWL, Section 12, TllN, Rl0E, UM RKB Elevation 102.0' AMSL Pad Elevation 60.8' AMSL Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5,965,286 346' FSL, 1334' FEL, Section 11, TllN, Rl0E, UM Eastings: 559,702 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 5891 3700 3598 Location at Total Depth NGS Coordinates Northings: 5,965,278 Eastings: 559,697 338' FSL, 1339' FEL, Section 11, TllN, Rl0E, UM Measured Depth, RKB: 6474 Total Vertical Depth, RKB: 4282 Total Vertical Depth, 55: 4180 and 1C-127 PERMIT IT. DOC Page 2 of 8 Printed: 7-Jun-01 ~' Apphcj1 1 for Permit to Drill, We1l1C-127 . ,:' Revision No.O Saved: 7-Jun-01 (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatt4 the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well- Please see Attachment 1: Directional Plan and (2) for all wells withk¡ 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 in public record0 and :,ÝJow that each named operator has been fumisl7ed a copy of the application by certified mail,' or (8) state that tlie applicant is the only affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (3) a diagram and description of'the blowout prevention equipment (80PE) as required by 20 AAC 25.03~ 20 MC 25.036; or 20 AAC 25.037- as applicable; Two different configurations of blowout prevention equipment will be used during rig operations on Well lC-127. For casing clean out operations an API 13-5/8" x 5,000 psi BOP stack will be used. A diagram of this stack is on file with the Commission. 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. During completion operations, a BOP stack combining API 13-5/8" x 5,000 psi preventers with API 11" x 5,000 psi preventers will be used. Please refer to Attachment 2: "13-5/8" 5k x 11" 5k BOP System, Nabors Rig 245e". 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to DriJl must be a(:r:ompanied by each of the following item~ except for an item already on file I/,¡ith the commission and identified in the application: (4) information on drilling hazards, including (A) tlie maximum downhole pressure that may be encountere~ criteria used to determlne it, and maximum potential surface pressure based on 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 WS1-01 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 1498 psi, calculated thusly: MPSP =(4282 ft)(0.46 - 0.11 psi/ft) =1498 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone0 and zones that have a propensity f..r;r differential stic/(ing/ Please see Attachment 3: Drilling Hazards Summary. 1C-127 PERMIT IT. DOC Page 3 of 8 Printed: 7-Jun-01 APPIiC("""'1 for Permit to Drill, We1l1C-127 Revision No.O , Saved: 7-Jun-01 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pem7it to Drill must be accompanied by each of Nle following item~ except for an item already on file witl¡ the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test~ as required under 20 AAC 2S030(f); 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 "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission with the Application for Permit to Drill for weIl1C-133, dated April 26th, 2001. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be aŒompanied by each of the following item~ except for an item alreat.1v 017 file wIth the commi!;:,:;ion and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030/ and a description of any slotted line0 pre- perforated line0 or screen to be Installed; Casing and Cementing Program Hole Size (in) 24 8-5/8 7-5/8 Cement Program Cemented to surface with 225 cf ArcticSet 1 Tapered String Cemented to Surface with 670 sx ASLite Lead, 390 sx Class G Tail Additionally, the 'A' Sand will be completed by perforating through the 7-5/8" casing, and then gravel packing between the casing and a set of screens and excluders inside the casing. See also Attachment 4: Cement Loads and CemCADE Summary, and Attachment 5: Completion Schematic Weight (Iblft) 62.5 Grade H-40 Connection Welded Length (ft) 120 Top MO/TVO (ft) 41/41 Btm MO/TVO (ft) 161 / 161 Csg/Tbg 00 (in) 16 9-7/8 9-7/8 36 N-80 Hyd 511 79 41/41 120 / 120 120 / 120 6474 / 4282 29.7 L-80 STCM 6354 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a PermIt to Drill must be accompanied by each of the following Item~ except for an item already on file with the comrnission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25: 035~ unless this requirement Is waived by the commission under 20 AAC 25:035(17)(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 weIl1C-133, dated April 26th, 2001. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application tòr a Permit to Drill must be accompanied by each of the fo/Jowing items, except for an item already on tHe v/ltll the commission and identified in the application: (lJ) a drilling flUId program/ includfi7g a diagram and description of the drilling r7uid system/ as required by 20 AAC 2.5.033; Drilling will be done with a bentonite slurry having the following properites over the listed intervals: 1C-127 PERMIT IT.OOC Page 4 of 8 Printed: 7-Jun-01 APPIiC{~' , for Permit to Drill, Well 1 C-127 Revision No.O Saved: 7-Jun-01 Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.5 9.4 - 9.6* Funnel Viscosity 150-200 150-200 (seconds) Yield Point 30-60 30-60 (cP) Plastic Viscostiy 8-15 11- 22 (lb1100 sf) 10 second Gel 15- 30 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 Strength (lb1100 sf) pH API Filtrate(cc) 8-15 6 Solids (%) 5-8 5-8 Base of Permafrost to Total Depth Initial Value Final Value 9.4 9.4 150 75 25-45 25-45 11- 22 11- 22 15-30 15-30 25-55 25-55 8-9 8-9 5-6 5-6 5-8 6-11 *9.8 ppg if hydrates are encountered Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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-Vf- 5 Centrifuges, Degassers, PVf System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by ead; of the following ¡tem0 except for an item already on file with the commis..sion and identified in the application: (9) for an explorato/Y or stratigraphic test vvell a tabu/ation setting out the depths ofpredícted abnormally geo-pressured strata as required by 20 MC 25. 033{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 app/ication for a Permit to Dri/I must be aŒompanied by each of the fo//owing item0 except for an item already on file ~',¡ith the commiS;;,7on and identified in the application: (iO) for an exploratory or stratigraphic test well; a seismic refraction or reflection analysis as required by 20 AAC 25.061{a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dlill must be accompanied by each of the fol/owing itemf:,~ except for an item already on file with the commission and identified in the applIcation: (il) for a well dn/led from an offshore platfo¡m; mobIle bottom-founded structure; jack-up rig; or floating dn/ling vessel an analysis olseabed conditIons as requìred 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 Dd/I mU!:J-t be accompanied by eaä7 of the following item'i; eXCéyJt for an item already on file with the commission and identified in the applIcation: (12) evidence showing that the requirements of 20 AAC 2li02S {Bonding}have been met/ 1C-127 PERMIT IT. DOC Page 5 of 8 Printed: 7-Jun-01 APPIiCi,'," 'for Permit to Drill, We1l1C-127 , Revision No.O Saved: 7-Jun-01 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 app/iCôtion for a Permit to Drill must be accompanied by each of the to/lowing item~ except tor an item already on tÎle with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A- Sand. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Perform wiper trip. Circulate and condition hole to run casing. Run hole opener if required. POOH. 5. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: ECP to be inflated as part of primary cement job. Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD. 6. Nipple down 21-1/4" diverter, nipple up dual completion well head and 13-5/8 x 5000 psi blowout preventer stack and test to 5,000 psi. 7. RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf. 8. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze protect. Continue POOH backfilling w/ seawater. 9. Nipple down BOPE and install 7-1/16" x 5,000 psi full bore valve atop wellhead. 10. RD Nabors Rig 245e and move off location. 11. RU E-Line Unit. Complete cement bond log. RD E-line unit, 12. MIRU Nabors Rig 245e. 13. ND full bore valve, nipple up 5,000 psi BOPE and test to 5,000 psi. 14. Pressure casing to 3,000 psi for 30 minutes. 15. RIH with drill bit and casing scrapers. 16. Displace well to filtered brine and perform caustic wash and pickle. POOH. 17. RU E-line unit and RIH with 4-1/2" guns. Perforate A2 / A3-Sands. RD E-Line unit. 18. RIH with workstring (open ended) and perform A-Sand frac. 1C-127 PERMIT IT. DOC Page 6 of 8 Printed: 7-Jun-01 Apphcéf "for Permit to Drill, We1l1C-127 . " Revision No.O Saved: 7-Jun-01 19. RIH and clean out frac sand and perforation debris. POOH. 20. PU tubing conveyed perforating guns. RIH and re-perforate the A-Sand as required. POOH. 21. RIH and set bridge plug +/- 15' below bottom perforation. POOH. 22. PU gravel pack assembly. RIH and tag top of bridge plug. Set packer and perform gravel pack of A sand as designed. POOH. 23. RU slick line unit. RIH and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit. 24. RIH, set packer plug and spot sand on top of packer to catch perforation debris. POOH. 25. RU E-line unit and RIH with 4-1/2" guns. Perforate B / D-Sands. RD E-Line Unit. 26. RIH, circulate sand off top of packer and retrieve packer plug. POOH. 27. PU and RIH with dual string completion assembly as designed. 28. RIH to just above top of gravel pack packer. 29. RU and circulate into top of SBE. PU and perform space out. With seal assembly unstung from SBE, freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-1/2" tubing strings. Land tubing. 30. RU Slick Line Unit. RIH and set plug in XN Nipple below gravel pack packer. 31. Set completion packers as per Service Representative on location. 32. Retrieve plug from XN Nipple. RD slick line unit. 33. ND BOPE, NU Dual Tree and pressure test. 34. RD Nabors 245e and move off. After the rig has moved off a jet pump will be landed in a nipple in the 3-1/2" tubing string and tied back to surface with 2" coil tubing. \A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when jet pump power fluid is pumped down the 2" coil tubing. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Pe/mlt to DrHI mustc be accompanied by each of the following Item~ except for an Item already on file with the commissíon and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular dl<iposa/ operation in the well.j: Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1C pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either processed through the ball mill (part of the drilling rig) and injected down a permitted annulus or approved disposal well, or stored temporarily on site, then hauled to the Prudhoe Bay Field for 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. 1C-127 PERMIT ITDOC Page 7 of 8 Printed: 7-Jun-01 APPIiCi,',V '1 for Permit to Drill, Well 1 C-127 , Revision No.O Saved: 7-Jun-01 15. Attachments Attachment 1 Directional Plan (11 pages) Attachment 2 13-5/8" 5k x 11" 5k BOP System, Nabors Rig 245e (1 page) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (1 page) Attachment 5 Well Schematic (3 pages) 1C-127 PERMIT IT. DOC Page BofB Printed: 7-Jun-01 240 - .,¡¡, -. 0 - ~ 960 - 1200 - ..-... 1440- - (l) (l) "I- ......." 1680- ..c:: - Cl. (l) 1920- 0 0 2160- U :¡:: I... (l) > 2400 - (l) ::J I... 2640 - l- I V 2880 - 3120 - 3360 - 3600 - 3840 - 4080 - 4320 - 4560 Phillips Alaska, Inc. Structure: Pad 1 C Well: 127 Field: Kuparuk River Unit Location: North Slope, Alaska Created by finch Dot. plotted: 26-Uor-2DD1 Plot Reference is 127 Ver (12. ~ ~," ~ For: S McKeever ESTIMATED RKB ELEVATION: 91' Coordinates ore in feet reference slot 1127. True Vertical Depths are reference Est. RKB 91'. Ríï8 IIAKDt HUGIES 240 - KOP .. 3,00 .. 6.00 .. 9.00 480 - INTE() 720- DLS: 3.00 deg per 100 ft 214.40 AZIMUTH 4000' (TO TARGET) Begin Turn 20.53 26,27 32.09 37.97 43.87 49.79 55.73 61.67 DLS: 6.00 deg per 100 ft ***Plane of Proposal*** MAXIMUM ANGLE 63.61 DEG TARGET ANGLE VERTICAL 0 240 480 EOC Bose Permafrost Top K-15 Begin Drop 60.00 55.00 50,00 45.00 Top Ugnu C 40.00 DLS: 5.00 deg per 100 ft 35,00 30.00 Top Ugnu B 25.00 Top Ugnu A 20,00 K1315.00 Top W Sak D 10,00 C B 5.00 A4 Target A3/EOC A2 A 1 Bose Pay Base W Sak TD - Casing Pt 720 960 1200 1440 1680 1920 2160 2400 2640 2880 3120 3360 Vertical Section (feet) -> Azimuth 214.40 with reference 0.00 N, 0.00 E from slot #127 " ~ .. ~ ~l 3600 3840 4080 ( Created by finch For: S McKeever Dote plotted: 27-lAor-2001 Plot Reference is 127 Ver '2. Coordinates ore in feet reference s50t 1127. Phillips Alaska, Inc. True Vertical Depths are reference Est. RKB 91'. Bf1I: Structure: Pad 1 C Well: 127  ............ ...... ("pmuJPs"\ .(Ð Field: Kuparuk River Unit Location: North Slope, Alaska 2400 2240 2080 1920 1760 1600 1440 <- West (feet) 1280 1120 960 800 640 480 320 160 INTEQ ESTIMATED SURFACE LOCATION: 1639' FNL, 923' FWL SEC. 12. T11N, R10E 214.4 AZIMUTH 4000' (TO TARGET) ***Plane of Proposal*** TRUE - 0 - 160 - 320 - 480 - 640 - 800 - 960 -1120 -1280 -1440 (/) 0 c:: -+- -1600 :r ".-.., -h ( ) -1760 ~ '-" I -1920 V - 2080 - 2240 - 2400 - 2560 - 2720 - 2880 - 3040 - 3200 I TARGET/TD LOCATION: I - 3360 340' FSL, 1340' FEL SEC. 11, T11 N, R10E f Phillips Alaska, Inc. ~ Crealed by conferrm For: S McKeever Structure: Pad 1 C Well: 127 ~ Date plotted: 27-Mar-2001 Plot Reference is 127 Ver 1/2, Field: Kuparuk River Unit Location: North Slope. Alaska Coordinates are in feet reference slot 1/127, True Vertical Depths are reference Est. RKB 91', "Ii BAKER HUGHES TNTEQ ==== PROF~LE COMMENT DATA ==== = ====== = ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 KOP 300.00 0.00 236.00 300.00 0.00 0.00 0.00 0.00 Begin Turn 800.00 15.00 236.00 794.31 -36.39 -53.95 60.51 3.00 EOC 1632.51 63.61 213.41 1421.67 -433.37 -368.75 565.90 6.00 Base Permafrost 2400.31 63.61 213.41 1 763.00 -1007.50 -747.41 1253.56 0.00 Top K-15 3484.56 63.61 213.41 2245.00 -1818.27 - 1 282. 1 3 2224.64 0.00 Begin Drop 4756.73 63.61 213.41 2810.54 -2769.55 -1909.53 3364.02 0.00 Top Ugnu C 5232.20 39.83 213.41 3103.00 -3078.90 -2113.55 3734.53 5.00 Top Ugnu B 5542.36 24.32 213.41 3365.00 -3215.98 -2203.96 3898.71 5.00 Top Ugnu A 5598.82 21.50 213.41 3417.00 -3234.33 -2216.06 3920.69 5.00 K13 5756.27 13.63 213.41 3567.00 -3273.96 -2242.21 3968.16 5.00 Top W Sak D 5880.42 7.42 213.41 3689.00 -3292.88 -2254.68 3990.82 5.00 C 5915.65 5.66 213.41 3724.00 -3296.23 -2256.89 3994.84 5.00 ."""""". B 5944.76 4.20 213.41 3753.00 -3298.32 -2258.27 3997.34 5.00 A4 5979.82 2.45 213.41 3788.00 -3300.02 -2259.39 3999.37 5.00 Target A3/EOC 6028.84 0.00 213.41 3837.00 -3300.89 -2259.97 4000.42 5.00 A2 6103.84 0.00 213.41 3912.00 -3300.89 -2259.97 4000.42 0.00 A1 Base Pay 6212.84 0.00 21 3.41 4021 .00 -3300.89 -2259.97 4000.42 0.00 Base W Sak 6307.84 0.00 21 3.41 41 1 6.00 -3300.89 -2259.97 4000.42 0.00 TD - Casinq pt 6462.84 0.00 213.41 4271 .00 -3300.89 -2259.97 4000.42 0.00 Standard Report Page 1 of 3 ( Phillips Alaska, Inc. Pad 1C 127 slot #127 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 127 Ver #2 Our ref: prop4376 License: Date printed: 26-Mar-2001 Date created: 8-Jan-2001 Last revised: 26-Mar-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.053,w149 29 52.183 Slot Grid coordinates are N 5968596.841, E 561929.843 Slot local coordinates are 1639.00 S 923.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Standard Report Page 2 of 3 Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,127 Your ref: 127 Ver #2 Kuparuk River Unit, North Slope, Alaska Last revised: 26-Mar-2001 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 0.00 0.00 236.00 0.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 236.00 300.00 0.00 N 0.00 E 0.00 0.00 KOP 400.00 3.00 236.00 399.95 1. 46 S 2.17 W 3.00 2.43 500.00 6.00 236.00 499.63 5.85 S 8.67 W 3.00 9.73 600.00 9.00 236.00 598.77 13 .15 S 19.49 W 3.00 21. 86 700.00 12.00 236.00 697.08 23.34 S 34.60 W 3.00 38.80 800.00 15.00 236.00 794.31 36.39 S 53.95 W 3.00 60.51 Begin Turn 900.00 20.53 228.30 889.51 55.31 S 77.80 W 6.00 89.59 1000.00 26.27 223.81 981. 26 82.97 S 106.23 W 6.00 128.48 1100.00 32.09 220.84 1068.54 119.07 S 138.95 W 6.00 176.75 1200.00 37.97 218.71 1150.39 163.21 S 175.59 W 6.00 233.86 1300.00 43.87 217.07 1225.93 214.90 S 215.75 W 6.00 299.21 1400.00 49.79 215.76 1294.31 273.59 S 258.99 W 6.00 372.06 1500.00 55.73 214.65 1354.80 338.63 S 304.84 W 6.00 451.63 1600.00 61.67 213.69 1406.73 409.30 S 352.79 W 6.00 537.03 1632.51 63.61 213.41 1421.67 433.37 S 368.75 W 6.00 565.90 EOC 2000.00 63.61 213.41 1585.04 708.16 S 549.99 W 0.00 895.03 2400.31 63.61 213.41 1763.00 1007.50 S 747.41 W 0.00 1253.56 Base Permafrost 2500.00 63.61 213.41 1807.32 1082.04 S 796.57 W 0.00 1342.84 3000.00 63.61 213.41 2029.59 1455.93 S 1043.16 W 0.00 1790.65 3484.56 63.61 213.41 2245.00 1818.27 S 1282.13 W 0.00 2224.64 Top K-15 3500.00 63.61 213.41 2251.86 1829.81 S 1289.75 W 0.00 2238.46 4000.00 63.61 213.41 2474.14 2203.70 S 1536.33 W 0.00 2686.28 4500.00 63.61 213.41 2696.41 2577.58 S 1782.92 W 0.00 3134.09 4756.73 63.61 213.41 2810.54 2769.55 S 1909.53 W 0.00 3364.02 Begin Drop 4828.84 60.00 213.41 2844.61 2822.60 S 1944.52 W 5.00 3427.55 4928.84 55.00 213.41 2898.32 2892.98 S 1990.94 W 5.00 3511. 85 5028.84 50.00 213.41 2959.18 2959.19 S 2034.60 W 5.00 3591.15 5128.84 45.00 213.41 3026.72 3020.71 S 2075.18 W 5.00 3664.84 5228.84 40.00 213.41 3100.42 3077.09 S 2112.36 W 5.00 3732.37 5232.20 39.83 213.41 3103.00 3078.90 S 2113.55W 5.00 3734.53 Top Ugnu C 5328.84 35.00 213.41 3179.73 3127.90 S 2145.87 W 5.00 3793.21 5428.84 30.00 213.41 3264.04 3172.73 S 2175.44 W 5.00 3846.92 5528.84 25.00 213.41 3352.72 3211. 27 S 2200.86 W 5.00 3893.07 5542.36 24.32 213.41 3365.00 3215.98 S 2203.96 W 5.00 3898.71 Top Ugnu B 5598.82 21.50 213.41 3417.00 3234.33 S 2216.06 W 5.00 3920.69 Top Ugnu A 5628.84 20.00 213.41 3445.07 3243.20 S 2221.92 W 5.00 3931. 32 5728.84 15.00 213.41 3540.42 3268.30 S 2238.47 W 5.00 3961.38 5756.27 13.63 213.41 3567.00 3273.96 S 2242.21 W 5.00 3968.16 K13 5828.84 10.00 213.41 3638.01 3286.36 S 2250.38 W 5.00 3983.01 5880.42 7.42 213.41 3689.00 3292 . 88 S 2254.68 W 5.00 3990.82 Top W Sak D 5915.65 5.66 213.41 3724.00 3296.23 S 2256.89 W 5.00 3994.84 C 5928.84 5.00 213.41 3737.13 3297.25 S 2257.57 W 5.00 3996.06 5944.76 4.20 213.41 3753.00 3298.32 S 2258.27 W 5.00 3997.34 B 5979.82 2.45 213.41 3788.00 3300.02 S 2259.39 W 5.00 3999.37 A4 6028.84 0.00 213.41 3837.00 3300.89 S 2259.97 W 5.00 4000.42 WS 1C M4 (5-DEC-00) 6103.84 0.00 213.41 3912.00 3300.89 S 2259.97 W 0.00 4000.42 A2 6212.84 0.00 213.41 4021.00 3300.89 S 2259.97 W 0.00 4000.42 Al Base Pay 6307.84 0.00 213.41 4116.00 3300.89 S 2259.97 W 0.00 4000.42 Base W Sak 6462.84 0.00 213.41 4271.00 3300.89 S 2259.97 W 0.00 4000.42 TD - Casing pt All data is in feet unless otherwise stated. Coordinates from slot #127 and TVD from Est. RKB 91' (91.00 Ft above mean sea level). Standard Report Page 3 of 3 Bottom hole distance is 4000.42 on azimuth 214.40 degrees from wellhead. Total Dogleg for wellpath is 128.56 degrees. Vertical section is from wellhead on azimuth 214.40 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad lC,127 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 127 Ver #2 Last revised: 26-Mar-2001 Comments in wellpath -------------------- -------------------- MD T~ Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 800.00 794.31 36.39 S 53.95 W Begin Turn 1632.51 1421.67 433.37 S 368.75 W EOC 2400.31 1763.00 1007.50 S 747.41 W Base Permafrost 3484.56 2245.00 1818.27 S 1282.13 W Top K-15 4756.73 2810.54 2769.55 S 1909.53 W Begin Drop 5232.20 3103.00 3078.90 S 2113.55W Top Ugnu C 5542.36 3365.00 3215.98 S 2203.96 W Top Ugnu B 5598.82 3417.00 3234.33 S 2216.06 W Top Ugnu A 5756.27 3567.00 3273.96 S 2242.21 W K13 5880.42 3689.00 3292.88 S 2254.68 W Top W Sak D 5915.65 3724.00 3296.23 S 2256.89 W C 5944.76 3753.00 3298.32 S 2258.27 W B 5979.82 3788.00 3300.02 S 2259.39 W A4 6028.84 3837.00 3300.89 S 2259.97 W WS lC M4 (5-DEC-00) 6103.84 3912.00 3300.89 S 2259.97 W A2 6212.84 4021. 00 3300.89 S 2259.97 W Al Base Pay 6307.84 4116.00 3300.89 S 2259.97 W Base W Sak 6462.84 4271.00 3300.89 S 2259.97 W TD - Casing pt Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 6462.84 4271.00 3300.89S 2259.97W 7 5/8" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS lC M4 (5-DEC-00) 559697.000,5965278.000,0.0000 3837.00 3300.89S 2259.97W 8-Jan-2001 Summary Clearance Report Page 1 of 1 Phillips Alaska, Inc. Pad lC 127 slot #127 Kuparuk River Unit North Slope, Alaska (: SUM MAR Y C LEA RAN C ERE paR T by Baker Hughes INTEQ Your ref: 127 Ver #2 Our ref: prop4376 License: Date printed: 26-Mar-2001 Date created: 8-Jan-2001 Last revised: 26-Mar-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.053,w149 29 52.183 Slot Grid coordinates are N 5968596.841, E 561929.843 Slot local coordinates are 1639.00 S 923.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath GMS <0-7753'>,,5,Pad 1C GMS <0-10243'>,,6,Pad 1C GMS <0-9784'>,,7,Pad 1C PGMS <0-9002'>,,10GI,Pad 1C Unknown Data"WS1,Pad 1C PMSS <0 - 10969'),,17,Pad 1C PMSS <0-8677'>,,13,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C MSS <0-7000'>,,9GI,Pad 1C PMSS <0-6529'>,,23 PB1,Pad 1C PMSS <1840-13975>,,23A,Pad 1C PMSS <0-10140'>,,25,Pad 1C PMSS <0-13910'>,,27,Pad 1C PMSS <0-14630'>,,26,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C GMS <0-7780'>"l,Pad 1C PMSS <0-9390'>,,15,Pad 1C PMSS <0-10980'>,,14,Pad 1C GMS <0-7575'>,,4,Pad 1C MMS <6948-7570'>"WS#24,Pad 1C GMS <0-9600'>,,8,Pad 1C PMSS <0-11300'>, ,11,Pad 1C PMSS <0-17089'>,,12,Pad 1C GMS <0-7615'>, ,2,Pad 1C GMS <0-9700'>,,3,Pad 1C Reference North is True North Closest approach with 3-D Last revised Distance 18-Dee-1998 196.0 18-Dee-1998 264.0 18-Dee-1998 360.1 18-Dee-1998 163.5 2-Nov-1998 7420.4 2-Dee-1998 434.9 1-Dee-1998 247.4 8-Jan-1999 228.4 2-Jan-1998 435.0 13-Jul-1999 354.6 8-Jun-1999 354.6 4-Jun-1999 405.8 1-Jan-1999 434.8 24-Aug-1999 420.7 22-Feb-1999 182.3 11-Mar-1999 448.0 17-Dee-1998 316.0 18-Mar-1998 228.0 18-Dee-1998 189.3 17-Dee-1997 11136.8 18-Dee-1998 468.5 19-Mar-1997 502.4 7-Jan-1998 487.4 18-Dec-1998 341.2 18-Dee-1998 248.4 Minimum Distance method M.D. Diverging from M.D. 0.0 311.1 300.0 300.0 300.0 300.0 1216.7 6462.8 875.0 875.0 100.0 100.0 260.0 6320.0 100.0 100.0 916.7 916.7 0.0 0.0 0.0 0.0 322.2 322.2 0.0 0.0 0.0 0.0 280.0 280.0 300.0 300.0 100.0 100.0 100.0 100.0 0.0 6462.8 900.0 6462.8 0.0 422.2 280.0 280.0 400.0 400.0 300.0 6462.8 300.0 6380.0 ( { Phillips Alaska, Inc. Creoted by finch For: S McKeever Dale ploUed : 26-1.10(-2001 Plot Reference is 127 Ver 1l2. Coordinates are in feet reference slot '127. Structure: Pad 1 C Well: 127 ~ r¡r¡a t ~ Field: Kuparuk River Unit Location: North Slope. Alaska True Vertical Depths ore reference Est. RKB 91', tn. BAJCD HUOIIES INTF:Q 240 ~~ ~ , I , \ 300 60 ~ III 70 II -6J 300 290 280 80 270 90 260 100 250 110 120 230 130 220 140 210 150 200 160 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 190 \ \ \ \ 1200 \ \ \ 1100 /B 400 \ / " 500 " 1 000 / / .. ~OO ~300 / .. 700 / / / " //800 / / / / Ii' '900 / / / / / / / )1</1000 / / / / / / / / / / ,111 00 / / / / / / / / .. 1500 / / / / / 'I¥/1200 / / I / / / / / / / / / I / / / / I I / @) 600 /'if' 700 /'if' / 800 / / ",/ / , / 900 // f I I I I I 1000 / iI' I I I I / / / / 1100 / .. / I 1800 I I I I I I I I ~ 1200 I I I I I I I I I I I I I I I .1300 I I ( Phillips Alaska, Inc.1 C'eoted by finch For: S McKeever Dote plotted: 26-lAo'-2oo1 Plot Reference is 127 Ver 12. Coordinates are in feet reference slot '127. True Vertical Depths ore reference Est. RKB 91'. 1ft. IIAKIR HUGHES INTIi:Q Structure: Pad 1 C Well: 127 Field: Kuparuk River Unit Location: North Slope, Alaska <- West (feet) 120 100 80 I , 1$1 ø & , "600 /.$¡oo - / / / ~áoo / "'ioo / "'500 / / "600 - - - - - - ""'g~O , / ¡¡(800 / ...- - - '/ / .. 700 0 - - 1000 - @ - - - - II< / Ii' /800 ///////900 20 - / / - /900 / - / / / - - / / / *"1000 40 - - - ~ - / --";100 />1' 1000 & 60 - 80- //-/1100 100- / -&// 260 240 220 200 180 160 140 60 40 - ;$-300 / ... 600 / JO /700 / / ;t 800 20 - --.. -+- ( ) ( ) 120- - ........... / , / '" 900 / / / / / ' 'II 1 000 / / / , / / / >I' 11 00 / , / / / / / .. 1400 / /"" ;200 ..c -+- :J 0 Ui I V / / / / / , / / / )If/1300 -43< 180 - CY 140- 160- 200- 220- 1900 .. 1600 240 - 260- 280- 300- .. 1700 320- ~ , I I " 260 240 220 200 180 160 ,@, , 140 , , 120 100 80 <- West (feet) , 60 - 60 4- 1100"P / - 80 .(1200 I I I y/ 1 300 I I I / .. 1400 / / / I 40 20 0 , ~ .. 1500 I I I I I I ,¡. 1600 I I I I I I I ~ 1700 I I I I I I I I + 1800 I 40 I I I I I I I I \ ~ , 0 I 20 ~~ r¡T¡a , ~ 20 40 - 40 - 20 - 0 - 20 /$40 -100 (j) 0 -120 S :T --.. - 140 CD CD -+- ........... -160 I V - 180 - 200 - 220 - 240 - 260 -280 - 300 - 320 , 20 I 40 / / / / / / / / 11300 / / / / / 2100 / / / / / / 2200 / /1400 / / / / / / / / I / / / / / I / / / / / 11500 / / / / / / / / / / I / / / / I / / / ./1600 / / / / / / / / / / / I I / / / / @ ( Phillips Alaska, Inc.1 Crected by finch For: S McKeever Date plotted: 26-Mor-2001 Plot Reference is 127 Ver #2, Coordinates ore in feet reference s.lot '127. Structure: Pad 1 C Well: 1 27 Field: Kuparuk River Unit Location: North Slope, Alaska True Vertical Depths ore reference Est. RKB 91', 10. BAKIiIt HUGHES INTF:Q 760 <- West (feet) 480 440 400 360 720 680 640 600 560 520 ~~~(ß /,' /"" "400 ~ ~ ~...t500 ... ... it' ;600 ... ... -1ßX 400- W ~~~~~~~ ..-~ 200 ~ ~ ~ ~ ~ ~ - ~ ~ ~ ~ ~ ~ 1500 @-- 240- 160 - ..c 0+- :J 0 (J") I V 140~",'" ... ... ... 150~.. ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... 1600)1''''''' ... ... ... ... ... ... 560 - &... 280 - 320 - 360- 440- "........, ~ Q) 480 - - ........... 520- 600 - 640 - 680- 720- 760 - 800- 840- 880 - I 760 I 720 I 680 I 640 I 600 I 560 I 520 I 480 I 400 <- West (feet) I 440 I 360 320 240 ~'181' 1 300 J.iY lÇJ ... )I' 1500.. ... ... 280 I 320 I 280 ~~ ~, ~ 200 160 '# / / / 11200 -160 - 200 240 -280 - 320 -360 - 400 - 440 (J) 0 -480 c: - ::J "........, - 520 - CD CD - ........... - 560 I V - 600 - 640 - 680 -720 -760 -800 -840 - 880 .. 1700 I 240 I 200 , 160 ( Phillips Alaska, Inc. Created by finch For: S McKeever Date plotted: 26-loIor-2001 Plot Reference is 127 Vcr '2. Coordinates are in feet reference slot 1127. Structure: Pad 1 C Well: 127 Field: Kuparuk River Unit Location: North Slope, Alaska True Vertical Depths ore reference Est. RKB 91.. lIit. BAICD HUGHES INTIi:Q <- West (feet) 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 ..s:: of- :J 0 (/) I V __~_~~' '& '& ~ I / / / 1 6oS./ / II - - - - - - .ÃJZÓOO : / /*Í 800 / " 2400 / ~~ ././ / --.-- I/'I ------ 2200 2000../t~800 // 1;600 _..-: -- ,/ ,/ I .. ,/ /* 800 - - - -- - - 2400 / / I /" 1800 I - -- .- - ~26;O 2200 ./,/ 30o.øí 1/ r:-;;\\ X / / I I 1000-~- / / I I 3200 / / I I 3400 ..-; / )0'2000 I 11800 / / 2400 / " I I ,/,/ ! I " ~600 / / I / /" I / )102800 / / I / ., 3000 .. " I I .. 3200 ,,2200 I '* 2000 @]./ / I I 3600 " " I I / I /',/ ¡ I / II / À /2400 II / / " 2200 I : / I / I I ,/,/ I ¡ ,// I I '" I I / / 2600 / I / / 2400"" I / I I / I I 2200 - " " I I ./n<3< / / I -& I I I I 2600¡ : II I I I I I I I I 2800"" I I I I I I 30001 I 3200/ 3400/ 3600L l!12J 400 - 600 - 1200- 1400- 1600 - 1800- -. Q) Q) 2000- - "-'" 2400 - 2600 - 8 2800 - 3000 - 3200 - 3400 - 3600 - 3800 - 4000 - 3000 2800 2600 2400 2200 2000 600 1800 1600 1200 1400 1000 800 <- West (feet) ~ ~ ~ 400 200 0 ~1~00 - 400 I I I ~ 1 600 - 600 I I I - 800 ,1800 - I I I - 1200 - 1400 -1600 ~ I 2600 . - 1800 I I (/) I I 0 2800 *' - 2000 c: - I :r I I -. I - 2200 - 3000 * ( ) I ( ) ~ - "-'" - 2400 I V - 2600 - 2800 - 3000 - 3200 - 3400 - 3600 - 3800 - 4000 400 200 0 13-5/811 5k x 11r.' 5k BOP System, Nab( ~s Rig 245e West Sak Dual Purpose Wells, Running Completion ---6 L 9 ~ 5 ~ Þ 8 ~ Þ ~ ~ ~ 7 ~ 6 ~ ~ ~ 5 Þ [ ] 4 [ ] 3 ~ ~[ ] Top of Vetco Gray 2 11-5K Tubing Head J 11 I" I I I I I I 8-5/8" Casing ¡! ' 16" Casing ~ ~ KEY: 1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 8-5/8" x 7-5/8" Casing Landed, Vetco Gray. 2. Tubing Head, 10-3/4" Vetco Gray Quick Connect Bottom x API 11" 5000 psi Flange Up, Vetco Gray. 3. Double Studded Adapter I Spacer Spool, 11" x 13-5/8" 5000 psi, Nabors. 4. Spacer Spool(s), 13-5/8" 5000 psi x 13-5/8" 5000 psi, Nabors. 5. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams, Nabors Typical Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. Typical BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 5000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 5000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi low and 5000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 5000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of Arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 5000 psi. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 6. Drilling Spool, 13-5/8" x 5000 psi, w/2 Side Outlets, Nabors 7. Adapter Flange, 13-5/8 x 5,000 psi bottom, 11" X 5,000 PSI top 8. Double Ram BOP, 11" x 5000 psi, with Dual Offset Pipe Rams 01 Top and Blind Rams on Bottom, Nordic 9. Annular BOP, 11" x 5000 psi, Hydril GK, Nordic 10. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nabors 11. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors 12. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors 13. Kill Line Valve, Hydraulically Operated, 3-1/8" x 5,000 psi, Nabors prepared by Steve McKeever 6n/01 ( lC-127 Drillinq Hazards Summa~ (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open Hole / 8-5/8" x 7-5/8" Casina Interval Hazard Broach of Conductor Risk Level I Mitigation Strategy Moderate Monitor cellar continuously during interval. Gas Hyd rates Moderate Running Sands and Gravels Moderate Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Dri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run gravel isolation string. Diverter drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling, pumping out 1 C-133 Drilling Hazards Summary prepared by Mark Chambers 2/18/01 West Sak 1C-127 Dual pu.\- .~e Well, Cement Loads and CemCAD:.J: .mmary. 35 % Excess Below permafrost, 250 % Above permafrost with 50 bbls to surface. 9-7/8" Openhole. TD @ 6463' MD. 7-5/8", 29.7# Casing. Base of permafrost @ 2400' MD. Port collar for no cement to surface contingency. Port Collar @ 1000' MD. Tail Slurry TOC @ 5380' MD. (500' above D Sand. ECP @ 5980' MD. Volume Cales: Pump 40 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 5380' MD with Class G + adds @ 15.8 ppg, and from 5380' to surface with ASLite @ 10.7 ppg. Leave cement in casing for ECP inflation. Lead Slurry Requirements: AS Lite @ 10.7 ppg, Class G + 50% D124, 3.5% D44, 0.4% D46, 30% D53, 1.5% S 1, 1.5% D79 - 4.44 ft3/sk (5380' - 2400') x 0.2148 ft3/ft x 1.35 (35% excess) 2400' x 0.2148 x 3.5 (250% excess) 50 bbls cement to surface Total 2949.21 ft3/4.44 ft3/sk = 864.14 ft3 = 1804.32 ft3 = 280.75 ft3 = 2949.21 ft3 = 664.2 sks Round upto 670 sks Tail Slurry Requirements: Expanding Cement @ 15.8 ppg, Class G + 0.45% D65, 0.3% M117, 2.0 gps D600G, 0.1 % D135, 0.2% D47, 3.0% D174 - 1.2 ft3/sk (6463' - 5380') x 0.2148 ft3/ft x 1.35 (35% excess) 80' (shoe joints) x 0.2578 ft3/ft (6383' - 5980') x 0.2578 ft3/ft (5 bbls above ECP) Total 466.64 ft3/l.2 ft3/sk = 314.05ft3 = 20.62 ft3 = 103.89 ft3 = 28.08 ft3 = 466.64ft3 = 388.86 sks Round upto 390 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW. 40 bbl CWI00 preflush, Drop Bottom Plug, 50 bbls 10.0 ppg MudPUSH XL spacer, 670 sks (530 bbls) AS Lite Lead, 285 sks (61 bbls) Class G + adds, Drop Top Plug, Pump additional 105 sks (22 bbls) Class G + adds on top of the plug. Displacement is approximately 270 bbls. Circulation: Circulation and cementing at or less than 6 bpm is within safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Estimated maximum surface pressure during the job is 500 psi. Run dye marker in the spacer to provide insight into the decision to open port collar or performing a top job. Recommended Conditioned Mud Properties: 9.6 ppg, PV < 12, Ty < 12, as thin and light as possible for effective mud removal. 04-30-2001 AT Well # 1C-127, AFE #AK0174 West Sak Dual Purpose Well Completion Schematic Sheet 1 of 3: Casing String Details Tubing Head, Vetco-Gray Horizontal for Dual Completion, API 1111 5000 psi Flange up x Vetco 13-5/811 Female Overshot Bottom Landing Ring: Vetco-Gray, 1611 Weld on Bottom x 13-5/811 Male Overshot Top 1611 Conductor ~ @ +/-161' MD \ ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors Rig 245 RKB @ 0' Eastings: 561,930.71 Northings: 5,968,597.14 Elevation: 102.0' AMSL ~Casing Hanger: ~ Vetco-Gray, with 8-5/811, 36#, Hydril 511 pin down x Acme box up (2) Joints Casing: 8-5/811,36#, N-80, Hydril 511 ~ Crossover: 8-5/811, 36#, N-80 Hydril 511 Box by 7-5/811,29.7#, L-80, BTC Pin Port Collar: TAM, 7-5/811, 29.7#, L-80, BTC Pin Set @ +/- 1000' MD / 982' TVD ~ (x) Joints Casing: 7-5/811,29.7#, L-80, BTCM External Casing Packer ~ Baker Model CTC 'Payzone', 30 ft length, 7-5/ ~ 811, 29.7#, L-80, BTCM, with 8 ft handling pup above and 3 ft handling pup below. Set at depth to isolate '8' Sand from' A' Sand ~(X) Joints Casing: 7-5/811,29.7#, L-80, BTCM I( Float Collar: Weatherford 7-5/811, 29.7#,BTCM (2) Joints Casing: 7-5/811,29.7#, L-80, BTCM « ==-- ~ Float Shoe: ~ Weatherford 7-5/811, 29.7#,BTCM TD 9-7/811 Hole: 6,474' MD /4,271' TVD 1 C-127 Completion Schematic Sheet 1 of 3: Casing String Details prepared by Steve McKeever June 7, 2001 (' Well # 1C-127, AFE #AK0174 West Sak Dual Purpose Well Completion Schematic Sheet 2 of 3: 'A' Sand Completion Details See Sheet 3 for 'B' and '0' Sand Completion Details 'A' Sand Perforations Plug Back TD @ +1- 5,330 MD ~~~ <3 <I <J ~,Ji t ," J' Î: ~ ~: ~~, "C c: m en co 't"'" I 'II::t 't"'" } oX CJ m D. ã; > m ø ~ i ' I ¡ I I :~ I '1'1',' ""'1' ',',1,1 1,1,1,1 ',1,1,' 'I',',' ',11'1' 1,1,111 1,',',1 III' ,',',',~ ' ,I,',', ~ ,',1,1, 1','111 "I ',I,ll' ',I,ll' '1'1'1' '1'1'1' ',','1' 1,',',1 11I1I11 1,11111 1,11111 '11,1,1 11111,1 I111111 'lilli' -~ i' ~~ ~' " ----- . \J. .:"" " ,'( ".. :~. :7~' ~1 :~~...... 7-5/8", 29.7#, L-80 casing @ 6,474' MD / 4,271' TVD ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Packer: Baker Model SC-1, wI 80-40 Seal Bore Extension and Sliding Sleeve. Set Above Top A-Sand Perforation. Gravel Pack Extension: Baker Model "S", Size 80-40 with Sliding Sleeve and lower extension, 5-1/2",18#, SLHT Pin x 5" 18# SLHT Pin XO: 5",18#, SLHT Box by 4",9.5#, SLHT Pin Tubing Pup: 4 ft long, 4", 9.5#, SLHT Box x Pin Nipple: 'XN', , 2-3/8", with 1.875" Polished Bore and 1.791" No-Go, installed into nipple reducer of 4" 'XN' Nipple Nipple: 'XN', ,4",9.5#, SLHT Box x Pin, with 3.313" Polished Bore and 3.135" No-Go, with nipple reducer XN lock installed. Shear Out Safety Joint: Baker Model GPR-24, 4", 9.5#, SLHT Box x Pin Excluder: Baker 2000, 4", 9.5#, SLHT Box x Pin Screen: Bakerweld 140, 4", 9.5#, SLHT Box x Pin Bull Plug: Baker, 4", 9.5#, SLHT Box up Bridge Plug: Baker Model N-1, 7-5/8", 29.7#, Size 4AA Set +/- 10 feet below bottom perforation. 1 C-127 Completion Schematic Sheet 2 of 3: :4' Sand Gravel Pack Details prepared by Steve McKeever June 7, 2001 ( Well # 1C-127, AFE #AK0174 West Sak Dual Purpose Well Completion Schematic Sheet 3 of 3: 'B' & 'D' Completion Details Wellhead & Tree: ABB Vetco Gray, Oual Horizontal with Coil Hanger II. . 211 Coil Tubing: rr . - 3-1/2 Tubmg, 9.2#, L-80, Hydnl511 Jet Pump: fi ) Landing Nipple: Weatherford, for 2.813" Polished Bore, and ~I>',¡ for Weatherford Jet Pump, with 5' x 2.813" connection to 2" COil,li,' Polished Bore and No-Go at Top. 2-3/811 Tu~ing ~:~ 3-1/211 Tubing, 9.2#, L-80, Hydril511 4.6#, L-80, Hydnl 511 ¡; XO: Gaslift Mandrel: j I 3-1/2" 9.2#, L-80, Hydril 511 Box by 2-3/8" 4.6# Camco Model KBMM, 2-3/8", with 6' Handling ~.... IdIII L-80 Hydriol 511 Pin Pups top and bottom 2-3/811 Tubing, 4.6#, L-80, Hydril 511 ( PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Tubing Anchor: Baker Parallel K22, 2-3/8" x 2.688", wI XO's above to 2-3/8" Hydril 511 box ScoopHead: Baker, Size 470, 2-3/8" x 2.688", with XO's below to Hydril 511, Made up in long string. 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Dual Packer @ +1- 4950' (Top of '0'): Baker Model 4704 GT, wI XO's above & below to Hydril 511 from NU 10rd pins top & bottom. 2-3/811 Tubing Pups 4.6#, L-80, Hydril 511 Telescoping Swivel: Baker, with 2 ft stroke, 2-3/8", 4.6# with XO on bottom from 2-3/8" NU 10rd to Hydril 511 pin 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511, Spaced out to be opposite the Slidign Sleeve 2-3/811 Tubing 4.6#, L-80, Hydril 511 Sliding Sleeve: Baker Model Slimline eMU, 2-3/8" x 1.875",with XO's top and bottom from 2-3/8" RTS-8 to Hydril511, Set above Top Perforation. 2-3/811 Tubing: 4.6#, L-80, Hydril 511 Landing Nipple: Halliburton 'X' , 2-3/8", 1.875" Polished Bore, Hydril511 Box and Pin 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511, Spaced out to be opposite the Gas Lift mandrel 2-3/811 Tubing, 4.6#, L-80, Hydril 511 ~ Dual Packer @ +/- 5941' (Mid 'c' Shale): Baker Model 4704 GT, wI XO's above & below to Hydril511 from NU 10rd pins top & btm. Waterflood Mandrel: Camco Model KBMGW, 2-3/8", with 6' Handling Pups top and bottom 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Polished Bore Receptacle: Baker, 2-3/8" x 1.875" Bore, 2-3/8", Hydril511 Tubing Joint: 30 ft long, 2-3/8", 4.6#, L-80, Hydril511 Landing Nipple: Halliburton 'XN' , 2-3/8", 1.875" Polished Bore, 1.791" No-Go, Hydril 511 Box and Pin Seal Assembly: Baker, 80-40 with Snap Latch, Indexing Mule Shoe, 14 ft long, wI 6 foot handling pup (2-3/8", 4.6#, Hydril 511) Packer @ +1- 5991' (Top 'A-4' Sand) Baker Model SC-1, wI 80-40 Seal Bore Extension and Sliding Sleeve. Set Above Top A-Sand Perforation prior to 'A' Sand gravel pack. Tubing Pup Joint: 10 ft long, 2-3/8", 4.6#, L-80, Hydril511 1 C-127 Completion Schematic Sheet 3 of 3: 'B' and '0' Sand Completion Details prepared by Steve McKeever June 7, 2001 ~~~ . PHILUPS ~ PHILLIPf ~Iaska, Inc. IÐ A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 ().()360 James Trantham Phone(907)265~ Fax: (907) 265-1535 Email: jtranth@ppco.com June 7, 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 Dual Purpose Well lC-123. Dear Commissioners: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore well in the West Sak Oil Pool, #lC- 127. This well will be completed with two strings of tubing, with one string being used for injection to provide pressure support for production from the West Sak "D" and "B" sands, and the other string being us~d for oil production from the West Sak "A" sand. The expected spud date for this well is June 21, 2001. 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 263-6434 or Steve McKeever at 265-6826. Sincerely, \ ~~) (1 (/\ù2~' ~()~«-L James Trantham Drilling Engineering Supervisor ( . TRANSMIT AL LETTER CHECK LIST ( CIRCLE APPROPRIATE LETTER/PARAGRAPHS 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) v DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNULAR DISPOSAL ('. I l'::-J L,:., V INJECTION WELL ANNULAR DISPOSAL v <--> YES INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL \c:.-\~\ "CLUE" The permit is for a new wellbore segment of existing well --J 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(1), 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 Disposalof drilling wastes will not be approved. .. -Amnllør nisro!i1!'t' nf drilline W9,tflU; will not be A"'lnon~d ~ . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS~ 5/:.,1:-... ..A.-nA(./r-'\(;:.:Xj - ~YES+ SPACING EXCEPTION 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. c..J ù~ \ u..)<è.\ \ \,,\q~~Ð\~~~~' . J'ùD,/ - ?t-~~E.. ~ .'~'6 4\~ù1" 7~ G~é- ßL..;o~ J- )N-i\L-t'eWú ~"(T~- lJ\t~ a~ (S A. Ll77 Ll:.. J)IFr~7 ~6"""itD( ÑG ~ tJN\JLA~ Dl6i<:>~L.. -r~\~ ~\~ Templates are located m drive\jody\templates ~ fib ~ m,'< \, ß1 \'\: ~( '/1\ cQ) J J\.. ~.b ~ J ~ -.::JJL æJ --~..fli ALASIi.& OIL AND GAS CONSERVAnONCO~SSION rAJY KNOWLES, GOVERNOR ,( 333 W. "fTH AVENUE. SUITE 1 00 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J ames Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit 1 C-123 Phillips Alaska, Inc. Permit No: 201-084 . SurLoc: 1609' FNL, 874' FWL, Section 12, TII1N, RIDE, UM Btmhole Loc. 1995' FSL, 1292'FEL, Section 11, TIIN, RIOE, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced w~ll. The permit to drill does not exempt you from obtaining, additional permits required by law from other governmental agencies, and does' not authorize conducting drilling operations until, all other required permitting determ, inati~ns are made. -f ~ ~r ~I.Þ/>-J.')S >-- Based on oulinfurmntion¡no ann~lar ,iij,currentlyapproved for disposal o.Mpad. f\Nt-)\ì~l A tZ-t:. .LD Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 'hours) must" be given to allow a representative 'of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~M.~ Julie M. Heusser Commissioner BY ORDER OF ~E COMMISSION DATED this J1 day of May, 2001 jjc/Enc1osures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo enc!. 1nI,"'if~,',1, ~""."t ,}'è ;'U/\ American Express~ Cash Advance Draft 139 DATE B J~~ z¿;o/ ~~:~g;E- )-t<~-(J II~& / ~CC -- loci SI!~Cò I . O~ ~J d"t~ ~ It" < DOLLARS 82-1011021 Issued.' by Integrated Payment System, Inc. Englewood. Colorado PERIOD ENDING ~=~71~ I: ~ 0 2 ~ 0 0 a.. 0 0 I: ~ 5 II' 0 ~ ? 5000 5 ~ bill 0 ~ ~ c¡ Pay¡W1e at Norwest~k øfGrand Junction - Downtown. NA GI'aI1dJunction. Colorado .- I ,., t I kp'q WELL PERMIT CHECKLIST COMPANY f>1; / ¡) ;f..l WELL NAME / c. - / .z..-7 PROGRAM: exp - dev ~ redrll- serv - wellbore seg _ann. disposal para req - FIELD & POOL Lf1D)~5c> INITCLASS O(""'LI /"'0/)') GEOLAREA 7-9ê\ UNIT# /1/6e> ON/OFFSHORE ð,u ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . .. . . . . . . . . . 0N b 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . .. . . . .. . Y ,N 4. Well located in a defined pooL. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit. ... '. . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N IJ JJ J ~~_R,' R YI:-/!~ ~} 12. Permit ca~ be issued without administrativ~ approval.. . . . . \ Y N f1T G/ ~ .?1! '..c..¡ / ./ 13. Can permit be approved before 15-day walt.. . . . . . . . . . \::!J N ENGINEERING 14. Conductor string provided. . . . .. . .. . . . . . . . . . . ~ N 15. Surface casing protects all known USDWs. . ."'. . . . . . . . ,N 16. CMT vol adequate to circulate on conductor& surfcsg. . . . . Y N 17. CMTvol adequate to tie-in long string to surfcsg. ....... Y N ~'Þ-.~~~--"'\."""':>~~\'\ 18. CMT will cover all known productive horizons. . . '. . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N 20. Adequate tankage or reserve pit.. . . . . . . . . . .. . . . . "N <L1--~~\-~ ~ ~'~, "C~~((:,.~\~ ~\À- 21. If a re-drill, has a 10-403 for abandonment been approved. . . --¥-N' ~ ~ 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . .. . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . .. . . . . . . . . . . N, ,.L, ~. .. \ C'\." \ lo." \ - ~ L\ h. 26. BOPE press rating appropriate; test to '\ht)"t) psig. N "'~,~, ~', ~ \ec cl~ '\ ~ ('~~ ~~C) t"\\"",~~~ ~'> ,Ot'CtO\II~~~" 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . .1 Þl, r'\. ~ \ 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y Qi) ~ \... ~~\~f{C,)'Wr '>~f'~"> ~ ~ ~~,. 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Da, ta presented on potential 0, ve, rpressure zones. . . . . . . y' / ) /) 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y /f ./. f-J" AßfR 9~!E/ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N rI ¿ WI.q'ð) 34. Contact name/phone for weekly progress reports [exploratory onl Y N C\ ~ '-, ANNULAR DISPOSAL35. With proper cementing records, this plan bt. ~ \r--.>t-o ~"'~\>~~<r))\ '-.. ~<t\\. ~\~~~ t Þ. ~ ~~~~\'o~\ "\ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N : ,. ' -\..~""~ ~\ \. (B) will not contaminate freshwater; or cause drilling waste. .. Y N f/J;.1"\ôê-. \)&<:.., -f':\'t7f\~O ì.:AÑGJA6f. Op- to surface; , ...:so~î' \:--\ \J-,)G S\ "" I '{..,.t;P- - Wh J (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEO~~Y: ENGINEERING: UIC/Annular COMMISSION: ~Þ8~ - ~ð~ WM 8~s úiI TE~~Í\7 JMH ðlf\'\.H ~({ç Iffi1 fA~ GEOLOGY APPR DATE c 0 Z 0 -I :E :u ) -I m Z -I :I: en » :u m » ì Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) 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 information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special. effort has been made to chronologically organize this category of information. c!ds, ( ~ Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe 1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 1, 2005 6518 1 3.5" 9.3Ib. L-80 Tubing Well: 1C-127 Field: Kuparuk State: Alaska API No.: 50-029-23024-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 5,992 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the WLEG @ 5,992' (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 condition with respect to corrosive damage, with the exception of a 22% wall penetration in joint 184 (5,861'). 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. Deposits are recorded in the interval between joints 100 and 106 (3,270' - 3,400'), with a minimum 1.0. of 2.50" (3,305'). 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 ( 22%) Jt. 184 @ 5,861 Ft. (MD) Corrosion ( 20%) Jt. 77 @ 2,481 Ft. (MD) Line of Pits ( 20%) Jt. 183.3 @ 5,839 Ft. (MD) Isolated Pitting ( 20%) Jt. 184.3 @ 5,893 Ft. (MD) Isolated Pitting ( 20%) Jt. 184.9 @ 5,931 Ft. (MD) MAXIMUM RECORDED CROSS..SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits Minimum 1.0. = 2.50" Minimum 1.0. = 2.50" Minimum 1.0. = 2.50" Minimum 1.0. = 2.60" Minimum 1.0. = 2.60" Jt. Jt. Jt. Jt. Jt. 104 @ 101 @ 105 @ 106 @ 103 @ 3,305 Ft. (MD) 3,214 Ft. (MD) 3,356 Ft. (MD) 3,266 Ft. (MD) 3,267 Ft. (MD) r..··.'. {'.·I!.'A ~~~~\~\~~.)) f) 'u G 2 () 2.0 US ;;'~ß¿i "~b~~\'l~,,-;~·'· ~..~ " I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services! lne. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 fax: (907) 659-2314 '7 )~\ - \\'-1 ck3s" Well: Field: Company: Coun try: 1 C-12 7 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA I Tubing: Weight 9.3 ppf Grade & Thread L-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 BIIJ metal loss body 150 100 50 o 0 to 1% 10 to 20 to 40 to 20% 40% 85% 1 to 10% over 85% Number of joints analysed (total = 206) pene. 1 63 141 1 0 loss 34 172 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 = 113) 50 60 3 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 1, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o 1 ~ metal loss body 50 100 45 Þ. F F- ~ c.....- æ:= s::- 95 145 GLM 1 GLM2 GLM3 =- 5::- it - 185~ !:-- Bottom of Survey = 185.9 Analysis Overview page 2 ~ ~ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-127 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 1, 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 1 35 0 0.04 17 .2 2.92 Shallow pitting. 1.1 66 0 0.03 13 .2 2.89 PUP Shallow pitting. 1.2 70 0 0.03 12 0 2.90 PUP Shallow pitting. 1.3 73 0 0.04 17 7 2.91 PUP Shallow corrosion. 1.4 75 0 0.03 13 1 2.92 PUP Shallow pitting. 2 80 0 0.03 13 3 2.89 Shallow pitting. 3 114 0 0.04 17 5 2.93 Shallow corrosion. 4 145 0 0.04 16 6 2.94 Shallow corrosion. 5 177 0 0.04 17 .2 2.92 Shallow corrosion. 6 208 0 0.03 13 .2 2.92 Shallow pitting. 7 240 0 0.04 16 .2 2.93 Shallow corrosion. 8 271 0 0.04 16 5 2.94 Shallow pitting. 9 303 0 0.04 17 3 2.94 Shallow corrosion. 10 334 0 0.05 18 3 2.93 Shallow corrosion. 11 365 0 0.04 16 6 2.91 Shallow corrosion. 12 396 0 0.04 15 5 2.94 Shallow corrosion. 13 427 0 0.03 13 4 2.92 Shallow corrosion. 14 459 0 0.04 15 .2 2.94 Shallow pitting. 14.1 490 0 0.04 14 1 2.89 PUP Shallow corrosion. 14.2 496 0 0 0 0 2.88 OS N jpple 14.3 498 0 0.03 11 1 2.92 PUP 15 504 0 0.04 18 4 2.94 Shallow corrosion. 16 535 0 0.04 17 5 2.94 Shë;dlow corrosion. 17 566 0 0.05 19 2 2.93 Shallow corrosion. 18 597 0 0.04 16 6 2.91 Shallow corrosion. 19 628 0 0.05 18 3 2.92 Shallow corrosion. 20 660 0 0.04 17 7 2.89 Shallow corrosion. 21 690 0 0.03 12 2 2.93 22 722 0 0.05 18 4 2.93 Shallow corrosion. 23 752 0 0.04 17 5 2.94 Shallow corrosion. 24 783 0 0.04 15 6 2.94 Shallow corrosion. 25 815 0 0.04 15 3 2.94 Shallow corrosion. 26 846 0 0.04 17 4 2.93 Shallow corrosion. Lt. Deposits. 27 877 0 0.04 17 3 2.94 Shallow corrosion. 28 909 0 0.04 15 3 2.95 Shallow corrosion. 29 940 0 0.03 13 4 2.94 Shallow pitting. 30 972 0 0.03 13 2 2.94 Shallow pitting. 31 1003 0 0.04 15 6 2.93 Shallow corrosion. Lt. Deposits. 32 1034 0 0.05 19 4 2.91 Shallow corrosion. 33 1066 0 0.05 19 6 2.92 Shallow corrosion. 34 1097 0 0.03 10 1 2.92 35 1129 0 0.02 9 1 2.91 36 1160 0 0.02 9 1 2.90 37 1192 0 0.01 4 2 2.90 38 1223 0 0.01 3 2 2.91 39 1255 0 0.01 3 2 2.91 40 1286 0 0.03 11 2.91 ~ 41 1317 0 0.03 11 2 2.91 42 1349 0 0.04 14 3 2.90 Shallow corrosion. 43 1380 0 0.03 12 1 2.87 I Penetration Body [~iì:l; Metal Loss Body Page 1 {l PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-127 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 1, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) ala (Ins.) 0 50 100 44 1412 0 0.01 5 2.89 ~ 45 1443 0 0.03 12 2.92 46 1475 0 0.03 11 2.91 47 1506 0 0.03 10 2.89 48 1537 0 0.02 9 ~ 2.88 49 1569 0 0.01 2 ~ 2.89 50 1600 0 0.01 4 1 2.89 51 1632 0 0.03 11 1 2.90 52 1663 0 0.01 3 2 2.91 53 1695 0 0.03 11 2 2.90 54 1726 0 0.01 4 2.91 55 1758 0 0.01 2 2 2.91 56 1789 0 0.04 14 2 2.89 Shallow corrosion. 57 1821 0 0.03 10 2.86 58 1852 0 0.03 10 2 2.86 59 1883 0 0.03 10 2.88 60 1915 0 0.02 9 2 2.89 61 1946 0 0.03 10 1 2.89 62 1978 0 0.03 11 1 2.89 63 2009 0 0.01 4 2 2.86 64 2041 0 0.04 14 2.87 Shallow corrosion. 65 2072 0 0.02 9 2 2.88 66 2104 0 0.03 13 2 2.86 Shallow corrosion. 67 2135 0 0.03 10 2 2.83 68 2167 0 0.03 10 2 2.82 69 2198 0 0.01 5 2 2.82 70 2229 0 0.03 10 2 2.84 71 2261 0 0.03 10 2 2.82 72 2292 0 0.02 9 2 2.82 73 2324 0 0.03 13 3 2.84 Shallow pitting. 74 2355 0 0.02 9 3 2.85 75 2387 0 0.02 8 2 2.83 Lt. Deposits. 76 2418 0 0.02 9 2 2.85 77 2450 0 0.05 20 .3 2.84 Corrosion. 78 2481 0 0.04 15 4 2.85 Shallow corrosion. 79 2513 0 0.02 9 .3 2.84 80 2544 0 0.03 11 3 2.77 81 2575 0 0.04 15 2 2.78 Shallow pitting. 82 2607 0 0.03 13 4 2.81 Shallow pitting. 83 2638 0 0.03 13 .3 2.79 Shallow pitting. Lt. Deposits. 84 2670 0 0.04 17 5 2.80 Shallow corrosion. Lt. Deposits. 85 2701 0 0.03 11 2 2.84 86 2733 0 0.04 15 3 2.82 Shallow corrosion. 87 2764 0 0.03 10 3 2.80 Lt. Deposits. 88 2795 0 0.04 16 4 2.82 Shallow corrosion. 89 2827 0 0.03 11 4 2.83 90 2858 0 0.03 11 3 2.83 Lt. Deposits. 91 2889 0 0.03 11 3 2.85 92 2921 0 0.03 10 .3 2.84 93 2952 0 0.04 14 4 2.83 Shallow corrosion. deposits. ! Penetration Body /i:ii Metal Loss Body Page 2 · Ii PDS\ KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1C-127 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 1, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 01<) (Ins.) 0 50 100 94 2983 0 0.03 10 4 2.79 Lt. Deposits. 95 3015 0 0.04 14 4 2.82 Shallow pitting. 96 3046 0 0.03 11 4 2.87 97 3078 0 0.03 11 3 2.83 98 3109 0 0.03 1 1 3 2.82 Lt. Deposits. 99 3140 0 0.03 10 3 2.85 Lt. Deposits. 100 3172 0 0.03 12 4 2.69 Deposits. 101 3203 0.02 0.03 10 1 2.50 Deposits. 102 3235 0 0.02 9 5 2.61 Deposits. 103 3266 0.05 0.02 9 1 2.60 Deposits. 104 3298 0 0.02 9 2 2.47 Deposits. 105 3329 0.03 0.02 9 6 2.50 Deposits. 106 3359 0 0.03 11 4 2.58 Deposits. 107 3392 0 0.03 '11 5 2.83 108 3423 0 0.03 12 3 2.83 Lt. Deposits. 109 3454 0 0.03 12 4 2.76 Shallow pitting. 110 3486 0 0.03 13 4 2.78 Shallow pitting. 111 3517 0 0.02 9 2 2.81 Lt. Deposits. 112 3549 0 0.03 13 5 2.82 Shallow corrosion. 113 3580 0 0.04 14 5 2.80 Line shallow corrosion. Lt. Deposits. 114 3611 0 0.03 13 7 2.80 Shallow pitting. Lt. Deposits. 115 3643 0 0.04 17 5 2.81 Shallow corrosion. Lt. Deposits. 116 3674 0.02 0.02 9 3 2.81 Lt. Deposits. 117 3706 0 0 0 3 2.75 Lt. Deposits. 118 3738 0 0.03 13 4 2.79 Shallow pitting. Lt. Deposits. 119 3769 0 0.04 16 3 2.79 Shallow pitting. Lt. Deposits. 120 3800 0 0.03 10 4 2.87 121 3832 0 0.03 12 6 2.86 122 3863 0 0.04 15 6 2.87 Shallow corrosion. 123 3895 0 0.04 14 6 2.87 Shallow pitting. 124 3926 0 0.03 13 4 2.88 Shallow pitting. 125 3957 0 0.04 14 7 2.88 Shallow corrosion. 126 3989 0 0.03 10 3 2.87 127 4021 0 0.04 14 5 2.86 Shallow pitting. 128 4052 0 0.03 13 3 2.83 Shallow pitting. 129 4083 0 0.03 11 4 2.85 130 4115 0 0.03 10 4 2.81 131 4146 0 0.04 17 5 2.81 Shallow pitting. 132 4177 0 0.04 15 3 2.81 Shallow corrosion. 133 4209 0 0.03 13 5 2.78 oval. Shallow pitting. 134 4240 0 0.04 15 6 2.84 Shallow corrosion. 135 4272 0 0.04 17 6 2.86 Shallow corrosion. 136 4303 0 0.03 13 6 2.85 Shallow pitting. 137 4335 0 0.03 12 5 2.81 Shallow pitting. 138 4366 0 0.02 9 5 2.87 139 4398 0 0.04 14 6 2.81 Shallow corrosion. 140 4429 0 0.04 15 4 2.87 Shallow pitting. 141 4460 0 0.03 13 5 2.88 Shallow pitting. 142 4491 0 0.04 14 4 2.80 Shallow corrosion. 143 4522 0 0.04 15 3 2.81 Shallow corrosion. I Penetration Body I:':~tl Metal Loss Body Page 3 '\ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1C-127 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHllLlPS ALASKA, INC. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 1, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body °/0 loss 1.0. Comments (% wall) (Ins.) (Ins.) 0/ (Ins.) 0 50 100 10 144 4553 0 0.04 15 4 2.86 Shallow pitting. 145 4585 0 0.04 15 4 2.85 Shallow pitting. 146 4616 0 0.04 15 4 2.81 Shallow pitting. 147 4648 0 0.03 12 3 2.82 oval. 148 4679 0 0.04 14 4 2.88 Shallow corrosion. 149 4710 0 0.04 14 10 2.88 Shallow pitting. 150 4741 0 0.03 13 10 2.89 Shallow pitting. 151 4772 0 0.04 14 10 2.91 Shallow pitting. 152 4804 0 0.04 14 8 2.86 Shallow corrosion. 153 4835 0 0.04 15 3 2.89 Shallow corrosion. 154 4866 0 0.05 19 7 2.90 Shallow corrosion. 155 4898 0 0.03 13 5 2.81 Shallow corrosion. Lt. Deposits. 156 4929 0 0.02 8 3 2.81 157 4960 0 0.03 11 .2 2.89 158 4991 0 0.02 9 7 2.82 159 5024 0 0.03 13 .2 2.86 Shallow corrosion. 160 5055 0 0.03 12 3 2.90 161 5087 0 0.03 10 .2 2.83 162 5118 0 0.02 9 .2 2.83 163 5149 0 0.02 7 2 2.86 164 5180 0 0.01 5 .2 2.86 165 5212 0 0.04 17 3 2.84 Shallow pitting. 166 5243 0 0.03 13 2 2.86 Shallow pitting. 167 5274 0 0.02 9 .2 2.85 168 5306 0 0.04 14 .2 2.90 Shallow corrosion. 169 5337 0 0.02 9 2 2.91 170 5369 0 0.02 8 3 2.91 171 5400 0 0.03 11 4 2.92 172 5431 0 0.03 10 2 2.91 173 5463 0 0.04 17 .2 2.87 Shallow corrosion. 174 5494 0 0.03 10 2.86 175 5525 0 0.03 11 2 2.89 176 5556 0 0.05 18 6 2.88 Shallow corrosion. 177 5587 0 0.04 18 6 2.91 Shallow corrosion. 178 ,5619 0 0.04 14 6 2.94 Shallow corrosion. 179 5650 0 0.04 14 5 2.93 Shallow pitting. 180 5680 0 0.03 13 4 2.92 Shallow corrosion. 181 5711 0 0.04 14 6 2.92 Shallow pitting. 182 5742 0 0.03 13 6 2.93 Shallow pitting. 182.1 5771 0 0.02 8 1 2.82 PUP 182.2 5777 0 0 0 0 N/A GLM 1 (Latch @ 3:00) 182.3 5785 0 0.03 13 1 2.87 PUP Shallow corrosion. Lt. Deposits. 183 5791 0 0.05 18 4 2.91 Shallow pitting. 183.1 5823 0 0.03 13 1 2.91 PUP Shallow pitting. 183.2 5829 0 0 0 0 3.88 PACKER 183.3 5839 0.05 0.05 20 .2 2.90 PUP Line of pits. 184 5845 0 0.06 22 2 2.94 PUP Line of pits. 184.1 5876 0.07 0.02 9 6 2.85 PUP 184.2 5880 0 0 0 0 N/A GlM 2 (Latch @ 1 :00) 1 84.3 5890 0 0.05 20 2 2.93 PUP Isolated pitting. I Penetration Body 1,1:!'~!! Metal Loss Body Page 4 ;({ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-12 7 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 1, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 84.4 5896 0 0.04 17 1 2.93 PUP Shallow pitting. - 184.5 5901 0 0 0 0 2.81 Sliding Sleeve 184.6 5906 0 0.01 2 1 2.91 PUP 1 84.7 5912 0 0.02 8 2 2.92 PUP 184.8 5918 0 0 0 0 3.88 PACKER 184.9 5925 0 0.05 20 3 2.90 PUP Shallow pitting. 185.1 5932 0 0.04 14 4 2.92 PUP Shallow pitting. 185.2 5937 0 0 0 0 N/A GLM 3 (LATCH @ 11 :00) 1 85.3 5946 0 0.04 15 1 2.91 PUP Shallow pitting. 185.4 5952 0 0.03 13 1 2.91 PUP Shallow pitting. 185.5 5958 0 0 0 0 2.75 Sliding Sleeve 185.6 5962 0 0.04 14 1 2.93 PUP Shallow pitting. 185.7 5967 0 0.02 8 1 2.91 PUP 185.8 5973 0 0.00 2 1 2.97 PUP 185.9 5982 0 0 0 0 N/A Seal Assembly I Penetration Body ,:::C: Metal Loss Body Page 5 cId..·.-.. ~....-.c- -.... -......... .. '. '. . ~. ·-6 I" PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-127 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 1, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 184 at depth 5860.61 ft Tool speed = 53 NominallD = 2.992 Nominal 00 = 3.500 Remaining wall area = 99 % Tool deviation = 20 0 Finger 3 Penetration = 0.056 ins Line of pits 0.56 ins = 22% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cld. ... ..:--.. -.-.·~.·:.·.....··....5.~ ~...- ~ ....~ c-. '- ~ - "- - - j~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-12 7 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA 3.5 ins 9.3 ppf L-BO Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 1, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 104 at depth 3304.72 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 71 0 Finger 6 Projection = -0395 ins Deposits Minimum 1.0. = 2.47 ins HIGH SIDE = UP Cross Sections page 2 .£:..J ~SJ" PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-12 7 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 1, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 101 at depth 3213.86 ft Tool speed = 47 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 79 0 Finger.5 Projection = -0.372 ins Deposits Minimum 1.0. = 2.50 ins HIGH SIDE = UP Cross Sections page 3 TUBING (0-5981 , 00:3.500, 10:2.992) Perf (5864-5904) Perf (5933-6003) Perf (5934-5970) SEAL (5975-5978, 00:4.000) PACKER (5978-5981, 00:6.500) JOINT (5987 -5991, 00:3.690) \ ConocoPhillips Alaska, Inc. .. API: 500292302400 SSSV Type: Nipple Annular Ruid: Reference Log: Last Tag: 6277 Last Tag Date: 9/3/2003 Casing String - ALL STRINGS Description CONDUCTOR SU RF/PROD SURF/PROD Tubing String - TUBING Size I Top 3.500 0 Peñorations Summary Interval TVD 5864 - 5904 3700 - 3738 5933 - 5934 3765 - 3766 5934 - 5970 3766 - 3800 5970 - 6003 3800 - 3832 6022 - 6038 3850 - 3866 6048 - 6070 3875 - 3897 6112 - 6134 3938 - 3959 Gas Lift MandrelslValves st MD TVD Man Man Type Mfr 1 5777 3621 CAMCO MMG Injection MandrelslValves St MD TVD Man Man Type Mfr 2 5882 3717 CAMCO MMG 3 5938 3770 CAMCO MMG Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 495 495 NIP 5830 3669 PACKER 5902 3736 SLEEVE-C - . ~ 1C-127 5920 5958 5974 5975 5978 5981 5986 5987 5991 5992 3753 3789 3804 3805 3808 3811 3816 3817 3820 3821 PACKER SLEEVE-C LOCATOR SEAL PACKER Extension XO JOINT NIP WLEG Well Type: INJ Orig Completion: 7/212001 Last w/o: Ref Log Date: ìD: 6450 ftKB Max Hole Angle: 67 deg ~ 2600 Size 16.000 8.625 7.625 Top o o 134 Bottom 158 134 6450 Bottom 5981 TVD 3811 Wt 9.30 Zone WS D WS B WS B WSA4 WSA3 WSA3 WSA2 Status Ft SPF 40 4 1 4 36 8 33 4 16 4 22 4 22 4 Date 8/4/2002 8/3/2002 8/4/2002 8/3/2002 8/3/2002 8/3/2002 8/3/2002 V Mfr V Type VOD DMY 1.5 V Mfr V Type VOD DMY DMY 1.5 1.5 Description KRU 1C-127 Angle ~ TS: deg (â>. Angle ~ TD: 10 deg ~ 6450 Rev Reason: Correct TBG top Last Update: 12/27/2004 TVD 158 134 6450 Wt 62.50 36.00 29.00 Grade H-40 N-80 L-80 Th read WELDED 511 Hydril BTCMOD Grade L-80 Thread Eue8rdMod Type Comment IPERF 3 3/8" HDS IPERF 3 3/8" HDS RPERF 3 3/8" HDS IPERF 3 3/8" HDS IPERF 3 3/8" HDS IPERF 3 3/8" HDS IPERF 3 3/8" HDS Latch Port TRO RK o Date Run 12117/2002 Vlv Cmnt 0.000 Latch Port TRO RK RK o o Date Run 8/5/2002 8/5/2002 Vlv Cmnt 0.000 0.000 ID 2.875 3.875 2.812 CAMCO DS NIPPLE BAKER PREMIER PACKER BAKER CMU SLIDING SLEEVE W/2.812" DS PROFILE - CLOSED 9/21/2003 BAKER S-3 PACKER BAKER CMU SLIDING SLEEVE, 2.75" 'D' PROFILE - CLOSED 9/21/2003 BAKER 80-80 NO GO LOCATOR BAKER 80-40 SEAL ASSEMBLY W/ 1/2 MULE SHOE BAKER FB1 RETAINER PRODUCTION PACKER BAKER MILLOUT EXTENSION CAMCO 'D' NIPPLE W/2.25" PROFILE BAKER WIRE LINE GUIDE 3.875 2.750 3.000 3.980 4.000 4.500 2.390 2.441 2.250 2.380 **** REEL HEADER **** LDWG 02/11/19 AWS 01 **** TAPE HEADER **** LDWG 02/11/19 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: LISTAPE.HED TAPE HEADER WEST SAK UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING MWD RUN 1 1 S. FRANK R. SPRINGER MWD RUN 4 2 J. KANT R. SPRINGER MSL 0) 1C-127 500292302400 Phillips Alaska, Inc. BAKER HUGHES INTEQ 19-Nov-02 MWD RUN 2 1RR J. KANT R. SPRINGER MWD RUN 5 12 11N 10E 102.00 MWD RUN 3 1RR2 S. FRANK R. SPRINGER MWD RUN 6 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) /)DJ-/ly I / ~ ~'ð ( 3RD STRING PRODUCTION STRING 24.000 9.875 16.000 158.0 6450.0 # REMARKS: PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM WELL SITE. SURFACE LOCATION: LAT: N70 DEG 19' 12.887" LONG: W149 DEG 30' 56.800" LOG MEASURED FROM D.F. AT 102.0 FT. ABOVE PERM. DATUM (M.S.L.). BAKER HUGHES INTEQ RUNS 1 THROUGH 4 UTILIZED MULTIPLE PROPAGATION RESISTIVITY (MPR) SERVICES IN A STEERABLE ASSEMBLY FROM 158 - 6450' MD (158 - 4270' TVD). PER PAl GEOSCIENCE REQUEST, THE CURVE "RS60", A 60" FIXED DEPTH OF INVESTIGATION RESISTIVITY RESULT FROM INTEQ'S POST PROCESSING ROUTINE (MPRTEQ), IS INCLUDED IN THIS LDWG OUTPUT. MPRTEQ PROCESSING WAS REQUESTED OVER AND IS ONLY PRESENTED FOR THE INTERVAL FROM 5115 - 6315' MD. 1) 16" CASING DEPTH - LOGGER: 158' MD (158' TVD) 16" CASING DEPTH - DRILLER: 158' MD (158' TVD). RESISTIVITY DATA RECORDED OVER THE INTERVAL FROM 158 - 1998 FEET MD (158 - 1774' TVD) IS ERRATIC DUE TO THE PRESENCE OF PERMAFROST. 2) THE INTERVAL FROM 1177 TO 1234 FEET MD (1144-1193' TVD) WAS LOGGED UP TO 9.5 HOURS AFTER BEING DRILLED DUE TO A TRIP TO REPLACE A FAILED MWD TOOL. 3) THE INTERVAL FROM 1395 TO 1465 FEET MD (1329-1386' TVD) WAS LOGGED UP TO 8.3 HOURS AFTER BEING DRILLED DUE TO RIG REPAIRS AND A TRIP TO REPLACE A FAILED MWD TOOL. 4) THE INTERVAL FROM 3460 TO 3517 FEET MD (2419 - 2444' TVD) WAS LOGGED 14.0 HOURS AFTER BEING DRILLED DUE TO A TRIP TO CHANGE THE BIT. 5) THE INTERVAL FROM 6393 - 6450' MD (4214 - 4270' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT TD. $ Tape Subfile: 1 83 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEOOl.HED 1 clipped curves; all bit runs merged. .500 START DEPTH 158.0 STOP DEPTH 6450.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MIND MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 lR lR 2 MERGE TOP 158.0 1177.0 1408.0 3460.0 MERGE BASE 1177.0 1408.0 3460.0 6400.0 # REMARKS: MERGED PASS. PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. THE CURVE "RS60" IS THE 60" FIXED DEPTH OF INVESTIGA- TION RESISTIVITY RESULT FROM INTEQ'S MPRTEQ POST PROCESSING ROUTINE. IT IS PRESENTED OVER THE INTERVAL FROM 5115 - 6315' MD ONLY. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT lc127 5.xtf 150 - Phillips Alaska, Inc. lC-127 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RS60 RS60 RES60 0.0 ( ( ROP FET MTEM ROP FET MTEM ROPS RPTH TCDM 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 40 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 25 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 ROP MWD 68 1 FPHR 4 4 8 FET MWD 68 1 HR 4 4 9 MTEM MWD 68 1 DEGF 4 4 ------- 36 Total Data Records: 504 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 158.000000 6450.000000 0.500000 **** FILE TRAILER **** Tape Sub file: 2 556 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 ( ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ Extract File: FILE011.HED 2 log header data for each bit run in separate files. 1 .2500 START DEPTH 150.0 STOP DEPTH 1177.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 22-JUN-01 MSB 18655 6.75 MPR MEMORY 1234.0 150.0 1177.0 0 .0 26.5 TOOL NUMBER DAS7196 MPR 4859 SRIG5073 9.875 158.0 FW GEL 8.90 .0 .0 500 .0 .000 .000 .000 .000 .0 60.0 .0 .0 .00 .000 .0 0 BIT RUN 1 (MWD RUN 1) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) REMARKS: ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 1c127.xtf 150 Phillips Alaska, Inc. 1C-127 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 147 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 150.000000 1177.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 233 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** ! 1'! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE012.HED 3 log header data for each bit run in separate files. 1R .2500 START DEPTH 1177.0 STOP DEPTH 1408.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 23-JUN-01 MSB 18655 6.75 MPR MEMORY 1465.0 1177.0 1408.0 0 29.8 32.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. TOOL NUMBER DAS2160 MPR 4859 SRIG5073 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 158.0 # BOREHOLE CONDITIONS ( MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # (' FW GEL 9.05 .0 .0 400 .0 .000 .000 .000 .000 .0 62.0 .0 .0 .00 .000 .0 0 BIT RUN 1RR (MWD RUN 2) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 1c127.xtf 150 Phillips Alaska, Inc. 1C-127 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM RPCL RPCL RPCLM RPSL RPSL RPCSLM RPCH RPCH RPCHM RPSH RPSH RPCSHM ROPS ROPS ROPS RPTH RPTH RPTHM TCDM TCDM TCDM * FORMAT RECORD (TYPE# 64) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 34 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 1177.000000 1408.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 4 120 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 1408.0 LDWG File Version 1.000 Extract File: FILE013.HED 4 log header data for each bit run in separate files. lR .2500 STOP DEPTH 3460.0 ( $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 25-JUN-01 MSB 18655 6.75 MPR MEMORY 3517.0 1408.0 3460.0 0 32.1 66.9 TOOL NUMBER DAS2160 MPR 4859 SRIG5073 9.875 158.0 FW GEL 9.05 .0 .0 400 .0 .000 .000 .000 .000 .0 69.0 .0 .0 .00 .000 .0 0 BIT RUN 1RR2 (MWD RUN 3) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU '. WDFN LCC CN WN FN COUN STAT 1c127.xtf 150 Phillips Alaska, Inc. 1C-127 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 294 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 1408.000000 3460.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 5 380 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEOI4.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 log header data for each bit run in separate files. 2 .2500 START DEPTH 3460.0 STOP DEPTH 6450.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 27-JUN-01 MSB 18655 6.75 MPR MEMORY 6450.0 3460.0 6450.0 0 9.7 65.7 TOOL NUMBER DAS2160 MPR 4859 SRIG5073 9.875 158.0 FW GEL 9.45 .0 .0 200 .0 .000 .000 .000 .000 .0 85.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 # REMARKS: BIT RUN 2 (MWD RUN 4) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RS60 - MPRTEQ 60" FIXED DEPTH OF INVEST. RESIS. ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ (OHMM) # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT lc127.xtf 150 Phillips Alaska, Inc. lC-127 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RS60 RS60 RES60 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 40 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 25 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 ROPS MWD 68 1 FPHR 4 4 8 RPTH MWD 68 1 MINS 4 4 9 TCDM MWD 68 1 DEGF 4 4 ------- 36 Total Data Records: 479 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 3460.000000 6450.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 6 567 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 02/11/19 01 **** REEL TRAILER **** LDWG 02/11/19 AWS 01 Tape Subfile: 7 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes
